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Home My WebLink About207-0471. 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): 16033'None Casing Collapse Structural Conductor Surface Intermediate Production D Liner Slotted 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 9/15/2024 16033'7573' 4-1/2" 3750' Packer: Baker Premier Packer SSSV: None Perforation Depth MD (ft): L-80 9917' 4070' 9944' Slotted Liner: 8533-15988' 4-1/2" Slotted Liner: 3640-3749' Perforation Depth TVD (ft): 108' 4100' 20" 10-3/4" 78' 7-5/8" 8199' MD MD 108' 2470' 3871' 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 207-047 P.O. Box 100360, Anchorage, AK 99510 50-029-23352-61-00 Kuparuk River Field West Sak Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 8147' MD and 3578' 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 Staff Wells Engineer KRU 1J-120L2 3750' 16033' 3750' 902 psi 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: 2024.07.25 09:41:38 -08'00' 324-432 By Grace Christianson at 3:36 pm, Jul 25, 2024 DSR-7/31/24SFD 7/29/2024VTL 8/5/2024 10-404X *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.08.05 15:19:55 -08'00'08/05/24 RBDMS JSB 080624 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 24, 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- 120L1(PTD# 207-046) and 1J-120L2 (PTD# 207-047). Well 1J-120 was drilled and completed in June 2007 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. In 2014, it was worked over to install a Jet Pump upper completion and lastly a RWO was completed to install a rigless ESP system in 2017, but is currently gas lifted. 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 be snapped together with sealed junctions. 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3" G Profile x 2 3/8" Hyd511 Pin Down 1.2 8800 2330.65 Welltec 314WLTP, Metal Expandable Packer - Hyd511 3 8801.2 Lower Seal Bore Receptacle, 1.813" PB - Hyd 511 0.95 8804.2 5 2 3/8" Hydrill 511 4.6lb/ft, L-80 Blank Tubing 155 8805.15 11 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 341 8960.15 9 2 3/8" Hydrill 511 4.6lb/ft, L-80 Blank Tubing 279 9301.15 50 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 1550 9580.15 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 11130.15 NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 11130.65 1892.8 16 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 496 11131.95 10 2 3/8" Hydrill 511 4.6lb/ft, L-80 Blank Tubing 310 11627.95 35 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 1085 11937.95 2 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 13022.95 ϭ:ͲϭϮϬ>ϭ͕ϭ:ͲϭϮϬ>ϮZtKWƌŽĐĞĚƵƌĞ tĞƐƚ^ĂŬWƌŽĚƵĐĞƌ ^ĐƌĞĞŶ^ĐĂď>ŝŶĞƌ/ŶƐƚĂůů Wdη͛ƐϮϬϳͲϬϰϲ͕ϮϬϳͲϬϰϳ WĂŐĞϮŽĨϰ NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 13023.45 1396.8 45 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 1395 13024.75 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 14419.75 NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 14420.25 962.8 31 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 961 14421.55 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 15382.55 NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 15383.05 652.8 19 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 589 15384.35 2 2 3/8" Hydrill 511 4.6lb/ft, L-80 Blank Tubing 62 15973.35 Solid Bullnose - Hydrill 511 Box 0.5 16035.35 16035.85 ϴ͘ KŶ>ĂƐƚƌƵŶ͕^ĞƚWĂĐŬĞƌĂŶĚƌĞůĞĂƐĞ͘ ϵ͘ Z/,ĂŶĚ&ŝƐŚ/>ĨƌŽŵ>ϭ>D ^ĂŶĚ>ĂƚĞƌĂůKƉĞƌĂƚŝŽŶƐ;ϭ:ͲϭϮϬ>ϮͿ ϭϬ͘ Z/,ǁŝƚŚ/>^ĞƚƚŝŶŐ,͕ƐŶĂƉŝŶƚŽ>Ϯ>DΛϴϮϮϱ͛Z<ĂŶĚƐĞƚ͘ ϭϭ͘ Z/,ŽŶϮϱͬϴ͟ŽŝůĞĚdƵďŝŶŐĂŶĚĂϯ͟EŽǌǌůĞĂŶĚĐŽŶĨŝƌŵd͕WKK,ůĂǇŝŶŐŝŶϴ͘ϲƉƉŐƐůŝĐŬƐĞĂǁĂƚĞƌ͘ ϭϮ͘ 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 8392 1927.65 Welltec 314WLTP, Metal Expandable Packer - Hyd511 3 8393.2 Lower Seal Bore Receptacle, 1.813" PB - Hyd 511 0.95 8396.2 5 2 3/8" Hydrill 511 4.6lb/ft, L-80 Blank Tubing 155 8397.15 57 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 1767 8552.15 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 10319.15 NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 10319.65 1737.8 56 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 1736 10320.95 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 12056.95 NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 12057.45 1582.8 51 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 1581 12058.75 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 13639.75 NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 13640.25 1148.8 37 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 1147 13641.55 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 14788.55 NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 14789.05 776.8 25 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 775 14790.35 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 15565.35 NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 15565.85 466.3 14 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 434 15567.15 1 2 3/8" Hydrill 511 4.6lb/ft, L-80 Blank Tubing 31 16001.15 Solid Bullnose - Hydrill 511 Box 0.5 16032.15 16032.65 ϭ:ͲϭϮϬ>ϭ͕ϭ:ͲϭϮϬ>ϮZtKWƌŽĐĞĚƵƌĞ tĞƐƚ^ĂŬWƌŽĚƵĐĞƌ ^ĐƌĞĞŶ^ĐĂď>ŝŶĞƌ/ŶƐƚĂůů Wdη͛ƐϮϬϳͲϬϰϲ͕ϮϬϳͲϬϰϳ WĂŐĞϯŽĨϰ ϭϰ͘ KŶ>ĂƐƚƌƵŶ͕^ĞƚWĂĐŬĞƌĂŶĚƌĞůĞĂƐĞ͘ ϭϱ͘ Z/,ĂŶĚ&ŝƐŚ/>ĨƌŽŵ>Ϯ>D ϭϲ͘ Z/,ĂŶĚ&ŝƐŚWůƵŐĨƌŽŵEŝƉƉůĞΛϴϳϯϳ͛Z< ϭϳ͘ ĨƌĞĞǌĞƉƌŽƚĞĐƚǁĞůů͘ ϭϴ͘ ^ĞƚW/ƐŽ^ůĞĞǀĞΛϳϵϱϯ͛Z< ZDK ϭϵ͘ EKW͘ ϮϬ͘ ZDK͘ WŽƐƚͲZŝŐtŽƌŬ Ϯϭ͘ ZĞƚƵƌŶƚŽƉƌŽĚƵĐƚŝŽŶ 'ĞŶĞƌĂůtĞůůŝŶĨŽ͗ WƌŽĚƵĐƚŝŽŶŶŐŝŶĞĞƌ͗Carolyn Kirchner tŽƌŬŽǀĞƌŶŐŝŶĞĞƌ͗Elliott 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: ϵϬϮƉƐŝƵƐŝŶŐϬ͘ϭƉƐŝͬĨƚŐƌĂĚŝĞŶƚ Static BHP͗ϭϮϱϬƉƐŝͬϯϰϳϴ͛dsŵĞĂƐƵƌĞĚŽŶϰͬϭϰͬϮϬϮϬ;ϲ͘ϵƉƉŐͿ ϭ:ͲϭϮϬ>ϭ͕ϭ:ͲϭϮϬ>ϮZtKWƌŽĐĞĚƵƌĞ tĞƐƚ^ĂŬWƌŽĚƵĐĞƌ ^ĐƌĞĞŶ^ĐĂď>ŝŶĞƌ/ŶƐƚĂůů Wdη͛ƐϮϬϳͲϬϰϲ͕ϮϬϳͲϬϰϳ WĂŐĞϰŽĨϰ Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:1J-120 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason; Pulled ESP Equipment, Closed Sliding Sleeves, Installed Isolation Sleeve, & Installed GL 1J-120 4/10/2020 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: or inflow performance issue are suspected 11/13/2017 pproven NOTE: Well shut-in repeatedly-high motor temperature, and a restriction in the pump intake 11/13/2017 pproven NOTE: MULTI-LATERAL WELL- 1J-120 (A-SAND), 1J-120L1 (B-SAND), 1J-120L2 (D-SAND)6/16/2007 lmosbor Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR2019.12 30.0 108.0 108.094.00 K-55 WELDED SURFACE 10 3/49.9530.34,100.0 2,469.6 45.50 L-80 BTC INTERMEDIATE 7 5/86.8727.49,944.4 3,871.2 29.70 L80 BTCM D LINER LEM 4 1/2 3.96 8,164.5 8,398.0 3,636.6 12.60 L-80 IBTM D LINER HH 4 1/2 3.48 8,235.1 8,515.7 3,659.3 11.60 L-80 BTC B LINER LEM 4 1/2 3.96 8,369.7 8,815.5 3,705.4 12.60 L80 IBT B LINER HH 4 1/2 3.48 8,670.4 8,955.3 3,725.1 11.60 L-80 BTC A LINER Slotted 4 1/2 3.48 8,771.7 15,200.0 3,935.7 11.60 L80 BTC w/ TR Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 22.3 Set Depth … 8,145.5 Set Depth … 3,577.3 String Max No… 4 1/2 Tubing Description Tubing – Production 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) 22.3 22.3 0.00 Hanger 10.875 Tubing Hanger, Vetco-Gray MB222A offset 10 3/4 x 4 1/2 w/false bowl Vetco Gray MB222A 3.900 3,652.4 2,307.1 69.23 GAS LIFT 5.984 GLM, Camco, KBG-2, 4-/2" x 1" with CV & BK-5 Latch, SN:13175-23 Camco KBG-2 3.860 7,685.6 3,460.3 74.76 GAS LIFT 5.984 GLM, Camco, KBG-2, 4-1/2" x 1" with DV & BK-5 Latch, SN: 13175-01 Camco KBG-2 3.860 7,753.8 3,478.3 74.60 Gauge4.500Baker SureSENS Gauge Baker SureSE NS 3.938 7,822.6 3,496.6 74.59 Sliding Sleeve CMU (Closed) 4.500 Gas Venting Sliding Sleeve CMU (with position #3 ACCESS profile for keys), 3.875" X Profile, Access ( Closed 4/9/2020 ) Access CMD 3.875" X 3.958 7,853.63,504.8 74.79Sliding Sleeve CMD (Closed) 4.500 Gas Venting Sliding Sleeve CMD (with position #4 ACCESS profile for keys), 3.875" X Profile, (Closed 4/9/2020) Access CMU 3.875" X 3.958 7,917.6 3,521.3 75.31 Motor Shroud/Centrali zer 5.500 Motor Shroud / Centralizer, Access, 5-1/2" FJL Pin x 5-1/2" FJL Pin ( Pulled 11/28/2018 ) Access Shroud/ Centraliz er 4.900 7,953.8 3,530.4 75.54 Annular Connection Port 5.500 Annular Connection Port, Access, 5- 1/2" FJL Box x 4-1/2" Vam Top Box Set 4.5" Access ISO Sleeve OAL = 135.5" 11/28/2018 Access Annular Connecti on Port 3.840 7,992.4 3,540.0 75.77 Profile Sub 4.500 B-Profile Sub, Access, 4-1/2", 12.6#, L-80, TXP Box x Box Access B-profile sub 3.956 8,013.2 3,545.1 75.89 No-Go 3.80" Sub 4.500 No-Go 3.80" Sub, Access, 4-1/2, 12.6#, L-80, TXP Box x Pin Access 3.80' No- Go Sub 3.800 8,068.23,558.4 75.94 Sliding Sleeve - CMU (Closed) 4.500 CMU Sliding Sleeve, 3.813" DB profile, Baker (4/9/2020 ) 3.810 8,132.33,574.0 75.78 Locator 4.500 Locater Sub, Baker, GBH-22 (bottom of the locator spaced out 1.59') Baker GBH-22 3.880 8,133.13,574.2 75.78Seal Assembly 4.500 Baker 192-47 Seal Assembly 4-1/2", 12.6#, L-80, IBTM Box Baker 192-47 3.870 Top (ftKB) 8,134.0 Set Depth … 8,199.3 Set Depth … 3,590.9 String Max No… 4.51 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.98 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) 8,134.03,574.5 75.77 PBR 6.690 PBR, Baker, 80-47 with 6.69" scoop guide, 4-1/2" 12.6# TC-II Pin down Baker 80-47 4.750 8,147.03,577.7 75.64PACKER 6.570 Premier Packer, Baker, 659-387, 4- 1/2", 12.6# TC-II Box x Pin Baker 659-387 Premier 3.870 8,162.6 3,581.6 75.49 LOCATOR 5.180 Locater (bottom of the locator spaced out 1') Baker 3.980 8,163.5 3,581.8 75.49 MULE SHOE4.510Mule Shoe Joint Baker 3.980 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) 7,953.0 3,530.2 75.54 ACCESS ISOLATION SLEEVE 4 1/2" ACCESS ISOLATION SLEEVE W/ 3.85" PACKING (11.25' OAL) 6/5/2021 3.000 1J-120, 7/24/2024 8:11:38 AM Vertical schematic (actual) A LINER Slotted; 8,771.7- 15,200.0 CASING; 15,194.3-15,200.0 Swell Packer; 15,174.8-15,194.3 Swell Packer; 15,113.5-15,133.0 SLOTS; 14,350.0-15,113.0 SLOTS; 13,445.0-14,179.0 SLOTS; 12,506.0-13,145.0 SLOTS; 10,240.0-12,205.0 INTERMEDIATE; 27.4-9,944.4 Weatherford Model 303 Sure Seal Float Shoe; 9,942.9- 9,944.4 Weatherford Model 402 Sure Seal Float Collar; 9,856.7- 9,858.0 B LINER HH; 8,670.4-8,955.3 BENT JT; 8,924.9-8,955.3 B LINER LEM; 8,369.7-8,815.5 SEAL ASSY; 8,812.2-8,815.5 SBE; 8,803.4-8,823.1 HANGER; 8,793.6-8,803.4 NIPPLE; 8,790.7-8,793.6 PACKER; 8,771.7-8,790.7 NIPPLE; 8,737.6-8,739.1 HANGER; 8,687.2-8,693.4 HANGER; 8,670.7-8,694.8 HANGER; 8,670.4-8,687.2 HANGER; 8,663.9-8,670.7 D LINER HH; 8,235.1-8,515.7 XO BUSHING; 8,407.4-8,408.8 D LINER LEM; 8,164.5-8,398.0 SBR; 8,388.4-8,407.4 SEAL ASSY; 8,394.7-8,398.0 PACKER; 8,369.7-8,388.4 HANGER; 8,252.0-8,258.0 HANGER; 8,235.7-8,260.2 HANGER; 8,235.1-8,252.0 HANGER; 8,225.1-8,235.7 NIPPLE; 8,213.8-8,215.4 XO BUSHING; 8,202.8-8,204.2 SBE; 8,183.1-8,202.8 MULE SHOE; 8,163.5 PACKER; 8,175.4-8,183.1 SLEEVE; 8,164.5-8,175.4 LOCATOR; 8,162.6 PACKER; 8,147.0 PBR; 8,134.0 Seal Assembly; 8,133.1 Locator; 8,132.3 Sliding Sleeve - CMU (Closed); 8,068.2 No-Go 3.80" Sub; 8,013.2 Profile Sub; 7,992.4 Annular Connection Port; 7,953.8 ACCESS ISOLATION SLEEVE; 7,953.0 Motor Shroud/Centralizer; 7,917.6 XO Enlarging (Tubing); 7,914.5 Gauge; 7,753.7 GAS LIFT; 7,685.6 SURFACE; 30.3-4,100.0 FLOAT SHOE; 4,098.2-4,100.0 FLOAT COLLAR; 4,015.6- 4,017.2 GAS LIFT; 3,652.4 CONDUCTOR; 30.0-108.0 Hanger; 22.4 KUP PROD KB-Grd (ft) 32.29 RR Date 6/16/2007 Other Elev… 1J-120 ... TD Act Btm (ftKB) 15,822.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292335200 Wellbore Status PROD Max Angle & MD Incl (°) 92.84 MD (ftKB) 13,392.03 WELLNAME WELLBORE Annotation Last WO: End Date 9/21/2017 H2S (ppm) 20 Date 1/25/2019 Comment SSSV: NONE 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) 3,652.4 2,307.1 69.23 1 ESP GLV BK 1 1,449.0 4/10/2020 Schlumb erger Camco BK-5 0.188 7,685.63,460.3 74.76 2 ESP OVBK 1 0.0 4/10/2020 Schlumb erger Camco BK-5 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) 8,164.5 3,582.0 75.48 SLEEVE 6.390 5.75" ID Tie back sleeve 5.750 8,175.4 3,584.8 75.37 PACKER 5.510 5.5"x7.625" "HRD" ZXP Liner Top Packer w/ hold down slips 4.960 8,202.83,591.8 75.11 XO BUSHING6.010 5.5" BTC x 4.5" IBT Cross Over Bushing 3.960 8,213.83,594.6 75.13 NIPPLE 4.500 DB Nipple 3.75" ID, 4.5" IBTM Box x Pin 3.750 8,418.7 3,641.0 77.96 ECP5.623 Baker Payzone External Casing Packer 3.960 8,484.8 3,653.9 79.62 BENT JT 4.500 4 1/2" ,12.6 ppf, L-80 STL BENT joint Blank Casing 3.992 8,369.7 3,630.4 77.42 PACKER 6.550 ZXP 5-1/2" x 7-5/8" Liner Top Packer TOP 5.530 8,388.4 3,634.5 77.45 SBR 6.290 109-47 Casing Seal Bore Receptacle 6.26" OD x 4.75 4.750 8,407.4 3,638.6 77.67 XO BUSHING 5.500 XO Bushing 5-1/2" Hydril 563 x 4- 1/2" IBT 4.500 8,737.63,693.181.09 NIPPLE 5.210 Camco "DB-6" Nipple, I.D. 3.562", IBT 3.562 8,770.03,698.280.75 BENT JT 4.500 4-1/2, 12.6 ppf. L-80, X/O Bent Jt. IBT Box X STL 3.958 8,857.23,711.5 81.86 ECP5.623 Baker Payzone External Casing Packer 3.960 8,924.9 3,720.9 82.04 BENT JT 4.500 4 1/2" ,12.6 ppf, L-80 STL BENT joint Blank Casing 3.992 8,771.7 3,698.5 80.73 PACKER 6.560 5.5"x 7.63" Baker "HRD" ZXP Liner Top Pkr 5.750 8,790.7 3,701.5 80.84 NIPPLE 6.070 "RS" Packoff Seal Nipple, 6.07" OD / 4.87" ID 4.870 15,113.5 3,935.4 90.39 Swell Packer 6.300 Swell Packer #2 3.960 15,174.8 3,935.4 89.54 Swell Packer 6.300 Swell Packer #1 3.960 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 10,240.012,205.03,873.83,905.2 WS A2, 1J-120 5/17/2007 32.0SLOTS2.5"x .125",4 circumferencial rows/ft 3" centers staggered 18 deg 12,506.013,145.03,911.23,930.0 WS A2, 1J-120 5/17/2007 32.0SLOTS2.5"x .125",4 circumferencial rows/ft 3" centers staggered 18 deg 13,445.0 14,179.0 3,920.6 3,922.9 WS A2, 1J-120 5/17/2007 32.0 SLOTS 2.5"x .125",4 circumferencial rows/ft 3" centers staggered 18 deg 14,350.0 15,113.0 3,925.6 3,935.5 WS A2, 1J-120 5/17/2007 32.0 SLOTS 2.5"x .125",4 circumferencial rows/ft 3" centers staggered 18 deg 1J-120, 7/24/2024 8:11:42 AM Vertical schematic (actual) A LINER Slotted; 8,771.7- 15,200.0 CASING; 15,194.3-15,200.0 Swell Packer; 15,174.8-15,194.3 Swell Packer; 15,113.5-15,133.0 SLOTS; 14,350.0-15,113.0 SLOTS; 13,445.0-14,179.0 SLOTS; 12,506.0-13,145.0 SLOTS; 10,240.0-12,205.0 INTERMEDIATE; 27.4-9,944.4 Weatherford Model 303 Sure Seal Float Shoe; 9,942.9- 9,944.4 Weatherford Model 402 Sure Seal Float Collar; 9,856.7- 9,858.0 B LINER HH; 8,670.4-8,955.3 BENT JT; 8,924.9-8,955.3 B LINER LEM; 8,369.7-8,815.5 SEAL ASSY; 8,812.2-8,815.5 SBE; 8,803.4-8,823.1 HANGER; 8,793.6-8,803.4 NIPPLE; 8,790.7-8,793.6 PACKER; 8,771.7-8,790.7 NIPPLE; 8,737.6-8,739.1 HANGER; 8,687.2-8,693.4 HANGER; 8,670.7-8,694.8 HANGER; 8,670.4-8,687.2 HANGER; 8,663.9-8,670.7 D LINER HH; 8,235.1-8,515.7 XO BUSHING; 8,407.4-8,408.8 D LINER LEM; 8,164.5-8,398.0 SBR; 8,388.4-8,407.4 SEAL ASSY; 8,394.7-8,398.0 PACKER; 8,369.7-8,388.4 HANGER; 8,252.0-8,258.0 HANGER; 8,235.7-8,260.2 HANGER; 8,235.1-8,252.0 HANGER; 8,225.1-8,235.7 NIPPLE; 8,213.8-8,215.4 XO BUSHING; 8,202.8-8,204.2 SBE; 8,183.1-8,202.8 MULE SHOE; 8,163.5 PACKER; 8,175.4-8,183.1 SLEEVE; 8,164.5-8,175.4 LOCATOR; 8,162.6 PACKER; 8,147.0 PBR; 8,134.0 Seal Assembly; 8,133.1 Locator; 8,132.3 Sliding Sleeve - CMU (Closed); 8,068.2 No-Go 3.80" Sub; 8,013.2 Profile Sub; 7,992.4 Annular Connection Port; 7,953.8 ACCESS ISOLATION SLEEVE; 7,953.0 Motor Shroud/Centralizer; 7,917.6 XO Enlarging (Tubing); 7,914.5 Gauge; 7,753.7 GAS LIFT; 7,685.6 SURFACE; 30.3-4,100.0 FLOAT SHOE; 4,098.2-4,100.0 FLOAT COLLAR; 4,015.6- 4,017.2 GAS LIFT; 3,652.4 CONDUCTOR; 30.0-108.0 Hanger; 22.4 KUP PROD 1J-120 ... WELLNAME WELLBORE Annotation Last WO: 9/21/2017 End Date 10/5/2017 Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:1J-120L1 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By REV REASON: H2S Update, GLM size & TD of L11J-120L1 4/13/2020 pproven 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 LINER Slotted 4 1/2 3.48 8,900.6 16,036.0 11.60 L-80 BTC 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) 8,900.63,700.987.41SLEEVE 5.500 HR LINER SETTING SLEEVE 4.980 8,920.63,701.7 87.83 SBR 5.500 SEAL BORE RECEPTACLE JT 4.880 15,973.7 3,804.288.75 XO Reducing 4.500 XO Sub 4.5" BTC X 3.5" IBT 5.05"OD X 2.992" ID 2.992 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 8,966.0 9,291.0 3,703.2 3,703.4 WS B, 1J-120L1 5/30/2007 32.0 SLOTS 2.5"x.125", 4 circumferencial rows/ft 3" centers staggered 18 deg 9,575.0 10,799.0 3,708.1 3,726.4 WS B, 1J-120L1 5/30/2007 32.0 SLOTS 2.5"x.125", 4 circumferencial rows/ft 3" centers staggered 18 deg 10,801.011,610.03,726.5 3,757.1 WS B, 1J-120L1 5/30/2007 32.0SLOTS2.5"x.125", 4 circumferencial rows/ft 3" centers staggered 18 deg 11,955.015,973.03,760.33,804.2 WS B, 1J-120L1 5/30/2007 32.0SLOTS2.5"x.125", 4 circumferencial rows/ft 3" centers staggered 18 deg 1J-120L1, 7/24/2024 8:11:45 AM Vertical schematic (actual) B LINER Slotted; 8,900.6- 16,036.0 SHOE; 16,006.0-16,036.0 SLOTS; 11,955.0-15,973.0 SLOTS; 10,801.0-11,610.0 SLOTS; 9,575.0-10,799.0 SLOTS; 8,966.0-9,291.0 SBR; 8,920.6-8,962.5 SLEEVE; 8,900.6-8,913.2 B LINER LEM; 8,369.7-8,815.5 INTERMEDIATE; 27.4-9,944.4 HANGER; 8,663.9-8,670.7 D LINER HH; 8,235.1-8,515.7 XO BUSHING; 8,407.4-8,408.8 D LINER LEM; 8,164.5-8,398.0 SBR; 8,388.4-8,407.4 SEAL ASSY; 8,394.7-8,398.0 PACKER; 8,369.7-8,388.4 HANGER; 8,252.0-8,258.0 HANGER; 8,235.7-8,260.2 HANGER; 8,235.1-8,252.0 HANGER; 8,225.1-8,235.7 NIPPLE; 8,213.8-8,215.4 XO BUSHING; 8,202.8-8,204.2 SBE; 8,183.1-8,202.8 MULE SHOE; 8,163.5 PACKER; 8,175.4-8,183.1 SLEEVE; 8,164.5-8,175.4 LOCATOR; 8,162.6 PACKER; 8,147.0 PBR; 8,134.0 Seal Assembly; 8,133.1 Locator; 8,132.3 Sliding Sleeve - CMU (Closed); 8,068.2 No-Go 3.80" Sub; 8,013.2 Profile Sub; 7,992.4 Annular Connection Port; 7,953.8 ACCESS ISOLATION SLEEVE; 7,953.0 Motor Shroud/Centralizer; 7,917.6 XO Enlarging (Tubing); 7,914.5 Gauge; 7,753.7 GAS LIFT; 7,685.6 SURFACE; 30.3-4,100.0 FLOAT SHOE; 4,098.2-4,100.0 FLOAT COLLAR; 4,015.6- 4,017.2 GAS LIFT; 3,652.4 CONDUCTOR; 30.0-108.0 Hanger; 22.4 KUP PROD KB-Grd (ft) 32.29 RR Date 6/16/2007 Other Elev… 1J-120L1 ... TD Act Btm (ftKB) 16,036.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292335260 Wellbore Status PROD Max Angle & MD Incl (°) 95.20 MD (ftKB) 11,890.00 WELLNAME WELLBORE Annotation Last WO: End Date 1/6/2014 H2S (ppm) 20 Date 1/25/2019 Comment SSSV: NONE Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:1J-120L2 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By REV REASON: H2S Update & GLM size 1J-120L2 4/13/2020 pproven 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 LINER Slotted 4 1/2 3.48 8,459.8 16,033.0 3,750.3 11.60 L-80 BTC 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) 8,459.83,637.385.29 SLEEVE 6.410 HR Liner Setting Sleeve w/ 10' TBR 5.5" 4.980 8,479.9 3,638.7 86.86 SBR 5.500 Receptacle Jt 5.5" 15.5# L80 5.5" Hdy b X p 4.880 8,521.8 3,639.8 90.11 XO Reducing 5.500 XO Sub 5.5"Hyd 521 X 4.5"Hyd 521 bXp 3.910 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 8,533.09,434.03,639.7 3,663.3 WS D, 1J-120L26/11/2007 32.0SLOTS2.5"x .125", 4 circumferencial rows/ft, 3" centers staggered 18 deg. 9,436.015,988.03,663.4 3,749.0 WS D, 1J-120L26/11/2007 32.0SLOTS2.5"x .125", 4 circumferencial rows/ft, 3" centers staggered 18 deg. 1J-120L2, 7/24/2024 8:11:48 AM Vertical schematic (actual) D LINER Slotted; 8,459.8- 16,033.0 SHOE; 16,031.3-16,033.0 SLOTS; 9,436.0-15,988.0 SLOTS; 8,533.0-9,434.0 SBR; 8,479.9-8,521.8 SLEEVE; 8,459.8-8,472.6 D LINER HH; 8,235.1-8,515.7 D LINER LEM; 8,164.5-8,398.0 INTERMEDIATE; 27.4-9,944.4 HANGER; 8,235.7-8,260.2 HANGER; 8,235.1-8,252.0 HANGER; 8,225.1-8,235.7 NIPPLE; 8,213.8-8,215.4 XO BUSHING; 8,202.8-8,204.2 SBE; 8,183.1-8,202.8 MULE SHOE; 8,163.5 PACKER; 8,175.4-8,183.1 SLEEVE; 8,164.5-8,175.4 LOCATOR; 8,162.6 PACKER; 8,147.0 PBR; 8,134.0 Seal Assembly; 8,133.1 Locator; 8,132.3 Sliding Sleeve - CMU (Closed); 8,068.2 No-Go 3.80" Sub; 8,013.2 Profile Sub; 7,992.4 Annular Connection Port; 7,953.8 ACCESS ISOLATION SLEEVE; 7,953.0 Motor Shroud/Centralizer; 7,917.6 XO Enlarging (Tubing); 7,914.5 Gauge; 7,753.7 GAS LIFT; 7,685.6 SURFACE; 30.3-4,100.0 FLOAT SHOE; 4,098.2-4,100.0 FLOAT COLLAR; 4,015.6- 4,017.2 GAS LIFT; 3,652.4 CONDUCTOR; 30.0-108.0 Hanger; 22.4 KUP PROD KB-Grd (ft) 32.29 RR Date 6/16/2007 Other Elev… 1J-120L2 ... TD Act Btm (ftKB) 16,033.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292335261 Wellbore Status PROD Max Angle & MD Incl (°) 91.86 MD (ftKB) 13,296.84 WELLNAME WELLBORE Annotation Last WO: End Date 1/6/2014 H2S (ppm) 20 Date 1/25/2019 Comment SSSV: NONE 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill erforate New Pool Repair Well Re-enter Susp Well Other: Convert ESP to GL Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 16,033 feet None feet true vertical 3,750 feet None feet Effective Depth measured 15,988 feet 47, 8175,8370, 8770,87 feet true vertical 3,749 feet 3578, 3585, 3630, 3698 feet Perforation depth: Tubing (size, grade, measured and true vertical depth)4.5 ''L-80 8,146' MD 3,592' TVD Packers and SSSV (type, measured and true vertical depth)PACKER BAKER PREMIER PKR 8,147' MD 3,578' TVD PACKER HRD ZXP LINER TOP PKR 8,175' MD 3,585' TVD PACKER HRD ZXP LINER TOP PKR 8,370' MD 3,630' TVD PACKER HRD ZXP LINER TOP PKR 8,772' MD 3,698' TVD SSSV N/A N/A N/AMD12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Sydney Autry Contact Name:Sydney Autry Authorized Title:Sr. Petroleum Engineer Contact Email:Sydney.Autry@cop.com Contact Phone:(907) 265-6813 Authorized Name: Authorized Signature with date: Senior Engineer: Senior Res. Engineer: 8533-9434, 9436-15988 feet 3640-3663, 3663-3749 feet Printed and Electronic Fracture Stimulation Data WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-166 508 1207 590 1203 289 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 165 165 214 144 171 N/A Representative Daily Average Production or Injection Data Measured depth: True Vertical depth: D LINER SLOTTED 7,573 feet 4 1/2 '' 16,033' MD 3750' TVD CONDUCTOR 78 feet 20" 108' MD 108' TVD INTERMEDIATE 8,212 feet 7 5/8 '' 8,239' MD 3871' TVD SURFACE 4,070 feet 10 3/4 '' 4,100' MD 2470' TVD Packer measured true vertical Casing Length Size MD TVD N/A Kuparuk River Field / West Sak Oil Pool Plugs measured Junk measured Burst Collapse 3. Address:P. O. Box 100360, Anchorage, Alaska 99510 50-029-23352-61 8. Well Name and Number:KRU 1J-120L2ADL 25650, ADL 25661 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name:ConocoPhillips Alaska, Inc.4. Well Class Before Work: 5. Permit to Drill Number: 207-047 GINJ SUSP SPLUG Gas Service Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Sydney Autry Digitally signed by Sydney Autry Date: 2020.04.28 13:28:12 -08'00' By Samantha Carlisle at 1:39 pm, Apr 28, 2020 1J-120 Well Events Summary Date Event Summary 3/26/2020 1J-120 SI & Freeze Protected, begin evaluating option to convert to gas lift 4/3/2020 Update automation from ESP to Gas Lift in IP.21 4/6/2020 Begin downhole on slickline to convert from ESP to gas lift 4/10/2020 Complete downhole conversion from ESP to gas lift. Passing MIT-IA to 2500 psi. IA DDT completed. 4/12/2020 Gas lift blinds rolled to open and orifice plate rotated to correct metering direction. 4/18/2020 1J-120 BOL to gas lifted production. Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag:1J-120 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason; Pulled ESP Equipment, Closed Sliding Sleeves, Installed Isolation Sleeve, & Installed GL 4/10/2020 1J-120 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.12 Top (ftKB) 30.0 Set Depth (ftKB) 108.0 Set Depth (TVD)… 108.0 Wt/Len (l… 94.00 Grade K-55 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 30.3 Set Depth (ftKB) 4,100.0 Set Depth (TVD)… 2,469.6 Wt/Len (l… 45.50 Grade L-80 Top Thread BTC Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 27.4 Set Depth (ftKB) 9,944.4 Set Depth (TVD)… 3,871.2 Wt/Len (l… 29.70 Grade L80 Top Thread BTCM Casing Description D LINER LEM OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 8,164.5 Set Depth (ftKB) 8,398.0 Set Depth (TVD)… 3,636.6 Wt/Len (l… 12.60 Grade L-80 Top Thread IBTM Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 8,164.5 3,582.0 75.48 SLEEVE 5.75" ID Tie back sleeve 5.750 8,175.4 3,584.8 75.37 PACKER 5.5"x7.625" "HRD" ZXP Liner Top Packer w/ hold down slips 4.960 8,183.2 3,586.7 75.30 SBE 190-47 Casing Seal Bore Recepetacle 6.30" OD x 4.75" ID 4.750 8,202.8 3,591.8 75.11 XO BUSHING 5.5" BTC x 4.5" IBT Cross Over Bushing 3.960 8,213.8 3,594.6 75.13 NIPPLE DB Nipple 3.75" ID, 4.5" IBTM Box x Pin 3.750 8,225.1 3,597.5 75.40 HANGER LEM Above Hook Hanger 3.970 8,235.7 3,600.1 75.66 HANGER LEM Below Hook Hanger 3.930 8,394.7 3,635.9 77.45 SEAL ASSY 190-47 Non-Locating Seal Assembly 3.880 Casing Description D LINER HH OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 8,235.1 Set Depth (ftKB) 8,515.7 Set Depth (TVD)… 3,659.3 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 8,235.1 3,600.0 75.65 HANGER Baker Model B-1 Hook Hanger 7 5/8" x 4 1/2" (Inside csg) 5.600 8,252.0 3,604.1 76.06 HANGER Baker Model B-1 Hook Hanger 7 5/8" x 4 1/2" (Outside csg) 4.000 8,418.7 3,641.0 77.96 ECP Baker Payzone External Casing Packer 3.960 8,484.8 3,653.9 79.62 BENT JT 4 1/2" ,12.6 ppf, L-80 STL BENT joint Blank Casing 3.992 Casing Description B LINER LEM OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 8,369.7 Set Depth (ftKB) 8,815.5 Set Depth (TVD)… 3,705.4 Wt/Len (l… 12.60 Grade L80 Top Thread IBT Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 8,369.7 3,630.4 77.42 PACKER ZXP 5-1/2" x 7-5/8" Liner Top Packer TOP 5.530 8,388.4 3,634.5 77.45 SBR 109-47 Casing Seal Bore Receptacle 6.26" OD x 4.75 4.750 8,407.4 3,638.6 77.67 XO BUSHING XO Bushing 5-1/2" Hydril 563 x 4-1/2" IBT 4.500 8,663.9 3,682.1 81.60 HANGER LEM Above Hook Hanger 3.688 8,670.7 3,683.1 81.62 HANGER LEM Inside Hook Hanger 3.688 8,737.6 3,693.1 81.09 NIPPLE Camco "DB-6" Nipple, I.D. 3.562", IBT 3.562 8,770.0 3,698.2 80.75 BENT JT 4-1/2, 12.6 ppf. L-80, X/O Bent Jt. IBT Box X STL 3.958 8,812.2 3,704.9 81.17 SEAL ASSY Baker Seal Assembly 4-1/2" STL Box up 3.880 Casing Description B LINER HH OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 8,670.4 Set Depth (ftKB) 8,955.3 Set Depth (TVD)… 3,725.1 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 8,670.4 3,683.1 81.62 HANGER Baker Model B-1 Hook Hanger 7 5/8" x 4 1/2" (Inside csg) 5.600 8,687.2 3,685.5 81.62 HANGER Baker Model B-1 Hook Hanger 7 5/8" x 4 1/2" (Outside csg) 4.000 8,857.2 3,711.5 81.86 ECP Baker Payzone External Casing Packer 3.960 8,924.9 3,720.9 82.04 BENT JT 4 1/2" ,12.6 ppf, L-80 STL BENT joint Blank Casing 3.992 Casing Description A LINER Slotted OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 8,771.7 Set Depth (ftKB) 15,200.0 Set Depth (TVD)… 3,935.7 Wt/Len (l… 11.60 Grade L80 Top Thread BTC w/ TR Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 8,771.7 3,698.5 80.73 PACKER 5.5"x 7.63" Baker "HRD" ZXP Liner Top Pkr 5.750 8,790.7 3,701.5 80.84 NIPPLE "RS" Packoff Seal Nipple, 6.07" OD / 4.87" ID 4.870 8,793.6 3,702.0 80.89 HANGER 5.5" X 7.63" "Flex-Lock" Liner Hgr, 6.59" OD/ 4.85 4.850 8,803.4 3,703.5 81.04 SBE 190-47 Seal Bore Ext, 6.29" OD / 4.75" ID 4.750 15,113.5 3,935.4 90.39 Swell Packer Swell Packer #2 3.960 15,174.8 3,935.4 89.54 Swell Packer Swell Packer #1 3.960 Tubing Strings Tubing Description Tubing RWO 2017 String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 22.3 Set Depth (ft… 8,145.5 Set Depth (TVD) (… 3,577.3 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 22.3 22.3 0.00 Hanger Tubing Hanger, Vetco-Gray MB222A offset 10 3/4 x 4 1/2 w/false bowl 3.900 7,753.8 3,478.3 74.60 GaugeBaker SureSENS Gauge3.938 7,822.6 3,496.6 74.59 Sliding Sleeve CMU (Closed) Gas Venting Sliding Sleeve CMU (with position #3 ACCESS profile for keys), 3.875" X Profile, Access ( Closed 4/9/2020 ) 3.958 1J-120, 4/28/2020 11:11:43 AM Vertical schematic (actual) A LINER Slotted; 8,771.7- 15,200.0 SLOTS; 14,350.0-15,113.0 SLOTS; 13,445.0-14,179.0 SLOTS; 12,506.0-13,145.0 SLOTS; 10,240.0-12,205.0 INTERMEDIATE; 27.4-9,944.4 B LINER HH; 8,670.4-8,955.3 B LINER LEM; 8,369.7-8,815.5 D LINER HH; 8,235.1-8,515.7 D LINER LEM; 8,164.5-8,398.0 MULE SHOE; 8,163.5 LOCATOR; 8,162.6 PACKER; 8,147.0 PBR; 8,134.0 Seal Assembly; 8,133.1 Locator; 8,132.3 Sliding Sleeve - CMU (Closed); 8,068.2 No-Go 3.80" Sub; 8,013.2 Profile Sub; 7,992.4 Annular Connection Port; 7,953.8 ACCESS ISOLATION SLEEVE; 7,953.0 Motor Shroud/Centralizer; 7,917.6 XO Enlarging (Tubing); 7,914.5 Gauge; 7,753.7 GAS LIFT; 7,685.6 SURFACE; 30.3-4,100.0 GAS LIFT; 3,652.4 CONDUCTOR; 30.0-108.0 Hanger; 22.4 KUP PROD KB-Grd (ft) 32.29 Rig Release Date 6/16/2007 1J-120 ... TD Act Btm (ftKB) 15,822.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292335200 Wellbore Status PROD Max Angle & MD Incl (°) 92.84 MD (ftKB) 13,392.03 WELLNAME WELLBORE Annotation Last WO: End Date 9/21/2017 H2S (ppm) 20 Date 1/25/2019 Comment SSSV: NONE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 7,853.6 3,504.8 74.79 Sliding Sleeve CMD (Closed) Gas Venting Sliding Sleeve CMD (with position #4 ACCESS profile for keys), 3.875" X Profile, (Closed 4/9/2020) 3.958 7,917.6 3,521.3 75.31 Motor Shroud/Centraliz er Motor Shroud / Centralizer, Access, 5-1/2" FJL Pin x 5-1/2" FJL Pin ( Pulled 11/28/2018 ) 4.900 7,953.8 3,530.4 75.54 Annular Connection Port Annular Connection Port, Access, 5-1/2" FJL Box x 4-1/2" Vam Top Box Set 4.5" Access ISO Sleeve OAL = 135.5" 11/28/2018 3.840 7,992.4 3,540.0 75.77 Profile Sub B-Profile Sub, Access, 4-1/2", 12.6#, L-80, TXP Box x Box 3.956 8,013.2 3,545.1 75.89 No-Go 3.80" Sub No-Go 3.80" Sub, Access, 4-1/2, 12.6#, L-80, TXP Box x Pin 3.800 8,068.2 3,558.4 75.94 Sliding Sleeve - CMU (Closed) CMU Sliding Sleeve, 3.813" DB profile, Baker (4/9/2020 )3.810 8,132.3 3,574.0 75.78 Locator Locater Sub, Baker, GBH-22 (bottom of the locator spaced out 1.59') 3.880 8,133.1 3,574.2 75.78 Seal Assembly Baker 192-47 Seal Assembly 4-1/2", 12.6#, L-80, IBTM Box 3.870 Tubing Description Stacker Packer RWO 2017 String Ma… 4.51 ID (in) 3.98 Top (ftKB) 8,134.0 Set Depth (ft… 8,199.3 Set Depth (TVD) (… 3,590.9 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 8,134.0 3,574.5 75.77 PBR PBR, Baker, 80-47 with 6.69" scoop guide, 4-1/2" 12.6# TC-II Pin down 4.750 8,147.0 3,577.7 75.64 PACKER Premier Packer, Baker, 659-387, 4-1/2", 12.6# TC-II Box x Pin 3.870 8,162.6 3,581.6 75.49 LOCATOR Locater (bottom of the locator spaced out 1') 3.980 8,163.5 3,581.8 75.49 MULE SHOE Mule Shoe Joint 3.980 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in) 7,953.0 3,530.2 75.54 ACCESS ISOLATION SLEEVE 4 1/2" ACCESS ISOLATION SLEEVE W/ 3.85" PACKING (11.25' OAL) 4/10/20203.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 10,240.0 12,205.0 3,873.8 3,905.2 WS A2, 1J-120 5/17/2007 32.0 SLOTS 2.5"x .125",4 circumferencial rows/ft 3" centers staggered 18 deg 12,506.0 13,145.0 3,911.2 3,930.0 WS A2, 1J-120 5/17/2007 32.0 SLOTS 2.5"x .125",4 circumferencial rows/ft 3" centers staggered 18 deg 13,445.0 14,179.0 3,920.6 3,922.9 WS A2, 1J-120 5/17/2007 32.0 SLOTS 2.5"x .125",4 circumferencial rows/ft 3" centers staggered 18 deg 14,350.0 15,113.0 3,925.6 3,935.5 WS A2, 1J-120 5/17/2007 32.0 SLOTS 2.5"x .125",4 circumferencial rows/ft 3" centers staggered 18 deg Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 3,652.4 2,307.1 Camco KBG-2 1 ESP GLV BK 0.188 1,449.0 4/10/2020 2 7,685.6 3,460.3 Camco KBG-2 1 ESP OVBK 0.3130.0 4/10/2020 Notes: General & Safety End Date Annotation 11/13/2017 NOTE: or inflow performance issue are suspected 11/13/2017 NOTE: Well shut-in repeatedly-high motor temperature, and a restriction in the pump intake 9/21/2017 NOTE: WO 1J-120, 4/28/2020 11:11:45 AM Vertical schematic (actual) A LINER Slotted; 8,771.7- 15,200.0 SLOTS; 14,350.0-15,113.0 SLOTS; 13,445.0-14,179.0 SLOTS; 12,506.0-13,145.0 SLOTS; 10,240.0-12,205.0 INTERMEDIATE; 27.4-9,944.4 B LINER HH; 8,670.4-8,955.3 B LINER LEM; 8,369.7-8,815.5 D LINER HH; 8,235.1-8,515.7 D LINER LEM; 8,164.5-8,398.0 MULE SHOE; 8,163.5 LOCATOR; 8,162.6 PACKER; 8,147.0 PBR; 8,134.0 Seal Assembly; 8,133.1 Locator; 8,132.3 Sliding Sleeve - CMU (Closed); 8,068.2 No-Go 3.80" Sub; 8,013.2 Profile Sub; 7,992.4 Annular Connection Port; 7,953.8 ACCESS ISOLATION SLEEVE; 7,953.0 Motor Shroud/Centralizer; 7,917.6 XO Enlarging (Tubing); 7,914.5 Gauge; 7,753.7 GAS LIFT; 7,685.6 SURFACE; 30.3-4,100.0 GAS LIFT; 3,652.4 CONDUCTOR; 30.0-108.0 Hanger; 22.4 KUP PROD 1J-120 ... WELLNAME WELLBORE Annotation Last WO: 9/21/2017 End Date 10/5/2017 Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag:1J-120L2 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By REV REASON: H2S Update & GLM size 4/13/2020 1J-120L2 pproven Casing Strings Casing Description D LINER Slotted OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 8,459.8 Set Depth (ftKB) 16,033.0 Set Depth (TVD)… 3,750.3 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 8,459.8 3,637.3 85.29 SLEEVE HR Liner Setting Sleeve w/ 10' TBR 5.5" 4.980 8,479.9 3,638.7 86.86 SBR Receptacle Jt 5.5" 15.5# L80 5.5" Hdy b X p4.880 8,521.8 3,639.8 90.11 XO Reducing XO Sub 5.5"Hyd 521 X 4.5"Hyd 521 bXp 3.910 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 8,533.0 9,434.0 3,639.7 3,663.3 WS D, 1J- 120L2 6/11/2007 32.0SLOTS 2.5"x .125", 4 circumferencial rows/ft, 3" centers staggered 18 deg. 9,436.0 15,988.0 3,663.4 3,749.0 WS D, 1J- 120L2 6/11/2007 32.0 SLOTS 2.5"x .125", 4 circumferencial rows/ft, 3" centers staggered 18 deg. Notes: General & Safety End Date Annotation 1/6/2014 NOTE: WORKOVER-2014 7/23/2008 NOTE: VIEW SCHEMATIC w/9.0REV 6/16/2007 NOTE: MULTI-LATERAL WELL- 1J-120 (A-SAND), 1J-120L1 (B-SAND), 1J-120L2 (D-SAND) 1J-120L2, 4/28/2020 11:14:47 AM Vertical schematic (actual) D LINER Slotted; 8,459.8- 16,033.0 SLOTS; 9,436.0-15,988.0 SLOTS; 8,533.0-9,434.0 INTERMEDIATE; 27.4-9,944.4 D LINER HH; 8,235.1-8,515.7 D LINER LEM; 8,164.5-8,398.0 MULE SHOE; 8,163.5 LOCATOR; 8,162.6 PACKER; 8,147.0 PBR; 8,134.0 Seal Assembly; 8,133.1 Locator; 8,132.3 Sliding Sleeve - CMU (Closed); 8,068.2 No-Go 3.80" Sub; 8,013.2 Profile Sub; 7,992.4 Annular Connection Port; 7,953.8 ACCESS ISOLATION SLEEVE; 7,953.0 Motor Shroud/Centralizer; 7,917.6 XO Enlarging (Tubing); 7,914.5 Gauge; 7,753.7 GAS LIFT; 7,685.6 SURFACE; 30.3-4,100.0 GAS LIFT; 3,652.4 CONDUCTOR; 30.0-108.0 Hanger; 22.4 KUP PROD KB-Grd (ft) 32.29 Rig Release Date 6/16/2007 1J-120L2 ... TD Act Btm (ftKB) 16,033.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292335261 Wellbore Status PROD Max Angle & MD Incl (°) 91.86 MD (ftKB) 13,296.84 WELLNAME WELLBORE Annotation Last WO: End Date 1/6/2014 H2S (ppm) 20 Date 1/25/2019 Comment SSSV: NONE 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: Convert ESP to GL 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?N/A Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 16,033'NONE Casing Collapse Conductor Surface Intermediate B Liner SLOTTED Packers and SSSV Type: 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 Commission Representative: GINJ Op Shutdown Abandoned Sydney Autry Contact Name:Sydney Autry Senior Petroleum Engineer Contact Email: Contact Phone: (907) 265-6813 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ConocoPhillips Alaska, Inc.207-047 NONE P. O. Box 100360, Anchorage, Alaska 99510 50-029-23352-61-00 KRU 1J-120L2 ADL 25650, ADL 25661 Kuparuk River Field / West Sak Oil Pool PRESENT WELL CONDITION SUMMARY 3,750' 15988 3749 947 Length Size MD TVD Burst 4,070' 10 3/4 4,100' 2470' 78' 20'' 108' 108' 7,573' 4 1/2 16,033' 3,750' 9,917' 7 5/8 9,944' 3871' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 8533-9434, 9436-15988 3640-3663, 3663-3749 4.5" L-80 PACKER - BAKER PREMIER PACKER PACKER - HRD ZXP LINER TOP PACKER PACKER - BAKER HRD ZXP LINER TOP PACKER PACKER - HRD ZXP LINER TOP PACKER SSSV - NONE 8147 MD and 3578 TVD 8175 MD and 3585 TVD 8370 MD and 3630 TVD 8772 MD AND 3698 TVD N/A 4/11/2020 8,146' Packers and SSSV MD (ft) and TVD (ft): Authorized Name: Authorized Title:Sydney.Autry@cop.com Authorized Signature: COMMISSION USE ONLY Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Sydney Autry Digitally signed by Sydney Autry Date: 2020.04.13 16:47:42 -08'00' By Samantha Carlisle at 5:22 pm, Apr 13, 2020 320-166 DLB 4/14/2020 10-404 4/13/2020 X X VTL 4/15/20 Comm 4/15/2020 dts 4/15/2020 JLC 4/15/2020 Sydney Autry Senior Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501 Phone: (907) 265-6813 April 06, 2020 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 Dear Commissioner, KRU 1J-120 is an ESP lifted well that has struggled to achieve expected rates due to the high viscosity of the oil and emulsions stabilized from the produced sand. The decision was made to convert 1J-120 to back-up gas lift to evaluate the production (premised until the watercut rises enough to reduce the effects of viscosity & emulsions on the pump). The down hole conversion work is in progress and includes pulling the pump & motor, closing all sleeves intended to assist in gas venting up the IA, and performing the appropriate MITs. Once complete, the status of the well will be “packered gas lift”. Enclosed you will find 10-403 forms for 1J-120, 1J-120L1 & 1J-120L2 (PTD 207-045, 207-046, & 207-047) and a summary of well events. Sincerely, Sydney Autry Senior Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501 Phone: (907) 265-6813 Sydney Autry Digitally signed by Sydney Autry Date: 2020.04.13 16:48:32 -08'00' 1J-120 Well Events Summary Date Event Summary 3/26/2020 1J-120 SI & Freeze Protected, begin evaluating option to convert to gas lift 4/3/2020 Update automation from ESP to Gas Lift in IP.21 4/6/2020 Begin downhole on slickline to convert from ESP to gas lift (3-5 days expected duration) Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag:1J-120L2 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By REV REASON: GLV C/O 10/12/2017 1J-120L2 pproven Casing Strings Casing Description D LINER Slotted OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 8,459.8 Set Depth (ftKB) 16,033.0 Set Depth (TVD)… 3,750.3 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 8,459.8 3,637.3 85.29 SLEEVE HR Liner Setting Sleeve w/ 10' TBR 5.5" 4.980 8,479.9 3,638.7 86.86 SBR Receptacle Jt 5.5" 15.5# L80 5.5" Hdy b X p4.880 8,521.8 3,639.8 90.11 XO Reducing XO Sub 5.5"Hyd 521 X 4.5"Hyd 521 bXp 3.910 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 8,533.0 9,434.0 3,639.7 3,663.3 WS D, 1J- 120L2 6/11/2007 32.0SLOTS 2.5"x .125", 4 circumferencial rows/ft, 3" centers staggered 18 deg. 9,436.0 15,988.0 3,663.4 3,749.0 WS D, 1J- 120L2 6/11/2007 32.0 SLOTS 2.5"x .125", 4 circumferencial rows/ft, 3" centers staggered 18 deg. Notes: General & Safety End Date Annotation 1/6/2014 NOTE: WORKOVER-2014 7/23/2008 NOTE: VIEW SCHEMATIC w/9.0REV 6/16/2007 NOTE: MULTI-LATERAL WELL- 1J-120 (A-SAND), 1J-120L1 (B-SAND), 1J-120L2 (D-SAND) 1J-120L2, 4/9/2020 2:43:26 PM Vertical schematic (actual) D LINER Slotted; 8,459.8- 16,033.0 SLOTS; 9,436.0-15,988.0 SLOTS; 8,533.0-9,434.0 INTERMEDIATE; 27.4-9,944.4 D LINER HH; 8,235.1-8,515.7 D LINER LEM; 8,164.5-8,398.0 MULE SHOE; 8,163.5 LOCATOR; 8,162.6 PACKER; 8,147.0 PBR; 8,134.0 Seal Assembly; 8,133.1 Locator; 8,132.3 Sliding Sleeve - CMU; 8,068.2 No-Go 3.80" Sub; 8,013.2 Profile Sub; 7,992.4 Annular Connection Port; 7,953.8 Motor Shroud/Centralizer; 7,917.6 ACCESS MOTOR; 7,904.0 XO Enlarging (Tubing); 7,914.5 Gauge; 7,753.7 GAS LIFT; 7,685.6 SURFACE; 30.3-4,100.0 GAS LIFT; 3,652.4 CONDUCTOR; 30.0-108.0 Hanger; 22.4 KUP PROD KB-Grd (ft) 32.29 Rig Release Date 6/16/2007 1J-120L2 ... TD Act Btm (ftKB) 16,033.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292335261 Wellbore Status PROD Max Angle & MD Incl (°) 91.86 MD (ftKB) 13,296.84 WELLNAME WELLBORE Annotation Last WO: End Date 1/6/2014 H2S (ppm) 20 Date 1/25/2019 Comment SSSV: NONE Pr!'ect Well Histo File Cover Pa e Image o~ ry g 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~ ~~-~~~ Weli History File Identifier Organizing ~aone~ Two-sided III IIIIII II III II III RES AN ms: l It C DIGITAL DATA No ~ iskettes or e o , . ^ Greyscale Items: ^ Other, No/Type: Poor Quality Originals: ~ 1"~""" v ~ Other: NOTES: v b ~ BY: _ Maria Date: Project Proofing ^ Rescan Needed III (I~IIIIIII IIIII OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSlZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: /s/ BY~ Maria Date: ~/~ ~/ Q 9 /s/ I I ~ ~ - T--~--~ • ~ ~ ~ . ~ ~ x 30 = + = TOTAL PAGES~_ Scamm~g Preparat~on ~ (Count does not include cover sheet) ~ ~Y: Maria Date: ~ /~a ~, ~ /s/ Production Scanning Stage 1 Page Count from Scanned File: (count aoes inciude cover sneet) Page Count Matches Number in Scanning Preparation: ~YES NO BY: Maria Date: ~ 3~~ ~ 7 /s/ rn Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: ~S~ Scannin is complete at this point unless rescanning is required. ~II ~III•) III~I II III 9 ReScanned II I II'I I) I( III II II) BY: Maria Date: ~S~ Comments about this file: Quality Checked ~II I~'lll III II~I I~I ~ 10/6/2005 Well History File Cover Page.doc ~y ~'r `,~. > ~- MICROFILMED 6I30i2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~.~ ~i '~,~ ; ,°d9` §. ~ ~ ~k~~ DATA SUBMITTAL COMPLIANCE REPORT 6/22/2009 Permit to Drili 2070470 Well Name/No. KUPARUK RIV U WSAK 1J-120L2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23352-61-00 MD 16033 ND 3750 Completion Date 6/16/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes' DATA INFORMATI~N Types Electric or Other Logs Run: GR/Res (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 12643 16033 Open 8/2/2007 D D Asc Directional Survey 8210 13212 Open 8/2/2007 PB 1 t 15347 LIS Verification 4073 16033 Open 8/23/2007 LIS Veri, GR, FET, ROP C Lis ~ 15347 ~'Induction/Resistivity 4073 16033 Open 8/23/2007 I LIS Veri, GR, FET, ROP ~ 15348~LIS Verification 4073 13212 Open 8/23/2007 PB1 LIS Veri, GR, FET, ROP D C Lis 15348~Induction/Resistivity 4073 13212 Open 8/23/2007 P61 LIS Veri, GR, FET, ROP D C 18136 ~ee Notes 0 0 Open 6/10/2009 EWR logs in CGM, EMF and PDS graphics i og Induction/Resistivity 25 Col 108 16033 Open 6/10/2009 MD ROP, EWR, DGR ~! Log InductionlResistivity 25 Col 108 16033 Open 6l10/2009 ND EWR, DGR D C 18137+~ee Notes 0 0 Open 6/10/2009 P61 EWR logs in CGM, EMF and PDS graphics Log Induction/Resistivity 25 Col 108 13212 Open 6/10/2009 PB1 MD ROP, EWR, DGR Well Cores/Sampies Information: Sample Interval Set Name Start Stop Sent Received Number Comments ~ ~ ~ DATA SUBMITTAL COMPLIANCE REPORT 6/22/2009 Permit to Drill 2070470 Well Name/No. KUPARUK RIV U WSAK 1J-120L2 Operator CONOCOPHILLIPS ALASKA INC MD 16033 ND 3750 Completion Date 6/16/2007 Completion Status 1-OIL Current Status 1-OIL ADDITIONAL INFORMATION Well Cored? Y' Daily History Received? ~ Chips Received? ~- Formation Tops ~ Analysis `J~I Received? API No. 50-029-23352-61-00 UIC N Comments: . Compliance Reviewed By: ~ Date: _ i ~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-120+L1+L1PBl+L1PB2+L1PB3+L1PB4+L2+L2PB1 AK-MW-5005556 June 1, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling, Arctic Blvd., Anchorage, AK 99518 1J-120+L1+L1PB1+L1PB2+L1PB3+L1PB4+L2+L2PB1 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23352-00,60,71,72,73,61,74 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23352-00,60,61 Digital Log Images 1 CD Rom 50-029-23352-00,60,71,72,73,61,74 L1PB1, L1PB2, L1PB3, L1PB4 and L2PB1 have no TVD. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling ~~~ _d c/~ I~/~~ ~~ ~ _~~ Attn: Bryan Burinda 6900 Arctic Blvd. ~j ,-O~/(, l~ (3i ~~ l~~ Anchorage, Alaska 99518 ~~`3~ OfFce: 907-273-3536 ~ ~ ~~3 Fax:m907-273-3535 Br~~ ~1 . ~;'; n com ~ ~( 3~ ~ d l3~/ . ~Ui~ ~. 0 ZOu9 Date: Signed: ~ ~ ~lask~ 6sl ~ ~as C~ns. Gom~nission Anch~raqe ~~~~~~~~ ~ ~ ~`~ G r 2 ~ 2Q~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIOPA~~S~€c~ ~C~~ k~ {~~~ ~ ~ , .. ,~~ , ;a~ REPORT OF SUNDRY WELL OPERATIONS ~:~~~ ~`- ~~~ ~_~~'~'~ ,~~ 1. Operations Pertormed: Abandon ^ RepBi~ Well ^~ - Plug Pertorations ~ Stimulate ~ Other ~ Alter Casing ^ Pull Tubing ^~ ~ Pertorate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhillips AlaskB, InC. Development ^~ • Exploratory ^ 207-047 /' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23352-61 • 7. KB Elevation (ft): 9. Weil Name and Number: RKB 28', 109' MSL 1J-120L2 ' 8. Property Designation: 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 16033' ' feet trueVertical 3750' ~ feet Plugs (measured) Effective Depth measured 16033' feet Junk (measured) true vertical 3750' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' SURFACE 4072' 10.75" 4100' 2470' INTERMEDIATE 9917' 7-5/8" 9945' 3872' D slotted liner 7573' 4.5" 16033' 3750' Perforation depth: Measured depth: ssss'-9434~, sa3s'-15988~ true vertical depth: ssao'-3663', 3663'-s7a9' Tubing (size, grade, and measured depth) tubing 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 93 • 3183 3 -- 181 Subsequent to operation 122 433 149 - 205 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 Cody Gauer @ 263-4802 Printed Name C U Title Wells Engineer Signature Phone: 263-4802 ~ Date ~/// .2.~~ ~~ ~ ~ ~ - Allsu Dra 63-4612 Pre a b" Sha ~i ~y , . , = d R ~.~.`r~` ; ~ f : r~ - ~~ °. ; i i ~ /~^Z~ ' ~.4V ~ 7 Form 10-404 Revised 04/2006 + Submit Orig ~~nal O I , ~ t S.~ i t~y ~~ ~ ;. cEi:, sG y G ~~~~ .. 7~ KU P ConocoPhitlips Well Attributes ____ ~g~~„ ~.: ,. 1 Well~oreAPVUWI Field Name 500292335271 IWEST SAK C«nmant H2S (ppm) ... we~icrnso- ~+~ ~2a.2 ;aii~swaea~,:;s.~m- ---~SSSV-NIPPLt 0 Smnnafv.w~ti~~i- - -~ ~~ ~ ~~~~ ~ ~~ ~ ~ ~ ~~~Anno~a~ion DeoM (flKBI EnE Date ~ 1J-120L2 ](ftKB) '~TD(max) 11,934.76 ! 16,033 IIRig Release Dat 6l16/2007 11.60 HANGER,P1 I ~ etm ~rvo~ NIP%.E.525 - GAS LIFT, 2.120 6AS LIFT, 3,888 SURFACE._ Od,100 NIPPLE. B.126 - - GAUGE. B.~PB'- LIX'ATOR. 8.1]d SEAL ASSY, _ _ 6.176 D HANGER. Liner comment i"x .125", 4 circumterencial rows/ft, cerners staggerea 18 deg. i"x .125", 4 circumterencial rows/ft, centers staggered 18 deg. Top ' Top Depih ' ~ I (TVD~ In I I OD Valva Latch PoA Size TRO Run I Sen Top (ftl(B) (nKg) (`) Make MoMI (in) Sarv : Typa Typa (in) (psi) Com_.I Run Dab 1 2,120.7 1,759.3 68.65 Camm KBG-2-iR 1 GasLih GLV BK 0.156 1,496.0 ' 10/12008 2 3,888.4I 2,3952~66J2 i Camco KBG2-7R 7 GasLih OV BK 1/4 0.0 I 7017/2008 CommBnt BR 5.5" 521 bXp DLMER SbnM. 8.660-16,033 TD (1J-120LP). . . _ . 16,033 ~~~~~~P~~~~~~5 Time Log & Summary 4Ye1N7ew V~eb Reyoxttng Re po rt Well Name: 1J-120 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 9l16/2008 9:30:00 AM Rig Release: 9/22/2008 4:00:00 AM 9/16/2008 24 hr Summarv Completed well 1J-101, RDMO, assembled LPR's on 13 5/8" BOP stack, set double mats on well 1J-120 and s otted ri over well, RU kill tank, um ed 420 bbls hot SW to kill well, ND tree and started NU BOPE. 08:00 10:00 2.00 MIRU MOVE RURD P Instali single gate on stack, set rig mats on 1J-120 for hi h weilhead. 10:00 11:00 1.00 MIRU MOVE MOB P Move to 1J-120, spot and level rig over well, set up handy berm. Accept Nordic ri 3 0930 hrs. 11:00 13:30 2.50 COMPZ RPCOM RURD P RU kill tank and hardline, PU lubricator and pull BPV, pressure test lines to 2,000 psi. SITP 600 psi, SICP 1,000 si. 13:30 17:00 3.50 COMPZ RPCOM CIRC P Pump 420 bbls 6% KCL seawater down tbg @ 6 bpm while venting IA to kill tank, shut down pump, tbg on vac, csg 50 psi, bleed off IA to kill tank and check for flow - no flow. RD and BD circ lines, set BPV. 17:00 00:00 7.00 COMPZ RPCOM NUND P ND tree, install test dart, MU spool and NU 13 5/8" BOP. 9/17/2008 RU on 1J-120, kil~ed weil, ND tree - NU BOPE and tested, unseated hanger and circ hot SW to clean tubing and jewelry, POOH with 4 1/2" ESP completion, racking back tbg in derrick. 00:00 02:00 2.00 COMPZ RPCOM NUND P Cont NU 13 5/8" BOPE and CO lower pipe rams to VBR 2 7/8" x 5 1 /2". 02:00 07:30 5.50 COMPZ WELCTI BOPE P Test and chart BOPE at 250 and 3,000 psi, tested both ram sets and annular with 3 1/2" and 4 1/2" pipe, witness of test was waived by AOGCC Rep Jeff Jones at 17:00 hrs on 9-16-08. 07:30 09:30 2.00 COMPZ RPCOM RURD P Pull test dart, attempt to pull BPV, pressure under BPV, pumped 50 bbis down tb and ulled BPV. 09:30 12:00 2.50 COMPZ WELCTL CIRC P With well shut in tbg @ 30 psi, pumped 150 bbls of SW down tbg @ 7 bpm @ 50 psi. Pumped 130 bbls of 120 degree SW down IA , M/U landing joint. B~eed down 50 psi on IA to kill tank, BOLDS. Open rams and strip through annular with 800 si to unland han er. 12:00 13:30 1.50 COMPZ WELCTL OWFF P Monitor well and heat up additional SW on VAC truck. 13:30 14:30 1.00 COMPZ WELCTL CIRC P Pump 150 bbls of 120 deg SW down IA @ 8.5 bpm, & 130 bbls down tbg la~ 12 bpm. 14:30 00:00 9.50 8,201 714 COMPZ RPCOM TRIP P Putl hanger to floor, LD landing joint, RU ESP cable to spooler. POOH with 4 1/2" ESP completion, racking tbg in derrick and drifting stands to 3.833". Using triple pipe displacement (7 bbls) for hole fill every 5 stands, and an additional 50 bbis per hour to well. 9/18/2008 RIH made clean out run, POOH, PU RIH with 245' ZXP and LEM assembly. 00:00 01:30 1.50 714 0 COMPZ RPCOM TRIP P Cont POOH with 4 1/2" ESP completion, stand back tbg and drift to 3.833" in derrick, using triple pipe displacement every 5 stands (7 bbls) lus 50 bbis eve hour to weil. 01:30 05:30 4.00 0 0 COMPZ RPCOM PULD P Break down ESP assembly and LD, clean floor, off load motor boxes and jewelry, load Baker tools, CO elevators, set wear ring, cont adding 50 bph SW to well. Recovered 11 SS bands, 3 protectrolizers, 2 flat guards, 154 cross coupler clamps. Missing 4 SS bands off ESP motor 05:30 13:00 7.50 0 7,989 COMPZ RPCOM TRIP P PU washdown BHA (448') and RIH with 3 1/2" DP from derrick to 7,989'. 13:00 15:00 2.00 7,989 8,402 COMPZ RPCOM CIRC P Washed down from 7,989' to 8,385' pumping @ 4.5 bpm down back side w/charge pump and 5.5 bpm @ 2500 psi down DP. Recip across hook hanger w/side wash tool (snouolator) 4 times. Wash from 8,385' to 8,402'. Saw 100 psi increase on DP when btm nozzle entered SBR. Tagged @ 8,402' RKB. U/down above hook was 135K/55K. 15:00 23:00 8.00 8,405 0 COMPZ RPCOM TRIP P POOH from 7,985' to 448' and LD BHA. 23:00 00:00 1.00 0 245 COMPZ RPCOM TRIP P PU and MU LEM and ZXP assembly 9/19/2008 RIH 30 fpm, oriented and set LEM assembly, pressure tested csg to 2,500 ps, POOH LD 3 1/2" DP and 4 3/4" DC's. 00:00 03:00 3.00 245 245 COMPZ RPCOM PULD P Cont MU Lem assembly (245') with running tools and MWD. CO s inners and elevators. 03:00 04:00 1.00 245 1,215 COMPZ RPCOM DHEQ P RIH 1 stnd 3 1/2" DP and perform shallow test on MWD. RIH 9 stnds to 1,214' and re-test as per request of MWD Rep. Electrical problem, trouble shoot MWD and transducer. 04:00 07:30 3.50 1,215 1,215 COMPZ RPCOM DHEQ T Electrical problem, trouble shoot MWD and transducer, wait on transducer being delivered from Deadhorse. Transducer re aired. 07:30 14:00 6.50 1,215 8,264 COMPZ RPCOM TRIP P Continue RIH from 1,215' to 8,170' w/ 9 DC's one stand below rotary for push if needed. • 14:00 16:00 2:00 8,264 8,075 COMPZ RPCOM DHEQ P At 8,170', up 150K, down 60K. MU top drive and pumped 120 gpm @ 500 psi for MWD. Found oriented @ 15R. Turned to 60R. RIH to 8,364', now oriented @ 70R. Continued down, pumping, and latched collet, now oriented 46R. PU & unlatched w/ 170K & oriented back to 60R. Latched again @ 26R. PU to 160K & break connection. Dropped 1.75" ball. Made connection and pumped ball to btm. MWD indicated 9L while displacing ball. Pressured up on DP to 3,400 psi to set ZXP @ 8,164' & released setting tool. Filled backside w/ charge pump & allowed to settie. Closed annular and PT csg & ZXP to 2,500 psi, OK. Bled off. POOH to above ZXP at 8,075'. 16:00 18:00 2.00 8,075 8,075 COMPZ RIGMNT SVRG P Cut and slip drill line. 18:00 00:00 6.00 8,075 3,565 COMPZ RPCOM TRIP P POOH LD DP & DC's, from 8,075' to PU and RIH with 4 1/2" gas lift completion, 00:00 05:00 5.00 3,565 0 COMPZ RPCOM TRIP P Cont POOH LD 3 1/2" DP from 3,565', LD LEM running tools and MWD and off load same. 05:00 07:30 2.50 0 0 COMPZ RPCOM RURD P Load completion jewelry and tec-wire spooler, CO spools, string sheaves, 07:30 00:00 16.50 0 6,417 COMPZ RPCOM RCST P RIH with 4.5" completion seal assembly to Guardian guage carrier. Splice and test TEC wire to guage. Continue RIH to 5,150' MD and install heat trace cable and test. (heat trace wiii sit at 3,015') Cont RIH from 5,150' to 6,417'. Installing clamps s-ower than normal due to tight fit or worn hydrauliGimpact 9/21 /2008 Space out, MU hanger, spotted corrosion inhibitor, landed hanger, tested 7 5/8" csg, ND BOP, NU tree and tested, RDMO, removed 13 5/8" BOP's for ri move. 00:00 09:30 9.50 6,417 8,177 COMPZ RPCOM RCST P Cont RIH from 6,417' to 8,177' with 4 1/2" gaslift completion w/ TEC wire & heat trace. Up/down above ZXP 125K/57K. Tag btm of sealbore & LD ~oints for s ace out. 09:30 12:30 3.00 8,177 8,177 COMPZ RPCOM HOSO P MU space joints, hanger w/ full joint below and landing joint w/ side port iso sleeve. Install penetrators. Splice heat trace & TEC wire & connect to penetrators. ~ 12:30 14:00 1.50 8,177 8,177 COMPZ RPCOM CIRC P Pumped 220 bbls 6% KCL seawater containing 1 % CRW-132 down backside. Sting in seals and fill backside in to BOP. Let air bubble out of backside. Drain stack thru IA valve. 14:00 16:00 2.00 8,177 8,177 COMPZ RPCOM HOSO P Guide pin did not line up hanger w/ side port properly. Lift hanger six inches and rotate top drive left roughly 1/4". Re-land hanger. Side , port now aligned properly. RILDS. Set TWC in han er. 16:00 17:00 1.00 8,177 8,177 COMPZ RPCOM CIRC P RU pump to IA & PT to 1,000 psi for 5 minutes OK, in case SOV sheared before 1,500 psi. Pressure IA to 1500 psi and SOV sheared. bled off and RD circ lines. 17:00 19:00 2.00 8,177 8,177 COMPZ RPCOM NUND P ND 13 5/8" BOP and LD 5 stnds of tbg from derrick. Test tec-wire and heat trace. 19:00 22:00 3.00 8,177 8,177 COMPZ RPCOM NUND P NU adaptor and tree, test at 250 and 5,000 si. 22:00 23:30 1.50 8,177 8,177 COMPZ WELCTt OTHR P Pu~l TWC, set BPV with lubricator. 23:30 00:00 0.50 8,177 8,177 COMPZ RPCOM RURD P Secure well, clean cellar area. Move Rig 3 off 1 J Pad and toward 1 D Pad. 00:00 00:30 0.50 COMPZ RPCOM RURD P Cont clean up and secure well site. 00:30 04:00 3.50 COMPZ MOVE DMOB P Pull rig off well, remove 13 5/8" BOP stack from cellar and place on skid, clean out cellar box, remove T mats and tarp. Nordic Rig 3 released at 04:00. SITP = 0, IA = 0, OA = 100 i CJ a~~~~~`~~ ~ ~ ~ s ~OI'10CQ~'llf~1~S August 8, 2008 A~r ~ ~ 200 Robert Christensen 8 Production Engineering Tech. ,a(~ ~; Greater Kuparuk Unit , NSK-69 ~'~~"~ ~'''~ ~~ { ~`'~ ' PO Box 196105 ~~~~~ ~~~`~~~~~~~f~nchorage, AK 99519-6105 r'; ~ , ~ `. ~ri°a^,~~ ~ Phone: (907) 659-7535 Fax:659-7314 Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7`~ Ave. Ste. 100 Anchorage, AK 99501 Dear Mr. Maunder, ConocoPhillips Alaska, Inc. has changed the artificial lift method in the West Sak 1J-120, 1J-120L1, and 1J-120L2 multilateral oil production wells. Enclosed you will find 10-404 Reports of Sundry Well Operation recording the change in artificial lift method to GL (Gas lifted) due to a failed ESP (Electrical Submersible Pump). If you have any questions regarding this matter, please contact me at 659-7535. Sincerely, ~ ~ ~ / ~ `~'----_...._ Robert D. Christensen Attachments ~ ~~ ~~~ ~ ~ ~ STATE OF ALASKA f; € ` , ; `y ~.~J ~,,~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WEI~~. E~PE``RAT~ON~ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ~ Stftnulate ~` Other Q Failed ESP to GL Alter Casing ^ Pull Tubing ^ Pertorate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ~ Re-enter Suspended We~l ^. 2. Operator Name: 4. WeII,Class Before Work: 5. Permit to Drili Number: ConoCOPhillips Alaska, InC. Development ~ Exploratory ^ 207-047 3. Address Strati ra hic g p ^ Service ^ 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-029-23352-61 7. KB Elevation (ft): 9. Well Name and Number: KB 109' 1 J-120L2 8. Property De ' nation~ 10. FieldlPool(s): ADL 25661, 25650 Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 16033' feet true vertical 3750' feet Plugs (measured) Effective Depth measured 10633 feet Junk (measured) true vertical 3750 feet Casing Length Size MD ND Burst Collapse CONDUCTOR 108' 20" 108' 108' SURFACE 4072' 10-3/4" 4100' 2470' INTERMEDIATE 9917' 7-5/8" 9945' 3872' D sd Slotted Linei 7573' 4-1/2" 16033' 3750' Perforation depth: Measured depth: 8533'-9434'; 9436'-15988' true vertical depth: 3640'-3663'; 3663'-3749' Tubing (size, grade, and measured depth) 4.5", L80, 8202' MD. Packers & SSSV (type & measured depth) Baker "HRD" ZXP Liner top Packed Pkr = 8772' no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) N~q 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 aperation 647 472 26 257 199 Subsequent to operation 2145 1832 165 910 228 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil~ Gas^ WAG^ GtNJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A contact Bob Christensen / Vacant Printed Name ,. O P~ .ChPI en Titie Production Engineering Technician Phone: 659-7535 Date ~ ~f nature ~ ~ ' '° ~ i-- -- Si ' ~ ~ .. g ~: ~,,.-~ ,1 l ~ ~~j ~ ~ =~ ~y~ ~ ~~ ` ~~ ~I ~~~~ - , ~ ~;~ . -~ Form 10-404 Revised 04/2 6 ~ ti,,,r j~~/~~ ~ Submit Original Only • ~ 1J-120L2 DESCRIPTION OF WORK COMPLETED SUMMARY ' Date Event Summary 07/28/08 SET 4-1/2°SLIP STOP CATCHER @ 4008' -WLM. PULLED SOV @ 2113' RKB. IN PROGRESS. 07/29/08 PULL DMY @ 3883' RKB, SET LV @ 2113' R~B & ATTEMPTED TO SET OV @ 3883' RKB, PULL SLIP STOP, OV IN SLIP STOP, DSO TO LEAVE WELL SHUT IN TILL CREW COMES TO RESET OV ,.,. ~ 08/02/08~SET 1/4" ORIFICE @ 3883' RKB. JOB COMPLETE. ~ 08/06/08 Open Well - Return to service ~ ~ WELL LOG TRANSI~TITTAL To: State of Alaska August 14, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-120 L2 PB1 AK-MW-5005556 1 LDWG formatted CD Rom with verification listing. API#: 50-029-233 52-74 PLEASE ACKNOWLEDGE RECEIPT BY SIGl~TING AND RETLTRNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchara e Alaska 99518 ~7~'~~~ ~ ,~ x~.-, ~. _ ~ ~ ' '~ "~ ~' ~ 7i?Q? -~.~.,~ ~ Date: ~1a5~~ ~i~ ~~ ~~s w~ns. ~o~n~-;is~ioi~ x:~,r,~~~~a ~ ~ Signed: c~0~-b~~~ ~ ~ S3 ~`1S ~ ~ WELL LOG TRANSMITTAL To: State of Alaska August 14, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-120 L2 AK-MW-5005556 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23352-61 PLEASE ACKNOWLEDGE RECEIPT BY SIGivING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~ ~. ~ ,~ ~~ ~ ~~ ~~i~~~~ ~~~ Date: ;`~~~ ~' ~ ZU07 ~~,;;~~,~~~ :~ar,~sni~sicn ^;~~;~~ ~€i 4: ~~ .~. ,~ ;x~~ ,~~;;~~.<..~. Signed: ~ av~--~~ '~ ~~3~r~- ! ~ • • ConocoPh~ll~ps July 18, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Reports for 1 J-120, 1 J-120L1, 1 J-120L2 Dear Commissioner: RE~EIVED JUL ~ 4 2007 Alaska Oif & Gas Cons. Commission Anchorage ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk West Sak wells 1J-120 and 1J-120L1 and 1 J-120L2. If you have any questions regarding this matter, please contact me at 265-6830 or Dennis Hartwig at 265-6862. Sincerely, ~ ~ ~~~~,~! ~. R. Thomas Kuparuk Drilling Team Leader CPAI Drilling /~jf C~ P v~'~' ~" f P cJf~ / - ` r~ ~ ~~ ~ ~ ~s ~ • Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 RT/skad ~~=~~'v~~ • STATE OF ALASKA ~ JU~` '~ `~ ZG~~ ALASKA OIL AND GAS CONSERVATION COMMISSION °~j~ska Orl ~~a~ WELL COMPLETION OR RECOMPLETION REPORT AN~~~~~ ~~mm°s~'Q,~ 1a. Well Status: Oil Q , Gas Plugged Abandoned ~ Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development Q= Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., oraband.: June 16, 2007 , 12. Permit to Drill Number: 207-047 /~ 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: June 3, 2007 ' 13. API Number: S0-029-23352-61 4a. Location of Well (Governmental Section): Surface: 1875' FSL, 2357' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: June 10, 2007 ~ 14. Well Name and Number: 1J-120L2 Top of Productive Horizon: 2380' FNL, 1848' FEL, Sec. 36, T11 N, R10E, UM 8. KB (ft above MSL): Ground (ft MSL): 109' MSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 109' FSL, 1991' FEL, Sec. 24, T11 N, R10E, UM 9. Plug Back Depth (MD + ND): 16033' MD / 3750' ND West Sak Oil P001 ° 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558854 ^ y- 5945688 - Zone- 4 10. Total Depth (MD + ND): * 16033' MD / 3750' TVD • 16. Property Designation: ADL 25661, 25650 ~ TPI: x- 564633 y- 5946760 Zone- 4 Total Depth: x- 564421 • - 5954527 Zone- 4 11. SSSV Depth (MD + ND): none 17. Land Use Permit: 471, 468 18. Directional Survey: Yes Q No~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): tso7' ND 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): Top of Window: 8239'-8252' MD °~ GR/Res 3G~l~~ 360~f ~h/I~ 22. CASING, LINER AND CEMENTING RECORD ~• 3T • o> SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENFING RECORD pULLED 20" x 34" 78.6# H-40 28' 80' 28' 80' 42" 360 sx AS 1 10.75" 45.5# L-80 28' 4100' 28' 2470' 13.5" 660 sx AS Lite, 180 sx DeepCRETE 7.625" 29.7# L-80 28' 9945' 28' 3872' 9.875" 552 sx DeepCRETE 4.5" 11.6# L-80 8235' 16033' 3600' 3750' 6.75" slotted liner 23. Open to production or injection? Yes O No If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore slots from 8533'-15988' MD 25. ACID, FRACTURE, CEMENTSQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production July 9, 2007 Method of Operation (Flowing, gas lift, etc.) ESP producer- shares production with 1J-120 and 1J-120L1 Date of Test 7/12l2007 Hours Tested 12 hours Production for Test Period --> OIL-BBL 1415 GAS-MCF 179 WATER-BBL 58 CHOKE SIZE 100% GAS-OIL RATIO 158 Flow Tubing press. 231 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 2684 ~ GAS-MCF 425 WATER-BBL 116 OIL GRAVITY - API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes ~ No ~ Sidewail Cores Acquired? Yes No / , If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 4'.!i .4~DM+?~ fJ;~: t''~n. f NONE ~` ' ~ i V+:.niF~~2. ;}'~ ~ ; Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE ~ !~ ~ ~ ~ ~ ~ J S 8~~ AUG ~ ~ 2D09 ~ ~~L ~ v~ i ~S~? Z~7-b~ ~~r ~~, ,~~~~~` 'j~b~ G 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD ND Well tested? Yes ~ No If yes, list intervals and formations tested, Permafrost - Top surface surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1655' 1507' (Est.) , needed, and submit detailed test information per 20 AAC 25.071. T3 1898' 1658' (est.) K15 2652' 1980' (est.) Ugnu C 6035' 3017' Ugnu B 7311' 3360' Ugnu A 7435' 3394' K13 7525' 3417' West Sak D 8240' 3601' N/A ' 1J-120L2PB1 TD 13212' 3703' Formation at total depth: Kuparuk D sand 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directionai Survey, slotted liner detail sheet 31. I hereby certify that the foregoing is true and corcect to the best of my knowledge. ContaCt: Dennis Hertwig @ 265-6862 Printed Name an homas Titie: Driliinp Team Leader ~~ ~ a Signature Phon `~ Date ~ ~ " C: / d/ jt ~° / INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on ali types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. 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 poo~ 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 and Ground level elevations in feet above mean sea level. 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: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. 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 additionai 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, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2l2007 ~ • Halliburton Company Survey Report ~ ~ Halliburton Company Survey Report ~€~~ariy: ConacoPhillips Ala~ka thc. I~at~ 7Mfl1~t~0'~' ~~, T~me 15~3'~ 3f3 ~~~ - ~, ~-~ Page: ~ :~t~ld. ~~ Kuparuk River ~lrtit ~o=~rrdinate~NE)Refer~xice~ ..;~: UWell: 1,~`f2C}, ~rue h~~rth '~ ~' Sitc;~_ Kuparuk tJ Pad ~ '~ertical ("1"~}~+~re~~e 'I~J '120L2 , 1~~.t~ ~ ' ~4'eti: ~~ ~3-'~2fi! ~ ~ ~ , ~~ :Section (V~}~I~ef'~te~ce ~tVe~ ~t~~QT*l;O;tiQ~ UOUAz~} `~ ~Yelipath': 'I,~-12UL2 Suruey CakaIatian MefhSrd. _,. ; NlinirnutrF GurvatuK~.. ;- ' Db~ OiaGt~ Survey 11~ID'~. =lueE~ ~ ' ~ A~im `= '~ Ti'D ~'~~ Sys T~D ~ ~.. 1~ilS'~ '~~ : EIW ~ ~ ' Mspl~i .,.. 1f~Iap~ ~~ ~ 1'n~l ;_ :<~ ~ ft ~teg d~ ' ft ft I ft ft . ~ , •:ft it: ,.. : . , - _ _ 1764.18 50.22 100.65 1577.33 1468.33 -92.24 594.42 , ,. 5945600.44 559448.56 __ MWD+IFR-AK-CAZ-SC 1811.78 52.25 100.28 1607.13 1498.13 -98.97 630.91 5945593.99 559485.11 MWD+IFR-AK-CAZ-SC 1860.00 54.41 100.37 1635.93 1526.93 -105.91 668.96 5945587.35 559523.20 MWD+IFR-AK-CAZ-SC 1906.00 56.63 100.95 1661.97 1552.97 -112.92 706.22 5945580.63 559560.51 MWD+IFR-AK-CAZ-SC 1953.65 59.45 100.66 1687.19 1578.19 -120.50 745.93 5945573.37 559600.28 MWD+IFR-AK-CAZ-SC 2002.10 62.53 100.65 1710.68 1601.68 -128.33 787.56 5945565.86 559641.97 MWD+IFR-AK-CAZ-SC 2048.00 65.03 101.48 1730.96 1621.96 -136.24 827.97 5945558.27 559682.43 MWD+IFR-AK-CAZ-SC 2097.58 67.17 100.81 1751.04 1642.04 -145.00 872.44 5945549.86 559726.97 MWD+IFR-AK-CAZ-SC 2140.17 69.96 101.21 1766.61 1657.61 -152.57 911.35 5945542.59 559765.93 MWD+IFR-AK-CAZ-SC 2191.72 69.37 102.10 1784.52 1675.52 -162.33 958.69 5945533.20 559813.34 MWD+IFR-AK-CAZ-SC 2287.00 71.11 99.96 1816.74 1707.74 -179.48 1046.70 5945516.75 559901.47 MWD+IFR-AK-CAZ-SC 2380.33 71.09 98.59 1846.97 1737.97 -193.71 1133.84 5945503.20 559988.71 MWD+IFR-AK-CAZ-SC 2474.42 68.24 99.71 1879.66 1770.66 -207.73 1220.93 5945489.86 560075.90 MWD+IFR-AK-CAZ-SC I i 2520.98 68.57 99.14 1896.80 1787.80 -214.82 1263.64 5945483.11 560118.66 ! MWD+IFR-AK-CAZ-SC ; 2571.00 69.40 99.08 1914.74 1805.74 -222.21 1309.74 5945476.07 560164.81 MWD+IFR-AK-CAZ-SC I 2666.25 69.55 99.54 1948.13 1839.13 -236.64 1397.77 5945462.33 560252.94 MWD+IFR-AK-CAZ-SC ~ 2761.18 69.14 99J2 1981.62 1872.62 -251.50 1485.35 5945448.16 560340.63 MWD+IFR-AK-CAZ-SC I 2857.55 67.86 101.62 2016.94 1907.94 -268.09 1573.46 5945432.26 560428.85 MWD+IFR-AK-CAZ-SC 2951.17 69.85 99.41 2050.71 1941.71 -284.02 1659.30 5945417.01 560514.81 MWD+IFR-AK-CAZ-SC 3046.18 69.57 101.25 2083.66 1974.66 -299.99 1746.96 5945401.72 560602.59 MWD+IFR-AK-CAZ-SC 3138.69 70.42 99.88 2115.31 2006.31 -315.93 1832.42 5945386.45 560688.15 MWD+IFR-AK-CAZ-SC 3231.48 68.92 98.03 2147.55 2038.55 -329.48 1918.36 5945373.58 560774.19 MWD+IFR-AK-CAZ-SC 3325.52 65.04 99.02 2184.32 2075.32 -342.30 2003.94 5945361.43 560859.86 MWD+IFR-AK-CAZ-SC 3421.09 67.53 100.43 2222.75 2113.75 -357.08 2090.17 5945347.32 560946.19 MWD+IFR-AK-CAZ-SC 3515.32 68.53 98.98 2258.01 2149.01 -371.81 2176.30 5945333.26 561032.43 MWD+iFR-AK-CAZ-SC 3566.18 69.06 99.79 2276.41 2167.41 -379.54 2223.08 5945325.90 561079.26 MWD+IFR-AK-CAZ-SC ~ ~ 3610.57 69.16 99.46 2292.23 2183.23 -386.48 2263.97 5945319.28 561120.20 MWD+IFR-AK-CAZ-SC I 3706.46 69.32 98.62 2326.22 2217.22 -400.57 2352.52 5945305.89 561208.85 MWD+IFR-AK-CAZ-SC ' 3802.06 6720 98.35 2361.63 2252.63 -413.67 2440.34 5945293.48 561296.76 MWD+IFR-AK-CAZ-SC i ~ 3898.96 67.00 99.37 2399.34 2290.34 -427.42 2528.54 5945280.42 561385.06 MWD+IFR-AK-CAZ-SC i 3994.30 69.50 99.59 2434.66 2325.66 -442.00 2615.87 5945266.52 561472.50 MWD+IFR-AK-CAZ-SC ; 405$.25 70.90 98.70 2456.33 2347.33 -451.56 2675.28 5945257.42 561531.97 MWD+IFR-AK-CAZ-SC 4125.50 72.67 98.76 2477.35 2365.35 -461.26 2738.41 5945248.22 561595.17 i MWD+IFR-AK-CAZ-SC 4220.99 72.29 99.56 2506.09 2397.09 -475.75 2828.31 5945234.43 561685.17 MWD+IFR-AK-CAZ-SC 4317.00 72.60 99.70 2535.05 2426.05 -491.07 2918.56 5945219.83 561775.53 MWD+IFR-AK-CAZ-SC 4411.79 73.12 99.88 2562.99 2453.99 -506.47 3007.82 5945205.12 561864.90 MWD+IFR-AK-CAZ-SC 4507.64 73.63 97.99 2590.41 2481.41 -520.73 3098.54 5945191.57 561955.72 MWD+IFR-AK-CAZ-SC 4602.45 73.69 97.52 2617.09 2508.09 -533.01 3188.69 5945180.00 562045.96 MWD+IFR-AK-CAZ-SC 4698.64 72.86 97.11 2644.77 2535.77 -544.74 3280.06 5945168.99 562137.41 MWD+IFR-AK-CAZ-SC 4794.59 73.04 98.24 2672.90 2563.90 -556.99 3370.97 5945157.45 562228.40 MWD+IFR-AK-CAZ-SC 4891.77 73.75 98.97 2700.67 2591.67 -570.92 3463.05 5945144.23 562320.57 MWD+IFR-AK-CAZ-SC 4985.59 74.65 99.12 2726.22 2617.22 -585.11 3552.20 5945130.74 562409.82 MWD+IFR-AK-CAZ-SC 5080.94 73.30 99.29 2752.54 2643.54 -599.77 3642.66 5945116.79 562500.39 MWD+IFR-AK-CAZ-SC i ~ 5176.11 72.80 98.31 2780.29 2671.29 -613.70 3732.63 5945103.57 562590.45 MWD+IFR-AK-CAZ-SC ! 5271.45 73.76 96.94 2807.72 2698.72 -625.81 3823.13 5945092.16 562681.03 MWD+IFR-AK-CAZ-SC ~ 5365.06 74.15 94.34 2833.59 2724.59 -634.65 3912.64 5945084.03 562770.61 MWD+IFR-AK-CAZ-SC i 5459.77 74.72 90.73 2859.01 2750.01 -638.68 4003.77 5945080.71 562861.76 MWD+IFR-AK-CAZ-SC ~ i 5556.42 75.49 87.51 2883.86 2774.86 -637.24 4097.15 5945082.88 562955.11 MWD+IFR-AK-CAZ-SC 5651.00 74.08 83.97 2908.69 2799.69 -630.48 4188.15 5945090.36 563046.04 MWD+IFR-AK-CAZ-SC 5745.60 73.37 80.69 2935.21 2826.21 -618.36 4278.13 5945103.17 563135.92 MWD+IFR-AK-CAZ-SC 5839.92 73.31 76.88 2962.26 2853.26 -600.79 4366.74 5945121.43 563224.39 MWD+IFR-AK-CAZ-SC 5934.40 73.90 73.67 2988.93 2879.93 -577.75 4454.39 5945145.15 563311.84 MWD+IFR-AK-CAZ-SC 6029.55 73.76 70.84 3015.44 2906.44 -549.91 4541.42 5945173.68 563398.64 MWD+IFR-AK-CAZ-SC ~ • Halliburton Company Survey Report • ! Halliburton Company Survey Report 'Gampany: GonE~4PhiliipS AlaSl~a;[nC. _ .. D~tte: ~ .;711Qf24t17 ' Ti~i~; 15:35:38 _ =-page: ' 4, : , K~~arule~2iverWnit ~FY~id: _ ' , . ,~ ~" - ~~=~ . ~Q~-rd~uat~~~iE}Itefe~nce:~ ' ~, Weli: 1~ 1~4,;True~lorth=`~~. ° _ '~~~Sitc: ~Guparl.~~'~J Pad ,: ='- ~ _;' ~; ~ . ~ ~ .. ..r. "S~c~CtlcaF(T~}~t~e~'+erc»~e~ '~~ 1J-'~24t~ i04~:(t,_:.. ~ "~ We11~ 1a-"T2{~ ~ ~ ,~ ~etio n {Vb'~ Re~`ei~enC~ V1f211 {4,~~#t~,~t ~#!~ ~t C~UAz) V4'eilpstli~., 1d-~20L2 , , ;;;~', : 5urveyCaktel~t~nM~thod ;~ '~ MinimuixtCtttva~tre :;.'~,'Db: ~'Jfi~c.~ ;; Survey ~~ ~M~3`~ = In~l Azi~n TYI? : .:Sys:TYI~ Nl3 ~~ '~ E1W , ~, ;; Mapl~T ~ ~~., MapE > i Tnui ~ ~ ;' K~~ . , , .:',~i~~ .; ~•:, ft~ =ft ~~~~ ~. ~~~ ft ~:~ft . ~~;" ~~ft ~ ft.: . .. ~ . . ; . . ~_ ~ ~. ~'~ ~:~ ~'~~ 10869.84 89.20 0.40 3687.83 3578.83 3642.65 5730.69 5949375.00 564554.99 MWD+IFR-AK-CAZ-SC ~ 10963.27 89.08 359.63 3689.23 3580.23 3736.07 5730.71 5949468.40 564554.29 MWD+IFR-AK-CAZ-SC j 11056.77 89.02 358.75 3690.78 3581.78 3829.54 5729.39 5949561.86 564552.24 MWD+IFR-AK-CAZ-SC ! 11153.04 88.89 358.76 3692.53 3583.53 3925.78 5727.30 5949658.06 564549.39 MWD+IFR-AK-CAZ-SC 11243.81 89.33 358.90 3693.94 3584.94 4016.52 5725.45 5949748.77 564546.83 MWD+IFR-AK-CAZ-SC 11336.73 89.63 358.58 3694.79 3585.79 4109.41 5723.40 5949841.64 564544.06 MWD+IFR-AK-CAZ-SC ~ 11429.98 89.02 358.43 3695.89 3586.89 4202.62 5720.97 5949934.82 564540.90 MWD+IFR-AK-CAZ-SC i I 11523.49 89.33 357.33 3697.23 3588.23 4296.06 5717.51 5950028.22 564536.71 MWD+lFR-AK-CAZ-SC ~ I ~ 11617.21 89.33 357.18 3698.33 3589.33 4389.66 5713.02 5950121.77 564531.49 MWD+IFR-AK-CAZ-SC ~ 11710.78 89.02 358.49 3699.68 3590.68 4483.15 5709.49 5950215.23 564527.23 MWD+IFR-AK-CAZ-SC ~ i 11803.72 89.08 0.45 3701.22 3592.22 4576.07 5708.63 5950308.13 564525.64 MWD+IFR-AK-CAZ-SC ~, 11897.53 88.65 359.03 3703.08 3594.08 4669.86 5708.20 5950401.90 564524.49 MWD+IFR-AK-CAZ-SC 'i ~ 11991.46 89.08 358,66 3704.94 3595.94 4763.75 5706.31 5950495.77 564521:86 MWD+IFR-AK-CAZ-SC 12084.58 89.14 358.99 3706.38 3597.38 4856.84 5704.40 5950588.83 564519.22 MWD+IFR-AK-CAZ-SC 12177.70 89.39 357.63 3707.58 3598.58 4949.91 5701.66 5950681.86 564515.75 MWD+IFR-AK-CAZ-SC 12270.63 89.39 359.95 3708.57 3599.57 5042.81 5699.69 5950774.73 564513.06 MWD+IFR-AK-CAZ-SC 12363.89 91.18 3.58 3708.10 3599.10 5136.00 5702.57 5950867.94 564515.20 MWD+IFR-AK-CAZ-SC 12457.71 89.70 3.76 3707.38 3598.38 5229.63 5708.57 5950961.60 564520.48 MWD+IFR-AK-CAZ-SC 12550.22 88.09 0.72 3709.17 3600.17 5322.03 5712.19 5951054.02 564523.37 MWD+IFR-AK-CAZ-SC 12643.14 87.35 353.58 3712.87 3603.87 5414.70 5707.57 5951146.65 564518.03 MWD+IFR-AK-CAZ-SC 12725.00 90.60 354.14 3714.33 3605.33 5496.07 5698.82 5951227.93 564508.65 MWD+IFR-AK-CAZ-SC 12772.49 87.35 352.70 3715.18 3606.18 5543.23 5693.38 5951275.05 564502.84 MWD+IFR-AK-CAZ-SC i i 12829.86 86.42 352.62 3718.30 3609.30 5600.05 5686.06 5951331.80 564495.08 MWD+IFR-AK-CAZ-SC I 12862.70 86.49 352.30 3720.33 3611.33 5632.54 5681.76 5951364.25 564490.52 MWD+IFR-AK-CAZ-SC 12923.22 87.90 354.33 3723.29 3614.29 5692.57 5674.73 5951424.22 564483.02 MWD+IFR-AK-CAZ-SC ~ 13016.68 88.03 358.77 3726.61 3617.61 5785.78 5669.11 5951517.38 564476.67 MWD+IFR-AK-CAZ-SC i 13111.59 89.82 2.68 3728.39 3619.39 5880.65 5670.31 5951612.24 564477.13 MWD+IFR-AK-CAZ-SC 13143.56 90.62 4.13 3728.27 3619.27 5912.56 5672.21 5951644.16 564478.78 MWD+IFR-AK-CAZ-SC 13203.95 91.61 4.92 3727.09 3618.09 5972.75 5676.97 5951704.38 564483.07 MWD+IFR-AK-CAZ-SC 13296.84 91.86 3.02 3724.28 3615.28 6065.37 5683.40 5951797.04 564488.78 MWD+IFR-AK-CAZ-SC 13392.36 91.36 2.29 3721.60 3612.60 6160.75 5687.82 5951892.44 564492.45 MWD+IFR-AK-CAZ-SC 13484.87 91.73 2.01 3719.10 3610.10 6253.16 5691.29 5951984.86 564495.20 MWD+IFR-AK-CAZ-SC 13578.88 91.24 2.04 3716.67 3607.67 6347.08 5694.61 5952078.80 564497.79 MWD+IFR-AK-CAZ-SC 13628.18 91.11 1.71 3715.66 3606.66 6396.34 5696.22 5952128.07 564499.01 MWD+IFR-AK-CAZ-SC ~ 13720.39 90.00 358.88 3714.76 3605.76 6488.53 5696.70 5952220.25 564498.77 MWD+IFR-AK-CAZ-SC i 13765.57 90.68 358.63 3714.50 3605.50 6533.70 5695.72 5952265.41 564497.43 MWD+IFR-AK-CAZ-SC ; 13816.74 90.07 356.96 3714.16 3605.16 6584.83 5693.75 5952316.51 564495.06 MWD+IFR-AK-CAZ-SC 13858.79 90.44 355.53 3713.97 3604.97 6626J9 5690.99 5952358.45 564491.98 MWD+IFR-AK-CAZ-SC i ~~ 13952.13 89.82 353.00 3713.76 3604.76 6719.65 5681.67 5952451.23 564481.93 MWD+IFR-AK-CAZ-SC I' 14044.53 89.82 352.17 3714.05 3605.05 6811.28 5669.74 5952542.75 564469.29 MWD+IFR-AK-CAZ-SC j 14136.98 88.77 352.73 3715.19 3606.19 6902.92 5657.60 5952634.28 564456.43 MWD+IFR-AK-CAZ-SC i 14228.69 89.94 355.01 3716.22 3607.22 6994.09 5647.81 5952725.37 564445.93 MWD+IFR-AK-CAZ-SC 14319.44 86.18 356.77 3719.29 3610.29 7084.54 5641.31 5952815.75 564438.72 MWD+IFR-AK-CAZ-SC 14409.93 87.72 354.17 3724.11 3615.11 7174.61 5634.17 5952905.75 564430.88 MWD+IFR-AK-CAZ-SC ' 14499.66 88.34 356.59 3727.19 3618.19 7263.98 5626.95 5952995.06 564422.96 MWD+IFR-AK-CAZ-SC ', 14590.90 88.46 358.99 3729.74 3620J4 7355.11 5623.43 5953086.15 564418.73 MWD+IFR-AK-CAZ-SC i 14682.29 90.00 4.16 3730.97 3621.97 7446.43 5625.94 5953177.47 564420.53 MWD+IFR-AK-CAZ-SC l 14713.78 90.25 5.61 3730.90 3621.90 7477.80 5628.62 5953208.86 564422.97 MWD+IFR-AK-CAZ-SC Ii 14772.11 89.94 4.64 3730.81 3621.81 7535.90 5633.83 5953266.99 564427J2 MWD+IFR-AK-CAZ-SC 14817.19 90.50 4.39 3730.63 3621.63 7580.84 5637.38 5953311.96 564430.92 MWD+IFR-AK-CAZ-SC 14863.59 89.94 3.15 3730.45 3621.45 7627.14 5640.43 5953358.27 564433.61 MWD+IFR-AK-CAZ-SC 14954.69 88.46 356.26 3731.73 3622.73 7718.17 5639.96 5953449.29 564432.43 MWD+IFR-AK-CAZ-SC ~ 14988.56 89.08 357.43 3732.45 3623.45 7751.98 5638.10 5953483.08 564430.30 MWD+IFR-AK-CAZ-SC i I~ ~ • Halliburton Company Survey Report '.Compa~ty: ContSGDl~hillips Alaska tnc. Datc : 71 i tI/2i3t17 Time: 1~:35:~$ page: ' ~ d nit s e~ K ~ k iJ C ~ aic~~Re~ren~e < w~[~ iJ-12a, Treae I~~rtn .. ... i u a~ ' ~ P ' Ye~ ~ ' (T1'~} ttce < 1J 12QL2: 1Q9.U Weli: " ` 1.1-12U S+c~tion(~?S);I2eferegce: ' iNetl~A;t1~N,Q,t~0~,0.Q4Ax~ Weilpat6: 'i.!-I2(1L2 ~nrvey Cak~atio n M'etbod lMinimutn GurvatU6e:: ' llb: Qracte Survey ~ 14~D' Incl; , A~im ' T'~I) `- Sys T'UD `" P~T/S . _., E1V~ ~~ ik~p~i l~pE Tnoi •' ~k ', deg: ,d~ ' ' fk ft : ', ft . . ft 'ft : ft' 15045.23 89.20 357.80 3733.31 3624.31 7808.59 5635.74 5953539.67 564427.50 MWD+IFR-AK-CAZ-SC 15087.64 89.08 356.44 3733.94 3624.94 7850.94 5633.61 5953582.00 564425.04 MWD+IFR-AK-CAZ-SC 15136.39 89.57 354.41 3734.52 3625.52 7899.53 5629.72 5953630.55 564420.77 MWD+IFR-AK-CAZ-SC 15173.62 90.00 355.89 3734.66 3625.66 7936.63 5626.58 5953667.62 564417.34 MWD+IFR-AK-CAZ-SC 15227.51 89.76 357.36 3734.77 3625.77 7990.42 5623.40 5953721.38 564413.74 MWD+IFR-AK-CAZ-SC 15319.06 86.92 357.42 3737.42 3628.42 8081.83 5619.24 5953812.74 564408.86 MWD+IFR-AK-CAZ-SC 15410.06 88.77 1.95 3740.84 3631.84 8172.74 5618.74 5953903.63 564407.66 MWD+IFR-AK-CAZ-SC 15501.11 89.76 3.12 3742.01 3633.01 8263.69 5622.77 5953994.60 564410.97 MWD+IFR-AK-CAZ-SC 15543.66 89.33 3.40 3742.35 3633.35 8306.17 5625.19 5954037.10 564413.06 MWD+IFR-AK-CAZ-SC 15589.40 89.57 2.95 3742.79 3633.79 8351.83 5627.72 5954082.78 564415.23 MWD+IFR-AK-CAZ-SC 15631.97 89.39 1.41 3743.18 3634.18 8394.37 5629.34 5954125.32 564416.52 MWD+IFR-AK-CAZ-SC 15676.76 88.83 359.19 3743.87 3634.87 8439.15 5629.57 5954170.10 564416.41 MWD+IFR-AK-CAZ-SC ~ 15725.87 89.20 359.09 3744.72 3635.72 8488.25 5628.84 5954219.18 564415.28 MWD+IFR-AK-CAZ-SC ~ 15769.35 88.83 0.14 3745.46 3636.46 8531.72 5628.54 5954262.65 564414.65 MWD+IFR-AK-CAZ-SC ~ 15860.19 89.63 2.22 3746.68 3637.68 8622.53 5630.41 5954353.46 564415.81 MWD+IFR-AK-CAZ-SC ~ 15951.13 88.65 1.95 3748.05 3639.05 8713.39 5633.72 5954444.34 564418.41 MWD+IFR-AK-CAZ-SC ~ 15994.43 88.34 1.91 3749.19 3640.19 8756.66 5635.18 5954487.61 564419.53 MWD+IFR-AK-CAZ-SC I 16033.00 ~ 88.34 1.91 3750.30 - 3641.30 8795.19 5636.46 5954526.14 . 564420.51 • PROJECTED to TD ! • 06/02/2007 11:30 ]6:00 4.50 0 0 COMPZ WELC T BOPE P RU and tested BOPE, tested rams, manifold and valves to 250 psi low and 3,000 psi high induding annular, tested with 4" and 4 1/2" testjts, performed Koomey test, starting press. 3,000 psi, after functioning rams 1,700 psi, took 38 seconds to ~ build 200 psi and 3 min 1 second for full recovery. 5 nitrogen 6ottles ave 2,200 psi. NOTE: Chuck Scheve with AOGCC waived witnessin of the test. 16:00 16:30 0.50 0 0 COMPZ STK OTHR P Installed wear bushing. 16:30 16:45 0.25 0 0 PROD3 STK OTHR P Held PJSM with Baker rep and Sperry Sun on MU of whipstock assernbly , with MWD. 16:45 20:00 3.25 0 512 PROD3 STK PULD P MU "D" sand whipstock seals and milling assembly along with MWD, oriented and uploaded same, then RIH with BHA #11 to 512'. 20:00 20:15 0.25 512 606 PROD3 STK OTHR P RIH 1 std to 606' and shallow tested MWD and ck'd ok. ~ 20:15 00:00 3.75 606 6,207 PROD3 STK TRIP P RIH whipstock from 606' to 6,207'. 06/03/2007 00:00 00:30 0.50 6,207 7,401 PROD3 STK TRIP P RIH with whipstock from 6,207' fo 7,401'. 00:30 01:00 0.50 7,401 7,478 PROD3 STK OTHR P Made MADD pass across K-13 sand from 7,401' to 7,478' 01:00 01:15 0.25 7,478 8,338 PROD3 STK TRIP P RIH from 7,478' to 8,338' ~ 01:15 02:00 0.75 8,338 8,370 PROD3 STK TRIP P Est circ at 275 gpm at 2,450 psi, st wt ' ~ ~ ~~' up 138K, dn wt 70K, RIH and oriented 1, .1.f WS to 17 deg. left of high side then ~ set WS by tagged up on "B" lat ZXP ' pkr at 8,370 and sheared off from same. 02:00 02:15 0.25 8,370 8,239 PROD3 STK CIRC P Began to displace hole over from SFMOBM to 8.5 ppg MOBM, pumped ~ - -.. ~ .-- ___ - - - -_ mud to above WS mills. ~ 02:15 07:00 4.75 8,239 8,281 PROD3 STK WPST P Milled window in "D" sand lateral from ~ 8,239' to 8,252' (13') then milled ' ~~ ~.~ 3-,i L• formation from 8,252' to 8,281' laaving 20' of gauged hole outside of the ~" ~ ~ ~~ ~r window. Milied at 2-6K WOM, 70-90 rpm's, 4-6K ft-Ibs torque, 300 gpm at 2,600 si. 07:00 08:00 1.00 8,281 8,207 PROD3 STK CIRC P Pumped 30 bbl wYd hi vis sweep and circ hole clean while working mills thru the window, circ at 300 gpm, 2,600 psi at 100 ~ m's with 5-7K ft-Ibs tor ue. 08:00 08:15 0.25 8,207 8,207 PROD3 STK OTHR P Monitored well-static, blew down top drive. 08:15 09:15 1.00 8,207 4,676 PROD3 STK TRIP P POOH from 8;207' to 4,676' 09:15 09:30 0.25 4,676 4,676 PROD3 STK OTHR P Held BOP kick while tripping drill with rig crew then held post drill discussion with the crew. f 06/03/2007 09:30 11:30 2.00 4,676 99 PROD3 STK TRIP P POOH from 4,676' to BHA at 99'. 11:30 12:30 1.00 99 0 PROD3 STK PULD P Downloaded MWD and LD milling assembly, upper mill in gauge and cleared ri floor. 12:30 13:30 1.00 0 0 PROD3 STK OTHR P Pulled wear bushing and flushed out BOP stack, re-installed wear bushin . 13:30 13:45 0.25 0 0 PROD3 RIGMN SFTY P Held PJSM on slipping on new spool of drl line. 13:45 16:30 2.75 0 0 PROD3 RIGMN SVRG P Slipped on 1,500' of drlg line from new s ool. 16:30 18:15 1.75 0 370 PROD3 DRILL PULD P MU Geopilot BHA #12 RIH to 370, MU 6 3/4" bit #5 rr2 on Geopilot, MWD and u foaded same. 18:15 18:45 0.50 370 463 PROD3 DRILL TRIP P RIH from 370' to 463'. 18:45 19:30 0.75 463 463 PROD3 DRILL DHEQ P Shallow tested MWD and broke in Geopilot at 280 gpm 1,050 psi at 80 r m's. 19:30 22:30 3.00 463 8,270 PROD3 DRILL TRIP P RIH from 463' to 8,270', no problems going thru the window. (TOW at 8,239'-BOW at 8,252' . 22:30 22:45 0.25 8,270 8,281 PROD3 DRILL REAM P Washed down from 8,270' to btm at 8,281'. 22:45 00:00 1.25 8,281 8,352 PROD3 DRILL DDRL P Drilled 6 3/4" hole with Geopilot from 8,281' to 8,352' MD/3,601' TVD (71') ADT .4 hrs, 8.5 ppg MOBM MW, ECD 9.52 06/04/2007 00:00 08:15 8.25 8,352 8,766 PROD3 DRILL DDRL P Directionally drilled 6 3/4" hole in "D" sand lateral with Geopilot from 8,352' to 8,766' MD/ 3,639' TVD ( 414') ADT 6.84 hrs. Lost highline power to rig and cam 08:15 08:45 0.50 8,766 8,766 PROD3 DRILL OTHR NP Lost highline to rig and camp, started rig engines. NOTE: rig and camp was back on hi hline at 10:10 hrs. 08:45 12:00 325 8,766 8,856 PROD3 DRILL DDRL P Cont. to directionally drill 6 3/4" hole from 8,766' to 8,856' MD/ 3,641' ND, (90') ADT 2.68 hrs, 8.4 ppg MOBM, ave ECD 9.86 ppg. drilled thru 4 concretions for 35'. 12:00 00:00 12.00 8,856 10,070 PROD3 DRILL DDRL P Cont. to directionally drili 6 3/4" hole from 8,856' to 10,070' MD/ 3,671' ND, (1,214') ADT 7.88 hrs, 8.45 ppg MOBM, ave ECD 10.14 ppg. ave BGG 20 units max gas 92 units, drilled thru 8 concretions for 32'. No swee s. 06/05/2007 00:00 00:15 0.25 10,070 10,070 PROD3 DRILL SFTY P PJSM - Hazard Assessment & Reco nition on Drillin ahead. 00:15 12:00 11.75 10,070 10,538 PROD3 DRILL DDRL P Cont. to directionally drill 6 3/4" hole from 10,070' to 10,538' MD! 3,678' ND (468') - ADT 8.53 hrs - 8.4 ppg MOBM - Ave ECD 9.98 ppg - Max gas 116 units - Drilled thru 6 concretions for 39'. No sweeps. 06/05/2007 12:00 1830 6.50 10,538 11,469 PROD3 DRILL DDRL P Cont. to directionally drill 6 3/4" hole from 10,538' to 11,469' MD/ 3,695' ND (931') - ADT 4.29 hrs - Pump 35 BBLS Hi-Vis swee . 18:30 19:15 0.75 11,469 11,469 PROD3 DRILL CIRC P Cire sweep out of hole @ drilling rates of 305 GPM & 130 rpm - 25% increase in cuttin s. 19:15 00:00 4.75 11,469 11,937 PROD3 DRILL DDRL P Cont. to directionally drill 6 3/4" hole from 11,469' to 11,937' MD/ 3,703' TVD (468') - ADT 6.74 hrs - 8.4+ ppg MOBM - Ave ECD 10.66 - Ave BGG 25 units - Max gas 131 units - Dri-led thru 1 concretion for 6'. 06/06/2007 00:00 00:15 0.25 11,937 11,937 PROD3 DRILL SFTY P PJSM - Hazard Assessment & Reco nition on Drillin ahead. 00:15 12:00 11.75 11,937 12,537 PROD3 DRILL DDRL P Cont. to directionally drill 6 3/4" hole from 11,937' to 12,537' MD/ 3,709' ND (600') - ADT 8.05 hrs - 8.4 ppg MOBM - Ave ECD 10.73 ppg - Max _ gas 140 units - Drilled thru 5 concretions for 29'. Pumped 35 BBL Hi-Vis Sweep @ 12,200' MD with 15% increase in returns. 12:00 00:00 12.00 12,537 13,150 PROD3 DRILL DDRL P Cont. to directionally drill 6 3/4" hole from 12,537' to 13,150' MD/ 3,706' TVD (613') - ADT 8.61 hrs - 8.4 ppg MOBM - Ave ECD 11.29 - Ave BGG 25 units - Max gas 69 units - Drilled thru 6 concretions for 51'. 06/07/2007 00:00 00:15 0.25 13,150 13,212 PROD3 DRILL DDRL P Cont. to directionally drill 6 3/4" hole from 13,150' to 13,212' MD - 3,703' ND (62') - ADT 0.041 hrs - Drilled thru 1 concretion for 3'. 00:15 00:30 025 13,212 12,685 PROD3 DRILL REAM T Discuss rock quality with geologist & engineer - Decision made to PUH & sidetrack. Backream from 13,212' to 12,685' MD. 00:30 01:30 1.00 12,685 12,695 PROD3 DRILL OTHR T Work string from 12,685' to 12,695' while MWD re-programs system in re aration for sidetracked wellbore. 01:30 02:00 0.50 12,695 12,725 PROD3 DRILL DDRL T Begin troughing per DD from 12,695' to 12,725' MD. 02:00 04:00 2.00 12,725 12,737 PROD3 DRILL DDRL T Start Time Drilling per DD on open hole sidetrack from 12,725' to 12,737' M D. 04:00 12:00 8.00 12,737 12,826 PROD3 DRILL DDRL T Directionally drill new 6-3/4" hole w/Geopilot from 12,737' to 12,826' MD - 3723' TVD (89') - ADT 7.59 hrs - Ave ECD 10.92' - Max gas 58 units - Drilled thru 2 concretions for 42'. 12:00 13:30 1.50 12,826 13,010 PROD3 DRILL DDRL T Continue to directionally drill 6-3/4" hole from 12,826' to 13,010' - ADT 1.26. 13:30 13:45 0.25 13,010 13,010 PROD3 DRILL REAM T Troubleshoot MWD due to erratic resistivity readings - Switch detection modes - POOH to 12,870' - RIH to BTM & trv aqain. ~ 06/07/2007 13:45 14:15 0.50 13,010 13,010 PROD3 DRILL OTHR T POOH f/13,010' to 12,870' MD - MWD appears to be working. RIH to 13,010' MD. 14:15 14:45 0.50 13,010 13,056 PROD3 DRILL DDRL T Continue drilling from 13,010' - 13,056' MD. ADT 0.28 hrs. 14:45 15:15 0.50 13,056 13,056 PROD3 DRILL OTHR T Continue to have tool problems - Trouble shoot MWD. 15:15 15:45 0.50 13,056 13,056 PROD3 DRILL OWFF T Survey off btm - Record SPR's. Monitor well - static. 15:45 16:15 0.50 13,056 12,620 PROD3 DRILL REAM T BROOH from 13,056' to 12,620' MD - 305 gpm @ 2750 psi, 85 spm, 120 rm 16:15 17:45 1.50 12,620 13,013 PROD3 DRILL OTHR T Trouble shoot MWD tools - Log 2 passes from 12,611' - 12,525' and 12,960' to 13,013' MD. 17:45 18:30 0.75 13,013 13,056 PROD3 DRILL TRIP T MWD appears to be working - Decision made per drlg engineer - RIH from 13,013' to 13,056' MD & continue drillin . 18:30 19:30 1.00 13,056 13,184 PROD3 DRILL DDRL T Continue to drill from 13,056' to 13,184' MD - 3727' ND. ADT 0.59 hrs - Max Gas 58 units - Ave ECD 10.79. 19:30 19:45 0.25 13,184 13,184 PROD3 DRILL OWFF T Decision made to POOH due to MWD failure - unreliable resistivity readings. Monitor well - static. 19:45 20:00 0.25 13,184 12,905 PROD3 DRILL TRIP T Attempt to POOH on elevators from 13,184' to 12,905' MD - Well swabbing and not takin ro er fill. 20:00 00:00 4.00 12,905 9,419 PROD3 DRILL REAM T BROOH from 12,905' to 9,419' MD - 305 2750 si, 85 s m, 120 m 06/08/2007 00:00 00:45 0.75 9,419 8,207 PROD3 DRILL REAM T Continue to back ream at 305 gpm, 2750 psi, and 120 rpm from 9,419' to 8,394' MD - POOH once stabilizers & bit across window from 8,394' to 8,207' M D. 00:45 01:00 0.25 8,207 8,207 PROD3 DRILL OTHR T Flow check - Static - Pump Dry Job and Blow Dwn To drive. 01:00 03:00 2.00 8,207 369 PROD3 DRILL TRIP T POOH on elevators from 8207' to 369' MD. 03:00 03:15 0.25 369 88 PROD3 DRILL PULD T Set back 25 stds HWDP w/Jars and NonMa Flex DC's 03:15 04:15 1.00 88 88 PROD3 DRILL OTHR T Check oil in GeoPilot - Plug into and download MWD 04:15 04:45 0.50 88 0 PROD3 DRILL PULD T LD Stab Float sub - TM - DGR, EWR, PWD - Break Bit 04:45 05:30 0.75 0 88 PROD3 DRILL PULD T MU BHA# 13 - PU New Bit, DGR, EWR, TM - Same PWD 05:30 06:15 0.75 88 88 PROD3 DRILL OTHR T Plug in and UpLoad MWD 06:15 06:30 025 88 463 PROD3 DRILL TRIP T Trip in hole to 463' MD. 06:30 07:00 0.50 463 463 I PROD3 DRILL DHEQ T Shallow Hole Test MWD @ 78 spm, 1051 qsi ~ • 06/08/2007 07:00 12:00 5.00 463 11,846 PROD3 DRILL TRIP T Continue to TIH from 463' to 9326' MD - Ran out of SO Wt - Reamed from 9326' to 9512' MD @ 41 spm, 100 rpm, Trq 7000, 1051 psi Continue to TIH from 9,512' to 11,098' MD - Reamed from 11,098' - 11,846' MD @ Same, Rot Wt = 75K. Filled pipe & tested MWD @ 2704', 5037', and 7368' MD. 12:00 13:00 1.00 11,846 12,951 PROD3 DRILL TRIP T PJSM - Continue RIH f/ 11,846' to 12,951' MD. 13:00 14:15 1.25 12,951 13,184 PROD3 DRILL SRVY T Madd Passfrom 12,951'to 13,184' MD @ 100 rpm, Trq 8000, 81 spm @ 2850 psi (250-300 FPH). Rot Wt = 81 K, SO = 0, PU = 145K si. 14:15 14:30 0.25 13,184 13,212 PROD3 DRILL DDRL T Directionally Drill from 13,184' to 13,212' MD - 3,726' ND - ADT 0.25 H rs. 14:30 00:00 9.50 13,212 14,034 PROD3 DRILL DRLG P Continue Drilling from 13,212' MD to 14,034' MD - 3,714' ND. ADT 4.67 hrs - 8.4+ ppg MOBM - Ave ECD 11.38 - Ave BGG 38 units - Max Gas 84 units - Drilled thru 2 concretions for 18'. Pumped Hi-Vis sweep @ 13,375' w/ 15% increase in cuttin s. 06/09/2007 00:00 00:15 0.25 14,034 14,034 PROD3 DRILL SFTY P PJSM - Hazard Assessment and Recognition on Drilling & Making connections. 00:15 12:00 11.75 14,034 15,088 PROD3 DRILL DDRL P Continue Drilling 6-3/4" hole with Geopilot from 14,034' MD to 15,088' MD - 3,733' ND. ADT 7.6 hrs - 8.4+ ppg MOBM - Ave ECD 10.26 - Max Gas 67 units - Drilled thru 6 concretions for 25'. 12:00 00:00 12.00 15,088 15,717 PROD3 DRILL DDRL P Continue Drilting 6-3/4" hole with Geopilot from 15,088' MD to 15,717' MD - 3,744' ND. ADT 6.62 hrs - 8.4 ppg MOBM - Ave ECD 11.49 - Max Gas 73 units - Drilled thru 9 concretions for 44'. 06/10/2007 00:00 02:00 2.00 15,717 16,033 PROD3 DRILL DDRL P Continue Drilling 6-3/4" hole with Geopilot from 15,717 MD to 16,033' MD 3750' TVD. ADT 1.3 hrs. 02:00 12:00 10.00 16,033 8,200 PROD3 DRILL REAM P BROOH from 16,033' MD to 8,200' MD @ 130 RPM - 89 spm - Initial pressure = 3800 psi. PU Wt 180K, SO Wt 0, Rot Wt 105, Trq 11,000. No problems encountered. 12:00 13:30 1.50 8,200 8,200 PROD3 DRILL CIRC P PJSM - Pump 30 BBL Hi-Vis sweep - Circulate & Recip from 8200' - 8100' MD @ 315 GPM, 2370 psi, 100 rpm - Sweep returned 15% excess - Continue circulatin 2 BU. 13:30 13:45 0.25 8,200 8,200 IPROD3 DRILL SFTY P PJSM - Cut and slip drilling line Hazard Recoqnition ~ i • 06/10/2007 13:45 14:45 1.00 8,200 8,200 PROD3 RIGMN SVRG P Cut & slip 74' Drlg line - Inspect & adjust brakes - Service Top Drive & Blocks - Monitor well. 14:45 16:15 1.50 8,200 11,380 PROD3 DRILL TRIP P Check coomie & RIH from 8200' to 11,380' MD (lost SO wt) Filled DP @ 11, 002'. 16:15 21:00 4.75 11,380 16,033 PROD3 DRILL REAM P Wash and ream from 11,380' to 16,033' MD @ 3.5 bpm & 90 rpm. Pick u 2 sin Ves to reach TD. 21:00 00:00 3.Q~ 16,033 16,033 PROD3 DRILL CIRC P Pump 30 bbl Hi-Vis sweep - Circ & Recip from 16,033' to 15,962' @ 300 gpm, 3900 psi, 130 rpm. Sweep returned 5% excess. Continue to circulate 2 BU's. 06/11/2007 00:00 00:15 0.25 16,033 16,033 PROD3 DRILL SFTY P PJSM on Displacement of SFOBM. Hazard assessment & designate spill cham for the 'ob. 00:15 01:00 0.75 16,033 16,033 PROD3 DRILL CIRC P Continue circulating & recip @ 300 GPM, 3900 psi, 130 rpm, Trq 10,000 ft-Ibs. 01:00 03:00 2.00 16,033 16,033 PROD3 DRILL CIRC P Displace to SFOBM @ 300 GPM, 3900 psi, 130 rpm. Obtain SPR's and flow check well - static. 03:00 10:15 7.25 16,033 370 PROD3 DRILL TRIP P LD 2 singles, Drop 1.88" OD Drift Rabbit on wire - POOH on elevators from 15,992' MD to 370' MD. Initia! wts: PU 210K, SO 0, Rot 102K. 10:15 1030 0.25 370 370 PROD3 DRILL SFTY P Flow check static - PJSM Hazard Assessment & Recognition on LD BHA. 10:30 11:15 0.75 370 88 PROD3 DRILL PULD P LD 5 jts HWDP, Jars, 3 jts NM Flex DC's, Stab & Float sub. 11:15 12:00 0.75 88 88 PROD3 DRILL OTHR P Plug in and download MWD. 12:00 13:00 1.00 88 0 PROD3 DRILL PULD P PJSM - LD MWD - GeoPilot & Bit - Clear Floor. 13:00 13:30 0.50 0 0 COMPZ CASINC RURD P RU equipment to run 4-1/2" slotted liner. 1330 13:45 0.25 0 0 COMPZ CASINC SFTY P PJSM for liner run; Identify hazards and review rocedure and liner detail. 13:45 18:00 4.25 0 7,520 COMPZ CASIN( RNCS P Run 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing to 7,520' as follows: Shoe Joint - 80 jts csg - 75 jts csg w/ Trq rings - XO - 22 jts Hydril 521 11.6 ppf L80 slotted csg - Hyd521 pup jt - XO. (177 jts total) Total of 75 Trq rings, 154 Hydroform centralizers w/no stop rings on jts #2 - 155. 18:00 19:00 1.00 7,520 7,582 COMPZ CASINC RNCS P PU Baker setting sleeve assembly - MU Baker Liner Receptacle Jt - Liner Pup Jt -"HR" Liner setting Sleeve. RD Casina Eaui~ment & Monitor well. ~ • 06/11/2007 19:00 00:00 5.00 7,582 14,172 COMPZ CASIN( RUNL P RIH with 4-1/2" liner on 4" DP from 7582' to 14,172'. Fill pipe every 15 stds. Lost SO wt @ 11,285' - Rotate liner to 14,172' MD @ 25 rpm. Rot wt 55K, Pu wt 150K, Tr 7000 ft-Ibs. 06/12/2007 00:00 02:15 2.25 14,172 16,033 COMPZ CASIN RNCS P Continue RIH w/4-1/2" liner on 4" DP - Rotating from 14,172' MD to 16,033' @ 25 rpm - Trq Limit set @ 8K. Recording Trq & Drag every 5 stands. PU Wt 185k, SO Wt 0, Rot 35k. Tight hole, worked pipe from 15,808' MD to Btm - Increased Trq limit to 14K ft-Ibs. Ta ed btm 16,042' MD. 02:15 03:00 0.75 16,033 8,469 COMPZ CASIN( CIRC P Drop 29/32" ball & circulated 850 sks down to ball seat - Pressured up to 4400 psi to release from running tool. PU Wt 155k, SO Wt 55k. Tagged top of liner @ 8469' MD. (9' below tally de th 03:00 06:15 3.25 8,469 0 COMPZ CASIN( RUNL P Flow check static - Blow Dwn TD - POOH from 8,469' MD to Baker settin tool - LD Liner Settin Tool. 06:15 06:30 0.25 0 0 COMPZ CASIN( OTHR P Cleared Rig Floor. 0630 07:00 0.50 0 344 COMPZ FISH PULD P PU & MU Baker Whipstock retrieving hook assembly with 1 Jt 3.5" HWDP, Flt Sub, Bumper sub, Oil Jars, XO, 3 Stds ush i e. 07:00 09:45 2.75 344 8,251 COMPZ FISH TRIP P TIH from 344' to 8,251' MD filling pipe 2,761' - 5,187' - 7,284' MD. 09:45 10:00 0.25 8,251 8,251 COMPZ FISH CIRC P Wash whipstock slot @ 8,244' MD @ 7 bpm, 1700 psi. PU Wt 130, SO 0 si. 10:00 10:15 0.25 8,251 8,244 COMPZ FISH FISH P Engage hook @ 8244' MD - Jar Free with 70K over. PU Wt 150K 10:15 12:00 1.75 8,244 7,192 COMPZ FISH TRIP P Monitor well on TT - Static. POOH from 8,244' to 7,192' MD. Dis lacement 1 bbl lon . 12:00 14:00 2.00 7,192 334 COMPZ FISH SFTY P PJSM - Hazard Recognition - CONT POOH to BHA 14:00 14:30 0.50 334 334 COMPZ FISH PULD P Stand back DC's, LD Oil Jars & Bum er sub. 14:30 16:00 1.50 334 0 COMPZ FISH PULD P LD Whipstock Assembly - Clean & Clear ri floor of tools. 16:00 16:30 0.50 0 0 COMPZ CASIN( RURD P PU & RU Tools for Hook Hanger Assembl 1630 16:45 0.25 0 0 COMPZ CASIN SFTY P PJSM - Review procedures & Hazards associated with hook hanger and PU slim hole MWD tools. 16:45 19:00 2.25 0 380 COMPZ CASIN PUTB P PU'D' Lateral Hook HangerAssembly with ECP Packer, Inner String, slim hole MWD - RIH and shallow tested tools an 380' MD. ~ • 06/12/2007 19:00 21:30 2.50 380 8,407 COMPZ CASIN RUNL P RIH with Hook Hanger Assembly and running tool on 4" DP as follows: 4.5" STL BENT jt Blank casing w/ full mule shoe - 4.5" XO Jt - 4.5" Pup jt - PayZone External Casing Packer - 4.5" Pup Jt - Space out pup jt - 2 Marker Pup Jts - 3 jts 4.5" 11.6 ppf L-80 BTC Blank Csg - BTC Hanger pup jt - Baker Model B-1 Hook Hanger. ~"Went into wellbore and tagged XO Bushing in B Lateral Liner @ 8407' MD" 21:30 23:00 1.50 8,515 8,515 COMPZ CASIN RUNL P POOH to above D Lat Liner @ 8222' and rotate 3x. On the 2nd attempt entered D-Lateral. PUH and oriented to High side. PU Wt 150K - SO Wt 60K. Hooked window @ 8252' MD with tool face 3 deg Right. Unhook and PU to 8222' and orient tool face 180 deg - SO to 8264' without tag. (6' below calculated tag). PU to 8222' and orient High Side & ReHook window @ 8252' with tool face @ 3 deg right. Slack 25K Dwn Wt - Confirmed hook was ositioned ro erl . 23:00 00:00 1.00 8,515 8,515 COMPZ CASIN( OTHR P Dropped ball & pumped down to seat @ 2.8 bpm, 900 psi. Ball on seat at 2000 psi - Quickly pressured up to 2700 psi to open valve - Re-Zero stroke counter & inflate ECP with a total of 0.25 bbls at 2800 psi - Increased PP to 4000 psi to release running tooi - PUH to confirm. Set top of HH at 8,252' MD with Mule Shoe @ 8515.74'. 06/13/2007 00:00 02:30 2.50 8,515 100 COMPZ CASINC RUNL P Completed pumping to inflate packer, blow ball seat & release from Hook Hgr setting tool. Blow Down - Flow check static - POOH to HH setting tool. 02:30 03:30 1.00 100 0 COMPZ CASINC RURD P Break Hook Hgr setting tool and lay down - Change elevator and lay down slim hole MWD and innerstrin . 03:30 03:45 0.25 COMPZ CASIN OTHR P Clear and Clean Rig Floor 03:45 04:00 0.25 COMPZ DRILL SFTY P PJSM - Discussed hazards with LD 4" DP via mouse hole to i e shed. 04:00 12:00 8.00 COMPZ DRILL PULD P Lay Down 396 jts of 4" DP to pipe shed. 12:00 12:15 0.25 COMPZ DRILL SFTY P PJSM - Discuss hazards and rocedures with LD 4" DP 12:15 14:30 2.25 COMPZ DRILL PULD P Continue LD 4" DP, HWDP, and H brid DC's. 14:30 14:45 0.25 ( COMPZ RIGMN SFTY P PJSM - Hazard recognition for Cut & slip DL. i 06/13/2007 14:45 15:45 1.00 COMPZ RIGMN SVRG P Cut & slip 81' of drilling line - Inspect Brakes - Check Crown-o-matic - Lube blocks, TD, & Crown 15:45 16:15 0.50 COMPZ RPCOti RURD P RU equipment to PU 4-1/2" Tbg 16:15 16:30 0.25 COMPZ RPCOh SFTY P PJSM - Review Hazards with PU Tbg 1630 00:00 7.50 COMPZ RPCOh PULD P RIH picking up 4-1/2" completion tbg 258 'ts total) 06/14/2007 00:00 00:15 0.25 COMPZ RPCOh SFTY P PJSM - Hazard recognition & awareness for POOH w/ tb . 00:15 02:45 2.50 COMPZ RPCOti PULD P Continue to POOH with 4-1/2" Tbg and racking back in the derrick. Total of 86 stands 258 'ts . 02:45 03:15 0.50 COMPZ RPCOh OTHR P Pull wear ring. 03:15 04:45 1.50 COMPZ RPCOh RURD P PU clamps and protectorizers, ESP sheeve, and tools from beaverslide. Pre-Job count = 255 Clamps & 13 SS Bands. 04:45 05:00 0.25 COMPZ RPCOh SFTY P PJSM with Halliburton Wireline, Centralift, and crews to review job procedures and discuss hazards with runnin ESP com letion. 05:00 05:30 0.50 COMPZ RPCOh RURD P PU Centralift Perforated Crossover w/Screen Intake, pup jt, and 2 jts 4-1/2" 12.6# L-80 IBTM tbg. PU Internal um assembl . 05:30 07:00 1.50 COMPZ RPCOh SLKL P Wireline RIH to seat pump assembly - Install D&D Pack Off with slip stop - Test on chart to 1000 psi (Good test). RD Slickline. PU Pup jt, Unique dischar e sub, u 't. 07:00 07:30 0.50 COMPZ RPCOh PULD P Rack back pump housing, 2 jts tbg, and dischar e sub. 07:30 10:00 2.50 COMPZ RPCOh PULD P PU & MU Weatherford Pump Gauge, Motor, Lower and Upper Tandem seal assembl . 10:00 11:00 1.00 COMPZ RPCO PULD P PU control wire from spool house & RU sheeve on rig floor. Plug in & test connections, seroice motor. 11:00 12:00 1.00 COMPZ RPCOti PULD P Clamp gauge control line and cable to motor & tandem seal assembl . 12:00 12:15 0.25 COMPZ RPCOb SFTY P PJSM to review RIH witf~ ESP com letion. 12:15 13:15 1.00 0 135 COMPZ RPCOh PULD P PU Assembly from Btm of motor/centralizer to zpup jt above discharge sub (135') Connect cap tube to ressure dischar e sub. 13:15 16:00 2.75 135 2,270 COMPZ RPCOh RCST P RIH with ESP 4-1/2" 12.6# L-80 IBTM SCC Tb . 16:00 20:00 4.00 2,270 2,270 COMPZ RPCOh OTHR T ESP cable kinked - Cable wedged between rollers in the spooling unit. Resulted in - 70' of damaged line. Centralift spliced cable & checked continuitv. ~ 06/14/2007 20:00 00:00 4.00 2,270 4,700 COMPZ RPCO RCST P Continue RIH with 4-1/2" 12.6# L-80 Tbg to 4700' MD as follows: 136 jts of 4-1 /2" 12.6# L-80 Tbg, Camco GLM w/ DV, 17 jts tbg '" S lice located 10' below ~t# 77 "" 06/15/2007 00:00 05:00 5.00 4,700 8,170 COMPZ RPCOh RCST P Continue RIH with 12.6# L-80 4-1/2" tbg: 50 jts of 12.6# L-80 4-1/2" tbg - GLM #1 with Shear Vlv - 67 jts of tbg. Ran a total of 262 jts of tbg - 151 Cannon Clamps - 15 SS Bands - 2 Flat Guard Clamps - 1 Motor Protector - 2 Pump protectors. Tested cable eve 1000 feet while RIH. 05:00 05:30 0.50 8,170 8,202 COMPZ RPCOh RCST P PU and MU Landing jt and Hanger - PU Wt 115k, SO Wt 52k. Landed with Btm of Centralizer @ 8201.76, XO screen intake @ 8139' GLM #1 @ 2112 and GLM #2 3883' MD. 05:30 09:00 3.50 8,202 8,202 COMPZ RPCOh OTHR P Splice cable and connect penetrator with 3 SS Bands - Check continui . 09:00 10:00 1.00 8,202 8,202 COMPZ RPCOh DHEQ P Land Tbg with 17k on hanger - Run in LDS - Test Upper & Lower seals to 5000 psi for 10 minutes, Good Test - LD Landin 't - Clear Floor. 10:00 10:15 0.25 COMPZ RPCOh SFTY P PJSM - Recognize hazards and procedures with ND BOP - Heavy loads and inch oints. 10:15 11:15 1.00 COMPZ RPCOb NUND P ND BOPE - Set back & Secure. 11:15 14:15 3.00 COMPZ RPCOh NUND P NU Tree - Test void with 5000 psi for 10 min - Continui test failed - W O O 14:15 15:30 1.25 COMPZ RPCOI~ NUND T ND Tree and NU BOP to troubleshoot electrical failure. 15:30 16:30 1.00 COMPZ RPCO PULD T RU Lubricator - Pull BPV - Set 2 way check - RD Lubricator. 1630 17:15 0.75 COMPZ WELCT BOPE T Fill stack with water - Test BOP Flange, Blinds, and choke line to 250 and 2500 si. 17:15 18:00 0.75 COMPZ RPCO PULD T RU Lubricator - pull 2 way check - Set BPV - RD Lubricator. 18:00 19:00 1.00 COMPZ RPCOh PULD T MU Landing jt - Back out LDS - Pull Tb Han er to floor. 19:00 21:30 2.50 COMPZ RPCOh OTHR T Centralift tested pigtale cable below hgr - Good test. Tested Penetrator - Test failed. Hanger scratched while PUH - Vetco Gray Rep dressing the scratches on the hrg and replacing seal rings. Centralift changed out penetrator with new. Continuity test passed. RIH with hanger and land with 17k. 21:30 22:15 0.75 COMPZ RPCO DHEQ T Run in LDS - Test Upper and Lower seals to 5000 psi for 10 minutes - Good Test. 22:15 23:00 0.75 ICOMPZ RPCO NUND T Pull landing jt - ND BOPE. • • ~ • ~.~ 1 J-120 "D" Lat Slotted and Blank Liner Detail well: >Phillips a.s" 11.6# L80 BTCM Date: .Alagka, ~n~-. Two Run System Rig: 1 J-120 L2 6/11/2007 Doyon 141 Supervisors : D. Gladden / N. Woods / S. Shultz DEPTH Num of Jts COMPLETE DESCRIPTION EQUIPMENT RUN ; , ~ aea~ _ OD(in) ominal Max OD(in) ctual ID(in) ctual LENGTH TOPS freseivect~ j~eserv~tl] [YesHVEdj ~reserved] [reserved] [reservedJ . _.: ]reserved] [reserved] [eeserved3 ~ . .. . ... .... .............. .. . .;. DIS'~ANGE f~r,~,R#CB' :.::::::: : :::: :::;: :.:.:;::::>::;::: .: __ _ 8451.22 4" DP eeded to Surtace =_> 8451.22 XO 4.5" XT39 x 3-1/2" IF 4.75 3.00 1.98 8451.22 Baker setting tool with pup jt(Does Not Stay In Hole) 3.50 4.76 2.59 6.61 8453.20 HR Liner Setting Sleeve w/ 10' TBR 5.5" 5.010 6.410 5.750 12.75 8459.81 Liner Pu Jt 5.5" 15.5# L80 5.5"H d 521 X 5.555 4.920 7.38 8472.56 Rece tacle Jt 5.5" 15.5# L80 5.5" Hd b X 5.530 5.700 4.890 41.82 8479.94 XO Sub 5.5"Hyd 521 X 4.5"Hyd 521 bXp 5.700 5.700 3.910 1.42 8521.76 4-1/2" H dril 52112.6 f, L-80 Pu 'oint 4.540 4.540 3.910 9.59 8523.18 22 ~ts 4-1/2" H dril 521 11.6 f L-80 Slotted Casin 4.750 4.000 901.56 8532.77 ;. ..:; > :~~:::: .;: ::: : :::. ; ;: :.;: . .... . <.;:.;:.;:.;:.; :.::.::.::.::.::.:::::;:;:.;;;::;:;;;:;:.;:. ~::., . .:. .;:. Xb:: . ;:.. . . ; ;: : ~u~.4 .~.. .H d.5$~1. 5. :. . . ~. ~.. ... . ~'~~~A:.;::>::>::::>::::>:::<:>:::««««::«««<>::::: <::«<:::: Y ........................~........................................................... ;;;;:;;;:.;;:;;;;:: ««<:::«:«::<: .................. .;:.;;:.;..:..:....;;:.;: <:>:<:~F:>74t1::::>:::: ..................... .;:;.;...;.....: :.;;: :::>:~E ~Q;:<: .................. :.;:.;;;:.;:.:<.;:<.;;:.;:.;:._;. , ..... :::<:>:;:::>:<:::>::::;::::: . 1, <: ;86: ........::..................... 3 9434.3 75 Jts 4-1/2" BTC 11.6 f L-80 Slotted Cs w/ Tor Rin s 4.740 4.000 3172.69 9436.19 8o Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 4.740 4.000 3379.14 12608.88 Shoe Joint - 4 1/2" Jt 11.6# L-80 BTCM Csg 4.740 4.000 43.32 15988.02 4/12 " shoe 1.66 16031.34 Bottom OF SHOE __> 16033.00 16033.00 16033.00 "D" LAT HR setting sleeve Top ( In Open Hole) 8459.81' MD 16033.00 XO No Go sub 8521.76' MD 16033.00 16033.00 16033.00 "D" sand window - Top 8,239' / Bttm 8,252' 77 deg 16033.00 16033.00 16033.00 TD 6-3/4" hole 16033' MD / 3750' TVD 16033.00 4-1/2" Shoe 16,033' MD / 3,750' ND / 88.64 Deg. 16033.00 16033.00 Run 154 hydroforms(80590- 3 rib) 1 Hydroform per jt. 16033.00 on joints #2 thru Jts # 155. No stops we1'e ran. 16033.00 Run torque rings in the 75 jts of the BTC-M liner. 16033.00 Jts # 81 thru Jt# 155 sloted BTCM w/ TR = 3172.69' 16033.00 16033.00 16033.00 16033.00 155 Its BTC = 6561.83', and 22 its Hvd 521 Slotted = 901.56'. TOTAL Slotts 745 3.39' 25" wide x 2.5" lon x 32 slo/ft. w/ 32 2.5" lon x.125" 4 U Wt ???k tial ad'acent rows,3" Centers sta ered 18de . 3' non-slotted ends. Dn Wt ??k ~ liner w/o tor ue rings to a. 4000 ft-Ibs, w! tor ue rin s to 8100 ft-Ibs, H d 521 to 4700 ft-!bs Block Wt 35k I-Seal thread compound on all connections. All drifted w/ 3.875" rabbit. • ~ 13-JuI-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-120 L2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 12,643.14' MD Window / Kickoff Survey 12,725.00' MD (if applicable) Projected Survey: 16,033.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ ~ ~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~ ~ _ ~ ~7 • ~ 13-Ju1-07 ACC: CC Libr=:ri~r 33:~ '.~1,~. ~~ ~ A~~~~ . ~ ~~~ 1:~;~ Anc"o, ~: ~:r:. At~~ , ~ 1 F=: Di:, . ~~ c:` :,~, r,~ey D~t~; ~ r',' ~II 1J-120 L2 PB1 De< <:~., ~ Si~, ~ =m~ Enc ;: ~, ~ o~~~~~~ ~ ~vi~~~~ ~~~,., *.PTT an ' x." ~~~~ files. _ ~:-on _ :,,~ 8,~ ' C~.. _ ~ MD ~~~dc ._ ~ ~ , ;ot ,_ i .~~y 8,~: ~. _ _ ~ MD (if applicable) -~~ ec: ~~ ~ ~.ve~ : 13,2 2.' :" MD P~ 1:~- r+C~:'~~; ; E[:: ;L ~~~CE~P ; ~`. :: '_NDING ~N EMAIL TO Tin:ct ,~...~'~Ile.~ '~ ";~L'~~UF'rO~'.CC^' Or `~GNING 1~ND RE i U~~`d;NG r-. :~~PY '~~i= T' ~;c TRAI~ ~~""~~~, ~i AL LETTER TO THE AT i" E P~~ ~~ ''? ;~,; ~;~; ~ S~~F:rr~r-"` ~ ~ ~t, ~ SE ~~~~~c~~~ A`F . -'~~ .c~ - ~ 69t ~ ~1 : ~ E~' , ~. An :;~or~~ =s~, :-~~ _~:~18 ~ D . ~ ~ ~'CJ < ' . , _ ~' <, ~~ ~ ~- ~;,~ ~ PI~ ~ .._ ,~~ , ;r; ~. ~~~ ; .~-~ ~~ ~ ,~, ; _. ,~~~. ~ ~ ..~stions cr concerns. Rea~a~c : ~r i r~r ~~, ~~~ ~ ~ ~~ , ; i S~~ ~, ~~ ~ ~a~ _ Att:~_' ~„e~~,'f a,C» ~ 0 `~? ~ ~ ~ ~ ~~ ~~~ ~ ~ ~ ~ : ~,.~ ~ ~, M ..:~ _.w.~ ~ ~ ,._.~? ~ '~..~ ~~ ~ ALASSA OIL A11TD G~S C011TSERQ~'1`I011T COl-IIrII5SIOI~T Randy Thomas Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 SARAH PALIN, GOVERNOR 333 W. 7thAVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-120L2 ConocoPhillips Alaska, Inc. Permit No: 207-047 Surface Location: 1875' FSL, 2357' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 109' FSL, 1995' FEL, SEC. 24, T11N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 1J-120, Permit No. 207- 045, API 50-029-23352-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Chairman DATED this ~ day of April, 2007 ~ cc: Department of Fish & Game, Habitat Section w/ o encl. Department of Environmental Conservation w/ o encl. ~ STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~l~ PERMIT TO DRILL 20 AAC 25.005 ~~~~~v~a~ M~~ 3 0 2007 ~i~sk~, ~i; & G~s Cans. Commissiart Ar~charage 1 a. Type of Work: 1 b. Current Well Class: Exploratory ~ Development Oil Q/ , 1 c. Specify if well is proposed for: Drill Q/ ~ Re-drill ^ Stratigraphic Test ^ Service ^ Development Gas ~ Coalbed Methane ^ Gas Hydrates ^ Re-entry ^ Multiple Zone^ Single Zone ~ Shale Gas ^ 2. Operator Name: 5. Bond: ~ Blanket Single Well 11. Well Name and Number: ConocoPhillipsAlaska, Inc. Bond No. 59-52-180 ' 1J-120L2 • 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 16050' ND: 3737' ~ Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 1875' FSL, 2357' FEL, Sec. 35, T11N, R10E, UM ~ ADL 25661, 25650 ~ West Sak Oil Pool • Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2313' FNL, 1854' FEL, Sec. 36, T11N, R10E, UM ALK 471, 468 5/11/2007 Total Depth: 9. Acres in Property: 14. Distance to 109' FSL, 1995' FEL, Sec. 24, T11 N, R10E, UM ' 2560 Nearest Property: < 1 mile 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation j~ ~/j~,sL ' 15. Distance to Nearest " ,Z.o J SurFace: x- 558854 • y- 5945688 Zone- 4 (Height above GL): ZH' RKB feet ~Nell within Pool: 1 D-141 L1 , 32s' ~ 16. Deviated wells: Kickoff depth: 8341' ft. 17. Maximum Anticipated Pressures in psig (see zo fwC 25.oa5) Maximum Hole Angle: g4° de9 Downhole: 1756 psig • SurFace: 1345 psig ' 18. Casing Program if ti S Setting Depth Quantiry of Cement Size iCa ons peC Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD 7VD MD ND (including stage data) 42" 20"x34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete 13.5" 10.75" 45.5# L-80 BTC 4100' 28' 28' 4100' 2472' 630 sx AS Lite, 180 sx DeepCRETE 9.875" 7.625" 29.7# L-80 BTCM 10092' 28' 28' 10092' 3910' 520 sx DeepCrete 6.75" 4.5" 11.6# L-80 BTC 7709' 8341' 3626' 16050' 3737' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing length Size Cement Volume MD TVD ConductodStructural Surface Intermediate Production Liner Pertoration 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 Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. ContaCt Dennis Haitwig @ 265-6862 Printed Name Randy Thomas Titie Drilling Team Leader Signature Y ~ ~.,~•` \'~;;~~ ~ Phone Z, (_, ~' C;~' ~t, Date ~ / ~ ~~ /'~l ~ n All Drak ' Commission Use Only Permit to Drill API Number: Permit Approval See cover letter ' / Number: ~ / ~ ~y ~ 50- ('~ 2q ~ Z. ~ ~ j Z~~' Date: ~ . . ~ for other requirements Conditions of apprOV81 : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas ydrates, or gas contained in shales: ~ Samples req'd: Yes ^ No LJ Mud log req'd: Yes ^ No []~ Other. ~Q~Q ~~ ~~~.~5-~-- H2S measures: Yes ~ Di ional svy req'd: Yes []' No ^ APPROVED BY THE COMMISSION ~ ~ , COMMISSIONER DATE: ~ O Form 10-401 Revised 12/2005 ~ R{~~~~~ - v v Submit in Duplicate ~ ~ ( e~~~7,.,~~-f ./.SD ~/• L •a7 ~ ~tion for Permit to Drill, Well 1 J-120 Revision No.O Saved: 28-Mar-07 Permit It - West Sak Well #1J-120 L2 (D-Sand) ~~~~ .., ;, Application for Permit to Drill Document *~~ ~ ~~m -:e w~~~ va~u4 Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (fl ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 Lateral Mud Program (MI VersaPro Mineral Oil 8ase) ........................................................................... 4 9. Abnormally Pressured Formation Information ..................................................... 4 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 4 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 1J-120L2 PERMIT IT Page 1 of 6 Printed: 28-Mar-07 E S ~ "s ~ ~ ~ ~ ~ ~ ~ ~ ~ . ~ ~ation for Permit to Drill, Well 1J-120 Revision No.O Saved: 28-Mar-07 13. Proposed Drilling Program ..................................................................................... 5 Reguirements 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 (fl Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a su~x to the name designated for the well by the operator and to the number assigned to the we!l 6y the commission. The well for which this Application is submitted will be designated as 1J-120 L2. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Dril! must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordrnates of the proposed location of the well at the surface, at the top of each objective formation, and at toEal depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National 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 1,875' FSL, 2 357' FEL, Section 35, T11N, R10E ' ASP Zone 4 NAD 27 Coordinates RKB Elevation 109.0' AMSL . Northings: 5,945,688 Eastings: 558,854 Pad Elevation 81.0' AMSL Location at Top of Productive Interval West Sak "D" Sand 2313' FNL, 1,854' FEL, Section 36, T11N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th RKB: 8,341 Northings: 5,946,827 Eastings: 564,626 Total Vertical De th RKB: 3 626 Total Vertical De th, SS: 3,517 Location at Total De th 109' FSL 1,995' FEL, Section 24, T11N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th RKB: 16 050 ~ Northings: 5,954,527 Eastings: 564,418 Total Vertical De th, RKB: 3,737 • Total Vertical De th, SS: 3,628 and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form i0-401) must 1J-120L2 PERMIT IT Page 2 of 6 Printed: 28-Mar-07 ~E~~G~~AL ~ ~tion for Permit to Drill, Well 1J-120 Revision No.O Saved: 28-Mar-07 (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnrshed a copy of the application by certified mail; or (8) state tl~at the applicanE is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-120 L2. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be 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 vary from 0.44 to 0.47 psi/ft, or • 8.5 to 9.0 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from Nearby West Sak wells The maximum potential surface pressure (MPSP) based on the above maximum press re gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak sand formation is 1,345 psi calculated thusly: ,~j~ MPSP =(3,737 ND)(0.47 - 0.11 psi/ft) y•y.a? = 1,345 psi ~ (8) data on potential gas zones The well bore is not expected to penetrate any gas zones. , and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: 1J-120 L2 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 following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(~; The parent wellbore,l]-120 will be completed with 7-5/8" intermediate casing landed at the top of the West Sak A2 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. 1J-120L2 PERMIT IT Page 3 of 6 Printed: 28-Mar-07 ~' ~' ~ ~' ~ ~A L ~ ~tion for Permit to Drill, Well 1 J-120 Revision No.O Saved: 28-Mar-07 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanred by each of the foUowing items, except for an item already on file with the commission and identifred in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program Hole Top Btm CsglTbg Size Weigh Length MD/TVD MD/ND OD (in) (in) t(Ib/ft) Grade Connection ft (ft (ft) Cement Program 4-1/2 6-3/4" A Sand 11.6 L-80 BTC 7,379 8.941 J 16,320 / 3,947 slotted- no cement slotted ~ateral (i]-120) 3,737 4-1/2 6-3/4" B Sand 11.6 L-80 BTC 7 216 8,841 / 16,057 / 3,803 Siotted- no cement SIO Lateral (1]-120 Li) 4-1/2 6-3/4" D Sand 11. - 0 BTC 7,709 8,341 / 16,050 / 3,737 Slotted- no cement slotted ~ateral (i]-12o ~2) 3,626 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following 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 used during operations on 1J-120 L2. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro Mineral Oil Base) A/B/D sand laterals Value Density (ppg) 8•4 or as needed Plastic Viscostiy 12 - 19 (Ib/100 sf) Yield Point ~ $ _ 28 (cP Oil / Water Ratio 80 / 20 Electrical 650-900 Stabilit 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. 9. Abnormally Pressured Formation lnformation Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: 1J-120L2 PERMIT IT Page 4 of 6 Printed: 28-Mar-07 ~ ~ ~ ,~,,~,? ~ ~ ~ ~ 1.. ~ ~tion for Permit to Drill, Well 1 J-120 Revision No.O Saved: 28-Mar-07 (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(~; 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 already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reFlection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (Ii) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an ana/ysis of seabed conditions as required by 20 AAC 25. 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 Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (i2) 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 Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the 1]-120 & 1J-120 L1 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of +/- 8,341' MD / 3,6Z6' 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 +J- 16,050' MD / 3,737' ND, 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. 10. POOH, laying down drill pipe as required. il. PU ESP completion with with backup gaslift as required and RIH to depth. Land tubing. Set BPV. 12. Nipple down BOPE, nipple up tree and test. Pull BPV. 13. Freeze protect well with diesel. 1J-120L2 PERMIT IT Page 5 of 6 Printed: 28-Mar-07 ~~I~1l~~L ~ ~tion for Permit to Drill, Well 1J-120 Revision No.O Saved: 28-Mar-07 14. Set BPV and move rig off. 15. Rig up wire line unit. Pull BPV. 16. Circulate out well with diesel through the ESP 17. Set gas lift valves in mandrels. Operate well on gas lift until ESP facilities are ready. 18. Replace gas lift valves with blank dummy valves. 19. Place well on production with ESP. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; 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 iJ 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-120L2 PERMIT IT Page 6 of 6 Printed: 28-Mar-07 ~~~G1~~L ~ ~ ~ono~aPh i I I i ps ~a~k~ ~ Plan: 1 J-120 L2 (wp09) Sperry Drilling Services Proposal Report - Geographic 23 March, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-120 - Slot 1J-120 Plan 1J-120 L2 Local Coordinate Origin: Centered on Well Plan 1J-120 - Slot 1J-120 Viewing Datum: oyon 141 Plan RKB @ 109.OOft (Doyon 141 (28+g1)) TVDs to System: N . North Reference: True ~ Unit System: API - US Survey Feet ~L~~~~ ~~ 8perry Orilling ~i~rvic~rs ~~~~~f~AL ~ ~ FlALLlBURTON Project: KuparukRiverUni L ~~~~AUS:r~,iJ-izo Site: Kuparuk iJ Pad Gowdlerel: BI00 Sperry Or7~linq S~rvio~s Well: Plan 1J-120 .w-s +FJ-W Non n~ ~w~ ~ewne ~~+nw~ si~~ Welibore: Plan 1J-120 L2 01"~ o0o svas~s soz >i8853i0 70°IS'43.975N iav°arzzziw iJ-izo Plan: 1 J-120 L2 (wp09) FORML^,TION TOP DEThILS :~ NDPath TVOSS MDPath Forma`ion ~ 1 1506.5d 1397.58 165470 Pfros~ 2 1658.11 1549.11 1897.55 T3 t979.92 1870.92 2727.69 K15 4 2245.96 2736.96 ~470.05 Casinq Pt °588.E9 2879.89 5879.06 U9nu C 5'~0 3305.52 3796.52 7058.39 Ugnu B \' ~/ 5782.02 3273.02 7355.88 Ugnu A ;;477.34 3368.34 7734.15 K 13 , '_d27 57 ;518 S7 8349 E9 W Sak D 7000 ~ ~~~~.~/ + ~~ ~J 7500 CASING DETAILS No MD TVD TVDss Namc Sic l JIOO.W 2i7I.71 2762.71 103/1" 10-3/4 2 R3JI.U2 3625.)7 3516.97 75/g"TOW 7-5/8 3 IGW9.R6 3737.00 lfi2%I)0 11/2" 1-1/2 ~ L2: 7 5/8" TOW ~ 8341' MD, 3626' ND: 2313' FNL, 1854' FEL - Sec36-Ti iN-R10E ~ L2: BHL @ 16050' MD, 3737' ND~ 109' FSL, 1995' FEL - Sec24-T11N-R10E o '„~ ________________ __________________ ______________________'_____'_______ ________________ 0 L - _ _~ _ _ _ _ _ _ ~ _~_ / _ _ _ _ _ _ _ _ _~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _1`r _ _ _ _ _ _ - - _ _ _ _ _ - - ~ _ _ a LL - _ _ 0. _ _ _ _O _ _ - p _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ O_ _- W rD O~~ ~__-- ___O_~_~_-- _~____~__-_`___--~----_-__-O____ _p__--e-__T_______________ 0 ~;:J~ -___k- _-_-0--_-~_-__d____~__~_.A___-Jf>.___-N.____~ ~ ---_---~ ! -o__p_-~-__-1_______________ ` ~ ~ ~ _ O -N- ~ N \ ~ _____ - ____ . ____ ~ ______ ______c__I_ •- _~_z-____`_'iJ-120L2(wp09) _____ ~r W Sak D`~ N ` w ~, d o i ~ 4JJ0 ~ ~ o~~ o N ~ i `~ ~ ~ ~ ~ 1~ 1, 4500 ~ ~ 1 ~ ~ 1J-120 MB D CP7 (0321/0~ ~ 1J-720 MB D CP3 (03/21/07) 1J-120 MB_D_CPS (03/21/0~ ~~ 1J-120 MB_D CP7 (03,'21/07) ~ 1J-120 MB D Toe (wp09 1J-120 MB_D, Heel (0321/0~ iJ-120 MB_D_CP2 (0321/On iJ-120 MB_D CP4 (03'21/0~ 1J-120 MB_D1CP6 (0321fOn 1J-720 MB_D_CPB (0321/0 500 1000 1500 2000 2500 3000 3500 4000 C5C0 SOJO `500 .,G00 GFGO 7000 7500 B000 8500 9000 9500 16000 Vertical Sedion at 0.00° (1000 Win) ~____ ~_~~.,y QRIG{l~AL • ~ HALL IBLJRTON Project: KuparukRiverUnit REFERENCEINFORMATION WEI.LDETADS: Plmill-120 Site: KuparuklJPad CoorEiiwte(N/E)Reference WeIIPIan1J~120-Sbt71120,TrueNOM GrowdLcwel: HI00 SPm'~'Y ~1«g S~~a~ Well: Plan 1 J-120 Verticai (ivD) Re/erenrw'. Doyon tat PWn RKB @ tO9.00R (DOyun 141 (28+91)) +N/-S +F/-W Nonhing Faaing Laonude Longilmle Slot Wellbore:Plan1J-120L2 MeasureC Depth Refemrice: Doyan 141 PWn RKB ~ 109.0011(~oynn 141128~811) cam~iaro~nnamoaw~~m~marvan„< 000 (1.00 59A5688.02 SS88i3.i0 ~0°IS'43.97iN 179°312~11 W I1-120 Plan: 1J-120 L2 (wp09) ~~WO 9sao i i-i ~a i~~„ i,m~, ~ YUW 1 41/2" ~ 1!-I'_n!/Ii D Tcx~ iwi~lw - _ _ _ _ . - - - - - - - - - - ~: BHL ~ 16050' MD, 3737' ND: '109' FSL, t995 FEl - Sec24-T11N-R10E ' - - 7737 8>W I1-120MF3 D CY8l0i/'Ipl] _"_'_ _ 8000 u-i.o~ncr~co_zrziu~ ----- ~soo ~ u-rzon,u3 c~~ovziro~ ------ n oou _ _ 6>W ILI?UMI3UCPilfliRllll" '___ 6(I(N) I).I'_iiMF3 D CP41Ui/'_I/i~: '_ _ _ __ 531~ 0 5000 `~-' li(p + s r 1000 I~_IJiAllt I) CP:ii~;~~~ru' "_____ _ _ ~ ;5(q s o N 3000 CASING DETAILS No MD TVD TVDSS Name Sirc I 11U(1.~0 2J71.71 2?62.71 103/i" 10-3/1 ' ' ii_i_~~MItUC~3iui,^_I/~~' _______ ~`W ~ 2 8311.U2 3G25.97 3i1G97 75/y" pW 7.5/R 3 IGOIY.BG 373ZU0 3628.W i 1/2" 4-U2 -- 2IX10 ISpp I!.I'_n!.q3 p CPl (1~321/U7 ' _ _' _ _ _ _ - 1~ IJ-I'_(i4Ili U Ilcelllli/?In~' _ _ _ _ _ _T _ _ _ _ _ _' _' _ _ _ _ L2:7i/8..'f<)W ~d. %ial'MI).il2G'IVD:2313'FNL.1854'FEL-Sec36T11N-RII~L 5(10 ~rPo T 0 $ - $ ~ M AzimNhs to True North MagneUC North~. 23.77° 103/4" 3 5 1 1~,o Strength: 76110n T -5~ ~ DiP Angle'. 80.80° ~ -1W0 7 Model'. BGGM2006 -iwo -250U -20UU -ISpp .~p()p .Spp 0 500 IWO ISUO 2000 25(q 3p(K1 3~00 J000 J500 5000 5500 6000 6500 7W0 7500 SUUO BSW /(IW 45(p IOOUO IOSOp ~~0~0 11500 12(N)0 IZS00 Ii0U0 Ii500 ISINHI ~ West(-)/East(+) (1750 ft/in) ConocoPhiltips ~ C~~~~I~~l~ ~ ~ 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 3/23/2007 3:31:52PM Page 2 of 8 QR~GII~AL COMPASS 2003.11 Build 48 ~~~~~I~~~ps Halliburton Company ~-l~4t,,.~..F1E3U~T1D~ ~~ Compass Proposal Report - Geographic gper~-y Or~ilNng ~i~vic~s ~ ~p Plan'~]J 120 Slot 1J-120 ~ ~ ~ ~ ~t -~. ~°..-- .. ~... ,r~em iua~~u ~+~v '~a ' A `...<..i ~!.~u~ _ . .............~~a~ma~p~~rt~. Well Position +N/-S 0.00 ft Northing: 5,945,688.02 ft' Latitude: 70° 15' 43.975" N +E/-W 0.00 ft Easting: 558,853.50 ft• Longitude: 149° 31' 27.210" W Position Uncertainty 0.00 ft Welihead Elevation: ft Ground Level: 81.OOft . ~ ~ ~ ~ ~ =- ~-~ ~ i!~ - ~,a~~~u~,~ ~~~a :~;~,~~;~ ~ i~ _ ~~ ,~,~~~ ~~ ~.ro~,~~u °~ == _ ~ ' ~,, ~ , i . - _ _ a „ ~~ -*~r.~ ~;; y'~i n ~~ : ~~~~ ~ ~~ ,' F i ~ ~~~' ~ ai~~~ ' a ~;~~ ~ : ~ii~ _ ~ ~I~ ~ Q __ ~ ~~i~ _ __ ~,,,;' - - ~i i i~ ii i ~ ~i i ' '_ W' ~ _ _ - y~ u _ ~I - ~ ' i ~ 8,341.00 a 75.99 %~^i .J 6.25 3,625.97 i ~ri~~ i 3,516.97 ..__ _- 1,093.69 5,781.67 ~~ 0.00 - 0.00 , ! i 0.00 r 0.00 8,353.00 77.90 6.25 3,628.68 3,519.68 1,105.31 5,782.95 15.90 15.90 0.00 0.00 8,383.00 77.90 6.25 3,634.97 3,525.97 1,134.47 5,786.14 0.00 0.00 0.00 0.00 8,676.58 91.66 357.75 3,661.67 3,552.67 1,425.69 5,796.07 5.50 4.69 -2.90 -32.12 8,913.09 91.66 357.75 3,654.82 3,545.82 1,661.92 5,786.78 0.00 0.00 0.00 0.00 8,970.37 89.57 358.69 3,654.21 3,545.21 1,719.17 5,785.00 4.00 -3.65 1.65 155.70 9,795.37 89.57 358.69 3,660.40 3,551.40 2,543.93 5,766.14 0.00 0.00 0.00 0.00 10,052.34 88.29 358.69 3,665.21 3,556.21 2,800.78 5,760.27 0.50 -0.50 0.00 -179.96 11,395.39 88.29 358.69 3,705.40 3,596.40 4,142.88 5,729.55 0.00 0.00 0.00 0.00 11,447.42 89.33 358.67 3,706.48 3,597.48 4,194.88 5,728.36 2.00 2.00 -0.03 -0.85 13,394.65 89.33 358.67 3,729.40 3,620.40 6,141.45 5,683.29 0.00 0.00 0.00 0.00 13,509.31 93.91 358.67 3,726.16 3,617.16 6,256.00 5,680.63 4.00 4.00 0.00 -0.06 13,585.44 93.91 358.67 3,720.97 3,611.97 6,331.94 5,678.87 0.00 0.00 0.00 0.00 13,694.99 89.53 358.69 3,717.68 3,608.68 6,441.38 5,676.34 4.00 -4.00 0.02 179.72 14,294.99 89.53 358.69 3,722.60 3,613.60 7,041.21 5,662.63 0.00 0.00 0.00 0.00 14,301.52 89.46 358.69 3,722.66 3,613.66 7,047.73 5,662.48 1.00 -1.00 0.00 -179.81 14,894.84 89.46 358.69 3,728.20 3,619.20 7,640.87 5,648.91 0.00 0.00 0.00 0.00 14,909.79 89.32 358.67 3,728.36 3,619.36 7,655.82 5,648.57 1.00 -0.99 -0.16 -171.01 15,592.78 89.32 358.67 3,736.50 3,627.50 8,338.57 5,632.67 0.00 0.00 0.00 0.00 15,794.43 90.11 0.52 3,737.50 3,628.50 8,540.21 5,631.24 1.00 0.39 0.92 66.76 16,049.87 90.11 0.52 3,737.00 3,628.00 8,795.64 5,633.55 0.00 0.00 0.00 0.00 3/23/2007 3:31:52PM Page 3 of 8 COMPASS 2003.11 Build 48 4,~J`Ei~~~~~~~ '*~' Halliburton Company HAt..~1 l.~~tTC`~ C~~~'d~~~~~~~ Compass Proposal Report - Geographic ,q~~ Sprerry t'~rilUng 8e~rvices ~ Ct~ru~coP~titlips Alaska Halliburton Company Compass Proposal Report - Geographic ~ ~"~~1-~.~..~~~~T~~ Sperry C]~rilttng Sarviass ~ y~~~,f~ _ --- - _ ° ~" ~ 1J-120 L2 ~,,, '~09) ~~ ~z~ ~~~.d~ ~ ~ ~ ~ ~ ~ ' ~ ~ -- ~, _ r -- ~'~ _ ,_ - ~ ' ~, ~ _ ~ „ ~ < , a ,~ 9,. ~ _~„''~~~~~c ''',' t r,,,,,, - =v _ ~' !,' ,' ~ ~ ~~ ,,, = ~ - , ; , ~ j ~' ~'' ~ , ~ ~ ~ _ ~~~~~ ~a'' ~ ,~ - -~ ,~~ ~ ~ ~~ ,~ ,,1; 8,341.00 75.99 6.25 3,625.97 3516.97 1,093.69 5,781.67 5,946,826.76 564,625.89 0.00 1,093.69 L2: 7 518" TOW @ 8 341' MD, 3626' ND: 2313' FNL, 1854' FEL - Sec36-T11N-R10E - 7 S/8" TOW 8,349.69 77.37 6.25 3,627.97 3518.97 1,102.10 5,782.60 5,946,835.17 564,626.75 15.90 1,102.10 W Sak D 8,353.00 77.90 6.25 3,628.68 3519.68 1,105.31 5,782.95 5,946,838.39 564,627.08 15.90 1,105.31 8,383.00 77.90 6.25 3,634.97 3525.97 1,134.47 5,786.14 5,946,867.57 564,630.04 0.00 1,134.47 8,400.00 78.69 5.75 3,638.42 3529.42 1,151.03 5,787.88 5,946,884.13 564,631.65 5.49 1,151.03 8,414.09 79.35 5.33 3,641.10 3532.10 1,164.79 5,789.22 5,946,897.91 564,632.88 5.51 1,164.79 1J-120 MB_D_Heel (03121I07j 8,500.00 83.37 2.82 3,654.01 3545.01 1,249.49 5,795.24 5,946,982.64 564,638.24 5.50 1,249.49 8,503.44 83.53 2.71 3,654.40 3545.40 1,252.90 5,795.40 5,946,986.05 564,638.37 5.55 1,252.90 1J-120 MB_D_CP1 ( 03/21/07) 8,600.00 88.06 359.94 3,661.48 3552.48 1,349.14 5,797.62 5,947,082.30 564,639.84 5.50 1,349.14 8,676.58 91.66 357.75 3,661.67 3552.67 1,425.69 5,796.07 5,947,158.82 564,637.70 5.50 1,425.69 8,700.00 91.66 357.75 3,660.99 3551.99 1,449.08 5,795.15 5,947,182.21 564,636.60 0.00 1,449.08 8,800.00 91.66 357.75 3,658.10 3549.10 1,548.96 5,791.23 5,947,282.05 564,631.89 0.00 1,548.96 8,900.00 91.66 357.75 3,655.20 3546.20 1,648.84 5,787.30 5,947,381.88 564,627.18 0.00 1,648.84 8,913.09 91.66 357.75 3,654.82 3545.82 1,661.92 5,786.78 5,947,394.95 564,626.56 0.00 1,661.92 8,970.37 89.57 358.69 3,654.21 3545.21 1,719.17 5,785.00 5,947,452.18 564,624.33 4.00 1,719.17 9,000.00 89.57 358.69 3,654.43 3545.43 1,748.78 5,784.32 5,947,481.79 564,623.43 0.00 1,748.78 9,100.00 89.57 358.69 3,655.18 3546.18 1,848.76 5,782.04 5,947,581.73 564,620.36 0.00 1,848.76 9,200.00 89.57 358.69 3,655.93 3546.93 1,948.73 5,779.75 5,947,681.67 564,617.29 0.00 1,948.73 9,300.00 89.57 358.69 3,656.68 3547.68 2,048.70 5,777.47 5,947,781.61 564,614.22 0.00 2,048.70 9,400.00 89.57 358.69 3,657.43 3548.43 2,148.67 5,775.18 5,947,881.55 564,611.16 0.00 2,148.67 9,500.00 89.57 358.69 3,658.18 3549.18 2,248.64 5,772.89 5,947,981.49 564,608.09 0.00 2,248.64 9,600.00 89.57 358.69 3,658.93 3549.93 2,348.61 5,770.61 5,948,081.43 564,605.02 0.00 2,348.61 9,700.00 89.57 358.69 3,659.68 3550.68 2,448.58 5,768.32 5,948,181.37 564,601.96 0.00 2,448.58 9,795.37 89.57 358.69 3,660.40 3551.40 2,543.93 5,766.14 5,948,276.69 564,599.03 0.00 2,543.93 1J-124 MB D_CP2 {63/21/O7) 9,800.00 89.55 358.69 3,660.44 3551.44 2,548.55 5,766.04 5,948,281.31 564,598.89 0.50 2,548.55 9,900.00 89.05 358.69 3,661.66 3552.66 2,648.52 5,763.75 5,948,381.25 564,595.82 0.50 2,648.52 10,000.00 88.55 358.69 3,663.76 3554.76 2,748.47 5,761.46 5,948,481.17 564,592.75 0.50 2,748.47 10,052.34 88.29 358.69 3,665.21 3556.21 2,800.78 5,760.27 5,948,533.46 564,591.15 0.50 2,800.78 10,100.00 88.29 358.69 3,666.64 3557.64 2,848.40 5,759.18 5,948,581.07 564,589.69 0.00 2,848.40 10,200.00 88.29 358.69 3,669.63 3560.63 2,948.33 5,756.89 5,948,680.97 564,586.62 0.00 2,948.33 10,300.00 88.29 358.69 3,672.62 3563.62 3,048.26 5,754.60 5,948,780.87 564,583.55 0.00 3,048.26 10,400.00 88.29 358.69 3,675.61 3566.61 3,148.19 5,752.32 5,948,880.77 564,580.48 0.00 3,148.19 10,500.00 88.29 358.69 3,678.61 3569.61 3,248.12 5,750.03 5,948,980.67 564,577.42 0.00 3,248.12 10,600.00 88.29 358.69 3,681.60 3572.60 3,348.05 5,747.74 5,949,080.57 564,574.35 0.00 3,348.05 10,700.00 88.29 358.69 3,684.59 3575.59 3,447.98 5,745.46 5,949,180.46 564,571.28 0.00 3,447.98 10,800.00 88.29 358.69 3,687.58 3578.58 3,547.91 5,743.17 5,949,280.36 564,568.21 0.00 3,547.91 10,900.00 88.29 358.69 3,690.58 3581.58 3,647.84 5,740.88 5,949,380.26 564,565.15 0.00 3,647.84 11,000.00 88.29 358.69 3,693.57 3584.57 3,747.76 5,738.59 5,949,480.16 564,562.08 0.00 3,747.76 11,100.00 88.29 358.69 3,696.56 3587.56 3,847.69 5,736.31 5,949,580.06 564,559.01 0.00 3,847.69 11,200.00 88.29 358.69 3,699.55 3590.55 3,947.62 5,734.02 5,949,679.96 564,555.94 0.00 3,947.62 11,300.00 88.29 358.69 3,702.55 3593.55 4,047.55 5,731.73 5,949,779.85 564,552.88 0.00 4,047.55 3/23/2007 3:31:52PM Page 4 of 8 COMPASS 2003.11 Build 48 ~~~~~~~~ ~ Halliburton Company Compass Proposal Report - Geographic ~ ~"'~~~..~.~~~~~~~ Cc~rtaco~ti[lips FUaska Sp~rry Drilfiing Bervice~ _ _,~- s~ .~ ~aiNiP~f~I - 9 '~~.IW ~ w 6 i i ~~ 1 J 120~ L2 09 ~ _ _ _ ^ ~ '~~ - ~ -- _ _- - ~~~ ti ' ~~ilr~' ~~ ° - - ~~~ ~ ~ - ~ _ _ _ _ < ;;,, ; ' ~ , _ _ ~ ~ I~ r~~ ~ ' - ~ - _ ~ ' ° - = - ~r _ " ~ - _ . l ~ - _-- ~ . ~ . ~ ~ ' ~ ~~~ ~ ~ ~~' ~ ~ ~ - ~~"; i l~ _~~ ` , _ ti~~ ~~ ~ ~ ~ ~ ~ ,~~ ~~~~ ~ r~~ s_. ~-- ~ ~ , ~ _, 11,395.39 88.29 358.69 3,705.40 3596.40 4,142.88 5,729.55 5,949,875.15 564,549.95 0.00 4,142.88 1J-120 MB_D CP3 (03/21/07) 11,400.00 88.38 358.69 3,705.53 3596.53 4,147.48 5,729.45 5,949,879.75 564,549.81 1.98 4,147.48 11,447.42 89.33 358.67 3,706.48 3597.48 4,194.88 5,728.36 5,949,927.14 564,548.35 2.00 4,194.88 11,500.00 89.33 358.67 3,707.10 3598.10 4,247.44 5,727.14 5,949,979.68 564,546.72 0.00 4,247.44 11,600.00 89.33 358.67 3,708.28 3599.28 4,347.41 5,724.82 5,950,079.62 564,543.62 0.00 4,347.41 11,700.00 89.33 358.67 3,709.46 3600.46 4,447.37 5,722.51 5,950,179.55 564,540.53 0.00 4,447.37 11,800.00 89.33 358.67 3,710.63 3601.63 4,547.34 5,720.20 5,950,279.49 564,537.43 0.00 4,547.34 11,900.00 89.33 358.67 3,711.81 3602.81 4,647.31 5,717.88 5,950,379.42 564,534.34 0.00 4,647.31 12,000.00 89.33 358.67 3,712.99 3603.99 4,747.27 5,715.57 5,950,479.36 564,531.24 0.00 4,747.27 12,100.00 89.33 358.67 3,714.16 3605.16 4,847.24 5,713.25 5,950,579.30 564,528.15 0.00 4,847.24 12,200.00 89.33 358.67 3,715.34 3606.34 4,947.20 5,710.94 5,950,679.23 564,525.05 0.00 4,947.20 12,264.48 89.33 358.67 3,716.10 3607.10 5,011.66 5,709.44 5,950,743.67 564,523.05 0.00 5,011.66 1J-120 MB_D_CP5 (03/21107) 12,300.00 89.33 358.67 3,716.52 3607.52 5,047.17 5,708.62 5,950,779.17 564,521.95 0.00 5,047.17 12,400.00 89.33 358.67 3,717.69 3608.69 5,147.14 5,706.31 5,950,879.10 564,518.86 0.00 5,147.14 12,500.00 89.33 358.67 3,718.87 3609.87 5,247.10 5,703.99 5,950,979.04 564,515.76 0.00 5,247.10 12,600.00 89.33 358.67 3,720.05 3611.05 5,347.07 5,701.68 5,951,078.97 564,512.67 0.00 5,347.07 12,700.00 89.33 358.67 3,721.23 3612.23 5,447.04 5,699.36 5,951,178.91 564,509.57 0.00 5,447.04 12,800.00 89.33 358.67 3,722.40 3613.40 5,547.00 5,697.05 5,951,278.84 564,506.48 0.00 5,547.00 12,900.00 89.33 358.67 3,723.58 3614.58 5,646.97 5,694.74 5,951,378.78 564,503.38 0.00 5,646.97 13,000.00 89.33 358.67 3,724.76 3615.76 5,746.93 5,692.42 5,951,478.72 564,500.29 0.00 5,746.93 13,100.00 89.33 358.67 3,725.93 3616.93 5,846.90 5,690.11 5,951,578.65 564,497.19 0.00 5,846.90 13,200.00 89.33 358.67 3,727.11 3618.11 5,946.87 5,687.79 5,951,678.59 564,494.10 0.00 5,946.87 13,300.00 89.33 358.67 3,728.29 3619.29 6,046.83 5,685.48 5,951,778.52 564,491.00 0.00 6,046.83 13,394.65 89.33 358.67 3,729.40 3620.40 6,141.45 5,683.29 5,951,873.11 564,488.07 0.00 6,141.45 1J-724 MB_D_CP4 (03/21/07) 13,400.00 89.54 358.67 3,729.45 3620.45 6,146.80 5,683.16 5,951,878.46 564,487.90 3.96 6,146.80 13,500.00 93.54 358.67 3,726.77 3617.77 6,246.72 5,680.85 5,951,978.34 564,484.81 4.00 6,246.72 13,509.31 93.91 358.67 3,726.16 3617.16 6,256.00 5,680.63 5,951,987.62 564,484.52 4.00 6,256.00 13,585.44 93.91 358.67 3,720.97 3611.97 6,331.94 5,678.87 5,952,063.54 564,482.16 0.00 6,331.94 13,600.00 93.33 358.67 3,720.05 3611.05 6,346.46 5,678.53 5,952,078.06 564,481.71 3.99 6,346.46 13,694.99 89.53 358.69 3,717.68 3608.68 6,441.38 5,676.34 5,952,172.95 564,478.78 4.00 6,441.38 13,700.00 89.53 358.69 3,717.72 3608.72 6,446.39 5,676.23 5,952,177.96 564,478.63 0.00 6,446.39 13,800.00 89.53 358.69 3,718.54 3609.54 6,546.36 5,673.94 5,952,277.90 564,475.56 0.00 6,546.36 13,900.00 89.53 358.69 3,719.36 3690.36 6,646.33 5,679.66 5,952,377.84 564,472.49 0.00 6,646.33 14,000.00 89.53 358.69 3,720.18 3611.18 6,746.30 5,669.37 5,952,477.78 564,469.43 0.00 6,746.30 14,100.00 89.53 358.69 3,721.00 3612.00 6,846.27 5,667.08 5,952,577.72 564,466.36 0.00 6,846.27 14,200.00 89.53 358.69 3,721.82 3612.82 6,946.24 5,664.80 5,952,677.66 564,463.29 0.00 6,946.24 14,294.99 89.53 358.69 3,722.60 3613.60 7,041.21 5,662.63 5,952,772.59 564,460.38 0.00 7,041.21 1J-120 MB D_CP6 (03/21I07) 14,300.00 89.48 358.69 3,722.64 3613.64 7,046.21 5,662.51 5,952,777.60 564,460.23 1.00 7,046.21 14,301.52 89.46 358.69 3,722.66 3613.66 7,047.73 5,662.48 5,952,779.11 564,460.18 1.00 7,047.73 14,400.00 89.46 358.69 3,723.58 3614.58 " 7,146.18 5,660.23 5,952,877.53 564,457.16 0.00 7,146.18 14,500.00 89.46 358.69 3,724.51 3615.51 7,246.15 5,657.94 5,952,977.47 564,454.09 0.00 7,246.15 14,600.00 89.46 358.69 3,725.45 3616.45 7,346.12 5,655.65 5,953,077.41 564,451.02 0.00 7,346.12 3/23/2007 3:31:52PM Page 5 of 8 COMPASS 2003.11 Build 48 ~!~~~1~.~~~~... ~ f Car~coPhi[IipS Alaska ~ Halliburton Company Compass Proposal Report - Geographic HAL.LIBURTC~~1 Sperry C?~ifiing 8ervice~ 4,700.00 89.46 358.69 3,726.38 3617.38 7,446.09 5,653.37 5,953,177.35 564,447.96 0.00 7,446.09 14,800.00 89.46 358.69 3,727.31 3618.31 7,546.06 5,651.08 5,953,277.29 564,444.89 0.00 7,546.06 14,894.84 89.46 358.69 3,728.20 3619.20 7,640.87 5,648.91 5,953,372.07 564,441.98 0.00 7,640.87 1J-120 MB_ D_CP7 (03/21/07) 14,900.00 89.41 358.68 3,728.25 3619.25 7,646.03 5,648.79 5,953,377.23 564,441.82 1.00 7,646.03 14,909.79 89.32 358.67 3,728.36 3619.36 7,655.82 5,648.57 5,953,387.01 564,441.52 1.00 7,655.82 15,000.00 89.32 358.67 3,729.43 3620.43 7,746.00 5,646.47 5,953,477.16 564,438.71 0.00 7 746.00 15,100.00 89.32 358.67 3,730.63 3621.63 7,845.96 5,644.14 5,953,577.10 564,435.61 0.00 , 7 845.96 15,200.00 89.32 358.67 3,731.82 3622.82 7,945.93 5,641.81 5,953,677.03 564,432.50 0.00 , 7,945.93 15,300.00 89.32 358.67 3,733.01 3624.01 8,045.89 5,639.49 5,953,776.97 564,429.39 0.00 8 045.89 15,400.00 89.32 358.67 3,734.20 3625.20 8,145.86 5,637.16 5,953,876.90 564,426.28 0.00 , 8,145.86 15,500.00 89.32 358.67 3,735.39 3626.39 8,245.83 5,634.83 5,953,976.84 564,423.17 0.00 8,245.83 15,592.78 89.32 358.67 3,736.50 3627.50 8,338.57 5,632.67 5,954,069.56 564,420.29 0.00 8,338.57 1J-120 MB_D_CP8 (03/21lU7) - 1J-120 MB_D_Toe (03/21/07) 15,600.00 89.35 358.73 3,736.58 3627.58 8,345.79 5,632.51 5,954,076.77 564,420.07 0.99 8 345.79 15,700.00 89.74 359.65 3,737.38 3628.38 8,445.78 5,631.10 5,954,176.74 564,417.88 1.00 , 8,445.78 15,794.43 90.11 0.52 3,737.50 3628.50 8,540.21 5,631.24 5,954,271.15 564,417.28 1.00 540.21 8 15,800.00 90.11 0.52 3,737.49 3628.49 8,545.78 5,631.29 5,954,276.72 564,417.29 0.00 , 8,545.78 15,900.00 90.11 0.52 3,737.30 3628.30 8,645.77 5,632.20 5,954,376.71 564,417.41 0.00 8,645.77 16,000.00 90.11 0.52 3,737.10 3628.10 8,745.77 5,633.10 5,954,476.70 564,417.54 0.00 8 745.77 16,049.87 ~ 90.11 0.52 3,737.00 • 3628.00 8,795.64 5,633.55 5,954,526.57 564,417.60 0.00 , 8,795.64 L2: BHL @ 1 6050' MD, 3737' ND: 109' FSL, 19 95' FEL - Sec24-T11 N-R10E - 4 112" - 1J-120 MB_D_Toe (wp09) 3/23/2007 3:31:52PM Page 6 of 8 COMPASS 2003.11 Build 48 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~~ ~ ~ u~~ ~ ° Plan 1J -12Q L2 _ o-, ~ U ~~~" i~i Yi ~~ -~- _ __ (~ i~i ~IIp77 i~ _ - i ~i i i ~i ~ ~ ~„~ "M1~i~~ ':i = .~ Y I ar! '~. I '~ . _- ~ ' I I I I~ r ~ i ~p _ p PoI ' - __ -, - _ _ ~~~. ~i ~ i ~i i ~ ~i ~l, „a .. - _. __ __ _. _ i~. ' ~ ~ ~5. ~ .. ~~ h . . i 3,737.00 1J-120 MB_D_Toe (wp09) 8,795.64 5,633.55 5,954,526.57 564,417.60 - Point 3,728.20 1J-120 MB_D_CP7 (03/21/07) 7,640.87 5,648.91 5,953,372.07 564,441.98 - Polygon Point 1 0.00 0.00 5,953,372.07 564,441.98 Point 2 697.80 -16.24 5,954,069.56 564,420.29 3,736.50 1J-120 MB_D_Toe (03/21/07) 9,045.62 5,635.81 5,954,776.54 564,417.90 - Point 3,705.40 1J-120 MB_D_CP3 (03/21/07) 4,142.88 5,729.55 5,949,875.15 564,549.95 - Polygon Point 1 0.00 0.00 5,949,875.15 564,549.95 Point2 1,998.75 -46.27 5,951,873.11 564,488.07 3,722.60 1J-120 MB_D_CP6 (03/21/07) 7,041.21 5,662.63 5,952,772.59 564,460.38 - Polygon Point 1 0.00 0.00 5,952,772.59 564,460.38 Point 2 599.77 -13.72 5,953,372.07 564,441.98 3,729.40 1J-120 MB_D_CP4 (03/21/07) 6,141.45 5,683.29 5,951,873.11 564,488.07 - Point 3,660.40 1J-120 MB_D_CP2 (03/21/07) 2,543.93 5,766.14 5,948,276.69 564,599.03 - Polygon Point 1 0.00 0.00 5,948,276.69 564,599.03 Point 2 1,599.54 -36.60 5,949,875.15 564,549.95 3,716.10 1J-120 MB_D_CP5 (03/21/07) 6,241.48 5,680.97 5,951,973.11 564,484.97 - Polygon Point 1 0.00 0.00 5,951,973.11 564,484.97 Point 2 799.85 -18.35 5,952,772.59 564,460.38 3,641.10 1J-120 MB_D_Heel (03/21/07) 1,094.66 5,782.01 5,946,827.73 564,626.22 - Polygon Point 1 0.00 0.00 5,946,827.73 564,626.22 Point 2 651.18 2.59 5,947,478.71 564,623.72 3,736.50 1J-120 MB_D_CP8 (03/21/07) 8,338.57 5,632.67 5,954,069.56 564,420.29 - Polygon Point 1 0.00 0.00 5,954,069.56 564,420.29 Point 2 707.05 3.14 5,954,776.54 564,417.90 3,654.40 1J-120 MB_D_CP1 (03/21/07) 1,745.70 5,784.60 5,947,478.71 564,623.72 - Polygon Point 1 0.00 0.00 5,947,478.71 564,623.72 Point 2 789.28 -18.53 5,948,267.69 564,599.03 3/23/2007 3:31:52PM Page 7 of 8 COMPASS 2003.11 Build 48 o ~ ~ ~ ~ Q 1: ~ ~ Halliburton Company H~4I~.,1~1~C~,J~T`QN ~~~~~~~~~~~ Compass Proposal Report - Geographic , Alaska Sprarry DriiEing S~~riaas ~ • 3/23/2007 3:31:52PM Page 8 of 8 COMPASS 2003.11 Build 48 ~ ~ ~ ~.d ~ Y '~ ;~ ~..s,. ~r-` Halliburton Company H~-~.,1~IIE3t.,11RTQ~' ~~IQCa~h~~~~1~5 Compass Proposal Report - Geographic 8pe~-y Dr~illing ~ervices __ . . _ _ _ _ ~ ~ ` ~ ~~J~10CC1~~'11 ~ ~ 1 ~JS Alaska ~ Plan: 1 J-120 L2 (wp09) Sperry Drilling Services Anticollision Summary 23 March, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-120 Plan 1J-120 L2 Local Coordinate Origin: Centered on Well Plan 1J-120 - Slot 1J-120 Viewing Datum: oyon 141 Plan RKB @ 109.OOft (Doyon 141 (28+81)) TVDs to System: N North Reference: True Unit System: API - US Survey FeeY ~iJ~L~~~i~~ i ~ 8ps~ry Drilltr~g Serwrices ~~~~~~~ .~ g • • SURVEY PROGRAM ConocoPhillips Alaska, Inc. ANTt~OLLISION SETTINGS Datc: 200~-07-71TIIO:n0:00 Validated: Ycs Versioo: Engineering Irrterpolation Methotl: MD Interval: 50Stations Calculation Method: Minimum Curvature Depth Range From: 8341 To 16050.4999757897 Dcpth FrumDeptM1 To Sun~cr/Plan Tuol Error System: ISCWSA Mazimum Range:1802.24999758 2A.00 lono.INl C&GYRO-SS Scan Me[hod: Trav. Cylintler North Reference: Plan: 1J-120 L2 (wp09) IUO4u0 N3JLO0 MWD+IFR-AK-CAZSC ErrorSuAace: EllipticalCOnic N31LIU1 I(.IU').73 IJd2U L2 (nyUY) MWD+IPR-AK-CA~SC Warning Me[hotl: Rules Based 0 /. 300 330 30 Q 75 330 30 ,,. „ 22 . ' - ~ . ~~, ~"" From Colour To MD ~ , ~ ~ 5 300 ' ~ B0 0 8250 300 ~ " 60 " ... , ; `\ \ ~ \ ~~ ~ ~~ . _.._ 500 . . 8250 - 8 i .' ~ ~ ~ , ~ 2 ~~ ,_ \` 8500 - 8750 , ~ ~ ~ 8750 ~~- - 9000 ~ ~~ ~~ 9000 9250 ~ , ~ . 9250 9500 270 90 270 ~ qp 9500 -- - ~ 9750 . . ~ . ~ A A " 9750 10000 ~ ~ , . ~ . ~ . . ~. \ ~ . . 10000 10250 ~ . ~ ~ ~ ~ ~ ~ 7 .. 10250 10500 ~ \ \t ~ ,~ ~osoo - -- ~o~so zao ~zo . ~ ~ ~ ~. ` ~ ~ ~ . 10750 11000 50 ~\ ~ ~ 11000 11250 ~ " ~ ~ 11250 - N 500 ~ ~ zao ' ~so . ~ - 11500 11750 y~0 ~ 150 - 11750 12000 75 ~ - . 12000 -- 12250 180 ~ . ~~ ~ ... ~ ~~ ~ 12250 -- ~- ~-- 12500 . ~ ~ ~ - 12500 12750 Trv.elliogC~linderAzimuth(TFO+A7.f)~°~rsCentreroCeotreSeparatiuo~SpR/in~ 210 750 ~- 12750 73000 30 13000 13250 180 13250 73500 13500 13750 ~a~ *F vs.~ q.i 13750 14000 14000 14250 Trnvelling Cylinder Azimnth (TFO+AZ[) [°] vs Centre to Centre Separation ~150 ft/in~ 14250 - 14500 ~y~~ __ P~ On~~oa -- '°'~ 14500 14750 uip _ cr.m~a~mn ,"'.,°•.ss °si:9 ie~.ni a~~s.o s~.,.s scea~v :w aa Meo „"°°"~ sas~ aee.n a~m,e azesoo s'fi°sieei 14750 ..... -.... 15000 ;i ~isi:'si esea a~ees ii'09~e' ~::~ie ss~e~. :m ,~°sn NAD 27 A5P Zone 4: WE~L DETAILS: Plan 1J-120 15000 -~- 15250 ~~~pMe o c~~N~p~~ _ cv~(wn~mr~ i~ ~.asa.ea es~ii a~xe x>saoe~ x~aesi o0o am 15250 .._____._ 15500 ~e~.sos~s io°e~ nvax ,sssex w3zer ~ao.n~o~ „~mMeoc~emv.~ron Ground Level~ 81.00 +N/S+~.W Northing Easting Latittude Lonyitude Slot 15500 15750 ~~ ~s~asm w~i osz 3~3~.ro e>sse~ xaaa~ om om ~..~zo eo_aiwoa~ 0.00 0.00 5945688.02 558853.50 70°75'43.975N 149°31'27.21W 1J-720 ~5750 16000 REFERENGEINFORMATION 18000 18250 Coordinate (NIE) Reference: Well Plan 1J-120 - Slot 1J-120, True North Vertiwl (ND) Reference: Doyon 141 Plan RKB ~ 109.OOft (Doyon 141 (28+81~) Section (VS) Reference: Slot - 1J-72010.00N, O.OOE) Measured Dep[h Reference: Ooyon 1A7 Plan RKB ~ 109.OOtt (Doyon 141 (28+81)) Calculation Method'. Minimum Gurvature 0~lGINAL ~ Halliburton Com an ~ P Y Anticollision Report Casing Points 8341.00 3626.14 7.625 9.875 7 5/8" TOW 16049.86 3737.00 4.500 6.750 41/2" Plan: 1J-120 L2 (wp09) Date Composed: 10/12/2006 Version: 3 Principal: Yes Tied-to: From: Definitive Path Summary Kuparuk 1 D Pad 1 D-138 1 D-138 VO Out of range Kuparuk 1 D Pad 1 D-141 1 D-141 VO Out of range Kuparuk 1 D Pad 1 D-141 1 D-141 L1 VO Out of range Kuparuk 1 D Pad 1 D-32 1 D-32 V5 Out of range Kuparuk 1 D Pad 1 D-32 1 D-32L1 V1 Out of range Kuparuk 1 D Pad 1 D-32 1 D-32L1 PB1 V1 Out of range Kuparuk 1 D Pad 1 D-34 1 D-34 V6 15989.63 8525.00 780.99 254.85 526.14 Pass: Major Risk Kuparuk 1 D Pad 1 D-36 1 D-36 V4 Out of range Kuparuk 1 D Pad 1 D-36 1 D-36L1 V3 Out of range Kuparuk 1 D Pad 1 D-36 1 D-36L2 V1 Out of range Kuparuk 1 D Pad 1 D-37 1 D-37 V4 Out of range Kuparuk 1D Pad 1D-37 1D-37L1 V1 Out of range Kuparuk 1 D Pad 1 D-37 1 D-37L2 V3 Out of range Kuparuk 1 D Pad 1 D-37 1 D-37L2P61 V1 Out of range Kuparuk 1 D Pad 1 D-39 1 D-39 V2 15982.36 8900.00 1483.42 175.33 1308.09 Pass: Major Risk Kuparuk 1J Pad 1J-03 1J-03 V9 10400.27 8075.00 796.76 122.54 674.22 Pass: Major Risk Kuparuk 1J Pad 1J-109 1J-109 V1 8661.19 7475.00 650.58 103.62 546.96 Pass: Major Risk Kuparuk 1J Pad 1J-109 1J-109P61 V3 8661.19 7475.00 650.58 103.84 546.75 Pass: Major Risk Kuparuk 1J Pad Plan 1J-107 Plan 1J-107 L1 VO Plan Out of range Kuparuk 1J Pad Plan 1J-107 Plan 1J-107 L2 VO Plan Out of range Kuparuk 1J Pad Plan 1J-107 Plan 1J-107 V1 Plan: 1 Out of range Kuparuk 1J Pad Plan 1J-111 Plan 1J-111 V1 Plan: 1 Out of range Kuparuk 1J Pad Plan 1J-120 Plan 1J-120 V2 Plan: 1 8350.00 8350.00 0.10 0.00 0.10 Pass: No Errors Kuparuk 1J Pad Plan 1J-122 Plan 1J-122 V2 Plan: 1 14922.66 17000.00 1428.51 263.45 1165.06 Pass: Major Risk Kuparuk 1J Pad Plan 1J-L14(BQ) Plan 1J-L14(BQ) VO Pla 14928.28 15200.00 1107.83 253.03 854.80 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-118 Plan: 1J-118 L1 V3 Pla 15977.79 14525.00 1265.59 273.18 992.41 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-118 Plan: 1J-118 L2 V1 Pla 15989.31 14525.00 1263.82 277.84 985.98 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-118 Plan: 1J-118 V4 Plan: 15981.37 14550.00 1281.14 276.92 1004.22 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-118 Rig: 1J-118 VO 15986.07 14525.00 1274.12 248.95 1025.17 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-118 Rig: 1J-118P61 VO 10147.41 8625.00 1181.67 124.49 1057.19 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-118 Rig: 1J-118PB2 VO 10197.16 8675.00 1181.56 125.44 1056.12 Pass: Major Risk ~ ~ ~ ~ ~ ~ ~ ~ GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: 1J-120 L2 (wp09) & NOT PLANNED Interpolation Method: MD + Stations Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 8341.00 to 16049.85 ft Scan Method: Trav Cylinder North Maximum Radius: 1802.19 ft Error Surface: Ellipse + Casing 1J-120 I~ Drillin Hazards~ummar ~ (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud Pressure 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 Wellbore Collision with Moderate Adhere to Directional Program, Directional Existing we11s Driller to update Traveling cylinder diagrams for every survey and monitor well to well roximities. ~ f"~ ~ p'°t ~ jq ~~~ 1J-120L1 Drilling Hazards Summary f'; v °`~ prepared by Dennis D. Harlwig 3/28/2007 1:25 PM 'Insulated conductor, 20" 94# K55 x 34" 0.312", set at +/. 80' MD. `Wellhead / Tubing Head / Tree, 10-3/4" x 4-7/2", 5,000 psi. Tubing String _ / 4-1/T' 12.6#, L-80, IBTM 3.958" ID, 3.833" Drift 10314" 45.5# L-80, Casing Shoe, set @ 4100' MD, 2,472' ND GLM, Camco 4-1/2" X 1" KBMG GLM, Camco 4-1/2" X 1" KBMG ConocoPhillips West Sak 7-5/8" Producer 1J-120 Tri-Lateral Completion wp_09 8341aMD, 3626' ND ~~ `~ `~ ` ~ \ ~'-~ 'D' Sand Lateral ` ECP 4-112" 11.6# L~0 SlotOed Liner Every Joint 4-112" Guide Shoe d-112" X 7SI8'• Model'B' HOOK Flanoer Assembly f~ 5-112" X 7S18" ZXP Liner Top Packer with Hold Downs Casing Sealbore Recepqcle 4.75" ID Orienting Profile ~~~ Automatic Alignment of LEM Positive Latching Collet ~~ Indicares Correct Location ~ Seal Bore for Lateral ~ Isolation - 3.68" ID Access Window Positive Lateral Access Via ~ Thru-Tubing Diverter Seal Bore for Lateral Isolation • 3.66" ID ~ Isolatlon Seal Aumbly 4.75" Seal OD 3.875" Seal ID 5-112" Bottom of Motor Centralizer Centralift 418 HP KMkIFER-4 ~ 4-112" Liner Shoe, 11.6# -80 BTC 5-'/:" Tieback Sleeve ~t @ 76050' MD, 7' ND ~ 4-'/:" Bent Muleshce Latera u P Orienting Profile B-sand Window at 8841' MD, 3720' ND Casing Sealbore 'B' Sand Lateral Receptacle 4.75" ID payzone ECP 4-112" 11.6# L-80 Slotted _ Liner Every Joint ., „ 4-112" X 7S18•' Model'B' HOOK Hanoer Seal Bore 3.68" ID 4-112" 12.6# Tubing 5-112" X 7518" ZXP Liner Top Packer ~` ~ with Hold Downs ~ s-vs° x ~s~s.. LinerHangerlPackerAssemblyat FlexLOCk LinerHanger +1-8950 MD Casing ~ Sealbore Receptacle, 4.75" ID ~ ~5-%" Tieback Sleeve 4-%" Bent Muleshoe 3.562" DB Nipple sA~1~~a IIUGIlS Baker Oil Tools As Planned With Diverters and Isolation Lateral Access Diverter Laleral Isolation Diverter GS Running Tool String Installed Installed (3.00" Lateral DriR) (2.50" ID Mainbore Dritt) 'GS' Profile tor ~ ~' Coil Connector ~RUnning/Retreving ~ i ~ (1.00' Length) l I~ Snap INSnap Out ~-Back Pressure Valve f PosRive Lxating~ (7.60' LengM) CoIIM Lateral Isolatfon~' r Flow-7hru Swivel Seals (725' Length) ~ Lateral Diverter . ~~ Hydrouli< Ramp Disconnect (1.50' Length) ~. Isolation/ Mainbore Diverter Sleeve I I ~_ GS Spear ~ I (1.50' Length) Laterel Isolation ~ 6.8 5 ft Approx. Seals OAL' may be required in highly deviatetl ' ~g.5' Diverter Langth 78.5' Sleeve Length ep applfcations (6 appro: IengthJ. Guide Shoe 4-1/2" Liner Shoe, 71.6lf, L-80 BTC Set @ 1605T MD, 3803' ND Seal Assembly 4.75" Seal OD • 3.875"ID ~A' Sand Undulatinq Pral 4112" 11.6# L~0 Slotted Liner Every Joint wl ¢~~y^ Eccentric ~ constrictorsforisolafion ,GuideShoe E~uinment Sqecifications 4-1/2" X 7-5/8" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with diverter: 4.63" Wteral Drift, no diverter or LEM: 3.88" Lateral Drift, wl diverter, no LEM: 3.88" LaterallMainbore Diverter OD: 6.75" 4-1/2" Lateral Entry Module Mainbore Drift: 3.65" Mainbore Drift, wl isolation sleeve: 2.50" Lateral Drift, wl coil diverter: 3.00" OD of Diverter and Sleeve: +l- 3.89" Diverter and Sleeve Length: +~_ 18.5' 4-1/T' Casing Shoe, 17.f# L~0 BTC Set @ 16320' MD, 394T ND 7-5/8", 29.7#, L~O, Casing Shce, Set m Baker Mughes I005. This tlocument maynot be reproduced or tlistrlbuhd, In whde or In part, In anytorm or Gy 8~ @'IOOSr M D, 3910' ND, 88 deg inc any means ebetronlc or mechanlwl, Inclutlin8 Photocopyhg, reeording, or by arry In}ormatlon storaqe antl retrkval sys@m now known or hereaRer InvmteQ witl~outwntlen permission hom eaker Huphes Ine. 2007 West Sak 7b2" TNaaterol Completlan - Produul Merc~31,2007 ~~ey: qeNabnNO.: Marc D. Nuck 0 C ~'I ~ I ~ i~..~~..~ ~ • ~ TRAYSMIT'~"AL L~'I'TER CH~CKLIST vVELL ~iANLE ,~C/c Gl /s.~~ - /~ L Z- PTD# Z.f~7- D~~ ~Development Service Eacptocatory Stratigraphic Z'est Yon-Coaventional Wel! Circle Appropriate Letter / Paragraphs to bc tncluded ia Transm~ttal Letter ' CE~CK i ADD-OiVS •` 1'EXT' FOR APPROVqL LETTER ~ wHAr I (OPTIONS) i ~ ; aPPLIES ~ ; ~ i I ;~ I MliLTI LATERAL ~ T'he permit is for a new we{lbore segment of existing ~ / ~ wetl ~u /+.7' /Z.Cj i I / ~(~IP last two digits in I Permit No.zp7-OS~~API No. ~0-D _Z33 s ~~ ~ I number are ; -.~~. Z~. ~ ; between 60-69) Production ~hou[d continue to be reported as a function of the ~ ; orivinal 4PI number stated above. ~ ~ ~ ~ PILOI' E{OLE i[n accordance with 20 A.AC 25.00~(~, all record;, data a,nd Ios,~s i I ~ acquired for the pilot hole must be c(earty differentiated in both ~ i ~"`~« ~e ~ PF~ and API number ~ ; ,' ~~4- - - ) from records, data and logs ~ ~ I acquired for we(I ( ~ . - ~ ' ~ SPACING The permit is approved subject to futl comptiarice with 20 AAC I ~ I EXCEPTION ~ 25.0~5. Approvat to perforate and r ee /''est is contingent ; f i ! upon issuance of a conservatioa ocder approving a spacing j : ~ ~ exc~ption. assum~s the ' ;~ j ~[iability of any protest ro the spacing exception that may occur. i ` ; DRY DITCH ~ AlI dry ditch sample sets subrnitted to tt~e-Eommission must be in ; ~ i SA!~IPLE I no greater thart 30' sample intecvals from below the permafrost or ; ' ~ I from where samp(es are frst caught and 10' sample intervals ; ~ ~ ~ ~ through target zones. ~ ~ i ~ ~_ ' ' ~ Please note the following, specia! condition of this permir: j Non-Conventional ~ produciion or production testing of coa! b~d methane is not allowed ! ~`'~`e« ~ for (name of wel!) until after (Companv Name) has designed and ~ ~ imp(emented a water we(1 testing program to provide baseline data ; ~ ; on water uali and uanti (Com Q ~Y q ty• ~anY Nam~) must contact the I ~ Commission to obtain advance approva! of such water we(t testing ; ~ ' Pcostram I Rev: 1 /2~i06 C:!jody~transmitta! checklist , ~ ~ , , ~ , . ,,~ ~~ k, .. ~ . ~ ! 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' N N N ` t' Z) ~ 1 7+ (7 0 ~ . ,C ~ ~ ~ v` ~ I Q ~ U a ¢ a `~ w a W ~ a~ ~ i c • Well Histo.ry Fife APPENDIX Information of detailed nature that is not • pa~ticula~ly geRnane to the Well Permitting Process but is part of the history file. To irnprove the readability of the Well History file and to simpl~fy finding information, information of this natu~e is accumulated at the end of the file under APPENDIX. No special efifort has been made to chronologically organize this category of information. s i ~ 1J120L200610200755N.tXt Sperry-Sun Drillin Services LIS Scan Uti~ity $Revision: 3 $ LisLib $Revision: 4 $ Fri Aug 10 15:24:10 2007 Reel Header Service name .............LISTPE Date . ...................07/08/10 Ori 9in ...................5T5 Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN comments .................5T5 ~zs writing ~ibrary. Scientific Technical Services Tape Header Service name .............LISTPE Date . ...................07/08/10 Origin ...................5T5 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: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNE55: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: 1J-120 L2 500292335261 ConocoPhillips ,4laska, znc. Sperry Drilling services 10-AUG-07 MWD RUN 2 Mw0005005556 T. GALVIN D. GLADDEN MWD RUN 15 Mw0005005556 P. ORTH D. GLADDEN MWD RUN 3 Mw0005005556 T. GALVIN D. GLADDEN MWD RUN 16 Mw0005005556 P. ORTH D. GLADDEN 35 11N lOE 1875 2357 MWD RUN 14 Mw0005005556 P. ORTH D. GLADDEN MWD RUN 17 Mw0005005556 P. ORTH D. GLADDEN Page 1 ~v~--~r~- ~ ~ 53`~~- , . ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 1J120L20061020075SN.tXt 109.00 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 10.750 4100.0 6.750 7.625 8239.0 ~ 1. ALL DEPTHS ARE MEASURED DEPTHS UNLE55 OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE IS AN OPENHOLE SIDETRACK, EXITING THE 1J-120 L2PB1 WELLBORE AT 12725'MD/3703~TVD, WITHIN THE MWD RUN 15 INTERVAL. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,3,14-17 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND GEO-PILOT ROTARY STEERABLE BHA (GP). 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 1-3,14-17 REPRESENT WELL 1J-120 L2 WITH API#: 50-029-23352-61. THIS WELL REACHED A TOTAL DEPTH (TD) OF 16033'MD/3750'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRIL~ING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). $ File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number...........1.0.0 Page 2 • i 1J120L20061020075SN.txt ~ate of Generation.......07/08/10 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD ~epth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 4073.5 15975.5 RPS 4085.0 15982.5 FET 4085.0 15982.5 RPD 4085.0 15982.5 RPX 4085.0 15982.5 RPM 4085.0 15982.5 ROP 4110.5 16033.5 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD $ BIT RUN NO MERGE TOP 2 4073.5 3 4283.0 14 8239.5 15 8281.0 16 12725.0 17 13185.0 # REMARKS: MERGED MAIN PASS. $ MERGE BASE 4283.0 8239.0 8281.0 12725.0 13185.0 16033.5 # Data Format Specification Record Data Record Type... ..........0 ~ata specification Block Type.....0 Log~ing Direction .................DOwn Optical log depth units.......,...Feet ~ata rteference Point ..............Undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 ~epth Units. . .. .. ..... ~atum Specification Block sub-type...0 Name service order units size Nsam Rep Code Offset DEPT FT 4 1 68 0 RPD MWD OHMM 4 1 68 4 RPM MWD OHMM 4 1 68 8 RPS MWD OHMM 4 1 68 12 RPX MWD OHMM 4 1 68 16 FET MWD HOUR 4 1 68 20 GR MWD API 4 1 68 24 ROP MWD FT/H 4 1 68 28 Page 3 Channel 1 2 3 4 6 8 • ~ 1J120L2006102007SSN.tXt First Last Name Service Unit Mi11 M1x M2dn Nsam Reading Reading DEPT FT 4073.5 16033.5 10053.5 23921 4073.5 16033.5 RPD Mw~ OHMM 3.32 2000 42.8426 23796 4085 15982.5 RPM MwD OHMM 5.68 1550.53 39.6764 23796 4085 15982.5 RPS MwD OHMM 5.38 2000 41.2127 23796 4085 15982.5 RPx MwD OHMM 3.66 2000 58.676 23796 4085 15982.5 FET MwD HOUR 0.16 640.96 2.27114 23796 4085 15982.5 GR MwD API 21.13 115.83 65.4171 23805 4073.5 15975.5 RoP Mw~ FT/H 0.15 499.34 208.986 23847 4110.5 16033.5 First Reading For Entire File..........4073.5 ~ast Reading For Entire File...........16033. File Trai.ler Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 ~ate of ~eneration.......07/08/10 Maximum Physical Record..65535 File Type ...:............LO Next File Name...........5T5LIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version tvumber.. ........1.0.0 ~ate of ~eneration.......07/08/10 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 INCREMEN7: .5000 # FILE SUMMARY VENDOR TOOL CODE GR RPD RPX FET RPS RPM ROP $ # LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 4073.5 4085.0 4085.0 4085.0 4085.0 4085.0 4110.5 STOP DEPTH 4245.5 4232.5 4232.5 4232.5 4232.5 4232.5 4283.0 Page 4 06-MAY-07 • i 1J120L20061020075SN.tXt SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4283.0 TOP LOG INTERVAL (FT): 4110.0 BOTTOM LOG INTERVAL (FT): 4283.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # # # # # BOREHOLE AND CASING DATA 72.3 72.7 TOOL NUMBER 053516 81390 OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 4100.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (5): 41.0 MUD PH: 8.6 MUD CHLORIDES (PPM): 250 FLUID LOSS (C3): 6.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 4.500 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 4.320 68.0 MUD FILTRATE AT MT: 5.400 65.0 MUD CAKE AT MT: 3.200 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Ddtd rtecord Type... ..........0 Data Specification Block Type.....0 Log~ing Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .1zN Max frames per record .............Undefined ,4bsent value... .................-999 Depth Units. .. .. .. ..... ~atum 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 Page S • ~ 1J120L200610 20075SN.tXt 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 N sam Reading Reading DEPT FT 4073.5 4283 4178.25 420 4073.5 4283 RPD MwD020 OHMM 3.32 2000 134.831 296 4085 4232.5 RPM MwD020 OHMM 6.93 1550.53 37.5355 296 4085 4232.5 RPS Mw~020 OHMM 5.62 1733.57 31.207 296 4085 4232.5 RPx MwD020 OHMM 3.66 1729.16 21.3865 296 4085 4232.5 FET Mw~020 HOUR 0.16 69.4 13.4449 296 4085 4232.5 GR MwD020 API 42.35 99.3 65.3099 345 4073.5 4245.5 ROP Mw~020 FT/H 27.58 418.49 252.325 346 4110.5 4283 First Reading For Entire File..........4073.5 ~ast Reading For Entire File...........4283 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/08/10 Maximum Physical Record..65535 File Type ................LO N2xt File Name...........STSLIB.003 Phy5iCd1 EOF File Header Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/10 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: 3 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 4233.0 8239.0 RPM 4233.0 8239.0 RPx 4233.0 8239.0 FET 4233.0 8239.0 RPD 4233.0 8239.0 GR 4246.0 8239.0 ROP 4283.5 8239.0 $ # Page 6 • ~ 17120L200610200755N.txt LOG HEADER DATA DATE LOGGED: 09-MAY-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8239.0 TOP LOG INTERVAL (FT): 4283.0 BOTTOM LOG INTERVAL (FT): 8239.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 72.6 MAXIMUM ANGLE: 83.6 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 157645 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 4100.0 # BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (s): 39.0 MUD PH: 9.2 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): 2.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 3.800 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.520 100.4 MUD FILTRAi"E AT MT: 4.500 65.0 MUD CAKE AT MT: 3.100 65.0 # 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 Log~ing Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............Undefined ,4bsent value ......................-999 Depth units. . .. .. ..... ~atum specification Block sub-type...0 Name Service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 Page 7 ~J ~1 U 1J120L200610200755N.tXt RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last i Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4233 8239 6236 8013 4233 8239 RPD Mw~030 OHMM 4.17 73.59 11.5375 8013 4233 8239 RPM MwD030 OHMM 5.68 38.73 10.851 8013 4233 8239 RPS MWD030 OHMM 5.38 48.22 10.7775 8013 4233 8239 RPx MwD030 OHMM 4.87 2000 11.3765 8013 4233 8239 FET Mw~030 HOUR 0.16 8.74 0.581481 8013 4233 8239 Grt MWD030 API 21.13 115.83 66.7246 7987 4246 8239 ROP MwD030 FT/H 3.25 499.34 211.62 7912 4283.5 8239 First Reading For Entire File..........4233 ~ast Reading For Entire File...........8239 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/08/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service 5ub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/10 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: 14 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 8239.5 8281.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE 03-7uN-07 Page 8 ~ • 1]120L200610200755N.tXt SURFACE SOFTWARE vERSION: insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8281.0 TOP LOG INTERVAL (FT): 8239.0 BOTTOM LOG INTERVAL (FT): 8281.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .O MAXIMUM ANGLE: .0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ TOOL NUMBER # # # # # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (5): 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 ~ata specification Block Type.....0 Log~ing Direction .................DOwn optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units ................ ..... ~atum Specification Block sub-type...0 6.750 8239.0 Mineral Oil Base 8.40 59.0 .0 80000 34.4 .000 .0 .000 90.0 .000 .0 .000 .0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD140 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading Page 9 • 1J120L2006102007SSN.txt DEPT FT 8239.5 8281 8260.25 ROP MWD140 FT/H 0.85 25.16 12.8796 First Reading For Entire File..........8239.5 ~ast tteading For Entire File...........8281 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... Version Number. ........1,0.0 ~ate of Generation.......07/08/10 Maximum Physical Record..65535 File Type ................LO N2xt Fi12 Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/08/10 Maximum Physical rtecord..65535 File Type. . .........LO Previous File Name.......5T5LIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD • $4 8239.5 8281 84 8239.5 8281 Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 15 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 8239.5 12725.0 GR 8239.5 12725.0 RPM 8239.5 12725.0 RPX 8239.5 12725.0 RPD 8239.5 12725.0 RPS 8239.5 12725.0 ROP 8281.5 12725.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWA RE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEE D (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # Page 10 06-7uN-07 znsite 72.13 Memory 12725.0 8281.0 12725.0 75.7 92.0 . ~ • 1J120L2006102007SSN.tXt TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 151107 EWR4 Electromag Resis. 4 156404 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 8239.0 # BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (5): 51.0 MUD PH: .O MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3): 4.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 107.6 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .O # 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 Log~ing Direction .................DOwn optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined absent value ......................-999 Depth units. . .. .. ..... ~atum Specification Block sub-type...0 Name service order units size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD150 OHMM 4 1 68 4 2 RPM MWD150 OHMM 4 1 68 8 3 RPS MWD150 OHMM 4 1 68 12 4 RPX MWD150 OHMM 4 1 68 16 5 FET MWD150 HOUR 4 1 68 20 6 GR MWD150 API 4 1 68 24 7 ROP MWD150 FT/H 4 1 68 28 8 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 8239.5 12725 10482.3 8972 8239.5 RPD MWD150 OHMM 5.12 1113.78 56.5808 8972 8239.5 RPM MwD150 OHMM 6.49 147.34 55.3056 8972 8239.5 Page 11 Last Reading 12725 12725 12725 ~ • 1J120L200610200755N.tXt RPS MWD150 OHMM 6.46 2000 57.6407 8972 8239.5 12725 RPx MWD150 OHMM 7.03 2000 82.084 8972 8239.5 12725 FET Mw~150 HOUR 0.18 640.96 3.06668 8972 8239.5 12725 GR MWD150 API 40.88 99.61 65.7959 8972 8239.5 12725 ROP MWD150 FT/H 0.51 465.35 216.545 8888 8281.5 12725 First Reading For Entire File..........8239.5 ~ast Reading For Entire File...........12725 File Trailer Service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/10 Maximum Physical Record..65535 File Ty e ................LO Next Fi~e Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLIB.006 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/10 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: 16 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12667.5 13127.5 FET 12674.5 13134.0 RPx 12674.5 13134.0 RPS 12674.5 13134.0 RPM 12674.5 13134.0 RPD 12674.5 13134.0 ROP 12725.5 13185.0 $ # LOG HEADER DATA DATE LOGGED: 07-JUN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 13185.0 TOP LOG INTERVAL (FT): 12725.0 BOTTOM LOG INTERVAL (FT): 13185.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG Page 12 . i i 17120~20061020075SN.txt MINIMUM ANGLE: 86.4 MAXIMUM ANGLE: 90.6 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 151107 EWR4 Electromag Resis. 4 156404 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 8239.0 # 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 Log~ing Direction .................DOwn optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined ,4bsent value ......................-999 Depth Units. . .. .. ..... ~atum specification Block sub-type...0 Name service order DEPT RPD MWD160 RPM MWD160 RPS MWD160 RPX MWD160 FET MWD160 GR MWD160 ROP MWD160 Name Service Unit Mineral Oil Base 8.40 85.0 .0 19000 4.6 .000 .0 .000 111.0 .000 .0 .000 .0 Units size tvsam Rep Code offset Channel FT 4 1 68 0 1 OHMM 4 1 68 4 2 OHMM 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 API 4 1 68 24 7 FT/H 4 1 68 28 8 First Last Min Max Mean Nsam Reading Reading Page 13 • • 1J120L2006102007SSN.txt DEPT FT 12667.5 13185 12926.3 1036 12667.5 13185 RPD MwD160 OHMM 40.4 194.92 60.4613 920 12674.5 13134 RPM MwD160 OHMM 38.03 136.46 57.8846 920 12674.5 13134 RPS MWD160 OHMM 39.23 1128.61 68.132 920 12674.5 13134 RPx MWD160 OHMM 42.36 2000 216.496 920 12674.5 13134 FET MwD160 OHMM 0.35 24.6 14.5385 920 12674.5 13134 GR MwD160 API 47.99 87.82 65.4484 921 12667.5 13127.5 RoP Mw~160 FT/H 0.15 322.95 167.871 920 12725.5 13185 First rteading For Entire File..........12667.5 ~ast Reading For Entire File...........13185 File Trailer Service name... .......STSLIB.006 service Sub ~evel Name... version Number. ........1.0.0 Date of Generation.......07/08/10 Maximum Physical rtecord..65535 File Ty e ................LO Next Fi~e Name...........STSLIB.007 Physical EOF File Header Service name... .......STSLIB.007 Service Sub Level Name... Version Number. ........1.0.0 Date of Generation.......07/08/10 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.006 comment rtecord FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 17 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 13128.0 15975.5 RPx 13134.5 15982.5 RPD 13134.5 15982.5 FET 13134.5 15982.5 RPM 13134.5 15982.5 RPS 13134.5 15982.5 RoP 13185.5 16033.5 $ # LOG HEADER DATA DATE LOGGED: 10-JUN-07 SOFTWARE SURFACE SOFTWA RE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7~}.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 16033.0 TOP LOG INTERVAL (FT): 13185.0 Page 14 i • 1J120L200610200755N.tXt BOTTOM LOG INTERVAL (FT): 16033.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.2 MAXIMUM ANGLE: 91.9 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10911222 EWR4 Electromag Resis. 4 228501 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 8239.0 # BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (5): 85.0 MUD PH: .O MUD CHLORIDES (PPM): 22500 FLUID LO55 (C3): 7.3 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 108.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ..........0 ~ata Specification Block Type.....0 Log~ing Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lzw Max frames per record .............undefined absent value ......................-999 ~epth units. . .. .. ..... Datum Specification Block sub-type...0 -vame Service order Units Size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD170 OHMM 4 1 68 4 2 RPM MWD170 OHMM 4 1 68 8 3 RPS MWD170 OHMM 4 1 68 12 4 RPX MWD170 OHMM 4 1 68 16 5 FET MWD170 HOUR 4 1 68 20 6 GR MWD170 API 4 1 68 24 7 ROP MWD170 FT/H 4 1 68 28 8 Page 15 ~ 1J120L200610200755N.tXt • First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13128 16033.5 14580.8 5812 13128 16033.5 RPD MwD170 OHMM 12.83 245.58 57.7477 5697 13134.5 15982.5 RPM MwD170 OHMM 18.33 246.62 52.9784 5697 13134.5 15982.5 RPS MwD170 OHMM 12.25 1605.31 54.5504 5697 13134.5 15982.5 RPx MWD170 OHMM 9.36 1607.33 65.1103 5697 13134.5 15982.5 FET MwD170 HOUR 0.17 19.54 0.983216 5697 13134.5 15982.5 GR MWD170 API 40.07 86.69 63.0528 5696 13128 15975.5 RoP MWD170 FT/H 1.01 339.45 200.436 5697 13185.5 16033.5 First Reading For Entire File..........13128 ~ast Reading For Entire File...........16033.5 File Trailer Service name... .......STSLIB.007 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/08/10 Maximum Physical Record..65535 File Ty e ................LO Next Fl~e Ndme...........STSLIB.008 Physical EOF Tape Trailer Service name .............LISTPE Ddte . ...................07/08/10 origin ...................STs Tape Name. .... ........UNKNOWN Continuation -vumber......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing R221 Trailer Service name .............LISTPE Date . ...................07/08/10 Ori in ...................STS Ree~ Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Physical EOF Physical EOF End Of LIS File ~ibrary. scientific Technical services ~ibrary. scientific Technical services Page 16 ~ 1J120L2PB100606200755N.tXt sperry-sun ~rillin9 services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Aug 10 15:40:10 2007 Reel Header Service name .............LISTPE Date . ...................07/08/10 Ori in ...................5T5 Ree~ Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comment5 .................5T5 LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................07/08/10 origin ...................5T5 Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. ~ Scientific Technical services Scientific Technical Services Physical EOF Comment Record TAPE HEADER west sak MWD/MAD LOGS # WELL NAME: 1J-120 L2 PBl API NUMBER: 500292335274 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 10-AUG-07 # JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 14 ~oa NUMBER: Mw0005005556 Mw0005005556 rww0005005556 LOGGING ENGINEER: T. GALVIN T. GALVIN P. ORTH OPERATOR WITNESS: D. GLADDEN D. GLADDEN D. GLADDEN MWD RUN 15 ~06 NUMBER: Mw0005005556 LOGGING ENGINEER: P. ORTH OPERATOR WITNE55: D. GLADDEN # SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 1875 FEL: 2357 FWL: Page 1 ~v'~- - o~~- ~ i s3~Ifs ~ ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1J120L2PB10060620075SN.tXt 109.00 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 4100.0 2ND STRING 6.750 7.625 8239.0 3RD STRING PRODUCTION STRING # REMARKS: • l. ALL DEPTHS ARE MEASURED DEPTHS UNLE55 OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 8239~ MD/3601'TVD, WITHIN THE RUN 3 INTERVAL OF THE 1J-120 WELLBORE. THE WHTP- STOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 14. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,3,14,15 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND GEO-PILOT ROTARY STEERABLE BHA (GP). 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 1-3,14,15 REPRESENT WELL 1J-120 L2PB1 WITH API#: 50-029-23352-74. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13212'MD/3703'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). $ Page 2 • 1J120L2PB100606200755N.txt File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 ~ate of ~eneration.......07/08/10 Maximum Physical Record..65535 File Type. ............~0 Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD ~epth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM FET RPD ROP $ 1 ~ clipped curves; all bit runs merged. .5000 START DEPTH 4073.5 4085.0 4085.0 4085.0 4085.0 4085.0 4110.5 STOP DEPTH 13154.0 13161.0 13161.0 13161.0 13161.0 13161.0 13212.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 4073.5 4283.0 Mw~ 3 4283.0 8239.0 Mw~ 14 8239.5 8281.0 MwD 15 8281.0 13212.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type... ..........0 ~ata Specification Block Type.....0 Log~ing Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined ,4bsen~t value ......................-999 ~epth 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 Page 3 • i 1J120L2P6100606200755N.tXt 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 4073.5 13212 8642.75 18278 4073.5 13212 RPD MwD OHMM 3.32 2000 36.4947 18153 4085 13161 RPM Mw~ OHMM 5.68 1550.53 33.9136 18153 4085 13161 RPS Mw~ OHMM 5.38 2000 34.9354 18153 4085 13161 RPx MwD OHMM 3.66 2000 47.3074 18153 4085 13161 FET Mw~ HOUR 0.16 640.96 2.02137 18153 4085 13161 GR Mw~ API 21.13 115.83 66.6631 18162 4073.5 13154 ROP Mw~ FT/H 0.51 499.34 212.753 18204 4110.5 13212 First Reading For Entire File......,...4073.5 ~ast Reading For Entire File...........13212 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/10 Maximum Physical Record..65535 File Ty e ................LO Next Fi~e Name...........5T5LIB.002 Physical EOF Fiie Header Service name... .......STSLIB.002 Service Sub Level Name... version rvumber. ........1.0.0 ~ate of ~eneration.......07/08/10 Maximum Physical Record..65535 File 7ype. .... ......~o Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPX RPM FET RPS ROP $ # LOG HEADER DATA header data for each bit run in separate files. 2 .5000 START DEPTH 4073.5 4085.0 4085.0 4085.0 4085.0 4085.0 4110.5 STOP DEPTH 4245.5 4232.5 4232.5 4232.5 4232.5 4232.5 4283.0 Page 4 • • 1J120L2PB1006062007SSN.tXt DATE LOGGED: 06-MAY-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4283.0 TOP LOG INTERVAL (FT): 4110.0 BOTTOM LOG INTERVAL (FT): 4283.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 72.3 MAXIMUM ANGLE: 72.7 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 053516 81390 # # # # # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 4100.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 41.0 MUD PH: 8.6 MUD CHLORIDES (PPM): 250 FLUID LO55 (C3): 6.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 4.500 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 4.320 68.0 MUD FILTRATE AT MT: 5.400 65.0 MUD CAKE AT MT: 3.200 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: # Data Format Specification Record Data Record Type... ..........0 ~ata Specification Block Type.....0 Log~ing Direction .................DOwn optical log depth units...........Feet ~ata tteference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 ~epth Units. . .. .. ..... ~atum 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 Page 5 ' • • 1J120L2PB1006062007SSN.tXt 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 4073.5 4283 4178.25 420 4073.5 4283 RPD MwD020 OHMM 3.32 2000 134.831 296 4085 4232.5 RPM MWD020 OHMM 6.93 1550.53 37.5355 296 4085 4232.5 RP5 MWD020 OHMM 5.62 1733.57 31.207 296 4085 4232.5 RPx MwD020 OHMM 3.66 1729.16 21.3865 296 4085 4232.5 FET MwD020 HOUR 0.16 69.4 13.4449 296 4085 4232.5 GR MwD020 API 42.35 99.3 65.3099 345 4073.5 4245.5 RoP MwD020 FT/H 27.58 418.49 252.325 346 4110.5 4283 First Reading For Entire File..........4073.5 ~ast Reading For Entire File...........4283 File Trailer Service name... .......STSLIB.002 Service Sub ~evel~Name... version Number. ........1.0.0 Date of Generation.......07/08/10 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 ~ate of Generation.......07/08/10 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LIB.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: 3 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 4233.0 8239.0 rtPx 4233.0 8239.0 RPM 4233.0 8239.0 RP5 4233.0 8239.0 RPD 4233.0 8239.0 GR 4246.0 8239.0 ROP 4283.5 8239.0 Page 6 ~ • 1J120L2PB100606200755N.txt $ # LOG HEADER DATA DATE LOGGED: 09-MAY-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8239.0 TOP LOG INTERVAL (FT): 4283.0 BOTTOM LOG INTERVAL (FT): 8239.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 72.6 MAXIMUM ANGLE: 83.6 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 157645 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 4100.0 # BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (5): 39.0 MUD PH: 9.2 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): 2.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 3.800 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.550 100.4 MUD FILTRATE AT MT: 4.500 65.0 MUD CAKE AT MT: 3.100 65.0 # 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 Log~ing Direction .................Down Optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined ,4bsent value ......................-999 ~epth Units. . .. .. ..... ~atum specification Block sub-type...0 Name service Order units size Nsam Rep Code Offset Channel Page 7 • • 1J1 20L2PB100606200755N.tXt DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4233 8239 6236 8013 4233 8239 RPD MWD030 OHMM 4.17 73.59 11.5375 8013 4233 8239 RPM MWD030 OHMM 5.68 38.73 10.851 8013 4233 8239 rtPS MwD030 OHMM 5.38 48.22 10.7775 8013 4233 8239 RPx MWD030 OHMM 4.87 2000 11.3765 8013 4233 8239 FET MWD030 HOUR 0.16 8.74 0.581481 8013 4233 8239 GR MWD030 API 21.13 115.83 66.7246 7987 4246 8239 ROP MwD030 FT/H 3.25 499.34 211.62 7912 4283.5 8239 First Reading For Entire File..........4233 ~ast Reading For Entire File...........8239 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/10 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.......07/08/10 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LIB.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: 14 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RoP 8239.5 8281.0 $ # LOG HEADER DATA Page 8 s • 17120~2PB1o06062007S5N.txt DATE LOGGED: 03-JUN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8281.0 TOP LOG INTERVAL (FT): 8239.0 BOTTOM LOG INTERVAL (FT): 8281.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .O # 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): 8239.0 # BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (5): 59.0 MUD PH: .O MUD CHLORIDES (PPM): 80000 FLUID LO55 (C3): 34.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 90.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O # 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 Log~ing Direction .................DOwn optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. . .. .. ..... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD140 FT/H 4 1 68 4 2 Page 9 ~ ~ 1J120L2PB100606200755N.tXt First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8239.5 8281 8260.25 84 8239.5 8281 ROP MWD140 FT/H 0.85 25.16 12.8796 84 8239.5 8281 First rteading For Entire File..........8239.5 ~ast Reading For Entire File...........8281 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/08/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........5T5LIB.005 Physical EOF File Header Service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/10 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LIB.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: 15 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 8239.5 13161.0 RPD 8239.5 13161.0 RPM 8239.5 13161.0 GR 8239.5 13154.0 FET 8239.5 13161.0 RPS 8239.5 13161.0 ROP 8281.5 13212.0 $ # LOG HEADER DATA DATE LOGGED: 06-JUN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 13212.0 TOP LOG INTERVAL (FT): 8281.0 BOTTOM LOG INTERVAL (FT): 13212.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 75.7 Page 10 i ~ 1J120L2PB10060620075SN.txt MAXIMUM A NGLE: 92.0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 151107 EWR4 Electromag Resis. 4 156404 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 8239.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (5): 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 Ddta Record Type... ..........0 Data Specification Block Type.....0 Log~ing Direction .................DOwn optical log depth units...........Feet ~ata tteference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined ,4bsent value ......................-999 ~epth Units. . .. .. ..... Datum Specification Block sub-type...0 Name service Order DEPT RPD MWD150 RPM MWD150 RPS MWD150 RPX MWD150 FET MWD150 GR MWD150 ROP MWD150 Name Service Unit DEPT FT Mineral Oil Base 8.40 51.0 .0 24000 4.6 .000 .0 .000 107.6 .000 .0 .000 .0 units size Nsam Rep Code offset Channel FT 4 1 68 0 1 OHMM 4 1 68 4 2 OHMM 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 HOUR 4 1 68 20 6 API 4 1 68 24 7 FT/H 4 1 68 28 8 First Last Min Max Mean Nsam Reading Reading 8239.5 13212 10725.8 9946 8239.5 13212 Page 11 ~ ~ 1J120L2PB100606200755N.txt RPD MwD150 OHMM 5.12 1113.78 53.853 9844 8239.5 13161 RPM MwD150 OHMM 6.49 147.34 52.5776 9844 8239.5 13161 RPS Mw~150 OHMM 6.46 2000 54.712 9844 8239.5 13161 RPx MWD150 OHMM 7.03 2000 77.3346 9844 8239.5 13161 FET MwD150 HOUR 0.18 640.96 2.84995 9844 8239.5 13161 GR MwD150 API 40.88 106.24 66.6607 9830 8239.5 13154 ROP MwD150 FT/H 0.51 465.35 213.977 9862 8281.5 13212 First Reading For Entire File..........8239.5 Last Reading For Entire File...........13212 File Trailer Service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/10 Maximum Physical Record..65535 File TyPe ................LO Next File Name...........5T5LIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/08/10 origin ...................STS Tape Name. .... ........UNKNOWN Continuation -vumber......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Reel Trailer service name .............LISTPE Date . ...................07/08/10 Ori in........... ......STS Ree~ Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Physical EOF Physical EOF End Of LIS File ~ibrary. 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