Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
204-199
• Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~,~ ~ - ~, ~ ~ Well History File Identifier Organizing (done) RESCAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: o,~,aea iiumiuuiruii DIGITAL DATA ~iskettes, No. ^ Other, NolType: Re.~a~~e~~ iuiuuiuiiuuu OVERSIZED {Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other.: BY: ~ Mari Date: ~ ~ ~ o ~ ~ (~ ~~ /s/ ` ~ Project Proofing III IIl~II VIII II III BY: Maria Date: ~ /s/ Scanning Preparation _,_,~ x 30 = + =TOTAL PAGES l0 i (Count does not include cover shee~f) BY: Maria Date: a /s/ Production Scanning Stage 1 Page Count firom Scanned File: (count does inciu~de co/ver sheet) Page Count Matches Number in Scanning Preparation: f/ YES NO BY: Maria Date: ~' /ad/©~] /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II((~IIII VIII ~I III ReScanned III II~IlI I~III II fll BY: Maria Date: Comments about this file: ~= /s! o,,,~~e~.e~ iuimiuiuumi 10/6/2005 Well History File Cover Page.doc ;~`- _.,,': ~~~ ~,. `Y. ~^-- , . .. MICROFILMED 03/0'1 /2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:~L.aserFiche\CvrPgs_InsertslMicrofilm Marker.doc 1 a ~.~ DATA SUBMITTAL COMPLIANCE REPORT 7/19/2007 Permit to Drill 2041990 Well Name/No. PRUDHOE BAY UN GRIN L-202L3 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23229-62-00 MD 10345 TVD 4444 Completion Date 7/11/2005 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples Nod Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD / GR, MWD / GR /RES / DEM / 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 I iy a meairrmc rvumoer Name ~caie meaia No Start Stop CH Received Comments D D Asc Directional Survey 0 10345 7/14/2005 pt Directional Survey 0 10345 7/14/2005 C Lis 15068 Induction/Resistivity 53 10344 Open 4/30/2007 LIS Veri, ROP, GR, DRHO, NPHI w/Graphics PDS & TXT Log 15068 Induction/Resistivity 2 Blu 6793 10345 Open 4/30/2007 MD Vision Service 5-Jul- 2005 Log 15068 Induction/Resistivity 2 Blu 6793 10345 Open 4/30/2007 TVD Vision Service 5-Jul- 2005 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y (~ Daily History Received? Chips Received? "~..~ Formation Tops 4 N Analysis Y~1V"'~ Received? Sample Interval Set Start Stop Sent Received Number Comments Comments: Compliance Reviewed By: ~~7 Date: 04/25/07 Schlum~erger Schlumberger-OCS 2525 Gambell St, Suite 400 Anchorage,AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 4223 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Orion Date BL Color CD L-213 ~ 11649950 MEMORY IPROF 03/17/07 1 W-210 S-104 11626075 10563057 USIT INJECTION PROFILE 03106107 05103/03 1 1 L-218 L-218 10913045 10913045 CEMENTlPERF EVALUATION MDT 09!04105 09104/05 1 1 S-111P81 S-111PB2 40011960 40011960 OH EDIT MWD/LWD OH EDIT MWDILWD 05/24/05 06/06105 2 2 1 1 L-202 L-202L7 40012017 40012011 OH EDIT MWD/LWD OH EDIT MWD/LWD 06/17/05 06/24/05 2 2 1 1 L-202L2 40012011 OH EDIT MWD/LWD 06/29/05 2 1 L-202L3 S-122 5-122PB1 40012011 40012137 40012137 OH EDIT MWDILWD OH EDIT MWDILWD OH EDIT MWD/LWD 07/05/OS 08/17/05 08109105 2 2 2 1 1 1 S-122P82 5-122PB3 40012137 40012137 OH EDIT MWD/LWD OH EDIT MWDILWD 08114105 08115105 2 2 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. ~ I Schlumber er-DCS Petrotechnical Data Canter LR2-1 ~-' 2525 Gambell St, Suite 400 900 E Benson Blvd. Anchorage, AK 99503-2838 Anchorage AK 99508-4254 ATTN: Belh (( ~~""~~ Date Delivered: Received by: y~~~y~ g~ fi,a ,~~~~~~~;;ems,' ~'{~e8a ~~~~~SiV1 ~14FA 4911 41d ~At9 g 's'., i STATE OF ALASKA ALASKA~L AND GAS CONSERVATION COMSION 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 2oAACZS.,,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 204199 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 7/3/2005 13. API Number 50-029-23229-62-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 7/5/2005 14. Well Name and Number: PBU L-202L3 2572 FSL, 3690 FEL, SEC. 34, T12N, R11 E, UM Top of Productive Horizon: 946' FSL, 1676' FEL, SEC. 27, T12N, R11E, UM (OA) g. KB Elevation (ft): 77.3' 15. Field /Pool(s): Prudhoe Bay Field / Orion Schrader Bluff Total Depth: 102' FSL, 1767' FWL, SEC. 26, T12N, R11E, UM 9. Plug Back Depth (MD+TVD) 10345 + 4444 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 583224 y- 5978293 Zone- ASP4 10. Total Depth (MD+TVD) 10345 + 4444 Ft 16. Property Designation: ADL 028238 TPI: x- 585190 y- 5981970 Zone- ASP4 Total Depth: x- 588644 Y- 5981166 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 EMENTING RECORD CASING fT7wc DEPTt~I MD ETTING D EPTH rvD 1-{OLE 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. 10-3/4" 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' 6781' 26' 4379' 9-718" 603 sx Class 'G' 4-1/2" 12.6# L-80 6776' 10324' 4378' 4443' 6-314" Uncemented Slotted Liner 23. Perforations open to Produc tion (MD +TV D of Top and " " 24. Tu61NG 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 6801' - 8662' 4386' - 4414' 8969' - 10281' 4418' - 4441' 25. , ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT S~ 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 AIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing PreSS. Casing Pressure CALCULATED 24-HOUR RATE AIL-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 ~F~ ~~ X ~ 2~~~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ~ ~ ~ 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 OA 6783' 4380' 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 i T h i l A t t D t ~ Titl ~ ~~'~S e ec n s an a ca ss e V ( Terrie Hubble PBU L-202L3 204-199 Prepared By Name/Number: TeYrie 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. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Irene 4b: TPI (Top of Producing Interval). Irene 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). Irene 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). Irene 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~IL AND GAS CONSERVATION COM SSION ~» t, rt;; WELL COMPLETION OR RECOMPLETION REPORT AND LOG -° .. - ~I~C ~. ~ ?~(~~ ia. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class ,-~,•- _ ®~3lopment [~ exploratory ^ Stratigraphi~ ~ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 7/11/2005 12. Permit to Drill Number 204-199 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 7/3/2005 13. APl Number 50-029-23229-62-00 4a. Location of Well (Governmental Section): Surtace: ' ' 7. Date T.D. Reached 7/5/2005 14. Well Name and Number: PBU L-202L3 2572 FSL, 3690 FEL, SEC. 34, T12N, R11 E, UM Top of Productive Horizon: 946' FSL, 1676' FEL, SEC. 27, T12N, R11 E, UM (OA) 8. KB Elevation (ft): 77.3' 15. Field /Pool(s): Prudhoe Bay Field / Orion Schrader Bluff Total Depth: 102' FSL, 1767' FWL, SEC. 26, T12N, R11E, UM 9. Plug Back Depth (MD+TVD) 10345 + 4444 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 583224 y- 5978293 Zone- ASP4 10. Total Depth (MD+ND) 10345 + 4444 Ft 16. Property Designation: ADL 028238 ___ TPI: x- 585190 y- 5981970 Zone-~ ASP4 Total Depth: x- 588644 y- 5981166 Zone- ASP4 11 • Depth where SSSV set (Nipple) 2258' MD 17. Land Use Permit: ------------~---- ----------_- ~------------"- 18. Directional Surrey ®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. ASING, LINER AND CEMENTING RECORD CASING ETT{NG EPTH MD ETTING EPTH ND HOLE MOUNT .SIZE WT. PER FT. GRADE OP OTTOM OP OTTOM SIZE GEMENTINQ RECORD PULLED 20" x 34" 215.5# A53 Surface 109' Surtace 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' 6781' 26' 4379' 9-7/8" 603 sx Class 'G' 4-1/2" 12.6# L-80 6776' 10324' 4378' 4443' 6-3/4" Uncemented Slotted Liner 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TuBwG RECORp Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Section 4-1l2", 12.6#, L-80 .6758' 6643' MD TVD MD TVD 6801' - 8662' 4386' - 4414' 8969' - 10281' 4418' - 4441' 25. ACID, FRACTURE, DEMENT SQUEEZE, ETC. - DEPTH INTERVAL MD AMOUNT 8c 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 fithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Sub it core chips; if none, state "none". ~` f,,a[ ~~ ~ ~ ~ ~~ ~ !~ C12 q3 ,~~ v:.. <'... i.Vi3 None IJ.4 1}~ll~ ~F~ At-G ~ ~ 1005 t z FDrm 10-407 ReVISed 12/2003 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 OA 6783' 4380' 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 Terris Hubble Title Technical Assistant Date PBU L-202L3 204-199 Prepared By Name/Number.• Terris Hubble, 564-4628 Well Number Permit No. / A rOVal No. Dolling Engineer: Michael Triolo, 564-5774 INSTRUCTIONS GeNeRAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing 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. Irene 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 BP EXPLORATION Page 1 of 4 Leak-Off Test Summary Legal Name: L-202 Common Name: L-202 -- Test Date Test Type Test Depth (TMD) Test Depth (ND) 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: 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 6/4/2005 00:00 - 03:00 3.00 MOB P PRE Set topdrive in rotary table, disconnect blocks from topdrive, bridle up, prep floor for derrick down move, tay 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. 03:00 -04:30 1.50 MOB P PRE Pull sub off L-2141, move sub around pad and position to pull over L-202. move pits around comer. 04:30 - 05:30 1.00 MOB P PRE Place well head equipment in cellar, lay mats, spread herculite, hang surface riser in cellar. 05:30 - 07:30 2.00 MOB P PRE Spot and level sub on L-202. 07:30 - 09:30 2.00 BOPSU P PRE Nipple up 20" Hydril and 16" diverter line, prior to setting mud pits. 09:30 - 10:30 1.00 MOB P PRE Spot and level mud pits, hook up power and service lines to pits. Accept Rig ~ 09:00 hrs 6/4/2005 10:30 - 12:30 2.00 RIGU P PRE PJSM, inspect and raise derrick. Raise and pin pipe chute. 12:30 - 14:00 1.50 RIGU P PRE Perform derrick inspection, bridle down, pin blocks to topdrive, take on water in pits. 14:00 - 16:30 2.50 BOPSU P PRE 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. 16:30 - 18:00 1.50 RIGU P PRE Service topdrive, install bails, adjust kelly hose. 18:00 - 19:00 1.00 RIGU P PRE Rig up floor. 19:00 - 23:00 4.00 RIGU P PRE Pick up 102 joints and rack back 34 stands of 5" DP. 23:00 - 00:00 1.00 RIGU P PRE Cut and slip drilling line. 6/5/2005 00:00 - 01:00 1.00 RIGU P PRE Held Pre-Spud meeting, with Co. Rep, Toolpusher, and all reig personnel. Pickup 14 joints 5" HWDP, jars and stand back. 01:00 - 01:30 0.50 RIGU P PRE Make up 3, 8" NM drill collars. 01:30 - 02:00 0.50 BOPSU P PRE Function test Diveter valve and 20" Hydril, Jeff Jones with AOGCC waived witness of diverter test. Rack back stand of drill collars. 02:00 - 03:00 1.00 RIGU P PRE Make up Bit, motor and MWD, tagged ice at 35', lay down stab and MWD. 03:00 - 03:30 0.50 RIGU P PRE Fill hole, check suface equipment for leaks. Drill ice from 35' to 108', POH rack back 1 stand HWDP. 03:30 - 05:00 1.50 RIGU P PRE Pickup remaing BHA per directional driller, PJSM, rig up Sperry e-line unit and Gyro tools. 05:00 - 07:00 2.00 DRILL P SURF Drill 13.5" Surface hole from 108' to 271, 595 gpm, 580 psi, 60 rpm, torque 1.5 to 2k 07:00 - 07:30 0.50 DRILL P SURF POH, stand back 2 stands 5" HWDP, pickup NM drill collars and jars. 07:30 - 12:00 4.50 DRILL P SURF 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. 12:00 - 20:30 8.50 DRILL P SURF 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 11:22:29 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: 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 6/5/2005 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 fast 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 C~ 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 SOk, 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 C~3 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' IJM drill collars, {ay 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 Page 3 of 21 Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Event Name: DRILL+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 9ES Date 'From-To Hours Task Code NPT Start: 6/3/2005 Rig Release: 7/11 /2005 Rig Number: Phase 6/7/2005 09:00 - 16:00 7.00 CASE P SURF 16:00 - 20:00 I 4.001 CASE I P I I SURF 20:00 - 00:00 4.001 CEMT ~ P I SURF 6/8/2005 00:00 - 02:00 2.00 BOPSU~ P SURF 02:00 - 07:30 5.50 BOPSU P SURF 07:30 - 12:00 4.50 BOPSU P SURF 12:00 - 12:30 0.50 BOPSU P SURF 12:30 - 14:30 2.00 BOPSU N SFAL SURF 14:30 - 16:00 I 1.501 BOPSUp P I I SURF Spud Date: 6/5/2005 End: 7/11 /2005 Description of Operations surface casing applying Best-o-life 2000 NM and 8,000 fflbs 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 C 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 71:22:29 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 Descripijon of Operations. 6/8/2005 14:30 - 16:00 1.50 BOPSU P SURF wear ring. 16:00 - 19:00 3.00 DRILL P INT1 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 float 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 INTi 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 4NT1 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 INTi 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 BHA#4 - 6 x 5" DP, ghost reamer, 48 x 5" DP, ghost reamer 20:00 - 21:30 1.50 DRILL P INTi 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 INTi RIH with BHA#4 on 5" DP to 3,240'. MAD pass from 3,240' to 3,303'. DriN from 3,303' to 3,501', 70i gpm, 1,680 psi, TQ on - 6k, PU - 115K, SO - 82K, ROT - 100K, 80 rpm, ART - 0.51. 6/10/2005 00:00 - 12:00 12.00 DRILL P INT1 Drill ahead directionally from 3,501' to 5,574', 700 gpm, 2,190 psi on bottom, 2,020 psi off bottom, TO on - 10k, TQ off - 9k, PU - 145k, SO - 94k, ROT - 110k, 80 rpm, Calculated ECD - 10.07 ppg, Actual ECD - 10.4 ppg. AST - 1.8, ART - 4.4 Printed: 7/18/2005 11:22:29 AM BP EXPLORATION Page 5 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 6/10/2005 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, TO 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 DriII 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 - 105k, ROT - 125k, 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 ~ 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 returns. 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 INTi RIH with 5" DP from the derrick from 3,273' to 7,675'. 01:30 - 03:30 2.00 DRILL P INT1 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 INT1 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 INT1 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 BTC-M 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 'BP EXPLORATION Page 6 of 2i' 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 6/12/2005 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 INT1 Circulate 1.5 times bottoms up while staging up to 8 bpm, 529 psi, with full returns. PU - 112k, SO - 101 k. 23:30 - 00:00 0.50 CASE P INT1 Continue to PU 7-518" 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'. Fill 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 INT1 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 INT1 RD casing handling equipment -elevators and long bails. 15:30 - 20:00 4.50 BOPSU P INTi Flush the stack and install test plug. Change oui the 7-5/8" casing rams to 3-1/2" 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 INT1 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 INTi RD testing equipment and install wear ring - 9" ID. 6/14/2005 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 7-5/8" 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 INTi POH standing back 4" DP. 07:00 - 12:00 5.00 DRILL P PROD1 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: 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 6/14/2005 07:00 - 12:00 5.00 DRILL P PROD1 VPWO, 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 PROD1 RIH with BHA#5 picking up 4" DP 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 R1H 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 i0-3/4" 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 PROD1 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 PRODi Drill 6-3/4" 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 t.00 DRILL P PROD1 POH to 11,453' and log down to 11,593' to confine geology. 18:00 -00:00 6.00 DRILL P PRODi 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: 7/18/2005 11:22:29 AM BP EXPLORATION Page 8 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 ot,Operations 6/16/2005 18:00 - 00:00 6.00 DRILL P PROD1 bottom, 60 rpm, TO on - 8k, TO off - 7k. Calculated ECD - 11.20, Actual ECD - 11.80. For the tour: AST - 1.16, ART - 2.97 6/17/2005 00:00 - 05:00 5.00 DRILL P 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 - Sk, TO off - 7k. 05:00 - 06:30 1.50 DRILL P 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 06:30 - 12:30 6.00 DRILL P 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 12:30 - 13:00 0.50 DRILL P PROD1 Circulate Bottoms Up at 7,665'. 299 gpm / 2640 psi. 80 rpm. Start ECD 10.78 ppg, Final ECD 10.49 ppg 13:00 - 13:30 0.50 DRILL P PROD1 PJSM-Service Top Drive 13:30 - 16:30 3.00 DR{LL P PROD1 R{H f! 7,665' - U 12,628'. FiH DP ~ 10,623' 16:30 - 18:30 2.00 DRILL P PRODi Circulate and Condition Hole w/ 9.2 ppg MOBM at 290 gpm / 3300 psi. Start ECD 10.83 ppg. Final ECD 10.83 ppg 18:30 - 19:00 0.50 DRILL P PROD1 Attempt to Downlink Downhole Tools w/o Success. As Per MWD Rep. 19:00 - 20:30 1.50 DRILL P 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 20:30 - 00:00 3.50 DRILL P PROD1 POH w/ 6-3/4" OBd Lateral BHA U 7-5/8" Shoe ~ 7,665'-Recording Up & Down String Weights Every 5 stds. 6/18/2005 00:00 - 00:30 0.50 DRILL P PROD1 Drop 2" Circulating Sub Ball and Pump Down to Seat. Pressure up U 2,250 psi and Open Cir. Sub. Pump Dry Job. 00:30 - 03:30 3.00 DRILL P PROD1 POH w/ 4" DP. Recording Up and Down String Weights Every 10 stds. 03:30 - 05:30 2.00 DRILL P PROD1 POH w/ 6-3/4" Obd Lateral BHA, Stand Back HWDP, Jars and Flex Collars. UD MWD tools, Motor & Bit 05:30 - 06:00 0.50 DRILL P PRODi Clear and Clean Rig Fllor 06:00 -06:30 0.50 CASE P RUNPRD PJSM-R/U 4-1/2" Liner Running Equipment 06:30 - 15:00 8.50 CASE P 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' 15:00 - 15:30 0.50 CASE P RUNPRD R/D 4-1/2" Liner Running Equipment 15:30 - 21:00 5.50 CASE P RUNPRD RIH w/ 4-1/2" Liner on 4" DP. Filling Dp Every 10 stds. Tag Bottom at 12,628' 21:00 - 22:00 1.00 CASE P 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 Ba1f 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 Page 9 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: 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 6/18/2005 21:00 - 22:00 1.00 CASE P RUNPRD Obsereved Packer Set w/ 50K Dn Wt. Repeat Process to Ensure Pkr. Set. P!U to 145K and Pressure Up Backside t/ 1,500 psi to Test Pkr. (held 5 min.). P/U 30' to Clear HR Tool. Monitor Well-Static. 22:00 - 00:00 2.00 CASE P RUNPRD POH w/ Running Tool on 4" DP 6/19/2005 00:00 - 02:30 2.50 P RUNPRD POH w/ 4-1/2" Liner Running Tool 02:30 - 03:00 0.50 CASE P RUNPRD Clear and Clean Floor 03:00 - 03:30 0.50 CASE P RUNPRD Slip and Cut Drilling Line 03:30 - 04:00 0.50 CASE P RUNPRD Service Top Drive and Crown 04:00 - 05:00 1.00 STWHIP P WEXIT P/U 9 - 4-3/4" DC's and Stand Back in Derrick 05:00 - 09:00 4.00 STWHIP P 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 Mill-Lower MiII-Flex Jt.-Upper Mill-1 jt. 3-1/2" HWDP-Float Sub-MW DAssy.-Bumper Jar-9 x 4-314" DC's-XO-18 x 4" HWDP = 981.42' Total Length. Shallow Test MWD, 254 gpm at 685 psi. 09:00 - 14:30 5.50 STWHIP P WEXIT RIH w/ Whipstock Assy. #1 on 4" DP.Running Speed of 45 fpm, as per Baker Rep. RIH U 7,043' 14:30 - 15:30 1.00 STWHIP P 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' 15:30 - 16:30 1.00 STWHIP P WEXIT Displace Wellbore w/ 9.1 ppg MOBM at 275 gpm / 1,875 psi. 16:30 - 23:00 6.50 STWHIP P WEXIT Mill f/ 7,072' - U 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 llbs. Average ROP 3.18 fph. Pumping Hi-Vis Sweep every 2 hrs. 23:00 - 00:00 1.00 STWHIP P WEXIT Circulate 50 bbl Hi-Vis Sweep Surface to Surface. Working Mills Through Window During Circulation 6/20/2005 00:00 - 00:30 0.50 STWHIP P WEXIT Circulate 50 bbl Hi-Vis Sweep Surface to Surface. Work Mills Through Window While Circulating. Pump Dry Job and Monitor Well. Static. 00:30 -04:00 3.50 STWHIP P WEXIT POH w/ 6-3/4" Whipstock Milling BHA on 4" DP. UD BHA Components. All Mills In Gauge 04:00 -04:30 0.50 STWHIP P WEXIT Clear and Clean Rig Floor. Remove All Milling Tools from Rig Floor. 04:30 - 05:00 0.50 BOPSU P WEXIT P/U and M/U BOP Stack Flushing Tool. Circulate at 10 bpm to Remove Excess Metal/Cuttings from Ram Cavities. 05:00 - 05:30 0.50 BOPSU P WEXIT M/U Floor Valves to Test Jt. Pull Wear Ring and Install Test Plug 05:30 - 07:00 1.50 BOPSU P WEXIT Remove Standard Blind Rams and Install Blind /Shear Rams 07:00 - 14:30 7.50 BOPSU P WEXIT Test BOP's, Choke Manifold and Floor Safety Valves. Alf Tests to 250 psi Low for 5 min. and 3,500 psi High. for 5 min. Test Witriessed 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 14:30 - 15:00 0.50 BOPSU P WEXIT Install Wear Ring 15:00 - 17:30 2.50 STWHIP P 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: 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 6/20/2005 17:30 - 20:00 2.50 STWHIP P WEXIT RAH 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'- V7,020'. 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. SOK, 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 5.1 k, 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 ~ 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 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 Dri116.75" OBb lateral from 10,561' to 11,401' S-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 11.80, 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 1 i ,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.Sk, 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 = i.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: NABORS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABORS 9ES Rig Number: Date ~ From - To I `-Hours Task' Code) NPT Phase Descl•iption of Operations 6/23/2005 103:00 - 06:00 3.00 DRILL P PROD2 1300 gpm, 3,180 psi, increase rpm to 120 while pumping sweep. 06:00 - 10:30 4.50 DRILL P PROD2 10:30 - 11:00 0.50 DRILL P PROD2 11:00 - 13:30 2.50 DRILL P PROD2 13:30 - 16:30 3.00 DRILL P PROD2 16:30 - 19:00 2.50 DRILL N DFAL PROD2 19:00 - 20:30 I 1.501 DRILL I P 20:30 - 00:00 3.501 DRILL P 6/24/2005 100:00 - 01:00 I 1.001 DRILL I P 01:00 - 04:00 I 3.001 DRILL I P 04:00 - 05:30 I 1.501 DRILL I P 05:30 -06:00 0.50 FISH P 06:00 - 08:00 2.00 FISH P 08:00 - 08:30 0.50 FISH P 08:30 - 11:00 2.50 FISH P 11:00 - 11:30 0.50 FISH P 11:30 - 12:00 0.50 FISH P 12:00 - 17:00 5.00 FISH P 17:00 - 18:30 1.50 FISH P 18:30 - 19:00 0.50 FISH P 19:00 - 19:30 0.50 CASE P 19:30 - 00:00 4.50 CASE P 6/25/2005 ~ 00:00 - 02:00 ~ 2.00 I CASE ~ P torque 7.5k, had a 30% increase in cuttings when sweep came back, with larger (pencil lead) sized cuttings. Monitor well, POH from 12,115' to to 7,000', hole taking proper fill, no problem pulling through window, monitor well. Service Topdrive. RIH from 7,000' to 12,115', taking 10 to 15k wieght from 11,050' to 11,850', no other hole problems. Make up topdrive and break circulation, intial rate 300 gpm, 3,565 psi, 80 rpm, torque 8.ik, 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. Attempt to down link MW D tools to faster data rate, down link was unsuccessful. PROD2 Displace well to SFMOBM, ~ 230 gpm, 2205 psi, 80 rpm, torque 8.5k 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. 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. PROD2 POH from 7,000' to BHA, recording up and down weights every 10 stands. monitor well at BHA. PROD2 PJSM, lay down BHA, remove sources, clear floor of all directional tools. PROD2 Clean floor, P/U Baker fishing tools to rig floor. PROD2 Make up Whipstock retrieval BHA, Retrieval hook, 1 jt 3 1/2' HWOP,float sub, MWD, bumper sub, oil jar, 12 4 3/4" drill collars,XO, 18 jts 4" HWDP and 1 stand 4" DP to 1,011'. PROD'2 Shallow test MWD, 230 gpm, 650 psi, ok. PROD2 RIH with whipstock retriving assembly from 1,011' to 7,043', fill DP ®4,276' 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, putted up to release bottom anchor, released ~ 215K, pulled seals from from seal bore extension, 165k, once clear up wt = 150k, monitor well, static. PROD2 Circulate bottoms up ~ 250 gpm, 1,485 psi, no gas at bottoms up, Monitor well, dead. PROD2 POH slowly with whipstock, rack back HWDP and collars. PROD2 Lay down fishing BHA, break and lay down whipstock and related tools. PROD2 Clear floor of Baker fishing tools, Clean floor. RUNPRD Rig up to run 4.5' slotted liner. 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. RUNPRD Continue running 4.5" 12.6# L-80 IBT- BTC OBb slotted liner Printed: 7/18/2005 11:2229 AM • BP EXPLQRATION 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: NABORS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABORS 9ES Rig Number: Date From -> To Nours Task Code NPfi Phase Description of Operations 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# BTC slotted liner, 1 4.5" 12.6# L-80 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 5 314" 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 the middle of the window saw a slight increase in torque 200-300 ft/Ibs, shut down rotary, continued RIH slowly, bent 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 tum 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 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 tine, 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 white seat/ 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 EXPLQRATION 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: 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 6/25/2005 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 1 314" ball and pump to seat i60 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 50K. 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 = SOK, 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 Mili 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 aA 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: 7/18/2005 11:22:29 AM • ! BP EXP'LORAT(ON 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: 7111!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 6/27/2005 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 12:00 - 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 6,228' 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' S-10k wob, 290 gpm, 3,270 psi on bottom, 3,150 psi off bottom, 60 rpm torque on bottom 7.8k, torque off bottom 7.6k, up wt = 146k, do wt = 64k, rt wt = 97k. Calculated ECD 11.04 Actual 11.48, AST = 1.08 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, C~ 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 8k 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 fi,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: 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 6/30/2005 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 ~ 14L, (detection problems with MWD) Up wt = 142k, do wt = 86K, 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 fUlbs. 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 soild 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, 53/4" straight blade rigid centralizers. 04:00 -04:30 0.50 CASE P RUNPRD Rig down liner 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 11,818', 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 turn 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 tum, and worked hanger 10' past bottom of window, putled 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: 7/1 8/21x15 11:22:29 AM • BP EXPLORATION 'Page 1s 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 7/1/2005 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 2 718" inner siting, ZXP packer assembly and HR running tool, 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 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 0.50 CASE P RUNPRD Orop 1 3/4" ball and pump to seat ~ 3 bpm 775 psi, pressure up positive indication of packer setting ~ 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 tool. 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 mills 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 C~ 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 STW HIP 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 PrintecS: 7/16/2005 11:22:29 AM • BP EXPLORATION Page 17 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 Holars Task Code. NPT Phase Description of Operations 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 Sk. 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 mills 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 dryjob. 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 BOPE 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 Hycalog 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' 5-10k 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' S-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: 7/18/2005 11:22:29 AM • - • BP EXPLORATION Page 18 of 21 Opelrations 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 7/4/2005 17:30 - 00:00 6.50 DRILL P PROD4 cuttings, YP increased from 16 to 23 due to sweeps. 5-tOk 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. 7/5/2005 00:00 - 06:00 6.00 DRILL P PROD4 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. 06:00 - 07:00 1.00 DRILL P PROD4 Circulate 2 x bottoms up, 300 gpm, 3,000 psi, 80 rpm. Calculated ECD - 10.98, Actual ECD - 11.24. 07:00 - 12:30 5.50 DRILL P PROD4 PU - 145k, SO - 77k without pumps. Monitor well -stable. Backream from 10,345' to 8,930' - TQ 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. 12:30 - 13:00 0.50 DRILL P PROD4 RIH from 8,600' to 8,972' without problems. 13:00 - 13:30 0.50 DRILL P PROD4 POH from 8,972' to 8,600', PU - 135k, SO - 87k -minimal overpull. 13:30 - 16:00 2.50 DRILL P PROD4 Backream from 8,600' to 7,113', TO - 6.5k, 300 gpm, 60 rpm. 16:00 - 16:30 0.50 DRILL P PROD4 Circulate bottoms up - 300 gpm, 2,500 psi, 60 rpm, TO - 4k. 16:30 - 18:00 1.50 DRILL P PROD4 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. 18:00 - 20:00 2.00 DRILL P PROD4 RIH from 6,740' to 10,345'. Wash the last stand to bottom. No problems. 20:00 - 22:00 2.00 DRILL P PROD4 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. 22:00 - 00:00 2.00 DRILL P PROD4 Displace the 9.2 ppg MOBM to 9.2 ppg SFMOBM - 300 gpm, 3,100 psi, 80 rpm, TO - 6.3k. 7/6/2005 00:00 -04:00 4.00 DRILL P PROD4 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'. 04:00 - 06:00 2.00 DRILL P PROD4 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 / 21 WT / G / X / 1 / ER / TD. Clear and clean the floor. 06:00 - 07:30 1.50 WHIP P RUNPRD MU Whipstock #3 Retrieving BHA to 1,012' -fixed tug retrieving tool, 1 x 3.5" HW DP, float sub, MWD, bumper sub, fishing jar, 12 x 4-314" drill collars, xo, 18 x 4' HWDP. 07:30 - 09:30 2.00 WHIP P RUNPRD RIH to 6,750' to retrieve Whipstock #3 09:30 - 10:00 0.50 WHIP P RUNPRD 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'. 10:00 - 11:00 1.00 WHIP P RUNPRD Circulate bottoms up - 3 bpm, 550 psi. Monitor well -stable. Printed: 7/18/2(x)5 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-life 2000 thread lubricant on each connection and torqued to the mark - 3,400 ttlbs 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~3 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 114 turn 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 RIH 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 bore 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 verify 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 11:22:29 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 I Rig Release: 7/11/2005 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours `Task Code NPT Phase bescrption of Operations. 7/7/2005 19:30 - 21:00 1.50 TIEBAC P OTHCMP 21:00 - 21:30 0.50 TIEBAC P OTHCMP 21:30 - 23:00 1.50 TIEBAC P OTHCMP 23:00 - 00:00 1.00 TIEBAC P OTHCMP 7!8!2005 00:00 - 01:00 1.00 TIEBAC P OTHCMP 01:00 - 08:30 7.50 TIEBAC P OTHCMP 08:30 - 09:30 1.00 TIEBAC N HMAN OTHCMP 09:30 - 10:30 1.00 TIEBAC P OTHCMP 10:30 - 14:30 4.00 TIEBAC N HMAN OTHCMP 14:30 - 20:30 6.00 TIEBAC N HMAN OTHCMP 20:30 - 22:00 1.50 TIEBAC P OTHCMP 22:00 - 22:30 0.50 TIEBAC P OTHCMP 22:30 - 23:30 1.00 TIEBAC P OTHCMP 23:30 -00:00 0.50 TIEBAC P OTHCMP 7/9/2005 00:00 -04:30 4.50 TIEBAC P OTHCMP 04:30 - 05:30 1.00 BUNCO RUNCMP 05:30 - 08:00 2.50 BUNCO RUNCMP 08:00 - 18:00 10.00 BUNCO RUNCMP 18:00 - 20:30 2.50 BUNCO RUNCMP 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. LD single and stand back 2 stands of 4" DP in the derrick. 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. Clean under the shakers and the troughs. Continue to clean under shakers and troughs Pump dry job. LD HWDP, drill collars and 4" DP. LD LEM running tools and inner string. PU 1 stand of 4" DP and MU mule shoe. Puli 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. Circulate at 7 bpm, 60 psi and check the possum belly, flow Tines, troughs and pill pit -did not find sling. Notify town and call out Slickline for fishing operation Service and lubricate the top drive, draw works, blocks and crown. Clean rig of the MOBM while waiting on Slickline. PJSM. RU slickline. RIH with 4 prong rope grabber to 6,738'. POH. Recovered dropped sling. RD slickline. RIH with 4" DP from the derrick to 6,600'. Circulate DP volume to clean out DP prior to laying down. Cut and slip 78' of drilling line. LD 4" DP from 6,600'. Continue to LD 4" DP from 6,600'. Pull wear ring and make dummy run with tubing hanger. RU 4.5" tubing handling tools, tongs, elevators and slips. MU floor safety valve. PU 1-wire spool and hang sheave in the derrick. MU 4.5" 12.6# L-80 IBT-M completion and RIH to 6,651'. 4.5" completion includes: WLEG/X assy (3.813" ID), X assy (3.813" ID) w/RHC-m profile, 7.625" x 4.5" Baker Premier Packer assy, 4.5" Phoenix Jet Pump gauge assy, 4.5" Baker CMD/Phoenix 7" Discharge Pressure gauge assy, 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 assy (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 assy have been Bakerlok'd. I-wire run from the Phoenix pressure gauge to surface 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 I-wire through the hanger and lock in place. Cut I-wire above hanger and secure to landing joint. Land the tubing on the Printed: 7/16/2005 11:22:29 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 From'- 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 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 1122:29 AM 3 ^ AAA^ A A .. Schlmberaer L~LVLL3 a7UI V~~/ ITG~~DI-Z Report Date: 5-Jul-05 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 105.000° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000'ft Structure I Slot: L-PAD / L-202 ND Reference Datum: Rotary Table well: L-202 ND Reference Elevation: 77.30 ft relative to MSL Borehole: L-202L3 Sea Bed I Ground Level Elevation: 48.80 ft relative to MSL UWVAPI#: 500292322962 ,,.Magnetic Declination:. 24.575° Survey Name /Date: L-202L3 /June 20, 2005 Total Field Strength: 57573.999 nT Tort / AHD I DDI / ERD ratio: 293.017° / 8049.75 ft / 6.740 / 1.811 Magnetic Dip: 80.843° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date:. June 20; 2005 Location LaULong: N 70 21 2.394, W 14919 27.488 `Magnetic Declination Model: BGGM 2005 Location Grid NIE 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: +24.575° Grid Scale Factor: 0.99990787 Local Coordinates Referenced To: Well Head u 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 1100 ft ftUS ftUS n i ~ U.w U.UU U.UU -r r.w v.vu u.vu u.w u.vu u.VV u.VV V.VV oa/tlZy3.LJ b25SZZ3.t5U N /U Zl Z.3y4 UV 14y 1y 2/.4tl8 First MW D+IFR+MS 300.84 0.34 25.11 223.54 300.84 0.16 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 0.18 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 0.06 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 0.02 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 0.40 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 0.99 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 1.27 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 1.59 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 1.92 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 1.55 80.64 80.55. 77.39 22.34 3.43 5978370.88 583245.28 N 70 21 3.155 W 149 19 9 1330.83 19.13 11.06 1241.56 1318.86 0.06 109.94 109.80 106.04 28.48 2.41 5978399.59 583251.10 N 70 21 3.436 W 149 1 1425.26 20.68 12.40 1330.35 1407.65 -1.76 142.09 141.91 137.51 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 -2.64 178.31 ,:178.12 172.72 43.54 3.53 5978466.42 583265.42 N 70 21 4.092 W 149 19 26.215 1617.99 23.95 13.68 1507.55 1584.85 -3.22 217.80 ' 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 -5.01 259.22 259.01 251.44 62.19 4.65 5978545.34 583283.18 N 70 21 4.866 W 149 19 25.670 1806.43 30.66 12.Oti 1674.19 1751.49 -7:59 305.53 ~ 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 -9.89 355.28 355.04 345.37 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 -12.77 411.42 .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 -16.98 474.07 473.78 461.73 106.14 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 -21.77 540.83 540.50 527.29 118.75 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 -26.14 611.67 611.33 596.72 132.83 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 -29:88 685.42 685.08 668.84 148.28 3.68 5978963.63 583364.63 N 70 21 8.971 W 149 19 23.154 2466.25 56.54 12.21 2141.19 2218.49 -33.59 762.66 762.31 744.32 164.67 2.70 5979039.28 583380.17 N 70 21 9.714 W 149 19 22.675 SurveyEditor Ver SP 1.0 Bld( doc40x_56) L-202\L-202\L-202L3\L-202L3 Generated 7/12/2005 4:53 PM Page 1 of 6 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole ' Closure NS fW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft it '' K de 11008 ftUS ttUS LJV V.4L 2654.71 2749.60 2843.79 2939.01 3033.56 3128.08 3223.61 3302.79 3332.92 3427.34 JO.La IL. 10 L ly I.yJ LLV~.LJ -J/.4~ 041.yy 041.04 OL I:00 101.4U 59.04 11 .60 2241.00 2318.30 59.40 11 .73 2289.56 2366.86 59.44 11 .64 2337.47 2414.77 59.34 11 .69 2385.96 2463.26 58.86 11 .85 2434.51 2511.81 58.78 11 .89 2483.45 2560.75 59.32 12 .07 2532.58 2609.88 58.27 13 .26 2573.60 2650.90 58.16 12 .74 2589.47 2666.77 57.83 12 .68 2639.52 2716.82 3520.48 59.11 12.46 2688.22 2765.52 3614.60 58.90 12.46 2736.69 2813.99 3708.59 58.76 12.33 2785.34 2862.64 3803.17 60.00 12.46 2833.51 2910.81 3897.73 59.55 12.44 2881.11 2958.41 3991.42 60.14 12.38 2928.18 3005.48 4085.47 60.66 14.91 2974.64 3051.94 4180.85 62.09 18.79 3020.34 3097.64 4275.50 62.77 19.74 3064.15 3141.45 4369.33 61.59 22.65 3107.95 3185.25 4463.07 60.92 24.56 3153.03 3230.33 4558.50 59.11 25.99 3200.72 3278.02 4652.08 58.36 27.82 3249.29 3326.59 4745.64 59.00 29.78 3297.93 3375.23 4840.53 59.04 32.79 3346.78 3424.08 4932.96 58.18 32.71 3394.93 3472.23 5029.33 57.47 34.52 3446.25 3523.55 5123.41 57.25 34.96 3496.99 3574.29 5217.80 58.51 34.97 3547.17 3624.47 5312.23 59.95 35.35 3595.48 3672.78 5405.78 61.32 35.70 3641.36 3718.66 5500.71 60.71 35.59 3687.36 3764.66 5596.24 61.46 38.08 3733.55 3810.85 5691.12 63.07 42.66 3777.73 3855.03 5785.12 63.56 47.61 3819.96 3897.26 5879.62 63.10 51.86 3862.39 3939.69 5973.89 60.96 55.76 3906.62 3983.92 6069.13 60.11 59.75 3953.48 4030.78 6163.57 61.29 64.17 3999.71 4077.01 6258.13 59.14 68.38 4046.70 4124.00 SurveyEditor Ver SP 1.0 Bld( doc40x_56 ) -41.88 922.51 -46.62 1004.03 -51.31 1085.12 -56.08 1167.07 -60.65 1248.20 -65.07 1329.07 -69.38 1410.99 -72.15 1478.72 -73.04 1504.33 -76.24 1584.40 -79.61 1663.78 -83.18 1744.47 -86.84. 1824.89. -90.54 1906.28 -94.17 1987.98 -97.83 2068.99 -99.76 21.50.76 -97.04. 2234.48 -90.80 2318.38' -81.86 2401.36 -69.56 2483.54 -54.83' 2566.20- -38.34 ' 2646.18 -19.27 2726.11 3.54 2807.46 27.60' 2866.36 53.63 2967.93 80.38 3047.15 107.68 3127.09 135.64 3208.22 164.23 3289.75 193.51 3372.79 224.61 3456.41 260.60 3540.37 302.76 3624.35 350.85 3708.79 402.99 3792.04 459.26 3874.95 519.44. 3957.30 583.42 4039.35 L-202\L-202\t 922.15 1003.67 1084.76 1166.70 1247.83 1328.70 1410.62 1478.34 1503.95 1584.02 1663.40 1744.08 1824.50 1905:89- 1987:60 2068:61 2150.35 2233.80 2317.14 2399.24- 2480.08 '2561,02 2t338.9T 2716.37 2794.38 2869.66 2947.31 3022.46 3098.40 3175.59 3253.19 3332.37 3411.76 3489:94 3565.68 3639.13 3709.01 3775.96 3839.40 3899.34 -202L3\L-2( 900.65 197.97 980.49 214.45 1059.90 230.88 1140:16 247.45 1219.59 263.99 1298.72 280.63 1378.87 297.63 1444.94 312.48 1469.90 318.24 1548.00 335.86 1625.49 353.13 1704.27. 370.54 1782.81 387.80 1862.31 405.27 1942.09 422.89 2021:21 440.30 2100.67 459.59 2'180.76 483.87 2259.,96 511.55 2337.33 541.54 2412:63 574.45 2487:38 609.73 2558171 645.92 2628.74 684.42 2698.25 726.66 2764.61 769.34 2832.54 814.49 2897.64 859.64 2963.15 905.45 3029:48 952.1$ 3095.83 999.55 3163.31 1047.94 3230.23 1098.07 3294:17 1152.46 3353.38 1211.97 3407.95 1276.38 3457.12 1343.54 3501.35 1413.64 3540.04 1486.32 3573.08 1561.41 ~2L3 1.0L O`J/`Jl l0.`J`J OOJJ`J~U.UD IV /U Z'I 1U.4/b VV 14y l~J ZL.liSb 0.97 5979195.96 583411.74 N 70 21 11.251 W 149 19 21.701 0.40 5979275.97 583427.33 N 70 21 12.037 W 149 19 21.219 0.09 5979355.55 583442.87 N 70 21 12.818 W 149 19 20.739 0.11 5979435.98 583458.55 N 70 21 13.607 W 149 19 20.255 0.53 5979515.58 583474.21 N 70 21 14.388 W 149 19 19.771 0.09 5979594.89 583489.96 N 70 21 15.166 W 149 19 19.285 0.59 5979675.21 583506.08 N 70 21 15.954 W 149 19 18.788 1.85 5979741.44 583520.18 N 70 21 16.604 W 149 19 18.354 1.51 5979766.45 583525.67 N 70 21 16.850 W 149 19 18.185 0.35 5979844.74 583542.41 N 70 21 17.618 W 149 19 ~0 1.39 5979922.41 583558.83 N 70 21 18.380 W 149 19 17.165 0.22 5980001.37 583575.36 N 70 21 19.155 W 149 19 16.656 0.19 5980080.09 583591.74 N 70 21 19.927 W 149 19 16.151 1.32 5980159.77 583608.33 N 70 21 20.709 W 149 19 15.641 0.48 5980239.73 583625.06 N 70 21 21.494 W 149 19 15.126 0.63 5980319.03 583641.58 N 70 21 22.272 W 149 19 14.616 2.40 5980398.69 583659.99 N 70 21 23.053 W 149 19 14.052 3.87 5980479.05 583683.38 N 70 21 23.841 W 149 19 13.342 1.14 5980558.54 583710.18 N 70 21 24.620 W 149 19 12.533 3.02 5960636.23 583739.30 N 70 21 25.381 W 149 19 11.656 1.92 5980711.89 583771.36 N 70 21 26.121 W 149 19 10.694 2.30 5980787.01 583805.81 N 70 21 26.856 W 149 19 9.662 1.85 5980858.73 583841.20 N 70 21 27.558 W 14919 8.604 1.92 5980929.18 583878.92 N 70 21 28.247 W 149 19 7.478 2.72 5980999.15 583920.38 N 70 21 28.930 W 149 19 6.243 0.93 5981065.97 583962.32 N 70 21 29.583 W 149 19 4.995 1.75 5981134.39 584006.71 N 70 21 30.251 W 149 19 5 0.46 5981199.98 584051.13 N 70 21 30.891 W 149 19 1.33 5981265.99 584096.20 N 70 21 31.535 W 149 19 5 1.56 5981332.83 584142.18 N 70 21 32.187 W 149 18 59.649 1.50 5981399.70 584188.81 N 70 21 32.840 W 149 18 58.264 0.65 5981467.71 584236.45 N 70 21 33.504 W 149 18 56.849 2.41 5981535.17 584285.83 N 70 21 34.162 W 149 18 55.383 4.60 5981599.70 584339.50 N 70 21 34.790 W 149 18 53.792 4.73 5981659.57 584398.34 N 70 21 35.373 W 149 18 52.052 4.05 5981714.84 584462.14 N 70 21 35.909 W 149 18 50.168 4.30 5981764.75 584528.74 N 70 21 36.393 W 149 18 48.205 3.75 5981809.76 584598.34 N 70 21 36.828 W 149 18 46.155 4.27 5981849.24 584670.57 N 70 21 37.208 W 149 18 44.029 4.48 5981883.11 584745.28 N 70 21 37.533 W 149 18 41.834 Generated 7/12/2005 4:53 PM Page 2 of 6 Comments Measured Inclination Azimuth SutrSea 1VD 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 /100 ft ftUS ftUS b3bU.`JO bb.b3 /Z.3U 4Uyb.13 41 /3.43 6445.47 57.16 76.61 4147.83 4225.13 6539.08 58.35 80.50 4197.79 4275.09 6633.04 63.82 84.48 4243.22 4320.52 Tie-In Survey 6727.96 67.49 87.23 4282.34 4359.64 Blind (Inc Only) 6779.20 68.66 89.20 4301.48 4378.78 6810.94 70.74 90.37 4312.49 4389.79 6841.19 73.80 91.45 4321.70 4399.00 6872.34 76.96 92.55 4329.56 4406.86 Last Blind (Inc Only) 6902.87 80.66 93.61 4335.49 4412.79 First MWD+IFR+MS 6934.63 84.50 94.69 4339.59 4416.89 6965.27 88.08 93.69 4341.57 4418.87 6997.00 91.61 96.56 4341.66 4418.96 7027.93 94.32 99.34 4340.06 4417.36 7059.02 95.53 101.67 4337.39 4414.69 7090.26 95.22 104.05 4334.46 4411.76 7121.15 95.77 105.60 4331.50 4408.80 7152.02 95.70 104.56 4328.42 4405.72 7183.75 95.80 104.85 4325.24 4402.54 7214.78 95.56 103.39 4322.17 4399.47 7245.94 94.84 102.75 4319.34 4396.64 7278.45 94.77 104.65 4316.62 4393.92 7307.47 94.67 104.28 4314.23 4391.53 7339.40 93.64 103.73 4311.92 4389.22 7370.92 90.51 104.42 4310.78 4388.08 7401.69 89.90 103.12 4310.67 4387.97 7433.54 90.14 103.06 4310.65 4387.95 7464.70 89.69 103.27 4310.70 4388.00 7495.39 91.44 105.42 4310.40 4387.70 7527.60 91.95 104.95 4309.45 4386.75 7558.25 91.61 104.98 4308.49 4385.79 7588.99 91.13 105.80 4307.76 4385.06 7620.52 90.86 105.76 4307.21 4384.51 7651.58 90.65 104.82 4306.80 4384.10 7682.39 89.25 104.64 4306.83 4384.13 7713.73 88.53 104.63 4307.44 4384.74 7744.15 87.80 105.17 4308.41 4385.71 7775.83 88.63 104.93 4309.40 4386.70 7807.61 89.73 104.99 4309.85 4387.15 7837.36 89.73 103.90 4309.99 4387.29 7867.61 89.45 104.63 4310.21 4387.51 7898.37 89.90 104.26 4310.38 4387.68 b4tS.U"I 41"i /.yL 3y53.bL 3byy.54 "Ib35.3/ 716.14 4197.03 4004.89 3620:73 1711.57 787.01 4276.19 4052.72 3636.41 1789.15 862.97 4358.40 4098.84 3647.08 1870.64 944.65 4444.86 4144.39 3653.30 1956.87 990.15 4492.39 4168.32 3654.78 2004.38 1018.88 4522.16 4182.82 3654.89 2034.14 1046.82 4550.97 4196.50 3654.43 2062.95 1076.19 4581..11. 4210.47 3653.37 2093.07 1105.49 4611.05' 4224:02 3651:76 2122.97 1136.41 4642.54 4237.93 3649.48 2154.37 1166.44 4673.11 4251:59 3647.25 2184.86 1197.69 4704.84 4265.50 3644.42 2216.46 1228:34 4735.72 4277.83 3640.15 2247.04 1259.22 4766.70 4289:12 3634.50 2277.50 1290.29 4797.80 4299.46 3627.58 2307.82 1321.04 4828.55 4308.87 3619.71 2337.54 1351.76 4859.26 4318.35 3611.72 2367.20 1383.33 4890.83 4328.49 3603.71 2397.73 1414.20 4921.71 4338.90 3596.17 2427.68 1445.21 4952.74 4350.10 3589.16 2457.91 1477.60 4985.14. 4361.65 3581.48 2489.38 1506.52 5014.06 4371.79 3574.26 2517.38 1538.36 5045.90 4383.38 3566.55 2548.28 1569.85 5077.40 4395.01 3558.89 2578.83 1600.61 5108.17 4406.70 3551.57 2608.72 1632.45 5140.02 4419.35 3544.36 2639.74 1663.59 5171.18 4431.88 3537.26 2670.08 1694:27 5201.87 4443.81 3529.66 2699.81 1726.47 5234.06 4456.09 3521.22 2730.88 1757.10 5264.70 4468.06 3513.31 2760.48 1787.83 5295.43 4480:05 3505.16 2790.11 1819.36 5326.95 4492:33 3496:58 2820.44 1850.41 5358.01 451)4.85 3488.39 2850.40 1881.22 5388:82 4517:72 3480.56 2880.20 1912.55 5420.15 4531.04 3472.64 2910.51 1942,96 5450.56 4544.01 3464.82 2939.90 1974.62!. 5482.22 4557.61 3456.60 2970.47 2006.40 551'4.00 4571.49 3448.40 3001.17 2036.15 5543.75 4584.88 3440.98 3029.98 2066.39 5574.00 4598.74 3433.53 3059.30 2097.1b 5604.76 4612.91 3425.85 3089.09 4.55 59251910.39 bti4ti7ti.94 N /U 27 3/./93 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 4.23 5981969.72 585187.28 N 70 21 38.335 W 149 18 28.881 7.41 5981970.16 585217.04 N 70 21 38.336 W 149 18 28.011 10.67 5981970.02 585245.85 N 70 21 38.332 W 149 18 27.168 10.70 5981969.30 585275.97 N 70 21 38.321 W 149 18 26.288 12.59 5981968.02 585305.89 N 70 21 38.305 W 149 18 25.414 12.55 5981966.09 585337.31 N 70 21 38.283 W 149 18 12.13 5981964.19 585367.82 N 70 21 38.261 W 149 18 ' 14.34 5981961.71 585399.44 N 70 21 38.233 W 149 18 22.680 12.54 5981957.78 585430.07 N 70 21 38.191 W 149 18 21.786 8.42 5981952.47 585460.58 N 70 21 38.135 W 149 18 20.895 7.65 5981945.89 585490.97 N 70 21 38.067 W 149 18 20.009 5.30 5981938.35 585520.78 N 70 21 37.989 W 149 18 19.140 3.36 5981930.69 585550.52 N 70 21 37.911 W 149 18 18.273 0.96 5981923.02 585581.14 N 70 21 37.832 W 149 18 17.380 4.75 5981915.82 585611.16 N 70 21 37.758 W 149 18 16.505 3.09 5981909.14 585641.46 N 70 21 37.688 W 149 18 15.621 5.83 5981901.82 585673.02 N 70 21 37.613 W 149 18 14.701 1.32 5981894.91 585701.10 N 70 21 37.542 W 149 18 13.882 3.65 5981887.55 585732.08 N 70 21 37.466 W 149 18 12.979 10.17 5981880.23 585762.71 N 70 21 37.390 W 149 18 12.085 4.67 5981873.24 585792.67 N 70 21 37.318 W 149 18 11.212 0.78 5981866.37 585823.77 N 70 21 37.247 W 149 18 10.305 1.59 5981859.61 585854.18 N 70 21 37.177 W 149 18 9.418 9.03 5981852.34 585883.99 N 70 21 37.102 W 149 18 8 2.15 5981844.25 585915.15 N 70 21 37.019 W 149 18~ 1.11 5981836.67 585944.83 N 70 21 36.941 W 149 18 6.775 3.09 5981828.84 585974.55 N 70 21 36.861 W 149 18 5.909 0.87 5981820.61 586004.97 N 70 21 36.777 W 149 18 5.022 3.10 5981812.75 586035.02 N 70 21 36.696 W 149 18 4.146 4.58 5981805.25 586064.90 N 70 21 36.619 W 149 18 3.275 2.30 5981797.67 586095.30 N 70 21 36.541 W 149 18 2.388 2.98 5981790.18 586124.76 N 70 21 36.464 W 149 18 1.529 2.73 5981782.30 586155.42 N 70 21 36.383 W 149 18 0.635 3.47 5981774.44 586186.21 N 70 21 36.302 W 149 17 59.738 3.66 5981767.34 586215.10 N 70 21 36.229 W 149 17 58.896 2.58 5981760.21 586244.49 N 70 21 36.156 W 149 17 58.039 1.89 5981752.87 586274.36 N 70 21 36.080 W 149 17 57.168 SurveyEditor Ver SP 1.0 Bld( doc40x_56) L-202\L-202\L-202L3\L-202L3 Generated 7/12/2005 4:53 PM Page 3 of 6 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 tt k ft k ft ' ft de /100 ft kUS ftUS I JLO.~"F aV.L/ I VJ.Y/ YJ I V.J'+ 4J0/ .V4 7959.73 90.27 103.49 4310.19 4387.49 7990.06 90.10 103.65 4310.09 4387.39 8021.26 89.86 103.61 4310.11 4387.41 8051.52 89.49 103.86 4310.28 4387.58 8082.18 90.24 103.79 4310.35 4387.65 8113.57 91.03 104.69 4310.00 4387.30 8143.75 90.75 105.21 4309.53 4386.83 8174.72 90.62 105.22 4309.16 4386.46 8205.72 89.01 104.36 4309.26 4386.56 8236.11 87.60 103.78 4310.16 4387.46 8266.56 87.29 103.34 4311.52 4388.82 8297.59 86.78 103.73 4313.12 4390.42 8327.44 86.36 103.66 4314.91 4392.21 8358.32 86.30 104.94 4316.89 4394.19 8390.23 86.26 104.76 4318.96 4396.26 8420.90 85.81 103.88 4321.08 4398.38 8452.19 86.64 105.24 4323.14 4400.44 8483.22 86.09 104.04 4325.10 4402.40 8514.42 86.43 105.81 4327.14 4404.44 8545.36 86.36 105.56 4329.09 4406.39 8576.32 85.91 105.69 4331.17 4408.47 8607.60 85.57 105.33 4333.50 4410.80 8638.01 86.67 106.77 4335.55 4412.85 8669.42 88.42 108.00 4336.90 4414.20 8699.44 87.63 106.51 4337.93 4415.23 8730.61 86.64 107.11 4339.49 4416.79 8762.05 87.19 108.21 4341.18 4418.48 8793.10 88.35 107.74 4342.39 4419.69 8824.13 89.79 106.32 4342.90 4420.20 8855.21 89.35 106.12 4343.13 4420.43 8887.34 90.34 106.35 4343.22 4420.52 8917.96 92.16 105.84 4342.55 4419.85 8948.16 91.82 105.56 4341.50 4418.80 8979.02 91.68 106.09 4340.56 4417.86 9011.28 90.51 105.60 4339.94 4417.24 9042.36 89.86 106.57 4339.84 4417.14 9074.10 89.52 106.20 4340.01 4417.31 9104.74 90.31 104.27 4340.06 4417.36 9135.91 90.34 104.97 4339.88 4417.18 9167.87 90.86 106.44 4339.55 4416.85 9199.04 90.62 106.96 4339.14 4416.44 LIL/.hG .7OJV.JJ 40L/:4L 3410.~J JI10./O 2158.49 5666.12 4642.38 3411.35 3148.71 2188.84 5696.45 4657.22 3404.23 317$.19 2220.01 5727165'. 4672,62. 3396.88 3208.51 2250.26 5757.91 4687.65 3389.70 3237.90 2280.91. 5788.57 4702.99 3382.37 3267.68 2312.30 5819.95 4718.66 3374.65 3298.10 2342.47 5850.13 4733.54 3366.$6 3327.25 2373.44 5881;10 4748.84 3358.74 3357.14 2404.44 5912.10 4,764.51 3350.82 3387.11 2434.81 5942.47 4780.33 3343:44 3416.57 2465.22 5972.89 4796.55 3336.31 3446.14 2496.20 6003.88 4813.22 3329.05 3476.27 2525.99 6033.68 4829.31 3322.00 3505.22 2556.80 6064.49 4845.82 3314.39 3535.08 2588.64 6096.34 4862.77 3306.23 3565.86 2619.24 6126.93 4$79.43 3298.66 3595.51 2650.46 6158.1 ti 4896.46 3290.81 3625.73 2681.42 61.89.12 4913.45 3282.98 3655.69 2712.56 6220.26 4930:55 3274.97 3685.77 2743.43' 6251.14 4947.28 3266.62 3715.50 2774.32 6262.02 4964.21 3258.30 3745.25 2805.51 6313.22 4981.48 3249.98 3775.30 2835.85 6343.56 4998.17 3241.57 3804.46 2867.20 6374.94 5014.95 3232:19 3834.41 2897.18 6404.94 5031.18 3223.29 3863.06 2928.29 6436.07 5048.37 3214.29 3892.86 2959.65 6467.46 5065:44 3204.77 3922.77 2990.63 6498.49 5082:30 3195.19 3952.28 3021.64 6529.52 5099.72 3186:11 3981.95 3052.71 6560.59 5117.66 3177.42 4011.79 3084.83 6592.72 5136.33 3168.44 4042.64 3115.44 6623.34 5154.31 3159.96 4072.05 3145.62 6653.52 5172.31 3151:79 4101.10 3176.46 6684.36 5190.78 314$.38 4130.78 3208.71 6716.62 5210.20 3134.57 4161.81 3239.7$ 6747.70 5228.93 3125.96 4191.67 3271.51 6779.44 X248.05 3117.01 4222.12 3302.15 6810.0$ 5267.11 3108.96 4251.68 3333.32. 6$41.25 5286:86 3101.09 4281.84 3365.28 6873.20 5306.76 3092.44 4312.61 3396.43 6904.37 X325.86 3083:48 4342.46 L.tlD Oytll /4AtSt1 DtSbJU4.1 "1 N /U L1 3b.UUtS W 14y 1 / b6.3UU 0.06 5981739.04 586334.13 N 70 21 35.937 W 149 17 55.425 0.77 5981732.25 586363.69 N 70 21 35.867 W 149 17 54.563 0.78 5981725.23 586394.09 N 70 21 35.795 W 149 17 53.676 1.48 5981718.38 586423.56 N 70 21 35.724 W 149 17 52.817 2.46 5981711.38 586453.40 N 70 21 35.652 W 149 17 51.947 3.81 5981704.00 586483.91 N 70 21 35.576 W 149 17 51.057 1.96 5981696.54 586513.15 N 70 21 35.499 W 149 17 50.205 0.42 5981688.75 586543.11 N 70 21 35.419 W 149 17 49.331 5.89 5981681.17 586573.17 N 70 21 35.341 W 149 17 48.455 5.02 5981674.11 586602.71 N 70 21 35.268 W 149 17 4 1.77 5981667.31 586632.36 N 70 21 35.198 W 149 17 2.07 5981660.39 586662.56 N 70 21 35.126 W 149 17 45. 48 1.43 5981653.66 586691.58 N 70 21 35.057 W 149 17 45.002 4.14 5981646.38 586721.52 N 70 21 34.982 W 149 17 44.129 0.58 5981638.56 586752.39 N 70 21 34.901 W 149 17 43.229 3.22 5981631.33 586782.11 N 70 21 34.827 W 149 17 42.363 5.08 5981623.81 586812.42 N 70 21 34.750 W 149 17 41.479 4.25 5981616.32 586842.46 N 70 21 34.672 W 149 17 40.603 5.76 5981608.64 586872.63 N 70 21 34.593 W 149 17 39.724 0.84 5981600.62 586902.44 N 70 21 34.511 W 149 17 38.855 1.51 5981592.63 586932.28 N 70 21 34.429 W 149 17 37.985 1.58 5981584.63 586962.42 N 70 21 34.347 W 149 17 37.106 5.95 5981576.56 586991.67 N 70 21 34.264 W 149 17 36.254 6.81 5981567.52 587021.71 N 70 21 34.172 W 149 17 35.379 5.62 5981558.94 587050.46 N 70 21 34.084 W 149 17 34.541 3.71 5981550.27 587080.35 N 70 21 33.996 W 149 17 33.670 3.91 5981541.08 587110.37 N 70 21 33.902 W 149 17 32.795 4.03 5981531.84 587139.98 N 70 21 33.808 W 149 17 6.52 5981523.08 587169.74 N 70 21 33.718 W 149 17 3 . 6 1.56 5981514.73 587199.68 N 70 21 33.633 W 149 17 30.193 3.16 5981506.09 587230.62 N 70 21 33.544 W 149 17 29.291 6.17 5981497.93 587260.12 N 70 21 33.460 W 149 17 28.432 1.46 5981490.09 587289.26 N 70 21 33.380 W 149 17 27.582 1.78 5981482.01 587319.03 N 70 21 33.297 W 149 17 26.715 3.93 5981473.55 587350.15 N 70 21 33.210 W 149 17 25.808 3.76 5981465.27 587380.10 N 70 21 33.125 W 149 17 24.935 1.58 5981456.66 587410.65 N 70 21 33.037 W 149 17 24.045 6.81 5981448.94 587440.29 N 70 21 32.958 W 149 17 23.181 2.25 5981441.41 587470.54 N 70 21 32.880 W 149 17 22.299 4.88 5981433.10 587501.39 N 70 21 32.795 W 149 17 21.400 1.84 5981424.47 587531.34 N 70 21 32.707 W 149 17 20.527 SurveyEditor Ver SP 1.0 Bld( doc40x_56) L-2021L-2021L-202L31L-202L3 Generated 7/12/2005 4:53 PM Page 4 of 6 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 /100 ft ftUS ftUS ~LL"J.~J yU.L/ IU/.UU 4JJ0..7U 441D.LU 34L/.JU O:lJO.LO .7J44./O 3V /4.40 43/L.UV 1.14 oaa i4 io./u 9261.05 90.21 106.58 4338.77 4416.07 3458.40 6966.38 5364.04 3065.47 4401.79 1.36 5981407.13 9292.01 90.79 106.05 4338.50 4415.80 3489.36 6997.34 5383.50 3056.77 4431.51 2.54 5981398.76 9323.36 90.62 105.29 4338.12 4415.42 3520.70 7028.69 5403.60 3048.31 4461.69 2.48 5981390.63 9355.07 90.48 106.03 4337.81 4415.11 3552.41 7060.39 5424,03 3039.75 4492.22 2.37 5981382.41 9386.02 90.24 106.23 4337.62 4414.92 3583.35 7091.34 5443.89 3031.15 4521.95 1.01 5981374.15 9416.23 89.59 105.79 4337.66 4414.96 3613.56 7121.55 5463.42 3022.82 4550.99 2.60 5981366.14 9447.03 89.04 106.49 4338.03 4415.33 3644.35 7152.35 5483.37 3014.26 4580.57 2.89 5981357.91 9479.08 89.18 104.84 4338.53 4415.83 3676.39 7184.40 5504.45 3005.60 4611.43 5.17 5981349.60 9509.75 89.69 103.84 4338.83 4416.13 3707.06 7215.07r 5525.24 .2998.01 4641.14 3.66 5981342.33 9541.15 89.38 102.90 4339.09 4416.39 3738.44 7246.46 554'7.00 2990.75 4671.69 3.15 5981335.41 9572.85 88.77 102.77 4339.60 4416.90 3770.13 7278.16 5569.28 2983.71 4702.59 1.97 5981328.72 9603.25 88.32 102.90 4340.37 4417.67 3800.48 7308.55 5590.72 2976.96 4732.22 1.54 5981322.29 9634.45 87.91 103.47 4341.40 4418.70 3831.65 7339.73 5612.68 2969.84 4762.58 2.25 5981315.52 9666.69 87.91 104.96 4342.57 4419.87 3863.86 7371.95 5635.04 2961.93 4793:81 4.62 5981307.96 9696.49 88.04 106.84 4343.63 4420.93 3893.64 7401.73 5655:16 2953.77 4822.46 6.32 5981300.12 9728.44 89.04 108.06 4344.44 4421.74 3925.55 7433.62 5676.19 2944.20 4852.92 4.94 5981290.88 9759.88 89.97 106.66 4344.71 4422.01 3956.96, 7465.11. 5697.03 2934.82 4882.93 5.35 5981281.83 9790.87 89.49 105.64 4344.86 4422.16 3987.94 7496.10 5718.15 2926.20 4912.70 3.64 5981273.55 9821.98 88.35 102.58 4345.44 4422.74 4019.04 7527.20 5740.22 2918.61 4942.86 10.49 5981266.30 9853.53 87.40 102.67 4346.61 4423.91 4050.54 7558.73 5763.25 2911.72 4973.62 3.02 5981259.75 9884.52 87.74 101.92 4347.93 4425.23 4081.47 7589.69 5786.06 2905.13 5003.88 2.66 5981253.50 9915.22 88.76 103.00 4348.86 4426.16 4112.12 7620.38 5808.69 2898.51 5033.84 4.84 5981247.21 9946.08 88.28 100.14 4349.66 4426.96 4142.92 7651,23 5831.83 2892.32 5064.06 9.39 5981241.36 9977.41 86.91 100.61 4350.98 4428.28 4174.11 7682.53 5855.80 2886.69 5094.85 4.62 5981236.07 10008.76 86.29 100.18 4352.84 4430.14 4205,31 7.713.83 5879.83 2881.04 5125.63 2.41 5981230.76 10040.09 86.77 101.70 4354.73 4432.03 4236.5p 7745.10 5903.73 2875.90 5156.33 5.08 5981225.17 10071.83 88.05 101.48 4356.17 4433.47 4268.15 7776:81 $927.79 2$68.73 5187.39 4.09 5981219.14 10102.75 88.53 100.80 4357.09 4434.39 4298.99 7807.71 5951:47 2$62.76 5217.71 2.69 5981213.51 10133.48 87.98 101.24 4358.02 4435.32 4329.63 7838.43 5975.11 2$56.89 5247.86 2.29 5981207.97 10165.04 88.15 101.22 4359.09 4436.39 4361.10 7869.97 5999.38. 2850.75 5278.80 0.54 5981202.18 10196.12 88.42 102.50 4360.02 4437.32 4392.12 7909.04 6023.13 2844:36 5309.20 4.21 10227.67 87.98 103.11 4361.01 4438.31 4423.63 7932.57 6046.97 2837:37 5339.95 2.38 10258.95 87.56 102.24 4362.23 4439.53 4454:86 2963.8$ 6070.71 2830:52 5370.45 3.09 Last MWD+IFR+MS 10289.85 86.84 103.09 4363.74 4441.04 4485,70 7994.69 6094.23 2823.75 5400.56 3.60 TD (Projected) 10345.00 86.84 103.09 4366.78 4444.08 4540.74 8049:75 61:36.08 2811.28 5454.20 0.00 Survey Type: Definitive Survey NOTES: GYD GC SS - (Gyrodata -gyro single shots --Gyrodata gyro orientation surveys. Not to be run above 70 degrees inclination. ) MWD +IFR + MS - (In-field referenced MWD with mutt-station analysis and correction applied in post-processing, Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Northing (Y)`[ftUS] Easting (X) [ftUS] SurveyEditor Ver SP 1.0 Bld( doc40x_56) L-202\L-202\L-202L3\L-202L3 5tS/bbU.`Jtf N /U L1 :S'L.(i1 tl VV 14y 1 / 19.fi(i:i 587590.87 N 70 21 32.529 W 149 17 18.792 587620.67 N 70 21 32.444 W 149 17 17.924 587650.94 N 70 21 32.360 W 149 17 17.042 587681.56 N 70 21 32.276 W 149 17 16.149 587711.39 N 70 21 32.191 W 149 17 15.280 587740.51 N 70 21 32.109 W 149 17 14.431 587770.19 N 70 21 32.025 W 149 17 13.566 587801.13 N 70 21 31.939 W 149 17 12.664 587830.92 N 70 21 31.864 W 149 17 11.796 587861.55 N 70 21 31.793 W 149 17 ~3 587892.52 N 70 21 31.723 W 149 17 10.000 587922.23 N 70 21 31.657 W 149 17 9.133 587952.66 N 70 21 31.587 W 149 17 8.246 587983.97 N 70 21 31.509 W 149 17 7.333 588012.70 N 70 21 31.428 W 149 17 6.496 588043.27 N 70 21 31.334 W 149 17 5.605 588073.38 N 70 21 31.241 W 149 17 4.728 588103.23 N 70 21 31.156 W 149 17 3.858 588133.48 N 70 21 31.082 W 149 17 2.976 588164.31 N 70 21 31.014 W 149 17 2.077 5981196.13 5981189.48 5981182.97 5981176.53 5981164.66 588194.63 588224.66 588254.95 588285.80 588316.63 588347.40 588378.53 588408.91 588439.12 588470.12 588500.59 588531.41 588561.98 588592.16 588645.93 N 70 21 30.949 W 149 17 1.193 N 70 21 30.883 W 149 17 0.317 N 70 21 30.822 W 149 16 59.433 N 70 21 30.767 W 149 16 58.533 N 70 21 30.711 W 149 16 57.633 N 70 21 30.652 W 149 16 56.736 N 70 21 30.589 W 149 16 5 8 N 70 21 30.531 W 149 16 N 70 21 30.473 W 149 16 5 0 N 70 21 30.412 W 149 16 53.156 N 70 21 30.349 W 149 16 52.267 N 70 21 30.280 W 149 16 51.368 N 70 21 30.212 W 149 16 50.477 N 70 21 30.146 W 149 16 49.597 N 70 21 30.023 W 149 16 48.029 Generated 7/12/2005 4:53 PM Page 5 of 6 Comments Measured Inclination Azimuth SulrSea TVD TVD Vertical Along Hole' Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure k de de k k ft ft ' k ' ft ft de /100 ft ftUS ftUS J GVG Ji UJV rGL JJY I IGIV !~ I IG VIVI BHL : 100 FSL 3511 FEL S26 T12N R11 E UM JSI OL~J.L:J JOJLLJ.OU 5981164.66 588645.93 C~ SurveyEditor Ver SP 1.0 Bld( doc40x_56 ) Generated 7/12/2005 4:53 PM Page 6 of 6 TREE = FMC 4-118" 5M WB.LHEAD = FMC GEN 5 ACTUATOR = kB. ELEV = 77.30' BF. ELEV - 51.08' KOP = 700 Max Angle = 92.7 @ 8295' Datum MD = xxxx' Datum TVD = xxxx' SS 20" CONDUCTOR I--I 114' 10-3/4" CSG. 40#, L-80, ID = 9.95" l~ 3273' L-202 L-202 L1 L-202 L2 L-202 L3 Minimum ID = 3.812" @ 6595' 4-1/2" CMD Sliding Sleeve 4.5"PHOENDC DSCHRGE-PRESS SUB,ID = 3.85" 6585' ~ 4.5" PHNDC MULTI-PRESS SENSOR, ID = 3.994" I-i 6619' RA TAG 6731' 7-5/8" x 5.5" BKR ZXP PACKER ID = 5.5" 6739' I BKR HUGHES HOOK HGR ~ = 5.64" I~ 6776' RA TAG 6897' 7-5/8" x 5.5" BKR ZXP PACKER ID = 3.98" 6885' I BKR HUGHES HOOK HGR, ID = 3.98" I~ 6942' •~A TAG I-L 7021 7-5/8" x 5.5" BKR ZXP PACKER ID = 4.94" 7011' I BKR HUGHES HOOK HGR, ID = 3.98" I~ 7067' PERFORATION SUMMARY REF LOG : ANGLE AT TOP PERF: xx @xxxx' Note: Refer to Production DB for historical pert data 51ZE SPF INTERVAL OpnlSgz DATE 4-1/2" SLID OA 6781' - 10324' O 07/07/05 4-1/2" SLTD OBa 6946' - 11865' O 06/30/05 4-1l2" SLTD OBb 7072' - 11183' O 06/24/05 4-1/2" 5LTD OBd 7665' - 12625' O 06/16/05 I i I I 7 5/8" CSG, 29.7#, L-80, D= 6.875" 7665' I i I I I PBTD 12623' I- ~ NOTES: 2258' --~4-1/2" HES X NIP, b = 3.813" GAS LIFT MANDRELS ST MD TVD 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 DMY 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' -14-1 /2" BKR CMD SLEEV E, ID = 3.812" 6643' 7.625" X 4.5" BKR PRM PKR ID = 3.875" -i 6710' ~--i4-1/2" HES X NIP, O = 3.813" I 6731' 4-1/2" HES XNIP, O = 3.813" 6758' 4-1/2" Guide shoe ---------------- 7 5/8" WINDOW @ 6781' 6781' - 10324' 6-3/4" OA LATERAL, ID = 3.958" 6913' 4-1/2" Seal Assembly I _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ 7 5/8" 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' I-j4-1/2"Seal Assembly I 7175' S-1/2" X 4-1l2" XO, ID = 3.96" 7538' I~ RA TAG 7665' -12,625' 6-3/4" OBd LATERAL, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT 07/11/05 TA/jdf ORIGINAL COMPLETION WELL: L-202, L-202 L1, L-202 L2, L-202 PERMff No: 204196(197)(198)(199) API No: 50-029-23229-00 (60) (61) (6 SEC 34, T12N, R11 E, 2572' NSL & 3690' WEL BP 6cploration (Alaska) SCHLUMBERGER J'`' G -~. Survey report Client ...................: BP Exploration (Alaska) Inc. Field ..................... Orion Well ...................... L-202L3 API number................: 50-029-23229-62 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 5-Jul-2005 10:39:42 Page 1 of 8 Spud date.. ................ 4-July-05 Last survey date.........: 05-Jul-05 Total accepted surveys...: 185 MD of first survey.......: 0.00 ft MD of .last survey........: 10345.00 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 C] • ~ ~ SCHLUMBERGER Survey Report 5-Jul-2005 10:39:42 Page 2 of 8 --- 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 7 764.71 857.53 2.54 4.53 25.42 18.44 94.25 92.82 764.66 857.30 0.40 0.99 5.95 11.28 2.01 4.05 6.28 11.99 18.67 19.75 2.11 2.19 MWD_ MWD_ IFR IFR_ _MS 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 25T.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 5-Jul-2005 10:39:42 Page 3 of 8 --- --- 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 31$.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 13 353 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 3S 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 TFR 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_ IFR _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 TFR 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 TFR 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 TFR MS SCHLUMBERGER Survey Report 5-Jul-2005 10:39:42 Page 4 of 8 --- --- 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 6779.20 68.66 89.20 51.24 4378.78 990.16 3654.78 2004.38 4168.32 28.74 4.23 BP_INC+TREND 72 6810.94 70.74 90.37 31.74 4389.79 1018.88 3654.89 2034.14 4182.81 29.10 7.41 BP_INC+TREND 73 6841.19 73.80 91.45 30.25 4399.00 1046.82 3654.43 2062.95 4196.50 29.45 10.67 BP_INC+TREND 74 6872.34 76.96 92.55 31.15 4406.86 1076.19 3653.37 2093.07 4210.47 29.81 10.70 BP_INC+TREND 75 6902.87 80.66 93.61. 30.53 4412.79 1105.49 3651.76 2122.97 4224.02 30.17 12.59 BP INC+TREND 76 6934.63 84.50 94.69 31.76 4416.89 1136.41 3649.48 2154.37 4237.93 30.55 12.55 MWD IFR ~ MS 77 6965.27 88.08 93.69 30.64 4418.87 1166.44 3647.25 2184.86 4251.59 30.92 12.13 MWD IFR MS 78 6997.00 91.61 96.56 31.73 4418.96 1197.69 3644.42 2216.46 4265.50 31.31 14.34 MWD IFR MS 79 7027.93 94.32 99.34 30.93 4417.36 1228.34 3640.14 2247.04 4277.83 31.69 12.54 MWD IFR MS 80 7059.02 95.53 101.67 31.09 4414.69 1259.22 3634.50 2277.50 4289.12 32.07 8.42 MWD IFR MS 81 7090.26 95.22 104.05 31.24 4411.76 1290.30 3627.58 2307.82 4299.46 32.46 7.65 MWD_ IFR_ MS • 82 7121.15 95.77 105.60 30.89 4408.80 1321.04 3619.71 2337.54 4308.87 32.85 5.30 MWD IFR MS 83 7152.02 95.70 104.56 30.87 4405.72 1351.76 3611.72 2367.20 4318.35 33.24 3.36 MWD IFR MS 84 7183.75 95.80 104.85 31.73 4402.54 1383.33 3603.70 2397.73 4328.49 33.64 0.96 MWD IFR ~ MS 85 7214.78 95.56 103.39 31.03 4399.47 1414.20 3596.17 2427.68 4338.90 34.02 4.75 MWD IFR MS 86 7245.94 94.84 102.75 31.16 4396.64 1445.21 3589.15 2457.91 4350.10 34.40 3.09 MWD IFR MS 87 7278.45 94.77 104.65 32.51 4393.92 1477.60 3581.48 2489.38 4361.65 34.80 5.83 MWD IFR ` MS 88 7307.47 94.67 104.28 29.02 4391.53 1506.52. 3574.26 2517.38 4371.79 35.16 1.32 MWD IFR MS 89 7339.40 93.64 103.73 31.93 4389.22 1538.36 3566.55 2548.28 4383.38 35.55 3.65 MWD IFR MS 90 7370.92 90.51 104.42 31.52 4388.08 1569.85 3558.89 2578.83 4395.01 35.93 10.17 MWD IFR MS SCHLUMBERGER Survey Report 5-Jul-2005 10:39:42 Page 5 of 8 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 7401.69 89.90 103.12 30.77 4387.97 1600.61 3551.57 -- - 2608.72 -------- 4406.70 ------- 36.30 ----- 4.67 ---- MWD - -- IFR ---- MS ~ 92 7433.54 90.14 103.06 31.85 4387.95 1632.45 3544.35 2639.74 4419.35 36.68 0.78 MWD IFR MS 93 7464.70 89.69 103.27 31.16 4388.00 1663.59 3537.26 2670.08 4431.88 37.05 1.59 MWD IFR MS ~ 94 7495.39 91.44 105.42 30.69 4387.70 1694.27 3529.66 2699.81 4443.81 37.41 9.03 MWD IFR MS 95 7527.60 91.95 104.95 32.21 4386.75 1726.47 3521.22 2730.88 4456.09 37.80 2.15 MWD IFR MS 96 7558.25 91.61 104.98 30.65 4385.79 1757.10 3513.31 2760.48 4468.06 38.16 1.11 MWD _IFR _MS 97 7588.99 91.13 105.80 30.74 4385.06 1787.83 3505.16 2790.11 4480.04 38.52 3.09 MWD _IFR • _MS 98 7620.52 90.86 105.76 31.53 4384.51 1819.36 3496.58 2820.44 4492.32 38.89 0.87 MWD IFR MS 99 7651.58 90.65 104.82 31.06 4384.10 1850.41 3488.39 2850.40 4504.85 39.25 3.10 MWD IFR MS 100 7682.39 89.25 104.64 30.81 4384.13 1881.22 3480.56 2880.20 4537.72 39.61 4.58 MWD IFR MS 101 7713.73 88.53 104.63 31.34 4384.74 1912.56 3472.64 2910.51 4531.04 39.97 2.30 MWD IFR MS 102 7744.15 87.80 105.17 30.42 4385.71 1942.96 3464.82 2939.90 4544.01 40.31 2.98 MWD IFR MS 103 7775.83 88.63 104.93 31.68 4386.70 1974.62 3456.60 2970.47 4557.61 40.67 2.73 MWD IFR MS 104 7807.61 89.73 104.99 31.78 4387.15 2006.40 3448.40 3001.17 4571.49 41.03 3.47 MWD IFR MS 105 7837.36 89.73 103.90 29.75 4387.29 2036.15 3440.98 3029.98 4584.88 41.37 3.66 MWD IFR MS 106 7867.61 89.45 104.63 30.25 4387.51 2066.39 3433.52 3059.30 4598.74 41.70 2.58 MWD IFR MS 107 7898.37 89.90 104.26 30.76 4387.68 2097.15 3425.85 3089.09 4612.91 42.04 1.89 MWD IFR MS 108 7928.94 90.27 103.47 30.57 4387.64 2127.72 3418.53 3118.76 4627.42 42.37 2.85 MWD IFR` MS 109 7959.73 90.27 103.49 30.79 4387.49 2158.49 3411.35 3148.71 4642.38 42.71 0.06 MWD IFR ` MS 110 7990.06 90.10 103.65 30.33 4387.39 2188.82 3404.23 3178.19 4657.22 43.03 0.77 MWD IFR MS 111 8021.26 89.86 103.61 31.20 4387.40 2220.01 3396.88 3208.51 4672.61 43.37 0.78 MWD_ IFR MS • 112 8051.52 89.49 103.86 30.26 4387.58 2250.26 3389.70 3237.90 4687.65 43.69 1.48 MWD _ IFR ` MS 113 8082.18 90.24 103.79 30.66 4387.65 2280.91 3382.37 3267.68 4702.99 44.01 2.46 MWD IFR MS 114 8113.57 91.03 104.69 31.39 4387.30 2312.30 3374.65 3298.10 4718.65 44.34 3.81 MWD IFR` MS 115 8143.75 90.75 105.21 30.18 4386.83 2342.47 3366.86 3327.25 4733.54 44.66 1.96 MWD IFR MS 116 8174.72 90.62 105.22 30.97 4386.46 2373.44 3358.74 3357.14 4748.84 44.99 0.42 MWD IFR MS 117 8205.72 89.01 104.36 31.00 4386.56 2404.44 3350.82 3387.11 4764.50 45.31 5.89 MWD IFR` MS 118 8236.11 87.60 103.78 30.39. 4387.46 2434.81 3343.44 3416.57 4780.33 45.62 5.02 MWD IFR MS 119 8266.56 87.29 103.34 30.45 4388.82 2465.22 3336.31 3446.14 4796.54 45.93 1.77 MWD IFR ` MS 120 8297.59 86.78 103.73 31.03 4390.42 2496.20 3329.05 3476.27 4813.22 46.24 2.07 MWD IFR MS SCHLUMBERGER Survey Report 5 -Jul-2005 10.:39:42 Page 6 of 8 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 8327.44 86.36 103.66 29.85 4392.21 2525.99 - 3322.00 --------- 3505.22 -------- 4829.31 ------- 46.54 ----- 1.43 ---- MWD - -- IFR ---- MS 122 8358.32 86.30 104.94 30.88 4394.19 2556.80 3314.39 3535.08 4845.82 46.85 4.14 MWD IFR MS 123 8390.23 86.26 104.76 31.91 4396.26 2588.64 3306.23 3565.86 4862.77 47.16 0.58 MWD IFR MS 124 8420.90 85.81 103.88 30.67 4398.38 2619.24 3298.66 3595.51 4879.43 47.47 3.22 MWD IFR MS 125 8452.19 86.64 105.24 31.29 4400.44 2650.46 3290..81 3625.73 4896.46 47.77 5.08 MWD IFR MS 126 8483.22 86.09 104.04 31.03 4402.40 2681.42 3282.98 3655.69 4913.45 48.07 4.25 MWD IFR MS 127 8514.42 86.43 105.81 31.20 4404.44 2712.56 3274.97 3685.77 4930.55 48.38 5.76 MWD IFR MS 128 8545.36 86.36 105.56 30.94 4406.38 2743.43 3266.62 37.15.50 4947.29 48.68 0.84 MWD _ IFR _ MS 129 8576.32 85.91 105.69 30.96 4408.47 2774.32 3258.30 3745.25 4964.21 48.98 1.51 MWD IFR MS 130 8607.60 85.57 105.33 31.28 4410.80 2805.51 3249.96 3775.30 4981.48 49.28 1.58 MWD IFR MS 131 8638.01 86.67 106.77 30.41 4412.85 2835.85 3241.57 3804.46 4998.17 49.57 5.95 MWD IFR MS 132 8669.42 88.42 108.00 31.41 4414.20 2867.20 3232.19 3834.40 5014.95 49.87 6.81 MWD IFR MS 133 8699.44 87.63 106.51 30.02 4415.23 2897.18 3223.29 3863.06 5031.18 50.16 5.62 MWD IFR MS 134 8730.61 86.64 107.11 31.17 4416.79 2928.29 3214.29 3892.86 5048.36 50.45 3.71 MWD IFR MS 135 8762.05 87.19 108.21 31.44 4418.48 2959.65 3204.77 3922.77 5065.44 50.75 3.91 MWD IFR MS 136 8793.10 88.35 107.74 31.05 4419.69 2990.64 319.5.19 3952.28 5082.30 51.05 4.03 MWD IFR MS 137 8824.13 89.79 106.32 31.03 4420.19 3021.64 3186.11 3981.95 5099.72 51.34 6.52 MWD IFR MS 138 8855.21 89.35 106.12 .31.08 4420.43 3052.71 3177.42 4011.79 5117.66 51.62 1.56 MWD IFR MS 139 8887.34 90.34 106.35 32.13 4420.51 3084.83 3168.44 4042.64 5136.33 51.91 3.16 MWD IFR MS 140 8917.96 92.16 105.84 30.62 4419.85 3115.44 3159.95 4072.05 5154.31 52.19 6.17 MWD IFR MS 141 8948.16 91.82 105.56 30.20 4418.80 3145.62 3151.79 4101.10 5172.31 52.46 1.46 MWD IFR MS 142 8979.02 91.68 106.09 30.86 4417.86 3176.46 3143.38 4130.78 5190.78 52.73 1.78 MWD IFR MS 143 9011.28 90.51 105.60 32.26 4417.24 3208.71 3134.57 4161..81 5210.20 53.01 3.93 MWD IFR MS 144 9042.36 89.86 106.57 31.08 4417.14 3239.79 3125.96 4191.67 5228.93 53.29 3.76 MWD IFR MS 145 9074.10 89.52 106.20 31.74 4417.31 3271.52 3117.01 4222.12 5248.05 53.56 1.58 MWD IFR MS 146 9104.74 90.31 104.27 30.64 4417.36 3302.15 3108.95 4251.68 5267.11 53.82 6.81 MWD IFR MS 147 9135.91 90.34 104.97 31.17 4417.18 3333.32 3101.09 4281.84 5286.86 54.09 2.25 MWD IFR MS 148 9167.87 90.86 106.44 31.96 4416.84 3365.28 3092.44 4312.61 5306.76 54.36 4.88 MWD IFR MS 149 9199.04 90.62 106.96 31.17 4416.44 3396.43 3083.48 4342.46 5325.86 54.62 1.84 MWD IFR MS 150 9229.93 90.27 107.00 30.89 4416.20 3427.30 3074.46 4372.00 5344.78 54.88 1.14 MWD IFR MS C • SCHLUMBERGER Survey Report 5-Jul-2005 10:39:42 Page 7 of 8 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 9261.05 90.21 106.58 31.12 4416.07 -- 3458.41 ------- 3065.47 --------- 4401.79 -------- 5364.04 ------- 55.15 ----- 1.36 ---- MWD - -- IFR ---- MS 152 9292.01 90.79 106.05 30.96 4415.80 3489.36 3056.77 4431.51 5383.50 55.40 2.54 MWD IFR MS 153 9323.36 90.62 105.29 31.35 4415.42 3520.70 3048.31 4461.69 5403.60 55.66 2.48 MWD IFR MS 154 9355.07 90.48 106.03 31.71 4415.11 3.552.41 3039.75 4492.22 5424.03 55.92 2.37 MWD IFR MS 155 9386.02 90.24 106.23 30.95 4414.92 3;5.83.35 303.1.15 4521.95 5443.89 56.17 1.01 MWD IFR MS 156 9416.23 89.59 105.79 30.21 4414.96 3613..56 3022.82 4550.99 5463.42 56.41 2.60 MWD IFR MS 157 9447.03 89.04 106.49 30.80 4415.33 3644.35 3014.26 4580.57 5483.37 56.65 2.89 MWD _IFR _MS 158 9479.08 89.18 104.84 32.05 4415.83 3.676.39 3005.60 4611.43 5504.45 56.90 5.17 MWD IFR MS 159 9509.75 89.69 103.84 30.67 4416.13 3707.06 2998.01 4641.14 5525.24 57.14 3.66 MWD IFR MS 160 9541.15 89.38 102.90 31.40 4416.39 3738.44 2990.75 4671.69 5547.00 57.37 3.15 MWD IFR MS 161 9572.85 88.77 102.77 31.70 4416.90 3770.12 2983.71 4702.59 5569.28 57.61 1.97 MWD IFR MS 162 9603.25 88.32 102.90 30.40 4417.67 3800.48 2976.95 4732.22 5590.72 57.83 1.54 MWD IFR MS 163 9634.45 87.91 103.47 31.20 4418.70 3831.65 2969.84 4762.58 5612.68 58.05 2.25 MWD IFR MS 164 9666.69 87.91 104.96 32.24 4419.87 3863.87 2961.93 4793.82 5635.04 58.29 4.62 MWD IFR MS 165 9696.49 88.04 106.84 29.80 4420.92 3893.64 2953.7.7 4822.46 5655.16 58.51 6.32 MWD IFR MS 166 9728.44 89.04 108.06 31.95 4421.74 3925.55 2944.19 4852.92 5676.19 58.76 4.94 MWD IFR MS 167 9759.88 89.97 106.66 31.44 4422.01 3956.96 2934.81 4882.93 5697.03 58.99 5.35 MWD IFR MS 168 9790.87 89.49 105.64 30.99 4422.16 3987.95 2926.19 4912.70 5718.15 59.22 3.64 MWD IFR MS 169 9821.98 88.35 102.58 31.11 4422.74 4019.04 2918.61 49.42.86 5740.22 59.44 10.49 MWD IFR MS 170 9853.53 87.40 102.67 31.55 4423.91 4050.5.4 2911.72 4973.62 5763.25 59.65 3.02 MWD IFR MS 171 9884.52 172 9915.22 173 9946.08 174 9977.41 175 10008.76 176 10040.09 177 10071.83 178 10102.75 179 10133.48 180 10165.04 • 87.74 101.92 30.99 4425.23 4081.47 2905.13 5003.88 5786.06 59.86 2.66 MWD_ IFR_ MS • 88.76 103.00 30.70 4426.16 4112.13 2898.51 5033.84 5808.69 60.07 4.84 MWD IFR MS 88.28 100.14 30.86 4426.96 4142.92 2892.32 5064.06 5831.83 60.27 9.39 MWD IFR MS 86.91 100.61 31.33 4428.28 4174.12 '2886.68 5094.85 5855.80 60.46 4.62 MWD IFR MS 86.29 100.18 31.35 4430.14 4205.3'1 2881.04 5125.63 5879.83 60.66 2.41 MWD IFR MS 86.77 101.70 31.33 4432.03 4236.50 2875.10 5156.33 5903.73 60.86 5.08 MWD IFR MS 88.05 101.48 31.74 4433.47 4268.15 2868.73 5187.39 5927.79 61.06 4.09 MWD IFR MS 88.53 100.80 30.92 4434.39 4298.99 2862..76 5217.72 5951.47 61.25 2.69 MWD IFR MS 87.98 101.24 30.73 4435.32 4329.63 2856.89 5247.87 5975.11 61.44 2.29 MWD IFR MS 88.15 101.22 31.56 4436.39 4361.10 2850.75 5278.80 5999.38 61.63 0.54 MWD IFR MS SCHLUMBERGER Survey Report 5-Jul-2005 10:39:42 Page 8 of 8 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) (f t) (ft) (ft) (deg) 100f) type (deg) 181 10196.12 88.42 102.50 31.08 4437.32 4392.12 2844.36 5309.21 6023.13 61.82 4.21 MWD_IFR_MS 182 10227.67 87.98 103.11 31.55 4438.31 4423.64 2837,37 5.339.96 6046.97 62.02 2.38 MWD IFR MS 183 10258.95 87.56 102.24 31.28 4439.53 4454.87 2830.52 5370.45 6070.71 62.21 3.09 MWD IFR MS 184 10289.85 86.84 103.09 30.90 4441.04 4.485.7.0 2823.75 5400.56 6094.23 62.40 3.60 MWD IFR MS 185 10345.00 86.84 103.09 55.15 4444.08 4540.74 2811.28 5454.20 6136.09 62.73 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-202L3 Date Dispatched: 11-Jul-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: "~'~ Please sign and return to: Drilling & Measurements LWD Division 2525 Gambell Street, Suite 400 Anchorage, Alaska 99501 nroset@slb.com Fax:907-561-8317 L • Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay L-202L3 BP Exploration (Alaska) Inc. Permit No: 204-199 Surface Location: 2572' NSL, 3690' WEL, SEC. 34, T12N, Rl lE, UM Bottomhole Location: 12' NSL, 2072' EWL, SEC. 26, 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 hours notice for a representative of the Commission to witness any required Commission's petroleum field inspector at Chairman BY ORDER ~ THE COMMISSION DATED this- day of October, 2004 (pager). twenty-four (24) test. Contact the cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. a :~, STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION .PERMIT TO DRILL 20 AAC 25.005 I~G~ i~(5 r~ ~ r'nrse I~:nIT1P1, 1SS!®f! 1a. Type of work ^ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ®Dev nt it ~^„i-Qy~t~Zone ^ Stratigraphic Test ^ Service ^ Development Gas one 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 2S100302630-277 11. Well Name and Number: PBU L-202L3 ~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 10674 TVD 4437 12. Field /Pool(s): Prudhoe Bay Field / Orion 4a. Location of Well (Governmental Section): Surface: 2572' NSL 3690' WEL SEC 34 T12N R11E UM 7. Property Designation: ADL 028238 Schrader Bluff , , . , , , Top of Productive Horizon: 650' NSL, 190' WEL, SEC. 27, T12N, R11E, UM (OA) 8. Land Use Permit: 13. Approximate Spud Date: November 8, 2004 Total Depth: 12' NSL, 2072' EWL, SEC. 26, 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: 6808 feet Maximum Hole Angle: 91 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.03 Downhole: 2035 Surface: 1580 1 asing Program: Size Specifications Setting Depth To Bottom Uantrty o ement 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' 80 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 3878' 6796' 4382' 10674' 4437' Uncemented Slotted Liner 19. ` PRESENT WELL CONDITION SUMMARY (To be completed for Redril{ AND Re-entry Operations) Total Depth MD (ft): 12349 Total Depth TVD (ft): 4564 Plugs (measured): None Effective Depth MD (ft): 12349 Effective Depth TVD (ft): 4564 Junk (measured): None Casing Len th Size Cement Volume MD TVD t rl Con for 80' 20" x 34" 60 sx Arctic Set A rox. 109' 109' ,-f 3171' 10-3/4" 580 sx AS Lite, 442 sx Class 'G' 3200' 2627' 7771' 7-5/8" 562 sx Class 'G' 7800' 4635' Pr ducti n i 4834' 4-1/2" Uncemented Slotted Liner 7800' - 12634' 4635' - 4722' Liner L1, OBb 5178' 4-1/2" Uncemented Slotted Liner 7126' - 4505' 12304' - 4602' Liner L2, OBa 5356' 4-1/2" Uncemented Slotted Liner 6993' - 4456' 12349' - 4564' Perforation Depth MD (ft): None Perforation Depth TVD (ft): None 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that th foregoing is true and correct to the best of my knowledge. Contact Rob Tirpack, 564-4166 Printed Name Low~I~Crane Title Senior Drilling Engineer - ' --~ Prepared By Name/Number: Si nature ,.~ , -c C~t~- Phone 564-4089 Date "` -~~ °~= Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: ~p API Number: 50- OZ - 2. ,3 Z Z -- ~ Permit Approval ate: to !~ ~r3 y See cover letter for other requirements Conditions of Approval: Samples Required ^ Yes No Mud Log Required ^ Yes No _ ,L Hydro en Sulfide Measures ^ Yes No Directional Survey Required Yes ^ No Other: t ~~ t ~U ~~ - ~ ~ X00 ~~~ l APPROVED BY A roved B ~ THE COMMISSION Date ~~ Form 10-401 Revised 08004 ~_, ~ '• SGbmit In Duplicate l ~~ ~, I ~ ~ 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: 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, R11E 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 .i ~;. 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 ~ 4,400' TVDss (Estimated) 8.6 - 8.7 ppg in Schrader O-Sands Permit to Drill 09/23/04 ,, Formation Markers Z-210 PB1(Based on Schlumberger wp03) 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 SVi 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' UG 1 5,388' 3,702' 3,625' i ,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 $.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 Yes 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 Densi Funnel vis YP PH FL Initial 8.5 - 9.2 250-300 50-70 8.5-9.0 NC-8.0 Base Perm 9.0 - 9.5 200-250 30-45 8.5-9.0 8.0 Interval TD 9.6 max 200-250 30-40 8.5-9.0 5.0-7.0 9-7/8" Intermediate Hole Mud Pro erties: 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 Densit Stabili Oil:Water Ratio YP PV API Filtrate MBT All four Laterals 9.0 9. 650-900 80:20 15-19 <20 4-5.5 < 6 ~, Survey and Logging Program: 13-1/2" Hote 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" Produciton Holes: Surve swill need to be iFR + MS corrected real time O en hole: MWD / GR / Res /Den / Neu /PWD /AIM All realtime with recorded orosi Cased Hole: N/A 2 Permit to Drill 09/23/04 C_acinn/T~~hinn Drnnram • 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-~/z" 10-3/a" 45.5# L-80 BTC 5,210 2,480 3,171' 29'/29' 3,200'/2,627' 9'/e" 7 5/a" 29.7# L-80 BTC-M 6,890 4,790 7,771' 29'/29' 7,800'/4,635' 6-3/a" OBd 4-~/2" 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-'h" slotted 12.6# L-80 IBT N/A N/A 5,178' 7,126'/4,505' 12,304'/4,602' 6-3/a" OBa 4-'/z" 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-~/z" slotted 12.6# L-80 IBT N/A N/A 3,878' 6,796'/4,382' 10,674'/4,437' Tubin 4-'h" 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. ('_Incp Annrnar_h Wpll 1 ict- Well Name Ctr-Ctr Distance Reference MD Allowable Deviation Precautions Comment L-200 15.8' 300' 10.7' Use Travelin C linder G ro L-216 60.3' 249' 56.2' Use Travelin C linder G ro L-118 61.9' 1,402' 37.5' Use Travelin C linder G ro L-103 76.7' 499' 68.9' Use Travelin C linder G ro L-101 95.2' 1,706' 65.3' Use Travelin C linder G ro Cement Calculations Casing Size: 10-3/a -in 45.5-Ib/ft 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) Lead 442 bbls, 2484 cult, 580 sks 10.7 Ib/ al ASL G + adds - 4.28 cuft/sk Tail 92 bbls, 517 cult, 442 sks 15.8 Ib/ al Class G + adds -1.17 cuftlsk Temp BHST -55° F, BHCT -60° F estimated by Schlumber er 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 Collar 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 Ma to at 5,965' M Total Cement Volume: Wash 20 bbls CW100 S acer 35 bbls of Viscosified S acer Mud ush II Desi n Wei hied to 10.3 Tail 120 bbls, 674 cuft, 562 sks 15.8 Ib/ al G + Gasblok -1.20 cuft/sk Temp BHST - 90° F from Temp Log, BHCT 80°_F estimated b Schlumber er 3 Permit to Drill 09/23/04 • • Centralizer Recommendations 10-~/a" Casing Centralizer Placement a) Run (25) 9-6/e" 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/8" Casing Space Out a) Space 7-S/e" 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-g/" casing slips can be used instead of the 7-5/e" mandrel hanger if required for space out. 7-s/8" String Centralizer Placement a) Centralizer size: 7-S/8" 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. L -- 2~'~ ~ L ~, t~-~G~-- BOP regular test frequency for-~i will be 14 days. Diverter, BOPE 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 C~ 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: 7-5/8" Casing Test: • Integrity Test - 6-3/4" hole: • Kick Tolerance: • Planned completion fluid: • 2,035 psi -Base of Schrader OBd (8.6 ppg C~3 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 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 Surface Casin 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/a" 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 7-5/e" x 9-%8" Rigid Straight Blade Centralizers 20 each 7 6/e' Stop Rings 2 lots 7-b/" casing pups 5', 10', 20' 4 each 7 5/8" 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/a" x 4-~/z" Baker ZXP Liner Top Packer 4 each 4-'/z" Halliburton Float Shoes 3 assemblies Baker Level 3 Hookwall Han ers with LEM Com letion: ` .Amount Descri tion 6,800' 4-'/2", 12.6 Ib/ft, L-80, BTC-M tubing 1 each Baker PRM Production Packer 7-5/8" X 4-'/z" 1 each 11" X 4-~/z" FMC tubing hanger 1 each 4-'i,s", 5m Cameron Tree 2 each Halliburton X-Nipple (3.813" ID) 1 each 4-1/z" Baker CMD Sliding Sleeve 4 each Camco 4-'/z" 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-~h" W LEG 5 Permit to Drill 09/23/04 • • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well 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. II. 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. 111. 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 C~ 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. 6-3/4" 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 Drill 09/23/04 • • L-202, L-202 L1, L-202 L2 & L-202 L3 DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig 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 Rip 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-'h" 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 SV1 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 BOPE 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. Grill 20' 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 5/e' x 10-3/a" annulus with dead crude to 2,200' TVD. 9. PU 6-3/a" conventional assembly with MWD/GR/Res/Den /Neu/PWD/AIM and RIH to the float collar. Test the 7 %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. Drill 20' 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. 13. PU the 7 5/8" 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 7-6/8" 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/Res/Den/Neu/PWD/AIM to whipstock. Directionally drill to the planned TD of 12,349' MD. Circulate and cond'ttion mud and perform wiper trip. POOH. 18. Pull whipstock #2. 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 #2 with ZXP liner top packer, POOH. 19. PU the 7 S/s" 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 6-3/0" 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 slickline. 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 flowfines 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 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 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 wilt 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 to 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 fails, 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: 10-3/4" special drift casing is being used. Ensure that casing equipment is properly drifted to ensure adequate ID for the 9-'/e" 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 '/e" 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-S/e° casing will be determined by isopaching down to the top of the OBd sand based on changes in GR/Res 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. A 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"j, 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 bowl 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. A 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. 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-~/e" 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 toplmiddle 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-s/8" 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 underbalance 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 b/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 5/$° casing. - TIW Valve: Ensure that a TIW valve with a cross over to 7 5/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 /ssues: - 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- 210P61 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. - ECD/Hole Cleaning: Utilize PWD to monitor for good hole cleaning and ECD trends. Cuttings will 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-~/s" 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 all 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-~/2" 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 i ! Job #12 /Job #17 /Job #22: Run 4-~h" 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 all 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 running the OBb liner to confirm additional weight pipe reouirements. 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 to 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 IBT 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-~/~" IBT - makeup to position Reference RPs: • "None Apply' Job #23 : Run 4-~/z" 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 still 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 Drill 09/23/04 L-202, L1, L2, & L3 PROPOSED COMPLETION Phoenix Pressure Gauge with control lines to surface RA Tag TBD ~ 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 ", SM csg.head w/ 7" mandrel hanger & packoff 11" x 11", 5M, tbg spool w/ 11" x 4-112" tubing hanger with control line 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` ND - 4-1/2" X 1" KBG-2 - SV -Halliburton 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 - 4-1I2" X 1" KBG-2 - DV Versapro MOBM in each Lateral and in mother bore from tbg tail down. ~~ 6-3/4" OA Lateral 6,796'-10,674` ~ Swell packer placement TBD Junction Specifications: / 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 Hookwalt Hanger @ 6,779' MD Window in 7-5/8" casing @ 6,783' - 6,796' MD Well Indination @ Window = 65° Baker Hughes Hookwall Hanger @ 6,976` MD Window in 7-5/8" casing @ 6,980' - 6,993' MD Well Indination @ Window = 69° Baker Hughes Hookwall Hanger @ 7,109' MD Window in 7-5/8" casing @ 7,113' - 7,126' MD Well Indination @ Window = 69° 6-3/4" OBa Lateral 6,993'-12,349` - - - `~. - - - - - Swell packer placement TBD 6-3/4" OBb Lateral 7,126'-12,304' =11ifi- =11it'- _-=~ ~ Swell packer placement TBD RA Tag TBD 7-5/8", 29.7#, L-80, BTC-M @ 7800' Casing Drift: 6.75" Casing ID: 6.875" DATE 1 REV. BY 1 COMMENTS :. ~ 9/9/2004 ~ R8T ~ Level 3Multi-Lateral, 4-1/2" GL Completion ~ F2A Tag 6~/4" OBd Lateral 7,800'-12,634' `ijG.~afe~., API NO: 50-029-~ooocx-00 ORION 5o-029-xxxxx-so WELL: L-202 ML 50-029 xxxxx-61 50-029 : xxxx-62 r Schlumberger L-202L3 P4 Pro oral RapoR Dab: September 7, 2004 tlurwy 1 DLS Camputatlon MaNod: Minknum Curvature / Lubkiski C9arrt BP Expkxalbn Alaska Vartleal Section A:Imulh: 105.000° FINd: Prudhoe Bay Unit - WOA VartleN 8ee8on Organ: N 0.000 $ E 0.000 fl tRrochr-a 181st: L-PAD / L-202 ~~' ~~ ~t ~ TVD Rafanrrea l9avatlon: 71.30 fl ralathre b MSL Wall: Plan L-202 (N-N) BorNrob: Plan L•202L3 OA ~~$ Sw BW I Orouml LavN Etavatlorr: 48.80 ft rela8ve b MSL IIYYYAPM: 50029 Napmtle Dacpnafton: 24.705° Surwy Nanra I Dab: L•202L3 (P4) / Sepember 7, 2004 Tatty FINd >pnnytlr. 57593.512 nT Tort l AlW I DDI I ERD ra8o: 181.501° 18354.15 R / 8.511 11.883 YaOnafk qp: x.807° Odd Coordlnala NAD27 Alaska Stale Planes, Tone 04, US Feet Dadinalbn Dab: November OB, 2004 lacatlan LaflLonp: N 70.35066488, W 149.32430214 tilapnatk Dadkratlar ModN: BGGM 2004 Loatlon Odd NIE YAt: N 5978293.250 ftUS, E 583223.800 ftUS NoM Rafarwwa: True NoM Orld Convaryana Aayb: +0.83835414° Tabl Corr Np portly o Tnx Nortlr: +24.705° l.annraraa krdbatloa Admalh TVD Sub•Sa TVD S ~ W n NS t:W DLS Taol Faa Rab Watlr Rab NoMbp EaaWq I.rrtlhrda laatltluda D ae rb R R R R R R R 60 R 00 R 00 R RUtl RU8 r Op vanlpSwcic O/OJ.W W.W OS7.iRr 4J//.10 9[lTJ.00 ir8V.1[ 44/LJ0 308U.1e 17feZ./O 4.W LJ.VW 1.70 4.24 .T`!Cl!l60.W Base Whipstock 8798.00 88.88 90.84 4382.48 4305.18 991.81 4484.23 3850.09 2004.82 18.00 O.OOG 14.52 7.35 5881985.04 KOP Crv 10/100 8808.00 88.88 80.94 4387.17 4309.87 1002.31 4495.27 3849.91 2015.88 0.00 25.886 0.00 0.00 5981964.88 8900.00 75.23 95.05 4417.03 4339.73 1087.34 4582.21 3845.29 2102.45 10.00 24.326 9.07 4.48 5981961.32 7000.00 84.37 99.17 4434.73 4357.43 1184.71 4880.52 3833.08 2199.98 10.00 23.59[3 9.14 4.12 5981850.20 End Crv 7071.71 90.95 102.03 4437.68 4360.38 1258.10 4752.09 3819.91 2270.38 10.00 O.OOG 9.17 3.99 5981837.81 Crv 6/100 8288.77 80.95 102.03 4417.60 4340.30 2489.37 5986.98 3388.87 3458.58 0.00 115.656 0.00 0.00 5981887.80 8300.00 90.80 102.75 4417.42 4340.12 2482.58 5980.21 3363.83 3471.49 8.00 11S.68G -2.80 5.41 5981895.11 L-Z02L3 OA Tgt 2 8323.18 90.00 104.00 4417.30 4340.00 2505.75 6003.39 3358.47 3494.04 6.00 118.046 -2.80 5.41 5981890.00 End Crv 8351.42 89.28 105.52 4417.48 4340.18 2533.99 8031.83 3351.27 3521.35 8.00 O.OOG -2.63 5.39 5981883.11 Crv 8/100 8489.82 89.28 105.52 4432.28 4354.96 3672.05 7188.73 3046.69 4817.84 0.00 57.416 0.00 0.00 5981390.75 L-202L3 OA Tgt 3 9492.53 89.35 10.5.87 4432.30 4355.00 3874.98 7172.84 3045.91 4820.75 8.00 23.716 3.23 5.08 5981390.00 End Crv 9499.87 89.78 105.85 4432.38 4355.08 3682.40 7180.08 3043.89 4827.91 8.00 O.OOG 5.49 2.41 5981388.06 TD / 4-112" Lnr 10874.05 ° 89.78 105.85 4437.30 4360.00 4858.34 8354.15 2723.24 5757.34 0.00 O.OOG 0.00 0.00 5981080.00 Surface : 2571 FSL 3890 FEL S34 T12N R11E UM Northino 1V1 5978293.25 f1'tU81 Eaetlrra 1X1 f 583223.80 RU81 L-202L3 OA Tgt 2 : 849 FSL 190 FEL S27 T72N R11E UM 5981890.00 586880.00 L-202L3 OA Tgt 3 : 335 FSL 4344 FEL S28 T1 2N R11E UM 5881390.00 587810.00 TD / BHL : 12 FSL 3208 FEL S26 T72N R11E UM 5981080.00 588950.00 ~tfOl/~./l N /V.3lSU6J6lL W 74g.:SUtl17tlM'1 585187.58 N 70.38083585 W 149.30802052 585198.81 N 70.38083535 W 149.30783089 585285.44 N 70.38082288 W 148.30722585 585383.10 N 70.38058922 W 149.30843384 585453.61 N 70.38055318 W 149.30586225 588844.45 N 70.35988011 W 149.29821255 588857.40 N 70.35965234 W 148.29610764 588680.00 N 70.35983787 W 149.29592455 588707.39 N 70.35881788 W 149.29570274 587807.19 N 70.35898428 W 149.28879812 567810.00 N 70.35896212 W 149.28677538 587817.18 N 70.35897858 W 149.28671720 588950.00 N 70.35809846 W 149.27754 WetlDesign Ver 3.1RT-SP3.03-HF5.00 Bid( do3lrt-548) L-202lPlan L-202 (N-N)lPlan L-202L3 OALL-202L3 (P4) Gener~ed 9/10/200412:13 PM Page 1 of 1 ~~~ Schlumberger ~" L-202 (P4) `E'° P ""°"'"~ rudhoe Bay Unit - WOA L-PAD were vr.n-r„ LbEr. l001I ZODl 04' eo.eor L ' Dr.: ro..ner ro. zoa auto. Lour- INDIT u.w. 94r vw.. zr. a. UB fr Lr. N)021z]w rMIWp: lY1s2vD13 MIB amt--: ~0 6]!WU' rr.r.rr Yp ~: •2L.fi5 F9: 6)6W 6nT . Lm: WW 101).4! _ ~Y 43t11.lO NS Bob irl 04r0]W ~ L'~ NI1 Wf. brr Trl~(/1]pl y...~,.. _. 1000 4000 z^Y~_ ~) Y) C 4500 _ ...... 5000 1000 by Schlumberger ~" L-202L3 (P4) `E`° Prudhoe Bay Unit - WOA "~"°'"E L-PAD MgrYC P9~Frn~Yn 9ulo Laollm IN011NM981W MF.29rr 01, l13FM LroMl~e- MaEM: BOOM 3001 [lb~. 90.p1' [NM: IMnbr06. 1001 li MO 111.]W Np Ds: q{.]06' FS 67000.0 nT Lon: WN919 Z1.Nt ~~: 09TB1BJ26 M19 OM Cana. W.9000M11' 9bl 1-101 NDRFI' Fp-Y T9pY (11.9D9+9n MBL1 E-IYp: Y6776.609116 8olY foe: O.F99F07006 PIIn: L.10ri]M) Spry [IFII: 61191nWw 01.100{ 2000 2500 3000 3500 4000 4500 5000 5500 4000 ,^~ 3500 n z Q~_ 7i c ~~ 3000 _d N V V V 2500 P3) 7 (P3) P4b) ~ 2000 2500 3000 3500 4000 4500 5000 5500 «< W Scale = 1(in):500(ft) E »> PERMIT TO DRILL 20 AAC 25.405 (e) If a well has multiple well branches, each branch requires a separate Permit to Drill. If 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 all information required under (c) of this section with the application for a Permit to Drill for that branch. For each subsequent well branch, the application for a Permit to Drill need only include information under (c) of this section that is unique to that branch and need not include the $100 fee. • • TRAANMMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~•,¢~ ~ ~ 2c, ~, ~ ~ PTD# 20 y -/ 9 g Development Exploration Service Stratigraphic CHECK WAAT ADD-OHS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well ~~G, G- z.oz ` ~' Permit No-2 /79~ API No. So-o ... 23 Z % ?` (lf API number Production. should continue to be reported as Iasi two. (2) digits a funciion•of the original API number. stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(1), all (PII] records, data and logs acquired for the pilot bole must be clearly differentiated ~in both name (name on permit plus P1Tj and API number (50 - 70/80) from records, data aad logs acquired for well (name on permit). SPACING The permit is approved subject •to fuU E7~CEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. SComnanv Hamel assumes ibe liability of any protest to the spacing ,exception that may occur. DRY DITCH ~ All dry ditch sample seas submitted to the SAMPLE Commission must be in na greater Than 30' sample intervals from below the permafrost or from where samples are first caught and 70' sample intervals through target zones. WELL P MIT CHECKLIST Field & Pool PRUDHOE BAY, ORION SCHR BL OIL - 640135 Well Name: PRUDHOE BAY UN ORIN L-202L3 Program DEV Well bore seg ^~ PTD#:2041990 Company BP EXPLORATION A( LAStCA} INC Initial Class(Type DEV! 1-OIL GeoArea Unit OnlOff Shore On Annular Disposal ^ Administration 1 Permit_feeattached------------------------------------ _--__---Yes- ______- -- - - - 2 Lease number appropriate _ _ _ _ Yes - - - - - - 3 UniquewelLnameandnumber-_______,._____--__-_._____ _._____Yes. -__--_- 4 Wflll located in a_defned_pool. - - - - - - Yes . - - - - - ----------------- 5 Welllocakedproperdistance-fromdrillingunit-boundary_______________ _________Yes. ____--___-_-________--___-____--_--_-____--_--__--_-__-___-____-_- 6 Well located pr_operdistance_fromotherwells______---__---_____ _________Yes_ --___---__-_--__-_--__-_____-,______-____--___--__ __-__--___-__---_--- 7 Sufficientacreageayailablein-drillinqunit-_-__-__-__.-_____-__ ___-.-__Yes- -_-__. -------------------------------------------------------------------- 8 If_deyiated,is_wellboreplat_included___--__________________ _______ _Yes_ -___--______-____-___-_.__--_ --------------------------------------------- 9 Operator only affected party_-.-______________________-__ ___---_-_Yes- _-__-.-__ 10 Ope[atorhasappropriate.bondinfQrce________________________ _________Yes- _--__--. 11 Petmit_canbeissuedvnthoutconservafionor~er--------.- ---.---Yes- ------ ----------------------------------------------------------------- Appr Date 12 Pe[mit_canbeissuedwithoutadminist[alive_approval-_-_,_-_-____ _-__-_-_Yes- --------------------------------------------- ----------------------------- RPC 1015!2004 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strataauthOrizedbylnjectionOrder#(put_1O#in-comments)-(For-NA__ ______________-_____--____--______--_-._-_-__-__---_-__-_--,___--- ----- 15 All wells withinll4.mileareaofreyiewidentified(Forservicewellonly)______ _________ NA_. ___.___,___-___._________._____._____._.-__-________--__---_..-_-___- ----- 16 Pre•produced injector duration-of pre production less than_ 3 months_ (For service well only) NA_ _ - _ _ - - - - - 17 AC_M_P_FindingofConsistency_h_asbeenissued_fgrthisproject__________ _________NA_- _____--,________---___-__----____. ------------------------------------- Engineering 18 Conductorstring-provided_______________________________ _-_-_-___NA__ ____,-__--____-_-- --_--_ ---------------------------------------------- 19 Surface casing protects all known- USDWS - - - NA - - - - - - - - - - - 20 CMT_voladeguate_tocifcul_ate_onconductor&su_rf_csg______________ ____-___ NA-_ __-. -__----__--__-_--__--___-__-------_--_-__---__--_-------_--_--_- 21 CMT_vol-adeguate_to tie-in long string tosurf csg_ - - - - - - - - NA - - - - - - - - - - 22 CMT-will coyer all knownproductiyehorizons_____________________ _________ No-__ -_._Slotted,-___.-__--_____--_--__--__-,----__--_--__----__---__---- -_--_ 23 CasingdesiynsadequateforC,T,B&-permafcost---------------- --.- -Yes-- ------.---------------------------------------------------------------- 24 Adequatetankage_orreservepit-___---_____---___________ _________Yes-_ ___.-Nabors-9ES,__--__-__-_____ - - -- -- 25 Ifa_re-drill,has-a_1.0-403forabandonmentbeen approved____--_____ _________ NA-_- ____-La_teral.----_---_--_--__--_____-_--------__----__-___----___--__- 26 Adequatewellboreseparationproposed_______________________ ____..___Yes__ _______-.__-__..___-____-._____.____-,__-_ 27 If_diverterrequired,dcesitmeekregulations______________________ _________NA__- ___ -Sidetrack.--_.__---_______--______--___-__-_--__------_--__-__--.- -- Appr Date 28 Dtillingfluid_prpgramschematic&equiplistadequate_______________ _________Yes_- --__-Max MW-9.2ppg,-____---_____-___-_-___-_--____-_------_-________--_--- WGA 10!5!2004 29 BOPEs,dotheymeetre9ulation--_---_____--___---_-._ ___--__-Yes-- ------------------------------------------------------------- 30 BOPS-pressratinq appropriate; lest to-(putpsig in comments)___________ _________Yes_- -___-Test to3500-psi._MSP15.80psi.____-___-_---__--____-__----___--_____---_--- 31 Choke_manifgldcomp_IieswlAPI-RP-53(May84)-_________________ ____---_Yes_- -__-_____---_______-__-__-_--____--_--__- ---------------------------- 32 Work willoccurwithoutoperationshctdown______________________ ___ ____Yes_- ___-.-___________-__- - - - - 33 Is presence ofH2Sgasprpbable-.-__--------------------- --------- No-_ ___-.NotanH2Spad.--___-___-___-___---__.---------.----------- _-- 34 Mechanical condition of wells within AOR verified- GFor-service well only) - - . _ - - NA_ _ - - Geology 35 Permikcanbeissuedwlohydrogen_sulfidemeasures-------------__ -----__._Yes_- -___._-__-_-___-______--_____-__ ----------------------------------------- 36 Data-p_resentedon_potential overpressure zones___________________ _________ NA-_ __---___-_-___._--_--_-____---__--__-_----_,-_--__-----__--- Appr Date 37 Seismic analysis of shallow gas zones - - - - - - Nq - - - - - - - - - - - - - RPC 1015!2004 38 Seabed condition survey_(if off_-shore} - - _ _ - - - _ - - - -- NA - - - -- - -- - - - 39 -Contact namelph4ne for weekly progress_reports [exploratory only]_ _ _ - _ _ - - _ _ - NA_ _ - Geologic Engineering Public Commissioner: Date: Commissioner: Date o loner Date ois 'o~b~~. ~~~~ • •
