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
205-178
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 direcrt inspe~cjtioQn of the file. o~, ~J - L ! C~ Well History File Identifier Organizing (done) RE AN C or Items: Greyscale Items: ~ ~~ ^ Poor Quality Originals: ^ Other: ~,~.ded iiiimiiiuiiiui DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: Re,~a~~eecea Illlllllllllllllil OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: BY: Maria Project Proofing BY: Maria Date: Date: ^ Other:: __~P .,uiiimmiriifu w~P f, '- Y I Scanning Preparation ~ x 30 = ~ + =TOTAL PAGES Count does not include cover sheet ( ) BY: Maria Date: /s/ Production Scanning III (VIII VIII II III Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Pre aration: _~YES NO BY: Maria Date: ~ ~~ iJ V /s/ ~/ VI, Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO Y BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II 11 11 I II II I I III ReScanned III IIIIIIIIIII VIII BY: Maria Date: /s/ Comments about this file: z o~,~,~~~kea iiiuiiiimumi P 10/6/2005 Well History File Cover Page.doc F:\LaserFiche\CvrPgs_Inserts\Mierofilm Marker.doc ~ d ~, a.~ ~ DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drill 2051780 Well Name/No. KUPARUK RIV UNIT 1L-25AL1-02 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-22174-62-00 MD 10374 TVD 5983 Completion Date 12/28/2005 REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Log s Run: MWD, GR Well Log Information: Log/ Electr Data Digital Dataset Typ Med/Frmt Number Name D Asc Directional Survey I', Fit Directional Survey (~ Directional Survey tKpt 15285 LIS Verification ~~6g 15285 Gamma Ray 4~ 15285 Gamma Ray ,~.Rpt 15286 LIS Verification ~~og 15286 Gamma Ray 15286 Gamma Ray Well Cores/Samples Information: Name Interval Start Stop ADDITIONAL INFORMt9,TION Well Cored? Y Chips Received? -"`I"71V"" Analysis Y~ Received? Completion Status 1-OIL Current Status 1-OIL UIC N Samples No Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH Scale Media No Start Stop CH Received Comments 9267 10374 Open 1 L-25A, 1 L-25A PB 1, 1 L- ~ 25A L1-01, 1L-25A L1-01 PB 1, 1 L-25A L1-02, 1 L- 25A L1-02 P61 on diskette i 9267 10374 Open 1L-25A L1-02 i 9359 10397 Open 1L-25A L1-02 PB1 8840 10374 Open 7/19/2007 LIS Veri w/Graphics Meta and TIF 25 Blu 8839 10374 Open 7/19/2007 MD GR 27-Dec-2005 25 Blu 8839 10374 Open 7/19/2007 TVD GR 27-Dec-2005 8840 10397 Open 7/19/2007 PB1 LIS Veri w/Graphics Meta and TIF 25 Blu 8839 10397 Open 7/19/2007 PB1 MD GR 27-Dec-2005 25 Blu 8839 10397 Open 7/19/2007 PB1 TVD GR 27-Dec-2005 Sent Received Daily History Received? Formation Tops Sample Set Number Comments LY.F~(V ~'/N DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drill 2051780 Well NamelNo. KUPARUK RIV UNIT 1L-25AL1-02 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-22174-62-00 MD 10374 TVD 5983 Completion Date 12/28/2005 Completion Status 1-OIL Current Status 1-OIL UIC N Comments: - - _ _ - -- _ _ - - --. - - Compliance Reviewed By: ___ __ ___ Date: ~_ ~ _~~~ ~~ Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: 1L-25AL1-02 i ~1.~® BAKER NUGNES Anchorage GEOScience Center Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR Measured Depth Log 1 blueline - GR TVD Log = - _~ . . ~I _ -- ~~ _ _ _ ;~ ~~ ~ _ ~!! =1 ~' _ _ , F`E -~- - - ~{ F ~ LAC Job#: 1025231 ~. ~ ~--- Sent By: Deepa Jog ekar Date: ! ~ ~ ~ t "~' ~ -tea Received By: Date: ~ `~~ ~ } _ ~~ ~_ 3~ ~ ~ v ~ "~' sa~~.~i~3 ~I~ c`~: ~~.~ vGd?~. ~,*cY3~it~3~aIG~'€ ~--1 _ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETUI~1G OR FAXING YOUR COPY ' r FAX: (907) 267-6623 ~ ~ _ Baker Hughes INTEQ ~ ~ __ 7260 Homer Drive Anchorage, Alaska ~O~ f ~ ~ ,~ 99518 '~ ~F 1 ~ ~5 Direct: (907) 267-6612 ~, FAX: (907) 267-6623 ~ ~~~~'_ ~ _ Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: 1L-25AL1-02PB 1 ~r~~~ BAKER NUGNES Anchorage GEOScience Center Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files} 1 LDWG lister summary 1 blueline - GR Measured Depth Log 1 blueline - GR TVD Log LAC Job#: 1025231 Sent By: Deepa J g kar Received By: ~' ~ ~ Date. ~,~fl~ ~~., Date ~' ~"- j ., ,, ~., ~I i _. -- . , .-_ _i L._ __ -, _ _ ---. _~.=i = t ,. ~, P - ~, ~~ [ i ,~ ~ - ~~ - --- 1. '~ ~~~~ ~~! ~_ was ;~o~~s. ;,~~nissiera , j~ ~~~~~~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 ~~~1~~ ~- ~Sa~ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~ -~ ~ -~.. =~ ~ _-- ~ __ ~~ - ~, I i ~ .. STATE OF ALASKA + ALASK~L AND GAS CONSERVATION COA/~SION `WIxLL COMPLETION OR RECOMPLETION REPORT AND LOG 05/03/06: Revised, Put on Production ~ 1 a. Well Status: ®Oil [~ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoaAC zs.,os zoAAC zs.~,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband. 12/28/2005 ~ 12. Permit to Drill Number 205-178 - 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 12/19/2005 13. API Number 50-029-22174-62-00 ' 4a. Location of Well (Governmental Section): Surface: ' ' ~ 7. Date T.D. Reached 12/27/2005 14. Well Name and Number: Kuparuk 1L-25AL1-02 ' 597 FNL, 143 FEL, SEC. 31, T11N, R10E, UM Top of Productive Horizon: 1293' FNL, 1263' FWL, SEC. 05, T10N, R10E, UM g, KB Elevation (ft): 130' 15. Field /Pool(s): Kuparuk River Unit /Kuparuk River Pool Total Depth: 1184' FNL, 2476' FWL, SEC. 05, T10N, R10E, UM 9. Plug Back Depth (MD+TVD} 10374 + 5983 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 539925 y- 5948371 Zone- ASP4 10. Total Depth (MD+TVD) 10374 + 5983 Ft 16. Property Designation: ADL 025664 TPI: x- 541384 y- 5942404 Zone- ASP4 Total Depth: x- 542596 Y- 5942519 Zone- ASP4 11. Depth where SSSV set 1810 MD 17. Land Use Permit: 1 if ff h Thi k f P f 20 t 18. Directional Survey ®Yes ^ No ore 9. Water depth, o s N/A MSL ness o erma ros . c 1500' (Approx.) 21. Logs Run: MWD, GR 2. ASING, LINER AND EMENTING ECORD CASING ETTING EPTH MD ETTING EPTH;TVD HOLE OUNT SIZE WT. PER FT. GRADH OP ` OTTOM OP OTrOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surface 122' Surface 122' 24" 235 sx Arcticset 9-5/8" 36# J-55 Surface 4978' Surface 3614' 12-1/4" 800 sx PF 'E', 550 sx Class 'G' 7" 26# J-55 Surface 8838' Surface 5976' 8-1/2" 250 sx Class 'G' 2-3/8" 4.43# L-80 8722' 10280' 5903' 5992' 3" Uncemented Slotted Liner 23. Perforations open•to Production (MD +TVD of Top and " " 24. TUBING RECORD Bottom Interval, Slze and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/8" Slotted Section Note: 3-1/2", 9.3#, J-55 8742' 8692' MD TVD MD TVD 8733' - 8899' 5910' - 6003' Only Well Branch 9151' - 9383' 5992' - 5987 1 L-25AL1-02 is 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10103' - 10268' 6004' - 5993' Directly A ibl DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED ccess e 2000' Freeze Protect w/ Diesel 26• PRODUCTION TEST Date First Production: March 6, 2006 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test 4/7/2006 Hours Tested 18 PRODUCTION FOR TEST PERIOD ~ OIL-BBL 72 GAS-MCF 1031 WATER-BBL 4 CHOKE SIZE 176% GAS-OIL RATIO 1448 Flow Tubing Press. 20 Casing Pressure 814 CALCULATED 24-HOUR RATE OIL-BBL g6 GAS-MCF 1374 WATER-BBL 5 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". g~~y _ _ .. g +. None L ~ 2,o`.a5; `" ,,.~ _ ~ _ ~~ f Form 10-407 Revised 12/2003 ~~'~' ONTINUED ON REVERSE SIDE ~-'~iS ~, s'. CG, 28. GEOLOGIC MARKE 29. ORMATION 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". (From 1 L-25) None Top Kuparuk C 8840' 5977 Top Kuparuk B 8873' 5994' Top Kuparuk B 9135' 5993' Top Kuparuk B 9404' 5987' Top Kuparuk B 10084' 6006' Top Kuparuk C4 10280' 5992' 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. e/ Signed Terrie Hubble Title Technical Assistant Date O`~I D~I Kuparuk 1 L-25AL 1-02 205-178 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. orriiin9 Engineer: Sean McLaugh~;n, 564-4387 INSTRUCTIONS GeNeRA~: 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 1'.?/2003 Submit Original Only STATE OF ALASKA ~,'' ALASKA~L AND GAS CONSERVATION COMN~~ WELL COMPLETION OR RECOMPLETION REPORT AN¢~~1(~ 7 2~p6 _. _t._ nst w Gas G4t~s~ COtt~miSSipn ia. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC25.105 2oAAC2s.~,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other -,,._ b• ~~~~ - --- development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband. 12/28/2005 12. Permit to Drill Number 205-178 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 12/19/2005 ~ 13. API Number 50-029-22174-62-00 ` 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 12/27/2005 ~ 14. Well Name and Number: Kuparuk 1L-25AL1-02 FNL, 143 FEL, SEC. 31, T11N, R10E, UM 597 Top of Productive Horizon: 1293' FNL, 1263' FWL, SEC. 05, T10N, R10E, UM 8. KB Elevation (ft): 130' 15. Field /Pool(s): Kuparuk River Unit /Kuparuk River Pool Total Depth: 1184' FNL, 2476' FWL, SEC. 05, T10N, R10E, UM 9. Plug Back Depth (MD+TVD) 10374 + 5983 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 539925 " y- 5948371 'Zone- ASP4 10. Total Depth (MD+TVD) 10374 + 5983 Ft 16. Property Designation: ADL 025664 TPI: x- 541384 y- 5942404 Zone- ASP4 Total Depth: x- 542596 Y- 5942519 -Zone- ASP4 11 • Depth where SSSV set 1810 MD 17. Land Use Permit: ---- - - _---- ------------------ - h if ff h m frost Thi k f P 20 18. Directional Surrey ®Yes ^ No , ore 19. Water dept o s N/A MSL ness o er a . c 1500 (Approx.) 21. Logs Run: ~ c } ~7 ~i3~ ~Y3 j~ j ~ `~ 7% ° '7'1~ MW D, GR ~,,~. Z Z2. vG 2. ASING, LINER AND CEMENTING ECORD CASING ETTING EPTH MD ETTING EPTH TVD HOLE MOUNT $IZE WT. PER FT. GRADE OP OTTOM OP TTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surface 122' Surface 122' 24" 35 sx Arcticset I 9-5/8" 36# J-55 Surface 4978' Surface 3614' 12-1/4" 00 sx PF 'E', 550 sx Class 'G' 7" 26# J-55 Surface 8838' Surface 5976' 8-1/2" 50 sx Class 'G' 2-3/8" 4.43# L-80 8722' 10280' 5903' 5992' 3" Uncemented Slotted Liner 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TUBING .RECORD none Bottom Interval, Size and Number; if none, state ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/8" Slotted Section Note: 3-1/2", 9.3#, J-55 8742' 8692' MD TVD MD TVD 8733' - 8899' 5910' - 6003' Only Well Branch 9151' - 9383' 5992' - 5987 1 L-25AL1-02 is 25 ACID, FRACTURE,' CEMENT SQUEEZE, ETC. 10103' - 10268' 6004' - 5993' Directly DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Accessible 2000' Freeze Protect w/ 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 $IZE GAS-OIL RATIO Flow Tubing Press. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none"' ~y~y ~r _ None ~- ~~~ •: r"' - s Form 10-407 Revised 12/2003 Vi CONTINUED ON REVERSE SIDE ( ~ ~ ~ GEOLOGIC MARKERS 29' ORMATION 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". (From 1 L-25) None Top Kuparuk C 8840' 5977 Top Kuparuk B 8873' 5994' Top Kuparuk B 9135' 5993' Top Kuparuk B 9404' 5987' Top Kuparuk B 10084' 6006' Top Kuparuk C4 10280' 5992' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foreg ing is true and correct to the best of my knowledge. ~ (~ 7~Q~p Signed Terrie Hubble Title Technical Assistant Date ~ Kuparuk 1 L-25AL1-02 205-178 Prepared By Name/Number Tenie Hubble, 564-4628 Well Number Permit No. / A royal No. Dolling Engineer: Sean McLaughlin, 564-4387 INSTRUCTIONS GeNeaA~: 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. lreM 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 30 Operations Summary .Report Legal Well Name: 1 L-25 Common Well Name: 1L-25 Spud Date: 11/25/2005 Event Name: REENTER+COMPLETE Start: 11!2712005 End: 12/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task .Code NPT Phase Description of Operations 11/27!2005 07:30 - 10:00 2.50 MOB P PRE Safety mtg re: move off well Jack up rig. DSO disconnect ESD from well on DS. Move rig off well. Clean up cellar area/post pad inspection w/ DSO. Fin load trailers with misc items. Safety mtg re: move rig to 1 L-25. Move rig to other side of Pad 10:00 - 16:00 6.00 MOB P PRE Enter CPF3 Spine Rd and head to 1 L-25 16:00 - 17:00 1.00 MOB P PRE Arrive on 1 L Pad. Move over well. Accept rig at 1700hrs. 17:00 - 23:00 6.00 BOPSU P PRE NU BOPE. grease all manifold, stack and tree valves. Lift and secure 2' coil reel #15178 w/ 15100'. Prep to test BOP's .Witnessing wavied by Chuck Sheive 23:00 -00:00 1.00 BOPSU P PRE Pressure test 80PE 250psi~ow 3500psi/high 5min ea. 11/28/2005 00:00 - 02:45 2.75 BOPSU P PRE Pressure test ROPE. 250 psi/low 3500psi/high SmiNea 02:45 - 03:00 0.25 RIGU P PRE PJSM review plan forward RU injector and possible hazards. 03:00 - 05:00 2.00 RIGU P PRE Hang injector and install pack-off and gooseneck assemblies. Install internal coil grapple. Stab coil to injector. Prep end of coil for Slack Management. 05:00 - 07:00 2.00 RIGU P PRE Fill coil with fluid -slowly in case of ice plugs. Then pump Slack Management. AES build berm for tiger tank 07:00 - 11:50 4.83 RIGU P PRE Cut off 90' CT. Install CTC. PT 40k, 4k. Meg line 44 ohms. Install BHI head and test. AES set tiger tank and fin berm. Run hardline and PT. Work w/ instrument tech to RU TRSSSV panel. This one is too big. Purchase one from Kuparuk whse 11:50 - 13:30 1.67 RIGU P PRE Mount permanent SSSV panel in temporary position on floor. Plumb lines and fill w/ aviation hyd fluid. Install tree cap Build BHI MWD for 2" CT 13:30 - 14:20 0.83 RIGU P PRE Check well for pressure and had 60 psi. Bleed off diesel/sli gas to tiger tank and monitor Conduct PreSpud meeting 14:20 - 15:05 0.75 STWHIP P WEXIT MU milling BHA (2.74' D331 mill, 1.75 deg WFT motor) PVT 356 15:05 - 16:50 1.75 STWHIP P WEXIT RIH w/ BHA #1 circ (used 8.7# mud from last well) thru mil " 0.5/1340 taking diesel returns to tiger tank. Open TRSSV w/ positive press. Continue RIH w/ open choke to tag at 8720' 16:50 - 17:45 0.92 STWHIP P WEXIT PUH to 8500'. Log GR tie-in down at 300'/hr while circ 1.0/2130 17:45 -00:00 6.25 STWHIP P WEXIT Tag at 8719', corr -6'. Begin drilling cement w/ LS TF 1.53/1.4713650 ECD 1.84 2k wob 12-18'/hr. 11/29/2005 00:00 - 02:25 2.42 STWHIP P WEXIT Continue drilling cement pilothole f/ 8815' to 8832' at 180TF 1.53/1.53/3550 3-400mw 2k wob 10-15'/hr 02:25 -03:00 0.58 STWHIP P WEXIT Orient TF to highside and drill cement ramp to intersect 7' csg. Tagged csg seen increase motor work and lefthand walk of TF. 03:00 -04:35 1.58 STWHIP P WEXIT TOH f/ window mill. 04:35 -04:45 0.17 STWHIP P WEXIT PJSM review plan forward for BHA changes. 04:45 -06:00 1.25 STWHIP P WEXIT UD 1.75 deg motor and PU 2.5 deg motor with 1 Step Window Mill 06:00 - 07:40 1.67 STWHIP P WEXIT RIH w/ BHA #2 circ thru EDC 0.6/1760. Set down several times at 1807' which is the TRSSSV. Orient to get by. RIH to 8760' 07:40 - 07:55 0.25 STWHIP P WEXIT Log GR tie-in down to marker at 8758', corr -5' 07:55 - 08:10 0.25 STWHIP P WEXIT RIH circ thru EDC 0.5/1800 and tag at 8840'. PUH 10', 26.1k Close EDC PVT 245 Printed: 1/3/2006 71:13:50 AM BP EXPLORATION Page 2 of 30 Operations Summary Report Legal Well Name: 1 L-25 Common Well Name: 1L-25 Spud Date: 11/25/2005 Event Name: REENTER+COMPLETE Start: 11/27/2005 End: 12/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date From.- To Hours Task ' Code NPT Phase. Description of Operations 11/29/2005 08:10 - 08:15 0.08 STWHIP P WEXIT Start motor 1.5/3700 and ream slowly to casing at 108. First MW at 8837.6', PUH to take up slack and park at 8836.6' PVT 246 08:15 - 11:25 3.17 STWHIP P WEXIT Begin time milling schedule at 8836.6' 1.53/3790/58 w/ 14.7k surface wt w/ 11.96 ECD 11:25 - 14:00 2.58 STWHIP P WEXIT Back to where we started at 8837.6' 1.53/3740/58 w/ 6.2k surface wt w/ 0.5k wob w/ 11.91 ECD. Getting good drilloffs on each 0.1' drilled. At 8839.0', 4k str wt w/ 3.2k wob 14:00 - 16:45 2.75 STWHIP P WEXIT Mill from 8839' 1.53/1.50/3660 250mw 3-4k wob .1'/5rnin at 8840.3' seeing good drill-off's 16:45 - 17:00 0.25 STWHIP P WEXIT Continue milling f18840.6' 2-3k wob 3-400psi mw. good drill-off's. 17:00 - 18:05 1.08 STWHIP P WEXIT Exited window. Drill rathole. 18:05 - 19:40 1.58 STWHIP P WEXIT POH to pick up crayola mill to dress window. 19:40 - 20:05 0.42 STWHIP P WEXIT Tag up at surface. Trap 950 psi below SSSV. Open choke and whitey valve on lubricator. No flow observed. Hold PJSM to discuss BHA swap. Recheck for flow. Confirmed that there is no flow observed. 20:05 - 21:10 1.08 STWHIP P ( WEXIT Lay down motor and mill from BHA #2. Mill gauged 2.74" Go, and 2.73" No-go. Mill had a good indication of center well. All looks as expected. Pick up WF crayola mill and 1.75 deg motor to dress window. 21:10 - 22:45 1.58 STWHIP P WEXIT RIH with BHA #3 to dress window. Trapped 950 psi on well, opened SSSV. Found 940 psi below SSSV, did not appear to be much bleed off during BHA swap. 22:45 - 23:00 0.25 STWHIP P WEXIT Log tie in pass over GR character at 8767'. Make +6' correction. 23:00 -00:00 1.00 STWHIP P WEXIT Orient to high side. Try to run down thru window with pumps on. Hung up at bottom of window at 8841'. Kick on pumps, ream down at bottom of window to clean up, holding TF at high side. 11/30/2005 00:00 - 02:00 2.00 STWHIP P WEXIT At 8841.5'. Continuing to ream down thru window with TF at 0 deg. Reaming down as per David Heam. Trying to clean up lip at bottom of the window. 02:00 -04:00 2.00 STWHIP P WEXIT Finally made it thru the spot at 8841' where we had problems. Run to bottom. Make backreaming passes at 0 deg, 45 and 90 degrees left and right of high side. 04:00 -04:30 0.50 STWHIP P WEXIT Set down at the bottom of the window. Continue to work window. 04:30 - 05:00 0.50 STWHIP P WEXIT Try to dry drift window, and set down at 8842', just past bottom of the window. Kick pumps on and able to work down thru it. Continue to ream bottom of window with tool face at high side as per David Heam. 05:00 -06:45 1.75 STW HI P P WEXIT TOH 06:45 -10:30 3.75 STWHIP N WEXIT Discuss with town group the options for salvaging this window a drilling new window. We believe the cement ramp has been milled out slightly below the casing window resulting in a small 'lip" at the bottom of the window. Of all the different options we finalized trying a new window mill with <1.75 deg motor. Small problem. No new mill on Slope. Other options discussed: Rerun 1.75 deg motor and new crayola mill. Dress window again best we can and continue with well. This might work for Printed: 1/3/2006 11:13:50 AM BP EXPLORATION Page 3 of 30 Operations Summary Report Legal Well Name: 1 L-25 Common Well Name: 1L-25 Spud Date: 11/25/2005 Event Name: REENTER+COMPLETE Start: 11!27!2005 End: 12/28!2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/30/2005 06:45 - 10:30 3.75 STWHIP N WEXIT awhile with higher bend motors but problems could arise with lateral motors and liners making it through the window. ` PU 2.5 motor and crayola mill. Redress window. No way to effectively mill on steel lip without hazardous effects on motors output shaft. ` With D331 drill past this cement ramp and make another ramp below both with or without cementing first. ` Setting LSK whipstock at bottom of pilothole and making a lowside exit. This would be a last resort option. 10:30 - 13:30 3.00 STWHIP N WEXIT Wait on 1 deg WF motor. 13:30 - 14:15 0.75 STWHIP N WEXIT MU BHA #3 with 1 deg motor and RR One Step Window Mill 14:15 - 15:45 1.50 STWHIP N WEXIT RIH with EDC open. Tagged SSSV PU then went through okay. 15:45 - 16:05 0.33 STWHIP N WEXIT Log tie-in starting at 8722' correction + 6.5' Close EOC 16:05 - 18:00 1.92 STWHIP N WEXIT RIH stow to 8842.5' seen small wt bump. PU to 8832 20.3k up wt RIH slow to 8839' wo pump then .5' increments looking for wob increase. PU to 8800' bring on pump 1.531150/4000 holding 200 on choke. RIH slow to 8836.6' Time mill .1'/5min from 8838.6' 18:00 - 19:00 1.00 STWHIP N DPRB WEXIT We appear to be on the lip at the bottom of the window. Continue time milling to see if we can clean up the lip. 8841.75'. WOB=600 lbs. 1.57 bpm, 4130 psi. PVT=244 bbls. 19:00 - 19:40 0.67 STWHIP N DPRB WEXIT 8842.15'. WOB=7801bs. 1.56 bpm, 4102 psi. PVT=248 bbls. 19:40 - 21:10 1.50 STWHIP N DPRB WEXIT 8842.6'. WOB=690 lbs. We seem to have constant WOB, but no metal coming back on the ditch magnets. This could indicate that we are not milling metal, but are skinning the inside of the fip. Discuss with David Heam. Call town and discuss with town engineer. POOH to pick up 1.75 deg motor with same milt in the hopes that we can get the mitt up a little higher and hook the lip. 21:10 - 21:25 0.25 STWHIP N DPRB WEXIT PJSM re: BHA swap. Flow check well during Safety meeting. No flow observed. 21:25 - 23:15 1.83 STWHIP N DPRB WEXIT Laydown 1 deg motor. BHA #4. Pickup 1.75 deg motor and same used 1 step window mill. BHA #5. Scribe same. 23:15 -00:00 0.75 STWHIP N DPRB WEXIT RIH with BHA #5. Hanging up at tubing collars while RIH. Having to roll the pumps to get by each collar. 12/1/2005 00:00 - 01:15 1.25 STWHIP N DPRB WEXIT Continue RIH. Having to roll the pumps at every tubing collar to get in the hole. 01:15 - 01:35 0.33 STWHIP N DPRB WEXIT Log tie in pass at 8750'. Make a +8' correction. 01:35 -06:45 5.17 STWHIP N DPRB WEXIT RIH dry at 8844.5'. PU, kick pumps on to 1.54 bpm, 3904 psi free spin. RBIH, begin milling from 8839.0' at 0.75 fph. Not seeing much motor work or WOB on this run. 06:45 -08:45 2.00 STWHIP N WEXIT At 8843.95' start seeing 100-200psi motorwork and 1.5k wob. Continue at .75fph Milled to 8844.5'. Opened EDC and CBU 50% metal 3096 scale 18% cmt 2°/a sd 08:45 -09:30 0.75 STWHIP N WEXIT Log tie-in no correction. Discussed with town plan forward. Will drill another 5' trying to confirm if we're in or out of the 7" casing. 09:30 - 10:15 0.75 STWHIP N WEXIT Start the 5' of milling/drilling?. From 8844.5' setdown to apply 5-6k wob 1.52/1.46/3850 400-600psi motorwork. Establish drilling rate. Work up from 6'/hr to 20'/hr. Drill to 8851.5' PU of Printed: 1/3/2006 11:13:50 AM BP EXPLORATION Page 4 of 30 Operations Summary .Report Legal Well Name: 1 L-25 Common Well Name: 1L-25 Spud Date: 11/25/2005 Event Name: REENTER+COMPLETE Start: 11/27/2005 End: 12/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/1/2005 09:30 - 10:15 0.75 STWHIP N WEXIT btm 20k to 8842'. RIH lightly tag 8851'. 10:15 - 11:25 1.17 STWHIP N WEXIT Circulate samples. Grab several samples prior to BU. Ist was 90% cmt. Each succeeding sample showed an increase in sand content. Sample f/ 8851 showed 25% sd. Other samples taken after BU showed a max of 30% sd. From the sample results we believe we must be outside the casing and into the old rathole. May have reamed the rathole. If we were inside the casing we would not expect to see any sand. 11:25-12:50 1.42 STWHIP N WEXIT TOH. 12:50 - 14:40 1.83 STWHIP P WEXIT LD 1-Step mill and WE motor. PU BHI 2.8deg motor and build section BHA. 14:40 - 16:20 1.67 DRILL P PROD1 RIH w/ BHA #6 following pressure schedule with open EDC and highside TF. BHA going smooth throughout TIH slowing down at mandrel depths. 16:20 - 16:40 0.33 DRILL P PROD1 Log tie-in starting at 8740'. +6' correction. 16:40 - 17:05 0.42 DRILL P PROD1 RIH highside TF with open EDC. Setdown ai 8841.5' PU 19k RIH again slow taking wt at 8841.5' PU orient 40L RIH slipped on through window to 8844.9' PU above window and orient back to highside. Orienter is at it's "backstop' unable to orient any farther to the right. Need to come up and orient around 360deg. PU slowly and come around to left with TF at HS again. RIH highside went to 8844 before taking weight. Repeat again. PU orient 15L RIH went through okay. Setting at 8845' close EDC 17:05 - 18:00 0.92 DRILL P PROD1 Bring on pump 1.56/1.50/3600 200whp 12.5ppg ECD. RIH .5'/min very little motonnrork 18:00 - 20:15 2.25 DRILL P PROD1 Drill build section as per DD. 1.58!1.50/3940 psi. PVT=258 bbls. Start mud swap to new mud. IAP=60 psi, OAP=280 psi. ECD=12.46 ppg. TF=highside. 20:15 -00:00 3.75 DRILL P PROD1 Drilled to 8873'. Stalled, made pickup. Couldn't get back down to bottom. Hanging up at 8853' each time. Looks like we are setting on a ledge. PU, set down multiple times. Tried pumps on and off. Finally kicked pumps on and drilled back down thru it. May be drilling new hole. 12/2/2005 00:00 -00:30 0.50 DRILL P PROD1 Continue drilling build section. 00:30 -00:50 0.33 DRILL P PROD1 Landed well at 8946'. Pickup thru window clean. RIH to confirm we can get thru window again. TF at 15R. Set down at 8841', bottom of window. PU, try to orient to 30L. Can't get orienter to hold 30L. Finally got it there. RIH thru the window ok. RIH, and set down at 8873'. Pickup and set down several times. Hard bottom each time at 8873'. DD checks INC. The INC now is 6 degrees bwer than the INC when we drilled the build section. Looks Nke we have 2 wellbores. One that is lower in INC with a TD at 8873'. One tl~at has 6 degrees higher INC, and landed at 8937'. There appear to have been 2 pilot holes from the various mi-ling and cleanout runs done previously. One pilot hole was drilled with the original 2.5 deg motor, and one pilot hole drilled with the 1.75 degree motor on the last cleanout run. The deepest leg is the one from the 2.5 degree pilot hole. The shallowest is from the 1.75 degree pilot hole. Printed: 1/3/2006 11:13:50 AM BP EXPLORATION Page 5 of 30 Operations Summary Reporf Legal Well Name: 1 L-25 Common Well Name: 1L-25 Spud Date: 11/25!2005 Event Name: REENTER+COMPLETE Start: 11/27/2005 End: 12/28/2005 Gontracior Name: NORDIC CALISTA Rig flejease: 12/2$/2005 Rig Name: NORDIC 2 Rig Number: .Date From - To Hours Task Code NPT Phase Description of Operations 12/2/2005 00:50 - 01:05 0.25 DRILL N DPRB PRODi Call town and discuss situation. The only real recourse is to try to preserve the hole with the lower INC. This is the hole the liner will try to find. We will treat the intersection of the 2 holes as an open hole sidetrack and try to ream high side and 45 degres left and right with the current BHA, to naw off the lip so that we stay in the leg with the lower INC. 01:05 - 02:10 1.08 DRILL N DPRB PROD1 PU to the window, and run back to bottom with TF at high side. Tagged up at 8873'. Backream up to 8845', as close as we dare to the window, with TF at high side. Ran back to bottom tagged up at 8873'. Ream up at 45 R. Ran to bottom, tagged up at 8873'. Ream up at 45 L. Reaming passes made from 8873'-8845'. RIH with TF at 45R to ensure we are going to stay in the proper wellbore. Tagged up at 8873. PU to 8845', orient to 45L, and RIH. Tagged up ai 8873'. 02:10 - 03:00 0.83 DRILL N DPRB PROD1 Pick up above window to let OD and MWD hand sort out paperwork and data files. Open EDC and circulate while they get things sorted out. 03:00 - 05:25 2.42 DRILL N DPRB PROD1 RIH thru the window slick at 30L. Tagged up at 8873', and stalled. Resume drilling. Free spin 3600 psi at 1.55 bpm. 05:25 - 07:00 1.58 DRILL P PROD1 Well is landed again. This time at 8935'. POOH to pick up lateral section BHA. Close SSSV trapping 950psi. Tagged up at surtace. 07:00 - 07:15 0.25 DRILL P PROD1 Hold PJSM. Review plan fonnrard. Same time bleed down well and observe. 07:15 - 10:30 3.25 DRILL N PRODi The SSSV seems to be leaking. Cycle the valve several times with no change. RU to pressure undeploy BHA. PJSM and review the deployment procedure. After tagging up ran in hole the require 3.8' depth to close the combi's on BHA. The 2" rams were inadverently shut instead. Maniflod pressure was at the 1500psi setting. Open the 2" and closed the 2-3/8" combi's. Continued with un-deploymnnt schedule and setback injector. PU lubricator. Unable to lower the no-go plate inside lubricator due to dried mud caking the the inner walls. Breakdown lubircator and wash. Finished undeploying BHA. 10:30 - 10:45 0.25 DRILL N PROD1 Held PJSM with HOWCO slickliners and rig crews for RU and the plan #onnrard to'brush" the SSSV 10:45 - 12:00 1.25 CASE N PROD1 RU slickline. Mean while inspect BHA. 2' rams closed on the EDC making it unuseable. We have 1 back-up tool. Need to order another from ANC. Opened BOP stack to inspect 2" rams. No damage to sealing surfaces. Could see where guide had engage EDC tools but no damage done. Install cap on our lubricator and full body tested stack to 250/3500 psi 5minlea Good test. Continue RU slickliners 12:00 - 16:30 4.50 CASE N PROD1 RIH with brush on slickline. Stopped at 1300'. Trip for more weight. RIH brush SSSV at 1810'. (unable to wash at same time). TOH. Cycle SSSV and test by bleeding down well. !t closes but we're not seeing the normal pressure hesitation when the flow tube shifts to the down position. All indications show it's stuck in the up positon allowing the flapper to be in Printed: 1/3/2006 11:13:50 AM BP EXPLORATION Page s of 30 Operations Summary Report Legal Well Name: 1L-25 Common Well Name: 1L-25 Spud Date: 11/25/2005 Event Name: REENTER+COMPLETE Start: 11/27/2005 End: 12/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date From - To' Hours Task Code NPT Phase Description of Operations 12/2/2005 12:00 - 16:30 4.50 CASE N PROD1 the open (flow thru) position. Left in this position it would act like a `trap door" with any tools run through the SSSV, allowing passage but most likely hanging up when brought back through. Plan forward is to PU a dimpling tool without punches snd set on top of the flow tube, pressure up the welibore and shift the sleeve to the down position. Then with coil R1H with a sidejet nozzle and wash the flow tube area. Stabilized WHP 527psi 16:30 - 18:00 1.50 CASE N PROD1 RIH with gauge ring, Called AOGCC and explained to Lou Grimaldi the situation with closing the 2" upper pipe rams on 2-3/8' toots. Told him we will test the 2` rams against test joint prior to drilling ahead. 18:00 - 18:45 0.75 CASE N DPRB PROD1 Shut down for crew change. Then hold PJSM with full rig crew and HES slickline crew. 18:45 - 20:00 1.25 CASE N DPRB PROD1 Run #4 Lockout tool to attempt to shift sleeve down. Land on top of sleeve, pressure up wetlbore with rig pumps to 1400 psi. Didn't see any indication that the sleeve shifted on the surface panel. Pull lockout tool to surface and inspect. 20:00 - 22:30 2.50 CASE N DPRB PROD1 Sleeve failed to shift down. Lockout tool functioned properly. The SSSV sleeve may be stuck in the down (Open) position. Dress tattle fate tool to see if flapper can be shut. This wiN tell us if the sleeve is up or down. RIH, bleed pressure off of SSSV, and POOH. Recovered tattletale. No indication of contact with the flapper. The sleeve appears stuck in the open position. 22:30 - 00:00 1.50 CASE N DPRB PROD1 Repeat run with longer tattletale and attempt to bleed WHP to zero to force flapper to close. This will confirm theory that SSSV sleeve is in the down or open position. Also, while making this run, call for SL friction tool to shift sleeve into the up or shut position. ' Able to cycle sleeve up and down, and confirm from the tattle tale that the flapper is closing. However it took 5000 psi on control panel as opposed to 3500 psi normal pressure to do so. There may be junk in the SSSV. Send SL hand to Y pad tool house to pick up a slick 2' Houle to make cleanout run with coil. 12/3/2005 00:00 - 02:00 2.00 CASE N DPRB PROD1 Wait for SL hand to return with 2' JSN. 02:00 -04:15 2.25 CASE N DPRB PROD1 Rig up 2' JSN, 2 stingers. PT lubricator to 1000 ps+. Open to well. Start pumping 20 bbl high vis sweep. RIH. Hold PJSM with SL hand to discuss plan forward for cleaning up the SSSV. Position Houle at 1780'. SSSV at 1810'. Run down thru SSSV jetting at 2.2 bpm with high vis sweep, Jet up and down accross SSSV for 5 minutes. This should clean up the top of the sleeve. Pull up above SSSV. Bleed off hydraulic control pressure. Run down thru closed SSSV jetting at 2.2 bpm. This should clean off seal area, and area below sleeve. Stop below SSSV, pump open. Opened at 4200 psi, slightly lower pressure than before. (Thats Good!) Pick up to 1780'. Shut SSSV. Run down pumping at 2.2 bpm thru shut SSSV. Open Printed: 1/3/2006 71:13:50 AM "' BP EXPLORATION Page 7 of 30 Operations Summary Report. Legal Well Name: 1L-25 Common Well Name: 1L-25 Spud Date: 11/25/2005 Event Name: REENTER+COMPLETE Start: 11/27/2005 End: 12/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date From - To, Hours Task Code NPT Phase Description of Operations 12/3/2005 02:00 -04:15 2.25 CASE N DPRB PROD1 SSSV. Pick up. Wash down from 1780'. Open SSSV again. Took 3800 psi to open this time. Seem to be making some progress. Make 2 more down jetting passes thru closed SSSV. Opened with 3600 psi. Make an additional down pass. Opened with 3600 psi again. Pick up above SSSV. Trap 700 psi on well and shut SSSV. Bleed down well for flow check. Well flowed a stream the size of a quarter. The SSSV will not hold. Note -Got lots of what appears to be pipe scale back with the initial high vis sweep. Geo inspected sample and reports that 8 is mostly old pipe scale and sand with only a very small trace of fine new metal from the window milling. 04:15 -04:35 0.33 CASE N DPRB PROD1 Puit OOH with coil pumping at full rate. There is 7 last thing to try. We plan to rig SL back up and run a friction tool. We can get a bite on the SSSV sleeve, and jar up to ensure that it is in the full open position. 04:35 - 05:45 1.17. CASE N DPRB PROD1 Stand back injector. Pick up slickline lubricator. Make up friction tool, 05:45 - 08:00 2.25 CASE N DPRB PROD1 RIH with friction tool to attempt to shift sleeve into the full up position. Engage the sleeve pull and spang jar up to assist the shift to full up position. Close the sleeve and see good pressure hesitation. Pull 500# tension on the sleeve and hyd. shift sleeve up, notice 50# decrease in tension -this is good. Flow test well -dead. SSSV is holding. There's not much more we can do with slickline. Time will tell if SSSV continues to work properly, Possibly wash the SSSV with opened EDC on TOH prior to shutting might help in the future. RD slickliners. 08:00 - 08:30 0.50 BOPSU N HMAN PROD1 RU to test upper 2" comt~i's. Test 250psi low/3500psi high 5/min ea. Held good. Installed lubricator cap and closed choke. Opened MV/SV well still dead. 08:30 - 08:50 0.33 DRILL P PROD1 PJSM review plan forward and staying focused with the job at hand. Plan to PU lateral BHA wo pressure deploying. Also made SOP to take time washing SSSV on TOH prior to shutting valve. Discussed actions we (TP,TL,WSL) are taking to help mimimize another accidental closure of the wrong set of 80P rams. Plan to make overlay temptetes writh better displays of each ram. These will be easily interchangable for other stack configruations that we use. We want thesetn place within 1-2 days. Presently we have the lower 2" pipe ram actuator buttons in the upper iefthand comer of the panel. They need to be re-wired to the lowest 'spare' buttons on tfte panel which a! present are not being used. (1 hr job) This will require an MOC from Nordic town group. Hopefully there's no pushback on this. It needs to be done RSAP. Also reminded everyone that they have the authority to stop the job anytime they see fit for wfiatever reason. 08:50 - 10:10 1.33 DRILL P PRODi PU 8HA #8 10:10 - 11:50 1.67 DRILL P PROD1 T1H open SSSV no problems 11:50 - 12:10 0.33 DRILL P PROD1 Log tie-in +5' correction. Printed: 7/3/2006 it:13:50AM BP EXPLORATION Page 8 of 30 Operations Summary Report Legal Well Name: 1 L-25 Common Well Name: 1L-25 Spud Date: 11/25/2005 Event Name: REENTER+COMPLETE Start: 11!27/2005 End: 12/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date From - To -Hours Task Code- NPT Phase Description of Operations 12/3/2005 12:10 - 12:25 0.25 DRILL P PROD1 Close EDC RIH no pump. Orient to 20L. 6k through piiothhole. touch ramp at 8832 still 6K at window 8842 no problem. Looking at NB inc 8845'-54,86 8848'-56.25 8853'-55.59 seem to be in right hole no problems 5-6k. Bring on pump 1.55/1.50/3800 8.8!7.7 ECD =12.86ppg little motorwork to get to bottom. Tagged at 8838' 12:25 - 18:00 5.58 DRILL P PROD1 Directionally drill ahead f/ 8838' 200-300 motorwork, 1k wob 85'/hr. Good drilling to 8845' then ran into Siderite. <i2'/hr 3-4k wob mud wt out has evened out. Returns from bottom had some oil content. 18:00 - 20:15 2.25 DRILL P PROD1 Drilling ahead with lateral section of well. Currently in 8 shale. Drilling at 1.56/1.56/3800 psi. PVT=335 bbls and has been constant all day. IAP=200 psi, 0AP-470 psi. DHWOB=4600 lbs. String wt = -5001bs. ROP=i8 fph. 20:15 - 20:30 0.25 DRILL P PROD1 Wiper trip to window. Clean PU off bottom. Free spin pressure is 3490 psi at 1.54 bpm. Clean to window, and back in hole. 20:30 - 00:00 3.50 DRILL P PROD1 Resume drilling lateral section. Now in `C' Sand. Drilling ahead at 1.57/1.55/3750 psi. WOB=2900 lbs. STring wt=5000 lbs. PVT=337 bbls. ROP=65 fph. 12/4/2005 00:00 - 01:10 1.17 DRILL P PROD1 Continue drilling lateral section from 9200'. 01:10 - 01:40 0.50 DRILL P PROD? Wiper trip to window. Clean PU off bottom and clean to window. One wt bobble when running back in hole at 8920', fell thru it easily. 01:40 - 07:15 5.58 DRILL P PROD1 Resume drilling lateral section. 1.5611.5114050 psi. PVT=334 bbts. IAP=364 psi, OAP=552 psi. WHP=O, BHP=3690 psi. ECD=12.13 ppg. DHWOB=3300 lbs. String wt = -600 lbs. 07:15 - 07:40 0.42 DRILL P PROD1 Wiper to 8740'. No problems up through window. 07:40 - 08:00 0.33 DRILL P PROD1 Log tie-in +2' correction 08:00 - 08:30 0.50 DRILL P PROD1 Wiper trip to bottom. Enter window at 20L no problems and clean at 8920' 08:30 -14:45 6.25 DRILL P PRODt Continue drilling ahead f/ 9385' 1.5211.50/3800 2-300 motonnrork 32-3k wob 15-30'/hr ECD 12.18ppg Owhp Cut pump to 1.42/1.36/3500 2-300 MW 8.84/8.80 12.17ECD 14:45 - 15:30 0.75 DRILL P PRODt Wiper trip to 8850' No problems 15:30 - 18:00 2.50 DRILL P PRODt Continue drilling ahead f/ 9536 1.45/1.45!3600 EDC 12.19 EDC 200-400mw 2-3k wob 18:00 - 21:10 3.17 DRILL P PROD1 Continue drilling lateral section. 1.45/1.3613750 psi. PVT=380 bbls. IAP=470 psi, OAP=fi00 psi. String wt = 1200 lbs. DHWOB=2000 lbs. ROP=25 fph. 8HP=3690 psi. ECD=12.13 ppg. INC=90 deg. Plan to drill ahead holding 90 deg to cross cut down dipping formation. 21:10 - 23:00 1.83 DRILL P PRODt Begin swap to new mud. New mud contains 49'° lubetex, 1.5% EMI-776 tube, and 14 ppb Kla-gard. 23:00 -00:00 1.00 DRILL P PROD1 Wiper trip to wirxiow. Clean PU off bottom at 20 klbs. Very clean up in open hole, 1 small weight bobble at 8894'. Mostly clean ~ the way back in the hole, 1 small weight bobble at 9058'. Nothing serious. 12!5/2005 00:00 -00:10 0.17 DRILL P PRODi Continue back to bottom. 00:10 -06:00 5.83 DRILL P PRODi Resume drilling. New mud in the hole. Free spin 3720 psi at 1.44 bpm. Drilling at 1.4411.3613875 psi. PVT~11 bbls. tAP=433 psi, OAP=564 psi. ECD=11.93 ppg. BHP=3625 psi. String wt= -5000 lbs. DHWOB=3360 psi. Now holding 88 deg Printed: (/3/2006 17:13:50 AM _~ BP EXPLORATION Page 9 of 30 Operations Summary Report Legal Well Name: 1 L-25 Common Well Name: 1L-25 Spud Date: 11/25/2005 Event Name: REENTER+COMPLETE Start: 1 i/27/2005 End: 12/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/5/2005 00:10 -06:00 5.83 DRILL P PROD1 to follow formation. 06:00 -08:25 2.42 DRILL P PROD1 TOH for PR. Also BHI is not comfortable with survey data received since drilling at 9604'. Check surveys on the way out and Made several wash passes across SSSV with the opened EDC then closed SSSV. Pulled to 200'. Bleed down wall. Dead, SSSV holding good. Looking back on 1 D-36L2 we tripped far slow ROP. Had identical bit in the hole as we have now. Came out 2-2-I Ran another new HCC bi-center and ROP > 100% Also time for weakly BOP function test. 08:25 - 08:40 0.25 DRILL P PROD1 PJSM: review BHA handling and precautions we'll take while function testing BOP's. 08:40 - 10:45 2.08 DRILL P PRODi Tag up. Setback injector. LD BHA. Install lubricator cap and shut-in MV & SV. Bit condition: 4 out of 6 jets were plugged with sliUsh/sa all 4 on the nose, cutters look okay. Wilt pu Hycalog 3 blade that might be less prone to packing off. Function tested all BOP componets while working on BHA PU BHA #9 changed out DPS sub checked torque on other breaks. 10:45 - 12:15 1.50 DRILL P PRODi TIH following pressure schedule 12:15 - 12:30 0.25 DRILL P PROD1 Log tie-in +5' 12:30 - 13:20 0.83 DRILL P PROD1 Close EDC RIH past window at 15L - no problems bring on pump to 1.5(3600 Seeing discrepancy in surveys all the way to TD. Surveys +/- 20deg off on azimuth. 13:20 - 15:20 2.00 DRILL N PROD1 Re-survey well f/ TD to 8950'. The new DPS tool is giving reliable survey data (acceptable range 80.5 - 81.4 dip). The "magnetic dip" data given while drilling lastnight starting 9604' (82-83) was out of the acceptable spec range but was thought to be induced by glauconite within the C sand. Tums out the DPS toot was progessively giving false data (but well within " spec) starting around 8950'. Replotting the good surveys has us on a 270deg azimuth path versus the planned 215 deg path and 250' to the north of the polygon edge. Possible cause maybe the DPS was magnetized at some point +/- 8950'. 15:20 - 18:00 2.67 DRILL N PROD1 Slowly PUH with open EDC. Discuss plan forward with town. 18:00 - 18:30 0.50 DRILL P PROD1 Plan forward is to drill back into the polygon and resume drilling to TD this latteral. Tag TD. Free spin 3590 psi at 1.47 bpm. DriNing ahead at 1.4711.4513700 psi. ROP 50-55 fph. A considerable improvement with this bit over the last one. 18:30 - 19:10 0.67 DRILL P PROD1 Drilling at 9825', plugged BHA. pressure went to 4400 psi, and held when pumps were shut down. Pick up off bottom clean at 19 k1bs. Annular pressure bled down, Bore (Internal 8HA) pressure held. Confirms a plugged BHA. Cycle pumps. Able to get returns again. Free spin now 4200 psi at 1.45 bpm. Probably have a plugged bit, possibly with stator rubber. Try to drill. Free spin came down to 3900 psi at 1.45 bpm. Unable to drill, and motor appears weak. Possibly shucked a stator, and plugged off the bit. 19:10 - 21:20 2.17 DRILL N DFAL PROD1 POOH. Watching bottoms up sample. Got a coffee cup of stator rubber back. Confirms theory that we shucked a stator Printed: 1/3/2006 11:13:50 AM BP EXPLORATION Page 10 of 30 - Operations Summary Report Legal Well Name: 1 L-25 Common Well Name: 1L-25 Spud Date: 11/25/2005 Event Name: REENTER+COMPLETE Start: 11/27/2005 End: 12128/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task 'Code NPT Phase Description of Operations 12/5/2005 19:10 - 21:20 2.17 DRILL N DFAL PROD1 rubber. POOH to change out motors and clean bit. Pulled clean in open hole. Open EDC below window. Pull out of hole pumping at full rate thru EDC. Wash SSSV while POH. 21:20 - 21:45 0.42 DRILL N DFAL PROD1 PJSM to discuss BHA swap. Emphasis placed on doing a good flow check to ensure SSSV is holding. Discuss proceedure for swapping BHA. Hazards and mitigations discussed. 21:45 -22:00 0.25 DRILL N DFAL PROD1 Tag up at surface. No flow check indicates SSSV is holding. 22:00 - 23:00 1.00 DRILL N DFAL PROD1 Lay down BHA ff9. Motor doesn't rotate properly with pipe wrenches. Found rubber in bit jets. Bit recovered graded 0,0. Make up new motor, same Hycalog DS100 bit. Pick up BHA #10 with motor set at 1.0 deg. Scribe motor and make up injector. 23:00 -00:00 1.00 DRILL N DFAL PROD1 Shallow hole test MWD, passed ok. Open EDC RIH pumping at full rate. Open SSSV, and continue RIH. 12/6/2005 00:00 - 00:45 0.75 DRILL N DFAL PROD1 Continue RIH. 00:45 - 01:00 0.25 DRILL N DFAL PRODi Log tie in pass above window, correction was +5'. 01:00 - 01:30 0.50 DRILL N DFAL PROD1 SD pumps, run thru window, bring pumps on and run to TD. No problems running in open hole. 01:30 - 03:50 2.33 DRILL P PROD1 Free spin 3480 psi at 1.45 bpm. Tag bottom, resume drilling lateral section. 1.45/1.4/3600 psi. PVT=418 bbls. IAP=260 psi, OAP=460 psi. DHWOB=1800 lbs. String wt = -1500 lbs. ECD=12.03 ppg. BHP=3670 psi. ROP=45 fph. 03:50 - 05:10 1.33 DRILL N RREP PROD1 Pump #1 has a leaking swab and can not be used. Swap to pump #2, and make wiper trip to the window so repairs can be made. .05:10 - 10:00 4.83 DRILL P PROD1 Resume drilling lateral section. 1.49/1.52/3700 psi. PVT=422 bbls. IAP=390 psi, OAP=530 psi. DHWOB=1800 lbs. String wt = -2300 lbs. ECD=12.2 ppg. BHP=3709 psi. ROP erratic 8-30'/hr good wt transfer 2-4k wob. Made small BHA wiper trip but no help. Into good sand at 9940 4-=50"/hr sustained 1-2k wob + figures on CTW 10:00 - 1 i:30 1.50 DRILL P PROD1 wiper trip to window. 19.2k of bottom 11:30 - 15:30 4.00 DRILL P PROD1 Continue drilling ahead f/ 10050' 1.47/1.50/3550psi PVT=425bb1s IAP=460 psi OAP=576psi WOB 2-4k ROP= 50-60'/hr CTW -32001bs ECD 12.20ppg ann 3721 psi 15:30 - 16:20 0.83 DRILL P PRODi W iper trip to the window. Clean PU off bottom at 19 klbs. Clean in open hole. 16:20 - 16:40 0.33 DRILL P PROD1 Drop pumps to 0, trap pressure on well. Pull thru window slick. Log tie in pass. Make +3.5' correction. Shut down pumps, run back down thru window slick. 16:40 - 17:30 0.83 DRILL P PROD1 Continue back in hole on wiper trip. Smooth in open hole until 10100', had a set down and had to work to bottom. 17:30 - 18:00 0.50 DRILL P PROD1 Resume drilling. 1.48/1.51/3700 psi. DHWOB=1700 tbs. String wt=-2400 lbs. ROP variable from 15-60 fph. ECD=12.3 ppg, BHP=3750 psi. WHP=O psi. PVT~25 bbls. 18:00 - 20:00 2.00 DRILL N RREP PROD1 Pump #1 had a swab go out again. Second time today. Different swab than this mornings failure. Make wiper trip to window to make repairs. 20:00 -00:00 4.00 DRILL N PROD1 Drill ahead from 10234' to 10327'. 12/7/2005 00:00 -03:00 3.00 DRILL P PRODi Drill ahead from 10327'. 3700 psi fs at 1.48 iM1.48 out. DPSI: 50-200 psi. DHWOB: 1.6 k#. WHP/BHP/ECD: 22/3801/12.43 ppg. IAlOA/PVT: 515!569/425 bbls. INClAZMlfF: Printed: 1/3/2006 11:13:50 AM ,t BP EXPLORATION Page 11 of 30 Operations Summary Report Legal Well Name: 1L-25 Common Well Name: 1L-25 Spud Date: 11/25/2005 Event Name: REENTER-rCOMPLETE Start: 11/27/2005 End: 12/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date From - To :Hours Task Code. NPT Phase >Description of Operations 12!7/2005 00:00 -03:00 3.00 DRILL P PROD1 92-94/205-210/75-105R. 03:00 - 06:00 3.00 DRILL P PR001 Wiper trip to wrindow. Hole smooth. 06:00 - 10:50 4.83 DRILL P PROD1 Drilling ahead. 1.5/1.52/3740 psi. DHWOB=800 lbs. String wt = 0 lbs. ROP=40 fph. IAP=580 psi, OAP=593 psi. ECD=12.59 ppg. BHP=3835 psi. WHP=O psi. 10:50 - 13:30 2.67 DRILL P PRODi We've made 93' in the last 5 hours. Average ROP is less than 20 fph. We can't get trucks for a mud swap. AES and Veco are all tied up. Need to try something different. POOH to pick up Agitator and new bit. Note -Mud quality still in fair shape. Grill solids only at 0.6~°, and tubes at maximum. Lubetex at 4%, EMI-776 at 1.5%. ~ Motor work and slight overpulls at 10000' while PUH in open hole. Clean the rest of the way. 13:30 - 13:45 0.25 DRILL P PROD1 Flow check well while holding PJSM. Discuss changes needed to BHA to pick up Agitator tool. Discuss hazards of operation and mitigation. 13:45 - 15:10 1.42 DRILL P PROD1 Check well for flow. No flow observed. Well 100% dead. Stand back injector. Lay down BHA #10. Break off bit and motor. Bit recovered at 2,1. Should have still drilled ok. Pick up Agitator, same motor, new Hycalog bit. BHA already had dart style float in lower DFS. Remove flapper checks from UGC. Make BHA back up. Scribe motor. Pick up Injector. 15:10 - 16:40 1.50 DRILL P PROD1 RIH with BHA #11. 1.0 deg motor with Hycalog DS100 bit with TREX cutters. Surface test of MW D toots passed ok. Open EDC and RIH pumping at full rate. Taking retums to the tiger tank. AES freed up 1 vac truck. Doing mud swap the old fashioned way, taking retums to the tiger tank and shuttling mud with the vac truck. 16:40 - 17:15 0.58 DRILL P PROD1 Log tie in pass down from 8750', pumping at 1.1 bpm. Make =11.5' correction. 17:15 - 18:45 1.50 DRILL P PROD1 SD pumps, run thru the window slick. Kick pumps on, continue " RIH in open 1wte. Set down at 10.020'. Able to work through with pumps off. 18:45 - 00:00 5.25 DRILL P PRODi grill ahead from 10,493'. 12/8/2005 00:00 - 01:45 1.75 DRILL P PROD1 Wiper trip to window. Some over pulls and motor work from 10,020' to 10,040'. Hole otherwise smooth. 01:45 - 05:00 3.25 DRILL P PROD1 Drill ahead from 10640'. 3900 psi fs at 1.55 iN1.52 out. DPSI: 150-200. DHWOB: 1.75 - 2.25k#. WHP/BHP/ECD: 26/3610/11.87 ppg. IA/OA/PVT: 344/325/456 bbls. INC/AZM/TF: 91092/260-270/105-135. ROP variable. 05:00 -06:00 1.00 DRILL P PROD1 Drill ahead from 10735'. 06:00 -06:50 0.83 DRILL P PROD1 Continue drilling ahead. 1.45/1.46/3900 psi. PVT=455 bbls. IAP=430 psi, OAP=390 psi. ROP=30 fph. WOB=1000 lbs. String wt = 2000 ibs. ECD=11.8 ppg. BHP=3570 psi. Have had problems around 10020' on past wipers. This is the belly of the well, and may have cuttings beds building up. Begin pumping high vis sweeps. 10 bbls, 1 time per hour to help clean hole. 06:50 - 08:50 2.00 DRILL P PROD1 Make wiper trip to window. Bump 10 bbl high vis sweep off bottom. 10180' slight packing off. Slowed down to 10 fpm. Printed: 1/3@006 17:73:50 AM BP EXPLORATION Page 12 of'30 Operations Summary Report Legal Well Name: 1 L-25 Common Well Name: 1L-25 Spud Date: 11/25/2005 Event Name: REENTER+COMPLETE Start: 11/27/2005 End: 12/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date ` Frorn'- To Hours Task " Code NPT Phase Description of Operations 12/8/2005 06:50 - 08:50 2.00 DRILL P PRODi 10060' started major packing off and losing returns. Work up thru it without intentional overpulls. Had to spend 10 mintues to get up thru interval. Got returns back, looks like we are chasing a major cuttings bed OOH. 10020' is the belly of the well. Continue pulling slowly. Pump a 2nd high vis sweep. Pulled clean the rest of the way up to the window. Checked first bottoms up sweep, and had major sand in it, not shale sloughings. Confirms hunch that cuttings are laying in the belly around 10020'. 08:50 - 10:00 1.17 DRILL P PROD1 RBIH. Smooth in the hole. Pump another sweep to exit the bit as we get back down to the belly. 10:00 - i 1:20 1.33 DRILL N DPRB PRODi Work interval 9990'-10200'. Pump sweeps, take little bites. Trying to clean up cuttings beds in the belly of the well. Drop rate to 0.8 bpm, run down thru it and pull back up at full rate pumping a sweep. Don't think this is a problem shale. Think we have cuttings laying in here. Finally got it cleaned up. Last trip up thru it was smooth as silk up and down. 11:20 - 11:45 0.42 DRILL P PROD1 Run to bottom. 11:45 - 15:25 3.67 DRILL P PRODi Resume drilling. Free spin 3720 psi at 1.44 bpm. PVT=449 bbls. Drilling at 1.45/1.5/3850 psi. Continue pumping 1, 10 bbl sweep per hour. 15:25 - 17:00 1.58 DRILL P PROD1 Geo indicates we have crossed the fault. Point the tool face up to get 1NC to 99 degrees, and look for the C sand again. 17:00 - 18:30 1.50 DRILL P PROD1 Wiper trip to window. Slight overpull off bottom. Took 26 klbs to PU, 22 klbs off bottom. Pump 10 bbl sweep. Pulled up to 10070', started getting packing off, motor work and overpulls. Put 200 psi on well. Able to pump at full rate (1.4 bpm) and pull through area. Cleaned up completely at +/-10,000'. 18:30 - 19:00 0.50 DRILL P PROD1 Log gr tie in. 19:00 - 20:15 1.25 DRILL P PROD1 Wiper trip back to TD. Held 200 psi WHP from 10,000 to 10,200'. Two minor bobbles at 10,080 an 10090 while circ at .9 bpm. Some minor hole trouble near TD. Backreamed and reduced pump rate to clean up same. WHP og 200 psi also " improved hole conditions. 20:15 - 00:00 3.75 DRILL P PROD1 Drill ahead from 10950'. 4000 psi fs at 1.57 in/out. DPSI: 100-250. DHWOB: 1.5-2.2k#. WHP/BHP/ECD:22/3646/12.01 ppg. IA/OA/PVT: 662/579/444 bbls. INCIAZM/TF: 95-98/265-245/270-350 deg. Weight tmasfer god. ROP averaging 40 fph. Continue to pump 10 bbls hi vis sweeps every hour. 12/9/2005 00:00 -00:30 0.50 DRILL P PROD1 Drill ahead to 11,110'. 00:30 - 02:30 2.00 DRILL P PROD1 Begin wiper trip to window. Hold 200 psi WHP with choke. Some overpulls from 10,175' to 10,020'. Time a 10 bbl hi vis sweep as BHA neared window. 02:30 -03:30 1.00 DRILL P PROD1 Run in hole. Reduced circulation rate and held 300 psi WHP to get past tight spots from 10020' to 10,090'. Also had to work past some tight spots from 10750' to btm. 03:30 - 06:30 3.00 DRILL P PROD1 Drill ahead from 11,110'. 06:30 -09:00 2.50 DRILL P PROD1 Made pickup and it was a little sticky. Make a precautionary wiper. Off bottom pressure is 4170 psi at 1.46 bpm. Clean up to 10180', started seeing return rate drop slightly, and motor work pick up slightly. Slow to 14 fpm, pump sweep exiting the motor ahead of us. Seeing some weight overpulls. Continue Printetl: tJ3/2006 11:13:50 AM BP EXPLORATION Page 13 of 30 Opelrafions Summary Report Legal Well Name: 1 L-25 Common Well Name: 1L-25 Spud Date: 11/25/2005 Event Name: REENTER+COMPLETE Start: 11/27/2005 End: 12/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date Prorn - To Hours Task Code NPT Phase Description of Operations 12/9/2005 06:30 - 09:00 2.50 ORiLL P PROD1 to have good returns. Continue up thru bad area. Slow speed to 7 fpm at 10100'. Not having bad overpulls, but slowing to wash sand ahead of us. Put 200 psi on well head, pulled up slowly. Got thru it finally. Clean from 9950' to the window. Geo caught sample from sweep when we were working beNy of well. It was all clean sand with a very small amount of siltstone. Nothing that he would categorize as shale or clays. 09:00 - 12:30 3.50 DRILL P PROD1 Ran in the hole clean. Started seeing debris in the hole again at 9990'. Work down thru it with pumps at 0.9 bpm, and 200 psi on wellhead. Just slowed down going down, didn't really have to work it. Pump another sweep, and pull back up thru debris field again from 10220'-9950. Pulled up slick, with no overpulls this time and slight motor work. Run back down, and had motor work from 10990' to TD. Tag TD, then wash back uphole to 10900', then back to bottom. 12:30 - 15:00 2.50 DRILL P PRODt Tag bottom, resume driAing. Geo reports we are drilling 30% siderite. ROP is only about 10 fph. Just going to have to nibble our way thru it. 15:00 - 15:45 0.75 DRILL P PROD1 Free spin 4600 psi at 1.48 bpm. Free spin 4000 psi at 1.35 bpm. Drilling at (.35/1.38/4270 psi. WOB=24001bs. On a hard spot, and having a tough time getting thru this siderite. 15:45 - 19:15 3.50 DRILL N DFAL PROD1 Haven't made any footage in the past 45 minutes. Been holding 2500 Ibs WOB, and getting 200 Ibs motor work. Something isnY right. POOH io check bit and motor. Clean PU off bottom at 22 klbs. Clean up thru belly of the well with no overpuNs or packing off. Clean up !o the window. Open EDC and pump ai full rate while POH. Wash SSSV. 2.1 bpm at 4220 psi. Continue to POOH. Jog back in hole to flush cuttings. No additional cutttings over shaker. Agitator is working. 19:15 - 19:30 0.25 DRILL N DFAL PROD( At surface. Flow check well to verify SSSV is holding. 19:30 - 20:15 0.75 DRILL N DFAL PROD1 Get off well. LD BHA. Bit in 1/1 condition. Found stator rubber in jets. Found a washed out port in motor body, which would have reduced motor power. 20:15 - 22:30 2.25 DRILL P PROD1 Reverse circulate through coil to pump slack. Cut 1203' of coil. Found wire 73' back inside coil. 22:30 -00:00 1.50 DRILL P PROD1 Re-head a-coil. Pressure, pull, and continuity check same. 12/10/2005 00:00 -00:30 0.50 DRILL P PROD1 Continue to MU a-line head. Circulate coil. 00:30 - 01:15 0.75 DRILL N DFAL PROD1 MU lateral BHA w/ new mtr (1.0 deg) and HTC bi-center bit. Stab coil. Test MWD. Get on well. 01:15 - 02:30 1.25 DRILL N DFAL PROD1 Run in hole following WHP schedule. Open SSSV. Continue in hole. 02:30 -03:00 0.50 DRILL N DFAL PROD1 Log gr tie in from 8750'. No correction. 03:00 -04:45 1.75 DRILL N DFAL PRODi Run in hole. Circ at 1.21 bpm/3270 psi. Tight hole and motor work from 9992' to 10060'. Hold 200 psi WHP and reduce circ rate to get through problem area. Encountered several additional tight spots while running to btm. Reamed and circulated through each. Begin displacement to new mud. 04:45 -06:00 1.25 DRILL P PRODi Drill ahead from 11,197'. 06:00 - 08:30 2.50 DRILL P PRODt Drilling ahead. 1.48/1.55/4200 psi. Taking on new mud. IAP=550 psi, OAP=532 psi. BHP=3725 psi. WOB = 1400 Ibs. Printed: 1!3/2006 11:13:50 AM BP EXPLORATION Page 14 of 30 Operations Summary -Report: Legal Well Name: 1 L-25 Common Well Name: 1L-25 Spud Date: 11/25/2005 Event Name: REENTER+COMPLETE Start: 11/27/2005 End: 12/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: .Date Frorn - To Hours Task Cotle NPT Phase Description of Operations 12/10/2005 06:00 - 08:30 2.50 DRILL P PROD1 ROP=50 fph. String wt=-2000 lbs. Pumping 1, 10 bbl sweep per hour to help in hole cleaning. 08:30 - 10:00 1.50 DRILL P PROD1 Wiper trip to shoe. Clean PU off bottom at 22 klbs. Clean in the 11000'-10600' interval. Pumped sweep as we pulled clean thru the belly of the well. Light motor work and overpulls from 10165'-9990'. Did not have to slow down or work it. Much better than yesterday. Based on out rate, we probably have bypassed some sand and will have to clean it up on the way back in the hole. Continue wiper to window clean with no problems. Watched returns when belly sweep got to surface. It was loaded up with sand. Note -This is the smoothest trip we have had for a few days. 10:00 - 12:15 2.25 DRILL P PROD1 RBIH on wiper trip. Clean while RIH. Had to work down slightly from 9990'-10050'. Wasn't real bad. Run to 10200', pull back up thru it. Pulled until we started seeing it on wt and out rate, then slowed down to 10 fph to wash it up. Pulled up with slight motor work and slight overpulls. Not bad. Pump another sweep, and run down thru it again. Run to bottom. Sweep was loaded up with sand when we got it back on surface. 12:15 - 16:20 4.08 DRILL P PROD1 Resume drilling. Free spin 4000 psi at 1.45 bpm. Drilling at 1.44/1.33/4140 psi. PVT=435 bbls. Continuing to pump sweeps 1 per hour. ROP=33 fph. DHWOB=1400 Ibs, Siring wt _ -6200 Ibs. 16:20 - 18:00 1.67 DRILL P PROD1 Getting a little hard to get wt to bit. Make wiper to wrndow. Clean PU off bottom at 24 klbs. Pump sweep prior to getting to belly of the weft, Clean up thru belly of the well. No overputis or packing off at all!. This is definately the best that it has been in 3 days. Continue clean to the window. 18:00 - 19:15 1.25 DRILL P PROD1 Wiper back in hole. Weight bobbles start at 9940'. Reduce pump rate and work pipe through. Not too bad. Continue trip to btm at reduced circ rate (1.05 bpm) Rest of hole mostly " smooth. 19:15 -00:00 4.75 DRILL P PROD1 Drill ahead from 11,471'. 3900 psi fs at 1.49 iNout. DPSI: 200-250 DHWOB: 1.5k# WHP/BHP/ECD: 18/3765112.41 ppg. lA/OA/PVT: 659/647/445 bbls. INC/AZM/TF: 86-90/247-294/75-105 deg. ROP hard to maintain, but avg 50 fph when actually drilling. Pumping a 10 bbl hi vis sweep every hour. 12/11/2005 00:00 - 01:30 1.50 DRILL P PROD1 Wiper trip to 7800'. Hole mostly smooth on trip out. Time sweep for 10,000' area. 01:30 - 02:00 0.50 DRILL P PROD1 Run in hole to btm. Did not notice any significant cuttings increase with sweep or short trip btms up. 02:00 -02:15 0.25 DRILL P PROD1 Log gr tie in from 8775'. 02:15 -03:45 1.50 DRILL P PROD1 Continue to run in hole. Ciro at 1.05 bpm in. Hold 200 psi WHP, to maintain BHP due to reduced pump rate. Mostly smooth from 9950' to 10150' (a few minor bobbles). Rest of hole very smooth, although string weight was negative from f 1,000' to bim. Hole conditions are looking good. 03:45 -04:00 0.25 DRILL P PROD1 Drill ahead from 11,630'. 04:00 -04:45 0.75 DRILL N SFAL PROD1 BHI depth counter not working. Found parted line at surface. Failed due to high winds pulling cable out of an electrical Printetl: 1/3/2006 11:13:50 AM BP EXPLORATION Page 15 of 30 Operations Summary Report Legal Well Name: 1L-25 Common Well Name: 1L-25 Spud Date: 11/25/2005 Event Name: REENTER+COMPLETE Start: 11/27/2005 End: 12/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/11/2005 04:00 -04:45 0.75 DRILL N SFAL PROD1 connector. Repair same. 04:45 - 06:00 1.25 DRILL P PROD1 Drill ahead from 11642'. 06:00 - 09:40 3.67 DRILL P PROD1 Continue drilling ahead from 11690'. 1.53/1.52/4420 psi. PVT=432 bbls. IAP=730. psi, OAP=677 psi. BHP=3869 psi. ECD=12.73 ppg. DHWOB=800 lbs. String wt = -1000 lbs. ROP=40 fph. INC=92 deg. Geo plan is to continue drilling up until we hit the Kalubik, then call TD. 06:50 - 09:40 2.83 DRILL P PROD1 Caught last sweep at surface. Found lots of sand contained in sweep. They appear to be doing some good. Continue drilling ahead and pumping sweeps once per hour. 09:40 - 13:30 3.83 DRILL P PR001 Wiper trip to window. Clean PU off bottom at 22 klbs. Clean up to 10158'. Slight overpulls and packing off rom 10158'-9940'. Didn't get stuck or have to work it hard, but have some sand here yet. Clean the rest of the way to the window. RBIH. Clean to 9950'. Held 300 psi WHP, and dropped rate to 0.8 bpm. Ran thru it with small wt bobbles and motor work. Set down momentarily at 11000', made it back to bottom ok. RIH weight near bottom was -2400 lbs. 13:30 - 18:00 4.50 DRILL P PROD1 Tag bottom, resume drilling. Free spin 4150 psi at 1.43 bpm. Drilling ahead at 1.43/1.47/4230 psi. ROP=20 fph. PVT=411 bbls. DHWOB=1200 lbs. String wt = -8000 lbs. Getting very close to lockup. Won't be able to drill a bunch more footage. 18:00 - 21:45 3.75 DRILL P PROD1 Wiper trip to window. Pump hi vis sweep as BHA passes 10,000' interval. Some minor overpulls and motor work from 9984' to 9920'. Trip back in hole smooth. Began having trouble pushing pipe to btm from 11,650' on down. Had to reduce circ rate and running speed to get to 11,902'. Mud LSRV is +/- 50k. Drillied solids are 0.6 21:45 -00:00 2.25 DRILL P PROD1 Drill ahead from 11,902'. 4050 psi fs at 1.44 iNout. DPSI: 150-200 DHW06:1.5.1.8k#. WHPlBHP/ECD:22l3915/i2.92 ppg. IA/OA/PVT: 745/675/391 bbls. INC/AZM/TF: 93-95/250-294/330-360. ROP very slow. May be in Kalubik. Catch frequent btms up samples to check cuttings. Prep to swap mud. 12/12/2005 00:00 - 03:00 3.00 DRILL P PRODi Drill ahead from 11,916'. Continue displacement to new mud. Send used system to MI for re-conditioning and thinning. ECD dropped from 12.89 to 12.33 ppg. DHWOB inceased from 1.5 k# to 2.5 k#. ROP still very slow, <10 fph. Geo reports a lot of highly cemented sand in samples. Drill to 11,929'. Finally found Kalubik in samples. 03:00 -06:00 3.00 DRILL P PRODi Wiper trip to 7800'. 20.8k# up weight off btm. Ream and back ream 9,900 to 10,100 area. Continue wiper into tubing. 06:00 - 07:45 1.75 DRILL P PROD1 Continue the wiper inside tubing up from 7700'. Pull up to 7000' pumping at full rate. RBIH pumping at full rate. SD pumps, run thru the window. Pumps back to full rate. RIH. 07:45 -09:25 1.67 DRILL N DPRB PRODt RIH pumping at full rate. Set down at 9941'. PU, drop rate to 0.95, WHP to 300 psi. Run down ~ru ft slow. Pump sweeps to try to clean up. Pull back up from 10200', pumping at full rate, and pulling at 10 fpm. Started seeing motor work and 2000 Ib overpull at 10120'. Slow rate to 6 fpm to allow to clean up. Getting lots of cuttings back with each sweep. Discuss with Geo. He reports that the interval 9990'-10200' is well Printed: 1!3/2006 11:13:50 AM BP EXPLORATION Page 1s of 30 Operations Summary Report Legal Well Name: 1 L-25 Common Well Name: 1L-25 Spud Date: 11/25/2005 Event Name: REENTER+COMPLETE Start: 11/27/2005 End: 12/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date From - To -Hours .Task Code' NPT Phase Description of Operations 12/12/2005 07:45 - 09:25 1.67 DRILL N DPRB PROD1 cemented, and he would not expect it to be washing out. He thinks that the belly of the well is trapping cuttings, that is what we are seeing. 09:25 - 13:15 3.83 DRILL N DPRB PROD1 Made backreaming pass up. Got packed off at 9937'. Stopped and washed it clear. Made another pass down at .88 bpm and 300 psi WHP. Try a pass up dry, holding +500 psi on whp. Pull at 30 fph from 10200'-9750' . Slick with no problems. RIH from 9750' dry while holding 500 psi on WHP. Set down at 10048'. PU, orient to high side. RIH, set down same place. Try again. Set down 2 more times. Kick pumps on. Wash down at 0.8 bpm and 300 psi. Saw a blip of motor work at 10050', clean below that. Run in to 10200', PUH to 9750' pumping at 0.8 bpm, and had no problems. Seems to be cleaning up. RIH at 300 psi, 0.8 bpm, and pumping a sweep. Make 3 more passes each way. Hole is as clean as we are going to get it. Haven't seen any motor work or overpulls on the last 3 passes. Pull up to 9750' on last up pass. Drop WHP to 0, bring on pumps to full rate. Chase cuttings to window. Geo caught a sample of our latest reaming and indicates he thought the latest samples were from the interval between 10200'-9950', and not cuttings from deeper in the hole. 13:15 - 15:20 2.08 DRILL N DPRB PROD1 Run back in hole from window. Pumping at 1.5 bpm. 9750', Trap 300 psi and drop rate to .83 bpm. Run down thru bad area clean. Bring pumps to full rate at 10200'. Set down and picked up at 10802'. Made it thru on 2nd try. Pump another sweep. Run to bottom pumping at full rate. Set down at 11467', PU, made it thru on 2nd try. RIH wt = 1200 lbs. W OB=200 lbs. 15:20 - 16:50 1.50 DRILL P PROD1 POOH laying in new mud with MI Alpine glass beads at 3 ppb. Pumping at 0.5 bpm, 400 psi whp. Pump a total of 51 bbls of bead pill. Smooth off bottom. Smooth up thru the belly of the well. Smooth to the window. This is as clean as we are going to be able to get the welt. 16:50 - 19:00 2.17 DRILL P PROD1 Drop pumps to 0, pull thru window. POOH pumping at max rate thru the EDC. 2.1 bpm, 3700 psi. Wash SSSV area. Continue out of hole. Jog in hole at surface to flush any remaining cuttings. At surface. Ftow check well. 19:00 - 19:30 0.50 DRILL P PROD1 LD BHA. HTC bit graded 1/1, with one chipped pilot cutter. 19:30 -00:00 4.50 BOPSU P PROD1 RU fro bi-weekly BOP test. Hold PJSM to discuss high pressure testing. Witness waived by J. Jones, AOGCC. Perform injector chain inspection during SOP test. 12/13/2005 00:00 - 01:00 1.00 BOPSU P PROD1 Continue and complete BOP test. No failures. 01:00 - 01:30 0.50 CASE P RUNPRD Rig up Boor to run 2-3/8' liner. Hold PJSM with all hands to discuss job assignments, risks and hazards, contingencies. 01:30 - 01:45 0.25 CASE P RUNPRD Hold PJSM to dicuss liner job. Review job and floor assignments. Discuss hazards, risks, and minimization of same. Discuss contingencies, handling safety joint, and more. 01:45 -03:45 2.00 CASE P RUNPRD MU 51 joints of slotted & solid 2-3/8",4.43#, L80, STL liner with indexing guide shoe, o-ring sub, and deployment sleeve. Total length: 1657.36' 03:45 -04:30 0.75 CASE P RUNPRD Make up MWD tools. PU injector and stab coil. Test mwd. Get on well. Open SSSV. Printed: 1/3/2006 17:13:50 AM BP EXPLORATION Page 17 of 30 Operations Summary Report Legal Well Name: 1L-25 Common Well Name: 1L-25 Spud Date: 11/25/2005 Event Name: REENTER+COMPLETE Start: 11!27/2005 End: 12/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operafions 12/13/2005 04:30 - 06:00 1.50 CASE P RUNPRD Circulate to fill liner. Pressure well to 900 psi. Open SSSV. Run in hole with finer assembly. 06:00 - 06:30 0.50 CASE P RUNPRD Stop at window. Wt check up = 22 klbs. Stop coil while we change crews. Continue RIH. RIH wt 9000 Ibs at the window. RIH smooth at window. Smooth to 9650'. String wt finally low enough, drop pumps to 0, shut the EDC. Continue RIH. 9700', RIH wt 8000 Ibs. 9900' RIH wt 65001bs. 06:30 - 07:15 0.75 CASE N DPRB RUNPRD RIH. 300 psi on WHP, pumps at 0.5 bpm. Set down solid at 10050'. PU 10', RIH, set down. PU 20', RIH set down. Repeat 6 times. PU at 24 klbs each time, set down solid at 10050' each time. PU 30', RIH at 80 fph. Set down. Repeat. PU 50', RIH at 100 fpm, Set down. PU 100'. SD pumps, trap 500 psi on WHP. RIH, and set down solid at same depth. PU 100', Open choke W FO. Try to flow the well. RIH, tag up solid. PU 100', Pressure up the we0 to 700 lbs. RIH, and tag up solid at 10050'. Same depth as all other tags. Set down on it, bleed WHP off and try to flow well. Can't make any progress. 07:15 -09:10 1.92 CASE N DPRB RUNPRD POOH. Call town and discuss options. Cali WF and Baker for more odds and ends. Bring in 1" CSH to pipe shed. 09:10 - 09:25 0.25 CASE N DPRB RUNPRD Safety meeting prior to standing back liner, and flowcheck of well 09:25 - 11:15 1.83 CASE N DPRB RUNPRD Check well for flow. Still getting a trickle. Pressure back up on wellhead to 900 psi, and cycle SSSV. Still getting a trickle. May have beads on seal area of SSSV. RIH to wash SSSV with open EDC. RIH to 100' below the SSSV. Jet up and down for 3 passes each way accross the SSSV. Check returns, getting a combination of beads and scale back. Not alot, but enough. POOH, pumping at full rate to chase debris out of the hole. 11:15 - 11:45 0.50 CASE N DPRB RUNPRD Tag back up at surface. Give well a good flow check. No flow observed. 11:45 - 14:00 2.25 CASE N DPRB RUNPRD Stand back injector. Lay down BHI tool. Stand back 2-318` liner. Recover Unique oriented guide show fuU of shale "pea " gravel". It wouldn't rotate due to the debris inside of it. 14:00 - 16:00 2.00 CASE N DPRB RUNPRD RU floor to run liner. MU motor & bit assy on finer. Run liner stands, scribing each stand. Hang off Liner in BOPs. 16:00 - 17:30 1.50 CASE N DPRB RUNPRD RU floor to run CSH work string. Hold PJSM to discuss job. Assignments, hazards, well control issues, procedures. Change dies in little jerks. 17:30 - 21:30 4.00 CASE N DPRB RUNPRD MU 51 jts 1"CSH and space out for stinger to bottom out 1' above O-ring sub w! 10' of pups. {nstaN BTT seal bore deployment sleeve w/ 3' GS splined spear. MU BHI MW D assy and test 21:30 -22:50 1.33 CASE N DPRB RUNPRD RIH w! liner on CT circ thru GS 0.15/2300 following pressure schedule. Open TRSSSV w/ 900 psi 22:50 - 23:40 0.83 CASE N DPRB RUNPRD 8800' 24k. RIH thru window, clean. Continue RIH in OH at 35'lmin 0.17/1970 w/ 400 psi by watching TF in free-wheel mode follow high left when drilled at 90R. Lock TF at 80L DTF at 9800' and RIH 35'/min while follow DTF thru prior set-down area at 10050' (like it had eyes-nary a bobble) 23:40 -00:00 0.33 CASE P RUNPRD Log tie-in down from 10437' (at -8750') and had no corr. RIH at 35'/min to set-down at 10515'. PUH 25k 12/14/2005 00:00 -00:20 0.33 CASE P RUNPRD Continue to set down solid at 10515' w/ clean PU's at 25k. Printed: 1/3/2006 71:13:50 AM BP EXPLORATION Page 18 of 30 Operations Summary Reporf Legal Well Name: 1 L-25 Common Well Name: 1 L-25 Spud Date: 11125/2005 Event Name: REENTER+COMPLETE Start: 11/27/2005 End: 12/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: ~IORDIC 2 Rig Number: Date From - To Hours Task :Code.` NPT Phase bescription of'Operations 12!14/2005 00:00 -00:20 0.33 CASE P RUNPRD This puts the GS/deployment sleeve gap at the bottom of the window. Work it 20+ times w/ various combinations and finally bounced over the lip (may have to deal with this later ...) 00:20 - 00:30 0.17 CASE P RUNPRD RIH at 0.17!1900 45'{min w/ +6k to set down at 10637'. PUH w/ 20k. Appears we released from the liner. RIH and latch up on second try 00:30 - 01:00 0.50 CASE P RUNPRD Continue RIH w! no resistance at 10637' ... RIH at 40'/min to set down at 10808'. PUH at 26.5k verifying finer still on. Work to get thru various set-down spots to 10837'. Orient 360 deg and started moving again w/o pump 01:00 - 01:40 0.67 CASE P RUNPRD Continue RIH from 10845' w/ +2k, but no retums. Incr rate to 0.5/2890 w! 800 psi whp and RIH at 18'/min w/full retums following assumed DTF, :Start climbing the hill at 10950' w/ ~ +i.5k. Crest at 11100' w/ 0.5k, 11300' •0.5k. Swap TF from 90R to 90L at 11500' and lost additional 2k. Just before setdown at 11555' had -3.5k at 20'/min 0.48/2990 w/ 830 psi whp. SD pump and work to planned TD of 11585' 01:40 - 01:45 0.08 CASE P RUNPRD PUH 27.4k for 20' and was clean. RIH w/o pump and set liner back at planned depth w! +5.2k surf wt w/ TF 180 out. Bleed off whp while bring rate up to 1.4/4500. PUH 19.Sk and GS released from liner. Left TOL at 9917' and BOL at 11585' 01:45 - 03:50 2.08 CASE P RUNPRD POOH w! CSH thru OH 1.3514130 w/ 300 psi whp. See the GS catch the top of window at 10508' CTD w/ 8k overpull (still on depth ...). Open EDC w/ CSH above window and circ 2.0/3800. Wash SSSV 03:50 -04:05 0.25 CASE P RUNPRD Tag up. Close TRSSSV. Check for flow 04:05 -04:35 0.50 CASE P RUNPRD Displace CSH and tubing above TRSSSV w! FW 04:35 - 05:00 0.42 CASE P RUNPRD LD MWD assy and GS. A few minor fresh scars on OD of GS 05:00 - 05:30 0.50 CASE P RUNPRD Safety mtg. RU to LD CSH 05:30 - 07:30 2.00 CASE P RUNPRD LD 51 CSH singles 07:30 - 10:30 3.00 CASE P RUNPRD Hold PJSM with crew. MU "A" 2-3/8' liner assembly, 30 jts slotted & solid pipe with bullrlose guide shoe and Weatherford aluminum billet. Inspect GS spear. Much smaller than BTT " spear. No square shoulders noted. Stab coil. Get on well. 10:30 - 12:30 2.00 CASE P RUNPRD Pressure well to 900 psi. Open SSSV. Run in hole following WHP schedule. 12:30 - 13:30 1.00 CASE P RUNPRD Weight check at 8780'. 22k# up. Run through window ok. Log gr tie in. No correction. GS through window ok. Wt check at 9916'. 25k# up. Pump at 1.12 bpm at 4450 psi. PU. 20k# up wt. Appear to be released. 13:30 - 15:30 2.00 CASE P RUNPRD Pull out of hole. Hold WHP as per schedule. 15:30 - 16:00 0.50 CASE P RUNPRD LD liner running BHA. LD Weatherford tools for toad out. 16:00 -17:30 1.50 STKOH P PROD2 LD liner running BHA. MU lateral drilling BHA. {1.9 mtr w! HTC STR324 bit). Stab coil. Get on well. Test tools. DPS is questionable. Run it any way as there is no back-up tool on location. Worked ok on liner run. 17:30 -19:20 1.83 STKOH P PROD2 RIH w! BHA #16 circ thru bit 0.412210 following pressure schedule. Open TRSSSV w/ 900 psi 19:20 - 19:40 0.33 STKOH P PROD2 Log tie-in down from 8770', con +2'. RIH at 0.4/2100 and tag at 8938' 19:40 - 19:50 0.17 STKOH P PROD2 PUH 2O.5k, start pump 1.5/3350, orient to 60L (orientor is very weak}. Perform three 10'/min down passes from 8910' and inadvertently stall at 8938' each time Printed: 1/3/2006 11:13:50 AM BP EXPLORATION Page,19 of 30 Operatioins Summary Report Legal Well Name: 1L-25 Common Well Name: 1 L-25 Spud Date: 11 /25/2005 Event Name: REENTER+COMPLETE Start: 11/27/2005 End: 12/28/2005 ' Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date Frorn - To Hours Task Code NPT Phase Description of Operations 12/14/2005 19:50 - 20:45 0.92 STKOH P PROD2 Park at 8935' for 5 min at 60L then begin 0.1'/min slow ream in hole. Minor dill at 8938.3' so assume this is the top of billet. Continue RIH at 0.1'/min and begin departure from billet 20:45 - 21:30 0.75 STKOH P PROD2 At 8941' and still at 0.1'/min w/ 1.5/3400/60L w/ 20-50 psi dill and wob sensor not working, but sliding good 21:30 - 21:45 0.25 STKOH P PROD2 Start adding wt and incr penetration rate from 8946'. Drill to 8960' 1.5/3380/62L w/ 100-250 psi dill at 40.60'/hr 21;45 - 22:10 0.42 STKOH P PROD2 8ackream at drilled TF 1.5/3330/60L at 10'/min to 8910', clean. Ream in hole 1.5/3380/60L at 8'/min and clean. Try to orient to 30L, but orientor won't respond. Backream to 8910' at 60L at 5'/min and orientor moved to 15L at 8934', and then to 60R by 8910'. Can't do anything else on this run, but acts clean enough for now. A few small alum flakes in samples 22:10 -00:00 1.83 STKOH P PROD2 POOH thru OH and window, clean. Open EDC at 8700'. POOH circ 1.85/3200 while follow pressure schedule 12/15/2005 00:00 -00:30 0.50 STKOH P PROD2 LD sidetrack BHA 00:30 - 01:40 1.17 DRILL P PROD2 MU lateral assy. Remove unuseabie DPS, change-out weak orientor. Change bit 01:40 - 03:15 1.58 DRILL P PROD2 RIH w/ BHA #17 {HCC bi-bit, 1.9 deg motor) following pressure schedule. Open TRSSSV w/ 900 psi 03:15 - 03:35 0.33 DRILL P PROD2 Log tie-in down from 8770', corr -0.5' 03:35 -04:00 0.42 DRILL P PROD2 RIH thru window, clean. Ream 1.46/3100/60L at 10'/min from 8910' to TD tagged at 8960', clean. Orient to 30L. Backream at 10'/min to 8910', and ream at 30L 10'/min to TD, clean. Repeat at 90L and was clean. No MW or wt loss anywhere 04:00 - 06:00 2.00 DRILL P PROD2 Drill from 8960' 1.66/3475/45L w/ 0-2.5k surface wob, 50-250 psi dill w/unknown ECD (due to no DPS) showing 90 deg on NB incl at 8946'. Get back into f 5'/ttr drilling at 8965' 06:00 - 09:00 3.00 DRILL P PROD2 Drill ahead from 9000'. 09:00 - 12:00 3.00 DRILL P PROD2 DriN ahead f/ 9050'. 3800 psi fs at 1.65 in/1.63 out. DSPI: 200-300. WHP: 37 psi. IA/OA/PVT: 377/631/421 bbls. Drilling ahead smoothly at 30 fph. Build to 97 deg and begin tum to azm: +/-100 deg. 12:00 - 16:15 4.25 DRILL P PROD2 Drill lateral to 9225'. Continue tum to east, begin to drop angle. 91 deg inc, 100 deg azm. Liner out for lateral section. 16:15 - 18:15 2.00 DRILL P PROD2 Circulate OOH to window. Open EDC and circ out of hole at 2 bpm. Follow WHP schedule. 18:15 - 19:10 0.92 DRILL P PROD2 LD tum assy. Adjust motor, rerun bit 19:10 - 20:40 1.50 DRILL P PROD2 RIH w/ 8HA #18 {HCC bi bit, 1.0 deg motor) foNowing pressure schedule. Open TRSSSV w/ 800 psi 20:40 - 21:05 0.42 DRILL P PROD2 Log tie-in down from 8770', no corr 21:05 - 21:20 0.25 DRILL P PROD2 RIH thru window, clean. Start motor and ream 1.55/3450 by OH sidetrack pant w/ no MW. Wiper to TD tagged at 9225' PVT 414 ~ 21:20 - 23:00 1.67 DRILL P PROD2 Drill from 9225' 1.55l3450/90L w/ 50-250 psi MW and 1-3k surf wob w/ unknown ECD (no DPS in string) at 92 deg NB incl at 9213' at 30-40'!hr to 9257'. Had two stalls, then started stacking full wt w/o progress 23:00 - 23:15 0.25 DRILL P PROD2 100' wiper was clean 23:15 -00:00 0.75 DRILL P PROD2 Drill from 9257' f.62/3380/85L and no progress while stacking full wt 12/16!2005 00:00 -00:30 0.50 DRILL N DFAL PROD2 Continue to attempt to drill from 9257' and not. Only getting 150 psi MW while stacking full wt. No drill-off whatsoever. Printed: 1/3/2006 t 1:13:50 AM I BP EXPLORATION Page 20 of 30 Operations Summary-Report Legal Well Name: 1L-25 Common Well Name: 1 L-25 Spud Date: 11 /25/2005 Event Name: REENTER+COMPLETE Start: 11/27/2005 End: 12/28!2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date. From - To Hours . Task Code NPT: Phase Description of Operations 12/16/2005 00:00 -00:30 0.50 DRILL N DFAL PROD2 Suspect motor, but no rubber on shaker 00:30 -00:50 0.33 DRILL N DFAL PROD2 Wiper thru window was clean 00:50 - 02:30 1.67 DRILL N DFAL PROD2 POOH to check BHA following pressure schedule. Close TRSSSV w/ 900 psi 02:30 - 03:00 0.50 DRILL N DFAL PROD2 LD drilling BHA. Found bit body had backed off of double pin connection to motor box leaving the matrix (body) of bit in the hole 03:00 -04:00 1.00 STKOH N DFAL PROD2 Discuss. Will do a low side OH sidetrack at -9220'. Adjust motor back to 1.9 deg. MU 2..73" R60ST w/ brass cap 04:00 - 05:45 1.75 STKOH N DFAL PROD2 RIH w/ BHA #19 circ 0.35/1930 thru EDC #ollowing pressure schedule. Open TRSSSV w/ 900 psi 05:45 -06:15 0.50 STKOH N DFAL PROD2 Log tie-in down from 8765'. No correction. 06:15 -06:30 0.25 STKOH N DFAL PROD2 Run in hole. Tag btm to remove brass ring. Set down 5k#, with min pump. 06:30 - 09:00 2.50 STKOH N DFAL PROD2 Back ream trough from 9220 to 9200'. Make three passes at 0.5 FPM. 09:00 - 09:30 0.50 STKOH N DFAL PROD2 Lock brake at 9219' for 30 minutes. TF: 170L. 3550 psi fs at 1.55 in/out. 09:30 - 13:30 4.00 STKOH N DFAL PROD2 Time drill: 1' per hr for 1 ft, 2' per hr for 2', 3' per hr for 3'. Begin to take weight. Slowly drill ahead. Rotate TF towards HS to minimze drop. Starting to see significant inclination change. Drill ahead to 9253. 13:30 - 14:45 1.25 STKOH N DFAL PROD2 Back ream and ream a few passes. Hole looks clean. 14:45 - 16:15 1.50 STKOH N DFAL PROD2 Pull through window. Open EDC. Circulate at max rate while POH. Wash SSSV area. Close SSSV w/ 900 psi on well. Continue to surface. 16:15 - 17:00 0.75 STKOH N DFAL PROD2 At surface. Flow check. Get off well. Unstab coil. Reduce motor angle to 1.0 deg. MU used HYC bi-center (as HTC is in the dog pound) 17:00 - 18:25 1.42 DRILL N DFAL PROD2 RIH w/ BHA #20 following pressure schedule. Open TRSSSV w/ 900 psi 18:25 - 18:45 0.33 DRILL N DFAL PROD2 Log tie-in down from 8755' 18:45 - 19:00 0.25 DRILL N DFAL PROD2 Wiper thru window and by TOL was clean 19:00 - 20:30 1.50 DRILL N DFAL PROD2 Set down and stall twice at 9218'. Try to RIH w/o pump thru new OH sidetrack area w!o success. Ream from 9210' 1.6/3800 at DTF at 1'/min. Saw considerable MW and wt loss 9218-9222'. Rest of sidetrack was tits in spots. Tag at 9253'. Backream to 9210'. Ream back down at 1'/min from 9215' 1.6/3530 w/ 3.5k eMra string wt to 9220' and sidetrack area is clean. Ream to TD 20:30 - 22:20 1.83 DRILL P PROD2 Drill from 9253' 1.6/3540/15L w/ 200-400 psi dill, 1-3k surf wob w/ unknown ECD (no PDS sub) w/ NB incl 88 deg at 9243'. Start to regain lost TVD from drilling around the junk. Drill to 9343' w/ 96 deg and had stall w/ overpull 22:20 - 22:35 0.25 DRILL P PROD2 100' wiper had minor overpulls 22:35 - 23:45 1.17 DRILL P PROD2 Drill from 9343' to 9400' 23:45 -00:00 0.25 DRILL P PROD2 Wiper to window. Hole smooth. 12/17/2005 00:00 -00:30 0.50 DRILL P PROD2 Wiper to window was clean both directions PVT 405 00:30 -04:35 4.08 DRILL P PROD2 Drill from 9400' 1.6/3580/90L w! 100-300 psi dill at 93 deg. Swap to right at 9450'. Drill to 9550' at 90 deg at 5847' TVD PVT 404 04:35 - 06:15 1.67 DRILL P PROD2 Wiper to window. Hole smooth. 06:15 - 10:20 4.08 DRILL P PROD2 grill ahead from 9550'. 3890 psi fs at 1.6 in/out. ROP erratic. Printed: 1/3/2006 17:13:50 AM BP EXPLORATION' Page 21 of 30 Operations Summary Report Legal Well Name: 1 L-25 Common Well Name: 1L-25 Spud Date: 11/25/2005 Event Name: REENTER+COMPLETE Start: 11127/2005 End: 12/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Cotle NPT- Phase Description of Operations 12/17/2005 06:15 - 10:20 4.08 DRILL P PROD2 Looked like Kalubik, but apparently not. 10:20 - 11:30 1.17 DRILL P PROD2 Wiper trip to above window. Log gr tie in. Subtract 2' correction. Run in hole. Hole smooth each way. 11:30 - 15:00 3.50 DRILL P PROD2 Drill ahead from 9700'. 3700 psi at 1.55 iNout. DPSI: 100-200 IA/OA/ PVT: 704/864/371 bbls. INC/AZM/TF: 88-91/61-1001240-280L. Drill several slow intervals, expecting each to be the Kalubik. Then ROP increases yet again. 15:00 - 18:00 3.00 DRILL P PR002 Drilling ahead at 9760'. 18:00 - 20:30 2.50 DRILL P PROD2 Drill from 9800' 1.62/3720/90L and continuing to make hole in short spurts. Pick up at 9839' had overpull. Stalled when RBIH at 9803', catch a sample which was mostly sand, no Kalubik shale, some small/fine rubber pieces .. . 20:30 - 21:10 0.67 DRILL P PROD2 Wiper to window, clean 21:10 - 21:20 0.17 DRILL P PROD2 Log tie-in down from 8770', corr +1.5' 21:20 - 22:00 0.67 DRILL P PROD2 Wiper to TD was clean 22:00 - 23:15 1.25 DRILL P PROD2 Drill from tag at 9840' 1.63/3740/45L w/ max suf wt and 100-200 psi dill. Still have slow and intermittent penetration rate. Drill to 9855' and assume motor problem 23:15 - 00:00 0.75 DRILL P PROD2 Wiper thru window was clean 12/i8/2005 00:00 - 01:45 1.75 DRILL P PROD2 POOH to check BHA following pressure schedule. Sample from 9850' showed Kalubik shale, but geo's want to drill further to see it on GR 01:45 - 03:00 1.25 DRILL P PROD2 LD drilling BHA. Motor was slightly overtite, bit had more wear than expected 3-3-I. Change out both, add DPS 03:00 -04:30 1.50 DRILL P PROD2 RIH w/ BHA #21 circ thru bit 0.35/2100 following pressure schedule. Open TRSSSV w/ 900 psi 04:30 -04:50 0.33 DRILL P PROD2 Log tie-in down from 8760', Corr -2' 04:50 - 05:30 0.67 DRILL P PROD2 Wiper thru window and OH was clean to set down at 9840' 05:30 - 05:45 0.25 DRILL P PROD2 PU with 6k overpull. Attempt to ream to TD of 9855', but had continual stalling with overpulls and no progress past 9841' w/ 12.64 ECD 05:45 -06:00 0.25 DRILL P PROD2 Wiper while wo crew change 06:00 -06:30 0.50 DRILL P PROD2 Reduce rate to 0.95. Hold 400 psi WHP. Try to work to btm. Able to make 4'-5', then pick up. Run back in and encounter same hole problems at the same depth. Discuss with geos and town, Decide to call TD to minimize risk to BHA. 06:30 - 08:15 1.75 DRILL P PROD2 Wiper trip to above window. Run to btm. Lay in 40 bbls clean flo pro pill. Pull through window. 08:15 - 10:00 1.75 DRILL P PROD2 Circulate out of hole. Wash SSSV. Jog in hole at surface. Tag up. 10:00 - 10:30 0.50 DRILL P PROD2 Get off well. LD BHA tools. 10:30 - 11:15 0.75 CASE P RUNPRD Rig up floor to run liner. Hold PJSM to discuss handling jointed pipe, assignments, hazards, procedures. 11:15 - 12:15 1.00 CASE P RUNPRD MU i4 jts 2-3/8' sbtted, L80, 4.3#, STL liner with bull nose guide store and Weatherford 2.5' aluminum billet. OAL: 470.8' 12:15 - 12:45 0.50 CASE P RUNPRD MU MWD tools. Stab coil. Test MW D. Get on well. 12:45 - 15:15 2.50 CASE P RUNPRD Run in hole. Pressure well to 900 psi. Open SSSV. Continue to RIH. Follow WHP schedule. Weight check with shoe at window: 21k# up, 6k# do wt. Run into open hole. Log GR tie in. Subtract 2' correction. Continue to RIH. Weight check near btm. 25k# up, 5 k# do wt. Push through Printed: 1/3/2006 11:13:50 AM BP EXPLORATION Page 22 of 30 Operations Summary Report Legal Well Name: 1 L-25 Common Well Name: 1L-25 Spud Date: 11/25/2005 Event Name: REENTER+COMPLETE Start: 11/27/2005 End: 12/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: ..Date From - To Hours Task Code NPT Phase Description of Operations 12/18/2005 12:45 - 15:15 2.50 CASE P RUNPRD Kalubik and tag btm at 9855'. Circ at 1.33 bpm at 4435 psi to release GS spear. PU wt: 21 k#. Appear to be released. BOL: 9855'. TOL:9384'. 15:15 - 17:00 1.75 CASE P RUNPRD POOH while circulating through GS. Wash SSSV area. Pull out to surtace. 17:00 - 17:30 0.50 CASE P RUNPRD Flow check. Get off well. LD BHA tools. 17:30 - 21:30 4.00 DRILL P PRODS E-line slack management. Cut off 105' of a-line 21:30 - 23:15 1.75 STKOH P PRODS RIH w/ BHA #23 (1.9 deg motor, used HCC STR324) following pressure schedule. Open TRSSSV ~ 900 psi 23:15 - 23:35 0.33 STKOH P PRODS Log tie-in down from 8770', Corr -3.5' 23:35 -00:00 0.42 DRILL P PRODS Wiper thru window and OH was clean 12/19/2005 00:00 -00:30 0.50 STKOH P PR003 Tag top of billet at min rate at 9379.8'. Set TF at 150E and - backream/ream to/from 20' above billet twice at 3'/min 1.55/3480 PVT 355 00:30 - 01:20 0.83 STKOH P PRODS Park at 9379.0' for 5 min at 150L, then begin 0.1'/min slow ream in hole. Minor dill at 9380.1', but otherwise nothing. Continue RIFT at 0.1'/min and begin departure from billet. Smatl aluminum flakes in samples 01:20 - 02:30 1.17 STKOH P PRODS Start adding wt and incr penetration rate from 9383' and drill at 15-20'/hr. Drill to 9400' at 150E 02:30 - 03:00 0.50 STKOH P PRODS Backream at DTF 1.56/3440/150L to 9850' at 8'/min. Ream at DTF at 8'/min from 9850'-TD. Repeat at 140E and 175E w/ no MW 03:00 - 03:30 0.50 STKOH P PRODS Wiper to above TOC was clean. Open EDC 03:30 - 05:30 2.00 STKOH P PRODS POOH Circ ihru EDC at 1.8/3400 following pressure schedule. Wash TRSSSV and close w/ 900 psi 05:30 -06:30 1.00 STKOH P PRODS LD sidetrack BHA 06:30 - 07:00 0.50 BOPSU P PRODS Function test BOPs. 07:00 - 07:30 0.50 DRILL P PRODS MU BHA #24, lateral 1.0 deg mtr w/ HYC re-reun bi-center bit. Stab coil. Get on well. 07:30 - 09:00 1.50 DRILL P PRODS Run in hole. Pressure well to 900 psi. Open SSSV. Continue in hole. 09:00 -09:30 0.50 DRILL P PRODS Log GR tie in. Subtract 1' correction. Begin displacement to new mud. 09:30 - 13:00 3.50 DRILL P PRODS Drill ahead from 9400'. 3450 psi fs at 1.6 in/out. DPSI: 100-200 DHWOB: 1.95k#. WHP/BHP/ECD: 15/3607/11.92 ppg IA/OA/PVT: 3501573/438 bbls. Hold incl at 82-83 deg to continue drop. Displacement to new mud completed. 13:00 - 19:45 6.75 DRILL P PRODS Drill ahead from 9473'. ROP varying from 10 to 50 fph. Drill to 9700' 19:45 - 20:45 1.00 DRILL P PRODS Wiper to window was clean both directions PVT 443 20:45 -00:00 3.25 DRILL P PRODS Drill from 9700' 1.64/3500l70R w/200-400 psi dill, 1-4k wob w/ 12.0 ECD at 81 deg at 5888' TVD 12/20/2005 00:00 - 01:00 1.00 DRILL P PRODS Drill from 9815' to 9850' (5900' TVD) 01:00 - 01:35 0.58 DRILL P PRODS Wiper to window was clean. Pull thru window 01:35 - 01:50 0.25 DRILL P PRODS log tie-in down from 8770', corr+2.5' 01:50 - 02:30 0.67 DRILL P PRODS Wiper back to TD was clean PVT 442 02:30 -04:00 1.50 DRILL P PRODS Drll from 9851' 1.613560/858 w/ 100-300 psi dill, 1-3.5k wob w/ 12.19 ED at 90 deg at 5900' TVD. Swap to left at 9900'. Oritl to 9917' and stacking 04:00 -04:25 0.42 DRILL P PRODS Wiper/ream to remove TF change 04:25 -06:00 1.58 DRILL P PRODS Drill from 9917' 1.59/3580/100L w/ 100-300 psi dill, 1.5-2.5k wob w/ 12.35 ECD at 90 deg at 5900' TVD. Have apparently Printed: 1/3/2006 11:13:50 AM BP EXPLORATION Page 23 of 30 Operations Summary .Report Legal Well Name: 1 L-25 Common Wel! Name: 1 L-25 Spud Date: 11!25!2005 Event Name: REENTER+COMPLETE Start: 11/27/2005 End: 12/28/2005 Contractor Name: NORDIC CAUSTA Rig Release: 12/2812005 Rig Name: NORDIC 2 Rig Number: Date ,:..From>-To, Hours) Task ,Code;.!: NPT I Phase ~ Description of Operations 12/20/2005 104:25 - 06:00 I 1.581 DRILL I P I ~ PRODS crossed fault and into Bsiltstone/shale Begin climb towards 06:00 - 07:45 I 1.751 DRILL I P 07:45 - 11:00 i 3.251 DRILL I P 12:40 - 16:30 I 3.831 DRILL I P 16:30 - 18:25 1.92 DRILL P 18:25 - 19:15 0.83 DRILL P 19:15 - 19:30 0.25 DRILL P 19:30 - 19:40 0.17 DRILL P 19:40 -00:00 4.33 DRILL P 12/21/2005 00:00 -06:25 6.42 DRILL P 07:30 - 09: 0 I 2.00 I DRILL I P 09:30 - 11:00 I 1.501 DRILL I P 11:00 - 12:40 I 1.671 DRILL I P 12:40 - 13:00 0.33 DRILL P 13:00 - 13:35 0.58 DRILL P 13:35 - 14:40 1.08 DRILL P 14:40 - 15:20 0.67 DRILL P 15:20 - 15:45 0.42 DRILL P 15:45 - 16:15 0.50 DRILL P 16:15 - 16:35 0.33 DRILL P 16:35 - 17:05 0.50 DRILL N PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS STUC PRODS C4. Wiper trip to window. Hole smooth. Monitor TF at three open hole depths. Drill ahead from 10,000'. 3460 psi fs at 1.6 in/out. Continue to build angle to 95-96 deg inc. Wiper trip to window, clean PVT 439 Drill from 10150' (-5883' TVD) 1.65/3650/85L w/ 100-200 psi dill, 1-2k wob wl 12.46 ECD at 97 deg. Having to use -6k surface wt to get 2k to bit. Still in B siltstone Drill from 10262' (-5872' TVD) with slow progress (acts like siderite) and assume this is the top of the B. ROP increase in good sand at 10270' drilled to 10295' then back into slow drilling. Wiper to window Log tie-in +3.5' Wiper back to bottom. Setdowns in B shale at 9570' and 9620. Worked through each without much trouble but this is the first problems we've seen here. Directionally drill ahead f/ 10295' 1.58/3570120L 100psi MW 2k 'wob 5-10'/hr Continue drilling ahead iNout of Siderite stringers 1.59l3580l90L i2.4ppg EDC, 2K wob 5-10'lttr. Drill to 10398' Wiper to window was clean POOH circ thru EDC following pressure schedule. Wash TRSSSV and close w/ 900 psi LD drilling BHA. Change motor and bit, chk UQC. Motor was sli loose, bit was 2-2-I w/ wom cutters on taper RIH w/ BHA #25 circ thru EDC 0.5/2040 following pressure schedule. Open TRSSSV w/ 800 psi Log tie-in down from 8770', corr -4' Wiper in hole was clean to setdown at 9575' Attempt to ream conventional, but stalling and packing off. Wash thru at 1.0 bpm w/ 200 psi WHP to 9633' at 5'/min, but rough all the way. Backream 1.5/3420 slowly w/ packing off/MW and 5-12k overpulls to 9570'. Wash thru again at 1.0 bpm w/ 200 psi to 9670'. Backream at 10'/min and was clean until MW and 15k overpull at 9570'. RBIH at 1.0 bpm w/ 200 psi and was clean to set-down at 9723' PUH w/ 17k over and motor stalled. Got normal wt back, then backream OOH t0'lmin for 50', okay. RIH at full pump at 15'/min to set down at 9830'. PUH w/ motor stalled and 15k overputl. Wiper back to 9500' was not too bad RIH from 9500' 1.0/2830 w/ 250 psi whp (seem to need 12.4 ECD or better to keep B2 open) and get io 9813' relatively clean. Work to 9846' and set doom, still at 1.0 bpm. PUH w/ 12k over and slowly get normal wt back. Attempt to incr pump rate, but stalling and pulling heavier. Circ a10.9 bpm while PUH slow to 9800'. Incr pump to 1.5/3500 and PUH 10'/min while discuss-the 62 has fallen apart Circ fresh mud to bit while discuss plaNpoint to sidetrack Wiper to window while displace to fresh mud was clean At 8900' pulled fife and packed off. Can't go up or down. Printed: 1/3/2006 11:13:50 AM BP EXPLORATION Operations Summary Report Page 24 of 30 I Legal Well Name: 1 L-25 Common We11 Name: 1L-25 Spud Date: 11/25/2005 Event Name: REENTER+COMPLETE Start: 11/27/2005 End: 12!28/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase `Description of Operations 12/21/2005 16:35 - 17:05 0.50 DRILL N STUC PRODS Pump down CT at 0.5 bpml1800 and motor was not stalled. 17:05 - 17:30 I 0.421 DRILL I P 17:30 - 19:20 I 1.83 i DRILL I P 19:20 - 20:00 0.67 DRILL P 20:00 - 20:15 0.25 CASE P 20:15 - 20:45 0.50 CASE P 20:45 - 21:50 1.08 CASE P 21:50 - 23:50 I 2.001 CASE I P 23:50 - 00:00 I 0.171 CASE I P 112122/2005 ~ 00:00 - 01:30 1.50 ~ CASE ~ P 01:30 - 03:15 I 1.751 STKOH I P 03:15 -04:40 1.42 STKOH P 04:40 -04:55 0.25 STKOH P 04:55 - 05:20 0.42 STKOH P 05:20 - 06:00 0.67 STKOH P 06:00 -09:55 3.92 STKOH P 09:55 - 10:30 I 0.58 I STKOH I P 10:30 - 11:00 I 0.50 I STKOH I P 1 t :00 - 12:00 I 1.001 STKOH I P 12:00 - 13:45 I 1.75 I STKOH I P 13:45 - 14:20 I 0.58 I STKOH I P 14:20 - 14:45 I 0.42 I :STKOH I P Limit max pull to 25k initial. Work it various ways w/ no retums. Pressure well up to 800 psi, dump it while pulling a bind and came free at 35k PRODS Wiper up hole to 20' below window, wiper in hole to 8950'. Wiper up hole and thru window at 1.3/3700/30L taking retums w1300 psi and while finish displacement to new mud PRODS POOH circ thru EDC 1.9/3800. Wash up around SSSV at 1810' through opened EDC. PRODS LD BHA PRODS PJSM: Discuss plan foward for PU of liner and BHi tools. PRODS RU to run liner. PRODS PU 6 jts of solid, 4jts slotted 2-3/8" 4.2# STL liner and WF aluminum sidetrack billet. PU BHI tools. Stab injector. PRODS RIH open SSSV. Follow pressure schedule with opened EDC. ~ Weight check at window 19k Close EDC. RIH no problem at window, okay to 9830 at 100'/min. Wt check up 21 K. RIH to 9830'. Bring on pump to 1.3.4200 psi Pick-up to release GS. Up wt 18k. liner seems to have dropped off. TOL +/- 9492'. PRODS TOH following pressure schedule. The cased hole section and openhole below will now be referred to as L1-02 P61 PRODS Finish TOH. Observe well after closing SSSV. Hold PJSM review plan forward. PRODS UD WF and BHi tools. MU 1.9 deg motor and sidetrack bit.. Surface test tools. MU BHA #27. PRODS RIH open SSSV PRODS Log tie-in -5' correction. PRODS RIH 20L thru window no problem. RIH tagged billet at 9488'. PRODS Start sidetrack. From 9475' trough at 30R PRODS Park at 9488' for 5 min at 30R 1.5813650. Begin RIH 0.1'/min. Staffed at 9491.2'. PUH and ream back down. RIH from 9491.2' at 0.1'lmin. Stalled at 9503.4' twice and had 3k ° overpull, muse, muse. Continue RIH at 0.1'/min w/ no MW to 9531' and watch NB incl track old hole, bummer. Decide to find where it is PRODS PUH 19.5k to 9470', clean. RIH to 9521' at 30R, clean. Orient to 180 deg and red rate to 0.5/2340 w/ 500 psi whp. RIH and stack Sk from 9532'. PUH to 9490', orient to 90R {DTF). RIH 0.5/2460 and first wt loss at 9532'. Stack full wt and see 3.6k wob-no movement. Assume top of billet is here PRODS Run the numbers w/ the new targets and determine can still make it PRODS RIH and tag again at 9532' and stack full wt. PUH and park at 9531.0' for 5 min 1.57l3580/30R. Begin RIH at 0.1'/min to begin sidetrack PRODS 9536' No motor work so #ar, but getting more and smaller aluminum pieces over shaker PRODS No motor work by 9547'. NB incl shows we are still in the old twle. RIH at 1.0'lmin and stall at 9559'. PUH 20k and discuss. We must be in contact wJ the liner and are vibrating it down. Will run another billet on liner PRODS Wiper thru open hole was clean ~~ Printed: 1/3/2006 tt13:50AM w BP EXPLORATION -Page 25 of 30 Operations Summary Report Legal Well Name: 1 L-25 Common Well Name: 1 L-25 Spud Date: 11!25/2005 Event Name: REENTER+COMPLETE Start: 11/27/2005 End: 12/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28!2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours "Task Gode' NPT Phase Description of Operations 12/22/2005 14:45 - 16:45 2.00 STKOH P 16:45 - 17:30 ~ 0.751 STKOH ( P 17:30 - 18:00 0.50 STKOH P 18:00 - 18:10 0.17 STKOH P 18:10 - 19:40 1 1.501 STKOH I P 19:40 - 22:10 J 2.501 STKOH I P 22:10 - 22:30 f 0.33 ` STKOH P 22:30 - 00:00 I 1.501 STKOH I P 112/23!2005 100:00 - 00:15 I 0.25 I STKOH I P 00:15 - 01:55 I 1.671 STKOH I P Oi :55 - 03:30 1.58 STKOH P 03:30 - 03:45 0.25 STKOH P 03:45 -04:00 0.25 STKOH P 04:00 - 06:00 2.00 STKOH P 06:00 - 08:45 I 2.75 I STKOH I P 08:45 - 09:10 I 0.42 I STKOH I P 09:10 - 11:00 I 1.83 I STKOH I P 12:00 - 13:40 l 1.671 STKOH I P 13:40 - 13:55 I 0.25 ~ STKOH I P 13:55 - 14:15 0.33 STKOH P 14:15 - 15:25 I 1.171 STKOH I P PROD3 Open EDC. POOH for liner following pressure schedule 1.7/3340 PROD3 LD sidetrack assy and reconfigure. Grease injector PROD3 RU to run liner PROD3 PJSM: Review plan forward with liner running and safety concerns. PROD3 PU 8 jts 2-3/8" slottedlsolid liner and Weatherford aluminum billet. PU BHi tools. PROD3 RIH open SSSV continue RIH following pressure schedule. ' PROD3 Tagged TOL at 9559'. Pushed lower liner down to 9598'. Tagged and setdown several times stacking +/- 10k on it. Held good. PU wt 19.6k Bring pump up to 1 bpm. PU drop off liner pick-up wt 17.6k. TOL -9318'. PROD3 TOH following pressure schedule. Wash up on SSSV and close. PROD3 Finish TOH. Check well for flow. PJSM. Review next BHA change. PROD3 Changeout injector packoff while surface testing BHi tools. PU BHA #29 PROD3 RIH open SSSV continueRlH following pressure schedule. PROD3 Log tie-in -4.5' PROD3 Close ECD RIH 20L thru window. Tagged TOL at 9313'. PROD3 Pull up to 9308' and trough several times down to aluminum billet with 1508 TF. Start sidetrack drilling at 5'/hr 1.53/3500 1-2k WOB EDC 11.97ppg PROD3 Continue RIH at 0.1'/min 1.54/3450/1558 and had two stalls at 9315.0'. Ream back down from 9311' at 0.1'/min and continue RIH at 0.1'Jmin. WOB fell off from 1.5k to 0.3k at 9316.3'. Continue RIH 0.1'/min w/o MW or wt loss to 9330'. NB incl showed still in the old hole. Discuss. Will trip for a OH sidetrack bit PROD3 PUH and had 10k overpull w/ MW in the first 10' coming off bottom. Assume BHA was beside billet and vibrating liner(s) down the hole Wiper to window was clean. Open EDC PROD3 POOH circ thru EDC 1.8/3400 following pressure schedule. Close TRSSSV w/ 900 psi PROD3 Change bit, chk motor PROD3 RIH w! BHA #29 (1.9 deg motor w/ R60ST bit) following pressure schedule. Open TRSSSV w/ 800 psi PROD3 Log tie-in down from 8770', Corr -5' PROD3 RIH at 0.512320 w/ 400 psi whp thru open hole to wt loss at 9323' and stack full wt w/o movement. PUH w15k overpull. PUH 20', start pump 1.6/3680/1508 and RIH and tag billet at 9323' and stack 5k while stalling motor and shucking brass cap. Repeal just to be sure PROD3 Planning to use 9312' as KO point (same as prior run) so PUH to 9312' and then begin first backream pass to 9285' 1.65/3600/1508 at 2-3'/min w/ 10'/min down. Repeat at 8'/min both directions, then 5'lmin down, 4'/min down, 1'lmin down. Formation is real firm and not shaving much off. On last pass down, started taking wt and getting MW at 9292'. Couldn't Printed: 1/3/2006 11:13:50 AM BP EXPLORAT{ON Page 26 of 30 Operations Summary Repor# Legal Well Name: 1L-25 Common Well Name: 1 L-25 Spud Date: 11!25/2005 Event Name: REENTER+COMPLETE Start: 11!27/2005 End: 12/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase ;Description of`Operations 12/23/2005 14:15 - 15:25 1.17 STKOH P PRODS ream this clean after several tries so decide to use stall depth of 9294' as new KO point 15:25 - 15:50 0.42 STKOH P PRODS Begin troughing from 9294' to 9275'. Park at 9294' w/ 1558 for 5 min 15:50 - 22:00 6.17 STKOH P PRODS Begin sidetrack from 9294' 1.63/3550/1558 at 0.1'/5 min initially and slowly increase penetration rate to 6'/hr while steadily increasing WOB to 1 k at 9315'. NB inc showing good OHST. Drilled to 9325'. 22:00 - 22:30 0.50 STKOH P PRODS Backream with 1558 TF to 9270' at 2'/min 22:30 - 23:25 0.92 STKOH P PRODS Ream down to 9325' w/ 1558 10'lmin. Backream to 9270' w/ 908 TF at 2'/min. Ream down to 9325' w! i 558. Repeat backream w/ HS TF to 9290'. OHST will be called at 9295' with a 1558 exit. 23:25 -00:00 0.58 STKOH P PRODS TOH following pressure schedule. Hold "Table Top Spill Drill" 12/24/2005 00:00 - 01:30 1.50 STKOH P PRODS Finish TOH. 01:30 - 02:25 0.92 STKON P PRODS UO OHST SHA and PU .9deg motor and bi-center bit. 02:25 -04:00 1.58 DRILL P PRODS RIH to 8770' following pressure schedule. 04:00 - 04:15 0.25 DRILL P PRODS Log tie-in -6' correction. 04:15 -04:30 0.25 DRILL P PRODS RIH to bottom. No problems at OHST held TF at 1558. 04:30 - 06:00 1.50 DRILL P PRODS Directionally drill ahead f/ 9325' 1.59/3475/908 ann= 3636 ECD= 12.OOppg 1-2k wob 40-50'fir. Swapped to left at 9335' 06:00 - 08:20 2.33 DRILL P PRODS Drill from 9385' 1.57/3480/90L w/ 100-300 psi dill, 2-4k wob wl 12.03 ECD at 90 deg 08:20 - 09:10 0.83 DRILL P PRODS Wiper to window was clean both directions 09:10 - 12:15 3.08 DRILL P PRODS Drill from 9475' 1.6/3500/80L w/ 200-450 psi dill, 1.6-3.5k wob w/ 12.04 ECD at 90 deg at 5857' TVD. DriII to 9625' 12:15 - 13:05 0.83 DRILL P PRODS Wiper to window was clean both directions 13:05 - 16:30 3.42 DRILL P PR003 Drill from 9625' 1.5873520/908 w/ 200-400 psi dill, 1-3.5k wob w/ 12.20 ECD at 90 deg at 5862' TVD. Begin planned drop from 9650'. Drill to 9775' (5870 TVD) 16:30 - 17:10 0.67 DRILL P PRODS Wiper to window. Had 8k overpull at 9750', rest of hole was clean. PUH thru window 17:10 - 17:25 0.25 DRILL P PRODS Log tie-in down from 8770', corn +2' 17:25 - 18:35 1.17 DRILL P PRODS Wiper back to TD. No problems at 9741' which is start of 62 shale. 18:35 - 21:25 2.83 DRILL P PRODS Continue drilling ahead f/ 9775' 1.61/3550/90L 2-300psi MW 1-2k WOB 40-50'fir ann= 3749 ECD= 12.31ppg Seen fault at 9870'. ROP not significantly affected. 21:25 -22:30 1.08 DRILL P PRODS Wiper trip to to just below window. Minor over pulls 9745', 9450', 9375'. Same places took 2k wt loss while passing down through. 22:30 - 23:15 0.75 DRILL P PRODS Continue drilling ahead f/ 9927' 1.61/3500l345TF 1-2K wob 50'-60'/hr CTW neutral to +1k. Drilled to 9969'.. Seeing 150psi loss on pump pressure while on bottom. Off bottom 500psi. 23:15 - 23:30 0.25 DRILL N DPRB PRODS Reduce pump rate to 1.0 and TOH looking for washout or pinhole. At 9640' found pinhole. Shutdown pump/charge pump trap 700psi on well open Baker choke. Continue pulling coil putting pinhole on reel. Hole on underside of coil +/- .125" Line-up to pump down backside for coil displacement. No spill involved with this pinhole. 23:30 -00:00 0.50 DRILL N RREP PRODS Continue TOH filling hole down kill line. Maintaining 900 psi on well Printed: 1/3/2006 7 7:13:50 AM BP EXPLORATION Page 27 of 30 Operations Summary Report Legal Well Name: 1 L-25 Common Well Name: 1L-25 Spud Date: 11/25/2005 Event Name: REENTER+COMPLETE Start: 11/27/2005 End: 12/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task - Code NPT Phase Descrip#jon of Operations 12/24/2005 23:30 -00:00 0.50 DRILL N RREP PRODS Called AOGCC gave notice for early BOP test. 12/25!2005 00:00 - 02:00 2.00 DRILL N RREP PRODS Merry Christmas. Continue TOH. Close SSSV trapping 950psi on well. Pull to 190' bleed down well and monitor. tag up setback injector. 02:00 - 02:30 0.50 DRILL N RREP PRODS LD BHA 02:30 - 03:45 1.25 DRILL N RREP PRODS Circulate coil and rig-up for N2. Hold PJSM for N2. 03:45 -04:30 0.75 DRILL N RREP PRODS Slowdown reel with N2 to Tiger Tank. 04:30 -06:00 1.50 DRILL N RREP PRODS Make preparations to unstab coil from injector and secure to reel 06:00 -06:15 0.25 DRILL N RREP PRODS Safety mtg re: pull CT back to reel 06:15 - 12:00 5.75 DRILL N RREP PRODS Pull CT back to reel and secure Safety mtg re: SIMOPS Begin bi weekly ROPE test at 0715 hrs. AOGCC waived ~ witnessing RD hardline in reelhouse. Load out pinholed reel w/ 422k RF Load in new E-CT. RU hardline in reelhouse. Connect a-line Finish BOPE test 1145 hrs 12:00 - 18:00 I 6.00 DRILL N RREP PRODS Nordic crew change Safety mtg. Pull test internal grapple. Pull CT to injector and stab. Change packoff. Install temp CTC. Slack management, cut off 60' CT. Install CTC. MU BHi's UOC start dressing electrical connection. 18:00 - 18:30 0.50 DRILL N PRODS Noticed coil hadn't been circulated in 2 hrs. Tried but frozen up between floor and reel. Also short in E-line seen during Meg test. 18:30 - 18:45 0.25 DRILL N PRODS Hold PJSM on rig floor and go over plan forward and coil cutting procedures and hazards. Need to cut-off Kendal CTC and cut out frozen coil. 18:45 - 19:10 0.42 DRILL N PRODS Remove BHi's UQC and Kendal CTC. Cut 120' coil back to unfrozen mud. Secure 5' E-fine to side of injector and stab over bunghole. Circulate and warm coil. 19:10 - 21:00 1.83 DRILL N PRODS Install Kendal CTC. Pull test to 35K. Rewarm coil over bunghole. Make-up BHi's UQC. Meg test -good test.Circulate ' over bunghole. PT CTC to 3800psi held good. Circ over bunghole. PJSM review picking up BHA. 21:00 - 21:35 0.58 DRILL N PRODS MU BHA #31 stab on injector. Surface test tools -good. 21:35 - 23:15 1.67 DRfLL N PRODS RiH 23:15 - 23:30 0.25 DRILL N PRODS Log tie-in -2.5' 23:30 -00:00 0.50 DRILL N PRODS RIH. Problems at 9646' worked down to 9693'. 12/26/2005 00:00 - 01:35 1.58 DRILL N PRODS Continue to work back to bottom. PU to 9630' (19k) RIH clean to 9720" PU to 9650'. RIH clean to 9722 work down to 9727'. Sticky pickup to 9711' then clean to 9670 RIH clean to 9734, ratty to setdown at 9743. Pulled tight at 9733' work back up to 9711 then clean to 9680'. RIH to 9741 clean pu work dw to 9748. Putting tight off bottom. Work back down cleaned up at 9740' area. RIH to 9774'. PU overpuils to 9735' work back dw 10'/min to 9800' then setdown. PU fairly clean 2-3k over to 9720'. RIH clean to 9803'. Apply 200psi on WH. Work area slowly and slip past 9804` easily. Work dw 24'/min not pretty but going to 9883. PU clean. Work area gradually making headway. Work dw to TD 9969'. Take off 200 whp. 01:35 - 02:30 0.92 DRILL P PRODS Directionally drill ahead f/ 9969' 1.57/3640/15L Plan to drill 1 hr then make a wiper trip to window. Fair amount of black shale Printed: 1/3/2006 11:13:50 AM BP EXPLORATION Page 28 of 30 Operations Summary Report Legal Well Name: 1 L-25 Common Welf Name: 1 L-25 Spud Date: 11125/2005 Event Name: REENTER+COMPLETE Start: 11127/2005 End: 12/28!2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Mours Task Code NPT' Phase Description of Operations 12!26/2005 01:35 - 02:30 0.92 DRILL P PRODS coming over shakers. Call for trucks to do a mud swap. i-2k wob 40-50'/hr 300psi MW 02:30 - 03:15 0.75 DRILL P PRODS Wiper trip back to window. Pulled tight at 9721' RIH then back up again and clean. Briefly tight at 8910'? (BHA at bottom of window) 100psi extra MW to 8850'. 03:15 -04:00 0.75 DRILL P PRODS Wiper back to bottom with drilled TF's. Setdowns at 9660' PU and went thru. 9741' overpulls to 31 k work back to bottom. Hole cleaning up. No show stoppers yet. 04:00 - 05:50 1.83 DRILL P PRODS Continue to drill ahead f/ 10020' 1.53/3600/80L 1-2k wob 50-60'/hr neutral CTW 12.i7ppg ECD StarUfinish mud swap. Penetration rate erratic from 10050' 05:50 - 06:15 0.42 DRILL P PRODS Attempt to drill from 10080' 1.58/3660/80L w/ 12.17 ECD and have stacking wJ overpulls. Minor packing off 06:15 - 06:55 0.67 DRILL P PRODS Wiper to window 1.55/3650 w/ 12.0 ECD avg. Minor overpulfs 9740-9600'. Minor MW over same area, but at 9650' had high MW. Rest of hole was clean to 8950'. Slow to 10'/min and have minor overpuBs and 100 psi MW to 8850' 06:55 - 07:45 0.83 DRILL P PRODS Wiper back to TD 1.55/3730 w/ 12.3 ECD avg was clean to 9739'. Had set down w/ MW and overpull twice. Try it again w/ 1.1!3050 wf 200 psi whp wJ 12.5 ECD and was clean to TD except for TF change areas. Start stacking wt from 10078'-assume another shale or formation change 07:45 - 08:20 0.58 DRILL P PRODS Resume drilling 1.57/3750/90L w/ 0-250 psi dill, 1-2k wob w/ 12.29 ECD at 95 deg at 5875' TVD. Had penetration rate increase after getting by 10084'. Started losing 0.1 bpm at 10098' PVT 416.- 08:20 - 10:20 2.00 DRILL P PRODS Drill from 10100' and losses healed, but penetration becoming difficult. Lot's of stacking w/ short drilloffs w/ MW so assume formation change area. Penetration rate picked up at 10120' drilling w/ 6k neg surf wt w! 2k wob and able to drill in spurts up to 200'/hr-looks like C4 sand. ECD increased to 12.6 due to P rate. Drill to 10166' 10:20 - 10:40 0.33 DRILL P PRODS Wiper to 9900' was clean going up-hole, but had set downs at " 10036' and 10123' when RIH 10:40 - 12:15 1.58 DRILL P PRODS Drill from 10166' 1.56/3780/90-120L w/ 12.4 ECD. Drill to 10215' and stacking 12:15 - 13:10 0.92 DRILL P PRODS W iper to window was clean. Pu11 thru window 13:10 - 13:25 0.25 DRILL P PRODS Log tie-in down from 8770', corr +4' 13:25 - 14:20 0.92 DRILL P PRODS Wiper back to TD 1.53/3730 w/ 12.3 ECD. At 9500' induce +/-100 psi whp to keep ECD at 12.5-12.7 ppg to go thru 62 and was clean to TD. Bleed off whp 14:20 - 16:15 1.92 DRILL P PRODS Attempt to drill and have trouble getting wt to bit. Also, had sticky pickups. Do a couple 70' wipers wl TF 180 out and start drilling, but acts like siderite 16:15 - 18:00 1.75 DRILL P PRODS Drill from 10236' 1.63/3960/15L w/ 12.4 ECD in siderite 18:00.20:20 2.33 DRILL P PRODS Pick-up got the 'kinks' out of the coil. Rotated TF's 30 deg IefUright finally got some MW and WOB. Back to positive CTW. 1.53/3750/30L 1k wob still drilling siderite stringers and streaks of sand. 5-20'/hr but do have a weight transfer problem. Kicking idea around of pu Aggitator tool. Drilled to 10258'. Increase pump rate 1.7/4170/60L 12.5 20:20 - 20:40 0.33 DRILL P PRODS Make a BHA wiper trip. Tum TF to 15L 20:40 - 23:00 2.33 DRILL P PRODS Drill ahead. 1.74/4200/60L 1.2k wob <6'/hr. ROP progressively Painted: 1/3/2006 11:13:50 AM $P EXPLORATION Page 29 of 30 Operations Summary Report Legal Well Name: 1 L-25 Common Weli Name: 1L-25 Spud Date: 11125/2005 Event Name: REENTER+COMPLETE Start: 11/27/2005 End: 12/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: -.Date From - Ta Hours Task Code NPT Phase Description of Operations 12/26/2005 20:40 - 23:00 2.33 DRILL P PRODS slower even with 1.87k WOB. This is the house of pain. 23:00 - 00:00 1.00 DRILL P PRODS TOH. 18k off bottom. Hole in good shape coming out. 12/27/2005 00:00 - 02:00 2.00 DRILL P PRODS Continue TOH following pressure schedule. Close SSSV. Bleed-off well and monitor. Setback injector. 02:00 - 03:00 1.00 DRILL P PRODS PU Aggitator tool and new bit. Replace upper check vavles. 03:00 -04:45 1.75 DRILL P PRODS Surface test tools. RIH following pressure schedule after opening SSSV 04:45 - 05:00 0.25 DRILL P PRODS Log tie-in -5.5' 05:00 - 05:50 0.83 DRILL P PRODS Wiper to TD at normal pump rate and RIH speed. Set down w1 TF 180 out at 9871', but otherwise clean. Adding 100-200 psi induced whp to keep 12.5-12.7 ECD on B2 shales seems to work. Tag TD at 10276' w/ +2k string wt, bleed off whp 05:50 - 08:20 2.50 DRILL P PR003 Drill from 10276' 1.41/3980/60L w/ 100-150 psi dill, 2-3k wob! w/ 12.12 ECD at 91 deg at 5863' TVD. Still in siderite based I on intermittent penetration rate increases. Swap to right at 10294'? 08:20 - 10:10 1.83 DRILL P PRODS Drill from 10303' 1.41/4010/1058 w/ 100-150 psi dill, 2-3k wob w/ -6.4k surface wt at 12.15 ECD w1 steady (10'/hr) penetration rate. Inadvertently built angle quicker than expected to 95 deg, but may be helping get drilled out of the siderite 10:10 - 11:10 1.00 DRILL P PRODS Drill from 10320' 1.44/4050/1508 and have a few stalls, but then get into 30-40'/hr drilling w/ 12.16 ECD at 97 deg. gamma showing this might be the Kalubik sh. 11:10 - 12:50 1.67 DRILL P PRODS Wiper back into tbg. Collect samples. Give town the info. WOO. TD has been called here. ~- 12:50 - 13:05 0.25 DRILL P PRODS RIH to tie-in point. 13:05 - 13:20 0.25 DRILL P PRODS Log tie-in +1' correction. 13:20 - 14:25 1.08 DRILL P PRODS Wiper back in hole with as drilled TF's. Setdown at 9765' work through okay. Stop wiper at 10280' at the top of Kalubik shale. This is agreed upon bottom of liner depth. 14:25 - 17:00 2.58 DRILL P PRODS TOH. Minor overpull at 9650'. Paint EOP flag at 8650'. Confine TOH following pressure schedule. 17:00 - 18:30 1.50 DRILL P PRODS Lay down final drilling BHA. 18:30 - 18:45 0.25 CASE P RUNPRD PJSM Re: Running liner. Discuss hazards and mitigations. Review liner run order. Doug Walton with Baker TT here to run liner. 18:45 - 21:30 2.75 CASE P RUNPRD Make up liner as per plan. Liner BHA (Top-Bot): BTT Deployment slv. BTT Pup Jt. 5 jts Slotted 2-3/8' Lnr 8 jts Solid 2-3/8" Lnr 7 jts Slotted 2-3/8" Lnr 23 jts Solid 2-3l8" Lnr 5 jts Slotted 2-3/8" Lnr BTT Oring Sub 1 jt Solid 2-3/8" Pup jt BTT Round guide shoe Total BHA length=1557.68'. 21:30 - 22:30 1.00 CASE P RUNPRD Make up BHI MWD tool to top of liner. Service UQC. Stab injector. 22:30 - 00:00 1.50 CASE P RUNPRD RIH with liner BHA, following pressure schedule. 12/28/2005 00:00 -00:45 0.75 CASE RUNPRD Wt check at window = 20 klbs. RIH smooth thru the window. RIH wt = 80001bs. Holding 350 psi on WHP, circulating at printed: 1/3/2006 11:13:50 AM BP EXPLORATION Page 30 of 30 Operations Summary Report Legal WeII Name: 1 L-25 Common Weli Name: 1L-25 Spud Date: 11/25/2005 Event Name: REENTER+COMPLETE Start: 11/27/2005 End: 12!28/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date From '- To Hours Task.... Code NPT ' Phase Description of Operations 12/28/2005 00:00 -00:45 0.75 CASE RUNPRD minimum rate. 12.6 ppg ECD. 9300', 6900 Ibs string wt. Smooth thru the shale at 9765`. Set down and bounced thru at 9890'. Check flag on way past. Stop at 10280'. 00:45 - 00:55 0.17 CASE RUNPRD Shut the EDC. Current DHWOB=2000 tbs. Bring pumps on line to 1.35 bpm, 4200 psi circ pressure. PU at i70001bs string wt. DHWOB sensor at -200 Ibs. Confirmed released from liner. 00:55 - 01:30 0.58 CASE RUNPRD Keep pumps on. Log tie in pass accross GR character at 8600', then RIH and tag top of liner. Top of liner at 8713'. Pushed it down to the correct depth of 8722.34'. Bottom of liner now on depth at 10280'. PU at 17 klbs string wt, -240 Ibs DHWOB. Confirmed free of liner. 01:30 - 03:15 1.75 CASE RUNPRD POH. Pumping mud to keep hole full and following pressure schedule as we POH.. Freeze protect top 2000' with diesel on way OOH. 03:15 - 04:15 1.00 CASE RUNPRD Lay down liner running BHA. All liner running eq recovered ok. 04:15 -04:30 0.25 RIGD POST PJSM Re: SIMOPs. Several different rig down activities will be taking place on the rig for the rest of tower. Discuss with rig hands the activities, stress making sure chat you don't interfer with other operations taking place on the rig. 04:30 - 10:00 5.50 RIGD POST Nipple down tree,install cap and test to 5K. Clean mud pits. Rig Released at 1000 hrs 12-28-2005 10:00 - 10:30 0.50 RIGD POST Hold PJSM review procedures and hazards for movin rig off well. 10:30 - 11:00 0.50 DEMOS POST Jack-up rig and move off well. Clean up area around wellhead and cellar. Install warning sign of open mousehole. Last entry. Moving rig to 3H-14B expected time 12-16 hrs AOGCC alerted for pending BOP test on next well. Printed: 1!3!2006 11:13:50 AM ~onocoPhitlips ~ Baker Hughes INTEQ Baker Hughes INTEQ Survey Report 3 ~i Pf&~KER r-tu~l?~t~~ Company: ConocoPhillips Alaska, Inc. llate: 1 /1 112 0 0 6 Time: 16:49:31 Pahc 1 Fuld: Kuparuk River Unit Co-ordinate(NE) Reference. WeII. 25, True North Site: KRU 1 L Pad Vertical (TVD) Reference: slot 24 130.0 ~, Well: 25 Section (VS) Reference: Well (O.OON,O.OOE,85.OOAzi) ~; V1'ellpath: 1 L-25AL1-02PB1 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model : bggm2004 Site: KRU 1L Pad ' I Site Position: Northing: 5948968.90 ft Latitude: 70 16 17.459 N ' From: Map Easting: 540062.68 ft Longitude: 149 40 33.550 W i Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.31 deg Wel{: 25 Slot Name: i Well Position: +N/-S -596.97 ft Northing: 5948371.23 ft Latitude: 70 16 11.588 N +El-W -143.01 ft Easting : 539922.87 ft Longitude: 149 40 37.713 W Position Uncertainty: 0.00 ft Wellpath: 1L-25AL1-02PB1 Drilled From: 1L-25AL1-01 Tie-on Depth: 9359.82 ft Current Datum: slot 24 Height 130.00 ft Above System Datum: Mean Sea Level Magnetic Data: 12129!2005 Declination: 23.97 deg Field Strength: 57614 nT Mag Dip Angle: 80.72 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 85.00 Survey Program for Definitive Wellpath Date: 12129!2005 Validated: No Version: 1 Actual From To Survey Toolcode Too{ Name ft ft 100.00 8800.00 GYRO (100.00-9353.00) (0) Good gyro Good Gyro i 8834.00 8920.23 MWD (8834.00-11929.00) (5) MWD MWD -Standard 8938.00 9189.87 MWD (8938.00-9257.00) (2) MWD MWD -Standard 9210.00 9359.82 MWD (9210.00-9855.00) (6) MWD MWD -Standard I 9380.00 10397.00 MWD (9380.00-10397.00) MWD MWD -Standard J Annotafion J1D TVD I ft ft ~ 9359.82 5979.78 TIP 9380.00 5978.55 KOP 10397.00 5988.30 TD Survey: MWD Start Date: 12129/2005 Company: Baker I-fughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path ~ k. Conocal~hiliips Baker Hughes INTEQ ~ [14KE3t~ tiUG9~1E5 Baker Hu hes INTE Surve Re ort ----- -- g Q Y P I~ r tir~> r - _ __ _ _ _ _ _ _ _ - _ _ _ _ _ - -- _ _ _ _~ i Company: ConocoPhillips Alaska, Inc. Date: 1/11/2006 Time: 16:49:31 Page: 2 I Field: Kuparuk River Unit Co-ordina[c(NF) Reference: Well: 25, True North i Sitc: KRU 1L Pad Vertical (fVD) Reference: slot 24 130.0 Well: 25 Section (VS) Reference: Well (O.OON,O.OOE,85.OOAzi) Wcllpath: 1 L-25AL1-02P81 / Survev Calculation Method: Minimum Curvature Db: Oracle Survev Mll Incl Azim TVD 5S 'f VD N/S E/W ~tapN MapN; VS DLS 'fool ft deg deg ft ft ft ft ft ft ft deg/100ft 9359.82 95.09 73.69 5979.78 5849.78 -6236.51 1767.00 5942144.79 541722.74 1216.73 0.00 MWD .. 9380.00 91.93 69.50 5978.55 ~ 5848.55 -6230.16 1786.11 5942151.25 541741.81 1236.31 25.97 MWD 9424.27 81.78 62.61 5980.97 5850.97 -6212.26 1826.43 5942169.35 541782.04 1278.05 27.69 MWD 9459.01 82.52 57.18 5985.72 5855.72 -6195.01 1856.19 5942186.77 541811.71 1309.20 15.63 MWD 9487.49 82.46 52.70 5989.45 5859.45 -6178.79 1879.30 5942203.10 541834.72 1333.63 15.60 MWD 9516.52 83.83 53.09 5992.91 5862.91 -6161.40 1902.29 5942220.61 541857.62 1358.04 4.90 M W D 9545.37 83.80 56.68 5996.02 5866.02 -6144.91 1925.74 5942237.23 541880.98 1382.85 12.37 MWD 9578.46 83.30 60.09 5999.74 5869.74 -6127.67 1953.74 5942254.61 541908.89 1412.24 10.35 MWD 9608.82 82.47 63.79 6003.50 5873.50 -6113.50 1980.32 5942268.92 541935.39 1439.96 12.40 MWD 9638.50 81.30 67.42 6007.69 5877.69 -6101.37 2007.07 5942281.19 541962.07 1467.67 12.73 MWD 9667.45 80.82 69.73 6012.19 5882.19 -6090.92 2033.69 5942291.78 541988.63 1495.09 8.05 MWD 9703.60 80.94 74.07 6017.92 5887.92 -6079.84 2067.61 5942303.04 542022.49 1529.85 11.86 MWD 9734.00 81.89 76.83 6022.46 5892.46 -6072.29 2096.70 5942310.75 542051.54 1559.49 9.51 MWD 9768.82 84.73 79.59 6026.52 5896.52 -6065.22 2130.55 5942317.99 542085.34 1593.82 11.34 MWD 9800.81 87.34 80.86 6028.73 5898.73 -6059.81 2162.00 5942323.57 542116.76 1625.62 9.07 MWD 9830.72 89.28 82.04 6029.61 5899.61 -6055.36 2191.56 5942328.17 542146.30 1655.46 7.59 MWD 9860.60 89.52 85.89 6029.93 5899.93 -6052.22 2221.27 5942331.47 542175.98 1685.33 12.91 MWD 9890.31 91.30 89.06 6029.71 5899.71 -6050.91 2250.94 5942332.94 542205.65 1715.00 12.24 MWD 9920.57 91.34 86.28 6029.02 5899.02 -6049.68 2281.17 5942334.33 542235.86 1745.22 9.19 MWD 9954.83 90.69 83.49 6028.41 5898.41 -6046.63 2315.28 5942337.56 542269.96 1779.47 8.36 MWD 9984.48 92.44 80.63 6027.60 5897.60 -6042.54 2344.63 5942341.81 542299.28 1809.07 11.30 MWD 10016.17 93.09 77.24 6026.07 5896.07 -6036.46 2375.69 5942348.05 542330.31 1840.54 10.88 MWD 10050.60 96.20 76.26 6023.28 5893.28 -6028.60 2409.09 5942356.09 542363.66 1874.50 9.47 MWD 10085.29 96.26 73.60 6019.52 5889.52 -6019.63 2442.39 5942365.23 542396.90 1908.45 7.62 MWD 10116.20 95.00 71.03 6016.48 5886.48 -6010.29 2471.69 5942374.73 542426.16 1938.45 9.22 MWD 10155.98 95.46 68.40 6012.86 5882.86 -5996.56 2508.84 5942388.65 542463.23 1976.66 6.68 MWD 10184.64 97.01 67.45 6009.75 5879.75 -5985.85 2535.25 5942399.50 542489.57 2003.90 6.33 MWD 10215.87 97.25 64.79 6005.87 5875.87 -5973.31 2563.58 5942412.19 542517.84 2033.22 8.49 MWD 10247.90 97.59 62.09 6001.73 5871.73 -5959.11 2591.99 5942426.54 542546.17 2062.75 8.43 MWD 10277.23 97.06 59.70 5997.99 5867.99 -5944.96 2617.40 5942440.82 542571.50 2089.30 8.28 MWD 10309.91 92.66 54.41 5995.22 5865.22 -5927.26 2644.71 5942458.67 542598.71 2118.05 21.01 MWD 10342.23 94.67 52.68 5993.16 5863.16 -5908.09 2670.65 5942477.97 542624.55 2145.56 8.20 MWD .10397.00 95.50 48.00 5988.30 5858.30 -5873.29 2712.64 5942512.99 542666.35 2190.42 8.64 MWD ConocaPhil{ips Baker Hughes INTEQ ~ ~A,~~~ ~~,~~~~ Baker Hughes INTEQ Survey Reporti ~,1 f.+l ~~~~-~ ~ Company: ConocoPhillips Alaska, Inc. Date: 1/11/2006 'time: 16:51:08 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Refere nce: Well: 25, True North tine: KRU 1L Pad Vertical (fVD) Keferencr. slot 24 130.0 Well: 25 Section (V S) Reference: Well (O.OON,O.OOE,SS.OOAzi) ~Wcllpath: 1 L-25AL1-02 Survey Calculation Method: Minimum Curvature Dh: Oracle Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model : bggm2004 Site: KRU 1 L Pad Site Position: Northing: 5948968.90 ft Latitude: 70 16 17.459 N From: Map Easting: 540062.68 ft Longitude: 149 40 33.550 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0:31 deg Well: 25 Slot Name: Well Position: +N/-S -596.97 ft Northing: 5948371.23 ft Latitude: 70 16 11.588 N +E/-W -143.01 ft Easting : 539922.87 ft Longitude: 149 40 37.713 W Position Uncertainty: 0.00 ft Wellpath: 1L-25AL1-02 Drilled From: 1L-25AL1-01 Tie-on Depth: 9267.87 ft Current Datum: slot 24 Height 130.00 ft Above System Datum: Mean Sea Leve{ Magnetic Data: 12/29/2005 Declination: 23.97 deg Field Strength: 57614 nT Mag Dip Angle: 80.72 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 85.00 Survey Program for Definitive Wellpath Date: 12!29/2005 Validated: No Version: 3 Actual From To Survey Toolcode Tool Name ft ft 100.00 8800.00 GYRO (100.00-9353.00) (0) Good gyro Good Gyro 8834.00 8920.23 MWD (8834.00-11929.00) (5) MWD MWD -Standard 8938.00 9189.87 MWD (8938.00-9257.00) (2) MWD MWD -Standard 9210.00 9267.87 MWD (9210.00-9855.00) (6) MWD MWD -Standard 9295.00 10374.00 MWD (9295.00-10374.00) MWD MWD -Standard Annotation r _ _ _ - - .- - - -- - - --- ~9D TVD - - _ -_ - - - - ~ ft ft 9267.87 5989.07 TIP 9295.00 5986.85 KOP 10374.00 5983.14 TD Survey: MWD Start Date: 12!29!2005 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path .~ ConocoPhillips Baker Hughes INTEQ Baker Hughes INTEQ Survey Report ~~ BAK~it NtJ!G~1ES t ~, ~ f~:~~ -,,, i Company: ConocoPhillips Alaska, Inc. Field: Kuparuk River Unit Site: KRU 1L Pad i ~Vcll: 25 Wcllpath: 1L-25AL1_02 Survey Date: 1!11(2006 Time: 16:51:08 Page: 2 Co-ordinate(NE) Reference: Well: 25, True North Vertical (TVD) Reference: slot 24 130.0 Section (VS) Reference: Well (O.OON,O.OOE,85.OOAzi) Survey Calculation Vlcthod: Minimum Curvature Db: Oracle ~; - ~1U _ ...Inc! _ Azim IV'll _`;S'1'VD _. V/S ft deg deg ft ft ft 9267.87 92.91 91.02 5989.07 5859.07 -6248.32 9295.00 96.49 86.32 5986.85 5856.85 -6247.70 9325.35 89.12 96.63 5985.36 5855.36 -6248.49 9355.04 88.78 89.87 5985.90 5855.90 -6250.17 9406.42 87.86 85.84 5987.41 5857.41 -6248.25 9438.06 88.29 78.44 5988.48 5858.48 -6243.93 9470.81 87.83 72.36 5989.59 5859.59 -6235.68 9501.60 87.40 67.29 5990.87 5860.87 -6225.07 9530.01 88.78 63.83 5991.81 5861.81 -6213.33 9573.84 89.28 58.03 5992.56 5862.56 -6192.04 9602.63 90.41 61.35 5992.64 5862.64 -6177.52 9636.64 90.32 68.20 5992.42 5862.42 -6163.03 9667.62 88.94 72.13 5992.62 5862.62 -6152.52 9710.26 85.90 81.36 5994.54 5864.54 -6142.76 9741.11 82.31 81.22 5997.71 5867.71 -6138.12 9776.05 80.84 85.91 6002.83 5872.83 -6134.24 9806.72 81.04 92.96 6007.67 5877.67 -6133.94 9838.03 80.48 93.50 6012.69 5882.69 -6135.68 9868.28 84.51 90.03 6016.65 5886.65 -6136.60 9899.36 88.05 86.58 6018.66 5888.66 -6135.68 9931.15 90.66 84.01 6019.02 5889.02 -6133.08 9965.99 93.80 78.05 6017.66 5887.66 -6127.65 9997.06 95.96 74.36 6015.02 5885.02 -6120.28 10028.48 96.73 69.82 6011.55 5881.55 -6110.68 10058.42 95.40 64.80 6008.38 5878.38 -6099.19 10093.88 96.36 59.64 6004.75 5874.75 -6082.76 10130.42 95.44 52.22 6000.98 5870.98 -6062.41 10159.89 95.10 48.95 5998.28 5868.28 -6043.78 10193.35 93.64 42.19 5995.72 5865.72 -6020.44 10222.76 91.12 35.66 5994.50 5864.50 -5997.59 I, 10253.88 92.60 31.22 5993.49 5863.49 -5971.65 10284.48 95.21 27.63 5991.41 5861.41 -5945.06 10314.20 97.54 28.53 5988.11 5858.11 -5919.01 ~ ~ 10374.00 92.00 29.07 5983.14 - 5853.14 -5866.80 El~V ft 1676.66 1703.68 1733.92 1763.54 1814.85 1846.16 1877.82 1906.68 1932.53 1970.81 1995.67 2026.41 2055.55 2096.96 2127.29 2161.62 2i 91.89 2222.74 2252.71 2283.70 2315.37 2349.74 2379.80 2409.51 2436.96 2468.16 2498.25 2520.91 2544.72 2563.17 2580.31 2595.30 2609.21 2637.90 ylapN - i\1apE - ft ft 5942132.50 541632.48 5942133.27 541659.49 5942132.64 541689.73 5942131.12 541719.36 5942133.31 541770.66 5942137.80 541801.93 5942146.21 541833.54 5942156.97 541862.35 5942168.85 541888.13 5942190.34 541926.30 5942204.99 541951.07 5942219.64 541981.74 5942230.30 542010.81 5942240.28 542052.17 5942245.09 542082.47 5942249.14 542116.78 5942249.60 542147.04 5942248.03 542177.90 5942247.27 542207.87 5942248.35 542238.85 5942251.12 542270.51 5942256.73 542304.84 5942264.26 542334.86 5942274.02 542364.51 5942285.65 542391.91 5942302.24 542423.01 5942322.75 542452.99 5942341.50 542475.55 5942364.96 542499.23 5942387.91 542517.56 5942413.94 542534.56 5942440.60 542549.41 5942466.73 542563.17 5942519.08 ~ 542591.59 VS DLS Tool ft deg/100ft _. - __- 1125.70 0.00 MWD 1152.68 21.73 MWD 1182.73 41.70 MWD 1212.09 22.79 M W D 1263.38 8.04 M W D 1294.94 23.41 MWD 1327.20 18.61 MWD 1356.88 16.51 MWD 1383.65 13.11 MWD 1423.64 13.28 MWD 1449.67 12.18 MWD 1481.56 20.14 MWD 1511.50 13.44 MWD 1553.60 22.77 M W D 1584.22 11.65 MWD 1618.76 13.93 MWD 1648.94 22.71 MWD 1679.52 2.47 M W D 1709.29 17.51 MWD 1740.25 15.89 MWD 1772.03 11.52 M W D 1806.74 19.32 MWD 1837.33 13.72 MWD 1867.76 14.57 M W D 1896.11 17.25 M W D 1928.62 14.73 MWD 1960.37 20.35 MWD 1984.57 11.11 MWD 2010.32 20.61 MWD 2030.69 23.78 MWD 2050.03 15.03 M W D 2067.28 14.48 MWD 2083.40 8.40 MWD 2116.54 9.31 MWD w KRU 1L-25A, AL1-01, end AL1-02 Producer C-sand CTD Completion DEV 10/21/05 9-5/8" 36# J-55 casing ~ 4978' 2-3/8" liner top ~ 8720' MD Window in 7" Top of Cement KOP at 8838' MD i L-25A western lateral TD: 11929' and H. 3-Yz" Camco TROP•4A-RO SSSV set at 1810 RKB, ^e.813" ID E. 3-V2" 9.3# J-55 EUE 8rd Mod tubing w/ 34/2" x 1" Camcc 'KBUG' mandrels D. Camco 3-1 /2" MMG gaslift mandrel a[ 8629 RKB C. Baker 3-t /2" HB packer at 8692 RKB B. 3-%z" Camco D nipple with 2.75" ID a[ 87()8 RKB A. 3.1 /2" tubing tail at 8742 RKB Aluminum billet @ //~ '~ C-sand perfs 8941' and / Top of billet 1 ?::;L1t7~1'ttiz at 9380' C-sand perfs ............ ............. ConocoPhillips Alaska, Inc. 1L-25AL1-01 TD: 9,855' 1L-25AL1-02 TD:10,374' 2-3/8" slotted liner 7" 26# J-55 ~ 933t' MD OHST at 9295' 2-3/8" blank liner across shale sections • • • Alaska ®il and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 Phone: (907) 279-1433 Fax: (907) 276-7542 Fax Transmission The information contained in this fax is confidential and/or privileged This fax is intended to be reviewed initially by only the individual named below. If the reader of this transmittal page is not the intended recipient or a representative of the intended recipient, you are hereby notified that any review, dissemination or copying of this fax or the information contained herein is prohibited. if you have received this fax in error, please immediately notify the sender by telephone and return this fax to the sender at the above address. Thank you. .--, To: ~~-Z_ -~. -{ ~ ~~ t= ti. ~ Fax #: From: ~'?4`~ ~~f~~.- ; %~`~t'~-a lr,.~~~ Phone #: Subject: Message: Date: / i ~i ~- /C?~ Pages (including cover sheet): n ~..~"_ ~-~c~- ,~~`,Z~-C ~ ~ ,,r.~ /l~~c~ _--------- . ~ .G-ter-- G «~~~- ~ c ~~ If you do not receive alf the pages or have any problems with this fax, please call far assistance at (907) 793-1223. 5~. ~~ i~ ~ 5~ ~ ~I }, ~,~ ~31 I~ ~ ~ s~ ~~ i i 1 ~ i ~ ~~ ~~ i; ~~ ~ ~ , ~A5SA OII, ~-I1TD GAS COIITSERQA~'IOi~ COl-i1~IISSIOI~ Sean McLaughlin CT Drilling Engineer ConocoPhillips Alaska Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 FAX (907) 276-7542 Re: Kuparuk 1 L-25AL 1-02 ConocoPhillips Alaska Inc. Permit No: 205-178 Surface Location: 597' FNL, 143' FEL, SEC. 31, T11N, R10E, UM Bottomhole Location: 842' FNL, 2856' FWL, SEC. 05, T l ON, R 10E, UM Dear Mr. McLaughlin: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager) . DATED this/~ day of November, 2005 ~ FRANK H. MURKOWSKI, GOVERNOR r 3 /~ 9 ~' 333 W. 7`" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 cc: Department of Fish & Game. Habitat Section w/o encl. STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COM~SION PERMIT TO DRILL 20 AAC 25.005 ~,..~. c`~g ia. Type of work ~ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ®Development Oil ^ Multiple Zone ^ Stratigraphic Test ^ Service ^Development Gas ^ Single Zone 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180 ~ 11. Well Name and Number: Kuparuk 1 L-25AL1-02 3. Address: Go P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: , MD 10800 ' TVD 5847ss 12. Field /Pool(s): Kuparuk River Unit /Kuparuk 4a. Location of Well (Governmental Section): Surface: 597' FNL 143' FEL SEC 31 T11N R10E UM 7. Property Designation: ADL 025664 ' River Pool , , . , , , Top of Productive Horizon: 1292' FNL, 1284' FWL, SEC. 05, T10N, R10E, UM 8. Land Use Permit: 13. Approximate Spud Date: November 20, 2005 Total Depth: 842' FNL, 2856' FWL, SEC. 05, T10N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 10250' 4b. Location of We11 (State Base Plane Coordinates): Surface: x- 539925 - 5948371 ' Zone- ASP4 10. KB Elevation (Height above GL): 130' feet is. Distance to Nearest Well Within Pool 1 L-26A is offset by 730' ~ 16. Deviated Wells: Kickoff Depth: 9350 'feet Maximum Hole Angle: 95 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3600 ' Surface: 30i 6 - 18. mg rogram: Size Specifications Setting Depth To Bottom uant~ty o ement c.f. or sacks Hote Casin Wei ht Grade Cou lin Len th MD TVD. MD TV 5 ~ ~'+°y includin sta a data 3" 2-3l8" 4.6# L-80 STL 400' 10400; 5861' 10800'. 5847% Uncemented Slotted Liner t9. PRESENT W ELL CONDITION SUMM ARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): 11600 Total Depth TVD (ft): 5870 Plugs (measured): None Effective Depth MD (ft): 11600 Effective Depth TVD (ft): 5870 Junk (measured): None Casin Len h Size Cement Volume MD TVD r C r 122' 16" 35 sx Arcticset I 122' 122' 4978' 9-5/8" 00 sx Permafrost 'E', 550 sx Class 'G' 4978' 3614' r i n 933i' 7" 50 sx Class 'G' 9331' 6293' Liner 1 L-25A 2665' 2-3/8" Uncemented Slotted Liner 8935' - 11600' 5907' - 5870' Liner iL-25AL1-01 400' 2-3/8" Uncemented Slotted Liner 9350' - 9750' 5847' - 5840' Perforation Depth MD (ft): None Perforation Depth TVD (ft): None 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564-x387 Printed Name Sean McLaughlin Title CT DriNing Engineer Preparetl By Name/NUmber. Si nature .e/ LC.--°- Phone 564-4387 Date I ~ 7 o Terrie Hubble, 564-x628 Commission Use Only Permit To Drill Number: ZL>S'-- /'7g API Number: 50- 029-22174-62-00 Permit Approval. Date: ; > i~ ~+s'~ See cover letter for other requirements Conditions of Approval: Samples Required `~ Yes '~No Mud Log Required ^ Yes ~No Hydr Sulfide Measures Yes ^ No ~Dijrectional Survey Required Yes ^ No Other: ~JS~ o .sv-~~~'~ES~' ~~~tfc.~''Ki~Q~ \ ~~D`~ ~~ ~D~ R{~~-a1-~. O 3 5 ~.~~ a ~ , ;~ ~ APPROVED BY ~ f A roved ~ ~~+ ~` ' ~ ~ ~'~,' i ~ THE COMMISSION Date (/ ~!1 Form 10-401~(evised Ob,i2864 - ` ~_ ' "" Stfbmit~(n Duplicate KRU 1L-25~4i L1-01, AL1-02, and AL1 Sidetrack oiled Tubing Drilling Summary of Operations: A coiled tubing drilling unit will dri114 laterals in producer KRU 1L-25 using the managed pressure drilling tec~t pique~MPD, see description below). These horizontal laterals will target Kuparuk C sand reserves for CTD Drill and Complete 1L-25A, ALl-Ol, ALl-02, and ALl grogram: Planned for November 20 2005 Pre-Rig Work 1. Positive pressure and drawdown tests on MV and SV 2. Test Packoffs - T&IC 3. Dummy GLV's 4. MIT-IA, MIT-OA ~~^~ 5. Caliper 3-1/2" liner / 6. Cement 7" casing in preparation for a cement ramp exit 7. MIRU Nordic 2. NU 7-1/16" BOPE, test 1L-25A 8. Mill 2.74" window off a cement ramp. Plan the top of ramp to start at 8838'. 9. Drill 3" bicenter hole horizontal lateral from window to 11600' TD targeting Kuparuk C sands. l0. Complete with a 2 segmented 2 318" slotted liner from TD to 8935' md. An aluminum billet will be on top of the second liner to use as a KOP for L1-Ol . Use SSSV for liner run. 1 L-25AL 1-01 11. Mill 2.74" window off the aluminum billet at 8935'. 12. Drill 3" bicenter hole horizontal lateral from window to 9750' TD targeting Kuparuk A sands. . Comp a liner from TD, to 9350'. Use SSSV for liner run. IL-25AL 1-02 -- ~ `~~ ~~~ l4. Mi112.74" window off the aluminum billet at 9350'. ~ ~ , 15. Drill 3" bicenter hole horizontal lateral from window to 10800' TD targeting Kuparuk A sands. 16. Complete with 2 3!8" slotted liner from TD, to 10400'. Use SSSV for liner run. `~ ~ 4 .~. 1 L-25AL 1 17. Mi112.74" window off the aluminum billet at 10400'. 18. Drill 3" bicenter hole horizontal lateral to 11600' targeting Kuparuk A sands. 19. Complete with 2 segmented 2 3/8" slotted liner from TD, to 8720'. Use SSSV for liner run. 20. ND BOPE. RDMO Nordic 2. Post Rig work 21. Post CTD rig -Run GLVs. Mud Program: • Step 8: chloride-based biozan brine (8.6 ppg) • Steps 9-20: chloride-based Flo-Pro (8.6 ppg) ~ Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. ~ KRU 1L-25~-L1-01, AL1-02, and AL1 Sidetrack oiled Tubing Drilling Casing Program: • l L-25A: 2 3/8", 4.6#, L-80, STL slotted liner from 8935' and to 11600' and • 1L-25AL1-O1: 2 3/8", 4.6#, L-80, STL slotted.liner from 9350' and to 9750' and • 1L-25AL1-02: 2 318", 4.6#, L-80, STL slotted liner from 10400' and to 10800' and ' • IL-25AL1: 2 3/8", 4.6#, L-80, STL slotted liner from 8720' and to 11b00' and CasinE/Liner Information 9 5/8", J-55, 36#, Burst 3520; collapse 2020 psi. 7", J-55, 26#, Burst 4140; collapse 2900 psi 3'/i", J-55, 9.3#, Burst 6990; collapse 7400 psi Well Control: • Two well bore volumes (-200 bbls) of KWF will be location during drilling operations. • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan for 1L-25A, AL1-Ol, AL1-02, AL1 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • The nearest well to 1L-25A is 1L-26A which is offset by 2625'. KPA boundary is 11000' away. • The nearest well to 1L-23AL1-01, ALl-02, and ALl is also ll~-2~iA which is offset by 730'. KPA boundary is 10250' away. Logging ~ • MWD directional and Gamma Ray will be run over all of the open hole section. Hazards • 1L-25A lateral will cross one mapped faults. Lost circulation risk is moderate. • 1L-25AL1-O1 and AL}-0Z"~vilf'f'D at a mapped fault. ' • 1 L-25AL 1 will cross 2 mapped faults • Expect to encounter increasing pressure as lateral is drilled away from the mother well. • Weli 1L-29 has recorded 250 ppm H2S. All H2S monitoring equipment will be operational. Reservoir Pressure • The most recent SBHP survey (9/05) was gauged at 3470 psi after a long term shut-in. The max. expected pressure is 3600 psi: The EMW is 11.9 ppg at 5840''TVD (AL1-Ol TD). Max. surface pressure with gas (0.1 psi/ft) to surface is 3016 psi. Variance request • BPXA requests a variance to the provisions of 20 AAC 25.036 (d)(4) THROUGH TUBING DRILLING AND COMPLETION. This is regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes. The variance will not apply when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) While drilling 1L-25 it will be routine to close the 2-3/8" combi rams (pipe/slip) on the BHA during deployment and undeployment. These activities will not compromise the integrity of the BOP equipment. Managed Pressure Drilling Managed pressure drilling techniques will be employed to provide constant bottom hole pressure by using ~ 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability Applying annular friction KRU iL-25Al~AL1-01, AL1-02, and AL1 Sidetrack oiled Tubing Drilling and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses andlor fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be installed between the BOPS choke manifolding and the mud pits and }vill be independent of the BOPE choke. This well has a tubing retrievable sub-surface safety valve that will be utilized to facilitate BHA deployments and liner running. However, it is still possible that deployment of the BHA under trapped wellhead pressure would be necessary. Pressure deployment of the BHA will be accomplished utilizing the BOP pipe/slips (2- 3/8" rams, see attached BOP configuration). The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at the 1L-25A TD• ` • Estimated reservoir pressure: 3470 psi at 5870' TVD, 11.4 ppg EMW. ~(~~ • ~=-~j~~~ `4 ~~ w~°~' ~'~~~~ • Expected annular friction losses while circulating: 1044 psi (based on 90 psi/1000 ft) ,~ X' "~~~ • Planned mud density: 8.6 ppg equates to 2625 psi hydrostatic bottom hole pressure. • While circulating 8.6 ppg fluid, bottom hole circulating pressure is estimated to be 3669 psi or 12.0 ppg ECD i • When circulation is stopped, a minimum of 1044 psi surface pressure will be applied to maintain constant BHP. • ConocoPhillips Alaska, Inc. KRU 1 L-25 1 L-25 API: 500292217400 WeII T INJ An le TS: 51 d 8840 sssv SSSV Type: TRDP Orig Com 5!31!1991 Angle @ TD: 50 deg ~ 9353 (t810-181~~ - Annular Fluid: Last W/O: 8/26/1992 Rev Reason: TAG FILL oo.3.soo) Reference Ref L Date: Last U e: 2!27/2004 Last T : 9093 TD: 93531UC8 Last T Date: 2/23/2004 Max Hole le: 54 7100 Casa SM -A LL STRING S Oescri n Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 78 78 62.50 H-40 SUR. CASING 9.625 0 4978 3614 36.00 J-55 PROD. CASING 7.000 0 9331 6293 26.00 J-55 Tubin Strin -TUBING Sbe T Bottom TVD Wt Grade Thread 3.500 0 8742 5915 9.30 J-55 EUE 8R0 AB MOD Pertorations Su mma Interval ND Zone Status Ft SPF Date T Comment 8838 -8840 5976 - 5977 2 6 2/22/1992 RPERF 21/8" na Stri ' 0 h 8840 -8870 5977 - 5996 C-4 30 10 3/4/1993 RPERF 2 1/8" Scaibp Gun U; 0 deg. ph; Oriented 180 deg. F/ low Side 8870 -8872 5996 - 5997 C-4 2 4 3/4/1993 RPERF 21/8" Scallop Gun U; 0 deg. ph; Oriented 180 deg. F/ Low Side 9039 -9065 6104 - 6121 A-5 26 4 6/16/1991 IPERF 4.5" Carrier 180 9138 - 9159 6168 - 6182 A-4 21 4 6/16/1991 IPERF 4.5" Carver 180 Gas Lift Ma ndr elsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2316 1905 Camco KBUG DMY 1.0 BK2 0.000 0 4/11!1993 2 3729 2809 Camco KBUG DMY 1.0 BK2 0.000 0 9/16/1994 3 4627 3391 Camco KBUG DMY 1.0 8K2 0.000 0 8!2611992 4 5434 3905 Camco KBUG DMY 1.0 BK2 0.000 0 8/26/1992 5 6240 4395 Camco KBUG DMY 1.0 BK 0.000 0 9/16/1994 6 7076 4896 Camco KBUG DMY 1.0 BK2 0.000 0 8/2611992 7 7910 5397 Camco KBUG DMY 1.0 BK2 0.000 0 8/26/1992 8 8629 5844 Camco MMG-2 DMY 1.5 RK 0.000 0 9/18/1994 Oth er s ui .etc. -JEWELRY De TVD T Descri lion ID 181 0 1582 SSSV Cartx:o TRDP-4A-RO' 2.813 8678 5875 PBR Baker 3.000 8692 5884 PKR Baker'HB' 2.890 i 8708 5894 NIP Camrw'D' Ni le NO GO 2.750 8741 5914 SOS Baker 2.992 8742 5915 TTL 2.992 ~ General Notes PaR Date Note (867&$879, OQ~3 500) 3/21/1993 COUk1 not get t0 bottom w/ 1175" CTU; successful Go Vvitll 1/5" CTU ' See WSR 3/15/93 PKR (8692-8693, i, 00:6.156) I ~ NIP (8708.8709, OD:3 500) . TUBING (0.8742, OD:3.500, x:2.992) Perf (8838.8870) Pert (8838.8870) i Pert (9039.9065) i~ Perf (9138-9159) KRU 1 L-25A & L1 Producer Proposed C-sand CTD Completion DEV 10/21!05 ConocoPhillips Alaska, Inc. H. 3•'~S" Camco TRDP-4A-RO SSSV set at 1810' RKB, 2.813" IO E. 3•fr'2" 9.3A J-gg El1E Std Mod tubing wi 3•irt" x t" Camco 'KBUG' mandrels 9518" ]~ J.SS casing ~ 4978' • D. Carnet 312' MMQ gasllft rnarxltel at 8829' RKB 2~, litter ~ (~ C. Baker 3112` FIB packer at 8892' RKB .t-8720' MD B. 3•sL" Camco D rtipple with 2.75' ID at 8708' RKB Window in 7" A 3-iC2" tubing tall at 87x7 RKB Top of :~~~• / ._r.`• ~i~'Yi Cement KOP al `•~ // ..:c~:`•~•`::%:'i +/•8838' MD _ i :................. 1 L-25A S,vestem lateral TD (~ 11600' and Aluminum billet 8935' and _ 500' stub liners (2-318" slotted) w/ C-sand perfs ' alum^um billet KO C-sand perfs 1 L-25AL 1-01 1L-25/0.1.1 ~I.1 eastern lateral TD Ccil 11600' and 2-318" sbtted liner ~, ~~-~ ® ~:~~>:> ~#~'>~~-::~:s~ 2-3/8" blank liner across 9331' MO shale sections LEGEND T Plan: Plan NB (25/Plan B, 1L-25AL7)-pZ B P Amoco 25 fL-2s) Azimuths to True North - - ~~~^ - 2s~Plane,fL-25ALf11 M Magnetic North: 24.04° cleemaeyeaMialallNOn Dale:,vvzoo6 6AKER 2s Plan B, 7L-25AL1-0 `~ - 25 PIanS. 1L-25A) Ma netic Field WELLPRTN DETPILS HUGNE9 ~1~ - pii 66~1L-25AL1 Shength: 57608nT `-O''tact nfc~.macon A &II Michaelson pen B. 1L25aL1 Dip ogle: 80.72° Direct. (901)267~'i624 Paren Twel~ ~: ]~:~ ssnL]o2 11 ,1 ~.(? ModeB~bggm2004 Cell- (907) 301-79570. E-mail' bdl.mlchaelson coley cnm R Rel. Oeurn 1p1 510125 130.OOR bq V_ ~e ~IL-5 ~E!-W Frpn ND I >5.00' 0.00 0.00 0.00 ', _ _ .I I ~ t .. REFERENCE INFORMATION 3~0 ~ I { I~ II1~ ' I I ~ ~ 1 ( i _ 1 i l~ Coortlinale ((WE) Reference: Well Centre: 25, True NaM I ~ I i ~._ ~ _ ~ ~ i T.. Fa . I • 1L-25AL1 Ta t 9 Veracal (TVD) Reference Syysl~m: Mean Sea Level .4600 '-r 7 ', Section (VS) Reference Sbl - (O.OON,O.OOE) I 1 i i ~ 1 . 1 ~ II MeasureC Depth Reference. ebt 25 130.00 1. _ . ~ ~ ~ I { , ~ I , .i Celwlaf9ln McMOd M,Mmum D9rvature ~~O '„ { I _ ~I I !I TroN OETmLS ~. ~ I , { I I. I r ~ ~ I ` Sec ~ 6TV0 .F1W 0uq V9c Tr°°t : I I i I I ,,.s ], -5000. ~:~ i 860 ] 30.0040 8000 12~_N 1 4 ~ r ~ • ! ~ , TD iie6 se. x: m:~ .sa ', : f +11 l}-~ ~ e °~ne o;.~ iiai ;] , ~ -s200 ~ I , - I ~ S I . 't` , I ~~.,~`~ I'7 ,L-25AL; Ta et7 1 i ti- i ~ '-+' 1L-25ALf Ta 19 t6 rtsm ai ie i6uPo w» 6z xs]966 tt. w. xl.zsr W _5400 ., ~.~ l , i i . ~ 1 ! I 1 ' l I ~~ .+. 25 PIa19 1L-25ALf-02 7 I I I 1 6 PNNOTRT ONS r • 0 5600 -1 ~ 1+ i h 1 1Y` - - - ' ' 5 rvD MD w,eoleu°~ "' • ~. ]..°. lVt 1 t l • t 1 I se ]o.oo.oo AL+3Q am"`ri°r°.?]°' r ~ ron~m~ -5800 + ~ r r. r ~ 1 3 SBB el 105x0.00 ]~ 20%100 DLS ~ r . ]6°.a0 1]lfl ]sN> wM ° + ~ I I i ', 1L-25AL1 P 5Be°.9. tDeeo aD . a~`iitr~e ee ~ l .T~--.-.; I ; ~ I .. ' ~: F1M 20'1100'DL ~ ~, SBIx.)11OI.O.OO 5 ~135u~r~9e] ]lOm ae.Om mss ab.° 5980.52 10936.8 8 y-/ -6~0 ~~ 1 I 58>2.6110926..9 L I ~I-j~~ Tie to lL-25RL1-02 { 5868.95 11051..8 9 ~ I i i ; II ' 5858.91 11251 68 T O :. {. ~ t~l ~~ } ! 58.3.981180000 D Z -6200 r I 1~ ~ ' ~ . I .. i I , I ; { , . ~ . j 25 ~en8 1L-25AL71H I ^-6400 ~ 1- .-I-, . i .. L - ,~ .• ~ I~ ~~.. 257E-25 : 4900: '. ~ -6600 I+~I I ~ I ~ I I , I i ..: i .. 1.: 5000 1. , 1 ,. ~ ` -6800 ~ ~ i. _. ~ '} a .~ I 4 , `-{ T.-. I. I 1 I f 1 ~ - ! .. ! I ~ . ~ ~ ~ ; _ ~I ,.T I Dlr.:: i-~~ ~. r~ 5100 , ~ ~ -7000 ~, t I ( ~`•, - - • ~ u ' ~~ 25 RanS iL-25A I ; I I I ~ ~ i I I ~ j 5200: ~ ~ - T -7200 '. , . r l 1 ! 1 -,. 1 r +. - r-~ - I I . II I C 5300 ' , a ~ -7400 ' { '~-` 4 ~~ '.f - + - 1 ~ + ~ r+ ~ ~-+'-`-'--~---=+-t -+ - . • I I I I .. I f I~ i I w , ~ ,I, ;';;i .•; 1 ; 1 ~ , I , i _; i :~ l : 1 ~ '~~ o saoo :. 1 r+ -7soo - - . X5500 ~ + I( :..; .. ., ... L 1 1200-1000 -800 600 -400 200 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 p-ssoo ' ~+ I• West(-)/East(+) [200ftlin] ~;1 cow s7oo I ' 25 PIanB 1L-25AL1-02 -I ~ ~ i , V 5800 :. 25 Bans 1L-254 251PIan8 7L-25AL1-01 - 1L-254Lf T 8 TD - ` _ I ~ 1 i I 1 ~L 9 '. 1L-25AL7 Te t9 i- ,1 I-~1 5900 3 6 5 B ~7 9 ;:~' -1 ~; _ EnD 20°Har DL 1L-25AL7 Ta 17 - I I-~ _ ~ I , ~ I { 'i ' ~ 6000. , l j I I I `+"' ~"_``I , I i { ~ I, r i i~ }-! 1 ~ -- i 1 ~ t I I -Ill I i +~ I-w-t~ r+.-; 1 ~ 11~ 6100 --+~, t ', :. ~ ~ ~ T r L I ~ - jl-- I - 111 ~ - l II 1~ 1 ~' -: i I I I I ~II ~ I.I I- l I I II' I~ 1' (( FFF 1 ~{ 25 1L-25 ~. j « 6200 ~ }' l l 1 . ._ , ~ i _' T I I . t T ~.I `r { + r '-"+~ t + rt F. '.1 I! ~ _ i I ) I I1, ... 1 I I ~ 1 -.I '- II ~ 1- ~ 1. - (I i I~ tt 'I I f ~ 1}- I t t-r 7 { 6300: I. ~ 1, !~ I' .- -~- --`°'- -+~+ + .- + ti 1~.._rr ~rl.._: ~ 1 .~I ~ .I ~. II !~ .1 , ~~ i t .,~ II I III i 1 ~ ~ { ., 1 I~:+ 6400 ~', .. ~. .. ... .. .. -. .... ..., , ~~-400 -300 ~-200 -100 0 100 200 300 400 500 ~~ ~ ~ ~ ~~ 200 1300 1400 1500 1600 1700 00 2000 2100 2200 2 500 2600 2700 2800 2900 3000 31~ -600 -500 600 700 800 900 1000 1100 1 1800 19 300 2400 2 00 3200 Vertical Section at 75.00° [100ft/in] PM • ConocoPhill~ps Baker Hughes INTEQ ~~ Baker Hughes INTEQ Planning Report IINTE(;~ Company: ConocoPhillips Alaska, Inc. Date:: 11/1/2005. Time: 1533:28 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 25, True North Site: KRU 1 L Pad Vertical (1'VD) Reference: slot 25 1'30.0 Well: 25 Section (VS) Reference: Well (O.OON,O.OOE,75.OOAzi) Wel(pathc Plan 6, 1L-25AL1-02 Survey Calculation Method: Minimum Gunrature Db: Oracle Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: KRU 1 L Pad Site Position: Northing: 5948968. 90 ft Latitude: 70 16 17.459 N From: Map Easting: 540062. 68 ft Longitude: 149 40 33.550 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.31 deg Well: 25 Slot Name: Well Position: +N/-S -596.97 ft Northing: 5948371 .23 ft Latitude: 70 16 11.568 N +E/-W -143.01 ft Easting : 539922. 87 ft Longitude: 149 40 37.713 W Position Uncertainty: 0.00 ft Wellpath: Plan 6, 1L-25AL1-02 Drilled From: Plan 6, 1L-25AL1-01 Tie-on Depth: 9350.00 ft Current Datum: slot 25 H eight 130.00 ft Above System Datum: Mean Sea Level Magnetic Data: 11!1!2005 Declination: 24.04 deg Field Strength: 57608 nT Mag Dip Angle: 80.72 deg Vertical Section: Depth From (TVD) +N!-S +E!-W Direction ft ft ft deg 0.00 0.00 0.00 75.00 Plan: Plan #6 Date Composed: 11/1/2005 Copy Lamar's plan 6 Version: 5 Principal: Yes Tied-to: From: Definitive Path Targets `Map '..Map <- Latitude. -> <- Longitude -> .Name Description TVD +N/-S +E/-W Northing .:Easting Deg-Min Sec Deg Min Sec Dip. 'Dir. ft ft ft ft ft 1L-25AL1-02 Fault! 130.00 -5918.41 2163.88 5942464.96 542117.89 70 15 13.377 N 149 39 34.771 W -Polygon 1 130.00 -5918.41 2163.88 5942464.96 542117.89 70 15 13.377 N 149 39 34.771 W -Polygon 2 130.00 -6118.43 2162.81 5942264.96 542117.89 70 15 11.410 N 149 39 34.804 W -Polygon 3 130.00 -6318.45 2161.75 5942064.96 542117.89 70 15 9.443 N 149 39 34.836 W 1L-25AL1-02 Fault2 130.00 -5356.79 2997.96 5943030.94 542948.90 70 15 18.898 N 149 39 10.503 W -Polygon 1 130.00 -5356.79 2997.96 5943030.94 542948.90 70 15 18.898 N 149 39 10.503 W -Polygon 2 130.00 -5556.81 2996.90 5942830.94 542948.90 70 15 16.931 N 149 39 10.537 W -Polygon 3 130.00 -5756.82 2995.84 5942630.94 542948.90 70 15 14.963 N 149 39 10.570 W 1L-25AL1 Target 11 5977.00 -5523.93 3020.07 5942863.94 542971.90 70 15 17.254 N 149 39 9.862 W 1L-25AL1 Target6 5986.00 -5727.79 2802.96 5942658.95 542755.89 70 15 15.250 N 149 39 16.180 W 1L-25AL1 Targets 6010.00 -5996.62 2389.48 5942387.95 542343.89 70 15 12.607 N 149 39 28.209 W 1 L-25AL1 Target 4 6035.00 -6142.42 2160.68 5942240.96 542115.88 70 15 11.174 N 149 39 34.866 W Annotation MD "TVD ft ft 9350.00 5977.21 Tie to 1L-25AL1-01 9370.00 5976.27 End 20°1100' DLS 9425.00 5975.67 3 9583.00 6000.35 4 9765.58 6024.21 5 '-~' • ~ w ConocoPhillips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report INTEQ Company: ConocoPhillips Alaska, Inc. Date: ' 11/112005. Time: 15:33:28 Page: 2 ~I Field: Kupanik River Unit Co-ordinate(NE) Reference: Well: 25, True North Site: KRU 1L Pad Vertical ('f VD) Reference: .slot 25 130.0 We1L• '' 25 Section (VS) Reference: Well (O.OON,O.OOE,75.OOAzi) Wellpath: Plan 6, 1 L-25AL1-02 Survey Calculation Method: Minimum Curvature Db: Oracte J Annotation - - MD TVD ft ft, - ~ 10005.58 6010.57 6 10205.58 6000.19 7 10530.58 5985.07 8 10800.00 0.00 TD Plan Section Information MD Iacl Azim TVD +N/-S +E!-W DLS Build ' Turn TFO Target ft deg ° deg ft ft ft deg/100ft deg/100ft degl100ft deg - -- 9350.00 94.56 83.72 - 5977.21 - -6211.37 1797.86 0.00 0.00 0.00 0.00 9370.00 90.80 82.35 5976.27 -6208.95 1817.68 20.00 -18 .80 -6.84 200.00 9425.00 90.45 75.76 5975.67 -6198.51 1871.65 12.00 -0 .64 -11.98 267.00 9583.00 71.49 75.76 6000.35 -6160.31 2022.21 12.00 -12 .00 0.00 180.00 9765.58 93.40 75.76 6024.21 -6116.08 2196.58 12.00 12 .00 0.00 0.00 10005.58 92.98 46.92 6010.57 -6002.36 2404.62 12.00 -0. 18 -12.02 270.00 10205.58 92.88 70.95 6000.19 -5900.06 2574.46 12.00 -0. 05 12.02 89.60 10530.58 92.24 31.92 5985.07 -5701.55 2823.40 12.00 -0. 20 -12.01 270.00 10800.00 91.09 64.24 5977.02 -5524.03 3021.14 12.00 -0 .43 12.00 91.50 Survey MD Incl Azim SS TVD N/S F./W MapN MnpE DLS VS TFO Tool ~ ft deg deg ft ft "ft ft ft degllOOft ff ---- deg - ~ --- ~ 9350.00 9370.00 94.56 90.80 83.72 82.35 5847.21 5846.27 -6211.37 -6208.95 1797.86 1817.68 5942170.10 5942172.62 541753.46 541773.27 0.00 20.00 128.98 148.75 0.00 200.00 MWD MWD 9375.00 90.77 81.76 5846.20 -6208.25 1822.63 5942173.34 541778.22 12.00 153.71 267.00 MWD 9400.00 90.61 78.76 5845.90 -6204.02 1847.27 5942177.70 541802.83 12.00 178.60 266.99 MWD 9425.00 90.45 75.76 5845.67 -6198.51 1871.65 5942183.34 541827.18 12.00 203.58 266.96 MWD 9450.00 87.45 75.76 5846.13 -6192.37 1895.88 5942189.62 541851.37 12.00 228.57 180.00 MWD 9475.00 84.45 75.76 5847.89 -6186.24 1920.04 5942195.87 541875.50 12.00 253.50 180.00 MWD 9500.00 81.45 75.76 5850.96 -6180.13 1944.09 5942202.10 541899.52 12.00 278.31 180.00 MWD 9525.00 78.45 75.76 5855.32 -6174.08 1967.95 5942208.28 541923.34 12.00 302.92 180.00 MWD 9528.32 78.05 75.76 5856.00 -6173.28 1971.10 5942209.10 541926.48 12.00 306.17 180.00 1 L-25AL 9550.00 75.45 75.76 5860.97 -6168.09 1991.55 5942214.39 541946.91 12.00 327.27 180.00 MWD 9575.00 72.45 75.76 5867.88 -6162.19 2014.84 5942220.42 541970.16 12.00 351.29 180.00 MWD 9583.00 71.49 75.76 5870.35 -6160.31 2022.21 5942222.33 541977.52 12.00 358.90 180.00 MWD 9600.00 73.53 75.76 5875.46 -6156.33 2037.93 5942226.40 541993.21 12.00 375.11 0.00 MWD 9617.03 75.57 75.76 5880.00 -6152.29 2053.84 5942230.53 542009.10 12.00 391.53 0.00 1 L-25AL 9625.00 76.53 75.76 5881.92 -6150.39 2061.33 5942232.47 542016.59 12.00 399.26 360.00 MWD 9650.00 79.53 75.76 5887.10 -6144.37 2085.04 5942238.61 542040.26 12.00 423.71 0.00 MWD 9675.00 82.53 75.76 5891.00 -6138.30 2108.97 5942244.80 542064.15 12.00 448.40 0.00 MWD 9700.00 85.53 75.76 5893.60 -6132.19 2133.07 5942251.04 542088.22 12.00 473.26 0.00 MWD 9725.00 88.53 75.76 5894.90 -6126.05 2157.26 5942257.31 542112.38 12.00 498.22 0.00 MWD 9750.00 91.53 75.76 5894.88 -6119.90 2181.49 5942263.59 542136.57 12.00 523.21 0.00 MWD 9765.58 93.40 75.76 5894.21 -6116.08 2196.58 5942267.49 542151.63 12.00 538.77 0.00 MWD 9775.00 93.40 74.63 5893.65 -6113.67 2205.67 5942269.94 542160.72 12.00 548.18 270.00 MWD 9800.00 93.39 71.63 5892.17 -6106.43 2229.55 5942277.31 542184.55 12.00 573.12 269.93 MWD 9825.00 93.37 68.62 5890.70 -6097.95 2253.02 5942285.92 542207.97 12.00 597.98 269.75 MWD 9850.00 93.35 65.62 5889.23 -6088.24 2276.01 5942295.74 542230.91 12.00 622.70 269.58 MWD 9875.00 93.31 62.61 5887.78 -6077.35 2298.46 5942306.76 542253.30 12.00 647.21 269.40 MWD 9900.00 93.27 59.61 5886.34 -6065.29 2320.31 5942318.93 542275.08 12.00 671.43 269.23 MWD 9925.00 93.21 56.60 5884.93 -6052.10 2341.50 5942332.23 542296.20 12.00 695.31 269.05 MWD 9950.00 93.15 53.60 5883.54 -6037.82 2361.97 5942346.61 542316.59 12.00 718.78 268.88 MWD 9975.00 93.08 50.59 5882.19 -6022.49 2381.66 5942362.05 542336.20 12.00 741.77 268.72 MWD 10000.00 93.00 47.59 5880.86 -6006.14 2400.53 5942378.49 542354.98 12.00 764.23 268.55 MWD 10005.58 92.98 46.92 5880.57 -6002.36 2404.62 5942382.30 542359.05 12.00 769.16 268.40 MWD 10025.00 92.99 49.26 5879.56 -5989.41 2419.05 5942395.33 542373.41 12.00 786.45 89.60 MWD ConocoPhillips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report • ^ ~nT~ ' Company: ConocoPhillips Alaska, Inc. Date: . 11!1!2005 Time: 15:33'28 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 25, True North ~ Site: KR U i L Pad Vertical (TVD) Reference: slot 25130.0 i ..Weil: 25 Section (VS) Reference:. Well (O.OON, O.OOE,75. OOAzi) t Wellpath: Plan 6, 1L-25AL1-02 Survey CalculaNoo Method: Minimum Curvature _ Db_ Oracle Survey - MD Inc! Azim SS TVD N/S E/W MapN MapE DLS VS TFO T 0 1 ft deg ..deg ft ft ft` ft ft deg/f00ft ft deg 10050.00 93.00 52.26 5878.25 -5973.62 2438.38 5942411.22 542392.66 12.00 809.21 89.72 MWD 10075.00 93.01 55.26 5876.94 -5958.86 2458.52 5942426.08 542412.71 12.00 832.48 89.88 MWD 10100.00 93.00 58.27 5875.63 -5945.18 2479.40 5942439.87 542433.52 12.00 856.19 90.04 MWD 10125.00 92.99 61.27 5874.32 -5932.61 2500.97 5942452.55 542455.02 12.00 880.28 90.19 MWD 10150.00 92.96 64.28 5873.03 -5921.19 2523.16 5942464.09 542477.15 12.00 904.67 90.35 MWD 10175.00 92.93 67.28 5871.74 -5910.95 2545.93 5942474.45 542499.86 12.00 929.31 90.51 MWD 10200.00 92.89 70.28 5870.47 -5901.91 2569.20 5942483.61 542523.08 12.00 954.13 90.66 MWD 10205.58 92.88 70.95 5870.19 -5900.06 2574.46 5942485.49 542528.33 12.00 959.69 90.81 MWD 10225.00 92.88 68.62 5869.21 -5893.36 2592.66 5942492.28 542546.49 12.00 979.00 270.00 MWD 10250.00 92.87 65.62 5867.96 -5883.65 2615.66 5942502.11 542569.44 12.00 1003.73 269.88 MWD 10275.00 92.85 62.61 5866.71 -5872.75 2638.12 5942513.13 542591.84 12.00 1028.25 269.73 MWD 10300.00 92.83 59.61 5865.47 -5860.69 2659.98 5942525.31 542613.63 12.00 1052.49 269.58 MWD 10325.00 92.79 56.60 5864.24 -5847.50 2681.18 5942538.61 542634.76 12.00 1076.38 269.43 MWD 10350.00 92.75 53.60 5863.03 -5833.21 2701.66 5942553.00 542655.16 12.00 1099.85 269.29 MWD 10375.00 92.70 50.60 5861.84 -5817.88 2721.36 5942568.44 542674.78 12.00 1122.85 269.14 MWD 10400.00 92.65 47.60 5860.68 ~ -5801.53 2740.23 5942584.89 542693.56 12.00 1145.31 269.00 MWD 10425.00 92.58 44.59 5859.53 -5784.21 2758.22 5942602.30 542711.46 12.00 1167.17 268.86 MWD 10450.00 92.51 41.59 5858.42 -5765.97 2775.28 5942620.62 542728.42 12.00 1188.37 268.72 MWD 10475.00 92.44 38.59 5857.34 -5746.87 2791.37 5942639.81 542744.40 12.00 1208.85 268.59 MWD 10500.00 92.35 35.59 5856.30 -5726.95 2806.43 5942659.81 542759.35 12.00 1228.56 268.46 MWD 10525.00 92.26 32.59 5855.29 -5706.26 2820.43 5942680.57 542773.24 12.00 1247.43 268.33 MWD 10530.58 92.24 31.92 5855.07 -5701.55 2823.40 5942685.30 542776.19 12.00 1251.53 268.21 MWD 10550.00 92.18 34.25 5854.32 -5685.29 2833.99 5942701.61 542786.69 12.00 1265.97 91.50 MWD 10575.00 92.09 37.25 5853.39 -5665.01 2848.59 5942721.96 542801.18 12.00 1285.31 91.59 MWD 10600.00 92.00 40.25 5852.50 -5645.53 2864.22 5942741.53 542816.71 12.00 1305.46 91.70 MWD 10625.00 91.90 43.25 5851.65 -5626.89 2880.86 5942760.25 542833.25 12.00 1326.35 91.81 MWD 10650.00 91,80 46.25 5850.84 -5609.15 2898.45 5942778.08 542850.74 12.00 1347.93 91.91 MWD 10675.00 91.69 49.25 5850.08 -5592.35 2916.94 5942794.98 542869.14 12.00 1370.14 92.01 MWD 10700.00 91.58 52.25 5849.36 -5576.54 2936.29 5942810.89 542888.41 12.00 1392.93 92.10 MWD 10725.00 91.46 55.25 5848.70 -5561.76 2956.45 5942825.77 542908.48 12.00 1416.22 92.19 MWD 10750.00 91.34 58.25 5848.09 -5548.06 2977.34 5942839.58 542929.30 12.00 1439.95 92.26 MWD 10775.00 91.22 61.24 5847.53 -5535.47 2998.93 5942852.29 542950.82 12.00 1464.06 92.34 MWD / 10800.00 91.09 64.24 5847.02 ~ -5524.03 3021.14 5942863.85 542972.97 12.00 1488.48 92.41 MWD • • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/pARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /~~u /L -ZS~I ~/^ ~~ PTD# 21~s! / ~~ CHECK WHAT I ADD-ONS "CLUE" APPLIES ~ (OPTIONS) MULTI The permit is for a new well yore segment of ~ LATERAL existing well k~~~. ~~-"_2 ~ ~j ~°=S=i~S API No. ~"t' ~`~ -Z21 ~j-© Permit No, L'' . (If API number Production should continue to be reported as 'last two (2) digits a function of .the original API number stated are between 60-69) ,above. PILOT HOLE In accordance with 20 AAC 25.005(fj, all (per I records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) i and API number (50 - ~ 70180) from records, data and togs acquired for well (name on permit). SPACL'~iG ~ The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Apgroval to perforate and groduce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Comuany Name) assumes the liability of any protest to the spacing j exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE `Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 C\jodyltransmittal_checklist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RV OIL - 490100 -Well Name: KUPARUK RIV UNIT 1L-25AL1-02 Program DEV Well bore see ^~ PTD#:2051780 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType DEV I PEND _GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Permitfeeattached____-_.__ _. -____:_-_-_--____-_- _.----NA-_ -___._Multilate[al_wellbore~f_eewaiYed-per20-AAC25.005(a)__.______-_-__________________ 2 Lease number appropriate___________________-_-____________ ____ Yes_ ___ - - - 3 Uniquewell-name and number________________________________ ______ Yea_ -_-------._--.____-. ------------------------------------------------------ 4 Well located in a_defined,pool- - - - - - - - - - - - - - - - - - - - - - - - - - -Yea _ . - - KUPARUK RIVER,_KUPARUK RVOIL-49Q100, governed by Conservation Order No. 4320._ _ - - - - _ - _ - 5 Well Igcaled proper distance from drilling unitboundary- - - - - . - - - - - - - - - - -Yes - . - - -Conservation Older No. 4320 contains no spacing restrictions with respe~ t4 drilling unit boundaries. . _ . _ _ 6 Well located proper distance from other wells- _ - Yes - - - . -Conservation Order No.,432C has no interweH_s acin -restrictions, _ - _ - - - A 9 - 7 Sufficient acreage ayaila4le in dril_linq unit- - _ - _ - _ _ Yes - - . - - -Conservation Order No. 4320 has no interwell-spacing_restrictions, Wellbore-will be.more than 500' from - - - - 8 If_deviated, is-wellbore plat_included . _ - _ _ - - _ - _ - _ _ - - - - Yes - - - - - . an external property line_whe[e_o_wnership or_lan_downersh~ changes. _ - ---------------------- 9 Operator only affectedparty__- -_----------- ------------- -- --Yes- ----.-- _----- 10 Operator has appropriate-bondinforce--- ------ -- - ---------- -----Yes- - ---- -- ---------- - ------- ------ ---------- -- -- ----- - --- 11 Permit-cat~beissued without conservationorder______________________ _____ Yes- -__-_.--_-.--- ---_- Appr Date 12 Permit_canbeissuedwithoutadministrative_appr_opal_________ _________ __ ___Yes- -_-_-_-_-_-_-__.---_-__-_.--_, - - - SFD 11!1412005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and-strata authorizedbglnjectionO[de[#(putlO#in_comments).(For-NA__ __-___-_-__--_-__.-.-_.-__--_--_-_--_---_-_._--__.-_----___----- 15 All wells within 114_mile area of review identified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ - - - - _ _ _ _ _ _ - - - 16 Pte-produced injector; duration-of pre production less than 3 months(For service we ll-Only) _ NA_ _ - _ - - 17 ACMP-Finding of Consistency_hasbeenissued_forthisproject--__--------- ------NA__ ___-_._______-_______.__-__-_____-_-_. ------------------------------ Engineering 18 Canductorstring_provided _ - . _ - _ - . ... - NA_ ConductorsQt_in motherbore,_1L-25-(191-070)_ .. - _ - - 19 Surface casingprotectsall_knownUSDWs___.___-- -_.-_____ -.-._-NA__ -_-__Allaquifersexempted,49CFR147.102(b)_(3).___-___-____________ _______________ 20 CMT-vol adequate-to circulate_on conductor & surf csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ Surface casing set in-motherbore. _ _ - _ - _ - _ _ _ - - _ - _ - _ - - _ - 21 CMT_vol_adequate-to tie-in long string to surfcsg__-_- _____-__._..__ --_._.NA__ _-__Production_casingset in_motherbore._____________________ ______________-__-_-- 22 CMT_will coverall know_n_productive horizons- - _ - - _ _ - _ - _ . _ _ - _ - .. - - No_ - _ _ _ _ - _ $lotte_d.finer completion pl_anned._ _ - _ _ _ - _ - - .. _ _ . - - . _ . - _ _ - - - - - - . - . 23 Casing designs adequate for G, T, B &_permafrost -- - - - - - - - - - - - - - - - - - - - - NA_ - - - . - Original well_tubulars_ met design_requirements. _NA for slotted liner. - . - - - .. - .... - - . - . - . - - . 24 Adequate tankage-or reserve pit . - - _ - _ Yes - - - - - -Rig is-equipped with steel_pits. No r_ese_rve_pitplanned, All was to apprgv_ed di_sposal_wells- - - - - - - - - - - - - 25 If a_re-drill, has_a 10-403 for abandonment been approved - - - - - - - - - - - - - - - - -Yes - - _ 305,248,_processed 11108!05. _ , - _ - - - _ - 26 Adequate wellbore separation_proposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - _ _ _ - _ Proximity- analysis performed: Nearest well section-is L1.01. branch and paths diverge.- - - _ - _ _ - _ _ - _ _ - _ - _ 27 Ifdive[terrequired,doesitmeetregulations____-_,__.__________ -_--_ NA_- ____-BOp_stackwillalreadybein-place.-______________________-_--____________-_-. Appr Date 28 Drilling fluid-program schematic & equip listadequate_ - - - - - - - _ _ _ _ - - -Yes . - - - - . Maximum expectedformation pressure 11.9 EMW. Managed pressure dril(ing_planned, W18,6_ppg fluid and-applie- TEM 11!18/2005 29 BOPEs, do they meet regulation - _ - _ - - - _ - . Yes - - . - pressure via fric#ion or trapped pressure. -2_well volumes of kill weight fluid ayailabie on-location. - _ _ - ~/^ ~ , A r r 30 BO_PE-press rating appropriate; test to-(put prig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes . _ _ _ - _ _ MASP calculated at 3Q16psi, 3500_psi_minimum BOP test, _ - _ _ _ _ _ _ - - _ _ . _ _ _ - _ - _ _ - _ _ _ - - _ . - _ - L / ~`i ~/~/~ 31 Choke-manifold complieswlAPI-RP-53 (May84)______________________ __ ___Yes_ -_--_----_-________-__-____- / 32 Work will occur Without operation shutdown _ _ Yes _ _ _ _ _ _ _ _ _ _ 33 Is presence_of H2S gas probable - - - - - - -- - - - - - - - - - - - - - - .Yes . - _ - - - Up to 250 ppm H2S reported on 1L pad. Mud should preclude H2S on rig. -Rig hassensors_and alarms. - _ - 34 Mechanical condition of wells Within AQR yenfied (For service well onyx - - _ _ - - - - _ NA_ - _ - _ . - _ _ - - Geology 35 Permit can be issued w/o hydrogen_sulfidemeosures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ Concentrations up to_250 ppm H2S have been measured on 1 L-Pad_wells._ H2S. measures required.- _ - _ 36 Data_presented on-potential overpressure zones _ - - - _ - _ - - - - _ .Yes - - - - Expected reservoirpressure is 11.4-11.9ppg EMW, will be drilled with coiled_tubing and 13,6_ppg mud - _ - - _ Appr Date 37 Seismic analysis o-f shallow gas zones- - - - - - - - - - - - - - - - - - - - - - - - - - NA- - _ _ _ _ -using overbalanced pressure drilling_techniques_t4ochieve 12.0 ppg_equivalent circulating density. SFD- SFD 11!14!2005 38 Seabed condition survey-(if off-shore) _ . - _ - - NA- - - - 39 Contact namelphone_fcr weekly progress,reports (exploratory only)- _ - _ - NA_ _ - - - - Geologic Engineering Publ' Date: Date Date This will be a "spoke" multilateral well bore drilled from the KRU 1L-25AL1 multilateral. SFD Commissioner: Co Commissioner: • s • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Welf Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. **** REEL HEADER **** MWD 07/07/12 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/12/27 1025231 01 2.375 CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWZS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 8840.8000: Starting Depth 5TOP.FT 10374.0000: Ending Depth 5TEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska Inc. WELL. WELL: 1L-25AL1-02 FLD FIELD: Kuparuk River Unit LOC LOCATION: 70 deg 16' 11.588"N 149 deg 40' 33.550"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375 CTK DATE. LOG DATE: 27-Dec-05 API API NUMBER: 50029221746200 Parameter Information Block #MNEM.UNIT Value Description #--------- --------------- ---------- SECT. 31 Section TOWN.N 11N Township RANG. l0E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 130.0 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 130.0 Elevation of Kelly Bushing EDF .F N/A Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks ~5 - r~~'~ Nsa~ss- • (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4} Baker Hughes INTEQ utilized CoilTrak downhole tools and the advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, and Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Directional, Outer Downhole Pressure, and Downhole Weight on Bit), a and Gamma Sub, and a Hydraulic Orienting Sub with a near Bit Inclination Sensor. (6) Data presented here is final and has not been depth adjusted to a PDC (Primary Depth Control) log. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (7) The sidetrack was drilled from 1L-25 through a milled window in 7" liner: Top of Window 8837.6 ft.MD (5845.3 ft.SSTVD) Bottom of window 8840.8 ft.MD (5847.3 ft.SSTVD) (8) The interval from 10337 ft.MD to 10374 ft.MD (5855.4 ft.to 5853.0 ft.SSTVD) was not logged due to bit to sensor offset at TD. (9) Tied to 1L-25 at 8758 ft.MD (5795.1 ft.SSTVD) (10) This wellbore 1L-25AL1-02 was kicked off the wellbore 1L-25AL1-01 at 9295 ft.MD (5856.8 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MGTD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 65 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN 1L-25AL1-02 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. WN 1L-25AL1-02 FN Kuparuk River Unit COUN North Slope Borough STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final has not been depth shifted *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM -- ODEP -- ------------------------------------ GR GR GRAX ------------ 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape-depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 37 Tape File Start Depth = 8840.000000 Tape File End Depth = 10374.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 46 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU ----------------------- WDFN 1L-25AL1-02.xtf LCC 150 CN ConocoPhillips Alaska In WN 1L-25AL1-02 FN Kuparuk River Unit COUN North Slope Boro STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves.: Name Tool Code Samples Units Size Length 1 GR MwD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 74 Tape File Start Depth = 8840.000000 Tape File End Depth = 10374.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape 5ubfile: 3 83 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD • • 05/12/27 1025231 01 **** REEL TRAILER **** M4~TD 07/07/12 BHI 01 Tape Subfile: 4 2 records. Minimum record length: 132 bytes Maximum record length: 132 bytes Tape Subfile 1 is type: LIS a • Tape Subfile 2 is type: LIS DEPTH GR 8840.0000 62.2900 8840.5000 51.5200 8900.0000 78.4300 9000.0000 134.4000 9100.0000 82.0400 9200.0000 88.4900 9300.0000 48.7700 9400.0000 77.1400 9500.0000 119.9600 9600.0000 117.8900 9700.0000 122.2800 9800.0000 148.5900 9900.0000 119.9600 10000.0000 120.9900 10100.0000 79.1167 10200.0000 77.6600 10300.0000 215.1400 10374.0000 -999.2500 ROP 0.0000 0.7000 60.6600 19.6300 19.4200 22.6600 45.7515 54.7300 55.3000 69.6900 46.1000 56.4900 42.8000 62.0300 69.9400 61.2100 6.2400 52.5000 Tape File Start Depth = 8840.000000 Tape File End Depth = 10374.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • • Tape Subfile 3 is type: LIS DEPTH GR ROP 8840.0000 62.2900 0.0000 8840.2500 57.4200 0.6900 8900.0000 78.4300 60.6600 9000.0000 134.4000 19.6300 9100.0000 82.0400 19.4200 9200.0000 88.4900 22.6600 9300.0000 48.7700 -999.2500 9400.0000 77.1400 54.7300 9500.0000 119.9600 55.3000 9600.0000 117.8900 69.6900 9700.0000 122.2800 46.1000 9800.0000 148.5900 56.4900 9900.0000 119.9600 42.8000 10000.0000 120.9900 62.0300 10100.0000 79.1167 69.9400 10200.0000 77.6600 61.2100 10300.0000 215.1400 6.2400 10374.0000 -999.2500 52.5000 Tape File Start Depth = 8840.000000 Tape File End Depth = 10374.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet Tape Subfile 4 is type: LI5 **** REEL HEADER **** MWD 07/07/12 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/12/21 1025231 01 2.375 CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!! !!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Information Block #MNEM.UNIT Data Type Information STRT.FT 8840.8000: Starting Depth STOP.FT 10397.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska Inc. WELL. WELL: 1L-25AL1-02PB1 FLD FIELD: Kuparuk River Unit LOC LOCATION: 70 deg 16' 11.588"N 149 deg 40' 33.550"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375 CTK DATE. LOG DATE: 21-Dec-05 API.. API NUMBER: 50029221746270 Parameter Information Block #MNEM.UNIT Valu e Description ----------------- SECT. -------------- 31 Section TOWN.N 11N Township RANG. 10E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 130.0 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 130.0 Elevation of Kelly Bushing EDF .F N{A Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks c~S /~~s 't ~5a s~ C~ (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, and Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Directional, Outer Downhole Pressure, and Downhole Weight on Bit), a and Gamma Sub, and a Hydraulic Orienting Sub with a near Bit Inclination Sensor. (6) Data presented here is final and has not been depth adjusted to a PDC (Primary Depth Control) log. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (7) The sidetrack was drilled from 1L-25 through a milled window in 7" liner: Top of Window 8837.6 ft.MD (5845.3 ft.SSTVD) Bottom of Window 8840.8 ft.MD (5847.3 ft.SSTVD) (8) The interval from 10367 ft.MD to 10397 ft.MD (5860.8 ft.to 5859.0 ft.SSTVD) was not logged due to bit to sensor offset at TD. (9) Tied to 1L-25 at 8758 ft.MD (5795.1 ft.5STVD) (10) This wellbore 1L-25AL1-02PB1 was kicked off the wellbore 1L- 25AL1-01 at 9380 ft.MD (5848.5 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 65 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN 1L-25AL1-02PB1 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. WN 1L-25AL1-02PB1 FN Kuparuk River Unit COUN North Slope Borough STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 • LJ The data presented here is final has not been depth shifted *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR Total Data Records: 38 1 Size Length 4 4 4 4 8 Tape File Start Depth = 8840.000000 Tape File End Depth = 10397.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 47 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------- WDFN 1L-25AL1-02PB1.xtf LCC 150 CN ConocoPhillips Alaska In WN 1L-25AL1-02PB1 FN Kuparuk River Unit COUN North Slope Boro STAY Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM -- - -- - - -- -- -- ----- -- ----- ODEP ------------ -- -- -- - - - - - - -- - GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 75 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = **** FILE TRAILER **** Tape Subfile: 3 84 Minimum record length: 54 Maximum record length: 4124 8840.OOOOOC 10397.000000 0.250000 feet records... bytes bytes **** TAPE TRAILER **** MWD • 05/12121 1025231 01 **** REEL TRAILER **** MWD 07/07/12 BHI Ol Tape Subfile: 4 2 records... • Minimum record length: 132 bytes Maximum record length: 132 bytes • • Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP 8840.0000 62.2900 0.0000 8840.5000 51.5200 0.7000 8900.0000 78.4300 60.6600 9000.0000 134.4000 19.6300 9100.0000 82.0400 19.4200 9200.0000 88.4900 22.6600 9300.0000 65.2800 43.1900 9400.0000 86.4300 44.0000 9500.0000 111.4500 61.6600 9600.0000 142.1400 33.8500 9700.0000 124.3400 37.6400 9800.0000 142.6600 39.4400 9900.0000 137.7600 48.2900 10000.0000 136.9800 46.3200 10100.0000 105.0000 44.6400 10200.0000 106.2900 40.4300 10300.0000 89.2600 58.7200 10397.0000 -999.2500 -999.2500 Tape File Start Depth - 8840.000000 Tape File End Depth = 10397.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH GR ROP 8840.0000 62.2900 0.0000 8840.2500 59.2150 0.3525 8900.0000 78.4300 60.6600 9000.0000 134.4000 19.6300 9100.0000 82.0400 19.4200 9200.0000 88.4900 22.6600 9300.0000 65.2800 43.1900 9400.0000 86.4300 44.0000 9500.0000 111.4500 61.6600 9600.0000 142.1400 33.8500 9700.0000 124.3400 37.6400 9800.0000 142.6600 39.4400 9900.0000 137.7600 48.2900 10000.0000 136.9800 46.3200 10100.0000 105.0000 44.6400 10200.0000 106.2900 40.4300 10300.0000 89.2600 58.7200 10397.0000 -999.2500 -999.2500 Tape File Start Depth = 8840.000000 Tape File End Depth = 10397.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS
