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Home My WebLink About206-0071. 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 10884'feet None feet true vertical 3426' feet None feet Effective Depth measured 10884'feet 4194', 4200'feet true vertical 3426' feet 3467', 3469' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 4222' MD 3475' TVD Packers and SSSV (type, measured and true vertical depth) 4194' MD 4200' MD N/A 3467' TVD 3469' 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: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 766 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker GBH-22 Packer Packer: ZXP Liner Top Packer SSSV: None Allen Eschete allen.eschete@conocophillips.com (907) 265-6558Interventions Engineer Slotted Liner: 4890-7847', 8174-10823' Slotted Liner: 3503-3444', 3459-3431' 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) 474 Gas-Mcf MD 622 Size 108' 2287 9201073 441 198799 224 measured TVD 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 206-007 50-029-23297-61-00 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-159L2 Plugs Junk measured Length Production D Sand Liner 5548' 6618' Casing 3695' 4-1/2" 5575' 10860' 3428' 2333' 108'Conductor Surface Intermediate 20" 10-3/4" 77' 2364' 2206' Burst Collapse 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 12:00 pm, May 14, 2024 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 16:02:31-08'00' Foxit PDF Editor Version: 13.0.0 Allen Eschete RBDMS JSB 051524 DSR-5/14/24 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-102/1J-159(off set) RPPG Summary of Operations DTTMSTART JOBTYP SUMMARYOPS Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-159 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Recovered lost Type II diverter 1J-159 8/15/2021 appleha Notes: General & Safety Annotation End Date Last Mod By NOTE: PULLED B LAT ISO SLEEVE 6/7/2013 pproven NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0REV 2/21/2009 lmosbor NOTE: MULTI-LATERAL WELL: 1J-159 (A-SAND), 1J-159L1 (B-SAND), 1J-159L2 (D-SAND) 5/11/2006 WV5.3 Conversio n 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 18.94 31.0 108.0 108.0 62.60 H-40 WELDED SURFACE 10 3/4 9.95 31.2 2,364.5 2,206.4 45.50 L-80 BTC PRODUCTION 7 5/8 6.87 26.6 5,575.1 3,695.3 29.70 L-80 BTCM L2 LINER LEM 4 1/2 3.96 4,189.2 4,386.3 3,515.8 12.60 L-80 IBT L1 LINER HH LEM 4 1/2 3.96 4,355.1 4,705.5 3,571.1 12.60 L-80 IBT A-SAND LINER 4 1/2 3.96 4,666.1 7,842.1 3,642.2 12.60 L-80 IBT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 22.6 Set Depth … 4,222.2 Set Depth … 3,475.2 String Max No… 4 1/2 Tubing Description TUBING WO Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 22.6 22.6 0.00 HANGER 10.800 TUBING HANGER T&C Non- Upset 3.958 515.0 514.8 5.01 NIPPLE 5.210 CAMCO 'DB' NIPPLE 3.875 2,589.4 2,407.6 26.19 GAS LIFT 5.984 CAMCO KBG-2- 1R 3.938 4,093.6 3,434.6 69.05 GAS LIFT 5.984 CAMCO KBG-2- 1R 3.938 4,137.2 3,449.6 70.75 NIPPLE 5.210 CAMCO DB Nipple 3.812 4,147.6 3,453.0 71.16 GAUGE 6.700 GUARDIAN GAUGE CARRIER 3.850 4,193.8 3,467.2 73.06 LOCATOR 5.200 LOCATOR 3.880 4,194.5 3,467.4 73.08 SEAL ASSY 4.750 BAKER GBH-22 PACKER 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) 23.0 23.0 0.00 HEAT TRACE HEAT TRACE SET DURING 1/23/2008 WORKOVER 1/24/2008 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,589.4 2,407.6 26.19 1 GAS LIFT GLV BK-5 1 1,530.0 2/19/2008 0.156 4,093.6 3,434.6 69.05 2 GAS LIFT OV BK 1 0.0 5/19/2016 0.219 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) 4,189.2 3,465.9 72.86 PBR 6.410 BAKER 190-47 PBR 5.750 4,200.2 3,469.1 73.32 PACKER 6.550 ZXP LINER TOP PACKER 4.950 4,227.5 3,476.6 74.48 XO Bushing 6.060 3.958 4,355.1 3,508.4 75.80 PACKER 7.500 ZXP LINER TOP PACKER 4.950 4,372.3 3,512.6 76.38 SBR 6.280 109-47 CASING SEAL BORE RECEPTACLE 4.750 4,391.9 3,517.1 77.04 XO BUSHING 6.060 CROSSOVER BUSHING 3.910 4,550.3 3,547.9 79.90 ABOVE HH 8.470 LEM ABOVE HOOK HANGER 4.020 4,560.9 3,549.7 80.16 INSIDE HH 8.470 LEM INSIDE HOOK HANGER 4.020 4,626.4 3,560.0 81.80 NIPPLE 5.000 CAMCO 'DB' NIPPLE 3.562 4,666.1 3,565.6 81.92 PACKER 6.540 "HRD" ZXP Liner Top Packer 5.5" X 7.6" 4.970 4,685.1 3,568.2 81.94 NIPPLE 6.070 "RS" Packoff Seal Nipple 5.5" 4.875 4,717.4 3,572.8 81.99 XO BUSHING 6.020 XO Bushing 3.92" ID, 6.02 OD 3.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,567.0 5,721.0 3,695.2 3,697.2 WS A2, 1J-159 2/23/2006 32.0 SLOTS SLOTTED LINER 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 5,845.0 6,091.0 3,694.4 3,688.1 WS A2, 1J-159 2/23/2006 32.0 SLOTS 6,399.0 7,810.0 3,681.8 3,642.2 WS A2, 1J-159 2/23/2006 32.0 SLOTS MULTIPLE LATERALS, 1J-159, 5/3/2024 12:37:59 PM Vertical schematic (actual) A-SAND LINER; 4,666.1-7,842.1 SLOTS; 6,399.0-7,810.0 SLOTS; 5,845.0-6,091.0 SLOTS; 5,567.0-5,721.0 PRODUCTION; 26.6-5,575.1 L1 LINER HH LEM; 4,355.1- 4,705.5 B-SAND LINER; 4,560.2- 11,161.1 L2 LINER LEM; 4,189.2-4,386.3 D-SAND LINER; 4,241.4- 10,859.6 GAUGE; 4,147.6 GAS LIFT; 4,093.6 GAS LIFT; 2,589.4 SURFACE; 31.2-2,364.5 HEAT TRACE; 23.0 NIPPLE; 515.0 CONDUCTOR; 31.0-108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 3/13/2006 Other Elev… 1J-159 ... TD Act Btm (ftKB) 7,857.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329700 Wellbore Status PROD Max Angle & MD Incl (°) 93.86 MD (ftKB) 6,310.37 WELLNAME WELLBORE1J-159 Annotation Last WO: End Date 1/28/2008 H2S (ppm) 60 Date 8/11/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-159L1 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: WELL REVIEW 1J-159L1 2/9/2011 osborl Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0REV 2/21/2009 lmosbor NOTE: MULTI-LATERAL WELL: 1J-159 (A-SAND), 1J-159L1 (B-SAND), 1J-159L2 (D-SAND) 3/12/2006 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread B-SAND LINER 4 1/2 3.96 4,560.2 11,161.1 3,506.3 12.60 L-80 BTC Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,585.2 3,553.6 81.67 SWIVEL 5.750 BAKER CASING SWIVEL 3.920 11,126.5 3,506.8 90.57 Cross over 3.500 4-1/2" IBT Box x 3-1/2" IBT Pin Crossover 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 4,590.0 4,633.0 3,554.3 3,559.1 WS B, 1J-159L1 3/3/2006 32.0 SLOTS SLOTTED LINER 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 4,643.0 7,891.0 3,559.9 3,510.6 WS B, 1J-159L1 3/3/2006 32.0 SLOTS 8,278.0 10,504.0 3,524.7 3,500.4 WS B, 1J-159L1 3/3/2006 32.0 SLOTS 10,506.0 11,127.0 3,500.5 3,506.8 WS B, 1J-159L1 3/3/2006 32.0 SLOTS MULTIPLE LATERALS, 1J-159L1, 5/3/2024 12:38:00 PM Vertical schematic (actual) B-SAND LINER; 4,560.2- 11,161.1 SLOTS; 10,506.0-11,127.0 SLOTS; 8,278.0-10,504.0 SLOTS; 4,643.0-7,891.0 SLOTS; 4,590.0-4,633.0 PRODUCTION; 26.6-5,575.1 L1 LINER HH LEM; 4,355.1- 4,705.5 L2 LINER LEM; 4,189.2-4,386.3 D-SAND LINER; 4,241.4- 10,859.6 GAUGE; 4,147.6 GAS LIFT; 4,093.6 GAS LIFT; 2,589.4 SURFACE; 31.2-2,364.5 HEAT TRACE; 23.0 NIPPLE; 515.0 CONDUCTOR; 31.0-108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 3/13/2006 Other Elev… 1J-159L1 ... TD Act Btm (ftKB) 11,187.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329760 Wellbore Status PROD Max Angle & MD Incl (°) 92.41 MD (ftKB) 7,600.66 WELLNAME WELLBORE1J-159 Annotation Last WO: End Date 1/23/2008 H2S (ppm) 60 Date 8/11/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-159L2 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: WELL REVIEW 1J-159L2 5/10/2013 osborl Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0REV 2/21/2009 lmosbor NOTE: MULTI-LATERAL WELL: 1J-159 (A-SAND), 1J-159L1 (B-SAND), 1J-159L2 (D-SAND) 3/12/2006 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread D-SAND LINER 4 1/2 3.96 4,241.4 10,859.6 3,427.7 11.60 L-80 BTC Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,266.4 3,486.4 76.78 SWIVEL 5.750 BAKER CSG SWIVEL - TENSION LOCK 3.960 4,320.8 3,497.0 80.81 SWELL PKR 6.300 3.960 4,876.8 3,503.3 91.74 SWELL PKR 6.300 3.960 10,825.3 3,430.4 94.42 XO Reducing 4.500 CROSSOVER 4.5x3.5" 3.958 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 4,890.0 7,847.0 3,502.9 3,443.6 WS D, 1J-159L2 3/10/2006 32.0 SLOTS SLOTTED LINER 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,174.0 10,823.0 3,459.1 3,430.6 WS D, 1J-159L2 3/10/2006 32.0 SLOTS MULTIPLE LATERALS, 1J-159L2, 5/3/2024 12:38:01 PM Vertical schematic (actual) D-SAND LINER; 4,241.4- 10,859.6 SLOTS; 8,174.0-10,823.0 SLOTS; 4,890.0-7,847.0 PRODUCTION; 26.6-5,575.1 L2 LINER LEM; 4,189.2-4,386.3 GAUGE; 4,147.6 GAS LIFT; 4,093.6 GAS LIFT; 2,589.4 SURFACE; 31.2-2,364.5 HEAT TRACE; 23.0 NIPPLE; 515.0 CONDUCTOR; 31.0-108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 3/13/2006 Other Elev… 1J-159L2 ... TD Act Btm (ftKB) 10,884.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329761 Wellbore Status PROD Max Angle & MD Incl (°) 94.51 MD (ftKB) 10,841.96 WELLNAME WELLBORE1J-159 Annotation Last WO: End Date 1/23/2008 H2S (ppm) 60 Date 8/11/2015 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 10884'feet None feet true vertical 3426' feet None feet Effective Depth measured 10884'feet 4194', 4200'feet true vertical 3426' feet 3467', 3469' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 4222' MD 3475' TVD Packers and SSSV (type, measured and true vertical depth) 4194' MD 4200' MD N/A 3467' TVD 3469' 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: 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: Baker GBH-22 Packer Packer: ZXP Liner Top Packer SSSV: None Allen Eschete allen.eschete@conocophillips.com (907) 265-6558Interventions Engineer Slotted Liner: 4890-7847', 8174-10823' Slotted Liner: 3503-3444', 3459-3431' 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 108' ~ ~~ Well Remains Shut-In ~~ ~ measured TVD 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 206-007 50-029-23297-61-00 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-159L2 Plugs Junk measured Length Production D Sand Liner 5548' 6618' Casing 3695' 4-1/2" 5575' 10860' 3428' 2333' 108'Conductor Surface Intermediate 20" 10-3/4" 77' 2364' 2206' Burst Collapse 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 3:17 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 14:58:21-09'00' 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-159 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Recovered lost Type II diverter 1J-159 8/15/2021 appleha Notes: General & Safety Annotation End Date Last Mod By NOTE: PULLED B LAT ISO SLEEVE 6/7/2013 pproven NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0REV 2/21/2009 lmosbor NOTE: MULTI-LATERAL WELL: 1J-159 (A-SAND), 1J-159L1 (B-SAND), 1J-159L2 (D-SAND) 5/11/2006 WV5.3 Conversio n 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 18.94 31.0 108.0 108.0 62.60 H-40 WELDED SURFACE 10 3/4 9.95 31.2 2,364.5 2,206.4 45.50 L-80 BTC PRODUCTION 7 5/8 6.87 26.6 5,575.1 3,695.3 29.70 L-80 BTCM L2 LINER LEM 4 1/2 3.96 4,189.2 4,386.3 3,515.8 12.60 L-80 IBT L1 LINER HH LEM 4 1/2 3.96 4,355.1 4,705.5 3,571.1 12.60 L-80 IBT A-SAND LINER 4 1/2 3.96 4,666.1 7,842.1 3,642.2 12.60 L-80 IBT Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 22.6 Set Depth 4,222.2 Set Depth 3,475.2 String Ma 4 1/2 Tubing Description TUBING WO Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 22.6 22.6 0.00 HANGER 10.800 TUBING HANGER T&C Non- Upset 3.958 515.0 514.8 5.01 NIPPLE 5.210 CAMCO 'DB' NIPPLE 3.875 2,589.4 2,407.6 26.19 GAS LIFT 5.984 CAMCO KBG-2- 1R 3.938 4,093.6 3,434.6 69.05 GAS LIFT 5.984 CAMCO KBG-2- 1R 3.938 4,137.2 3,449.6 70.75 NIPPLE 5.210 CAMCO DB Nipple 3.812 4,147.6 3,453.0 71.16 GAUGE 6.700 GUARDIAN GAUGE CARRIER 3.850 4,193.8 3,467.2 73.06 LOCATOR 5.200 LOCATOR 3.880 4,194.5 3,467.4 73.08 SEAL ASSY 4.750 BAKER GBH-22 PACKER 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) 23.0 23.0 0.00 HEAT TRACE HEAT TRACE SET DURING 1/23/2008 WORKOVER 1/24/2008 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,589.4 2,407.6 26.19 1 GAS LIFT GLV BK-5 1 1,530.0 2/19/2008 0.156 4,093.6 3,434.6 69.05 2 GAS LIFT OV BK 1 0.0 5/19/2016 0.219 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) 4,189.2 3,465.9 72.86 PBR 6.410 BAKER 190-47 PBR 5.750 4,200.2 3,469.1 73.32 PACKER 6.550 ZXP LINER TOP PACKER 4.950 4,227.5 3,476.6 74.48 XO Bushing 6.060 3.958 4,355.1 3,508.4 75.80 PACKER 7.500 ZXP LINER TOP PACKER 4.950 4,372.3 3,512.6 76.38 SBR 6.280 109-47 CASING SEAL BORE RECEPTACLE 4.750 4,391.9 3,517.1 77.04 XO BUSHING 6.060 CROSSOVER BUSHING 3.910 4,550.3 3,547.9 79.90 ABOVE HH 8.470 LEM ABOVE HOOK HANGER 4.020 4,560.9 3,549.7 80.16 INSIDE HH 8.470 LEM INSIDE HOOK HANGER 4.020 4,626.4 3,560.0 81.80 NIPPLE 5.000 CAMCO 'DB' NIPPLE 3.562 4,666.1 3,565.6 81.92 PACKER 6.540 "HRD" ZXP Liner Top Packer 5.5" X 7.6" 4.970 4,685.1 3,568.2 81.94 NIPPLE 6.070 "RS" Packoff Seal Nipple 5.5" 4.875 4,717.4 3,572.8 81.99 XO BUSHING 6.020 XO Bushing 3.92" ID, 6.02 OD 3.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,567.0 5,721.0 3,695.2 3,697.2 WS A2, 1J-159 2/23/2006 32.0 SLOTS SLOTTED LINER 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 5,845.0 6,091.0 3,694.4 3,688.1 WS A2, 1J-159 2/23/2006 32.0 SLOTS 6,399.0 7,810.0 3,681.8 3,642.2 WS A2, 1J-159 2/23/2006 32.0 SLOTS MULTIPLE LATERALS, 1J-159, 7/26/2023 1:16:59 PM Vertical schematic (actual) A-SAND LINER; 4,666.1-7,842.1 SLOTS; 6,399.0-7,810.0 SLOTS; 5,845.0-6,091.0 SLOTS; 5,567.0-5,721.0 PRODUCTION; 26.6-5,575.1 L1 LINER HH LEM; 4,355.1- 4,705.5 B-SAND LINER; 4,560.2- 11,161.1 L2 LINER LEM; 4,189.2-4,386.3 D-SAND LINER; 4,241.4- 10,859.6 GAUGE; 4,147.6 GAS LIFT; 4,093.6 GAS LIFT; 2,589.4 SURFACE; 31.2-2,364.5 HEAT TRACE; 23.0 NIPPLE; 515.0 CONDUCTOR; 31.0-108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 3/13/2006 Other Elev 1J-159 ... TD Act Btm (ftKB) 7,857.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329700 Wellbore Status PROD Max Angle & MD Incl (°) 93.86 MD (ftKB) 6,310.37 WELLNAME WELLBORE1J-159 Annotation Last WO: End Date 1/28/2008 H2S (ppm) 60 Date 8/11/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1J-159L1 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: WELL REVIEW 1J-159L1 2/9/2011 osborl Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0REV 2/21/2009 lmosbor NOTE: MULTI-LATERAL WELL: 1J-159 (A-SAND), 1J-159L1 (B-SAND), 1J-159L2 (D-SAND) 3/12/2006 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread B-SAND LINER 4 1/2 3.96 4,560.2 11,161.1 3,506.3 12.60 L-80 BTC Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,585.2 3,553.6 81.67 SWIVEL 5.750 BAKER CASING SWIVEL 3.920 11,126.5 3,506.8 90.57 Cross over 3.500 4-1/2" IBT Box x 3-1/2" IBT Pin Crossover 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 4,590.0 4,633.0 3,554.3 3,559.1 WS B, 1J-159L1 3/3/2006 32.0 SLOTS SLOTTED LINER 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 4,643.0 7,891.0 3,559.9 3,510.6 WS B, 1J-159L1 3/3/2006 32.0 SLOTS 8,278.0 10,504.0 3,524.7 3,500.4 WS B, 1J-159L1 3/3/2006 32.0 SLOTS 10,506.0 11,127.0 3,500.5 3,506.8 WS B, 1J-159L1 3/3/2006 32.0 SLOTS MULTIPLE LATERALS, 1J-159L1, 7/26/2023 1:16:59 PM Vertical schematic (actual) B-SAND LINER; 4,560.2- 11,161.1 SLOTS; 10,506.0-11,127.0 SLOTS; 8,278.0-10,504.0 SLOTS; 4,643.0-7,891.0 SLOTS; 4,590.0-4,633.0 PRODUCTION; 26.6-5,575.1 L1 LINER HH LEM; 4,355.1- 4,705.5 L2 LINER LEM; 4,189.2-4,386.3 D-SAND LINER; 4,241.4- 10,859.6 GAUGE; 4,147.6 GAS LIFT; 4,093.6 GAS LIFT; 2,589.4 SURFACE; 31.2-2,364.5 HEAT TRACE; 23.0 NIPPLE; 515.0 CONDUCTOR; 31.0-108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 3/13/2006 Other Elev 1J-159L1 ... TD Act Btm (ftKB) 11,187.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329760 Wellbore Status PROD Max Angle & MD Incl (°) 92.41 MD (ftKB) 7,600.66 WELLNAME WELLBORE1J-159 Annotation Last WO: End Date 1/23/2008 H2S (ppm) 60 Date 8/11/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1J-159L2 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: WELL REVIEW 1J-159L2 5/10/2013 osborl Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0REV 2/21/2009 lmosbor NOTE: MULTI-LATERAL WELL: 1J-159 (A-SAND), 1J-159L1 (B-SAND), 1J-159L2 (D-SAND) 3/12/2006 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread D-SAND LINER 4 1/2 3.96 4,241.4 10,859.6 3,427.7 11.60 L-80 BTC Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,266.4 3,486.4 76.78 SWIVEL 5.750 BAKER CSG SWIVEL - TENSION LOCK 3.960 4,320.8 3,497.0 80.81 SWELL PKR 6.300 3.960 4,876.8 3,503.3 91.74 SWELL PKR 6.300 3.960 10,825.3 3,430.4 94.42 XO Reducing 4.500 CROSSOVER 4.5x3.5" 3.958 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 4,890.0 7,847.0 3,502.9 3,443.6 WS D, 1J-159L2 3/10/2006 32.0 SLOTS SLOTTED LINER 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,174.0 10,823.0 3,459.1 3,430.6 WS D, 1J-159L2 3/10/2006 32.0 SLOTS MULTIPLE LATERALS, 1J-159L2, 7/26/2023 1:17:00 PM Vertical schematic (actual) D-SAND LINER; 4,241.4- 10,859.6 SLOTS; 8,174.0-10,823.0 SLOTS; 4,890.0-7,847.0 PRODUCTION; 26.6-5,575.1 L2 LINER LEM; 4,189.2-4,386.3 GAUGE; 4,147.6 GAS LIFT; 4,093.6 GAS LIFT; 2,589.4 SURFACE; 31.2-2,364.5 HEAT TRACE; 23.0 NIPPLE; 515.0 CONDUCTOR; 31.0-108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 3/13/2006 Other Elev 1J-159L2 ... TD Act Btm (ftKB) 10,884.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329761 Wellbore Status PROD Max Angle & MD Incl (°) 94.51 MD (ftKB) 10,841.96 WELLNAME WELLBORE1J-159 Annotation Last WO: End Date 1/23/2008 H2S (ppm) 60 Date 8/11/2015 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 10884'feet feet true vertical 3426' feet feet Effective Depth measured 10884'feet feet true vertical 3426' feet feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 4222' MD Packers and SSSV (type, measured and true vertical depth) 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: 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 Allen Eschete allen.eschete@conocophillips.com (907) 265-6558Interventions Engineer Slotted Liner: 4890-7847', 8174-10823' Slotted Liner: 3503-3444', 3459-3431' 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 108' ~ ~~ Well Remains Shut-In ~~ ~ measured TVD 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 206-007 50-029-23297-61-00 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-159L2 Plugs Junk measured Length Production D Sand Liner 5548' 6618' Casing 3695' 4-1/2" 5575' 10860' 3428' 2333' 108'Conductor Surface Intermediate 20" 10-3/4" 77' 2364' 2206' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov None None 4194', 4200' 3467', 3469' Packer: Baker GBH-22 Packer Packer: ZXP Liner Top Packer SSSV: None 4194' MD 4200' MD N/A 3475' TVD 3467' TVD 3469' TVD N/A By Grace Christianson at 3:04 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 09:34:52-08'00' 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-159 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Recovered lost Type II diverter 1J-159 8/15/2021 appleha Notes: General & Safety Annotation End Date Last Mod By NOTE: PULLED B LAT ISO SLEEVE 6/7/2013 pproven NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0REV 2/21/2009 lmosbor NOTE: MULTI-LATERAL WELL: 1J-159 (A-SAND), 1J-159L1 (B-SAND), 1J-159L2 (D-SAND) 5/11/2006 WV5.3 Conversio n 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 18.94 31.0 108.0 108.0 62.60 H-40 WELDED SURFACE 10 3/4 9.95 31.2 2,364.5 2,206.4 45.50 L-80 BTC PRODUCTION 7 5/8 6.87 26.6 5,575.1 3,695.3 29.70 L-80 BTCM L2 LINER LEM 4 1/2 3.96 4,189.2 4,386.3 3,515.8 12.60 L-80 IBT L1 LINER HH LEM 4 1/2 3.96 4,355.1 4,705.5 3,571.1 12.60 L-80 IBT A-SAND LINER 4 1/2 3.96 4,666.1 7,842.1 3,642.2 12.60 L-80 IBT Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 22.6 Set Depth 4,222.2 Set Depth 3,475.2 String Ma 4 1/2 Tubing Description TUBING WO Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 22.6 22.6 0.00 HANGER 10.800 TUBING HANGER T&C Non- Upset 3.958 515.0 514.8 5.01 NIPPLE 5.210 CAMCO 'DB' NIPPLE 3.875 2,589.4 2,407.6 26.19 GAS LIFT 5.984 CAMCO KBG-2- 1R 3.938 4,093.6 3,434.6 69.05 GAS LIFT 5.984 CAMCO KBG-2- 1R 3.938 4,137.2 3,449.6 70.75 NIPPLE 5.210 CAMCO DB Nipple 3.812 4,147.6 3,453.0 71.16 GAUGE 6.700 GUARDIAN GAUGE CARRIER 3.850 4,193.8 3,467.2 73.06 LOCATOR 5.200 LOCATOR 3.880 4,194.5 3,467.4 73.08 SEAL ASSY 4.750 BAKER GBH-22 PACKER 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) 23.0 23.0 0.00 HEAT TRACE HEAT TRACE SET DURING 1/23/2008 WORKOVER 1/24/2008 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,589.4 2,407.6 26.19 1 GAS LIFT GLV BK-5 1 1,530.0 2/19/2008 0.156 4,093.6 3,434.6 69.05 2 GAS LIFT OV BK 1 0.0 5/19/2016 0.219 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) 4,189.2 3,465.9 72.86 PBR 6.410 BAKER 190-47 PBR 5.750 4,200.2 3,469.1 73.32 PACKER 6.550 ZXP LINER TOP PACKER 4.950 4,227.5 3,476.6 74.48 XO Bushing 6.060 3.958 4,355.1 3,508.4 75.80 PACKER 7.500 ZXP LINER TOP PACKER 4.950 4,372.3 3,512.6 76.38 SBR 6.280 109-47 CASING SEAL BORE RECEPTACLE 4.750 4,391.9 3,517.1 77.04 XO BUSHING 6.060 CROSSOVER BUSHING 3.910 4,550.3 3,547.9 79.90 ABOVE HH 8.470 LEM ABOVE HOOK HANGER 4.020 4,560.9 3,549.7 80.16 INSIDE HH 8.470 LEM INSIDE HOOK HANGER 4.020 4,626.4 3,560.0 81.80 NIPPLE 5.000 CAMCO 'DB' NIPPLE 3.562 4,666.1 3,565.6 81.92 PACKER 6.540 "HRD" ZXP Liner Top Packer 5.5" X 7.6" 4.970 4,685.1 3,568.2 81.94 NIPPLE 6.070 "RS" Packoff Seal Nipple 5.5" 4.875 4,717.4 3,572.8 81.99 XO BUSHING 6.020 XO Bushing 3.92" ID, 6.02 OD 3.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,567.0 5,721.0 3,695.2 3,697.2 WS A2, 1J-159 2/23/2006 32.0 SLOTS SLOTTED LINER 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 5,845.0 6,091.0 3,694.4 3,688.1 WS A2, 1J-159 2/23/2006 32.0 SLOTS 6,399.0 7,810.0 3,681.8 3,642.2 WS A2, 1J-159 2/23/2006 32.0 SLOTS MULTIPLE LATERALS, 1J-159, 7/26/2023 1:16:59 PM Vertical schematic (actual) A-SAND LINER; 4,666.1-7,842.1 SLOTS; 6,399.0-7,810.0 SLOTS; 5,845.0-6,091.0 SLOTS; 5,567.0-5,721.0 PRODUCTION; 26.6-5,575.1 L1 LINER HH LEM; 4,355.1- 4,705.5 B-SAND LINER; 4,560.2- 11,161.1 L2 LINER LEM; 4,189.2-4,386.3 D-SAND LINER; 4,241.4- 10,859.6 GAUGE; 4,147.6 GAS LIFT; 4,093.6 GAS LIFT; 2,589.4 SURFACE; 31.2-2,364.5 HEAT TRACE; 23.0 NIPPLE; 515.0 CONDUCTOR; 31.0-108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 3/13/2006 Other Elev 1J-159 ... TD Act Btm (ftKB) 7,857.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329700 Wellbore Status PROD Max Angle & MD Incl (°) 93.86 MD (ftKB) 6,310.37 WELLNAME WELLBORE1J-159 Annotation Last WO: End Date 1/28/2008 H2S (ppm) 60 Date 8/11/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1J-159L1 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: WELL REVIEW 1J-159L1 2/9/2011 osborl Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0REV 2/21/2009 lmosbor NOTE: MULTI-LATERAL WELL: 1J-159 (A-SAND), 1J-159L1 (B-SAND), 1J-159L2 (D-SAND) 3/12/2006 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread B-SAND LINER 4 1/2 3.96 4,560.2 11,161.1 3,506.3 12.60 L-80 BTC Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,585.2 3,553.6 81.67 SWIVEL 5.750 BAKER CASING SWIVEL 3.920 11,126.5 3,506.8 90.57 Cross over 3.500 4-1/2" IBT Box x 3-1/2" IBT Pin Crossover 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 4,590.0 4,633.0 3,554.3 3,559.1 WS B, 1J-159L1 3/3/2006 32.0 SLOTS SLOTTED LINER 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 4,643.0 7,891.0 3,559.9 3,510.6 WS B, 1J-159L1 3/3/2006 32.0 SLOTS 8,278.0 10,504.0 3,524.7 3,500.4 WS B, 1J-159L1 3/3/2006 32.0 SLOTS 10,506.0 11,127.0 3,500.5 3,506.8 WS B, 1J-159L1 3/3/2006 32.0 SLOTS MULTIPLE LATERALS, 1J-159L1, 7/26/2023 1:16:59 PM Vertical schematic (actual) B-SAND LINER; 4,560.2- 11,161.1 SLOTS; 10,506.0-11,127.0 SLOTS; 8,278.0-10,504.0 SLOTS; 4,643.0-7,891.0 SLOTS; 4,590.0-4,633.0 PRODUCTION; 26.6-5,575.1 L1 LINER HH LEM; 4,355.1- 4,705.5 L2 LINER LEM; 4,189.2-4,386.3 D-SAND LINER; 4,241.4- 10,859.6 GAUGE; 4,147.6 GAS LIFT; 4,093.6 GAS LIFT; 2,589.4 SURFACE; 31.2-2,364.5 HEAT TRACE; 23.0 NIPPLE; 515.0 CONDUCTOR; 31.0-108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 3/13/2006 Other Elev 1J-159L1 ... TD Act Btm (ftKB) 11,187.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329760 Wellbore Status PROD Max Angle & MD Incl (°) 92.41 MD (ftKB) 7,600.66 WELLNAME WELLBORE1J-159 Annotation Last WO: End Date 1/23/2008 H2S (ppm) 60 Date 8/11/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1J-159L2 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: WELL REVIEW 1J-159L2 5/10/2013 osborl Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0REV 2/21/2009 lmosbor NOTE: MULTI-LATERAL WELL: 1J-159 (A-SAND), 1J-159L1 (B-SAND), 1J-159L2 (D-SAND) 3/12/2006 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread D-SAND LINER 4 1/2 3.96 4,241.4 10,859.6 3,427.7 11.60 L-80 BTC Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,266.4 3,486.4 76.78 SWIVEL 5.750 BAKER CSG SWIVEL - TENSION LOCK 3.960 4,320.8 3,497.0 80.81 SWELL PKR 6.300 3.960 4,876.8 3,503.3 91.74 SWELL PKR 6.300 3.960 10,825.3 3,430.4 94.42 XO Reducing 4.500 CROSSOVER 4.5x3.5" 3.958 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 4,890.0 7,847.0 3,502.9 3,443.6 WS D, 1J-159L2 3/10/2006 32.0 SLOTS SLOTTED LINER 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,174.0 10,823.0 3,459.1 3,430.6 WS D, 1J-159L2 3/10/2006 32.0 SLOTS MULTIPLE LATERALS, 1J-159L2, 7/26/2023 1:17:00 PM Vertical schematic (actual) D-SAND LINER; 4,241.4- 10,859.6 SLOTS; 8,174.0-10,823.0 SLOTS; 4,890.0-7,847.0 PRODUCTION; 26.6-5,575.1 L2 LINER LEM; 4,189.2-4,386.3 GAUGE; 4,147.6 GAS LIFT; 4,093.6 GAS LIFT; 2,589.4 SURFACE; 31.2-2,364.5 HEAT TRACE; 23.0 NIPPLE; 515.0 CONDUCTOR; 31.0-108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 3/13/2006 Other Elev 1J-159L2 ... TD Act Btm (ftKB) 10,884.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329761 Wellbore Status PROD Max Angle & MD Incl (°) 94.51 MD (ftKB) 10,841.96 WELLNAME WELLBORE1J-159 Annotation Last WO: End Date 1/23/2008 H2S (ppm) 60 Date 8/11/2015 Comment SSSV: NIPPLE STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate r . Other Pull L1 -LEM Pull Tubing Stimulate - Frac Waiver Isolation Sleeve Alter Casing ,I g r r r Time Extension �' (B -sand) Change Approved R - ogram r Operat. Shutdown r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. ' • Development p. Exploratory r _ 206 -007 - 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service (' 50- 029 - 23297 -61 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL025661; ADL025662 1J -159L2 • 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Kuparuk River Field / West Sak Oil Pool , 11. Present Well Condition Summary: Total Depth measured 10884 • feet Plugs (measured) None true vertical 3426 feet Junk (measured) None Effective Depth measured 10585 feet Packer (measured) 4200 true vertical 3428 feet (true vertical) 3469 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20 108 108 0 0 SURFACE 2333 18.125 2364 2206 0 0 PRODUCTION 4219 7.625 4246 3481 0 0 L2 LINER LEM 57 6.61 4246 3481 0 0 D -SAND LINER 6618 8.47 10860 3428 0 0 SCANNED JUN 1 8 2013 Perforation depth: Measured depth: 4890 8174 - 10823 C � j� /� True Vertical Depth: 3503 -3444; 3459 -3430 D J(/ I /� N 1 2013 Tubing (size, grade, MD, and TVD) 4.5, L - 80, 4222 MD, 3467 TVD AOQf1/1 - Packers & SSSV (type, MD, and TVD) PACKER - ZXP LINER TOP PKR @ 4200 MD and 3469 TVD VV� NIPPLE - CAMCO DB NIPPLE @ 4137 MD and 3450 TVD 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 Casing Pressure Tubing Pressure Prior to well operation 984 348 434 770 188 Subsequent to operation 1007 341 455 907 196 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r • Development ' Service r Stratigraphic fi 16. Well Status after work: • Oil J Gas r VVDSPL r Daily Report of Well Operations X GSTOR r VVINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Bob Christensen /Darrell Humphrey Email N1139aconocophillios.com Printed Name - obert D hristensen Title NSK Production Engineering Specialist Signature f 40 12 ,.. K C ` Phone: 659 -7535 Date 6)// 2 / / 3 li Vf ,11,0, RBDMS JUN 14 20 Form 10 -404 Revised 12/2012 ,/ I41/3 Submit Original Only • 1J -159L2 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06 /07 /13IRIH to 4553' CTMD, latch B lat Isolation sleeve. KUP 1J -159L2 ConoC0 hiflips Well Attributes 'Max Angle & MD TD 7 Alaska, Inc. Wellbore API /UWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) lonoc[Y'hlll,ps - ' 500292329761 WEST SAK PROD 94.51 10,841.96 10,884.0 Comment H2S (ppm) Date Annotation End Date KB -Grd 99 Rig Release Date Well Confg: MULTIPLE LATERALS - iJ- 159L2, 5/10/20138:48:08 AM SSSV: NIPPLE 75 8/14/2012 Last WO: 1/23/2008 31.01 3/13/2006 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason: WELL REVIEW osborl 5/10/2013 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) String WL.. String ... String Top Thrd D - SAND LINER 4 1/2 3.958 4,24 1 0,859.6 3,427.7 11 L -80 BTC HANGER, 23 - - 04 — — Liner Details Top Depth (TVD) Top Inc! Noml... IMMINIIMMIMININNIMIgil — Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 4,241.4 3,480.3 74.93 HANGER BAKER MODEL B -1 FLANGED HOOK HANGER (Inside) 4.020 111 1111 4,266.4 3,486.1 76.78 SWIVEL BAKER CSG SWIVEL - TENSION LOCK 3.960 4,320.8 3,496.3 80.81 SWELL PKR 3.960 V-1-- 4,876.8 3,503.2 91.74 SWELL PKR 3.960 10,825.3 3,430.4 94.42 XO Reducing CROSSOVER 4.5x3.5" 3.958 CONDUCTOR, _. Perforations & Slots 0 ,. 3t 108 Shot Top (ND) Btm (TVD) Dens NIPPLE, 515 { I. Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (s Type Comment 4,890.0 7,847.0 3,502.8 3,444.0 WS D, 1J - 159L2 3/10/2006 32.0 SLOTS SLOTTED LINER 0.125' x 2.5" x 32 HEAT TRACE. 23 rows, 3" Ce rs Circumferential adjacent staggered 1 deg., 3 ft. non - cloned ends 8,174.0 10,823.0 3,459.1 3,430.6 WS D, 1J -159L2 3/10/2006 32.0 SLOTS Notes: General & Safety SURFACE, — J End Date Annotation 31 - 2,364 ' 3/12/2006 NOTE: MULTI - LATERAL WELL: 1J -159 (A- SAND), 1J -159L1 (B- SAND), 1J -159L2 (D -SAND) 2/21/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.OREV El GAS LIFT, _ 1 CIF 2,589 • GAS LIFT, ,094 4,094 gill all NIPPLE, 4,137 - - -- mem GAUGE, 4,148 -. ii i LOCATOR. 1,__. 4,194 1 SEAL ASSY, 4,195 a v e L2 LINER LEM, a,189A,386\ PRODUCTION, 275,575 H 11 SLOTS. 4.890-7,847 : SLOTS andrel Details I 8174-10,823 Top Depth Top Port I (ND) Inc! OD Valve Latch Size TRO Run N... Top (1168) (ftKB) (/ Make Model (in) Sery Type Type (in) (psi) Run Date Com... D 1 2,589.4 2,407.1 25.48 CAMCO KBG -2 -1R 1 GAS LIFT GLV BK -5 0.156 1,530.0 2/19/2008 4,24110 � 2 4,093.6 3,432.7 68.81 CAMCO KBG -2 -1R 1 GAS LIFT OV BK -5 0.250 0.0 2/19/2008 TD (1J-159L2). 10,884 w~ ,~ .~ :.~ ~'> ~ = ` ~-, ti- ~~ p~ a'FA ~ .MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~. 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 ~p - ~ ~ _ Well History File Identifier Organizing (aone> ~wo-sided III IIIII II III II III ^ Rescan Needed III IIIIII II II III III RE CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: ~skettes, No. I ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: ^ Other: NOTES: OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: Maria Date: /s/ Project Proofing III IIIIII IIIII II III BY: Maria Date: ~ /s/ Scanning Preparation ~ x 30 = a + ~ ~ =TOTAL PAGES (Count does not include cover sheet) BY: Maria Date: ~ /s/ Production Scanning III IIIIII IIIII II III Stage 7 Page Count from Scanned File: _~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: Maria Date: ~ (~.. ~ ~ /s/ ~/~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO Y BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II III II IIIII ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III II~III'II(I'II(I P P 10/6/2005 Well History File Cover Page.doc 6J~ ~ STATE OF ALASKA ~~~ 2 ~ 208 ALASKA OIL AND GAS CONSERVATION COMMI ~ ~ (~;~~ ~ ~~~ ~OIiS ~Qnif~iiSSI0T1 REPORT OF SUNDRY WELL OPERATtON~,~~~~-,~ ~ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Q Set a-LEM Isolation Sleeve Alter Casing. ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ (B-sand) Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended. Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhillips Alaska, Inc. Development ^ Exploratory ^ 206-007 ~ 3. Address: Stratigraphic ^ Service ^ 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-029-23297-6'Y 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' 1J-159L2 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 10884' ~ feet .true vertical 3426'_ feet Plugs (measured) None Effective Depth measured 10858' feet Junk (measured) true vertical 3428' feet _..._~ Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 2365' 10-3/4" 2365' 2207 PRODUCTION 5575' 7-5/8" 5575' 3695'~~~~N~® AUG ®~ 2~d~ WINDOW 1' 7" 4247 3482' D-sand Slotted l_ir 6600' 4-1/2" 10858' 3428' Perforation depth: Measured depth: 4890'-7847; 8174'-10823' ~ `~y ,~~~~ ~ ~~~~'~~ V ~ ' true vertical depth: 3503'-3444 ; 3459'-3431' ~~~~ ~ ~ \ ~ `~,~~. ~l S~~s`C~ "tC ~~ . C,~ Tubing (size, grade, and measured depth) 4-1/2", L-80, 4386.36 MD. l `~ Packers & SSSV t e & measured de th P k r= _ ( yp p ) ace ZXP Liner Top Pkr Pkr 4200' SSSV= NIP SSSV= 515' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A 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 804 261 474 948 220. Subsequent to operation. 773 224 294 861 ' :239 t4. Attachments 15. Well Class afterwork: Copies of Logs and Surveys run _ Exploratory ^ Development^ Service ^ Daily Report of Well Operations _X 16. Well Status after work: OiIO Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Bob Christensen /Bob Buchholz Printed Name. Ro rt D. istensen Title Production Engineering Technician Signature Phone: 265-6471 Date J / Form 10-404 Revised 04/2006 O I ~ ~ ~ ~ ~~ ~t~., ~.. c Submit Original Only 1J-159L2 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 5/24/2008 MADE 3 PASSES ACROSS B SAND LEM WITH 2.2 OD JSN TO CLEAN AREA OF ISO SLEEVE. USED 2.88" OD SIDI HIPP TRIPPER TO SET ISO SLEEVE ACROSS B SAND LEM @4588' CTMD. B SAND IS NOW ISOLATED. (****NOTE: IGS TOOL INDICATED DOWNWARD FORCE BY HIPP TRIPPER OF 5400#.****)" ~ ~ ~.~ia~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIV~Q MAR 1 0 200$ REPORT OF SUNDRY WELL OPERATIO~~ ~~` e~ CQ~"~ 1. Operations Performed: Abandon ^ Repair Well ~ Plug Perforations ~ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^~ Perforate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drili Number. COnOCOPhillips Alaska, InC. Development ~ Exploratory ~ ' 206-007 /' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 a. 50-029-23297-61 7. KB Elevation (ft): 9. Well Name and Number: RKB 28'y+ v 1J-159L2 ` 8. Property Designation: 10. Field/Pool(s): ''~ ADL 25661 & 25662 ~ \ Kuparuk River Fieid / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 10884' - feet true vertical 3426' - feet Plugs (measured) Effective Depth measured 10858'- feet Junk (measured) true vertical 3428' ~ feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' SURFACE 2337' 10-3/4" 2365' 2207' PRODUCTION 5547' 7-5/8" 5575' 3696' `" ° D-SAND LINER 6643' 4-1/2" 10860' 3428' PerForation depth: Measured depth: 4890'-7847', 8174'-10823' true vertical depth: 3503'-3444', 3459'-3431' ~'#:;~,;~~?a~~;~„~.~ ~ i%- .~ ti;~;~al~:? Tubing (size, grade, and measured depth) 4-1l2" , L-80, 4195' MD. Packers 8 SSSV (type & measured depth) zxp Iiner pkr @ a2oo' Camco 'DB' nipple @ 515' 12. Stimulation or cement squeeze summary: Interoals treated (measured) not appl-cable 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 413 1561 55 -- 194 Subsequent to operation 1722 1121 1906 -- 230 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. sundry Number or N/A if C.O. Exempt: none contact Brett Packer Printed Name Brett Packe Title Wells Group Engineer ~/ S / " Signature ~ Phone: 265-6845 ~ 1p / ~ Date P2 red b haron Allsu -Dr k 263-4612 Form 10-404 Revised 04/2006 ~~ L~ ~~~ ~ ~%%~ /( ' ~( ~V ~r'.. ~~~ Submit Original Only • • Cc~nocc~Phillips Time Log Summary WetJriew Web ReAOrttrtg - ~ { ..._. . _ -.. ~ . , - u ~ ,\ ~~. _ : , .. , . . , a .~.-; '~ 4 .:~. ~ ~. • ,,., . _ ...._ a.~-: ;,_ ., ~.~ .. ~. a . ..:. _ ~:..~:..i. _.. ~v- ~:~ -, =~~o-. Well Name: 1J-159 Job Type: RECOMPLETION , ~, _ ~: ~ , , ~~_ ~~ ~:~, ~ - ~ . ~2 ~, ,~ -;~ ~ , . ,., , ~ . , , ~ : , - F~ ~~i~ .~ ~:, ~ _ -~ , .. ~. ~, M , . ,. . ~~, ~~, ~ .. _. ,. 01/18/2008 00:00 01:00 1.00 MIRU MOVE RURD P PJSM, R/D prep for rig move. 01:00 03:00 2.00 MIRU MOVE RURD P Move off well # 1J-152. Move over 1J-159. spot & level, berm up. Accepted rig @ 0300 hrs today, 1 /18/2007. 03:00 07:00 4.00 MIRU MOVE RURD P Roll down tarps, spot tanks, & e ui ment. 07:00 09:00 2.00 MIRU MOVE RURD P RU hardline to kill tank. Heat up Seawater w/hot oil. 09:00 10:30 1.50 PROD1 RPCO RURD P PJSM, Pull BPV w/Lubricator. Some troubie linin u tools. 10:30 12:00 1.50 PROD1 RPCO RURD P RU line in cellar, P!f w/air. P/T w/fluid to 2500 si. 12:00 15:00 3.00 PROD1 WELC KLWL P Blow down hard(ine, sfart pumping well kill. IA pressure 480 psi and Tubing press 240 psi. Pumped @ 2 BPM 200 bbls hot seawater down annulus increasing rate to 4 BPM. Switched over and pumped 60 bbls hot seawater down tubing @ same rate. Shut down, check press. Small amount +/- 5 psi. Pumped another 50 bbls down tubing at same rate. Shut in monitor. 15:00 17:00 2.00 PROD1 WELC KLWL P While monitoring well, changed out ESP spools. Check well for pressure 0 IA/ 0 tubing. RD Circ lines and Blow down lines to kill tank. 17:00 18:30 1.50 PROD1 WELC BOPE P Install 4" H-BPV. ND and inspect tree. 18:30 23:30 5.00 PROD1 WELCT BOPE P NU BOPE 2330 00:00 0.50 PROD1 WELC BOPE P Function Test and frll stack 01/19/2008 00:00 08:00 8.00 PROD1 WELC BOPE P Continue to BOPE 250/2500 psi 08:00 15:30 7.50 PROD1 WELCT BOPE T Change out choke valve #2 and retest 250/2500 si. 15:30 16:30 1.00 PROD1 RPCOh OTHR P Pull BPV. Bent T-bar made difficult to line u . 16:30 20:00 3.50 PROD1 RPCOh PULD T Attempt to screw in landing jt in hanger, bad thread. Ordered out another landin 't and s ear. 20:00 21:00 1.00 PROD1 FISH PULL T Engage hanger and pull to surface 90k u wt. Break out and la down fish. 21:00 21:30 0.50 PROD1 RPCOh PULD P Pull and lay down pup jts and e line over sheeve and tie into s ool. • • ~ ~ ~ ~ , ~ . a ` .:: ,. . ,.~ ;~ ~ ~ _.,_ ~, , =_ _ . ,,. ~ ~£ , ~: f x ~ ~ . f : ,~ , ~: ~,,~, ~, , ~ f~7~ . ~.. ~. - ` "E}LI ~. - ~. ~ `~ ~. :. . E:~~.. . ~~ ~".. e~ ; 3 ~- ~,~ ~ ~. ~~ 01/21/2008 16:30 18:30 2.00 0 459 PROD1 RPCOh PULD P MU BHA#3 (clean out assy) RD Eckles and RU S inners 18:30 20:00 1.50 459 4,142 PROD1 RPCOh TRIP P Rihf/459.OU4142.0 20:00 22:3Q 2.50 4,142 4,392 PROD1 RPCOh FCO P MU Top Drive, fill pipe & wash down f/ 4142' t/ 4392'. Circ @ 5 bpm @ 2220 si. 105k u wt. 75k dn wt. 22:30 23:00 0.50 4,392 4,360 PROD1 RPCOh TRIP P LD 2 singles and Blow down Top drive 23:00 00:00 1.00 4,360 PROD1 RPCOh OTHR P Load Pipe shed w/ completion e ui ment and re are to Pooh. 01/22/2008 00:00 01:30 1.50 4,360 459 PROD1 RPCO TRIP P Pooh f/ 4360' U 459.0 0130 02:00 0.50 0 PROD1 RPCOh OTHR P RD Spinners and RU Eckles 02:00 03:00 1.00 459 183 PROD1 RPCOh PULD P Lay down BHA# 3 03:00 03:30 0.50 PROD1 RPCO SFTY P PJSM 03:30 04:00 0.50 183 0 PROD1 RPCOti PULD P Continue to lay down BHA# 3 04:00 05:00 1.00 PROD1 RPCOti OTHR P Clean and Clear rig floor. Clear Pipe shed 05:00 07:30 2.50 0 208 PROD1 RPCOh PULD P PU and MU BHA# 4 L-2 LEM/MWD assy. Shallow test MWD @ 2bpm @ 340 si. - ood test. 0730 08:00 0.50 208 208 PROD1 RPCOti PULD P C/O handling equip rig floor. 08:00 12:00 4.00 208 3,873 PROD1 RPCO TRIP P Resume RIH 3-1/2 DP to 3873 ft. 12:00 13:30 1.50 3,873 3,873 PROD1 RPCO CIRC P Circ out crude oil flow back thru DP due to ti ht kr / cs tolerance. 13:30 'l4:00 0.50 3,873 4,200 PROD1 RPCOti TRIP P RIH to 4200 ft. 14:00 15:30 1.50 4,200 4,200 PROD1 RPCOb CIRC P Bleed / circ crude / gas from annulus. 15:30 16:00 0.50 4,200 4,386 PROD1 RPCOti TRIP P RIH to tag @ 4376' work down U 4386' 16:00 17:30 1.50 4,386 PROD1 RPCOti PACK P Wash / re-cip pipe to latch point with LEM. Orient MWD. Multiple attempts due to fill. Latch in, confirm orientation. Unlatch / relatch, confirm depth / orientation. Final depths @ 4386' 1730 19:30 2.00 PROD1 RPCO PACK P Drop ball, pressure up U 1975 psi - set pkr, continue to pressure up to 4,000 si and release settin tool. 19:30 21:00 1.50 PROD1 RPCO DHEQ P Pressure test IA to 2,500 psi and chart for 30 minutes. 21:00 22:00 1.00 PROD1 RPCOh OTHR P Remove unneeded equipment from i e shed. 22:00 23:00 1.00 4,189 3,396 PROD1 RPCOti OTHR P Pooh laying down dp f/ 4189' ( New to of PBR to 3396' 23:00 00:00 1.00 3,396 PROD1 RPCOh WOEQ T Wait on Pipe Containment equipment to arrive to store oily drill pipe pulled from welL a a ~ ~ 13 DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060070 Well Name/No. KUPARUK RIV U WSAK 1J-159L2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23297-61-00 MD 10884 TVD 3426 Completion Date 3/13/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey .Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED Asc Directional Survey 4165 10884 Open 6/27!2006 Lis 13932 -~(nduction/Resistivity 4246 10823 Open 6/27/2006 GR EWR4 ABI ROP PWD ~g Induction/Resistivity 25 Col 218 10884 Open 4/21/2008 MD ROP, DGR, EWR 9- Mar-2006 ;Cog Induction/Resistivity 25 Col 218 3425 Open 4/21/2008 TVD DGR, EWR 9-Mar- 2006 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y~N Daily History Received? ~/ N Chips Received? 'Y-/-M~- Formation Tops ~/ N Analysis Y`t'N Received? Comments: Date: Compliance Reviewed By: WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 • April 10, 2008 RE: MWD Formation Evaluation Logs 1 J-159+PB l+L 1+L 1 PB 1+L 1 PB2+L2 AK-MW-4150952 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 J-159+pB 1+L l+L 1 PB 1+L 1 PB2+L2 2" x 5" MD TC Logs: 1 Color Log 50-029-23 297-00,60,61, 70, 71,72 2" x 5" TVD TC Logs: 1 Color Log 50-029-23297-00,60,61 Digital Log Images 1 CD Rom 50-029-23297-00,60, 61, 70, 71, 72 PBI, L1PB1 and L1PB2 have no TVD's. 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: c~~5 R ~( ~~ 'FS 2oCo-~,~ `~ r~,~19 ao~ ~~ ~ c ~ ~ a6 i ~E~~wE ~ ~ JUN 12 ~{?;?? STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cc+rr~. ~`FP'1'~RT ®F SUNDRY. WELL OPERATIONS 1. Operations Performed: 11C ~'n ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^/ ESP to GL Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number. ConocoPhillipsAlaska, lnc• Development 0 Exploratory ^ 206-007/ ` 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23297-61 .- 7. KB Elevation (ft): 9. Well Name and Number. RKB 109' 1J-159L2 8. Property Designation: 10: Field/Pool(s): ADL 25661 & 25662 Kuparuk River Field /West Sak Oil Pool 11: Present WeII Condition Summary: Total Depth measured 10884', feet true vertical 3426' ~ feet Plugs (measured) Effective Depth measured 10858' feet Junk (measured) true vertical 3427 feet Casing - Length Size MD TVD Burst Collapse Structural D- WINDOW #N/A CONDUCTOR 108' 20" 108' 108' SURFACE 2256' 10-3/4" 2365' 2207 PRODUCTION 5466' 7-5/8" 5575' 3695' D-SAND LINER 6643' 4-1/2" 10884' 3425' Perforation depth: Measured depth: Liner slots 4890-7847 8174-10823 WS D true vertical depth: Liner slots 3503-3444 3459-3431 WS D Tubing (size, grade, and measured depth) 4-1/2" , L-80, 3633' M0. Packers &SSSV (type & measured depth) no packer no SSSV no SSSV 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 710. , 751 41 293 189 Subsequent to operation 737 ' 1735 90 570. 192 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ , Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work:. Oil^~ ~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: contact Bob Christensen /Bob Buchholz Printed Name Robert W. Buchholz Title Production Engineering Technician Signature ~ one 659-7535 Date / ry ~ j ~ ~, ~ ~ ~ ~ ~ ~~iC~IMS BFI ~uN 1 ~ zoo, ,~ , ~ Form 10-404 Revised 04/2004 ~ ~ ~- Su mit Oi~i 1 J-159 L2 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/28/07 =SP Stopped producing. Diagnostics determined that there was a ground which wilt require a -ig workover to replace the rig deployed equipment. 05/07/07 Replaced sheared SOV with DV @ 2577 RKB. 05/11/07 Replaced STA #2 with 5/16" OV @ 3172' RKB. Replaced STA #1 DV with 0.188" PORT,TRO=1375_ @ 2577 RKB. 05/17/07 Well returned to service with gaslift. "a f ~ t ~ ~~ ~~~pC~ 1 r ( 4 ~' a t a ,,~' ALASSA OII, A1~TD GAS COI~TSERQATIOI~T COl-IIrIISSI01~ Perry Klein Problem Well Supervisor ConocoPhillips Alaska P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, 1J-159L2 Sundry Number: 307-161 Dear Mr. Klein: SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the unapproved Application for Sundry Approval relating to the above referenced well. We are returning your application for Sundry Approval unapproved. Since operating the well is equipped with gas lift if the ESP failed was described in the Application for Permit to Drill this sundry is not needed. DATED this ~ d of May, 2007 Encl. ~o~-c~U~ • Conoco~Phillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 7, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: RECE~V~~ ~1AY 1 ~ 2007 Alaska .Oil $ Gas Cons. C0~-ission Anchorage Enclosed please find 10-403 applications for Sundry Approval for ConocoPhillips Alaska, Inc. well 1J-159 PTD 206-005, 1J-159L1 PTD 206-006, and 1J-159L2 PTD 206007 to produce via gas lift until the failed ESP is replaced. Please call Marie McConnell or myself if you have any questions. Sincerely, Pe gin Problem Well Supervisor Attachments ~ ~,~.~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 RECE~WED MAY 1 0 2007 Alaska Oil & Gas Cons. Commission Anchorage 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^/ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q _ Exploratory ^ 206-007 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23297-61 ` 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: /~ b' Spacing Exception Required? YeS ^ NO [~ 5'~ 1J-159L2 ' 9. Property Designation: ,9i7t- a s-~(r/ `~ j-.yo ~9 10. KB Elevation (ft): 11. Field/Pool(s): Kuparuk River Unit ZCi~Z /' RKB 109' Kuparuk River Field /West Sak Oil Pool ' 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measure ~ Junk (measured): 10884' ~' 3426' - Casing Length Size MD VD Burst Collapse D- WINDOW #N/A CONDUCTOR -1' 20" 108' 108 SURFACE 2256' 10-3/4" 2365' 2207 PRODUCTION 5466' 7-5/8" 55 3486 D-SAND LINER 6643' 4-1/2" 4' 3424 Perforation Depth MD (ft): Perforation Depth (ft ~ Tubing Size: Tubing Grade: Tubing MD (ft): liner slots 4890-7847 8174-10823 WS D liner slots 3503-3444 9- 431 4-1~2" L-8~ 3633' Packers and SSSV Type: Pa rs a d SSS MD (ft) no packer SSSV Q~ ' no Sr o SSSV 13. Attachments: Description Summary of Propo al W lass after propose ork: Detailed Operations Program ^ B t ^ x loratory ~ Development Q Service ^ 15. Estimated Date for a Status after pro d work: Commencing Operations: i ^~ / Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: /, W ^ /~' GINJ ^ WINJ ^ WDSPL ^ Commission Representative: V 18. I her the foregoing ' ru d Corr t to the best of my know dge. / Contact: Perry klein /Marie McConnell 'nted Name P rry Klei Title: Problem Wells supervisor Signature Phone: 659-7224 Date: 05/07/07 Commission Use Only Sundry Number: Conditions of approval: Notify mmission so that a representat ive may witness ~ ~ f Plug Integrity ^ BOP Test [] Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: S , ~A~ 2 ~ ZDQ/ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 06/2006 U ~"~ f ~ ~ ~" /~ ~ ~~ Submit in t~/ .t • ConocoPhillips Alaska, Inc. West Sak Injection Well 1J-159 (PTD 206005), 1J-159L1 (PTD 206006) & 1J-159L2 (PTD 206007) SUNDRY NOTICE 10-403 VARIANCE REQUEST 05/07/2007 The purpose of this Sundry Notice is for approval to produce tri-lateral West Sak producer i J- 159via gas lift until the failed ESP is replaced. The well is completed as an ESP (electric submersible pump) producer and does not have a packer. 1J-159 was completed in May, 2006 and produced via ESP unti104/28/07, at which time it was shut-in due to a downhole motor electrical failure. Prior to failure, the ESP had drawn the bottom hole pressure down to 780 psi. A RWO is planned to replace the failed ESP within the next 2 years. The tubing is configured with two gas lift mandrels at 2577' RKB (2396' TVD) and 3172' RKB (2905' TVD). An attempt to place this well on gaslift is desired until the well is worked over and the ESP completion replaced. Due to the deviation coiled tubing will be used to pull the ESP to give the produced fluids a path through the intake ports in the tubing. if the pump can not be pulled then the tubing will be perforated above the ESP. An unloading valve will be installed in the upper gas lift mandrel. The lower gas lift mandrel will not be accessible by slickline and an attempt to pull the dummy valve and replace it with an orifice valve will be made using an electric line tractor tool. Gas lift will be applied in the "standard" configuration; i.e., gas will be injected down the annulus and enter the tubing through the orifice valve or tubing holes. The last production test on 04/26/07 recorded 710 BOPD, 41 BWPD (5%WC), and 751 MSCF of gas. Attached is a wellbore diagram of the well. The following is a summary of the proposed plan: 1. The AOGCC approve this request for a time period not to exceed 24 months from the approval date; 2. Should a workover not be completed within the approved time period the AOGCC will be contacted for a review and discussion of the plan forward. • • Subject: Re: FW: 1J-159 PTD # 206-005 ESP failure ~~ ~ - ~v~ From: Thomas Maunder <tom_maunder@adminatate,ak.us> Date: Tue, 15 May 2007 15: S'? :17 -0800 To: NSK Prahtem' We11 Supv •n 1 G1?@conocaphillips.com'~ Marie, I discussed this with Commissioner Foerster, your interpretation is correct. The well maybe produced on gas lift. Call or message with any questions. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 5/15/2007 11:12 AM: Torn, The west sak engineers Hated that gas lift backup was included in the PTD for these wells and were wondering if that would cover approval to gas lift the failed ESP. An excerpt ofi the PTD program for reference: 39. RU and run a 4 1/2" ESP completion with backup gaslift. 40. Space out tubing and land tubing in tubinghead. 41. Nipple down BOPE, nipple up tree and test, change over the hole to diesel. 42. Set BPV and RDMO Doyon 141. 43. Rig up wire line unit. Pull BPV. 44. Circulate out well with diesel through the ESP. 45. Set gas lift valves in mandrels. Operate well on gas lift until ESP facilities are ready. 46. Replace gas lift valves with blank dummy valves. 47. Place well on production with ESP. Marie From: Thomas Maunder [mailtoaorn_maunder@admin.state.ak.us] Sent: Monday, May 14, 2007 2:20 PM ', To: NSK Problem Well Supv Subject: Re: 1=W: 1J-159 PTD # 206-005 ESP failure Marie, I have not seen the sundries yet. I will check to see if they are in-house. Tom i NSK Problem Well Supv wrote, On 5/14/2007 2:14 PM: Tom, Last Monday, Perry Klein, submitted 10-403s to gas lift well 1 J-159 (wellbores 1 J-159, 1 J-159t_1, & 1 J-159L2) failed ESP while waiting on a RWO. Has AOGCC received the sundry applications? 1 of 2 5/22/2007 8:49 AM lte: 1^ W: 1.1-1 ~y P l ll # ZU6-UUS ESl' failure • They may still be in the mail. I understand your work load, especially with the vacancies, so not intending to add any undue rush for approval. We'd just like to know as soon as practical once approval is granted for rate optimization. Currently, the well is SI waiting an approval to gas lift. Operations is ready to start gas lifting as soon as commission approval is obtained, and they were wondering about timing. I'll let them know it will be a few weeks at least for paperwork processing. Thanks, Marie McConnell Problem Wetl Supervisor (907) 659-7224 n1617~conocophillips.com From: NSK Problem Well Supv Sent: Friday, May 04, 2007 9:57 AM To: 'Thomas Maunder' Cc: NSK West Sak Prod Engr Subject: 1J-159 PTD # 206-005 ESP failure Tom, 1J-159 PTD # 206-005 ESP producers ESP failed 4128. Centrilift has confirmed that the pump is grounded down hole and will require a RWO to repair /replace. Plan forward is to attempt to pull the pump with a coiled tubing unit in preparation to lift via the pump intake manifold. CPAI would like permission to temporarily produce the well on gas lift, not to exceed 30 days. If permission is granted and the test proves the well is economically viable a 10-403 will be submitted requesting permission to produce the well via gas lift until a rig work over is possible. Thanks in advance. Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617(a~conocophillips.com 2 of 2 5/22/2007 8:49 AM • 12-May-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 J-159 L2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 4,165.31' MD Window /Kickoff Survey: 10,841.95' MD (if applicable) Projected Survey: 10,884.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 ._-~ Date 27 ~.0(,~d W Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~.s 6 -~ ~ 7 • WELL LOG TRANSMITTAL • To: State of Alaska May 31, 2006 Alaska Oil and Gas Conservation Co. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-159 L2, AK-MW-4212091 1 LDWG formatted Disc with verification listing. API#: 50-029-23297-61 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTTON OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~~ ~~ Dat~~~ g~(1D6 ~~~~ ()tl & Signed: ~ , ~ ~~g3a • STATE 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. of Completions _ Other _ 1b. Well Class: Development ^ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: March 13, 2006 12. Permit to Drill Number: 206-007 / - 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded~,~ $ ar'~ Febr , 2606 y ~/ 13. API Number: -~G 50-029-23297-61 ' 4a. Location of Well (Governmental Section): Surface: 2035' FSL, 2545' FEL, Sec. 35, T11 N, R10E, UM 7. Date TD Reached: March 8, 2006 14. Well Name and Number: 1J-159L2 At Top Productive Horizon: 1373' FSL, 1620' FEL, Sec. 35, T11N, R10E, UM 8. KB Elevation (ft): 28' RKg 15. Field/Pool(s): Kuparuk River Field Total Depth: 38' FSL, 1858' FEL, Sec. 2, T10N, R10E, UM 9. Plug Back Depth (MD + TVD): 10858' MD / 3428' TVD West Sak Oil Poof 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558664 • y- 5945847 ~ Zone- 4 10. Total Depth (MD + TVD): 10884' MD / 3426' TVD 16. Property Designation:. ADL 25661 & 25662 TPI: x- 559595 y- 5945192 Zone- 4 Total Depth: x- 559416 - - 5938576 ' Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 471 & 2177 18. Directional Survey: Yes ~ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 2365' MD 21. Logs Run: T./ e-~~ Z (~ ~ ~ .37 ~ ~ ~ '7~vh GR/Res, Dens/Neu ~~ 3'•/L•p` 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 62.58# H-40 28' 108' 28' 108' 42" 233 sx AS 1 10.75" 45.5# L-80 28' 2364' 28' 2207' 13.5" 469 sx Class G, 175 sx Class G 7-5/8" 29.7# L-80 28' 5575' 28' 3696' 9-7/8" 351 sx LiteCRETE 4.5" 12.6#/11.6# L-80 4241' 10860' 3428' 6.75" slotted liner 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore 3633' 4666' slotted liner from 4889'-7847', 8174'-10823' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production May 5, 2006 Method of Operation (Flowing, gas lift, etc.) ESP oil producer- shares production with 1J-159 and 1J-159L1 Date of Test 5/10/2006 Hours Tested 14.5 hours Production for Test Period --> OIL-BBL 2316 GAS-MCF 1072 WATER-BBL 0 CHOKE SIZE 20% Gas-OIL RA7lo 506 Flow Tubing press. 32o psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 3659 GAS-MCF 1850 WATER-BBL 1 OIL GRAVITY -API (corr) 19° 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). ,,.... ~. ...,.,k,..-~: Submit core chips; if none, state "none". ~,,) s 'Et:`ci { 1 ~. } '!3 °6 p NONE S DF~> MAY ~ ~ 20Q6 ~ 1/f~ "`~~ i~ ....~..w~.---..,...-° Form 10-407 Revised 12!2003 CONTINUED ON REVERSE ~ r•/~.•O~. Q~1~~A~ ~~(~~ y6~6 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1J-159L2 West Sak D Sand 4250' 3483' Base West Sak D sand 10884' 3426' N/A ' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Pat Reilly @ 265-6048 Printed Ran s Titie: Greater Kuoaruk Area Drilling Team Leader /(r l0 signature ~ S 6 ,~ 3 0 Date S 6 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 ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Event Name: ROT -DRILLING Start: 2/11/2006 Contractor Name: n1334@ppco.com Rig Release: 3/13/2006 Rig Name: Doyon 141 Rig Number: Date 2/11/2006 14:00 - 18:00 I 4.00 18:00 - 20:30 'i 2.50 Page 1 of 19 Spud Date: 2/12/2006 End: 3/13/2006 Group: From - To 'Hours Code 'Code Phase Description of Operations 12:00 - 14:00 ', 2.00 MOVE ' MOB MOVE Disconnect all Electrical lines. Pull Swing arm over, and pin same in ,place. Continue prep for move. MOVE MOVE MOVE PJSM with crew & Peak Truck drivers. Discuss Safety issues and li procedure for rig move. Lay matting boards down pulling sub base. ', I Move Pipeshed modules, Rockwasher, Boilers, Motors and Pit Modules from 1J-166. Move Sub base 8~ spot rig on well 1J-159. MOVE POSN MOVE Clean up 1J-166 Well area, spot matting boards for complexes. Move & Spot Boilers, Motors and Pit Modules to rig. 20:30 - 22:00 1! 22:00 - 00:00 ~! 2/12/2006 00:00 - 01:30 '; 01:30 - 03:00 ', 03:00 - 05:15 !: ~~ 05:15 - 06:30 ' 'i 06:30 - 07:00 07:00 - 08:00 ', 1108:00 - 09:15 I I I 09:15 - 09:45 'i 09:45 - 10:30 Iii 10:30 - 11:15 11:15 - 12:00 12:00 - 13:30 13:30 - 15:00 1.501 MOVE POSN MOVE Spot matting boards for for complexes. Move & Spot Pipeshed '. modules & Rockwasher to rig. Release Peak @ 2200 HRS. 2.00'. DRILL RIRD RIGUP ~ Connect all Steam, Hydraulic, Air, & water lines. Connect electrical lines Work on Ri acce tance checklist Ri acce ted @ 0001 HRS 1.50 1.50 2.25 1.25 0.50 1.00 1.25 0.50 0.75 9 P 9 p 12/12/06. WELCTL!, NUND RIGUP !Install Riser Bell Nipple on Diveter System, and install 4" Valves on ~ I conductor. RIGMNT! RGRP RIGUP Change out Saver Sub on Top Drive to 4 1/2" IF threads. DRILL ' , PULD RIGUP Strap & Pick up 45 joints of 5" DP from pipe shed. Racking back in Derrick. 15 stands. RIGMNT I RSRV ! RIGUP Slip & Cut 60' of Drilling Line. RIGMNT I RSRV 'i RIGUP Inspect & Service Top Drive. DRILL OTHR I RIGUP 'Pick up 1 Stand of DP. RIH & Perform Diverter Function test. Witness ~, of test waived by AOGCC Jeff Jones. Test witnessed by Co. Rep. ~~ Simops: Pull BHA equipment to rig floor. DRILL PULD ',RIGUP 1 Pick up 5" HWDP, Drilling jars, and 3 NonMag Flex Drill Collars. Rack '~ in Derrick. DRILL SFTY ', RIGUP II Held PJSM with crew & DD's. Discuss safety issues and procedures for DRILL PULD SURFAC picking up BHA, and Spud. RKB to casing Head = 22.55' Make up 13 1/2" HTC MXC1 bit with 3 x 20's, & 1 x 13 jets (1.00'). 8" 1 Sperry Drill Lobe 4/5 - 5.3 stage (28.69'), 8" WB type Stabilizer (4.42'), 8" Non Mag Float Sub (2.15'), Bottleneck Crossover (2.47'), and 1 stand 5" HWDP (90.83'). 0.751 DRILL CIRC SURFAC Prime mud pumps, and flood conductor. Test surface lines to 3000 PSI. No Leaks. 0.75' DRILL DRLG SURFAC Drill 13 1/2" Surface hole from 90' -130'. Pumps at 450 GPM - 420 PSI. ~ 60 RPM's. 3K torque. ADT = .62 HRS. 1.50! DRILL II DRLG SURFAC Continue Drill 13 1/2" Surface hole from 130' -218'. Pumps at 430 GPM - 450 PSI. 60 RPM's. 3K torque. ADT = 1.85 HRS. 1.50' DRILL 'TRIP SURFAC 'POOH 2 stands. Blow down Top Drive. PJSM with GYRO crew. RU 15:00 - 16:30 '! 1.50 16:30 - 00:00 ', 7.50 2/13/2006 ~, 00:00 - 12:00 I 12.00 Gyro Unit. DRILL 'PULD SURFAC 'Make up MWD assembly, 8" DWD KM8 (26.91'), UBHO sub (3.45'). Orient MWD to motor. MU 1 stand Non Mag Flex Drill Collars (92.91'), and 5" HWDP. Break Circulation. NOTE: STarting JAR HRS = 130.72 DRILL ,DRLG !SURFAC !i Drill 13 1/2" Surface hole from 218' - 615' (39T). Run Gyro survey every !, ~, 91' for close approach issues & kick off. AST = 1.47 HRS, ADT = 5.04 '1 HRS. Up WT = 74k, SO WT = 74K, ROT WT = 70K. TO on BTM = li ', 13-4k, TO off BTM = 2K. JAR HRS total = 138.85. Pumps @ 480 GPM's - 900 PSI. Rotate @ 60 RPM's. WOB = 10 - 20K. Mud WT = 8.8 PPG ~ Viscosity = 400. YP = 83, Gels = 26 / 59. with Solids @ 4.0 DRILL DRLG 11 SURFAC Continue Drill 13 1/2" Surface hole from 615' -1634' (1019'). RD Gyro survey. AST = 4.07 HRS, ADT = 7.45 HRS, ART = 4.00 HRS. Up WT = 98k, SO WT = 90K, ROT WT = 95K. TO on BTM = 4-6k, TO off BTM = 5K. JAR HRS total = 146.58. Pumps @ 550 GPM's - 1750 PSI. Rotate @ 65 RPM's. Max Gas = 54 units. WOB = 30 - 35K. Mud WT = 9.2 Printed: 4/12/2006 1:53:21 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2/13/2006 1 J-159 1 J-159 ROT -DRILLING n 1334@ppco.com Doyon 141 From - To ~ Hours ' Code ' Sub Code 00:00 - 12:00 12.001 DRILL DRLG 12:00 - 18:45 ' 6.75 18:45 - 20:00 li 1.25 20:00 - 21:00 1.00 ', 21:00 - 21:30 0.50 21:30 - 22:00 0.50 22:00 - 00:00 2.00 DRILL Page 2 of 19 Spud Date: 2/12/2006 Start: 2/11/2006 End: 3/13/2006 Rig Release: 3/13/2006 Group: Rig Number: Phase Description of Operations ~, SURFAC • PPG Viscosity = 300. YP = 47, Gels = 22 / 38. with Solids @ 6.5 Total ', 'AST = 5.54 HRS, ART = 9.04 HRS. Survey @ 1449.84 MD 1411.87 TVD, INC = 25.21 DEG, AZ = 45.28 DEG. Total Bit HRS = 14.58 DRLG ',SURFAC ',Continue Drill 13 1/2" Surface hole from 1634' -2370' (736'). Run Gyro survey @ 1300' for close appraoch issues. AST = 1.82 HRS, ADT = 3.7 HRS, ART = 1.89 HRS. Up WT = 110K, SO WT = 97K, ROT WT = 103K. TO on BTM = 5-6k, TO off BTM = 3K. JAR HRS total = 150.29 DRILL ',CIRC DRILL IIWIPR i DRILL IIWIPR Pumps @ 700 GPM's - 2100 PSI. Rotate @ 75 RPM's. Max Gas = 54 'units. WOB = 20 - 35K. Mud WT = 9.15 PPG Viscosity = 275. YP = 47, ', Gels = 22 / 38. with Solids @ 6.5. Total AST = 7.36 HRS, ART = 10.93 ~~ HRS. Survey @ 2322.58 MD 2169.4 TVD, INC = 28.82 DEG, AZ = 80.98 DEG. Released GYRO Unit @ 1400 HRS. Total Bit HRS = 18.29 'SURFAC .Circulate hole clean while reciprocating drill string @ 700 GPM's - 2100 ' ~ PSI. 'SURFAC Attempt to POOH on elevators, observing proper hole fill. Overpull from 5 - 30K. Wipe through spots at 1900' & 1825'. Decision to run back to bottom and pump out of hole, with no rotation. I'I SURFAC Trip back to bottom @ 2370' on elevators. No issues on TIH. 5 Stands. DRILL CIRC ~ SURFAC Circulate btms up @ 700 GPM's - 2100 PSI. 75 RPM's ~ 4K TO. DRILL TRIP SURFAC 'Pump out of hole, no rotation from 2370' - 1266'. (1104'). Observe no issues, and slight overpull @ 1300'. Pumps @ 500 GPM's - 1200 PSI, to keep from washing out 13 1/2" hole. Observe good cuttings at shakers but not excessive. 2!14/2006 100:00 - 00:30 I,i 00:30 - 01:45 01:45 - 02:30 I'I I~ 02:30 - 03:00 ~I 03:00 - 03:45 ' 03:45 - 04:00 ', 04:00 - 06:00 '~, 06:00 - 10:00 ', 0.50; DRILL (TRIP SURFAC Pumped OOH from 1,266' to 1,082' w/ 500 gpm, 1100 psi. 1.251, DRILL I TRIP SURFAC POOH from 1,082' to 61'. UD 15 jts HWDP. I PUW=90K SOW=85K 0.75'. DRILL I PULD SURFAC UD 3 jts NMFDCs, UBHO sub, float sub. 0.50; DRILL I PULD SURFAC Downloaded MWD. 0.75 DRILL PULD SURFAC ' UD stab, MWD, motor and flushed same. UD bit and cleared and cleaned rig floor. 0.25', DRILL OTHR SURFAC ~~ Made a dummy run to check hanger. 2.00 CASE I RURD SURFAC I Held PJSM. R/U to run 10 3/4" casing. 4.00 !CASE I RUNC ~ SURFAC ~ Ran 57 jts 10 3!4" casing to 2,364.47" w/ total 22 bowspring centralizers 'ii 10:00 - 10:30 ' 0.50 10:30 - 11:15 ', 0.75 111:15 - 12:00 0.75 12:00 - 12:30 ~, 0.50 12:30 - 15:30 II I I 3.00 ~ II as follows: ', Ran 1 centralizer on stop collar 5' above shoe. Ran 2 centralizers one ~~ I 110' above and one 10' below float collar. One centralizer per jt. #3-#19. 'I One centralizer over collar on jt #56 and #57. CASE ,CIRC SURFAC I Circ'd BUs w/ Franks fill-up tool @ 6 bpm, 375 psi. ,PUW=140K SOW=95K. CASE ~ RURD ',SURFAC ', R/D Franks fill-up tool, blew down TD, and installed cement head. CASE CIRC ,SURFAC ~ Conditioned mud through cement head. CASE. CIRC ~~,' SURFAC Cont'd to circ and cond. mud @ 6 bpm, 400 psi. PUW=145K SOW=95K Held PJSM. CEMENT PUMP SURFAC Continue pumped an additional 50 bbls of CW 100 (50 bbls total}, ', 'Followed by 50 bbls of 10.5 ppg mudpush w/ red dye, dropped btm ', 'plug, began mixing and pumping Arcticset lead slurry, Pumped 375.0 i bbls (471 sxs) of lead cement at 10.7 ppg and 4.45 yield with additives, I ' 'ave 6.6 bpm at 275 psi, Followed with 74.1 bbls (169 sxs) of DeepCrete ', 'tail cmt at 12.0 ppg and 2.46 yield with add., ave 4.8 bpm at 230 psi, i~ shut down and dropped top plug, Kick plug out with 20 bbls fresh water, 'i I Reciprocated casing 10' to 15' until 150 bbls cement around shoe then Printed: 4/12/2006 1:53:21 PM ConocoPhillips Alaska Page 3 of 19 Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J -159 Spud Date: 2!12/2006 Event Name: ROT -DRILLING Start: 2/11/2006 End: 3/13/2006 Contractor Name: n1 334@ppco.com Rig Release: 3/13/2006 Group: Rig Name: Doyon 141 Rig Number: Date .From - To ', Hours Code Code Phase Description of Operations 2/14/2006 12:30 - 15:30 ' 3 00' CEMENl~ PUMP SURFAC ,pipe became tight and landed on hanger, Up 135K, Dn 80K..Turn over ~ ~i to rig and displace cement w/ 197 bbls (1967 stks to bump plug) of 9.5 ~~ I ,ppg mud, Displaced cement at 7.0 bpm, Initial pump pressure 280 psi, i ' max pressure at 7.0 bpm 320 psi, Observed red dye at shakers after ', I pumping 135 bbls mud, Slowed rate down to 3 bpm @ 280 psi 10 bbls ' ' I prior to bumping plug, Bumped plug w/ 1100 psi, Held 10 min, Check , ~ ', I !, ,floats- OK, CIP @ 1525 hrs 2/14/2006, Had full returns through out job ', !, ', ', li with 72.1 bbls 10.7 ppg cement to surface, Shoe @ 2,364.47, TVD = ' ! 2 207. Float collar 2,279.47. ~ I 1 ', I Test Float Equipment. Floats held. , ~ !,15:30 - 16:30 ' 'i CEMENT KURD 'SURFAC I, Flushed stack and flow line. R/D Schlumberger and pulled landing jt. 1.00 i 16:30 - 18:00 ', 1.50 ~, WELCTL NUND SURFAC '~ Nippled down diverter and knife valve, pulled riser, functioned and ' I ~ 'washed Hydril. Removed Hydril and diverter spool. 18:00 - 20:00 2.0011 WELCTL NUND ,SURFAC '~, Cleaned wellhead and installed Vetco Gray 11"wellhead and tested to i 20:00 - 23:30 I 15000 psi. 3.50' WELCTLI NUND ''SURFAC Nippled up BOPs, 13 5/8" X 11"adapter spool, attached turnbuckles. 23:30 - 00:00 i 0.50', WELCTLI NUND I~ SURFAC ', P/U 11"wellhead equip. including test plugs, wear rings, and running tools. 2/15/2006 00:00 - 00:45 00:45 - 10:45 0.75' WELCT~ NUND SURFAC Finished N/U BOPE. 10.00'. WELCTLI BOPE I SURFAC ' PJSM - Dicuss testing BOP's & Safety Issues. Perform BOP test. As ~ I 'follows:(1) Tested 7.625" rams, HCR choke (2) 3.5"X6" top rams, HCR 'kill and choke valves, valves 1,12,13,14 (3) Top rams, manual kill, I ' i choke valves 9,11, auto IBOP (4) Top rams, manual kill, choke valves I '1 ~ 5,8,10, manual IBOP (5) Top rams, manual kill, choke valve 4,6,7 (6) I ', Top rams, manual kill, choke valve 2, 4" TIW valve (7) Top rams, I~ I manual kill, choke valve 3, 4" dart valve (8) Top rams, manual kill, HCR ', ~~ choke, 5" TIW valve (9) Top rams, manual kill, 5" dart valve, (10) I I~ II ',Annular preventer, manual choke + kill (11) Perform Koomey test. I System Pressure = 3000 PSI, Pressure after close = 1900 PSI. First 1200 PSI attained in 49 secs, and full pressure attained in 3 min 39 secs. II 'I IIAVG pressure in Nitrogen bottles = 2300 PSI. (12) Blind rams. All test '~1 I Ito 250 PSI -low, 3500 PSI High. AOGCC rep, Jeff Jones witnessed I I tests. 10:45 - 12:00 '~ 1.251 WELCTL BOPE !SURFAC !,Unable to test Hydril against 5" test joint. Rubber element in need of ',12:00 - 15:15 ~', ~~ C/O. R/U to replace element. 3.251 WELCTL BOPE !SURFAC ~ R/U scaffolding to access BOPE. While R!U scaffolding an incident ', ', !, occured wherein an individual injured a finger. Taken to medic for I ~ ', ,examination, with scaffolding not fininshed or signed off. Scaffolding ', i ' crew returned @ 1400 hrs. Work concluded @ 1515 hrs. 15:15 - 19:30 'I Changed out Hydril element and installed riser. 4.25 ~~ WELCTL', BOPE 'I SURFAC I ',,19:30 - 21:30 ' , 2.00' WELCTL' BOPE ',SURFAC I, Retrieved test plug, noted Hydril rubber on plug. Washed rubber off 121:30 - 00:00 I and retrieved plug. Checked seals. 2.50 WELCTL BOPE .SURFAC ', R/U 5" test jt and set test plug. Tested annular preventer to 250 / 3000 'psi. UD 5" test jt and P/U 4" test jt. M/U test plug and RIH. Tested I 'annular preventer to 250 / 3000 psi. " 2/16/2006 00:00 - 00:30 I, test jt. Performed 0.501, WELCTLI BOPE SURFAC 'Finished testing annular to 250 / 3000 psi against 4 '~ ' accumulator test after rebuild of 4-way valve. System Pressure = 3000 1 ', 11 PSI, Pressure after close = 1800 PSI. First 200 PSI attained in 35 secs, ', 1 ', I, "and full pressure attained in 3 min 079 secs. AVG pressure in Nitrogen ,bottles = 2300 PSI. I 00:30 - 01:00 '', I OTHR SURFAC 'Pulled test plug and installed wear ring. 0.50 ~' DRILL " " ' 01:00 - 02:30: IF to 4 XT-39. ~, RSRV SURFAC ',Changed out saver sub from 4.5 1.50 RIGMNT 02:30 - 03:00 ': 0.50'1 DRILL I, RIRD I SURFAC ',Installed bails and elevators. Printed: 4/12/2006 1:53:21 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date 2/16/2006 12:00 - 14:30 '' 2.50 !,14:30 - 16:00 '; 1.50 ,16:00 - 17:30 ~'~, I 1.50 17:30 - 20:30 II 3.00 From - To ~ Hours ' Cade 'Code Phase 03:00 - 08:00 5.00 DRILL PULD I SURFAC 08:00 - 12:00 ', 4.00 DRILL PULD ~', SURFAC 1.50 I DRILL PULD 'SURFAC CASE MIT 'SURFAC RIGMNTI RGRP ''SURFAC CEMEN7DSH0',SURFAC CEMENT LOT ',SURFAC !~ 20:30 - 22:00 II I 22:00 - 00:00 2/17/2006 00:00 - 12:00 2/18/2006 2.001 DRILL 1 DRLG 12.00; DRILL ~ DRLG INTRMI INTRM1 12:00 - 00:00 12 00 ;DRILL I DRLG INTRM1 00:00 - 06:30 6.50 DRILL DRLG 'INTRMI Page 4 of 19 Spud Date: 2/12/2006 Start: 2/11/2006 End: 3/13/2006 Rig Release: 3/13/2006 Group: Rig Number: Description of Operations P/U 150 jts 4" DP and racked back same (50 jts at a time). P/U and M/U BHA #2 including: Bit, Mud Motor, Sub -Float Stabilizer, 6 3/4" DM Collar-MWD, 6 3/4" Gamma/Res/PWD/HCIM. Held PJSM for nuclear sources. P/U 2 flex DCs, HWDP and jars, 3 stds 5" DP, and ghost reamer, 12 stands 5" DP, XO to 4" DP. Tagged up @ 2268' Circa and S/B 1 std. R/U and tested casing to 3000 psi for 30 mins. Repaired 4-way valve on accumulator (controlled top rams) ,bled air from new lines. 'Drilled out shoe track w/ 400 gpm, 950 psi, 2-5K WOB, TQ=4-6, !ROT=95K. '; Tagged float @ 2,274' and shoe @ 2,360'. Drilled 25' of new hole to 12395' MD 2233' TVD. Swapped mud, R/U and performed LOT to 13.7 EMW w/ 550 psi at ~, surface. R/D and blew down. Garnered SPRs. 'SPR#1=30stk/180psi, 40stk/230psi SPR#2=30stk/180psi, 40stk/240psi @ 2,395' MD / 2,233' TVD and 9.0 PPG. ~I Drilled from 2,395' to 2,523' MD / 2,344' TVD. ART=0.36 AST=0.43 Jar Hrs=151.08 I PUW=112K SOW=82K ROT=95K ~ Continue Directional drill 9 7/8" Intermediate from 2,523' to 3,829' MD / III 3,323' TVD. IADT =8.21 hrs ART=2.69 AST=5.52 Total Bit HRS=9.0. Total Jar HRS ~I =159.29 I~ PU WT = 135K, SO WT = 85K, ROT WT =105K. TQ on/off=5-10/5-10K. Pumps - 589 GPM's -1900 PSI. RPMs = 100. WOB = 5-20K. Mud Wt ~1=9.00 PPG, Visc = 57, ECD = 9.59 PPG, Max gas = 62 Units. SPR#1=20stk/250psi, 30stk/330psi SPR#2=20spm/260psi,30stk/320psi @ 3,736' MD/ 3,265' TVD 9.OMW Continue Directional drill 9 7/8" Intermediate from 3,829' to 4,483' MD / 3,531' TVD. ADT =8.2 hrs ART=4.64 AST=3.56 Total Bit HRS=17.2. Total Jar HRS =167.49 PU WT = 135K, SO WT = 81 K, ROT WT =98K. TQ on/off=5-9/6-8K. Pumps - 564 GPM's -1925 PSI. RPMs = 100-110. WOB = 15-25K. Mud Wt =9.0+ PPG, Visc = 51, ECD = 9.6 PPG, Max gas =110 Units. Observed drilling through concretions from 4275'-4280', 4297'-4300', 4312'-4314',4320'-4327',4329'-4338', 4390'-4392'. ',SPR#1=20stk/180psi,30stk/230psi SPR#2=20spm/170psi,30stk/230psi @ 4,390' MD/ 3,516' TVD 9.0 MW Continue Directional drill 9 7!8" Intermediate from 4,483' to 4,773' MD / ', 3,576' TVD. 'ADT =4.72 hrs ART=4.46 AST=0.26 Total Bit HRS=21.92. Total Jar HRS =172.21 I PU WT = 135K, SO WT = 75K, ROT WT =95K. TQ on/off=6/7K. !Pumps - 615 GPM's -2000 PSI. RPMs = 100-110. WOB = 5-35K. Mud Wt =9.1+ PPG, Visc = 55, ECD = 9.63 PPG, Max gas =174 Units. ;,Observed drilling through concretions from 4625'-4635'. Printed: 4/12/2006 1:53:21 PM ConocoPhillips Alaska Code 6.5011 DRILL ~~ DRLG j INTRMI Legal Well Name: 1J-159 Common Well Name: 1J-159 Event Name: ROT -DRILLING Start: 2/11/2006 Contractor Name: n1334@ppco.com Rig Release: 3/13/2006 Rig Name: Doyon 141 Rig Number: Date From - To ' Hours Code ', Sub ', Phase 2/18/2006 ~, 00:00 - 06:30 06:30 - 07:00 ' 07:00 - 07:30 '; 07:30 - 08:45 '! 08:45 - 10:30 'i 10:30 - 11:00 11:00 - 12:00 12:00 - 12:30 12:30 - 13:00 13:00 - 13:15 13:15 - 13:45 13:45 - 14:15 14:15 - 14:45 14:45 - 15:30 15:30 - 16:30 16:30 - 17:30 ' 0.50' DRILL 0.50, DRILL 1.25 ~'~, DRILL 1.75 i, DRILL 0.501 DRILL 1.00 i DRILL 0.501 DRILL DEOT IINTRM1 CIRC INTRMI TRIP INTRM1 TRIP INTRMI OBSV INTRM1 TRIP INTRM1 TRIP INTRMI 0.50' DRILL 0.25 DRILL 0.50 DRILL 0.50 DRILL 0.50 DRILL 0.751 DRILL 1.00 DRILL 1.001 DRILL Operations Summary Report 'IPULD IPULD IPULD IPULD '~,PULD IPULD PULD ';PULD 17:30 - 18:00 ' 0.501 DRILL 18:00 - 20:30 20:30 - 00:00 PULD INTRMI INTRM1 INTRMI INTRM1 INTRM1 INTRMI INTRM1 INTRMI INTRM1 2.50 DRILL ;TRIP ~INTRM1 3.501 DRILL ',DRLG INTRM1 Page 5 of 19 Spud Date: 2/12/2006 End: 3/13/2006 Group: Description of Operations SPR#1=20stk/180psi,30stk/230psi SPR#2=20spm/170psi,30stk/230psi @ 4,390' MD/ 3,516' TVD 9.0 MW MWD failed. Attempt to troubleshoot. Circa BU @ 625 gpm, 2250 psi. POOH from 4,673' to 3.926' MD w/ 40-80 excess drag. POOH from 3.926' to 2,056' MD w/ 500 gpm, 1400 psi. Checked flow, static. Changed over to 5" handling tools. Cont'd to POOH from 2,056' to 1,684'. POOH from 1,684' to 660'. SLM OOH (no correction). Fill Act=49 Calc=38. R/B HWDP and jars. UD 1 jt. NMFDCs. Held PJSM. Removed MWD source. P/U 1 jt. NMFDC, R/B 1 std NMFDC. Downloaded MWD. UD nuclear string w/ DGR, PWD, TM collar M/U BHA #3. Oriented, P/U DGR, PWD, nuclear string, TM collar. Uploaded MWD. P/U 1 std. NMFDCs, UD 1 jt. NMFDCs. SHT MWD w/ 119 spm, 830 psi. Held PJSM. Loaded source fro MWD. P/U 1 jt. NMFDC. TIH w/ HWDP and jars, 5 stds to 657'. TIH from 657' to 4,777'. Washed and reamed to 4,777' w/ 120 spm, 1600 psi, 90 rpm, TO=6-7K Continue Directional drill 9 7/8" Intermediate from 4,473' to 4,990' MD / 3,615' TVD. ADT =1.73 hrs ART=1.22 AST=0.51 Total Bit HRS=23.65. Total Jar HRS =173.94 PU WT = 135K, SO WT = 75K, ROT WT =92K. TO on/off=6-7K/6-7.5K. Pumps - 615 GPM's -2000 PSI. RPMs = 100-110. WOB = 5-35K. Mud Wt =9.1+ PPG, Visc = 55, ECD = 9.71 PPG, Max gas =108 Units. Observed drilling through concretions from 4772'-4776', 4836'-4841', 4849'-4855'. 2/19/2006 ' 00:00 - 08:00 08:00 - 09:15 09:15 - 12:00 12:00 - 12:30 ISPR#1=20stk/220psi,30stk/300psi ~ SPR#2=20spm/240psi,30stk/310psi @ 4,948' MD/ 3,612' TVD 9.1+ MW 8.00 DRILL :!DRLG ~, INTRM1 ,Continue Directional drill 9 7/8" Intermediate from 4,990' to 5,580' MD / 3,696' TVD. ADT =6.95 hrs ART=3.13 AST=2.82 ~~ ~ Total Bit HRS=24.15. Total Jar HRS =180.89 ~ I PU WT = 135K, SO WT = 75K, ROT WT =92K. TO on/off=7/7K. i ~ I Pumps - 636 GPM's -2500 PSI. RPMs = 90. WOB = 15-20K. Mud Wt ~I ~' ~~i =9.25+ PPG, Visc = 55, ECD = 9.84 PPG, Max gas =108 Units. Ii 'i I Observed drilling through concretions from 5072'-5076'. 1.2511 DRILL (CIRC II INTRM1 I 2.75 DRILL TRIP '~ INTRM1 0.50~II DRILL TRIP I INTRM1 ISPR#1=30stk/270psi,40stk/350psi ISPR#2=30spm/280psi,40stk/360psi @ 5,580' MD/ 3,696' TVD 9.1 MW i~ Circa a hi-vis weighted sweep + 1 BU @ 636 GPM, 2400 psi. Checked, flow static. Pumped dry job, blew down TD. POOH from 5,511' to 2,988'. POOH from 2,988' to 2,053'. Changed over to 5" handling tools. Checked flow. static. Printed: 4/12!2006 1:53:21 PM ConocoPhiltips Alaska Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date 2/19/2006 1 J-159 1 J-159 ROT -DRILLING Start: 2/11/2006 n1334@ppco.com Rig Release: 3/13/2006 Doyon 141 Rig Number: Page 6 of 19 Spud Date: 2/12/2006 End: 3/13/2006 Group: From - To Hours Code Code II Phase Description of Operations 12:30 - 13:00 13:00 - 13:45 13:45 - 14:30 14:30 - 15:00 15:00 - 16:00 16:00 - 16:30 '~ 16:30 - 17:30 17:30-21:15 21:15 - 21:45 ', 0.50 ~; DRILL II TRIP ',INTRMI ', UD 5" DP (45 jts) to 663' 0.75',. DRILL I PULD INTRM1 ~ UD 5 stds HWDP and jars. 0.75! DRILL I PULD 'INTRMI UD 1 NMFDC. Held PJSM on nuclear sources. UD 2 NMFDCs. 0.50 i DRILL ~ PULD ', INTRM1 'Downloaded MWD. 1.00' DRILL 'PULD ' I INTRM1 UD TM, nuclear string w/ DGR, PWD, DM, stab, F/S, motor, and bit. 0.50; DRILL 'OTHR INTRMI 'Cleared and cleaned rig floor. 1.00' CASE ' 'RURD INTRM1 R/U to run 7 5/8" casing. 3.75 i CASE 'RUNC INTRMI ': Held PJSM. Ran 7 5/8" casing to 2319'. 0.501 CASE CIRC INTRMI Circ'd pipe volume @ 3.5 BPM, 350 psi. Staged up as follows: 4.5 'I 21:45 - 00:00 2.25 2/20/2006 ' 00:00 - 00:30 0.50 00:30 - 01:45 I 1.25 01:45 - 02:15 0.50 02:15 - 04:00 I 1.75 04:00 - 06:15 ~~ 2.25 06:15 - 07:15 ', 1.00 BPM, 300 psi; 5.5 BPM, 350 psi; 6.5 BPM, 400 psi. CASE ', RUNC INTRM1 ~I Cont'd running 7 5/8" casing to 4,312'. CASE ~ RUNC ~ INTRM1 ~ Cont'd to run casing from 4,312' to 5,567. PUW=190K SOW=90K CASE CIRC INTRM1 Circ'd w/ Franks tool staging up to 5 BPM, 450 psi. I CASE I RURD INTRM1 R/D Franks fill up tool, blew down TD. R/U cement head. CEMENTCIRC INTRM1 Circ'd and cond mud for cement job @ 7 BPM, 450 psi. CEMENT PUMP I INTRM1 Pumped cement as follows: Fill both Mud pumps & lines with MOBM. ', Turn Rig over to Dowell lines. Dowell pumped 10 bbls CW 100 at 8.3 1 ', ppg at rate of 4.7 bpm @ 168 psi, Pressure tested lines to 4,000 psi, ', ' Then pumped 40 add. bbls of CW 100 at rate of 5.0 bpm @ 255 psi. ~~ Dropped btm plug then pumped 50 bbls of MudPush at 11.0 ppg at rate ', ' of 5.0 bpm @ 420 psi, then pumped 142 bbls, (351 sxs - 25% over ', 'caliper) of DeepCrete cmt at 12.5 ppg, 2.25 yield with additives, avg 4.9 'bpm at 750 psi, Reciprocated pipe with full returns 15' to 20'. Drop top 1 ' plug and Dowell kicked top plug out with 10 bbls fresh water, @5 BPM 1 '; 200 PSI. Rig displaced cement with 9.0 ppg OBM, Bumped plug after pumping 244 bbls MOBM (96% pump effJ 2416 Strokes, avg 6.5 bpm I ', ii while displacing cmt, Observed lift pressure as cement turned corner. Slowed pump rate to 3 bpm, @ 830 psi prior to bumping. Bumped plug ' to 1270 psi, ck floats and held. CIP at 0615 hrs, 2-20-2006. I~ Reciprocated pipe 10' to 20' until Mud PUSH at shoe, then recip. 10' ', until Cmt at shoe, then recip. 10' until 2000 stks looked a little ratty. II i Landed csg with Shoe @ 5575', Float Collar @ 5486', Calc TOC @ ', ', I, 2226, Had full returns thru out job. Well static after shut down. CEMENT OTHR 07:15 - 09:30 ' 2.25': CASE "', OTHR 09:30 - 10:30 1.00', WELCTL~ BOPE 10:30 - 11:00 ' 0.50 ~I WELCTLI BOPE 11:00 - 12:00 ,' 1.001 DRILL I LOT 12:00 - 13:00 I 1.001 DRILL I RIRD 13:00 - 13:30 1 0.501 DRILL 'i OTHR INTRM1 I NTRM 1 I Checked floats, R/D cement head and blow down all lines. Shoe @ 15575'. RU and suck out MOBM from inside of 7 5/8"joint to below well head level. Nipple down BOP stack, and raise for installation of 'emergency slips. Set slips with 75K overpull on casing. R/U WACHS pneumatic cutter and cut casing as per Vetco Gray reps. PULD cut off joint. # 129 Cut off ', length = 36.02'. INTRMI N/U BOPE and wellhead. INTRMI Installed test plug and performed body test on BOPS 250 / 3000 psi for 5 min each. INTRM1 Inject 30 bbls H2O into the 10 7/8" X 7 5/8" annulus. Broke down w/ 7.7 bbls and 860 psi. Final circ press. 710 psi. UD casing tools and cleared rig floor. INTRM1 Installed bails and 4" elevators. Flushed gas buster w/ H2O also flushed choke manifold. INTRMI I Installed wear bushing and sim-oped by C/O 6" liners to 5.5" in mud Printed: 4/12/2006 1:53:21 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date 2/20/2006 1 J-159 1 J-159 ROT -DRILLING n 1334@ppco. com Doyon141 From - To Hours ~ 13:00 - 13:30 I ~i~ 13:30 - 14:15 ~, 14:15 - 16:30 !~ 16:30 - 18:00 '~ 18:00 - 19:00 Ii19:00-21:30 ' 121:30 - 22:00 ~, 22:00 - 23:30 ', 0.50 0.75 2.25 1.50 1.00 2.50 0.50 1.50 Code 'Sub Code ' DRILL OTHR DRILL OTHR DRILL PULD DRILL I PULD DRILL PULD DRILL .PULD DRILL ~!, OTHR RIGMNT!, RSRV '~ 23:30 - 00:00 ' 0.50 2/21 /2006 III 00:00 - 01:00 ', 1.00 I i 01:00 - 02:00 ' 1.00 ~, 02:00 - 03:00 ', i 1.00 03:00 - 06:00 ' 3.00 06:00 - 06:30 06:30 - 08:00 08:00 - 09:30 09:30 - 10:30 '. 10:30 - 11:00 11:00 - 12:00 12:00 - 14:00 2/22/2006 14:00 - 19:30 ', 19:30 - 00:00 ', 00:00 - 12:00 DRILL I PULD DRILL PULD DRILL II PULD DRILL ~ PULD DRILL 'TRIP 0.50!, DRILL CIRC 1.50' CASE i MIT 1.50 CEMENTDSHO 1.00'; CEMENTCIRC 0.50'' CEMEN7LOT 1.00' DRILL DRLH 2.001 DRILL ;DRLH 5.50', DRILL 4.50'. DRILL Phase INTRMI INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRMI INTRM1 INTRMI INTRMI INTRMI INTRM1 I~ INTRMI I~ INTRMI ~ INTRM1 ' INTRM1 ', INTRM1 INTRM1 'PROD PROD DRLH ;PROD DRLH '',PROD 12.00', DRILL ;DRLH '!PROD Page 7 of 19 Spud Date: 2/12/2006 Start: 2/11/2006 End: 3/13/2006 Rig Release: 3/13/2006 Group: Rig Number: Description of Operations pumps. Cleaned pits. 'Loaded pipeshed w/ BHA and DP. ' P/U 30 stds 4" DP w/super-sliders. ', POOH w/ 30 stds 4" DP w/ super-sliders and R/B. ', P/U 7 stds 4" HWDP, POOH and R/B same. 'i P/U 10 stds hybrid DP and R/B same. '',Cleared and cleaned rig floor. ',Slipped and cut 58' drill line. Serviced TD and DWs. Sim-opd by 'flushing 10 7/8" X 7 5/8" annulus w/ 105 bbls H2O @ 2.5 BPM, 780 psi '~~ max, 700 psi FCP. ' P/U BHA tools to rig floor. M/U BHA from bit to TM HOC as follows: Bit, 5" Sperry Drill 6/7 6.0 ~', Stg., Non Mag Float Sub, Non Mag String Stabilizer, 4 3/4" DM Hang Off Collar, 4 3/4" Slimphase 4 w/Gamma/Res, 4 3/4" PWD Collar, 4 3/4" TM Hang Off Collar. Uploaded MWD. P/U NMFDCs, HWDP, jars. Pulse tested MWD, blew down TD. Singled in 39 jts 4" DP. P/U XO, Andergauge agitator, shock sub, XO (BHA length 1595') . P/U 12 jts 4" DP. Continued to RIH from 1,969' to 5,585'. Tagged float equip. Circa 1 BU @ 82 spm, 3200 psi. R/U and tested 7 5/8" casing to 3000 psi for 30 mins. Good test, R/D. Drilled out FC, shoe track, and shoe + 25' of new hole to 5,605' MD w/ 277 gpm, 3400 psi, 100 rpm. PUW=105K SOW=75K ROT=90K. Circa and cond. mud for LOT @ 277 gpm, 3400 psi. R/U and performed LOT to 14.3 psi @ 5,605' MD / 3,695'. R/D equip. Drilled from 5,605' to 5,609' MD / 3,698' TVD. ADT=0.42 AST=0.42 TOon/off=3K ECD=9.81 Jar hrs=0.42 Drilled from 5,609 to 5,810' MD / 3,694' TVD. Exited top of formation. ADT=1.71 AST=0.64 ART=1.07 Jar hrs=2.31 PUW=105K SOW=70K ROT=85K RPM=90 WOB=3-5K Pump #2=77 spm, 2500 psi. Pulled back to 5,613' MD. Low-sided and drilled from 5,613' to 5,810'. Drilled from 5,810 to 6,170' MD / 3,689' TVD. AST=3.20 ART=3.05 (Times from 1400 hrs) Total Jar and Bit hrs=8.38 PUW=105K SOW=70K ROT=85K RPM=80-100 WOB=3-10K Pump #1=78 spm, 2600 psi. ECD=10.19 Max Gas= 88 Concretions depths: 5655'-5660', 5696'-5701', 5709'-5710', 5767'-5769', 5795'-5800', 5803'-5810', 5824'-5826', 5852'-5854', 5868'-5870', 5880'-5882', 5890'-5893', 5954'-5957', 5981'-5992', 6004'-6006', 6010'-6018', 6079'-6082' SPR#1=20stk/410psi, 30stk/620psi SPR#=20stk/440psi, 30stk/650psi @ 5,797' MD / 3,676' TVD 8.7 MW. KREVs for tour=10521 Drilled from 6,170' to 7,275' MD / 3,652' TVD. Printed: 4/12/2006 1:53:21 PM ConocoPhillips Alaska Page 8 of 19 Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Spud Date: 2/12/2006 Event Name: ROT -DRILLING Start: 2/11/2006 End: 3/13/2006 Contractor Name: n1334@ppco.com Rig Release: 3/13/2006 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours ' Code 'Code Phase Description of Operations 2!22/2006 00:00 - 12:00 ___ _ -- DRILL 'DRLH PROD ADT=6.23 AST=2.49 ART=3.74 Total Jar and Bit hrs=15.68 ICI PUW=120K SOW=75K ROT=90K RPM=100 WOB=3-5K TOon/off=5K ~, Pump #1=88 spm, 3200 psi. ECD=10.46 Max Gas= 88 SPR#1=20stk/430psi, 30stk/630psi SPR#2=20stk/440psi, 30stk/640psi @ 7,093' MD / 3,659' TVD 8.7+ MW. 12:00 - 17:15 12.00 5.25 '17:15-17:30 ' I 0.25 I ',:17:30 - 21:00 IC 3.50 I ':21:00 - 21:30 i 0.50 DRILL I DRLH PROD DRILL OBSV PROD I DRILL WIPR PROD DRILL CIRC PROD 21:30 - 21:45 0.251. DRILL OBSV PROD ! 21:45 - 23:00 1.25 ,DRILL WIPR PROD ~ 1 23:00 - 00:00 1.00 DRILL CIRC II PROD 2/23/2006 1 00:00 - 00:30 0.50 i DRILL CIRC I PROD 00:30 - 01:15 01:15 - 01:30 01:30 - 05:15 05:15 - 06:00 06:00 - 06:30 0.75! DRILL CIRC PROD 0.25' DRILL I OBSV 'PROD 3.75',.... DRILL TRIP PROD 0.751, DRILL II PULD 'PROD 0.50', DRILL ~ PULD 'PROD 06:30 - 07:00 i 0.50', DRILL I OTHR CMPLTN 07:00 - 08:00 1.00'', CASE RURD 'CMPLTN 08:00 - 10:45 1 2.751 CASE ~~ RUNC CMPLTN 10:45 - 12:00 1.25 ~, CASE III RUNC ~! CMPLTN 12:00 - 15:00 i 3.001 CASE 1 RUNL ,CMPLTN 15:00 - 16:15 I 1.25 I CASE I DEOT 'CMPLTN Drilled from 7,275' to 7,857' MD / 3,642' TVD. Pumped a weighted hi-vis sweep of 35 bbls @ 7,760' and observed a 35% increase in cuttings. ADT=3.65 AST=3.20 ART=0.45 Total Jar and Bit hrs=19.33 PUW=133K SOW=84K ROT=102K RPM=95-110 WOB=3-12K TOon/off=SK/5.5K Pump #1=92 spm, 3825 psi. ECD=10.68 Max Gas=53 KREVs=23400 Concretion depths: 7474-7481', 7520-7541', 7557-7571', 7580-7595', 7600-7609'. Garnered SPRs. Checked flow, static. SPR#1=20stk/440psi, 30stk/660psi SPR#2=20stk/460psi, 30stk/670psi @ 7,857' MD 13,642' TVD 8.7+ MW. ' BROOH from 7,857 to 5,570' w/ 78 spm, 3000 psi, 100 rpm, TO=SK. CBU @ work pipe from 5,570' to 5,519' w! 100 rpm, TO=4K II PUW=100K SOW=75K ~, Checked flow, static. ITIH from 5,519' to 7,857. Clrc'd hole clean @ 7,857 w/ 92 spm, 3800 psi, TO=SK ', Circ'd @ 925 spm, 3800 psi. PUW=124K SOW=80K ROT=98K TOoff=SK 'ECD=10.54 Displaced well to SFOBM w/ 92 spm, 3800 psi. !PUW=144K SOW=87K ROT=105K 'ECD=10.28 'Garnered SPRs. Blew down TD. Checked flow, static. UD 2 jts. POOH from 7,857 to 94'. UD XO, shock sub, Andergauge agitator, and XO. ', Downloaded MWD data. ' Cont'd to UD BHA including: TM HOC, slimphase 4 w/ DGR and EWR, ', DM HOC, stab, float sub, motor and bit. Cleaned and cleared rig floor. R/U to run 4.5" liner. Held PJSM. RIH w/ 4.5" liner as per detail to 3124'. Ran a total of 41 jts of blank 'pipe (1265.73') and 59 jts. of slotted pipe (1842.08'). II P/U and M/U seal bore, flexlock liner hanger, RS packoff seal nipple, 'i HRD ZXP liner top packer, and liner running tool to 3,189'. TIH w/ liner on DP to 7,857. Pulled up to 7,842'. Checked TO on II supersliders while RIH. PUW=135K SOW=81 K i Drop 1 1/2" ball, Position liner w/shoe @ 7,842.07' & top of liner @ ~I4,666.13', Circ ball down w/ 35 spm and 400 psi. Pressure up to 2500 Printed: 4/12/2006 1:53:21 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Event Name: ROT -DRILLING Start: 2/11/2006 Contractor Name: n1334@ppco.com Rig Release: 3/13/2006 Rig Name: Doyon 141 Rig Number: Date 2/23/2006 From - To ' Hours r Code 'Sub 'Code _ .......1.25 ,CASE - ' 15:00 - 16:15 DEOT Phase CMPLTN 16:15 - 16:45 ' 0.501 DRILL CIRC I CMPLTN 16:45 - 19:00 ' 2.25 DRILL . TRIP I CMPLTN 19:00 - 19:15 ', 0.25 DRILL ~ ~ PULD '',CMPLTN 19:15 - 19:45 ', 0.50 DRILL OTHR li CMPLTN 19:45 - 22:00 ', 2.25 DRILL , PULD I PROD2 122:00 - 22:45 I 0.7511 DRILL ' 22:45 - 23:00 0.25 DRILL 23:00 - 00:00 1.00 DRILL 2/24/2006 00:00 - 01:30 1 1.50'':. WINDI 1 '101:30 -.02:30 ~, 1.00 WINDI 02:30 - 03:00 0.50 WINDI ~, 03:00 - 03:30 '', ' 0.50; WINDI I I i 03:30 - 04:15 i 0.751 WINDI 04:15 - 09:15 ', 5.00 WIN I~ 09:15 - 10:00 I 0.75 T W I N 10:00 - 10:15 0.25 '.10:15 - 12:00 12:00 - 12:30 ':12:30 - 13:45 13:45 - 15:30 15:30 - 16:15 ', 16:15 - 17:15 ', 17:15 - 18:15 ' 18:15 - 18:45 ':PULD ''PROD2 !.PULD !PROD2 ;TRIP PROD2 TTRIP ' PROD2 I/OTHR '~ PROD2 ~JfRIP II PROD2 ~JSETW ~~ PROD2 IRC PROD2 TWP ICI PROD2 TWP ~' PROD2 WINDOWOTHR ' PROD2 1.75', WINDOWTRIP ' PROD2 0.50' WINDOWTRIP PROD2 1.25', WINDOWPULD PROD2 1.751 DRILL ', OTHR ', PROD2 0.75, DRILL ~I, OTHR ' PROD2 1.00'x, DRILL I, PULD ~, PROD2 1.001, DRILL PULD 1 PROD2 0.501 DRILL I PULD PROD2 Page 9 of 19 Spud Date: 2/12/2006 End: 3/13/2006 Group: Description of Operations 'PSI to set hanger. Set down 55K to set slips as per BOT rep, continue Ii pressure up to 4200 PSI, to complete setting PKR. Bleed pressure, Rig ', up and pressure test down annulus to test PKR at 1000 PSI - 5 'Minutes. P/U w/ 125K and pulled up 8'. RIH and tagged top of liner @ ', 4666.13'. Pulled up to 4,595'. Circa 1 BU w/ 80 spm, 1275 psi. Checked flow, static. POOH from 4,595' to 56'. UD running tool. Cleaned and cleared rig floor. P/U whipstock BHA as follows:Liner Seals, Locator Sub, Uploader Sub, 3 1/2" HWDP, Blanking Crossover Sub, Bottom Trip Anchor, -Shear Disconnect Sub, Drain Sub, Debris Sub, Removable Whipstock, Window Mill,+Lower Mill+Upper Mill, HWDP, Non-Mag Float Sub w/ Spacer, 4 3/4" DM HOC, 4 3/4" Slimphase 4 w/ DGR & Res, 4 3/4" PWD, 4 3/4" TM HOC ,Uploaded MWD. ', P/U and M/U Lub Bumper Sub, Crossover Sub, Hybrid Drill Collars. ',RIH from 392' to 1,792' MD. Tour Note: Freeze protected 10 3/4" X 7 5/8" annulus w/ 85 bbls diesel ICP=1500 psi FCP= 1500 psi @ 1.4 bpm Cont'd to RIH form 1,792' to 3,843' MD. Filled pipe @ 2,559', 3,843'. Made MAD pass from 3,900' to 4,024' MD. Correlation within 1'. Cont'd to RIH from 4,024' to 4,659' MD. Established PUW=120K and SOW=90K prior to setting trip anchor. Orient whipstock @ 11 deg left of high-side and set trip anchor after tagging A Lat ZXP as expected @ 4,666'. Pulled up to 130K to verify trip anchor st. Sheared off bolt w/ 60K downweight. Mill @ 4,565' MD=Top of B Lat window. Held PJSM and displaced well to MOBM @ 70 spm, 1500 psi. 'Milled window from 4,565' to 4,577. Milled 20' of gauge hole to total 'depth of 4,606'. PUW=112K SOW=92K ROT=95K TOon/off=6-7K/3.5K Pumped 30 bbl weighted hi-vis sweep (observed 50% increase in cuttings) w/ 64 spm, and 100 psi. Rotated through window w/ pumps on and 100 rpm. Repeated sliding. PUW=120K SOW=90K 'Garnered SPR. Flow checked well, static. Pumped dry job. ;SPR#1=25stks/350psi, 35stks/550psi ',SPR#2=25stks/370psi, 35stksl530psi @ 4,606' MD/ 3,557 TVD ', POOH from 4,606' to 1,224' MD. Checked sliders on the way OOH. i Cont'd POOH from 1,224' to 290'. ', UD XO, downloaded MWD. UD MWD, NM FS, 1 jt 3.5" HWDP, upper ~'I and lower window mills. Upper mill in gauge. Cleaned and cleared rig floor. Pulled wear bushing, flushed stack, set wear bushing. P/U 2 stds hybrid DP and 2 stds HWDP. Racked back in derrick. I~ M/U BHA #6 as follows: Security PDC bit, Geo-pilot, flexcollar, DM, 1 smart sub, slimpahse 4 w/ DGR and EWR, PWD, TM, NM FS, stab. Uploaded MWD. ', Cont'd to MU BHA w/ NMFDCs, 2 stds HWDP and jars. SHT MWD w/ ', 84 spm, 298 gpm, 1350 psi. Printed: 4/12/2006 1:53:21 PM ConocoPhillips Alaska Page 10 of 19 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date From - To 2/24/2006 II 18:45 - 20:00 20:00 - 21:00 21:00 - 21:30 21:30 - 21:45 1 J-159 1J-159 Spud Date: 2/12/2006 ROT -DRILLING Start: 2/11/2006 End: 3/13/2006 n1334@ppco.com Rig Release: 3/13/2006 Group: Doyon 141 Rig Number: I Hours Code Code', Phase ', Description of Operations 1.251 DRILL ~I TRIP ! PROD2 P!U 6 stds DP. TIH to 4,375' MD. 21:45 - 22:15 22:15 - 23:15 ', 23:15 - 00:00 II I 2/25/2006 00:00 - 09:00 ~i i I I 09:00 - 09:30 ": 09:30 - 10:00 10:00-12:00' 12:00 - 12:45 12:45 - 13:00 ICI ',,13:00 - 13:45 it 13:45 - 14:15 i ~ 14:15 - 15:00 15:00 - 15:30 15:30 - 17:00 17:00 - 18:00 ' I I,18:00 - 19:00 i, ',19:00-19:15' 119:15-19:45 '', '19:45-20:15 '' 1.00 RIGMNT RSRV 1 PROD2 0.50 RIGMNT RSRV ', PROD2 0.25 DRILL TRIP ' PROD2 0.50' DRILL DRLH I PROD2 1.001 DRILL ~ DRLH '' PROD2 0.75' DRILL I DRLH ' PROD2 i 9.00 ~° DRILL ~i DRLH PROD2 I 0.501 DRILL CIRC 0.501 DRILL !CIRC 2.00 DRILL ii (TRIP 0.751 DRILL TRIP 0.25 DRILL 0.75 ~ DRILL 0.50', DRILL 0.751 DRILL 0.50' DRILL 1.50': DRILL 1.00 DRILL 1.00; DRILL 0.25 DRILL 0.50', DRILL 0.501 DRILL PULD PULD PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PULD 'PROD2 !PULD jPROD2 (PULD ''PROD2 ',,TRIP ~ PROD2 -.TRIP I~ PROD2 I :TRIP PROD2 ';DEOT PROD2 'TRIP PROD2 TRIP PROD2 20:15 - 20:45 ' 0.50' DRILL DRLH I PROD2 Cut and slipped drill line (38'). Serviced TD and inspected saver sub. 1 Established PUW=95K SOW=76K ROT=85K TO=3.5K w/ 70 spm and !,1500 psi. Went through window to 4585' w! no problems. Reamed to ~, 4,606'. j Drilled from 4,606' to 4,620' MD. Geo-Pilot not holding toolface. Troubleshot Geo-pilot. Pulled into casing and reset manually. Run back through window to bottom. ', Drilled from 4,620' to 4,624' MD / 3,559' TVD. ADT=0.52 PUW=95K SOW=76K ROT=85K TOon/off=4.5Kl3.5K Total bit hrs=0.52 Total jar hrs=19.90 Drilled from 4,624' to 4,987 MD / 3,550' TVD. iADT=6.81 PUW=105K SOW=70K ROT=84K TOon/off=4K/4K ECD=9.61 Mas Gas=51 ;Total bit hrs=7.33 Total jar hrs=26.71 iSPR#1=25stks/280psi, 30stks/430psi SPR#2=25stks/300psi, 30stks/440psi @ 4,966' MD/ 3,551' TVD 8.8 MW Stop drilling for geology. Out top of formation. CBU @ 91 spm, 2150 psi, ROT=100 TOoff=3K. Geo-Pilot failed. ABI I failed which determines highside for toolface referencing. ICI Checked flow, static. POOH from 4,987 to 4,553' w/ hole taking proper fill. Pumped dry job. Cont'd to POOH to 2,883'. POW=105K SOW=70K Cont'd to POOH from 2,883' to 91'. UD BHA including: NMFDCs, 2 stds HWDP and jars. Downloaded MWD tool. Cont'd to UD BHA including: stab, NM FS, TM, PWD, slimphase 4 w/ ~~ DGR and EWR, smart sub, DM, flex collar, geo-pilot, and Security it PDC, bit M/U BHA #7 including: Reed Hycalog Bit, 5" Sperry Drill 6/7 6.0 Stg, ', Non Mag Float Sub, 4 3/4" DM Hang Off Collar, 4 3/4" slimphase 4 ',w/Gamma/Res, 4 3/4" PWD Collar, 4 3/4" TM Hang Off Collar. Uploaded MWD. P/U lstd NMFDCs, 2jts HWDP wljars. TIH inserting Andergauge Agitator and XOs @ 2,598'. TIH from 356' to 4,530' MD. '!PUW=95K SOW=75K ';Oriented to the highside and slid through window w/ 86 spm, 3100 psi. 'Good pulse on MWD, slid through no problems to 4,675'. Attempted to ',get good pulse test MWD, no luck. Agitator interfering w/ signal @ this 'i depth. POOH to 2,524'. UD 2 XOs and Andergauge Agitator w/ shock sub. ~~Tested MWD w/ 76 spm, 1600 psi. All tests successful. TIH from 2,524' to 4,553'. Oriented to the highside and slid through window w/ 77 spm, 1900 psi. Good pulse on MWD, slid through no problems to 4,680'. Drill trough for low-side sidetrack from 4,680' to 4,687. Printed: 4/12/2006 1:53:21 PM ConocoPhillips Alaska 1.50 !, DRILL ',DRLH PROD2 10.501 DRILL I~', DRLH PROD2 Legal Well Name: 1J-159 Common Well Name: 1J-159 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 2/25/2006 :20:45 - 22:00 1.251 DRILL 'DRLH PROD2 22:00 - 00:00 2.00 I DRILL I DRLH ~ PROD2 2/26/2006 .00:00 - 01:30 ~I 01:30 - 12:00 I 12:00 - 00:00 ' 12.00 DRILL i DRLH I PROD2 2/27!2006 i 00:00 - 03:30 3.50 ', I I 03:30 - 04:15 ' 0.75 j 04:15 - 05:15 05:15 - 06:45 06:45 - 12:00 Operations Summary Report DRILL ' DRLH '', PROD2 ~~ ~, DRILL '~ REAM !: PROD2 1.00' DRILL I DRLH PROD2 1.50; DRILL DRLH PROD2 5.251 DRILL ~ DRLH PROD2 Start: 2/11 /2006 Rig Release: 3/13/2006 Rig Number: Page 11 of 19 Spud Date: 2/12/2006 End: 3/13/2006 Group: Description of Operations __ _ _ Time drilled for low-side sidetrack from 4,687' to 4,710'. Drilled from 4,710' to 4,839' MD / 3,555' TVD. ~~, ADT=2.17 AST=1.93 ART=0.24 PUW=104K SOW=74K ROT=85K TOon/off=4.5K/5K ECD=9.64 Mas Gas=50 Total bit hrs=2.17 Total jar hrs=28.88 SPR#1=20stks/280psi, 30stks/440psi SPR#2=20stks/300psi, 30stks/450psi @ 4,839' MD7 3,555' TVD 8.7+ MW Drilled from 4,839' to 4,987' MD. Back to measured depth before sidetrack operations began. ADT=0.88 AST=0.62 ART=0.22 Drilled from 4,987' to 5,503' MD ! 3,551' TVD. ADT=8.06 AST=2.89 ART=5.17 PUW=104K SOW=70K ROT=82K TOon/off=4K/5K ECD=9.77 Mas Gas=76 Total bit hrs=11.11 Total jar hrs=37.82 Concretion Depths: 4977-4987', 5026-5037', 5045-5056', 5064-5090', 5120-5126', 5144-5148', 5168-5181', 5188-5200', 5203-5204', 5212-5230', 5248-5249',5288-5290', 5306-5320', 5327-5351', 5389-5393', 5400-5401', 5405-5412',5481-5488', 5494-5504'. SPR#1=20stks/280psi, 30stks/440psi i, SPR#2=20stks/300psi, 30stks/450psi @ 4,839' MD/ 3,555' TVD 8.7+ Drilled from 5,503' to 6,508' MD / 3,529' TVD. ADT=8.86 AST=2.57 ART=6.29 PUW=105K SOW=68K ROT=82K TOon/off=5K/5.5K ECD=10.02 Mas Gas=123 "Total bit hrs=19.97 Total jar hrs=46.68 iConcretion Depths: 5551-5565', 5570-5584', 5587-5589', 5600-5605', 5611-5619', 5754-5760', 5803-5818', 5850-5852', 5983-5995', 6065-6075', 6097-6110', 6113-6115', 6141-6143', 6169-6173', 6268-6284', 6318-6323', 6334-6336', 6350-6353'. SPR#1=20stks/310psi, 30stks/480psi ,SPR#2=20stksJ330psi, 30stks/490psi @ 5,886' MD/ 3,554' TVD 8.7+ ~, Drilled from 6,508' to 6,832' MD / 3,520' TVD. ADT=1.86 AST=0.71 ART=1.15 'PUW=108K SOW=64 ROT=81 K TOon/off=5K/5K ECD=10.02 Mas Gas=123 After looking at logs went out of zone @ 6,740' MD/ 3,526' ND per geos. BROOH from 6,832' to 6,282' MD w/ 88 spm, 310 gpm, 2600 psi, 100 rpm. PUW=108K SOW=64K Cut trough for sidetrack w/ 88 spm, 310 gpm, 2500 psi. Time drilled from 6,289' to sidetrack point @ 6,294' MD / 3,541' ND. Drilled from 6,294' to 6,714' MD / 3,540' TVD. ADT=4.78 AST=2.43 ART=2.35 PUW=110K SOW=65K ROT=82K TOon/off=5K/5K ECD=10.25 Mas Gas=84 Printed: 4/12/2006 1:53:21 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To 'Hours ' Code ~' Sub !, Phase 'Code, 2/27/2006 06:45 - 12:00 1~ 5.251 DRILL 12:00 - 12:30 I 0.501 DRILL 12:30 - 00:00 I 11.501 DRILL 2/28/2006 00:00 - 01:30 1.501 DRILL 01:30 - 01:45 0.2511 DRILL 01:45 - 09:00 7.25 DRILL II I III 09:00 - 10:15 1.251 DRILL 3/1 /2006 10:15 - 12:00 I 1.751 DRILL 12:00 - 00:00 ', 12.001 DRILL 00:00 - 12:00 '1 12.001 DRILL 12:00 - 17:00 I 5.001 DRILL 17:00 - 18:00 I 1.001 DRILL Start: 2/11 /2006 Rig Release: 3/13/2006 Rig Number: Page 12 of 19 Spud Date: 2/12/2006 End: 3/13/2006 Group: Description of Operations --- I __ -- _ - ---- ------- DRLH : PROD2 ', Total bit hrs=26.61 Total jar hrs=53.32 Concretion Depths: 6318-6321', 6334-6336', 6350-6353', 6396-6398', 6489-6492',6521-6523' ~ISPR#1=20stks/390psi, 30stks/560psi I SPR#2=20stks/410psi, 30stks/580psi @ 6,707 MD/ 3,538' TVD 8.7+ !DRLH ! PROD2 Drilled from 6,714' to 6,832' MD / 3,536' TVD. ~~ ADT=0.73 AST=0.26 ART=0.47 I I PUW=106K SOW=65K ROT=81 K TOon/off=SK/5.5K 'DRLH ' PROD2 ~I Drilled from 6,832' to 7,843' MD / 3,510' TVD. ~iADT=6.37 AST=0.25 ART=6.12 ', !, PUW=105K SOW=62K ROT=81 K TOon/off=SK/5-6K ~ ECD=10.44 Mas Gas=88 ', Total bit hrs=33.71 Total jar hrs=55.76 ~~Concretion Depths: 7082-7092', 7248-7269', 7716-7721', 7731-7738', 17834-7844' ', ISPR#1=20stks/400psi, 30stks/570psi SPR#2=20stks/420psi, 30stks/590psi @ 7735' MD/ 3,514' TVD 8.7+ IIKREVs=8008 ',DRLH !, PROD2 I Drilled f/ 7843' to 8049' (206') ! 3513' TVD, ART= 1.13 hrs, AST= 0.11 ~ I hrs, ADT= 1.24 hrs, Up 110K, Dn 65K, Rot 81 K, Torque On/Off 5K/6K, ~ I Concretions @ 7834' to 7844'. ~ ',CIRC I PROD2 I Circ for geologist. DRLH ', PROD2 ', Drilled f/ 8049' to 8473' (424') / 3519' TVD, ART= 2.4 hrs, AST= 1.94 1, 11 hrs, ADT= 4.34 hrs, Up 120K, Dn 65K, Rot 85K, Torque On/Off 6K/6K, 1 Concretions @ 8250' to 8258', 8405' to 8410', Ave ECD's 10.7 ppg, 1, 1 Max gas 54 units. TRIP PROD2 ~ POOH w/ 3 stands Hybrid pushPipe to 8204', Pick up & test Andergauge Agitator & shock sub for pressure increase, Had 600 psi @ 250 gpm & 700 psi @ 300 gpm (good test), RIH w/ 3 stands HWDP to 18473'. DRLH PROD2 I Drilled f/ 8473' to 8610' (137) / 3523' ND, ART= 0.52 hrs, AST= 0.17 ~i hrs, ADT= 0.69 hrs, Up 115K, Dn 65K, Rot 84K, Torque On/Off 5K/5K, Ave ECD's 10.7 ppg, Max gas 54 units. !DRLH I PROD2 Drilled f/ 8610' to 9512' (902') ! 3504' TVD, ART= 6.47 hrs, AST= 1.78 hrs, ADT= 8.25 hrs, Up 129K, Dn 75K, Rot 98K, Torque On/Off 17K/6.5K, Ave ECD's 10.8 ppg, Max gas 50 units, Concretions= 8610'-8612', 8622'-8627, 8654'-8664', 8668'-8674', 8680'-8690', ' ~~ 8695'-8700', 8710'-8739', 8745'-8755', 8808'-8809', 8813'-8815', I, 9009'-901 T, 9205'-9212'. ',DRLH ' PROD2 I Drilled f/ 9,512' to 10,712' (1200') / 3500' TVD, ART= 6.04 hrs, AST= ', 1.00 hrs, ADT= 7.04 hrs, Up 151 K, Dn 70K, Rot 104K, Torque On/Off '~ 8K/9K, Ave ECD's 11.3 ppg, Max gas 58 units, Concretions= I 9553'-9560', 9891'-9899', 9913'-9914', 9945'-9947, 10190'-10198', 1, 10202'-10213', 10230'-10240', 10390'-10397, 10401'-10415', 10424'-10434', 10439'-10440', 10488'-10493'. "DRLH ~ PROD2 Drilled f/ 10,712' to 11,187 T.D. (475') / 3506' TVD, ART= 2.19 hrs, AST= 1.52 hrs, ADT= 3.71 hrs, WOB 4-12K, 312 gpm @ 3850 psi, Up 158K, Dn 67K, Rot 102K, Torque On/Off 8.5K/8.5K, Ave ECD's 11.22 1 ppg, Max gas 56 units, Pump Hi-vis sweep on last stand. K-Rev's 51799. CIRC 1 PROD2 ,Finish pumping Hi-vis weighted sweep out of hole at rate of 312 gpm @ 13900 psi -Had 10% increase of cuttings, ECD's 11.3 ppg, Monitor well - Static. Printed: 4/12/2006 1:53:21 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To !Hours Code Code'.. Phase ! 3/1/2006 ::18:00 - 00:00 6.00 ! DRILL 1 WIPR PROD2 I 3/2/2006 00:00 - 02:45 ' 2.75 !, DRILL 'WIPR I PROD2 02:45 - 04:00 ', 1.25!, DRILL 'CIRC PROD2 ! 04:00 - 06:15 ', 2.25!, WELCTL BOPE III PROD2 06:15 - 11:00 4.751 WELCTL BOPE PROD2 11:00 - 12:45 ' 1.75', WELCTL' BOPE PROD2 ~ 12:45 - 16:15 3.50 DRILL 'TRIP ~ PROD2 ',,,16:15 - 18:45 I 2.50' DRILL ,CIRC PROD2 I Ii 18:45 - 20:00 1.25 ~ DRILL ',CIRC PROD2 !! 20:00 - 00:00 II 4.00 ~' DRILL 'TRIP PROD2 3/3/2006 100:00 - 02:00 !! 2.00 ~ DRILL 'TRIP PROD2 02:00 - 03:00 ~ 1.00 DRILL ',TRIP it PROD2 03:00 - 04:00 ~ 1.00I DRILL TRIP PROD2 ~I 04:00 - 06:45 ' I, 06:45 - 07:15 2.75 j WINDOWTRIP i CMPLT2 0.50' WINDOWTRIP CMPLT2 III 07:15 - 08:00 0.751 WINDOWCIRC I'll CMPLT2 08:00 - 12:30 4.50 I CMPLTN, CIRC 1 CMPLT2 ! !,12:30 - 14:30 ' CASE ~ RURD CMPLT2 2.00 ! 14:30 - 18:15 3.751 CASE !PULR II CMPLT2 !I 18:15 - 19:30 I 1.251 CASE 1 PULR I, CMPLT2 CI 19:30 - 21:30 2.00 CASE ~I PULR I CMPLT2 'I 21:30 - 22:30 I 1.00 CASE 'i PULR I CMPLT2 22:30 - 00:00 ' 1.50 !I CASE ICI RUNL I CMPLT2 3/4/2006 ! 00:00 - 01:30 I 1.50 CMPLTNI RUNT 'CMPLT2 01:30 - 02:45 I 1.25 CMPLTNII OTHR 1 CMPLT2 02:45 - 03:00 I 0.25 CMPLTN] OTHR 'CMPLT2 03:00 - 03:45 I!, 0.75 CMPLTN CIRC CMPLT2 ! 03:45 - 05:30 ~, 1.75 CMPLTN! TRIP 'CMPLT2 !!I 05:30 - 07:45 II 2.25 CMPLTNI PULD :CMPLT2 107:45 - 09:30 I,I I 1.7511 CMPLTNII PULD ,CMPLT2 !! Start: 2/11 /2006 Rig Release: 3/13/2006 Rig Number: Page 13 of 19 Spud Date: 2/12/2006 End: 3/13/2006 Group: Description of Operations Back ream out of hole at drilling rate 312 gpm @ 3800 to 2850 psi, 90 RPM, 8K Torque, Hole in very good shape but did have mild packing off @8160'&7915'. Back ream out of hole at drilling rate 310 gpm @ 2800 psi, 90 RPM, 6K '! Torque, Hole in very good shape. ~I! Pump 30 bbt Hi-vis weighted sweep, Circ 3 times btm's up at 310 gpm @ 2800 psi, Had 10% Increase in cuttings w/ sweep. Pull 2 stands drill pipe, Pick up Agitator & shock sub- Break down same i & crossover subs, Lay same back down, Pick up Baker 7-5l8" Storm packer, RIH & set @ 86' w/ bit @ 4468', Pull wear bushing. Test all BOPE to 250 psi low & 3000 psi high, Good test - No failures, Test all alarms, Test waived by AOGCC Jeff Jones. Set wear bushing, RIH to 86', Release packer, Monitor well -Static, Retrieve & lay down storm packer RIH with no problems to 11,145', Wash to 11,187'. I Pump 35 bbl Hi-vis weighted sweep, Circ 3 times btm's up at 291 gpm @ 3900 psi, 100 RPM, Torque 8K, Had 10% Increase in cuttings w/ I sweep. I Change over to 8.7 ppg SFOBM at rate of 295 gpm @ 3850 psi, 100 RPM, Torque 9.5K, Up 165K, Dn 52K, Rot 105K, SPR's, Monitor well. Drop 1-7/8" Rabbit, POOH on elevators with no problem. Monitor well @ 4550', POOH to 82'. Down load MWD tools. Lay down BHA, MWD tools, Motor & Bit. I Make up Whipstock retrieving tools, RIH to 4497, Break circ. I Hook whipstock on depth @ 4570', Pull same loose w/ 85K over pull, 1, Hole took 10 bbls mud. ', POOH to 4497, Circ btm's up 220 gpm @ 950 psi, Lost 10 more bbls !mud (Total 20 bbls). Monitor well-OK, POOH & Lay down whipstock & tools, Clean rig floor. ! Rig to run 4-1/2" liner, PJSM w/all personnel, Bring jewelry & tools to rig floor. Run 4-1 /2" liner as per detail & tag crossover on A2 lateral @ 471 T. Pull back to above window @ 4565', Rotate and orient bent joint, RIH & ;tag A2 lateral liner @ 471 T -Took 4 attempts to work thru window. Continue running 4-1/2" liner (Total 158 jts.) to Hook hanger. Pick up Baker Hook hanger, Sperry-Sun MWD and orient same. RIH w/ 3 stands drill pipe to insure shoe past sidetrack @ 6832', Shallow test MWD -OK, Blow down top drive, Continue RIH to 7267. Cont RIH with Liner on drillpipe to 11,141'. P/U = 165k, S/O = 70k !Orient Hook Hanger & Hook w/ top @ 4560', Pull up and turn 180 'degrees, Run past 10', Pull up & Reorient to 1 L, Slack off to 35k on hook, Toolface jumped around to 16 R, Top of hook hanger assembly !!~ @ 4560.20' and Shoe @ 11,161.07. 1 Drop ball and pumped down w/ 3 bpm, 1000 psi. Ball bumped at 415 ~~ stks and pressured up to 3000 psi. Released from liner P/U 125K ', Picked up off bottom and CBU at 4500' with 36 spm, 450 psi. Monitor well: static. POOH. Trip out displacement talc = 36.1 bbls, I~ actual 40.8 bbls. I R/U tongs. Break and UD BHA, slimhole MWD, and Liner running tool. ~! Held PJSM. M/U LEM to 350.5'. Baker seal assembly (3.29'), XO Bent 'joint 4.5" IBT x STL (43.43'), 4.5" tubing (30.98), Camco DB nipple ~! (1.49'), 4.5" IBT tubing (31.04'), 4.5" pup (9.84'), LEM assembly Printed: 4!12/2006 1:53:21 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 J-159 Common Well Name: 1J-159 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.co Rig Name: Doyon 141 Date From - To Hours Code ' Code ~ Phase - - -- - 3!4/2006 ~ 07:45 - 09:30 ' 1.75', CMPLTN PULD CMPLT2 ~' Start: 2/11 /2006 Rig Release: 3/13/2006 Rig Number: Page 14 of 19 Spud Date: 2/12/2006 End: 3/13/2006 Group: Description of Operations (34.83'), 5 jts of 4.5" (153.22'), XO bushing (1.36'), Seal bore receptacle (19.69'), ZXP liner top packer (17.14'). Total tools to stay in hole. 350.5'. ', 09:30 - 09:45 0.251, CMPLTN RURD '-CMPLT2 !, R/D csg equipment. 09:45 - 12:00 1 2.251 CMPLTN RUNT 'CMPLT2 ~'i RIH with LEM assembly. P/U = 98K, S/O = 80K 12:00 - 13:30 ~'~, 1.501 CMPLTN RUNT ;CMPLT2 I Cont to RIH w/ LEM. Stab into hanger at 4560', P/U 125K, S/O = 95K. I 13:30 - 16:30 j I 3.00 ~ CMPL ':16:30 - 18:30 2.00 WIND 18:30 - 19:15 ~'~, 0.75 WIND 19:15 - 22:00 I~ 2.75 WIND 122:00 - 22:30 I 0.50 WIND !22:30-23:30 ' 1.00 WIND ' 23:30 - 00:00 3/5/2006 00:00 - 00:15 0.50' WI 0.25 W I 00:15 - 05:00 ' 4.75 05:00 - 06:00 ! 1.00 06:00 - 07:45 ' 1.75 WI WI WI 07:45 - 09:00 ; 1.251, WINDi 09:00 - 13:30 L 4.50 DRILL 113:30 - 16:00 ICI 16:00 - 17:00 ', 1,17:00-20:15 20:15 - 21:00 ', 2.50 DRILL 1.00 DRILL 3.25' DRILL 0.75' DRILL II 21:00 - 00:00 3/6/2006 ', 00:00 - 12:00 ~I 3.00'; DRILL 12.00': DRILL ~ ; 'Set down with 30K, Pull test LEM to 15K over, Set back down with 30K 'and picked up to neutral weight. Drop ball and chase with 3 bpm @ 500 ',psi, 330 stks. Pressure up to 4000 psi. S/O with 30K. Pressure test ZXP 'to 1000 psi f/ 5 min- OK. P/U with overpull of 5K. Set back down and ',tagged liner top. Blow down top drive and kill line. PULD CMPLT2 POOH with running tools and UD. VPULD PROD3 ,Clear and clean rig floor. MU whipstock assembly. fIPULD '~, PROD3 ,Upload MWD. fIPULD ~', PROD3 ', PU XO, 3 stands hybrid DP, and shallow test MWD. RIH to 3878'. RIP ' PROD3 ', MAD pass from 3888' to 4006' @ 350' HR. ETW PROD3 I Cont to RIH to 4355'. Set 22K on Baker trip anchor. PU 10K over and confirm trip anchor release. PU to 42K to shear off of whipstock. PU ', ', before 115K i~ SO 87K. After 107K & 80K. Whipstock set at 17 degree ', left high side. iICIRC PROD3 ', Displace well from SFOBM to drilling MOBM. IRC i~ PROD3 ', Cont to displace over from SFOBM to MOBM. Pump @ 310 gpm & 1 2100 psi. 1~ PROD3 VSCML Mill out window from 4246' to 4258'. Drill 5' of gauged hole to 4274'. ', ', ~ ', SPR @ 4274' / 3488' TVD. pump #1:20 spm= 230psi 30 spm = 310 psi 1 ' ~ V pump #2: 20 spm= 230psi 30 spm = 350 psi ! SCML PROD3 Work mills through window @ 60 rpm, 78 spm, 275 gpm, 1750 psi. ', 'Pumped 30 bbl hi vis sweeps @ 4255' ii 4274'. Able to slide through ', window with no pump problems. VTRIP PROD3 'Monitor well: static. Pump dry job. POOH to 96'. Trip out actual fill 38.3 '~I bbls, Calc 32.85 bbls. VPULD PROD3 LD BHA: XO, Bumper sub, down load MWD. Mill in gauge. Clean Rig 'floor. PUII wear pushing, flush stack, install wear bushing. 'PULD ~ PROD3 ~! PU BHA #9 including: Bit, motor, NMFS, DM HOC, MWD, PWD, TM I HOC, Flex DC, HWDP & Jars. Upload MWD. RIH to 2685' and PU li agitator. ;TRIP PROD3 ',Continue to RIH to 4209'. Fill pipe. PJSM. Cut and slip 65' of drilling (line. :TRIP ~I~ PROD3 ~I Calibrate depth. Inspect Saver sub. Establish circulation and go through DRLH ' PROD3 I window. i~ Drilled from 4,247 to 4,486' MD / 3,505' TVD. ,DRLH '1 PROD3 1 Trouble getting detection from MWD due to agitator interference. 11 (Adjusted pump rate down from 330 gpm to 250 gpm and regained ~ I~ detection. DRLH PROD3 I Continued to drill from 4486' to 4766' MD / 3506' TVD. ~, ~ '~ i ADT=1.38 hrs. AST= 1.38 hrs Jar hrs=90.28 ', ~, PUW=100K SOW=74K ROT=82K TOon/off=4/4K Max Gas=46 Units Max ECD=9.64 DRLH PROD3 11 Drilled from 4,766' to 5,607 MD / 3481' TVD. ', IADT=6.76 hrs. AST= 1.64 hrs ART= 5.12 hrs !,Jar hrs=97.04 ',PUW=103K SOW=71 K ROT=82K TOon/off=4/5K c.a l>b ~`'`. Printed: 4/12/2006 1:53:21 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name:. 1J-159 Common Well Name: 1J-159 Event Name: ROT -DRILLING Start: 2/11/2006 Contractor Name: n1334@ppco.com Rig Release: 3/13/2006 Rig Name: Doyon 141 Rig Number: Date 3/6/2006 3/7/2006 3/8/2006 From - To 'Hours ' Code ' Sub Code 00:00 - 12:00 I 12.00' DRILL 'DRLH 12:00 - 00:00 12.00' DRILL DRLH 00:00 - 12:00 '' 12.00' DRILL DRLH ', L 12:00 - 00:00 ', 12.00', DRILL I DRLH 00:00 - 12:00 ' 12.00' DRILL 'DRLH 'I i I 12:00 - 20:15 ' 8.25 I DRILL i DRLH Page 15 of 19 Spud Date: 2/12/2006 End: 3/13/2006 Group: Phase Description of Operations PROD3 ' Max Gas=52 Units Max ECD=10.01 SPR@ 4895'MD / 3502' ND, #1 @ 20spm/370 psi, 30spm/590 psi #2@ 20spm/410 psi, 30spm/620 psi Concretion depths = 4857-4859', 4867-4870', 4919'-4925', 4947-4948', ',.5013'-5015', 5020'-5024', 5034-5037, 5048'-5050', 5054'-5057, ', 5081'-5088', 5134'-5160', 5420'-5424', 5447-5450' PROD3 'Drilled from 5,607 to 7,101' MD / 3461' ND. 'ADT=10.41 hrs. AST= 2.48 hrs ART= 7.93 hrs 'Jar hrs=107.45 !, PUW=110K SOW=65K ROT=85K TOonloff = 5-6/5-6K Max Gas=136 Units Max ECD=10.48 ',SPR@ 6074'MD / 3478' ND, '~, #1 @ 30spm/670 psi, 40spm/930 psi ', #2@ 30spm/710 psi, 40spm/970 psi !,Concretion depths =5607-5608, 5650'-5651', 5667-5670', 5700'-5702', i 5720'-5722', 5793'-5799', 5900'-5902', 5930'-5931', 6015'-6019', 6566'-6569', 6593'-6597' PROD3 ~~ Drilled from 7,101' to 8,167 MD / 3458' ND. ADT=8.07 hrs. AST= 1.25 hrs ART= 6.82 hrs Jarhvs=115.52 PUW=122K SOW=54K ROT=80K TOon/off = 5/5K ~~ Max Gas=137 Units Max ECD=10.65 ~I SPR@ 7101'MD / 3461' ND, #1 @ 20spm/480 psi, 30spm710 psi ~, #2@ 20spm/480 psi, 30spm/720 psi 'Concretion depths =7473'/7476', 7585'/7586', 772T/7731' PROD3 ', Drilled from 8,167 to 9437 MD / 3458' ND. ~'~ ADT=8.67 hrs. AST= 2.15 hrs ART= 6.52 hrs ',Jar hrs=124.92 !, PUW=118K SOW=54K ROT=85K TOon/off = 7/6K Max Gas=107 Units Max ECD=11.34 SPR@ 8502"MD / 3473' ND, #1 @ 30spm/800 psi, 40spm/1080 psi #2@ 30spm/850 psi, 40spm/1140 psi 'Concretion depths =7800'/7802', 8093'/8101', 8129'/8140', 8596'/8601', 19418/9425" PROD3 'Drilled from 8,167 to 10372' MD / 3455' ND ,ADT=8.37 hrs. AST= 1.5 hrs ART= 8.22 hrs Jar hrs=133.29 'PUW=130K SOW=55K ROT=85K TOon/off = 8l7K ',Max Gas=88 Units Max ECD=11.27 ',SPR@ 10112' MD / 3424' ND, ', #1 @ 20spml660 psi, 30spm/820 psi #2@ 20spm/640 psi, 30spm/840 psi 'Concretion depths =9984'/9989', 9993'/9998', 10008'/10012', ',10030'/10037, 10110'/11115', 10120'/10125', 10136'/10138', ',10188'/10192', 10249'!10261', 10268'/10285', 10296'/10300', 10304'/10306', 10316'/10319' PROD3 'Drilled from 10372' MD to TD @ 10884' MD / 3424' ND. ',ADT=5.42 hrs. AST= 1.66 hrs ART=3.59 hrs Jar hrs=138.71 PUW=140K SOW=60K ROT=103K TOon/off = 8/7K Printed: 4/12/2006 1:53:21 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Event Name: ROT -DRILLING Start: 2/11/2006 Contractor Name: n1334@ppco.com Rig Release: 3/13/2006 Rig Name: Doyon 141 Rig Number: Date 3/8/2006 3/9/2006 From - To 'Hours Code Sub Code 112:00 - 20:15 I 8.25'1 DRILL ', DRLH 20:15 - 00:00 00:00 - 05:45 05:45 - 06:30 06:30 - 10:30 10:30 - 12:00 Phase PROD3 3.7511 DRILL ,REAM li PROD3 5.75 II, DRILL II REAM ~ PROD3 0.751 DRILL ,CIRC I PROD3 4.00 DRILL li TRIP I PROD3 1.501 DRILL i CIRC I PROD3 Page 16 of 19 Spud Date: 2/12/2006 End: 3/13/2006 Group: Description of Operations ~' Units Max ECD=11.23 I Concretion depths =10370'/10415', 10424'/10426', 10471'/10474', '...10488'/10513', 10715'/10730', 10795'/10805' 'Circ clear BHA for 10 mins. Pump up survey. BROOH @ 90 rpm, TO 7K, 294-300 gpm, 4000/3500 psi. Cont BROOH from 9159' to 4246' MD. Orinet High side and pull thru ',window (no problems). : PU = 97k, SO = 80k, Rot = 86k, TO = 4k 'Pump 35 BBI weighted High Vis sweep @ 4209'. Circ SS x 1 bottoms up @ 86 spm, 300 gpm, 3100 psi, Rot @ 60 rpm. 'Orient High side, monitor well, RIH and check condition of '.'Super-Sliders' on TIH. RIH to 10,808' MD and Wash and Ream from 10,808' to 10,884' MD. Circ Hole Clean @ 10,884' MD. 78 spm, 275 gpm, 3900 psi, 100 rpm, Off Bttm TO = 7k i, I i II i ~ ~ '~ Trip OUT Actual Fill = 80.6 Bbls (46.3 Bbls Calc) 1 ~ I ',Trip IN Actual Gain = 42 Bbls (40.81 Bbl Calc) 12:00 - 13:00 '1 1.001 DRILL 1 CIRC PROD3 1 ', Displace well to SFOBM @ 80 spm and 3800 psi ... observe well. 13:00 - 20:15 7.25 1 DRILL I TRIP PROD3 ,POOH w/ BHA #9 ... monitor T&D every 5 stands in open hole and I 1~, I ,every 10 stands in cased hole. 20:15 - 21:15 ' I 1.00 I DRILL PULD ~, PROD3 ' LD BHA #9 ~ 21:15 - 22:00 I 0.75 DRILL SURV ' PROD3 Down Load MWD I, 22:00 - 00:00 2.00', DRILL 'PULD II PROD3 ,Continue LD BHA #9 ... Clean Rig Floor K-Revs = 20,067 3/10/2006 100:00 - 00:45 ', 0.75' WINDOWPULD CMPLT3 ' MU BHA - MU retriving hook, 1 jt 3.5" HWDP, float sub, bumper sub, ', ' I ' jars, XO, 2 stds Hybrid DCs.(total 261.60") ~ 00:45 - 02:15 ' 1.50 ! WINDOWTRIP 'CMPLT3 RIH to 4,214" -Break Circu, 4 BPM @ 600 PSI -Wash down to 4,259' - ', ', Pull back up to 4,235' -Put 1.5 rounds turn in string - Up wt 125K - Dn ', ! wt 97k. 02:15 - 02:45 ', 0.50' WINDOWTRIP 'CMPLT3 'Engage hook slot @ 4,252' -apply 75k over pull -Trip jar and pulled trip anchor free. Pull up to 4,232' MD 102:45 - 03:30 ', 0.75 WINDOWCIRC ',CMPLT3 CBU @ 4,232' - PR 4 BPM, 600 psi II 03:30 - 06:15 2.75 WINDOWTRIP .CMPLT3 Monitor well -Static- POOH to 261' 06:15 - 07:45 ', 1.50', WINDOWPULD 'CMPLT3 ! PJSM - UD BHA, Whipstock and Trip Anchor assy 07:45 - 08:30 ' 0.75 !, WINDOWPULD 'CMPLT3 Clean rig floor -Remove all tools from rig floor I~ 08:30 - 09:30 1.00'1 CASE ', RURD CMPLT3 P/U csg equip from beaver slide - PU slim hole MWD tools - RU 4.5" I ', csg tools. I 09:30 - 12:00 ', I 2.50', CASE ~~ PULR CMPLT3 II ; RIH w/ 4.5" D Sand Liner - 50 jts (2,200') II ', !, I Trip IN Actual Gain = 34 BBLs (Galt = 32.78 BBLs) I Trip OUT Actual Fill = 41 BBLs (Galt = 35.18 BBLs) 12:00 - 16:30 4.50 ~, CASE II PULR ! CMPLT3 , RIH w/ 4.5" D Sand Liner to 4,391' MD -Tag up - LD 2 jts of tubing and I ', I ', i !pull to 4,240' and turn pipe -attempt stab @ window3 times with same ', I I ! I; procedure then continue RIH w! Liner I 16:30 - 17:30 ', 1.00'1 CASE L, PULR ',CMPLT3 ' PU Liner running tool and Slim Hole MWD - MU same and Orient -Rig 1 1 ' :Down Casing Tools. 1,17:30 - 20:15 II, 2.7511 CASE 'i RUNL I CMPLT3 '; RIH w/ Liner on DP -Shallow test MWD on first stand -Continue RIH w/ Printed: 4/12/2006 1:53:21 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To '! Hours '! Code .Sub Code 3/10/2006 ;17:30 - 20:15 ~, 2.75 ~I CASE ~ RUNL 20:15 - 21:30 21:30 - 00:00 3/11/2006 ~!100:00 - 01:45 I 101:45 - 02:15 02:15 - 03:00 03:00 - 03:45 3/12/2006 03:45 - 05:15 05:15 - 10:30 '' 10:30 - 12:00 12:00 - 15:15 15:15 - 17:30 17:30 - 22:30 22:30 - 00:00 00:00 - 01:00 100:00 - 01:00 01:00 - 01:30 01:00 - 01:30 .01:30 - 02:00 01:30 - 02:00 02:00 - 06:30 02:00 - 06:30 06:30 - 07:00 06:30 - 07:00 07:00 - 10:00 07:00 - 10:00 I, 10:00 - 10:30 ~~ 10:00 - 10:30 10:30 - 12:00 10:30 - 12:00 12:00 - 15:00 1.25 CASE (RUNL Phase -_ I~ CMPLT3 CMPLT3 I ~I ~, CMPLT3 CMPLT3 2.501 CMPLTN' TRIP 1.75'; CMPLTN',TRIP 0.50 0.75 0.75 1.50 5.25 1.50 3.25 2.25 5.00 1.50 1.00 1.00 0.50 0.50 0.50 0.50 4.50 4.50 CMPLTN' PULD 'CMPLT3 CMPLTN' PULD 'I CMPLT3 CMPLTN', PULD CMPLT3 RIGMNT'~, RSRV CMPLT3 CMPLTNI PULL CMPLT3 CMPLTNI PULL CMPLT3 CMPLTNI, PULL CMPLT3 CMPLTN'', RURD CMPLT3 CMPLTNI TRIP CMPLT3 CMPLTNITRIP CMPLT3 CMPLTNI TRIP CMPLT3 CMPLTNITRIP CMPLT3 CMPLTNI RURD I, CMPLT3 CMPLTN OTHR ',CMPLT3 CMPLTN RURD 'CMPLT3 CMPLTNI PULD ''~ CMPLT3 CMPLTNI RUNT !.CMPLT3 CMPLTNI RUNT CMPLT3 0.50 i CMPLTN' SLIN 0.50; CMPLTN'ISLIN 3.00' CMPLTN! SLIN 3.00'; CMPLTN'.. SLIN 0.50 CMPLTN', SLIN 0.50' CMPLTN!, SLIN 1.50'', CMPLTNI RUNT CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 1.501 CMPLTNI RUNT I CMPLT3 3.001 CMPLTNI RUNT I CMPLT3 Start: 2/11 /2006 Rig Release: 3/13/2006 Rig Number: Page 17 of 19 Spud Date: 2/12/2006 End: 3/13/2006 Group: Description of Operations DP to 10,785' Liner Depth ~, PU = 150k, SO = 57k II Break Circ @ 35 SPM & 940 psi -Orient High Side and Tag up with 25k Wt -Pull Back up and turn 180? -Pass Thru window 10' - PU and Re-Orient High Side - Re-Tag with 25k -Drop ball and chase @ 3 BPM for 300 strokes -slow to 1.5 BPM and set ball @ 370 strokes -Pressure I up to 3,000 psi to actuate hydraulic set hanger- PU Wt now 125k - ~ Attempt to blow ball seat with 4,000 psi - RU test pump and shear ball @ 4,350 psi -Rig down and Blow down. PJSM -Stand Back Hybrid and HWDP - PU 4 stands Sliders from 1 Derrick and POOH removing Super Sliders (VVVVT Rep Present) PJSM - Con't POOH std bk 4" DP -Removing WWT supersliders from DP - 90 total. The SS's will be shipped to Anchorage to be serviced by WWT. ,Clean rig floor - UD all tools from rig floor - UD WWT super sliders for shipping -Wash rig floor Make Service breaks and UD Baker liner running tool & slim hole MWD !Clear rig floor - UD Baker liner tool out beaver slid and all csg runnig tools, tongs, slips, bowl, ect, PJSM -Slip & Cut drill line (59') and service rig top drive. 'PJSM - UD 207 jts (69 stds) 4" DP from derrick thru/ mouse hole. Con't UD 9 stds Hybrid DCs (1 jt HWDP + 2 - 43/4" Sprial DC) Con't UD 3 stds Hybrid DCs 8~ 9 stds of HWDP push pipe. UD Mouse hole -Clear and pick up rig floor -Pull tbg running tools to rig floor. ~i RIH open ended w/ completion tbg picking up singles from pipe shed 1111 jts) 37 stds POOH w/ completion tbg string and std bk in derrick. I Cont POOH and std bk 4.5" tbg in derrick - (Total 37 stds in derrick) PJSM - Con't POOH std bk 4-1 /2" Tbg string -Rack back 32 stands PU test jt and pull wear bushing - LD same PU Test Jt, Pull Wear ring, LD Same ~I PJSM - PU and RU ESP Tools + Eqipment, clamps, hands tools. PU & RU ESP Tools & Equipment 1 PJSM - PU/MU Motor centralizer,A well pump guage, Motor 418 HP, I Tandem seal section, screen intake, 2 jts 4.5" SCC tbg, Discharge sub, II 3 jts 4.5" SCC. Total 234.37 PJSM, PU & MU Motor Centralizer, Pump Guage, Tandem Seal Section, Screen Intake, 2 jts 4.5" Tbg, Discharge Sub, 3 more jts 4.5" ~iTbg w/ cable clamps ' RU Slick line unit to run ESP pump. RU Slickline Unit ', Run pump on slick line, set packoff and test to 1000 psi / 10 min, run 'and set pump lock. ', Wireline Pump Assy, Pack-off Assy, and Tbg Stop RD Slick line unit. RD Slickline Unit Cont to run 4.5" 12.6# L80 IBTM completion tbg. Ran total 17 jts, 1 'GLM -Run cannon clamp every other connection. ', Cont RIH w/ 4.5" Tbg from derrick (17 jts, 1 GLM & clamps every other 'connection) Cont to run 4.5" 12.6# L80 IBTM completion tbg. With total 47 jts, 2 Printed: 4/12/2006 1:53:21 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To '', Hours Code Code Phase _I _ ---~ _ _ ------ 3/12/2006 i 12:00 - 15:00 3.00 CMPLTNI RUNT CMPLT3 12:00 - 15:00 I! 3.0011 CMPLTN RUNT CMPLT3 I I I 1~~ 15:00 - 18:00 I, 3.00 CMPLTNI TRIP CMPLT3 1 15:00 - 18:00 3.00 CMPLTNI TRIP i CMPLT3 ~' '~' I~ I'' ', I 18:00 - 19:15 1.25' CMPLTNI TRIP '.CMPLT3 3/13/2006 ', 08:45 - 09:15 ! 0.50 09:15 - 10:00 ! 0.75 ',.10:00 - 11:30 1.50 ',11:30 - 12:00 ', 0.50 '',12:00 - 13:30 ' 1.50 13:30 - 14:30 ' 1.00 ,18:00 - 19:15 'ii 1.25 i CMPLTNI, TRIP ;CMPLT3 19:15 - 22:00 ' 2.75' CMPLTN! TRIP ',CMPLT3 I~, ii '.19:15 - 22:00 ICI 2.75' CMPLTN DEOT CMPLT3 !.22:00 - 00:00 I~, 2.00'', CMPLTN' RUNT I CMPLT3 22:00 - 00:00 ~, 2.00 ~' CMPLTN RUNT I~1 CMPLT3 1.00:00 - 05:00 '', 5.00 CMPLTN!. RUNT 'I CMPLT3 05:00 - 06:30 ' 1.50 ~ CMPLTN RUNT CMPLT3 ', 06:30 - 08:45 ' 2.25'x, CMPLTN'', RURD CMPLT3 1,14:30 - 15:30 ', 1.00 15:30 - 15:45 '' 0.25 CMPLTN' DEOT '1 CMPLT3 CMPLTNI,, RURD I CMPLT3 CMPLTNI NUND CMPLT3 CMPLTNI DEOT CMPLT3 .CMPLTNI, NUND CMPLT3 CMPLTN SEAT CMPLT3 CMPLTN FRZP I CMPLT3 CMPLTNI FRZP CMPLT3 Start: 2/11 /2006 Rig Release: 3/13/2006 Rig Number: Page 18 of 19 Spud Date: 2/12/2006 End: 3/13/2006 Group: Description of Operations GLM in hole -Run cannon clamp every other connection. -Control cable would not megger. Double checked meter and coil - NO Test. RIH w/ 4.5" Tbg from derrick w/ ESP clamps every other jt -Gas Lift w/ 2k Shear on top of jt #32 -Test line every 10 stands ... Make it to 1595.5' MD - 47 jts In Hole -ESP line did not test ~~ POOH checking for bad spot in control power cable. Pulled back to I GLM #1 w! 2K shear 1121' -Had smashed spots at each end of 1, mandrel. Megger line and could still not get a reading. I POOH standing Tbg back and testing ESP line - 1,121' -GLM w/ 2k I Shear -line smashed in 2 places (@ top and bottom of concintric offset ', of GLM) 'Cut line -Test from truck to rig floor -Good ... Test down hole no good Con't to POOH GLM #2 - 525' -Cable smashed at top and bottom of mandrel just like #1. Motor cable had been installed in the wrong place running along the GLM outside almost directly across from the concentric shoulder. Cont POOH to bottom of ('Dummy') GLM @ 525' -Cable smashed in 2 'places again (on top and on bottom of GLM) , Test line to Motor -Good -Make splice on Motor control line. "`NOTE`•* Had to cut out 728' of Motor control cable. Will have to ', have two splices at top of hole. #1 -Splice on more cable #2 Splice on ', penitrator lead. ', Test Line down hole -Good I Splice ESP cable -Test same -Good RIH w/ 4.5" completion string from derrick -ESP cable clamps every ~' otherjt - 2K shear GLM @ 1,121'. I RIH w/ 4.5" Completion String from derrick -ESP cable clamps every otherjt - 2k Shear GLM @ 1,121' Con't RIH w/ 4.5" ESP completion from derrick. Cannon clamp every 11 other joint. Test cable every 1000' PU tbg hanger on full jt tbg, Orient hanger, MU landing joint ~! Splice control cable to penetrator lead. Install penetrator and hookup to cable. ~!, Plug into penetrator and test cable. All test "OK" 'I Land hanger - RILDS and torque to spec -Test upper and lower hanger seals to 5000 psi f/ 10 min "OK" (@ landing PU wt 133K - Dn wt 125K ) ~~~ ND BOP stack and set back on stump. Test ESP Cable "OK" ~ NU Vetco /Gray Production Tree Testing tree void to 5000K psi -Test tree to 5000K psi -Test ECP cable "OK" ~, Scaffold up around tree -Pull 2 way check -Rig up to Freeze protect ~~ well. We will pump 186 bbls diesel down the annulus and taking returns thru the tbg to the willis choke. PR Max 4 BPM. ~~ Start pumping 4 BPM = 600 psi and finish pumping 4 BPM 1050 psi. Pumped 186 bbls diesel. ;Tbg psi 170 , IA 400, OA 0 ,Scaffold up around tree -Pull 2 way check -Rig up to Freeze protect well. We will pump 186 bbls diesel down the annulus and taking returns thru the tbg to the willis choke. PR Max 4 BPM. Printed: 4/12/2006 1:53:21 PM Printed: 4/12/2006 1:53:21 PM Halliburton Companyi Global Report ('owpau~: ConocoPhillipsAlaska Inr. I)aic: 4i 1112006 lime: 16.0325 Parr. t I~ietd: Kupanik River Unit Cu-ordinatef~~f:) Re ference: Well: 1J-159, Tru e North Sic. Kuparuk 1J Pad vertical ("f~'11) Refe rence: 1J-159L2: 109-0 ~~ell: 1 J-'159 Section (BSI Refere nce: Well (O OON,O OOF_,O OOAziI 11cII~iaUc 1J-159L2 Snn~cv (calculation ~Icihod: Minimum Curvatu re 11b: Oracle Survey: Start Date: Company: Engineer: Tool: Tied-to: Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic M odel: bggm2005 Site: Kuparuk 1J Pad Site Position: Northing: 5945919.64 ft Latitude: 70 15 46.258 N From: Map Easting: 558789.95 ft Longitude: 149 31 29.007 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergen ce: 0.45 deg Well: 1J-159 Slot Name: Well Position: +N/-S -71.86 ft Northing: 5945846.80 ft • Latitude: 70 15 45.551 N +E/-W -126.82 ft Easting : 558663.71 ft Longitude: 149 31 32.697 W Position Uncertainty:. 0.00 ft = Wellpath: 1J-159L2 Drilled From: 1J-159PB1 500292329761 Tie-on Depth: 4165.31 ft Current Datum: 1J-159L2: Height 109.00 ft Above System Datum: Mean Sea Level Magnetic Data: 2/9/2005 Declination: 24.57 deg Field Strength: 57557 nT Mag Dip Angle: 80.76 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 0.00 Survey Program for Definitive Wellpath Date: 4/11/2006 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft 50.00 717.00 1J-159PB1 gyro (50.00-717.00) CB-GYRO-SS Camera based gyro single shot 749.61 1403.57 1J-159 (717-1449) (749.61-1403 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1449.80 1549.80 1J-159P61 gyro(1449-1549) (144 CB-GYRO-SS Camera based gyro single shot 1619.68 4165.31 1J-159 (1619.68-5751.68) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4246.00 10841.95 1J-159L2 (4246.00-10841.95) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey 1IU Intl ~zim ll'U tits 7~'I) \;S t:~1 SlaliA 11ap1; ~foni ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945846.80 558663.71 TIE LINE 50.00 0.36 208.13 50.00 -59.00 -0.06 -0.03 5945846.74 558663.68 CB-GYRO-SS 100.00 0.32 197.19 100.00 -9.00 -0.33 -0.15 5945846.47 558663.56 CB-GYRO-SS 200.00 0.32 216.08 200.00 91.00 -0.83 -0.39 5945845.97 558663.32 C6-GYRO-SS 264.00 0.65 197.76 264.00 155.00 -1.32 -0.61 5945845.48 558663.11 CB-GYRO-SS 355.00 0.37 95.03 354.99 245.99 -1.83 -0.48 5945844.96 558663.25 CB-GYRO-SS 444.00 2.89 49.19 443.95 334.95 -0.39- 1.51 5945846.42 558665.22 CB-GYRO-SS 534.00 5.58 38.99 533.70 424.70 4.49 5.98 5945851.34- 558669.65 CB-GYRO-SS 626.00 8.98 35.44 624.94 515.94 13.82 12.96 5945860.72 558676.56 CB-GYRO-SS 717.00 13.78 33.39 714.13 605.13 28.67 23.05 5945875.64 558686.53 CB-GYRO-SS 749.61 14.47 29.58 745.75 636.75 35.45 27.20 5945882.46 558690.63 MWD+IFR-AK-CAZ-SC 842.05 16.42 27.05 834.85 725.85 57.13 38.84 5945904.23 558702.10 MWD+IFR-AK-CAZ-SC 934.49 16,12 24.17 923.59 814.59 80.48 50.04 5945927.66 558713.11 MWD+IFR-AK-CAZ-SC ~ 978.89 15.93 26.88 966.27 857.27 91.54 55.32 5945938.76 558718.31 MWD+IFR-AK-CAZ-SC 1025.72 15.66 29.47 1011.33 902.33 102.77 61.33 5945950.04 558724.23 MWD+IFR-AK-CAZ-SC Halliburton Company Global Report ('omp:ui~: ConocuPhillips Alaska Inc. I)atc: 4i 11/2006 I inic: 16.0325 I':~,r. Ficl~: Kuparuk River Unit (u-~~r~JinatclSl:) Kcfcrcncc: Well: 1J-159. True North bite: Kuparuk 1J Pad ~ crtical (I~~ 1)1 Itcferenre: iJ-159L2: 109.0 ~~dl: 1J-159 tieciiun ~~~NI ftefcrcnce: Well i0 00N.0 ODE.0-OOAzi) l~ell~iarh: 1J-159L2 tiurcc~~ ('alcul:~tiun ~Icth~xl: Minimum Curvature Uh: Oracle tiurccc ~IU Incl Azim l~~U des 1 ~I) \;ti P:;~1 ~la~iA ~Ia1~F~. Tnnl ft deg deg ft ~ ft ft ft ft ft 1063.68 15.73 30.50 1047.87 938.87 111.67 66.46 5945958.97 558729.30 MWD+IFR-AK-CAZ-SC 1124.97 15.49 33.39 1106.90 997.90 125.66 75.18 5945973.03 558737.91 MWD+IFR-AK-CAZ-SC 1217.44 16.35 39.14 1195.83 1086.83 146.07 90.20 5945993.55 558752.76 MWD+IFR-AK-CAZ-SC 1309.86 20.27 41.59 1283.56 1174.56 168.14 109.04 5946015.77 558771.43 MWD+IFR-AK-CAZ-SC 1403.57 25.11 44.48 1369.99 1260.99 194.48 133.76 5946042.30 558795.94 MWD+IFR-AK-CAZ-SC 1449.80 25.72 48.64 1411.75 1302.75 208.11 148.17 5946056.04 558810.24 CB-GYRO-SS 1499.80 26.89 50.63 1456.57 1347.57 222.45 165.05 5946070.51 558827.01 CB-GYRO-SS 1549.80 26.01 51.60 1501.34 1392.34 236.43 182.39 5946084.62 558844.23 CB-GYRO-SS 1619.68 26.54 49.51 1564.00 1455.00 256.09 206.27 5946104.46 558867.96 MWD+IFR-AK-CAZ-SC 1680.87 29.46 51.24 1618.02 1509.02 274.39 228.40 5946122.93 558889.95 MWD+IFR-AK-CAZ-SC 1772.82 30.78 54.80 1697.56 1588.56 302.11 265.26 5946150.94 558926.59 MWD+IFR-AK-CAZ-SC 1866.42 30.99 55.49 1777.89 1668.89 329.57 304.69 5946178.70 558965.80 MWD+IFR-AK-CAZ-SC 1959.63 32.44 57.34 1857.18 1748.18 356.66 345.52 5946206.10 559006.40. MWD+IFR-AK-CAZ-SC 2050.50 31.68 64.11 1934.22 .1825.22 380.24 387.51 5946230.01 559048.21 MWD+IFR-AK-CAZ-SC 2144.19 30.77 69.13 2014.35 1905.35 399.52 432.05 5946249.64 559092.59 MWD+IFR-AK-CAZ-SC 2236.02 29.86 73.73 2093.63 1984.63 414.30 475.95 5946264.75 559136.37 MWD+IFR-AK-CAZ-SC 2300.28 28.53 78.34 2149.73 2040.73 421.88 506.34 5946272.57 559166.70 MWD+IFR-AK-CAZ-SC 2322.58 28.21 80.61 2169.36 2060.36 423.82 516.76 5946274.59 559177.10 MWD+IFR-AK-CAZ-SC 2422:10 27.18 88.20 2257.50 2148.50 428.37 562.70 5946279..50 559223.00 MWD+IFR-AK-CAZ-SC 2479.77 25.89 92.10 2309.10 2200.10 428.32 588.45 5946279.65 559248.75 MWD+IFR-AK-CAZ-SC 2572.77 26.16 98.98 2392.69 2283.69 424.38 629.00 5946276.02 559289.32 MWD+IFR-AK-CAZ-SC 2668.69 26.35 108.60 2478.75 2369.75 414.28 670.08 5946266.25 559330.47 MWD+IFR-AK-CAZ-SC 2761.93 27.37 119.14 2561.98 2452.98 397.24 708.43 5946249.50 559368.96 MWD+IFR-AK-CAZ-SC 2852.14 28.67 128.27 2641.65 2532.65 373.72 743.55 5946226.27 559404.25 MWD+IFR-AK-CAZ-SC 2947.41 32.19 138.44 2723.84 2614.84 340.55 778.36 5946193.37 559439.32 MWD+tFR-AK-CAZ-SC 3041.26 35.21 147.66 2801.96 2692.96 298.95 809.45 5946152.01 559470.73 MWD+IFR-AK-CAZ-SC 3134.05 38.69 155.81 2876.15 2767.15 249.84 835.66 5946103.12 559497.32 MWD+IFR-AK-CAZ-SC 3227.21 44.67 164.51 2945.75 2836.75 191.62 856.38 5946045.07. 559518.49 MWD+IFR-AK-CAZ-SC 3320.49 51.09 171.09 3008.32 2899.32 124.06 870.78 5945977:63 559533.41 MWD+IFR-AK-CAZ-SC 3414.92 52.58 175.27 3066.69 2957.69 50.37 879.56 5945904.02 559542.77 MWD+IFR-AK-CAZ-SC 3507.84 52.22 175.12 3123.38 3014.38 -22.99 885.73 5945830.71 559549.51 MWD+IFR-AK-CAZ-SC 3601.74 51.76 175.40 3181.20 3072.20 -96.72 891.85 5945757.04 559556.20 MWD+IFR-AK-CAZ-SC 3695.29 51.60 174.04 3239.21 3130.21 -169.80 898.60 5945684.02 559563.52 MWD+IFR-AK-CAZ-SC 3789.71 55.75 174.70 3295.13 3186.13 -245.49 906.05 5945608.40 559571.56 MWD+IFR-AK-CAZ-SC 3882.32 60.01 172.71 3344.36 3235.36 -323.43 914.68 5945530.54 559580.79 MWD+IFR-AK-CAZ-SC 3977.16 64.36 175.95 3388.62 3279.62 -406.87 922.91 5945447:18 559589.68 MWD+IFR-AK-CAZ-SC 4071.75 68.20 177.90 3426.66 3317.66 -493.32 927.54 5945360.77 559594.97 MWD+IFR-AK-CAZ-SC 4165.31 71.85 179.96 3458.62 3349.62 -581.22 929.16 5945272.90 559597.28 MWD+IFR-AK-CAZ-SC -4246.00 75.27 183.75 3481.46. 3372.46 -658.54 926.63 5945195.56 559595.36 MWD+IFR-AK-CAZ-SC 4352.32 83.14 182.00 3501.36 3392.36 -762.76 921.42 5945091.31 559590.96 MWD+IFR-AK-CAZ-SC 4444.75 88.64 185.75 3507.99 3398.99 -854.69 915.18 5944999.35 559585.43 MWD+IFR-AK-CAZ-SC 4537.52 91.24 188.75 3508.08 3399:08 -946.70 903.48 5944907.26 559574.45 MWD+IFR-AK-CAZ-SC 4631.68 90.50 188.64 3506.65 3397.65 -1039.76 889.24 5944814.09 559560.94 MWD+IFR-AK-CAZ-SC 4723.27 90.30 186.20 3506.01 3397.01 -1130.58 877.42 5944723.20 .559549.82 MWD+IFR-AK-CAZ-SC 4817.04 91.16 183.82 3504.82 3395.82 -1223.98 869.23 5944629.75 559542.36 MWD+IFR-AK-CAZ-SC 4913.56 92.10 182.97 3502.07 3393.07 -1320.29 863.52 5944533.41 559537.40 MWD+IFR-AK-CAZ-SC 5006.84 93.09 182.11 3497.85 3388.85 -1413.38 859.39 5944440.30 559534.00 MWD+IFR-AK-CAZ-SC 5097.71 89.58 184.48 3495.73 3386.73 -1504.05 854.16 5944349.59 559529.48 MWD+IFR-AK-CAZ-SC 5191.14 90.81 .187.68 3495.41 3386.41 -1596.94 844.27 5944256.64 559520.31 MWD+IFR-AK-CAZ-SC 5283.77 90.78 188.97 3494.13 3385.13 -1688.58 830.86 5944164.90 559507.62 MWD+IFR-AK-CAZ-SC 5379.37 90.19 189.35 3493.32 3384.32 -1782.96 815.64 5944070.42 559493.14 MWD+IFR-AK-CAZ-SC 5471.68 92.60 189.46 3491.07 3382.07 -1874.00 800.56 5943979.28 559478.77 MWD+IFR-AK-CAZ-SC 5564.45 92.84 188.93 3486.67 3377.67 -1965.47 785.76 5943887.70 559464.68 MWD+IFR-AK-CAZ-SC Halliburton Company Global Report ('~nnpan~; Conor_oPhillipsAlaska Inc. Field: Kupanik River U nit Site: Kuparuk 1J Pad ~~ ell: 1 J-159 1Vcllhath: 1 J-159L2 Surcc~ III) Inrl liim ft deg deg 5659.10 90.84 187.10 5752.49 89.82 185.64 5845.24 90.75 186.52 5938.73 91.06 186.80 6032.56 91.06 188.46 6126.75 91.16 183.17 6219.21 91.42 181.07 6312.37 90.81 181.40 6405.96 91.73 181.88 6498.59 91.36 181.46 6593.82 91.23 180.17 6686.96 89.88 181.36 6780.58 92.29 179.17 6874.17 90.93 179.51 6965.77 90.24 177.27 7060.67 89.81 179.65 7152.39 92.29 179.53 7246.47 91.42 178.88 7340.39 91.17 177.56 7433.75 89.33 177.40 7528.78 91.89 177.93 7619.98 91.71 177.06 .7713.40 90.06 179.10 7805.04 93.21 182.85 7897.40 90.61 181.64 7992.07 85.43 182.99 8087.75 85.68 182.19 8181.63 . 86.36 182.24 8280.94 87.41 182.07 8367.57 87.66 180.88 8462.05 .93.34. 182.29 8555.01 91.36 180.69 8648.56 92.39 178.08 8740.72 90.87 178.67 8834.48 91.98 178.74 8927.49 92.04 178.23 9022.08 91.55 178.16 ll 11 ft 3483.63 3483.09 3482.63 3481.16 3479.42 3477.59 3475.51 3473.70 3471.62 3469.13 3466.98 3466.07 3464.30 3461.67 3460.74 3460.69 3459.01 3455.97 3453.85 3453.44 3452.43 3449.56 3448.12 3445.50 3442.42 3445.69 3453.11 3459.63 3465.02 3468.75 3467.92 3464.11 3461.05 3458.43 3456.10 3452.84 3449.87 9114.64 92.17 178.24 3446.87 9209.07 93.13 179.99 3442.50 9293.98 91.49 181.32 3439.08 9395.00 90.43 182.95 3437.39 9487.88 93.34 182.25 3434.33 9581.60 90.99 180.95 3430.79 9670.34 89.49 181.34 3430.42 9762.79 88.46 180.80 3432.07 9853.81 90.61 180.10 3432.81 9944.95 90.25. 179.48 3432.13 10037.67 88.90 179.27 3432.82 10128.75 89.82 180.38 3433.83 10216.49 89.57 182.13 3434.30 10307.47 89.45 180.53 3435.08 10400.96 88.06 179.64 3437.11 ~)LitC: 4/11/2006 Cimc: 16:0~~25 Pair: 3 ('u-ur~inatc(\H:) Rcii•rencc: WeL 1J-159, True North ~ crtical (1~ ~)) Nrfcrcncc: 1 J-159L2 109.0 ticrtiun t~ S) Hcfcrcucc: Well (0.OON,O.ODEO.OOAzi) ~uncc('alculation 1lcthnd: Minimum Curvature Uh: OraCle 5~~1~D V'S f_:11' ~iahA Vahf: l~nnl ft ft ft ft ft 3374.63 -2059.14. 772.57 5943793.94 559452.22 MWD+IFR-AK-CAZ-SC 3374.09 -2151.95 762.21 5943701.06 559442.58 MWD+IFR-AK-CAZ-SC 3373.63 -2244.17 752.38 5943608.77 .559433.48 MWD+IFR-AK-CAZ-SC 3372.16 -2337.02 741.54 5943515.85 559423.36 MWD+IFR-AK-CAZ-SC 3370.42 -2430.00 729.09 5943422.79 559411.63 MWD+IFR-AK-CAZ-SC 3368.59 -2523.65 719.55 5943329.07 559402.83 MWD+IFR-AK-CAZ-SC 3366.51 -2616.02 716.13 5943236.69 559400.13 MWD+IFR-AK-CAZ-SC 3364.70 -2709.14 714.12 5943143.56 559398.85 MWD+IFR-AK-CAZ-SC 3362.62 -2802.67 711.44 5943050.03 559396.90 MWD+IFR-AK-CAZ-SC 3360.13 -2895.23 708.74 5942957.46 559394.92 MWD+IFR-AK-CAZ-SC 3357.98 -2990.42 707.39 5942862.27 559394.31 MWD+IFR-AK-CAZ-SC 3357.07 -3083.54 706.15 5942769.15 559393.79 MWD+IFR-AK-CAZ-SC 3355.30 -3177.13 705.71 5942675.57 559394.09 MWD+IFR-AK-CAZ-SC 3352.67 -3270.68 .706.79 5942582.04 559395.89 MWD+IFR-AK-CAZ-SC 3351.74 -3362.23 709.36 5942490.52 559399.18 MWD+IFR-AK-CAZ-SC 3351.69 -3457.09 711.91 5942395.69 559402.47 MWD+IFR-AK-CAZ-SC 3350.01 -3548.78 712.57 5942304.02 559403.84. MWD+IFR-AK-CAZ-SC 3346.97 -3642.80 713.88 5942210:02 559405.87 MWD+IFR-AK-CAZ-SC 3344.85 -3736.65 716.79 5942116.20 559409.52 MWD+IFR-AK-CAZ-SC 3344.44 -3829.92 720.90 5942022.98 559414.35 MWD+IFR-AK-CAZ-SC 3343.43 -3924.86 724.77 5941928.09 559418.96 MWD+IFR-AK-CAZ-SC 3340.56 -4015.92 728.75 5941837.06 559423.66 MWD+IFR-AK-CAZ-SC 3339.12 -4109.27 731.88 5941743.75 559427.51 MWD+IFR-AK-CAZ-SC 3336.50 -4200.83 730.33 5941652.19 559426.67 MWD+IFR-AK-CAZ-SC 3333.42 -4293.06 726.71 5941559.94 559423.77 MWD+IFR-AK-CAZ-SC 3336.69 -4387.56. 722.89 5941465.42 559420.69 MWD+IFR-AK-CAZ-SC 3344.11 -4482.86 718.58 5941370.11 559417.12 MWD+IFR-AK-CAZ-SC 3350.63 -4576.44 714.96 5941276.51 559414.23 MWD+IFR-AK-CAZ-SC 3356.02 -4675.53 711.23 5941177.40 559411.28 MWD+IFR-AK-CAZ-SC 3359.75 -4762.05 709.01 5941090.88 559409.72 MWD+IFR-AK-CAZ-SC 3358.92 -4856.45 706.39 5940996.47 559407.85 MWD+IFR-AK-CAZ-SC 3355.11 -4949.29 703.98 5940903.62 559406.16 MWD+IFR-AK-CAZ-SC 3352.05 -5042.78 704.98 5940810.15 559407.89 MWD+IFR-AK-CAZ-SC 3349.43 -5134.86 707.59 5940718.10 559411.22 MWD+IFR-AK-CAZ-SC 3347.10 -5228.57 709.71 5940624.42 559414.07 MWD+IFR-AK-CAZ-SC 3343.84 -5321.49 712.17 5940531.54 559417.25 MWD+IFR-AK-CAZ-SC 3340.87 -5415.98 715.15 5940437.07 559420.96 MWD+IFR-AK-CAZ-SC 3337.87 -5508.45 718.05 5940344.64 559424.59 MWD+IFR-AK-CAZ-SC 3333.50 -5602.76 719.51. 5940250.35 559426.78 MWD+IFR-AK-CAZ-SC 3330.08 -5687.59 718.54 5940165.53 .559426.47 MWD+IFR-AK-CAZ-SC 3328.39 -5788.52 714.78 5940064.58 559423.49 MWD+IFR-AK-CAZ-SC 3325.33 -5881.25 710.57 5939971.83 559420.00 MWD+IFR-AK-CAZ-SC 3321.79 -5974.85 707.95 5939878.22 559418.12 MWD+IFR-AK-CAZ-SC 3321.42 -6063.57 706.18 5939789.50 559417.04 MWD+IFR-AK-CAZ-SC 3323.07 -6155.99 704.45 5939697.08 559416.03. MWD+iFR-AK-CAZ-SC 3323.81 -6247.00 703.74 5939606.07 559416.03 MWD+IFR-AK-CAZ-SC 3323.13 -6338.13 704.07 5939514.95 .559417.07 MWD+IFR-AK-CAZ-SC ~ 3323.82 -6430.84 705.08 5939422.26 55941$.80 MWD+IFR-AK-CAZ-SC 3324.83 -6521.92 705.36 5939331.20 559419.79 MWD+IFR-AK-CAZ-SC ~ 3325.30 -6609.63 703.44 5939243.49 559418.55 MWD+IFR-AK-CAZ-SC 3326.08 -6700.58 701.33 5939152.53 559417.15 MWD+IFR-AK-CAZ-SC 3328:11 -6794.04 701.19 5939059.08 559417.74 MWD+IFR-AK-CAZ-SC Halliburton Company Global Report ('nw~,au~: ConocoPhillips Alaska Inc. Ustc: .4111/2000 Cimc: 16.0325 Pshc: 1 Field: Kuparuk River U nit C~~-urdina~tcl~l.) Reference: Well: 1J-159. True North bite: Kuparuk 1J Pad ~crric,il (I~~l>I Reference: 1J-159L2 109.0 ~~ell: 1J-1~9 Sccliun IBS) Reference: Well (O OON_O.OOE O OOAziI 1~'rllp:rth: 1J-159L2 Sung C.ilculalim~ )tcthud: Minim um Curvature Uh: Oracle Sm~~ ct VIII Intl Aiiru llll ti~~ ll U ~ \r~ti 1~~,11' 11a~iA 11.~~iE. Ind ft deg deg ft ft ft ft ft ft 10490.97 87.84 179.81 3440.33 3331.33 -6883.99 701.62 5938969.14 559418.87 MWD+IFR-AK-CAZ-SC 10581.99 89.92 181.57 3442.11 3333.11 -6974.98 700.53 5938878.16 559418.48 MWD+IFR-AK-CAZ-SC 10671.84 92.47 181.30 3440.24 3331.24 -7064.78 698.28 5938788.36 559416.94 MWD+IFR-AK-CAZ-SC 10762.49 94.08 180.91 3435.06 3326.06 -7155.26 696.53 5938697.87 559415.89 MWD+IFR-AK-CAZ-SC 10841.95 94.51 180.37 . 3429.11 3320.11 -7234.49 695.65 5938618.64. 559415.63 MWD+IFR-AK-CAZ-SC 10884.00 94.51 180.37 3425.80 ., 3316.80 -7276.41 695.38 5938576.73 559415.68 • PROJECTED to TD ~. ,,. :.;:.. ._ s N l '1 KRU 1 J-159 ' z- Proposed Producer 3~ 20~OOs0 ~~-~~~ Confidential wells are red SFD 1/18/2006 ~ a i res '"" ~, ~.,- ~ -~ sa~~o '~ 600? 7000 _ _ _ ~r _. --- soon . sooo loooa l.r-lS~`~ LZ ~~' 1100 1J-154L1 /~-I~~,L1 2 Feet 4 1,444 2,444 3,444 4,444 • FW: 1J-1 S9 L2 (wp06).pdf • • Subject: FW: 1J-15~> L2 (wp06).pdf From: "Reilly, Petrick .I" I'atrick_.f.Reilly~conocophillips.com:= Date: Fri, 20 Jan ?OO~i 1O:-~1:~O -0900 "['o: t~~m i~~~iuncler~uaciit~in.stalc.ak.US Tom, Here is the corrected directional. Sorry for the error and thanks for the help. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick . J . Reif l.yc%~conocop}:i l'.. ..ps , ccr:.t -----Original Message----- From: Hartwig, Dennis D Sent: Friday, January 20, 2006 10:38 AM To: Reilly, Patrick J Subject: FW: 1J-159 L2 (wp06).pdf Importance: High Please pass on my apologies to Mr. Maunder Dennis Hartwig Directional Planner Sperry Drilling Services Office: 265-6024 Cell: 632-2294 Home: 644-2872 Content-Description: 1J-159 L2 (wp06).pdf 1J-159 L2 (wp06).pdf Content-Type: application/octet-stream'' Content-Encoding: base64 ~Q `~ ~t_ ~~ it v~E cc~ c~ ~c~~~ o~~ e~.C~~ co~~~ ~ 1 ~ " ~ ~" l ~ ~ao"~ ~ 1 of 1 1/20/2006 2:09 PM i • I, ~ ~ ~ ~ a ~ ~ ~ ~ ~'~~ ?~ ~ FRANK H. MURKOWSK/, GOVERNOR ~7~1 OIL ~i`~ ~ 333 W. 7~" AVENUE, SUITE 100 C01~TSERQATIOI~T COMD'IISSIOIQ ~~ ANCHORAGE, ALASKA 99501-3539 1 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River, 1J-159L2 ConocoPhillips Alaska, Inc. Permit No: 206-007 Surface Location: 2036' FSL, 2545' FEL, Sec. 35, T 11 N, R 10E, UM Bottomhole Location: 39' FSL, 1864' FEL, Sec. 2, TlON, R10E, UM Dear Mr. Thomas: Enclosed is the approved application .for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is for a new wellbore segment of existing well KRU 1J-159, Permit No. 206-005, API 50-029-23297-00. Production should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager). 206-007 Sincerely, Daniel T. Seamount Jr. Chairman ~«.~•~ ~~ ~ cp DATED this day ofs~ertfll, ~A6{' cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conoco~hillips Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907)265-6830 Email: Randy.L.Thomas@conocophillips.com January 16, 2006 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 RECEIVED JAN 1 8 2p06 Alaska Oil & Gas Cons. Comrniasion Anchorage Re: Applications for Permit to grill, West Sak Producer, 1J-159, iJ-159 Ll, iJ-159 L2 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore producer well, a trilateral horizontal well in the West Sak °A2", "B"and °D" sands. The main bore of the well will be designated lJ- 159, and the lateral bores of the well will be designated 1J-159L1 and 1J-159L2. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of iJ-159 is February 9, 2006. If you have any questions or require any further information, please contact Pat Reilly at 265-6048. ~~~ Sincerely, Randy Thomas Greater Kuparuk Area Drilling Team Leader ~ECE~VEp STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ SAN Y ~ 2006 PERMIT TO DRILL Alaska Oil $ Gas c©ns ~nmm;ss;on A 20 AAC 2s.oos nchora e 1 a. Type of Work: Drill / Redrill Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil / Multiple Zone ^ Stratigraphic Test ^ Service ^ Development Gas ^ Single Zone ^/ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-159L2 ` 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 10900' ~~ TVD: 3399' . 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well ~,Gover mental S ct_ion): ~'~' ~~ ~~ icy, Surface:12933' FSL, 2545' FE Sec. 35, T11 N, R10E, UM' 7. Property Designation: ~ LS ., ~ 1`~ ADL 25661 & 0 ' ~(~, West Sak Oil Pool " Top of Productive Horizon: 1358' FSL, 1623' FEL, Sec. 35, T11 N, R10E, UM 8. Land Use Permit: ALK 471 & 468 13. Approximate Spud Date: 2/9/2006 Total Depth: ~ ~~D,/` /f~tJ4:: rj; L~TIU~v~ f~IOC 39' FSL, 1864' FEL, Sec.,~'~T, , R10E, UM ~ 9. Acres in Property: 2560 14. Distance to *~ ~y~, /~ ~~ Nearest Property: 1,358 7, iy. c 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558664 ~ y- 5945847 ~ Zone- 4 10. KB Elevation (Height above GL): 28' RKB feet 15. Distance to Nearest Well within Pool: 1 J-154 , 1199' @ 10839' 16. Deviated wells: Kickoff depth: 4286 ' ft. Maximum Hole Angle: 91.9° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1579 psig ' Surface: 1192 psig 18. Casing Program ifi ti S Setting Depth Quantity of Cement Size pec ca ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" x 34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCRETE 13.5" 10.75" 45.5# L-80 BTC 2364' 28' 28' 2392' 2207' 470 sx ASLite, 170 sx DeepCRETE 9-7/8" 7-5/8" 29.7# L-80 BTCM 5528' 28' 28' 5556' 3698' 350 sx DeepCRETE 6.75" 4.5" 12.6# L-80 IBTM 6615' 4285' 3482' 10900' 3399' slotted liner ~- 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (tt): Plugs (measured) Effective Depth MD (tt): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Perforation Depth MD (ft): ~ u n f~~ J ~,(!~ Perforation Depth TVD (ft): 20. Attachments: Filing Fee ~ BOP Sketch Drilling Program / Time v. Depth Plot Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Pat Reilly @ 265-6048 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~ ~ ~ Phone ~;Suz~~U Date (~t6/o6 P r d b har All Drak Commission Use Only Permit to Drill Number: ~~~ _ ~-%~ API Number: 50-~`~- ~~.~ 7"~j Permit Approval Date: ( ~ ~ See cover letter for other requirements Conditions of approval Samples required Yes ^ No ~~ Mud log required Yes ^ No U Hcy~drogen sulfidetmeasures Y ~`^ No ~'"'~ Directional survey required Yes [~ No ^ ,(~ fJ Other. ,~~Q®,k~S ~ `~~~,'~C`STf~S Ql~y~l ~ ~Jd'i`'_ -~;' E~ APPROVED BY Approved by: THE COMMISSION Date: ~ ~ Form 10-401 Revised 06/2004 ~_~~° ~ ~ ~ ~ ~ ~ Submit in Duplicate ~k:... f. ~ ~ 9 5 • Ap~n for Permit to Drill, Well 1J-159 L2 Revision No.O Saved: 13-Jan-06 Permit It -West Sak Well #1J-159 L2 •~°~ r.~ +~l App/ication for Permit to Dril/ Document„ 1~1~Well Mpxirriix~ 1Mell Value Table of Contents 1. Well Name ................................................................................................................. 2 q ......................... 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 Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program ............................................................................ 3 Requirements of 20 AAC 25.005(c)(6) ...............................................................................•--................. 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 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) .....-•-•---•-•-•-• ............................................................................... 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-159L2 PERMIT IT Page 1 of 6 Printed: 13-Jan-O6 OR!GIN.AL App~n for Permit to Drill, Well 1J-159 L2 Revision No.O Saved:13-Jan-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 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 2Q AAC25.1140(b). For a we/! with multip/e we//branches, each branch must similarly be identified by a unique name andAPl number by adding a suffix to the name designated for the we// by the operator and to the number assigned to the we// by the commission. The well for which this Application is submitted will be designated as iJ-159 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 following items, except for an item already on file with the commission and identified in the app/icatron; (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed /ocation of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section /mes (B) the coordinates of the proposed location of the wel! at the surface, referenced to the state plane coordinate system for this state as maintained by the lUationa/Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the wet/ at the top of each objective formation and at total depth; Location at Surface 2 036' FSL 2 545' FEL, Section 35 T11N, R10E ' ASPZone 4 NAD27Coord/nates RKB Elevation 109.0' AMSL Northings.' 5,945,846 Eastings; 558,663 Pad Elevation 81.0' AMSL Location at Top of Productive Interval West Sak "D" Sand 1,358' FSL, 1,623' FEL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 4,286 Northings; 5,945,170 Eastings; 559,592 Total ~ertica/ De th RKB; 3 482 Total I/ertica/ De th SS.' 3,373 ~ ~~~ fFtB:o~ Location at Total De th 39' FSL, 1,864' FEL, Section R10E ~ -Tit.~fv ASP Zone 4 NAD 27 Coordinates Measured e th, RKB,' 10,900 Northings; 5,938,577 Eastings; 559,409 Total ~ertica/De th RKB,' 3 399 Total vertical De th, SS.' 3,289 and (D) other information required by 10 AAC Z5.050(b); 2.w~ 1J-159L2 PERMIT IT Page 2 of 6 "'a. I~ Printed: 13-Jan-O6 i ~ ~'L Ap~n for Permit to Drill, Well 1 J-159 L2 Revision No.O Saved: 13-Jan-06 Requirements of 20 AAC 25.050(b) If a we!/ is to be intentionalfy deviated, the app/ication for a Permit to Dri!/ (Form 10-401) must (1) inclode a p/at, drawn to a sur"tab/e sca/e, showing the path of the proposed weldbore, inc/uding a//adjacent we//bores within 200 feet of any portion of the proposed we/% Please see Attachment 1: Directional Plan and (2) for at/ we//s within 200 feet of the proposed weUbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been 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 app/ication for a Permit to Dri/l must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the applicatian.• (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC25, 036, or 20 AAC 25.037, as applicab/e; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete the well. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except far an item a/ready on file with the commi _sian and identified in the application: (4) information on drilling hazards, inc/uding (A) the maximum downho% pressure that maybe encountered, criteria used to determr`ne 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 1,214 psi, calculated thusly: MPSP =(3,508 ft T~/D)(0.45 - 0.11 psi/ft) =1,192 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 ho% problems such as abnonna/!y geo pressured strata, lost circulation zones, and zones that have a propensity for dih`erentia/sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Dri// must be accompanied by each of the fo/%wing items, except for an item already on fi/e with the commission and identified in the app/ication: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(fJ; The parent wellbore, 1J-159, 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-159L2 PERMIT IT Page 3 of 6 Printed: 13-Jan-O6 ~~ Ap~n for Permit to Drill, Well 1J-159 L2 Revision No.O Saved: 13-Jan-06 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An app/ication for a Permit to Drr// must be accompanied by each of the fo/lowing 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 20 AAC 25.030, and a description of any slotted /iner, pre- perforated /iner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weigh Length MD/TI/D MD/TVD OD in in t /b/ft Grade Connection ft ft ft Cement Pro ram 4-1/2 6-3/4" A Sand 1Z.6 L-80 IBTM 6,026 5,556 / 3,698 7,857 / 3,641 Slotted- no cement slotted Lateral (1J-159) 4-1/2 6-3/4" B Sand 12.6 L-80 -IBTM 7,113 4,588/ 3,548 11,205 / 3,474 Slotted- no cement slotted Lateral (iJ-159 Li) 4-1/2 6-3/4" D Sand 12.6 L-80 IBTM 7,521 4,285/ 3,482 10,900 / 3,399 Slotted- no cement slotted Lateral (1J-159 L2) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Dri// must be accompanied by each of the fo/%wing items, earcept 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 AAC25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); No diverter system will be utilized during operations on iJ-159 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 fol%wing items, except far an item already on frle with the commission and identified in the app/ication: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro, Mineral Oil Base) Value Densit 8.6 Plastic Viscostiy 15 - 25 Ib/100 s Yield Point 18.28 cP HTHP Fluid loss (ml/30 min <4 0 @ 200psi & . 150° Oil /Water Ratio 70 / 30 Electrical 650-900 Stabilit 1J-159L2 PERMIT IT Page 4 of 6 Printed: 13-Jan-O6 ~2lGINAL Ap~n for Permit to Drill, Well 1J-159 L2 Revision No.O Saved: 13-Jan-06 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Dril/must be accompanied by each of the fallowing items, except far an item a/ready an file with the commission and identified in the app/ication: (9) for an exploratory or stratigraphic test well, atabu/anon setting out the depths of predicted abnormally geo pressured strata as required by 20 AAC 25, 033(1); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An app/ication far a Permit to DriJ! must be accompanied by each of the following items, except for an item already on file with the commission and identified in the app/ication: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An app/ication far a Permit to Dri// must be accompanied by each of the fot/owing items, except for an item already on file with the commission and identified in the application: (11) for a wet/ drit/ed from an offshore platform, mobi/e bottom-founded structure, jack-up rig, or floating drilling vess% an analysis ofseabed conditions as required by 20AAC25.061(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 Dri!/ must be accompanied by each of the fallowing items, except for an item a/ready on file with the commission and identified in the application: (12) evidence showing that the requirements of20AAC25.025 {&onding}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 app/ication For a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item a/ready on fife 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-159 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 4,285' MD / 3,482' 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 10,900' MD / 3,399' 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. 1J-159L2 PERMIT /T Page 5 of 6 ^ ~ ~ Printed: 13-Jan-O6 • App1~n for Permit to Drill, Well 1J-159 I_2 Revision No.O Saved: 13-Jan-06 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. 10. POOH and lay down drill pipe. 11. RU and run a 4 1/2" ESP completion with backup gaslift. 12. Space out tubing and land tubing in tubinghead. 13. Nipple down BOPE, nipple up tree and test, change over the hole to diesel. 14. Set BPV and RDMO Doyon 141. 15. Rig up wire line unit. Pull BPV. 16. Circulate out well with diesel through the ESP. 17. Set gas lift valves in mandrels. Operate well on gas lift until ESP facilities are ready. 18. Replace gas lift valves with blank dummy valves. 19. Place well on production with ESP. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Dri// music be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified m the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annu/ar disposal operation in the we/l.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 1J Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual. processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 1J-159L2 PERMIT IT Page 6 of 6 Printed: 13-Jan-O6 • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-159 1 J-159 L2 Plan: 1J-159 L2 (wp06) Proposal Report 14 December, 2005 • -"AL.~~JR"'~"Q Sperry Driiling Services ~ ~ ~ N Nd~0 r f/1 ~ r~ J [ t+1 OD N ~p 0 1A ~ F 2~ne ~ ~vmo Z m m o0 Q N a O l.1 ~ O O O ~i~ NOf N ~ l"1 Z~Nt~ C d ~ N ~ > a ~ a ~ ~ ~ ; r ~i~~ R N ~ ~ ~ > j N `~ Y Ya o~ V ad+ N ~ C o~3~a a` ~Upj O v ~ J r v 7 ~ Z J r W ~ ~ W .~- ~ O J ~ ~ j ~ ~ N J r r ~ ~l i C C r c0 fC a a O O O O O O O O O O O O O O O O O O O O O ~ ~ r ~ N N N M ~"~ < (uinl 008) ~:ldaa 12aiUan any i i\ iD O 3 a t0 H N J ~O O ~~ ~ a N n Z+ Of ~ s06 e~ ' N H ~ O ~ ~ ~ $. ~ 3 ~ 0 0o H, 01 O N J O J _ m < ~ ~ ~ ~ ~ N J 00 a 3 0 `o ~ ~ ~ J voi ~ ^ F` h ~ ~ .u ~ ~ O O N ~ V C b e~f ~ 1~ u 0 ~ D ~ c O m m ~ ~ ~ 3 v ~ ~' ~ ~ C O N ~ N ~ O O ~ io C ~ o68 N N J 7 ~ C_ ~ ~ ~ ~ ~ O O ` ~ _ 0o a0 ° ~ v y c ° o M ~ N J O ~ ~ m ~ c O o ~ O o ~ ~ N O 3 ~ r ~ ~ ~ U J ~° H ~ J O ~ O ._ U c ~ ~. N N M °° ' ~ m ~ ~ U_ N R ~ p O O ~ O ; M ~ O ~ in N C t0 .. ~a .~ ~ ~ ~ O 0 ~ ~ Y m N C C ~ N ~ ppOpp Q J U N J O O M N 0 0 N ~ O fD ~ ~ o 3 m ~ ~ ~ o J D g M `~ ~ vOS ~ .. U C V - _ _ _ - _ ~ O Q ~ ~O` ~ ~ ~ ~ ' O r J o '08 R fR N o < ohs J ~Sd O O O N ~O ~~d O O 400 -1200 -1600 -2000 L2: TOW ~ 4286ft MD, 3482ft ND L2: BOW ~ 4298ft MD, 3485ft ND -Drill out 30' Rathole L2: Build ~ 6°1100ft to 69.8° lint - 4328 tt MD, 3490ft LEGEND $ Plan 1J-159, 1J-159 L1, 1J-159 L1 (wp06) VO $ Plan 1J-159, 1J-159, 1J-159 (wp06) VO $ 1J-159 L2 (wp06) -3200 ~ 0 0 m -3600 + t 1= 0 Z -aooo r 0 to 1J-159 L2 T1 (wp06) 1J-159 L2 T2 (wp06)7 1J•159 L2 T3 (wp06) 10 3/a° ^o ,.' ConocoPhillips ° 150 AI<~sk~ 171° 180° L L2: Continue BuildlTum ~ 5°1100ft, 4509ft MD, 3508ft ND I L2: Sall ~ 91.4° Inc : 4630ft MD, 3507ft ND 188° L2: Continue Dir ~ 5°1100ft , 5831ft MD, 3478ft ND L2: Sail ~ 91.6° Inc : 5975ft MD, 3474ft ND L2: Begin GeoSteerin D-Sand 6475ft MD,3460ft ND 181° 180° 180° -5600 -6000 -6400 1J-159 L2 T4 (wp06) CASING DETAILS No ND MD Name Size 1 2207.00 2392.47 10 3/4" 10-3/4 2 3482.00 4285.82 75/8" 7-5/8 3 3399.0010900.08 41/2" 4-1/2 160° 1J-159 L2 T5 (wp06) T M _ L2: BHL ~ 10900ft MD, 3399ft ND Azimuths tc T« re Nor^. -- -- - Magnetlc North: 24.53° Magnetic Field 180° Strength:57579.1nT Dip Ante: 80.72° Date: 11/28/2004 1J-159 L2 T6 (wp06) Model: 6ccmzooa - HALLIBIlRTON a vz° Sperry Drilling Services -2400 -2000 -1600 -1200 -800 X00 0 400 800 1200 1600 2000 2400 2800 3200 West(-)/East(+) (800 ft/in) i LLBORE TARGET DETAILS (MAP CO-ORDINAT Name TVD NDSS +N/-S +E/-W Northing Fasting Shape 1J-159 L2 T5 (wp06) 3398.00 3289 -6803.04 693.94 5939250.00 559409.00 Point 1J-159 L2 T6 (wp06) 3399.00 3290 -7276.09 688.69 5938577.00 559409.00 Point 1J-159 L2 T4 (wp06) 3411.00 3302 -5852.99 699.78 5940000.00 559409.00 Point 1J-159 L2 T2 (wp06) 3432.00 3323 -3952.87 714.59 5941900.00 559409.00 Point 1J-159 L2 T3 (wp06) 3446.00 3337 -4652.91 709.13 5941200.00 559409.00 Point 1J-159 L2 T1 (wp06) 3460.00 3351 -2852.82 726.16 5943000.00 559412.00 Point SECTION DETAILS Sec MD Inc Azi ND NDss +N/-S +E/-W Northing Fasting DLeg TFace VSec Target 1 4285.81 77.000 182.00 3482.00 3373 -678.08 923.12 5945176.00 559592.00 0.00 0.000 678.08 2 4297.81 78.908 182.00 3484.50 3375.5 -689.81 922.71 5945164.27 559591.68 15.90 0.000 689.81 3 4327.81 78.908 182.00 3490.28 3387.28 -719.23 921.69 5945134.84 559590.88 0.00 0.000 719.23 4 4509.23 89.793 182.00 3508.11 3399.11 -899.38 915.40 5944954.66 559586.00 6.00 360.000 899.38 5 4629.68 91.393 187.81 3506.86 3397.86 -1019.33 905.11 5944834.65 559576.64 5.00 74.572 1019.33 6 5831.27 91.393 187.81 3477.64 3368.64 -2209.43 741.95 5943643.43 559422.77 0.00 0.000 2209.43 7 5975.40 91.591 180.60 3473.88 3364.88 -2353.04 731.39 5943499.76 559413.34 5.00 -88.337 2353.04 8 6475.40 91.591 180.60 3460.00 3351 -2852.82 726.16 5943000.00 559412.00 0.00 0.000 2852.82 1J-159 L2 T1 (wp06) 9 6482.07 91.458 180.60 3459.82 3350.82 -2859.49 726.09 5942993.33 559411.98 2.00 178.855 2859.49 10 7575.87 91.458 180.60 3432.00 3323 -3952.87 714.59 5941900.00 559409.00 0.00 0.000 3952.87 1J-159 L2 T2 (wp06) 11 7721.38 88.553 180.43 3431.99 3322.99 X098.36 713.28 5941754.52 559408.82 2.00-176.564 4098.36 12 8276.13 88.553 180.43 3446.00 3337 -4652.91 709.13 5941200.00 559409.00 0.00 0.000 4652.91 1J-159 L2 T3 (wp06) 13 8443.72 91.904 180.45 3445.33 3336.33 -4820.48 707.85 5941032.45 559409.02 2.00 0.333 4820.48 14 9476.84 91.904 180.45 3411.00 3302 -5852.99 699.78 5940000.00 559409.00 0.00 0.000 5852.99 1J-159 L2 T4 (wp06) 15 9523.89 90.963 180.45 3409.82 3300.82 -5900.02 699.42 5939952.97 559409.00 2.00-179.914 5900.02 1610227.03 90.963 180.45 3398.00 3289 -6603.04 693.94 5939250.00 559409.00 0.00 0.000 6603.04 1 J-159 L2 T5 (wp06) 1710281.67 89.871 180.45 3397.60 3288.6 -6657.68 693.51 5939195.36 559409.00 2.00 179.998 6657.68 1810900.09 89.871 180.45 3399.00 3290 -7276.09 688.69 5938577.00 559409.00 0.00 0.000 7276.09 1J-159 L2 T6 (wp06) ANNOTATIONS ND NDss MD Annotation 3482.00 3373 4285.82 L2: TOW ~ 4286ft MD, 3482ft TVD -1358ft FSL 8< 1623ft FEL -Sec 35 - T11 N - 810E 3484.51 3375.51 4297.82 L2: BOW ~ 4298ft MD, 3485ft TVD -Drill out 30' Rathole 3490.28 3381.28 4327.82 L2: Build ~ 6°/100ft to 89.8° lint - 4328 ft MD, 3490ft ND 3508.11 3399.11 4509.24 L2: Continue Build/Tum ~ 5°/100ft , 4509ft MD, 3508ft TVD 3506.86 3397.86 4629.69 L2: Sail ~ 91.4° Inc :46308 MD, 3507ft ND 3477.64 3368.64 5831.28 L2: Continue Dir ~ 5°/100ft , 5831ft MD, 3478ft TVD 3473.88 3364.88 5975.41 L2: Sail ~ 91.6° Inc : 5975ft MD, 3474ft ND 3460.00 3351 6475.41 L2: Begin GeoSteer in D-Sand 6475ft MD, 3460ft ND 3399.00 3290 10900.08 L2: BHL ~ 10900ft MD, 33998 ND : 39ft FSL & 1864ft FEL -Sec 2 - T10N - 810E -- , _ -- «~.L ~ `~ .~~ c ~~~~ ELLBORE TARGET DETAILS (MAP CO-0RDINA Name ND NDSS +N/S +E/-W Northing Easting Shape 1J-159 L2 T5 (wp06) 3398.00 3289 -6603.04 693.94 5939250.00 559409.00 Point 1J-159 L2 T6 (wp06) 3399.00 3290 -7276.09 688.69 5938577.00 559409.00 Point 1J-159 L2 T4 (wp06j 3411.00 3302 -5852.99 699.78 5940000.00 559409.00 Point 1 J-159 L2 T2 (wp06) 3432.00 3323 X952.87 714.59 5941900.00 559409.00 Point 1J-159 L2 T3 (wp06) 3446.00 3337 -4&52.91 709.13 5941200.00 559409.00 Point 1J-159 LZ T1 (wp06) 3460.00 3351 -2852.82 726.16 5943000.00 559412.00 Point SECTION DETAILS Sec MD Inc Azi ND NDss +N/-S +EI-W Northing Easting Leg TFace VSec Target 1 4285.81 77.000 182.00 3482.00 3373 -678.08 923.12 5945176.00 559592.0 0.00 0.000 678.08 2 4297.81 78.908 182.00 3484.50 3375.5 -689.81 922.71 5945164.27 55959 8 15.90 0.000 689.81 3 4327.81 78.908 182.00 3490.28 3381.28 -719.23 921.69 5945134.84 559 0.88 0.00 0.000 719.23 4 4509.23 89.793 182.00 3508.11 3399.11 -899.38 915.40 5944954.66 55 86.00 6.00 360.000 899.38 5 4629.68 91.393 187.81 3506.86 3397.86 -1019.33 905.11 5944834.65 9576.64 5.00 74.572 1019.33 6 5831.27 91.393 187.81 3477.64 3368.64 -2209.43 741.95 5943643.43 559422.77 0.00 0.000 2209.43 7 5975.40 91.591 180.60 3473.88 3364.88 -2353.04 731.39 5943499.7 559413.34 5.00 -88.337 2353.04 8 6475.40 91.591 180.60 3460.00 3351 -2852.82 726.16 594300 559412.00 0.00 0.000 2852.82 1J-159 l2 T1 (wp06) 9 6482.07 91.458 180.60 3459.82 3350.82 -2859.49 726.09 59429.8'3.33 559411.98 2.00 178.855 2859.49 10 7575.87 91.458 180.60 3432.00 3323 -3952.87 714.59 594y+900.00 559409.00 0.00 0.000 3952.87 1J-159 L2 T2 (wp06) 11 7721.38 88.553 180.43 3431.99 3322.99 -4098.36 713.28 59,41754.52 559408.82 2.00-176.564 4098.36 12 8276.13 88.553 180.43 3446.00 3337 -4652.91 709.13 941200.00 559409.00 0.00 0.000 4652.91 1J-159 L2 T3 (wp06) 13 8443.72 91.904 180.45 3445.33 3336.33 -4820.48 707.85941032.45 559409.02 2.00 0.333 4820.48 14 9476.84 91.904 180.45 3411.00 3302 -5852.99 699. 5940000.00 559409.00 0.00 0.000 5852.99 1J-159 L2 T4 (wp06) 15 9523.89 90.963 180.45 3409.82 3300.82 -5900.02 69 .42 5939952.97 559409.00 2.00-179.914 5900.02 1610227.03 90.963 180.45 3398.00 3289 -6603.04 6 3.94 5939250.00 559409.00 0.00 0.000 6603.04 1J-159 L2 T5 (wp06) 1710281.67 89.871 180.45 3397.60 3288.6 -6657.68 93.51 5939195.36 559409.00 2.00 179.998 6657.68 1810900.09 89.871 180.45 3399.00 3290 -7276.09 688.69 5938577.00 559409.00 0.00 0.000 7276.09 1 J-159 L2 T6 (wp06) ~~ `~~. ~~ ~~ ANNOTATIONS ND NDs MD Annotation 3482.00 33 3 4285.82 L2: TOW @ 4286tt MD, 3482ft ND -1358ft FSL 8~ 1623ft FEL -Sec 35 - T11 N - R10E 3484.51 337 .51 4297.82 L2: BOW @ 4298tt MD, 3485ft ND -Drill out 30' Rathole 3490.28 33 .28 4327.82 L2: Build @ 6°/100ft to 89.8° lint - 4328 ft MD, 3490ft ND 3508.11 3 .11 4509.24 L2: Continue Build/Turn @ 5°I100tt , 4509ft MD, 350812 ND 3506.86 397.86 4629.69 L2: Sail @ 91.4° Inc : 4630ft MD, 35 ""~•-•-• 3477.64 3368.64 5831.28 L2: Continue Dir @ 5°/10 1t2 MD, 3478ft ND _ ,,,., ~_.Y_ 3473.88 3364.88 5975.41 L2: Sail @ 91.6° In 512 MD, 3474ft ND 3460.00 3351 6475.41 L2: Begin G eer in DSand 6475ft MD, 346012 ND 3399.0 3290 10900.08 L2: BH 10900ft MD, 3399ft ND : 39ft FSL 8186412 FEL -Sec 10 - T10N - R10E ~~~~~~~~ l Con+acoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-159 Wetlbore: 1J-159 L2 Design: 1J-159 L2 (wp06) • Halliburton Energy Services !-IAl.LIE3Ut~"rphl Planning Repart -Geographic ~ ~~ Speyrry ~ri!lfrtig S~snric~s Local Co-ordinate Reference: Weil Plan 1J-159 TVD Reference: Planning RK6 @ 109:OOft (Doyon 141 (28+81)) MD Reference: Planning RKB ~ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk Rover Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1 J-159 Well Position +N/-S 0.00 ft Northing: 5,945,846.8(1 ft Latitude: 70° 15' 45.551" N +E/-W 0.00 ft Easting: 558,663.71 ft Longitude: 149° 31' 32.697" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft ~ Wellbore 1J-159 L2 _ _ _ _ _ _ I Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°- l°) (nTl I LL -- BGGM2004 11/28/2004 24.531 80.724 57,579 De sign 1 J-159 L2 (wp06 ) - AudR Notes: Version: Phase: PLAN Tie On Depth: 4,285.81 Vertical Section: Depth From (TVD) +N/-S +E/.W Direction (ftl lftl (ft) (°I 28.00 0.00 0.0o iso.oo 12/14/"1005 6:57:36PM Page 2 of 6 COMPASS 2003.11 Build 48 • Haliiburton Energy Services HAt.LiE3UpT`ON ConocoPhillipS Planning Report -Geographic - - --- ---- Alaska Sperry drilling Services Database: EDM 2003.11 Single User Db local Co-ordinate Re#erence: Well Plan iJ-159 Company: GonocoPhillips Alaska (Kuparuk) TVD Referenc®: Planning RKB @ 109:OOft (Doyon 14t (28+&1)) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109,OOft (Doyon 141 (28+81)) Slte: Kuparuk 1J Pad North Reference: True Well: Plan 1J-159 Survey Ca~ulation Method: Minimum Curvature Wellbore: 1J-159 L2 Design: 1J-159 ~2 (wp06) Plan Summary Measured Vertical Dogleg Build Turn Depth IncNnation Azimuth Depth +N/S +EI-W Rat® Rate Rate ° TfO Ift) (°) (°) Iftl (ft) (ft) (°h0+Nt) (°nooft- /looft> ( (') 4,285.81 77.000 182.00 3,482.00 -678.08 923.12 0.00 0.00 0.00 0.000 4,297.81 78.908 182.00 3,484.50 -689.81 922.71 15.90 15.90 0.00 0.000 4,327.81 78.908 182.00 3,490.28 -719.23 921.69 0.00 0.00 0.00 0.000 4,509.23 89.793 182.00 3,508.11 -899.38 915.40 6.00 6.00 0.00 360.000 4,629.68 91.393 187.81 3,506.86 -1,019.33 905.11 5.00 1.33 4.82 74.572 5,831.27 91.393 187.81 3,477.64 -2,209.43 741.95 0.00 0.00 0.00 0.000 5,975.40 91.591 180.60 3,473.88 -2,353.04 731.39 5.00 0.14 -5.00 -88.337 6,475.40 91.591 180.60 3,460.00 -2,852.82 726.16 0.00 0.00 0.00 0.000 6,482.07 91.458 180.60 3,459.82 -2,859.49 726.09 2.00 -2.00 0.04 178.855 7,575.87 91.458 180.60 3,432.00 -3,952.87 714.59 0.00 0.00 0.00 0.000 7,721.38 88.553 180.43 3,431.99 -4,098.36 713.28 2.00 -2.00 -0.12 -176.564 8,276.13 88.553 180.43 3,446.00 -4,652.91 709.13 0.00 0.00 0.00 0.000 8,443.72 91.904 180.45 3,445.33 -4,820.48 707.85 2.00 2.00 0.01 0.333 9,476.84 91.904 180.45 3,411.00 -5,852.99 699.78 0.00 0.00 0.00 0.000 9,523.89 90.963 180.45 3,409.82 -5,900.02 699.42 2.00 -2.00 0.00 -179.914 10,227.03 90.963 180.45 3,398.00 -6,603.04 693.94 0.00 0.00 0.00 0.000 10,281.67 89.871 180.45 3,397.60 -6,657.68 693.51 2.00 -2.00 0.00 179.998 10,900.09 89.871 180.45 3,399.00 -7,276.09 688.69 0.00 0.00 0.00 0.000 12/142005 6:57:36PM Page 3 of 6 COMPASS 2003.11 Build 48 r-` Halliburton Energy Services ~„~~L~~~~~~-~~ CQt'1000 P~l1~A p 5 Planning Report -Geographic _ . _ ._. _. _. ~ Sperry iDrillli~g S+arvicss Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-159 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB.(c~ 109.OQft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planning I?KB @~ 109.OOft (Doyorr t41 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-159 Survey Calculation Method: Minimum Curvature Wellbore: 1J-159 L2 Design: 1J-159 L2 (wp06) Planned Survey 1J-159 L2 (wp06) Map Map MD Inclination Azimuth TVD SSTVD +N/S +E/-W Northing Easting DLSEV Vert Section Iftl (°) l°) Iftl Iftl Ift1 Iftl lftl Ift) 1°rlooftl (ft1 4,285.81 77.000 182.00 3,482.00 3,373.00 -678.08 923.12 5,945,176.00 559,592.00 0.00 678.08 L2: TOW @ 4286ft MD, 3482ft TVD -1358ft FSL 81623ft FE L -Sec 35 - T11 N - R10E - 7518" 4,297.81 78.908 182.00 3,484.50 3,375.50 -689.81 922.71 5,945,164.27 559,591.68 15.90 689.81 L2: BOW @ 4298ft MD, 3485ft TVD -Drill out 30' Rathole 4,300.00 78.908 182.00 3,484.93 3,375.93 -691.96 922.64 5,945,162.12 559,591.62 0.00 691.96 4,327.81 78.908 182.00 3,490.28 3,381.28 -719.23 921.69 5,945,134.84 559,590.88 0.00 719.23 Build @ 6°/ 100ft to 89.8° lint - 4328 ft MD, 3490ft TYD 4,400.00 83.238 182.00 3,501.48 3,392.48 -790.49 919.20 5,945,063.58 559,588.95 6.00 790.49 4,500.00 89.238 182.00 3,508.03 3,399.03 -890.16 915.72 5,944,963.88 559,586.25 6.00 890.16 4,509.23 89.793 182.00 3,508.11 3,399.11 -899.38 915.40 5,944,954.66 559,586.00 6.01 899.38 Continue Build/Turn @ 5°/100ft , 4509ft MD, 3508ft TVD 4,600.00 91.000 186.37 3,507.48 3,398.48 -989.89 908.77 5,944,864.12 559,580.08 5.00 989.89 4,629.68 91.393 187.81 3,506.86 3,397.86 -1,019.33 905.11 5,944,834.65 559,576.64 5.00 1,019.33 Sail @ 91.4° Inc : 4630ft MD, 3507ft TVD ~ 4,700.00 91.393 187.81 3,505.15 3,396.15 -1,088.98 895.56 5,944,764.93 559,567.64 0.00 1,088.98 4,800.00 91.393 187.81 3,502.72 3,393.72 -1,188.03 881.98 5,944,665.79 559,554.83 0.00 1,188.03 4,900.00 91.393 187.81 3,500.29 3,391.29 -1,287.07 868.40 5,944,566.66 559,542.03 0.00 1,287.07 5,000.00 91.393 187.81 3,497.86 3,388.86 -1,386.11 854.82 5,944,467.52 559,529.22 0.00 1,386.11 5,100.00 91.393 187.81 3,495.42 3,386.42 -1,485.16 841.24 5,944,368.38 559,516.42 000 1,485.16 5,200.00 91.393 187.81 3,492.99 3,383.99 -1,584.20 827.66 5,944,269.25 559,503.61 0.00 1,584.20 5,300.00 91.393 187.81 3,490.56 3,381.56 -1,683.25 814.09 5,944,170.11 559,490.81 0.00 1,683.25 5,400.00 91.393 187.81 3,488.13 3,379.13 -1,782.29 800.51 5,944,070.97 559,478.00 0.00 1,782.29 5,500.00 91.393 187.81 3,485.70 3,376.70 -1,881.33 786.93 5,943,971.83 559,465.19 0.00 1,881.33 5,600.00 91.393 187.81 3,483.26 3,374.26 -1,980.38 773.35 5,943,872.70 559,452.39 0.00 1,980.38 5,700.00 91.393 187.81 3,480.83 3,371.83 -2,079.42 759.77 5,943,773.56 559,439.58 0.00 2,079.42 5,800.00 91.393 187.81 3,478.40 3,369.40 -2,178.47 746.19 5,943,674.42 559,426.78 0.00 2,178.47 5,831.27 91.393 187.81 3,477.64 3,368.64 -2,209.43 741.95 5,943,643.43 559,422.77 0.00 2,209.43 Continue Dir ~ 5°/100ft , 5831ft MD, 3478ft TVD 5,900.00 91.491 184.37 3,475.91 3,366.91 -2,277.75 734.66 5,943,575.06 559,416.02 5.00 2,277.75 5,975.40 91.591 180.60 3,473.88 3,364.88 -2,353.04 731.39 5,943,499.76 559,413.34 5.00 2,353.04 Sail @ 91.6° Inc : 5975ft MD, 3474ft TVD 6,000.00 91.591 180.60 3,473.20 3,364.20 -2,377.63 731.13 5,943,475.17 559,413.27 0.00 2,377.63 6,100.00 91.591 180.60 3,470.42 3,361.42 -2,477.58 730.09 5,943,375.22 559,413.01 0.00 2,477.58 6,200.00 91.591 180.60 3,467.65 3,358.65 -2,577.54 729.04 5,943,275.27 559,412.74 0.00 2,577.54 6,300.00 91.591 180.60 3,464.87 3,355.87 -2,677.49 727.99 5,943,175.32 559,412.47 0.00 2,677.49 6,400.00 91.591 180.60 3,462.09 3,353.09 -2,777.45 726.95 5,943,075.37 559,412.20 0.00 2,777.45 6,475.40 91.591 180.60 3,460.00 3,351.00 -2,852.82 726.16 5,943,000.00 559,412.00 0.00 2,852.82 Begin GeoSteer in D-Sand 6475ft MD, 3460ft TVD -1J-159 L2 T1 (wp06) 6,482.07 91.458 180.60 3,459.82 3,350.82 -2,859.49 726.09 5,942,993.33 559,411.98 2.00 2,859.49 6,500.00 91.458 180.60 3,459.37 3,350.37 -2,877.41 725.90 5,942,975.41 559,411.93 0.00 2,877.41 6,600.00 91.458 180.60 3,456.82 3,347.82 -2,977.37 724.85 5,942,875.45 559,411.66 0.00 2,977.37 6,700.00 91.458 180.60 3,454.28 3,345.28 -3,077.33 723.80 5,942,775.50 559,411.39 0.00 3,077.33 6,800.00 91.458 180.60 3,451.74 3,342.74 -3,177.29 722.74 5,942,675.54 559,411.12 0.00 3,177.29 6,900.00 91.458 180.60 3,449.19 3,340.19 -3,277.25 721.69 5,942,575.58 559,410.84 0.00 3,277.25 7,000.00 91.458 180.60 3,446.65 3,337.65 -3,377.22 720.64 5,942,475.62 559,410.57 0.00 3,377.22 7,100.00 91.458 180.60 3,444.10 3,335.10 -3,477.18 719.59 5,942,375.67 559,410.30 0.00 3,477.18 12/14/1005 6:57:36PM Page 4 of 6 COMPASS 2003.11 Build 48 / Halliburton Energy Services Hx1l,.L~BtJpTO1V ~C?I14r~0 5 ~~'ll~~ Planning Report -Geographic -~~- -- ~~~ ~~~ } Sperry DriDing Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-159 Company: ConocoPhillips Alaska (Kuparuk) TYD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 p Project: Kuparuk River Unit MD Reference: Planning RKB ~ 109.OOft (Doyon 1`41 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-159 Survey Calculation Method: Minimum Curvature Wetibore: 1J-159 L2 Design: 1J-159 L2 (wp06) Planned Survey 1J-159 L2 (wp06) i Map Map MD Inclination Azimuth TVD SSTVD +N/.S +E/-W Northing Easting OLSEV Vert Section (ftl (°) (°) (ft) Iftl ln) lftl (ftl (ft) (°/100ft) (ft) 7,200.00 91.458 180.60 3,441.56 3,332.56 -3,577.14 718.54 5,942,275.71 559,410.02 0.00 3,577.14 7,300.00 91.458 180.60 3,439.02 3,330.02 -3,677.10 717.49 5,942,175.75 559,409.75 0.00 3,677.10 7,400.00 91.458 180.60 3,436.47 3,327.47 -3,777.07 716.44 5,942,075.79 559,409.48 0.00 3,777.07 7,500.00 91.458 180.60 3,433.93 3,324.93 -3,877.03 715.38 5,941,975.84 559,409.21 0.00 3,877.03 7,575.87 91.458 180.60 3,432.00 3,323.00 -3,952.87 714.59 5,941,900.00 559,409.00 0.00 3,952.87 1J-159 L2 T2 (wp06) 7,600.00 90.976 180.57 3,431.49 3,322.49 -3,976.99 714.34 5,941,875.88 559,408.94 2.00 3,976.99 7,700.00 88.980 180.45 3,431.53 3,322.53 -4,076.98 713.44 5,941,775.89 559,408.82 2.00 4,076.98 7,721.38 88.553 180.43 3,431.99 3,322.99 -4,098.36 713.28 5,941,754.52 559,408.82 2.00 4,098.36 7,800.00 88.553 180.43 3,433.97 3,324.97 -4,176.95 712.69 5,941,675.93 559,408.85 0.00 4,176.95 7,900.00 88.553 180.43 3,436.50 3,327.50 -4,276.92 711.94 5,941,575.97 559,408.88 0.00 4,276.92 8,000.00 88.553 180.43 3,439.03 3,330.03 -4,376.88 711.20 5,941,476.01 559,408.91 0.00 4,376.88 8,100.00 88.553 180.43 3,441.55 3,332.55 -4,476.85 710.45 5,941,376.06 559,408.94 0.00 4,476.85 8,200.00 88.553 180.43 3,444.08 3;335.08 -4,576.81 709.70 5,941,276.10 559,408.98 0.00 4,576.81 8,276.13 88.553 180.43 3,446.00 3,337.00 -4,652.91 709.13 5,941,200.00 559,409.00 0.00 4,652.91 1J-159 L2 T3 (wp06) 8,300.00 89.029 180.43 3,446.50 3,337.50 -4,676.78 708.95 5,941,176.14 559,409.01 2.00 4,676.78 8,400.00 91.029 180.44 3,446.45 3,337.45 -4,776.77 708.19 5,941,076.15 559,409.02 2.00 4,776.77 8,443.72 91.904 180.45 3,445.33 3,336.33 -4,820.48 707.85 5,941,032.45 559,409.02 2.00 4,820.48 8,500.00 91.904 180.45 3,443.46 3,334.46 -4,876.72 707.41 5,940,976.21 559,409.02 0.00 4,876.72 8,600.00 91.904 180.45 3,440.14 3,331.14 -4,976.66 706.63 5,940,876.27 559,409.02 0.00 4,976.66 8,700.00 91.904 180.45 3,436.82 3,327.82 -5,076.61 705.85 5,940,776.34 559,409.02 0.00 5,076.61 8,800.00 91.904 180.45 3,433.49 3,324.49 -5,176.55 705.07 5,940,676.40 559,409.02 0.00 5,176.55 8,900.00 91.904 180.45 3,43017 3,321.17 -5,276.49 704.29 5,940,576.47 559,409.01 0.00 5,276.49 9 ~^0 uu 91.904 180.45 3,426.85 3,317.35 -5,376.43 703.51 5,940,476.53 559,409.01 0.00 5,376.43 ; . 9,100.00 91.904 180.45 3,423.52 3,314.52 -5,476.37 702.73 5,940,376.59 559,409.b1 0.00 5,476.37 9,200.00 91.904 180.45 3,420.20 3,311.20 -5,576.31 701.94 5,940,276.66 559,409.01 0.00 5,576.31 9,300.00 91.904 180.45 3,416.88 3,307.88 -5,676.26 701.16 5,940,176.72 559,409.00 0.00 5,676.26 9,400.00 91.904 180.45 3,413.55 3,304.55 -5,776.20 700.38 5,940,076.79 559,409.00 0.00 5,776.20 9,476.84 91.904 180.45 3,411.00 3,302.00 -5,852.99 699.78 5,940,000.00 559,409.00 0.00 5,852.99 1J-159 L2 T4 (wp06) 9,500.00 91.442 180.45 3,410.32 3,301.32 -5,876.14 699.60 5,939,976.85 559,409.00 2.00 5,876.14 9,523.89 90.963 180.45 3,409.82 3,300.82 -5,900.02 699.42 5,939,952.97 559,409.00 2.00 5,900.02 9,600.00 90.963 180.45 3,408.54 3,299.54 -5,976.12 698.82 5,939,876.88 559,409.00 0.00 5,976.12 9,700.00 90.963 180.45 3,406.86 3,297.86 -6,076.11 698.04 5,939,776.90 559,409.00 0.00 6,076.11 9,800.00 90.963 180.45 3,405.18 3,296.18 -6,176.09 697.26 5,939,676.92 559,409.00 0.00 6,176.09 9,900.00 90.963 180.45 3,403.50 3,294.50 -6,276.07 696.49 5,939,576.95 559,409.00 0.00 6,276.07 10,000.00 90.963 180.45 3,401.82 3,292.82 -6,376.05 695.71 5,939,476.97 559,409.00 0.00 6,376.05 10,100.00 90.963 180.45 3,400.14 3,291.14 -6,476.04 694.93 5,939,377.00 559,409.00 0.00 6,476.04 10,200.00 90.963 180.45 3,398.45 3,289.45 -6,576.02 694.15 5,939,277.02 559,409.00 0.00 6,576.02 10,227.03 90.963 180.45 3,398.00 3,289.00 -6,603.04 693.94 5,939,250.00 559,409.00 0.00 6,603.04 1J-159 L2 T5 (wp06) 10,281.67 89.871 180.45 3,397.60 3,288.60 -6,657.68 693.51 5,939,195.36 559,409.00 2.00 6,657.68 10,300.00 89.871 180.45 3,397.64 3,288.64 -6,676.01 693.37 5,939,177.04 559,409.00 0.00 6,676.01 10,400.00 89.871 180.45 3,397.87 3,288.87 -6,776.01 692.59 5,939,077.05 559,409.00 0.00 6,776.01 10,500.00 89.871 180.45 3,398.10 .3,289.10 -6,876.00 691.81 5,938,977.06 559,409.00 0.00 6,876.00 10,600.00 89.871 180.45 3,398.32 3,289.32 -6,976.00 691.03 5,938,877.06 559,409.00 0.00 6,976.00 10,700.00 89.871 180.45 3,398.55 3,289.55 -7,076.00 690.25 5,938,777.07 559,409.00 0.00 7,076.00 12/142005 6:57:36PM Page 5 of 6 COMPASS 2003.11 Build 48 • • ~~ Halliburton Energy Services ~~~~,~~~,~~-~~ COt14COP~ll~~pi5 Planning Report -Geographic --,- „-- -- Sperry Drilling Services Database: EDM 2003.11. Single UserDb Local Co-ordinat® Reference: Weil PIan1J-159 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Project: KuparukRiver Unit MD Reference: Planning RKB Q 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True. Well: Plan 1J-159 Survey Calculation Method: Minimum Curvature Wellbor®: 1J-159 LZ Design: iJ-159 L2 (wp06) Planned Survey 1J-159 L2 (wp06) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV (ft) ° ft Vert Section (ft) t°) (°) lftl (ft) (ft) ( /100ft) ) (ft) I (ft) 10,800.00 89.871 180.45 3,398.77 3,289.77 -7,175.99 689.47 5,938,677.08 559,409.00 0.00 7,175.99 10,900.09 89.871 180.45 3,399.00 3,290.00 -7,276.09 688.69 5,938,577.00 559,409.00 0.00 7,276.09 L2 76 (wp06) 59 L2: BHL ~ 10900ft MD, 3399ft TVD : 39ft FSL 81864ft FEL -Sec 2 - T10N - R10E - 41/2" -1J-1 .- ._ Geologic Targets ,,1J-159 L2 - , ^ ~~1w ~,t O( V" ~ ~ ~ ~ i ~ 1' ' TVD Target Name + .W ~ Northing " +N/S Easting Ift) -Shape ft ft Ift) (ft) 3,460.00 1J-159 L2 T1 (wp06) -2,852.82 726.16 5,943,000.00 559,412.00 - Point 3,398.00 1J-159 L2 T5 (wp06) - Point 3,411.00 1J-159 L2 T4 (wp06) - Point 3,446.00 1J-159 L2 T3 (wp06) - Point 3,399.00 1J-159 L2 T6 (wp06) - Point 3,432.00 1J-159 L2 T2 (wp06) - Point -6,603.04 693.94 5,939,250.00 559,409.00 -5,852.99 699.78 5,940,000.00 559,409.00 -4,652.91 709.13 5,941,200.00 559,409.00 -7,276.09 688.69 5,938,577.00 559,409.00 -3,952.87 714.59 5,941,900.00 559,409.00 ~Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter 2,392.47 2,207.00 10-314 13-112 4,285.82 3,482.00 7-5/8 9-7/8 10,900.08 3,399.00 4-1t2 6~/4 12/14/2005 6:57:36PM Page 6 of 6 COMPASS 2003.11 Build 48 • +C~Ct~~"11~~1~f5 Aiasi<a Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-159 Wellbore: 1J-159 L2 Design: 1J-159 L2 (wp06) Planned Survey 1J-159 L2 (wp06) MD Inclination Azimuth TVD (ft) (°) (°) (ft) 10,800.00 89.871 180.45 3,398.77 ~ 10,900.09 89.871 180.45 3,399.00 ' L2: BHL @ 10900ft M D, 3399ft TVD : 39ft FSL,Bf Geologic Targets 1J-159 L2 HaIIIbUrtOn En@rgy ServIC@S HALLLBURTON Planning Report -Geographic - -- . Sperry Drilling 5ervites Local Co-ordinate Reference: Well Plan 1J-159 TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: Minimum Curvature Map p SSTVD +N/-S +E/-W Northing asting DLSEV Vert Section 289~i'''~ -7,175.99 689.47 5,938,677.08 559,409.00 0.00 7,175.99 X90.00 -7,276.09 688.69 5,938,577. 559,409.00 0.00 7,276.09 64ft FEL - SeyiG~T10N - R10E - 4112" -1J- L2 T6 (wp06) ~L ~ f~ /i=C)E~ TVD Targe~ltlaFUe.._ _~ +EI-W Northing Easting (ft) -Shape ft (ft) (ft) 3,460.00 1J-159 L2 T1 (wp06) ~ 2,852.82 726.16 5,943,000.00 559,412.00 - Point Fj 3,398.00 1J-159 L2 75 (wp06) ~6~03.04 ~ 693.94 5,939,250.00 559,409.00 - Point ~ -C\ ~ 3,411.00 1J-159 L2 T4 (wp06) -5,852.99 699.78 5,940,000.00 559,409.00 - Point \~~ 3,446.00 1J-159 L2 T3 (wp06 -4,652.91 709.13 5,941,200.00 559,409.00 - Point 3,399.00 1J-159 L2 T6 ( p06) 7,276.09 688.69 5,938,577.00 559,409.00 - Point 3,432.00 1J-159 L 2 (wp06) -3,952.87 714.59 5,941,900.00 559,409.00 - Point Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) (") (°) 2,392. 2,207.00 10-3/4 13-112 4,285 2 3,482.00 7-518 9-718 10,9 0.08 3,399.00 4-112 6-3/4 12/14/2005 6:57:36PM Page 6 of 6 COMPASS 2003.11 Build 48 t f 4 G a ~ ~ ?~ ..-.,n, • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-159 1J-159 L2 Anticollision Summary 14 December, 2005 1'"~A L~.1 ~3 tJ R"TC' Sperry Drilling Services ~ L 0 u 'p ~ = C yY UyEaH~Um Y 33 ~? m US,:.- N V C2 ~~ f :~ a ax €~mo ~~ 8» t E =a$e~ C ~ O ~ Y) OI yGG C S aW^~E • W; ~ ~' » U ~ V N a o~ J~ a i c yy 8 V ? a e ,gq~b JG J~ A 9 wy ~ a.~ S ~a.~; N ~ '$ q $n Y c°e z a ~g ~e 3$ +e o~ m~~iO ~ ~0~8 ~ ~~~~ W C~Nb m - qi o'er` T3i ~~ $,m O B<qg c~ £~rcv ~ ~ E~ `gym o$1E~ m ° ~ ~ g~ ~Eg -a 0 c~> M ~ o rn N o ~ fD M ` I ~ N m° o_ N O OD (F H (fNy {Hy (Fy ~fNy J J J J J J b b b N b ~'em rlaDi lniyp~$mamnmamo~mo ~ n S ~ T ~ O N b N N Om i ~ b~yp p Nppp p bppp oW OpO1 ~ b A OO)h Y0ONNN NtO+1y QON1D mA 4~~~~e~~~~~~~~~~~w~ Fp1 C G G O A G C¢ C~ G A C O G^ C^ G N $ S S tt$OO $ $ Wm$ S $ $ S S $ $ $ $ S S J ~G~GIE YD CYfGCI G/V GPICMGCIG a 3^t_Sp ~O01 Y)OlA aO P'IN YONyy 01 W 001 ''/~OWN~Y01~O011001 G ~l"IN~10ON ~e~tC fGO C! W A W pf~)MI YC N NN~pOPINN~~OO01010101 a0 0 +01010101 OI AI`I~I~I~A A1~010)0)0)10 V ymoYONp~1Mp^e1~YNOeaAerQmQli.lmp0~pYwpc8WfpBpmS H ~^YO0~01~0 W 1ANN V OQNbf01O0A 0/ 1~YD0 N1+1O m41 p ~Ny NNNM ~ S 1 A N ~ a 0010 Y 00 $ a NO S S O M S m S N S ~~~~M~S~~~~~~~A~^^M '~$$$$aomp$p°m 1°po°maaap~pp~p~ppp~~ YND a~D a~D mYA00AD YD aOD fO OOO aO0 mYOD 01 YD CO aDS ~~~~~~~~~~~~~g$ g~~~~~ ~~~i 8in rein auWiaeeedl ~+p~op~aAOm n AAYOD W 010ppl pWp W W 00O at0 W 010OD Yp0 .~~, CpOONfO0NOOO~1O'1 ~1~~aO0OmO Ml 1pNp~111e(~A 10pp1001 ~01pp1 Y~YppN yWy Nb~tY yyM aO ~'/1~~G yUOQOOQN NIO ~I~AYO aD Q1 ON OOO f// ~ N M O Y! 0 A 40 O1 ~ ~ ~ ~ ~ ~~ ~~ O H O O U O LL ~ g ~n $o g o g 25 g o g o$ $o o c< O 1[1 ~ 1D (O r r m m rn rn E N O u~'i O O pp~ O 8 0 0 0 p S O pp~ O O Q Q N N t0 N n r GGaD m O> Obi O O C r 0 m ~Vry` u '~' > dzm ~~ } U G D 8 ~u~E s ~ ~ ~ y i d~~~ o g fi~'z~ ~~~' y V=1 0 # O r r T T 58 8 _~ 1`$W$ ,; ~o ~= $ i~=~~ F u c rc FF ~ c o c 7 ~ s .~ _.~ ~ LL A S A.~ Z ~smss W `m m o 11W KCYK p e ~ S ~ a'„ z-e~ $'~$a V ConocoPhillips Alaska Halliburton Energy Services Anticollision Report Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O:OOft Reference Well: Plah 1J-159 Well Error: O.OOft Reference Wellbore 1J-159 L2 Reference Design: 1J-.159 L2 (wp06) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: H A l.l..l B tJ It=t'T©h1 8p~a~ry Df#Iling $eirVices Well: Plan 1J-159 Planning RKB C«~ 109:OOft (Doyon fi41 (28+81)) Planning RK6 @ 109:OOft (Doyon 141 (28+81)) True. Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset. Datum Reference 1J-159 L2 (wp06) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of referee Interpolation Method: MD Interval 50.OOft Error Model: ISCWSA Depth Range: 4,285.82 to 10,900.09ft Scan Method: Trav. Cylinder North Results Limited by: Ma>omum center-center distance of 1,287.21ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 12/14/2005 From To (ft) (ft) Survey (VYellbore) 28.00 800.00 1J-159 (wp06) (1J-159) 800.00 4,285.81 1J-159 (wp06) (1J-159) 4,285.81 10,900.09 1J-159 L2 (wp06) (1J-159 L2) Tool Name Description CB-GYRO-SS Camera based gyro single shot MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 12/142005 7:16:05PM Page 2 of 3 COMPASS 2003.11 Build 48 .] j ~t~1'IOCO~~lll~lp5 t'Y'~J~4fd Halliburton Energy Services Hs~t~.~~BUA-rotU Anticoliision Report $ps~r Trifling Se~ric~s Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-159 Well Error: O.OOft Reference Wellbore 1J-159 L2 Reference Design: 1J-159 l2 (wp06) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: WeII Plan 1J-159 Planning RKB ~ 109.OOft (Doyon 14t (28+81)) Planning RK6 @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Sit® Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design Iftl Ift) (ft) Ift) Kuparuk 1J Pad 1J-154 -1J-154 - 1J-154 Rig 8,563.33 8,550.00 1,252.51 196.21 1,056.30 Pass -Major Risk 1J-154 - 1J-154 L1 - 1J-154 L1 10,021.41 10,000.00 1,187.31 243.24 944.07 Pass -Major Risk 1J-154 -1J-154 L2 - 1J-154 L2 10,838.79 10,800.00 1,198.89 267.90 930.99 Pass -Major Risk 1J-164 -1J-164 L2 -1J-164 L2 Out of range 1J-168 - 1J-168 - 1J-168 Rig Out of range 1J-168 - 1J-168 L1 - 1J-168 L1 Rig Out of range 1J-168 -1J-168 L2 - 1J-168 L2 Out of range 1J-168 - 1J-168 L2 PB1 - 1J-168 L2 P61 Rig Out of range Plan 1 J-102 -1J-102 - 1 J-102 (wp03) 4,294.92 5,450.00 1,030.36 93.17 937.20 Pass -Major Risk Plan 1J-102 -1J-102 L1 -1J-102 L1 (wp03) 4,467.29 5,650.00 1,025.55 100.65 924.90 Pass -Major Risk Plan 1J-102 - 1J-102 L2 - 1J-102 L2 (wp03) 4,327.46 5,499.98 1,016.64 97.15 919.49 Pass -Major Risk Plan 1J-103 -Plan 1J-103 -1J-103 (wp01) BHI Out of range Plan 1 J-105 -Plan 1 J-105 - 1 J-105 (wp01) BH I Out of range Plan 1J-107 -Plan 1J-107 - 1J-107 (wp01) BHI Out of range Plan 1J-109 -Plan 1J-109 -1J-109 (wp03) (S GuIM Out of range Plan 1 J-111 -Plan 1 J-111 -1 J-111 (wp01) Out of range Plan 1J-136 - 1J-136 - 1J-136 (wp03) 9,176.75 6,550.00 1,091.89 207.01 884.88 Pass -Major Risk Plan 1J-136 - 1J-136 L1 - 1J-136 L1 (wp03) 9,176.75 6,550.00 1,091.89 206.79 885.10 Pass -Major Risk Plan 1J-137 -1J-137 - 1J-137 (wp03) 10,861.20 8,099.97 204.95 68.35 136.60 Pass - No Errors Plan 1J-137 - 1J-137 L1 - 1J-137 L1 (wp03) 10,861.20 8,099.97 204.95 68.35 136.60 Pass - No Errors Plan 1J-152 - 1J-152 - 1J-152 (wp04) Out of range Plan 1J-152 -1J-152 L1 - 1J-152 L1 (wp04) Out of range Plan 1J-152 - 1J-152 L2 -1J-152 L2 (wp04) Out of range Plan 1 J-156 -Plan 1 J-156 - 1 J-156 (wp02) Out of range Plan 1J-158 -1J-158 - 1J-158 (wp2A) BHI Out of range Plan 1J-159 -1J-159 -1J-159 (wp06) 4,299.98 4,299.98 0.27 1.57 -1.29 FAIL -Major Risk Ptan 1J-159 - 1J-159 L1 -1J-159 L1 (wp06) 4,299.98 4,299.98 0.27 1.57 -1.29 FAIL -Major Risk Plan 1J-160 -Plan 1J-160 - 1 J-160 (wp01) BHI Out of range Plan 1J-162 - 1J-162 - 1J-162 (wp03.1-North Heel) Out of range Plan 1 J-162 - 1 J-162 L1 - 1 J-162 L1 (wp3.1) Out of range Plan 1J-162 - 1J-162 L2 - 1J-162 L2 (wp3.1) Out of range Plan iJ-170 -Plan 1J-170 -1J-170 (wp02) Out of range Plan 1J-184 - 1J-184 - 1J-184 (wp08) 10,855.34 8,050.00 1,072.50 279.27 793.23 Pass -Major Risk Plan 1J-184 - 1J-184 L1 - 1J-184 L1 (wp08) 10,855.34 8,050.00 1,072.50 279.32 793.18 Pass -Major Risk WSP-13 -WSP-13 -WSP-13 4,442.35 3,550.00 273.38 101.16 172.22 Pass -Major Risk WSP-1 S -WSP-1 S -WSP-1 S Out of range CC -Min centre to center distance or covergent pant, SF -min separation factor, ES -min ellipse separation 12/14/2005 7:16:05PM Page 3' of 3 COMPASS 2003.11 Build 48 1~-159L~rillina Haz (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3/4" Open Hole / 4-i/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 a' ~ '' ~ ~: ~ ~ 1J-159L2 Drilling Hazards Summary ~ ~ r ~ ~ ' , ~ - ~ 1/16/2006 9:08 AM 10.314" 68# Casing Shoe, set @ 2392' MD, 2207' TVD Tubing String 4-1 /2" 12.6#, L-80, IBTM 3.958" ID, 3.833" Drift ~GLM, Camco 4.112" X 1" KBMG, Gas Recombination GLM, Camco 4.1/2" X 1" KBMG Bottom of Motor Centralizer Centralift 418 HP KMHFER 2610 198 D-sand Window at 4285' MD, rDr _ i 3482' TVD ConocoPhillips West Sak 7-5/8" Producer 1 J-159 Tri-Lateral Completion 1 4-112" 12.6# L-80 Slotted Liner Every Joint ~ 3-112" Bent Joint 1 i 3-1/2" Gui Shoe 4-112" X 7-518" Model 'B' HOOK Hancer Liner Top Packer with Hold Downs Assembly I .----- 5-112" X 7-818" ZXP Liner Top Packer with Hold Downs Casing Sealbore Receptacle 4.75" ID - Tubing Swivel, 4-1/2" - Orienting Profile Automatic Alignment of LEM - Positive Latching Collet Indicates Correct Location ~ Seai Bore for Lateral Isolation - 3.68" ID ~ Access Window Positive Lateral Access Via 7hru-Tubing Diverter Seal Bore for Lateral Isolation - 3.68" ID Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID ~~ 4-112" L er Shoe, 12.6#, L-60 IBTM ~~Yl,.~ ,,MM[[ `` Set 10901' MD, 3399' TVD V V W W~ Casing Sealbore Receptacle 4.75" ID 4-112" X 7-518" Model 'B' HOOK Hancer Seal Borr 3.68" ID 4-1/2" 12.6# T Lateral Entry Module(LEM) Orienting Profile B-sand Window 'g' Sand Lateral at 4588' MD, 3548' TVD 4-1/2" 12.6# L-80 Slotted As Planned Baker Oil Tools Lateral Entry Module (LEM) With Di verters and Isolation Lateral Access Divartef Lateral Isolation Diverter GS Running Tool String Installatl Installetl (3.00" Lateral D!M) (2.50" ID Mainbore DrM) 'GS' Profle for ' Coil Connector -.- 1Running/Retrieving ~ .~ (1.00' Length) ~ I Snap lNSnap Out r Back Pressure Valve /Positi catingti ' (1.80' Length) Collet ~ I ~ ~ I i Lateral lsolauon~~ ,r Flow•Thm Swivel i '~. ~~' Seals f Lateral Diverter Hydraulic Disconnect Ramp t / ~~~ (1.50'Length) ~ ~ Isolation Mainbore Diverter Sleeve ' ~/ GS Spear (1.50' Length) ~- ~ Lateral isolation ~ ' Seals I ,, T ` 8.85 kApprox. OAL' \~ -•~. '~ tr 'Jars may be reyl~ired in highly tleviatetl ' I tg,5' Diverter Length 18.5' Sleeve Length - or deep appl~cat,ons Ifi approx length). + Li Every Jo t 3-112" Benl Joint t 3-712" Guide Shoe v~,,~.mn~+mxr ,--~ _~, ~,:J.+w.. ,W.1 _, , 4.112" Liner Shoe, 12.6#, L-80 IBTM Set @ 11205' MD, 3472' TVD 3.562" DB Nipple 5-1 /2" X 7-518" ZXP Liner Top Packer ~ Seal Assembly with Hold Downs 4.75" Seal OD 3.875" ID 5-112" X 7-5/8" Liner Hanger /Packer Assembly at Flex Lock ~ ' +l- 4700' MD Liner Hanger ~,, Casing ~ Sealbore Receptacle, 4.75" ID 'A' Sand Undulatina Lateral Diverter and Sleeve Length:+1.16.5' 4-112" 12.6# L-80 Slotted Liner Every Joint 4-112" Eccentric 1 Guide Shoe _ °""°"='"! ~ 4-112" Casing Shoe, 12.6#, L-80 18TM _, ~~'...~. „ Set @ 7857 MD, 3641' TVD 7-518" Casing Shoe, Set at @ ® Beker Hughes 2005. This tlocument may not ba reprotlucetl or tllstdDNetl, In whole or In part, In any loan or 5556' MD, 3698' TVD, 84 deg inc owe Tnle: onwing xo.: by any means electronic or mecnanlcel, Inclutling photocopying, recortling, or by eny IMOrmetlon aloraga 2008 West oak 7S/8" Trt-Ybrel Complatlon - Protlucer entl retrlaval system now known Or hereslUr Invsnletl, wllhoul wrXNn partnlsslon /rom Beker Hughes Inc. Dsle: Drswn By: Rwbien no.: Pape Xo.: ~ OI: January 18, 2005 Marc D. Kuek 1 1 t Eauinment Specifications 4-112" 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" 4-1/2" Lateral Entry Module Mainbore Driit: 3.65" Mainbore Drift, wt isolation sleeve: 2.50" Lateral Drift, wl coil diverter: 3.00" OD of Diverter and Sleeve: N- 3.89" • • • TRANSMITTAL LETTER. CHECKLIST WELL NAME ~_~- (~. / '~1 ~ ~S ~~ ~ Z- PTD# ~~-~r` Development Service Exploratory Stratigraphic Test Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The perm/it is for a new wellbore se ment of existing ~ ~ ~~ well /~/~~ j , (If last two digits in ~ API No. 50-L3~. - L3L~ 7 - permit No. ~~ ~ ~. API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(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 logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / infect 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 SAMPLE in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 1/05/06 C:\jody\transmittal_checklist ~ • ^ ~ N ~ a ~ `°'r ~ , ; ~ ~ o , s ~ ~ _ ~ ~,; ~, ~ C N a~ 3' / s, a o ~~ a ~i ~ ~ ; ~ ~, 3 ~ - ~ c. ~, o. ~ ~ ~ ~ c O o o. 3 I o. ~ a 'w' m. ~ o ~ ~ ~ Z• c m ~~ ~ ~ ~ rn U. o , m, ~ aai~~ ~ ~ ~ ~ ~ ~ ~ ~ a`r $~ 4 ~ o, ~ o, ~ °S a~ _ O. CV, ~ a O. ~ ~ 'O N' ~ 'd o' - `' o a~ o, ' Z ~ ~ o, 3. a~, ~ ~, a; m. c ~ ~ o m a ~, a' °, ~, ~ a, c' ~ s' ~, Q. a ~ °~ 3. ~= ~ J ~, O' fl: ~ ~ ~ ~ ~ Z C ~ m, ~ ~ C ~ a. 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Q :: O, y. a ~ O ~, a N, N. ~ ~ Y Z ~, o c, a ~' o, ° ;c v m, a~, of a U' ~ o, c. y. o~ c' N' °' ct o, o, ~ °, 4 ~' Q' s. c' m ~ °, c. of o, ~ - ~ ~ ~ E, E~ 'NOS ~ ` C, ~~ ~~ ~ ~6~ m ~ O ~~ ~ C~ ~: N~ >~ ~~ ~ a, 0 ~, ~S, ~ . ~~ ~~ ~~ ~ ~~ a~ p, O: N~ .C O: ~ C ~ a ~ ~ o o ~ ~ - o ~ ' v o a a' °' ~~ ~ . ~ L ` o` 3' o' ° m ' ~, C~ ... '~ °, a ~ c' a, a~: o. ~' d. , o ~ n, 3' o ° N N' >' m' ~' T o .~ 'N 4. U , ~, p. c_ c: c O ~ ~ o ~ U c. ::, c "o. °' . ca. c, ° is Q. ro, m N. a, o. Op O. Y N N Y Q ~ :? ~ n ~ ~ n m. ~ ~ ~, r . ~ ° m ~, ~ ~ °, ~ Z ° ~m, ~, ~ rn a N °. ` ~ ° `~ 3 rn m. ' ' c, a, m. a oa . c a ° ~' a, w • -° ~, ~ a~ ° ~ c a i N. a i M. ~, N, _ ~, ~ a~' o: 3' o o' ' c; T ' E W - d Q a, ~, ~?, w; ' ~~ ° a' ~, 3 3, ~ ~ ~ ~ .. ~ :~ ~ 'v. , .- o ~ ~ ~, o, ~ a ' ~ ~, o. 3. o t' ~' °' U °o ~ o, v, ~, •~ v, ~ a a~ ~ ~ ~ o ~ '~, o, o' o' ° o, o, c' ~ o ~ o N, a, ~, ~, Q ° ~ ~, rn o ~ a N, ° ~ a J ~, a of .°, ~, ~ ~ ~, ~, o. ° ~' a Q c, v; °' U' N o: O' ai ai Y' a ai ~'. ~' -o m' E, ` rn °' U' :: • v i ~' c' o' o ~ ' = L' ~ ~ ~ Q O~ OO. O. ~' ~ ~~ .~ ~~ 3~ (6' . ~~ ~; Q ~ N L, , O, r C, O) O- fd N : ~ (6 f6' ~ , OS f6• p, N• p' N• , ~ O T C. U a, 3, N, -0~ _, C . N, O. N, C. O, N: . • • L~ 4 a N d O ~ ~ ~, f6' Q, C C, Q O. , a' a' a' N. N T U• • y ~~ Q, ~ ' 3~ . . L; a' ~ p: ~ C p O ~~ ~ ~ ~ N' ~ N > ~ C~ Q ~~ Qj 6 0- w ~ N~ p U O~ U~ • . N a ..N.~ T 'd Q fb ~ ~~ lL U N• ~, - ~, ~, ~~ ~, C N. ~~ O. f6 L. C C, ~ a U7, U, ~~ N, ca. ~~ ~~ ~ . U' N O, ~ , N, ' ~, ~ 'd. O, , N ~~ U, O, Y m. N C, C, : C: N. C, O. ~ f6. ~" Z ~ c 3, m m m ~ ~ o o ~ ~, E ~ N~ -a, ~' o. ° = v. ~ _ •- ~, ~ ? a, a ~, C . ~: c, ~, ~, ~, m U, c ~ ~ J `1 U ~ ~, ° a~ .s - - c °~ ° °~~ ' ~ m a> ~ v' 4 a~, ~, ~ c 4 a~ a~ m - °' 3. °' ~ - ~ U, c, ~, F- F- g' ~' ~ o F' 'N g; m aai a ` m ~ ~' d, ~ a -° ._ O d, o, L O i ~ ~~ ° °' ~ ~, :~ .N m~ m a~ a~ a~ c 4 `~ ~ U >, c , a, J, , ~, ~; S', ~, U, ~-'; O, O, a; a; U 'S' a. a, a, ~ , , , , U, U, U. U. , U, U, , a. . . - Q. "= o', °°, , . °°, U, 'S ~' ~, , , , , a, o, U, U, U, W a ~ _ ~ N M ~t ~ (D I~ O W O N M r st ~ CO a0 O) O ~ .- N N N M N N c} N to (p f~ 00 m N N N N N _ O M M N M ~ M M M ~ O ~ W M M M M O) M ~ 0 i 0 0 .. ~ c C p +p~' N +p~' N w N U C ~ ~ ° O " p a0 ~ p o p a0 am ,~ ° N W 0 cD 1 6 y~•, ~ c ~ ~ - ° E J N ~ ~ ~ ~ Q E O J 4k o ~ E C a O w ~ a s a~ a ~ ~ ` a w a~ ° a~ ~ a~ w • • Well History File APPENDIX Information of detailed nature that is not particularly germane io the Well Permitting Process but is part of the history file. To improve the readability of the Well Nistory file and to simplify finding infom~ation, information of this nature is accumulated at the end of the fife under APPENDIX. No special efCori has been made to chronologically organize this category of information. Sperry-Sun Dr~ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed May 31 08:54:40 2006 Reel Header Service name .............LISTPE Date .....................06/05/31 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/05/31 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0004212091 P. ORTH D. GLADDEN 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 c7C~5 -C3US i ~ ~ 393x- Scientific Technical Services Scientific Technical Services 1J-159 L2 500292329761 ConocoPhillips Alaska, Inc. Sperry Drilling Services 3I-MAY-06 MWD RUN 11 MWD RUN 12 MW0004212091 MW0004212091 P. ORTH P. ORTH M. THORNTON MIKE THORNTO 35 11N 10E 2035 2545 109.00 81.00 CASING DRILLERS SIZE (IN) DEPTH (FT) 10.750 2365.0 7.875 4246.0 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 LATERAL WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 4246'MD/ 3481'TVD, WITHIN THE RUN 2 INTERVAL OF 1J-159 PB1. THE WHIPSTOCK WAS SET, THE WINDOW MILLED, AND 16' OF RAT HOLE DRILLED DURING MWD RUN 11. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,12 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 12 ALSO INCLUDED AT-BIT INCLINATION (ABI) MWD RUN 2 POROSITY DATA ARE PRESENTED FOR THE 1J-159 PB1 WELLBORE ONLY. 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 1,2,11,12 REPRESENT WELL 1J-159 L2 WITH API#: 50-029-23297-61. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10884'MD/3425'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.......06/05/31 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 TH STOP DEPTH GR 2325.5 10823.5 FET 2345.0 10830.5 RPD 2345.0 10830.5 RPS 2345.0 10830.5 RPM 2345.0 10830.5 RPX 2345.0 10830.5 ROP 2370.5 10884.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD BIT RUN NO MERGE TOP 2 2325.5 11 4246.5 12 4274.0 REMARKS: MERGED MAIN PASS. MERGE BASE 4246.0 4274.0 10884.5 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 HOUR 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 2325.5 10884.5 6605 17119 2325.5 10884.5 RPD MWD OHMM 0.64 2000 50.8776 16972 2345 10830.5 RPM MWD OHMM 0.77 1749.02 44.5187 16972 2345 10830.5 RPS MWD OHMM 0.54 1832.11 43.4442 16972 2345 10830.5 RPX MWD OHMM 0.42 2000 56.8583 16972 2345 10830.5 FET MWD HOUR 0.19 383.08 1.61787 16972 2345 10830.5 GR MWD API 19.79 117.61 67.9658 16997 2325.5 10823.5 ROP MWD HOUR 1.99 481.14 188.968 17029 2370.5 10884.5 First Reading For Entire File..........2325.5 Last Reading For Entire File...........10884.5 File Trailer Service name .............STSLIB.001 Service Sub Level Name.. • Version Number...........1.0.0 Date of Generation.......06/05/31 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/31 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 2325.5 4246.0 FET 2345.0 4246.0 RPX 2345.0 4246.0 RPS 2345.0 4246.0 RPM 2345.0 4246.0 RPD 2345.0 4246.0 ROP 2370.5 4246.0 LOG HEADER DATA DATE LOGGED: 18-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4246.0 TOP LOG INTERVAL (FT) 2370.0 BOTTOM LOG INTERVAL (FT) 4246.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 25.9 MAXIMUM ANGLE: 81.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 157645 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2365.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 51.0 MUD PH: 8.9 MUD CHLORIDES (PPM): ~ 250 FLUID LOSS (C3) 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.900 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.950 100.0 MUD FILTRATE AT MT: 3.000 65.0 MUD CAKE AT MT: 5.000 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 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 2325.5 4246 3285.75 3842 2325.5 4246 RPD MWD020 OHMM 0.64 2000 29.6398 3803 2345 4246 RPM MWD020 OHMM 0.77 1749.02 13.2303 3803 2345 4246 RPS MWD020 OHMM 0.54 40.9 10.6309 3803 2345 4246 RPX MWD020 OHMM 0.42 38.27 10.0234 3803 2345 4246 FET MWD020 HOUR 0.19 113.21 2.22013 3803 2345 4246 GR MWD020 API 19.79 117.61 65.3356 3842 2325.5 4246 ROP MWD020 FT/H 11.1 481.14 179.867 3752 2370.5 4246 First Reading For Entire File..........2325.5 Last Reading For Entire File...........4246 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/31 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 • Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/31 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: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 4246.5 4274.0 LOG HEADER DATA DATE LOGGED: 05-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4274.0 TOP LOG INTERVAL (FT) 4246.0 BOTTOM LOG INTERVAL (FT) 4274.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM} VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 4246.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 72.0 MUD PH: .0 MUD CHLORIDES (PPM): 118000 FLUID LOSS (C3) 2.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 72.6 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD110 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4246.5 4274 4260.25 56 4246.5 4274 ROP MWD110 FT/H 1.99 40.98 12.9677 56 4246.5 4274 First Reading For Entire File..........4246.5 Last Reading For Entire File...........4274 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/31 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/31 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: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 4246.5 10830.5 RPD 4246.5 10830.5 RPM 4246.5 10830.5 GR 4246.5 10823.5 . RPS 4246 10830.5 FET 4246.5 10830.5 ROP 4274.5 10884.5 LO G HEADER DATA DATE LOGGED: 08-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10884.0 TOP LOG INTERVAL (FT) 4274.0 BOTTOM LOG INTERVAL (FT) 10884.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 83.0 MAXIMUM ANGLE: 94.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 017851 EWR4 Electromag Resis. 4 159439 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 4246.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 70.0 MUD PH: .0 MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3) 2.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 125.6 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD120 OHMM 4 1 68 4 2 n i RPM MWD120 OHMM ~ 1 68 8 3 RPS MWD120 OHMM 4 1 68 12 4 RPX MWD120 OHMM 4 1 68 16 5 FET MWD120 HOUR 4 1 68 20 6 GR MWD120 API 4 1 68 24 7 ROP MWD120 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4246.5 10884.5 7565.5 13277 4246.5 10884.5 RPD MWD120 OHMM 1.74 1053.78 57.0107 13169 4246.5 10830.5 RPM MWD120 OHMM 1.36 1146.19 53.5543 13169 4246.5 10830.5 RPS MWD120 OHMM 1.18 1832.11 52.9201 13169 4246.5 10830.5 RPX MWD120 OHMM 0.93 2000 70.3835 13169 4246.5 10830.5 FET MWD120 HOUR 0.2 383.08 1.44394 13169 4246.5 10830.5 GR MWD120 API 39.55 114.84 68.7339 13155 4246.5 10823.5 ROP MWD120 FT/H 3.91 366.25 192.296 13221 4274.5 10884.5 First Reading For Entire File..........4246.5 Last Reading For Entire File...........10884.5 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/31 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/05/31 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................06/05/31 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