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Home My WebLink About205-076• • 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 inspectio/n ~of the file. ~Q ~ - Q ~ (p Weli History File Identifier Organizing (done> ^ Two-sided !II ll~lltllllf II~1I ^ Rescan Needed III II~IIIIIII IIIIII RESCAN DIGITAL DATA OVERSIZED (Scannable) ~olor Items: iskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other. ^ Logs of various kinds: NOTES: BY: Maria Date: ~ a Q ^ Other: / / ... s Project Proofing III II~III IIIII II III BY: Maria Date: `~ Q /s/ Scanning Preparation 1_ x 30 = j ~, D + ~_ =TOTAL PAGES ~ ~ ~ rrr~~~ BY I 1 ,,, (Count does not include cover sheet) ", n ,V / : Maria Date: ' a„ / ~ © ~ /s/ Y ~ Y r Production Scanning Stage 7 Page Count from Scanned File: ~ ~ ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: Maria Date: f 'a„., („~- ~ O /s/ 1 r '7 1M, I~ Stage ~ 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 III II I I III ReScanned BY: Maria Date: /s/ Comments about this file: o~a~.~~e~kea iiiimiuiiomii 10/6/2005 Well History File Cover Page.doc ~• ConotoPhillips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri126, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333, West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: P ."'~ P R ~~~~~r~ ~t. ~~ ~ ~ _g a ~. /~g '_ ~ err-, . Q a,~ ;. s7 4~~`hsg. ,~ '~ ~/ ~ 1 f ' 3.d Enclosed please fmd the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. wells 1E-170, 1E-170L1, 1E-170L2 concentric gaslift mandrel installation. Please call Brent Rogers or myself if you have any questions. Sincerely, ~~ Martin Walters Problem Well Supervisor ~~ STATE OF ALASKA ~CEI~/~~ ~~ ~P~ ~ o zoos ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons Commission REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other 0 Install CGLM l Alter Casing ^ Puil Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number. ConOCOPhIIIIpS Alaska, InC. Development ^~ Exploratory ^ 205-076 ° 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50029232646100' 7. KB Elevation (ft): 9. Well Name and Number: RKB 42' • 1 E-170L2 • 8. Property Designation: 10. Field/Pool(s): ADL 25660 " Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 15940' feet true vertical 3354' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 120' 20" _ 162' _ 162' SURFACE 5012' 13-3/8" 5054' 2312' INTERMEDIATE' 10372' 9-518" 10414' 3451' D-SAND WINDO+ 10' 9-5/8" 9412' 3350' D SAND LINER 6123' S-1 /2" 15736' 3186' Pertoration depth: Measured depth: Intervals from 9,737 -15,693' true vertical depth: Intervals from 3187' - 3275' Tubing (size, grade, and measured depth) 4-1 /2", L-80, 9386.74' MD. 2.441" Concentric GLM set in CMU sliding sleeve ~ 9221' MD Packers &SSSV (type & measured depth) Baker ZXP 9308' SSSV = 3.875 "DB" Nipple at 558' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oi10 Gas ^ WAG^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A contact Brent Rogers/Martin Walters Printed Name Martin Walters Title Problem Well Supervisor ~ ~ ~ 659-7224 Date /tf, 4/26/2009 ~ Signature / ~ r Form 10-404 Revised 04/2006 ~ ~ Su mib t Origi~ Ohry ~. 1 E-170 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 4/7/2009 SET CAT-SV @ 9277 CTMD, FLUID PACK TUBING & IA WITH 663 BBLS DIESEL, PERFORMED SUCCESSFUL TXIA MIT 4/8/2009 CLOSED CMU, PERFORMED SUCCESSFUL TUBING MIT, PULLED CAT-SV & OPENED CMU. UNABLE TO SET CONCENTRIC GLM. RTN IN A.M. 4/11/2009 SET CONCENTRIC GLM IN CMU @ 9213 CTMD, JOB COMPLETE, 4/15/2009 Re-TIFL (passed ), T/I/0= 225/850/5. SI well and gas lift, shot initial IA-FL @ 9101'. Stacked well T/110= 675/700/5. Bled IA, T/I/0= 725/300/0. Shot second IA-FL @ same location. 15 min post bleed and final T/I/0= 725/300/0. .°~ '3 L ~- ._ _. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Abu;:, . ~,! REPORT OF SUNDRY WELL OPERATIONS ~~:~~~,,~,,; 1. operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^ Other Q Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ ESP to Gaslift Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~ Exploratory ^ 205-076 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23264-61 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 41' 1 E-170L2 8. Property Designation: 10. Field/Pool(s): ADL 25660 ~ Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 15748' • feet true vertical 3186' feet Plugs (measured) Effective Depth measured 15748 feet Junk (measured) true vertical 3186 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 120' 20" 120' 120' SURFACE 5054' 13-3/8" 5054' 2311' WINDOW D 10' 9-5/8" 9412' 3275' INTERMEDIATE 10373' 9-5/8" 10414 3451' LINER D 6324' S-1/2" 15736 3185' Perforation depth: Measured depth: 9732-15693 true vertical depth: 3275-3187 , , ~~~~L ' c ~,r; J~~ ~ ~~ ~~t:=7 ~ -~; Tubing (size, grade, and measured depth) 4.5, L-80, 4990' MD . Packers &SSSV (type & measured depth) Packer =None 0 SSSV =None 0 12. Stimulation or cement squeeze summary: Intervals treated (measured) .Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 392 375 23 272 266 Subsequent to operation 460 62 501 273 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations X 16. Well Status after proposed work: Oil^ ~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or Nia if C.O. Exempt: N/A contact B. Christensen/ D. Humphrey Printed Name Darrell R. Humphrey Title Production Engineering Specialist Signature Phone: 659-7535 Date l 7. ~ 2 (~ ' ~ D iz•~3•~'8 Form 10-404 Revised 04/2004 ~ ~ ~~ «~ ~~ ~ `~' ~~~~ ~~ ~/ ~J submit Original Only • • 1 E-170L2 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/04/08 12/05/08 12/06/08 12/07/08 12/12/08 12/16/08 CLEAN DOWN TO TOP OF SLIP-STOP @ 4913' CTMD.MADE MULTIPLY ATTEMPTS TO START ESP WITH NO SUCCESS. RETURN IN AM TO START PULLING SLIP-STOP, PACKOFF AND ESP TO TEST MOTOR. RIH WITH 4" GS SPEAR AND PULLED SLIP-STOP, PACKOFF ASSEMBLY AND ESP. USE DEPLOYMENT FLANGE ON TREE TO HOLD ESP UNTIL SLICK-LINE CAN PULL PUMP. CYCLE ESP UP & DOWN TO CONFIRMED PUMP MOVE FREELY) PULLED & LAYED DOWN 4-1/2" x 47' 10" FC6000 ESP FROM DEPLOYMENT FLANGE. READY FOR CTU. RIH AND CLEAN TUBING DOWN TO TOP INTAKE CROSSOVER @ 4966' CTMD. WHILE MAKING UP BAKER BHA TO TEST MOTOR, TILT CYLINDER SEAL STARTED LEAKING ON T-BAR.ROAD UNIT TO PRUDHOE TO PERFORM MAINTENANCE AND REPAIRS. JOB INCOMPLETE RAN IN HOLE TO 4968' CTMD WITH ESP MOTOR TEST TOOL, SEATING PINS SHOWN THAT TEST TOOL WAS ENGAGED INTO ESP MOTOR SHAFT BUT ROTATIONAL TATTLE TAILS WERE STILL INTACT INDICATING ESP MOTOR SHAFT PROBLEMS, WELL LEFT SHUT IN AND FREEZE PROTECTED WITH DIESEL DOWN TO TOP OF MOTOR. (( COMPLETE )) REPLACE SOV @ 817' RKB W/ DV. RAN HOLEFINDER, GOOD TEST OF DV. JOB COMPLETE ~ KUP 1 E-170L2 a ~OIIOCOP~'11~~Ip5 ` 1 Well Attributes ° '~~''~'"'' ~'~' 1 Wellbora APIIUWI Field Name 500292326471 NIEST SAK ) MD (fU(B) TD (max) (ft . Well Statue Prod/InJ Well Type Incl ( PROD 97.84 11,422.93 15,940.0 Comment MPS (ppm) Date Annotation End Date KB-Grd (R) Rlg Release Date •'• SSSV: NONE 0 7/1/2008 Last WO: Wsll Con - 1E-070L2 11lI1I hemelb- 00B t09.78 PM I Annotation DepN (RKB) E nd Dad Annotation End Dete Last Tag: Rev Reason: SET ESP 11/2/2008 Casin Strin s - -- Slring OD Slring ID '.iet Depth Set Depth (TVD) String Wt SUing Casing Deecriptlon (In) (In) Top (RKB) (RKB') (RKB) (Ibsttt) Orada String Top Thrtl LINER D 5 1/ 2 4.950 9,613.0 15,736.0 3,186.0 15.50 1-80 BTCM Other In Hole All Jewel : Tubin Run 3 Retrievable Fish etc. MANGER, /1 Top Daplh (TVD) Top Top (/tl(B) IRKS) Incl (°) Descriptlan Comment Run Data ID (In) 9,412.0 3,274.6 81.38 HANGER L2 0.SAND BAKER MODEL 8-1 HOOK HANGER 915/2005 3.980 conoucroR. t Po 9,433.0 3,280.8 90.23 HANGER L2 DSAND LEM BAKER MODEL B-1 HOOK HANGER 9/5/2005 7.000 9,555.0 3,280.0 92.17 CSG PKR DSAND BAKER PAYZONE EXTERNAL CASING PACKER 9/5/2005 5.500 9,613.0 3,272.7 87.74 SLEEVE D-SAND BAKER'HR' LINER SETTING SLEEVE 9/5/2005 5.500 EsP 15,735.0 3,186.0 91.27 SHOE 0.SAND WEATHERFORD GUIDE SHOE 9/5/2005 5.500 MANDREL, B17 P rt ti e ora ona Shot Top (TVD) Btm (TVD) Dena Top (RKB) Btm (f[NB) (RK8) (RKB) Zona Dete tah"' Type Comment PUMP ASSY, 9,732.0 15,693.0 3,275.4 3,187.0 WS D, tE-17012 9/412005 32.0 Slots Slotted casing ~ D~' Notes: General & Safet y End Date An nolatlon DISCHARGE, 11/12/2005 NOTE: MULTI-LATERAL WELL: 1E-170(A2-SAND), 1E-170L1(BSAND), tE-170L2(DSAND) 4,ess %O. 4 974 SEAL, 4,990 MOiOft. 5.003 Csntrsl¢sr, 5,D39 SURFACE, 5,054 SHOE. 5,073 WINDOW D, 9,417 HANGER lP. 9,412 HANGER LP, 9,133 PUP, 9.439 CSG PKR, 9,555 SLEEVE, 9,613 TERMEDIATE, 10,414 P I I Ebb, 9,732.15,893 SHOE, 15,735 LINER D, 15,736 TD l1 E-770L2), ' 15,748 t ~~,~ _ ~ ,~: ~: . ~;. x ,:~~ DATA SUBMITTAL COMPLIANCE REPORT 10/29/2007 Permit to Drill 2050760 Well Name/No. KUPARUK RIV U WSAK 1 E-170L2 Operator CONOCOPHILLIPS ALASKA INC MD 15748 TVD 3186 Completion Date 9/10/2005 Completion Status 1-OIL Current Status 1-OIL REQUIRED INFORMATION API No. 50-029-23264-fit-00 UIC N Mud Log No Samples No Directional Survey Yes c..°' DATA INFORMATION Types Electric or Other Logs Run: GR/RES, CCL, USIT Well Log Information: Log/ Electr Data Digital Dataset Types Med/Frmt Number Name Sample Interval Set Start Stop Sent Received Number Comments /f" D Asc Directional Survey 9398 15748 Open 10/26/2005 IIFR D Asc Directional Survey 9398 15748 Open 10/26/2005 MWD D Lis 13452~tnduction/Resistivity 5054 15710 Open 1/31/2006 ASLD/GR/EWR4/CNP/SLD /ROP/ACAL/PWD/GEOPIL OT pt 13452 LIS Verification 5054 15710 Open 1/31/2006 ASLD/GR/EWR4/CNP/SLD '~, /ROP/ACAL/PWD/GEOPIL OT Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? .~ Chips Received? ~~ Analysis Y7'I~ Received? Comments: Compliance Reviewed By: (data taken from Logs Portion of Master Well Data Maint Interval Log Log Run OH / Scale Media No Start Stop CH Received Comments Daily History Received? ~ N Formation Tops ~/ N Date: ,~ • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Signed: ~ RE: MWD Formation Evaluation Logs: 1E-170,+PB1+PB2+PB3+Ll+L2 AK-MW-3778283 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 E-170,+PS 1+PB2+PB3+L 1+L2 Digital Log Images: 50-029-23264-00, 70, 71, 72, 60, 61 September 10, 2007 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 a, . ~a Date:~~V 'J '?ui~, ~b5 = 6`~ L( ~'` ~5 G3~ i 563 t S~,3g ~5 6L1~ ~osa~s ~s~~l/ __----- aoso~~ ~s~~a 3 • WELL LOG TRANSMITTAL • To: State of Alaska January 10, 2006 Alaska Oil and Gas Conservation Co. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1E-170 L2, °2~~~ ~ h_ AK-MW-3778283 4 rl 1 LDWG formatted Disc with verification listing. API#: 50-029-23264-61 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~ _ Signed - r~c~~i~~f,.,,# • ~ DEC 15 2005 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ,: ~ Gas Cons. COfI'N11iS51{~11 WELL COMPLETION OR RECOMPLETION REPORT AND~ne 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned ^ Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: Development ^ Exploratory ^ Service ^ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or,4band.: September 10, 2005 12. Permit to Drill Number: 205-076 / 305-268 / 305-283 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: 5 zs z~s 2005 ~ ~L/S• 13. API Number: e S 50-029-23264-61 4a. Location of Well (Governmental Section): Surface: 247' FNL, 641' FEL, Sec. 21, T11N, R10E, UM ` 7. Date TD Reached: September 1, 2005 14. Well Name and Number: 1E-170L2 • At Top Productive Horizon: 2383' FSL, 224' FWL, Sec. 27, T11 N, R10E, UM 8. KB Elevation (ft): 41' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 1322' FSL, 167' FWL, Sec. 34, T11 N, R10E, UM 9. Plug Back Depth (MD + TVD): 15748' MD / 3186' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 549890 ~ y- 5959340 " Zone- 4 10. Total Depth (MD + TVD): 15748' MD / 3186' TVD 16. Property Designation: ADL 25660 TPI: x- 550824 y- 5951417 Zone- 4 Total Depth: x- 550823 - 5945076 Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 470 18. Directional Survey: Yes 0 No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1733' MD 21. Logs Run: ~~ ' q~/Z %Yl~j 327y •T/.~ GR/Res, CCL, USIT Y /Z • /S• cS 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 94# H-40 41' 120' 41' 120' 42" 375 sx AS I 13.375" 68# L-80 41' 5054' 41' 2311' 16" 917 sx AS Lite, 272 sx DeepCrete 9-5/8" 40# L-80 41' 10414' 41' 3451' 12.25" 305 bbls DeepCrete 5.5" 15.5# L-80 9412' 15736' 3275' 3185' 8.5" slotted liner 23. Pertorations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET tubing run in main wellbore 1E-170 only slotted liner from 9732'-15693' MD 3275'-3075' TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) ESP Oil Producer -shares production with 1 E-170 and 1 E-170L1 -waiting on facility hook-up Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 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". s ,.. .,.~ .. ~', ti ~ NONE ~ . EC ~ ~ ~D05 -, -,~;,r~.~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ~ ^~~^IAL ' zs. 2s. GEOLOGIG MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 E-170L2 West Sak D 9401' 3273' .. Base West Sak D 15748' 3186' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed Nark Rand Thomas Title: Greater Kuoaruk Area Drillino Team Leader ~ 2-l(t ~or Signature Phone 2„~ ~- ~~ 30 Date INSTRUCTIONS Prepared by Sharon Allsup-Drake 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. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 w • ConocoPhillips Alaska Page ~ of ~~ Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To Hours Code '~ Sub ,phase ,Code - - 6/22/2005 03:30 - 00:00 20.50 MOVE MOB MOVE 6/23/2005 00:00 - 03:00 3.00 MOVE MOVE MOVE 03:00 - 04:00 1.00 MOVE MOVE MOVE 04:00 - 06:30 2.50 MOVE MOVE MOVE 06:30 - 18:00 11.50 MOVE MOVE MOVE 118:00 - 21:30 3.50 MOVE MOVE I MOVE 21:30 - 00:00 I 2.501 MOVE I MOVE I MOVE 6/2412005 00:00 - 00:30 0.50 MOVE MOVE MOVE 00:30 - 05:00 4.50 MOVE MOVE MOVE 05:00 - 09:00 4.00 MOVE MOVE MOVE 09:00 - 12:00 3.00 MOVE MOVE MOVE 12:00 - 17:00 5.00 MOVE MOVE MOVE 17:00 - 19:30 2.50 MOVE MOVE MOVE 19:30 - 21:30 I 2.00 I MOVE I MOVE I MOVE 21:30 - 23:00 1.50 MOVE MOVE MOVE 23:00 - 23:30 0.50 MOVE POSN MOVE 23:30 - 00:00 0.50 MOVE MOVE MOVE 6/25/2005 00:00 - 01:00 1.00 MOVE POSN MOVE 03:00 - 04:45 I 1.7051 MOVE POSN I MOVE 04:45 - 09:30 I 4.751 MOVE POSN I MOVE 09:30 - 10:30 I 1.00 I DRILL I RIRD I RIGUP 10:30 - 12:00 1.50 DRILL RIRD RIGUP 12:00 - 18:00 6.00 DRILL RIRD RIGUP 18:00 - 23:00 I 5.001 DRILL I RIRD I RIGUP 23:00 - 00:00 I 1.001 DRILL I PULD I RIGUP Start: 6/22/2005 Rig Release: 9/10/2005 Rig Number: 15 Spud Date: 6/26/2005 End: 9/10/2005 Group: Description of Operations Move Rig T/ 1 E-170 Turn Key Rig Move: Lay Mats Over all colvert crossings and plywood. Tum Key Rig Move: Rig trying to get over matted culvert crossing powered out. While Trying to work over crossing by backing up and getting run at crossing the back end of Drill unit was allowed to get to close to side of road causing road to blow out. Tum Key Rig Move: Call for Equip, to pull out of hole. Move pit module back to where equipment would have access to rear of drill module. Turn Key Rig Move: W.O. equipment, 08:30 Unload and Road equipment to drill module, Hook up cats to rear beam, Pull sub backwards out of hole unhook cats road back to reload take to FRONT FURTHER HELP. Tum Key Rig Move: Lay plywood Move rig T/KIC. Junction Inspect Rig Wait to lay mats, Move Front of K.O.C. APRS laying plywood 1 E turn off build up acsess road with plywood. Rig Crews waiting on road crew to lay plywood and mats. Turn Key Rig Move: Move rig to 1 E acsess road hook up cats and help pull overUp grade Acsess. Move Pit complex over road to back of KOC. Stop Move pits and rig back of koc Wait on mats to be layed and mats to be around. Move from behind KOC to 1 E pad. Derrick Module broke through road Build up road. Back module out, Matt road all the way to 1 E pad, Move derrick module and pit Module to entrance of 1 E pad, Set malts for rig foot print Move derrick and pit modules onto 1E pad, Move pits around~derrick module, Lay more mats not a big enough foot print layed the first time. Spot pit module on mats Repair hose on pit module. Moving system. Spot Pit Module on Mats Move Sub base on Malts spot over Well. Skid Rig and spot pits.To be moved into sub. Crane called to move well house to be able to set pit module.Not reconized until sub and pits on well Hook up servce lines that can be hooked up Set beaver slide. Move well house @ 07;00 Set pit module cunt, hooking up service line's. Set rock washer unit,Rigging up service fines, Switch to high line power. Rig Accepted By Fred Herbert @ 10:OOhr. Rig up cutting tank and berm ,Nipple Up Riser, Rizer was to short had to add 27 inches, Could of found out @ 0600 when asked, but did not check until 12;OOhrs. Continue R/U koomey lines, Make up flow lines, Turn Buckles, Start filling pits with fluid. Start loading pipe shed loaded 78jts. Herculate around riser and drip pan. Clear floor of 4"XT subs and handling equipment. Change Saver Sub on top drive,lnstall Shaker screens on shakers.Tighten bolts on riser, Change air boot on flow Iine,Tighten dresser sleeve on flow Iine.Start Building Spud mud, Load pipe shed with 180 5" D.P. 29 HWT DP 3 - 8" flex Collar 8" Motor and MWD.Function test, Koomey Test, Waived by State Man Jeff Jones. Rig Up and start picking up 5" Drill Pipe. standing back in derrick. Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska Page 2 of ~5'' Operations Summary Report Legal Well Name: 1 E-170 Common W ell Name: 1 E-170 Spud Date: 6/26/2005 Event Nam e: ROT -D RILLIN G Start: 6/22/2005 End: 9/10/2005 Contractor Name: D15CM @conoc ophillip s.com Rig Release: 9/1.0/2005 Group: Rig Name: Doyon 1 5 Rig Number: 15 t D F '' T H ~ Sub ~ ' P o O a e rom o aurs Code Code . hase Descripti perations n of 6/26/2005 00:00 - 05:30 5.50 DRILL PULD RIGUP Pick Up 5" Drill Pipe and stand in Derrick total 180 joints. 05:30 - 09:00 3.50 DRILL PULD RIGUP Pick Up 5" HWT Drill Pipe and stand in Derrick total 29 joints and set Jars. 09:00 - 10:00 1.00 DRILL PULD RIGUP Pick Up BHA Subs to rig floor, Fill Conductor and check surface equipment. 10:00 - 13:00 3.00 DRILL PULD SURFAC PJSM; Pick Up BHA, Upload MWD, Rick up slick line in derrick for. Gyro. 13:00 - 13:30 0.50 DRILL TRIP SURFAC Test Mud lines 3,000psi. Tag fill @ 88', Clean out to 120'. 13:30 - 14:00 0.50 DRILL DRLG SURFAC Drilling From; 120' - 135'. 14:00 - 14:30 0.50 DRILL RGRP SURFAC Working on Power limit control to SCR's 14:30 - 16:30 2.00 RIGMNT DRLG SURFAC Drilling From; 135' - 230'. Gravel returns. 16:30 - 17:30 1.00 DRILL TRIP SURFAC Trip Out Hole; Replace with 3 flex Collars, and jars. 17:30 - 18:00 0.50 DRILL SURV SURFAC Gyro Survey @ 215' 18:00 - 00:00 6.00 DRILL DRLG SURFAC -Drill and survey 16" Hole from 230' MD to 645'MD (640 TVD. TST = 2.77 hrs, TRT = 2.65 hrs, TDT = 5.42 hrs. Avg. ROP = 96 fph. UP WT. 105K, DN WT. 105K, ROT Wt 100K. Tq on Btm 3K, Tq off Btm 1K, at 50 rpm. Pump at 155 spm, 650 gpm 2,340 psi. APIG= 61.76'per Hr. Jar hrs, 128 6/27/2005 00:00 - 06:00 6.00 DRILL DRLG SURFAC Drill and Slide; survey(gyro) 16" Hole. From 645' MD: (640 TVD). To 1,111 MD (1,074' tvd)AST =1.73 hrs, ART =2.62 hrs, TDT = 5.42 hrs. Avg. ROP = 85.9 fph. UP WT. 110K, DN WT. 110K, ROT Wt 115K. Tq on Btm 2K, Tq off Btm 1 K, WOB 15-30k, 60 rpm. Pump at 180 spm, 763 gpm, 3500 psi.Total Drill time 8.32. 106 ROP Average, APIG= 73.41'per Hr. Total Ft Drilled 881' 12hrs. 06:00 - 12:00 6.00 DRILL DRLG SURFAC Drill and Slide; survey 16" Hole From 1,111' MD. (640 TVD). To 1,637' MD (1,519'TVD)AST =2.70 hrs, ART =1.43 hrs, ADT = 4.03hrs. Avg. ROP = 130 fph. UP WT. 130K, DN WT. 120K, ROT Wt 125K. Tq on Btm5K, Tq off Btm 3K, WOB 15-30k, 60 rpm. 553 - 763 gpm, 3500 psi.Total Drill time 12.45. 106 ROP Average, APIG= 78.16'per Hr. Total • Ft Drilled 1,407' 18hrs. 12:00 - 18:00 6.00 DRILL DRLG SURFAC Drill and Slide; survey 16" Hole From 1,637'MD. (1,519' TVD). To 2,253' MD (1,857'TVD) AST= 2.22 hrs, ART =1.58 hrs, ADT = 3.8hrs. Avg. ROP = 162 fph. UP WT. 130K, DN WT. 120K, ROT Wt 125K. Tq on Btm 7K, Tq off Btm 4K, WOB 15-30k, 60 rpm. 553 - 763 gpm, 3500 psi. Total Drill time 16.12. ROP Average,125.4'. APIG= 84.29 'per Hr. Total Ft Drilled 2,023' 24hrs. 18:00 - 20:00 2.00 DRILL DRLG SURFAC Drill and Slide; survey 16" Hole From 2,253' MD. (1,857 TVD). To 2,411' MD (1,894'TVD) AST= .2 hrs, ART =1.52 hrs, ADT = 1.74hrs. Avg. ROP = 90.80 fph. UP WT. 140K, DN WT. 120K, ROT Wt 125K. Tq on Btm 7K, Tq off Btm 4K, WOB 15-30K 60 rpm. 553 - 763 gpm, 3500 psi. Total Drill time 17.36hrs .125.6 ROP Average, APIG= 83.88' per Hr. Total Ft Drilled 2,181' 26hrs. Total Jar hrs. 141.21. 20:00 - 20:30 0.50 DRILL CIRC SURFAC Circ & Condition Hole for Trip. Last Survey 76.97 incl. 173.56 Azm. 2,347 MD (TVD 1,894') 20:30 - 00:00 3.50 DRILL TRIP SURFAC Trip Out Hole; Pump out hole To 900' Pull Out Of Hole. Alot of clay bound to Tool Joints and BHA. 6/28/2005 00:00 - 02:00 2.00 DRILL TRIP SURFAC Trip Out Hole; Pump out hole To 900' Pull Out Of Hole. Alot of clay bound to Tool Joints and BHA. Clean Bit and BHA. 02:00 - 03:00 1.00 DRILL PULD SURFAC Work BHA; Change bend in Motor from 1.83deg to 1.15deg. Lay Down Pony Collar and drop press drop sub, Orientate tools. 03:00 - 04:30 1.50 DRILL TRIP SURFAC Change pulsar valve and attemt to grease valve, Tool Failure, Low Amp hours on Battery, Down load MWD, Pick up new pulsar valve. 04:30 - 05:00 0.50 DRILL TRIP SURFAC Re- Orientate Upload MWD. Welding on 4" outlets on Conducter, Printed: 9/30/2005 6:19:05 AM • • ConocoPhillips Alaska ' Page 3 of 45 .....Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: ROT -DRILLING Start: 6/22/2005 End: 9/10/2005 Contractor Name: D15CM@conocophillips.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 15 Rig Number: 15 Date i Fror7~ - To Hours Code Code Phase 6/28/2005 104:30 - 05:00 ~ 0.501 DRILL TRIP SURFAC 05:00 - 06:00 1.00 RIGMNT RSRV SURFAC 06:00 - 10:00 4.00 RIGMNT OTHR SURFAC 10:00 - 10:30 0.50 DRILL TRIP SURFAC 10:30 - 11:00 0.50 DRILL CIRC SURFAC 11:00 - 11:45 0.75 DRILL TRIP SURFAC 11:45-12:15 0.50 DRILL CIRC SURFAC 12:15 - 12:30 0.25 DRILL TRIP SURFAC 12:30 - 12:45 0.25 DRILL REAM SURFAC 12:45 - 18:00 5.25 DRILL DRLG SURFAC 18:00 - 00:00 I 6.001 DRILL I DRLG I SURFAC 16/29/2005 ~ 00:00 - 06:00 ~ 6.001 DRILL I DRLG I SURFAC 06:00 - 12:00 I 6.00 DRILL DRLG SURFAC 12:00 - 18:00 I 6.001 DRILL I DRLG I SURFAC 18:00 - 22:30 I 4.501 DRILL I DRLG I SURFAC 22:30 - 23:00 0.50 DRILL CIRC SURFAC 23:00 - 00:00 1.00 DRILL TRIP SURFAC 6/30/2005 00:00 - 05:00 5.00 I DRILL I REAM I SURFAC Description of Operations Working with Surface mud, Clean Rock Washer tank torn screens allowed alot of solids in tank. Rig Service ,Grease Crown ,Inspect Drill line. Welding 4"outlets on conductor, Finish up cleaning out rock washer and run fluid back over screens Ship to 1 r pad. Trip in Hole; Finish Picking up upper Bha. Trip in hole to 1,116' Circ and Condition @ 400 gpm 870psi. 200bb1s. High Vis Mud returns. Trip in Hole to 2,064' MD, UP WT. 115k DN WT 110k. Break Circulation, Condition Mud, @400gpm 1050psi. High Vis. Mud Returns. Trip in Hole to 2,360 MD Wash 51' to 2,411' @ 600 gpm, 80 RPM, Drill and Slide; survey 16" Hole From 2,411' MD. (1,894' TVD). To 2,916" MD (1,980'TVD) AST= .72 hrs, ART =2.11 hrs, ADT = 2.83hrs. Avg. ROP = 177.8 fph. UP WT. 130K, DN WT. 110K, ROT Wt 120K. Tq on Btm 7K, Tq off Btm 5K, WOB 15-30K 120 rpm.600-800 gpm,2300 psi. Total Drill time 21.01 hrs .133.63 ROP Average, APIG= 85' per Hr. Total Ft Drilled- 2686', 31.25hrs. Drill and Slide; survey 16" Hole From 2,916' MD. (1,980' TVD). To 3,549' MD (2,029' TVD) AST= .82 hrs, ART =3.31 hrs, ADT = 4.13hrs. Avg. ROP = 153 fph. UP WT. 130K, DN WT. 90K, ROT Wt 110K. Tq on Btm 9-10kK, Tq off Btm6K, WOB 15-30K 120 rpm.800-900 gpm,2,590 psi. Total Drill time 25.14 hrs .136 ROP Average, APIG= 89' per Hr. Total Ft Drilled-3,319', 37.25 hrs. Drilt and Slide; survey 16" Hole From 3,549' MD. (2,029' TVD). To 3,875' MD (2,064' TVD) AST= 2.00 hrs, ART =2.56 hrs, ADT = 4.56hrs. Avg. ROP = 72 fph. UP WT. 130K, DN WT. 95K, ROT Wt 110K. Tq on Btm 9-10K, Tq off Btm 6K, WOB 15-20K 120 rpm.900 gpm,2,950 psi. Total Drill time 32.26 hrs 116ROP Average, APIG= 79 'per Hr. Total Ft Drilled-3755', 53.25 hrs. Drill and Slide; survey 16" Hole From 3,875' MD. (2064' TVD). T/ 4,340' MD (2,140' TVD) AST= 2.80 hrs, ART =2 hrs, ADT = 4.80hrs. Avg. ROP = 97 fph. UP WT. 140K, DN WT. 90K, ROT Wt 110K. Tq on Btm 11 K, Tq off Btm 9K, WOB 15K 120 rpm.900 gpm,2,850 psi. Total Drill time37.06 hrs 113ROP Average, APIG= 71 'per Hr. Total Ft Drilled4220', 59.25 hrs. Drill and Slide; survey 16" Hole From 4,340' MD. (2140' TVD). T/ 4,733' MD (2,245' TVD) AST= 3.13 hrs, ART =.89 hrs, ADT = 4.02hrs. Avg. ROP = 97 fph. UP WT. 160K, DN WT. 80K, ROT Wt 115K. Tq on Btm 14K, Tq off Btm 11K, WOB 15K 120 rpm. 750 gpm,2240 psi. Total Drill time 41.08 hrs 112ROP Average, APIG= 70' per Hr. Total Ft Drilled4,613', 65.25 hrs. Drill and Slide; survey 16" Hole From 4,733' MD. (2245' TVD). T! 5,090' TD (2319 TVD) AST= 1.45 hrs, ART =1.46 hrs, ADT =2.91 hrs. Avg. ROP = 122 fph. UP WT. 170K, DN WT. 75K, ROT Wt 115K. Tq on Btm 14K, Tq off Btm 11 K, WOB 15K 120 rpm. 900 gpm,3300 psi. Total Drill time 43.99 hrs 112 ROP Average, APIG= 71 'per Hr. Total Ft Drilled4,970', 69.75 hrs. Circulate and pump 11 ppg density sweep 60bhls. Trip Out Hole; Back Ream Out Hole 800 GPM 120 RPM Pull @ 35 Ft per Min. Trip Out Hole; Back Ream Out Hole 800 GPM 120 RPM Pull @ 35 Ft per Min. Attempt to pull pipe (over pull 20k,) Cont. Back Reaming to Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska ` Page 4''of 45 Qpell-ations Surnmally Report • Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: ROT -DRILLING Start: 6/22/2005 End: 9/10/2005 Contractor Name: D15CM@conocophillips.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 15 Rig Number: 15 Date 6/30/2005 From - To ~ Hours Code Code .Phase Description of Operations 00:00 - 05:00 5.00 DRILL 05:00 - 08:30 3.50 DRILL 08:30 - 09:30 1.00 DRILL 09:30 - 18:00 8.50 DRILL REAM SURFAC 1,300' Shakers Clean, Pull 2 stands. Pulled free. T/ 1,160'. REAM SURFAC Trip Back in Hole, Plotting Torq and Drag, Tight Spot @ 4,061' to 4,221' MD. Pumped one jt. down was able to work Dn to 4,221' Up WT. 150k- DN WT.70k After 4,221' Dn wt increased T/ 75-78k Run in To 5,050 CIRC SURFAC Circulated 11ppg. weighted sweep @ 940 GPM, W/ 3,670 PSI and 150 RPM, out of drill pipe. REAM SURFAC- Trip Out Hole; Backreaming Pumping @ 940 GPM W/ 3600 PSI and 150 RPM, F/ 5090' T/ 139T MD REAM SURFAC Trip Out Hole; Cont. back reaming @ Step Down Rate supplied by MWD to circ, with out causing damage Pular Valve 700,600,500,400, 300 GPM and 100 RPM, F/ 1,397' (tvd 1,273' 30.22incl.) T/ 670' (Tvd 660' ). Shakers Cleaned Up pulling slow to 670' 18:00 - 19:45 19:45 - 21:00 1.751 DRILL 1.25 ~ DRILL TRIP SURFAC Trip Out Hole; Handling BHA, Stand back HWT-Jar, One stand of Flex 21:00 - 21:30 21:30 - 22:00 22:00 - 22:30 22:30 - 23:00 23:00 - 00:00 7/1/2005 00:00 - 01:15 01:15 - 02:00 02:00 - 04:00 04:00 - 05:15 DC, 0.50 DRILL PULD SURFAC Trip Out Hole; UD BHA, Stab, Float Sub, Ubho Sub to MWD. 0.50- DRILL PULD SURFAC MWD; Service Pulser valve and UD same. 0.50 DRILL PULD SURFAC Trip Out Hole; Flush Motor, Drain same, Break bit and grade, UD Motor 0.50 DRILL PULD SURFAC Clean and clear floor of BHA. 1.00 CASE SFTY SURFAC PJSM, on running casing, R/U casing equipment. 1.25 CASE RURD SURFAC PJSM, on running casing, R/U casing equipment. M/U hanger and 0.75 CASE 2.00 CASE 1.251 CASE 05:15 - 06:00 0.751 CASE 06:00 - 07:30 1.50 CASE 07:30 - 10:00 I 2.501 CASE 10:00 - 10:45 I 0.751 CASE 10:45 - 12:15 1.50 CASE 12:15 - 14:45 2.50 CASE 14:45 - 16:00 I .1.251 CASE 16:00 - 16:15 0.25 CASE 16:15 - 17:30 1.25 CASE 17:30 - 18:30 I 1.001 CASE 18:30 - 19:00 0.50 CASE 19:00 - 20:00 1.00 CASE 20:00 - 00:00 4.00 CASE 7/2/2005 100:00 - 02:00 I 2.001 CEME Landing Jt. Make dummy run with Vetco/Gray hanger. RURD SURFAC P/U & M/U franks fillup tool RUNC .SURFAC P/U and run Shoe2- jts Float 1- Jt fill each test Floats. Run 13 3/8 68# L-80 BTC. 893'. OTHR SURFAC Wieght stacked out on ledge work pipe. From 893' hang collar on conductor 863'. Circulate @ 230 gpm 100psi. Work pipe hitting hard no gain Turn pipe and work down. .RUNC SURFAC Run in Hole W/ 13 3i8 Csg. 68# L-80,BTC.F/ 893' T/ 1,533', Fill every Jt. UP WT. 155k, DN WT. 130k. CIRC SURFAC Circulate; Work 2-Jts Down @ 300 bbls. 5.5 bpm 340 psi. UP WT. 168k, DN WT. 140k. RUNC SURFAC Run in Hole W/ 13 3/8 Csg. 68# L-80,BTC. F/ 1,645, T/ 3,100' Fill every Jt. UP WT. 225k, DN WT. 140k. CIRC SURFAC Circulate; Work Pipe pump 273 bbls. 6.5 bpm 440 psi. UP WT.225k, DN WT. 140k. RUNC SURFAC Run in Hole W/ 13 3/8 Csg. 68# L-80,BTC. F/ 3100, T/ 4500' Fill every Jt. UP WT. 280k, DN WT. 125k. CIRC SURFAC Circulate; Work Pipe pump 638 bbls. 6.2 bpm 450 psi. UP WT.260k, DN WT. 130k. RUNC SURFAC Run in Hole W/ 13 3/8 Csg. 68# L-80,BTC. F/ 4,500 T/ 5,032' Fill every Jt. UP WT. 335k, DN WT. 115k. Install Centalizer. RURD SURFAC M/U Hanger and Landing Jt. OTHR SURFAC Centralizer 17 1/8 would not go through landing ring 17" (shoe @. 5,035'). UD Hanger Jt. P/U to the centralizer on jt # 121. OTHR SURFAC Circulate and Condition; While Grinding Centralizer down to 16 3/4" OD. ` RUNC. SURFAC M/U Hanger and Landing Jt. and land hanger @ 5,079'. RURD SURFAC UD Franks Circulating tool and Install Cement Head. CIRC SURFAC Circulate and Condition Mud for Cmt Job. Before Treatment PV 23, YP 33, Gels 10/10/30= 21/49/75, 9.6ppg. MW, F.V. 92. After Treatment PV 18, YP 18, Gels 10!10/30min 10/15/25, 9.6ppg. F.V. 60. CIRC SURFAC Circulate and Condition Mud for Cmt Job. Before Treatment PV 23, YP 33, Gels 10/10/30= 21/49/75, 9.6ppg. MW, F.V. 92. After Treatment PV Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska Page 5 of 45` Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: ROT -DRILLING Start: 6/22/2005 End: 9/10/2005 Contractor Name: D15CM@conocophillips.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To Hours '~ Code Code Phase Description of Operations -_ -~ ~ 7/2/2005 00:00 - 02:00 2.00 CEMEN CIRC SURFAC 18, YP 18, Gels 10/10/30min 10/15/25, 9.6ppg. F.V. 60. 02:00 - 05:00 3.00 CEMEN PUMP SURFAC Pump 10,bb1's CW 100, Test Line to 3,500 psi, Pump 40 bbl's CW100, 50 bbl's mudpush@ 10.5 ppg W/red dye/ Shutdown and drop BTM plug, Pump 734 bbl's lead cement 10.7 ppg Silo's class ASL yield 4.49 FT3/SK Mix 21.150 Gal/Sk Porosity 62.9% Solid Fraction 37.1 % Slurry type tail cement 12.0 ppg Deep Crete Yield 2.47 FT3/SK Mix Fluid 8.231 GAUSK Porosity 44.5% Solid Fraction 55.5% Recriprocating casing could not get back down to hanger. Casing stuck pulled 420K up casing broke free. Up Wt after free 330 K. Could not work back down came up free stopped 24' above hanger. Drop top plug chase with 20 bbl's water 05:00 - 07:00 2.00 CEMEN DISP SURFAC Start displacement at 7 bpm - 260 PSI with rig pumps. Diverted to cellar with contaminated mud at 4,352 strokes. Slowed pump rate down to 3 - bpm at 5,405strks. To handle returns @ surface. Staged pump rate back up to 5.5 bpm by 5,941 strokes. At 6,200 strokes good cement to surface / 7,050 Strokes pump rate decreased to 3 BPM. 790 psi. Plug bumped at 7,185 strokes W/500 psi over. Total psi 1,300 // CIP 06:46 With 98 bbl's good cement returned to surface. 06:52 checked floats. O.K. C.LP. 07:00 - 09:00 2.00 CASE OTHR SURFAC Rig Down and Wash. Pump Retarder pill through stack and surface lines and stack Function and wash out hydril. 09:00 - 12:45 3.75 CASE OTHR SURFAC Nipple down Diverter, Flow lines and turn buckles. Pull Riser and hydril, Cut 4" lines off conductor. Back out lock downs. P/U hydril To set Emergency slips. Center 13 3/8" Csg. Set Slips 330,000#-70,000 Block WT. = 260k on slips. 12:45 - 16:45 4.00 CASE OTHR SURFAC Cut Hole in 13 3/8" Csg. Drain, R/D Cement head Do Ruff Cut on csg. UD landing jt, Hanger and cut off piece 13 3/8". 16:45 - 20:00 3.25 CASE OTHR SURFAC N/D diverter, Hydril, and 16" riser, Remove Vetco grey head Had trouble removing wellhead (skirt). 20:00 - 23:00 3.00 CASE OTHR SURFAC Welder working on well head doing final cut, Lay Down all csg Tools, Change out bails, Cleaning Rock washer and pits. 23:00 - 00:00 1.00 RIGMNT RSRV SURFAC Change Oil & Filters in Top Drive, Sevice Rig. Heating and welding on well head. 7!3/2005 00:00 - 03:00 3.00 RIGMNT RSRV SURFAC Change Oil & Filters in Top Drive, Sevice Rig. Heating and welding on well head. Wrap well head. Let cool 00;45. 03:00 - 04:30 1.50 RIGMNT RSRV SURFAC Cut and slip drill line 110'. Inspect brakes, 04:30 - 06:30 2.00 RIGMNT RGRP SURFAC Work on Top Drive. Could not P/U Drill Pipe. Clean Rig Floor, Well head cooling, Making up LSDN mud. 06:30 - 08:30 2:00 WELCT OTHR SURFAC Clean Rig Floor, Well head cooling, Making up LSDN mud: 08:30 - 10:30 2.00 WELCT OTHR SURFAC Test Weld Transition to casing 80%Collapse 1,800psi.Test Well head to 5,000psi. F/15min. M/U csg. head and test 5,000psi. F/15min. 10:30 - 16:30 6.00 WELCT NUND SURFAC Nipple up BOP's need to cut down 20" flow nipple. Still Working on Top Drive. 16:30 - 20:30 4.00 WELCT BOPE SURFAC Test BOPE per AOGCC Regs, Approved Drilling Permit, .Test pressures were 250 psi and 3,000 psi. test lower tree seal 250,5,000psi.All test pressures held for 5 min and charted on test recorder. Waived By AOGCC Chuck Scheve, Drilling Supervisor ,and DDI Tourpusher witnessed BOPE test. # 10 Choke Manifold Valve Failed. Will replace before drilling out shoe Notified State Repersenative of plan O.K. By Chuck Scheve. 20:30 - 00:00 .3.50 WELCT BOPE SURFAC Nipple up and test. Time Exceeded 10hrs Contract time allowed. Continue Testing BOP Equipment. 7/4/2005 00:00 - 01:00 1.00 WELCT BOPE SURFAC Test BOPE perAOGCC Regs, Approved Drilling Permit, .Test Printed: 9!30/2005 6:19:05 AM • ConocoPhillips Alaska Page 6 of 45 Operation's Summary Report Legal Well Common Event Nam Contractor Rig Name: Date Name: Well Name: e: Name: _Fi-om - To 1 E-170 1 E-170 ROT -D D15CM Doyon 1 Hours RILLIN @conoc 5 .Code G ophillip Code .com Phase 7/4/2005 00:00 - 01:00 1.00 WELCT BOPE SURFAC 01:00 - 02:00 1.00 WELCT OTHR SURFAC 02:00 - 06:00 4.00 DRILL PULD SURFAC 06:00 - 12:00 6.00 DRILL TRIP SURFAC 12:00 - 13:45 1.75 DRILL CIRC . SURFAC 13:45 - 16:00 2.25 DRILL DEQT SURFAC 16:00 - 18:00 2.00 CEMEN DSHO SURFAC 18:00 - 19:15 1.25 DRILL CIRC SURFAC 19:15 - 21:15 2.00 DRILL CIRC SURFAC 21:15 - 21:30 0.25 DRILL CIRC SURFAC 21:30 - 23:00 1.50 DRILL FIT SURFAC 23:00 - 23:15 0.25 DRILL OTHR INTRM1 23:15 - 00:00 0.75 DRILL DRLG INTRM1 7/5/2005 00:00 - 03:45 3.75 DRILL TRIP INTRM1 03:45 - 04:00 0.25 DRILL TRIP INTRM1 04:00 - 06:00. 2.00 DRILL DRLG INTRM1 06:00 - 08:00 2.00 DRILL DRLG INTRM1 08:00 - 08:45 0.75 DRILL CIRC INTRM1 08:45 - 12:00 3.25 DRILL DRLG INTRM1 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 bescription of Operations pressures were 250 psi and 3,000 psi. test lower tree seal 250,5,000psi.All test pressures held for 5 min and charted on test recorder. Waived By AOGCC Chuck Scheve, Drilling Supervisor ,and DDI Tourpusher witnessed BOPE test. # 10 Choke Manifold Valve Failed. Will replace before drilling out shoe Notified State Repersenative of plan O.K. By Chuck Scheve. Time Exceeded 10hrs Allowed to Nipple up and test BHA. Contractors Charge. UD Test Equipment, Set Wear Ring I.D. OF wear ring 12.312. Move 5" HWT. in Derrick and Change Out Jars. P/U GEO Pilot and Bit. P/U MWD and Upload. P/U BHA. Trip In Hole P/U 5" Drill Pipe, Install Ghost Reamer #1 on jt. # 11, Run 28 more Install Ghost Reamer #2, Run in hole P/U Drill Pipe. Shallow test Geo Tools and MWD @ 700gpm 1,380psi. RiH P/U singles T/ 4,925' Up Wt 155k - DN WT. 70K. Top Drive wieght is 70K Circulate and Condition for Casing Test. Test Casing T/ 3,000psi. Chart and plot. F/30min. Drill Float Equipment and shoe, Float @ 4,967', Shoe @ 5,054 Drilling F/ 5,090'MD New Hole 650GPM 1500 psi. 80 Rpm ART=.14 Pull back up into shoe and circulate while spotting trucks for mud swap over operation Displace well to 9.1 ppg LSND new mud @ 6.5 BPM W/ 280 PSt max. due to cuttings auger. Preform Base Line for PWD with new mud and record SPRs R/U and perform FIT, open hole MD= 5110' TVD= 2323' ,Casing shoe @ 5054' MD/ 2311' TVD, LOT @ 430 psi =EMW= 12.7ppg w/ New Mud wt=9.1 ppg Attemp to down {ink command to Geo Pilot with 720 GPM, losing mud over shakers. Changed jet do skid to size 22 Drill F/ 5110' T/ 5181' ART= .87 TVD= 2326' Pull out of hole f/ 5181' to 13 3/8" casing shoe @ 5054'. Change out jet in Ged pilot skid. Change out shaker screens on shakers. Attempt to work Geo pilot. Change out jet on Geo Pilot skid. Attempting to pump 400 gpm. Shakers running over. Change out all shaker screens to one shaker (set of 4 screens) all 80 mesh, other two shakers to 50 mesh screens. RIH Trip in hole f/ 5084' to 5181 Directional drill 12 1/4" hole f/ 5181' to 5568' (2410' TVD) (387') ART 1.96 hrs w/ Sperry Sun geo pilot, 10-25 WOB, 150 rpm's, 600-900 gpm, 9.1 ppg mw, on bottom pressure 1040-1300 psi, off bottom pressure 980-1500 psi, on bottom toque 10-20k ft/Ib, off bottom torque 8-10k ft/Ib, PU wt 145-150k, SO wt 90-100k, Rot wt 11.8-120k. Directional drill 12 1/4" hole f/ 5568' to 5780' (2441' TVD) (212') ART 1.48 hrs w/ Sperry Sun geo pilot, 10-15 WOB, 150 rpm's, 900-855 gp'm, 9.1 ppg mw, on bottom pressure 1300-1770 psi, off bottom pressure 1500-1750 psi, on bottom toque 10-15k ft/Ib, off bottom torque 7-9k ft/Ib, PU wt 140k, SO wt 100k, Rot wt 115k. PU off bottom, circ @ reduced rate (440 gpm) while change out shaker screens to finer size. Directional drill 12 1/4" hole f/ 5780' to 5998' (2478' TVD) (218') ART 2.16 hrs w/ Sperry Sun geo pilot, 10-20 WOB, 150 rpm's, 865-938 gpm, 9.1 ppg mw, on bottom pressure 1770-1920 psi, off bottom pressure 1750-1890 psi, on bottom toque 10-12k fUlb, off bottom torque 7-10k ft/Ib, PU wt 145k, SO wt 95k, Rot wt 120k. Hard stringers between Printed: 9/30/2005 6:19:05 AM • ConocOPhillips'Rlaska Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To Hours Code Code ~ >Phase' -- 7/5/2005 08:45 - 12:00 3.25 DRILL DRLG INTRMI 12:00- 18:00 6.00 DRILL DRLG INTRM1 18:00 - 00:00 i 6.00 i DRILL i DRLG INTRM1 17/6/2005 i 00:00 - 08:45 8.751 DRILL DRLG I INTRM1 08:45 - 12:00 I 3.251 DRILL I REAM I INTRM1 12:00 - 14:00 I 2.001 DRILL I OTHR I INTRM1 14:00 - 14:45 I 0.751 DRILL I REAM I INTRM1 14:45 - 16:45 2.00 DRILL TRIP INTRM1 16:45 - 18:00 1.25 DRILL OTHR INTRM1 18:00 - 20:30 2.501 DRILL OTHR I INTRM1 20:30 - 00:00 I 3.501 DRILL I OTHR I INTRM1 17/7/2005 100:00 - 11:00 I 11.001 DRILL I OTHR I INTRM1 11:00 - 11:15 0.25 FISH SFTY INTRM1 11:15 - 13:15 2.00 FISH RURD INTRM1 13:15 - 14:00 0.75 FISH ELIN INTRM1 14:00 - 15:00 1.00 FISH ELIN INTRM1 15:00 - 17:00 2.00 FISH OTHR INTRM1 17:00 - 18:30 I 1.501 FISH I ELIN. I INTRM1 Start: 6/22/2005 Rig Release: 9/10/2005 Rig Number: 15 Page T'of 45 Spud Date: 6/26/2005 End: 9/10/2005 Group: Description of Operations 5900' and 6998'. Directional drill 12 1/4" hole f/ 5998' to 6736' (2635' TVD) (740') ART 3.51 hrs w/ Sperry Sun geo pilot, 10-20 WOB, 150 rpm's, 855-942 gpm, 9-9.1 ppg mw, on bottom pressure 1690-2200 psi, off bottom pressure 1650-2190 psi, on bottom toque 10-13k ft/Ib, off bottom torque 7-11 k ft/Ib, PU wt 140-170k, SO wt 100-88k, Rot wt 115-125k. Directional drill 12 1/4" hole f/ 6736' to 7681' (2867' TVD) (945') ART 3.39 hrs w/ Sperry Sun geo pilot, 15-20 WOB, 150 rpm's, 900-933 gpm, 9-9.1 ppg mw, on bottom pressure 2110-2350 psi, off bottom pressure 2100-2310 psi, on bottom toque 10-13k ft/Ib, off bottom torque 8-12k ft/Ib, PU wt 170-172k, SO wt 95-90k, Rot wt 125-127k. Directionally drilled 12 1/4" hole with Geo-pilot f/ 7681' to 9,108' MD/ 3,225' TVD, (1,427') ART 4.29 hrs, 10-20 WOB, 90- 150 rpm's, circ at between 576 at 1,850 psi, to 930 gpm at 2,370 psi, , on bottom torque 13-17k ft-1bs, off bottom torque 10-14k ft/Ib, PU wt 180k, SO wt 100k, Rot wt 130k, 9-9.1 ppg mw, ave ECD 10.1 ppg, while backreaming up to make Conn at 9,068' hole packed off and lost retums Backreamed out of hole slowly while rotating and attempting to regain circ, backreamed out from 9,108' to 8,803' at 150 rpm's and 23K ft-Ibs torque and was unable to regain circ Attempted to regain circ while rotating pipe at 8,803' at 150 rpm's with no success, PU to 300K on DP slacking off to block wt of 70K with no upward movement Reamed down from 8,803' to 9,016' at 150 rpm's while attempting to circ and would pump mud away with no returns POOH f/ 9016' to 8824', PU wt 250-270k ,ream up f/ 8824' to 8774' (tight @ 8774'). While attempting to est circ, pipe rotation stopped, pulled 430K on DP and worked DP up from 9,016' to 8,712', still unable to rotate or circ Attempted to pull pipe free, began PU to 500K on DP while maintaining 900 psi on DP, hydrauliced and moved pipe up hole 24' from 8,712' to 8,688' and pipe stopped Cont to work pipe up while attempting to circ, working pipe up to 500K and down to block wt of 70K, attempting to rotate pipe and circ with no success, called out Baker fishing hand along with Schlumberger wireline, cont. to work pipe while waiting on Schlumberger Cont to work pipe up while attempting to circ, working pipe up to 500K and down to block wt of 70K, attempting to rotate pipe and circ with no success while W.O. Schlumberger (SWS) E-line Held PJSM with SWS and rig crew on RU of E-line RU SWS wireline scheaves and lubricator, MU 1.56" pert gun on 1 11/16" tool string, tool length 16.1' RIH with 1.56" pert gun with CCL on E-line to 2,200' with no pump, attempted to pump down tool from 2,200' and was only able to get to 2,400', staged pump rate up from 1/2 bpm to 4 bpm at 1,080 psi and was unable to get tool deeper POOH and LD perf gun Changed out E-line from .39" to .23" line and added 3- 2" pieces (4' total) of roller stem to tool string, overall tool length 17.9' RIHwith 1.56" pert gun with CCL on E-line to 2,200' with no pump, attempted to pump down tool from 2,200' and was only able to get to 2,500', staged pump rate up to 3 bpm at 960 psi and was unable to get tool deeper Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska Page s of 45 Operations Summary Report Legal Well. Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To Hours Code Code Phase ___ 7/7/2005 18:30 - 19:45 1.25 FISH ELIN INTRM1 19:45 - 21:30 1.75 FISH ELIN INTRM1 21:30 - 23:00 I 1.501 FISH I ELIN I INTRM1 23:00 - 00:00 1.00 FISH ELIN INTRM1 7/8/2005 00:00 - 01:30 .1.50 FISH ELIN INTRM1 01:30 - 09:30 8.00 WAITON EQIP INTRM1 09:30 - 12:30 3.00 WAITON EQIP INTRM1 12:30 - 13:30 1.00 FISH FISH INTRM1 13:30 - 16:15 2.75 RIGMNT RSRV INTRM1 16:15 - 17:15 1.00 FISH JAR INTRM1 17:15 - 00:00 6.75 WAITON EQIP INTRM1 17/9/2005 00:00 - 00:30 0.50 FISH SFTY INTRM1 00:30 - 04:30 4.00 FISH ELIN INTRM1 04:30 - 06:15 I 1.751 FISH I ELIN I INTRM1 06:15 - 07:15 1.00 FISH ELIN INTRM1 07:15 - 08:15 1.00 FISH RURD INTRM1 08:15-09:15 1.00 FISH. OTHR INTRM1 09:15 - 10:30 1.25 FISH ELIN INTRM1 10:30 - 11:15 I 0.751 FISH I RURD INTRM1 12:20 - 14:15 ( 1.921 FISH I ELIN I INTRM1 14:15 - 15:30 I 1.251 FISH I ELIN I INTRM1 15:30 - 16:45 1.251 FISH I ELIN I INTRM1 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations POOH and LD perf gun MU perf string with roller stem and MU 5" OD x 1/4" thick piece of DP rubber wiper plug on btm of perf string to aid in pumping tool down RIH with 1.56" perf gun pumping tool down, staged pump rate up from 1 bpm at 870 psi to 4 bpm at 1,050 psi, was only able to get tool down to 2,200', appears to be pumping mud past tool string POOH and LD perf gun, saw no wear on wiper plug, Note: while attempting to pump tool down hole on the 3 runs we pumped a total of 216 bbls away RD Schlumberger wireline and scheaves Waited on coiled tbg unit and crane, repositioned HWDP in derrick for coiled tbg and performed derrick inspection, tightening bolts. on top drive rails, decision was made at 09:30 not to run coil tbg and re-run E-line, crane and coiled tbg unit on location at 06:30 hrs Called out SWS, prep rig for wireline while W.O. SWS, called out WeIlTech tractor tool and equipment also Performed blind back off on top jt and changed out same due to egged spot on tube Changed out 4 1/2" IF saver sub on top drive, inspected and serviced top drive and greased blocks Jarred on fish at 8,688' with no movement, PU to 500K working jars Waited on E-line unit with tractor tool, SWS and Well Tech worked on hooking tractor tool electronics to E-line unit at KIC, E-line unit arrived location at 23:45 hrs Held PJSM with SWS, Welltec and rig crew on RU of wireline tools RU SWS scheaves, grease injector head and control line, 2-5" pup jts with safety valve, MU 1.56" x 5' perf gun with 30 shots on 1 11/16" tool string with 2 pieces of roller stem (3' long) along with SWS SCUD tool used to assist in pumping down tools RIH with 1.56" perf gun to 2,320' without pumping, began staging pump rate up from 1/2 bpm to 4 bpm at 970 psi while working tool string down to 2,952', took 30 min to work tool last 12', pumped a total of 217 bbls of 9.0 ppg mud while attempting to pump tool down POOH w/ wireline. Deepest could get was 2952'. Held PJSM. Rig down Schlumberger lubricator, hoses f/ grease tube, sheaves, and drill pipe pup jts. PU on string to 225k. Set slips w/ 225k on slips. Rig up Schlumberger sheaves, TIW valve, and grease head for tractor run w/ perf guns. Waiting on Schlumberger tools (40' gun spacer-(2) 20' jts- blank gun stock w/ TCP connection on top). PU Schlumberger wireline gun and Weltech tractor assembly. MU pump in head and packoff. Tool string consisted of 1-11/16" wireline head, 1-11/16" Swivel, 2-1/8" Weltech tractor, 1-11/16" CCL, 1-11/16" Addressable tractor protection switch, 1-11/16" Firing head, 1.56" Gun (High Shot Density (HSD powerjet) 60 deg phase/360 deg, 6 shots per ft). Total tool string length 31.T. RIH w/ Schlumberger wireline tools to 2202' using gravity. Start using Welltec tractor to get 31.7' tool string (5' perf guns} in hole f/ 2202' to 6500'. Running 40'/min. Continue Welltec tractor, RIH f/ 6500' to tie in CCL w/ 2nd ghost reamer in hole @ 7882.39'. Continue Welltec tractor, RIH f/ 7882' to 8300' Printed: 9/30!2005 6:19:05 AM s • ConocoPhillips Alaska page 9' of 45' Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: ROT -DRILLING Start: 6/22/2005 End: 9/10/2005 Contractor Name: D15CM@conocophillips.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 15 Rig Number: 15 Date ', From - To Hours Code .Code Phase 'r Description of Operations 7/9/2005 16:45 - 17:00 0.25 FISH ELIN INTRM1 Continue to RIH w/ tool string f/ 8300' to CCL depth of 8376.5'. This places top shot @ 8381'- bottom shot @ 8386'. (This is 3'-4' away f/ bottom tool joint upset and 3'-4' f/ middle upset bottom, on first 5" HWDP above Daily/V1/eatherfordfars). Another way to put this is: 5.36' above box on jars is bottom shot placement. Tooljoint is 2.3' long. 17:00 - 18:15 1.25 FISH ELIN INTRM1 Attempt to fire Schlumberger guns @ 8381'- 8386' in jt of 5" HWDP above jars. Could not fire guns. Confirm w/ gun manufacter on rig up, running w/ tractor. Toolstring needs another piece. Note: 4 bbls fluid lost in last 12 hours to the hole. 18:15 - 19:30 1.25 FISH ELIN INTRM1 POOH w/ Schlumberger WL and Welltec tractor f/ 8376' to surface. 19:30 - 20:45 1.25 FISH ELIN INTRM1 UD Schlumberger toolstring. Reconfigure toolstring w/ xtra switch. 20:45 - 21:00 0.25 FISH SFTY INTRM1 PJSM on picking up wireline tools. 21:00 - 21:30 0.50 FISH ELIN INTRM1 PU tool string, RIH 200' MU grease head and control lines. 21:30 - 00:00 2.50 FISH ELIN iNTRM1 RIH w/ Schlumberger WL and Welltec tractor w/ 5' pert gun at 4000' 7/10/2005 00:00 - 01:00 1.00 FISH ELIN INTRM1 Continue RIH w/ Schlumberger WL and Welltec tractor w/ 5' pert gun at f/ 4000' to 6233'. 01:00 - 02:45 1.75 FISH ELIN INTRM1 Generator supporting Weltech tractor drive, failed. Change out generator. 02:45 - 06:00 3.25 FISH ELIN INTRM1 Continue RIH w/ Schlumberger WL and Weltech tractor w/ 5' pert gun at f/ 4000' to 7882'. Second ghost reamer @ 7882'. 06:00 - 06:45 0.75 FISH ELIN INTRM1 Continue RIH w/ SWS WL and Welltec tractor f/ 7882'. Tie in w/ CCL with second ghost reamer @ 7882' PU wt 1550 pounds while pulling @ 50'/ min 06:45 - 07:45 1.00 FISH ELIN INTRM1 Continue RIH w/ SWS WL and Welltec tractor f/ 7950'-8250' (First HWDP @ 8237). 07:45 - 09:42 1.95 FISH ELIN INTRM1 Continue RIH w/SWS WL and Welltec tractor f/ 8250' to CCI on depth @ 8372.3' (top shot @ 8381', bottom shot @ 8386'. 09:42 - 09:45 0.05 FISH ELIN INTRM1 SWS fire guns w/ 1120 pounds line tension, lost 20-25 pounds line tension once guns were activated. 09:45 - 09:50 0.08 FISH ELIN INTRM1 POOH w/SWS wireline. Log ghost reamer on way out. 7882'-7888' WLM. On depth. 09:50 - 10:45 0.92 FISH ELIN INTRM1 Continue POOH w/ wireline f/ 7882' to 200' @ 150'/min. Wireline size .32": wireline displacement 185#/ft/1000' @ 8300'= .5 bbls= 31' inside dp. 10:45 - 11:30 0.75 FISH ELIN INTRM1 R/D SWS packoff, finish POOH w/ wireline tools, UD tools. leave equipment on floor. All shots fired. 11:30 - 11:45 0.25 FISH CIRC INTRM1 MU top drive. Pump @ 1 bpm 800/810 psi. 6 bbls to fill and/or pump away. Pump total of 9 bbls. Shut down pumps. Attempt to cock jars w/ no success, work pipe down to 500K (pressure bleed to 670 psi).. 11:45 - 14:30 2.75 FISH CIRC INTRM1 Start pumps @ .75 bpm w/ 530 psi. 7% flow. Work up slow to 2.5 bpm w/ 860 psi w/ 14% flow. MW out 9.4 ppg vis 108. MW in 9.0+ vis 55. Total fluid pumped 350 bbls so far. 14:30 - 14:45 0.25 FISH CIRC INTRM1 Increase pumps f/ 2.5bpm to 3 bpm. 3BPM w/ 940-753 psi w/ 25% flow. Total fluid pumped 420 bbls so far. 14:45 - 15:15 0.50 FISH CIRC INTRM1 Increase pumps f/ 3bpm to 5 bpm. 5 BPM w/ 800 psi w/ 26% flow. Total fluid pumped 500 bbls so far. 15:15 - 16:15 1.00 FISH CIRC INTRM1 Increase pumps f/ 5 bpm to 6 then 7 bpm. 7 BPM w/ 900 psi w/ 30% flow. Total fluid pumped 870 bbls so far. 16:15 - 17:45 1.50 FISH CIRC INTRM1 Increase pumps f/ 7bpm to 8 then 9 bpm. 9 BPM w/ 940 psi w/ 33% flow. Total fluid pumped 2475 bbl, then pump 62 bbl sweep 9.2 ppg w/ 83 vis. Follow w/ 9.1 59-62 vis mud. Started working pipe @ 1645 hrs. PU 480k Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska Page 10 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date ~ From - To ~ Hours Code Sub ~ Phase Code 7/10/2005 17:45 - 20:00 ~ 2.25 ~ FISH CIRC INTRM1 20:00 - 20:30 I 0.501 FISH I CIRC I INTRM1 20:30 - 21:30 1.00 I FISH CIRC I INTRM1 21:30 - 23:15 I 1.751 FISH I CIRC I INTRM1 23:15 - 00:00 I 0.751 FISH I PULL I INTRM1 7/11/2005 00:00 - 00:30 0.50- DRILL TRIP INTRM1 00:30 - 06:00 5.50 DRILL REAM INTRM1 06:00 - 07:45 1.75 DRILL CIRC INTRM1 07:45 - 08:30 0.75 DRILL CIRC INTRM1 08:30 - 08:45 0.25 DRILL TRIP INTRM1 08:45 - 09:15 0.50 DRILL CIRC INTRM1 09:15 - 11:15 2.00 DRILL TRIP INTRM1 11:15 - 11:45 0.50 DRILL TRIP INTRM1 11:45 - 12:30 0.75 DRILL PULD INTRM1 12:30 - 13:30 1.00 DRILL PULD INTRM1 13:30 - 14:30 1.00 DRILL PULD INTRM1 14:30 - 15:30 1.00 DRILL PULD INTRM1 15:30 - 16:30 1.00 RIGMNT RSRV INTRM1 16:30 - 18:00 1.50 DRILL PULD INTRM1 18:00 - 19:00 1.00 DRILL PULD INTRM1 19:00 - 20:00 1.00 DRILL PULD INTRM1 20:00 - 21:30 1.50 DRILL TRIP INTRM1 21:30 - 22:00 0.50 DRILL TRIP INTRM1 22:00 - 22:30 0.50 DRILL CIRC INTRMI 22:30 - 23:15 0.75 DRILL TRIP INTRM1 23:15 - 23:45 0.50 DRILL TRIP INTRM1 23:45 - 00:00 0.25 DRILL OTHR INTRM1 17/12/2005 00:00 - 01:15 1.25 RIGMNT RSRV INTRM1 01:15 - 02:00 0.75 DRILL OTHR INTRM1 02:00 - 02:30 0.50 DRILL TRIP INTRM1 02:30 - 06:00 3.50 DRILL REAM INTRMI 06:00 - 07:45 I 1.751 DRILL I REAM I INTRM1 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations Increase pumps f/ 9 bpm to 10 bpm. 10 BPM w/ 940 psi w/ 34% flow. Total fluid pumped after sweep, 600 bbls so far. Increase pumps f/ 10 bpm to 11 bpm. 11 BPM w/ 1150 psi w/ 35% flow. Total fluid pumped after sweep, 850 bbls so far. MW in 9.1 vis 61, mw out 9.1 vis 59. Increase pumps f/ 11 bpm to 12 bpm. 12 BPM w/ 1230 psi w/ 37% flow. Total fluid pumped after sweep, 1200 bbls so far. MW in 9.1 vis 61, mw out 9.1 vis 59. Pump 40 bbls water, follow w/ 80 bbl 9.0 mw 92 vis sweep. Continue circ @ 12 bpm 1100 psi 38% flow while working drill pipe and jars, pulled 450K and actuated jars, afterjars hit continue to pull up to 500K BHA began to move, worked pipe and BHA, pulled bit to 8,418' with 420K-480K at report time - Pulling bit f/ 8,418' with 420K-480K, continue pulling to 8226'. Backream out of hole f/ 8226' to 4992'. Ream w/ 60 RPM, 12-14k torque, 337 gpm w/ 500 psi. Rig down Schlumberger wireline. Circ and condition mud and hole. Pump 920 gpm w/ 1750 psi, rotate 150 rpm. Perform derrick inspection after jarring.. Bit is inside of 13 3/8" casing. POOH 5 stands f/ 4992' to 4527', monitor fill, ok. Pump dry job, blow down top drive. POOH f/ 4527' to 1699'. UD top ghost reamer. Continue POOH. f/ 1699' to 800', UD second ghost reamer. POOH f/ 800' to 358'. UD 1 jt 5" HWDP, UD HWDP above jars w/ shot holes. 31 dimples in jt. (lowest 7.35' above pin end connection)( while in hole perf's @ 8379'-8384'). UD Daily/Weatherford jars( ser # 15161078). POOH 1 stand 5" HWDP. UD Sperry Sun BHA. 8" NM flex DC's (ser# 192421, 192413, 192417), NM float sub (ser # 4150). Break Security 12 1/4" FMFX 553 bit (ser # 10394493) Download Sperry Sun MWD/LWD. UD 8" pulsar (ser # 78388K8), 8" GR/RES/PWD(ser # 7745HAWRG8), NM GP flex DC(ser # CP972705), Geo Pilot 9600 with top stab (ser # TL078) Service top drive. PJSM, PU/MU new BHA, MU bit #3. Upload Sperry Sun MWD tools. Continue PU/MU Speny BHA. SLM 4 stands 5" HWDP. Continue trip in hole 11 jts 5" DP, MU Weatherford 12 1/4".ghost reamer, 28 jts 5" DP, Weatherford ghost reamer RIH 5" DP f/ 1828' to 2550'. Fill pipe, break circ. RIH 5" DP f( 2550' to 3500', fill pipe. RIH 5" DP f/ 3500' to 5026', fill pipe. Move 5" dp in derrick f/ ODS to DS. Inspect brakes on drawworks. Loose jam nut, tighten same. Replace broken grease fitting line. Base line PWD. RIH f/ 5086' to 5290'. Taking weight going down. No string weight left. Ream in hole f/ 5290' to 6389', rotate @ 60 rpm, pump 900 gpm w/ 2350 psi, 10'/min. PU wt 170k, so wt 80k, rot wt 125k. Torque 10-11 k. Ream in hole f/ 6389' to 6975', rotate @ 60 rpm, pump 900 gpm w/ Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska Page ~ ~ of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date ~ From - To Hours Code ~ Sub ~ Phase. Code 7/12/2005 06:00.- 07:45 1.75 DRILL REAM INTRM1 07:45 - 14:30 6.75 DRILL REAM INTRM1 14:30 - 16:30 2.001 DRILL CIRC I INTRM1 16:30 - 17:00 I 0.501 DRILL REAM INTRM1 17:00 - 18:00 I 1.001 DRILL I DRLG INTRM1 18:00 - 00:00 I 6.00 DRILL I DRLG INTRM1 17/13/2005 ~ 00:00 - 06:00 6.001 DRILL I DRLG I INTRM1 06:00 - 11:00 I 5.00 DRILL I DRLG INTRM1 11:00 - 11:30 0.50 DRILL CIRC INTRM1 11:30 - 12:00 0.50 DRILL REAM INTRM1 12:00 - 18:00 6.00 DRILL REAM INTRM1 18:00 - 00:00 6.00 DRILL REAM INTRM1 7/14/2005 00:00 - 02:15 2.25 DRILL REAM INTRM1 02:15 - 03:30 1.25 DRILL CIRC INTRM1 03:30 - 04:00 0.50 DRILL TRIP INTRM1 04:00 - 05:30 1.50 DRILL CIRC INTRM1 05:30 - 06:00 0.50 DRILL OBSV INTRM1 06:00 - 09:30 3.50 DRILL TRIP INTRM1 09:30 - 11:00 1.50 DRILL PULD INTRM1 11:00 - 11:45 0.75 DRILL PULD 1NTRM1 11:45 - 12:00 0.25 DRILL TRIP INTRM1 12:00 - 13:00 1.00 DRILL TRIP INTRM1 13:00 - 16:30 3.50 CASE OTHR INTRM1 16:30 - 17:00 0.50 CEMEN PULD INTRM1 17:00 - 18:00 1.00 CASE RUNC INTRM1 18:00 - 18:30 0.50 CASE SFTY INTRM1 18:30 - 00:00 5.50 CASE RUNC INTRM1 7/15/2005 100:00 - 04:30 4.501 CASE RUNC I INTRM1 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations 2350 psi, 10'/min. PU wt 170k, so wt 80k, rot wt 125k. Torque 10-11 k. Ream in hole f/ 6975' to 9048', rotate @ 150 rpm, pump 900 gpm w/ 2650 psi, 15'/min. PU wt 180k, so wt 95k, rot wt 133k. Torque 16-19k ft/Ibs ECD 9.98. No losses while reaming to bottom. Circ & cond to clean hole. Backream @ 2 fpm f/ 9048`-8950'. 910 gpm w/ 2650 psi, Up wt, 180k, Dn wt. 95k, Rt wt. 133k, Torque 16-19k ft/Ibs. Perform Base line for PWD w/ clean hole (9.94). Ream to bottom f/ 9048' to 9108' All reaming parameters same as above. Drilling f/ 9108' to 9170'. 750 gpm w/ 2050 psi. 120 rpm, Torque on bttm 16-18 k ft/Ibs, off bottom 16k ft/Ibs, Up wt 180k, Dn wt 95k, Rot wt 134k. ADT .55 hrs Drilling f/ 9170' to 9506'. 905 gpm w/ 2750 psi, 150 rpm, Up wt. 190k, Dn wt. 98k, Rot wt. 133k. Torque 14-20k fUlbs. ADT = 4.96 hrs. Drilling f/ 9506' to 9960'.(ND 3363'). Up wt. 195k, Dn wt 100k, Rot wt 130k, Torque 20-21 k ft/Ibs on bttm, 15-16k ft/Ibs off bttm w/ 150 rpm, 916 gpm w/ 2950 psi. ART= 3.95 hrs. ECD= 10.33 Drilling f/ 9960' to 10,420'.(ND 3452'). Up wt. 190k, Dn wt 90k, Rot wt 130k, Torque 20-22k ft/Ibs on bttm, 17-22k ft/Ibs off bttm w/ 150 rpm, 900 gpm w/ 2950 psi. ART= 2.55 hrs. ECD= 10.4 Circulate w/ Rotation & reciprocation. MWD survey, SPR's Backream out of hole @ 2 fpm w/ 150 rpm, 900 gpm to clear cuttings from BHA. Back ream out of hole f/ 10,365' to 8706' @ 15 fpm w/ 150 rpm, 900 gpm. Record TAD data w/ backreaming. Torque 13-18k ft/Ibs. No Losses Back ream out of hole f/ 8706' to 6960'. 850 gpm w/ 2500 psi, 125 rpm. From 8706' to 8007' BROOH @ 2-3 fpm (Torque erratic 10-22k ft/Ibs) to help clean holes BROOH f/ 8007' to 7436' @ 15-16 fpm (Torque 10-22k ft/Ibs). From 7436' to 6960' @ 15-16 fpm (Torque 13-17k fUlbs). ECD's f/ 10.4-10.1. Steady cuttings load @ shakers (no waves). Slight Losses (16 bhr) Continue BROOH from 6,960' - 5,897'. Circ bottoms up 2X, at 874 gpm, 1,900 psi. ,POOH from 5,897 - 5,054' - no problems. Circ hole clean @ 874 gpm and 1,900 psi, spot tube pill. RPM = 125, TO = 9,000 ft-Ib, UWT = 135K, DWT = 100K, ROT = 115K. Monitor well -static. Pump dry job, blow down TD, drop 2-7/8" Rabbit. POOH to BHA. SLM 5" DP. LD Reamers. LD BHA -Jars, 3-Flex DCs, and break out bit. Download MWD. LD MWD Continue LD BHA, clean and clear floor. Change out bottom RAMS to 9-5/8". Function test Blind RAMs, Lower Pipe RAMS and Annular preventer. Pull Wear Ring, test 9-5/8" RAMS to 250 / 3,000 psi, 5 min each. Install Wear Ring and LD test Jt. RU Cement head. RU 9-5/8" Csg equipment PJSM with all parties. PU/MU liner shoe joints. Check floats -okay. Run 70 jts of 9-5/8", 40 Ib/ft, L-80, BTC to 2,690' tmd. Spiralglider centralizers run on every joint (floating). Fill pipe every 5 joints. Run torque rings in every joint. Average MU t4 = 8,500 ft-Ib. Continue running 9-5/8" liner without problems. Run a total of 144 jts Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska Page:.. ~ 2 of 45 Operations'Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: ROT -DRILLING Start: 6/22/2005 End: 9/10/2005 Contractor Name: D15CM@conocophillips.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 15 Rig Number: 15 Date From'- To ~i Hours Code Code Phase Description of Operations - ~ - ---- 7/15/2005 00:00 - 04:30 4.50 CASE RUNC INTRM1 with a total of 142 spiralglider centralizers -floating. 04:30 - 05:30 1.00 CASE RUNC INTRM1 RD casing handling equipment and change elevators for 5" DP. Install wiper plug and MU 9-5/8" x 13-3/8" hanger.. Mix packer hydraulic fluid and fill same. Set Iron Roughneck track and MU first stand of DP. 05:30 - 06:00 0.50 CASE RUNC INTRM1 CBU at 300 GPM and 200 psi. Rotate liner string at 10 rpm with 12-17K ft-Ib of torque. UWT=190K, DWT=102K, ROT=112K 06:00 - 12:00 6.00 CASE RUNC INTRM1 RIH w/ liner to 7,350'. Circ new mud in hole every 5 stds. UWT - 195K, DWT - 80K, ROT - 120K. 12:00 - 15:00 3.00 CASE RUNC INTRM1 Wash and ream pipe from 7,350 - 8100'. Note: Pipe would no longer slide downhole without pumping and or rotating from 7,350' on. 15:00 - 18:00 3.00 CASE RUNC INTRM1 Work pipe from 8,100 - 9,200'. UWT - 125K, DWT - 80K, ROT - 125K. Rotate at 10-15 rpm with 15-20K ft-Ib of TQ, 65 SPM and 320 psi. 18:00 - 20:45 2.75 CASE RUNC INTRM1 Continue to work liner to bottom circulating at 4-6 BPM with 320-380 psi, 15-20 RPM and 20 ft-Ib ofTQ. Tag bottom and PU 6'. UWT=245K, DWT=90K. 20:45 - 21:00 0.25 CEMEN RURD INTRM1 RU cmt head and circ lines. MU same. 21:00 - 00:00 3.00 CEMEN CIRC INTRM1 Rotate and reciprocate liner at 20 rpm. Circ and condition mud for cmt job. Stage pump from 4.5 BPM to 8BPM at 500 psi. Mud before/after = 9.45/9.0 ppg, PV/YP = 16/25 =>11/16. 7/16/2005 00:00 - 01:30 1.50 CEMEN CIRC INTRM1 Fin circ & cond mud for cementing, circ at 80 spm, 8 bpm at 560 psi, st up wt 205K do wt 145K, torque limiter set at 20K ft-Ibs with 10-20 rpm's up & down. Held PJSM W/Dowell, ASRC and rig crew on cementing detail and potential hazards, cont to circ hole while holding PJSM, Mud before/after = 9.45/9.0 ppg, PV/YP = 16/25 =>11/16. 01:30 - 02:15 0.75 CEMEN PUMP INTRM1 Turned over to Dowell and pumped 10 bbls CW 100, pressure tested lines to 4,000 psi, pumped 30 bbls add. CW 100 at 8.3 ppg, ave 6.75 bpm at 350 psi, then pumped 40 bbls of MudPush at 10.5 ppg, ave 5 bpm at 100 psi, began mixing cmt @ 02:00 hrs, started pumping cmt at 02:02 cont to rotate & reciprocate pipe, at 02:15 after pumping 63 bbls of cmt, pump truck went down, appears to be an electrical problem (5hrs pump time on cmt). 02:15 - 03:15 1.00 CEMEN OTHR INTRM1 Worked pipe every 5 min's rot &recip & ck ok while Dowell swapped out pump trucks. 03:15 - 04:00 0.75 CEMEN PUMP INTRM1 Resumed pumping at 03:18 hrs, pumped an additional 242 bbls of cmt, pumped a total of 305 bbls (761 sxs) of DeepCrete cement at 12.5 ppg and 2.25 yield with additives, ave 5.75 bpm at 80 psi , cont to rotate and recip. pipe with fullreturns, shut down. 04:00 - 05:15 1.25 CEMEN DISP INTRM1 Dropped DP wiper plug, Dowell pumped 10 bbls water and rig displaced cmt. With 9.0 ppg LSND mud, Initial rate 8 bpm at 400 psi, slowed pump rate to 3 bpm and saw LWP shear at 1,100 psi, cont to displace cmt at 8 bpm, final pressure at 8 bpm 690 psi, slowed to 3 bpm and landed liner wiper plug, cont to rot. &recip pipe till within 5 min of bumping plug, st wt up 200K, do wt 110K, with torque limiter set at 25K ft-Ibs had 10-15 rpms while working pipe, bumped plug on calc displacement, CIP at 05:10 hrs, Est TOC @ 6,305', had full returns during the job 05:15 - 05:30 0.25 CEMEN OTHR INTRM1 Pressured upon liner wiper plug to 2,500 psi and slacked oft 40K and set Flex-Lock hanger, pressured up to 4,000 psi and released from HR ~, running tool, bled pressure down to 750 psi and pulled out of "RS" packoff and pressure bled off, st up wt 140K, set TOL at 8,432' i MD/2,265' TVD. 05:30 -07:45 2.25 CEMEN CIRC INTRM1 Circ hole clean above TOL at 8,432', circ at 150 spm, 640 gpm at 1,180 Pflflt0tl: 5/3U/20Ub 6:1 y:Ub AM • ConocoPhillips Alaska Page ~ 3 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud. Date: 6/26/2005 Event Name: ROT -DRILLING Start: 6/22/2005 End: 9/10/2005 Contractor Name: D15CM@conocophillips.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 15 Rig Number: 15 Date'. From - To i __ 7/16/2005 05:30 -.07:45 Hours Code Code ...Phase .2.251 CEMEN CIRC INTRMI Description of Operations 07:45 - 08:00 0.25 CEMEN RURD INTRM1 08:00 - 11:00 3.00 CEMEN TRIP INTRM1 11:00 - 12:00 1.00 CEMEN PULD INTRMI 12:00 - 12:30 0.50 CASE OTHR INTRM1 12:30 - 13:30 1.00 CASE . RURD INTRM1 13:30 - 13:45 0.25 CASE SFTY INTRM1 13:45 - 00:00 10.25 CASE RUNC INTRM1 7/17/2005 00:00 - 00:30 00:30 - 01:30 0.50 CASE RUNC INTRMI 1.00 CASE RUNC INTRM1 01:30 - 02:15 02:15 - 03:15 03:15 - 05:30 05:30 - 06:00 06:00 - 08:00 08:00 - 09:30 0.751 CASE I RUNC I INTRM1 1.00 CASE CIRC. INTRM1 2.25 CASE CIRC INTRM1 0.50 CASE OTHR INTRM1 2.00 CASE OTHR INTRM1 1.501 CASE I OTHR I INTRM1 09:30 - 11:00 1.50 CASE OTHR INTRM1 11:00 - 12:30 1.50 WELCT NUND INTRM1 12:30 - 14:30 2.00 WELCT NUND INTRM1 14:30 - 15:30 1.00 WELCT NUND INTRM1 15:30 - 18:00 2.50 WELCT NUND INTRM1 18:00 - 19:00 1.00 DRILL PULD INTRM1 19:00 - 20:15 1.25 DRILL PULD INTRM1 20:15 - 21:00 0.75 WELCT OTHR INTRM1 21:00 - 00:00 3.00 WELCT BOPE INTRMI 7/18/2005 00:00 - 02:00 2:00 WELCT BOPE INTRM1 psi, at btms up saw a slight amount of CW 100 back at surface, monitored well static RD cement head/plug dropping head and lines POOH from 8,432' to liner running tool at 34' Made service breaks on liner running tool and LD same Pulled wear bushing RU GBR's 9 5/8" csg equipment Held PJSM on MU seal assembly, packer and RlH with 9 5/8" csg MU Baker 13 3/8 x 9 5/8" JMZXP packer with seal assembly and RIH slow with 9 5/8", 40#, L-80, BTCM csg to 4,650', RIH with 120 jts of 125 total to be ran, installed 1 straight blade aluminum centralizer on every 3rd jt st wt up 175K, do wt 118K Run 9-5/8", L-80, BTC-Mod, 40 ppf casing to liner top. 124 joints total, run one centriizer every third joint 41 total: Up Wt175k, Dn wt 118k. MN XO sub f/ Top Drive & torque same. P/U joint 125.& M1U same to TopDrive. PJSM w/ Company Rep, Toolpusher & Rig Hands. Break Circ w/ mud, 3 bpm @ 70 psi, 4 bpm @ 80 psi. Slack off locate seals S/D pumps slack to 4840' (No-Go) Mark Casing. Circ Bottoms up w/ Mud @ 4 bpm 100 psi. Displace to H2O @ 4830', Pump 6 bpm w/ 100 psi. Monitor well for flow (static) R/U lines & Reverse Diesel into annulus. 2.5 bpm. 110 psi. Continue to freeze protect annulus w/ diesel @ 2.5 bpm 270 bbls total FCP 320 psi. ,Slack off to insert seals & set JMZX packer. Set down all the available weight unable to get complete set, bleed off annular pressure to 200 psi ~ transfer more weight to packer. Press. up to test packer bleeding by. 'Increase pressurer 700 psi & bleed off same. Packer set. Pressure up to 1000 psi / 15 minutes O psi loss. Bleed off pressure & open Hydril. P/U to 275k to check packer (up wt 175k) PJSM- Break circ swedge, f/ 9-5/8" casing & Top Drive. blow down all lines, Pump out casing for cut-off, drain stack. Nipple down flow liine, turnbuckles choke line, drip pan, split stack stack & raise same. P/U casing to 225k, center casing, set slips, cut-off 9-5/8" casing and clean up metal shavings. Install 13-3/8" X 9-5/8" pack-off seals. Set down BOPS. Test seals to 2200 psi / 15 min. OK. Nipple up BOPs, Clean out cement in flow line f/ surface job. Change bottom rams to 6" X 3-1/2" VBRs. Check accumulator bottles. Break down TIW valve & XO f/ Top of joint. UD 9-5/8"joint & cut off joint (9.90') P/U cmt head & break down same. Clear floor R/U for BOP test Test BOP's. Lou Grimauldi, AOGCC rep witnessed test. Test to 250 psi low, 3000 psi high. Test BOP's 250/ Low 5 min, 3000/ high 5 min, Chart test. AOGCC rep. Lou Grimauldi witnessed the test. Tested Hydril, HCR's, Upper rams, Choke manifold (valves 1-18), Floor safety valve, Dart valve, Manual choke & Kill line valves, Lower pipe rams, Blind rams, Upper IBOP, Lower IBOP. Perform Accumulator test, Starting pressure 3000, PSI Printed: 9/30/2005 6:19:05 AM • ConocoPhillips,Alaska Page ~~ ot45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM~a conocophillips.com Rig Name: Doyon 15 Date From -'To ff Hours ,Code Code Phase 7/18/2005 ~ 00:00 - 02:00 ~ 2.00 I WELCT BOPE I INTRM1 02:00 - 02:30 I 0.501 DRILL I RIRD I INTRM1 02:30 - 04:30 2.00 DRILL TRIP INTRM1 04:30 - 05:30 1.00 RIGMNT RSRV INTRM1 05:30 - 06:00 0.50 DRILL PULD INTRM1 06:00 - 06:30 0.50 DRILL PULD INTRM1 06:30 - 14:00 7.50 DRILL TRIP INTRM1 14:00 - 15:00 1.00 RIGMNT RSRV INTRM1 15:00 - 18:00 3.00 RIGMNT OTHR INTRMI 18:00 - 20:00 2.00 RIGMNT OTHR INTRM1 20:00 - 23:00 3.00 DRILL PULD INTRM1 23:00 - 00:00 - 1.00 -DRILL PULD INTRM1 00:00 - 00:30 0.50 DRILL PULD INTRM1 00:30 - 01:45 1.25 DRILL PULD INTRM1 01:45 - 08:30 6.75 DRILL TRIP INTRM1 08:30 - 11:30 3.00 DRILL TRIP INTRM1 11:30 - 12:00 0.50 DRILL SFTY INTRM1 12:00 - 15:30 3.50 DRILL CIRC INTRM1 15:30 - 18:00 I 2.501 DRILL I DEQT I INTRM1 18:00 - 19:15 1.25 DRILL OTHR INTRM1 19:15 - 00:00 4.75 DRILL TRIP INTRM1 7/20/2005 00:00 - 01:30 1.50 DRILL PULD INTRM1 01:30 - 02:00 0.50 DRILL OTHR INTRM1 02:00 - 04:15 2.25 DRILL TRIP INTRM1 04:15 - 06:30 2.25 DRILL OTHR INTRM1 06:30 -.07:30 1.00 DRILL OTHR INTRM1 07:30 - 09:00. 1.50 DRILL OTHR INTRM1 09:00 - 10:00 1.00 DRILL OTHR INTRM1 10:00 - 12:00 2.00 DRILL DEQT INTRM1 12:00 - 13:30 1.50 DRILL OTHR INTRM1 13:30 - 16:30 3.00 DRILL OTHR INTRMI 16:30 - 17:00 0.50 DRILL OTHR INTRM1 17:00 - 18:00 1.00 RIGMNT RSRV INTRM1 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description'of Operations after function 1450, 200 psi increase 38 seconds, Final pressure build 3 minutes 45 seconds. Nitrogen bottles average press, 2450 psi. Rig down Test Equipment & set wear ring. OD = 13-7/16", ID = 9", Length = 3.18' RIH w/ 50 Stds f/ Derrick. Cut & Slip Drilling Line 106' Bring Lo-Tads to floor. Bring Lo-Tads to floor. Caliper, strap & record serial numbers. POOH install Lo-Tads on stands. SLM stds in derrick. Service Top Drive. Shim Top Drive rails for motor alignment Continue to Shim Top Drive rails. P/U Geo-Pilot and MWD tools. Make up BHA Upload LWD tools, Shallow test Tools - - Load NuculearSources in MWD Picking up BHA, Breaking in new heavy Wt. Drill Pipe. Picking up new 5" Drill Pipe Make and Brake.. Trip in Hole (out of Derrick). Tag CMT @ 10,306' PJSM; All Personal Involved in change out well to Oil Base Mud Displace well to 9ppg Oil Base Mud. Start Pumping @ 2 bpm, Rotate @ 5 rpm. Staging Up SPM + RPM to 70spm, 120 rpm's. Pumped; 50bbls Mineral oil,65bbls High Vis Spacer, Oil Base Mud 9ppg. Test 9 5/8" 40ppf Csg. Bit Depth 10,249' Pressure up to 3,000psi. Bleed off. Check Surface Equipment and pressure test surface equipment T/3,000psi.O.K. Pressure. up Csg, To 500psi. Watching press on 13 3!8 x 9 5/8 annulas, 240psi. 9 5/8 csg bled down To 110psi.13 3/8 x 9 5/8 Annulas press to 260psi. Monitior Well, Build and pump Dry Job 2ppg over, Trip Out the hole for RTTS. Trip Out Hole T/ Bha, Calculated Fill 75bbls-Actual Fill 117bb1s. Working BHA Calc fill 7.7bbls -Actual 8.2bbls. PJSM; Remove Nukes, De-energize MWD, Lay Down Pressure sub. Clean Rig Floor, Load RTTS in Pipe shed. P/U RTTS Tool, Run in Hole to 5,059' Set RTTS Set RTTS Tool pump down 9 5/8 annulas. Test Tie Back, Press up to 800psi. injecting. Shut in Press bleed down to 280psi. in 6 minutes. Test down Drill Pipe testing 5,059' to 10,306' T/ 3,000psi. held for 15 min loss 70psi. Pull up to 4,812' test annulas 3,000 psi. no loss. Move 4,869' Pump down Drill Pipe Press 3,000psi. 10min no loss. Leak Isolated @ 4,812'-4,869' R/U Test 13 3/8 x 9 5/8 annulas to 1,000psi. 10 min no Loss. Pull up RTTS to 4,812' and. perform infectivity test. @ 1 bpm =1,081 psi. 1.5 bpm 1,370psi. 2 bpm 1,730 psi. Shutin Well bled down to 510psi. Unset RTTS, Blow down test line's. Monitior well, Clean pits #5, Pill pits #1&#2. Isolate leak Set RTTS, 4,853-4,863', 4,862',4,861',4,860',Leak @ 4,858'-4,860'. Mix 65 bbls Biozan Spacer, Mix 35 bbls Mineral Oil Pill, PJSM W/ Crew and support Personal, Displace Well 35 bbls Mineral Oil Pill, 50 bbls Biozan Spacer, Water Spot 10 bbls Biozan pill @ 4,965 Service Top Drive, Grease Crown Printed: 9/30!2005 6:19:05 AM • ConocoPhillips Alaska Page 15 of 45 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 7/20/2005 18:00 - 21:00 21:00 - 21:45 1 E-170 1 E-170 ROT -DRILLING D15CM@conocophillips.com Doyon 15 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Hours ,Code Code Phase 3.00 WAITON EOIP INTRM1 0.75 CEMENI~SOEZ INTRM1 21:45 - 22:15 0.50 CEMEN SOEZ INTRM1 22:15 - 23:45 1.50 CEMEN SOEZ INTRMI 17/21/2005 100:00 - 010:105 I 10.251 DRILLN~C RC INTRM1 04:45 - 06:45 2.00 DRILL I PULD I INTRM1 06:45 - 07:15 ~ 0.501 CASE I MIT I INTRMI 07:15- 10:30 I 3.251 DRILL (TRIP IINTRM1 10:30 - 12:00 1.50 CASE CIRC INTRM1 12:00 - 14:00 2.00 CASE DEOT INTRM1 14:00 - 18:30 4.50 DRILL TRIP INTRM1 18:30 - 19:30 1.00 DRILL OTHR INTRM1 19:30 - 22:00 2.50 DRILL TRIP INTRM1 22:00 - 22:15 0.25 DRILL TRIP INTRM1 22:15 - 22:45 0.50 DRILL CIRC INTRM1 22:45 - 00:00 1.25 CASE MIT INTRM1 17/22/2005 100:00 - 01:15 I 1.251 CASE I OTHR I INTRM1 01:15 - 01:30 0.251 CASE OTHR INTRMI 01:30 - 01:45 0.25 DRILL TRIP INTRMI 01:45 - 02:15 0.50 CASE -MIT INTRM1 02:15 - 05:30 3.251 CASE MIT INTRM1 05:30 - 06:30 1.00 CASE OTHR I INTRMI Description of Operations Wait On Cementers, Rig Serv. Prepare for Cmt Job. R/U Cementers, Install TIW Head Pin space out.Set @ 4,812' RTTS @ 4,810' Pump 6 bbls water, Press Test 3,000psi.Set RTTS Perform Injection test W/ Dowe11.1BPM-500psi. 1 1/2 BPM-950psi. 2 BPM-1,100psi. Shut in 1 min press 600psi. Pumped total of 21 bbls. Bled Back total 17.3 bbls. PJSM; Pump 2 bbls water to insure RTTS unseated. Close Hydril Batch up CMT. Pump 20 bbls CMT. Hold holding 350psi. Back pressure @ 36PM. 150 psi. 55 bbls. Water @ 4BPM. 500psi. Slow to 2 bbls min. Set RTTS. Bleed press off 9 5/8x5" Annulas. Open Hydril. to insure RTTS set. 73bbls into displcement 150 psi. increase. 100 to 150psi. increase per bbl. Squeezed 18 bbls Cmt. into leak 2 bbls left in csg.13 3/8 x 9 5/8 annulas = 44bbls cap to shoe: RTTS to leak capacity 3.7 bbls. Capacity Drill pipe 86 bbls, Pump total 89 bbls water final Press 2,408psi. Hold for 5 min press no losses. Bleed back volume 5 1/2 bbls. Unseated RTTS Pull 10' Monitior no flow back. Line up To Reverse Circulate. 36 spm 360 psi. 3bbl of contamanated return's @ BTM up. Reverse Circulate. 36 spm 360 psi. 2x Btms Up. Approx. 3 bbls Contaimanated Water Back to surface. Monitior well, POOH W/ RTTS. P/U Rotary Steerable BHA, P/U Pulsar sub, Plug into Mwd tools Upload. Shollow Test tools. R/U to test casing. Press up to 300psi. Call from town shut down test. Bleed off Trip in hole Rotary steerable and W/ MWD pulse test Load sources. Trip in to 4,957' Up Wt. 120k, Dn Wt. 95k. Rt Wt. 120k. Trq 8k. 640gpm. 500 psi. Circulate 640 gpm 500 psi. Btm Up. Rig Up & Test Csg. Would not test.bled back to 300 psi Bleed off pressure 6 bbls. retuns. R/D test equipment, Monitior well. Pull out hole, PJSM remove Nukes, Download MWD, UD pulsar Sub. P/U RTTS Change out element. Trip in Hole, T/ 5,235' took weight 4,000#. Pull out hole T/ 4,960' ,Spot 12 bbls Bio-zan pill, 38spm 159gpm 130psi. Pull Out Hole T/ 4,866' Set RTTS test Failed, Move down to 4,869' set RTTS test failed. Pull 4,813' test Bacck side T/2,000psi. Test O.K. Move to 4,894' Tested O.K. Pulled up to 4,884 test failed. Pull up T/ 4,854' test annulas test O.K. Good Test, From 4,854' to Surface all tested Good. From 4,894' to 10,306' tested good. Pull up Hole T/ 4,780' R/U for squeeze talk to Engineer trouble shoot leak. R/D Cmt equipment Trip in Hole. T/ 4,970' R/U to Test 13 3/8x9 5/8 500 psi. Held F/ 10 min. no loss, Pull up to Re-Test and isolate leak. Pull up to 4,895 Re-Test and isolate leak. No test trouble setting RTTS. Move down to 4,957' Test down Drill pipe. Tested T/ 1,500psi. @ 5'-10' Increaments T/ 4,862' all good test. 4,857' Did not test. Tested down 9 5/8"x5" Ann. Tested T/ 1,800psi. Tested Good. Isolating Leak @ 4,857'-4,862'. Monitior well R/D Testing Equipment. Blow down lines. Printed: 9!30/2005 6:19:05 AM r1 U u ConocoPhillips Alaska Operation's Su'mmary'Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date 'From - To 7/22/2005 06:30 - 08:00 08:00 - 11:45 1 E-170 1 E-170 ROT -DRILLING D15CM@conocophillips.com Doyon 15 , Hours Code Code Phase. 1.50 CASE PTCH INTRM1 3.75 CEMEN SQEZ INTRM1 11:45 - 13:30 1.75 CEMEN CIRC INTRM1 13:30 - 17:30 4.00 CEMEN CIRC INTRM1 17:30 - 18:00 0.50 CEMEN RURD INTRM1 18:00 - 19:00 1.00 WAITON CMT INTRM1 19:00 - 22:00 3.00 CEMEN TRIP INTRM1 22:00 - 23:00 1.00 CEMEN TRIP INTRM1 23:00 - 00:00 1.00 CEMEN TRIP INTRM1 17/23/2005 100:00 - 01:15 01:15 - 03:00 1.25 DRILL (TRIP IINTRM1 1.751 DRILL I CIRC I INTRM1 03:00 - 05:15 2.25 DRILL REAM INTRM1 05:15 - 06:00 0.75 DRILL CIRC INTRM1 06:00 - 07:00 1.00 CASE OTHR INTRM1 07:00 - 09:00 2.00 CASE MIT INTRM1 09:00 - 10:30 1.50 CASE PTCH INTRM1 10:30 - 12:00 1.50 CASE .PTCH 1NTRM1 12:00 - 14:00 2.00 CASE PTCH INTRM1 14:00 - 15:30 1.50 CASE CIRC INTRM1 15:30 - 18:00 2.50 DRILL TRIP INTRM1 18:00 - 20:00 2.00 DRILL TRIP INTRM1 20:00 - 21:00 1.00 DRILL TRIP INTRM1 21:00 - 22:15 1.25 DRILL . TRIP INTRM1 22:15 - 23:00 I 0.751 DRILL I TRIP I INTRM1 23:00 - 00:00 I 1.001 DRILL I TRIP I INTRMI Start: 6/22/2005 Rig Release: 9/10/2005 Rig Number: 15 Page 1 G of ~5 Spud Date: 6/26/2005 End:. 9/10/2005 Group: Description of Operations P.O.O.H; Position RTTS Packer @ 4,589' R/U To Squeeze CMT. PJSM: Unseat packer Circulate 5 bbls water, Test lines T/ 3,000psi. Seat RTTS. Establish Injection rate 2 bpm @ 950 psi. after shut down for 1min 550 psi 2min 490 psi.Bled back 6 1/2 bbls Total pumped 14bbls, Release packer pump 2 bpm verify circulation, Close Hydril Circulate through Choke, Batch up CMT @ 09:30. Pump 20 bbls 15.81b per gal.yield 1.17 mix fluid 5.207per/sx Porisity 59.4% solid frac. 40.6%. CMT. 3 bbls per min. 150 psi. 400psi. back press. Displace W/ Water 56 bbls water displaced Slow T/ 1 BPM seat RTTS bleed off annulas Open Hydril to verify no communacation past RTTS. Pump 82 bbls CMT T/ Leak @ 4,862' Press 1,111 psi. @ 1 BPM. Squeeze 10 bbls stop press. 1,240psi. Press drop 1,029' after 5 min. Start pumping 1 BPM squeeze 5 bbls Press 1,794psi. Stop hold 15 min. press drop T/ 1,258psi. Pump @ 1/2 BPM: Squeeze 1 bbl stop press. 1,551 psi. CIP- @ 11:05. Hold F/ 30 min. press drop 905 psi. Bleed back volume 4 3/4 bbls. Unseat RTTS Reverse Circulate 4 bpm 530 psi. No Cmt returns no losses or gains. High PH in returns. Circulate 3 Drill pipe Volume's Ph dropped. Circulate down Drill pipe @ 3 BPM 60 psi. R/D CMT Equipment Blow Down. Monitior Well, W.O.C. P.O.O.H. Lay down RTTS small piece of rubber stuck above element. Not Part of element. P/U Clean out BHA. Trip in hole with BHA # 7. Drill pipe has cement remnants rattle pipe going in hole.4,576'. Trip in hole with BHA # 7. Slow Looking for Cmt Stringers T/ 5,046' No Cement. PJSM; Displace Top of Hole back to Oil Base Mud, Pump 40 bbl high vis Spacer, 70 bbl Base Oil Pill, Chase With OBM. Rotate and Reciprocate pipe. TIH took weight @ 5,054', Wash and Ream CMT stringers F/ 5,054 - 5,718' Started to clean up @ 5,430' - 5,718' Circulate and .clean hole for Casing Test. R/U Test Equipment, Test 9 5/8" CSG, Pressure up T/ 500psi. Bleed off pressure test surface lines T/ 2,000psi., Pressure CSG. T! 1,000psi. Shut in F/ 30 min 695psi. Final Pressure, Bleed Back 6.8 bbls. Pulf out of hole. T/ 4,850' Mix 67 bbl Calcium pill, 10 ppg, 280 Viscosity Pump 50 bbls of Pill, Close Hydril ,Squeeze @ 1/2 - 1 bbls per min., Final pump press. 1100-850psi. Bleed off pressure, Check Flow, Open Hydril Circulate B/U, Monitor well, Pump dry job, Blow down Top Drive. Pull out of hole for BHA # 8 Pick Up BHA # 8 load MWD tools and PJSM on Nukes. Load Nukes. Trip in Hole, Rattle Drill Pipe while tripping in hole, cement in pipe. Pull out Hole, To pulsar check for Cmt, Pieces. Clean Out Cement From Float Sub and Pulsar. Trip in Hole 20 stands inspect Drill Pipe see no More Cmt in Pipe. @ 2099' Pull Out Hole Laying Down pipe with Cement Stringers in pipe. Wet Printed: 9/30/2005 6:'19:05 AM • ConocoPhillips Alaska' Page' ~ 7 of ~5' Operations Summary Report Legal Well Name: 1 E-170 Common- Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: ROT -.DRILLING Start: 6/22/2005 End: 9/10/2005 Contractor Name: D15CM@conocophillips.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 15 Rig Number: 15 Date ~ Fj rom - To Hours f .Code I Code Phase Description of Operations ~__ 7/23/2005 23:00 - 00:00 1.00 DRILL TRIP INTRM1 7/24/2005 100:00 - 03:45 _ 3.75 DRILL PULD INTRM1 03:45 - 04:30 0.75 DRILL OTHR INTRM1 04:30 - 12:00 7.50 DRILL TRIP INTRM1 12:00 - 12:45 I 0.75{ DRILL {CIRC I INTRM1 12:45 - 14:00 1.25 DRILL TRIP INTRM1 14:00 - 17:30 3.50 CEMEN DSHO INTRM1 17:30 - 18:00 0.50 CASE MIT INTRM1 18:00 - 19:00 1.00 CEMEN DSHO INTRM1 19:00 - 21:00 2.00 DRILL CIRC INTRM1 21:00 - 22:30 I 1.501 DRILL I LOT I INTRM1 22:30 - 00:00 I 1.501 DRILL I DRLH I PROD 17/25/2005 100:00 - 01:15 I 1.251 DRILL I DRLH I PROD 01:15 - 02:15 I 1.001 DRILL I TRIP I PROD 02:15 - 03:45 1.50 DRILL OTHR PROD 03:45 - 05:00 1.25 DRILL CIRC PROD 05:00 - 05:30. 0.50 DRILL TRIP PROD 05:30 - 10:30 5.00 DRILL DRLH PROD 10:30 - 13:00 I 2.501 DRILL (CIRC I PROD 13:00.- 13:45 0.75 DRILL TRIP PROD 13:45 -14:15 0.50 DRILL OTHR PROD 14:15 - 18:00 3.75 DRILL TRIP PROD 18:00 - 22:00 4.00 DRILL TRIP PROD 22:00 - 22:30 0.50 DRILL PULD PROD 22:30 - 00:00 1.50 DRILL TRIP PROD 7/26/2005 00:00 - 00:30 0.50 CEMEN OTHR PROD 00:30 - 05:00 4.50 CEMEN TRIP PROD 05:00 - 05:30 0.50 CEMEN CIRC PROD 05:30 - 05:45 0.25 CEMEN PLUG PROD 05:45 - 06:45 1.00 CEMEN TRIP PROD 06:45 - 07:15 0.50 CEMEN CIRC PROD 07:15 - 07:30 0.25 CEMEN SFTY PROD 07:30 - 09:15 1.75 CEMEN PLUG PROD 09:15 - 10:30 I 1.251 CEMENlITRIP I PROD Pipe, Suck Out with Vac. Plug W/ Absorbant. 20 Jts down. Pull. Out Hole Laying Down pipe with Cement Stringers in pipe. Wet Pipe Suck with Vac. Plug W/Absorbant. Clean Rig Floor and Derrick feg. Trip in Hole With BHA #8 Pick up New 5" Drill Pipe Make and Brake and Make all newjts. Trip in Hole T/8,168' Circulate Bottoms Up @ 8,168' 633 GPM, 3,120psi. 40 RPM 8-9k nTorq. Rt Wt-120k, Up Wt-165k, Dn Wt-110k Trip in Hole T/ 10,302' Drill Landing Collar @ 10,302'. Float Collar @ 10,343',.CMT T/ 10,410' Circulate and Perform Press Test T/ 525psi. Drill Out Shoe @ 10,417', Drill To 10,450' 30' New Hole. Pull Back T/ Shoe.Circulate and Condition For Leak Off Test, MWD base line test ECD. R/U Perform Leak Off Test EMW 12.1 @3,437 TVD 3437 9 ppg.10 min gels 34, Pumped 10.1 bbls, Bleed Back 9 bbls. Drilling f/ 10,450' -T/ 10,602'.TVD 3,489' 600 gpm. W/3,720 psi. 120 rpm, Torque on bttm 10-15 k ft/Ibs, off bottom 12k ft/Ibs, Up wt 200k, Dn wt 95k, Rot wt 134k. ADT .55 hrs. Drilling f/ 10,602' -T/ 10,757'.TVD 3,518' 500 gpm. W/2200 psi. 100 rpm, Torque on bttm 10-20 k ft/Ibs, off bottom 12k ft/Ibs, Up wt 200k, Dn wt 95k, Rot wt 134k. ADT .89 hrs. Pump Out Hole T/ 10,329' Circulate Bottoms Up. Directional difficutly's not able to build. dropped out of A sands. Monitior Well, Clean Rig. Call 1E-170 engineer. Circulate and Condition Waite On Decision From Town Trip In Hole T/ 10,757' Drilling f/ 10,757' -T/ 11,230'.TVD 3,550' 420 gpm. W/2,270 psi. 60-70 rpm, Torque on bttm 10-15 k ft/Ibs, off bottom 12k ft/Ibs, Up wt 230k, Dn wt 95k, Rot wt 140k. ADT 3.29 hrs. Circulate and Condition, 600 GPM 3,660psi. Was Building incl, 3.5 to 4 last 100' lost ability to build. Monitior Well: Pull Out Of Hole above Shoe @ 10,371' Monitior Well; Pump Dry Job. Trip Out Hole; To 5" Hwt DP monitior well. Stand Back HWT Drill Pipe/Jars, PJSM On handling Sources, Clear Floor, Remove Source. Down Load MWD L/D BHA. Change Out Elevators and R/U Tbg. Tongs to Run 2 7/8 tbg, stinger. Trip in Hole P/U 2 7/8" Rabbit 1-Mule Shoe jt. and 31Jts. Move Flex Collars and 5" HWT DP. to drillers side to run 5" Drill Pipe. M/U XO and Trip in Hole W/5" Drill Pipe, From derrick to 10,385' Break circulation @ 10,385' 3pm 480 psi. Trip in Hole; T/ 11,206' Break circulation @ 10,385' 6pm 980 psi. Up Wt - 195k, DN WT.-100k, R/U To Cement. PJSM; Pump Cement Balanced Plug. Pumped 15 bbls biozan Pill, 3 bbls water test cement lines to 3,000psi. 70 bbls 17 ppg yield 1 mix Fluid 3.867 gal/sx Cement porosity 51.5%, solid fraction 48.5% Slurry type Conventional. Hold Back press on Annulas not exceed LOT. 3 bbls water 2 bbls biozan. Displaced W/ 9 ppg. OBM. 172 bbls. L/D top Single with head pin P.O,O.H. Slowly Approximately 3 min stand, pipe 2/3 dry. T! 10,187', Printed: 9/3012005 6:19:05 AM • ConocoPhillips Alaska Page 18 of 45 Operations Summary Report Legal. Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: ROT -DRILLING Start: 6/22/2005 .End: 9/10/2005 Contractor Name: D15CM@conocophillips.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 15 Rig Number: 15 Date j From-- To Hours ~ Code Code~ase 7/26/2005 110:30 - 12:45 I 2.251 CEMEN1iCIRC I PROD 12:45 - 14:30 I 1.751 CEMENl(CIRC I PROD 14:30 - 14:45 0.25 CEMEN OTHR PROD 14:45 - 18:00 3.25 CEMEN TRIP PROD 18:00 - 19:00 1.00 CEMEN RURD PROD 19:00 - 21:15 2.25 CEMEN PULD PROD 21:15 - 22:15 1.00 CEMEN RURD PROD 22:15 - 23:30 1.25 WELCT BOPE PROD 23:30 - 00:00- .0.50 WELCT BOPE PROD 7/27/2005 00:00 - 03:45 3.75 WELCT BOPS PROD 03:45 - 04:45 1.00 WELCT NUND PROD 04:45 - 08:30 3.75 DRILL PULD PROD 08:30 - 13:30 5.00 DRILL TRIP PROD 13:30 - 14:45 1.25 RIGMNT RSRV PROD 14:45 - 15:45 1.00 RIGMNT RSRV PROD 15:45 - 16:15 0.50 DRILL TRIP PROD 16:15 - 18:00 1.75 DRILL OTHR PROD 18:00 - 00:00 6.00 DRILL DRLH PROD ~ 7/28/2005 ~ 00:00 - 06:00 06:00 - 12:00 12:00 - 16:00 6.001 DRILL I DRLH I PROD 6.001 DRILL I DRLH I PROD 6.001 DRILL I DRLH I PROD Description of Operations M/U Top Drive 10,187' pumped 5bbls to clear pipe, P/U joint W/ Head Pin run in T/ 10,215 R/U cement Hose to Reverse Circulate Btms up. Taking returns to one tank monitor losses, No Losses @ 3BPM-630 psi. Dump 20 bbls Spacer pill Contaminated OBM. Approximant Cement Top @ 10,245'. Circulated Total 238bb1s. Rig Down Cement Hose and Head pin, Make Up Top Drive Circulate Down drill Pipe 7 BPM - 1,030psi. 10 RPM Pumped BTMS UP @ 545 bbls. Monitor well pump slug. Trip out hole T/ 1,013' 2 7/8 tbg. R/U Csg. Tongs, To lay Down 2 7/8 tbg.(Crew Change) Lay Down 2 7/8 Tbg. Stinger. R/D Tbg. Equipment and Clean Rig Floor. Rig Up Test Equipment To test BOPE, Test BOPE 250 low; 3,DOOHigh. Test BOP's 250/ Low 5 min, 3000/ high 5 min, Chart test. AOGCC rep. Chuck Scheve waived wittness of test. Tested Hydril, HCR's, Upper rams, Choke manifold (valves 1-18), Floor safety valve, Dart valve, Manual choke & Kill line valves, Lower pipe rams, Blind rams, Upper IBOP, Lower IBOP. Perform Accumulator test, Starting pressure 3000, PSI after function 1700, 200 psi increase 39 seconds, Final pressure build 2 minutes 58 seconds. Nitrogen bottles average press, 2450 psi. Pull Test Plug, Set Wear ring. P/U BHA; Motor W/1.5 deg bend, MWD, Up load Tools, PJSM handle Source, Shallow Test MWD tools Rate 445 gpm-800psi. Load Source. TIH W/ BHA. i Trip in hole: Filling Pipe every 25 stands, SLM in Hole. Strap difemce 2'. Cut Drill Line, 154', Inspect Brake linkage and re-seal chain cover Rig Service Trip in hole: Tag Cement @ 10,216' Drill Cement; From 10,216' - 10,420` Rot Wt 130k Dill Ahead: Side Track From 10,420' to 10,544' Tie in Survey's @ 10,463' 78.24 incl. 180.75 Azm. @ 10,512' 78.64 incl. 181.27 Azm. New Survey @ 10,481' 82.06 incl 179.12 Azm. ** Up Wt. 210,Dn Wt. 85, Rot Wt. 135, Tq on Btm 18-20, Tq Off Btm 15, W.O.B. 10-20. Art-.41hrs, Ast-3.41 hrs.Jar Hrs- 9.85. Bit Hrs-4.52. Drill Ahead: From 10,544' to 10,917' M.D. 3,498' TVD. Up Wt. 225,Dn Wt. 90, Rot Wt. 140,RPM 80, GPM 590, Press On BTM 3,200, Off BTM 3,100psi. Tq on Btm 18-20, Tq Off Btm 15, W.O.B. 10-20.Arf-.68hrs, Ast-2.47hrs.Jar Hrs- 12.95. Bit Hrs-7.62. APIG=41.41, Total ft Drilled 497', Average ROP 65' per hr. Drill Ahead: From 10,917' to 11,282' M.D. 3,469' TVD. Up Wt. 230,Dn Wt. 85, Rot Wt. 140,RPM 90, GPM 600, Press On BTM 3,540, Off BTM 3,450psi. Tq on Btm 18-22, Tq Off Btm 17, W.O.B. 5-15. Art-.2.88hrs, Ast-1.49hrs.Jar Hrs- 15.58. Bit Hrs-10.25. APIG=47' per hr. Total ft drilled 862' Average ROP 84 ft per hr., Began Running 5" Hwt Drill Pipe @ 10,943' for push pipe. Pumped Weighted Sweep @ 11,173' 11 ppg. 117vis. Approximately 20% increase in cutting sweep to surface. Drill Ahead: From 11,282' to 11,700' M.D. 3,469' TVD. Up Wt. 245,Dn Wt. 85, Rot Wt. 150, RPM 90, GPM 600, Press On BTM 3,580, Off BTM 3,430 psi. Tq on Btm 18-22, Tq Off Btm 18, W.O.B. 5-15. Art- 1.36hrs, Ast-1.35hrs. Jar Hrs- 18.29. Bit Hrs-12.96. APIG=53' per hr. Total ft drilled 1280' Average ROP 98.7 ft per hr., Continue Running 5" Printed: 9!30/2005 6:19:05 AM • • ConocoPhillips Alaska Page>~19 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: ROT -DRILLING Start: 6/22/2005 End: 9/10/2005 Contractor Name: D15CM@conocophillips.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To Hours- Code Code ~ Phase 7/28/2005 12:00 - 18:00 6.00 DRILL DRLH PROD 18:00 - 21:00 3.00 DRILL DRLH PROD 21:00 - 00:00 3.00 I RIGMNTI RGRP I PROD 7/29/2005 00:00 - 02:45 02:45 - 03:15 03:15 - 08:00 08:00 - 12:00 2.751 DRILL I TRIP I PROD ..0.50 DRILL OTHR PROD 4.75 DRILL TRIP PROD 4.00 DRILL PULD PROD 12:00 - 13:30 13:30 - 15:30 1.50 RIGMNT RSRV PROD 2.00 LOG TRIP PROD 15:30 - 17:45 2.25 LOG TRIP PROD 17:45 - 18:00 0.25 LOG TRIP PROD 18:00 - 19:00 1.00 LOG TRIP PROD 19:00 - 19:15 0.25 LOG TRIP PROD 19:15 - 20:00 0.75 LOG TRIP PROD 20:00 - 21:15 1.25 LOG CIRC PROD 21:15 - 00:00 2.75 RIGMNT RSRV PROD 7!30/2005 00:00 - 00:30 0.50 RIGMNT RSRV PROD 00:30 - 03:45 3.25 DRILL TRIP PROD 03:45 - 04:15 0.50 DRILL OTHR PROD 04:15 - 05:30 1.25 DRILL OTHR PROD 06:00 - 07:105 10.251 OG L I RURD ~ PROD 07:15 - 07:30 0.25 LOG SFTY PROD 07:30 - 08:45 1.25 LOG RURD PROD 08:45 - 09:15 0.50 LOG PULD PROD 09:15 - 09:45 0.50 LOG ELOG PROD 09:45 - 13:00. 3.25 LOG ELOG PROD 13:00 - 13:15 0.25 LOG ELOG PROD 13:15 - 14:30 1.25 LOG ELOG PROD 14:30 - 16:15 I 1.751 LOG I ELOG I PROD 16:15 - 17:00 I 0.751 LOG I ELOG I PROD 17:00 - 19:00 I 2.00 I LOG I ELOG I PROD Description of Operations Hwt Drill Pipe for push pipe. Changed Over to rig power @ 13:15hrs. Drill Ahead: From 11,700' to 11,887' M.D. 3,481' TVD. Up Wt. 255,Dn Wt.100, Rot Wt. 160, RPM 90, GPM 600, Press On BTM 3,610, Off BTM 3,450 psi. Tq on Btm 18-20, Tq Off Btm 18, W.O.B. 5-15. Art- .63hrs, Ast-.90hrs. Jar Hrs- 19.82. Bit Hrs-14.49. APIG=54' per hr. Total ft drilled 1467' Average ROP 101ft per hr, Continue Running 5" Hwt Drill Pipe for push pipe. Top Drive Down: Can Pump and Break and Make Up Drill Pipe, Cannot Rotate in Drilling Mode. Pump and Work pipe out of hole slowly T /11,589' while Trouble shooting Top Drive, GPM 425, 2,000psi. Talk with Geologist, Strata Steer, Directional Driller, Project Engineer and Project Geologist on Directional Plan Pump Out Hole From 11,589' - 10,351'. @ 400 gpm, 2000psi. Up Wt. 240k, Dn Wt 100k, - MonitiorWell, 15min. Pump Dry Job. Trip Out Hole. 10,351' to 287'. Top Drive Still Down Waiting on Part. Work BHA: PJSM on pulling Sources, Remove and Store I Density(gamma) and Neutron Sources. Plug in and Down Load LWD Tools. Lay Down BHA. Rig Service Pick Up, BHA #10 - 8 1/2 Bit / 9 5/8 Scrapper /Junk Basket, Run Collars and all Hwt Drill Pipe. Trip in Hole to 5,877' Up Wt. 150k, Dn Wt. 85k. Monitior Well Trip Out Hole From 5,877 to 4,737' Monitior Well, Clean Floor Trip in Hole; To 5,837' W/ Scrapper Circulate 2x Btms Up @ 650 GPM, 2,000 psi. PJSM: Change Out Drill Line, Change Out To new drill Line Spool. Finish Changing Out Drill Line New Spool, Trip Out Hole: With 9 5/8" Scrapper, Lay Down Bit and Scrapper Retrieved pieces of Alunimuim and Cmt Chunks out of Junk Baskets. Clean and Clear Rig Floor, P/U Geo Pilot and LWD Tools. hook up tool and check connections, Stand back in Derrick Hook up Geo Skid connections and safety chains While spotting Schlumberger unit and picking up tools, cont. cleaning OBM from under rotary table Held PJSM with Schlumberger, Rig crews, and Co. Rep. Rig up wire sheaves, M/U USIT, Gamma Ray and collar locator assembly M/U Tractor assembly on top, Total Length. = 64.3' RIH with wire Line, Able to free fall to 2175' with wire line Active Tractor assembly to get wire line down F/2175'- T/3,483'. Taking Wieght made 4 attemps. No Go, POOH to 2600' Attempted to Tractor back into hole, second attempt made it to 3,121' set down. Taking weight P.O.O.H L/D Tractorassembly Approx. 4 oz fine metal shavings found on collar locator. Change oil in the tractor. From 10wt. to 16 wt. P/U tractor assembly and RIH T/2400' Good 2,974' set down hard. 6 times, Able to run tractor and wire line down F/2,974 : T/3,430' (Test Top Printed: 9!30/2005 6:19:05 AM • • ConocoPhillips Alaska ...Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To Hours I Code Code Phan 7/30/2005 17:00 - 19:00 2.00 LOG ELOG PROD 19:00 - 20:00 1.00 LOG ELOG PROD 20:00 - 20:30 0.50 LOG PULD PROD 20:30 - 20:45 0.25 DRILL PULD PROD 20:45 - 23:00 2.25 DRILL PULD PROD 23:00 - 23:30 0.50 DRILL TRIP PROD 23:30 - 00:00 0.50 DRILL TRIP PROD 7/31/2005 00:00 - 00:45 0.75 DRILL TRIP PROD 00:45 - 02:00 1.25 DRILL C-RC PROD 02:00 - 04:00 2.00 DRILL TRIP PROD 04:00 - 05:00 I 1.001 DRILL I PULD I PROD 05:00 - 06:30 1.50 DRILL OTHR PROD 06:30 - 07:30 1.00 DRILL TRIP PROD 07:30 - 11:15 3.75 DRILL TRIP PROD 11:15 - 12:45 I 1.50 I DRILL I TRIP I PROD 12:45 - 14:30 1.75 DRILL OTHR PROD 14:30 - 18:00 3.50 DRILL DRLH PROD 18:00 - 22:30 4.50 DRILL DRLH PROD 22:30 - 00:00 1.501 DRILL I DRLH I PROD 18/1/2005 100:00 - 06:00 I 6.001 DRILL ~ DRLH I PROD Page 20 of 45 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 ~ Description of Operations Drive) All Working. P.O.O.H ' Break Down Tools and Rig Down Wireline. Pick Up BHA Stood Back in Derrick and M/U bit. Run in hole. P/U Load Pulsar in TM H.O.C, Make Up to BHA, Up Load LWD Tools, and Shallow Test Tools. PJSM Load Nuetron and Gamma Sources. Test Geo Surface Equipment T(3,500psi. Trip Hole Jars and 8 Jts 5"Hwt Drill Pipe, Trip in Hole; 31jts 5" Drill Pipe 8 1/2" ghost Reamer. Continue to Trip in Hole W/5" Drill Pipe Trip in Hole: To 3,055' Fill Pipe: Test Top Drive, Went to Fault, Reset Worked Good 130 RPM backed down Torq ,Until Stopped, Start Backup and function all Controls, Test MWD No Pulse, Cycle Pumps Still Failed. TripOut Hole for Directional Assembly Failure. Break Off Top of Pulsar was Clean, PJSM; Remove Nuetron and Gamma Sources, Plug into to tools to trouble shoot Tools Check Out OK, Break Top Of T.M. Collar pull Pulsar Looks Clean, Change Out Pulsar. Plug into LWD Tools and Upload Tools. Pick Up BHA. Trip in Hole, To 2,900' fill pipe, Test MWD, 417 GPM, 1,010' MD. Trip in Hole; To 10,160' fill pipe every 25 stands, Monitior well before going in open hole, Up Wt. 200k,Dn Wt. 88k. Trip in Hole; To 11,300' Establish Circulation at 450 GPM 2430 psi., Up Wt. 210k, Dn Wt. 85k, Rot Wt.130k. Record SPR. Start Troughing F/ 11,300' MD To 11,342' Up wt, 21 k, Dn Wt. 85k, Rot Wt. 130k, 450 GPM, 2,460' psi. Start side track; F/ 11,342'MD, 3,489' ND, Drill T/ 11,619' MD. 3,469' ND, ART-2.44hrs. Bit Hrs.- 2.44hrs., Jar Hrs. 22.26hrs., GPM 525 - 2,680ppsi. On Btm. - 2,660 Off Btm, 17k Torq on Btm, 15k Off Btm. 120 RPM. 10-20 WOB, 230k Up Wt., 80k Dn Wt., 130k Rot Wt.11.0 ECD. DriA Ahead; F( 11,619'MD, 3,469' ND, Drill T/ 11,88T MD. 3,464' ND, GPM 550-600 - 2970psi.-3,520psi. On Btm. - 2,800psi.-3,460psi. Off Btm, Torq. Off Btm, 17k, Torq on Btm, 20k. 120 RPM. 10-20 WOB, 230k Up Wt.,90k Dn Wt., 140k Rot Wt.11.4 ECD. Drill Ahead; F/ 11,887'MD, 3,464' ND, Drill T/ 12,036' MD. 3,464' ND, ART-4.06 Bit Hrs.- 6.5hrs., Jar Hrs. 26.3hrs., GPM 550-600 - 2970psi: 3,520psi. On Btm. - 2,800psi.-3,460psi. Off Btm, Torq. Off Btm, 17k, Torq on Btm, 20k. 120 RPM. 10-20 WOB, 230k Up Wt.,90k Dn Wt., 140k Rot Wt.11.4 ECD. Note: Drilled Out of Sands Formation ramp up or fracture, True vertical throw Estamate 17' Out at 11,915'MD. 3,465' ND, Back in Sands 12,268'MD, 3,448' ND. 353ft sands lost. Drill Ahead; F/ 12,036'MD, 3,464' ND, Drill T/ 12,487' MD. 3,440' ND, ART----- Bit Hrs.-10.77hrs., Jar Hrs.26.32hrs., GPM 550-600 - 2970psi: 3,520psi. On Btm. - 2,SOOpsi.-3,460psi. Off Btm, Torq. Off Btm, 17k, Torq on Btm, 20k. 120 RPM. 10-20 WOB, 230k Up Wt.,90k Dn Wt., 140k Rot Wt.11.4 ECD. 12,295' Pumped Sweep 11.ppg, 107 Vis. 40% increase at Shakers of Cuttings. ECD F/11.8, T/ 11.4ppg. Concreations 12,459-12461' (2'), Note: Drilled Out of Sands Formation ramp up or fracture, True Nnntea: aisui~uua e:~a:uaHiw • • ConocoPhillips Alaska Page 21 of 45 Operations Summary,Report Legal Well Name: 1 E-170 Common W ell Name: 1 E-170 Spud Date: 6/26/2005 Event Nam e: ROT -D RILLIN G Start: 6/22/2005 End: 9/1.0/2005 Contractor Name: D15CM @conoc ophillip s.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 1 5 Rig Number: 15 Date From - To Hours ~ Code % d ~ Phase ~ Description of Operations Co e 8/1/2005 00:00 - 06:00 6.00 DRILL DRLH PROD vertical throw Estamate 17' Out at 11,915'MD. 3,465' TVD, Back in Sands 12,268'MD, 3,448' TVD. 353ft sands lost. 06:00 - 12:00 6.00 DRILL DRLH PROD Drill Ahead; F/ 12,487'MD. 3,440'TVD. T/ 12,713'MD. 3,436'TVD. ART-5.07hrs. Bit Hrs-15.84hrs. GPM-600, W/ 3,420psi. On Btm.-3,400.Off BTM. 120RPM.-18-23 Tq.On Btm.-17-20. Up Wt.-240k,Dn Wt.-70,Rot Wt.-135k. ECD 11.3 ppg. Concreations 12,543'-12,552'(9'), 12,568'-12,580'(12'), 12,624'-12,630'(6'), 12,646'-12,650'(4'), 12:00 - 18:00 6.00 DRILL DRLH PROD Drill Ahead; F/ 12,713'MD. 3,436'TVD. T/ 12,847'MD. 3,433'TVD. ART-4.96hrs. Bit Hrs-20.80hrs. GPM-600, W/ 3,420psi. On Btm.-3,400.Off BTM. 120RPM.-18-23 Tq.On Btm.-17-20. Up Wt.-240k,Dn Wt.-70,Rot Wt.-135k. ECD 11.4 ppg. Concreations 12,670'-12,680'(10'), 12,700'-12,708'(8'), 12,712'-12,718'(6'),. 12,743'-12,752'(9'),12,775'-12,800'(25'), 12,836-12,844'(8'), 18:00 - 00:00 -6.00 DRILL DRLH PROD Drill Ahead; F/ 12,84TMD. 3,433'TVD. T( 13,284'MD. 3,429'TVD. ART-4.15hrs. Bit Hrs-24.95hrs. GPM-600, W/ 3,500psi. On Btm.-3,480.Off BTM. 120RPM.-19 Tq.On Btm: 20. Up Wt: 240k,Dn Wt.(less then block Wt of 70k),Rot Wt.-130k. ECD 11.6 ppg. APIG- 58ft per hr. 33.5hrs, Footage Drilled 1,942' Average ROP 77' per Hr. Concreations 12,954'-12,985'(9'). 8/2/2005 00:00 - 07:00 7.00 DRILL DRLH PROD Drill Ahead; F! 13,284'MD. 3,429'TVD. T! 13,879'MD. 3,408'TVD. ART-4.20hrs. Bit Hrs-28.75hrs. GPM-600, W/ 3,760psi. On Btm: 3,670.Off BTM. 120RPM: 19 Tq.On Btm: 20. Up Wt-255k,Dn Wt.(less then block Wt of 70k),Rot Wt.-132k. ECD 12.2 ppg. APIG- 62.64ft per hr, 40.5hrs, Footage Drilled 2,537' Average ROP 88' per Hr. 07:00 - 11:30 4.50 DRILL REAM PROD Back Ream Out Of Hole: From 13,879' To 12,150', 20-25ft per min. 120RPM, 575GPM, 3,320psi. 18-20TQ, 11:30 - 13:00 1.50 DRILL REAM PROD Back Ream Out Of Hole: From 12,150' To 11,727',Slow Pull Rates To 10-15ft per min. 120RPM, 575GPM, 3,200psi. 18TQ, The last 300' Pumped 1200 bbls 2x BTM Up, 13:00 - 14:00 1.00 DRILL TRIP PROD Trip Out Of Hole: Attempt to Pull pipe with out back reaming, 11,727'-11,536' Hole not taking correct fill Up Wt 220-235, Pumped out To 11,156'. 500GPM. 2,250 psi. 200k Up Wt. Ghost Reamer 9,690'. 14:00 - 14:45 0.75 DRILL TRIP PROD Trip in Hole: From 11,156' - 11>628' Up Wt,220, Dn Wt. 85k. Lost Dn Wt. 11,628' 14:45 - 00:00 9.25 DRILL TRIP PROD Trip in Hole; Pump and Rotate because of loss of down Wieght From 11,628' - 13,879', 11,727' Attempt to run in hole with out Rotating No Down Wt. Check-Shot survey to Confirm in Side Track, at 11,622', 11,722', 90RPM 600GPM 3,450 psi.110Rot Dn Wt. Started install of LoTads on Stand # 126 at (12,624'Depth of Lodtad), To Stand # 139 (13,897' Depth of LodTad) Total LodTads Picked Up 14. Total in Hole 69 LodTads. ECD 12 8/3/2005 00:00 - 00:15 0.25 DRILL TRIP PROD Trip in Hole; Pump and Rotate because of loss of down Wieght From i 13,866' - 13,879',.600GPM 3,800 psi120Rot Dn Wt. Started install of LoTads on Stand # 126 at (12,624'Depth of Lodtad), To Stand # 139 (13,897' Depth of LodTad) Total LodTads Picked Up 14. Total in Hole 69 LodTads. ECD 12 Pumped 11ppg. 120vis sweep. No Increase in returns. 00:15 - 05:30 5.25 DRILL DRLH PROD Drill Ahead; F/ 13,879'MD. 3,408'TVD. T/ 14,196'MD.3,380'TVD. ART 3.30hrs. Bit Hrs 32.48hrs. GPM-600, W/ 3,884psi. On Btm.-3,840.Off BTM. 140RPM.-18 Tq.On Btm.-18. Up Wt.-225k>Dn Wt.(less then block Wt of 70k),Rot Wt.-138k. ECD 12.2 ppg. 2,854'. Started with 5" HWDP Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska Page 22 of 45 Operations Summary'Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From -To I Hours Code C'Stab ~ phase -- 8/3/2005 00:15 - 05:30 ( 5.25 DRILL DRLH PROD 05:30 - 06:30 1.00 DRILL DEOT PROD 06:30 - 09:15 2.75 DRILL .DRLH PROD 09:15 - 09:45 0.501 DRILL I CIRC I PROD 09:45 - 11:30 1.75 DRILL REAM PROD 11:30 - 12:00 :0.50 RIGMNT RGRP PROD 12:00 - 17:00 5.00 DRILL DRLG PROD 17:00 - 22:15 5.25 DRILL DRLG PROD 22:15 - 00:00 1.751 DRILL DRLG PROD 18/4/2005 100:00 - 01:30 I 1.50 DRILL I DRLG I PROD 01:30 - 03:30 2.00 I DRILL DRLG PROD 03:30 - 13:00 9.50 DRILL REAM PROD 13:00 - 13:30 0.50 DRILL OBSV PROD 13:30 - 14:30 1.00 DRILL CIRC PROD 14:30 - 18:45 4.25 DRILL TRIP PROD 18:45 - 20:30 1.75 DRILL PULD PROD 20:30 - 20:45 0.25 DRILL CIRC PROD 20:45 - 22:30 1.75 DRILL TRIP PROD 22:30 - 22:45 0.25 DRILL TRIP PROD 22:45 - 00:00 1.25 DRILL PULD PROD 8/5/2005 00:00 - 02:00 2.00 DRILL TRIP PROD 02:00 - 03:00 .1.00 DRILL PULD PROD 03:00 - 04:45 I 1.751 DRILL I PULD I PROD Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations Stand # 140, 13,965'. Slow R.O.P T/50ft per Hr. From 14,020'-14055' 100-120ft per Hr 14,055' - 14,196' Per Directional Driller. MWD Pulsar and detection problems, Problems down linking to Geo-Pilot. Drill Ahead; F/ 14,196'MD. 3,380'ND, T! 14,397'MD.3,364'TVD. ~ ART2.03hrs. Bit Hrs 34.51 hrs. GPM-610, W/ 4,010psi. On Btm.-3,990.Off BTM. 120RPM.-19 Tq.On Btm.-19. Up Wt.-240k,Dn Wt.(less then block Wt of 70k),Rot Wt.-140k. ECD 12.3 ppg. Footage Drilled 3,055' Average ROP 88' per Hr. Motors overheat Pick up off Btm. Slow Pumps and Rotary let motors cool Down. Back Ream Out Hole:From 14,397'MD 3,364'ND To 13,768'MD 33,412' 600GPM, 3,900psi. 120RPM, Up Wt. 230k Rot WT. 125k, Mode switched LWD tools, Change Liner Out in #2 Pump. Work Pipe - Low side, From 13,758'-13,768' Open Hole Side Track: From 13,768'MD 3,412'ND, @ 13,864' Geo inclination confirmed sidetrack, Drill Ahead From 13,864'MD 3,412ND To 14,330'MD 3,405' ND, ART 4.44hrs. Including side track, Bit Hrs.38.95. 614 GPM, 3,780psi. on BTM, 3,750psi. off Btm. 235 Up Wt. W/O pumps, 130k Rot W/O pumps. neg Dn WT. ECD 11.9. Drill Ahead; F/ 14,330'MD. 3,405'ND. T/ 14,388'MD.3,402'ND. Total Drilled 58', @ 14,371'MD .Bad Detection on LWD tools, Work with Sperry sun on parameters, Mode Change, Check and clean pump suction screens, Screens O.K. Continue trouble shoot pull 1 stand back, Survey @ Drill Ahead; F/ 14,388'MD. 3,405'ND. T/ 14,397'MD.3,405'ND. Total Drilled 10", Bad Detection on LWD tools, Work with Sperry sun on parameters, Change modes, Stand Back 1 stand HWDP, Pump 450 GPM and Press Up Pulsation dampeners, to 1,000psi. From #1- SOOpsi, #2 -750psi. Good Detection on LW D tools both modes. Drill Ahead; F/ 14,397'MD. 3,405'ND. T/ 14,435'MD.3,397'ND. Total Drilled 38', tools, Work with Sperry Sun on Down link and Geo-Pilot problem. Last Survey @ 14,393 94.49 incl. 180.53 Azm. Back Ream Out Hole: 25-35ft per min. Re -Check, Geo -Tool at 13,658' and at 12,297 - 12,200, Monitor Well, @ 10,367'. Clean Rig Floor. Circulate Btms Up at 10,367', 600 GPM 3,100psi. Press, Worked on Pipe Handler. Trip Out Hole: Pump Dry Job, Pull Out Hole. Pick Up 30 jts. 5" HWT Drill Pipe, T/ 2,632' Circulate 70 Bbls through 5" HWT DP, Pump Dry Job. Trip Out Hole: 10 stands 5" HWT DP,13 Stands 5" DP, UD Ghost Reamer 1/8" under gauge, 3 stands 5" HWT DP and Jars, 1 stand Flex Drill Collars, PJSM; Removing and storing Neutron and gamma Sources, Remove and Store Sources. Down Load LWD Tools. Down Load LWD Tools. Pull Pulsar, P/U 15' Pup to stand Back in Derrick, P/U Break Out Bit, UD Geo Pilot, could not rotate housing, Housing locked up. P/U new Geo pilot (housing turned), Make up Bit, MWD,Install Pulsater in H.O.C. collar Printed: 9/30/2005 6:19:05 AM • • ConocoPhillips Alaska Page 23 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common W ell Name: 1 E-170 Spud Date: 6/26/2005 Event Nam e: ROT -D RILLING Start: 6/22/2005 End: 9/10/2005 Contractor Name: D15CM @conoc ophillip s.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 1 5 Rig Number: 15 Date 'From - To Hours Code Phase ` ~ Description of Operations ,Code . 8/5/2005 04:45 - 05:45 1.00 DRILL DEQT PROD Up Load and test & Test MWD. 05:45 - 06:30 0.75 RIGMNT RGRP PROD Trouble Shoot Top Drive fault. 06:30 - 08:00 1.50 DRILL DEQT PROD Shallow test MWD Tools, PJSM on Install of Nuetron and gamma sources, Install sources, Pick up BHA. 08:00 - 12:00 4.00 DRILL TRIP PROD Trip in Hole: Fill pipe every 25 stands to 10,370' MD, 175k Up Wt. 95' Dn Wt. 12:00 - 13:15 1.25 RIGMNT RSRV PROD Cut and slip Drill line 104', Inspect Brakes 13:15 - 14:15 1.00 RIGMNT RSRV PROD Service Rig, Adjust Compensator. 14:15 - 15:15 1.00 DRILL TRIP PROD Trip in Hole: From 10,370'to 11,612'MD Up Wt 190k, Dn Wt. 90k. 15:15 - 16:15 1.00 DRILL REAM PROD Make Up Top Drive, Wash and ream From 11,612'MD, to 12,013'MD. 16:15 - 19:00 2.75 DRILL TRIP PROD Trip in Hole: Fill Pipe every 10 stands, 12,013'- 14,241' {13,180' Up Wt. 200k Dn Wt 100k, 14,148' Up Wt. 205k Dn Wt. 100k. 14,148'. Up Wt. 205k Dn Wt.100k.} Check Shot Survey new hole Confirmed. 19:00 -20:00 1.00 DRILL REAM PROD Wash and Ream: From 14,148'to 14,435'MD3,39TTVD. 230 Up Wt: 100 Dn Wt, 20:00 - 00:00 4.00 DRILL DRLH PROD Drill Ahead; F/ 14,435'MD. 3,397'TVD. T/ 14,610' MD. 3,386'TVD. ART2.46hrs. Bit Hrs2.46hrs. GPM-600, W/ 4,200psi. On Btm.-4,120.Off BTM. 120RPM.-20 Tq.On Btm.-19. Up Wt.-250k,Dn Wt.-85,Rot Wt.-155k. ECD 11.9 ppg. No Concretions, APIG,43.75 Average ROP 71' hr. 8/6/2005 00:00 - 02:45 2.75 DRILL DRLH PROD Drill Ahead; F/ 14,610'MD. 3,397'TVD. T/ 15,065' MD. 3,379'TVD. 1.76ARThrs. Bit Hrs 4.22hrs. GPM-600, W/ 4,200psi. On Btm.-4,120.Off BTM. 120RPM.-20 Tq.On Btm.-19. Up Wt. 250k,Dn Wt.-85,Rot Wt.-155k. ECD 11.9 ppg. No Concretions, APIG,43.75 Average ROP 71' hr. ChargePump Pulsater Dampners T/ 1,400psi. 02:45 - 03:45 1.00 DRILL REAM PROD Loss signal, No Pulse Back Ream Out 3 stands Hwt Drill Pipe, replace with 5" drill Pipe, Trip Drill Pipe back in hole on Elevators, Down Wt 90k, 240 Up Wt. 03:45 - 05:00 1.25 DRILL DRLH PROD Drill Ahead: F/ 15,065 MD, T/ 15,078'MD, TVD 140 Up Wt. 90 Dn Wt. 152k Rot Wt. Tried One pump @ 430 GPM 2,700psisignal but to dirty to read, Bumped Up Pulsater T/ 1,500 #2 Pump. No Change, Raised GPM T/630 4,350 psi. Pulse signal Drill Kelly down Make Connection lost signal. @ same Rate, Total hrs on bit @ 15078' = 4.69 hrs. 05:00 - 06:00 1.00 DRILL REAM PROD Back Ream Out of Hole f/ 15078' T/14610'. Will replace HWDP w/ 5" DP w/o Lo-tads. 06:00 - 08:00 2.00 DRILL REAM PROD Continue back Ream Out of Hole f/ 14610' T/13,868. All HWDP out of hole on pipe rack. 08:00 - 09:00 1.00 DRILL TRIP PROD RIH on elevators, replacing 5" HWT Drill Pipe W/ 5" Drill Pipe (no lo-tads). RIH f/ 13868' to 15014'. 09:00 - 09:30 0.50 DRILL REAM. PROD Fill pipe, test Sperry Sun MWD/LWD and Sperry Sun geopilot, OK. Take SPR's. Wash and ream f/ 15014' to 15078'. 09:30 - 12:00 2.50 DRILL DRLG PROD Directional drill 8 1/2" hole f/ 15078' to 15135' (3378.5' TVD) (57') ART 1.91 hrs w/ Sperry Sun geo pilot, 6-7k WOB, 120 rpm's, 600 gpm, 9.0-9.1 ppg mw, on bottom pressure 4010 psi, off bottom pressure 3960 psi, on bottom torque 19k ft/Ib, off bottom torque 18k ft/Ib, PU wt 240k, SO wt 75k, Rot wt 130k. Note: Poor detection, intermittent MWD/LWD data Total bit hrs 6.6 12:00 - 12:30 0.50 RIGMNT RGRP PROD Work. on #1 mud pump. Replace liner and swab. Liner gasket was leaking earlier, liner gasket was changed earlier. Back reamed +/- 30' of a stand, set stand back, backream slow w/ circ @ reduced rate w/ #2 mud pump, while working on #1 pump. Printed: 9/30/2005 6:19:05 AM • • ConocoPhillips Alaska Page 24 of 45' Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date (From - To 18/7/2005 12:30 - 14:30 1 E-170 1 E-170 ROT -DRILLING D15CM@conocophillips.com Doyon 15 Hours ~ Code Code Phase 2.00 DRILL DRLG PROD 14:30 - 18:00 I 3.501 DRILL I DRLG I PROD 18:00 - 00:00 I 6.001 DRILL I DRLG I PROD 00:00 - 02:30 I 2.501 DRILL I DRLH I PROD 02:30 - 02:45 I 0.251 DRILL I CIRC I PROD 02:45 - 06:30 3.75 DRILL REAM PROD 06:30 - 07:45 1.25 RIGMNT RGRP PROD 07:45 - 10:45 I 3.00 I DRILL I REAM PROD 10:45 - 12:45 2.00 DRILL I REAM I PROD 12:45 - 15:15 I 2.501 DRILL I REAM I PROD 15:15 - 17:00 I 1.751 DRILL I CIRC I PROD Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 J Description of Operations - Directional drill 8 1/2" hole f/ 15135' to 15202' (3378' TVD) (67') ART 1.33 hrs w/ Sperry Sun geo pilot, 25k WOB, 120 rpm's, 610 gpm, 9.0-9.1 ppg mw, on bottom pressure 4080 psi, off bottom pressure 3990 psi, on bottom torque 19k ft/Ib, off bottom torque 19.5k ft/Ib, PU wt 230k, SO wt 70k, Rot wt 130k. Note: 15202' is the last of 5" drill pipe slick drilled down. Next will be 5" HWDP. Total hours on bit 7.93 hrs Note: MWD/LWD/PWD working ok, so far. Directional drill 8 1/2" hole f/ 15202' to 15,297' (3,377' TVD) ART 2.60 hrs w/ Sperry Sun geo pilot, 20-25k WOB, 120 rpm's, 600 gpm, 9.0-9.1 ppg mw, on bottom pressure 3,940 psi, off bottom pressure 3,920 psi, on bottom torque 19k ft/Ib, off bottom torque 19k ft/Ib, PU wt 230k, Dn Wt. none ,Rot wt 138k. Note:Drilling W/ 5".HWDP. Lostdeteetion 1530 hrs @ 15261' MD/ 3370' TVD, cylcled pumps and came on. Lost Detection on and off. MAD Pass 15,297' - 15,290' lost detection. Directional drill 8 1/2" hole From 15,297' to 15,727' (3,370' TVD) ART2.13 hrs w/ Sperry Sun geo pilot, 20-25k WOB, 120 rpm's, 600 gpm, 9.0-9.1 ppg mw, on bottom pressure 3,940 psi, off bottom pressure 3,920 psi, on bottom torque 19k ft/Ib, off bottom torque 19k ft/Ib, PU wt 230k, Dn Wt. none ,Rot wt 138k. Note: #1 Pump 100strks - #2 38strks'. When detection lost send downlink to start back up, Drilling Ahead, Making mad Passes on Log area needed for Geoligist. 430' Footage Drilled, Out of A2 sands 15,440' Back in sands @ 15,730' Pumped 10.9 130 vis sweep 40 bbls @ 15,674'. seen sweep no increase of cuttings. Directional drill 8 1/2" hole From 15,727' to T.D.@15,940' (3,354' TVD). ART1.22 hrs. 14.46 Bit Hrs. w/ Sperry Sun geo pilot, 20-25k WOB, 120 rpm's, 580 gpm, 9.0-9.1 ppg mw, on bottom pressure 3,929' psi, off bottom pressure 3,910 psi, on bottom torque 19-20k ft/Ib, off bottom torque 19k ft/Ib, PU wt 240k, Dn Wt. none ,Rot wt 145k. Note: When detection lost send downlink to start back up Detection instead of restarting pump, Drilling Ahead, Making mad Passes on Log area needed for Geoligist that missed on detection. 213' Footage Drilled, Note: Drilled out of A2 sands Base 15,440'MD, 3,377'TVD, Back in sands 15,730'MD,3,370TVD. lost sands 290'. Ciculate, Survey @ T.D. 15,940'MD. 3,354' TVD. 93.64incl. 182.97AZM. Slow Pump rates. Back Ream Out Hole: F/ 15,940' T/ 13,871', 600GPM . 3,750'psi. Pull 25-30' per min. Running Speed. S pipe leaking on Top Drive, Tighten up, pressure up still leaking, R/U to circiulate,Break pipe free no Down Wieght, Circ, While Change out seal on Union, Lay Down Three jt, to keep LodTads in wind Wall area. Back Ream Out Hole: F/ 13,773' T/ 12,686', 600GPM . 3,740'psi. Pull 25-30' per min. Running Speed. Back Ream Out Hole: F/ 12,686' T/ 11,632', 447GPM . 1,830'psi. Pull 15-20' per min. Running Speed. Shut in #2 Pump, Shock Hose leaking, Continue backreaming slower rate. Back Ream Out Hole: F/ 11,632' T/ 10,167', 600GPM . 3,740'psi. Pull 25-30' per min. Running Speed. #2 Pump Back On Line Pump and pull at full rate. Pump High Wieghted,Vis Sweep - 120RPM - 600GPM - 3,151 psi. Rotate and Recipacate pipe 2 Btms Up 1211 bbs, Printed: 9/30/2005 6:19:05 AM • • ConocoPhillips Alaska Operations Summary. Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date 8/7/2005 18/8/2005 From - To Hours Code Code Phase 17:00 - 17:30 0.50 RIGMNT RSRV PROD 17:30 - 21:45 4.25 DRILL TRIP PROD 22:00 - 00:00 I 2.001 DRILL ICIRC (PROD 00:00 - 01:00 I 1.00 DRILL ICIRC PROD 01:00 - 03:00 I 2.00 DRILL ICIRC PROD 03:00 - 03:15 I 0.251 DRILL I OBSV I PROD 03:15 - 06:00 2.75 DRILL TRIP PROD 06:00 - 06:45 0.75 DRILL TRIP PROD 06:45 - 08:15 1.50 LOG DLOG PROD 08:15 - 09:00 0.75 DRILL TRIP PROD 09:00 - 11:15 2.25 LOG DLOG PROD 11:15 - 14:00 2.75 DRILL TRIP PROD 14:00 - 16:30 2.50 DRILL TRIP PROD 16:30 - 17:30 1.00 DRILL TRIP PROD 17:30 - 18:45 1.25 DRILL TRIP PROD 18:45 - 19:15 0.50 DRILL OTHR PROD 19:15.- 19:30 0.25 LOG SFTY CMPLTN 19:30 - 21:30 2.00 LOG RURD CMPLTN 21:30 - 00:00 2.50 LOG ELOG CMPLTN 18/9/2005 00:00 - 02:00 2.00 LOG ELOG CMPLTN 02:00 - 04:00 2.00 LOG ELOG CMPLTN 04:00 - 06:00 ~ 2.001 LOG ELOG CMPLTN 06:00 - 10:00 I 4.001 LOG I ELOG I CMPLTN 10:00 - 12:00 2.00 LOG ELOG CMPLTN 12:00 - 13:30 1.50 LOG ELOG CMPLTN Start: 6/22/2005 Rig Release: 9/10/2005 Rig Number: 15 Page 25'of 45 Spud Date: 6/26/2005 End: 9/10/2005 Group: Description of Operations Service Rig, Monitior Well Trip in Hole: From 10,167' To 15,851' Fill every 10 stands 200k Up Wt, 95 Dn Wt. Had 95-100 Dn Wt all the way in Hole. Wash and Ream F/ 15,831' - T/ 15,940' Circulate; 600 GPM 4050 psi. @ 15,940' Getting Trucks with Solids Free OBM loaded up and all OLD O.B.M out of Pits. Trucks not lined up slow circ rate and rotary after Btms Up. Wait On Trucks. Circulate; Getting Trucks with Solids Free OBM loaded up and all OLD O.B.M out of Pits. Trucks not lined up slow circ rate and rotary after Btms Up. Wait On Trucks. Pump Sweep 40bbls, 100bb1s OBM, Followed By Solids Free OBM, Old OBM: While Pumping and Rotate and Recipacation 138 Up Wt.129 Dn Wt. 120 RPM Torque 19k, 600 Gpm, 4,100psi. Solids Free OBM around: Up Wt.143k, DnWt, 135k, 120 RPM, Torque 23-24k, 600 Gpm, 4.,100 Psi. Total Strks Solids Free Mud To surface 11,200 Strks, Calculated 10,557 strks, 7 % over Calculated. Monitior Well, Slow Pump Rates, Pull 1 stand watch hole for swab. PU wt 240k, SO wt -no down wt. Trip Out Hole on elevators: F/ 15,831' - 11153' Trip Out Hole on elevators: F/ 11153' - 9900' Speny Sun LWD MAD pass West sak "B" sands, log 9900' MD to 9700' MD/ 3353' TVD-3319' TVD. Log @ 200 ft/hr or less. Gamma Ray is 38' behind bit depth. Continue POOH f/ 9700' to 8713'. Sperry Sun LWD MAD pass West sak K13 marker, log 8713' MD to 8432" MD/ 3129' TVD-3057' TVD. Log @ 200 ft hr or less. Gamma Ray is 38' behind bit depth. Continue POOH f/ 8432' to 1376', UD Ghost reamer. Continue POOH f/ 1376' to 1376', L/D Ghost reamer. Stand back dp,stand back HWDP &jas, retrieved 2.33": rabit on top of jars, Stand back flex collars. PJSM, remove nuke sources. Download MWD/ LWD. UD BHA, break and grade bit. Clear and clean rig floor. PJSM; Sclumberger RU Schlumberger. and P/U Tools Run in Hole with wire line tools for USIT Log. Free Fall T/ 2,500' start tracktering, 5,300' @ Midnight. Run in Hole with wire line tools for USIT Log. 5,300' - 6,600' @ 02;OOhrs 650' a Hr. Run in Hole with wireline tools for USIT log, 6,600' - 7,390' @ 04;OOhrs 395'/ Hr. Run in Hole with wireline tools for USIT log, 7,390'- 8,300' @ 06;OOhrs 455'/Hr. Run in Hole with wireline tools for USIT log, using Schlumberger tractor.RlH f/ 8300'- 9284' Tractor not able to get tools deeper than 9284'. Tool string 87.6' long (SON, USIT, centralizer, (2) knucle jts, 5 1/2" rollers GR, Telemtry, 5 1/2" rollers, adapter, Tractor, adapter, swivel, logging wireline head. Log cement job on 9 5/8: casing f/ 9284' to 4900'. Top of good cement @ 5910'. Log f/ hole in 9 5/8" in tie back area of 9 5/8" casing f/ 4900' to 4800'. POOH to 2500'. Printed: 9!30!2005 6:19:05 AM • • ConocoPhillips,Alaska Page 26 of 45' Operations Summary Report. Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date ~ F,rom - To ~ Hours .Code Phase . Code ~ 8/9/2005 13:30 - 15:30 2.00 . LOG ELOG CMPLTN 15:30 - 16:30 1.00 LOG ELOG CMPLTN 16:30 - 17:00 0.50 WELCT OTHR CMPLTN 17:00 - 17:30 0.50 WELCT OTHR CMPLTN 17:30 - 21:45 4.25 WELCT BOPE CMPLTN 21:45 - 22:45 22:45 - 00:00 1.00 WELCT OTHR CMPLTN 1.25 CMPLTN RURD CMPLTN 8/10/2005 100:00 - 00:30 00:30 - 06:00 06:00 - 09:45 09:45 - 11:30 11:30 - 12:30 12:30 - 14:30 14:30 - 15:00 15:00 - 16:00 16:00 - 16:15 16:15 - 16:30 16:30 - 18:00 18:00 - 21:30 0.50 CMPLTNI SFTY CMPLTN 5.50 CMPLTN RUNT- CMPLTN 3.751 CMPLTNI TRIP I CMPLTN 1.751 CMPLTNI TRIP I CMPLTN 1.00 I CMPLTNI TRIP I CMPLTN 2.001 CMPLTNI TRIP I CMPLTN 0.501 CMPLTNI PCKR I CMPLTN 1.001 CMPLTNI PCKR I CMPLTN 0.251 CMPLTN PCKR CMPLTN 0.25 CMPLTN PCKR CMPLTN 1.501 CMPLTNI TRIP I CMPLTN 3.501 CMPLTNI TRIP I CMPLTN Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations Log for casing wear in 9 5/8" casing f/ 2500' to 1500', POOH. R/D Schlumbrger, L/D tools, clear rig floor. Drain stack, pull Vetco/Gray wear bushing. RU BOP test equipment. Test BOPE. Weekly test waived by AOGCC inspector Jeff Jones. Tested all componets to 250 psi low and 3000 psi high. Held each test 5 min each. Tested accumulator,2950 psi full charge, bled down to 1400, 52 sec f/ 200 psi build up, 3 min 59 sec full charge Pull test plug. Set wearVetco/Gray wear bushing (3.18' long, 9" ID). Blow down kill and choke lines and choke manifold. RU to run 5.5", 15.5 #/ft, L-80, BTC-mod liner f/A2 lateral. Blanks and slots. PJSM on running 5.5", 15.5 #/ft, L-80, BTC liner (slots and blanks). Ran Weatherford float shoe, one blank jt, (1)slofited w/insert P/O bushing, (1) slot, (9) blanks, (73) slots, (10) blanks, (6) slots, (9) blanks,. (12) slots, (5) blanks, (2) slots, (12) blanks w/ seal rings installed, pup jt, x-o, 190-47 casing seal bore ext, x-o, Baker flexlock liner hanger, "RS" packoff seal nipple, "HRD" ZXP liner top packer, running tool. Ran total of (8) easy solutions swell packers 7.98" OD. Install Weatherford 5.5" x 8.25" spiralgliders on all joints other than jts w/ swell packers and shoe jt, total ran 132 spiralgliders. PU wt 115k, SO wt 85-90k, Blocks 70k. Liner length 6048.46' + Baker running tool 12.72'= 6061.18'. 46 joints blank = 1974.81' + 95 jts slotted 4020.39' = 5995.2' PU wt 115k, SO wt 85-90k, blocks 70k. RIH w/ liner on 44 stands of 5" dp w/ LoTads. SLM. Record PU & SO wt's every 10 stands in casing. With liner @ 9 5/8" shoe, 30 rpm: torque 10K w/ PU wt of 145k, 8500 ft/Ib down wt of 125k, Rot wt 130k w/ 9k ft/ Ib torque. With liner @ 9 5/8" shoe, 15 rpm: torque 8k w/ PU wt of 145k, Sk ft/Ib down wt of 105k, Rot wt 130k w/ 8.5k ft/Ib torque. PU wt not rotating 170k, SO wt not rotating 110k Continue RIH w/ liner in open hole to 12500' (66 stands total of5" dp, 55 stands 5" dp w /LoTads + 13 stands slick 5" dp. Continue RIH w/ liner in open hole f/ 12730' to 15940' (66 stands total of 5" dp, 55 stands w /LoTads + 13 stands 5" dp slick + 14 stands 5" dp w/ LoTads + 20 stands 5" HWDP (first 10 stands Weatherford pipe, last 10 stands Doyon pipe). Fill pipe and circ down last stand @ 3bpm w/ 270 psi. Tag bottom. SO wf 110k, PU wt 265k. ,POOH f/ 15940' to 15919' (Top of "HRD" ZXP liner top packer @ 9870.46') Drop 1 7/16" ball, Circ ball down @ 5 bpm w/ 500 psi. Slow down to 3.5 bpm w/ 110 bbls pumped. Ball landed @ 136 bbls pumped (1350 strokes). Pressure to 2000 psi to set hanger. Slacked off 30k on slips. Increase pressure to 3000 psi to shear pusher tool. Increased pressure to 3300 psi and saw presure drop. Pressure continued to drop with slight returns in annulus. PU to 220k to check to see if released. Did not think released. Apply left hand rotation f/ safety release f/ liner. PU wt was 240k: Exposed dog sub. Set down 70k wt on ZXP packer 3 times. Rotate 70k on top of packer w/ dog sub. POOH to 9670', verify pump pressure. 30 spm (3bpm) = 150 psi. Continue POOH f/ 9670' to 6964' Continue POOH w/ Baker running tools f/ 6964' to surface. Calc fill 95.5 Printed: 9/30!2005 6:19:05 AM • • ConocoPhillips Alaska Pace 27 of 45 Operations Summary Report Legal We11 Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Nam e: ROT -D RILLIN G Start: 6/22/2005 End: 9/10/2005 Contractor Name: D15CM @conoc ophillip s.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 1 5 Rig Number: 15 Date ~ From - To i HOl.ll"S Code Code ~ Phase Description of Operations 8/10/2005 18:00 - 21:30 3.50 CMPLTN TRIP CMPLTN bbls, actual fill 120.1 bbls, 24.6 bbls over. 21:30 - 22:00 0.50 CMPLTN PULD CMPLTN Made service breaks and UD Baker liner running tools. 22:00 - 22:30 0.50 WINDO ULD CMPLTN Break down stand of 5" HWDP f/derrick to use in whipstock assembly. Measure joints. 22:30 - 22:45 0.25 WINDO SFTY PROD2 PJSM on PU and running Baker whipstock assembly. 22:45 - 23:15 0.50 WINDO PULD PROD2 Pick tools to rig floor. 23:15 - 00:00 0.75 WINDO ULD PROD2 PU/MU Whipstock assembly. Baker 8" Window mill, 8" Lower mill, Flex joint, 8.5" upper mill, (1)joint 5" HWDP, float sub, MWD. 8/11/2005 00:00 - 00:45 0.75 WINDO PULD PROD2 PU/MU Whipstock assembly. Baker 8" Window mill, 8" Lower mill, Flex joint, 8.5" upper mill, (1)joint 5" HWDP, float sub, MWD. 00:45 - 02:00 . 1.25 WINDO OTHR PROD2 Upload Speery Sun MWD, shallow test tools., check orientation of mills and MWD, stand back MWD & mills. 02:00 - 03:15 1.25 WINDO OTHR PROD2 PU whipstock assembly, bolt together. Whipstock assembly: Seal assembly w/ bull nose, stop sub (8.5" OD), unloader sub, (1)jf 5" HWDP, (2) 5" pup joints, blanking sub, bottom trip anchor, safety disconnect, ported drain sub, debris sub, Windowmaster shipstock, window mill, lower mill, (1) joint HWDP, float sub, Sperry sun telemetry module, Sperry sun memory module, sperry sun Gamma ,Sperry sun DM 03:15 - 04:00 0.75 WINDO OTHR PROD2 MU Baker/ Bowen bumper sub. 2 stands 5" HWDP 04:00 - 06:00 2.00 WINDO RIP PROD2 Trip in hole w/ Baker Windowmaster system using 5" DP w/ LO-Tads ,SLM, running speed 2 min/stand f/ 384' to 2856'. Fill pipe. 06:00 - 08:00 2.00 WINDO RIP PROD2 Trip in hole w/ Baker Windowmaster system using 5" DP w/ Lo-Tads, SLM, running speed 2 min/stand f/ 2856' to 4844'. PU wt 170k, SO wt 90K. Note: on Hi-line power @ 0830 hrs. 08:00 - 09:00 1.00 WlNDO OTHR PROD2 Set down @ 4844' (45 stands +10'). Check string weight. Check location of assembly in relation to 9 5/8" Tie-Back Note: 4844'MD = 2268.5 TVD, 77.67 deg inclination, 174.79 azimuth, 1.31 deg dogleg. 09:00 - 10:00 1.00 WINDO OTHR PROD2 Check casing profiles, logs and options. 10:00 - 11:30 1.50 WINDO OTHR PROD2 MU top drive, work string. Rotate ! 15 rpm, up and down, rotate up watching torque (7-10k ft/Ib), Rotate/PU slow. 11:30 - 12:30 1.00 WINDO RIP PROD2 POOH to check whipstock assembly. 12 stands out. 12:30 - 13:00 0.50 WINDO SFTY PROD2 Quarterly Safety Assessment w/ Doyon, CPAI and rig crew. 13:00 - 15:00 2.00 WINDO RIP PROD2 Continue POOH w/ Baker whipstock. Set back 2 stands 5" HWDP. 15:00 - 16:30 1.50 WINDO RIP PROD2 Work BHA f/ whipstock. Drain stack. Pull through stack slow. NO Whipstock. 16:30 - 17:30 1.00 WINDO ULD PROD2 UD Sperry Sun MWD, UD (1) HWDP, UD Baker mills. 17:30 - 18:00 0.50 WINDO OTHR PROD2 Clear rig floor of tools. 18:00 - 18:30 0.50 RIGMNT RSRV PROD2 Service rig and top drive. 18:30 - 20:00 1.50 FISH PULD PROD2 PU tools to fish whipstock. MU BHA: Baker retieving hook , (1) 5" HWDP, float sub, 6.25" Bowen, 6.25" Oil Jar, (5) stands 5" HWDP. (Total length of BHA = 523.86') 20:00 - 22:15 2.25 FISH TRIP PROD2 RIH w/ 5" DP w/ LoTads to fish whipstock. Run 42 stands. 22:15 - 22:45 0.50 FISH FISH PROD2 MU top drive on stand 43, strap 5' going in hole, to locate slot in whipstock w/ retrieving tool. Apply torque to drill string and rotate. Found top of whipstock @ 78.4' in and keyhole @ 84.7' in on stand 43. PU wt 135k, SO wt 100k 22:45 - 23:00 0.25 FISH FISH PROD2 PU 60-65kk over (210k) to release bottom trip anchor. Note: next daay recoved whipstock. Whipstock had signs of retieving too! @ slot had jumped off, anchor did not release. Pulled anchor loose next trip. Printed: 9/30/2005 6:19:05 AM • • LonocoPhillips Alaska Page 2s'of 45 Operations Summary. Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: ROT -DRILLING Start: 6122!2005 End: 9/10/2005 Contractor Name: D15CM@conocophilljps.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 15 Rig Number: 15 Date 'Fro«i - To Hours' ~ Code ~' °uD _ Code 8(1112005 23:00 - 00:00 1.001 FISH ~ TRIP Phase Description of Operations PROD2 POOH slow w/ whipstock assembly FISH (/.4762' to 3490' (Window Master Whipstock, debris sub w/ 9.625" barrier cup, ported drain sub, safety disconnect sub, 9 5/8" bottom trip anchor, blanking sub, 14.68' 5" pup jt, 9.48' 5" pup joint, (1) joint 5" HWDP, unloader sub, 8.5" OD stop sub, 7 7/16" OD Seal assembly w/ bull nose) Note: no fish recovered POOH slow w/ whipstock assembly f/ 3490' to 524' FISH (Window Master Whipstock, debris sub w/ 9.625" barrier cup, ported drain sub, safety disconnect sub, 9 5/8" bottom trip anchor, blanking sub, 14.68' S" pup jt, 9.48' 5" pup joint, (1) joint 5" HWDP, unloader sub, 8.5" OD stop sub, 7 7/16" OD Seal assembly w/ bull nose) Stand back 5 stands 5" HWDP, UD Oil jars, bumper jars and float sub. PU & Inspect Baker retrieving hook; whipstock assembly not recovered, signs of contact on top edge of retrieving tool. UD Baker hook, PU/MU Baker box tap (rolling dog sub), MU same. Trip in hole w/ whipstock retrieving tool (Box Tap) on (1) jt 5" HWDP, float sub, 6.25" Bowen bumper sub, 6.25" Bowen Oil jar, (5) stands 5" HWDP. Trip in hole w/ fishing BHA to latch whipstock. RIH w/ 5" dp w/ Lo-Tads f/ 520' to 4756', run a total of 42 stands 5" dp w/ to-Tads, MU top drive on stand 43 and 5' strap in. Tag @ 4756.74'. (82.5' on stand 43) Note: PU wt 132k, SO wt 100k, Rot wt 115k, rot torque 5-7k ft/Ib. Engage fish (top of whipstock), PU 3' w/ 145k PU wt, SO, apply tums- watching torque-max 9k ft/Ib. Let jars bleed W/ PU wt of 170k, final of 140k, PU to 160k, 170k, 185k, 205k, 210k anchor released. Pull up hole w/ 140-145k PU wt. Slack off to tag up again; but went past stop point. Slack off to 10' past (4766'). PU again w/ 140-143k past stop point, slack off and tagged up this time (Indication of still having whipstock fish assembly). POOH slow w/ fish (Whipstock window masterassembly). Pull 50-60 ft/min. Stand back (5) stands 5" HWDP, Lay down bumper sub, jars and float sub. Pull (1) joint 5" HWDP and box tap w/ whipstock assembly(fish). UD Fish consisting of: Whipstock, debris sub, ported drain sub, safety disconnect, bottom trip anchor, blanking sub, 5" pup joint 14.68' long, 5" pup joint 9.48" long, one joint 5" HWDP, unloader, 8.5" OD stop sub, 7-7/16" OD seals w/ bull nose. Total length 94.21'+ seals below stop. Clear rig floor of unneccessary tools. PU/MU Whipstock assembly #2. PU/MU Debris sub, ported drain sub, safety disconnect, bottom trip anchor, blaking sub. UD same to pipe shed. PU/MU MWD assembly: 8" window starting mill, 8" lower mill, flex joint, 8.51" upper mill, (1) joint 5" HWDP float sub, Sperry Sun directional probe, Sperry Sun MWD/LWD, Sperry Sun telemetry module. Up load Sperry Sun MWD, shallow test @ 505 gpm w/ 640 psi. Stand back MWD assembly. PU whipstock, MU whipstock. Attatch mills and MWD to whipstock. Check orientation. MU bumper sub, PU (3) 6 3/4" spiral drill collars. Rabbit w/ 2 3/8" drift before Picking up DC's. Trip in (2) stands 5" HWDP. Whipstock assembly consists of: Seals, stop sub, unloader (1} jt 5" HWDP, 9.48' long 5" pupjt, 14.68' long 5" pupjt, blanking sub, bottom trip anchor, 8(12/2005 00:00 - 02:30 2.50 FISH TRIP PROD2 02:30 - 03:00 0.50 FISH TRIP PROD2 03:00 - 04:45 1.75 FISH OTHR PROD2 04:45 - 05:00 0.25 FISH TRIP PROD2 05:00 - 06:30 1.501 FISH I TRIP PROD2 06:30 - 07:45 I 1.251 FISH I FISH I PROD2 07:45 - 11:00 I 3.251 FISH I TRIP I PROD2 11:00 - 11:30 I 0.501 FISH I TRIP I PROD2 11:30 - 13:30 I 2.001 FISH I PULD I PROD2 13:30 - 14:00 0.50 FISH OTHR PROD2 14:00 - 16:45 2.75 WINDO ULD PROD2 16:45 - 18:00 1.25 WINDO ULD PROD2 18:00 - 18:45 0.75 WINDO ULD PROD2 18:45 - 19:30 0.75 WINDO ULD PROD2 19:30 - 20:15 0.75 WINDO ULD PROD2 Printed: 9/30/2005 6:19:05 AM • • ConocoPhillips Alaska Page 29 of ~~ Operations Summally,Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT.- DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To Hours ~ Code `{{ Sub Phase fCode~ 8/12/2005 19:30 - 20:15 0.75 WIN 20:15 - 00:00 3.75 W I N 8/13/2005 00:00 - 04:45 4.75 WIN 04:45 - 06:30 1.75 WIN 06:30 - 08:30 2.00 W I N 08:30 - 09:30 1.00 .WIN 09:30 - 09:45 0.25 WINI 09:45 - 11:30 1.75 WINI 11:30 - 14:20 2.83 WINI 14:20 - 18:00 I 3.671 W 1 NI 18:00 - 00:00 I 6.00 8/14/2005 00:00 - 06:00 6.00 WIN 06:00 - 08:00 2.00 W I N 08:00 - 08:30 0.50 W I N 08:30 - 10:00 10:00 - 10:30 10:30.- 15:00 15:00 - 16:30 16:30 - 17:00 17:00 - 18:30 1.50 RIGI 0.50 WIN 4.50 WIN 1.50 WIN 0.50 WIN 1.50 WIN 18:30 - 19:15 0.75 PROD2 P I PROD2 P PROD2 rHR PROD2 tIP PROD2 :TW PROD2 ~TY PROD2 RC PROD2 'WP PROD2 P I PROD2 PROD2 ISTWP PROD2 'CIRC PROD2 'OTHR PROD2 RSRV PROD2 CIRC PROD2 TRIP PROD2 PULD PROD2 PULD PROD2 OTHR PROD2 OTHR I PROD2 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations safety disconnect, ported drain sub, debris sub, Whipstock, 8" starter mill, 8" lower mill, flexjoint, 8.51" upper mill, (1) joint 5" HWDP, float sub, Sperry Sun irectional, Sperry sun LWD, Speny sun telementry module, Bown bumper sub, (3) 6 3/4" Spiral DC's, (2 stands) 5" HWDP. Follow w/ 5" drill pipe w/ Lo-Tads RIH in hole slow w/ Whipstock on 5" drill pipe w/ Lo-Tads f/ 477' to 2949', fill pipe, RIH w/ 5" drill pipe w/ Lo-Tads f/ 2949' to 4927. RIH in hole slow w/ Whipstock on 5" drill pipe w/ Lo-Tads f/ 4927'- 8857.72' MAD pass log f/ 8857.72' to 9061'. Pumping 600 gpm w/ 2875 psi. Logging @ less than 300 ft/min RIH in hole slow w/ Whipstock on 5" drill pipe w/ Lo-Tads f/ 9061' to 9820'. PU wt 220k, SO wt 115k Orient whipstock. Set whipstock top 9776.6' w/ top of window @ 9778'. Set 24 deg Left of high side. PU wt 210k, SO wt 102k. PJSM w/ crew and AES vac truck operators, mud engr. Displace well f/ 9.0 ppg Solids free oil base mud to 9.0 ppg Mineral oil base mud. Displace @ 505 gpm w/ 2545 psi. Start milling window f/ "B" lateral @ 9778.5' to 9794.5' (16'). 75-105 RPM, torque 13-19k ft/Ib. Pump 505 gpm w/ 2550 psi. PU wt 220k, SO wt 115k, Rot wt 160k.Top of window @ 9778.5'/ 3331'TVD. Bottom of window @ 9794.5'/ 3334' TVD. Continue milling window f/ 9794' to 9803' (9'). PU wt 220k, SO wt 115k, Rot wt 160k, 95rpm, 19-13k ft/Ibs on bottom, 12-13k ft/Ib off bottom torque, 505 gpm w/ 2680 psi. Continue milling window f/ 9803' to 9808 (5') TVD = 3336'. PU wt 220k, SO wt 115k, Rot wt 160k, 105-120rpm, 14-17k ft/Ibs on bottom, 12-13k ft/Ib off bottom torque, 505 gpm w/ 2680 psi. Weight on mill 25k. Pumped 30 bbls weighted Hi-Vis sweep @ 2230 hrs (9807'), no improvement in milling ROP. Note: This section of hole was slow drilling in 12 1/4" hole section. 9810' starter mill depth, rate gets better. Starter mill to upper milt = 19.34' Continue milling window f/ 9808' to 9818 (10') TVD = 3337. PU wf 220k, SO wt 115k, Rot wt 160k, 105-120rpm, 14-17k ft/Ibs on bottom,. 12-13k ft/Ib off bottom torque, 505 gpm w/ 2680 psi. Weight on mill 25-30k. Note: "B" lateral window: 9778.5' to 9794.5' MD (3331' TVD-3334' TVD) Pump 30 bbls weighted (2ppg over =11.0 ppg) Hi-Vis sweep @ 520 gpm w/ 2580 psi. Circ to surface + a bottoms up (12,000 strokes, 1208 bbls). Work through window several times. No Problems. PU wt 220k, SO wt 140k. TD of starter mill w/ no compression is 9818' (3337' TVD), full 8.5" guage mill 4.76' outside of window. PU to 9756', stand a stand back Slip and cut drilling line,. adjust brakes. Pump dry job. POOH f/ 9756' to 383'. UD milling BHA. Upper mill guaged @ 8.5" OK. Clear rig floor of unneccessary tools. Pull wear bushing. Wash stack, function all rams & annular, kill line valves, choke line valves. Install Vetc/Gray wear bushing. UD (2) 5" HWDP. Printed: 9/30/2005 6:19:05 AM • • ConocoPhillips Alaska Page 30 of 45 Operations Summary Report ~ i Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From -;To Hours Code ~ Code I PPhase 8/14!2005 19:15 - 20:15 1.00 RIGMNT RSRV PROD2 20:15 - 22:00 1.75 DRILL PULD PROD2 22:00 - 23:00 1.00 DRILL OTHR PROD2 23:00 - 23:30 0.50 DRILL TRIP PROD2 23:30 - 23:45 I 0.251 DRILL I OTHR PROD2 23:45 - 00:00 0.25 DRILL TRIP PROD2 8/15/2005 00:00 - 05:30 5.50 DRILL TRIP PROD2 05:30 - 06:30 I 1.00 I DRILL I OTHR I PROD2 06:30 - 07:00 I 0.501 DRILL I LOT I PROD2 07:00 - 12:00 I 5.00 DRILL I DRLG PROD2 12:00 - 13:00 I 1.00 DRILL I DRLG PROD2 13:00 - 13:30 0.50 DRILL CIRC PROD2 13:30 - 14:00 0.50 DRILL TRIP PROD2 14:30-18:00 3.50 DRILL TRIP IPROD2 18:00 - 18:30 I 0.501 DRILL I TRIP I PROD2 18:30 - 19:30 1.00 DRILL TRIP PROD2 19:30 - 20:00 0.50 DRILL OTHR PROD2 20:00 - 21:00 1.00 DRILL PULD PROD2 21:00 - 22:30 1.50 DRILL PULD PROD2 8/16/2005 100:00 - 01:00 I 10.001 DRILL ITOR PR IPROD2 01:00 - 05:30 4.50 DRILL TRIP PROD2 05:30 - 06:00 0.50 DRILL REAM PROD2 Spud Date: 6/26/2005 Start: 6/22/2005. End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations Change out washpipe packing on top drive. PU drilling assembly to drill out of "B" lateral whipstock/window. PU Speny Sun motor, MU bit, PU Sperry Sun MWD/LWD, float sub, then orient. Upload MWD. PU stand of flex collars, stand of HWDPw/jars., RIH 1 stand of Weatherford 5" slick dp to 440' Shallow test Sperry Sun MWD tools @ 440'. Pressure test swivel packing to 4500 psi. OK. SLM while R{H w/ Weatherford 5" dp f/ 440' to 824'. SLM while RIH w/ Weatherford 5" dp f/ 824' to 9719'. RIH w/ 1.5 deg motor to drill out of "B" lateral window, fill pipe every 25 stands. Picked up 10 more Lo-Tads to stand back in derrick. Have a total of 79 Lo-Tads in derrick or hole. Orient motor to high side. Turn off pumps, go .past top of whipstock @- 9776', top of window 9778.5' MD/ 3331' TVD, bottom of window @ 9794.5' MD/ 3334' TVD, then to full guage hole @ 9799'. Break circ @ 9799', wash/ream underguage hole f/ 9799' to 9820' w/ 600 gpm 3650 psi. PU wt 185k w/o pumps, SO wt 112 w/o pump. PU wt 162k w/ pump, SO wt 105 w/ pump. PU f! 9820' to 9719'. No trouble going through window. RU to perform LOT. Decided not too. R/D test equipment. Directional drill 8 1/2" hole f/ 9820' to 9990'.(3341' TVD) ART 2.35 hrs, AST 1.15 hrs w/ Sperry Sun 1.5 deg motor, 10-25k WOB, 0-80 rpm's, 550 gpm, 9.0-9.1 ppg mw, on bottom pressure 3150 psi, off bottom pressure 2980 psi, on bottom torque 14-17k ft/Ib, off bottom torque 12k ft/Ib, PU wt 180k, Dn Wt 95k ,Rot wt 130k. Directional drill 8 1/2" hole f/ 9990' to 10050' (3337' TVD) ART .27 hrs, AST .19 hrs w/ Sperry Sun 1.5 deg motor, 10-25k WOB, 0-80 rpm's, 550 gpm, 9.0-9.1 ppg mw, on bottom pressure 3150 psi, off bottom pressure 2890 psi, on bottom torque 14-17k ft/Ib, off bottom torque 13k ft/Ib, PU wt 180k, Dn Wt 95k ,Rot wt 130k. Circ w/ recip and rotate pipe. MWD survey, SPR's, monitor well. POOH f/ 10050' to 9705'. No problems through window bottom @ 9794.5' to 9778.5' top of window. Monitor well, pump dry job: Continue POOH f/ 9705' to 1295' w/ Sperry Sun 1.5 deg motor to PU Geo-pilot. No problems. Continue POOH f/ 1295' to 348' w/ Speny Sun 1.5 deg motor to PU Geo-pilot. Work BHA. Stand back HWDP, jars, flex collars, break bit. Download Sperry Sun MWD. L/D Sperry Sun MWD and motor. PU/MU Geopilot, Sperry Sun LWD/MWD tools, nuke sub and pulsar sub. Up Load MWD/LWD. PJSM on loading nuke sources Shallow test MWD/LWD tools @ 108' w/ 560 gpm 1180 psi. Shallow test MWD/LWD tools @ 108' w/ 560 gpm 1180 psi. PJSM; Load Gamma and Nuetron sources. Trip in Hole with BHA # 17 Trip in Hole; 5" Drill Pipe 31jts Pick Up ghost Reamer, Continue trip in Hole Fill Pipe Every 25 stands To 9,778' Go Through window, Wash and Ream from 9,960' To 10,038' Up WT. 180k, Dn Wt. 110k, Rot Wt. 125k, 120 RPM, 600GPM, 3,330psi. Printed: 9/30/2005 6:19:05 AM • • ConocoPhillips Alaska Page 31 of 45 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: .Date. From - To 8/16/2005 06:00 - 12:00 12:00 - 18:00 18:00 - 00:00 8/17/2005 00:00.- 06:00 06:00 - 12:00 12:00 - 18:00 18:00 - 00:00 8/18/2005 00:00 - 06:00 1 E-170 1 E-170 ROT -DRILLING D15CM@conocophillips.com Doyon 15 Start: 6/22/2005 Rig Release: 9/10/2005 Rig Number: 15 Spud Date: 6/26/2005 End: 9/10/2005 Group: Hours 'Code Sub i Phase Code~~ 6.00 DRILL DRLH I PROD2 6.001 DRILL I DRLH I PROD2 6.00 I DRILL ~ DRLH PROD2 6.00 I DRILL I DRLH I PROD2 6.00 I DRILL DRLH I PROD2 6.00 I DRILL I DRLH PROD2 6..001 DRILL I DRLH 1 PROD2 6.00 I DRILL I DRLH I PROD2 06:00 - 13:00 I 7.001 DRILL I I PROD2 Description of Operations Directional Drill 8 1/2" hole F/ 10,050' Tl10,305' (3,333' TVD) ART 4.62 hrs, Bit Hrs 4.62, 5-20k W0B,80 - 120 RPM, 550 gpm, 9.0-9.2ppg MW, On BTM 2,870 psi, Off BTM 2800 psi, On BTM 11-17k ft/Ib,Off Btm 14k ft/Ib, PU wt 165k, Dn Wt 90k ,Rot wt 130k. ECD 11.4ppg. Directional Drill 8 1/2" hole F/ 10,305' (3,333' TVD) T/ 10,549' (TVD 3,338') ART 5.28 hrs, Bit Hrs 9.9, 5-20k WOB,80 - 120 RPM, 550 gpm, 9.0-9.2ppg MW, On BTM 2,940 psi, Off BTM 2,850 psi, On BTM 13-18k ft/Ib,Off Btm 14k ft/Ib, PU wt 180k, Dn Wt 80k ,Rot wt 130k. Directional Drill 8 1/2" hole F/ 10,549' (TVD 3,338') T/ 11,018' (TVD 3,328') ART 3.49 hrs, Bit Hrs 13.65, 5-20k WOB,80 - 120 RPM, 600 gpm, 9.0-9.2ppg MW, On BTM 3,210 psi, Off BTM 3,160psi, On BTM 13-18k ft/Ib,Off Btm 14k ft/Ib, PU wt 215k, Dn Wt 95k ,Rot wt 140k. ECD 11.8 Directional Drill 8 1/2"hole F/ 11,018' (TVD 3,328') T/ 11,238' (3,331'Tvd} ART 4.97 hrs, Bit Hrs 18.62, 15-25k W06,140 RPM, 600 gpm, 9.0-9.2ppg MW, On BTM 3,330 psi, Off BTM 3,260psi, On BTM 15-24k ft/Ib,Off Btm 14k ft/Ib, PU wt 220k, Dn Wt 95k ,Rot wt 140k. .ECD 11.8. Average Rate of Penatration 45'per hr 220' Total ft Drilled. Directional Drill 8 1/2" hole F/ 11,238' (3,331') T/ 11,673' (3,331' Tvd)ART 3.69 hrs, Bit Hrs 22.31, 5-25k WOB,140 RPM, 550 gpm, 9.2ppg MW, On BTM 2,870 psi, Off BTM 2,840psi, On BTM Torq 13-24k ft/Ib,Off Btm Torq 21k ft/Ib, PU wt 225k, Dn Wt 80k ,Rot Wt. 140k. ECD 11.7 Average Rate Penetration 117' per hr. 435' Total Ft. Drilled. Directional Drill 8 1/2" hole F/ 11,673' (3,331') T/ 11,814' (3,330' Tvd) ART 5.53 hrs, Bit Hrs 27.84, 10-25k WOB,140 RPM, 550 gpm, 9.0-9.1 ppg MW, On BTM 2,930 psi, Off BTM 2,840psi, On BTM Torq 15-214k ft/Ib, Off Btm Torq 15-21 k ft/Ib, PU Wf. 225k, Dn Wt. 85k ,Rot Wt. 140k. ECD 11.4 Average Rate Penetration 25' per hr. 141' Total Ft. Drilled. Directional Drill 8 1/2" hole F/ 11,814' (3,330' Tvd) - T/ 12,093' (3,324'Tvd) - PU Wt. 220k,- Dn Wt. 95k, -Rot Wt. 140k.- GPM 600 - Press on Btm-3,280': Press off Btm 3,180' -RPM 140,- Torq,on Btm. 17-22,- Torq Off Btm. 14-16,-Actual Drill Time 5.10 -Bit Hrs. 32.94 - Average Rate Penetration 55' per hr: 279' Total Ft. Drilled. -Max Gas 242 units. Directional Drill 8 1/2" hole F/ 12,093' (3,324'Tvd) T/ 12,489' (3,319' Tvd) - UP Wt. 230k,- Dn Wt. 90k, -Rot Wt. 140k.- GPM 557 -Press on Btm-2,900'.- Press off. Btm 2,870' -RPM 120,- Torq,on Btm. 17-22,- Torq Off Btm. 18,-Actual Drill Time 4.92 -Bit Hrs. 37.86 -Average Rate Penetration 80' per hr.- 396' Total Ft. Drilled. -Max Gas 127 units. Note; Hit possible fault @ approximately 400' further then expected @12,300' Dropped RPM and GPM to help build angle. 12,490' Back in sands. Directional Drill 8 1/2" hole F/ 12,489' (3,319'Tvd) T/ 12,687' (3,311' Tvd) - UP Wt. 225k,- Dn Wt. 85k, -Rot Wt. ~130k.- GPM 600 -Press on Btm-3,430'.- Press off Btm 3,380' -RPM 120,- Torq,on Btm. 15-22,- Torq Off Btm. 14-19k; Actual Drill Time 6.15 -Bit Hrs. 44.01 -Average Rate Penetration 33' per hr.- 198' Total Ft. Drilled. -Max Gas 161 units. 13:00 - 16:30 I 3.50) RIGMNTI RGRP I PROD2 I Circulate while repair on #1 pump liner gasket, Broke stud on pony rod. 16:30 - 18:00 1.50 DRILL DRLH I PROD2 Directional Drill 8 1/2" hole F/ 12,687' (3,311' Tvd) - T 12,697' (3,310' Tvd)Up Wt. 225k,- Dn Wt. 85k, -Rot Wt. 130k.- GPM 600 -Press on Printed: 9!30!2005 6:19:05 AM • • ConocoPhillips' Alaska Page 32 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: ROT -DRILLING Start: 6/22/2005 End: 9/10/2005 Contractor Name: D15CM@conocophillips.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To ~ Hours Code Code Phase ~ Description of Operations _I 8/18/2005 16:30 - 18:00 1.50 DRILL DRLH PROD2 Btm-3,430'.- Press off Btm 3,380' -RPM 120,- Torq,on Btm. 15-22,- Torq Off Btm. 14-19k; Actual Drill Time 1.41 -Bit Hrs.45.42 -Average Rate Penetration 7' per hr.- 10' Total Ft. Drilled. -Max Gas151units. ECD 11.6ppg. 18:00 - 23:15 5.25 DRILL DRLH PROD2 Directional Drill 8 1/2" hole F/ 12,687' (3,311' Tvd) - T 12,920' (3,308' Tvd) UP Wt. 225k,- Dn Wt. 85k, -Rot Wt. 130k.-GPM 600 -Press on Btm -3,430'.- Press off Btm 3,380' -RPM 120,- Torq,on Btm. 15-22,- . Torq Off Btm. 14-19k,-Actual Drill Time 3.78 -Bit Hrs.49.20 -Average Rate Penetration 59' per hr.- 223' Total Ft. Drilled. -Max Gas 242 units. ECD 11.8ppg 23:15 - 00:00 0.75 RIGMNT RGRP PROD2 Work on Kelly hose wearing on stand Upper Tool Jt. While Drilling. Showing signs of wear. Loosen union and put tum in hose. 8/19/2005 00:00 - 06:00 6.00 DRILL DRLH PROD2 Directional Drill 8 1/2" hole F/ 12,920' (3,308' Tvd). T/ 13,323'(3,302 TVD) PU Wt. 220k; Dn Wt. 90k, -Rot Wt. 140k.-GPM 600 -Press on Btm-3,430': Press off Btm 3,380' -RPM .140,- Torq,on Btm. 16-23; Torq Off Btm. 18k,-Actual Drill Time 4.25 -Bit Hrs.53.45 -Average Rate Penatration 94.82' per hr.- 403' Total Ft. Drilled. -Max Gas 142 units. ECD 11.8ppg NOTE; Pumped Sweep @ 13,118', 40% increase on retums. 10.9 ppg 160vis.40bbls. ECD 12.2ppg 11.8ppg. After Sweep. 06:00 - 12:00 6.00 DRILL DRLH PROD2 Directional Drill 8 1/2" hole FJ 13,323'(3,302 TVD) Ti 13,711' (3,290' Tvd). PU Wt. 230k,- Dn Wt. 80k, -Rot Wt. 125k.-GPM 600 -Press on Btm-3,430'.- Press off Btm 3,390' -RPM 140,- Torq,on Btm. 15-21,- Torq Off Btm. 18k,- Actual Drill Time 4.25 -Bit Hrs.57.61 -Average Rate Penatration 91.29' per hr.- 388' Total Ft. Drilled. - ECD 12ppg. 12:00 - 18:00 6.00 DRILL DRLH PROD2 Directional Drill 8 1/2" hole F/ 13,711' (3,290' TVD) T/ 13,811' (3,284' Tvd). PU Wt. 230k,- Dn Wt. 80k, -Rot Wt. 125k: GPM 600 -Press on Btm-3,560'.- Press off Btm 3,490' -RPM 140,- Torq,on Btm. 15-21,- Torq Off Btm. 18k,-Actual Drill Time 5.29 -Bit Hrs. 62.90 -Average Rate Penatration 18' per hr.- 100' Total Ft. Drilled. - ECD 12.2ppg. 18:00 - 00:00 18/20/2005 100:00 - 01:30 6.001 DRILL DRLH I PROD2 Directional Drill 8 1/2" hole F/ 13,811' (3,284' TVD) T/ 14,058' (3,277' Tvd). PU Wt. 220k,- Dn Wt. 85k, -Rot Wt. 135k.- GPM 600 -Press on Btm-3,570'.- Press off Btm 3,510' -RPM 140,- Torq,on Btm. 19,- Torq Off Btm. 19k,- Actual Drill Time 4.35 -Bit Hrs. 67.25 -Average Rate Penatration 18' per hr.- 247' Total Ft. Drilled. - ECD 12.3ppg. Pumped Sweep @ 14,038' 40 bbl sweep 25°!o increase in returns. Directional Drill 8 1/2" hole F/ 14,058' (3,284' TVD) T/ 14,101' (3,277' Tvd). UP Wt. 220k,- Dn Wt. 85k, -Rot Wt. 135k.-GPM 600 -Press on Btm-3,570'.- Press off Btm 3,510' -RPM 140,- Torq,on Btm. 19,- Torq Off Btm. 19k; Actual Drill Time.57 -Bit Hrs. 67.42 -Average Rate Penetration 75' per hr.- 43' Total Ft. Drilled. - ECD 12.6ppg. No Change in ECD. After Sweep. Back Ream Out of Hole,F/14,101' T/12,490' Pull Speed 10-20 feet a min, 600 GPM, 3,560psi. Short Trip to Place Ghost Reamer at window. Circulate Hole while Cleaning up fluid discharged from broken mud bucket line. 3 bbls in Containment Approximately 6 gals Outside containment Security and Environmental notified @ 04;05am. Replace line and clean up. Back Ream Out of Hole,F/12,290' T11,275' Pull Speed 4-6 feet a min, 600 GPM, 3,360psi. Short Trip to Place Ghost Reamer at window. 1.501 DRILL I DRLH I PROD2 01:30 - 04:00 2.50 DRILL REAM PROD2 04:OQ - 06:30 2.50 RIGMNT RGRP PROD2 06:30 - 13:00 6:50 DRILL I REAM I PROD2 Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska Operations Summary Report.. Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To i Nours, ~ Code Code Phase.. 8/20/2005 13:00 - 14:00 1.00 DRILL CIRC PROD2 14:00 - 16:00 2.00 DRILL TRIP PROD2 16:00 - 16:30 0.50 DRILL REAM PROD2 16:30 - 18:00 1.50 DRILL DRLH PROD2 18:00 - 00:00 8/21/2005 100:00 - 06:00 6.001 DRILL I DRLH I PROD2 6.001 DRILL I DRLH I PROD2 06:00 - 17:30 I 11.501 DRILL I DRLH I PROD2 17:30 - 18:00 18:00 - 23:45 23:45 - 00:00 8/22/2005 00:00 - 00:30 00:30 - 01:00 01:00 - 01:45 01:45 - 08:15 0.50 DRILL CIRC PROD2 5.75 DRILL TRIP PROD2 0.501 DRILL (CIRC IPROD2 0.50 DRILL TRIP PROD2 0.75 DRILL REAM PROD2 6.50 I DRILL I REAM I PROD2 08:15 - 15:30 7.25 DRILL OTHR PROD2 15:30 - 16:30 1.00 RIGMNT RSRV PROD2 16:30 - 19:15 2.75 DRILL TRIP PROD2 19:15 - 22:45 3.50 DRILL REAM PROD2 22:45 - 00:00 1.251 DRILL (CIRC IPROD2 Start: 6/22/2005 Rig Release: 9/10/2005 Rig Number: 15 .Page 33`'of 45 Spud Date: 6/26/2005 End: 9/10/2005 Group: Description of Operations Circulate and Recipacate F/ 11,275' - T/ 11,330' Trip in Hole; F/11,275' - 14,006' Average slack off wt 80k Dn Wt. Wash and Ream F/ 14,006' - T/ 14,101' No Hole Problems on Trip. Directional Drill 8 1/2" hole F/ 14,101' (3,277' TVb) T/ 14,138' (3,3,274' Tvd). UP Wt. 230k,- Dn Wt. 80k, -Rot Wt. 120k.- GPM 585 -Press on Btm-3,640'.- Press off Btm 3,510' -RPM 140,- Torq,on Btm. 19,- Torq Off Btm. 19k; Actual Drill Time..65 -Bit Hrs. 68.47 -Average Rate Penetration 56 per hr.- 37' Total Ft. Drilled. - ECD 12.6ppg. No Change in ECD. After Sweep. Directional Drill 8 1/2" hole F! 14,138' (3,274' TVD) T/ 14,575' (3,269' Tvd). UP Wt. 230k,- Dn Wt. 80k, -Rot Wt. 120k.- GPM 550 -Press on Btm-3,120'.- Press off Btm 3,090' -RPM 140,- Torq,on Btm. 20,- Torq Off Btm. 18k,-Actual Drill Time. 4.07 -Bit Hrs. 72.54 -Average Rate Penetration 107 per hn- 43T Total Ft. Drilled. - ECD 11.7ppg. Max Gas Units 247, Lower Pump Rate @ 14,292' F/600GPM - T/ 550 GPM T/ Manage ECD. Annular Velocity 220 ft per min. @ 550GPM in 8.8 hole. Directional Drill 8 1/2" hole F/ 14,575' (3,269' Tvd). T/ 15,000' (3,252'Tvd) UP Wt. 230k,- Dn Wt. 80k, -Rot Wt. 130k.-GPM 550 - Press on Btm-3,200'.- Press off Btm 3,170' -RPM 140,- Torq,on Btm. 20,- Torq Off Btm. 18k,- Actual Drill Time. 4.53 -Bit Hrs. 77.07 - Average Rate Penetration 94 per hr.- 425' Total Ft. Drilled. - ECD 11.7ppg. Max Gas Units 550, Pumped Sweep @ 14,903' 35% increase in returns at Shakers. Directional Drill 8 1/2" hole F! 15,000' (3,252'Tvd) T/ 15756' (3,231' Tvd)TD. UP Wt. 2250k,- Dn Wt. Ok, -Rot Wt. 139k.- GPM 550 -Press on Btm-3,640'.- Press off Btm 3,580' -RPM 140,- Torq,on Btm. 20,- Torq Off Btm. 18k,- Actual Drill Time. 6.98 -Bit Hrs. 84.05 -Average Rate Penetration 94 per hr.- 425' Total Ft. Drilled. - ECD 12.6ppg. Max Gas Units 490. Pumped Sweep @ 15,430' Circulate Rotate and Reciprcate Back Ream Out of Hole,F/15,756' - T/ 14,000' Pull Speed 4-6 feet a min, first 8 stands, 25-30 feet per min. while backreaming out 550 GPM, 3,210psi. Short Trip to last short trip depth 14,000' Pull 3 stands on Elevators pulled good.T/ 13,714. Circulate, Rotate and Recipacate BTMs Up. Circulate, Rotate and Recipacate BTMs Up. 600 GPM - 3,340psi - 140 RPM Up Wt. Trip in Hole 13,714 Would not go down Wash and Ream F 13,912' - T/ 14,420' Still would not go down with out washing and reaming @ 550 GPM -140 RPM - Back Ream Out of Hole F/ 14,420' - T/ 10,700' - 140 RPM;- 560GPM -3,100psi. Pumped Sweep while slowly pulling up T/Windoow W/ Ghost Reamer, 40% increase in cutting (fine sand). Pull through window with Ghost reamer continue back reaming T/10,700 Mad Pass F/10,700' - T/ 9,762' @ 3-4ft a min/Per MWD. Service Rig, Monitior well Trip in Hole; F/ 9,762' - T/ 14,450' Wash and Ream in Hole F/ 14,450' 6 stands of Heavy wieght on top. 14,450' Wash 2stands down try to go down without rotation, Still no down wieght, Ream stand down, Pull up 30' try to go down just with pumps, No down wieght, 15,561, 18 stands Heavy wt. Was able to get down wt. 80k down Ream to Btm. 15, 756'. Circulate and condition hole, Pump 35 BBL Sweep 10.5ppg 130vis. Printed: 9/30/2005 6:19:05 AM • ConocoPhillips'A!aska Page 34 of 45 Operations Surrtmary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: ROT -DRILLING Start: 6/22/2005 End: 9/10/2005 Contractor Name: D15CM@conocophillips.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 15 Rig Number: 15 Date '.From - To i Hours' Code Code ~ ,..Phase 8/22/2005 22:45 - 00:00 1.25 DRILL CIRC PROD2 18/23/2005 100:00 - 01:45 01:45 - 06:45 1.751 DRILL (CIRC PROD2 5.001 DRILL I TRIP I PROD2 06:45 - 07:45 1.00 RIGMNT RSRV PROD2 07:45 - 12:00 4.25 DRILL TRIP PROD2 12:00 - 13:30 1.50 DRILL PULD PROD2 .13:30 - 14:15 0.75 DRILL PULD PROD2 14:15 - 18:15 4.00 DRILL PULD PROD2 18:15 - 19:15 1.00 DRILL PULD PROD2 19:15 - 19:45 0.50 DRILL OTHR CMPLT2 19:45 - 00:00 4.25 WELCT BOPE CMPLT2 18/24/2005 100:00 - 03:00 03:00 - 10:00 3.00 WELCT BOPE CMPLT2 7.00 RIGMNT RGRP CMPLT2 10:00 - 10:30 10:30 - 11:15 11:15 - 12:00 12:00 - 12:30 12:30 - 20:00 20:00 - 20:15 20:15 - 00:00 8/25/2005 100:00 - 01:00 01:00 - 01:30 0.50 WELCT BOPE CMPLT2 0.75 RIGMNT RGRP CMPLT2 0.75 CMPLTN RURD CMPLT2 0.50 CMPLTN SFTY CMPLT2 7.50 CMPLTN RUNT CMPLT2. 0.25 CMPLTN OTHR CMPLT2 3.751 CMPLTNI RUNT I CMPLT2 1.001 CMPLTNI RUNT CMPLT2 0.501 CMPLTNI CIRC I CMPLT2 Description of Operations 50% increase in returns. GPM-537, PSI.-3,840' RPM-140, UP WT. 260k - Dn Wt.- 115k, -Rot Wt. 170k. Torq 20k.After sweep. Circulate and Condition Hole: Displace hole with solids free Oil Base Mud. GPM 537- PSI 4,000-RPM 140- Up Wt. 280k.-Dn Wt.95k-Rot Wt.170.- Torq 22k. after Displaced. Note; Before displacement GPM 537-PSI 3,840. -RPM 140.-Up Wt. 260k.-Dn Wt. 115k: Rot Wt. 170k. Torq 20 Trip Out Hole. Drop Drift 2", SLM, F/ 15,756'- T/ 9,650' Up Wt 230k, Dn Wt.90k. Note: Tight Spot @ F/13,417' - T/13,222' 30-35k overpull. Cut Drill Line, 140' Inspect Brakes, Monitor Well Trip Out Hole: SLM, F/ 9,650' - T/ 385' L/D NWT D.P. Jars, and flex co{lars. .PJSM on removing gamma and nuetron sources, and remove. Download LWD tools. Lay Down BHA. Clean rig floor. Rig Up to test BOPE 250psi. low 3,000psi. high, Pull wear ring. Set test plug, Test BOPE (test Jt Bad had to UD and R/U new Jt.) Rig Up to test BOPE 250psi. low 3,000psi. high, Test ROPE, All test except Hydril Tested. Hydril Failed. Nipple Down Bell Nipple,Flow Line, Change Out Hydril Element. Nipple up Flow nipple and equipment, Re-Test Hydril 250 low, 3,000high. Pull test plug and set wear ring. Re-Install Drip Pan R/U to run 5 1/2" liner PJSM; Co-Man, Baker Rep and rig crew on running 5 1/2" Liner. Make Up Shoe Jt.-Insert Pack off Jt.Run. -Cross -Over Pup DWCxBTC- 5 1/2" L-80 slotted Liner 42- DWC, Cross-Over Pup BTC x BTCM, 32- BTCM 5 1/2" L-80 15.5 Slotted Liner, 10- BTCM 5 1/2"L-80 15.5 Blanks with 4 Restrictors, 50- BTCM 5 1/2" L-80 15.5 Slotted Liner. 1-BTCM 5 1/2" L-80 Blank,- 5 1/2"x7" Cross Over,1-Jt. BTCM 7" 26ppf. I-80 CSG, 1- 7" BTCM 26ppf L-80 Pup, Baker "HR" liner setting Sleeve 7", Running Tool,-5,799' of 5 1/2 liner W/ Running Tool.(4.22'), liner Up Wt,115k, Dn Wt, 90k, 5" DP, 5 -stands slick Pipe-35 Stands 5" W/ LodTads, 5 1/2" liner @ 9 5/8" Window 9,738' ,Pumps On 30RPM: Torque 7K - UP wt of 150k, 7500 ft/Ib Dn Wt 115k, Rot wt 125k w/ 7500k ft/ Ib torque.3 bpm 150psi. Pumps Off 30 RPM 7,500k Torq, Up Wt. 170k, Dn Wt. 105k. Rot Wt.130k. Run in Hole; F / 9,738' T/ 13,770' W/ 5 1/2" Liner. 43 Stands 5" W/ LodTads, 3 stand 5" HWDP. Trouble Getting in hole F/ 11,648' Work pipe. Rotated through and work through tight spot Depth 11,648' 11,728',11,900', 12,155', 12,205', 12,801', 12,420', Up Wt 210k, Dn Wt 85k when we could get down weight. 30 RPM, 15,000 Torq. Worked pipe down T/ 13,493', to best use 5" Hwt. Drill Pipe. Ran 3 stands 5" Hwt Up Wt.240k, Dn Wt 80k. Run in Hole W/ 5 1/2" Liner. F/ 13,770' - T/ 15,756' Total = 5 stands- 5" Drill Pipe. 73 Stands 5" W/ LodTads, 19 stand 5" HWDP. 6 -Stands 5" Drill pipe W/ LodTads. Tagged Btm @ 15,756', Up Wt. 290k. Dn Wt. 105k. Drop 7116" ball. put liner on depth @ 15,745' Liner Top @ 9,950' Circ Printed: 9!30/2005 6:19:05 AM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 8/25/2005 01:00 - 01:30 01:30 - 05:45 4.25 CMPLTN TRIP CMPLT2 05:45 - 06:00 0.25 CMPLTN OTHR CMPLT2 06:00 - 07:00 1.00 CMPLTN PULD CMPLT2 07:00 - 1.0:00 3.00 CMPLTN TRIP CMPLT2 10:00 - 11:00 I 1.001 CMPLTN OTHR I CMPLT2 11:00 - 12:45 1,75 CMPLTN CIRC CMPLT2 1 E-170 1 E-170 ROT -DRILLING Start: 6/22/2005 D15CM@conocophillips.com Rig Release: 9/10/2005 Doyon 15 Rig Number: 15 ours ~ Code ~ Sub Phase>~ i Code 0.501 CMPLTN CIRC CMPLT2 Page'35 of 45 Spud Date: 6/26/2005 End: 9/10/2005 Group: Description of Operations ball down @ 5 bpm w/ 500 psi. Slow down to 3.5 bpm w/ 125 bbls pumped. Ball landed @ 152 bbls pumped (1,504 strokes). Pressure to 3000 psi to set hanger. Slacked off 10k .Pull Up 240k Up Wt. Up Wt was 290k W /liner. Press 4,000psi. T/ Unseat ball Liner Released. Trip Out hole. Break Off Liner Running tool Clean rig Floor P/U Whip Stock Retrieval BHA Trip in Hole With Whipstock Retrieval BHA. T/ 9,710' Up Wt. 230k-Dn Wt. 120k. Fill Pipe, Establish Circulation 53 SPM W/ 535psi. Up Wt. 230k- Dn Wt. 120k. Slack Off T/ 9,785' Latch Up Whip Stock @ 9,783'. Pulled 100k Over Up Wt. No Movement Jarred Up, Took 8 Attempts and sheared out @ 120k Over. Pulled up T/ 9,685' and Flow Check, Circulate Btms Up @ 115 SPM W/ 2,210psi.Pumped 470 bbls. Btms Up Gas 120 units Circulate Additional Btms Up 470 bbls Flow Check ,well static, Trip Out Hole W/ Whipstock. UD Retrieving Tool, Whipstock Assembly and Seal Assembly Clean Rig Floor of Tools and Oil Base R/U Csg Equipment Tongs and Elevators. P/U Hook Hanger Assembly and 2 7/8" Internal Assembly, R/D Csg Tools and Handling Tools Trip In Hole W/ Hook Hanger Assembly Total Assembly Length 227.77' T/1098' Trip in Hole W/ Hook Hanger F/ 1,098' - T/ 9,761' 2 min a stand. Up Wt. 230k, Dn Wt. 130k. @ Window Trip in Hole Tagged @ 9,900 P/U Wt 240. Dn Wt.130k.Pull Back Up T/ Window 9,780' Rotate Pipe 3 Tums Slacked off tagged at 9,883`. Showed on tally 5 1/2" x 8" centralizer On spacerjt @ Window, Worked pipe Through window Tagged @ second Centralizer 78' on Pup above ECP Work Through window, Hooked on window on Depth 9,794' depth of hook P/U rotate Pipe Went down and tagged on 7" x 5 1/2" Cross-over on Depth @ 10,004' pull Back Up Rotate Missed Hoook, Rotate work Torque down Landed on hook pulled back off came right back down hooked window again. on depth 9,794' set down 50k 2x Each time 10-15k over pull coming back off. Pull up break connection drop 29132 Ball. Pump Total of 160 bbls press up to. 800psi. ball .unseated. Pull Up Break connection Dropped 1 3/4 ball press up staged ~ up T/2,700Psi. Ecp started to fill press back up T/2,700psi total amount to fill ecp .8 bbl. Pressure up to 3,500psi Hydrolic release Up Wt. 240k Trip Out Hole W/ Running tool. Lay Down Running tools and 2 7/8 and 2 3!8 Inner string. Clean Rig Floor and clear of Equipment. PJSM on Running L.E.M. running order R/U Tongs, Elevators, and Handling equipment. Make Up seal, LEN, and Packer Assembly, Change Elevators, Clear Floor, Pick up LodTads to Replace worn loadtads, While Tripping in hole. Trip in Hole: 70'-80' Per Min. With L.E.M. Assembly. Replacing Worn LodTads. Trip in Hole: With L.E.M. Assembly remove Worn LodTads Replace with new. T/ 9,748' Total Changed Out 34 LodTads, Up Wt. 235k. Dn Wt. 130k. 12:45 - 16:45 4.00 CMPLTN TRIP CMPLT2 16:45 - 18:00 1.25 CMPLTN PULD CMPLT2 18:00 - 19:00 1.00 CMPLTN OTHR CMPLT2 19:00 - 20:30 1.50 CMPLTN RURD CMPLT2 20:30 - 22:45 2.25 CMPLTN PULD CMPLT2 22:45 - 23:30 0.75 CMPLTN PULD CMPLT2 23:30 - 00:00 0.50 CMPLTN TRIP CMPLT2 18/26/2005 ~ 00:00 - 05:30 05:30 - 09:45 5.501 CMPL 4.251 CMPL TRIP CMPLT2 SOHO CMPLT2 09:45 - 13:30 3.75 CMPLTN TRIP CMPLT2 13:30 - 15:00 1.50 CMPLTN RURD CMPLT2 15:00 - 15:30 0.50 CMPLTN RURD CMPLT2 15:30 - 17:00 1.50 CMPLTN PULD CMPLT2 17:00 - 17:30 0.50 CMPLTN OTHR CMPLT2 17:30 - 00:00 6.50 CMPLTN TRIP CMPLT2 8/27/2005 00:00 - 03:45 3.75 CMPLTN TRIP CMPLT2 Printed: 9/30/2005 6:19:05 AM • • ConocoPhillips Alaska Page 3~ of -~5 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: ROT -DRILLING Start: 6/22/2005 End: 9/10/2005 Contractor Name: D15CM@conocophillips.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 15 Rig Number: 15 -Date From - To I Hours' 8/27/2005 103:45 - 04:15 04:15 - 05:30 Code Code '''.Phase. 0.50 CMPLTNI TRIP I CMPLT2 1.251 CMPLTNI PCKR I CMPLT2 05:30 - 09:45 4.25 CMPLTN TRIP CMPLT2 09:45 - 10:15 0.50 CMPLTN TRIP CMPLT2 10:15 - 10:45 0.50 CMPLTN OTHR CMPLT2 10:45 - 12:00 1.25 RIGMNT RSRV CMPLT2 12:00 - 13:00 1.00 RIGMNT RSRV CMPLT2 13:00 - 14:00 1.00 RIGMNT RGRP CMPLT2 14:00 - 16:15 2.25 WINDO ULD PROD3 16:15 - 17:00 0.75 WINDO ULD PROD3 17:00 - 18:00 1.00 WINDO PULD PROD3 18:00 - 23:45 5.75 WINDO RIP PROD3 23:45 - 00:00 0.25 WINDO OTHR PROD3 8/28/2005 00:00 - 00:45 0.75 WINDO SETW PROD3 00:45 - 01:15 I 0.501 WINDOV'VCIRC I PROD3 01:15 - 07:15 6.00 I WINDOVVSCML PROD3 07:15 - 08:30 1.25 WINDO CIRC PROD3 08:30 - 08:45 0.25 WINDO RIP PROD3 08:45 - 10:00 1.25 RIGMNT RSRV PROD3 10:00 = 12:00 2.00 WINDO RIP PROD3 12:00 - 12:15 0.25 WINDO CIRC PROD3 12:15- 13:30 1.25 WINDO RIP PROD3 13:30 - 15:15 1.75 WINDO ULD PROD3 15:15- 16:00 0.75 WINDO OTHR PROD3 16:00 - 18:00 2.00 DRILL PULD PROD3 18:00 - 22:00 4.001 DRILL TRIP PROD3 22:00 - 22:30 0.50 DRILL OTHR PROD3 22:30 - 00:00 I 1.501 DRILL I DRLG I PROD3 Description of Operations Trip in Hole: With L.E.M. Assembly T/ 9,772' Top of Hook hanger with Seal Jt. Up Wt.235k Dn Wt. 130k. Did not see any weight change, Run in T/ 9,912' set 30k Down pull up 25k Over Pull Release. Slack Back off set 30k Pull 15k over set slips break Jt. Drop Ball. Depth's Mule Shoe @ 9,912', Hanger @ 9,772', Top Of L.E.M. 9,710' Circulate 1 3/4" Ball down T/ Set Packer Press up T/ 3,000psi Hold for 2 min press stayed at 3,000psi. Bleed down. Press up Annulus T/ 500psi to test Packer, Hole @ (4,857'-4,861') LOT 620 Psi. W/ 9ppg. Put 500psi on 9 5/8 annulus bleed Down, Monitor 13 3/8x9 5/8" Annulus started W/ 200psi.(Diesel in Annulus). Press up 9 5!8"x 5" to 500psi. 13 3/8"x 9 5/8" Press climbed to 740psi. Bleed Down 9 5/8 annulus. 13 3/8 x 9 5/8 annulus tracked down with bleed Off. Back T/250psi. Pull up to confirm release, Pulled free set back down 3 times 40k to manually confirm packer set. Up Wt. 230k. Dn Wt. 130k. Trip Out Hole: With L.E.M. Running Tool F/ 9,710' L/D L.E.M. Running Tool, Clear Floor of handling tools Test 13 3/8" x 9 5/8" Rate .5 BPM @ 300psi. Pumped 3 bbls returns at flow nipple. Change Out Saver Sub on Top Drive Rig Service Change Out Low Drum Drawworks Chain (Preventive Maintance) Pick Up seal, Whip stock and Mill Assembly Upload MWD Tools. P/U Remainder BHA and Shallow Test MWD tools. Continue to P/U BHA and shallow test MWD Trip in Hole: W! Whip Stock Assembly and Mill Assembly T/ 9,650' Break circulation and Orientate Whip Stock 16 left. Up Wt. 240k, Dn Wt. 128. Set Anchor (Locator sub at 9,710') W/ 50k, Pulled 10k over 250k insure set. Set 15,000 Torque limit rotate Stall, Worked pipe rotate at free point. Whip Stock set Depth; Top of Window 9412' (TVD 3,274') Bottom of Window, 9,428'. (TVD 3,276') All Markers on Depth. PJSM: Mud Change Out From Solids Free Oil Base To Drilling Oil base Mud, 504 GPM, 2,950psi. When Drilling OBM Clears Bit. Start Milling ,Window. Milling Window, RPM 80-100 (Less vibration on MWD higher RPM), Torq 10-15k, GPM 505, PSI 2,950, WOB 3-6k, Milling Depth Top of Window 9,412', BTM Of Window 9,428' TVD 3,276'. Note; Mud Swap Done @ 02:00. Pump Sweep 130vis, 11 ppg. GPM 600- PSI 3,640', Monitior Well, Trip Out Hole T/ 9,355' Cut and Slip Drill Line, Inspect Brakes, Service Top Drive. Trip Out Hole: F/ 9,335' - T/ 5,807' Pipe came wet, Stop Pump Sweep, Trip Out of Hole: F/ 5,807 - T/ 200' UD Mill BHA, Upper Mill in Gauge, P/U stack washer and wash out B.O.P. Pick Up Drilling BHA, Surface Test MWD, GPM 500, PSI 440, P/U Total BHA. TIH W/ 5" D.P. F! DERRICK FILLING EVERY 25 STANDS TO 9396' ORIENT TOOL FACE TO 16L STOP PUMP AND SLIDE THROUGH WINDOW 9412' TO 9431' START PUMPS Directional Drill 8 1/2" D Lateral sands: W/ 1.5 Motor: F/ 9,448' T/ Printed: 9/30/2005 6:19:05 AM • • ConocoPhilJips Alaska Page 3Tof 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To Hours ~ Code Code. Phase 8/28/2005 22:30 - 00:00 ~ 1.50 DRILL ~ DRLG I PROD3 8/29/2005 ~ 00:00 - 05:45 I 5.751 DRILL I DRLH PROD3 05:45 - 07:15 i 1.501 DRILL I REAM PROD3 07:15 - 07:30 0.25 DRILL TRIP PROD3 07:30 - 08:15 0.75 DRILL CIRC PROD3 08:15 - 08:30 0.25 DRILL OBSV PROD3 08:30 - 12:00 3.50 DRILL TRIP PROD3 12:00 - 13:45 1.75 .DRILL PULD PROD3 13:45 - 14:00 0.25 DRILL OTHR PROD3 14:00 - 17:00 3.00 DRILL PULD PROD3 17:00 - 17:30 0.50 DRILL SFTY PROD3 17:30 - 18:00 0.50 DRILL PULD PROD3 18:00 - 22:45 4.75 DRILL TRIP PROD3 22:45 - 23:00 0.25 DRILL TRIP PROD3 23:00- 00:00 1.00 DRILL REAM PROD3 8/30/2005 00:00 - 01:30 1.50 DRILL OTHR PROD3 01:30 - 06:00 06:00 - 12:00 12:00 - 18:00 18:00 - 00:00 8/31 /2005 100:00 - 03:00 4.501 DRILL DRLG I PROD3 6.00 i DRILL i DRLG PROD3 6.00 i DRILL i DRLG I PROD3 6.00 i DRILL i DRLG I PROD3 3.001 DRILL I DRLG I PROD3 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005. Group: Rig Number: 15 Description of Operations 9,678' Up Wt. 195k Dn Wt. 115k Rot Wt. 125k GPM 508 PSI 2,965 RPM 50 Tq On BTM 10K Tq Off BTM 8K JAR HRS 1.0 ADT .59 AST .41 BIT HRS 1.0, Directional Drill 8 1/2" D Lateral sands: W/ 1.5 Motor: F/ 9,678' - T/ 10,154' (3,279 TVD) Up Wt. 195k Dn Wt. 115k Rot Wt. 125k GPM 508 PSI 2,965 RPM 80 Tq On BTM 12K Tq Off BTM 9K JAR HRS 4.70 ADT 3.42 AST 1.24 BIT HRS 4.70, Pump Sweep 30% increase at shakers, Back Ream Out Hole: F/ 10,154' - T/ 9,491' Check Shots every 100', Up Wt. 185k, Dn Wt 115k, Rot Wt. 135, Torq. 11k, RPM 80, GPM 500, PSI 2,870, Trip Out Hole: F/ 9,491' - T/ 9,301' Circulate: Clean Hole @ GPM 550, PSI 3,100, Pumped Total 480bb1s. Monitioor Well: Pump Dry Job Trip Out Hole: F/ 9,301' - T/ 350' UD BHA # 21 and download MWD. Clear and Clean Rig Floor. P/U BHA # 22 Geo-Pilot; Up link LWD and shallow Test Tools. PJSM: Handling and loading of Nuetron and Gamma Sources and Install. P/U BHA # 22 Flex Collars, Jars and Hwt Dp. Total 292.89 Trip in Hole: Fill every 25 stands, T/ 9,360' Fill Pipe, set Deflection, Go Through window (9,412'-9,428'). Ream F/ 9,480' - T/ 10,051' Pump Sweep 30 bbl 11 ppg 146 vis Reamed F/ 10,051' Tagged at 10,060', Took Wieght went T/ 10,065' Picked Up to verify Depth,( Depth is correct). Look at logs and Drilling slide sheet. Started Drilling @ 10,060' Old logs and Tag coralate With being 95' off of Motor Run. Directional drill 8 1/2" "D" lateral sands f/ 10,060' to 10,486' (3267' TVD) ART 3.17 hrs, w/ Sperry Sun Geo-Pilot, 4-9k WOB, 120 rpm's, 600 gpm, 9.0 ppg mw, on bottom pressure 3100 psi, off bottom pressure 3015 psi, on bottom torque 13-16k ft/Ib, off bottom torque 15k ft/Ib, PU wt 190-195k, Dn Wt 98-95k ,Rot wt 140-138k. Directional drill 8 1/2" "D" lateral sands f/ 10,486' to 10,939' (3267' TVD) ART 3.52 hrs, w/ Sperry Sun Geo-Pilot, 10-20k WOB, 120 rpm's, 600 gpm, 9.0 ppg mw, on bottom pressure 3150 psi, off bottom pressure 3120 psi, on bottom torque 15-17k ft/Ib, off bottom torque 15-16k ft/Ib, PU wt 200k, Dn Wt 95k ,Rot wt 135k. ECD 11.22ppg Directional drill 8 1/2" "D" lateral sands f/ 10,939' to 11,500' (3262' TVD) ART 4.3 hrs, w/ Sperry Sun Geo-Pilot, 10k WOB, 120 rpm's, 600 gpm, 9.0 ppg mw, on bottom pressure 3190 psi, off bottom pressure 3110 psi, on bottom torque 15-17k ft/Ib, off bottom torque 17-21k ft/Ib, PU wt 202k, Dn Wt 90k ,Rot wt 130k. ECD 11.63ppg. Pumped Hi-vis weighted to 11.0 ppg sweep @ 11240' f/ ECD's. Note: Vetco/Gray tested 13 3/8" x 9 5/8" packoff to 4200 psi f/ 15 min. OK. Directional drill 8 1/2" "D" lateral sands f/ 11,500' to 12,127' (3257' TVD) ART 3.95 hrs, w/ Sperry Sun Geo-Pilot, 7-17k WOB, 120 rpm's, 600 gpm, 9.0 ppg mw, on bottom pressure 3200-3320 psi, off bottom pressure 3100-3280 psi, on bottom torque 14-20k ft/Ib, off bottom torque 14-20k ft/Ib, PU wt 210-215k, Dn Wt 85-90k ,Rot wt 135k. ECD 11.7 ppg. Pumped Hi-vis weighted to 11.0 ppg sweep @ 12050' f/ ECD's. Directional drill 8 1/2" "D" lateral sands f/ 12,127'to 12,405' (3253' TVD) Printed: 9/30/2005 6:'19:05 AM • 03:00 - 05:30 ConocoPhillips Alaska Page 38 of 45 .Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 18/31/2005 100:00 - 03:00 19/1/2005 05:30 - 06:00 06:00 - 12:00 1 E-170 1 E-170 ROT -DRILLING D15CM@conocophillips.com Doyon 15 Hours I Code i Code ~ Phase 3.00 ~ DRILL DRLG I PROD3 2.501 RIGMNT RGRP I PROD3 0.50 RIGMNT RGRP PROD3 6.00 DRILL DRLG PROD3 12:00 - 18:00 I 6.00 DRILL DRLG I PROD3 18:00 - 00:00 I 6.001 DRILL I DRLG I PROD3 00:00 - 06:00 I 6.00 f DRILL i DRLG I PROD3 06:00 - 12:00 I 6.001 DRILL I DRLG I PROD3 Spud Date: 6/26/2005 Start: .6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations ART 1.98 hrs, w/ Sperry Sun Geo-Pilot, 5-10k WOB, 120 rpm's, 600 gpm, 9.0 ppg mw, on bottom pressure 3270-3320 psi, off bottom pressure 3250-3200 psi, on bottom torque 14-19k ft/Ib, off bottom torque 14-18k ft/Ib, PU wt 210-215k, Dn Wt 85-90k ,Rot wt 135k. ECD 11.6 PPg• Back ream f/ 12,405' to 11,745' w/ 454 gpm and 2000 psi, w/ 120rpm, 15-17k torque. Pulling @ 6-7 ft/min. Working on # 2 mud pump liner gasket. RIH from 11,745' to 12,405' w/ no problems Directional drill 8 1/2" "D" lateral sands f/ 12,405' to 12,816' (3255' TVD) ART 4.08 hrs, w/ Sperry Sun Geo-Pilot, 10-20k WOB, 120 rpm's, 600 gpm, 9.0 ppg mw, on bottom pressure 2990-3300 psi, off bottom pressure 3240-3200 psi, on bottom torque 15-19k ft/Ib, off bottom torque 14-19k ft/Ib, PU wt 210-205k, Dn Wt 80-82k ,Rot wt 135-140k. ECD 1.1.6-1.1.8 ppg. Pumped 11.0 ppg hi vis sweep @ 12050' and 12,780', 30% increase in cuttings returns. Directional drill 8 1/2" "D" lateral sands f/ 12,816' to 13510' (3237' TVD) ART 3.98 hrs, w/ Sperry Sun Geo-Pilot, 10-15k WOB, 120 rpm's, 600 gpm, 9.0 ppg mw, on bottom pressure 3350-3460 psi, off bottom pressure 3210-3310 psi, on bottom torque 16-19k ft/Ib, off bottom torque 16-20k ft/Ib, PU wt 210k, Dn Wt 85-80k ,Rot wt 142-135k. ECD 11.8-11.95 ppg. Directional drill 8 1/2" "D" lateral sands f/ 13510' to 14199' (3221' TVD) ART 3.78 hrs, w/ Sperry Sun Geo-Pilot, 6-12k WOB, 120-140 rpm's, 600 gpm, 9.0 ppg mw, on bottom pressure 3550-3720 psi, off bottom pressure 3500-3650 psi, on bottom torque 19k ft/Ib, off bottom torque 18-20k ft/Ib, PU wt 215-230k, pn Wt 80- 70k ,Rot wt 135-132k. ECD 12-12.4 PPg• Pumped weighted hi vis sweep @ 13,640' and 14,110', no increase in cuttings retums. Directional drill 8 1/2" "D" lateral sands f/ 14199' to 14780' (3209' TVD) ART 3.43 hrs, w/ Sperry Sun Geo-Pilot, 6-12k WOB, 140 rpm's, 600 gpm, 9.0 ppg mw, on bottom pressure 3690-3890 psi, off bottom pressure 3650-3800 psi, on bottom torque 19-20k ft/Ib, off bottom torque 18-20k ft/Ib, PU wt 220k, Dn Wt 75-70k (block wt 70k) ,Rot wt 128-135k. ECD 12.4-12.6 ppg. Pump 11.0 ppg 140 vis sweep @ 14464' w/ no increase in cuttings. All 83 Lo tads in hole, started HWDP @ 14594'. Directional drill 8 1/2" "D".lateral sands f/ 14780' to 15405' (3194' TVD) ART 3.78 hrs, w/ Sperry Sun Geo-Pilot, 6-20k WOB, 140 rpm's, 600 gpm, 9.0 ppg mw, on bottom pressure 3890-4140 psi, off bottom pressure 3800-4030 psi, on bottom torque 19-21 k ft/Ib, off bottom torque 18-21 k ft/Ib, PU wt 220-235k, Dn Wt 70k (block wt 70k) ,Rot wt 135-138k. ECD 12.6-12.8 ppg. Pump 11.0 ppg 140 vis sweep @ 15116' MD w/ 10% increase in cuttings. 12:00 - 15:30 3.50 DRILL DRLG PROD3 Directional drill 8 1/2" "D" lateral sands f/ 15405' to 15748' (3185' TVD) ART 1.94 hrs, w/ Sperry Sun Geo-Pilot, 10-15k WOB, 140 rpm's, 600 gpm, 9.0 ppg mw, on bottom pressure 4140-4260 psi, off bottom pressure 4030-4260 psi, on bottom torque 20-23k ft/Ib, off bottom torque 18-21 k ft/Ib, PU wt 235-2455k, Dn Wt 70k (block wt 70k) ,Rot wt Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska Page 39 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: ROT -DRILLING Start: 6/22/2005 End: 9/10/2005 Contractor Name: D15CM@conocophillips.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 15 Rig Number: 15 Date ~ From - To Hours ~, Code' Code Phase ' Description of Operations 9/1/2005 12:00 - 15:30 3.50 ~ DRILL DRLG PRODS 135-142k. ECD 12.6-12.8 ppg. 15:30 - 15:45 I 0.251 DRILL I CIRC I PRODS 15:45 - 18:00 2.251 DRILL REAM I PRODS 18:00 - 00:00 I 6.001 DRILL I REAM I PRODS 9/2/2005 00:00 - 03:00 3.00 DRILL REAM PRODS 03:00 - 05:30 2.50 LOG DLOG PRODS 05:30 - 06:00 0.50 DRILL TRIP PRODS 06:00 - 08:00 2.00 DRILL CIRC PRODS 08:00 - 08:45 08:45 - 09:45 09:45 - 14:00 14:00 - 14:15 14:15 - 14:45 14:45 - 16:30 16:30 - 16:45 16:45 - 18:00 18:00 - 19:00 19:00 - 20:30 20:30 - 22:00 22:00 - 22:15 22:15 - 23:15 23:15 - 00:00 9!3/2005 00:00 - 00:45 00:45 - 01:30 01:30 - 06:00 0.75 RIGMNT RSRV PRODS 1.00 RIGMNT RSRV PRODS 4.25 DRILL TRIP PRODS 0.25 DRILL REAM PRODS 0.50 DRILL CIRC PRODS 1.75 RIGMNT RGRP PRODS 0.25 RIGMNT RGRP PRODS 1.25 DRILL REAM PRODS 1.00 DRILL REAM PRODS 1.50 DRILL CIRC PRODS 1.50 DRILL CIRC PRODS 0.25 DRILL CIRC PRODS 1.00 DRILL CIRC PRODS 0.75 DRILL TRIP PRODS 0.75 DRILL TRIP. PRODS 0.75 DRILL TRIP PRODS 4.50 DRILL TRIP PRODS 06:00 - 09:30 3.50 DRILL TRIP PRODS 09:30 - 10:00 0.50 DRILL PULD PRODS 10:00 - 10:30 0.50 DRILL SFTY PRODS 10:30 - 12:00 1.50 DRILL OTHR PRODS 12:00 - 13:00 1.00 DRILL PULD PRODS 13:00 - 14:00 1.00 CMPLTN RURD CMPLT3 Pump 11.0 ppg 140 vis sweep @ 15702' w/ 30% increase in cuttings. Circ on bottom @ 15748' (3185' TVD) @ 600 gpm w 4240 psi, 140 rpm to move cuttings above BHA. Pump up survey @ 15745'. Backream f/ TD @ 15748' to 14597' @ 600 gpm w/ 4240- 4100 psi, rotate @ 120 rpm, torque 18k ft/Ib. Rotating weight 125k w/ pumps on. Pulling speed 30-40 ft/min. Continue backream f/ TD @ 15748' to 11437' @ 600 gpm w/ 4100-3120 psi, rotate @ 120-180 rpm, torque 18-16k ft/Ib. PU wt 205-190k. SO wt 85k-98k .Pulling speed 30-40 ft/min. Continue backream f/ 11437'- 9850' @ 600 gpm w/ 3120-3000 psi, rotate @ 180 rpm, torque 16k ft/Ib. Pulling speed 30-40 ft/min. PU wt 180k, SO wt 100k, Rot wt 128k. Record PU & SO wt's. Mad Pass logging f/ 9850' to 9502' bit depth. Logging tool depth 9763' to 9495'. Pumping 600 gpm w/ 2950 psi, 120 rpm, torque 12k. Pull BHA f/ 9502', thru window (9428'-9412'), then up to 9360'. Circ 45 bbls weighted 11 ppg 140 vis sweep, follow w/ 3 bottoms up (1600 bbls), Rotate 120 rpm, 600 gpm w/ 2960 psi. Slip and cut 109' drilling line. Inspect brake bands. Service. rig and top drive. Trip in hole on elevators f/ 9360' to 15702'. Pu wt 215k, SO wt 90K. No problems. Fill pipe every 20 stands. Record PU SO wt's. MU top drive, establish circ, precautionary ream fl 15702'- TD @ 15748'. Pump @ 580 gpm w/ 4190 psi. Circ total of 180 bbls when stand pipe "Y" leaked on rig floor. Blow down mud line. POOH slow while repair leak on stand pipe. POOH f/ 15748' to 14700'. PU wt 260k, SO wt 70k (block wt 70k). Pressure test stand pipe to 4000 psi. OK. Ream in hole f/ 14700' to 15428'. Pump 500 gpm w/ 3800 psi, 120 rpm. Finish reamin back to bottom f/ 14700' to 15748'. Pump 460 gpm w/ 3100 psi, 120 rpm. Torque 12-20k. Circ BU prior to displacing well f/ 9.0 ppg oil base mud to solids free oit base mud. PJSM w/ vac drivers, rig crew and mud engr while circ. Pump 35 bbls spacer, follow w/8.9+ solids free oil base mud. Pump total of 1094 bbls solids free. Shut down. Line up pits to take returns. Take slow pump rates. Continue circ solids free total of 668 bbls pumped. Circ 600 gpm w/ 4200 psi. Monitor well. Drop 2.00" rabbit, POOH. f/ 15748' to 14689'. PU wt 300k, SO wt 70K= block wt POOH F/ 14689' to 13990'. Air boot leaking on flow line. @ BOP riser. POOH F/ 13990' to 13865' slowly while working to replace air boot on flowline. Changed out (2) 12" air boots. POOH F/ 13865' to 7480'. Ghost reamer and BHA came through window w/ no problems. Monitor well @ window- static. PU wt 220k, SO wt 85k. POOH F/ 7480' to 292'. PU wt 230k, SO wt 85k. UD HWDP, jars and flex collars. PJSM on unloading nuke sources. Remove sources. Download MWD/LWD tools. UD tools. Continue UD tools. Clear floor of handling tools, change elevators, hold PJSM on running Printed: 9/30/2005 6:19:05 AM • • ConocoPhillips Alaska Page 4o''of ~5' Operations. Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 I Sub I Date "From - To Hours ~ Code Code Phase 9/3/2005 14:00 - 18:00 I 1.00 CMPLTN RURD CMPLT3 4.00 CMPLTN RUNT CMPLT3 18:00 - 19:00 1.00 I CMPLTNI RUNT I CMPLT3 19:00 - 23:00 I 4.00 I CMPLTNI TRIP CMPLT3 23:00 - 00:00 1.00 I CMPLTNI TRIP I CMPLT3 19/4/2005 100:00 - 06:00 I 6.00 CMPLTNI TRIP I CMPLT3 06:00 - 07:15 I 1.251 CMPLTNI TRIP CMPLT3 07:15 - 08:30 I 1.251 CMPLTNI TRIP I CMPLT3 08:30 - 09:00 ~ 0.501 CMPLTNI OTHR CMPLT3 09:00 - 10:00 I 1.001 CMPLTNI CIRC I CMPLT3 10:00 - 12:00 2.00 CMPLTN TRIP CMPLT3 12:00 - 12:45 0.75 CMPLTN OTHR CMPLT3 12:45 - 14:15 1.50 CMPLTN TRIP CMPLT3 14:15 - 16:00 1.75 FISH PULD CMPLT3 16:00 - 20:15. 4.25 FISH TRIP CMPLT3 20:15 - 20:45 I 0.501 FISH l FISH I CMPLT3 20:45 - 21:00 I 0.251 FISH I TRIP CMPLT3 Spud Date: 6/26/2005 Start: 6/22/2005. End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations liner, RU to run liner. Clean floor. Run 5 1/2" "D" lateral completion liner to 6004' (5 1/2" guide shoe, 1 jt 5 1/2" BTCM 15.5 ppf L-80 blank jt, 1 jt 5 1/2" 15.5 BTCM L-80 slotted jt w/ insert packoff @ pin end, 138 jts 5 1/2" BTCM 15.5 ppf L-80 slotted pipe). 120k PU wt, 110K SO wt. Torque rings installed in all connections. Continue PU/MU/Run 5 1/2" "D" lateral completion liner f/ 6004' to 6127'. Run 1 5 1/2" BTCM 15.5 ppf L-80 blank pup jt, 1 5 1/2" BTCM 15.5 ppf L-80 blank jt, 7" BTC box x 5 1/2" BTCM pin crossover, 1 jt 7" BTCM 26 ppf L80 blank jt, 1 7" BTCM 26 ppf L-80 blank pup jt, Baker 7" "HR" liner setting Sleeve, Baker running tool. PU wt 125k, SO wt 80k, Block wt 70k. Torque rings installed in all connections. Run liner in hole on 5" dp. Run 5 stands slick, 62 stands w/ to-tads= 67 stands total dp. Record UP/Down and rotating weights. @ 6223', 7099', 8089', 8584', 9079', 9376', 10067, 10561', 11056', 11551',.12045`, 12539'. PU wt 205k, SO wt =block wt 70K, rot wt 145k. Started rotating 5 1/2" liner in hole @ 12605' w/ 25RPM, 14k torque, string speed 5'/min. Rotate to 12735'. Rotating 5 1/2" liner in hole f/ 12735' to' 14197'w/ 25RPM, 16k torque, string speed 5-10'/min. Recording PU/SO/ Rotating weight @ 13031', 13525', 14012`. PU wt 240k, S0= block wt 70k, rotation 110k w/ slacking off. Rotating 5 1/2" liner in hole f/ 14197' to' 15748' w/ 25RPM, 16k torque, string speed 10-15'/min. Recording PU/SO/ Rotating weight @ 14475' and 14844'. Rotating 5 1/2" liner in hole f/ 14844'- 15748', w/ 25 rpm, 15k torque,string speed 45'/min- 60'/min. Recording PU/SO/ Rotating weight @ 15388' and TD 15748'. PU wt 290K, SO wt 80k, block wt 70k. Tag bottom w/ liner @ 15748' rotating w/ 25RPM. Drop 29/32" ball. Put pipe on depth wi shoe @ 15736'. Note: Liner was run w/ 5 stands 5" slick dp (476.27'), 74 stands 5" dp w/ IoTads (7316.41'), then 20 stands 5" HWDP (1834.71'), 19' left above Rig floor. Baker guide shoe @ 15, 736.14', top of Baker "HR" setting sleeve @ 9612.71'. Circ 29/32" ball down @ 5bpm w/ 800 psi., slow to 3 bpm w/ 340 psi, pressure to 2400 psi to release liner. Pumped total of 152 bbls 8.9+ SFOBM. Pressure to 4080 psi to blow ball seat. PU to verify liner release. PU wt 245k. SO to check liner depth. Top of "D" lateral Baker 7" liner sleeve @ 9612.71'. POOH w/ Baker liner running tools f/ 9612' to 4500'. Monitor well Continue POOH f/ 4500'. Clear rig floor of tools. PU Baker Whipstock retieving tools to floor, Make up Baker rertieving hook, 1 jt 5" HWDP, Sperry sun float sub, Baker bumper sub, Baker fishing jar. Total Inth of BHA 62.08'. RIH on 5 stands 5" slick dp, 83 stands 5" dp w/ to tads, 8 stands of HWDP. Fill pipe every 25 stands. PU wt 230k, SO wt110K. Slack off to find keyhole in whipstock @ 9418'. Work/ orient and rotate pipe several times, jar @ 290k, pull to 310, work up to 340K to pull free. Pipe movement @ 300k. Pull top of whipstock f/ 9418' to 9388'. Whipstock assembly consists of Whipstock slide, debris sub, ported sub, shear disconnect, bottom trip Printed: 9/30/2005 6:19:05 AM • • ConocoPhillips Alaska Page 41"of 45 Operations Summary Report Legal Well Name:. 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 -Date From - To ~ Hours ode 'f Sub ~ Phase Code 9/4/2005 20:45 - 21:0 0.251 FISH TRIP I CMPLT3 21:00 - 23:15 I 2.251 FISH I CIRC I CMPLT3 23:15 - 00:00 0.75 FISH TRIP CMPLT3 9/5/2005 00:00 - 06:00 6.00 FISH TRIP CMPLT3 06:00 - 07:00 1.00 FISH TRIP CMPLT3 07:00 - 07:15 0.25 FISH SFTY CMPLT3 07:15 - 08:00 -0.75 FISH PULD CMPLT3 08:00 - 09:00 1.00 I FISH I PULD I CMPLT3 09:00 - 09:15 0.25 CMPLTN SFTY CMPLT3 09:15 - 10:30 1.25 CMPLTN RURD CMPLT3 10:30 - 11:15 0.75 CMPLTN RUNT CMPLT3 11:15 - 11:30 0.25 CMPLTN RURD CMPLT3 11:30 - 12:00 0.50 CMPLTN RUNT CMPLT3 12:00 - 12:45 0.75 CMPLTN RUNT CMPLT3 12:45 - 13:15 ~ 0.50 ~ CMPLTNI PULD ~ CMPLT3 13:15 - 18:00 4.751 CMPLTNI RUNT CMPLT3 18:00 - 18:45 0.751 CMPLTNI RUNT CMPLT3 18:45 - 19:30 I 0.751 CMPLTNI TRIP CMPLT3 19:30 -20:15 I 0.751 CMPLTNI TRIP I CMPLT3 Start: 6/22!2005 Rig Release: 9/10/2005 Rig Number: 15 Spud Date: 6/26/2005 End: 9/10/2005 Group: Description of Operations anchor, blank sub, (8) jts 5" dp, 5" pup jt (4.18', unloader sub, locator sub, seal assembly w/ bull nose. Total length of whipstock assembly 298.06' Circ 2 bottoms up @ 8 bpm w/ 1000 psi. Get slow pump rates. Circ total 997 bbls. Blow down top drive. PU wt 220-260k. POOH slowly (20ft/min) f/ 9684' (bottom of fish) to 9136' Continue POOH slowly(30-45 ft/min) with whipstock assembly from 9136' to 1135'. Continue POOH slowly(30-45 ft/min) with whipstock assembly from 9136' to 362'. PJSM w/ Baker rep, rig crew and CPAI rep on laying down whipstock assembly. UD-Jars, bumper sub, float sub, jt of 5"HWDP, hook. Secure whipstock slide @ rotary table. UD Baker whipstock slide, debris sub, ported sub, shear disconnectm bottom trip anchor, blank sub. UD 8 jts 5" dp, 5" pup jt, unloader sub, locator sub, seal assembly w/ bull nose. Clear rig floor of tools. PJSM on running Baker hook Hanger assembly. RU to run Baker hook Hanger assembly. RU to run Baker hook Hanger assembly consisting of: (1) jt 5 1/2" 15.5 ppf L-80 BTCM bent joint, (1) jt 5.5" BTCM 15.5ppf L-80 , (1) 5.5" BTCM 15.5 ppf L-80 pup jt, Baker Pay Zone external casing Packer, (3) 5.5" BTCM 15.5 ppf L-80 pup jt, (2) jts 5 1/2" BTCM 15.5 ppf L-80, (1) 5.5" BTCM 15.5 ppf L-80 pup jt, crossover bushing, Baker 9 5/8" x 7" Model B-1 Hook Hanger f/ LEM. Total length = 250.31' to leave in hole. Torque to 5k, install (2) 5 1/2" x 8 1/4" x 8" straight blade centralizers on pup jt above handling pup on ECP and pup below ECP. PU 2 7/8" handling tools to floor, RU same. MU 2 7/8" inner string per Baker rep. Total length 217'. Change out elevators and MU Baker 9 5/8" x 7" Model B-1 hook hanger. Change out elevators. MU crossover to 5" drill pipe. Clear rig floor of casing tools. RIH w/ hook hanger (70 feet per min) on 5". Run (5) stands slick 476.27', (74) stands 5" DP w/ LoTads 7316.41', (8) stands 5" HWDP 739.24'= total depth of 8789'. Continue RIH w/hook hanger (70 feet per min) on 5". Run (5) stands slick 476.27', (74) stands 5" DP w/ LoTads 7316.41', (19) stands 5" 'HWDP 1741.95' = 9791.98' w/ 60.6' up = 9731'. Tag up on crossover in "B" lateral (2.5' deep). POOH 4 stands f/ 9731' to 9412'. Screw into stand #94, PU w/ mule shoe 5' above window. Rotate 4 rounds to right w/ max torque 10k ft/Ib. Hold torque, slack off, hit bottom of window with centralizer 90' in on stand#95. This puts bottom of window 4' deep. PU, work pipe until centralizer went through.. Continue in hole, hit top centralizer 35.5' in on stand #96 Work centralizer to get by window. (window 4' deep) Hook window @ 9433 w/ baker hook hanger. PU stand #97. PU wt 255k, SO wt 120k. Slackoff, tag mule shoe60' in on stand #97. Pickup 20', rotate 3 rounds to right, max torque 8k ft/Ibs, work pipe & slack off,tag crossover @ 60' in. Pickup, rotate one round, work pipe, slackoff. Hang hook hanger 55' in on stand #97 w/ 40k down. PU 15', rotate 3 rounds to right, max torque 8k ft/Ib.Slackoff & tag crossover 60' Printed: 9/30/2005 6:19:05 AM • C ConocoPhillips Alaska Page 42''of 45 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 1 E-170 1 E-170 Spud Date: 6/26/2005 ROT -DRILLING Start: 6/22/2005 End: 9/10/2005 D15CM@conocophillips.com Rig Release: 9/10/2005 Group: Doyon 15 Rig Number: 15 i Date From - To Hours Code ,Code .Phase 9/5/2005 119:30 - 20:15 0.75 CMPLTN TRIP ~ CMPLT3 20:15 - 20:45 I 0.50 I CMPLTNI OTHR I CMPLT3 19/6/2005 20:45 - 21:30 I 0.751 CMPLTNI CIRC I CMPLT3 21:30 - 00:00 2.50 CMPLTN TRIP CMPLT3 00:00 - 02:00 2.00 CMPLTN TRIP CMPLT3 02:00 - 02:15 0.25 CMPLTN SFTY CMPLT3 02:15 - 02:30 0.25 CMPLTN OTHR CMPLT3 02:30 - 03:30 1.00 CMPLTN PULD CMPLT3 03:30 - 04:30 1.00 CMPLTN PULD CMPLT3 04:30 - 04:45 0.25 CMPLTN SFTY CMPLT3 04:45 - 06:00 1.25 CMPLTN PULD CMPLT3 06:00 - 06:45 0.75 CMPLTN PULD CMPLT3 06:45 - 07:00 0.25 CMPLTN PULD CMPLT3 07:00 - 07:15 0.25 CMPLTN OTHR CMPLT3 07:15 - 12:45 5.50 CMPLTN TRIP CMPLT3 12:45 - 13:00 0.251 CMPLTNI TRIP I CMPLT3 13:00 - 13:15 I 0.251 CMPLTNI OTHR I CMPLT3 13:15 - 13:45 I 0.501 CMPLTNI CIRC I CMPLT3 13:45 - 14:00 0.251 CMPLTNI PCKR I CMPLT3 14:00 - 14:15 I 0.251 CMPLTNI OTHR I CMPLT3 Description'of Operations in. PU 20', rotate 2 rounds to right with max torque 7k ft/Ib. Work pipe and slackoff, tag crossover 60' in. PU 20', rotate one round, max torque 6k ft/Ib. Work pipe. Slack off, hung hook hanger@ 55' in, set down 40k. PU, took 20k overpull to unhook hanger. Slack off. Hooked @ 55' in w/ 40k down wt. (5' deep) Drop 29/32" ball, fill pipe then pumped 6 bbls & pressured up. Stopped pumping @ 1800 psi. Bleed off, pressure to 1500 psi. Zero stroke counter. Pressure up to 2000 psi w/ 3 strokes. Pressure up to 2500 psi w/ 3 more strokes. pressure to 2800 psiw/ 2 more strokes. Pressure to 2900 psi w/ 2 more strokes and ECP opened. Allow pressure to bleed back to 2700 psi & held pressure. Pressure back up to 2500 psi w/ 3 strokes (.3 bbls to inflate). Pressure up to 4000 psi, bleed off pressure. PU to Free travel @ 250k. Pull 2 stands to 9246'. Circulate @ 5bpm w/ 400 psi, circ 100 bbls. POOH w/ hook hanger running tools. f/ 9260' to 4493'. POOH w/ hook hanger running tools f/ 4493' to BHA inner string PJSM on L/D inner string 2 7/8" Clean rig floor. L/D 2 7/8" inner string. Clear floor of tools. PU tools to PU 4 1/2" LEM. PJSM on running 4 1/2" LEM f/ "D" lateral. PU/MU 4 1/2" LEM consisting of :Baker seal assembly, (1) jt 4 112" 12.6 ppg L-80 IBT x STL, (7) jts 4 1/2" 12.6ppf L-80 IBTM tubing, 4 1/2" pup jt, LEM, (3) 4 1/2" pup jts, 4 1/2" casing swivel, crossover bushing 5 1/2 563 x 4 1/2" IBT, 190-47 casing seal bore, crossover 7" x 5 1/2" 563, (1) jt 7" 26 ppf, L80 Hydril 563 casing Make up 2 7/8" inner string to 9 518" x 7" ZXP liner top packer. Make up 9 5/8" x7" ZXP liner top packer, Check screws. OK. Clean rig floor, remove csg tools. RIH on 5" dp : 4 1/2" LEM consisting of :Baker seal assembly, (1) jt 4 1/2" 12.6 ppg L-80 IBT x STL, (7) jts 4 1/2" 12.6ppf L-80 IBTM tubing, 4 1/2" pupjt, LEM, (3) 4 1/2" pupjts, 4 1/2" casing swivel, crossover bushing 5 1/2 563 x 4 1/2" IBT, 190-47 casing seal bore, crossover 7" x 5 1/2" 563, (1) jt 7" 26 ppf, L80 Hydril 563 casing, Baker 9 5/8" x 7" ZXP liner top packer = 430.62' then Baker setting tool and 5' dp pup jt. Total of 441.59'. RIH 5 stands 5" slick (476.27', 74 stands 5" dp w/ to-tads (7316.41'), 12 stands 5" HWDP(1105.62') w/ 21.1' up. PU wt 230k, SO wt 120k. Slack off watching top of "D" lateral @ 9412.28' (did not see anything), Continue running stands of HWDP f/derrick. Run stand 92, 93,94,95, and 96. PU wt 245k, SO wt 125k. Continue RIH w/ stand 96 (17th stand of HWDP). Did not see crossover in "B" lateral @ 21' in (9728'),.continue slack off to latch @ 37' in on stand 96 (9739' mule shoe depth) (9412,28' top of LEM in hook hanger of "D" lateral). Top of Casing seal receptacle in "B" lat LEM a 9729.91', bottom of casing seal receptacle @ 9749.31'. PU to 265k to verify latch. Drop 1 3/4" ball, pump down @ 5bpm w/ 500 psi f/ 100 bbls, slow to 3 bpm 300 psi, ball seated @ 120 bbls pumped. Pressure up to 3080 psi, set Baker ZXP packer @ 9308.62', presure to 4000 psi to release. PU, PU wt 240K-245K (verified release). PU 20' f/ 9308' to 9288'. Slack off 40k down w/ dogs to mech set packer as well. PU 20' rotate down w/ 40k on liner top pkr twice. Printed: 9/30/2005 6:19:05 AM • ConocoPhillips Alaska '' Page 43'of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: ROT -DRILLING Start: 6/22/2005 End: 9/10/2005 Contractor Name: D15CM@conocophillips.com Rig Release: 9/10/2005 Group: Rig Name: Doyon 15 Rig Number: 15 Date ~ From'- T 9/6/2005 114:15 - 16:00 16:00 - 22:00 22:00 - 22:30 Hours ~ Cade [Code 'Phase'>~ 1.751 CMPLTNI TRIP I CMPLT3 6.00 RIGMNT RGRP CMPLT3 0.50 CMPLTN TRIP CMPLT3 22:30 - 00:00 I 1.501 CMPLTNI TRIP CMPLT3 9/7/2005 00:00 - 03:00 3.00 CMPLTN TRIP CMPLT3 03:00 - 03:15 0.25 CMPLTN SFTY CMPLT3 03:15 - 04:00 0.75 CMPLTN PULD CMPLT3 04:00 - 05:00 1.00 CMPLTN OTHR CMPLT3 05:00 - 05:15 0.25 CMPLTN SFTY CMPLT3 05:15 - 06:00 I 0.751 CMPLTNI PULD. I CMPLT3 06:00 - 08:45 2.751 CMPLTNI PULD CMPLT3 08:45 - 13:45 I 5.00 I RIGMNTI RGRP I CMPLT3 13:45 - 14:45 1.00 RIGMNT RSRV CMPLT3 14:45 - 15:15 0.50 CMPLTN PULD CMPLT3 15:15 - 18:00 I 2.751 CMPLTNI PULD CMPLT3 18:00 - 19:45 I 1.751 CMPLTNI PULD I CMPLT3 19:45 - 20:00 I 0.251 CMPLTNI OTHR I CMPLT3 20:00 - 20:30 0.501 CMPLTNI PCKR I CMPLT3 20:30 - 21:00 I 0.50 CMPLTNI PCKR I CMPLT3 21:00 - 23:00 4 2.001 CMPLTNI CIRC I CMPLT3 Description' of Operations Monitor well, POOH w/ running tools f/ LEM f/ 9308' to 8135'. PU wt 245k, SO wt 120k. Attempt to break out 1st stand LoTad. High torque 30k. Broke 1st Lo Tad w/ rig tongs w/ 30K. Repair/ replace top cylinder of iron roughneck breakout. POOH f/ 8135 to 7938'. Check out Iron roughneck by making breaks on stand 78, OK. Break & UD LoTad f/ stand 78. Pull stand 79, break and lay down LoTad f/ stand simulating laying down dp f/derrick and removing LoTads. OK. Continue POOH f/ 7938' to 5964'. 51 stands Lotads in hole @ midnight Continue POOH f/ 5964' to 80' 51 stands Lotads in hole. PJSM on UD LEM tools. UD LEM running tools. Pull Vetco/Gray wear bushing, clear rig floor. PJSM on PU 7".Baker Model WG Bridge plug and Baker Heavy duty Model "EA" retrievamatic, w/ 3 1/2" IF joint and 3 1/2" H738 DP. MU 7" Baker Model WG Retievable Bridge plug, (1) jt 3 1/2" 13.3 dp 3 1/2" IF, Baker Heavy duty Model "EA" retrievamatic, crossover 3 1/2" IF x 3 1/2 HT38, 3 1!2" HT38 DP. One joint made up @ 0600 hrs. Continue RIH w/ 7" Baker Model WG Retrievable Bridge plug, (1) jt 3 1/2" 13.3 dp 3 1/2" IF, Baker Heavy duty Model "EA" retrievamatic, crossover 3 1/2" IF x 3 1/2 HT38, on 71 joints 3 1/2" 13.3ppf HT38. Rabbit dp to 2 5116". Torque 3 1/2" IF Conn to 10k, HT38 conn to 16.5k ft/Ib. Trouble shoot and repair of pipe handling machine. Selonoid valve and spool Slip & cut 136' drilling line. Continue RIH w/ 7" Baker Model WG Retrievable Bridge plug, (1) jt 3 1/2" 13.3 dp 3 1/2" IF, Baker Heavy duty Model "EA" retrievamatic, crossover 3 1/2" IF x 3 1/2 HT38, on 71 joints 3 1/2" 13.3ppf HT38, then start w/ 3 1/2" 15.5 ppf HT38, 44 jts of 15.5 ppf in hole now. Total of 115 jts HT in hole. Rabbit dp to 2 5/16". Torque HT38 conn to 16.5k ft/Ib. Continue RIH w/ 7" Baker Model WG Retrievable Bridge plug, (1) jt 3 1/2" 13.3 dp 3 1/2" IF, Baker Heavy duty Model "EA" retrievamatic, crossover 3 1/2" IF x 3 1/2 HT38, on 71 joints 3 1/2" 13.3ppf HT38, then start w/ 3 1/2" 15.5 ppf HT38, 167 jts of 15.5 ppf in hole now. Total of 238 jts HT in hole. Continue RIH w/ 7" Baker Model WG Retievable Bridge plug, (1) jt 3 112" 13.3 dp 3 1/2" IF, Baker Heavy duty Model "EA" retrievamatic, crossover 3 1/2" IF x 3 1/2 HT38, on 71 joints 3 112" 13.3ppf HT38, then start w/ 3 1/2" 15.5 ppf HT38, 167 jts of 15.5 ppf in hole now. Total of 295 jts HT Picked up. Tag 9.04' in on jt # 295. PU wt 165k, SO wt 75k. MU crossover on jt 295, MU top drive and tag top of liner @ 9308' (9.04' in on jt 295), bottom of bridge plug @ 9354.94'. PU, Break off single and drop 1-1/2" ball MU single, SO tag liner top, PU 6' above tag, circ ball to seat @ 3bpm w/ 700 psi. Pressure up @ 50 bbls pumped. Pressure to 2300 psi. Pick up to 180k, shear off of bridge plug. Bridge plug top @ 9346.24', bottom @ 9348.94". Length of bridge plug 2.70' UD 2 jts, PU jt w/ x-o, MU top drive.Jt # 293 in hole while testing, jt 294 above rig floor. 9308' bottom of tool Circulate bottoms up @ 5bpm w/ 1880 psi. Circ 600 bbls. Printed: 9/30!2005 6:19:05 AM • • ConocoPhillips Alaska 'Page 44 of 45 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date. From - To Hours Code Code ~ Phase ~r _ 9/7/2005 23:00 - 23:15 I 0.251 CMPLT DEQT I CMPLT3 23:15 - 00:00 I 0.751 CMPLTNI DEQT CMPLT3 19/8/2005 9/9/2005 00:00 - 00:30 I 0.501 CMPLTNI DEOT I CMPLT3 00:30 - 02:00 I 1.501 CMPLTNI TRIP I CMPLT3 02:00 - 02:30 0.50 CMPLTN TRIP CMPLT3 02:30 - 03:00 0.50 CMPLTN DEQT CMPLT3 03:00 - 03:45 0.75 CMPLTN DEQT CMPLT3 03:45 - 04:00 0.25 CMPLTN OTHR CMPLT3 04:00 - 04:30 0.50 CMPLT TRIP CMPLT3 04:30 - 05:15 0.75 CMPLTN TRIP CMPLT3 05:15 - 07:30 2.25 CMPLTN OTHR CMPLT3 08:00 -100:00 2.001 CMPLTNIC RC CMPLT3 10:00 - 13:00 I 3.001 CMPLTNI OTHR I CMPLT3 13:00 - 13:30 0.50 CMPLTN SFTY CMPLT3 13:30 - 14:15 0.75 CMPLTN CIRC CMPLT3 14:15 - 14:30 0.25 CMPLTN TRIP CMPLT3 14:30 - 15:00 0.50 CMPLTN SOHO CMPLT3 15:00 - 15:15 I 0.251 CMPLTNI SOHO I CMPLT3 15:15 - 15:45 0.50 CMPLTNI DEQT CMPLT3 15:45 - 16:00 0.25 CMPLTNI OTHR CMPLT3 16:00 - 16:30 0.50 DRILL SFTY CMPLT3 16:30 - 18:00 I 1.501 DRILL I PULD I CMPLT3 18:00 - 19:30 1.50 DRILL I PULD CMPLT3 19:30 -21:30 2.00 DRILL PULD CMPLT3 21:30 - 00:00 2.50 RIGMNT RGRP CMPLT3 00:00 - 00:30 0.50 RIGMNT RGRP CMPLT3 00:30 - 06:00 5.50 DRILL PULD CMPLT3 06:00 - 10:30 4.501 DRILL I PULD I CMPLT3 Spud Date: 6/26/2005 Start: 6/22/2005 End: 9/10/2005 Rig Release: 9/10/2005 Group: Rig Number: 15 Description of Operations RU to test Baker 7" Model WG Retrievable bridge plug seY@ 9346.24' , ZXP liner top packer @ 9308' w/test pkr @ 9259'. Rotate 5 turns to set packer. Set down 5k. Attempt to test Retrievable bridge plug. No test. PKR depth 9259'. Not enough weight to set test pkr. Circulating to surface. Attempt to test Retrievable bridge plug & ZXP packer. No test. PKR depth 9259'. Not enough weight to set test pkr. Only 5k above block weight. Circulating to surface. POOH Ud 5 jts of 3 1/2" 15.5 ppf XT38 dp. Stand back 11 stands in derrick to 8211' Trip in hole w/ 11 stands 5" HWDP f/ 8211' to 9090'. 10 stands HW in hole. PU wt 190k. SO wt 105k. RIH f/ 9090' to 9163' (element center @ 9114'). Apply 5 rounds RH w/ 8k torque. Set test packer w/ 35k down wt to 70k block wt. Attempt to test, no test, PU to 9114', set 35k down wt. Test RBP @ 9346', ZXP liner top packer @ 9308' w/ test packer @ 9114'. Test to 2540 psi. Chart test. Held 97.3% of test pressure in 30 min. Pressure lost 68 psi f/ 2540 to 2472 psi. Bleed off pressure, upset packer. POOH f/ 9114' to 8170' w! 5" HWDP. UD single 3 1/2" DP, TIH 11 stands 3 1/2" dp, PU 4 jts 3 1/2" dp. Total of 293 jts 3 1/2" in hole 27' up.=9308'. Flush surface lines, cement line, geopilot skid, kill and choke lines and manifold. PJSM on displacing f/ 9.0 ppg SFOBM to 9.6 p.pg Sodium Chloride. Displace 9.0 ppg SFOBM to 9.6 ppg Sodium Chloride. Pump @ 6 bpm w/ 1540 psi. Pump a total of 6285 strokes (632 bbls). Cleaning on rig floor, transfer mud f/ rock washer while wait on brine to be brought over f/mud plant in Prudhoe. RU truck of 290 bbls 9.6 brine. PJSM w/ crew. Fluid transfer paperwork. Pump 290 bbls 9.6 ppg Sodium Chloride @ 6 bpm w/ 1540 psi. POOH 3 jt 3 1/2" 15.5 ppf S-135 HT38 dp. 290 jts left in hole total. PU/MU Vetco/Gray 13 3/8" x 4 1/2" M6222, 13 1/2" OD hanger w/ dummy installed as penetrator and two way check instal-ed in hanger. MU to 4 1/2" landing joint w/ 4.909 MCA connection on top of hanger. Drain BOP stack to land kill string w/ running tool f/ 7" retrievalble bridge plug on bottom @ 9287.23' Run in LDS on Vetco Gray hanger. Test lower body seals to 5000 psi f/ 10 min. OK. Test upper body seals to 5000 psi f/ 10 min. OK. Back out landing joint. UD same. PJSM. Install mouse hole. Rig up to UD 5" dp f/ derrick. Have Tota1.170 stands 5" DP in derrick. 20 stands 5" HWDP, 83 stands w/ LoTads, 67 stands slick. Cleaning fluids f! pits and rock washer. UD total of 13 stands 5" HWDP. Cleaning fluids. f/ pits and rock washer. UD total of 7 stands 5" HWDP. Cleaning fluids f/ pits and rockwasher. UD 5" DP w/ Lo7ads. Total of 83 to UD. UD 17 stands @ 1930 hrs.. Cleaning fluids f/ pits and rockwasher. Pull Hyd cyl f/ pipe spinner on iron roughneck f/ repair. Pull Hyd cyl f/ pipe spinner on iron roughneck f/ repair. UD 5" DP w/ LoTads. Total of 83 to UD. UD total of 42 stands. @ 0600 hrs. Cleaning fluids f/ pits and rockwasher. UD 5" DP w/ LoTads. Total of 83 to UD. UD total of 53 stands @ 1030 Printed: 9/30/2005 6:19:05 AM • • ConocoPhillips Alaska Page 45 of 45 ,Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: ROT -DRILLING Start: 6/22/2005 End: 9/10/2005 Contractor Name: D15CM@conocophillips,com Rig Release: 9/10/2005 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To i Hours ~ Code l Code Phase Description of Operations 9/9/2005 06:00 - 10:30 4.50 DRILL PULD CMPLT3 hrs. Cleaning fluids f/ pits and rockwasher. 1030 -11:30 1.00 RIGMNT RGRP CMPLT3 Replace pipe spinners on iron. roughneck. Cleaning fluids f/ pits and rockwasher. 11:30 - 12:30 1.00 RIGMNT RSRV CMPLT3 Service rig. 12:30 - 13:00 0.50 DRILL PULD CMPLT3 UD 5" DP w/ LoTads. Total of 83 to UD. UD total of 55 stands @ 1300 hrs. Cleaning fluids f/ pits and rockwasher. 13:00 - 15:00 2.00 RIGMNT RGRP CMPLT3 Replace lower dies in iron roughneck lower jaw. Could not get die retainer loose f/iron roughneck easily. 15:00 - 18:00 3.00 DRILL PULD CMPLT3 UD 5" DP w! LoTads. Total of 83 to UD. UD total of 74 stands @ 1800 hrs. Cleaning fluids f/ pits and rockwasher. 18:00 - 20:00 2.00 DRILL PULD CMPLT3 UD 5" DP w/ LoTads. Total of 83 to UD. UD total of 83 stands @ 1800 hrs. All LoTads are Layed down. Cleaning fluids f/ pits and rockwasher. Blow down mud lines in pits. Clean rock washer pits. 20:00 - 00:00- 4.00 DRILL PULD CMPLT3 UD 5" DP. Total of 67 to L/D. UD total of31 stands@ Midnight. - - Cleaning fluids f/ pits and rockwasher. 9/10/2005 00:00 - 03:15 3.25 DRILL PULD CMPLT3 UD 5" DP. Total of 67 to L/D. UD total of 67 stands @ 0315 hrs. Cleaning fluids f/ pits and rockwasher. 03:15 - 05:00 1.75 DRILL PULD CMPLT3 UD mousehole, UD pipe spinners (xtra), UD 8 1/2" ghost reamer, clean and UD Sperry Sun geo pilot 05:00 - 06:00 1.00 WELCT NUND CMPLT3 Disconnect kill and choke lines. Prep to nipple down BODE. Cleaning rig floor. 06:00 - 11:30 5.50 WELCT NUND CMPLT3 Clean pipe racks, nipple down BOPE. Move rock washer away f/ rig modules, stage on 1 E pad. 11:30 - 15:00 3.50 WELCT NUND CMPLT3 RU and nipple up Vetco Gray tree. 15:00 - 16:30 1.50 WELCT NUND CMPLT3 Continue nippling up Vetco Gray tree. Test void to 5000 psi f/ 10 min. Leak on bleeder threads on tree cap flange. Test against swab valve to 5000 psi.OK. Note: Disconnect f/ HI LINE power @ 1500 hrs. Switch to rig power 16:30 - 18:00 1.50 WELCT EQRP CMPLT3 Prep rig floor for skidding rig. Rig down all complexes for rig move. 18:00 - 21:00 3.00 WELCT .EQRP CMPLT3 Blow down steam to pit module. tum tires & prepare to move pit module. Fold in beaver slide and secure same. 21:00 - 22:30 1.50 WELCT EQRP CMPLT3 Change out 9" Otis tree cap on Vetco Gray 4 1/6" 5m flange. Leak on 1" NPT fitting on flange(galled threads). Use tree cap F/ 1J168 well. Reinstall tree cap, test to 250 psi low f! 10 min. OK. Test to 5000 psi high f/ 10 min. OK. 22:30 - 00:00 1.50 DRILL OTHR CMPLT3 Secure well. PU tools in cellar. Release rig @ midnight 9/10/2005. f/ 5.1 mile move f/ 1 E-170 to 1 C-28. Move pits off of mats, move mats f/ pit module and spot on road. Blow down steam to sub module. Printed: 9!30/2005 6:19:OSAM • Phase ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-170 Common We11 Name: 1 E-170 Event Name: WORKOVER/RECOMP Start: 10/17/2005 Contractor Name: N3SCM@conocophillips.com Rig Release: 11/13/2005 Rig Name: Nabors 3S Rig Number: Date Fror7~ - To Hours Code Sub Code 110/17/2005 100:00 - 08:30 I 8.501 MOVE I RURD 08:30 - 11:00 2.50 MOVE ~ RURD 11:00 - 11:30 0.50 WELCT NUND 11:30 - 17:30 I 6.001 WELCTU BOPE 17:30-18:30 1.00 WELCT~SFTY 18:30 - 00:00 5.50 WELCT BOPE 10/18/2005. 00:00 - 01:00 1.00 WELCT BOPE 01:00 -.03:00 2.00 WELLS PLGM 03:00 - 06:00 3.00 WELLS RURD 06:00 - 12:00 6.00 FISH PULL 12:00 - 19:00 7.00 FISH PULL 20:00 - 20:30 1.50 FISHLS~ PURD 21:30 - 00:00 2.50 FISH PULL 10/19/2005 00:00 - 01:00 1.00 WELLS RURD 01:00 - 02:00 1.00 WELLS RURD 02:00 - 06:30 4.50 WELLS RURD 06:30 - 10:30 4.00 WELLS TRIP 10:30 - 13:00 I 2.501 WELLSF~ TRIP 13:00 - 19:00 I 6.00 WELLSR TRIP 19:00 - 22:30 ~ 3.50 ~ LOG RURD 22:30 - 00:00 1.50 LOG I ELOG 10/20/2005 00:00 - 05:30 5.50 LOG ~ ELOG i 05:30 - 07:00 i 1.50 LOG PULD C Page 1 of 14 Spud Date: 6/26/2005 End: 11 /13/2005 Group: Description of Operations MOVE Rig on location, line rig up with well head and locate position for rig mats and containment. Pull rig forward, spot rig mats and layout Herculite for containment. Spot rig over well. Connect modules (pipe shed & pits). MOVE Raise derrick, connect all lines and secure rig. Accept rig @ 1100 hrs 10/17/2005. DECOMP Raise derrick, connect all lines and secure rig: Accept rig @ 1100 hrs 10/17/2005. DECOMP NU BOPE. (13-5/8" stack.)Verify well is dead, Pull BPV, install two way check. DECOMP Held pre-spud meeting with both crews. DECOMP Test BOP's to 250/3000 psi, annular to to 250/2500 psi. Chuck Sheve with (AOGCC) waived BOP test. DECOMP Complete BOP test.. DECOMP Drain BOP stack. Pull two way check DECOMP Make up landing joint to tubing hanger. Back out lock down studs. Unland tubing hanger at 95k up weight. Lay down landing joint, tubing hanger with one joint of 4.5" tubing below hanger. DECOMP Begin POOH w/ 3.5" HT38 drill pipe with test packer to 5000'. Standing back and strapping drill pipe in derrick to ensure the exact location of leak. DECOMP Hunting hole in 9 5/8" casing with test packer and 3.5" HT38 DP. Found two leaks one at 4' out on jt.137 approximate depth 4863' MD. Isolated second leak to be at 20' out on jt 190 or about 4769' MD tested bottom of top leak and found it to be less than 5' lower or 4774' MD. Depths are approximate until we strap out and measure the sealing elements on test packer. Top leak communicated with OA 13 5/8 by 9 5/8 immediately. This means we would need to span 94' of leaks. DECOMP Lay down head pin DECOMP Begin POOH w/ 3.5" HT38 drill pipe with test packer. Standing back and strapping drill pipe in derrick to confirm leak depths. DECOMP Continue OOH w/drill pipe. On surface with drill pipe and test packer. DECOMP Lay down BHA (test packer assembly) DECOMP Install wear ring DECOMP Make up scraper run BHA DECOMP After back strapping out of hole with kill string leak depths where determined to be (bottom leak 4861'-4856' RKB 2 BPM @ 910 PSI top leak 4757'-4752' RKB we could not establish a rate as we where not rigged up to cir). The OA but we could pump @ 26PM threw the leak) overall length of 109' of bad pipe. BHA made up 217' total length consisting of 8" Casing Scraper, 8 5/8" String milt, Bit Sub, Bumper Sub, Oil Jar, 6-6" Drill Collars and Drill Pipe to surface. Start running in the hole with Scraper run to 5000' MD with 3.5" HT38 DP. DECOMP On depth with scraper run. Work threw squeeze depth could not see any indications of tightness. Work up and down and Circulate long way 1.5 bottoms up 4.5 BPM @ 420 psi DECOMP Bottoms up circulation completed. Pull out of hole with scraper run standing back Drill Pipe. DECOMP Rig-up E-line for USIT log to 5500' with wireline tractor. Had trouble function testing tools on surface. Finally got good function test. DECOMP RIH w/ USIT log assembly with tractor to 5500' DECOMP Continue E-line USIT log with tractor to 5500'. DECOMP i Rig DWN Schlumberger and Clear rig floor. Prepare to re-rig return rnntea: iir[~[uu5 y:4a:~oHm ConocoPhillips Alaska Page 2 of 14 Operations Summary Report .Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: WORKOVER/RECOMP Start: 10/17/2005 End: 11/13/2005 Contractor Name: N3SCM@conocophillips.com Rig Release: 11/13/2005 Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 10/20/2005 05:30 - 07:00 1.50 LOG PULD DECOMP lines from OA. 07:00 - 09:00 2.00 WELCT NUND DECOMP Re-rig harline to tanks for circulation step rate test from 9 5/8" to 13 3/8" casing. Burm up new 70 BBL returns tank. 09:00 - 10:30 1.50 WELCT CIRC DECOMP Begin circulation step rate test. 1 BPM 9 5/8" = 50 13 3/8" = 400 2 BPM 9 5/8" = 160 13 3/8" = 400 3 BPM 9 5/8" = 220 13 3/8" = 400 4 BPM 9 5/8" = 270 13 3/8" = 400 Maintained 400 PSI on the OA to stay 75 PSI over ISIP Returns = 1-1 throughout step rate test. Re-freeze protected OA with 65 BBLS diesel. Utilized 41 BBLS during test, and added 24 BBLS for good measure. 10:30 - 11:30 1.00 WELCT NUND DECOMP Rig up Hot oil for the freeze protect. Pump freeze protect 1-1:30 - 1.2:00. 0.50 WAITON EOIP DECOMP Change of scope. Call out Baker RBP w/sand plug for isolation of lower... wellbore. Clean rig floor. 12:00 - 13:30 1.50 WAITON EOIP DECOMP Continue to STBY for Baker. 13:30 - 15:30 2.00 WAITON SFTY WRKOVR Nabors management meeting with hourly employees to discuss issues within the ranks. 15:30 - 18:00 2.50 CMPLTN TRIP WRKOVR Pick up Baker RBP asym with tubing stop. Baker RBP 8.22" OD, tubing stop @ 8.5" OD aprox 680' above RBP. Begin RIH. 18:00 - 21:30 3.50 CMPLT TRIP WRKOVR Located liner lap @ 25.5" in on stand number 87 (4850'). Pulled stand number 87. 21:30 - 23:00 1.50 WELLS PLGM WRKOVR Set Baker RBP. Top of plug @ 5445'. Rig-up head pin. Rig-up Schlumberger pump truck to lay sand plug above RBP. 23:00 - 00:00 1.00 WELLS PLGM WRKOVR Held PJSM. Mix sand for sand plug. 10/21/2005 00:00 - 02:00 2.00 WELLS PLGM WRKOVR Release from RBP. Pressure test Schlumberger equipment and lines to 3000 psi. Pump 18.5 bbls sand/gelling/antifoam agent followed by 34 bbls brine from pits @ 3 bpm (550 psi). Rig down pump Schlumberger. Remove head pin. Pull four stands. Slight over balance on outside of DP after pumping sand plug. Reverse circulate 40 bbls brine. 02:00 - 05:30 3.50 WELLS TRIP WRKOVR POOH w/ 3.5" DP and Baker retrieving head. Pick up circulating head and circulate bottoms up due to pulling wet. 05:30 - 07:30 2.00 WELLS TRIP WRKOVR Continue to POOH. Monitoring hole conditions. 07:30 - 08:00 0.50 WELLS PULD WRKOVR Lay down running tools for RBP. Clear rig floor and prepare to RBIH for HES cement retainer deployment. 08:00 - 09:30 1.50 WELLS PULD WRKOVR Pick up HES cement retainer and prepare to RBIH. Installed 10ea. 5K shear pins into retainer. Tool string data in pipe tally. Hole conditions are stable. 09:30 - 12:00 2.50 WELLS TRIP WRKOVR Continue to RIH. 12:00 - 15:15 3.25 WELLS PLGM WRKOVR Set HES cement retainer @ 4,672' RKB. Rotate 26 turns to the right and witnessed 4 turns of reactive torque. 15:15 - 15:45 0.50 WELLS CIRC WRKOVR Pressure test drill pipe by 9 5/8"ann to 1,000 PSI. Pressure test good. Unsting from retainer and circulate. 2 BPM @ 145 PSI. returns 1-1 15:45 - 16:25 0.67 WELLS CIRC I WRKOVR Drill pipe and 9 5/8" ann no longer pressure testing. Returns to surface instantly after pump initiation. Initial test held. Not sure what has happened. 16:25 - 18:50 , 2.42 WELLS CIRC WRKOVR After several attempts to reseal HES cement retainer perform. injection 'test. 2 BPM @ 970 PSI on the OA while bullheading. Discuss with Anchorage about continuing program as per plan with extra caution. 18:50 - 19:50 I 1.00 WELLS SFTY I WRKOVR Discuss with all personal, job issues and safety concerns. Call out little I i ` red for a OA injection test. 19:50 - 20:20 ! 0.501 WELLSPo CIRC ~ WRKOVR Little Red on location. 20:20 - 22:00 1.671 WELLSF~ CIRC I WRKOVR Rig-up LRS on IA. PT lines 2500#. Verify if check in retainer is holding. Panted: 11/2"L'LW5 9:48:25 AM • ConocoPhillips Alaska Page 3 of 14 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: WORKOVER/RECOMP Start: 10/17/2005 End: 11/13/2005 Contractor Name: N3SCM@conocopfliflips.com Rig Release: 11/13/2005 Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Code Phase Description of Operations 10/21/2005 20:20 - 22:00 1:67 WELLSF~ CIRC WRKOVR Able to get return up DP, test failed, Rig down LRS. 22:00 - 23:00 1.00 CEMEN PULD WRKOVR PJSM. PT lines to 4000 psi. Pump 5 bbls water. Stab stinger into cement retainer. Start pumping cement. Pumped 20 bbls initally at 3 bpm 540 psi, starting OA pressure 320 psi, then closed bag. Got another 15 bbls away, pressure started bluilding. After 37 bbls cement away, pressure spiked to 3700 psi, shut down pump. Appears retainer is plugged, bleed pressure off. Sting out of retainer, open annular, start pumping water, sting back into retainer, pump 5 bbls water, pressure spiked to 2000 psi. Bleed off, open pipe rams, sting out of retainer, rig down cement crew. 23:00- 00:00 1.00 WELLS CIRC WRKOVR Circulate cement out of DP and well bore. 10/22/2005 00:00 - 03:00 3.00 WELLS CIRC WRKOVR Circulate hole clean long way, total of 400 bbls. Rig down head pin. 03:00 - 07:30 4.50 WELLS TRIP WRKOVR POOH w/ 3.5" DP and cement retainer stinger 07:30 -12:30 - 5.00 -WELLS RURD WRKOVR Out of hole with cement string bottom hole assemble complete with stinger. Rig up Kelley in preparation to run in the hole and drill out. retainer and cement. Cement retainer stinger after being taken apart at HES shop was full of sand. 12:30 - 15:30 3.00 WELLS TRIP WRKOVR Rig up BHA to drill out cement retainer and cement. BHA consisting of. 8.5" tri cone Bit, two 7" Boot Baskets, One 8.5" Stabilizer, One 6.25" Drill Collar, One 6.25" Bumper Sub, One 6.25" 11.58' Oil Jar, Three jts. Of Heavy Wall 3.5" HT38 Drill Pipe. 15:30 - 16:30 1.00 WELLS TRIP WRKOVR BHA picked up and ready to start in the hole with. 56 Stands of 3.5" HT-38 Drill Pipe, 12 jts. of Heavy Wall Drill Pipe, 9 Stands of HT38 Drill Pipe, 25 jts of 3.5" HT38 Drill Pipe to be picked up and drilled down with the Kelly as singles. 16:30 - 21:30 5.00 WELLS TRIP WRKOVR RIH w/ 3.5" DP and milling BHA to 4075' 21:30 - 00:00 2.50 WELLS PULD WRKOVR Remove bails and elevators, torque all upper kelly connections to 48K. Test two kelly valves 250 psi / 3000 psi. Reinstall bails and elevatorss, blow down lines. 10!23/2005 00:00 - 02:00 2.00 WELLS TRIP WRKOVR Continue in hole with milling BHA. Tag cement above retainer 4650'. Get up and down weight 62UP / 31 DN. Mill apprxomiately 20 minutes, made 2' of hole. Make first 20 barrel! sweep, very little cement returns accross shakers. 02:00 - 04:00 2.00 WELLS MILL WRKOVR Continue milling operations on retainer, Able to mill through retainer, possibly very small of cement below retainer. Add single joint of DP, No restriction encountered. 04:00 - 05:30 1.50 WELLS MILL WRKOVR Add three additional single joint of tubing, same results, no restrictions. 05:30 - 09:00 3.50 WELLS CIRC WRKOVR Start pumping second sweep (25 bbls) with rig pump and LRS @ 9 ~' BPM purred a total of 430 bbls until returns cleaned up. 09:00 - 09:15 0.25 WELLS DEOT WRKOVR Pressure test casing post drilling out retainer and cement to 4800' failed to pressure test OA tracking drill pipe pressure. Increase OA to 800 psi and shut down pressure slowly bleed down to 150 psi in 1 min. 09:15 - 11:30 2.25 WELLS MILL WRKOVR RIH with drill string to 4900', tagged up on cement stringer or RS nipple 4832' went threw with 7000 Ibs down wt. continued down to 4900' without seeing any more obstructions. 11:30 - 13:30 2.00 WELLS CIRC WRKOVR Circulated up solids from bottom with 450 bbls and a 25 bbls Bio gel ~ sweep. Recovered lots of sand and more pieces of the retainer. Rig up ~ for infectivity test down the drill pipe and up the OA to open top tank. 13:30 - 14:30 j 1.00 WELLSPo CIRC WRKOVR Injection test down drill pipe threw top hole back up OA to open top ~ ~ tank. Holding 300-psi back pressure with 9.6 ppg brine. 1.5-bpm = ~ ' 90-psi DP and 380-psi OA, 2-bpm = 180-psi DP and 400-psi OA, 3-bpm = 340-psi DP and 400 OA, 4-bpm = 480-psi DP and 400-psi OA. Total of 45-bbls of brine was pumped LRS pumped 45-bbls of diesel down F'flrlt0d: 71/LLLUUS `.i:4i5:L5 AM • ConocoPhillips Alaska Page a of ~4 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: WORKOVER/RECOMP Start: 10/17/2005 :.End: 11/13/2005 Contractor Name: N3SCM@conocophillips.com Rig Release: 11/13/2005 Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 10/23/2005 13:30 - 14:30 1.00 WELLS CIRC WRKOVR the OA to replace the diesel freeze protect. Next we pumped infectivity test into the bottom hole closing the OA valve and injecting in to the bottom hole. Injection leaved out at 2.2-bpm = 880-psi DP and 1100-psi OA. Conclusion is that both holes are open and do not seem to have been effected by the prior cement job. 14:30 - 21:00 6.50 WELLS TRIP WRKOVR POOH with clean out string standing back drill pipe and laying down BHA. 21:00 - 21:30 0.50 WELLS PULD WRKOVR Pull wear ring 21:30 - 22:30 1.00 WELLS KURD WRKOVR Rig up for weekly BOP test 22:30 - 00:00 1.50 WELCT BOPE WRKOVR Test BOP and choke 250 psi low / 3000 psi high: Lou Grimaldi with AOGCC waived witness 8:30 PM on 10/23/05 10/24/2005 00:00 - 02:00 2.00 WELCT BOPE WRKOVR Continue with BOP test, Lay down test equipment, install wear ring. 02:00 - 03:00 1.00 CEMEN PULD WRKOVR Make up cement retainer BHA (cast iron retainer/setting tool) .03:00 - 07:00 .4.00 CEMEN TRIP.. WRKOVR RIH w/HES EASYSV retainer and 3.5" HT38 DP with five stands of 3.5" HW DP above 1800' to setting depth of 4645'. 07:00 - 08:00 1.00 CEMENT NFLT WRKOVR Set cement retainer with 36 turns to the right. Shear out of retainer- 132,000# and PUH 10'. Pressure test IA to 1,000 PSI for 10 min. Test passed. No flow to surface OA. 08:00 - 08:30 0.50 CEMEN FIT WRKOVR Sting back into retainer and perform injection test. 1 BPM @ 440 PSI DDP. 740 PSI OA 08:30 - 10:00 1.50 CEMENTCIRC WRKOVR Mix Biozan pills in pits. Blew air through all lines prior to pumping and or taking returns. Calibrate pressure gauges. Wait on second ASRC hand for assist on remote choke. Clean rig. Services blocks. 10:00 - 11:00 1'.00 CEMENI~SFTY WRKOVR Pre-job safety meeting: Discuss all options and contingencies with contractors. 11:00 - 11:30 0.50 CEMENTSEOT WRKOVR Pressure test cement line and Schlumberger to 3,500 PSI. Prepare to begin cement program. Initial OA pressure = 280 PSI IDPP = 0 11:30 - 11:40 0.17 CEMEN PUMP WRKOVR Cement to weight!!!!! 2 hours and 45 min to set. Pumps on line at 1 BPM to start. 350 PSI DPP. 2 BPM @ 530 DPP. Allowed 25 BBLS into 9 5/8" pipe below retainer prior to openning up OA. 11:40 - 12:40 .1.00 CEMEN SQEZ WRKOVR Begin pressure schedule for OA bleed off to allow cement to run into OA at a 1-1 ratio through known hole at 4,752' after allowing 25 BBLS of 15.7 PPG cement to flow into 9 5/8" casing below cement retainer. 12:40 - 13:15 0.58 CEMENTTRIP WRKOVR 125 BBLS away 600 PSI DPP 1200 PSI OA. 132 BBLS total slurry away. 25 BBLS into 9 5/8" casing and 97 BBLS into 13 3/8" outer ~, annulus. Estimated top of cement in OA = 3,127 RKB. Roughly 235' TVD difference. Un-sting from cement retainer with 10 BBLS left in .drill pipe to lay cement plug on the top. Shut down pumps to perform this stage. More than likely that we only put 5-6 BBLS on top of retainer, Suspect that over balance of OA to 9 5/8" casing will leach into and possibly plug lower hole at 4,852-54' RKB. Final OA pressure = 50 PSI 13:15 - 15:30 2.25 CEMENTCOUT WRKOVR Circulate 1 1/2 times bottoms up while moving pipe up and down to ensure that pipe is frees No cement returns to surface. 15:30 - 16:30 ~ 1.00 CEMENTRURD WRKOVR Rig down circulating system and clear rig floor for POOH. 16:30 - 18:00 ~ 1.50 CEMENTOTHR WRKOVR Go through stand pipe manifold and remove all cement from lines. Clear HCR and blow down all line on rig to ensure that no valves leaked ~ cement through. 18:00 - 22:00 i 4.00 CEMEN TRIP WRKOVR POOH w/ 3.5" DP and HES setting tool, Lay down setting tool, Prep rig ~ i floor bit run. 22:00 - 23:00 i 1.00 CEMENTRURD ' WRKOVR Make up bit BHA, Oil jars/Bumper sub/Dril collar/Bit sub/Boot ~ ~ ~ baskets/Mill tooth bit. Printed: 11/22/2005 9:48:25 AM • ConocoPhillips Alaska Operations Summary Report Page 5 of 14 'I Legal Well Name: 1 E-170 Common Well Name: 1E-170 Spud Date: 6/26/2005 Event Name: WORKOVER/RECOMP Start: 10/17/2005 End:. 11/13/2005 Contractor Name: N3SCM@conocophillip s.com Rig Release: 11/13/2005 Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 10/24/2005 23:00 - 00:00 1.00 CEMEN ~ TRIP WRKOVR RIH w/ 3.5" DP and bit BHA 10/25/2005 00:00 - 01:30 1.50 CEMEN TRIP WRKOVR Continue in hole with cleanout BHA. 01:30 - 10:30 ~ 9.00 CEMEN TRIP WRKOVR Rig on stand by above cement plug, waiting for cement to set up. Crews will use this to perform general maintenance and housekeeping duties. 10:30 - 12:00 1.50 CEMEN LOT WRKOVR Pressure test OA with little Red. Pumped 2.6 BBLS to pressure up to 1,500 PSI. Initial test failed due to air in the system. Second test passed. Lost 50-70 PSI in 15 MIN. Rig down Little Red and prepare to engage cement. 12:00 - 16:00 4.00 CEMEN DSTG WRKOVR After changing hydraulic filters out last night, system will not pressure up past 100 PSI. Mechanic in route. Not sure what the issues was. Pulled a control valve -reinstalled it and rig works. (((CODE 8))). 16:00 - 19:00 3.00 WELLS MILL WRKOVR Hydraulics fixed. Prepare to RIH to begin milling. Pick up Kelly and test: 19:00.- 21:00 2.00 WELLS MILL WRKOVR Begin milling cement @4526; circulating to pits at4bpm, sweeping the hole with 3# biozan pills. ROP approx. 30-50'/hr. Stacking 15k down 21:00 - 00:00 3.00 10/26/2005 00:00 - 01:00 1.00 01:00 - 07:30 6.50 07:30 - 12:00 4.50 12:00 - 13:00 1.00 13:00 - 14:00 1.00 14:00 - 15:30 I 1.50 15:30 - 18:00 18:00 - 22:30 22:30 - 00:00 10/27/2005 , 00:00 - 05:00 MILL WRKOVR Continue to mill 4630'. MILL WRKOVR Tag top of cement retainer at 4658'. Set Sk down, begin slowly milling through. Circulating at 4 pm. Not seeing much cement at shakers; call out Hot Oil for pump to up circ rate. MILL WRKOVR Finished milling up retainer. Continue to RIH to 4,778' prior to testing OA. Hot oli on location. Rlg up and conduct pre-job safety meeting. Come online with hot oil and rig pump in tandem circulating hole at 6-7 bpm. MILL WRKOVR Target depth achieved. Prepare to pressure test 9 5/8" X 3 1/2" drill pipe annulus. Note that drilling became very easy after 4,755' RKB. Pump 1 1/2 volume for hole circulation. CIRC WRKOVR Begin high rate bottoms circulation with little Red assist. 8.5 BPM @ 1,350 PS1 DPP 25 BBL 3# biozan sweep. Returns = 1-1. OTHR WRKOVR Pressure test 3 1/2" DP X 9 5/8" casing attempt failed. Able to inject into formation via lower leak at 4,852' at 4 BPM 1,600 PSI DPP. Blow down all lines and prep for OA test with Little Red. OTHR WRKOVR Pressure test OA to 1,500 PSI with diesel. Test passed with 1.6 BBL to pressure up. 100 PSI loss at 30 MIN. Blow down all lines and re-rig Little Red to assist rig in pump rates. 2.50 WELLS MILL WRKOVR Continue milling up cement with Kelly. Min torque spikes to 4,500 ft/Ib indicate stringers. 4.50 WELLS MILL WRKOVR Continue RIH, still encountering stringers forcing us to mill through. Circulate bottoms up with rig pumplHot Oil every so often. Seeing large pieces of rubber element from retainer at the shaker, however, only metal fines -- nothing substantial. 1.50 WELLS MILL WRKOVR Continue in hole, still milling through cement stringers /pumping bio sweeps. 5.00 WELLS ~ MILL WRKOVR Continue to mill down to RBP. Able to clean out with out rotating on j occasion, however, still encountering either cement stringers or parts of I the cement retainer requiring us to mill through. 05:00 - 08:00 i 3.00 WELLS I CIRC WRKOVR ~ Work down to tag at 5,423', pump 30 bbl bio sweep around and !circulate out of hole. 08:00 - 09:00 ! 1.00 WELLSR CIRC WRKOVR Finnish circulation. Blow down lines and prepare to release Little Red. ~ I Pump dry job. 09:00 - 13:QO ~ 4.00 WELLSR~ TRIP i WRKOVR i POOH with drill pipe while monitoring hole conditions. Pfmtetl: 1122/"LOOS 9:4825 AM • ConocoPhillips Alaska Operations Summary Report Page 6 of 14 Legal Well Common W Event Nam Contractor Rig Name: Date Name: el{ Name: e: Name: From - To 1 E-170 1 E-170 WORKO N3SCM Nabors Hours VER/R @conoc 3S Code ECOM ophillip Sub Code P s.com Phase Spud Date: 6/26/2005 Start: 10/17/2005 End: 11/13/2005 Rig Release: 11/13/2005 Group: Rig Number: Description of Operations 10/27/2005 13:00 - 14:30 1.50 WELLS TRIP WRKOVR Continue to POOH with milling string. Discuss with Anchorage the different options with the program. 14:30 - 16:00 1.50 WELLS PULD WRKOVR Lay down BHA and prepare to RBIH with reverse out BHA 16:00 - 17:00 1.00 WELLS SFTY WRKOVR Perform safety shut down with rig crew to discuss ConocoPhillips commitment to target 0 and their personal safety!! 17:00 - 19:00 2.00 WELLS PULD WRKOVR Pick up reverse out BHA and prepare to RIH. 19:00 - 22:30 3.50 WELLS TRIP WRKOVR Begin RIH with cleanout BHA. Perform BOP drill. 22:30 - 23:15 0.75 WELLS SFTY WRKOVR Conduct company-wide safety stand down meeting with night shift rig personnel. Dlscuss safety issues and heighten awareness of attempt to achieve a zero incident culture. 23:15 - 00:00 0.75 WELLS TRIP WRKOVR Resume running back in hole with cleanout BHA. 10/28/2005 00:00 - 05:00 5.00 WELLS WASH WRKOVR Starting to see scraper work at at 5100'; losing wgt running in hole, clean pick-ups. Sit down @ 5229'; begin rigging up kelly. Begin circulating at 3 bpm and rotating in order to make hole (stacking 4-5k#). Appear to be scraping cement sheath from .casing walls. 05:00 - 06:00 1.00 WELLS WASH WRKOVR Continue to scrape to 5,425`. 06:00 - 07:00 1.00 WELLS WASH WRKOVR Begin to POOH with scraper asym. PUH and monitor well. POOH. UP WT = 70K DWN WT = 40K. Rotating = 45K 07:00 - 07:15 0.25 WELCT OBSV WRKOVR Monitor well for flow. 07:15 - 08:30 1.25 WELCT OBSV WRKOVR Finish monitoring well. Thaw out air system and POOH. Clean rig floor and prepare to POOH 08:30 - 09:00 0.50 WELLS RURD WRKOVR Blow dwn Kelly and rig it back. 09:00 - 12:30 3.50 WELLS TRIP WRKOVR OOH with drill pipe begin breaking dwn BHA. 12:30 - 14:00 1.50 WELLS PULD WRKOVR Break out BHA. Take pictures and inserted into 1 E-170 work folder. Composite bridge plug at about 20% inside wash pipe. Cast iron cement retainer broken up in 2-3" chunks. Small pieces in boot baskets. Clear rig floor and prepare to pick up test PKR. 14:00 - 14:30 0.50 WELLS RURD WRKOVR Complete clearing rig floor. 14:30 - 16:30 2.00 WELLS PULD WRKOVR Begin installing Baker retrievamatic packer as per pipe tally. Tubing stop is installed in string to locate _ 4,850.17' RKB. We had to steam retrievamatic packer to thaw out and lubricate moving parts. Surface test passed. Begin running in hole. 16:30 - 22:00 5.50 WELLS TRIP WRKOVR Begin running in hole with test packer assembly.. 22:00 - 22:30 0.50 WELLS TRIP WRKOVR Sat down on trash at +-4840', slight overpull getting back off of it. No-go out 25' in on stand #78 (tbg stop located with a 1' of where it was suppose to + or - 4850' orig RKB). 22:30 - 23:30 1.00 WELLS DEQT WRKOVR Pull out stand #78, rack back. Install headpin. Set test packer, top of element at 4866' orig RKB. PUW=57k. Have difficulties getting packer set, only able to set do at most 15k. Pick up /set down hai-d...repeatedly, finally able to get set. Test to 2500 psi...good. 23:30 - 00:00 0.50 WELLS DEQT WRKOVR pull up hole 5' to 4861' (top of element). Set packer and test. Hold 5 mins at 2500 psi-- good. Bleed off. Pull up hole 2' to 4859'. Set packer and test....found leak between 4859' and 4861' orig RKB. Leak rate 1 bpm at 250 psi. Bleed off. 10/29/2005 00:00 - 01:30 1.50 WELLS DEQT WRKOVR Top of test packer element at 4859' orig RKB. Swap pump around to 9-5/8"xdrill pipe annulus and pressure up to 2500 psi. OA=O psi Hold for 30 mins. Good test...lost 30 psi in 30 mins. OA stil reading 0 psi. Bleed down. Discuss cleanout run W/O Engineer. 01:30 - 05:30 4.00 WELLSR TRIP WRKOVR ; Begin pulling out of hole with test packer. 05:30 - 06:30 1.00 WELLSf~ PULD WRKOVR i Break out and lay down BHA. Little bits of fiberglass in BHA. 06:30 - 09:00 ~ 2.50 RIGMNT~ RSRV ~ WRKOVR ! Rig service ,Crown, Blocks Prep to pick up washpipe. Change out 09:00 - 12:00 i 3.00 I WELLSR I PULD ! WRKOVR , handeling gear. Make up washpipe BHA. Special care. pieces to small for rig Printed: 11!22!2005 9:48:25 AM • ConocoPhillips Alaska Page 7 of ~4 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: WORKOVER/RECOMP Start: 10/17/2005 End: 11/13/2005 Contractor Name: N3SCM@conocophillips.com Rig Release: 11/13/2005 Group: Rig Name: Nabors 3S Rig Number: Date From - 70 Hours Code 10/29/2005 ~ 09:00 - 12:00 ~ 3.00 ~ WELLS 12:00 - 14:30 2.50 WELLS 14:30 - 16:30 2.00 RIGMN 16:30 - 20:00 3.50 WELLS 20:00 - 00:00 4.00 WELLS 10/30!2005 100:00 - 02:30 I 2.50 WELLS 02:30 - 04:00 ~ 1.50 04:00 - 06:00 06:00 - 06:15 06:15 - 08:00 08:00 - 10:00 2.00 0.25 1:75 2.00 Sub Phase ~ Description of Operations Code PULD WRKOVR equipment on floor. Contact Baker and have shop make up smaller. pieces. Changeout handling equipment. TRIP WRKOVR Begin running in the hole with cleanout BHA. RGRP WRKOVR Shut down to cuUslip drill line. TRIP WRKOVR Resume trip in the hole. Perform BOP drill. WASH WRKOVR 82 stands in the hole; begin picking up singles. Rlg up headpin and begin reverse circulating while stripping through the bag. Circulating at 4 bpm, begin working pipe in hole, however, having difficulties stripping in due to circ. press/pipe wgt. WASH WRKOVR Cont. rev-circulating/washing 4 bpm, 550 psi circ press. Lots of sand, composite, rubber, cement across shaker. Hole out of balance due to solids; U-tubing unable to make up newjts. Circulate hole around to clean up 2x bottoms up. Wash down to 5438'. Pump 30 bbl 3# bio sweep, circulate around. WASH WRKOVR Watch returns at shaker until clean. 38 bbls brine lost while ci rc u tati n g/washing. TRIP WRKOVR Begin pulling out of hole. SFTY WRKOVR Crew change out. TRIP WRKOVR Continue to POOH . At 1,880' pipe quit draining and is now pulling wet. TRIP WRKOVR OOH with all drill pipe. Begin picking up handling equip for 8 1!4" pipe. 10:00 - 11:00 1.00 WELLS SFTY WRKOVR I Flappers are plugged on bottom of 8 1/4" wash pipe. pre job safety meeting. Round up the proper PPE. Banna suites, goggles, rubber gloves. 11:00 - 12:00 1.00 WELLS PULD WRKOVR Lay down wash pipe. Prepare to clean rig. 12:00 - 14:30 2.50 RIGMNT RSRV WRKOVR Clean rig from wash pipe. 14:30 - 15:00 0.50 WELLS PULD WRKOVR Begin picking up retrieval head for RBP. 15:00 - 19:00 4.00 FISH TRIP WRKOVR RIH with retrieving head to pull RBP at 5445'. 19:00 - 20:00 1.00 FISH FISH WRKOVR PUW=66k, do=28k. Wash down 5430 to RBP at 5445'; latch up and pick up, see slight drag to 70k. Run back in hole past set depth ensure RBP is latched. 20:00 - 22:00 2.00 FISH CIRC WRKOVR Pull up hole 15' and begin circulating bottoms up to ensure no gas was trapped under RBP. 22:00 - 00:00 2.00 FISH CIRC WRKOVR Resume pulling out of hole. At 4980', hanging up on trash/debris. PUW=65k, dragging to 100k, breaking back. Rig up to rev-circulate. Circulate 2 bottoms up @ 4 bpm, resume pulling out of hole. Well U-tubing badly due to solids concentration in drill pipe. Move pipe 4-6' i make sure pipe is free, swap to circulating the long way. 50 bbls away, shut down and pull up hole 10', still dragging. Resume circulating the long way @ 4 bpm, 420 psi. Pump 25 bbl 3# bio sweep. 10/31/2005 00:00 - 02:30 2.50 FISH CIRC WRKOVR Cont. Circulating 25 bbl 3# bio sweep around the long way @ 4 bpm. 02:30 - 06:00 3.50 FISH CIRC WRKOVR Begin pulling out of hole. Still dragging heavy in a few spots. 06:00 - 10:00 4.00 FISH TRIP WRKOVR Trip OOH 10:00 - 11:00 1.00 FISH RURD WRKOVR At surface; break down RBP. Send pictures to Anchorage of missing , rubber. 1!2" gouge in gauge ring. Rubber element missing is .17' tall, 8 3/16" OD, 6 7/16" ID. Prepare to make fish /cleanout run. Ordered out 8 1!2" wash pipe with flapper bit. Pull wear ring and prep for BOP ~ 11:00 - 15:30 4.50 WELCTTI~ BOPS WRKOVR test. Conduct BOP test; 250 low test, 3000 high. Test witnessed by state rep, John Spaulding. Also checking for rubber trapped in gates. 15:30 - 16:00 0.50 WELLSR SEQP WRKOVR , Install wear ring. 16:00 - 19:00 ' 3.00 WELLS RURD WRKOVR I Begin making up rev-circulating junk basket BHA for cleanout run. ~ 19:00 - 00:00 5.00 WELLSR TRIP I WRKOVR ; Begin RIH with cleanout BHA. Nnntea: ~ i~[u[uus a:4a:[5 nm • • ConocoPhillips Alaska Page s of ~~ Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: WORKOVER/RECOMP .Start: 10/17/2005 End:. 11/13/2005 Contractor Name: N3SCM@conocophillips.com Rig Release: 11/13/2005 Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Code Phase Description of Operations -. _ _- 11/1/2005 ~ 00:00 - 01:15 1.25 WELLS TRIP WRKOVR Continue RIH with cleanout BHA. PUH; set down at 3565'. PUH, clean pickup. Rig up to rev-circulate. Circulate bottoms up plus @ 4 bpm, resume RIH. Obstruction appears gone. RIW 28k, PUW=65k. 01:15 - 03:00 1.75 WELLS TRIP WRKOVR Lose wgt again at stand #72 (4600') roughly last spot we pulled heavy through last night. Install head pin and rig to rev-circulate. 03:00 - 05:00 2.00 WELLS WASH- WRKOVR Begin rev-circulating at 4 bpm; circulate bottoms up plus. Remove head pin and begin running back in hole. Set down 30' deeper. Remove a single and make up head pin again; begin stripping through bag while running in rev-circulating at 4 bpm. 05:00 - 07:00 2.00 WELLS WASH WRKOVR Continue RIH. Still seeing an occasional "bobble", possible pushing something down with us. Stop every 4-5 stands in and circulate bottoms up at 4 bpm @ 420 psi, plus. RIW=25k, PUW=70k. Seeing lots of sand at the shaker, CP=650 psi. Continue to circulate until it cleans up, pumping 3# bio sweeps. 07:00 - 08:00 1.00 WELLS WASH WRKOVR Resume running in hole, rev-circulating bottoms up plus after every 5 stands. Change out shaker screens. 08:00 - 11:30 3.50 WELLS WASH WRKOVR Have RIH to 5460'; continue to rev-circulate at 4 bpm. Pump 25 bbl bio sweep; pump one in as one exits. Last sweep was clean, nothing back on this sweep. 11:30 - 12:00 0.50 WELLS TRIP WRKOVR Blow down lines and start POH. 12:00 - 15:00 3.00 WELLS TRIP WRKOVR Start hanging up @ 4920'. Pulled 30K over to keep moving. Dragging up to 4790'. Broke free back down to normal string wt. Lowered back down to 4920' start taking wt. Set all of string wt down. Picked up dragging back up to 4790'. Pulled free. POOH. 15:00 - 16:30 1.50 WELLS TRIP WRKOVR Finish POOH laying down BHA. Cleaned out junk basket. Had several approximately 1" pieces of cast from retainer. 16:30 - 23:30 7.00 WELLS TRIP ~ WRKOVR Remove casing scraper from rev-circ BHA, keep 8-5/8" string mill in place for drift. Swap out finger catch back to flapper style. Begin RIH. 23:30 - 00:00 0.50 WELLS TRIP WRKOVR 75 stands in hole; Rig up to circulate. 11/2/2005 00:00 - 01:00 1.00 WELLS WASH WRKOVR Cont: 75 stands in the hole. Tie in ASRC pump to assist with rate. begin running in singles stripping through bag while reverse circulating #hrough tie-back area. Having difficulties stripping through bag, no pipe wgt. RIW=25k, PUW=70k. 01:00 - 02:45 1.75 WELLS WASH WRKOVR 75 stands in and 2 singles (4855') tag up. Begin rev-circulating at 7 bpm, pump 2 bttms up. Bleed off, open bag and make several drift passes through tight spot (trash) with string mill. Resume stripping in ~ single #3 while rev-circulating at 3-5 bpm, seems clear. Note: did see hose jump as large piece of debris was washed to surface, unable to find at the shaker. Hole take approx 0.75 bpm while circulating at 7 bpm, 620 psi. 02:45 - 04:30 ~ 1.75 WELLS WASH i WRKOVR Strip down single #4 to 4935' while rev-circulating 3-5 bpm. Pull back out of hole through tie-back while rev-circulating at 5-6 bpm, laying the 4 singles back down. 04:30 - 05:00 0.50 WELLS TRIP ~ WRKOVR Run back in hole, set down (12k) at 5010'. Try to work into pipe. RIH i ~ to 5030' without seeing anything else. ~ 05:00 - 08:00 ~ 3.00 ~ WELLS CIRC ~ WRKOVR Rig up head pin and begin reverse-circulating at 7-8 bpm. Pump 25 bbl ~ high-vise sweep and circulate around. Returns showed approx. 10 gals j i of sand and metal shavings. Fluid losses increased to approx. 1.25 ~ BPM. Shut down pumps, blow down lines, prep to POOH. ~ 08:00 - 09:00 ' 1.00 ~ WELLS TRIP WRKOVR Pull out of hole slow looking for any drag with ASRC pump on standby. ~ i i ~ i Pulled up to 3700' no indications of drag or trash. Released ASRC I pump. 09:00 - 13:00 4.00 ~ WELLSR TRIP j WRKOVR ~ Continue to pull out of hole. Layed dow BHA, cleaned out reverse junk Pnntetl: 11/22/"LUUS 9:413:15 AM • • ConocoPhillips Alaska Page ~ of 1a Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005. Event Name: WORKOVER/RECOMP Start: 10/17/2005 End: 11/13/2005 Contractor Name: N3SCM@conocophillips.com Rig Release: 11/13/2005 .Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 11/2/2005 09:00 - 13:00 4.00 WELLS TRIP WRKOVR basket. Retrieved approx. 1 cup of composite material and small cast debris. 13:00 - 16:30 3.50 WELLS PULD WRKOVR Picked up the EXPatch and running/setting tool and made up same. 16:30 - 21:30 5.00 WELLS TRIP WRKOVR PJSM covering details of running the EXPATCH. RIH with the FJCPatch and setting assembly on the 3-1l2" HT38 drill pipe. 21:30 - 22:00 0.50 WELLS TRIP WRKOVR 55 stands in the hole; everything looks good, hole appears clean to here. Order out inhibited brine, verify timing of Hot Oil pump. 22:00 - 00:00 2.00 WELLS TRIP WRKOVR 75 stands (plus a single) in the hole. Have pre-job review depths/ setting procedure with Baker reps/completion eng/toolpusher/etc. Discuss corrosion inhibtor placement; decide to omit from procedure-- virtually noway to spot and concern over washing trash back into patch setting area. 11/3/2005 00:00 - 00:30 0.50 WELLS SFTY WRKOVR 27k RIW, 57k up. On depth at 25..5' in on stand #75 (single in hole as well) placing BHA at 4873.67, top of element on seal jt at 4849'. Conduct pre-job with rig crew /Hot Oil regarding setting procedures, pressures, safety. 00:30 - 00:50 0.33 WELLS CIRC WRKOVR Drop setting ball and make up headpin. P/T Hot Oil /standpipe to 4500 psi. Come online with Hot Oil @ 1 bpm, 150 psi. 00:50 - 01:00 0.17 WELLS CIRC WRKOVR 25 bbls away. Bring rate up to 1.5 bpm. 01:00 - 02:00 1.00 WELLS CIRC WRKOVR 30 bbls away, ball on seat, see pressure rise. Drop rate to 0.5 bpm and begin setting sequence. At 3500 psi, see piston stroking, cont. up to 4500 psi--movement has stopped. Shut down and bleed off. RIH w/ pipe, verify 11' of travel. Re-attempt to stroke patch further...pressure up to 5000 psi on drill pipe. No movement. Confer w/ Baker Reps. Appears we are stacked out expanding through RS nipple. At max. pressure for rig equipment and Hot OiI pump. 02:00 - 03:00 1.00 WELLS OTHR WRKOVR Regroup and explore options. Call out cement pumper; find they are currently working at Doy 141, but finishing soon. Will attempt to set patch at higher pressure (6-7k). 03:00 - 06:30 3.50 WAITON EOIP WRKOVR On stanby for cement pumper. Perform rig maintenance. Conduct H2S drill. 06:30 - 09:45 3.25 WELLS RURD WRKOVR RU Schlumberger hardline from pump truck to headpin. Tested lines to 6000 psi 09:45 - 11:15 1.50 WELLS PLGM WRKOVR Opened valve. Filled lines with 1.5 bbls. Press up to 5500 psi short stroked seal jt thru RS nipple @ 4852' press dropped down to 3300 psi to complete the stroke. Bled press off, opened valve, slacked off 8'. (Total of 19' has been swedged leaving 10' remaing to swedge. Pulled -cone back thru RS nipple and liner hanger. Pulled cone thru RS nipple with 140K. Picked up to upper hanger and first tried with 250K, 190K over pull. Worked up to 280K max. Pulled free approx. 1' still stuck. Slacked off to 240K, pulled free back to string wt of 60K. Decision made to POOH, run back with 7.915" cone with jars and collars. 11:15 - 14:00 2.75 WELLS RURD WRKOVR RD hardline and prep to POOH. Closed bag and press test 9-5/8" casing and patch to 1000 psi held for 15 min. 14:00 - 18:50 4.83 WELLS TRIP WRKOVR POOH with workstring and Baker EXPatch running tool. Pull wet,. dropped ball to open circ sub. Continue to POOH. i 18:50 - 21:30 2,67 WELLSPo RURD WRKOVR At surface; break down BHA...swap out swedge with back-up which ~ i was turned down 1/100" at BakerMachine. Make up new BHA adding ~ i (2) drill collars, jars, and accelerator. 21:30 - 00:00 2.50 WELLSa TRIP I WRKOVR i Begin RBIH with new swedge/BHA. 11/4/2005 00:00 - 02:00 200 WELLS TRIP WRKOVR ~ Continue tripping in hole with patch setting BHA. Call out SLB cementers for pump support. i 02:00 - 03:00 i 1.00 WELLSFj PLGM ~ WRKOVR Tag up 23' in on top joint of stand #74 (plus a single) putting us on I I I rnncea: i utucuuo a:vo.co ruvi ConocoPhillips Alaska Page ~o of ~4 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud. Date:. 6/26/2005 Event Name: WORKOVER/RECOMP Start: 10/17/2005 End: 11/13/2005 Contractor Name: N3SCM@conocophillips.com Rig Release: 11/13/2005 .Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 11/4/2005 02:00 - 03:00 1.00 WELLS( PLGM WRKOVR depth. Note: drifted through top of patch cleanly. Pull mousehole, rlg up cementers through hole in floor. P/T pump line to 6200 psi--good. Conduct pre-job safety meeting. 03:00 - 04:00 1.00 WELLS PLGM WRKOVR Come online w/ SLB cement pumper, pressure up to 2200 psi to 1800 psi...see expansion tool stroke remainder of the way out of patch- 10'(visually saw it pop through). Bleed off, RIH and bury stand #74 ... appears to be clear. Pick up a single and RIH to 4882' for drift (swedge cone OD=7.915"). 04:00 - 05:00 1.00 WELLS TRIP WRKOVR Rig down SLB pumpers; clean up rig floor. Begin POOH. Hang up again with swedge in area of lower hanger. Pull 150k, pop through: POOH above patch, (2) stands and a single, and rig up for MIT. 05:00 - 06:30 1.50 WELLS DEQT WRKOVR Close bag; bring up 9-5/8 x drill pipe annulus press to 2500 psi. Monitor and chart OA press= lost 0 psi in 30 min. Bled off press. Dropped ball to open tire. sub, blew out at 1500 psi. 06:30 - 13:00 6:50 WELLS PULD WRKOVR POOH standing back drill pipe. LD EXPatch running tools. Clear rig floor and prep for running retrieving tool for RBP. 13:00 - 00:00 11.00 WELLS TRIP WRKOVR Make up retrieving tool on workstring, RIH 11/5/2005 00:00 - 01:00 1.00 WELLS .TRIP WRKOVR 145 stands, 3 singles (9275'); PUW=105k, RIW=20k. Make up headpin.. 01:00 - 02:30 1.50 WELLS RURD WRKOVR Rig up 2" hose to hardline in teller to kill tanks. Line up trucks from displacement. Conduct pre-job safety meeting w/ ARSC, rig crews, Baker rep. 02:30 - 08:15 5.75 WELLS CIRC WRKOVR Rev-tire 25 bbl visc/caustic sweep chased by new 8.9 brine, circulating to kill tanks @ 4.5 bpm. Recip pipe in between truck swaps. Pumped until fluid cleaned up, switch last 100 bbls 8.9 ppg to pits. 08:15 - 14:00 5.75 WELLS TRIP WRKOVR PU to get up wt =120K. Attempted to run in and latch onto RBP, stacked out all of wt and would not go down. PU 5' twice and lost 5' each time, would not go down. Pulled drill pipe out of hole with the intention of adding drill collars and heavy w# pipe to push down and retrieve RBP. Pulied up to 8170' and attempted to go down but stacked out. 14:00 - 21:00 7.00 WAITON OTHR WRKOVR Shut down, closed rams and pressured up to 1000 psi test casing. Held OK. Ordered 290 bbls 8.9 ppg Lube. Wait on Lube. 21:00 - 22:00 1.00 WAITON OTHR WRKOVR Brine on location; still waiting on load os "slick" fluid. 22:00 - 23:00 1.00 WELLS SFTY WRKOVR Fluid on loc. Spot up trucks. Conduct pre-job safety meeting. 23:00 - 00:00 1.00 WELLSFZ~ CIRC WRKOVR Come online w/ rig pump circulating Flo-Pro w/3% EP Lube Friction reducer around the long way back to the pits. 290 bbls tube pumped, displace with 54 bbls new 8.9 brine. 11/6/2005 00:00 - 00:30 0.50 WELLS CIRC WRKOVR Continued. Circulating Flo-Pro w/3% EP Lube Friction reducert around to lubricate. 290 bbls pumped, chased with 50 bbls of 8.9 brine (left 5 bbls in dp). Perform BOP drill. 00:30 - 02:00 1.50 WELLS TRIP WRKOVR RIH w/drill pipe...having to work in hole PUW=108k, RIW=15k. Run stand 131 in hole, begin picking up heavy wgt pipe. Run 15 jts of heavy ~ wgt in; back on stands. 02:00 - 03:00 i 1.00 WELLS CIRC I WRKOVR Drillpipe running over while tripping; stop, rig up head pin and mix up ~ dry job. 03:00 - 04:30 i 1.50 WELLS TRIP WRKOVR Resume tripping back in hole. 04:30 - 07:00 2.50 WELLSf WASH WRKOVR Tag up approx. 30' above RBP. Review tallies, discuss. Rig up to wash ~ down to top of RBP. Begin circulating at 3 bpm, 300 psi .See pipe ~ "drop through" top of 7" liner slack off 10', tag bottom of 7" liner tie back sleeve @ 9326'. Circulated @ 3 bpm w 300 psi tied to work past several times but would not go. 07:00 - 10:30 3.50 ~ WELLSR PLGM I WRKOVR PU Kelly and test. rnntea: tvcuLUUS a:au:~of+m r1 LJ ~1 u ' ConocaPhillips Alaska Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: WORKOVER/RECOMP Start: 10/17/2005 Contractor Name: N3SCM@conocophillips.com Rig Release: 11/13/2005 Rig Name: Nabors 3S Rig Number: Page 11 or" 14 Spud Date: 6/26/2005 End: 11 /13/2005 Group: Date From - Yo Hours Code Sub Phase Description of Operations Code 11/6/2005 10:30 - 11:30 11:30 -13:00 13:00 - 00:00 11 /7/2005 00:00 - 03:00 03:00 - 04:30 04:30 - 15:00 15:00 - 22:00 22:00 - 00:00 11 /8/2005 00:00 - 03:00 03:00 - 05:00 05:00 - 18:30 ~ 18:30 - 20:12 20:12 - 20:31 20:31 - 22:00 22:00 - 00:00 1.001 WELLSFa PLGM 1.501 WELLSPoOBSV 11.001 WELLSRTRIP 3.00 WELLSRTRIP 1.50 WELLS TRIP 10.50 WELLS PULD 7.00 CMPLTN RUNT 2:00 CMPLTN RUNT 3.00 WELLS SLIN 2.001 CMPLTNITRIP 13.50 CMPLTNITRIP 1.701 CMPLTNI PULL 0.321 CMPLTNI DEOT 1.481 CMPLTNI CIRC 2.001 CMPLTNI PULL WRKOVR Ran down tagged liner top again: Rotate off, ran 10' tagged bottom of tie back sleeve again. Broke circulate @ 3bpm w/ 380 psi. Rotated thru, RIH and tagged RBP @ 9352'. Pressure increased to 440 psi. Shut pump down. PU pulled RBP 5' up hole. Wait 5 min. let plug relax. Slacked off 6' lower than where we picked up plug. WRKOVR Picked up on kelly, monitored well. Fluid dropped. Lost 19 bbls in 5 min. Filled hole, monitored well, losing fluid at approx. 25 bph WRKOVR Began POH laying down workstring. Called state to discuss weekly BOP testing due Monday (tomorrow); state (Chuck Sheve) waived need if running new completion. Fluid loss at midnight approx. 16 bbls/hr. WRKOVR Cont. Pulling out of hole with RBP, pumping hole fill every 10 jts. WRKOVR Fluid loss has dropped to approx. 10 bbls/hr. WRKOVR At surface with RBP; break out and lay down BHA. Begin running in hole the remaining. 5 stands of drill pipe in the derrick and pull back out breaking singles, laying down. Lay down. Kelly,pull wear ring, clear rig floor. Unload pipe shed and begin bringing ESP equipment into pipe shed to warm up. Bring in last 41 jts. 4-1 /2" IBTM, strap and drift. RU power tongs for 4.5" completion. Change Xover for floor safety valve. WRKOVR Rig up spooling unit, raise cable sheave and string power cable. Pick up ESP completion assembly. Make up per weH plan / Centrilft specifications. Fluid losses approx 3 bbl / hr. WRKOVR Ready to run in hole. Rlg up wireline equipment; prep to run pump and I packoff assembly in hole.. Make up last of pump assembly and run in hole with pump /packoff on slickline. WRKOVR Continued. Running in hole with slickline w/4.5" GS i~ 38.5'OAL ESP Pump. Set pump. RIH w/ 4.5" Packer stinger assy. 103" OAL, 94" to KOBE Knock off to same tap down shear off beat down more. RIH w/3" SS & D&D test tool to top of packer shear off POOH. Pressure tested packer to 1000 psi good test. RIH w/3" JDC to 106' WLM, latch test tool, POOH. RIHw/4.5" GS & 4.5"sloip stop to top of packer. POOH and rig down Halliburton and resume running in hole with completion. Install clamps per well plan / Centrilift recommendations. WRKOVR Rig up hose to fill tubing off of charge pump. Well taking approx. 1 bbl/hr. WRKOVR Continue running in hole with ESP completion. PJSM with day crew. Install GLM @ 8669' w/3000 psi SOV & @ 2090' w/Dummy. Filling tubing. with fluid every 1000'. Ran with cable clamps on every collar of first 4100' of tubing and every other collar on connections above the patch @ +/- 4800' MD. Performed electrical inspection /test on ESP cable and TEC wire every 1000'. Saw a small wt jump when GLM went thru top of casing patch. Test ESP cable, good test. Continue in hole. WRKOVR Meg report on ESP cable shows direct ground. POOH to last meg depth of 5,372'. We will re-meg cable at this depth to confirm. If cable still megs negative. Continue to POOH and monitor cable for physical damage. Alert wire line for possible pump extraction and GLV change out. WRKOVR Meg test failed. Prepare to shear out valve at GLM #1. Shear out ~ pressure is 3,000 PSI. WRKOVR ~ Unable to shear the SOV. Several attempts of pressures up to 4,500 PSI with no luck. Prepare to POOH wet. New gloves on location to assist in pulling seal rings from tubing. WRKOVR Continue to POOH with completion string. Wireline on call to assist with SOV and pump. rnnceo: _i vmtwo a:4a:~o rvvi • ~ ConocoPhillips Alaska Page 12 of ~4 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 .Spud Date: 6/26/2005 Event Name: WORKOVER/RECOMP Start: 10!17/2005 End: 11/13/2005 Contractor Name:. N3SCM@conocophillips.com Rig Release: 11/13/2005 Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Code Phase Description of Operations 11/9/2005 00:00 - 12:30 12.50 CMPLTN PULL WRKOVR Continue POOH wet. Centrilift hand says that a kink in the ESP control cable at +-3,831' RKB. This will need to be repaired while RBIH. 12:30 - 14:00 1.50 CMPLTN PULL. WRKOVR Pulling out of hole, found bad clamp at 1357', cable visually good shape at this point. Continued to pull found camp missing from connection @ 1201', and cable severed. Cable bad in several places and clamps mangled up. Lost 1 clamp only. 14:00 - 18:00 4.00 CMPLTN PULL WRKOVR Layed down GLM. RU Halliburton 18:00 - 21:00 3.00 CMPLTN SLIN WRKOVR Pull pack off with wireline. Several issues with pump attempting to pull with pack off. After 35 spang licks was able to pull packoff. Pull pump to surface and dog collar. Release HES. Top stage of pump is seized up.. 21:00 - 23:00 2.00 CMPLTN PULL WRKOVR Pull motor slowly to surface watching for lost clamp. Damage to clamp above handling. pup.. Lay down motor and ESP cable,_ 23:00 - 00:00 .1.00 CMPLTN OTHR WRKOVR OOH. Clean rig floor and prepare for test plug to be inserted for BOPE gate opening. 11!1012005 00:00 - 02:00 2.00 WELCT NUND CMPLTN Set plug in landing profile and open gates to visually inspect for lost Cannon clamp. No clamp. Reseal gates and prepare for BOPE test. Test waived witness by Lou Gramaldi. 02:00 - 06:00 4.00 WELCT BOPE .CMPLTN BOPE test. Test Variable boreRams, blinds, and valves to 250/3000 psi and annular to 250 / 2500. Install wear ring. Inspect KIC tent for storage of power swivel and power pack. 06:00 - 11:00 5.00 WAITON EOIP CMPLTN Waiting on Baker Junk Shoe and Baker KB retrievable packer & Kobel Knock out plug. 11:00 - 18:00 7.00 CMPLTN OTHR CMPLTN Pulled wear ring back out. Removed ESP cable from spooler, installed new 7000' ESP cable in Spooler. 18:00 - 23:00 5.00 WAITON EOIP CMPLTN Continue waiting on Baker Junk Shoe and Baker KB retrievable packer & Kobel Knock out plug. 23:00 - 00:00 ,.11/11/2005 00:00 - 02:00 02:00 - 08:00 08:00 - 11:00 1.00 CMPL 2.00 WAIT( 6.001 CMPLTNI PULD SFTY CMPLTN Pre-job safety meeting. Load pipe shed with BHA and confirm straps. ORDR CMPLTN Discuss with anchorage issues with junk catcher fluid bypass: Tool is good to go. CMPLTN Begin Centrilift installation procedures. PU 7.5" OD junk catcher on bottom of motor centralizer, pressure sensor and motor. Fill motor with prescribed lubricant and allow for air to pass. Pick up Seal Section and assemble to the motor section. Service Seal Section. Splice in motor lead to new ESP power cable reel. Feed motor lead extension cable through sheave to floor and connect. Lower unit in well, connect pump receptacle assy. to top of seal section. Continue to run assy. in hole installing Cannon single-channel cross coupling cable clamp on each jot. Install the a-well Discharge Sub and connect capillary to pressure sensor. Run 2jt. 4.5" tubing. CMPLTN RU Halliburton Slick line. Fill hole. RIH with pump assembly on slick line and set pump in pump housing. Ran pack off stinger, tubing pack off, press test to 1000 psi and run tubing stop. RDMO slick line. CMPLTN PU and RIH with 1jt.4.5" tubing w/ 4.5" Baker KB retrievable packer and Kobe knock out plug already installed in jt to allow the tubing to be run dry to decrease drag on tubing clamps. Continue RIH with ESP assembly on 4.5" tubing installing Cannon single-channel cross-coupling cable clamps on each jt. Witnessed no bobbles entering patch at 4,842'. Tagged up at 5,095'. Set 5K dwn wt. on pipe. Pulled up 10' for re-attempt with max wt 5K DWN. Making no hole. Called Anchorage and discuss options. Decided to use 16,000# as max DWN wt. Current pick up wt = 36,000#, free float WT = 26,000#. Blocks = 3.00 CMPLTNI PULD 11:00 - 23:30 I 12.501 CMPLTNI RUNT rnntea: i u[ozuua y:4o:[o r+m tr1 ~ ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: WORKOVER/RECOMP Start: 10/17/2005 Contractor Name: N3SCM@conocophillips.com Rig Release: 11/13/2005 Rig Name: Nabors 3S Rig Number: Date 11/11/2005 From - To Hours Code Code Phase 11:00 - 23:30 12.50 CMPLTNI RUNT CMPLTN 23:30 - 00:00 0.501 WAITON ORDR CMPLTN 11/12/2005 00:00 - 01:30 01:30 - 02:00 02:00 - 02:30 1.50 WAITON ORDR CMPLTN 0.50 CMPLTN SFTY CMPLTN 0.501 CMPLTNI PULL CMPLTN 103:00 - 03:30 0.50 CMPLTN KURD CMPLTN 03:30 - 08:00 I 4.501 CMPLTNI RURD I CMPLTN 08:00 - 09:30 1.501 CMPLTNI RURD CMPLTN 09:30 - 11:00 I 1.501 CMPLTNI RURD I CMPLTN 11:00 - 18:00 7.00 CMPLTNI PULD CMPLTN 18:00 - 21:30 3.50 WELCT NUND CMPLTN 21:30 - 22:00 0.50 WELCT NUND CMPLTN 22:00 - 00:00 2.00 WELCT NUND CMPLTN 11/13/2005 00:00 - 02:10 2.17 WELCT NUND CMPLTN 02:10 - 04:00 1.83 WELCT BOPE CMPLTN 04:00 - 04:30 0.501 CMPLTN KURD. CMPLTN 04:30 - 07:00 2.50 ~ CMPLTN NUND CMPLTN 07:00 - 08:30 ~ 1.501 CMPLTN DEOT ,CMPLTN 08:30 - 15:00 6.50 ~ CMPLTNf NUND ;CMPLTN Page 13 of 14 Spud Date: 6/26/2D05 End: 11 /13/2005 Group: Description of Operations 10K. Two attempts at 16K dwn wt. No movement. Anchorage to discuss with assets. Wait on decision from asset. Monitor well. Bring tubing. hanger assembly into pipe shed to warm up for inspection. In discussions with Anchorage as to which avenue to pursue. Build new completion tally to reflect discussions with Anchorage as to completing well as-is-where-is. Prepare to POOH above pre-installed GLM 6 joints away and pull GLM out of original completion string. RBIH and complete well no deeper than 5,076' RKB. Hold pre job safety meeting for everybody to be on same page. POOH, remove GLM and replace with joint number 219 @ 27.82' long. Up wt = 36K. 15K overpuN to begin POOH. Pull out GLM and replace with tubing joint 219. RBIH to 5,043' to begin installation of tubing hanger: Orient tubing hanger and steam for thaw assist. Prepare for ESP pigtail install Make final splice of ESP cable to wellhead penetrator. Test cable & penetrato, good test. Double check orientation of hanger. Land tubing with extreme caution. RILDS. Back out landing jt. and wash out and drain BOP stack, lay down landing jt. Test hanger body seals and void to 5000 psi. Rig down sheave from derrick and Elephant trunk hose. Spool up cable end into spooler. RU tools to lay down 22 stands of 4.5" tubing out of 'derrick thru mousehole. RU tools and lay down 22 stands of 4.5" tubing out of derrick thru mousehole. Empty pits. Load out trucks with tubing and tools to go back. Pull mousehole, LD. Rig off BOP's and prepare to install production tree. Hold meeting in cellar. Production tree is not lining up with penetrator. Notice that looking into casing valve you can see 3/4" of hanger that has rotated clock ways. Galled AOGCC and asked Lou Grimaldi for permission to re-install BOPE and perform a body pressure test along with a function test of the rams. Permission granted with the exception of, (We are only allowed to pick up and turn the hanger. If further work is needed we will sit back down RILDS and re-visit the possibility of a Full BOP test.) Begin to re-instal{ BOP. Continue to rig up BOP and prepare for test. Begin BOP test. RIH w/landing joint pick up tubing hanger 4" and inguaged alignment pin. Land hanger. RILDS. Confirm by looking in casing valve at full guage hole. Tested upper and lower seals on hanger to 5000 psi. NDBOP. Cleaned void area, inspect landing head. Test penetrator and ESP cable, showed 30K OHM to ground. Called out 2nd service hand to double check readings determined that Phoenix guage needed to be check with reverse polarity. Retested reversing polarity and tested good. NU tree. Test hanger void / packoff to 250 /5000 psi. Pull BPV install 2-way check. Attempt to test tree, press up to 5000 psi and discovered hairline crack in tree bonnet just behind penetrator. Pressured up again to confirm leak, same results. Confirmed with VETCO Gray no replacement on slope. Change out 2-way check valve with BPV. Clean rnnceu. i ucucvw a.vo.w nm • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Event Name: WORKOVER/RECOMP Contractor Name: N3SCM@conocophillips.com Rig Name: Nabors 3S Date From - To Hours Code Sub Phase Code Start: 10/17/2005 Rig Release: 11/13/2005 Rig Number: Page 14 of 14 Spud. Date: 6/26/2005 End: 11 /13/2005 Group: Description of Operations 11/13/2005 08:30 - 15:00 6.50 CMPLTN NUND CMPLTN tree and cellar. Released rig @ 1500 hrs on 11-13-2005. 15:00 - 19:00 4.00 MOVE MOVE CMPLTN Prepare rig for move to 1 E-166. Scoped derrick down @ 1700 hrs. 19:00 - 20:00 1.00 MOVE MOVE CMPLTN Move rig off of 1 E-170 and begin preparations for spotting up on 1 E-166. 20:00 - 00:00 4.00 MOVE MOVE CMPLTN Continue spotting rig on 166. Printed: 111222005 9:48:25 AM Ll~~Id ..'i e~i,., Halliburton Sperry-Sun Western North Slope ConocoPhillips Kuparuk 1 E 1 E-170L2 Job No. AK-ZZ-0003778283, Surveyed: 1 September, 2005 Survey Report 26 September, 2005 Your Ref: 500292326461 • Surface Coordinates: 5959339.91 N, 549889.64E (70° 1T 58.8873" N, 149° 35'45.4351" 4 Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 959339.91 N, 49889.64E (Grid) Surface Coordinates relative to Structure: 420.32 S, 2.66 W (True) Kelly Bushing Elevation: 111.05ft above Mean Sea Level Kelly Bushing Elevation: 111.05ft above Project V Reference Kelly Bushing Elevation: 111.05ft above Structure 5~ "~t'~~/-~5'Uf"'1 GRILLING SERVICE'S SurveyRef.•svy2166 A Halliburton Company Halliburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-170L2 Your Ref:500292326461 Job No. AK-ZZ-0003778283, Surveyed: 1 September, 2005 Western North Slope ConocoPhillips Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 9398.24 81.360 181.100 3161.46 3272.51 7925.78 S 882.28E 5951420.17 N 550824.52E 7925.78 Tie-On Point 9412.00 81.380 181.160 3163.53 3274.58 ~ 7939.38 S 882.01E 5951406.56 N 550824.34E 0.455 7939.38 Window Point 9499.63 90.830 181.630 3169.48 3280.53 8026.68 S 879.88E 5951319.25 N 550822.80E 10.797 8026.68 9599.28 91.730 181.880 3167.25 3278.30 8126.26 S 876.83E 5951219.65 N 550820.41E 0.937 8126.26 9699.87 90.740 181.490 3165.08 3276.13 8226.78 S 873.88E 5951119.12 N 550818.12E 1.058 8226.78 9738.62 92.080 182.240 3164.13 3275.18 8265.49 S 872.62E 5951080.39 N 550817.11E 3.963 8265.49 9836.69 91.610 182.940 3160.97 3272.02 8363.41 S 868.19E 5950982.45 N 550813.33E 0.859 8363.41 9930.77 90.740 182.040 3159.04 3270.09 8457.38 S 864.10E 5950888.45 N 550809.87E 1.330 8457.38 10025.10 91.670 181.030 3157.06 3268.11 8551.66 S 861.57E 5950794.16 N 550807.97E 1.455 8551.66 10117.95 90.970 180.520 3154.92 3265.97 8644.47 S 860.32E 5950701.34 N 550807.33E 0.933 8644.47 10216.93 88.990 181.410 3154.95 3266.00 8743.43 S 858.65E 5950602.37 N 550806.32E 2.193 8743.43 10316.15 89.110 180.590 3156.60 3267.65 8842.62 S 856.92E 5950503.17 N 550805.25E 0.835 8842.62 10415.18 90.100 182.930 3157.28 3268.33 8941.59 S 853.88E 5950404.18 N 550802.86E 2.566 8941.59 10515.37 89.180 179.590 3157.91 3268.96 9041.74 S 851.68E 5950304.02 N 550801.33E 3.458 9041.74 10613.92 90.910 181.500 3157.83 3268.88 9140.28 S 850.74E 5950205.48 N 550801.04E 2.615 9140.28 10712.50 89.110 177.040 3157.82 3268.87 9238.82 S 851.99E 5950106.95 N 550802.95E 4.879 9238.82 10809.23 90.290 177.650 3158.32 3269.37 9335.45 S 856.47E 5950010.36 N 550808.08E 1.373 9335.45 10908.78 90.530 177.180 3157.61 3268.66 9434.89 S 860.96E 5949910.94 N 550813.22E 0.530 9434.89 11008.70 92.010 177.940 3155.40 3266.45 9534.69 S 865.22E 5949811.17 N 550818.14E 1.665 9534.69 11108.19 91.770 178.300 3152.11 3263.16 9634.08 S 868.48E 5949711.81 N 550822.06E 0.435 9634.08 11207.73 89.540 177.390 3150.98 3262.03 9733.53 S 872.22E 5949612.38 N 550826.46E 2.420 9733.53 11306.51 89.110 176.620 3152.14 3263.19 9832.17 S 877.38E 5949513.78 N 550832.28E 0.893 9832.17 11403.39 90.410 175.850 3152.55 3263.60 9928.84 S 883.74E 5949417.16 N 550839.28E 1.560 9928.84 11499.33 89.170 177.170 3152.90 3263.95 10024.59 S 889.58E 5949321.44 N 550845.76E 1.888 10024.59 11599.92 90.470 180.540 3153.21 3264.26 10125.15 S 891.59E 5949220.91 N 550848.44E 3.591 10125.15 11700.74 91.090 179.570 3151.84 3262.89 10225.95 S 891.50E 5949120.10 N 550849.01E 1.142 10225.95 11799.59 90.230 180.150 3150.70 3261.75 10324.80 S 891.74E 5949021.26 N 550849.91E 1.049 10324.80 11898.74 90.910 180.630 3149.72 3260.77 10423.94 S 891.06E 5948922.12 N 550849.89E 0.839 10423.94 11997.93 90.840 180.440 3148.20 3259.25 10523.11 S 890.14E 5948822.94 N 550849.62E 0.204 10523.11 12097.23 90.590 181.690 3146.96 3258.01 10622.39 S 888.29E 5948723.66 N 550848.44E 1.284 10622.39 12196.13 90.720 180.950 3145.83 3256.88 10721.25 S 886.01E 5948624.78 N 550846.81E 0.760 10721.25 12293.65 90.910 179.760 3144.44 3255.49 10818.76 S 885.41E 5948527.27 N 550846.86E 1.236 10818.76 12391.40 89.790 175.520 3143.85 3254.90 10916.40 S 889.43E 5948429.66 N 550851.53E 4.486 10916.40 12490.47 89.980 176.160 3144.05 3255.10 11015.21 S 896.62E 5948330.90 N 550859.37E 0.674 11015.21 12588.64 90.530 177.330 3143.61 3254.66 1111322 S 902.19E 5948232.93 N 550865.60E 1.317 11 113.22 • • 26 September, 2005 - 10:39 Page 2 of 4 DrillQuest 3.03.06.008 Western North Slope Halliburton Sperry-Sun Survey Report for Kuparuk 1 E - 1 E-170L2 Your Ref.• 500292326461 Job No. AK-ZZ-0003778283, Surveyed: 1 September, 2005 ConocoPhillips Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 12688.01 89.420 179.520 3143.65 3254.70 11212.54 S 904.93E 5948133.62 N 550868.99E 2.471 11212.54 12786.13 90.530 181.130 3143.69 3254.74 11310.66 S 904.37E 5948035.51 N 550869.08E 1.993 11310.66 12886.43 90.350 182.180 3142.92 3253.97 11410.91 S 901.47E 5947935.24 N 550866.85E 1.062 11410.91 12984.94 91.400 183.220 3141.42 3252.47 11509.30 S 896.83E 5947836.82 N 550862.86E 1.500 11509.30 13083.32 91.520 181.400 3138.91 3249.96 11607.56 S 892.87E 5947738.53 N 550859.55E 1.853 11607.56 13182.40 91.580 182.810 3136.23 3247.28 11706.53 S 889.23E 5947639.54 N 550856.57E 1.424 11706.53 13280.33 91.890 183.690 3133.27 3244.32 11804.26 S 883.68E 5947541.78 N 550851.67E 0.952 11804.26 13380.33 91.520 182.030 3130.29 3241.34 11904.09 S 878.69E 5947441.92 N 550847.35E 1.700 11904.09 13477.86 91.460 180.620 3127.76 3238.81 12001.56 S 876.44E 5947344.44 N 550845.74E 1.447 12001.56 13577.12 91.650 180.620 3125.06 3236.11 12100.77 S 875.37E 5947245.21 N 550845.33E 0.191 12100.77 13675.44 91.710 178.630 3122.18 3233.23 12199.04 S 876.01E 5947146.95 N 550846.62E 2.024 12199.04 13773.91 91.770 177.170 3119.19 3230.24 12297.40 S 879.62E 5947048.62 N 550850.88E 1.483 12297.40 13873.15 90.780 179.320 3116.98 3228.03 12396.56 S 882.65E 5946949.48 N 550854.58E 2.385 12396.56 13972.06 91.400 179.130 3115.10 3226.15 12495.44 S 883.99E 5946850,61 N 550856.57E 0.656 12495.44 14070.40 90.910 180.360 3113.12 3224.17 12593.76 S 884.43E 5946752.30 N 550857.66E 1.346 12593.76 14169.87 91.330 182.110 3111.17 3222.22 12693.19 S 882.29E 5946652.86 N 550856.18E 1.809 12693.19 14268.86 91.340 181.010 3108.87 3219.92 12792.11 S 879.59E 5946553.92 N 550854.14E 1.111 12792.11 14368.21 91.580 181.440 3106.34 3217.39 12891.41 S 877.47E 5946454.61 N 550852.68E 0.496 12891.41 14466.28 90.600 181.870 3104.47 3215.52 12989.42 S 874.64E 5946356.59 N 550850.50E 1.091 12989.42 14564.68 90.720 180.890 3103.34 3214.39 13087.78 S 872.27E 5946258.21 N 550848.78E 1.003 13087.78 14657.36 91.090 180.970 3101.87 3212.92 13180.44 S 870.76E 5946165.55 N 550847.89E 0.408 13180.44 14748.65 92.320 182.290 3099.16 3210.21 13271.64 S 868.17E 5946074.32 N 550845.90E 1.976 13271.64 14841.13 92.700 180.550 3095.11 3206.16 13364.00 S 865.88E 5945981.95 N 550844.22E 1.924 13364.00 14934.92 92.880 180.320 3090.54 3201.59 13457.68 S 865.17E 5945888.27 N 550844.14E 0.311 13457.68 15027.10 91.710 179.790 3086.85 3197.90 13549.78 S 865.08E 5945796.17 N 550844.66E 1.393 13549.78 15120.34 90.220 179.510 3085.28 3196.33 13643.01 S 865.65E 5945702.95 N 550845.85E 1.626 13643.01 15213.13 89.240 180.030 3085.72 3196.77 13735.79 S 866.02E 5945610.17 N 550846.84E 1.196 13735.79 15304.02 90.840 183.770 3085.65 3196.70 13826.61 S 863.01E 5945519.33 N 550844.43E 4.475 13826.61 15394.15 92.300 184.560 3083.18 3194.23 13916.47 S 856.46E 5945429.43 N 550838.48E 1.842 13916.47 15486.31 92.960 184.190 3078.95 3190.00 14008.26 S 849.44E 5945337.60 N 550832.07E 0.821 14008.26 15579.21 90.220 184.160 3076.38 3187.43 14100.87 S 842.68E 5945244.94 N 550825.92E 2.950 14100.87 15670.11 90.230 180.980 3076.02 3187.07 14191.67 S 838.61E 5945154.12 N 550822.45E 3.498 14191.67 15715.03 91.270 179.140 3075.43 3186.48 14236.58 S 838.56E 5945109.21 N 550822.70E 4.705 14236.58 15748.00 91.270 179.140 3074.70 3185.75 14269.54 S 839.05E 5945076.26 N 550823.41E 0.000 14269.54 Projected Survey All data is in Feet (US Su rvey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical dept hs are relative to Well. Northings and Eastings are re lative to Well. • • 26 September, 2005 - 10:39 Page 3 of 4 DrilPQuest 3.03.06.008 t Western North Slope Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 15748.OOft., The Bottom Hole Displacement is 14294.19ft., in the Direction of 176.635° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 9398.24 3272.51 7925.78 S 882.28E Tie-On Point 9412.00 3274.58 7939.38 S 882.01E Window Point 15748.00 3185.75 14269.54 S 839.05E Projected Survey Halliburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-170L2 Your Ref: 500292326461 Job No. AK-ZZ-0003778283, Surveyed: 1 September, 2005 ConocoPhillips • Survey tool program for 1E-170L2 From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 826.00 815.65 To Measured Vertical Depth Depth (ft) (ft) 826.00 815.65 15748.00 3185.75 Survey Tool Description CB-SS-Gyro (1E-170P61) MWD+IIFR+MS+SAG {1E-170PB1) 26 September, 2005 - 10:39 Page 4 of 4 DriflQuest 3.03.06.008 • ConocoPhi[Iips Alaska Qperations Sulmmary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/5/2005 9/6/2005 9/7/2005 1 E-170 1 E-170 ROT -DRILLING Start: 6/21 /2005 D15CM@conocophillips.com Rig Release: Doyon 15 Rig Number: 15 I r=rom - To ; H 21:30 - 00:00 00:00 - 02:00 02:00 - 02:15 02:15 - 02:30 02:30 - 03:30 a 03:30 - 04:30 04:30 - 04:45 04:45 - 06:00 06:00 - 06:45 06:45 - 07:00 07:00 - 07:15 07:15 - 12:45 X12:45-13:00 ~~ 13:00 -13:15 ~, !13:15-13:45 13:45 - 14:00 I 14:00 - 14:15 I 14:15 - 16:00 ; i i 16:00 - 22:00 ' 122:00 - 22:30 Spud Date End: Group: Page 42 of 44 6!26!2005 ours Gode j ~ de ~ Phase Description,ofi Operations -- 2.50 CMPLTN N I TRIP ~ CMPLT3 '.POOH w! hook hanger running tools f/ 9260' to 4493'. ' 2.00, CMPLT ~ TRIP CMPLT3 ~ POOH w! hook hanger running tools f/ 4493 to BHA inner string 0.25 CMPLTN ' SFTY ~ CMPLT3 PJSM on UD inner string 2 7/8" 0.25 CMPLTN I OTHR CMPLT3 Clean rig floor. ; 1.00; CMPLTN I PULD ;CMPLT3 UD 2 7i8" inner string. 1.00 ~ CMPLTN PULD ~ CMPLT3 ~ Clear floor of tools. PU tools to PU 4 1/2" LEM. 0.25 ~ CMPLTN SFTY ~ CMPLT3 PJSM on running 4 1/2" LEM f! "D" lateral. ~ " 1.25' CMPLTf~ PULD CMPLT3 PU/MU 4 1/2 LEM consisting of :Baker seal assembly, (1) jt 4 1/2" 12.6 I j ppg L-80 IBT x STL, (7) jts 4 1/2" 12.6ppf L-80 IBTM tubing, 4 1/2" pup i 'jt, LEM, (3) 4 1/2" pup jts, 4 1/2" casing swivel, crossover bushing 5 1/2 i i ~ 563 x 4 1/2"IBT, 190-47 casing seal bore, crossover 7" x 5 1/2" 563, (1) Ijt 7" 26 ppf, L80 Hydril 563 casing 0.75: CMPLTN PULD ~ CMPLT3 .Make up 2 718" inner string to 9 5/8" x 7" ZXP liner top packer. 0.25 ~ CMPLTN PULD ~ CMPLT3 ~ Make up 9 5/8" x7" ZXP liner top packer, Check screws. OK. 0.25 ~ CMPLTN OTHR ~ CMPLT3 Clean rig floor, remove csg tools. 5.50! CMPLTNITRIP CMPLT3 RIH on 5" dp : 4 1/2" LEM consisting of :Baker seal assembly, (1) jt 4 ~ j 1/2" 12.6 ppg L-80 IBT x STL, (7) jts 4 1!2" 12.6ppf L-80 IBTM tubing, 4 ~ I~ ! 1/2" pup jt, LEM, (3) 4 1/2" pup jts, 4 1/2" casing swivel, crossover I i bushing 5 1/2 563 x 4 1/2" IBT, 190-47 casing seal bore, crossover 7" x ' 5 1!2" 563, (1) jt 7" 26 ppf, L80 Hydril 563 casing, Baker 9 5/8" x 7" ZXP ~ ~ ~ I liner top packer = 430.62' then Baker setting tool and 5' dp pup jt. Total of 441.59'. ~ ~ RIH 5 stands 5" slick (476.27, 74 stands 5" dp w/ to-tads (7316.41'), 12 1 {stands 5" HVWP(1105.62') w/ 21.1' up. PU wt 230k, SO wt 120k. 0.25 CMPLTNI TRIP ~ CMPLT3 'Slack off watching top of "D" lateral @ 9412.28' (did not see anything), ~ j ~ ~ Continue running stands of HWDP f/ derrick. Run stand 92, 93,94,95, ~ and 96. PU wt 245k SO wt 125k. 0.25 ~~ CMPLTN OTHR ~ CMPLT3 , ~ Continue RIH w/ stand 96 (17th stand of HWDP). Did not see crossover in "B" lateral @ 21' in (9728'), continue slack off to latch @ 3T in on stand 96 (9739' mule shoe depth) (9412,28' top of LEM in hook hanger " " " " ' of D lateral). Top of Casing seal receptacle in lot LEM a 9729.91 B , ' 0.501 CMPLTN CIRC CMPLT3 ~ bottom of casing seal receptacle @ 9749.31'. PU to 265k to verify latch. ;Drop 1 3/4" ball, pump down @ 5bpm w/ 500 psi f/ 100 bbls, slow to 3 ' 0.25 ~ CMPLTN PCKR CMPLT3 ~ bpm 300 psi, ball seated @ 120 bbls pumped. Pressure up to 3080 psi, set Baker ZXP packer @ 9308.62', presure to I j4000 psi to release. 0.25; CMPLTN OTHR i CMPLT3 j PU, PU wt 240K-245K (verified release). PU 20' f/ 9308' to 9288'. Slack off 40k down w/ dogs to mech set packer as well. PU 20' rotate down w/ f ; 40k on liner top pkr twice. 1.75',' CMPL 6.001 RIGMI 0.50; CMPL 22:30 - 00:00 I 1.50 00:00 - 03:00 3.00 03:00 - 03:15 0.25 03:15 - 04:00 ' 0.75 04:00 - 05:00: 1.00 05:00 - 05:15 i 0.25 TRIP I CMPLT3 RGRP I CMPLT3 TRIP I CMPLT3 CMPLTN TRIP ;CMPLT3 CMPLTN TRIP ;CMPLT3 CMPLTN SFTY (CMPLT3 CMPLTN PULD CMPLT3 CMPLTN OTHR ~ CMPLT3 CMPLTNI SFTY I CMPLT3 Monitor well, POOH w/ running tools f! LEM f/ 9308' to 8135'. PU wt I; 245k, SO wt 120k. Attempt to break out 1st stand LoTad. High torque 30k. Broke 1st Lo Tad w/ rig tongs w/ 30K. Repair/ replace top cylinder of iron roughneck breakout. POOH f/ 8135 to 7938'. Check out Iron roughneck by making breaks on 'stand 78, OK. Break & UD LoTad f/ stand 78. Pull stand 79, break and lay down LoTad f/ stand simulating laying down dp f/derrick and removing LoTads. OK. Continue POOH f/ 7938' to 5964'. 51 stands Lotads in hole @ midnight Continue POOH f/ 5964' to 80' 51 stands Lotads in hole. PJSM on UD LEM tools. UD LEM running tools. Pull Vetco/Gray wear bushing, clear rig floor. j PJSM on PU 7" Baker Model WG Bridge plug and Baker Heavy duty Printed: 9/92005 10:19:09 AM C l ConocoPhillips,Alasica Page 43'of 44 l Operations Summary Report i Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: ROT -DRILLING Start: 6/21/2005 End: Contractor Name: D15CM@conocophillips.com Rig Release: Group: Rig Name: Doyon 15 Rig Number: 15 Date `'From - To ' Hours ~ Gode ~ Code ' Phase j Description of Operations i 9/7/2005 05:00 - 05:15 ~ 0.251 CMPLTN SFTY CMPLT3 105 15 75 06 00 ~ CMPLTN P T D i Model "EA" retrievamatic, w/ 3 1/2" IF joint and 3 1/2" XT38 DP. " R l l 3 1/ " : - : ; 0. UL i CMPL 3 ug, (1) jt ~ MU 7 Baker Model WG etievab e Bridge p 2 13.3 dp 3 1/2" iF, Baker Heavy duty Model "EA" retrievamatic, crossover 3 1/2" IF ~ ~ ~ 06 00 08 45 ~ 2 75 CMPLTNI P LD CMP T3 I x 3 1 /2 XT38, 3 1/2" X738 DP. One joint made up @ 0600 hrs. i / " M WG R bl B id l 1 : - : . ~ U L nue RIH w 7 Baker etrieva r ge p ) jt 3 Cont odel e ug, ( ~ ~ ~ ~ 1/2" 13.3 dp 3 1/2" IF, Baker Heavy duty Model "EA" retrievamatic, ~ crossover 3 1/2" IF x 3 1/2 XT38, on 71 joints 3 1/2" 13.3ppf XT38. ~ ~ Rabbit dp to 2 5/16". Torque 3 1/2" IF Conn to 10k, XT38 Conn to 16.5k j 08:45 -13:45 ~ 5.001 RfGMNTi RGRP .CMPLT3 ft/Ib. ~ Trouble shoot and repair of pipe handling machine. Selonoid valve and i i spool. 13:45 - 14:45 I 1.00! RIGMNT~ RSRV I CMPLT3 14:45 -15:15 0.50 ~ CMPLTNI PULD .CMPLT3 Slip & cut 136' drilling line. Continue RIH w/ 7" Baker Model WG Retrievable Bridge plug, (1) jt 3 I j ~ 11/2" 13.3 dp 3 1/2" IF, Baker Heavy duty Model "EA" retrievamatic, crossover 3 1/2" IF x 3 1/2 XT38, on 71 joints 3 1/2" 13.3ppf XT38, then ' ~ start w/ 3 1/2" 15.5 ppf XT38, 44 jts of 15.5 ppf in hole now. Total of 115 I ~ j ~ ~ jts XT in hole. 15:15 - 18:00 ! 2.75 ~ CMPLTNI PULD ~ CMPLT3 Rabbit dp to 2 5/16". Torque XT38 corm to 16.5k ft/Ib. I Continue RIH w/ 7" Baker Model WG Retrievable Bridge plug, (1) jt 3 " " " " I ~ 1/2 13.3 dp 3 1/2 IF, Baker Heavy duty Model EA retrievamatic, ~ I i crossover 3 1/2" IF x 3 1/2 XT38, on 71 joints 3 1/2" 13.3ppf XT38, then ' I start w/ 3 1/2" 15.5 ppf XT38, 167 jts of 15.5 ppf in hole now. Total of ~ 238 jts XT in hole. 18:00 -19:45 { 1.75 ~ CMPLTtJI PULD ~ CMPLT3 i Continue RIH w/ 7" Baker Model WG Retievable Bridge plug, (1) jt 3 j ~ ~ 112" 13.3 dp 3 1/2" IF, Baker Heavy duty Model "EA" retrievamatic, ~ crossover 3 1/2" IF x 3 1/2 XT38, on 71 joints 3 1/2" 13.3ppf XT38, then ~ I f start w! 3 1/2" 15.5 ppf XT38, 167 }ts of 15.5 ppf in hole now. Total of 295 jts XT Picked up. Tag 9.04' in on jt # 295. PU wt 165k SO wt 75k. ~ 19:45 - 20:00 j 0.251 CMPLTNI OTHR 'CMPLT3 , ~ MU crossover on jt 295, MU top drive and tag top of liner @ 9308' (9.04' I ~ in on jt 295), bottom of bridge plug @ 9354.94'. PU, Break off single and drop 1-1/2" ball. 120:00 - 20:30 ~ 0.50 ~ CMPLTN PCKR ~ CMPLT3 MU single, SO tag liner top, PU 6' above tag, circ ball to seat @ 3bpm I ~ w/ 700 psi. Pressure up @ 50 bbls pumped. Pressure to 2300 psi. Pick ~, I i ~ I up to 180k, shear off of bridge plug. Bridge plug top @ 9346.24', bottom @ 9348 Length of bridge plug 2 70' 94" 20:30 - 21:00 0.50 i CMPLTN PCKR I CMPLT3 . . . ~ UD 2 jts, PU jt w/ x-o, MU top drive.Jt # 293 in hole while testing, jt 294 ~ 21:00 - 23:00 ~ 2.00 CMPLTN CIRC ~ CMPLT3 ~ above rig floor. 9308' bottom of tool ~ Circulate bottoms up @ 5bpm w/ 1880 psi. Circ 600 bbls. 123:00 - 23:15 0.251 CMPLTNI DEQT CMPLT3 ~ RU to test Baker 7" Model WG Retrievable bridge plug set @ 9346.24' , ' ' 23:15 - 00:00 ~, 0.75 i CMPLTNI DEQT i CMPLT3 ZXP liner top packer @ 9308 w/ test pkr @ 9259 . ~ Rotate 5 turns to set packer. Set down 5k. Attempt to test Retrievable 1 ~ ~ I j bridge plug. No test. PKR depth 9259'. Not enough weight to set test pkr. Circulating to surface. 3/8/2005 i 00:00 - 00:30 ': 0.50, CMPLTNI DEQT !CMPLT3 ~ I j j Attempt to test Retrievable bridge plug & ZXP packer. No test. PKR ~ depth 9259'. Not enough weight to set test pkr. Only 5k above block 00:30 - 02:00 1.501 CMPLTNI TRIP ~ CMPLT3 'weight. Circulating to surface. I POOH Ud 5 jts of 3 1/2" 15.5 ppf XT38 dp. Stand back 11 stands in I , 02:00 - 02:30 I 0.50 ~ CMPLTN TRIP CMPLT3 derrick to 8211' I Trip in hole w/ 11 stands 5" HWDP f/ 8211' to 9090'. 10 stands HW in i i hole. PU wt 190k. SO wt 105k. 02:30 - 03:00 ! 0.501, CMPLTNI DEQT ~ CMPLT3 RIH f/ 9090' to 9163' (element center @ 9114'). Apply 5 rounds RH wl I8k torque. Set test packer w/ 35k down wt to 70k block wt. Attempt to test, no test, PU to 9114', set 35k down wt. Printed: 9/9/2005 10:19:09 AM C: • ConocoPhillips Alaska Page 4a of a4 Operations Summary Report Legal Well Name: 1 E-170 Common Well Name: 1 E-170 Spud Date: 6/26/2005 Event Name: ROT -DRILLING Start: 6/21/2005 End: Contractor Name: D15CM@conocophillips.com Rig Release: Group: Rig Name: Doyon 15 Rig Number: 15 'Sub ', Qate ~~ From - To< HOUFS ! Code. ~ ~ Phase ~ ~ Description of Q~eratlons 19/8/2005 !Code; 03:00 - 03 45 j 0.75 CMPLTN DEQT CMPLT3 ~ Test RBP @ 9346', ZXP liner top packer @ 9308' w/ test packer @ I 9114'. Test to 2540 psi. Chart test. Held 97.3% of test pressure in 30 ~ 03:45 - 04:00 ~ 0.25I CMPLTN~ OTHR CMPLT3 min. Pressure lost 68 psi f/ 2540 to 2472 psi. ~ Bleed off pressure, unset packer. 04:00 - 04:30 ' 0.50 ~ CMPLTNI TRIP I CMPLT3 4 30 05 1 5 CM MP ~ ~ POOH f/ 9114' to 8170' w! 5" HWDP. 3 1/2" 1/ 1/ t ' " " : - : I 0 5 , 0.7 PLTNI TRIP C LT3 dp, PU 4 j s UD single 3 2 DP, TIH 11 stands 3 2 dp. Total ~ ` ~, of 293 jts 3 1/2" in hole 2T up.=9308'. 05:15 - 07:30 2.25I CMPLTN OTHR ~ CMPLT3 Flush surface lines, cement line, geopilot skid, kill and choke lines and I manifold. 07:30 - 08:00 0.501 CMPLT SFTY ~ CMPLT3 ~ T PJSM on displacing f/ 9.0 ppg SFOBM to 9.6 ppg Sodium Chloride. 08:00 - 10:00 I~ 2.00 CMPL CIRC I CMPLT3 Displace 9.0 ppg SFOBM to 9.6 ppg Sodium Chloride. Pump @ 6 bpm I / i P l f 5 t k 632 bbl 10:00 -13:00 3.00' CMPLTNI OTHR j CMPLT3 w . ump a tota s ro es ( s). 1540 ps o 628 'Cleaning on rig floor, transfer mud f/ rock washer while wait on brine to ~ be brought over f/mud plant in Prudhoe. 13:00 -13:30 ~ 0.50 'I CMPLT SFTY I, CMPLT3 T ~ RU truck of 290 bbls 9.6 brine. PJSM w/ crew. Fluid transfer paperwork. 13:30 - 14:15 ' 0.75 14:15 -14:30 ~ 0.25 ; CMPL CIRC I CMPLTNj TRIP ( CMPLT3 CMPLT3 'Pump 290 bbls 9.6 ppg Sodium Chloride @ 6 bpm w/ 1540 psi. ~ POOH 3 jt 3 1/2" 15.5 ppf S-135 XT38 dp. 290 jts left in hole total. 14:30 - 15:00 i 0.50 ', CMPLTNI SOHO CMPLT3 PU/MU Vetco/Gray 13 3/8" x 4 1/2" MB222, 13 1/2" OD hanger w! ~ I dummy installed as penetrator and two way check installed in hanger. MU to 4 112" landing joint w/ 4.909 MCA connection on top of hanger. 15:00 - 15:15 0.25 i CMPLTNI SOHO CMPLT3 ' Drain BOP stack to land kill string w/ running tool f/ 7" retrievalble bridge l tt 9287 23' b 15:15 - 15:45 ~ 0.50 ~ CMPLTf~ DEQT ~ CMPLT3 ug on om @ . o p Run in LDS on Vetco Gray hanger. Test lower body seals to 5000 psi fl 45 16 15 00 5 ' ' MPLT CMPLTN R ~ 10 min. OK. Test upper body seals to 5000 psi f/ 10 min. OK. di B k l i t UD : - : 0.2 I OTH C 3 ac an ng jo n . same. out 16:00 - 16:30 ~ 0.50' DRILL j SFTY I CMPLT3 PJSM. Install mouse hole. Rig up to UD 5" dp f/ derrick. Have Total 170 ~I I stands 5" DP in derrick. 20 stands 5" HWDP, 83 stands w/ LoTads, 67 16:30 - 18:00 1.501 DRILL ~ PULD ' CMPLT3 I I stands slick. Cleaning fluids f/pits and rock washer. UD total of 13 stands 5" HWDP. Cleaning fluids f/ pits and rock washer. 18:00 -19:30 , 1.50'' ~ DRILL PULD ~ CMPLT3 ~ UD total of 7 stands 5" HWDP. Cleaning fluids f/ pits and rockwasher. " 19:30 - 21:30 I 2.00 DRILL ,PULD i CMPLT3 I DP w/ LoTads. Total of 83 to UD. UD 17 stands @ 1930 hrs. UD 5 Cleaning fluids f/ pits and rockwasher. 21:30 - 00:00 2.501 RIGMNT RGRP ~ CMPLT3 Pull Hyd cyl f/pipe spinner on iron roughneck f/ repair. Printed: 9/9/2005 10:19:09 AM • • AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 E-170 L2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and ~`.PDF files. Tie-on Survey: 9,398.24' MD Window /Kickoff Survey: 9,412.00' MD (if applicable) Projected Survey: 15,748.00' MD 05-Oct-05 ~.,. '"~~~~~. ~t~mm~s~ir :w~~~ PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ ~4 J Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~.~ J`--~ ~ ~, • • ..: 'r' _v~J~ ;~''.,. s ... 05-Oct-05 , . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 E-170 L2 MWD Dear Dear Sir/Madam: Enclosed is one disk with the `.PTT and *.PDF files. Tie-on Survey: 9,398.24' MD Window /Kickoff Survey: 9,412.00' MD (if applicable) Projected Survey: 15,748.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date 2 7 U5 ~~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) r1 m ~' ~ i ~ ~; ~ i ~ ~ '~ ~`i ~ t i ~ ` ~- rr ~ .~ l t i ~ ~ ~. ~ '~ 7 ~ I ~ i~ i f t' '+ ~ i ALASKA OIL A1~TD GAS CO1~T5ER~ATI011T CO1~II~IISSI011T Randy Thomas GKA Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: 1E-170L2 Sundry Number: 305-283 Dear Mr. Thomas: • rr 1 FRANK H. MURKOWSKI, GOVERNOR T ~ 333 W. 7T" AVENUE, SUITE 100 J' ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. C'7 ' _ DATED this- day of September, 2005 Encl. • ConocoPhillips Randy Thomas GKA Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 September 23, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Af,~arra Qil & Gas Cons. p~chorapo Com-nissioR Subject: Application for Sundry Approval for 1 E-170, 1 E-170L1, 1 E-170L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the Kuparuk multilateral 1 E-170, 1 E-170L1 and 1 E-170L2. We are planning to re- enterthis well, do a workover and run tubing according to the attached procedure. The Nabors 3S rig is scheduled to perForm this work. If you have any questions regarding this matter, please contact me at 265-6830. Sincerely, ~ „° w--_ R. Thomas GKA Drilling Team Leader CPAI Drilling and Wells RT/skad • ~ 1 \~V~1 V . T T S A E OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION S~F ~ ~ 2005 ~ j$~ APPLICATION FOR SUNDRY APPROVAL t C k il & G ans. i~uffiltt s;irr as a q las 20 AAC 25.2so 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver Other ^ Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended WeII ^/ 2. Operator Name: 4. Current WeII Class: 5. Pert to Drill Number: ConoCOPhillips Alaska, Inc. Development Q Exploratory ^ 205-076 / 305-268 3. Address: Stratigraphic ^ Service ^ 6. AP1 Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23264-61 7. KB Elevation (ft): 9. Well Name and Number: RKB 41' 1 E-170L2 8. Property Designation: 10. Field/Pool(s): ADL 25660, ALK 470 Kuparuk River Field !West Sak Oil Pool 11. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft}: Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15748' 3185' 9346' Casing Length Size MD TVD Burst Collapse Conductor g0' 20" x 34" 120' 120' Surface 5011' 13-3/8" 5054' 2311' Intermediate 10371' 9-5/8" 10414' 3451' Liner 6123' 5.5" 15736' 3185' Pertoration Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none none none Packers and SSSV Type: Packers and SSSV MD (ft) 2:XP liner pkr @ 9259' no SSSV no SSSV 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: October 3, 2005 Oil ~ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Mukavitr @ 263-4021 Printed Name Randv Thomas Title: GKA Drilling Team Leader Signature - ._..~r-~ Phone `2 6 ~ 6~~ 5 o Date °i /2-6 l03" Commission-Use Onl C ditio f l N tif C i i th t ti it t Sundry Nur~i er: ~O ns o approva : on o y omm ve may w ss on so a a represen a ness Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: ~~~ PS ~ ~ ~ v~v ~ ~~~ ~eS~ , S BFI, s~~ ~ ~ 2005 Subseque or Re d: APPROVED BY 6~ Appr COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 7/2005 Sub it in Duplicate Ri Workover Procedure g Well 1 E-170 West Sak Producer The objectives of the rig Workover are as follows: ^ Re-locate and confirm the presence of a single leak in the 9-5/8" casing from approximately 4858' - 4860' MD using the 3-1/2" work string and test packer. While setting and testing the "B" lateral LEM and ZXP packer, communication was suspected between the 9-5l8" casing and 13-318" x 9-5/8" annulus. This could be the result of a second leak in the 9-5/8" tieback string above the 13-3/8" x 9-5/8" packer, or the result of the 13-3/8" x 9-5/8" tieback string packer leaking and allowing communication from the production casing through the existing leak to the 13-3l8"' x 9-5/8" annulus. ^ Make a casing scraper run with a gauge ring to ensure clean casing across the patch interval ^ Install a Baker expandable casing patch (approximately 32' long) over the suspected 9- 5/8" casing leak from 4858' - 4860' MD. Test the production casing to 2500 psi. -a~-~--. ^ Retrieve the 7" RBP in the "D" lateral LEM • Run the 4-1/2" production tubing and ESP, and nipple up the tree _ _ _ ! a j cc { ~ ~ 1 3 a ~ 1 ! ~ ~ ! ,~~, 1 7 i ~ '; '' ~°"'~ ~ ~ ~°'; ` I FRANK H. MURKOWSK/, GOVERNOR ~ r ~' ~~ O~ ~ ~ ~~ 333 W. 7T" AVENUE, SUITE 100 COI~TSER~A7`I011T COMA'IISSIOIQ ,~~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas GKA Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk 1 E-170L2 Sundry Number: 305-268 Dear Mr. Thomas: ass-a7~' Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~ ~~ ~ ~~ ; .:~-~ John 1~ Norman Chairman ~~~ DATED this ~~ day of September, 2005 Encl. ,~, ~ ~- f~'' ©S ~ ~ i-~ ~_ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION `-' ~~ ~/ APPLICATION FOR SUNDRY APPROVAL `'~' -~~., ' `~ .., 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown Q Perforate ~ ~ ~ ~i~'er ~ ~E7ther ^ Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ Time Extension ' ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 205-076 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23264-61 7. KB Elevation (ft): 9. Well Name and Number: RKB 41' 1 E-170L2 8. Property Designation: 10. Field/Pool(s): ADL 25660, ALK 470 Kuparuk River Field /West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15748' 3185' 9346' Casing Length Size MD TVD Burst Collapse Conductor g0' 20" x 34" 120' 120' Surface 5011' 13-3J8" 5054' 2311' Intermediate 10371' 9-518" 10414' 3451' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none none none Packers and SSSV Type: Packers and SSSV MD (ft) ZXP liner pkr @ 9259' no SSSV no SSSV 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: September 9, 2005 Oil 0 Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: _ WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 4~C~`~ ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve McKeever @ 265-6826 Printed Name Randy ThOI11aS Title: GKA Drilling Team Leader Signature ~~, Phone ~S Via' °g~ Date ~~~ ~ } Commission Use Onl Sun Nu~r._~~-~ Conditions of approval: Notify Commission so that a representative may witness 7vC Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clppearat`nce ^ Other: S LaFlm SAP ~ ~ ?~fl~ Subse went Form Re wired: ~ S~~'le ~ ~~ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 9- /~¢- OS~ Form 10-403 Revised 7!2005 fi t Submit in Duplicate IR~rt l..li~'` .~..~,w. u...~, . , „ ...,~~ ~,......,..u.,... .,µ~...~ ..,,Yu.. ~~u,...... • Subject:-RE: ~W:Kuparuk 18-170 West Sak Producer -Casing Repair (Sundries 30~-283, 305-284, and 30~-285). From: "Mukavitz, Steve J" <Steve.J.Mukavitz@conocophillips.com> Date: Mon; 07 Nov 2005 T4:31:36 -0900- To~Thomas ti-tat~nd~:r ~~=~onl_ r'naunder@admin.state.ak.us> We're hypothesizing that the bottom leak is due to over-torqueing the 9-518" liner in the liner hanger area while running the string and rotating to get it in the hole. The upper leak is in a 4-5` interval with 25-35% wall loss in the easing, probably associated with casing wear. We're still looking at trying to determine what or when the wear may have occurred. It was isolated to }ust this one spot. Regards, Steve Mukavitz ConocoPhillips Alaska, Inc. 700 G Street, ATO 1548 Anchorage, AK 99501 907-263-4021 -' ~~~ -c~~ ~ ~- -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, November 07, 2005 9:30 AM To: Mukavitz, Steve J Subject: Re: FW: Kuparuk 1E-170 West Sak Producer -Casing Repair (Sundries 305-283, 305-284, and 305-285) Good news. Any determination as to the cause of the leaks?? Tom Maunder, PE AOGCC Mukavitz, Steve J wrote, On 11/7/2005 9:21 AM: Tom, Update on 1 E-170 for your info. We squeezed the upper leak from 4752' - 4757' MD and tested to 2500 psi last week. We then ran the Baker expandable casing patch over the weekend and successfully patched the (over leak from 4856' - 4861' MD. We then tested the entire 9-518" string to 2500 psi and it held great. We're currently preparing to run the 4-112" completion. ,, Let me know if you have questions. Regards, Steve Mukavitz ConocoPhillips Alaska, Inc. 700 G Street, ATO 1548 Anchorage, AK 99501 907-263-4021 1 of 3 11/7/2005 2:49 PM FW: Kuparuk 1E-170 West Sak Producer - Casin Repair (Sundries... Subject: FW: Kuparuk 1E-170 West Sak Producer - CasingRepair (Sundries 305-283, 305-284,and 305-285) From: "Mukavitz, Steve J" <Steve.J.Mukavitz(u~conocophillips.com> Date: Mon, 07 Nov 2005.09:21:29 -0900 ~S Tv: Thomas ~Iaundcr ~~_-tom maunder(u'acimin.state.ak.us== CC: "Goher, No~~~~ard" ~F[oward.Gobc~r(uconucoPhillips.coiz~~ Tom, ~~ S '~ l ~O ~ Update on 1 E-170 for your info, We squeezed the upper leak from 4752' - 4757' MD and tested to 2500 psi last week. We then ran the Baker expandable casing patch over the weekend and successfully patched the lower leak from 4856' - 4861' MD. We then tested the entire 9-5I8" string to 2500 psi and it held great. We're currently preparing to run the 4-112" completion, Let me know if you have questions. Regards, Steve Mukavitz ConocoPhillips Alaska, Inc. 700 G Street, ATO 1548 Anchorage, AK 99501 907-263-4021 -----Original Message----- From: Mukavitz, Steve 7 Sent: Thursday, October 20, 2005 8:32 AM To: 'tom_maunder@admin.state.ak.us' Subject: FW: Kuparuk 1E-170 West Sak Producer -Casing Repair (Sundries 305-283, 305-284, and 305-285) Tom, We rigged upon 1 E-170 in Kuparuk itri-lateral West Sak producer) over the weekend and are proceeding with our diagnostics and repair of the 9-518" production casing. i='ur#her testing on Tuesday indicates a second leak in the 9-518" casing, 100' shave the first. We have a 30` Baker expandable casing patch on location, but this obviously won't cover both leaks. Lead time on additional patch cladding to extend the patch is 8 weeks. { talked to Winton yesterday about squeezing the upper leak and attempting to get a pressure test prior to running the patch over the lower leak. The upper leak is in the 9-518'" tie-back string (we ran the 9-518" tieback after the 9-5/8" liner was set, and the upper leak is above the 13-3/8" x 9-518'° packer at the bottam of the tieback string). We'll essentially be circa{sting cement into the annulus (plan is 1000' of cement). We'll pressure test to 2500 psi when finished with the cement and patch. Winton indicated to continue under our current Sundry Approvals for the well. Please call if you have questions or need more information. Regards, Steve Mukavitz 1 of 2 11/7/2005 11:08 AM FW: Kuparuk 1E-170 West Sak Producer -Casing Repair (Sundries... • • ConocoPhillips Alaska, Inc. 700 G Street, ATO 1548 Anchorage, AK 99501 907-263-4021 -----Original Message----- From: Nabors 3S Company M Sent: Wednesday, October 19, 2005 7:58 AM To: Mukavitz, Steve J Subject: Leaks Steve After back strapping out of hole with kill string leak depths where determined to be (bottom leak 4861'-4856' RKB top leak 4757'-4752' RKB) overall length of 109' of bad pipe. Just wanted to make sure you had the right depths and length for patch design.l put an update in Dims Nabors 3S Rig Supervisor (907) 659-7639 Office (907) 659-7295 Fax 2 of 2 11/7/2005 11:08 AM RE: FW: Kuparuk 1E-170 West Sak Produceaing Repair (Sund... • Subject:RE: FW: Kuparuk 1E-170 West Sak Producer -Casing Repair (Sundries 305-283, 305-284, and 305-285) From: "Mukavitz, Steve J° <Steve.J.Mukavitz@conocophillips.com> Date: Thu; 20 Oct 2005 11:31:09 -0800 '1'0: 1~honuis 1~~1~~under ~=tong maunder(crzldmin.state.ak.us= Tom, Sorry for the fate reply. Been chasing things all morning. ®~~~ ~~ ~~~'S - ~ ~. ~D '~---- The 13-3f8"" x 9-5i8"" annulus is full of diesel right now.... we're actually pumping some additional diesel down the backside as we speak to ensure it`s full after doing some injection testing this morning. We're going to pump our normal Arctic Set 1 cement we use for surface casing since were so shallow (2000 - 2300' TVA) and ensure we spot cement across the leaks prior to circulating cement to minimize any brine in the annulus (we have 9.6 in there now). We've been working on a plan where we actually squeeze the upper and lower leaks together... figure it can't hurt to get cement in the bottom leak as well and this will save us a drill out of a plug. This will also help get cement across the upper leak before opening up the backside and taking returns to bring the cement into the annulus. The upper leak takes fluid much easier than the lower as expected (the tower's already been squeezed a couple times as you probably recall) which is fine since it's our primary focus. Regards, Steve Mukavitz ConocoPhillips Alaska, Inc. 700 G Street, ATO 1548 Anchorage, AK 99501 907-263-4021 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, October 20, 2005 8:42 AM To: Mukavitz, Steve ) Subject: Re: FW: Kuparuk 1E-170 West Sak Producer -Casing Repair (Sundries 305-283, 305-284, and 305-285) Steve, Your plan does sound appropriate, unfortunately. Will placing the cement give any problems with freeze protection?? Tom Maunder, PE AOGCC Mukavitz, Steve J wrote, On 10!20/2005 8:31 AM: Tom, We rigged up on 1 E-170 in Kuparuk (tri-lateral West Sak producer} over the weekend and are proceeding with our diagnostics and repair of the 9-5/8„ production casing. Further testing on Tuesday indicates a second leak in the 9-5/8'° casing, --100' above the first. We have a 30° Baker expandable casing patch on location, but this obviously won"t cover both leaks. Lead 1 of 2 11!7!2005 11:09 AM RE: FW: Kuparuk 1E-170 West Sak Producer - asmg Repair (Sund... time on additional patch cladding to extend the patch is 8 weeks. I talked to Winton yesterday about squeezing the upper leak and attempting to get a pressure test prior to running the patch over the lower leak. The upper Beak is in the 9-5f$" tie-back string (we ran the 9-5/8" tieback after the 9-5/8" liner was set, and the upper leak is above the 13-3/8" x 9-5/8°' packer at the battom of the tieback string)- We'll essentially be circulating cement into the annulus {plan is 1000' of cement}. We°ll pressure test to 2500 psi when finished with the cement and patch. Winton indicated to continue under our current Sundry Approvals for the well. Please call if you have questions or need more information. Regards, Steve Mukavitz ConocoPhillips Alaska, Inc. 700 G Street, ATO 1548 Anchorage, AK 99501 907-263-4021 -----Original Message----- From: Nabors 3S Company M Sent: Wednesday, October 19, 2005 7:58 AM To: Mukavitz, Steve J Subject: Leaks Steve After back strapping out of hole with kill string leak depths where determined to be (bottom leak 4861'-4856' RKB .top leak 4757'-4752' RKB) overall length of 109' of bad pipe. Just wanted to make sure you had the right depths and length for patch design. I put an update in Dims Nabors 3S Rig Supervisor (907) 659-7639 Office (907) 659-7295 Fax 2 of 2 11!7/2005 11:09 AM inc. ix:-i iv ~a.,i aiiu i.c~ .~uaj.rcu~ivu vYciauv~u rtati i aos-o~~ Subject: Re: 1E-170(Ll and L2) Suspension Operations and plan ~~~ From: 'Thomas Maunder <tom matar-der a.~admin.state.ak.us> ,^. ~~ ~ ~~ Date: Fri. 09 Sep ?00511:07:14 -0800 To: "1E~icKee~ er. Step e" ~Steve.ti'1cKee~°er a~eo~aocophillips.com== Ct:: "(=greener, !~~1ike K." <l~~like.R.Greener cr;canocophillips.com%, "iA~lukavitz, Steve .T" <Steve..1.Mukatitzi«conocopliillips.coin~, ":~llsup-Drake, Sharon K" <S1i:arc~n.K.:111~up-U~~akc:~i conocophillips_com>, Lou Grim<~ldi =~lou_~~~imaldi ~admin.5tatc.al:.u~~- Steve, et al: Thanks for the information. As we discussed this morning, I was able to find some prior messages regarding the leak at/near the liner hanger and the remaining work of drilling and equipping the laterals was conducted according to the plans transmitted in those messages. At this point, it is probably appropriate to designate this as an "operational SD" and a sundry is necessary. My reasoning is that the rig will be changed and there is a some amount of new work that will be planned for 3 S to accomplish. Starting the 3 S work will also require submitting a sundry to transmit the work plan. Based on the information you have provided, you may continue with the work to secure the well and move off the rig. I will look forward to receiving the sundries. Sharon, just send in the 4~forms. I will attach this message as back up. Tom Maunder, PE t.~p-3 AOGCC McKeever, Steve wrote, On 9/9/2005 10:50 AM: Tom- As we discussed this morning, we are in the process of suspension operations on our well 1E-170, in anticipation of moving off Doyon 15 and completing the work with Nabors 35 later this month.. I have attached a summary of our recent Doyon 15 operations on this well. Summarizing those operations, we successfully ran a liner into the upper lateral and ran the LEM assembly into the upper hook hanger. This LEM assembly had a joint of 7" casing just below the ZXP packer, allowing us to set and test a retrievable bridge plug in that joint of 7", providing full hydraulic isolation from all three laterals. Following the test of the bridge plug with a retrievable test packer, the wellbore above the plug was displaced to 9.6 ppg NaCI brine, and the 3-1/Z" work string and test packer were hung off from the tubing hanger. Currently we are preparing to Hippie down the BOP, nipple up and test the tree, and move off the well. Nabors 3s will move onto the well later this month. Once they have nippled up and tested their BOP stack the plan is to: • Re-locate and confirm the presence of a single leak in the 9-5/8" casing from approximately 4858' - 48b0' MD (x-over below the 9-5/8" liner hanger) using the 3-1/2" work string and test packer currently hung off in the well as a kill string. I of 2 9/9/2005 I :55 PM tce: i ~- - r u ~L i anu i,~~ auspension vperano~a Tian • • Install a Baker expandable casing patch over the 9-5/8" casing leak from 4858' - 4860' MD. Test the production casing to 2500 psi. • Retrieve 7" retrievable bridge plug in "D" sand Lateral Entry Module. • Run the 4-1/2" production tubing and ESP completion and nipple up the tree. Please let me know if you approve this plan of operations, and if any further paper work in required. Thanks kindly. «1E-170 Suspension Operations.pdf» Steve McKeever Senior Drilling Engineer ConocoPhillips Alaska, Inc. 700 "G" Street Anchorage, Alaska 99501 st~ve.mckeeverC~conocophi llps.com office: 907/265-6826 fax: 907/265-1535 pager: 907/275-0369 "The short fortune-teller who escaped from prison was a smal{ medium at large." 2 of 2 9/9/2005 1:55 PM tic. ir,-i iv luwiuicuia~c ~,cuicu~ • • Subject: Re: 1E-170 Intermediate Cement From: STMaunder@aol.com e., Date: Sat, 23 Jul 2005 18:13:12 -0400 (EDT} ~ S _ ~ ` `` To: Patrick.J.Reilly@conocophillips.com ,. ~~ CC: D15CM@conocophillips.com, tom_maunder@admin.state.ak.us Pat and Fred, It appears that you afl have clearly identified where the leak is and pumped serveral barrels of cement. The latest test is 690 psi on top of the mud column you have in the hole. When Pat and !talked, it was indicated that the EMW calculated with that pressure and the mud column 14.8 if I remember correctly. That was better than 2 ppg greater than the LOT at the 13-3/8" shoe and (assuming 9.0 ppg mud) better than 5 ppg greater than the MW. It is not likely that further applications of cement will improve the pressure tollerance. The plan to ultimately set a patch across the leak is a sound one. You are proposing to continue drilling the laterals as planned and then install the patch when the laterals are complete. Since your 12-1/4" hole penetrated all the sands of the West Sak without experiencing any pressure problems, there is little risk that drilling the laterals will result in encountering higher pressures than previously experienced. Your plan to proceed is acceptable. Pat, please contact me on Monday for an update. Feel free to call if there are additional developments. Tom Maunder, PE AOGCC 1 of 1 7/25/2005 9:05 AM • Subject: 1E-170 Intermediate Cement From: "Reilly, Patrick J" <Patrick.J.Reilly@conocophillips.com> Date: Sat, 23 Jul 2005 13:03:49 -0800 To: <stmaunder@aol.com> CC: "Doyon 15 Company Man" <D 1 SCM@conocophillips.com> Tom, • We would like to proceed with drilling the laterals on this well patch after running the lateral completion equipment. . ~~ ~~~ We will install a casing The following is the chronology of events on the 1E-170 intermediate casing tests: INITIAL CASING TEST After running the tie back string - Pressured up to 3000 psi, pressure immediately dropped to 300 psi. Tested surface equipment to 3000 psi - OK. 1ST RTTS RUN Tested from 5059' - 10306' for 15 minutes at 3000 psi. - OK Tested from Surface to 4812' for 15 minutes at 3000 psi. - OK Tested 13 3/8" x 9 5f8" annulus from the surface to the ZXP for 10 minutes at 1000 psi. - OK Performed infectivity test with oil based mud in the hole 1.0 BPM @ 1080 psi 1.5 BPM @ 1370 psi 2.0 BPM @ 1710 psi - Shut in, pressure dropped to 475 psi in 1 minutes 1ST CEMENT SQUEEZE - 20 BBLS - NO HESITATION Placed high vis pill just below the leak point Pumped 18 bbls out of the casing leaving 2 bbls inside the casing iassuming no cement running on the low side below the pill) Pressured up to 2400 psi (last 2 bbls) Bled off Waited on cement (CIP 2345 hrs, ZO July) TOOH for drilling assembly 1ST CEMENT CLEAN OUT AND SQUEEZE TEST RIH with drilling assy. Pressured up to 1000 psi, shut in, pressure dropped to 430 psi in 5 minutes. TOOH for RTTS. 2ND RTTS RUN & 2ND CEMENT SQUEEZE 20 BBLS - HESITATION RIH wfRTTS and reconfirmed leak location Pumped se cond cement squeeze Squeezed 10 bbls @ 1.0 bpm, STOP, pressure @ 1240 psi Pressure dropped to 1029 in 5 minutes Squeezed 5 bbls @ 1.0 bpm, STOP, pressure @ 1794 psi Pressure dropped to 1258 in 15 minutes Squeezed 1 bbl Q 0.5 bpm, STOP, pressure at 1551psi Pressure dropped to 905 psi in 30 minutes (CIP 1105 hrs, 21 July) 2ND CEMENT CLEAN OUT AND SQUEEZE TEST RIH with clean out assembly 0630 hrs, 22 July (20 hours since batch mix) Pressure up to 1050, shut in. Pressure dropped to 950 psi immediately 900 psi @ 1.0 min 875 psi @ 1.5 min 825 psi @ 2 min 750 psi @ 4 min 750 psi @ 5 min 725 psi @ 10 min 700 psi @ 15 min 700 psi @ 20 min 690 psi @ 25 min 1 of 2 7/25/2005 9:06 AM 690 psi @ 30 min Pat Reilly ConocoPhillips Alaska Drilling & Wells ('~ ~„~ (907) 265-6048 WORK O ~ ` v (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J.Rzi11y@conocophillips.com __/'~~ «Patrick.J.Reillv@conoeophillios.com.vcf » ~J V~ V Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J.Reillv~=Kcanocophillips.com 1E-170 Intermediate Cement.emlii 2 of 2 7/25/2005 9:06 AM tce: mtormanon ror y pia., ripe xepair on ir,-i iu Subject: Re: Information for 9 5/8" Pipe Repair on 1E-170 From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Thu, 21 Jul 2005 11:23:59 -0800 To: NSK Fld Drlg Supv <n1335@conocophillips.com> CC: Mike.R.Greener@conocophillips.com L --~ a~5 -c~`~~ ~~ cos-~~ ~-- Steve and Mike, Thanks for the additional information. From the pressure response, it appears that the leak was successfully squeezed. 2400 psi at 2 bpm isn't bad at all. I agree that testing the casing/squeeze to a lower pressure due to the potential to damage the tieback is appropriate at recommended by your equipment provider. The MASP lies between the 1000 and 1500 psi test pressures that have been proposed. The MASP is calculated with a gas gradient of (0.1 psi/ft) making the calculated pressure high and therefore conservative. In normal drilling operations well pressures should not approach this value even when a well control situation is considered. The ultimate test pressure value is CPAI's to determine, but I agree with what appears to the minimum of 1000 psi. Tom Maunder, PE AOGCC NSK Fld Drlg Supv wrote: Tom, Mike has called the rig and they have agreed to pressure testing the 9 5/8" casing to 1000 psi in order to prevent any further damage to the suspect crossover. The squeeze operations took 20 bbls of cement with all that volume going into the 13 3/8" X 9 5/8" annulus as calculated from the displacement. At 2 bpm the pressure stepped up progressively to +/-2400 psi making it appear that a good squeeze was obtained on the lap area. The leakoff tests in this area of the West Sak have normally been in the range of 450 to 600 psi surface pressure with a 9.0 ppg mud, which is what they should be drilling out with. Once the three laterals have been drilled and all the liners are run a 9 5/8" casing patch will be run across the area of the damaged crossover for improving casing integrity in the future. Upon the successful execution of that procedure the ESP completion will be run. Thanks Steve 1 of 1 7/21/2005 2:43 PM P VV . 1P~-1 / V ll1LC1111C111QLC GQSllI~' 1C4K ~ • Subject: FW: 1E-170 Intermediate casing leak From: "Greener, Mike R." <Mike.R.Greener@conocophillips.com> Date: Thu, 21 Jul 2005 10:09:58 -0800 To: Tom Maunder <tom maunder@admin.state.ak.us> -----Original Message----- From: Greener, Mike R. Sent: Thursday, July 21, 2005 9:49 AM 70: Tom Maunder' Cc: Thomas, Randy L Subject: 1E-170 Intermediate casing leak ~.Q~ 4 ~~ This is an update on the casing leak that I visited with you about the other night or1 the phone. The leak was detennii~ed to be in a collar on a crossover pup joint directly below° the liner hanger. East night we squeezed the leak ~°ith 20 bbls of Class "C" cement. We pumped 1 g bbls through the leak. and left 2 bbls inside the 9-~%8" casing. The volume below the RTTS packer to the leak. was slightly over ~ bbls. The 9-5/$" Y 13-31~" annulus volume from the leak to the 1.3-3/8" shoe was 1.1.9 obis. Vt%e are currently picking up our BHA to go in and drill out what cement is .left inside the 9-5f8" casing. Casing movement calculations from Baker indicate that if eve pressure to 3,400 psi we will be putting the ma~i_mum load on the tieback string paeker..T any recommending that we only pressure to 1,544 psi with the plan to place a casing patch across the leak area after we have finished placing into the well all. the liner hook equipment and lateral entl-y equipment that c~~e Dave to run. in the ~~,~ell.. The casing patch is to ensure filture casing integrity as a back up to the cement squeeze. Mike Greener Senior Drilling Engineer 907.263.4820 1 of 1 7/21/2005 2:42 PM 3 i1 ~ ~( 1~ ~4 a ~1 3~ a , , ,~, i s y'~, j # f ~ ~ ( ~ r a a a (i ~ i~, ) ~ ~, ~~ g ~ ~ ~ ~ ~ y ~ S ~ a ~ i " ~ ~ 3 ~ ~, ALASFiA OIL ~11TD G~5 Co11TSERVA~`IO11T corn~SSjon Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 IJj FRANK H. MURKOWSKI, GOVERNOR ;, ~' 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 89501-3539 PHONE (907) 279-1433 ' FAX (907) 276-7542 Re: Kuparuk 1E-170L2 ConocoPhillips Alaska, Inc. Permit No: 205-076 Surface Location: 247' FNL, 641' FEL, SEC. 21, T11N, RIOE, UM Bottomhole Location: 1322' FSL, 174' FWL, SEC. 34, T11N, RlOE, UM Dear Mr. Thomas: 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 approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Plea provide at least twenty-four (24) hours notice for a representative of the Commission to it ess any required test. Contact the Commission's petroleum field inspector at~A-7~r~59 ~ 7 ger). DATED this/! day of May, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conoco~hilli s ~ p Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com May 4, 2005 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, West Sak Producer, 1E-170 L2 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for an onshore production wellbore, the upper lateral wellbore of a multilateral horizontal well, in the West Sak "D" sand. The main bore of this well will be designated 1E-170 and has been permitted under a separate application, submitted on May 4, 2005. This application is for the upper lateral of that well, to be designated 1E-170 L2. The expected date that operations will begin on 1E-170 L2 is June 25, 2005. Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for each of this well bore. Please contact Mike Greener at 263-4820 if more information is needed to issue a Permt to Drill for 1E- 170 L2. Sincerely, ~~~ ~ Randy Thomas GKA Drilling Team Leader STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~~~ MAY I? X005 ,~~~ ~ Alaska OTC & ,~~ Coy. Camfnissiar ~nl;hora~e 1a. Type of Work: Drill / Redrill 1 b. Current Well Class: Exploratory Development Oil / Multiple Zone ^ Re-entry ^ Stratigraphic Test ^ Service ^ Development Gas ^ Single Zone 0 2. Operator Name: 5. Bond: / Blanket Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 1 E-170L2 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 15646' - TVD: 3184' ' Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 247' FNL, 641' FEL, Sec. 21, T11 N, R10E, UM r ADL 25660 West Sak Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2491' FSL, 221' FWL, Sec. 27, T11 N, R10E, UM / ALK 470 6/25/2005 Total Depth: 9. Acres in Property: 14. Distance to 1322' FSL, 174' FWL, Sec. 34, T11 N, R10E, UM 2560 Nearest Property: 4639' at surface 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest ! ~ iS2~ 7 %~~-!/ ~ Surface: x- 549890 ' y- 5959340 Zone- 4 (Height above GL): 28' RKB feet well within Pooh u-EB-rt~C132*r 16. Deviated wells: Kickoff depth: 9193 '' ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) ,~ Maximum Hote Angle: 94° deg Downhole: 1433 psig Surface: 1083 psig 18. Casing Program cific ti S Setting Depth Quantity of Cement Size pe a ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" x 34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCRETE 16" 13-3/8" 68# L-80 BTC 5086' 28' 28' 5086' 2317' 980 sx ASLite, 260 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 10433' 28' 28' 10433' 3447' 790 sx DeepCRETE 8.5" 5.5" 15.5# L-80 BTCM 7396' 9193' 3243' 15646' 3184' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD ND Structural Conductor Surface Intermediate Production Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^ BOP Sketch Drilling Program / Time v. Depth Plot Shallow Hazard Analysis Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~~ Z ~ Phone '?~S"b~~~ Date S`/y/q S' Pr r n All r Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: ~ 5' b~(® , / 50- b ~~° ~ 3 ~ `~ '"~ ~ Date: for other requirements Conditions of approval S p s required Yes ^ No ~ Mud log required Yes ^ No ydr gen sulfide measures Yes ~ No ^ Directional survey required Yes ~ No ^ Other. ~ ~i ~ ~,~ li o~ i _ !? '~'S APPROVED BY Approv THE COMMISSION Date: Form 10-401 Revised 06/2004 ~ ~ ~ ~ Submit in Duplicate Ap~ion for Permit to Drill, Well 1 E-170 L2 Revision No.O May 4, 2005 Permit It -West Sak Well #1 E-170 L2 ("D" Sand) Application for Permit to Orill Document Mpxirtlizp Y1@II Value Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (f) ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ...................................................................................3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6} ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 5 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 5 Lateral Mud Program (MI FloPro NT) ..................................................................................................... 5 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bonding ............................................................................................... 5 Requirements of 20 AAC 25.005 (c}(12) ................................................................................................ 5 1E-170 L2 PERMIT/T.doc Page 1 of 6 Printed: May 4, 2005 ~~ ~~CU~L Ap~on for Permit to Drill, Well 1 E-170 L2 Revision No.O May 4, 2005 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments ............................................................................................................. 6 Attachment 1 Directional Plan ................................................................................................................ 6 Attachment 2 Drilling Hazards Summary ............................................................................................... 6 Attachment 3 Well Schematic ............................................................................................................... 6 1. Well Name Requirements of 20 AAC 25.005 (fl Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(tr). For a well with mu/tip/e well branches, each branch must similarly be identfied by a unique name and API number by adding a suffix to the name designated for the weil by the operator and to the number assigned to the we/! by the commission. The well for which this Application is submitted will be designated as 1E-170 L2. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An app/ication for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the app/ication: (2) a plat identifying the property and the property's owners and showing (A)che coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines (t3) the coordinates of the proposed location of the we/l at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at Iota! depth; Location at Surface FNL:246.91' FEL:640.83' Sec 21, Ti1N/R10E, UM ASPZone 4 NA017Coordinates RKB Elevation 98.8` AMSL Northings: 5,959,340 Eastings: 549,890 Pad Elevation 70.8' AMSL Location at Top of Productive Interval West Sak "D" Sand FSL:2491', FWL:221', Sec 27, T11N/R10E, UM ASP Zone 4 NAD 27 Coordinates Measured De th RKB: 9 193' Northingss 5,951, Eastings: 550,820 Total 1/ertical De th, RKB: 3,243` Total I/ertical De th, SS.• 3 133' Location at Total De th FSL:1322', FWL:174', Sec 34, T11N/R10E UM ASP Zone 4 NAD 27 Coordinates Measured De th RKB: 15,646' Northings: 5,945,076 Eastings: 550,830 Total I/ertical De th RKB: 3 184' Total ~ertica! De th SS: 3,074' and (D) other information required by 20 AAC25.050(b); 1E-170 L2 PERMIT /T.doc Page 2 of 6 Printed: May 4, 2005 ORIGINAL Ap~on for Permit to Drill, Well 1 E-170 L2 Revision No.O May 4, 2005 Requirements of 20 AAC 25.050(b) If a we/! is to be intentlona//y deviated, the app/ication for a Permit to Dri// (form 10-401) must (1) include a plat, drawn to a suitab/e sca/e, showing the path of the proposed wel/bore, nc/uding a// adjacent we//bores within 200 feet of any portion of the proposed we/% Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those welfs, to the extent that those names are known or discoverab/e in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (ROPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.03T, as appficab/e,• An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1E-170 L2. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 {c)(4) An app/ication for a Permit to Dri// must be accompanied by each of the following items, except far an item a/ready on file with the commission and identified in the application: (4) information on drilling hazards, ine/uding (A) the maximum dawnho% pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1E-170 L2 area vary from 0.0.42 to 0.0.45 ~° psi/ft, or 8.1 to 8.6 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from the nearby West Sak wells. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak B sand formation is 1082.56 psi, calculated thusly: MPSP =(3,184 ft)(0.45 - 0.11 psi/ft) =1082.56 psi a (8) data on potentia/gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of ho% problems such as abnormally geo pressured strata, lost circulation zones, and zones that have a propensity for differentia) sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on file with the commission and identified in the application: (S) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.0300; The parent wellbore, 1E-170, will be completed with 9 5/8" intermediate casing landed in the West Sak A-Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance i, , ,,:., ~ ~ ~ ~ .a.. 1E-170 L2 PERMIT ITdoc Page 3 of 6 Printed: May 4, 2005 t Ap~ion for Permit to Drill, Well 1 E-170 L2 Revision No.O May 4, 2005 with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Ori/l must be accompanied by each of the following items, except for an item already on file with the commission and identified in the app/ication: (6) a comp/ete proposed casing and cementing program as required by ZO AAC25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3 APD for 1E-170: Cement Summa Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MDIND OD (in in) (Ib/ft Grade Connection (ft {ft (ft Cement Program 20 x 34 42 94 K55 Welded 80 28 / 28 108 / Cemented to surface with 108 260 cf ArcticCRETE 13 3/8 16 68 L-80 BTC 5,086 28 / 28 5,086 / Cemented to Surface with 2,317 980 sx ASLite Lead, 260 sx Dee CRETE Tail 9 5/8 12 ~/a 40 L-80 BTCM 10,433 28 / 28 10,433 / Cement Top planned @ 3,447 6,000' MD / 2,439' TVD. Cemented w/ 790 sx Dee CRETE 5 1/2 8 1/2" 15.5 L-80 BTCM 5,386 10,433 / 15,819 / Slotted- no cement slotted "A" Lateral 3,447 3,431 1E-170 5 1/2 8 1/2" 15.5 L-80 BTCM 6,127 9,523 / 15,650 / Slotted- no cement slott teral 3,305 3 258 1E-170 5 1/2 8 1/2 15.5 L-80 BTCM 7,396 9,193 j 15,646 / Slotted-no cement slotted "D" Lateral 3,243 3,184 1E-170 L2 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application For a Permit to Dri/! must be accompanied by eae:h of the following items, except for an item a/ready on fi/e with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 10 AAC 25.035, unless this requirement is waived by the commission under 20 AAC Z5.035(h)(Z); No diverter system will be utilized during operations on 1E-170 L2 1E-170 L2 PERMIT /T.doc Page 4 of 6 Printed: May 4, 2005 ORIGINAL • Ap~on for Permit to Drill, Weil 1 E-170 L2 Revision No.0 May 4, 2005 8. Drilling Fluid Program Requirements of 2D AAC 25.005(c)(8) An application for a Permit to Dri11 must be acrnmpanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, inciudinq a diagram and description of the dri/ling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (VersaPro, Oil Base Mud) Properties Value Densit ( 9.0 Funnel Viscosity (seconds) 30 Yield Point (cP) 18 - 28 Electric Stability 650 - 900 Chlorides (mg/I) 40000 pH N/A API filtrate (cc / 30 min) NA **HTHP filtrate (cc /30 min) <10 MBT (Ib /gal) NA Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon 141 Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to ©ri/l must be accompanied by each of the following items, earcept for an item a/ready on fi/e with the commission and identified in the application: (9} for an exploratory ar stradgraphic test well, a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 2©AAC 25.033(1); Not applicable: Application is not for an exploratory or stratigraphic test well. ~' 9. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Ori// must be accompanied by each of the foi/owing items, except for an item a/ready on /5/e with the commission and identified in the application.• (10} for an exp/oratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC25.061(a},• Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application far a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on frle with the commission and identified in the application: (11} for a weil dri/led from an offshore p/atform, mobiie bottom-,Founded structure, jack-up rig, or floating dri/sing verse/, an ana/ysis ofseabed condilrons as required by 20 AAC 25.061 (b}; Not applicable: Application is not for an offshore well. ' 11. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Dri//must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the application: (12}evidence showing that the requirements of 20 AAC 25.025 {,3onding}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. pal, j~;vAL 1E-170 L2 PERMIT /T.doc Page 5 of 6 Printed: May 4, 2005 • A~ion for Permit to Drill, Well 1 E-170 L2 Revision No.O May 4, 2005 12. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Dri// must be accompanied by each of the fo/lowing items, except for an item a/ready on fi/e with the commission and identified in the application: The proposed drilling program for 1E-170 L2 is listed below. Note: Previous operations are covered under the 1E-170 Application for Permit to Drill. s 1. Run and set Baker WindowMaster whipstock system, at window point of 9,193' MD / 3,243' TVD, the top of the D sand. Mill 81/2" window. POOH. f Pick up 81/2" drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of "D" sand lateral at 15,646' MD / 3,184' TVD, as per directional plan. 5. POOH, back reaming out of lateral. RH and spot solids free OBM. POOH. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 51/2" slotted liner. o 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POOH 10. Make up ESP drive section (motor only, no pump), other completion equipment and tubing as required and RIH to depth. Land tubing. Set BPV. 11. Nipple down BOPE, nipple up tree and test. Pull BPV. 12. Set BPV and move rig off. 13. Freeze protect well with diesel by pumping into 4 i/2"" x 9 5/8"annulus, taking returns from tubing and allowing to equalize. 14. Rig up wire line unit. Pull BPV and install gas lift valves 15. Operate well on gas lift for +/- 180 days. 16. Replace gas lift valves with dummies. 17. Run ESP through tubing 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Dri//music be accompanied by each of the fo//owing items, except for an item a/ready on fi/e with the commission and identified in the application: (14) a general description of how the operator p/ans to dispose of dril/ing mud and cuttings and a statement of whether the operator intends to request authorization under 10 AAC 25. [7BQ for an annular disposai operation in the wefi.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1E Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on lE Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 14. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic t~~~ 1E-170 L2 PERMIT IT.doc Page 6 of 6 Printed: May 4, 2005 s ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1 E-170 L2 Plan: 1 E-170 L2 (wp04} Proposal Report 02 May, 2005 • F~ALLtBIJF~TQN Sperry Drilling Services OR161NAL r~ ~ M ~i<~'I~~ llJ~~1l ~~ ~-ka -60 West(-)/East(+) (2000 ft/in) 00 -5000 -4000 -3000 -2000 -1000 0 1000 2000 000 4000 NALLI Ep~ny Dr 5000 60 BURTON llllnq E~rvle~s 00 looo Project: Kuparuk River Un t looo Site: Kuparuk 1 E Pad Well: Plan 1 E-170 ~ Wellba-e: Plan 1E-170 L2 o o Plan: 1 E-170 L2 (wp04) 17g° -1000 173° -1000 -2000 -2000 -3000 -3000 133!8" -4000 X000 174° -5000 -5000 TOW~2491ftFSL221ftFWL-Sec 27-T11N-R10E:9193ftMD,3243ft ND -6000 \ -6000 ~ ~ o \ c ~ !BOW -Assume 13.6°I100 DLS : 92108 MD, 37468 ND O ~ ~',~ N -7000 3264ft T1/D ~` Sail ~ 94.20Mnc 8.178.78°Azi : 96648 MD, -7000 oZ V __, T / _ ~ s ~ 9 6l8" i / v O Z ~ -8000 --- ' ° tE-170 L2T1(wpOM1) -8000 0 End 30 Rathde -Begin BuNd ~ 4 I100ft : 92408 MD. 32618 ND ~ ~ L ~ o Drop ~ 3°NOOR to 90.67°Inc : 98408 MD, 32438 ND 180° ~ -9000 , - - - --- - , = tE-170 L2 T2(wp04) i -9000 = "~ 180° Begin Geoateering -Target 16' from top oT D-Sand: 9961ft MD, 3238ft ND -10000 -1E-170 L2 TS (wpdi) ~i -10000 180° i 1 E-170 L2 T4 (WP04) ,i -11000 -11000 -12000 180° -12000 1 E-170 L2 T6 (wp04) _' -13000 -13000 181° -14000 a 17D t~ 2 T~,e Iw~,oa~ ~ -14000 T M Azinuths to True North -15000 M89netic North: 24.49° \ -15000 Magnetic Field \ SlrangM. 67680.dnT Dip Angle: 80.76° Date: 12H 6/2004 -16000 Motlel: BGGM2004 ~ / -16000 BHL ~ 166468 MD, 3184ft ND :13228 FSL & 174ft FWL-Sec 34-T11N-R10E -60 00 -5000 X000 -3000 -2000 -1000 0 1000 2000 3000 4000 5000 60 00 West(-)/East(+) (2000 ft/in) ORIGINAL -asoo Site: Kuparuk 1E Pad Well: Pian 1E-170 bore: Plan 1E-170 LZ 1 E-170 L2 (wp04) MALLIBURTON >ip~rry Drilling E~rvius -3600 TOW @ 2491ft FSL 221ft FWL -Sec 27 - T11 N - R10E : 9193ft MD, 3243ft ND II BOW -Assume 13.6°/100 DLS : 9210ft MD, 3246ft N~ -2700 ~\ - End 30' Rathole -Begin Build @ 4°/t00ft : 9240ft MD. 3251ft ND ~, .,Sail @ 94.20°Inc & 179.78°Azi : 9564ft MD, 3264ft N~ -1800 Drop @ 3°/100ft to 90.57°Inc : 9840ft MD, 3243ft ND -900 0 0° ~ 10' 0 900 ~_Y o ~,S ~fi'n 13 3/8" L a p 1800 ~ ~ Begin Geosteering -Target 15' from top of D-Sand: 9961ft MD, 3238ft ND r _ ~ ~ = ' ~ 1E-170 L2 Tce (wp04) 2700 _~ - - F ~ o i ~ o Bann West Sak D ak D ° ~ , 1E-170 L? T4 (wp04) 1 E-170 L2 T3 (wp04) I1E-170 L2 T2 (wp04) 1E-170 L2 T5 (wp04) LEGEND 1E-170 L2 T1 (wp04) -~ Plan 1E-170, Plan 1E-170 L1, 1 E-170 L1 (wp04) VO ~HL @ 15646ft MD, 3184ft ND : 1322ft FSL 8 174ft FWL --Sec 34-T11 N-R10E $ Plan 1 E-170, Plan 1 E-170, 1 E-170 (wp04) VO $ 1E-170 L2 04 -900 0 900 1800 2700 3600 4500 5400 6300 7200 8100 9000 9900 10800 11700 12600 13500 14400 15300 Vertical Section at 180.00° (1800 tt/in) ~' ~ ~ ~' ConocoPhillips Halliburton Company Pl i R G hi rt HALLIBURTON ann ng epo eograp c - Alaska Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Coordinate Reference: Well Plan 1 E-170 Company: ConocoPhillips A{aska (Kuparuk} TVD Reference: ' 70.4 GL + 40 RT @ 110.40ft (Doyon 15) Project: Kuparuk River Unit MD-Reference: " 70.4 GL + 40 RT @ 110.40ft (Doyon 15) Site: Kuparuk 1E Pad North Reference: True Well: Plan 1 E-170 Survey Calculation Method: Minimum Curvature Welibore: Plan 1E-170 LZ Design: 1E-170 L2 (wp04) Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor ~ We11 Plan 1E-170 Well Position +N/S 0.06 ft Northing: 5,959,339.91 ft Latitude: 70° 17' 58.887" N +E/_yy 0.00 ft Easting: 549,889.64 ft Longitude: 149° 35' 45.435" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 70.40 ft Yyelibore Plan 1E-170 L2 Magnetics Model Name. , Sampie Date Declination Dip Angle Field Strength bggm2004 12/16/2004 24.49 80.74 57,580 Design 1E-170 L2 (wp04) Audit Notes: Version: Phase: PLAN Vertical tsection: Depth From (TVD) +NIS ~~) (ft) 40.00 0.00 Tie On Depth: 9,193.40 +EI-W Direction (ft) (°) 0.00 180.00 5/2!2005 8:50:5TPM Page 2 of 6 COMPASS 2003.11 Build 48 1~ ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: 'Kuparuk River Unit Site: Kuparuk 1 E Pad Well: Plan 1E-170 Wellbore: Plan 1 E-170 L2 Design: 1 E-170 L2 (wp04) Hallibulton Company HALLtBURTON Planning Report -Geographic Sperry Drilling Services LocatCo-ordinate Reference: Well Plan 1E-170 TVD Reference: 70.4 GL + 40 RT @ 110.40ft (Doyon 15) MD Reference: 70.4 GL + 40 RT @ 110.40ft (Doyon 15) North Reference• True SurvegCalculation Method: Minimum Curvature Plan Summary Measured Vertical Dogleg. Build Tum Depth . .Inclination Azimuth Depth ; +r1/S +El-W Rate Rate Rate TFO (ft) (`) (o) (ff) (~) (~) (°MOOft) (°/100ft) (°/100ft) (°) 9,193.40 79.00 179.77 3,243.40 -7,821.67 878.54 0.00 0.00 0.00 0.00 9,209.90 81.24 179.77 3,246.23 -7,837.93 878.60 13.60 13.60 0.00 0.00 9,239.90 81.24 179.77 3,250.80 -7,867.58 878.72 0.00 0.00 0.00 0.00 9,473.05 90.57 179.77 3,267.42 -8,099.87 879.66 4.00 4.00 0.00 0.00 9,563.77 94.20 179.78 3,263.65 -8,190.50 880.01 4.00 4.00 0.02 0.24 9,840.00 94.2D 179.78 3,243.42 -8,465.99 881.04 0.00 0.00 0.00 0.00 9,960.96 90.57 179.81 3,238.39 -8,586.82 881.47 3.00 -3.00 0.02 179.60 10,160.96 90.57 179.81 3,236.40 -8,786.81 882.13 0.00 0.00 0.00 0.00 10,194.81 89.90 179.76 3,236.26 -8,820.66 882.26 2.00 -1.99 -0.15 -175.68 11,361.15 89.90 179.76 3,238.40 -9,986.99 887.17 0.00 0.00 0.00 0.00 11,384.43 90.36 179.74 3,238.35 -10,010.27 887.27 2.00 2.00 -0.07 -1.90 12,171.30 90.36 179.74 3,233.40 -10,797.11 890.79 0.00 0.00 0.00 0.00 12,213.18 90.90 180.39 3,232.94 -10,838.99 890.74 2.00 1.28 1.53 50.12 14,418.79 90.90 180.39 3,198.40 -13,044.28 675.87 0.00 0.00 0.00 0.00 14,472.45 90.65 181.43 3,197.68 -13,097.93 875.02 2.00 -0.46 1.95 103.42 15,646.19 90.65 181.43 3,184.40 -14,271.23 845.72 0.00 0.00 0.00 0.00 5?/2005 8:50:57PM Page 3 of 6 COMPASS 2003.11 Build 48 ~-~ ~ • lr Hallibufton Company ~' ~~ HA LLIBU RTON COIlOCO tl l 5 p Planning Report -Geographic Alaska Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference:. Well Plan 1 E-170 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: 70.4 GL + 40 RT @ 110.40ft (Doyon 15) Project: Kuparuk River Unit MD Reference:. 70.4 GL + 40 RT @ 110.40ft (Doyon 15) .Site: Kuparuk 1 E Pad North Reference: True Wel[: Plan 1 E-170 `Survey Calculation Method: Minimum Curvatu re Weilbore: ' Plan 1E-170 L2 Design: 1 E-170 L2 (wp04) _- j Planned Survey 1E-170 L2 04) - (w p I Map Map ' MD Inclination Azimuth TVD SSTVD +N/S +E/-W Northing Easting DLSEV Vert Section (ft) ~°) (°) (fti (ftl (ft) (tt) (ft) (ft) !°I100ft) !ft) i / 9,193.40 79.00 179.77 3,243.40 3,133.00 -7,821.67 878.54 5,951,525.00 550,820.00 0.00 7,821.67 TOW @ 2491ft FSL 221ft FWL -Sec 27 - T71N - R10E : 9193ft MD, 3243ft TVD - 95/8" 9,200.00 79.89 179.77 3,244.61 3,134.21 -7,828.16 878.57 5,951,518.52 550,820.07 13.52 7,828.16 9,209.90 81.24 179.77 3,246.23 3,135.83 -7,837.93 878.60 5,951,508.75 550,820.17 13.65 7,837.93 BOW -Assume 13.6°1100 DLS : 9210ft M D, 3248ft TVD 9,239.90 81.24 179.77 3,250.80 3,140.40 -7,867.58 878.72 5,951,479.11 550,820.49 0.00 7,867.58 End 30' Rathote • Begin Build @ 4°I100ft ; 9240ft MD. 3251ft TVD 9,300.00 83.65 179.77 3,258.70 3,148.30 -7,927.15 878.96 5,951,419.54 550,821.12 4.00 7,927.15 9,400.00 87.65 179.77 3,266.28 3,155.88 -8,026.84 879.36 5,951,319.86 550,822.19 4.00 8,026.84 9,473.05 90.57 179.77 3,267.42 3,157.02 -8,099.87 879.66 5,951,246.84 550,822.96 4.00 8,099.87 9,500.00 91.65 179.77 3,266.90 3,156.50 -8,126.82 879.76 5,951,219.90 550,823.25 3.99 8,126.82 9,563.77 94.20 179.78 3,263.65 3,153.25 -8,190.50 880.01 5,951,156.23 550,823.92 4.00 8,190.50 ~ Sail @ 94.20°Inc 8179.78°Azi : 9584ft MD, 3284ft TVD 9,600.00 94.20 179.78 3,260.99 3,150.59 -8,226.63 880.14 5,951,120.10 550,824.29 0.00 8,226.63 9,700.00 94.20 179.78 3,253.67 3,143.27 -8,326.36 880.52 5,951,020.39 550,825.33 0.00 8,326.36 9,800.00 94.20 179.78 3,246.35 3,135.95 -8,426.09 880.89 5,950,920.67 550,826.37 0.00 8,426.09 9,840.00 94.20 179.78 3,243.42 3,133.02 -8,465.99 881.04 5,950,880.78 550,826.78 0.00 8,465.99 Drop @ 3°/100ft to 90.57°Inc : 9840ft MD , 3243ft TVD 9,900.00 92.40 179.80 3,239.97 3,129.57 -8,525.88 881.26 5,950,820.89 550,827.40 3.00 8,525.88 9,960.96 90.57 179.81 3,238.39 3,127.99 -8,586.82 881.47 5,950,759.96 550,628.01 3.00 8,586.82 BegM Geosteering -Target 15' from top of DSand: 9981ft MD, 3238ft TVD 10,000.00 90.57 179.81 3,238.00 3,127.60 -8,625.86 881.60 5,950,720.93 550,828.40 0.00 8,625.86 10,100.00 90.57 179.81 3,237.01 3,126.61 -8,725.85 881.93 5,950,620.95 550,829.39 0.00 8,725.85 10,160.96 90.57 179.81 3,236.40 3,126.00 -8,786.81 882.13 5,950,560.00 550,830.00 0.00 8,786.81 1 E-170 L2 T2 (wp04) 10,194.81 89.90 179.76 3,236.26 3,125.86 -8,820.66 882.26 5,950,526.16 550,830.35 2.00 8,820.66 10,200.00 89.90 179.76 3,236.27 3,125.87 -8,825.85 882.28 5,950,520.97 550,830.41 0.00 8,825.85 10,300.00 89.90 179.76 3,236.46 3,126.06 -8,925.85 882.70 5,950,420.99 550,831.49 0.00 8,925.85 10,400.00 89.90 179.76 3,236.64 3,126.24 -9,025.85 883.12 5,950,321.00 550,832.58 0.00 9,025.85 10,500.00 89.90 179.76 3,236.82 3,126.42 -9,125.84 883.54 5,950,221.02 550,833.66 0.00 9,125.84 i 10,600.00 89.90 179.76 3,237.01 3,126.61 -9,225.84 883.96 5,950,121.03 550,834.75 0.00 9,225.84 10,700.00 89.90 179.76 3,237.19 3,126.79 -9,325.84 884.39 5,950,021.05 550,835.83 0.00 9,325.84 10,800.00 89.90 179.76 3,237.37 3,126.97 -9,425.84 884.81 5,949,921.07 550,836.91 0.00 9,425.84 10,900.00 89.90 179.76 3,237.55 3,127.15 -9,525.84 885.23 5,949,821.08 550,838.00 0.00 9,525.84 11,000.00 89.90 179.76 3,237.74 3,127.34 -9,625.84 885.65 5,949,721.10 550,839.08 0.00 9,625.84 11,100.00 89.90 179.76 3,237.92 3,127.52 -9,725.84 886.07 5,949,621.11 550,840.17 0.00 9,725.84 11,200.00 89.90 179.76 3,238.10 3,127.70 -9,825.84 886.49 5,949,521.13 550,841.25 0.00 9,825.84 11,300.00 89.90 179.76 3,238.29 3,127.89 -9,925.84 886.91 5,949,421.14 550,842.34 0.00 9,925.84 11,361.15 89.90 179.76 3,238.40 3,128.00 -9,986.99 887.17 5,949,360.00 550,843.00 0.00 9,986.99 1 E-170 L2 T3 (wp04) 11,384.43 90.36 179.74 3,238.35 3,127.95 -10,010.27 887.27 5,949,336.73 550,843.26 2.00 10,010.27 11,400.00 90.36 179.74 3,238.25 3,127.85 -10,025.83 887.34 5,949,321.16 550,843.43 0.00 10,025.83 11,500.00 90.36 179.74 3,237.62 3,127.22 -1D,125.83 887.78 5,949,221.18 550,844.54 0.00 10,125.83 11,600.00 90.36 179.74 3,236.99 3,126.59 -10,225.83 888.23 5,949,121.20 550,845.65 0.00 10,225.83 11,700.00 90.36 179.74 3,236.36 3,125.96 -10,325.83 888.68 5,949,021.21 550,846.76 0.00 10,325.83 11,800.00 90.36 179.74 3,235.73 3,125.33 -10,425.82 889.13 5,948,921.23 550,847.87 0.00 10,425.82 5!2/2005 8:50:5TPM Page 4 of 6 COMPASS 2003.11 Build 48 ORIGINAL . • ConocoPh~li~ 5 p Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project Kuparuk River Unit Site: Kuparuk 1E Pad WeIL• Plan 1E-170 Wellbore: Plan 1E-770 L2 Design: 1 E-170 L2 (wp04) Halliburton Company Planning Report -Geographic Local Coordinate Reference: ND Reference: MDReference: North Reference: Survey Calculation Method: • HALLIBURTON Speny Drilling Services Well Plan 1 E-170 70.4 GL + 40 RT @ 110.40ft (Doyon 15) 70.4 GL + 40 RT @ 110.40ft (Doyon 15) True Minimum Curvature r - 'Planned Survey 1 E-170 L2 (wp04) - Map Map MD Inclination Azimuth. TVD SSTVD +NIS +FJ6W Northing Easting DLSEV I Vert Section tftl (°) (°) ift) lft) (ft) (ft) (ft) ift) (°/100ft) (ft) 11,900.00 90.36 179.74 3,235.11 3,124.71 -10,525.82 889.57 5,948,821.25 550,848.99 0.00 10,525.82 12,000.00 90.36 179.74 3,234.48 3,124.08 -10,625.82 890.02 5,948,721.27 550,850.10 0.00 10,625.82 12,100.00 90.36 179.74 3,233.85 3,123.45 -10,725.81 890.47 5,948,621.29 550,851.21 0.00 10,725.81 12,171.30 90.36 179.74 3,233.40 3,123.00 -10,797.11 890.79 5,948,550.00 550,852.00 0.00 10,797.11 1 E-170 L2 T4 (wp04) 12,200.00 90.73 180.18 3,233.13 3,122.73 -10,825.81 890.81 5,948,521.30 550,852.21 2.00 10,825.81 12,213.18 90.90 180.39 3,232.94 3,122.54 -10,838.99 890.74 5,948,508.13 550,852.23 2.01 10,838.99 12,300.00 90.90 180.39 3,231.58 3,121.18 -10,925.80 890.16 5,948,421.33 550,852.22 0.00 10,925.80 12,400.00 90.90 180.39 3,230.01 3,119.61 -11,025.78 889.48 5,948,321.35 550,852.21 0.00 11,025.78 12,500.00 90.90 180.39 3,228.45 3,118.05 -11,125.77 888.81 5,948,221.37 550,852.20 0.00 11,125.77 12,600.00 90.90 180.39 3,226.88 3,116.48 -11,225.75 888.13 5,948,121.39 550,852.19 0.00 11,225.75 12,700.00 90.90 180.39 3,225.32 3,114.92 -11,325.74 887.46 5,948,021.41 550,852.18 0.00 11,325.74 12,800.00 90.90 180.39 3,223.75 3,113.35 -11,425.72 886.78 5,947,921.44 550,852.17 0.00 11,425.72 12,900.00 90.90 180.39 3,222.18 3,111.78 -11,525.71 886.11 5,947,821.46 550,852.16 0.00 11,525.71 13,000.00 90.90 180.39 3,220.62 3,110.22 -11,625.69 885.44 5,947,721.48 550,852.15 0.00 11,625.69 13,100.00 90.90 180.39 3,219.05 3,108.65 -11,725.68 884.76 5,947,621.50 550,852.14 0.00 11,725.68 13,200.00 90.90 180.39 3,217.49 3,107.09 -11,825.67 884,09 5,947,521.52 550,852.13 0.00 11,825.67 13,300.00 90.90 180.39 3,215.92 3,105.52 -11,925.65 883.41 5,947,421.55 550,852.12 0.00 11,925.65 13,400.00 90.90 180.39 3,214.35 3,103.95 -12,025.64 882.74 5,947,321.57 550,852.11 0.00 12,025.64 13,500.00 90.90 180.39 3,212.79 3,102.39 -12,125.62 882.06 5,947,221.59 550,852.10 0.00 12,125.62 13,600.00 90.90 180.39 3,211.22 3,100.82 -12,225.61 881.39 5,947,121.61 550,852.09 0.00 12,225.61 13,700.00 90.90 180.39 3,209.66 3,099.26 -12,325.59 880.72 5,947,021.63 550,852.08 0.00 12,325.59 13,800.00 90.90 180.39 3,208.09 3,097.69 -12,425.58 880.04 5,946,921.66 550,852.06 0.00 12,425.58 13,900.00 90.90 180.39 3,206.52 3,096.12 -12,525.56 879.37 5,946,821.68 550,852.05 0.00 12,525.56 14,000.00 90.90 180.39 3,204.96 3,094.56 -12,625.55 878.69 5,946,721.70 550,852.04 0.00 12,625.55 14,100.00 90.90 180.39 3,203.39 3,092.99 -12,725.53 878.02 5,946,621.72 550,852.03 0,00 12,725.53 14,200.00 90.90 180.39 3,201.83 3,091.43 -12,825.52 877.34 5,946,521.74 550,852.02 0.00 12,825.52 14,300.00 90.90 180.39 3,200.26 3,089.86 -12,925.51 876.67 5,946,421.76 550,852.01 0.00 12,925.51 14,400.00 90.90 180.39 3,198.69 3,088.29 -13,025.49 876.00 5,946,321.79 550,852.00 0.00 13,025.49 14,418.79 90.90 180.39 3,198.40 3,088.00 -13,044.28 875.87 5,946,303.00 550,852.00 0.00 13,044.28 1 E-170 L2 T5 (wp04) 14,472.45 90.65 181.43 3,197.68 3,087.28 -13,097.93 875.02 5,946,249.35 550,851.51 2.00 13,097.93 14,500.00 90.65 181.43 3,197.36 3,086.96 -13,125.47 874.33 5,946,221.81 550,851.00 0.00 13,125.47 ~ 14,600.00 90.65 181.43 3,196.23 3,085.83 -13,225.43 871.83 5,946,121.85 550,849.17 0.00 13,225.43 14,700.00 90.65 181.43 3,195.10 3,084.70 -13,325.39 869.34 5,946,021.88 550,847.34 0.00 13,325.39 14,800.00 90.65 181.43 3,193.97 3,083.57 -13,425.35 866.84 5,945,921.91 55Q845.50 0.00 13,425.35 14,900.00 90.65 181.43 3,192.84 3,082.44 -13,525.32 864.35 5,945,821.94 550,843.67 0.00 13,525.32 15,000.00 90.65 181.43 3,191.71 3,081.31 -13,625.28 861.85 5,945,721.98 550,841.84 0.00 13,625.28 15,100.00 90.65 181.43 3,190.58 3,080.18 -13,725.24 859.35 5,945,622.01 550,840.01 0.00 13,725.24 15,200.00 90.65 181.43 3,189.45 3,079.05 -13,825.20 856.86 5,945,522.04 550,838.18 0.00 13,825.20 15,300.00 90.65 181.43 3,188.32 3,077.92 -13,925.17 854.36 5,945,422.08 550,836.34 0.00 13,925.17 15,400.00 90.65 181.43 3,187.18 3,076.78 -14,025.13 851.86 5,945,322.11 550,834.51 0.00 14,025.13 15,500.00 90.65 181.43 3,186.05 3,075.65 -14,125.09 849.37 5,945,222.14 550,832.68 0.00 14,125.09 15,600.00 90.65 181.43 3,184.92 3,074.52 -14,225.05 846.87 5,945,122.18 550,830.85 0.00 14,225.05 15,646.19 90.65 181.43 3,184.40 3,074.00 -14,271.23 845.72 5,945,076.00 550,830.00 0.00 14,271.23 * BHL Q 15645ft MD, 3184ft ND : 1322ft FSL 8174ft FWL--Sec 34-T11 N-R10E - 51/2" 5/2/2005 8:50:57PM Page 5 of 6 COMPASS 2003.11 Build 48 ORIGINAL • / ConocoPhillips Alaska Database:. EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1E Pad Well: Plan 1 E-170 Wellbore: Plan 1 E-170 L2 Design: 1E-170 L2 (wp04) Halliburton Company HALLIBURTON Planning Report -Geographic Sperry Drilling Services ,Local Co-ordinate Reference: Well Plan 1E-170 TVD Reference: 70.4 GL + 40 RT @ 110.40ft (Doyon 15) MD Reference: ' 70.4 GL + 40 RT ~ 110.40ft (Doyon 15) North Reference: True Survey Calculation Method: Minimum Curvature Geologic Targets Plan 1 E-170 L2 TVD TargetNatne +N/-S +E/-W Northing Easting (ft1 -Shape ft ft (ft) (ft) 3,184.40 1E-170 L2 Toe (wp04) -14,271.23 845.72 5,945,076.00 550,830.00 - Circle (radius 100.00) 3,238.40 1E-170 L2 T3 (wp04) -9,986.99 887.17 5,949,360.00 550,843.00 -Circle (radius 100.00) 3,198.40 1E-170 L2 TS (wp04) -13,044.28 875.87 5,946,303.00 550,852.00 - Circle (radius 100.00) 3,233.40 1E-170 L2 T4 (wp04) -10,797.11 890.79 5,948,550.00 550,852.00 -Circle (radius 100.00) 3,240.40 1E-170 L2 T1 (wp04) -8,386.76 880.79 5,950,960.00 550,826.00 -Circle (radius 100.00) 3,236.40 1E-170 L2 T2 (wp04) -8,786.81 882.13 5,950,560.00 550,830.00 - Circle (radius 100.00) Prognosed Casing Points - ~I Measured, Vertical Gaging Hole Depth:.:. Depth: oiarrreter Diameter (~) (ff? C'? (") 5,086.26 2,317.40 13.3!8 16 9,193.41 3,243.40 8-6/8 12-114 15,646.18 3,184.40 6-112 8-112 ~ Prognosed Formation Intersection Points Measured Yertical Depth inclination Azimuth ~~ +N/-E +E/-W (ffl (°t' (°) (R) (ft) (ft) Name 1,732.70 61.30 172.10 1,508.40 -609.88 123.91 Base ofPerrnafrost 2,335.83 76.87 173.95 1,692.40 -1,177.91 194.05 T3 3,449.21 76.87 173.95 1,945.40 -2,256.11 308.41 K16 5,086.26 76.87 173.95 2,317.40 -3,841.44 476.56 T3 +676 6,450.47 76.87 173.95 2,627.40 -5,162.56 616.68 Ugnu C 7,436.23 76.87 173.95 2,851.40 -6,117.17 717.93 Ugnu B 7,612.26 76.87 173.95 2,891.40 -6,287.63 736.01 Ugrtu A 8,347.17 76.87 173.95 3,058.40 -6,999.33 811.50 K73 9,193.40 79.00 179.77 3,243.40 -7,821.67 878.54 West Sak D 5x1/2005 8:50:57PM Page 6 of 6 COMPASS 2003.11 Build 48 • • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1 E-170 Plan 1 E-170 L2 Anticollision Summary 02 May, 2005 HAL.L.IBURTt71V Sperry Drilling Services ORIGINAL 0 SI~RVN:Y PROGRAM Date: 200SOS02T00:00:00 Validated: Yes Version: Depth FromDepth To Survey/Plan Tool 40.00 812.00 C&GYRO-SS 812.00 9193.40 MWD+IFR-AK-CATrSC 9193.4015646.19 1 X170 L2 (wp04) M W D+1 FR-AK-CATrSC zoo ConocoPhillips Alaska (Kuparuk) Engineering West Sak Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surtace: Elliptical Conic Warning Method: Rules Based so Travelling Cylinder Azimuth (TFO+A7,q ~°~ vs Centre to Centre Separation X100 fUn NAD 27 ASP Zone 4: WELL DETAILS: Plan 1 E-170 L2 (wp04) Ground Level: 70A0 +WS +EI-W Northing Easting Latiltude Longitude Sbt 0.00 0.00 5959339.91 549889.64 70°1T58.887N 149°35'45.435W REFERENCEINFORMATION Coordinate (NIE) Reference: Well Plan 1E-170, True North Vertical (TVD) Reference: 70.4 GL+ 40 RT ~ 110.40ft (Doyon 15) Section (VS) Reference: Slot - (O.OON, O.OOE) Measured Depth Reference: 70.4 GL + q0 RT ~ 110.40a (Doyon 15) Calculation Method: Minimum Curvature From Colour To MD 0 112 112 212 212 462 462 712 712 962 962 1462 1462 1962 1962 ---- 2462 2462 2962 2962 3462 3462 4962 4962 6462 6462 --- 7962 7962 9462 9462 10962 10962 12462 12462 13962 13962 16442 ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: 25Stations Depth Range From: 9193.4 To 15646.19 Maximum Range:5000 Reference: Plan: 1E-170 L2 (wp04) 1so Travelling Cylinder Azimuth (T'FO+A7.1) ~°~ vs Centre [o Centre Separation X15 ftfin~ so fiat M° k /a TVD .WS .E/-W DL49 1 9193.40 ]9.00 1)9.]7 329340 -]8218] 8]851 000 TFS[e VSec TaryN 000 ]8216> 2 9X19.90 Bt 34 179]] 324623 ]03]83 8]8.80 13.60 3 9239.90 61.24 1]9.7] 3250.80 -]88].56 8]8.]2 000 000 ]83]83 0.00 ]86]58 d 91]305 90.5] 1]9.7] 326"/42 8089.87 879% 900 5 8563.]] 91.20 1]9.]8 )263 fi5 8190.50 88001 400 000 BfB987 0.24 819050 8 984000 99.X1 179.78 324342 8Mi589 88101 0.00 ] 9960.86 90.5] 179.Bt )23839 -058882 881 e] 300 800 816599 1]9.80 8586.82 e 10180.96 90.57 179.81 )23840 4)0681 08213 000 9 10194.81 BB.BD 1]8.]6 )238]8 482086 88226 2.00 0.00 878681 tE-1 ]012 T21wp01) -t ]560 882088 10 1138115 89.90 1]9 ]6 32)840 -8988.99 68] 1] 000 1111384.1) 90.36 1]9.]4 3238.3510010.2] 88]2] 2.00 000 998699 1E-1]0 L2 T3 (wp04) -190100102] ti t2t ]130 90.36 1]9.74 323).40 -10)9].11 890.]9 0.00 13 1221 J.10 90 90 160 39 3232 91-10838.99 690.]4 200 000 10]9711 1E-1]0 L2 T4 (wp04) 50.12 1063898 1d 19416.]9 9090 180.39 3198.4013044.28 8758] 0.00 0.0013094.28 1E-17013 TS fivpW) 15144]245 90.65 16143 319].68-I3(p].9J 6>5.02 200 1615646.19 90.65 181.4] 318940-1927133 80.5.)2 000 103121309793 000142)1.23 1E-1 ]0 L2 TOa (w901) 180 ~ ~ ' I' Halliburton Com an p Y HALLlBURTON COI IOCOP IIIIi S p Anticollision Report p~as~ Sperry Drilling Services Company; ConocoPhillips Alaska (Kuparuk) Local Co-ordinate Reference: Well Plan 1 E-170 Project: Kuparuk River Unit TW References - 70.4 GL + 40 RT @ 110.40ft (Doyon 15) Reference Site: Kuparuk 1 E Pad MD Reference: '' 70.4 GL + 40 RT @ 110.40ft (Doyon 15) Site Error, O.OOft IVOrth Reference: True Reference Well: Plan 1 E-170 Survey Calculation Method: Minimum Curvature Well Error: O.OOft Output errors are of 2.00 sigma Reference Wellbore Plan 1 E-170 L2 Database: EDM 2003.11 Single User Db Reference Designs 1 E-170 L2 (wp04) Offset TVD Reference: Offset Datum Reference 1 E-170 L2 (wp04) , Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 25.OOft Error Model: ISCWSA Depth Range: 9,193.40 to 15,646.19ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of S,000.OOft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 5/2/2005 From To (ft) (ft) Survey (Vllelibore) Tool Name Description 40.00 812.00 1 E-170 (wp04} (Plan 1 E-170) CB-GYRO-SS Camera based gyro single shot 812.00 9,193.40 1 E-170 (wp04) (Plan 1 E-170) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9,193.40 15,646.19 1 E-170 L2 (wp04) (Plan 1 E-170 L2) MWD MWD -Standard ..Summary Reference Offset Centre to No-Go Allowable Measuroed Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset W811 - Wellbore -Design (ft) (ft) (ft) lft) Kuparuk 1 E Pad 1 E-35 - 1 E-35 - 1 E-35 9,196.54 10,400.00 3,187.59 238.83 2,948.76 Pass -Major Risk 1 E-35 - 1 E-35A - 1 E-35A (wp02) 9,193.40 10,450.00 3,178.11 291.84 2,886.28 Pass -Major Risk Plan 1 E-117 - 1 E-117 - 1 E-117 (wp05) 14,416.68 14,850.00 1,545.26 379.56 1,165.70 Pass -Major Risk Plan 1E-117- 1E-117 L1 - 1E-117 L1 (wp05) 14,418.79 14,850.00 1,527.86 367.02 1,160.84 Pass- Major Risk Plan 1 E-117 - 1 E-117 L2 - 1 E-117 L2 (wp05) 14,418.79 14,850.00 1,526.01 367.06 1,158.95 Pass -Major Risk Kuparuk 1J Pad Plan 1J-160 (M2) -Plan 1J-M2 Lat A -Plan 1J-M2 Lat A 15,599.94 7,675.00 1,592.74 237.57 1,355.16 Pass -Major Risk Plan 1J-162 (M1) - 1J-162 - 1J-162 (wp03.1-North Heel 15,582.88 8,825.00 370.86 182.02 188.84 Pass -Major Risk Plan 1J-162 (M1) - 1J-162 L1 - 1J-162 L1 (wp3.1) 15,582.88 8,825.00 370.86 181.91 188.95 Pass- Major Risk Plan 1J-162 (M1) - 1J-162 L2 - 1J-162 L2 (wp3.1) 15,582.88 8,825.00 370.86 181.91 188.95 Pass -Major Risk Kuparuk River Unit Non Pad Kup-34-11-10-1 - 34-11-10 - 3411-10 14,833.43 3,575.00 360.25 249.40 110.85 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 5/`2/2005 8:56:38PM Page 2 of 2 COMPASS 2003.11 Build 48 OR!Glf~~;al • • -170 L2 Drillina Hazards Summ (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 8 1/2" Open Hole / 5 1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, Shut-in drills, Increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD Tools, Hole 0 ener, Decreased mud wei ht Lost Circulation Moderate Reduced um rates, Mud rheolo , LCM Hole Swabbing on Trips High Trip speeds, Proper hole filling (use of trip sheets , Pum in out 1E-126 Drilling Hazards Summary prepared by Steve Shultz 420/2005 11:15 AM OR16!~!AL O r V I °~ Y r..~ O n ~~ ~. m x ~ [~c'1 ''0 t- w c ~i ~ "' S "° 'o' ^~ 3 .-. ~ ~~ 0 Wellhead /Tubing Head /Tree, 13-5/8" x 4-''/z", 5,000 ksi Insulated Conductor ing, 20", 94#, KSS x 34", 0.312" WT @ +/- 8d MD - Tubing String: 4-I/2", 12.6 #, L-80, IBTM (1) 3.875" DB nipple set @ 500' 13-3/8", 68#, L-80, BTC, R3 -~ ~ ~ +/_ 5,086' MD / 2, 31 T T V D 77 degrees TD 16" hole Top of Ugnu C nn, ~ 6,450' MD / 2,627 TVD Lateml Entry Module #2 (LEM), Baker, with seal bore and ZXP packer above. Top of West Sak D nn ~ 9,193' MD / 3,243' TVD Lateral Entry Module #1 (LEM), Baker, with seal bore and ZXP packer above. Top of West Sak B 9,523' MD / 3,305' TVD ~ Tubing, 4-%" IBTM, from LEM to - A2 Liner, with seal stem and CAMCO 3.562" "DB" nipple. ~ , m; ~~ Seal bore and ZXP packer For A2 liner _ +/- 90' below "B" window _ ^` ~ 9-5/8", 40#, L-80, BTCM, R3 Csg tt +/- 10,433' MD / 3,447 TVD -- 8I degrees TD 12-1/4" hole A2 Sand Liner, 5-''/z", 15.5#, L80, BTCM, R3 % slotted and % blank, cnnsbiclrNS,~rr isrdc#iorr IE-170 Planned: ASP NAf) 271-auines. 347%x9 ASP NN) 27 N~xthin~~. 5,959,33Y Pad f~:lc~ation. (,(~. I'AMSI. Doyon Rig I S Rig Floor (RF) an,. 0' Elevation: 94.1' AMSL I E-170 L2: 8-1/2" Dsand lateral - TD 15,646' MD / 3,184' T V D IE-170 LI. _ 8-I/2" "B" san TD 1 ~65P ~ / 3,258' TVD IE-170: 8-I/2 A2 sand lateral _ TD 15,819' MD / 3,431' TVD (I)Gas Lift Mandrels, CAMC04-1/2" x 1" Model KBG-2, one (I) set at <72 deg, one at 2400' TVD. (1) Sliding Sleeve, with 3.812" nipple, one (1)joint above packer. I OS L2 "D" Sand Window +/- 9,193' MD / 3,243' T VD 79 degrees j ~~S- p'~ ~ 105 LI "B" Sand Window @ +/- 9,523' MD / 3,305' TVD "D" Liner, S-1/2", 15.5#, L80, BTCM, R3 '/z slotted and '/z blank, (0.125" x 2. S" slots, 32 per foot, S 9% open area) "B" Liner, S-I/2", 15.5#, L80, BTCM, R3 '/, slotted and''/z blank, (0.125" x 2.5" slots, 32 per foot, 5.9°/ open area) e S- ~-~ -0.34 1 1 ~1 L 4 h 1 iF-2 ~ • 1L-0 ~0 1 15 // ~1 L 14\. ~ • , ! ~ ~ ', , , ,~ ,~ ~ IE t 1 E ~ 1 E- 0 1E- IE 2 E~ 19 ~ ~~ tE- 8 O z~~' t 18 E- ~i c tE-17 1E-JO 2 1E t IE-04 29' • ~ ~. e , t9 tE•~i n a 't•-''~11D-14 ''. , ~, ~' `' KRU 1 E-170L2 ~` ~-~;~' '°--'" ~``~ Proposed 1-Oil ~~ ~ ,; lE-20 ,D-~~ ;r West Sak "D" Sand i ~ r~",.. ~ ~. r._ ,,~~~_ ,D,~~--_~ `, 2050760 .~ - ~~ - --- i 'i -.~~~ - ~ - Confidential wells are red -\ \ ~ys~-+~T• ~•.,~`~~~-.``--~-_ -- ~ SFD 5/10/2005 ~ 10-1 23 10-1,~ - -' < ~~ ~5E-24 0 ~ 1 E-33~PE'F'".~ ~~~/ T D~ t 3~0-' 'Sp , S; ., -, .. ~ p ~ ; ~ .`C - ~~ •` ~'(D-128 t 33r i ,-i 9 •~ -138 / ~,' 1D_ttF ~ r _F$ti4 ~QQ \\\\\\ iD-1 tE 3 1D 133 L 1 129 i ,y iD-i 1 QQ tE-02 ~ ~ ~' 10-132 1 ~ il1D-12 1D-131 0 ~t1D 3a tE-31 31 ~'~,` IE-tO5PB1 •'1 ~'• ` ' 2~ ~ .~' 1~ t, ~~~-- z ~ ~ r. ~ ,. to-37 tE-34 •1 1 ~=1®$L~ L¢t 08 tL-os tL-za ~ 8~Q Y~q9 ~-~~~ e 5 ~, 4/ ~ ~~o o i E-3`- ~~ ~ 1 L 2` _ _ ~ ~ ~10 _ - ~-- ~~ ^~ 1 1P00 t J-1 0''~. \ 32 :~.~ ~ ;~ ~ 2000 ` -_ ~~~ ~ .A._ ~+-'-J- ~~-~ ---`:l 13~0~ - .. .. .. .':DP Slotted Liner '~°°° ~~ooo \~ tE-117L2 '' *:a 1 E- 170L2 iL-tg. 1L-22 iD-3 ~,•` t 34 `•t 35 -. ~'t ~ ~-~~ ,D-J9 r,=-~ . `'~q; ;c Feet WSP--, ~~ ~ -_-- 2;00 4,Fi~~9 ,D ~` • • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO SE INCLUDED IN TRANSMITTAL LETTER WELL NAME /~.~`: /~ "~ ~~ ~- Z- PTD# ~J ~-D ~~o CHECK WHAT ADD-ONS "CLUE" APPLIES OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (p)~ 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 - 70/80) from records, data and logs acquired for well (name on permit). SPACING 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. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01!05 C\jody\transmittal_checklist WELL PER IT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK 1 E-170L2 Program DEV Well bore seg ^~ PTD#:2050760 Company CONOCOPHILLIPS ALASKA INC Initial Classlfype DEV I PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Pe[mitfee attached_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ .. _ _ - _ - _ _ - _ _ _ _ . _ _ _ . - - NA_ _ - _ - _ _ _ West Sak D Sand multilate[al well segment; fee_waived per 20 AAC 25.005(e), - - _ _ _ _ _ _ _ _ _ _ _ - _ _ . _ _ 2 Lease number appropriate-__-_________________________ ___--_____Yes_ ___-._Top_producti_veinterval and TD-inADl.025660.__._.-__,.-_____-____-_-_________-.----- 3 Uniquewell,nameandnumber ------------- - ----- ----- -..._ Yes_ - -- ----- --- ------ -- ----------- - ----------------------------------- 4 Well located ina_definedpool--._______________ _______ _____.____-Yes__ .__-.KRUWestSak Oil Pool,governed_byConservation_Order_No.4066_____-,__ -,--_____.-_-.__,- 5 Well located proper distance from drilling unit_boundary.. - - - - - - - - _ - - - - - - - _ Yes - _ Well is more than-500 feet from an external property life, _ - . _ - - - _ - - - _ - 6 Well located proper distance_from other wells, _ - - _ _ - , _ _ _ _ - - Yes _ . - No restrictions as_to well spacing in CO.406B.- - _ _ - -------------------------- 7 Sufficient acreage available in_drilling unit, _ - _ _ . _ _ - _ _ - , Yes _ - - - . _ No restrictions as-to well spacing except thak no_pay shall be opened kn a well closer - - . _ _ _ - 8 If deviated,is.wellboreplat_included________________________ __.---____ Yes__ ____-than 500 feetto_anexternal_prope[tyline._-_-__--_-__-_-___-__. -- -- 9 Ope(atoronlyaffectedparty--------------------------- ---------Yes-- ------------------------ ----------------------------------------------- 10 OpQratarhas.appr9priate.bondinforce. -------------------- ----- ---Yes - ----- ----------------- ------------- --------------------------- --- -- 11 Pe[mitcanbeissuedwithoutconservationorder____~---_,_______ _____ ____Yes__ ___..___.._________..____.____--____-__-_____.___--__ -------------- Appr Date 12 Permit can be issued without administ[ative_approval_______________ ______--.Yes__ _-____-_______-,__-_.___--_____--__-__--___-__-_- --------------------- SFD 5!10/2005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and_strata authorized by_Injection Order # (putlO# in_ comments)_(FQr- _NA_ - _ . - _ _ - - . _ . - _ _ . - - . _ . _ . - _ _ _ _ - _ _ _ _ - - - _ _ _ _ - _ _ _ _ _ _ - - _ _ _ _ _ _ _ - - _ _ - _ 15 All wells_within 1/4_mile area of review identified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ - _ _ - _ _ - - - . - _ _ - - . - _ _ _ - _ , - - _ - - --------------------------------------------- 16 Pre-produced injector: duration of pre production Less than 3 months_(For service well only) _ - NA_ _ - ----------------------------------------------------------------------- 17 ACMP-Finding of Consistency_hasbeenissued-forthispr_oject_--____-_ ____---_ NA_-_ ______._.____________________________________________________-_- ----_ Engineering 18 Conductorstring_provided_______________________________ __________NA_- ___Conductorsetinmotherbore,_1E-170j205-074),____-_-_________-_--_____._---_-_--_ 19 Surface,casing_proteetsall_knownUSDWs_________________-__ ____---__NA__. -__--A4 aquifersex_empted,40CFR_147.102(bJ(3).____-_.____-____--___-____-___.---- 20 CMTvotadeguate_tocircul_ate_onconductor&surf-csg_---_____--_ __--__.NA___ __--_Surfacecasingset in-motherbore._________-__-___-_____--_-.---____--__-.____ 21 CMT_vol adeguate_to tie-in long string to surf csg_ _ _ _ _ _ _ . - _ - _ _ _ _ NA_ _ - _ _ _ - - Production_casing set in motherbore_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - _ _ - - - - 22 CMT-will coverall know_n_productiyehorizons____-___-_____ _-_--__--_No__ __-_Slottedliner completion planned.,,_,__.__--___-_---_______-.-_--_ ------------- 23 C,~SingdesignsadequateforG,T6&_pe[mafcost---------------- ----------Yes-- --------------------------------------------------------------------- 24 Adequake tan_kage_or reserve pit - _ _ - _ _ - _ _ . _ _ - - - _ Yes _ _ - _ - .Rig is.equipped with steelpits. _NO reserve_pitplanned_ All waste to approved annulus or CI_ass II well. - - _ - - 25 Ifa-re-d[ill,has_a10-403 forabandonmenkbeenapproved____________ __________ NA__- ___-______--_-___---____--____--__--_-._-.-__.__--_-_--___---__---_ 26 Adequake wellbore separationproposed- - - - - -- - - - - - -- - - - - - - - - - - - - - - - - -- -Yes _ _ _ _ - - _ Proximity- analysis performed: Nearest wellbare_is Bsand-lateral, X65' tvd below. _ _ - - _ _ _ _ _ - - - _ - - - - _ - 27 If diverterrequired,doesitmeetregulations-___________________ __________ NA__ _ _____BOPStackwillalready-be in place,-___________---_____._____--_______,--__-. Appr Date 28 Dulling fluid_program schematic-& equip list adequate, - . _ - - . _ _ _ _ _ - _ Yes _ _ _ . Maximum expQCted fo[mafion pressure 8.6_EMW~ Planned.MW 9.Oppg in WS.- _ - _ _ _ _ _ - TEM 5!11!2005 29 BOPEs,dotheymeetregulation___________________________ ___.___-_Yes_ _-_.._ _____ __ - -- 30 BOPE_press rating appropriate; test to_(put prig in comments), _ _ - - _ _ _ - _ - , Yes - - _- _--_ _-____.__- - -- - - MA$P calculated at 1083psi, 3000_psi_appropriate. -CPAI normally tests to 6000_psi_ _ _ _ _ _ _ _ _ _ __ _ _ _ _ 31 Choke_manifold comp_liesw/APiRP-53 (May 84) - - - - - Yes - - - - - - - - - - - - 32 Work willoccu[withoutoperationshutdown___-__-_____.____ _-__--__--Yes__ ___--____-________________________ - - -- 33 Is presence-of H2S gas probable- - . , _ - - - . - _ Yes - - . H2S has_bee reported in 1 E WS wells. Mud should preclude H2$ on rig. Rig has_senso_rs-and alarms.. - .. - 34 Mechanical condition of wells within AOR verified (FOrservice well only) - _ _ _ _ - - _ NA_ _ Geology 35 Permit_can be issued wlo hydrogen_sulfide measures - - - - - - ---- - - - - - - - - - - - -N_o- _ _ _ _ KRU 1 E-Pad West Sak wells measured from 22 to 76 ppm H2S in 2004. R~_has sensors and alarms., , . _ _ . 36 Data.presented on-potential overpressure zones.. _ - - - . - - _ ... Yes - Expected reseruoirpressure is 8,1.- 8,6_ppg EM_W_; will be drilled wish 0.0 ppg ail-base mud. _ _ - _ - . - - Appr Date 37 Saismic.analysis ofshallow gas-zones, _ - - _ - _ . - NA_ _ - - . - _ - - _ . SFD 5110!2005 38 Seabed condition survey-(ifoff_-shore)-_-___-________________ __________NA._ _ - - - 39 _ Contact namelphone_for weekly progress,reports (exploratory only), _ _ _ _ _ _ _ _ _ _ _ __ _ NA_ _ _ . _ _ _ - - _ . _ _ _ - _ _ - _ _ _ _ _ _ _ _ _ _ - . _ _ - - _ _ - _ _ - Geologic Engineering Public Commissioner: Date: Comm ner: Date Comm' iss io Date ~ y ~ • • 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 ilie Well History file and to simplify i'inding infom~ation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made 1o chronologically organize this category of information. + • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Jan 09 15:34:29 2006 Reel Header Service name .............LISTPE Date .....................06/01/09 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/01/09 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library • 1345 ~' b~-D7 Lo Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: 1E-170 L2 API NUMBER: 500292326461 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 09-JAN-06 JOB DATA MWD RUN 3 MWD RUN 4 MWD RUN 17 JOB NUMBER: MW0003778283 MW0003778283 MW0003778283 LOGGING ENGINEER: B. HENNINGSE B. HENNINGSE B. HENNINGSE OPERATOR WITNESS: G. RIZEK G. RIZEK G. WHITLOCK MWD RUN 18 MWD RUN 19 JOB NUMBER: MW0003778283 MW0003778283 LOGGING ENGINEER: C. COCHRAN B. HENNINGSE OPERATOR WITNESS: G. WHITLOCK G. WHITLOCK SURFACE LOCATION SECTION: 21 TOWNSHIP: 11N RANGE: l0E FNL: 247 FSL: FEL: 641 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 111.05 GROUND LEVEL: 70.40 WELL CASING RECORD OPEN HOLE CASING DRILLERS s BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 5054.0 2ND STRING 8.500 9.625 9412.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 9412' MD/3274'TVD, WITHIN THE RUN 4 INTERVAL OF THE 1E-170 PB1 WELLBORE. 5. MWD RUNS 3,4,18,19 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE-WHILE-DRILLING (PWD) RUNS 3,4,19 INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP) MWD RUN 19 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL STABILIZED LITHO-DENSITY (ABED), AND ACOUSTIC CALIPER (ACAL). SROP DATA ONLY ARE PRESENTED FOR RUN 17. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-4,17-19 REPRESENT WELL 1E-170 L2 WITH API#: 50-029-23264-61. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15748'MD/3186'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING), SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE LITHOLOGY, ACAL-DERIVED). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. ACAL = ACOUSTIC CALIPER. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: ACAL-DERIVED - 8.5" BIT MUD WEIGHT: 9.0-9.1 PPG MUD SALINITY: 40000-60000 PPM CHLORIDES FORMATION WATER SALINITY: 11000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH FET 5046.5 15702.5 RPX 5046.5 15702.5 RPS 5046.5 15702.5 RPM 5046.5 15702.5 RPD 5046.5 15702.5 GR 5054.0 15710.5 ROP 5090.5 15748.0 NPHI 9971.5 15657.0 FCNT 9971.5 15657.0 NCNT 9971.5 15657.0 CALA 9976.5 15660.5 RHOB 9984.5 15670.0 PEF 9984.5 15670.0 DRHO 9984.5 15670.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP 3 5046.5 4 9064.5 17 9412.5 18 9442.0 19 10061.0 REMARKS: MERGED MAIN PASS. MERGE BASE 9108.0 9412.0 9442.0 10061.0 15748.0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN • Max fr ames per record ..... ........Undefined Absent value ... ........... ........-999 Depth Units .... ........... ........ Datum Specifica tion Block sub- type...0 Name Serv ice Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 GALA MWD INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5046.5 15748 10397.3 21404 5046.5 15748 ROP MWD FT/H 0.58 2345.03 237.551 21316 5090.5 15748 GR MWD API 24.43 138.57 68.9463 21314 5054 15710.5 RPX MWD OHMM 2.1 2000 54.5237 21313 5046.5 15702.5 RPS MWD OHMM 4.74 2000 56.2092 21313 5046.5 15702.5 RPM MWD OHMM 5.09 1835.59 56.2654 21313 5046.5 15702.5 RPD MWD OHMM 1.58 2000 63.023 21313 5046.5 15702.5 FET MWD HOUR 0.06 1130.8 1.94069 21313 5046.5 15702.5 NPHI MWD PU-S 8.2 56.72 40.3215 11372 9971.5 15657 FCNT MWD CNTS 687.64 4186.89 893.966 11372 9971.5 15657 NCNT MWD CNTS 34754.4 199031 128828 11372 9971.5 15657 RHOB MWD G/CM 1.993 2.701 2.13334 11372 9984.5 15670 DRHO MWD G/CM -0.098 0.34 0 .0209903 11372 9984.5 15670 PEF MWD BARN 1.03 6.08 1.90079 11372 9984.5 15670 CALA MWD INCH 8.46 10.01 8.65025 11309 9976.5 15660.5 First Reading For Entire File..........5046.5 Last Reading For Entire File...........15748 File Trailer Service name .............STSLI$.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 • Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 5046.5 9064.0 RPX 5046.5 9064.0 RPM 5046.5 9064.0 RPD 5046.5 9064.0 FET 5046.5 9064.0 GR 5054.0 9071.5 ROP 5090.5 9108.0 LOG HEADER DATA DATE LOGGED: 06-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9108.0 TOP LOG INTERVAL (FT) 5090.0 BOTTOM LOG INTERVAL (FT) 9108.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 74.2 MAXIMUM ANGLE: 82.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 59672 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 5054.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 50.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 1000 FLUID LOSS (C3) 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 7.500 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 5.380 93.2 MUD FILTRATE AT MT: 5.000 65.0 MUD CAKE AT MT: 2.300 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: i Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5046.5 9108 7077.25 8124 5046.5 9108 ROP MWD030 FT/H 1.06 2345.03 329.886 8036 5090.5 9108 GR MWD030 API 24.43 138.57 65.8909 8036 5054 9071.5 RPX MWD030 OHMM 2.1 84.28 14.8458 8036 5046.5 9064 RPS MWD030 OHMM 4.74 2000 17.3313 8036 5046.5 9064 RPM MWD030 OHMM 5.09 1835.59 18.6538 8036 5046.5 9064 RPD MWD030 OHMM 5.01 2000 20.1687 8036 5046.5 9064 FET MWD030 HOUR 0.06 122.75 1.70767 8036 5046.5 9064 First Reading For Entire File..........5046.5 Last Reading For Entire File...........9108 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 • DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 9064.5 9412.0 FET 9064.5 9412.0 RPD 9064.5 9412.0 RPM 9064.5 9412.0 RPS 9064.5 9412.0 GR 9072.0 9412.0 ROP 9108.5 9412.0 LOG HEADER DATA DATE LOGGED: 13-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9412.0 TOP LOG INTERVAL (FT) 9108.0 BOTTOM LOG INTERVAL (FT) 9412.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 77.7 MAXIMUM ANGLE: 81.5 TOOL STRING (TOP TO BOTTOM) 12.250 5054.0 VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124725 EWR4 ELECTROMAG. RESIS. 4 116184 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN LSND 9.30 65.0 8.5 800 4.0 • 2.500 67.0 1.490 116.6 1.950 67.0 1.980 67.0 • • Max frames per record ....... ......Undefined Absent value ... ............. ......-999 Depth Units .... ............. ...... Datum Specifica tion Block su b-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9064.5 9412 9238.25 696 9064.5 9412 ROP MWD040 FT/H 28.98 268.5 175.867 608 9108.5 9412 GR MWD040 API 65.26 113.29 94.7091 681 9072 9412 RPX MWD040 OHMM 7.48 24.42 9.64629 696 9064.5 9412 RPS MWD040 OHMM 8.25 26.96 10.7056 696 9064.5 9412 RPM MWD040 OHMM 8.55 33.63 11.1399 696 9064.5 9412 RPD MWD040 OHMM 9.3 37.41 12.3452 696 9064.5 9412 FET MWD040 HOUR 0.22 153.21 20.4736 696 9064.5 9412 First Reading For Entire File..........9064.5 Last Reading For Entire File...........9412 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 17 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 9412.5 9442.0 • • LO G HEADER DATA DATE LOGGED: 28-AUG-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9442.0 TOP LOG INTERVAL (FT) 9412.0 BOTTOM LOG INTERVAL (FT) 9442.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 81.4 MAXIMUM ANGLE: 81.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 9412.0 BOREHOLE CONDITIONS MUD TYPE: Oil Based MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 22.0 MUD PH: .0 MUD CHLORIDES (PPM): 40000 FLUID LOSS (C3) 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 113.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD170 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9412.5 9442 9427.25 60 9412.5 9442 ROP MWD170 FT/H 0.58 19.32 -8.514 60 9412.5 9442 First Reading For Entire File..........9412.5 Last Reading For Entire File...........9442 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER • FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 18 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 9412.5 10016.0 GR 9412.5 10019.5 RPX 9412.5 10016.0 RPS 9412.5 10016.0 RPD 9412.5 10016.0 RPM 9412.5 10016.0 ROP 9442.5 10061.0 LOG HEADER DATA DATE LOGGED: 29-AUG-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10061.0 TOP LOG INTERVAL (FT) 9442.0 BOTTOM LOG INTERVAL (FT): 10061.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 80.3 MAXIMUM ANGLE: 92.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 157645 BOREHOLE AND CASING DATA • OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 9412.0 BOREHOLE CONDITIONS MUD TYPE: Oil Based MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 90.0 MUD PH: .0 MUD CHLORIDES (PPM): 60000 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 107.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD180 FT/H 4 1 68 4 2 GR MWD180 API 4 1 68 8 3 RPX MWD180 OHMM 4 1 68 12 4 RPS MWD180 OHMM 4 1 68 16 5 RPM MWD180 OHMM 4 1 68 20 6 RPD MWD180 OHMM 4 1 68 24 7 FET MWD180 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9412.5 10061 9736.75 1298 9412.5 10061 ROP MWD180 FT/H 42.8 1297.5 221.81 1238 9442.5 10061 GR MWD180 API 41.99 87 66.0539 1215 9412.5 10019.5 RPX MWD180 OHMM 10.57 2000 82.3453 1208 9412,5 10016 RPS MWD180 OHMM 12.46 2000 71.4156 1208 9412.5 10016 RPM MWD180 OHMM 5.59 1809.23 61.4197 1208 9412.5 10016 RPD MWD180 OHMM 1.58 2000 71.2638 1208 9412.5 10016 FET MWD180 HOUR 0.15 1130.8 4.86507 1208 9412.5 10016 First Reading For Entire File..........9412.5 Last Reading For Entire File...........10061 File Trailer • Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 19 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FCNT 9971.5 NCNT 9971.5 NPHI 9971.5 CALA 9976.5 RHOB 9984.5 DRHO 9984.5 PEF 9984.5 RPX 10016.5 RPS 10016.5 RPM 10016.5 RPD 10016.5 FET 10016.5 GR 10020.0 ROP 10061.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 15657.0 15657.0 15657.0 15660.5 15670.0 15670.0 15670.0 15702.5 15702.5 15702.5 15702.5 15702.5 15710.5 15748.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON ALD Azimuth. Litho-Den ACAL Acoustic Caliper O1-SEP-05 Insite 66.37 Memory 15748.0 10061.0 15748.0 89.0 93.0 TOOL NUMBER 132477 10505932 174114 10507541 727424 • BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 9412.0 BOREHOLE CONDITIONS MUD TYPE: VersaPro MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 83.0 MUD PH: .0 MUD CHLORIDES (PPM): 50000 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 137.5 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD190 FT/H 4 1 68 4 2 GR MWD190 API 4 1 68 8 3 RPX MWD190 OHMM 4 1 68 12 4 RPS MWD190 OHMM 4 1 68 16 5 RPM MWD190 OHMM 4 1 68 20 6 RPD MWD190 OHMM 4 1 68 24 7 FET MWD190 HOUR 4 1 68 28 8 NPHI MWD190 PU-S 4 1 68 32 9 FCNT MWD190 CNTS 4 1 68 36 10 NCNT MWD190 CNTS 4 1 68 40 11 RHOB MWD190 G/CM 4 1 68 44 12 DRHO MWD190 G/CM 4 1 68 48 13 PEF MWD190 BARN 4 1 68 52 14 CALA MWD190 INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9971.5 15748 12859.8 11554 9971.5 15748 ROP MWD190 FT/H 7.11 4 00.68 178.533 11374 10061.5 15748 GR MWD190 API 45.54 90.96 69.8707 11382 10020 15710.5 RPX MWD190 OHMM 14.02 2000 82.3509 11373 10016.5 15702.5 RPS MWD190 OHMM 17.49 18 33.67 84.8494 11373 10016.5 15702.5 • RPM MWD190 OHMM 27.69 1623.34 85.0553 11373 10016.5 15702.5 RPD MWD190 OHMM 25.32 1794.68 95.5293 11373 10016.5 15702.5 FET MWD190 HOUR 0.19 19.34 0.660555 11373 10016.5 15702.5 NPHI MWD190 PU-S 8.2 56.72 40.3215 11372 9971.5 15657 FCNT MWD190 CNTS 687.64 4186.89 893.966 11372 9971.5 15657 NCNT MWD190 CNTS 34754.4 199031 128828 11372 9971.5 15657 RHOB MWD190 G/CM 1.993 2.701 2.13334 11372 9984.5 15670 DRHO MWD190 G/CM -0.098 0.34 0.0209903 11372 9984.5 15670 PEF MWD190 BARN 1.03 6.08 1.90079 11372 9984.5 15670 GALA MWD190 INCH 8.46 10.01 8.65025 11309 9976.5 15660.5 First Reading For Entire File..........9971.5 Last Reading For Entire File...........15748 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/01/09 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................06/01/09 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF Scientific Technical Services Scientific Technical Services End Of LIS File