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205-027
2.05 - a 2.I RECEIVED 1k2-1 MAY 06 2016 WELL LOG TRANSMITTAL#903188506 A G To: Alaska Oil and Gas Conservation Comm. May 4, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 Z.n�i2o, M.K.BENDER SED RE: Injection Profile : 1E-117L1 Run Date: 3/15/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1E-117L1 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-23251-60 Injection Profile Log 1 Color Log 50-029-23251-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: , / , ,/, • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~(~ ~ ©o~„~ Well History File Identifier Organizing (done> ~wo-sided 111 IIIIII II III (~ III ^ Rescan Needed III IIIII II II III III RESCAN DIGITAL DATA OVERSIZED (Scannable) ~o(or Items: Diskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: ^ Other: OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ` /s/ Project Proofing III IIlIIIIIIII IIIII BY: Maria Date: ~~ 3D~(18 /s1 ~~ Scanning Preparation ~` x 30 = ~ + ~ ~ =TOTAL PAGES l 3 ~. (Count does not include cover sheet) BY: Maria Date: ~ ~ ~/~ ~ /') ~ /s/ ~l I Production Scanning Stage 1 Page Count from Scanned File: _,~~ (Count does include~cov~er sheet) Page Count Matches Number in Scanning Preparation: V YES NO BY: Maria Date: ~ l~ n ~ O ~' /s/ ~ /~ /~ . ( V ~V~~ Stage 1 If NO m stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II II II I II II IIIII ReScanned III IIlIIIIIII IIIII BY: Maria Date: /s! Comments about this file: Quality Checked III IIIII III III III 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other ❑✓ WINJ to WAG Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Current Well Status: . Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑ Exploratory El' 205-027 3. Address: Stratigraphic ❑ Service 0 API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 23251 -60 N;. Elevation (ftZ Well Name and Number: RKB S"I 1 1 E -1171_1 8 Property Designation: N. Field /Pool(s): ADL 25660 Kuparuk River Field / West Sak Oil; Pool 11. Present Well Condition Summary: Total Depth measured 15667' feet true vertical \ 3275' feet Plugs (measured) Effective Depth measured 15667' feet Junk (measured) true vertical 3275' feet Casing Length Size MD TVD Burst Collapse 9 9 CONDUCTOR 108' 20" 108' 108' SURFACE 5448' 13 -3/8" 5543' 2364' INTERMEDIATE 10477' 9 -5/8" 10572' 3510' - LINER 5888' 5 -1/2" 15675' 3275' Perforation de depth: Measured the 9845 - 15631' p p true vertical depth: 3406 -3275' Tubing (size, grade, and measured depth) 4 -1/2 ", L -80, 9347' MD. Packers & SSSV (type & measured depth) ZXP Packer 9645 SSSV =NIP 505' 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 Casino Pressure _ L . Lubinq Pressure Prior to well operation 788 1117 576 Subsequent to operation 1810 803 1783 14. Attachments . 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: ❑ Nz Gas❑ WAGE GINJ WINJ ❑ WDSPL❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt 309 -051 Contact B. Christensen/ D. Humphrey Printed NaZ R rt D. C istense Title Production Engineering Specialist Signature Phone: 659 -7535 Date / a Dq Form 10-404 Revised 04/2004 Submit Original 0 nly 1 E -1 17L1 ` DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/23109 Commenced Viscous Recovery WAG Injection ConocoPhillips Alaska, Inc. KRU 1 E-1 171-1 1E -117L1 AP I 50 Well T e: INJ An le TS: de - - -- - TUBING SSSV Typ e: NONE Orig Completion: 8/13/2005 An le TD: 91 de 15667 (0-9347, Annular Fluid: Last W /O: 10/16/2005 Rev Reason: FORMAT UPDATE OD:4.500, Reference Loa: 28' RKB Ref Log Date: Last Upda te: 12127/2007 03.958) Last Tag. TD: 15675 ftKB TERMEDIATE Last T alc Date: Max Hole An le: 94 de 10001 0D:9.625, CasingStr M N ST Wt:40.00) Description Size To Bottom TVD Wt Grade Thread INTERMEDIATE 9.625 0 _10572 _3380 40.00 L -80 BTCM CONDUCTOR 20.000 0 _ 108 108 94.00 K -55 WELDED SURFACE 13.275 0 5543 2364 68.00 L -80 BTC SURFACE — lbsing String - B -SAND Slotted Liner (Alternating is blank/slotted pipe 2.5"k. 125M 4 (0 -5543, Descri tion _ Si ze To Bottom TVD Wt Grade Thread OD:13.275, — —_ — - — Wt:68.00) B -Sand Slotted Liner 5.500 9787 15675 15675 15.50 L - BTCM Tubing String - TUBING Siz Top__ Bottom TVD Wt Grade Thread 4.500 0 9347 1 3333 1 12.60 L -80 IBTM Perforati ma SLEEVE -C Interval TVD Zone Status Ft SPF Date Type _ Comment (9248 -9249, 9845-10141 3407-3391 WS B 296 40 7/23/2005 Slotted Alternating blank/slotted liner its OD:5.490) 10420 - 10504 3381-3380 WS B 84 40 7/23/2005 Slotted Alternating blank/slotted liner Its 10547 - 10675 3380-3379 WS B 128 40 7/23/2005 Slotted Alternating blank/slotted liner'ts 10718 - 10845 3378-3373 WS B 127 40 7/23/2005 Slotted Alternating blank/slotted liner Its 11146 - 11563 3361 -3353 WS B 417 40 7/23/2005 Slotted Alternating blank/slotted liner'ts 11994 - 12038 3353-3353 WS B 44 40 7/23/2005 Slotted Alternating blank/slotted liner'ts 12080 - 12122 3354-3354 WS B 42 40 7/23/2005 Slotted Alternating blank/slotted liner'ts LOCATOR 12165 - 12291 3354-3353 WS B 126 40 7/23/2005 Slotted Alternating blank/slotted liner its ODA.7 50) (9 12335 - 12464 3353-3351 WS B 129 40 7/2312005 Slotted Alternating blank/slotted liner'ts D:4.7 12722 - 12806 3344-3341 WS B 84 40 7/23/2005 Slotted Alternating blank/slotted liner'ts 12849 - 12976 3340-3337 WS B 127 40 7/23/2005 Slotted Alternating blank/slotted liner'ts 13018 - 13185 3335-3331 WS B 167 40 7/23/2005 Slotted Alternating blank/slotted liner'ts 13488 - 13526 3323-3322 WS B 38 40 7/23/2005 Slotted Alternating blank/slotted liner'ts 13570 - 13612 3321-3321 WS B 42 40 7/23/2005 Slotted Alternating blank/slotted liner'ts D -sand - 13656 - 13781 3320 - 3316 WS B 125 40 7/23%2005 Slotted Alternating blank/slotted liner is window 13825 - 13952 3314-3310 WS B 127 40 7/23/2005 Slotted Alternatin blank/slotted liner'ts (9391 -9407, 14211 - 14289 3303-3301 WS B 78 40 7/23/2005 Slotted Alternating bIank/slotted lineCts OD:8.835) 14333 - 14375 3300-3299 WS B 42 40 7/23/2005 Slotted Alternating blank/slotted liner'ts 14419 - 14545 3298 - 3294 WS B 126 40 7/23/2005 Slotted Alternating blank/slotted liner its 14586 - 14712 3292-3290 WS B 126 40 7/23/2005 Slotted Alternatin blank/slotted liner its Hook HGR - 14962 - 15043 3284-3282 WS B 81 40 7/23/2005 Slotted Alternating blank/slotted liner'ts (9397 -9398, 15084 - 15168 3282-3280 WS B 84 40 7/23/2005 Slotted Alternatin blank/slott ed liner'ts OD:9.625) 15210 - 15252 3279-3278 WS B 42 40 7/23/2005 Slotted Alternating blank/slotted liner'ts 15293 - 15336 3277-3277 WS B 43 40 7/23/2005 Slotted Alternatin blank/slotted liner its 15380 - 15422 3277-3278 WS B 42 40 7/23/2005 Slotted Alternating blank/slotted liner its 15464 - 15504 3278-3278 WS B 40 40 7/23/2005 Slotted Alternating blank/slotted liner'ts 15546 - 15631 3277-3276 WS B j 85 40 7/23/2005 Slotted Alternatin blank/slotted liner'ts Was Lift MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type VOID Latch Port TRO Date Run Vlv Cmnt 1 1876 1501 CAMCO KBG -2 -1R DMY 1.0 BK 0.000 0 1/20/2006 Other lugs equip., etc.) - _COM J EWELRY Depth TVD � Type De scription ID 22 22 _ HANGER TU BING HANGER _ _ _ 3.900 506 505 1 NIP CAMCO'DB'NIPPLE 10/ 16/2005 3.875 PACKER — 9248 3313 1 SLEEVE -C BAKER SLIDING SLEEV - CLOSED 10/28/200 3.812 (9648 -9666, 9330 3330 LOCATOR BAKER LOCATOR SEAL ASSEMBLY 3.875 OD:8.490) 9391 3342 D -Sand D -SAND WINDOW 7.000 X0 Window (9666 -9667, 9397_ _ 3344 Hook HGR D -SAND MODEL B -1 HOOK HANGER 7.000 OD:6.030) 9647 3391 B -Sand LEM B -SAND LATERAL ENTERY MODULE 3.880 9648 3392 PACKER B -SAND LINER TOP PACKER w /HRD PROFILE 7.500 9666 3395 1 XO 4.940 9667 3395 1 SBR B -SAND LINER 190-47 CASING SBR 4.750 9687 3398 BUSHING XO BUSHING 3.940 9687 3398 PUP _ 3.958 9688 3398 SWIVEL CASING SWIVEL 3.960 9706 3401 B -Sand B -SAND WINDOW 7.000 Window Other - B -SAND LINER JEWELRY Depth TVD Type Description ID 9694 3399 HOOK HGR B -SAND LEM ABOVE HOOK HANGER MODEL B -1 3.980 Perf 9707 3401 HOOK HGR B -SAND LEM INSIDE HOOK HANGER 3.688 (9845 - 10141) 9756 3406 CSG B -SAND BAKER PAYZONE EXTERNAL CASING PACKER 7.000 Perf _ _ PACKER 10420 10504) KW Not Perf - Date I Note 10547- 10675) 7/25/2005 NOTE: MULTI - LATERAL WELL: 1E -117 A -SAND , 1E -117L1 B -SAND 1E -117L2 D -SAND Perf — I 10115/2005 NOTE: WORKOVER RIG PULLED KILL STRING/ -SAND HOOK HANGER & REPLACED 10718- 10845) -- -- I Perf — 11146- 11563) Perf '11994- 12038) Perf I I 12080- 12122) Perf 12165- 12291) — • • ~;= ~ ~~, ~~ ~ ~ ~~ ~ ~ ~ " r '` ~ ~ ~ "" ~ ~F "s r r t r t~~ N ~~~g~ tL ~ ~ ~~ ~ , ~ ~ ~ ~ ~ ~ ~ L ~ f ~ ~ ~ c. x e ~~ Y: ~ a r ~~ ~ ~ ~ ~ i ~ ~ ~~~ n t f ~ k ~ ~ ~ ~ ~ ~ ~~ .~ ~-- ~ a: ~ ~ ~ ~~`~ ~~ ~ `~ ~ ~ k ~ !~ ~ ~ ~ ~ ~ ~ ~ SEAN PARNELL, GOVERNOR ~,~ __~ ~~ ~! € i~ ~ ~, ~~~~ ~_' ,~~ ~ f o- ~~; b~~4~,~ ~- ~ ~ ~~~ ~~ , ~ ~*~ SA I ~ta~ ~ ~T taLAS 0~ tusi~ ~ ~ 333 W. 7th AVENUE, SU E 100 COI~TSERQATIOI~T CO1~II~IIS51O1~T ~ ANCHORAGE, ALASKA 99501-3539 ~r PHONE (907) 279-1433 , FAX (907) 276-7542 Mr. M.J. Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. ~ P.O. Box 100360 ~ 1 ~ Anchorage, AK 99510 _ ~ Re: Kuparuk River Unit, West Sak Pool, 1 E-117L 1 Sundry Number: 309-051 ~~~~~~~ ~G ~ ~ ~ ~~~~ Dear Mr. Loveland: 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. When providing 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, ~ ~i ~~~~ Cathy P. Foerster Commissioner r"~ DATED this ~ day of October, 2009 Encl. . ! • y' . . ConocoPh111~ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 13, 2009 ;:~~~ Mr. Tom Maunder '~ ~~~ r~~„~ Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~' ~. ~ u~d~.. `~~i` -~`~~.: Dear Mr. Maunder: Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhilli s Alaska, Inc. Trilateral West Sak injection well 1E-117 (205-026), E-117L1 205-02 1E-117L2 (205-028) for viscosity reducing water alternating gas cycles (WRWAG). Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, /~~~~ ~~~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures r p~ ~b o' ~ ~~~~~~~~ • STATE OF ALASKA • ~~Q ~ 7 ~(~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPRO~-~~~ ~~# ~ ~~s ~on~R ~°'~m+ss~~n 20 AAC 25.280 An~hara~e 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ~ Other Q Alter casing ^ Repair well ~ Plug Perforations ^ Stimulate ^ Time Extension ~ Change approved program ^ Pull Tubing ~ Perforate New Pool ^ Re-enter Suspended Well ^ VR EOR WAG 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, IIIC. Development ^ ~cp~oratory ^ 205-027 ' 3. Address: Stratigraphic ~ Service Q/ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23251-60 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Y@S ^ NO ~^ 1E-117L1 , 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25660 • RKB 95' Kuparuk River Field / West Sak Oil Pool • 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective oepth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 15667' • 3275' • Casing Length Size MD ND Burst Collapse CONDUCTOR 108' 20" 108' 108' SURFACE 5448' 13-3/8" 5543' 2364' INTERMEDIATE 10477' 9-5/8" 10572 3510' 5888' S-1 /2" 15675' ~ 3275 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slotted liner 9845'-15631' 3406-3275' 4-1/2" L-80 9347' Packers and SSSV Type: Packers and SSSV MD (ft) ZXP packer 9648 no SSSV - DB Nipple no SSSV - DB Nipple 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Development ^ Service ~^ • 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: U~~ EJ / C'~ ~ Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG Q . GINJ ^ WINJ ^ WDSPL ~ Commission Representative: 18. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Perry Klein/MJ Loveland Printed Name MJ Loveland/Per KI Il / Title: Well Integrity Project Supervisor Signature ~"~ ~-r/. `~-~~_'/ Phone659-7043 Date ~-;z~ ~~,~ ~ ~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~~ ~ Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: ~('ILi~na.Z~ or~?~'a~'°i. ih r 2CC.o~r~Y W~-~ Z U.~y I Subsequent Form Required: t~_:d 1~~~°' t~ ~ APPROVED BY Approved by: COMMI SI ER THE CO MISSION Date: " Form 10-403 Rev%~ed 06/2006 ~,-~ r ~,~~ ~~ Submit in Duplicate ~ ~ ~ . ~-: f ~~,~ Q ~ t ~~~o'J ~ ~z • i~•°9 • • ConocoPhillips Alaska, Inc. 1 E-117 (PTD 205-026) & L1 (PTD 205-027) & L2 (PTD 205-028) Sundry Notice 10-403 Request Februray 12, 2009 Purpose: The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska Inc., intent to inject viscosity reducing water alternating gas (VRWAG) cycles in .~ West Sak Injection Well 1 E-117 (PTD 205-026) and gain approval to do so. This well is part of a 4 pattern field trial of the West Sak VRWAG process that will increase the oil recovery in each pattern and prove the incremental benefit of VRWAG to West Sak for a potential future project to expand EOR on a broader scale. See attached pattern map. Well History: 1 E-117 was drilled in July 2005, completed as a pre produced injector in October 2005, and placed in water only injection service in February 2006. '~ The well was drilled with a 20" conductor to 108'. The surFace hole was drilled with a 16" bit and cased with 13-3/8" casing to a TD of 5544'. The casing was cemented in place with 792 bbl of lead cement and 124 bbl of tail cement. Lost returns with 86 bbl left to pump. Bumped plug and saw mud push at surFace. Ran in annulus with 1'/4" Hydril to 264' and pumped 46 bbl cement with good returns to surFace. The intermediate hole was drilled with a 12 1/4" bit and cased to 10572' with 9 5/8" casing. The casing was cemented in place with 324 bbl LiteCrete cement no returns were mentioned. The top of cement is confirmed at 5520' by a USIT log. The USIT log also shows good bond through and above the West Sak and Ugnu intervalw. See attached USIT excerpt. Proposed Plan: The proposed plan includes the following: 1. Inject VRWAG cycles into 1 E-117 2. Injection well 1 E-117 will be operated and maintained in compliance with 20 AAC 25 and Area Injection Order 2B. 3. All West Sak wells with in '/4 mile of 1 E-117 will be completed (or recompleted) with a tubing & packer completion (vs. ESP). 4. The VRWAG cycles will be closely monitored with frequent oil and gas samples from the offset West Sak producers. 5. All Kuparuk wells with in'/4 mile will have OA pressure indicating transmitters installed prior to VRWAG start up. 6. Prior to start up well integrity issues and corresponding mitigating VRWAG strategies will be clearly documented. 2009 WSAK EOR Pattern Targets ~ ~ 1E-117 injector •Logged from 10,180 to 5,400' Tops UG C 7,077 •Top of cement labeled @-5,520' (above Ugnu) UG B 7,829 •Unable to determine cumulative footage of good bond UG A 7,933 K13 8,522 •Some channeling appears in CBL K13 8,820 D 9,391 10,200-10,030 Top interval 5,680'-5,500' • • MICROFILMED 03101 /Z00~ DO NOT PLACE ANY NEW MATERIAL UNDER THIS PACE F:\L~aserFiche~CvrPgs_InsertslAilicrofilm Marker.cbc DATA SUBMITTAL COMPLIANCE REPORT 11 /23/2007 Permit to Drill 2050270 Well Name/No. KUPARUK RIV U WSAK 1 E-117L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23251-60-00 MD 15667 TVD 3275 Completion Date 10/16/2005 Completion Status 1-OIL Current Status 1WINJ ~ UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Su DATA INFORMATION Types Electric or Other Logs Run: GR/Res, CCL Well Log Information: Log/ Electr Data Digital Dataset Tye Med/Frmt Number Name ' D Asc Directional Survey ED D Asc Directional Survey ~D D Lis 13421 Induction/Resistivity ~ tiRpt 13421 LIS Verification ~D D Lis 13422 Induction/Resistivity ~pt 13422 LIS Verification x.15 ~' ' ED C -lies 14455 Induction/Resistivity Well Cores/Samples Information: Name (data taken from Logs Portion of Master Well Data Maint Interval Log Log Run Scale Media No Start Stop OH / CH Received Comments ~' _ 11632 15667 Open 9/26/2005 IIFR 9615 11853 Open 9!26!2005 PB 1 IIFR 5524 15629 Open 1/31/2006 GR/EWR4/CNP/SLD/ROP/ '~ ACAUPWD/GEOPILOT L1 5524 15629 1/31/2006 GR/EWR4/CNP/SLDlROP/ ACAL/PWD/GEOPILOT L1 i 5524 11815 Open 1/31/2006 GRlEWR4/CNP/SLD/ROP/ ACAL/PWD/GEOPILOT L1 P61 5524 11815 1/31/2006 GR/EWR4/CNP/SLD/ROP/ ACAUPWD/GEOPILOT L1 PB1 5517 15667 Open 1/29/2007 LIS Veri, FET, GR, ROP, NCNT, NPHI, CALA, DRHO, DRHO w/Graphics **L1 P61 information is missing on this disk** Sample Interval Set Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 11 /23/2007 Permit to Drill 2050270 Well Name/No. KUPARUK RIV U WSAK 1 E-117L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23251-60-00 MD 15667 TVD 3275 ADDITIONAL INFORMATION Well Cored? Y ~N Chips Received? ~- Analysis JLLDd- Received? Comments: Completion Date 10/16/2005 Completion Status 1-OIL Daily History Received? Formation Tops Compliance Reviewed By: Current Status 1WINJ ~N ~/ N Date: UIC Y ~. • • WELL LOG TRANSMITTAL To: State of Alaska November 13, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: lE-ll7, PBl, L1, L1 PB1, L2 & L2 PB1, AK-MW-3775114 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 1E-117, PB1, L1, Ll PB1, L2 & L2 PBl: Digital Log Images: CD Rom 50-029-23251-00, 70, 60, 71, 61 & 72 USc2os-o~~ #`~L~~y ~ ~ ~( ~ W®s-d~oe- sa.~s a~'t31 ~,~~~°Ii~-t--.t is uu~5s~~~> ~ C - t t~ i i~ U~c ao~ - U ~'~ ~ f~-IUSS ~~~{a~i ~ ~ ~~} ~~r~ a~S -U~~ ~ t~~iS ~ RE~E~IVED ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~ STATE OF ALASKA FEB 0 6 2006 Alaska Oi! & Gas Icons. Clurrxunission REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Q Prod to WIND Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ 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 ^ 205-027 3. Address: Strati ra hic g p ^ Service ~ ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23251-60 7. KB Elevation (ft): 9. Well Name and Number. RKB 95' 1 E-117L1 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 15667' feet true vertical 3275' feet Plugs (measured) Effective Depth measured 15675' feet Junk (measured) true vertical 3275' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR .108' 20" 108' 108' SURFACE 5448' 10-3/4" 5543' 2364' INTERMEDIATE 10477' 9-5/8" 10572' 3509' PROD. CASING 5888' 5-1/2" 15675' 3275' Perforation depth: Measured depth: 9845 - 15631' Slotted true vertical depth: 3407' - 3276' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 9347' MD. Packers &SSSV (type & measured depth) no packer SSSV=NIP SSSV= 506' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none S ~I•~ ! i<EB Treatment descriptions including volumes used and final pressure: . ~ ~ 20D6 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1901 526 33 900 328 Subsequent to operation 2795 943 -9 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 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 N/A if C.O. Exempt: Contact Robert W. Buchholz Printed Name Title Production Engineering Technician Signature ~~ ~/~ ~~`~~,,~~ Phone ~/ ~ 907-659-7535 Date / ~ O / D 6 Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only 1 E-117L1 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 1/29/2006 Commenced Water Injection Robert D. Christensen Production Engineering Technician ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: KRU 1 E-117L 1 Sundry; Number: 306-003 Dear Mr. Christensen: FRANK H. MURKOWSKI, GOVERNOR #,~ P 333 W. 7T" AVENUE, SUITE 100 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. ~i n rPral~r DATED thisday of January, 2006 Encl. C:halrman ~~ < /~ STATE OF ALASKA ~ I.~ ~ ~ _~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL ,s~~ '£'' 20 AAC 25.280 n _ __ _ ~ ~ ____ _ .. . 1. Type of Request: Abandon ^ Suspend ^ Operation Shutdown ^ s,~~.,.,..~,_ Perforate ^ ,y Waiver Other ^ ~ ~ Alter casing ^ Repair well ^ Plug Perforations ^ ~, /1 , ~ tAM-iiL~ Stimulate ^ Time Extension ^ ~ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ _ Re-enter Suspended Well ^ ~"~'~ 1 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 205-0 /27/' 3. Address: Stratigraphic ^ Service ^ 6. API Number: ~ P. O. Box 100360, Anchorage, Alaska 99510 50-029-23251- , 60, 7. KB Elevation (ft): ' 9. Well Name and~~N~~~~umber: " ~ ~ RKB 95 1 E-117, L1, ~ G.t~ (3 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit 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): 15774' 3415' 15751' 3625' Casing Length Size MD ND Burst Collapse CONDUCTOR 108' 20" 108' 108 SURFACE 5448' 13-3/8" 5543' 2364 INTERMEDIATE 1047T 9-5/8" 10572' 3510 A-SAND SLOTTED LINER 5369' 5-1/2" 15751' 3415 L1 B-SAND SLOTTED LINER 5888' S-1/2" 15675' 3275 L2 D-SAND SLOTTED LINER 6179' 4-1 /2" 15661' 3208 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): A: 10570-15685' Slotted; L1:9845-15631' Slotted; L2: 9580-15517' Slotted A: 341(1-3415'; L1:341 2-3416'; L2: 3361-3416' 4-1/2" L-80 9347' Packers and SSSV Type: Packers and SSSV MD (ft) no packer SSSV= NIP SSSV= 506' 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 14. Estimated Date for 15. Well Status after proposed work: 01 /10/06 Commencing Operations:. 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: Robert D. Christensen Printed Name Robert D. ristense Title: Production Engineering Technician Signature , j~ Phone 659-7535 Date ~~ ~ ~ Commission Use Only l N if i h i i Sundry Number: ~ oo~ Conditions of approva : ot y Commiss on so t at a representat ve may w tness Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ ~ Location Clearance ^ Other: S ~F~...~A~ ~ loos Subsequent F e r ('~L..` APPROVED BY n6 CO I I N Approved b HE COMMISSION Date: " ~ (/ t/7 7 Form 10-403 ReDf~ed 07/20. ~ ~ ~ ! Submit in Duplicate 1E-117 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Multi-Lateral Water Injection service in West Sak Well 1 E-117, L1, L2. This well was placed on production service on November 4, 2005. This multi-lateral wellbore will provide pressure support for the West Sak A, B, & D sands. The D sand lateral injection tubing/casing annulus is isolated via a Baker Payzone External Casing Packer" located @ 9456' and / 3352' tvd. The B sand lateral injection tubing/casing annulus is isolated via a lower ZXP 9-5/8" x 4-1/2" Liner Top Packer w/HRD located @ 9648' and / 3392' tvd. The A sand injection tubing/casing annulus is isolated via lower ZXP 9-5/8" x 4- 1/2" Liner Top Packer w/HRD located @ 10382' and / 3486' tvd. A MITIA was performed prior to placing the well on production service on 10/28/05; MITIA to 3000 psi for 30 minutes, Passed The following is a summary of the proposed plan: 1) Replace 1" x 3/16" GLV w/1" DV. 1) Close sliding sleeve with coil tubing unit and perform MITIA prior to injection. 2) Place well on Injection service. - 3) Performed State witnessed MITIA shortly after injection is initiated and submit test results to the AOGCC. FW: Plans for IE-117 • Subject: FW: Plansfor 1E-117 From:~NSK Problem We] l Supv <n1617 a conocophillips.com> p1 ~ ~ - Date: l-ri, 1(~ I~cc 2005 U8:5S:19 -0900 'Co: toils nr~underru`.admin.state.akus, "Spei~celev. Neil" ~~AeiI.K.S;~ct~cele~~u!conocohhillips.eot~~~- C'C: NSK Problem ~~'ell Supe ~~-nl(il~'~~rconocophillips.com-° Neil and Tom: After reviewing the approved 10-403 (#305-323} to produce 1 E-117, and from the note received from Tom Maunder about approval to extend the production period, the plan forward wifl be the fallowing: 1. Produce the well until January 15, 2006; 2. Reconfigure the well for injection and perform and MIT; 3. Submit a 10-403 to covert the permit to injection service; 4. Place well on injection; 5. Notify AOGCC Inspector for witnessing the initial MIT. Tom: It appears I owe you a 10-404 and production report, I will get thattn the mail. If you find I have missed anything please let me know. Thanks) Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, December 15, 2005 4:31 PM To: Spenceley, Neil Cc: NSK West Sak Prod Engr; NSK Prod Engr Tech; Dethlefs, Jerry C; Paul, Jerome Subject: Re: Plans for 1E-117 Neil, et al, Extending the production period is not a problem. I need to check the paperwork, but prior to returning the well to injection, sundry requests should be filed requesting that change. Jerry is familiar with that process. Call or message with any questions. Tom Maunder, PE AOGCC Spenceley, Neil wrote, On 12/15/2005 3:59 PM: Tom, As we discussed we would like to continue producing the well to enable us to properly diagnose a potential production problem. To accomplish this I request to extend the pre-production period until January 15th, 2006. Please call me if you have any questions or concerns. Thanks. Neil Spenceley, P. Eng Drillsite Petroleum Engineer ConocoPhillips Alaska -Greater Kuparuk Area 1 of 2 1/3/2006 12:48 PM • ~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Co. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1~~~"~ 1E-117 L1, ~~_~~.1 November 18, 2005 AK-MW-3775114 1 LDWG formatted Disc with verification listing. A PI# : 50-029-23251-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETLJIZNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Signed: • ~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Co. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs November 18, 2005 ~~~a~ 1E-117 L1 PB1, ~O~~~A~-MW-3775114 1 LDWG formatted Disc with verification listing. API#: 50-029-23251-71 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETL1ItNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~~ ~ ~~ Signed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~i~v WELL COMPLETION OR RECOMPLETION REPO~~E?N~Conmissio~ 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned Suspended ^ WAG ^ 20AAC 25.105 20AAC 25.110 ~ GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other_XXX Pre-Produced Injector 1b. Well Class: Development ^ Exploratory ^ Service ~ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: October 16, 2005 12. Permit to Drill Number: 205-027 ! 305-281 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded:~~~ j 3i ~~.ry~" ~yaz21"2005 y ~f i6~,~_ 13. API Number: 50-029-23251-60 4a. Location of Well (Governmental Section): Surface: 11' FSL, 228' FEL, Sec. 16, T11N, R10E, UM 7. Date TD Reached: July 21, 2005 ~ 14. Well Name and Number: 1E-117L1 At Top Productive Horizon: 2432' FSL, 1709' FWL, Sec. 27, T11 N, R10E, UM 8. KB Elevation (ft): 28' RKB / 95' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 1740' FSL, 1769' FWL, Sec. 34, T11 N, R10E, UM 9. Plug Back Depth (MD + TVD): 15667' MD / 3275' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 550301 ' y- 5959601 Zone- 4 10. Total Depth (MD + TVD): 15667' MD / 3275' TVD "" 16. Property Designation: ADL 25660 TPI: x- 552309 y- 5951476 Zone- 4 Total Depth: x- 552421 - 5945505 f Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 470 18. Directional Survey: Yes ^~ No 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 2052' MD 21. Logs Run: .~+ ~~~~, ~ ~~ ~~ ~'7r~G~ ~ , a.3Y~a~ '~T-~ GR/Res, CCL ~ ~ ~ ~/° • ~6 : ~ ~ 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE C G O AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE EMENTIN REC RD PULLED 20" x 34" 62.5# H-40 Surf. 108' Surf. 108' 42" 390 sx AS I 13-3/8" 68# L-80 Surf. 5544' Surf. 2364' 16" 1047 sx AS Lite, 280 sx DeepCrete 9-5/8" 40# L-80 Surf. 10572' Surf. 3510' 12.25" 299 bbls LiteCrete 5.5" 15.5# L-80 9787 15675' 3407 3275' 8.5" slotted liner 23. Perforations 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 tbg run in main wellbore 1 E-117 only slotted liner from 9845' - 15631' MD 3406'-3275' TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNTANDKIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production November 4, 2005 Method of Operation (Flowing, gas lift, etc.) Pre-Produced Injector -shares rate with 1 E-117 and 1 E-117L2 Date of Test 11/6/2005 Hours Tested 5 hours Production for Test Period --> OIL-BBL 335 GAS-MCF 163 WATER-BBL 27 CHOKE SIZE 60% GAS-OIL RATIO 531 Flow Tubing press. 411 psi Casing Pressure 1376 Calculated 24-Hour Rate -> OIL-BBL 1565 GAS-MCF 783 WATER-BBL 134 OIL GRAVITY -API (corn) not available 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". ~~ ~av ~ ~ Zoos NONE ~...r'~'_L><' t',~ t f _... __ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ~~ zs. zs. GEOLOGIC 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-117L1 Top West Sak B 9690' 3398' Base West Sak B 15667 3275' N/A 1 E-117L1 P61 TD 11853' 3345' 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: Steve Mukavitz @ 263-4021 Printed N Ra d Thomas Title: Greater Kuoaruk Area Drilfino Team Leader Signature Phone ~,s'-6~ j ~~ Date t ~~f `r (~~ 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 • ConocoPhiliips Alaska Page 1 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Spud Date: 6/20/2005 Event Name: ROT -DRILLING Start: 6/20/2005 End: 8/13/2005 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Cod Phase Description of Operations e 6/20/2005 01:30 - 03:00 1.50 MOVE DMOB MOVE Disconnected service loops between rig complex's, blow down lines and prep rig for move 03:00 - 04:00 1.00 MOVE MOVE MOVE Moved rig complex's and staged on pad 04:00 - 06:00 2.00 MOVE MOVE MOVE Moved sub base from 1 E-105 and spotted over well 06:00 - 10:00 4.00 MOVE RURD MOVE Spotted in rig complex's and rigged up, connected service loops and bermed around rig, completed rig acceptance check list and ACCEPTED RIG at 10:00 Hrs 6/20/2005 10:00 - 12:00 2.00 WELCT NUND RIGUP NU 21 1/4" 2M diverter and 16" line, loaded pipe shed with 5" DP and took on water in the mud pits 12:00 - 15:15 3.25 DRILL OTHR RIGUP Fin loading pipe shed with 5" DP and HWDP and strapped same, began mixing spud mud, rig went on highline at 13:00 hrs 15:15 - 20:00 4.75 DRILL PULD RIGUP PU and stood back 150 jts (50 stds) of 5" DP 20:00 - 21:15 1.25 DRILL PULD RIGUP PU and stood back 29 jts 5" HWDP and jars (10 stds) 21:15 - 21:45 0.50 WELCT BOPE RIGUP Function tested diverter, knife valve and accumulator, good test. Note: John Crisp with AOGCC waived witnessing of test, initial pressure 2900 psi, after closing 1800 psi. 200 psi buildup req 45 seconds, full charge 3 min 24 seconds, nitrogen bottles (5) avg 2275 psi. 21:45 - 22:30 0.75 DRILL PULD RIGUP PU and stood back 1 std of 8" NM Flex dc's 22:30 - 23:00 0.50 DRILL PULD SURFAC PU and MU 16" bit #1 on 8" motor with 1.83 deg bend RIH to 32' 23:00 - 23:30 0.50 DRILL OTHR SURFAC Flooded conductor with water and checked lines for leaks, pressure tested mudline to 3,500 psi 23:30 - 00:00 0.50 DRILL TRIP SURFAC Washed down from 32' and tagged cement inside conductor at 107' and ~ ~ cleaned out to 108', washed down at 30 rpm's, 450 gpm, 325 psi, rot wt 46K, up wt 40K, do wt 44K 6/21/2005 00:00 - 01:15 1.25 DRILL DRLG SURFAC Drilled 16" hole from 108' to 180' MD/ 180' TVD (72') ART 1.1 hrs, 5-7K wob, 30 rpm's, 448 gpm, 8.8 ppg mw, on btm pressure 450 psi, rot wt 40K, up wt 40K, do wt 40K. 01:15 - 01:30 0.25 DRILL TRIP SURFAC POOH f/ 108' to 32'. 01:30 - 03:00 1.50 DRILL OTHR SURFAC MU BHA. Plug in and upload Sperry Sun MWD. 03:00 - 03:45 0.75 DRILL OTHR SURFAC MU Float sub, UBHO, orient MWD and motor. RIH w. 1 stand NM flex collars to 162'. 03:45 - 04:15 0.50 DRILL SFTY SURFAC PJSM. RU Sperry Sun Gyro unit. 04:15 - 04:45 0.50 DRILL SURV SURFAC Run Gyro @ 162'. 04:45 - 06:00 1.25 DRILL DRLG SURFAC Drilled 16" hole from 180' to 256' MD/ 256' TVD (76') ART .93 hrs, 10-12K wob, 30-40 rpm's, 440 gpm, 8.9 ppg mw, on btm pressure 1150 psi, rot wt 55K, up wt 55K, do wt 56K. 06:00 - 06:30 0.50 DRILL SURV SURFAC Run Gyro @ 262'. 06:30 - 08:15 1.75 DRILL DRLG SURFAC Drilled 16" hole from 256' to 347' MD/ 347' TVD (91') ART .42 hrs, AST 1.22 hrs, 10-12K wob, 60 rpm's, 500 gpm, 8.9 ppg mw, on btm pressure 1325 psi, rot wt 59K, up wt 57K, do wt 59K. 08:15 - 08:30 0.25 DRILL SURV SURFAC Run Gyro @ 347'. 08:30 - 09:45 1.25 DRILL DRLG SURFAC Drilled 16" hole from 347' to 439' MD/ 439' TVD (92') ART .23 hrs, AST 1.08 hrs, 10-15K wob, 60 rpm's, 500 gpm, 8.9 ppg mw, on btm pressure 1400 psi, rot wt 63K, up wt 60K, do wt 63K. 09:45 - 10:00 0.25 DRILL SURV SURFAC Run Gyro @ 439' 10:00 - 11:15 1.25 DRILL DRLG SURFAC Drilled 16" hole from 439' to 530' MD/ 529' ND (92') ART .23 hrs, AST .73 hrs, 10-15K wob, 60 rpm's, 500 gpm, 8.9 ppg mw, on btm pressure 1400 psi, rot wt 63K, up wt 60K, do wt 63K. 11:15 - 11:30 0.25 DRILL SURV SURFAC Run Gyro @ 530'. 11:30 - 12:00 . 0.50 DRILL DRLG SURFAC Drilled 16" hole from 530' to 560' MD/ 559' TVD (30') AST .43 hrs, 15K wob, 60 rpm's, 500 gpm, 8.9 ppg mw, on btm pressure 1425 psi, rot wt 67K, up wt 66K, do wt 67K. 12:00 - 12:30 0.50 DRILL DRLG SURFAC ~ Drilled 16" hole from 560' to 621' MD/ 619' TVD (61') ART .15 hrs, AST Printed: 10/28/2005 10:29:27 AM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 1 E-117 1E-117 ROT -DRILLING Date From - To Hours Code Code Phase 6/21/2005 ~ 12:00 - 12:30 ~ 0.50 ~ DRILL DRLG ~ SURFAC 12:30 - 12:45 0.25 DRILL SURV SURFAC 12:45 - 00:00 11.25 DRILL DRLG SURFAC 6/22/2005 100:00 - 07:30 07:30 - 10:30 7.50 DRILL ~ DRLG I SURFAC 3.001 DRILL I REAM I SURFAC 10:30 - 12:00 1.50 DRILL TRIP SURFAC 12:00 - 12:30 0.50 DRILL OTHR SURFAC 12:30 - 13:00 0.50 DRILL TRIP SURFAC 13:00 - 13:30 0.50 DRILL TRIP SURFAC 13:30 - 14:00 0.50 DRILL REAM SURFAC 14:00 - 00:00 I 10.00 I DRILL I DRLG I SURFAC 6/23/2005 100:00 - 12:00 I 12.00 I DRILL I DRLG I SURFAC 12:00 - 13:00 13:00 - 20:15 20:15 - 20:30 20:30 - 00:00 6/24/2005 100:00 - 04:15 1.001 DRILL I OTHR I SURFAC 7.25 I DRILL i DRLG I SURFAC 0.251 DRILL I OTHR !SURFAC 3.501 DRILL I DRLG (SURFAC 4.25 i DRILL I DRLG I SURFAC Page 2 of 33 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations .30 hrs, 15K wob, 60 rpm's, 500 gpm, 8.9 ppg mw, on bttm pressure 1425 psi, rot wt 67K, up wt 66K, do wt 67K. Run Gyro @ 621'. Drilled 16" hole from 621' to 1453' MD! 1311' TVD (832') ART 1.44 hrs, AST 7.74 hrs, 15-30K wob, 60 rpm's, 508 gpm, 8.9-9.3 ppg mw, on btm pressure 1525-1825 psi, off bttm press 1400-1550 psi, on bttm torque 3-6k, off bttm torque 2-3k, rot wt 70-90K, up wt 69-92K, do wt 67-87K. Drilled 16" hole from 1453' to 1956' MD7 1528' ND (503') ART .65 hrs, AST 5.51 hrs, 30-33K wob, 60 rpm's, 508 gpm, 9.2-9.6 ppg mw, on btm pressure 1700-1825 psi, off bttm press 1550-1600 psi, on bttm torque 5k, off bttm torque 4k, rot wt 87-81 K, up wt 92K, do wt 82-73K. Backream out of hole f/ 1956' to 901' w/ 700-800 gpm, 2700 psi, 80 rpm. No problems. POOH f/ 901' to surface on elevators. No problems. Change bend on motor f/ 1.83 deg to 1.5 deg., remove UBHO sub. Trip in hole w/ BHA, HWDP and jars to 1082'. Continue trip in hole w/ 5" dp f/ 1082' to 1915'. Precautionary wash and ream f/ 1915' to 1956' w/ 80 rpm, 697 gpm, 3700 psi (plugged nozzle), torque 7k. Drilled 16" hole from 1956' to 2800' MD/ 1716' TVD (844') ART 2.24 hrs, AST 3.38 hrs, 10-30K wob, 80 rpm's, 508- 698 gpm, 9.6 ppg mw, on btm pressure 2250-3000 psi, off bttm press 1575-2750 psi, on bttm torque 7-10k, off bttm torque 6k, rot wt 82-75K, up wt 88-90K, do wt 75-64K. Drilled 16" hole from 2800 to 3865' MD/ 1953' TVD (1065') ART 4.10 hrs, AST 3.36 hrs, 10-30K wob, 90-100 rpm's, 554-800 gpm, 9.6 ppg mw, on btm pressure 2050-3700 psi, off bttm press 1850-3700 psi, on bttm torque 7-10k, off bttm torque 7-8k, rot wt 75-78K, up wt 87-100K, do wt 60-65K. Avg BG gas 35 units. Max gas 70 units while drilling @ 3675' Note: While drilling @ 3680'-3772' MD/ 1919'-1937' TVD, oil shows started appearing @ shakers. This would have been f/ approx 3605'-3630' MD/ 1904'-1910' TVD. CBU to clean hole. Lots of cuttings. Screen one shaker w 50's, other two have 140's. Drilled 16" hole from 3865 to 4439' MD/ 2090' TVD (574') ART 2.15 hrs, AST 2.0 hrs, 15-25K wob, 100 rpm's, 664-800 gpm, 9.6 ppg mw, on btm pressure 3100-3700 psi, off bttm press 2950-3700 psi, on bttm torque 10-12k, off bttm torque 7-11 k, rot wt 78-84K, up wt 100-120K, do wt 65-57K. Avg BG gas 50 units. Max gas 151 units while drilling @ 4290'. Change one shaker w 38's, other two have 50's. Lost 80 bbls fluid in 20 min to rockwasher prior to change. Drilled 16" hole from 4439' to 4658' MD/ 2133' TVD (219') ART 1.3 hrs, AST .44 hrs, 20-25K wob, 100 rpm's, 664-800 gpm, 9.6 ppg mw, on btm pressure 3100-3700 psi, off bttm press 2950-3600 psi, on bttm torque 11-12k, off bttm torque 10-11 k, rot wt 82K, up wt 122K, do wt 54-52K. Avg BG gas 60 units. Max gas 108 units while drilling @ 4540'. Note: Shaker screens @ midnight :one set of 84's, one set of 50's, one set of 110/110/84. Drilled 16" hole from 4658' to 4886' MD/ 2198' TVD (228') ART 1.83 hrs, AST 1.18 hrs, 0-25K wob, 100 rpm's, 700-800 gpm, 9.6 ppg mw, Printed: 10/28/2005 10:29:27 AM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 1 E-117 1 E-117 ROT -DRILLING Date From - To 'Hours Code Code Phase 6/24/2005 ~ 00:00 - 04:15 ~ 4.25 ~ DRILL ~ DRLG ~ SURFAC 04:15 - 06:15 I 2.00 I DRILL I REAM I SURFAC 06:15 - 06:45 0.50 DRILL TRIP SURFAC 06:45 - 12:00 5.25 DRILL DRLG SURFAC 12:00 - 16:45 I 4.751 DRILL I DRLG I SURFAC 16:45 - 00:00 I 7.25 I DRILL I REAM I SURFAC 6/25/2005 100:00 - 04:00 I 4.001 DRILL I REAM I SURFAC 04:00 - 04:30 0.50 DRILL TRIP SURFAC 04:30 - 05:00 0.50 DRILL TRIP SURFAC 05:00 - 06:00 1.00 DRILL OTHR SURFAC 06:00 - 06:45 0.75 DRILL OTHR SURFAC 06:45 - 07:00 0.25 DRILL OTHR SURFAC 07:00 - 07:15 0.25 DRILL TRIP SURFAC 07:15 - 07:45 0.50 RIGMNT RSRV SURFAC 07:45 - 08:15 0.50 RIGMNT RGRP SURFAC 08:15 - 10:45 2.50 DRILL TRIP SURFAC 10:45 - 12:00 I 1.25 I DRILL I REAM I SURFAC 12:00 - 14:00 2.00 DRILL DRLG SURFAC 14:00 - 15:45 1.75 DRILL REAM SURFAC 15:45 - 16:15 0.50 DRILL ~ CIRC ~ SURFAC 16:15 - 19:30 3.25 DRILL TRIP SURFAC 19:30 - 20:00 0.50 DRILL PULD SURFAC 20:00 - 20:45 0.75 DRILL OTHR SURFAC 20:45 - 21:45 1.00 DRILL PULD SURFAC 21:45 - 22:15 0.50 DRILL OTHR SURFAC 22:15 - 22:45 0.5b CASE OTHR SURFAC 22:45 - 00:00 I 1.25 I CASE {KURD I SURFAC Page 3 of 33 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations on btm pressure 2950-3700 psi, off bttm press 2750-3500 psi, on bttm torque 12k, off bttm torque 10-11 k, rot wt 82K, up wt 122-145K, do wt 52-44K. Avg BG gas 50 units. Max gas 68 units while drilling @ 4820'. Backream out of hole. Pull slow (2-10'/hr), pumping 800 gpm, rotate 100 rpm. Ream f/ 4886' to 4327', torque 12-14k. RIH on elevators f/ 4327' to 4793', orient to high side and RIH to 4886'. Drilled 16" hole from 4886' to 5164' MD! 2273' TVD (278') ART 1.15 hrs, AST 1.8 hrs, 0-25K wob, 100 rpm's, 700-800 gpm, 9.6 ppg mw, on btm pressure 2950-3700 psi, off bttm press 2750-3500 psi, on bttm torque 12k, off bttm torque 10-11 k, rot wt 82K, up wt 122-145K, do wt 52-44K. Avg BG gas 50 units. Max gas 68 units while drilling @ 4820'. Backream @7' per min. Drilled 16" hole from 5164' to 5361' MD/ 2329.61' TVD (197') ART .4 hrs, AST 1.78 hrs, 15-20K wob, 100 rpm's, 710-800 gpm, 9.6 ppg mw, on btm pressure 3650-3750 psi, off bttm press 3550-3675 psi, on bttm torque 12-15k, off bttm torque 13-16k, rot wt 85K, up wt 155-175K, do wt 35K. Avg BG gas 160 units. Max gas 475 units while drilling @ 5260'. Backream @ 8' per min. Monitor well. Backream out of hole f/ 5361' to 2200' @ 700 to 800 gpm, 3100-3650 psi, 100 rpm. Pulling slow, 10'/min. Lots of sand returns. Backream out of hole f/ 5361' to 2200' @ 800-550 gpm, 3100-2300 psi, 100 rpm. Pulling slow, 10'/min.Torque 5-9k. Sand and clay and gravel in returns. Pull and stand back stand NM flex drill collar. Pull bit out of hole, clean a little, and grade bit. UD MWD. PU MWD. Remove restrictor to allow more flow w/ less pressure. Upload MWD. Orient MWD and motor. MU stand flex NMDC. Service top drive. Repair hydraulic fitting on top drive. RIH f/ 162' to 5109' with no problems, fill pipe @ HWDP and every 25 stands. Wash thru 5109' w/ no problems. Precautionary ream f/ 5258'- 5350', orient high side, wash f/ 5350' to 5361' Drilled 16" hole from 5361' to 5560' MD/ 2367' TVD (199') ART .51 hrs, AST .48 hrs, 10-20K wob, 100 rpm's, 795 gpm, 9.6-9.7 ppg mw, on btm pressure 3000 psi, off bttm press 2950 psi, on bttm torque 11-12k, off bttm torque 13k, rot wt 90-K, up wt 160-150K, do wt 60-63K. Avg BG gas 30units. Max gas 40 units while drilling. BU gas max 290 units Backream @ 8' per min. Monitor well. Backream out of hole f! 5560' to 5074'. 100 rpm's, 867 gpm, 3300 psi, Pump dry job, blow down top drive. POOH on elevators. UD BHA. Download MWD UD MWD, bit and mtr. Calc displ 54.1 bbl, actual 56 bbls. Clean rig floor. Dummy run Vetco/Gray 13 3/8" landing joint and hanger. Load shoulder to rig floor 29.89'. Rig up to run 13 3!8", 68 ppf, L-80 BTC casing. Printed: 10/28/2005 10:29:27 AM C. ConocoPhillips Alaska Page 4 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase 6/26/2005 00:00 - 00:30 0.50 CASE SFTY SURFAC 00:30 - 04:15 3.75 CASE RUNC SURFAC 04:15 - 05:00 I 0.75 I CASE I CIRC I SURFAC 05:00 - 07:00 I 2.00 I CASE I RUNC I SURFAC 07:00 - 07:30 I 0.501 CASE I OTHR I SURFAC 07:30 - 07:45 0.25 CASE RUNC SURFAC 07:45 - 08:15 0.50 CASE CIRC SURFAC 08:15 - 09:15 1.00 CASE RUNC SURFAC 09:15 - 10:15 1.00 CASE RUNC SURFAC 10:15 - 10:45 0.50 CASE RUNC SURFAC 10:45 - 11:15 0.50 CASE RUNC SURFAC 11:15 - 11:30 0.25 CASE RUNC SURFAC 11:30 - 12:00 0.50 CASE RUNC SURFAC 12:00 - 16:15 4.25 CEMEN CIRC SURFAC 16:15 - 16:45 0.50' CEMEN SFTY SURFAC 16:45 - 19:45 3.00 CEMEN PUMP SURFAC 19:45 - 21:45 2.00 ; CEMENl~ DISP SURFAC Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations PJSM on running 13 3/8", 68 ppf, L-80, BTC. Run 13 3/8": MU Weatherford model 303 Float Shoe, w/ stop ring 10' above and Weatherford bow centralizer over stop, also on box, MU jt # 2 with stop 10' below box and bow centralizer over stop, Weatherford model 402 Float collar on bottom of jt # 3 (all below joints baker locked to bottom of collar of jt #3. Jts # 3-15 have centralizers on box. Total of 16 centralizers. All casing 13 3/8", 68 ppf, L-80, BTC casing. Torque to 10,000 ft/Ib. Run to jt # 56 (2187') Record PU & SO wt's every 10 jts. Break circ slow @ 2187', then bring up to 6 bpm w/ 325 psi, work jt 56 down slow, then the same with joint 57 to depth of 2265'. Circ total of 160 bbls. MW out 10 ppg, mw in 9.7 ppg. Final pressure 300 psi @ 6 bpm. PU wt 160k, SO wt 98K Continue running casing f/ jt #58 to jt #88. (2265' to 3525'). Record PU & SO wt's every 10 jts. UD jt # 89(43.56'). Pin end bad. Replace jt. with spare joint # 141(37.54'). Continue running casing to jt # 89 in hole (3525'-3574'). Break circ @ 4 bpm w/ 290 psi while running jt # 90 and #91( 3574'-3661'). Circ total of 100 bbls. PU wt 245k, SO wt 85k. Continue running casing to jt # jt 114 (3661' - 4600'). PU 295, SO wt 70k Break circ @ 4 bpm w/ 300 psi while running jt # 115, then 5 bpm 350 psi w/ running jt # 116 (4601'- 4684'). Circ total of 120 bbls. Continue running casing f/ 4684' to 5283' (jt #116-# 131). PU wt 350k, SO wt 70k Tagged up @ 5283' Qt # 131) in hole, work pipe and circ w! Frank's fillup tool. PU wt 350, SO wt 70k. Pulled to 480k to free up, went down w/ 70-80k. Ran jt # 132 f/ 5283' to 5320'. Continue running casing f/ jt # 131 to jt # 137 (5320- 5510') MU Vetco/Gray hanger and landing jt. Remove casing slips, RIH f/ 5510' to 5543.56' landed. PU wt 350k, So wt 75k, blocks 35k of this wt. Circ and condition mud prior to cement. Reciprocated 9 times w/ only 4' of pipe movement @ surface then hanging up on base of conductor Note; Had no pipe movment and worked pipe to btm after working pipe 9 times- Set pipe on hanger. Circ @ 7bpm w/ 475 psi. Circ total of 1785 bbls. Mud properties before: wt 9.7 ppg, vis 232, PV 43, YP 73. Mud properties after: wt 9.5 ppg, vis 49, PV 19, YP 14. PJSM prior to cement job. Dowell pump 10 bbls CW 100 (8.3 ppg) @ 4 bpm, test lines to 3500 psi, pump 40 more bbls CW100 (8.3 ppg) @ 4 bpm w/ 75 psi, pump 50 bbls mudpush w/ Red Dye (10.5 ppg) @ 5.8 bpm ,drop bottom plug, pump 792 bbls (990sx) lead Arctic set lite (10.7 ppg) (yield 4.49 cu ft/sx) @ 7 bpm w/ 73-121 psi, 124 bbls (280sx) tail DeepCrete (12.0 ppg) (yield 2.48 cu ft/sx) @ 7bpm w/ 128-87 psi, drop top plug, pump 20 bbls water through tub. Rig displace cement w/ 9.5-9.6 ppg mud. Pump @ 7.5 bpm until last 82 bbls pumped pressure increasing f/ 400 psi to 820 psi. Lost returns @ 86 bbls left to bump, slowed to 5 bpm 650 psi, until last 10 bbls, then to 3 bpm @ 600 psi. Bump plug @ 7956 strokes (801 bbl) with 1100 psi. Note: Saw mud push @ 4300 strokes into displacement (433 bbls). Mud returns were 10.2+ ppg until losing returns @ 7100 strokes (715 bbls), Did not have any true signs of cement to surface. Unable to precirocate casing due to no movement. Printed: 10/28/2005 10:29:27 AM ConocoPhillips Alaska Page 5 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Spud Date: 6/20/2005 Event Name: ROT -DRILLING Start: 6/20/2005 End: 8/13/2005 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Code Phase '" Description of Operations 6/26/2005 121:45 - 00:00 I 2.251 CEMENTOTHR I SURFAC 6/27/2005 100:00 - 02:00 I 2.001 CEMENTOTHR I SURFAC 05:00 - 06:00 1. 0 CEMENl~TR PD SURFAC 06:00 - 06:30 0.50 CEMEN OTHR SURFAC 06:30 - 11:30 5.00 CEMEN OTHR SURFAC 11:30 - 12:00 0.50 CEMEN OTHR SURFAC 12:00 - 12:45 0.75 CASE RURD SURFAC 12:45 - 14:15 1.50 WELCT OTHR ~ SURFAC 14:15 - 15:00 0.75 WELCT NUND ~ SURFAC 15:00 - 20:45 5.75 WELCT OTHR ~ SURFAC 210:00 - 22:45 10.75 WELCT NUND SURFAC 22:45 - 23:00 0.25 WELCT OTHR SURFAC 23:00 - 00:00 1.00 WELCT NUND SURFAC 6/28!2005 00:00 - 00:15 0.25 WELCT NUND SURFAC 00:15 - 02:00 1.75 WELCT NUND SURFAC 02:00 - 07:00 5.00 WELCT BOPE SURFAC 07:00 - 07:15 0.25 WELCT ROPE SURFAC 07:15 - 09:00 1.75 DRILL PULD SURFAC 09:00 - 10:00 1.00 DRILL PULD SURFAC 10:00 - 12:00 2.00 DRILL PULD SURFAC 12:00 - 15:00 3.00 DRILL PULD SURFAC 15:00 - 18:00 3.00 DRILL TRIP SURFAC 18:00 - 18:15 ' 0.25 DRILL DEOT SURFAC 18:15 - 19:45 1.50 DRILL TRIP SURFAC 19:45 - 20:00 0.25 DRILL TRIP SURFAC Cleaning out diverter stack, trying to catch sample @ Vetco Gray quick connect, thick fluid would not come out 2" valve. UD Dowell cement head. Prepare to UD landing joint. R/D casing equipment, UD landing joint, Flush thick mud f/ stack w/ water usnig 5" dp and rig pumps. N/D diverter line and diverter stack. RIH w/ 1.315" Hydril CS tubing (OD of connection 1.61 "), 2.25 ppf. Run between Outs in hanger and landing ring (1.625" clearance). RIH to 53' RKB. Circ w/ rig water press (70 psi). Returns 10.2+ ppg. RIH 2 more joints to 112' RKB. Circ w/ Rig water pressure thick stuff 10.2+ ppg. POOH w/ 1.315" Hydril CS tubing. Welder cut 4" wide x 4" hole in conductor to take returns to cellar. Rig & run 8 jts 1-1/4" Hydril tubing to 264' RKB, 80' below ground level in 13-3/8" x 20" annulus (Volume 14.6 bbls) & 156' in 13-3/8" x 16" (11.6 bbls), washing each joint down with fresh water and was unable to make any further progress. Flushed well with 58 bbls fresh water using Dowell. Mixed & pumped a total of 46.0 bbls (57 sacks) Lead cmt mixed @ 10.7 ppg. Had good 10.7 ppg cement returns to surtace after pumping 26.1 bbls cement, C.I.P. @ 10:50 hrs 6/27/05. Pulled out of the hole w/ tubing and the fluid level dropped 4". Cleanup cellar box prep f/ welder. R/D casing equipment f/ rig floor. Crane removed diverter pieces and set in Vetco/Gray wellhead equip in the cellar area. NU Vetco gray multibowl wellhead. Test seal on graylock. Failed 4 different times. Test failed @ pressures of 4500 psi, 4800 psi, 5000 psi and again 5000 psi. Remove Vetco gray multibowl. Will install bowl assigned to 1J-154. NU Vetco/Gray multibowl (used the one assigned to 1J-154, set up as a producer). Test seal sub to 5000 psi f/ 15 min. OK. Change orientation of valves on Vetco/Gray multibowl. Change orientation of valves on Vetco/Gray multibowl f/ injector well. NU 13 5/8" BOPE. RU and test 13 5/8" BOPE. Witness of test waived by AOGCC inspector Chuck Scheve. Test using lower test plug. One test made @ 5000 psi high and 250 psi low to test all valves which were changed around. Only lower annulus valve of multibowl was NOT TESTED. This valve will be tested to 3000 psi when testing casing. Other tests were to 3000 psi. high and 250 psi low. Instal! wear bushing - RILDS P/U and single in hole 51 jts 5" DP from pipe shed Stand back these 17 stds in derrick -Clean rig floor M/U BHA #4 -w/ bit & 9.625 Geo -Pilot ** Note** Had to have Bit rep come over because the bit breaker would not fit the bit. He had the welder do a small modification to where it would fit after he confered with his engineers. Con't PU BHA #4 - Up Load MWD TIH picking up singles from pipe shed. Install ghost reamers @ 824' and 1666' behind bit. Break in Geo Pilot Bearing Con't TIH PU singles from pipe shed TIH w/ DP from derrick - Dn wt 35K -Will need to circu and wash to FC Printed: 10!28/2005 10:29:27 AM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 1 E-117 1 E-117 ROT -DRILLING Date From.- To Hours Code Code Phase 6/28/2005 20:00 - 22:15 ~ 2.25 ~ DRILL ~ REAM ~ SURFAC 22:15 - 23:45 1.50 DRILL DEQT SURFAC 23:45 - 00:00 0.25 RIGMNT RSRV SURFAC 6/29/2005 00:00 - 01:30 1.50 RIGMNT RSRV SURFAC 01:30 - 02:30 1.00 RIGMNT RGRP SURFAC 02:30 - 05:00 2.50 CEMEN DSHO .SURFAC 05:00 - 06:15 I 1.25 !DRILL I CIRC I SURFAC 06:15 - 07:00 0.75 DRILL LOT SURFAC 07:00 - 12:00 5.00 DRILL DRLG INTRM1 12:00 - 00:00 12.00 ~ DRILL DRLG INTRMI 6/30/2005 100:00 - 11:00 I 11.001 DRILL I DRLG I INTRM1 11:00 - 12:00 1.00 DRILL CIRC INTRM1 12:00 - 17:15 5.251 DRILL ~ DRLG INTRM1 17:15 - 18:30 I 1.251 DRILL I DRLG I INTRM1 18:30 - 00:00 I 5.501 DRILL I DRLG I INTRM1 Page 6 of 33 Spud Date: 6/20/2005 Start: 6!20/2005 End: 8/13!2005 Rig Release: Group: Rig Number: Description of Operations Wash and Ream 4670' to 5450' MD - 500 gpm, PP 1100 psi, RPMs 50, Troq 13-15k -(Surface Float Collar @ 5461' MD) Circu 10 min - RU & Test Csg to 3000 psi on chart for 30 min - No loss Slip & Cut drill line. Con't Slip & Cut drill line (59' cut) -Service Top Drive & Draworks Repair fitting on top drive tube oil pump cooler Drlg shoe track + 20' new hole f/ 5560' to 5580' MD (2371' TVD) PP 2050, PR SPM 188, 735 gpm, WOB 10 -20k, RPMs 90- No problems noted on drill out. PU to shoe -Circu BU -Condition mud until uniform in and out. -Mud weight 9.1 ppg , Vis 60 RU for & Preform LOT - EMW 13.1 ppg Drlg 12.25" hole 5580' to 6117' MD (2467' TVD) ADT 3.6 hrs - PP 2050 psi, PR 188 SPM, 735 gpm, WOB 10-20k, RPMs 124 -Torg off Bttm 12 -18k, on Bttm 12-18k. Mud tubes 2.5% (1 % being CO)? - No problems noted - 9.625" Geo-Pilot appears to be hooking up better than the 8" tools of the past as we started drilling, we will see how it preforms as we drill.- Drilling Engineer (Pat Reilly) is on site to try and increase our daily ROP by changing some drilling parameters, WOB, Pump rate, RPMs ect,ect. to maximize footage drilled per tour. Drlg 12.25" hole 6117' to 7418' MD (2826' TVD) ADT 8.4 hrs- PP 2100 psi, PR 167 SPM, 700 gpm, WOB 10-20k, RPMs 130 -Torg off Bttm 14-18k, on Bttm 13-17k. Up wt 188k, Dn wt 56k, Rot wt 94k - ECD 9.68 Adding tubes to mud to help with torq. We will try to maintain 2.5-3 tubes (Not Including CO) and see if this helps with high Torqs? -High flow rates had to be reduced to about 700+ gpm to get good preformance from the geo-pilot. This 9.625" OD tool appears to work fairly well and stay hooked up. So far it has shown to give good response with 40 to 70% deflection if we do not pump faster than 720-730 gpm. The Sperry DD is keeping th FR and RPMs as HIGH as possible to maximize ROPs while still maintaining clean hole. Drlg 12.25" hole 7418' to 8718' MD (3188' TVD) ADT 8.18 hrs - PP 2300 psi, PR 155 SPM, 650 gpm, WOB 5-35k, RPMs 130 -Torg off Bttm 16 -17k, on Bttm 17-19k. Mud tubes 2.5% No problems noted - 9.625" Geo -Pilot continued to perform well- Observed max gpm's @ 730 before decrease in performance. PU wt = 192K SO wt = 68K ROT WT = 102K Circulate weighted sweep until clean @ 700 GPM's and 2480 PSI RPM's = 130 When sweep at surface, observed 10%- 15% increase in cuttings at shakers. Drlg 12.25" hole 8718' to 9274' MD ADT 7.95 hrs - PP 2100 psi, PR 150 SPM, 635 gpm, WOB 10-35k, RPMs 110 -Torg off Bttm 16 -17k, on Bttm 17-19k. Mud tubes 2.5% (1 % being CO)? - No problems noted - 9.625" Geo- pilot performing well. PU WT + 207K SO WT = 63K ROT WT = Control drill as per Geologist from 9274' - 9367' MD Geologist neede to evaluate correlated depths. Drlg 12.25" hole 9367' to 9758' MD tvd = 3408' ADT 7.95 hrs - PP 2100 psi, PR 150 SPM, 635 gpm, WOB 10-35k, RPMs 110 -Torg off Bttm 16 -17k, on Bttm 17-19k. Mud tubes 3.0% - No problems noted - 9.625" Geo- pilot performing well. PU WT + 207K SO WT = 63K ROT WT = 101 K Printed: 10/28/2005 10:29:27 AM • ConocoPhilfips Alaska Page 7 of 33 Operations Summary. Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase 7/1/2005 00:00 - 03:30 3.50 DRILL DRLG INTRM1 03:30 - 05:00 1.50 DRILL ,CIRC INTRM1 05:00 - 06:45 1.751 DRILL DRLG INTRM1 06:45 - 07:15 I 0.501 DRILL I REAM I INTRM1 07:15 - 07:30 0.25 DRILL DRLG INTRM1 07:30 - 09:00 I 1.501 DRILL I REAM I INTRM1 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations Continue Drilling From 9758'-10388'. TVD =3486' Con't ciru Hi-Visc weighted sweep. 38 BBL, 11.1 PPG @ 750 GPM's , 2800 PSI. BU of sweep showed a moderate increase in cutting. Continue drill from 10388'-10573 TVD = 3510' Obtain slow pump rates and surveys,. Monitor well, static. Back ream out of hole to 10390', at 600 GPM's - 2000 PSI Rotating torque = 14K RIH back to 10573'. Continmue drill from 10573' - 10580' MD TVD = 3511' PU wt = 152K Slack off wt = 75K Rot WT = 103K Torque on bottom = 15K torque off bottom = 13K RPM's = 100 Pumps at 600 GPM's w/ 2000 PSI ART = 3.31 HRS Back ream out of hole to 10384'. Stop and circulate @ 600 spm,2200 psi. Reciprocate drill string. 09:00 - 10:15 1.25 RIGMNT RGRP i INTRM1 10:15 - 12:00 1.75 DRILL REAM INTRM1 12:00 -16:00 I 4.001 DRILL I REAM I INTRM1 16:00 - 16:30 0.501 DRILL CIRC INTRMI 16:30 - 19:00 2.50 DRILL TRIP INTRM1 19:00 - 22:15 3.25 DRILL CIRC INTRM1 22:15 - 00:00 1.751 DRILL (TRIP INTRMI 7/2/2005 100:00 - 04:00 I 4.001 DRILL I TRIP I INTRM1 04:00 - 05:00 I 1.001 DRILL I CIRC I INTRM1 05:00 - 05:15 ~ 0.25 ~ DRILL TRIP ' INTRM1 05:15 - 07:45 2.50 DRILL TRIP INTRMI 07:45 - 08:30 0.75 DRILL PULD INTRM1 08:30 - 09:15 0.75 DRILL PULD INTRM1 Repair Top Drive. Change out SHot Pin Assembly on TD. Continue back ream out of hole, from 10384' - 9725' Pumps @ 600 GPM's 1975 PSI RPM's = 100, with 12-14k torque. Observed clean hole and no overpull issues. Continue back ream out of hole, from 10384' - 9725' Pumps @ 600 GPM's 1975 PSI RPM's = 100. with 12-14k torque. PU wt = 145k SO WT = 70K Continued to see no hole problems, or overpull. Circulate and condition hole and mud while reciprocating drill string, pumping at 600 GPM's 1600 PSI, 100 RPM's and 12K free torque. Had several shows of small batches of cutting to surface. Trip in hole from 7112'-10580', observed clean hole conditions. Change out 2 joints of drill pipe as a resuly of washouts. Circulate and condition. Pump a 30 BBL Hi-Visc weighted sweep @ 700 GPM's and 2675 PSI. 130 RPM's, and 14K free torque. Observe increase in cuttings on shakers when sweep came back, and observe hole cleaned up. Slowly TOH on elevators. Observed clean hole, and no issues until 9495' MD and work through tight spot. This is where we drilled a concretion earlier, and hole cleaned up by pumping 600 GPM's and 100 RPM's for one stand. We went back through tight spot with no pump or rotation and observed clean hole. Continue TOH "slowly" on elevators with no more overpull issues. Displacement was correct and no swabbing occured. Con't TOH on elevators to 9356' - 8720" MD -Tight spot, 40k over pull - M/U top drive and BR tight spot 8750' thru 8628' -Run back thru and wipe until clean - PR 600 gpm, 1500 PSI, 80 RPMs. - Con't TOH 8628' to 5560' MD - Spot tube across casing -Pump 60 bbls tube pill and displace back to 1500' in Ann. 57 bbls mud, 3 sx soda ash and 3 drums EMI 920. PR 600 gpm, PP 1500 psi, 100 RPMs. BDTD - FCW "OK" Con't TOH 5560' to 174' MD UD NM Flex Collars and float sub Down Load MWD Printed: 10/28/2005 10:29:27 AM • ConocoPhillips Alaska Page 8 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1E-117 Spud Date: 6/20/2005 Event Name: ROT -DRILLING Start: 6/20/2005 End: 8/13/2005 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Code Phase 7/2/2005 ~ 09:15 - 10:30 ~ 1.25 ~ DRILL ~ PULD ~ INTRM1 10:30 - 11:00 0.50 CASE OTHR INTRMI 11:00 - 12:00 1.00 CASE RUNC INTRM1 12:00 - 12:45 0.75 CASE RUNC INTRM1 12:45 - 13:30 0.75 CASE SFTY INTRM1 13:30 - 17:30 I 4.001 CASE I RUNC I INTRM1 17:30 - 17:45 I 0.251 CASE I CIRC I INTRM1 17:45 - 20:15 I 2.501 CASE I RUNC I INTRMI 20:15 - 21:00 0.75 CASE CIRC INTRM1 21:00 - 23:30 2.50 CASE RUNC , INTRM1 23:30 - 00:00 I 0.501 CASE I CIRC I INTRM1 7/3/2005 00:00 - 01:00 1.00 CASE CIRC INTRM1 01:00 - 11:30. 10.50 CASE RUNC INTRM1 11:30 - 12:00 0.50 CASE CIRC INTRMI 12:00 - 13:15 1.25 CASE CIRC INTRMI 13:15 - 13:45 0.501 CEMEN RURD INTRM1 13:45 - 17:00 3.25 ~ CEMEN CIRC INTRM1 17:00 - 18:15 I 1.251 CEMENlf PUMP I INTRM1 18:15 - 20:15 I 2.001 CEMENI?DISP I INTRM1 20:15 - 21:15 I 1.001 CEMENl1RURD i INTRM1 Description of Operations BK and UD Bit, Geo Pilot, NM GP Flex, GR, Res, PWD and pulser tools. R/U and pull wear bushing -Clean tools from rig floor R/U to run 9 5/8", L80, BCTM Csg Continue to RU to run 9 5/8 csg. PJSM with crew. Discuss safety issues, running procedures and centralizer placement. Make up Shoe jnt and float collar jnt, continue run 9 5!8 casing installing tandem rise centralizers as per plan Circulate BTMS up @ 1933', at 4 BPM - 250 PSI, 6 BPM - 350 PSI, and 8 BPM - 500 PSI PUwt=106K So wt=70K Continue run 9 5/8 csg form 1933' - 3670', installing tandem rise centralizers as per plan. Circulate BTMS up @ 3670', at 4 BPM - 350 PSI, 6 BPM - 450 PSI, 8 BPM - 600 PSI PU wt = 125 K SO wt = 66 K Continue run 9 5/8 csg form 3670' - 5530'. Shoe depth. Installing tandem rise centralizers as per plan. Circulate and condition mud at the shoe. Pumps at 4 bpm - 400 PSI, 10 BPM - 850 PSI PUwt=155K SO wt=70K Con't to circu and condition @ surface shoe (5530' MD w/ Csg) PR 400 gpm, 95 SPM, PP 850 psi, Up wt 155k, Dn wt 70k. Circu BU f/ 1800' & 3600' to maximize good mud properties of mud in hole while running casing. Con't running csg 5,530' to 10,530 MD -Fill csg as ran. After every 10 to 12 joints were ran we would circu while coming down slowly with 2 to 3 joints. This kept fresh mud in the well bore so we could run pipe without stopping the job in open hole. PR 190 gpm, PP550. We had a good solid run without any problems. Circu & Condition with Franks tool 1 BUs+-Work pump rate up to 8 bpm slowly. @ 4.5 bpm, Continue Circu & Condition with Franks tool -Work pump rate up to 8 bpm slowly. @ 4.5 bpm, 8.0 BPM - 880 psi Reciprocate string from 10560' -10540' PU WT = 225K SO WT = 60K RD Franks Tool. RU Cement head & Lines. Con't to Circulate & Condition Mud for CMt Job. 80 SPM - 800 PSI. PU WT = 215K SO WT = 55K CMT 9 5/8" Csg -Pump 10 bbl CW100, Test lines to 3500 psi, pump remaining 30 bbls CW100, pump 40 bbls 10.5 ppg MudPush, drop bttm plug, pump 299.4 BBLS of DeepCrete 12.5 PPG tail cmt, Drop Top Plug, kick out plug w! 3 BBLS of water. Rig displace cmt with 9.1 PPG OBM @ 8 BPM - 425 PSI, reciprocating pipe in 20' strokes. Up WT = 225K Dn WT = 68K. Allow mud push, and cement to turn corner, resume working string. Parked casing in place @ 6200 STKS( 122 bbls cmt around corner), Bump plug at 7976 STKS @ 20:15 HRS. Pressure = 780 PSI. Bring Press up to 1300 PSI, Hold for 5 min. Bleed Press. Final Up Wt = 240K DN WT = 40K, Check floats, OK RD Cement Head, ND and lift BOP stack. Printed: 10/28/2005 10:29:27 AM ~~ ConocoPhi}}ips Alaska Operati©ns Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase 7/3/2005 121:15 - 23:30 2.251 WELCTL NUND ~ INTRM1 7/4/2005 7/5/2005 23:30 - 00:00 0.50 WELCT~ NUND INTRM1 00:00 - 01:00 1.00 WELCT BOPE INTRM1 01:00 - 03:30 2.501 WELCTLI BOPE INTRMI 03:30 - 04:00 ~ 0.50 ! WELCTLJ BOPE INTRMI 04:30 - 05:30 10.00 DRILLT~ PULD INTRMI 05:30 - 06:30 1.00 DRILL PULD INTRM1 06:30 - 08:30 2.00 DRILL TRIP INTRM1 08:30 - 12:00 3.50 DRILL TRIP INTRM1 12:00 - 15:30 3.50 DRILL TRIP INTRM1 15:30 - 16:30 I 1.001 DRILL I TRIP I INTRM1 16:30 - 16:45 0.25 DRILL OTHR INTRM1 16:45 - 18:15 1.50 RIGMNT RSRV INTRM1 18:15 - 19:00 0.75 RIGMNT RGRP INTRM1 19:00 - 22:30 3.50 DRILL TRIP INTRM1 22:30 - 00:00 1.501 DRILL STRIP ~ INTRMI 00:00 - 01:00 1.00 DRILL ~ TRIP ~ INTRM1 01:00 - 02:15 I 1.25) DRILL I CIRC I INTRMI 02:15 - 03:45 I 1.501 DRILL (TRIP I INTRMI 03:45 - 04:00 0.25 DRILL CIRC INTRM1 04:00 - 07:00 3.00 RIGMNT RGRP INTRM1 07:00 - 10:15 3.251 DRILL TRIP INTRM1 10:15 - 10:45 0.50 DRILL CIRC INTRM1 10:45 - 11:30 0.75 CASE DEOT INTRM1 11:30 - 14:45 3.25 CEMEN DSHO INTRM1 Page 9 of 33 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations Set Emergency slips with 290K pulled on string. = 50K on slips. RU WACHS pneunatic cutter & make final cut on 9 5!8 csg as per Vetco wellhead rep. POOH, lay down cut off joint. Length = 34.82'. Install 9 5/8 csg packoff. NU BOP stack, and Run in Lock down screws. RU to test packoff. RU & Test 9 5/8 csg packoff to 2400 PSI - 10 min. Test witnessed by Co. Rep RU to 13 318" X 9 518" Annulus, and press test line. Perform infectivity LOT, observe breakover @ 6.9 bbls and 800 psi (EMW 13.8 ppg). Pump 340 bbls of water annulus flush with a FCP of 775 psi. Recorded on chart. Changed BOP rams to 5" during injection. *"*NOTE*** Hot Oil came out and pumped freeze protect. Pumped 140 bbls diesel 2413') Install test plug. RU & test 5" rams and body test BOP's. 250 psi low / 3000 psi high Record on chart. Witnessed by Co. Rep & TP RD test equipment. Install W.B - RILDS PU 20 Lo-Tads from beaver slide, set on rig floor. C/O swivel packing on Top Drive Open and inspect Top Drive Saver Sud RIH w! 60 stands of DP from Derrick, w/ mule shoe to 5570' POOH, installing Lo-Tads on DP. 24 Total. Rack in Derrick Continue POOH, installing Lo-Tads on DP back to surface. Rack in derrick PU 18 jnts of 5" HWDP for push pipe, and POOH racking back in derrick. Clean floor area of OBM Slip & cut 74' of drilling line. Service TD and draworks. Change out Hydraulic fitting, filter and "O" ring on TD HYD filter housing MU BHA #5. 8 1/2 BIT, Geo-Pilot assmy, GP pony, stabilizer, MWD, Stabilizer, HCIM, Neu/Den, TM, HOC, Float sub, INMFDC. Plug in and download. RIH to 160' and perform shallow hole pulse test. OK 5 BPM, 890 PSI. Hold PJSM, and load sources. PU 2 NMFDC's, 2 stnds of HWDP and jars. RIH picking up new drill pipe. make up, breakout clean and re-make every connection. picked up 24 jnts. Cont RIH from 1,146' with 8 1/2" BHA #5 PU new drill pipe, make up, breakout clean and re-make every connection, RIH to 2,384' Broke in bearings on Geo-pilot and shallow tested MWD, had no pulse on MWD, circ a DP cap and regained pulser Cont RIH from 2,384' with 8 1/2" BHA #5 PU new drill pipe, make up, breakout clean and re-make every connection, RIH to 4,010' (PU a total of 114 jts of Weatherfords 5" S-135 DP) Filled DP & re-checked MWD and ck ok Replaced pipe rotating assembly motor on top drive RIH with DP from derrick with BHA #5 from 4,010' and tagged cmt above FC at 10,483' (FC@ 10,490') Circ 50 bbls of mud to clear air from DP for csg test RU and tested 9 5/8" csg to 3,000 psi for 30 min Drilled out plugs and Float collar at 10,490', shoe track and float shoe at 10,572' then cleaned out to btm at 10,580', drilled 25' of new hole to 10,605', ADT .26 hrs, drilled out with 5-8K wob, 100 rpm's, 500 gpm at Printed: 10/28/2005 10:29:27 AM • ConocoPhillips Alaska Page 10 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common W ell Name: 1 E-117 Spud Date: 6/20/2005 Event Nam e: ROT -D RILLING Start: 6/20/2005 End: 8/13/2005 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Code' Phase Description of Operations 7/5/2005 11:30 - 14:45 3.25 CEMEN DSHO INTRMI 2,400 psi and 15-19K ft-Ibs torque, rot wt 105K, up wt 178K, do wt 66K 14:45 - 15:45 1.00 DRILL CIRC INTRM1 Circ btms up for LOT, evened MW in and out at 9.1 ppg MOBM, circ hole at 550 gpm, 2,750 psi, 100 rpm's with 14-19K ft-Ibs torque 15:45 - 16:30 0.75 DRILL LOT INTRMI RU and performed LOT to 14.4 ppg EMW with 964 psi, 9.1 ppg MOBM at 3,511' TVD 16:30 - 17:15 0.75 DRILL DRLG PROD Drilled 8 1/2" hole in A2 sand from 10,605' to 10,699' (94') ADT .38 hrs 17:15 - 17:45 0.50 DRILL CIRC PROD Circ hole while geology evaluated logs, circ at 490 gpm, 2,350 psi, 100 rpms and 14-19K ft-Ibs torque 17:45 - 21:30 3.75 DRILL DRLG PROD Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 10,699' to 11,143' MD/ 3,493' TVD, (444') ADT 2.16 hrs, 8-15K wob, 100-140 rpm's, 180 spm, 640 gpm, 3,700 psi, off btm torque 15-20K ft-Ibs, on btm 10-20K ft-Ibs, rot wt 104K, up wt 200K, do wt 61 K, 9.0 ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 11.3 ~ ppg, ave BGG 150 units, max gas 856 units 21:30 - 23:00 1.50 DRILL CIRC PROD Circ hole while geology evaluated logs, circ at 550 gpm, 2,775 psi, 100 rpms and 16K ft-Ibs torque, determined to have drilled out the top of A2 sand at 11,040' MD/3,501' TVD 23:00 - 00:00 1.00 DRILL DRLG PROD Directionally drilled 8 112" Hole in A2 sand from 11,143' to 11,189' MD/ 3,493' TVD (46') ADT .29 hrs 7/6/2005 00:00 - 04:00 4.00 DRILL DRLG PROD Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 11,186' to 11,593' MD/ 3,506' TVD, (407') ADT 2.71 hrs, 10-15K wob, 140 rpm's, 180 spm, 640 gpm, 3,700 psi, off btm torque 15-20K ft-Ibs, on btm 10-20K ft-Ibs, rot wt 105K, up wt 205K, do wt 55K, 9.0 ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 11.5 ppg, ave BGG 100 units, max gas 537 units, NOTE decision was made to sidetrack well since drilling out of zone from 11,040' MD/ 3,501' TVD to 11,400' MD/ 3,498' TVD (360' total) 04:00 - 05:00 1.00 DRILL REAM PROD Backreamed out at Drlg rate from 11,593' to 11,382' and cont to Pump out of hole to 10,820', pumped out at 160 gpm at 500 psi, st wt up 200K, do wt 60K 05:00 - 08:00 3.00 DRILL DRLG PROD Troughed well to preform OH sidetrack from 10,820' to 10,850' then time drilled from 10,850' to 10,860' and sidetracked well. 08:00 - 15:30 7.50 DRILL DRLG PROD Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 10,860' to 11,593' MD/ 3,513' TVD, (733') ADT 5.8 hrs, 10-15K wob, 140 rpm's, 180 spm, 640 gpm, 3,700 psi, off btm torque 14-20K ft-Ibs, on btm 9-14K ft-Ibs, rot wt 104K, up wt 221 K, do wt 54K, 9.0+ ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 11.8 ppg, ave BGG 120 units, max gas 581 units 15:30 - 00:00 8.50 DRILL DRLG PROD Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 10,860' to 11,593' MD/ 3,513' TVD, (997') ADT 6.1 hrs, 10-15K wob, 140 rpm's, 180 spm, 640 gpm, 3,750 psi, off btm torque 15-20K ft-Ibs, on btm 8-14K ft-Ibs, rot wt 105K, up wt 220K, do wt 55K, 9.0 ppg MOBM, clean hole ECD is 10.8 ppg, ave ECD 11.7 ppg, ave BGG 140 units, max gas 600 units 7/7/2005 00:00 - 06:00 6.00 DRILL DRLG PROD Directionally drilled 8 1!2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 12590' to 13245' MD/ 3,479' TVD, (655') ADT 4.52 ~ hrs, 5-15K wob, 140 rpm's, 180 spm, 640 gpm, 3,800 psi, off btm torque 16-20K ft-Ibs, on btm 15-16K ft-Ibs, rot wt 104K, up wt 220K, do wt 50K, 9.0+ ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 12.0 ppg, ave BGG 54 units, max gas 675 units 06:00 - 06:45 0.75 DRILL CIRC PROD Stop Drilling - PU and circu off bttm to evaluate logs. 06:45 - 10:15 3.50 DRILL DRLG PROD Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilot and i , Stratasteer tool from 13245' to 13610' MD/ 3,485' TVD, (365') ADT 1.82 Printed: 10/28/2005 10:29:27 AM ~- ConocoPhillips Alaska Page 11 of 33 Operati©ns Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase 7/7/2005 ~ 06:45 - 10:15 ~ 3.50 ~ DRILL ~ DRLG ~ PROD 10:15 - 10:45 0.50 DRILL CIRC PROD 10:45 - 12:00 I 1.25 ~ DRILL ~ DRLG ~ PROD 12:00 - 13:45 I 1.75 I DRILL I DRLG I PROD 13:45 - 14:15 ~ 0.501 DRILL CIRC PROD 14:15 - 21:30 I 7.25 I DRILL I DRLG I PROD 21:30 - 00:00 2.501 RIGMNTI RGRP I PROD 7/8/2005 100:00 - 12:00 I 12.00 I RIGMNTI RGRP I PROD 12:00 - 14:15 I 2.251 RIGMNTI RGRP I PROD 14:15 - 16:00 1.75 RIGMNT RGRP PROD 16:00 - 17:00 1.00 RIGMNT RGRP PROD 17:00 - 00:00 I 7.00 I DRILL I DRLG I PROD 7/9/2005 100:00 - 06:00 I 6.001 DRILL I DRLG I PROD Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations hrs, 5-15K wob, 140 rpm's, 180 spm, 640 gpm, 3,800 psi, off btm torque 16-20K ft-Ibs, on btm 15-16K ft-Ibs, rot wt 104K, up wt 220K, do wt 50K, 9.0+ ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 12.0 ppg, ave BGG 54 units, max gas 675 units. While drilling do std pumped Wt/ Hi Vis sweep. Circu weigthed sweep out of hole -Saw 35% increase in cutting when sweep came to surface Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 13610' to 13703' MD/ 3,487' TVD, (93') ADT .59 hrs, 5-20K wob, 140 rpm's, 180 spm, 640 gpm, 3,850 psi, off btm torque 16-20K ft-Ibs, on btm 15-16K ft-Ibs, rot wt 104K, up wt 220K, do wt 50K, 9.0+ ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 12.0 ppg, ave BGG 70 units, max gas 470 units Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 13703' to 13931' MD/ 3,490' TVD, (228') ADT 1.34 hrs, 5-20K wob, 140 rpm's, 172 spm, 610 gpm, 3,850 psi, off btm torque 20-22K ft-Ibs, on btm 15-16K ft-Ibs, rot wt 100K, up wt 245K, do wt 40K, 9.0+ ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 12.1 ppg, ave BGG 55 units, max gas 275 units Stop Drilling - PU and circu off bttm to evaluate Iogs.PR 173 SPM, 615 GPM, PP 3700 psi, 130 RPMs Directionally drilled 8 1!2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 13931' to 14660' MD/ 3,448' TVD, (729') ADT 4.67 hrs, 5-20K wob, 140 rpm's, 175 spm, 620 gpm, 3,850 psi, off btm torque 20-22K ft-Ibs, on btm 15-16K ft-Ibs, rot vut 100K, up wt 245K, do wt 40K, 9.0+ ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 12.1 ppg, ave BGG 55 units, max gas 275 units *"' NOTE** @ 9:30 the #2 mud pump started leaking at the cyclinder head. Pump shut down for repairs. We cannot drill with 1 pump. While mud pump is repaired we will BROOH to shoe. TIH and be ready to drill when pump is repaired. BROOH PR 110 SPM, 130 RPMs, BR speed slow to allow hole to clean up Slowly BROOH 14,215' to 11,756' MD, PR 103 spm, 362 gpm, PP 1360 psi, RPMs 120, Troq 16-24k Moderate show of cutting at shakers - 10-15 % above drilling rate. Some slight pack off problems sceen if BR rate was to FAST. BGG 89 units Con't to slowly BROOH 11,756' to 11,510' MD, PR 105 spm, 374 gpm, PP 1400 psi, RPMs 120, Troq 15-19k. BGG 68 units TIH to 14,573' MD, Dn wt 60k, Up wt 185k - No problems TIH Wash & Ream 14,573 to 14,660' MD -Run in Pump #2 and ck for leaks - Re-Torq bolts after pressure run in. PR 168 spm, 597 GPM, PP 3700 psi, RPMs 120, Torq 18k Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 14660' to 15303' MD/ 3,427' TVD, (643') ADT 4.63 hrs, 5-15K wob, 120 rpm's, 164 spm, 585 gpm, 3,850 psi, off btm torque 17-23K ft-Ibs, on btm 16K ft-Ibs, rot uvt 112K, up rvt 267K, do wt 49K, 9.0+ ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 11.8 ppg, ave BGG 75 units, max gas 310 units Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 15,303' to 15,774' MD/ 3,415' TVD, (T.D.) (471') ADT 3.6 hrs, 5-12K wob, 120 rpm's, 163 spm, 580 gpm, 3,975 psi, off btm torque 20-23K ft-Ibs, on btm 17-18K ft-Ibs, rot wt 125K, up wt 260K, Printed: 10/28/2005 10:29:27 AM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code ' Phase 7/9/2005 00:00 - 06:00 { 6.00 {DRILL { DRLG PROD 06:00 - 06:15 06:15 - 09:30 09:30 - 10:45 10:45 - 11:15 11:15 - 13:30 0.25 DRILL OBSV PROD 3.25 DRILL WIPR PROD 1.251 DRILL I WIPR I PROD 0.50 RIGMNT RGRP PROD 2.25 DRILL CIRC PROD 13:30 - 15:15 15:15 - 15:30 15:30 - 21:00 21:00 - 21:15 21:15 - 00:00 7/10/2005 00:00 - 02:00 02:00 - 02:30 02:30 - 05:30 05:30 - 06:30 06:30 - 07:00 07:00 - 07:30 07:30 - 11:15 11:15 - 12:30 12:30 - 16:00 16:00 - 16:30 1.751 DRILL (CIRC ~ PROD 0.25 DRILL OBSV PROD 5.50 DRILL TRIP ,PROD 0.25 DRILL OBSV PROD 2.75 DRILL TRIP PROD 2.00 DRILL TRIP PROD 0.50 DRILL PULD PROD 3.00 DRILL PULD PROD 1.00 DRILL PULD PROD 0.50 CASE RURD CMPLTN 0.50 CASE SFTY CMPLTN 3.751 CASE I PULR I CMPLTN 1.25 ~ CASE PULR ~ CMPLTN 3.50 I CASE !RUNL I CMPLTN 0.501 CASE I CIRC I CMPLTN 16:30 - 17:30 1.00 I CASE RUNL CMPLTN 17:30 - 20:00 2.50 CASE RUNL CMPLTN 20:00 - 22:15 2.25 CASE RUNL CMPLTN 22:15 - 23:30 1.25 CASE RUNL { CMPLTN Page 12 of 33 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations do wt 70K, 9.0 ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 12.0 ppg, ave BGG 50 units Monitored well-static Backreamed out of hole from 15,774' to 14,600' with no problems, BROOH to previous trip at 120 rpm's, 130 spm, 462 gpm at 2,500 psi, RIH from 14,600' to btm at 15,774' with no problems, pumped weighted hi vis weep and #2 mud pump went down Circu & Condition hole -Changed out valve and seat on #2 mud pump Cont to circ out weighted hi vis sweep and circ an additional btms up and was clean at shakers, circ hole clean at 560 gpm at 3,900 psi, 140 rpm's with 18K ft-Ibs torque Changed hole over from 9.0 ppg MOBM to 9.0 ppg SFMOBM, displaced hole out at 140 rpm's with 25K ft-Ibs torque and 547 gpm at 3,775 psi, rot wt 125K, up wt 295K, do wt 38K Monitored well-static, took SPR's POOH wet on elevators from 15,774' to 10,484' (Csg Shoe @ 10,572') with no problems Monitored well at shoe-static, dropped 2 3/8" rabbit on a wire Cont to POOH wet from 10,484' to 5,496' Con't POOH from 5,496 to BHA at 378', UD 2- 8.5" ghost reamers from string POOH from 378' to 150', LD 5 jts HWDP, Jars and 2 NM FDCs Held PJSM and remove radioactive sources then down Loaded MWD, calc fill on trip out of hole 141 bbls, actual fill 154 bbls of 9.0 ppg SFMOBM Fin POOH and LD BHA #5, cleaned rig floor RU Doyon's 5 1/2" liner running tools Held PJSM and reviewed liner detail and discuss know hazards, Stressed "Stay Focused" on task at hand. PU and RIH with 5 1/2", 15.5#, L-80, BTCM Liner per well program to 5,311' (125 Jts total), ran 5 1/2" ROT silver bullet guide shoe with no float, ran a total of 53 jts (2,262') of 5 1/2" 15.5#, L-80, BTCM blank liner and ran 72 jts (3,027') of 5 1/2", 15.5# L-80 BTCM slotted liner per detail sheet, ran 124 - 5 1/2" x 8 1/2" spiralglide centralizers 1/jt, jts #2 thru # 125, ran 12 constrictor packers placed on blank liner to cover shale sections. Micro Slots on liner 120 - 1.5" long X .018" @ 4 rows per/ft. MU Baker 190-47 seal bore ext, 9 518" x 7" Flexlock liner hanger with, "RS" pack-off seal nipple and "HRD" ZXP liner top packer and RIH to 5,369", st wt up 60K, do wt 57K, RD liner running tools RIH with 5 1/2" liner on DP from 5,369' to 10,554', (csg shoe @ 10,572') RIH slow 30-45 fpm to minimize surge with large OD packer. Circ a DP volume at csg shoe, circ at 300 gpm at 500 psi, st wt up 163K, do wt 53K, set torque limiter on top drive at 8,500 ft-Ibs and attempted to rotate liner and would not rotate RIH with liner from 10,554' to 11,950' when liner began floating and down wt was running 45-35K (blk wt), up wt 175K Worked liner down from 11,950' to 13,366', having to work weight down by reciprocating liner. RIH with liner from 13,366' to 14,706', RIH with 14 stds of HWDP from derrick and MU 1-lo-tad per std while RIH RIH with liner from 14,706' to 15,266', RIH PU 2 additional stds of HWDP with Lo-Tads and 4 stds of 6 3/4" Dc's from pipe shed, st wt up Printed: t0Y18/2005 10:29:27 AM • ConocoPhillips Alaska Page 13 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase 7/10/2005 22:15 - 23:30 1.25 CASE RUNL CMPLTN 23:30 - 00:00 0.50 CASE RUNL CMPLTN 7/11/2005 100:00 - 00:15 0.251 CASE RUNL CMPLTN 00:15 - 01:45 1.50 CASE OTHR CMPLTN 01:45 - 02:00 0.25 CASE DEOT CMPLTN 02:00 - 02:15 0.25 DRILL TRIP CMPLTN 02:15 - 03:30 I 1.251 DRILL I CIRC I CMPLTN 03:30 - 03:45 0.25 DRILL OBSV CMPLTN 03:45 - 10:00 6.25 DRILL TRIP CMPLTN 10:00 - 11:00 1.00 DRILL PULD CMPLTN 11:00 - 11:15 0.25 LOG SFTY CMPLTN 11:15 - 12:15 1.00 LOG RURD CMPLTN 12:15 - 20:00 I 7.75 LOG ELOG CMPLTN 20:00 - 22:00 I 2.00 I LOG I ELOG I CMPLTN 22:00 - 23:00 1.00 LOG RURD ' CMPLTN 23:00 - 23:30 0.50 WELCT OTHR CMPLTN 23:30 - 00:00 0.50 WELCT BOPE CMPLTN 7/12/2005 00:00 - 05:15 ~ 5.25 WELCT BOPE CMPLTN 05:15 - 07:00 1.75 RIGMNT RSRV CMPLTN 07:00 - 08:00 1.00 RIGMNT RSRV CMPLTN 08:00 - 08:30 0.50 RIGMNT RSRV CMPLTN 08:30 - 13:00 4.50 WINDO ULD PROD2 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations 270K, do wt 55K RIH from 15,266' to 15,742' with slick DP ftom derrick, st wt up 280K, do wt 40K, NOTE: Ran liner prior to running USIT bond log due to no tractor or personnel on slope Fin RIH with liner from 15,742' to 15,752' and placed A2 sand liner on depth with TOL at 10,382' and shoe at 15,752, st wt up 280K, do wt 40K Dropped 1 3/4" ball and pumped down to seat, initial rate of 4 1/2" bpm at 550 psi, slowed to 2 bpm at 200 psi and with ball on seat pressured up to 1,700 psi, slacked off on liner and hanger wasn't set, pressured up to 2,150 psi and slacked off and hanger hadn't set, pressured up to 2,200 psi and slacked off to blk wt and hanger was set. Pressured up to 3,000 psi and saw tXP packer set then pressured up to 4,000 psi to release HR running tool. Set TOL at 10,382' MD/ 3,486' TVD with guide shoe at 15,752' Pressure tested ZXP pkr and annulus to 1,000 psi for 5 min, good test PU 245K and was released from running tool, LD 1-single POOH to 10,350' Circ btms up at 10,350' with no gas at btms up, circ at 295 gpm at 950 psi Monitored well-static, took SPR's POOH with HR liner running tool from 10,350' to 50', while POOH LD 4 stds of 6 3/4" DC's and 2 stds of HWDP with Lo-Tads used to run liner, removed 4 Lo-Tads from HWDP leaving 10 stds of HWDP with Lo-Tads in the derrick Made service breaks on liner running tool and LD same, cleared and cleaned rig floor, calc fill on trip out of hole 101 bbls, actual fill 111 bbls Held PJSM with rig crew and Schlumberger wireline (SWS) RU SWS wireline and scheaves, MU USIT logging tools with SWS 2 1/8" tractor tool RIH with USIT logging tools to 2,080' and tool stopped, powered up SWS tractor tool and cont RIH, tractor and tools stopped at 10,180' and was unable to go deeper, tool was RIH on .46" line and possibly stopped due to weight of line and tool string Ran USIT bond log from 10,180' to 5,400' then POOH with logging tools, had good cement bond from 10,180' to 5,670' with some cement shown up to 5,520' (13 3/8" Shoe @ 5,546') LD logging tools and RD SWS Pulled wear bushing RU to test BOP's Tested BOPE, tested rams, valves and manifold to 250 psi low and 3,000 psi high, tested annular to 250 psi then 2,800 psi, Lou Grimaldi with AOGCC witnessed testing, RD test equip. and installed wear bushing Changed out 4 1/2" IF saver sub on top drive Slip and cut 60' of drlg line Serviced top drive and greased drawworks PU & MU Whipstock milling assembly BHA #6 and RIH to 870', MU milling assembly and LD, MU seal assembly, locator sub, unloader sub, then PU 20 jts of 5" DP and 2-DP pup jts for spacing out and RIH with seal assembly, MU whipstock and milling assembly with MWD, oriented and uploaded MWD, RIH PU 3 -6 3/4" DC's, RIH to 870', st wt up 65K, do wt 60K Printed: 10/28/2005 10:29:27 AM • 1 E-117 1E-117 ROT -DRILLING Opera.#ions' Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date From - To Hours Code Code Phase 7/12/2005 13:00 - 15:00 2.00 WIN 15:00 - 15:15 0.25 WIN 15:15 - 17:00 1.75 WIN 17:00 - 17:45 0.75 WIN 17:45 - 20:15 2.50 WIN 20:15 - 21:00 0.75 WIN 21:00 - 22:00 1.00 WIN 22:00 - 23:30 1.50 WIN 23:30 - 00:00 0.501 WIN 7/13/2005 00:00 - 00:45 00:45 - 08:30 0.75 7.75 08:30 - 09:30 09:30 - 09:45 09:45 - 13:45 13:45 - 14:45 14:45 - 16:00 16:00 - 18:00 18:00 - 21:45 21:45 - 22:00 22:00 - 00:00 7/14/2005 100:00 - 02:30 1.00 0.25 4.00 1.00 1.25 ConocoPhillips `Alaska RIP PROD2 IRC PROD2 RIP PROD2 THR PROD2 RIP PROD2 IRC PROD2 RIP PROD2 ETW PROD2 IRC PROD2 IRC PROD2 TWP PROD2 IRC PROD2 THR PROD2 RIP PROD2 ULD PROD2 THRIPROD2 2.001 DRILL I PULD I PROD2 3.751 DRILL (TRIP IPROD2 0.25 I DRILL I REAM I PROD2 2.00 DRILL DRLG PROD2 2.50 DRILL DRLG PROD2 Page 14 of 33 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations RIH slow with whipstock assembly BHA #6 from 870' to 3,158' Shallow tested MWD at 3,158' at 460 gpm at 880 psi and tool ck ok RIH slow with whipstock assembly BHA #6 from 3,158' to 6,250' when highline power went down Highline power to 1 E pad went down at 17:00 hrs, began to bring rig motors on line when highline power was restored at 17:45 RIH slow with whipstock from 6,250' to 9,335' Made MADD pass from 9,335' to 9,241' (sensor depth 8,602' to 8,508') and correlated MWD to K-13, no corr. circ at 500 gpm at 2,050 psi, st wt up 193K, do wt 58K Cont to RIH with whipstock from 9,241' to 10,310', st wt up 220K, do wt 65K Oriented whipstock 13 deg left of high side, RIH from 10310' and tagged TOL at 10,382', set whipstock and sheared off from same, top of whipstock at 9,706' MD/3,401' TVD, RIH with whipstock milling assembly with 24 stds of slick 5" DP, 60 stds of 5" DP with Lo-tads, 14 stds of 5" HWDP (10 W/Lo-Tads), 1 std and a double of 5" DP Began to displace hole over from 9.0 ppg SFMOBM to re-conditioned 9.0 ppg MOBM, circ hole at 500 gpm at 2,550 psi Fin displacing hole over from 9.0 ppg SFMOBM to 9.0 ppg MOBM,circ at 465 gpm at 2,100 psi Milled 8 1/2" window in "B" sand lateral from 9,706' to 9,722', cont to mill to 9,738' MD/ 3,405' TVD, (32' total W/5' of gauge hole out of window) milled at 4-7K wob, 70-90 rpm's, 450 gpm at 1,950 psi, on btm torque 13-20K ft-Ibs, rot wt 120K, up wt 195K, do wt 95K Pumped 30 bbl weighted hi vis sweep and circ hole clean while working mills thru window, circ hole at 550 gpm, 2,800 psi and 100 rpm's, rot wt 120K, up wt 195K, do wt 95K Monitored well-static, pumped dry job POOH with BHA #6 from 9,738' to BHA at 190' POOH LD milling BHA #6, LD 3-6 3/4" dc's, bumper sub, MWD and mills, gauged mills and upper mill was in gauge, calc fill on trip out of hole 90 bbls, actual fill 102 bbls, cleared rig floor Pulled wear bushing and flushed out BOP stack after milling window, re-installed wear bushing MU 8 1/2" BHA #7 RIH to 346', MU RR 8 1/2" insert bit on 7" motor with 1.5 deg bend, float sub and MWD, uploaded MWD and RIH PU 3-NM Flex dc's, HWDP and jars from pipe shed while RIH to 346' RIH with BHA #7 from 346' to 9,597', shallow tested MWD at 2,726' while filling DP and tool ck ok Oriented motor at 9,597' and RIH thru window at 9,706' to 9,726' with no problems, washed down from 9,726' to btm at 9,738', washed down at 450 gpm, 2,100 psi, st wt up 144K, do wt 70K Directionally drilled 8 1/2" hole with motor from 9,738' to 9,769' MD! 3,409' TVD (31'), ART -0-, AST 1.33 hrs, 25 K wob, 126 spm, 450 gpm, 2,300 psi st wt up 144K, do wt 70K, drilling on concretion from 9,759' to 9,769' Directionally drilled 8 1/2" hole with mud motor from 9,769' to 9,849' MD/ 3,409' TVD (80'), ART .30 hrs, AST 1.74 hrs, 25-28K wob, 60 rpm's, 128 spm, 455 gpm, 2,200 psi, rot wt 95K, up wt 175K, do wt 75K, drilled on concretions from 9,769' to 9,779' (10'), 9,788 to 9,790' (2'), 9,794' to 9,795' (1') and 9,848' to 9,849' (1'), drilled deep enough to line well up in middle of sand and to get Geo-Pilot out into open hole, did Printed: 10/28/2005 10:29:27 AM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 1E-117 1E-117 ROT -DRILLING Date From - To ,Hours Code '" Code, Phase 7/14/2005 00:00 - 02:30 2.50 DRILL DRLG PROD2 02:30 - 02:45 0.25 DRILL TRIP PROD2 02:45 - 03:30 I 0.751 DRILL I CIRC I PROD2 03:30 - 03:45 0.25 DRILL I OBSV PROD2 03:45 - 07:15 3.50 DRILL TRIP PROD2 07:15 - 08:30 1.25 DRILL PULD PROD2 08:30 - 12:00 I 3.50 I DRILL I PULD I PROD2 12:00 - 16:00 4.001 DRILL PULD PROD2 16:00 - 00:00 I 8.00 I DRILL I DRLG I PROD2 7/15/2005 00:00 - 12:00 12.00 DRILL DRLG PROD2 12:00 - 00:00 12.00 DRILL DRLG PROD2 7/16/2005 00:00 - 03:15 03:15 - 04:30 04:30 - 05:00 3.251 DRILL DRLG PROD2 1.251 DRILL CIRC PROD2 0.50 I DRILL 1 REAM I PROD2 Page 15 of 33 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations not drill out of zone. Pumped out of hole from 9,849' to 9,725' then POOH thru window to 9,694' to above top of whipstock, pumped out at 450 gpm at 2,150 psi, no problems pulling thru window Circ btms up at 9,694' and was clean at shakers, Circ at 600 gpm at 3,350 psi and 60 rpm's Monitored well-static, pumped dry job POOH with BHA #7 from 9,694' to BHA at 346' LD BHA #7, stood back HWDP, jars and NM flex dc's, LD MWD, motor and bit, cleared rig floor, talc fill on trip out of hole 83 bbls, actual fill 92 bbls PU & MU 8 1/2" BHA #8 &RIH to 384', MU new 8 1/2 PDC bit, GEO-Pilot, MWD with Stratasteer, GR/Res/PWD//Neutron/density, uploaded MWD, held PJSM and loaded radioactive sources, cont RIH with NM flex dc's, HWDP and jars to 384' RIH with BHA #8 from 384' to btm at 9,849', no problems going thru window or RIH to btm, PU 2 ghost reamers and placed 1-962' back from the bit and 2nd one 1,825' back from the bit Directionally drilled 8 1/2" hole in "B" sand lateral with Geo-pilot and Stratasteer tool from 9,849' to 10,110' MD/ 3,390' TVD, (261') ADT 3.72 hrs, 7-20K wob, 90-120 rpm's, 169 spm, 600 gpm at 3,100 psi, off btm torque 14-20K ft-Ibs, on btm torque 14-18K ft-Ibs, rot wt 102K, up wt 190K,dn wt 62K, 9.0 ppg MOBM, ave ECD 10.9 ppg, ave BGG 60 units, max gas 480 units. Drilled thru concretions from 9,849' to 9,862' (13'), 9,869' to 9,888' (19'), 9,966' to 9,979' (13') and 9,988' to to 10,009' (21') Directionally drilled 8 1/2" hole in "B" sand lateral with Geo-pilot and Stratasteer tool from 10,110' to 10,494' MD/ 3,381' TVD, (384') ADT 10.21 hrs, 8-20K wob, 90-140 rpm's, 600 to 640 gpm at 3,100 to 3,300 psi, off btm torque 14-23K ft-Ibs, on btm torque 13-20K ft-Ibs, rot wt 104K, up wt 195K,dn wt 56K, 9.0 ppg MOBM, ave ECD 11.0 ppg, ave BGG 100 units, max gas 572 units. Drilled thru concretions from 10,128'-10,132' (4'), 10,158'-10,180' (22'), 10,182'-10,197' (15'), 10,271'-10,281' (10'), 10,295'-10,309' (14'), 10,350'-10,358' (8'), 10,389'-10,407' (18'), 10,425'-10,445', (20') 10,478'-10,490' (12') Directionally drilled 8 1/2" hole in "B" sand lateral with Geo-pilot and Stratasteer tool from 10,494' to 11,481' MD/ 3,356' TVD, (987') ADT 9.24 hrs, 5-20K wob, 90-140 rpm's, 660 gpm at 3,750 psi, off btm torque 15-20K ft-Ibs, on btm torque 12-20K ft-Ibs, rot wt 102K, up wt 205K,dn wt 52K, 9.1 ppg MOBM, ave ECD 11.8 ppg, ave BGG 90 units, max gas 330 units. Drilled thru concretions from 10,998'-11,018' (20'), 11,070'-11,076' (6'), 11,081'-11,089' (8'), 11,102'-11,109' (7'), 11,121'-11,126' (5'), 11,161'-11,163' (2'), 11,191'-11,193' (2') Directionally drilled 8 1/2" hole in "B" sand lateral with Geo-pilot and Stratasteer tool from 11,481' to 11,853' MD/ 3,342' TVD, (372') ADT 1.82 hrs, 12-19K wob, 110-140 rpm's, 660 gpm at 3,700 psi, off btm torque 15-20K ft-Ibs, on btm torque 13-16K ft-Ibs, rot wt 100K, up wt 200K,dn vrt 50K, 9.1 ppg MOBM, ave ECD 11.8 ppg, ave BGG 90 units, max gas 162 units. No concretions Circ hole and worked pipe while geologist evaluated logs, appears to either have crossed fault orjust drilled out of zone at 11,766' MDl3,347' TVD, decision was made to sidetrack well Backreamed out of hole from 11,853' to 11,650', backreamed out at 140 rpm's, 600 gpm at 3,200 psi Printed: 10/28/2005 10:29:27 AM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase 7/16/2005 05:00- 07:45 ~ 2.75 ~ DRILL ~ DRLG ~ PROD2 07:45 - 11:15 3.501 DRILL DRLG PROD2 11:15 - 00:00 I 12.751 DRILL I DRLG I PROD2 7/17/2005 00:00 - 12:00 12.00 DRILL DRLG PROD2 12:00 - 22:45 10.751 DRILL DRLG PROD2 22:45 - 00:00 7/18/2005 00:00 - 00:45 00:45 - 01:00 01:00 - 12:00 12:00 - 18:45 1.251 RIGMNT RGRP PROD2 0.75 RIGMNT RGRP PROD2 0.25 RIGMNT RGRP PROD2 11.00 ~ DRILL DRLH PROD2 6.751 DRILL I DRLH I PROD2 Page 16 of 33 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Qescription of Operations Time drilled and sidetracked well from 11,650' to 11,666', ave 5'/hr with 135 rpm's, 610 gpm at 3,250', sidetracked well at 11,650' Directionally drilled 8 1/2" hole from 11,666' to 11,853' MD/ 3,354' TVD ADT 1.31 hrs. Directionally drilled 8 1/2" hole in "B" sand lateral with Geo-pilot and Stratasteer tool from 11,853' to 12,769' MD/ 3,342' TVD, (916') ADT 9.74 hrs, 8-20K wob, 110-140 rpm's, 660 gpm at 3,825 psi, off btm torque 15-20K ft-Ibs, on btm torque 13-14K ft-Ibs, rot wt 98K, up wt 204K,dn wt 47K, 9.05 ppg MOBM, ave ECD 11.8 ppg, ave BGG 100 units, max gas 753 units. Drilled thru concretions at 11,233'-11,239' (6'), 11,830'-11,835' (4'), 11,956'-11,962' (6'), 11,969'-12,006' (37'), 12,046'-12,063' (17'), 12,130'-12,138' (8') Directionally drilled 8 1/2" hole in "B" sand lateral with Geo-pilot and Stratasteer tool from 12,769' to 13,279' MD/ 3,328' TVD, (510') ADT 10.55 hrs, 10-21 K wob, 110-135 rpm's, 655 gpm at 3,825 psi, off btm torque 17-18K ft-Ibs, on btm torque 13-15K ft-Ibs, rot wt 99K, up wt 200K,dn wt 47K, 9.0 ppg MOBM, ave ECD 11.7 ppg, ave BGG 70 units, max gas 197 units. Drilled thru concretions at 12,768'-12,772' (4'), 12,837'-12843' (6'), 12,898'-121,913' (15'), 12,948'-12,962' (14'), 12,969'-12,980' (11'), 13,028'-13,034' (6'), 13,145'-13,150' (5') 13,176'-13,183' (7'), 13,201'-13,219' (18')13,241'-13,246' (5'), 13,258'-13,268' (10'), 13,277'-13,281' (4') Directionally drilled 8 1/2" hole from 13,279' to 14,085' MD/ 3,306' TVD, (806') ADT 8.4 hrs, 5-21 K wob, 90-135 rpm's, 647 gpm at 3,900 psi, off btm torque 17-20K ft-Ibs, on btm torque 15-16K ft-Ibs, rot wt 97K, up wt 202K,dn wt 37K, 9.0 ppg MOBM, ave ECD 11.9 ppg, max 12.0 ppg, ave BGG 80 units, max gas 253 units. Drilled thru concretions at 13,394'-13,400' (6'), 13,485'-13,490' (5'), 13,510'-13,520' (10'), 13,687'-13,700' (13'), 13,790'-13,796' (6'), 13,804'-13,825' (21'), 13,831'-13,835' (4'), 13,844'-13,846' (2'), 13,923'-13,931' (8'), 13,981'-14,000' (19'). NOTE: 4" Demco valve on kill line failed causing a spill inside rigs secondary containment, spilled was approx 1/2 bbl with 1 gal leaking outside of rig onto side of the rig and matting board, notified security and spill was cleaned up Worked pipe out of hole slowly from 14,085' to 13,880' while changing out O-ring on 4" Demco valve on kill line, tested and still leaked, began to RU 2" line to circ hole while cunt to repair valve. NOTE: Had a medical emergency with a Doyon employee after he had gone off tour, hand was sent to KOC medic then to Anchorage for further evaluation Changed out valve stem (bonnett) on 4" kill line valve and tested, ck ok, circ ho{e thru 2" line at 3 bpm at 270 psi while slowly working pipe at 13,880' while repairing valve RIH from 13,880' to btm at 14,085' Directionally drilled 8 1/2" hole in "B" sand lateral with Geo-pilot and Stratasteer tool from 14,085' to 14,336' MD/ 3,299' TVD, (251') ADT 9.3 hrs, 10-22K wob, 90-135 rpm's, 642 gpm at 3,800 psi, off btm lorque 18-20K ft-Ibs, on btm torque 16-17K ft-Ibs, rot wt 95K, up wt 205K,dn wt 35-40K, 9.0 ppg MOBM, ave ECD 11.9 ppg, ave BGG 50 units, max gas 132 units. Drilled thru concretions at 14,118'-14,122' (4'), 14,193'-14,205' (12'), 14,201'-14,221' (20'), 14,246'-14,259' (13'), 14,268'-14,278' (10'), 14,292'-14,311' (19'), 14,313'-14,343' (30') Directionally drilled 8 1/2" hole in from 14,336' to 14,566' MD/ 3,294' Printed: 10/28/2005 10:29:27 AM • ConocoPhitlips Alaska Page 17 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations 7/18/2005 12:00 - 18:45 ~ 6.75 ~ DRILL ~ DRLH ~ PROD2 18:45 - 20:00 1.25 DRILL OBSV PROD2 20:00 - 00:00 4.00 DRILL TRIP PROD2 7/19/2005 00:00 - 05:00 ~ 5.00 DRILL TRIP PROD2 05:00 - 06:00 ~ 1.001 DRILL (TRIP PROD2 06:00 - 10:30 4.50 DRILL ~ TRIP PROD2 10:30 - 11:00 0.50 ~ DRILL PULD PROD2 11:00 - 12:00 1.00 DRILL PULD PROD2 12:00 - 14:15 2.25 DRILL PULD PROD2 14:15 - 17:15 I 3.001 DRILL I PULD (PROD2 17:15 - 21:30 4.25 DRILL TRIP PROD2 21:30 - 21:45 0.25 DRILL TRIP PROD2 21:45 - 23:15 1.50 RIGMNT RSRV ' PROD2 23:15 - 00:00 0.75 DRILL TRIP PROD2 7/20/2005 , 00:00 - 00:30 0.50 DRILL TRIP PROD2 00:30 - 02:30 I 2.00 I DRILL I OTHR I PROD2 02:30 - 03:00 0.50 DRILL TRIP PROD2 03:00 - 09:30 6.50 DRILL REAM PROD2 09:30 - 12:00 2.50 DRILL DRLH PROD2 TVD, (230') ADT 5.73 hrs, 10-22K wob, 90-135 rpm's, 642 gpm at 3,800 psi, off btm torque 18-20K ft-Ibs, on btm torque 16-17K ft-Ibs, rot wt 95K, up wt 205K,dn wt 35-40K, 9.0 ppg MOBM, ave ECD 11.9 ppg, ave BGG 50 units, max gas 132 units. Drilled thru concretions at 14,394'-14,402' (8'), 14,480'-14,496' (16'), 14,531'-14,539' (8'), 14,541'-14,552' (11'), last 3 concretions from ROP only no logs, penetration rate slowed thru concretions to 2-3'!hr down from 10', decision made to trip for bit Monitored well-static, took SPR's POOH on elevators from 14,566' to 14,261' (3 stds) and hole wasn't taking proper fill, backreamed out of hole from 14,261' to 11,764', backreamed out at 622 gpm at 3,700 psi, 120 rpm's with 17K ft-Ibs torque, initial string speed was 20-25'/min due to torquing up but did not pack-off, increased speed to 25-30'/min, attempted to POOH on elevators at 13,433' and 12,505' and well was not taking any fill and had 30-40K add. drag BROOH from 11764 -10036' . Attempt to POOH on elevators from 10904' to 10518' and hole wasn't taking proper fill, backreamed out of hole from 10036' to 9746', backreamed out at 622 gpm at 3,700 psi, 120 rpm's with 17K ft-Ibs torque. POOH on elevators through window to 9649'. No issues through window. Monitor well. Static. POOH from 10036' - 8682', observed well taking proper fil. Shut down GEO- PILOT, pump dry job, Continue POOH from 8682' - 106' PJSM, remove radioactive sources from tool string. Plug in and download MWD Continue to download MWD, POOH -lay down HOC, MWD and bit. Grade bit to 0-0-NO-ALL-X-N-NO-ROP Make up BHA #9. Service GEO-PILOT and MU bit, MWD w/ NEU-DEN and HOC. Plug in -Upload MWD and perform shallow hole test. Hold PJSM, and load radiactive sources in tools. Continue MU 1- stnd of NM flex collars, 5 studs of HWDP and Jars. Trip in hole from 383' - 9615' (91' above TOW) Calibrate Caliper logging tool. 126 SPM, 448 GPM's at 1900 PSI. 30 RPM's with 14K free torque 202 K Up weight, 60k down weight 105k rotating weight Slip & Cut drilling line. Service Top drive & Drawworks. Continue trip in hole to 9914'. No issues going through window w/ driiling assembly. Continue TIH form 9914' - 10112', working pipe through a few tight spots. Perform caliper log coming up hole at 4-5 ft /min from 10112' - 9812'. Pumping at 144 spm, 2500 psi and 60 rpm's. TIH form 9812' - 10264', working pipe in hole at tight spots from 10140' Wash & Ream from 10264' -10683'. Attempt to RIH on elevators, NO-GO. Stacking out and run out of weight. Continue to wash & ream from 12217', and once again attempt to RIH on elevators to 12495'. Continue wash & ream to tag bottom @ 14482'. 206 k up weight, 47 K down, and 104K rot wt. Torque = 17K, Trip gas 90 units. Directionally drilled 8 1/2" hole w/ Geo-Pilot from 14,482' (Corrected depth 14,482) to 14,645' MD / 3,291' TVD; (163') ADT 1.64 hrs, 10-25K wob, 90-120 rpm's, 575 gpm at 3,900 psi, off btm torque 18-20K ft-Ibs, Printed: 10/28/2005 10:29:27 AM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 1E-117 1E-117 ROT -DRILLING Date From - To Hours Code Sub Phase Code 7/20/2005 ~ 09:30 - 12:00 2.50 ~ DRILL ~ DRLH PROD2 12:00 - 00:00 I 12.00 DRILL DRLH ~ PROD2 7/21 /2005 00:00 - 09:15 09:15 - 09:45 09:45 - 10:30 10:30 -12:00 12:00 - 12:15 12:15 - 13:00 13:00 - 13:15 13:15 - 22:15 22:15 - 23:30 23:30 - 00:00 7/22/2005 00:00 - 01:15 01:15 - 01:30 01:30 - 03:30 03:30 - 06:15 9.251 DRILL I DRLH I PROD2 0.50 DRILL CIRC ~ PROD2 0.75 RIGMNT RGRP I PROD2 1.501DRILL (CIRC IPROD2 0.251 DRILL CIRC PROD2 0.75 RIGMNT RGRP PROD2 0.25 WELCT OBSV PROD2 9.00 DRILL TRIP PROD2 1.251 DRILL CIRC PROD2 0.50 RIGMNT RGRP PROD2 1.25 RIGMNT RGRP PROD2 0.251 DRILL CIRC PROD2 2.001 DRILL I TRIP I PROD2 2.751DRILL (TRIP IPROD2 06:15 - 08:30 2.251 DRILL (CIRC IPROD2 Page 18 of 33 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations on btm torque 16-18K ft-Ibs, rot wt 104K, up wt 206K,dn wt 47K, 9.0 ppg MOBM, ave ECD 11.9 ppg, ave BGG 50 units, max gas 132 units. Directionally drilled 8 112" hole wJ Geo-Pilot from 14,645' to 15268' MD / 3,277' TVD, (623') ADT 10.08 hrs, 10-25K wob, 90-120 rpm's, 575 gpm at 3,900 psi, off btm torque 18-20K tt-Ibs, on btm torque 19-21 K tt-Ibs, rot wt 116K, up wt 230K,dn wt 35K, 9.0 ppg MOBM, ave ECD 11.9 ppg, ave BGG 49 units, max gas 555 units. Continue Directional drill 8 1/2" hole with Geo -Pilot from 15268' -15667' TD. (399') TVD = 3275' Drilled through concretions from 15145 - 15159, 15165 -15183, 15190 -15192, 15216 - 15233, 15267 -15276, 15327 - 15344, 15426 - 15437, 15446 - 15482, 15114, and 15598. ART = 7.96 HRS 570 GPM's at 3950 PSI. 140 RPM's, 230k up, 57K dn, 125K rot wt. ECD 11.8,and Tq off btm = 20K, on btm = 17-18K. WOB = 10-25K Jars = 220.15 HRS Obtain surveys, and Slow Pump rates. POOH rack back 1 stand. Remove and Repair Top Drive shot pin assembly, while circulate @ 71 spm, w/ 1100 PSI Pump Hi visc weighted sweep at 560 GPM's, 3950 PSI, and 140 RPM's while reciprocate drill string. 230k up, 57K dn, and 125K rot wt. Tq = 20k Continue pump Hi Visc weighted sweep at 560 GPM's, 3950 PSI, and 140 RPM's while reciprocate drill string. 230k up, 57K dn, and 125K rot wt. Tq = 20k Install repaired shot pin assembly on Top Drive. Monitor well, static Attempt to POOH on elevators from 15582' -15391' (191'). Observe improper hole fill. BROOH from 15391'-14451 (940') Attempt to POOH on elevators and observed hole swabbing. Continue BROOH to 9690'. (5701' Total) No issues pulling ghost reamer or BHA through window. TOW = 9706' 568 GPM's, 3950 PSI, 125 RPM's, TO = 18K Pump 30 BBL Hi Visc weighted sweep while reciprocate drill string from 9690' - 9624' 140 RPM's, TO = 12-23K, 180 SPM, 640 GPM's, w/ 3200 PSI. Pumped 3 btms up and observed 10 % increase in cuttings and casing clean. Swivel packing on Top Drive failed. Change out swivel packing Swivel packing on Top Drive failed. Change out swivel packing, Test same. Note: Rig Hand reported muscle sprain in back white hammering on Swivel packing. A PIR was generated and he was sent to medic, returned to work. Contimue Circulate while reciprocate drill string from 9690' - 9624' 140 RPM's, TO = 12-23K, 180 SPM, 640 GPM's, w/ 3200 PSI. Pumped 3 btms up and observed 10 % increase in cuttings and casing clean. TIH f/ 9690' - 13098'. (3408') No issues through window area with BHA. Tagged up at 13098' .Drill string would not go to bottom on elevators. Wash & ream from 13098' - 15667' TD. (2569') TVD 3275'. Pumps at 72 SPM, 250 GPM's at 1000 PSI. Rotating @ 70 RPM"S w/ 15-17K TO. Attempt to RIH numerous times without wash & ream, and string would not go. 185K up, 67K down Rot wt = 125K Pump Hi Visc weighted sweep @ 575 Gpm's, 4250 PSI. 250K up, 55k dn, Rot wt = 120K TO = 18-20K, 140 RPM's. Observed 20% increase in cuttings and shakers cleaned up. Reciprocate drill string while circulating. Printed: 10!28/2005 10:2927 AM r~ u ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase 7/22/2005 08:30 - 10:30 10:30 - 12:00 12:00 - 19:30 2.00 DRILL CIRC PROD2 1.501 DRILL (TRIP IPROD2 7.501 DRILL I TRIP I PROD2 19:30 - 20:15 20:15 - 22:00 22:00 - 23:00 123:00 - 23:15 23:15 - 00:00 7/23/2005 00:00 - 00:30 00:30 - 04:00 04:00 - 05:00 05:00 - 07:30 07:30 - 09:45 09:45 - 12:00 0.751 DRILL (TRIP PROD2 1.75 DRILL TRIP PROD2 1.00 DRILL TRIP PROD2 0.25 DRILL OTHR PROD2 0.75 CASE RURD CMPLT2 0.50 CASE SFTY CMPLT2 3.50 CASE PULR CMPLT2 1.001 CASE I PULR I CMPLT2 2.50 I CASE I RUNL I CMPLT2 2.251 CASE RUNL CMPLT2 2.251 CASE I RUNL I CMPLT2 12:00 - 14:00 2.00 CASE RUNL CMPLT2 14:00 - 15:45 I 1.75 i CASE I CIRC I CMPLT2 15:45 - 16:30 0.75 CASE OTHR CMPLT2 16:30 - 17:30 i 1.001 CASE I CIRC I CMPLT2 Page 19 of 33 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations Dispalce well with 9.0 PPG SFMOBM @ 121 SPM, 432 GPM"S, w/ 2500 PSI. Reciprocate drill string while displacing. After dispalcement 275K , 35K dn, rot wt = 124K, TO = 23-25K with pumps off. Obtain slow pump rates. POOH on elevators from 15667' - 14356' (1311') Observe hole clean, no swabbing. Continue POOH on elevators from 14356' - 90' (14266') Observe hole clean, no swabbing. Lay down Ghost Reamer. Breakout & lay down bad Lo-Tads off of stand # 92 , 90, 86, and 84. Serial #'s = 260856, 258285, 260862, and 260840. Held Pre- Job Safety Meeting with Crew. Removing radioactive sources form BHA .Pull sources from assembly, secure and lay down same. Stand back 1 stand NMDC's. Plug into MWD, and download. POOH lay down remaining BHA. Breakout Bit, inspect and gauge same. Bit gauge = 0/0/NOlA/X!I/NO/TD Clear & Clean floor area. Rig up to run 5 1/2 15.5#, L-80 slotted liner assembly with Baker "HR" liner setting sleeve. RU tongs, slips, and change out elevators. Held PJSM with entire crew. (Picking up 5 1/2 slotted liner assembly) Make up Guide shoe jnt, and Insert jnt. Continue RIH picking up 138 jnts of 5 112" blank -slotted liner assembly. Ran a total of 69 Blank jnts ( 2935.51') and a total of 69 Slotted jnts (2893.99') with (10) 2.5" long x 1/8" wide,4 circumferential rows, 40 slots per foot. Ran total of 137 5-1/2" x 8" Centralizers, Liner was drifted to 4.825". Liner connections w/ torque rings, and a total of 14 constrictors @ depths of 14959', 14708', 14208', 13959',13459', 13208', 12709', 12461', 11959', 11561', 11108', 10859', 10408', and 10159', when landed. Make up 1 jnt 7" 26#, with 5 1/2" 15.5# XO jnt. Make up Baker "HR" setting sleeve with a 7" 26# pup and running tool, ball seat assembly crossed over to 4 1/2 IF for Drill. pipe. Liner weight = 85 K up, 55K down TIH with 5 1/2 liner assembly to TOW @ 9700'. 140K up, 65K dn. Rot wt = 86K, w/ 20 RPM's 9K TO, 40 Rpm's 8K TQ Continue TIH with 5 1/2 Liner, obtaing torque and drag parameters. At 10297' -rot wt = 86K, 20 Rpm's -10K TO, 40 Rpm's - 10K TO. At 10784' -rot wt = 86K, 20 Rpm's - 11 K TO, 40 Rpm's - 13K TO. At 11169' -rot wt = 85K, 20 Rpm's -11 K TO, 40 Rpm's - 12K TO. At 12114', rot wt = 80K, 20 Rpm's - 13K TO, 40 Rpm's 15K TO. Fill DP every 20 stands. Stopped at 12626'. No issues running through window. Rotate 5 1/2" liner down from 12626' - 14054' (1428'). Rot Wt = 65K, 20 Rpm's 16K Average running speed = 20 tt per minute. Continue Rotate 5 1/2" liner in hole from 14054' - 15675' (1621'). 250K up, 40K dn, and 115K rot wt. 19K TO at 20 Rpm's. Landed 8.71' lower in well. Drop ball in Dp, and allow to fall while pumping down DP @ 3 BPM, 250 PSI. 2 BPM @ 150 PSI. Ball landed. Pressure up Dp to 1900 PSI to release from 5 1/2" Liner. Continue to pressure up to 3300 PSI to shear ball seat. POOH to 9700' (above TOW @ 9706') 5 1!2" Liner top at 9787.86'. Circulate Bottoms up @ 8.3 BPM, 1000 PSI. 225K up, 80K dn, rot wt Printed: 10/28/2005 10:29:27 AM • ConocoPhillips Alaska Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Operations Summary Report 1E-117 1E-117 ROT -DRILLING Date From - To Hours Code Code Phase 7/23/2005 16:30 - 17:30 1.00 17:30 - 21:45 4.25 21:45 - 22:00 ; 0.25 22:00 - 22:15 I 0.25 22:15 - 00:00 1.75 7/24/2005 ~ 00:00 - 04:00 ~ 4.00 04:00 - 05:30 1.50 05:30 - 07:15 1.75 07:15 - 08:15 1.00 08:15 - 08:30 0.25 08:30 - 12:00 3.50 12:00 - 14:30 2.50 14:30 - 15:45 1.25 15:45 - 17:30 1.75 17:30 - 18:30 1.00 18:30 - 20:45 2.25 20:45 - 00:00 i 3.25 7/25/2005 00:00 - 02:45 02:45 - 03:15 2.75 CASE CIRC CMPLT2 CASE OTHR CMPLT2 CASE RURD CMPLT2 WINDO ULD CMPLT2 WINDO ULD CMPLT2 WINDO RIP CMPLT2 RIGMNT RSRV CMPLT2 WINDO RIP CMPLT2 WINDO IRC CMPLT2 WELCT OBSV CMPLT2 WINDO RIP CMPLT2 WINDO RIP CMPLT2 WINDO ULD CMPLT2 WINDO ULD CMPLT2 CASE OTHR CMPLT2 CASE PUTB CMPLT2 CASE RUNL CMPLT2 CASE RUNL CMPLT2 0.50 i CASE ~ RUNL CMPLT2 Page 20 of 33 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations = 133K @ 20 Rpm's and 15K TO Monitor well. Static. POOH from 9700' -surface. On TOH, breakout & lay do Bad Lo-Tads. Pins coming out, rollers flat. Stnd # 63, serial # 258260, Stnd # 49, serial # 258313, and Stnd # 38, serial # 258291. Lo-Tad lengths= 3.80' ea. Pin size on Lo-Tads = 3/8" x 2' long. We left 1 pin in hole. Total layed down = 11.40' from DP tally. Inspect remaing Lo-Tads on TOH. Breakout, lay down & inspect running tool. Small marks on running tool indicated set down on top of liner after released from liner. Clean floor area, and pull tools to floor. PJSM, with crew. (Picking up BHA) Make up Whipstock retrieving BHA as per BOT Rep. Make up Hook (8.30'), 1 -JNT HWDP(30.86'), Float sub(2.47'), 6 1/4" Bumper Jar(8.70'), 6 1/4" Oil jar(11.53'), Pump Out sub(2.02'), 3 x 6 1/4" Drill Cotlars(92.13'), and 1 - Stnd of 5" HWDP(92.42'). Total lenght of BHA = 248.43' TIH with Whipstock retrieving assembly From 248' - 9638' (9390') Fill pipe every 20 stands. Slip & cut Drilling Line. Service TD. replaced Hydaraulic fitting on TD. Continue RIH F/ 9638' - 9722' (84') to position wash slots on Hook at slot in whipstock @ 9712'. Wash slot at 6-7 BPM, - 750 PSI. 210K up, 80K dn. Hook window and pull to 265K to allow jars to bleed open, and continue staright pull to 275K to observe BTA shear and pulling seals from lower liner top. Pull up to 9666', 225K new up weight. Circulate Bottoms up @ 96 SPM, 1100 PSI. No gas. 13 BBL loss. Monitor well, static. POOH with whipstock assembly, observe no swabbing. 118K upweight. Continue POOH with whipstock assembly to whipstock. Hang in clamp on rig flloor. Breakout and lay down whipstock retrieving assembly. Layed down Hook, 1 JNT of 5" HWDP, Float sub, 6 1/4" Bumper Jar & Oil Jar, Pump out sub, 3 - 6 1/4" drill collars, and 1 stand of 5" HWDP. Breakout and lay down whipstock assembly. Inspect whipstock. Layed down Whipstock Slide, Debris barrier cup and sub, drain sub, Shear disconnect, BTA, Blanking sub, 20 JNTS of 5" DP, 1-Flex joint, 1 JNT of 5" DP, Unloader Valve, Crossover sub, Locator sub, and seal assembly. Note: We recovered the lost Lo-Tad pin in the debris barrier cup. Clean & clear floor area. Pull tools to rig floor. PJSM with entire crew and BOT rep. Make up Hook hanger assembly. Picked up 1 JNT 5 1/2" L-80 BENT blank casing, (42.25'), 5 1/2" Pup (5.96'), 5 1/2" Pup (10.09'), Baker Payzone External Casing packer with pups (2.20',23.66' PKR, 6.60'), 5 12/" Pup (10.10'), Model B-1 Hook Hanger assembly with Crossover & pups (4.12',1.33', 27.38'). Make up Crossover to 4 1/2 IF for DP. and Baker running tool. RIH w/ Drill Pipe from derrick at a running speed of 90 ft /minute, as per BOT rep. Continue RIH w/ Hook assembly w/drill pipe from 5920' - 10420' 4500') at a running speed of 90 ft /minute, as per BOT rep. Tag Main Bore Crossover in seal bore at 10420'. We did not go into "B" lateral on first try. POOH back to 9680'. Printed: 10/28/2005 10:29:27 AM • ConocoPhillips Alaska Page 21 of 33 Operations Summary Rep©rt Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase 7/25/2005 103:15 - 04:45 ~ 1.50 ~ CASE ~ RUNL ~ CMPLT2 04:45 - 06:00 I 1.251 CASE I CIRC I CMPLT2 06:00 - 06:30 0.501 CASE SFTY CMPLT2 06:30 - 07:30 1.00 CASE MIT CMPLT2 07:30 - 08:15 I 0.75 I DRILL I TRIP I CMPLT2 08:15 - 08:30 0.25 WELCT OBSV CMPLT2 08:30 - 12:00 3.50 DRILL TRIP CMPLT2 12:00 - 12:30 0.50 DRILL TRIP CMPLT2 12:30 - 13:15 0.75 CASE RURD CMPLT2 13:15 - 14:15 I 1.00 CASE ~ RURD CMPLT2 14:15 - 14:45 0.50 RIGMNT RSRV CMPLT2 14:45 - 16:45 2.00 CASE PULR CMPLT2 16:45 - 17:15 I 0.50 I CASE I PULR I CMPLT2 17:15 - 23:30 I 6.25 I CASE I RUNL I CMPLT2 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of ©perations Turn drill string 5 1/2 RH turns to orient bent joint to go through window. Slack off to to observe hooked hanger @ 9727.79'. (5.79' below original window cut) Pull up and un-hook hanger, rotate 1/4 RH turn increments to RIH and tag crossover in TOL @ 9845.88'.(1.98' low), and verify Hook depth. Hooked and Re-hooked a total of 4 times, to finally set @ 9727.79'. Set down 40K on Hook. 215 K up, 75K do Drop 29/32" ball, With Rig, pump to seat 800 stks @ 3 BPM - 325 PSI, 2 BPM -200 PSI. Total of 2311stks to seat ball. Pressure to 450 PSI. and line up to hold pressure on DP. Hold PJSM with entire crew and Schlumberger. Discuss pressure test and procedure of pumping. Line up Pump truck to DP. Pressure test lines to 3500 PSI. Good test. Pressure up to 1000 PSI, Hold 2 min. Check tank level. Pressure to 1500 PSI, Check tank level. Continue pressure up in 200 PSI increments to observe ECP inflate at 2695 PSI. Pressure bled back to 1700 PSI. Held Pressure 5 min. Bled pressure to 500 PSI. Check tank level, observed .45 BBLS to inflate ECP. Bleed all pressure off. Job went very well. Pull up off of Hanger to 9700'. (27') CBU @ 180 SPM, 2900 PSI. 215K up, 80K do wt. Monitor well. Static. POOH from 9700' - 2167' (7533'). Inspect for failed Lo-Tads Continue to POOH from 2167' -surface. Lay down entire Hook Hanger running tool assembly. Visually inspect same. Clean and clear Rig Floor. Lay down all runnng tools. Service Top Drive, and inspect threads. PJSM with entire crew. Pull tools to floor, and RU to run LEM assembly. Make up 4 1/2" Baker Seal assembly (3.29') on 1 jnt of 4 1/2" IBT x STL 12.6# L-80 tubing, (43.67'), Seals = 4.73" x 3.87" ID. Make up &RIH w/ 21 jnts of 4 1/2" IBTM 12.6# L-80 tbg, (615.72'). Collar OD = 5.21" x 3.958". Make up Camco "DB" nipple assmy. 4 1/2" IBT tbg pup (5.88'), DB Nipple (1.52') with an ID of 3.563" and profile of 5.21"., 1 jnt 4 1/2" IBT tbg (30.23) 21 jnts of tbg total ran. Make up LEM assembly. Pick up LEM Inside Hook Hanger (22.90') 7.69" x 3.688". MU LEM Above Hook Hanger (12.40') 8.49" x 3.98", 4 1/2" IBT tbg pup (3.80') 5.20" OD x 3.98" ID, 4 1/2 "Casing Swivel, 12.6# IBT (2.52') OD 5.75" x 3.96" ID. Crossover Bushing 5 1/2" Hydril 563 x 5 12/" IBT (1.40') OD 6.03" x 4.75" ID, 190-47 Casing Seal Bore Receptacle (19.45') OD 6.26" x 4.75" ID, Crossover 7" x 5 1/2" Hydril 563 (1.14') 7.67" OD x 4.94" ID, ZXP Liner top PKR 7" x 9 5/8" w/ HRD profile (18.50') OD 8.49" x 7.5" ID, and Baker Hydraulic setting tool 5.10'), and Baker running tool (5.42'). Trip in hole Lem assembly from 792' - 10430' (9638'). Running speed of 60-80 Ft /Min as per BOT rep. Observe seals going into SBR @ 10420' and continue RIH to latch up to Hook Hanger @ 9706.69', Top of ZXP PKR @ 9647.48'. 220K up, 82K do wt. Pull 10K over to verify latch up. Layed down bad Lo-tads off of Stand # 37 (ser#258293), Stnd # 39 (ser#258289), Stnd # 43 (ser#258290), Stnd # 44 ser#258294), Stnd# 46 (ser#258262), Stnd# 48 (ser#258263), Stnd# 51 (ser#258266), Stnd# 52 (ser#258259), Stnd# 54 (ser#258372), Stnd# 55 (ser#258256), and Stnd# 57 (ser#258315). 11 Total layed down on trip. Printed: 10/28/2005 10:29:27 AM • ConocoPhill~ps Alaska Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code i Code Phase 7/25/2005 17:15 - 23:30 6.25 CASE RUNL CMPLT2 23:30 - 00:00 0.50 CASE RURD CMPLT2 7/26/2005 00:00 - 01:00 1.00 CASE DEOT CMPLT2 01:00 - 01:30 01:30 - 02:30 02:30 - 10:30 10:30 - 11:00 11:00 - 12:00 12:00 - 12:30 12:30 - 16:30 16:30 - 17:00 17:00 - 21:45 21:45 - 00:00 7/27/2005 00:00 - 02:45 02:45 - 07:30 07:30 - 12:00 12:00 - 14:30 14:30 - 15:30 0.50 CASE ~ DEQT ~ CMPLT2 1.00 I CASE I CIRC I CMPLT2 8.001 CASE I OTHR I CMPLT2 0.50 ~ CASE OTHR CMPLT2 Page 22 of 33 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations Rig up lines to pump down DP and utilize rig test pump if neccessary. Line up to record on chart. Continue to Rig up lines to pump down DP and utilize rig test pump if neccessary. Line up to record on chart. Drop 1 3/4". Using Rig pump, pump ball do to seat at 3 BPM- 300 PSI. Ball on seat @ 1550 STKS. Pressure to 3000 PSI, then stage pressure up to 4200 PSI to set ZXP Liner Top PKR @ 9647.48' DPM. Pull up 10' to release from PKR and verify set. PJSM, Discuss pressure test and procedure. Close annular and pressure test down annulus to test ZXP @ 1000 PSI. Record on chart and hold 10 minutes. Good test. Rig down test equipment. POOH, lay do 2 - 10; 5" DP pups, and screw into TD. 220K up, 82K do wt. CBU @ 180 SPM, 630 GPM's - 2900 PSI. Monitor well, Static. POOH, Breakout & lay down all Lo-Tads. We shipped out a total of 61 bad Lo-Tads. The 10 Lo-Tads on HWDP were kept on location for re-use as they are in good shape. Note: Bad Lo-Tads consisted of pins falling out, and rollers being "flat". Make service breaks on Running and Setting tools, and lay down same. 1.00 WELCTL~ BOPE CMPLT2 BOLDS, Pull wear bushing. Install Test plug. RILDS. RU test pump. 0.50 WELCT BOPE CMPLT2 Continue RU test pump and equipment to test BOP's. 4.00 WELGT ROPE CMPLT2 Tested BOPE, tested rams, valves and manifold to 250 psi low and ' 3,000 psi high, tested annular to 250 psi then 2,800 psi. Test i Accumulator. Chuck Sheave with AOGCC waived witnessing testing, RD test equip. and installed wear bushing. RILDS 0.50 WELCT BOPE CMPLT2 RD test equipment, and pull tools to floor. 4.75 WINDO ULD PROD3 Make up Whipstock Assembly with Space out drill pipe. MU BOT seals (3.43'), Locator sub (1.87'), Crossover 3 1/2 IF x 4 1/2 IF (1.57'), Unfoader sub pinned for 60K Shear (6.47'), 7 - JNTS 5" Space out pipe. (216.78'), Blanking sub (1.57'), 9 5/8" Bottom Trip anchor (2.81'), Shear Disconnect sub 120k Shear (2.73'), Ported Drain sub (1.49'), Debris barrier sub w/ Cup (1.59'), 9 5/8" Windowmaster Whipstock (18.98'), 8" Starting Mill (1.55'), 8" Lower Mill (5.67'), 8.510" Upper Mill (6.17'), 1 - JNT 5" HWDP (30.74'), Float Sub (2.47'), MWD Assmy (42.62'), 6 1/4" Bumper Jar (8.70'), 6 - 6 1/4" Drill Collars (184.48'), 13 -stand 5" ~ HWDP (1194.60'). Totat BHA with Whipstock = 1732.85'. Total BHA withou Whipstock = 255.86'. Orient MWD to High side face of Slide. Pulse test MWD assmy, good. Shear Bolt = 45K 2.25 WINDO ULD PROD3 Trip in hole w/ 9 5/8" Whipstock assembly from 1732' - 2670'. (938') 105K up, 65K do wt. 2.75 WINDO RIP PROD3 Continue to TIH from 2670' - 6622' (3952') 90 seconds to 2 minutes per stand as per BOT rep. PU = 160K, SO WT = 53K 4.75 WINDO RIP PROD3 POOH, after deciding we didn't have enough downweight to shear off and mill window. POOH, from 6622' - 722' (5900') POOH 90 seconds ~ per stand. Reposition HWDP in assembly. 4.50 WINDO RIP PROD3 TIH with 9 5/8" Whipstock Assembly. from 722' - 4835' (4113'). 90 seconds to 2 minutes per stand as per BOT rep. PU = 110K, SO WT = 55K. Install Lo-Tads on stands # 10,13,16,19,22,25,28,31,34, and 37. Installed a total of 10 Lo-Tads. 2.50 WINDO RIP PROD3 Continue to TIH from 4835' - 8790'. (3955'). 90 seconds to 2 minutes per stand as per BOT rep. 1.00 WINDO RIP PROD3 Perform MADD PASS to K-13 for depth check. From 8790' - 8895' Printed: 10/28/2005 10:29:27 AM • Con©coPhillips Alaska Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours '' Code Code Phase 7/27/2005 14:30 - 15:30 ,15:30 - 15:45 15:45 - 16:15 16:15 - 19:15 19:15 - 20:00 0.75 W I 20:00 - 21:45 1.75 W I 1.00 WINDO RIP PROD3 0.25 WINDO RIP PROD3 0.50 WINDO ETW PROD3 3.00 WINDO ETW PROD3 21:45 - 22:15 0.50 W I 22:15 - 00:00 1.75 WI 7/28/2005 00:00 - 00:45 0.75 WIN 00:45 - 02:00 ~ 1.25 WIN 02:00 - 02:45 0.751 WIN 02:45 - 10:15 7.50 WIN 10:15 - 11:00 I 0.751 WIN IRC PROD3 ETW PROD3 ETW PROD3 ETW PROD3 ETW PROD3 ULD PROD3 ULD PROD3 ULD PROD3 ULD PROD3 Page 23 of 33 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations (105'). Continue TIH with Whipstock assembly from 8895' - 9644' (749'). PU = 215K SO WT = 68K. RIH to 80' above top of ZXP liner top. Orient 9 5/8 Whipstock face to 12 Degrees left of High side As per Directional Driller and plan. PU = 215k, SO Wt = 68K Slack off to observe Seals going into top of ZXP liner top (3') and set down to 35K to Set BTA. Pull up to 10k over to verify BTA set. PU = 215K , SO WT = 68K. Slack off to 35K to Shear bolt, set for 45K shear. Repeat 3 times. Pull up to neutral position at 160K and attempt to rotate free. NOT free. Continue to work 5 Right Hand turns into drill string, and work torque down to bolt, by slacking off to 35k, and max pull to 215K. Repeat numerous times. No free rotation. Continue attempts to turn free with a max torque of 20,000 ft/Ibs, and pumps at 450 GPM's, 1970 PSI. NOTE: MWD tool face readings indicated 155 degrees left of high side, and holding. We suspect starting mill pinched off in casing, not releasing torque back. Dispalce well from SFMOBM to MOBM at 525 GPM's and 2500 PSI. The decision was made to displace at this time to have the added lubricityin the MOBM possibly help in torque, up/down weights as well as transfer torque to bottom of assembly. This was a planned operation and trucks were ready. Continue attempt to rotate free by working torque to bottom of hole. Observed Bumper Jar movement at 225K UP, and 75K down. Decision from town to MAX Pull to 70K over. We pulled to 285K. Repeat, numerous times. NOTE: The BTA is designed to release @ 60K overpull. The shear disconnect is designed to release with a 120K overpull. We positioned the string in neutral position. Free rotation was obtained by rotaing to a max torque of 28K. Observed 100 RPM's 20K free torque, and we rotated only for 1/2 minute. Stopped Rotation. Discuss options with town, and it was decided to continue with planned operations, start milling. Circulate @ 500 GPM 'S, 2900 psi, no rotation or reciprocating string. String in neutral position, while wait on decision. Attempt to re-establish free rotation. Repeat procedures as above, and could not gain rotation again. This procedure was repeated numerous times, changing variables such as pump speeds, and trying to find the neutral position again. PU WT = 215K SO WT = 68K. Continue Attempt to re-establish free rotation. Repeat procedures as above, and could not gain rotation again. This procedure was repeated numerous times, changing variables such as pump speeds, and trying to find the neutral position again. PU WT = 215K SO WT = 68K. Discuss options with town rig engineers. . Decision to POOH with Whipstock assembly. Work drill string in increments of 25K, working up to a MAx pull of 425K. 75K Down. Assembly pulled free at 410K, and we pulled up hole 60'. Note: BTA designed to release with 60K overpull. Shear disconnect designed to release at 120K overpull. 210K UP WT. , 75K DN WT. POOH, with 1 stand HWDP, and lay down 1 single. Monitor well for swabbing. Hole taking fluid. Up WT = 215K. Pump Dry Job. POOH from 9554' - 88' (9466'). Lay down 10 Lo-Tads to reposition them on next TIH. Lay down MWD assembly, Bumper Jar, Float Sub, and drain BOP stack. Clean & clear floor area. Printed: 10/28/2005 10:29:27 AM • Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code 7/28/2005 11:00 - 11:30 0.50 W I N 11:30 - 12:00 0.50 WIN 12:00 - 12:15 0.25 WIN 12:15 - 12:45 0.50 WIN 12:45 - 13:30 0.75 WIN 13:30 -18:45 5.25 18:45 - 20:45 2.00 20:45 - 22:30 1.75 22:30 - 00:00 1.50 7/29/2005 00:00 - 02:45 2.75 02:45 - 03:45 1.00 03:45 - 04:30 ~ 0.75 04:30 - 05:30 1.00 05:30 - 12:00 6.50 ConocoPhillips Alaska Operations Summary;Report Page 24 of 33 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Sub !phase Description of Operations Code:. iPULD PROD3 PJSM, with entire crew, and BOT reps. Discuss procedure to strip Whipstock assembly through BOP stack & rotary table considering it may be sheared. Discuss rigging up a 25' JNT of 9 5/8" 40# casing. "*' Special Note "**"' CPF 1 ask us to take the Rig off Hi Line @ 11:00 AM. May be off for 8 to 10 days ?? iPULD PROD3 Pick up 1 JNT of 9 5/8" 40# casing cut to a lenght of 25', with tugger, and strip it over 1 JNT of 5" HWDP hanging in blocks. MU HWDP to string hanging in slips. 'PULD PROD3 Pull Milling Assembly to floor through 9 5/8" casing. We did not have tfie whipstock assembly. Clean & Inspect mills. Starting mill showed damage on OD. Indicatiions mill was pinched and pulled by brass pad on slide, and casing drag marks. Broken buttons and damged carbide. Pictures were taken and sent to town. 'PULD PROD3 POOH, lay down 9 5/8" casing jnt. Lay down remaing Mill assembly. Layed down 8" Starting Mill (1.55'), 8" Lower mill (5.67'), 8.510" Upper Mill (6.17'), and 1 -JNT 5" HWDP. rTRIP PROD3 Pick up Whipstock retrieving assembly. Retrieving Hook (8.3'), 1 -JNT 5" HWDP (30.74'), Float Sub (2.47'), MWD assembly (42.62'), 6 1/4" Bumper Jar (8.70'), 6 1/4" Oil Jar (11.53'), Pump Out Sub (2.02'), 3 - JNTS 6 1/4" Drill Collars (92.13'), 2 -Stands 5" HWDP (184.03'). Orient MWD to whipstock hook. DRIP PROD3 TIH from 416' - 9315' (8899'). Pulse test MWD, Inspect saver sub on Top Drive. Pick up 9 Lo-Tads on TIH. Lo-Tads on Stands #10 (ser#260830), #13 (ser#260851), #16 (ser#260854), #19 (ser#260832), #22 (ser#260852), #25 (ser#260833), #28 (ser#260837), #31 (ser#260861), #34 (ser#260813), and #37 (ser#260819). PU WT = 175K, SO WT = 78K. 'SETW PROD3 Orient Hook to 12 Degrees left of High Side. Attempt to engage WHipstock slot @ 9396'. Could not get over top of Whipstock with Hook. Tag top of whipstock @ 9390'. Orient Hook to 180 Degrees opposite @ 177 Deg Right. Slack off to below top of whipstock and re-orient Hook to 19 Deg left. Hook Slide and pull up to 205K (25K over) to verify catch. Pump up MWD surveys to verify whipstock still set, and oriented to 19 degrees left of high side. 530 GPM's 2840 PSI. Directional Driller confirmed orientation, and satisfied. Un-Hook from whipstock, and pull up to 60' over top of slide to verify free. 180K PU WT, 70K SO WT. TRIP PROD3 Monitor well, Static. Pump dry job. Obtain parameters. 195K PU WT, 83K SO WT, ROT WT = 120K, 80 RPM's, 13 -15K Free Torque. 530 GPM's, 2840 PSI. POOH from 9390' - 6910' (2480'). PU WT = 150K SO WT = 62K RSRV PROD3 ~ Slip & Cut Drilling Line. Service Top Drive. TRIP PROD3 Continue POOH from 6910' - 198' (6712'). Observe proper hole fill. TRIP PROD3 Breakout & Lay down BHA. Layed down 3 - JNTS 6 1/4" Drill collars 92.13'), Pump out sub { 2.02'), 6 1/4" OiI Jar (11.53'), 6 1/4" Bumper Jar (8.70'), MWD assembly (42.62'), Flaot Sub (2.47'), 1 -JNT 5" HWDP (30.74'), Retrieving Hook (8.3'). TRIP PROD3 Clean & clear Rig floor. Pull tools to floor. TRIP PROD3 MU Whipstock Milling BHA. MU GEN 2 window mill (1.24'), 8" Lower mill (5.67'),8.510" Upper Mill (6.17'), 1 -JNT 5" HWDP (30.74'), Float Sub (2.47'), 6 1/4" Bumper Jar (8.70'), 3 - 6 1/4" Drill Collars (92.13'), and 3 -Stands 5" HWDP (275.59'). TRIP PROD3 TIH with Milling BHA, 38 Stands S-135 DP. Make Up Lo-Tads on Stand Printed: 10/28/2005 10:29:27 AM • ConocoPhillips Alaska Page 25 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations 7/29/2005 05:30 - 12:00 6.50 WINDO~RIP PROD3 12:00 - 13:30 1.50 WINDO RIP PROD3 13:30 - 19:30 ~ 6.00 WINDOVVOTHR PROD3 19:30 - 20:00 0.501 WINDOVVCIRC PROD3 20:00 - 20:30 0.50 WINDO IRC PROD3 20:30 - 00:00 3.50 WINDO RIP PROD3 7!30/2005 00:00 - 00:15 0.25 WINDO~RIP PROD3 00:15 - 01:00 0.75 WINDO RIP PROD3 01:00 - 01:30 0.50 WINDO RIP ~ PROD3 01:30 - 02:30 1.00 WINDO THR PROD3 02:30 - 03:30 ~ 1.001 DRILL PULD PROD3 03:30 - 03:45 0.25 DRILL DEOT PROD3 03:45 - 07:15 3.50 DRILL TRIP PROD3 07:15 - 08:00 0.75 DRILL TRIP PROD3 08:00 - 10:30 I 2.50 I DRILL I DRLG I PROD3 10:30 - 11:45 I 1.25 I DRILL I TRIP I PROD3 11:45 - 12:00 0.25 DRILL OBSV PROD3 12:00 - 15:45 3.75 DRILL TRIP PROD3 15:45 - 17:30 I 1.751 DRILL I PULD I PROD3 #39. TIH from 422' - 7036'. (6614'). Continue TIH with Milling Assembly from 7036' - 9390' (2354') installing Lo-Tads. Installed a total of 42 Lo-Tads on Stands #39 - #80. PU WT = 168K, SO WT = 87K, Rot WT = 115K. Mill Wlndow from 9390' - 9422' (32'). Milled 16' window in 3.8 HRS. AVG ROP = 4.2 Ft per hour. Milled open hole in .63 HRS AVG ROP = 25.26 Feet per hour. Total milling time = 4.83 hrs. AVG Milling Time Total = 6.62 Feet per hour. Avg Torque in window area = 15K - 17K. 90 RPM's. Mud weight = 9.0 PPG MOBM. YP = 18 VISC = 83. PU WT = 168K SO WT = 87K. Pumps at 500 GPM's 2000 PSI. WOB = 2K - 10K. Milled to ensure 5' of 8 1/2" gauged hole beyond slide. Work drill string to dress window area until clean. Pumping. Hi-Visc sweep. @ 500 GPM's - 2000 PSI. 168K PU WT, 87K SO WT, 90 RPM's TQ = 12-13K Continue circulate sweep out of hole. 670 GPM's - 3300 PSI. Obtain Slow pump rates. 30 SPM - 280 PSI 40 SPM - 270 PSI. Pump #1. Monitor well. Static. Pump Dry Job. POOH from 9390' - 2422' 6968') PU WT = 182K SO WT = 92K TOH pipe displacement 1.1 bbls difference from calculated. Continue POOH with window milling assembly from 2422' - 422' (2000') Breakout & Lay down Whipstock Milling BHA. MU GEN 2 window mill 1.24'), 8" Lower mill (5.67'),8.510" Upper Mill (6.17'), 1 - JNT 5" HWDP ( 30.74'), Float Sub (2.47'), 6 1/4" Bumper Jar (8.70'), 3 - 6 1/4" Drill Collars (92.13'), and 3 -Stands 5" HWDP (275.59'). Gauge mill to full 8 1/2". Mills looked good. Clean & clear floor area, pull tools to floor. BOLDS, Pull wear bushing. Make up tools and flush stack. Install wear bushing. RILDS. Make up BHA #15, 8 1/2" Drilling assembly. PU 8 1/2" Roller cone Insert Bit (1.00') (TFA = .746), 7" Sperry drill lobe 7/8 - 6.0 stage motor (25.10'), Non-mag Float sub (2.50'), 6 3/4" MWD DM HOC (8.87'), 6 3/4" Gamma/Res (23.75), 6 3/4" TM HOC (10.0'), 3 - jnts Non Mag flex drill collars (91.54'), 1 -jnt 5" HWDP (30.76'), 6 1/4" Drilling Jar 30.38), and 4 -jnts 5" HWDP (123.28'). Pulse test MWD equipment at 450 GPM's, 1400 PSI. OK Trip in hove w/ Drilling assembly from 347' - 9377'. (9030'). Orient toolface to 12 degrees left of high side, to pass through window, down to 9422. Directional Drill 8 1/2" hole from 9422' - 9598'. (176'), to line up in "D" sand for Geo -Pilot Assmy. TVD = 3354'. AST = 1.49 HRS, ART = .3 HRS. ADT= 1.79 HRS. PU WT = 150K, SO WT = 95K, Rot WT = 95K. Torque on bottom = 13-14K, Off Bottom = 15-18K. Pumps @ 500 GPM's - 3000 PSI. Jars = 1.79 HRS POOH with drilling assembly from 9598' - 9377' (221'). Monitor well, static. Note: Wlndow at 9391' - 9407'. Pump dry job, flow check. Continue POOH from 9377' - 347' (9030'). Hole fill 9.0 BBIs more than calculated. Down load MWD. Breakout & Lay do BHA #15, 8 1/2" Drilling assembly. 8 1/2" Roller cone Insert Bit (1.00') (TFA = .746), 7" Sperry drill lobe 7/8 - 6.0 stage motor (25.10'), Non-mag Float sub (2.50'), 6 3/4" MWD DM HOC (8.87'), 6 3/4" Gamma/Res (23.75), 6 3/4" TM HOC (10.0'), 3 - jnts Non Mag flex drill collars (91.54'), 1 - jnt 5" HWDP Printed: 10/28/2005 10:29:27 AM • ConocoPhillips Alaska Page 26 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common W ell Name: 1 E-117 Event Nam e: ROT -D RILLING Contractor Name: Rig Name: Date From - To Hours ' Code ~' ~ ode ' _.__ Phase 7/30/2005 15:45 - 17:30 1.75 DRILL PULD PROD3 17:30 - 18:00 0.50 DRILL TRIP PROD3 18:00 - 19:30 1.50 RIGMNT RGRP PROD3 19:30 - 00:00 4.50 I DRILL PULD PROD3 7!31/2005 00:00 - 00:30 j 0.50 DRILL TRIP PROD3 00:30 - 04:00 3.50 DRILL TRIP PROD3 04:00 - 04:30 0.50 DRILL REAM PROD3 04:30 - 12:00 7.50 DRILL DRLG PROD3 I a 12:00 - 00:00 12.00 ~ DRILL i DRLG PROD3 8/1/2005 00:00 - 12:00 12.00 DRILL I DRLG PROD3 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations ( 30.76'), 6 1/4" Drilling Jar (30.38), and 4 -jnts 5" HWDP (123.28'). Bit Gauge=l/I/WT/A/E/I/NO/BHA Clean floor area, lay do tools, pull tools to rig floor. Change ou saver sub on Top Drive. Measure ID of Rotary table., = 27 1/2". ID of wear bushings = 10 3/4". Service Top Drive. MU 8 1/2" Geo -Pilot drilling assembly. PU 8 1/2" PDC FMF2643 w/ 1.118 RP, Ser# 5012193RW (TFA = 1.666)(1.60'), 7600 GEO-Pilotw/ top motor stabilizer (23.22), Non MAg GP Flex pony collar (9.21'), Smart Stabilizer (2.20'), 6 3/4" MWD - GR/RES/PWD (21.01'), Smart stabilizer( 1.96'), 6 3/4" MWD HCIM (6.94'), 6 3/4" MWD - NEU !DEN 29.92'), 6 3/4" TM HOC (10.0'), Non mag Float sub (2.50), 3 -Non mag Flex drill collars (91.54'), 1 - Jnt 5" HWDP (30.76'), Drilling Jars 30.38'), 4 -JNTS 5" HWDP (123.28'), 16 - 5" Slick DP (508.02), 8 1/2" Ghost Reamer (6.97'), 48 -JNTS 5" SLick DP (1427.84'), and a 8 1/2" Ghost Reamer (6.95'). Pulse test MWD @ 525 Gpm's- 1050 PSt. , Upload, and break in GEO bearing. PJSM W/ entire crew. Install radioactive sources in drilling assembly. Contininue to make up BHA to 385'. TIH w/drilling assembly from 385' -9521' (9136'), picking up Ghost reamers in BHA @ 508' & 1428'. Fill drillstring @ 2779',5130',7491',and 9327'.. Continue TIH to 9521'. No issues passing asembly through window @ 9391'-9407'. Wash & Ream down from 9521' -9598' (77'). Observe clean hole. Pumps @ 500 GPM's - 2500 PSI PU WT = 150K, SO WT = 72K, ROT WT = 93K. TQ = 14-15K Directional Drill 8 1/2" hole in the "D" sand from 9598' - 9865' (267'). TVD = 3340'. Drill through Concretion @ 9531' - 9537' (6'). ADT = 5.52 HRS. PU WT = 175K, SO WT = 60K, ROT WT = 90K. TQ on BTM = 15-20K, TQ off BTM = 15-18K, @ 130 RPM"S. JAR HRS = 7.31, 630 GPM's - 3400 PSI ECD = 10.4 PPG. MW = 9.0 PPG YP = 23-25 MAX WOB = 5-15K Continue Directional Drill 8 1/2" hole in the "D" sand from 9865' - 10577' (267'). TVD = 3345'. Drill through 16 Concretions @ 9608' - 9615' (7'), 9645' -9654' (9'),9670' - 9678' (8'), 9688' -9700' (12'), 9708' - 9712' (4'), 9761' - 9765' (4'), 9795' - 9798' (3'), 9822' - 9826' (4'), 9860' -9872' (12'), 10041' - 10046' (5'), 10060' - 10072' (12'), 10282' - 10289' (7'), 10521' - 10524' (3'), 10540' - 10553' (13'), 10557' - 10563' (6'), 10558' - 10570' (12'). Total of 127' of concretions = 13% of drilled hole.. ADT = 7.86 HRS. PU WT = 200K, SO WT = 60K, ROT WT = 100K. TQ on BTM = 15-17K, TQ off BTM = 18-20K, @ 135 RPM"S. JAR HRS = 15.1, 635 GPM's - 3550 PSI ECD = 11.5 PPG. MW = 9.0 PPG YP -23-25. MAX WOB = 10-25K Observed Higher Torque up to 23K when 1st Ghost Reamer going through window. Directional Drill 8 1/2" hole in the "D" sand from 10577' - 10979' (402'). TVD = 3308'. Drill through 10 Concretions @ 10586' - 10595' (9'), 10602' - 10610' (8'), 10655' - 10670' (15'),10680' - 10691' (11'), 10730' ~ - 10745' (15'), 10790' - 10810' (20'), 10845' - 10862' (17'), 10890' - ~ 10914 (24'), 10930' - 10950' (20'), 10968' - 10979' (11'}. 150' Total Concretions = 38 % of drilled hole. ADT = 8.07 HRS. PU WT = 185K, SO WT = 50K, ROT WT = 85K. TQ on BTM = 15-22K, TQ off BTM = 17-18K, @ 130 RPM"S. Jars = 23..24 HRS Pumps at 622 GPM's - 3400 PSI ECD = 11.7 PPG. MW = 9.0 PPG YP = 23-25 MAX WOB = 10-30K Printed: 10/28/2005 10:29:27 AM r~ ConocoPhillips Alaska Page 27 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Coe Phase 8/1/2005 ~ 12:00 - 19:00 7.00 ~ DRILL ~ DRLG ~ PROD3 19:00 - 20:30 ( 1.501 DRILL I REAM I PROD3 20:30 - 00:00 I 3.50 I DRILL I DRLG I PROD3 8/2/2005 00:00 - 07:45 7.75 DRILL DRLG i PROD3 07:45 - 09:15 1.50 DRILL ~ DRLG I PROD3 09:15 - 09:45 0.50 ~ DRILL CIRC PROD3 09:45 - 14:15 4.501 DRILL DRLG PROD3 14:15 - 17:15 I 3.00 I DRILL I REAM I PROD3 17:15 - 17:45 0.50 DRILL PULD PROD3 17:45 - 19:45 2.00 DRILL TRIP PROD3 19:45 - 20:30 0.751 DRILL REAM PROD3 20:30 - 00:00 I 3.501 DRILL I DRLG I PROD3 8/3/2005 100:00 - 02:15 I 2.25 I DRILL I DRLG I PROD3 02:15 - 03:00 0.75 RIGMNT RGRP PROD3 03:00 - 14:15 11.25 DRILL DRLG PROD3 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations Continue Directional Drill 8 1/2" hole in the "D" sand from 10979" - 11479' (500'). TVD = 3287'. Drill through 2 Concretions @ 10990' - 11005' (15'), 11086' -11095' (9'). Total of 24' of concretions = 5% of drilled hole.. ADT = 4.91 HRS. PU WT = 185K, SO WT = 50K, ROT WT = 98K. TQ on BTM = 21-22K, TQ off BTM = 21 K, @ 130 RPM"S. JAR HRS = 29.14 HRS, Pumps @ 635 GPM's - 3500 PSI ECD = 11.62 PPG. MW = 9.0 PPG YP -23-25. MAX WOB = 10-25K Note: MWD Density tool stopped working at 9843' MD, and came back on @ 10663'. Lost - (820'). BROOH from 11479' - 10980' (499'), at drilling rate. Decision with town to pull back and sidetrack as per Geologist. Work drill string from 10980' - 10997', troughing hole to start sidetrack. TVD = 3307'. 135 RPM's 18K TO, 635 GPM's 3500 PSI. ECD @ 11.6 PPG WOB = 0-2K ADT = .99 HRS ""' Note'""` Deprature point 10,980' MD Directionally Drill 8 1/2" hole in "D" Sand lateral with Geo-Pilot from 10,997' to 11,479', (482') ADT 5.09 hrs Drilled 8 1/2" Hole in "D" sand lateral from 11,479' to 11,609' MD/ 3,291' TVD, (130') ADT .73 hrs, 8-15K wob, 110-130 rpm's, 180 spm, 640 gpm, 3,700 psi, off btm torque 22K ft-Ibs, on btm 18K ft-Ibs, rot wt 95K, up wt 185K, do wt 35K, (Blk Wt), 9.05 mw, ave ECD 12.0 ppg, ave bgg 70 units, max gas 656 units Circ hole and evaluated logs for geology Drilled 8 1/2" Hole in "D" sand lateral from 11,609' to 12,062' MD/ 3,284' TVD, (453') ADT 2.74 hrs, 5-12K wob, 130 rpm's, 178 spm, 630 gpm, 3,650 psi, off btm torque 22K ft-Ibs, on btm 19K ft-Ibs, rot wt 94K, up wt 205K, do wt 37K, 9.05 mw, ave ECD 12.0 ppg, ave bgg 175 units, max gas 807 units, (reed additional Lo-Tads) Backreamed out of hole at drlg rate from 12,062' to 10,487' to install additional Lo-Tads PU add. Lo-tads to rig floor RIH from 10,487' to 11,780' installing 1-Lo-tad per std, lost down wt at 11,780' Washed and reamed down from 11,780' to btm at 12,062', installed a total of 16 Lo-tads to 5" DP, (58 total in hole) having to rotate DP down to set slips Drilled 8 1/2" Hole in "D" sand lateral from 12,062' to 12,390' MD/ 3,280' TVD, (328') ADT 2.21 hrs, 5-10K wob, 130 rpm's, 176 spm, 625 gpm, 3,700 psi, off btm torque 20-22K ft-Ibs, on btm 18K ft-Ibs, rot wt 95K, up wt 200K, do wt 37K, having to rotate DP to set slips due to no slack off wt, 9.0 mw, ave ECD 12.1 ppg, ave bgg 70 units, max gas 135 units, Drilled a few small concretions after sidetracking well and no concretions since 11,200' Directionally drilled 8 1/2" hole in "D" sand lateral with Geo-Pilot from 12,390' to 12,665' MD/3,276' TVD (275') ADT 1.62 hrs Circ hole at a reduced rate while changing out valves and seats on #1 mud pump Drilled 8 1/2" Hole in "D" sand lateral from 12,665' to 13,561' MD/ 3,258' TVD, (896') ADT 7.28 hrs, 10-25K wob, 130 rpm's, 176 spm, 625 gpm, 3,825 psi, off btm torque 20-22K ft-Ibs, on btm 18K ft-Ibs, rot wt 98K, up wt 205K, do wt 35K, 9.05 mw, ave ECD 12.05 ppg, ave bgg 80 units, max gas 190 units, NOTE: A rubber boot on pump in rock washer failed Printed: 10!26/2005 10:29:27 AM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase 8/3/2005 ~ 03:00 - 14:15 11.25 DRILL ~ DRLG PROD3 8/4/2005 8/5/2005 8/6/2005 14:15 - 14:45 0.50 RIGMNT RGRP PROD3 14:45 - 00:00 9.25 DRILL DRLG PROD3 00:00 - 12:00 I 12.001 DRILL I DRLG I PROD3 12:00 - 17:00 5.00 DRILL DRLG PROD3 17:00 - 17:30 0.50 RIGMNT RGRP PROD3 17:30 - 22:00 4.50 DRILL DRLG PROD3 22:00 - 00:00 2.00 DRILL ~ WIPR PROD3 00:00 - 11:00 I 11.001 DRILL I WIPR I PROD3 11:00 - 15:00 I 4.00 LOG DLOG PROD3 15:00 - 17:00 2.00 DRILL WIPR PROD3 17:00 - 00:00 7.00 DRILL REAM PROD3 00:00 - 01:00 1.00 (DRILL REAM PROD3 01:00 - 03:15 2.251 DRILL CIRC (PROD3 03:15 - 04:45 ~ 1.501 DRILL CIRC PROD3 Page 28 of 33 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations causing 3.6 bbls of MOBM to spill inside secondary containment inside rig, had 1 gal leak onto the secondary containment outside of rock washer. Changed out swab on #2 mud pump Drilled 8 1/2" Hole in "D" sand lateral from 13,561' to 14,340' MD/ 3,236' TVD, (779') ADT 5.6 hrs, 5-10K wob, 130 rpm's, 173 spm, 615 gpm, 4,100 psi, off btm torque 22-23K ft-Ibs, on btm 19-20K ft-Ibs, rot wt 112K, up wt 250K, do wt 35K, (blk wt), still having to rotate DP to set slips due to no down wt, began running 5" HWDP at 13, 422' with no change in do wt, 9.05 ppg mw, ave ECD 12.3 ppg, ave bgg 90 units, max gas 170 units, drilled thru a few concretions last 24 hrs Directionally drilled 8 1/2" Hole in "D" sand lateral with Geo-Pilot from 14,340 to 15,195' MD/ 3,214' TVD, (855') ADT 6.62 hrs, 5-15K wob, 130 rpm's, 169 spm, 600 gpm, 4,100 psi, off btm torque 23-25K ft-Ibs, on btm 22K ft-Ibs, rot wt 100K, up wt with pumps on 205K, do wt 35K, (blk wt) 9.0 mw, ave ECD 12.3 ppg, ave bgg 70 units, max gas 160 units, Note: At 15,078' began taking torque readings with pumps on, still unable to get down wts without rotating Drilled 8 1/2" hole from 15,195' to 15,470' MD/ 3,208' TVD (275') ADT 2.67 hrs Circ hole with pump #2 while changing out swab on #1 mud pump Drilled 8 1/2" Hole in "D" sand lateral from 15,470' to 15,661' MD/ 3,208' TVD, (191') (T.D.) ADT 2.6 hrs, 5-15K wob, 120-130 rpm's, 162 spm, 575 gpm, 4,000 psi, off btm torque 26K ft-Ibs, on btm 25K ft-Ibs, with pumps on rot wt 95K, up wt 230K, do wt 35K, (blk wt) Drilled last 200' with directional only, no log data, ave bgg 50 units, surveyed at TD and monitored well-static. We were able to pump up a survey using 1 pump 360 gpm. Sperry said dropping the #2 pump lessoned the "pump noise" and a good siignal was received to pump up survey. Began backreaming out of hole to window, BROOH from 15,661' to 15,360', BROOH at 110 rpm's 25K ft-Ibs torque, 580 gpm at 4,100 psi Backreamed out of hole from 15,360' to 9,617' MD/ 3,352' TVD, BROOH at 110 rpm's, 176 spm, 625 gpm at 4,000 psi, no problems BROOH or packing off MADD pass for caliper log from 9,617' to 9,476', logged at 80 rpm's, 15-24K ft-Ibs torque, 159 gpm, 565 gpm at 2,500 psi, circ hole clean while logging. RIH from 9,476' to 11,453' when we lost all down weight Washed and reamed from 11,453' to 14,946', washed down at 80 rpm's, 15-22K ft-Ibs torque, 113 spm, 400 gpm at 2,150 psi, MU an additional 11 stds DP with Lo-Tads while RIH, 69 total Lo-Tads in the hole, attempted several times to RIH with no pump and still had no down wt. Washed and reamed from 14,946' to btm at 15,661', washed down at 80 rpm's, 20-23K ft-Ibs torque, 113 spm, 400 gpm at 2,300 psi Pumped 35 bbl weighted hi vis sweep and circ hole clean at 15,661', had no increase in cuttings back from sweep and circ a total of 2X btms up and was clean at shakers, circ at 572 gpm at 4,100 psi, 140 rpm's with 20-23K ft-Ibs torque, after adding Lo-tads and moving HWDP up hole, torque was down 4-5K ft-Ibs and had good MWD signal. Initial ECD was 12.3 ppg, max during sweep was 12.7 ppg and after circ hole clean was down to 12.0 ppg and no gas Displaced hole over from 9.0 ppg MOBM to 9.0 ppg SFMOBM, circ at Printed: 10/28/2005 10:29:27 AM • ConocoPhillips Alaska Page 29 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Co e ` Phase 8/6/2005 ~ 03:15 - 04:45 ~ 1.50 ~ DRILL ~ CIRC ~ PROD3 04:45 - 05:00 0.25 DRILL ~ OBSV PROD3 05:00 - 09:30 ~ 4.50 DRILL ~ TRIP PROD3 09:30 - 10:30 1.00 RIGMNT RSRV PROD3 10:30 - 11:00 0.50 RIGMNT RSRV PROD3 11:00 - 14:45 3.75 DRILL TRIP PROD3 14:45 - 16:00 i 1.251 DRILL I PULD I PROD3 16:00 - 19:00 3.00 DRILL PULD PROD3 19:00 - 20:00 1.00 DRILL PULD PROD3 20:00 - 20:30 0.50 CASE RURD CMPLT3 20:30 - 20:45 0.251 CASE SFTY CMPLT3 20:45 - 00:00 I 3.25 I CASE I PULR I CMPLT3 8/7/2005 ~ 00:00 - 01:00 1.00 CASE PULR CMPLT3 01:00 - 01:30 I 0.501 CASE I PULR I CMPLT3 01:30 - 01:45 0.25 CASE RURD CMPLT3 01:45 - 08:30 6.75 CASE RUNL CMPLT3 08:30 - 09:45 I 1.251 CASE I OTHR !CMPLT3 09:45 - 10:15 ! 0.50 I CASE I CIRC I CMPLT3 10:15 - 14:15 4.00 CASE I RUNL CMPLT3 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations 572 gpm at 4,100 psi, 140 rpm's, rot wt 100K ,st wt up 280K, off btm torque 24-25K ft-Ibs Monitored well-static Dropped 1 15/16" rabbit and POOH on elevators from 15,661' to 9,230' with no problems, monitored well-static (TOW @ 9,391') Slip and cut 74' of drlg line Serviced top drive POOH from 9,230' to BHA at 385', LD 2-8 1/2" ghost reamers, gauged same and were 1/8" undergauge POOH from 385' to 111', stood back 1 std of HWDP, LD 2 jts HWDP, jars and 2 NMFDC's, held PJSM and removed radioactive sources, LD 1 more NMFDC Downloaded MWD Fin LD BHA #15, LD MWD and Geo-Pilot, cleared rig floor RU Doyons 5 1/2" liner running equipment Held PJSM with rig crew and tong operator on liner running detail and associated hazards PU and RIH with 93 jts of 5 112" 15.5 ppf, L-80 slotted/blank liner per detail sheet to 4,000' Cont to PU and RIH with 5 1/2" liner from 4,000' to 6,080', PU a total of 145 jts of 5 1 /2", 15.5#, L-80, BTCM Liner with torque rings per well program, RIH to 6,080', ran 5 1 /2" ROT silver bullet guide shoe with no float, ran a total of 56 jts (2,384') of 5 112" 15.5#, L-80, BTCM blank liner, ran 89 jts (3,738') of 5 1/2", 15.5# L-80 BTCM slotted liner, ran 128 - 5 1/2" x 8 1/4" spiralglide centralizers 1Jjt #3 thru #144, ran 14 constrictor packers placed on blank liner to cover shale sections, did not run any centralizers on jts with constrictor packers. Accual Blank & Slot footage counting the 3' blank on each end of slotted joints= 2850' blank 46.8% and 3240' slotted 53.2%. Total of 6090' MU 7" tie-back assembly RIH to 6,191', MU 5 1/2" XO Jt to 7", 1-Jt of 7" csg and tie-back sleeve, st wt up 85K, do wt 52K RD Doyons liner running equipment and cleared rig floor RIH with 5 1/2" liner on 5" DP from 6,191' to btm at 15,661', RIH to 12,476' and worked pipe down to btm, no problems thru whipstock, did not have to rotate liner to get to btm, took torque and drag readings while RIH, st up wt on btm 250K, do wt 45K, rot wt 112K, R{H with liner with 4 stds slick 5" DP, 69 stds DP with Lo-Tads, 11 stds slick and 15 stds of 5" HWDP. Took torque readings at: 6,285', st up wt 85K, do wt 52K, rot wt 65K, 20 rpm's = 3k ft-Ibs torque, 40 rpm's=2-4K ft Ibs 9,363', TOW, st wt up 135K, do wt 57K, rot wt 90K, 20 rpm's = 6,500 ft-Ibs torque, 40 rpm's = 6,500 ft-Ibs 10,534, st wt up 147K, do wt 53K, rot wt 90K, 20 rpm's = 9-11 K ft-Ibs torque, 40 rpm's = 9K ft-Ibs 15,661', st wt up 250K, do wt 45K, rot wt 112K, 40 rpm's = 20K ft-Ibs torque Dropped 29/32" ball and pumped down to seat, pumped down at 4 bpm at 400 psi,slowed to 1 bpm, with ball on seat pressured up to 3,000 psi to release running tool, then pressured up to 3,720 psi and blew ball seat, PU and st wt up was 220K, top of 7" tie back sleeve at 9,483' POOH from 9,482 to 9,394', est circ and washed top of whipstock face from 9,394' to 9,302', circ at 420 gpm at 1,400 psi Monitored well-static, POOH wet from 9,302' to HR running tool at 20', Printed: 10/28/2005 10:29:27 AM • ConocoPhillips Alaska Page 30 of 33 Opera#ions Summary Report Legal Well Name: 1 E-117 Common W ell Name: 1 E-117 Spud Date: 6/20/2005 Event Nam e: ROT -D RILLING Start: 6/20/2005 End: 8/13/2005 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Code Phase Description of Operations 8!7/2005 10:15 - 14:15 4.00 CASE RUNL CMPLT3 calc fill on trip out 87 bbls, actual fill 97 bbls 14:15 - 15:00 0.75 DRILL PULD CMPLT3 LD Baker HR running tool and cleared rig floor 15:00 - 16:15 1.25 FISH PULD CMPLT3 MU whipstock retrieving BHA #16 and RIH to 337', MU retrieving hook, 1 jt HWDP, bumper sub, oil jars, pump out sub, 3-6 3/4" Dc's and 2 stds of 5" HWDP 16:15 - 19:45 3.50 FISH TRIP CMPLT3 RIH with BHA #16 from 337' to 9,352', st wt up 218K, do wt 77K 19:45 - 20:15 0.50 FISH FISH CMPLT3 Hooked whipstock at 9,391' on 6th attempt. PU on whipstock and had 25K drag, did not see btm trip release, possibly due to over pull when pulling milling assembly loose, PU and stood back std, st wt up was 250K, after standing back std string wt dropped to 225K, set back down and tagged up 25' higher 20:15 - 21:15 1.00 FISH CIRC CMPLT3 Stood back 1 std to 9,345' and circ btms up, circ at 420 gpm at 1,500 psi, max gas at btms up 20 units. 21:15 - 00:00 2.75 FISH TRIP CMPLT3 Monitored well-static, POOH slow with whipstock assembly from 9,345' to 6,324' 8/8/2005 00:00 -04:00 4.00 FISH TRIP CMPLT3 Cont to POOH with whipstock assembly from 6,324' to BHA #16 at 337' 04:00 - 05:30 1.50 FISH PULD CMPLT3 POOH and stood back 2 stds HWDP - LD 3-6 3/4" dc's, bumper sub, oil jars, pump out sub, 1 jt HWDP and retrieving hook and cleared rig floor of tools 05:30 - 06:30 1.00 FISH PULD CMPLT3 POOH and LD whipstock slide, 7 jts of 5" DP used for space out pipe and seals 06:30 - 07:30 1.00 CASE RURD CMPLT3 RU Doyon's 5 1/2" elevators and tongs, brough pup jts and XO subs to rig floor 07:30 - 07:45 0.25 CASE SFTY CMPLT3 Held PJSM with rig crew and Baker Oil tool rep on MU hook hanger assembly and procedure to hook hanger and pressures required to set ECP packer 07:45 - 08:45 1.00 CASE PULR CMPLT3 MU "D" lateral hook hanger assembly with ECP Pkr RIH to 153', MU 5 1/2" bentjt, 1-5' pupj of 5 1/2" 15.5#, L-80 IBTM blank liner, ECP, 1-6',1-21' and 1-10' pup jts and hook hanger assembly 08:45 - 09:15 0.50 CASE RURD CMPLT3 RD Doyon's 5 1/2" elevators and tongs 09:15 - 14:15 5.00 CASE RUNL CMPLT3 RIH with hook hanger assembly from 153' to above top of window to 9,352', st wt up 200K, do wt 83K (TOW @ 9,391') 14:15 - 17:30 3.25 CASE OTHR CMPLT3 Worked bentjt thru window on 1st attempt setting down 40K at 9,407', did not see ECP Pkr go thru window, attempted to turn hook and go thru window, made approx 30-1/2 round turns on DP and was unable to go deeper, stood back 1 std to 9,369' to above TOW 17:30 - 20:00 2.50 CASE OTHR CMPLT3 Increased torque limiter on top drive and and rotated DP 20 turns and was able to work pipe down, worked pipe down to 9,555' well past no go, determined to be in main bore, PU to 9,375' and rotated pipe and after 12 1/4 turns worked hook hanger thru window and tagged no go at 9,535', PU to above TOW and after 8 attempts hooked hanger at BOW at 9,704', unhooked hanger and after several attempts re-hooked hanger setting 45K st wt down on hook, set top of hook hanger at 9,386' with bentjt spaced out 7' above 7" x 5 1/2" XO at 9,536' 20:00 - 20:45 0.75 CASE CIRC CMPLT3 Dropped 29!32" ball and pumped down to seat, pumped at 3.5 bpm, 375 psi, with ball on seat pressured up to 850 psi and shut in 20:45 - 21:30 0.75 CASE OTHR CMPLT3 RU Dowell and pressure test lines to 5,000 psi, bled down to 850 psi ~ and opened Dowell to DP. Pressured up in 200 psi increments to observe ECP inflate at 2660 psi, pressure bled back to 1580 and stabilized for 5 min. Bled pressure to 850 psi. Check tank level and took .5 bbls to inflate ECP. Pressured up to 4,343 psi and sheared ball seat, bled off pressure. 21:30 - 22:30 1.00 CASE CIRC CMPLT3 PU from top of hook hanger at 9,386' to 9,319', st wt up 225K, do wt Printed: 10/28/2005 10:29:27 AM ConocoPhillips Alaska Page 31 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase 8/8/2005 121:30 - 22:30 ~ 1.00 I CASE ~ CIRC ~ CMPLT3 22:30 - 00:00 1.50 CASE RUNL CMPLT3 8/9/2005 00:00 - 01:45 1.75 CASE RUNL CMPLT3 01:45 - 02:45 1.00 CASE PULR CMPLT3 02:45 - 03:15 0.50 CMPLTN RURD .CMPLT3 03:15 - 03:30 0.25 CMPLTN SFTY CMPLT3 03:30 - 04:45 1.25 CMPLTN PULD CMPLT3 04:45 - 10:15 I 5.50 I CMPLTNI TRIP I CMPLT3 10:15 - 12:30 I 2.25 I CMPLTNI TRIP I CMPLT3 12:30 - 16:45 4.251 CMPLTNI TRIP CMPLT3 16:45 - 17:15 0.50 CMPLTN RURD CMPLT3 17:15 - 19:00 1.75 CMPLTN PULD CMPLT3 19:00 - 19:15 ~ 0.25 WELCT OTHR CMPLT3 19:15 - 23:45 4.50 WELCT BOPE CMPLT3 23:45 - 00:00 0.25 WELCT OTHR CMPLT3 8/10/2005 00:00 - 01:00 1.00 RIGMNT RSRV CMPLT3 01:00 - 01:30 0.50 RIGMNT RSRV CMPLT3 01:30 - 05:45 4.25 DRILL PULD CMPLT3 05:45 - 06:30 0.75 CASE RURD CMPLT3 06:30 - 07:45 1.25 CASE PULR CMPLT3 07:45 - 08:00 0.25 CASE RURD CMPLT3 08:00 - 13:00 5.00 CASE RUNL CMPLT3 13:00 - 16:00 3.00 (CASE RUNL CMPLT3 16:00 - 17:45 1.751 CASE CIRC CMPLT3 17:45 - 22:30 4.75 j CASE RUNL CMPLT3 22:30 - 22:45 0.25 CASE ,RURD CMPLT3 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations 77K, circ btms up from 9,319' at 180 spm, 640 gpm at 2,950 psi, monitored well-static POOH with hook hanger running tool from 9,319' to 6,771'. Cont to POOH with hook hanger running tool from 6,771' to running tool at 40' LD hook hanger running tool and cleared rig floor RU Doyon's 4 1/2" tbg handling tools Held PJSM wiith rig crew and tong operator on running of LEM MU "D" sand LEM assembly with SLZXP packer, hanger, CSR, LEM and 7 jts of 4 1/2" 12.6 ppf, L-80 IBT tubing and seals, RIH to 366' RIH with LEM assembly from 366' to top of hook hanger at 9,86', st wt up 210K, do wt 77K RIH with LEM from 9,386' and set down at 9,460', worked seal assembly approx 12 times trying to get to go thru hook with no success, worked pipe and rotated string at 15 rpm's with 15K tt-Ibs torque while attempting to go thru btm of hook at 9,407', st wt up 210K, do wt 77K rot wt 105K, appears collar above seals is setting down on XO bushing below hook on D lat Monitored well-static, POOH with LEM assembly from 9,460 to LEM at 366' RU Doyon's 4 1/2" tbg handling tools POOH LD LEM assembly with SLZXP packer, hanger, CSR, LEM and 7 jts of 4 1/2" 12.6 ppf, L-80 IBT tubing and seals, found collar above seals to show signs of where it was hitting on XO below hook, ZXP packer element had some scarring, sent packer to Baker to be re-dressed, calc fill on trip out of hole 85 bbls, actual 92 bbls Pulled wear bushing RU and tested valves, rams, annular and manifold to 250 psi low and 3,000 psi high, Note: Jeff Jones with AOGCC waived witnessing of test, RD test equipment Installed wear bushing Slip and cut 71' of drlg line Serviced top drive LD 38 stds of Weatherford 5" S-135 rental DP down from derrick while waiting on SLZXP packer to return from Baker Oil tools RU Doyon's 4 1/2" tbg handling equipment and held PJSM on running of LEM MU "D" sand LEM assembly #2 with SLZXP packer, hanger, CSR, LEM and 7 jts and 2-pup jts of 4 1/2" 12.6 ppf, L-80 IBT tubing and seals, RIH to 365' RD Doyon's 4 1/2" tbg handling equipment RIH with LEM assembly #2 from 365' to 9,343' (Top of Hook Hanger 9,386'), st wt up 205K, do wt 80K RIH from 9,343' and set down at 9,447', collar above seals tagging up at XO below hook at 9,413', rotated LEM and oriented seals thru hook after 4th attempt, cunt to RIH and set down at 9,589', (87' F/Latching hook) attempted to work LEM down rotating string with no success, rotated at 10 rpm's with 15-17K fl-Ibs torque, st wt up 225K, do wt 75K, rot wt 110K Circ 1 complete circ from 9,589' while working LEM, would not go deeper, circ hole at 265 gpm at 750 psi, monitored well-static POOH with LEM assembly #2 from 9,589' to LEM at 365' RU Doyon's 4 1/2" tbg handling equipment and held PJSM on LD LEM Printed: 10/28/2005 10:29:27 AM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase 8/10/2005 ~ 22:45 - 00:00 ~ 1.25 CASE i PULR (CMPLT3 8/11/2005 00:00 - 01:15 01:15 - 02:30 02:30 - 06:00 06:00 - 07:30 1.25 I CASE I PULR I CMPLT3 1.251 FISH ~ PULD i CMPLT3 3.50 FISH (TRIP (CMPLT3 1.50 I FISH I TRIP I CMPLT3 07:30 - 09:30 09:30 - 10:30 10:30 - 12:30 12:30 - 12:45 12:45 - 16:00 16:00 - 18:00 18:00 - 19:00 19:00 - 20:45 20:45 - 00:00 8/12/2005 00:00 - 00:30 00:30 - 03:30 03:30 - 05:00 05:00 - 05:15 05:15 - 06:45 06:45 - 07:00 2.00 FISH CIRC CMPLT3 1.00 FISH j OTHR CMPLT3 2.00 i FISH TRIP CMPLT3 0.25 FISH OTHR CMPLT3 3.25 FISH TRIP CMPLT3 2.00 FISH PULD CMPLT3 1.00 FISH PULD CMPLT3 1.75 FISH PULD CMPLT3 3.25 FISH (TRIP CMPLT3 0.50 FISH TRIP ~ CMPLT3 3.00 I FISH I TRIP I CMPLT3 1.501 FISH I CIRC I CMPLT3 0.25 DRILL OBSV CMPLT3 1.50 DRILL PULD CMPLT3 0.25 DRILL PULD CMPLT3 Page 32 of 33 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations POOH and LD SLZXP packer, CSR and LEM, pkr, pkr element ck'd ok with only a couple of scratches, LEM had some scratches on upper OD of tool also, POOH to 4 1/2" tbg to 267', SLM out of hole, no correction Fin POOH from 267' LD remaining 4 1/2" tbg, POOH and checked seals, had 3-4 seals damaged leaving 8-9 good seals, changed out special clearance collar on seals to 5.2" IBT collar MU dummy run BHA #16 with seal assembly on bent jt, 10 jts 4 1/2" tbg with 7" OD boot basket and RIH to 353' RIH with BHA #16 from 353' and tagged top of hook hanger at 9,386', st wt up 220K, do wt 80K Oriented seal assembly and RIH below hook hanger and tagged up on XO below hook at 9,413', PU and re-oriented seal and on 2nd attempt went thru hook, cont RIH and tagged up at 9,589', same spot as last run, set down 10K wt down, est circ at 6 bpm at 550 psi, est rotation at 15 rpm's with 15-16K ft-Ibs torque and set 10K wt down with no movement, st wt up 220K, do wt 78K, rot wt 115K Circ hole at 9,589' while working junk basket, circ at 150 spm, 533 gpm at 2,050 psi Attempted to work seals deeper, rotated on obstruction at 20 rpm's with 17-18K ft-Ibs torque with 10K wt down and circ hole at 50 spm, 178 gpm at 700 psi was able to go down 3' to 9,592' Attempted to POOH, worked pipe from 9,592' to 9,385' pulling 25-35K over st wt, hole extremly tight possibly due to junk in hole, POOH to 9,331' to above top of hook at 9,386' Monitored well-static POOH from 9,331' to BHA #16 at 353' POOH and LD BHA #16, LD boot basket, 10 jts of 4 1 /2" tbg, bent jt with seals, had 1 piece of brass with a few pieces of cement in junk basket, btm 3 collars where shined up with scrathes from iron, guide shoe on seals had 2 indentions on ID of seals PU tools for BHA #17 to rig floor MU reverse junk basket on BHA #17 and RIH to 362', MU 6 3/4" rev. junk basket, 2- 4 11/16" boot baskets,3-4 3/4" DC's, and 7 jts of 4" XT-39 DP{and Rlh to 362' RIH with BHA #17 from 362' to 6,147' RIH with reverse circ junk basket on BHA #17 from 6,147' to 9,341', st wt up 210K, do wt 82K, est circ at 6 bpm at 750 psi, rotated string at 30 rpm's with 13-15K torque, rot wt 105K, do wt 105K, up wt 150K RIH from 9,341' began to see 10-15K drag at 9,398' (TOW @ 9,391') circ hole and worked reverse junk basket down and tagged XO below hook at 9,413', attempted to go out of hook window with BHA #17 with no success, worked pipe approx 30 times and could not get to go thru window, tried numerous combinations trying to go thru window, with and without pumps, rotating pipe up different turns, rotating down etc. and wouldn't go thru. Decision was made to change hole over to brine, run 4 1/2" tbg and move rig off. POOH from 9,413' to above hook to 9,380', pumped 30 bbls sweep with 9.0 ppg brine and Safe Surf-O then displaced hole over from 9.0 ppg SFMOBM to 9.0 ppg Brine, circ hole at 8 bpm at 1,050 psi, 50 rpm's with 11-13K ft-Ibs torque, circ a total of 700 bbls of brine Monitored well-static, took SPR's POOH with BHA #17 from 9,380' to 8,424' LD 10 stds of 5" HWDP RIH with 5 stds of 5" HWDP to 8,885' Printed: 10/28/2005 10:29:27 AM ConocoPhillips Alaska Page 33 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common W ell Name: 1 E-117 Event Nam e: ROT -D RILLING Contractor Name: Rig Name: Date From - To Hours Code Phase Code 8/12/2005 07:00 - 16:30 9.50 DRILL PULD CMPLT3 16:30 - 19:15 2.75 DRILL PULD CMPLT3 19:15 - 21:00 1.75 FISH PULL CMPLT3 21:00 - 21:30 0.50 CMPLTN PULD CMPLT3 21:30 - 22:00 0.50 CMPLTN RURD CMPLT3 22:00 - 22:15 0.25 CMPLTN SFTY CMPLT3 22:15 - 00:00 1.75 CMPLTN RUNT CMPLT3 8/13/2005 00:00 - 05:00 5.00 CMPLTN RUNT CMPLT3 05:00 - 05:45 0.75 CMPLTN RUNT CMPLT3 05:45 - 06:15 0.50 CMPLTN SOHO CMPLT3 06:15 - 07:00 0.75 CMPLTN RURD CMPLT3 07:00 -11:00 4.00 CMPLTN NUND CMPLT3 11:00 - 12:00 1.00 CMPLTN RURD CMPLT3 12:00 - 13:00 1.00 RIGMNT RSRV CMPLT3 13:00 - 15:00 2.00 RIGMNT RSRV CMPLT3 15:00 - 16:30 1.50 CMPLTN OTHR CMPLT3 Spud Date: 6/20!2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations POOH with BHA #17 LD HWDP & DP from 8,885' to BHA at 362', tD 5 stds of 5" HWDP, 11 stds 5" slick DP, 69 stds of 5" DP with Lo-Tads and 4 stds of slick 5" DP to BHA (267 jts total) found many Lo-Tads to be worn and rollers flat spotted, cleaned rig floor RU mousehole and LD 37 stds of slick 5" DP out of derrick, LD a total of 408 jts of DP RU 4" handling equipment and POOH LD BHA #17 from 362', LD jars, 7-jts of 4" XT-39 DP, 2-boot baskets and 6 3!4" reverse circ junk basket, had no recovery in reverse circ junk basket or lower boot basket, in upper boot basket had 2 small pieces of metal and approx 1/2 cup of pieces of cement, talc fill on trip out of hole 83 bbls, actual fill 99 bbls Pulled wear bushing RU Doyon's 4 1/2" tbg handling equipment Held PJSM with rig crew and tong operator on running order of 4 1/2" tubing and associated hazards PU seal assembly on 1 bent jt of 4 112" 12.6#, L-80 tbg, changed out used collar, then began PU and RIH with 4 1/2" 12.6#, L-80, IBT tubing to hang off in well, RIH with 55 jts of 4 1/2" tbg to 1,737' RIH with 4 1/2" kill string with bentjt and seal assembly from 1,737' to 9,362' (Top of Hook @ 9,386') st wt up 100K, do wt 55K, ran 247 jts of tbg (302 jts total) Cont to RIH and tagged XO below hook at 9,413' with end of seals at 9,446', PU rotating tbg to TOW at 9,391' and on 3rd attempt went thru hook, cunt to RIH and tagged junk in hole at 9,592' PU and spaced out kill string with 2-4 1/2" pup jts (13.65'), MU full jt of tbg above pups and then MU hanger, landed hanger with no problems, landed tbg with end of seals at 9,590', st wt up 100K, do wt 53K (EOT -2' above Junk) RIH with seals, 1-4 1/2" bentjt, 307 jts 4 1/2" 12.6 ppf, L-80 IBT tbg, 2-pup jts,1-jt tbg and hanger, total RIH 9,567.14 (RKB to ULDS 22.74') LD landing jt and RD Doyon's 4 1/2" handling equipment, Vetco Gray tested both upper and lower seals on hanger to 5,000 psi and tested each for 10 min, good test ND BOP's and set off stack, NU Vetco Gray 13 5/8" x 4 1/16" 5M Tree, tested tree and void to 5,000 psi each for 10 min, good test, pulled TWC and installed BPV and secured well Cleared rig floor, LD XO subs and cont to clean mud pits and rock washer, cleaned out cellar box Slip and cut 62' of drlg line Changed out saver sub and serviced top drive while cont. to clean mud pits Fin cleaning mud pits and rock washer, Sim-Ops: moved camp, sewer plant and truck shop to 1J pad, RELEASED RIG @ 16:30 hrs 8/13/05, Rig to move to 1 J-168 Printed: 10/28/2005 10:29:27 AM ConocoPhillips Alaska Page 1 of 9 Operations Summary Report Legal Well Name: 1 E-117 Common W ell Name: 1 E-117 Spud Date: 6/20/2005 Event Nam e: WORKO VER/RE COMP Start: 9/24/2005 End: Contractor Name: Rig Release: Group: Rig Name: Nabors 3 S Rig Number: Date From - To Hours Code Code Phase Description of Operations 9/24!2005 18:00 - 00:00 6.00 MOVE RURD DEMOB Rig down lower derrick and prepare to move to 1 E-117 9/25/2005 00:00 - 03:00 3.00 MOVE RURD DEMOB Rig down lower derrick and prepare to move to 1 E-117 03:00 - 09:00 6.00 MOVE MOVE DEMOB Move From 1 D to 1 E-117 Spot rig over well 09:00 - 13:00 4.00 WAITON OTHR RIGUP Pre-job safety meeting. Prepare to spot rig. Call out BPV crew and install with scaffolding crew also. 13:00 - 16:00 3.00 MOVE RURD DEMOB Spot rig and prep for rig up. 16:00 - 00:00 8.00 WAITON WOW RIGUP Except rig @ 16:00 hrs 9/25/200. Wind speed from 19 MPH to 34 MPH stand by for raising derrick. Chuck Scheavy AOGCC declined to witness BOP test tonight @ 07:OOPM 9/26/2005 00:00 - 06:00 6.00 WELCT NUND DECOMP ND tree and NU BOP's, 13 5/8 with variables 3.5"- 6" 06:00 - 13:00 7.00 WELCT BOPE DECOMP Tower safety meeting continue to NU BOP's BOPE test waived by Chuck Sheavy @ 1900 hrs 9-25-2005. Perform BOPE test 250 PSI iow, 3,000 PSI high. 13:00 - 14:00 1.00 WELCT NUND DECOMP Blow dwn all line and prepare to pull Two way check. 14:00 - 14:30 0.50 WELCT NUND DECOMP Pull Two way check. No pressure on well. 14:30 - 15:30 1.00 FISH SFTY DECOMP Pre-spud program. All hands for meeting. 15:30 - 17:30 2.00 FISH PULL DECOMP Prep rig floor for Pull. Pull hanger to floor. 67K up wt. no overpull while pulling out of hanger bowl. At 24' 15K over pull with normal fallback. Monitor wellbore for conditions. Clean and lay down hanger assym for inspection. Small mark on side. Vetco rep Erick says no problem. 17:30 - 18:00 0.50 FISH SFTY DECOMP Count 220 jts in pipe shed. All that will fit in our current configuration and still be able to lay down 4.5" kill string. ROPE drill. Shot fluid level @ 26' and holding 18:00 - 00:00 6.00 FISH SFTY DECOMP Night shift pre-spud program. Continue to POOH with 4.5" Kill string. Up WT. 72K 9/27/2005 00:00 - 06:00 6.00 FISH PULL DECOMP Continue to POOH with 4.5" kill string 06:00 - 12:00 6.00 FISH PULL DECOMP Pre Tower safety meeting, then continue pulling Kill string. Continue to work with fluid @ 26' below Kelly, DHD will shoot two fluid level shots per day 6:00 and 18:00. 41 bbl loss for the day. 12:00 - 15:00 3.00 FISH PULD DECOMP Out of the hole with the kill string. Strap remainder of pipe pulled, check OD of collars. All collars 5.17-5.20", pipe count /lengths matched run tally. Confer with workover engineer. 15:00 - 20:30 5.50 WAITON EOIP DECOMP Waiting on modifications to be made on mainbore diverter at Baker machine shop. Move remainder of PH-6 workstring into pipe shed and begin strapping. 20:30 - 23:30 3.00 WELLS EORP DECOMP Ph-6 work-string loaded in pipe shed and strapped. BHA on location ; begin rigging up. 23:30 - 00:00 0.50 WELLS TRIP DECOMP BHA rigged up consisting of Diverter 5'Iong, with a 9.48' 4.5 IF pup, 3.5" X 4.5" IF XO 1.90' long, Sperry Sub 3.5" IF 2.89' long, with UBHO inside, a 3.5 IF pup 7.59' long and a XO 3.5" IF to PH-6 1.67' long. Followed by 300 joints of PH-6 work-string to surface UBHO is set to start 12 hours from 11:00 PM Tuesday (or 11:00 AM) and will take samples for 16 hours @ 1 sample per min. until Thursday morning at 2:00 AM. Start tripping in the hole 9/28/2005 00:00 - 06:00 6.00 WELLS TRIP DECOMP Continue to trip Sperry's memory UBHO to verify orientation of Main bore Diverter 06:00 - 11:40 5.67 WELLS TRIP DECOMP Pre tower safety meeting, high wind spead +_ 50 MPH Continue to trip Sperry's memory UBHO on 3.5 PH-6 tubing avg. about 26 joints per hour. Fluid level is aprox. 10' down from RKB. 43 bbl loss during for the day. 11:40 - 12:10 0.50 WELLS OTHR DECOMP Tag up at 9386'. PU wgt=75k, RIW=16k. Pick up off hook hanger...clean pickup, no overpull. RBIH and tag same, pick up to Printed: 10/282005 10:23:49 AM r~1 ConocoPhillips Alaska Page 2 of 9 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Spud Date: 6/20/2005 Event Name: WORKOVER/RECOMP Start: 9/24/2005 End: Contractor Name: Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Code Phase Description of Operations 9/28/2005 11:40 - 12:10 12:10 - 12:35 12:35 -13:00 13:00 - 14:45 14:45 - 18:00 18:00 - 00:00 9/29/2005 00:00 - 01:30 01:30 - 06:00 06:00 - 08:30 08:30 - 09:30 09:30 - 11:00 11:00 - 12:30 12:30 - 18:00 18:00 - 23:00 23:00 - 00:00 9/30/2005 00:00 - 01:30 01:30 - 02:30 0.50 0.42 0.42 1.75 3.25 6.00 1.50 4.50 2.50 1.00 1.50 1.50 5.50 5.00 1.00 OTHRIDECOMP OTHR ~DECOMP OTHRIDECOMP OTHRDECOMP TRIP DECOMP TRIP DECOMP EORP DECOMP TRIP DECOMP TRIP ~ DECOMP PERF (DECOMP PERF IDECOMP PERF ~DECOMP TRIP I DECOMP TRIP DECOMP RURD DECOMP 103k, latched. Get 5 minute sample. Pick up, see tool unlatch at 100k. PUH 10' and rotate pipe w! power tongs. 2 turns in (see turn at 4-5k torque), get 1-3/4 back. Get 5 minute sample. Run back in hole and tag same; latch up. Get 5 minute sample. Pick up; see diverter unlatch again at 100k continue out 10'. Attempt to rotate, get 3/4 turn downhole. Get 5 minute sample. Run back in hole and tag same; latch up. Get 5 minute sample. Attempt to pull free; 95k pulling out off hole dragging what appears to be the hook hanger. Pull up approx. 8'; dragging 95k. Attempt to run back in hole, stacking out. Shut down to confer and call W/O engineer. Discuss options. Decide to attempt to "shuck" off hook hanger. Pull up hole a little quicker, 100-105k#...still just dragging. Run back in hole and re-attempt only pulling faster. At 120k pick up weight, see snap latch release leaving hook hanger at approx. 9374'. Begin puling out of hole racking back workstring, pumping hole fill. Shoot fluid level; fluid approx. 175' down. Continue pulling out of hole. Assembly BHA for Schlumberger gun run, consisting of 20.4' pert gun, 28.31' of CS HYD, 2.05' of XO, 14.02' space out pups, HR running tool 22.65', Bumper sub 7.86', XO to PH-6, and PH-6 work string to 9440' RKB to punch 9 holes in ECP. Fill hole with 15 bbls of 8.7 brine this brought the fluid level in the stack but it was dropping slowly. BHA made up ready to start running stands of PH-6 work-string. Fluid level about 90' Tower safety meeting Shoot fluid level to insure stable hole. Continue to RIH with PH-6 and pert gun Averaging 25 stands per HR. Tag up in hook hanger at 5' down on jt. #30. RIW=17k, PUW=75k. Pull up hole to see if latched; slight wgt increase 5-6k# to 80K. Run back in hole and set down in same spot, pull up hole of see if latched, same as previous attempt. Repeat with same results, not conclusive if latched. Install headpin, rig to check for circulation. Establish ability to circulate, 1 bpm @ 200 psi. Drop ball and come online displacing at 1 bpm. Perf interval spaced out putting top shot at 9466', lower shot at 9468'. Latched HR profile at 9419'. 77 bbls away, see circulating pressure drop, rate increase. Good indication of gun firing. Attempt to run in hole, move freely 4'. Rig down headpin and begin pulling out of hole. No "bobbles" or drag seen through window, nothing definitive to show packer is on. Note: Sperry hand called to inform he was able to get info from UBHO tool. Sperry tool indicated diverter aligned 100 deg L of high side placing hanger oriented 180 deg R of high side. Averaging about 18-20 stands/hr. Keeping hole full; losing approx 5 bbls/hr. Make crew changeout. Continue to pull fishing string OOH OOH with BHA Hook Hanger on HR running tool, and ECP packer all shots fired ECP deflated and on surface element intact. Rig up Clean out BHA consisting of a 4-5/8"junk basket, two 3-1 /8" collars, 8-5/8" OD string mill, 4 joints 3-1/2" 13.3# HT38 drill pipe, and fishing jars on the 3-1/2" PH6 work string wash to the bottom of the "B" lateral LEM seal bore (4.75" ID; top at 9667' RKB and bottom at 9687'). Continue to rig up Clean out BHA fluid level approximately. 110' RIH with cleanout BHA using 150 stands and 7 joints of 3.5" PH-6 tubing torque to 7000 psi Rig maintenance slipping drill line. Fluid level 90' down, man rig floor 1.50 1.00 RURD DECOMP TRIP DECOMP 02:30 - 03:30 1.00 RIGMNT RSRV DECOMP Printed: 1028/2005 10:23:49 AM C: Conoc©Phillips Alaska Operations`Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: WORKOVER/RECOMP Start: 9/24/2005 Contractor Name: Rig Release: Rig Name: Nabors 3S Rig Number: Page 3 of 9 Spud Date: 6/20/2005 End: Group: Date From - To Hours Code Code Phase Description of Operations 9/30/2005 02:30 - 03:30 03:30 - 06:00 06:00 - 10:00 10:00 - 11:00 11:00 - 18:00 18:00 - 20:00 20:00 - 22:00 22:00 - 00:00 10/1/2005 100:00 - 02:30 1.00 RIGMNT~ RSRV 2.50 WELLS TRIP 4.001 WELLSRTRIP 1.001 WELLSR MILL 7.001 WELLSR RURD 2.00 WELLS RURD 2.00 WELLS MILL 2.00 WELLSR RURD 2.501 WELLSR RURD 02:30 - 06:00 I 3.501 WELLSR' TRIP 06:00 - 18:00 ~ 12.00 WELLS TRIP 18:00 - 21:00 3.00' WELLS TRIP 21:00 - 00:00 i 3.00 WELLSR RURD 10/2/2005 100:00 - 03:00 I 3.001 WELLSR RURD 03:00 - 06:00 I 3.001 WELLSR TRIP 06:00 - 07:30 I 1.501 WELLSRTRIP 07:30 - 15:00 7.501 WELLSRTRIP 15:00 - 18:00 I 3.001 WELLSR TRIP 18:00 - 00:00 I 6.001 WELLSR TRIP 10/3/2005 00:00 - 03:30 3.50 WELLSRTRIP 03:30 - 05:00 1.50 WELLS TRIP DECOMP and monitor well DECOMP Continue to RIH with fishing string drill line slipped and ready to trip pipe. Hole stable, fluid level 90' from surface. DECOMP Pre tower meeting continue RIH with cleanout string. Fluid loss to well= 73 bbl last 24 hrs, 193 bbls cummulative. Shoot fluid level, 54' from surface. DECOMP Tag up at 9470'. putting depth of string mill at 9400'. PUW = 87k. Pull up hole 10', attempt to rotate with power tongs while moving back in hole. Pipe rotating freely at 3800# of torque while moving. Rih to tag; pipe "torquing" at tag, 5500-6500#. Shut down and prep to rig up power swivel. DECOMP Conduct pre-job safety meeting on picking up /rigging up power swivel. Begin rig-up. DECOMP Crew change-out. Shoot fluid level=59' continue to rig up power swivel DECOMP Milling with string mill from 9390'-9396'. PUW = 85k. Pipe rotating at 6000# of torque about 36 RPM pump rate 3 BPM 1100 psi long way, RIH slowly, power swivel stalling out @ about 7000#. Work pipe free and attempt to mill down for two hours with same results making no hole. Concern over losing BHA below string mill (due to backlash from milling operation) resulted in Shut down milling with this BHA and rigging down power swivel. Circulating resulted in 50 of OBM returns to surface. DECOMP Rig down power swivel and prepare to come out of hole with PH-6 laying down ordered 290 bbls of 8.9 pps brine with 3% KCL. 4" XT-39 drill pipe from Doyon 141 on location load into pipe shed and strap. DECOMP Continue rigging down power swivel and prepare to come out of hole with PH-6 laying down DECOMP Power swivel laid down start pulling PH-6 laying. down sideways. Hole fill, pipe displacement plus 3 bbls per 10 JTS. Fluid down approximately 60'. Conduct BOP drill. DECOMP Tower safety meeting continue to trip PH-06 OOH. Shoot fluid level =57'. Filling hole with pipe displacement, adding 2-3 bbls roughly every 5 stands. DECOMP Crew changeout. Continue out of hole with fishing string. DECOMP OOH with BHA, 8 5/8" string mill showed some scratches on smooth gauge of Mill. Clean floor, load 4" XT-39 drill pipe in shed and pick up Kelly. DECOMP Kelly picked up ready set floor up to rig up fishing BHA. Continue loading pipe shed and strapping XT-39 drill pipe. Drift 2.347" DECOMP Assemble Fishing BHA consisting of 8.5"Junk Basket, 8.625" String Mill, 6.25 Oil Jar, One 6" Drill Collar, and 4" XT-39 Drill pipe to surface. DECOMP Tower Safety meeting Ice conditions and safey use of spinner safety topics. Make up BHA and prep to begin RIH with 4" drill pipe, Mill and ,Junk Basket. Note: Lost 48 bbls to formation in last 24 hrs. DECOMP Pipe skate broken; chain on skate has come apart. Begin hunting down parts, call out mechanic. Pull BHA back to surface. DECOMP Resume running back in hole with 4" drill pipe, milling string. Conduct spill drill. DECOMP Crew changeout. Shoot fluid level= 120'. continue to RIH with 4"drill pipe average 25 jts. hour Rabiting Drill string 2.347" DECOMP Continue running back in hole with 4" drill pipe, milling string. DECOMP Pick up Kelly and tighten connections prepare to rotate through tight spot @ 9400' RKB Printed: 10/28/2005 10:23:49 AM n ConocoPhillips,Alaska_ Page 4 of 9 Operations Summary Report Legal Well Name: 1 E-117 Common W ell Name: 1 E-117 Spud Date: 6/20/2005 Event Nam e: WORKO VER/RE COMP Start: 9/24/2005 End: Contractor Name: Rig Release: Group: Rig Name: Nabors 3 S Rig Number: Date From - To Hours Code Phase Description of Operations ~ Code 10/3/2005 05:00 - 07:00 2.00 WELLS MILL DECOMP Tagged obstruction @ 9392' RKB, rotating and working downfrom 9387' to dress up window. 60 RPM's pumping 2 BPM long way, torque gauge is not showing any torque, though off zero. 115K# up WT. 34K# down WT , 62K# down WT while rotating. Circulating at 2 bpm. 38 bbls lost in last 24 hrs, 287 bbls cumulative. 07:00 - 08:00 1.00 WELLS MILL DECOMP Mill through to 9407'; see little to no "work" .Pull back through and make 2 more trips backreamming through. Down wgt. 30k, up wgt. 125k. Clean pickups through window. Make trip across window without rotating...clean pick-ups. Kelly buried; stop circulating pick up 10' of pups and work down to 9417'. Resume circulating at 2 bpm. 08:00 - 09:00 1.00 WELLS MILL DECOMP Make 3 additional trips through window at 90 RPM. Trip again across window without rotating, 30k dn, 125k up, 70k rotating...clean pickups. Make 1 more trip back across window at 100 RPM. Stop circulating. 09:00 - 11:00 2.00 WELLS MILL DECOMP Break out pups and pick up full jt. Resume circulating 2.0 bpm. Work through to Stop pumping. Begin picking up singles under Kelly and continue running in hole. 11:00 - 12:30 1.50 WELLS CIRC DECOMP Tag up 30' in on Kelly, jt #307 in hole (9646' orig RKB); come back online circulating bottoms up @ 3 bpm. Reciprocate with Kelly off ~ bottom, make 3 trips to bottom while rotating, PUH after tag. 12:30 - 14:30 2.00 WELLS CIRC DECOMP 250 bbls around; break out Kelly and stand back. 14:30 - 18:00 3.50 WELLS TRIP DECOMP Begin pooh with 4" drillpipe, racking back. Begin filling hole across the top on the way out. 18:00 - 00:00 6.00 WELLS TRIP DECOMP 60 stands out of. Losing 3 bbls every 5 stands, swap back to filling pipe displacement, pumping extra every 5 stands. 10/4/2005 00:00 - 01:30 1.50 WELLS TRIP DECOMP POOH with String Mill and Rev. Junk Basket. Junk Basket full of combination of Cement and Metal cuttings some of the cement pieces are 4" to 6" long metal cuttings some 2" to 3" long appear to be from window cutting operation. Rig up floor to start BOP testing. Cont to rig down BHA. 01:30 - 06:00 4.50 WELCT ROPE DECOMP Prepare for weekly BOP test. State witness of BOP test waived by John Crisp @ 3:00 pm 10/3. Function test BOP rams. Press test BOP and choke manifold to 250 / 3000 psi. 06:00 - 06:30 0.50 WELCT BOPE DECOMP Tower safety meeting currently BOP testing. 06:30 - 07:30 1.00 WELCT BOPE DECOMP Pressure test Kelly valves to 250 / 3000 psi. 07:30 - 11:00 3.50 WELLS PULD DECOMP BOP Test completed at 07:30. Stand back Kelly and prep to pick up drillpipe. 11:00 - 17:30 6.50 WELLS TRIP DECOMP Pick up and run in hole with Bent jt of 5.5", Xovers and 4" Drill pipe. 17:30 - 18:00 0.50 WELLS SFTY DECOMP Tower safety meeting. Focus on pinch points and incident with floofiand getting finger pinched & fractured between 4" DP and DP Spinner Hawk. 18:00 - 21:30 3.50 WELLS TRIP DECOMP Cont RIH with 4" DP std's from derrick. Weights at 9360' 107 Klbs up/27 Klbs down. 21:30 - 22:00 0.50 WELLS TRIP DECOMP Tag up 6.5" OD x-over above 5.5" Bent joint on 6.25" ID X-over6 ft into 7" Tie-back, at 9506' RKB. Based on above, bottom of Bent joint at 9550'. Tie-back top is at 9500' and 7" x 5.5" X-over at 9553' RKB. L2 "D"-lateral liner is set 17' deeper than reported. 22:00 - 23:00 1.00 WELLS TRIP DECOMP Pull back into main bore, rotate 6 turns, get 1.5 turns back. Trip in hole, take 4-5 Klbs weight from 9655' to hard tag at 9660' RKB. Re-tag same depth and set down 8 Klbs. Estimate 5-6 ft of junk above seal bore ~ below ZXP packer. 23:00 - 00:00 1.00 WELLS TRIP DECOMP POH racking 4" DP back stands in derrick Fill hole with displacement + 2-3 bbls everey 10 stands. 17 of 153 stands out at rpt time. 10/5/2005 00:00 - 06:00 6.00 i WELLS TRIP DECOMP Continue pooh with 4" DP and 5.5" bent joint assy. Depth at 06.00 hrs= Printed: 10/28/2005 10:23:49 AM • ConocoPhiNips Alaska Operations Summary Repast Page 5 of 9 Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Spud Date: 6/20/2005 Event Name: WORKOVER/RECOMP Start: 9/24/2005 End: Contractor Name: Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Code Phase Description of Operations 10!572005 00:00 - 06:00 6.00 WELLS TRIP DECOMP 1600 ft. 120 bbls 8.9 ppg brine 3°lo HCL lost to well last 24 hrs. 06:00 - 08:30 2.50 WELLS TRIP DECOMP Tower safety meeting. Cont pooh to surface. 08:30 - 09:30 1.00 WELLS PULD DECOMP Rig up to handle bent joint x-o's, break and lay down same. 09:30 - 11:30 2.00 WELLS PULD CMPLT3 Clear rig floor. Load pipe shed with Hook Hanger assy and pup joints, bring same to rig floor. 11:30 - 12:00 0.50 RIGMNT RSRV CMPLT3 Lubricate and service rig. 12:00 - 16:00 4.00 WELLS PULD CMPLT3 Pick up and make up 5.5" bent jnt, 5.5" pup jnt's, ECP, 5.5" spacer pup jnt's, Model 'B' Hook Hanger and running tool. Details of Hook Hanger BHA under Pipe Tally. 16:00 - 17:00 1.00 WELLS OTHR CMPLT3 Clear and clean rig floor in preparation for tripping in hole. 17:00 - 18:00 1.00 WELLS TRIP CMPLT3 Rih with Hook Hanger BHA on 4" XT DP. Tower safety meeting. 18:00 - 00:00 6.00 WELLS TRIP CMPLT3 Continue rih wih HH BHA on 4" XT Drill Pipe. Depth at rpt time 6331 ft. 10/6/2005 00:00 - 03:00 3.00 WELLS TRIP CMPLT3 Cont rih to 9350'. Record up/down weights 105 / 21 Klbs. 03:00 - 05:30 2.50 WELLS PLGM CMPLT3 Rih and slide to a stop at 9554'. Puh, increase speed dwn and tag 7" x 5,5" x-o in L2 "D" at 9556' rkb w! full weight of string. Puh to 9550, rih confirm tag at 9556'. Puh w/ 10 Klbs o/pull to 9505', rotate 8 turns, get 5 back, rih set down at 9533'. Puh to 9520' w/ 20 Klbs o/pull. Increase speed down and tag up 9554, puh & see 25 Klbs o/pull at 9549'. Rih tag 9556', puh hang up at 9539'. Rih 10', puh faster and slipped past rests w/ 45 K1bs o/pull, puh to 9520'. Rotate 12 turns, get 7 back. Rih tag 9556', puh hang up at 9543'. Free movement of pipe between 9543' and 9556', make +-30 attempts to pull past restriction av various speeds and and o/pull, max o/pull 75 Klbs (180 Klbs). 05:30 - 09:30 4.00 WELLS PLGM CMPLT3 Evaluate and discuss with town options to free and land hook hanger . 09:30 - 11:30 2.00 WELLS PLGM CMPLT3 Put 5 rounds torque in pipe, held with rig tongs. Worked up and down to work torque down to Hook for orienting Hook in window. Got 2 rounds back. Picked back up to 175K (50K overpull) still stuck but have 13' of travel. Worked up and down atempting to set Hook with no luck. Repeated procedure trying to work torque down to turn the Hook. On second attempt we got 5 1/2 turns back. Made third attempt putting 8 rounds in without holding torque with rig tongs. Released and got 3 turns back. Worked up and down 6 times, on down stroke of 6th attempt appeared to hook. Picked up to unhook and pulled over to 175K. Wt bled off to 150K, picked back up to 175K, original tight spot. Tried to go back down to where we hooked but could not get all the way back down, 3' higher. Worked pipe up and down attempting to get loose, max pull was 225K. 11:30 - 14:30 3.00 WELLS PLGM CMPLT3 ~ Evaluate and discuss options to free or shear HR. 14:30 - 19:00 4.50 WELLS CMPLT3 RU head pin. Filled hole. Established circulation.26PM @160 psi. Worked pipe while circulating still stuck no movement. Set weight down, dropped ball, ciruclated ball down at 3 BPM @ 220 psi for 60 ~ bbls. Slowed pump down to 1.5 BPM @ 120 psi. Ball on seat at 85 bbls. Press up to 1400 psi, picked up was not released. Set wt back down press up to 1600 psi, bled off press. Picked up to 150K popped free, pulled free for 4' hung up again pulled up to 225K. Worked pipe up and down and rotating to work free. Pulled up to 235K and pulled i free. Note: When released the Hook Hanger the top of hanger @ 9383', Hook @9404' and the mule shoe @ 9543'. 19:00 - 21:00 2.00 WELLS TRIP CMPLT3 Pooh to 8200' laying down 4" DP. 21:00 - 00:00 3.00 WELLS TRIP CMPLT3 Tower safety meeting. Continue pooh laying down 4" DP. Depth at rpt time: 6100'. Lost 48 bbls brine to well last 24 hrs 10/7/2005 00:00 - 02:30 ~ 2.50 WELLS TRIP CMPLT3 Continue pooh with Hook Hanger Running assy, laying down 4" XT39 Printed: 10/28/2005 10:23:49 AM ConocoPhiltips Alaska Operations Summary Report Page 6 of 9 Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Spud Date: 6/20/2005 Event Name: WORKOVER/RECOMP Start: 9/24/2005 End: Contractor Name: Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Coe Phase 10/7/2005 00:00 - 02:30 2.50 02:30 - 03:30 1.00 03:30 - 10:30 7.00 10:30 - 11:30 1.00 11:30 - 16:00 4.50 16:00 - 18:00 2.00 18:00 - 21:30 3.50 21:30 - 22:00 0.50 22:00 - 00:00 2.00 10/8/2005 100:00 - 05:30 05:30 - 06:30 06:30 - 11:00 11:00 - 15:00 15:00 - 16:00 ~ 16:00 -18:30 18:30 - 20:30 20:30 - 23:00 23:00 - 00:00 10/9/2005 00:00 - 07:30 5.50 1.00 4.50 4.00 1.00 2.50 2.00 TRIP CMPLT3 OTHR CMPLT3 TRIP CMPLT3 TRIP CMPLT3 OTHR CMPLT3 OTHR CMPLT3 PULD CMPLT3 OTHR CMPLT3 TRIP CMPLT3 TRIP CMPLT3 TRIP CMPLT3 TRIP CMPLT3 TRIP CMPLT3 OTHR CMPLT3 OTHR CMPLT3 OTHR CMPLT3 2.50 WELLS PULD CMPLT3 1.00 WELLS TRIP CMPLT3 7.50 WELLS TRIP CMPLT3 07:30 - 09:00 1.50 WELLSR TRIP CMPLT3 09:00 - 13:00 4.00 WAITON EQIP CMPLT3 13:00 - 14:00 14:00 - 20:00 20:00 - 20:30 20:30 - 00:00 1.001 WELLSR PULD I CMPLT3 6.00 WELLS TRIP CMPLT3 0.50 WELLS SFTY CMPLT3 3.50 ~ WELLS TRIP CMPLT3 10/10/2005 00:00 - 02:30 2.501 WELLSR TRIP (CMPLT3 Description of Operations DP. Swap 4" DP handling equipment, returning equipment belonging to Doyon 141. Cont pooh and laying down 4" XT39 DP. Lay down Baker HR running tool and associated jewelry. Unload pipe shed and rig floor of all and any Xt-39 drill pipe and handling tools and ship back to rig 141. Began loading pipe shed with 4" HT-38 drill pipe. Strapped all 4"-HT-38. Move BHA and handling equipment to rig floor. Pick up Main Bore Diverter, Sperry UBHO sub, bumper sub, and jars. Set UBHO to start recording at 05.10 hrs AM, 10/08/05, recording interval 1 min. Clear and clean rig floor in prep for tripping. Rih picking up 4" HT38 singles from pipe shed. Depth at rpt time 1381 ft. Lost 48 bbls 8.9 ppg brine to formation last 24 hrs. Cont trip in hole with Main Bore Diverter, Sperry UBHO, oil jar and bumper sub, picking up 4" HT38 singles from pipe shed. Tower safety meeting. Focus on drop zones, lock-out procedures and handling DC's. Load remaining 4" HT38 DP into pipe shed and strap same. Cont rih with 4" HT38 DP from 6063' to 8670'. Picked up 15 - 6 1/8" Drifl collars and 9 more jts of HT38 drill pipe. Up wt.= 111 K Dwn wt.=48K. Lowered diverted and latched up 9393.65',(top of hook hanger @ 9385' Hook @ 9406'). Set 15K down wait 10 min. PU pulling 115K dragging 10'. Wait 5 min. RIH set down 15K again at same depth, wait 10 min. PU pulling 115K again dragging, wait 5 min. RIH set 30K down at same depth. Wait 10 min. PU pulling 117K dragging. Pulled up 10' to connection, broke connection and set TIW valve. Discuss options with town. Tower safety meeting, focus on handling 6" DC's Rih from 9381', start to take wt @ 9393', set down all wt @ 9398' (18:54 hrs). Wait 10 min, DP slide to regain all down wt 40 Klbs (19:04 hrs). Cont rih with full wt 40 Klbs to 9402' (19:12 hrs, Hook @ 9414' RKB). Puh to 1st connection 9381' (19:54 hrs) with 90 - 95 Klbs. Reason for loss of up wt unknown. Cont puh to 9350', same up wt but indications of Hook Hanger assy being pulled through window. Pull 4 stands with 90-95 Klbs up wt. PuII and lay down 13 ea 6" XH DC's. Trip out of hole with 4" HT38 DP. Depth at report time 7800'. Lost 82 bbls brine to formation last 24 hrs. Cont pooh from 7800' racking back 4" HT38 DP stands in derrick. Tower safety meeting, focus on breaking and laying down SHA. Start laying down BHA. Did not recover Hook Hanger. LD Diverter. Discussed options with town Engineers. Wait on Baker HR running tool. PU and run in hole with Baker HR Tool (6.80" OD), bumper sub and jars on HT38 drill pipe to fish out Hook Hanger. Rih with 4" HT38 DP to 4800 ft. Kick / BOPE drill /audit, followed up by debrief and safety meeting. Cont trip in hole to 8200' with 4" HT38 DP stands from derrick. Lost 93 bbls brine to formation last 24 hrs. Cont rih stands from 8200' to 9345'. Check weights up 87 Klbs /down Printed: 10!28/2005 10:23:49 AM • ConocoPhillips Alaska Page 7 of 9 Operations Summary Report Legal Well Name: 1 E-117 Common W ell Name: 1 E-117 Spud Date: 6/20/2005 Event Nam e: WORKO VER/RE COMP Start: 9/24/2005 End: Contractor Name: Rig Release: Group: Rig Name: Nabors 3 S Rig Number: Date From - To Hours Code Phase Description of Operations Code 10/10/2005 00:00 - 02:30 2.50 WELLS TRIP CMPLT3 27 Klbs. 02:30 - 04:00 1.50 WELLS TRIP CMPLT3 Cont rih to 9600' picking up singles, HR running/pulling tool latch mechanism at 9590'. (Top of ZXP Packer at 9647' MD). No indications of weight fluctuations across window area. Weights up 95 /down 25 Klbs 04:00 - 04:30 0.50 WELLS TRIP CMPLT3 POOH past window to 9300' , no indications of weight fluctuations 04:30 - 12:30 8.00 WELLS TRIP CMPLT3 POOH with HR tool, standing back DP. 12:30 - 13:00 0.50 WELLS TRIP CMPLT3 Layed down BHA. 13:00 - 14:00 1.00 WELLS TRIP CMPLT3 Pick up and make up 8-1/2" Venturi Junk Basket, 8 jts 4" HT 38 drill pipe, bumper sub and oil jar. Tower safety meeting. 14:00 - 21:00 7.00 WELLS TRIP CMPLT3 RIH on 4" HT 38 drill pipe to 9375'. Check weights up 93 /down 30 Klbs. 21:00 - 22:30 1.50 WELLS WASH CMPLT3 Cont rih tag up !set down 4 Klbs at 9397'. Pick up full wt at 9393', bumper sub open at 9391'. Rih set down 6000 Ibs at 9397'. Set back stand, make up single and head pin. Pick up to 9350'. Rih while pumping at 4.6 BPM / 390 psi pump press. Tag up gently at 9397'. Repeat wash run same interval 3 times. See gradual incr in p/u weigth, final p/u weight from tag was 110 Klbs, gradually dropping off until normal at +-75 ft above tag. 22:30 - 00:00 1.50 WELLS TRIP CMPLT3 Pooh racking back 4" HT38 DP stands in derrick. Depth at rpt time 6600'. Lost 91 bbls brine to formation last 24 hrs. 10/11/2005 00:00 - 05:00 5.00 WELLS TRIP CMPLT3 Cont pooh from 6600' to 267' standing back4" HT38 DP in derrick. in 05:00 - 07:30 2.50 WELLS PULD CMPLT3 Lay down 8.5" Venturi Jet Junk Basket BHA. Recover Minor cement 'rocks' and 3 pieces of steel, appr L 2" x W 0.4". Pictures of debris on NSK server 07:30 - 09:00 1.50 WELCT BOPE CMPLT3 Make up running tool to test jnt, pull wear ring. 09:00 - 11:30 2.50 WELCT BOPE CMPLT3 Make up ported pump in sub, dart- 8 safety valves, test plug. Rih and land same in wellhead. 11:30 - 12:00 0.50 WELCT BOPE CMPLT3 Attempt to test Annular Preventer, leak at Choke Line HCR. Grease seals and re-test, still leaking. Blow down and ready to replace HCR. 12:00 - 15:00 3.00 WELCT BOPE CMPLT3 Replace leaking Choke Line HCR 15:00 - 18:00 3.00 WELCT BOPE CMPLT3 Perform weekly BOPE test to 250 psi / 3000 psi. State witness of BOPE test waived by John Spaulding @ 12:00 pm 10/10/05. 18:00 - 19:00 1.00 WELCT BOPE CMPLT3 Pull test plug, set wear ring in wellhead, lay down test equipm. 19:00 - 21:00 2.00 WELCT BOPE CMPLT3 PJSM. Pick up Kelly, press test upper & lower Kelly valves to 250 psi / ; 3000 psi. Break out test sub and stand back Kelly. Weekly ROPE test complete. 21:00 - 22:30 1.50 WELLS OTHR CMPLT3 ; PJSM. Remove BOP test equipm from rig floor- WOO- Clean and clear rig floor. 22:30 - 00:00 1.50 WELLS PULD CMPLT3 Pick up BHA: 3.625" Venturi Jet Junk Basket w/ 4.625" Burning Shoe, Bit Sub, 62 ft of 2.875" PAC DC's, X-O's, 316 ft of 4" HT38 DP, Bumper Sub and Oil Jars. See DIMS Tally for details. Depth at rpt time 443 ft. Lost 101 bbls of 8.9 ppg Brine to formations last 24 hrs. 10/12/2005 00:00 - 04:00 4.00 WELLS TRIP CMPLT3 Trip in hole to 7670' with 4.625" Venturi Jet Junk Basket BHA on 4" HT38 DP std's from derrick. 04:00 - 06:00 2.00 RIGMNT RSRV CMPLT3 PJSM. Slip & Cut Drill Line. 06:00 - 08:00 2.00 WELLS TRIP CMPLT3 Continue trip in hole to 7670' with 4.625" Venturi Jet Junk Basket BHA on 4" HT38 DP std's from derrick. 08:00 - 09:15 1.25 FISH WASH CMPLT3 : Record up and down wts just above Top of Hook hanger up wt = 98K dwn wt = 37K. Saw no movement of wt indicator when passing top of Hook hanger. Tagged top of ZXP @ 9647', set 5K on it an felt past. Tagged top of SBE Xover @ 9664' set 5K down, no movement, set 10K down, fell thru. Lowered down and tagged bottom of of SBE @ 9687'. Printed: 10/28/2005 10:23:49 AM ConocoPhillips Alaska Operations Summary Report Page 8 of 9 Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Spud Date: 6/20/2005 Event Name: WORKOVER/RECOMP Start: 9/24/2005 End: Contractor Name: Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Code Phase 10/12/2005 108:00 - 09:15 I 1.251 FISH I WASH 09:15 - 12:30 3.25 WELLS CIRC 12:30 - 19:30 7.00 WELLS TRIP 19:30 - 21:00 I 1.501 WELLSR PULD 21:00 - 00:00 ~ 3.001 WELLSR OTHR 10/13/2005 00:00 - 02:00 2.00 WELLS PULD 02:00 - 09:00 7.00 WELLS PULD 06:00 - 17:00 1.00 WELLS PLGM 17:00 - 18:30 ~ 1.50 WELLSR, PLGM 18:30 - 20:30 I 2.00 I WELLSR PLGM 20:30 - 21:00 I 0.50 I WELLSR DEOT 21:00 - 22:00 1.00 WELLS RURD 22:00 - 00:00 2.00 WELLS TRIP 10/14/2005 05:00 - 19:00 14.00 WELLS TRIP 19:00 - 00:00 ~ 5.001 WELLSR PULD 10/15/2005 00:00 - 02:00 1.00 CMPLTNI PU LD 02:00 - 15:15 I 13.25 ~ CMPLTNI PULD 15:15 - 17:30 I 2.25 I CMPLTNI SOHO Description of Operations CMPLT3 NU headpin establish circulation 36PM @ 810 psi. Run down while pumping and tagged up at same 9687', made this same movement 3 times to clean out. CMPLT3 Picked up to 9657' and circulated hole volume to balance well. CMPLT3 Lay down 4 jts 4" HT 38 Drill Pipe and POOH standing back 150 stands. CMPLT3 Lay down BHA. Recover 1/6 gal cement lumps in Junk Basket barrel. See pictures on NSK server. CMPLT3 Clear and clean rig floor, prep to run completion. Load completion assy's into pipe shed and strap same. CMPLT3 Make final preparations to run completion. PJSM for completion. CMPLT3 Pick up & make up completion Sub Assy's: Seal Assy, 4.5" tbg Spacer Jnt's, LEM, Premier Packer, Seal Bore Ext, Liner Setting Sleeve and Running Tool. CMPLT3 RIH 'D' Lateral LEM assy on 4" HT 38 drill pipe, on bottom at 16:00 CMPLT3 Stopped to get up &dwn wts. UP=94K dwn=32K. Lowered LEM slowly past top of Hook @ 9397' clear, lowered past top of ZXP @ 9647' clear. Continued in hole to 9665' set 10k down, no movement. PU UP wt = 97K. Lowered back down tagged same @ 9665' set 10K down again no movement. PU UP wt 97K again. Lowered back down a little faster, tagged again @ 9665' put 10K down wt fell off. RIH to 9667' set 10k down no movement. PU UP wt= 103K. RIH tagged same spot @ 9667', set 15K down wt fell off. RIH steady down to 9675' set down 10K. PU UP 90K RIH set 15K down at same spot 9675'. Shut down activity, call Engineer. CMPLT3 PU to UP wt 94K lowered at faster rate, set down at same spot 9675', put 20k wt fell off made 2' (9677'). Set all wt dwn (32K). PU to 110K to confirm Iatch.This put bottom seals in the middle of the "B" lateral LEM seal bore @ 9667'-9687' (9677'). CMPLT3 Drop ball and circ same to seat with 80 bbls at 1.6 BPM / 150 psi. Press test surface lines to 4000 psi. Open headpin and pressure up to 4000 psi to set packer at 9369 ft (top of Premium Retrievable Packer). Clear indication of 2 sets of shear pins in packer shearing. Bled press off to 0 psi, PU to up wt 95K, free, pulled 2'. CMPLT3 Close piperams, pressure up Drill Pipe x 9 5/8" csg annulus to 2500 psi / 30 min, good test, recorded on chart. Pump /bleed back 6.5 bbls. CMPLT3 R/D Headpin, blow down kill&choke lines and std pipe manifold. Clear and clean rig floor in prep for pooh. PJSM. CMPLT3 Pooh with 4" HT38 laying down singles. 108 bbls brine lost to form last 24 hrs. Depth at report time 7900 ft. CMPLT3 Continue tripping ooh laying down 4" HT38 DP and BHA. CMPLT3 Lay down 2 stands from derrick pull wear ring. Rig down the kelly. PJSM CMPLT3 Load remainder of 4.5"tubing in pipe shed and strap same. Replace seal rings and drift all joint's. Lost 108 bbls brine to formation last 24 hrs. CMPLT3 Make final preparations to run completion CMPLT3 Pick up Seal Assy w/ Muleshoe. Rih 2 ea 4.5" tbg jnt's. Pick up and make up'CMU' Sliding Sleeve Assy. CMPLT3 Rih with 4.5" 12.6# L-80 IBTM tubing joints. Weights UP 77 K /DOWN 27 K CMPLT3 Tagged top of liner sleeve with muleshoe on depth @ 9321'. Pick up rotate to get into sleeve. Tagged bottom of crossover below the Liner Printed: 10/28/2005 10:23:49 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: WORKOVER/RECOMP Contractor Name: Rig Name: Nabors 3S Date From - To ' Hours Code Co e ~ Phase Start: 9/24/2005 Rig Release: Rig Number: Page 9 of 9 Spud Date: 6/20/2005 End: Group: Description of Operations 10/15/2005 ~ 15:15 - 17:30 ~ 2.25 (CMPLTN SOHO CMPLT3 setting sleeve @ 9332' with locator, end of seals (muleshoe) @ 9349'. 17:30 - 19:30 I 2.00 I CMPL' 19:30 - 20:00 I 0.50 I CMPL' 20:30 - 22:30 I 2.00 I CMPL 22:30 - .00:00 I 1.50 10/16/2005 100:00 - 01:00 I 1.00 I CMPL 01:00 - 06:00 5.OO) WAITI 06:00 - 07:30 1.50 CMPL 07:30 - 12:00 4.50 12:00 - 12:30 0.50 12:30 - 15:30 3.00 15:30 - 16:00 I 0.50 16:00 - 00:00 8.00 MOVE Set 10K down several times space out 2' off no-go. Layed down 3 jts. Installed space out pups, PU jt 306, make up hanger with head pin to pump corrosion inhibitor. CIRC CMPLT3 Pumped 25 bbls 8.9 ppg brine with 2% by volume Petrolite CRW-132 (corrosion inhibitor) followed with 120 bbls 8.9 brine to spot. Close annular and bullhead 10 bbls @1.6 BPM / 80 psi. SOHO CMPLT3 Open Annular Preventer. Drain BOP stack. Rih with Tubing Hanger, orient and land same. Make up Lock Down Bolts, back out & lay down landing joint. Press test between seals on Tubing hanger to 4000 psi. SOHO CMPLT3 Found orientation of Tbg Hanger side outlet to be appr 180 deg oposite flow line outlet on Well Head. B/O Lockdown Bolts. Install landing jnt and pull Tbg Hanger to Rig Floor, confirm orienting slot to be incorrectly machined / no match to wellhead. EOIP CMPLT3 Locate replacement Tubing Hanger at KCC, wait for same to arrive on location. Lost 95 bbls brine to formation last 24 hrs. SOHO CMPLT3 Bring replacement Tubing Hanger to rig floor. Attempt to make up lift sub to 4.909" MCA Box top of hanger, no-go, 1 thread entered only. Attempt to m/u landing jnt to 4.909" MCA Box. No-go. Lay down tbg hanger. EOIP CMPLT3 Hot shot replacement tubing Hanger to Baker Machine Shop, Deadhorse. Machine threads and return to location. SOHO CMPLT3 MU new tubing hanger, RIH and orient and land same. Confirm side outlet lines up with flow line. RILDS. Set BPV. NUND CMPLT3 ND BOPE. NU tree. PLGM CMPLT3 Set two way check. SEOT CMPLT3 Test tree to 250 / 5000 psi. Tubing hanger void / packoff to 250 /5000 psi. PLGM CMPLT3 Pull two way check and set BPV, secure well, clean cellar area. Release rig @1600 hrs 10/16/2005. MOVE MOVE Prepare rig for move to 1 E-117. Lower derrick at 19.30 hrs -Pull pipe shed & pits away. Move rig from !E-117 to 1E-170. Printed: 10/28/2005 10:23:49 AM D~ s~viTc~~ Halliburton Sperry-Sun Western North Slope ConocoPhillips Kuparuk 1 E 1E-117L1 Job No. AK-ZZ-0003775114, Surveyed: 21 July, 2005 Survey Report 1 September, 2005 Your Ref.• AP1500292325160 Surface Coordinates: 5959600.86 N, 550300.51E (70° 18' 01.4269" N, 149° 35' 33.4054" Vl~ Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 959600.86 N, 50300.51E (Grid) Surface Coordinates relative to Structure: 162.13 S, 409.92E (True) Kelly Bushing Elevation: 94.90ft above Mean Sea Level Kelly Bushing Elevation: 94.90ft above Project V Reference Kelly Bushing Elevation: 94.90ft above Structure ^RILLING SERVICES Survey Ref:svy2198 A Halliburton Company :] • Halliburton Sperry-Sun .Survey Report for Kuparuk 1E - 1E-117L1 Your Ref: API 500292325160 Job No. AK-ZZ-0003775114, Surveyed: 21 July, 2005 Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 11632.35 90. 980 176.040 3256.29 3351.19 10077.62 S 1969.63E 5949536.65 N 552337. 55 E 11650.00 91. 180 176.090 3255.96 3350.86 10095.23 S 1970.84E 5949519.05 N 552338. 88 E 11728.42 89. 380 177.090 3255.58 3350.48 10173.51 S 1975.50E 5949440.81 N 552344. 07 E 11820.08 89. 640 177.090 3256.36 3351.26 10265.04 S 1980.15E 5949349.30 N 552349. 34 E 11914.38 89. 760 178.070 3256.85 3351.75 10359.26 S 1984.14E 5949255.12 N 552353. 95 E 12006.80 89. 080 178.260 3257.79 3352.69 10451.63 S 1987.10E 5949162.77 N 552357. 52 E 12098.64 89. 330 179.300 3259.06 3353.96 10543.43 S 1989.05E 5949070.98 N 552360. 09 E 12192.80 91. 070 178.390 3258.74 3353.64 10637.57 S 1990.95E 5948976.86 N 552362. 62 E 12284.64 90. 000 179.470 3257.88 3352.78 10729.39 S 1992.66E 5948885.05 N 552364. 95 E 12377.01 90. 320 179.090 3257.62 3352.52 10821.75 S 1993.82E 5948792.70 N 552366. 73 E 12471.82 91. 060 179.820 3256.48 3351.38 10916.55 S 1994.73E 5948697.91 N 552368. 27 E 12564.40 91. 860 181.250 3254.12 3349.02 11009.09 S 1993.86E 5948605.36 N 552368. 02 E 12657.07 91. 860 180.830 3251.11 3346.01 11101.70 S 1992.18E 5948512.75 N 552366. 96 E 12748.82 91. 920 181.680 3248.09 3342.99 11193.37 S 1990.17E 5948421.06 N 552365. 57 E 12841.71 91. 480 181.930 3245.33 3340.23 11286.18 S 1987.25E 5948328.24 N 552363. 26 E 12934.18 91. 670 181.710 3242.79 3337.69 11378.56 S 1984.31E 5948235.83 N 552360. 95 E 13026.75 91 .550 181.620 3240.19 3335.09 11471.06 S 1981.62E 5948143.32 N 552358. 88 E 13119.32 91 .800 181.430 3237.48 3332.38 11563.56 S 1979.16E 5948050.81 N 552357. 03 E 13212.32 91 .300 181.460 3234.97 3329.87 11656.49 S 1976.82E 5947957.86 N 552355. 31 E 13305.41 91 .980 181.070 3232.30 3327.20 11749.52 S 1974.76E 5947864.82 N 552353. 88 E 13397.40 91 .360 181.450 3229.62 3324.52 11841.45 S 1972.74E 5947772.88 N 552352. 47 E 13491.60 91 .120 179.400 3227.58 3322.48 11935.62 S 1972.04E 5947678.71 N 552352. 41 E 13584.33 90 .500 179.960 3226.27 3321.17 12028.34 S 1972.56E 5947586.00 N 552353. 54 E 13677.26 90 .930 177.820 3225.11 3320.01 12121.24 S 1974.36E 5947493.11 N 552355. 97 E 13769.12 93 .100 178.430 3221.88 3316.78 12212.98 S 1977.36E 5947401.39 N 552359. 58 E 13862.60 92 .040 177.190 3217.69 3312.59 12306.30 S 1980.93E 5947308.10 N 552363. 78 E 13955.33 91 .670 177,360 3214.69 3309.59 12398.88 S 1985.34E 5947215.55 N 552368. 80 E 14048.32 91 .300 176.200 3212.28 3307.18 12491.69 S 1990.56E 5947122.78 N 552374. 65 E 14134.36 91 .550 176.670 3210.14 3305.04 12577.53 S 1995.91E 5947036.97 N 552380. 57 E 14233.07 91 .490 177.350 3207.52 3302.42 12676.07 S 2001.06E 5946938.47 N 552386. 38 E 14326.95 91 .550 178.280 3205.03 3299.93 12769.85 S 2004.63E 5946844.71 N 552390 .58 E 14419.73 91 .240 178.460 3202.77 3297.67 12862.57 S 2007.27E 5946752.02 N 552393. 84 E 14512.07 92 .470 180.420 3199.78 3294.68 12954.85 S 2008.17E 5946659.75 N 552395 .36 E 14607.36 90 .980 179.780 3196.91 3291.81 13050.09 S 2008.01E 5946564.50 N 552395 .83 E 14705.45 90 .920 179.250 3195.29 3290.19 13148.16 S 2008.84E 5946466.44 N 552397 .32 E ConocoPhillips Dogleg Vertical Rate Section (°/100ft) Comment 10077.62 Tie-On Point 1.168 10095.23 Window Point 2.626 10173.51 0.284 10265.04 1.047 10359.26 0.764 10451.63 1.165 10543.43 2.085 10637.57 1.655 10729.39 0.538 10821.75 1.096 10916.55 1.769 11009.09 0.453 11101.70 0.928 11193.37 0.545 11286.18 0.314 11378.56 0.162 11471.06 0.339 11563.56 0.539 11656.49 0.842 11749.52 0.790 11841.45 2.191 11935.62 0.901 12028.34 2.349 12121.24 2.454 12212.98 1.744 12306.30 0.439 12398.88 1.309 12491.69 0.619 12577.53 0.691 12676.07 0.992 12769.85 0.386 12862.57 2.505 12954.85 1.702 13050.09 0.544 13148.16 • • 1 September, 2005 - 15:49 Page 2 of 4 DrillG?uest 3.03.06.008 Ha!!i>bur~on Sperry-Sun Survey Reporf for Kuparuk 1E- 1E-117L1 Your Ref: API 500292325160 Job No. AK-ZZ-0003775114, Surveyed: 21 July, 2005 Western North Slope Measured True Sub-Sea Vertical Local Coordi nates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 14800.87 91.300 179.670 3193.44 3288.34 13243.56 S 2009.74E 5946371.05 N 552398.86 E 14896.17 91.980 179.980 3190.71 3285.61 13338.82 S 2010.03E 5946275.79 N 552399.78 E 14990.85 90.790 178.020 3188.42 3283.32 13433.45 S 2011.68E 5946181.18 N 552402.07 E 15085.28 91.240 179.060 3186.75 3281.65 13527.83 S 2014.09E 5946086.81 N 552405.11 E 15181.32 91.670 179.630 3184.31 3279.21 13623.84 S 2015.18E 5945990.82 N 552406.85 E 15273.65 90.610 178.770 3182.47 3277.37 13716.14 S 2016.47E 5945898.53 N 552408.75 E 15365.21 89.680 178.910 3182.24 3277.14 13807.68 S 2018.33E 5945807.00 N 552411.22 E 15457.95 89.440 177.590 3182.96 3277.86 13900.37 S 2021.16E 5945714.33 N 552414.67 E 15549.99 91.300 178.950 3182.36 3277.26 13992.36 S 2023.94E 5945622.36 N 552418.07 E 15635.59 90.670 178.810 3180.89 3275.79 14077.93 S 2025.61E 5945536.81 N 552420.31E -- 15667.00 90.670 178.810 3180.52 3275.42 - 14109.33 S 2026.26E 5945505.41 N 552421.18 E -- All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. 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 15667.OOft., The Bottom Hole Displacement is 14254.09ft., in the Direction of 171.828° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 11632.35 3351.19 10077.62 S 1969.63 E 11650.00 3350.86 10095.23 S 1970.84 E 15667.00 3275.42 14109.33 S 2026.26 E Comment Tie-On Point Window Point Projected Survey ConocoPhillips Dogleg Vertical Rate Section Comment (°/100ft) 0.594 13243.56 0.784 13338.82 2.421 13433.45 1.200 13527.83 0.743 13623.84 1.478 13716.14 1.027 13807.68 1.447 13900.37 2.503 13992.36 0.754 14077.93 0.000 14109.33 Projected Survey L • 1 September, 2005 - t 5:49 Page 3 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-117L1 Your Ref: AP1500292325160 Job No. AK-ZZ-0003775114, Surveyed: 21 July, 2005 Western North Slope Survey tool program for 1E-117L1 From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 534.60 533.84 534.60 533.84 15667.00 3275.42 ConocoPhillips Survey Tool Description CB-SS-Gyro (1E-117PB1) MWD+IIFR+MS+SAG (1E-117P61) • 1 September, 2005 - 15:49 Page 4 of 4 DrillQuest 3.03.06.008 DEFfs~9T§~!~ Halliburton Sperry-Sun Western North Slope ConocoPhillips Kuparuk 1 E 1 E-117L 1 PB 1 Job No. AK-ZZ-0003775114, Surveyed: 16 July, 2005 Survey Report 1 September, 2005 Your Ref: AP1500292325171 Surface Coordinates: 5959600.86 N, 550300.51E (70° 18' 01.4269" N, 149° 35' 33.4054" VIA Grid Coordinate System: NA027 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 959600.86 N, 50300.51E (Grid) Surface Coordinates relative to Structure: 162.13 S, 409.92E (True) Kelly Bushing Elevation: 94.90ft above Mean Sea Level Kelly Bushing Elevation: 94.90ft above Project V Reference Kelly Bushing Elevation: 94.90ft above Structure SpEC't'~~-SUf~i DRILLING ~SERVtCES Survey Ref:svy2160 A Halliburton Company Halliburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-117L1PB1 Your Ref: API 500292325171 Job No. AK-ZZ-0003775114, Surveyed: 16 July, 2005 Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 9615.61 80.250 181.310 3291.61 3386.51 8064.44 S 1955.09E 5951549.68 N 552309.54 E _' 9706.00 81.480 180.690 3305.96 3400.86 •= 8153.67 S 1953.53E 5951460.45 N 552308.58 E 9751.83 84.910 181.220 3311.39 3406.29 8199.17 S 1952.78E 5951414.95 N 552308.13 E 9813.67 91.700 181.930 3313.22 3408.12 8260.92 S 1951.08E 5951353.19 N 552306.84 E 9903.92 93.100 182.960 3309.44 3404.34 8351.00 S 1947.23E 5951263.08 N 552303.60 E 10000.73 93.890 181.590 3303.54 3398.44 8447.55 S 1943.39E 5951166.50 N 552300.41 E 10096.29 92.840 181.530 3297.93 3392.83 8542.91 S 1940.80E 5951071.13 N 552298.45 E 10190.77 92.780 181.120 3293.30 3388.20 8637.25 S 1938.62E 5950976.78 N 552296.90 E 10290.22 92.410 180.050 3288.79 3383.69 8736.60 S 1937.60E 5950877.43 N 552296.55 E 10387.35 90.740 180.480 3286.12 3381.02 8833.68 S 1937.15E 5950780.34 N 552296.75 E 10483.71 90.680 179.450 3284.93 3379.83 8930.04 S 1937.21E 5950683.99 N 552297.46 E 10579.92 89.630 179.520 3284.67 3379.57 9026.24 S 1938.08E 5950587.80 N 552298.96 E 10676.92 90.820 178.780 3284.29 3379.19 9123.23 S 1939.51E 5950490.82 N 552301.05 E 10773.49 91.990 178.160 3281.92 3376.82 9219.73 S 1942.09E 5950394.34 N 552304.28 E 10870.16 93.410 178.440 3277.37 3372.27 9316.25 S 1944.96E 5950297.84 N 552307.79 E 10966.63 92.600 177.350 3272.31 3367.21 9412.52 S 1948.50E 5950201.60 N 552311.97 E 11063.20 92.040 177.590 3268.40 3363.30 9508.91 S 1952.75E 5950105.23 N 552316.87 E 11159.88 90.990 178.500 3265.84 3360.74 9605.50 S 1956.05E 5950008.67 N 552320.82 E 11257.36 90.990 179.490 3264.16 3359.06 9702.95 S 1957.76E 5949911.23 N 552323.18 E 11354.00 90.680 178.740 3262.75 3357.65 9799.57 S 1959.25E 5949814.63 N 552325.32 E 11448.55 91.120 178.030 3261.27 3356.17 9894.07 S 1961.92E 5949720.15 N 552328.62 E 11540.97 92.050 178.150 3258.71 3353.61 9986.40 S 1965.00E 5949627.84 N 552332.31 E 11632.35 90.980 176.040 3256.29 3351.19 10077.62 S 1969.63E 5949536.65 N 552337.55 E 11726.17 92.050 176.280 3253.81 3348.71 10171.20 S 1975.91E 5949443.11 N 552344.46 E 11822.25 91.610 176.140 3250.74 3345.64 10267.02 S 1982.25E 5949347.34 N 552351.45 E 11853.00 91.610 176.140 3249.88 3344.78 10297.69 S 1984.32E 5949316.69 N 552353.72 E All data is in Feet (US Survey) unless otherwise state d. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are re lative to Well. Global Northings and Eas tings are rel ative to NAD27 Alaska State Planes., Zone 4. The Dogleg Se verity is in Degrees pe r 100 feet (US Survey). Vertical Section is from Well and calc ulated along an Azimuth of 1 80.000° (True). Based upon Mi nimum Cu rvature type calculations, at a Measured Depth of 11853.OOft , The Bottom Hole Displacement is 10487.13ft., in the Direction of 1 69.093° (True). ConocoPhillips Dogleg Vertical Rate Section Comment (°/100ft) 8064.44 Tie-On Point 1.520 8153.67 Window Point 7.572 8199.17 11.040 8260.92 1.925 8351.00 1.631 8447.55 1.101 8542.91 0.438 8637.25 1.137 8736.60 1.775 8833.68 1.071 8930.04 1.094 9026.24 1.445 9123.23 1.371 9219.73 1.497 9316.25 1.406 9412.52 0.631 9508.91 1.437 9605.50 1.015 9702.95 0.840 9799.57 0.883 9894.07 1.015 9986.40 2.588 10077.62 1.169 10171.20 0.481 10267.02 0.000 10297.69 Projected Survey ~~ 1 September, 2005 - 15:44 Page 2 of 3 DriflQuest 3.03.06.008 - ,.. Western North Slope Comments Halliburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-117L1P61 Your Ref: API 500292325171 Job No. AK-ZZ-0003775114, Surveyed: 16 July, 2005 Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 9615.61 3386.51 8064.44 S 1955.09 E 9706.00 3400.86 8153.67 S 1953.53 E 11853.00 3344.78 10297.69 S 1984.32 E Survey tool program for ~E-~~7L1PB1 From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 534.60 533.84 To Measured Vertical Depth Depth (ft) (ft) 534.60 533.84 11853.00 3344.78 Comment Tie-On Point Window Point Projected Survey Survey Tool Description CB-SS-Gyro (1E-117P61) MWD+IIFR+MS+SAG (1E-117P61) ConocoPhillips • • 1 September, 2005 - 15:44 Page 3 of 3 Dri1/Quesr 3.03.06.008 • • 23-Sep-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 E-117 L1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 11,632.35' MD Window /Kickoff Survey: 11,650.00' MD (if applicable) Projected Survey: 15,667.00' 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_~ Signed Please call meat 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) a ~ ~ = ~~ ~ • • 23-Sep-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 E-117 L1 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 9,615.61' MD Window /Kickoff Survey: 9,706.00' MD (if applicable) Projected Survey: 11,853.00' 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 ~ ~ ~~~ Signed - Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) do3 -oz7 • • ~ ~ ~ .~ '~ i s.bl ~ ~`~ ~ 1~1, ' ''°' ~~ a v e~~ )~~ i 1 a1 ~~~~ ~3 ~~~~r r ~ ~d ~ 7 14 ~ ~ ~ ~ ~ `3 ; T~ ' ; ; ~ , ~ '~ '°~h ~ °~ ~ ~ i'~ ~ j FRANK H. MURKOWSKI GOVERNOR , ~ ~~ , ~ ~ ~, , ~ ~ a, ~ ~ , a ~ ~~ ~~+ ~t ~ ~+ ~4[>•-7~A OIL ~ ~ ~ 333 W. T" AVENUE, SUITE 100 ;~f CO1~T5ERQA'1`IO1~T COMI~II5SIOI~T 501-3539 27 RA 1 '~ PHONE 907) 9- 433 FAX (907) 276-7542 Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99519 Re: 1E-117 L1 Sundry Number: 305-324 Dear Mr. Dethlefs: 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. DATED this2 / da of October 2005 y , Encl. 10/'L1/10b5 17:57 90765 NSK WELLS GROI ~ PAGE 02 9 ~ ~ `" . ~ ,~ sTAT>= of a~ASKa /~, ~~ AI..~, 3KA QILAND GAS CONSERVATIQN COMMISSION '~~~\ `. APPLII'.ATION FOR SUNDRY p-PPROVAL _.~, .. _. _ 20 AAc 25.2ao 1. Type of Ab Edt ^ ,~ aspart4 ^ Operational $huMown ^ Perforate ^ Walver Q Other ^ alter casing ^ ROt air well ^ Plug Perforatlona ^ Stimulate ^ Tlme Extension Cnattge approved program ^ Puf 7Ubing ^ Perforate New Pool ^ Re•enter Suapendetl VVBII ~] 2, pperator Name; ~ 4, Current Well Class: 5, Permit to Drill IVuynber: CanpcoPhillips Aiaska, Inc• oev®lopment ^ Exploratory ^ 205-027 3. Address: stratigrapnie ^ Service ^ B. APl Number, P. O. Box 100360, Anchara e, Alaska 9851 ! 50-429-23251-60 7. KB Eievatlon (it): 9. Well Name and Number; RKB 95' 1 E-11 ~ Li 8. Prop®rty Designation: 10, FieldJPaol(s): Kuperuk River Unlt Kuparuk River Field J West Sak OII Pool 11. ~ PRESENT WELL CONDITION SUMMARY Total depth MI] (ft). Total Depth TVD (ft): Effect'. ~e GepU+ MO (tt}: Effective Pepth TVD (ft): Plugs (measured)_ Junk (measured): 15774' 3415' 15757 3625 Gasin Length ~ Slz® MD TVO Burst Cotiapse CONDUCTOR 10g~ 20" 108' 108 SURFACE 544g' 13-318" 5543' 2364 INTERMEDIATE 10477 9.518" 10572' 351Q UNDULATING A- SANDSLOTTED 3415 LINER 5369' S• 112" 15751' Petfaratipn Depth MD (ft): PerF: ~atlon Oepth TND (ft): Tubing Size: Tubing Grade: Tubing MD (ft}; L1: 9?87.15675' slotted L1: <l 112-3ais' 4-1/2" L-80 9590' Packers and 5SSV Typa: ~ Packers and S$SV MD (ft) no packer na SSSV no SSSV 12, Attachments: Description $umrnary of Propo+.~ d J"~ 13. W®II Class after proposed work: Temporary Detailed Operations Program Q BOF' Sketch ~ Exploratory ~ Dsveiopment ^ Service 14. Estimated Qate for 15, Well Status aft®r proposed work; Commencing Op®ratlons: d.: Taber 25, 2005 Oil 0 Gas ^ Plwgged ^ Abanddned ^ 16. Herbal Approval: Oate: WAG (] O1NJ n WlN.- ^ WDSPL ~] Commission Representative: 17. I hereby certify that the foregoing is true and c~: •rect to the best of my knowledg®. Contact: MunllNeaaticky 659-7061 Printed Name Je Dethfefs~~" Trtie: Problem Well Supervisor Z ~~~ Signature +c-o-r-~ ~-.rC.J "+'~' -~ Phone 859-7Q43 date /~J Comrnissiotl Use Onl Sundry Number. Conditions of approval: Notify Commission so th d a repres®ntative may witness -~ Plug Integrity ~ BOP Test ^ M®ci anical Integrity Test n Location Clearance ^ Other: ~~ .7 ~ ~~ ~ ~~~~~~© ~F~ C? ~, i ~ ~ 20D~ Subsequent F ut d: Annrnv . /OMMISSIONEC~ APPROVED BY THE COMMISSION Date: ~~ _,._ _ _ Form •40 i ed 7/ 005 ~ } Submi in Dupil to QRI~I~IA 10/21/2005 17; 57 9076597 NSK WELLS GROU. PAGE 04 ConacaPlwiillips Alaska, )<nc. West Sak [njectian Well X1~-1i7 (PTD 205b260) & L1 ()PTD 2050274) & X,2 (PTD 2054284) SUNK CRY NaTICI ] 0-403 VARIANCE REQUEST 10/21 /05 Th.e purpose o>'this Sundry ~iotice iq for approval to tem.po.rarily pre-produce multilateral West Sak injector lE~l 17. The to nporary production period is not to exceed 45 days from the time it is placed in service. The we+ 1 is new and has not been in previous service. 1 E~117 is a high-an,gl.e infer, lion well with a shallow gaslift mandrel at 1876' MD and a sliding sleEVe at 9248' MD. Deepe: gaslift naa.nd.rels were not run. due to the inability to operate S1.ickHne tools at tl~e high ai .g1e. The shallow gasli.ft mandrel will not provide enough lift for production, so th.e open slid: ra.g al.eeve will be used fn.r lift gas Entry. With the sliding sleeve open ther. a will be known tubing ~ Inner Annulus communication during the production period. A variance from 20 AAC 25,.'? ~0 PRODUCTJQN EQUIPMENT (d) is requested for the limited production period. T'he fol1ow.ing is a su~rnmar;~ of the proposed plan: 1. Sundry 10-403 approval equest for gaslift production, n.ot to exceed 45 days with l~nowr~ T x IA, communication (open' sliding sleeve to be used for gasl.ift); 2. Perform CMIT T x IA or MITIA against a plug to demonstrate the production casing and packer have mechanical. ntegrity; 3. Produce well, not to exc~: ~d 45 days; 4. Close sliding sleeve witl'i coil tubing unit and perform MITI,A prior to injection; 5. Place well ox~ injection s~; rvice; 6. Perform State witra.essed vI.ITIA shortly a.£tcr injection i.s i.n.itiated and submit test results to the AQGCC. After the temporary produc ion status the well will be classified as a Service well. Attached i.s a wellbore schematic from tl'~ ; WeI1 Plan (actual depths m.ay be different}. Q LssulaDed Ca[dxlo[ ~1 Cbi~6+'b'.9+9~.iCSSa 3~•,~s3a•~rr@ ~~ Y~ ~v;~ ~• ~~ ~ ~ ]3dra', E8d,1r8q Bri ~a}~!- 4,i3T !AQ J ~~7a ~69~gre;IDlb Si re ~m A W ~' r20 o ~ ~ ro ~ ~ R Baker, RiW seal hcte aad 2XP packrd ahov~ I E At F5 Z`lOY IJr37ALLID UNk4JOV4N OBSTRUCTION,-~ (a~ -~ 9,592' Lattral F~1ry !AOdule+5 ¢ ES.f], Ha;<~, ~m ~ hate and z~ gackrr etiase. Tuhing, 4Ys' IBTdI, from LEtiito 93Lirx , with sea] seem an6 C.91.{C03.5€d"`DB" ni~da. Sea] hats aadZhl' Eaclxr Ear ,52 Jincr _ +1- 9d Letaw "bn uin9aw 9-5~8', 90d,L-BIk STCfrf, R3 Cs6 ~+~ 10,57x' b,~ 13,675 TYD ~ ~sod,Tnl~lr~•h~ k2Sandliaw, S-'l,',LS.i9,IP0, BTCM, a13 'h sfakled and ~ ulaalr, awisY'acdms j6~imd~wt L2: 8.113' Dsandlagaa] 'ID 15,662' ~ ! 3,399' TYD LI: TD ls.~as ~~!],453' rvls 8.112,2 aaodl~cral 97} 15,75cr 2~II] 13,824 7:YE} ohfag Strict #-]/l', f 25 Y, L-~0, 7H'FT1H 4.S'TUSING'MTH BENT JOINT AND SE,4LS dN END SET 2` ABdVE UNKNdWN OBSTRUCTION ~ - 9,596` L2 "D" Sand 4Vmdaw ~ 9,391' • 93105' 35 de~teea 8.S P~'G BR1NE FRO~Vi TUB]NCs TAIL TO SURF,4CE - THE REST dF THE Pd~THER 84RE Ai~JD LATERALS CdNTAfN 9.0 ~'PG 50LIDS FREE dIL BASED MUD "II° I:mu, 5-1lL', 15.5, I,ffO, HiChf, R3 3S domed and 5l 6lmofs {0.125' x 25` sat 32 ~r foof.39Sl. open area) ~.a "!r' sand e~r~sa~, - ~ 9.7ce - 9,~, 75 depees = - - "a^ Liaer, ~-Vt-, ]S.SV, iao, a'l'Ch~ A3 / ~ 3S clamed sod 3S Ll~, (0.125' x 25' a1Ns, / 32pee~5.436apma~ m N F-+ N m m CJ1 J ~o m p~ [Jl I ~ 1 z cn m r r fil iC] O i~ D m m ~n C~ ;~ ~ lit (: ~~ ~" j~~ ~ ~)~ ~ '~~ '~'~~ ~,j w° t ~ ~ ~ ~ ~ ; , 1 1 A ~ '~ ~ , ~~ ~~ `~ ~ ~ t ~~ .vd ~ au ~ ~ r~ '.~ ~ ~~..o~ a.d ~ ~j ~ ~J AtASsA ou Awn c~As COI~TSERQATIOI~T CO1rII~IISSIOIQ Randy Thomas GKA Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: KRU West Sak 1E-117L1 Sundry Number: 305-281 Dear Mr. Thomas: i FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 +~ PHONE (907) 279-1433 FAX (907) 276-7542 a~~'~~- 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 K. Norman Chairman DATED thisSday of September, 2005 Encl. ' ~ • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~3 tj APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type Of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other Q Alter casing ^ Re air well ^ p Plu Perforations ^ g Stimulate ^ pre-produced ^ Time Extension injector 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 ^ Exploratory ^ 2~7132~3 ~.~~ 3. Address: Stratigraphic ^ Service Q ` 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23251-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 28', 107' AMSL 1 E-117L1 8. Property Designation: 10. Field/Pool(s): ADL 25660, 25651 / 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): 15667' 3275' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 20" 108' 108' SURFACE 5504' 13-3/8" 5544' 2364' INTERMEDIATE Production 10532' 9-5/8" 10572' 3510' Liner 6331' S.5" 15675' 3275' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none none 4.5" L-80 9590' Packers and SSSV Type: Packers and SSSV MD (ft) no packer no SSSV no SSSV 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 14. Estimated Date for 15. Well Status after proposed work: PRE-PRODUCED INJECTOR Commencing Operations: September 23, 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 Mukavitz @ 263-4021 Printed Name Randv Thomas Title: GKA Drilling Team Leader r---~. Signature t, ~ -- Phone a-~ S G~ 3 ~ Date `-~ /~,l~S Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~ Plug Integrity ^ BOP Test -~ Mechanical Integrity Test ^ Location Clearance ^ Other: OC> ~ w~t,~~ ~ Qr~~~ CC3~~`-~~dd~S S ~ ~ ~ ~ 1 ~~~~~ \ ~~~ Subsequent Form Required: ~~~ ~~1 ~~~ ~ ~ 200 .~ Approved by: y~-~ COMMISSIONER APPROVED BY THE COMMISSION Date: / -'7i - ~~ Form 10-403 Revised 7!2005 ~ ~ ° ~ , ~~ Submit in Duplicate ` • Rig Workover Procedure Well 1 E-117 West Sak Injector Remove Obstruction and Complete Well Well History and Rig Workover Objectives: 1 E-117 was drilled and completed as a tri-lateral injector in the West Sak A2, B, and D sands by Doyon 141. Doyon 141 spudded the well June 21, 2005. 9-5/8" production casing was set and the two bottom laterals were drilled and slotted 5-1/2" liners run. After drilling the upper "D" sand lateral, running the 5- 1/2' liner, and installing the Baker Model B Hook Hanger junction at 9386', an attempt was made to install the "D" sand Lateral Entry Module (LEM) Assembly. The seal assembly would not pass through the hook hanger into the main wellbore, but instead went out into the "D" lateral. A second attempt was made to set the LEM, this time the seals were successfully oriented through the hook hanger into the main bore, however, the assembly set down at 9589' MD, approximately 78' above the top of the "B" lateral ZXP seal bore at 9667'. Attempts to rotate and work the seals down further were unsuccessful. A subsequent attempt to make a dummy run with a set of seals, junk basket and bent joint again tagged at 9589' MD and the seals were worked down 3' to 9592'. The assembly then puked tight from 9592' to 9385' (to the top of the hook hanger) with 1 piece of brass and a few pieces of cement recovered form the junk basket when the assembly was pulled. A fourth run with a clean out assembly was unsuccessful in getting through the hook hanger into the main bore, at which time the decision was made to RDMO Doyon 141 and complete the well with Nabors 3S. The well was changed over from 9.0 ppg solids-free OBM to 8.9 ppg NaCI brine at 9380' MD and the clean out assembly was pulled, recovering 2 small pieces of metal and approximately % cup of cement. A 4-1/2" tubing/kill string with a bent joint on bottom was then run and was rotated through the "D" lateral hook hanger and landed at 9590' MD (2' above the final depth of the obstruction at 9592' MD). The 5K tree was nippled up and tested and Doyon 141 was released on August 13, 2005. The objectives of the rig Workover are as follows: ^ POOH with kill string. Install a Mainbore Diverter in the "D" lateral Hook Hanger with a memory MWD tool in the setting string to confirm the actual orientation of the "D" lateral Hook Hanger (the window was milled between 12 and 19 deg left of high-side) ^ If the Mainbore Diverter cannot be installed, try to install the LEM without the lower seal assembly to help orient the Hook Hanger if it is slightly out of line ^ Attempt to re-install the Mainbore Diverter after running the LEM to provide easier access to the main bore and the obstruction at 9592' MD. ^ Clean out the obstruction at 9592' down to the bottom of the "B" lateral ZXP seal bore at 9687' MD using the 3-1/2" work string and clean out assembly. ^ Run the "D" lateral LEM assembly and ZXP packer. If the LEM cannot be installed, run a 9-5/8" Premier packer on the ~vorkstring and set approximately 85' above the "D" lateral Hook Hanger. Test packer and casing to 2500 psi. ^ Run the 4-1l2~' injection tubing and completion equipment and sting into the ZXP or Premier packer. Nipple up the tree. Page 3 9/20/2005 DRAFT r ~ ~ Randy Thomas GKA Drilling Team Leader Drilling & Wells ConocoPhillips September 20, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 Subject: Application for Sundry Approval for 1 E-117, 1 E-117L1, 1 E-117L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the Kuparuk multilateral 1 E-117, 1 E-117L1 and 1 E-117L2. We are planning to re- enterthis well, clean out an obstruction, and run tubing. These wells have been permitted as injectors but we are planning to pre-produce them. We are requesting these sundries to be approved by Friday September 23, 2005. We apologize for the short notice. If this is a problem, please let us know. If you have any questions regarding this matter, please contact me at 265-6830. Sincerely, ~ t R. Thomas GKA Drilling Team Leader CPAI Drilling and Wells RT/skad • • ~ ~ g ~' FRANK H. MURKOWSKt, GOVERNOR 1 ~~ ~~ ~ ~ 333 W. 7'" AVENUE, SUITE 100 COI~TSFiRQATIOIQ COMDIISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchoragae, Alaska 99510 Re: Kuparuk 1 E-117L 1 Sundry Number: 305-233 Dear Mr. Thomas: 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~perior Court unless rehearing has been requested. ~~ DATED this~~ day of August, 2005 Encl. Randy Thomas GKA Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 ~~~~~~~~ ~ ~ ~ ~~ Phone: 907-265-6830 August 15, 2005 ~ " ~ Commissioner State of Alaska ~~:~~~is' ~I <<3 , , n _ Alaska Oil & Gas Conservation Commission s:~~, 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval for 1 E-117, 1 E-117L1, 1 E-117L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the Kuparuk multilateral 1 E-117, 1 E-117L1 and 1 E-117L2. We are planning to shutdown temporarily operations on this well. Please see the attached diagram. There is an unknown obstruction in the mother bore between the top and middle laterals. Our plan forward is as follows: 1. Run video log (non-rig) to obstruction. 2. Evaluate log for rig 3S intervention. 3. MIRU 3S 4. Perform second video log to determine condition of top (D Lateral) liner hanger. 5. Evaluate second video log to determine final completion plan. If you have any questions regarding this matter, please contact me at 265-6830. Sincerely, ~ ( -~ R. Thomas GKA Drilling Team Leader CPAI Drilling and Wells RT/skad ~~ ~ ~. ~. ale-~s' • STATE OF ALASKA ~S 8'//~ ALASKA OIL AND GAS CONSERVATION COMMISSION cb lilo APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon Sus end ^ O erational shutdown ~ ^ ^ p p ^ Perforate ^ Waiver ^ Other Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended WeIL_1 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ /~ 205-027 v 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23251-60 7. KB Elevation (ft): 9. Well Name and Number: 40' RKB, 107' AMSL 1 E-117L1 8. Property Designation: 10. Field/Pools(s): ADL 25660, 25651 / ALK 470 Ku aruk 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): 15667' 3275' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 108' 108' Surface 5504' 13-3/8" 5544' 2364' Intermediate Production 10532' 9-5/8" 10572' 3510' Liner 6331' S.5" 15675' 3275' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None None None None Packers and SSSV Type: Packers and SSSV MD (ft): None None 12. Attachments: Description Summary of Proposal ~ 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: 8/15/2005 Oil ^ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG 0 GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Pat Reilly a(7. 265-6048 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~ Phone 265-6830 Date ~l rT~os COMMISSION USE ONLY Conditions of approval: Notify. Commission so that a representative may witness Sundry Number: ~a_.S o1-3 Plug Integrity ^ BOP Test ~ Mechanical lnt egrity Test ^ Location Clearance ^ 2 ~ Other. ~~-~~~"~ r ~a~j~ 1n~CW`~~„1 O ~ ~[..~C~~Va~pt~S ~~~`V't~V`Cq,.~~V~ ~~ `~ oh ©=r Coin-c ~ RQDIVIS BFI ~!! ~ ~ ~RO~ APPROVED BY Approve COMMISSIONER THE COMMISSION Date: ~^' Form 10-403 Revised 11/2004 t~ ~' ~ ~ ~'E ~, ~~ -. SUBMIT IN DUPLICATE 0 0 ~~ Insulated Catduetor Casing, 2(1", 94k, KSS x 34", 0.312" WT +/- 80' MD Tubing String: 41 /2", 12.6 N, L-80, IB'I'M ~~. m l3.3/8", 68N; L-80, BTC, R3 («~+l- 4,537 Mll / 2,474' TVD -~ a, 69 degrees TD 16" hole Baker, with seal bore and ZXP packer abm'e. LEM IS NO'f INSTALLL-D Q.5"TUBING WITH BENT JOINT AND SEALS ON END SET 2' ABOVE UNKNOWN OBSTRUCTION I @ ~ 9, 590' L2 "D" Sand Window 9,391' - 9,407 75 degrees 'sJ m ClJ ~: t' o ,~~ w ~i n ^: ~' l7 0 o ~ o ~. y ~' C rrl UNKNOWN OBSTRUCTION~.~ @ ~ 9, 592' Lateral Entry Module Nl (LEM), Baker, with seal bore andLXP packer above. L2 "D"Sand Window Q 9,706' - 9,722' 75 degrees 8.9 PPG BRINE FROM TUBING TAIL TO SURFACE- THE REST OF THE MOTHER BORE AND LATERALS CONTAfN 9.0 PPG SOLIDS FREE OIL BASED MUD "D"Liner, 5.1/T', 15.5q, LSQ BTCM, R3 slotted and % blank, (0.125" ~, 2.5" slots, 32 per foot, S.9% open area) "B" Lurer, 5-Il2", 1 S.StI, L80, BTCM, R3 /~' /slotted uid ; bluilc, (0.125" ~ 2.5" slots, / 32. per foot., 5.9% open area) c~, o '~ ~~ oa csy~i k''a ~vo o,' yon ~ y. ~~~v <~a' 8.~: Tubing,, 4-'/," IBTM, from LEM to A2 Liner, with seal stem and CAMCO 3.562" "DB"nipple. Seal bore and ZXP packer for A2 liner +/- 90' below "B" window 9-5/8", 40q, L-80, B"I'CM, K3 Csg « +/- 10,572' MD / 3,675"fVD -- n, 80 degrees TD 12-1/4" hole A2 Sand Liner, 5-%", t S.Sq, L80, BTCM, R3 % slotted and % blank, cons[riceors_for isolu[io~s L2: 8-1J2" D sand IateraY Tll ]5,662' MD / 3,399' TVD Lt: R-1/2" "B"sand lateral TD L5,675' MD ! 3,453"I'W 8-1/2 A2 surd lateral TD ] 5,752' MD ! 3,625' TVD ~~~ ~`C` ~~: :. .`~;\- ttc: r w . in-i i i riaii rurwaru - ~,ntiivvr, • Subject: Re: FW: 1E-117 Plan Forward -CHANGE From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Fri, 12 Aug 2005 11:07:19 -0800 To: "Reilly, Patrick J" <Patrick.J.Reilly@conocophillips.com> • --~~ s -o a f dos ~oaFS Pat, The total information here is a little sketchy, however based on the conversations with you and Steve yesterday I understand that there is some mechanical obstruction that is preventing the completion tubing from being run as planned. You all have determined to halt operations and set the well up so further evaluation can be done. You plan to run a tubing string deep in the well to facilitate the evaluations which will also provide a kill string for well control/circulating. After the work plan is determined, the 3 S workover rig will move on the well to effect repairs. What you are planning is an "Operational SD" and a sundry will need to be filed. By copy of this email, you plan is acceptable. Please call or message with any questions. Tom Maunder, PE AOGCC Reilly, Patrick J wrote, On 8/12/2005 10:43 AM: Tom, Thanks for discussing 1 E-117 this morning. Please see the plan forward below. Sharon is out today. As per our conversation, we will prepare the sundry on Monday. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907} 265-1535 FAX Patrick.J. Reilly(a~conocophillips. com «Patrick.J, Reiily~conocophillips. com.vcf» -----Original Message----- From: Reilly, Patrick J Sent: Friday, August 12, 2005 10:34 AM To: Doyon 141 Company Man; Lowe, Dan E Cc: Thomas, Randy L; Spenceley, Neil; Gober, Howard; Jerome; McKeever, Steve; Greener, Mike R. Subject: 1E-117 Plan Forward -CHANGE Davis, Eric R.; Peterson, Erick Martin; Paul, Mike, We worked out a plan to get a video fog on the obstruction before 3S moves in. When you leave, the Wells group will run a fiber optic video log down to the obstruction. Howard will have time to evaluate the video log and plan the 3S intervention. When 3S moves in, the rig will pick up the tubing to the hook hanger depth and get a second video 1 of 3 8/16/2005 10:20 AM tce: r w : i r,- i i ~ rtan r orwara - ~nviv~,~ • log of.the hook hanger. '! 1. Continue POOH laying down DP. 2. Remove the burrs from the bottom of the seal assembly on the bent joint. 3. Run 4.5" IBT tubing (with bent joint and seal assembly on bottom) to just above the obstruction in the mother bore. 4. Space out tubing such that the seal assembly is at least 1-2' above the obstruction but not much higher than that. That should allow Wells to get a good video. 5. Land hanger. Howard is arranging the video log with Mark Chaney. Mark can help at the rig site if you need more information on the space out. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J.ReiIlyCc~conocophillips.com «Patrick.J.Rei!lyCc?.conocophiilips.com.vcf» -----Original Message----- From: Reilly, Patrick J Sent: Thursday, August il, 2005 5:26 PM To: Doyon 141 Company Man; Lowe, Dan E Cc: Thomas, Randy L; Spenceley, Neil; Gober, Howard; Davis, Eric R.; Peterson, Erick Martin Subject: 1E-117 P{an Forward Mike, I consulted with Howard Gober and Hal Martens. We came up with the following plan forward after you complete your junk basket run. 6. Displace to 8.9 ppg brine. (Hal is sending the recipe to his mud man on the rig) 7. POOH laying down DP. 8. Run 2,500' of 4.5 IBT tubing as a freeze protect string. (This might change to 3.5" PH6 if the torque required for the workover rig is low enough for PH6). Dan Lowe is running some TAD calculations for Howard. 9. Land hanger. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907} 265-1535 FAX Patrick.J.Reilly ,conocophillips.com 2 of 3 8/16/2005 10:20 AM ~ a ' ~ ~ pp ~~ ~ 3 ~~ ~, ~' ~~ ~ ; °s~ FRANK H. MURKOWSKI, GOVERNOR ~78~ OII/ ~D a]rcaa7 333 W. 7"' AVENUE, -SUITE 100 COI~TSER'QA'1`IO1K COl-II~IISSIOI~T ANCHORAGE, ALASKA 99501-3539 ~' PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk 1 E-117L 1 ConocoPhillips Alaska, Inc. Permit No: 205-027 Surface Location: 11' FSL, 228' FEL, SEC. 16, T11N, R10E, UM Bottomhole Location: 1742' FSL, 3548' FEL, SEC. 34, T11N, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. The permit is for a new wellbore segment of existing well KRU 1E-117, Permit No. 205-026, API 50-029-23251-00. Production should continue to be reported as a function of the original API number stated above. 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. Ple e provide at least twenty-four (24) hours notice for a representative of the Commission wi ess any required test. Contact the Commission's petroleum field inspector at (9659 6(y7j ( ager). DATED this day of February, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ConocoPhillips Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com February 16, 2005 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, West Sak Injector, 1E-117L1 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for an onshore injection wellbore, the upper lateral wellbore of a multilateral horizontal well, in the West Sak ~~B" sand. The main bore of this well will be designated 1E-117 and has been permitted under a separate application, submitted on February 16, 2005. This application is for the middle lateral of that well, to be designated 1E-117L1. The expected date that operations will begin on 1E-117L1 is 4/30/2005. 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 Steve Shultz at 263-4620 if more information is needed. Sincerely, Randy Thomas GKA Drilling Team Leader STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: Drill ^/ Redrill ^ 1 b. Current Well Class: Exploratory Development Oil Multiple Zone ^ Re-entry ^ Stratigraphic Test ^ Service ^~ Development Gas ^ Single Zone Q 2. Operator Name: 5. Bond: Blanket a Single Well ^ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 1 E-117L1 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 15642' ~ TVD: 3261' ~ Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: ,~ Surface: 11' FSL, 228' FEL, Sec. 16, T11 N, R10E, UM ' ADL 25660' West Sak Oil Pool ~ ~ ~:.,,,,~ Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2400' FSL, 3536' FEL, Sec. 27, T11N, R10E, UM ALK470 4/30/2005 ~ i~'° Total Depth: ~ 9. Acres in Properly: 14. Distance to j. ~ ,u; /~;, ~ " 1742' FSL, 3548' FEL, Sec. 34, T11 N, R10E, UM 2560 Nearest Property: ~39Er3 ~3 ~~ 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well ~ Surface: x- 550301 ~ y- 5959601 Zone- 4 ., (Height above GL): 40' RKB / 10T AMSL fvmll`~l `/~ Within Pool: ,,pent ~ x z.3 c 16. Deviated wells: Kickoff depth: G~~~ 932' feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) z't-3~vs" Maximum Hole Angle: 93 deg. Downhole: 1516 psig Surface: 116f psig 18. Casing Program: Specifications Setting Depth Quantity of Cement Size Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 40" 20" 94# K-55 Welded 80' 40' 40' 120' 120' 260 cf ArcticCrete 16" 13-3/8" 68# L-80 Butt 5347' 40' 40' 5387' 2379' 970 sx AS Lite, 260 sx DeepCrete /8'~"' 12.25" 4 L-80 1 40' 40' 10 33' ete 8.5" 5.5" 15.5# L-80 BTCM 6 13' 9600' 3408' 15642' 3261' 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 TVD Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (tt): Perforation Depth TVD (tt): 20. Attachments: Filing Fee ~ ~ BOP Sketch ^ Drilling Program Q Time v. Depth Plot Shallow Hazard Analysis Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Shultz @ 263-4620 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader ..,. Signature ~ ~~~ "' ,~•~, Phone ~~,-~- G~~ yt~ Date ~-~~I~IoS ~ ~... ~z. e _ . ,__------_ Commission Use Only Permit to Drill J ~ API Number: ~ Permit Approval ~ ~ See cover letter for other Number. ~.~, 3. ~7 50- (j ~~ ~~ ~~ ~-• ~j~ j D ~ Date: a ~, ~ requirements Conditions of approval Samples required Yes ^ No ~ Mud log required Yes ^ No Hy ogen sulfide measures Yes' No ^ Directional survey required Yes, No ^ Other: ~ ~ Q e~ V~-~.'v.'~ z~~ ~~s~-. APPRO~/~ED BY Appnveri ~ THE COMMISSION Date: C Form 10-40` R ise v 0~ ~~/ / Sub ~ in Duplicate o~~~~~~L implication for Permit to Drill, Well 1 E-117L1 Revision No.O February 16, 2005 Permit- West Sak #1 E-117L1 Injector "B" Sand) •~°d r.~ ~1 App/ication for Permit to Dril/ Document,; I~IaW~ll M d x i m i a 8 1Mell Vvlue 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) ....................................................................................................... 2 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 ............................................................................................... 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 ORIGINAL Permit for 1E-117L1 Injector Page 1 of 6 Printed: February 16, 2005 • implication for Permit to Drill, Well 1 E-117L1 Revision No.0 February 16, 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 Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 1. Well Name Requirements of 20 AAC 25.005 (f) 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(6). For a well with multip/e well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the weal by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1E-117L1. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) 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: (2) a plat identifying the property and the property's owners Lind showing (A)the coordinates of the proposed location of the wel/ at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the Nationa/ Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth,• Location at Surface FSL 10.5' ,FEL 228', Sec.16, T11 NlR10E ASP Zone 4 NAD 27 Coordinates ~ RKB Elevation 107' AMSL Northings; 5959600.8 Eastings; 550300 Pad Elevation 67' AMSL Location at Top of Productive Interval West Sak "B" Sand FSL 2400', FEL 3536', Sec. 27, T11 N/R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 9600 Northings; 5951444 Eastings; 552344 Total 1/ertical De th RKB; 3408 Tota/ ~ertica/ De th SS.• 3301 Location at Total Depth FSL 1742', FEL 3548', Sec 34, T11 NlR1OE ASP Zone 4 NAD 27 Coordinates Measured De th, RKB; 15642' Northings;5945507 Eastings; 552384 Total l/ertical De th RKB; 3261' Tota/ l/ertica/ De th, SS.• 3154' and (D) other information required by 20 AAC 25.050(6); i Requirements of 20 AAC 25.050(6) If a we/l is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (i) include a plat, drawn to a suitable scale, showing the path of the proposed we//bore, including all adjacent wellbores within 200 feet of any portion of the proposed wel% ORIGINAL Permit for 1E-117L1 Injector Page 2 of 6 Printed: February 16, 2005 implication for Permit to Drill, Well 1 E-117L1 Revision No.0 February 16, 2005 Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wel/bore (A) list the names of the operators of those wells, to t9e extent that those names are known or discoverable in public records, and show that each named operator has been furnishf?d a copy of the application by certified mail; or (B) state that the app/icant 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 following 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 (BOPS) as required by 20 AAC 2s. 035, 20 AAC 2s. 036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1E-117L1. Due to the formation pressures being far less then the rating of the BOPE, CPAI would like to request that the stack be operated under the 3,000 psi BOP guidelines thereby allowing the use of one ram cavity for casing rams and negating an additional BOP test once the intermediate casing has been run. Please see information on Doyon 15 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downho% 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-117L1 area vary from 0.0.44 to 0.0.47 psi/ft, or 8.6 to 9.0 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 1161 psi, calculated thusly: MPSP =(3225 ft)(0.47 - 0.11 psi/ft) =1161 psi ~ (e) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such .as abnormally geo pressured strata, lost circulation zones, and zones that have a propensity for differential 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: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(1); The parent wellbore,lE-117L1, will be completed with 9 5/8" intermediate casing landed in the West Sak B-Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance ORIGINAL Permit for 1E-117L1 Injector Page 3 of 6 Printed: February 16, 2005 implication for Permit to Drill, Well 1 E-117L1 Revision No.O February 16, 2005 with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. ~~~ ~~-at-~b~ 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on Erie with the commission and identified in the application: (6) a campfete proposed casing and cementing program as required by 20 AAC 25.030, 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-117L1: Cement Summa Hole Top Btm Csy/Tbg Size Weight Length MD/TVD MD/TVD OD in) (in) (Ib/ft Grade Connection (ft) ft (ft) Cement Program 20" 40" 94 K55 Welded 80' 40' / 40' 120' / 120' Cemented to surface with 260 cf ArcticCRETE 13 3/8" 16" 68# L-80 Butt 5347' 40'/40' 5387'/2379' Cemented to Surface with 970sx ASLite Lead, 260sx Dee CRETE Tail 12 1/4" 9 5/8" 40# L-80 BTCM 10455' 40'/40' 10495'/3533' Cement Top planned @ 6100' MD/' TVD. Cemented w/ 810 sx Dee CRETE 5 1/2" 8 1/2" °A" 15.5# L-80 BTCM 6052' 9700'/3422' 15752'/3411' Slotted- no cement d ateral ,r 1/ 8 1 B" 15.5# L-80 BTCM 6042' 9600 3408' 3261' Slotted- no ce t slotted Lateral 1 E- 1 5 1 8 1/2"°D" L-80 B M 6289 o ed-no cement slotted Lateral 1 E-117 L2 4 1/2 NA 12.6# L-80 IBTM 9160' 40'/40' 9200'/3300' Production Tubing tubin 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on fi/e with the commission and identified in the application: (7) a diagram and description of the diverter system as requirnd by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 1E-117L1. Please see diagrams of the Doyon 15 diverter system on file with the Commission. ORIGINAL Permit for 1E-117L1 Injector Page 4 of 6 Printed: February 16, 2005 • implication for Permit to Drill, Well 1 E-117L1 Revision IVo.0 February 16, 2005 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) 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: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with mud having the following properties over the listed intervals: Lateral Mud Program (VersaPro, Oil Base Mud) Pro ernes Production Densit pp) 9.0 Funnel Viscosity (seconds) 60 Yield Point (cP) 18-28 Electric Stability 650-900 Chlorides (mgA) NA H NA API filtrate (cc / 30 min) <4 **HTHP filtrate (cc / 30 min) <10 ~' 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 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An app/ication for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item already on fi/e with the commission and identified in the application: (9) for an exploratory or .stratigraphic test wel% a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 20 AAC 25.0.:33(1); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An app/ication for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on fl/e with the commission and identified in the app/ication: (10) for an exploratory or stratigraphic test wel% a seismic refn~ction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11.Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An app/ication for a Perm,~t to Drill must be accompanied by each of the fo/%wing items, except for an item a/ready on fi/e with the commission and identified in the application: (i1) far a we/l drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating dri/ling vess% an ana/ysis ofseabed conditions as required by 20 AAC 25.061(6); Not applicable: Application is not for an offshore well. ORIGINAL Permit for 1E-117L1 Injector Page 5 of 6 Printed: February 16, 2005 implication for Permit to Drill, Well 1 E-117L1 Revision No.O February 16, 2005 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An app/ication for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on fi/e with the commission and identified in the application: (12J evidence showing that the requirements of20 AAC Z5.0.?5 {Bonding}have been met, Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the fa/lowing items, except for an item already on file with the commission and identihe~c/ in the application: The proposed drilling program for 1E-117L1 after the intermediate 9 5/8" casing has been set is listed below. 1. Run and set Baker WindowMaster whipstock system, at window point of 9629' MD / 3408' TVD, the top of the "B" sand. 2. Mill 8 1/2" window. POOH. 3. Pick up drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of "B" sand lateral at 15642' MD / 3261' T~/D, as per directional plan. 5. POOH, back reaming out of lateral. POOH. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4 1/2" slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool, POOH 10. PU LEM, RIH and install same li. POOH and prepare for drilling the "D" lateral. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the fo/%wing items, except for an item a/ready on F/e with the commission and identified in the application: (i4) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annu{ar disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class ~- II disposal well. All cuttings generated will be disposed of by 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. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic ORIGINAL Permit for 1E-117L1 Injector Page 6 of 6 Printed.' February 16, 2005 Injector 1 E-117 Slimhole Design Note: the interemediate and all laterals are to be drilled with rotary steerable 16" Hole (8.8 ppg Spud Mud) 13 3/8" Casing Hydraulics: KOP: 300' Surface: 900-1200 gpm Build at 3-5 Intermediate: 700-900 gpm degrees/ 100' 5387' MD Laterals: 450-500 gpm Figure on a 50 YP for surface 2379' TVD Figure on a 35 YP for intermediate Pore Pressure 1450 psi Figure on a 28 YP for laterals ,~ TVDss 3130 ft TVD 3225 ft MWE 8.6 ppg ,~ Window @ 9352' MD Top of Ugnu "D" Sand (9.0 ppg Oil Base Mud) +l-6600 ' MD \~~~~ ~ ' 811!2" Hole 5 1/2" Liner / --- Top of Cement +/-6100' MD Tangent Angle: 75 degrees • 15639' MD ~.,,--`"" 319 ' -~8'~--~-..._...___..~~-"" 1 "B" Sand (9.0 ppg Oil Base Mud) ! Window C«3 9635'MD 8 1/2" Hole / ~~ ~ 1 /7" 1 ina 12114" Hole (9.0 ppg LSND) 9 5/8" Casing 10,495' MD 3533' TVD (80 degrees) 15642" MD ~ ~ ~ ~ ~ « ~.--~ 3261' 'TVD "A-2" San~Y(9:"0 ppg Oil Base Mud) 8 112" Hole (Undulating) 5 1/2" Liner / 15752' MD 3411' TVD ConocoPhillips Alaska ConocoPhillips Alaska Inc.(Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1 E-117 1 E-117 L1 Plan: 1 E-117 L1 (wp04) Proposal Report 09 February, 2005 L~ pEr-~r~y~-u~r A Halliburton Company ConocoPhillips ~a:~a 1 E-117 L1 (wp04) LEGEND r__ _,..._._... ~.~~,«~ n ,~eacmn _ aer, ~~ _ t11N - 810E Drill out 8 1l2 Hole 9635 fi MD, 3413 ft ND ..~ `~ ,..~ `! C_ O O L a O m U 1= d J H $ Plan 1 E-117, 1 E-117 L2, 1 E-117 L2 (wp04) VO ~ Plan 1 E-117, 1 E-117, 1 E-117 (wp04) VO $ 1E-117 L1 (wp04) 6000 6500 7000 7500 tluuu aouu awv ~~~~ ~~_-- •---- ---- Vertical Section at 180.00° (1000 tVin) w ~- sperry-gun lips al~~.k.i .........w.. West(-)/East(+) (1800 ft/in) -900 0 900 1800 2700 3600 4500 5400 6300 7200 8100 9000 9900 900 Project: Kuparuk River Unit Site: Kuparuk 1 E Pad Well: Plan 1 E-117 0 \ Wellbore: 1 E-117 L1 Plan: 1 E-117 L1 (wp04) ~ Top of Wndow- 2465'FSL & 1745'FWL -Sect 27 - T11 N - R10E : Driu out 81/2 Hole : 9635 ft MD. 3413 ft TVD / -5400 ~ttom Whipstock Assume 13.60°/100ft : 9652 ft MD, 3415 ft ND -5400 c / N o c ~ -6300 0 -6300 ao Z 0 + ~ r -7200 Build @4.00°/100ft , 9682 ft MD, 3418 ft ND I -7200 + -- o i - _ Z _~ " ~ ~ ~ -- o t _-- o o -8100 -8100 ~~. Sail (iil 97.33° Inc & 180.00° Azi, 10009 ft MD, 3414 ft ND Continue Dir @ 3.00°/100ft , 10099 ft MD, 3402 ft ND in B-Lateral : 10234 ft MD, 3390 ft ND -11700 -11700 1 E-117 L1 (wp04) _~~ann _~~ann ~BHL:1747FSL81732FWL-Sed34-T11N-R10E 15642ftMD.3261ftND -900 0 900 1800 2700 3600 4500 5400 6300 7200 8100 9000 9900 West(-)/East(+) (1800 ft/in) ORIGINAL • • . Halliburton Company ~"'t ~C~(Jn Conoco Phillips Planning Report -Geographic AI85Ica A Halllburton Company Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1 E-117 Company: ConocoPhillips Alaska Ina(Kuparuk) TVD Reference: 66.9 GL + 40RF=106.9 @ 106.90ft (Doyon 15 (66.9GL + 40R Project: Kuparuk River Unit MD Reference: 66.9 GL + 40RF=106.9 @ 106.90ft (Doyon 15 (66.9GL + 40R Site: Kuparuk 1 E Pad North Reference: True Well: Plan 1 E-117 Survey Calculation Method: Minimum Curvature ~ Wellbore: 1 E-117 L1 Design: 1 E-117 L1 (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 ~ - Well Plan 1 E-117, Tri -Lateral Injector Well Position +N/-S 0.00 ft Northing: b,9b9,600.86 ft ~ Latitude: 70° 18' 01.427" N +E/-W 0.00 ft Easting: 550,300.b1 ft / Longitude: 149° 35' 33.405" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 68.90 ft Wellbore 1E-117 L1 Magnetics Model Name Sample Date bggm2004 12/15/2004 Design 1 E-117 L1 (wp04) Audit Notes: Version: Phase: Vertical Section: Depth From (TVD) (ft) 40.00 Declination (°) 24.49 PLAN +N/-S (ft) 0.00 Dip Angle Field Strength (°) (n~ 80.74 57,580 Tie On Depth: 9,835.04 +E/-W Direction (ft) (°) 0.00 180.00 2/5/2005 8:28.~47PM Page 2 of 7 COMPASS 2003.11 Build 50 ' • ~ ~-~ Halliburton Company ~h -5UP"1 Conoco Phiilips Planning Report -Geographic Alaska A HaIIIbuROn Company Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well P{an 1 E-117 Company: ConocoPhillips Alaska Inc(Kuparuk) TVD Reference: 66.9 GL + 40RF=106.9 @ 106.90ft (Doyon 15 (66.9GL + 40R Project: Kuparuk River Unit MD Reference: 66.9 GL + 40RF=106.9 @ 106.90ft (Doyon 15 (66.9GL + 40R Site: Kuparuk 1 E Pad North Reference: True Well: Plan 1 E-117 Survey Calculation Method: Minimum Curvature Weltbore: 1 E-117 L1 Design: 1 E-117 L1 (wp04) Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +NlS +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 9,635.04 82.00 180.03 3,413.41 -8,106.52 1,989.69 0.00 0.00 0.00 0.00 9,651.54 84.24 180.03 3,415.39 -8,122.90 1,989.69 13.60 13.60 0.00 0.00 9,681.54 84.24 180.03 3,418.40 -8,152.75 1,989.67 0.00 0.00 0.00 0.00 9,907.44 93.28 180.03 3,423.27 -8,378.36 1,989.55 4.00 4.00 0.00 0.00 10,008.73 97.33 180.00 3,413.91 -8,479.20 1,989.52 4.00 4.00 -0.02 -0.35 10,099.04 97.33 180.00 3,402.39 -8,568.77 1,989.51 0.00 0.00 0.00 0.00 10,234.09 93.28 180.03 3,389.90 -8,703.22 1,989.47 3.00 -3.00 0.02 179.64 10,264.28 92.37 180.00 3,388.41 -8,733.37 1,989.46 3.00 -3.00 -0.10 -178.03 10,831.69 92.37 180.00 3,364.90 -9,300.29 1,989.48 0.00 0.00 0.00 0.00 10,851.75 91.79 180.13 3,364.17 -9,320.34 1,989.45 3.00 -2.93 0.65 167.40 11,052.82 91.79 180.13 3,357.90 -9,521.31 1,989.00 0.00 0.00 0.00 0.00 11,066.68 91.40 179.97 3,357.51 -9,535.16 1,988.98 3.00 -2.78 -1.14 -157.68 12,031.24 91.40 179.97 3,333.90 -10,499.43 1,989.45 0.00 0.00 0.00 0.00 12,045.84 90.97 180.03 3,333.60 -10,514.03 1,989.45 3.00 -2.98 0.37 172.95 13,152.53 90.97 180.03 3,314.90 -11,620.56 1,988.95 0.00 0.00 0.00 0.00 13,209.17 92.67 180.01 3,313.10 -11,677.17 1,988.93 3.00 3.00 -0.02 -0.45 13,772.24 92.67 180.01 3,286.90 -12,239.64 1,988.80 0.00 0.00 0.00 0.00 13,835.67 90.76 179.98 3,285.00 -12,303.03 1,988.80 3.00 -3.00 -0.04 -179.15 ~ 15,641.66 90.76 179.98 3,260.90 ~ -14,108.86 1,989.29 0.00 0.00 0.00 0.00 2/9!2005 8:28:47PM Page 3 of 7 ~~ COMPASS 2003.11 Build 50 lri • ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc.(Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1 E Pad Well: Plan 1 E-117 Wellbore: 1E-117 L1 Design: 1E-117 L1 (wp04) Planned Survey 1 E-117 L1 (wp04) Halliburton Company Planning Report -Geographic Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: spry-sun A Hallfburton Company Well Plan 1 E-117 66.9 GL + 40RF=106.9 @ 106.90ft (Doyon 15 (66.9GL + 40R 66.9 GL + 40RF=106.9 @ 106.90ft (Doyon 15 (66.9GL + 40R True Minimum Curvature Map Map MD Inclination Azimuth TVD SS7VD +N/-S +E/-W Northing Easting tft) (°) (°) (ft) (ft} (ft) (ft) (ft) (ft) 9,635.04 82.00 180.03 3,413.41 3,306.51 -8,106.52 1,989.69 5,951,508.62 552,344.23 Top of Window- 2485'FSL 81745'FWL -Sect 27 - T11 N - R10E :Drill out 8112 Hole : 9835 ft MD, 3413 ft TVD - 9618" Window Top 9,646.91 83.61 180.03 3,414.90 3,308.00 -8,118.29 1,989.69 5,951,496.85 552,344.30 West Sak B 9,651.54 84.24 180.03 3,415.39 3,308.49 -8,122.90 1,989.69 5,951,492.25 552,344.33 Bottom Whipstock :Assume 13.60°I100ft : 9852 ft MD, 3415 ft TVD 9,681.54 84.24 180.03 3,418.40 3,311.50 -8,152.75 1,989.67 5,951,462.40 552,344.51 Build X4.00°/100ft , 9682 ft MD, 3418 ft TVD 9,700.00 84.98 180.03 3,420.13 3,313.23 -8,171.13 1,989.66 5,951,444.02 552,344.63 9,800.00 88.98 180.03 3,425.40 3,318.50 -8,270.97 1,989.61 5,951,344.20 552,345.24 9,900.00 92.98 180.03 3,423.68 3,316.78 -8,370.94 1,989.56 5,951,244.24 552,345.86 9,907.44 93.28 180.03 3,423.27 3,316.37 -8,378.36 1,989.55 5,951,236.81 552,345.90 10,000.00 96.98 180.01 3,415.00 3,308.10 -8,470.54 1,989.52 5,951,144.65 552,346.49 10,008.73 97.33 180.00 3,413.91 3,307.01 -8,479.20 1,989.52 5,951,135.99 552,346.55 Begin Sail ~ 97.33° Inc 8 '180.00° Azi, 10009 ft MD, 3414 ft TVD 10,099.04 97.33 180.00 3,402.39 3,295.49 -8,568.77 1,989.51 5,951,046.43 552,347.14 Continue Dir ~ 3.00°MOOft ,10098 ft MD, 3402 ft TVD 10,100.00 97.30 180.00 3,402.26 3,295.36 -8,569.72 1,989.51 5,951,045.48 552,347.15 10,200.00 94.30 180.02 3,392.15 3,285.25 -8,669.20 1,989.49 5,950,946.01 552,347.79 10,234.09 93.28 180.03 3,389.90 3,283.00 -8,703,22 1,989.47 5,950,912.00 552,348.00 Begin Geosteering in B-Lateral : 10234 ft MD, 3390 ft TVD -1 E-117 L1-T1 (v3) 10,264.28 92.37 180.00 3,388.41 3,281.51 -8,733.37 1,989.46 5,950,881.85 552,348.19 10,300.00 92.37 180.00 3,386.93 3,280.03 -8,769.06 1,989.47 5,950,846.17 552,348.43 10,400.00 92.37 180.00 3,382.79 3,275.89 -8,868.97 1,989.47 5,950,746.27 552,349.10 10,500.00 92.37 180.00 3,378.64 3,271.74 -8,968.88 1,989.47 5,950,646.36 552,349.78 10,600.00 92.37 180.00 3,374.50 3,267.60 -9,068.80 1,989.47 5,950,546.46 552,350.45 10,700.00 92.37 180.00 3,370.36 3,263.46 -9,168.71 1,989.47 5,950,446.56 552,351.12 10,800.00 92.37 180.00 3,366.21 3,259.31 -9,268.63 1,989.48 5,950,346.66 552,351.79 10,831.69 92.37 180.00 3,364.90 3,258.00 -9,300.29 1,989.48 5,950,315.00 552,352.00 1E-117 L1-T2 (v3) 10,851.75 91.79 180.13 3,364.17 3,257.27 -9,320.34 1,989.45 5,950,294.95 552,352.11 10,900.00 91.79 180.13 3,362.67 3,255.77 -9,368.56 1,989.34 5,950,246.73 552,352.32 11,000.00 91.79 180.13 3,359.55 3,252.65 -9,468.51 1,989.12 5,950,146.79 552,352.77 11,052.82 91.79 180.13 3,357.90 3,251.00 -9,521.31 1,989.00 5,950,094.00 552,353.00 1E-117 L7-T3 (v2) 11,066.68 91.40 179.97 3,357.51 3,250.61 -9,535.16 1,988.98 5,950,080.15 552,353.08 11,100.00 91.40 179.97 3,356.70 3,249.80 -9,568.47 1,989.00 5,950,046.84 552,353.32 11,200.00 91.40 179.97 3,354.25 3,247.35 -9,668.44 1,989.05 5,949,946.89 552,354.04 11,300.00 91.40 179.97 3,351.80 3,244.90 -9,768.41 1,989.10 5,949,846.93 552,354.75 11,400.00 91.40 179.97 3,349.35 3,242.45 -9,868.38 1,989.14 5,949,746.97 552,355.47 11,500.00 91.40 179.97 3,346.91 3,240.01 -9,968.35 1,989.19 5,949,647.01 552,356.19 11,600.00 91.40 179.97 3,344.46 3,237.56 -10,068.32 1,989.24 5,949,547.06 552,356.91 11,700.00 91.40 179.97 3,342.01 3,235.11 -10,168.29 1,989.29 5,949,447.10 552,357.62 11,800.00 91.40 179.97 3,339.56 3,232.66 -10,268.26 1,989.34 5,949,347.14 552,358.34 11,900.00 91.40 179.97 3,337.11 3,230.21 -10,368.23 1,989.39 5,949,247.18 552,359.06 12,000.00 91.40 179.97 3,334.66 3,227.76 -10,468.20 1,989.43 5,949,147.22 552,359.78 DLSEV Vert Section 1°I100ft) Ift) 0.00 8,106.52 13.60 8,118.29 13.60 8,122.90 0.00 8,152.75 3.99 8,171.13 4.00 8,270.97 4.00 8,370.94 4.00 8,378.36 4.00 8,470.54 4.00 8,479.20 0.00 8,568.77 3.00 8,569.72 3.00 8,669.20 3.00 8,703.22 3.00 8,733.37 0.00 8,769.06 0.00 8,868.97 0.00 8,968.88 0.00 9,068.80 0.00 9,168.71 0.00 9,268.63 0.00 9,300.29 3.00 9,320.34 0.00 9,368.56 0.00 9,468.51 0.00 9,521.31 3.00 9,535.16 0.00 9,568.47 0.00 9,668.44 0.00 9,768.41 0.00 9,868.38 0.00 9,968.35 0.00 10,068.32 0.00 10,168.29 0.00 10,268.26 0.00 10,368.23 0.00 10,468.20 2/92005 8:28:47PM Page 4 of 7 COMPASS 2003.11 Build 50 '/ • ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: Con~~coPhillips Alaska Inc.(Kuparuk) Project: Kup<3ruk River Unit Site: Kuparuk 1E Pad Well: Plan 1E-117 Wellbore: 1 E-117 L1 Design: 1E-117 L1 (wp04) Planned Survey 1 E-117 L1 (wp04) Halliburton Company Planning Report -Geographic Local Co-ordinate Reference: TW Reference: MD Reference: North Reference: Survey Calculation Method: MD Inclination Aaimuth TVD SSTVD +N/-S +E/-W (ft) (°> (°) (ft1 (ft1 (ft) (ft) 12,031.24 91.40 179.97 3,333.90 3,227.00 -10,499.43 1,989.45 1E-117 L1-T4 (v3} 12,045.84 90.97 180.03 3,333.60 3,226.70 -10,514.03 1,989.45 12,100.00 90.97 180.03 3,332.88 3,225.78 -10,568.18 1,989.42 12,200.00 90.97 180.03 3,330.99 3,224.09 -10,668.17 1,989.38 12,300.00 90.97 180.03 3,329.30 3,222.40 -10,768.15 1,989.33 12,400.00 90.97 180.03 3,327.61 3,220.71 -10,868.14 1,989.29 12,500.00 90.97 180.03 3,325.92 3,219.02 -10,968.13 1,989.24 12,600.00 90.97 180.03 3,324.24 3,217.34 -11,068.11 1,989.20 12,700.00 90.97 180.03 3,322.55 3,215.65 -11,168.10 1,989.15 12,800.00 90.97 180.03 3,320.86 3,213.96 -11,268.08 1,989.11 12,900.00 90.97 180.03 3,319.17 3,212.27 -11,368.07 1,989.06 I 13,000.00 90.97 180.03 3,317.48 3,210.58 -11,468.05 1,989.01 13,100.00 90.97 180.03 3,315.79 3,208.89 -11,568.04 1,988.97 13,152.53 90.97 180.03 3,314.90 3,208.00 -11,620.56 1,988.95 1E-117 L1-TS (v3} 13,200.00 92.39 180.01 3,313.51 3,206.61 -11,668.01 1,988.93 13,209.17 92.67 180.01 3,313.10 3,206.20 -11,677.17 1,988.93 13,300.00 92.67 180.01 3,308.88 3,201.98 -11,767.90 1,988.91 13,400.00 92.67 180.01 3,304.22 3,197.32 -11,867.80 1,988.88 13,500.00 92.67 180.01 3,299.57 3,192.67 -11,967.69 1,988.86 13,600.00 92.67 180.01 3,294.92 3,188.02 -12,067.58 1,988.84 13,700.00 92.67 180.01 3,290.26 3,183.36 -12,167.47 1,988.82 13,772.24 92.67 180.01 3,286.90 3,180.00 -12,239.64 1,988.80 i 1E-117 L1-T6 (v3) 13,800.00 91.84 180.00 3,285.81 3,178.91 -12,267.37 1,988.80 13,835.67 90.76 179.98 3,285.00 3,178.10 -12,303.03 1,988.80 13,900.00 90.76 179.98 3,284.14 3,177.24 -12,367.35 1,988.82 14,000.00 90.76 179.98 3,282.81 3,175.91 -12,467.35 1,988.85 14,100.00 90.76 179.98 3,281.47 3,174.57 -12,567.34 1,988.87 14,200.00 90.76 179.98 3,280.14 3,173.24 -12,667.33 1,988.90 14,300.00 90.76 179.98 3,278.80 3,171.90 -12,767.32 1,988.93 14,400.00 90.76 179.98 3,277.47 3,170.57 -12,867.31 1,988.95 14,500.00 90.76 179.98 3,276.14 3,169.24 -12,967.30 1,988.98 14,600.00 90.76 179.98 3,274.80 3,167.90 -13,067.29 1,989.01 14,700.00 90.76 179.98 3,273.47 3,166.57 -13,167.28 1,989.04 14,800.00 90.76 179.98 3,272.13 3,165.23 -13,267.27 1,989.06 14,900.00 90.76 179.98 3,270.80 3,163.90 -13,367.27 1,989.09 15,000.00 90.76 179.98 3,269.46 3,162.56 -13,467.26 1,989.12 15,100.00 90.76 179.98 3,268.13 3,161.23 -13,567.25 1,989.14 15,200.00 90.76 179.98 3,266.79 3,159.89 -13,667.24 1,989.17 15,300.00 90.76 179.98 3,265.46 3,158.56 -13,767.23 1,989.20 15,400.00 90.76 179.98 3,264.12 3,157.22 -13,867.22 1,989.22 15,500.00 90.76 179.98 3,262.79 3,155.89 -13,967.21 1,989.25 15,600.00 90.76 179.98 3,261.46 3,154.56 -14,067.20 1,989.28 15,641.66 90.76 179.98 3,260.90 3,154.00 ~ -14,108.86 1,989.29 BHL :1742' FSL 81732' FLAIL -Sect 34 - 711 N - R10E :15642 ft MD, 3261 ft TVD - 51/2" Map Map Northing Easting DLSEV Vert Section lft) lft) (°1100ft1 Iftl 5,949,116.00 552,360.00 0.00 10,499.43 5,949,101.40 552,360.10 3.00 10,514.03 5,949,047.26 552,360.44 0.00 10,568.18 5,948,947.28 552,361.06 0.00 10,668.17 5,948,847,31 552,361.68 0.00 10,768.15 5,948,747.33 552,362.31 0.00 10,868.14 5,948,647.36 552,362.93 0.00 10,968.13 5,948,547.39 552,363.55 0.00 11,068.11 5,948,447.41 552,364.18 0.00 11,168.10 5,948,347.44 552,364.80 0.00 11,266.08 5,948,247.46 552,365.43 0.00 11,368.07 5,948,147.49 552,366.05 0.00 11,468.05 5,948,047.52 552,366.67 0.00 11,568.04 5,947,995.00 552,367.00 0.00 11,620.56 5,947,947.56 552,367.30 3.00 11,668.01 5,947,938.39 552,367.36 3.00 11,677.17 5,947,847.68 552,367.95 0.00 11,767.90 5,947,747.80 552,368.59 0.00 11,867.80 5,947,647.92 552,369.24 0.00 11,967.69 5,947,548.04 552,369.89 0.00 12,067.58 5,947,448.16 552,370.53 0.00 12,167.47 5,947,376.00 552,371.00 0.00 12,239.64 5,947,348.27 552,371.18 2.99 12,267.37 5,947,312.61 552,371.43 3.00 12,303.03 5,947,248.30 552,371.87 0.00 12,367.35 5,947,148.32 552,372.57 0.00 12,467.35 5,947,048.34 552,373.27 0.00 12,567.34 5,946,948.36 552,373.96 0.00 12,667.33 5,946,848.38 552,374.66 0.00 12,767.32 5,946,748.40 552,375.35 0.00 12,867.31 5,946,648.42 552,376.05 0.00 12,967.30 5,946,548.44 552,376.75 0.00 13,067.29 5,946,448.46 552,377.44 0.00 13,167.28 5,946,348.49 552,378.14 0.00 13,267.27 5,946,248.51 552,378.84 0.00 13,367.27 5,946,148.53 552,379.53 0.00 13,467.26 5,946,048.55 552,380.23 0.00 13,567.25 5,945,948.57 552,380.92 0.00 13,667.24 5,945,848.59 552,381.62 0.00 13,767.23 5,945,748.61 552,382.32 0.00 13,867.22 5,945,648.63 552,383.01 0.00 13,967.21 5,945,548.65 552,383:71 0.00 14,067.20 5,945,507.00 552,384.00 0.00 14,108.86 ~ r -sun ~~' S/ A Halllbunton Company Well Plan 1E-117 66.9 GL + 40RF=106.9 @ 106.90ft (Doyon 15 (66.9GL + 40R 66.9 GL + 40RF=106.9 @ 106.90ft (Doyon 15 (66.9GL + 40R True Minimum Curvature 2/92005 8:28:47PM Page 5 of 7 COMPASS 2003.11 Build 50 ~~'~ ' • ~ `' Ph ll C Halliburton Company ~rf ~SV~ onoco ~ ips Planning Report -Geographic Alaska A Flallibunon Company Database: EDM 2003.11 Single User Db Local Co-0rdinate Reference: Well Plan 1 E-117 Company: ConocoPhillips Alaska Inc.(Kuparuk) TVD Reference: 66.9 GL + 40RF=106.9 @ 106.90ft (Doyon 15 (66.9GL + 40R Project: Kuparuk River Unit MD Reference: 66.9 GL + 40RF=106.9 @ 106.90ft (Doyon 15 (66.9GL + 40R Site: Kuparuk 1E Pad North Reference: True Well: Plan 1 E-117 Survey Calculation Method; Minimum Curvature Wellbore: 1E-117 L1 Design: 1E-117 L1 (wp04) Geologic Targets 1 E-117 L1 TVD Target Name +N/S +E/-W Northing Easting (ft) - Shaae ft ft (ft) (ft) 3,286.90 1E-117 L1-T6(v3) -12,239.64 1,988.80 5,947,376.00 552,371.00 - Point 3,314.90 1E-117 L1-TS (v3) -11,620.56 1,988.95 5,947,995.00 552,367.00 - Point 3,389.90 1E-117 L1-T1 (v3) -8,703.22 1,989.47 5,950,912.00 552,348.00 - Point 3,364.90 1E-11T L1-T2 (v3) -9,300.29 1,989.48 5,950,315.00 552,352.00 - Point 3,333.90 1E-117 L1-T4 (v3) -10,499.43 1,989.45 5,949,116.00 552,360.00 - Point 3,260.90 1E-117 L1-Toe (v3) -14,108.86 1,989.29 5,945,507.00 552,384.00 - Point 3,357.90 1E-117 L1-T3 (v2) -9,521.31 1,989.00 5,950,094.00 552,353.00 - Point 3,364.90 1E-117 L1 Fauit#1Prognosed Intersection -9,059.30 1,995.09 5,950,556.00 552,356.00 - Point Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) (") (") 5,382.18 2,377.90 13-3/8 16 9,635.05 3,413.42 9-616 12-114 15,641.65 3,260.90 b-1/2 8-1/2 2/9/2005 8.~28:47PM Page 6 of 7 COMPASS 2003.118ui1d 50 '~~'~1'~~'~1l,~ ~ Y Halliburton C ompany ConocoP hiNips P lanning Report - Geographic Alaska Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Company: ConocoPhillipsAlaska Inc.(Kuparuk) TVDReference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1E Pad North Reference: Well: Plan 1 E-117 Survey Calculation Method: Wellbore: 1 E-117 L1 Design: 1 E-117 L1 (wp04) Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E!-W (ft) (°) (°) (~) Itt1 (ftl 2,051.72 73.00 160.00 1,528.90 -959.86 368.52 2,876.10 75.44 166.31 1,747.90 -1,723.42 585.36 3,910.36 75.44 166.31 2,007.90 -2,696.03 822.22 5,382.18 75.44 166.31 2,377.90 -4,080.13 1,159,29 6,607.37 75.44 166.31 2,685.90 -5,232.31 1,439.87 7,605.82 75.44 166.31 2,936.90 -6,17126 1,668.53 7,776.87 75.44 166.31 2,979.90 -6,332.11 1,707.70 8,492.90 75.44 166.31 3,159.90 -7,005.46 1,871.68 9,335.04 78.00 180.03 3,357.90 -7,811.78 1,989.85 9,530.04 79.90 180.03 3,396.90 -8,002.84 1,989.75 9,646.91 83.61 180.03 3,414.90 -8,118.29 1,989.69 ~ err -sun ~ ~/ A Halllburton Company Well Plan 1E-117 66.9 GL + 40RF=106.9 @ 106.90ft (Doyon 15 (66.9GL + 40R 66.9 GL + 40RF=106.9 @ 106.90ft (Doyon 15 (66.9GL + 40R True Minimum Curvature Name Base of Pertnatrost T3 K1li T3+g75 Ugnu C Ugnu B Ugnu A K13 West Sak D West Sak C West Sak B 219/2005 8:28:47PM Page 7 of 7 COMPASS 2003.11 Build 50 OR!G!Nq! SORVE\~ PROGWtM Dafc: X50? OTElIC:P..".00 V°.lidatM: Yca lc: a:on: Depth From Depth To Survey/Plan Toul 4D.W 80(1.1111 C&CYROSS 800.110 9635.p1 MWD 9635.67 156.11.56 1E-117 Ll (x p04) MWD 90 Frem Cc!our T° MD 0 100 100 -- 200 200 '-- 300 300 400 400 500 500 600 600 700 700 800 800 -- -- 900 900 1000 1000 1500 1500 2000 2000 3000 3000 4000 4000 5000 5000 6000 6000 - 7000 7000 - 8000 8000 9000 9000 10000 10000 ----- 11000 11000 12000 12000 13000 13000 "~" -- 14000 14000 ---- 15000 15000 17000 180 averting Cylinder Azimuth (TFO+AZI) I°~ vs Centre to Centre Separation 150 Ftrnl ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: 25Stations Depth Range From: 9635.04 To 15641.66 Maximum Range:1800 Reference: Plan: 1 E-117 Lt (wp04) REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plan tE-117, True North Venical (TVD) Reference: 86.9 GL + 40RF=106.9 ~ 106.90ft (Doyon 15 (66.9GL + 40RK8)) Section (VS) Reference: Slot - (O.OON. O.OOE) Measuretl Depth Reference: 66.9 GL + 40RF=106.9 (~ 106.90fl (Doyon 15 (66.9GL + 40RK8)) Calculation Method: Minimum Curvature WELL DETAILS: PWn 1E-117 Ground Level: 66.90 +WS +EI-W NoMing Easting Latiltude Longitude Slot 0.00 0.00 5959600.86 550300.51 70°18'1.427N 149°35'33.405W Conocophillips Alaska Inc.(Kuparuk) Engineering West Sak Calculation Method: Minimum Curvature Enor System: 19CVVSA Scan Melflod: Trav. Cylinder North En'orSurface: Elliptical Conic blaming Metlwd: Rules Based LEGEND -~- 1E-112,1E-112. 1E~112 V1 ~- 1E-112.1E-11211. 1E~112L1 VO --~}- tE~112.1E~112L2, 1E~11212 V1 -~-- tE-112,1E-112P81, tE-t 12PB1 Vi -~ 1E-111.1E-114,1E-1 t4 Vf tE-114.1E-114L1. 1E-114L1 V1 -~-- tE-114,1E-114L2, tE~11412 VO -~- tE-118, 1E-119.1E-119 V1 -~ tE-186.1E-168. tE-166 V1 I tE-186.1E-198L1, 1E-1B6L1 V1 -(~~~ 1E-186,1E-186L1PB1. tE-166L1PB1 V2 -~ tE-188.1E-1B6L2.1E-18&2 V1 -{}-_ 1E-160, 1E-186, 1E-168 V1 -~--- tE-198.1F-16aL1.tE-180L1 V3 -~~ tE-168.1E-166L2. 1E-t80L2 V1 -~ 1E-160. tE-160L2PB1. tE-168L2PB1 V3 -~- tE-180, tE-t86P01. tE-186PB1 V3 -~- tE-23,1E-2].1E-23V1 -~ 1E-24, 1E-21.1E-24 V4 ~- 1E-24,1F-24A.1E-24A V1 -~- tE-25,1E-25,1E-25V1 - tE-28. tE-26.1E-26 V1 -£-- tE-3J. tE-J3. tE~33 V2 -~ 1E-33PB1. 1E-3JPB1, 1E~33PB1 V2 tE-J5, 1E-35.1E-35 V 1 ~~ flan tE-1]O.PYn IE-1 ]0, tE-t]0 (wpOJ)VO -~- Ran tE-1]O, Plan tE-1 ]0 L1,1E-1]OL1 (wpOJ)VO Ran tE-1]O, Ren tE-17<l L2. tE-1 ]0 L2 (wpOJ)VO -~- a-1o. u1o. ulnw ---y4--~ Plen 1J-158.1}M3A Lateral,lJ-M3AlaleMl VarsaZ.A V' -$- Phn 11160. Plan 11M2 Let A, Plan 1J-M2 LetAVO ~- PMn t}1621M11. 1}162, 1J-162 (wp03.1lJOM Nae6 V0 --e- Ran 1J-182 (M11.1J-162 L1, 1J-182 L1 (wp3.11 V0 ~- Plan 111621M1),1}162 L2, 1J-18212 (wpJ.1)VO $- Plan 11168.11168. tJ-tea (wp0]I VO ~- Ran 11168,17-16a L1, 111fi0 L1 (wpOJ)VO --E)-°°' Ran 1J-166, 1J-188 L2, 1J-160 L2 (wp03) VO Kup#11-141. #11-10. #11-10 Vi --&- WSAK-03.WSAK-03. W6AK-03 V0 ~- 1E-11]Lt (wp04) 180 9• Travelling Cylinder Azimuth (TFO+AZI) ~°~ vs Centre to Centre Separation X10 ft/in~ SECTION DETAILS Sec MD Inc Azi ND +N/-S +E/-W DLeg TFace VSec Target 1 9635.04 82.00 180.03 3413.41 -8106.52 1989.69 0.00 0.00 8106.52 2 9651.54 84.24 180.03 3415.39 -8122.90 1989.69 13.60 0.00 8122.90 3 9681.54 84.24 180.03 3418.40 -8152.75 1989.67 0.00 0.00 8152.75 4 9907.44 93.28 180.03 3423.27 -8378.36 1989.55 4.00 0.00 8378.36 5 10008.73 97.33 180.00 3413.91 -8479.20 1989.52 4.00 -0.35 8479.20 6 10099.04 97.33 180.00 3402.39 -8568 77 1989.51 0.00 0.00 8568.77 7 10234.09 93.28 180.03 3389.90 -8703.22 1989.47 3.00 179.64 8703.22 1E-117 L7-T7 (v3) 8 10264.28 92.37 180.00 3388.41 -8733.37 1989.46 3.00 -178.03 8733.37 9 10831.69 92.37 180.00 3364.90 -9300.29 1989.48 0.00 0.00 9300.29 1E-117 Lt-T2 (v3) 1010851.75 91.79 180.13 3364.17 -9320.34 1989 45 3.00 187.40 9320.34 1111052.82 91.79 180.13 3357.90 -9521.31 1989.00 0.00 0.00 9521.31 1E-117 L7-T3 (v2) 1211066.68 91.40 179.97 3357.51 -9535.16 1988.98 3.00 -157.68 9535.16 1312031.24 91.40 179.97 3333.9610499.43 1989.45 0.00 0.0010499.43 1E-117 Lt-T4 (v3) 1412045.84 90.97 180.03 3333.6610514.03 1989.45 3.00 172.9510514.03 1513152.53 90.97 180.03 3314.9611620.56 1988.95 0.00 0.0011620.56 1E-117 L1-TS (v3) 1613209.17 92.67 180.01 3313.1611677.17 1988.93 3.00 -0 45 11677.17 1713772.24 92.67 180.01 3286.9612239.64 1988.80 0.00 0.00 12239.64 1E-117 L1-T6 (v3) 1813835.67 90.78 179.98 3285.0612303.03 1988.80 3.00 -179.1512303.03 1915641.86 90.76 179.98 3260.9614108.86 1989.29 0.00 0.0014108.88 1E-117 L1-Toe (v3) • • • Halliburton Company Anticollision Report Company: ConocoPhillips Alaska Inc, Field: Kuparuk River Unit Reference Site: Kuparuk 1 E Pad Reference WeII: Plan 1 E-117 Reference Wellpath: Plan 1E-117 L1 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 100.000 ft Depth Range: 9635.040 to 15641.660 ft Maximum Radius:10000.000 ft 'Date: 2!9/2005 Time: 21:23'05 Page: 1 Co-ordinate(NE) Reference: Well: Plan 1E-117, True North Vertical (TVD) Reference: Doy0n 15 (40 +66.9) 106.9 Db: Oracle Reference: Plan: 1 E-117 (wp04) & NOT PLANNED Error Model: ISCWSA Ellipse Scan Method: Trav Cylinder North Error Surface: Ellipse + Casing Casing Points MD TVD Diameter Idle Size Name ft ft in in; 15641.660 3260.854f 5.500 8.500 51/2" Plan: 1 E-117 (wp04) Date Composed: 2/9/2005 Version: 1 Principal: Yes Tied-to: From: Definitive Path Summary Offset Wetlpath ----~.------- Reference Offset Ctr-Ctr No-Go Allowable ' Site Well Wellpath MD IVID Distance Area Deviation Warning ft ft ft ft ft Kuparuk 1 E Pad 1 E-166 1 E-166 V1 Out of range Kuparuk 1 E Pad Plan 1 E-170 Plan 1 E-170 L1 V1 Plan 15562.238 1 5000.000 1545.969 795.619 750.350 Pass: Major Risk Kuparuk 1 E Pad Plan 1 E-170 Plan 1 E-170 L2 V1 Plan 15569.533 1 5000.000 1547.994 794.360 753.634 Pass: Major Risk Kuparuk 1 E Pad Plan 1 E-170 Plan 1 E-170 VO Plan: 1 15546.479 1 5000.000 1555.673 826.022 729.651 Pass: Major Risk Kuparuk 1J Pad 1J-10 1J-10 V7 12739.992 7600.000 1699.566 434.790 1264.777 Pass: Major Risk Kuparuk 1J Pad Plan 1J-158 Plan 1J-M3 Lat A VO 15606.602 5800.000 1859.448 586.847 1272.602 Pass: Major Risk Kuparuk 1J Pad Plan 1J-160 Plan 1J-M2 Lat A VO 15640.280 7100.000 558.410 440.046 118.364 Pass: Major Risk Kuparuk 1J Pad Plan 1J-162 1J-162 V3 Plan: 1J-162 15591.143 7900.000 872.021 476.819 395.203 Pass: Major Risk Kuparuk 1J Pad Plan 1J-168 1J-168 L1 V2 Plan: 1J- 15399.958 6800.000 1553.878 600.297 953.582 Pass: Major Risk Kuparuk 1J Pad Plan 1J-168 1J-168 L2 V1 Plan: 1J- 15399.958 6800.000 1553.878 600.297 953.582 Pass: Major Risk Kuparuk 1J Pad Plan 1J-168 1J-168 V1 Plan: 1J-168 15399.958 6800.000 1553.878 600.297 953.582 Pass: Major Risk Kuparuk River Unit N KUP 34-11-10-1 KUP 34-11-10-1 V1 15349.234 3400.000 1165.436 644.747 520.689 Pass: Major Risk Non-Pad WSAK-03 WSAK-03 VO 10241.108 3400.000 838.113 418.705 419.408 Pass: Major Risk Site: Kuparuk 1E Pad Well: Plan 1 E-170 Rule Assigned: Major Risk Wellpath: Plan 1 E-170 L1 V1 Plan: 1E- 170 L2 (wp03) V2 Inter-Site Error: 0.000 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TEO+AZI TFO-HS Casing/HSDistance Area. Deviation Warning ft ft ft ft ft ft deg tieg in ft ft ft - - - - _ 9650.719 3415.261 9100.000 3254.422 123.191 44.862 263.972 83.942 6.750 1532.089 508.691 1023.398 Pass 9757.447 3423.962 9200.000 3280.028 124.744 45.426 264.625 84.595 6.750 1529.886 514.452 1015.434 Pass 9865.367 3425.019 9300.000 3301.688 126.338 45.997 265.397 85.367 6.750 1527.622 520.157 1007.465 Pass 9970.910 3418.195 9400.000 3316.767 127.936 46.326 266.182 86.168 6.750 1525.589 525.295 1000.295 Pass 10071.441 3405.862 9500.000 3323.402 129.421 46.529 266.878 86.873 6.750 1524.024 530.154 993.871 Pass 10168.472 3394.733 9600.000 3322.106 130.587 46.726 267.273 87.255 6.750 1523.077 534.449 988.628 Pass 10264.353 3388.362 9700.000 3318.599 131.499 46.932 267.370 87.371 6.750 1522.485 537.970 984.516 Pass 10364.351 3384.219 9800.000 3315.091 132.863 47.148 267.394 87.395 6.750 1522.050 542.294 979.756 Pass 10464.345 3380.075 9900.000 3311.788 134.329 47.364 267.424 87.426 6.750 1521.605 546.885 974.719 Pass 10564.291 3375.93410000.000 3310.885 135.795 47.566 267.546 87.547 6.750 1521.053 551.486 969.567 Pass 10664.233 3371.793 10100.000 3310.145 137.262 47.793 267.673 87.674 6.750 1520.501 556.156 964.346 Pass 10764.174 3367.652 10200.000 3309.405 138.729 48.028 267.801 87.802 6.750 1519.957 560.845 959.113 Pass 10867.031 3363.649 10300.000 3308.665 140.069 48.256 268.055 87.925 6.750 1519.375 565.215 954.161 Pass 10967.001 3360.531 10400.000 3307.925 141.446 48.502 268.144 88.014 6.750 1518.652 569.678 948.974 Pass 11063.491 3357.549 10500.000 3307.185 142.896 48.762 268.107 88.098 6.750 1517.949 574.322 943.626 Pass 11162.436 3355.124 10600.000 3306.445 144.266 49.021 268.133 88.161 6.750 1517.528 578.881 938.647 Pass 11262.420 3352.67610700.000 3305.705 145.739 49.283 268.198 88.225 6.750 1517.111 583.620 933.491 Pass 11362.405 3350.22810800.000 3304.965 147.212 49.550 268.262 88.289 6.750 1516.696 588.373 928.322 Pass 11462.390 3347.780 10900.000 3304.225 148.686 49.822 268.326 88.353 6.750 1516.282 593.141 923.141 Pass 11562.375 3345.333 11000.000 3303.485 150.161 50.100 268.390 88.418 6.750 1515.871 597.923 917.947 Pass 11662.359 3342.885 11100.000 3302.745 151.636 50.382 268.454 88.482 6.750 1515.461 602.719 912.742 Pass 11762.344 3340.437 11200.000 3302.005 153.112 50.669 268.518 88.546 6.750 1515.053 607.529 907.524 Pass 11862.329 3337.98911300.000 3301.265 154.588 50.962 268.583 88.610 6.750 1514.647 612.352 902.296 Pass • • 1 E-117L1 Drilling Hazards Summary 8 1/2" Open Hole /51/2" 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 O ever, Decreased mud wei ht Lost Circulation Moderate Reduced um rates, Mud rheolo , LCM Hole Swabbing on Trips Low Trip speeds, Proper hole filling (use of trip sheets , Pum in out 1E-114 Drilling Hazards Summary prepared by Steve Shultz 2/16f2005 2:00 PM ~ • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PA.R.AGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ,~~~~~~ f~ " /f ~~ ~-- l PTD# ~-~ ~ _ ~ ~-- Development Exploration Service Stratigraphic CHECK WIiAT ADD-OHS "CL13E"• APPLIES (OPTIONS MULTI The permit is !or s new wellbore •segment of LATERAL existing well /<~~ /C`~/~ Z~~-~Z~API No. 5t'°~'' ~' Z~ZS / Permit No (lf 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 DOLE In accordance with ~ 20 AAC 25.005(f), all (PII] records, data and logs acquired. far the pilot . bole must be clearly differentiated 'in both • name (name on permit plus PIS and API iaumber (50 - 70/80) lrom records, data and logs acquired • for well (same on permit). SPACING The permit is approved subject •to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving s spacing exception. SCompany Hamel assumes ibe liability of any protest to the spacing •exception that may occur. DRY DITCH All dry ditch sample sets submitted to ibe SAMPLE Commission must be in no greater •ihan 30' . sample intervals from below ibe permafrost • or from where samples are first cangbt and ] 0' sample intervals through target zones. -Gp WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAKOIL- 490150 Well Name: KUPARUK RIV U WSAK 1E-117L1 Program SER Well bore seg ~ PTD#: 2050270 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType SER ! PEND GeoArea 890 Unit i 1160 On/Off Shore On Annular Disposal Administration 1 Pe[mft_fee attached_ - - - - - _ - _ _ _ _ - - _ _ NA_ _ - _ . - - Multilaterakwell segment; fee waived per 20 AAC 25.005(e)_ - - - - - , - - - 2 Lease number apprppriate--_--- _--_-__--_--__-_______ ___ _____Yes- _____-Well bore segment_locatedin-ADL-025660,__-_--_-__--_-__ - - 3 Unkquewell_nameandnumber__--.____-. ____ Yes_ ________________________ 4 Well located in a_defnedpool_ _ - _ - _ _ _ - _ _ _ - - _ - - _ - - - - _ _ Yes - KRU West,$ak Oil Pool,governed-by Conse_rvation_OMer_No. 4b66- _ ---------------- 5 Well located proper distance from drilling unitboundary- - - - - - - - - - - - - - - Yes - - . - - .Well is mote than_500 feet from an external property line. - . - - - - - _ _ _ - - - - - - 6 Well located proper distance from other wells_ - - _ - _ _ - - - - - - Yes - . - _ - - No restrictions as_to well spacing in CO-406B . - - _ - - - - - - - - - 7 Sufflcientacreageayail_ablein_drillingu-n)t-------------------- -- -- ------Yes- ___-.-_..__.__. ---------------------------------------------------------- 8 Ifdeviated,is-wellboreplat-inc_luded__-.__-_________________ _-___-_- Yes. _.__-.__.-_..--__.___._ - - - - - 9 Operator only affected padY - - Yes - - - - - - . - .. - - 1D Ope[akorhas-approprkate.bondknfQrcB --------- -- ---------- ---- ----Yes- ----~ - ---------~-- -- -...---~-----.._..--~-- - ---~---------- -- 11 Permitcanbeissuedwithoutconservatignorder________ __________ _________Yes_ __-_--._-.__._.__ - - Appr Date 12 Pe[mit_canbeissuedwithoutadminist[ative-approval--._--__-___._ _--_-_-_Yes_ ______ _________________ ___ _____-_--_-______-_-- -_--_-__--__-__ SFD 2!23/2005 13 Can permit be approved before 15-day wait Yes 14 Well located within! area and strata authorized by-Injection Order # (put 10# in_commsnts) (For_ Yes - . - - - . - Area Injection Order No.-2B - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 15 Allwells-within 114.mile area of review identified (For service well only)_ _ __ _ _ _ _ _ _ _ _ _ _ _ Yes - - _ - . - - Kup.34-11-10/1,1 ~-166 +.Iaterals,1E112 ± laterals, iJ-150, 1J-162,1J-10, 1 E-35 16 Pre-produced injector; duration of preproduction less than 3 rnonths-(For service well only) - - No_ _ - _ _ .. _ - - _ . - - _ ...- _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - 17 ACMP-Find)ngofConsi_stenGy_h_asbeenissued-for this project_._____-- __--_-__NA-- ---- -------------------_-_----_---_------_ Engineering 18 Conductor string_provided - , _ _ NA- - - _ .. Conductor set_in motherbore,-1_E-1.17 X205-026), - - - - - - - - - - - _ - . - - - . 19 Surface.casing-protects all known- U$DWS _ - . _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA- - _ - - . _ .All aquifers exempted,-4D CFR-147.102jb)(3). _ _ - - _ _ _ - - _ - _ - . 20 CMTvokadequate-tocirculate-onconductar&surf-csg__--- ------- --- ----- NA-- __.--Surface casing set in lE-117,--_ __-___--_.___ -_-----,-____--_ - 21 CMTvoI. adequate_to tie-in long string tosurf csg- - - - - . - - - . - - ----- - NA- - - - . - Pr_oduckion-casing set in_1 E-117.- All hydrocarbon-zones-planned_to be covered._ - ---------- 22 CMT.will coyer all knownproductive horizons_ - - No_ Slotted liner completion planned._ _ - 23 Casing designs adequatefo[C,?~&_pe[mafrost------------.--- ---------Yes- ---- -------------.--------------.-.----------, ---_-------------- 24 Adequate tankage-or reserve pit Yes - - , - Rig is_equipped with steel-pits.. No reserve-pitplanned, All waste to-an approved annulus or Class_ Ilwell: - - 25 Ifa-re•drill,has-a_t0.403for abandonment beenapproved_ -__-__--_ __----_. NA__ ________________--__.._-____-__--.__-__---_------ - - 26 Adequate wellbore separation-proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _Yes - _ _ - - . _ Proximkty. analysis performed: Traveling cylinder plotprovided.- Nearest wellbore is-motherbore located_below_ . . 27 Ifdiverterrequired,doesitmeet_regulations____________________- ____-__- NA-- __---BOPstackwillal[eddy-be_inplace,_--_--___-___-__-_----------_---__--_---_ _ Appr Date 28 Drilling fluid_prQgram schernatic & equip list adequate- - - - - . - - - - _ _ Yes - - . - . Maxirnum expected formatipn pressure 8,6-- 9,0 EMW. Planned MW up ko-9.0 ppg. - - - - - _ _ _ TE/M~~,, d21~28l2005 29 BOP]=s, do they meet regulation - - - - - - - - - - - - - - - - - - - - - _ Yes - t~;,~/YV" 30 BOPS-press rating appropriate; test to-(pu_t prig in comments)- - - _ _ - _ _ - _ _ - Yes _ _ _ - MASP calculated at 1161 psi. 3000_psi appropriate. CPA! pormally tests_to 5000-psi. _ _ 31 32 Choke-manifold complies w/API-RP-53 (May 84) - - Work will occur without operation shutdown__--___..---.__ _- - - Yes _------._Yes- - - - - - - - - - - ._-.__-._--__-__-_---- - - 33 Is presence-of H2S gasprgbable- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - . _ _ - _ H2S has been seen in 1E-VyS wells: Mud should_preclude H2S on rig. Rig has sensors and alarms. - .. _ .. _ . 34 Mechanical condition of wells within AOR verified (For service well onlya _ - - _ - _ - _ _ Yes - - - . - 34.11-1.0.1- (188-158) Only penetration in AOR, File review kndicates_well )sproperly P&A. _ - _ - Geology 35 Permitean be fssu-ed wlo hydrogen_sulfide measu[es - . ... .. - .. - - - .. No- - - KRU 1E-Pad West Sak wells measured from 22_to 76 ppm H2S i_n 2004- - - - - - - - - - - - - - - - - - - - 36 Data-presented on-potential overpressure zones- - - - _ _ - _ Yes - - - - Expected reseruo]rpressure is 8,6 - 9.0 ppg EMW; will be drilled with 9.0 ppg mud. Appr Date 37 Seismic analys)s_ofshallowgas-zones______________ __--_ -NA-_ . - _ - - - - - ------------ ---_-__,-_--_ - SFD 2123/2005 38 Seabed cond)tfon survey (if off-shore) - - - - - - - - 39 -Contact namelphone fgr weekly progress reports [exploratory only]- - - - - - - - - - - - - - NA_ - - Geologi Engineering ublic Commissi ~I S Commissioner: Date issi ner SEAMQU e O • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pertr~itting Process but is part of the history file. To improve the readability of the Well History file and to simplify t`inding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Nov 16 10:28:28 2005 Reel Header Service name .............LISTPE Date ......................05/11/16 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................05/11/16 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. ~ 13~~~. ~~ ~ - D~ I Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1E-117 L1 PB1 API NUMBER: 500292325171 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 16-NOV-05 JOB DATA MWD RUN 4 MWD RUN 7 MWD RUN 8 JOB NUMBER: MW0003775114 MW0003775114 MW0003775114 LOGGING ENGINEER: P. ORTH J. MARTIN J. MARTIN OPERATOR WITNESS: D. GLADDEN M. THORNTON M. THORNTON MWD RUN 9 JOB NUMBER: MW0003775114 LOGGING ENGINEER: J. MARTIN OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: 16 TOWNSHIP: 11 RANGE: 10 FNL: FSL: 11 FEL: 228 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 94.90 GROUND LEVEL: 66.90 WELL CASING RECORD OPEN HOLE CASING DRILLERS • BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 5543.0 2ND STRING 8.500 9.625 9706.0 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. THIS WELLBORE EXITS 1E-117 PB1 AT 9706'MD/3401'TVD. 4. MWD RUNS 1-3, 7 WERE DIRECTIONAL ONLY NO DATA ARE PRESENTED, EXCEPT FOR SROP DATA FOR RUN 7. 5. MWD RUNS 4, 8, 9 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE-WHILE-DRILLING (PWD) RUNS 4 & 9 INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP) MWD RUN 9 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AND ACOUSTIC CALIPER (ACAL) . 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 1-4,7,8,9 REPRESENT WELL 1E-117L1PB1 WITH API#: 50-029-23251-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11853'MD/3345'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 MATRIX, 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: 39000 - 46000 PPM CHLORIDES FORMATION WATER SALINITY: 6000 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.......05/11/16 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 RPX 5517.0 11807.0 RPS 5517.0 11807.0 RPM 5517.0 11807.0 RPD 5517.0 11807.0 FET 5517.0 11807.0 GR 5524.5 11815.0 ROP 5560.5 11853.0 NPHI 9758.5 11761.0 FCNT 9758.5 11761.0 NCNT 9758.5 11761.0 CALA 9761.0 11764.5 DRHO 9771.0 11774.5 RHOB 9771.0 11774.5 PEF 9771.0 11774.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 4 5517.0 9706.0 7 9706.5 9738.0 8 9738.0 9849.0 9 9849.0 11853.0 REMARKS: MERGED MAIN PASS. 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 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 5517 11853 8685 12673 5517 11853 ROP MWD FT/H 0.51 430.52 187.69 12586 5560.5 11853 GR MWD API 27.74 132.01 69.3534 12582 5524.5 11815 RPX MWD OHMM 1.76 2000 39.3055 12581 5517 11807 RPS MWD OHMM 3.06 2000 45.1004 12581 5517 11807 RPM MWD OHMM 5.4 1835.59 59.6895 12581 5517 11807 RPD MWD OHMM 4.99 2000 69.7341 12581 5517 11807 FET MWD HOUR 0.14 311.08 1.48182 12581 5517 11807 NPHI MWD PU-S 8.11 41.75 33.0359 4006 9758.5 11761 FCNT MWD CNTS 695 4622 1179.5 4006 9758.5 11761 NCNT MWD CNTS 120480 209723 142253 4006 9758.5 11761 RHOB MWD G/CM 1.968 2.729 2.21063 4008 9771 11774.5 DRHO MWD G/CM -0.083 0.214 0.0336964 4008 9771 11774.5 PEF MWD BARN 0.93 7.23 2.19512 4008 9771 11774.5 CALA MWD INCH 8.54 9.7 8.7977 3983 9761 11764.5 First Reading For Entire File..........5517 Last Reading For Entire File...........11853 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 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.......05/11/16 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 5517.0 9706.0 RPM 5517.0 9706.0 RPS 5517.0 9706.0 RPX 5517.0 9706.0 FET 5517.0 9706.0 GR 5524.5 9706.0 ROP 5560.5 9706.0 LOG HEADER DATA DATE LOGGED: O1-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9706.0 TOP LOG INTERVAL (FT) 5560.0 BOTTOM LOG INTERVAL (FT) 9706.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 70.6 MAXIMUM ANGLE: 83.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 120558 EWR4 ELECTROMAG. RESIS. 4 67981 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 5543.0 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 Water Based 9.30 63.0 9.0 140 4.8 4.000 65.0 2.770 97.0 3.400 65.0 3.000 65.0 • • 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 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 5517 9706 7611.5 8379 5517 9706 ROP MWD040 FT/H 1.15 430.52 202.567 8292 5560.5 9706 GR MWD040 API 27.74 132.01 72.5005 8364 5524.5 9706 RPX MWD040 OHMM 1.76 1345.45 12.975 8379 5517 9706 RPS MWD040 OHMM 3.06 1234.97 15.1144 8379 5517 9706 RPM MWD040 OHMM 5.4 1835.59 17.2712 8379 5517 9706 RPD MWD040 OHMM 4.99 2000 21.2289 8379 5517 9706 FET MWD040 HOUR 0.14 89.37 1.38132 8379 5517 9706 First Reading For Entire File..........5517 Last Reading For Entire File...........9706 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 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.......05/11/16 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: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH s • ROP 9706.5 9738.0 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) 9738.0 TOP LOG INTERVAL (FT) 9706.0 BOTTOM LOG INTERVAL (FT) 9738.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 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) 9706.0 BOREHOLE CONDITIONS MUD TYPE: Water Based MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 61.0 MUD PH: •0 MUD CHLORIDES (PPM): 133000 FLUID LOSS (C3) •0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 102.0 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 ...............e.....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 MWD070 FT/H 4 1 68 4 2 First Last . Name Service Unit Min Max Mean Nsam Reading DEPT FT 9706.5 9738 9722.25 64 9706.5 ROP MWD070 FT/H 0.51 31.23 10.255 64 9706.5 First Reading For Entire File..........9706.5 Last Reading For Entire File...........9738 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 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.......05/11/16 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: 8 DEPTH INCREMENT: .5000 $# FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 9706.5 9800.5 RPD 9706.5 9800.5 RPM 9706.5 9800.5 RPS 9706.5 9800.5 RPX 9706.5 9800.5 GR 9706.5 9807.5 ROP 9738.5 9849.0 LOG HEADER DATA DATE LOGGED: 14-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9849.0 TOP LOG INTERVAL (FT) 9738.0 BOTTOM LOG INTERVAL (FT) 9849.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.9 MAXIMUM ANGLE: 91.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 157645 Reading 9738 9738 . ~ r S BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT) 9706.0 BOREHOLE CONDITIONS MUD TYPE: Oil Based MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 80.0 MUD PH: .0 MUD CHLORIDES (PPM): 43500 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 98.6 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 MWD080 FT/H 4 1 68 4 2 GR MWD080 API 4 1 68 8 3 RPX MWD080 OHMM 4 1 68 12 4 RPS MWD080 OHMM 4 1 68 16 5 RPM MWDO80 OHMM 4 1 68 20 6 RPD MWD080 OHMM 4 1 68 24 7 FET MWD080 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9706.5 9849 9777.75 286 9706.5 9849 ROP MWD080 FT/H 1.86 239.3 87.3708 222 9738.5 9849 GR MWD080 API 35.2 75.07 55.0597 203 9706.5 9807.5 RPX MWD080 OHMM 7.38 2000 312.446 189 9706.5 9800.5 RPS MWD080 OHMM 15.3 2000 201.563 189 9706.5 9800.5 RPM MWD080 OHMM 9.95 1 353.7 95.1664 189 9706.5 9800,5 RPD MWD080 OHMM 19.49 2000 220.622 189 9706.5 9800.5 FET MWD080 HOUR 0.54 3 11.08 13.049 189 9706.5 9800.5 First Reading For Entire File..........9706.5 Last Reading For Entire File...........9849 ~ • File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 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.......05/11/16 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: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 9758.5 11761.0 FCNT 9758.5 11761.0 NCNT 9758.5 11761.0 CALA 9761.0 11764.5 RHOB 9771.0 11774.5 DRHO 9771.0 11774.5 PEF 9771.0 11774.5 RPM 9801.0 11807.0 RPS 9801.0 11807.0 RPD 9801.0 11807.0 FET 9801.0 11807.0 RPX 9801.0 11807.0 GR 9808.0 11815.0 ROP 9849.5 11853.0 LOG HEADER DATA DATE LOGGED: 16-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11853.0 TOP LOG INTERVAL (FT) 9849.0 BOTTOM LOG INTERVAL (FT): 11853.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 89.6 MAXIMUM ANGLE: 93.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CO DE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132477 EWR4 ELECTROMAG. RESIS. 4 66259 ~ • CTN COMP THERMAL NEUTRON 179954 ASLD Azimuthal Litho-Den 143795 ACAL Acoustic Caliper 143795 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 9706.0 BOREHOLE CONDITIONS MUD TYPE: Oil Based MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 73.0 MUD PH: .0 MUD CHLORIDES (PPM): 45000 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 149.0 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 MWD090 FT/H 4 1 68 4 2 GR MWD090 API 4 1 68 8 3 RPX MWD090 OHMM 4 1 68 12 4 RPS MWD090 OHMM 4 1 68 16 5 RPM MWD090 OHMM 4 1 68 20 6 RPD MWD090 OHMM 4 1 68 24 7 FET MWD090 HOUR 4 1 68 28 8 NPHI MWD090 PU-S 4 1 68 32 9 FCNT MWD090 CNTS 4 1 68 36 10 NCNT MWD090 CNTS 4 1 68 40 11 RHOB MWD090 G/CM 4 1 68 44 12 DRHO MWD090 G/CM 4 1 68 48 13 PEF MWD090 BARN 4 1 68 52 14 CALA MWD090 INCH 4 1 68 56 15 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 9758.5 11853 10805.8 4190 9758.5 ROP MWD090 FT/H 1.07 .3 18.84 165.302 4008 9849.5 Last Reading 11853 11853 v 7I GR MWD090 API 36.32 122.99 63.52 4015 9808 11815 RPX MWD090 OHMM 9.44 1692.92 81.4186 4013 9801 11807 RPS MWD090 OHMM 10.05 2000 100.341 4013 9801 11807 RPM MWD090 OHMM 11.23 1809.23 146.587 4013 9801 11807 RPD MWD090 OHMM 14.67 2000 163.905 4013 9801 11807 FET MWD090 HOUR 0.21 17.57 1.14689 4013 9801 11807 NPHI MWD090 PU-S 8.11 41.75 33.0359 4006 9758.5 11761 FCNT MWD090 CNTS 695 4622 1179.5 4006 9758.5 11761 NCNT MWD090 CNTS 120480 209723 142253 4006 9758.5 11761 RHOB MWD090 G/CM 1.968 2.729 2.21063 4008 9771 11774.5 DRHO MWD090 G/CM -0.083 0.214 0.0336964 4008 9771 11774.5 PEF MWD090 BARN 0.93 7.23 2.19512 4008 9771 11774.5 CALA MWD090 INCH 8.54 9.7 8.7977 3983 9761 11764.5 First Reading For Entire File..........9758.5 Last Reading For Entire File...........11853 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................05/11/16 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................05/11/16 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 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Nov 16 10:27:16 2005 Reel Header Service name .............LISTPE Date .....................05/11/16 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................05/11/16 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. ~~~a~ ao~ oa7 Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1E-117 L1 API NUMBER: 500292325160 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 15-NOV-05 JOB DATA MWD RUN 4 MWD RUN 7 MWD RUN 8 JOB NUMBER: MW0003775114 MW0003775114 MW0003775114 LOGGING ENGINEER: P. ORTH J. MARTIN J. MARTIN OPERATOR WITNESS: D. GLADDEN M. THORNTON M. THORNTON MWD RUN 9 MWD RUN 10 MWD RUN 11 JOB NUMBER: MW0003775114 MW0003775114 MW0003775114 LOGGING ENGINEER: J. MARTIN J. MARTIN J. MARTIN OPERATOR WITNESS: M. THORNTON M. THORNTON M. THORNTON SURFACE LOCATION SECTION: 16 TOWNSHIP: 11 RANGE: 10 FNL: FSL: 11 FEL: 228 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 94.90 GROUND LEVEL: 66.90 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 5543.0 2ND STRING 8.500 9.625 9706.0 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. THIS WELLBORE EXITS 1E-117 L1 PB1 AT 11650'MD/3350'TVD. 4. MWD RUNS 1-3, 7 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED, EXCEPT FOR SROP DATA FOR RUN 7. 5. MWD RUNS 4, 8-11 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE-WHILE-DRILLING (PWD) MWD RUNS 4, 9-11 INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP) RUNS 9-11 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AND ACOUSTIC CALIPER (ACAL). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CFAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-4,7-11 REPRESENT WELL 1E-117 Ll WITH API#: 50-029-23251-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15667'MD/3275'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 MATRIX, 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: 39000 - 46000 PPM CHLORIDES FORMATION WATER SALINITY: 6000 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.......05/11/16 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 RPX 5517.0 15621.0 RPS 5517.0 15621.0 RPM 5517.0 15621.0 RPD 5517.0 15621.0 FET 5517.0 15621.0 GR 5524.5 15629.0 ROP 5560.5 15667.0 NCNT 9758.5 15575.0 FCNT 9758.5 15575.0 NPHI 9758.5 15575.0 CALA 9761.0 15578.0 RHOB 9771.0 15588.5 DRHO 9771.0 15588.5 PEF 9771.0 15588.5 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 MWD BIT RUN NO MERGE TOP MERGE BASE 4 5517.0 9706.0 7 9706.5 9738.0 8 9738.0 9849.0 9 9849.0 11650.0 10 11650.5 14482.0 11 14482.0 15667.0 REMARKS: MERGED MAIN PASS. 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 Specificat ion Block sub- type...0 Name Service 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 CALA MWD INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5517 15667 10592 20301 5517 15667 ROP MWD FT/H 0.01 430.52 174.997 20214 5560.5 15667 GR MWD API 27.74 132.01 67.0074 20210 5524.5 15629 RPX MWD OHMM 1.76 2000 49.0276 20209 5517 15621 RPS MWD OHMM 3.06 2000 48.4656 20209 5517 15621 RPM MWD OHMM 5.4 1835.59 54.2525 20209 5517 15621 RPD MWD OHMM 4.99 2000 57.8996 20209 5517 15621 FET MWD HOUR 0.14 311.08 1.49299 20209 5517 15621 NPHI MWD PU-S 8.11 45.62 34.3664 11634 9758.5 15575 FCNT MWD CNTS 695 5055 1233.63 11634 9758.5 15575 NCNT MWD CNTS 120480 233943 146348 11634 9758.5 15575 RHOB MWD G/CM 1.577 2.729 2.2242 11636 9771 15588.5 DRHO MWD G/CM -0.087 0.293 0 .0343598 11636 9771 15588.5 PEF MWD BARN 0.91 7.23 2.24328 11636 9771 15588.5 CALA MWD INCH 8.37 10.18 8.76032 11611 9761 15578 First Reading For Entire File..........5517 Last Reading For Entire File...........15667 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 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.......05/11/16 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 5517.0 9706.0 RPM 5517.0 9706.0 RPD 5517.0 9706.0 FET 5517.0 9706.0 RPX 5517.0 9706.0 GR 5524.5 9706.0 ROP 5560.5 9706.0 LOG HEADER DATA DATE LOGGED: O1-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9706.0 TOP LOG INTERVAL (FT) 5560.0 BOTTOM LOG INTERVAL (FT) 9706.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 70.6 MAXIMUM ANGLE: 83.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 120558 EWR4 ELECTROMAG. RESIS. 4 67981 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 5543.0 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: water Based 9.30 63.0 9.0 140 4.8 4.000 65.0 2.770 97.0 3.400 65.0 3.000 65.0 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 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 MWD040 FTjH 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 5517 9706 7611.5 8379 5517 9706 ROP MWD040 FTjH 1.15 430.52 202.567 8292 5560.5 9706 GR MWD040 API 27.74 132.01 72.5005 8364 5524.5 9706 RPX MWD040 OHMM 1.76 1345.45 12.975 8379 5517 9706 RPS MWD040 OHMM 3.06 1234.97 15.1144 8379 5517 9706 RPM MWD040 OHMM 5.4 1835.59 17.2712 8379 5517 9706 RPD MWD040 OHMM 4.99 2000 21.2289 8379 5517 9706 FET MWD040 HOUR 0.14 89.37 1.38132 8379 5517 9706 First Reading For Entire File..........5517 Last Reading For Entire File...........9706 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05j11j16 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.......05f11/16 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: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 9706.5 9738.0 LOG HEADER DATA DATE LOGGED: 13-JLTL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9738.0 TOP LOG INTERVAL (FT) 9706.0 BOTTOM LOG INTERVAL (FT) 9738.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 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) 9706.0 BOREHOLE CONDITIONS MUD TYPE: Water Based MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 61.0 MUD PH: •0 MUD CHLORIDES (PPM): 133000 FLUID LOSS (C3) •0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 102.0 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 MWD070 FT/H 4 1 68 4 2 • • First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9706.5 9738 9722.25 64 9706.5 9738 ROP MWD070 FT/H 0.51 31.23 10.255 64 9706.5 9738 First Reading For Entire File..........9706.5 Last Reading For Entire File...........9738 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 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.......05/11/16 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: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 9706.5 9800.5 GR 9706.5 9807.5 RPX 9706.5 9800.5 RPM 9706.5 9800.5 FET 9706.5 9800.5 RPS 9706.5 9800.5 ROP 9738.5 9849.0 LOG HEADER DATA DATE LOGGED: 14-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9849.0 TOP LOG INTERVAL (FT) 9738.0 BOTTOM LOG INTERVAL (FT) 9849.0 BIT ROTATING SPEED (RPM) HOLE INCLINATION (DEG MINIMUM ANGLE: 84.9 MAXIMUM ANGLE: 91.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE DGR EWR4 TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 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 Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT ROP MWD080 GR MWD080 RPX MWD080 RPS MWD080 RPM MWD080 RPD MWD080 FET MWD080 TOOL NUMBER 132482 157645 8.500 9706.0 Oil Based 9.00 80.0 .0 43500 .0 .000 .0 .000 98.6 .000 .0 .000 .0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 l 68 4 2 API 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 HOUR 4 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 9706.5 9849 9777.75 286 ROP MWD080 FT/H 1.86 239.3 87.3708 222 GR MWD080 API 35.2 75.07 55.0597 203 RPX MWD080 OHMM 7.38 2000 312.446 189 RPS MWD080 OHMM 15.3 2000 201.563 189 RPM MWD080 OHMM 9.95 1353.7 95.1664 189 RPD MWD080 OHMM 19.49 2000 220.622 189 FET MWD080 HOUR 0.54 311.08 13.049 189 First Last Reading Reading 9706.5 9849 9738.5 9849 9706.5 9807.5 9706.5 9800.5 9706.5 9800.5 9706.5 9800.5 9706.5 9800.5 9706.5 9800.5 • First Reading For Entire File..........9706.5 Last Reading For Entire File...........9849 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 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.......05/11/16 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: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 9758.5 11650.0 FCNT 9758.5 11650.0 NPHI 9758.5 11650.0 CALA 9761.0 11650.0 PEF 9771.0 11650.0 DRHO 9771.0 11650.0 RHOB 9771.0 11650.0 FET 9801.0 11650.0 RPD 9801.0 11650.0 RPM 9801.0 11650.0 RPS 9801.0 11650.0 RPX 9801.0 11650.0 GR 9808.0 11650.0 ROP 9849.5 11650.0 LOG HEADER DATA DATE LOGGED: 16-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11650.0 TOP LOG INTERVAL (FT) 9849.0 BOTTOM LOG INTERVAL (FT) 11650.0 BIT ROTATING SPEED (RPM) HOLE INCLINATION (DEG MINIMUM ANGLE: 89.6 MAXIMUM ANGLE: 93.9 TOOL STRING (TOP TO BOTTOM) • VENDOR TOOL CODE DGR EWR4 CTN ASLD ACAL TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMP THERMAL NEUTRON Azimuthal Litho-Den Acoustic Caliper 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 Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT ROP MWD090 GR MWD090 RPX MWD090 RPS MWD090 RPM MWD090 RPD MWD090 FET MWD090 NPHI MWD090 FCNT MWD090 NCNT MWD090 RHOB MWD090 DRHO MWD090 PEF MWD090 CALA MWD090 TOOL NUMBER • 132477 66259 179954 143795 143795 8.500 9706.0 Oil Based 9.00 73.0 .0 45000 .0 .000 .0 .000 149.0 .000 .0 .000 .0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 HOUR 4 1 68 28 8 PU-S 4 1 68 32 9 CNTS 4 1 68 36 10 CNTS 4 1 68 40 11 G/CM 4 1 68 44 12 G/CM 4 1 68 48 13 BARN 4 1 68 52 14 INCH 4 1 68 56 15 First Last r~ ~_J Name Service Unit Min Max Mean Nsam DEPT FT 9758.5 11650 10704.3 3784 ROP MWD090 FT/H 1.07 318.84 165.941 3602 GR MWD090 API 36.32 90.08 62.4463 3685 RPX MWD090 OHMM 15.72 1692.92 79.8012 3699 RPS MWD090 OHMM 18.1 1781.47 76.335 3699 RPM MWD090 OHMM 19.03 1809.23 92.5236 3699 RPD MWD090 OHMM 19.79 2000 94.7578 3699 FET MWD090 HOUR 0.21 17.57 1.20948 3699 NPHI MWD090 PU-S 8.11 41.75 32.9703 3784 FCNT MWD090 CNTS 695 4622 1191.71 3784 NCNT MWD090 CNTS 120480 209723 142461 3784 RHOB MWD090 G/CM 1.968 2.729 2.20919 3759 DRHO MWD090 G/CM -0.083 0.214 0.0318978 3759 PEF MWD090 BARN 0.96 7.23 2.20227 3759 CALA MWD090 INCH 8.54 9.7 8.79756 3755 First Reading For Entire File..........9758.5 Last Reading For Entire File...........11650 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 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.......05/11/16 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Read ing Reading 9758.5 11650 9849.5 11650 9808 11650 9801 11650 9801 11650 9801 11650 9801 11650 9801 11650 9758.5 11650 9758.5 11650 9758.5 11650 9771 11650 9771 11650 9771 11650 9761 11650 Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DRHO 11650.5 14403.0 FET 11650.5 14436.0 ROP 11650.5 14482.0 GR 11650.5 14444.0 RPX 11650.5 14436.0 RPS 11650.5 14436.0 RPM 11650.5 14436.0 RPD 11650.5 14436.0 NPHI 11650.5 14482.0 FCNT 11650.5 14482.0 RHOB 11650.5 14403.0 PEF 11650.5 14403.0 GALA 11650.5 14393.5 NCNT 11650.5 14482.0 a • $ LOG HEADER DATA DATE LOGGED: 18-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 14482.0 TOP LOG INTERVAL (FT) 11650.0 BOTTOM LOG INTERVAL (FT) 14482.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 89.1 MAXIMUM ANGLE: 93.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132477 EWR4 ELECTROMAG. RESIS. 4 66259 CTN COMP THERMAL NEUTRON 179954 ASLD Azimuthal Litho-Den 143795 ACAL Acoustic Caliper 143795 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 9706.0 BOREHOLE CONDITIONS MUD TYPE: Oil Based MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 64.0 MUD PH: •0 MUD CHLORIDES (PPM): 44000 FLUID LOSS (C3) •0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 149.0 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 MWD100 FT/H 4 1 68 4 2 GR MWD100 API 4 1 68 8 3 RPX MWD100 OHMM 4 1 68 12 4 RPS MWD100 OHMM 4 1 68 16 5 RPM MWD100 OHMM 4 1 68 20 6 RPD MWD100 OHMM 4 1 68 24 7 FET MWD100 HOUR 4 1 68 28 8 NPHI MWD100 PU-S 4 1 68 32 9 FCNT MWD100 CNTS 4 1 68 36 10 NCNT MWD100 CNTS 4 1 68 40 11 RHOB MWD100 G/CM 4 1 68 44 12 DRHO MWD100 G/CM 4 1 68 48 13 PEF MWD100 BARN 4 1 68 52 14 CALA MWD100 INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11650.5 14482 13066.3 5664 11650.5 14482 ROP MWD100 FT/H 0.01 252.49 153.181 5664 11650.5 14482 GR MWD100 API 34.85 96.41 64.6014 5588 11650.5 14444 RPX MWD100 OHMM 15.72 302.82 70.0022 5572 11650.5 14436 RPS MWD100 OHMM 18.37 233.49 66.9825 5572 11650.5 14436 RPM MWD100 OHMM 21.75 1228.77 73.5581 5572 11650.5 14436 RPD MWD100 OHMM 26.84 630.02 76.7745 5572 11650.5 14436 FET MWD100 HOUR 0.21 7.44 1.00629 5572 11650.5 14436 NPHI MWD100 PU-S 8.36 45.62 34.6776 5664 11650.5 14482 FCNT MWD100 CNTS 792 4822 1221.36 5664 11650.5 14482 NCNT MWD100 CNTS 127030 211073 144014 5664 11650.5 14482 RHOB MWD100 G/CM 1.577 2.715 2.23257 5506 11650.5 14403 DRHO MWD100 G/CM -0.087 0.293 0.0340514 5506 11650.5 14403 PEF MWD100 BARN 0.91 5.26 2.25831 5506 11650.5 14403 CALA MWD100 INCH 8.53 10.18 8.83277 5487 11650.5 14393.5 First Reading For Entire File..........11650.5 Last Reading For Entire File...........14482 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF File Header Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 • FILE SUMMARY J VENDOR TOOL CODE START DEPTH STOP DEPTH CALA 14394.0 15578.0 RHOB 14403.5 15588.5 DRHO 14403.5 15588.5 PEF 14403.5 15588.5 RPM 14436.5 15621.0 RPS 14436.5 15621.0 RPD 14436.5 15621.0 FET 14436.5 15621.0 RPX 14436.5 15621.0 GR 14444.5 15629.0 ROP 14482.5 15667.0 NPHI 14482.5 15575.0 FONT 14482.5 15575.0 NCNT 14482.5 15575.0 LO G HEADER DATA DATE LOGGED: 21-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 15667.0 TOP LOG INTERVAL (FT) 14482.0 BOTTOM LOG INTERVAL (FT) 15667.0 BIT ROTATING SPEE D (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 89.4 MAXIMUM ANGLE: 92.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 163686 EWR4 ELECTROMAG. RESIS. 4 134760 CTN COMP THERMAL NEUTRON 105918 ASLD Azimuthal Li tho-Den 143795 ACAL Acoustic Cal iper 143795 BOREHOLE AND CASI NG DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASI NG DEPTH (FT) 9706.0 BOREHOLE CONDITIONS MUD TYPE: Oil Based MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S) 70.0 MUD PH: •0 MUD CHLORIDES (PPM): 43000 FLUID LOSS (C3) •0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 138.2 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 MWD110 FT/H 4 1 68 4 2 GR MWD110 API 4 1 68 8 3 RPX MWD110 OHMM 4 1 68 12 4 RPS MWD110 OHMM 4 1 68 16 5 RPM MWD110 OHMM 4 1 68 20 6 RPD MWD110 OHMM 4 1 68 24 7 FET MWD110 HOUR 4 1 68 28 8 NPHI MWD110 PU-S 4 1 68 32 9 FCNT MWD110 CNTS 4 1 68 36 10 NCNT MWD110 CNTS 4 1 68 40 11 RHOB MWD110 G/CM 4 1 68 44 12 DRHO MWD110 G/CM 4 1 68 48 13 PEF MWD110 BARN 4 1 68 52 14 GALA MWD110 INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 14394 15667 15030.5 2547 14394 15667 ROP MWD110 FT/H 2.47 3 01.99 157.098 2370 14482.5 15667 GR MWD110 API 37.41 94.95 61.4099 2370 14444.5 15629 RPX MWD110 OHMM 10.56 2 63.55 58.1402 2370 14436.5 15621 RPS MWD110 OHMM 13.88 899.3 67.136 2370 14436.5 15621 RPM MWD110 OHMM 19.08 12 66.88 76.6144 2370 14436.5 15621 RPD MWD110 OHMM 24.68 198.6 72.6672 2370 14436.5 15621 FET MWD110 HOUR 0.22 42.07 2.55301 2370 14436.5 15621 NPHI MWD110 PU-S 10.57 44.69 35.9769 2186 14482.5 15575 FCNT MWD110 CNTS 877 5055 1338 2186 14482.5 15575 NCNT MWD110 CNTS 142335 2 33943 159124 2186 14482.5 15575 RHOB MWD110 G/CM 2.014 2.714 2.22854 2371 14403.5 15588.5 DRHO MWD110 G/CM -0.073 0.226 0.0389793 2371 14403.5 15588.5 PEF MWD110 BARN 1.59 4.35 2.27339 2371 14403.5 15588.5 CALA MWD110 INCH 8.37 9 8.53351 2369 14394 15578 First Reading For Entire File..........14394 Last Reading For Entire File...........15667 File Trailer Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.008 Physical EOF • Tape Trailer Service name .............LISTPE Date .....................05/11/16 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date .....................05/11/16 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF C7 Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services End Of LIS File
