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205-200
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Screen Scab Liner Install 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 12994'None Casing Collapse Structural Conductor Surface Intermediate Production D Sand Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 9/1/2024 12953'7951' 4-1/2" 3528' Packer: ZXP Liner Top Packer SSSV: None Perforation Depth MD (ft): L-80 6324' 2338' 6350' 5067-12921' Alternating Slotted Liner 4-1/2" 3426-3527' Alternating Slotted Liner Perforation Depth TVD (ft): 108' 2368' 16" 10-3/4" 78' 7-5/8" 4922' MD 108' 2194' 3649' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY West Sak Oil Pool TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025650, ADL0025661 205-200 P.O. Box 100360, Anchorage, AK 99510 50-029-23291-61-00 Kupauk River Field West Sak Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 4885' MD and 3390' TVD N/A Travis Smith Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: Travis.T.Smith@conocophillips.com (907) 265-6846 Willow Staff Completions Engineer KRU 1J-166L2 3531' 12994' 3531' 440 None N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Travis Smith Digitally signed by Travis Smith Date: 2024.07.18 11:44:38 -08'00' 324-418 By Grace Christianson at 2:56 pm, Jul 18, 2024 X DSR-7/18/24A.Dewhurst 05AUG24 10-404 VTL 8/5/2024JLC 8/6/2024 Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.08.07 10:35:00 -08'00' 08/07/24 RBDMS JSB 080824 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 16, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Elliott Tuttle Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Producer 1J- 166L1(PTD# 205-199) and 1J-166L2 (PTD# 205-200). Well 1J-166 was drilled and completed in February 2006 by Doyon 141 as a tri-lateral West Sak Producer with an ESP upper completion. The well was then worked over in April 2008 by Nordic 3, where a LEM (Lateral Entry Module) was landed in the L2 Hook hanger and a 4 1/2" Gas Lifted upper completion. The well has a history of making sand and it is known that if sand production is limited, it reduces the risk of MBE's (Matrix Bypass Events) from occuring. This RWO request is to land screen scab liners in the L1 and L2 Laterals. If you have any questions or require any further information, please contact me at 907-252-3347. Scab liners will be run in the L1 and L2 laterals by way of 2 5/8" Coiled Tubing on a service unit. The Scab liner will have to be run in sections to reach TD and will snapped together with sealed junctions. The last section run will have the packer and will be set by way of CT pressure to isolate the scab liner. ϭ:Ͳϭϲϲ>ϭ͕ϭ:Ͳϭϲϲ>ϮZtKWƌŽĐĞĚƵƌĞ tĞƐƚ^ĂŬWƌŽĚƵĐĞƌ ^ĐƌĞĞŶ^ĐĂď>ŝŶĞƌ/ŶƐƚĂůů Wdη͛ƐϮϬϱͲϭϵϵ͕ϮϬϱͲϮϬϬ WĂŐĞϭŽĨϰ WƌĞͲZŝŐtŽƌŬ͗ ϭ͘ ^ĞƚWůƵŐΛϱϰϰϯ͛Z<ƚŽŝƐŽůĂƚĞŵĂŝŶďŽƌĞůĂƚĞƌĂů Ϯ͘ ^Ğƚ/ŶĐƌĞĂƐĞĚĐĐĞƐƐ>ĂƚĞƌĂůŝǀĞƌƚĞƌ;/>ͿŝŶ>ϭůĂƚĞƌĂů ŶƚƌLJDŽĚƵůĞ;> DͿΛϱϯϲϳ͛Z<͕ƌŝĨƚǁŝƚŚϯ͘Ϯϱ͟ ^ĐƌĞĞŶƌŝĨƚ ϯ͘ KŶĐĞƌŝĨƚŝƐĐŽŵƉůĞƚĞĚ͕ƐĞƚ/ƐŽͲ^ůĞĞǀĞĂĐƌŽƐƐ>Ϯ> D͕WĞƌĨŽƌŵ^ĂŶĚ>ĂƚĞƌĂůĨůƵĨĨĂŶĚƐƚƵĨĨĐůĞĂŶŽƵƚĚŽǁŶƚŽ d;ϭϮ͕ϵϬϵ͛Z<ͿŽƌƚŽůŽĐŬƵƉ ϰ͘ WƵůů/ƐŽ^ůĞĞǀĞĨƌŽŵ>Ϯ> D͕WƵůů/>ŝǀĞƌƚĞƌĨƌŽŵ>ϭ> D͘ ϱ͘ ^ĞƚƉŽƐŝƚŝŽŶϭ/ƐŽͲƐůĞĞǀĞŝŶƚŚĞ>ϭ> D ϲ͘ ^Ğƚ/>ŝŶ>Ϯ> DΛϰϵϵϱ͛Z< ϳ͘ ƌŝĨƚ> DǁŝƚŚϯ͘Ϯϱ͟^ĐƌĞĞŶƌŝĨƚ͕WKK, ϴ͘ WĞƌĨŽƌŵ>ĂƚĞƌĂůĨůƵĨĨĂŶĚƐƚƵĨĨĐůĞĂŶŽƵƚĚŽǁŶƚŽd;ϭϮ͕ϵϱϯ͛Z<ͿŽƌƚŽůŽĐŬƵƉ ϵ͘ WƵůů/>ĂŶĚ/ƐŽ^ůĞĞǀĞ͕WƵůůWůƵŐ ϭϬ͘ KďƚĂŝŶƵƉĚĂƚĞĚ^,W^ƵƌǀĞLJĂƚϱϬϬϱ͛dD;KƌŶŽƚĞŐĂƵŐĞƉƌĞƐƐƵƌĞΛϯϯϴϬ͛ds͕ĂŶĚŬŶŽǁŶĨůƵŝĚďĞůŽǁ ŐĂƵŐĞĚĞƉƚŚͿ ϭϭ͘ ZĞŵŽǀĞǁĞůůŚŽƵƐĞĂŶĚďƵŝůĚƐĐĂĨĨŽůĚŝŶŐƚŽƐƵƉƉŽƌƚƚŚĞŵĂŬĞƵƉŽĨƚŚĞƐĐĂďůŝŶĞƌ ZŝŐtŽƌŬ͗ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ϵͬϭͬϮϬϮϰ D/Zh ϭ͘ D/Zh^>͞ Z͟ŽŝůƉĂĐŬĂŐĞƌŝŐƵƐŝŶŐϮϱͬϴ͟ĐŽŝůĞĚƚƵďŝŶŐŽŶϭ:Ͳϭϲϲ͘Ehϱϭͬϴ͟KD/KW ͕ƚĞƐƚƐĂŵĞƚŽ ϮϱϬϬƉƐŝ͘ Ϯ͘ Z/,ĂŶĚƐĞƚWůƵŐΛϱϰϰϯ͛Z<͘ ^ĂŶĚ>ĂƚĞƌĂůKƉĞƌĂƚŝŽŶƐ;ϭ:Ͳϭϲϲ>ϭͿ ϯ͘ Z/,ǁŝƚŚ/>^ĞƚƚŝŶŐ,͕ƐŶĂƉŝŶƚŽ>ϭ> DΛϱϯϲϳ͛Z<ĂŶĚƐĞƚ͘ ϰ͘ Z/,ŽŶϮϱͬϴ͟ŽŝůĞĚdƵďŝŶŐĂŶĚĂϯ͟EŽnjnjůĞĂŶĚĐŽŶĨŝƌŵd͕WKK,ůĂLJŝŶŐŝŶϴ͘ϲƉƉŐƐůŝĐŬƐĞĂǁĂƚĞƌ͘ ϱ͘ Wh^ĐƌĞĞŶ^ĐĂď>ŝŶĞƌǁŚŝůĞƉƵŵƉŝŶŐĂĐƌŽƐƐƚŚĞƚŽƉǁŝƚŚƐĂŵĞĨůƵŝĚŽŶĂŶĞƐƚĂďůŝƐŚĞĚĨŝůůƐĐŚĞĚƵůĞ Ă͘ ,ĂǀĞϮϱͬϴ͟ŬŝĐŬ:ŶƚŶĞĂƌǁŽƌŬƉůĂƚĨŽƌŵǁŝƚŚďĂůůƚLJƉĞƐĂĨĞƚLJǀĂůǀĞ͘ ϲ͘ ^ĐĂďůŝŶĞƌǁŝůůďĞƌƵŶŝŶƐĞĐƚŝŽŶƐ͕ĚƌĂĨƚƌƵŶŶŝŶŐŽƌĚĞƌ͗ # of Jnts Complete Description Length Tops Length of Liner/ Run Shorty Deployment Slv, 1.813" Polish Bore - 3" G Profile x 2 3/8" Hyd511 Pin Down 1.2 5402 160.65 Welltec 314WLTP, Metal Expandable Packer - Hyd511 3 5403.2 Lower Seal Bore Receptacle, 1.813" PB - Hyd 511 0.95 5406.2 5 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 155 5407.15 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 5562.15 NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 5562.65 2481.8 80 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 2480 5563.95 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 8043.95 NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 8044.45 1892.8 4 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 124 8045.75 8 2 3/8" Hydrill 511 4.6lb/ft, L-80 Blank Tubing 248 8169.75 49 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 1519 8417.75 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 9936.75 NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 9937.25 1272.8 5 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 155 9938.55 ϭ:Ͳϭϲϲ>ϭ͕ϭ:Ͳϭϲϲ>ϮZtKWƌŽĐĞĚƵƌĞ tĞƐƚ^ĂŬWƌŽĚƵĐĞƌ ^ĐƌĞĞŶ^ĐĂď>ŝŶĞƌ/ŶƐƚĂůů Wdη͛ƐϮϬϱͲϭϵϵ͕ϮϬϱͲϮϬϬ WĂŐĞϮŽĨϰ 26 2 3/8" Hydrill 511 4.6lb/ft, L-80 Blank Tubing 806 10093.55 10 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 310 10899.55 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 11209.55 NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 11210.05 1055.8 34 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 1054 11211.35 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 12265.35 NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 12265.85 641.8 5 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 155 12267.15 5 2 3/8" Hydrill 511 4.6lb/ft, L-80 Blank Tubing 155 12422.15 10 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 310 12577.15 2 2 3/8" Hydrill 511 4.6lb/ft, L-80 Pup Jnts 20 12887.15 3" OD Solid Bullnose - Hydrill 511 Box 0.5 12907.15 12907.65 ϳ͘ KŶ>ĂƐƚƌƵŶ͕^ĞƚWĂĐŬĞƌĂŶĚƌĞůĞĂƐĞ͘ ϴ͘ Z/,ĂŶĚ&ŝƐŚ/>ĨƌŽŵ>ϭ> D ^ĂŶĚ>ĂƚĞƌĂůKƉĞƌĂƚŝŽŶƐ;ϭ:Ͳϭϲϲ>ϮͿ ϵ͘ Z/,ǁŝƚŚ/>^ĞƚƚŝŶŐ,͕ƐŶĂƉŝŶƚŽ>Ϯ> DΛϰϵϵϱ͛Z<ĂŶĚƐĞƚ͘ ϭϬ͘ Z/,ŽŶϮϱͬϴ͟ŽŝůĞĚdƵďŝŶŐĂŶĚĂϯ͟EŽnjnjůĞĂŶĚĐŽŶĨŝƌŵd͕WKK,ůĂLJŝŶŐŝŶϴ͘ϲƉƉŐƐůŝĐŬƐĞĂǁĂƚĞƌ͘ ϭϭ͘ Wh^ĐƌĞĞŶ^ĐĂď>ŝŶĞƌǁŚŝůĞƉƵŵƉŝŶŐĂĐƌŽƐƐƚŚĞƚŽƉǁŝƚŚƐĂŵĞĨůƵŝĚŽŶĂŶĞƐƚĂďůŝƐŚĞĚĨŝůůƐĐŚĞĚƵůĞ Ă͘ ,ĂǀĞϮϱͬϴ͟ŬŝĐŬ:ŶƚŶĞĂƌǁŽƌŬƉůĂƚĨŽƌŵǁŝƚŚďĂůůƚLJƉĞƐĂĨĞƚLJǀĂůǀĞ͘ ϭϮ͘ ^ĐĂďůŝŶĞƌǁŝůůďĞƌƵŶŝŶƐĞĐƚŝŽŶƐ͕ĚƌĂĨƚƌƵŶŶŝŶŐŽƌĚĞƌ͗ # of Jnts Complete Description Length Tops Length of Liner/ Run Shorty Deployment Slv, 1.813" Polish Bore - 3" G Profile x 2 3/8" Hyd511 Pin Down 1.2 5040 2485.65 Welltec 314WLTP, Metal Expandable Packer - Hyd511 3 5041.2 Lower Seal Bore Receptacle, 1.813" PB - Hyd 511 0.95 5044.2 80 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 2480 5045.15 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 7525.15 NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 7525.65 2047.8 9 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 279 7526.95 7 2 3/8" Hydrill 511 4.6lb/ft, L-80 Blank Tubing 217 7805.95 10 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 310 8022.95 8 2 3/8" Hydrill 511 4.6lb/ft, L-80 Blank Tubing 248 8332.95 32 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 992 8580.95 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 9572.95 NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 9573.45 1644.8 8 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 248 9574.75 22 2 3/8" Hydrill 511 4.6lb/ft, L-80 Blank Tubing 682 9822.75 23 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 713 10504.75 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 11217.75 NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 11218.25 993.8 32 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 992 11219.55 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 12211.55 ϭ:Ͳϭϲϲ>ϭ͕ϭ:Ͳϭϲϲ>ϮZtKWƌŽĐĞĚƵƌĞ tĞƐƚ^ĂŬWƌŽĚƵĐĞƌ ^ĐƌĞĞŶ^ĐĂď>ŝŶĞƌ/ŶƐƚĂůů Wdη͛ƐϮϬϱͲϭϵϵ͕ϮϬϱͲϮϬϬ WĂŐĞϯŽĨϰ NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 12212.05 740.8 23 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 713 12213.35 Spaceout Jnts - 2 3/8" Hydrill 511 26 12926.35 3" OD Solid Bullnose - Hydrill 511 Box 0.5 12952.35 12952.85 ϭϯ͘ KŶ>ĂƐƚƌƵŶ͕^ĞƚWĂĐŬĞƌĂŶĚƌĞůĞĂƐĞ͘ ϭϰ͘ Z/,ĂŶĚ&ŝƐŚ/>ĨƌŽŵ>Ϯ> D ϭϱ͘ Z/,ĂŶĚ&ŝƐŚWůƵŐĨƌŽŵEŝƉƉůĞΛϱϰϰϯ͛Z<͕ĨƌĞĞnjĞƉƌŽƚĞĐƚǁĞůů͘ ZDK ϭϲ͘ EKW ͘ ϭϳ͘ ZDK͘ WŽƐƚͲZŝŐtŽƌŬ ϭϴ͘ ZĞƚƵƌŶƚŽƉƌŽĚƵĐƚŝŽŶ 'ĞŶĞƌĂůtĞůůŝŶĨŽ͗ WƌŽĚƵĐƚŝŽŶ ŶŐŝŶĞĞƌ͗Carolyn Kirchner tŽƌŬŽǀĞƌ ŶŐŝŶĞĞƌ͗Elliott Tuttle (907-252-3347/ Elliott.tuttle@conocophillips.com) ƵƌƌĞŶƚKƉĞƌĂƚŝŽŶƐ͗On Production tĞůůdLJƉĞ͗Producer ^ĐŽƉĞŽĨtŽƌŬ͗Confirm TD in L1 and L2 Laterals then deploy screen scab liners up to lateral windows. KWĐŽŶĨŝŐƵƌĂƚŝŽŶ͗Attached below MPSP: ϴϵϳƉƐŝƵƐŝŶŐϬ͘ϭƉƐŝͬĨƚŐƌĂĚŝĞŶƚ Static BHP͗ϭϮϯϱƉƐŝͬϯϯϳϳ͛dsŵĞĂƐƵƌĞĚŽŶϭϮͬϭϬͬϮϮ;ϳ͘ϬϯƉƉŐͿ ϭ:Ͳϭϲϲ>ϭ͕ϭ:Ͳϭϲϲ>ϮZtKWƌŽĐĞĚƵƌĞ tĞƐƚ^ĂŬWƌŽĚƵĐĞƌ ^ĐƌĞĞŶ^ĐĂď>ŝŶĞƌ/ŶƐƚĂůů Wdη͛ƐϮϬϱͲϭϵϵ͕ϮϬϱͲϮϬϬ WĂŐĞϰŽĨϰ 1J-166 Remedial SAS Install COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 108 108 16 15.25 62.5 H-40 Welded Welded Surface 2368 2194 10 3/4 9.95 45.5 L-80 BTC BTC Intermediate 6350 3649 7 5/8 6.87 29.7 L-80 BTC-M BTC-M D Liner LEM 5137 3443 4 1/2 3.958 12.6 L-80 IBT IBT B Liner LEM 5522 3520 4 1/2 3.958 12.6 L-80 IBT IBT A Sand Liner 12840 3717 4 1/2 3.958 12.6 L-80 IBT IBT Tubing 4922 3398 4 1/2 3.958 12.6 L-80 IBT-M IBT-M D Sand (L2), Screen Liner by Trips Trips Length (ft) Description 1 741 QCLL, Screen Jnts, Solid Bullnose 2 994 QCLL, Screen Jnts 3 1,645 QCLL, Solid and Screen Jnts 4 2,048 QCLL, Solid and Screen Jnts 5 2,486 3" G Profile, 314 WLTP, Screen Jnts, QCLL B Sand (L1), Screen Liner by Trips Trips Length (ft) Description 1 642 QCLL, Solid and Screen Jnts, Solid Bullnose 2 1,056 QCLL, Screen Jnts 3 1,273 QCLL, Solid and Screen Jnts 4 1,893 QCLL, Solid and Screen Jnts 5 2,482 QCLL, Screen Jnts 61613" G Profile, 314 WLTP, 5 Screen Jnts, QCLL (For Space Out) Surface Casing Conductor Perfs 4-1/2" DB-6 Landing Nipple @ 503' RKB (3.875" ID) 4-1/2" x 1" Camco KBG-2-1R GLM @ 2572' RKB 4-1/2" x 1" Camco KBG-2-1R GLM @ 4320' RKB Baker CMD Sliding Sleeve @ 4831' (3.812" ID) 4-1/2" Gauge Carrier, BH Gaurdian Gauge @ 4842' RKB 4-1/2" Locator/ Seal Assembly @ 4893' RKB D Sand LEM (Pos 2): - ZXP Liner Top Packer @ 4896' RKB - 190-47 Seal Bore Extension @ 4904'-4923' RKB - 3.75" DB Nipple @ 4959' RKB - Top of LEM 4995' RKB B Sand LEM (Pos 1): - ZXP Liner Top Packer @ 5104' RKB - 190-47 Seal Bore Extensoin @ 5123'-5143' RKB - Top of LEM 5366.6' RKB Pos 1 LEM Latched into L1 B Hook Hanger Intermediate Casing L1 Lateral: 6263' of Screen Jnts 1236' Solid Jnts L2 Lateral: 6680' of Screen Jnts 1172' Solid Jnts Pos 2 LEM Latched into L1 B Hook Hanger Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-166 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled Gauges 1J-166 12/10/2022 zembaej Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR Insulated 16 15.25 30.0 108.0 108.0 62.50 H-40 WELDED SURFACE 10 3/4 9.95 30.1 2,368.4 2,194.2 45.50 L-80 BTC INTERMEDIATE 7 5/8 6.87 26.4 6,350.0 3,648.8 29.70 L-80 BTCM D LINER LEM 4 1/2 3.96 4,885.0 5,137.0 3,443.3 12.60 L-80 IBT B LINER LEM 4 1/2 3.96 5,107.5 5,521.5 3,519.7 12.60 L-80 IBT A-SAND LINER 4 1/2 3.96 5,480.0 12,840.0 3,717.2 12.60 L-80 IBT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 22.4 Set Depth … 4,922.0 Set Depth … 3,398.0 String Max No… 4 1/2 Tubing Description TUBING WO Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 22.4 22.4 0.00 HANGER 10.850 TUBING HANGER T&C Non- Upset 3.958 503.3 503.3 0.57 NIPPLE 5.210 3.875" Camco "DB" Nipple 3.875 2,572.0 2,361.6 36.03 GAS LIFT 5.984 CAMCO KBG-2- 1R 3.938 4,319.5 3,225.8 69.38 GAS LIFT 5.984 CAMCO KBG-2- 1R 3.938 4,831.4 3,377.1 75.81 SLEEVE 5.490 BAKER CMD Sliding Sleeve (verified closed 1/11/21) 3.812 4,842.1 3,379.7 76.04 GAUGE 4.900 Baker Guardian Guage 4.000 4,893.7 3,391.7 77.04 LOCATOR 5.480 Locator / 2' space out 3.910 4,897.4 3,392.6 77.09 SEAL ASSY 4.750 BAKER 190-47 SEAL ASSEMBLY 3.880 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 10.0 10.0 0.00 HEAT TRACE HEAT TRACE 5/17/2008 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,572.0 2,361.6 36.03 1 GAS LIFT GLV BK-5 1 1,427.0 11/15/2020 0.156 4,319.5 3,225.8 69.38 2 GAS LIFT OV BK-5 1 0.0 11/15/2020 0.313 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,885.0 3,389.8 76.92 TIE BACK 6.430 TIE BACK EXTENSION 5.750 4,896.0 3,392.2 77.07 PACKER 6.550 ZXP LINER TOP PACKER 4.980 4,958.7 3,405.8 77.91 NIPPLE 5.000 3.75" DB NIPPLE 3.750 5,107.5 3,436.8 77.43 PACKER 6.550 ZXP LINER TOP PACKER 4.950 5,126.6 3,441.0 77.14 SBR 6.280 109-47 CASING SEAL BORE RECEPTACLE 4.750 5,145.9 3,445.3 76.85 XO BUSHING 6.040 CROSSOVER BUSHING 3.950 5,147.3 3,445.7 76.83 SWIVEL 5.770 BAKER CASING SWIVEL 3.960 5,442.8 3,506.5 80.17 NIPPLE 5.200 CAMCO DB-6 NIPPLE 3.563 5,475.2 3,512.0 80.32 BENT JT 4.500 3.880 5,480.0 3,512.8 80.35 PACKER 7.600 "HRD" ZXP Liner Top Packer 5.5" X 7.6" 4.970 5,499.0 3,516.0 80.44 NIPPLE 5.500 "RS" Packoff Seal Nipple 5.5" 4.875 5,531.4 3,521.3 80.59 LINRE XO THREAD 6.020 XO Bushing 3.92" ID, 6.02 OD 3.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,360.0 8,698.0 3,649.9 3,655.8 WS A2, A3, 1J- 166 1/19/2006 32.0 SLOTS ALL PERFS THIS WELLBORE - Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,945.0 10,031.0 3,661.1 3,711.7 WS A2, 1J-166 1/19/2006 32.0 SLOTS 10,648.0 10,710.0 3,678.3 3,668.4 WS A2, 1J-166 1/19/2006 32.0 SLOTS 10,990.0 12,808.0 3,651.8 3,715.9 WS A2, 1J-166 1/19/2006 32.0 SLOTS 1J-166, 7/17/2024 12:20:46 PM Vertical schematic (actual) A-SAND LINER; 5,480.0- 12,840.0 SLOTS; 10,990.0-12,808.0 SLOTS; 10,648.0-10,710.0 SLOTS; 8,945.0-10,031.0 SLOTS; 6,360.0-8,698.0 INTERMEDIATE; 26.4-6,350.0 B LINER LEM; 5,107.5-5,521.5 B-SAND LINER; 5,377.3- 12,909.3 D LINER LEM; 4,885.0-5,137.0 D-SAND LINER; 5,002.1- 12,952.7 GAS LIFT; 4,319.5 GAS LIFT; 2,572.0 SURFACE; 30.1-2,368.4 HEAT TRACE; 10.0 NIPPLE; 503.3 CONDUCTOR Insulated; 30.0- 108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 2/11/2006 Other Elev… 1J-166 ... TD Act Btm (ftKB) 12,853.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329100 Wellbore Status PROD Max Angle & MD Incl (°) 99.97 MD (ftKB) 10,663.58 WELLNAME WELLBORE1J-166 Annotation Last WO: End Date 4/17/2008 H2S (ppm) 424 Date 7/6/2023 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-166L1 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: WELL REVIEW 1J-166L1 5/13/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread B-SAND LINER 4 1/2 3.96 5,377.3 12,909.3 3,590.5 12.60 L-80 IBT Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 10,235.0 3,579.0 88.97 PLUG B-SAND IBP set 6/3/2008 6/3/2008 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,402.2 3,499.3 81.08 SWIVEL 5.750 Baker Casing Swivel 3.960 12,877.8 3,589.1 87.11 XO Reducing 4.500 4-1/2" X 3-1/2" XO sub 2.992 12,879.2 3,589.1 87.14 BENT JT 3.500 3-1/2" Bent Joint IBT, 9.2 ppf, L- 80 2.900 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,409.0 8,178.0 3,500.3 3,512.6 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,426.0 10,101.0 3,519.4 3,576.8 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 10,905.0 12,417.0 3,522.5 3,563.9 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 12,571.0 12,878.0 3,570.1 3,589.1 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 1J-166L1, 7/17/2024 12:20:47 PM Vertical schematic (actual) B-SAND LINER; 5,377.3- 12,909.3 SLOTS; 12,571.0-12,878.0 SLOTS; 10,905.0-12,417.0 PLUG; 10,235.0 SLOTS; 8,426.0-10,101.0 SLOTS; 5,409.0-8,178.0 B LINER LEM; 5,107.5-5,521.5 INTERMEDIATE; 26.4-6,350.0 D LINER LEM; 4,885.0-5,137.0 D-SAND LINER; 5,002.1- 12,952.7 GAS LIFT; 4,319.5 GAS LIFT; 2,572.0 SURFACE; 30.1-2,368.4 HEAT TRACE; 10.0 NIPPLE; 503.3 CONDUCTOR Insulated; 30.0- 108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 2/11/2006 Other Elev… 1J-166L1 ... TD Act Btm (ftKB) 12,952.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329160 Wellbore Status PROD Max Angle & MD Incl (°) 99.97 MD (ftKB) 10,422.57 WELLNAME WELLBORE1J-166 Annotation Last WO: End Date 4/17/2008 H2S (ppm) 424 Date 7/6/2023 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-166L2 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Type 1 Isolation Sleeve 1J-166L2 11/9/2019 mcanej Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread D-SAND LINER 4 1/2 3.96 5,002.1 12,952.7 3,528.4 12.60 L-80 IBT Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,027.0 3,419.7 79.25 SWIVEL 4.750 Baker Casing Swivel 3.960 12,920.8 3,526.8 87.23 XO Reducing 4.500 4-1/2" X 3-1/2" XO sub 2.992 12,922.2 3,526.9 87.22 BENT JT 3.500 3-1/2" Bent Joint IBT, 9.2 ppf, L- 80 2.900 12,951.2 3,528.4 87.03 WLEG 3.500 Baker 3-1/2" Guide Shoe ( No float) 2.900 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,067.0 7,805.0 3,426.4 3,464.7 WS D, 1J-166L2 2/7/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,021.0 8,325.0 3,463.9 3,471.5 WS D, 1J-166L2 2/7/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,571.0 9,806.0 3,472.2 3,492.6 WS D, 1J-166L2 2/7/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 10,517.0 12,921.0 3,453.1 3,526.9 WS D, 1J-166L2 2/7/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 1J-166L2, 7/17/2024 12:20:48 PM Vertical schematic (actual) D-SAND LINER; 5,002.1- 12,952.7 SLOTS; 10,517.0-12,921.0 SLOTS; 8,571.0-9,806.0 SLOTS; 8,021.0-8,325.0 SLOTS; 5,067.0-7,805.0 INTERMEDIATE; 26.4-6,350.0 D LINER LEM; 4,885.0-5,137.0 GAS LIFT; 4,319.5 GAS LIFT; 2,572.0 SURFACE; 30.1-2,368.4 HEAT TRACE; 10.0 NIPPLE; 503.3 CONDUCTOR Insulated; 30.0- 108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 2/11/2006 Other Elev… 1J-166L2 ... TD Act Btm (ftKB) 12,994.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329161 Wellbore Status PROD Max Angle & MD Incl (°) 95.60 MD (ftKB) 10,233.79 WELLNAME WELLBORE1J-166 Annotation Last WO: End Date 4/17/2008 H2S (ppm) 424 Date 7/6/2023 Comment SSSV: NIPPLE OF Tkt • • 4t,, 1 y/ s., THE STATE Alaska Oil and Gas 4,Q of ALA, AS}(A Conservation Commission itittS = 333 West Seventh Avenue f .;'»h:' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 o Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov John Pierce Sr. Wells Engineer .' 'a ) ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage,AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-166L2 Permit to Drill Number: 205-200 Sundry Number: 318-014 Dear Mr. Pierce: 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration 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. Sincerely, Hollis S. French \ Chair DATED this36' day of January, 2018. RBDMS L'—f: - 1 2018 0 • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALSJAN 1 2 2018 ( ei 20 AAC 2 .280 AOtcCO � • 5 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ElRepair Well Aerations shutdown❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other: RPPG MBE Trtrnt 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development 0. 205-200 ' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-23291-61 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1J-166L2 Will planned perforations require a spacing exception? Yes ❑ No 0 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25650,ADL 25661 . Kuparuk River Field/West Sak Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12,994'\ 3,531' k 12949 , , 3528 1500 psi NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 108' 108' Surface 2,338' 103/4 2,368' 2,194' Intermediate 4,991' 7 5/8 5,017' 3,649' Liner 7,951' 4 1/2 12,953' 3,528' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5067-7805,8021-8325,8571- 3426-3465,3464-3471,3472- 4 1/2 L-80 4,922' 9806. 10517-12921 ' 3493,3453-3527 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER=ZXP LINER TOP PACKER • 4896 MD and 3392 ND PACKER=ZXP LINER TOP PACKER 15107 MD and 3467 ND PACKER=HRD ZXP LINER TOP PACKER • 5480 MD and 3513 ND SSSV =NONE N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development[]- Service ❑ 14.Estimated Date for 3/1/2018 15.Well Status after proposed work: Commencing Operations: OIL 0, WINJ 0 WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR 0 SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce Contact Name: John Peirce Authorized Title: Sr.Wells Engineer Contact Email: John.W.Peirce@cop.com n 1—A �_ r Contact Phone: (907)265-6471 Authorized Signature: l.✓ Date: 1 1 '� COMMISSION USE ONLY Conditions of approval: Notify Commis ion so that a representative may witness Sundry Number: I . 1-3 . 0 , L Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes ❑ No I RBD,Mf p Li, FT - 1 2C18 Spacing Exception Required? Yes ❑ No V Subsequent Form Required: /19 " -40 C?1— --.%*s-N-II--' Approved by: COMMISSIONER APPROVED BY T AT: Date: t )Tb l)I'M 1113.11 AoteOis i j TL 1/2G l"f G ' Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate , KUP P D 1J-166 Cono Phillips 3 y Well AttributeW Max Angle./ TD Alaska,me Wellbore API/UWI Field Nome Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) CnruocofMBips 500292329100 WEST SAK PROD _ 99.97 10,663.58 12,853.0 •.• ,� Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) t Rig Release Date 1J-166,1/10/20189.1:13 AM SSSV:NIPPLE Last WO: 4/17/2008 31.01 2/11/2006 Vertical ni mate jactuen Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:WELL REVIEW osborl 5/13/2013 HANGER;22.4 ) I I f ll Casing strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR Insulated 16 15.250 30.0 108.0 108.0 62.50 H-40 WELDED Casing Description OD(in) ID(In) Top(kKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 1,. SURFACE 103/4 9.950 30.1 2,368.4 2,194.2 4550 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ing INTERMEDIATE 75/8 6.875 26.4 6,350.0 3,648.8 29.70 L-80 BTCM CONDUCTOR Insulated;30.6„„ 11 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVO)...Wt/Len(I...Grade Top Thread 108.0 D LINER LEM 41/2 3.958 4,885.0 5,137.0 3,443.3 12.60 L-80 IBT NIPPLE;503.3 _ Liner Details HEAT TRACE;10.0 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Indy) Item Des Com (in) 4,885.0 3,389.8 76.92 TIE BACK TIE BACK EXTENSION 5.750 4,896.0 3,392.2 77.07 PACKER ZXP LINER TOP PACKER 4.980 SURFACE;30.1-2,388.4----.. 44,904.0 3,394.0 77.18 SBE SEAL BORE EXTENSION 190-47 4.760 4,958.7 3,405.8 77.91 NIPPLE 3.75"DB NIPPLE 3.750 it GAS LIFT;2,572.0 it 4,994.7 3,413.3 78.13 HANGER LEM ABOVE HOOK HANGER 3.910 5,001.5 3,414.7 78.12 HANGER LEM INSIDE HOOK HANGER 3.930 5,133.7 3,442.6 77.04 SEAL ASSY NON-LOCATING SEAL ASSEMBLY 3.890 al Casing DescriptionOD(in) ID(in) Top(ftKB) Set Depth(ftKB) set Depth(ND)...WtlLen(I...Grade Top Thread B LINER LEM 41/21 3.9581 5,107.51 5,52151 3,519 12.601 L-80 IBT ME Liner Details GAS LIFT;4,319.5 Nominal ID I Top(ORB) Top(TVD)(ftKB) Top Incl)°) Item Des Com (in) 5,107.5 3,436.8 77.43 PACKER ZXP LINER TOP PACKER 4.950 SLEEVE,4,831.4II 5,126.6 3,441.0 77.14 SBR 109-47 CASING SEAL BORE RECEPTACLE 4.750 5,145.9 3,445.3 76.85 XO BUSHING CROSSOVER BUSHING 3.950 GAUGE;4,842.1 ��t., 5,147.3 3,445.7 76.83 SWIVEL BAKER CASING SWIVEL 3.960 5,366.6 3,493.2 79.61 HANGER LEM ABOVE HOOK HANGER 3.950 B 5,377.3 3,495.1 79.69 HANGER LEM INSIDE HOOK HANGER 3.688 LOCATOR 4,893.7 5,442.8 3,506.5 80.17 NIPPLE CAMCO DB-6 NIPPLE 3.563 -- 5,475.2 3,512.0 80.32 BENT JT 3.880 SEAL ASSY,4,897.4 5,518.2 3,519.2 80.53 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread A-SAND LINER 4 1/2 3.958 5,480.0 12,840.0 3,717.2 12.60 L-80 IBT Liner Details " Nominal ID Top(kKB) Top(TVD))ftKB) Top Ind()) Item Des Com (in) 5,480.0 3,512.8 80.35 PACKER "HRD"ZXP Liner Top Packer 5.5"X 7 6" 4.970 Al99.0 3,516.0 80.44 NIPPLE "RS"Packoff Seal Nipple 5.5" 4.875 D-SAND LINER;5,002.1- '�fi� 5,511.7 3,518.1 80.49 SBE 190-47 Casing Seal Bore Ext.4.75"10 x 6.25"OD 4.750 12,952.7 4 Tubing Strings Tubing Description String Ma...ID(in) Top(kKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ibfft) Grade Top Connection TUBING WO 41/2 3.958 22.4 4,922.0 3,398.0 12.60 L-80 IBTM Completion Details Top(ftKB) Top(TVD)(ftKB) lop Incl(°) Item Des Com Nominal ID (in) „�,t 22.4 22.4 0.00 HANGER TUBING HANGER 3.958 0 LINER LEM;4,885.0-5,1370 503.3 503.3 0.57 NIPPLE 3.875"Camco"DB"Nipple 3.875 i* 4,831.4 3,377.1 75.81 SLEEVE BAKER CMD Sliding Sleeve 3.812 4,842.1 3,379.7 76.04 GAUGE Baker Guardian Guage 4.000 4,893.7 3,391.7 77.04 LOCATOR Locator/2'space out 3.910 '4 1 4,897.4 3,392.6 77.09 SEAL ASSY BAKER 190-47 SEAL ASSEMBLY 3.880 0-SAND LINER 5,233 77. `fig 4' Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(kKB) (kKB) (°) Des Com Run Date ID(in) 10.0 10.0 0.00 HEAT HEAT TRACE 5/17/2008 0.000 EA TRACE Perforations&Slots Et -- Shot Dens .(7'..- 7-4 Top(TVD) Btm(TVD) (shots/ It Top(ftKB) Btm(kKB) (ftKB) (ftKB) Zone Date ft) Type Com 6,360.0 8,698.0 3,649.9 3,655.8 WS A2,A3, 1/19/2006 32.0 SLOTS ALL PERFS THIS B LINER LEM;5,107.5-5,521.5 1J-166 WELLBORE- • Alternating slotted/blank pipe 0.125"x 2.5"x 32 spf @ 4 Circumferential adjacent rows,3" Centers staggered 18 deg.,3 ft.non-slotted ends INTERMEDIATE;28.4-6,350.0 8,945.0 10,031.0 3,661.1 3,711.7 WS A2,1J- 1/19/2006 32.0 SLOTS 166 SLOTS;8,360.0.8,898.0 1. ! 10,648.0 10,710.0 3,678.3 3,668.4 WS A2,1J- 1/19/2006 32.0 SLOTS Ilr- t 166 10,990.0 12,808.0 3,651.8 3,715.9 WS A2,1J- 1/19/2006 32.0 SLOTS SLOTS;8,945.0-10,031.0 166 - y- Mandrel Inserts - 1- St SLOTS;10,648.0-10,710.0 ati N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com SLOTS;10,990.612,808.0 1 2572 0 2,301 6 CAMCO KBG-2- 1 GAS LIFT GLV BK-5 0.125 1,475.0 4/23/2008 l'- 1R A-SAND LINER;5,480.6 12,840.0' KUP IND • 1J-166 Con©coPhillips 0 AI,Iskd. Cono 4hiNipa --- 1.1-186,1/10/20189:15'.15 AM Verdratschematic.,iacaw/ HANGER;22.4 I -� j I Mandrel Inserts St ati onTop(TVD) Valve Latch Port Size TRO Run .,::. N Top 15165) MKS) Make Model OD(in) Sery Type Type (In) (psi) Run Date Com 2 4,319.5 3,225.8 CAMCO KBG-2- 1 GAS LIFT OV BK-5 0.313 0.0 4/23/2008 1R CONDUCTOR Insulated, Notes:General&Safety 1050 End Date Annotation NIPPLE;503.3 2/10/2006 NOTE:MULTI-LATERAL WELL:1J-166(A2-SAND),1J-166L1(B-SAND),1J-166L2(D-SAND) HEAT TRACE;10.0 6/22/2008 NOTE:VIEW SCHEMATIC w/9.0REV SURFACE;30.1-2,358.4—, I. GAS LIFT;2,572.0 z.: •- GAS LIFT;4,319.5 ISM SLEEVE,4,831.4 -� 111 GAUGE;4,842.1 LOCATOR;4,893.7 —� SEAL ASSY;4,897.4IT -_ D-SAND LINER;S 12,952.7,952.7 D LINER LEM;4,585.0-55,137.0 dl F' er 0-SAND LINER;5,377.3- t)]1 rfl 12,909.3 (I 1 V P B LINER LEM',5,107.5-5.521 5 '; . l INTERMEDIATE;26.4-6,350.0 SLOTS;8,360.0-8,698.0 SLOTS;8,945.0-10,031.0.--.I I SLOTS,10,e4e.0-10,710.0 r SLOTS;10,990.0-12,608.0 A-SAND LINER;5,480.0- 12,840.0 KUP PPD 1J-166L2 ConocoPhillips 1Well Attribute Max Angle TD AIask.a li1G:. Wellbore APIIUWI Field Name Wellbore Status ncl("1 MD(ftKB) Act Btm(ftKB) wro0tiphigips'`'' 500292329161 WEST SAK PROD 95.60 10,233.79 12,994.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1J-1662,1/1020189:16:26 AM SSSV:NIPPLE Last WO: 4/17/2008 31.01 2/11/2006 Vedual sc{.emapc{actual}. Annotation Depth(ftKB) End Date Annotation Last Mod By End Date .. .. _ . _.. _... _.__.. ....__. Last Tag: Rev Reason:WELL REVIEW osborl 5/13/2013 Casing Strings HANGER;22.4 cm ,,,,,.lit '',, Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread D-SAND LINER 4 1/2 3.958 5,002.1 12,952.7 3,528.4 12.60 L-80 IBT Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) ' 5,002.1 3,414.8 78.11 HANGER 7-5/8"x 4-1/2"Baker Mod B1 EHH(Outside Casing 5.630 1 .. i 1 .1sMeJ1I]I.uuuuuIIs! I*lIIuuuIIr1:L8IIi:Yue1tt:lIIIIIIIIIII ].'efrd:!t1!iT10D!I.IIaD:fl.1TtTttttrbvnI.....IuuIKIIt(8l f CONDUCTOR Insulated;30.0.- - il I II 5,027.0 3,419.7 79.25 SWIVEL Baker Casing Swivel 3.960 108 12,920.8 3,526.8 87.23 XO Reducing 4-1/2"X 3-1/2"XO sub 2.992 NIPPLE;5033 - 12,922.2 3,526.9 87.22 BENT JT 3-1/2"Bent Joint IBT,9.2 ppf,L-80 2.900 12,951.2 3,528.4 87.03 WLEG Baker 3-1/2"Guide Shoe(No float) 2.900 HEAT TRACE;10.0 Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots/ Top(MB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com SURFACE;30.1-2,368.4---. 5,067.0 7,805.0 3,426.4 3,464.7 WS D,1J- 2/7/2006 32.0 SLOTS Alternating slotted/blank 166L2 pipe 0.125"x 2.5"x 32 spf @ 4 Circumferential adjacent rows,3" Centers staggered 18 deg.,3 ft.non-slotted GAS LIFT,2,572.0 - ends 8,021.0 8,325.0 3,463.9 3,471.5 WS D,1J- 2/7/2006 32.0 SLOTS Alternating slotted/blank 166L2 pipe 0.125"x 2.5"x 32 spf @ 4 Circumferential adjacent rows,3" Centers staggered 18 deg.,3 ft non-slotted ends GAS LIFT;4,319 5 8,571.0 9,806.0 3,472.2 3,492.6 WS D,1J- 2/7/2006 32.0 SLOTS Alternating slotted/blank 166L2 pipe 0.125"x 2.5"x 32 spf @ 4 Circumferential . adjacent rows,3" 11 Centers staggered 18 SLEEVE;4,831.4 11111 deg.,3 ft.non-slotted ends GAUGE;4,8421 nets 10,517.0 12,921.0 3,453.1 3,526.9 WS D,1J- 2/7/2006 32.0 SLOTS Alternating slotted/blank 166L2 pipe 0.125"x 2.5"x 32 spf @ 4 Circumferential adjacent rows,3" Centers staggered 18 17 deg.,3 ft.non-slotted ends LOCATOR;4,893.7 Notes:General&Safety SEAL ASSY;4,897 4 I' End Date Annotation 2/10/2006 NOTE:MULT-LATERAL WELL.1J-166(A2-SAND),1J-166L1(B-SAND),1J-166L2(D-SAND) 6/22/2008 NOTE:VIEW SCHEMATIC w/9.0REV �.I I' 11 I INTERMEDIATE;26.46,3500 )I� I D LINER LEM,4,885.0.5,137.0' L I' td € l' I 1 i SLOTS,5,067.0-7,005.0 - r SLOTS;8,021.0-8,325.0 "- ____ [ SLOTS,8,571.0.9606.0 t SLOTS,10,517.0.12,921.0 1-- D-SAND LINER,5,002.1 8 - 12,952.7 • • 1J-170L2 to 1J-166L2 RPPG Treatment of D MBE West Sak 1J-170L2 is a D sand horizontal injector lateral constructed with 4.5", L-80 liner located at 6409' - 12671' RKB. The D lateral contains slotted joints alternating with blank joints over the entire liner length. On 10/10/15 an MBE occurred in 1J-170 while the 1J-170L1 B lateral was isolated by an Iso-Sly (due to a B MBE identified 8/1/08 at —8060' RKB by a B lateral (PROF). Mainbore IPROF's were performed in late 2015 that indicated a D MBE was likely. An IPROF of 1/5/18 was run in the 1J-170L2 D lateral to 12621' RKB and identified a D MBE at —9350' MD about half way down the lateral. Currently 1J-170 has a D Diverter set, and a B Iso-Sly set, but the A sand lateral is open. It is proposed that the D lateral be perforated near the D MBE and that a fullbore RPPG treatment be performed to seal the D MBE at —9350' RKB. Proposed Procedure: Coil Tubing: 1) Reconfigure 1J-170 for a D MBE treatment as follows: a) Pull D Diverter at 6400' RKB b) Pull B Iso-Sly at 6818' RKB c) Set DB Plug in DB Nipple at 6896' RKB d) Reset B Iso-Sly at 6818' RKB e) Reset D Diverter at 6400' RKB 2) RIH with 2" run OD perf gun to shoot 5' of large hole perfs, 6 spf, 60 deg phasing, in 4.5" slotted liner at +/- 9350 - 9355' RKB (target) to perforate over the D MBE area at —9350' RKB. POOH with gun. Verify all shots fired. Fullbore Pump RPPG Treatment to Seal D MBE: 3) Shut-In 1J-166 offset producer to the MBE —24 hrs before RPPG job, and then put 1J-170L2 on PWI at 500 - 1000 BWPD to reestablish injection through D MBE to 1J-166L2. RU mixing van & pumping equipment on 1J-170. SI PWI to 1J-170L2 and then proceed to fullbore pump RPPG slurry at steady established rate in range of 2 - 3 bpm. Mix slurry in Seawater by adding 1 - 4 mm mesh RPPG to make —0.75 ppg slurry concentration on-the-fly, while fullbore pumping slurry down 1E-1J-170L2 to D MBE located at 142 bbls down the wellbore. Continue pumping at steady rate and slurry concentration until WHIP reaches —800 psi, and then swap from RPPG slurry to 100 bbls Seawater spacer, followed by 41 bbls Diesel FP (to 2000' TVD), to leave RPPG slurry —1 bbl underdisplaced to MBE, followed by Shutdown. Wait 48 hrs for swelling RPPG particles to fully crosslink together in the D MBE to form a very stout amalgamated non-flowing gel before returning 1 E-166 to production. Coil Tubing: 4) RIH with jet swirl nozzle & tag RPPG top. If needed, jet RPPG to deep as possible with Diesel, to prevent stuck CT, while injecting RPPG & Diesel from liner to MBE &/or formation. POOH. RD CTU. Place 1J-170L2 on PWI to evaluate D MBE treatment results. JWP 1/11/2018 Image Project Vl/ell 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. ~Q ~ - a,~ ~ Well History File Identifier Organizing (done) RESCAN ~olor Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: .~.,,d~ iiumiiiuiiuui DIGITAL DATA ~skettes, No. ^ Other, No/Type: ae.~a~~eeded iuuiumiiiuii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ a3 © /s/ Project Proofing II I II II II I I III ((III BY: aria Date: ~ (~ /s/ Scanning Preparation ~_ x 30 = © + ~ =TOTAL PAGES~~ BY i t D 3 (Count does not include cover sheet) / / : ar a a e: O s Production Scanning Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES NO BY: aria Date:~~~ ~ ©g ~ /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO I BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II II II I II II I I III ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIII III (I'I II P P P 10lfif2005 We11 History File Cover Page.doc • Page 1 of 2 Maunder, Thomas E (DOA) From: Schwartz, Guy L [Guy.L.Schwartz@conocophillips.com] Sent: Friday, September 19, 2008 8:27 AM ~ Q S _ ~ Q~ To: Maunder, Thomas E (DOA) ~ ~~ ~ ~ ~ L ~ Subject: RE: 1J-166L1 (205-199) Attachments: 1J-166 A2 Lat Blank- Slotted Liner detail.xls; 1J-166 B Lat Blank- Slotted Liner detail.xls; 1J- 166 D Lat Blank- Slotted Liner detail.xls Here is the liner details... let me know if anything else is needed! Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 guy. I. schwartz@conocoph i Ilips. com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, September 19, 2008 8:10 AM To: Schwartz, Guy L Subject: RE: 1J-166L1 (205-199) Guy, Thanks for the information. Yes, would you please send the liner detail and for the other legs as well. I do think it is appropriate to have sent the 404. Having information on potential remedies for MBEs is important. It all goes to maintaining the best available well file possible. Call or message with any questions. Tom Maunder, PE AOGCC From: Schwartz, Guy L [mailto:Guy.L.Schwartz@conocophillips.com] Sent: Thursday, September 18, 2008 4:48 PM To: Maunder, Thomas E (DOA) Subject: RE: iJ-166L1 (205-199) Tom, We have swell packers staged (in some of the blank pipe sections} in the well to give us some options of shutting off part of the well. Thus we set a IBP in a blank section to isolate the lower section from a MBE breakthrough (ie water !!). It seemed to work great.... The B lateral has .125" slotted liner alternating with blank sections. I could forward the liner detail if you want it. the key though is that we ran swell packers too. Good thing in this well as it allowed us to shut off a lower water 9/19/2008 • source. • Page 2 of 2 Let me know if this is enough info... I wasn't sure if we needed to send a 404 in as this is a retrievable plug. But in this case we would like to make it at least permanent for the short term. Could be in there for a while!! Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 guy.I.schwartz@conocophillips.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, September 18, 2008 4:13 PM To: Schwartz, Guy L Subject: 1J-166L1 (205-199) Guy, Could you enlighten me a little on this RBP work? Is there an MBE contributing water? Also, looking at the 404, long perforated intervals are listed. Does the liner alternate slotted and solid sections? On the 404 they are listed as perfs. Thanks in advance. Tom Maunder, PE AOGCC 9/19/2008 • • 1J-166 'D' Sand Liner Detail well: 1J-166 L2 4-112" Slotted and Blank Liner Date: 2/7/2006 Alasi~a, Inc. ~v~i~ v~ DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 1 LENGTH TOPS 4991.95 4991.95 4" DP to Surface =_> 4991.95 4991.95 4991.95 4" DP XO 4.75" OD X 2.5625" A 1.61 4991.95 Liner Runnin Tool 5" Does not sta in hole 8.58 4993.56 7-518"x 4-1/2" Baker Mod B1 FHH (Inside Casing 16.86') 16.86 5002.14 7-5/8"x 4-1 /2" Baker Mod B1 FHH (Outside Casing 6.04') 6.04 5019.00 4-1 /2" Crossover Pu Joint 2.01 5025.04 Baker Casin Swivel 2.80 5027.05 4-112" IBT, 12.6 f, L-80 Pu Joint 5.78 5029.85 Jts 256 to 256 1 Jts 4-112", 12.6 f, L-80, IBT Blank Casin 31.29 5035.63 Jts 167 to 255 89 Jts 4-1/2",12.6 f, L-80, IBT Slotted Casin 2738.35 5066.92 Jts 160 to 166 7 Jts 4-1/2", 12.6 f, L-80, IBT Blank Casin 216.10 7805.27 Jts 150 to 159 10 Jts 4-112",12.6 f, L-80, IBT Slotted Casin 303.44 8021.37 Jts 142 to 149 8 Jts 4-1/2", 12.6 f, L-80, IBT Blank Casin 245.91 8324.81 Jts 102 to 141 40 Jts 4-1 /2",12.6 f, L-80, IBT Slotted Casin 1235.49 8570.72 Jts 79 to 101 23 Jts 4-1/2", 12.6 f, L-80, IBT Blank Casin 710.77 9806.21 Jts 1 to 7s 78 Jts 4-1 /2",12.6 f, L-80, IBT Slotted Casiri 2403.77 10516.98 4-1 /2" X 3-1 /2" XO sub 1.43 12920.75 3-1 /2" Bent Joint IBT, 9.2 f, L-80 29.03 12922.18 Baker 3-1/2" Guide Shoe No float 1.44 12951.21 12952.65 TD 6-3/4" Hole 12,994' MD / 3530' TVD Shoe 12,952.65' Rathole 41.35' To of window "D" lateral 5005' MD Bttm of window "D" lateral 5017' MD Hooked btm of window 5019° w/ FHH 2' low Total of 6 Constrictor Packers 10,505', 9806', 8565', 8347', 8005', 7825' To of "B" lateral LEM 5,104' H droForm Centralizers laced 1 er 'oint on all 'oints Sto rin sin the middle of 'oints 1-167 and 225-256 32 'oints. No centralizers on constrictor 'oints. Total of 250 Centralizers and 192 Sto s. Ran total o f 217 'ts Slo tted = 6681.05' and 39 'ts Blank= 1204.07', Slots are U Wt 187K w/ 32 2.5" Ion x .125" 4 Circumferential ad'acent rows, 3" Centers Dn Wt 50K sta eyed 18 de ., 3 ft. non-slotted ends Block Wt 35K Ran 250-- 4.5" X 5.75"OD H droForm centralizers. DO NOT run an centrilizers on the 'oints with a constrictor packer. Top centrilizer_ 5040' MD Used Run-N-Seal thread compound on all connections. All drifted w/ 3.833" rabbit. FZ~~,;t~vcu ~ ~ STATE OF ALASKA MAY 2 0 200$ ALASKA OIL AND GAS CONSERVATION COMMISSION p,~aska Oil & Gas Cons. COTI'1f111SS10fi REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Pertormed: Abandon ^ Repair Well ^~ ` Plug Perforations ~ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^~ ' PerForate New Pooi ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development 0' Exploratory ^ 205-2Q0 /• 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23291-61 - 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' - 1J-166L2 ~ 8. Property Designation: 10. Field/Pool(s): ADL 25661 & 25650 Kuparuk River Field / West Sak Oil Pool • 11. Present Well Condition Summary: Total Depth measured 12994' ~ feet true vertical 3531' ~ feet Plugs (measured) Effective Depth measured 12949' feet Junk (measured) true vertical 3528' feet Casing Length Size MD TYD Burst CoUapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 2259' 10-3/4" 2368' 2194' INTERMEDIATE 6241' 7-5/8" 6356' 3650' - •`' '-'°°'"' LINER 7950' 4-1/2" 12950' 3530' PerForation depth: Measured depth: 5067'-7805', 8021'-8325', 8571'-9806', 10517'-72921' true vertical depth: 3426'-3465', 3464'-3471', 3472'-3492', 3453'-3527' ~~'y~~~,~±~~~~, ~,~j;~ ~ t; ~~1~~; Tubing (size, grade, and measured depth) tbg in main wellbore, , MD. Packers & SSSV (type & measured depth) no packer no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation 1529 - 1059 2707 - 251 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^' Service ^ Daily Report of Well Operations _X 16. Well Status after work: 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: none contact Brett Packer Printed Name Brett Packe~ Title Wells Group Engineer s/~5/~~ .-i~n~ Signature Phone: 265-6845 Date P red b Sha n AIlsu rak 263-4612 h~'n ~(~ ~~ ~, s.2~. ~ Form 10-404 Revised 04/2006 ~~~ 1\ 1 t~ ~ ~*- ~~~ 1`~~ ~;; ~~ ~ 7(~~~ ~ Submit O i' al Qnl~ ,,~ ~ ~ i ~I ~- ~ ,, ,%~ _~ -,~ ti:`~ C~r~a~oPhi~~ips Time Log Summary ~ . . WelNtew 6Yeb ReAorting . . . . ~, ..,-.. . ., _<-- .~.. ,<. .., .. ......__ ., ~ ~; ~ ~„ ~ :_~~~. .~ _:~,~:x. ,~r. <~ ..:~z ~`~~`.. . ..~ .=`~~ Well Name: 1 J-166 Job Type: RECOMPLETION ~~}~~ . .. . ~ ~ :._.-A,~.., ..,. _ ,. Y i ,~,. \ > ~-'i~x q~x .z ;rERaa4`.~'~., " 4 . ~ ? ~ .... ~ ,,... ~z , ,T.~ ~"~#n.'~~::. ., P.i«. . .. . ~ ~~~ , _"^?.F`. ,: ,T..'~. ~ " , ~ _ ~ _`~, 'a~'-~. ~.~, ~ E`l~ ~o xsl, ' - ~ ~m~~ ~ \ 04/10/2008 00:00 01:30 1.50 COMPZ MOVE MOB P Nordic 3 Pulled off of 1J-135 and clean u cellar and tree. Move ri to 1J-166. 01:30 02:00 0.50 COMPZ MOVE PSIT P Spot and level rig. Set up handi berm. 02:00 05:00 3.00 COMPZ RPCOti OTHR P Take on 600 bbls of hot 6% KCL fluid. Load lubricator in pipe shed and lubricate BPV from well. Tie into tree and IA. Open up well: 450 psi tbg, 700 si IA, 500 si OA. 05:00 09:00 4.00 COMPZ RPCO OTHR P Vent gas off of well to Tiger tank. Shut down to reconfigure Tiger tank for Simm Ops on 1J-10. PT line to tiger tank to 2500 si. 09:00 11:00 2.00 COMPZ RPCO CIRC P Reverse circulate 340 bbl of 8.4 ppg 6°/a KCL @-110 deg. Inital tubing press = 330 psi, initial IA press = 680 psi. Tubing and IA press at 0 psi after circulating. 340 bbl of refurns to the ti er tank. 11:00 1730 6.50 COMPZ RPCOh NUND P Install BPV, ND tree, NU BOPE. Install blankin lu . 17:30 22:30 5.00 COMPZ WELC BOPE P Test BOPE 250/2500 psi. Test Annular @ 250/2,500 psi. 24 hr Notice was given @ 19:00 hrs on 4-9-08 to AOGCC and witness of test was waived by Chuck Scheve @ 14:00 hrs on 4-10-08. 2230 00:00 1.50 COMPZ RPCOh OTHR P Pull blanking plug and BPV. RU ESP E ui . 04/11/2008 00:00 01:30 1.50 COMPZ RPCOh OTHR P Continue to RU ESP Equip. Install Landin Jt. BOLDS. 01:30 02:00 0.50 4,083 4,078 COMPZ RPCOh OWFF P Unland hanger @ 150k. Pull inner hanger above Outer Hanger w/ 130k u wt. Monitor well for flow/Good. 02:00 02:30 0.50 4,078 4,025 COMPZ RPC06 OTHR P Continue to Pull hanger to floor and cut ESP cable below splice. Lay down landing jt. Lay down Hanger and 't. 02:30 11:30 9.00 4,025 4,025 COMPZ RPCOti OTHR P String ESP cable over sheave and tie into s ool. POOH 11:30 14:00 2.50 4,025 0 COMPZ RPCOh PULD P Lay down ESP completion. Recovered all clamps and bands: 68 cannon clamps, 3 protectolizers, 2 flat guards, 4 SSbands. Load out ESP com letion. 14:00 14:30 0.50 0 0 COMPZ RPCOti OTHR P Clean rig floor. • ~ • • ' . • 04/14/2008 04:30 0730 3.00 0 96 COMPZ RPCOh SFTY P Held PJSM w/ crew and third party contractors on Rih w/ 4 1/2 Com fetion. MU Guardian ua e. 0730 11:30 4.00 96 1;877 COMPZ RPCOti RCST P RIH with 4-4/2 completion with TEC wire. 11:30 1230 9.00 1,877 1,877 COMPZ RPCOh PULD P Crew change, PJSM. Rig up equipment to start running heaf trace cable. 12:30 00:00 11.50 1,877 4,418 COMPZ RPCOti RCST P RIH with 4-1/2' gaslift compietion with TEC wire and heat trace cabie. 04/15/2008 00:00 02:30 2.50 4,418 4,924 COMPZ RPCOti RCST P Continue to Rih f/ 4,418' to 4,924' w/ 4 1/2 Gas Lift Completion. Tag w/ 24.5' in on 't 157. 82k u wt 74k dn wt 0230 03:00 0.50 4,924 4,924 COMPZ RPCO DHEQ P Fiil IA w/ 10 bbis. PT to 5Q0 psi for 5. minutes. Bleed off. 03:00 03:30 0.50 4,924 4,841 COMPZ RPCOh HOSO P Pooh and lay downjts - 157,156,155. 03:30 04:30 1.00 4,841 4,898 COMPZ RPCOti HOSO P Rih w/ 3 pup jts = 25' and 1 jt w/ han er. 04:30 09:30 5.00 4,898 COMPZ RPCOh OTHR P Make Final spice w/ heat trace and I tec wire. Test heat trace - good. Trouble shoot I tec wire - connection roblems. Test ood. 09:30 10:30 1.00 COMPZ RPCOh CIRC P Reverse circulate w/ 130 bbls of 6% KCL w/ 1% b VoL CRW-132 10:30 11:00 0.50 4,922 COMPZ RPCOh HOSO P Drain stack and land hanger. RILDS. w/ 3.875" DB Nipple @ 503', GLM #1 @ 2,572' to 2,579', Heat trace starting @ 3,046', GLM #2 @ 4,320 to 4,327', 3.812" ID Sliding Sleeve @ 4,832', Guardian Gauge @ 4,842', Bottom of seais @ 4,922', ZXP Pkr @ 4,885' to 4,904', SBE @ 4,904' to 4,924', 3.75" DB Nippte @ 4,959', Bottom of non locating seals @ 5,137' placed in B Lateral SBE @ 5,123' to 5,143'. Ran 10 - SS Bands, 478 - 5' Clamps, 3- 2' Clamps, 2- 3' Clamps, 1- End Shoe and 60 X- Cou lin Clam s. 11:00 12:30 1.50 COMPZ RPCOh DHEQ P PT IA to 1,000 psi for 30 min. and Chart. PT Upper/Lower tbg hanger void @ 5,000 psi for 10 minutes. Attempt to shear SOV @ 4,316' @ 2,000 psi - no shear - Pressure to 3,500 si - no shear. 12:30 14:00 1.50 COMPZ RPCOh WOEL T Wait for HES slickline unit to RD off of 1J Pad well and move to 1J-166. 14:00 15:00 1.00 COMPZ RPCOh SFTY T Held PJSM w/ crew and RU Slickline. I ~ • . ~ ~ ~l ~. DATA SUBMITTAL COMPLIANCE REPORT 5/12/2008 Permit to Drill 2052000 Well Name/No. KUPARUK RIV U WSAK 1J-166L2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23291-61-00 MD 12994 TVD 3531 Completion Date 2/11/2006 __ _ _ __ Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Surve Ye DATA INFORMATION Types Electric or Other Logs Run: Gr/Res, Dens/Neu (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log! Electr Data Digital Dataset Log Log Run Interval OH / T y pe Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~~ FF ,,~~ D Asc V"" _ - _ _ _ - - - -- - - - - --- --- - --- - Directional Survey ---- ----- ------ --- 28 --- 12994 -- Open - - 4/17/2006 -- -- `ED Asc Directional Survey 28 8359 Open 4/17/2006 PB 1i pt 13877L,LIS Verification 2331 13936 Open 5/19/2006 Y 6 ' .[ D Lis 13877 Induction/Resistivity 2331 12936 Open 5/19/2006 GR, EWR4, ABI, ROP, PWD, Geoplot ~ ED C Li ~ 13876 i d ti /R i i i s / n uc on v es st ty 2331 8301 Open 5/19/2006 PB1, ROP, FET, GR, Res CAD C Lis 16076vtnduction/Resistivity 2331 12994 Open 4/2/2008 LIS Veri, GR, FET, RPM, RPX, RPD, RPS, ROP QED C Lis 16076 induction/Resistivity 2331 8359 Open 4/2/2008 P61 LIS Veri, GR, FET, RPM, RPX, RPD, RPS, i ROP Lpg Induction/Resistivity 25 Col 219 12994 Open 4/2/2008 MD ROP, DGR, EWR 5- ~~ ~ I ti /R i d i Feb-2006 g n uc on es st vity 25 Col 219 3530 Open 4/2/2008 TVD ROP, DGR, EWR 5- Feb-2006 og Induction/Resistivity 25 Col 219 8359 Open 4/2/2008 P61 MD ROP, DGR, EWR !. 1-Feb-2006 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comme nts DATA SUBMITTAL COMPLIANCE REPORT 5/12/2008 Permit to Drill 2052000 Well Name/No. KUPARUK RIV U WSAK 1J-166L2 Operator CONOCOPHILLIPS ALASKA INC MD 12994 TVD 3531 Completion Date 2/11/2006 Completion Status 1-OIL Current Status 1-OIL ADDITIONAL INFORMATION Well Cored? Y / N Daily History Received? Y / N Chi sR ~ d~ Y/N F Y/N p eceive ormation Tops Analysis Y / N Received? __ Comments: Compliance Reviewed By __ _ _ ~ __ ___ Date: API No. 50-029-23291-61-00 UIC N ._ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 March 21, 2008 RE: MWD Formation Evaluation Logs 1J-166+L1+L1PB1+L2+L2PB1 AK-MW-4149018 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 J-166+L 1+L 1 PB 1+L2+L2PB 1: 2" x 5" MD Resistivity & Gamma Ray Logs: 1 Color Log 50-029-23291-00,60,61,70,71 2" x 5" TVD Resistivity & Gamma Ray Logs: 1 Color Log 50-029-23291-00,60,61 Digital Log Images 1 CD Rom 50-029-23291-00,60,61,70,71 Some sections of this well have no TVD. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services c905 /9~j '~ /w~~/ Attn: Rob Kalish ~}~j~,-~q~ ~ a (~b ~Sf 6900 Arctic Blvd. Alaska 99S 1,8 ~D~ ~~ ~ ~ ~d~~ Anchorage, ~ Date: Signed: 1\I'i~ ~3 ~ lUL!sS 9Zi Elii, ~. ~ { ~~~ ~ ,:i::i i ~~~ it;, 1J~/ I (1{~~iti~~~iSi ~~s y To: State of Alaska WELL LOG TRANSMITTAL Alaska Oil and Gas Conservation Co. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-166 L2 PB1, May 3, 2006 AK-MW-4149018 1 LDWG formatted Disc with verification listing. API# : 50-029-23291-71 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: - o~ Signed: o2.c1c1 ~ ~s ~~" To: State of Alaska Alaska Oil and Gas Conservation Co. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-166 L2, WELL LOG TRANSMITTAL May 3, 2006 AK-MW-4149018 1 LDWG formatted Disc with verification listing. API#: 50-029-23291-61 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETIJI2NING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ,.; Signed: .--- - .- 02-Apr-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 J-166 L2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 7,618.38' MD Window /Kickoff Survey: 10,609.85' MD (if applicable) Projected Survey: 10,702.88' 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 r Date ~ ~.~ ~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~,~9 -~,0® ~~rl.. 02-Apr-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1J-166 L2 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. a ~ - ~ 3s~ Tie-on Survey: 4,976.26' MD Window /Kickoff Survey: 8,275.46' MD (if applicable) Projected Survey: 8,359.00' 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 ,t® Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment{s) ~ ~ j .~ z~® ~~~~ ConocoPhillips April 7, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 ~~~ Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 Subject: Well Completion Reports for 1 J-166, 1 J-166L1 and 1 J-166L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk well 1 J-166, 1 J-166L1 and 1 J-166L2. If you have any questions regarding this matter, please contact me at 265-6830 or Mike Greener at 263-4820. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad '.~„„, STATE OF ALASKA .,,,,,,,.~' ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ ~ a zoos WELL COMPLETION OR RECOMPLETION REPOI~~~l~a Commission 1a. Well Status: Oil ^/ Gas Plugged Abandoned Suspended ~ WAG ~ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well class: AnC~IOPag@ Development ~ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: February 11, 2006 12. Permit to Dritl Number: 205-200 / ` 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: 3O '~ Janua , 2006 ~• ~v`n 13. API Number: 50-029-23291-61 - 4a. Location of Well (Governmental Section): Surface: 1880' FSL, 2508' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: February 5, 2006 ' 14. Well Name and Number: 1J-166L2 At Top Productive Horizon: 1942' FNL, 773' FWL, Sec. 35, T11 N, R10E, UM 8. KB Elevation (ft): 2g' RKg 15. FieldlPool(s): Kuparuk River Field Total Depth: 721' FSL, 998' FWL, Sec. 23, T11 N, R10E, UM 9. Plug Back Depth (MD + ND): 12949' MD / 3528' ND West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558703 , y- 5945692 ' Zone- 4 10. Total Depth (MD + ND): °' 12994' MD ! 3531' TVD ~ 16. Property Designation: ADL 25661 & 25650 TPI: x- 556691 y- 5947134 Zone- 4 Total Depth: x- 556846 - 5955077 ~ Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 471 & 468 18. Directional Survey: Yes ~ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 2368' MD 21. Logs Run: ^-T-/(,v ~ ~ SQ[,>~ ~1~f~y~ ,} /~ ~?Y~ GR/Res, DenslNeu 1j yr• /n_ nL 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE MENTIN RECORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CE G PULLED 20" x 34" 62.58# H-40 28' 108' 28' 108' 42" 367 sx AS 1 10.75" 45.5# L-80 28' 2368' 28' 2194' 13.5" 460 sx Class G, 166 sx LiteCRETE 7-5/8" 29.7# L-80 28' 6356' 28' 3650' 9-7/8" 470 sx LiteCRETE 4.5" 12.6# L-80 5000' 12951' 3414' 3530' 6.75" slotted liner 23. Pertorations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore 4085' 5480' slotted liner from 5065'-7803', 8019'-8323', 8569'-9804', 10515'-12918' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n!a 2g, PRODUCTION TEST Date First Production March 26, 2006 Method of Operation (Flowing, gas lift, etc.) Gas Lift Oil -shares production with 1 J-166 and 1 J-166L1 Date of Test 4/5/2006 Hours Tested 14 hours Production for Test Period --> OIL-BBL 2425 GAS-MCF 3054 WATER-BBL 0 CHOKE SIZE 21 % GAS-OIL RATIO 1303 Flow Tubing press. 52o psi Casing Pressure 1009 Calculated 24-Hour Rate -> OIL-BBL 4104 ' GAS-MCF 5347 WATER-BBL 1 OIL GRAVITY -API (corr) 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". ~~., ~~~ ~ ~ zoos NONE 4 rat ~~ ~~? :. is i..:~~f i ~.~. i s 1 __._. ._ -~-..__... ~; Form 10-407 Revised 12/2003 CONTINUED ON REVERSE p~ ~~ • ~ 6 ~,J 11~ ,~ ~ 1 1 ~ ~~tit ~. X111 ~v ~/<d~(7l Y ~' ` 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 J-166L2 Top West Sak D Sand 5020' 3418' Base West Sak D sand 12994' 3530' N/A 1 J-166L2PB 1 TD 8359' 3455' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed Nan~_~__ Rand Thomas. Title: Greater Kuparuk Area Drilling Team Leader ~ ~r l ~ laG "7 Signature t ~`--~---~'`~~"c'k"'--.e Z~, ~j` ~, E, ~ ~v Date INSTRUCTIONS rrepareo ay ~naron Hnsup-urar<e 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 ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-166 Common Well Name: 1 J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date '~~ From - To Hours Cods: Sub Phase j Code 1 /7/2006 12:00 - 14:15 ~ 2.25 ~ MOVE I MOVE I MOVE 16:15 - 20:15 I 4.00 MOVE POSN MOVE 1 /8/2006 1 /9/2006 20:15 - 00:00 3.751 MOVE I MOB I MOVE 00:00 - 02:45 2.75 WELCT NUND RIGUP 02:45 - 07:00 4.25 DRILL PULD RIGUP 07:00 - 07:30 I 0.501 WELCTu BOPE I RIGUP 08:00 - 09:00 10.001 DRILL PULD SURFAC 09:00 - 09:30 0.50 DRILL OTHR SURFAC 09:30 - 09:45 0.25 DRILL DRLG SURFAC 09:45 - 12:00 2.25 DRILL DRLG SURFAC 12:00 - 13:00 1.001 DRILL ~ DRLG I SURFAC 13:00 - 13:30 0.50 DRILL TRIP SURFAC 13:30 - 15:30 2.00 DRILL PULD SURFAC 15:30 - 16:15 I 0.751 DRILL I DRLG I SURFAC 16:15 - 19:45 3.501 RIGMNTI RGRP I SURFAC 19:45 - 00:00 I 4.251 DRILL I DRLG I SURFAC 00:00 - 08:15 I 8.251 DRILL I DRLG I SURFAC Start: 1 /7/2006 Rig Release: 2!11/2006 Rig Number: Page 1 of 25 Spud Date: 1/8/2006 End: 2/11!2006 Group: Description of Operations PJSM with crew & Peak Truck drivers. Discuss Safety issues and procedure for rig move. Move Pipeshed modules, Rockwasher, Boilers, Motors and Pit Modules to other side of Pad. Move Sub base from 1J-101 to spot over well 1J-166. Spot Pipeshed modules, Rockwasher, Boilers, Motors and Pit Modules to Rig sub base. Prepare rig for Acceptance. Install all water, steam, hydraulic and air lines. Continue work on Rig Acceptance checklist. Spot pipe shed tioga, berm & trim herculite liner on rockwasher. Apply steam, glycol & air to lines. Set up pipe skate. Rig up mud pump lines, and install all drain plugs in centifugal pumps. Rig Accepted @ 0000 HRS.1/8/2006 Nipple up Diverter system, & Riser. Continue Load pits with water & mix spud mud. Load pipe shed with 5" DP, and HWDP. Strap same. PJSM with crew. Discuss aSafety issues & procedure to PU 5" Drill Pipe. Pick up 29 joints of 5" HWDP and Drilling Jars, Rack back in derrick. Pick up 45 Joints of 5" DP, and rack back in derrick. Pick up 1 stand of 8" Non Mag flex drill Collars. Pick up 1 stand of 5" DP. Perform Diverter Function test. AOGCC rep Chuck Sheave waived the witness of Diverter Fuction Test. No leaks. Pull all tools to rig floor for BHA #1. Held PJSM. Make up BHA. Make up 13 1/2" Hughes MXC1 bit w/ 3 x 20's & 1 x 13 Jets (1,0'), 8" SperryDrill Lobe 4/5 -5.3 Stage Motor (28.71'), 8" Integral Blade stabilizer (5.57'), and a Bottle neck Crossover sub (2.68'). Make up 1 stand of 5" HWDP. 6 1/4" Jar Hrs to start = 87.10 .Flood Conductor and fill all lines. Inspect for leaks. Test mud line to 3000 PSI. Observed NO leaks. Begin drilling ICE from 85' to 108'. Spud well and drill from 108' - 151' (43'). ART = 1.57 HRS. PU WT = 50K, SO WT = 50K, ROT WT = 46K JAR HRS Total = 88.67. Bit HRS Total = 1.57. Continue drill from 151' - 215' MD'(68'). TVD = 219' ART = 1.29 HRS. PU WT = 44K, SO WT = 48K, ROT WT = 46K. Torque = 1 K. Pump out of hole from 219' - 32' (187'). 100 SPM - 424 GPM - 350 PSI. Hang off Sheave & line in derrick for GYRO. RU GYRO E-Line unit. Continue make up BHA. Make up 8" Non-mag Crossover sub (1.65'), 8" Non-Mag Pressure drop sub (1.63'), 8" MPT w/ DIR (25.06'), 8" NON-Mag float sub (2.42'), 8" Non-Mag UBHO Sub (2.94'), 3 - Non-Mag Flex Drill Collars (92.77'), and 5" HWDP back to 215'. Orient MWD & UBHO Sub. Continue Drilling 13 1/2" Surface hole from 215' - 252'.(37'). ADT =.67 HRS. TVD = 252'. PU WT = 44K, SO WT = 48K, ROT WT = 46K, with torque at 1 K. Observe failed Saver SUb on Top Drive. POOH from 252' - 32' (220'). Blow down all lines, and Top Drive. Change out & inspect top drive saver sub. Observed Spacing on pipe grabber, grabbing in wrong position and damaging saver sub & top 2 joints on 5" HWDP stands. Breakout & lay down top 2 joints. Replace same. Correct the Pipe Tally. Trip back in hole and continue driling from 252' - 528' (276'). ADT = 5.03 HRS. PU WT = 58K, SO WT = 66K, ROT WT = 64K. Torque on Bottom = 1.5K, Torque off bottom = 1 K. Total Jar Hrs = 93.70. Total Bit Hrs = 6.60. Pumps @ #1 - #2, 66 SPM each @ 560 GPM's, 550 PSI. Continue driling from 528' - 1087' (559'). Run GYRO survey after each Printed: 2/13!2006 12:29:18 PM ~. ConocoPhillips Alaska Page 2 of 25 Operations Summary Report Legal Well Name: 1 J-166 'Common W ell Name: 1 J-166 Event Nam e: ROT -D RILLIN G Contractor Name: n1334@ ppco.co m Rig Name: Doyon 1 41 Date ~I From - To Hours Code ~, Sub ,Code Phase 1/9/2006 00:00 - 08:15 8.25 DRILL DRLG SURFAC 08:15 - 09:00 0.75 RIGMNT RGRP SURFAC 09:00 - 12:00 3.00 DRILL DRLG SURFAC 12:00 - 13:15 1.25 DRILL DRLG SURFAC 13:15 - 13:45 0.50 RIGMNT RGRP SURFAC 13:45 - 20:00 6.25 DRILL DRLG SURFAC 20:00 - 00:00 4.00 DRILL CIRC SURFAC 1/10/2006 00:00 - 01:00 1.00 DRILL TRIP SURFAC 01:00 - 01:45 0.75 DRILL PULD SURFAC 01:45 - 02:15 0.50 DRILL PULD SURFAC 02:15 - 03:00 0.75 DRILL PULD SURFAC 03:00 - 03:30 0.50 DRILL PULD SURFAC 03:30 - 05:00 1.50 CASE RURD SURFAC 05:00 - 08:15 3.25 CASE RUNC SURFAC 08:15 - 08:30 0.25 CASE RUNC SURFAC Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/1112006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations stand to confirm Close Approach issues. ADT = 6.14, ART = 3.58 HRS, AST = 2.66 HRS. PU WT = 85K, SO WT = 91 K, ROT WT = 90K. Torque on Bottom = 2-4K, Torque off bottom = 1 K. Pumps @ 132 SPM - 1900 PSI, 560 GPM's. Mud WT = 9.1 PPG, Visc @ 250-300, YP = 42 MAX Gas = 23 BTU. WOB = 10-38K. Release GYRO Hand & E-Line unit @ 0630 HRS. Good MWD Surveys. Repair Conveyor Belts in pits. Adjust Linkage. Continue driling from 1087' - 1343' (256'). ADT = 1.99, ART = .5 HRS, AST = 1.49 HRS. PU WT = 90K, SO WT = 94K, ROT WT = 94K. Torque on Bottom = 4-5K, Torque off bottom = 2-3K. Total Jar Hrs = 100.22. Total Bit Hrs = 13.14. Pumps @ 156 SPM - 1980 PSI, 560 GPM's. Mud WT = 9.1 PPG, Visc @ 250-300, YP = 42 MAX Gas = 23 BTU. WOB = 10-38K. Continue driling from 1343' - 1517' (174'). 1474'. TVD. ADT =.1.07, ART _ .40 HRS, AST = .43 HRS. PU WT = 95K, SO WT =. 94K, ROT WT = 96K. Torque on Bottom = 4-5K, Torque off bottom = 2-3K. Pumps @ 156 SPM - 1980 PSI, 560 GPM's. Mud WT = 9.1 PPG, Visc @ 250-300, YP = 42 MAX Gas = 86 BTU. WOB = 10-38K. Pull back to 1453'. Reciprocate & rotate drill string while work on drag ~ chain in pits. Replace motor. Continue driling from 1517' - 2378' MD (861'). 2201.9' TVD. ADT = 4.78, ART = 2.79 HRS, AST = 2.23 HRS. PU WT = 110K, SO WT = 96K, ROT WT = 105K. Torque on Bottom = 4-5K, Torque off bottom = 3-4K. Observed Hydrates up to 3000 BTU's @ 2035' MD. Total Jar Hrs = 106.07. Total Bit Hrs = 18.99. Pumps @ 1980 PSI, 640 GPM's. Mud WT = 9.3 PPG, Visc @ 250-275, YP = 38. WOB = 5-25K. Last survey @ 2378' MD, 2201.9 TVD, 35 Deg INC, 266.73 Deg AZ. Circulate bottoms up 3 times @ 176 SPM - 750 GPM's, 2500 PSI. RPM's = 70 with 4K torque. BROOH from 2378' - 1077' (1301') at drilling rate. Pull to HWDP and lay down 13 1/2" Ghost Reamer. Continue POOH, pumping at a lower rate of 600 GPM's and observe hole unloading and continued to clean up each stand. Pull from 1071' - 104' (967'). PUWT = 85K, SO WT = 84K, 120 SPM- 600 GPM's - 1950 PSI. Breakout & Lay down 3 joints of Non Mag Drill Collars (92.77'), UBHO sub (2.94'), and 8" Float sub (2.42'). Plug in and download MWD assembly. Continue breakout & lay down remaining BHA. Lay down 13 1/2" Hughes MXC1 bit w/ 3 x 20's & 1 x 13 Jets (1.0'), 8" SperryDrill Lobe 4/5 -5.3 Stage Motor (28.71'), 8" Integral Blade stabilizer (5.57'), 8" Non-mag Crossover sub (1.65'), 8" Non-Mag Pressure drop sub (1.63'), 8" MPT w/ DIR (25.06'), Inspect & Gauge 13 1/2" bit to 2 / 2 / BT /ALL / E/I/WT/TD. Clean & Clear rig floor area. Send tools outside. PJSM with crew. Discuss Safety issues and procedure for rigging up casing equipment, and running casing. Rig up all equipment to run 10 3/4" surface casing string. Make up shoe joint, and Float Collar joints. Check floats. OK. Continue RIH picking up 58 total joints of 10 3/4" casing installing Bowspring centralizers as per detail to 2348'. Make up torque = 10,000 FT /LBs. Observe hole taking proper hole fill and no issues in OH. Total centralizers run = 21. Total Stop Collars =3. Make up 10 3/4" x 18 1/8" Vetco Gray casing hanger and landing joint rnrneu: u,oi<uvo ic.ca. io nvi ~~-- C011000PhIIIIpS Alaska Page 3 of 25 Operations Summary Report Legal Well Name: 1 J-166 Common W ell Name: 1J-166 Spud Date: 1/8/2006 Event Nam e: ROT -D RILLIN G .Start: 1/7/2006 End: 2/11/2006 Contractor Name: n1334@ ppco.co m Rig Release: 2/11/2006 Group: Rig Name: Doyon 1 41 Rig Number: Date ~ From = To Hours Code .Sub '~~ Code Phase ~~ Description of Operations ~ , 1/10/2006 08:15 - 08:30 0.25 CASE RUNC SURFAC as per Vetco Gray rep. RIH, land casing in hanger, verifying good set. RKB = 30.11' 08:30 - 09:15 0.75 CASE CIRC SURFAC Circulate 1 bottoms up with Franks fill up tool while recirocating casing 20'. UP WT = 127K, SO WT = 97K, @ 6 BPM - 350 PSI. 09:15 - 09:45 0.50 CEMEN RURD SURFAC Breakout & lay down Franks fill up tool. Load plugs into Cement Head. Make up crossover and Cement head & all lines. 09:45 - 11:30 1.75 CEMEN CIRC SURFAC Continue Circulate & condition mud. Pre job properties - 9.6 PPG, Viscosity = 225, PV = 41, YP = 62, Gels @ 17 / 32. Properties of mud for cement job = 9.2 PPG, Viscosity = 42, PV = 15, YP = 7, Gels @ 2 / 3. Circulating @ 6 BPM - 350 PSI. Total Circulation time = 3.0 HRS. 11:30 - 12:00 0.50 CEMEN PUMP SURFAC Held PJSM with crew & Dowell. Designate a spill champion. With Dowell, pump 10 BBLS of CW 100. Pressure test lines to 3500 PSI. . Good. test. 12:00 - 14:15 2.25 CEMEN PUMP SURFAC Continue pumped an additional 40 bbls of CW 100 (50 bbls total), Followed by 50 bbls of 10.5 ppg mudpush w/ red dye, dropped btm plug, began mixing and pumping Arcticset lead slurry, Pumped 376.0 bbls (460 sxs) of lead cement at 10.7 ppg and 4.45 yield with additives, ave 6.6 bpm at 275 psi, Followed with 75 bbls (175 sxs) of DeepCrete tail cmt at 12.0 ppg and 2.47 yield with add., ave 4.8 bpm at 230 psi, shut down and dropped top plug, Kick plug out with 20 bbls fresh water, Reciprocated casing 10' to 15' until 150 bbls cement around shoe then pipe became tight and landed on hanger, Up 135K, Dn 80K..Turn over to rig and displace cement w/ 220 bbls (Total 199 bbls to bump) of 9.2 ppg mud, Displaced cement at 7.0 bpm, Initial pump pressure 280 psi, max pressure at 7.0 bpm 320 psi, Observed red dye at shakers after pumping 135 bbls mud, Slowed rate down to 3 bpm @ 280 psi 10 bbls prior to bumping plug, Bumped plug w/ 1200 psi, Held 10 min, Check floats- OK, CIP @ 14:00 hrs 1/10/2006, Had full returns through out job with 63 bbls 10.7 ppg cement to surface, Shoe @ 2,368.38', TVD = 2193.66. Float collar @ 2,282.73'. Test Float Equipment. Floats held. 14:15 - 16:30 2.25 CEMEN RURD SURFAC Flush Stack & Lines. Rig down Cement head & lines. Back out & lay down Landing joint. 16:30 - 18:30 2.00 WELCT NUND SURFAC Nipple down Diverter stack and Riser. Lay down XO for Diverter & Conductor. Lay down Knife Valve. Position all equipment in rear of cellar for crane pick & removal. Pull all Diverter stack equipment from rear of cellar using crane. Move & Set wellhead equipment in cellar. 18:30 - 20:45 2.25 WELCT NUND SURFAC Nipple up Multi-bowl wellhead as per Vetco Gray rep. Test same to 5000 PSI - 10 minutes. 20:45 - 23:30 2.75 WELCT NUND SURFAC Nipple up BOP stack & all lines. Change out saver sub on Top Drive, from 4 1/2 IF to 4" XT39, grabbers and bell guide. 23:30 - 00:00 0.50 WELCT BOPE SURFAC PJSM, Discuss safety issues and procedures. Rig up equipment to test BOP's. 1/11/2006 00:00 - 06:15 6.25 WELCT BOPE SURFAC PJSM - Dicuss testing BOP's & Safety Issues. Perform BOP test. Test 7 5/8" Lower rams, & Annular with 7 5/8" test joint. Test 6"x 3 1/2" VBR's in top set, and Annular with 5" test joint. Continue test 5" Dart Valve, Floor Valve, 4" Floor & Dart valves, and 3 1/2" x 6" VBR's with 4" test joint. Test HCR & Choke, and manual valves. Test Choke manifold valves #1, #12, #13, #14. Upper IBOP, Choke Manifold valves # 9, #11. Test Lower IBOP & choke manifold valves # 5, #8, #10. All test to 250 PSI -low, 3500 PSI High. AOGCC rep, Lou Grimaldi waived witness of test at 2000 HRS, 1/10/2006. Test Dart & Floor valve for 4" DP, Choke ninieu: uioicwo i .io na `° ConocoPhillips Alaska Page 4 of 25 Operations Summary Report Legal Well Name: 1 J-166 Common Well Name: 1J-166 Spud Date: 1/8/2006 Event Name: ROT -DRILLING Start: 1/7/2006 End: 2/11/2006 Contractor Name: n1334@ppco.com Rig Release: 2/11/2006 Group: Rig Name: Doyon 141 Rig Number: Date I From - To Hours Code Sub Code Phase I 1/11/2006 00:00 - 06:15 6.251 WELCTI~ BOPE ~ SURFAC 06:15 - 07:00 0.75 WELCT BOPE SURFAC 07:00 - 07:45 0.75 DRILL PULD SURFAC 07:45 - 09:45 2.00 DRILL PULD SURFAC 09:45 - 10:45 1.00 DRILL PULD SURFAC 10:45 - 12:00 1.25 DRILL PULD SURFAC 12:00 - 16:00 4.00 DRILL PULD SURFAC 16:00 - 18:15 18:15 - 19:15 19:15 - 20:30 20:30 - 21:00 21:00 - 22:00 22:00 - 23:15 23:15 - 00:00 1 /12/2006 00:00 - 00:30 2.251 DRILL (PULD (SURFAC 1.00 DRILL PULD SURFAC 1.25 DRILL TRIP SURFAC 0.50 DRILL CIRC SURFAC 1.00 CASE DEQT SURFAC 1.25 CEMEN DSHO SURFAC 0.75 DRILL CIRC SURFAC 0.50 DRILL LOT SURFAC 00:30 - 12:00 I 11.501 DRILL DRLG I INTRM1 Description of Operations manifold valves # 4, #8, #7 & #2. Test HCR's Choke & Manual valves, Annular. Perform Koomey test. System Pressure = 3000 PSI, Pressure after close = 1900 PSI. First 200 PSI attained in 42 secs, and full pressure attained in 3 min. AVG pressure in Nitrogen bottles = 2200 PSI. Test Blind rams, Choke manifold valves #3, & #4. Install Wear bushing. RILDS. PJSM with crew. Discuss pick up procedure & safety issues. Rig up Short bales on Top Drive, hang elevators. Pick up 63 jnts of 4" XT39 Slick Drill pipe running in hole to 2000'. POOH, rack back 21 stands n Derrick. Pick up 23 joints of 4" XT39 Slick Drill pipe running in hole to 731'. Continue pick up 40 more joint of 4" XT39 Slick DP to 2000'. 63 joints total. POOH rack back 21 stands in derrick for a total of 42 stands of Slick 4" DP. RIH with 21 joints of 4" HWDP, and POOH racking back 7 stands. PJSM. discuss safety issues and procedure to MU BHA. Make up BHA #2. 9 7/8" Hughes MX-CX1 bit with 3 x 20, 1 x 12 jets (1.0') TFA = 1.031 SQ. IN., 7" Sperry Drill Lobe 7/8 - 6.0 stage (25.35'), 6 3/4" Float sub (2.49'), 6 3/4" Integral Blade Stabilizer (5.61'), 6 3/4" DM Collar (9.02'), 6 3/4" Gamma/Res/PWD (28.08'), 6 3/4" TM Collar (9.83'). Plug in and Up load MWD assembly. Continue MU 3 - 6 1!2" NonMAg Flex Drill Collars (93.09'), 4 - 5" HWDP (121.72'), 6 1/4" Drilling Jars w/ 106.09 HRS (30.78'), 10 - 5" HWDP (306.69'). Total BHA = 633.66' NOTE: Install Corrosion Ring in top joint of 5" HWDP Serial #19936 RIH from Derrick with 5 stands of 5" HWDP. -POOH, breakout & lay .down 15 joints of 5" HWDP not needed for this assembly. Trip in hole with 3 stands of 5" Slick DP, Make up 9 7/8" Ghost Reamer (5.08'), and 12 more stands of 5" DP. Crossover to 4" Dp and RIH with 4" DP to 2216'. Perform Shallow pulse test on MWD assembly. Good Test @ 115 SPM -487 GPM -1250 PSI. Continue TIH to tag firm Cement @ 2275' DPM. Circulate & condition mud at 115 SPM - 487 GPM"s - 1250 PSI. PU WT = 100k, SO WT = 82K, ROT WT = 90K. Torque @ 3.5K. Pull 1 stand back to 2211'. Mud wt = 9.0 PPG. Rig up and flush lines to ensure no air in lines. Test 10 3/4" Casing to 3000 PSI for 30 Minutes. Record on chart. Good test. Bleed & blow down lines. RD test equipment. RIH with 1 stand, MU Top Drive & drill cement & float equipment from 2275' - 2400' (22' of new hole). FC @ 2284', & FS @ 2368'. ADT = .23 HRS. PU WT = 100k, SO WT = 82K, ROT WT = 90K. Torque = 4K on bottom, 3.5K off bottom. Mud wt = 9.0 PPG, WOB = 3-10K, Pumps at 107 SPM - 454 GPM - 1100 PSI. Displace well with 9.0 PPG conditioned mud @ 107 SPM - 454 GPM's - 1100 PSI, checking mud properties until same in & out for LOT test. Mud wt = 9.0 PPG, 10 sec Gels = 17. Rig up & perform LOT to 15.3 PPG EMW. Mud wt = 9.0 PPG, 10 sec Gels = 17. Observe pressure breakover @ 724 PSI @ 3 BBLS pumped. 10 Minute shut in, pressure bled from 650 psi - 480 PSI. SHoe depth = 2368' MD, 2193' TVD. Directional drill 9 7/8" Intermediate hole from 2400' - 3895' (1495') MD. TVD = 3057'. ADT = 7.79 HRS, ART = 3.76 HRS, AST = 4.03 HRS. PU WT = 112K, SO WT = 80K, ROT WT = 90K. Torque on btm = 4-7K, Off bottom = 3-tiK. Pumps - 600 GPM's - 2075 PSI. RPM's = 80. WOB = rnnteu: u ioi<ooo i<.<a. io nvi ~~ ConocoPhillips Alaska Page 5 of 25 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ~ From - To 1 /12!2006 ~ 00:30 - 12:00 1 J-166 1 J-166 ROT -DRILLING n1334@ppco.com Doyon141 Hours Code Sub Phase Code 11.501 DRILL I DRLG I INTRM1 12:00 - 00:00 ~ 12.00 ~ DRILL ~ DRLG ~ INTRM1 ~ 1!1312006 ~ 00:00 - 12:00 ~ 12.00 ~ DRILL ~ DRLG ~ INTRM1 12:00 - 13:45 ~ 1.75 ~ DRILL ~ DRLG ~ INTRMI 13:45 - 14:45 1.00 DRILL CIRC INTRM1 14:45 - 17:15 2.50 DRILL WIPR INTRMI 17:15- 19:30 I 2.251 DRILL STRIP IINTRM1 19:30 - 22:00 ~ 2:50 ~ DRILL ~ TRIP ~ INTRM1 22:00 - 22:15 0.25 DRILL PULD INTRM1 22:15 - 23:00 0.75 DRILL PULD INTRMI 23:00 - 00:00 1.00 DRILL PULD INTRM1 Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations 5-30K. Total Bit HRS = 8.02 HRS. Total Jar HRS = 114.11 Mud Wt = 9.0 PPG, Visc = 75,YP = 27, Gels @ 12 / 21. Max gas units = 49 BTU's, ECD =10.14 PPG. Survey @ 3668' MD, 2970 TVD, INC = 67.15 Deg, AZ = 317.80 Deg. Obtain SPR's at 3709' MD, 2984' TVD Pump #1 , 25 SPM -240 PSI, 35 SPM - 300 PSI. Pump #2, 25 SPM -250 PSI, 35 SPM - 320 PSI. Continue Directional drill 9 7/8" Intermediate hole from 3895' - 5125' (1230') MD. TVD = 3440'. ADT = 8.35 HRS, ART = 3.28 HRS, AST = 5.7 HRS. PU WT = 115K, SO WT = 76K, ROT WT = 90K. Torque on btm = 5-7K, Off bottom = 5-7K. Pumps - 615 GPM's - 2400 PSI. RPM's = 75. WOB = 15-35K. Total Bit HRS = 16.37 HRS. Total Jar HRS = 122.46 Mud Wt = 9.1 PPG, Visc = 59,YP = 29, Gels @ 14 / 22. Max gas units = 105 BTU's, ECD =10.33 PPG. Survey @ 5067' MD, 3428 TVD, INC = 28.03 Deg, AZ = 1.76 Deg. Obtain SPR's at 4736' MD, 3352' TVD Pump #1 , 25 SPM -270 PSI, 35 SPM - 350 PSI. Pump #2, 25 SPM -270 PSI, 35 SPM - 340 PSI. Pump Hi Visc weighted sweep @ 3895' MD, & 5000' MD observing 20% increase in cuttings at shakers. Continue Directional drill 9 7/8" Intermediate hole from 5125' - 6195' (1070') MD. TVD = 3627'. ADT = 8.29 HRS, ART = 6.95 HRS, AST = 1.34 HRS. PU WT = 123K, SO WT = 73K, ROT WT = 88K. Torque on btm = 7-8K, Off bottom = 5-8K. Pumps - 600 GPM's - 2500 PSI. RPM's = 85. WOB = 10-25K. Total Bit HRS = 24.49 HRS. Total Jar HRS = 130.75 Mud Wt = 9.2 PPG, Visc = 54,YP = 25, Gels @ 12 / 25. Max gas -units = 189 BTU's, ECD =10.38 PPG. Survey @ 6153' MD, 3621 TVD, INC = 81.48 Deg, AZ = 2.28 Deg. Obtain SPR's at 5764' MD, 3559' TVD Pump #1 , 25 SPM -270 PSI, 35 SPM - 350 PSI. Pump #2, 25 SPM -260 PSI, 35 SPM - 340 PSI. Continue Directional drill 9 7/8" Intermediate hole from 6195' - 6355' (160') MD. TVD = 3650'. ART = 1.13 HRS. PU WT = 125K, SO WT = 76K, ROT WT = 90K. Torque on btm = 7-8K, Off bottom = 5-6K. Pumps - 600 GPM's - 2550 PS1. RPM's = 80. WOB = 10-25K. Total Bit HRS = 25.33 HRS. Total Jar HRS = 131.88 Mud Wt = 9.25 PPG, Visc = 54,YP = 26, Gels @ 121 17. Max gas units = 206 BTU's, ECD =10.50 PPG. Survey @ 6312' MD, 3644 TVD, INC = 82.47 Deg, AZ = .45 Deg. Obtain SPR's at 5764' MD, 3559' TVD Pump #1 , 25 SPM -270 PSI, 35 SPM - 350 PSI. Pump #2, 25 SPM -260 PSI, 35 SPM - 340 PSI. Pump Weighted Hi Visc sweep @ 6280'. Observe 5% increase in cuttings at shakers. Circulate bottoms up 3 times @ 600 GPM -2550 PSI. Reciprocate & rotate drill string. BROOH from 6355' - 4739' (1616'). Pull last 2 stands @ 10' /minute as to get another bottoms up and clean hole. Observed hole taking proper displacement. Monitor well -static. Continue POOH on elevators 5 more stands,with hole taking proper fill. Mix & pump dry job. Continue POOH on elevators to 2030'. (2709'). Shoe @ 2368' ,Monitor well -static. Change out elevators, & heads in Iron Roughneck. Continue POOH laying down 45 joints of 5" Drill pipe, 24 joints of 5" HWDP, and drilling jars. Breakout & lay down 3 - 8" NonMag Flex Drill Collars. Plug in and download MWD assembly. Pull up to breakout bit, and drain mud motor. Breakout & lay down ~~: ConocoPhillips Alaska Page v of 25 Operations Summary Report Legal Well Name: 1 J-166 Common Well Name: 1J-166 Spud Date: 1/8/2006 Event Name: ROT -DRILLING Start: 1!7/2006 End: 2/11/2006 Contractor Name: n1334@ppco.com Rig Release: 2/11/2006 Group: Rig Name: Doyon 141 Rig Number: ~ From To° Date Hours Code 'Code Phase 1/13/2006 23:00 - 00:00 1.00 DRILL PULD INTRM1 1/14/2006 00:00 - 00:30 0.50 DRILL PULD INTRM1 00:30 - 01:00 0.50 CASE OTHR INTRM1 01:00 - 02:45 1.75 CASE RURD INTRMI 02:45 - 07:30 4.75 CASE RUNC INTRM1 07:30 - 08:00 0.50 CASE CIRC INTRM1 08:00 - 09:15 1.25 CASE RUNC INTRM1 09:15 - 09:45 0.50 CASE RUNC INTRM1 09:45 - 12:00 2.25 CASE RUNC INTRM1 12:00 - 12:45 0.75 CASE RUNC INTRM1 12:45 - 13:30 0.75 CASE CIRC INTRMI 13:30 - 14:00 0.50 CEMEN~PULD INTRMI 14:00 - 15:45 1.75 CEMEN CIRC INTRM1 15:45 - 17:30 1.75 CEMENI~PUMP ~ INTRM1 17:30 - 18:00 I 0.501 CEMENIiPUMP I INTRM1 18:00 - 20:00 ~ 2.00 ~ WELCTu NUND ~ INTRM1 20:00 - 21:00 ~ 1.00 ~ WELCTLJ OTHR ~ INTRMI Description of Operations MWD TM -HOC. Continue breakout & lay down remaining BHA. Inspect & grade bit. Clean & clear floor area, send tools outside. Bit grade = 1 / 2 ! WT ! A / E/ER/TD. BOLDS, pull wear bushing. PJSM with, crew. Discuss safety issues and procedure for rigging up casing equipment. Rig up all 7 5/8" casing equipment. Double check order of casing in shed. Pick up & run 7 5/8" L80 29.7# casing to 2334'. Make up torque = 8K ft/Ibs. Observe casing taking proper fill. At shoe, circulate bottoms up at 5 BPM -300 PSI, through Franks Fill up tool. PU WT = 100K, SO WT = 74K. Monitor well -static. Continue run 7 5/8" casing from 2334' - 3477' (1143'). Continue run 7 5/8"casing, run out of downweight, Circulate @ 4 BPM - 470 PSI, slacking off washing down 2 joints until observing hole cleanning up. Continue run 7 5/8" casing from 3564' - 5779' (2215'). Crew Change Continue run 7 5/8" casing from 5779' - 6355' (576'). Circulate bottoms up with Franks fill up tool @ 6.5 BPM - 600 PSI. PU WT = 170K, SO WT = 87K. Reciprocate casing while circulating ~ approximately 25'. Breakout & lay down Franks fill up tool. Install Crossover and make up cement head with plugs loaded. Continue circulate & condition mud with cement head @ 7 BPM - 850 PSI. PU WT = 170K, SO WT = 87K. Reciprocate casing while circulating approximately 25'. Before conditioned mud = 9.8 PPG, Viscosity = 84, PV = 28, YP = 39, Gels @ 17 / 23. After mud conditioned for cement job .Mud wt = 9.2 PPG, Viscosity = 39, PV =12, Turn Rig over to Dowell lines. Dowell pumped 10 bbls CW 100 at 8.3 ppg at rate of 4.7 bpm @ 230 psi, Pressure tested lines to 3,500 psi, Then pumped 40 add. bbls of CW 100 at rate of 4.5 bpm @ 170 psi, Pumped 50 bbls of MudPush at 11.0 ppg at rate of 4.7 bpm @ 215 psi, Dropped btm plug then pumped 144 bbls, (370 sxs - 25% over caliper) of DeepCrete cmt at 12.5 ppg, 2.25 yield with additives, avg 5.6 bpm at 275 psi, Reciprocated pipe with full returns 15' to 20'. Drop top plug and Dowell kicked top plug out with 10 bbls fresh water, @5 BPM -200 PSI. Rig displaced cement with 8.9 ppg OBM, Bumped plug after pumping 287.5 bbls MOBM (96% pump eff.) 2867 Strokes, avg 6.8 bpm while displacing cmt, Observed lift pressure f/ 500 psi to 800 psi prior to slowing pump rate to 3 bpm, Slowed pump rate to 3 bpm @ 500 psi with 10 bbls left to pump and bumped plug to 1250 psi. CIP at 1730 hrs, 1-14-06. Reciprocated pipe 15' to 20' until MudPUSH at shoe, then recip. 10' until Cmt at shoe, then recip. 10' until last 30 bbls, then recip. 5' until last 10 bbls then stopped pipe, Landed csg with Shoe @ 6350', Float Collar @ 6264', Calc TOC @ 3355', Had full returns thru out job. Well static after shut down. Check Float Equipment. Held, no bleed back. Rig down casing equipment. PJSM with crew. Discuss Safety and procedure to complete 7 5/8" casing run. Nipple down BOP stack and raise. Set 7 5/8" emergency slips as per Vetco Gray rep, with 75K overpull on casing. Suck out all MOBM in 7 5/8" casing down to 40'. Rig up WACHS casing rnn[ea: uiaftuua ic~a: is nvi ConocoPhillips Alaska Page 7 of 25 Operations Summary Report Legal Well Name: 1J-166 Common W ell Name: 1J-166 Spud Date: 1/8/2006 Event Nam e: ROT -D RILLIN G Start: 1/7/2006 End: 2/11/2006 Contractor Name: n1334@ ppco.co m Rig Release: 2/11/2006 Group: Rig Name: Doyon 1 41 Rig Number: ~ ~ Sub ~ ' Date From- To 'Hours ~ Code ~~ Code , Phase '~ Description of Operations 1/14/2006 20:00 - 21:00 1.00 WELCT OTHR INTRM1 cutter. Make beveled cut on 7 5/8" CSG, and dress same. Joint # 148 - length left in well = 38.56'. Cut off piece = 5.02'. POOH, breakout & lay down pups. 21:00 - 21:45 0.75 WELCT OTHR INTRM1 Install 7 5/8" pack-off as per Vetco rep. 21:45 - 22:30 0.75 WELCT NUND INTRM1 Nipple up BOP stack & well head flange. 22:30 - 23:00 0.50 WELCT BOPE INTRM1 Rig up test pump & lines. Test inner & outer seals on packoff, and the flange connection to 5000 PSI - 15 minutes. 23:00 - 23:30 0.50 WELCT OTHR INTRM1 Install wear bushing with landing joint. ID of wear bushing = 9.125". 23:30 - 00:00 0.50 DRILL FIT INTRM1 Rig up lines and test chart for LOT test & infectivity test on the 10 3/4" x 7 5/8" annulus at 2368' MD. 1/15/2006 00:00 - 01:00 1.00 DRILL FIT INTRM1 PJSM. Perform LOT & Infectivity test on the 10 3/4" x 7 5/8" annulus @ 2368'. Test to 13.1 PPG EMW and hold 10 minute shut in test. Record all on chart. Pump 30 BBLS water down annulus @ 3 BPM - 520 PSI. SIMOPS: Install Schlumberger MWD standpipe sensor. 01:00 - 06:00 5.00 DRILL PULD INTRM1 RU & pick up 90 joints of 4" Drill pipe with super sliders on them.. Re-position, inspect and re-torque all sliders while run in hole. 06:00 - 07:00 1.00 DRILL PULD INTRM1 POOH racking back 30 stands of 4" DP with super sliders. SIMOPS: Inject 80 more barrels of water down the 10 3/4" x 7 5/8" annulus for flush @ 3 BPM - 510 PSI. Rig up Little Red services, pump 90 bBLS of freeze protect diesel down annulus @ 3 BPM. Shut in annulus. 07:00 - 07:30 0.50 DRILL PULD INTRM1 Clean & clear floor area. 07:30 - 10:30 3.00 DRILL PULD INTRM1 Make up 15 stands of Hybrid Push pipe running in hole. Hybrid = 2 -4 3/4" Drill Collars + 1-4" DP per stand. 10:30 - 12:00 1.50 DRILL PULD INTRM1 Re-position 4" HWDP in Derrick. POOH racking back 15 stands of Hybrid push pipe. Crew change. 12:00 - 12:30 0.50 DRILL PULD INTRM1 PJSM with crew & SWS. Discuss Safey issues and procedure for making up Schlumberger BHA. Pick up 6 3/4" Hycalog RSX711 M-A2 bit with 2 x11's, 2 x 12' jets (.58'), 4 3/4" BIAS Unit w/ 22 restrictor (2.96'), 4 15/16" Control Collar (10.36'), 5" PD XO (1.17'), 5" Reciever (4.92'), 4 3/4" Flex XO (2.36'), 4 11/16" Periscope (25.01'), 4 3/4" Impulse MWD assembly (33.87'). Note: Bit = #3 RR1 with starting hours of 66.25 HRS from 1J-101 A Lateral. 12:30 - 12:45 0.25 DRILL PULD INTRM1 Test Power Drive @ Surface with 62 SPM - 220 GPM - 450 PSI. Good. 12:45 - 13:30 0.75 DRILL PULD INTRM1 Continue MU remaining BHA, 5 1/4" Bypass Sub /Float Sub (2.35'), 3 - 4 3/4" NonMag Flex Drill Collars (92.51'), 4 7/8" XO Sub (1.65'), 4 3/4" Drilling Jars (28.81') and 2 -joints 4" HWDP (60.48'). Total BHA = 357.80' 13:30 - 14:00 0.50 DRILL TRIP INTRMI Trip in hole with singles 4" DP from pipe shed to 670'. 14:00 - 14:15 0.25 DRILL DEOT INTRM1 Perform Shallow hole pulse test on MWD assembly @ 300 GPM - 1200 PSI. Good test. 14:15 - 18:00 3.75 DRILL TRIP INTRM1 Continue trip in hole from 670' - 6264' (5594'). Tag Float collar @ 6264' DPM. 18:00 - 19:15 1.25 CASE DEOT INTRM1 Pull back to 6245'. Rig up casing test egipment & lines. Test 7 5/8" Casing to 3000 PSI - 30 minutes. Recorded on chart. Good test. Bleed pressures and rig down equipment. 19:15 - 22:15 3.00 CEMEN DSHO INTRM1 Drill out float equipment @ 6264', firm cement to shoe @ 6350', and 21' of new hole to 6376', at 320 GPM - 2225 PSI. Torque @ 3-5K. ART = .28 HRS. PU WT = 97K, SO WT = 70K. 22:15 - 22:45 0.50 DRILL CIRC INTRMI Circulate Bottoms up @ 321 GPM-s - 2225 PSI, until shakers clean. Mud wt in /out = 8.7+. YP = 18, Gels -18 / 23. Obtai clean hole ECD @ 9.91 PPG. Condition mud for LOT. Blow down Top Drive. Pull 1 stand. 22:45 - 23:45 1.00 DRILL LOT INTRM1 Fill lines & Perform LOT on the 7 5/8" casing shoe @ 6350' MD, 3650 TVD. Test to leak off at 1259 PSI = 15.3 PPG Equivalent Mud Weight. rnntea: zri ait~uo ic~y:io nv~ ConocoPhillips Alaska Page 8 of 25 Operations Summary Report Legal Well Name: 1 J-166 Common Well Name: 1J-166 Spud Date: 1/8/2006 Event Name: ROT -DRILLING Start: 1/7/2006 End: 2/11/2006 Contractor Name: n1334@ppco.com Rig Release: 2/11/2006 Group: Rig Name: Doyon 141 Rig Number: Date From To ~ Hours Code ~~~ Code Phase ~~! 1/15/2006 22:45 - 23:45 23:45 - 00:00 1/16/2006 00:00-12:00 12:00 - 00:00 1.001 DRILL ~ LOT ~ INTRM1 0.251 DRILL I TRIP PROD 12.001 DRILL I DRLG I PROD 12.00 DRILL I DRLG PROD 1/17/2006 00:00 - 12:00 I 12.001 DRILL ~ DRLG ~ PROD 12:00 - 00:00 ~ 12.00 ~ DRILL ~ DRLG ~ PROD 1/18/2006 ~ 00:00 - 12:00 ~ 12.00 ~ DRILL ~ DRLG ~ PROD Description of Operations Held 10 minute shut in, observe shut in pressure bled from 860 PSI to 712 PSI. Bleed all pressure. Rig down equipment & lines. Pick up 1 stand & TIH back to 6376'. PU WT = 97K, SO WT = 70K, ROT WT = 70K Torque on = 3-7K, Torque off = 5K ECD = 9.91 PPG, Jar HRS = .28, Bit HRs = .28, MAX gas = 25 BTU's. Drill 6 3/4" hole in the A Lateral from 6376' - 7425' (1049'). MD. TVD = 3656'. ADT = 7.94 HRS,Total ADT = 8.22 HRS. PU WT = 105K, SO WT = 70K, ROT WT = 85K. Torque on/off bottom = 5.5K. Pumps - 345 GPM's - 2500 PSI. RPM's = 160. WOB = 3-5K. Total Bit HRS = 8.23 HRS. Total Jar HRS = 8.22. Mud Wt = 8.75 PPG, Visc = 76,YP = 18, Gels @ 21 / 28. Survey @ 7301' MD, 3656' TVD, 90 Deg INC, .52 Deg AZ. ECD = 10.32 PPG, Max gas = 140 Units. Observed drilling through concretions from 6384' -6400' (16'), 6409'-6414'(5'), 6570'-6586' (16'), 6591'-6600' (9'),6920' - 6937' (17'), 7054' -7058' (4'),7255' - 7263' (8'), and 7400'-7406' (6'). Obtain Slow pump rates @ 7176' MD, 3657 TVD. Pump #1 - 20 SPM - 320 PSI, 30 SPM - 440 PSI. Pump #2 - 20 SPM - 330 PSI, 30 SPM - 450 PSI. Continue Drill 6 3/4" hole in the A Lateral from 7425' - 8478' (1053'). MD. TVD = 3655'. ADT = 7.69 HRS,Total ADT = 15.91 HRS. PU WT = 116K, SO WT = 63K, ROT WT = 82K. Torque on/off bottom = 6-7K. Pumps - 350 GPM's - 2750 PSI. RPM's = 160. WOB = 2-10K. Total Bit HRS = 7.69 HRS. Total Jar HRS = 15.91. Mud Wt = 8.75 PPG, Visc = 68,YP = 18, Gels @ 21 / 28. Survey @ 8329' MD, 3655' TVD, 90 Deg INC, 1.51 Deg AZ. ECD = 10.35 PPG, Max gas = 92 Units. Observed drilling through concretions from 8021' -8025' (4'), 8415'-8420'(5'), 8473'-8483' (10'). Obtain Slow pump rates @ 8390' MD, 3655 TVD. Pump #1 - 20 SPM - 370 PSI, 30 SPM - 480 PSI. Pump #2 - 20 SPM - 410 PSI, 30 SPM - 500 PSI. Total K-Revs on Super Sliders for the day = 26524 HRS. Drill 6 3/4" hole in the A Lateral from 8478' - 9566' (1088'}. MD. TVD = 3692'. ADT = 7.91 HRS,Total ADT =23.82 HRS. PU WT = 120K, SO WT = 60K, ROT WT = 85K. Torque on/off bottom = 6.5K. Pumps - 335 GPM's - 2700 PSI. RPM's = 160. WOB = 3-10K. Total Bit HRS =23.82 HRS. Total Jar HRS = 23.82. Mud Wt = 8.75 PPG, Visc = 60,YP = 16, Gels @ 16 / 23. ECD = 10.38 PPG, Max gas = 167 Units. Observed drilling through concretions from 8469' -8485' (16'), 8643'-8658'(15'), 9100'-9110' (10'), 9488'-9502' (14'), 9533' - 9535' (2'). Obtain Slow pump rates @ 9418' MD, 3687 TVD. Pump #1 - 20 SPM - 350 PSI, 30 SPM - 480 PSI. Pumped hi-vis sweep @ 9415' and observed 5% increase in cuttings over the shakers. Continue Drill 6 3/4" hole in the A Lateral from 9566' - 10543' (977'). MD. TVD = 3711'. ADT =7.88 HRS,Total ADT = 31.70 HRS. PU WT = 126K, SO WT = 47K, ROT WT = 82K. Torque on/off bottom = 6K. Pumps - 320 GPM's - 2700 PSI. RPM's = 160. WOB = 3-10K. Total Bit HRS = 31.70 HRS. Total Jar HRS = 31.70. Mud Wt = 8.75 PPG, Visc = 64,YP = 17, Gels @ 19 / 24. ECD = 10.91 PPG, Max gas = 102 Units. Obtain Slow pump rates @ 10353' MD, 3734' TVD. Pump #1 - 25 SPM - 460 PSI, 35 SPM - 630 PSI. Pump #2 - 25 SPM - 470 PSI, 35 SPM - 610 PSI. Drill 6 3/4" hole in the A Lateral from 10543" - 11462' (919') MD. TVD = 3669'. ADT = 8.17HRS,Total ADT =39.87 HRS. PU WT = 135K, SO WT = 49K, ROT WT = 88K. Torque on/off bottom = 7.5K. Pumps - 320 .°~.~~ ConocoPhillips Alaska Page 9 of 25 ~ Operations Summary Report Legal Well Name: 1J-166 Common Well Name: 1 J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code l Phase 1/18/2006 00:00 - 12:00 ( 12.00 ~ DRILL ~ DRLG ~ PROD 12:00 - 00:00 I 12.001 DRILL I DRLG ~ PROD f 1/19/2006 ~ 00:00 - 03:00 1 3.001 DRILL 1 DRLG ~ PROD 03:00 - 07:00 I 4.001 DRILL 1 CIRC ~ PROD 07:00 - 08:30 1.501 DRILL I CIRC I PROD 08:30 - 12:00 3.501 DRILL 1 TRIP 1 PROD 12:00 - 13:15 1.25 DRILL TRIP PROD 13:15 - 14:45 1.50 WELLS EORP PROD 14:45 - 17:00 2.25 DRILL TRIP PROD 17:00 - 18:00 1.00 DRILL PULD PROD 18:00 - 20:15 I 2.251 CMPLTN RURD 1 CMPLTN 20:15 - 00:00 ~ 3.751 CASE 1 RUNC 1 CMPLTN 1/20/2006 00:00 - 00:15 0.25 CASE SFTY CMPLTN 00:15 - 00:45 0.50 CASE RURD CMPLTN 00:45 - 03:30 I 2.751 CASE ~ PULR ~ CMPLTN 03:30 - 04:30 ~ 1.00 ~ CASE 1 PULR ~ CMPLTN 04:30 - 05:00 0.50 CASE RURD CMPLTN 05:00 - 11:00 6.00 CASE RUNL CMPLTN 11:00 - 12:00 1 1.001 CASE 1 DEQT 1 CMPLTN Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group:. Rig Number: Description of Operations GPM's - 3300 PSI. RPM's = 160. WOB = 3-12K. Total Bit HRS =106.37 HRS. Total Jar HRS =39.87. Mud Wt = 8.75 PPG, Visc = 64 ECD = 10.91 PPG, Max gas = 165 Units. Observed drilling through concretions from 10675-10691' (16'), 11059-11067' (8'), 11093-11103' (10'), 11216-11225' (9'), 11269-11300' (31'). Obtain Slow pump rates @ 11279' MD, 3656' TVD. Pump #1 - 25 SPM - 500 PSI, 35 SPM - 660 PSI. Pump #2 - 25 SPM - 510 PSI, 35 SPM -670 PSI. Continue Drill 6 3/4" hole in the A Lateral from 11462'-12461' (999') MD. TVD = 3705'. ADT =8.12 HRS,Total ADT = 47.99 HRS. PU WT = 155K, SO WT = 50K, ROT WT = 101 K. Torque on/off bottom =5K/8K. Pumps - 315 GPM's - 3500 PSI. RPM's = 160. WOB = 3-10K. Total Bit HRS = 114.5 HRS. Total Jar HRS = 47.99. Mud Wt = 8.75 PPG, Visc = 64 ECD = 11.31 PPG, Max gas = 94 Units. Observed drilling through concretions from 11980-11983' (3'), 11992-1.1995' (3'), 12051-.12065'. (14'), 12088-12090' (2'), 12416-12435' (19'}. Obtain Slow pump rates @ 12276' MD, 3693' TVD. Pump #1 - 25 SPM - 600 PSI, 35 SPM - 790 PSI. Pump #2 - 25 SPM - 580 PSI, 35 SPM - 780 PSI. Total K-Revs=173,414 Drilled from 12,461' to 12,853' MD / 3,724' TVD. ADT=2.05 TDT=50.04 Jar Hours=50.04 PUW=175K SOW=60K ROT= 110K TOon/off=8K Max Gas=101 Units ECD=11.56 Pumped hi-vis weighted sweep @ 338 gpm, 4100 psi. Pumped total 22188 stks. Final ECD=11.20 Held PJSM for displacement to SFOBM. Displaced well to SFOBM. SPRs, UD single, dropped 1 7/8" rabbit. SPR#1=25stk/620psi, 35stk/780psi SPR#2=25stk/620psi, 35stk/790psi @ 12,822' MD 3,722' TVD 8.7 MW. POOH from 12,826' to 9,515'. Start PUW=190K SOW=40K End PUW=140K SOW=45K Cont'd to POOH from 9,515' to 6,338'. Serviced TD, slipped and cut 76' drill line. POOH from 6,338' to 35T. L/D BHA, rack back 2 stds HWDP w/jars, UD NMFDCs, MWD, Periscope tool, break bit, UD Powerdrive. Cleared rig floor, R/U csg equip, loaded pipe shed 4 1/2" balnks and slots, Sim-Ops, R/D Schlumberger. RIH w/ 4 1/2" slotted liner. Ran 120 jts to 3739'. PUW=68K SOW=64K Held PJSM and reviewed liner detail. P/U liner pups to rig floor. R/U back-up casing tongs, as others had washed out hyd. valve. Cont'd to run 4.5" liner as per detail. Ran a total of 64 jts blank pipe and 172 jts slotted liner (4.5", L-80 12.6# IBT) with 2 pups. PUW=83K SOW=60K Make up XO Bushing, Casing Seal Bore Ext, Flexlock Liner Hanger, RS Packoff Seal nipple, and HRD ZXP Liner Top PKR, with BOT running tools. Total BHA length of liner assembly = 7359.98'. PU WT = 85K, SO WT = 60K. R/D Doyon casing equip. Continue RIH with Liner on Drill Pipe from7360' - 12840' with no problems. Get PUW=180K SOW=60K. Drop 1 7/16" ball, Position liner w/ shoe rnnieu: a ioicvvo ic.<~.io nn \•y_. / ConocoPhillips Alaska Page ~o of 25 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date Fro~~~ - To 1!20/2006 111:00 - 12:00 1 /21 /2006 1/22/2006 12:00 - 14:45 14:45 - 15:15 15:15 - 15:30 15:30 - 15:45 15:45 - 18:30 18:30 - 21:15 1 J-166 1 J-166 ROT -DRILLING n 1334@ppco. com Doyon 141 Hours Code ~'~~ Sub Phase ,Code 1.00 CASE DEOT ~ CMPLTN 2.75 DRILL TRIP CMPLTN 0.50 DRILL PULD CMPLTN 0.25 DRILL RIRD CMPLTN 0.25 WINDO ULD PROD2 2.75 WINDO ULD PROD2 2.75 WINDO RIP PROD2 21:15 - 23:00 1.751 WINDOVOTHR PROD2 23:00 - 00:00 .1.00 WINDO RIP PROD2 00:00 - 00:15 0.25 WINDO ETW PROD2 00:15 - 01:15 1.001 WINDOWCIRC ~ PROD2 01:15 - 05:45 4.50 WINDO TWP PROD2 05:45 - 07:15 1.50 WINDO TWP PROD2 07:15 - 09:45 2.50 WINDO RIP PROD2 09:45 - 11:00 1.25 WINDO ULD PROD2 11:00 - 12:00 1.00 DRILL OTHR PROD2 12:00 - 13:00 1.00 DRILL OTHR PROD2 13:00 - 14:00 1.00 WELCT BOPE PROD2 14:00 - 15:00 1.00 WELCT BOPE PROD2 15:00 - 19:30 4.50 WELCT BOPE PROD2 19:30 - 23:00 3.50 WELCT BOPE PROD2 23:00 - 23:30 0.50 DRILL OTHR PROD2 23:30 - 00:00 0.50 RIGMNT RSRV PROD2 00:00 - 01:30 1.50 DRILL PULD PROD2 01:30 - 03:00 1.50 DRILL PULD PROD2 03:00 - 03:30 0.50 DRILL PULD PROD2 03:30 - 04:15 0.75 DRILL DEOT PROD2 04:15 - 05:15 ~ 1.00 ~ DRILL ~ TRIP ~ PROD2 Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations @ 12840' & top of liner @ 5480.02'. Circa ball down w/ 3 BPM and pressure up to set .Set down 55K to set slips as per BOT rep, continue pressure up to 4000 PSI, to complete setting PKR. Bleed pressure, Rig up and pressure test down annulus to test PKR at 1000 PSI - 10 Minutes. Blow down Top Drive and Kill Line. Monitor well -Static. PUW=130K SOW=100K after setting ZXP. Monitored well and POOH. Lay down liner running tools. Clear & clean rig floor. P/U whipstock and associated BHA from beaverslide. P/U and M/U whipstock BHA. TIH from 388' to 4,570'. Shallow tested MWD w/ 80 spm 1150 psi @ 1,789' (good test). MAD passed from 4,570' to 4,725' w/ 80 spm and 2200 psi. TIH from 4,725' to 5,372'. PUW=115K SOW=95K. TIH from 5,372' to 5,480' MD. Orient whipstock @ 5 deg left of high-side and set trip anchor, sheared off bolt w/ 60 K downweight. PUW=125K SOW=90K ROT=109K TQ=3-7K. Held PJSM and displaced well to MOBM @ 80 spm, 2200 psi. SPR#1=25stks/350psi, 35stks/550psi SPR#2=25stks/370psi, 35stks/530psi Milled window from 5,380' to 5,392'. Milled 20' of gauge hole to total depth of 5,422'. Pumped 30 bbl weighted hi-vis sweep and worked mill through window. Rotated through window w/ pumps on 8 times. Repeated sliding 4 more times, sliding w/o pumps 2 times. PUW=120K SOW=90K Monitored well, static. Pumped dry job and POOH from 5,422' to 286'. UD BHA. S/B 2 stds push pipe, UD 2 bumper subs. Plugged in and downloaded MWD. Cont'd to UD BHA including: TM HOC, MWD, DM HOC, NMFS, 1 jt 3.5" HWDP, upper mill (in gauge), lower mill and window mill. Pulled wear bushing, cleaned rig floor, C/O elevators. R/U and flush stack w! stack washer after milling operations. R/U and begin to test BOPE. Valve #13 on manifold failed along with HCR choke valve. Began to repair equipment. Removed and rebuilt choke valve bonnet assy. on #13. Removed bonnet on HCR choke and C/O seals and seat assy. Tested ROPE w/ low pressure test @ 250 psi and high @ 3500 psi. Tested annular, top 3.5"X6" rams, blinds, IBOP, lower IBOP, dart valve, floor valve, manual choke and kill, HCR choke and kill. Choke manifold valves 1-14. Performed accumulator test 3000 psi decreased to 1800 psi with all elements closed (3 min 25 sec recovery time to 3000 psi). Five nitrogen bottles showed avg. pressure of 2100 psi. R/D test equip. Witnessing of test waived by J. Spaulding of AOGCC. Set wear bushing. Inspected saver sub and serviced T/D. M/U BHA. Uploaded MWD tools Cont'd to M/U BHA. Shallow tested MWD @ 453'. Rotated to break-in seals on Geo-Pilot tool w/ 80 spm, 20 rpm, 1200 psi. RIH from 453' to 2,239' MD and filled pipe. Shallow-tested to ensure rnnieo: u wi<uuo i<.<a. io nv, ConocoPhillips Alaska Page ~ ~ of 25 Operations Summary Report Legal Well Name: 1J-166 Common Well Name: 1J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Sub '~ Date Frori~ - To Hours Code Code Phase 1 /22/2006 04:15 - 05:15 05:15 - 06:45 06:45 - 08:45 08:45 - 12:00 12:00 - 00:00 1.00 DRILL TRIP PROD2 1.50 DRILL TRIP PROD2 2.00 DRILL DEQT PROD2 3.25 DRILL DRLH PROD2 12.00 DRILL I DRLH I PROD2 1/23/2006 ~ 00:00 - 12:00 ~ 12.00 ~ DRILL ~ DRLH ~ PROD2 12:00 - 00:00 I 12.001 DRILL ~ DRLH ~ PROD2 1/24/2006 ~ 00:00 - 10:30 ~ 10.50 ~ DRILL ~ DRLH ~ PROD2 Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations downlink w/ Geo-Pilot. Cont'd to RIH from 2,239' to 5,322'. Washed down to 5,422' w/ 80 spm @ 2000 psi. Ran through window w/ no problems. Trouble-shot MWD smart tools. Drilled from 5,422' to 5,490' MD / 3,514' TVDRRT=ADT=2.8 hrs Jar hrs=52.90 PUW=102K SOW=65K ROT=85K TOon/off=5K ECD=9.71 Calc clean hole ECD=9.75 Max Gas=51 units SPR#1=25stk/340psi, 35stk/500psi SPR #2=25stk/350psi, 35stk/510psi @ 5,490' MD / 3,516' TVD EMW= 8.7+ Concretion depths: 5465-5476' (12') Drilled from 5,490' to 6,790' MD / 3,521' TVD ART=ADT=9.1 hrs Jar hrs=62 PUW=117K SOW=64K ROT=82K TOon/off=5K/5.5K ECD=10.28 Calc clean hole ECD=9.75 Max Gas=48 units SPR#1=25stk/420psi, 35stk/590psi SPR #2=25stk/440psi, 35stk/610psi @ 6,534' MD / 3,510' TVD EMW= g.7+ Concretion depths: 5466-5488' (12'), 5489-5493' (4'), 5531-5534' (3'), 5670-5685' (15'), 5706-5724' (18'), 5787-5788' (1'), 5873-5880' (7'), 5946-5967' (21'), 6564-6567' (3'), 6652-6661' (9'), 6671-6677' (6'). Drill 6 3/4" B Lateral w/ Sperry-Sun GeoPiolt from 6790' - 7793' (1003') MD. TVD = 3515'. ADT = 9.6 hrs. PU WT = 116K, SO WT = 60K, ROT WT = 81 K. Torque on/off bottom = 5.5/6.OK. Pumps - 330 GPM's - 2700 PSI. RPM's = 140. WOB = 3-15K. Total Bit HRS =21.5 hrs. Total Jar HRS = 71.6. Mud Wt = 8.75 PPG, Visc = 72, ECD = 10.25 PPG, Max gas = 47 Units. Observed drilling through concretions from 6950'-6960', 7047'-7055', 7062'-7070', 7202'-7204', 7548'-7553', 17589'-7590', 7620'-7630', 7637'-7639', 7640'-7648', 7729', 7746', 7749'-7762', 7776'-7778'. Obtain Slow pump rates @ 7374' MD, 3525' TVD. Pump #1 - 25 SPM - 460 PSI, 35 SPM - 650 PSI. Pump #2 - 25 SPM - 440 PSI, 35 SPM -570 PSI. Drill 6 3/4" B Lateral w/ Sperry-Sun GeoPiolt from 7793' - 8723' (930') MD. TVD = 3522'. ADT = 9.45 hrs. PU WT = 130K, SO WT = 50K, ROT WT = 82K. Torque on/off bottom = 6.5K. Pumps - 330 GPM's - 2800 PSI. RPM's = 120. WOB = 3-15K. Total Bit HRS =30.95 hrs. Total Jar HRS = 81.05. Mud Wt = 8.70 PPG, Visc = 72, ECD = 10.83 PPG, Max gas = 47 Units. Observed drilling through concretions from 7781'-7795', 7820'-7829', 7970'-7974', 8030'-8032', 8056'-8061', 8445'-8447', 8473'-8478', 8480'-8495', 8541'-8549', 8568'-8573', 8584'-8590', 8599'-8604', 8624'-8629', 8682'-8689'. Obtain Slow pump rates @ 8496' MD, 3527' TVD. Pump #1 - 25 SPM - 490 PSI, 35 SPM - 650 PSI. Pump #2 - 25 SPM - 510 PSI, 35 SPM -670 PSI. Pumped 35 bbl Hi-vis weight sweep @ 8483' w/ 10% increase in cuttings. K-REV's 44852 (6 stands on sliders in hole) Drill 6 3/4" B Lateral w/ Sperry-Sun GeoPiolt from 8723' - 9617' (991') MD. TVD = 3541'. ADT = 8.9 hrs. PU WT = 130K, SO WT = 55K, ROT WT = 82K. Torque on/off bottom = 7/6.OK. Pumps - 330 GPM's - 2900 PSI. RPM's = 120. WOB = 5-15K. Total Bit HRS =21.5 hrs. Total Jar HRS = 90.04 Mud Wt = 8.75 PPG, Visc = 79, ECD = 11.19 PPG, Max gas = 457 Units. Observed drilling through concretions from 8727'-8732', 8769'-8773', 8792'-8801', 8849'-8871', 8883'-8895', rnn~ea: to atwo ic:a~.io nvi ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 J-166 1 J-166 ROT -DRILLING n 1334@ppco.com Doyon 141 Start: 1 /7/2006 Rig Release: 2/11/2006 Rig Number: Page 12 of 25 Spud Date: 1/8/2006 End: 2/11/2006 Group: Date '~ From - To ~~ Hours Code ~ Code ~ Phase 1/24/2006 ~ 00:00 - 10:30 ~ 10.50 DRILL ~ DRLH ~ PROD2 10:30 - 12:00 12:00 - 12:45 1.50 DRILL CIRC PROD2 0.75 DRILL CIRC PROD2 12:45 - 19:30 19:30 - 22:00 22:00 - 00:00 1 /25/2006 100:00 - 08:00 08:00 - 08:30 08:30 - 12:00 6.751 DRILL I OTHR I PROD2 2.50 DRILL DRLH PROD2 2.00 DRILL DRLH PROD2 8.001 DRILL I DRLH I PROD2 0.501 DRILL CIRC PROD2 3.501 DRILL I DRLH I PROD2 12:00 - 00:00 12.001 DRILL ~ DRLH ~ PROD2 1/26/2006 ~ 00:00 - 09:45 I 9.751 DRILL I DRLH ~ PROD2 Description of Operations 8904'-8911', 8941'-8955', 8981'-8995', 9078'-9084', 9259'-9260', 9290'-9292'. Obtain Slow pump rates @ 9430' MD, 3537' TVD. Pump #1 - 25 SPM - 600 PSI, 35 SPM - 790 PSI. Pump #2 - 25 SPM - 620 PSI, 35 SPM -800 PSI. Wait on geology decision from town. Worked pipe from 9527'-9617' while waiting on geology to evaluate log data w/ 84 spm, 2600 psi, 120 rpm, TQ off=6K Pulled up to 9340' to begin sidetracking operations. Cut groove and trough from 9340' to 9380'. Time drilled to 9389'. Checked for sidetrack, no good. Pulled up to 9383' and cut trough. Time drilled again to 9389'. ADT=3.49 hrs. Drilled from 9389' to 9617'. ADT=1.75 hrs. Drill 6 3/4" B Lateral w/ Sperry-Sun GeoPiolt from 9617' - 9714' (97') MD. TVD = 3566'. ADT = 1.25 hrs.. PU WT = 135K, SO WT = 55K, ROT WT = 82K. Torque on/off bottom = 6/7.OK. Pumps - 330 GPM's - 3050 PSI. RPM's = 120. WOB = 4-15K. Total Bit HRS before sidetrack =43.43 hrs. Total Jar HRS = 98.28ud Wt = 8.75 PPG, Visc = 74, ECD = 11.19 PPG, Max gas = 43 Units. Observed drilling through concretions from 9598'-9601', 9615'-9626', 9672'-9686'. Obtain Slow pump rates @ 9430' MD, 3537' TVD. Pump #1 - 25 SPM - 600 PSI, 35 SPM - 790 PSI. Pump #2 - 25 SPM - 620 PSI, 35 SPM -800 PSI. Krevs=187393 Drill 6 3/4" B Lateral w/ Sperry-Sun GeoPiolt from 9714' - 10458' (744') MD. TVD = 3555'. ART=6.4 Wait on geology decision from town. Circa @ 57 spm, 200 gpm, 1600 psi, 100 rpm, TO off=6K. Drill 6 314" B Lateral w/ Sperry-Sun GeoPiolt from 10458' - 10755' (297') MD/ 3555' ND. ADT =2.1 hrs. Total Bit HRS =54.93 hrs. Total Jar HRS =106.8 PU WT = 140K, SO WT = OK, ROT WT = 80K. TO on/off=7/6.5K. Pumps - 330 GPM's - 3250 PSI. RPMs = 120. WOB = 5-15K. Mud Wt = 8.75 PPG, Visc = 79, ECD = 11.76 PPG, Max gas = 54 Units. Observed drilling through concretions from 9760'-9775', 9780'-9784', ..9796'-9800', 9804'-9810', 9867'-9870', 9883'-9886', 9897'-9901', 9944'-9952', 10034'-10037', 10053'-10065'. SPR#1=25stk/680psi,35stk/790psi SPR#2=25spm/680psi,35stk/850psi @ 10458 MD/ 3555 TVD Drill 6 3/4" B Lateral w/ Sperry-Sun GeoPiolt from 10755' - 11745' (990') MD / 3542' TVD. Pumped a 30 bbl hi-vis weighted sweep @ 10,739' and observed a 10% increase in cuttings across the shakers. Total Bit HRS=63.96. Total Jar HRS =115.81 ADT =9.03 hrs. PU WT = 170K, SO WT = OK, ROT WT = 90K. TO on/off = 8.5/8 Pumps - 330 GPM's - 3600 PSI. RPM's = 120. WOB = 4-16K. Mud Wt = 8.75 PPG, Visc = 72, ECD = 11.94 PPG, Max gas = 52 Units. Observed drilling through concretions from 10768'-10772', 10804'-10807', 11075'-11076', 11105'-11106', 11110'-11112', 11116'-11120', 11123'-11126', 11136'-11138', 11149'-11157', 11163'-11178', 11185'-11190', 11200'-11208', 11248'-11253', 11263'-11270', 11290'-11294', 11510'-11518', 11521'-11533' SPR#1=25stk/680psi,35stk/850psi SPR#2=25spm/670psi,35stk/850psi @ 11381 MD/ 3533TVD KREVs=335868 Drill 6 3/4" B Lateral w/ Sperry-Sun GeoPiolt from 11,745' - 12,524' ranted: znmzuua 1Y:Zy:1tl YM ConocoPhillips Alaska Page ~~ 3 of 25 Operations Summary Report Legal Well Name: 1 J-166 Common Well Name: 1J-166 Spud Date: 1/8/2006 Event Name: ROT -DRILLING Start: 1/7/2006 End: 2/11/2006 Contractor Name: n1334@ppco.com Rig Release: 2/11/2006 Group: Rig Name: Doyon 141 Rig Number: Date From - To i Hours Code Code Phase 1!26/2006 00:00 - 09:45 9.75 DRILL DRLH PROD2 09:45 - 10:15 0.50 DRILL CIRC PROD2 10:15 - 12:00 1.75 DRILL DRLH PROD2 12:00 - 16:45 I 4.751 DRILL I DRLH I PROD2 11 /27/2006 16:45 - 18:30 1.75 DRILL CIRC PROD2 18:30 - 18:45 0.25 DRILL OBSV PROD2 18:45 - 00:00 5.25 DRILL WIPR PROD2 00:00 - 05:15 5.25 DRILL WIPR PROD2 05:15 -06:15 I 1.001 DRILL I CIRC PROD2 06:15 - 09:30 3.25 DRILL WIPR PROD2 09:30 - 12:00 2.50 DRILL WIPR PROD2 12:00 - 12:45 0.75 DRILL WIPR PROD2 12;45 - 15:30 2.75 DRILL CIRC PROD2 15:30 - 16:45 1.25 DRILL CIRC PROD2 16:45 - 17:00 I 0.251 DRILL I OBSV I PROD2 21:30 - 21:45 I 0.251 DRILL I OBSV I PROD2 Description of Operations (779') MD. TVD = 3566'. ART=7.43 PUW=165K SOW=O ROT=107K Wait on geology decision from town. Pumped 30 bbl weighted hi-vis sweep @ 93 spm, 330 gpm. Drill 6 3/4" B Lateral w/ Sperry-Sun GeoPiolt from 12,524' - 1700' (176') MD/ 3583' ND. ADT =1.02 hrs TDT=8.45. Total Bit HRS =75.41 hrs. Total Jar HRS =124.3 PU WT = 170K, SO WT = OK, ROT WT =105K. TQ on/off=8.9/8.5K. Pumps - 330 GPM's - 4000 PSI. RPMs = 120. WOB = 5-15K. Mud Wt = 8.75 PPG, Visc = 72, ECD = 12.05 PPG, Max gas = 40 Units. Observed drilling through concretions from 12015'-12021', 12056'-12062', 12146'-12154', 12159'-12162', 12207'-12219', 12257-12261', 12268'-12281', 12546'-12550'. SPR#1=25stk/730psi,35stk/920psi SPR#2=25spm/730psi,35stk/920psi @ 12524 MD/ 3566 TVD Drill 6 3/4" B Lateral w/ Sperry-Sun GeoPiolt from 12700' - 12952' (252') MD / 3591' TVD. Pumped a 30 bbl hi-vis weighted sweep @ 12,745' and observed a 50% increase in cuttings across the shakers. (Pumped another sweep @ 12,952' and observed 100% increase in cuttings. ECD prior to 1st sweep=11.89 after last sweep =11.45) Total Bit HRS=79.5. Total Jar HRS =128.4 ADT =4.09 hrs. PU WT = 205K, SO WT = OK, ROT WT = 111 K. TQ onloff = 10.5/9K Pumps - 330 GPM's - 4050 PSI. RPM's = 120. WOB = 4-15K. Mud Wt = 8.75 PPG, Visc = 67, ECD = 12.01 PPG, Max gas = 41 Units. Observed drilling through concretions from 12843'-12854', 12861'-12868', 12905'-12918', 12935'-12938'. KREVs=158305 Pumped hi-vis sweep @ 12,952' and 2X BU w/ 90 spm, 4000 psi, 140 rpm, and TQoff=8K. Garnered SPRs. Observed well, static. SPR#1=25stk/700psi,35stk/910psi SPR#2=25spm/730psi,35stk/940psi @ 12952 MD/ 3591 TVD BROOH from 12,952' to 9,620' w/ 140 rpm, 3500 psi, 330 gpm. BROOH from 9,620' to window @ 5,380' w! 140 rpm, 330 gpm, 3000 psi. Pumped weighted hi-vis sweep @ 5,380' w/ 330 gpm, 2200 psi. Observed a negligible 5% increase in cuttings. Monitored well, static. RIH from 5,380' to 10,368' where SOW=O. Washed through a bridge @ 9,246'. Washed and reamed from 10,368' to 12,290' w/ 248 gpm, 2800 psi, 120 rpm, TQ=7.5K. PUW=155K SOW=45K ROT=110K Washed and reamed from 12,290' to 12,952' Pumped a 35 bbl weighted hi-vs sweep followed by 3 BUs @ 85 spm, 302 gpm, 3900 psi, 140 rpm, TQ=8.5K Displaced to SFOBM w/ 85 spm, 302 psi, 3900 psi, 120 rpm, TO=8.5. PUW=190K SOW=OK ROT=112K Garnered SPRs. Monitored well, static. Dropped 1 7/8" rabbit. SPR#2=25stkl550psi, 35stk/830psi @ 12,952' MD/ 3592' TVD w/ 8.8 PPG SFOBM. POOH from 12,952' to above window @ 5,347'. Observed well, static. rrincea: uiwtuun -ic~a:-farm ConocoPhillips Alaska From'- To 'Hours Legal Well Name: 1 J-166 Common Well Name: 1J-166 Event Narne: ROT -DRILLING Start: 1/7/2006 Contractor Name: n1334@ppco.com .Rig Release: 2/11/2006 Rig Name: Doyon 141 Rig Number: Date 1 /27/2006 Operations Summary Report Code Sub Phase Code 21:45 - 00:00 2.251 DRILL (TRIP PROD2 1/28/2006 00:00 - 00:15 I 0.251 DRILL I PULD PROD2 00:15 - 01:00 0.75 DRILL OTHR PROD2 01:00 - 01:45 0.75 DRILL PULD PROD2 01:45 - 02:15 0.50 DRILL PULD PROD2 02:15 - 02:45 0.50 WINDO ULD CMPLT2 02:45 - 05:45 I 3.001 WINDOWfRIP I CMPLT2 05:45 - 06:00 0.251 WINDOVI/fRIP I CMPLT2 06:00 - 06:45 0.75 WINDO IRC CMPLT2 06:45 - 09:45 3.00 WINDO RIP CMPLT2 09:45 - 11:15 1.50 WINDO ULD CMPLT2 11:15 - 12:00 0.75 WINDO ULD CMPLT2 12:00 - 12:30 0.50 CASE RURD CMPLT2 12:30 - 16:30 4.00 CASE RUNC CMPLT2 16:30 - 17:00 0.50 CASE RUNC CMPLT2 17:00 - 18:30 1.50 CASE RUNC CMPLT2 18:30 - 19:45 1.25 CASE RUNL CMPLT2 19:45 - 21:45 2.00 CASE RUNL CMPLT2 22:45 - 00:00 1.25 CASE RUNL CMPLT2 11!29/2006 00:00 - 02:00 2.001 CMPLTNI OTHR I CMPLT2 02:00 - 02:30 I 0.501 CMPLTNI OTHR I CMPLT2 02:30 - 03:00 I 0.501 CMPLTNI CIRC I CMPLT2 03:00 - 04:45 1.75 RIGMNT RSRV CMPLT2 04:45 - 07:00 2.25 CMPLTN TRIP CMPLT2 Page 14 of 25..1 Spud Date: 1/8/2006 End: 2/11/2006 Group: Description of Operations POOH from 5,347' to BHA @ 369'. KREVs=218619 Rack back 2 stds HWDP w/jars, 1 std NMFDCs. UD BHA SMT sub, flt sub. Downloaded MWD. Cont'd to UD BHA including: DM HOC, NMFDC, Geo-pilot, and bit. Cleaned and cleared rig floor. UD BHA tools. M/U BHA including: 1 jt 3.5" HWDP, hook, flt sub, bumper sub, oil jars, XO, and 3 stds push pipe. RIH retorquing super sliders on the way in (90 total). RIH to 5,333'. PUW=130 SOW=95 Washed down to 5,386' and attempted to hook whipstock. Turned 1/4 turn 3 times and hooked on 4th try. Pulled 50K over; jars fired w/ no release. Second try pulled 60K over; jars fired w/ release and shear of trip anchor. PUW=140K Pulled up to 5,363' and CBU @ 56 spm, 200 gpm, 950 psi. POOH from 5,363' to 61'. UD XO, oil jars, bumper sub, float sub, 1 jt 3.5" HWDP; hook. UD whipstock debris sub, shear disc sub, bottom trip anchor blanking sub, flex jt, 2 jts 3.5" DP, unloader sub, locator sub w/seal unit. Cleared and cleaned rig floor. R/U to run 4 1/2" liner in "B" Lateral. Held PJSM. Ran 4 1/2" liner to 5,591'. Tagged up on "D" Lateral ZXP. Pulled up to 5,365'. Attempted to go through window, no luck. Turn 90 deg, try again -through window @ 5380+'. Cont'd to run liner from window to 7,500'. PUW=83K SOW=60K PJSM. Discuss safety issues and procedure for making up Slim Hole MWD assmy. Make up Baker Model B1 FHH Hook Hanger assembly, pups, with crossoverjoint, Casing Swivel, running and setting tools. Make up Ball seat shear sub and Slimhole MWD assembly, oriented 180 DEG from Hook on hanger. Ran in 2 stds and SHT MWD equip. PUW=84K SOW=62K TIH on DP to 11,636'. Slack-off weight nearly equal to block weight. PUW=137 SOW=36K Worked pipe to 12,727' with very little down weight. PUW=185 SOW=36-38K Cont'd to RIH w/ DP and very little down weight. Oriented hook to high side and worked liner to 12,919' w/ the hook 10' past the window. Pulled up and re-oriented hook, set hook @ 5394' (2' low) and 29? right of highside (whipstock for window milling set @ 5? left ofhigh-side). Pulled up and re-hooked to verify with same toolface and depth. Top of hook assembly @ 5,377.27' and bottom of hook assembly @ 5,394.13'. PUW=185K SOW=40K Dropped ball and pumped down w/ 2 bpm, 680 psi. Ball bumped @ 511 stks and pressured up to 3500 psi. Released from hook, continued to pressure up to 4200 psi to shear out ball seat. Racked back 1 std push pipe, UD 1jt 4" DP. CBU w/ 70 spm, 1300 psi, 247 gpm. Slipped and cut drilling line, serviced top drive, inspected saver sub. TOOH from 5,254' to 56'. Trip out displacements Calc=42.21 bbis rnnceu: u wi<uuo ic.ca.io nv~ ConocoPhillips Alaska Page ~5 of 25 Operations Summary Report Legal Well Name: 1 J-166 Common Well Name: 1J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To _:`- Hours '~ Code ~ Sub ~ Code' Phase 1!29/2006 04:45 - 07:00 2.25 CMPLTN TRIP CMPLT2 07:00 - 08:00 1.00 CMPLTN PULD CMPLT2 08:00 - 09:45 1.75 RIGMNT RGRP CMPLT2 09:45 - 10:15 0.50 CMPLTN RURD CMPLT2 10:15 - 12:00 1.75 CMPLTN PULD CMPLT2 12:00 - 14:30 2.50 CMPLTN TRIP CMPLT2 14:30 - 15:00 I 0.501 CMPLTN PCKR ~ CMPLT2 15:00 - 15:30 I 0.501 CMPLTNI PCKR I CMPLT2 15:30 - 16:00 0.50 CMPLTN CIRC CMPLT2 16:00 - 18:00 2.00 CMPLTN TRIP CMPLT2 18:00 - 18:45 0.75 CMPLTN PULD CMPLT2 18:45 - 21:45 3.00 WINDO ULD PROD3 21:45 - 00:00 2.25 1/30/2006 00:00 - 01:15 1.25 01:15 - 01:45 0.50 01:45 - 02:30 0.75 02:30 - 06:15 3.75 06:15 - 07:15 1.00 WI 07:15 - 09:30 2.25 WI 09:30 - 10:45 1.25 WI 10:45 - 12:15 1.50 12:15 - 12:30 0.25 RIP PROD3 RIP PROD3 ETW PROD3 JCIRC PROD3 /SCML PROD3 (CIRC PROD3 ~T'RIP PROD3 PULD PROD3 EQRP PROD3 PULD PROD3 Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations Actual=48.0 bbls. UD BHA, liner running tool, slim hole MWD. C/O saver sub. R/U casing equip. Held PJSM. M/U LEM to 430.2'. Baker Seal assembly (3.26'), Crossover joint IBT x STL (43.04'), 4 1/2" IBT pup (30.88'), Camco "DB" Nipple 3.563" ID (1.55'), 4 1/2" IBT JNT (31.35'), 4 1/2" IBT pups (9.83), LEM assembly (35.93'), 7 - JNTs of 4 1/2" IBT (215.49'), 4 1/2" IBT pup (3.82'), Baker Casing Swivel (2.82'), XO Bushing (1.40'), 109-47 Casing Seal Bore receptacle (19.69'), ZXP Liner Top Packer (19.03'). Total tools to stay in hole 417.2'. TIH w/ LEM assy. from 430' to 5,521'. PUW=133K SOW=100K Good indication of latch up w/ 35K over on downweight. Pulled up gently w/ 5K overpull to 138K. Set down 40K. LEM in place with top @ 5367.22'. Top of ZXP packer element @ 5104.38'. Dropped 1.75" ball and pumped down w/ 30 spm, 350 psi. Seated ball and pressured up to 2200 psi release pressure. Slowly pressure up to 4400 psi. Bled pressure to zero. Release from LEM. Tested ZXP packer to 1000 psi for 5 mins. P/U 8' with PUW=128K down from 133K. Verify top of ZXP @ 5104 with tag. POOH to 5039'. CBU w/ 1300 psi, 70 spm. Monitored well, static. POOH from 5039' to 42'. Trip out displacements Calc=44 bbls Actual=47.0 bbls. UD running tool. Cleaned and cleared rig floor. P!U and M/U whipstock and mill BHA. Uploaded MWD, SHT MWD w/ 82 spm, 291 gpm, 900 psi. TIH from 466' to 3,362'. PUW=84K SOW=74K Made MAD pass from 4,660' to 4,690'. Oriented 15? left of high side. RIH to 4,997' and oriented @ 15? left of high side w/ 86 spm, 300 gpm, 2450 psi. Tagged ZXP @ 5104'. Set trip anchor w/ 20K down weight. Pulled up to 130K to confirm setting. Whipstock set @ 18? left of high side. Set down w/ 50K down weight to shear bolt. Mill @ 5,005' for window cutting. Held PJSM and displaced wel- to MOBM. Garnered SPRs. SPR#1=25stk/340psi, 35stk/490psi SPR#2=25stk/350psi, 35stk/500psi @ 5046' MD / 3423' TVD 8.8+MW Milling from 5,005' to 5046'. Milled window from 5,005' to 5,017' + 20' of gauged hole to 5037'. TD= 5,046' Milled w/ 80 spm, 2400 psi, 120 rpm. TOW=5,005' BOW=5,017" Worked. mill through window w/ 120 rpm, 86 spm, 300 gpm, 2400 psi. Rotated through window up and down 6 times. Slid through window twice w/ pumps on, no problems. Monitored well, static. Pumped dry job and POOH from 5,046' to 98'. PUW=125K SOW=90K prior to POOH. UD mill, XO, bumper sub, downloaded MWD, TM, MWD, DM, F/S, 1 jt 3.5" HWDP, window mill, lower and upper mill (upper mill in gauge). Removed mill and BHA from rig floor. Drained stack after milling operations. Pulled wear bushing. R/IU and flushed stack. R/D stack washer. UD milling BHA from rig floor. L2 /~ /ca.6(s Printed: 2113!2006 12:29:18 PM ~I,~ ConocoPhillips Alaska Page ~~ of 25 Operations Summary Report Legal Well Name: 1 J-166 Common Well Name: 1J-166 Spud Date: 1/8/2006 Event Name: ROT -DRILLING Start: 1/7/2006 End: 2/11/2006 Contractor Name: n1334@ppco.com Rig Release: 2/11/2006 Group: Rig Name: Doyon 141 Rig Number: Date From - To ~~ Hours ~ Code Code. Phase 1/30/2006 ~ 12:30 - 15:30 ~ 3.00 ~ WELCT~ BOPE PROD3 15:45 - 18:00 2.25 DRILLS PUOLD PROD3 18:00 - 20:00 2.00 DRILL TRIP PROD3 20:00 - 00:00 I 4.00 I DRILL I DRLH I PROD3 11/31/2006 100:00 - 12:00 I 12.001 DRILL I DRLH I PROD3 12:00 - 16:45 16:45 - 17:00 17:00 - 17:45 17:45 - 20:30 20:30 - 22:30 22:30 - 00:00 4.75 DRILL DRLH I PROD3 0.25 DRILL DRLH PROD3 0.75 . DRILL TRIP PROD3 2.751 DRILL I TRIP I PROD3 Description of Operations R/U and test BOP stack, HCR's & manual valves. Test Choke mainfold valves 1-14, upper & lower IBOP valves, floor safety valve & dart valve.All tests 250 PSI Low / 3500 PSI High. Recorded on chart. Accumulator test: Starting=3000 psi Ending=1900 psi after all elements closed. Recovery time=3 min 4 sec. Nitrogen bottle pressure=2100 psi Chuck Shieve with AOGCC waived witness of test. Tested gas alarms and PVT and high flow alarms. R/D test equipment. Set wear bushing. P/U and M/U BHA #9 including: bit, geo-pilot, pony collar, DM, smart stab, slimphase, PWD, TM, NM F/S, stab. Uploaded MWD. Cont'd M/U NM flex DCs, XO, 2 std HWDP, jars, .Broke in geo-pilot bearings and SHT MWD w/ 84 spm, 1400 psi. TIH from 369' to 4,949'. Went through window, and TIH to 5,036'. Reamed to 5,046' w/ 90 rpm, 84 spm, 2100 psi, TQ=4K. PUW=91 K SOW=75K Drilled from 5,046' to 5,506' MD ! 3,460' TVD. ADT=2.51 hrs. Jar hrs=125.89 PUW=107K SOW=65K ROT=80K TQon/off=5/4.5K Max Gas=149 Units Max ECD=10.09 SPR#1=25stk/380psi, 35stk/550psi SPR#2=25stk/390psi, 35stk/560psi @ 5133' MD / 3441' TVD 8.9+MW Drilled from 5,506' to 7188' MD / 3,465' TVD. ADT=8.12 hrs. Jar hrs=136.52 PUW=110K, SOW=60K, ROT=80K, TQon/off=6K, 6K Max Gas=184 Units. Max ECD=10.24 SPR#1=25stk/420psi, 35stk/610psi SPR#2=25stk/460psi, 35stk/600psi @ 7094' MD ! 3447' TVD 8.8+MW Concretions @ 5713'-5722' (9'), 5757'-5761'(4'), 5769'-5774'(5'), 5787'-5789'(2'), 6039'-6040'(1'), 6981'-6984'(3'), 6993'-6998'(5'). Total concretions this tour = 29'. Drilled from 7,188' to 7,530' MD / 3,448' TVD. ADT=4.17 hrs. Jar hrs=140.69 PUW=108K, SOW=60K, ROT=80K, TQon/off=6K, 6K Max Gas=81 Units. Max ECD=10.26 SPR#1=25stk/420psi, 35stk/580psi SPR#2=25stk/430psi, 35stk/600psi @ 7530' MD / 3448' TVD 8.7+MW Concretions @ 7453'-7474' (19'), 7481'-7499'(18'), 7506'-7528'(22'). Total concretions this tour = 59'. Last survey @ 7494.91' MD, 3451.91 TVD, INC = 89.81 DEG, AZ = 352.77 DEG. Pump up surveys. Obtain SPR's. Monitor well -static. POOH on elevators from 7530'-7191' (339'). Observe hole not taking proper fill. BROOH from 7191' - 5136' (2055'), @ 92 SPM, 326 GPM, and 2500 PSI. Pull assembly through window @ 5005' with no issues up to 4949'. 2.00 DRILL TRIP PROD3 Monitor well -static. POOH 15 stands. observed well 3 BBLS behind in fill. Continue POOH to 2735'. Hole fill good, well static. Calcualted displacement = 29.5 BBLs. 1.50 DRILL PULD PROD3 Rack back 4" HWDP, Drilling Jars, and 1 stand Non Mag Flex Drill Collars. Plug in and download MWD assembly. Printed: 2/13/2006 12:29:18 PM ,~ ConocoPhillips Alaska Page I ~ of 25 Operations Summary Report Legal Well Name: 1 J-166 Common Well Name: 1J-166 Spud Date: 1/8/2006 Event Nam e: ROT -D RILLIN G Start: 1/7/2006 End: 2/11/2006 Contractor Name: n1334@ ppco.co m Rig Release: 2/11/2006 Group: Rig Name: Doyon 1 41 Rig Number: Date From - To ~' Hours ~ Code Code Phase Description of Operations 2/1/2006 00:00 - 00:30 0.50 DRILL PULD PROD3 Continue POOH, Breakout & lay down BHA. Lay down NM IBS Stabilizer (5.30'), NM Float Sub (2.41'), 4 3/4" TM HOC (11.28'),4 3/4" PWD Tool (10.78'), 4 3/4" Slimphase 4 w/ DGR &RES (24.51'), 4 3/4" Smart Stabilizer (3.59'), 4 3/4" DM HOC (8.55'), GP Non MAg Flex Pony Collar (11.54'), 5200 Geo Pilot #002 (16.19') & 6 3/4" Hycalog CRXE 1005H+ bit. Inspected bit & gauged to a 1 / 1, we will rerun. Observed bearing pack in Geo -Pilot seized up. Housing would not spin freely. 00:30 - 01:30 1.00 DRILL PULD PROD3 Make up BHA #9. Make up 6 3/4" Hycalog bit (5RR1) on backup 5200 Geo-Pilot (16.19'), NM IBS Stabilizer (5.30'), NM Float Sub (2.41'), 4 3/4" TM HOC (11.28'),4 3/4" PWD Tool (10.78'), 4 3/4" Slimphase 4 w/ DGR &RES (24.51'), 4 3/4" Smart Stabilizer (3.59'), 4 3/4" DM HOC (8.55'), GP Non MAg Flex Pony Collar (11.54'). 01:30 - 02:45 1.25 DRILL OTHR PROD3 Plug in and upload MWD assembly. 02:45 - 03:15 0.50 DRILL TRIP PROD3 Trip in hole to 1304'. Picking up 3 -Non Mag Flex Drill collars (92.70'), Crossover (1.61'), 3 - 4" HWDP (90.77'), 4 3/4" Drilling jars (28.81'), & 2 - 4" HWDP (60.48'). Total BHA = 369.79' 03:15 - 03:45 0.50 DRILL OTHR PROD3 Rig up and perform Shallow pulse test on MWD assembly. Good test. Break in seals on Geo-Pilot, downlink same. All tests good. 03:45 - 06:45 3.00 DRILL TRIP PROD3 Continue trip in hole from 1304' - 7530' (6226'). Wash from 7471' - 7530' at 94 SPM, 330 GPM, 2750 PSI, Rotating 50 RPM's with 6K torque. 06:45 - 12:00 5.25 DRILL- DRLH PROD3 Continue Directional drilling from 7,530' to 7,845' MD 13,452' TVD. ADT=4.00 hrs. Jar hrs=144.69 PUW=110K, SOW=56K, ROT=80K, TQon/off=6K, 6K Max Gas=43 Units. Max ECD=10.09 Concretions @ 7540'-7555' (15'), 7560'-7562'(2'), 7595'-7604'(9'), 7650'-7660' (10'),665'-7670' (5'),7749'-7824'(75'). Total concretions this tour = 116'. Last survey @ 7494.91' MD, 3451.91 TVD, INC = 89.81 DEG, AZ = 352.77 DEG. 12:00 - 17:00 5.00 DRILL DRLH PROD3 Continue Directional drilling from 7845' to 8359' MD / 3455' TVD. ADT=4.52 hrs. Jar hrs=149.91 PUW=114K, SOW=56K, ROT=80K, TQon/off=6K, 6K Max Gas=46 Units. Max ECD=10.47 SPR#1=25stk/450psi, 35stk/640psi SPR#2=25stk/450psi, 35stk/620psi @ 8030' MD / 3441' TVD 8.7 MW Concretions @ 7834'-7855' (21'), 7869'-7890'(21'), 8009'-8022'(13'), 8132'-8136' (4'), 8150'-8158' (8'). Total concretions this tour = 67'. Last survey @ 8359' MD, 3455 TVD, INC = 86.25 DEG, AZ = 352.59 DEG. Geologist decided to pull back and sidetrack as we were out of zone. 17:00 - 18:00 1.00 DRILL WIPR PROD3 BROOH from 8359' - 7845' (514') for sidetrack. Back ream at 93 SPM - 330 GPM -2850 PSI, 120 RPM's with 6.5K torque. No hole issues. 18:00 - 21:45 3.75 DRILL DRLH PROD3 Cut trough from 7845' - 7855' (10'). NOTE: We have 21 feet of concretions on either side of picked sidetrack point. Trough hole @ 330 GPM"s 2850 SPI, 120 RPM's, and 6K torque. Begin time drilling @ 3 minutes per inch from 7855' -7869' observing no change in inclination and indication of falling back in OLD hole. Pull back to old hole @ 7845'. 21:45 - 23:00 1.25 DRILL DRLH PROD3 Once again, cut trough from 7845' - 7855' at same parameters as above. PU WT = 11 OK, SO WT = 56K, ROT WT =80K. TQ = 6K. 23:00 - 00:00 1.00 DRILL DRLH PROD3 Time drill from 7855'-7856' at 4 minutes per inch, as per DD. ADT = .7 rnntea: znsizuue ~z:za:~urm ,~; ConocoPhillips Alaska Page 1 a of 25 Operations Summary Report Legal Well Name: 1 J-166 Common W ell Name: 1J-166 Spud Date: 1/8/2006 Event Nam e: ROT -D RILLING Start: 1/7/2006 End: 2/11/2006 Contractor Name: n1334@ ppco.co m Rig Release: 2/11/2006 Group: Rig Name: Doyon 1 41 Rig Number: Date ~~ From -To ~i Hours ~'~, Code Cocb Phase Description of Operations 2/1/2006 23:00 - 00:00 1.00 DRILL DRLH PROD3 HRS. TVD = 3452'. 2/2/2006 00:00 - 04:30 4.50 DRILL DRLH PROD3 Continue time drill @ 4 minutes per inch from 7856' - 7870' (14'). Observed inclination @ 92 Degrees indicating bit being in Old Hole. Note: we have a 21' concretion on each side of the attempted sidetrack point. We need to make at least 10' of hole to obtain a good survey. 04:30 - 05:00 0.50 DRILL WIPR PROD3 Pull back up hole to 7658' after dicussing with DD & Geologist to a better sidetrack point. PU WT = 110K, SO WT = 56K. 05:00 - 06:00 1.00 DRILL DRLH PROD3 Work drill string and cut trough from 7670'-7680', at 100 RPM's, 94 SPM, 330 GPM, 2700 PSI with 6K torque. 06:00 - 12:00 6.00 DRILL DRLH PROD3 Time drill from 7680' until verified kicked off and good survey indications. Continue Directional Drill 6 3/4" hole in the "D" lateral to 7835' MD. 3473' TVD. ART = 5.11 HRS. PU WT = 110k, SO WT = 65K, ROT WT = 80K. MAx gas observed = 37 BTU's, Torque on /off bottom = 6K. Max ECD = 10.0 PPG. Jar HRS = 149.80 WOB = 0-2K, 110 RPM's, Pump at 93 SPM, 330 GPM & 2700 PSI. 12:00 - 15:30 3.50 DRILL DRLH PROD3 .Continue Directional drilling from 7835' to 8359' MD / 3,472' TVD. ADT=2.91 hrs. PUW=112K, SOW=55K, ROT=80K, TQ on/off=6.5K, 6.5K Max Gas=64 Units. Max ECD=10.80 Concretions @ 7888'-7889' (1'). NOTE: 8359' =last Hole depth before sidetrack. 15:30 - 19:30 4.00 DRILL DRLH PROD3 Continue Directional drilling from 8359' to 8860' MD / 3478' TVD. ADT=3.09 hrs. Total Jar hrs=156.09 Total ADT = 6.29 HRS PUW=120K, SOW=50K, ROT=80K, TQ on/off=6.5K, 6.5K Max Gas=64 Units. Max ECD=11.65 SPR#1=25stk/480psi, 35stk/650psi SPR#2=25stk/490psi, 35stk/650psi @ 8901' MD / 3479' TVD 8.7 MW Concretions @ 8563'-8568' (5'), 8604'-8609'(5'), 8611'-8613'(2'), 8620'-8622' (2'), 8839'-8844' (5'). Total concretions this tour = 20'. Last survey @ 8835' MD, 3475 TVD, INC = 86.43 DEG, AZ = 358.74 Total K-revs for the day = 27014 19:30 - 20:00 0.50 DRILL DRLH PROD3 Trouble shooting Geo-Pilot Assembly. Indications are Geo-Pilot is not holding desired tool face. Repeat trouble shooting attempts. 20:00 - 20:30 0.50 DRILL DRLH PROD3 Continue Directional. Drill From 8860' - 8901 (41'), while trouble shooting Geo-Pilot Assembly. Indications are Geo-Pilot is not recognizing commands and will not hole desired tool face. Suspect internal electronics failure as per DD. Repeat trouble shooting attempts with no success. 20:30 - 21:00 0.50 DRILL WIPR PROD3 Obtain Slow pump rates. Monitor well -static. 21:00 - 00:00 3.00 DRILL WIPR PROD3 Attempt to POOH on elevators, observe well swabbing. BROOH to 6817' (2084') @ 93 SPM , 330 GPM, 2800 PSI, 120 RPM's with 6.5K torque @ 60 -75 ft/ hr. 2/3/2006 00:00 - 02:00 2.00 DRILL WIPR PROD3 Continue BROOH from 6817' - 5150' (1667'). Pull drilling assembly through window area @ 5005' with no issues. 02:00 - 04:00 2.00 DRILL TRIP PROD3 Continue POOH on elevators observing hole taking proper fill. Rack back 4" HWDP, Drilling Jars, and 1 stand Non Mag Flex Drill Collars. 04:00 - 05:00 1.00 DRILL OTHR PROD3 Plug in and down load MWD assembly. 05:00 - 06:00 1.00 DRILL PULD PROD3 POOH, breakout & lay down BHA #9. Lay down Lay down NM IBS Stabilizer (5.30'), NM Float Sub (2.41'), 4 3/4" TM HOC (11.28'),4 3/4" PWD Tool (10.78'), 4 3/4" Slimphase 4 w/ DGR & RES (24.51'), 4 3/4" Smart Stabilizer (3.59'), 4 3/4" DM HOC (8.55'), GP Non MAg Flex Pony Collar (11.54'), 5200 Geo Pilot #002 (16.19') & 6 3/4" Hycalog CRXE 1005H+ bit. Inspected bit & gauged to a 1 / 1/ WT / A ! X / I / NO ~, ConocoPhillips Alaska Page ~~ ot25 Operations Summary Report Legal Well Name: 1 J-166 Common Well Name: 1J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Dafe From - To Hours Code ~ Code -- Phase 2/3/2006 05:00 - 06:00 1.00 DRILL PULD PROD3 06:00 - 06:30 0.50 DRILL PULD PROD3 06:30 - 08:00 1.50 DRILL PULD PROD3 08:00 - 09:15 1.25 DRILL OTHR PROD3 09:15 - 09:30 0.25 DRILL TRIP PROD3 09:30 - 10:00 0.50 DRILL OTHR PROD3 10:00 - 12:00 2.00 DRILL TRIP PROD3 12:00 - 12:30 0.50 DRILL TRIP PROD3 12:30 - 15:00 2.50 DRILL TRIP PROD3 15:00 - 00:00 I 9.001 DRILL ~ DRLH I PROD3 12/4/2006 00:00 - 01:30 1.50 DRILL DRLH PROD3 01:30 - 02:00 0.50 DRILL DRLH PROD3 02:00 - 12:00 1 10.001 DRILL ~ DRLH ~ PROD3 Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations / DTF. Clean & Clear floor area. Send tools outside. PJSM, Discuss safety issues and procedure for BHA make up. Make up BHA #10. MU 6 3/4" Security FSF2641 bit w/ 3 x 21 Jets TFA = 1.015sq in (1.27'), 5200 Geo Pilot #002 (16.22'), NM IBS Stabilizer (5.30'), NM Float Sub (2.41'), 4 3/4" TM HOC (11.28'),4 3/4" PWD Tool (10.78'), 4 3/4" Slimphase 4 w/ DGR & RES (24.51'), 4 3/4" Smart - Stabilizer (3.59'), 4 3/4" DM HOC (8.55'), GP Non MAg Flex Pony Collar (11.54'). Plug in and Up Load MWD assembly. Trip in hole making up 4" HWDP, Drilling Jars, and 1 stand Non Mag Flex Drill Collars. Total BHA = 369.82'. Perform Shallow pulse test and break in Geo-Pilot bearings @ 81 SPM, 290 GPM, 1300 PSI, and 50 RPM's. Good test. Trip in hole from 455' - 4949' (4504'). PU WT = 90k, SO WT = 70K. PJSM, crew change -new crew. Fill drill string, and inspect saver sub on Top Drive. Continue trip in hole from 4949' - 8901' (3952'). Observe hole taking proper hole fill. Work assembly through window area with no issues. Continue RIH to 8873' MD. Wash & ream from 8873' - 8901'. Shoot survey @ 8873'. Continue Directional drilling from 8901' to 9750' MD / 3493' TVD: ADT=6.05 hrs. Total Jar hrs=162.14 Total ADT = 6.05 HRS PUW=125K, SOW=50K, ROT=85K, TQ on/off=6.5K, 6.5K Max Gas=138 Units. Max ECD=10.45 SPR#1=25stk/ 530psi, 35stk! 730psi SPR#2=25stk/ 530psi, 35stk! 730psi @ 9244' MD / 3486' TVD 8.7 MW Concretions @ 8900'-8903' (3'), 9112'-9116'(4'), 9359'-9364'(5'), 9365'-9374' (9'), 9376'-9383' (7'), 9399'-9401' (5'), 9407'-9411' (4'), 9420'-9430' (10'), 9574'-9579' (4'), 9581'-9588' (7'), 9590'-9595' (5'). Total concretions this tour = 61'. Last survey @ 9675' MD, 3492 TVD, INC = 89.98 DEG, AZ = 354.87 Total K-revs for the day = 89530 Continue Directionakl Drill 6 3/4" D lateral from 9750' - 9898'. (148'). ART = 1.08 HRS. Trouble Shoot MWD. Could not get a good signal, and surveys were false & misleading. Repeat survey attempts until verifying tool working correctly and we had good surveys. Continue Directional drilling from 9898' to 10926' MD / 3455' TVD. ADT=7.63 hrs. Total Jar hrs=176.90 Total ADT = 8.71 HRS, Total Bit Hrs = 14.76. PUW= 125K, SOW= 40K, ROT= 80K, TQ on/ofF=7K, 6K Max Gas=88 Units. Max ECD=11.55 SPR#1=25stk/ 600psi, 35stk/ 790psi SPR#2=25stk/ 620psi, 35stk/ 800psi @ 10269' MD / 3460' TVD 8.7+ MW Concretions @ 9574'-9579' (5'), 9581'-9588'(7'), 9590'-9595'(5'), 9740'-9755' (15'), 9758'-9778' (20'), 9932'-9935' (3'), 10164'-10169' (5'), 10251'-10255' (4'), 10391'-10409' (18'), 10468'-10470' (2'), 10560'-10571' (11'), 10678'-10685" (7'). Total concretions this tour = 102'. Pump A 30 BBL Hi Visc Weighted sweep @ 10552', observed a 5% increase in cuttings upon return. Survey @ 10422' MD, 3453 TVD, INC = 89.01 DEG, AZ = .96 NOTE :Drilled through a Fault @ 10160' MD, 3469' TVD, with an 81' Throw up. ConocoPhillips Alaska Page 20 of 25 Operations Summary Report Legal Well Name: 1 J-166 Common Well Name: 1 J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date i From - To Hours Code ','Code Phase 2/4/2006 02:00 - 12:00 ~ 12:00 - 00:00 12.00 DRILL DRLH PROD3 ~ 2/5/2006 ~ 00:00 - 12:00 ~ 12.00 ~ DRILL ~ DRLH ~ PROD3 12:00 - 13:45 1.751 DRILL ~ DRLH ~ PROD3 13:45 - 15:30 1.75 DRILL CIRC PROD3 15:30 - 00:00 8.50 DRILL WIPR PROD3 2/6/2006 ~ 00:00 - 02:15 ~ 2.25 ~ DRILL ~ WIPR ~ PROD3 02:15 - 03:30 ~ 1.25 ~ DRILL ~ CIRC ~ PROD3 03:30 - 04:45 1.25 RIGMNT RSRV PROD3 04:45 - 07:30 2.75 DRILL WIPR PROD3 07:30 - 12:00 4.50 DRILL REAM PROD3 Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations Continue Directional drilling from 10926' to 12000' MD / 3489' TVD. ADT=8.09 hrs. Total Jar hrs=184.99 Total ADT = 16.80 HRS, Total Bit HRS = 22.85. PUW= 145K, SOW= 35K, ROT= 95K, TO onloff=9-10K, 8K Max Gas=61 Units: Max ECD=11.51 SPR#1=25stk/ 680psi, 35stk/ 830psi SPR#2=25stk/ 630psi, 35stk/ 850psi @ 11292' MD / 3467' TVD. 8.7+ MW Concretions @ 11010'-11017' (7'), 11220'-11225' (5'), 11350'-11357 ' (7'), 11475'-11481' (6'), 11485'-11493' (8'), 11555'-11561' (6'), 11566'-11573' (7'), 11590'-11594' (4'), 11708'-11716' (8'). Total concretions this tour = 58'. Pump A 30 BBL Hi Visc Weighted sweep @ 11473', observed a 20% increase in cuttings upon return. Survey @ 11892' MD, 3488 TVD, INC = 88.61 DEG, AZ = 1.08 Total K-revs for the day = 74338 Continue Directional drilling from 12000 ' to 12866' MD / 3525' TVD. ADT=8.97 hrs. Total Jar hrs=193.96 Total ADT = 25.77 HRS, Total Bit HRS = 31.82. PUW= 177K, SOW= 35K, ROT= 106K, TO on/off=9-10K, 9.5K Max Gas=163 Units. Max ECD=11.75 SPR#1=25stk/ 740psi, 35Stk/ 900psi SPR#2=25stk/ 760psi, 35stk/ 910psi @ 12198' MD / 3479' TVD. 8.7+ MW Concretions @ 12003'-12018' (15'), 12023'-12037' (14'), 12039'-12058' (19'), 12556'-12559' (3'), 12566'-12570' (4'), 12611'-12614' (3'), 12670'-12676' (6'), 12708'-1.2717' (9'). Total concretions this tour = 73'. Continue Directional drilling from 12866 ' to 12994' MD / 3530' TVD. Well TD'd as per Geologist & Directional Driller. ADT=1.76 hrs. Total Jar hrs=195.72 Total ADT = 27.53 HRS, Total Bit HRS = 33.58. PUW= 180K,~ SOW= 35K, ROT= 110K, TO on/off=9-10K, 9.5K Max Gas=155 Units. Max ECD=11.80 g,7+ MW. Concretions @ 12936'-12940' (4'), 12946'-12954' (8'). Total concretions this tour = 12'. Survey @ 12994' MD, 3530.64 TVD, 86.99 Deg INC., 3.93 Deg AZ. Total K-revs for the day = 120717. Total AVG ROP for bit = 122' FtlHr Reciprocate & Rotate Drill String while CBU 2 times @ 300 GPM - 3900 PSI. Pump up final survey. Montor well -static. BROOH form 12994' - 7004' (5990'). Back ream at rates of 20 - 80 ft/minute @ 330 GPM - 3900 PSI to start, and then 2800 PSI at 7004'. 120 RPM's, with 7K - 9K torque. Continue BROOH at rates of 60 - 80 ft/minute @ 330 GPM - 2800 PSI at 120 RPM's, with 7K - 9K torque. Pulled assembly through window area with no issues. Pump a 30 BBL Hi Vis Weighted sweep, and circulate 3 bottoms up to verify clean hole conditions. Pump @ 330 GPM - 2550 PSI. Observed 5-10 % increase in cutting upon return of sweep. PJSM, Discuss safety issues and procedure for Slip & Cut. Slip & Cut 68' of drilling line. Inspect brakes & Top Drive. Trip back in hole on elevators, until run out of downweight @ 10087'. Observed good hole conditions and no issues. Make up Top Drive on each stand and wash & ream from 10087' - 12928' (2841'). Pump @ 44 SPM -1000 PSI Rotating @ 100 RPM's with ~.~ ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 J-166 Common Well Name: 1 J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To ' Hours Code Sub Code 2/6/2006 ~ 07:30 - 12:00 4.50 ~ DRILL I REAM 12:00 - 14:45 14:45 - 16:00 16:00 - 22:00 22:00 - 23:30 23:30 - 00:00 2/7/2006 00:00 - 00:15 00:15 - 01:15 01:15 - 02:15 02:15 - 02:30 02:30 - 06:45 06:45 - 07:15 07:15 - 07:45 07:45 - 11:00 11:00 - 12:00 12:00 - 13:00 13:00 - 13:45 Phase PROD3 2.751 DRILL I CIRC PROD3 1.251 DRILL I CIRC I PROD3 6.00 ~ DRILL ~ TRIP 1 PROD3 1.50 ~ DRILL ~ PULD ~ PROD3 0.50 DRILL OTHR CMPLT3 0.25 DRILL SURV CMPLT3 1.00 DRILL PULD CMPLT3 1.00 DRILL PULD CMPLT3 0.251 DRILL I PULD I CMPLT3 4.251 DRILL (TRIP (CMPLT3 0.501 DRILL I (CMPLT3 0.501 DRILL 1 CIRC 1 CMPLT3 3.251 DRILL (TRIP (CMPLT3 1.001 DRILL 1 PULD 1 CMPLT3 1.001 DRILL I PULD I CMPLT3 0.751 CASE I RURD 1 CMPLT3 Start: 1 /7/2006 Rig Release: 2/11/2006 Rig Number: Page 2~1 of 25 Spud Date: 1/8/2006 End: 2/11 /2006 Group: Description of Operations 7K Torque. We were able to TIH on elevators from 11294' - 11496' (202') with 35 - 40K downweight, and no pump or rotation needed. Continue wash & ream from 12928'-12994' MD (66') 3530' TVD. Pump a 30 BBL Hi Vis Weighted sweep, and circulate 3 bottoms up to verify clean hole conditions While reciprocat & rotate drill string. Pump @ 82 SPM -300 GPM, 4000 PSI. 120 RPM's, 7-8K torque. PU WT = 180K, SO WT = 35K, Rotating WT = 105K. Monitor well -static. Held PJSM. Discussed Safety & Spill Issues. Assigned a Spill Champion for Displacement. Displace well with 8.7 PPG SFMOBM @ 300 GPM - 3950 PSI. Observe drill string torque up and stalled@ 11 K, 100 strokes short of displacement. Finish Displacement. Suspect difference in Lubricity from MOBM would not allow free rotation without excessive torque. POOH on elevators from 12994' - 369'. (12625'). Observed pulling up to 40K over at times initially off bottom, and hole taking proper fill. No issues while POOH. Breakout & lay down BHA # 10. Layed down 4" HWDP, Drilling Jars, and 1 stand Non Mag Flex Drill Collars, Stabilizer & Float Collar. Plug in and down load MWD assembly. Total K-Revs = 46783 Continue Download MWD assembly. Breakout & lay down remaining BHA #10. Lay down 6 3/4" Security FSF2641 bit w/ 3 x 21 Jets TFA = 1.015sq in (1.27'), 5200 Geo Pilot #002 (16.22'), NM IBS Stabilizer (5.30'), NM Float Sub (2.41'), 4 3/4" TM HOC (11.28'),4 3/4" PWD Tool (10.78'), 4 3/4" Slimphase 4 w/ DGR & RES (24.51'), 4 3/4" Smart Stabilizer (3.59'), 4 3/4" DM HOC (8.55'), GP Non MAg Flex Pony Collar (11.54'). Grade Bit @ 1 / 1 / ER / A/X/I/NO/TD. Clear & Clean rig Floor Area. Pull 31 Lo-Tads to floor. Held PJSM. Discuss Safety issues and installation of Lo-Tads. Make up BHA # 11. MU Baker Retrieving Hook (7.50'), 1 - jnt of 3 1/2" HWDP (28.84'), 4 3/4" Float Sub (2.41'), 4 3/4" Bumper Jar (7.87'), 4 3/4" Oil Jar (11.14'), Crossover (1.04') and 3 -stands of Hybrid Push Pipe (270.06'). Trip in hole from 328' -5000' (4672'). Install 31 total Lo-Tads on stands while RIH. PU WT = 128K, SO WT =98K. Observe hole taking proper fill Locate & wash retrieving slot pumping @ 4 BPM - 700 PSI. Attempt to engage slot. Work drill string installing 3/4 RH turns in string until observe engaged whipstock slot. Pull up to verify and fire jars with 75K overpull, whipstock free. Increase in upweight 5K. Pull up 30' no swabbing observed. Circulate bottoms up @ 7 BPM - 72 SPM - 1400 PSI. No gas or fluid loss Monitor well -static. POOH from 4972' -328' (4644'). Observe hole taking proper Hole fill. Rack back 3 stands of Hybrid Push pipe, Breakout & lay down retrieving Hook BHA. Layed down Baker Retrieving Hook (7.50'), 1 -jnt of 3 1/2" HWDP (28.84'), 4 3/4" Float Sub (2.41'), 4 3/4" Bumper Jar (7.87'), 4 3/4" Oil Jar (11.14'), Crossover (1.04') Breakout & Lay down Whipstock and space out assembly. Inspect Whipstock slide. Indications of milling full 12' on slide. Seals looked good. Clear & Clean rig floor area. Pull tools to floor. RU Liner running tools. rnncea: u_i ai~wo ic~a: io rm ConocoPhillips Alaska Page 22 of 25 Operations Summary Report Legal Well Name: 1 J-166 Common Well Name: 1J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Dafe ~ From - To '~ Hours ~ Code Sub Phase 'Code 2/7/2006 13:45 - 17:30 ~ 3.751 CASE RUNC CMPLT3 17:30 - 18:15 18:15 - 22:00 22:00 - 00:00 2/8/2006 00:00 - 00:15 00:15 - 00:45 00:45 - 02:30 02:30 - 03:00 03:00 - 06:00 06:00 - 07:00 07:00 - 07:30 07:30 - 12:00 12:00 - 15:00 0.75 RIGMNT RGRP CMPLT3 3.75 CASE RUNC CMPLT3 2.00 I CASE I RUNC CMPLT3 0.251 CASE RUNC CMPLT3 0.501 CASE RUNL CMPLT3 1.751 CASE I RUNL I CMPLT3 0.50 ~ CASE ~ RUNL ~ CMPLT3 Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations PJSM, Discuss Safety Issues and procedure to run 4 112" Liner assembly. Make up 31/2" Bent joint with Guide shoe & crossover. Continue RIH picking up 4 1/2" liner. Avg. make up torque = 3500 ft/Ibs. Install total of 250 Hydroform Centralizers on each joint except constrictorjnts. Constrictors installed as to be spaced out at 10505', 9806', 8565', 8347', 8005', and 7825'. Total Slotted joints ran = 217, length = 6681.05'. Total Blank joints ran = 39. Total length = 1204.07'. 192 total stop rings run on first 160 joints, and last 32 joints. Trouble shoot hydraulic problem with Power Tongs. Motor failed. Lay down bad tings, and RU backup set. Continue run 4 112" Liner to 7960'. PU WT = 86K, SO WT = 55K. Obtain TAD parameters every 10 joints on TIH. PJSM. Discuss Safety issues and procedure for making up Slimhole MWD assembly. Pull tools to floor and RU tongs. Make up Slimhole MWD assembly as per MWD & BOT hands. Orient MWD to 180 Degrees out from Hook Hanger hook. Continnue Making up Slim Hole MWD Assembly, and Hook Hanger. PU WT = 87K, SO WT = 60K. Pick up 1 stand of DP, perform shallow pulse test @ 33 SPM, 117 GPM, 600 PSI. Good test. Continue run liner on Drill pipe from 7960' - 8359' (399'). Observed Guide shoe tracked ion to Old hole and bottomed out. Set down 10K. POOH with 5 stands of Drilll pipe, and stand back 3 stands of 4 1/2" liner. With guide shoe above kick off point, rotate 3.5 right hand turns in liner. PU WT = 97K, SO WT = 55K. Run in hole with 4 1/2" liner from derrick and continue with Drill Pipe. NOTE: We did not breakout MWD asembly as it was stood back in Derrick with Hook Hanger. Observed Guide shoe assembly in new hole. 3.00 CASE RUNL CMPLT3 Continue RIH with liner on drill pipe from 8444' - 12906'. No issues running through fault area at 10160'. Tagged bridge at 12906'. PU WT = 187K. 1.00 CASE RUNL CMPLT3 Work string to observe getting past bridge area, and continue to RIH, observing weight falling off, and having to pick up and work through spots. Locate bottom of window @ 5019', working string to allow Hook Hanger to Hook. Obtain good MWD reading @ 20 Deg. L, set Hook on window @ 5019' MD, and observe survey @ 8 deg. L two times. PU 20', turn string 180 Deg. Work torque to Hook ,and slack off 8' past bottom of window. Observe difficulty in moving string as the weight did not allow us to move freely. Pull up hole 30'. Install 180 Deg turn in string. Work torque down to Hook. MWD survey at 8 Deg. Left. Set Hook Hanger with better movement ih string as we worked it, observing MWD survey @ 6 Deg Right when set. Repeat same operation with the same 6 Deg. Right survey 2 times to confirm definite Hook Hanger Hooked on window @ 5019' MD = 2' Low . UP & Down weights while working string 175-200K up, 50 -30K down. 0.50 CASE RUNC CMPLT3 Rig up, drop 29/32" ball. Pump ball down @ 3 BPM - 700 PSI until observe ball seated @ 448 strokes. Bring pressure up to 2950 PSI, wait 3 minutes, continue bring pressure up to 4200 PSI to shear ball seat. Bleed all pressures. Pick up to verify free of Hook Hanger and loss of weight. PU WT = 125K, SO WT = 105K. 4.50 CMPLTN TRIP CMPLT3 POOH with Drill pipe, inspecting & removing all Lo-Tads, and Super Sliders. Racking back drill pipe in derrick to drain. Crew Change 3.00 CMPLTN TRIP CMPLT3 Continue POOH standing back DP, inspecting and removing all rnnwa: u_i oi~u~o ic~a: io nvi ConocoPhillips Alaska Page 23 of 25 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date "' From - To 2/8/2006 ~ 12:00 - 15:00 15:00 - 15:45 15:45 - 17:00 17:00 - 18:00 18:00 - 18:30 18:30 - 19:30 19:30 - 20:00 20:00 - 00:00 2/9/2006 00:00 - 09:15 09:15 - 09:45 09:45 - 10:00 10:00 - 10:15 110:15 - 11:15 11:15 - 12:00 12:00 - 15:45 15:45 - 17:30 17:30 - 18:00 18:00 - 00:00 2/10/2006 00:00 - 00:30 00:30 - 01:00 01:00 - 02:30 1 J-166 1J-166 Spud Date: 1/8/2006 ROT -DRILLING Start: 1/7/2006 End: 2/11/2006 n1334@ppco.com Rig Release: 2/1.1/2006 Group: Doyon 141 Rig Number: i Hours Code Sub Phase Description of Operations Code 3.00 CMPLTN TRIP CMPLT3 Lo-Tads & Super Sliders. Floor hand pinched fingers between Iron Roughneck, and Stump. Send hand to Medic immediately. 0.75 CMPLTN SFTY CMPLT3 Safety stand down on rig, Review & investigate incident with crew. 1.25 CMPLTN TRIP CMPLT3 Lay down last Lo-Tad. Stand back last stand. Clean off all Lo-Tads for SPCC, load & send outside. Clean off all sliders and send outside. Clear & clean floor area. 1.00 CMPLTN TRIP CMPLT3 Rig up, Breakout, inspect & lay down all Liner running tools and MWD assembly. All tools looked good. 0.50 CMPLTN OTHR CMPLT3 Rig up Mouse hole for laying down drill string. PJSM. Discuss safety issues and procedure for laying down drill pipe from derick. 1.00 CMPLTN SFTY CMPLT3 Incident investigation of accident on floor. Re-enact accident and inspect all equipment. All day & night supervisors participated. Discuss accident & prevention with crew. Change out hinge pins on doors of Iron Roughneck. 0.50 CMPLTN OTHR CMPLT3 Pull barrells of thread protectors to floor, rig. up floor area and pipe shed to lay down drill pipe. 4.00 CMPLTN OTHR CMPLT3 Lay down dril pipe from derrick. 9.25 CMPLTN OTHR CMPLT3 PJSM. Discuss Safety issues and procedure to lay down DP using mousehole.. Continue lay down 74 stands of DP, 15 Stands of Hybrid Push Pipe, and 7 stands of 4" HWDP. 0.50 CMPLTN OTHR CMPLT3 Clear & Clean rig floor area. Send tools out. 0.25 CMPLTN OTHR CMPLT3 PJSM. Discuss safety issues and forward plan with crew. Changing out Geo-Span unit, Rigging up 4 1/2" Liner running equipment, & Running 4 1/2" Tbg in hole. 0.25 CMPLTN OTHR CMPLT3 Change out Geo-span unit on rig floor. Send old one to town for inspection. 1.00 CMPLTN PULD CMPLT3 Rig up 4 1/2" Tubing running equipment. Double stack tongs. 0.75 CMPLTN PULD CMPLT3 Run 4 1/2" Tubing in hole to 300'. Crew Change 3.75 CMPLTN PULD CMPLT3 PJSM, with crew. Discuss Safety issues and forward plan as above. Continue RIH with a total of 123 joints of 4 1/2" tubing. 1.75 CMPLTN PULD CMPLT3 POOH, rack back 41 stands of 4 1/2" tubing. 123 joints. 0.50 CMPLTN NUND CMPLT3 Rig up bushing puller. BOLDS & pull wear bushing. 6.00 CMPLTN RUNT CMPLT3 Pull Centrilift equipment to rig floor. Stack, count & record clamps. PJSM with entire rig team & Centrilift. Discuss safety issues including well control, and all pinch points & lifting procedures for equipment. Pull ESP cable to floor and hang sheave. Make up Baker Centrilift 5.62" OD 418 HP KMHFER 2610 Motor (33.85'), with 4.60" A-Well pump gauge (2.11') and 6" OD centralizer (2.00'). MU 5.13" Tandem Seal Section GSB 3 DB AB/HSN PFSA (13.80'),5.13" OD TTC Crossover w/ Screen Intake with 4-1/2" IBT pup (20.43'). Install oil, and CPAI witness free rotation of motor, utilizing CPAI checklist for installation of ESP assembly. SIMOPS: Change out mud pump liners to 6" in #1 pump. 0.50 CMPLTN RUNT CMPLT3 PJSM with entire rig team & cehtrilift. Discuss safety issues including well control, and all pinch points & lifting procedures for equipment.Continue running ESP Completion. Pick up #1 & #2 joints of 4 1/2" tubing.Start to PU A-Well Discharge Pressure sub. 0.50 CMPLTN RUNT CMPLT3 Observed that the OD of the Discharge Pressure sub .measured at 6 3/8" OD. The ESP line OD = 5/8" Total = 7" OD. 7 5/8 casing ID = 6.875". Discuss options with town. Decision to run completion without it. 1.50 CMPLTN RUNT CMPLT3 . Lay down Pressure sub & send out. Install 4 1/2" pup joint in place of Pressure sub. 9.87' long. Secure & plug unused "I" Line from A-well pump. Printed: 2/13/2006 12:29:18 PM ConocoPhillips Alaska Page 24 of 25 Operations Summary Report Legal Well Name: 1J-166 Common W ell Name: 1J-166 Event Nam e: ROT -D RILLIN G Contractor Name: n1334@ ppco.co m Rig Name: Doyon 1 41 Date. ~ From - To ~ Hours Code Code Phase 2/10/2006 02:30 - 03:00 0.50 CMPLTN RUNT CMPLT3 03:00 - 04:30 1.50 CMPLTN RUNT CMPLT3 04:30 - 05:00 0.50 CMPLTN RUNT CMPLT3 05:00 - 06:15 1.25 CMPLTN RUNT CMPLT3 06:15 - 07:00 0.75 CMPLTN RUNT CMPLT3 07:00 - 07:30 0.50 CMPLTN PULD CMPLT3 I 07:30 - 12:00 4.50 CMPLTN PULD CMPLT3 12:00 - 14:00 2.00 CMPLTN PULD CMPLT3 14:00 - 16:45 2.75 CMPLTN RUNT CMPLT3 16:45 - 20:15 3.50 CMPLTN RUNT CMPLT3 20:15 - 21:00 0.75 CMPLTN RUNT CMPLT3 21:00 - 00:00 3.00 CMPLTN RUNT CMPLT3 2/11/2006 00:00 - 01:30 1.50 CMPLTN RUNT CMPLTN 01:30 - 02:15 0.75 CMPLTN RUNT CMPLTN 03:30 - 04:15 0.75 CMPLTN NUND CMPLTN 04:15 - 04:30 0.25 CMPLTN NUND CMPLTN Spud Date: 1/8/2006 Start: 1/7!2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations Conduct Insulation test on ESP Line. Good Test. Continue RIH with 4 1/2" tubing. Install GLM's # 1 & #2 to be positioned in well at depths of 3215' & 2606' as planned. Avg Make up torque on tubiing = 3000 Ft! lbs. Conduct Insulation test on ESP Line. A-well Representative indicated a bad test, but advised continu running in hole as he believed the test unit he used was faulty. He repaired unit while continue RIH. Continue RIH with 4 1/2" tubing to 1775' . Conduct Insulation test on ESP Line. A-well Representative indicated a bad test, after repairing test unit and verifying bad test on A-Well pump. Recommend POOH to A-Well Pump. PJSM. Discuss safety issue & procedure on POOH, and prepare matting boards with pit liner for ESP line, for Spill prevention. POOH with 4 1/2" ESP completion tubing. Removing all Clamps, SS Bands. Standing back tubing in Derrick, and lay down GLM's. Disconnect ESP line from motor. Attempt to break out centrailizer, threads galled. Remove A-Well Pump Gauge. Crew Change. Observe "I" line was damaged when initially clamped up to motor assembly. Continue remove A-Well Pump gauge from Motor. Remove unused & damaged "I" line. Install new A-Well Gauge & Centralizer. Service Motor. Re-attach ESP line, service seals, and test equipment. RIH with Motor Assembly. Pick up 2 joints of 4 1/2" tubing from shed, 10' pup. RIH making up GLM's as mentioned above, installing cannon clamps on every other 'joint of tubing as per Centrilift Rep. RIH back to 1775'. Continue RIH with ESP conpletion assembly on 4 1/2" Tbg. Install Cannon Clamps on every otherjoint as per Centrilift Rep. Pick up GLM's #3 & #4, spaced out to be located in well at 148', and 94' as planned: Pick up landing joint. MU Vetco Gray 11" x 4 112" Manger with 4.909" MCA top with 4 1/2" tubing joint made up on it, (30.00'). Install TWC into hanger for RIH. MAke up joint to string and obtain UP WT = 82K, SO WT = 68K. Located hanger close to floor for Slice as per Centrilift Rep. Used a total of 68 Cannon Clamps, 4 stainless steel bands, 3 Protectolizers, and 2 Flat Guards. Splice ESP cable to hanger pigtail as per Centrilift Rep. SIMOPS:. Clear & Clean Floor area. Lay down all tubing running equipment. Count used clamps. Lay down Sheave with unused ESP line. Clean up all pit liner on matting boards and prepare Spooling unit for removal. Observed NO SPILLS on ground from ESP line & Spooling Unit. Continue Splice ESP cable to hanger pigtail as per Centrilift Rep. SIMOPS:. Clear & Clean Floor area. Lay down all tubing running equipment. Count used clamps. Lay down Sheave with unused ESP line. Rig down Spooling unit, prepare to move unit. Make up Pigtail ESP to Penetrator on Hanger. Band line to tubing 7 perform Insulation test on ESP line. Good test. RIH land Tbg Hanger as per Vetco Gray Rep. UP WT =82K, SO WT = 70K. Ensure hanger seated. RILDS. Perform packoff tests on upper & lower packoff seals. Test to 250 PSI LOW, 5000 PSI High. 10 Minutes each. Witnessed by Co. Rep. Nipple down BOP stack, lines and Flow nipple. Perform insulation test on ESP line after Nipple Down. Good Test. rnntea: L~aizuue ~z:za: iu rm ConocoPhillips Alaska Page 25 of 25 i Operations Summary Report Legal Well Name: 1 J-166 Common Well Name: 1J-166 Spud Date: 1/8/2006 Event Name: ROT -DRILLING Start: 1/7/2006 End: 2/11/2006 Contractor Name: n1334@ppco.com Rig Release: 2/11/2006 Group: Rig Name: Doyon 141 Rig Number: Date 'From- To Hours I, Code Sub '.Code Phase Description of Operations 2/11/2006 04:30 - 06:30 2.00 CMPLTN NUND CMPLTN Nipple up Adapter Flange & Tree. Install Actuator valve. Perform Insulation test on ESP line afrter NU. Final test. Good. 06:30 - 07:00 0.50 CMPLTN NUND CMPLTN Fill Tree with Diesel. Rig test equipment & test tree to 250 PSI LOW, 5000 PSI High. Good Test. 07:00 - 07:30 0.50 CMPLTN FRZP CMPLTN PJSM with crew and Little Red Hot Oil Reps. Discuss Safety issues and procedure to pump freeze protect Diesel as well as Spill prevention. Rig up Little Red, test lines to 2500 PSI. Good test. SIMOPS: Rig up Scaffold in cellar. Pull TWC. 07:30 - 08:30 1.00 CMPLTN FRZP CMPLTN Freeze protect well by pumping 180 BBLS of Diesel down annulus with returns to tubing, and pits. Pump at 4 BPM - 1175 PSI. 08:30 - 09:00 0.50 CMPLTN FRZP CMPLTN Blow down & rig down Little Red. Secure Tree closing valves. 09:00 - 10:00 1.00 CMPLTN OTHR CMPLTN Rig up Lubricator & install BPV as per Vetco Gray Rep. Rig down Lubricator & Scaffold. Clean out cellar area with Super Sucker. 10:00 - 11:15 1.25 MOVE DMOB MOVE Clean out Rockwasher & last pit. Prepare Rig for Move. 11:15 - 12:00 0.75 MOVE DMOB MOVE Blow down all Steam, water lines, and disconnect all neccessary Hydraulic, air, water, and steam lines. Rig Released at 1200 HRS for move Rig to 1J-159. rnncea: zn art~uo ic~a: w rm Halliburton Company `~;: Global Report C~uupan~: ConocoPhillipsAlaska Inc. I)atr. 3i6~006 time: 14906 t'a!,e: l IicI~L• Kuparuk River Unit C~~-urdinalc~AI') Itc ~cicucc: VVell_ 1J-l E6 Tru e North tiitc: Kuparuk 1J Pad vertical (lll)) ltcfc rcucc: 1J-166L2 109.0 ~V'cll: 1J-166 ~cctiun I~SI ltcfcrc ucc: 4Nell %O OON.0-OOEQOOA~ii \1'ell~ialli: 1J-166L2 tiun~c~ ('alculation 1lcthud: PAinimum Curva'u re I)h: Oraele Survey: Start Date: Company: Engineer: Tool: Tied-to: Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: Kuparuk 1J Pad Site Position: Northing: 5945919.64 ft Latitude: 70 15 46.258 N From: Map Easting: 558789.95 ft Longitude: 149 31 29.007 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergen ce: 0.45 deg Well: 1 J-166 Slot Name: Well Position: +N/-S -227.23 ft Northing: 5945691.74 ft Latitude: 70 15 44.023 N +E/-W -89.01 ft Easting : 558702.73 ft Longitude: 149 31 31.59.7 W Position Uncertainty: 0.00 ft Wellpath: 1J-166L2 Drilled From: Tie-on Depth: 1J-166L2P61 7618.38 ft Current Datum: 1 J-166L2 : H eight 109.00 ft Above System Datum: Mean Sea Level Magnetic Data: 2/5/2006 Field Strength: 57564 nT Declination: Mag Dip Angle: 24.19 deg 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 0.00 Survey Program for Definitive Wellpath Date: 3/6/2006 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 50.00 723.00 1 J-166 gyro (50.00-723.00) (0) CB-GYRO-SS Camera based gyro single shot 755.46 4976.26 1 J-166 (755.46-6312.36) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5005.00 7618.38 1 J-166L2P61 (5005.00-8275.46) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7680.00 12957.64 1J-166L2 (7680.00-12957 .64) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey ~u~ ~uc~ ~,~~~~ r~u s ~~nl~ ~;~ i~~~~ ~i:~i,~ ~la~,f: 1~~~,i ft deg rieg ft ft ff ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945691.74 558702.73 ~ TIE LINE 50.00 0.11 163.00 50.00 -59.00 -0.02 0.01 5945691.72 558702.74 CB-GYRO-SS 100.00 0.22 163.87 100.00 -9.00 -0.16 0.05 5945691.58 558702.78 CB-GYRO-SS 200.00 0.16 96.82 200.00 91.00 -0.36 0.24 5945691.38 558702.97 CB-GYRO-SS 300.00 0.15 129.50 300.00 191.00 -0.46 0.48 5945691.28 558703.21 CB-GYRO-SS 400.00 0.22 89.10 400.00 291.00 -0.54 0.77 5945691.21 558703.51 CB-GYRO-SS 448.00 0.37 50.51 448.00 339.00 -0.44 0.98 5945691.31 558703.72 CB-GYRO-SS 540.00 0.70 272.11 540.00 431.00 -0.23 0.65 5945691.52 558703.38 CB-GYRO-SS 630.00 4.15 258.63 629.90 520.90 -0.85 -3.09 5945690.86 558699.64 CB-GYRO-SS 723.00 9.11 253.90 722.25 613.25 -3.56 -13.47 5945688.08 558689.29 CB-GYRO-SS 755.46 10.23 253.96 754.25 645.25 -5.07 -18.71 5945686.53 558684.06 MWD+IFR-AK-CAZ-SC 800.29 11.50 250.47 798.28 689.28 -7.66 -26.75 5945683.87 558676.04 MWD+IFR-AK-CAZ-SC 844.21 11.01 247.29 841.35 732.35 -10.74 -34.74 5945680.73 558668.07 MWD+IFR-AK-CAZ-SC 934.25 12.79 .252.02 929.46 820.46 -17.14 -52.16 5945674.19 558650.71 MWD+IFR-AK-CAZ-SC 1025.65 14.38 250.54 1018.30 909.30 -24.05 -72.48 5945667.13 558630.44 MWD+IFR-AK-CAZ-SC 1123.61 16.73 248.45 1112.66 1003.66 -33.28 -97.07 5945657.71 558605.93 MWD+IFR-AK-CAZ-SC Halliburton Company.,`: Global Report C"umpan~~: ConocoPhilli~.~s Alaska Inc. Uatr. 3;6/2006 7~imc: 14.~9~05 Pa_~c 1 I~icld: Kuparuk River Unit l.u-o rdinate(\I.~ K Mcrcncr. VVell: 1J-166. Tru e Ncr.h tiitc: Kuparuk 1J F'ad 1crti cal 1"I'~l1) Kcf crcucc: iJ -1h6L2 109.0 11 ell: iJ-16b ~cc~i on (~'~I Ilcfcrc ucc: Well i0-OCN,QOO EO.OOAzii ~1'cll~ialh: 1J-1~?6~2 tiur~c} (alrulatiun ~icthrnl: ~~1i nimum C~_ir~~ahi re Uh: Grade ~unc~ ~fll lucl 9zim llU ti~~l~'I) 1'S F7l1 11a~i~A ~IapF: l~uil ft deg deg ft ft ft ft ft ft 1218.57 18.46 251.58 1203.18 1094.18 -43.05 -124.05 5945647.73 558579.03 MWD+IFR-AK-CAZ-SC 1312.43 23.25 251.77 1290.86 1181.86 -53.55 -155.76 5945636.99 558547.41 MWD+IFR-AK-CAZ-SC 1405.28 26.40 251.15 1375.12 1266.12 -65.95 -192.71 5945624.29 558510.56 MWD+IFR-AK-CAZ-SC 1496.25 29.08 251.96 1455.63 1346.63 -79.34 -232.88 5945610.60 558470.50 MWD+IFR-AK-CAZ-SC 1588.67 31.16 251.74 1535.57 1426.57 -93.78 -276.95 5945595.81 558426.55 MWD+IFR-AK-CAZ-SC 1681.66 31.48 250.28 1615.01 1506.01 -109.52 -322.65 5945579.72 558380.98 MWD+IFR-AK-CAZ-SC 1774.60 29.77 250.85 1694.98 1585.98 -125.27 -367.29 5945563.62 558336.46 MWD+IFR-AK-CAZ-SC 1866.00 31.26 251.58 1773.72 1664.72 -140.21 -411.23 5945548.34 558292.65 MWD+IFR-AK-CAZ-SC 1959.32 33.33 252.47 1852.60 1743.60 -155.59 -458.65 5945532.60 558245.35 MWD+IFR-AK-CAZ-SC 2052.31 33.19 251.09 1930.36 1821.36 -171.53 -507.09 5945516.28 558197.04 MWD+IFR-AK-CAZ-SC 2144.84 33.32 258.24 2007.77 1898.77 -184.92 -555.95 5945502.51 558148.29 MWD+IFR-AK-CAZ-SC. 2237.05 34.20 266.36 2084.47 1975.47 -191.73 -606.64 5945495.30 558097.66 MWD+IFR-AK-CAZ-SC 2328.42 32.70 266.73 2160.70 2051.70 -194.77 -656.91 5945491.87 558047.42 MWD+IFR-AK-CAZ-SC 2425.32 34.42 273.37 2241.47 2132.47 -194.65 -710.40 5945491.57 557993.94 MWD+IFR-AK-CAZ-SC 2452.74 34.40 276.43 2264.10 2155.10 -193.33 -725.84 5945492.77 557978.49 MWD+IFR-AK-CAZ-SC 2546.43 35.67 281.89 2340.83 2231.83 -184.74 -778.88 5945500.95 557925.39 MWD+IFR-AK-CAZ-SC 2639.81 36.99 2.86.70 2416.07 2307.07 -171.05 -832.44 5945514.22 557871.73 MWD+IFR-AK-CAZ-SC 2734.07 40.43 293.17 2489.64 2380.64 -150.86 -887.74 5945533.98 557816.27 MWD+IFR-AK-CAZ-SC 2827.46 44.92 296.60 2558.29 2449.29 -124.17 -945.10 5945560.22 557758.71 MWD+IFR-AK-CAZ-SC 2916.42 48.89 302.39 2619.09 2510.09 -92.12 -1001.53 5945591.82 557702.04 MWD+IFR-AK-CAZ-SC 3013.64 51.39 304.85 2681.40 2572.40 -50.79 -1063.65 5945632.67 557639.61 MWD+IFR-AK-CAZ-SC 3107.78 54.97 308.08 2737.82 2628.82 -5.98 -1124.20 5945677.00 557578.72 MWD+IFR-AK-CAZ-SC 3212.63 63.29 312.15 2791.58 2682.58 52.05 -1192.86 5945734.48 557509.62 MWD+IFR-AK-CAZ-SC 3293.01 67.08 314.30 2825.32 2716.32 102.02 -1245.99 5945784.03 557456.10 MWD+IFR-AK-CAZ-SC 3387.01 67.12 314.00 2861.89 2752.89 162.33 -1308.12 5945843.85 557393.51 MWD+IFR-AK-CAZ-SC 3480.85 67.18 316.43 2898.34 2789.34 223.70 -1369.03 5945904.74 557332.13 MWD+IFR-AK-CAZ-SC 3574.21 67.77 317.21 2934.10 2825.10 286.59 -1428.04 5945967.16 557272.63 MWD+IFR-AK-CAZ-SC 3668.21- 67.15 317.80 2970.14 2861.14 350.60 -1486.69 5946030.71 557213.49 MWD+IFR-AK-CAZ-SC 3759.77 67.37 317.37 3005.53 2896.53 412.94 -1543.65 5946092.60 557156.06 MWD+IFR-AK-CAZ-SC 3854.31 66.02 318.81 3042.93 2933.93 477.55 -1601.65 5946156.74 557097.56 MWD+IFR-AK-CAZ-SC 3948.54 66.04 318.80 3081.21 2972.21 542.34 -1658.36 5946221.08 557040.36 MWD+IFR-AK-CAZ-SC. 4042.25 66.49 317.82 3118.93 3009.93 606.40 -1715.41 5946284.69 556982.81 MWD+IFR-AK-CAZ-SC 4135.67 67.17 319.34 3155.69 3046.69 670.80 -1772.22 5946348.64 556925.50 MWD+IFR-AK-CAZ-SC 4229.40 66.96 324.69 3192.24 3083.24 738.80 -1825.33 5946416.22 556871.87 MWD+IFR-AK-CAZ-SC 4323.14 69.48 329.50 3227.04 3118.04 811.87 -1872.57 5946488.91 556824.07 MWD+IFR-AK-CAZ-SC 4416.59 72.03 335.04 3257.86 3148.86 889.94 -1913.57 5946566.65 556782.47 MWD+IFR-AK-CAZ-SC 4509.82 71.51 339.57 3287.04 3178.04 971.60 -1947.73 5946648.04 556747.67 - MWD+IFR-AK-CAZ-SC 4602.46 72.84 348.30 3315.44 3206.44 1056.26 -1972.08 5946732.49 556722.66 MWD+IFR-AK-CAZ-SC 4695.65 74.40 352.02 3341.73 3232.73 1144.33 -1987.35 5946820.44 556706.72 MWD+IFR-AK-CAZ-SC 4789.72 74.94 355.52 3366.61 3257.61 1234.50 -1997.19 5946910.52 556696.17 MWD+IFR-AK-CAZ-SC 4882.78 76.89 358.45 3389.26 3280.26 1324.63 -2001.92 5947000.59 556690.74 MWD+IFR-AK-CAZ-SC 4976.26 78.15 1.69 3409.47 3300.47 1415.88 -2001.80 5947091.84 556690.14 MWD+IFR-AK-CAZ-SC 5005.00 78.11 1.71 3415.38 3306.38 1444.00 -2000.97 5947119.95 556690.76 MWD+IFR-AK-CAZ-SC 5097.32 82.89 3.92 3430.61 3321.61 1534.91 -1996.49 5947210.89 556694.53 MWD+IFR-AK-CAZ-SC 5191.86 83.76 5.07 3441.60 3332.60 1628.51 -1989.13 5947304.54 556701.16 MWD+IFR-AK-CAZ-SC 5285.68 86.58 7.72 3449.50 3340.50 1721.40 -1978.71 5947397.50 556710.85 MWD+IFR-AK-CAZ-SC 5379.38 87.18 6.85 3454.60 3345.60 1814.21 -1966.85 5947490.38 556721.99 MWD+IFR-AK-CAZ-SC. 5471.94 89.54 6.46 3457.25 3348.25 1906.10 -1956.13 5947582.35 556731.99 MWD+IFR-AK-CAZ-SC 5565.06 93.50 6.47 3454.78 3345.78 1998.57 -1945.65 5947674.90 556741.75- MWD+IFR-AK-CAZ-SC 5658.34 93.67 4.72 3448.95 3339.95 2091.23 -1936.57 5947767.60 556750.10 MWD+IFR-AK-CAZ-SC 5752.22 89.69 0.41 3446.19 3337.19 2184.93 -1932.38 5947861.33 556753.56 MWD+IFR-AK-CAZ-SC 5843.54 88.10 359.80 3447.96 3338.96 2276.23 -1932.21 5947952.62 556753.02 MWD+IFR-AK-CAZ-SC 5937.81 87.73 359.64 3451.39 3342.39 2370.44 -1932.67 5948046.81 556751.83 MWD+IFR-AK-CAZ-SC Halliburton Company.... ~; Global Report C~nnp:ui~: Conoco Phillips Alaska Inc. Ua[c: 3rb'20G6 fimc: I4 39~0'o f'a~.;c 3 I~irld: Kuparuk FZfVI f U nit G~-ur din:~lc1AP:) K ctirencr: ~ti~ell, 1J-1~6. Tru° North ,file: Kuparuk 1J Pad ~'crtir nl (l'~I)) Itrf crcncc: 1 J-166L2 _ 109.0 1V~ell: 1J-160 Sccliu n ~~ti~ ItcCcr aicc: Wall 10 OON,O OOEO OOAzi1 ~~'cllpath: 1J-166L2 Sur~c} (alcul:~tion Vethrul: M lr~im~m Curvat~_i re Uh: Oracle ~unr~~ -~~~) X11 ('~ .'<11f11 ~ ~ ~) ti~'ti ~ ~. ~) ~.'~ ~'~~~~ ~~:1 ~1~ ~~~1 ~1 ~', ~ flll~ ft deg deg ft f, ft ft ft ft 6032.43 85.81 357.84 3456.72 3347.72 2464.87 -1934.75 5948141.22 556749.01 MWD+IFR-AK-CAZ-SC 6125.25 89.80 7.19 3460.28 3351.28 2557.41 -1930.67 5948233.78 556752.37 MWD+IFR-AK-CAZ-SC 6216.13 91.58 10.41 3459.18 3350.18 2647.20 -1916.77 5948323.67 556765.56 MWD+IFR-AK-CAZ-SC 6308.93 89.70 9.15 3458.15 3349.15 2738.64 -1901.01 5948415.22 556780.61 MWD+IFR-AK-CAZ-SC 6404.02 89.22 7.60 3459.04 3350.04 2832.71 -1887.16 5948509.38 556793.73 MWD+IFR-AK-CAZ-SC 6497.55 89.47 7.47 3460.11 3351.11 2925.43 -1874.90 5948602.18 556805.26 MWD+IFR-AK-CAZ-SC 6591.59 90.52 9.13 3460.12 3351.12 3018.48 -1861.32 5948695.33 556818.11 MWD+IFR-AK-CAZ-SC 6685.36 89.71 6.22 3459.93 3350.93 3111.40 -1848.80 5948788.33 556829.91 MWD+IFR-AK-CAZ-SC 6778.89 90.02 8.18 3460.15 3351.15 3204.18 -1837.08 5948881.20 556840.91 MWD+IFR-AK-CAZ-SC 6872.15 93.06 8.57 3457.65 3348.65 3296.41 -1823.50 5948973.51 556853.76 .MWD+IFR-AK-CAZ-SC 6968.60 92.74 6.18 3452.77 3343.77 3391.93 -1811.14 5949069.12 556865.38 MWD+IFR-AK-CAZ-SC 7058.88 87.71 359.96 3452.41 3343.41 3482.00- -1806.31 5949159.22 556869.51 MWD+IFR-AK-CAZ-SC 7153.69 89.04 358.59 3455.10 3346.10 3576.76 -1807.51 5949253.96 556867.57 MWD+IFR-AK-CAZ-SC 7248.32 89.27 358.94 3456.50 3347.50 3671.36 -1809.55 5949348.53 556864.79 MWD+IFR-AK-CAZ-SC 7340.71 91.27 359.26 3456.06 3347.06 3763.73 -1811.00 5949440.88 556862.62 MWD+IFR-AK-CAZ-SC 7434.50 92.25 357.36 3453.18 3344.18 3857.43 -1813.76 5949534.55 556859.13 MWD+IFR-AK-CAZ-SC 7525.33 89.02 353.09 3452.17 3343.17 3947.91 -1821:32 5949624.95 556850.86 MWD+IFR-AK-CAZ-SC 7618.38 89.10 351.87 3453.70 3344.70 4040.15 -1833.50 5949717.08 556837.97 MWD+IFR-AK-CAZ-SC 7680.00 89.26 348.26 3454.58 3345.58 4100.83 -1844.13 5949777.67 556826.87 MWD+IFR-AK-CAZ-SC 7759.16 83.44 352.42 3459.62 3350.62 4178.65 -1857.38 5949855.39 556813.01 MWD+IFR-AK-CAZ-SC 7807.17 83.85 353.73 3464.94 3355.94 4226.02 -1863.14 5949902.70 556806.89 MWD+IFR-AK-CAZ-SC 7901.23 91.49 354.16 3468.76 3359.76 4319.41 -1873.04 5949996.00 556796.25 MWD+IFR-AK-CAZ-SC 7994.94 93.00 356.48 3465.09 3356.09 4412.72 -1880.68 5950089.25 556787.89 MWD+IFR-AK-CAZ-SC 8088.63 90.19 357.76 3462.48 3353.48 4506.25 -1885.39 5950182.72 556782.46 MWD+IFR-AK-CAZ-SC 8181.66 86.91 359.09 3464.83 3355.83 4599.20 -1887.94 5950275.64 556779.17 MWD+IFR-AK-CAZ-SC 8274.99 87.49 358.91 3469.39 3360.39 4692.40 -1889.57 5950368.82 556776.82 MWD+IFR-AK-CAZ-SC 8368.48 87.86 1.30 3473.18 3364.18 4785.81 -1889.40 5950462.21 556776.26 MWD+IFR-AK-CAZ-SC 8462.64 89.60 2.04 3475.27 3366.27 4879.90 -1886.65 5950556.32 .556778.27 MWD+IFR-AK-CAZ-SC 8555.60 93.19 358.86 3473.01 3364.01 4972.80 -1885.92 5950649.21 556778.28 MWD+IFR-AK-CAZ-SC 8648.77 91.18 358.17 3469.46 3360.46 5065.87 -1888.34 5950742.25 556775.14 MWD+IFR-AK-CAZ-SC 8742.37 87.90 358.68 3470.21 3361.21 5159.42 -1890.91 5950835.76 556771.84 MWD+IFR-AK-CAZ-SC 8836.22 88.51 3.19 3473.15 3364.15 5253.18 -1889.38 5950929.53 556772.64 MWD+IFR-AK-CAZ-SC 8928.74 89.05 6.38 3475.12 3366.12 5345.35 -1881.66 5951021.74 556779.64 MWD+IFR-AK-CAZ-SC. 9021.97 89.53 7.36 3476.27 3367.27 5437.90 -1870.51 5951114.37 556790.07. MWD+IFR-AK-CAZ-SC 9115.76 87.73 6.84 3478.52 3369.52 5530.94 -1858.92 5951207.49 556800.93 MWD+IFR-AK-CAZ-SC 9209.74 88.11 5.85 3481.93 3372.93 5624.28 -1848.54 5951300.90 556810.58 MWD+IFR-AK-CAZ-SC 9302.10 88.05 4.54 3485.02 3376.02 5716.21 -1840.18 5951392.88 556818.22 MWD+IFR-AK-CAZ-SC 9396.75 89.72 2.71 3486.86 3377.86 5810.64 -1834.20 5951487.35 556823.46 MWD+IFR-AK-CAZ-SC 9489.71 88.41 359.99 3488.38 3379.38 5903.56 -1832.01 5951580.27 556824.93 MWD+IFR-AK-CAZ-SC 9582.92 88.04 356.80 3491.27 3382.27 5996.67 -1834.62 5951673.35 556821.59 MWD+IFR-AK-CAZ-SC 9675.84 89.97 354.80 3492.88 3383.88 6089.32 -1841.43 5951765.93 556814.07 MWD+IFR-AK-CAZ-SC 9768.46 90.08 356.90 3492.84 3383.84 6181.69 -1848.13 5951858.24 556806.65 MWD+IFR-AK-CAZ-SC 9860.57 91.51 1.43 3491.56 3382.56 6273.76 -1849.47 5951950.29 556804.59 MWD+IFR-AK-CAZ-SC 9957.61 95.11 2.33 3485.96 3376.96 6370.57 -1846.29 5952047.11 556807.01 MWD+IFR-AK-CAZ-SC 10049.97 94.90 2.68 3477.90 3368.90 6462.49 -1842.27 5952139.05 556810.31 MWD+IFR-AK-CAZ-SC 10142.57 94.52 0.80 3470.30 3361.30 6554.73 -1839.47 5952231.30 556812.40 MWD+IFR-AK-CAZ-SC 10233.78 95.60 1.31 3462.26 3353.26 6645.56 -1837.80 5952322.14 556813.36 MWD+IFR-AK-CAZ-SC 10331.07 93.10 1.89 3454.88 3345.88 6742.53 -1835.09 5952419.11 556815.31 MWD+IFR-AK-CAZ-SC 10422.74 89.01 0.96 3453.19 3344.19 6834.13 -1832.81 5952510.72 556816.88 MWD+IFR-AK-CAZ-SC 10515.77 91.02 2.02 3453.16 3344.16 6927.12 -1830.39 5952603.72 556818.57 MWD+IFR-AK-CAZ-SC 10609.85 91.51 0.80 3451.09 3342.09 7021.15 -1828.08 5952697.75 556820.15 MWD+IFR-AK-CAZ-SC 10702.88 91.38 0.31 3448.74 3339.74 7114.15 -1827.18 5952790.74 556820.33 MWD+IFR-AK-CAZ-SC Halliburton Company.., Global Report ('nnip:ui}~: ConocoPh;llips Alaska Inc. Ffcl~l: Kuparuk River U nit ~itc: Kuparuk 1J Pad 1~eIL IJ-166 ~l'cllt~arli: 1 J-166L2 tiiu~cec III) lucl ~iim l ~U tips II~D ft deg deg ft ft 10796.81 88.77 359.31 3448.62 3339.62 10891.56 88.66 358.63 3450.74 3341.74 10985.94 88.04 0.40 3453.46 3344.46 11075.69 87.92 3.41 3456.63 3347.63 11167.31 87.18 3.88 3460.54 3351.54 11257.16 88.61 1.28 3463.84 3354.84 11347.50 88.29 3.09 3466.29 3357.29 11438.27 87.67 1.08 3469.49 3360.49 11528.79 87.68 357.27 3473.16 3364.16 11620.27 87.68 353.36 3476.86 3367.86 11711.06 87.43 353.86 3480.74 3371.74 11801.68 87.24 356.74 3484.95 3375.95 11891.94 88.61 1.08 3488.22 3379.22 11981.25 89.47 4.02 3489.72 3380.72 12072.31 92.07 3.16 3488.49 3379.49 12161.19 89.64 3.27 3487.17 3378.17 12252.12 87.29 3.49 3489.60 3380.60 12343.56 86.06 3.36 3494.91 3385.91 12433.57 85.14 2.77 3501.81 3392.81 12524.34 86.14 1.06 3508.71 3399.71 12617.51 86.32 1.57 3514.84 3405.84 12708.93 89.05 3.18 3518.53 3409.53 12798.58 87.42 2.77 3521.29 3412.29 12890.35 87.43 2.69 3525.42 3416.42 12957.64 86.99 3.93 3528.69 3419.69 12994.00 86.99 3.93 3530.60 , 3421.60 I)au~: :;%612006 l imc 14.39:06 Pa~,r: ~ Cu-u rilin;i tcltl:) f2clcrcucc: V`JeL 1J-1o6, True No~~th ~'crtii~al (T~l)) 1Lcfrrcncc: iJ-166L2 : 109 0 ~eciiu^ (~~1 Hcfcrcncr. Well (O OON 0 OOE,O OOFlzIi Sm~~cc (~ailculaliun ~~1<~rlmil: Minimum Curv2ture I)h: Oracle \R I?11' \latiA ~latt~l~: fn~il ft ft ft ft 7208.07 -1827.49 5952884.65 556819.28 MWD+IFR-AK-CAZ-SC 7302.78 -1829.19 5952979.33 556816.84 MWD+IFR-AK-CAZ-SC 7397.11 -1829.99 5953073.65 556815.31 MWD+IFR-AK-CAZ-SC 7486.75 -1827.01 5953163.30 556817.59 MWD+IFR-AK-CAZ-SC 7578.10 -1821.19 5953254.68 556822.70 MWD+IFR-AK-CAZ-SC 7667.78 -1817.15 5953344.39 556826.04 MWD+IFR-AK-CAZ-SC 7758.02 -1813.71 5953434.64 .556828.78 MWD+IFR-AK-CAZ-SC 7848.67 -1810.41 5953525.30 556831.37 MWD+IFR-AK-CAZ-SC 7939.09 -1811.71 5953615.70 556829.36 MWD+IFR-AK-CAZ-SC 8030.17 -1819.17 5953706.71 556821.19 MWD+IFR-AK-CAZ-SC 8120.31 -1829.27 5953796.77 556810.39 MWD+IFR-AK-CAZ-SC 8210.52 -1836.68 5953886.91 556802.27 MWD+IFR-AK-CAZ-SC 8300.68 -1838.40 5953977.04 556799.86 MWD+IFR-AK-CAZ-SC 8389.88 -1834.43 5954066.26 556803.14 MWD+IFR-AK-CAZ-SC 8480.75 -1828.72 5954157.16 556808.13 MWD+IFR-AK-CAZ-SC 8569.47 -1823.74 5954245.91 556812.42 MWD+IFR-AK-CAZ-SC 8660.20 -1818.38 5954336.67 556817.07 MWD+IFR-AK-CAZ-SC 8751.32 -1812.93 5954427.82 556821.81 MWD+IFR-AK-CAZ-SC 8840.94 -1808.13 5954517.47. 556825.91 MWD+IFR-AK-CAZ-SC 8931.39 -1805.11 5954607.93 556828.23 MWD+IFR-AK-CAZ-SC 9024.33 -1802.97 5954700.88 556829.64 MWD+IFR-AK-CAZ-SC 9115.59 -1799.19 5954792.15 556832.71 MWD+IFR-AK-CAZ-SC 9205.07 -1794.54 5954881.66 556836.67 MWD+IFR-AK-CAZ-SC 9296.65 -1790.17 5954973.26 556840.32 MWD+IFR-AK-CAZ-SC 9363.74 -1786.29 5955040.37 556843.67 MWD+IFR-AK-CAZ-SC 9399.97 -1783.80 5955076.61 556845.88 PROJECTED to TD Halliburton Company Global Report ('nmp:ui~: Conoco Phillips Alaska Inc. lore: ~%6x2006 finer. 1~:4~~28 Pa~c: I Field: Kuparuk River Unit (b-urdinalc~AI:) Rct i~rcucc: Wall: 1J-1GC. True North tiirt~: Kuparuk 1J f'ad ~~crtical (I11)~ Refer ence: 1J-16:iL2P51 10 9 G ~lcll: iJ-lo6 ~rcliun (~~~1 Rcfcrcu cc: Well i0.00N 0 00E0.00A.zij 1~'cllp:uh: 1J-166L2PB1 tiur~c~ ("alcul:~tiun ~ Ir(hixl: Minimum Curt~ahi re Ill: Oracle Survey: Start Date: Company: Engineer: Tool: Tied-to: Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Syste m: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: Kuparuk 1J Pad Site Position: Northing: 5945919.64 ft Latitude: 70 15 46.258 N From: Map Easting: 558789.95 ft Longitude: 149 31 29.007 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.45 deg Well: 1 J-166 Slot Name: Well Position: +N/-S -227.23 ft Northing: 5945691.74 ft Latitude: 70 15 44.023 N +E/-W -89.01 ft Easting : 558702.73 ft Longitude: 149 34 31.597 W Position Uncertainty: 0.00 ft Wellpath: 1J-166L2PB1 Drilled From: 1J-166 Tie-on Depth: 4976.26 ft Current Datum: 1 J-166L2P61 : Height 109.00 ft Above System Da tum: Mean Sea Level Magnetic Data: 1/6/2006 Declination: 24.22 deg Field Strength: 57564 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 0.00 Survey Program for Definitive Wellpath Date: 3/6/2006 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 50.00 723.00 1J-166 gyro (50.00-723.00) (0) CB-GYRO-SS Camera based gyro single shot 755.46 4976.26 1 J-166 (755.46-6312.36) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5005.00 8275.46 1J-166L2P61 (5005.00-8275.46) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey _ tilU Intl ~iim TAU ti_c,ll~D ~~?S f;'1~ ~tap,A ~tai~l: lluil ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945691.74 558702.73 TIE LINE 50.00 0.11 163.00 50.00 -59.00 -0.02 0.01 5945691.72 558702.74 CB-GYRO-SS 100.00 0.22 163.87 100.00 -9.00 -0.16 0.05 5945691.58 558702.78 CB-GYRO-SS 200.00 0.16 96.82 200.00 91.00 -0.36 0.24 5945691.38 558702.97 CB-GYRO-SS 300.00 0.15 129.50 300.00 191.00 -0.46 0.48 5945691.28 558703.21. CB-GYRO-SS 400.00 0.22 89.10 400.00 291.00 -0.54 0.77 5945691.21 558703.51 CB-GYRO-SS 448.00 0.37 50.51 448.00 339.00 -0.44 0.98 5945691.31 558703.72 CB-GYRO-SS 540.00 0.70 272.11 540.00 431.00 -0.23 0.65 5945691.52 558703.38 CB-GYRO-SS 630.00 4.15 258.63 629.90 520.90 -0.85 -3.09 5945690.86 558699.64 CB-GYRO-SS 723.00 9.11 253.90 722.25 613.25 -3.56 -13.47 5945688.08 558689.29 CB-GYRO-SS 755.46 10.23 253.96 754.25 645.25 -5.07 -18.71. 5945686.53 558684.06 MWD+IFR-AK-CAZ-SC 800.29 11.50 250.47 798.28 689.28 -7.66 -26.75 5945683.87 558676.04 MWD+IFR-AK-CAZ-SC 844.21 11.01 247.29 841.35 732.35 -10.74 -34.74 5945680.73 558668.07 MWD+IFR-AK-CAZ-SC 934.25 12.79 252.02 929.46 820.46 -17.14 -52.16 5945674.19 558650.71 MWD+IFR-AK-CAZ-SC 1025.65 14.38 250.54 1018.30 909.30 -24.05 -72.48 5945667.13 558630.44 MWD+IFR-AK-CAZ-SC 1123.61 16.73 248.45 1112.66 1003.66 -33.28 -97.07 5945657.71 558605.93 MWD+IFR-AK-CAZ-SC 1218.57 18.46 251.58 1203.18 1094.18 -43.05 -124.05 5945647.73 558579.03 MWD+IFR-AK-CAZ-SC Halliburton Company ~, Global Report ~'rnupan}: ConocoPhillips Alaska Inc. Iicl~l: Kuharuk R(ver Unit Ila(e. 3;'0%2006 I~inn~: 13:4823 Pa~~c 3 Cu-~~nlin:+tc(\1,~ Kcli•rcnce: U'J211 1J-1~5. I~o.ie North tiilc: Kuparuk 1J Pad ~~crtic al ('I~-111 ltcf crcucc: 1J -~66L2P[31 10 9 0 ~~~~II: iJ-166 ~eetiu n 1~ ~~l Refere nce: W ell i0 00N.0 00E.0 OOAzii ~~cll~iatlc 1J-1~~6L'PB1 Sunk }~ (':~Icularimi AIctlunl: Mi nimum Curvatu re 11 b: Oacle Sm ~e~ ~~11) luel \ziw ll~U ti~,~ f111 1''S 1~: 1~ ~Int~~ ~l~ipF: ~frml ft deg deg ft ft ft ft ft ft 1312.43 23.25 251.77 1290.86 1181.86 -53.55 -155.76 5945636.99 558547.41 MWD+IFR-AK-CAZ-SC 1405.28 26.40 251.15 1375.12 1266.12 -65.95 -192.71 5945624.29 558510.56 MWD+IFR-AK-CAZ-SC 1496.25 29.08 251.96 1455.63 1346.63 -79.34 -232.88 5945610.60 558470.50 MWD+IFR-AK-CAZ-SC 1588.67 31.16 251.74 1535.57 1426.57 -93.78 -276.95 5945595.81- 558426.55 MWD+IFR-AK-CAZ-SC 1681.66 31.48 250.28 1615.01 1506.01 -109.52 -322.65 5945579.72 558380.98 MWD+IFR-AK-CAZ-SC 1774.60 29.77 250.85 1694.98 1585.98 -125.27 -367.29 5945563.62 558336.46 MWD+IFR-AK-CAZ-SC 1866.00 31.26 251.58 1773.72 1664.72 -140.21 -411.23 5945548.34 558292.65 MWD+IFR-AK-CAZ-SC 1959.32 33.33 252.47 1852.60 1743.60 -155.59 -458.65 5945532.60 558245.35 MWD+IFR-AK-CAZ-SC 2052.31 33.19 251.09 1930.36 1821.36 -171.53 -507.09 5945516.28 558197.04 . MWD+IFR-AK-CAZ-SC 2144.84 33.32 258.24 2007.77 1898.77 -184.92 -555.95 5945502.51 558148.29 MWD+IFR-AK-CAZ-SC 2237.05 34.20 266.36 2084.47 1975.47 -191.73 -606.64 5945495.30 558097.66 MWD+IFR-AK-CAZ-SC 2328.42 32.70 266.73 2160.70 2051.70 -194.77 -656.91 5945491.87 558047.42 -MWD+IFR-AK-CAZ-SC 2425.32 34.42 273.37 2241.47 2132.47 -194.65 -710.40 5945491.57 557993.94 MWD+IFR-AK-CAZ-SC 2452.74 34.40 276.43 2264.10 2155.10 -193.33 -725.84 5945492.77 557978.49 MWD+IFR-AK-CAZ-SC 2546.43 35.67 281.89 2340.83 2231.83 -184.74 -778.88 5945500.95 557925.39 MWD+IFR-AK-CAZ-SC 2639.81 36.99 286.70 2416.07 2307.07 -171.05 -832.44 5945514.22 557871.73 MWD+IFR-AK-CAZ-SC 2734.07 40.43 293.17 2489.64 2380.64 -150.86 -887.74 5945533.98 557816.27 MWD+IFR-AK-CAZ-SC 2827.46 44.92 296.60 2558.29 2449.29 -124.17 -945.10 5945560.22 557758.71 MWD+IFR-AK-CAZ-SC 2916.42 48.89 302.39 2619.09 2510.09 -92.12 -1001.53 5945591.82 557702.04 MWD+IFR-AK-CAZ-SC 3013.64 51.39 304.85 2681.40 2572.40 -50.79 -1063.65 5945632.67 557639.61 MWD+IFR-AK-CAZ-SC 3107.78 54.97 308.08 2737.82 2628.82 -5.98 -1124.20 5945677.00 557578.72 MWD+IFR-AK-CAZ-SC 3212.63 63.29 312.15 2791.58 2682.58 52.05 -1192.86 5945734.48 557509.62 MWD+IFR-AK-CAZ-SC 3293.01 67.08 314.30 2825.32 2716.32 102.02 -1245.99 5945784.03 557456.10 MWD+IFR-AK-CAZ-SC 3387.01 67.12 314.00 2861.89 2752.89 162.33 -1308.12 5945843.85 557393.51 MWD+IFR-AK-CAZ-SC 3480.85 67.18 316.43 2898.34 2789.34 223.70 -1369.03 5945904.74 557332.13 MWD+IFR-AK-CAZ-SC 3574.21 67.77 317.21 2934.10 2825.10 286.59 -1428.04 5945967.16 557272.63 MWD+IFR-AK-CAZ-SC 3668.21 67.15 317.80 2970.14 2861.14 350.60 -1486.69 5946030.71 557213.49 MWD+IFR-AK-CAZ-SC. 3759.77 67.37 317.37 3005.53 2896.53 412.94 -1543.65 5946092.60 557156.06 MWD+IFR-AK-CAZ-SC 3854.31 66.02 318.81 3042.93 2933.93 477.55 -1601.65 5946156.74 557097.56 MWD+IFR-AK-CAZ-SC 3948.54 66.04 318.80 3081.21 2972.21 542.34 -1658.36 5946221.08 557040.36 MWD+IFR-AK-CAZ-SC 4042.25 66.49 317.82 3118.93 3009.93 606.40 -1715.41 5946284.69 556982.81 MWD+IFR-AK-CAZ-SC 4135.67 67.17 319.34 3155.69 3046.69 670.80 -1772.22 5946348.64 556925.50. MWD+IFR-AK-CAZ-SC 4229.40 66.96 324.69 3192.24 3083.24 738.80 -1825.33 5946416.22 556871.87 MWD+IFR-AK-CAZ-SC 4323.14 69.48 329.50 3227.04 3118.04 811.87 -1872.57 5946488.91 556824.07 MWD+IFR-AK-CAZ-SC 4416.59 72.03 335.04 3257.86 3148.86 889.94 -1913.57 5946566.65 556782.47 MWD+IFR-AK-CAZ-SC 4509.82 71.51 339.57 3287.04 3178.04 971.60 -1947.73 5946648.04 556747.67 MWD+IFR-AK-CAZ-SC 4602.46 72.84 348.30 3315.44 3206.44 1056.26 -1972.08 5946732.49 556722.66 MWD+IFR-AK-CAZ-SC 4695.65 74.40 352.02 3341.73 3232.73 1144.33 -1987.35 5946820.44 556706.72 MWD+IFR-AK-CAZ-SC 4789.72 74.94 355.52 3366.61 3257.61 1234.50 -1997.19 5946910.52 556696.17 MWD+IFR-AK-CAZ-SC 4882.78 76.89 358.45 3389.26 3280.26 1324.63 -2001.92 5947000.59 556690.74 MWD+IFR-AK-CAZ-SC 4976.26 78.15 1.69 3409.47 3300.47 1415.88 -2001.80 5947091.84 556690.14 MWD+IFR-AK-CAZ-SC 5005.00 78.11 1.71 3415.38 3306.38 1444.00 -2000.97 5947119.95 556690.76 MWD+IFR-AK-CAZ-SC 5097.32 82.89 3.92 3430.61 3321.61 1534.91 -1996.49 5947210.89 556694.53 MWD+IFR-AK-CAZ-SC 5191.86 83.76 5.07 3441.60 3332.60 1628.51 -1989.13 5947304.54 556701.16 MWD+IFR-AK-CAZ-SC 5285.68 86.58 7.72 3449.50 3340.50 1721.40 -1978.71 5947397.50 556710.85 MWD+IFR-AK-CAZ-SC 5379.38 87.18 6.85 3454.60 3345.60 1814.21 -1966.85 5947490.38 556721.99 MWD+IFR-AK-CAZ-SC 5471.94 89.54 6.46 3457.25 3348.25 1906.10 -1956.13 5947582.35 556731.99 MWD+IFR-AK-CAZ-SC 5565.06 93.50 6.47 3454.78 3345.78 1998.57 -1945.65 5947674.90 556741.75 MWD+IFR-AK-CAZ-SC 5658.34 93.67 4.72 3448.95 3339.95 2091.23 -1936.57 5947767.60 556750.10 MWD+IFR-AK-CAZ-SC 5752.22 89.69 0.41 3446.19 3337.19 2184.93 -1932.38 5947861.33 556753.56 MWD+IFR-AK-CAZ-SC 5843.54 88.10 359.80 3447.96 3338.96 2276.23 -1932.21 5947952.62 556753.02 MWD+IFR-AK-CAZ-SC 5937.81 87.73 359.64 3451.39 3342.39 2370.44 -1932.67 5948046.81 556751.83 MWD+IFR-AK-CAZ-SC 6032.43 85.81 357.84 3456.72 3347.72 2464.87 -1934.75 5948141.22 556749.01 MWD+IFR-AK-CAZ-SC Halliburton Company ~, Global Report ('nml~an~: ConocoPhillipsAlaskalne. U,~re: 3ro'2006 lime: 134823 Pa~c 3 Ifel~l: Kup~ruk Kf~~er U nit C~~-u r~lin.nc(\I.1 K clcrc~ice: Well 1J 16b. Irue Nord; .tine: Kuparuk 1J Pad ~"crti c l ("111)) Itcf ereucc: 1J -166L2PB i ~ 10 9.0 Nell: 1J-IG~i tic:ri un(1~Illcfcra icc VVeIIf0,00N.0-CUE G-OGA~iI N'rll~r~th: IJ-i66L2PE1 5in~~~ ey ('alculntiou 1lctho~l: Mi nimum Curvatu re I)h: Grade Sur~cc Ill loci \zini ll U ~c~ f\ I) \;,~ I~_l1~" ~fa~iA ~lapl~: l~nnl ft deq deg ft ft ft ft ft ft 6125.25 89.80 7.19 3460.28 3351.28 2557.41 -1930.67 5948233.78 556752.37 MWD+IFR-AK-CAZ-SC 6216.13 91.58 10.41 3459.18 3350.18 2647.20 -1916.77 5948323.67 556765.56 MWD+IFR-AK-CAZ-SC 6308.93 89.70 9.15 3458.15 3349.15 .2738.64 -1901.01 5948415.22 556780.61 MWD+IFR-AK-CAZ-SC 6404.02 89.22 7.60 3459.04 3350.04 2832.71 -1887.16 5948509.38 556793.73 MWD+IFR-AK-CAZ-SC 6497.55 89.47 7.47 3460.11 3351.11 2925.43 -1874.90 5948602.18 556805.26 MWD+IFR-AK-CAZ-SC 6591.59 90.52 9.13 3460.12 3351.12 3018.48 -1861.32 5948695.33 556818.11 MWD+IFR-AK-CAZ-SC 6685.36 89.71 6.22 3459.93 3350.93 3111.40 -1848.80 5948788.33 556829.91 MWD+IFR-AK-CAZ-SC 6778.89 90.02 8.18 3460.15 3351.15 3204.18 -1837.08 5948881.20 556840.91 MWD+IFR-AK-CAZ-SC 6872.15 93.06 8.57 3457.65 3348.65 3296.41 -1823.50 5948973.51 556853.76 MWD+IFR-AK-CAZ-SC 6968.60 92.74 6.18 3452.77 3343.77 3391.93 -1811.14 5949069.12 556865.38 MWD+IFR-AK-CAZ-SC 7058.88 87.71 359.96 3452.41 3343.41 3482.00 -1806.31 5949159.22 556869.51 MWD+IFR-AK-CAZ-SC 7153.69 89.04 358.59 3455.10 3346.10 3576.76 -1807.51 5949253.96 556867.57 MWD+IFR-AK-CAZ-SC 7248.32 89.27 358.94 3456.50 3347.50 3671.36 -1809.55 5949348.53 556864.79 MWD+IFR-AK-CAZ-SC 7340.71 91.27 359.26 3456.06 3347.06 3763.73 -1811.00 5949440.88 556862.62 MWD+IFR-AK-CAZ-SC 7434.50 92.25 357.36 3453.18 3344.18 3857.43 -1813.76 5949534.55 556859.13 MWD+IFR-AK-CAZ-SC 7525.33 89.02 353.09 3452.17 3343.17 3947.91 -1821.32 5949624.95 556850.86 MWD+IFR-AK-CAZ-SC 7618.38 89.10 351.87 3453.70 3344.70 4040.15 -1833.50 5949717.08 556837.97- MWD+IFR-AK-CAZ-SC 7712.01 89.34 346.38 3454.98 3345.98 4132.05 -1851.15 5949808.84 .556819.60 MWD+IFR-AK-CAZ-SC 7806.93 91.51 353.99 3454.27 3345.27 4225.50 -1867.32 5949902.15 556802.70 MWD+IFR-AK-CAZ-SC 7901.21 95.61 359.62 3448.41 3339.41 4319.40 -1872.57 5949995.99 556796.72 MWD+IFR-AK-CAZ-SC 7994.88 92.23 358.62 3442.01 3333.01 4412.82 -1874.01 5950089.40 556794.56 MWD+IFR-AK-CAZ-SC 8088.42 89.64 352.75 3440.48 3331.48 4506.04 -1881.05 5950182.54 556786.80 MWD+IFR-AK-CAZ-SC 8181.74 86.55 352.05 3443.58 3334.58 4598.47 -1893.38 5950274.87 556773.74 MWD+IFR-AK-CAZ-SC 8275.46 86.25 352.59 3449.47 3340.47 4691.17 -1905.88 5950367.46 556760.52 MWD+IFR-AK-CAZ-SC 8359.00 86.25 352.59 3454.93 3345.93 4773.83 -1916.63 5950450.03 556749.13 PROJECTED to TD ~ ~ °~ ~y J I ; I ~ ~ ~ ) ~~ , ~ '~~ ~ FRANK H. MURKOWSKI, GOVERNOR i ~ ~ J - s ~. ~...~ ~~ t]WC!-7~ OiL ~ GAS ~ 333 W. T" AVENUE, SUITE 100 COI~SER~'ATIOI~T COMlI'I155IOIQ ~ ANCHORAGE, ALASKA 99501-3539 j PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: West Sak 1J-166L2 ConocoPhillips Alaska, Inc. Permit No: 205-200 Surface Location: 1880' FSL, 2508' FEL, Sec. 35, T 11 N, R 1 OE, UM Bottomhole Location: 720' FSL, 948' FWL, Sec. 23, T11N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is for a new wellbore segment of existing well KRU 1J-166L2, Permit No. 205-198, API 50-029-23291-00. Production should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 {pager). 205-200 `"`"° DATED this~ay of December, 2005 i ~~; cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~~`°`'~ STATE OF ALASKA ~~-~~ ~~C 0 2005 R~ ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oii $t Gag Cans. Coi~sian PERMIT TO DRILL Anchorep~ 20 AAC 25.005 1a. Type of Work: Drill / Redrill Re-entry ^ 1b. Current Well Class: Exploratory Development Oil ~ Multiple Zone ^ Stratigraphic Test ^ Service ^ Development Gas ^ Single Zone 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-166L2 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 12980' ~ TVD: 3531' ~ 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1880' FSL, 2508' FEL, Sec. 35, T11 N, R10E, UM ~ 7. Property Designation: ADL 25661 & 25650 ~ West Sak Oil Pool Top of Productive Horizon: 1934' FNL, 778' FWL, Sec. 35, T11 N, R10E, UM 8. Land Use Permit: ALK 471 & 468 13. Approximate Spud Date: 1/1/2006 Total Depth: 720' FSL, 948' FWL, Sec. 23, T11 N, R10E, UM 9. Acres in Property: 2560 14. Distance to~~G M,~.i S 'lfb ~f(I~GGI Nearest Property: 188oQpv 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558703 ~ y- 5945692 ~ Zone- 4 10. KB Elevation (Height above GL): 28' RKB feet 15. Distance to Nearest Well within Pool: 1 D-127 ,sal' @ 12980' 16. Deviated wells: Kickoff depth: 5033 ' ft. Maximum Hole Angle: 98.8° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1589 psig Surface: 1201 psig 18. Casing Program Setting Depth Quantity of Cement Size Specifications Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" x 34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCRETE 13.5" 10.75" 45.5# L-80 BTC 2360' 28' 28' 2360' 2183' 460 sx ASLite, 170 sx DeepCRETE g_ ~ 7 /g" - TCM 6.75" 4.5" 12.6# L-80 TM 7947' 5033' 3418' 12980' 3531' 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 Perforation Depth MD (ft): ~ ~ Perforation Depth TVD (ft): 20. Attachments: Filing Fee ~ BOP Sketch Drilling Program^/ Time v. Depth Plot Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^ 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 Mike Greener @ 263-4820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~, ~o Phone `-Z. ~ S~ ~, ~ 3v Date 1 , ~ 2 c~ 1~~- Pr ar b r n All u -Dr k Commission Use Only Permit to Drill Number: 2.QS~^ ~~ API Number: 50- ~~.~- ~~~-G ~ ~ ~ ~ Permit Approval `~ Date: a.. ~ J See cover letter for other requirements Conditions of approval am les required Yes ^ No `~ Mud log required Yes ^ No Hyd gen sulfide measures Yes ~ No ~ Directional survey required Yes' No ^ Other: - ~ „~5~ ~~ ~~ `\ F `~'~CJ APPROVED BY ~~~ ~ D~ Approved ` / THE COMMISSION Date: Form 10-401 Revised 06/2004 ~ ~ ~ ~~ ~~ Submit in Duplicate ~.r' Ap;~~ion for Permit to Drill, Well 1 J-166 L2 Revision No.O Saved: 28-Nov-05 Permit It -West Sak Well #1J-166 L2 Application for Permit to Drill Document Y1e~l I 'falu e Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (f) ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ...................................................................................3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program ............................................................................ 3 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC ?5.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 Lateral Mud Program (MI VersaPro Mineral Oil Base) ........................................................................... 4 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bonding ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 7J-166L2 PERMIT IT.doc Page 7 of 6 Printed: 28-Nov-05 nRisINAL AEI !ion for Permit to Drill, Well 1J-166 L2 Revision No.O Saved: 28-Nov-05 13. Proposed Drilling Program ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments ............................................................................................................. 6 Attachment 1 Directional Plan ................................................................................................................ 6 Attachment 2 Drilling Hazards Summary ............................................................................................... 6 Attachment 3 Well Schematic ................................................................................................................ 6 1. Well Name Requirements of 20 AAC 25.005 (t7 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(b). For a well with mu/tiple 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 well 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 1J-166 L2. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Dri/l must be accompanied by each of the fo/%wing items, except for an item a/ready on file with the commission and identified in the application: (2) a plat identifying the property and the propertys owners and showing (A)the coordinates of the proposed /ocation of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines (8) the coordinates of the proposed /ocation of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the Nationa/ 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 1 880' FSL, 2 508' FEL, Section 35 T11N R10E ASP Zone 4 NAD 27 Coordinates RKB E/evation 109.0' AMSL Northings: 5,945,692 Eastings: 558,703 Pad E/evation 81.0' AMSL Location at Top of Productive Interval 1,934' FNL, 778' FWL, Section 35, T11N, R10E West Sak "D" Sand ASP Zone 4 NAD 27 Coordinates Measured De th RKB: 5,033 Northings: 5,947,141 Eastings: 556,695 Total l/ertical De th RKB; 3,416 Total l/ertical De th, SS: 3,307 Location at Total De th 720' FSL, 948' FWL, Section 23, T11N R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB; 12 980 Northings: 5,955,076 Eastings: 556,795 Total I/ertica/De th RKB; 3 531 Total 1/ertical De th SS: 3 422 and (D) other information required by 20 AAC25.050(b); 1J-166L2 PERMIT IT.doc Page 2 of 6 Printed: 28-Nov-05 OR161NAL Ap,~jion for Permit to Drill, Well 1J-166 L2 ~,,~,; Revision No.O Saved: 28-Nov-05 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (I) inclade a plat, drawn to a suitab/e sca/e, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet ofany portion of the proposed wel% Please see Attachment 1: Directional Plan and (2) for al! wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wel/s, to the extent that those names are known or discoverab/e in public records, and show that each named operator has been furnished a copy of the app/ication by certified mail; or (B) state that the applicant is the on/y affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An app/ication for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item a/ready on fi/e with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicab/e; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete the well. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Dri/l must be accompanied by each of the fo/lowing items, except for an item a/ready on fi/e with the commission and identified in the app/ication: (4) information on drilling hazards, inclading (A) the maximum downhole 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 1J area are 0.45 psi/ft, or 8.7 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. 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 ~~D" sand formation is 1,201 psi, calculated thusly: MPSP = (3,531 ft TVD)(0.45 - 0.11 psi/ft) = 1,201 psi (B) data on potent>a/gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of ho% problems such as abnormal/y geo pressured strata, lost circa/ation zones, and zones that have a propensity for dih'erentia/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 ldentiFed in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(!); The parent wellbore, 1J-166, will be completed with 7-5/8" intermediate casing landed in the West Sak A- Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 7J-166L2 PERMIT IT.doc Page 3 of 6 Printed: 28-Nov-05 ORIGINAL ,,-, AK, ;ion for Permit to Drill, Well 1 J-166 L2 `~ Revision No.O Saved: 28-Nov-05 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An app/ication for a Permit to Dril/must be accompanied by each of the fo/lowing items, except for an item a/ready on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description ofany slotted liner, pre- perforated liner, or screen to be insta/led; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weigh Length MD/TVD MD/TVD OD in in t Ib/ft Grade Connection ft ft ft Cement Pro ram 4-1/2 6-3/4" A Sand 12.6 L-80 IBTM 7,383 5,458 / 3,501 12,841 / 3,733 Slotted- no cement slotted Lateral (1J-166) 4-1/2 6-3/4" a Sand 12.6 L-80 IBTM 77 5 368 / 3,489 12,945 / 3,588 Slotted- no cement Lateral(iJ-1 1) 4-1/2 - /4" D Sand 12.6 L-80 IBTM 7,947 5,033 / 3,418 12,980 / 3,531 Slotted- no cement slotted Lateral (1J-166 L2) _ ~~ 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An applcation 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: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); No diverter system will be utilized during operations on iJ-166 L2. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Dril/must be accompanied by each of the fol%wing items, except for an item a/ready 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 muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro, Mineral Oil Base) Value Densit ( 8.6 Plastic Viscostiy (!b/100 s 15 - 25 Yield Point cP) 18 - 28 HTHP Fluid loss (ml/30 min @ 200 si & 150° <4.0 Oil /Water Ratio 70 / 30 Electrical Stabilit 650-900 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 Rig 141. 1J-166L2 PERMIT IT.doc Page 4 of 6 Printed: 28-Nov-05 ORIGINAL ~~ AK~~ion for Permit to Drill, Well 1 J-166 L2 Revision No.O Saved: 28-Nov-05 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An app/ication for a Permit to Dril/ 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: (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 25.033(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 application for a Permit to Drill must be accompanied by each of the following items, except for an item a/ready on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test wel% a seismic refraction or reflection ana/ysis as required by 20 AAC 2s.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 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: (11) for a wel! drilled from an offshore p/atform, mobile bottom-founded structure, jack-up rig, or floating dril/ing vesse% an ana/ysis ofseabed conditions as required by 20 AAC25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Dril! 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: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips 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 Dri// 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: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the 1J-166 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of +/- 5,033' MD / 3,416' TVD, the top of the D sand. 2. Mill 6-3/4" window. POOH. 3. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of D sand lateral at +/- 12,980' MD / 3,531' TVD, as per directional plan. 5. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 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. 1J-156L2 PERMlT 1T.doc Page 5 of 6 Prinfed.~ 28-Nov-05 ORIGINAL ~: A~,~ Jtion for Permit to Drill, Well 1 J-166 L2 -•~ Revision No.O Saved: 28-Nov-05 10. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. 11. POOH, laying down drill pipe as required. 12. PU completion as required and RIH to depth. Land tubing. Set BPV. 13. Nipple down BOPS, nipple up tree and test. Pull BPV. 14. Freeze protect well with diesel. 15. Set BPV and move rig off. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(94) An app/ication for a Permit to Drill mustc be accompanied by each of the fol%wing items, except for an item a/ready on file with the commission and identiFed in the application: (14) a genera/ description of how the operator plans to dispose of dril/ing 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 wel%; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 1J Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 1J-166L2 PERMIT IT.doc Page 6 of 6 Printed: 28-Nov-05 ORIGINAL 1J-166I~ Drilling Hazardsummary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud weight. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out, backreaming 1J-166L2 Drilling Hazards Summary.doc prepared by Shane C/oninger 11/16/2005 11:29 AM ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-166 1J-166 L2 Plan: 1J-166 L2 (wp07) Proposal Report 04 November, 2005 Sperry tyrillin~g Services ORIGINAL o O 3 > y ~ODN Noou~~ (/1N r1~ V v n ~ O ~ 3 ~p C _ ° K p Y O ' ~UmQ r9i _ ~ O W O a rjj ~ ~g=~ ~r .e Jeff oirn ~~~ J d a- - E_ ~~N ~ ~ ~ ~ ~~ o n ~ ~ ~ 3 a rn i 3 N H 6L8i ~ N _ N O ° LL HYF»>Y Q Z N~i~ O ~ (~O (00 Z N - ~ ~ ri d $ lV IA W Y) ' IpA ~ ~ ~ O tnp V N ~ ll.l r r d ~ 1D 908 ~ O .'- p _' ~ ~ N N ~ N ~ O Z 000 N pMp °m ~yJ (~D fD N N ~ 3 ~ ~ p pp p p p p p p p p p p p p p gOO OOo0OO0O0 f ~ a N b e~1 N b w S~ ~ Q V N~f7N J ~ ~ fD fD y ~ ~ _ _ o8B _ _ _ __ _ _ - _. _ O N 00 a0 p rgc L ~ N''f O N 1~0 1~ a0 0~ 0 0 0 0 ~ tO 0D ~ ~ C C ~ ~ a a ' ~ (O ( O O N PY P') ~ ~ ~ ~ ~ oD6 ' ~ °m o Z ~ N M V m ~ ~ n ~ e d ° LL 3 i o o ~ r~ ~ n o 088 ~ ~ o ° co _ _ O O M M C >_ a1° `~ 8 ~ ~~~ 3 Y Y ~ ~ N > »>J ~ L r r ~ ~ ` r Y Ya$~ r d~m~R .o~33a a` _ ~ O ~ _~ Z H ~ i~ l") i ~ ~ O 0 M T ~ m ~ °o ~ rn ~ r ~ M ~ M ~ LL N J O O ~ 0 ~ O m N ~ ~ °a ?i p ~ G ~ H ^ O J m ~ a O ~ 90°! ~ ° ~ ° O N 5 L ~ 088: 1 3 m J ~ _ ~ O 'O ~ H N N ~ N ~ ~ ~ .. ~ ~ ~ ~ o ° w m o68 ! ° O ~ ~ ~ ~ o a ~ ~ c°~i ~ H e~8 : O O a ~ ~ J ~ 47 v c o m o ~' ~ J a 3 O (n ° ° a ° ~ ~ ~ _ N ' J J ~p ~ 00 o4s o ,~ 0 LL m ~ ~, ~ N J n ~ ~ _ _ 006 i z ~tl8 ------------------- ----------- ---- ~P 0 o O o O o 0 o u~ o N _$ M H N O n J O ~ ~ N r ~ ~ ~ N O O ' J N p O ~ N . 3 ~ .: `J N O J 0 ~ 0 N °o 0 0 ° ~~ fl.~ ° n l u g V ° ° 0 O O o ' 0 0 0 u~ o u~ ~ N N ^ ~ ®' ~ ~ A I Project: Kuparuk River Unit ~ ~OIlOCO~'li~ l 5 Site: Kuparuk 1J Pad ~ p Well: Plan 1J-166 10625 ~ Wellbore: 1J-166 L2 Plan: 1J-166 L2 (wp07) 10000 4 1/2" L2.9HL@12980ftMD.3531ftND 720ftFSL8948ftFWL--Sec 23-T11N-R10E 1J-166 L2 T12 Toe (wp07) 9375 0° 1J-166 L2 T11 (wp07) CASING DETAILS 8750 _ 0 No ND MD Name Size 1 80.00 80.00 20" 20 1J-166 L2 T10(wp10) 0 0° 2 2183.00 2359.67 10 3l4" " 103/4 8125 3 3416.00 5033.40 7 5/8 7-518 4 3531.0012980.22 4112" 4-1/2 1J-166 L2 T9 (wp07) 0° 7500 1 J-166 L2 T8 (wp07) - 0° 1J-166 L2 T7 (wp07) _ _. 6875 1J-166 L2 T6 (wp07) L2 Budd ~ 3°/1 f%lft - Ewt D-Sand High m Prep for Upthrown Fault, 9848ft MD, 3484ft ND 6250 1 J-186 L2 TS (wp07) _ _ o° - _ - -- - L2 Possible Downthrown Fault. 9508ft MD. 3485ft ND 5625 0° 1 J-166 L2 T4 (wp07) 5000 c 0 1J-166 L2 T3 (wp07) _ 0° N `'' 1J-166 L2 T2 (wp07) ° :} 0 4375 L Z 1J-166 L2 T1 (wp07) ~ 3750 0 ~ 0° L2: Continue Geosteerin D Sand,8126ft MD,3439R ND 3125 2500 L2 Sail at 90.31 °. 5334ft MD, 3443ft ND 6° 1875 L2 Entl 30' Rathole .Budd (~ 5.5°/100ft . 5076ft MD. 3424ft ND ~~ 1 1360° ~ ~ - ~ - - - - - - - - - ,L2 -. BOW 5046ft MD. 34198 ND , 1250 _ 33~ 625 L2 : TOW 5033ft MD. 3416ft ND 1934ft FNL 8 778ft FWL Sec 35 - T11 N - 810E ~9 9 T 8 ~ 20.. o ~ 0 M ,~ r Azimuths to 'rue Nortn ~~ o Magnetic North: 24.64° o -625 Magnetic Field Strength: 57570.3nT Dip Angle: 80.72° 10 3/4" Date: 9/1 /2004 Model: BGGM2004 -1250 -4375 -3750 -3125 -2500 -1875 -1250 -625 0 625 1250 1875 2500 3125 3750 4375 est - /Ea (+) (1250 ft/in UKIVIiVHL ` "°"' Halliburton Company HALLI~UIFt7t'~N COI'~OC4 Pf"l1~~1~5 Planning Report -Geographic -~~-- -~~~~~ ~~- ~~° ~~~~ Alaska Sperry Orillin~ S~nr[ces Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1 J-166 Company: CohocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109AOft (Doyon 141 (28+81)) Project; Kuparuk River Unit. MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-166 Survey Calculation Method: Minimum Curvature Wellbore: 1J-166 L2 Design: 1J-166 L2 (wp07) 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 1J-166 Well Position +N/-S 0.00 ft Northing: 5,945,691.74 ft Latitude: 70° 15' 44.023" N +E/-W 0.00 ft Easting: 558,702.73 ft Longitude: 149° 31' 31.597" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft ..Wellbore 1J-166,L2 - Magnetics Model Name Sample Date Declination Dip Angle Field Strength.. 2004 9/1(2004 (°) 24 64 (°) 72 80 (nT) ~ 57,570 bggm _ . _ _ . _ Design 1J-166. L2 (wp07) _ Audit Notes: Version: Phase: PLAN Tie On Depth: 5,033.39 Vertical Section: Depth From (ND) +N/-S +EI-W Direction (ft) (ft) (ft) (°) 28.00 0.00 0.00 0.00 11/4/2005 5:40:44PM Page 2 of 8 COMPASS 2003.11 Build 48 ORIGINAL ` ~-°' Halliburton Company H~+-~~Il~u~rr~N ConocoPhllllps Planning Report -Geographic Alaska Sperry Drlllin~ Servlce~ Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-166 Company: ConocoPhillips Alaska (Kuparuk) 1VD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J`Pad North R®ference: True Well: Plan 1J-166 Survey Calculation Method: Minimum Curvature Wellbore: 1J-166 L2 Design: 1J-166 L2 (wp07) Plan Summary Measured Vertical Dogleg Build Turn bepth Inclination Azimuth Depth +N/-S +E/-W Rate (°I100ft) Rate (°1100ft) Rate (°I100ft) TFO ~ (ft) (°) (°) (ft) (ft) (ft) ( ) 5,033.39 77.00 2.51 3,416.00 1,466.00 -1,995.55 0.00 0.00 0.00 0.00 5,046.39 79.07 2.51 3,418.69 1,478.70 -1,995.00 15.90 15.90 0.00 0.00 5,076.39 79.07 2.51 3,424.38 1,508.13 -1,993.71 0.00 0.00 0.00 0.00 5,267.72 89.59 2.51 3,443.27 1,698.07 -1,985.38 5.50 5.50 0.00 360.00 5,334.00 90.31 6.08 3,443.33 1,764.16 -1,980.41 5.50 1.08 5.39 78.68 6,125.85 90.31 6.08 3,439.09 2,551.54 -1,896.48 0.00 0.00 0.00 0.00 6,315.19 89.59 0.45 3,439.27 2,740.49 -1,885.69 3.00 -0.38 -2.98 -97.24 7,815.19 89.59 0.45 3,450.00 4,240.40 -1,873.91 0.00 0.00 0.00 0.00 7,869.66 87.96 0.45 3,451.17 4,294.86 -1,873.49 3.00 -3.00 -0.01 -179.88 8,285.51 87.96 0.45 3,466.00 4,710.43 -1,870.25 0.00 0.00 0.00 0.00 8,324.63 89.13 0.45 3,466.99 4,749.54 -1,869.94 3.00 3.00 0.00 0.01 8,785.63 89.13 0.45 3,474.00 5,210.47 -1,866.35 0.00 0.00 0.00 0.00 8,841.57 90.81 0.45 3,474.03 5,266.40 -1,865.91 3.00 3.00 0.00 0.00 8,985.66 90.81 0.45 3,472.00 5,410.48 -1,864.79 0.00 0.00 0.00 0.00 9,066.61 88.38 0.45 3,472.57 5,491.42 -1,864.16 3.00 -3.00 0.00 180.00 9,505.90 88.38 0.45 3,485.00 5,930.52 -1,860.74 0.00 0.00 0.00 0.00 9,571.87 90.36 0.45 3,485.73 5,996.48 -1,860.22 3.00 3.00 0.00 0.00 9,847.94 90.36 0.45 3,484.00 6,272.54 -1,858.07 0.00 0.00 0.00 0.00 10,058.54 98.78 0.44 3,467.23 6,482.27 -1,856.44 4.00 4.00 0.00 -0.01 10,163.94 98.78 0.44 3,451.14 6,586.43 -1,855.63 0.00 0.00 0.00 0.00 10,434.00 87.98 0.45 3,435.24 6,855.61 -1,853.53 4.00 -4.00 0.00 179.97 10,484.00 87.98 0.45 3,437.00 6,905.58 -1,853.13 0.00 0.00 0.00 0.00 10,507.13 87.52 0.45 3,437.91 6,928.70 -1,852.95 2.00 -2.00 -0.01 -179.58 11,178.71 87.52 0.45 3,467.00 7,599.62 -1,847.72 0.00 0.00 0.00 0.00 11,280.35 89.55 0.45 3,469.60 7,701.21 -1,846.93 2.00 2.00 0.00 0.00 11,585.80 89.55 0.45 3,472.00 8,006.65 -1,844.55 0.00 0.00 0.00 0.00 11,657.81 88.11 0.45 3,473.47 8,078.64 -1,843.99 2.00 -2.00 0.00 -180.00 11,977.03 88.11 0.45 3,484.00 8,397.68 -1,841.50 0.00 0.00 0.00 0.00 12,005.51 87.54 0.45 3,485.08 8,426.13 -1,841.28 2.00 -2.00 0.00 180.00 12,376.43 87.54 0.45 3,501.00 8,796.70 -1,838.39 0.00 0.00 0.00 0.00 12,396.16 87.15 0.45 3,501.91 8,816.41 -1,838.24 2.00 -2.00 0.00 -180.00 12,980.23 87.15 0.45 3,531.00 9,399.74 -1,833.69 0.00 0.00 0.00 0.00 11/4/2005 5.~40:44PM Page 3 of 8 COMPASS 2003.11 Build 48 ORIGINAL / ~ ~ ~``°°' Halliburton Company Conoco Phillips Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Project: Kuparuk RiverUnit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1J-166 Survey Calculation Method: Wellbore: 1J-166 L2 Design: 1 J-166 L2 (wp07) ,~ HALLIBU~i'1"'CirN Sperry Drilling Services Well Plan 1J-166 Planning RKB @ 109.OOft (Doyon 141 (28+81)) Planning RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature Planned Survey 1J-166 L2 (wp07) -- - -- i Map Map MD dncllnatlon Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft1 1ft) (ft) (ft) (ft) (°/100ft) {ft) 5,033.39 77.00 2.51 3,416.00 3,307.00 1,466.00 -1,995.55 5,947,142.00 556,696.00 0.00 1,466.00 ~ L2 : TOW : 5033ft MD, 3416ft TVD : 1834ft FNL & 778ft FWL Sec 35 - T1 1 N - R10E -West Sak D - 7 518" 5,046.39 79.07 2.51 3,418.69 3,309.69 1,478.70 -1,995.00 5,947,154.70 556,696.46 15.90 1,478.70 L2 : BOW : 5046ft MD, 3418ft TVD 5,076.39 79.07 2.51 3,424.38 3,315.38 1,508.13 -1,993.71 5,947,184.14 556,697.52 0.00 1,508.13 L2 : End 30' Rathole , Build ~ 5.5°/100ft , 5076ft MD, 3424ft TVD 5,100.00 80.36 2.51 3,428.60 3,319.60 1,531.34 -1,992.69 5,947,207.35 556,698.35 5.50 1,531.34 5,200.00 85.86 2.51 3,440.58 3,331.58 1,630.48 -1,988.34 5,947,306.52 556,701.93 5.50 1,630.48 5,267.72 89.59 2.51 3,443.27 3,334.27 1,698.07 -1,985.38 5,947,374.12 556,704.36 5.50 1,698.07 5,300.00 89.94 4.25 3,443.40 3,334.40 1,730.30 -1,983.48 5,947,406.36 556,706.02 5.50 1,730.30 5,334.00 90.31 6.08 3,443.33 3,334.33 1,764.16 -1,980.41 5,947,440.24 556,708.81 5.50 1,764.16 L2 : Sail at 90.31°, 5334ft MD, 3443ft TVD 5,400.00 90.31 6.08 3,442.97 3,333.97 1,829.78 -1,973.42 5,947,505.91 556,715.30 0.00 1,829.78 5,500.00 90.31 6.08 3,442.44 3,333.44 1,929.22 -1,962.82 5,947,605.41 556,725.12 0.00 1,929.22 5,600.00 90.31 6.08 3,441.90 3,332.90 2,028.65 -1,952.22 5,947,704.92 556,734.94 0.00 2,028.65 5,700.00 90.31 6.08 3,441.37 3,332.37 2,128.09 -1,941.62 5,947,804.42 556,744.77 0.00 2,128.09 5,800.00 90.31 6.08 3,440.84 3,331.84 2,227.52 -1,931.02 5,947,903.93 556,754.59 0.00 2,227.52 5,900.00 90.31 6.08 3,440.30 3,331.30 2,326.96 -1,920.42 5,948,003.44 556,764.41 0.00 2,326.96 6,000.00 90.31 6.08 3,439.77 3,330.77 2,426.40 -1,909.82 5,948,102.94 556,774.24 0.00 2,426.40 6,100.00 90.31 6.08 3,439.23 3,330.23 2,525.83 -1,899.22 5,948,202.45 556,784.06 0.00 2,525.83 6,125.85 90.31 6.08 3,439.09 3,330.09 2,551.54 -1,896.48 5,948,228.17 556,786.60 0.00 2,551.54 L2 : Continue Geosteer in D Sand, 8128ft MD, 3439ft TVD 6,200.00 90.03 3.88 3,438.88 3,329.88 2,625.40 -1,890.04 5,948,302.07 556,792.46 3.00 2,625.40 6,300.00 89.65 0.90 3,439.17 3,330.17 2,725.30 -1,885.87 5,948,401.99 556,795.85 3.00 2,725.30 6,315.19 89.59 0.45 3,439.27 3,330.27 2,740.49 -1,885.69 5,948,417.18 556,795.91 3.00 2,740.49 6,400.00 89.59 0.45 3,439.87 3,330.87 2,825.29 -1,885.03 5,948,501.98 556,795.92 0.00 2,825.29 6,500.00 89.59 0.45 3,440.59 3,331.59 2,925.29 -1,884.24 5,948,601.97 556,795.92 0.00 2,925.29 6,600.00 89.59 0.45 3,441.30 3,332.30 3,025.28 -1,883.46 5,948,701.96 556,795.93 0.00 3,025.28 6,700.00 89.59 0.45 3,442.02 3,333.02 3,125.28 -1,882.67 5,948,801.95 556,795.94 0.00 3,125.28 6,800.00 89.59 0.45 3,442.74 3,333.74 3,225.27 -1,881.88 5,948,901.93 556,795.94 0.00 3,225.27 6,900.00 89.59 0.45 3,443.45 3,334.45 3,325.27 -1,881.10 5,949,001.92 556,795.95 0.00 3,325.27 7,000.00 89.59 0.45 3,444.17 3,335.17 3,42526 -1,880.31 5,949,101.91 556,795.95 0.00 3,425.26 7,100.00 89.59 0.45 3,444.88 3,335.88 3,525.25 -1,879.53 5,949,201.90 556,795.96 0.00 3,525.25 7,200.00 89.59 0.45 3,445.60 3,336.60 3,625.25 -1,878.74 5,949,301.89 556,795.96 0.00 3,625.25 7,300.00 89.59 0.45 3,446.31 3,337.31 3,725.24 -1,877.96 5,949,401.87 556,795.97 0.00 3,725.24 7,400.00 89.59 0.45 3,447.03 3,338.03 3,825.24 -1,877.17 5,949,501.86 556,795.98 0.00 3,825.24 7,500.00 89.59 0.45 3,447.74 3,338.74 3,925.23 -1,876.39 5,949,601.85 556,795.98 0.00 3,925.23 7,600.00 89.59 0.45 3,448.46 3,339.46 4,025.23 -1,875.60 5,949,701.84 556,795.99 0.00 4,025.23 7,700.00 89.59 0.45 3,449.18 3,340.18 4,125.22 -1,874.82 5,949,801.82 556,795.99 0.00 4,125.22 7,800.00 89.59 0.45 3,449.89 3,340.89 4,225.22 -1,874.03 5,949,901.81 556,796.00 0.00 4,225.22 7,815.19 89.59 0.45 3,450.00 3,341.00 4,240.40 -1,873.91 5,949,917.00 556,796.00 0.00 4,240.40 1J-166 L2 T1 (wp07) 7,869.66 87.96 0.45 3,451.17 3,342.17 4,294.86 -1,873.49 5,949,971.45 556,796.00 3.00 4,294.86 7,900.00 87.96 0.45 3,45225 3,343.25 4,325.18 -1,873.25 5,950,001.77 556,796.00 0.00 4,325.18 8,000.00 87.96 0.45 3,455.82 3,346.82 4,425.11 -1,872.47 5,950,101.70 556,796.00 0.00 4,425.11 8,100.00 87.96 0.45 3,459.38 3,350.38 4,525.04 -1,871.69 5,950,201.62 556,796.00 0.00 4,525.04 8,200.00 87.96 0.45 3,462.95 3,353.95 4,624.98 -1,870.91 5,950,301.55 556,796.00 0.00 4,624.98 11/4/2005 5:40:44PM Page 4 of 8 COMPASS 2003.11 Build 48 ORIGINAL ~~, ""'~ Halliburton Company Conoco Phifllps Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Company: ConocoPhillips Alaska (Kuparuk) ND Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1J-166 Survey Calculation Method: Wellbore: 1J-166 L2 Design: 1J-166 L2 (wp07) r-rAr.r.rr~u~aror~ Sperry Drilling Serviceas„ Well Plan 1J-166 Planning RKB @ 109.OOft (Doyon 141 (28+81)) Planning RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature Planned Survey 1J-166 L2 (wp07) Map Map MD Inclination Azimuth TVD SSTVD +N!-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) Yft) (ft) (ft) (ft) 8,285.51 87.96 0.45 3,466.00 3,357.00 4,710.43 -1,870.25 5,950,387.00 556,796.00 1J-156 L2 T2 (wp07) 8,300.00 88.39 0.45 3,466.46 3,357.46 4,724.91 -1,870.13 5,950,401.48 556,796.00 8,324.63 89.13 0.45 3,466.99 3,357.99 4,749.54 -1,869.94 5,950,426.10 556,796.00 8,400.00 89.13 0.45 3,468.14 3,359.14 4,824.90 -1,869.36 5,950,501.45 556,796.00 8,500.00 89.13 0.45 3,469.66 3,360.66 4,924.88 -1,868.58 5,950,601.43 556,796.00 8,600.00 89.13 0.45 3,471.18 3,362.18 5,024.87 -1,867.80 5,950,701.41 556,796.00 8,700.00 89.13 0.45 3,472.70 3,363.70 5,124.85 -1,867.02 5,950,801.39 556,796.00 8,785.63 89.13 0.45 3,474.00 3,365.00 5,210.47 -1,866.35 5,950,887.00 556,796.00 1J-186 L2 T3 (wp07) 8,800.00 89.56 0.45 3,474.16 3,365.16 5,224.84 -1,866.24 5,950,901.37 556,796.00 8,841.57 90.81 0.45 3,474.03 3,365.03 5,266.40 -1,865.91 5,950,942.93 556,796.00 8,900.00 90.81 0.45 3,473.21 3,364.21 5,324.83 -1,865.46 5,951,001.35 556,796.00 8,985.66 90.81 0.45 3,472.00 3,363.00 5,410.48 -1,864.79 5,951,087.00 556,796.00 1 J-168 L2 T4 (wp07) 9,000.00 90.38 0.45 3,471.85 3,362.85 5,424.82 -1,864.68 5,951,101.33 556,796.00 9,066.61 88.38 0.45 3,472.57 3,363.57 5,491.42 -1,864.16 5,951,167.93 556,796.00 9,100.00 88.38 0.45 3,473.52 3,364.52 5,524.79 -1,863.90 5,951,201.30 556,796.00 9,200.00 88.38 0.45 3,476.35 3,367.35 5,624.75 -1,863.12 5,951,301.25 556,796.00 9,300.00 88.38 0.45 3,479.18 3,370.18 5,724.71 -1,862.34 5,951,401.20 556,796.00 9,400.00 88.38 0.45 3,482.00 3,373.00 5,824.66 -1,861.56 5,951,501.15 556,796.00 9,500.00 88.38 0.45 3,484.83 3,375.83 5,924.62 -1,860.78 5,951,601.10 556,796.00 9,505.90 88.38 0.45 3,485.00 3,376.00 5,930.52 -1,860.74 5,951,607.00 556,796.00 L2 : Possible Downthrown Fault, 8505ft MD, 3485ft TVD -1 J-155 L2 T5 (wp07) 9,571.87 90.36 0.45 3,485.73 3,376.73 5,996.48 -1,860.22 5,951,672.96 556,796.00 9,600.00 90.36 0.45 3,485.55 3,376.55 6,024.61 -1,860.00 5,951,701.09 556,796.00 9,700.00 90.36 0.45 3,484.93 3,375.93 6,124.60 -1,859.22 5,951,801.07 556,796.00 9,800.00 90.36 0.45 3,484.30 3,375.30 6,224.60 -1,858.44 5,951,901.06 556,796.00 9,847.94 90.36 0.45 3,484.00 3,375.00 6,272.54 -1,858.07 5,951,949.00 556,796.00 L2 : Build ~ 3°l100ft -Exit D-Sand High in Prep for Upthrown Fault, 9848ft MD, 3484ft TVD -1J-166 L2 T5 (wp07) 9,900.00 92.44 0.45 3,482.73 3,373.73 6,324.57 -1,857.66 5,952,001.03 556,796.00 10,000.00 96.44 0.45 3,474.99 3,365.99 6,424.25 -1,856.89 5,952,100.70 556,796.00 10,058.54 98.78 0.44 3,467.23 3,358.23 6,482.27 -1,856.44 5,952,158.72 556,796.00 10,100.00 98.78 0.44 3,460.90 3,351.90 6,523.24 -1,856.12 5,952,199.69 556,796.00 10,163.94 98.78 0.44 3,451.14 3,342.14 6,586.43 -1,855.63 5,952,262.87 556,795.99 10,200.00 97.34 0.45 3,446.09 3,337.09 6,622.13 -1,855.35 5,952,298.57 556,795.99 10,300.00 93.34 0.45 3,436.78 3,327.78 6,721.67 -1,854.57 5,952,398.11 556,795.99 10,400.00 89.34 0.45 3,434.44 3,325.44 6,821.62 -1,853.79 5,952,498.05 556,796.00 10,434.00 87.98 0.45 3,435.24 3,326.24 6,855.61 -1,853.53 5,952,532.04 556,796.00 10,484.00 87.98 0.45 3,437.00 3,328.00 6,905.58 -1,853.13 5,952,582.00 556,796.00 DLSEV Vert Section (°1100ft) (ft) 0.00 4,710.43 2.99 4,724.91 3.00 4,749.54 0.00 4,824.90 0.00 4,924.88 0.00 5,024.87 0.00 5,124.85 0.00 5,210.47 2.99 5,224.84 3.00 5,266.40 0.00 5,324.83 0.00 5,410.48 2.99 5,424.82 3.00 5,491.42 0.00 5,524.79 0.00 5,624.75 0.00 5,724.71 0.00 5,824.66 0.00 5,924.62 0.00 5,930.52 3.00 5,996.48 0.00 6,024.61 0.00 6,124.60 0.00 6,224.60 0.00 6,272.54 4.00 6,324.57 4.00 6,424.25 4.00 6,482.27 0.00 6,523.24 0.00 6,586.43 4.00 6,622.13 4.00 6,721.67 4.00 6,821.62 4.00 6,855.61 0.00 6,905.58 1J-165 L2 T7 (wp07) 10,500.00 87.66 0.45 3,437.61 3,328.61 6,921.57 -1,853.01 5,952,597.99 556,796.00 2.00 6,921.57 10,507.13 87.52 0.45 3,437.91 3,328.91 6,928.70 -1,852.95 5,952,605.11 556,796.00 2.00 6,928.70 10,600.00 87.52 0.45 3,441.93 3,332.93 7,021.47 -1,852.23 5,952,697.88 556,796.00 0.00 7,021.47 10,700.00 87.52 0.45 3,446.26 3,337.26 7,121.37 -1,851.45 5,952,797.78 556,796.00 0.00 7,121.37 10,800.00 87.52 0.45 3,450.60 3,341.60 7,221.28 -1,850.67 5,952,897.68 556,796.00 0.00 7,221.28 10,900.00 87.52 0.45 3,454.93 3,345.93 7,321.18 -1,849.89 5,952,997.57 556,796.00 0.00 7,321.18 11/42005 5:40:44PM Page 5 of 8 COMPASS 2003.11 Build 48 ORIGINAL / '" Halliburton Company ConocoPhilllps Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad WeIL' Plan 1J-166 Wellbore: 1J-1.66 L2 Design: 1J-166 L2 (wp07) HALLIIC~lJRTC>rN Sperry Drilling Snrviaes Local Co-ordinate Reference: Well Plan 1J-166 TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: Minimum Curvature Pianned Survey 1J-166 L2 (wp07) Map Map MD Inclination Azimuth TVD SSTVD +N/-5 +E1-W Northing fasting DLSEV Vert Section (ft) (°) (°) (ft) fft1 Ift) (ft) (ft) (ft) (°/100ft) (ftl 11,000.00 87.52 0.45 3,459.26 3,350.26 7,421.08 -1,849.11 5,953,097.47 556,796.00 0.00 7,421.08 11,100.00 87.52 0.45 3,463.59 3,354.59 7,520.99 -1,848.34 5,953,197.37 556,796.00 0.00 7,520.99 11,178.71 87.52 0.45 3,467.00 3,358.00 7,599.62 -1,847.72 5,953,276.00 556,796.00 0.00 7,599.62 1J-166 L2 T8 (wg07) 11,200.00 87.94 0.45 3,467.84 3,358.84 7,620.89 -1,847.56 5,953,297.27 556,796.00 2.00 7,620.89 11,280.35 89.55 0.45 3,469.60 3,360.60 7,701.21 -1,846.93 5,953,377.58 556,796.00 2.00 7,701.21 11,300.00 89.55 0.45 3,469.76 3,360.76 7,720.87 -1,846.78 5,953,397.24 556,796.00 0.00 7,720.87 11,400.00 89.55 0.45 3,470.54 3,361.54 7,820.86 -1,846.00 5,953,497.22 556,796.00 0.00 7,820.86 11,500.00 89.55 0.45 3,471.33 3,362.33 7,920.86 -1,845.22 5,953,597.21 556,796.00 0.00 7,920.86 11,585.80 89.55 0.45 3,472.00 3,363.00 8,006.65 -1,844.55 5,953,683.00 556,796.00 0.00 8,006.65 1J-166 L2 T9 (wp07) 11,600.00 89.27 0.45 3,472.15 3,363.15 8,020.85 -1,844.44 5,953,697.20 556,796.00 1.99 8,020.85 11,657.81 88.11 0.45 3,473.47 3,364.47 8,078.64 -1,843.99 5,953,754.99 556,796.00 2.00 8,078.64 11,700.00 88.11 0.45 3,474.86 3,365.86 8,120.81 -1,843.66 5,953,797.15 556,796.00 0.00 8,120.81 11,800.00 88.11 0.45 3,478.16 3,369.16 8,220.75 -1,842.88 5,953,897.08 556,796.00 0.00 8,220.75 11,900.00 88.11 0.45 3,481.46 3,372.46 8,320.69 -1,842.10 5,953,997.02 556,796.00 0.00 8,320.69 11,977.03 88.11 0.45 3,484.00 3,375.00 8,397.68 -1,841.50 5,954,074.00 556,796.00 0.00 8,397.68 1J-166 L2 T10 (wp10) 12,000.00 87.65 0.45 3,484.85 3,375.85 8,420.63 -1,841.32 5,954,096.95 556,796.00 2.00 8,420.63 12,005.51 87.54 0.45 3,485.08 3,376.08 8,426.13 -1,841.28 5,954,102.45 556,796.00 2.00 8,426.13 12,100.00 87.54 0.45 3,489.14 3,380.14 8,520.54 -1,840.54 5,954,196.85 556,796.00 0.00 8,520.54 12,200.00 87.54 0.45 3,493.43 3,384.43 8,620.44 -1,839.76 5,954,296.75 556,796.00 0.00 8,620.44 12,300.00 87.54 0.45 3,497.72 3,388.72 8,720.35 -1,838.98 5,954,396.65 556,796.00 0.00 8,720.35 12,376.43 87.54 0.45 3,501.00 3,392.00 8,796.70 -1,838.39 5,954,473.00 556,796.00 0.00 8,796.70 1J-166 L2 T11 (wpOT) 12,396.16 87.15 0.45 3,501.91 3,392.91 8,816.41 -1,838.24 5,954,492.71 556,796.00 2.00 8,816.41 12,400.00 87.15 0.45 3,502.11 3,393.11 8,820.25 -1,838.21 5,954,496.54 556,796.00 0.00 8,820.25 12,500.00 87.15 0.45 3,507.09 3,398.09 8,920.12 -1,837.43 5,954,596.41 556,796.00 0.00 8,920.12 12,600.00 87.15 0.45 3,512.07 3,403.07 9,019.99 -1,836.65 5,954,696.27 556,796.00 0.00 9,019.99 12,700.00 87.15 0.45 3,517.05 3,408.05 9,119.87 -1,835.87 5,954,796.14 556,796.00 0.00 9,119.87 12,800.00 87.15 0.45 3,522.02 3,413.02 9,219.74 -1,835.09 5,954,896.01 556,796.00 0.00 9,219.74 12,900.00 87.15 0.45 3,527.00 3,418.00 9,319.61 -1,834.31 5,954,995.87 556,796.00 0.00 9,319.61 12,980.23 87.15 0.45 3,531.00 3,422.00 9,399.74 -1,833.69 5,955,076.00 556,796.00 0.00 9,399.74 L2 : BHL (~ 12980ft MD, 3531ft TVD : T20ft FSL 8 948ft FWL -Sec 23 - - ' T11 N - R10E - 4112" 91/4/2005 5:40:44PM Page 6 of 8 COMPASS 2003.11 Build 48 ORIGINAL ` ~~ `"'°~ / Halliiburton Company HALLlf3Uf~Ti~N Conoco Phdhps Planning Report -Geographic Alaska Sp+arry Drilling S~nrices Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-166 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+g1)) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-166 Survey Calculation Method: Minimum Curvature Wellbore: 1J-166 L2 Design: 1J-166 L2 (wp07) Geologic Targets 1 J-166 L2 T'~/D Target Name +N/-S +E/-W Northing Fasting (ft) -Shape ft ft (ft) (ft) 3,485.00 1J-186 L2 T5 (wp07) 5,930.52 -1,860.74 5,951,607.00 556,796.00 - Point 3,474.00 1J-186 L2 T3 (wp07) 5,210.47 -1,866.35 5,950,887.00 556,796.00 - Point 3,484.00 1J-166 L2 T8 (wp07) 6,272.54 -1,858.07 5,951,949.00 556,796.00 - Point 3,437.00 1J-166 L2 T7 (wp07) 6,905.58 -1,853.13 5,952,582.00 556,796.00 - Point 3,501.00 1J-166 L2 T11 (wp07) 8,796.70 -1,838.39 5,954,473.00 556,796.00 - Point 3,531.00 1J-166 L2 T12 Toe (wp07) 9,399.74 -1,833.69 5,955,076.00 556,796.00 - Point 3,484.00 1J-166 L2 T10 (wp10) 8,397.68 -1,841.50 5,954,074.00 556,796.00 - Point 3,466.00 1J-186 L2 T2 (wp07) 4,710.43 -1,870.25 5,950,387.00 556,796.00 - Point 3,467.00 1J-166 L2 T8 (wp07) 7,599.62 -1,847.72 5,953,276.00 556,796.00 - Point 3,472.00 1J-166 L2 T9 (wp07) 8,006.65 -1,844.55 5,953,683.00 556,796.00 - Point 3,450.00 1J-166 L2 T1 (wp07) 4,240.40 -1,873.91 5,949,917.00 556,796.00 - Point 3,472.00 1J-186 L2 T4 (wp07) 5,410.48 -1,864.79 5,951,087.00 556,796.00 - Point Prognosed Casing Points Measured Vertical Casing Hole. Depth Depth Diameter Diameter (ft) (ft) ('7 (") 80.00 80.00 20 28 2,359.67 2,183.00 10-314 13-112 5,033.40 3,416.00 7-518 9-718 12,980.22 3,531.00 4-112 8-3/4 11/4/7005 5:40:44PM Page 7 of 8 COMPASS 2003.11 Build 48 u ` ~ ~~ °"" / Halliburton Company IiALL13BUarc~nr Conaco Phllllps Planning Report -Geographic Alaska Sp@~'Y OriI1Mg Sorvlces Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: well Plan 1 J-166 Company: ConocoPhillips Alaska (Kuparuk) ND Reference: Planning RKB @ 109.o0ft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-166 Survey Calculation Method: . Minimum Curvature Wellbore: 1J-166 L2 Design: 1 J-166 L2 (wp07) Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N!-E +El-W Name 1ft) (°) (°) (ft) (ft) (ft) 1,564.10 32.54 250.00 1,514.00 -89.18 -245.01 Permafrost 1,712.37 32.54 250.00 1,639.00 -116.45 -319.94 T3 2,057.54 32.54 250.00 1,930.00 -179.94 -494.39 K15 2,359.67 34.74 267.80 2,183.00 -219.24 -653.82 T3+550 3,455.75 66.68 318.11 2,863.00 207.21 -1,342.07 Ugnu C 4,001.42 66.68 318.11 3,079.00 580.24 -1,676.66 Ugnu B 4,207.29 67.30 323.72 3,160.00 724.15 -1,799.44 Ugnu A 4,500.12 70.06 339.15 3,267.00 962.97 -1,929.05 K13 5,033.40 77.00 2.51 3,416.00 1,466.01 -1,995.55 West Sak D 11/4/2005 5:40:44PM Page 8 of 8 COMPASS 2003.118u1/d 48 OR161N.AL ,~, ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-166 1 J-166 L2 Anticollision Summary 04 November, 2005 .'~ip~'PI"',~ ~PI~~11'1~ 'S~ervlC~s ORI6lNAL SURVEY PROGRAM NAD 27 ASP Zone 4: WELL DETAILS: Plan iJ-166 AN71-COLLJSION SETTINGS Date: 20(LS-11-03TIXI:OO:fq Validated: Yea Version: Ground Level: 81.00 IMerpola[ion Method: MD Interval: 50Stations +WS +E/-W Northing Easting Latittude Longitude Depth Fmm DQplh Ta Sunzy/Plan Tool Depth Range Fran: 5033.39 To 12980.23 0.00 0.00 6%6691.74 558702.73 70°t 5'44.023N 149°31'31.597W 28.1x1 ROO.Iq C&CYRO-SS Maximus Range:1481.30656428897 Nlxl.gl 51133.39 MWD4IFR-AK-CAZSC Reference: Plan: tJ-166 L2 (wp07) 5033.39 12979.73 IJ-166 L2 (wp07) MWD+IFR-AK-CAZSC 330 0 270 ~om Colour To MD 0 250 250 500 500 -- --- _~- -~- 750 750 1000 180 1000 1250 1250 1500 1500 1750 Travelling Cylinder Azimuth (TFO+A7.1) ~°~ vs Centre tD Centre Separation X150 fdin~ 1750 2000 2000 - 3000 3000 4000 4000 5000 5000 6000 6000 7DD0 7000 - 6000 ConocoPhillips Alaska (Kupamk) Drilling 8 Wells Slot West Sak Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: 7rav. Cylinder North Error Surtace: Elliptical Conic Warning Method: Rules Based 60 240 I 120 2 25 210 150 30 180 Travelling Cylinder Azimuth (TFO+AZJ) ~°~ vs Centre t0 Centre Separation X15 ft/in) sccnoa a:raLs s« aro iM n:. Tw .ws .6J-w olne TQace vs~ Targei 1 6ox.x noe 1 6046.x ]9.0] 261 x19.06 14se.o0 x99565 0.00 2.61 x10.69 1{18]0 -199800 15.90 0.00 1196.00 O.W t{10.]0 3 50)6.19 ]9.0] d 528].]2 99.69 2.61 3421.38 1508.13 -19901 0.00 261 3413.2] 1fi900] -190530 6.60 000 1608.13 360.00 1899.0] 6 63x.00 90.31 fi 6126.86 90.J1 6.08 3{03.31 1)81.16 -189011 6.60 6.00 x39.09 266160 -1898.69 0.00 ]0.88 1)61.16 0.00 2561.61 ] 6315.19 89.69 8 ]815.19 89.69 046 x39.2] 2]10.19 -1086.89 3.00 0.46 x60.00 4260.{0 -10)191 0.00 e].x 2]d0.0.9 000 12b.40 iJ-166 L2 T11~'0011 9 18fi9.66 81.98 10 9286.61 01.98 045 31611) 6191.86 -1013.19 3.00 0.45 318800 111063 -10)0.26 0.00 -1]9.88 1294.88 0.00 {]10.13 1118811 T21wp011 11 933/.63 09.13 12 0]86.83 89-13 0.16 318899 dT{9.61 -1889.94 3.00 0.1fi x10.00 63104] -18fi6.J6 000 0.01 {10.9.61 0.00 621061 1.4168 L3 T31wP0]) 13 0011.6) 90.81 1{ 8986.68 9081 0.16 x11.03 6288.40 -1886.91 3.00 0.{6 x12.00 6n0.19 -1881.]9 0.00 0.00 6208.00 0.00 x10A8 11188 L2 TI Iw90]) 15 9088.81 88.38 16 9606.90 88.30 OA6 x12.fi) bW1A3 -1860.18 3.00 0.{6 x0600 6930.62 -1880.)1 0.00 100.00 6191.{2 0.00 69]0.62 11188 L2 TS IwpOTI 1] 9611.8] 90.x 18 986].x 90.38 OA6 3185]3 6988.18 -186022 3.00 0.46 x84.00 82]2.60 1868.0) 0.00 0.00 69%.48 0.00 82T6.64 11168 L2 Te 1wp0Tl 19 10060.61 98.]8 20 1018] W 99.18 0.40 318123 61822) -1868.M 0.00 O.M x61.11 6586.63 1856.83 0.00 J1.01 6682.21 000 fib%.43 21 101x.00 9].98 21 10164.x0 a1.9e 0.46 xJ6.20 6065.61 -1BW.63 0.00 0.46 x3].QO fieo669 -1966.13 0.00 1]9.9] 6866.81 6.x6 8906.60 111x9 L2nlw9)1 23 10601.13 81.62 26 111]8.]1 8].62 0.46 x1).91 8928.)0 -196296 2.00 OK 3181.00 )699.82 -191].]2 0.00 -119.68 8828.]0 0.00 ]588.82 11188 L3 TBIw9]1 26 11280.36 09.66 26 11506.80 99.66 046 118960 T]01.211808.93 2.00 0.66 x1200 800fi66 ~18M.66 0.00 0.00 ]]QI.21 000 800665 1118fi L2 T911w6]I 2] 1166).81 08.11 18 119>).O3 BB.it 0.66 x13.4] 9010.x 1843.99 2.00 0.{6 3196.00 Bx].fi8 -1x1.60 000 -18000 80]866 0.00 839].88 1J-166 L2 T101wP10) R 12006.61 8].61 x 123)60.1 81.61 0.16 3106.08 0128.13 -1841.28 2.00 0.{6 360100 8198.]0 -1839.39 0.00 190.00 0626.13 0.00 01%.]0 11188 LI T111wpOT) 31 12396.16 81.15 32 12980.23 81.16 0.{6 3601.91 881811 -18x.x 2.00 0.{6 363100 93991d -1933.89 0.00 -180.00 881641 0.00 9399.]{ 11188 L2 T12 Tce 1°N9T) REFERENCE INFORMATION 8000 9000 9000 10000 Coordinate (WE) Reference: Well Plan tJ-166, True North Vertical (TVD) Reference: PWnning RKB ~ t09.00fl (DOyon 141 (28+81)) 10000 11000 ~/ ConocoPhillips Alaska Company; ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-166 Well Error: O.OOft Reference Wellbore 1J-166 L2 Reference Design: 1J-166 L2 (wp07) Halliburton Company Anticollision Report Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: HALL..IBEJI~'TON Sperry Drilling Servic®s Well Plan 1J-166 Planning RKB @ 109.OOft (Doyon 141 (28+81)) Planning RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature 2.57 sigma EDM 2003.11 Single User Db Offset Datum Reference 1J-166 L2 (wp07) Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 50.OOft Error Model: ISCWSA Depth Range: 5,368.39 to 12,944.98ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,481.31ft Error Surtace: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 1113/2005 From To (ft) (ft) Survey (Wellbore) 28.00 800.00 1J-166 (wp07) (1J-166) 800.00 5,033.39 1J-166 (wp07) (1J-166) 5,033.39 12,979.73 1J-166 L2 (wp07) (1J-166 L2) Tool Name Description CB-GYRO-SS Camera based gyro single shot MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary Reference Offset Centre to No-Go Allowable .Measured Measured Centre Distance Deviation. Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 1 E Pad 1 E-105 - 1 E-105 - 1 E-105 12,913.88 11,550.00 1,286.17 262.08 1,024.09 Pass -Major Risk 1E-105 - 1E-105L1 - 1E-105L1 12,897.30 11,550.00 1,279.72 269.37 1,010.35 Pass -Major Risk 1 E-105 - 1 E-105L2 - 1 E-105L2 12,145.76 12,300.00 1,298.26 251.04 1,047.22 Pass -Major Risk 1 E-105 - 1 E-105PB2 - 1 E-105P62 12,368.97 12,100.00 1,272.64 257.53 1,015.11 Pass -Major Risk Kuparuk 1J Pad 1 J-03 - 1 J-03 - 1 J-03 Out of range 1J-09 - 1J-09 - 1J-09 7,108.00 5,450.00 907.29 158.40 748.88 Pass -Major Risk 1J-10 - 1J-10 - 1J-10 Out of range 1J-168 - 1J-168 - 1J-168 Rig Out of range 1J-168 - 1J-168 L1 - 1J-168 L1 Rig Out of range 1 J-168 - 1 J-168 L2 - 1 J-168 L2 Out of range 1J-168 - 1J-168 L2 PB1 - 1J-168 L2 P61 Rig Out of range Plan 1J-109 -Plan 1J-109 - 1J-109 (wp01) BHI Out of range Plan 1J-115 (L9) -Plan 1J-L9 Lat A -Plan 1J-L9 L Out of range Plan 1J-118 (L10) -Plan 1 J-L10 Lat A -Plan 1J-L' Out of range Plan 1J-120 (L11) -Plan 1J-L11 Lat A -Plan 1J-L' Out of range Plan 1J-122 (L12) -Plan 1 J-L12 Lat A -Plan 1J-L' Out of range Plan 1J-124 (L13) -Plan 1J-L13 Lat A -Plan 1J-L' Out of range Plan 1J-127 (LS) -Plan 1J-L8 LatA -Plan 1J-L8 L~ Out of range Plan 1J-150 (Ugnu Disposal) -Plan 1J-UgnuDispc 6,533.80 4,900.00 690.28 120.23 570.05 Pass -Major Risk Plan 1J-152 (M5) - 1J-152 - 1J-152 (wp04) 5,368.80 3,450.00 1,240.00 86.77 1,153.23 Pass -Major Risk Plan 1J-152 (M5) - 1J-152 L1 - 1J-152 L1 (wp04) 5,368.80 3,450.00 1,240.00 86.75 1,153.25 Pass -Major Risk Plan 1J-152 (M5) - 1J-152 L2 - 1J-152 L2 (wp04) 5,368.80 3,450.00 1,240.00 86.75 1,153.24 Pass -Major Risk Plan 1J-164 - 1J-164 - 1J-164 (wp07) 12,547.90 11,403.54 1,289.76 303.68 986.07 Pass -Major Risk Plan 1J-164 - 1J-164 L1 - 1J-164 L1 (wp07) 12,636.13 11,485.60 1,270.15 339.72 930.43 Pass -Major Risk Plan 1J-164 - 1J-164 L2 - 1J-164 L2 (wp07) 12,663.04 11,507.42 1,266.90 344.80 922.11 Pass -Major Risk Plan 1J-170 -Plan 1J-170 - 1J-170 (wp01) 5,376.68 7,850.00 1,301.77 123.62 1,178.14 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 11/4/2005 5:54:25PM Page 2 of 2 COMPASS 2003.11 Build 48 ;?R!G!pJAL n (~ Insulated Conductor n Casing, 20", 94#, K55 z Q ~ 34", 0.312" WT ~ +/- 80' MD D~ u. b t/1 ~r P~ A m 'r7 F [r1 r' s w n n ^. " ~ o 0 3 0 _~ .A c. a b sa ~~ a~~~ Tubing, 4-'/" IBTM, from LEM to A2 Liner, with seal stem and - CAMCO 3.562" "DB" nipple. ~ Seal bore and ZXP packer for A2liner ~ / +/- 9p' below'B" window 7-5/8", 40#, L-80, BTCM, R3 Csg ~~ a 6,288' MD / 3,645' TVD --! 84 degrees TD 9-5/8" hole ~~ "D° Liner, 4-1/2", 12. 11-166 L2' (0.125" x 2.5" slots, 32 per foot, 5.9%open area) 6- D sand lateml TD 12,980' MD 531' TVD Angle 87.1 ~~ ds~- a~ 166 L1~-~~°d Window ~r3U8'MD/3,489'TVD U- L1: 80 degrees "B" Lt , L80, BTCM, R3 6-3/ sand lateral (0.125" x 2.5" slots, 32 per foot, 5.9% open area) TD 12 945' MD / 3,588' TVD Angle 87 degrees I1-166. A2 Sand Liner, 4-I/2", 12.8#, L80, 6-3/4 A2 sand lateral .~- BTCM, R3'/z slotted and'/: blank, TD 12,841' MD / 3,733' TVD ~ cona2ric(rw.c for i.ro/nlir,n ~1 Angle 88.85 degrees Wellhead /Tubing Head /Tree, 10-3/4" x 4-''/x", 5,000 ksi Tubing String: 4-1/2", 12 6 #, L-80, [BTM 10-3/4", 68#, 1. 80, BTC, R3 ~ @2,360'MD/2,183'TVD- n 34.7 degrees TD 13-3/8" hole Top of Ugnu C nu, ~ 3,456' MD / 2,863' TVD Top of West Sak B na, ~ 5,355' MD / 3,487' TVD Lateral Entry Module #1 (LEM), Baker, with seal bore and 7-XP packer above. (1)Gas LiR Mandrel, CAMCO 4-I/2"x l" Mode1KBG- 2,one(1)set rd 2,400'MD, 2,2I6'TVD. (I)Gas LiR Mandrel, CAMCO 4-I/2"x 1" ModeIKBG- 2, one (I) set at < 72 deg, 4,700' MD, 3,331' TVD, Electric Submersible Pnmp, CentriliR 418 HP motor, with FC6000 wireline deployed pump. Bottom at 5,000' MD, 3,408' TVD 166 L2 "D" Sand Window n 5,033'MD/3,416'TVD 77 degrees Top of West Sak A an, ~ 5,579' MD / 3,526' TVD • ~,i `~~,,, TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPIiS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~,~u /°T ~~ C. Z- PTD# ?.D ~' ~~ ~E~~~a ~~ CHECK WHAT i ADD-ONS "CLUE" i APPLIES i (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) The permit is for a new we 1 ore segment of existing well /~~ ~ ~' ~~~ L Z Permit No~oS`- /gB~API No. S'"D -(~Z°j--Z~ ~r'O~ Production should continue to be reported as a function of the original API number stated above. PILOT HOLE ~ In accordance with 20 AAC 25.005(fj, all ~ (PIT) 1 records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) ~ and API number (50 - ~ 70/80) from records, data and logs acquired for welt (name on permit). SPACL'~iG ~ The permit is approved subject to full EXCEPTION I compliance with 20 AAC 25.055. Approval to perforate and groduce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH I Ali dry ditch sample sets submitted to the SAMPLE ~ Commission must be in no greater than 30' ~ sample intervals from below the permafrost j or from where samples are f€rst caught and IO' sample intervals through target zones. Rev: 04/01 /05 Cijody\transmittal checklist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL-490150 Well Name: KUPARUK RIV U WSAK 1J-166L2 Program DEV _ Well bore seg PTD#:2052000 Company CONOCOPHILLIPS ALASKA INC Initial Classliype DEV / PEND GeoArea 890 Unit 11170 On/Off Shore On Annular Disposal 'u Administration ;1 Permit fee attached- - - . N_A- - . - - West Sak D Sand multilateral well segment; fee waived per 20 AAC 25,005{e), . _ !2 Lease number appropriate_ - - - - - - - - - - - - - - - - - Yes Surface location and top productive interval in ADL 025661;. TD in ADL 025650.. - - .... _ .. - I3 Uniquewell-name and number--- --- ---- --- --- -- Yes - - --- --- - ----- ------- ------------------------------------ 4 Well located in a-definedpogl_ - - - - _ - , . Yes . - - . KRU West_Sak Oil Pool,goyerned_by Conservation-Order No, 4068- . 15 Well located properdistance-from drilling unit_boundary- --- - - - - - - - - - - - - - - - - - - - - Yes - _ _ - .. -Well is more-than_500 feet from an external ro _e- line.. _ - _ - - - . - - - - .. - P P dY '6 Well located proper distance from other wells- - - - - - - - - - - - - - Yes No restrictions as_to well s acin m CO 4066._ - - . - P g '7 Sufficient acreage available in-drilling unit- - Yes - - - _ - . - No restrictions as_to well spacing except that no_pay shall be o _ened in a well closer _ .. - , P ',8 If deviated, is-wellbore plat_included - - - .. - . Yes - _ - - - . ,than 500 feet to-an external,property line._ - 9 Operator only affected party____,----.-__ _----------------_ Yes- __---.__ ___ - - -- '10 Operator has-appropriate. bond in force....- ---- --- -------- ---- Yes - -- --- ---- - ---------- --- -- - - ---- -- - - - - 11 Permit_canbeissuedwithout~nsenrationorder---------------------------- Yes- -_.,____--._. -- Appr Date ';12 Permitc_an be issued without administrative-approval _ _ - .. - _ _ , - Yes - . - ... - - .. - SFD 12!8/2005 '13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authprized by Injection Orde[# (put1O# in_comments)_(Fpr. NA_ . _ -- - 15 All wells within1/4_mileareaofreyiewident~ed(Forservicewellonly)___-_-______-- NA__ ________________________----_---_---------_-----_------_-- _ 116 Pre-produced injector; duration.of pre production less than_ 3 months-(For service well only) .. NA_ - _ - _ _ - - . - _ _ - . _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - i ACMP-Finding of Consistency.has been issued_forthis project_ _ - NA_ _ Engineering 18 Conductorstring_provided-------------------__-.___--____-______ NA__ _---__Conductorset_inmotherbore,_1J,166(205-198x.__.-_--_-_, _______--------___---.----- 19 SurfacecasingproteetsallknownU$DWs----..______________________- NA__ __--__Allaquifersexempted, 4DCFR_147.102(b)_(3~.__-______-------__-,-----___--_..-_-. 20 CMT-vol. adequate-to circulate.on conductor & surf_csg - - - - - - - - - - - - - _ - - _ _ - - - - NA_ _ _ - - . .Surface casing set in_motherbore.. _ _ _ - - - - _ _ - - - _ _ ------------------------ ~ 21 CMT-vol-adeguate_totie-in longstringtourfag---------------------------- NA__ ______Production-casing set in motherbore._______-_---__-_---_-_-___-_-_---__--_----- 22 CMT-will coverall knownproductiye horizons_ - ... - - . _ - _ - - .. - No- _ Slotted liner completion planned-- - - - - - - - - - - - - - - - - - - -- 23 Casing designs adequate for C, T B &.permafrost . . . . . . .... . .. . . . . . NA_ _ - - - _ _ _ Motherbore met design requiremeots._ NA for slotted_liner, _ _ - - _ - _ - _ - - - _ - - . - , - _ _ - , - - - , - - - 24 Adequate tankage-or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - Yes _ - Rig is_equipped with steel-pits. _ No reserve-pitplanned, All waste to approved annulus ordisposalwell.- . - - - - - 25 If a-re-drill, has.a.10-403 for abandonment been approved - - - - - - - NA_ _ - _ - - 26 Adequate wellbore separation-proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - . - - _ _ _ Proximit analysisperformed. _NearestBranch is_B section ~70' tvd below, - _ _ _ _ - _ ----- -------- 27 If dive[ter required, does it meet regulations- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ BOP stack_will already-be in place, _ _ - - _ _ - - _ _ _ - - - Appr Date 28 Drilling fluid_program schematic & equip listadequate . . . . .... . . ... . . . . . . . . .. Yes _ - - - _ - -Maximum expected formation pressure 8,7,EMW._ Planned MW 8.9_ppg.- - . - - _ _ _ - - . - . _ - - TEM 12/13/2005 29 BOPEs, do they meet regulation . - Yes +~~ i 30 _ _ _ _ „ _ . BOPE press rating appropriate; test to (put prig in comments) . _ - - - - Yes . . - - _ _ - - _ _ - _ - -- - .. - MASP calculated at 1201 psi, 3000_psi_BOf? testproposed._ _ - - - 31 Choke-manifold complies wlAPI-RP-53 (May 84) Yes _ _ _ _ - - - - 32 Work willoccurwithoutoperationshutdown___________ ___________________ Yes_ --___-.-__-._ - ---------------------------------------------- 33 Is presence. of H2S gas-probable_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ No- - - - - - - - $Ight_H2S_is reported in offset wells. Mud should preclude H2S on rig. _ Rig has_sensors and alarms. - - - _ _ _ _ - ,34 Mechanical.conditionofwellswithinAORyerified(Forse[vicewellonly)-------------- NA__ _____- -------__ ___-----.-_-„_----.----_---.--__ Geology 35 Permil can be issued wlo hydrogen-sulfide measures . - - - - - .. - - . Yes . . , _ _ Nearest wells in-pool, ! D-127-& 1 D-131-measured 2 & 8.ppmin 2002 &_2004, 36 Data_presented on potential overpressure zones Yes . - - _ respectively._ Expeeted_reservoir pressure is 8.7ppg EMW; will be drilled with . . - - _ Appr Date 37 Seismic-anal sis_ of shallow as-zones- ... - . - y g - .... - - - IJA- . - - - _ - - 8.6 ppg oil-based mud. Mitigation measures discuss.in Drilljng Hazards section. SFD 1218!2005 38 Seabed condition survey_(if off-shore) - .. NA - - 39 Contact name/phone for weekly_progress reports [exploratory only] . _ NA- . - _ Geologic Commissioner: Engineering Pu West Sak D Sand multilateral well se ment. SFD Date: Commissioner: Date Co s Date 9 ~1 ~ f~ t Well History File APPENDIX Information of detailed nature that is not particularly gem~ane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drting Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue May 02 11:37:29 2006 'fJU / V f~~ Reel Header Service name .............LISTPE Date .....................06/05/02 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Tape Header Service name .............LISTPE Date .....................06/05/02 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-166 L2 API NUMBER: 500292329161 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 02-MAY-06 JOB DATA MWD RUN 2 MWD RUN 7 MWD RUN 8 JOB NUMBER: MW0004149018 MW0004149018 MW0004149018 LOGGING ENGINEER: P. ORTH T. CALVIN P. ORTH OPERATOR WITNESS: D. GLADDEN M. THORNTON M. THORNTON MWD RUN 9 MWD RUN 10 MWD RUN 11 JOB NUMBER: MW0004149018 MW0004149018 MW0004149018 LOGGING ENGINEER: P. ORTH P. ORTH P. ORTH OPERATOR WITNESS: M. THORNTON M. THORNTON M. THORNTON SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 1880 FEL: 2508 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: 81.00 ## WELL CASING RECORD OPEN HOLE CASING DRILLERS ' ~ ~ BIT S Y~,' (IN) SIZE (IN) DEPTH (FT) ~ 1ST STRING 9.875 10.750 2368.0 2ND STRING 6.750 7.875 6350.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK EXITING THE 1J-166 L2 PB1 WELLBORE AT 7680'MD/3455'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,8-11 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 8-11 ALSO INCLUDED AT-BIT INCLINATION (ABI) AND GEOPILOT ROTARY STEERABLE BHA (GP) THE PURPOSE OF MWD RUN 7 WAS TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. ONLY SROP DATA ARE PRESENTED FOR RUN 7. 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 1,2,7-11 REPRESENT WELL 1J-166 L2 WITH API#:50-029-23291-61. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12994'MD/3531TVD. 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. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 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 GR 2331.0 12936.0 FET 2350.0 12943.5 RPM 2350.0 12943.5 RPX 2350.0 12943.5 RPD 2350.0 12943.5 RPS 2350.0 12943.5 ROP 2378.5 12994.0 I i ,~~',' 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 2 2331.0 5005.0 7 5005.5 5046.0 8 5046.0 7530.0 9 7530.0 7680.0 10 7680.5 8901.0 11 8901.0 12994.5 REMARKS: MERGED MAIN PASS. S 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 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 2331 12994 7662.5 21327 2331 12994 RPD MWD OHMM 1.21 2000 54.395 21185 2350 12943.5 RPM MWD OHMM 3.53 1073.44 43.583 21188 2350 12943.5 RPS MWD OHMM 4.09 269.45 47.1477 21188 2350 12943.5 RPX MWD OHMM 4.1 473.23 47.4718 21188 2350 12943.5 FET MWD HOUR 0.13 429.24 1.70724 21188 2350 12943.5 GR MWD API 23.8"~' 130.17 69.4568 21211 ~f2331 ROP MWD FT/H 0.03 643.1 214.369 21232 2378.5 First Reading For Entire File..........2331 Last Reading For Entire File...........12994 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2331.0 5005.0 RPD 2350.0 5005.0 RPM 2350.0 5005.0 RPX 2350.0 5005.0 RPS 2350.0 5005.0 FET 2350.0 5005.0 ROP 2378.5 5005.0 LOG HEADER DATA DATE LOGGED: 13-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5005.0 TOP LOG INTERVAL (FT) 2378.0 BOTTOM LOG INTERVAL (FT) 5005.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 34.4 MAXIMUM ANGLE: g2.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 163686 EWR4 ELECTROMAG. RESIS. 4 56933 1293& 12994 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (TN) 9.875 DRILLER'S CASING DEPTH (FT): 2368.0 $OREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G) 9.25 MUD VISCOSITY (S) 59.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 100 FLUID LOSS (C3) 4.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.900 60.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.580 116.0 MUD FILTRATE AT MT: 3.500 60.0 MUD CAKE AT MT: 3.000 60.0 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 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2331 5005 3668 5349 2331 5005 RPD MWD020 OHMM 1.21 2000 20.0928 5311 2350 5005 RPM MWD020 OHMM 3.53 1073.44 11.8892 5311 2350 5005 RPS MWD020 OHMM 4.09 35.45 11.3487 5311 2350 5005 RPX MWD020 OHMM 4.1 29.97 10.7364 5311 2350 5005 FET MWD020 HOUR 0.18 53.06 1.06102 5311 2350 5005 GR MWD020 API 23.81 114.32 67.7627 5349 2331 5005 ROP MWD020 FT/H 6.22 461.05 206.126 5254 2378.5 5005 First Reading For Entire File..........2331 Last Reading For Entire File...........5005 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 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 5005.5 5046.0 LOG HEADER DATA DATE LOGGED: 30-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5046.0 TOP LOG INTERVAL (FT) 5005.0 BOTTOM LOG INTERVAL (FT) 5046.0 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) 6.750 DRILLER'S CASING DEPTH (FT) 6350.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 74.0 MUD PH: •0 MUD CHLORIDES (PPM): 111000 FLUID LOSS (C3) •8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 75.9 MUD FILTRATE AT MTV 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 .000 .000 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 Name Service Unit Min Max DEPT FT 5005.5 5046 ROP MWD070 FT/H 2.21 113.98 Mean Nsam 5025.75 82 49.1298 82 First Reading For Entire File..........5005.5 Last Reading For Entire File...........5046 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD ~o, .0 First Reading 5005.5 5005.5 Last Reading 5046 5046 Curves and log header dal~for each bit run in separate fr~s. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 5005.5 7479.0 GR 5005.5 7472.5 RPM 5005.5 7479.0 RPX 5005.5 7479.0 RPS 5005.5 7479.0 RPD 5005.5 7479.0 ROP 5046.5 7530.0 LOG HEADER DATA DATE LOGGED: 31-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7530.0 TOP LOG INTERVAL (FT) 5046.0 BOTTOM LOG INTERVAL (FT) 7530.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 82.9 MAXIMUM ANGLE: 93.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 EWR4 Electromag Resis. 4 159439 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6350.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.85 MUD VISCOSITY (S) 82.0 MUD PH: •0 MUD CHLORIDES (PPM): 27000 FLUID LOSS (C3) 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 108.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): #f 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 RPD MWD080 OHMM 4 1 68 4 2 RPM MWDO80 OHMM 4 1 68 8 3 RPS MWDO80 OHMM 4 1 68 12 4 RPX MWD080 OHMM 4 1 68 16 5 FET MWD080 HOUR 4 1 68 20 6 GR MWDO80 API 4 1 68 24 7 ROP MWDO80 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5005.5 7530 6267.75 5050 5005.5 7530 RPD MWD080 OHMM 4.45 133.73 60.2471 4948 5005.5 7479 RPM MWD080 OHMM 4.72 113.15 52.3896 4948 5005.5 7479 RPS MWD080 OHMM 10.03 157.11 52.8949 4948 5005.5 7479 RPX MWD080 OHMM 8.87 210.57 50.2877 4948 5005.5 7479 FET MWD080 HOUR 0.17 429.24 2.97462 4948 5005.5 7479 GR MWD080 API 49.63 94.75 68.0098 4935 5005.5 7472.5 ROP MWD080 FT/H 5.04 347.7 218.191 4968 5046.5 7530 First Reading For Entire File..........5005.5 Last Reading For Entire File...........7530 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 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 GR 7473.0 7680.0 ~` ' FET 7479. ~°° 7680.0 RPS 7479.5 7680.0 RPX 7479.5 7680.0 RPM 7479.5 7680.0 RPD 7479.5 7680.0 ROP 7530.5 7680.0 S LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): O1-FEB-06 Insite 66.37 Memory 7680.0 7530.0 7680.0 86.3 95.6 TOOL NUMBER 178505 4 159439 6.750 6350.0 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 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 Mineral Oil Base 8.85 82.0 .0 27000 3.0 .000 .0 .000 108.0 .000 .0 .000 .0 ` '~' Name Service Order Units S rsz Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD090 OHMM 4 1 68 4 2 RPM MWD090 OHMM 4 1 68 8 3 RPS MWD090 OHMM 4 1 68 12 4 RPX MWD090 OHMM 4 1 68 16 5 FET MWD090 HOUR 4 1 68 20 6 GR MWD090 API 4 1 68 24 7 ROP MWD090 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7473 7680 7576.5 415 7473 7680 RPD MWD090 OHMM 60.17 136.42 94.028 402 7479.5 7680 RPM MWD090 OHMM 50.01 105.81 75.6005 402 7479.5 7680 RPS MWD090 OHMM 50.66 129.68 79.0502 402 7479.5 7680 RPX MWD090 OHMM 49.09 145.48 76.0065 402 7479.5 7680 FET MWD090 HOUR 0.18 16.15 4.44199 402 7479.5 7680 GR MWD090 API 47.17 82.94 65.2123 415 7473 7680 ROP MWD090 FT/H 10.2 310.79 167.986 300 7530.5 7680 First Reading For Entire File..........7473 Last Reading For Entire File...........7680 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 7680.5 8850.0 ROP 7680.5 8901.0 RPX 7680.5 8850.0 RPS 7680.5 8850.0 RPD 7680.5 8850.0 GR 7680.5 8843.5 RPM 7680.5 8850.0 s LO G HEADER DATA DATE LOGGED: 02-FEB- 06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8901.0 TOP LOG INTERVAL (FT) 7680.0 BOTTOM LOG INTERVAL (FT) 8901.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 83.4 MAXIMUM ANGLE: 93.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 EWR4 Electromag Resis. 4 159439 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6350.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 67.0 MUD PH: •0 MUD CHLORIDES (PPM): 22000 FLUID LOSS (C3) 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 115.0 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 RPD MWD100 OHMM 4 1 68 4 2 RPM MWD100 OHMM 4 1 68 8 3 RPS MWD100 OHMM 4 1 68 12 4 RPX MWD100 OHMM 4 1 68 16 5 FET MWD100 HOUR 4 1 68 20 6 ~ GR MWD100 ~ API 1 68 24 7 ROP MWD100 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7680.5 8901 8290.75 2442 7680.5 8901 RPD MWD100 OHMM 14.09 112.37 52.7825 2340 7680.5 8850 RPM MWD100 OHMM 12.61 78.22 45.2918 2340 7680.5 8850 RPS MWD100 OHMM 12.27 90.75 48.9231 2340 7680.5 8850 RPX MWD100 OHMM 12.12 110.23 49.1875 2340 7680.5 8850 FET MWD100 HOUR 0.21 25.76 3.12476 2340 7680.5 8850 GR MWD100 API 48.86 92.97 69.7426 2327 7680.5 8843.5 ROP MWD100 FT/H 0.03 403.18 185.841 2442 7680.5 8901 First Reading For Entire File..........7680.5 Last Reading For Entire File...........8901 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 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.......06/05/02 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 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8844.0 12936.0 RPM 8850.5 12943.5 RPS 8850.5 12943.5 RPX 8850.5 12943.5 FET 8850.5 12943.5 RPD 8850.5 12943.5 ROP 8901.5 12994.5 LOG HEADER DATA DATE LOGGED: 05-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) `'~-° 12994.0 TOP LOG INTERVAL (FT) 8901.0 BOTTOM LOG INTERVAL (FT) 12994.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.2 MAXIMUM ANGLE: 95.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 EWR4 Electromag Resis. 4 159439 S BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6350.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.75 MUD VISCOSITY (S) 65.0 MUD PH: •0 MUD CHLORIDES (PPM): 18000 FLUID LOSS (C3) 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 123.8 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 RPD MWD110 OHMM 4 1 68 4 2 RPM MWD110 OHMM 4 1 68 8 3 RPS MWD110 OHMM 4 1 68 12 4 RPX MWD110 OHMM 4 1 68 16 5 FET MWD110 HOUR 4 1 68 20 6 GR MWD110 API 4 1 68 24 7 ROP MWD110 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 884' 12994.5 10919.3 8302 RPD MWD110 OHMM 9.5 2000 71.6252 8187 RPM MWD110 OHMM 8.67 171.76 56.7601 8187 RPS MWD110 OHMM 8.63 269.45 64.8236 8187 RPX MWD110 OHMM 8.38 473.23 67.7091 8187 FET MWD110 HOUR 0.13 19.54 0.821041 8187 GR MWD110 API 40.92 130.17 71.5703 8185 ROP MWD110 FT/H 0.57 643.1 229.191 8187 First Reading For Entire File..........8844 Last Reading For Entire File...........12994.5 File Trailer Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.008 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/05/02 Origin ...................STS Tape Name ................LTNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................06/05/02 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF ~` ' 8844 ~ 12994.5 8850.5 12943.5 8850.5 12943.5 8850.5 12943.5 8850.5 12943.5 8850.5 12943.5 8844 12936 8901.5 12994.5 Scientific Technical Services Scientific Technical Services End Of LIS File - - ~ ....+.... ~ nJ Sperry-Sun Dr`~rling Services /3 ~? G `~ ~8,} '~?~-~ LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue May 02 14:38:03 2006 Reel Header Service name .............LISTPE Date .....................06/05/02 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Tape Header Service name .............LISTPE Date .....................06/05/02 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-166 L2 PB1 API NUMBER: 500292329171 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 02-MAY-06 JOB DATA MWD RUN 2 MWD RUN 7 MWD RUN 8 JOB NUMBER: MW0004149018 MW0004149018 MW0004149018 LOGGING ENGINEER: P. ORTH T. GALVIN P. ORTH OPERATOR WITNESS: D. GLADDEN M. THORTON M. THORTON MWD RUN 9 JOB NUMBER: MW0004149018 LOGGING ENGINEER: P. ORTH OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: 10E FNL: FSL: 1880 FEL: 2508 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS ~~ BIT S~rr$ (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 2368.0 2ND STRING 6.750 7.875 6350.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS LATERAL WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 5005'MD/ 3415'TVD, WITHIN THE RUN 2 INTERVAL OF 1J-166. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,8,9 COMPRISED DIRECTIONAL, DUAL GAMMA RAY(DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4(EWR4), AND PRESSURE WHILE DRILLING(PWD) MWD RUNS 8,9 ALSO INCLUDED AT-BIT INCLINATION (ABI) AND GEOPILOT ROTARY STEERABLE BHA (GP) THE PURPOSE OF MWD RUN 7 WAS TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. ONLY SROP DATA ARE PRESENTED FOR RUN 7. 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 1,2,7-9 REPRESENT WELL 1J-166 L2 PBl WITH API#:50-029-23291-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8359'MD/3455'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. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 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; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 2331.0 FET 2350.0 RPM 2350.0 RPS 2350.0 RPD 2350.0 RPX 2350.0 ROP 2378.5 all bit runs merged. STOP DEPTH 8301.0 8308.5 8308.5 8308.5 8308.5 8308.5 8359.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP 2 2331.0 7 5005.5 8 5046.0 9 7530.0 REMARKS: MERGED MAIN PASS. MERGE BASE 5005.0 5046.0 7530.0 8359.0 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 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2331 8359 5345 12057 2331 8359 RPD MWD OHMM 1.21 2000 43.1004 11918 2350 8308.5 RPM MWD OHMM 3.53 1073.44 34.2795 11918 2350 8308.5 RPS MWD OHMM 4.09 157.11 34.4993 11918 2350 8308.5 RPX MWD OHMM 4.1 210.57 32.8586 11918 2350 8308.5 FET MWD HOUR 0.17 429.24 1.9269 11918 2350 8308.5 GR MWD API 23.81 114.32 68.0438 11941 2331 8301 ROP MWD FT/H 2.21 461.05 204.233 11962 2378.5 8359 i First Reading For Entire File..........2331 Last Reading For Entire File...........8359 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 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 BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY for each bit run in separate files. VENDOR TOOL CODE START DEPTH GR 2331.0 RPD 2350.0 RPX 2350.0 RPM 2350.0 FET 2350.0 RPS 2350.0 ROP 2378.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) STOP DEPTH 5005.0 5005.0 5005.0 5005.0 5005.0 5005.0 5005.0 13-JAN-06 Insite 68.18 Memory 5005.0 2378.0 5005.0 34.4 82.5 VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 163686 EWR4 ELECTROMAG. RESIS. 4 56933 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 ' ' ~'(FT DRILLER' S CASING DEP'I ) 2368. 0 "~" BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G) 9.25 MUD VISCOSITY (S) 59.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 100 FLUID LOSS (C3) 4.4 RESISTIVITY (OHMM) AT TEMP ERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.900 60.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.580 116.0 MUD FILTRATE AT MT: 3.500 60.0 MUD CAKE AT MT: 3.000 60.0 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 N sam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2331 5005 3668 5349 2331 5005 RPD MWD020 OHMM 1.21 2000 20.0928 5311 2350 5005 RPM MWD020 OHMM 3.53 1073.44 11.8892 5311 2350 5005 RPS MWD020 OHMM 4.09 35.45 11.3487 5311 2350 5005 RPX MWD020 OHMM 4.1 29.97 10.7364 5311 2350 5005 FET MWD020 HOUR 0.18 53.06 1.06102 5311 2350 5005 GR MWD020 API 23.81 114.32 67.7627 5349 2331 5005 ROP MWD020 FT/H 6.22 461.05 206.126 5254 2378.5 5005 First Reading For Entire File..........2331 Last Reading For Entire File...........5005 File Trailer Service name .............STSLIB.002 Service Sub Level Name ..``:~--' `~'J Version Number...........1.0.0 Date of Generation.......06/05/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 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 5005.5 5046.0 LOG HEADER DATA DATE LOGGED: 30-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5046.0 TOP LOG INTERVAL (FT) 5005.0 BOTTOM LOG INTERVAL (FT) 5046.0 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) 6.750 DRILLER'S CASING DEPTH (FT) 6350.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) $•80 MUD VISCOSITY (S) 74.0 MUD PH: •0 MUD CHLORIDES (PPM): 111000 FLUID LOSS (C3) •a RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 75.9 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 Name Service Unit Min Max DEPT FT 5005.5 5046 ROP MWD070 FT/H 2.21 113.98 Mean Nsam 5025.75 82 49.1298 82 First Reading 5005.5 5005.5 Last Reading 5046 5046 First Reading For Entire File..........5005.5 Last Reading For Entire File...........5046 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 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 # ``~,, FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5005.5 7472.5 FET 5005.5 7479.0 RPX 5005.5 7479.0 RPM 5005.5 7479.0 RPD 5005.5 7479.0 RPS 5005.5 7479.0 ROP 5046.5 7530.0 LO G HEADER DATA DATE LOGGED: 31-JAN- 06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7530.0 TOP LOG INTERVAL (FT) 5046.0 BOTTOM LOG INTERVAL (FT) 7530.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 82.9 MAXIMUM ANGLE: 93.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 EWR4 Electromag Resis. 4 159439 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6350.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.85 MUD VISCOSITY (S) 82.0 MUD PH: •0 MUD CHLORIDES (PPM): 27000 FLUID LOSS (C3) 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 108.0 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: S 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 Specificat ion Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWDO80 OHMM 4 1 68 4 2 RPM MWD080 OHMM 4 1 68 8 3 RPS MWD080 OHMM 4 1 68 12 4 RPX MWD080 OHMM 4 1 68 16 5 FET MWD080 HOUR 4 1 68 20 6 GR MWD080 API 4 1 68 24 7 ROP MWD080 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5005.5 7530 6267.75 5050 5005.5 7530 RPD MWD080 OHMM 4.45 133.73 60.2471 4948 5005.5 7479 RPM MWD080 OHMM 4.72 113.15 52.3896 4948 5005.5 7479 RPS MWD080 OHMM 10.03 157.11 52.8949 4948 5005.5 7479 RPX MWD080 OHMM 8.87 210.57 50.2877 4948 5005.5 7479 FET MWD080 HOUR 0.17 429.24 2.97462 4948 5005.5 7479 GR MWDO80 API 49.63 94.75 68.0098 4935 5005.5 7472.5 ROP MWD080 FT/H 5.04 347.7 218.191 4968 5046.5 7530 First Reading For Entire File..........5005.5 Last Reading For Entire Fi1e...........7530 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 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 GR 7473.0 8301.0 RPX 7479.5 8308.5 RPD 7479.5 8308.5 FET 7479.5 8308.5 `` ' ` 8308.5 RPM 7479. x ` RPS 7479.5 8308.5 ROP 7530.5 8359.0 LO G HEADER DATA DATE LOGGED: O1-FEB- 06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8359.0 TOP LOG INTERVAL (FT) 7530.0 BOTTOM LOG INTERVAL (FT) 8359.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.3 MAXIMUM ANGLE: 95.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 EWR4 Electromag Resis. 4 159439 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6350.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.85 MUD VISCOSITY (S) 82.0 MUD PH: .0 MUD CHLORIDES (PPM): 27000 FLUID LOSS (C3) 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 108.0 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 RPD MWD090 OHMM 4 1 68 4 2 ~` ' ~~ RPM MWD090 OHMM ~ 4 1 68 8 3 RPS MWD090 OHMM 4 1 68 12 4 RPX MWD090 OHMM 4 1 68 16 5 FET MWD090 HOUR 4 1 68 20 6 GR MWD090 API 4 1 68 24 7 ROP MWD090 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7473 8359 7916 1773 7473 8359 RPD MWD090 OHMM 24.27 149.85 65.615 1659 7479.5 8308.5 RPM MWD090 OHMM 21.32 113.94 51.9441 1659 7479.5 8308.5 RPS MWD090 OHMM 20.33 146 53.7469 1659 7479.5 8308.5 RPX MWD090 OHMM 18.96 174.81 51.696 1659 7479.5 8308.5 FET MWD090 HOUR 0.18 16.15 1.57402 1659 7479.5 8308.5 GR MWD090 API 47.17 87.6 69.0521 1657 7473 8301 ROP MWD090 FT/H 8.07 342.74 164.082 1658 7530.5 8359 First Reading For Entire File..........7473 Last Reading For Entire File...........8359 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/05/02 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................06/05/02 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
