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206-112
New Plugback Esets 6/21/2024 Well Name API Number PTD Number ESet Number Date Nikaitchuq 3 PB1 50-629-23242-70-00 205-001 T38970 9-26-2005 Nikaitchuq 3 PB2 50-629-23242-71-00 205-001 T38971 9-26-2005 Nikaitchuq 3 PB3 50-629-23242-72-00 205-001 T38972 9-26-2005 1E-24BL1 PB1 50-029-20857-70-00 212-009 T38973 4-17-2012 1E-24BL1 PB2 50-029-20857-71-00 212-009 T38974 4-17-2012 1E-24BL1 PB3 50-029-20857-72-00 212-009 T38975 4-17-2012 1J-102 PB1 50-029-23317-70-00 206-110 T38976 3-4-2008 1J-102 PB2 50-029-23317-71-00 206-110 T38977 3-4-2008 1J-102 PB3 50-029-23317-72-00 206-110 T38978 3-4-2008 1J-102L2 PB1 50-029-23317-73-00 206-112 T38979 3-24-2008 1J-102L2 PB2 50-029-23317-74-00 206-112 T38980 3-24-2008 1J-103 PB1 50-029-23318-70-00 206-114 T38981 12-12-2008 1J-103 PB2 50-029-23318-71-00 206-114 T38982 12-12-2008 1J-103 PB3 50-029-23318-72-00 206-114 T38983 12-12-2008 1J-102L2 PB1 50-029-23317-73-00 206-112 T38979 3-24-2008 1J-102L2 PB2 50-029-23317-74-00 206-112 T38980 3-24-2008 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: RPPG Pumping Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 12095'feet None feet true vertical 3501' feet 5040' feet Effective Depth measured 12095'feet 4673', 4681'feet true vertical 3501' feet 3524', 3526' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 4707' MD 3533' TVD Packers and SSSV (type, measured and true vertical depth) 4673' MD 4681' MD N/A 3524' TVD 3526' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: West Sak Oil Pool 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 Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 2643' 2255' Burst Collapse Production D Sand Liner 5880' 7144' Casing 3741' 4-1/2" 5920' 12081' 3501' 2600' 120'Conductor Surface Intermediate 20' 10-3/4" 80' measured TVD 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 206-112 50-029-23317-61-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025661, ADL0025662 Kuparuk River Field/ West Sak Oil Pool KRU 1J-102L2 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 120' ~~~ INJECTOR ~~ ~ N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: ZXP Liner Top Packer Packer: Baker GBH-22 Seal Assembly SSSV: None Allen Eschete allen.eschete@conocophillips.com (907) 265-6558Interventions Engineer Alternating Slotted Liner: 5254-12042' Alternating Slotted Liner: 3564-3502' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Allen Eschete DN: CN=Allen Eschete, E=Allen.Eschete@ ConocoPhillips.com Reason: I am the author of this document Location: Date: 2024.05.13 15:59:15-08'00' Foxit PDF Editor Version: 13.0.0 Allen Eschete By Grace Christianson at 12:03 pm, May 14, 2024 DSR-5/14/24 RBDMS JSB 051524 DTTMSTART JOBTYP SUMMARYOPS 4/18/2024 REPAIR WELL SNF FLOWPERM RPPG FULLBORE PUMP JOB PUMPED 355 BBLS OF 2%KCL SLURRY w/ 6215 LBS OF SNF FLOWPERM BETWEEN 0.6 PPG TO 0.86 PPG CONCENTRATION TO MBE @ ~5620' RKB IN THE D SAND LATERAL. CALLED FLUSH @ 1410 PSI. FINAL TREATING PRESSURE AT THE END OF FLUSH WAS 1175 PSI. WELL TO REMAIN SHUT IN FOR 48 HOURS. 1J-102 RPPG Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-102 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: ADDED FISH TO D-LAT, PUSHED TO 8150' 1J-102 10/18/2023 condijw Notes: General & Safety Annotation End Date Last Mod By NOTE: Crystal Seal slurry @ average 0.27 ppg concentration 4/26/2016 pproven NOTE: FullBore Crystal Seal B MBE treatment. Placed 2970# of 1-2-4 mesh 4/26/2016 pproven NOTE: concentration of 0.28 ppg 11/14/2015 pproven NOTE: FullBore MBE treatment per design Placed 2310# of 1-2-4 mesh Crystal Seal slurry 11/14/2015 pproven NOTE: FullBore MBE treatment per design placing ~290 bbls 3% KCL / 4 mil Crystal Seal slurry 9/18/2015 pproven NOTE: into formation (3795# of CS)9/18/2015 pproven NOTE: EXTERNAL SLEEVE (.500 X 65) WELDED ON SC FROM 42.5' TO 53.8' 7/3/2014 hipshkf NOTE: VIEW SCHEMATIC w/9.0 10/16/2008 lmosbor NOTE: MULTI-LATERAL WELL: 1J-102 (A-SAND), 1J-102L1 (B-SAND), 1J-102L2 (D-SAND) 12/27/2007 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 20 19.12 40.0 120.0 120.0 94.00 H-40 Welded SURFACE 10 3/4 9.95 42.5 2,642.8 2,255.0 45.50 L-80 BTC INTERMEDIATE 7 5/8 6.87 40.4 5,920.0 3,741.1 29.70 L-80 BTC-mod D LINER LEM 4 1/2 3.69 4,672.7 4,866.2 3,567.8 12.60 L-80 IBT-mod D LINER HH 4 1/2 3.69 4,727.2 4,984.9 3,591.9 11.60 L-80 Buttress B LINER LEM 4 1/2 3.56 4,836.9 5,191.6 3,632.6 12.75 L-80 B LINER HH 4 1/2 3.69 5,046.1 5,296.0 3,648.4 11.60 L-80 A LINER Slotted 4 1/2 3.48 5,149.7 10,040.4 3,746.2 11.60 L-80 Buttress Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 35.8 Set Depth … 4,707.5 Set Depth … 3,533.0 String Max No… 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L80 Top Connection IBT-mod 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) 35.8 HANGER 10.750 VETCO GRAY TUBING HANGER, Drifted 3.885" Vetc/Gra y MB228 3.900 515.9 513.6 12.36 NIPPLE 5.250 CAMCO DB Nipple 3.875" NO GO PROFILE CAMCO "DB" 3.875" 3.875 2,789.2 2,362.7 41.08 GAS LIFT 6.437 4-1/2" x1" KBGM w/ Dummy, BK-5 latch CAMCO KBMG 3.860 4,486.5 3,458.1 66.91 GAS LIFT 6.437 4-1/2" x1" KBGM w/ Dummy, BK-5 latch CAMCO KBMG 3.860 4,631.5 3,510.8 71.27 SLEEVE-C 5.490 BAKER MODEL CMU. Profile 3.812" CAMCO "DB". (SET3.81'' BAKER ISO SLEEVE ( OAL = 49'' / 2.5'' ID / MID PACKING TO MID PACKING 36'' 10/25/18) Baker 3.81 "DB" profile 2.500 4,679.1 3,525.3 73.50 LOCATOR 5.500 LOCATOR Baker GBH-22 3.990 4,680.8 3,525.8 73.60 SEAL ASSY 4.740 BAKER GBH-22 SEAL ASSEMBLY: Size 192-47. Baker 3.880 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 4,632.0 3,511.0 71.29 LEAKING CMU LEAKING CMU 1/21/2018 0.000 4,958.0 3,586.5 78.48 Retrievable Bridge Plug 343-450 4140 ME Retrievable Bridge Plug S/N: A135070 FN: 3" GS PROFILE 10/25/2018 0.000 5,046.0 3,603.9 78.67 Type 1 ISOSLEEVE Old Style Type 1 ISOSLEEVE across B LAT 4/30/2018 2.500 8,150.0 3,735.3 90.08 FISH LOWER CENTRALIZER, CFS SPINNER, (1.69" OD X 3.7' L) 10/18/2023 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,789.2 2,362.7 41.08 1 GAS LIFT DMY BK-5 1 0.0 10/3/2006 0.000 4,486.5 3,458.1 66.91 2 GAS LIFT DMY BK-5 1 0.0 9/9/2015 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,672.7 3,523.5 73.15 PACKER 6.540 ZXP Liner Top Packer Baker "HRD" ZXP 4.940 4,691.7 3,528.8 74.19 SBR 6.280 109-47 Casing Seal Bore receptacle Baker 4.750 4,711.3 3,534.0 75.26 XO Bushing 5.990 XO Bushing Baker 3.930 4,802.5 3,554.2 77.79 ECP 5.630 PAYZONE EXTERNAL CASING PACKER Baker Oil Tools 3.950 4,836.9 3,561.5 77.72 PACKER 6.800 ZXP Liner Top Packer 5.500 4,856.0 3,565.6 77.75 SBR 6.260 109-47 Casing Seal Bore receptacle 4.750 4,875.7 3,569.8 77.91 XO Bushing 5.500 XO Bushing 4.500 1J-102, 5/3/2024 12:37:14 PM Vertical schematic (actual) A LINER Slotted; 5,149.7- 10,040.4 FISH; 8,150.0 SLOTS; 5,923.0-9,987.0 INTERMEDIATE; 40.4-5,920.0 B LINER HH; 5,046.1-5,296.0 B LINER LEM; 4,836.9-5,191.6 D LINER HH; 4,727.2-4,984.9 Retrievable Bridge Plug; 4,958.0 D LINER LEM; 4,672.7-4,866.2 LEAKING CMU; 4,632.0 GAS LIFT; 4,486.4 GAS LIFT; 2,789.2 SURFACE; 42.5-2,642.8 NIPPLE; 515.9 CONDUCTOR; 40.0-120.0 KUP INJ KB-Grd (ft) 44.29 RR Date 10/4/2006 Other Elev… 1J-102 ... TD Act Btm (ftKB) 11,025.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292331700 Wellbore Status INJ Max Angle & MD Incl (°) 94.25 MD (ftKB) 6,155.17 WELLNAME WELLBORE1J-102 Annotation Last WO: End DateH2S (ppm) 100 Date 8/14/2012 Comment SSSV: NIPPLE Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,081.4 3,611.0 78.47 NIPPLE 5.400 CAMCO "DB" Nipple 3.563 5,118.4 3,618.4 78.27 ECP 6.800 Baker Payzone External Csg PKR 4.500 5,149.7 3,624.8 78.64 PACKER 7.600 "HRD" Liner top packer Baker Oil Tools 5.500 5,168.6 3,628.4 79.20 NIPPLE 6.060 "RS" Packoff Seal Nipple Baker Oil Tools 4.870 5,200.1 3,634.0 80.15 XO BUSHING 5.960 Cross Over Bushing 3.930 9,993.7 3,745.8 89.36 ECP 4.500 Swell Packer Rubber Element Easy Well Solutions 3.476 10,007.9 3,745.9 89.35 XO thread 4.500 Cross Over 3.500 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,923.0 9,987.0 3,741.5 3,745.7 WS A2, WS A3, 1J-102 9/10/2006 32.0 SLOTS All Perfs in this well: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferencial adjacent rows, 3" centers staggered 18 degrees, 3' non-slotted ends 1J-102, 5/3/2024 12:37:15 PM Vertical schematic (actual) A LINER Slotted; 5,149.7- 10,040.4 FISH; 8,150.0 SLOTS; 5,923.0-9,987.0 INTERMEDIATE; 40.4-5,920.0 B LINER HH; 5,046.1-5,296.0 B LINER LEM; 4,836.9-5,191.6 D LINER HH; 4,727.2-4,984.9 Retrievable Bridge Plug; 4,958.0 D LINER LEM; 4,672.7-4,866.2 LEAKING CMU; 4,632.0 GAS LIFT; 4,486.4 GAS LIFT; 2,789.2 SURFACE; 42.5-2,642.8 NIPPLE; 515.9 CONDUCTOR; 40.0-120.0 KUP INJ 1J-102 ... WELLNAME WELLBORE1J-102 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-102L1 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: QC 1J-102L1 10/26/2015 smsmith Notes: General & Safety Annotation End Date Last Mod By NOTE: EXTERNAL SLEEVE (.500 X 65) WELDED ON SC FROM 42.5' TO 53.8' 7/3/2014 hipshkf NOTE: VIEW SCHEMATIC w/9.0 10/16/2008 lmosbor NOTE: MULTI-LATERAL WELL: 1J-102 (A-SAND), 1J-102L1 (B-SAND), 1J-102L2 (D-SAND) 10/6/2006 triplwj 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 5,244.9 12,093.4 3,585.2 11.60 L-80 Buttress Thread Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,244.9 3,607.4 93.51 SLEEVE 6.410 Baker HR Liner setting sleeve 5.750 5,303.1 3,604.1 92.97 XO BUSHING 5.500 Hydril 521 XO Joint 3.960 12,058.5 3,584.7 88.77 xo thread 4.500 Cross Over Joint USS 3.476 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,308.0 12,058.0 3,603.9 3,584.7 WS B, WS C, 1J -102L1 9/22/2006 32.0 SLOTS All Perfs in this well: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferencial adjacent rows, 3" centers staggered 18 degrees, 3' non-slotted ends 5,328.0 5,333.0 3,603.0 3,602.7 WS A2, WS A3, 1J-102 9/2/2015 6.0 IPERF 2in Powerflow HSD, 2006FP, 6SPF 1J-102L1, 5/3/2024 12:37:16 PM Vertical schematic (actual) B LINER Slotted; 5,244.8- 12,093.4 SLOTS; 5,308.0-12,058.0 IPERF; 5,328.0-5,333.0 INTERMEDIATE; 40.4-5,920.0 B LINER HH; 5,046.1-5,296.0 B LINER LEM; 4,836.9-5,191.6 D LINER HH; 4,727.2-4,984.9 Retrievable Bridge Plug; 4,958.0 D LINER LEM; 4,672.7-4,866.2 LEAKING CMU; 4,632.0 GAS LIFT; 4,486.4 GAS LIFT; 2,789.2 SURFACE; 42.5-2,642.8 NIPPLE; 515.9 CONDUCTOR; 40.0-120.0 KUP INJ KB-Grd (ft) 44.29 RR Date 10/4/2006 Other Elev… 1J-102L1 ... TD Act Btm (ftKB) 12,242.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292331760 Wellbore Status INJ Max Angle & MD Incl (°) 94.63 MD (ftKB) 10,743.74 WELLNAME WELLBORE1J-102 Annotation Last WO: End DateH2S (ppm) 100 Date 8/14/2012 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-102L2 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: ADDED FISH TO D-LAT, PUSHED TO 8150' 1J-102L2 10/18/2023 condijw Notes: General & Safety Annotation End Date Last Mod By NOTE: EXTERNAL SLEEVE (.500 X 65) WELDED ON SC FROM 42.5' TO 53.8' 7/3/2014 hipshkf NOTE: VIEW SCHEMATIC w/9.0 10/16/2008 lmosbor NOTE: MULTI-LATERAL WELL: 1J-102 (A-SAND), 1J-102L1 (B-SAND), 1J-102L2 (D-SAND) 10/6/2006 triplwj 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 4,936.9 12,081.3 3,501.3 11.60 L-80 Buttress Thread 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) 5,040.0 FISH BOTTOM PORTION OF MEMORY TOOL 4/23/2008 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,936.9 SLEEVE 6.410 "HR" Liner setting sleeve w/ 10' TBR Baker Oil Tools 5.750 4,994.8 XO Bushing 5.500 Cross Over Bushing 3.930 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,254.0 12,042.0 3,501.9 WS D, 1J-102L2 9/30/2006 32.0 SLOTS All Perfs in this well: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferencial adjacent rows, 3" centers staggered 18 degrees, 3' non-slotted ends 1J-102L2, 5/3/2024 12:37:17 PM Vertical schematic (actual) D LINER Slotted; 4,936.9- 12,081.3 SLOTS; 5,254.0-12,042.0 FISH; 5,040.0 INTERMEDIATE; 40.4-5,920.0 D LINER HH; 4,727.2-4,984.9 D LINER LEM; 4,672.7-4,866.2 LEAKING CMU; 4,632.0 GAS LIFT; 4,486.4 GAS LIFT; 2,789.2 SURFACE; 42.5-2,642.8 NIPPLE; 515.9 CONDUCTOR; 40.0-120.0 KUP INJ KB-Grd (ft) 44.29 RR Date 10/4/2006 Other Elev… 1J-102L2 ... TD Act Btm (ftKB) 12,095.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292331761 Wellbore Status INJ Max Angle & MD Incl (°) 93.92 MD (ftKB) 10,739.95 WELLNAME WELLBORE1J-102 Annotation Last WO: End DateH2S (ppm) 100 Date 8/14/2012 Comment SSSV: NIPPLE 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: RPPG Pumping Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 12095'feet None feet true vertical 3501' feet 5040' feet Effective Depth measured 12095'feet 4673', 4681'feet true vertical 3501' feet 3524', 3526' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 4707' MD 3533' TVD Packers and SSSV (type, measured and true vertical depth) 4673' MD 4681' MD N/A 3524' TVD 3526' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: West Sak Oil Pool 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 Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 2643' 2255' Burst Collapse Production D Sand Liner 5880' 7144' Casing 3741' 4-1/2" 5920' 12081' 3501' 2600' 120'Conductor Surface Intermediate 20' 10-3/4" 80' measured TVD 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 206-112 50-029-23317-61-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025661, ADL0025662 Kuparuk River Field/ West Sak Oil Pool KRU 1J-102L2 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 120' ~ ~~ INJECTOR ~~ ~ N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: ZXP Liner Top Packer Packer: Baker GBH-22 Seal Assembly SSSV: None Allen Eschete allen.eschete@conocophillips.com (907) 265-6558Interventions Engineer Alterenating Slotted Liner: 5254-12042' Alternating Slotted Liner: XXX-3502' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:12 pm, Dec 04, 2023 Digitally signed by Allen Eschete DN: CN=Allen Eschete, E=Allen.Eschete@ ConocoPhillips.com Reason: I am the author of this document Location: Date: 2023.12.04 14:59:12-09'00' Foxit PDF Editor Version: 13.0.0 Allen Eschete DTTMSTART JOBTYP SUMMARYOPS 11/2/2023 REPAIR WELL RPPG FULLBORE PUMP JOB PUMPED 293 BBLS OF 2%KCL SLURRY w/ 7920 LBS OF RPPG @ 0.75 PPG TO MBE @ ~5620' RKB IN THE D SAND LATERAL. CALLED FLUSH @ 869 PSI. FINAL TREATING PRESSURE AT THE END OF FLUSH WAS 1093 PSI. WELL TO REMAIN SHUT IN FOR 48 HOURS. 1J-102 RPPG Treatment Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1J-102 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Interwell Plug and CMU ISO sleeve 1J-102 10/25/2018 aappleh Notes: General & Safety Annotation End Date Last Mod By NOTE: Crystal Seal slurry @ average 0.27 ppg concentration 4/26/2016 pproven NOTE: FullBore Crystal Seal B MBE treatment. Placed 2970# of 1-2-4 mesh 4/26/2016 pproven NOTE: concentration of 0.28 ppg 11/14/2015 pproven NOTE: FullBore MBE treatment per design Placed 2310# of 1-2-4 mesh Crystal Seal slurry 11/14/2015 pproven NOTE: FullBore MBE treatment per design placing ~290 bbls 3% KCL / 4 mil Crystal Seal slurry 9/18/2015 pproven NOTE: into formation (3795# of CS) 9/18/2015 pproven NOTE: EXTERNAL SLEEVE (.500 X 65) WELDED ON SC FROM 42.5' TO 53.8' 7/3/2014 hipshkf NOTE: VIEW SCHEMATIC w/9.0 10/16/2008 lmosbor NOTE: MULTI-LATERAL WELL: 1J-102 (A-SAND), 1J-102L1 (B-SAND), 1J-102L2 (D-SAND) 12/27/2007 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 20 19.12 40.0 120.0 120.0 94.00 H-40 Welded SURFACE 10 3/4 9.95 42.5 2,642.8 2,255.0 45.50 L-80 BTC INTERMEDIATE 7 5/8 6.87 40.4 5,920.0 3,741.1 29.70 L-80 BTC-mod D LINER LEM 4 1/2 3.69 4,672.7 4,866.2 3,567.8 12.60 L-80 IBT-mod D LINER HH 4 1/2 3.69 4,727.2 4,984.9 3,591.9 11.60 L-80 Buttress B LINER LEM 4 1/2 3.56 4,836.9 5,191.6 3,632.6 12.75 L-80 B LINER HH 4 1/2 3.69 5,046.1 5,296.0 3,648.4 11.60 L-80 A LINER Slotted 4 1/2 3.48 5,149.7 10,040.4 3,746.2 11.60 L-80 Buttress Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 35.8 Set Depth 4,707.5 Set Depth 3,533.0 String Ma 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L80 Top Connection IBT-mod 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) 35.8 HANGER 10.750 VETCO GRAY TUBING HANGER, Drifted 3.885" Vetc/Gra y MB228 3.900 515.9 513.6 12.36 NIPPLE 5.250 CAMCO DB Nipple 3.875" NO GO PROFILE CAMCO "DB" 3.875" 3.875 2,789.2 2,362.7 41.08 GAS LIFT 6.437 4-1/2" x1" KBGM w/ Dummy, BK-5 latch CAMCO KBMG 3.860 4,486.5 3,458.1 66.91 GAS LIFT 6.437 4-1/2" x1" KBGM w/ Dummy, BK-5 latch CAMCO KBMG 3.860 4,631.5 3,510.8 71.27 SLEEVE-C 5.490 BAKER MODEL CMU. Profile 3.812" CAMCO "DB". (SET3.81'' BAKER ISO SLEEVE ( OAL = 49'' / 2.5'' ID / MID PACKING TO MID PACKING 36'' 10/25/18) Baker 3.81 "DB" profile 2.500 4,679.1 3,525.3 73.50 LOCATOR 5.500 LOCATOR Baker GBH-22 3.990 4,680.8 3,525.8 73.60 SEAL ASSY 4.740 BAKER GBH-22 SEAL ASSEMBLY: Size 192-47. Baker 3.880 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 4,632.0 3,511.0 71.29 LEAKING CMU LEAKING CMU 1/21/2018 0.000 4,958.0 3,586.5 78.48 Retrievable Bridge Plug 343-450 4140 ME Retrievable Bridge Plug S/N: A135070 FN: 3" GS PROFILE 10/25/2018 0.000 5,046.0 3,603.9 78.67 Type 1 ISOSLEEVE Old Style Type 1 ISOSLEEVE across B LAT 4/30/2018 2.500 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,789.2 2,362.7 41.08 1 GAS LIFT DMY BK-5 1 0.0 10/3/2006 0.000 4,486.5 3,458.1 66.91 2 GAS LIFT DMY BK-5 1 0.0 9/9/2015 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,672.7 3,523.5 73.15 PACKER 6.540 ZXP Liner Top Packer Baker "HRD" ZXP 4.940 4,691.7 3,528.8 74.19 SBR 6.280 109-47 Casing Seal Bore receptacle Baker 4.750 4,711.3 3,534.0 75.26 XO Bushing 5.990 XO Bushing Baker 3.930 4,802.5 3,554.2 77.79 ECP 5.630 PAYZONE EXTERNAL CASING PACKER Baker Oil Tools 3.950 4,836.9 3,561.5 77.72 PACKER 6.800 ZXP Liner Top Packer 5.500 4,856.0 3,565.6 77.75 SBR 6.260 109-47 Casing Seal Bore receptacle 4.750 4,875.7 3,569.8 77.91 XO Bushing 5.500 XO Bushing 4.500 5,081.4 3,611.0 78.47 NIPPLE 5.400 CAMCO "DB" Nipple 3.563 5,118.4 3,618.4 78.27 ECP 6.800 Baker Payzone External Csg PKR 4.500 1J-102, 7/26/2023 1:16:21 PM Vertical schematic (actual) A LINER Slotted; 5,149.7- 10,040.4 SLOTS; 5,923.0-9,987.0 INTERMEDIATE; 40.4-5,920.0 B LINER HH; 5,046.1-5,296.0 B LINER LEM; 4,836.9-5,191.6 D LINER HH; 4,727.2-4,984.9 Retrievable Bridge Plug; 4,958.0 D LINER LEM; 4,672.7-4,866.2 LEAKING CMU; 4,632.0 GAS LIFT; 4,486.4 GAS LIFT; 2,789.2 SURFACE; 42.5-2,642.8 NIPPLE; 515.9 CONDUCTOR; 40.0-120.0 KUP INJ KB-Grd (ft) 44.29 RR Date 10/4/2006 Other Elev 1J-102 ... TD Act Btm (ftKB) 11,025.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292331700 Wellbore Status INJ Max Angle & MD Incl (°) 94.25 MD (ftKB) 6,155.17 WELLNAME WELLBORE1J-102 Annotation Last WO: End DateH2S (ppm) 100 Date 8/14/2012 Comment SSSV: NIPPLE Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,149.7 3,624.8 78.64 PACKER 7.600 "HRD" Liner top packer Baker Oil Tools 5.500 5,168.6 3,628.4 79.20 NIPPLE 6.060 "RS" Packoff Seal Nipple Baker Oil Tools 4.870 5,200.1 3,634.0 80.15 XO BUSHING 5.960 Cross Over Bushing 3.930 9,993.7 3,745.8 89.36 ECP 4.500 Swell Packer Rubber Element Easy Well Solutions 3.476 10,007.9 3,745.9 89.35 XO thread 4.500 Cross Over 3.500 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,923.0 9,987.0 3,741.5 3,745.7 WS A2, WS A3, 1J-102 9/10/2006 32.0 SLOTS All Perfs in this well: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferencial adjacent rows, 3" centers staggered 18 degrees, 3' non-slotted ends 1J-102, 7/26/2023 1:16:22 PM Vertical schematic (actual) A LINER Slotted; 5,149.7- 10,040.4 SLOTS; 5,923.0-9,987.0 INTERMEDIATE; 40.4-5,920.0 B LINER HH; 5,046.1-5,296.0 B LINER LEM; 4,836.9-5,191.6 D LINER HH; 4,727.2-4,984.9 Retrievable Bridge Plug; 4,958.0 D LINER LEM; 4,672.7-4,866.2 LEAKING CMU; 4,632.0 GAS LIFT; 4,486.4 GAS LIFT; 2,789.2 SURFACE; 42.5-2,642.8 NIPPLE; 515.9 CONDUCTOR; 40.0-120.0 KUP INJ 1J-102 ... WELLNAME WELLBORE1J-102 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1J-102L1 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: QC 1J-102L1 10/26/2015 smsmith Notes: General & Safety Annotation End Date Last Mod By NOTE: EXTERNAL SLEEVE (.500 X 65) WELDED ON SC FROM 42.5' TO 53.8' 7/3/2014 hipshkf NOTE: VIEW SCHEMATIC w/9.0 10/16/2008 lmosbor NOTE: MULTI-LATERAL WELL: 1J-102 (A-SAND), 1J-102L1 (B-SAND), 1J-102L2 (D-SAND) 10/6/2006 triplwj 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 5,244.9 12,093.4 3,585.2 11.60 L-80 Buttress Thread Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,244.9 3,607.4 93.51 SLEEVE 6.410 Baker HR Liner setting sleeve 5.750 5,303.1 3,604.1 92.97 XO BUSHING 5.500 Hydril 521 XO Joint 3.960 12,058.5 3,584.7 88.77 xo thread 4.500 Cross Over Joint USS 3.476 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,308.0 12,058.0 3,603.9 3,584.7 WS B, WS C, 1J -102L1 9/22/2006 32.0 SLOTS All Perfs in this well: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferencial adjacent rows, 3" centers staggered 18 degrees, 3' non-slotted ends 5,328.0 5,333.0 3,603.0 3,602.7 WS A2, WS A3, 1J-102 9/2/2015 6.0 IPERF 2in Powerflow HSD, 2006FP, 6SPF 1J-102L1, 7/26/2023 1:16:23 PM Vertical schematic (actual) B LINER Slotted; 5,244.8- 12,093.4 SLOTS; 5,308.0-12,058.0 IPERF; 5,328.0-5,333.0 INTERMEDIATE; 40.4-5,920.0 B LINER HH; 5,046.1-5,296.0 B LINER LEM; 4,836.9-5,191.6 D LINER HH; 4,727.2-4,984.9 Retrievable Bridge Plug; 4,958.0 D LINER LEM; 4,672.7-4,866.2 LEAKING CMU; 4,632.0 GAS LIFT; 4,486.4 GAS LIFT; 2,789.2 SURFACE; 42.5-2,642.8 NIPPLE; 515.9 CONDUCTOR; 40.0-120.0 KUP INJ KB-Grd (ft) 44.29 RR Date 10/4/2006 Other Elev 1J-102L1 ... TD Act Btm (ftKB) 12,242.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292331760 Wellbore Status INJ Max Angle & MD Incl (°) 94.63 MD (ftKB) 10,743.74 WELLNAME WELLBORE1J-102 Annotation Last WO: End DateH2S (ppm) 100 Date 8/14/2012 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1J-102L2 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: QC 1J-102L2 10/26/2015 smsmith Notes: General & Safety Annotation End Date Last Mod By NOTE: EXTERNAL SLEEVE (.500 X 65) WELDED ON SC FROM 42.5' TO 53.8' 7/3/2014 hipshkf NOTE: VIEW SCHEMATIC w/9.0 10/16/2008 lmosbor NOTE: MULTI-LATERAL WELL: 1J-102 (A-SAND), 1J-102L1 (B-SAND), 1J-102L2 (D-SAND) 10/6/2006 triplwj 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 4,936.9 12,081.3 3,501.3 11.60 L-80 Buttress Thread 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) 5,040.0 FISH BOTTOM PORTION OF MEMORY TOOL 4/23/2008 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,936.9 SLEEVE 6.410 "HR" Liner setting sleeve w/ 10' TBR Baker Oil Tools 5.750 4,994.8 XO Bushing 5.500 Cross Over Bushing 3.930 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,254.0 12,042.0 3,501.9 WS D, 1J-102L2 9/30/2006 32.0 SLOTS All Perfs in this well: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferencial adjacent rows, 3" centers staggered 18 degrees, 3' non-slotted ends 1J-102L2, 7/26/2023 1:16:23 PM Vertical schematic (actual) D LINER Slotted; 4,936.9- 12,081.3 SLOTS; 5,254.0-12,042.0 FISH; 5,040.0 INTERMEDIATE; 40.4-5,920.0 D LINER HH; 4,727.2-4,984.9 D LINER LEM; 4,672.7-4,866.2 LEAKING CMU; 4,632.0 GAS LIFT; 4,486.4 GAS LIFT; 2,789.2 SURFACE; 42.5-2,642.8 NIPPLE; 515.9 CONDUCTOR; 40.0-120.0 KUP INJ KB-Grd (ft) 44.29 RR Date 10/4/2006 Other Elev 1J-102L2 ... TD Act Btm (ftKB) 12,095.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292331761 Wellbore Status INJ Max Angle & MD Incl (°) 93.92 MD (ftKB) 10,739.95 WELLNAME WELLBORE1J-102 Annotation Last WO: End DateH2S (ppm) 100 Date 8/14/2012 Comment SSSV: NIPPLE Operations shutdownPull TubingFracture StimulatePlug PerforationsSusp Well Insp1. Operations Change Approved ProgramAlter CasingOther StimulatePerforateInstall WhipstockPerformed: Other: RPPG PumpingCoiled Tubing OpsRepair WellPerforate New PoolMod Artificial Lift ExploratoryDevelopment 6. API Number:ServiceStratigraphic 8. Well Name and Number:7. Property Designation (Lease Number): 10. Field/Pool(s):9. Logs (List logs and submit electronic data per 20AAC25.071): 11. Present Well Condition Summary: measuredTotal Depth 12095'feet feet feetfeet3501'true vertical measuredEffective Depth 12095'feet feet feetfeet3501'true vertical Measured depthPerforation depth True Vertical depth 4707' MDL-804-1/2"Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/ATreatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: West Sak Oil Pool13b. Pools active after work: 15. Well Class after work: StratigraphicServiceExploratory DevelopmentDaily Report of Well Operations WDSPLGasOil16. Well Status after work:Copies of Logs and Surveys Run SPLUGSUSPGINJGSTORElectronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: Authorized Name and Contact Name:Digital Signature with Date: Contact Email: Contact Phone:Authorized Title: N/A Sr Res Eng:Sr Pet Geo:Sr Pet Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Allen Eschete allen.eschete@conocophillips.com (907) 265-6558Interventions Engineer measured true vertical Packer Representative Daily Average Production or Injection Data Tubing PressureCasing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 120' ~~~ INJECTOR ~~ ~ measured TVD 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 206-112 50-029-23317-61-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025661, ADL0025662 Kuparuk River Field/ West Sak Oil Pool KRU 1J-102L2 Plugs measuredJunk Length Production D Sand Liner 5880' 7144' Casing 3741' 4-1/2" 5920' 3501'12081' 2600' 120'Conductor Surface Intermediate 20' 10-3/4" 80' 2255'2643' CollapseBurst Submit in PDF format to aogcc.permitting@alaska.govDue Within 30 days of OperationsForm 10-404 Revised 10/2022 Alterenating Slotted Liner: 5254-12042' Alternating Slotted Liner: 3564-3502' None 5040' 4673',4681' 3524',3526' Packer: ZXP Liner Top Packer Packer: Baker GBH-22 Seal Assembly SSSV: None 4673' MD 4681' MD N/A 3533' TVD 3524' TVD 3526' TVD N/A By Grace Christianson at 3:08 pm, Aug 14, 2023 Digitally signed by Allen Eschete DN: CN=Allen Eschete, E=Allen.Eschete@ ConocoPhillips.com Reason: I have reviewed this document Location: Date: 2023.08.14 09:29:08-08'00' Foxit PDF Editor Version: 12.1.2 Allen Eschete DTTMSTART JOBTYP SUMMARYOPS 7/14/2023 ACQUIRE DATA (AC EVAL) MIT IA TO 2000 PSI (PASSED), IA DDT TO 500 PSI (PASSED) 7/17/2023 ACQUIRE DATA SLB E-LINE: MBE SUSPECTED @ ~5800' IN D SAND LATERAL, OBJECTIVE TO RIH AS DEEP AS POSSIBLE AND RECORD PRESSURE AND TEMPERATURE WHILE RPPG JOB PUMPED TO SEAL OFF THE MBE BETWEEN 1J-102 AND 1J-159. HALLIBURTON PUMPED 180 BAGS-> 7920# RPPG, MAX RATE 3.8 BPM, MAX PSI 1423, TOTAL CLEAN VOLUME PUMPED 388.6 BBL 7/18/2023 ACQUIRE DATA SLB E-LINE: MBE SUSPECTED @ ~5800' IN D SAND LATERAL, OBJECTIVE TO RIH AS DEEP AS POSSIBLE AND RECORD PRESSURE AND TEMPERATURE WHILE RPPG JOB PUMPED TO SEAL OFF THE MBE BETWEEN 1J-102 AND 1J-159. 1J-102/ 1J-159 RPPG MBE Treatment Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1J-102 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Interwell Plug and CMU ISO sleeve 1J-102 10/25/2018 aappleh Notes: General & Safety Annotation End Date Last Mod By NOTE: Crystal Seal slurry @ average 0.27 ppg concentration 4/26/2016 pproven NOTE: FullBore Crystal Seal B MBE treatment. Placed 2970# of 1-2-4 mesh 4/26/2016 pproven NOTE: concentration of 0.28 ppg 11/14/2015 pproven NOTE: FullBore MBE treatment per design Placed 2310# of 1-2-4 mesh Crystal Seal slurry 11/14/2015 pproven NOTE: FullBore MBE treatment per design placing ~290 bbls 3% KCL / 4 mil Crystal Seal slurry 9/18/2015 pproven NOTE: into formation (3795# of CS) 9/18/2015 pproven NOTE: EXTERNAL SLEEVE (.500 X 65) WELDED ON SC FROM 42.5' TO 53.8' 7/3/2014 hipshkf NOTE: VIEW SCHEMATIC w/9.0 10/16/2008 lmosbor NOTE: MULTI-LATERAL WELL: 1J-102 (A-SAND), 1J-102L1 (B-SAND), 1J-102L2 (D-SAND) 12/27/2007 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 20 19.12 40.0 120.0 120.0 94.00 H-40 Welded SURFACE 10 3/4 9.95 42.5 2,642.8 2,255.0 45.50 L-80 BTC INTERMEDIATE 7 5/8 6.87 40.4 5,920.0 3,741.1 29.70 L-80 BTC-mod D LINER LEM 4 1/2 3.69 4,672.7 4,866.2 3,567.8 12.60 L-80 IBT-mod D LINER HH 4 1/2 3.69 4,727.2 4,984.9 3,591.9 11.60 L-80 Buttress B LINER LEM 4 1/2 3.56 4,836.9 5,191.6 3,632.6 12.75 L-80 B LINER HH 4 1/2 3.69 5,046.1 5,296.0 3,648.4 11.60 L-80 A LINER Slotted 4 1/2 3.48 5,149.7 10,040.4 3,746.2 11.60 L-80 Buttress Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 35.8 Set Depth 4,707.5 Set Depth 3,533.0 String Ma 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L80 Top Connection IBT-mod 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) 35.8 HANGER 10.750 VETCO GRAY TUBING HANGER, Drifted 3.885" Vetc/Gra y MB228 3.900 515.9 513.6 12.36 NIPPLE 5.250 CAMCO DB Nipple 3.875" NO GO PROFILE CAMCO "DB" 3.875" 3.875 2,789.2 2,362.7 41.08 GAS LIFT 6.437 4-1/2" x1" KBGM w/ Dummy, BK-5 latch CAMCO KBMG 3.860 4,486.5 3,458.1 66.91 GAS LIFT 6.437 4-1/2" x1" KBGM w/ Dummy, BK-5 latch CAMCO KBMG 3.860 4,631.5 3,510.8 71.27 SLEEVE-C 5.490 BAKER MODEL CMU. Profile 3.812" CAMCO "DB". (SET3.81'' BAKER ISO SLEEVE ( OAL = 49'' / 2.5'' ID / MID PACKING TO MID PACKING 36'' 10/25/18) Baker 3.81 "DB" profile 2.500 4,679.1 3,525.3 73.50 LOCATOR 5.500 LOCATOR Baker GBH-22 3.990 4,680.8 3,525.8 73.60 SEAL ASSY 4.740 BAKER GBH-22 SEAL ASSEMBLY: Size 192-47. Baker 3.880 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 4,632.0 3,511.0 71.29 LEAKING CMU LEAKING CMU 1/21/2018 0.000 4,958.0 3,586.5 78.48 Retrievable Bridge Plug 343-450 4140 ME Retrievable Bridge Plug S/N: A135070 FN: 3" GS PROFILE 10/25/2018 0.000 5,046.0 3,603.9 78.67 Type 1 ISOSLEEVE Old Style Type 1 ISOSLEEVE across B LAT 4/30/2018 2.500 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,789.2 2,362.7 41.08 1 GAS LIFT DMY BK-5 1 0.0 10/3/2006 0.000 4,486.5 3,458.1 66.91 2 GAS LIFT DMY BK-5 1 0.0 9/9/2015 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,672.7 3,523.5 73.15 PACKER 6.540 ZXP Liner Top Packer Baker "HRD" ZXP 4.940 4,691.7 3,528.8 74.19 SBR 6.280 109-47 Casing Seal Bore receptacle Baker 4.750 4,711.3 3,534.0 75.26 XO Bushing 5.990 XO Bushing Baker 3.930 4,802.5 3,554.2 77.79 ECP 5.630 PAYZONE EXTERNAL CASING PACKER Baker Oil Tools 3.950 4,836.9 3,561.5 77.72 PACKER 6.800 ZXP Liner Top Packer 5.500 4,856.0 3,565.6 77.75 SBR 6.260 109-47 Casing Seal Bore receptacle 4.750 4,875.7 3,569.8 77.91 XO Bushing 5.500 XO Bushing 4.500 5,081.4 3,611.0 78.47 NIPPLE 5.400 CAMCO "DB" Nipple 3.563 5,118.4 3,618.4 78.27 ECP 6.800 Baker Payzone External Csg PKR 4.500 1J-102, 7/26/2023 1:16:21 PM Vertical schematic (actual) A LINER Slotted; 5,149.7- 10,040.4 SLOTS; 5,923.0-9,987.0 INTERMEDIATE; 40.4-5,920.0 B LINER HH; 5,046.1-5,296.0 B LINER LEM; 4,836.9-5,191.6 D LINER HH; 4,727.2-4,984.9 Retrievable Bridge Plug; 4,958.0 D LINER LEM; 4,672.7-4,866.2 LEAKING CMU; 4,632.0 GAS LIFT; 4,486.4 GAS LIFT; 2,789.2 SURFACE; 42.5-2,642.8 NIPPLE; 515.9 CONDUCTOR; 40.0-120.0 KUP INJ KB-Grd (ft) 44.29 RR Date 10/4/2006 Other Elev 1J-102 ... TD Act Btm (ftKB) 11,025.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292331700 Wellbore Status INJ Max Angle & MD Incl (°) 94.25 MD (ftKB) 6,155.17 WELLNAME WELLBORE1J-102 Annotation Last WO: End DateH2S (ppm) 100 Date 8/14/2012 Comment SSSV: NIPPLE Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,149.7 3,624.8 78.64 PACKER 7.600 "HRD" Liner top packer Baker Oil Tools 5.500 5,168.6 3,628.4 79.20 NIPPLE 6.060 "RS" Packoff Seal Nipple Baker Oil Tools 4.870 5,200.1 3,634.0 80.15 XO BUSHING 5.960 Cross Over Bushing 3.930 9,993.7 3,745.8 89.36 ECP 4.500 Swell Packer Rubber Element Easy Well Solutions 3.476 10,007.9 3,745.9 89.35 XO thread 4.500 Cross Over 3.500 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,923.0 9,987.0 3,741.5 3,745.7 WS A2, WS A3, 1J-102 9/10/2006 32.0 SLOTS All Perfs in this well: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferencial adjacent rows, 3" centers staggered 18 degrees, 3' non-slotted ends 1J-102, 7/26/2023 1:16:22 PM Vertical schematic (actual) A LINER Slotted; 5,149.7- 10,040.4 SLOTS; 5,923.0-9,987.0 INTERMEDIATE; 40.4-5,920.0 B LINER HH; 5,046.1-5,296.0 B LINER LEM; 4,836.9-5,191.6 D LINER HH; 4,727.2-4,984.9 Retrievable Bridge Plug; 4,958.0 D LINER LEM; 4,672.7-4,866.2 LEAKING CMU; 4,632.0 GAS LIFT; 4,486.4 GAS LIFT; 2,789.2 SURFACE; 42.5-2,642.8 NIPPLE; 515.9 CONDUCTOR; 40.0-120.0 KUP INJ 1J-102 ... WELLNAME WELLBORE1J-102 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1J-102L1 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: QC 1J-102L1 10/26/2015 smsmith Notes: General & Safety Annotation End Date Last Mod By NOTE: EXTERNAL SLEEVE (.500 X 65) WELDED ON SC FROM 42.5' TO 53.8' 7/3/2014 hipshkf NOTE: VIEW SCHEMATIC w/9.0 10/16/2008 lmosbor NOTE: MULTI-LATERAL WELL: 1J-102 (A-SAND), 1J-102L1 (B-SAND), 1J-102L2 (D-SAND) 10/6/2006 triplwj 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 5,244.9 12,093.4 3,585.2 11.60 L-80 Buttress Thread Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,244.9 3,607.4 93.51 SLEEVE 6.410 Baker HR Liner setting sleeve 5.750 5,303.1 3,604.1 92.97 XO BUSHING 5.500 Hydril 521 XO Joint 3.960 12,058.5 3,584.7 88.77 xo thread 4.500 Cross Over Joint USS 3.476 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,308.0 12,058.0 3,603.9 3,584.7 WS B, WS C, 1J -102L1 9/22/2006 32.0 SLOTS All Perfs in this well: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferencial adjacent rows, 3" centers staggered 18 degrees, 3' non-slotted ends 5,328.0 5,333.0 3,603.0 3,602.7 WS A2, WS A3, 1J-102 9/2/2015 6.0 IPERF 2in Powerflow HSD, 2006FP, 6SPF 1J-102L1, 7/26/2023 1:16:23 PM Vertical schematic (actual) B LINER Slotted; 5,244.8- 12,093.4 SLOTS; 5,308.0-12,058.0 IPERF; 5,328.0-5,333.0 INTERMEDIATE; 40.4-5,920.0 B LINER HH; 5,046.1-5,296.0 B LINER LEM; 4,836.9-5,191.6 D LINER HH; 4,727.2-4,984.9 Retrievable Bridge Plug; 4,958.0 D LINER LEM; 4,672.7-4,866.2 LEAKING CMU; 4,632.0 GAS LIFT; 4,486.4 GAS LIFT; 2,789.2 SURFACE; 42.5-2,642.8 NIPPLE; 515.9 CONDUCTOR; 40.0-120.0 KUP INJ KB-Grd (ft) 44.29 RR Date 10/4/2006 Other Elev 1J-102L1 ... TD Act Btm (ftKB) 12,242.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292331760 Wellbore Status INJ Max Angle & MD Incl (°) 94.63 MD (ftKB) 10,743.74 WELLNAME WELLBORE1J-102 Annotation Last WO: End DateH2S (ppm) 100 Date 8/14/2012 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1J-102L2 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: QC 1J-102L2 10/26/2015 smsmith Notes: General & Safety Annotation End Date Last Mod By NOTE: EXTERNAL SLEEVE (.500 X 65) WELDED ON SC FROM 42.5' TO 53.8' 7/3/2014 hipshkf NOTE: VIEW SCHEMATIC w/9.0 10/16/2008 lmosbor NOTE: MULTI-LATERAL WELL: 1J-102 (A-SAND), 1J-102L1 (B-SAND), 1J-102L2 (D-SAND) 10/6/2006 triplwj 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 4,936.9 12,081.3 3,501.3 11.60 L-80 Buttress Thread 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) 5,040.0 FISH BOTTOM PORTION OF MEMORY TOOL 4/23/2008 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,936.9 SLEEVE 6.410 "HR" Liner setting sleeve w/ 10' TBR Baker Oil Tools 5.750 4,994.8 XO Bushing 5.500 Cross Over Bushing 3.930 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,254.0 12,042.0 3,501.9 WS D, 1J-102L2 9/30/2006 32.0 SLOTS All Perfs in this well: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferencial adjacent rows, 3" centers staggered 18 degrees, 3' non-slotted ends 1J-102L2, 7/26/2023 1:16:23 PM Vertical schematic (actual) D LINER Slotted; 4,936.9- 12,081.3 SLOTS; 5,254.0-12,042.0 FISH; 5,040.0 INTERMEDIATE; 40.4-5,920.0 D LINER HH; 4,727.2-4,984.9 D LINER LEM; 4,672.7-4,866.2 LEAKING CMU; 4,632.0 GAS LIFT; 4,486.4 GAS LIFT; 2,789.2 SURFACE; 42.5-2,642.8 NIPPLE; 515.9 CONDUCTOR; 40.0-120.0 KUP INJ KB-Grd (ft) 44.29 RR Date 10/4/2006 Other Elev 1J-102L2 ... TD Act Btm (ftKB) 12,095.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292331761 Wellbore Status INJ Max Angle & MD Incl (°) 93.92 MD (ftKB) 10,739.95 WELLNAME WELLBORE1J-102 Annotation Last WO: End DateH2S (ppm) 100 Date 8/14/2012 Comment SSSV: NIPPLE • K 101._41. • P 41- P I11- Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.co Sent: Tuesday, August 30, 2016 7:58 AM 0(. 01 (Co To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr; Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Haakinson, David; Braden, John C Subject: Defeated LPP/SSV on CPAI well 1J-102 Jim, The low pressure pilot(LPP) on well 1J-102 (PTD#206-1 tO, 206-111, X 06-112 as defeated today, 8/30/16, after the well was returned to water injection service following the CPF-1 facility shut .own. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the"Facility Defeated Safe Device Log." The well is currently injecting 1100 BWPD at a wellhead injectionpressure of 15 psig. The AOGCC will be notified when the injection pressure has increased to above 100 psig and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Kind Regards, Scott Stanley / David Haakinson West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com a JAN 2 7 2017 1 • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q~ Q ~ - ~ ~ ~ Well History File Identifier Organizing (done> RES AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: ~ Maria _ Project Proofing BY: Maria _ Scanning Preparation BY: Maria „~o.,cea iuummiuiuu DIGITAL .DATA iskettes, No.3 ^ Other, No/Type: Date: Date: a~~a,~ee~e~ iiiiiiiii~iiiiuii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: /s/ iuuiuuuwiim v mP x 30 = 1,5D Date: + _~ =TOTAL PAGES__l~ (Count does not include cover sheet) /s/ Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date:' I /4 D ~ lsl V Vt Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II I I III ReScanned III ~I'IIIVIII VIII BY: Maria Date: /s/ Comments about this file: Quality Checked III II~III III IIII III 1016!2005 Well History File Cover Page.doc ~. r ,* _~ ~~ .` + _ r ~~ '~ t x .4i- ~ ~ .`~~ .. MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Mazker.doc ~~° .~y~ ~ ~ ~ STATE OF ALASKA `~ ~ ~ ~ ~ ~ ~ C~ u ALASKA OIL AND GAS CONSERVATION COMMISSI(S~g X11 ~~~ ~, REPORT OF SUNDRY WELL OPERATIONS ~~~n;~; ~~; 1. operations Performed: Abandon ^ Repair Well ^~ ~ Plug Pertorations ^ Stimulate ^ Other ~ Install Iso Sleeve Alter Casing ^ Pull Tubing ^ Pertorate New Paol ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Pertorate ^ Re-enter Suspended Well ^ 2.Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConoeoPhillips Alaska, InC. t3evelapment ^ Exploratory ^ 206-112 3. Address: Stratigraphic ^ Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23317-61 7. KB Elevation (ft): 9. Well Name and Number: RKB 121' • 1J-102L2 • 8. Property Designation: • 10. FieldJPool{s): ADL 25661 & 25662 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: r (~~~ Total Depth measured _y7.835`' ~~~.~~~ feet true vertical ~ ~~ feet Plugs (measured) S'~' Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 20" 120' 120' 1,530' 520' SURFACE 10-3/4" 2,681' 2,323' 5,210' 2,480' INTERMEDIATE 7-518" 5,920' 3,780' 6,890' 4,790' D SAND LINER 4-1/2" 12,081' 3,501' 7,780' 6,350' ' 'R" Perforation depth: Measured depth: 5254 - 12042 true vertical depth: 3502' - 3531' Tubing (size, grade, and measured depth) 4-1/2:, L-80, 4706' (3.81" OD, 2.25" ID, CMU Isolation Sleeve at 4631') Packers &SSSV (type & measured depth) Loc Seal Assbly 4681', D-SAND LEM 4673', B-SAND LEM 4837', HRD Liner Top Packer 5150' SSSV = Camco DB Nipple 516' 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 NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ~ ` Daily Report of Well Operations X 16. Weil Status after work: C^ Ga~ WAG^ GINJ ^ WINJ ~ • WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. sundry Number or wA if c.o. Exempt: Contact Martin Walters Printed Name Martin Walters Title Problem Wells Supervisor Signature ~~~ Phone: 659-7224 Date 5/31/2009 red b Mertin WaHers 659-7224 1 ~ Form 10-404 Revised 04/2006. A. „(JAI 1 ~ ~ Cr Submit ri0 ainal~?nhc i _i ~ - • 1J-102 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summa 5/24/2009 5/27/2009 5/27/2009 MITIA- failed; State witnessed (Robert Noble) Initial T/I/0= 564/880/166; Rigged up to IA with LRS and attempted to pressure up IA with no success. pumped 11.6bbls. Final T/I/0= 564/880/166 IDENTIFY LEAK @CMU 4631' RKB W/ HOLE FINDER. ATTEMPT TO CLOSE & OPEN CMU BUT UNABLE TO ENGAGE IN (BOTH DIRECTIONS) SET 4' 3" 3.82 OD, 2.60 ID, CMU ISO SLEEVE @ 4606' SLM, MIT-IA 2500# (PASS), JOB IN PROGRESS. MITIA (passed): Pre T/IA/OA = 560/2350/220, Initial T/IA/OA = 560/2500/240, 15 minute T/IA/OA = 575/2450/200 30 minute T/IA/OA = 575/2450/200 PULLED ISO SLEEVE FROM CMU @ 4631' RKB. BRUSH CMU @ 4631' RKB. ATTEMPT TO OPEN CMU (UNABLE TO ENGAGE). SET 3.81" CMU ISO SLEEVE ON DB LOCK (2.83 NOGO, 2.25 MIN ID, 4' 6" LONG) @ 4631' RKB. MIT-IA 2500# (PASS), JOB COMPLETE. l ~Q ~ DATA SUBMITTAL COMPLIANCE REPORT 9/17/2008 Permit to Drill 2061120 Well Name/No. KUPARUK RIV U WSAK 1J-102L2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23317-61-00 MD 12095 TVD 3501 Completion Date 10/4/2006 Completion Status 1-OIL Current Status 1WINJ UIC Y REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name Samples No Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments Rpt 14217 LIS Verification 2606 12095 Open 11/9/2006 GR, ROP, FET Rpt 14217 LIS Verification 2606 5805 Open 11/9/2006 PB 1 GR, ROP, FET Rpt 14217 LIS Verification 2606 9599 Open 11/9/2006 PB 2 GR, ROP, FET ~D C Lis 14217 Gaf2't~ ,r,~~'~- -'~,~.~ 2606 12095 Open 11/9/2006 GR, ROP, FET D/ C Lis 14217 Gamntzri?ay Z„~~ ~. 2606 5805 Open 11/9/2006 PB 1 GR, ROP, FET ~D C Lis 14217 G3tnrrr~R~y r..~,~~' ~ 2606 9599 Open 11/9/2006 PB 2 GR, ROP, FET I,iF,B" D Asc Directional Survey 4730 12095 Open 11/9/2006 115 D Asc Directional Survey 4730 5805 Open 11/9/2006 PB 1 / ~5 D Asc Directional Survey 4730 9599 Open 11/9/2006 PB 2 C Lis 16049 Induction/Resistivity 2606 12095 Open 3/24/2008 LIS Veri, GR, FET, RPD, ~~ RPM, RPX, ROP `'ED C Lis 16049 Induction/Resistivity 2606 5805 Open 3/24/2008 PB1 LIS Veri, GR FET , , RPD, RPM, RPX, ROP ~ D C Lis 16049 Induction/Resistivity 2606 9599 Open 3/24/2008 PB3 LIS Veri, GR, RPD, RPM, FET, RPX, ROP ~~B' C 16049 ,/, Sse-P1of~s ~K ~,v~ t y.. ~+~n ~,- 0 0 Open 3/24/2008 MD and TVD logs in CGM, EMF and PDF graphics ~' L99 Induction/Resistivity 25 Col 120 12095 Open 3/24/2008 MD ROP, DGR, EWR 30- l ~ / Sep-2006 I ~ I #Je6g Induction/Resistivity 25 Col 120 3501 Open 3/24/2008 TVD ROP, DGR, EWR 30- Sep-2006 {'Log Induction/Resistivity 25 Col 120 5805 Open 3/24/2008 PB1 MD ROP, DGR, EWR 26-Sep-2006 og Induction/Resistivity 25 Col 120 9599 Open 3/24/2008 PB2 MD ROP, DGR, EWR 26-Sep-2006 DATA SUBMITTAL COMPLIANCE REPORT 9/17/2008 Permit to Drill 2061120 Well Name/No. KUPARUK RIV U WSAK 1J-102L2 Operator CONOCOPHILLIPS ALASKA INC MD 12095 TVD 3501 Completion Date 10/4/2006 Completion Status 1-OIL Current Status 1WINJ Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Chips Received? -~-i#~-~ Analysis Y / Received? Daily History Received? Formation Tops ~/ N API No. 50-029-23317-61-00 UIC Y Comments: --- Compliance Reviewed By: _ __ _._____ _.___. Date: ~~ WELL LOG TRANSMITTAL To: State of Alaska March 21, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-102+L1+L2+L2PB1+L2PB2+PB1+pB2+pB3 AK-MW-4559176 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-102+L1+L2+L2PB1+L2PB2+PBl+pB2+PB3; 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-23317-00,60,61,73,74,70,71,72 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-23317-00,60,61 Digital Log Images 50-029-23317-00,60,61,73,74,70,71,72 Some sections of this well have no TVD. 1 Color Log 1 Color Log 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 690 ~ ~ Ancrage )~a~`~~1~8-~`' ~~:~ Date: ~ ?SOS Signed: ~ OzCc'~~-tea r~ l~b~~ V=~ aCSI~,-l t ~ ,~ t lod~~l Ll 1 / UV • 4V1~.4~V tl VL1 •. 1/ •. •u.• ~ a•~.+• a.r ~-+. j ... v •• ... ~.. .. '- ""O- - ~ ~- Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, August 27, 2007 9:52 AM To: 'NSK West Sak Prod Engr'; Regg, James B (DOA) Cc: CPF1 DS lead Techs; CPF1 Prod Supt; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPPISSN defeated on 1E-112, 1J-102, 1J-127, 1J-164, 1J-180 Thanks Hai, While we will file this information in the main wellbore file, it is probably appropriate to list the lateral permit numbers for completeness. Call or message with any questions. Tom Maunder, PE AOGCC From: NSK West Sak Prod Engr [mailto:n1638@conocophillips.com] Sent: Sunday, August 26, 2007 8:59 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPFl DS Lead Techs; CPFi Prod Supt; NSK West Sak Prod Engr; Hollar, Erie Andrew; Rodgers, James T Subject: RE: LPPISSN defeated on 1E-112, iJ-102, 1)-127, 1J-164, iJ-180 Tom /Jim, The LPPISSN's on all of the West Sak DS1 E and DS1J wells are now back in service as their wellhead injection pressures have increased to above 500 psi. The following wells had been defeated; permit to dril- numbers are also listed. I wasn't sure if you wanted the permit to drill number for the mainbore only or the laterals as we!I so I included both. WELL ID Permit to Dri9i No. 1E-112 204-091 (MAINBORE), 204-092 (L1), 204-093 (L2) --~ 1J-102 206-110 (P/IAINBORE), 206-111 (L1), 206-112 (L2) 1J-105 207-027 (MAi(~1BORE), 207-028 (L1), 207-029 (L2) 1J-'127 206-047 (MAINBORE), 206-048 (L1), 206-049 (L2} 1J-160 207-015 (MAII`1BORE), 207-016 (L1), 207-0'17 (L2} 1J-164 205-144 (MAINBORE), 205-145 (L1), 205-146 (L2) 1J-180 206-150 (MAINBORE), 206-151 (L1} Note: 1J-105 and 1J-160 were defeated in early July 2007, before the CPF1 ESD, because they were new injectors (notification for these wells was sent 7/9/2007). Let me know if you have any questions. Regards, Hai Hunt Hai Hunt /Pete Nezaticky /Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com 8/27/2007 t~~C:EIVED MAR 1 3 ZtlO~ STATE OF ALASKA AIBSka QII ~ G8S COBS. Commission ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^/ ~ Alter Casing. ^ Pull Tubing ^ Perforate New Pool ^ ~ /"'_" Waiver ^ Time. Extension ^ 7 ..Chan eA roved Pro ram 9 Pp 9 ^ Operat. Shutdown^ .Perforate ^ bw ' (`c Re-enter Suspended Well ^ p ~• 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number. ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 206-1121 3. Address: Strati ra hic 9 p ^ Service / ^ 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-029-23317-61 7. KB Elevation (ft): 9. Well Name and Number. RKB 121' 1J-102L2 8. Property Designation: 10. Field/Pool(s): ADL 25661 & 25662 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12095' feet true vertical 3501' feet Plugs (measured) Effective Depth measured 12080' feet Junk (measured) true vertical 3501' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 140' 20" 140' 140' SURFACE 2602' 10-3/4" 2642' 2254' INTERMEDIATE 5880' 7-5/8" 5920' 3741' D-SAND LINER. 7145' 4-1/2" 12081' 3501' Perforation depth: Measured depth: Slotted Liner 5254' - 12 042' true vertical depth: 3564' - 3502' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 4708' MD . Packers &SSSV (type & measured depth) no packer SSSV=NIP SSSV= 516' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1539 2216 97 861 360 Subsequent to operation 1838 986 5 14, Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service. 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ Q WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: 306-381 contact Bob Christensen /Bob Buchholz Printed Name Robert D. C i tensen Title Production Engineering Technician Signature Phone 659-7535 Date ~ ~' ~ Form 10-404 Revised 04/2004 ~ j Y ~ `" r r ~`~~' k ~ ~+ ~ # ~ YYY ~~' 111 3'~4'a7 SubmitOrig'i ~/~ 1J-102L2 ' DESCRIPTION OF WORK COMPLETED SUMMARY Date Event.Summary 02/20/07 Commenced Water Injection Service SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE I00 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-75423 Robert Buchholz Production Engineering Technician ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, IJ-102L2 Sundry. Number: 306-381 Dear Mr. Buchholz: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~~day of December, 2006 Encl. a.p(o- ~~a Sincerely, ~~~~~ V ~ ~ ~. ~ STATE OF ALASKA ~~ ~t a. DEC ®~ ?~ °1 l ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons Oo+~Nnission APPLICATION FOR SUNDRY APPROVAL Anchorage 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other •0 Alter casing ^ Repairwell ^ Plug Pertorations ^ Stimulate ^ Time Extension ^ Chan e a roved ro ram g pp p g ^ Pull Tubing ^ Perforate New Pool ^ Producer to Re-enter Suspended Well ^ Injector 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Nyptber: ConocoPhillips Alaska, Inc. Development Q ~ Exploratory ^ 206-112 • 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23317-61 • ~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Y@S ^ NO Q 1J-102L2 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25661 & 25662' RKB 121' Kuparuk River Field /West Sak Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 12095' 3501' 12080' 3501' - Casing Length Size MD TVD Burst Collapse CONDUCTOR 140' 20" 140' 140' SURFACE 2521' 10-3/4" 2642' 2254' INTERMEDIATE 5799' 7-5/8" 5920' ~~~ 3 ~~ D-SAND LINER 7145' 4-1/2" 12081' 3501' Pertoration Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted Liner 5254' - 12042' 3564' - 3502' 4-1 /2" L-80 4708' Packers and SSSV Type: 1 Packers and SSSV MD (ft) acker 'Z.,~~ ~ i ~~. t` ~~ Q~C~~ ~ ~b1a SSSV= NIP SSSV= 516' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: January 14, 2007 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^~ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen /Bob Buchholz Printed Name Robert W. Buchholz Title: Production Engineering Technician Signature ~ Phone 659-7535 Date / Z 3 Commission Use Onl Sundry Number. Conditions of approval: Notify Commission so that a representative may witness 61.11 -- Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other. ~~+, p r~ Subsequent Form Required: ~~~~ APPROVED BY /~ ~ ~,/~ / «<///"'~~~ Approved by: OMMISSIONER THE COMMISSION Z ' Date: f Form 10-403 Revised 06/2006 ` Submit in Duplicate 1J-102L2 • DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Tri- lateral Well 1 J-102L2. Plans are to pre-produce well for 30 days in order to recover Oil based drilling fluids prior to putting the well on injection. Lateral 1 J-102L2 will provide pressure , support for the West Sak D sands. The 10-3/4" Surface casing (2642' and / 2254' tvd) was cemented with 389 bbls AS Lite followed by 76 bbls DeepCRETE. The 7-5/8" Intermediate casing (5920' and / 3741' tvd) was cemented with 350 sx DeepCRETE. The injection tubing/casing annulus is isolated via the following: Upper D sand ZXP 5-1/2" x 7- 5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 4673' and / 3524' tvd, Upper B sand ZXP 5-1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 4837' and / 3562' tvd, and an Upper A sand ZXP 5-1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 5150' and / 3625' tvd. The top of West Sak D sand was found at 4730' and / 3539' tvd. - The top of West Sak B sand was found at 5047' and / 3604' tvd. The top of West Sak A sand was found at 5876' and / 3735' tvd. ~` F KRU 1 J-102L2 "` MEC:3ANICAL INTEGRITY :tEPORT ~ - - \ia ?UD D:_:=: ~ ~f~5`Vi~ C~PEt2 ~ FZELD ~,~~ ~ _ ~~1DC3-~ viL -- ~~~ ",~ ALL D c T ~_ TD : ?-~.. '?'VD ; ? B TD : ?~ I'VD :,as i~:g : _ '~ ~~~ Shoe : 5 ~y rID -~~~ ~T~ t yV : ~~- '-~ i3 b. :~~i --==~e= • Shoe . '~ T`dT ; .'OP . '_~~ 'i7 ~~„ C..\~~~4` pacxe_ '~ T'J7i Ser at =oie S=~e and peT~; to -.~~,C'r'..r~?~=C~.1, _NTEGR?'TY - PART #1 ~~ v..i~r`~~~ ~..i~l~~a~ ~~ , ~'~S'~~~ -~.~~ n.:uius Press Test: _? Comments: S GIi n :; 0 min i '~' CHP?4I Cr'1, ZNTEGRIT`~ - PART # 2 .~.~-~ `~^lO ~~ ~ S Cement Volumes :- Amt. Liner ~ ~ CsQ ~~ Sti. DV lN~ Cwt -rol to cove, oers G 3p~cti`ES S~ G~~~~~~ti~©~3 coq ~icE~.~ ~ i ~ S l~ 3 _::eoretical TOC ~ ~p ~ `~~ ~~C. "~ ~i~(~ Cement Bond Log (Yes or No) ~LS ~ ~In~A GCC File CBL Evaluation, cone above pens ~[.~t~\\c,,'~.~ ~r~~~1-~ Production Log: Igoe CONCLUS=ONS: PaLt 1I art rL \ `°~ a~C. Evaluation • • Maunder, Thomas E (DOA) From: Thomas Maunder [tom maunder@admin.state.ak.us] Sent: Tuesday, December 12, 2006 11:04 AM To: NSK Prod Engr Tech Cc: Allsup-Drake, Sharon K Subject: Re: 1 J-102, et al conversion a o c~ - ~~-~ Bob, Looking at your reply, I believe that the depths you give for the L2 window are not correct. According to the operations summary the window top is the same as the sand tops given in the same line. Would you confirm please? Call or message with any questions . j~-; ~~ ~yr~1 r~^ C~~~C~~ ~~~~ Tom Maunder, PE ~~` \-.F `" l~c `~/ AOGCC I NS~K P r o d E n g r T e c h w r o t e, O n 1 2/ 7/ 2 0 0 6 6: 1 6 A M: ~p°~ ~'~'~ >To >Here's what I found: > >7-5/8" asing: > Top - 40'md (40' tvd), Bottom = 5920' (3741' tvd), Length = 5880', >common to 11 3 wellbores. >7-5/8" casi Windows: > 1J-102L Top @ 4937' md (3582' tvd), D sand top found @ 4730'md (3539' >tvd) > 1J-102L1 To @ 5047' md (3604' tvd), B sand top found C 5047'md (3604' >tvd) > 1J-102 (Mothe wellbore), A sand top found @ 5876' md (3735' >tvd) > >Per your suggestion, we ill start including window depths in the >"Description Summary of P oposal" page as we do not have enough room on >the 10-403 proper. > >I have forwarded your suggesti n on the liner top packers to Sharon >Allsup-Drake for consideration. pparently this question has come up in >the past. We currently provide t's information in the "Description >Summary of Proposal" page. > >Sorry for the confusion. >Bob Christensen >ConocoPhillips Alaska, Inc. ;~~,~a~~~#~l~~ a~(~~-~ ~ ;~ ~~~ j >Greater Kuparuk Area >Production Engineering Technician >Office (907) 659-7535 NSK-69 >Pager (907) 659-7000 (924) > > >-----Original Message----- >From: Thomas Maunder [mailto:tom maunderC~admin.state. k.us] >Sent: Wednesday, December 06, 2006 9:04 AM >To: NSK Prod Engr Tech >Subject: 1J-102, et al conversion > > >Bob and Bob, >I am looking at the sundries for converting 1J-102 and the late ls to >injection. A couple of questions, > >1. The length of the 7-5/8" casing is listed at 5799', but the sett'ng >depth is 5920'. There seems to be a disconnect here. Based on the R 1 ~ • Maunder, Thomas E (DOA) From: NSK Prod Engr Tech [n1139@conocophillips.com] Sent: Thursday, December 07, 2006 6:16 AM To: Thomas Maunder Cc: Ailsup-Drake, Sharon K Subject: RE: 1J-102, et al conversion Tom, Here's what I found: 7-5/8" casing: Top = 40'md (40' tvd), Bottom wellbores. 7-5/8" casing Windows: 1J-102L2 Top @ 4937' md (3582' 1J-102L1 Top @ 5047' md (3604' 1J-102 (Mother wellbore), A sa tvd) = 5920' (3741' tvd), Length = 5880', common to all 3 tvd), D sand top found @ 4730'md (3539' tvd) tvd), B sand top found @ 5047'md (3604' tvd) nd top found @ 5876' md (3735' Per your suggestion, we will start including window depths in the "Description Summary of Proposal" page as we do not have enough room on the 10-403 proper. I have forwarded your suggestion on the liner top packers to Sharon Allsup-Drake for consider~tion. Apparently this question has come up in the past. We currently provide this information in the "Description Summary of Proposal" page. Sorry for the confusion. Bob Christensen ConocoPhillips Alaska, Inc. Greater Kuparuk Area Production Engineering Technician Office (907) 659-7535 NSK-69 Pager (907) 659-7000 (924) -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, December 06, 2006 9:04 AM To: NSK Prod Engr Tech Subject: 1J-102, et al conversion Bob and Bob, I am looking at the sundries for converting 1J-102 and the laterals to injection. A couple of questions, l. The length of the 7-5/8" casing is listed at 5799', but the setting depth is 5920'. There seems to be a disconnect here. Based on the RKB height, I think the length of casing should be about 5880'. Can you reconcile? 2. According to the 407, the tvd setting depth of the 7-5/8" casing is 3741' tvd. On the -Ll 403 the tvd depth is listed as 3592' and on the -L2 403 the tvd depth is listed as 3533'. According to the calculations done over here -Ll window is at 5047' md, 3604' tvd and -L2 window is at 4730' md, 3539' tvd. Are these the window tops? I know our respective depths are close. On future applications, it may make sense to have a line that lists the full intermediate casing string with another line that has the specifics of the window. What do you think? 3. On each sundry, it is indicated that there is no packer in the 1 well. While technically the~e isn't a packer, the LEM ZXP li'~'f~r top packer at 4672' is the functional equivalent. You might check with the drilling or production engineers about the specifics. Thanks in advance for looking into these questions. I look forward to your reply. All in all, the construction looks good. The bond log is excellent. Just need to clarify these points and recommending approval should not be a problem. Tom Maunder, PE AOGCC 2 Sl`ATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ._ -.- AND... LOG 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. ofCompletions~ Other_ 1b. Well Class: Development Q Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: October 4, 2006 ~ 12. Permil to Drill Number: 206-112 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded Z,~' Z~yP 25, 2006 ~~~/~( 13. API Number: 50-029-23317-61 4a. Location of Well (Governmental Section): Surface: 2245' FSL, 2446' FEL, Sec. 35, T11 N, R10E, UM 7. Date TD Reached: r September 29, 2006 14. Well Name and Number: ~ 1 J-102L2 At Top Productive Horizon: 2000' FSL, 553' FEL, Sec. 35, T11 N, R10E, UM 8. KB Elevation (ft): 40' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 61' FNL, 647' FEL, Sec. 11, T10N, R10E, UM 9. Plug Back Depth (MD + ND): 12080' MD / 3501' ND West Sak Oil P001 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558761 y- 5946057 Zone- 4 10. Total Depth (MD + ND): ~ 12095' MD / 3501' ND - 16. Property Designation: ADL 25661 & 25662 TPI: x- 560656 y- 5945827 Zone- 4 Total Depth: x- 560627 - - 5938487 - Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 471 & 2177 18. Directional Survey: Yes Q No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 3628' MD 21. Logs Run: ~' !.J W 730 /f'iD/ ,~5.3~ ~T'Vj~ /~~/ .C~ GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE TING AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMEN RECORD PULLED 20" 62.6# H-40 40' 120' 40' 120' 42" 300 sx AS 1 10.75" 45.5# L-80 40' 2643' 40' 2252' 13.5" 389 bbls AS Lite, 76 bbls DeepCRETE 7-5/8" 29.7# L-80 40' 5920' 40' 3741' 9-7/8" 350 sx DeepCRETE 4.5" 11.6# L-80 4936' 12081' 3569' 3501' 6.75" slotted liner 23. Pertorations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET tubing in original wellbore none slotted liner from 4936' to 11326' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production not available Method of Operation (Flowing, gas lift, etc.) waiting on facility hook-up Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". / P' ~ i~iv ~q ~~~~`~ g ~ ''~~E~ ~ ~J ZJU~ LQ 7~.~~6 NONE .1 ` Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ~~~~~"~ ~l• ~~. ~o ' i~ a ~ r a .... i 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessaiy.= ~.na'te3sfs were - ~. conducted, state "None". 1 J-102L2 West Sak D 4730' 3539' ' 1 J-102L2P61 TD 5805' 3535' N/A 1 J-102L2PB2 TD 9599' 3520' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Pat Reilly @ 265-6048 Printed Na~ Randv Thomas Title: Greater Kuoaruk Area Drillino Team Leader t f /t j/0 (~ Signature ne G~ 5-~_~ ~ U Date INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ~ } ; ~a.. ~ , „~IIalliburton Company Survey Report Company: ConocoPhitlips Alaska Inc . Date: 10/18/2006 Time: 08:19:02 Pa~;c: 1 Field: KuparukRiver Unit Co-ordinate(NE) Rcfrrcncei Well: 1J-102, True North Site: Kuparuk 1J Pad Vertical(TVD) Re ference: 1J-102L2: 121.3 Well: 1J-102 Section (VS) Reference: Well (O.OON,QOO E,180AOAzi) Wellpath: 1J-102L2 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 ' Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1 J-102 Slot Name: Well Position: +N/-S 137.61 ft Northing: 5946057.02 ft Latitude: 70 15 47.611 N +E/-W -27.19 ft Easti ng : 558761.69 ft Longitude: 149 31 29.798 W ~ Position Uncertainty: 0.00 ft ~ ^Wellpath: 1J-102L2 Drilled From: 1J-102L2PB2 500292331761 Tie-on Depth: 9428.80 ft Current Datum: 1 J-102L2: Height 121.30 ft Above System Datum: Mean Sea Level Magnetic Data: 8/25/2006 Declination: 23.82 deg Field Strength: 57608 nT Mag Dip Angle: 80.80 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg i 40.30 0.00 0.00 180.00 ~ Survey Program for Definitive Wellpa th Date: 10/18/2006 Validated: No Version: 3 Actual From To Survey Toolcode Tool Name ft ft 121.00 820.00 1J-102P61 gyro (12 1.00-820.00) CB-GYRO-SS Camera based gyro single shot 869.87 4664.00 1J-102PB1 (869.87-8124.27) (3) 4730.00 5585.13 1J-102L2PB1 (4730.00-5757.03) ~ MWD+IFR-AK-CAZ-SC MWD+IFRAK CAZ SCC MWD+IFR-AK-CAZ-SC MWD+IFRAK CAZ SCC 5640.00 9428.80 1 J-102L2PB2 (5640 .00-9564.50) MWD+IFR-AK-CAZ-SC MWD+IFRAK CAZ SCC 9490.00 12060.81 1J-102L2 ( 9490.00-12060.81) MWD+IFR-AK-CAZ-SC MWD+IFRAK CAZ SCC Survey __ _ __ - MD Intl s:~zim TVD SysTVD N/S E/~V MapN tlapE Tool ft deg deg ft ft ft ft ft ft 40.30 0.00 0.00 40.30 -81.00 0.00 0.00 5946057.02 558761.69 TIE LINE 121.00 0.45 106.20 121.00 -0.30 -0.09 0.30 5946056.93 558761.99 CB-GYRO-SS 220.00 0.78 44.56 219.99 98.69 0.28 1.15 5946057.31 558762.84 CB-GYRO-SS 320.00 4.66 32.21 319.86 198.56 4.21 3.79 5946061.26 558765.45 CB-GYRO-SS 420.00 8.21 30.63 419.22 297.92 13.79 9.60 5946070.88 558771.18 CB-GYRO-SS 520.00 , 12.54 26.87 517.56 396.26 29.63 18.15 5946086.78 558779.60 CB-GYRO-SS ~ 620.00 15.71 25.57 614.52 493.22 51.53 28.90 5946108.77 558790.18 CB-GYRO-SS 720.00 18.93 27.89 709.98 588.68 78.08 42.34 5946135.43 558803.41 CB-GYRO-SS ~ 820.00 23.00 33.80 803.35 682.05 108.67 60.80 5946166.15 558821.64 CB-GYRO-SS 869.87 23.17 37.49 849.23 727.93 124.55 72.19 5946182.12 558832.90 MWD+IFR-AK-CAZ-SC 964.72 24.49 38.35 935.99 814.69 154.78 95.75 5946212.53 558856.22 MWD+IFR-AK-CAZ-SC 1058.43 24.67 42.44 1021.21 899.91 184.45 121.00 5946242.39 558881.23 MWD+IFR-AK-CAZ-SC 1153.43 24.88 48.25 1107.48 986.18 212.39 149.29 5946270.55 558909.31 MWD+IFR-AK-CAZ-SC 1248.76 26.13 49.54 1193.52 1072.22 239.36 180.23 5946297.76 558940.03 MWD+IFR-AK-CAZ-SC 1342.77 27.89 48.40 1277.28 1155.98 267.40 212.42 5946326.04 558972.00 MWD+IFR-AK-CAZ-SC 1439.09 31.30 50.15 1361.02 1239.72 298.40 248.49 5946357.32 559007.82 MWD+IFR-AK-CAZ-SC 1535.84 30.64 50.08 1443.98 1322.68 330.32 286.69 5946389.54 559045.77 MWD+IFR-AK-CAZ-SC 1631.24 32.51 50.90 1525.25 1403.95 362.09 325.23 5946421.61 559084.06 MWD+IFR-AK-CAZ-SC ' 1723.25 36.09 52.10 1601.25 1479.95 394.35 365.82 5946454.17 559124.39 MWD+IFR-AK-CAZ-SC 1821.35 41.06 53.68 1677.92 1556.62 431.20 414.61 5946491.40 559172.88 MWD+IFR-AK-CAZ-SC 1916.57 44.73 53.28 1747.67 1626.37 469.77 466.68 5946530.37 559224.65 MWD+IFR-AK-CAZ-SC 2010.97 45.69 55.27 1814.17 1692.87 508.88 521.07 5946569.90 559278.72 MWD+IFR-AK-CAZ-SC 2105.87 45.73 56.87 1880.44 1759.14 546.79 577.43 5946608.25 559334.78 MWD+IFR-AK-CAZ-SC 2201.01 47.60 61.41 1945.75 1824.45 582.23 636.82 5946644.15 559393.89 MWD+IFR-AK-CAZ-SC 2293.68 46.11 65.63 2009.14 1887.84 612.39 697.30 5946674.78 559454.12 MWD+IFR-AK-CAZ-SC i 2391.30 46.49 70.60 2076.60 1955.30 638.67 762.75 5946701.57 559519.36 MWD+IFR-AK-CAZ-SC ~Ialliburton Company Survey Report Company: ConocoPhillips Alaska lnc. Date: 10/18/2006 Time: 08:19:02 Page: 2 Field: Ku paruk River Unif Co-ordinate(NE) Reference: Well: 1J-10 2, True North Site: Ku paruk 1J Pad Vertic al (TV D) Reference: 1J-102L2 121.3 Well: 1J-102 Sectio n (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) ~Vellpath: 1J -102L2 Survey Calc ulation Method: MinimumC urvature Db: Oracle Survey SID Intl Azim TVD Svs TVD N/S _ E/W 1~1apN MapE Tool ft deg deg ft ft ft ft ft ft 2486.23 45.57 74. 98 2142. 53 2021.23 658. 90 827. 98 5946722. 30 559584. 42 MWD+IFR-AK-CAZ-SC 2581.48 43.53 80. 15 2210. 42 2089.12 673. 33 893. 17 5946737. 23 559649. 50 MWD+IFR-AK-CAZ-SC 2602.96 43.39 80. 76 2226. 01 2104.71 675. 78 907. 74 5946739. 80 559664. 04 MWD+IFR-AK-CAZ-SC 2692.50 43.33 80. 12 2291. 12 2169.82 685 .99 968. 36 5946750. 48 559724. 58 MWD+IFR-AK-CAZ-SC 2789.32 41.08 80. 53 2362. 83 2241.53 696 .92 1032. 48 5946761. 91 559788. 60 MWD+IFR-AK-CAZ-SC 2883.45 39.91 82. 89 2434. 42 2313.12 705 .75 1092. 95 5946771. 21 559849. 00 MWD+IFR-AK-CAZ-SC 2978.49 42.09 87. 64 2506. 16 2384.86 710. 84 1155. 05 5946776. 78 559911. 05 MWD+IFR-AK-CAZ-SC ± 3072.35 42.28 89. 81 2575. 71 2454.41 712. 24 1218. 06 5946778. 67 559974. 04 MWD+IFR-AK-CAZ-SC j 3164.88 43.18 96. 30 2643. 71 2522.41 708. 87 1280. 68 5946775. 79 560036. 68 MWD+IFR-AK-CAZ-SC 3260.78 43.19 102. 29 2713. 67 2592.37 698 .28 1345. 39 5946765. 71 560101. 46 MWD+IFR-AK-CAZ-SC 3353.79 43.31 108. 49 2781. 44 2660.14 681 .38 1406. 77 5946749. 29 560162. 97 MWD+IFR-AK-CAZ-SC 3447.64 44.63 113. 39 2849. 00 2727.70 658 .07 1467. 58 5946726. 46 560223. 95 MWD+IFR-AK-CAZ-SC 3541.79 46.90 119. 91 2914. 72 2793.42 627. 78 1527. 77 5946696. 65 560284. 36 MWD+lFR-AK-CAZ-SC 3636.01 48.89 126. 24 2977. 92 2856.62 589. 62 1586. 25 5946658. 95 560343. 14 MWD+IFR-AK-CAZ-SC 3729.21 49.70 132. 74 3038. 74 2917.44 544 .72 1640. 70 5946614. 47 560397. 94 MWD+IFR-AK-CAZ-SC 3823.40 49.11 138. 38 3100. 06 2978.76 493 .70 1690. 75 5946563. 85 560448. 38 MWD+IFR-AK-CAZ-SC 3916.77 49.70 146. 22 3160. 87 3039.57 437 .67 1734. 03 5946508. 17 560492. 09 MWD+IFR-AK-CAZ-SC 4010.22 51.80 150. 91 3220. 01 3098.71 375 .94 1771. 71 5946446. 74 560530. 25 MWD+IFR-AK-CAZ-SC 4104.27 55.02 157. 51 3276. 11 3154.81 307. 98 1804. 45 5946379. 04 560563. 51 MWD+IFR-AK-CAZ-SC I 4198.08 57.40 161. 80 3328. 29 3206.99 234 .90 1831. 51 5946306. 18 560591. 13 MWD+IFR-AK-CAZ-SC 4291.04 62.13 164. 89 3375. 10 3253.80 157 .97 1854. 46 5946229. 45 560614. 69 MWD+IFR-AK-CAZ-SC 4384.47 65.15 169. 96 3416. 60 3295.30 76 .30 1872. 63 5946147. 93 560633. 49 MWD+IFR-AK-CAZ-SC 4474.72 66.68 173. 83 3453. 44 3332.14 -5 .25 1884. 23 5946066. 48 560645. 72 MWD+IFR-AK-CAZ-SC 4566.87 68.47 176. 21 3488. 59 3367.29 -90 .10 1891. 61 5945981. 70 560653. 77 MWD+IFR-AK-CAZ-SC j 4664.00 72.68 180. 95 3520. 91 3399.61 -181 .62 1893. 83 5945890. 20 560656. 70 MWD+IFR-AK-CAZ-SC 4730.00 76.27 181. 66 3538. 57 3417.27 -245 .18 1892. 38 5945826. 64 560655. 74 MWD+IFR-AK-CAZ-SC 4833.97 81.93 182. 00 3558. 22 3436.92 -347 .18 1889. 12 5945724. 62 560653. 28 MWD+IFR-AK-CAZ-SC 4927.11 84.96 185. 86 3568. 86 3447.56 -439 .47 1882. 77 5945632. 30 560647. 65 MWD+IFR-AK-CAZ-SC 5021.49 89.18 187. 65 3573. 68 3452.38 -533 .04 1871. 68 5945538. 65 560637. 29 MWD+IFR-AK-CAZ-SC 5115.81 93.38 192. 16 3571. 57 3450.27 -625 .89 1855. 47 5945445 .69 560621. 81 MWD+IFR-AK-CAZ-SC ~ 5209.41 93.11 189. 97 3566. 27 3444.97 -717 .60 1837. 54 5945353. 85 560604. 60 MWD+IFR-AK-CAZ-SC 5303.05 93.98 188. 57 3560. 48 3439.18 -809 .83 1822. 48 5945261. 51 560590. 26 MWD+IFR-AK-CAZ-SC 5397.45 93.67 186. 74 3554. 19 3432.89 -903 .18 1809. 94 5945168. 08 560578. 45 MWD+IFR-AK-CAZ-SC 5491.21 94.96 186. 64 3547. 13 3425.83 -996 .04 1799. 05 5945075. 15 560568. 28 MWD+IFR-AK-CAZ-SC 5585.13 92.47 184. 32 3541. 05 3419.75 -1089 .32 1790. 10 5944981 .81 560560. 06 MWD+IFR-AK-CAZ-SC 5640.00 93.18 182. 47 3538. 34 3417.04 -1144 .02 1786. 85 5944927 .09 560557. 25 MWD+IFR-AK-CAZ-SC 5679.43 89.90 181. 24 3537. 28 3415.98 -1183 .41 1785. 58 5944887. 69 560556. 28 MWD+IFR-AK-CAZ-SC 5772.26 91.51 180. 88 3536. 14 3414.84 -1276 .21 1783. 86 5944794. 89 560555. 28 MWD+IFR-AK-CAZ-SC ~ 5865.24 91.00 176. 87 3534. 10 3412.80 -1369 .13 1785. 69 5944701. 99 560557. 83 MWD+IFR-AK-CAZ-SC 5960.71 91.26 176. 39 3532. 22 3410.92 -1464 .42 1791. 30 5944606 .76 560564. 19 MWD+IFR-AK-CAZ-SC 6024.35 89.45 173. 85 3531. 83 3410.53 -1527 .82 1796. 71 5944543 .41 560570. 10 MWD+IFR-AK-CAZ-SC 6054.32 90.97 173. 70 3531. 72 3410.42 -1557 .61 1799. 96 5944513 .65 560573. 58 MWD+IFR-AK-CAZ-SC 6147.62 89.83 169. 04 3531. 06 3409.76 -1649 .83 1813. 96 5944421. 56 560588. 29 MWD+IFR-AK-CAZ-SC 6240.68 90.77 173. 19 3530. 58 3409.28 -1741 .75 1828. 33 5944329. 76 560603. 38 MWD+IFR-AK-CAZ-SC 6334.05 91.82 175. 63 3528. 47 3407.17 -1834 .64 1837. 42 5944236 .95 560613. 19 MWD+IFR-AK-CAZ-SC 6428.32 90.63 178. 78 3526. 45 3405.15 -1928 .76 1842. 01 5944142 .87 560618. 52 MWD+IFR-AK-CAZ-SC 6521.64 88.96 182. 57 3526. 78 3405.48 -2022 .06 1840, 91 5944049 .58 560618. 15 MWD+IFR-AK-CAZ-SC 6616.50 90.34 186. 65 3527. 36 3406.06 -2116 .59 1833, 29 5943955 .01 560611. 27 MWD+IFR-AK-CAZ-SC 6709.57 91.26 186. 08 3526. 06 3404.76 -2209 .07 1822, 97 5943862 .45 560601. 67 MWD+IFR-AK-CAZ-SC i 6803.56 6897.45 91.25 91.87 187. 183. 05 78 3524. 3521. 01 45 3402.71 3400.15 -2302 -2395 .42 .85 1812. 1803. 23 38 5943769. 5943675 03 .55 560591. 560583. 66 53 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC 6991.15 91.81 181. 50 3518. 44 3397.14 -2489 .39 1799. 06 5943581 .98 560579. 95 MWD+IFR-AK-CAZ-SC 7084.20 90.13 175. 81 3516. 86 3395.56 -2582 .36 1801. 25 5943489 .04 560582. 86 MWD+IFR-AK-CAZ-SC ~Ialliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 10/18/2006 r Time: 08:19:02 Page: 3 Field: Kuparuk River Unit Co-ordinatc(NE) Reference: Well: 1J-102, True North Site: Ku paruk 1J Pad Verticat(TVD) Reference: 1J-1021.2: 121.3 Well: 1J -102 Sectio n (V'S}Reference: Wefl (O.OON,O.OOE,18pADAzi) Wellpath: 1J -102L2 Survey Calculati on Method: Minimum Curvature Db: Oracle Sunev 11ID Intl Azim TVll Sys TVD N/S E/W h1apN 111apE Tool ft deg deg ft ft ft ft ft ft 7178.46 89.96 170.64 3516. 79 3395.49 -2675 .93 1812.36 5943395. 57 560594.70 MWD+IFR-AK-CAZ-SC 7273.17 90.70 173.81 3516. 24 3394.94 -2769 .76 1825.17 5943301. 86 560608.25 MWD+IFR-AK-CAZ-SC 7367.10 89.71 175.16 3515. 91 3394.61 -2863. 25 1834.20 5943208. 45 560618.00 MWD+IFR-AK-CAZ-SC 7461.10 89.53 177.74 3516. 53 3395.23 -2957. 06 1840.02 5943114. 70 560624.55 MWD+IFR-AK-CAZ-SC ~ 7554.49 90.02 179.17 3516. 90 3395.60 -3050. 41 1842.54 5943021. 37 560627.80 MWD+IFR-AK-CAZ-SC 7648.06 90.02 182.40 3516. 87 3395.57 -3143 .96 1841.26 5942927. 83 560627.25 MWD+IFR-AK-CAZ-SC 7742.48 88.96 180.68 3517. 71 3396.41 -3238 .34 1838.72 5942833. 44 560625.45 MWD+IFR-AK-CAZ-SC 7835.76 89.72 177.49 3518. 78 3397.48 -3331 .59 1840.21 5942740. 22 560627.66 MWD+IFR-AK-CAZ-SC 7930.78 90.02 179.35 3519. 00 3397.70 -3426 .56 1842.83 5942645. 27 560631.02 MWD+IFR-AK-CAZ-SC 8024.06 90.08 178.66 3518. 92 3397.62 -3519 .83 1844.45 5942552. 03 560633.37 MWD+IFR-AK-CAZ-SC 8117.60 90.64 181.77 3518. 33 3397.03 -3613. 36 1844.10 5942458. 51 560633.75 MWD+IFR-AK-CAZ-SC 8211.12 89.64 181.28 3518. 10 3396.80 -3706 .84 1841.61 5942365. 02 560631.99 MWD+IFR-AK-CAZ-SC 8303.73 88.97 181.75 3519. 22 3397.92 -3799 .41 1839.16 5942272. 44 560630.27 MWD+IFR-AK-CAZ-SC 8398.36 89.84 182.10 3520. 20 3398.90 -3893 .98 1835.98 5942177. 86 560627.83 MWD+IFR-AK-CAZ-SC 8495.99 89.59 183.95 3520. 69 3399.39 -3991 .47 1830.83 5942080. 34 560623.44 MWD+IFR-AK-CAZ-SC 8587.51 90.39 182.32 3520. 71 3399.41 -4082 .85 1825.82 5941988. 94 560619.14 MWD+IFR-AK-CAZ-SC 8680.80 90.14 180.28 3520. 27 3398.97 -4176 .11 1823.71 5941895. 67 560617.76 MWD+IFR-AK-CAZ-SC 8773.99 89.28 178.25 3520. 75 3399.45 -4269 .28 1824.90 5941802. 52 560619.68 MWD+IFR-AK-CAZ-SC 8866.41 89.22 179.57 3521. 96 3400.66 -4361 .68 1826.66 5941710. 15 560622.16 MWD+IFR-AK-CAZ-SC ~ ~ 8960.13 90.40 180.76 3522. 27 3400.97 -4455 .39 1826.39 5941616. 44 560622.62 MWD+IFR-AK-CAZ-SC j 9055.05 90.89 176.54 3521. 20 3399.90 -4550 .26 1828.63 5941521. 61 560625.59 MWD+IFR-AK-CAZ-SC 9147.46 89.02 175.20 3521. 27 3399.97 -4642 .42 1835.28 5941429. 51 560632.97 MWD+IFR-AK-CAZ-SC 9241.69 88.54 178.90 3523. 28 3401.98 -4736 .49 1840.13 5941335. 49 560638.55 MWD+IFR-AK-CAZ-SC 9335.66 90.46 182.37 3524. 10 3402.80 -4830 .43 1839.09 5941241. 55 560638.24 MWD+IFR-AK-CAZ-SC 9428.80 89.58 182.68 3524. 07 3402.77 -4923 .48 1834.98 5941148. 48 560634.86 MWD+IFR-AK-CAZ-SC 9490.00 90.03 182.89 3524. 27 3402.97 -4984. 61 1832.01 5941087. 34 560632.37 MWD+IFR-AK-CAZ-SC 9522.90 87.49 182.71 3524. 99 3403.69 -5017 .46 1830.40 5941054. 48 560631.02 MWD+IFR-AK-CAZ-SC 9618.22 87.49 180.88 3529. 16 3407.86 -5112 .64 1827.42 5940959. 29 560628.78 MWD+IFR-AK-CAZ-SC i 9710.77 90.10 183.85 3531. 11 3409.81 -5205 .07 1823.60 5940866. 84 560625.68 MWD+IFR-AK-CAZ-SC 9805.16 89.34 181.86 3531. 57 3410.27 -5299 .33 1818.90 5940772. 55 560621.72 MWD+IFR-AK-CAZ-SC 9898.81 89.53 181.67 3532. 49 3411.19 -5392 .94 1816.02 5940678. 94 560619.56 MWD+IFR-AK-CAZ-SC 9992.66 91.06 180.81 3532. 01 3410.71 -5486 .76 1813.99 5940585. 11 560618.26 MWD+IFR-AK-CAZ-SC 10085.62 89.21 178.71 3531. 79 3410.49 -5579 .71 1814.38 5940492. 18 560619.38 MWD+IFR-AK-CAZ-SC ~ 10178.75 87.11 179.37 3534. 78 3413.48 -5672 .77 1815.94 5940399. 14 560621.66 MWD+IFR-AK-CAZ-SC 10272.55 88.05 181.73 3538. 74 3417.44 -5766 .48 1815.04 5940305. 44 560621.49 MWD+IFR-AK-CAZ-SC 10365.83 90.22 181.29 3540. 15 3418.85 -5859 .71 1812.58 5940212. 20 560619.77 MWD+IFR-AK-CAZ-SC 10458.78 90.95 181.98 3539. 20 3417.90 -5952 .61 1809.93 5940119. 28 560617.84 MWD+IFR-AK-CAZ-SC 10552.84 93.80 179.17 3535. 30 3414.00 -6046 .57 1808.98 5940025. 33 560617.63 MWD+IFR-AK-CAZ-SC ~ 10645.74 93.66 174.15 3529. 25 3407.95 -6139 .08 1814.38 5939932. 87 560623.75 MWD+IFR-AK-CAZ-SC 10739.95 93.92 172.02 3523. 03 3401.73 -6232 .40 1825.70 5939839. 66 560635.79 MWD+IFR-AK-CAZ-SC 10833.26 91.05 172.59 3518. 98 3397.68 -6324 .77 1838.18 5939747. 39 560648.99 MWD+IFR-AK-CAZ-SC 10925.60 89.02 176.06 3518. 92 3397.62 -6416 .64 1847.31 5939655. 61 560658.84 MWD+IFR-AK-CAZ-SC 11019.88 90.34 177.99 3519. 45 3398.15 -6510 .78 1852.20 5939561. 51 560664.46 MWD+IFR-AK-CAZ-SC 11113.19 91.82 181.05 3517. 69 3396.39 -6604 .06 1852.98 5939468. 25 560665.97 MWD+IFR-AK-CAZ-SC 11207.51 90.63 181.80 3515. 68 3394.38 -6698 .33 1850.64 5939373. 98 560664.36 MWD+IFR-AK-CAZ-SC 11301.30 90.39 180.67 3514. 84 3393.54 -6792 .09 1848.62 5939280. 21 560663.07 MWD+IFR-AK-CAZ-SC ~ ~ ' 11395.79 90.95 183.78 3513. 74 3392.44 -6886 .49 1844.95 5939185 .80 560660.14 MWD+IFR-AK-CAZ-SC ~ 11489.79 91.26 185.45 3511. 92 3390.62 -6980 .17 1837.39 5939092. 08 560653.31 MWD+IFR-AK-CAZ-SC 11584.01 91.50 185.52 3509. 65 3388.35 -7073 .93 1828.38 5938998. 26 560645.04 MWD+IFR-AK-CAZ-SC 11679.35 91.07 183.83 3507. 52 3386.22 -7168 .92 1820.61 5938903. 21 560638.02 MWD+IFR-AK-CAZ-SC 11770.52 91.44 184.41 3505. 52 3384.22 -7259 .83 1814.07 5938812. 26 560632.18 MWD+IFR-AK-CAZ-SC 11863.30 91.07 183.04 3503. 49 3382.19 -7352 .39 1808.04 5938719. 67 560626.88 MWD+IFR-AK-CAZ-SC ~ ,~IIalliburton Company Survey Report Company: ConocoPhillipsAlaskalnc. Date: 10/18/2006 Time: 08:19:02 P.~;;e: a Field: Kuparuk River Unit Go-ordiuate(NE)fteference: Weil: 1J-102, True North Site: Kuparuk 1J Pad Vertical (TVD) Re[e~ence: 1J-102L2: 121.3 Well: 1J-102 Sectio~r (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-10212 Survey Calculation Method: MinimumCurvature Db: Orade Surve~~ MD __ Incl Azim TVD Sys TVD Nl5 E1W htapN MapE Tool ', ft deg deg ft ft ft ft ft ft 11954 .41 90.32 181.75 3502. 38 3381.08 -7443.42 1804.23 5938628.63 560623 .78 MWD+IFR-AK-CAZ-SC 12046 .70 90.45 178.46 3501. 76 3380.46 -7535.69 1804.06 5938536.36 560624. 33 MWD+IFR-AK-CAZ-SC 12060 .81 90.90 178.05 3501. 59 3380.29 -7549.79 1804.49 5938522.26 560624. 87 MWD+IFR-AK-CAZ-SC . 12095 .00 90.90 178.05 3501. 06 3379.76 -7583.96 1805.66 5938488.11 _ 560626. 30 .- PROJECTED to TD ~Ialliburton Company Survey Report Company: CanocoPhillipsAlaska Inc. Date: 10/16/2Dp6 Time: 15:56:39 Pale: 1 Field: Kuparuk River Unit Co -ordinate(NE) Rcfercncr. Well: 1J-102, T rue North Site: Kuparuk 1J Pad Ve rtical (TVD)-'Rc fcrcucr. 1J-102L2PB1: 121.3 Well: 1J-102- Section (VS) llrfcr cncc Well (O.OON,O.OOE,180:OOAzf} Wellpath: 1J-102t2P81 Survey Calculatiuu iVlethod: Minimum`Curvature llb: Oracle Field: Kuparuk River Unit North Slope Alaska ~ United States Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 ~ Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre ~ Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1 J-102 Slot Name: ~ i Well Position: +N/-S 137.61 ft Northing: 5946057.02 ft Latitude: 70 15 47.611 N +E/-W -27.19 ft Easting : 558761.69 ft Longitude: 149 31 29.798 W Position Uncertainty: 0.00 ft j Wellpath: 1J-102L2PB1 Drilled From: 1J-102P61 500292331773 Tie-on Depth: 4664.00 ft Current Datum: 1J-102L2P61: Height 121.30 ft Above System Datum: Mean Sea Level Magnetic Data: 8/25/2006 Declination: 23.82 deg Field Strength: 57608 nT Mag Dip Angle: 80.80 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.30 0.00 0.00 180.00 Survey Program for Definitive Wellpath Date: 10/16/2006 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 121.00 820.00 1 J-102PB1 gyro (121.00-820.00) CB-GYRO-SS Camera based gyro single shot 869.87 4664.00 1 J-102P61 (869.87-8124.27) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4730.00 5757.03 1J-102L2P61 (4730. 00-5757.03) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey __ _ ~ __ 1V1D lrrcl Azim 'hD Sys 1VD 'V/S EIW ~11api1 MapF: -Fool ft deg deg ft ft ft ft ft ft 40.30 0.00 0.00 40.30 -81.00 0.00 0.00 5946057.02 558761.69 TIE LINE 121.00 0.45 106.20 121.00 -0.30 -0.09 0.30 5946056.93 558761.99 CB-GYRO-SS 220.00 0.78 44.56 219.99 98.69 0.28 1.15 5946057.31 558762.84 CB-GYRO-SS 320.00 4.66 32.21 319.86 198.56 4.21 3.79 5946061.26 558765.45 CB-GYRO-SS 420.00 8.21 30.63 419.22 297.92 13.79 9.60 5946070.88 558771.18 CB-GYRO-SS 520.00 12.54 26.87 517.56 396.26 29.63 18.15 5946086.78 558779.60 CB-GYRO-SS 620.00 15.71 25.57 614.52 493.22 51.53 28.90 5946108.77 558790.18 CB-GYRO-SS 720.00 18.93 27.89 709.98 588.68 78.08 42.34 5946135.43 558803.41 CB-GYRO-SS 820.00 23.00 33.80 803.35 682.05 108.67 60.80 5946166.15 558821.64 CB-GYRO-SS 869.87 23.17 37.49 849.23 727.93 124.55 72.19 5946182.12 558832.90 MWD+IFR-AK-CAZ-SC 964.72 24.49 38.35 935.99 814.69 154.78 95.75 5946212.53 558856.22 MWD+IFR-AK-CAZ-SC 1058.43 24.67 42.44 1021.21 899.91 184.45 121.00 5946242.39 558881.23 MWD+IFR-AK-CAZ-SC 1153.43 24.88 48.25 1107.48 986.18 212.39 149.29 5946270.55 558909.31 MWD+IFR-AK-CAZ-SC 1248.76 26.13 49.54 1193.52 1072.22 239.36 180.23 5946297.76 558940.03 MWD+IFR-AK-CAZ-SC 1342.77 27.89 48.40 1277.28 1155.98 267.40 212.42 5946326.04 558972.00 MWD+IFR-AK-CAZ-SC 1439.09 31.30 50.15 1361.02 1239.72 298.40 248.49 5946357.32 559007.82 MWD+IFR-AK-CAZ-SC 1535.84 30.64 50.08 1443.98 1322.68 330.32 286.69 5946389.54 559045.77 MWD+IFR-AK-CAZ-SC 1631.24 32.51 50.90 1525.25 1403.95 362.09 325.23 5946421.61 559084.06 MWD+IFR-AK-CAZ-SC 1723.25 36.09 52.10 1601.25 1479.95 394.35 365.82 5946454.17 559124.39 MWD+IFR-AK-CAZ-SC '~ 1821.35 41.06 53.68 1677.92 1556.62 431.20 414.61 5946491.40 559172.88 MWD+IFR-AK-CAZ-SC 1916.57 44.73 53.28 1747.67 1626.37 469.77 466.68 5946530.37 559224.65 MWD+IFR-AK-CAZ-SC 2010.97 45.69 55.27 1814.17 1692.87 508.88 521.07 5946569.90 559278.72 MWD+IFR-AK-CAZ-SC 2105.87 45.73 56.87 1880.44 1759.14 546.79 577.43 5946608.25 559334.78 MWD+IFR-AK-CAZ-SC 2201.01 47.60 61.41 1945.75 1824.45 582.23 636.82 5946644.15 559393.89 MWD+IFR-AK-CAZ-SC j i 2293.68 46.11 65.63 2009.14 1887.84 612.39 697.30 5946674.78 559454.12 MWD+IFR-AK-CAZ-SC 2391.30 46.49 70.60 2076.60 1955.30 638.67 762.75 5946701.57 559519.36 MWD+IFR-AK-CAZ-SC 2486.23 45.57 74.98 2142.53 2021.23 658.90 827.98 5946722.30 559584.42 MWD+IFR-AK-CAZ-SC 2581.48 43.53 80.15 2210.42 2089.12 673.33 893.17 5946737.23 559649.50 MWD+IFR-AK-CAZ-SC alliburton Company Survey Report ''fiompany: ConocoPhillipsAlaska Inc. Field: Kuparuk River Unit' Site: Kuparuk 1J Pad y~'ell: 1J-102 ~~'ellpath: 1J-102L2PB1 Survey Date: 10/16/2006 Time: 15:56:39 Page: _' Co-ordinate(NE) Reference: Well: 1J-102, True North Vertical (Tti'D) Reference: -1J-102LZPB1: 121.3 Section (VS) Reference: Well (O.OON;O.OOE,180AOAz) Survey Calculation ;Method: Minimum Curvature Dh: Oracle v[D Incl Aaim TVD Sys TVD 1V1S ft deg deg ft ft ` ft 2602 .96 43.39 80 .76 2226. 01 2104.71 675.78 2692 .50 43.33 80. 12 2291. 12 2169.82 685.99 2789 .32 41.08 80 .53 2362. 83 2241.53 696.92 2883 .45 39.91 82 .89 2434. 42 2313.12 705.75 2978 .49 42.09 87. 64 2506. 16 2384.86 710.84 3072 .35 42.28 89. 81 2575. 71 2454.41 712.24 3164 .88 43.18 96 .30 2643. 71 2522.41 708.87 3260 .78 43.19 102 .29 2713. 67 2592.37 698.28 3353 .79 43.31 108. 49 2781. 44 2660.14 681.38 3447 .64 44.63 113 .39 2849. 00 2727.70 658.07 3541 .79 46.90 119 .91 2914. 72 2793.42 627.78 3636 .01 48.89 126 .24 2977. 92 2856.62 589.62 3729 .21 49.70 132 .74 3038. 74 2917.44 544.72 3823 .40 49.11 138 .38 3100. 06 2978.76 493.70 3916 .77 49.70 146 .22 3160. 87 3039.57 437.67 4010 .22 51.80 150. 91 3220. 01 3098.71 375.94 4104 .27 55.02 157. 51 3276. 11 3154.81 307.98 4198 .08 57.40 161 .80 3328. 29 3206.99 234.90 4291 .04 62.13 164 .89 3375. 10 3253.80 157.97 4384 .47 65.15 169. 96 3416. 60 3295.30 76.30 4474 .72 66.68 173 .83 3453. 44 3332.14 -5.25 4566 .87 68.47 176 .21 3488. 59 3367.29 -90.10 4664 .00 72.68 180. 95 3520. 91 3399.61 -181.62 • 4730 .00 76.27 181. 66 3538. 57 ~ 3417.27 -245.18 4833 .97 81.93 182 .00 3558. 22 3436.92 -347.18 4927 .11 84.96 185 .86 3568. 86 3447.56 -439.47 5021. 49 89.18 187. 65 3573. 68 3452.38 -533.04 5115 .81 93.38 192 .16 3571. 57 3450.27 -625.89 5209 .41 93.11 189 .97 3566. 27 3444.97 -717.60 5303 .05 93.98 188 .57 3560. 48 3439.18 -809.83 5397. 45 93.67 186. 74 3554. 19 3432.89 -903.18 5491 .21 94.96 186 .64 3547. 13 3425.83 -996.04 5585 .13 92.47 184 .32 3541. 05 3419.75 -1089.32 ~ 5679. 20 93.68 181. 14 3536. 00 3414.70 -1183.13 5738 .86 91.11 177. 58 3533. 51 3412.21 -1242.72 5757 .03 88.53 175 .68 3533. 56 3412.26 -1260.86 i 5805 .00 88.53 175 .68 3534. 79 3413.49 -1308.67 E/W IV1ap\ b1apE fool ft ft ft 907.74 5946739.80 559664.04 MWD+IFR-AK-CAZ-SC 968.36 5946750.48 559724.58 MWD+IFR-AK-CAZ-SC 1032.48 5946761.91 559788.60 MWD+IFR-AK-CAZ-SC 1092.95 5946771.21 559849.00 MWD+IFR-AK-CAZ-SC 1155.05 5946776.78 559911.05 MWD+IFR-AK-CAZ-SC 1218.06 5946778.67 559974.04 MWD+IFR-AK-CAZ-SC 1280.68 5946775.79 560036.68 MWD+IFR-AK-CAZ-SC 1345.39 5946765.71 560101.46 MWD+IFR-AK-CAZ-SC 1406.77 5946749.29 560162.97 MWD+IFR-AK-CAZ-SC 1467.58 5946726.46 560223.95 MWD+IFR-AK-CAZ-SC 1527.77 5946696.65 560284.36 MWD+IFR-AK-CAZ-SC 1586.25 5946658.95 560343.14 MWD+IFR-AK-CAZ-SC 1640.70 5946614.47 560397.94 MWD+IFR-AK-CAZ-SC 1690.75 5946563.85 560448.38 MWD+IFR-AK-CAZ-SC 1734.03 5946508.17 560492.09 MWD+IFR-AK-CAZ-SC 1771.71 5946446.74 560530.25 MWD+IFR-AK-CAZ-SC 1804.45 5946379.04 560563.51 MWD+IFR-AK-CAZ-SC 1831.51 5946306.18 560591.13 MWD+IFR-AK-CAZ-SC 1854.46 5946229.45 560614.69 MWD+IFR-AK-CAZ-SC 1872.63 5946147.93 560633.49 MWD+IFR-AK-CAZ-SC 1884.23 5946066.48 560645.72 MWD+IFR-AK-CAZ-SC 1891.61 5945981.70 560653.77 MWD+IFR-AK-CAZ-SC 1893.83 5945890.20 560656.70 MWD+IFR-AK-CAZ-SC 1892.38 5945826.64 560655.74 MWD+IFR-AK-CAZ-SC 1889.12 5945724.62 560653.28 MWD+IFR-AK-CAZ-SC 1882.77 5945632.30 560647.65 MWD+IFR-AK-CAZ-SC 1871.68 5945538.65 560637.29 MWD+IFR-AK-CAZ-SC 1855.47 5945445.69 560621.81 MWD+IFR-AK-CAZ-SC 1837.54 5945353.85 560604.60 MWD+IFR-AK-CAZ-SC 1822.48 5945261.51 560590.26 MWD+IFR-AK-CAZ-SC 1809.94 5945168.08 560578.45 MWD+IFR-AK-CAZ-SC 1799.05 5945075.15 560568.28 MWD+IFR-AK-CAZ-SC 1790.10 5944981.81 560560.06 MWD+IFR-AK-CAZ-SC 1785.62 5944887.97 560556.32 MWD+IFR-AK-CAZ-SC 1786.29 5944828.40 560557.45 MWD+IFR-AK-CAZ-SC 1787.36 5944810.27 560558.66 MWD+IFR-AK-CAZ-SC 1790.97 5944762.49 560562.65 PROJECTED to TD ~Ialliburton Company +~ Survey Report Company: ConocoPhillips Alaska Inc. Date: 10/18/2006 Time: 08:13:18 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-102, True North Site: Kuparuk 1 J Pad Ve rticat (TVD) Re ference: 1 J-102L2P62 1 21.3 WeH: 1J-102 Section (VS)Reference: Well (0.OON,O.O OE,180.OOAzi) ~!'ellpath: 1J-102L2PB2 Su rvey Calculation Method: Minimum Curvature Db: Oracle Field: Kuparuk River Unit I North Slope Alaska United States Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1 J-102 Slot Name: Well Position: +N/-S 137.61 ft Northing: 5946057.02 ft Latitude: 70 15 47.611 N +E/-W -27.19 ft Easti ng : 558761.69 ft Longitude: 149 31 29.798 W Position Uncertainty: 0.00 ft Wellpath: 1J-102L2P62 Drilled From: 1J-102L2PB1 500292331774 Tie-on Depth: 5585.13 ft Current Datum: 1 J-102L2P62 Height 121.30 ft Above System Datum: Mean Sea Level Magnetic Data: 8/25/2006 Declination: 23.82 deg Field Strength: 57608 nT Mag Dip Angle: 80.80 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direcfion ft ft ft deg 40.30 0.00 0.00 180.00 Survey Program for DeSnitive Wellpath Date: 10/17/2006 Validated: No Version: 6 Actual From To Survey Toolcode Tool Name 1 ft ft 121.00 820.00 1J-102PB1 gyro (12 1.00-820.00) C B-GYRO-SS Camera based gyro single shot 869.87 4664.00 1J-102PB1 (869.87-8124.27) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4730.00 5585.13 1J-102L2PB1 (4730 .00-5757.03) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5640.00 9564.50 1 J-102L2PB2 (5640 .00-9564.50) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey MD Incl Aziui 'I'VD Sys'I'~'D N/5 E/V1' MapN btapE Tool ft deg deg ft ft k ft ft ft 40.30 0.00 0.00 40.30 -81.00 0.00 0.00 5946057.02 558761.69 TIE LINE I 121.00 0.45 106.20 121.00 -0.30 -0.09 0.30 5946056.93 558761.99 I CB-GYRO-SS 220.00 0.78 44.56 219.99 98.69 0.28 1.15 5946057.31 558762.84 CB-GYRO-SS 320.00 4.66 32.21 319.86 198.56 4.21 3.79 5946061.26 558765.45 CB-GYRO-SS 420.00 8.21 30.63 419.22 297.92 13.79 9.60 5946070.88 558771.18 CB-GYRO-SS 520.00 12.54 26.87 517.56 396.26 29.63 18.15 5946086.78 558779.60 CB-GYRO-SS 620.00 15.71 25.57 614.52 493.22 51.53 28.90 5946108.77 558790.18 CB-GYRO-SS 720.00 18.93 27.89 709.98 588.68 78.08 42.34 5946135.43 558803.41 CB-GYRO-SS 820.00 23.00 33.80 803.35 682.05 108.67 60.80 5946166.15 558821.64 CB-GYRO-SS 869.87 23.17 37.49 849.23 727.93 124.55 72.19 5946182.12 558832.90 MWD+tFR-AK-CAZ-SC i 964.72 24.49 38.35 935.99 814.69 154.78 95.75 5946212.53 558856.22 MWD+IFR-AK-CAZ-SC 1058.43 24.67 42.44 1021.21 899.91 184.45 121.00 5946242.39 558881.23 MWD+IFR-AK-CAZ-SC 1153.43 24.88 48.25 1107.48 986.18 212.39 149.29 5946270.55 558909.31 MWD+IFR-AK-CAZ-SC 1248.76 26.13 49.54 1193.52 1072.22 239.36 180.23 5946297.76 558940.03 MWD+IFR-AK-CAZ-SC I 1342.77 27.89 48.40 1277.28 1155.98 267.40 212.42 5946326.04 558972.00 MWD+IFR-AK-CAZ-SC 1439.09 31.30 50.15 1361.02 1239.72 298.40 248.49 5946357.32 559007.82 MWD+IFR-AK-CAZ-SC 1535.84 30.64 50.08 1443.98 1322.68 330.32 286.69 5946389.54 559045.77 MWD+IFR-AK-CAZ-SC ~! 1631.24 32.51 50.90 1525.25 1403.95 362.09 325.23 5946421.61 559084.06 MWD+IFR-AK-CAZ-SC 1723.25 36.09 52.10 1601.25 1479.95 394.35 365.82 5946454.17 559124.39 MWD+IFR-AK-CAZ-SC 1821.35 41.06 53.68 1677.92 1556.62 431.20 414.61 5946491.40 559172.88 MWD+IFR-AK-CAZ-SC 1916.57 44.73 53.28 1747.67 1626.37 469.77 466.68 5946530.37 559224.65 MWD+IFR-AK-CAZ-SC 2010.97 45.69 55.27 1814.17 1692.87 508.88 521.07 5946569.90 559278.72 MWD+IFR-AK-CAZ-SC ', 2105.87 45.73 56.87 1880.44 1759.14 546.79 577.43 5946608.25 559334.78 MWD+IFR-AK-CAZ-SC i 2201.01 47.60 61.41 1945.75 1824.45 582.23 636.82 5946644.15 559393.89 MWD+IFR-AK-CAZ-SC 2293.68 46.11 65.63 2009.14 1887.84 612.39 697.30 5946674.78 559454.12 MWD+IFR-AK-CAZ-SC ~, 2391.30 46.49 70.60 2076.60 1955.30 638.67 762.75 5946701.57 559519.36 MWD+IFR-AK-CAZ-SC 2486.23 45.57 74.98 2142.53 2021.23 658.90 827.98 5946722.30 559584.42 MWD+IFR-AK-CAZ-SC ,~Ialliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 10!18/2006 Trnn•: 08:13:18 Page:_ Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well; 1 J-102, True North Site: Kuparuk 1J Pad Vertical (TV"D) Reference: iJ-102L2PB2 121.3 Well: 1J-102 Section (VS) Reference: Well (O.OON,O:OOE,180.OOAz) 1Veltpath: 1J-102L2PB2 Survey Calculation Method: Minimum Curvature Db: Oracle Survey NID Inc! Azim l ~ I) Sys TVD 'Vl5 E/W ~1apA MapE Tool ft deg deg ft ft ft ft ft ft 2581.48 43.53 80.15 2210.42 2089.12 673.33 893.17 5946737.23 559649.50 MWD+IFR-AK-CAZ-SC 2602.96 43.39 80.76 2226.01 2104.71 675.78 907.74 5946739.80 559664.04 MWD+IFR-AK-CAZ-SC 2692.50 43.33 80.12 2291.12 2169.82 685.99 968.36 5946750.48 559724.58 MWD+IFR-AK-CAZ-SC 2789.32 41.08 80.53 2362.83 2241.53 696.92 1032.48 5946761.91 559788.60 MWD+IFR-AK-CAZ-SC 2883.45 39.91 82.89 2434.42 2313.12 705.75 1092.95 5946771.21 559849.00 MWD+IFR-AK-CAZ-SC 2978.49 42.09 87.64 2506.16 2384.86 710.84 1155.05 5946776.78 559911.05 MWD+IFR-AK-CAZ-SC 3072.35 42.28 89.81 2575.71 2454.41 712.24 1218.06 5946778.67 559974.04 MWD+IFR-AK-CAZ-SC 3164.88 43.18 96.30 2643.71 2522.41 708.87 1280.68 5946775.79 560036.68 MWD+IFR-AK-CAZ-SC 3260.78 43.19 102.29 2713.67 2592.37 698.28 1345.39 5946765.71 560101.46 MWD+IFR-AK-CAZ-SC 3353.79 43.31 108.49 2781.44 2660.14 681.38 1406.77 5946749.29 560162.97 MWD+IFR-AK-CAZ-SC 3447.64 44.63 113.39 2849.00 2727.70 658.07 1467.58 5946726.46 560223.95 MWD+IFR-AK-CAZ-SC 3541.79 46.90 119.91 2914.72 2793.42 627.78 1527.77 5946696.65 560284.36 MWD+IFR-AK-CAZ-SC 3636.01 48.89 126.24 2977.92 2856.62 589.62 1586.25 5946658.95 560343.14 MWD+IFR-AK-CAZ-SC 3729.21 49.70 132.74 3038.74 2917.44 544.72 1640.70 5946614.47 560397.94 MWD+IFR-AK-CAZ-SC 3823.40 49.11 138.38 3100.06 2978.76 493.70 1690.75 5946563.85 560448.38 MWD+IFR-AK-CAZ-SC 3916.77 49.70 146.22 3160.87 3039.57 437.67 1734.03 5946508.17 560492.09 MWD+IFR-AK-CAZ-SC 4010.22 51.80 150.91 3220.01 3098.71 375.94 1771.71 5946446.74 560530.25 MWD+IFR-AK-CAZ-SC 4104.27 55.02 157.51 3276.11 3154.81 307.98 1804.45 5946379.04 560563.51 MWD+IFR-AK-CAZ-SC 4198.08 57.40 161.80 3328.29 3206.99 234.90 1831.51 5946306.18 560591.13 MWD+IFR-AK-CAZ-SC ~ 4291.04 62.13 164.89 3375.10 3253.80 157.97 1854.46 5946229.45 560614.69 MWD+IFR-AK-CAZ-SC 4384.47 65.15 169.96 3416.60 3295.30 76.30 1872.63 5946147.93 560633.49 MWD+IFR-AK-CAZ-SC 4474.72 66.68 173.83 3453.44 3332.14 -5.25 1884.23 5946066.48 560645.72 MWD+IFR-AK-CAZ-SC 4566.87 68.47 176.21 3488.59 3367.29 -90.10 1891.61 5945981.70 560653.77 MWD+IFR-AK-CAZ-SC 4664.00 72.68 180.95 3520.91 3399.61 -181.62 1893.83 5945890.20 560656.70 MWD+IFR-AK-CAZ-SC 4730.00 76.27 181.66 3538.57 3417.27 -245.18 1892.38 5945826.64 560655.74 MWD+IFR-AK-CAZ-SC 4833.97 81.93 182.00 3558.22 3436.92 -347.18 1889.12 5945724.62 560653.28 MWD+IFR-AK-CAZ-SC ~ 4927.11 84.96 185.86 3568.86 3447.56 -439.47 1882.77 5945632.30 560647.65 MWD+IFR-AK-CAZ-SC 5021.49 89.18 187.65 3573.68 3452.38 -533.04 1871.68 5945538.65 560637.29 MWD+IFR-AK-CAZ-SC 5115.81 93.38 192.16 3571.57 3450.27 -625.89 1855.47 5945445.69 560621.81 MWD+IFR-AK-CAZ-SC 5209.41 93.11 189.97 3566.27 3444.97 -717.60 1837.54 5945353.85 560604.60 MWD+IFR-AK-CAZ-SC 5303.05 93.98 188.57 3560.48 3439.18 -809.83 1822.48 5945261.51 560590.26 MWD+IFR-AK-CAZ-SC 5397.45 93.67 186.74 3554.19 3432.89 -903.18 1809.94 5945168.08 560578.45 MWD+IFR-AK-CAZ-SC 5491.21 94.96 186.64 3547.13 3425.83 -996.04 1799.05 5945075.15 560568.28 MWD+IFR-AK-CAZ-SC 5585.13 92.47 184.32 3541.05 3419.75 -1089.32 1790.10 5944981.81 560560.06 MWD+IFR-AK-CAZ-SC 5640.00 93.18 182.47 3538.34 3417.04 -1144.02 1786.85 5944927.09 560557.25 MWD+IFR-AK-CAZ-SC 5679.43 89.90 181.24 3537.28 3415.98 -1183.41 1785.58 5944887.69 560556.28 MWD+IFR-AK-CAZ-SC 5772.26 91.51 180.88 3536.14 3414.84 -1276.21 1783.86 5944794.89 560555.28 MWD+IFR-AK-CAZ-SC 5865.24 91.00 176.87 3534.10 3412.80 -1369.13 1785.69 5944701.99 560557.83 MWD+IFR-AK-CAZ-SC I 5960.71 91.26 176.39 3532.22 3410.92 -1464.42 1791.30 5944606.76 560564.19 MWD+IFR-AK-CAZ-SC 6024.35 89.45 173.85 3531.83 3410.53 -1527.82 1796.71 5944543.41 560570.10 MWD+IFR-AK-CAZ-SC 6054.32 90.97 173.70 3531.72 3410.42 -1557.61 1799.96 5944513.65 560573.58 MWD+IFR-AK-CAZ-SC 6147.62 89.83 169.04 3531.06 3409.76 -1649.83 1813.96 5944421.56 560588.29 MWD+IFR-AK-CAZ-SC 6240.68 90.77 173.19 3530.58 3409.28 -1741.75 1828.33 5944329.76 560603.38 MWD+IFR-AK-CAZ-SC 6334.05 91.82 175.63 3528.47 3407.17 -1834.64 1837.42 5944236.95 560613.19 MWD+IFR-AK-CAZ-SC 6428.32 90.63 178.78 3526.45 3405.15 -1928.76 1842.01 5944142.87 560618.52 MWD+IFR-AK-CAZ-SC 6521.64 88.96 182.57 3526.78 3405.48 -2022.06 1840.91 5944049.58 560618.15 MWD+IFR-AK-CAZ-SC 6616.50 90.34 186.65 3527.36 3406.06 -2116.59 1833.29 5943955.01 560611.27 MWD+IFR-AK-CAZ-SC ', 6709.57 91.26 186.08 3526.06 3404.76 -2209.07 1822.97 5943862.45 560601.67 MWD+IFR-AK-CAZ-SC 6803.56 91.25 187.05 3524.01 3402.71 -2302.42 1812.23 5943769.03 560591.66 MWD+IFR-AK-CAZ-SC ~ 6897.45 91.87 183.78 3521.45 3400.15 -2395.85 1803.38 5943675.55 560583.53 MWD+IFR-AK-CAZ-SC 6991.15 91.81 181.50 3518.44 3397.14 -2489.39 1799.06 5943581.98 560579.95 MWD+IFR-AK-CAZ-SC 7084.20 90.13 175.81 3516.86 3395.56 -2582.36 1801.25 5943489.04 560582.86 MWD+IFR-AK-CAZ-SC 7178.46 89.96 170.64 3516.79 3395.49 -2675.93 1812.36 5943395.57 560594.70 MWD+IFR-AK-CAZ-SC ,~Ialliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 10/18/2006 Time: 08:13:18 Page: 3 Rield: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-102, True North Site: Kuparuk 1J Pad Vertical (TVD)-Reference: 1J-102L2PB2 121.3 Well: 1J-102 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-102L2P62 Survey Calculation ;Method: Minimum Curvature Db: Oracle Survcv __J1D lncl Azim T~'D SvsTVD N/S E/W i~1apN MapE Tool - ft deg deg ft ft ft ft ft ft 7273.17 90. 70 173.81 3516. 24 3394 .94 -2769.76 1825 .17 5943301.86 560608. 25 MWD+IFR-AK-CAZ-SC 7367.10 89. 71 175.16 3515. 91 3394. 61 -2863.25 1834 .20 5943208.45 560618. 00 MWD+IFR-AK-CAZ-SC 7461.10 89. 53 177.74 3516. 53 3395 .23 -2957.06 1840 .02 5943114.70 560624. 55 MWD+IFR-AK-CAZ-SC 7554.49 90. 02 179.17 3516. 90 3395. 60 -3050.41 1842 .54 5943021.37 560627. 80 MWD+IFR-AK-CAZ-SC 7648.06 90. 02 182.40 3516. 87 3395. 57 -3143.96 1841 .26 5942927.83 560627. 25 MWD+IFR-AK-CAZ-SC 7742.48 88. 96 180.68 3517. 71 3396. 41 -3238.34 1838 .72 5942833.44 560625. 45 MWD+IFR-AK-CAZ-SC 7835.76 89. 72 177.49 3518. 78 3397. 48 -3331.59 1840 .21 5942740.22 560627. 66 MWD+IFR-AK-CAZ-SC 7930.78 90. 02 179.35 3519. 00 3397. 70 -3426.56 1842 .83 5942645.27 560631. 02 MWD+IFR-AK-CAZ-SC 8024.06 90. 08 178.66 3518. 92 3397. 62 -3519.83 1844 .45 5942552.03 560633. 37 MWD+IFR-AK-CAZ-SC 8117.60 90. 64 181.77 3518. 33 3397 .03 -3613.36 1844 .10 5942458.51 560633. 75 MWD+IFR-AK-CAZ-SC 8211.12 89. 64 181.28 3518. 10 3396. 80 -3706.84 1841 .61 5942365.02 560631. 99 MWD+IFR-AK-CAZ-SC 8303.73 88. 97 181.75 3519. 22 3397. 92 -3799.41 1839 .16 5942272.44 560630. 27 MWD+IFR-AK-CAZ-SC 8398.36 89. 84 182.10 3520. 20 3398. 90 -3893.98 1835 .98 5942177.86 560627. 83 MWD+IFR-AK-CAZ-SC 8495.99 89. 59 183.95 3520. 69 3399. 39 -3991.47 1830 .83 5942080.34 560623. 44 MWD+IFR-AK-CAZ-SC 8587.51 90. 39 182.32 3520. 71 3399. 41 -4082.85 1825 .82 5941988.94 560619. 14 MWD+IFR-AK-CAZ-SC 8680.80 90. 14 180.28 3520. 27 3398 .97 -4176.11 1823 .71 5941895.67 560617. 76 MWD+IFR-AK-CAZ-SC 8773.99 89. 28 178.25 3520. 75 3399 .45 -4269.28 1824 .90 5941802.52 560619. 68 MWD+IFR-AK-CAZ-SC 8866.41 89. 22 179.57 3521. 96 3400. 66 -4361.68 1826 .66 5941710. i 5 560622. 16 MWD+IFR-AK-CAZ-SC 8960.13 90. 40 180.76 3522. 27 3400. 97 -4455.39 1826 .39 5941616.44 560622. 62 MWD+IFR-AK-CAZ-SC 9055.05 90. 89 176.54 3521. 20 3399. 90 -4550.26 1828 .63 5941521.61 560625. 59 MWD+IFR-AK-CAZ-SC 9147.46 89. 02 175.20 3521. 27 3399 .97 -4642.42 1835 .28 5941429.51 560632. 97 MWD+IFR-AK-CAZ-SC 9241.69 88. 54 178.90 3523. 28 3401 .98 -4736.49 1840 .13 5941335.49 560638. 55 MWD+IFR-AK-CAZ-SC 9335.66 90. 46 182.37 3524. 10 3402 .80 -4830.43 1839 .09 5941241.55 560638. 24 MWD+IFR-AK-CAZ-SC 9428.80 89. 58 182.68 3524. 07 3402 .77 -4923.48 1834 .98 5941148.48 560634. 86 MWD+IFR-AK-CAZ-SC 9523.63 90. 27 183.01 3524. 19 3402. 89 -5018.19 1830 .28 5941053.74 560630. 90 MWD+IFR-AK-CAZ-SC 9564.50 94. 27 185.06 3522. 57 3401. 27 -5058.92 1827 .41 5941013.00 560628. 34 MWD+IFR-AK-CAZ-SC 9599.00 94. 27 185.06 3520. 00 3398. 70 -5093.19 1824 .37 5940978.71 560625. 58 PROJECTED to TD '~'' ~ono~oPhliips Time Log Summary bk'~Ifvlt:+W 4'VeU Reparirng Time Lo s ..Date From To Dur S. De th E. De th Phase Code.. Subcode T COM 08/15/2006 06:00 10:00 4.00 MIRU MOVE DMOB P Rig Released form 1J-109 @ 0600 HRS. Prepare Rig Floor for Skid. Rig down Handi-Berms on Pit Module, Clean out Cellar Box & Pollution Pan. Move Rock Washer. 10:00 11:30 1.50 MIRU MOVE SFTY P Held "Fall Arrest" Training at Doyon 141. 11:30 12:15 0.75 MIRU MOVE DMOB P PJSM wit crew. Discuss Safety Issues and procedure for moving Rig and Modules. Discuss new hands in new ositions. 12:15 13:00 0.75 MIRU MOVE DMOB P Turn tires on rig, and install drag Links on front & rear of pit module. 13:00 14:15 1.25 MIRU MOVE SFTY P Held "Fall Arrest" Training at Doyon 141 with rew #2. 14:15 14:45 0.50 MIRU MOVE DMOB P Move Pit Complex out of the way and down the ad. 14:45 15:00 0.25 MIRU MOVE DMOB P PJSM with crew. Discuss Safety issue s and procedure for skidding rig floor and derrick. 15:00 16:45 1.75 MIRU MOVE DMOB P Skid rig floor and Derrick. 16:45 17:00 0.25 MIRU MOVE SFTY P PJSM with crew and Crane operator. Discuss safety issues and procedurte for removing windwall section from roof of ri floor. 17:00 18:00 1.00 MIRU MOVE DMOB P Rig up & remove windwall section from roof of rig, with crane. No issues. Crew Chan e 18:00 19:00 1.00 MIRU MOVE DMOB P Prepare cellar for rig move. Lift Stompers, open windwall doors, and chain off same. Prepare Sub Complex for movin . 19:00 20:30 1.50 MIRU MOVE MOB P Move Sub Module off of 1J-109, onto ad area out of the wa . 20:30 23:00 2.50 MIRU MOVE MOB P Remove and stack all matting boards used under rig. Remove all pit liner. Clean location area, and set down Pit Liner on 1J-102. 23:00 00:00 1.00 MIRU MOVE MOB P Continue laying down pit liner on 1J-102 location. Install rig mats as tanned for ri move. 08/16!2006 00:00 03:00 3.00 MIRU ll~lOl~E MOB P Continue to set matting boards on location in re aration for ri move. 03:00 06:00 3.00 MIRU MOVE MOB P Move sub base over well to spot and center u .Crew Chan e Page 1 of'69 Time Logs `Date From To Dur S. D E. De th Phase Code.. Subcode T C 08/16/2006 06:00 12:00 6.00 MIRU MOVE MOB P Continue to move & spot pit complex. Level rig and pit complex. Lower stompers in cellar. Rig released to Summer Maintenance scheduie @ 1200 HRS. 12:00 00:00 12.00 MIRU RIGMN RGRP P Summer Maintenance. Details in Non Well Activit re ort. 08/24/2006 18:00 00:00 6.00 MIRU WELCT NUND P Rig accepted @ 1800 HRS as per Doyon 15 Rig acceptance checklist. Nipple up diverter system & diverter lines, and check lock downs as per Vetco Rep. Install signs on location for rig on diverter. Check & trim all herculite. Pull hand tools, tongs, elevators and slips to rig floor. Load mud pits with 1 load of spud mud from plant. Load & strap 5" DP &HWDP into shed. Load BHA into pipe shed. Inspect & adjust brakes on draw works. 08/25/2006 00:00 02:30 2.50 MIRU DRILL RURD P Install signs on location for rig on diverter. Check & trim all herculite. Pull hand tools, tongs, elevators and slips to rig floor. Load mud pits with 1 load of spud mud from plant. Strap 5" DP & HWDP in shed. Load BHA into pipe shed. Inspect & adjust brakes on draw works. Install mouse hole in rotary table for ickin u DP. 02:30 03:00 0.50 MIRU DRILL SFTY P Held PJSM with entire crew and Varco representative. Discuss safety issues and procedure for picking up 5" DP and racking back same. Discuus training on new ST-80 Iron roughneck while PU DP. 03:00 06:00 3.00 MIRU DRILL PULD P Pickup 63 joints (21 stands) of 5" drill pipe from shed. Rack back in derrick. NOTE: Varco rep on rig floor training hands on operation of new ST-80 iron roughneck. Pick up 20 joints of 5" HWDP with 8" Drilling jars, and rack back in derrick. Crew Change. Note: Rig crews attending SIMS training @ KOC. 06:00 06:15 0.25 MIRU DRILL RURD P Calibrate Block Height for MWD. 06:15 07:00 0.75 MIRU DRILL PULD P Continue to pick up 5" HWDP and rack back stands in derrick. Total of 7 Stands. 07:00 08:45 1.75 MIRU DRILL RURD P Pull mouse hole from rotary table. Pick up 8" Dailey drilling jar, and make up to 5" HWDP double, rack in derrick. !ns ect saver sub. Page 2 of 69 Time Logs <Date From To Dur S. D E. De th Phase Code Subcode T COM Page 3 of 69 08/25/2006 08:45 09:15 0.50 MIRU RIGMN RGRP P Clean & clear rig floor area. Rig up to change out saver sub on Top Drive. Held PJSM -discuss safety issues and procedure for changing out saver sub. Discuss hazards and record on HR card. 09:15 11:30 2.25 MIRU RIGMN RGRP P Change out saver sub on Top Drive. 11:30 12:00 0.50 MIRU DRILL OTHR P Pick up 1 stand of DP from derrick. RIH tag bottom @ 106' RKB, Indicating 14' of cement to drill. 12:00 12:30 0.50 MIRU WELCT BOPE P Function test 21 1/4" Diverter system. Check all lines & valves. Hydril closed in 33 seconds, Knife valve in 3 secorids. Accumulator system pressure = 2900 PSI. 5 bottle nitogen pressure avg = 2400 PSI. All gas aiarms tested. Witness of test waived b Chuck Sheave with AOGCC. 12:30 13:15 0.75 MIRU WELCT BOPE P Perform Accumulator draw down test. Pressure from 2900 PSI, to 1600 PSI when closed. 33 seconds for 200 PSI increase with full Accumulator pressure back @ 2 minutes, 12 seconds. 13:15 14:00 0.75 MIRU WELCT BOPE P Flood all lines & diverter system. Perform surface equipment test on all equipment & lines to 2500 PSI. Low ressure test 500 PSI. 14:00 14:45 0.75 MIRU DRILL RURD P Held PJSM. Discuss safety issues and procedure for rigging up Halliburton Gyro survey unit. Spot & Rig up unit with sheaves to ri floor. 14:45 16:15 1.50 SURFA DRILL PULD P Make up BHA#1.13 1/2" drilling assembly with 13 1/2" Hughes MX-1 PDC bit with 1 x 13, and 3 x 20 jets for a TFA of 1.050 Sq in" (1.70') SperryDrill Lobe 4/5 - 5.3 stage 28.85' & HWDP to s ud. 16:15 16:30 0.25 106 120 SURFA DRILL DRLG P RIH with drilling assembly. Tag and wash from 106' - 120' MD. Observe cement returns. 16:30 17:30 1.00 120 220 SURFA DRILL DDRL P Spud & directional drill 13 1/2" surface hole from 120' - 220' MD(100'). TVD = 220'. UP WT = 92K, SO WT = 80K, ROT WT = 80K. 50 RPM's. Pumps @ 450 GPM's - 700 PSI. 750 PSI on bottom. Max gas = 18.1 units. Bit Hrs _ .77, AST = .77 HRS. Total Jar Hrs = 74.45. Mud wt = 9.0 PPG, Visc = 320, YP = 63, Gels 39/59/67 17:30 18:00 0.50 220 30 SURFA DRILL TRIP P POOH with drilling assembly from 220' to 30' for make up of remaining BHA. Crew chan e. 18:00 19:00 1.00 30 122 SURFA DRILL PULD P Pick up 3 Non Mag Flex drill collars. 92.03' from i r shed. Time Logs Date From To Dur S. D ~ E. De th Phase 'Code Subcode T COM 08/25/2006 19:00 00:00 5.00 220 570 SURFA DRILL DDRL P Continue driectional drill 13 1/2" surface hole from 220' - 570' MD(350'). TVD = 563'. UP WT = 108K, SO WT = 105K, ROT WT = 105K. WOB = 10-30K. 50 RPM's. Pumps @ 525 GPM's - 1250 PSI. 1300 PSI on bottom. Max gas = 0 units. Bit Hrs = 3.27, ADT = 2.50 Hrs, AST = 2.10 HRS. ART = .40 Total Jar Hrs = 76.95. Mud wt = 9.0 PPG, Visc = 320, YP = 63, Gels @ 39/59/67. Obtain Gyro surve s 121' and 220'. 08/26/2006 00:00 04:00 4.00 570 905 SURFA DRILL DDRL P Continue driectional drill 13 1/2" surface hole from 570' - 905' MD(335'). TVD = 874'. UP WT = 114K, SO WT = 111 K, ROT WT = 110K. WOB = 10-20K. 90 RPM's. Pumps @ 700 GPM's - 1850 PSI. 1950 PSI on bottom. Max gas = 0 units. Bit Hrs = 5.52, ADT = 2.25 Hrs, AST = 2.00 HRS. ART = .25 Total Jar Hrs = 79.20. Mud wt = 9.4 PPG, Visc = 280, YP = 60, Gels 39/59/67. Crew Chan e 04:00 04:45 0.75 905 905 SURFA DRILL SRVY P Run Gyro surveys at depths of 220', 320', 420', 520', 620', 720', and 820'. WLOH & rig down Halliburton gyro unit. 04:45 06:00 1.25 905 1,041 SURFA DRILL DDRL P Continue driectional drill 13 1/2" surface hole from 905' - 1041 MD(136'). TVD = 1008'. UP WT = 122K, SO WT = 115K, ROT WT = 120K. WOB = 20-25K. 90 RPM's. Pumps @ 600 GPM's - 1700 PSI. 1800 PSI on bottom. Max gas = 10 units. Bit Hrs = 6.44, ADT = 3.17 Hrs, AST = 2.10 HRS. ART = 1,07 Total Jar Hrs = 80.12. Mud wt = 9.3 PPG, Visc = 300, YP = 63, Gels @ 39/59/67. Survey @ 964.72 MD, TVD - 936', INC = 24.49 De , AZ - 38.35 De .Crew Chan e 06:00 12:00 6.00 1,041 1,634 SURFA DRILL DDRL P Continue driectional drill 13 1/2" surface hole from 1041' - 1634' MD(593'). TVD = 1529'. UP WT = 142K, SO WT = 121 K, ROT WT = 130K. WOB = 20-30K. 90 RPM's. Pumps @ 650 GPM's - 1950 PSI. 2280 PSI on bottom. Max gas = 42 units. Bit Hrs = 10.06, ADT = 3.62 Hrs, AST = 2.24 HRS. ART = 1.38 Total Jar Hrs = 83.74. Mud wt = 9.3 PPG, Visc = 300, YP = 63, Gels @ 39/59/67. Survey @ 1631.24 MD, TVD - 1525.25', INC = 32.51 Deg, AZ - 50.90 De . Page 4 of 69 ~ Yl~to Gr.,.,~, T., fli it 4 rl ~~ F flAnth DI-~~eo (`nria ~~ihrnria T ('flM ~ 08/26/2006 12:00 18:00 6.00 1,634 2,262 SURFA DRILL DDRL P Continue driectional drill 13 1/2" surface hole from 1634' - 2262' MD(628'). TVD = 1986'. UP WT = 146K, SO WT = 125K, ROT WT = 135K. WOB = 20-30K. 90 RPM's. Pumps @ 650 GPM's - 2000 PSI. 2350 PSI on bottom. Max gas = 42 units. Bit Hrs = 12.72, ADT = 2.66 Hrs, AST = 1.40 HRS. ART = 1.26 Total Jar Hrs = 86.40. Mud wt = 9.4 PPG, Visc = 300, YP = 63, Gels @ 39/59/67. Survey @ 2201.01 MD, TVD - 1945.75', INC = 47.60 Deg, AZ - 61.41 De .Crew Chan e 1$:00 22:00 4.00 2,262 2,652 SURFA DRILL DDRL P Continue driectional drill i3 1/2" surface hole from 2262' - 2652' MD(390'). TVD = 2259'. UP WT = 160K, SO WT = 122K, ROT WT = 135K. WOB = 20-25K. 90 RPM's. Pumps @ 700 GPM's - 2350 PSI. 2500 PSI on bottom. Max gas = 40 units. Bit Hrs = 15.10, ADT = 2.38 Hrs, AST = 1.22 HRS. ART = 1.16 Total Jar Hrs = 88.78. Mud wt = 9.4 PPG, Visc = 300, YP = 63, Gels @ 39/59/67. Survey @ 2602.96 MD, TVD - 2226.01', INC = 43.39 Deg, AZ - 80.76 Deg. Obtain last survey on bottom. 22:00 00:00 2.00 2,652 1,965 SURFA DRILL REAM P BROOH from 2652' -1965' (687'). pumps @ 700 GPMs - 2300 PSI. 90 RPM's with 3-5K torque. Pull slow for 4 stands at 10 ft/ minute allowing for good bottoms up. Then increase pulling speed to 35 - 40 ft/minute. Decrease pump rates to 600 GPMs- 2000 PSI @ 2000'. Observe good hole conditions. 08/27/2006 00:00 02:00 2.00 1,965 791 SURFA DRILL REAM P Continue BROOH from 1965' - 791' (1174'). Pumps @ 500 GPMs - 1650 PSI. 90 RPM's with 3-5K torque. Pulling speed @ 45 - 50 ft/minute. Decrease pump rates to 500 GPMs- 1350 PSI @ 1300'. Observe good hole conditions. 02:00 02:15 0.25 791 791 SURFA DRILL PULD P Clean, breakout & lay down 13 1/2" Ghost reamer. 02:15 04:45 2.50 791 66 SURFA DRILL TRIP P Continue POOH on elevators from 791' - 66' racking back 5" HWDP & drilling jars (655'), and laying down 3 - 8" Non Mag Flex drill collars (93.03'). Breakout & lay down 8" Non Mag UBHO sub (3.38'), and 8" Non mag Flaot Sub (2.41'). Observing good hole conditions with ro er hole fill. Page 5 of 69 I'"n..~,, c..,.., T„ n~~r C no'nTF, G no..+h Dhow CnNo Gihrnrln T (`(1RA I 08/27/2006 04:45 05:15 0.50 66 0 SURFA DRILL PULD P Continue POOH break out & lay down remaining BHA. Lay down 8" MPT w/ DIR (24.97'), 8" Non Mag pressure drop sub (2.03'), 8" Integral Blade Stabilizer (6.99'), *" SperyDrill Lobe 4/5 - 5.3 stg Mud motor (28.85'), and 13 1/2" Hughes MX-1 Bit. Inspect & gauge bit to 2/1/BT/I/E/1/16/ERlTD 05:15 05:45 0.50 0 0 SURFA DRILL PULD P Clean & clear Floor area. Lay down tools. 05:45 06:00 0.25 0 0 SURFA CASIN( RURD P Rig up to run 10 3/4 casing. Rig up to make dummy run with casing hanger & landin 'oint. Crew Chan e 06:00 08:00 2.00 0 0 SURFA CASIN( RURD P Continue rig up to run 10 3/4" casing strip .. 08:00 08:15 0.25 0 0 SURFA CASIN( SFTY P Held PJSM with crew &GBR casing service. Discuss Safety issues and rocedure for runnin 10 3/4" Casin . C8:15 12:OC 3.75 0 1,250 SURFA CASIN( RI`!CS p snake up 10 3/4" shoe joint :vith Weatherford Model 303 Sure Seal Float shoe (1.75'), and 2 joints 10 3/4 45.5# L80 casing (79.88') Weather Modei 402 Sure Seal Float Collar (1.42'). Check floats -Good. Continue run 10 3/4" casing filling every joint with Franks fill up tool. Circulate 2 'oints down after eve 10 ran. 12:00 14:45 2.75 1,250 2,642 SURFA CASIN( RNCS P Continue run 10 3/4" casing filling every joint with Franks fill up tool. Circulate 2 joints down after every 10 ran. Circulate down joints # 63 & 64 (2514' - 2596'). Pick up landing joint with vetco Gray casing hanger. Change out anti rotation handling sub. Land 10 3/4" casing with hanger. Shoe de th = 2642.83' MD TVD = 2252'. 14:45 15:15 0.50 2,642 2,642 SURFA CEME~ RURD P Rig down GBR casing crew. Clean & clear floor of all running tools. Reci rocate casin strip . 15:15 16:15 1.00 2,642 2,642 SURFA CEMEf~ RURD P Rig up and install 10 3/4" cement head in landin 'oint. Ri u lines. 16:15 16:30 0.25 2,642 2,642 SURFA CEMEt~ CIRC P Break circulation @ 4 BPM- 130 PSI. UP WT = 190K, SO WT = 130K. Increase pump rate to 5 BPM - 190 PSI. Observed O ring failed in cement head. Shut down um s, land hap er. 16:30 18:00 1.50 2,642 2,642 SURFA CEMEI~ RURD T Rig down cement head & change out O ring in cement head. Make up cement head &. lines. Crew Chanoe. Page 6 of 63 Time Logs Date From To Dur S De E. De th Phase. .Code.. Subcode T COM 08/27/2006 18:00 20:00 2.00 2,642 2,642 SURFA CEMEf~ CIRC P Circulate & condition mud to pre cement properties of 9.6 PPG, Visc = 50, PV = 22, YP = 15, with Gels @ 6/8. Reciprocate casing string. UP WT = 195K, SO WT = 140K. Held PJSM with entire rig team, truck drivers and cement crew. Discuss safety issues, hazard recognition and procedure to rig u and um surface cement ~ob. . 20:00 22:30 2.50 2,642 2,642 SURFA CEMEf~ CIRC P Turn rig over to Dowell Schlumberger cement crew. Pump 5 BBIs fresh water to flush lines. Pressure test lines to 3500 PSI -good test. Pump 50 BBIs of 8.3 PPG CW100 @ 6 BPM - 150 PSI. Pump 50 BBLS of 10.5 PPG MudPush II with Red Dye @ 5 BPM - 180 PSI. Drop bottom plug. Continue pump 389.4 BBLS of 10.7 PPG Lead cement @ 6.2 BPM - 225 PSI. Stop movement of casing string, and land in hanger 320 BBLS in to pumping Lead cement. Pump 76 BBLS of 12.0 PPG Tail cement @ 5.6 BPM - 275 PSI. Drop Top Plug. Pump 20 BBLS of fresh water for rinse & flush. Reciprocate casing string. UP WT = 220K, SO WT = 145K. 22:30 23:30 1.00 2,642 2,642 SURFA CEMEf~ DISP P Turn over to rig pumps. Displace cement job with 9.6 PPG mud, observing red dye to surface @ 125 strokes into displacement. Observe cement @ surface @ 1258 Strokes in to displacement. Pumps @ 7 BPM for 1175 stks. 6 BPM for 1380 stks, slowing to 5 BPM to 2148stks. Slow pumps to 3.5 BPM - 500 PSI to observe plugs bumped @ 2246 strokes, (226.17 BBLS). pressure to 1150 PSI. Hold pressure 5 minutes. Bleed pressure & check floats. Floats held. CIP @ 2300 HRS, Reciprocated csg 10'-15' until 66 bbls cement around shoe, then csg got tight and land same on hanger, Had 99.3 bbls good cement to surface. 23:30 00:00 0.50 2,642 0 SURFA CEMEf~ RURD P Rig down cement lines on rig floor. Rig down cement head, blow down all lines. Clean & flush all lines & valves & cement a ui ment. 08/28/2006 00:00 01:45 1.75 0 0 SURFA CEMEh RURD P Rig down cement head & lines. Flush Diverter riser & flow lines with rinsate from truck. Page 7 of 69 Time Lo s bate From ' To Dur S. be E. De th Phase Code Subcode T COM Page. 8 of 68 08/28/2006 01:45 04:00 2.25 0 0 SURFA WELCT NUND P Nipple down Diverter system. Remove Riser, and nipple down lines outside. Rig down long bales on top drive. Lay down spiders. Rig off of Hi -Line power and on Cat power @ 0330 HRS, to remove all Diverter equipment, and install wellhead a ui ment. 04:00 06:00 2.00 0 0 SURFA WELCT NUND P Continue nipple down Diverter system. Rinse Annular & lines with rinsate using vac truck. Remove Diverter system adapter flange as per Vetco Gray rep. SIMOPS: Work on Top drive Shot Pin assembly and Brake. Varco re on ri floor. 06:00 08:15 2.25 0 0 SURFA RPCO~ NUND P Clean out cellar box, Install Vetco Gray well head as per rep. Rig up & test wellhead seal to 5000 PSI, for 15 minutes - ood test. 08:15 08:45 0.50 0 0 SURFA WELCT NUND P Install double block drilling valve for annular. 08:45 12:00 3.25 0 0 SURFA WELCT NUND P Held PJSM with crew. Discuss safety issues and procedure for nippling up BOP's. Nipple up BOP's .Crew Chan e 12:00 18:00 6.00 0 0 SURFA WELCT NUND P Held PJSM with crew. Discuss safety issues and procedure for nippling up BOP's. Continue Nipple up BOP's . Install Koomey lines, kill lines, and choke line. Install 3 1/2" VBR's in top set of rams, and 7 5/8" rams in lower set of rams. SIMOPS: Begin changing Saver sub on To Drive. 18:00 20:30 2.50 0 0 SURFA WELCT OTHR P Continue change out saver sub on Top Drive. Remove 4 1/2 IF sub, Install 4" XT39 sub. Load pipe shed with 120 'oints of 4" XT39 drill i e. Stra same. 20:30 00:00 3.50 0 0 SURFA DRILL PULD P Held PJSM with crew. Discuss safety issues and procedure for picking up 4" DP and building stands & racking in derrick. Pick up 40 joints of 4" DP from pipe shed. Note: New crew being trained on proper operation of new ST80 iron rou hneck. Crew Chan e 08/29/2006 00:00 04:00 4.00 0 0 SURFA DRILL PULD P Held PJSM with crew. Discuss safety issues and procedure for picking up 4" DP and building stands & racking in derrick. Pick up 80 joints of 4" DP from pipe shed. Crew Change Rabbit 4" w/ 2.33" rabbit. 04:00 06:00 2.00 0 0 SURFA WELCT BOPE P L/D 4 stands of 5" HWDP. Rig up & test BOP's. Test 4-1/2" IF floor safety valve and dart valve to 250 psi low and 3000 si hi h. Hold each test 5 min. 06:00 08:00 2.00 0 0 SURFA WELCT NUND P PJSM, then PU and install riser, install flowline and ad'ust turnbuckles. 08:00 09:00 1.00 0 0 SURFA WELCT OTHR P RU to test BOPE. Fill stack w/ water. Time Lo s Date From _ To - Dur S. De E. De th Phase Gode Subcode T COM Page 9 of 69 08/29/2006 09:00 16:15 7.25 0 0 SURFA WELCT BOPE P Test BOPE to 250 psi low and 3000 psi high. Tested bottom pipe rams w/ 7-5/8" test jt. Test upper pipe rams (3-1/2" x 6") w/ 4" dp & 5" dp. Test annular w/ 4" dp. Tested all valves on choke manifold and kill and choke valves. Tested top drive IBOP. Witness of test waived by AOGCC inspector Chuck Sheave. 16:15 17:30 1.25 0 0 SURFA WELCT OTHR P Rig down testing equipment. Pull test plug. Install Vetco/Gray wear ring (10.75" OD x 9.9" ID, length 4.92'). Blow down choke manifold and cill and choke lines. 17:30 17:45 025 0 SURFA BRILL SFTY P PJSM on PU/MU BHA #2. 17:45 20:45 3.00 0 446 SURFA DRILL PULD P PU/MU BHA #2 to 446'. MU Hughes 9-7/8" EP5848 bit w/ (3) 20/32 and (1) 12/32 nozzle. 7" Soerrvdrill lobe 7/8-6 stage motor w/ 1.5 deg bend, nm float sub, welded blade stabilizer, MWD DM HOC, MWD Gamma/Res/PWD, MWD TM HOC, (3) 6-7/8" NM drill collars, (3) 5" HWDP, Drilling jar (6.2" OD), (5) 5" HWDP. 20:45 21:45 1.00 446 2,452 SURFA DRILL TRIP P RIH w/ BHA #2 f/ 446' to 2452'. Total of 21 stands of Weatherford 5" dp in hole. Installed Ghost reamer on top of stand #4. 21:45 22:15 0.50 2,452 2,452 SURFA DRILL OTHR P Change elevators to 4". Install bell uide f/ 4" d on to drive. 22:15 23:00 0.75 2,452 2,548 SURFA DRILL CIRC P Make top drive connection on stand #22. Fill pipe. Circulate bottom's up. Pumping 140 spm w/ 1850 psi. Pump 2200 strokes. Rotate 50 rpm w/ 5-6k ft Ibs for ue. Shallow test MWD. 23:00 23:45 0.75 2,548 2,548 SURFA DRILL DHEQ P Test 10-3/4" 45.5 ppf, L-80 BTC to 3000 si. Chart test and hold f/ 30 min. 23:45 00:00 0.25 2,548 2,559 SURFA CEMEf~ CIRC P MU top drive to stand #23. Establish circulation. PU wt 145k, SO wt 110k, Rot wt 128k. Rotate 50 rpm w/ 5-6k ft Ib torque, pumping 149 spm (633 gpm) w/ 1970 psi off bottom, 2040 psi on bottom. Prepare to drill wiper plugs and then float collar 2559.78' 08/30/2006 00:00 01:45 1.75 2,652 2,672 SURFA CEME~ DRLG P MU top drive to stand #23. Establish circulation. PU wt 145k, SO wt 110k, Rot wt 128k. Rotate 50 rpm w/ 5-6k ft Ib torque, pumping 149 spm (633 gpm) w/ 1970 psi off bottom, 2040 psi on bottom. Drill wiper plugs and then float collar @ 2559.78', cement, FS 2642', rat hole to 2652', then 20' new hole to 2672' (2276' TVD). Drill w/ 10k WOB. Bit hrs .12 hrs, jar hrs 39.08 hrs. Time Lo s -Date From To Dur S De th E De th Phase Code Subcode T COM Page 10 of 69' 08/30/2006 01:45 02:15 0.50 2,672 2,672 SURFA CEMEI~ CIRC P Circulate and displace mud to new 9.0 ppg LSND. Circ BU after displacement.Pumping 150 spm (634 gpm) w/ 1660 psi. Baseline clean hole ECD is 9.27 02:15 02:45 0.50 2,672 2,645 SURFA CEMEf~ LOT P Stand back stand # 24 after drilling 27' to 2672'. Perform LOT w/ 9.1 ppg mud. 502 psi, csg shoe @ 2642' (2252' TVD). EMW = 13.4 PPG. Hrs on bit .12 hrs 02:45 03:00 0.25 2,645 2,645 INTRM1 DRILL OTHR P Bleed off pressure. Blow down top drive. Threads on saver sub are ailed. 03:00 06:00 3.00 2,645 2,672 INTRM1 DRILL OTHR T Change out saver sub on top drive. Check connections which were screwed into. Replace top jt on stand #23, replace top and bottom jts of stand # 24. Corrected i e tall . 06:00 08:00 2.00 2,672 2,829 I INTRM1 DRILL DDRL P Drilling 9-7/8" intermediate from 2672' (2276' T~,~C) to 2829' (15T) (2391' TVD) Bit hours= .99, Jar hours= 39.97, AST=.00 hrs, ART=.87 hrs, ADT=.87 hrs, WOB= 10-15k, 60-80 rpm, Mtr rpm 210-214, 636-650 gpm @ 1750-1770 psi on bottom and 1700 psi off bottom. Torque = 5k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 9.42 ppg. P/U = 140-145k, S/O = 115-120k, Rot= 130k w/ pump off. 08:00 09:00 1.00 2,829 2,829 INTRM1 DRILL OTHR T Trouble shoot surface equipment (Mud pump, etc.). Having problems getting detection f/ surveys. Clean suction screens on both mud pumps. Lower pressure in discharge pulsation dampners. SPR's: #1 @ 20 spm = 120 psi, 30 spm = 180 psi. #2 mp @ 20 s m = 120 si, 30 s m = 180 si. 09:00 09:15 0.25 2,829 2,829 INTRM1 DRILL OTHR T Mode switch MWD tool. Appears to be workin . 09:15 12:00 2.75 2,829 3,160 INTRM1 DRILL DDRL P Drilling 9-7/8" intermediate from 2829' (2391' TVD) to 3160' (331') (2640' TVD) Bit hours= 2.94, Jar hours= 41.92, AST=.1.11 hrs, ART=..84 hrs, ADT= 1.95 hrs, WOB= 5-15k, 80 rpm, Mtr rpm 214, 650 gpm @ 1770-2000 psi on bottom and 1700-1950 psi off bottom. Torque = 4-5k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 9.4-9.5 ppg. P/U = 145-160k, S/O = 115-120k, Rot= 130-135k w/ um off. Time Lo s .Date From To Dur 5 ~De th_ E. De th Phase Code Subcode T COM Page 11 of B9 08/30/2006 12:00 18:00 6.00 3,160 3,888 INTRM1 DRILL DDRL P Drilling 9-7/8" intermediate from 3160' (2640' TVD) to 3888' (331') (3143' TVD) Bit hours= 6.62, Jar hours= 45.60, AST= 2.63 hrs, ART=1.05 hrs, ADT= 3.68 hrs, WO6= 10-15k, 80 rpm, Mtr rpm 205-214, 623-650 gpm @ 1970-2350 psi on bottom and 1940-2300 psi off bottom. Torque = 4-5k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 9.6-9.84 ppg. Gas units = 14. P/U = 155-160k, S/O = 120-125k, Rot= 135-140k w/ pump off. Pump 25 bbls hi vis sweep while drilling @3679' (3092' TVD), no noticable increase in cuttin s. 18:00 00:00 6.00 3,888 4,480 INTRM1 DRILL DDRL P Drilling 9-7/8" intermediate from 3888' (3143' TVD) to 4480' (592') (3457' TVD) Bit hours= 10.35, Jar hours= 49.33, AST= 2.41 hrs, ART=1.32 hrs, ADT= 3.73 hrs, WOB= 10-20k, 80 rpm, Mtr rpm 208-211, 636-640 gpm @ 2280-2590 psi on bottom and 2280-2390 psi off bottom. Torque = 4-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 9.84-9.97 ppg. Gas units = 14 P/U = 153-158k, S/O = 127-125k, Rot= 135-140k w/ pump off. SPR @ 4145' (3299' TVD) #1 mp @ 20 spm = 190 psi, 30 spm=250 psi, #2mp @ 20spm=190 psi, 30 spm=260 Pump 25 bbls hi vis sweep while drilling @ 4425' (3433' TVD}, no noticable increase in cuttin s. 08/31/2006 00:00 06:00 6.00 4,480 4,892 INTRM1 DRILL DDRL P Drilling 9-7/8" intermediate from 4480' (3457' TVD) to 4892' (412') (3564' TVD) Bit hours= 14.6, Jar hours= 53.58, AST= 2.03 hrs, ART=2.22 hrs, ADT= 4.25 hrs, WOB= 10-22k, 80-90 rpm, Mtr rpm 208-211, 636-640 gpm @ 2590-2700 psi on bottom and 2400-2600 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.29-10.02 ppg. P/U = 160-155k, S/O = 125-122k, Rot= 140-135k w/ um off. 06:00 12:00 6.00 4,892 5,406 INTRM1 DRILL DDRL P Drilling 9-7/8" intermediate from 4892' (3564' TVD) to 5406' (514') (3660' TVD) Bit hours= 18.54, Jar hours= 57.52, AST= 1.39 hrs, ART=2.55 hrs, ADT= 3.94 hrs, WO6= 15-20k, 90 rpm, Mtr rpm 210-206, 636-625 gpm @ 2670-2480 psi on bottom and 2590-2200 psi off bottom. Torque = 4-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 9.87-9.79 ppg. Avg gas 100 units. P/U = 155k, S/O = 125-120k, Rot= 135k w/ um off. 'Time Lo s Date From To Dur S De th E. De th Phase Code Subcode T COM Page 12 of 69 08/31/2006 12:00 18:00 6.00 5,406 5,922 INTRM1 DRILL DDRL P Drilling 9-7/8" intermediate from 5406' (3660' TVD) to 5922' (516') (3742' TVD) Bit hours= 22.47, Jar hours= 61.45, AST= 1.02 hrs, ART=2.91 hrs, ADT= 3.93 hrs, WOB= 15-20k, 90 rpm, Mtr rpm 211-214, 642-650 gpm @ 2720-2800 psi on bottom and 2600-2710 psi off bottom. Torque = 4-7k ft-Ibs on botttom and 5-7k ft-Ibs off bottom. ECD= 9.80-10.4 ppg. Avg gas 30 units. P/U = 155-150k, S/O = 120-115k, Rot= 135k w/ um off. 18:00 18:15 0.25 5,922 5,926 INTRM1 DRILL DDRL P Drilling 9-7/8" intermediate from 5922' (3742' TVD) to 5926' (4') (3742' TVD) Bit ho! rs= 22.50, Jar hours= 61.48, AST= .03 hrs, ART= O.Ohrs, ADT= .03 hrs, WOB= 15-20k, 90 rpm, Mtr rpm 214, 650 gpm @ 2800 psi on bottom and 2710 psi off bottom. Torque = 4-7k ft-Ibs on botttom and 5-7k ft-Ibs off bottom. ECD= 10.4 ppg. P/U = 155k, S/O = 115k, Rot= 135k w/ um off. 18:15 19:00 0.75 5,926 5,833 INTRM1 DRILL CIRC P Set back a stand. SPR's and Pump Hi vis weighted sweep (10 ppg, 250 vis), while backreaming slow f/ 5926' to 5833'. Pumping 650 gpm w/ 2800 psi, rotating 90 rpm w/ 7k ft Ib torque. No noticable increase in cuttin s. 19:00 00:00 5.00 5,833 3,390 INTRM1 DRILL REAM P Continue backreaming out of hole f/ 5833' to 3390. Pumping 650 gpm w/ 2800- 2200 psi. ECD's 11.01 max. ECD's @ 3390' 10.44 ppg. Pulling @ 40-45 ft/min. 09/01/2006 00:00 00:30 0.50 3,390 3,000 INTRMI DRILL REAM P Continue backreaming out of hole f/3390 to 3000'. Pumping 650 gpm w/ 2200-1800 psi. ECD's 10.44 max. Pullin 40-45 ft/min. 00:30 01:30 1.00 3,000 2,800 INTRM1 DRILL REAM P Hole unloading lots of clay. Continue backreaming out of hole f/3000' to 2800'. Pumping 650 gpm w/ 1800 psi. ECD's 10.44 max. Slowed pulling s eed to 15 ft/min. 01:30 02:15 0.75 2,800 2,520 INTRMI DRILL REAM P Continue backreaming out of hole f/2800' to 2520'. Pumping 650 gpm w/ 1800- 1600 psi. ECD's 10.44 to 9.8 ppg. Increased pulling speed to 35-45 ft/min. 02:15 03:30 1.25 2,520 2,520 INTRM1 DRILL CIRC P Circ to clean up mud in casing. Initial ECD's 9.8 ppg, final 9.32 ppg. Circ @ 650 gpm w/ 1600 psi while working pipe. Rotating 60 rpm. Circ 9.7 ppg 245vis sweep, follow till mud in good shape to run casing. Final MW 9.0= in and out. 03:30 04:00 0.50 2,520 2,520 INTRMI DRILL OWFF P Monitor well. OK. Pump dryjob, blow down to drive. Time Lo s Date From To Dur S. De th E De th Phase Code Subcode T COM 09/01/2006 04:00 04:15 0.25 2,520 2,454 INTRM1 DRILL TRIP P Pull and stand back last stand of 4" dp, remove crossover. Change elevators to 5" 04:15 05:30 1.25 2,454 450 INTRM1 DRILL TRIP P POOH/stand backs"dpf/2454'to 450'. La ed down 9-7/8" host reamer. 05:30 06:00 0.50 450 80 INTRM1 DRILL TRIP P Stand back 3 stands of 5" HWDP w/ 'ars.. L/D Flex dc's. 06:00 06:45 0.75 80 80 INTRM1 DRILL OTHR P Download Sperry Sun MWD. 06:45 08:00 1.25 80 0 INTRM1 DRILL PULD P Finish UD BHA#2. 08:00 09:00 1.00 0 0 INTRM1 DRILL OTHR P Rig up and pull wear bushing. 09:00 09:15 0.25 0 0 INTRM1 CASIN( SFTY P PJSM on rigging up to run 7-5/8" intermediate casin . 09:15 10:45 1.50 0 0 INTRMI CASIN( RURD P Rig up to run 7-5/8" casing w/GBR casin tools and Frank's fillu tool. 10:45 11:00 0.25 0 0 INTRM1 CASIN( SFTY P PJSM on running 7-5/8", 29.7 ppf, L-80 BTC casing wi rig crew and GBR casin crew. 11:00 15:30 4.50 0 2,640 INTRMI CASIN( RNCS P Run 7-5/8" casing: MU Weatherford model 303 float shoe, 2 jts , Weatherford model 402 float collar, 18 jts, One joint f/ "B" sand window, 6 jts, a 20' pup, one jt f/ "D" sand window, then to jt # 62 in hole to 2640'. Ran tandem rise(TR2) centralizers 3/2 jts on first 30 jts. Then run TR2 centralizers on collars of #31 to #54. Ran total of 62 tandem rise and 28 sto s. 15:30 15:45 0.25 2,640 2,640 INTRM1 CASIN( CIRC P Circ BU (101 bbls) @ 2645' (inside 10-3/4" casing). Circ 4-6 bpm w/ 230-330 si. 15:45 19:30 3.75 2,640 5,890 INTRM1 CASIN( RNCS P Continue running 7-5/8" 29.7 ppf L-80 BTC-mod casing f/ 2640' to 4750' (jt # 111), break circ, run casing f/ 4750' to 5115' Qt # 120), break circ, run casing f/ 5115' to 5840' (jt # 137, break circ, run casin f/ 5840' to 5890' 't # 138 . 19:30 19:45 0.25 5,890 5,926 INTRMI CASIN( RNCS P MU Jt # 139, circulate jt down to 5926'. 19:45 20:30 0.75 5,926 5,926 INTRM1 CEMEf~ RURD P Remove Frank's fillup tool, blow down to drive, install Dowell cement head. 20:30 22:45 2.25 5,926 5,926 INTRMI CEMEn CIRC P Circulate prior to cementing. Circulate @ 6 bpm w/ 380 psi. PU wt 200k and SO wt 140k after circ. Circulated total of 740 bbls prior to cementing. Held PJSM w/ cep ~ renting :,revs a..d APC truck drivers while circulating. Mud properties before : 8.9ppg, 44 vis, 9/17 PV/YP. Mud properties after conditioning : 8.9ppg, 40 vis, 9/15 PV/YP. Reci i e 5' er min, 30' stroke. Page 13 of 69 Time Logs Date From To Dur S De th E De th Phase Code Subcode T COM Page 14 ofi 69 09/01/2006 22:45 00:00 1.25 5,926 5,926 INTRMI CEME~ OTHR P Dowell, pump 10 bbls CW100, test lines to 3500 psi, pump @ 5 bpm w/ 220- 330 psi (40 bbls CW100), mix and pump @ 5 bpm w/ 320-220 psi (72.6 bbls MudPush II) @ 11.0 ppg, drop bottom plug, mix and pump @ 4.4 bpm w/ 235-100 psi (138.9 bbls DeepCrete) @ 12.5 ppg, drop top plug, Dowell kick out plug w/ 5 bbl water. Reci i e 5'/min, 30' stroke. 09/02/2006 00:00 00:45 0.75 5,926 5,920 INTRM1 CEMEI~ DISP P Displace cement with rig pumping 8.9ppg OBM @ 6 bpm until last 9 bbls then slow down to 3 bpm. Initial pressure 100 psi, final @ 3bpm was 850 psi. Bumf plug @ talc strokes (2602) w/ 1400 psi. CIP @ 0045 hrs 9/2/2006. Continue recip 7-5/8" casing 5'/min 30' stroke while displacing cement w/ OBM. Recip until last 25 bbls pumped. Final PU wt 170k, SO wt 100-110k. Float shoe 5920'. 00:45 02:15 1.50 5,920 5,920 INTRM1 CEMEI~ RURD P Bleed off pressure, check floats, OK. Blow down cement line. hang cement hose in derrick. Remove Dowell cement head. Drain stack. Vacum out landin 't. 02:15 02:30 0.25 5,920 5,920 INTRM1 DRILL OTHR P PJSM on picking up stack and setting slips w/ Vetco Gray and Tourpusher and crew. 02:30 03:00 0.50 5,920 5,920 INTRM1 WELCT NUND P Break Vetco Gray multibowl, PU BOP stack. 03:00 04:30 1.50 5,920 5,920 INTRMI WELCT OTHR P Install Vetco Gray 7-5/8" slips. Slack off on slips w/ 180k on weight indicator. Blocks = 70k. Cut off 7-5/8" casing. dress cut on jt # 138. Lay down landin 't w/ 11' cutoff f/ 't # 138. 04:30 05:00 0.50 5,920 5,920 INTRM1 WELCT OTHR P Install Vetco Gray packoff. Tighten lockdown screws to 580 ft lbs. 05:00 06:15 1.25 0 0 INTRM1 WELCT NUND P Set BOP's and Vetco Gray multibowl back down. Tighten break on multibowl. 06:15 06:45 0.50 0 0 INTRM1 WELCT BOPE P Testing 7-5/8" packoff and break on Vetco/Gray Multibowl to 250 psi low and 3850 si hi h f/ 10 min each. OK. 06:45 08:45 2.00 0 0 INTRM1 DRILL LOT P Continue laying down casing tools. RU & perform LOT on 10-3/4" x 7-5/8" Annulus. EMW of fluid in annulus is 9.7 ppg (11.Oppg mudpush (I and 8.36ppg CW100, 9.0 ppg mud). 200 psi @ TVD of 2252' at the 10-3/4" casing shoe = 11.4 ppg EMW. After test, pump 30 bbls fresh water to flush annulus of ossible cement. 08:45 09:15 0.50 0 0 INTRM1 DRILL OTHR P Install Vetco Gray wear bushing. 10.5" OD, 6-7/8" ID x 3.45" Ion . ..Time Los Date From To Dur S De th E De th Phase Code . Subcode T COM Page 15 of B9 09/02/2006 09:15 10:00 0:75 0 0 INTRM1 WELCT NUND P Nipple up flowline, install and tighten turnbuckles on BOP stack. 10:00 10:15 0.25 0 0 INTRM1 DRILL SFTY P PJSM on picking up Weatherford 4" drill pipe w/ Western Well Tools super sliders from i e shed. 10:15 11:15 1.00 0 0 INTRM1 DRILL PULD P PU/MU/RIH Weatherford 4" drill pipe w/ Western Well Tools super sliders. Flush 10-3/4" x 7-5/8" annulus w/ 120 bbls water 2.5 b m wl 670 si. 11:15 13:00 1.75 0 0 INTRM1 DRILL PULD P PU/MU/RIH Weatherford 4" drill pipe w/ Western Well Tools su er sliders. 13:00 16:15 3.25 0 3,720 INTRM1 DRILL PULD P Continue PU/MU/RIH Weatherford 4" drill pipe w/ Western Well Tools super sliders. Total of 120 jts (40 stands) of 4" pipe w/ super sliders picked up a rox 3720' 16:15 16:45 0.50 3,720 3,720 INTRM1 DRILL CIRC P Pump @ 4bpm w/ 360 psi to clean out drill pipe. Note: Littie Red pumping 80 bbis of diesel into 10-3/4" x 7-5/8" annulus f/ freeze protection. Pressure test to 2500 psi. pump @ 2bpm w/ 1000 psi. Final ressure 750 si after um in . 16:45 18:00 1.25 3,720 2,883 INTRM1 DRILL TRIP P POOH wet w/ 4" drill pipe w/ super sliders, rack back on off drilier's side of derrick. 9 stands out @ 1800 hrs, approx depth 2883'. All mud its are cleaned. 18:00 18:30 0.50 2,883 2,325 INTRM1 DRILL TRIP P Continue POOH wet w/ 4" dp w/super sliders f/ 2883' to 2325'. Rack on off driller's side. 18:30 19:00 0.50 2,325 2,325 INTRM1 DRILL CIRC P Crew change, pump dryjob. Blow down to drive. 19:00 21:00 2.00 2,325 0 INTRMI DRILL TRIP P Continue POOH wet w/ 4" dp w/super sliders f/ 2325' to all 40 stands out of hole. Rack on off driller's side. 21:00 23:15 2.25 0 0 INTRM1 DRILL OTHR P Getting 4" dp in pipe shed, strap and read to PU. 23:15 23:30 0.25 0 0 INTRM1 DRILL SFTY P PJSM on picking up 5" DC's and 4" HWDP to build H brids. 23:30 00:00 0.50 0 0 INTRMI DRILL PULD P PU/MU Hybrids (2 jts of Weatherford (5" OD x 2/58" ID) DC's w/ jt of 4" HWDP on top). MU in mouse hole, stand back in derrick on driller's side. Rabbit w/ 2.33" OD rabbit. 4 stands of total of 15 to be picked up, in derrick midni ht. 09/03/2006 00:00 02:15 2.25 0 0 INTRM1 DRILL PULD P Continue PU/MU Hybrids (2 jts of Weatherford (5" OD x 2/58" ID) DC's w/jt of 4" HWDP on top). MU in mouse hole, stand back in derrick on driller's side and off driller's side. Rabbit w/ 2.33" OD rabbit. 10 stands on driller's side, 5 stands on off driller's side. :Time Logs Date From To Dur S De th E De th Phase Code Subcode T COM Page 16 of 69 09/03/2006 02:15 03:00 0.75 0 0 INTRMI DRILL PULD P Pu/MU/ Standback in derrick 4 stands of Weatherford 4" HWDP. 03:00 04:45 1.75 0 126 INTRM1 DRILL PULD P PU/MU BHA # 3: Security 6-3/4" FMF 3641 Z bit w/ (3) 21 /32's (TFA 1.015), SperrySun geoPilot 5200 (ser # TL019), geoppilot flex collar, SperrySun 4-3/4" DIR, smart stab, gamma/res, pwd, tm hoc, nm flaot sub, welded blade stab, (1) 4-3/4" NM DC. to 126' 04:45 05:15 0.50 126 51 INTRM1 DRILL OTHR P Upload MWD tools. 05:15 06:00 0.75 51 285 INTRM1 DRILL PULD P Continue PU/MU BHA #3: PU (2) 4-3/4" nm DC's, x-o, (1) 4" HWDP, DNT'ars, 1 4" HWDP to 285'. 06:00 06:15 0.25 285 285 INTRM1 DRILL DHEQ P Pulse test MWD tool. Pumping 300 gpm w/ 1300 psi. Break in seals on eoPilot. Ob:15 12:00 5.75 285 3,752 IN T Rid i ^vl~iLL PULD P PU/iviU 111 jts of +' dp tJ shed. Rabbit to 2.33". 12:00 13:15 1.25 3,752 4,409 INTRM1 DRILL PULD P Continue PU/MU BHA#3: DNTjars, then rest of 4" dp in pipe shed to 4409'. Back on Hi-Line ower 1300 hrs. 13:15 13:30 0.25 4,409 4,409 INTRM1 DRILL OTHR P Lower skate ramp on rig floor,remove thread protectors, clear and clean rig floor. 13:30 14:15 0.75 4,409 5,724 INTRM1 DRILL TRIP P RIH f/ 4409' to 4771' (3547' TVD), fill pipe. Pumping 300 gpm w/ 2470 psi, 30 rpm, 3-4k ft Ib torque. Continue RIH to 5724' 3711' TVD . 14:15 15:45 1.50 5,724 5,800 INTRM1 DRILL CIRC P While CBU @ 300 gpm w! 2850 psi, 50 r m, to ed strin ers 5800'. 15:45 16:00 0.25 5,800 5,800 INTRM1 DRILL SFTY P PJSM on tripping in hole. 16:00 16:15 0.25 5,800 5,818 INTRM1 CEME~ COCF P MU stand, cleanout to 5818'. 16:15 17:00 0.75 5,818 5,818 INTRM1 RIGMN SFTY P PJSM on changing out drilling line. 17:00 21:45 4.75 5,818 5,818 INTRM1 RIGMN OTHR P Change out 1-3/8" drilling line. Install new line on drum. 21:45 22:15 0.50 5,818 5,818 INTRM1 RIGMN SVRG P Service top drive and drawworks. 22:15 22:45 0.50 5,818 5,818 INTRM1 RIGMN OTHR P Calibrate block height on TOTCO and Sperry Sun computers. TOTCO rep hel ed to ex lain rocedure. 22:45 23:45 1.00 5,818 5,818 INTRM1 CASIN( DHEQ P Test casing to 3000 psi f/ 30 min. Chart test. 23:45 00:00 0.25 5,818 5,832 INTRMI DRILL CIRC P Establish circulation w/ 298 gpm, 2310 psi, rot 100 rpm w/ 3-4k ft Ib torque. PU wt 150, SO 115k, Rot 125k. Drill f/ 5818' to to of FC 5832'. 09/04/2006 00:00 02:15 2.25 5,832 5,926 INTRM1 CEME~ COCF P Drill FC @ 5832', cement, FS top @ 5918.5, rat hole to 5926'. 300- 325 gpm 2400-2650, rotate 100 rpm w/ 5k ft Ib for ue. .Time Logs .Date From To Dur S: De th E. De th Phase Code Subcode T COM 09/04/2006 02:15 02:30 0.25 5,926 5,946 INTRMI DRILL DDRL P Drill 20' new hole f! 5926' to 5946'. Drill w/ 4-6k wob, 300 gpm w/ 2800 psi, rotate 100 rpm w/ 4k ft Ib torque. ART = .10 hrs. Jar # 0043 = 84.67 hrs, Jars 0019 = 175.41 hrs 02:30 03:45 1.25 5,946 5,946 INTRM1 DRILL CIRC P Backream twice, then stand a stand back and finish circulating 480 bbls till hole clean (2BU+). Circ 309 gpm w/ 2400 psi, rotate 90 rpm w/ 3-4k ft Ib torque. Obtain baseline f/ ECD's/PWD. 9.75 w/ clean hole-8.8 mud 03:45 04:45 1.00 5,946 5,946 INTRM1 DRILL LOT P Perform LOT. Shoe @ 5920' (3741' TVD), 8.8 ppg mud wt, 1080 psi applied pressure =Leak off @ 14.4 04:45 06:00 1.25 5,946 6,035 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f/ 5946' (3744' TVD) to 6035' (89') (3750' TVD) Bit hours= .95, Jar (#141-0019) hours= 179.91, Jar (#i47 i-vv43) hours = 89.17, Accelerators (#1447-1034) = 179.91 hrs, ART= 0.85hrs, WOB= 6-8k, 90 rpm, 310 gpm @ 2600 psi on bottom and 2400 psi off bottom. Torque = 5k ft-Ibs on botttom and 4k ft-Ibs off bottom. ECD= 9.67 ppg. P/U = 150k, S/O = 115k, Rot= 125k w/ um off. 06:00 12:00 6.00 6,035 6,751 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f/ 6035' (3750' TVD) to 6751' (716') (3721' TVD) Bit hours= 5.45, Jar (#141-0019) hours= 170.76, Jar (#1471-0043) hours = 90.02, Accelerators (#1447-1034) = 180.76 hrs, ART= 4.5 hrs, WOB= 2-8k, 90-130 rpm, 310-347 gpm @ 2600-2880 psi on bottom and 2400-2800 psi off bottom. Torque = 5-7k ft-!bs on botttom and 4-5k ft-Ibs off bottom. ECD= 9.67-1D.25 ppg. P/U = 150-155k, S/O = 115-108k, Rot= 125k w/ um off. 12:00 18:00 6.00 6,751 7,403 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f/ 6751' (3721' TVD) to 7403' (652') (3731' TVD) Bit hours= 10.12, Jar (#141-0019) hours= 185.43, Jar (#1471-0043) hours = 94.69, Accelerators (#1447-1034) = 185.43 hrs, ART= 4.67 hrs, WOB= 4-10k, 130 rpm, 347-350 gpm @ 2780-3000 psi on bottom and 2720-2950 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.16-10.3 ppg. P/U = 155-160k, S/O = 115-100k, Rot= 125-120k w/ um off. Page 77 of 69 I ~.. ~ ~,....~ ~ ~,,..*h oti., ~,,,~o c~,h...,,-~o T rnnn I vac 09/04/2006 ~ iv~u 18:00 i v 00:00 vw 6.00 .~. ~ 7,403 7,979 PROD1 DRILL DDRL P - - - Drilling 6-3/4" production A2 lateral f/ 7403' (3731' TVD) to 7979' (576') (3724' TVD) Bit hours= 14.6, Jar (#141-0019) hours= 189.91, Jar (#1471-0043) hours = 99.17, Accelerators (#1447-1034) = 189.91 hrs, ART= 4.48 hrs, WOB= 2-10k, 130 rpm, 350 gpm @ 3000-3250 psi on bottom and 2950-3250 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.3-11.01 ppg. P/U = 155-160k, S/O = 100-95k, Rot= 125-122k w/ um off. 09/05/2006 00:00 01:15 1.25 7,979 8,159 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f/ 7979' (3724' TVD) to 8159' (180') (3731' TVD) Bit hours= 15.33, Jar (#141-0019) hours= 190.64, Jar (#1471-0043) hours = 99.9, Accalaratnrs (#1447-1034) = 190.64 hrs, ART= .73 hrs, WO6= 2-10k, 130 rpm, 350 gpm @ 3250 psi on bottom and 3250 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.3-11.01 ppg. Avg gas 20 units.P/U = 155-160k, S/O = 100-95k, Rot= 125-122k w/ pump off. 01:15 01:30 0.25 8,159 8,159 PROD1 DRILL REAM T PJSM on backreaming out of hole f/ sidetrack. 01:30 02:30 1.00 8,159 7,780 PROD1 DRILL REAM T Backream out of hole f/ 8159' (3731' TVD) to 7780' (TVD= 3731') f/ sidetrack. Out of A2 sands. Pumping 350 gpm w/ 3200 psi, rotating 130 rpm w/ 4k ft Ib torque. PU wt 160k, SO wt 100k. Pulling speded 40-45 ft/min. ECD's were 11.01 ppg, final ECD's 10.48 02:30 06:15 3.75 7,780 7,675 PROD1 DRILL REAM T Troughing f/ openhole sidetrack @ 7780' 7800'. Pumping 350 psi w/ 3000 psi. Rotate 120 rpm w/ 5-6k ft Ib torque. ECD's 10.11 ppg. WOB 0-2k. Set back a stand. 06:15 08:30 2.25 7,675 7,710 PROD1 DRILL REAM T Trough f/ 7675' to 7710' (3734' TVD) f/ o en hole sidetrack. 08:30 10:30 2.00 7,710 7,757 PROD1 DRILL OTHR T Time drill f/ 7710' to 7757' (3733' TVD). 350 gpm w/ 3000 psi. Rotate 120 rpm w/ 5-6k ft Ib for ue. ECD's 1011 10:30 11:00 0.50 7,757 7,757 PROD1 DRILL OTHR T Lost Hi-line power. Start engines. Start shakers and air compressors. Start mud um s, re ain circulation. Page 18 of 69 Time Logs , Date From To Dur S De th E De th Phase Code Subcode T COM Page 19 of 69 09/05/2006 11:00 12:00 1.00 7,757 7,825 PROD1 DRILL OTHR T Drilling sidetrack hole 6-3/4" production A2 lateral f/ 7757' (3733' TVD) to 7825' (68') (3732' TVD) Bit hours= 18.12, Jar (#141-0019) hours= 193.43, Jar (#1471-0043) hours = 102.69, Accelerators (#1447-1034) _ 1193.43 hrs, ART= 2.79 hrs-- includes time drilling & troughing, WOB= 2-8k, 130 rpm, 350 gpm @ 3150-3250 psi on bottom and 3080-3170 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.5-10.24 ppg. P/U = 160-162k, S/O = 95-105k, Rot= 125k w/ pump off. 12:00 13:00 1.00 7,825 8,159 PROD1 DRILL OTHR T Drilling sidetrack hole 6-3/4" production A2 lateral f/ 7825' (3732' TVD) to 8159' (334') (3741' TVD) Bit no. ors= 1 g.1 ~, aar (#141-0019) hours= 194.43, Jar (#1471-0043) hours = 103.69, Accelerators (#1447-1034) _ 1194.43 hrs, ART= 1 hrs, WOB= 2-8k, 130 rpm, 350-310 gpm @ 3250-2800 psi on bottom and 3170-2710 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.3-9.98 ppg. P/U = 160k, S/O = 100k, Rot= 125k w/ um off. 13:00 17:30 4.50 8,159 8,401 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f/ 8159' (3741' TVD) to 8401' (242') (3739' TVD) Bit hours= 21.88, Jar (#141-0019) hours= 197.19, Jar (#1471-0043) hours = 106.45, Accelerators (#1447-1034) = 1197.19 hrs, ART= 2.76 hrs, WO6= 8-14k, 130 rpm, 350 gpm @ 3400 psi on bottom and 3400 psi off bottom. Torque = 5-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 9.98-10.6 ppg. P/U = 160-165k, S/O = 100k, Rot= 125k w/ um off. 17:30 18:30 1.00 8,401 8,160 PROD1 DRILL TRIP T Geopilot is drilling left when it says it is drilling right. Pump out of hole f/ 8401' to 8160', taking check shot surveys. Pumping 340 gpm w/ 3000 si. PU wt 160k, SO wt 100k. 18:30 18:45 0.25 8,160 8,160 PROD1 DRILL SFTY T Elevators contacted platform (Diving board) @ derrick board. Picked board u 6-8". Check out board. OK. 18:45 19:15 0.50 8,160 7,875 PROD1 DRILL TRIP T Continue pumping out f/ 8160' to 7875'. Pum in 340 m w/ 3000 si. 19:15 20:30 1.25 7,875 6,660 PROD1 DRILL TRIP T Pull out of hole on elevators f/ 7875' to 6660' wet while mixing a dry job. PU wt 165k, SO wt 109k. 20:30 21:00 0.50 6,660 6,660 PROD1 DRILL CIRC T Monitor well. Pump dry job, line up on tri tank. Check crown-o-matic. I r, r__... ~-_ n.._ c n., ..+~ c n,..,+h oh.,,.,, r~a~ C ~h.-.,~lo T (`(1M I vuw 09/05/2006 21:00 00:00 3.00 6,660 1,977 PROD1 DRILL __ _ TRIP T - - POOH f/ 6660' to 1977'. Record PU and SO wt's every 5 in open hole and every 10 stands in cased hole. PU wt 115k, SO wt 105k. 09/06/2006 00:00 01:00 1.00 1,977 348 PROD1 DRILL TRIP T POOH f/ 1977' to 348'. Record SO wt's eve 10 stands in cased hole. 01:00 01:45 0.75 348 92 PROD1 DRILL TRIP T Standback HWDP and BHA #3 to S er Sun MWD tools. 01:45 02:30 0.75 92 92 PROD1 DRILL OTHR T Plug in, download data f/MWD. Break bit. 02:30 04:00 1.50 92 0 PROD1 DRILL PULD T UD Geopilot ser # TL019, PU GeoPilot # TL018, change out directional collar, MU new bit. 04:00 G4:45 0.75 0 92 PROD1 DRILL OTHR T Upload Sperry Sun MWD tools. 04:45 05:15 0.50 92 348 PROD1 DRILL TRIP T RIH w/ BHA #4, f/ 92' to 348'. 05:15 09:30 4.25 348 5,900 PROD1 DRILL TRIP T Continue RIH w/ BHA #4 f/ 348' to 5900'. 09:30 10:00 0.50 5,900 5,900 PROD1 DRILL CIRC T Fill pipe. Circ 280 gpm (66 spm) w/ 2010 si. Pum ed 48 bbls. 10:00 10:15 0.25 5,900 5,900 PROD1 DRILL OTHR T Monitor well. Blow down top drive. 10:15 10:30 0.25 348 348 PROD1 DRILL OTHR T Shallow test MWD tools. Break in seals on geopilot. Send downlink to eo ilot. 10:30 13:00 2.50 5,900 5,900 PROD1 RIGMN SVRG P Change out saver sub on top drive. Service ri . 13:00 14:15 1.25 5,900 7,600 PROD1 DRILL TRIP T RIH w/ BHA #4 from 5900' to 7600'. 14:15 14:30 0.25 7,600 7,600 PROD1 DRILL CIRC T Fill pipe. Break circulation. 14:30 15:30 1.00 7,600 7,640 PROD1 DRILL DDRL T Trough for open hole sidetrack #2. Trough 7600' to 7640'. Pumping 350 gpm w/ 3100 psi. Rotate 130-150 rpm w/ 5k ft Ib for ue. 15:30 17:30 2.00 7,640 7,640 PROD1 DRILL DDRL T Attempt to sidetrack @ 7640'. Survey showed no sidetrack. Start over @ 7640' time drillin . 17:30 18:00 0.50 7,600 7,600 PROD1 DRILL CIRC T Time drill f/ 7600'. No detection w/ MWD while time drilling. Loss of pump pressure over time. Totco showed #2 mp --82 psm @ 1430 hrs= 3250 psi, @ 1800 hrs 2550 psi. Difference of 700 si. 18:00 19:00 1.00 7,600 7,600 PROD1 DRILL OTHR T Check pumps and surface equipment for loss of ressure. Alt OK. 19:00 22:15 3.25 7,600 3,784 PROD1 DRILL TRIP T POOH wet w/ BHA #4, looking for washout. Found washout in Daily DNT drilling jars (ser # 147-10019). Hole in bod 16.6' down f/ box. 22:15 00:00 1.75 3,784 3,784 PROD1 DRILL PULD T Lay down Daily DNT drilling jars (ser # 147-10019). Hole in body 16.6' down f/ box. Clean floor. PU/MU Daily jars (ser # 147-10005 . Rabbit 'ars to 1.62" Page 20 of 69 Time Lo s Date From To Dur S. De th> E. De th Phase Code Subcode T COM 09/07/2006 00:00 00:30 0.50 3,784 3,940 PROD1 DRILL PULD T Lay down Daily accelerators (ser # 1447-71034), PU Accelerators (ser # 1447-1003 w/ 77.54 hrs). Rabbit jars to 1.62" 00:30 01:00 0.50 3,940 3,940 PROD1 DRILL CIRC T Make up top drive, circw/# 1 mp @ 350 gpm (83 spm) w/ 2500 psi 31 flow, #2 mp 350 gpm (83 spm) w/ 2600 pis 31% flow. Downlink, OK. MWD ood detection. 01:00 02:15 1.25 3,940 5,922 PROD1 DRILL TRIP T RIH w/ BHA #5 (number change after Chan in out 'ars f/ 3940' to 5922'. 02:15 02:30 0.25 5,922 5,922 PROD1 DRILL CIRC T Fill pipe. Circ 82 spm w/ 2950 psi on Totco, 31 % flow. 02:30 03:30 1.00 5,922 7,500 PROD1 DRILL TRIP T RIH f/ 5922' to 7600'.FIII pipe. 03:30 05:30 2.00 7,600 7,646 PROD1 DRILL REAM T Time drill, 2 min per 1" f/ 7640' to 7644'., then 1 min per 1". f/ 7644' to 7646'. Toolface 145L, 80% deflection. 83 spm (350 gpmj, w/ 3250 psi. Rotate 130 r m. PU wt 145k, SO wt 110k. 05:30 06:00 0.50 7,646 7,663 PROD1 DRILL REAM T Trying to sidetrack #2 f/ 7640', pumping 83 spm w/ 3250 psi, 140 rpm, 80% deflection. 85 spm (358 gpm) w/ 3300 psi. WOB 2k. Rotate 130 rpm w/ 5k for ue. ECD's 10.32 06:00 06:30 0.50 7,663 7,690 PROD1 DRILL REAM T Drilling f/ 7663' to 7690', survey, no sidetrack. 85 spm (358 gpm w/ 3300 si. Rotate 130 r m w/ 5k ft Ib for ue. 06:30 08:45 2.25 7,600 7,640 PROD1 DRILL REAM T Troughing and time drill f/ 7600' to 7640. 350 gpm, 3250 psi. 130 rpm w/ 5k ft Ib torque. Sidetrack #2 7600' 3737' TVD . 08:45 12:00 3.25 7,640 7,970 PROD1 DRILL DDRL T Drilling 6-3/4" production (sidetrack #2) A2 lateral f/ 7640' (3737' TVD) to 7970' (330') (3736' TVD) Bit hours= 2.45, Jar (#141-0005) hours= 2.45, Jar (#1471-0043) hours = 108.9, Accelerators (#1447-1033} = 79.99 hrs, ART= 2.45 hrs, WO6= 2-6k, 105-130 rpm, 345-350 gpm @ 3000-3100 psi on bottom and 2880-3010 psi off bottom. Torque = 4-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.13-10.28 ppg. Avg gas 80 units.P/U = 150k, S/O = 100k, Rot= 125k wl um off. Page 21 of 69 {; n_a~ cam,.... T., n... C nor+h G nonth C]hxo (`nrlc Cuhrnrla T r`ClM G .vatc 09/07/2006 i ivn.~ 12:00 16:30 4.50 7,970 8,401 PROD1 DRILL - -- - DDRL T - --- Drilling 6-3/4" production (sidetrack #2) A2 lateral f/ 7970' (3736' TVD) to 8401' (431') (3734' TVD) Bit hours= 6.01, Jar (#141-0005) hours= 6.01, Jar (#1471-0043) hours = 112.46 Accelerators (#1447-1033) = 83.55 hrs, ART= 3.56 hrs, WOB= 2-8k, 110-130 rpm, 350 gpm @ 3020-3120 psi on bottom and 3050-2940 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 4-6k ft-Ibs off bottom. ECD= 10.13-10.26 ppg. Avg gas 40 units.P/U = 155k, S/O = 95k, Rot= 125-120k w/ pump off. Stared running Western Well Tools su er sliders 8162'. 16:30 18:00 1.50 8,401 8,508 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f/ 8401' (3734' TVD) to 8508' (107') (3736' T\,[~l1 Ri+ hniirg= 7,Q3 rlar (tl1d1-QQQ51 hours= 7.03, Jar (#1471-0043) hours = 113.48 Accelerators (#1447-1033) _ 84.57 hrs, ART= 1.02 hrs, WO6= 2-8k, 110-130 rpm, 350 gpm @ 3020-3120 psi on bottom and 3050-2940 psi off bottom. Torque = 5-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.26-10.36 ppg. Avg gas 33 units.P/U = 155k, S/O = 95k, Rot= 125-120k w/ um off. 18:00 00:00 6.00 8,508 9,025 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f/ 8508' (3736 TVD) to 9025(517') (3735' TVD) Bit hours= 11.42, Jar (#141-0005) hours= 11.42, Jar (#1471-0043) hours = 117.87 Accelerators (#1447-1033) = 88.96 hrs, ART= 4.39 hrs, WO6= 2-8k, 110-120 rpm, 350 gpm @ 3290-3450 psi on bottom and 3200-3450 psi off bottom. Torque = 5-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.26-10.95 ppg. Max gas 147 units.P/U = 155-165k, S/O = 95-100k, Rot= 125-120k w/ um off. Page Z2 of 69 Time Lo s `Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/08/2006 00:00 06:00 6.00 9,025 9,430 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f/ 9025' (3735 TVD) to 9430'(405') (3734.5' TVD) Bit hours= 16.15, Jar (#141-0005) hours= 16.15, Jar (#1471-0043) hours = 122.6 Accelerators (#1447-1033) = 93.69 hrs, ART= 4.73 hrs, WOB= 2-8k, 110 rpm, 350 gpm @ 3420-3450 psi on bottom and 3300-3400 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.92-11.01 ppg. Max gas 147 units.P/U = 165-170k, S/O = 95k, Rot= 120-122k w/ pump off. Pumped a 30 bbls hi vis sweep (225), while drillin 9401'- 9430'. 06:00 06:30 0.50 9,430 9,430 PROD1 DRILL CIRC P Finish circulating sweep out of hole. Slight increase in cuttings. Geologist i..~ tovrn suggested to continue drilling f/ 9430', down thru A2 sands. 06:30 10:30 4.00 9,430 9,846 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f/ 9430' (3734.5 TVD) to 9846' (416') (3734.5' TVD) Bit hours= 19.28, Jar (#141-0005) hours= 19.28, Jar (#1471-0043) hours = 125.73 Accelerators (#1447-1033) = 96.82 hrs, ART= 3.13 hrs, WOB= 2-10k, 110-130 rpm, 345-350 gpm @ 3420-3980 psi on bottom and 3230-3840 psi off bottom. Torque = 5-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 11.01-11.68 ppg. Avg gas 30 units. P/U = 170-172k, S/O = 95k, Rot= 120k w! pump off. Pumped 40 bbls hi weight- hi vis sweep (10.8 ppg, 225 vis) while drilling 9750'-9846. 10:30 11:15 0.75 9,846 9,846 PROD1 DRILL CIRC P Finish circulating sweep out of hole. Slight increase in cuttings. Survey @ 9753'. Geologist suggested pulling back and sidetrack well a ain +/- 9200'. 11:15 12:15 1.00 9,846 9,191 PROD1 DRILL TRIP T POOH f/ 9846' to 9191' to sidetrack well. 12:15 13:00 0.75 9,191 9,210 PROD1 DRILL REAM T Trough f/ 9191' to 9210' for sidetrack #3. 13:00 13:15 0.25 9,210 9,219 PROD1 DRILL DDRL T Time drill f/ 9210' to 9219'. Rotate w/ 130 rpm, 80% deflection, TF 160L. Pum in 350 m. 13:15 13:30 0.25 9,219 9,210 PROD1 DRILL DDRL T Pull back, check sidetrack w/ ABI on geopilot. OK. Sidetracked well @ 9210'. Page Z3 of 69 n~a,. r-...... T.. fl„~ C hr, r~4h G honk{', Dk~oco l~nflo C~~hrn~p T (~n~~ ua~c 09/08/2006 r-. i~rn, 13:30 18:00 4.50 9,210 9,730 PROD1 __ DRILL __ _ DDRL T - - Drilling 6-3/4" production (Sidedtrack #3) A2 lateral f/ 9210' (3734.5 TVD) to 9730' (539') (3736' TVD) Bit hours= 22.88, Jar (#141-0005) hours= 22.88, Jar (#1471-0043) hours = 129.33 Accelerators (#1447-1033) = 100.42 hrs, ART= 3.60 hrs, WOB= 2-6k, 110 rpm, 331-350 gpm @ 3310-3700 psi on bottom and 3240-3600 psi off bottom. Torque = 6-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.32-11.08 ppg. Avg gas 30 units. P/U = 165-170k, S/O = 100-95k, Rot= 120k w/ um off. i8:G0 22:45 4.75 9,846 10,337 PROD1 DRILL DDRL P Drilling 6-3/4" production (Sidetrack #3) A2 lateral f/ 9846' (3747' TVD) to 10337' (491') (3741' TVD) Bit hours= 26.83, Jar (#141-0005) hours= 26.83, Jar (#1471-0043) hours = 13328 Accelerators (#1447-1033) = 104.37 hrs, ART= 3.23 hrs, WO6= 2-6k, 110 rpm, 350 gpm @ 3700-3870 psi on bottom and 3600-3780 psi off bottom. Torque = 6-7k ft-Ibs on botttom and 6k ft-Ibs off bottom. ECD= 11.15-11.2 ppg. P/U = 170k, S/O = 90-85k, Rot= 122-120k w/ um off. 22:45 00:00 1.25 9,730 9,846 PROD1 DRILL DDRL T Drilling 6-3/4" production (Sidetrack #3) A2 lateral f/ 9730' (3736' TVD) to 9846' (116') (3747' TVD) Bit hours= 23.6, Jar (#141-0005) hours= 23.6, Jar (#1471-0043) hours = 130.05 Accelerators (#1447-1033) = 101.14 hrs, ART= 1.37 hrs, WOB= 2-6k, 110 rpm, 344 gpm @ 3700 psi on bottom and 3600 psi off bottom. Torque = 6k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 11.08-11.15 ppg. P/U = 170k, S/O = 95-92k, Rot= 120-122k w/ um off. Page 24 of 69 09/09/2006 00:00 06:00 6.00 10,337 10,877 PROD1 On:vO u7:i5 i.25 10,877 11,025 ~ PROC1 07:15 08:30 1.25 11,025 10,035 PROD1 08:30 12:00 3.50 10,033 8,724 PROD1 12:00 18:00 6.00 8,724 5,817 PROD1 18:00 19:30 1.50 5,817 5,817 PROD1 19:30 21:00 1.50 5,817 5,815 PROD1 21:00 23:00 2.00 5,815 10,035 PROD1 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM DRILL DDRL P Drilling 6-3/4" production (Sidetrack #3) A2 lateral f/ 10337' (3741' TVD) to 10877' (540') (3733' TVD) Bit hours= 31.29, Jar (#141-0005) hours= 31.29, Jar (#1471-0043) hours = 137.74 Accelerators (#1447-1033) = 108.83 hrs, ART= 4.46 hrs, WOB= 2-8k, 110 rpm, 350 gpm @ 34150-3980 psi on bottom and 4050-3910 psi off bottom. Torque = 6-7k ft-Ibs on botttom and 6-7k ft-Ibs off bottom. ECD= 11.23-11.56 ppg. P/U = 173-190k, S/O = 85-78k, Rot= 122-120k w/ pump off. Pumped weighted hi vis sweep (10.8 ppg, 225 vis) while drilling @ 10,499'-1-590'. Slight increase in cuttin s returns. DRILL CDRL P DrilFng S-3/4" prcduction (Sidetrack #3) A2 lateral f/ 10877' (3733' TVD) to 11025' (148') (3779' TVD) Bit hours= 32.22, Jar (#141-0005) hours= 32.22, Jar (#1471-0043) hours = 138.67 Accelerators (#1447-1033) = 109.76 hrs, ART= .93 hrs, W06= 4-7k, 110 rpm, 350 gpm @ 3980 psi on bottom and 3910 psi off bottom. Torque = 7k ft-Ibs on botttom and 6-7k ft-Ibs off bottom. ECD= 11.23-11.56 ppg. Avg gas 35 units. P/U = 190k, S/O = 78k, Rot= 120k w/ um off. DRILL TRIP P POOH f/ 11025' to 10035'. DRILL REAM P Backream out of hole f/ 10035' to shoe @ 8724'. Pumping 350 gpm w/ 3570 psi. Rotate @ 130 rpm w/ 7k torque. ECD's 10.83 DRILL REAM P Continue backreaming out of hole f/ 8724' to shoe @ 5920', then to 5817'. Pumping 350 gpm w/ 2800 psi, Rotate @ 130 rpm w/ 6k torque. ECD's 9.89 ppg. Pulling speed 40-45 ft/min. Tight s of 10035'. DRILL CIRC P MU top drive, pump 40 bbls hi vis his wt sweep (10.8ppg, 200 vis). Recip 5817' to 5720'. Rotate 100 rpm w/ 6k ft Ib torque, pump 350 gpm w/ 2850 psi. Pump surface to surface. PU wt 140k, SO wt 110k.then 2 BU. RIGMN SVRG P Service top drive and traveling equipment, crown. Inspect top drive. Re air broken tie wire on swivel. DRILL TRIP P Trip in hole f/ 5815' to 10035' (3768' TVD). Fill pipe every 20 stands purring 5.5 bpm w/ 1700 psi. Record PU and SO wt's eve 5 stands in o en hole. Page ZS of 69 ~''n.,+~ Gnm Tr, Il~ir C lion+h G flopth PhncA (~nrla Ciihcnrla T (~(~M ~ 09/09/2006 23:00 00:00 1.00 10,035 10,035 PROD1 DRILL CIRC P Establish circulation. Rotate @ 100 rpm w/ 6k ft Ib torque. Pumping 350 gpm w/ 3600 psi. Pump 40 bbls hi vis hi wt swee 10.8 , 200 vis . 09/10/2006 00:00 00:30 0.50 10,035 10,035 PROD1 DRILL CIRC P Establish circulation. Rotate @ 100 rpm w/ 6k ft Ib torque. Pumping 350 gpm w/ 3600 psi. Pump 40 bbls hi vis hi wt swee 10.8 , 200 vis . 00:30 00:45 0.25 10,035 10,035 PROD1 DRILL SFTY P PJSM on displacement f/ 8.8 ppg OBM to 8.7 ppg SFOBM. Continue circulating while conducting meeting. Total of 510 bbls um ed. 00:45 01:15 0.50 10,035 10,035 PROD1 DRILL CIRC P Displace 8.8ppg OBM w/ 8.7 ppg SFOBM. Pump 245 bbls, fol!e~v w/ 20 bbls dry job (10.8 ppg), then chase lines w/ 10 bbls. 01:15 01:45 0.50 10,035 10,035 PROD1 DRILL OWFF P Monitor well, OK. Blow down top drive. PJSM on POOH to run 4-1/2" liner. Drop 2-5/16" hollow rabbit w/ 120' wire on stand #65. 01:45 06:00 4.25 10,035 2,147 PROD1 DRILL TRIP P POOH f/ 10035' (3668' TVD) to 2147'. PU and SO wt's @ 2147' : 107k up, 107k down. 06:00 08:15 2.25 2,147 92 PROD1 DRILL TRIP P Continue trip out w/ BHA #5 f/ 2147' to 92', to run 4-1/2" A2 liner. 08:15 09:00 0.75 92 92 PROD1 DRILL OTHR P Download Sperry Sun MWD tools. 09:00 10:15 1.25 92 0 PROD1 DRILL PULD P UD BHA #5. 10:15 11:00 0.75 0 0 COMPZ CASIN( OTHR P Clean and clear rig floor. RU to run 4-1/2" 11.6 ppg, L-80, BTC slotted and blank liner. 11:00 11:15 0.25 0 0 COMPZ CASIN( SFTY P PJSM on running 4-1/2" 11.6 ppf, L-80 BTC slotted/blank liner. 11:15 16:00 4.75 0 4,857 COMPZ CASIN( RNCS P RIH w/ 4-1/2" slotted liner per detail. Run 3-1/2" 9.3 ppf L-80 EUE 8rd (orange peeled end), x-o, x-o, 4-1/2" Easy Well Solutions Swell Packer, then 4-1/2" 11.6 ppf L-80 BTC slots and blanks. Run 31 slots (1309.01') and 83 blanks (3472.64'), 4-1/2" pup jt, x-o bushing, 190-47 casing seal bore extension to 4857' 16:00 16:30 0.50 4,857 4,857 COMPZ CASIN( RNCS P PU/MU Baker "HRD" ZXP liner top packer assembly. GBR casing tongs locked up and damaged Flex Lock liner hanger, while trying to torque to 7900 ft lbs. 16:30 17:30 1.00 4,857 4,857 COMPZ CASIN( OTHR T Remove GBR power tongs f/ liner han er assembl . 17:30 18:00 0.50 4,857 4,857 COMPZ CASIN( OTHR T UD Baker liner hanger assembly to send to Deadhorse to have Flex-Lockliner han er than ed out. Page Z6 of 69 I n.,+~ Grl..,, Tn niir C north F nanth PhacP (:nrla Cuhenria T C'.nM I ......, 09/10/2006 ,,,,.. 18:00 ,., 21:15 .f .., 3.25 v...., ... 4,857 ~. -- -.. 4,857 _-- COMPZ ---- CASIN( ------- WOEQ T -- Waiting on Baker hanger. Hanger sent to Baker Machine shop to remove Flex lock hanger and apply another. Clear and clean rig floor. RU GBR backu set of ton s. 21:15 21:30 0.25 4,857 4,857 COMPZ CASIN( OTHR T Load baker liner hanger assembly into i e shed. 21:30 22:00 0.50 4,890 4,890 COMPZ CASIN( RNCS T PU/ MU Baker hanger assembly to 7000 ft Ib torque. Check brass screws. RIH to 4890'. 22:00 22:45 0.75 4,890 4,890 COMPZ CASIN( OTHR P Mix gel (PAL Mix) to pour in liner top tie back extension. Allow el to set u . 22:45 23:00 0.25 4,890 4,900 COMPZ CASIN( OTHR P RIH w/ Baker liner hanger assembly to 4900'. Chan e elevators f/ 3-1f2" to 4". 23:00 00:00 1.00 4,900 5,920 COMPZ CASIN( RUNL P RIH w/ 4-1/2" slotted/blank liner f/ 4900' to 5900'. Run on 4" dp w/super sliders. Run 11 stands till midnight. Record PUwt 128k, SO wf 105k, Roate wt 115k. Roate @ 25 rpm w/ 3-4k ft Ib torque. Circ 3 bpm w/ 250 psi w/ 18% flow. 09/11/2006 00:00 04:30 4.50 5,920 10,058 COMPZ CASIN( RUNL P RIH w/ 4-1/2" slotted/blank liner on 4" drill pipe f/ 5900' to 10058'. Run on 4" dp w/ super sliders. Run 36 stands total, then 4 stands 4" HWDP, then 15 stands hybrids [(2) 5" DC's w/ (1) 4" HWDP on top], then PU single HWDP. Record PU and SO wt's every 5 stands in open hole. Rabbit to 2.33" f/ 20th stand of super sliders to stand 36, i then all 4 HWDP, 15 hybrids and single HWDP. Break circ every 20 stands. Circ @ 5900' 3 bpm w/ 250 psi. PU wt 128k, SO wt 105k. Rotate @ 20 rpm w/ 3-4k ft Ib torque. Rotating weight 115k. Circ @ 7700' 3 bpm w/ 350 si. PU wt 150k, SO wt 100k. 04:30 05:00 0.50 10,058 10,040 COMPZ CASIN( OTHR P Work liner f/ 10058 to 10030'. Record PU and SO wt's. Beginning PU wt 215k, SO wt 105k. After working twice the PU wt was 205k, SO wt 112k. Drop 1-3/4" ball and set pipe on depth w/ top of liner @ 5149.6' and bottom of 3-1/2" shoe joint @ 10040.39' while circulating ball down @ 3 bpm w/ 500 si. 05:00 05:30 0.50 10,040 5,150 COMPZ CASIN( OTHR P Pressure up to 1600 psi, set down, Pick back up to mark, pressure to 2500 psi, slack off to 70k (top drive wt), liner set. Pressure to 3900 psi and release liner. PU 5', break off single. PU wt 180-185k. SO wt 142k. 05:30 05:45 0.25 5,150 5,150 COMPZ CASIN( DHEQ P Pressure test packer and annulus to 1000 si f/ 5 min. Chart test. 05:45 06:00 0.25 5,150 5,150 COMPZ CASIN( OTHR P Pick up, slack off to tag top of liner w/ do s. Page 27 of 69 l n~+o Grnm Tn n. ~r G flanth F rlanth Phaca (:nr1e Suhrncla . T CC~M I 09/11/2006 06:00 06:45 0.75 5,150 5,039 COMPZ CASIN( RUNL P Pull and set back a stand wet.to 5039'. 06:45 07:30 0.75 5,039 5,039 COMPZ CASIN( CIRC P Circulate bottoms up @ 5 bpm w/ 800 si. Pum ed 150 bbls. 07:30 08:00 0.50 5,039 4,946 COMPZ CASIN( RUNL P Pull and set back a stand wet.to 4946'. 08:00 08:30 0.50 4,946 4,946 COMPZ CASIN( CIRC P Pipe was pulling wet. Pumped 30 bbls dry job. Blow down top drive and kill line. 08:30 11:00 2.50 4,946 0 COMPZ CASIN( RUNL P Continue POOH w/ Baker liner running tool. Cleaning and inspecting 4" Western Well Toolssuper sliders on wa out. 11:00 11:45 0:7 5 C 0 COMPZ. CASIN( OTHR P Break and !ay down Baker liner runnin tool. 11:45 12:30 0.75 0 0 COMPZ CASIN( OTHR P Clear and clean rig floor after POOH w/ A2 liner runnin tools. 12:30 13:15 0.75 0 0 COMPZ EVALV~ SFTY P PJSM w/ Schlumberger wireline on RU and running USIT. Safety meeting w/ both ri crews. 13:15 14:30 1.25 0 0 COMPZ EVALV~ RURD P Rig up Schlumberger wireline. MU toolstrin .. 14:30 15:45 1.25 0 0 COMPZ EVALVI~ OTHR T RIH w/USIT and tractor to 200'. Trouble shoot problem w/ tools string. POOH change sub. RIH to 200'. Same roblem. POOH, chan e out SONDE. 15:45 17:15 1.50 0 5,120 COMPZ EVAL1l~ ELOG P RIH w/ Schlumberger USIT and Schlumberger tractor. RIH to 4750', tractor f/ 4750' to 5120'. 17:15 18:45 1.50 5,120 0 COMPZ EVALV4 ELOG T Trouble w/ USIT toolstring. Touble shoot problem. POOH to continue troubleshooting toolstring. Found bad telemet cartid a Brains . 18:45 19:30 0.75 0 5,120 COMPZ EVALVI~ ELOG T RIH w/ Schlumberger USIT and tractor to 4850', tractor f/ 4850' to 5120'. 19:30 21:00 1.50 5,120 0 COMPZ EVALV~ ELOG P Begin logging up. Logged to 2700'. POOH. Identified top of cement @ 2885'. Note: 10-3/4" shoe @ 2642.83'. TOC is 242.17' below 10-3/4" shoe. Well was flushed and freeze protected w/ 80 bbls diesel on 9/2/2006. 21:00 22:00 1.00 0 0 COMPZ EVALV~ RURD P Rig down Schlumberger wireline. 22:00 22:30 0.50 0 0 COMPZ WELCT OTHR P Pull Vetco gray wear bushing. 22:30 00:00 1.50 0 0 COMPZ WELCT BOPE P Set Vetco Gray test plug. PJSM. RU to test BOPE. 09/12/2006 00:00 06:30 6.50 0 0 COMPZ WELCT BOPE P Test BOPE (2 week test). Test witnessed by AOGCC inspector John Spaulding. Test all to 250 low f/ 5 min, then to 3000 si hi f/ 5 min. Chart test. 06:30 08:00 1.50 0 0 COMPZ WELCT OTHR P Rig down BOPE testing equipment. Pull test plug. Install Vetco Gray wear bushing.Blow down kill line, choke line, choke manifold and to drive. Page Z8 of 69 IC1-.tom Cr.,.., Tn n~ it C rlcnth F rlonth Ph~co r~nt~la ~uhenrla T ('(1M 09/12!2006 08:00 09:00 v 1.00 0 vV 0 PROD2 FISH SFTY P PJSM on picking up BHA #6 (Whipstock f/ "B" lateral}. Puil all tools to ri floor. 09:00 09:30 0.50 0 0 PROD2 FISH PULD P Breakout & lay down Smart Stabilizer & PWD assembl . 09:30 11:00 1.50 0 200 PROD2 FISH PULD P PU/MU BHA #6 (Whipstock & mills f/ 'B" lateral). Make up Baker Seal assembly w/ No-Go (1.92'), 4 3/4" Unloader Sub (5.18'), 2 -joints of 3 1/2" DP (62.30'), 3 1/2" Flex Joint (6.50'), Double Pin Crossover (2.28'), 7 5/8" Bottom Trip Anchor (3.23'), 3 1/2" Shear Disconnect (1.69'), 4 3/4" Drain Sub. (1.49'), Debris S!~b with Cup (2.0'), 7 5/8" Whipstock Slide ('14.45'), 6.156" Starting Mill (1.08'), 6.313" Lower Mill (5.57'), 6 3/4" Upper watermelon mill (5.83'), 1 -joint 3 1/2" HWDP (29.80'), 4 3%4" FIOat SUb ~L.33` . 11:00 12:00 1.00 200 250 PROD2 FISH PULD P Make up 4 3/4" MWD assembly (46.02'). Orient MWD to whipstock face. Plug in and download MWD assembl . 12:00 13:30 1.50 250 250 PROD2 FISH PULD P Continue download & orient MWD to whipstock face. Observe bad Float in FLoat sub, Chan e out same. 13:30 14:00 0.50 250 485 PROD2 FISH PULD P Complete make up BHA with 4 3/4" Bumper Jar (7.73'), Crossover Sub (2.99'), and 3 -stands of Hybrid Drill Collars (278.43'). Total BHA = 485.03'. Total BHA after setting whipstock = 379.78'. 14:00 14:30 0.50 485 485 PROD2 FISH PULD P Make Top Drive connection .Rig up to perform Pulse test on MWD assembly. Pumps @ 300 GPM - 890 PSI. Good test. 14:30 18:00 3.50 485 3,477 PROD2 FISH TRIP P Trip in hole with BHA #6 at 3 -minutes / stand as per Baker Rep, and Co. Rep from 485' - 3477'. Fiil Drill String every 25 stands. Crew Chan e. Page 29 of 69 Time Lo s `.Date .From To Dur S. De th E. De th Phase Code Subcode T COM 09/13/2006 07:30 08:30 1.00 0 0 PROD2 DRILL OTHR P Make up Stack washing tool and RIH to flush stack of all metal cuttings from milling. Function rams, HCR's, and manual valves while flushing. Blow down all lines, and To Drive. 08:30 09:00 0.50 0 0 PROD2 DRILL OTHR P Breakout & lay down Stack washing tool. prepare rig floor for MU BHA #7. Hold PJSM with crew, DD &MWD reps. Discuss safety issues and procedure for making up 6 3/4" driling assembl ,BHA #7. 09:00 12:00 3.00 0 3,496 PROD2 DRILL PULD P Make up 6 3/4" Smith bit MDT52 9.84') with 6 x 13's jets for a TFA of .778 sq. in. on a 5" SperryDrill 6/7-6.0 stg w/ ABi motor (32.02'), 4 3/4" Non MAg Float sub (2.33'), 4.870" Welded Blade Stabilizer (5.22'), 4 3/4" MWD terminating sub (1.85'), 4 3/4" n.- / /~~ c ~~ ~ /n fl;. ti ~ ~dmma/Res ~L~.J2~, MJ1,~ ~~~ec~~ona~ (8.56'), 4 3/4" PWD (10.82'), 4 3/4" TM HOC (11.10'), 3 -Non MAg Flex Drill Collars (93.28'), Crossover Sub (2.99'), 1-jnt of 4" HWDP (30.67'), 4 3/4" Dailry Drilling jars (31.96'), 1-jnt of 4" HWDP (30.68'), 48 jnts of 4" XT39 DP (1498.26'), Crossover sub (2.97'), Agitator (8.75'), Shock Sub (8.30'), Crossover sub (3.00'), 48 jnts of 4" XT39 DP (1500.26'), Dailey DNT Mechanical jars (32.24'), 2 jnts of 4" XT39 DP 962.32'), Accelerator jar (31.14'), and 2 jnts of 4" Xt39 DP (62.50'). Total BHA #7 = 3496.58'. perform Shallow pulse test on MWD with pumps @ 245 GPMs- 1100 PSI. Good test. 12:00 15:15 3.25 3,496 4,960 PROD2 DRILL TRIP P Trip in hole with 4" DP from 3496' - 4960'. 15:15 15:45 0.50 4,960 4,960 PROD2 DRILL TRIP P Fill drill string with mud, check pump pressures and MWD assembly. Held "Man down drill". 15:45 16:00 0.25 4,960 4,960 PROD2 RIGMN SFTY P Held PJSM with rig crew. Discuss Safety issues and procedure for sli in and cuttin drillin line. 16:00 17:30 1.50 4,960 4,960 PROD2 RIGMN SVRG P Slip & cut 110' of drilling line. Inspect and adjust brakes on draw works. Service Top drive, Blocks and crown section. Inspect shot pin asembly on TD. Page 31 of 69 n r__~ -r_ n.._ n n,..ii., c n....aL, ni-.....,. r`...d., C~~h..nrlo T !'(l~A 09/13/2006 17:30 18:00 0.50 4,960 5,062 PROD2 DRILL TRIP P Continue trip in hole with 4" DP to 5000' MD. Fill drill string Obtain SPR's, and orient tool face on drill string to 15 degrees left of high side for passing through window area @ 5047' - 5059' MD. Observe no issues going through window and continue TIH to tag @ 5062' MD. Wash down to 5070'. Crew Chan e 18:00 00:00 6.00 5,062 5,279 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 5070' - 5279' MD (209'). TVD = 3606'. Pumps @ 300 GPMs - 3150 PSI. RPMs = 70-80, WOB = 2-1 OK, Torque on = 5K, Torque Off btm = 3K, UP WT = 138K, SO WT = 110K, ROT WT = 125K,. ADT = 3.16 HRS, AST = 2.09 HRS, ART = 1.07 HRS. Total Bit HRS = 3.16 HRS. Total Jar HRS #14710043 = 141.83 HRS. Total Jar HRS # 14710005 = 35.38 HRS. ACC HRS = 112.92. MAx gas observed = 134 units, ECD = 9.48 PPG. Observed drilling Concretions @ 5077'-5079', 5101'-5106', 5122'-5129', 5146'-5150', 5160'-5168', 5182'-5185', 5200'-5204', for a total of 33'. Survey @ 5207.76 MD, INC = 93.83 DEG, AZ = 179.27 DEG, 3610.26 TVD. Mud WT = 8.85 PPG Visc = 62, YP = 18, PV = 16. Gels = 16/26/34 09/14/2006 00:00 06:00 6.00 5,279 5,396 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 5279' - 5396' MD (117'). TVD = 3599'. Pumps @ 300 GPMs - 3320 PSI. RPMs = 70-80, WOB = 2-6K, Torque on = 5K, Torque Off btm = 4K, UP WT = 135K, SO WT = 110K, ROT WT = 125K,. ADT = 7.41 HRS, AST = 4.30 HRS, ART = 3.11 HRS. Total Bit HRS = 7.41 HRS. Total Jar HRS #14710043 = 146.08 HRS. Total Jar HRS # 14710005 = 39.63 HRS. ACC HRS = 117.08. Max gas observed = 98 units, ECD = 9.55 PPG. Observed drilling Concretions @ 5286'-5298, 5300'-5313',5337'-5346',5385'-5395' for a total of 44'. Survey @.5394.41 MD, INC = 87.96 DEG, AZ = 182.35 DEG, 3602.10 TVD. Mud WT = 8.8 PPG. Visc = 61, YP = 18, PV = 1 b. Gels = 17/25. Crew Chan e Page 32 of 69 Time Lo s Date. From To Dur S. De E. De th Phase Code Subcade T C 09/14/2006 06:00 12:00 6.00 5,396 5,748 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 5396' - 5748' MD (352'). TVD = 3599'. Pumps @ 300 GPMs - 3350 PSI. RPMs = 70-90, WOB = 2-6K, Torque on = 5K, Torque Off btm = 4K, UP WT = 140K, SO WT = 112K, ROT WT = 125K,. ADT = 7.41 HRS, AST = 4.30 HRS, ART = 3.11 HRS. Total Bit HRS = 10.90 HRS. Total Jar HRS #14710043 = 149.57 HRS. Total Jar HRS # 14710005 = 43.12 HRS. ACC HRS = 120.66. Max gas observed = 29 units, ECD = 9.80 PPG. Observed drilling Concretions @ 5435'-5441' , 5465'=5473', 5478'-5490', 559 9'-5604',5650'-5657', for a total of 38'. Survey @ 5676.75 MD, INC = 90.44 DEG, AZ = 183.07 DEG, 3599.35 TVD. Mud WT = 8.85 PPG Visc = 60, YP = 18, PV = 16. Gels = 16/24. Obtain Slow pump rates @ 5730' MD, TVD - 3603'. #1 pump @ 20 SPM - 470 PSI, 30 SPM - 740 PSI. #2 pump @ 20 SPM - 430 PSI, 30 SPM - 730 PSI. 12:00 18:00 6.00 5,748 5,987 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 5748' - 5987' MD (239'). TVD = 3591'. Pumps @ 300 GPMs - 3450 PSI. RPMs = 80, WOB = 2-6K, Torque on = 5K, Torque Off btm = 4K, UP WT = 145K, SO WT = 110K, ROT WT = 124K,. ADT = 3.60 HRS, AST = 2.42 HRS, ART = 1.18 HRS. Total Bit HRS = 14.50 HRS. Total Jar HRS #14710043 = 153.17 HRS. Total Jar HRS # 14710005 = 46.72 HRS. ACC HRS = 124.26. Max gas observed = 64 units, ECD = 9.72 PPG. Observed drilling Concretions @ 5815'-5833', 5842'-5858', 5878'-5881', 590 5'-5914',5947'-5950',5954'-5963', for a total of 58'. Survey @ 5955.41' MD, INC = 88.78 DEG, AZ = 182.51 DEG, 3592.07 TVD. Mud WT = 8.85 PPG Visc = 60, YP = 18, PV = 16. Gels = 16/24. Obtain Slow pump rates @ 6020' MD, TVD - 3592'. #1 pump @ 20 SPM - 490 PSI, 30 SPM - 840 PSI. #2 pump @ 20 SPM - 480 PSI, 30 SPM - 750 PSI. Crew Chan e Page 33 of 69 ~ n r__M T_ n...- C n,...ah C n,...th Dhnon !`nrio G ihrnr{n T C`(1M ~ vatc 09/14/2006 i ivtu 18:00 i ~ 00:00 vw 6.00 v. vv u ~ 5,987 ~. ~.... .~ ~ 6,308 ~ ........- PROD2 ........ DRILL ____--- DDRL ~ P - - -- _- Directional Drill 6 3/4' hole in the B Lateral from 5987'- 6308' MD (321'). TVD = 3590'. Pumps @ 300 GPMs - 3400 PSI. RPMs = 80, WOB = 2-6K, Torque on = 5K, Torque Off btm = 4K, UP WT = 145K, SO WT = 110K, ROT WT = 122K,. ADT = 3.14 HRS, AST = .74 HRS, ART = 2.40 HRS. Total Bit HRS = 17.64 HRS. Total Jar HRS #14710043 = 156.31 HRS. Total Jar HRS # 14710005 = 49.86 HRS. ACC HRS = 127.40. Max gas observed = 161 units, ECD = 9.8 PPG. Observed drilling Concretions @ 6000'-6005' , 6047'-6056' , 6073'-6086' , 611 7'-6127',6133'-6135',6145'-6150', for a total of 44'. Survey @ 6190.88' MD, INC = 90.31 DEG, AZ = 180.88 DEG, ~5a3.34 T~iD. M~!d WT = 8.85 PPG Visc = 60, YP = 18, PV = 16. Gels = 16!24. 09/15/2006 00:00 06:00 6.00 6,308 6,869 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 6308' - 6869' MD (561'). TVD = 3591'. Pumps @ 300 GPMs - 3500 PSI. RPMs = 80, WOB = 2-6K, Torque on = 5K, Torque Off btm = 4K, UP WT = 142K, SO WT = 105K, ROT WT = 125K,. ADT = 3.35 HRS, AST = .77 HRS, ART = 2.58 HRS. Total Bit HRS = 20.99 HRS. Total Jar HRS #14710043 = 159.66 HRS. Total Jar HRS # 14710005 = 53.21 HRS. ACC HRS = 130.75. Max gas observed = 188 units, ECD = 10.0 PPG. Observed drilling Concretions @ 6310'-6312',6802'-6808', for a total of 8'. Survey @ 6843.65' MD, INC = 88.57 DEG, AZ = 180.07 DEG, 3588.26 TVD. Mud WT = 8.9 PPG Visc = 75, YP = 19, PV = 17. Gels = 20/28. Obtain Slow pump rates @ 6869' MD, TVD - 3590'. #1 pump @ 20 SPM - 540 PSI, 30 SPM - 810 PSI. #2 pump @ 20 SPM - 550 PSI, 30 SPM - 820 PSI. Crew Chan e Page 34 of 69 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/15/2006 06:00 12:00 6.00 6,869 7,151 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 6869' - 7151' MD (282'). TVD = 3581'. Pumps @ 300 GPMs - 3450 PSI. RPMs = 80, WOB = 5-8K, Torque on = 5K, Torque Off btm = 4K, UP WT = 150K, SO WT = 106K, ROT WT = 126K,. ADT = 3.21 HRS, AST = .99 HRS, ART = 2.22 HRS. Total Bit HRS = 24.20 HRS. Total Jar HRS #14710043 = 162.87 HRS. Total Jar HRS # 14710005 = 56.42 HRS. ACC HRS = 133.96. Max gas observed = 148 units, ECD = 9.75 PPG. Observed drilling Concretions @ 7115'-7127', for a total of 12'. Surrey @ 7126.83' MD, INC = 92.96 DEG, AZ = 179.78 DEG, 3583.46 TVD. Mud WT = 8.9 PPG Visc = 75, YP = 19, PV = 17. Gels = 20/28. 12:00 18:00 6.00 7,151 7,402 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 7151'-7402' MD (251'). TVD = 3584'. Pumps @ 300 GPMs - 3510 PSI. RPMs = 80, WOB = 5-8K, Torque on = 5K, Torque Off btm = 5K, UP WT = 151 K, SO WT = 107K, ROT WT = 128K,. ADT = 3.35 HRS, AST = .90 HRS, ART = 2.58 HRS. Total Bit HRS = 27.68 HRS. Total Jar HRS #14710043 = 166.35 HRS. Total Jar HRS # 14710005 = 59.90 HRS. ACC HRS = 137.44. Max gas observed = 152 units, ECD = 9.98 PPG. Observed drilling Concretions @ 7199'-7214', 7245'-7247',7266'-7273',737 6'-7384',7394'-7415', for a total of 43'. Surrey @ 7361.02' MD, INC = 88.95 DEG, AZ = 180.23 DEG, 3583.12 TVD. Mud WT = 8.75 PPG Visc = 63, YP = 21, PV = 17. Gels = 16/27. Obtain Slow pump rates @ 7432' MD, TVD - 3588'. #1 pump @ 20 SPM - 590 PSI, 30 SPM - 870 PSI. #2 pump @ 20 SPM - 600 PSI, 30 SPM - 870 PSI. Crew Chan e Page 35 of 69 n..a.. ~........ T,. n. ~. C n.-...+h G non4h Dhooo (~n'!o C~ ihrnr-la T ('(1M 09/15/2006 18:00 00:00 6.00 7,402 7,714 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 7402'-7714' MD (312'). TVD = 358&'. Pumps @ 300 GPMs - 3620 PSI. RPMs = 80, WOB = 2-8K, Torque on = 5K, Torque Off btm = 5K, UP WT = 150K, SO WT = 105K, ROT WT = 122K,. ADT = 2.99 HRS, AST = .29 HRS, ART = 2.70 HRS. Total Bit HRS = 30.67 HRS. Total Jar HRS #14710043 = 169.34 HRS. Total Jar HRS # 14710005 = 62.89 HRS. ACC HRS = 140.43. Max gas observed = 197 units, ECD = 10.01 PPG. Observed drilling Concretions @ 7457'-7466',7487'-7495',7563'-7576', for a total of 30'. Survey @ 7643.08' MD, INC = 90.00 DEG, AZ = 177.14 DEG, 3587.11 TVD. Mud WT = 8.75 PPG Visc = 69, YP = 21, PV = 19. Gels = 26/33. Obtain Slow pump rates @ 7432' MD, TVD - 3588'. #1 pump @ 20 SPM - 590 PSI, 30 SPM - 870 PSI. #2 pump @ 20 SPM - 600 PSI, 30 SPM - 870 PSI. 09/16/2006 00:00 02:45 2.75 7,714 7,714 PROD2 RIGMN RGRP NP Pull 1 stand. Monitor wel -static. Install Safety Valve in drill string. Work drill string periodically while change out Saver Sub on Top Drive. Observed no well control issues while C/O saver sub. 02:45 06:00 3.25 7,714 8,016 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 7714' - 8016' MD (302'). TVD = 3583'. Pumps @ 300 GPMs - 3670 PSI. RPMs = 80, WOB = 2-6K, Torque on = 6K, Torque Off btm = 5K, UP WT = 150K, SO WT = 100K, ROT WT = 122K,. ADT = 1.60 HRS, AST = .33 HRS, ART = 1.27 HRS. Total Bit HRS = 32.27 HRS. Total Jar HRS #14710043 = 170.94 HRS. Total Jar HRS # 14710005 = 64.89 HRS. ACC HRS = 141.54. Max gas observed = 158 units, ECD = 10.28 PPG. Observed drilling Concretions @ 7849'-7853', for a total of 4'. Survey @ 8017.86' MD, INC = 91.73 DEG, AZ = 179.80 DEG, 3582.80 TVD. Mud WT = 8.75 PPG Visc = 69, YP = 21, PV = 19. Gels = 26/33. Obtain Slow pump rates @ 8091' MD, TVD - 3588'. #1 pump @ 20 SPM - 620 PSI, 30 SPM - 900 PSI. #2 pump @ 20 SPM - 630 PSI, 30 SPM - 920 PSI. Crew Chan e Page 36 of 69 Time n_a_ c........ 'r-.. n. ~. C n.~...4h G no.,4h Dhooo ('nrlc Ci ihrndA -r (`n~~ vac 09/16/2006 i wni 06:00 12:00 vu. 6.00 8,016 8,321 PROD2 DRILL - DDRL P - - - Directional Drill 6 3/4' hole in the B Lateral from 8016' - 8321' MD (305'). TVD = 3579'. Pumps @ 300 GPMs - 3700 PSI. RPMs = 90, WOB = 5-8K, Torque on = 6K, Torque Off btm = 5K, UP WT = 150K, SO WT = 105K, ROT WT = 123K,. ADT = 3.84 HRS, AST = .98 HRS, ART = 2.86 HRS. Total Bit HRS = 36.11 HRS. Total Jar HRS #14710043 = 174.78 HRS. Total Jar HRS # 14710005 = 68.33 HRS. ACC HRS = 145.87. Max gas observed = 145 units, ECD = 10.15 PPG. Observed drilling Concretions @ 8045'-8048', 8082'-8086',8092'-8118',819 0'-8210',8300'-8303', for a total of 56'. Survey @ 8297.15' MD, INC = 91.42 DEG, AZ = 181.86 DEG, 3578.31 TVD. Mud WT = 8.8 PPG Visc = 62, YP = 20, PV = 16. Gels = 25/26. 12:00 18:00 6.00 8,321 8,630 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 8321'-8630' MD (309'). TVD = 3569'. Pumps @ 322 GPMs - 4150 PSI. RPMs = 80, WOB = 8-10K, Torque on = 7K, Torque Off btm = 6K, UP WT = 160K, SO WT = 100K, ROT WT = 125K,. ADT = 3.58 HRS, AST = .84 HRS, ART = 2.74 HRS. Total Bit HRS = 39.69 HRS. Total Jar HRS #14710043 = 178.36 HRS. Total Jar HRS # 14710005 = 71.91 HRS. ACC HRS = 149.45. Max gas observed = 217 units, ECD = 10.12 PPG. Observed drilling Concretions @ 8322'-8326', 8341'-8343',8348'-8350',852 5'-8534', 8535'-8543', 8547'-8550', 8605'-8 609', for a total of 32'. Survey @ 8628.68' MD, INC = 88.53 DEG, AZ = 180.78 DEG, 3574.41 TVD. Mud WT = 8.8 PPG Visc = 62, YP = 20, PV = 16. Gels = 25/26. Obtain Slow pump rates @ 8653' MD, TVD - 3574'. #1 pump @ 20 SPM - 580 PSI, 30 SPM - 920 PSI. #2 pump @ 20 SPM - 580 PSI, 30 SPM - 850 PSI. Crew Chan e Page 37 of 69 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/16/2006 18:00 00:00 6.00 8,630 8,933 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 8630'-8933' MD (303'). TVD = 3960'. Pumps @ 310 GPMs - 3960 PSI. RPMs = 90, WOB = 2-8K, Torque on = 7K, Torque Off btm = 6K, UP WT = 158K, SO WT = 98K, ROT WT = 120K,. ADT = 4.17 HRS, AST = .53 HRS, ART = 3.64 HRS. Total Bit HRS = 43.86 HRS. Total Jar HRS #14710043 = 182.53 HRS. Total Jar HRS # 14710005 = 76.08 HRS. ACC HRS = 153.62. Max gas observed = 250 units, ECD = 10.30 PPG. Observed drilling Concretions @ 8665'-8670',8672'-8689', 8699'-8704',870 7'-8719',8729'-8737', for a total of 47'. Survey @ 8768.72' MD, INC = 88.84 DEG, AZ = 180.97 DEG, 3578.98 T\/[l, PAud \NT = R.$ PPC~ ViSr. = 6:i; YP = 19, PV = 17. Gels = 30/33. 09/17/2006 00:00 06:00 6.00 8,933 9,170 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 8933'-9170' MD (237'). TVD = 3592'. Pumps @ 310 GPMs - 3720 PSI. RPMs = 90, WOB = 2-8K, Torque on = 7K, Torque Off btm = 6K, UP WT = 160K, SO WT = 98K, ROT WT = 122K,. ADT = 3.69 HRS, AST = .58 HRS, ART = 3.11 HRS. Total Bit HRS = 47.55 HRS. Total Jar HRS #14710043 = 186.22 HRS. Total Jar HRS # 14710005 = 79.77 HRS. ACC HRS = 157.31. Max gas observed = 159 units, ECD = 10.40 PPG. Observed drilling Concretions @ 8998'-9004' , 9055'-9059', 9060'-9070', 913 3'-9147',9150'-9160'„ for a total of 44'. Survey @ 9140.86' MD, INC = 90.64 DEG, AZ = 174.87 DEG, 3591.18 TVD. Mud WT = 8.75 PPG Visc = 63, YP = 19, PV = 17. Gels = 25/30. Crew Chan e Page 38 of 69 Time Lo s Date From To Dur S De th E De th Phase Code Subcode T GOM Page 39 of 69 09/17/2006 06:00 12:00 6.00 9,170 9,472 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 9170' - 9472' MD (302'). TVD = 3599'. Pumps @ 315 GPMs - 4000 PSI. RPMs = 90, WOB = 2-8K, Torque on = 7K, Torque Off btm = 6K, UP WT = 170K, SO WT = 109K, ROT WT = 122K,. ADT = 3.71 HRS, AST = .85 HRS, ART = 2.86 HRS. Total Bit HRS = 51.26 HRS. Total Jar HRS #14710043 = 189.93 HRS. Total Jar HRS # 14710005 = 83.48 HRS. ACC HRS = 161.02. Max gas observed = 122 units, ECD = 10.55 PPG. Observed drilling Concretions @ 9392'-9397',9443'-9450',9459'-9461', for a total of 14'. Survey @ 9424.34' MD, INC = 90.18 DEG, AZ = 180.67 DEG, 3592.33 TVD. Mud WT = 8.75 PPG ~~isc = 62, YP = 2~ , PV = 16. Gels = 17/27. 12:00 18:00 6.00 9,472 9,879 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 9472'-9879' MD (407'). TVD = 3588'. Pumps @ 315 GPMs - 4071 PSI. RPMs = 80, WOB = 8-10K, Torque on = 8K, Torque Off btm = 7K, UP WT = 175K, SO WT = 92K, ROT WT = 122K,. ADT = 3.57 HRS, AST = .81 HRS, ART = 2.76 HRS. Total Bit HRS = 54.83 HRS. Total Jar HRS #14710043 = 193.50 HRS. Total Jar HRS # 14710005 = 87.05 HRS. ACC HRS = 164.59. Max gas observed = 133 units, ECD = 10.58 PPG. Observed drilling Concretions @ 9469'-9484' , 9526'-9540' , 9810'-9815' , 985 0'-9852', for a total of 36'. Survey @ 9794.20' MD, INC = 89.50 DEG, AZ = 180.11 DEG, 3586.57 TVD. Mud WT = 8.75 PPG Visc = 62, YP = 21, PV = 16. Gels = 17/27. Obtain Slow pump rates @ 9872' MD, TVD - 3586'. #1 pump @ 20 SPM - 670 PSI, 30 SPM - 970PS1. #2 pump@20 SPM-660 PSI, 30 SPM - 1070 PSI. Crew Chan e I r, r__.,_ T_ n.._ c n,...~ti ~ n,...a4, oti.,..~ r„,~o G~hnr.do T (`(1M I vac 09/17/2006 18:00 19:00 1.00 9,879 9,880 PROD2 DRILL __ _ DDRL P _ _ - Directional Drill 6 3/4' hole in the B Lateral from 9879'-9880' MD (1'). TVD = 3588'. Pumps @ 315 GPMs - 4071 PSI. RPMs = 80, WOB = 8-10K, Torque on = 8K, Torque Off btm = 7K, UP WT = 175K, SO WT = 92K, ROT WT = 122K,. ADT = .08 HRS, AST = 0 HRS, ART = .08 HRS. Total Bit HRS = 54.91 HRS. Total Jar HRS #14710043 = 193.58 HRS. Total Jar HRS # 14710005 = 87.13 HRS. ACC HRS = 164.67. Max gas observed = 133 units, ECD = 10.58 PPG. Observed drilling Concretions @ 9879', for a total of 1'. Cun;ey @ 9794.20' MD, INC = 89.50 DEG, AZ = 180.11 DEG, 3586.57 TVD. Mud WT = 8.75 PPG Visc = 62, YP = 21, PV = 16. Gels = 17/27. n_h±air Clow pump rates @ 9872' MD, TVD - 3586'. #1 pump @ 20 SPM - 670 PSI, 30 SPM - 970 PSI. #2 pump @ 20 SPM - 660 PSI, 30 SPM - 1070 PSI. 19:00 20:45 1.75 9,880 9,880 PROD2 DRILL CIRC T Observed drilling ROP stopped. Could not gain differential pressure. Work drill string and different pump rates to attempt to gain any ROP. No success. Suspect failed mud motor. Pump 35 BBLS of HI VISC weighted sweep, at 310 GPM's - 3850 PSI. Reciprocate & rotate drill string while pump sweep. UP WT = 175K, SO WT = 92K, ROT WT = 122K with 7K torque. Observed 50% increase in cuttings when sweep returned. 20:45 21:45 1.00 9,880 9,375 PROD2 DRILL REAM T Monitor well -static. BROOH for 5 stands @ 25 ft/min from 9880' - 9375' MD. Observe good hole conditions. Monitor well -static. 21:45 00:00 2.25 9,375 6,405 PROD2 DRILL TRIP T Continue POOH on elevators from 9375' - 8936' MD, wet string. Observe good hole conditions and proper hole fill. Monitor well -static, pump 20 BBL dry job, 10.8 PPG, and continue POOH from 8936' - 6405' MD, again with good hole conditions observed with ro er hole fill. 09/18/2006 00:00 03:15 3.25 6,405 1,995 PROD2 DRILL TRIP T Continue POOH from 6405' - 5059'. Pull slow through Window area to 5047' No issues with BHA going through window. Continue POOH from 5047' - 1995'. record T& D parameters as er ri en ineer. Page 40 afi 69 f "n _._ r,_.... -r.. n.._ ~ n,...+H c n,,..+H oti.,~., r~..Jo C~ iF~rnr7o T f`(lAA I v Gll. 09/18/2006 03:15 04:15 1.00 1,995 1,995 PROD2 ~ ~ DRILL ~ ~~ - OTHR T Observed drip pan under rotary table with plugged drains. OBM from drill string would not drain away. Obtain permit, and clean all drains and drip an. 04:15 06:00 1.75 1,995 97 PROD2 DRILL TRIP T Continue POOH from 1955' - 97 MD. Record T&D parameters. Break out, rack back 3 -Non Mag Flex Drill Collars (93.28'), Crossover Sub (2.99'), 1-jnt of 4" HWDP (30.67'), 4 3/4" Dailey Drilling jars (31.96'), 1-jnt of 4" HWDP (30.68'), 48 jnts of 4" XT39 DP (1498.26'), Crossover sub (2.97'), Agitator (8.75'), Shock Sub (8.30'), Crossover sub (3.00'), 48 jnts of 4" XT39 DP (1500.26'), Dailey DNT Mechanical jars (32.24'), 2 jnts of 4" XT39 DP 962.32'), Accelerator jar (31.14'), and 2 jnts of 4" Xt~9 np (62.50').plug into MWD asembly. Crew Chan e 06:00 07:00 1.00 97 97 PROD2 DRILL PULD T Download MWD assembly. PJSM with crew & Sperry Sun reps. Discuss safety issues and procedure for laying down BHA. 07:00 09:00 2.00 97 0 PROD2 DRILL PULD T Continue POOH, breakout & lay down BHA #7, laying down 6 3/4" Smith bit MDT52 9.84') with 6 x 13's jets for a TFA of .778 sq. in. on a 5" SperryDrill 6/7-6.0 stg w/ ABI motor (32.02'), 4 3/4" Non Mag Float sub (2.33'), 4.870" Welded Blade Stabilizer (5.22'), 4 3/4" MWD terminating sub (1.85'), 4 3/4" Gamma/Res (24.52'), MWD Directional (8.56'), 4 3/4" PWD (10.82'), 4 3/4" TM HOC (11.10'). inspect & grade bit to 1/6/BT/G/X/2/CT/DTF. Observed proper hole fill on TOH. 09:00 09:15 0.25 0 0 PROD2 DRILL OTHR T Clean & clear rig floor of OBM & tools. 09:15 09:30 0.25 0 0 PROD2 DRILL SFTY T Held PJSM with crew and Sperry Sun reps. Discuss safety issues and procedure for making up BHA #8, Geo-Pilot Assembl . 09:30 10:45 1.25 0 90 PROD2 DRILL PULD T Make up BHA #8. Make up 6 3/4" Security FMF3641Z PDC long gauge bit (1.29') with 3 x 21 jets for a TFA of 1.015 sq. in., 5 1/4" 5200 Series Geo-pilot TL-043 (16.18'), 4 3/4' Non Mag Geo-pilot Flex Collar (11.54'), 4 3/4" MWD DM HOC (8.56'), 4 3/4" Smart Stabilizer (3.60'), 4 3/4" MWD Gamma/Res (24.57'), 4 3/4" PWD 10.82' 4 3/4" TM HOC 11.10' . 10:45 12:30 1.75 90 90 PROD2 DRILL PULD T Plug in and Upload MWD assembly. Continue Clean ri floor of OBM. Page. 41 of 69 I n..a.. ~.,,.,. -r,., n, ~. c nom.,+h G no.,4h oh~~o ~`nrio G ihrnrlo T C'(1M I 09/18/2006 12:30 13:30 / 1.00 90 ~ 2,160 PROD2 DRILL PULD T Continue make up BHA #8, Make up 4 3/4" Non mag float sub (2.33'), 4 3/4" Welded Blade stabilizer (5.22'), 3 - Non Mag Flex Drill Collars (93.28'), Crossover (2.99'), 1-jnt of 4" HWDP (30.67'), 4 3/4" Dailey Drilling jars (31.96'), 1-jnt of 4" HWDP (30.68'), and 4" XT 39 drill i e to 2160' MD. 13:30 14:30 1.00 2,160 2,160 PROD2 DRILL OTHR T Screw into Top Drive and fill drill string. Attempt to perform Shallow pulse test on BHA -failed. Repeat attempts. Pumps @ 250 GPM's. Blow down TD and ri u to POOH for failed tools. 14:30 16:00 1.50 2,160 90 PROD2 DRILL TRIP T POOH from 2160' - 90' MD. Rack back 4 3/4" Non mag float sub (2.33'), 4 3/4" Welded Blade stabilizer (5.22'), 3 - Non Mag Fiex Drill Collars (93.28'), Crossover (2.99'), 1-jnt of 4" HWDP (30.57'), 4 3/4" Dailey Drilling jars (31.96'), 1-jnt of 4" HWDP (30.68'), and 4" XT 39 drill i e to 2160' MD. 16:00 16:45 0.75 90 90 PROD2 DRILL OTHR T Plug in and download MWD assembly. Clean & clear rig floor of OBM from wet tri . 16:45 18:00 1.25 90 0 PROD2 DRILL PULD T Spin & clear OBM mud from Geo-pilot assembly. Breakout & lay down Make up 6 3/4" Security FMF3641Z PDC long gauge bit (1.29') with 3 x 21 jets for a TFA of 1.015 sq. in., 5 1/4" 5200 Series Geo-pilot TL-043 (16.18'), 4 3/4' Non Mag Geo-pilot Flex Collar (11.54'). lay down Geo-pilot & battery pack. Crew Chan e. 18:00 18:45 0.75 0 90 PROD2 DRILL PULD T PJSM with new rig crew. Discuss safety issues and procedure for making up BHA #9. Make up Make up 6 3/4" Security FMF3641Z PDC long gauge bit (1.29') with 3 x 21 jets for a TFA of 1.015 sq. in., 5 1/4" 5200 Series Geo-pilot TL-043 (16.18'), 4 3/4' Non Mag Geo-pilot Flex Collar (11.54'), 4 3/4" MWD DM HOC (8.56'), 4 3/4" Smart Stabilizer (3.60'), 4 3/4" MWD Gamma/Res (24.57'), 4 3/4" PWD 10.82' 4 3/4" TM HOC 11.10' . 18:45 19:15 0.50 90 90 PROD2 DRILL PULD T Plug in and upload MWD assembly. 19:15 19:45 0.50 90 90 PROD2 DRILL PULD T Pull back up hole to the bit. Change out bits as per Co. Rep. Make up 6 3/4" Security FMF3642 PDC bit (1.29') with 3 x 21 jets for a TFA of 1.015 Sq In. Page 42 of 69 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/18/2006 19:45 21:15 1.50 90 120 PROD2 DRILL PULD T Make up 4 3/4" Non mag float sub (2.33'), 4 3/4" Welded Blade stabilizer (5.22'), 3 -Non Mag Flex Drill Collars (93.28'). 1 stand of 4" DP. Perform Shallow pulse test on MWD assembly with pumps @ 300 GPM's - 2100 PSI. Good test. 21:15 22:15 1.00 120 120 PROD2 RIGMN SVRG T Inspect & Service Top Drive. Inspect mounting plates on motor for TD. ti hten bolts. 22:15 00:00 1.75 120 3,760 PRODZ DRILL TRIP T Continue trip in hole from 120' - 3940'. Make up remaining BHA with 37 stands of 4" DP (3467.56'), Crossover sub (2..97'), Dailey DNT Mechanical jars (32.24'}, 2 jnts of 4" XT39 DP (62.32'), Accelerator jar (31.14'), and 2 jnts of 4" Xt39 DP (62.50'). Total BHA = 3940.53'. 09/19/2006 00:00 06:00 6.00 3,76u 7,035 PROD2 DRILL TRIP T Continue trip ii. hole with BHA #9 fro... 3760' - 5047'. Pump to verify Geo-pilot deflection at zero. Work Drill string through window area, observing haging up on Bit & Stabilizers. Continue TIH, tagging, hanging up & firing jars in spots @ 5253', 5470' and different areas to 7035' MD. Screw into Top drive @ 5470' pumping and observing deflection at 125%. Send commands to zero defletion. Continue trip in hole having to ream in spots from 5047' - 7035' MD, until observe needing to pump almost every stand. Pumps @ 315 GPM's - 2150 PSI, 50 RPM's with 5K for ue. Crew than e 06:00 06:30 0.50 7,035 7,410 PROD2 DRILL TRIP T Continue trip in hole 7035' - 7410' MD on elevators. Observed continued han in u with over ull. 06:30 11:45 5.25 7,410 9,880 PROD2 DRILL REAM T Wash & ream each stand from 7410' - 9880' MD. Pumps @ 330 GPM's - 3100 PSI. 5-8K WOB, with 90-100 RPM's. ROT WT = 120K. Page 43 of 69 Time Lo s Date From To Dur S De th E De th Phase Code Subcode T COM Page 44 of 69 09/19/2006 11:45 12:00 0.25 9,880 9,884 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 9880'- 9884' MD (4'). TVD = 3588'. Pumps @ 345 GPMs - 3430 PSI. RPMs = 110, WOB = 2-8K, Torque on = 9K, Torque Off btm = 8K, UP WT = 172K, SO WT = 92K, ROT WT = 122K,. ADT = .15 HRS, Total Bit HRS = .15 HRS. Total Jar HRS #14710043 = 198.73 HRS. Total Jar HRS # 14710005 = 87.28 HRS. ACC HRS = 164.92. Max gas observed = 43 units, ECD = 11.1 PPG. Surrey @ 9812.24' MD, INC = 88.28 DEG, AZ = 180.60 DEG, 3586.92 TVD. Mud WT = 8.8 PPG Visc = 70, YP = 21, PV = 17. Gels = 28/30. Obtain Slow pump rates @ 9844' MD; TVD - 3586'. #1 pump @ 20 SPM - 570 PSI, 30 SPM - 820 PSI, #2 pump @ 20 SPM - 570 PSI, 30 SPM - 830 PSI. 12:00 18:00 6.00 9,884 10,501 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 9884'- 10501' MD (617'). TVD = 3613'. Pumps @ 340 GPMs - 3650 PSI. RPMs = 110, WOB = 2-1 OK, Torque on = 8K, Torque Off btm = 8K, UP WT = 185K, SO WT = 85K, ROT WT = 121 K,. ADT = 4.25 HRS, Total Bit HRS = 4.25 HRS. Total Jar HRS #14710043 = 202.98 HRS. Total Jar HRS # 14710005 = 91.53 HRS. ACC HRS = 169.07. Max gas observed = 82 units, ECD = 11.2 PPG. Observed drilling Concretions @ 9920'-9923',10336'-10339',10426'-1043 0', for a total of 10'. Survey @ 10466.42' MD, INC = 91.10 DEG, AZ = 180.78 DEG, 3611.83 TVD. Mud WT = 8.8 PPG Visc = 69, YP = 21, PV = 17. Gels = 28/30. Obtain Slow pump rates @ 9844' MD, TVD - 3586'. #1 pump @ 20 SPM - 570 PSI, 30 SPM - 820 PSI. #2 pump @ 20 SPM - 570 PSI, 30 SPM - 830 PSI. Crew Chan e ~ n„~,. C....., T„ n..r C Ilon4h G rlon4h Phom ('nria Cuhrnrla T (~(~M ~ ~..m.. 09/19/2006 18:00 00:00 6.00 10,501 11,020 PROD2 --- DRILL - -- - DDRL P - - -- Directional Drill 6 3/4' hole in the B Lateral from 10501'-11020' MD (519'). TVD = 3593'. Pumps @ 340 GPMs - 3610 PSI. RPMs = 110, WOB = 8-10K, Torque on = 9K, Torque Off btm = 8K, UP WT = 185K, SO WT = 75K, ROT WT = 120K,. ADT = 4.59 HRS, Total Bit HRS = 8.99 HRS. Total Jar HRS #14710043 = 207.57 HRS. Total Jar HRS # 14710005 = 96.12 HRS. ACC HRS = 173.66. Max gas observed = 162 units, ECD = 11.93 PPG. Observed drilling Concretions @ 10982'-1.0984',10994'-10995',11052'-11 063',11128'-11130', for a total of 1S'. Survey @ 10934.25' MD, INC = 92.18 DEG, AZ = 180.08 DEG, 3595.80 TVD. Mud WT = 8.9 PPG Visc = 68, v _ ~ nv _ ~ i.. _ ~ni~~ ~P- i9,rv- i7.Geia-.+....,~. 09/20/2006 00:00 06:00 6.00 11,020 11,626 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 11020' - 11626' MD (606'). TVD = 3592'. Pumps @ 340 GPMs - 3300 PSI. RPMs = 100, WOB = 8-10K, Torque on = 9K, Torque Off btm = 7K, UP WT = 185K, SO WT = 75K, ROT WT = 120K,. ADT = 4.18 HRS, Total Bit HRS = 13.17 HRS. Total Jar HRS #14710043 = 211.75 HRS. Total Jar HRS # 14710005 = 100.30 HRS. ACC HRS = 177.84. Max gas observed = 145 units, ECD = 11.57 PPG. Observed drilling Concretions @ 11052'-11063',11128'-11130',11309'-11 314',11393'-11402', for a total of 27'. Survey @ 11591.66' MD, INC = 91.89 DEG, AZ = 175.37 DEG, 3595.58 TVD. Mud WT = 8.8 PPG Visc = 68, YP = 19, PV = 17. Gels = 30/31. Pump Hi Visc weighted sweep @ 11400' MD, observe 75% increase in cuttings on shakers when returned. Obtain Slow pump rates @ 11153' MD, TVD - 3590'. #1 pump @ 20 SPM - 620 PSI, 30 SPM - 890 PSI. #2 pump @ 20 SPM - 620 PSI, 30 SPM - $90 PSI. Crew Chan e Page 45 of 69 no+o Grnm T., n. ~r C non+h F flAnth Phaca (nrla Si ihnnrla T CC~M 09/20/2006 06:00 12:00 6.00 11,626 11,907 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 11626'-11907' MD (281'). TVD = 3586'. Pumps @ 340 GPMs - 3775 PSI. RPMs = 80-120, WOB = 2-8K, Torque on = 9K, Torque Off btm = 7K, UP WT = 190K, SO WT = 85K, ROT WT = 120K,. ADT = 4.77 HRS, Total Bit HRS = 17.94 HRS. Total Jar HRS #14710043 = 216.52 HRS. Total Jar HRS # 14710005 = 105.07 HRS. ACC HRS = 182.61. Max gas observed = 69 units, ECD = 11.53 PPG. Observed drilling Concretions @ 11724'-11738',11744'-11762', for a total of 32'. Survey @ 11874.01' MD, iNC = 92.63 DEG, AZ = 181.69 DEG, 3586.20 TVD. Mud WT = 8.8 PPG Visc = 68, YP = 19, PV = 17. Gels = 30/31. 12:00 16:00 4.00 11,907 12,242 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 11907'-12242' MD (335'). TVD = 3580'. Pumps @ 340 GPMs - 3750 PSI. RPMs = 80-130, WOB = 2-12K, Torque on = 9K, Torque Off btm = 7K, UP WT = 210K, SO WT = 85K, ROT WT = 120K,. ADT = 1.79 HRS, Total Bit HRS = 19.73 HRS. Total Jar HRS #14710043 = 218.31 HRS. Total Jar HRS # 14710005 = 106.86 HRS. ACC HRS = 184.40. Max gas observed = 79 units, ECD = 11.45 PPG. Observed drilling Concretions @ 11985'-11987',12138'-12143',12163'-12 165', for a total of 9'. Survey @ 12148.86' MD, INC = 91.34 DEG, AZ = 177.58 DEG, 3584.64 TVD. Mud WT = 8.8 PPG Visc = 68, YP = 19, PV = 17. Gels = 30/31. Obtain Slow pump rates @ 12075' MD, TVD - 3584'. #1 pump @ 20 SPM - 660 PSI, 30 SPM - 920 PSI. #2 pump @ 20 SPM - 650 PSI, 30 SPM - 910 PSI. Observe 23 deg dogleg @ 12152', and then MWD trouble. Decision to call TD in lateral. 16:00 16:15 0.25 12,242 12,184 PROD2 DRILL REAM P Back ream out of hole from 12242' -12184', pumps @ 340 GPM's - 3750 PSI, 100 RPMs, with for ue 8K. 16:15 16:30 0.25 12,184 12,094 PROD2 DRILL TRIP P POOH on elevators from 12184'- 12094'. UP WT = 210K, SO WT = 90K. 16:30 18:00 1.50 12,094 12,094 PROD2 DRILL CIRC P Pump 40 BBLS Hi Visc weighted sweep, 10.7 PPG, 200 Visc, @ 330 GPM's - 3780 PSI. Reciprocate & rotate drill string at 100 RPM's with 8K torque. Monitor well -static. Crew Chan e. Page 46 of 69 n.,a,. C..,.., T.. n. ~. C non+h G' non+h Dhocc ('nrln .~'i ihrnrlo T ~nn~ 09/20/2006 18:00 21:00 v 3.00 12,094 10,750 PROD2 DRILL REAM P BROOH from 12094' - 11430'. Attempted to POOH on elevators, observed tight hole, continue BROOH from 11430' - 10750'. Pumps @ 340 GPM's - 3600 PSI. 100 RPM's. Circulated strokes = 2 btms up, before attem t POOH on elevators. 21:00 22:00 1.00 10,750 10,200 PROD2 DRILL TRIP P POOH on elevators from 10750' - 10200'. Observe good hole conditions and proper hole fill. Monitor well - static. 22:00 00:00 2.00 10,200 7,900 PROD2 DRILL TRIP P Pump dry job. Blow down TD & lines. Continue POOH on elevators from 10200' - 7900' MD. Obserre good hole conditions and ro er hole fill. 09/21/2006 00:00 02:15 2.25 7,900 4,972 PROD2 DRILL TRIP P Continue POOH on elevators from 7900' - 4972' MD. Observe good hole conditions and ro er hole fill. 02:15 03:30 1.25 4,972 4,972 PROD2 DRILL CIRC P Circulate 40 BBL Hi Visc weigted sweep (10.8 PPG - 170 Visc) @ 3410 GPM's - 2600 PSI. 100 RPM's with 5K torque. Reciprocate 7 rotate drill string while pump. Observed no significant increase in cuttings on return of swee . 03:30 05:15 1.75 4,972 4,972 PROD2 RIGMN SVRG P Slip & cut 105' of drilling line. Inspect & adjust brakes on draw works. Ins ect & service To Drive. 05:15 06:00 0.75 4,972 6,000 PROD2 DRILL TRIP P Trip back in hole from 4972' - 6000' MD. Observe proper hole fill. Observed no issues when BHA going through window area. UP WT = 145K, SO WT = 105K. Obtain T&D parameters as er ri en ineer. Crew Chan e 06:00 09:15 3.25 6,000 9,942 PROD2 DRILL TRIP P Continue trip in hole from 6000' - 9942' MD. Obtain T&D parameters as per rig engineer. Every 5 stands in open hole. Observed good hole conditions, filling drillin drill strin eve 25 stands. 09:15 12:00 2.75 9,942 11,709 PROD2 DRILL REAM P Ran out of downweight. Make Top Drive connection. Fill drill string. Wash & ream from 9942' - 11709'. Pumps @ 126 GPM - 1000 PSI & 60 RPM's 12:00 12:30 0.50 11,709 12,094 PROD2 DRILL REAM P Continue wash & ream in hole from 11709' - 12094' MD. Pumps @ 126 GPM - 1000 PSI & 60 RPM's 12:30 14:15 1.75 12,094 12,094 PROD2 DRILL CIRC P Establish Circulation rates of 340 GPM's- 4000 PSI. 140 RPM's, and pump a Weighted Hi Visc sweep. Reciprocate & rotate drill string while pumping. UP WT = 124K, SO WT = 104K, ROT WT = 112K. Circulate swee + 2 Btms u until clean. Page 47 of 69 I n~to Fmm Tn rl~ir C flonth F rlanth Phaca C~nrla ~uhnnria T C:nM I 09/21/2006 14:15 15:00 0.75 12,094 12,094 PROD2 DRILL CIRC P Rig up and displace production hole section to 8.9 PPG SFMOBM, 350 BBLS. Chase with 25 BBL Dryjob. Calculated top of SFMOBM = 4500' MD 15:00 15:15 0.25 12,094 12,094 PROD2 DRILL TRIP P Monitor well -static. Drop 2 1/4" drift with tail wire in DP. 15:15 18:00 2.75 12,094 8,162 PROD2 DRILL TRIP P POOH on elevators from 12094' - 8162' MD. Observed good hole conditions and no overpull issues.Observed ro er hole fill. Crew Chan e 18:00 20:00 2.00 8,162 4,980 PROD2 DRILL TRIP P Continue POOH with BHA #9 from 8162' - 4980'. observed no issues going_throuh window area with BHA. Monitor well -static. 20:00 20:30 0.50 4,980 3,940 PROD2 DRILL TRIP P Continue POOH from 4980' - 3940' . Stand back Acceleratorjar (31.14'), and 2 jnts of 4" Xt39 DP (62.50'). Pull 2 '114" Drif[ from assembly, and drop in remainin BHA with tail wire. 20:30 22:00 1.50 3,940 295 PROD2 DRILL TRIP P Continue POOH from 3940' - 295' MD. Racking back 37 stands of 4" DP (3467.56'), Crossover sub (2.97'), Dailey DNT Mechanical jars {32.24'), 2 'nts of 4" XT39 DP 62.32' . 22:00 22:45 0.75 295 97 PROD2 DRILL PULD P Continue POOH breakout & lay down 4 3/4" Welded Blade stabilizer (5.22'), 3 -Non Mag Flex Drill Collars (93.28'), Crossover (2.99'), 1-jnt of 4" HWDP (30.67'), 4 3/4" Dailey Drilling jars (31.96'), 1-jnt of 4" HWDP (30.68'), and 4" XT 39 drill i e 22:45 23:15 0.50 97 97 PROD2 DRILL PULD P Plug in and download MWD asembly. prepare rig floor for next run with 4 1/2" liner. 23:15 00:00 0.75 97 25 PROD2 DRILL PULD P Continue POOH, Breakout & lay down 4 3/4" MWD terminating sub (1.85'), 4 3/4" Gamma/Res (24.52'), MWD Directional (8.56'), 4 3/4" PWD 10.82' , 4 3/4" TM HOC 11.10' . 09/22/2006 00:00 00:15 0.25 25 0 PROD2 DRILL PULD P Continue POOH breakout & lay down 6 3/4" Security FMF3641Z PDC long gauge bit (1.29') with 3 x 21 jets for a TFA of 1.015 sq. in., 5 1/4" 5200 Series Geo-pilot TL-043 (16.18'), 4 3/4' Non Mag Geo-pilot Flex Collar (11.54'). lay down Geo-pilot & battery pack, 4 3/4" Non mag float sub (2.33'). Inspect & au a bitto 1/1/BT/A/X/I/NO/DTF. 00:15 00:45 0.50 0 0 COMPZ CASIN( RURD P Clean & clear rig floor area. Send tools out. Rig up liner running tools for 4 1/2" Slotted liner. Pick up Tongs, elevators, and sli s. . Page 48 of 69 Time Lo s Date From To Dur S De th E De th Phase Code Subcode T COM Page 49 of 69 09/22/2006 00:45 01:30 0.75 0 0 COMPZ CASIN( SFTY P Held PJSM with rig crew, GBR rep, and BOT rep. Discuss safety issues and procedure for picking up 4 1/2" slotted liner. Open blind rams and monitor well -static. 01:30 06:00 4.50 0 6,402 COMPZ CASIN( RNCS P Make up 4 1/2" Siver Bullet Shoe (1.67'), 1 - jnt of 4 1/2" 12.6# IBT blank (31.17'), and 4 1/2" XO pup to BTC (2.06'). Continue make up 4 1/2" Slotted /Blank liner as per detail. Run from surface to 6402' MD. Obtain T&D parameters as per rig engineer. MU TQ = 4500 FUlbs. MU TQ w/ TO rings = 5K FT/LBs. Observe no issues as Shoe passing through window area. Crew Chan e 06:00 07:00 1.00 6,402 6,857 COMPZ CASIN( RNCS P Continue run 4 1/2'' Slotted liner from I 6402' - 6857'. Observed proper hole fill. No 0 8n hole issues. 07:00 07:30 0.50 6,857 6,857 COMPZ CASIN( RNCS P Change elevators & power tongs. Make up 5 1/2" Hydril 521 x 4 1/2" BTC XO bushing (1.42') with 4 1/2" BTC pup (3.80'), 1 joint of 5 1/2" Hydril 521 Biank (36.60'), 5 1/2" Hydril 521 pup (8.98'), and BOT "H R" liner setting sleeve (12.64'), with running tool & XO (6.44',2.99'). Rig down GBR casing equipment. Clean & clear floor area for TIH w/ DP. 07:30 12:00 4.50 6,857 11,700 COMPZ CASIN( RUNL P obtain Up/DN weights with liner. UP WT = 125K, SO WT = 95K. ROT WT = 109K. TIH with 4 1/2" Slotted liner on DP form 6857' - 10600' MD. Running speed as per BOT rep. Rotate liner in hole from 10600' - 11700' MD at 20 RPM's - 5K t . 12:00 13:15 1.25 11,700 12,093 COMPZ CASIN( RUNL P Continue RIH with Slotted liner rotating liner from 11700' - 12093' MD. 25 RPM's - 7K for ue. Set liner on de th. 13:15 14:15 1.00 12,093 12,093 COMPZ CASIN( OTHR P Drop 29/32" Ball, pumping @ 2.5 BPM, observing ball landed and pressuring up to 3500 PSI. Continue pressure to 4000 PSI, releasing liner setting tool with the top @ 5244' MD. Bleed all pressures. Pull up to observe wei ht loss and free from liner. 14:15 14:30 0.25 5,244 4,947 COMPZ CASIN( RUNL P POOH with DP from 5244' - 4947' MD. Observe wet drill strin . 14:30 15:00 0.50 4,947 4,947 CCMPZ CASIN( CIRC P Circulate bottoms up @ 300 GPM's - 1075 PSI. Monitor well -static. 15:00 15:30 0.50 4,947 4,947 COMPZ CASIN( RUNL P Pump dry job. Blow dow TD & lines. Dro 1.93" drift in DP with tail wire. 15:30 18:00 2.50 4,947 0 COMPZ CASIN( RUNL P POOH with DP from 4947' -surface. Inspect, breakout and fay down BOT runnin tools. All ood. Crew Chan e. 18:00 19:00 1.00 0 0 COMPZ CASIN( RUNL P Finish laying down running tools. Clean & clear ri floor area. ~ D F T D r S De th E De th Phase Cade Subcode T COM .ate 09/22/2006 rom 19:00 o 19:45 u 0.75 0 0 COMPZ RIGMN RGRP T Change out HI -LOW valve for draw works drum clutch. Pull tools to flooe for Whi stock retrieval run. 19:45 21:45 2.00 0 0 COMPZ RIGMN SVRG P Change out saver sub on Top Drive. 21:45 22:30 0.75 0 0 COMPZ STK PULD P Make up Baker retrieving hook assembly. make up Retrieving hook (7.50'), 1-jnt of 4" HWDP (37.28'), 4 3/4" Bumper jar (7.73'), 4 3/4" Oil Jar (11.15'), crossover sub (2.99') and 3 stands of h brid ush i e 278.43' . 22:30 00:00 1.50 0 2,600 COMPZ STK TRIP P Trip in hole with retrieving assembly from surface to 2600' MD. Observe rc er hole fill. 09/23/2006 00:00 02:15 2.25 2,600 5,052 COMPZ STK TRIP P Continue TIH with BOT whipstock retrieving tool from 2600 - 5052'. UP WT = 140K, SO WT = 100K. Observed ro er hole fill on TIH. 02:15 05:00 2.75 5,052 5,052 COMPZ STK CIRC P Locate wash port in tool joint to the slot in whipstock. Wash slot with pumps @ 5 BPM - 1650 PSI. Continue to wash & attempt to engage slot with hook. repeat attempts to engage working string in 1/4 turn increments. Wash slot numerous times to observe hooking Whiopstock pulling 50K over allowing jars to bleed. Slack off and re-cock jars, pulling to 75K over to fire jars and observe assembly free with 8K added wei ht or dra . 05:00 05:15 0.25 5,052 4,960 COMPZ STK OWFF P Pull 1 stand slow observing fluid falling in well bore, and rack back 1 stand. Make To Drive connection. 05:15 06:00 0.75 4,960 4,960 COMPZ STK TRIP P Circulate bottoms up at 5.5 BPM - 1000 PSI as per BOT rep. Monitor well - static. Crew Chan e 06:00 06:30 0.50 4,960 4,960 COMPZ STK CIRC P Pump dry job, blow down Top Drive & lines. 06:30 10:00 3.50 4,960 337 COMPZ STK TRIP P POOH with Whipstock Retrieving assembly and whipstock from 4960' - 337'. Observed proper hole fill. No swabbin . 10:00 12:00 2.00 337 0 COMPZ STK PULD P Brekaout & lay down Fishing BHA. Lay down Retrieving hook (7.50'), 1-jnf of 4" HWDP (37.28'), 4 3/4" Bumper jar (7.73'), 4 3/4" Oil Jar (11.15'), crossover sub (2.99') and rack back 3 stands of hybrid push pipe (278.43'). Continue breakout & lay down Whipstock assembly with jewelry and s ace out i e. 12:00 12:30 0.50 0 0 COMPZ STK PULD P Continue POOH breakout & lay down Whipstock assembly with jewelry and space out pipe. Observed seal in good shape on seal assembly. Whipstock slide was in ood sha e. _ _ Page 50 of 69 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/23/2006 12:30 13:00 0.50 0 0 COMPZ STK PULD P Clean & Clear Rig Floor area and send tools out. 13:00 13:15 0.25 0 0 COMPZ CASIN( RURD P Rig up to run Hook Hanger assembly. Rig up Tongs and elevators. Pull e ui ment to ri floor. 13:15 13:30 0.25 0 0 COMPZ CASIN( SFTY P Held PJSM with crew, GBR, BOT & Sperry Sun reps. Discuss safety issues and procedure for making up Hook Han er assembl . 13:30 15:00 1.50 0 259 COMPZ CASIN( PUTB P Make up Hook hanger asembly. make up 7 5/8" x 4 1/2" Baker Model B-1 HH for LEM (16.71', 6.12'), 4 1/2" pup (3.85'), 4 1/2" Blank jnt (39.86'), 4 1/2" pup (5.75'), baker Payzone External Casing Packer (13.06'), 4 1/2" Pup (3.06'), 4 1/2" Pup (3.80'), 2 - jnts Slotted liner (86.68'), 4 1/2" Crossover jnt (42.71'), and 4 1/2" Bent joint 28.25' . I otal BHA = 258.93' 15:00 15:30 0.50 259 259 COMPZ CASIN( PUTB P make up Sperry Sun MWD Slim Hole assembly and orient MWD to Hook han er hook. 15:30 16:15 0.75 259 259 COMPZ CASIN( PUTB P Rig down all casing running equipment. Clean & clear rig floor area of OBM. RU to TIH with DP. 16:15 17:30 1.25 259 2,300 COMPZ CASIN( RUNL P Trip in hole with Hook hanger assembl from 259' - 2300'. 17:30 17:45 0.25 2,300 2,300 COMPZ CASIN( RUNL P Perform Shallow pulse test on MWD tools. Good test. 17:45 18:00 0.25 2,300 2,438 COMPZ CASIN( RUNL P Continue TIH with B lateral Hook Haanger assembly from 350 - 2438'. Crew Chan e 18:00 20:30 2.50 2,438 5,047 COMPZ CASIN( RUNL P Continue TIH with B Lateral Hook Han er Assembl from 2438' - 5047'. 20:30 21:45 1.25 5,047 5,296 COMPZ CASIN( RUNL P Attempt to run Shoe through window and observed tagging up on the A Lateral Crossover @ 5200'. Repeat attempts 4 times rotating string 1/4 RH turns to finally observe shoe into open hole. UP WT = 170K, SO WT = 140K. Page 51 of 69 Time Lo s Date From To Dur S De th E De th Phase Code Subcode T COM Page 52 of 69 09/23/2006 21:45 22:45 1.00 5,296 5,296 COMPZ CASIN( OTHR P Pick up single DP. Continue RIH to 15' above Window. Pump to orient Hook to 26 Deg left. Slack off, observe Hook engaged window and MWD indicated set down @ 9 Deg Right. Pulf up to orient 180 Degrees out, and slack off to tag Crossover in B Lat Setting Sleeve on depth @ 5303' MD. Pull back up above window, and re-orient Hook to 23 Deg, Left. Slack off observing Hook engaged window once again, and corrected MWD toolface indicated 12 Deg right on the final set down w/ 30K set down on Hook. Pumps @ 117 GPM - 1000 PSI. Found Bottom of window and hooked hanger @ 5062.87' MD (2.87' low). Drop 29/32" ball down drill string and CiiBSe Yvit~i pu~i~ps @ 2.5 BPM - 1000 PSI until observed ball landed. 22:45 00:00 1.25 5,296 5,296 COMPZ CASIN( OTHR P With ball seated, pressure to 2800 PSI, to release setting tool and inflate ECP @ 5118.45' MD. Allow pressure to bleed to 2000 PSI. Hold 10 Minutes. Pressure to 2800 PSI observing 1.2 strokes or .14 BBIs to inflate as per BOT rep. Mule shoe @ 5296.01' MD = 7' from crossover. 09/24/2006 00:00 00:45 0.75 5,060 5,060 COMPZ CASIN( RUNL P Bleed all pressures. Rack back 1 stand, and lay down single joint. Pump Dry Job. Momitor well -static. Blow down To drive & lines. 00:45 03:15 2.50 5,060 90 COMPZ CASIN( RUNL P POOH with setting tools from 5060' - surface. Observe ro er hole fill. 03:15 04:15 1.00 90 0 COMPZ CASIN( RUNL P Breakout & lay down Running & setting tools for Hook Hanger assmy. La down Slim hole MWD assembl . 04:15 05:00 0.75 0 0 COMPZ CASIN( OTHR P Clean & clear rig floor area. Held PJSM with crew. Discuss Safety issues and procedure for making up B lateral LEM tools. 05:00 06:00 1.00 0 369 COMPZ CASIN( RUNL P MU 4 1/2" Bent joint (43.25') with Seals Assembly (3.25'). Run 2 joints of 4 1/2" 12.6 L80 IBT TBG (62.17'), Camco DB-6 Nipple with 3.563" ID profile (1.55'), Pup jnt (9.80'), LEM assembly (35.17'),Pup Jnt (3.83'), XO Bushing (1.44'), 109-47 Casing Seal Bore receptacle (19.69'), 7 5/8" ZXP Liner Top PKR (19.08') and running & setting tools with XO.. Total BHA = 369.05' Crew Chan e 06:00 07:00 1.00 369 369 COMPZ CASIN( RUNL P Continue MU remaining LEM assembly. rig down casing running tools. Clean & clear rig floor of OBM & tools. Ti I r` ~__.._ T_ n.._ e n....+h ~ n,,.,+t, oti.,~„ r`.,.-~o Cuhrnrio T ('(1M I vats 09/24/2006 i ivn~ 07:00 iv 12:00 vui 5.00 v. ~.. 369 5,191 COMPZ CASIN( RUNL P - TIH with LEM runing assembly 25-30 ft/minute as per BOT rep from 369' - 5128'. Make Top Drive connection, observe seals going through B lateral Hook Hanger with 20k drag, latching up on depth as planned with seals @ 5191.65' MD. Top of ZXP PKR at 4837.00' MD. 12:00 13:00 1.00 5,191 4,837 COMPZ CASIN( RUNL P Drop 1 3/4" ball, allowing to fall chasing it with pumps @ 2.5 BPM - 250 PSI. Observed ball seated. pressuring to 4000 PSI to release setting tool. Pick up to verify free movement, and Close annular bag. Pressure down annulus to 1000 PSI for 10 Minutes. Good test. All pressures and tests recorded on chart. 13:00 13:15 0.25 4,837 4,800 I COMPZ CASIN( RUNL P Pull running & setting tool out of packer top, and rig down all pressure test a ui ment. 13:15 14:00 0.75 4,800 4,800 COMPZ CASIN( CIRC P Circulate bottoms up with pumps at 7 BPM - 1200 PSI. Monitor well -static. Pum d 'ob. 14:00 14:15 0.25 4,800 4,800 COMPZ CASIN( OTHR P Blow down Top drive and lines. Prep ri floor for POOH. 14:15 16:15 2.00 4,800 0 COMPZ CASIN( RUNL P POOH from 4800' to surface with running & setting tools. Observe proper hole fill. 16:15 17:00 0.75 0 0 COMPZ CASIN( RUNL P Breakout, inspect and lay down running & setting tools as per BOT re 17:00 17:15 0.25 0 0 PROD3 STK PULD P Clear & clean floor area from OBM. Lay down tools. Pull all tools to floor for whi stock run. 17:15 18:00 0.75 0 0 PROD3 STK PULD P Held brief PJSM. Discuss picking up whipstock assembly with seals & s ace out i e. Crew Chan e 18:00 19:30 1.50 0 497 PROD3 STK PULD P Mu Whipstock assembly. Pick up Seals with No-Go (4.21'), 4 3/4" Unloader sub (5.19'), 3 1/2" pup joint (11.85'), 2 -joints of 3 1/2" drill pipe (62.30'), 4 3/4" Double pin blanking sub (1.02'), 7 5/8" Bottom Trip Anchor (3.23'0, 4 3/4" Shear Disconnect (2.63'), 4 5/8" Drain sub (1.03'), 4 11/16" Debris barrier sub (1.88'), 7 5/8" Whipstock slide (15.45'), MU 6.156" Starting Mill (1.10'), 6 5/16" Lower mill (5.5'), 6 3/4" Upper mill (5.84'), 1 joint of 3 1/2" HWDP 29.78' . 19:30 20:30 1.00 497 497 PROD3 STK PULD P Make up 4 3/4" Float sub (2.35'), MWD assembly (56.32') and orient MWD to Whi stock face. 20:30 21:00 0.50 497 497 PROD3 STK PULD P Plug in and upload MWD assembly. Page 53 of 69 I .. n n_._a~, r_ n,...ai., n~.,..,,. r.,.~., G,h.-r..1.~ T ('(lAA I ua~c 09/24/2006 ~ iwu 21:00 i v 21:30 vu. 0.50 v. ~+ 497 497 PRODS STK -- PULD P -- Continue make up 4 3/4" Bumper jar (7.73'), Crossover sub (2.99'), and 3 stands of 4" Hybrid push pipe 278.43' .Total BHA = 496.54'. 21:30 21:45 0.25 497 497 PRODS STK TRIP P Run 1 stand of drill pipe & perform shallow pulse test on MWD. Good test with um s 300 GPM-1000 PSI. 21:45 22:15 0.50 497 620 PRODS STK TRIP P Pick up 2 stands of Hybrid push pipe. Blow down Top drive & lines. Held PJSM with crew & WWT rep. Discuss saftey issues and procedure for moving Su er Sliders on each 'oint of DP. 22:15 00:00 1.75 620 1,433 PRODS STK TRIP P TIH with 7 5/8" Whipstock assembly, 2 minutes per stand as per BOT rep from 496' - 1433' MD. iJiove each super slider up 1 ft from last position to prevent wear on DP. Observe proper hole fill on TIH. 09/25/2006 00:00 04:00 4.00 1,433 4,516 PROD2 F15H TRiP P Continue TIH with 7 518" irVhipstock assembly, 2 minutes per stand as per BOT rep from 1433' - 4516 MD. Move each super slider up 1 ft from last position to prevent wear on DP. Observe ro er hole fill on TIH. 04:00 04:45 0.75 4,516 4,556 PROD2 FISH OTHR P Perform MAD PASS as per geoligist from 4516' - 4556' Bit depth with pumps at 300 GPM's - 2000 PSI. Observed Lo at 2' Dee from Ian. 04:45 05:30 0.75 4,556 4,837 PROD2 FISH TRIP P Continue TIH with 7 5/8" Whipstock assembly, 2 minutes per stand as per BOT rep from 4556' - 4837' MD. Observe ro er hole fill on TIH. 05:30 06:00 0.50 4,837 4,837 PROD2 FISH OTHR P Make Top drive Connection. Pumps at 300 GPM's - 2100 PSI. Orient Whipstock face @ 13 Deg Left of High Side as per BOT rep, and Sperry Sun DD. Observe seal going into liner top at 4837'. Set down to set trip anchor @ 12K, and pick up to verify set with 10K overpull. Set down 35K to shear bolt. Pick up to neutral position and rotate drill string free with 5K torque. Whipstock top = 4730.5' MD. D Sand top = 4730' as per Geologist. Crew Chan e 06:00 11:15 5.25 4,730 4,771 PRODS FISH MILL P Mill window from 4730' - 4743' in 3.75 HRS, Continue to mill open hole to 4771' in 1.6 HRS. AVG ROP = 3.47 ~~ ~,~ ~.. ft/hr in the window area. Gauged open hole = 16' below window. Pumps @ 300 GPM's - 1900 PSI. UP WT = 143K, SO WT = 113K, ROT WT = 127K. 100 RPM's with 2-8K torque. WOB = 2-5K. Pump 40 BBL sweep at bottom of window. Page 54 of 69 Time Lo s Date From Ta Dur S De th E De th Phase Code Subcode T GOM I rage 55 of S9 09/25/2006 11:15 12:15 1.00 4,771 4,771 PROD3 FISH MILL P Pump 40 BBL Hi Viscweighted sweep at 4771' MD, while working mills through window area until cleaned up. Work window without pumps, window clean in and out. 12:15 13:00 0.75 4,771 4,771 PROD3 FISH MILL P Monitor well -static. Pump dry job. Blow down To Drive & lines. 13:00 14:45 1.75 4,771 496 PROD3 FISH TRIP P POOH from 4730' - 390'. Observe proper hole fill. SIMOPS: Test Choke manifold & floor valves for scheduled BOP test while POOH. All tests recorded on chart. 14:45 16:30 1.75 496 0 PROD3 FISH PULD P Stand back 3 -stands of Hybrid push pipe (278.43'). Breakout & lay down Milling BHA. Lay down 6.156" Starting Mill (1.10'), 6 5/16" Lower mill (5.5'), 6 3/4" Upper mill (5.84'), 1 joint of 3 1/2" HWDP (29.78'), 4 3/4" Float sub (2.35'). Plug in and download MWD assembly. Rack Back MWD assembly (56.32') in derrick, Lay down 4 3/4" Bumper jar (7.73'), Crossover sub (2.99'). Inspect & gauge upper mill to full au e of 6 3/4". 16:30 18:00 1.50 0 0 PROD3 FISH OTHR P Make up BOP Stack washing tool. Flush BOP stack while functioning HCR valves and manuals, Functioned all rams, & annular bag. Blow down all lines. Lay down stack washing assembl .Crew Chan e 18:00 21:45 3.75 0 0 PROD3 WELCT BOPE P Pull Wear Bushing. Rig up to complete scheduled BOP test. Install testjoint, test plug & test BOP's & Top Drive valves. Perform Accumulator test. First 200 PSI = 50 secs, full charge = 3 min-20 sec. AVG for 5 Nitrogen bottles pressure = 2950 PSI. Rig down all test e ui ment. 21:45 22:00 0.25 0 0 PROD3 DRILL PULD P Clean & clear floor area. Send tools out, and pull tools to floor for next BHA. 22:00 22:15 0.25 0 0 PROD3 DRILL OTHR P Blow down Top Drive and all lines. Line up Choke manifold valves, and Stack valves. 22:15 22:45 0.50 0 0 PROD3 DRILL SFTY P Held PJSM with new crew, Sperry Sun DD &MWD reps. Discuss safety issues and procedure for making up BHA #12, 6 3/4" Geo-pilot drilling assembl . 22:45 00:00 1.25 0 0 PROD3 DRILL PULD P Make up 6 3/4" Drilling assembly. Make up 6 3/4" Security PDC FMF 36142 bit (1.30') with 3x21 jets for a TFA of 1.015 sq. in., 5200 Seies Geo-Pilot Assembly (16.18'), 4 3/4" Non MAg Geo Pilot Flex collar 11.55' . Time UCSIG 09/26/2006 I IVIJ I 00:00 I v 01:30 vul 1.50 v. vc 30 87 PROD3 DRILL ~ PULD P - - Continue make up 4 3/4" Directional HOC (8.56'), 5 1/4" Smart Stabilizer (3.59'), 4 3/4" Gamma/Res (24.51'), 4 3/4" PWD (10.79'), 4 3/4" TM HOC 10.61' .Chan e out Pulsar & Float. 01:30 02:00 0.50 87 87 PROD3 DRILL PULD P Plug in and download MWD assembly. 02:00 03:00 1.00 87 372 PROD3 DRILL PULD P Continue make up 4 3/4" Welded blade Stabilizer (4.62'), 3 -juts Non Mag Flex Drill Collars (93.28'), Crossover (2.99'), 1 - jnt of 4" HWDP (30.67'), 4 3/4" Dailey Hyd Combo Drilling jars (28.82'), and 4 - jnts of 4" HWDP 12275' .Total BHA = 372.57. 03:00 03:15 0.25 372 465 PROD3 DRILL OTHR P RIH with 1 stand of DP. Perform Shallow pulse test & break in of Geo-Pilot. 03:15 05:15 2.00 465 4,683 PROD3 DRILL TRIP P TIH with BHA #12, 6 3/4" Geo-Pilot Drilling assembly from 465' - 4683' Fill drill string every 25 stands. Observe ro er hole fill. 05:15 06:00 0.75 4,683 4,683 PROD3 RIGMN SVRG P PJSM with crew. Discuss safety issues and procedure for Slip & Cut. Slip & Cut drilling line. Inspect & service Top Drive. Inspect Brakes on draw works. 06:00 07:45 1.75 4,683 4,683 PROD3 RIGMN SVRG P PJSM, then continue to cut and slip 102' of 1-3/8" drillin line. 07:45 08:15 0.50 4,683 4,683 PROD3 RIGMN SVRG P Service top drive. 08:15 08:30 0.25 4,683 4,770 PROD3 DRILL TRIP P Trip in hole f/ 4683' to 4770' with out pumps on or rotating thru window. Top of window @ 4730'. Bottom of window 4743'. 08:30 12:00 3.50 4,770 5,177 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 4770' to 5177' (407') (3566' TVD) Bit hours= 2.11, Jar (#140-01019) hours= 2.11, ART= 2.11 hrs, WO6= 4-12k, 40-110 rpm, 310-282 gpm @ 2030-1860 psi on bottom and 2000-1800 psi off bottom. Torque = 3-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.01- 9.9 ppg. Avg gas 45 units. P/U = 145-150k, S/O = 110-105k, Rot= 120-125k w/ um s off. 12:00 15:30 3.50 5,177 5,620 PROD3 DRILL DDRL P Driiling 6-3/4" production D lateral f/ 5177' to 5620' (443') (3539' TVD) Bit hours= 5.0, Jar (#140-01019) hours= 5.0, ART= 2.89 hrs, WOB= 4-12k, 110- 130 rpm, 282-345 gpm @ 1860-2410 psi on bottom and 1800-2400 psi off bottom. Torque = 4-5k ft-Ibs on botttom and 4-6k ft-Ibs off bottom. ECD= 10.31-10.04 ppg. Avg gas 55 units. P/U = 150k, S/O = 105-100k, Rot= 120k w/ um s off. Page S6 of 69 Time I .. ~ n__,~, c n,...,L. nti,.,.,. r,.,a., G~h.-~,rJo T (`(lAA I va~C 09/26/2006 i ivni 15:30 ~ ~ 17:30 vu~ 2.00 .~. ~-... 5,620 5,805 PROD3 DRILL DDRL P - Drilling 6-3/4" production D lateral f/ 5620' to 5805' (185') (3537' TVD) Bit hours= 6.01, Jar (#140-01019} hours= 6.01, ART= 1.01 hrs, WO6= 6-10k, 130 rpm, 345-336 gpm @ 2450-2370 psi on bottom and 2400-2320 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.16-10.04 ppg. Avg gas 55 units: P/U = 152k, S/O = 100k, Rot= 120k w/ um s off. 17:30 18:00 0.50 5,805 5,613 PROD3 DRILL TRIP T POOH f/ 5805' to 5613' to sidetrack hole. Had a 17 deg dogleg in previous hole: 18:00 19:30 1.50 5,613 5,640 PROD3 DRILL DDRL T Trough hole f/ 5613' to 5640'. Pumping @ 344 gpm w/ 2500 psi. Rotate 130 r m w/ 5-6k ft Ib for ue. 19:30 20:30 1.00 5,640 5,805 PROD3 DRILL DDRL T Drilling 6-3/4" production D lateral f/ 5640' to 5805' (165') (???' TVD) Bit hours= 6.83, Jar (#140-01019) hours= 6.83, ART= .82 hrs, WO6= 6-10k, 130 rpm, 345-336 gpm @ 2450-2370 psi on bottom and 2400-2320 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.16-10.04 ppg. Avg gas 55 units. P/U = 152k, S/O = 100k, Rot= 120k w/ um s off. 20:30 00:00 3.50 5,805 6,015 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 5805' to 6015' (210') (3532' TVD) Bit hours= 9.03, Jar (#140-01019) hours= 9.03, ART= 2.2 hrs, WO6= 6-10k, 100-80 rpm, 344-340 gpm @ 2400-2530 psi on bottom and 2380-2520 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.0 ppg. Max gas 33 units. P/U = 150-152k, S/O = 102k, Rot= 120k w/ pumps off. Pumped a 10.7 ppg, 180 vis sweep while drilling @ 6006'. A 15% estimated increase in cuttings observed the shakers. Page 57 of 69 'Time Logs Date From To Dur S De th E De th Phase Code Subcode T COM Page 58 of 69 09/27/2006 00:00 06:00 6.00 6,015 6,814 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 6015' to 6814' (799') (3524' TVD) Bit hours= 13.08, Jar (#140-01019} hours= 13.08, ART= 4.05 hrs, WOB= 4-8k, 120-110 rpm, 340-330 gpm @ 2420-2660 psi on bottom and 2350-2600 psi off bottom. Torque = 6-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.0-10.37 ppg. Max gas 60 units. P/U = 155-158k, S/O = 102k, Rot= 120k w/ pumps off. Pumped a 10.7 ppg, 180 vis sweep while drilling @ 6530'. No significant increase in cuttings. A 6' Concretion ending @ 0015', then a 3' concretion was drilled @ 6181' to 6184'. 06:00 12:00 6.00 6,814 7,495 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ ti814`to 7495' (68i') (35 i 8' TVD} Bit hours= 17.38, Jar (#140-01019) hours= 17.38, ART= 4.3 hrs, WOB= 6-8k, 90-130 rpm, 305-336 gpm @ 2660-2340 psi on bottom and 2600-2280 psi off bottom. Torque = 6-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.24-10.37- ppg. AVG gas 75 units. P/U = 155-165k, S/O = 102-95k, Rot= 120k w/ pumps off. 12:00 18:00 6.00 7,495 8,395 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 7495' to 8395' (900') (3521' TVD) Bit hours= 21.32, Jar (#140-01019) hours= 21.32, ART= 3.94 hrs, WOB= 6-10k, 130 rpm, 330-347 gpm @ 2580-2880 psi on bottom and 2500-2820 psi off bottom. Torque = 6-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.38 -10.79 ppg. AVG gas 55 units. P/U = 165k, S/O = 95k, Rot= 120k w/ pumps off. Pumped a 30 bbl Hi vis (180) weighted (10.7 ppg) sweep while drilling @ 8344'. A 10-15% increase in cuttings noticed when sweep was back at shakers. A 2' concretion was drilled @ 8116' to 8118'. Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/27/2006 18:00 00:00 6.00 8,395 9,102 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 8395' to 9102' (707') (3519' TVD) Bit hours= 26.04, Jar (#140-01019) hours= 26.04, ART= 4.72 hrs, WO6= 8-10k, 130 rpm, 340-348 gpm @ 2840-3200 psi on bottom and 2790-3170 psi off bottom. Torque = 6-8k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.79-10.93 ppg. AVG gas 55 units. P/U = 165-167k, S/O = 95-92k, Rot= 95-125k w/ pumps off. Pumped a 30 bbl Hi vis (180) weighted (10.7 ppg) sweep while drilling @ 8999'. A 15% increase in cuttings noticed when sweep was back at shakers. A 8' Concretion was drilled f/ 8712' to 8720', then a 18' Concretion was drilled f/ 8721' to 8739', +hen a 12' C^vnCr°~}inn was drilled f/ 8991' to 9003'. 09/28/2006 00:00 03:30 3.50 9,102 9,490 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 9102' to 9490' (388') (3524.28' TVD) Bit hours= 28.54, Jar (#140-01019) hours= 28.54, ART= 2.5 hrs, WOB= 6-10k, 130 rpm, 340-348 gpm @ 3150-3250 psi on bottom and 3050-3170 psi off bottom. Torque = 7-8k ft-Ibs on botttom and 6-7k ft-Ibs off bottom. ECD= 10.8-11.54 ppg. Max gas 183 units. P/U = 165-170k, S/O = 92-88k, Rot= 125-120k w/ pumps off. Pumped a 30 bbl Hi vis (200) weighted (10.8 ppg) sweep while drilling @ 9400' (3523' TVD). An approximate 25% increase in cuttings noticed when sweep was back at shakers. A 3' Concretion was drilled f/ 9176' to 9179', then a 11' Concretion was drilled f/ 9293' to 9304'. Page 59 of 69 Time Lo s Date From To Dur S. D E. De th Phase Code Subcode T C 09/28/2006 03:30 04:45 1.25 9,490 9,599 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 9490' to 9599' (109') (3520' TVD) Bit hours= 29.12, Jar (#140-01019) hours= 29.12, ART= .58 hrs, WO6= 6-10k, 130 rpm, 340-348 gpm @ 3150-3250 psi on bottom and 3050-3170 psi off bottom. Torque = 7-8k ft-Ibs on botttom and 6-7k ft-Ibs off bottom. ECD= 10.8-11.54 ppg. Max gas 183 units. P/U = 165-170k, S/O = 92-88k, Rot= 125-120k w/ pumps off. A 4' concretion was drilled f/ 9555' to 9559'. When the Concretion @ 9555' was drilled, it caused an 11 deg dogleg in the well (9 deg/100' build and 5 deg turn ri ht . 04:45 05:00 0.25 9,599 9,466 PROD3 DRILL TRIP T Survey check shot @ 9564'. POOH f/ 9599' to 9466' for sidetrack because of an 11.01 deg dogleg in hole (9 deg per hundred build and 5 de turn ri ht . 05:00 06:30 1.50 9,466 9,490 PROD3 DRILL DDRL T Trough hole f/ 9466' to 9490'. Pumping 340 gpm w/ 3100 psi. Rotating 130 r m w! 6500 ft Ib for ue. 06:30 08:30 2.00 9,490 9,599 PROD3 DRILL DDRL T Drilling 6-3/4" production D lateral f/ 9490' to 9599' (109') (3528' TVD) Bit hours= 30.98, Jar (#140-01019) hours= 30.98, ART= 1.86 hrs, WOB= 6-8k, 110 rpm, 340 gpm @ 3200 psi on bottom and 3120 psi off bottom. Torque = 7-8k ft-Ibs on botttom and 6-7k ft-Ibs off bottom. ECD= 11.33 ppg. Max gas 183 units. P/U = 170k, S/O = 85k, Rot= 120k w/ um s off. 08:30 12:00 3.50 9,599 10,076 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 9599' to 10076' (477') (3530' TVD) Bit hours= 33.46, Jar (#140-01019) hours= 33.46, ART= 2.48 hrs, WOB= 4-8k, 130 rpm, 340-348 gpm @ 3330-3480 psi on bottom and 3280-3400 psi off bottom. Torque = 7-9k ft-Ibs on botttom and 6-7k ft-Ibs off bottom. ECD= 10.43-10.96 ppg. Avg gas 60 units. P/U = 170-175k, S/O = 85-80k, Rot= 120-118k w/ um s off. Page 80 of 69 Time Lo s Date From To Dur S De th E De th Phase Code Subcode T COM I Page 61 of 69 09/28/2006 12:00 18:00 6.00 10,076 10,822 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 10076' to 10822' (746') (3516' TVD) Bit hours= 37.77, Jar (#140-01019) hours= 37.77, ART= 4.31 hrs, WOB= 4-10k, 80-130 rpm, 293-345 gpm @ 2690-3670 psi on bottom and 2600-3560 psi off bottom. Torque = 7-9k ft-Ibs on botttom and 7k ft-Ibs off bottom. ECD= 10.6-11.2 ppg. Avg gas 75 units. P/U = 175-180k, S/O = 80-75k, Rot= 120-118k w/ pumps off. Pumped a 20 bbl Hi Weight, Hi vis sweep while drilling @ 10645'. Slight increase in cuttin s noted shakers. 18:00 00:00 6.00 10,822 11,698 PROD3 DRILL DDRL P 09/29/2006 00:00 03:00 3.00 11,698 12,095 PROD3 DRILL DDRL P Drilling 6-3/4" production Dlateral f/ 11698' to 12095' (397') (3506' TVD) Bit hours= 42.74, Jar (#140-^v 1019) hours= 42.74, ART= 1.63 hrs, WOB= 8-12k, 90 rpm, 280-290 gpm @ 2640-2900 psi on bottom and 2620-2590 psi off bottom. Torque = 9-10k ft-Ibs on botttom and 8-9k ft-Ibs off bottom. ECD= 11.1-11.50 ppg. Max gas 230 units. P/U = 195-198k, S/O = 75k, Rot= 120k w/ pumps off. Pumped a 20 bbl Hi Weight (10.8 ppg), Hi vis (200) sweep while drilling 12050'. 03:00 04:45 1.75 12,095 11,741 PROD3 DRILL CIRC P Pump 20 bbls hi vis (200), hi wt (10.8 ppg) to inside casing while roating 130 rpm w/ 9k ft Ib torque. Pumping 337 gpm w/ 3700 psi. Recip pipe f/ 12095' to 12000' until sweep inside of casing, then continue backreaming to 11741', till sweep out of hole. Circ total of 712 bbls. 04:45 05:30 0.75 11,741 12,095 PROD3 DRILL REAM P Ream from 11741' back to bottom @ 12095'. No down weight without rotation. Pump 280 gpm w/ 2575 psi. Rotate 100 rpm w/ 8k ft Ib torque. ECD's 11.12 ppg. Pumped a total of 149 bbls while reaming back to bottom. 05:30 07:45 2.25 12,095 10,650 PROD3 DRILL TRIP P POOH L/D single 4" dp, continue POOH 15 stands to 10650', hole taking proper displacement. No problems. Record PU and SO wt's eve 5 stands. 07:45 08:00 0.25 10,650 10,650 PROD3 DRILL OWFF P Monitor well. Clean rig floor. Hole takin a small amount of fluid. 08:00 08:15 0.25 10,650 10,650 PROD3 DRILL CIRC P Pump dry job. 08:15 09:15 1.00 10,650 10,200 PROD3 DRILL TRIP P POOH f/ 10650' to 10200'. Tight spot 10200'. Work i e. ~ r. r.,.... -r., n,.- c n,...+h C nr,..+h DI-~o ~r,rio Ciihrnrla T (~CIAA ~ vaic 09/29/2006 ivni 09:15 10:30 ~w 1.25 10,200 9,654 PROD3 DRILL -- - REAM P - - Backream out of hole f/ 10200' to 9654'. Pumping 340 gpm w/ 3320 psi, rotating 120 rpm w/ 7k ft Ib torque. Pulling 45 ft per min. Record PU and SO wt's eve 5 stands. 10:30 12:00 1.50 9,654 8,560 PROD3 DRILL REAM P Backream out of hole every other stand f/ 9654' to 8560'. Pumping 340 gpm w/ 3320 psi, rotating 120 rpm w/ 7k ft Ib torque. Pulling 45 ft per min. Record PU and SO wt's every 5 stands. 12:00 16:30 4.50 8,560 4,965 PROD3 DRILL REAM P Backream out of hole every other stand f/ 8560' to 4965'. Pumping 340 gpm. ~n,/ 3320 psi, rotating 120 rpm w/ 7k ft Ib torque. Pulling 45 ft per min. Record PU and SO wt's every 5 stands. 16:30 16:45 0.25 4,965 4,683 PROD3 DRILL TRIP P Pull 3 stands f/ 4965' to 4683'. No pumping or rotation while puiiing these stands throw h window. 16:45 17:00 0.25 4,683 4,683 PROD3 DRILL OWFF P Monitor well. Static. 17:00 18:00 1.00 4,683 4,683 PROD3 DRILL CIRC P Pump 30 bbl hi vis (200), hi wt (10.8 ppg) sweep and circulate 3 bottom's up (4250 strokes/ 427 bbls). Pumped @ 345 gpm w/ 2750 psi. Rotate 120 rpm w/ 4-5 k ft/Ib torque. Observed hole losses of 8b h. 18:00 19:15 1.25 4,683 4,683 PROD3 RIGMN SVRG P Service rig and top drive. Crown and blocks serviced. Measure windwall pin ockets for wall b derrick board. 19:15 23:45 4.50 4,683 10,309 PROD3 DRILL TRIP P Trip in hole f/ 4683' to 10309'. Record PU and SO wt's every 5 stands. Fill i e after 25 stands. 23:45 00:00 0.25 10,309 10,402 PROD3 DRILL REAM P Start reaming in the hole f/ 10309'. No Down weight. Ream to 10402'. Pumping 85 gpm w/ 600 psi. Rotate 50 rpm w/ 7-8k ft Ib torque. Running speed 20-30 ft/min. Record PU and SO wt's eve 5 stands. 09/30/2006 00:00 04:00 4.00 10,402 12,095 PROD3 DRILL REAM. P Continue reaming in the hole f/ 10402' to 12095'. No Down weight. Ream to 10402'. Pumping 85 gpm w/ 600 psi. Rotate 50 rpm w/ 7-8k ft Ib torque. Running speed 20-30 ft/min. Record PU and SO wt's eve 5 stands. 04:00 05:30 1.50 12,095 12,095 PROD3 DRILL CIRC P Pump 23 bbl Hi vis (140), hi wt (10.8 ppg) sweep. Circ total of 7250 strokes (725 bbls). Reid PJSM w/truck drivers and crew prior to displacement to SFOBM. Pump @ 340 gpm w/ 4000 si. ECD's 12.1. 05:30 05:45 0.25 12,095 12,095 PROD3 DRILL OWFF P Monitor well. OK. Take SPR's w/ 8.8 ppg OBM in hole @ 12095' (3501' TVD . Page 62 of 69 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/30/2006 05:45 06:45 1.00 12,095 12,095 PROD3 DRILL CIRC P Displace "D" lateral open hole from 8.8 ppb OBM to 8.7 ppg SFOBM. Pump 340 gpm w/ 3800-3600 psi. Rotate 130 rpm w/ 7-9k ft Ib's torque. Pumped 345 bbls SFOBM, follow w/ 24 bbls dry job, chase w/ 6 bbls OBM. 06:45 07:00 0.25 12,095 12,065 PROD3 DRILL PULD P Break off single 4" HWDP. UD jt. Drop 2.32" rabbit w/ wireline 100' lus. 07:00 10:15 3.25 12,065 4,700 PROD3 DRILL TRIP P POOH on elevators f/ 12065' to 4700' to run 4-1/2" PLOP and Drop liner. Record PU and SO wt's every 5 stands in o en hole. Above window. 10:15 10:30 0.25 4,700 4,700 PROD3 DRILL OWFF P Monitor well. Static. 10:30 12:15 1.75 4,700 372 PROD3 DRILL TRIP P Continue POOH f/ 4700' to BHA @ 372'. Record PU and SO wt's every 10 stands in cased hole. 12:15 14:00 1.75 372 92 I PROD3 DRILL PULD P UD HWDP, jars and flex collars to i e shed. 14:00 14:30 0.50 92 92 PROD3 DRILL OTHR P Sperry Sun download MWD tools. Clean and clear ri floor. 14:30 15:30 1.00 92 0 PROD3 DRILL PULD P UD MWD tools, break bit. L/D Sperry Sun GeoPilot. 15:30 16:15 0.75 0 0 COMPZ CASIN( RURD P RU casing running tools while laying down subs f/ BHA # 12. 16:15 16:30 0.25 0 0 COMPZ CASIN( SFTY P PJSM on running 4-1/2" Plop and drop liner f/ "D" lateral 16:30 18:00 1.50 0 1,285 COMPZ CASIN( RNCS P Running 4-1/2" Plop and drop slotted and blank liner f/ "D" lateral to 1285'. Record PU and SO wt's every 20 jts in casin . 18:00 23:00 5.00 1,285 7,151 COMPZ CASIN( RNCS P Continue running 4-1/2" Plop and drop slotted and blank liner f/ "D" lateral f/ 1285' to 7151'. Record PU and SO wt's every 20 jts in casing, every 10 jts in open hole. With all the liner in the hole: PU wt 122k, SO wt 93k. Rot wt 105k. Rotating 25 rpm w/ 4-5k ft Ib torque, PU wt= 115k, SO wt 103k. 23:00 00:00 1.00 7,151 8,185 COMPZ CASIN( RUNL P Run 4-1/2" slotted/blank liner as a Plop and drop in the "D" lateral. Run liner on 4" DP f/ 7151' to 8185'. Run 3 stands slick, then start w/ 4" dp w/ super sliders. Record PU and SO wt's eve 5 stands in o en hole. 10/01/2006 00:00 02:30 2.50 8,185 12,081 COMPZ CASIN( RUNL P Run 4-1/2" slotted/blank liner as a Plop and drop in the "D" lateral. Run liner on 4" DP f/ 8185' to 12081'. Run 31 stands 4" dp w/ super sliders, 4 stands 4" HWDP, then 15 stands of Hybrids ((2) 5" DC's and one 4" HWDP). Record PU and SO wt's every 5 stands in o en hole. Page 63 of 69 I n„i., G~.,.,, Tn rli it C rlpn+h F rlenth Phaca ('nrle SuhcnflP. T C(~M I vac 10/01/2006 ivin 02:30 02:45 0.25 12,081 12,092 COMPZ - CASIN( - -- - OTHR P - - - Rotate liner @ 12081'. Without rotating: PU wt 215k, SO wt 93k. Rotating wt 155k. Rotate @ 25 rpm w/ 8k ft Ibs torque. While rotating: PU wt 180k, SO wt 135k. 02:45 03:00 0.25 12,092 12,092 COMPZ CASIN( OTHR P PU/MU single 4" HWDP, rotate and tag bottom @ 12095', PU and L/D single. Drop 29/32" ball. Make up top drive. 03:00 03:45 0.75 12,092 12,081 COMPZ CASIN( CIRC P Rotate and PU string to set shoe @ 12081.34'. Pump ball down @ 3bpm w/ 500 psi f/ 26 bbls, then slow to 2 bpm w/ 320 psi till ball on seat (411 strokes). Pressure to 3000 psi, to release liner, set down to 110k (30k), PU and string wt was 170k (loss of 45k liner weight). PU 10', pressure to 3875 si to blow ball seat. 03:45 04:15 0.50 4,929 4,730 COMPZ CASIN( RUNL P POOH wet 2 stands of Hybrids. Make up top drive, pull 3rd stand out. Strap stand in. 04:15 04:45 0.50 4,730 4,730 COMPZ CASIN( CIRC P Circ and rotate to clean key slot in whipstock. Pump 80 spm w/ 1525 psi. Rotate 40 rpm w/ 4k ft Ibs torque. Pump a total of 197 bbls. 8.6 ppg mud wt. 04:45 05:00 0.25 4,730 4,730 COMPZ CASIN( RUNL P Monitor well. Static. Pump dry job. 05:00 06:00 1.00 4,730 2,996 COMPZ CASIN( RUNL P Blow down top drive. POOH f/ 4730' to 2996' 06:00 08:00 2.00 2,996 0 COMPZ CASIN( RUNL P Continue POOH w/ liner running tools f/ "D" lateral. 08:00 08:30 0.50 0 0 COMPZ CASIN( OTHR P Break and UD Baker tools to pipe shed. 08:30 09:15 0.75 0 0 COMPZ CASIN( OTHR P Clear and clean rig floor. L/D casing runnin tools, subs, ets. 09:15 09:30 0.25 0 0 COMPZ FISH SFTY P PJSM on picking up Baker Whipstock retieval hook assembl . 09:30 10:00 0.50 0 59 COMPZ FISH PULD P MU BHA to retieve whipstock. MU hook to a single 3-1/2" HWDP, bumper 'ars, oil 'ars, x-o. 10:00 10:30 0.50 59 425 COMPZ FISH TRIP P PU 3 stands hybrids as part of BHA and a sin le stand of 4" su er sliders. 10:30 10:45 0.25 425 425 COMPZ RIGMN SFTY P PJSM on cutting drilling line. 10:45 12:15 1.50 425 425 COMPZ RIGMN SVRG P Slip and cut 126' of 1-3/8" drilling line. 12:15 15:00 2.75 425 4,736 COMPZ FISH TRIP P Continue RIH w/ Baker whipstock retrieval assembly. Ran 35 super slider stands, 4 stands HWDP and 8 stands H brids, then sin le HWDP. 15:00 15:30 0.50 4,736 4,736 COMPZ FISH CIRC P Break Circ @ 3bpm w/400 psi. PU wt 170k, SO wt 135k. 15:30 15:45 0.25 4,736 4,736 COMPZ FISH FISH P Found slot and hooked @ 4735.5'. Pulled 90k over to 260k. Page 64 of 69 Time. Lo s Date From To Dur S. De th E. De th Phase .Code Subcode T COM 10/01/2006 15:45 16:00 0.25 4,736 4,726 COMPZ FISH TRIP P PU and L/D single HWDP. 16:00 16:45 0.75 4,726 4,660 COMPZ FISH CIRC P Pull stand up and circ @ 4660'. Circ bottom's up @ 8 bpm w/ 2140 psi. Pum 200 bbls. 16:45 17:00 0.25 4,660 4,660 COMPZ FISH OTHR P Monitor well. Static. 17:00 17:30 0.50 4,660 4,660 COMPZ FISH CIRC P Pump 25 bbls dry job, drop 2.32" rabbit. Blow down to drive. 17:30 18:00 0.50 4,660 3,370 COMPZ FISH TRIP P POOH w/ whipstock assembly f! 4660' to 3370' 18:00 21:00 3.00 3,370 0 COMPZ FISH TRIP P POOH w/ whipstock retieval BHA and whipstock assembly. 15 bbls over calc on tri out. I 21:00 21:30 0.50 0 0 COMPZ FISH PULD P UD Baker Fishing assembly (Hooking assembl 21:30 22:30 1.00 107 0 COMPZ FISH PULD P UD Whipstock assembly: Whipstock, circ sub, anchor, debris sub, 2 jts of 3-1/2" HWDP, safety shear sub, unloader sub, 15' 3-1/2" pup, no go and seals. 22:30 23:00 0.50 0 0 COMPZ FISH PULD P Cleaning rig floor and UD Baker tools. Hole takin 6.5 b h. 23:00 23:00 0.00 0 0 COMPZ CASIN( RURD P RU casing tools to run 4-1/2" Hook Han er. 23:00 23:15 0.25 0 0 COMPZ CASINC SFTY P PJSM on PU Hook Hanger assembly f/ "D" lateral 23:15 00:00 0.75 0 30 COMPZ CASIN( PUTS P PU/MU 4-1/2" Slot/blank hook hanger assembl 10/02/2006 00:00 02:30 2.50 30 266 COMPZ CASIN( OTHR P MU Sperry Sun MWD up to Baker hook han er, orient same. 02:30 02:45 0.25 266 266 COMPZ CASIN( DHEQ P Shallow test MWD w/ 100 gpm w/ 490 si. 02:45 05:45 3.00 266 4,875 COMPZ CASIN( RUNL P RIH w/ hook hanger on 4" dp. Use 35 stands w/super sliders, 4 stands 4" HWDP, then hybrids ((2) 5" DC's w/ one 4" HWDP). Top of window is @ 4730', Bottom of window @ 4743'. Tagged up on no go (x-o bushing) in "B" lateral 4875'. 05:45 07:00 1.25 4,875 4,875 COMPZ CASIN( RUNL P On fourth attempt to exit window w/ 4-1/2" bent joint w/ mule shoe, we did exit window. Run to 4875'. 07:00 07:30 0.50 4,875 4,963 COMPZ CASIN( CIRC P Continue RIH w/ hook hanger assembly f/ 4875' to 4963'. Circulate 100 gpm w/ 890 psi. Orient hook hanger to hook window. PU wt 170k, SO wt 140k. Page &5 of 69 I n..... ~.,,.., -r,, n.., c no„++, G no..++, o+,~ro r`r,flo ciihrndc T rnnn i 10/02/2006 07:30 08:00 y 0.50 4,963 4,985 COMPZ CASIN( OTHR P Slack off and hook window, unhook, rotate 180 deg to pass through w/ hook hanger, slack off and tag no go (crossover bushing in Plop and drop assembly @ 4995'), PU above window, orient to hook window (oriented to 17 Left, when hooked went to 3 left), set down 30k on hook. PU wt 170k, SO wt 147k. 08:00 08:45 0.75 4,985 4,985 COMPZ CASIN( OTHR P Drop 29/32" ball, circ down to seat w/ 125 gpm w/ 1050 psi for 250 stokes, then to 85 gpm till on seat @ 40.46 bbls pumped. Pressure to 1450 psi, hold, continue to increase pressure to 2800 psi (opening ECP, dropping to 1570 psi. Increase pressure to 2800 psi w/ 3 strokes (.301 bbls). PU to 170k. 08:45 09:00 0.25 ",718 ^ a58 ~ COnAP7 rnSlr.lr RI NL p DOOR and stand back a stand.Pump d 'ob. Blow down to drive. 09:00 11:45 2.75 4,668 0 COMPZ CASIN( RUNL P POOH w/ Baker Hook Hanger running tools. 11:45 13:15 1.50 0 0 COMPZ CASIN( OTHR P Break and UD Baker running tools. 13:15 14:00 0.75 0 0 COMPZ CASIN( OTHR P Clean and clear rig floor while laying down Baker tools and subs. 14:00 14:30 0.50 0 0 COMPZ CASIN( SFTY P PJSM on running 4-1/2" LEM for "D" lateral. 14:30 16:00 1.50 0 204 COMPZ CASIN( PUTB P PU/MU LEM assembly f/ "D" lateral to 204'. 16:00 18:00 2.00 204 3,600 COMPZ CASIN( RUNL P RIH w/ LEM f/ 204' to 3600' on 4" drill strin . 18:00 19:15 1.25 3,600 4,866 COMPZ CASIN( RUNL P Continue RIH w/ LEM on 4" drill string f/ 3600' to 4866'. LEM sna ed in 19:15 19:30 0.25 4,866 4,866 COMPZ CASIN( OTHR P Set down 30k, Pull to 230k and snap out. RIH and latch in w/ 30k on LEM. PU to 180k. Drop 1-3/4" ball. PU wt 192k, SO wt 125k. 19:30 19:45 0.25 4,866 4,866 COMPZ CASIN( CIRC P Circ ball to seat. Pump 3 bpm w/ 400 psi ,then to 2 bpm w/ 260 psi. Ball on seat 32.7 bbls. 19:45 20:30 0.75 4,866 4,866 COMPZ CASIN( OTHR P Pressure to 2500 psi, hold, then increase to 4000 psi to neutralize pusher tool, slack off to 115k to release HRD setting tool. Break off top drive. Test annulus to 1000 psi f/ 5 min., chart test. 20:30 20:45 0.25 4,866 4,574 COMPZ CASIN( RUNL P After LEM set and released: PU wt 170k, SO wt 140k. POOH to 4574' 20:45 21:00 0.25 4,574 4,574 COMPZ CASIN( CIRC P Pump dry job, blow down top drive. 21:00 23:15 2.25 4,574 0 COMPZ CASIN( RUNL P POOH w/ LEM running tools f/ 4574' to surface. 23:15 00:00 0.75 0 0 COMPZ CASIN( OTHR P UD Baker LEM running tools. Page 66 of 59 Time Lo s .Date From To Dur S. De E. De th Phase Code _Subcode T C 10/03/2006 00:00 00:45 0.75 0 0 COMPZ CASIN( OTHR P UD Baker LEM running tools. 00:45 01:15 0.50 0 0 COMPZ CASIN( OTHR P Clean and clear rig floor. Monitor well via tri tank and hole fill um . 01:15 01:45 0.50 0 0 COMPZ RPCOti OTHR P Pull Vetco/Gray wear bushing. Hole takin 2 b h. 01:45 02:15 0.50 0 0 COMPZ RPCOf~ RURD P PJSM, Rig up to run 4-1/2" completion, GBR casing crew and e ui ment. 02:15 02:30 0.25 0 0 COMPZ RPCOh SFTY P PJSM on running 4-1/2" 12.6 ppf L-80 IBT-mod completion. GBR casing crew, Baker completion supervisor, tour usher and ri su ervisor. 02:30 03:15 0.75 0 65 COMPZ RPCOti RCST P PU Baker 4-3/4" seal assembly, Made up 1 jt 4-1/2" 12.6 ppg L-80 IBT-mod tubing, then 4-1/2" pup on CMU did not make u correct. 03:15 04:45 1.50 65 65 COMPZ RPCOf~ PULD T Break out CMU assembly w/ pup, break a~~d UD botto~~~ pup, PU/MU another 4-1/2" 12.6 ppf L-80 IBT-mod pup which did not make up correct again. UD 1 st joint and replace w/ jt # 150 (same length 31.07'). Make up pup jt 6.17', then make up CMU. Torque tubing to 2500 ft Ib torque to middle makeup mark. Probably overtorqued collar of 1 st jt. Collar was hot. Pin end of pup jt screwed in ast make u mark. 04:45 06:00 1.25 65 600 COMPZ RPCOti RCST P Continue MU 4-1/2" completion. Checking torque and MU. 2500 ft Ib seems to be optimum torque on 4-1/2" IBT-M. Check make up mark on every connection (4-3/8" MU thread loss on 't . 06:00 09:45 3.75 600 4,713 COMPZ RPCOti RCST P Continue MU 4-1/2" completion. Run f/ 600' to 4672' (top of LEM ZXP packer (LEM Tally)). Locate @ 4683.66' (11.01' inside ZXP (LEM Tally)), Tubing detail =4686.01'. Checking torque and MU. 2500 ft Ib seems to be optimum torque on 4-1/2" IBT-M (4-3/8" thread loss). Note: Tagged 2.35' deeper by tubing tall numbers. 09:45 10:30 0.75 4,713 4,627 COMPZ RPCOh HOSO P UD 3 joints (149, 148, 147), leaving jt # 146 in hole. PU 7.80' 4-1/2" 12.6 ppf L-80 IBT-mod tubing pup drifted to 3.91 ". Rabbit Vetco Gray hanger and u to 3.885". 10:30 10:45 0.25 4,627 4,635 COMPZ RPCOf~ HOSO P MU 7.80' 4-1/2" 12.6 ppf L-80 IBT-mod tubing pup drifted to 3.91". MU jt # 147. 10:45 11:15 0.50 4,635 4,708 COMPZ RPCOti HOSO P MU Vetco Gray hanger w/ pup, then landing joint. RIH and land hanger. Install BPV, RILDS. Page 67 of 69 Time Lo s .Date From To Dur S. De E. De th Phase Code Subcode T C 10/03/2006 11:15 12:00 0.75 0 0 COMPZ DRILL OTHR P Clean and clear rig floor, laying down casing equipment, subs and Baker tools. 12:00 12:30 0.50 0 0 COMPZ DRILL RURD P RU to laydown 4" drill string f/ derrick, usin mousehole. 12:30 12:45 0.25 0 0 COMPZ DRILL SFTY P PJSM on laying down 4" drill string f/ derrick, usnin mousehole in stack. 12:45 18:00 5.25 0 0 COMPZ DRILL PULD P Lay down 4". Layed down 15 stands of hybrids ((2) 5" DC's w/ a single 4" HWDP), 4 stands 4" HWDP, then 30 stands of slick drill i e. 18:00 00:00 6.00 0 0 COMPZ DRILL PULD P Lay down 37 stands of 4" slick drill pipe. Note: 15 slick stands + 40 stands w/ su er sliders left to be !a~ ed down. 10/04/2006 00:00 08:30 8.50 0 0 COMPZ DRILL PULD P Lay down 15 stands 4" slick dp + 40 stands w/ su er sliders . 08:30 10:00 1.50 0 0 COMPZ DRILL PULD P Lay down thread protectors. Clear and Clean rig fluor. ,v"GVc i i .~9ta1IdJ 5" DP in derrick f/ off driller's side to driller's side while cleaning drip pan under rig floor. Total of 21 stands 5" dp in derrick + 2 stands 5" HWDP + stand w/ ~ars. 10:00 10:45 0.75 0 0 COMPZ DRILL PULD P UD Mousehole, subs, lifting subs, elevators, test plugs, etc. not needed on ri an more. 10:45 11:00 0.25 0 0 COMPZ DRILL OTHR P Blow down all surface equipment and um s. 11:00 15:00 4.00 0 0 COMPZ RPCOh NUND P Nipple down 13-5/8" BOPE. Cleaning its. 15:00 15:45 0.75 0 COMPZ RPCOh NUND P NU Vetco Gray tree. Install actuator on horizontal tree. 15:45 16:00 0.25 0 0 COMPZ RPCOh OTHR P Rig up to test tree. 16:00 16:15 0.25 0 0 COMPZ RPCOh DHEO P Test tree to 5000 psi. Chart test f/ 10 minutes. 16:15 16:45 0.50 0 0 COMPZ RPCOti SFTY P PJSM w/ little Red on freeze protection/ displacement to diesel. Test lines to 3000 si. 16:45 19:30 2.75 0 0 COMPZ RPCOh FRZP P Freeze protect/ displace well by pumping down 7-5/8" x 4-1/2" annulus. CMU open @ 4631'. Taking returns from tubing to pits. Monitor rates, pressures and return volume to pits. 11 bbls to fill well. 16 bbls pumped to get returns to pits. Pumped a total of 217 bbls diesel. Calc volume surface to surface is 192 bbls. Did not loose over a bbl on displacement. start @ 1 bpm w/ 200 psi, when pumping @ 2.5 bpm appeared to be losing 1/3 bbl. Pumped @ 2bpm till diesel @ CMU w/ 600 psi, then increase rate to keep about 500 si. Final rate 4 b m w/ 475 si. Page 68 of 69 Time Lo s Date From To Dur S. De E. De th Phase Code Subcode T C 10/04/2006 19:30 20:00 0.50 0 0 COMPZ RPCOti FRZP P Rig down and blow down freeze rotection a ui ment and hoses. 20:00 20:45 0.75 0 COMPZ RPCOh NUND P Cleaning pits, Remove double valve on inner annulus, install companion flange and guage. Remove fittings on Actuated valve, install guages. Tubing pressure 200 psi. 7-5/8" x 4-1/2" ann pressure= 225 psi. 10-3/4" x 7-5/8" ressure = 175 si. 20:45 00:00 3.25 0 0 COMPZ RPCOh OTHR P PU lubricator, Install BPV w/ Vetco/Gray. Secure well. Continue cleaning pits. Blow down steam to sub module. R/D mud lines, water lines and steam lines between modules. Cleaning pits, preparing to clean cellar. Tubing pressure 200 psi. 7-5/8" x 4-1/2" ann pressure= 225 psi. 10-3/4" x 7-5/8" ressure = 175 si. Page 69 of 69 ~ • 08-Nov-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well. 1J-102L2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 9,428.80' MD Window /Kickoff Survey: 4,730.00' MD (if applicable) Projected Survey: 12,095.00' 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 ~ t V ~~ ~ Signed ~ D Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ao 6-iiz • • 08-Nov-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-102L2PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 4,664.00' MD Window /Kickoff Survey: 4,730.00' MD (if applicable) Projected Survey: 5,805.00' 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 t /U ~a a f/ z~4 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~, 6 (~ -- ~ ~ ~. • • 08-Nov-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-102L2PB2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 5,585.13' MD Window /Kickoff Survey: 4,730.00' MD (if applicable) Projected Survey: 9,599.00' 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 r~ Date ~ ~~,~ ~ 4 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~ • WELL LOG TRANSMITTAL To: State of Alaska November 6, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7t" Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data: 1J-102, PB1, PB2, PB3, L1, L2, L2 PB1 & L2 PB2 AK-'VIW-4559176 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23317-00, -70, -71, -72, -60, -61, -73 & -74. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: v ~r~~-_ ~3, Boa, ~~ ~ ! ~~a, ~R3 ~_. ~ ~. - = ~° ~, Signed: RE: 1J-102 L2 PB1 (206-112) • ~ Subject: RE: 1J-142 L2 PB1 (206-112) From: "Nugent, David Arnold° <David.A.Nugent@conocophillips.com=- Date: Thu, 28 Sep 2006 07:50:16 -0800 To: Thomas Maundcr~ om nlaurldcr~~i?adrnin.state.ak.us=~ Tom: Yes. All the lost section was in the sand. David -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, September 28, 2006 7:38 AM To: Nugent, David Arnold Subject: Re: i)-102 L2 PB1 (206-112) Thanks David. Was all the lost section in the sand? Tom Maunder, PE AOGCC Nugent, David Arnold wrote, On 9/27/2006 2:55 PM: Tom: Well: 1 J-102 L2 Rig: Doyon 15 Permit #: 206-112 Date: September 26, 2006 Time: 1800 hours Last casing: 7-5/8" at 5926' Top of window for L2: 4730' MD of abandoned section: 5613' - 5805' While drilling the D sand in L2, we hit a concretion that caused us to have a 17.7 deg dogleg, so we immediately decided to back up and bypass the large dogleg. We low sided the hole and drilled past the spot that originally gave us the large dogleg with no problems. We won't case off the abandoned hole and expect it will eventually collapse. David A. Nugent Staff Drilling Engineer ConocoPhillips Alaska 907-265-6862 (office) 918-662-6886 (fax) 1 of 1 9/28/2006 7:53 AM 1J-102 L2 PB2 (206-112) Subject: 1J-102 LZ PB2 (206-112) From: "Nu`=ent, David Arnold" <David.A.Nugent cr,conocophillips.com> Date: Thu. ~~ Sep ?006 I (_):07:34 -0~~10 To: Thomas Maunder <tom maunder(r?admin.state.ak.us> Tom: Well: 1 J-102 L2 Rig: Doyon 15 Permit #: 206-112 Date: September 28, 2006 Time: 0500 hours Last casing: 7-5/8" at 5926' Top of window for L2: 4730' MD of abandoned section: 9490' - 9599' (total 109') While drilling the D sand in L2, we hit a concretion that caused us to have a 12.2 deg dogleg, so we immediately decided to back up and bypass the large dogleg. We low sided the hole and drilled past the spot that originally gave us the large dogleg with no problems. We won't case off the abandoned hole and expect it will eventually collapse. We stayed in the sand the entire time. David A. Nugent Staff Drilling Engineer ConocoPhillips Alaska 907-265-6862 (office) 918-662-6886 (fax) 1 of 1 9/28/2006 10:12 AM • FRANK H. MURKOWSKI, GOVERNOR Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 333 W. 7T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-102L2 ConocoPhillips Alaska, Inc. Permit No: 206-112 Surface Location: 2245' FSL, 2446' FEL, SEC. 35, Tl 1N, R10E, UM Bottomhole Location: 5221' FSL, 595' FEL, SEC. 11, TlON, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is for a new wellbore segment of existing well KRU 1J-102, Permit No 206-110 API No. 50-029-23317-00. Injection should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commiss>_o petroleum field inspector at (907) 659-3607 (pager). ~~ DATED this day of August, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. RECEIVED • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSfON~ Yd~-- ~UL 2 6 2006 PERMIT TO DRILL Alaska pil & Gas Cons. Commission 20 AAC 25.005 Qnrhnre,,,, 1 a. Type of Work: Drill Q Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil ^ Stratigraphic Test ^ Service Q Development Gas ^ Multiple Zone^ Single Zone Q • 1 c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-102L2 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 12188' • ND: 3509' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 2245' FSL, 2446' FEL, Sec. 35, T11 N, R10E, UM 7. Property Designation: ADL 25661 & 25662 West Sak Oil Pool Top of Productive Horizon: 1977' FSL, 541' FEL, Sec. 35, T11 N, R10E, UM 8. Land Use Permit: ALK 471 & 2177 13. Approximate Spud Date: 8/27/2006 Total Depth: 5221' FSL, 595' FEL, Sec. 11, T10N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: > 2 miles 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558761 • y- 5946057 ' Zone- 4 10. KB Elevation (Height above GL): 40' RKB feet 15. Distance to N arest Wel~w~ithDinrPo~~ ~j? 7 ~? 16. Deviated wells: Kickoff depth: 4865 • ft. Maximum Hole Angle: g3° deg 17. Maximum Anticipated Pressures in psig (see 20 aAC 25.035) Downhole: 1609 psig Surface: 1215 psig • 18. Casing Program ecif cations S Setting Depth Quantity of Cement Size i p Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 42" 20" x 34" 94# K-55 Welded 80' 40' 40' 108' - 108' 260 cf ArcticCRETE 13.5" 10.75" 45.5# L-80 BTC 2618' 40' 40' 2646' 2243' 490 sx AS Lite, 180 sx DeepCRETE 9-7/8" 7-5/8" 29.7# L-80 BTCM 5979' 40' 40' 5988' ~ 3755' 350 sx DeepCRETE 6.75" 4.5" 12.6# L-80 IBTM 7322' 4865' 3551' 12187' 3509' see above 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 ND Conductor/Structu ra I Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ~ BOP Sketch Drilling Programa 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 Pat Reilly @ 265-6048 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature \ `"~, l Phone 'ZC S (s~~c, Date 712s~06 Pre har n Al k Commission Use Only Permit to Drill Number: Z ~~ - ~ ~Z API Number: / 5o-1S~q - Z33 ~ 7 '~ (p / Permit A proval Date: g • '~-~ • ~ ~ See cover letter for other requirements Conditions of approval : If box is checked, well may not used to explore for, test, or produce Coalbedr-myethane, gas hydrates, or gas contained in shales: Q ©©~ eSc ~D~~ES t~G-S ~~~~ Samples req'd: Yes ^ No U dlog req'd: Yes ^ No [/]~ Other: ~ ~ H2S m surest Yes ^ No Di I svy req'd: Yes [~ No ^ ~`~~C~'t-CS ©~rU~\OhS'~r-GCCO~°i'j~ Ia.~,C7 a-~ PROVED BY THE COMMISSION I r DATE: ,COMMISSIONER Form 10-401 Revised 12/2005 Sub,~nit in Duplicate -z~~ o~ • Permit It -West Sak Well #1J-102 L2 Application for Permit to Drill Document Appli~or Permit to Drill, Well 1J-102 L2 Revision No.0 Saved: 24-Jul-06 Mpxirriizp WWII Vvlue Table of .Contents 1. Well Name ............................................................~.................................................... 2 Re uirements of 20 AAC 25.005 ......................:...:..... 2 2. Location Summary .............................................................................:..................... 2 Requirements of 20 AAC 25.005(c)(2) ...................................................:............................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) .......................................................................•---........................ 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ....................................................................................::............ 3 5. Procedure for Conducting Formation Integirity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) ..............e................................................................................... 3 6. Casing and Cementing Program ............................................................................ 3 Requirements of 20 AAC 25.005(c)(6) ...........................•----...........-----•------............................................ 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 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 Base) ..........................................:................................ 4 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9)..........e ....................................................................................... 5 10 .Seismic Analysis .......................................... ......................................'................. .... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11 . Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12 . Evidence of Bonding ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ..............................................•-----------..........................---......... 5 1J-102L2 PERMIT IT Page 1 of 6 Printed: 24-Jul-O6 ~~~~~ • Applic~or Permit to Drill, Well 1J-102 L2 Revision No.O Saved: 24-Jul-06 13. Proposed Drilling Program ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments ............................................................................................................. 6 Attachment 1 Directional Plan ..................................................................•-•-•--•-•--.................................. 6 Attachment 2 Drilling Hazards Summary ............................................................................................... 6 Attachment 3 Well Schematic ................................................................................................................ 6 1. Well Name Requirements of 20 AAC 25.005 (fl Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 2fJ AAC25.040(b). For awet/ with multip/e wet! branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the we!/ by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1J-102 L2. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the fo/Jowing items, except far an item already on F/e with the commission and identified in the application: (2) a plat identifying the property and the property`s owners and showing (A)the coordinates of the proposed location of the wel! at the surface, at the tap of each objective formation, and at total depth, referenced to governmenta/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 m the Nationa/Oceanic and Atmospheric Administration, (C) the proposed depth of the we!/ at the top of each objective formation and at total depth; Location at Surface 2245' FSL & 2446' FEL -Sec 35 - T11N - R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 108' AMSL Northings; 5,946,057 Eastings; 558,761 Pad Elevation 81' AMSL Location at Top of Productive Interval West Sak "D" Sand 1977ft FSL & 54Ift FEL -Sec 35 - T11N - R10E ASPZone 4 NA027Coordinates Measured De th, RKB; 4,865 Northings; 5,945,803 Eastings: 560,668 Total I/erticalDe th, RKB; 3,551 Total l/ertica/ De th SS.• 3,430 Location at Total De th 5221ft FSL & 595ft FEL -Sec 11 - T10N - R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB.' 12,188 Northings; 5,938,489 Eastings; 560,679 -Total I/ertica/ De th, RKB; 3,509 Total t/ertica/De th, SS,• 3,388 and (D) other mformatian required by 20 AAC 25.0511(6); 1J-102L2 PERMIT IT Page 2 of 6 ®~ ~ ~ ~ ~ ~ ! Printed: 24-Jul-06 Applic~or Permit to Drill, Well 1J-102 L2 Revision No.O Saved: 24-Jul-06 Requirements of 20 AAC 25.050(b) df a wet/ is to be intentionally deviated, the application far a Permit to DriJ/ (Form 10-401) must (I) inc/ude a plat, drawn to a suitable sca/e, showing the path of the proposed wel/bore, including a!/adjacent wellbares within 200 feet afany portion of the proposed wel% Please see Attachment 1: Directional Plan and (2) for a!l wells within 200 feet of the proposed wellbore (A) list the names of the operators of those we//s, to the extent that those names are known ar discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only off ected 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 Dri// must be accompanied by each of the fol%wing items, except far an item a/ready on file with the commission and identified in the app/ication: (3) a diagram and description of the blowout prevention equipment (BUFF) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as app/icab>e,~ lt~2i ~.27.oL An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well iJ~L2. Please see information on Doyon 15 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An app/ication for a Permit to Drill must be accompanied by each of the following items, except for an item already on fr/e with the commission and identified in the application: (4) information an drilling hazards, including (A) the maximum downhole pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1J -area are 0.45 psi/ft, or 8.7 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak ~~D" sand formation is 1,215 psi, calculated thusly: MPSP =(3,575 ft ND)(0.45 - 0.11 psi/ft) =1,215 psi (B) data on potential gas zones,' The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hale prob/ems such as abnorma//y geo pressured strata, lost circulation zones, and zones that have a propensity far differential sticking; Please see Attachment 2: 1J-102 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 far 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(17; The parent wellbore, iJ-102, will be completed with 7-5/8'° intermediate casing landed in the West Sak A- Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 1J-102L2 PERMIT IT Page 3 of 6 n ~ ~ ~ ~ ~ ~ ~ Printed.' 24-Jul-O6 • Appli~or Permit to Drill, Well 1J-102 L2 Revision No.O Saved: 24-Jul-06 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application far 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: (6) a complete proposed casing and cementing program as required by 2D AAC 25.03D, and a description of ant'slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program C Hole Top Btm Csg/Tbg Size Weigh Length MD/TVD MD/TVD OD in in t Ib/ft Grade Connection ft ft ft Cement Pro ram 4-1/2 6-3/4" A Sand 12.6 L-80 IBTM 8,403 5,285 / 3,638 13,688 / 3,728 Slotted- no cement Slotted Lateral (1J-102) 4-1/2 6-3/4" B Sand 12.6 L-80 IBTM 7,307 5,185/ 3,621 12,492 / 3,582 Slotted- no cement e Lateral (iJ-102 4-1/2 6-3/4" D Sand 12.6 L-80 IBTM 7,322 4,865/ 3,551 12,187 / 3,509 Slotted- no cement Slotted Lateral (1J-102 L2) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An app/ication for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25. D35, unless this requirement is waived by the commission under 2D AAC 25, D35(h)(2); No diverter system will be utilized during operations on 1J-102 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 fo/fowing items, except for an item already on fi/e wr"th the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro, Mineral Oil Base) Value Density 8.6 Plastic Viscosity Ib/100 s 15 - 25 Yield Point cP 18 - 28 HTHP Fluid loss (ml/30 min <4 0 @ 200psi & . 150° Oil /Water Ratio 70 / 30 Electrical Stability 650-900 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 1J-102L2 PERMIT lT Page4of6 Printed: 24-Jul-06 • Appli~for Permit to Drill, Well 1J-102 L2 Revision No.0 Saved: 24-J u1-06 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An app/ication for a Permit to Ori/l must be accompanied by each of the following items, except for an item already an h/e with the commission and identified in the application: (9) for an exploratory or stratigraphic test wel/, a tabulation setting out the depths of predicted abnormal/y geopressured strata as required by 20 AAC 25.033(17; 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 Dri/I must be accompanied by each of the following items, except for an item a/ready on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test we/% 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 Dri// must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (i1) fora welt drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling uess% an analysis ofseabed conditions as required by 20 AAC25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An app/ication for a Permit to Drill must be accompanied by each of the following items, except for an item already on fi/e with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the fol/owing items, except for an item already on fi/e with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the 1J-102 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 4,865' MD / 3,551' TVD, the top of the D sand. 2. Mill 6-3/4" window. POOH. 3. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of D sand lateral at 12,187' MD / 3,509' TVD, as per directional plan. 5. POOH, back reaming out of .lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4-1/2" slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POOH. 1J-102L2 PERMIT IT Page 5 of 6 n ~ ~ ~ [~ ~ ~~ Printed: 24-Jul-06 r: Appli~ for Permit to Drill, Well 1J-102 L2 Revision No.O Saved: 24-Jul-06 10. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. 11. POOH, laying down drill pipe as required. 12. PU completion as required and RIH to depth. Land tubing. Set BPV. 13. Nipple down BOPE, nipple up tree and test. Pull BPV. 14. Freeze protect well with diesel. 15. Set BPV and move rig off. 16. Rig up wire line unit. Pull BPV. 17. Set gas lift valves in mandrels. Operate well on gas lift for +/- 45 days (flowback cleanup). Shut well in. 18. Rig. up vvireline. Replace gas lift valves with blank dummy valves. Return well to injection. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Fermit to Drill mustc be accompanied by each of the fo/lowing items, except for an Item already on fife. with the commission and identified in the application: (14) a genera/ description of how the operator plans to dispose of dri/ling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposa! operation in the we/%; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids , into a permitted annulus on iJ Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 1J Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in -the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Aftachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 1J-102L2 PERMIT /T Page 6 of 6 Printed: 24-Jul-06 ConocoPhillips Alaska ConocoPhillips Alaska Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-102 -Slot 1J-102 1J-102 L2 Plan: 1J-102 L2 (wp07) Proposal Report 21 May, 2006 • Sperry- Dr~l[ing Services ORIGIN.41 _1 Project: Kuparuk River Unit CASING DETAILS Site: Kuparuk 1J Pad Well: Plan 1J-102 No MD TVD TVDss Name Size Wellbore: 1J-102 L2 1 120.00 120.00 -1 20" 20 Plan: 1J-102 L2 (wp07) 2 2645.82 2243.00 2122 10 3/4" 10-3/4 3 4865.09 3551.00 3430 7 5/8" TOW7-5/8 412187.52 3509.00 3388 41/2" 4-1/2 FORMATION TOP DETAILS -800 NoTVDPath TVDSS MDPath Fortnatlon 1 1533.00 1412 1644.52 Base Perm 2 1671.00 1550 1633.69 T3 3 1962.00 1841 2246.77 K15 -400 5 2987.0 2866 3690.24 Ugnu C 6 3230.00 3109 4065.23 Ugnu B 7 3311.00 3190 4209.74 Ugnu A 8 3417.00 3296 4430.93 K13 0 20" 9 3551.00 3430 4865.07 Wsak D ~ 0° 400 10° 800 ?p° 1200 ~o° 3600 ---- so-------- ------------------ ------------------------------------------------------------ -------- L2:TOW~4865ftMD,36li1R ------------------- ------------------------------------------------------ i r -- ------------r- L2:BOW~4877ftMD.3554ft ----- ------ ------------------------- ~ ----------------- i L2 : BHL 12188ft MD, 35098 TVD - 41/2 10 3/4" ~ ~ ~- - - - - - - - - - - - ~- - - - - - - ~-' - - - L2 : End 30' Rethole - Build ~ 6°!1008, 49078 MD, 36698 - - J - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 45° ~ i i i ~ L2 : Continue GaoSteer In 0.Sand 6127ft MD, 3li74ft ~ ~ ~~ - i i ~~ ,-'~ i i -' i ,, - - - - v - - } - - J - - - - - - r - - - - - - - - r~ / - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ` \ - - - - - - - -~ - g~ ~ , -' ~ 1J-102 L2 (wp07 - - - - 1J-102 Lt (wp07 ~ - ° io r ° i ° i ~ i i ~ i i i ~ ~ i i i ~ / i i ~ ~ ~ i i ~ ~ ~ i i ~ ~ ~ i I / ~ ~ ~ 1 / ~ I ~ ~ I I ~ I I ~ i ~ ~ 1J-102 (wp07 1J-102 L2 T1 (wp07 ~ , 1J-102 L2 T4 (Toe) (wp07 1J-102 L2 T2 (wp07 1J-102 L2 T3 (wp03 ~uu HALLIBURTQN R'~ Sperry DriNiny Services Co~ocoPhi~~ips Alaska 600 -800 -400 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 8400 8800 Vertical Section at 1£30.00. 11000 film) 10 3l4" 0 1 i r ,boo -a u, ° 00 ° O° ~ 1g0 20" ~ 175° 1 1 L2: TOW@48558 MD,3551ftN ------------------------------------. L2 : BOW @ 4877ft MD, 3554ft N . -' ~ ~ t _,-'~~ i _-'" ~ L2 : End 30' Rathole • Build @ 5°/100ft, 4907ft MD, 3559ft N ~ I I I i L2 _Continue_Geo Steer in_ D-Sand 5127ft M0.._ 3574ft Np I 80° --___----- 1J-102 L2 T1(wp07 1 -4760 -sloo -5440 -5780 -6120 0 0 Z s 0 i ~ I ~ I ~ i I I ' I 1J-102 L2 DD @ 95% Poly (wp07) ; '80° I DD Polygon Describes a corridor 100' wide I with a 50'+/-allowance EIW from the I I proposed wellbore. ' i ' 1 I I I I ' ' I 1J-102 L2 Geo Poly (wp07) I _ _ _ _ _ I ~ -------1J-102 L2 T2(wp07 Geo Polygon portrays the maximum positional ~ uncertainty , @ 95% confidence, if actual wellpath is at ~ oy, outer edge of Red DD polygon. -- - -- - - h i f I I ~ I I I I I ' I ' Project: Kuparuk River Unit ~9° Site: Kuparuk 1J Pad ~ ~I Well: Plan 1J-102 , ' Wellbore: 1J-102 L2 ~ ~-----____ Plan: 1 J-102 L2 (wp07) i ~ - - - 1J-102 L2 T3 (wpo3 I I ~ I 7g' T ~,zimuths to True North Magnetic North: 23.88° Magnetic Field Strength: 57604.OnT Dip Angle: 80.60° Date: 7!1/2006 Model: BGGM2006 I NALLIBURTON I ~ Syerry Drilling S~rvlus I I ~ it y,. i -71 CASING DETAILS No MD TVD TVDss Name Size 1 120.00 120.00 -1 20" 20 2 2645.82 2243.00 2122 10 3/4" 10-3/4 3 4865.09 3551.00 3430 7 5/8" TOW5/8 4 12187.52 3509.00 3388 4 1 /2" 4-1 /2 I 80° ConocoPhill~ps I I Alaska t i i I i I ~ 1J-102 L2 T4(Toe)(wp07 I I ~- I I I ,,-~ i ,, ~ _ _ _ _ _ _ _ L2 : BHL @ 12188ft MD, 3509ft ND - 411 ' -2040 -1700 -1360 -1020 -680 -340 0 340 680 1020 1360 1700 2040 2380 2720 3060 3400 3740 4080 ~Ir-' ~ Halliburton Energy Services ~ p~`~~~~~~- C©C1000~'YI~~i(75 Planning Report -Geographic ~---~-~~- Qrilli Sa}rvic Database: Alaska _EDM_2003.11 b48 Company: ConocoPhillips Alaska Inc. Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-102 Wellbore: 1J-102 L2 Design: 1J-102 L2 (wp07) SPotr1- ~8 es Local Co-ordinate Reference: Well Plan 1J-102 -Slot 1J-102 TVD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) MD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1J-102 -Slot 1J-102 Well Position +N/-S 0.00 ft Northing: 5,946,056.80ft Latitude: 70° 15' 47.609" N +E/-W 0.00 ft Easting: 558,781.70 ft Longitude: 149° 31' 29.797" W Position Uncertainty 0.00 ft Wellhead E levation: ft Ground Level: 81.OOft - - Wellbore -- 1J-102 L2 _ _ _ - 'Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2006 7/1/2006 23.88 80.80 57,604 Design 1J-102 L2 (wp07 ) Audit Notes: Version: 16 Phase: PLAN Tie On Depth: 4,865.08 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction lft) (ft) (ft) (°) 40.00 0.00 0.00 180.00 Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°I100ft) (°/100ft) (°/100ft) (°) 4,865.08 77.00 180.00 3;551.00 -268.16 1,904.44 0.00 0.00 0.00 0.00 4,877.08 78.91 180.00 3,553.51 -279.89 1,904.44 15.90 15.90 0.00 0.00 4,907.08 78.91 180.00 3,559.28 -309.33 1,904.44 0.00 0.00 0.00 0.00 5,126.80 93.16 188.32 3,574.47 -527.18 1,888.46 7.50. 6.49 3.79 30.61 5,396.24 93.16 188.32 3,559.63 -793.38 1,849.54 0.00 0.00 0.00 0.00 5,572.01 91.05 179.78 3,553.16 -968.42 1,837.15 5.00 -1.20 -4.86 -103.69 6,072.01 91.05 179.78 3,544.00 -1,468.34 1,839.07 0.00 0.00 0.00 0.00 6,083.61 90.97 180.12 3,543.80 -1,479.93 1,839.08 3.00 -0.73 2.91 104.05 8,326.58 90.97 180.12 3,506.00 -3,722.59 1,834.48 0.00 0.00 0.00 0.00 8,375.45 89.15 179.39 3,505.95 -3,771.44 1,834.69 4.00 -3.71 -1.49 -158.12 9,016.60 89.15 179.39 3,515.44 -4,412.50 1,841.53 0.00 0.00 0.00 0.00 9,053.09 90.61 179.45 3,515.52 -4,448.98 1,841.90 4.00 4.00 0.17 2.38 9,853.09 90.61 179.45 3,507.00 -5,248.90 1,849.57 0.00 0.00 0.00 0.00 9,878.94 89.58 179.37 3,506.96 -5,274.75 1,849.84 4.00 -3.99 -0.31 -175.59 10,567.50 89.58 179.37 3,512.02 -5,963.24 1,857.41 0.00 0.00 0.00 0.00 10,587.52 90.11 179.97 3,512.07 -5,983.26 1,857.52 4.00 2.65 2.99 48.47 12,187.52 90.11 179.97 3,509.00 -7,583.26 1,858.36 0.00 0.00 0.00 0.00 5/21/2006 11:17:39AM Page 2 of 7 COMPASS 2003.11 Build 50 Y • H llib E i t S ~ ~ ~ ~~ a ur on nergy erv ces ~,~~~~~,~.~ ~`~~C© ~ ~~~ Planning Report -Geographic ~ a"~ ~- Alaska. ~~~~ ~~ Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-102 -Slot 1J-102 Company: ConocoPhillips Alaska Inc. TVD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) Project: Kuparuk River Unit MD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-102 Survey Calculation Method: Minimum Curvature Wellbore: 1J-102 L2 Design: 1J-102 L2 (wp07} Planned Survey 1J-102 L2 (wp07) Map MD Inclination Azimuth ND SSTVD +N/-S +E/_yy Northing (ft) (°) (°) (ft) (ftl (ft) (ft) (ft) 4,865.08 77.00 180.00 3,551.00 3,430.00 -268.16 1,904.44 5,945,803.54 L2 : TOW @ 4865ft MD, 3551ft TVD : 1977ft FSL & 541ft FE L -Sec 35 - T11 N - R10E - 7 518" TOW - 4,877.08 78.91 180.00 3,553.51 3,432.51 -279.89 1,904.44 5,945,791.80 L2 : BOW @ 4877ft MD, 3554ft TVD Map Fasting DLSEV Vert Section (ft) (°/100ft) (ft) 560,667.99 0.00 268.16 560,668.08 15.90 279.89 4,900.00 78.91 180.00 3,557.92 3,436.92 -302.38 1,904.44 5,945,769.32 560,668.26 0.00 302.38 4,907.08 78.91 180.00 3,559.28 3,438.28 -309.33 1,904.44 5,945,762.37 560,668.31 0.00 309.33 L2 : End 30' Rathole - Build @ 6°/100ft, 4907ft MD, 3559ft TVD 5,000.00 84.92 183.56 3,572.34 3,451.34 -401.23 1,901.57 5,945,670.46 560,666.16 7.50 401.23 5,100.00 91.42 187.31 3,575.54 3,454.54 -500.65 1,892.10 5,945,570.97 560,657.47 7.50 500.65 5,126.80 93.16 188.32 3,574.47 3,453.47 -527.18 1,888.46 5,945,544.42 560,654.03 7.51 527.18 L2 : Continue GeoSteer in D-San d 5127ft MD, 3574ft TVD 5,200.00 93.16 188.32 3,570.43 3,449.43 -599.50 1,877.89 5,945,472.03 560,644.03 0.00 599.50 5,300.00 93.16 188.32 3,564.93 3,443.93 -698.30 1,863.44 5,945,373.13 560,630.35 0.00 698.30 5,396.24 93.16 188.32 3,559.63 3,438.63 -793.38 1,849.54 5,945,277.95 560,617.19 0.00 793.38 5,400.00 93.11 188.14 3,559.42 3,438.42 -797.10 1,849.00 5,945,274.23 560,616.69 4.97 797.10 5,500.00 91.92 183.28 3,555.03 3,434.03 -896.48 1,839.07 5,945,174.79 560,607.54 5.00 896.48 5,572.01 91.05 179.78 3,553.16 3,432.16 -968.42 1,837.15 5,945,102.83 560,606.18 5.00 968.42 5,600.00 91.05 179.78 3,552.65 3,431.65 -996.41 1,837.26 5,945,074.85 560,606.51 0.00 996.41 5,700.00 91.05 179.78 3,550.82 3,429.82 -1,096.39 1,837.65 5,944,974.89 560,607.67 0.00 1,096.39 5,800.00 91.05 179.78 3,548.98 3,427.98 -1,196.37 1,838.03 5,944,874.92 560,608.83 0.00 1,196.37 5,900.00 91.05 179.78 3,547.15 3,426.15 -1,296.36 1,838.41 5,944,774.95 560,610.00 0.00 1,296.36 6,000.00 91.05 179.78 3,545.32 3,424.32 -1,396.34 1,838.80 5,944,674.99 560,611.16 0.00 1,396.34 6,072.01 91.05 179.78 3,544.00 3,423.00 -1,468.34 1,839.07 5,944,603.00 560,612.00 0.00. 1,468.34 1J-102 L2 T1 (wp07) 6,083.61 90.97 180.12 3,543.80 3,422.80 -1,479.93 1,839.08 5,944,591.41 560,612.10 3.00 1,479.93 6,100.00 90.97 180.12 3,543.52 3,422.52 -1,496.32 1,839.05 5,944,575.02 560,612.20 0.00 1,496.32 6,200.00 90.97 180.12 3,541.83 3,420.83 -1,596.31 1,838.85 5,944,475.04 560,612.77 0.00 1,596.31 6,300.00 90.97 180.12 3,540.15 3,419.15 -1,696.29 1,838.64 5,944,375.07 560,613.35 0.00 1,696.29 6,400.00 90.97 180.12 3,538.46 3,417.46 -1,796.28 1,838.44 5,944,275.09 560,613.92 0.00 1,796.28 6,500.00 90.97 180.12 3,536.78 3,415.78 -1,896.26 1,838.23 5,944,175.12 560,614.50 0.00 1,896.26 6,600.00 90.97 180.12 3,535.09 3,414.09 -1,996.25 1,838.03 5,944,075.15 560,615.07 0.00 1,996.25 6,700.00 90.97 180.12 3,533.41 3,412.41 -2,096.24 1,837.82 5,943,975.17 560,615.65 0.00 2,096.24 6,800.00 90.97 180.12 3,531.72 3,410.72 -2,196.22 1,837.61 5,943,875.20 560,616.22 0.00 2,196.22 6,900.00 90.97 180.12 3,530.04 3,409.04 -2,296.21 1,837.41 5,943,775.22 560,616.80 0.00 2,296.21 7,000.00 90.97 180.12 3,528.35 3,407.35 -2,396.19 1,837.20 5,943,675.25 560,617.37 0.00 2,396.19 .7,100.00 90.97 180.12 3,526.67 3,405.67 -2,496.18 1,837.00 5,943,575.27 560,617.95 0.00 2,496.18 7,200.00 90.97 180.12 3,524.98 3,403.98 -2,596.16 1,836.79 5,943,475.30 560,618.52 0.00 2,596.16 7,300.00 90.97 180.12 3,523.30 3,402.30 -2,696.15 1,836.59 5,943,375.32 560,619.10 0.00 2,696.15 7,400.00 90.97 180.12 3,521.61 3,400.61 -2,796.14 1,836.38 5,943,275.35 560,619.67 0.00 2,796.14 7,500.00 90.97 180.12 3,519.93 3,398.93 -2,896.12 1,836.18 5,943,175.37 560,620.25 0.00 2,896.12 7,600.00 90.97 180.12 3,518.24 3,397.24 -2,996.11 1,835.97 5,943,075.40 560,620.82 0.00 2,996.11 7,700.00 90.97 180.12 3,516.56 3,395.56 -3,096.09 1,835.77 5,942,975.43 560,621.40 0.00 3,096.09 7,800.00 90.97 180.12 3,514.87 3,393.87 -3,196.08 1,835.56 5,942,875.45 560,621.97 0.00 .3,196.08 7,900.00 90.97 180.12 3,513.19 3,392.19 -3,296.06 1,835.36 5,942,775.48 560,622.55 0.00 3,296.06 8,000.00 90.97 180.12 3,511.50 3,390.50 -3,396.05 1,835.15 5,942,675.50 560,623.12 0.00 3,396.05 8,100.00 90.97 180.12 3,509.82 3,388.82 -3,496.03 1,834.95 5,942,575.53 560,623.70 0.00 3,496.03 8,200.00 90.97 180.12 3,508.13 3,387.13 -3,596.02 1,834.74 5,942,475.55 560,624.27 0.00 3,596.02 8,300.00 90.97 180.12 3,506.45 3,385.45 -3,696.01 1,834.54 5,942,375.58 560,624.85 0.00 3,696.01 5/21/2006 11:17.39AM Page 3 of 7 COMPASS 2003.11 Build 50 ORIGINAL ~ Halliburton Energy Servic es y~~L~BUI~~t-oN C©II'tOCO~"11~~~3 5 Planning Report -Geographic ---~ ~®~ ~ Spenry Drilling Services Database: _EDM 2003.11 b48 Local Co-ordinate Reference: Well Plan 1J-102 -Slot 1J-102. Company: ConocoPhillips Alaska Inc. TVD Reference: Doyon 15 Plan @ 121.OOft {Doyon 15 (81+40p Project: Kuparuk River Unit MD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-102 Survey Calculation Method: Minimum Curvature Wellbore: 1J-102 L2 Design: 1J-102 L2 (wp07) Planned Survey 1J-102 L2 (wp07) Map Map ', MD Inclination Azimuth TVD SSTVD +NI-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 8,326.58 90.97 180.12 3,506.00 3,385.00 -3,722.59 1,834.48 5,942,349.00 560,625.00 0.00 3,722.59 1J-102 L2 T2 (wp07) 8,375.45 89.15 179.39 3,505.95 3,384.95 -3,771.44 1,834.69 5,942,300.15 560,625.59 4.00 3,771.44 8,400.00 89.15 179.39 3,506.31 3,385.31 -3,795.99 1,834.95 5,942,275.60 560,626.04 0.00 3,795.99 8,500.00 89.15 179.39 3,507.79 3,386.79 -3,895.98 1,836.02 5,942,175.64 560,627.89 0.00 3,895.98 8,600.00 89.15 179.39 3,509.27 3,388.27 -3,995.96 1,837.09 5,942,075.68 560,629.74 0.00 3,995.96 8,700.00 89.15 179.39 3,510.75 3,389.75 -4,095.94 1,838.15 5,941,975.72 560,631.58 0.00 4,095.94 8,800.00 89.15 179.39 3,512.23 3,391.23 -4,195.93 1,839.22 5,941,875.76 560,633.43 0.00 4,195.93 8,900.00 89.15 179.39 3,513.72 3,392.72 -4,295.91 1,840.28 5,941,775.79 560,635.27 0.00 4,295.91 9,000.00 89.15 179.39 3,515.20 3,394.20 -4,395.89 1,841.35 5,941,675.83 560,637.12 0.00 4,395.89 9,016.60 89.15 179.39 3,515.44 3,394.44 -4,412.50 1,841.53 5,941,659.23 560,637.43 0.00 4,412.50 9,053.09 90.61 179.45 3,515.52 3,394.52 -4,448.98 1,841.90 5,941,622.76 560,638.08 4.00 4,448.98 9,100.00 90.61 179.45 3,515.02 3,394.02 -4,495.88 1,842.35 5,941,575.86 560,638.90 0.00 4,495.88 9,200.00 90.61 179.45 3,513.95 3,392.95 -4,595.87 1,843.31 5,941,475.89 560,640.64 0.00 4,595.87 9,300.00 90.61 179.45 3,512.89 3,391.89 -4,695.86 1,844.27 5,941,375.92 560,642.38 0.00 4,695.86 9,400.00 90.61 179.45 3,511.82 3,390.82 -4,795.85 1,845.22 5,941,275.95 560,644.12 0.00 4,795.85 9,500.00 90.61 179.45 3,510.76 3,389.76 -4,895.84 1,846.18 5,941,175.98 560,645.86 0.00 4,895.84 9,600.00 90.61 179.45 3,509.69 3,388.69 -4,995.83 1,847.14 5,941,076.01 560,647.60 0.00 4,995.83 9,700.00 90.61 179.45 3,508.63 3,387.63 -5,095.82 1,848.10 5,940,976.04 560,649.34 0.00 5,095.82 9,800.00 90.61 179.45 3,507.57 3,386.57 -5,195.81 1,849.06 5,940,876.07 560,651.08 0.00 5,195.81 9,853.09 90.61 179.45 3,507.00 3,386.00 -5,248.90 1,849.57 5,940,823.00 560,652.00 0.00 5,248.90 1 J-102 L2 T3 (wp03) 9,878.94 89.58 179.37 3,506.96 3,385.96 -5,274.75 1,849.84 5,940,797.15 560,652.47 4.00 5,274.75 9,900.00 89.58 179.37 3,507.11 3,386.11 -5,295.80 1,850.07 5,940,776.10 560,652.86 0.00 5,295.80 10,000.00 89.58 179.37 3,507.85 3,386.85 -5,395.79 1,851.17 5,940,676.13 560,654.74 0.00 5,395.79 10,100.00 89.58 179.37 3,508.58 3,387.58 -5,495.79 1,852.27 5,940,576.16 560,656.62 0.00 5,495.79 10,200.00 89.58 179.37 3,509.32 3,388.32 -5,595.78 1,853.37 5,940,476.19 560,658.50 0.00 5,595.78 10,300.00 89.58 179.37 3,510.05 3,389.05 -5,695.77 1,854.47 5,940,376.22 560,660.38 0.00 5,695.77 10,400.00 89.58 179.37 3,510.79 3,389.79 -5,795.76 1,855.57 5,940,276.25 560,662.26 0.00 5,795.76 10,500.00 89.58 179.37 3,511.52 3,390.52 -5,895.75 1,856.66 5,940,176.28 560,664.14 0.00 5,895.75 10,567.50 89.58 179.37 3,512.02 3,391.02 -5,963.24 1,857.41 5,940,108.81 560,665.41 0.00 5,963.24 10,587.52 90.11 179.97 3,512.07 3,391.07 -5,983.26 1,857.52 5,940,088.79 560,665.68 4.00 5,983.26 10,600.00 90.11 179.97 3,512.05 3,391.05 -5,995.74 1,857.53 5,940,076.31 560,665.78 0.00 5,995.74 10,700.00 90.11 179.97 3,511.86 3,390.86 -6,095.74 1,857.58 5,939,976.32 560,666.61 0.00 6,095.74 10,800.00 90.11 179.97 3,511.66 3,390.66 -6,195.74 1,857.63 5,939,876.34 560,667.45 0.00 6,195.74 10,900.00 90.11 179.97 3,511.47 3,390.47 -6,295.74 1,857.68 5,939,776.35 560,668.28 0.00 6,295.74 11,000.00 90.11 179.97 3,511.28 3,390.28 -6,395.74 1,857.74 5,939,676.36 560,669.11 0.00 6,395.74 11,100.00 90.11 179.97 3,511.09 3,390.09 -6,495.74 1,857.79 5,939,576.38 560,669.94 0.00 6,495.74 11,200.00 90.11 179:97 3,510.90 3,389.90 -6,595.74 1,857.84 5,939,476.39 560,670.78 0.00 6,595.74 11,300.00 90.11 179.97 3,510.70 3,389.70 -6,695.74 1,857.89 5,939,376.40 560,671.61 0.00 6,695.74 11,400.00 90.11 179.97 3,510.51 3,389.51 -6,795.74 1,857.95 5,939,276.42 560,672.44 0.00 6,795.74 11,500.00 90.11 179.97 3,510.32 3,389.32 -6,895.74 1,858.00 5,939,176.43 560,673.27 0.00 6,895.74 11,600.00 90.11 179.97 3,510.13 3,389.13 -6,995.74 1,858.05 5,939,076.44 560,674.11 0.00 6,995.74 11,700.00 90.11 179.97 3,509.94 3,388.94 -7,095.74 1,858.10 5,938,976.46 560,674.94 0.00 7,095.74 11,800.00 90.11 179.97 3,509.74 3,388.74 -7,195.74 1,858.16 5,938,876.47 560,675.77 0.00 7,195.74 11,900.00 90.11 179.97 3,509.55 3,388.55 -7,295.74 1,858.21 5,938,776.48 560,676.61 0.00 7,295.74 12,000.00 90.11 179.97 3,509.36 3,388.36 -7,395.74 1,858.26 5,938,676.50 560,677.44 0.00 7,395.74 12,100.00 90.11 179.97 3,509.17 3,388.17 -7,495.74 1,858.31 5,938,576.51 560,678.27 0.00 7,495.74 5/21/2006 11:17:39AM Page 4 of 7 COMPASS 2003.11 Build 50 ~. , ~ Halliburton Energy Services • HA41.1BLlRT®N CanoCt~P~h1111p5 Planning Report -Geographic °~~~~°~-~--~~---~~-°°~---- Database: Alaska _EDM_2003.11_b48 Company: ConocoPhillips Alaska Inc. Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-102 Wellbore: 1 J-102 L2 Design: 1J-102 L2 (wp07) Planned Survey 1J-102 L2 (wp07) Local Co-ordinate Reference: Well Plan 1J-102 -Slot 1J-102. ND Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) MD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) North Reference: True Survey Calculation Method: Minimum Curvature Map MD Inclination Azimuth ND SSND +N/-S +E/-W Northing (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) 12,187.52 90.11 179.97 3,509.00 3,388.00 -7,583.26 1,858.36 5,938,489.00 L2 : BHL @ 12188ft MD, 3509ft ND : 5221ft FSL & 595ft FEL - Sec11 - T10N - R10E - 41/2" . -- _ - 1 Map Fasting DLSEV Vert Section (ft) (°/100ft) (ft) 560,679.00 0.00 7,583.26 5/21/2006 11:17:39AM Page 5 of 7 COMPASS 2003.11 Build 50 ' ~ ~ r- Halliburton Energy Servic es HA~~isus~-roiv ~Ur1C7tt+Ct3~1I~~~~S Planning Report -Geographic ---~~~--~-----~-~---- Alaska Sperry brining Services Database: EDM 2003.11 b48 Local Co-ordinate Reference: Well Plan 1J-102 -Slot 1J-102 Company: ConocoPhillips Alaska Inc. TVD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15{81+40)) Project: Kuparuk River Unit MD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-102 Survey Calculation Method: Minimum Ctarvatiare Wellbore: 1J-102 L2 Design: 1J-102 L2 (wp07) Geologic Targets - 1 J-102 L2 -- - ND Target Name +N/-S +El-W Northing Easting I (ft) -Shape ft ft (ft) (ft) 3,509.00 1J-102 L2 T4 (Toe) (wp07) -7,583.26 1,858.36 5,938,489.00 560,679.00 - Point 3,544.00 1J-102 L2 DD @ 95% Poly (wp0 7) -268.15 1,869.44 5,945,803.27 560,633.00 - Polygon Point 1 -50.00 0.39 5,945,803.27 560,583.00 Point 2 -50.10 -11.34 5,945,791.54 560,582.99 Point 3 -50.36 -40.78 5,945,762.10 560,582.96 Point 4 -63.52 -313.73 5,945,489.08 560,571.94 Point 5 -77.41 -473.04 5,945,329.69 560,559.29 Point 6 -82.67 -599.91 5,945,202.79 560,555.02 Point 7 -80.37 -1,199.79 5,944,603.00 560,562.00 Point 8 -80.35 -1,216.71 5,944,586.09 560,562.15 Point 9 -84.96 -3,454.04 5,942,349.00 560,575.00 Point 10 -84.67 -3,522.24 5,942,280.81 560,575.83 Point 11 -77.98 -4,138.70 5,941,664.49 560,587.33 Point 12 -77.55 -4,180.41 5,941,622.78 560,588.08 Point 13 -69.87 -4,980.35 5,940,823.00 560,602.00 Point 14 -69.51 -5,008.75 5,940,794.61 560,602.58 Point 15 -62.32 -5,478.18 5,940,325.30 560,613.44 Point 16 -62.03 -5,514.75 5,940,288.73 560,614.01 Point 17 -61.09 -7,314.72 5,938,489.00 560,629.00 Point 18 38.92 -7,315.50 5,938,489.00 560,729.00 Point 19 37.97 -5,515.53 5,940,288.73 560,714.01 Point 20 37.69 -5,478.96 5,940,325.30 560,713.44 Point 21 30.49 -5,009.53 5,940,794.61 560,702.58 Point 22 30.13 -4,981.14 5,940,823.00 560,702.00 Point 23 22.45 -4,181.19 5,941,622.78 560,688.08 Point 24 22.03 -4,139.48 5,941,664.49 560,687.33 Point 25 15.34 -3,523.03 5,942,280.81 560,675.83 Point 26 15.04 -3,454.82 5,942,349.00 560,675.00 Point 27 19.65 -1,217.49 5,944,586.09 560,662.15 Point 28 19.63 -1,200.58 5,944,603.00 560,662.00 Point 29 17.33 -600.69 5,945,202.79 560,655.02 Point 30 22.60 -473.82 5,945,329.69 560,659.29 Point 31 36.49 -314.51 5,945,489.08 560,671.94 Point 32 49.64 -41.56 5,945,762.10 560,682.96 Point 33 49.90 -12.12 5,945,791.54 560,682.99 Point 34 50.00 -0.39 5,945,803.27 560,683.00 3,506.00 1J-102 L2 T2 (wp07) -3,722.59 1,834.48 5,942,349.00 560,625.00 - Point 3,544.00 1J-102 L2 T1 (wp07) -1,468.34 1,839.07 5,944,603.00 560,612.00 - Point 3,512.00 1J-102 L2 Geo Poly (wp07) -268.15 1,869.44 5,945,803.27 560,633.00 - Polygon Point 1 -63.00 0.49 5,945,803.27 560,570.00 Point 2 -95.04 -515.59 5,945,287.00 560,542.00 Point 3 -120.51 -3,523.78 5,942,279.00 560,540.00 Point 4 -116.71 -5,471.05 5,940,332.00 560,559.00 Point 5 -131.09 -7,314.17 5,938,489.00 560,559.00 Point 6 112.92 -7,316.08 5,938,489.00 560,803.00 Point 7 91.25 -5,479.68 5,940,325.00 560,767.00 Point 8 51.51 -3,524.12 5,942,280.00 560,712.00 Point 9 35.92 -523.62 5,945,280.00 560,673.00 Point 10 65.00 -0.51 5,945,803.27 560,698.00 3,507.00 1J-102 L2 T3 (wp03) -5,248.90 1,849.57 5,940,823.00 560,652.00 5/21/2006 11:17:39AM Page 6 of 7 COMPASS 2003.11 Build 50 Halliburton Energy Services ~Ot"tOC4P~"11~~lp5 Planning Report -Geographic HA6.t,.IF3URTC'~Nt ~- Alaska Sperry Drilling ;cervices Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-102 -Slot 1J-102 Company: ConocoPhillips Alaska Inc. TVD Reference: Doyon T5 Plan @ 121.OOft (Doyon 15 (81+40)) Project: Kuparuk River Unit MD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) Site: KuparuklJ Pad North Reference: True Well: Plan 1J=102 Survey Calculation Method: Minimum Curvature Wellbore: 1J-102 L2 Design: 1J-102 L2 (wp07) - Point Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) Cft) f') (") 120.00 120.00 20 26 2,645.82 2,243.00 10-3/4 13-1/2 4,865.09 3,551.00 7-5/8 9-7/8 12,187.52 3,509.00 4-112 6-3/4 Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth (ft) (~) (~) (ft) 1,644.52 41.31 39.85 1,533.00 1,833.69 45.35 42.00 1,671.00 2,246.77 45.04 64.21 1,962.00 2,645.82 45.38 80.79 2,243.00 3,690.24 45.94 126.94 2,987.00 4,065.23 53.91 149.24 3,230.00 4,209.74 57.96 156.46 3,311.00 4,430.93 64.85 166.33 3,417,00 4,865.07 77.00 180.00 3,551.00 +N/-E +E/-W (ft) (ft) Name 355.99 271.36 Base Perm 453.76 355.93 T3 629.18 588.66 K15 705.73 860.12 T3 + 550 644.07 1,563.71 Ugnu C 430.99 1,750.57 Ugnu B 324.52 1,804.97 Ugnu A 140.72 1,866.25 K13 -268.15 1,904.44 Wsak D 5/21/2006 11:17:39AM Page 7 of 7 COMPASS 2003.11 Build 50 ORIGINAL • • ConocoPhillips Alaska ConocoPhillips Alaska Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-102 1 J-102 L2 1 J-102 L2 (wp07) Anticollision Report 21 May, 2006 F,ALLIBU~TQ Sperry ©rilfing Service apF~?~4~~~.~. ~ m a r A L z °"d a - _ t a ~ Z o ~ O Q V ?3cmm m m ~-. G n rnE ~ ~a)U.C O d~EAW9 O U E 9 ~ ~ L CL~ « W ..y O'C~ M ~ O N m S C ~ W t E _ ~ W w U ~ N `~ r- 0 i F ~ ~ ~~ d {-~~~ ~ o+p o !`~ J ~ C a N o9m J ~ ~ ~ F W J n 0 J J 3 ~ n C ~ G ~ N (7 ~ m 6 Ww a cm Z O e Z d 30 ul N 2 e + o O N ~ N n N A 3 FrZ z H O J `~ CFn~ N m V ~ ~ pea N ~ m J 00 C4 O r E ~ m u V ° E c r ~ LL z E: m"v a~•~ orc~ d n c 0 M O n 3 ~ r n O ~ ~ j ~, n n c 3 3 3 g N C r r r ~ J J J J o ~~ `a c rn ~ ~ ~ ~ .- I n y V l L n V n Obi N d N m n N m ' r ~ NaC ai oi rieo ao ai ri~NaO and wi a'i ni ~Ne~V~Nnm«N~ yy nmmm r-r•m~«u~i vii umi ~mnr r ~ ~y00 opom N ~ ~ ~ d r ~ J ~ boo onoaoaoaooo oro ~ "> ~ a ~o~ u i ° _ 0 3$$$a~dn~oovm~o°,,n a°o 'a,~M O N N O N O N N M O ~ ~ Z O d d d m O i l h m +m m~nnneS~<~mwnmro r-~~~~~ ~.-.-~r-r-~~ar°r-r- ~ ~ y w N '?~ rmia°ro umi$a°~ °1 o°+1O Sao of of ~: ei ao W ai tir ri ayoc~^i ri ri ~nmmm ~ ~Nr~i nm y g ~ed- i~y N ' ' ' ' ~ , ' n ~ ~ ^ i V h ~o rd b O aid mN~~ ~ as ~.h .amm~me.m ea r ~ n Me~.h .o d G v ~ y 6 ~ n C C a~9 O N U en G - n~~mmmmmmmmmmmmmm ~ °emome°m °n'ooen~~ ~ L ~ N ~aem.n ~nmmmmmmm ___ N O O Q .-Hmdnmrmm~ ~~ r-~.-ems e- M N o c c G O 0 0 ~n o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 .n o ~n o .n 0 0 0 0 0 0 in o~ ~n r o N ~n o 0 0 0 0 N M V N t0 f~ - 0 0 0 0 0 0 0 ~n 0 0 o N W W r r- ~ N ~ N N f~ ~ ~ ' N N ~ I I I I I I V I I ~ r C O O N N O O O O O O O O O O O O O O ~f1 O N O N O N 0 0 0 0 0 u7 f~ O O N N 0 0 0 0 N O O O O 0 0 0 0 0 0 0 0 O ~ ~ ~ N N N M 7 N c0 I~ W m O 0 m 0 m Ci U 6Q UU Y :G Naa y ~~~ ~ _vcc a~ ~" FUSE C V ` '.~~ } ~ C ~ 9 y a ~ e ~ ~ ~,:~v a ~z~r ~ E $ Sic 3 LnY~ O N C ~J bA c Y F~ t°a °a o~ Z •~ 2 c r o 0 °o 0 icwr oo$o y~Z~~ ~~o ~N Z r- o C ? F ~aoaV ~ n ' ~ c o a _`o DoE ~ 3awo~ z w Si o U ~+ O Z a~rd« w ~ ~f w rc¢¢¢o 1' W ONE q Z ~ > 6 ~ O !~ 'a ~atj v C N h O O ~ U Conoco~illips Alaska Company: ConocoPhillipsAlaskaJnc. Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-102 Well Error: O.OOft Reference Wellbore 1J-102 L2 Reference Design; 1J-402 L2 (wp07) Halliburton Energy Services Anticollision Report Local Co-ordinate Reference: Well Plan 1 TVD Reference: Doyon 15 P MD Reference: Doyon 15 P North Reference: True Survey Calculation Method: Minimum C Output errors are at 2.00 sigma Database: _EDM_200 Offset TVD Reference: Reference HALLIBURTON Sperry Qrilling Services J-102 -Slot 1 J-102 Ian @ 121.OOft (Doyon 15 (81+40)) Ian @ 121.OOft (Doyon 15 (81+40)) urvature 3.11 _b48 Datum Reference 1J-102 L2 (wp07) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 50.OOft Error Model: ISCWSA Depth Range: 4,865.08 to 12,187.52ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,414.75ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 5/21/2006 From To (ft) (ft) Survey (Wellbore) Tool Name Description 40.00 800.00 1J-102 (wp07) (1J-102) CB-GYRO-SS Camera based gyro single shot 800.00 4,865.08 1J-102 (wp07) (1J-102) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4,865.08 12,187.52 1J-102 L2 (wp07) (1J-102 L2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 5/21/2006 11:29:59AM Page 2 of 4 COMPASS 2003.11 Build 50 s ConocoPhillips Alaska Company: ConocoPhillips Alaska Inc. Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-102 Well Error: O.OOft Reference Wellbore 1 J-102 L2 Reference Design: 1J-102 L2 (wp07) Halliburton Energy Services Anticollision Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: • HALLiBURTON Spery Driiiing Services Well Plan 1J-102-Slot 1J-102 Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) Doyon 15 Plan @ 121.OOft (Doyon 1 S (81+40)) True Minimum Curvature 2.00 sigma _EDM 2003.11_b48 Reference Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well - Wellhore -Design (ft) (ft) (ft) (ft) Kuparuk 1J Pad 1J-14 - 1J-14 - 1J-14 7,272.69 4,550.00 672.30 138.76 560.78 Pass- Major Risk 1 J-152 - 1 J-152 - 1 J-152 Out of range 1 J-152 - 1 J-152 L1 - 1 J-152 L1 Out of range 1 J-152 - 1 J-152 L2 - 1 J-152 L2 Out of range 1J-152- 1J-152 L2 PB1 - 1J-152 L2 PB1 Out of range 1J-152 - 1J-152 P61 - 1J-152 PB1 Out of range 1 J-152 - 1 J-152 PB2 - 1 J-152 PB2 Out of range 1 J-154 - 1 J-154 - 1 J-154 Out of range 1J-154 - 1J-154 L1 - 1J-154 L1 Out of range 1 J-154 - 1 J-154 L2 - 1 J-154 L2 Out of range 1 J-159 - 1 J-159 - 1 J-159 5,518.79 4,250.00 1,014.15 104.16 912.96 Pass -Major Risk 1J-159 - 1J-159 L1 - 1J-159 L1 5,518.79 4,250.00 1,014.15 104.03 913.09 Pass -Major Risk 1J-159 - 1J-159 L1 PB1 - 1J-159 L1 P61 5,518.79 4,250.00 1,014.15 104.13 912.99 Pass -Major Risk 1J-159 - 1J-159 L1 PB2 - 1J-159 L1 P62 5,518.79 4,250.00 1,014.15 104.73 912.38 Pass -Major Risk 1J-159 - 1J-159 L2 - 1J-159 L2 5,544.72 4,300.00 1,014.80 104.52 913.01 Pass -Major Risk 1J-159 - 1J-159 PB1 - 1J-159 PB1 5,518.79 4,250.00 1,014.15 104.03 913.09 Pass -Major Risk Plan 1J-102 - 1J-102 - 1J-102 (wp07) 4,899.96 4,899.98 0.97 0.60 0.37 Pass - No Errors Plan 1J-102 - 1J-102 L1 - 1J-102 L1 (wp07) 4,899.96 4,899.98 0.97 0.60 0.37 Pass - No Errors Plan 1J-103 - 1J-103 - 1J-103 (wp03) -North Heel 9,621.92 11,019.86 1,344.25 241.00 1,109.95 Pass- Major Risk Plan 1J-103 - 1J-103 L1 - 1J-103 L1 (wp03) -North Hee 9,622.95 11,008.37 1,323.98 255.04 1,071.10 Pass -Major Risk Plan 1J-103 - 1J-103 L2- 1J-103 L2 (wp03) -North Hee 8,053.19 9,450.00 1,250.32 199.80 1,052.19 Pass- Major Risk Plan 1 J-105 -Plan 1 J-105 - 1 J-105 (wp02) Out of range Plan 1J-107 -Plan 1J-107 - 1J-107 (wp02) Out of range Plan 1J-109 -Plan 1J-109 - 1J-109 (wp05) Out of range Plan 1J-111 -Plan 1J-111 - 1J-111 (wp03) Out of range Plan 1J-127 -Plan 1J-127 - 1J-127 (wp04) Out of range Plan 1J-127 -Plan 1J-127 L1 - 1J-127 L1 (wp04) Out of range Plan 1 J-127 -Plan 1 J-127 L2 - 1 J-127 L2 (wp04) Out of range Plan 1 J-133 - 1 J-133 - 1 J-133 (wp06) 8,122.57 5,050.00 1,141.45 169.82 1,005.58 Pass -Major Risk Plan 1J-133- 1J-133 L1 - 1J-133 L1 (wp06) 8,122.57 5,050.00 1,141.45 169.82 1,005.59 Pass- Major Risk Plan 1J-135 -Plan 1J-135 -Plan 1J-135 (wp01) 8,559.53 5,400.00 930.50 183.72 775.31 Pass -Major Risk Plan 1J-136 - 1J-136 - 1J-136 (wp04) 11,942.15 8,399.97 183.97 34.01 154.51 Pass -Minor 1/200 Plan 1J-136 - 1J-136 L1 - 1J-136 L1 (wp04) 11,942.15 8,399.97 183.97 34.01 154.50 Pass -Minor 1/200 Plan 1 J-137 - 1 J-137 - J-137 (wp05) 12,155.94 8,350.00 936.90 305.03 637.56 Pass -Major Risk Plan 1J-137 - 1J-137 L1 - 1J-137 L1 (wp05) 12,155.94 8,350.00 936.90 305.03 637.56 Pass -Major Risk Plan 1J-156 - 1J-156 - 1J-156 (wp05) Out of range Plan 1J-156 - 1J-156 L1 - 1J-156 L1 (wp05) Out of range Plan 1J-156 - 1J-156 L2 - 1J-156 L2 (wp05) Out of range Plan 1J-158 - 1J-158 - 1J-158 (wp03) Out of range WSP-1 S -WSP-1 S -WSP-1 S Out of range CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 5/21/2006 11:29:59AM Page 3 of 4 COMPASS 2003.11 Build 50 ~! ~ ~. 1~-102L2~rilling Hazards~ummary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs decreased mud wei ht Lost Circulation Low Reduced um rates mud rheolo , LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out backreamin _, 7J-102L2 Drilling Hazards Summary 7/24/2006 3:38 PM 20" 94.0# x 34" Insulated Conductor, K-55, set at +/- 80' 10-3/4" x 4-112" Wellhead, 5,000 psi 10.3/4", 68#, BTC )~ Shoe set @ 2646' MD, 2243' TVD / Tubing String 4-1/2" 12.6#, L-80, IBTM 3.958" ID, 3.833" Drift 5-112" X 7SI8" ZXP Liner Top Packer wl Hold Seal Assembly Downs 4.75" Seal OD 4-112" X 7-518" Seal Bores / Model'B' HOOK Hanger 3.68" ID (l.' 5-112" X 7-518" ZXP Liner Top Packer wl Hold Downs Lateral Entry Module (LEM) Assembly f~ 5-112" X 7-518" ZXP Liner Top Packer with Hold Downs ~~_ Casing Sealbore Receptacle 4.75" ID Orienting Profile Automatic Alignment of LEM Positive Latching Collet ~~ Indicates Correct Location Seal Bore for Lateral ~' Isolation - 3.68" ID Access Window Positive Lateral Access Via Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3.68" ID Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID Tubing, 4-112", 12.6#, IBTM, Special Drift to +/_ 500' 3.875" DB Nipple, for Possible SSSV, +/- 500' GLM, Camco KBG-2, 4-1/2" X 1", 25 deg, 1,200 ft MD GLM, Camco KBG-2, 4-1/2" X 1", 70 deg, +/- 1 jt above sliding sleeve CMD Sliding Sleeve, wl 3.81" DB Nipple, 72 deg, +/- 1 jt above seals Casing Sealbore Receptacle, 20' Length Lateral Entry~~-~ ¢and Window 4865' MD, 3551' rvD 4-112" 11.6# L-80 Slotted Liner Swivel Liner Everv Other Joint Casing Sealbore Receptacle 20' Length ~onacoPhillips West Sak 7-5/8" Injector 1 J-102 Tri-Lateral Completion 'D' Sand Lateral 3-112" Bent Joint 3-112" Guide Shoe -' 4.1/2" Liner Shoe, 11.6#, L-80 BTC (('~~ Set ~ 12187' MD, 3509' TVD 4e75'ASe I OD 1~ `, V ~~ 4112" X 7-516" Model 'B' HOOK Hanger Seal Bon 3.68" ID 4-112" 12.6# Tubin9_____-----'~\ 3.833" Drift 3.958" ID 5-112" X 7318" ZXP Liner Top Packer with Hold Downs 5-112" X 7-518" Flex Lock Liner Hanger 1 Packer Assembly at Liner Hanger +l- 5300' MD Casing Sealbore Receptacle, 20' Length ® Baker Hughes 3005. This document may not be reproducetl or tllshlbuhq In whole or In part, In any form or by any mans electronic or mechanical, Inclutling phorocopying, recording, or by any Information storage and rebleval system now known or hereafter Invented, without written permission hom Baker Hughes Inc. Lateral Entry Module(LEM) As Planned rii:~ NYGNES Baker Oil Tools Late With ral Entrv Module (LEMI Diverters and Isolation Lateral Access Diverter Lateral Isolatlon Diverter GS Running Tool String Installed Installed (J.00" Lateral Dritt) (2.50" ID Mainbore Drift) 'cs' Praae ror Coil Connector i lRUnning/Retrievlrg \ (1.00' Length) I Snap INSnap Out i /Positive Locating r Back Pressure Valve I Collet i (1.60' Length) 1 I Lateral Isolation ~' r Flow-Thru Swivel Seals / (1.25' Length) i / Lateral Diverter i II , ~/ Hydraulic Ramp i I Disconnect Isolation/ Mainbore i (1.50' Length) Diverter SMeve I ~~ GS Spear ' ~~ Lateral Isolatbn ~ I (1.50 Length) Seals 6.85 tt Approx. OAL' ~I B•sand Window - 'an'al y pe `~O1eO or deep applications at 5185' MD, 3621' rvD 'B' Sand Lateral 4-112" 11.6# L-80 Slotted Liner Swivel Liner Every Other Joint / 3-112" Bent Joint \ __-~_--~~_._.__..i .-..r - 3-112" Guide Shoe 3.562" DB Nipple I hly deviated 18.5' Diverter Length 18.5' Sleeve Length rox lena[hl. Equipment Specifications 4-1/2" X 7-518" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with diverter: 4.63" Lateral Drift, no diverter or LEM: 3.88" Lateral Drift, wl diverter, no LEM: 3.88" LaterallMainbore Diverter OD: 6.75" 4112" 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: +1- 3.89" Diverter and Sleeve Length: +l- 18.5' 4-1/2" Liner Shoe, 11.6#, L-80 BTC Set @ 12492' MD, 3582' TVD Seal Assembly 4.75" Seal OD 'A' Sand Undulating Lateral 4-112" 11.6# L-80 Slotted Liner Every Other Joint 4-112" Eccentric / ,Guide Shoe 7.518" 40# Casing, L-80, BTCM, Set at @ 5988' MD, 3755' TVD (84 degj 4-112" Casing Shoe, 11.6#, L-80 BTC Set @ 13688' MD, 3728' TVD weat sak r-sla^ rrt-taterm completion - In)ecror Jul 34, 3008 Down BY: I Y Marc O. Kuck • • i • TRANSMITT/A~L LETTER CHECKLIST WELL NAME /~~~ f~r ~d ~G- 2-~- PTD# Zoe, -- / t Z Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER I WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing / we l I /~l~ G~, ~ o~^ ~O Z,,, , (If last two digits in permit I~Jp. ?~'lo~/lam API No. 50-~Z~ - 2 33/7- d6 API number are , . . ~~CCtt'' between 60-69) P should continue to be reported as a function of the I original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH} and API number (50- - -) from records, data and togs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in ~ SAMPLE no greater than 30' sample intervals from below the permafrost or ~ from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed ~ Well for (name of well) until after (Company NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company NameZmust contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25106 C:\j ody\transmittal_checkl i st WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAKOIL -490150 Well Name: KUPARUK RIV U WSAK 1J-102L2 Program SER_.__ Well bore seg [J PTD#:2061120 Company CONOCOPHILLIPS ALASKA INC Initial Classlfype SER I PEND GeoArea 890 Unit 11160 On/off Shore On Annular Disposal Administration 1 Permit_fee attached_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _ . - _ - . - - .. _ _ . _ _ NA_ _ _ _ _ _ _ _ West Sak DSand multilater-al well branch; fee waived per 20 AAC 25.005(e), _ _ _ _ _ _ _ _ _ _ _ - . _ _ _ _ _ 2 Lease numberappropriate______________________-..--.__ -__-_____Yes--_ _--Top-productive interval inADL025661;TD_inADL025662._.___-__----._ 3 Uniquewell_nameandnumber -- - ------------- - -- - ------ Yes- - -- -- -- --- ------- - -- ------ -- - ------------------------------- 4 Well located in a_d_efnedpool______________________ ______ __________Yes--- ----KuparukRiver,West_SakOil Pool-490150,_governed, by CO406B_-___-__,_,____,___ 5 Well located proper distance from drilling unit_boundary, _ - .. _ - - , _ Yes - . - - - ..Well is more than_ 500 feet from an external property line_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 6 Well located proper distance from other wells- _ - - _ - _ _ .. _ - _ _ _ . _ Yes CO 4066, Rule 3:- nor-estrictions as to well spacing except that no_pay shall be o _ened in a well closer _ p 7 Sufficient acreage_available in-drilling unit_ - _ - .... _ . - Yes - - _ . . - . than 500 feet to_an external-properly line where ownershjp-or fandownetship changes_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 8 If deviated, is-wellbore plat_included - - - - Yes - - - - - - - - 9 Operator only affected party____-------------------- ----------Yes-- ------------------ ------------------------------------------------ 10 Operator has appropria#e-bondinf4rce-- --------- -- - --- -- --Yes--- -- ---- --------- --- ---------- ---------------- - ----- --- -- 11 Pe[mit_canbeissuedwithoutconservationorder__________________ __________Yes_-_ _- _______________.____ _._____---_---_-___________-__________ -__ Appr Date 12 Pe[mitcanbeissuedwithoutadministrativ_e_appr_oval_____---.-_-_ __________ Yes___ ________________________ ________________________-_--_____________-- SFD 7127/2006 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by_ Injection Order # (put_1O# in_comments)_(For_ Yes _ . - - - . -Area Injection Order No._ 26 - - - _ - . _ . . 15 All wells within 114-mile area of review identified (For service well only) - - - - - - - - - - - - - - -Yes - - - - - - - WSP,3, WSP,9, WSPc11, WSP-13,_KRl11J-159 and laterals- _ - _ _ _ _ _ _ _ - - _ ------------------- 16 Pre-produced injector; duration_ofpve-production less than_ 3 months_(Forserv ice well only) . -Yes _ - - _ - -KRU 1 J-Pad_injectionwells are.typicallypre-produced 30-45 days for cleanup._ 17 tJonconven, gas conforms to A$31,05.030([.1_.A),(y2.A-D) _ ... - - ~ - - - - - - - - Engineering 18 Conductor string-provided______________________________ __________ NA__,- __--Conduetorset_in 1J-102_(206-110). _____-______,_--_--_----........--_____...... 19 Surfacecasingprotectsall-knownUSDWs___________________- __________ NA-_ -----aqur rsexempte,4. CFR_147.102_(b)_(3).___________------_----.-...----__..- -._. 20 CMT-voladequate_tocircul_ate.onconductor&surf,csg____.________ __________ NA____ __._Surfacecasingsetin1J-102.--_---_____-_______________,__-_--.__.__-___ 21 CMT-vol_adegu_a#e_totie-in long string tosurfcsg________ _________ __________ NA___ __-..Production-casing set in-1J,102._________________._--_-.-----...---__--__....-_ 22 CMT.willcoyerallknown_productivehorizons____________________ __________ No-__ ___ Slotted liner completion planned.__.-__--__--__--_-_________________,___._.______ 23 Casing designs adequate for C, T, B &.permafrost- _ _ - - - . - . _ NA- - - _ _ Original well met design spec~cattons. NA for slotted liner._ .. _ . _ _ 24 Adequate tankage_or reserve pit _ _ - - _ _ - . _ _ - - - - - - - - - - - - - Yes Rig is equipped with steel-pits.. Noreserve-pitplanned, All waste to approved annulus or disposal well.- - _ _ . 25 Ifa_re-drill,has_a-10-403 for abandonment been approved____________ __________ NA___ __--_--.---_______-._____-___________.._--_--_--__--__--__--__________-. 26 Adequate wellbore separation,proposed - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ - - _ - - - Proximit analysisperformed. -Nearest well segment is B-lateral, -70' tyd deeper, - _ - - _ - - - - - - - - _ - _ - - - - 27 If_diverler required, does it meet regu_l~tions_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA- _ - _ _ _ _ _ BOP stack-will already_be in place, _ _ _ _ - _ - _ - - - .. - - _ _ - ---------------------------- Appr Date 28 Drilling fluid-program schematic & equip list_adequate- _ _ _ Yes - . _ . - -Maximum expected formation pressure 8,7_~MW._ Planned MW 8.6ppg or_as needed., TEM 812!2006 29 BOPEs,dolheymeetregulation_________------------ ---_ Yes--- --.-------.--------------,-------------------------------------------- * ~ 30 BOPE_pres5 rating appropriate; test to-(put prig in comments)- - - -Yes - - - . _ . MASP calculated at 1215 psi. 3K stack arrangement and BOP test planned._ - - - - ~ 31 Choke_manifoldcompliesw/API_RP-53(May84)__________________ __________Yes_-. ___--_--___,________ -- -- -- 32 Work will occur without operation shutdown _ _ _ _ _ Yes _ . _ _ ..... _ _ _ _ _ 33 Is presence.af H2S gas_probable- -- - - - - - - - - - - - -- - - - - No- _ - - _ _ - - H2$ has notbeen reported at 1J_pad._ Rig isequipped with sensors and alarms, . - _ _ _ _ 34 Mechanical condition of wells within AOR yerifed (For_service well onty) - . - - - _ - - - - _ _ Yes - - _ - - No isolation issues identifed on wells in AOR._ _ - - _ - - Geology 35 Pe[mit_can be issued wlo hydr-ogen-sulfide measures _ _ - _ - .. - - . _ Yes _ .. No H2S has_been measured in.W Sak wells drilled south from 1 J-Pad. Rig has sensors and_a_larms. _ _ . 36 Data_presented on potential overpressure zones. - _ _ _ _ - - Yes - - - - .. -Expected res._pressure is ~8.7ppg EMW, will be drilled with 8.6 pRgoil-based-mud, Mud weight will be - - - - - _ . Appr Date 37 Seismic-analysis of shallowgas_zones______-___..__--..-.._ _-_--_--_NA__-_ __ -adjusted as needed________________________.___ - -- -- SFD 7127/2006 38 Seabed condition survey_(if off-shore) - - - - - - - - - - - - -- - NA - - - - - - 39 Contactnamelphoneforweekly_progressreports_[exploratoryonlyj____.-_ _--.----_ NA___ ___________________________________________________ ------------------ Geologic Engineering ub' Date: ate Date West Sak D sand injector. This is one of the well branches from tri-lateral injection well KRU 1J-102. SFD Commissioner: on C~o~~~ n~o~ UP j/~'^ • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. r Sperry-Sun Dri~ng Services • LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Nov 03 12:32:42 2006 Reel Header Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Kuparuk River Unit 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 WITNESS: SURFACE LOCATION Scientific Technical Services Scientific Technical Services 1J-102L2 500292331761 ConocoPhillips Alaska, Inc. Sperry Drilling Services 03-NOV-06 MWD RUN 2 MWD RUN 12 MWD RUN 13 MW0004559176 MW0004559176 MW0004559176 B. HENNINGSE R. WILSON B. HENNINGSE M. THORNTON M. THORNTON M. THORNTON MWD RUN 14 MWD RUN 15 MW0004559176 MW0004559176 B. HENNINGSE B. HENNINGSE M. THORTON M. THORNTON SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 2245 FEL: 2446 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 121.30 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING ~b~-11~ ~~~~ DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT S K (IN) 9.875 6.750 SIZE (IN) DEPTH (FT) 10.750 2642.0 7.625 4730.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK EXITING THE 1J-102 L2 PB2 WELLBORE AT 9490'MD/3524'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,13-15 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). MWD RUNS 13-15 ALSO INCLUDED 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 1,2,12-15 REPRESENT WELL 1J-102 L2 WITH API#: 50-029-23317-61. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12095'MD/3501'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). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2606.0 12037.5 FET 2630.0 12045.0 RPD 2630.0 12045.0 RPM 2630.0 12045.0 RPX 2630.0 12045.0 RPS 2630.0 12045.0 ROP 2652.5 12095.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 2606.0 4730.0 12 4730.5 4770.0 13 4770.0 5640.0 14 5640.5 9490.0 15 9490.5 12095.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2606 12095 7350.5 18979 2606 12095 RPD MWD OHMM 1.26 2000 46.3475 18831 2630 12045 RPM MWD OHMM 1.54 2000 40.7691 18831 2630 12045 RPS MWD OHMM 2.05 2000 40.0537 18831 2630 12045 RPX MWD OHMM 2.11 2000 40.5071 18831 2630 12045 FET MWD HOUR 0.14 629.35 0.977957 18831 2630 12045 GR MWD API 20.76 126.62 64.0309 18864 2606 12037.5 ROP MWD FT/H 0.66 1098.43 231.52 18886 2652.5 12095 First Reading For Entire File..........2606 Last Reading For Entire File...........12095 • • File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2606.0 4730.0 RPX 2630.0 4730.0 RPM 2630.0 4730.0 RPD 2630.0 4730.0 RPS 2630.0 4730.0 FET 2630.0 4730.0 ROP 2652.5 4730.0 LOG HEADER DATA DATE LOGGED: 31-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4730.0 TOP LOG INTERVAL (FT) 2652.0 BOTTOM LOG INTERVAL (FT) 4730.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 39.9 MAXIMUM ANGLE: 82.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2642.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G) ~ 9.10 MUD VISCOSITY (S) 58.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 450 FLUID LOSS (C3) 4.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.500 84.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.140 113.0 MUD FILTRATE AT MT: 1.650 84.0 MUD CAKE AT MT: 1.800 84.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2606 4730 3668 4249 2606 4730 RPD MWD020 OHMM 1.26 2000 22.5902 4201 2630 4730 RPM MWD020 OHMM 1.54 1743.45 13.0735 4201 2630 4730 RPS MWD020 OHMM 2.05 129.28 9.94464 4201 2630 4730 RPX MWD020 OHMM 2.11 22.1 8.85026 4201 2630 4730 FET MWD020 HOUR 0.14 81.01 1.50442 4201 2630 4730 GR MWD020 API 20.76 126.62 64.1707 4249 2606 4730 ROP MWD020 FT/H 2.98 1098.43 214.589 4156 2652.5 4730 First Reading For Entire File..........2606 Last Reading For Entire File...........4730 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................ Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 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: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 4730.5 4770.0 LOG HEADER DATA DATE LOGGED: 25-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4770.0 TOP LOG INTERVAL (FT) 4730.0 BOTTOM LOG INTERVAL (FT): 4770.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 76.3 MAXIMUM ANGLE: 76.3 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) 4730.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 61.0 MUD PH: •0 MUD CHLORIDES (PPM): 21000 FLUID LOSS (C3) •0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD120 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4730.5 4770 4750.25 80 4730.5 4770 ROP MWD120 FT/H 0.66 21.75 12.7357 80 4730.5 4770 First Reading For Entire File..........4730.5 Last Reading For Entire File...........4770 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 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: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 4730.5 5640.0 GR 4730.5 5640.0 RPX 4730.5 5640.0 RPM 4730.5 5640.0 RPS 4730.5 5640.0 FET 4730.5 5640.0 ROP 4770.5 5640.0 LOG HEADER DATA DATE LOGGED: 26-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5640.0 TOP LOG INTERVAL (FT) 4770.0 BOTTOM LOG INTERVAL (FT) 5640.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 76.3 MAXIMUM ANGLE: 94.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 4730.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.90 MUD VISCOSITY (S): 60.0 MUD PH: .0 MUD CHLORIDES (PPM): 22000 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 1 19.7 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 ~ Name Service Order Units Si N sam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD130 OHMM 4 1 68 4 2 RPM MWD130 OHMM 4 1 68 8 3 RPS MWD130 OHMM 4 1 68 12 4 RPX MWD130 OHMM 4 1 68 16 5 FET MWD130 HOUR 4 1 68 20 6 GR MWD130 API 4 1 68 24 7 ROP MWD130 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4730.5 5640 5185.25 1820 4730.5 5640 RPD MWD130 OHMM 7.97 67.36 30.0449 1820 4730.5 5640 RPM MWD130 OHMM 8.2 59.91 27.1616 1820 4730.5 5640 RPS MWD130 OHMM 7.96 62.02 26.5138 1820 4730.5 5640 RPX MWD130 OHMM 7.57 1 69.66 26.9791 1820 4730.5 5640 FET MWD130 HOUR 0.16 6 29.35 3.59799 1820 4730.5 5640 GR MWD130 API 48.86 102.4 72.602 1820 4730.5 5640 ROP MWD130 FT/H 17.88 3 85.36 226.169 1740 4770.5 5640 First Reading For Entire File..........4730.5 Last Reading For Entire File...........5640 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data BIT RUN NUMBER: 14 DEPTH INCREMENT: .5000 FILE SUMMARY for each bit run in separate files. VENDOR TOOL CODE START DEPTH ROP 5640.5 GR 5640.5 FET 5640.5 RPX 5640.5 RPS 5640.5 RPM 5640.5 RPD 5640.5 STOP DEPTH 9490.0 9490.0 9490.0 9490.0 9490.0 9490.0 9490.0 • # LO G HEADER DATA DATE LOGGED: 28-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9490.0 TOP LOG INTERVAL (FT) 5640.0 BOTTOM LOG INTERVAL (FT): 9490.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.5 MAXIMUM ANGLE: 94.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 4730.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 60.0 MUD PH: .0 MUD CHLORIDES (PPM): 19000 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 1 19.7 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .................. ..60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD140 OHMM 4 1 68 4 2 RPM MWD140 OHMM 4 1 68 8 3 RPS MWD140 OHMM 4 1 68 12 4 RPX MWD140 OHMM 4 1 68 16 5 FET MWD140 HOUR 4 1 68 20 6 ~ • GR MWD140 API 1 68 24 7 ROP MWD140 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5640.5 9490 7565.25 7700 5640.5 9490 RPD MWD140 OHMM 26.68 381.02 58.2454 7700 5640.5 9490 RPM MWD140 OHMM 25.25 2000 53.4161 7700 5640.5 9490 RPS MWD140 OHMM 12.56 2000 54.8236 7700 5640.5 9490 RPX MWD140 OHMM 20.9 2000 56.0119 7700 5640.5 9490 FET MWD140 HOUR 0.17 2.74 0.458549 7700 5640.5 9490 GR MWD140 API 40.32 84.97 62.9417 7700 5640.5 9490 ROP MWD140 FT/H 3.74 473.23 233.816 7700 5640.5 9490 First Reading For Entire File..........5640.5 Last Reading For Entire File...........9490 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 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: 15 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 9490.5 12045.0 ROP 9490.5 12095.0 RPD 9490.5 12045.0 GR 9490.5 12037.5 FET 9490.5 12045.0 RPM 9490.5 12045.0 RPX 9490.5 12045.0 LOG HEADER DATA DATE LOGGED: 29-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 12095.0 9490.0 12095.0 87.1 91.5 TOOL NUMBER 135134 167218 6.750 4730.0 Mineral Oil Base 8.80 59.0 .0 17500 .0 .000 .0 .000 119.7 .000 .0 .000 .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 Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9490 RPD MWD150 OHMM 28.93 RPM MWD150 OHMM 28.99 RPS MWD150 OHMM 26.37 RPX MWD150 OHMM 24.49 FET MWD150 HOUR 0.17 GR MWD150 API 39.61 ROP MWD150 FT/H 4.01 12095 10792.8 5210 490.5 12095 105.35 53.7568 5110 9490.5 12045 100.28 49.3274 5110 9490.5 12045 108.72 47.3731 5110 9490.5 12045 138.9 47.9873 5110 9490.5 12045 3.32 0.394646 5110 9490.5 12045 92.48 62.4986 5095 9490.5 12037.5 397.75 246.779 5210 9490.5 12095 First Reading For Entire File..........9490.5 Last Reading For Entire File...........12095 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF Scientific Technical Services Scientific Technical Services End Of LIS File Sperry-Sun Dri1~ling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Nov 03 11:53:55 2006 Reel Header Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0004559176 B. HENNINGSE M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD .OPEN HOLE BIT SIZE (IN) 1ST STRING 9.875 2ND STRING 6.750 3RD STRING PRODUCTION STRING • Scientific Technical Services Scientific Technical Services 1J-102L2 PB1 500292331773 ConocoPhillips Alaska, Inc. Sperry Drilling Services 03-NOV-06 MWD RUN 12 MWD RUN 13 MW0004559176 MW0004559176 R. WILSON B. HENNINGSE M. THORNTON M. THORNTON 35 11N l0E 2245 2446 121.30 81.00 ~O~ ~ l~~ ~ I ~ CASING DRILLERS SIZE (IN) DEPTH (FT) 10.750 2642.0 7.625 4730.0 REMARKS: ~ • 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 4730' MD/3538'TVD, WITHIN THE RUN 2 INTERVAL OF THE 1J-102 PB1 WELLBORE. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 12. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,13 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 13 ALSO INCLUDED 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 1,2,12,13 REPRESENT WELL 1J-102 L2 PBl WITH API#: 50-029-23317-73. THIS WELL REACHED A TOTAL DEPTH (TD) OF 5805'MD/3534'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). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY ~ PBU TOOL CODE START D H STOP DEPTH GR 2606.0 5748.0 FET 2630.0 5755.0 RPD 2630.0 5755.0 RPS 2630.0 5755.0 RPM 2630.0 5755.0 RPX 2630.0 5755.0 ROP 2652.5 5805.0 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 2606.0 4730.0 MWD 12 4730.5 4770.0 MWD 13 4770.0 5805.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2606 5805 4205.5 6399 2606 5805 RPD MWD OHMM 1.26 2000 26.3627 6251 2630 5755 RPM MWD OHMM 1.54 1743.45 18.8055 6251 2630 5755 RPS MWD OHMM 2.05 129.28 16.4814 6251 2630 5755 RPX MWD OHMM 2.11 169.66 15.9514 6251 2630 5755 FET MWD HOUR 0.14 629.35 2.07683 6251 2630 5755 GR MWD API 20.76 126.62 66.5994 6285 2606 5748 ROP MWD FT/H 0.66 1098.43 215.878 6306 2652.5 5805 First Reading For Entire File..........2606 Last Reading For Entire File...........5805 File Trailer Service name .............STSLIB.001 Service Sub Level Name.. ~ • Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY for each bit run in separate files. VENDOR TOOL CODE START DEPTH GR 2606.0 FET 2630.0 RPX 2630.0 RPS 2630.0 RPM 2630.0 RPD 2630.0 ROP 2652.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) STOP DEPTH 4730.0 .4730.0 4730.0 4730.0 4730.0. 4730.0 4730.0 31-AUG-06 Insite 72.13 Memory 4730.0 2652.0 4730.0 39.9 82.9 VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: 9.875 2642.0 Fresh Water Gel 9.10 58.0 9.1 MUD CHLORIDES (PPM): • FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT RPD MWD020 RPM MWD020 RPS MWD020 RPX MWD020 FET MWD020 GR MWD020 ROP MWD020 Name Service Unit DEPT FT RPD MWD020 OHMM RPM MWD020 OHMM RPS MWD020 OHMM RPX MWD020 OHMM FET MWD020 HOUR GR MWD020 API ROP MWD020 FT/H 450 4.4 1.500 84.0 1.140 113.0 1.650 84.0 1.800 84.0 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 2606 4730 3668 4249 2606 4730 1.26 2000 22.5902 4201 2630 4730 1.54 1743.45 13.0735 4201 2630 4730 2.05 129.28 9.94464 4201 2630 4730 2.11 22.1 8.85026 4201 2630 4730 0.14 81.01 1.50442 4201 2630 4730 20.76 126.62 64.1707 4249 2606 4730 2.98 1098.43 214.589 4156 2652.5 4730 First Reading For Entire File..........2606 Last Reading For Entire File...........4730 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 • • Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 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: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 4730.5 4770.0 LOG HEADER DATA DATE LOGGED: 25-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME):. Memory TD DRILLER (FT) 4770.0 TOP LOG INTERVAL (FT) 4730.0 BOTTOM LOG INTERVAL (FT) 4770.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 76.3 MAXIMUM ANGLE: 76.3 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) 4730.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S) 61.0 MUD PH: •0 MUD CHLORIDES (PPM): 21000 FLUID LOSS (C3) • 0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): ,® REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD120 FT/H 4 1 68 4 2 • First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4730.5 4770 4750.25 80 4730.5 4770 ROP MWD120 FT/H 0.66 21.75 12.7357 80 4730.5 4770 First Reading For Entire File..........4730.5 Last Reading For Entire File...........4770 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 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: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 4730.5 5755.0 RPD 4730.5 5755.0 RPM 4730.5 5755.0 GR 4730.5 5748.0 . RPS 4730 5755.0 FET 4730.5 5755.0 ROP 4770.5 5805.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 27-SEP-06 Insite 72.13 Memory 5805.0 4770.0 5805.0 76.3 94.0 TOOL NUMBER 135134 4 167218 6.750 4730.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Mineral Oil Base 8.90 60.0 .0 22000 .0 .000 .0 .000 119.7 .000 .0 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD130 OHMM 4 1 68 4 2 ~ RPM MWD130 OHMM 1 68 8 3 RPS MWD130 OHMM 4 1 68 12 4 RPX MWD130 OHMM 4 1 68 16 5 FET MWD130 HOUR 4 1 68 20 6 GR MWD130 API 4 1 68 24 7 ROP MWD130 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4730.5 5805 5267.75 2150 4730.5 5805 RPD MWD130 OHMM 7.97 98.83 34.0936 2050 4730.5 5755 RPM MWD130 OHMM 8.2 84.23 30.552 2050 4730.5 5755 RPS MWD130 OHMM 7.96 88.59 29.8771 2050 4730.5 5755 RPX MWD130 OHMM 7.57 169.66 30.5034 2050 4730.5 5755 FET MWD130 HOUR 0.16 629.35 3.24985 2050 4730.5 5755 GR MWD130 API 48.86 102.4 71.6679 2036 4730.5 5748 ROP MWD130 FT/H 8.94 391.61 226.318 2070 4770.5 5805 First Reading For Entire File..........4730.5 Last Reading For Entire File...........5805 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library Physical EOF Physical EOF Scientific Technical Services Scientific Technical Services End Of LIS File y ~ Sperry-Sun Dri~ng Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Nov 03 13:01:37 2006 Reel Header Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: MW0004559176 LOGGING ENGINEER: B. HENNINGSE OPERATOR WITNESS: M. THORNTON • Scientific Technical Services Scientific Technical Services 1J-102L2 PB2 500292331774 ConocoPhillips Alaska, Inc. Sperry Drilling Services 03-NOV-06 MWD RUN 12 MWD RUN 13 MW0004559176 MW0004559176 R. WILSON B. HENNINGSE M. THORNTON M. THORNTON MWD RUN 14 JOB NUMBER: MW0004559176 LOGGING ENGINEER: B. HENNINGSE OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 2245 FEL: 2446 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 121.30 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS ~~ - ~~a ~ /~/a I ~ 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT S(IN) 9.875 6.750 SIZE (IN) DEPTH (FT) • 10.750 2642.0 7.625 4730.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK EXITING THE 1J-102 L2 PB1 WELLBORE AT 5640'MD/3539'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,13,14 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 13,14 ALSO INCLUDED 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 1,2,12-14 REPRESENT WELL 1J-102 L2 PB2 WITH API#: 50-029-23317-74. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9599'MD/3520'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). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2606.0 9542.0 RPS 2630.0 9549.0 RPM 2630.0 9549.0 FET 2630.0 9549.0 RPD 2630.0 9549.0 RPX 2630.0 9549.0 ROP 2652.5 9599.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 2606.0 4730.0 12 4730.5 4770.0 13 4770.0 5640.0 14 5640.5 9599.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2606 9599 6102.5 13987 2606 9599 RPD MWD OHMM 1.26 2000 43.7149 13839 2630 9549 RPM MWD OHMM 1.54 2000 37.7005 13839 2630 9549 RPS MWD OHMM 2.05 2000 37.4363 13839 2630 9549 RPX MWD OHMM 2.11 2000 37.8335 13839 2630 9549 FET MWD HOUR 0.14 629.35 1.18934 13839 2630 9549 GR MWD API 20.76 126.62 64.5882 13873 2606 9542 ROP MWD FT/H 0.66 1098.43 226.117 13894 2652.5 9599 First Reading For Entire File..........2606 Last Reading For Entire File...........9599 File Trailer • • Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2606.0 4730.0 RPM 2630.0 4730.0 RPD 2630.0 4730.0 RPX 2630.0 4730.0 FET 2630.0 4730.0 RPS 2630.0 4730.0 ROP 2652.5 4730.0 LOG HEADER DATA DATE LOGGED: 31-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4730.0 TOP LOG INTERVAL (FT) 2652.0 BOTTOM LOG INTERVAL (FT) 4730.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 39.9 MAXIMUM ANGLE: 82.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 2642.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): Fresh Water Gel 9.10 MUD VISCOSITY (S) • 58.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 450 FLUID LOSS (C3) 4.4. RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.500 84.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.140 113.0 MUD FILTRATE AT MT: 1.650 84.0 MUD CAKE AT MT: 1.800 84.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2606 4730 3668 4249 2606 4730 RPD MWD020 OHMM 1.26 2000 22.5902 4201 2630 4730 RPM MWD020 OHMM 1.54 1743.45 13.0735 4201 2630 4730 RPS MWD020 OHMM 2.05 129.28 9.94464 4201 2630 4730 RPX MWD020 OHMM 2.11 22.1 8.85026 4201 2630 4730 FET MWD020 HOUR 0.14 81.01 1.50442 4201 2630 4730 GR MWD020 API 20.76 126.62 64.1707 4249 2606 4730 ROP MWD020 FT/H 2.98 1098.43 214.589 4156 2652.5 4730 First Reading For Entire File..........2606 Last Reading For Entire File...........4730 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name..........~LIB.003 t Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 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: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 4730.5 4770.0 LOG HEADER DATA DATE LOGGED: 25-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4770.0 TOP LOG INTERVAL (FT) 4730.0 BOTTOM LOG INTERVAL (FT) 4770.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 76.3 MAXIMUM ANGLE: 76.3 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) 4730.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 61.0 MUD PH: •0 MUD CHLORIDES (PPM): 21000 FLUID LOSS (C3) •0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD120 FT/H 4 1 68 4 2 r1 ~J First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4730.5 4770 4750.25 80 4730.5 4770 ROP MWD120 FT/H 0.66 21.75 12.7357 80 4730.5 4770 First Reading For Entire File..........4730.5 Last Reading For Entire File...........4770 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 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: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4730.5 5640.0 FET 4730.5 5640.0 . RPX 4730 5640.0 RPD 4730.5 5640.0 RPS 4730.5 5640.0 RPM 4730.5 5640.0 ROP 4770.5 5640.0 LOG HEADER DATA DATE LOGGED: 26-SEP- 06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5640.0 TOP LOG INTERVAL (FT) 4770.0 BOTTOM LOG INTERVAL (FT) 5640.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 76.3 MAXIMUM ANGLE: 94.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 4730.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.90 MUD VISCOSITY (S) 60.0 MUD PH: •0 MUD CHLORIDES (PPM): 22000 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 119.7 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel ~ DEPT FT 1 68 0 1 RPD MWD130 OHMM 4 1 68 4 2 RPM MWD130 OHMM 4 1 68 8 3 RPS MWD130 OHMM 4 1 68 12 4 RPX MWD130 OHMM 4 1 68 16 5 FET MWD130 HOUR 4 1 68 20 6 GR MWD130 API 4 1 68 24 7 ROP MWD130 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4730.5 5640 5185.25 1820 4730.5 5640 RPD MWD130 OHMM 7.97 67.36 30.0449 1820 4730.5 5640 RPM MWD130 OHMM 8.2 59.91 27.1616 1820 4730.5 5640 RPS MWD130 OHMM 7.96 62.02 26.5138 1820 4730.5 5640 RPX MWD130 OHMM 7.57 169.66 26.9791 1820 4730.5 5640 FET MWD130 HOUR 0.16 629.35 3.59799 1820 4730.5 5640 GR MWD130 API 48.86 102.4 72.602 1820 4730.5 5640 ROP MWD130 FT/H 17.88 385.36 226.169 1740 4770.5 5640 First Reading For Entire File..........4730.5 Last Reading For Entire File...........5640 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 14 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 5640.5 9549.0 ROP 5640.5 9599.0 RPD 5640.5 9549.0 GR 5640.5 9542.0 RPM 5640.5 9549.0 FET 5640.5 9549.0 RPS 5640.5 9549.0 ~ • LOG HEADER DATA DATE LOGGED: 28-SEP- 06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9599.0 TOP LOG INTERVAL (FT) 5640.0 BOTTOM LOG INTERVAL (FT) 9599.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.5 MAXIMUM ANGLE: 94.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 4730.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 60.0 MUD PH: .0 MUD CHLORIDES (PPM): 19000 FLUID LOSS (C3) •0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 119.7 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD140 OHMM 4 1 68 4 2 RPM MWD140 OHMM 4 1 68 8 3 RPS MWD140 OHMM 4 1 68 12 4 RPX MWD140 OHMM 4 1 68 16 5 FET MWD140 HOUR 4 1 68 20 6 GR MWD140 API 4 1 68 24 7 ROP MWD140 FT/H ~ 1 68 28 8 • First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5640.5 9599 7619.75 7918 5640.5 9599 RPD MWD140 OHMM 26.68 381.02 58.2486 7818 5640.5 9549 RPM MWD140 OHMM 25.25 2000 53.3873 7818 5640.5 9549 RPS MWD140 OHMM 12.56 2000 54.7516 7818 5640.5 9549 RPX MWD140 OHMM 20.9 2000 55.9345 7818 5640.5 9549 FET MWD140 HOUR 0.17 2.74 0.459309 7818 5640.5 9549 GR MWD140 API 40.32 84.97 62.9467 7804 5640.5 9542 ROP MWD140 FT/H 3.74 473.23 234.313 7918 5640.5 9599 First Reading For Entire File..........5640.5 Last Reading For Entire File...........9599 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date........ ..............06/11/03 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library Physical EOF Physical EOF Scientific Technical Services Scientific Technical Services End Of LIS File
