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205-175
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. 5- ~ ~ ~ Well History File Identifier Organizing (doge) ^ Two-sided III II III II III ~~ III ^ Rescan Needed III IIIIII II II III III RESCAN DIGITAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. ~~ ^ Maps: ~Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor C2uality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: i Maria Date: /s/ Protect Proofing III IIIIIIIIIII IIIII , BY: Maria Date: ~ ~ /s/ Scanning Preparation ~ x 30 = d + ~~ =TOTAL PAGES BY: ~ Maria Date: ~ (Count does not include cover sheet) ~,g D~ /s/ ~ „ ~' Production Scanning Stage 1 Page Count from Scanned File: n ' / (Count does include cov sheet) Pa a Count Matches Number in Scanning Preparation: YES NO 9 BY: Maria Date: ~ ~g ~ Q lsl ~l' IV ~ I v Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II IIIII ReScanned III IIIII IIIII II III BY: Maria Date: /s! Comments about this file: Quality Checked III II'IIt III II'I Ill 10/6/2005 well History File Cover Page.doc .mom . .4..., ~1'~~`.> DATA SUBMITTAL COMPLIANCE REPORT Z~si2oos Permit to Drill 2051750 Well Name/No. KUPARUK RIV UNIT 1L-25A MD 11929 TVD 5977 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 D Asc Directional Survey ~t Directional Survey Rpt Directional Survey 15281 LIS Verification !1~dg 15281 Gamma Ray ~itog 15281 Gamma Ray ~t 15282 LIS Verification I~ tog 15282 Gamma Ray Log 15282 Gamma Ray Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y~N Chips Received? ~-~i-fd''~ Analysis ~1LLN Received? Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-22174-01-00 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 Scale Log Media Run No Interval Start Stop OH / CH Received Comments 8800 11929 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 8800 11929 Open 1 L-25A 8800 8945 Open 1L-25APB1 8840 11929 Open 7/19/2007 LIS Veri w/Graphics Meta and TIF 25 Blu 1 8839 11929 Open 7/19/2007 MD GR 25 Blu 1 8839 11929 Open 7/19/2007 TVD GR 8840 8944 Open 7/19/2007 P61 LIS Veri w/Graphics Meta and TIF 25 Blu 1 8839 8945 Open 7/19/2007 P61 MD GR 25 Blu 1 8839 8945 Open 7/19/2007 PB1 TVD GR Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~/ N Formation Tops ~ / N DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drill 2051750 Well Name/No. KUPARUK RIV UNIT 1L-25A Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-22174-01-00 MD 11929 ND 5977 Completion Date 12/28/2005 Completion Status 1-OIL Current Status 1-OIL UIC N Comments: Compliance Reviewed By: - - - ----. -. ___. _..._ ____ _ Date. __ .__ '~ ~~~ ~ r Transmittal Form r/..' BAKER HUGNES INTEQ Anchorage GEOScience Center ~..~.., _.. _ ~1 To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska __-- 99501 Attention: Christine Mahnken __w.. Reference: 1L-25A _.wM Contains the following: 1 LDWG Compact Disc _ (Includes Graphic Image files) ~ ~' e 1 LDWG lister summary `~ ~ 1 blueline - GR Measured Depth Log _ II, _~ 1 blueline - GR TVD Log ~ ;~ <~ ~ - - I !, ~~ ~ ,~ Ii '. 77~ 1 P~ S'~ _. ?~ ~ ~ ~i LAC lob#: 1025231 ~ _; ,~ ~~ .~ `~'~~ _ ~ - Sent By: Deepa Joglekar Date ~ - ,~'i '~ ""~~ - -- t~..__ _ Received By: Date: ~ ~ L ~ :l, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING -- OR FAXING YOUR COPY -- ~ -"~ ~--- FAX: (907) 267-6623 Baker HughesINTEQ ~,~ ~I 7260 Homer Drive ~- Anchorage, Alaska a[7~J "~~5 99518 ~ _„N '; ' _ :__ ~- ~ 5~ ~ I Direct: (907) 267-6612 ! ; - FAX: (907) 267-6623 Transmittal Form ~'~® BAKER NUCNES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska --_- 99501 Attention: Christine Mahnken ---~- Reference: 1L-25APB1 ---- Contains the following: ;; ~ . ~ 11 1 LDWG Compact Disc e (Includes Graphic Image files) '~ -~ 1 LDWG lister summary ?~ ~ u - ~ ~ `i `~ 1 blueline - GR Measured Depth Log ~ 1 blueline - GR TVD Log ' r f~ E . __.. F € Ir 1 ~ __._- ~) LAC Job#: 1025231 ~ .~ ~--- s _-- __.~._~____~.,___ ~..~_____. ~ .~ ~ ~ Sent By: Deepa Joglekar Date ; ~6 fl ,~ ~~,.- Y ~, . `'~~ ,: .. Received By: y Date: q ~ n ~ 7 ' ;~ ~~-~= PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & R'~TR~IING s ~ ~; OR FAXING YOUR COPY T-', ry FAX: (907) 267-6623 ~. Baker Hughes INTEQ ~ 1 7260 Homer Drive °' Anchorage, Alaska. ! ~"'LL ~~ ~~-S` 99518 ~ _ Direct: (907) 267-6612 .~ ~° j a ~ c7 FAX: (907) 267-6623 ~+ STATE OF ALASKA ALASK~IL AND GAS CONSERVATION COIVV~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG i 05/03/06: Revised, Put on Production 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 ® Development ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other ^ Stratigraphic ^ Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number Conoco Phillips Alaska Inc. 12/28/2005 / 205-175 3. Address: 6. Date Spudded 13. API Number c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 12/1/2005 50-029-22174-01-00 ' 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: / 597' FNL 143' F 1 S 12/12/2005 Kuparuk 1L-25A ' , EL, EC. 3 , T11N, R10E, UM Top of Productive Horizon: g. KB Elevation (ft): 15. Field /Pool(s): 1546' FNL 1274' FWL SEC T10N R10E 05 UM 130' Kuparuk River Unit /Kuparuk , , . , , , River Pool Total Depth: 9. Plug Back Depth (MD+TVD) 2353' FNL, 3885' FWL, SEC. 06, T10N, R10E, UM 11929 + 5977 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 539925 y- 5948371 Zone- ASP4 11929 + 5977 Ft ADL 025664 TPI: x- 541397 y- 5942151 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 538990 Y- 5941331 Zone- ASP4 1810 MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Surve Y ®Yes ^ No N/A MSL 1500' (Approx.} 21. Logs Run: MWD, GR ASING, INER AND EMENTING ECORD CASING ETTING EPTH M© ETTING EPTH TVD HOLE ~J NT SIZE WT. PER FT. GRADE OP OTTOM OR OTTOM SIZE CEMENTING RECOF~ ~ ED 2-3/8" 4.6# L-80 8940' 11585' 6008' 5991' 3" Uncemented Slotted Liner ~ "-~.';, --: ,y cr, 23. Perforations open to Production (MD +TVD of Top and B I " " 24.: TUBING RECORD v. ottom nterval, Size and Number; if none, state none ): SIZE DEPTH SET (MD} P,~KER SET (MD} 2-3/8" Slotted Section Note: 3-1/2", 9.3#, J-55 8742' 8692' MD TVD MD TVD l 9144' - 9916' 5993' - 6009' Well Branch Well Branch ' ' ' ' 25. ACID CEMENT SQUEEZE ETC. FRACTURE 10329 - 10758 6008 - 5999 1 L-25A Departs 1 L-25A is not , , , 11043' - 11541' 5985' - 5988' From Well Directly Branch A ibl DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED ccess e 1 L-25AL1-02, PTD # 205-178, at 8938' MD (6008' TVD) 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Reported on 1L-25AL1-02 See 1L-25AL1-02 10-407 (Dated 05/03/06, PTD 205-178) for Production & Test Data Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED E OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) Press. 24-HouR RAT 27• CORE DATA Brief description of lithology, porosity,. fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". _-~ None ~~ ~F~ ~9AV ~ 2~~6 .. ' .~t~.~t.o.S Form 10-407 Revised 12/2003 If-"' ~" r" - ' ' Cbr~iNl~D ON REVERSE SIDE .. 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". Kuparuk B 9103' 5996' None Kuparuk B 9935' 6011' J Kuparuk B 10285' 6010' Kuparuk B 11018' 5989' Kuparuk C4 11918' 5978' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Titl T i h l A i t D t t ~~/~3/~ e n ec ca ss an a e s Terrie Hubble Kuparuk 1 L-25A 205-175 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Sean McLaughlin, 564-4387 Permit No. /Approval No. INSTRUCTIONS GeNeRaL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Irene 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Irene 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Front: "Hubble. Terrie I:;" <Terrie.Hubble crbp.coni=> Date: T'hu, 02 1~1ar 2006 15:3: ~0 -0900 To: bob_lleckenste.inla:'ad~»in.state.ak.us, tolTl maundec(a?admit~.state~.ak.us CC: "f~Ilsup-Dralcc, Sharon K (ConocoPhi~lips)" <Sharon.K.Allsup-Dra4:e ii:!conocophillips.co~zi= Hi Bob & Tom, There are two errors, as I already discussed with you both, on the 10-407's for the following legs of the 1 L-25 Multilaterals. I have checked the rest of the data to ensure that there were no other errors {I hope). These 10-407's will be resubmitted when the wells are brought on line and I'll be sure to make these corrections. 1 L-25A, PTD 205-175, 50-029-22174-01-00 BHL should read: 2353' FNL, 3885' FWL, SEC. 06, T10N, R10E 1 L-25A11-01, PTD 205-177, 50-029-22174-61-00 BHL should read: 1467' FNL, 2078' FWL, SEC. 06, T10N, R10E Thanks for letting me know there was a problem. Have a great weekend. Terrie 1 of 1 3/3/2006 8:27 AM ~` ALAS AND GAS CONSERVATION COMAI~ION ~~~i~r~ ' WELL COMPLETION OR RECOMPLETION REPORT AND LOG FEB 1 7('000 Alaska 06! & Oas Cans. Carnri~ssion 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 2oAACZS.,os 2oAACZS.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other ib. Well Clas~nChOragl: - ®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 205-175 ' 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 12/1/2005 ~ 13. API Number 50-029-22174-01-00 ' 4a. Location of Well (Governmental Section): Surface: ' ' ~ 7. Date T.D. Reached 12/12/2005 ~ 14. Well Name and Number: Kuparuk 1 L-25A 597 FNL, 143 FEL, SEC. 31, T11 N, R10E, UM Top of Productive Horizon: 1546' FNL, 1274' FWL, SEC. 05, T10N, R10E, UM g. KB Elevation (tt): 130' 15. Field /Pool(s): Kuparuk River Unit /Kuparuk River Pool Total Depth: 2353' FNL, 2926' FWL, SEC. 06, T10N, R10E, UM 9. Plug Back Depth (MD+TVD) 11929 + 5977 Ft 4b. Location of Well (State Base Plane Coordinates): 5948371 ' Surface: x- 539925 ' y- Zone- ASP4 10. Total Depth (MD+TVD) 11929 + 5977 Ft 16. Property Designation: ADL 025664 _ _ TPI: x- 541397__ y- 5942151 Zone- ASP4 Total Depth: x- 538990 Y- 5941331 ~ Zone- ASP4 11. Depth where SSSV set 1810 MD 17. Land Use Permit: --- ---- ------- -------- - h if d ff h ss of P rmafrost Thi k 20 18. Directional Survey ®Yes ^ No , ore 19. Water ept o s N/A MSL ne c e . 1500' (Approx.) 21. Logs Run: ~77j`c.~%;..~,...~~-~ f'a~~'7 r rr~t~~ ?S- °"7'~,!~ MWD, GR 2.22 -Vfv 2. ASING, LINER AND EMENTING ECORD CASING ETTINO EPTH MD ETi1N0 EPTH TVD HOLE OUNT SIZE WT. PER FT. GRADE OP 7TOM OP TTOM SIZE .CEMENTING REGARD PULLED 2-3/8" 4.6# L-80 8940' 11585' 6008' 5991' 3" Uncemented Slotted Liner 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TUBING'RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/8" Slotted Section Note: 3-1l2", 9.3#, J-55 8742' 8692' MD TVD MD TVD 9144' - 9916' 5993' - 6009' Well Branch Well Branch ' 10329' - 10758' 6008' - 5999' 1 L-25A Departs 1 L-25A is not 25. ACID, FRACTURE„CEMENT SQUEEZE,' ETC. 11043' - 11541' 5985' - 5988' From Well Directly DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Branch Accessible 1 L-25AL1-02, PTD # 205-178, at 8938' MD (6008' TVD) 26. PRODUCTION TEST Date First Production: Reported on 1 L-25AL1-02 Method of Operation (Flowing, Gas Lift, etc.): See 1 L-25AL1-02 10-407 (Dated 02/17/06, PTD 205-178) for Production & Test Data - Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. Casing 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". ~ " `"` . G None ~~5 ~F~r 1= t= ~~ ~ ~ ~~~~ ', 1 ~ ~~f. ~~ 4J .. ? ~ '-~ ~ h . Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE V 8. GEOLOGIC MARKERS 29' RMATION 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". Kuparuk B 9103' 5996' None ' Kuparuk B 9935' 6011' Kuparuk B 10285' 6010' Kuparuk B 11018' 5989' Kuparuk C4 11918' 5978' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. (~ Signed Terrie Hubble Title Technical Assistant Date "- ~ ~ ~ f Q Kuparuk 1 L-25A 205-175 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. OriUingEngineer: Sean McLaughlin, 564-4387 INSTRUCTIONS GeNeaaL: 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. ITEM 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). YrEM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Page 1 of 30 Operations Summary Report Legal Well Name: 1 L-25 Common W ell Name: 1 L-25 Spud Date: 11/25/2005 Event Nam e: REENTE R+COM PLET E Start : 11/27/2005 End: 12/28/2005 Contractor Name: NORDIC CALIS TA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date From - To _T Hours ~ -_ Task __ ! Code ~ _- NPT ~- - ---- Phase L 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 1L-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 ROPE. 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 Shelve 23:00 - 00:00 1.00 BOPSU P PRE Pressure test BOPE 250psi/low 3500psi/high 5min ea. 11/28/2005 00:00 - 02:45 2.75 BOPSU P PRE Pressure test BOPE. 250 psi/low 3500psi/high 5min/ea 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'Jhr 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 1.53/1.47/3650 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 11:13:50 AM $P EXPLORATION Operations Summary Report Legal Well Name: 1 L-25 Common Well Name: 1 L-25 Event Name: REENTER+COMPLETE Start: 11/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours I Task j Code NPT Phase I ___- 11 /29/2005 08:10 - 08:15 0.08 STWHIP --} - P ~ WEXIT 08:15 - 11:25 I 3.171 STWHIPIP I I WEXIT 11:25 - 14:00 I 2.581 STWHIPIP i I WEXIT 14:00 - 16:45 2.75 STWHIP P WEXIT 16:45 - 17:00 0.25 STWHIP P WEXIT 17:00 - 18:05 1.08 STWHIP P WEXIT 18:05 - 19:40 1.58 STWHIP P WEXIT 19:40-20:05 0.42 STWHIP P WEXIT 20:05-21:101 1.081 STWHIPIP (WEXIT 21:10-22:45 I 1.581 STWHIPIP I (WEXIT 22:45-23:001 0.251STWHIPIP I (WEXIT 23:00 - 00:00 I 1.001 STWHIPIP I I WEXIT 11 /30/2005 100:00 - 02:00 I 2.00 I STWHIPIP I I W EXIT 02:00-04:001 2.OOISTWHIPIP I (WEXIT 04:00-04:30 I 0.501 STWHIPIP I (WEXIT 04:30 - 05:00 I 0.501 STWHIPIP I I WEXIT 05:00-06:45 1.75 STWHIP P WEXIT 06:45 - 10:30 3.75 STWHIP N WEXIT Page 2 of 30 Spud Date: 11 /25/2005 End: 12/28/2005 Description of Operations 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 Begin time milling schedule at 8836.6' 1.53/3790/58 w/ 14.7k - surface wt w/ 11.96 ECD 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 Mill from 8839' 1.53/1.50/3660 250mw 3-4k wob .1'/5min at 8840.3' seeing good drill-offs Continue milling f/ 8840.6' 2-3k wob 3-400psi mw. good drill-off's. Exited window. Drill rathole. POH to pick up crayola mill to dress window. 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. 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. 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. Log tie in pass over GR charecter at 8767'. Make +6' correction. 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. At 8841.5'. Continuing to ream down thru window with TF at 0 deg. Reaming down as per David Hearn. Trying to clean up lip at bottom of the window. 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. Set down at the bottom of the window. Continue to work window. 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 Hearn. TOH Discuss with town group the options for salvaging this window or 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 1 1:13:50 AM h 4 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: I Date From - To - Hours Task I Code NPT I 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 EDC 16:05 - 18:00 1.92 STWHIP N WEXIT RIH slow 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 1.53/150/4000 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'. W06=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 lip. Discuss with David Hearn. Call town and discuss with town engineer. POOH to pick up 1.75 deg motor with same mill in the hopes that we can get the mill 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 30% scale 18% cmt 2% sd 08:45 - 09:30 0.75 STWHIP N WEXIT Log tie-in no correction. Discussed with town plan forward. WiII 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 71;13:50 AM BP EXPLORATION Page 4 of 30 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 1 ell Name: 1 e: Name: From - To L-25 L-25 REENTE NORDIC NORDIC Hours R+COM CALIS 2 ~ Task PLET TA ~ ! Code ~ E ~ NPT Start Rig Rig ~, Phase Spud Date: 11!25!2005 : 11/27/2005 End: 12/28/2005 Release: 12/28/2005 Number: 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 at 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 motorwork 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 lower than the INC when we drilled the build section. Looks like we have 2 wellbores. One that is lower in INC with a TD at 8873'. One that has 6 degrees higher INC, and landed at 8937'. There appear to have been 2 pilot holes from the various milling 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 Operations Summary Report Legal Well Name: 1 L-25 Common W ell Name: 1 L-25 Event Nam e: REENTE R+COM PLET E Contractor Name: NORDIC CALIS TA Rig Name: NORDIC 2 Date From - To ' Hours ~ Task ~ Code E NPT _ 12/2/2005 00:50 - 01:05 0.25 DRILL N DPRB 01:05 - 02:10 1.08 DRILL N DPRB 02:10 - 03:00 0.83 DRILL N DPRB 03:00 - 05:25 2.42 DRILL N DPRB 05:25 - 07:00 1.58 DRILL P 07:00 - 07:15 0.25 DRILL P 07:15 - 10:30 3.25 DRILL N 10:30 - 10:45 0.25 DRILL N 10:45 - 12:00 1.25 CASE N 12:00 - 16:30 4.50 CASE N Page 5 of 30 Spud Date: 11!25!2005 Start: 11!27/2005 End: 12/28/2005 Rig Release: 12/28/2005 Rig Number: Phase Description of Operations PROD1 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. 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 at 8873'. PROD1 Pick up above window to let DD and MWD hand sort out paperwork and data files. Open EDC and circulate while they get things sorted out. PROD1 RIH thru the window slick at 30L. Tagged up at 8873', and stalled. Resume drilling. Free spin 3600 psi at 1.55 bpm. PROD1 Well is landed again. This time at 8935'. POOH to pick up lateral section BHA. Close SSSV trapping 950psi. Tagged up at surface. PROD1 Hold PJSM. Review plan forward. Same time bleed down well and observe. PROD1 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-deploymnet 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. PROD1 Held PJSM with HOWCO slickliners and rig crews for RU and the plan forward to "brush" the SSSV 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 5min/ea Good test. Continue RU slickliners 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. It 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 6 of 30 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ' Name: 1 ell Name: 1 e: Name: From - To L-25 L-25 REENTE NORDIC NORDIC Hours ~ R+COM CALIS 2 Task I PLET TA Cod~ E NPT ~' 12/2/2005 12:00 - 16:30 4.50 CASE N 16:30 - 18:00 1.50 CASE N 18:00 - 18:45 0.75 CASE N DPRB 18:45 - 20:00 1.25 CASE N DPRB 20:00 - 22:30 2.50 CASE N DPRB 22:30 - 00:00 1.50 CASE N DPRB 12/3/2005 00:00 - 02:00 2.00 CASE N DPRB 02:00 - 04:15 2.25 CASE N DPRB Spud Date: 11/25/2005 Start: 11/27/2005 End: 12/28/2005 Rig Release: 12/28/2005 Rig Number: Phase i Description of Operations 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 wellbore and shift the sleeve to the down position. Then with coil RIH with a sidejet nozzle and wash the flow tube area. Stabilized WHP 527psi PRODi RIH with gauge ring. Called AOGCC and explained to Lou Grimaldi the situation with closing the 2" upper pipe rams on 2-3/8" tools. Told him we will test the 2" rams against test joint prior to drilling ahead. PROD1 Shut down for crew change. Then hold PJSM with full rig crew and HES slickline crew. PROD1 Run #4 Lockout tool to attempt to shift sleeve down. Land on top of sleeve, pressure up wellbore 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. PROD1 Sleeve failed to shift down. Lockout tool functioned properly. The SSSV sleeve may be stuck in the down (Open) position. Dress tattle tale tool to see if flapper can be shut. This will 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. PRODi 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" nozzle to make cleanout run with coil. PRODi Wait for SL hand to return with 2" JSN. PRODi Rig up 2" JSN, 2 stingers. PT lubricator to 1000 psi. 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 nozzle 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 11:13:50 AM BP EXPLORATION Page 7 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 02:00 - 04:15 2.25 CASE N DPRB PRODi 04:15 - 04:35 0.33 CASE N DPRB PROD1 04:35 - 05:45 1.17 CASE N DPRB PROD1 05:45 - 08:00 . 2.25 CASE N DPRB PROD1 08:00 - 08:30 0.50 BOPSU N HMAN PRODi 08:30 - 08:50 0.33 DRILL P PROD1 08:50 - 10:10 1.33 DRILL P PROD1 10:10 - 11:50 1.67 DRILL P PROD1 11:50 - 12:10 0.33 DRILL P 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 it is mostly old pipe scale and sand with only a very small trace of fine new metal from the window milling. Pull OOH with coil pumping at full rate. There is 1 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. Stand back injector. Pick up slickline lubricator. Make up friction tool 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. RU to test upper 2" combi's. Test 250psi low/3500psi high 5/min ea. Held good. Installed lubricator cap and closed choke. Opened MV/SV wet! still dead. 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 BOP rams. Plan to make overlay templetes with better displays of each ram. These will be easily interchangable for other stack configruations that we use. We want these in place within 1-2 days. Presently we have the lower 2" pipe ram actuator buttons in the upper lefthand corner of the panel. They need to be re-wired to the lowest "spare" buttons on the panel which at 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 ASAP. Also reminded everyone that they have the authority to stop the job anytime they see fit for whatever reason. PU BHA #8 TIH open SSSV no problems Log tie-in +5' correction. Printed: t/3/2006 11:13:50 AM BP EXPLORATION Operations Summary Report pilothhole. 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' PRODi Directionally drill ahead f/ 8838' 200-300 motorwork, 1k wob 85'/hr. Good drilling to 8845' then ran into Siderite. <12'/hr 3-4k wob mud wt out has evened out. Returns from bottom had some oil content. PROD1 Drilling ahead with lateral section of well. Currently in B shale. Drilling at 1.56/1.56/3800 psi. PVT=335 bbls and has been constant all day. IAP=200 psi, OAP=470 psi. DHWOB=4600 lbs. String wt = -500 lbs. ROP=18 fph. 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. PROD1 Resume drilling lateral section. Now inr"C" Sahd. Drilling ahead at 1.57/1.55/3750 psi. WOB=2900 lbs. STring wt=5000 lbs. PVT=337 bbls. ROP=65 fph. PROD1 Continue drilling lateral section from 9200'. PROD1 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. PROD1 Resume drilling lateral section. 1.56/1.51/4050 psi. PVT=334 bbls. IAP=364 psi, OAP=552 psi. WHP=O, BHP=3690 psi. ECD=12.13 ppg. DHWOB=3300 lbs. String wt = -600 lbs. PROD1 Wiper to 8740'. No problems up through window. PROD1 Log tie-in +2' correction PROD1 Wiper trip to bottom. Enter window at 20L no problems and clean at 8920' PROD1 Continue drilling ahead f/ 9385' 1.52/1.50/3800 2-300 motorwork 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 PRODi Wiper trip to 8850' No problems PROD1 Continue drilling ahead f/ 953& 1.45/1.45/3600 EDC 12.19 EDC 200-400mw 2-3k wob PROD1 Continue drilling lateral section. 1.45/1.36/3750 psi. PVT=380 bbls. IAP=470 psi, OAP=600 psi. String wt = 1200 lbs. DHWOB=2000 lbs. ROP=25 fph. BHP=3690 psi. ECD=12.13 ppg. INC=90 deg. Plan to drill ahead holding 90 deg to cross cut down dipping formation. PROD1 Begin swap to new mud. New mud contains 4% lubetex, 1.5% EMI-776 tube, and 14 ppb Kla-gard. PROD1 Wiper trip to window. Clean PU off bottom at 20 klbs. Very clean up in open hole, 1 small weight bobble at 8894'. Mostly clean on the way back in the hole, 1 small weight bobble at 9058'. Nothing serious. PROD1 Continue back to bottom. PRODi Resume drilling. New mud in the hole. Free spin 3720 psi at 1.44 bpm. Drilling at 1.44/1.36/3875 psi. PVT=411 bbls. IAP=433 psi, OAP=564 psi. ECD=11.93 ppg. BHP=3625 psi. String wt= -5000 lbs. DHWOB=3360 psi. Now holding 88 deg Page 8 of 30 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: * - ~ Phase Description of Operations 12/3/D2005 12r Om1225 ~ Ho025i Task Code NPT - I _ - - DRILL ~ P ~ ~ PROD1 Close EDC RIH no pump. Orient to 20L. 6k through 12:25 - 18:00 I 5.581 DRILL I P 18:00 - 20:15 I 2.251 DRILL I P 20:15 - 20:30 I 0.25 I DRILL I P 20:30 -.00:00 I 3.501 DRILL I P 12/4/2005 00:00 - 01:10 1.17 DRILL P 01:10 - 01:40 0.50 DRILL P 01:40 - 07:15 I 5.581 DRILL I P 07:15 - 07:40 0.42 DRILL P 07:40 - 08:00 0.33 DRILL P 08:00 - 08:30 0.50 DRILL P 08:30 - 14:45 I 6.251 DRILL I P 14:45 - 15:30 0.75 DRILL P 15:30 - 18:00 2.50 DRILL P 18:00 - 21:10 I 3.171 DRILL I P 21:10 - 23:00 1.83 DRILL P 23:00 - 00:00 1.00 DRILL P 12/5/2005 00:00 - 00:10 0.17 DRILL P 00:10 - 06:00 5.83 DRILL P Printed: 1/3/2006 11:13:50 AM BP EXPLORATION Page 9 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 Code NPT Phase '; Description of Operations I ' -- _ --- - - _ -- - 12/5/2005 00:10 - 06:00 5.83 DRILL P - _ _ __ _ _ - -- - PROD1 to follow formation. 06:00 - 08:25 2.42 DRILL P PRODi 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 well. Dead, SSSV holding good. Looking back on 1 D-36L2 we tripped for 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°/a Also time for weekly 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 PROD1 Tag up. Setback injector. LD BHA. Install lubricator cap and shut-in MV & SV. Bit condition: 4 out of 6 jets were plugged with siit/sh/sa all 4 on the nose, cutters look okay. Will 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 PROD1 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 PRODi 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. Turns out the DPS tool 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. Drilling ahead at 1.47/1.45/3700 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 klbs. Annular pressure bled down, Bore (Internal BHA) 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: 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 i Hours `Task Cod~NPT ~ Phase i 12/5/2005 19:10 - 21:20 ~ 2.17 DRILL N ~ DFAL ~ PRODi 21:20 - 21:45 0.421 DRILL N i DFAL PROD1 21:45 - 22:00 I 0.25 DRILL N DFAL PROD1 22:00 - 23:00 ~ 1.00 DRILL N DFAL PROD1 23:00 - 00:00 1.00 DRILL N DFAL PROD1 12/6/2005 00:00 - 00:45 0.75 DRILL N DFAL PROD1 00:45 - 01:00 0.25 DRILL N DFAL PROD1 01:00 - 01:30 0.50 DRILL N DFAL PRODi 01:30 - 03:50 2.33 DRILL P PROD1 03:50 - 05:10 1.33 DRILL N RREP PROD1 05:10 - 10:00 4.83 DRILL P PROD1 10:00 - 11:30 1.50 DRILL P PROD1 11:30 - 15:30 4.00 DRILL P PROD1 15:30 - 16:20 I 0.831 DRILL I P I I PROD1 16:20 - 16:40 I 0.331 DRILL I P I I PROD1 16:40 - 17:30 I 0.831 DRILL I P I I PROD1 17:30 - 18:00 I 0.501 DRILL { P I I PROD1 18:00 - 20:00 I 2.001 DRILL I N I RREP I PROD1 20:00 - 00:00 4.00 DRILL N PROD1 12/7/2005 00:00 - 03:00 3.00 DRILL P PROD1 Description of Operations 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. 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. Tag up at surface. No flow check indicates SSSV is holding. Lay down BHA #9. 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. Shallow hole test MWD, passed ok. Open EDC RIH pumping at full rate. Open SSSV, and continue RIH. Continue RIH. Log tie in pass above window, correction was +5'. SD pumps, rurrthru window, bring pumps on and run to TD. No problems running in open hole. 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. 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. 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 Vbs. ECD=i2.2 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 wiper trip to window. 19.2k of bottom Continue drilling ahead t/ 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 Wiper trip to the window. Clean PU off bottom at 19 klbs. Clean in open hole. 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. Continue back in hole on wiper trip. Smooth in open hole until 10100', had a set down and had to work to bottom. Resume drilling. 1.48/1.5113700 psi. DHWOB=1700 lbs. String wt=-2400 lbs. ROP variable from 15-60 fph. ECD=12.3 ppg, BHP=3750 psi. WHP=O psi. PVT=425 bbls. 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. Drill ahead from 10234' to 10327'. Drill ahead from 10327'. 3700 psi fs at 1.48 in/1.48 out. DPSI: 50-200 psi. DHWOB: 1.6 k#. WHP/BHP/ECD: 22/3801/12.43 ppg. IA/OA/PVT: 515/569/425 bbls. INC/AZM/TF: Printed: 7/3/2006 11:13:50 AM BP EXPLORATION Operations Summary Report Legal Well Name: 1 L-25 Common Well Name: 1 L-25 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date ~~ From - To Hours Task Code NPT 12/7/2005 ~ 00:00 - 03:00 3.00 DRILL P 03:00 - 06:00 3.00 DRILL P 06:00 - 10:50 4.83 DRILL P 10:50 - 13:30 J 2.671 DRILL P 13:30 - 13:45 0.25 DRILL P 13:45 - 15:10 1.42 DRILL P 15;10-16:40 1.50 DRILL P 16:40 - 17:15 0.58 DRILL P 17:15 - 18:45 1.50 DRILL P 18:45 - 00:00 12/8/2005 00:00 - 01:45 01:45 - 05:00 5.25 DRILL P 1.75 DRILL P 3.25 DRILL P 05:00 - 06:00 06:00 - 06:50 06:50 - 08:50 1.00 DRILL P 0.83 DRILL P 2.001 DRILL I P Page 11 of 30 Spud Date: 11/25/2005 Start: 11/27/2005 End: 12/28/2005 Rig Release: 12/28/2005 Rig Number: Phase ~ Description of Operations PROD 1 92-94/205-210/75-105R. PROD1 Wiper trip to window. Hole smooth. 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. PROD1 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. Drill 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. PRODi Flow check well while holding PJSM. Discuss changes needed to BHA to pick up Agitator tool. Discuss hazards of operation and mitigation. 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 UOC. Make BHA back up. Scribe motor. Pick up Injector. PROD1 RIH with BHA #11. 1.0 deg motor with Hycalog DS100 bit with TREX cutters. Surface test of MWD tools passed ok. Open EDC and RIH pumping at full rate. Taking returns to the tiger tank. AES freed up 1 vac truck. Doing mud swap the old fashioned way, taking returns to the tiger tank and shuttling mud with the vac truck. PROD1 Log tie in pass down from 8750', pumping at 1.1 bpm. Make =11.5' correction. PROD1 SD pumps, run thru the window slick. Kick pumps on, continue RIH in open hole. Set down at 10.020'. Able to work through with pumps off. PROD1 Drill ahead from 10,493'. PROD1 Wiper trip to window. Some over pulls and motor work from 10,020' to 10,040'. Hole otherwise smooth. PROD1 Drill ahead from 10640'. 3900 psi fs at 1.55 in/1.52 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. PROD1 Drill ahead from 10735'. 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 lbs. 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. 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!2006 11:13:50 AM BP EXPLORATION Page 12 of 30 Operations Summary Report Legal Well Name: 1 L-25 Common Well Name: 1 L-25 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours ~ Task ,Code NPT 12/8/2005 ~ 06:50 - 08:50 ~ 2.00 ~ DRILL ~ P 08:50 - 10:00 I 1.171 DRILL I P 10:00 - 11:20 I 1.331 DRILL I N I DPRB 11:20 - 11:45 0.42 DRILL P 11:45 - 15:25 3.67 DRILL P 15:25 - 17:00 I 1.581 DRILL I P 17:00 - 18:30 I 1.501 DRILL I P 18:30 - 19:00 0.50 DRILL P 19:00 - 20:15 1.25 DRILL P 20:15 - 00:00 I 3.751 DRILL I P 12/9/2005 00:00 - 00:30 0.50 DRILL P 00:30 - 02:30 2.00 DRILL P 02:30 - 03:30 1.00 DRILL P 03:30 - 06:30 3.00 DRILL P 06:30 - 09:00 2.50 DRILL P Spud Date: 11 /25/2005 Start: 11/27/2005 End: 12/28/2005 Rig Release: 12/28/2005 Rig Number: Phase Description of Operations PROD1 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'. PROD1 RBIH. Smooth in the hole. Pump another sweep to exit the bit as we get back down to the belly. PROD1 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. PROD1 Run to bottom. PROD1 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. PROD1 Geo indicates we have crossed the fault. Point the tool face up to get INC to 99 degrees, and look for the C sand again. 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'. PROD1 Log gr tie in. PRODi 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. PROD1 Drill ahead from 10950'. 4000 psi fs at 1.57 in/out. DPSI: 100-250. DHW06:1.5-2.2k#. WHP/BHP/ECD:22/3646/12.01 ppg. IA/OA/PVT: 662/579/444 bbls. INC/AZM/TF: 95-98/265-245/270-350 deg. Weight trnasfer god. ROP averaging 40 fph. Continue to pump 10 bbls hi vis sweeps every hour. PRODi Drill ahead to 11,110'. 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. PRODi 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. PROD1 Drill ahead from 11,110'. PRODi 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 Printed: 1!3/2006 1 7 ~ 13:50 AM BP EXPLORATION Page 13 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 G. 12/9/2005 06:30 - 09:00 2.50 DRILL 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 belly of well. It was all clean sand with a very small amount of siltstone. Nothing that he would catagorize 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 PROD1 Tag bottom, resume drilling. 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 1.35/1.38/4270 psi. WOB=2400 lbs. 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 isn't right. POOH to check bit and motor. Clean PU off bottom at 22 klbs. Clean up thru belly of the well with no overpulls or packing off. Clean up to the window. Open EDC and pump at 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 PROD1 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 PRODi 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 PRODi 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 PROD1 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 PROD1 Drill ahead from 11,197'. 06:00 - 08:30 2.50 DRILL P PRODi 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 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 L-25 1 L-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 11 /27/2005 Rig Release: 12/28/2005 Rig Number: Date From - To Hours ~ Task Code ~ NPT Phase 12/10/2005 06:00 - 08:30 2.50 DRILL P PROD1 08:30 - 10:00 1.50 DRILL P PRODi 10:00 - 12:15 I 2.251 DRILL I P 12:15 - 16:20 4.08 DRILL P 16:20 - 18:00 1.67 DRILL P 18:00 - 19:15 1.25 DRILL P 19:15 - 00:00 12/11/2005 ~ 00:00 - 01:30 01:30 - 02:00 02:00 - 02:15 02:15 - 03:45 03:45 - 04:00 04:00 - 04:45 4.751 DRILL I P 1.50 DRILL P 0.50 DRILL P 0.25 DRILL P 1.50 DR1LL P 0.25 DRILL P 0.75 DRILL N PROD1 PROD1 PRODi PRODi PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 SFAL PROD1 Page 14 of 30 Spud Date: 11/25/2005 End: 12/28/2005 Description of Operations ROP=50 fph. String wt= 2000 lbs. Pumping 1, 10 bbl sweep per hour to help in hole cleaning. 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. 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. 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, String wt _ -6200 Ibs. Getting a little hard to get wt to bit. Make wiper to window. Clean PU off bottom at 24 klbs. Pump sweep prior to getting to belly of the well. Clean up thru belly of the well. No overpulls or packing off at all!. This is definately the best that it has been in 3 days. Continue clean to the window. 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. Drill ahead from 11,471'. 3900 psi fs at 1.49 in/out. DPSI: 200-250 DHWOB: 1.5k# WHP/BHP/ECD: 18/3765/12.41 ppg. IA/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. Wiper trip to 7800'. Hole mostly smooth on trip out. Time sweep for 10,000' area. Run in hole to btm, Did not notice any significant cuttings increase with sweep or short trip btms up. Log gr tie in from 8775'. Continue to run in hole. Circ 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 11,000' to btm. Hole conditions are looking good. Drill ahead from 11,630'. BHI depth counter not working. Found parted line at surface. Failed due to high winds pulling cable out of an electrical Printed: 1/3/2006 11:13:50 AM BP EXPLORATION Page 15 of 30 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ~ From - To 12!11/2005 04:00 - 04:45 04:45 - 06:00 06:00 - 09:40 06:50 - 09:40 09:40 - 13:30 1 L-25 1L-25 Spud Date: 11/25/2005 REENTER+COMPLETE Start: 11/27/2005 End: 12/28/2005 NORDIC CALISTA Rig Release: 12/28/2005 NORDIC 2 Rig Number: Hours ~` Task Code NPT Phase j Description of Operations 0.75 DRILL N 1.25 DRILL P 3.67 DRILL P 2.831 DRILL I P 3.831 DRILL I P SFAL PROD1 connector. Repair same. PROD1 Drill ahead from 11642'. 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. 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. PROD1 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 13:30 - 18:00 4.50 DRILL P 18:00 - 21:45 3.75 DRILL P 21:45 - 00:00 2.25 DRILL P 12/12/2005 100:00 - 03:00 03:00 - 06:00 06:00 - 07:45 07:45 - 09:25 3.00 DRILL P 3.00 DRILL P 1.75 DRILL P 1.67 DRILL N 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. PRODi 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. 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 PROD1 Drill ahead from 11,902'. 4050 psi fs at 1.44 in/out. DPSI: 150-200 DHWOB: 1.5-1.8k#. WHP/BHP/ECD: 22/3915/12.92 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. PROD1 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. PROD1 Wiper trip to 7800'. 20.8k# up weight off btm. Ream and back ream 9,900 to 10,100 area. Continue wiper into tubing. 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. DPRB PROD1 RIH pumping at full rate. Set down at 9941'. PU, drop rate to 0.95, WHP to 300 psi. Run down thru it 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 Operations Summary Report Legal Well Name: 1 L-25 Common Well Name: 1 L-25 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours Task~ Code Start: 11 /27/2005 Rig Release: 12/28/2005 Rig Number: NPT I Phase Page 16 of 30 Spud Date: 11 /25/2005 End: 12/28/2005 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. WOB=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 well. 16:50 - 19:00 2.17 DRILL P PRODi 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. Flow 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 PRODi RU fro bi-weekly BOP test. Hold PJSM to discuss high pressure testing. Witness waived by J. Jones, AOGCC. Perform injector chain inspection during BOP 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 floor 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 11:13:50 AM BP EXPLORATION Operations Summary Report Legal Well Name: 1 L-25 Common Well Name: 1 L-25 Event Name: REENTER+COMPLETE Start: 11/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date ~~ From - To Hours Task '~ Code f NPT ! Phase 12/13/2005 04:30 - 06:00 1.50 CASE P RUNPRD 06:00 - 06:30 0.50 CASE P RUNPRD 06:30 - 07:15 0.75 CASE N DPRB RUNPRD 07:15 - 09:10 1.92 CASE N DPRB RUNPRD 09:10 - 09:25 0.25 CASE N DPRB RUNPRD 09:25 - 11:15 1.83 CASE N DPRB RUNPRD 11:15 - 11:45 0.50 CASE N DPRB RUNPRD 11:45 - 14:00 2.25 CASE N DPRB RUNPRD 14:00 - 16:00 2.00 CASE N DPRB RUNPRD 16:00 - 17:30 1.50 CASE N DPRB RUNPRD 17:30 - 21:30 4.00 CASE N DPRB RUNPRD 21:30 - 22:50 1.33 CASE N DPRB RUNPRD 22:50 - 23:40 0.83 CASE N DPRB RUNPRD 23:40 - 00:00 0.33 CASE P RUNPRD 12!14/2005 00:00 - 00:20 0.33 CASE P RUNPRD Page 17 of 30 Spud Date: 11/25/2005 End: 12/28/2005 Description of Operations Circulate to fill liner. Pressure well to 900 psi. Open SSSV. Run in hole with liner assembly. 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 6500 Ibs. 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 WFO. Try to flow the well. RIH, tag up solid. PU 100', Pressure up the well to 700 Ibs. 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. POOH. Call town and discuss options. Call W F and Baker for more odds and ends. Bring in 1" CSH to pipe shed. Safety meeting prior to standing back liner, and flowcheck of well. 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. Tag back up at surface. Give well a good flow check. No flow observed. Stand back injector. Lay down BHI tool. Stand back 2-3/8" liner. Recover Unique oriented guide show full of shale "pea gravel". It wouldn't rotate due to the debris inside of it. RU floor to run liner. MU motor & bit assy on liner. Run liner stands, scribing each stand. Hang off liner in BOPS. RU floor to run CSH work string. Hold PJSM to discuss job. Assignments, hazards, well control issues, procedures. Change dies in little jerks. MU 51 jts 1"CSH and space out for stinger to bottom out 1' above O-ring sub w/ 10' of pups. Install BTT seal bore deployment sleeve w/ 3" GS splined spear. MU BHI MWD assy and test RIH w/ liner on CT circ thru GS 0.15/2300 following pressure schedule. Open TRSSSV w/ 900 psi 8800' 24k. RIH thru window, clean. Continue RIH in OH at 35'/min 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) Log tie-in down from 10437' (at -8750') and had no corr. RIH at 35'/min to set-down at 10515'. PUH 25k Continue to set down solid at 10515' w/ clean PU's at 25k. Printed: 1/3/2006 11:73:50 AM BP EXPLORATfON Page 18 of 30 Operations Summary Report Legal Well Name: 1 L-25 Common Well Name: 1 L-25 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date ~ From - To ~ Hours ~~ Task Code ~ NPT -_ _ _ ___ _ 12/14/2005 ~ 00:00 - 00:20T 0.33 CASE ~ P 00:20 - 00:30 ! 0.171 CASE I P 00:30 - 01:00 I 0.501 CASE I P 01:00 - 01:40 I 0.671 CASE I P 01:40 - 01:45 I 0.081 CASE I P 01:45 - 03:50 I 2.081 CASE I P 03:50 -04:05 0.25 CASE P 04:05 - 04:35 0.50 CASE P 04:35 - 05:00 0.42 CASE P 05:00 - 05:30 0.50 CASE P 05:30 - 07:30 2.00 CASE P 07:30 - 10:30 3.00 CASE P 10:30 - 12:30 2.00 ~ CASE P 12:30 - 13:30 ~ 1.00 ~ CASE ~ P 13:30 - 15:30 2.00 CASE P 15:30 - 16:00 0.50 CASE P 16:00 - 17:30 1.50 STKOH P 17:30 - 19:20 ~ 1.83 ~ STKOH ~ P 19:20 - 19:40 0.331 STKOH P Spud Date: 11 /25/2005 Start: 11/27/2005 End: 12/28/2005 Rig Release: 12/28/2005 Rig Number: Phase i Description of Operations 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 ...) RUNPRD RIH at O.i7l1900 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 RUNPRD Continue RIH w/ no resistance at 10637' ... RIH at 40'/min to set down at 10808'. PUH at 26.5k verifying liner still on. Work to get thru various set-down spots to 10837'. Orient 360 deg and started moving again w!o pump RUNPRD Continue RIH from 10845' w/ +2k, but no returns. Incr rate to 0.5/2890 w/ 800 psi whp and RIH at 18'/min w/ full returns following assumed DTF. Start climbing the hill at 10950' w/ +1.5k. 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 w1830 psi whp. SD pump and work to planned TD of 11585' 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 19.5k and GS released from liner. Left TOL at 99tT and BOL at 11585' 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 RUNPRD Tag up. Close TRSSSV. Check for flow RUNPRD Displace CSH and tubing above TRSSSV w/ FW RUNPRD LD MWD assy and GS. A few minor fresh scars on OD of GS RUNPRD Safety mtg. RU to LD CSH RUNPRD LD 51 CSH singles RUNPRD Hold PJSM with crew. MU "A" 2-3/8" liner assembly, 30 jts slotted & solid pipe with bullnose guide shoe and Weatherford aluminum billet. Inspect GS spear. Much smaller than BTT spear. No square shoulders noted. Stab coil. Get on well. RUNPRD Pressure well to 900 psi. Open SSSV. Run in hole following WHP schedule. 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. RUNPRD Pull out of hole. Hold WHP as per schedule. RUNPRD LD liner running BHA. LD Weatherford tools for load out. 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. PROD2 RIH w/ BHA #16 circ thru bit 0.4/2210 following pressure schedule. Open TRSSSV w/ 900 psi PROD2 Log tie-in down from 8770', corr +2'. RIH at 0.4/2100 and tag. 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 EXPLORATfON Page 19 of 30 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ~ Name: 1 ell Name: 1 e: Name: From - To L-25 L-25 REENTE NORDIC NORDIC Hours ~ R+COM CALIST 2 Task PLET A Code E PT Start Rig Rig Phase ~ Spud Date: 11/25/2005 : 11/27/2005 End: 12/28/2005 Release: 12/28/2005 Number: 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 stow 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 Backream at drilled TF 1.5/3330/60L at 10'/min to 8910', clean. Ream in hole 1.5/3380/60L at 8'lmin 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 asst'. Remove unuseable 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 15'!hr 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 Drill 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 turn to azm: +/-100 deg. 12:00 - 16:15 4.25 DRILL P PROD2 Drill lateral to 9225'. Continue turn 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 turn asst'. Adjust motor, rerun bit 19:10 - 20:40 1.50 DRILL P PROD2 RIH w/ BHA #18 (HCC bi bit, 1.0 deg motor) following 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 point w/ no MW. Wiper to TD tagged at 9225' PVT 414 21:20 - 23:00 1.67 DRILL P PROD2 Drill from 9225' 1.55/3450/90L 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' 1.62/3380/85L 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 11:13:50 AM i BP EXPLORATION Page 20 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 12/16/2005 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 following 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 tite in spots. Tag at 9253'. Backream to 9210'. Ream back down at 1'/min from 9215' 1.6/3530 w/ 3.5k extra 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 i P ~ PROD2 Drill ahead from 9550'. 3890 psi fs at 1.6 in/out. ROP erratic. Printed: 1/3/2006 11:13:50 AM BP EXPLORATION Page 21 of 30 Operations Summary Report Legal Well Name: 1 L-25 Common Well Name: 1 L-25 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Start: 11 /27/2005 Rig Release: 12/28/2005 Rig Number: Spud Date: 11/25/2005 End: 12/28/2005 i Date !From.- To I Hours I Task j Code __ 12/i7/2005 06:15 - 10:20 4.08 DRILL P 10:20 - 11:30 1.17 DRILL P 11:30 - 15:00 I 3.501 DRILL I P 15:00 - 18:00 3.00 DRILL P 18:00 - 20:30 2.50 DRILL P 20:30 - 21:10 0.67 DRILL P 21:10 - 21:20 0.17 DRILL P 21:20 - 22:00 0.67 DRILL P 22;00 - 23:15 1.25 DRILL P 23:15 - 00:00 0.75 DRILL P 12/18/2005 00:00 - 01:45 1.75 DRILL P 01:45 - 03:00 1.25 ~ DRILL ~ P 03:00 - 04:30 I 1.501 DRILL I P 04:30 - 04:50 0.33 DRILL P 04:50 - 05:30 0.67 DRILL P 05:30 - 05:45 0.25 DRILL P 05:45 - 06:00 0.25 DRILL P 06:00 - 06:30 0.50 DRILL P 06:30 - 08:15 1.75 DRILL P 08:15 - 10:00 1.75 DRILL P 10:00 - 10:30 0.50 DRILL P 10:30 - 11:15 0.75 CASE P 11:15 - 12:15 I 1.001 CASE I P 12:15 - 12:45 0.50 CASE P 12:45 - 15:15 2.50 CASE P NPT ' Phase Description of Operations PROD2 Looked like Kalubik, but apparently not. PROD2 Wiper trip to above window. Log gr tie in. Subtract 2' correction. Run in hole. Hole smooth each way. PROD2 DriN ahead from 9700'. 3700 psi at 1.55 in/out. DPSI: 100-200 IA/OA/ PVT: 704/864/371 bbls. INC/AZM/TF: 88-91/61-100/240-280L. Drill several slow intervals, expecting each to be the Kalubik. Then ROP increases yet again. PROD2 Drilling ahead at 9760'. 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 .. . PROD2 Wiper to window, clean PROD2 Log tie-in down from 8770', corr +1.5' PROD2 Wiper to TD was clean PROD2 Drill from tag at 9840' 1.63/3740/45L w/ max suf wt and 100-200 psi diff. Still have slow and intermittent penetration rate. Drill to 9855' and assume motor problem PROD2 Wiper thru window was clean 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 PROD2 LD drilling BHA. Motor was slightly overtite, bit had more wear than expected 3-3-I. Change out both, add DPS PROD2 RIH w/ BHA #21 circ thru bit 0.35/2100 following pressure schedule. Open TRSSSV w/ 900 psi PROD2 Log tie-in down from 8760', corr -2' PROD2 Wiper thru window and OH was clean to set down at 9840' 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 PROD2 Wiper while wo crew change 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, PROD2 Wiper trip to above window. Run to btm. Lay in 40 bbls clean flo pro pill. Pull through window. PROD2 Circulate out of hole. Wash SSSV. Jog in hole at surface. Tag up. PROD2 Get off well. LD BHA tools. RUNPRD Rig up floor to run liner. Hold PJSM to discuss handling jointed pipe, assignments, hazards, procedures. RUNPRD MU 14 jts 2'-3/8" slotted., L80, 4.3#, STL liner with bull nose guide shoe and Weatherford 2.5" aluminum billet. OAL: 470.8' RUNPRD MU MWD tools. Stab coil. Test MWD. Get on well. RUNPRD Run in hole. Pressure well to 900 psi. Open SSSV. Continue to RIH. Follow WHP schedule. Weight check with shoe at window: 21 k# up, 6k# do wt. Run into open hole. Log GR tie in. Subtract 2' correction. Continue to RIH. Weigh4 check near btm. 25k# up, 5 k# do wt. Push through Printed: 7/3/2006 17:13:50 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 ! 12/18/2005 From - To 12:45 - 15:15 '~~ Hours I 2.50 Task !Code CASE P NPT Phase RUNPRD Description of Operations Kalubik and tag btm at 9855'. Circ at 1.33 bpm at 4435 psi to 15:15 - 17:00 17:00 - 17:30 17:30 - 21:30 21:30 - 23:15 23:15 - 23:35 23:35 - 00:00 12/19/2005 00:00 - 00:30 release GS spear. PU wt: 21 k#. Appear to be released. BOL:9855'. TOL:9384'. i.75 CASE P RUNPRD POOH while circulating through GS. Wash SSSV area. Pull out to surface. 0.50 CASE P RUNPRD Flow check. Get off well. LD BHA tools. 4.00 DRILL P PROD3 E-line slack management. Cut off 105' of a-line 1.75 STKOH P PROD3 RIH w/ BHA #23 (1.9 deg motor, used HCC STR324) following pressure schedule. Open TRSSSV @ 900 psi 0.33 STKOH P PROD3 Log tie-in down from 8770', corr -3.5' 0.42 DRILL P 0.50 STKOH P 00:30 - 01:20 0.831 STKOH ~ P 01:20 - 02:30 1.17 STKOH P 02:30 - 03:00 0.50 STKOH P 03:00 - 03:30 03:30 - 05:30 05:30 - 06:30 06:30 - 07:00 07:00 - 07:30 07:30 - 09:00 09:00 - 09:30 09:30 - 13:00 0.50 STKOH P 2.00 STKOH P 1.00 STKOH P 0.50 BOPSU P 0.50 DRILL P 1.50 DRILL P 0.50 DRILL P 3.50 DRILL P 13:00 - 19:45 I 6.751 DRILL I P 19:45 - 20:45 1.00 DRILL P 20:45 - 00:00 3.25 DRILL P PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 12/20/2005 00:00 - 01:00 1.00 DRILL P PROD3 01:00 - 01:35 0.58 DRILL P PROD3 01:35 - 01:50 0.25 DRILL P PROD3 01:50 - 02:30 0.67 DRILL P PROD3 02:30 -04:00 1.50 DRILL P PROD3 04:00 - 04:25 0.42 DRILL P PROD3 04:25 - 06:00 1.58 DRILL P PROD3 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 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 RIH at 0.1'/min and begin departure from billet. Small aluminum flakes in samples Start adding wt and incr penetration rate from 9383' and drill at 15-20'/hr. Drill to 9400' at 150E 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 Wiper to above TOC was clean. Open EDC POOH circ thru EDC at 1.8/3400 following pressure schedule. Wash TRSSSV and close w/ 900 psi LD sidetrack BHA Function test BOPs. MU BHA #24, lateral 1.0 deg mtr w/ HYC re-reun bi-center bit. Stab coil. Get on well. Run in hole. Pressure well to 900 psi. Open SSSV. Continue in hole. Log GR tie in. Subtract 1' correction. Begin displacement to new mud. Drill ahead from 9400'. 3450 psi fs at 1.6 in/out. DPSI: 100-200 DHW06:1.95k#. WHP/BHP/ECD: 15/3607/11.92 ppg IA/OA/PVT: 350/573/438 bbls. Hold incl at 82-83 deg to continue drop. Displacement to new mud completed. Drill ahead from 9473'. ROP varying from 10 to 50 fph. Drill to 9700' Wiper to window was clean both directions PVT 443 Drill from 9700' 1.64/3500/708 w/200-400 psi dill, 1-4k wob w/ 12.0 ECD at 81 deg at 5888' TVD Drill from 9815' to 9850' (5900' TVD) Wiper to window was clean. Pull thru window Log tie-in down from 8770', corr +2.5' Wiper back to TD was clean PVT 442 Drill from 9851' 1.6/3560/858 w/ 100-300 psi dill, 1-3.5k wob w/ 12.19 ED at 90 deg at 5900' TVD. Swap to left at 9900'. Drill to 9917' and stacking Wiper/ream to remove TF change Drill from 9917' 1.59/3580/100L w/ 100-300 psi diff, 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 Operations Summary Report Legal Well Name: 1 L-25 Common Well Name: 1 L-25 Event Name: REENTER+COMPLETE Start: 11/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: I NPTl Phase Date From - To Hours Task Code __ - -- _ _ -- -ff __ 12/20/2005 04:25 - 06:00 I 1.581 DRILL P I PROD3 06:00 - 07:45 ~ 1.751 DRILL ~ P I PROD3 07:45 - 11:00 ~ 3.251 DRILL ~ P PROD3 11:00 - 12:40 1.67 DRILL P PROD3 12:40 - 16:30 3.83 DRILL P PROD3 16:30 - 18:25 1.92 DRILL P PROD3 18:25 - 19:15 0.83 DRILL P PROD3 19:15 - 19:30 0.25 DRILL P PROD3 19:30 - 19:40 0.17 DRILL P PROD3 19:40 - 00:00 ~ 4.33 ~ DRILL ~ P ~ PROD3 12/21/2005 ~ 00:00 - 06:25 ~ 6.42 ~ DRILL ~ P ~ ~ PROD3 06:25 - 07:30 1.08 DRILL P PROD3 07:30 - 09:30 2.00 DRILL P PROD3 09:30 - 11:00 I 1.501 DRILL I P I I PROD3 11:00 - 12:40 I 1.671 DRILL I P I I PROD3 12:40 - 13:00 0.33 DRILL P PROD3 13:00 - 13:35 0.58 DRILL P PROD3 13:35 - 14:40 1.08 DRILL P PROD3 14:40 - 15:20 0.67 DRILL P PROD3 15:20 - 15:45 0.42 DRILL P PROD3 15:45 - 16:15 0.50 DRILL P PROD3 16:15 - 16:35 0.33 DRILL P PROD3 16:35 - 17:05 0.50 DRILL N STUC PROD3 Page 23 of 30 Spud Date: 11 /25/2005 End: 12/28/2005 Description of Operations crossed fault and into Bsiltstone/shale. Begin climb towards 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) 1.65/3650l85L w/ 100-200 psi dill, 1-2k wob w/ 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 in/out of siderite stringers 1.59/3580/90L 12.4ppg EDC, 2K wob 5-10'/hr. 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 UOC. Motor was sli loose, bit was 2-2-I w/ worn 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 10'/min for 50', okay. RIH at full pump at 15'/min to set down at 9830'. PUH w/ motor stalled and 15k overpull. 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 to 9813' relatively clean. Work to 9846' and set down, 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 at 0.9 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 plan/point to sidetrack Wiper to window while displace to fresh mud was clean At 8900' pulled tite and packed off. Can't go up or down. Printed: 1/3/2006 11:13:50 AM BP EXPLORATION Operations Summary Report Legal Well Name: 1 L-25 Common Well Name: 1 L-25 Event Name: REENTER+COMPLETE Start: 11/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date ~ From - To ~~~, Hours ~ Task Code 1 NPT Phase 12/21/2005 16:35 - 17:05 ~ 0.50 DRILL N ~STUC PROD3 17:05 - 17:30 I 0.421 DRILL I P I I PROD3 17:30 - 19:20 1.831 DRILL I P PROD3 19:20 - 20:00 0.67 DRILL P PROD3 20:00 - 20:15 0.25 CASE P PROD3 20:15 - 20:45 0.50 CASE P PROD3 20:45 - 21:50 1.08 CASE P PROD3 21:50 - 23:50 23:50 - 00:00 2.001 CASE I P 0.171 CASE I P PROD3 PROD3 12/22/2005 00:00 - 01:30 01:30 - 03:15 03:15 -04:40 04:40 - 04:55 04:55 - 05:20 05:20 - 06:00 06:00 - 09:55 09:55 - 10:30 10:30 - 11:00 11:00 - 12:00 i 2:00 - 13:45 13:45 - 14:20 14:20 - 14:45 1.50 CASE P 1.75 STKOH P 1.42 STKOH P 0.25 STKOH P 0.42 STKOH P 0.67 STKOH P 3.92 STKOH P 0.581 STKOH I P 0.50 STKOH P 1.00 STKOH P 1.75 STKOH P 0.58 STKOH P 0.42 STKOH P PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 Page 24 of 30 Spud Date: 11 /25/2005 End: 12/28/2005 Description of Operations Pump down CT at 0.5 bpm/1800 and motor was not stalled. Limit max pull to 25k initial. Work it various ways w/ no returns. Pressure well up to 800 psi, dump it while pulling a bind and came free at 35k Wiper up hole to 20' below window, wiper in hole to 8950'. Wiper up hole and thru window at 1.3/3700/30L taking returns w/ 300 psi and while finish displacement to new mud POOH circ thru EDC 1.9/3800. Wash up around SSSV at 1810' through opened EDC. LD BHA PJSM: Discuss plan foward for PU of liner and BHi tools. RU to run liner. PU 6 jts of solid, 4jts slotted 2-3/8" 4.2# STL liner and W F aluminum sidetrack billet. PU BHI tools. Stab injector. 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'. TOH following pressure schedule. The cased hole section and openhole below will now be referred to as Li-02 PB1 Finish TOH. Observe well after closing SSSV. Hold PJSM review plan forward. UD WF and BHi tools. MU 1.9 deg motor and sidetrack bit.. Surface test tools. MU BHA #27. RIH open SSSV Log tie-in -5' correction. RIH 20L thru window no problem. RIH tagged billet at 9488'. Start sidetrack. From 9475' trough at 308 Park at 9488' for 5 min at 308 1.58/3650. Begin RIH 0.1'/min. Stalled at 9491.2'. PUH and ream back down. RIH from 9491.2' at 0.1'/min. 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 PUN 19.5k to 9470', clean. RIH to 9521' at 308, clean. Orient to 180 deg and red rate to 0.5/2340 w/ 500 psi whp. RIH and stack 5k from 9532'. PUH to 9490', orient to 908 (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 Run the numbers w/ the new targets and determine can still make it RIH and tag again at 9532' and stack full wt. PUH and park at 9531.0' for 5 min 1.57/3580/308. Begin RIH at 0.1'/min to begin sidetrack 9536' No motor work so far, but getting more and smaller aluminum pieces over shaker No motor work by 9547'. NB incl shows we are still in the old hole. RIH at 1.0'/min and stall at 9559'. PUH 20k and discuss. We must be in contact w/ the liner and are vibrating it down. Will run another billet on liner W iper thru open hole was clean Printed: 1/3/2006 11:13:50 AM BP EXPLORATION Page 25 of 30 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ~, Name: 1 ell Name: 1 e: Name: From - To L-25 L-25 REENTE NORDIC NORDIC Hours R+COM CALIS 2 Task PLET TA i Code j E PT Start Rig Rig Phase Spud Date: 11/25/2005 : 11/27/2005 End: 12/28/2005 Release: 12/28/2005 Number: Description of Operations 12/22/2005 14:45 - 16:45 2.00 STKOH P PRODS Open EDC. POOH for liner following pressure schedule 1.7/3340 16:45 - 17:30 0.75 STKOH P PRODS LD sidetrack assy and recontigure. Grease injector 17:30 - 18:00 0.50 STKOH P PRODS RU to run liner 18:00 - 18:10 0.17 STKOH P PRODS PJSM: Review plan forward with liner running and safety concerns. 18:10 - 19:40 1.50 STKOH P PRODS PU 8 jts 2-3/8" slotted/solid liner and Weatherford aluminum billet. PU BHi tools. 19:40 - 22:10 2.50 STKOH P PRODS RIH open SSSV continue RIH following pressure schedule. 22:10 - 22:30 0.33 STKOH P PRODS 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'. 22:30 - 00:00 1.50 STKOH P PRODS TOH following pressure schedule. Wash up on SSSV and close. 12/23/2005 00:00 - 00:15 0.25 STKOH P PRODS Finish TOH. Check well for flow. PJSM. Review next BHA change. 00:15 - 01:55 1.67 STKOH P PRODS Changeout injector packoff while surface testing BHi tools. PU BHA #29 01:55 - 03:30 1.58 STKOH P PRODS RIH open SSSV continueRlH following pressure schedule. 03:30 - 03:45 0.25 STKOH P PRODS Log tie-in -4.5' 03:45 -04:00 0.25 STKOH P PRODS Close ECD RIH 20L thru window. Tagged TOL at 9313'. 04:00 - 06:00 2.00 STKOH P PRODS 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 06:00 - 08:45 2.75 STKOH P PRODS 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'/min. 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 08:45 - 09:10 0.42 STKOH P PRODS 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 09:10 - 11:00 1.83 STKOH P PRODS POOH circ thru EDC 1.8/3400 following pressure schedule. Close TRSSSV w/ 900 psi 11:00 - 12:00 1.00 STKOH P PRODS Change bit, chk motor 12:00 - 13:40 1.67 STKOH P PRODS RIH w/ BHA #29 (1.9 deg motor w/ R60ST bit) following pressure schedule. Open TRSSSV w/ 800 psi 13:40 - 13:55 0.25 STKOH P PRODS Log tie-in down from 8770', corr -5' 13:55 - 14:15 0.33 STKOH P PRODS RIH at 0.5/2320 w/ 400 psi whp thru open hole to wt loss at 9323' and stack full wt w/o movement. PUH w/ 5k 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. Repeat just to be sure 14:15 - 15:25 1.17 STKOH P PRODS 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'/min down, 4'/min down, 1'/min 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 EXPLORATION Page 26 of 30 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 1 ell Name: i e: Name: From - To L-25 L-25 REENTE NORDIC NORDIC Hours ~ R+COM CALIST 2 Task ~ PLET A Code E NPT Start Rig Rig Phase Spud Date: 11/25/2005 : 11/27/2005 End: 12/28/2005 Release: 12/28/2005 Number: I~ 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 0.921 STKOH P PRODS Ream down to 9325' w/ 1558 10'/min. Backream to 9270' w/ 908 TF at 2'/min. Ream down to 9325' w/ 1558. 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 STKOH P PRODS UD OHST BHA 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'/hr. 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 w/ 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. Drill 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 PRODS Drill from 9625' 1.58/3520/908 w/ 200-400 psi diff, 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', corr +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'/hr ann= 3749 ECD= 12.31 ppg 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' 1.61l3500/345TF 1-2K wob 50'-60'/hr CTW neutral to +1 k. 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 I well. Printed: 1/3/2006 11:13:50 AM BP EXPLORATION Page 27 of 30 Operations Summary Report Legal Well Name: 1 L-25 Common Well Name: 1 L-25 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date ~' From - To 'Hours Task Code NPT 12/24/2005 23:30 - 00:00 0.50 DRILL N RREP 12/25/2005 00:00 - 02:00 2.00 DRILL N RREP 02:00 - 02:30 0.50 DRILL N RREP 02:30 - 03:45 1.25 DRILL N RREP 03:45 - 04:30 0.75 DRILL N RREP 04:30 - 06:00 1.50 DRILL N RREP 06:00 - 06:15 0.25 DRILL N RREP 06:15 - 12:00 5.75 DRILL N RREP 12:00 - 18:00 6.00 DRILL N RREP 18:00 - 18:30 0.501 DRILL N 18:30 - 18:45 I 0.251 DRILL I N 18:45 - 19:10 I 0.421 DRILL I N 19:10 - 21:00 I 1.831 DRILL I N 21:00 - 21:35 0.58 DRILL N 21:35 - 23:15 1.67 DRILL N 23:15 - 23:30 0.25 DRILL N 23:30 - 00:00 0.50 DRILL N 12/26/2005 00:00 - 01:35 1.58 DRILL N 01:35 - 02:30 I 0.921 DRILL I P Spud Date: 11 /25/2005 Start: 11/27/2005 End: 12/28/2005 Rig Release: 12/28/2005 Rig Number: Phase ~ Description of Operations PRODS Called AOGCC gave notice for early BOP test. PRODS Merry Christmas. Continue TOH. Close SSSV trapping 950psi on well. Pull to 190' bleed down well and monitor. tag up setback injector. PRODS LD BHA PRODS Circulate coil and rig-up for N2. Hold PJSM for N2. PRODS Slowdown reel with N2 to Tiger Tank. PRODS Make preparations to unstab coil from injector and secure to reel. PRODS Safety mtg re: pull CT back to reel PRODS Pull CT back to reel and secure Safety mtg re: SIMOPS Begin bi weekly BOPE 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 PRODS Nordic crew change Safety mtg. Pull test internal grapple. Pull CT to injector and stab. Change packoff. Install temp CTC.. 51ack management, cut off 60' CT. Install CTC. MU BHi's UOC start dressing electrical connection. 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. 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. PRODS Remove BHi's UOC and Kendal CTC. Cut 120' coil back to unfrozen mud. Secure 5' E-line to side of injector and stab over bunghole. Circulate and warm coil. 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. PRODS MU BHA #31 stab on injector. Surface test tools -good. PRODS RIH PRODS Log tie-in -2.5' PRODS RIH. Problems at 9646' worked down to 9693'. 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. Pulling tight off bottom. Work back down cleaned up at 9740' area. RIH to 9774'. PU overpulls 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. 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 Operations Summary Report Legal Well Name: 1 L-25 Common Well Name: 1 L-25 Event Name: REENTER+COMPLETE Start: 11/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/28/2005 Rig Name: NORDIC 2 Rig Number: Date j From - To Hours Task Code NPT Phase ~ 12/26/2005 ~ DRILL P ~ PROD3 101:35 - 02:30 0.92 ~- ~- 02:30 - 03:15 I 0.751 DRILL I P 03:15 - 04:00 I 0.751 DRILL I P 04:00 - 05:50 ~ 1.83 ~ DRILL ~ P 05:50 - 06:15 I 0.421 DRILL I P 06:15 - 06:55 ~ 0.67 ~ DRILL ~ P 06:55 - 07:45 I 0.831 DRILL I P 07:45 - 08:20 I 0.581 DRILL I P 08:20 - 10:20 I 2.001 DRILL I P 10:20 - 10:40 0.331 DRILL P 10:40 - 12:15 1.58 DRILL P 12:15 - 13:10 0.92 DRILL P 13:10 - 13:25 0.25 DRILL P 13:25 - 14:20 0.92 DRILL P 14:20 - 16:15 I 1.921 DRILL I P 16:15 - 18:00 1.75 DRILL P 18:00 - 20:20 2.33 DRILL P 20:20 - 20:40 0.33 DRILL P 20:40 - 23:00 2.33 DRILL P Page 28 of 30 Spud Date: 11 /25/2005 End: 12/28/2005 Description of Operations coming over shakers. Call for trucks to do a mud swap. 1-2k wob 40-50'/hr 300psi MW 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'. 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. Continue to drill ahead fl 10020' 1.53/3600/80L 1-2k wob 50-60'/hr neutral CTW 12.17ppg ECD StarUfinish mud swap. Penetration rate erratic from 10050' Attempt to drill from 10080' 1.58/3660/80L w/ 12.17 ECD and have stacking w/ overpulls. Minor packing off Wiper to window 1.55/3650 w/ 12.0 ECD avg. Minor overpulls 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 overpulls and 100 psi MW to 8850' 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 w/ 200 psi whp w/ 12.5 ECD and was clean to TD except for TF change areas. Start stacking wt from 10078'-assume another shale or formation change Resume drilling 1.57/3750/90L w/ 0-250 psi diff, 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 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' Wiper to 9900' was clean going up-hole, but had set downs at 10036' and 10123' when RIH Drill from 10166' 1.56/3780/90-120L w/ 12.4 ECD. Drill to 10215' and stacking Wiper to window was clean. Pull thru window Log tie-in down from 8770', Corr +4' 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 Attempt to drill and have trouble getting wt to bit. Also, had sticky pickups. Do a couple 70' wipers w/ TF 180 out and start drilling, but acts like siderite Drill from 10236' 1.63/3960/15L w/ 12.4 ECD in siderite 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 1 k 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 Make a BHA wiper trip. Turn TF to 15L Drill ahead. 1.74/4200/60L 1.2k wob <6'/hr. ROP progressively PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 Printed: 1/3/2006 11:13:50 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 L-25 1 L-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To ~ Hours Task ~ Code ~, NPT 12/26/2005 20:40 - 23:00 2.33 DRILL P 23:00 - 00:00 1.00 DRILL P 12/27/2005 00:00 - 02:00 2.00 DRILL P 02:00 - 03:00 1.00 DRILL P 03:00 - 04:45 1.75 DRILL P 04:45 - 05:00 0.25 DRILL P 05:00 - 05:50 0.83 DRILL P 05:50 - 08:20 I 2.501 DRILL I P 08:20 - 10:10 I 1.831 DRILL I P 10:10 - 11:10 ( 1.00 I DRILL I P 11:10 - 12:50 I 1.671 DRILL I P 12:50 - 13:05 0.25 DRILL P 13:05 - 13:20 0.25 DRILL P 13:20 - 14:25 1.08 DRILL P 14:25 - 17:00 I 2.581 DRILL I P 17:00 - 18:30 1.50 DRILL P 18:30 - 18:45 0.25 CASE P 18:45 - 21:30 ~ 2.75 ~ CASE ~ P 21:30 - 22:30 I 1.001 CASE I P 22:30 - 00:00 1.50 CASE P 12/28/2005 00:00 - 00:45 0.75 CASE Page 29 of 30 Spud Date: 11/25/2005 Start: 11/27/2005 End: 12/28/2005 Rig Release: 12/28/2005 Rig Number: Phase Description of Operations PRODS slower even with 1.87k WOB. This is the house of pain. PRODS TOH. 18k off bottom. Hole in good shape coming out. PRODS Continue TOH following pressure schedule. Close SSSV. Bleed-off well and monitor. Setback injector. PRODS PU Aggitator tool and new bit. Replace upper check vavles. PRODS Surface test tools. RIH following pressure schedule after opening SSSV PRODS Log tie-in -5.5' PRODS Wiper to TD at normal pump rate and RIH speed. Set down w/ TF 180 out at 9871', but otherwise clean. Adding 100-200 psi induced whp to keep 12.5-12.7 ECD on 62 shales seems to work. Tag TD at 10276' w/ +2k string wt, bleed off whp PRODS 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 on intermittent penetration rate increases. Swap to right at 10294'? 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 w/ steady (10'/hr) penetration rate. Inadvertently built angle quicker than expected to 95 deg, but may be helping get drilled out of the siderite 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. PRODS Wiper back into tbg. Collect samples. Give town the info. WOO. TD has been called here. PRODS RIH to tie-in point. PRODS Log tie-in +1' correction. 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. PRODS TOH. Minor overpull at 9650'. Paint EOP flag at 8650'. Confine TOH following pressure schedule. PRODS Lay down final drilling BHA. RUNPRD PJSM Re: Running liner. Discuss hazards and mitigations. Review liner run order. Doug Walton with Baker TT here to run liner. 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 2-3/8" 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'. RUNPRD Make up BHI MWD tool to top of liner. Service UOC. Stab injector. RUNPRD RIH with liner BHA, following pressure schedule. RUNPRD Wt check at window = 20 klbs. RIH smooth thru the window. RIH wt = 8000 lbs. Holding 350 psi on WHP, circulating at Printed: 1/3/2006 11:13:50 AM i BP EXPLORATION Operations Summary Report Legal Well Name: 1 L-25 Common Well Name: 1 L-25 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 I Date ~ From - To ~~~ Hours Task Code _ -_ - '~ 00:00 - 00:45..1 _-- - - 12/28/2005 ~ 0.75 ~ CASE 00:45 - 00:55 0.17 CASE 00:55 - 01:30 0.58 CASE 01:30 - 03:15 1.75 CASE 03:15 - 04:15 1.00 CASE 04:15 - 04:30 0.25 RIGD 04:30 - 10:00 5.50 RIGD 10:00 - 10:30 0.50 RIGD 10:30 - 11:00 ~ 0.50 ~ DEMOB Start: 11 /27/2005 Rig Release: 12/28/2005 Rig Number: NPT Phase -__ ___ RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD POST POST Page 30 of 30 Spud Date: 11/25/2005 End: 12/28/2005 Description of Operations 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'. Shut the EDC. Current DHWOB=2000 Ibs. Bring pumps on line to 1.35 bpm, 4200 psi circ pressure. PU at 17000 Ibs string wt. DHWOB sensor at -200 Ibs. Confirmed released from liner. Keep pumps on. Log tie in pass accross GR charecter 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. POH. Pumping mud to keep hole full and following pressure schedule as we POH.. Freeze protect top 2000' with diesel on way OOH. Lay down liner running BHA. All liner running eq recovered ok. 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 that you don't interfer with other operations taking place on the rig. Nipple down tree,install cap and test to 5K. Clean mud pits. Rig Released at 1000 hrs 12-28-2005 POST Hold PJSM review procedures and hazards for movin rig off well. 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 i BP Alaska Baker Hughes INTEQ Survey Report ~_ -_- _ _- Company: ConocoPhillips Alaska, Inc. Date: 1/10/2006 'time: 16:45:41 Page: 1 Field: Kuparuk River Unit Cu-ordinate(NN~) Reference: Well: 25, True North Site: KRU 1L Pad Vertical (TVD) Reference: slot 25 130.0 Well: 25 Section (VS) Reference: Well (O.OON,O.OOE,235.OOAzi) Wetlpath: 1L-25APB1 Snrvcy Calculafion Method: Minimum Curvature Db: Sybase __ - -- , - -- -- - - - - - _ __ 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: Weft Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: KRU 1L 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 W ell: 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 Wetlpath: 1 L-25APS1 Drilled From: 1 L-25 500292217401 Tie-on Depth: 8800.00 ft Current Datum: slot 25 Height 130.00 ft Above System Datum: Mean Sea Level Magnetic Data: 9/26/2005 Declination: 24.08 deg Field Strength: 57604 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 0.00 235.00 Survey Program for Definitive Wetlpath Date: 10/28!2005 Validated: No Version: 2 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 8945.00 MWD (8834.00-8945.00) MWD MWD -Standard Annotation MU TVD ft ft 8800.00 5951.58 TIP 8834.00 5973.06 KOP 8945.00 6001.00 TD Survey: MWD Start Date: 12!2/2005 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD Intl Azim 1'VD Sys TVD N/S E/W 11apN Mapb: VS DLS 'fool ft deg deg ft ft ft ft ft ft ft deg/100ft 8800.00 50.85 162.07 5951.58 5821.58 -5946.39 1416.89 5942433.02 541371.13 2250.06 0.00 MWD 8834.00 50.75 161.95 5973.06 5843.06 -5971.45 1425.02 5942408.01 541379.40 2257.77 0.40 MWD 8864.34 69.26 161.95 5988.17 5858.17 -5996.32 1433.13 5942383.18 541387.64 2265.40 61.01 MWD 8895.27 80.38 169.00 5996.26 5866.26 -6025.17 1440.55 5942354.38 541395.21 2275.86 42.13 MWD 8917.77 82.32 179.00 5999.65 5869.65 -6047.26 1442.87 5942332.30 541397.65 2286.64 44.77 MWD 8945.00 92.00 186.00 6001.00 5871.00 -6074.38 1441.68 5942305.18 541396.60 2303.17 43.83 MWD r BP Alaska Baker Hughes INTEQ Survey Report BAK R w~raaec ~~ Company: ConocoPhillips Alaska, Inc. Dute: 1/10/2006 'l'ime: 16:3321 Page: 1 Field: Kuparuk River Unit Co-ordinate(NN;) Reference: Well: 25, True North Site: KRU 1 L Pad Vertical (TVD) Reference: slot 25 130.0 We1L 25 Section (VS) Reference: Well (O.OON,O.OOE,235.OOAzi) _W'ellpath: 1 L-25A Survcv Calculation Nfcthod: Minimum Curvature Db: Sybase 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 Well Position: +N/-S -596.97 ft Northing: 5948371.23 ft +E/-W -143.01 ft Easting : 539922.87 ft Position Uncertainty: 0.00 ft Wellpath: 1 L-25A 500292217401 Current Datum: slot 25 Height 130.00 ft Magnetic Data: 12/6/2005 Field Strength: 57612 nT Vertical Section: Depth From (TVD) +N!-S ft ft 0.00 0.00 Survey Program for Definitive Wellpath Date: 1 2/612 0 0 5 Validated: No Actual From To Survey ft ft Slot Name: Latitude: 70 16 11.588 N Longitude: 149 40 37.713 W Drilled From: 1 L-25 Tie-on Depth: 8800.00 ft Above System Datum: Mean Sea Level Declination: 24.00 deg Mag Dip Angle: 80.72 deg +E/-W Direction ft deg 0.00 235.00 Version: 0 Toolcode Tool Name 100.00 8800.00 GYRO (100.00-9353.00) (0) Good gyro Good Gyro 8834.00 11929.00 MWD (8834.00-11929.00) MWD MWD -Standard Annotation - - :fID - TVD - - - ~~ ~~ ft ft 8800.00 5951.58 TIP 8834.00 5973.06 KOP 11929.00 5977.17 TD Survey: MWD Start Date: 1216!2005 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey M11D ft 8800.00 8834.00 8863.52 8891.37 8920.23 8949.49 8980.46 9011.38 9056.12 9092.24 9133.19 9164.36 9192.35 9221.32 9253.28 Inc! A~iro deg deg 50.85 162.07 50.75 161.95 60.80 164.62 72.29 166.83 83.13 168.90 91.79 178.42 94.41 179.14 96.85 181.99 94.87 186.11 92.66 189.15 94.17 194.96 93.64 200.86 92.56 206.69 92.63 210.22 90.45 214.30 T'V D ft 5951.58 5973.06 5989.65 6000.72 6006.85 6008.15 6006.47 6003.44 5998.87 5996.50 5994.06 5991.93 5990.42 5989.11 5988.25 Sys TVD ft 5821.58 5843.06 5859.65 5870.72 5876.85 5878.15 5876.47 5873.44 5868.87 5866.50 5864.06 5861.93 5860.42 5859.11 5858.25 V/S E/W ft ft -5946.39 1416.89 -5971.45 1425.02 -5994.80 1432.00 -6019.52 1438.27 -6047.05 1444.18 -6076.04 1447.39 -6106.96 1448.05 -6137.72 1447.75 -6182.11 1444.60 -6217.82 1439.82 -6257.78 1431.28 -6287.36 1421.72 -6312.92 1410.46 -6338.36 1396.67 -6365.37 1379.63 MapN ~lapE ft ft 5942433.02 541371.13 5942408.01 541379.40 5942384.70 541386.50 5942360.01 541392.90 5942332.52 541398.95 5942303.55 541402.32 5942272.64 541403.14 5942241.88 541403.00 5942197.48 541400.09 5942161.74 541395.50 5942121.75 541387.18 5942092.12 541377.78 5942066.50 541366.65 5942040.99 541353.00 5942013.89 541336.10 VS DLS 'fool ~~ ft deg/100ft 2250.06 0.00 MWD 2257.77 0.40 MWD 2265.45 34.85 MWD 2274.50 41.89 MWD 2285.45 38.21 MWD 2299.44 43.94 MWD 2316.64 8.77 MWD 2334.53 12.10 MWD 2362.56 10.17 MWD 2386.97 10.39 MWD 2416.88 14.63 MWD 2441.67 18.96 MWD 2465.56 21.15 MWD 2491.45 12.17 MWD 2520.90 14.47 MWD v J BP Alaska Baker Hughes INTEQ Survey Report a BAKER yuc.wEs INTEQ Cmnpany: ConocoPhillips Alaska, Inc. Date: 1/10/2006 'Time: 16:33:21 Page: 2 Field: Kuparuk River Unit Co-ordinate(\E) Reference: Well: 25, True North Site: KRU 1L Pad Vertical (TVD) Reference: slot 25 130.0 WeII: 25 Section (vS) Reference: Well (O.OON,O.OOE,235.OOAzi) ~Wcllpath: 1 L-25A Survey Calculation Dlethod: Minimum Curvature Db: Sybase __ _ __ - -- -_ Sur'vcc VID Ind Azim TVD Sys TVD V1S E/W MapN ~1apE VS DLS 'fool ft deg deg ft ft ft ft ft ft ft deg/100ft I~ _ -_ _ - _ _ - _ ___ __ -_- __ _- _ __ - 9286.25 90.29 218.33 5988.03 5858.03 -6391.93 1360.10 5941987.23 541316.72 2552.13 12.23 MWD 9326.14 88.69 224.64 5988.39 5858.39 -6421.80 1333.70 5941957.23 541290.47 2590.89 16.32 MWD ~ 9356.20 89.19 229.02 5988.95 5858.95 -6442.36 1311.78 5941936.56 541268.67 2620.64 14.66 MWD 9385.32 89.98 232.41 5989.16 5859.16 -6460.79 1289.25 5941918.00 541246.23 2649.67 11.95 MWD 9415.20 88.33 235.07 5989.60 5859.60 -6478.46 1265.16 5941900.21 541222.24 2679.53 10.47 MWD 9447.01 87.80 239.55 5990.67 5860.67 -6495.63 1238.41 5941882.90 541195.59 2711.29 14.17 MWD 9477.20 86.79 243.07 5992.10 5862.10 -6510.10 1211.96 5941866.29 541169.22 2741.26 12.12 MWD 9506.83 86.45 246.12 5993.84 5863.84 -6522.79 1185.24 5941855.46 541142.57 2770.42 10.34 MWD 9536.16 88.97 249.61 5995.02 5865.02 -6533.83 1158.10 5941844.28 541115.49 2798.99 14.67 MWD 9566.34 89.68 254.31 5995.37 5865.37 -6543.17 1129.42 5941834.79 541086.86 2827.84 15.75 MWD 9603.80 91.09 257.74 5995.12 5865.12 -6552.21 1093.07 5941825.55 541050.57 2862.80 9.90 MWD 9640.19 88.76 262.57 5995.17 5865.17 -6558.43 1057.23 5941819.14 541014.76 2895.73 14.74 MWD 9673.04 89.98 266.42 5995.53 5865.53 -6561.59 1024.54 5941815.82 540982.09 2924.31 12.29 MWD 9705.38 87.52 270.97 5996.24 5866.24 -6562.32 992.23 5941814.91 540949.79 2951.21 15.99 MWD 9735.10 87.56 274.25 5997.51 5867.51 -6560.97 962.57 5941816.10 540920.13 2974.72 11.03 MWD 9762.65 88.36 270.58 5998.49 5868.49 -6559.81 935.07 5941817.12 540892.62 2996.59 13.63 MWD 9783.73 87.03 267.75 5999.34 5869.34 -6560.12 914.01 5941816.70 540871.57 3014.01 14.82 MWD 9811.98 88.57 263.59 6000.43 5870.43 -6562.25 885.87 5941814.42 540843.44 3038.29 15.69 MWD 9845.73 85.68 260.44 6002.12 5872.12 -6566.93 852.50 5941809.56 540810.10 3068.31 12.66 MWD 9874.67 83.99 257.65 6004.72 5874.72 -6572.40 824.20 5941803.94 540781.83 3094.63 11.24 MWD 9904.64 83.71 253.44 6007.94 5877.94 -6579.84 795.36 5941796.35 540753.03 3122.52 14.00 MWD 9934.14 83.40 248.72 6011.25 5881.25 -6589.34 767.63 5941786.70 540725.36 3150.68 15.93 MWD 9964.72 87.59 245.50 6013.65 5883.65 -6601.20 739.56 5941774.70 540697.35 3180.48 17.26 MWD 9994.36 88.11 241.43 6014.76 5884.76 -6614.43 713.07 5941761.33 540670.93 3209.77 13.83 MWD 10024.33 90.14 237.69 6015.22 5885.22 -6629.61 687.24 5941746.02 540645.19 3239.63 14.20 MWD 10054.35 90.97 233.44 6014.93 5884.93 -6646.58 662.48 5941728.92 540620.53 3269.64 14.42 MWD 10087.26 90.97 227.57 6014.37 5884.37 -6667.50 637.10 5941707.86 540595.26 3302.43 17.83 MWD 10116.38 90.81 222.77 6013.92 5883.92 -6688.02 616.46 5941687.24 540574.73 3331.11 16.49 MWD 10146.27 91.58 218.15 6013.30 5883.30 -6710.75 597.07 5941664.40 540555.46 3360.03 15.67 MWD 10179.44 93.88 214.17 6011.72 5881.72 -6737.49 577.53 5941637.56 540536.06 3391.38 13.85 MWD 10217.26 87.65 204.83 6011.21 5881.21 -6770.35 558.94 5941604.60 540517.65 3425.46 29.67 MWD 10250.19 91.31 205.14 6011.51 5881.51 -6800.19 545.03 5941574.69 540503.90 3453.97 11.15 MWD 10279.66 92.07 208.48 6010.64 5880.64 -6826.48 531.75 5941548.34 540490.76 3479.93 11.62 MWD 10310.43 93.40 211.07 6009.17 5879.17 -6853.16 516.49 5941521.58 540475.64 3507.73 9.45 MWD 10341.00 94.59 216.74 6007.04 5877.04 -6878.46 499.48 5941496.20 540458.77 3536.17 18.91 MWD 10376.37 92.42 220.24 6004.88 5874.88 -6906.08 477.52 5941468.46 540436.96 3570.01 11.63 MWD 10404.79 91.77 223.99 6003.84 5873.84 -6927.15 458.47 5941447.30 540418.03 3597.69 13.38 MWD 10432.71 93.34 229.07 6002.59 5872.59 -6946.33 438.24 5941428.01 540397.90 3625.27 19.03 MWD 10462.85 94.40 234.87 6000.56 5870.56 -6964.85 414.56 5941409.37 540374.32 3655.28 19.52 MWD 10502.69 90.05 241.47 5999.01 5869.01 -6985.82 380.76 5941388.21 540340.64 3695.00 19.83 MWD 10532.54 89.06 245.74 5999.24 5869.24 -6999.09 354.03 5941374.81 540313.98 3724.51 14.68 MWD 10563.28 87.71 250.09 6000.11 5870.11 -7010.64 325.57 5941363.11 540285.58 3754.45 14.81 MWD 10596.71 87.62 255.90 6001.47 5871.47 -7020.41 293.64 5941353.17 540253.71 3786.20 17.37 MWD 10640.23 91.64 265.44 6001.75 5871.75 -7027.45 250.75 5941345.90 540210.86 3825.37 23.78 MWD 10677.31 92.71 272.88 6000.34 5870.34 -7027.99 213.73 5941345.16 540173.85 3856.01 20.26 MWD 10707.75 92.10 279.68 5999.06 5869.06 -7024.67 183.52 5941348.33 540143.62 3878.85 22.41 MWD 10741.70 88.57 281.56 5998.87 5868.87 -7018.41 150.16 5941354.40 540110.23 3902.59 11.78 MWD 10778.57 88.17 274.87 5999.92 5869.92 -7013.15 113.70 5941359.47 540073.75 3929.44 18.17 MWD 10806.70 88.91 270.37 6000.63 5870.63 -7011.86 85.62 5941360.61 540045.66 3951.71 16.21 MWD 10843.61 89.52 265.47 6001.14 5871.14 -7013.20 48.75 5941359.07 540008.80 3982.68 13.38 MWD 10875.16 89.59 261.52 6001.38 5871.38 -7016.78 17.41 5941355.33 539977.49 4010.40 12.52 MWD 10907.05 90.35 258.62 6001.40 5871.40 -7022.28 -14.00 5941349.67 539946.11 4039.28 9.40 MWD 10939.58 94.04 254.12 6000.15 5870.15 -7029.93 -45.58 5941341.85 539914.58 4069.54 17.88 MWD 10971.16 98.10 252.77 5996.82 5866.82 -7038.88 -75.67 5941332.75 539884.53 4099.32 13.54 MWD 11003.25 99.83 249.42 5991.81 5861.81 -7049.14 -105.66 5941322.32 539854.61 4129.77 11.64 MWD 11037.18 99.17 241.99 5986.21 5856.21 -7062.90 -136.13 5941308.40 539824.21 4162.63 21.68 MWD 11072.23 101.06 244.22 5980.05 5850.05 -7078.51 -166.90 5941292.63 539793.52 4196.79 8.26 MWD 11103.47 93.49 244.66 5976.10 5846.10 -7091.87 -194.84 5941279.12 539765.66 4227.33 24.27 MWD Y v, ~' BP Alaska Baker Hughes INTEQ Survey Report -. B uluCE~rR1~fi Company: ConocoPhillips Alaska, Inc. Field: Kuparuk River Unit Site: KRU 1L Pad Wcll: 25 Wellpath: 1L-25A Sunset' - JID Incl .4zim ft deg deg -_ - _ -- -- 11133.12 87.34 244.17 5 11159.30 85.19 247.89 11189.34 86.42 253.08 5 11228.53 88.91 258.78 5 11269.50 90.75 265.90 5 11298.74 90.35 268.60 5 11329.77 89.43 279.38 5 11359.53 88.32 286.34 5 11389.36 87.56 288.71 5 11419.73 86.79 294.44 5 11453.19 88.79 300.91 5 11484.18 88.70 306.05 11515.79 88.36 303.97 5 11551.38 86.45 298.25 5 11581.61 87.41 294.33 5 11613.47 90.05 292.05 5 11643.95 90.93 286.65 5 11683.02 90.05 278.01 5 ~ 11712.73 90.72 274.36 5 11742.13 92.93 269.27 5 11771.80 95.88 268.44 5 11802.36 94.86 263.29 5 11832.33 93.73 257.73 5 11862.27 94.04 250.75 5 11890.42 92.01 247.87 5 .11929.00 92.01 247.87 5 Date: 1/10/2006 'l'ime: 16:33:21 Yage: i Co-ordinate(NE:) Reference: Well: 25, True North Vertical (TVD) Reference: slot 25 130.0 Section IVS) Reference: Well (O.OON,O.OOE,235.OOAzi) Survey Calculation ~~lethod: Minimum Curvature Db: Sybase VD Sys TVD N/S E/~~' ft ft ft ft 975. 88 5845. 88 -7104 .67 -221 .57 977. 59 5847. 59 -7115 .28 -245 .43 979. 79 5849. 79 -7125 .28 -273 .66 981. 38 5851. 38 -7134 .80 -311 .63 981. 51 5851. 51 -7140 .25 -352 .20 981. 23 5851. 23 -7141 .66 -381 .40 981. 29 5851. 29 -7139 .50 -412 .31 981. 87 5851. 87 -7132 .88 -441 .30 982. 94 5852. 94 -7123 .91 -469 .73 984. 44 5854. 44 -7112 .76 -497 .92 985. 73 5855. 73 -7097 .24 -527 .52 986. 41 5856. 41 -7080 .15 -553 .35 987. 22 5857. 22 -7062 .02 -579 .23 988. 84 5858. 84 -7043 .66 -609 .65 990. 45 5860. 45 -7030 .29 -636 .71 991. 16 5861. 16 -7017 .75 -665 .99 990. 90 5860. 90 -7007 .66 -694 .73 990. 57 5860. 57 -6999 .32 -732 .86 990. 37 5860. 37 -6996 .12 -762 .40 989. 43 5859. 43 -6995 .19 -791 .75 987. 15 5857. 15 -6995 .78 -821 .33 984. 29 5854. 29 -6997 .98 -851 .66 982. 04 5852. 04 -7002 .90 -881 .13 980. 01 5850. 01 -7011 .01 -909 .86 978. 53 5848. 53 -7020 .94 -936 .15 977. 17 5847. 17 -7035 .47 -971 T 5 5 .87 D1apN VIapF ft ft 5941266.19 539739.00 5941255.45 539715.20 5941245.30 539687.03 5941235.58 539649.12 5941229.91 539608.57 5941228.35 539579.38 5941230.35 539548.46 5941236.81 539519.44 5941245.63 539490.97 5941256.63 539462.72 5941271.99 539433.05 5941288.94 539407.13 5941306.93 539381.16 5941325.13 539350.64 5941338.35 539323.51 5941350.74 539294.17 5941360.68 539265.38 5941368.81 539227.21 5941371.85 539197.66 5941372.63 539168.30 5941371.88 539138.73 5941369.52 539108.41 5941364.44 539078.98 5941356.18 539050.29 5941346.11 539024.06 5941331.40 538988.42 VS DLS 'T'ool ft deg/100ft 4256.57 20.81 MWD 4282.20 16.38 MWD 4311.06 17.71 MWD 4347.62 15.86 MWD 4383.99 17.95 MWD 4408.71 9.33 MWD 4432.80 ~ 34.87 MWD 4452.75 23.68 MWD 4470.88 8.34 MWD 4487.59 19.01 MWD 4502.92 20.22 MWD 4514.28 16.58 MWD 4525.09 6.67 MWD 4539.48 16.93 MWD 4553.98 13.33 MWD 4570.76 10.95 MWD 4588.52 17.95 MWD 4614.97 22.23 MWD 4637.33 12.49 MWD 4660.84 18.87 MWD 4685.41 10.33 MWD 4711.52 17.11 MWD 4738.48 18.88 MWD 4766.66 23.28 MWD 4793.90 12.50 MWD 4831.49 0.00 MWD L ~' 2.3/8" liner top ~ 8720' MD Window in 7" ~ Top of Cement KOP at 8838' MD H. 3-'fi" Cameo TRDP-4A-RO SSSV set at 1810 RKB, ^e.813" ID E. 3.1/2" 9.3# J-55 EUE Srd Mod tubing w/ 3-1/2" x 1" Camcc 'KBUG' mandrels D. Cameo 3-1 /2" MMG gaslift mandrel at 8629 RKB G. Baker 3-1 /2" HB packer at 8692 RKB B. 3-%z" Cameo D nipple with 2.75" ID at 8708 RKB A. 3-1 /2" tubing tail at 8742 RKB ConocoPhillips Alaska, Inc. u 1L-25A1_1-01 TD: 9,855' 1L-25AL1-02 TD:10,374' OHST at 9295' KRU 1L-25A, AL1-01, end AL1-02 Producer C-sand CTD Completion DEV 10/21/05 9-S/8" 38# J-55 casing ~ 4978' 2-3/8" slotted liner ~• 2seJ-s5 ~ 9331' MD 2-3/8" blank liner across shale sections 11/09/04 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BO PE Test Report Submit to: ,t~E"3,.-rE'g~,~v~~rr:F_3,s~~_tt~,~~c,q bf3>'~,_E{£?~ ~E`f1S~£'Eft ~3L~tTi~3:S~~:~~_ ~?C,~I4 . Contractor: Nordic Rig No.: 2 DATE: 12/12/05 Rig Rep.: Holmes-Igtanloc Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Goodrich-Sarber E-Mail si~~c~;~~~rl~~,r~~;~~~"~c?~I~?qs(~€~r_ ~~~~7.~_~.I Well Name: 1 L-25A PTD # .205-175 Operation: Drlg: XXX Workover: Explor.: Test: Initial: Weekly: Bi-Weekly XXX Test Pressure: Rams: 250-3500 Annular: 250-2500 Valves: 250-3500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NT Housekeeping: P Drl. Rig P Lower Kelly NT PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP NT BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2" P Trip Tank P P Annular Preventer 1 7 1/16" P Pit Level Indicators P P #1 Rams 1 Blind /Shear P Flow Indicator P P #2 Rams 1 2" Combi P Meth Gas Detector P P #3 Rams 1 2 3/8" Combi P H2S Gas Detector P P #4 Rams 1 2" Combi P #5 Rams NIA NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves 1 P HCR Valves 2 3 1/8" P Kill Line Valves 1 3 1/8" P ACCUMULATOR SYSTEM: Check Valve N/A NA Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 2150 P Quantity Test Result 200 psi Attained 20 sec P No. Valves 14 P Full Pressure Attained 93 secs P Manual Chokes 1 P Blind Switch Covers: All stations Y Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 2150 Test Results Number of Failures: 0 Test Time: 5 Hours Components tested 29 Repair or replacement of equipment will be made within 0 days. Notify the N orth Slope Inspector 659-3607, follow with written confirmation to Superviser at: ,~iE~3.. rE~r~~ ~~~rri f3,~~~_k f,~~c: Remarks: Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES XXX NO c - Oper./Rig Waived By Jeff Jones c -Database Date 12/11/05 Time 20:00 c -Trip Rpt File Witness McConnell / Goodrich c -Inspector Test start 20:00 Finish 01:00 Coil Tubing BFL 11/09/04 Nordic 2 BOP 12-12-05p.xls i ~~ 11/09/04 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BO PE Test Report Submit to: .tiE~3... rf'g~ ~t~r~i;~_s~~k f~: ~>t,u eLC~~_'.....~%' EE~~1L?£?..~+'3r* {~;cEi~?~lEf1:~~i~F?_c~~,Ee b~b~3 ;£?::l{E`f15~£?t1 ~U~L~f~"Ei~3.St~'~t,.~?C.Ei~i Contractor: Nordic Rig No.: 2 DATE: 11/28/05 Rig Rep.: Mckeirnan ! Igtanloc Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Sevcik/Feketi E-Maila~a ~1=r~ ~f~~~c?~1~~~y~E=;E~~;~~~_~_~~I ..k.ri Well Name: 1 L-25A PTD # Ztlr&-fi75 Operation: Drlg: XXX Workover: Explor.: Test: Initial: XXX Weekly: Bi-Weekly Test Pressure: Rams: 250-3500 Annular: 250-3500 Valves: 250-3500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NT Housekeeping: P Drl. Rig P Lower Kelly NT PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP NT BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2" P Trip Tank P P Annular Preventer 1 7 1/16" P Pit Level Indicators P P #1 Rams 1 Blind /Shear P Flow indicator P P #2 Rams 1 2" Combi P Meth Gas Detector P P #3 Rams 1 2 3/8" Combi P H2S Gas Detector P P #4 Rams 1 2" Combi P #5 Rams N/A NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves 1 P HCR Valves 2 3 1/8" P Kill Line Valves 1 3 1/8" P ACCUMULATOR SYSTEM: Check Valve N/A NA TimelPressure Test Result System Pressure 3050 P CHOKE MANIFOLD: Pressure After Closure 2000 P Quantity Test Result 200 psi Attained 0:23 P No. Valves 14 P Fuli Pressure Attained 1:33 P Manual Chokes 1 P Blind Switch Covers: All stations Y Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 2050 Test Results Number of Failures: 0 Test Time: 4.0 Hours Components tested 29 Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: ,~iE~3...rE~cE,:~;~,~~~t~it3_~t~~_f_.~~c.u Remarks: Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES NO X c - Oper./Rig Waived By Chuck Scheve c -Database Date 11/27/05 Time 0600 c -Trip Rpt File Witness c -Inspector Test start 2300 Finish 0300 Coil Tubing BFL 11/09/04 Nordic 2 BOP 11-28-05p.xls RE: 1L-25 naming conventions for permit • • Subject: RE: IL-25 naming con~untions for permit From; "McLau~~hlin, Se:~n 1~1" ~~Sean.NlcLaugltlin crbp.com> Date: >\1on, ~ 1 Noy' ?U0~ Q9:?~l: ~4 -U9OQ :I'o: Thomas ~Taundcr <tom_rr~aun~lcr ci-~:a~~min.state.ak.us> CC: { Ioi~~ard Ukla~ld ~~ho~~-ard okl in~l%uadmin.state.ak us=>, Stc~,~e Da~~cs <s~eve davies~uadnlin.state.ak.us> Tom, The drilling has been fine with the exception of a few geological surprises. Our current schedule has us drilling at Kuparuk thru January i`1 more wells) then we'll head to Endicott for a while. No problem giving the survey in digital form - I'm all for making things easier. Let me know if this format doesn't works for you, I can try something else. seen From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday, November 18, 2005 11:50 AM To: McLaughlin, Sean M Cc: Howard Okland; Steve Davies Subject: Re: 1L-25 naming conventions for permit Sean, How goes the coil drilling?? What does your schedule look like for the coming weeks?? 2 of the 1L-25 permits should have issued. I am working on the remainder. I have a request. Is it possible to provide the planned survey information in digital form?? What you all are planning is, needless to say, a little complex. Having the survey in digital form will make Howard's job of getting it into our system much easier. Thanks. Call or message with any questions. If you send the digits, please make sure Howard gets copied. Tom Maunder, PE AOGCC Stephen Davies wrote, On 10/26/2005 4:32 PM: Sean, That's okay. Although the naming doesn't match the drilling order, labeling the stubby liners as "spokes" 1 and 2 (L 1-01 & L 1-02) makes the most sense when you look at the overall geometry of the well bores after they are drilled. The stubby liners will truly be spokes emanating from the long, main well bore even though the main well bore was not drilled during one single, continuous operation. Please let me know if you have additonal questions. Steve Davies Petroleum Geologist AOGCC 907-793-1224 McLaughlin, Sean M wrote: Tom, I'm starting to work up a permit request for 1 L-25. I've attached a better schematic for this well. !labeled it how I'd like. to name the well's. The long string of accessible liner will be L1. The stubby liner will be L1-01 ~~ ,~~~ ~' i' ~co~' 1 of 3 3/2/2006 10:38 AM RE: 1L-25 naming conventions for permit and L1-02. However the namin I've ro osed doesn't track with he r• g p p t o er drilled. Regards, Sean From: Thomas Maunder [mailtoaom_maunder~a admin.state.ak.us] Sent: Monday, October 17, 2005 3:16 PM To: McLaughlin, Sean M Subject: Re: 1L-25 naming conventions for permit Hi Sean, Steve Davies and I will have look at this. Tom McLaughlin, Sean M wrote, On 10/17/2005 3:10 PM: Tom, Our Kuparuk CTD multi-tats seem to be getting more and more interesting. We are currently planning a lateral with complicated faulting in the area. The plan is to drill into the fault to get a handle on its XY position. We will then run a short liner (250' -500') and kick off the top of the liner and repeat this at the second expected fault (see attached schematic). Each of the faults will throw the C sand wellbore into the Kalubik so it is necessary to cross the fault in the B shale and get faulted back into the C sand. Do the laterals need to be named in the order they were drilled/lined or can they be named with respect to the continuous string of liner? If the laterals are named in the order they were drilled I think the names would look something like: 1L-25AL1 ---> AL1-01 ----> AL1-01-01 The other option is to call the long string of continuous liner AL1. The short liners which cannot be accessed would be AL1-01 and AL1-02. Your thoughts are appreciated, sean Sean McLaughlin CTD Engineer 564-4387 Office 223-6784 Cell 564-5510 Fax 2 of 3 3/2/2006 10:38 AM RE: 1 L-25 naming conventions for permit • • CR1..1 ~ L-2~~1 ~ L1 Frvdu~~r Pro~~sed ~-sand ~CTD (1'orrtr~lr-~ti~n Content-Description: -1 L-25A, L 1-O 1, L 1-02, L 1 compass export files.zip _1L-25A, Ll-Ol, L1-02, Ll compass export files.zip'' '' Content-Type: application/x-zip-compressed (Content-Encoding: base64 3 of 3 3/2/2006 10:38 AM RE: 1L-25 naming conventions for permit KRIJ 7l--25A S~ L't Producer Proposed C-sand CTG] Com pi~t3on GEU 10l2 t105 Ce~r'ac~crPt-ti i l ps Sri Sicz~., Irx...- w.„a7w an r 1 F~ ~._~• a „n nz w..a• ~ a~ e.cm raxo r~„ ~ ~' ~. ~i U .b, ~~ 3 f J' t 3 4 - ~~3 y /mil ~ ~* -~ ~UU' st~sb ti ~ s (I 3/$^ e3oftaV) w! t, t i S ,( ) ) l Al ~ - ~; 1 ,t {`fl -l~~ C Y ~ ris a D~ttcst KQ m Tf\ m A'Li f fv ~ ~~ _ , ~~`\ -._.._. - -~~~ k l f ~ _ ear ~-- < and L fs tC _ _ 'T- =_ -~ 1 C _ L - ~7J } ^~~ '8^' siattod f3n6~ - ~'~'_ n ....- •a ~ r. -~. ~:. ~ti~-~-.w--.-" -. .a~ ..i- s ati 2..?.f tY i 5- 1c i -_~ as: ..__. 039i~ MD '- - &halo ti~cflAi~3 Content-Description: _1L-25A, Ll-01, L1-02, Ll compass export files.zip _iL-25A, Ll-Ol, L1-02, Ll compass export files.zip', Content-Type: application/x-zip-compressed Content-Encoding: base64 n 3 of 3 3/2/2006 10:39 AM ~ 'd ~'~ }• CO1~T5ERQA j~ ° ~ ~ ~ ~ FRANK H. MURKOWSK/, GOVERNOR ~7i>•t~ O~ ~ V[!>•-7 333 W. 7"" AVENUE, SUITE 100 ~Ox CO1rII-II55IO1Q ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Sean McLaughlin CT Drilling Engineer Conoco Phillips Alaska Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Kuparuk 1 L-25A Conoco Phillips Alaska Inc. Permit No: 205-175 Surface Location: 597' FNL, 143' FEL, SEC. 31, T11N, R10E, UM Bottomhole Location: 2396' FNL, 4282' FWL, SEC. 06, T10N, R10E, UM Dear Mr. McLaughlin: Enclosed is the approved application for permit to drill 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) . Sincerely, w.~' ~~ ii cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. John K. Norman Chairman DATED thi day of month, 2005 r STATE OF ALASKA ALAS' OIL AND GAS CONSERVATION MISSION PERMIT TO DRILL 20 AAC 25.005 ~~~~ ~ , ~;~ii~ Ct 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. 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-25A 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: ~ MD 11600 i TVD 5870ss 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: 2396' FNL, 4282' FWL, SEC. 06, T10N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 11000' ~ 4b. Location of Well (State Base Plane Coordinates): Surface: x- 539925 ~ - 5948371 ' Zone- ASP4 10. KB Elevation (Height above GL}: 130 feet 15. Distance to Nearest Well Within Pool 1 L-26A is offset by 2625' ~ 16. Deviated Wells: Kickoff Depth: 8838 ~ feet Maximum Hole Angle: 100 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3600 ~ Surface: 3016 18. asmg rogram: Size Specifications Setting Depth To Bottom uarttity o ement c.f, or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD ;~ ,4s includin sta a data 3" 2-3/8" 4.6# L-80 STL 2665' 8935' ~ 11600', 5870 ~ Uncemented Slotted Liner S~>~` ~~~ ;~.~ y,~ l9. PRESENT WELL CONDITI ON SUMMARY (To be completed forl3edrill AND Re-entry Operations) Total Depth MD (ft): 9350 Total C-epth TVD (ft): 6305 Plugs (measured): None Effective Depth MD (ft): 9093 Effective Depth ND (ft): 6139 Junk (measured): None Casin Len h Size Cement Volume. MD TVD r I on for 122' 16" 35 sx Arcticset I 122' 122' 4978' 9-518" 00 sx Permafrost'E', 550 sx Class 'G' 4978` 3614' ro 9331' 7" 50 sx Class 'G' 9331' 6293' Perforation Depth MD (ft): 8838' - 9159' Perforation Depth TVD (ft): 5976' - 6182' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth. Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverfer Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564-4387 Printed Name Sean McLaughlin Title CT Drilling Engineer e Prepared ey Name/Number. Si nature ~et,_- /~, L ~ Phone 564-4387 Date Il ~ o Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: Z~O$- t'7S API Number: 50- 029-22174-01-00 Permit Approval Date: See cover letter for other requirements Conditions of Approval: Samples Required ~ Yes ~' No Mud Log Required ^ Yes ~' No Hydrogen Sulfide Measures Yes ^ No Directional Siu_rvi ey Required ,~ Yes ^ No 1 Other: ~~,~~i~ ~`ey~~~ve'4.~~ ~s~ ~ a~~~4~ ~~~ c¢CC~~~~~E. t~~~C~~rQ3~~~1 ~/ ~_• - ..>.~;, -~ -~~ ~pAN $ => ,.-~..._._..~___,_ _.. APPROVED BY A roved B THE COMMISSION Date ° ~ ` Form 10-401 Revised 06!2004 U K I (.~ ~ ~~ /~ ~ Submit In Duplicate KRU 1~A, AL1-01, AL1-02, and AL1 Sidets -Coiled Tubing Drilling Summary of Operations: ~ A coiled tubing drilling unit will dri1141aterals in producer KRU 1L-25 using the managed pressure drilling ' technique (MPD, see description below). These horizontal laterals will target Kuparuk C sand reserves for CTD Drill and Complete 1L-25A, AL1-O1, AL1-02, and AL1 program: 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 ~. Cement 7" casing in preparation for a cement ramp exit Rig Work IL-25A 2. NU 7-1/16" BOPE, test 8. Mill 2.74" window off a cement ramp. Plan the top of ramp to start at 8838'. ~ 9. Dri113" bicenter hole horizontal lateral from window to 11600' TD targeting Kuparuk C sands. ~ 10. 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-O1. Use SSSV for liner run. cos- ~ s ' ~~` . i t n r i n i F` `~ S ~.~' 11. Mill 2.74" window off the aluminum billet at 8935' . 12. Dri113" bicenter hole horizontal lateral from window to 9750' TD targeting Kuparuk A sands. 13. Complete with a 2 3/8" slotted liner from TD, to 9350'. Use SSSV for liner run. 1L-25AL1-02 14. Mill 2.74" window off the aluminum billet at 9350' . 15. Dril13" 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. 1L-25AL1 17. Mill 2.74" window off the aluminum billet at 10400' . 18. Dri113" 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 IT 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. i KRU 1~A, AL1-01, AL1-02, and AL1 Sidets -Coiled Tubing Drilling Casing Program: • 1L-25A: 2 3t$", 4.6#, L-80, STL slotted liner from 8935' and to l I600' and • 1L-25AL1-O1: 2 3/8", 4.6#, L-80, STL slotted liner from 9350' and to 9750' and • 1L-25AL1-02: 2 3/8", 4.6#, L-80, STL slotted liner from 10400' and to 10800' and • 1L-25AL1: 2 3/8", 4.6#, L-80, STL slotted liner from 8720' and to 11600' and Casing/I,iner Information 9 5/8", J-55, 36#, Burst 3520; collapse 2020 psi. 7", J-55, 26#, Burst 4140; collapse 2900 psi 31/z", J-55, 9.3#, Burst 6990; collapse 7400 psi Well Control: • Two well bore volumes 0200 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-O1, 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 as .1.1000' .away. • The nearest well to IL-25AL1-Ol, ALI-02, and AL1 is also 1L-26A which is offset by 730'. KPA boundary is 10250' away. i ' 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 AL1-02 will TD at a mapped fault. • 1L-25AL1 will cross 2 mapped faults • Expect to encounter increasing pressure as lateral is drilled away from the mother well. • Well 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 (ALl-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 ~ $.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 1 ~A, AL1-01, AL1-02, and AL1 Sidet~s -Coiled Tubing Drilling and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will 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 pipelslips (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. /Lf1~C . t ~C~~.c~c.c~ra ~6ooPs<, .~, • Expected annular friction losses while circulating: 1044 psi (based on 90 psi/1000 ft) //9~~r ~~ttt/- • 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 • When circulation is stopped, a minimum of 1044 psi surface pressure will be applied to maintain constant BHP. ' • • ConocoPhillips Alaska, Inc. 1L-25 API: 500292217400 Well T e: INJ SSSV Type: TRDP Orig 5/31. sssv Com letion: (~6io-ia~i, Annular Fluid: Last W/O: 8/26 OD:3.500) oese.o.,..o I .,/,• RPf I nn Date' KRU 1 L-25 Angle @ TD: ~ 50 deg @ 9353 deg. ph; Oriented 180 deg. F/ Low Side 8870 -8872 5996 - 5997 C-4 2 4 3/4/1993 RPERF 2 1/8" 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 de h 9138 - 9159 6168 - 6182 A-4 21 4 6/16/1991 IPERF 4.5" Carrier 180 d h Gas Lift Mandrels Nalves 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 4 4627 5434 3391 3905 Camco Camco KBUG KBUG DMY DMY 1.0 1.0 BK2 BK2 0.000 0.000 0 0 8/26/1992 8/26/1992 5 6 7 6240 7076 7910 4395 4896 5397 Camco Camco Camco KBUG KBUG KBUG DMY DMY DMY 1.0 1.0 1.0 BK BK2 BK2 0.000 0.000 0.000 0 0 0 9/16/1994 8/26/1992 8/26/1992 8 8629 5844 Camco MMG-2 DMY 1.5 RK 0.000 0 9/18/1994 Ath wr Inh~n c wnui n_ etc_l -JE WELRY PBR (667a•as7s, OD:3.500) PKR (6692-8693, OD:6.156) NIP (8708-8709, OD:3.500) TUBING (0-8742, OD:3.500, ID:2.992) PeA (8838-8870) PeA (8838870) PeA (9039-9065) to bottom Perf (9138-9759) KRU 1 L-25A & L1 Producer Proposed C-sand CTD Completion DEV 10/21/05 H. 3h" Camco TRDP-4A-RO SSSV set at 1810' RKB, 2.813" ID ConocoPhillips Alaska, Inc. E. 3.1+'2" 9.3X J•55 EUE 8rd Mod tWing wl 3•tl2" x 1° Camco 'KBUG' marbrols 9-SIS' 36M JAS' S casing ~ 1978' • D. Camco 3112' MMG gasliB marxkel et 8529' RKB r 1 L-25A western lateral TD Q 11600' and - y Aluminum billet 8935' and , 2-318° liner top (~ ./-8720' MD C. Baker 3112' F1B packer al 8692' RKB window in 7" Top of Cement KOP at +1-a638' MD B 3-':," Camco D rvpple with 2 75' ID at 8708' RKB A 3-frT wbing lair at 87x2 RKB 500' stub liners (2-3/8" slotted) w! aluminum billet KO C-sand perfs C-sand perfs 1L-25AL1-01 1 L-25AL 1-02 t L-25AL i eastern lateral TD @ 11600' and 2-3/8" slotted liner r zs+r J-55 8331' MD 2-318" blank liner across sha-e sections BP Amoco wnas~nt °ornno IMnl, 1L]!a soonxtn~a Las ~darc a Iw. o.w ~ tao.eae ° ~ °.~ia o:am• o.eo o.oo o.ao REFERENCEINFORMATION Co-oNlnate ((N/E) Relerence: Well Centre: 25, True NorM VerBral (TVD) Relerence: System: Mean Sea Level Section (VS) Reference.- Sbt - (O.OON,O OOE) Measured DeDlh Relerence. sbt 25 130.00 Calculation Method. Minimum Curvature .c.. n.°. .... .w r r , w s-°. as.~ o wr'djpeya~ °Ow .~. ro~. °" w.rnar -m,i~i a -a :"0"~ Vie. rtes.*~a wrm eeex rrw v. 6000. , .. ; ;-+-_ - . 5100 ~'_ ... .... 5200 ~ ~ ;::il r-r5300 - C ' ii 5400 - ''' .F ' - ii i~ iILj 4;i ~ 5500 i ~ 5600 ~ ~ - -"-~+;~ d I:I G s7oo t0 SBOO 251PIan 6 tl-25AL1- y~5900 25(PlanB tL-25AL1-021 ~ sooo d Fsioo I ;, 'I .,~!'.: 6200 r' 6300 ! F. -_._,~ 6400 6500 2500 2600 2700 r~:.r BAKER HUGHES ~p •°. i . LEGEND T AzimOths t0 True North Plan. Plat' k5 (25/PbnS. 1L 25A) 25 n-26) - ZS ~Plen tf, 1L-25AL7) --- ZS Plan 8, 1L-25AL1-0 - 25 Plan 6, tL-25ALi-0 - PIen6. tL-25A - pin NB ) M Magnetic North: 24.08° Magnetic Field Stren the 57604nT Dip ngle: 80.72° creates Bg as Michaelson Date: it/12005 -- _ - -" --- -- Contad Imormation Bail Michaelson Direct 1907) 267-662a Date:9/26/2005 ceu, (9o7)3ot-73570 Model: bggm2004 E-maiP. bill.michaelsOn®inteq com West(-)/East(+) [100ft/in] PM Vertical Section at 225.00° [100ft/in] ConocoPhillips • • Baker Hughes INTEQ Baker Hughes INTEQ Planning Report INTEC,~ Company: ConocoPhillips Alaska, Inca Date: 11/1/2005 Time: 11:40:35 Page: 1 Fieid: Kuparuk RiverUnit Co-ordinate(NE) Reference: Well: 25, True North ' Site: -KRU 1 L Pad Vertical (TVD) Reference: Slot 25 130.0 Well: 25 Section (VS) Reference: Well (O:OON,O.OOE,225. OOAzi) WeUpath: PIan5, ]L-25A Survey Caleuladon Method: :Minimum Curvature i Db: Orate Targets Map Map <- Latitude -> <- Longitude -> Name Description TVD +N/-S +E!-W Northiug Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 1 L-25A Polygon 130.00 -5850.27 1386.15 5942528.97 541339.89 70 15 14.049 N 149 39 57.393 W -Polygon 1 130.00 -5850.27 1386.15 5942528.97 541339.89 70 15 14.049 N 149 39 57.393 W -Polygon 2 130.00 -5931.73 1282.71 5942446.97 541236.89 70 15 13.248 N 149 40 0.402 W -Polygon 3 130.00 -6227.12 1350.15 5942151.97 541305.89 70 15 10.343 N 149 39 58.442 W -Polygon 4 130.00 -6439.64 1255.01 5941938.97 541211.89 70 15 8.253 N 149 40 1.210 W -Polygon 5 130.00 -6576.88 1108.27 5941800.97 541065.89 70 15 6.903 N 149 40 5.479 W -Polygon 6 130.00 -6794.06 949.10 5941582.97 540907.89 70 15 4.767 N 149 40 10.109 W -Polygon 7 130.00 -6873.97 743.65 5941501.97 540702.89 70 15 3.982 N 149 40 16.085 W -Polygon 8 130.00 -6812.02 375.94 5941561.97 540334.89 70 15 4.591 N 149 40 26.779 W -Polygon 9 130.00 -6891.32 54.48 5941480.97 540013.89 70 15 3.811 N 149 40 36.128 W -Polygon 10 130.00 -6988.99 -198.07 5941381.97 539761.89 70 15 2.851 N 149 40 43.473 W -Polygon 11 130.00 -6926.51 -664.79 5941441.97 539294.89 70 15 3.465 N 149 40 57.047 W -Polygon 12 130.00 -7195.42 -687.22 5941172.97 539273.89 70 15 0.820 N 149 40 57.699 W -Polygon 13 130.00 -7246.15 -174.43 5941124.97 539786.89 70 15 0.322 N 149 40 42.785 W -Polygon 14 130.00 -7081.20 404.51 5941292.97 540364.89 70 15 1.944 N 149 40 25.948 W -Polygon 15 130.00 -7148.18 776.20 5941227.97 540736.89 70 15 1.285 N 149 40 15.139 W -Polygon 16 130.00 -7038.66 1058.81 5941338.97 541018.89 70 15 2.362 N 149 40 6.919 W -Polygon 17 130.00 -6501.18 1544.72 5941878.97 541501.89 70 15 7.647 N 149 39 52.784 W -Polygon 18 130.00 -6151.54 1619.58 5942228.97 541574.89 70 15 11.085 N 149 39 50.605 W -Polygon 19 130.00 -5829.92 1510.27 5942549.97 541463.89 70 15 14.249 N 149 39 53.782 W 1 L-25A Fault 1 130.00 -6782.55 856.13 5941593.98 540814.87 70 15 4.881 N 149 40 12.813 W -Polygon 1 130.00 -6782.55 856.13 5941593.98 540814.87 70 15 4.881 N 149 40 12.813 W -Polygon 2 130.00 -6982.57 855.07 5941393.98 540814.87 70 15 2.914 N 149 40 12.844 W -Polygon 3 130.00 -7182.58 854.01 5941193.98 540814.87 70 15 0.946 N 149 40 12.876 W 1 L-25A Fault 2 130.00 -6774.15 218.10 5941599.00 540176.87 70 15 4.964 N 149 40 31.369 W -Polygon 1 130.00 -6774.15 218.10 5941599.00 540176.87 70 15 4.964 N 149 40 31.369 W 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 WeUpath: PIan5, 1 L-25A Drilled From: 1 L-25 500292217401 Tie-on Depth: 8800.00 ft Current Datum: slot 25 Height 130.00 ft Above System Datum: Mean Sea Level Magnetic Data: 9/26/2005 Declination: 24.08 deg Field Strength: 57604 nT Mag Dip Angle: 80.72 deg Vertical SeMion: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 225.00 Plan: Plan #5 Date Composed: 9/26/2005 copy Lamar's plan 5 Version: 5 Principal: Yes Tied-to: From: Definitive Path ConocoPh~llips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ftIVTE(~ Company:.. ,GonocoPhiBips Alaska, Inc. Date: 11/1!2005 Time: 11:40:35 Page: 2 Field: Kupanik River Unit Co-ordinate(N>;) Reference: Well: 25, True North Site: KRU`1L Pad Vertical (1'VD) Reference: slot 25 130.0 Well: 25 Section (VS) Reference: Well (O.OON,O.OOE,225.OOAzi) Wellpath: PIanS, 1L-25A Survey Calculation Method: M inimum Curvature Db: Oracle Targets iMap Map <- Latitude -> <- Longitude --> Name Description TVD +N/-S +E/-W Northing EasNng Deg Min Sec Deg Min Sec Dip.. Dir. ft ft ft ft ft -Polygon 2 130.00 -6974.17 217.04 5941399.00 540176.87 70 15 2.997 N 149 40 31.400 W -Polygon 3 130.00 -7174.19 215.98 5941199.00 540176.87 70 15 1.029 N 149 40 31.431 W 1 L-25A Fault 3 130.00 -6910.00 -377.69 5941460.01 539581.87 70 15 3.628 N 149 40 48.697 W -Polygon 1 130.00 -6910.00 -377.69 5941460.01 539581.87 70 15 3.628 N 149 40 48.697 W -Polygon 2 130.00 -7111.08 -178.73 5941260.01 539781.87 70 15 1.650 N 149 40 42.911 W -Polygon 3 130.00 -7312.15 20.22 5941060.01 539981.87 70 14 59.673 N 149 40 37.125 W 1 L-25A Target 7 5980.00 -7057.67 -67.44 5941314.00 539892.87 70 15 2.175 N 149 40 39.674 W 1 L-25A Target 2 5986.00 -6421.94 1313.10 5941956.97 541269.88 70 15 8.427 N 149 39 59.521 W 1 L-25A Target 6 5990.00 -7042.32 55.66 5941330.00 540015.87 70 15 2.326 N 149 40 36.094 W 1 L-25A Target 3 5994.00 -6762.89 1108.26 5941614.98 541066.87 70 15 5.074 N 149 40 5.480 W 1 L-25A Target 8 6000.00 -7072.95 -577.58 5941296.01 539382.87 70 15 2.025 N 149 40 54.510 W 1 L-25A Target 4 6003.00 -6988.88 726.02 5941386.99 540685.87 70 15 2.852 N 149 40 16.598 W 1 L-25A Target 5 6017.00 -6968.30 241.07 5941404.99 540200.87 70 15 3.054 N 149 40 30.702 W Annotation `MD TVD ft' - ft 8800.00 5951.58 TIP 8838.00 5975.59 KOP 8852.00 5983.91 End of 40°/100' DLS 8935.69 6004.95 End of 45°/100' DLS 9135.69 5992.12 5 9335.69 5986.14 6 9545.69 5988.54 7 9760.69 5993.67 8 10235.69 6002.57 9 10435.69 6009.23 10 10735.69 6017.13 11 10813.69 6010.56 12 10938.69 5990.41 13 11063.69 5980.45 14 11363.69 5988.27 15 11600.00 0.00 TD Plan Section Information MD Inc! Azim TVD +N/-S +1:J-W DLS guild Turn TFO Target ft degs deg ft ft ft deg/100ft deg/100ft deg/100ft deg 8800.00 50.85 162.07 5951.58 -5946.39 1416.89 0.00 0.00 0.00 0.00 8838.00 50.74 161.94 5975.59 -5974.39 1425.98 0.39 -0.29 -0.34 222.44 8852.00 56.34 161.94 5983.91 -5985.10 1429.47 40.00 40.00 0.00 0.00 8935.69 94.00 161.94 6004.95 -6060.63 1454.10 45.00 45.00 0.00 0.00 9135.69 93.25 185.98 5992.12 -6257.66 1474.94 12.00 -0.38 12.02 91.00 9335.69 90.13 209.79 5986.14 -6446.52 1413.97 12.00 -1.56 11.91 97.00 9545.69 88.59 234.94 5988.54 -6600.42 1273.61 12.00 -0.74 11.98 93.60 9760.69 88.73 209.14 5993.67 -6758.71 1130.90 12.00 0.07 -12.00 270.00 10235.69 89.31 266.14 6002.57 -7002.54 746.08 12.00 0.12 12.00 90.00 10435.69 86.93 290.04 6009.23 -6974.64 549.62 12.00 -1.19 11.95 96.00 10735.69 90.16 254.17 6017.13 -6963.89 254.83 12.00 1.08 -11.96 274.50 10813.69 99.52 254.17 6010.56 -6985.07 180.14 12.00 12.00 0.00 0.00 10938.69 98.93 238.98 5990.41 -7033.99 67.28 12.00 -0.47 -12.15 269.00 11063.69 90.19 251.22 5980.45 -7086.22 -45.45 12.00 -6.99 9.79 125.00 11363.69 86.92 287.09 5988.27 -7090.64 -340.40 12.00 -1.09 11.96 95.50 ConocoPhillips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~~ iNTE(t Company: ConocoPhillips Alaska,Jnc. Date: ' 11/1/2005. Time: 11:40:35 Page: 3 ..Field: Kuparuk River Unit Co-ordtnate(NE) Reference: WeIL• 25, True North - Site: KRU 1 L Pad Vertical (T'VD) Reference: slot 25 130..0 Well: 25 Sectiou (VS) Reference: Well (O.OON, O.OOE,225 .OOAzi) Wellpat6: PIanS, 1 L-25A Survey Calculation Method: Minimum Curvature Db: Oracle Plan Section Information MD Incl Azim TVD +N!-S +E/-W DLS Bu ild. Turn TFO Target ft deg deg ft ft ft deg/100ft deg/1DOft deg/100ft deg 11600.00 87.29 258.70 6000.44 -7078.86 -573.70 12.00 0 .16 -12.01 270.00 Survey MD Incl - Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tooi ft deg deg ft ft ft ft ft deg/100ft ft deg 8800.00 50.85 162.07 5821.58 -5946.39 1416.89 5942433.02 541371.13 0.00 3202.84 0.00 MWD 8825.00 50.78 161.98 5837.37 -5964.82 1422.86 5942414.63 541377.21 0.39 3211.65 222.44 MWD i 8838.00 50.74 161.94 5845.59 -5974.39 1425.98 5942405.07 541380.37 0.39 3216.21 222.50 MWD 8845.18 53.61 161.94 5850.00 -5979.79 1427.74 5942399.69 541382.16 40.00 3218.78 0.00 1 L-25A 8850.00 55.54 161.94 5852.79 -5983.52 1428.96 5942395.96 541383.40 40.00 3220.56 360.00 MWD 8852.00 56.34 161.94 5853.91 -5985.10 1429.47 5942394.39 541383.92 40.00 3221.31 0.00 MWD 8855.86 58.08 161.94 5856.00 -5988.18 1430.48 5942391.31 541384.94 45.00 3222.78 360.00 1 L-25A 8863.83 61.66 161.94 5860.00 -5994.73 1432.61 5942384.77 541387.11 45.00 3225.90 0.00 1 L-25A 8872.85 65.72 161.94 5864.00 -6002.42 1435.12 5942377.09 541389.66 45.00 3229.57 0.00 1 L-25A 8875.00 66.69 161.94 5864.87 -6004.29 1435.73 5942375.23 541390.28 45.00 3230.46 360.00 MWD 8890.08 73.44 161.94 5870.00 -6017.76 1440.12 5942361.78 541394.74 44.76 3236.88 360.00 1 L-25A 8900.00 77.94 161.94 5872.45 X026.90 1443.10 5942352.66 541397.77 45.36 3241.23 0.00 MWD 8925.00 89.19 161.94 5875.25 -6050.48 1450.79 5942329.13 541405.58 45.00 3252.47 0.00 MWD 8935.69 94.00 161.94 5874.95 - -6060.63 1454.10 5942318.99 541408.95 45.00 3257.31 360.00 MWD 8950.00 93.97 163.66 5873.95 -6074.27 1458.32 5942305.38 541413.24 12.00 3263.97 91.00 MWD 8975.00 93.90 166.67 5872.24 -6098.38 1464.71 5942281.31 541419.75 12.00 3276.50 91.12 MWD 9000.00 93.83 169.67 5870.55 -6122.79 1469.82 5942256.93 541425.00 12.00 3290.14 91.33 MWD 9025.00 93.74 172.68 5868.90 -6147.44 1473.65 5942232.30 541428.95 12.00 3304.87 91.53 MWD 9050.00 93.65 175.68 5867.29 -6172.25 1476.18 5942207.50 541431.61 12.00 3320.63 91.73 MWD 9075.00 93.54 178.69 5865.72 -6197.17 1477.40 5942182.59 541432.97 12.00 3337.38 91.92 MWD 9100.00 93.43 181.69 5864.20 -6222.12 1477.32 5942157.64 541433.02 12.00 3355.08 92.11 MWD 9125.00 93.30 184.69 5862.73 -6247.04 1475.93 5942132.72 541431.76 12.00 3373.68 92.29 MWD 9135.69 93.25 185.98 5862.12 -6257.66 1474.94 5942122.10 541430.83 12.00 3381.90 92.47 MWD 9150.00 93.04 187.68 5861.34 -6271.85 1473.24 5942107.90 541429.20 12.00 3393.13 97.00 MWD 9175.00 92.66 190.66 5860.09 -6296.50 1469.26 5942083.24 541425.35 12.00 3413.37 97.09 MWD 9200.00 92.28 193.64 5859.01 -6320.91 1464.00 5942058.80 541420.23 12.00 3434.35 97.24 MWD 9225.00 91.89 196.62 5858.10 -6345.02 1457.48 5942034.65 541413.83 12.00 3456.02 97.37 MWD 9250.00 91.50 199.60 5857.36 -6368.77 1449.71 5942010.86 541406.19 12.00 3478.30 97.48 MWD 9275.00 91.10 202.57 5856.80 -6392.09 1440.72 5941987.50 541397.33 12.00 3501.15 97.57 MWD 9300.00 90.70 205.54 5856.40 -6414.91 1430.54 5941964.62 541387.26 12.00 3524.49 97.63 MWD 9325.00 90.30 208.52 5856.18 -6437.18 1419.18 5941942.30 541376.02 12.00 3548.27 97.68 MWD 9335.69 90.13 209.79 5856.14 -6446.52 1413.97 5941932.94 541370.87 12.00 3558.55 97.71 MWD 9350.00 90.02 211.50 5856.12 -6458.83 1406.68 5941920.59 541363.64 12.00 3572.41 93.60 MWD 9375.00 89.83 214.50 5856.15 -6479.79 1393.06 5941899.56 541350.14 12.00 3596.86 93.60 MWD 9400.00 89.65 217.49 5856.27 -6500.02 1378.37 5941879.26 541335.56 12.00 3621.55 93.60 MWD 9425.00 89.46 220.48 5856.46 -6519.45 1362.65 5941859.74 541319.94 12.00 3646.41 93.58 MWD 9450.00 89.27 223.48 5856.74 -6538.03 1345.93 5941841.08 541303.32 12.00 3671.37 93.56 MWD 9475.00 89.09 226.47 5857.10 -6555.71 1328.26 5941823.30 541285.75 12.00 3696.36 93.53 MWD 9500.00 88.91 229.47 5857.54 -6572.44 1309.69 5941806.47 541267.27 12.00 3721.32 93.49 MWD 9525.00 88.73 232.46 5858.05 -6588.18 1290.28 5941790.63 541247.94 12.00 3746.18 93.43 MWD 9545.69 88.59 234.94 5858.54 -6600.42 1273.61 5941778.30 541231.34 12.00 3766.62 93.37 MWD 9550.00 88.59 234.42 5858.64 -6602.92 1270.10 5941775.79 541227.84 12.00 3770.87 270.00 MWD 9575.00 88.59 231.42 5859.26 -6617.98 1250.16 5941760.62 541207.98 12.00 3795.62 270.01 MWD 9600.00 88.59 228.42 5859.87 -6634.07 1231.04 5941744.44 541188.95 12.00 3820.52 270.09 MWD 9625.00 88.60 225.42 5860.49 -6651.14 1212.78 5941727.27 541170.79 12.00 3845.50 270.16 MWD 9650.00 88.62 222.42 5861.09 -6669.14 1195.45 5941709.18 541153.55 12.00 3870.48 270.23 MWD 9675.00 88.64 219.42 5861.69 -6688.02 1179.08 5941690.22 541137.29 12.00 3895.41 270.31 MWD 9700.00 88.66 216.42 5862.28 -6707.73 1163.72 5941670.42 541122.03 12.00 3920.21 270.38 MWD • Conoco~illips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~"s! 1NTEtt Company: ConocoPhillips Alaska, Inc. Date: 11/1/2005 Time: 11:40:35 Page: 4 Field: Kuparuk River Unit Co-ordinate{NE) Reference: Well: 25, True North Site: KRU 1 L Pad Vertical (1'VI)) Reference: slot 25 130. 0 WeII: 25 Section (V5) Reference: Well (O.OON ,b.00E,225 .00A2i) Wellpath; PIa nS, 1L-25A Survey Calculation Method: Minimum Curvature Db: Oracle SUCVey MD Incl. Azim - SS TVD N/S E/W MapN MapE bL5 VS TFO Tool ft deg deg ft ft ft ft ft - deg/100ft - ft deg ~ 9725.00 88.68 213.42 5862.86 -6728.23 1149.42 5941649.86 541107.84 12.00 3944.81 270.45 MWD 9750.00 88.71 210.42 5863.43 -6749.44 1136.20 5941628.58 541094.74 12.00 3969.16 270.52 MWD 9760.69 88.73 209.14 5863.67 -6758.71 1130.90 5941619.28 541089.48 12.00 3979.47 270.59 MWD 9775.00 88.73 210.85 5863.99 -6771.10 1123.75 5941606.85 541082.40 12.00 3993.29 90.00 MWD 9800.00 88.73 213.85 5864.54 -6792.22 1110.37 5941585.67 541069.14 12.00 4017.67 89.96 MWD 9825.00 88.74 216.85 5865.09 -6812.60 1095.91 5941565.21 541054.79 12.00 4042.31 89.90 MWD 9850.00 88.75 219.86 5865.64 -6832.20 1080.40 5941545.53 541039.38 12.00 4067.13 89.83 MWD 9875.00 88.76 222.86 5866.18 -6850.95 1063.89 5941526.69 541022.97 12.00 4092.07 89.76 MWD 9900.00 88.78 225.86 5866.72 -6868.82 1046.42 5941508.73 541005.60 12.00 4117.06 89.70 MWD 9925.00 88.80 228.86 5867.25 -6885.75 1028.04 5941491.70 540987.31 12.00 4142.03 89.63 MWD 9950.00 88.83 231.86 5867.77 -6901.70 1008.79 5941475.66 540968.15 12.00 4166.91 89.57 MWD 9975.00 88.85 234.86 5868.27 -6916.61 988.74 5941460.64 540948.18 12.00 4191.64 89.51 MWD 10000.00 88.88 237.86 5868.77 -6930.46 967.93 5941446.68 540927.45 12.00 4216.14 89.45 MWD 10025.00 88.92 240.86 5869.25 -6943.20 946.43 5941433.83 540906.01 12.00 4240.36 89.39 MWD 10050.00 88.95 243.86 5869.71 -6954.79 924.29 5941422.12 540883.94 12.00 4264.21 89.33 MWD 10075.00 88.99 246.86 5870.16 -6965.21 901.57 5941411.58 540861.28 12.00 4287.64 89.27 M W D 10100.00 89.03 249.86 5870.59 -6974.43 878.34 5941402.24 540838.10 12.00 4310.59 89.22 MWD 10125.00 89.08 252.86 5871.00 -6982.42 854.66 5941394.13 540814.46 12.00 4332.98 89.17 MWD 10150.00 89.13 255.86 5871.39 -6989.16 830.59 5941387.27 540790.43 12.00 4354.77 89.12 MWD 10175.00 89.18 258.86 5871.76 -6994.63 806.20 5941381.67 540766.07 12.00 4375.88 89.07 MWD 10200.00 89.23 261.86 5872.11 -6998.81 781.56 5941377.35 540741.46 12.00 4396.26 89.03 MWD 10225.00 89.28 264.86 5872.44 -7001.70 756.73 5941374.33 540716.65 12.00 4415.86 88.99 MWD 10235.69 89.31 266.14 5872.57 -7002.54 746.08 5941373.43 540706.00 12.00 4423.99 88.95 MWD 10250.00 89.13 267.85 5872.76 -7003.29 731.79 5941372.61 540691.71 12.00 4434.62 96.00 MWD 10275.00 88.82 270.83 5873.21 -7003.58 706.79 5941372.19 540666.73 12.00 4452.50 95.98 MWD 10300.00 88.51 273.82 5873.80 -7002.56 681.82 5941373.07 540641.75 12.00 4469.44 95.92 MWD 10325.00 88.20 276.81 5874.51 -7000.25 656.94 5941375.25 540616.86 12.00 4485.39 95.85 MWD 10350.00 87.91 279.79 5875.36 -6996.64 632.22 5941378.73 540592.13 12.00 4500.32 95.77 MWD 10375.00 87.61 282.78 5876.34 -6991.76 607.73 5941383.48 540567.61 12.00 4514.19 95.67 MWD 10400.00 87.33 285.77 5877.45 -6985.60 583.53 5941389.51 540543.38 12.00 4526.95 95.55 MWD 10425.00 87.05 288.76 5878.67 -6978.19 559.68 5941396.80 540519.50 12.00 4538.57 95.42 MWD 10435.69 86.93 290.04 5879.23 -6974.64 549.62 5941400.29 540509.41 12.00 4543.18 95.27 MWD 10450.00 87.07 288.32 5879.98 -6969.95 536.12 5941404.91 540495.89 12.00 4549.40 274.50 MWD 10475.00 87.31 285.33 5881.21 -6962.72 512.22 5941412.01 540471.96 12.00 4561.19 274.59 MWD 10500.00 87.56 282.34 5882.33 -6956.75 487.97 5941417.85 540447.68 12.00 4574.12 274.74 MWD 10525.00 87.82 279.35 5883.34 -6952.05 463.44 5941422.42 540423.13 12.00 4588.14 274.87 MWD 10550.00 88.08 276.36 5884.23 -6948.64 438.70 5941425.70 540398.37 12.00 4603.22 274.99 MWD 10575.00 88.35 273.37 5885.01 -6946.52 413.80 5941427.69 540373.46 12.00 4619.33 275.10 MWD 10600.00 88.62 270.38 5885.67 -6945.70 388.83 5941428.37 540348.49 12.00 4636.41 275.19 MWD 10625.00 88.90 267.39 5886.21 -6946.19 363.84 5941427.75 540323.50 12.00 4654.43 275.27 MWO 10650.00 89.18 264.40 5886.63 -6947.98 338.91 5941425.83 540298.59 12.00 4673.32 275.33 MWD 10675.00 89.46 261.42 5886.92 -6951.06 314.11 5941422.61 540273.80 12.00 4693.04 275.38 MWD 10700.00 89.75 258.43 5887.10 -6955.44 289.49 5941418.11 540249.22 12.00 4713.53 275.42 MWD 10725.00 90.03 255.44 5887.14 -6961.09 265.14 5941412.33 540224.90 12.00 4734.75 275.44 MWD 10735.69 90.16 254.17 5887.13 -6963.89 254.83 5941409.48 540214.60 12.00 4744.02 275.45 MWD 10750.00 91.87 254.17 5886.87 -6967.79 241.06 5941405.50 540200.86 12.00 4756.52 0.00 MWD 10775.00 94.87 254.17 5885.40 -6974.60 217.06 5941398.57 540176.89 12.00 4778.31 0.00 MWD 10800.00 97.87 254.17 5882.63 -6981.38 193.16 5941391.66 540153.03 12.00 4800.00 0.00 MWD 10813.69 99.52 254.17 5880.56 -6985.07 180.14 5941387.90 540140.03 12.00 4811.81 0.00 MWD 10825.00 99.49 252.79 5878.69 -6988.24 169.44 5941384.67 540129.35 12.00 4821.62 269.00 MWD 10850.00 99.41 249.75 5874.59 -6996.16 146.09 5941376.63 540106.05 12.00 4843.73 268.77 MWD 10875.00 99.31 246.71 5870.52 -7005.31 123.19 5941367.36 540083.19 12.00 4866.40 268.27 MWD C011000~'11~~IpS • • Baker Hughes INTEQ Baker Hughes INTEQ Planning Report s~ INTE(~ Company: ConocoPhillips Alaska, lnc. Date: 11/1/2005 Time: 11:40:35 Page: 5 Field: Kuparuk River Unit Co-ordinste(NE) Reference: Well: 25, True North Sitee KRU 1L Pad Vertical (TVD),Reference: slot25130.0 Well: 25 Section (VS) Reference: Well (O.OON ,O.OOE,225 .OOAzi) Wellpath: PIan5, 1 L-25A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD - Incl ' Azim SSTVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 10900 .00 99.18 243.68 5866.50 -7015.66 100.79 5941356.89 540060.85 12.00 4889.55 267.78 MWD 10925 .00 99.02 240.64 5862.55 -7027.19 78.97 5941345.25 540039.09 12.00 4913.13 267.29 MWD 10938 .69 98.93 238.98 5860.41 -7033.99 67.28 5941338.39 540027.44 12.00 4926.21 266.81 MWD 10950 .00 98.15 240.10 5858.73 -7039.66 57.64 5941332.67 540017.83 12.00 4937.03 125.00 MWD 10975 .00 96.41 242.57 5855.56 -7051.55 35.88 5941320.67 539996.14 12.00 4960.83 125.17 MWD 11000 .00 94.67 245.02 5853.15 -7062.53 13.56 5941309.56 539973.88 12.00 4984.38 125.48 MWD 11025 .00 92.91 247.46 5851.49 -7072.58 -9.27 5941299.39 539951.10 12.00 5007.63 125.72 MWD 11050 .00 91.15 249.89 5850.61 -7081.67 -32.54 5941290.19 539927.88 12.00 5030.51 125.88 MWD 11063 .69 90.19 251.22 5850.45 -7086.22 -45.45 5941285.56 539915.00 12.00 5042.85 125.96 MWD 11075 .00 90.06 252.57 5850.42 -7089.74 -56.20 5941281.99 539904.27 12.00 5052.94 95.50 MWD 11100 .00 89.77 255.56 5850.46 -7096.60 -80.24 5941275.00 539880.27 12.00 5074.79 95.50 MWD 11125 .00 89.48 258.54 5850.62 -7102.20 -104.60 5941269.27 539855.95 12.00 5095.98 95.50 MWD 11150 .00 89.20 261.53 5850.91 -7106.53 -129.22 5941264.82 539831.35 12.00 5116.44 95.48 MWD 11175 .00 88.91 264.52 5851.32 -7109.56 -154.03 5941261.65 539806.56 12.00 5136.13 95.44 MWD 11200 .00 88.63 267.51 5851.86 -7111.30 -178.96 5941259.78 539781.64 12.00 5154.99 95.40 MWD 11225 .00 88.36 270.49 5852.51 -7111.73 -203.94 5941259.21 539756.66 12.00 5172.97 95.33 MWD 11250 .00 88.08 273.48 5853.29 -7110.87 -228.91 5941259.95 539731.69 12.00 5190.01 95.25 MWD 11275 .00 87.82 276.47 5854.19 -7108.70 -253.80 5941261.98 539706.80 12.00 5206.07 95.16 MWD 11300 .00 87.56 279.46 5855.19 -7105.24 -278.54 5941265.31 539682.05 12.00 5221.12 95.05 MWD 11325 .00 87.30 282.46 5856.32 -7100.49 -303.05 5941269.93 539657.51 12.00 5235.09 94.93 MWD 11350 .00 87.05 285.45 5857.55 -7094.47 -327.28 5941275.82 539633.25 12.00 5247.97 94.80 MWD 11363 .69 86.92 287.09 5858.27 -7090.64 -340.40 5941279.58 539620.11 12.00 5254.54 94.65 MWD 11375 .00 86.92 285.73 5858.87 -7087.45 -351.24 5941282.71 539609.26 12.00 5259.95 270.00 MWD 11400 .00 86.93 282.73 5860.21 -7081.32 -375.43 5941288.72 539585.03 12.00 5272.72 270.07 MWD 11425 .00 86.95 279.72 5861.55 -7076.46 -399.92 5941293.45 539560.52 12.00 5286.60 270.23 MWD 11450 .00 86.97 276.72 5862.87 -7072.89 -424.62 5941296.89 539535.80 12.00 5301.54 270.39 MWD 11475 .00 87.01 273.71 5864.19 -7070.62 -449.48 5941299.02 539510.93 12.00 5317.52 270.55 MWD 11500 .00 87.05 270.71 5865.48 -7069.66 -474.43 5941299.85 539485.99 12.00 5334.47 270.71 MWD 11525 .00 87.10 267.71 5866.76 -7070.00 -499.39 5941299.38 539461.03 12.00 5352.37 270.87 MWD 11550 .00 87.15 264.70 5868.02 -7071.65 -524.30 5941297.59 539436.13 12.00 5371.15 271.02 MWD 11575 .00 87.22 261.70 5869.24 -7074.61 -549.09 5941294.50 539411.36 12.00 5390.77 271.17 MWD i 11600 .00 87.29 258.70 5870.44 ~ -7078.86 -573.70 5941290.12 539386.78 12.00 5411.17 271.32 MWD • • • • ss-si,25z 236 TERRIE L RUBBLE ,D~~ s BP EXPLORATION AK INC ^Mastercard Cheek" DATE PO BOX 196612 MB 7-5 ANCHORAGE,. AK 99 51 9-66 1 2 _ PAY TO THE ~ pOLLARS ORDER OF - First NationalAKa 99501 ka Anchorage, t L,'25 MEMO 200060~:99L4•n6227~~~L556~~' 0236 ~.L25 TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRAvNS,M~ITTAL LETTER WELL NAME 1~-~- ~ l~' ~2`S~ PTD# ~'~~ _ ~ ~~ CHECK WHAT ~, ADD-ONS ~ "CLUE" APPLIES ~ (OPTIONS) MULTI I The permit is for a new wellbore segment of LATERAL I existing well , Permit No, API No. ~ (If API number Production should continue to be reported as -ast two (2) digits a function of .the original API number stated are between 60-69) ,above. PILOT HOLE j In accordance with 20 AAC 25.005(f), all (per ~ records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) '~ _ _and API number (50 - j 70/80) from records, data and togs acquired for well (name on permit). SPACIl~TG !The permit is approved subject to full EXCEPTION ~ compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. _ fCompany 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 I Commission must be in no greater than 30' ~ sample intervals from below the permafrost or from where samples are first caught and i 10' sample intervals through target zones. Rev: 04/01/05 C\jody\transm ittal_checklist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RVOIL-490100 Well Name: KUPARUK RIV UNIT 1L-25A ____Program DEV Well bore seg ^ PTD#:2051750 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType DEV I PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ^ Administration 1 Permitfeeattached_______________ ______ __ Yes_ --_----__-__--_-__--__ 2 Lease number appropriate - - Yes ------------------------------ i 3 Uniquewell_nameandnumber_________________________________-___ Yes_ ____,.__--_____- 4 Well located in a_d_efnedpool- - - - - ---------------- Yes - - KUPARUK RIVER,_KUPARUK.RVOIL- 490100, governed by Conservation Order No. 4320.- - 5 Well located proper distance-from dolling unit_boundary_ - . - - . - - - Yes Conservation Older No. 4320 contains no spacing restrictions with respect-to drilling uni# koundaries. ... - - - - 6 Well located proper distance_fro_m other wells- - _ - - Yes - . _ _ .. -Conservation Order No. 4320 has no intenxell_spacing_restrictions, _ - - - - _ - - 7 Sufficient acreage available in drilling unit _ _ Yes Conservation Order No. 4320 has no interwell-spacing_restr_ictions, Wellbo[e_will be_more than 500' from _ . 8 .If deviated, is_wellborep/at-included - - - Yes - - an external property line-whe[e_ownership orJan_downership changes. - . _ _ _ - - _ 9 Ope(ator only affected party- - - - - , - _ _ _ _ _ - - Yes - _ _ _ _ 10 Operator has.appropriate-bond in force - ------- -- ---~-- - --- -- Yes- ----- -- --- ------~ -- -- --- -- --~ - ---- -- ...--- --- ---- 11 Permilcanbeissuedwithoutconseryalionorder-__________________ Yes_ ____---.---__-____-_________-__--__ ___ ___-----_-___--_-_-____---_,-__, Appr Date 12 Permit_can be issued without ad_ministrative_approval - : _ _ _ _ _ - Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - SFD 11/1412005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and-strata a4thorized bylnjection Order# (put_1O# in_comments)-(For_ NA_ - - - - - - - - - - - - - - _ - _ - - _ - _ _ _ _ - - - - _ _ - - _ _ _ _ - _ - - - . _ - _ _ _ _ _ _ - - _ - _ _ _ _ _ - _ _ _ _ - 15 All wells_within 114_mile area of review identified (For service well only) - - - - - - - - - - - - - - - NA- _ _ - .. - - _ _ _ _ _ - - _ , . - _ _ _ _ - 16 Pre-produced injector; duration of preproduction I_essthan 3 months_(For service well only) NA_ -- - 17 ACMP-Finding of Consistency_h_asbeenissued_far_thisproject_- -------___ NA._ _ _Re-drill--.______________________-.-_-_____----_--_____ Engineering 18 Conductor string_provided - _ - - - NA_ _ - - - - Conductorset_in motherbore,-1L-25-(191-070). _ _ - - - 1 19 Surface-casing-protects all_known- l1SDWs - - _ NA- All aquifers exempted, 40 CFR_147.102 (b)_(3).- . - .. - - - - - 1 20 CMT-vol adeguate_to circulate-on conductor_& surf-csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ - -Surface casing set in motherbore. _ _ _ _ - _ _ - - _ _ _ 21 CNIT-vol adeguate_to tie-in long string tosurf csg_ NA_ Pr_oducti4n casin set in-motherbore. - - - - - . - . - 9- - 22 CMT_will coyer all known-productive horizons_ - - - _ - - _ - - - - _ No- _ - - _ _ Slotted liner completion pl_anned._ - - - - - . _ 23 Casing designs adequate for C,_T, B &_permafrost- - - NA- _ _ - - Original well tabulars_met design_requirQments. _NA for slotted liner-- - - -- - - -- - - - - - - - - - 24 Adequate tankage-or reserve pit _ - _ - - - - - - Yes _ . - . -Rig is-equipped with steel_pits. No reserve. pitplanned. All waste to approved disposalwells._ - - _ _ 25 Ifa-re-drill,has-a_10-403 forabandgnmentbeenapp_roved---------------------- Yes_ __ _--305-348,_processed11108/05..____-_---__ ___ -_--_-_______-________- 26 Adequate wellbore separation-proposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ - . - . _ Proximity analysis performed, Nearest wey section_is orginal well and_paths diverge.- _ _ - _ _ _ _ _ , - - - _ _ _ 27 If diverter required, does it meet regulations_ _ - - _ _ - . NA- - BOP stackwill already_be in place. - - Appr Date 28 l)rillingf/uid-program schematic & equip list adequate_ _ _ - _ - - Yes - Maximum expected formation pnssure 11.9 EMW.-Managed pressure drilling_planned, w! &.6 ppg-fluid and applie TEM 1111512005 2g BOPEs,_do they meetregulation - _ _ - - - - - Yes _ _ - . _ _ - pressure via friction or trapped pressure. -2_well volumes of kill weight fluid available on_ location. _ ~s~ 30 BOPS-press rating appropriate; test to-(put prig in comments)- - - - _ - - - Yes MA$P calculated at 3016 psi.- 3500_psi_minimum BOP_ test._ _ - 31 Choke-manifold complieswlAPI-RP-53 (May84)__-___._ Yes_ -_--_---________________________________---_ 32 Work willoccurwithoutoperationshutdo_wn_______________________________ Yes_ ______-_--________________--__--_____ 33 Is presence of H2S gas probable - . - - - - - - _ ... - Yes _ - - _ - - Up to 240 ppm H2S reported on 1 L pad. Mud should preclude H2S on rig. -Ri has-sensors_ and alarms. 9 34 Mechanical condition of wells within AOR verified (.For_service well only) - . - - _ . - tJA_ _ . - _ - - _ - - -- Geology 35 Permitcan be issued wfohydrogen-sulfide measures - _ - _ - - . - - _ No_ - - - _ Concent[ations 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 withcoiled-tubingand 8,6_ppg mud Appr Date 37 Seismic analysis of shallow gas_zones- . - ... _ . NA- using overbalanced pressure drillingtechniques tp achieve 12.0 ppg-e-quivalent circulating density. SFD_ . _ _ _ _ - SFD 11114/2005 ~ 138 Seabed condition survey-(if off_-shore) - - - ~ - - - - - - - ~39 _ Contact name/phone for weekly progress-reports [exploratory only]_ NA_ - - _ _ - . - - Geologic Engineering Public Date: Date Date Co lmissio r: // Commissioner: Commissioner J • • Well History File APPENDIX Information of detailed nature that is not • particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify Minding information, information of this nature is accumulated at the end of the Mile under APPENDIX. No special effort has been made to chronologically organize this category of information. • **** REEL HEADER **** MWD 07/07/10 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/12/02 1025231 01 2.375 CTK *** LIS COMMENT RECORD *** !!!!!!!!!! !!!!!!!!! Remark File Version. 1.000 !!!!!!!!!! !!!!!!!!! Extract File: ldwg.las Version I nformation VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 8840.0000: Starting Depth STOP.FT 8945.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska Inc. WELL. WELL: 1L-25APB1 FLD FIELD: Kuparuk River Unit LOC LOCATION: 70 deg 16' 11.588"N 149 deg 40' 33.550"W CNTY. COUNTY: North Slope Borough STAY. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375 CTK DATE. LOG DATE: 02-Dec-05 API API NUMBER: 50029221740170 Parameter Information Block #MNEM.UNIT Value 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 ~~ = r ~ 5~ ¢ ~Sa~sa (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 8921 ft.MD to 8945 ft.MD (5870 ft.to 5871 ft.55TVD) was not logged due to bit to sensor offset at TD. (9) Tied to 1L-25 at 8758 ft.MD (5795.1 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 63 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN 1L-25APB1 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. WN 1L-25APB1 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: 3 Tape File Start Depth = 8840.000000 Tape File End Depth = 8944.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 12 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1L-25APB1.xtf LCC 150 • CN ConocoPhillips Alaska In WN 1L-25APB1 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 MVdD 68 1 F/HR 4 4 8 Total Data Records: 5 Tape File Start Depth = 8840.000000 Tape File End Depth = 8944.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 14 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 05/12/02 1025231 • • 01 **** REEL TRAILER **** MWD 07/07/10 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • Tape Subfile 1 is type: LIS • o Tape Subfile 2 is type: LIS DEPTH GR ROP 8840.0000 62.2900 0.0000 8840.5000 56.1400 0.7050 8900.0000 122.7600 45.6400 8944.0000 -999.2500 -999.2500 Tape File Start Depth = 8840.000000 Tape File End Depth = 8944.000000 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 122.7600 45.6400 8944.0000 -999.2500 -999.2500 Tape File Start Depth = 8840.000000 Tape File End Depth = 8944.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS **** REEL HEADER **** MWD 07/07!10 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/12/12 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 Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 8840.8000: Starting Depth STOP.FT 11929.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska Inc. WELL. WELL: 1L-25A 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: 12-Dec-05 API API NUMBER: 50029221740100 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 CA5E.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks ~bS- c~-5 ~ c5a ~ ~ • i (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 11895 ft.MD to 11929 ft.MD (5848.3 ft.to 5847.2 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) The wellbore 1L-25AL1-01PB1 was kicked off this wellbore 1L-25A at 8938 ft.MD (5878.16 ft.55TVD) 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-25A 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. WN 1L-25A 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: 74 Tape File Start Depth = 8840.000000 Tape File End Depth = 11929.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 83 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU ~ ~ ------------------ WDFN 1L-25A.xtf LCC 150 CN ConocoPhillips Alaska In WN 1L-25A 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: 148 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = **** FILE TRAILER **** Tape Subfile: 3 157 Minimum record length: 54 Maximum record length: 4124 8840.000000 11929.000000 0.250000 feet records... bytes bytes **** TAPE TRAILER **** MWD • 05/12/12 1025231 01 **** REEL TRAILER **** MWD 07/07/10 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • Tape Subfile 1 is type: LIS • i 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 103.0300 28.0500 9100.0000 130.4500 34.6000 9200.0000 90.2200 26.8200 9300.0000 90.9900 30.9400 9400.0000 74.5900 20.1900 9500.0000 90.4700 22.3500 9600.0000 107.9000 22.8100 9700.0000 94.8300 30.1200 9800.0000 104.7400 22.6400 9900.0000 104.2200 45.5500 10000.0000 128.9900 46.9100 10100.0000 121.5100 51.0100 10200.0000 124.6000 50.0300 10300.0000 110.4100 67.7000 10400.0000 107.5800 22.9600 10500.0000 98.2900 35.9400 10600.0000 111.1000 31.5600 10700.0000 114.5400 56.3000 10800.0000 116.3500 24.4000 10900.0000 100.3500 44.9600 11000.0000 112.2200 43.7700 11100.0000 103.9700 39.3900 11200.0000 102.6800 8.4800 11300.0000 122.2800 34.5200 11400.0000 99.0600 23.5500 11500.0000 91.0700 41.6200 11600.0000 106.5854 55.2000 11700.0000 86.4300 38.4500 11800.0000 86.6800 19.0200 11900.0000 -999.2500 7.0700 11929.0000 -999.2500 3.5900 Tape File Start Depth = 8840.000000 Tape File End Depth = 11929.000000 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 103.0300 28.0500 9100.0000 130.4500 34.6000 9200.0000 90.2200 26.8200 9300.0000 90.9900 30.9400 9400.0000 74.5900 20.1900 9500.0000 90.4700 22.3500 9600.0000 107.9000 22.8100 9700.0000 94.8300 30.1200 9800.0000 104.7400 22.6900 9900.0000 104.2200 45.5500 10000.0000 128.9900 46.9100 10100.0000 121.5100 51.0100 10200.0000 124.6000 50.0300 10300.0000 110.4100 67.7000 10400.0000 107.5800 22.9600 10500.0000 98.2900 35.9400 10600.0000 111.1000 31.5600 10700.0000 114.5400 56.3000 10800.0000 116.3500 24.4000 10900.0000 100.3500 44.9600 11000.0000 112.2200 43.7700 11100.0000 103.9700 39.3900 11200.0000 102.6800 8.4800 11300.0000 122.2800 34.5200 11400.0000 99.0600 23.5500 11500.0000 91.0700 41.6200 11600.0000 106.5854 55.2000 11700.0000 86.4300 38.4500 11800.0000 86.6800 19.0200 11900.0000 -999.2500 7.0700 11929.0000 -999.2500 3.5900 Tape File Start Depth = 8840.000000 Tape File End Depth = 11929.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • Tape Subfile 4 is type: LIS
