The URL can be used to link to this page

Home My WebLink About205-1991. 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 Treatment- Offset Well 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 12952'feet 10235'feet true vertical 3593' feet None feet Effective Depth measured 10235'feet 4896', 4897', 5107', 5480' feet true vertical 3579'feet 3392', 3393', 3437', 3513' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 4922' MD 3398' TVD Packers and SSSV (type, measured and true vertical depth) 4896' MD 4897' MD 5107' MD 5480' MD N/A 3392' TVD 3393' TVD 3437' TVD 3513' 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: 2368' 2194' Burst Collapse B Liner LEM B Sand Liner 6324' 414' 7532' Casing 3649' 3520' 4-1/2" 6350' 5521' 12909' 3590' 2338' 108'Conductor Surface Intermediate 16" 10-3/4" 78' measured TVD 7-5/8" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 205-199 50-029-23291-60-00 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: ADL0025650, ADL0025661 Kuparuk River Oil Field/ West Sak Oil Pool KRU 1J-166L1 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 108' ~~~ Well Remains Shut-In ~~ ~ 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. RPPG pumped down Injector 1J-164L1. (details in events) Packer: ZXP Liner Top Packer Packer: Baker 109-47 Seal Assembly Packer: ZXP Liner Top Packer Packer: HRD ZXP Liner Top Packer SSSV: None Jan Byrne jan.byrne@conocophillips.com 265-6471Staff Well Interventions Engineer Alternating Slotted Liner: 5409-12878' Alternating Slotted Liner: 3500-3589' 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 3:08 pm, Aug 20, 2025 Digitally signed by Jan Byrne DN: OU=Wells Group, O=ConocoPhillips, CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2025.08.20 11:32:04-08'00' Foxit PDF Editor Version: 13.1.6 Jan Byrne RBDMS JSB 082525 DSR-9/11/25J.Lau 11/4/25 DTTMSTART JOBTYP SUMMARYOPS 7/25/2025 REPAIR WELL RIH WITH MOTOR AND 3.8" JUNK MILL. TAG ICE AT 22'. BREAK THROUGH ICE AT 60'. FREEZE PROTECT WELL WITH 45 BBL DIESEL AND DRIFT TO 4000'. PERFORM WEEKLY BOP TEST. 7/26/2025 REPAIR WELL PUMP FULL BORE RRPG TO MBE IN B SAND LATERAL AT 7320' RKB. PUMPED 27161 LBS OF DAQING RPPG PRODUCT AT 1.375 PPG FOR 132 BBL, PSI FLAT LINE INCREASE TO 1.5 PPG FOR 116 BBL PSI INCREASE SLIGHTLY, INCREASE TO 1.8 PPG FOR 118 BBLS STEADY PSI INCREASE, FLUSH CALLED AT 1195 PSI, 656 JSV. STEADY INCREASE TO MAX PSI 1300. TOTAL JSV 734 BBL. WELL TO REMAIN SHUT FOR 48 HRS FOR RPPG TO FULLY CROSSLINK 1J-164/ 1J-166 RPPG Treatment Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-166 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled Gauges 1J-166 12/10/2022 zembaej Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR Insulated 16 15.25 30.0 108.0 108.0 62.50 H-40 WELDED SURFACE 10 3/4 9.95 30.1 2,368.4 2,194.2 45.50 L-80 BTC INTERMEDIATE 7 5/8 6.87 26.4 6,350.0 3,648.8 29.70 L-80 BTCM D LINER LEM 4 1/2 3.96 4,885.0 5,137.0 3,443.3 12.60 L-80 IBT B LINER LEM 4 1/2 3.96 5,107.5 5,521.5 3,519.7 12.60 L-80 IBT A-SAND LINER 4 1/2 3.96 5,480.0 12,840.0 3,717.2 12.60 L-80 IBT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 22.4 Set Depth … 4,922.0 Set Depth … 3,398.0 String Max No… 4 1/2 Tubing Description TUBING WO Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 22.4 22.4 0.00 HANGER 10.850 TUBING HANGER T&C Non- Upset 3.958 503.3 503.3 0.57 NIPPLE 5.210 3.875" Camco "DB" Nipple 3.875 2,572.0 2,361.6 36.03 GAS LIFT 5.984 CAMCO KBG-2- 1R 3.938 4,319.5 3,225.8 69.38 GAS LIFT 5.984 CAMCO KBG-2- 1R 3.938 4,831.4 3,377.1 75.81 SLEEVE 5.490 BAKER CMD Sliding Sleeve (verified closed 1/11/21) 3.812 4,842.1 3,379.7 76.04 GAUGE 4.900 Baker Guardian Guage 4.000 4,893.7 3,391.7 77.04 LOCATOR 5.480 Locator / 2' space out 3.910 4,897.4 3,392.6 77.09 SEAL ASSY 4.750 BAKER 190-47 SEAL ASSEMBLY 3.880 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 10.0 10.0 0.00 HEAT TRACE HEAT TRACE 5/17/2008 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,572.0 2,361.6 36.03 1 GAS LIFT GLV BK-5 1 1,427.0 11/15/2020 0.156 4,319.5 3,225.8 69.38 2 GAS LIFT OV BK-5 1 0.0 11/15/2020 0.313 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,885.0 3,389.8 76.92 TIE BACK 6.430 TIE BACK EXTENSION 5.750 4,896.0 3,392.2 77.07 PACKER 6.550 ZXP LINER TOP PACKER 4.980 4,958.7 3,405.8 77.91 NIPPLE 5.000 3.75" DB NIPPLE 3.750 5,107.5 3,436.8 77.43 PACKER 6.550 ZXP LINER TOP PACKER 4.950 5,126.6 3,441.0 77.14 SBR 6.280 109-47 CASING SEAL BORE RECEPTACLE 4.750 5,145.9 3,445.3 76.85 XO BUSHING 6.040 CROSSOVER BUSHING 3.950 5,147.3 3,445.7 76.83 SWIVEL 5.770 BAKER CASING SWIVEL 3.960 5,442.8 3,506.5 80.17 NIPPLE 5.200 CAMCO DB-6 NIPPLE 3.563 5,475.2 3,512.0 80.32 BENT JT 4.500 3.880 5,480.0 3,512.8 80.35 PACKER 7.600 "HRD" ZXP Liner Top Packer 5.5" X 7.6" 4.970 5,499.0 3,516.0 80.44 NIPPLE 5.500 "RS" Packoff Seal Nipple 5.5" 4.875 5,531.4 3,521.3 80.59 LINRE XO THREAD 6.020 XO Bushing 3.92" ID, 6.02 OD 3.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,360.0 8,698.0 3,649.9 3,655.8 WS A2, A3, 1J- 166 1/19/2006 32.0 SLOTS ALL PERFS THIS WELLBORE - Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,945.0 10,031.0 3,661.1 3,711.7 WS A2, 1J-166 1/19/2006 32.0 SLOTS 10,648.0 10,710.0 3,678.3 3,668.4 WS A2, 1J-166 1/19/2006 32.0 SLOTS 10,990.0 12,808.0 3,651.8 3,715.9 WS A2, 1J-166 1/19/2006 32.0 SLOTS 1J-166, 8/11/2025 2:26:36 PM Vertical schematic (actual) A-SAND LINER; 5,480.0- 12,840.0 SLOTS; 10,990.0-12,808.0 SLOTS; 10,648.0-10,710.0 SLOTS; 8,945.0-10,031.0 SLOTS; 6,360.0-8,698.0 INTERMEDIATE; 26.4-6,350.0 B LINER LEM; 5,107.5-5,521.5 B-SAND LINER; 5,377.3- 12,909.3 D LINER LEM; 4,885.0-5,137.0 D-SAND LINER; 5,002.1- 12,952.7 GAS LIFT; 4,319.5 GAS LIFT; 2,572.0 SURFACE; 30.1-2,368.4 HEAT TRACE; 10.0 NIPPLE; 503.3 CONDUCTOR Insulated; 30.0- 108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 2/11/2006 Other Elev… 1J-166 ... TD Act Btm (ftKB) 12,853.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329100 Wellbore Status PROD Max Angle & MD Incl (°) 99.97 MD (ftKB) 10,663.58 WELLNAME WELLBORE1J-166 Annotation Last WO: End Date 4/17/2008 H2S (ppm) 424 Date 7/6/2023 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-166L1 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: WELL REVIEW 1J-166L1 5/13/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread B-SAND LINER 4 1/2 3.96 5,377.3 12,909.3 3,590.5 12.60 L-80 IBT Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 10,235.0 3,579.0 88.97 PLUG B-SAND IBP set 6/3/2008 6/3/2008 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,402.2 3,499.3 81.08 SWIVEL 5.750 Baker Casing Swivel 3.960 12,877.8 3,589.1 87.11 XO Reducing 4.500 4-1/2" X 3-1/2" XO sub 2.992 12,879.2 3,589.1 87.14 BENT JT 3.500 3-1/2" Bent Joint IBT, 9.2 ppf, L- 80 2.900 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,409.0 8,178.0 3,500.3 3,512.6 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,426.0 10,101.0 3,519.4 3,576.8 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 10,905.0 12,417.0 3,522.5 3,563.9 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 12,571.0 12,878.0 3,570.1 3,589.1 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 1J-166L1, 8/11/2025 2:26:37 PM Vertical schematic (actual) B-SAND LINER; 5,377.3- 12,909.3 SLOTS; 12,571.0-12,878.0 SLOTS; 10,905.0-12,417.0 PLUG; 10,235.0 SLOTS; 8,426.0-10,101.0 SLOTS; 5,409.0-8,178.0 B LINER LEM; 5,107.5-5,521.5 INTERMEDIATE; 26.4-6,350.0 D LINER LEM; 4,885.0-5,137.0 D-SAND LINER; 5,002.1- 12,952.7 GAS LIFT; 4,319.5 GAS LIFT; 2,572.0 SURFACE; 30.1-2,368.4 HEAT TRACE; 10.0 NIPPLE; 503.3 CONDUCTOR Insulated; 30.0- 108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 2/11/2006 Other Elev… 1J-166L1 ... TD Act Btm (ftKB) 12,952.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329160 Wellbore Status PROD Max Angle & MD Incl (°) 99.97 MD (ftKB) 10,422.57 WELLNAME WELLBORE1J-166 Annotation Last WO: End Date 4/17/2008 H2S (ppm) 424 Date 7/6/2023 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-166L2 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Type 1 Isolation Sleeve 1J-166L2 11/9/2019 mcanej Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread D-SAND LINER 4 1/2 3.96 5,002.1 12,952.7 3,528.4 12.60 L-80 IBT Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,027.0 3,419.7 79.25 SWIVEL 4.750 Baker Casing Swivel 3.960 12,920.8 3,526.8 87.23 XO Reducing 4.500 4-1/2" X 3-1/2" XO sub 2.992 12,922.2 3,526.9 87.22 BENT JT 3.500 3-1/2" Bent Joint IBT, 9.2 ppf, L- 80 2.900 12,951.2 3,528.4 87.03 WLEG 3.500 Baker 3-1/2" Guide Shoe ( No float) 2.900 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,067.0 7,805.0 3,426.4 3,464.7 WS D, 1J-166L2 2/7/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,021.0 8,325.0 3,463.9 3,471.5 WS D, 1J-166L2 2/7/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,571.0 9,806.0 3,472.2 3,492.6 WS D, 1J-166L2 2/7/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 10,517.0 12,921.0 3,453.1 3,526.9 WS D, 1J-166L2 2/7/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 1J-166L2, 8/11/2025 2:26:38 PM Vertical schematic (actual) D-SAND LINER; 5,002.1- 12,952.7 SLOTS; 10,517.0-12,921.0 SLOTS; 8,571.0-9,806.0 SLOTS; 8,021.0-8,325.0 SLOTS; 5,067.0-7,805.0 INTERMEDIATE; 26.4-6,350.0 D LINER LEM; 4,885.0-5,137.0 GAS LIFT; 4,319.5 GAS LIFT; 2,572.0 SURFACE; 30.1-2,368.4 HEAT TRACE; 10.0 NIPPLE; 503.3 CONDUCTOR Insulated; 30.0- 108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 2/11/2006 Other Elev… 1J-166L2 ... TD Act Btm (ftKB) 12,994.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329161 Wellbore Status PROD Max Angle & MD Incl (°) 95.60 MD (ftKB) 10,233.79 WELLNAME WELLBORE1J-166 Annotation Last WO: End Date 4/17/2008 H2S (ppm) 424 Date 7/6/2023 Comment SSSV: NIPPLE 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 Treatment 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 12952'feet 10235'feet true vertical 3593' feet None feet Effective Depth measured 10235'feet 4896', 4897', 5107', 5480' feet true vertical 3579'feet 3392', 3393', 3437', 3513' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 4922' MD 3398' TVD Packers and SSSV (type, measured and true vertical depth) 4896' MD 4897' MD 5107' MD 5480' MD N/A 3392' TVD 3393' TVD 3437' TVD 3513' 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: 2368' 2194' Burst Collapse B Liner LEM B Sand Liner 6324' 414' 7532' Casing 3649' 3520' 4-1/2" 6350' 5521' 12909' 3590' 2338' 108'Conductor Surface Intermediate 16" 10-3/4" 78' measured TVD 7-5/8" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 205-199 50-029-23291-60-00 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: ADL0025650, ADL0025661 Kuparuk River Oil Field/ West Sak Oil Pool Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 108' ~~~ Well Remains Shut-In ~~ ~ N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: ZXP Liner Top Packer Packer: Baker 109-47 Seal Assembly Packer: ZXP Liner Top Packer Packer: HRD ZXP Liner Top Packer SSSV: None Jan Byrne jan.byrne@conocophillips.com 265-6471Staff Well Interventions Engineer Alternating Slotted Liner: 5409-12878' Alternating Slotted Liner: 3500-3589' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov KRU 1J-166L1 By Grace Christianson at 12:30 pm, Dec 23, 2024 Digitally signed by Jan Byrne DN: OU=Wells Group, O=ConocoPhillips, CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2024.12.23 12:07:51-09'00' Foxit PDF Editor Version: 13.0.0 Jan Byrne RBDMS JSB 122624 VTL 9/8/2025 DSR-1/8/25 DTTMSTART JOBTYP SUMMARYOPS 11/27/2024 REPAIR WELL RIG UP TO PUMP RPPG TREATMENT. DELAYS FROM TROUBLESHOOTING SUPPORT EQUIPMENT, PRODUCT QUALITY CONCERNS, LEAKY TREE VALVES AND ICE PLUGS RESULTED IN CREW HOURING OUT. WILL RETURN IN THE AM. JOB IN PROGRESS. 11/28/2024 REPAIR WELL PUMPED FULLBORE RPPG TREATMENT TO MBE @7320' RKB IN THE B LATERAL. PUMPED 6864 LBS OF RPPG. CALLED FLUSH AT 676 PSI. STEADY PRESSURE INCREASE WHILE PUMPING. FINAL WHP=900 PSI, TARGET WAS ~1000 PSI. WELL TO REMAIN SHUT IN FOR 48 HRS. 1J-164L1 RPPG Treatment Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-166 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled Gauges 1J-166 12/10/2022 zembaej Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR Insulated 16 15.25 30.0 108.0 108.0 62.50 H-40 WELDED SURFACE 10 3/4 9.95 30.1 2,368.4 2,194.2 45.50 L-80 BTC INTERMEDIATE 7 5/8 6.87 26.4 6,350.0 3,648.8 29.70 L-80 BTCM D LINER LEM 4 1/2 3.96 4,885.0 5,137.0 3,443.3 12.60 L-80 IBT B LINER LEM 4 1/2 3.96 5,107.5 5,521.5 3,519.7 12.60 L-80 IBT A-SAND LINER 4 1/2 3.96 5,480.0 12,840.0 3,717.2 12.60 L-80 IBT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 22.4 Set Depth … 4,922.0 Set Depth … 3,398.0 String Max No… 4 1/2 Tubing Description TUBING WO Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 22.4 22.4 0.00 HANGER 10.850 TUBING HANGER T&C Non- Upset 3.958 503.3 503.3 0.57 NIPPLE 5.210 3.875" Camco "DB" Nipple 3.875 2,572.0 2,361.6 36.03 GAS LIFT 5.984 CAMCO KBG-2- 1R 3.938 4,319.5 3,225.8 69.38 GAS LIFT 5.984 CAMCO KBG-2- 1R 3.938 4,831.4 3,377.1 75.81 SLEEVE 5.490 BAKER CMD Sliding Sleeve (verified closed 1/11/21) 3.812 4,842.1 3,379.7 76.04 GAUGE 4.900 Baker Guardian Guage 4.000 4,893.7 3,391.7 77.04 LOCATOR 5.480 Locator / 2' space out 3.910 4,897.4 3,392.6 77.09 SEAL ASSY 4.750 BAKER 190-47 SEAL ASSEMBLY 3.880 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 10.0 10.0 0.00 HEAT TRACE HEAT TRACE 5/17/2008 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,572.0 2,361.6 36.03 1 GAS LIFT GLV BK-5 1 1,427.0 11/15/2020 0.156 4,319.5 3,225.8 69.38 2 GAS LIFT OV BK-5 1 0.0 11/15/2020 0.313 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,885.0 3,389.8 76.92 TIE BACK 6.430 TIE BACK EXTENSION 5.750 4,896.0 3,392.2 77.07 PACKER 6.550 ZXP LINER TOP PACKER 4.980 4,958.7 3,405.8 77.91 NIPPLE 5.000 3.75" DB NIPPLE 3.750 5,107.5 3,436.8 77.43 PACKER 6.550 ZXP LINER TOP PACKER 4.950 5,126.6 3,441.0 77.14 SBR 6.280 109-47 CASING SEAL BORE RECEPTACLE 4.750 5,145.9 3,445.3 76.85 XO BUSHING 6.040 CROSSOVER BUSHING 3.950 5,147.3 3,445.7 76.83 SWIVEL 5.770 BAKER CASING SWIVEL 3.960 5,442.8 3,506.5 80.17 NIPPLE 5.200 CAMCO DB-6 NIPPLE 3.563 5,475.2 3,512.0 80.32 BENT JT 4.500 3.880 5,480.0 3,512.8 80.35 PACKER 7.600 "HRD" ZXP Liner Top Packer 5.5" X 7.6" 4.970 5,499.0 3,516.0 80.44 NIPPLE 5.500 "RS" Packoff Seal Nipple 5.5" 4.875 5,531.4 3,521.3 80.59 LINRE XO THREAD 6.020 XO Bushing 3.92" ID, 6.02 OD 3.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,360.0 8,698.0 3,649.9 3,655.8 WS A2, A3, 1J- 166 1/19/2006 32.0 SLOTS ALL PERFS THIS WELLBORE - Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,945.0 10,031.0 3,661.1 3,711.7 WS A2, 1J-166 1/19/2006 32.0 SLOTS 10,648.0 10,710.0 3,678.3 3,668.4 WS A2, 1J-166 1/19/2006 32.0 SLOTS 10,990.0 12,808.0 3,651.8 3,715.9 WS A2, 1J-166 1/19/2006 32.0 SLOTS 1J-166, 12/19/2024 3:20:05 PM Vertical schematic (actual) A-SAND LINER; 5,480.0- 12,840.0 SLOTS; 10,990.0-12,808.0 SLOTS; 10,648.0-10,710.0 SLOTS; 8,945.0-10,031.0 SLOTS; 6,360.0-8,698.0 INTERMEDIATE; 26.4-6,350.0 B LINER LEM; 5,107.5-5,521.5 B-SAND LINER; 5,377.3- 12,909.3 D LINER LEM; 4,885.0-5,137.0 D-SAND LINER; 5,002.1- 12,952.7 GAS LIFT; 4,319.5 GAS LIFT; 2,572.0 SURFACE; 30.1-2,368.4 HEAT TRACE; 10.0 NIPPLE; 503.3 CONDUCTOR Insulated; 30.0- 108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 2/11/2006 Other Elev… 1J-166 ... TD Act Btm (ftKB) 12,853.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329100 Wellbore Status PROD Max Angle & MD Incl (°) 99.97 MD (ftKB) 10,663.58 WELLNAME WELLBORE1J-166 Annotation Last WO: End Date 4/17/2008 H2S (ppm) 424 Date 7/6/2023 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-166L1 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: WELL REVIEW 1J-166L1 5/13/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread B-SAND LINER 4 1/2 3.96 5,377.3 12,909.3 3,590.5 12.60 L-80 IBT Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 10,235.0 3,579.0 88.97 PLUG B-SAND IBP set 6/3/2008 6/3/2008 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,402.2 3,499.3 81.08 SWIVEL 5.750 Baker Casing Swivel 3.960 12,877.8 3,589.1 87.11 XO Reducing 4.500 4-1/2" X 3-1/2" XO sub 2.992 12,879.2 3,589.1 87.14 BENT JT 3.500 3-1/2" Bent Joint IBT, 9.2 ppf, L- 80 2.900 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,409.0 8,178.0 3,500.3 3,512.6 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,426.0 10,101.0 3,519.4 3,576.8 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 10,905.0 12,417.0 3,522.5 3,563.9 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 12,571.0 12,878.0 3,570.1 3,589.1 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 1J-166L1, 12/19/2024 3:20:06 PM Vertical schematic (actual) B-SAND LINER; 5,377.3- 12,909.3 SLOTS; 12,571.0-12,878.0 SLOTS; 10,905.0-12,417.0 PLUG; 10,235.0 SLOTS; 8,426.0-10,101.0 SLOTS; 5,409.0-8,178.0 B LINER LEM; 5,107.5-5,521.5 INTERMEDIATE; 26.4-6,350.0 D LINER LEM; 4,885.0-5,137.0 D-SAND LINER; 5,002.1- 12,952.7 GAS LIFT; 4,319.5 GAS LIFT; 2,572.0 SURFACE; 30.1-2,368.4 HEAT TRACE; 10.0 NIPPLE; 503.3 CONDUCTOR Insulated; 30.0- 108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 2/11/2006 Other Elev… 1J-166L1 ... TD Act Btm (ftKB) 12,952.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329160 Wellbore Status PROD Max Angle & MD Incl (°) 99.97 MD (ftKB) 10,422.57 WELLNAME WELLBORE1J-166 Annotation Last WO: End Date 4/17/2008 H2S (ppm) 424 Date 7/6/2023 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-166L2 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Type 1 Isolation Sleeve 1J-166L2 11/9/2019 mcanej Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread D-SAND LINER 4 1/2 3.96 5,002.1 12,952.7 3,528.4 12.60 L-80 IBT Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,027.0 3,419.7 79.25 SWIVEL 4.750 Baker Casing Swivel 3.960 12,920.8 3,526.8 87.23 XO Reducing 4.500 4-1/2" X 3-1/2" XO sub 2.992 12,922.2 3,526.9 87.22 BENT JT 3.500 3-1/2" Bent Joint IBT, 9.2 ppf, L- 80 2.900 12,951.2 3,528.4 87.03 WLEG 3.500 Baker 3-1/2" Guide Shoe ( No float) 2.900 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,067.0 7,805.0 3,426.4 3,464.7 WS D, 1J-166L2 2/7/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,021.0 8,325.0 3,463.9 3,471.5 WS D, 1J-166L2 2/7/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,571.0 9,806.0 3,472.2 3,492.6 WS D, 1J-166L2 2/7/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 10,517.0 12,921.0 3,453.1 3,526.9 WS D, 1J-166L2 2/7/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 1J-166L2, 12/19/2024 3:20:07 PM Vertical schematic (actual) D-SAND LINER; 5,002.1- 12,952.7 SLOTS; 10,517.0-12,921.0 SLOTS; 8,571.0-9,806.0 SLOTS; 8,021.0-8,325.0 SLOTS; 5,067.0-7,805.0 INTERMEDIATE; 26.4-6,350.0 D LINER LEM; 4,885.0-5,137.0 GAS LIFT; 4,319.5 GAS LIFT; 2,572.0 SURFACE; 30.1-2,368.4 HEAT TRACE; 10.0 NIPPLE; 503.3 CONDUCTOR Insulated; 30.0- 108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 2/11/2006 Other Elev… 1J-166L2 ... TD Act Btm (ftKB) 12,994.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329161 Wellbore Status PROD Max Angle & MD Incl (°) 95.60 MD (ftKB) 10,233.79 WELLNAME WELLBORE1J-166 Annotation Last WO: End Date 4/17/2008 H2S (ppm) 424 Date 7/6/2023 Comment SSSV: NIPPLE 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Screen Scab Liner Install 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 12952'None Casing Collapse Structural Conductor Surface Intermediate Production B Sand Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 9/1/2024 12909' 4-1/2" 3723' Packer: ZXP Liner Top Packer Packer: HRD ZXP Liner Top Packer SSSV: None Perforation Depth MD (ft): L-80 6324' 2338' 6350' 5409-12878' Alternating Slotted Liner 7532' 4-1/2" 3500-3589' Alternating Slotted Liner Perforation Depth TVD (ft): 108' 2368' 16" 10-3/4" 78' 7-5/8" 4922' MD 108' 2194' 3649' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY West Sak Oil Pool TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025650, ADL0025661 205-199 P.O. Box 100360, Anchorage, AK 99510 50-029-23291-60-00 Kupauk River Field West Sak Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 4885' MD and 3390' TVD 5104' MD and 3436' TVD N/A Travis Smith Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: Travis.T.Smith@conocophillips.com (907) 265-6846 Willow Staff Completions Engineer KRU 1J-166L1 3593' 10235' 3579' 440 10235' N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Travis Smith Digitally signed by Travis Smith Date: 2024.07.18 11:42:43 -08'00' 324-417 By Grace Christianson at 2:47 pm, Jul 18, 2024 X DSR-7/18/24 10-404 VTL 8/5/2024 A.Dewhurst 05AUG24JLC 8/6/2024 Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.08.07 10:33:38 -08'00' 08/07/24 RBDMS JSB 080824 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 16, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Elliott Tuttle Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Producer 1J- 166L1(PTD# 205-199) and 1J-166L2 (PTD# 205-200). Well 1J-166 was drilled and completed in February 2006 by Doyon 141 as a tri-lateral West Sak Producer with an ESP upper completion. The well was then worked over in April 2008 by Nordic 3, where a LEM (Lateral Entry Module) was landed in the L2 Hook hanger and a 4 1/2" Gas Lifted upper completion. The well has a history of making sand and it is known that if sand production is limited, it reduces the risk of MBE's (Matrix Bypass Events) from occuring. This RWO request is to land screen scab liners in the L1 and L2 Laterals. If you have any questions or require any further information, please contact me at 907-252-3347. Scab liners will be run in the L1 and L2 laterals by way of 2 5/8" Coiled Tubing on a service unit. The Scab liner will have to be run in sections to reach TD and will snapped together with sealed junctions. The last section run will have the packer and will be set by way of CT pressure to isolate the scab liner. ϭ:Ͳϭϲϲ>ϭ͕ϭ:Ͳϭϲϲ>ϮZtKWƌŽĐĞĚƵƌĞ tĞƐƚ^ĂŬWƌŽĚƵĐĞƌ ^ĐƌĞĞŶ^ĐĂď>ŝŶĞƌ/ŶƐƚĂůů Wdη͛ƐϮϬϱͲϭϵϵ͕ϮϬϱͲϮϬϬ WĂŐĞϭŽĨϰ WƌĞͲZŝŐtŽƌŬ͗ ϭ͘ ^ĞƚWůƵŐΛϱϰϰϯ͛Z<ƚŽŝƐŽůĂƚĞŵĂŝŶďŽƌĞůĂƚĞƌĂů Ϯ͘ ^Ğƚ/ŶĐƌĞĂƐĞĚĐĐĞƐƐ>ĂƚĞƌĂůŝǀĞƌƚĞƌ;/>ͿŝŶ>ϭůĂƚĞƌĂůŶƚƌǇDŽĚƵůĞ;>DͿΛϱϯϲϳ͛Z<͕ƌŝĨƚǁŝƚŚϯ͘Ϯϱ͟ ^ĐƌĞĞŶƌŝĨƚ ϯ͘ KŶĐĞƌŝĨƚŝƐĐŽŵƉůĞƚĞĚ͕ƐĞƚ/ƐŽͲ^ůĞĞǀĞĂĐƌŽƐƐ>Ϯ>D͕WĞƌĨŽƌŵ^ĂŶĚ>ĂƚĞƌĂůĨůƵĨĨĂŶĚƐƚƵĨĨĐůĞĂŶŽƵƚĚŽǁŶƚŽ d;ϭϮ͕ϵϬϵ͛Z<ͿŽƌƚŽůŽĐŬƵƉ ϰ͘ WƵůů/ƐŽ^ůĞĞǀĞĨƌŽŵ>Ϯ>D͕WƵůů/>ŝǀĞƌƚĞƌĨƌŽŵ>ϭ>D͘ ϱ͘ ^ĞƚƉŽƐŝƚŝŽŶϭ/ƐŽͲƐůĞĞǀĞŝŶƚŚĞ>ϭ>D ϲ͘ ^Ğƚ/>ŝŶ>Ϯ>DΛϰϵϵϱ͛Z< ϳ͘ ƌŝĨƚ>DǁŝƚŚϯ͘Ϯϱ͟^ĐƌĞĞŶƌŝĨƚ͕WKK, ϴ͘ WĞƌĨŽƌŵ>ĂƚĞƌĂůĨůƵĨĨĂŶĚƐƚƵĨĨĐůĞĂŶŽƵƚĚŽǁŶƚŽd;ϭϮ͕ϵϱϯ͛Z<ͿŽƌƚŽůŽĐŬƵƉ ϵ͘ WƵůů/>ĂŶĚ/ƐŽ^ůĞĞǀĞ͕WƵůůWůƵŐ ϭϬ͘ KďƚĂŝŶƵƉĚĂƚĞĚ^,W^ƵƌǀĞǇĂƚϱϬϬϱ͛dD;KƌŶŽƚĞŐĂƵŐĞƉƌĞƐƐƵƌĞΛϯϯϴϬ͛ds͕ĂŶĚŬŶŽǁŶĨůƵŝĚďĞůŽǁ ŐĂƵŐĞĚĞƉƚŚͿ ϭϭ͘ ZĞŵŽǀĞǁĞůůŚŽƵƐĞĂŶĚďƵŝůĚƐĐĂĨĨŽůĚŝŶŐƚŽƐƵƉƉŽƌƚƚŚĞŵĂŬĞƵƉŽĨƚŚĞƐĐĂďůŝŶĞƌ ZŝŐtŽƌŬ͗ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ϵͬϭͬϮϬϮϰ D/Zh ϭ͘ D/Zh^>͞Z͟ŽŝůƉĂĐŬĂŐĞƌŝŐƵƐŝŶŐϮϱͬϴ͟ĐŽŝůĞĚƚƵďŝŶŐŽŶϭ:Ͳϭϲϲ͘Ehϱϭͬϴ͟KD/KW͕ƚĞƐƚƐĂŵĞƚŽ ϮϱϬϬƉƐŝ͘ Ϯ͘ Z/,ĂŶĚƐĞƚWůƵŐΛϱϰϰϯ͛Z<͘ ^ĂŶĚ>ĂƚĞƌĂůKƉĞƌĂƚŝŽŶƐ;ϭ:Ͳϭϲϲ>ϭͿ ϯ͘ Z/,ǁŝƚŚ/>^ĞƚƚŝŶŐ,͕ƐŶĂƉŝŶƚŽ>ϭ>DΛϱϯϲϳ͛Z<ĂŶĚƐĞƚ͘ ϰ͘ Z/,ŽŶϮϱͬϴ͟ŽŝůĞĚdƵďŝŶŐĂŶĚĂϯ͟EŽǌǌůĞĂŶĚĐŽŶĨŝƌŵd͕WKK,ůĂǇŝŶŐŝŶϴ͘ϲƉƉŐƐůŝĐŬƐĞĂǁĂƚĞƌ͘ ϱ͘ Wh^ĐƌĞĞŶ^ĐĂď>ŝŶĞƌǁŚŝůĞƉƵŵƉŝŶŐĂĐƌŽƐƐƚŚĞƚŽƉǁŝƚŚƐĂŵĞĨůƵŝĚŽŶĂŶĞƐƚĂďůŝƐŚĞĚĨŝůůƐĐŚĞĚƵůĞ Ă͘ ,ĂǀĞϮϱͬϴ͟ŬŝĐŬ:ŶƚŶĞĂƌǁŽƌŬƉůĂƚĨŽƌŵǁŝƚŚďĂůůƚǇƉĞƐĂĨĞƚǇǀĂůǀĞ͘ ϲ͘ ^ĐĂďůŝŶĞƌǁŝůůďĞƌƵŶŝŶƐĞĐƚŝŽŶƐ͕ĚƌĂĨƚƌƵŶŶŝŶŐŽƌĚĞƌ͗ # of Jnts Complete Description Length Tops Length of Liner/ Run Shorty Deployment Slv, 1.813" Polish Bore - 3" G Profile x 2 3/8" Hyd511 Pin Down 1.2 5402 160.65 Welltec 314WLTP, Metal Expandable Packer - Hyd511 3 5403.2 Lower Seal Bore Receptacle, 1.813" PB - Hyd 511 0.95 5406.2 5 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 155 5407.15 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 5562.15 NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 5562.65 2481.8 80 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 2480 5563.95 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 8043.95 NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 8044.45 1892.8 4 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 124 8045.75 8 2 3/8" Hydrill 511 4.6lb/ft, L-80 Blank Tubing 248 8169.75 49 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 1519 8417.75 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 9936.75 NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 9937.25 1272.8 5 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 155 9938.55 ϭ:Ͳϭϲϲ>ϭ͕ϭ:Ͳϭϲϲ>ϮZtKWƌŽĐĞĚƵƌĞ tĞƐƚ^ĂŬWƌŽĚƵĐĞƌ ^ĐƌĞĞŶ^ĐĂď>ŝŶĞƌ/ŶƐƚĂůů Wdη͛ƐϮϬϱͲϭϵϵ͕ϮϬϱͲϮϬϬ WĂŐĞϮŽĨϰ 26 2 3/8" Hydrill 511 4.6lb/ft, L-80 Blank Tubing 806 10093.55 10 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 310 10899.55 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 11209.55 NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 11210.05 1055.8 34 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 1054 11211.35 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 12265.35 NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 12265.85 641.8 5 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 155 12267.15 5 2 3/8" Hydrill 511 4.6lb/ft, L-80 Blank Tubing 155 12422.15 10 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 310 12577.15 2 2 3/8" Hydrill 511 4.6lb/ft, L-80 Pup Jnts 20 12887.15 3" OD Solid Bullnose - Hydrill 511 Box 0.5 12907.15 12907.65 ϳ͘ KŶ>ĂƐƚƌƵŶ͕^ĞƚWĂĐŬĞƌĂŶĚƌĞůĞĂƐĞ͘ ϴ͘ Z/,ĂŶĚ&ŝƐŚ/>ĨƌŽŵ>ϭ>D ^ĂŶĚ>ĂƚĞƌĂůKƉĞƌĂƚŝŽŶƐ;ϭ:Ͳϭϲϲ>ϮͿ ϵ͘ Z/,ǁŝƚŚ/>^ĞƚƚŝŶŐ,͕ƐŶĂƉŝŶƚŽ>Ϯ>DΛϰϵϵϱ͛Z<ĂŶĚƐĞƚ͘ ϭϬ͘ Z/,ŽŶϮϱͬϴ͟ŽŝůĞĚdƵďŝŶŐĂŶĚĂϯ͟EŽǌǌůĞĂŶĚĐŽŶĨŝƌŵd͕WKK,ůĂǇŝŶŐŝŶϴ͘ϲƉƉŐƐůŝĐŬƐĞĂǁĂƚĞƌ͘ ϭϭ͘ Wh^ĐƌĞĞŶ^ĐĂď>ŝŶĞƌǁŚŝůĞƉƵŵƉŝŶŐĂĐƌŽƐƐƚŚĞƚŽƉǁŝƚŚƐĂŵĞĨůƵŝĚŽŶĂŶĞƐƚĂďůŝƐŚĞĚĨŝůůƐĐŚĞĚƵůĞ Ă͘ ,ĂǀĞϮϱͬϴ͟ŬŝĐŬ:ŶƚŶĞĂƌǁŽƌŬƉůĂƚĨŽƌŵǁŝƚŚďĂůůƚǇƉĞƐĂĨĞƚǇǀĂůǀĞ͘ ϭϮ͘ ^ĐĂďůŝŶĞƌǁŝůůďĞƌƵŶŝŶƐĞĐƚŝŽŶƐ͕ĚƌĂĨƚƌƵŶŶŝŶŐŽƌĚĞƌ͗ # of Jnts Complete Description Length Tops Length of Liner/ Run Shorty Deployment Slv, 1.813" Polish Bore - 3" G Profile x 2 3/8" Hyd511 Pin Down 1.2 5040 2485.65 Welltec 314WLTP, Metal Expandable Packer - Hyd511 3 5041.2 Lower Seal Bore Receptacle, 1.813" PB - Hyd 511 0.95 5044.2 80 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 2480 5045.15 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 7525.15 NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 7525.65 2047.8 9 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 279 7526.95 7 2 3/8" Hydrill 511 4.6lb/ft, L-80 Blank Tubing 217 7805.95 10 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 310 8022.95 8 2 3/8" Hydrill 511 4.6lb/ft, L-80 Blank Tubing 248 8332.95 32 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 992 8580.95 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 9572.95 NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 9573.45 1644.8 8 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 248 9574.75 22 2 3/8" Hydrill 511 4.6lb/ft, L-80 Blank Tubing 682 9822.75 23 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 713 10504.75 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 11217.75 NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 11218.25 993.8 32 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 992 11219.55 NSAK QCLL, Shrouded Latch - Hyd 511 Box (latched length) 0.5 12211.55 ϭ:Ͳϭϲϲ>ϭ͕ϭ:Ͳϭϲϲ>ϮZtKWƌŽĐĞĚƵƌĞ tĞƐƚ^ĂŬWƌŽĚƵĐĞƌ ^ĐƌĞĞŶ^ĐĂď>ŝŶĞƌ/ŶƐƚĂůů Wdη͛ƐϮϬϱͲϭϵϵ͕ϮϬϱͲϮϬϬ WĂŐĞϯŽĨϰ NSAK QCLL, Deployment Receptacle - Hyd 511 Pin 1.3 12212.05 740.8 23 2 3/8" Hydrill 511 4.6lb/ft Double Jacket Extra Fine Mesh Screen 713 12213.35 Spaceout Jnts - 2 3/8" Hydrill 511 26 12926.35 3" OD Solid Bullnose - Hydrill 511 Box 0.5 12952.35 12952.85 ϭϯ͘ KŶ>ĂƐƚƌƵŶ͕^ĞƚWĂĐŬĞƌĂŶĚƌĞůĞĂƐĞ͘ ϭϰ͘ Z/,ĂŶĚ&ŝƐŚ/>ĨƌŽŵ>Ϯ>D ϭϱ͘ Z/,ĂŶĚ&ŝƐŚWůƵŐĨƌŽŵEŝƉƉůĞΛϱϰϰϯ͛Z<͕ĨƌĞĞǌĞƉƌŽƚĞĐƚǁĞůů͘ ZDK ϭϲ͘ EKW͘ ϭϳ͘ ZDK͘ WŽƐƚͲZŝŐtŽƌŬ ϭϴ͘ ZĞƚƵƌŶƚŽƉƌŽĚƵĐƚŝŽŶ 'ĞŶĞƌĂůtĞůůŝŶĨŽ͗ WƌŽĚƵĐƚŝŽŶŶŐŝŶĞĞƌ͗Carolyn Kirchner tŽƌŬŽǀĞƌŶŐŝŶĞĞƌ͗Elliott Tuttle (907-252-3347/ Elliott.tuttle@conocophillips.com) ƵƌƌĞŶƚKƉĞƌĂƚŝŽŶƐ͗On Production tĞůůdǇƉĞ͗Producer ^ĐŽƉĞŽĨtŽƌŬ͗Confirm TD in L1 and L2 Laterals then deploy screen scab liners up to lateral windows. KWĐŽŶĨŝŐƵƌĂƚŝŽŶ͗Attached below MPSP: ϴϵϳƉƐŝƵƐŝŶŐϬ͘ϭƉƐŝͬĨƚŐƌĂĚŝĞŶƚ Static BHP͗ϭϮϯϱƉƐŝͬϯϯϳϳ͛dsŵĞĂƐƵƌĞĚŽŶϭϮͬϭϬͬϮϮ;ϳ͘ϬϯƉƉŐͿ ϭ:Ͳϭϲϲ>ϭ͕ϭ:Ͳϭϲϲ>ϮZtKWƌŽĐĞĚƵƌĞ tĞƐƚ^ĂŬWƌŽĚƵĐĞƌ ^ĐƌĞĞŶ^ĐĂď>ŝŶĞƌ/ŶƐƚĂůů Wdη͛ƐϮϬϱͲϭϵϵ͕ϮϬϱͲϮϬϬ WĂŐĞϰŽĨϰ 1J-166 Remedial SAS Install COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 108 108 16 15.25 62.5 H-40 Welded Welded Surface 2368 2194 10 3/4 9.95 45.5 L-80 BTC BTC Intermediate 6350 3649 7 5/8 6.87 29.7 L-80 BTC-M BTC-M D Liner LEM 5137 3443 4 1/2 3.958 12.6 L-80 IBT IBT B Liner LEM 5522 3520 4 1/2 3.958 12.6 L-80 IBT IBT A Sand Liner 12840 3717 4 1/2 3.958 12.6 L-80 IBT IBT Tubing 4922 3398 4 1/2 3.958 12.6 L-80 IBT-M IBT-M D Sand (L2), Screen Liner by Trips Trips Length (ft) Description 1 741 QCLL, Screen Jnts, Solid Bullnose 2 994 QCLL, Screen Jnts 3 1,645 QCLL, Solid and Screen Jnts 4 2,048 QCLL, Solid and Screen Jnts 5 2,486 3" G Profile, 314 WLTP, Screen Jnts, QCLL B Sand (L1), Screen Liner by Trips Trips Length (ft) Description 1 642 QCLL, Solid and Screen Jnts, Solid Bullnose 2 1,056 QCLL, Screen Jnts 3 1,273 QCLL, Solid and Screen Jnts 4 1,893 QCLL, Solid and Screen Jnts 5 2,482 QCLL, Screen Jnts 61613" G Profile, 314 WLTP, 5 Screen Jnts, QCLL (For Space Out) Surface Casing Conductor Perfs 4-1/2" DB-6 Landing Nipple @ 503' RKB (3.875" ID) 4-1/2" x 1" Camco KBG-2-1R GLM @ 2572' RKB 4-1/2" x 1" Camco KBG-2-1R GLM @ 4320' RKB Baker CMD Sliding Sleeve @ 4831' (3.812" ID) 4-1/2" Gauge Carrier, BH Gaurdian Gauge @ 4842' RKB 4-1/2" Locator/ Seal Assembly @ 4893' RKB D Sand LEM (Pos 2): - ZXP Liner Top Packer @ 4896' RKB - 190-47 Seal Bore Extension @ 4904'-4923' RKB - 3.75" DB Nipple @ 4959' RKB - Top of LEM 4995' RKB B Sand LEM (Pos 1): - ZXP Liner Top Packer @ 5104' RKB - 190-47 Seal Bore Extensoin @ 5123'-5143' RKB - Top of LEM 5366.6' RKB Pos 1 LEM Latched into L1 B Hook Hanger Intermediate Casing L1 Lateral: 6263' of Screen Jnts 1236' Solid Jnts L2 Lateral: 6680' of Screen Jnts 1172' Solid Jnts Pos 2 LEM Latched into L1 B Hook Hanger Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-166 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled Gauges 1J-166 12/10/2022 zembaej Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR Insulated 16 15.25 30.0 108.0 108.0 62.50 H-40 WELDED SURFACE 10 3/4 9.95 30.1 2,368.4 2,194.2 45.50 L-80 BTC INTERMEDIATE 7 5/8 6.87 26.4 6,350.0 3,648.8 29.70 L-80 BTCM D LINER LEM 4 1/2 3.96 4,885.0 5,137.0 3,443.3 12.60 L-80 IBT B LINER LEM 4 1/2 3.96 5,107.5 5,521.5 3,519.7 12.60 L-80 IBT A-SAND LINER 4 1/2 3.96 5,480.0 12,840.0 3,717.2 12.60 L-80 IBT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 22.4 Set Depth … 4,922.0 Set Depth … 3,398.0 String Max No… 4 1/2 Tubing Description TUBING WO Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 22.4 22.4 0.00 HANGER 10.850 TUBING HANGER T&C Non- Upset 3.958 503.3 503.3 0.57 NIPPLE 5.210 3.875" Camco "DB" Nipple 3.875 2,572.0 2,361.6 36.03 GAS LIFT 5.984 CAMCO KBG-2- 1R 3.938 4,319.5 3,225.8 69.38 GAS LIFT 5.984 CAMCO KBG-2- 1R 3.938 4,831.4 3,377.1 75.81 SLEEVE 5.490 BAKER CMD Sliding Sleeve (verified closed 1/11/21) 3.812 4,842.1 3,379.7 76.04 GAUGE 4.900 Baker Guardian Guage 4.000 4,893.7 3,391.7 77.04 LOCATOR 5.480 Locator / 2' space out 3.910 4,897.4 3,392.6 77.09 SEAL ASSY 4.750 BAKER 190-47 SEAL ASSEMBLY 3.880 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 10.0 10.0 0.00 HEAT TRACE HEAT TRACE 5/17/2008 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,572.0 2,361.6 36.03 1 GAS LIFT GLV BK-5 1 1,427.0 11/15/2020 0.156 4,319.5 3,225.8 69.38 2 GAS LIFT OV BK-5 1 0.0 11/15/2020 0.313 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,885.0 3,389.8 76.92 TIE BACK 6.430 TIE BACK EXTENSION 5.750 4,896.0 3,392.2 77.07 PACKER 6.550 ZXP LINER TOP PACKER 4.980 4,958.7 3,405.8 77.91 NIPPLE 5.000 3.75" DB NIPPLE 3.750 5,107.5 3,436.8 77.43 PACKER 6.550 ZXP LINER TOP PACKER 4.950 5,126.6 3,441.0 77.14 SBR 6.280 109-47 CASING SEAL BORE RECEPTACLE 4.750 5,145.9 3,445.3 76.85 XO BUSHING 6.040 CROSSOVER BUSHING 3.950 5,147.3 3,445.7 76.83 SWIVEL 5.770 BAKER CASING SWIVEL 3.960 5,442.8 3,506.5 80.17 NIPPLE 5.200 CAMCO DB-6 NIPPLE 3.563 5,475.2 3,512.0 80.32 BENT JT 4.500 3.880 5,480.0 3,512.8 80.35 PACKER 7.600 "HRD" ZXP Liner Top Packer 5.5" X 7.6" 4.970 5,499.0 3,516.0 80.44 NIPPLE 5.500 "RS" Packoff Seal Nipple 5.5" 4.875 5,531.4 3,521.3 80.59 LINRE XO THREAD 6.020 XO Bushing 3.92" ID, 6.02 OD 3.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,360.0 8,698.0 3,649.9 3,655.8 WS A2, A3, 1J- 166 1/19/2006 32.0 SLOTS ALL PERFS THIS WELLBORE - Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,945.0 10,031.0 3,661.1 3,711.7 WS A2, 1J-166 1/19/2006 32.0 SLOTS 10,648.0 10,710.0 3,678.3 3,668.4 WS A2, 1J-166 1/19/2006 32.0 SLOTS 10,990.0 12,808.0 3,651.8 3,715.9 WS A2, 1J-166 1/19/2006 32.0 SLOTS 1J-166, 7/17/2024 12:20:46 PM Vertical schematic (actual) A-SAND LINER; 5,480.0- 12,840.0 SLOTS; 10,990.0-12,808.0 SLOTS; 10,648.0-10,710.0 SLOTS; 8,945.0-10,031.0 SLOTS; 6,360.0-8,698.0 INTERMEDIATE; 26.4-6,350.0 B LINER LEM; 5,107.5-5,521.5 B-SAND LINER; 5,377.3- 12,909.3 D LINER LEM; 4,885.0-5,137.0 D-SAND LINER; 5,002.1- 12,952.7 GAS LIFT; 4,319.5 GAS LIFT; 2,572.0 SURFACE; 30.1-2,368.4 HEAT TRACE; 10.0 NIPPLE; 503.3 CONDUCTOR Insulated; 30.0- 108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 2/11/2006 Other Elev… 1J-166 ... TD Act Btm (ftKB) 12,853.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329100 Wellbore Status PROD Max Angle & MD Incl (°) 99.97 MD (ftKB) 10,663.58 WELLNAME WELLBORE1J-166 Annotation Last WO: End Date 4/17/2008 H2S (ppm) 424 Date 7/6/2023 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-166L1 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: WELL REVIEW 1J-166L1 5/13/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread B-SAND LINER 4 1/2 3.96 5,377.3 12,909.3 3,590.5 12.60 L-80 IBT Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 10,235.0 3,579.0 88.97 PLUG B-SAND IBP set 6/3/2008 6/3/2008 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,402.2 3,499.3 81.08 SWIVEL 5.750 Baker Casing Swivel 3.960 12,877.8 3,589.1 87.11 XO Reducing 4.500 4-1/2" X 3-1/2" XO sub 2.992 12,879.2 3,589.1 87.14 BENT JT 3.500 3-1/2" Bent Joint IBT, 9.2 ppf, L- 80 2.900 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,409.0 8,178.0 3,500.3 3,512.6 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,426.0 10,101.0 3,519.4 3,576.8 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 10,905.0 12,417.0 3,522.5 3,563.9 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 12,571.0 12,878.0 3,570.1 3,589.1 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 1J-166L1, 7/17/2024 12:20:47 PM Vertical schematic (actual) B-SAND LINER; 5,377.3- 12,909.3 SLOTS; 12,571.0-12,878.0 SLOTS; 10,905.0-12,417.0 PLUG; 10,235.0 SLOTS; 8,426.0-10,101.0 SLOTS; 5,409.0-8,178.0 B LINER LEM; 5,107.5-5,521.5 INTERMEDIATE; 26.4-6,350.0 D LINER LEM; 4,885.0-5,137.0 D-SAND LINER; 5,002.1- 12,952.7 GAS LIFT; 4,319.5 GAS LIFT; 2,572.0 SURFACE; 30.1-2,368.4 HEAT TRACE; 10.0 NIPPLE; 503.3 CONDUCTOR Insulated; 30.0- 108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 2/11/2006 Other Elev… 1J-166L1 ... TD Act Btm (ftKB) 12,952.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329160 Wellbore Status PROD Max Angle & MD Incl (°) 99.97 MD (ftKB) 10,422.57 WELLNAME WELLBORE1J-166 Annotation Last WO: End Date 4/17/2008 H2S (ppm) 424 Date 7/6/2023 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-166L2 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Type 1 Isolation Sleeve 1J-166L2 11/9/2019 mcanej Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread D-SAND LINER 4 1/2 3.96 5,002.1 12,952.7 3,528.4 12.60 L-80 IBT Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,027.0 3,419.7 79.25 SWIVEL 4.750 Baker Casing Swivel 3.960 12,920.8 3,526.8 87.23 XO Reducing 4.500 4-1/2" X 3-1/2" XO sub 2.992 12,922.2 3,526.9 87.22 BENT JT 3.500 3-1/2" Bent Joint IBT, 9.2 ppf, L- 80 2.900 12,951.2 3,528.4 87.03 WLEG 3.500 Baker 3-1/2" Guide Shoe ( No float) 2.900 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,067.0 7,805.0 3,426.4 3,464.7 WS D, 1J-166L2 2/7/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,021.0 8,325.0 3,463.9 3,471.5 WS D, 1J-166L2 2/7/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,571.0 9,806.0 3,472.2 3,492.6 WS D, 1J-166L2 2/7/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 10,517.0 12,921.0 3,453.1 3,526.9 WS D, 1J-166L2 2/7/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 1J-166L2, 7/17/2024 12:20:48 PM Vertical schematic (actual) D-SAND LINER; 5,002.1- 12,952.7 SLOTS; 10,517.0-12,921.0 SLOTS; 8,571.0-9,806.0 SLOTS; 8,021.0-8,325.0 SLOTS; 5,067.0-7,805.0 INTERMEDIATE; 26.4-6,350.0 D LINER LEM; 4,885.0-5,137.0 GAS LIFT; 4,319.5 GAS LIFT; 2,572.0 SURFACE; 30.1-2,368.4 HEAT TRACE; 10.0 NIPPLE; 503.3 CONDUCTOR Insulated; 30.0- 108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 2/11/2006 Other Elev… 1J-166L2 ... TD Act Btm (ftKB) 12,994.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329161 Wellbore Status PROD Max Angle & MD Incl (°) 95.60 MD (ftKB) 10,233.79 WELLNAME WELLBORE1J-166 Annotation Last WO: End Date 4/17/2008 H2S (ppm) 424 Date 7/6/2023 Comment SSSV: NIPPLE 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 Treatment 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 12952'feet 10235'feet true vertical 3593' feet None feet Effective Depth measured 12952'feet 4896', 5107', 5480'feet true vertical 3593' feet 3390', 3437', 3513'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 4922' MD 3398' TVD Packers and SSSV (type, measured and true vertical depth) 4896' MD 5107' MD 5480' MD N/A 3390' TVD 3437' TVD 3513' 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: 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: 2368' 2194' Burst Collapse Production B-Sand Liner 6324' 7532' Casing 4-1/2" 6350' 12909' 3590' 2338' 108'Conductor Surface Intermediate 16" 10-3/4" 78' measured TVD 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 205-199 50-029-23291-60-00 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: ADL0025650. ADL0025661 Kuparuk River Field/ West Sak Oil Pool KRU 1J-166L1 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 108' ~ ~~ Well Remains Offline ~~ ~ N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: ZXP Liner Top Packer Packer: ZXP Liner Top Packer Packer: HRD ZXP Liner Top Packer SSSV: None Allen Eschete allen.eschete@conocophillips.com (907) 265-6558Interventions Engineer Alternating Slotted/Blank Pipe: 5409-8178', 8426-10101', 10905-12417', 12571-12878' Alternating Slotted/Blank Pipe: 3500-3513', 3519-3577', 3522-3564', 3570-3589' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 3649' By Grace Christianson at 3:46 pm, Dec 01, 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: 2023.11.30 14:44:51-09'00' Foxit PDF Editor Version: 13.0.0 Allen Eschete DTTMSTART JOBTYP SUMMARYOPS 10/31/2023 REPAIR WELL FULLBORE RPPG PUMP JOB TO MBE @ 7320' RKB IN THE B LATERAL. PUMPED 7656 LBS OF RPPG @ 0.75 PPG. CALLED FLUSH @ 777 PSI / 214 BBLS RPPG SLURRY VOLUME. PRESSURE INCREASE WAS STEADY UNTIL IT REACHED 985 PSI & LEVELED OFF **TARGET FINAL PRESSURE WAS ~1400 PSI**. WELL TO REMAIN SHUT IN FOR 48 HOURS. 1J-164 RPPG Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1J-166 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled Gauges 1J-166 12/10/2022 zembaej Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR Insulated 16 15.25 30.0 108.0 108.0 62.50 H-40 WELDED SURFACE 10 3/4 9.95 30.1 2,368.4 2,194.2 45.50 L-80 BTC INTERMEDIATE 7 5/8 6.87 26.4 6,350.0 3,648.8 29.70 L-80 BTCM D LINER LEM 4 1/2 3.96 4,885.0 5,137.0 3,443.3 12.60 L-80 IBT B LINER LEM 4 1/2 3.96 5,107.5 5,521.5 3,519.7 12.60 L-80 IBT A-SAND LINER 4 1/2 3.96 5,480.0 12,840.0 3,717.2 12.60 L-80 IBT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 22.4 Set Depth 4,922.0 Set Depth 3,398.0 String Max No 4 1/2 Tubing Description TUBING WO Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 22.4 22.4 0.00 HANGER 10.850 TUBING HANGER T&C Non- Upset 3.958 503.3 503.3 0.57 NIPPLE 5.210 3.875" Camco "DB" Nipple 3.875 2,572.0 2,361.6 36.03 GAS LIFT 5.984 CAMCO KBG-2- 1R 3.938 4,319.5 3,225.8 69.38 GAS LIFT 5.984 CAMCO KBG-2- 1R 3.938 4,831.4 3,377.1 75.81 SLEEVE 5.490 BAKER CMD Sliding Sleeve (verified closed 1/11/21) 3.812 4,842.1 3,379.7 76.04 GAUGE 4.900 Baker Guardian Guage 4.000 4,893.7 3,391.7 77.04 LOCATOR 5.480 Locator / 2' space out 3.910 4,897.4 3,392.6 77.09 SEAL ASSY 4.750 BAKER 190-47 SEAL ASSEMBLY 3.880 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 10.0 10.0 0.00 HEAT TRACE HEAT TRACE 5/17/2008 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,572.0 2,361.6 36.03 1 GAS LIFT GLV BK-5 1 1,427.0 11/15/2020 0.156 4,319.5 3,225.8 69.38 2 GAS LIFT OV BK-5 1 0.0 11/15/2020 0.313 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,885.0 3,389.8 76.92 TIE BACK 6.430 TIE BACK EXTENSION 5.750 4,896.0 3,392.2 77.07 PACKER 6.550 ZXP LINER TOP PACKER 4.980 4,958.7 3,405.8 77.91 NIPPLE 5.000 3.75" DB NIPPLE 3.750 5,107.5 3,436.8 77.43 PACKER 6.550 ZXP LINER TOP PACKER 4.950 5,126.6 3,441.0 77.14 SBR 6.280 109-47 CASING SEAL BORE RECEPTACLE 4.750 5,145.9 3,445.3 76.85 XO BUSHING 6.040 CROSSOVER BUSHING 3.950 5,147.3 3,445.7 76.83 SWIVEL 5.770 BAKER CASING SWIVEL 3.960 5,442.8 3,506.5 80.17 NIPPLE 5.200 CAMCO DB-6 NIPPLE 3.563 5,475.2 3,512.0 80.32 BENT JT 4.500 3.880 5,480.0 3,512.8 80.35 PACKER 7.600 "HRD" ZXP Liner Top Packer 5.5" X 7.6" 4.970 5,499.0 3,516.0 80.44 NIPPLE 5.500 "RS" Packoff Seal Nipple 5.5" 4.875 5,531.4 3,521.3 80.59 LINRE XO THREAD 6.020 XO Bushing 3.92" ID, 6.02 OD 3.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,360.0 8,698.0 3,649.9 3,655.8 WS A2, A3, 1J- 166 1/19/2006 32.0 SLOTS ALL PERFS THIS WELLBORE - Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,945.0 10,031.0 3,661.1 3,711.7 WS A2, 1J-166 1/19/2006 32.0 SLOTS 10,648.0 10,710.0 3,678.3 3,668.4 WS A2, 1J-166 1/19/2006 32.0 SLOTS 10,990.0 12,808.0 3,651.8 3,715.9 WS A2, 1J-166 1/19/2006 32.0 SLOTS 1J-166, 11/13/2023 4:54:36 PM Vertical schematic (actual) A-SAND LINER; 5,480.0- 12,840.0 SHOE; 12,838.7-12,840.0 SLOTS; 10,990.0-12,808.0 SLOTS; 10,648.0-10,710.0 SLOTS; 8,945.0-10,031.0 SLOTS; 6,360.0-8,698.0 INTERMEDIATE; 26.4-6,350.0 FLOAT SHOE; 6,348.5-6,350.0 FLOAT COLLAR; 6,264.4- 6,265.6 SBE; 5,511.7-5,531.4 B LINER LEM; 5,107.5-5,521.5 SEAL ASSY; 5,518.2-5,521.5 Liner Hanger; 5,501.9-5,511.7 NIPPLE; 5,499.0-5,501.9 PACKER; 5,480.0-5,499.0 NIPPLE; 5,442.8-5,444.3 B-SAND LINER; 5,377.3- 12,909.3 HANGER; 5,377.3-5,401.6 HANGER; 5,377.3-5,394.1 HANGER; 5,366.6-5,377.3 SWIVEL; 5,147.3-5,151.1 XO BUSHING; 5,145.9-5,147.3 D LINER LEM; 4,885.0-5,137.0 SBR; 5,126.6-5,145.9 SEAL ASSY; 5,133.7-5,137.0 PACKER; 5,107.5-5,126.6 D-SAND LINER; 5,002.1- 12,952.7 HANGER; 5,001.5-5,025.9 HANGER; 5,002.1-5,019.0 HANGER; 4,994.7-5,001.5 NIPPLE; 4,958.7-4,960.3 SBE; 4,904.0-4,923.7 SEAL ASSY; 4,897.4 PACKER; 4,896.0-4,904.0 LOCATOR; 4,893.7 TIE BACK; 4,885.0-4,896.0 GAUGE; 4,842.1 SLEEVE; 4,831.4 GAS LIFT; 4,319.5 GAS LIFT; 2,572.0 SURFACE; 30.1-2,368.4 FLOAT SHOE; 2,366.6-2,368.4 FLOAT COLLAR; 2,282.7- 2,284.2 HEAT TRACE; 10.0 NIPPLE; 503.3 CONDUCTOR Insulated; 30.0- 108.0 HANGER; 30.1-33.6 HANGER; 22.4 KUP PROD KB-Grd (ft) 31.01 RR Date 2/11/2006 Other Elev 1J-166 ... TD Act Btm (ftKB) 12,853.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329100 Wellbore Status PROD Max Angle & MD Incl (°) 99.97 MD (ftKB) 10,663.58 WELLNAME WELLBORE1J-166 Annotation Last WO: End Date 4/17/2008 H2S (ppm) DateComment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1J-166L1 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: WELL REVIEW 1J-166L1 5/13/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread B-SAND LINER 4 1/2 3.96 5,377.3 12,909.3 3,590.5 12.60 L-80 IBT Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 10,235.0 3,579.0 88.97 PLUG B-SAND IBP set 6/3/2008 6/3/2008 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,402.2 3,499.3 81.08 SWIVEL 5.750 Baker Casing Swivel 3.960 12,877.8 3,589.1 87.11 XO Reducing 4.500 4-1/2" X 3-1/2" XO sub 2.992 12,879.2 3,589.1 87.14 BENT JT 3.500 3-1/2" Bent Joint IBT, 9.2 ppf, L- 80 2.900 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,409.0 8,178.0 3,500.3 3,512.6 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,426.0 10,101.0 3,519.4 3,576.8 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 10,905.0 12,417.0 3,522.5 3,563.9 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 12,571.0 12,878.0 3,570.1 3,589.1 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 1J-166L1, 11/13/2023 4:54:37 PM Vertical schematic (actual) B-SAND LINER; 5,377.3- 12,909.3 LINER SHOE; 12,907.9- 12,909.3 BENT JT; 12,879.2-12,907.9 SLOTS; 12,571.0-12,878.0 SLOTS; 10,905.0-12,417.0 PLUG; 10,235.0 SLOTS; 8,426.0-10,101.0 SLOTS; 5,409.0-8,178.0 SWIVEL; 5,402.2-5,405.0 Liner Hanger; 5,394.1-5,400.2 INTERMEDIATE; 26.4-6,350.0 B LINER LEM; 5,107.5-5,521.5 HANGER; 5,377.3-5,394.1 HANGER; 5,377.3-5,401.6 HANGER; 5,366.6-5,377.3 SWIVEL; 5,147.3-5,151.1 XO BUSHING; 5,145.9-5,147.3 D LINER LEM; 4,885.0-5,137.0 SBR; 5,126.6-5,145.9 SEAL ASSY; 5,133.7-5,137.0 PACKER; 5,107.5-5,126.6 D-SAND LINER; 5,002.1- 12,952.7 HANGER; 5,001.5-5,025.9 HANGER; 5,002.1-5,019.0 HANGER; 4,994.7-5,001.5 NIPPLE; 4,958.7-4,960.3 SBE; 4,904.0-4,923.7 SEAL ASSY; 4,897.4 PACKER; 4,896.0-4,904.0 LOCATOR; 4,893.7 TIE BACK; 4,885.0-4,896.0 GAUGE; 4,842.1 SLEEVE; 4,831.4 GAS LIFT; 4,319.5 GAS LIFT; 2,572.0 SURFACE; 30.1-2,368.4 FLOAT SHOE; 2,366.6-2,368.4 FLOAT COLLAR; 2,282.7- 2,284.2 HEAT TRACE; 10.0 NIPPLE; 503.3 CONDUCTOR Insulated; 30.0- 108.0 HANGER; 30.1-33.6 HANGER; 22.4 KUP PROD KB-Grd (ft) 31.01 RR Date 2/11/2006 Other Elev 1J-166L1 ... TD Act Btm (ftKB) 12,952.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329160 Wellbore Status PROD Max Angle & MD Incl (°) 99.97 MD (ftKB) 10,422.57 WELLNAME WELLBORE1J-166 Annotation Last WO: End Date 4/17/2008 H2S (ppm) DateComment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1J-166L2 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Type 1 Isolation Sleeve 1J-166L2 11/9/2019 mcanej Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread D-SAND LINER 4 1/2 3.96 5,002.1 12,952.7 3,528.4 12.60 L-80 IBT Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,027.0 3,419.7 79.25 SWIVEL 4.750 Baker Casing Swivel 3.960 12,920.8 3,526.8 87.23 XO Reducing 4.500 4-1/2" X 3-1/2" XO sub 2.992 12,922.2 3,526.9 87.22 BENT JT 3.500 3-1/2" Bent Joint IBT, 9.2 ppf, L- 80 2.900 12,951.2 3,528.4 87.03 WLEG 3.500 Baker 3-1/2" Guide Shoe ( No float) 2.900 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,067.0 7,805.0 3,426.4 3,464.7 WS D, 1J-166L2 2/7/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,021.0 8,325.0 3,463.9 3,471.5 WS D, 1J-166L2 2/7/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,571.0 9,806.0 3,472.2 3,492.6 WS D, 1J-166L2 2/7/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 10,517.0 12,921.0 3,453.1 3,526.9 WS D, 1J-166L2 2/7/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 1J-166L2, 11/13/2023 4:54:38 PM Vertical schematic (actual) D-SAND LINER; 5,002.1- 12,952.7 WLEG; 12,951.2-12,952.7 BENT JT; 12,922.2-12,951.2 SLOTS; 10,517.0-12,921.0 SLOTS; 8,571.0-9,806.0 SLOTS; 8,021.0-8,325.0 SLOTS; 5,067.0-7,805.0 SWIVEL; 5,027.0-5,029.8 HANGER; 5,019.0-5,025.0 INTERMEDIATE; 26.4-6,350.0 D LINER LEM; 4,885.0-5,137.0 HANGER; 5,002.1-5,019.0 HANGER; 5,001.5-5,025.9 HANGER; 4,994.7-5,001.5 NIPPLE; 4,958.7-4,960.3 SBE; 4,904.0-4,923.7 SEAL ASSY; 4,897.4 PACKER; 4,896.0-4,904.0 LOCATOR; 4,893.7 TIE BACK; 4,885.0-4,896.0 GAUGE; 4,842.1 SLEEVE; 4,831.4 GAS LIFT; 4,319.5 GAS LIFT; 2,572.0 SURFACE; 30.1-2,368.4 FLOAT SHOE; 2,366.6-2,368.4 FLOAT COLLAR; 2,282.7- 2,284.2 HEAT TRACE; 10.0 NIPPLE; 503.3 CONDUCTOR Insulated; 30.0- 108.0 HANGER; 30.1-33.6 HANGER; 22.4 KUP PROD KB-Grd (ft) 31.01 RR Date 2/11/2006 Other Elev 1J-166L2 ... TD Act Btm (ftKB) 12,994.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329161 Wellbore Status PROD Max Angle & MD Incl (°) 95.60 MD (ftKB) 10,233.79 WELLNAME WELLBORE1J-166 Annotation Last WO: End Date 4/17/2008 H2S (ppm) DateComment SSSV: NIPPLE ! " # " $%&' ( ') * +,! - *( ./ !0 1"!! 2/ ./ 34354-04 6. 0 " * ( ' ( % 7 . 899 0 : 7. *9 0 3 ;8 * , . 0 < ; 5" : ( * " ') * ( / * +" : $ "(/ ' ( $ $,!= > />$ *!!6 ') ! 8 ", ' ' ? .24-03+5#+4<1 8! " 8 ",!="$ " ( * ,@ ( A" &": !"# " #& "$%&'() * +,-* "$%&'() * +,-* !!!' . !"# . #& :9, $&/0 : 123 '/B /B,/!($!' 7,!%%,,! &% &#!/&4.% %&5! 5 ( !3 ! ! &)44<+4 9B2254 $ #% =: !6 72* +2 17 22897+ - 72* +2 17 22897+ - -,* * *: &#/ A .; 34354-49354-9C3531<0 < $:+*:-&;*#78.2!+-7 7 , "+ 1 :*2 ' ' " 77+ 4#A4A <63434 " <4* By Samantha Carlisle at 2:41 pm, Aug 04, 2021 Stefan Weingarth Digitally signed by Stefan Weingarth Date: 2021.08.04 13:35:57 -08'00' RBDMS HEW 8/5/2021 VTL 8/9/21 DSR-8/4/21 !"#$%&'($ !"#$%& )&*'*+ *&%,% & ,&!% - . / /0//'1 2//0/0/ 11 230 //-2 - . / /0///0/0// 4 . -1 . / / /0//415136 / //0// ///0/41271289 /'. /15-.39::/ 632/.. /615-. //0/41.0//41512./ //0//412.::/ 3 0////11 1.3 6 '3. / - . / 7''72./ / //0/';/./ /0// ; /./ ///0/;/.9 /'//015-212 ; /.6/'//:///63 2' //.6/3//./ ' / //. -< . / /' //// / =12 .'/312/'/030/ / 15-;12 >//6- ?./1.1; //1; @/;'37 '6/ 1; @ 55 .= >? /:'' //./ /63.1; @; //'>- .1; //?./8/ <1; ///// 0///'.< .6//3' <;3 /'/ /73//; / '/ ; '//://6/63 // /'. ./A//6// 3;'<;3.B//// 3/ ; (*,#%*(%$% (*C&)*(%#&$" Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag:1J-166 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pull CAT SV, confirm CMD closed 1/11/2021 1J-166 rogerba Casing Strings Casing Description CONDUCTOR Insulated OD (in) 16 ID (in) 15.25 Top (ftKB) 30.0 Set Depth (ftKB) 108.0 Set Depth (TVD)… 108.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 30.1 Set Depth (ftKB) 2,368.4 Set Depth (TVD)… 2,194.2 Wt/Len (l… 45.50 Grade L-80 Top Thread BTC Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 26.4 Set Depth (ftKB) 6,350.0 Set Depth (TVD)… 3,648.8 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Casing Description D LINER LEM OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 4,885.0 Set Depth (ftKB) 5,137.0 Set Depth (TVD)… 3,443.3 Wt/Len (l… 12.60 Grade L-80 Top Thread IBT Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 4,885.0 3,389.8 76.92 TIE BACK TIE BACK EXTENSION 5.750 4,896.0 3,392.2 77.07 PACKER ZXP LINER TOP PACKER 4.980 4,904.0 3,394.0 77.18 SBE SEAL BORE EXTENSION 190-47 4.760 4,958.7 3,405.8 77.91 NIPPLE 3.75" DB NIPPLE 3.750 4,994.7 3,413.3 78.13 HANGER LEM ABOVE HOOK HANGER 3.910 5,001.5 3,414.7 78.12 HANGER LEM INSIDE HOOK HANGER 3.930 5,133.7 3,442.6 77.04 SEAL ASSYNON-LOCATING SEAL ASSEMBLY 3.890 Casing Description B LINER LEM OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 5,107.5 Set Depth (ftKB) 5,521.5 Set Depth (TVD)… 3,519.7 Wt/Len (l… 12.60 Grade L-80 Top Thread IBT Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 5,107.5 3,436.8 77.43 PACKER ZXP LINER TOP PACKER 4.950 5,126.63,441.0 77.14 SBR 109-47 CASING SEAL BORE RECEPTACLE 4.750 5,145.9 3,445.3 76.85 XO BUSHING CROSSOVER BUSHING 3.950 5,147.33,445.7 76.83 SWIVEL BAKER CASING SWIVEL 3.960 5,366.6 3,493.2 79.61 HANGER LEM ABOVE HOOK HANGER 3.950 5,377.3 3,495.1 79.69 HANGER LEM INSIDE HOOK HANGER 3.688 5,442.8 3,506.5 80.17 NIPPLE CAMCO DB-6 NIPPLE 3.563 5,475.2 3,512.0 80.32 BENT JT 3.880 5,518.23,519.280.53SEAL ASSY BAKER SEAL ASSEMBLY 3.880 Casing Description A-SAND LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 5,480.0 Set Depth (ftKB) 12,840.0 Set Depth (TVD)… 3,717.2 Wt/Len (l… 12.60 Grade L-80 Top Thread IBT Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 5,480.0 3,512.8 80.35 PACKER "HRD" ZXP Liner Top Packer 5.5" X 7.6" 4.970 5,499.03,516.080.44 NIPPLE "RS" Packoff Seal Nipple 5.5" 4.875 5,511.7 3,518.1 80.49 SBE 190-47 Casing Seal Bore Ext. 4.75"ID x 6.25" OD 4.750 Tubing Strings Tubing Description TUBING WO String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 22.4 Set Depth (ft… 4,922.0 Set Depth (TVD) (… 3,398.0 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 22.4 22.4 0.00 HANGER TUBING HANGER 3.958 503.3 503.30.57 NIPPLE 3.875" Camco "DB" Nipple 3.875 4,831.4 3,377.1 75.81 SLEEVE BAKER CMD Sliding Sleeve 3.812 4,842.1 3,379.7 76.04 GAUGE Baker Guardian Guage 4.000 4,893.7 3,391.7 77.04 LOCATOR Locator / 2' space out 3.910 4,897.4 3,392.6 77.09 SEAL ASSY BAKER 190-47 SEAL ASSEMBLY 3.880 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 10.0 10.00.00 HEAT TRACE HEAT TRACE 5/17/2008 0.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 6,360.0 8,698.0 3,649.9 3,655.8 WS A2, A3, 1J- 166 1/19/2006 32.0SLOTS ALL PERFS THIS WELLBORE - Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,945.010,031.03,661.13,711.7 WS A2, 1J-166 1/19/2006 32.0SLOTS 10,648.0 10,710.0 3,678.3 3,668.4 WS A2, 1J-166 1/19/2006 32.0 SLOTS 10,990.012,808.03,651.83,715.9 WS A2, 1J-166 1/19/2006 32.0SLOTS Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 2,572.02,361.636.03 CAMCO KBG-2- 1R 1 GAS LIFT GLV BK-5 0.1561,427.011/15/2020 2 4,319.5 3,225.869.38 CAMCO KBG-2- 1R 1 GAS LIFT OVBK-50.313 0.011/15/2020 1J-166, 8/4/2021 11:21:39 AM Vertical schematic (actual) A-SAND LINER; 5,480.0- 12,840.0 SLOTS; 10,990.0-12,808.0 SLOTS; 10,648.0-10,710.0 SLOTS; 8,945.0-10,031.0 SLOTS; 6,360.0-8,698.0 INTERMEDIATE; 26.4-6,350.0 B LINER LEM; 5,107.5-5,521.5 B-SAND LINER; 5,377.3- 12,909.3 ISOLATION SLLEEVE; 5,380.0 D LINER LEM; 4,885.0-5,137.0 D-SAND LINER; 5,002.1- 12,952.7 GAS LIFT; 4,319.5 GAS LIFT; 2,572.0 SURFACE; 30.1-2,368.4 HEAT TRACE; 10.0 NIPPLE; 503.3 CONDUCTOR Insulated; 30.0- 108.0 KUP PROD KB-Grd (ft) 31.01 Rig Release Date 2/11/2006 1J-166 ... TD Act Btm (ftKB) 12,853.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329100 Wellbore Status PROD Max Angle & MD Incl (°) 99.97 MD (ftKB) 10,663.58 WELLNAME WELLBORE Annotation Last WO: End Date 4/17/2008 H2S (ppm)DateComment SSSV: NIPPLE Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag:1J-166L1 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: WELL REVIEW 5/13/2013 1J-166L1 osborl Casing Strings Casing Description B-SAND LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 5,377.3 Set Depth (ftKB) 12,909.3 Set Depth (TVD)… 3,590.5 Wt/Len (l… 12.60 Grade L-80 Top Thread IBT Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 5,377.3 3,495.1 79.68 HANGER 7-5/8"x 4-1/2" Baker Mod B1 FHH ( Inside Casing 16.86' ) 5.630 5,402.2 3,499.3 81.08 SWIVEL Baker Casing Swivel 3.960 12,877.8 3,589.1 87.11 XO Reducing 4-1/2" X 3-1/2" XO sub 2.992 12,879.2 3,589.1 87.14 BENT JT 3-1/2" Bent Joint IBT, 9.2 ppf, L-80 2.900 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 5,380.0 3,495.6 79.70 ISOLATION SLLEEVE TYPE 1 ISOLATION SLEEVE 11/9/2019 2.500 10,235. 0 3,579.0 88.97 PLUG B-SAND IBP set 6/3/2008 6/3/2008 0.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 5,409.0 8,178.0 3,500.3 3,512.6 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,426.0 10,101.0 3,519.4 3,576.8 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 10,905.0 12,417.0 3,522.5 3,563.9 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 12,571.0 12,878.0 3,570.1 3,589.1 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 1J-166L1, 8/4/2021 11:21:43 AM Vertical schematic (actual) B-SAND LINER; 5,377.3- 12,909.3 SLOTS; 12,571.0-12,878.0 SLOTS; 10,905.0-12,417.0 PLUG; 10,235.0 SLOTS; 8,426.0-10,101.0 SLOTS; 5,409.0-8,178.0 B LINER LEM; 5,107.5-5,521.5 INTERMEDIATE; 26.4-6,350.0 ISOLATION SLLEEVE; 5,380.0 D LINER LEM; 4,885.0-5,137.0 D-SAND LINER; 5,002.1- 12,952.7 GAS LIFT; 4,319.5 GAS LIFT; 2,572.0 SURFACE; 30.1-2,368.4 HEAT TRACE; 10.0 NIPPLE; 503.3 CONDUCTOR Insulated; 30.0- 108.0 KUP PROD KB-Grd (ft) 31.01 Rig Release Date 2/11/2006 1J-166L1 ... TD Act Btm (ftKB) 12,952.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329160 Wellbore Status PROD Max Angle & MD Incl (°) 99.97 MD (ftKB) 10,422.57 WELLNAME WELLBORE Annotation Last WO: End Date 4/17/2008 H2S (ppm)DateComment 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 feet feet true vertical feet feet Effective Depth measured feet feet true vertical feet feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 4922' 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: 2368' 2194' Burst Collapse Production 6324' Casing 3649' 4-1/2" 6350' 2338' 108'Conductor Surface Intermediate 16" 10-3/4" 78' measured TVD 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 205-199 50029-23291-60-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025650, ADL0025661 Kuparuk River Field/ West Sak Oil Pool KRU 1J-166L1 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 900 Gas-Mcf MD 950 Size 108' 1800 910650 800 2851600 265 N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 550 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 Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 12952' 3593' 12952' 3593' 10235' None 4896', 5108' 3392', 3437' B Sand Liner 12909'3591'7532' 5409-8178', 8426-10101', 10905-12417', 12571-12878' 3500-3513', 3519-3577', 3523-3564', 3570-3589' Packer: ZXP Liner Top Packer Packer: ZXP Liner Top Packer SSSV: N/A 4896' MD 5108' MD N/A 3398' TVD 3392' TVD 3437' TVD N/A By Grace Christianson at 1:28 pm, Aug 07, 2023 Digitally signed by Allen Eschete DN: CN=Allen Eschete, E=Allen.Eschete@ ConocoPhillips.com Reason: I have reviewed this document Location: Date: 2023.08.07 08:12:49-08'00' Foxit PDF Editor Version: 12.1.2 Allen Eschete DTTMSTART JOBTYP SUMMARYOPS 7/11/2023 ACQUIRE DATA RPPG TREATMENT COMPLETED PUMPED 7216 LB RPPG, 430 BBL 2%KCL, 40.9 BBL DIESEL MAX SURFACE PSI 1488, MAX RATE 3.5 BPM. SLB E-LINE: OBJECTIVE TO MONITOR TEMPERATURE & PRESSURE IN WELL 20' TO 50' ABOVE B-SAND LEM AT 6812' WHILE RPPG IS PUMPED INTO LATERAL. IF UNABLE TO REACH TARGET DEPTH, PARK AS FAR DOWN. TARGET DEPTH REACHED OF 50 FT ABOVE LATERAL B. 1J-170/ 1J-166 RPPG MBE Treatment Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1J-166 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled Gauges 1J-166 12/10/2022 zembaej Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR Insulated 16 15.25 30.0 108.0 108.0 62.50 H-40 WELDED SURFACE 10 3/4 9.95 30.1 2,368.4 2,194.2 45.50 L-80 BTC INTERMEDIATE 7 5/8 6.87 26.4 6,350.0 3,648.8 29.70 L-80 BTCM D LINER LEM 4 1/2 3.96 4,885.0 5,137.0 3,443.3 12.60 L-80 IBT B LINER LEM 4 1/2 3.96 5,107.5 5,521.5 3,519.7 12.60 L-80 IBT A-SAND LINER 4 1/2 3.96 5,480.0 12,840.0 3,717.2 12.60 L-80 IBT Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 22.4 Set Depth 4,922.0 Set Depth 3,398.0 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) 22.4 22.4 0.00 HANGER 10.850 TUBING HANGER T&C Non- Upset 3.958 503.3 503.3 0.57 NIPPLE 5.210 3.875" Camco "DB" Nipple 3.875 2,572.0 2,361.6 36.03 GAS LIFT 5.984 CAMCO KBG-2- 1R 3.938 4,319.5 3,225.8 69.38 GAS LIFT 5.984 CAMCO KBG-2- 1R 3.938 4,831.4 3,377.1 75.81 SLEEVE 5.490 BAKER CMD Sliding Sleeve (verified closed 1/11/21) 3.812 4,842.1 3,379.7 76.04 GAUGE 4.900 Baker Guardian Guage 4.000 4,893.7 3,391.7 77.04 LOCATOR 5.480 Locator / 2' space out 3.910 4,897.4 3,392.6 77.09 SEAL ASSY 4.750 BAKER 190-47 SEAL ASSEMBLY 3.880 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 10.0 10.0 0.00 HEAT TRACE HEAT TRACE 5/17/2008 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,572.0 2,361.6 36.03 1 GAS LIFT GLV BK-5 1 1,427.0 11/15/2020 0.156 4,319.5 3,225.8 69.38 2 GAS LIFT OV BK-5 1 0.0 11/15/2020 0.313 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,885.0 3,389.8 76.92 TIE BACK 6.430 TIE BACK EXTENSION 5.750 4,896.0 3,392.2 77.07 PACKER 6.550 ZXP LINER TOP PACKER 4.980 4,958.7 3,405.8 77.91 NIPPLE 5.000 3.75" DB NIPPLE 3.750 5,107.5 3,436.8 77.43 PACKER 6.550 ZXP LINER TOP PACKER 4.950 5,126.6 3,441.0 77.14 SBR 6.280 109-47 CASING SEAL BORE RECEPTACLE 4.750 5,145.9 3,445.3 76.85 XO BUSHING 6.040 CROSSOVER BUSHING 3.950 5,147.3 3,445.7 76.83 SWIVEL 5.770 BAKER CASING SWIVEL 3.960 5,442.8 3,506.5 80.17 NIPPLE 5.200 CAMCO DB-6 NIPPLE 3.563 5,475.2 3,512.0 80.32 BENT JT 4.500 3.880 5,480.0 3,512.8 80.35 PACKER 7.600 "HRD" ZXP Liner Top Packer 5.5" X 7.6" 4.970 5,499.0 3,516.0 80.44 NIPPLE 5.500 "RS" Packoff Seal Nipple 5.5" 4.875 5,531.4 3,521.3 80.59 LINRE XO THREAD 6.020 XO Bushing 3.92" ID, 6.02 OD 3.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,360.0 8,698.0 3,649.9 3,655.8 WS A2, A3, 1J- 166 1/19/2006 32.0 SLOTS ALL PERFS THIS WELLBORE - Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,945.0 10,031.0 3,661.1 3,711.7 WS A2, 1J-166 1/19/2006 32.0 SLOTS 10,648.0 10,710.0 3,678.3 3,668.4 WS A2, 1J-166 1/19/2006 32.0 SLOTS 10,990.0 12,808.0 3,651.8 3,715.9 WS A2, 1J-166 1/19/2006 32.0 SLOTS 1J-166, 7/26/2023 12:11:52 PM Vertical schematic (actual) A-SAND LINER; 5,480.0- 12,840.0 SLOTS; 10,990.0-12,808.0 SLOTS; 10,648.0-10,710.0 SLOTS; 8,945.0-10,031.0 SLOTS; 6,360.0-8,698.0 INTERMEDIATE; 26.4-6,350.0 B LINER LEM; 5,107.5-5,521.5 B-SAND LINER; 5,377.3- 12,909.3 D LINER LEM; 4,885.0-5,137.0 D-SAND LINER; 5,002.1- 12,952.7 GAS LIFT; 4,319.5 GAS LIFT; 2,572.0 SURFACE; 30.1-2,368.4 HEAT TRACE; 10.0 NIPPLE; 503.3 CONDUCTOR Insulated; 30.0- 108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 2/11/2006 Other Elev 1J-166 ... TD Act Btm (ftKB) 12,853.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329100 Wellbore Status PROD Max Angle & MD Incl (°) 99.97 MD (ftKB) 10,663.58 WELLNAME WELLBORE1J-166 Annotation Last WO: End Date 4/17/2008 H2S (ppm) DateComment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1J-166L1 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: WELL REVIEW 1J-166L1 5/13/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread B-SAND LINER 4 1/2 3.96 5,377.3 12,909.3 3,590.5 12.60 L-80 IBT Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 10,235.0 3,579.0 88.97 PLUG B-SAND IBP set 6/3/2008 6/3/2008 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,402.2 3,499.3 81.08 SWIVEL 5.750 Baker Casing Swivel 3.960 12,877.8 3,589.1 87.11 XO Reducing 4.500 4-1/2" X 3-1/2" XO sub 2.992 12,879.2 3,589.1 87.14 BENT JT 3.500 3-1/2" Bent Joint IBT, 9.2 ppf, L- 80 2.900 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,409.0 8,178.0 3,500.3 3,512.6 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,426.0 10,101.0 3,519.4 3,576.8 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 10,905.0 12,417.0 3,522.5 3,563.9 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 12,571.0 12,878.0 3,570.1 3,589.1 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 1J-166L1, 7/26/2023 12:11:53 PM Vertical schematic (actual) B-SAND LINER; 5,377.3- 12,909.3 SLOTS; 12,571.0-12,878.0 SLOTS; 10,905.0-12,417.0 PLUG; 10,235.0 SLOTS; 8,426.0-10,101.0 SLOTS; 5,409.0-8,178.0 B LINER LEM; 5,107.5-5,521.5 INTERMEDIATE; 26.4-6,350.0 D LINER LEM; 4,885.0-5,137.0 D-SAND LINER; 5,002.1- 12,952.7 GAS LIFT; 4,319.5 GAS LIFT; 2,572.0 SURFACE; 30.1-2,368.4 HEAT TRACE; 10.0 NIPPLE; 503.3 CONDUCTOR Insulated; 30.0- 108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 2/11/2006 Other Elev 1J-166L1 ... TD Act Btm (ftKB) 12,952.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329160 Wellbore Status PROD Max Angle & MD Incl (°) 99.97 MD (ftKB) 10,422.57 WELLNAME WELLBORE1J-166 Annotation Last WO: End Date 4/17/2008 H2S (ppm) DateComment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1J-166L2 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Type 1 Isolation Sleeve 1J-166L2 11/9/2019 mcanej Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread D-SAND LINER 4 1/2 3.96 5,002.1 12,952.7 3,528.4 12.60 L-80 IBT Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,027.0 3,419.7 79.25 SWIVEL 4.750 Baker Casing Swivel 3.960 12,920.8 3,526.8 87.23 XO Reducing 4.500 4-1/2" X 3-1/2" XO sub 2.992 12,922.2 3,526.9 87.22 BENT JT 3.500 3-1/2" Bent Joint IBT, 9.2 ppf, L- 80 2.900 12,951.2 3,528.4 87.03 WLEG 3.500 Baker 3-1/2" Guide Shoe ( No float) 2.900 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,067.0 7,805.0 3,426.4 3,464.7 WS D, 1J-166L2 2/7/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,021.0 8,325.0 3,463.9 3,471.5 WS D, 1J-166L2 2/7/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,571.0 9,806.0 3,472.2 3,492.6 WS D, 1J-166L2 2/7/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 10,517.0 12,921.0 3,453.1 3,526.9 WS D, 1J-166L2 2/7/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 1J-166L2, 7/26/2023 12:11:54 PM Vertical schematic (actual) D-SAND LINER; 5,002.1- 12,952.7 SLOTS; 10,517.0-12,921.0 SLOTS; 8,571.0-9,806.0 SLOTS; 8,021.0-8,325.0 SLOTS; 5,067.0-7,805.0 INTERMEDIATE; 26.4-6,350.0 D LINER LEM; 4,885.0-5,137.0 GAS LIFT; 4,319.5 GAS LIFT; 2,572.0 SURFACE; 30.1-2,368.4 HEAT TRACE; 10.0 NIPPLE; 503.3 CONDUCTOR Insulated; 30.0- 108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 2/11/2006 Other Elev 1J-166L2 ... TD Act Btm (ftKB) 12,994.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329161 Wellbore Status PROD Max Angle & MD Incl (°) 95.60 MD (ftKB) 10,233.79 WELLNAME WELLBORE1J-166 Annotation Last WO: End Date 4/17/2008 H2S (ppm) DateComment SSSV: NIPPLE ! " # " $%&' ( ') * +,! - *( ./ !0 1"!! 2/ ./ 34354-04 6. 0 " * ( ' ( % 7 . 899 0 : 7. *9 0 3 ;8 * , . 0 < ; 5" : ( * " ') * ( / * +" : $ "(/ ' ( $ $,!= > />$ *!!6 ') ! 8 ", ' ' ' ' !"# , $ % < &!"!'($)"*$+,#-'.$/ -,* * *: &#/ ? .; 34354-49354-9@3531<0 $ #% =: -$0 '/A /A,/!($!' 7,!%%,,! (1/.(.*-2(3,1./1(4.- 5 ( !3 ! ! &)44<+4 9A2254 #& :9, &(25 : %#6 ?" &": " #& /&1(789/$ " /:'" /&1(789/$ " /:'" ---7 #" #$ % ##+; '$ #" #$ % ##+; '$ " ,"<$ -6!#$ ( * ,B ( C .24-03+5#+4<1 8! " 8 ",!="$ 4#?4? <63434 " <4* By Samantha Carlisle at 9:19 am, May 26, 2021 Stefan Weingarth Digitally signed by Stefan Weingarth Date: 2021.05.25 14:49:20 -08'00' SFD 5/26/2021DSR-5/26/21 RBDMS HEW 6/10/2021 -00 sfd 5/26/2021 VTL 8/9/21 ! " # $ $##### # # %& %& ###$$## ! ' # $"$ ###$$## # %& ####$$## ( $""!)*+,-*., /--+)0123*)+,41.5 Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag:1J-166 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pull CAT SV, confirm CMD closed 1/11/2021 1J-166 rogerba Casing Strings Casing Description CONDUCTOR Insulated OD (in) 16 ID (in) 15.25 Top (ftKB) 30.0 Set Depth (ftKB) 108.0 Set Depth (TVD)… 108.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 30.1 Set Depth (ftKB) 2,368.4 Set Depth (TVD)… 2,194.2 Wt/Len (l… 45.50 Grade L-80 Top Thread BTC Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 26.4 Set Depth (ftKB) 6,350.0 Set Depth (TVD)… 3,648.8 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Casing Description D LINER LEM OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 4,885.0 Set Depth (ftKB) 5,137.0 Set Depth (TVD)… 3,443.3 Wt/Len (l… 12.60 Grade L-80 Top Thread IBT Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 4,885.03,389.8 76.92 TIE BACK TIE BACK EXTENSION5.750 4,896.03,392.2 77.07PACKER ZXP LINER TOP PACKER 4.980 4,904.0 3,394.0 77.18 SBE SEAL BORE EXTENSION 190-47 4.760 4,958.7 3,405.8 77.91 NIPPLE 3.75" DB NIPPLE 3.750 4,994.7 3,413.3 78.13 HANGER LEM ABOVE HOOK HANGER 3.910 5,001.5 3,414.7 78.12 HANGER LEM INSIDE HOOK HANGER 3.930 5,133.7 3,442.6 77.04 SEAL ASSY NON-LOCATING SEAL ASSEMBLY 3.890 Casing Description B LINER LEM OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 5,107.5 Set Depth (ftKB) 5,521.5 Set Depth (TVD)… 3,519.7 Wt/Len (l… 12.60 Grade L-80 Top Thread IBT Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 5,107.5 3,436.8 77.43 PACKER ZXP LINER TOP PACKER 4.950 5,126.63,441.0 77.14 SBR 109-47 CASING SEAL BORE RECEPTACLE 4.750 5,145.93,445.3 76.85XO BUSHINGCROSSOVER BUSHING3.950 5,147.3 3,445.7 76.83 SWIVEL BAKER CASING SWIVEL 3.960 5,366.6 3,493.2 79.61 HANGER LEM ABOVE HOOK HANGER 3.950 5,377.3 3,495.1 79.69 HANGER LEM INSIDE HOOK HANGER 3.688 5,442.8 3,506.5 80.17 NIPPLE CAMCO DB-6 NIPPLE 3.563 5,475.23,512.080.32 BENT JT 3.880 5,518.23,519.280.53SEAL ASSY BAKER SEAL ASSEMBLY 3.880 Casing Description A-SAND LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 5,480.0 Set Depth (ftKB) 12,840.0 Set Depth (TVD)… 3,717.2 Wt/Len (l… 12.60 Grade L-80 Top Thread IBT Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 5,480.03,512.880.35PACKER "HRD" ZXP Liner Top Packer 5.5" X 7.6"4.970 5,499.03,516.080.44 NIPPLE "RS" Packoff Seal Nipple 5.5" 4.875 5,511.7 3,518.1 80.49 SBE 190-47 Casing Seal Bore Ext. 4.75"ID x 6.25" OD 4.750 Tubing Strings Tubing Description TUBING WO String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 22.4 Set Depth (ft… 4,922.0 Set Depth (TVD) (… 3,398.0 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 22.4 22.4 0.00 HANGER TUBING HANGER 3.958 503.3 503.30.57 NIPPLE 3.875" Camco "DB" Nipple 3.875 4,831.4 3,377.1 75.81 SLEEVE BAKER CMD Sliding Sleeve 3.812 4,842.13,379.7 76.04 GAUGEBaker Guardian Guage 4.000 4,893.7 3,391.7 77.04 LOCATOR Locator / 2' space out 3.910 4,897.4 3,392.6 77.09 SEAL ASSY BAKER 190-47 SEAL ASSEMBLY 3.880 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 10.010.00.00 HEAT TRACE HEAT TRACE5/17/2008 0.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 6,360.0 8,698.0 3,649.9 3,655.8 WS A2, A3, 1J- 166 1/19/2006 32.0SLOTS ALL PERFS THIS WELLBORE - Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,945.0 10,031.0 3,661.1 3,711.7 WS A2, 1J-166 1/19/2006 32.0 SLOTS 10,648.0 10,710.0 3,678.3 3,668.4 WS A2, 1J-166 1/19/2006 32.0 SLOTS 10,990.012,808.03,651.83,715.9 WS A2, 1J-166 1/19/2006 32.0SLOTS Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 2,572.0 2,361.6 36.03 CAMCO KBG-2- 1R 1 GAS LIFT GLV BK-5 0.156 1,427.0 11/15/2020 2 4,319.5 3,225.8 69.38 CAMCO KBG-2- 1R 1 GAS LIFT OVBK-50.3130.0 11/15/2020 1J-166, 5/20/2021 3:50:02 PM Vertical schematic (actual) A-SAND LINER; 5,480.0- 12,840.0 SLOTS; 10,990.0-12,808.0 SLOTS; 10,648.0-10,710.0 SLOTS; 8,945.0-10,031.0 SLOTS; 6,360.0-8,698.0 INTERMEDIATE; 26.4-6,350.0 B LINER LEM; 5,107.5-5,521.5 B-SAND LINER; 5,377.3- 12,909.3 ISOLATION SLLEEVE; 5,380.0 D LINER LEM; 4,885.0-5,137.0 D-SAND LINER; 5,002.1- 12,952.7 GAS LIFT; 4,319.5 GAS LIFT; 2,572.0 SURFACE; 30.1-2,368.4 HEAT TRACE; 10.0 NIPPLE; 503.3 CONDUCTOR Insulated; 30.0- 108.0 KUP PROD KB-Grd (ft) 31.01 Rig Release Date 2/11/2006 1J-166 ... TD Act Btm (ftKB) 12,853.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329100 Wellbore Status PROD Max Angle & MD Incl (°) 99.97 MD (ftKB) 10,663.58 WELLNAME WELLBORE Annotation Last WO: End Date 4/17/2008 H2S (ppm)DateComment SSSV: NIPPLE Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag:1J-166L1 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: WELL REVIEW 5/13/2013 1J-166L1 osborl Casing Strings Casing Description B-SAND LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 5,377.3 Set Depth (ftKB) 12,909.3 Set Depth (TVD)… 3,590.5 Wt/Len (l… 12.60 Grade L-80 Top Thread IBT Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 5,377.33,495.1 79.68 HANGER 7-5/8"x 4-1/2" Baker Mod B1 FHH ( Inside Casing 16.86' ) 5.630 5,402.2 3,499.3 81.08 SWIVEL Baker Casing Swivel 3.960 12,877.83,589.187.11 XO Reducing 4-1/2" X 3-1/2" XO sub 2.992 12,879.23,589.187.14 BENT JT 3-1/2" Bent Joint IBT, 9.2 ppf, L-80 2.900 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 5,380.0 3,495.6 79.70 ISOLATION SLLEEVE TYPE 1 ISOLATION SLEEVE 11/9/2019 2.500 10,235. 0 3,579.0 88.97 PLUG B-SAND IBP set 6/3/2008 6/3/2008 0.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 5,409.08,178.03,500.33,512.6 WS C, 1J-166L11/28/2006 32.0SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,426.0 10,101.0 3,519.4 3,576.8 WS C, 1J-166L1 1/28/2006 32.0 SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 10,905.012,417.03,522.5 3,563.9 WS C, 1J-166L11/28/2006 32.0SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 12,571.012,878.03,570.13,589.1 WS C, 1J-166L11/28/2006 32.0SLOTS Alternating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 1J-166L1, 5/20/2021 3:50:06 PM Vertical schematic (actual) B-SAND LINER; 5,377.3- 12,909.3 SLOTS; 12,571.0-12,878.0 SLOTS; 10,905.0-12,417.0 PLUG; 10,235.0 SLOTS; 8,426.0-10,101.0 SLOTS; 5,409.0-8,178.0 B LINER LEM; 5,107.5-5,521.5 INTERMEDIATE; 26.4-6,350.0 ISOLATION SLLEEVE; 5,380.0 D LINER LEM; 4,885.0-5,137.0 D-SAND LINER; 5,002.1- 12,952.7 GAS LIFT; 4,319.5 GAS LIFT; 2,572.0 SURFACE; 30.1-2,368.4 HEAT TRACE; 10.0 NIPPLE; 503.3 CONDUCTOR Insulated; 30.0- 108.0 KUP PROD KB-Grd (ft) 31.01 Rig Release Date 2/11/2006 1J-166L1 ... TD Act Btm (ftKB) 12,952.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329160 Wellbore Status PROD Max Angle & MD Incl (°) 99.97 MD (ftKB) 10,422.57 WELLNAME WELLBORE Annotation Last WO: End Date 4/17/2008 H2S (ppm)DateComment SSSV: NIPPLE • • 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. ~~ S- ~ ~ ~ .Well History File Identifier Organizing (done> RESCAN ~lor Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: o.~.,a~ uummiiiuuii DI/GITAL DATA ~ f7(Diskettes, No. ~.. ^ Other, No/Type: ae.v~~ttaea iuumuiiuuu OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ !s/ Project Proofing _ III IIIIII VIII II III BY: / Maria ~ Date: ~ / ' ~ ~ /s/ ~~ Y' `i-/ L ~.T Scanning Preparation ~v _ x 30 = ~ + =TOTAL PAGES--1~ ount does not include cover sheet BY: Maria Date: ~ /s/ ) Production Scanning Stage 1 Page Count from Scanned File: (Count does include cover sheet) Page Count Matches Number in Scanning Pr paration: ~/YES NO BY: Maria Date: ~~~,3 O $ /s/ ~M Y p Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II II II I (I II I I III Rescanned II I II II II I I III I ~ III BY: Maria Date: /s/ Comments about this file: Quality Checked III IIII~I III IIII III ~D 10!6/2005 Well History File Cover Page.doc • • ~~ ~ • ~~~;I'~~~~~ STATE OF ALASKA O CT ~~ ZQ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ ~~~ ~~8S ~O(i~. ~Qft~tlliSSiOn REPORT OF SUNDRY WELL OPERATIOI~ A....w...... 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ~ Stimulate ~ Other ~ Pull B Sand ISO Alter Casing ^ Pull Tubing ^ Perforate New Pool ~ Waiver ^ Time Extension ^ Sieeve Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: ''5. Permit to Drill Number: ConocoPhillips Alaska, If1C. Development ~^ F~cploratory ^ p 205-199 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 -~ 50-029-23291-60 KB Elevation (ft): 9. Well Name and Number: RKB 28' ~' 1J-166L1 8. P erty Designation: ~ 10. Field/Pool(s): ADL 25661 & 25650 Kuparuk River Field/ West Sak Oil Pool 11. Present Well Condition Summary: , .v` ~ Total Depth measured 12952 feet true vertical ~ 3593 feet Plugs (measured) 10235 Effective Depth measured 12907 feet Junk (measured) true vertical 3590 feet Casing Length Size MD ND Burst Collapse Conductor 80' 20" 108' 108' Surface 2340' 10-3/4" 2368 2194' Intermediate 6328' 7-5/8" 6356' 3650' Liner B Sand 7532' 4.5" 12909' 3592' Perforation depth: Measured depth: 5409'-8178', 8426'-10101', 10905'-12417', 12571'-12878' true vertical depth: 3499'-3513', 3519'-3577', 3522'-3564', 3571'-3589' Tubing (size, grade, and measured depth) TBG in main Wellbore, , MD. f Packers & SSSV (type & measu~ed depth) v(p liner top packers 4885', 5104' 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 979 313 14 575 198 Subsequent to operation 1387 138 1249 868 251 14. Attachments Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations X 16. Well Status after proposed work: il~ 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 wA if C.O. Exempt: N/A Contact B. Christensen/ D. Humphrey Printed Name Darrell R. Humphrey Titie Production Engineering Specialist Signature ~ Phone: 659-7535 Date /D•~~•d`T '\ Form 10-404 Revised 04/2004 ~~ ~ r~~~~~ ~ S bm t O gi al Only • ~ ,. 1J-166L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/20/09 PULLED ISO SLEEVE FROM B-LEM @ 5390 CTMD, SLEEVE HUNG UP IN D-LEM, HIT 9 JAR LICKS TO FREE UP, JOB COMPLETE. ~ Conoco/Phillips A13Sk3,If1C. KUP ell Altrlbutes IOora APIIUWI Fleltl Name 500292329160 WESTSAK 1J-166L1 IN Lt ~t~ ITVDI ... IBT _-_ =_-_-_ ~ i~ a ~------_- NIPPIE. 5IXi EATTRACE, 70 SURFIICE, GAS LIFT, 2,512 ZAne SIEEVE,0,831 GAUGE,4.B12 ~ocnroR, 4,890 SEALASSY, a.es~ w~aow o-snrio. s,ooss.we PACKEft L1, 5.10/ CSft L7. 5.123 26-6.350 ~ Sbls, S.CWE.178 Sbb, 8,02&10,101 PWG, 10,Z6 12.S11-12.8]8 1 Linar B-SAND, 5,377-12.909 TD (1J~166L7). 12,952 ~omme~~ ID S,4lFJ S,1/S 3,4fFJ.U 3,S11.ti W5G,1J-ltitill 1lltillWti 3Z.U SIOtS AlternaOngSloRed/DlanKpipeU.lZb'X 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. narslotted ends 8,426 10,101 3,518.8 3,577.1 WS C, 1J-166L1 1I28I2006 32.0 Slots Altematlng slottedlblank pipe 0.125" x 2.5" x 32 spf ~ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. norrslotted ends 10,905 12,417 3,522.5 3,563.9 WSC,1J-i66L1 128/2008 32.0 Slots AltemaNrgslotted/blankpipe0.125"x 2.5" x 32 spf a~ 4 Circumferentlal adjacent rows, 3" Centers staggered 18 deg., 3 ft, norFSlotted ends 12,571 12,878 3,570.6 3,589.7 WS C, iJ-166L1 1R8/2006 32.0 Slots Altemating slotted/blank pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3° Centers staggered 18 deg., 3 ft. non-slotted ends Make I Motlal Valw ~ La4h i i Page 1 of 2 Maunder, Thomas E (DOA) From: Schwartz, Guy L [Guy.L.Schwartz@conocophillips.com] Sent: Friday, September 19, 2008 8:27 AM O' ~ S ` ~ ~F. To: Maunder, Thomas E (DOA) Subject: RE: 1J-166L1 (205-199) Attachments: 1J-166 A2 Lat Blank- Slotted Liner detail.xls; 1J_-166 B Lat Blank- Slotted Liner detail.xls; 1J- 166 D Lat Blank- Slotted Liner detail.xls Here is the liner details... let me know if anything else is needed! Guy Schwartz Drilling and Wells Engineer ofFce: 907-265-6958 Cell: 240-5696 ATO-1512 guy.I.schwartz@conocophillips.com ~,~J~~~~~ S~F ~J E, 2OC~€~ From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, September 19, 2008 8:10 AM To: Schwartz, Guy L Subject: RE: iJ-166L1 (205-199) Guy, Thanks for the information. Yes, would. you please send the liner detail and for the other legs as well. I do think it is appropriate to have sent the 404. Having infomlation on potential remedies for MBEs is important. It all goes to maintaining the best available well file possible. Call or message with any questions. Tom Maunder, PE AoGCc From: Schwartz, Guy L [mailto:Guy.L.Schwartz@conocophillips.com] Sent: Thursday, September 18, 2008 4:48 PM To: Maunder, Thomas E (DOA) Subject: RE: iJ-166L1 (205-199) Tom, We have swell packers staged (in some of the blank pipe sections) in the well to give us some options of shutting off part of the well. Thus we set a IBP in a blank section to isolate the lower section from a MBE breakthrough (ie water !!). It seemed to work great.... The B lateral has .125" slotted liner alternating with blank sections. I could forward the liner detail if you want it. the key though is that we ran swell packers too. Good thing in this well as it allowed us to shut off a lower water 9/19/2008 • source. Page 2 of 2 Let me know if this is enough info... I wasn't sure if we needed to send a 404 in as this is a retrievable plug. But in this case we would like to make it at least permanent for the short term. Could be in there for a while!! Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 guy.I.schwartz@conocophillips.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, September 18, 2008 4:13 PM To: Schwartz, Guy L Subject: 1J-166L1 (205-199) Guy, Could you enlighten me a little on this RBP work? Is there an MBE contributing water? Also, looking at the 404, long perforated intervals are listed. Does the liner alternate slotted and solid sections? On the 404 they are listed as perfs. Thanks in advance. Tom Maunder, PE AOGCC 9/19/2008 • 1J-166'8' Sand Liner Detail Well: 1J-166 L1 1~ 4-1l7" Slotted and Blank Liner Date: 1/28/2006 Alaska, Inc. DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 1 LENGTH TOPS 5365.61 5365.61 4" DP to Surface =_> 5365.61 5365.61 5365.61 4" DP XO 4.75" OD X 2.5625" 1.61 5365.61 Liner Runnin Tool 5" Does not sta in hole 10.05 5367.22 7-518"x 4-1t2" Baker Mod B1 FHH (Inside Casing 16.86') 16.86 5377.27 7-5/8"x 4-1/2" Baker Mod B1 FHH (Outside Casing 6.04') 6.04 5394.13 4-1 /2" Crossover Pu Joint 2.04 5400.17 Baker Casin Swivel 2.75 5402.21 4-1/2" IBT, 12.6 f, L-80 Pu Joint 3.85 5404.96 Jts 153 to 242 90 Jts 4-1 /2",12.6 f, L-80, IBT Slotted Casin 2768.77 5408.81 Jts 145 to 152 8 Jts 4-1/2", 12.6 f, L-80, IBT Blank Casin 248.45 8177.58 Jts 91 to 144 54 Jts 4-1 /2",12.6 f, L-80, IBT Slotted Casin 1674.82 8426.03 Jts 65 to 90 26 Jts 4-1/2", 12.6 f, L-80, IBT Blank Gasin 804.02 10100.85 Jts 16 to 64 49 Jts 4-1 /2",12.6 f, L-80, IBT Slotted Casin 1511.77 10904.87 Jts 11 to 15 5 Jts 4-1/2", 12.6 f, L-80, IBT Blank Casin lf~ 7,~ 154.01 12416.64 Jts 1 to 10 10 Jts 4-1/2",12.6 f, L-80, IBT Slotted Casin 307.17 12570.65 4-112" X 3-1/2" XO sub 1.42 12877.82 3-112" Bent Joint IBT, 9.2 f, L-80 ~~ 28.63 12879.24 Baker 3-1/2" Guide Shoe No float 1.43 12907.87 12909.30 TD 6-3/4" Hole 12,952' MD /3592' TVD ~ Shoe 12,909' Rathole 43' Sfl c~, To of window "B" lateral 5380' MD Bttm of window "B" lateral 5392' MD Hooked btm of window 5,394' w/ FHH 2.13' low) Total of 6 Constrictor Packers 12,557', 12,427', 10,897', 10,107', 8,424', 8,197'. To of A2 lateral liner 5,480' H droForm Centralizers laced 1 er 'oint with sto rin in the middle of each 'oint on Slotted 'oints and 1 eve other 'oint on Blank 'oints for first 160 'oints. Ran total o f 39 'ts Blan k = 1,206.48' and 203 'ts Slotted= 6,262.53', Slots. are Up Wt 185K w/ 32) 2.5" Ion x .125" 4 Circumferential ad'acent rows, 3" Centers Dn Wt 40K sta ered 18 de ., 3 ft. non-slotted ends Block Wt 35K Ran 140-- 4.5" X 5.75"OD H droForm centralizers. DO NOT run an centrilizers on the 'oints with a constrictor packer. Top centrilizer @ 7928' MD Used Run-N-Seal thread compound on all connections. All drifted w/ 3.833" rabbit. STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^ Other Q Install Plug Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConOCOPhillips Alaska, InC. Development ^~ Exploratory ^ 205-199 / ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23291-60 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' 1J-166L1 ' 8. Property Designation: 10. Field/Pool(s): ADL 25661 & 25650 ~ Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12952' feet true vertical 3593' feet Plugs (measured) 10235' Effective Depth measured 12907' feet Junk (measured) true vertical 3590' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' SURFACE 2340' 10-3/4" 2368' 2194' INTERMEDIATE 6328' 7-5/8" 6356' 3650' LINER B-SAND 7532' 4.5" 12909' 3592' P f i d h M ' ' ' ' ' ' ' ~E~~ ~~~ ..~~ ' er orat on ept : easured depth: 5409 -8178 , 8426 -10101 , 10905 -12417 , 12571 -12878 true vertical depth: 3499'-3513', 3519'-3577', 3522'-3564', 3571'-3589' ,~~P Tubin size, rade, and measured de th 9 ( 9 P ) tubing in main wellbore, , MD. ~~aska Oil & Gas Coy _ „ Anchoraj Packers &SSSV (type & measured depth) ZXP liner top packers @ a885~, 51oa' no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1258 not available 733 -- 251 Subsequent to operation 1070 1728 122 -- 196 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 NiA if C.O. Exempt: none Contact Guy Schwartz @ 265-6958 Printed Name Guy Schw Title Wells Group Engineer ~~ Signature S' Phone: 265-6958 Date ~_ ~~ ~ $ '~~~ Pre ared b Sharon Allsu Drak 263-4612 (~ Form 10-404 Revised 04/2006 ~~, jFr~ ~ ~ 200tl t'1~.~ Submit Origi rd~~~/~, 1J-166 Well Events Summary DATE SUMMARY 6/1/08 RIH PUMPING SD, COULD ~ ESTABLISH 1:1 RETURNS BELOW 350 T. PERFORMED FLUFF & STUFF DOWN "A" LATERAL. PUMPING SD & BIO SWEEPS @ 2 BPM TO 8072' CTMD, COULD NOT PUSH FURTHER. JET LEM MULTIPLE TIMES WHILE POOH. SHUT IN SWAB, SECURE WELL AND STAND BACK CTU FOR NIGHT. RETURN IN AM FOR DIVERTER &IBP RUN. 6/2/08 Make up Baker MHA, 2-3/8" Hipptrip, 4" Hyd. GS, LEM #1 DEVERTER. HAD TO TAP THROUGH D LATERAL HANGER @ 4988' - 5030 'CTMD. P/U WEIGHTS LOOKED GOOD, RIH SET DEVERTER IN "B" LAT @ 5402' CTMD (5380 RKB). POOH AND CHANGE BHA TO 2.5" JSN AND STRAIGHT BARS. RIH PUMPING SD, MADE IT TO 6200', WITH PIPE STRAIGHTNER APPLIED TO 4500'. P/U TO 4500' SWITCH TO FRICTION REDUCER DIESEL, RETURNS TO SURFACE. RIH WITH PIPE STRAIGHTNER APPLIED TO BOTTOM. CLOSE IN RETURNS AND FLUFF & STUFF DOWN TO 9650' CTMD WEIGHT CHECKS EVERY 500'. TRY & RUN IBP USING CT.POOH LEAVING FRICTION REDUCER IN WELL FOR IBP RUN IN AM. 6/3/08 RIH WITH BAKER MHA, INFLATION VALVE, HYD. RUNNING TOOL, 2.5" RETRIEVABLE BRIDGE PLUG (FISHING NECK 1.375 JDC, 5500# PULL RELEASE, 1800# DOWN EQUALIZE, IBP LENGHT 11.05'). SET ~ 10.235' RKB IN "B" LATERAL. PIPE STRIAGHTNER APPLIED FROM SURFACE, START PUMPING .5 BPM OF S.D.(ID LUBE), INCREASE TO 1 BPM FROM 5300', MADE IT DOWN TO SETTING DEPTH OF 10,260'CTMD. P/U 10 FEET AND SET IBP @ 10, 250' CTMD IN "B" LATERAL. PUMPED BALL TO SEAT WITH SSW, GOOD INDICATION OF SETTING, SWITCH TO S.D. -POOH. SWAP BHA @ SURFACE. RIH TO PULL "B" LATERAL DIVERTER @ 5387' CTMD. POOH. WELL LEFT FREEZE PROTECTED, HANDED OVER TO DSO. JOB COMPLETED. 'Insulated conductor, 20" 94# K55 x 34" 0.312", set at +l- 80' MD. Tubing String F112" 12.fip, L-00, IaTM 1.959" Id, 1.611" brXi 503' MD - 3.875" DB Nipple, 503' TVD, .4 deg 2572' MD -GLM, Camco 4-112" X 1" KBG-2, 2361' ND, 35deg 4319' MD -GLM, Camco 4-1/2" X 1" KBG-2, 3225' ND, 69deg - ~ 4831' MD - CMD Sliding Sleeve, wl 3.81" DB Profile, 3377 ND, 77deg ConocoPhillips West Sak 7-5/8" Producer 1J-166 Tri-Lateral Completion 10310" ds.5p L-80, ~,. " ~ caemg sno•s•t@ ~, r~ 2766• Mo, 2196• rvo \_ / 4922' MD -Bottom of Seal Assembly 4.75" Seal OD /~\\ 4959' MD - 3,75" DB Nipple, 3405' TVD, 78deg 4885' MD - 5-112" X 7-5/8"/ZXP \\• 4995' MD -Lateral Entry Module (LEM) Liner Top Packer wl Hold Downs \' ~~~ D-Sand Window at 5005' MD, 76 deg inc 'p' Sand Lateral 4904' MD -Casing Sealbore 4-i12" 12.6# L-80 Slotted Receptacle 4.75" ID \, sozr Mo • user swro•1 Liner Ev/ery Joint /3-112" Bent Joint i~-- ~~ _ 1 .. / ~ 3-112" Guide Shoe 5002' MD - 4-112" X 7-518" ~ /~ Model 'B' HOOK Hanger Seal Bores 3.68" ID 5104' MD - 5.112" X 7-518" 2J(P Liner Top Packer wl Hold Downs 5-1/2" X 7-518" 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 ~ Seal Bore for Lateral Isolation - 3.68" ID ~ Access Window Positive Lateral Access Via Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3.68" ID Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID 5123' MD -Casing Sealbore Receptacle 4.75" ID Liner Shoe, Set @ 12953' MD, 3530' ND 5137' MD -Bottom of Seal Assembly 4.75" Seal OD / 5145' MD -Tubing Swivel 5367 MD -Lateral Entry Module(LEM) 8-sand Window \L at 5380 MD, 79.5 deg Inc 'B' Sand Lateral / 4-12" 12.611 L-80 Slotted f 5402' MD -Liner LI E J t ~.. Baker Oil Tools RWO As Completed Lateral Access Diverter Lateral isolation Diverter GS Running Tool String installed Installetl (3.00" Lateral Drift) (2.50" ID Mainbore Drift) ~~ 'GS' Pro01e for ' Coil Connector fRUnning/Retrieving~~ I (1.00' Length) I ~ ~ ' ~ . II ~ Snap In15nap Out ~ ,r Back Pressure Valve /Positlve Locatingti $ (1.60' Length) Collet ~~ Lateral Isolation ~- ~~ ,,r Flow•Thru Swivel i . '~ Seals / Lateral Diverter - - ~Hytlraulic Ramp ` Disconnect \ Icolatlonl Mainbore~'~ (1.50' Length) Diverter sleeve L~ ~ ~GS Spear ~ _ ~® ~ (1.50' Length) ~ ~ Lateral Isolation "~i 6.55 ft Approx. _ Seals ! I OAL` ~i L J ner very om 3-112" Bent Joint Swivel 5377' MD - 4-112" X 7-518" ~ 3.1/2" Guide Shoe Model 'B' HOOK Hanger ! - ~. _;( I _ •..."r.,, l 1 ... Liner Shoe, Set @ 12909' Seal Bores ;. ~~ - MD, 3592' ND 3.68" ID 4-1/2" 12.6# 5443' MD - 3.562" DB Nipple 5-1 /2" X 7-518" ZXP \\~' Liner Top Packer ~ \\\ with Hoid Downs 5-112" X 7-518" Liner Hanger I Packer Assembly at Flex Lock 5480' MD Liner Hanger 5512' MD - Casing ~ Sealbore Receptacle, 4.75" ID ®Beker Nugh•f 2005. ThN document may not ba roproducatl or tli•Irkrut•tl, in whoN or in purl, In sny /ortn or by any masse el•aronk or machsnical, including photocopying, recording, or by any inbrmelbn florage antl rolriwel syelem now known or Mroefl•r invented, wahoul vrcaten permission hom Baker Nughw Inc. 5521' MD Seat Assembly 4.75" Seal OD 'A' Sand Undulating Lateral 1 S 4-112" X 7-518" HOOK Hanger ~ Mainbore Drift: 5.32" Mainbore Drift, with diverter: 4,63" Lateral Drift, no diverter or LEM: 3.68" Lateral Drift, wl diverter, no LEM: 3.88" LaterallMainbore Diverter OD: 6.75" 4-112" Lateral Entry Module i Mainbore Drift: 3.65" Mainbore Dritt, wl isolation sleeve: 2.50" Lateral Driit, wl toll tliverter: 3.00" OD of Diverter and Sleeve: +/- 3.89" i Diverter and Sleeve Length: +/- 16.5' 4- 12 12.6# L•80 lotted Liner Every Joint 4-1n" Eccentric ~~ ~ ~Gulde Shoe d ~~~' ~~_-_ ~ ~_ ="i'P'F~~. 4-112" Casing Shoe, 12.6#, L•80 IBTM \i - - - ~ - 1? Set @ 12840' MD, 3723' TVD 7-518" Casing Shoe, Set at @ 6350' MD, 3649' ND • SURFACE, 0.2,378 GAS LIFT 1, 2,572 GAS LIFT 2, SLEEVE, 4,831 Hydrualle Settlng Toal LEM, 4,883 TIE BACK LEM, 4,885 PACKER, 4,898 SBE, 4,996 XO, 4,926 HANGER L2, 5,902 HANGER, 5,019 SWIVEL, 5,027 Window D-SAND, 5,0055,066 PACKER L7, 5,101 CSR L7, 5,123 XO Bushlrg, 5,143 SwNN L7, 5,145 PUP, 5,147 HANGER LEM, 5,387 HANGER LEM, 5,377 MANGER L1, 5,396 PLUG, 10,235 ~: I I: XO, 12,878 BeM .biM, 12, 879 1 SHOE, 12,908 ~ ': i XO, 12,921 Uner BSAND, `~ 4,980.12, 934 ~ ~ TO (1J-18611),12,952 KUP 1J-166L1 50 ' 1/1Y2008 Last iNO: 4/17/2008 31.01 2/1112006 tatlon Depth (RKB) End Date Annotation End Date TBD: Rev Reason: SET IBP IN L1 612212008 Ig Description uo tin( iD (~) Top irtKB) 1Sel Depth lfiKBl ~,oIC pln lT;of lnKel w2li[. Ri ne ~'rop ecU< 'B-SAND 4112 3.958 4,954.0 I 12,934.0 `')1? i~.iiii -80 IBiM .. 4 ,..... r .. ~ .:. (tIKB) Dexriptlon Comment Run Date ID .,394.0 HANGER L1 B-SAND BAKER MOD 81 FHH OUTSIDE CSG HANGER 1/2&2006 3. Btm snot canal... Dens Shot sho... Total Dah Commerd MnOtatiOn Valve Lanh Port I TRO Run Make ~ ModN OD linl Type Type Size (in)~ Ipe9 Run Date Comment _ _ _ _ __ _ RE~El~E[3 • STATE OF A~,4SKA • MAY 2 U 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIC'~a Oi1 & Gas C~ns. Commission • ~_L _'___ t. Operations Performed: Abandon ^ Repair Well ~~ Plug Perforations ~ Stimulate ^ Other Alter Casing ^ Pull Tubing ^~ ~ Pertorate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Wel! Class Before Work: 5. Perrr-it to Driil Number: ConocoPhillips Alaska, IIIC. Development ~ Exploratory ^ 205-199 /. 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23291-60 ~ 7. KB Elevation (ft): ~ 9. Well Name and Number: RKB 28' 1 J-166L1 . 8. Property Designation: ~ 10. Field/Pool(s): ADL 25661 & 25650 Kuparuk River Fieid / West Sak Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 12952' ~ feet true vertical 3593' ' feet Plugs (measured) Effective Depth measured 12907' feet Junk (measured) true vertical 3590' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 2259' 10-3/4" 2368' 2194' INTERMEDIATE 6241' 7-5/8" 6350' 3650' LINER 7532' 4.5" 12909' 3592' Perforation depth: Measured depth: 5409'-8178', 8426'-10101', 10905'-12417', 12577'-12878' true vertical depth: 3499'-3513', 3519'-3577', 3522'-3564', 3571'-3589' }y` ` ~~~~~' `~ f;~ '~~~~~ Tubing (size, grade, and measured depth) tbg in main wellbore, , MD. ~~~., ~~ + ~~ Packers & SSSV (type & measured depth) no packer no SSSV 12. Stimulation or cement squeeze summary; Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation 1529 ' 1059 2707 -- 251 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ ~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact Brett Packer Printed Name Brett Packer Titie Wells Group Engineer ~, Signature ~ ~ ~y/,~~~~ '~~ Phone: 265-6845 Date ~j/°j/t~~' -i~~ " " ared b Sh n Allsu Drak 2 3-4612 ""~ ~ ' ~~:. ,. ,_ ~ ~ ~~ . ~'? . ~.-. l=,'~.. ~1 s~ 2~~~ S'R~/•~ Form 10-404 Revised 04/2006 ~~~Submit al O I 0 R I G I~I A L ~, ,~..~~.~~~~~~.~ . ~ ~~t~~c~~'~~~~~p~ ~Al~sk~, ~r~~. KRU 1J-166L1 • • Cc~r~c~c~Ph~~~ips Time Log Summary . WelNiew Web RePDrbnq . . . . . . . . ;,y ,:::s, ... ~~ . ~ ~` 3 s:~-- .E~ ' . ~' . ~.~~ti, .;. ,..agAs: • : =,.~',-£`,° . T ~ ,. ~ ~ , e~h~ ~ X ~ . . ~;~~ "~ .#'~f ~: ~_ <_ ~~: -,A ~ .,~ ., k :'-_^-.6 .~.'~ t.x..~ % v ~ ~^ ~~`a;,~ Well Name: 1 J-166 _ : Job Type: RECOMPLETION _ r . ~. - ,> . .~- '~ ~ ~- -~~ ~ .. ,z _. .~ r , „« ~ ~-'"~.. `' ~ -':~ ~°, . .. . '. ...... .. .: s --...~ <'~.:3m.~~ . 2 ~'~.. : e _ ~,`.., ~\ . ,£n.. ,i> , *. , < ~~, . "~-~ ..-~^. ~`.N„\. ~ ~ ~Fa~ ~ \ I Ls„ 04/10/2008 00:00 01:30 1.50 COMPZ MOVE MOB P Nordic 3 Pulied off of 1J-135 and clean u cellar and tree. Move ri to 1J-166. 01:30 02:00 0.50 COMPZ MOVE PSIT P Spot and )evel rig. Set up handi berm. 02:00 05:00 3:00 COMPZ RPCOh OTHR P Take on 6Q0 bbls of hot 6%o KCL fluid. Load lubricator in pipe shed and lubricate BPV from well. Tie into tree and IA. Open up well: 450 psi tbg, 700 si IA, 500 si OA. 05:00 09:00 4.00 COMPZ RPCOI~ OTHR P Vent gas off of well to Tiger tank. Shut down to reconfigure Tiger tank for Simm Ops on 1J-10. PT line to tiger tank to 2500 si. 09:00 11:00 2.00 COMPZ RPCOti CIRC P Reverse circulate 340 bbi of 8.4 ppg 6% KCL @-110 deg. tnital tubing press = 330 psi, initial IA press = 680 psi. Tubing and IA press at 0 psi after circulating. 340 bbl of returns to the ti er tank. 11:00 17:30 6.50 COMPZ RPCOti NUND P Install BPV, ND tree, NU BOPE. Install blankin lu . 17:30 22:30 5.00 COMPZ WELC BOPE P Test BOPE 250/2500 psi. Test Annular @ 250/2,500 psi. 24 hr Notice was given @ 19:00 hrs on 4-9-08 to AOGCC and witness of test was waived by Chuck Scheve @ 14:00 hrs on 4-10-08. 22:30 00:00 1.50 COMPZ RPCOh OTHR P Pull blanking plug and BPV. RU ESP E ui . 04/11/2008 00:00 01:30 1.50 COMPZ RPCOti OTHR P Continue to RU ESP Equip. Install Landin Jt. BOLDS. 01:30 02:00 0.50 4,083 4,078 COMPZ RPCOh OWFF P Unland hanger @ 150k. Pull inner hanger above Outer Hanger w/ 130k u wt. Monitor well for flow/Good. 02:00 02:30 0.50 4,078 4,025 COMPZ RPCOti OTHR P Continue to Pull hanger to floor and cut ESP cable below splice. Lay down landing jt. Lay down Hanger and .t 02:30 11:30 9.00 4,025 4,025 COMPZ RPCOti OTHR P String ESP cable over sheave and tie into s ool. POOH 11:30 14:00 2.50 4,025 0 COMPZ RPCOh PULD P Lay down ESP completion. Recovered all clamps and bands: 68 cannon clamps, 3 protectolizers, 2 flat guards, 4 SS bands. l.oad out ESP com letion. 14:00 14:30 0.50 0 0 COMPZ RPGOti OTHR P Clean rig floor. . • • • ~..J 04/14/2008 04:30 0730 3.00 0 96 COMPZ RPCOti SFTY P Held PJSM w/ crew and third party contractors on Rih w/ 4 1/2 Com letion. MU Guardian ua e. 07:30 11:30 4.00 96 1,877 COMPZ RPCOti RCST P RIH with 4-1/2 completion with TEC. wire. 11:30 1230 1.00 1,877 1,877 COMPZ RPCO PULD P Crew change, PJSM. Rig up equipment to start running heat trace cable. 12:30 00:00 11.50 1,877 4,418 COMPZ RPCOh RCST P RIH with 4-1/2' gaslift completion with TEC wire and heat trace cabie. 04/15/2008 00:00 02:30 2.50 4,418 4,924 COMPZ RPCOh RCST P Continue to Rih f/ 4,418' to 4,924' wl 4 1/2 Gas Lift Completion. Tag w/ 24.5' in on 't 157. 82k u wt 74k dn wt. 02:30 03:00 0.50 4,924 4,924 COMPZ RPCOh DHEQ P Fill IA w/ 10 bbls. PT to 500 psi for 5 minutes. Bleed off. 03:00 03:30 0.50 4,924 4,841 COMPZ RPCOti HOSO P Pooh and lay down jts - 157,156,155. 03:30 0430 1.00 4,$41 4,898 COMPZ RPCOti HOSO P Rih w/ 3 pup jts = 25' and 1 jt w/ han er. 04:30 0930 5.00 4,898 COMPZ RPCOh OTHR P Make Final spice w/ heat trace and I tec wire. Test heat trace - good. Trouble shoot I tec wire - connection roblems. Test ood. 0930 10:30 1.00 COMPZ RPCOh CIRC P Reverse circulate w/ 130 bbls of 6% KCL w/ 1% b Vol. CRW-132 10:30 11:00 0.50 4,922 COMPZ RPCOti HOSO P Drain stack and land hanger. RILDS. w/ 3.875" DB Nipple @ 503', GLM #1 @ 2,572' to 2,579', Heat trace starting @ 3,046', GLM #2 @ 4,320 to 4,327', 3.812" ID Sliding Sleeve @ 4,832', Guardian Gauge @ 4,842', Bottom of seals @ 4,922', ZXP Pkr @ 4,885' to 4,904', SBE @ 4,904' to 4,924', 3.75" DB Nipple @ 4,959', Bottom of non locating seals @ 5,137' placed in B Lateral SBE @ 5,123' to 5,143'. Ran 10 - SS Bands, 478 - 5' Clamps, 3- 2' Clamps, 2- 3' Clamps, 1- End Shoe and 60 X- Cou lin Clam s. 11:00 12:30 1.50 COMPZ RPCOh DHEQ P PT IA to 1,000 psi for 30 min. and Chart. PT Upper/Lower tbg hanger void @ 5,000 psi for 10 minutes. Attempt to shear SOV @ 4,316' @ 2,000 psi - no shear - Pressure to 3,500 si - no shear. 1230 14:00 1.50 COMPZ RPCOh WOEL T Wait for HES slickiine unit to RD off of 1J Pad weli and move to 1J-166. 14:00 15:00 1.00 ~ COMPZ RPCOti SFTY T Held PJSM w/ crew and:RU Slickline. ~ • . , ~ i ~~ DATA SUBMITTAL COMPLIANCE REPORT 5/12/2008 Permit to Drill 2051990 Well NamelNo. KUPARUK RIV U WSAK 1J-166L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23291-60-00 MD 12952 TVD 3593 Completion Date 2/11/2006 REQUIRED INFORMATION Mud Log No Completion Status 1-OIL Samples No DATA INFORMATION Types Electric or Other Logs Run: GrlRes, Dens/Neu Well Log Information: Log/ Electr Current Status 1-OIL UIC N Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Data Digital Dataset Log Log Run Interval OH / Type M ed/Frmt Number Name Scale Media No Start Stop CH Received Comments ~D D Asc Directional Survey 28 12952 Open 4/17/2006 iED D Asc Directional Survey 28 9618 Open 4/17/2006 PB 1 / ~t 13878 LIS Verification 2331 12894 Open 5/19/2006 D Lis 13878~nduction/Resistivity 2331 12894 Open 5/19/2006 GR, EWR4, ABI, ROP, PWD, Geoplot /19/2006 !~D C Lis 1607~/Induction/Resistivity 2331 12952 Open 4/2/2008 LIS Veri, GR, FET, RPM, RPD, RPS, RPX, ROP ~D C Lis 16075~nduction/Resistivity 2331 9618 Open 4/2/2008 PB1 LIS Veri, GR, FET, RPM, RPD, RPS, RPX, ROP ~~ 6+a9 Induction/Resistivity 25 Col 219 3592 Open 4/2!2008 TVD DGR, EWR 27-Jan- 2006 l~xfg Induction/Resistivity 25 Col 219 12952 Open 4/2/2008 MD ROP, DGR, EWR 27- Jan-2006 Induction/Resistivity 25 Col 219 9618 Open 4/2/2008 PB1 MD ROP, DGR, EWR 24-Jan-2006 Well Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 5/12/2008 Permit to Drill 2051990 Well NamelNo. KUPARUK RIV U WSAK 1J-166L1 Operator CONOCOPHILLIPS ALASKA tNC MD 12952 TVD 3593 ADDITIONAL INFORMATION Well Cored? Y Chips Received? ~PI~ Analysis ~`tid- Received? Completion Date 2/11/2006 Completion Status 1-OIL Daily History Received? Formation Tops Current Status 1-OIL Y/N Comments: Compliance Reviewed By: API No. 50-029-23291-60-00 UIC N Date: ~. WELL LOG TRANSMITTAL To: State of Alaska March 21, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-166+L1+L1PB1+L2+L2PB1 AK-MW-4149018 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 J-16 6+L 1 +L 1 P B 1 +L 2+L 2 P B 1: 2" x 5" MD Resistivity & Gamma Ray Logs: 1 Color Log 50-029-23291-00,60,61,70,71 2" x 5" TVD Resistivity & Gamma Ray Logs: 1 Color Log 50-029-23291-00,60,61 Digital Log Images 1 CD Rom 50-029-23291-00,60,61,70,71 Some sections of this well have no TVD. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services c~05 !9 ~ '~ 1 CoU~'~/ Attn: Rob Kalish ~~ ,.,~cl~a ~ ~ 6U ~S_ 6900 Arctic Blvd. Alaska 99518 X05 ~~ ~ ~ ~d~~ Anchorage, ~ ~~ ~ l~ ~ ~~ ~~ ~~ ~~ ~~ ~~» ` V Date: II Signed: (~ diet i 7 y r_ (.,ii; ~ .~iiit>, l.A 1! Ii{f'~Filr-rl f it;llt i~~~3!~1+~ 13-~ ~~ ~°~-' _~ ~~~ -r~~ WELL LOG TRANSMITTAL To: State of Alaska May 3, 2006 Alaska Oil and Gas Conservation Co. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-166 Ll, AK-MW-4149018 1 LDWG formatted Disc with verification listing. API#: SO-029-23291-60 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 Dater ~~ p Signed: ~ ~~~~~~~~~ 13~~ 02-Apr-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 J-166 L1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. ~~ ~/~~~~ Tie-on Survey: 9,300.88' MD Window /Kickoff Survey: 10,702.44' MD (if applicable) Projected Survey: 10,795.91' 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 B Date ~ 4~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ,.~.. 02-Apr-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 J-166 L1 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 5,347.17' MD Window /Kickoff Survey: 9,582.35' MD (if applicable) Projected Survey: 9,618.00' 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 ~~ ~ i Date S Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ,~~s =/qq~'~ `,' ConocoPhillips April 7, 2006 Randy Thomas `w~rw Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 - - ,- - Anchorage, Alaska 99501 Subject: Well Completion Reports for 1 J-166, 1 J-166L1 and 1 J-166L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk well 1 J-166, 1 J-166L1 and 1 J-166L2. If you have any questions regarding this matter, please contact me at 265-6830 or Mike Greener at 263-4820. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad ' STATE OF ALASKA •,,w.i ~{~~ ~ O ZOO6 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT A~~}~~~~~i°~'~• Commies"°~ 1a. Well Status: Oil O 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.: February 11, 2006 ~ 12. Permit to Drill Number: 205-199 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: ~ January~8~2006 •~~'~~ 13. API Number: 50-029-23291-60 ' 4a. Location of Well (Governmental Section): Surface: 1880' FSL, 2508' FEL, Sec. 35, T11N, R10E, UM ' 7. Date TD Reached: January 26, 2006 / 14. Well Name and Number: 1J-166L1 ~ At Top Productive Horizon: 1595' FNL, 785' FWL, Sec. 35, T11 N, R10E UM 8. KB Elevation (ft): 2g' RKg 15. Field/Pool(s): Kuparuk River Field Total Depth: 675' FSL, 945' FWL, Sec. 23, T11 N, R10E, UM 9. Plug Back Depth (MD + TVD): 12907' MD / 3590' TVD West Sak Oil Pool .- 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558703 ~ y- 5945692 ' Zone- 4 10. Total Depth (MD + TVD): , 12952' MD / 3593' TVD ~ 16. Property Designation: ADL 25661 & 25650 - TPI: x- 556693 Y- 5947481 Zone- 4 Total Depth: x- 556793 - 5955031 Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 471 & 468 18. Directional Survey: Yes ^/ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 2368' MD 21. Logs Run: T~ W stJ S`3$D'rn.,~ i .3 li~T/D GR/Res, Dens/Neu ~ ~'~`~' °~ 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE CEMENTING RECORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 20" x 34" 62.58# H-40 28' 108' 28' 108' 42" 367 sx AS 1 10.75" 45.5# L-80 28' 2368' 28' 2194' 13.5" 460 sx Class G, 166 sx LiteCRETE 7-5/8" 29.7# L-80 28' 6356' 28' 3650' 9-7/8" 47o sx LiteCRETE 4.5" 12.6# L-80 5377' 12909' 3495' 3592' 6.75" slotted liner 23. Pertorations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore 4085' 5480' slotted liner from 5409'-8177', 8426'-10100', 10905'-12416', 12571'-12878' MD ' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a P8, PRODUCTION TEST Date First Production March 26, 2006 Method of Operation (Flowing, gas lift, etc.) Gas Lift Oil -shares production with 1J-166 and 1J-166L2 Date of Test 4/5/2006 Hours Tested 14 hours Production for Test Period --> OIL-BBL 2425 GAS-MCF 3054 WATER-BBL 0 CHOKE SIZE 21 % (iAS-OIL RATIO 1303 Flow Tubing press. 520 psi Casing Pressure 1009 Calculated 24-Hour Rate -> OIL-BBL 4104 GAS-MCF 5347 WATER-BBL 1 OIL GRAVITY -API (corr) not available P7, CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~~~ APf~ ~ ~ 2006 =. ", NONE ;`. ?._~ ~/-off /~~_1.~ ~ Form 10-407 Revised 1212003 CONTINUED ON REVERSE a~~~~_ 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". 1 J-166L1 Top West Sak B Sand 5375' 3495' Base West Sak B sand 12952' 3591' N/A 1 J-166L1 PB1 TD 9617' 3542' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed Name..,,,__,_ Rand oma Title: Greater Kuoaruk Area Drilling Team Leader ~ 7 ~ ~y ~ ~' ~ - - --P.i34ne Z_~S 6 "Z ~ d Date ~ Signature ~~ 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: 1 J-166 Common Well Name: 1 J-166 Event Name: ROT -DRILLING Start: 1/7/2006 Contractor Name: n1334@ppco.com Rig Release: 2/11/2006 Rig Name: Doyon 141 Rig Number: Date From - To Hours. Code ~ Sub Code Phase 1/7/2006 12:00 - 14:15 2.25 MOVE MOVE MOVE 14:15 - 16:15 2.00 MOVE MOVE MOVE 16:15 - 20:15 4.00 MOVE POSN MOVE 20:15 - 00:00 1 /8/2006 00:00 - 02:45 02:45 - 07:00 07:00 - 07:30 3.751 MOVE ~ MOB MOVE 2.751 WELCTLI NUND I RIGUP 4.251 DRILL I PULD I RIGUP 0.501 WELCTu BOPE ~ RIGUP 07:30 - 08:00 0.50 DRILL PULD RIGUP 08:00 - 09:00 1.00 DRILL PULD SURFAC 09:00 - 09:30 0.50 DRILL OTHR SURFAC 09:30 - 09:45 0.25 DRILL DRLG SURFAC 09:45 - 12:00 2.25 DRILL DRLG SURFAC 12:00 - 13:00 I 1.00 DRILL DRLG I SURFAC 13:00 - 13:30 0.50 DRILL TRIP SURFAC 13:30 - 15:30 2.00 DRILL PULD SURFAC 15:30 - 16:15 0.75 DRILL DRLG SURFAC 16:15 - 19:45 3.501 RIGMNTI RGRP ~ SURFAC 19:45 - 00:00 4.251 DRILL I DRLG SURFAC 1 /9/2006 ~ 00:00 - 08:15 ~ 8.251 DRILL ~ DRLG ~ SURFAC Page 1 of 25 j Spud Date: 1/8/2006 End: 2/11 /2006 Group: Description of Operations PJSM with crew & Peak Truck drivers. Discuss Safety issues and procedure for rig move. Move Pipeshed modules, Rockwasher, Boilers, Motors and Pit Modules to other side of Pad. Move Sub base from 1 J-101 to spot over well 1 J-166. Spot Pipeshed modules, Rockwasher, Boilers, Motors and Pit Modules to Rig sub base. Prepare rig for Acceptance. Install all water, steam, hydraulic and air lines. Continue work on Rig Acceptance checklist. Spot pipe shed tioga, berm & trim herculite liner on rockwasher. Apply steam, glycol & air to lines. Set up pipe skate. Rig up mud pump lines, and install all drain plugs in centifugal pumps. Rig Accepted @ 0000 HRS.1/8/2006 Nipple up Diverter system, & Riser. Continue Load pits with water & mix spud mud. Load pipe shed with 5" DP, and HWDP. Strap same. PJSM with crew. Discuss aSafety issues & procedure to PU 5" Drill Pipe. Pick up 29 joints of 5" HWDP and Drilling Jars, Rack back in derrick. Pick up 45 Joints of 5" DP, and rack back in derrick. Pick up 1 stand of 8" Non Mag flex drill Collars. Pick up 1 stand of 5" DP. Perform Diverter Function test. AOGCC rep Chuck Sheave waived the witness of Diverter Fuction Test. No leaks. Pull all tools to rig floor for BHA #1. Held PJSM. Make up BHA. Make up 13 1/2" Hughes MXC1 bit w/ 3 x 20's & 1 x 13 Jets (1.0'), 8" SperryDrill Lobe 415 -5.3 Stage Motor (28.71'), 8" Integral Blade stabilizer (5.57'), and a Bottle neck Crossover sub (2.68'). Make up 1 stand of 5" HWDP. 6 1/4" Jar Hrs to start = 87.10 Flood Conductor and fill all lines. Inspect for leaks. Test mud line to 3000 PSI. Observed NO leaks. Begin drilling ICE from 85' to 108'. Spud well and drill from 108' - 151' (43'). ART = 1.57 HRS. PU WT = 50K, SO WT = 50K, ROT WT = 46K JAR HRS Total = 88.67. Bit HRS Total = 1.57. Continue drill from 151' - 215' MD'(68'). TVD = 219' ART = 1.29 HRS. PU WT = 44K, SO WT = 48K, ROT WT = 46K. Torque = 1 K. Pump out of hole from 219' - 32' (187'). 100 SPM - 424 GPM - 350 PSI. Hang off Sheave & line in derrick for GYRO. RU GYRO E-Line unit. Continue make up BHA. Make up 8" Non-mag Crossover sub (1.65'), 8" Non-Mag Pressure drop sub (1.63'), 8" MPT w/ DIR (25.06'), 8" NON-Mag float sub (2.42'), 8" Non-Mag UBHO Sub (2.94'), 3 - Non-Mag Flex Drill Collars (92.77'), and 5" HWDP back to 215'. Orient MWD & UBHO Sub. Continue Drilling 13 1/2" Surface hole from 215' - 252' (37'). ADT =.67 HRS. TVD = 252'. PU WT = 44K, SO WT = 48K, ROT WT = 46K, with torque at 1 K. Observe failed Saver SUb on Top Drive. POOH from 252' - 32' (220'). Blow down all lines, and Top Drive. Change out & inspect top drive saver sub. Observed Spacing on pipe grabber, grabbing in wrong position and damaging saver sub & top 2 joints on 5" HWDP stands. Breakout & lay down top 2 joints. Replace same. Correct the Pipe Tally. Trip back in hole and continue driling from 252' - 528' (276'). ADT = 5.03 HRS. PU WT = 58K, SO WT = 66K, ROT WT = 64K. Torque on Bottom = 1.5K, Torque off bottom = 1 K. Total Jar Hrs = 93.70. Total Bit Hrs = 6.60. Pumps @ #1 - #2, 66 SPM each @ 560 GPM's, 550 PSI. Continue driling from 528' - 1087' (559'). Run GYRO survey after each ConocoPhillips Alaska Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Page 2 of 25 Operations Summary Report 1 J-166 1 J-166 ROT -DRILLING n1334@ppco.com Doyon 141 Date From - To Hours Code Code Phase 1 /9/2006 100:00 - 08:15 08:15 - 09:00 09:00 - 12:00 8.251 DRILL DRLG SURFAC 0.75 RIGMNT RGRP SURFAC 3.00 DRILL DRLG SURFAC 12:00 - 13:15 1.25 ~ DRILL ~ DRLG ~ SURFAC 13:15 - 13:45 0.50 RIGMNT RGRP SURFAC 13:45 - 20:00 6.25 DRILL DRLG SURFAC 20:00 - 00:00 4.00 DRILL ~ CIRC ~ SURFAC 1/10/2006 00:00 - 01:00 ~ 1.00 ~ DRILL ~ TRIP ~ SURFAC 01:00 - 01:45 0.75 DRILL PULD SURFAC 01:45 - 02:15 0.50 DRILL PULD SURFAC 02:15 - 03:00 0.75 DRILL PULD SURFAC 03:00 - 03:30 0.50 DRILL PULD SURFAC 03:30 - 05:00 1.50 CASE RURD SURFAC 05:00 - 08:15 3.251 CASE RUNC ~ SURFAC 08:15 - 08:30 0.251 CASE ~ RUNC ~ SURFAC Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations stand to confirm Close Approach issues. ADT = 6.14, ART = 3.58 HRS, AST = 2.66 HRS. PU WT = 85K, SO WT = 91 K, ROT WT = 90K. Torque on Bottom = 2-4K, Torque off bottom = 1 K. Pumps @ 132 SPM - 1900 PSI, 560 GPM's. Mud WT = 9.1 PPG, Visc @ 250-300, YP = 42 MAX Gas = 23 BTU. WOB = 10-38K. Release GYRO Hand & E-Line unit @ 0630 HRS. Good MWD Surveys. Repair Conveyor Belts in pits. Adjust Linkage. Continue driling from 1087' - 1343' (256'). ADT = 1.99, ART = .5 HRS, AST = 1.49 HRS. PU WT = 90K, SO WT = 94K, ROT WT = 94K. Torque on Bottom = 4-5K, Torque off bottom = 2-3K. Total Jar Hrs = 100.22. Total Bit Hrs = 13.14. Pumps @ 156 SPM - 1980 PSI, 560 GPM's. Mud WT = 9.1 PPG, Visc @ 250-300, YP = 42 MAX Gas = 23 BTU. WOB = 10-38K. Continue driling from 1343' - 1517' (174'). 1474' TVD. ADT = 1.07, ART _ .40 HRS, AST = .43 HRS. PU WT = 95K, SO WT = 94K, ROT WT = 96K. Torque on Bottom = 4-5K, Torque off bottom = 2-3K. Pumps @ 156 SPM - 1980 PSI, 560 GPM's. Mud WT = 9.1 PPG, Visc @ 250-300, YP = 42 MAX Gas = 86 BTU. WOB = 10-38K. Pull back to 1453'. Reciprocate & rotate drill string while work on drag chain in pits. Replace motor. Continue driling from 1517' - 2378' MD (861'). 2201.9' TVD. ADT = 4.78, ART = 2.79 HRS, AST = 2.23 HRS. PU WT = 110K, SO WT = 96K, ROT WT = 105K. Torque on Bottom = 4-5K, Torque off bottom = 3-4K. Observed Hydrates up to 3000 BTU's @ 2035' MD. Total Jar Hrs = 106.07. Total Bit Hrs = 18.99. Pumps @ 1980 PSI, 640 GPM's. Mud WT = 9.3 PPG, Visc @ 250-275, YP = 38. WOB = 5-25K. Last survey @ 2378' MD, 2201.9 TVD, 35 Deg INC, 266.73 Deg AZ. Circulate bottoms up 3 times @ 176 SPM - 750 GPM's, 2500 PSI. RPM's = 70 with 4K torque. BROOH from 2378' - 1077' (1301') at drilling rate. Pull to HWDP and lay down 13 1/2" Ghost Reamer. Continue POOH, pumping at a lower rate of 600 GPM's and observe hole unloading and continued to clean up each stand. Pull from 1071' - 104' (967'). PUWT = 85K, SO WT = 84K, 120 SPM- 600 GPM's - 1950 PSI. Breakout & Lay down 3 joints of Non Mag Drill Collars (92.77'), UBHO sub (2.94'), and 8" Float sub (2.42'). Plug in and download MWD assembly. Continue breakout & lay down remaining BHA. Lay down 13 1/2" Hughes MXC1 bit w/ 3 x 20's & 1 x 13 Jets (1.0'), 8" SperryDrill Lobe 4/5 -5.3 Stage Motor (28.71'), 8" Integral Blade stabilizer (5.57'), 8" Non-mag Crossover sub (1.65'), 8" Non-Mag Pressure drop sub (1.63'), 8" MPT w/ DIR (25.06'), Inspect & Gauge 13 1/2" bit to 2 / 2 ! BT /ALL / E/I/WT/TD. Clean & Clear rig floor area. Send tools outside. PJSM with crew. Discuss Safety issues and procedure for rigging up casing equipment, and running casing. Rig up all equipment to run 10 3/4" surface casing string. Make up shoe joint, and Float Collar joints. Check floats. OK. Continue RIH picking up 58 total joints of 10 3/4" casing installing Bowspring centralizers as per detail to 2348'. Make up torque = 10,000 FT /LBs. Observe hole taking proper hole fill and no issues in OH. Total centralizers run = 21. Total Stop Collars =3. Make up 10 3/4" x 18 1/8" Vetco Gray casing hanger and landing joint rnrneo: zriarzuuo ic~a:ia rm ConocoPhillips Alaska Page 3 of 25 E Operations Summary Report Legal Well Name: 1 J-166 Common W ell Name: 1 J-166 Spud Date: 1 /8/2006 Event Nam e: ROT -D RILLING Start: 1/7/2006 End: 2/11/2006 Contractor Name: n 1334@ ppco.co m Rig Release: 2/11/2006 Group: Rig Name: Doyon 1 41 Rig Number: Date From. - To Hours Code Code i Phase Description of Operations 1/10/2006 08:15 - 08:30 0.25 CASE RUNC SURFAC as per Vetco Gray rep. RIH, land casing in hanger, verifying good set. RKB = 30.11' 08:30 - 09:15 0.75 CASE CIRC SURFAC Circulate 1 bottoms up with Franks fill up tool while recirocating casing 20'. UP WT = 127K, SO WT = 97K, @ 6 BPM - 350 PSI. 09:15 - 09:45 0.50 CEMEN RURD SURFAC Breakout & lay down Franks fill up tool. Load plugs into Cement Head. Make up crossover and Cement head & all lines. 09:45 - 11:30 1.75 CEMEN CIRC SURFAC Continue Circulate & condition mud. Pre job properties - 9.6 PPG, Viscosity = 225, PV = 41, YP = 62, Gels @ 17 / 32. Properties of mud for cement job = 9.2 PPG, Viscosity = 42, PV = 15, YP = 7, Gels @ 2 / 3. Circulating @ 6 BPM - 350 PSI. Total Circulation time = 3.0 HRS. 11:30 - 12:00 0.50 CEMEN PUMP SURFAC Held PJSM with crew & Dowell. Designate a spill champion. With Dowell, pump 10 BBLS of CW 100. Pressure test lines to 3500 PSI. Good test. 12:00 - 14:15 2.25 CEMEN PUMP SURFAC Continue pumped an additional 40 bbls of CW 100 (50 bbls total), Followed by 50 bbls of 10.5 ppg mudpush w/ red dye, dropped btm ', plug, began mixing and pumping Arcticset lead slurry, Pumped 376.0 bbls (460 sxs) of lead cement at 10.7 ppg and 4.45 yield with additives, ave 6.6 bpm at 275 psi, Followed with 75 bbls (175 sxs) of DeepCrete tail cmt at 12.0 ppg and 2.47 yield with add., ave 4.8 bpm at 230 psi, ', shut down and dropped top plug, Kick plug out with 20 bbls fresh water, Reciprocated casing 10' to 15' until 150 bbls cement around shoe then pipe became tight and landed on hanger, Up 135K, Dn 80K..Turn over to rig and displace cement w/ 220 bbls (Total 199 bbls to bump) of 9.2 ppg mud, Displaced cement at 7.0 bpm, Initial pump pressure 280 psi, max pressure at 7.0 bpm 320 psi, Observed red dye at shakers after pumping 135 bbls mud, Slowed rate down to 3 bpm @ 280 psi 10 bbls prior to bumping plug, Bumped plug w/ 1200 psi, Held 10 min, Check floats- OK, CIP @ 14:00 hrs 1/1012006, Had full returns through out job with 63 bbls 10.7 ppg cement to surface, Shoe @ 2,368.38', TVD = 2193.66. Float collar @ 2,282.73'. Test Float Equipment. Floats held. 14:15 - 16:30 2.25 CEMEN RURD SURFAC Flush Stack & Lines. Rig down Cement head & lines. Back out & lay down Landing joint. 16:30 - 18:30 2.00 WELCT NUND SURFAC Nipple down Diverter stack and Riser. Lay down XO for Diverter & Conductor. Lay down Knife Valve. Position all equipment in rear of cellar for crane pick & removal. Pull all Diverter stack equipment from rear of cellar using crane. Move & Set wellhead equipment in cellar. 18:30 - 20:45 2.25 WELCT NUND SURFAC Nipple up Multi-bowl wellhead as per Vetco Gray rep. Test same to 5000 PSI - 10 minutes. 20:45 - 23:30 2.75 WELCT NUND SURFAC Nipple up BOP stack & all lines. Change out saver sub on Top Drive, from 4 1/2 IF to 4" XT39, grabbers and bell guide. 23:30 - 00:00 0.50 WELCT BOPE SURFAC PJSM, Discuss safety issues and procedures. Rig up equipment to test BOP's. 1/11/2006 00:00 - 06:15 6.25 WELCT BOPE SURFAC PJSM - Dicuss testing BOP's & Safety Issues. Perform BOP test. Test 7 5/8" Lower rams, & Annular with 7 5/8" test joint. Test 6"x 3 1/2" VBR's in top set, and Annular with 5" test joint. Continue test 5" Dart Valve, Floor Valve, 4" Floor & Dart valves, and 3 1/2" x 6" VBR's with 4" test joint. Test HCR & Choke, and manual valves. Test Choke manifold valves #1, #12, #13, #14. Upper IBOP, Choke Manifold valves # 9, #11. Test Lower IBOP & choke manifold valves # 5, #8, #10. All test to 250 PSI -low, 3500 PSI High. AOGCC rep, Lou Grimaldi waived witness of test at 2000 HRS, 1/10/2006. Test Dart & Floor valve for 4" DP, Choke Nnnted: znsizoos ~z:zana rnn ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 J-166 Page 4 of 25 Common Well Name: 1J-166 Spud Date: 1/8/2006 Event Name: ROT -DRILLING Start: 1/7/2006 End: 2/11/2006 Contractor Name: n1334@ppco.com Rig Release: 2/11/2006 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Code Phase 1/11/2006 00:00 - 06:15 6.25 WELCT BOPE SURFAC 06:15 - 07:00 0.75 WELCT BOPE SURFAC 07:00 - 07:45 0.75 DRILL PULD SURFAC 07:45 - 09:45 2.00 DRILL PULD SURFAC 09:45 - 10:45 1.00 DRILL PULD SURFAC 10:45 - 12:00 1.25 DRILL PULD SURFAC 12:00 - 16:00 4.00 DRILL PULD SURFAC 16:00 - 18:15 18:15 - 19:15 19:15 - 20:30 20:30 - 21:00 21:00 - 22:00 22:00 - 23:15 23:15 - 00:00 1/12/2006 00:00 - 00:30 2.251 DRILL I PULD I SURFAC 1.00 DRILL PULD SURFAC 1.25 DRILL TRIP SURFAC 0.50 DRILL CIRC SURFAC 1.00 CASE DEOT SURFAC 1.25 CEMEN DSHO SURFAC 0.75 DRILL CIRC SURFAC 0.50 DRILL LOT SURFAC 00:30 - 12:00 11.501 DRILL DRLG INTRM1 Description of Operations manifold valves # 4, #5, #7 & #2. Test HCR's Choke & Manual valves, Annular. Perform Koomey test. System Pressure = 3000 PSI, Pressure after close = 1900 PSI. First 200 PSI attained in 42 secs, and full pressure attained in 3 min. AVG pressure in Nitrogen bottles = 2200 PSI. Test Blind rams, Choke manifold valves #3, & #4. Install Wear bushing. RILDS. PJSM with crew. Discuss pick up procedure & safety issues. Rig up Short bales on Top Drive, hang elevators. Pick up 63 jnts of 4" XT39 Slick Drill pipe running in hole to 2000'. POOH, rack back 21 stands n Derrick. Pick up 23 joints of 4" XT39 Slick Drill pipe running in hole to 731'. Continue pick up 40 more joint of 4" XT39 Slick DP to 2000'. 63 joints total. POOH rack back 21 stands in derrick for a total of 42 stands of Slick 4" DP. RIH with 21 joints of 4" HWDP, and POOH racking back 7 stands. PJSM. discuss safety issues and procedure to MU BHA. Make up BHA #2. 9 7/8" Hughes MX-CX1 bit with 3 x 20, 1 x 12 jets (1.0') TFA = 1.031 SO. IN., 7" Sperry Drill Lobe 7/8 - 6.0 stage (25.35'), 6 3/4" Float sub (2.49'), 6 3/4" Integral Blade Stabilizer (5.61'), 6 3!4" DM Collar (9.02'), 6 3/4" Gamma/Res/PWD (28.08'), 6 3/4" TM Collar (9.83'). Plug in and Up load MWD assembly. Continue MU 3 - 6 1!2" NonMAg Flex Drill Collars (93.09'), 4 - 5" HWDP (121.72'), 6 1/4" Drilling Jars w/ 106.09 HRS (30.78'), 10 - 5" HWDP (306.69'). Total BHA = 633.66' NOTE: Install Corrosion Ring in top joint of 5" HWDP Serial #19936 RIH from Derrick with 5 stands of 5" HWDP. POOH, breakout & lay down 15 joints of 5" HWDP not needed for this assembly. Trip in hole with 3 stands of 5" Slick DP, Make up 9 7/8" Ghost Reamer (5.08'), and 12 more stands of 5" DP. Crossover to 4" Dp and RIH with 4" DP to 2216'. Perform Shallow pulse test on MWD assembly. Good Test @ 115 SPM -487 GPM -1250 PSI. Continue TIH to tag firm Cement @ 2275' DPM. Circulate & condition mud at 115 SPM - 487 GPM"s - 1250 PSI. PU WT = 100k, SO WT = 82K, ROT WT = 90K. Torque @ 3.5K. Pull 1 stand back to 2211'. Mud wt = 9.0 PPG. Rig up and flush lines to ensure no air in lines. Test 10 3/4" Casing to 3000 PSI for 30 Minutes. Record on chart. Good test. Bleed & blow down lines. RD test equipment. RIH with 1 stand, MU Top Drive & drill cement & float equipment from 2275' - 2400' (22' of new hole). FC @ 2284', & FS @ 2368'. ADT = .23 HRS. PU WT = 100k, SO WT = 82K, ROT WT = 90K. Torque = 4K on bottom, 3.5K off bottom. Mud wt = 9.0 PPG, WOB = 3-10K, Pumps at 107 SPM - 454 GPM - 1100 PSI. Displace well with 9.0 PPG conditioned mud @ 107 SPM - 454 GPM's - 1100 PSI, checking mud properties until same in & out for LOT test. Mud wt = 9.0 PPG, 10 sec Gels = 17. Rig up & perform LOT to 15.3 PPG EMW. Mud wt = 9.0 PPG, 10 sec Gels = 17. Observe pressure breakover @ 724 PSI @ 3 BBLS pumped. 10 Minute shut in, pressure bled from 650 psi - 480 PSI. SHoe depth = 2368' MD, 2193' TVD. Directional drill 9 7/8" Intermediate hole from 2400' - 3895' (1495') MD. TVD = 3057'. ADT = 7.79 HRS, ART = 3.76 HRS, AST = 4.03 HRS. PU WT = 112K, SO WT = 80K, ROT WT = 90K. Torque on btm = 4-7K, Off bottom = 3-6K. Pumps - 600 GPM's - 2075 PSI. RPM's = 80. WOB = Nnnrea: znsizuuti lZ Z`Jatl YM ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: (Contractor Name: ;Rig Name: Date From - To 1 J-166 1 J-166 ROT -DRILLING n 1334@ppco. com Doyon141 Hours Code Code Phase - -- 1/12/2006 00:30 - 12;00 11.50 DRILL DRLG INTRM1 12:00 - 00:00 ~ 12.001 DRILL I DRLG ~ INTRM1 1/13/2006 100:00 - 12:00 I 12.001 DRILL ~ DRLG ~ INTRM1 12:00 - 13:45 I 1.751 DRILL I DRLG I INTRM1 13:45 - 14:45 I 1.001 DRILL CIRC INTRM1 14:45 - 17:15 I 2.50 ~ DRILL ~ WIPR ~ INTRM1 17:15 - 19:30 I 2.251 DRILL (TRIP I INTRM1 19:30 - 22:00 2.501 DRILL (TRIP I INTRM1 22:00 - 22:15 0.25 DRILL PULD INTRM1 22:15 - 23:00 0.75 DRILL PULD INTRM1 23:00 - 00:00 1.00 DRILL PULD INTRM1 Page 5 of 25 Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations 5-30K. Total Bit HRS = 8.02 HRS. Total Jar HRS = 114.11 Mud Wt = 9.0 PPG, Visc = 75,YP = 27, Gels @ 12 / 21. Max gas units = 49 BTU's, ECD =10.14 PPG. Surrey @ 3668' MD, 2970 TVD, INC = 67.15 Deg, AZ = 317.80 Deg. Obtain SPR's at 3709' MD, 2984' TVD Pump #1 , 25 SPM -240 PSI, 35 SPM - 300 PSI. Pump #2, 25 SPM -250 PSI, 35 SPM - 320 PSI. Continue Directional drill 9 7/8" Intermediate hole from 3895' - 5125' (1230') MD. TVD = 3440'. ADT = 8.35 HRS, ART = 3.28 HRS, AST = 5.7 HRS. PU WT = 115K, SO WT = 76K, ROT WT = 90K. Torque on btm = 5-7K, Off bottom = 5-7K. Pumps - 615 GPM's - 2400 PSI. RPM's = 75. WOB = 15-35K. Total Bit HRS = 16.37 HRS. Total Jar HRS = 122.46 Mud Wt = 9.1 PPG, Visc = 59,YP = 29, Gels @ 14 / 22. Max gas units = 105 BTU's, ECD =10.33 PPG. Survey @ 5067' MD, 3428 TVD, INC = 78.03 Deg, AZ = 1.76 Deg. Obtain SPR's at 4736' MD, 3352' TVD Pump #1 , 25 SPM -270 PSI, 35 SPM - 350 PSI. Pump #2, 25 SPM -270 PSI, 35 SPM - 340 PSI. Pump Hi Visc weighted sweep @ 3895' MD, & 5000' MD observing 20% increase in cuttings at shakers. Continue Directional drill 9 7/8" Intermediate hole from 5125' - 6195' (1070') MD. TVD = 3627'. ADT = 8.29 HRS, ART = 6.95 HRS, AST = 1.34 HRS. PU WT = 123K, SO WT = 73K, ROT WT = 88K. Torque on btm = 7-8K, Off bottom = 5-8K. Pumps - 600 GPM's - 2500 PSI. RPM's = 85. WOB = 10-25K. Total Bit HRS = 24.49 HRS. Total Jar HRS = 130.75 Mud Wt = 9.2 PPG, Visc = 54,YP = 25, Gels @ 12125. Max gas units = 189 BTU's, ECD =10.38 PPG. Survey @ 6153' MD, 3621 TVD, INC = 81.48 Deg, AZ = 2.28 Deg. Obtain SPR's at 5764' MD, 3559' TVD Pump #1 , 25 SPM -270 PSI, 35 SPM - 350 PSI. Pump #2, 25 SPM -260 PSI, 35 SPM - 340 PSI. Continue Directional drill 9 7/8" Intermediate hole from 6195' - 6355' (160') MD. TVD = 3650'. ART = 1.13 HRS. PU WT = 125K, SO WT = 76K, ROT WT = 90K. Torque on btm = 7-8K, Off bottom = 5-6K. Pumps - 600 GPM's - 2550 PSI. RPM's = 80. WOB = 10-25K. Total Bit HRS = 25.33 HRS. Total Jar HRS = 131.88 Mud Wt = 9.25 PPG, Visc = 54,YP = 26, Gels @ 12 / 17. Max gas units = 206 BTU's, ECD =10.50 PPG. Survey @ 6312' MD, 3644 TVD, INC = 82.47 Deg, AZ = .45 Deg. Obtain SPR's at 5764' MD, 3559' TVD Pump #1 , 25 SPM -270 PSI, 35 SPM - 350 PSI. Pump #2, 25 SPM -260 PSI, 35 SPM - 340 PSI. Pump Weighted Hi Visc sweep @ 6280'. Observe 5% increase in cuttings at shakers. Circulate bottoms up 3 times @ 600 GPM -2550 PSI. Reciprocate & rotate drill string. BROOH from 6355' - 4739' (1616'). Pull last 2 stands @ 10' /minute as to get another bottoms up and clean hole. Observed hole taking proper displacement. Monitor well -static. Continue POOH on elevators 5 more stands,with hole taking proper fill. Mix & pump dry job. Continue POOH on elevators to 2030'. (2709'). Shoe @ 2368' ,Monitor well -static. Change out elevators, & heads in Iron Roughneck. Continue POOH laying down 45 joints of 5" Drill pipe, 24 joints of 5" HWDP, and drilling jars. Breakout & lay down 3 - 8" NonMag Flex Drill Collars. Plug in and download MWD assembly. Pull up to breakout bit, and drain mud motor. Breakout & lay down Printed: vl aizoos 12:29:18 PM ConocoPhillips Alaska Page 6 of 25 -....Operations Summary Report Legal Well Name: 1 J-166 Common W ell Name: 1 J-166 Spud Date: 1/8/2006 Event Nam e: ROT -D RILLING Start: 1/7/2006 End: 2/11/2006 Contractor Name: n1334@ ppco.co m Rig Release: 2/11/2006 Group: Rig Name: Doyon 1 41 Rig Number: Date From - To Hours Code Code Phase Description of Operations 1!13/2006 23:00 - 00:00 1.00 DRILL PULD INTRM1 MWD TM -HOC. 1/14/2006 00:00 - 00:30 0.50 DRILL PULD INTRM1 Continue breakout & lay down remaining BHA. Inspect & grade bit. Clean & clear floor area, send tools outside. Bit grade = 1 / 2 / WT / A / E/ER/TD. 00:30 - 01:00 0.50 CASE OTHR INTRMI BOLDS, pull wear bushing. 01:00 - 02:45 1.75 CASE RURD INTRM1 PJSM with crew. Discuss safety issues and procedure for rigging up casing equipment. Rig up all 7 5/8" casing equipment. Double check order of casing in shed. 02:45 - 07:30 4.75 CASE RUNC INTRM1 Pick up & run 7 5/8" L80 29.7# casing to 2334'. Make up torque = 8K ft/Ibs. Observe casing taking proper fill. 07:30 - 08:00 0.50 CASE CIRC INTRM1 At shoe, circulate bottoms up at 5 BPM -300 PSI, through Franks Fill up tool. PU WT = 100K, SO WT = 74K. Monitor well -static. 08:00 - 09:15 1.25 CASE RUNC INTRM1 Continue run 7 5/8" casing from 2334' - 3477' (1143'). 09:15 - 09:45 0.50 CASE RUNC INTRM1 Continue run 7 5/8" casing, run out of downweight, Circulate @ 4 BPM - 470 PSI, slacking off washing down 2 joints until observing hole cleansing up. 09:45 - 12:00 2.25 CASE RUNC INTRM1 Continue run 7 5/8" casing from 3564' - 5779' (2215'). Crew Change 12:00 - 12:45 0.75 CASE RUNC INTRMI Continue run 7 5/8" casing from 5779' - 6355' (576'). 12:45 - 13:30 0.75 CASE CIRC INTRM1 Circulate bottoms up with Franks fill up tool @ 6.5 BPM - 600 PSI. PU WT = 170K, SO WT = 87K. Reciprocate casing while circulating approximately 25'. 13:30 - 14:00 0.50 CEMEN PULD INTRM1 Breakout & lay down Franks fill up tool. Install Crossover and make up cement head with plugs loaded. 14:00 - 15:45 1.75 CEMEN CIRC INTRM1 Continue circulate & condition mud with cement head @ 7 BPM - 850 PSI. PU WT = 170K, SO WT = 87K. Reciprocate casing while circulating approximately 25'. Before conditioned mud = 9.8 PPG, Viscosity = 84, PV = 28, YP = 39, Gels @ 17 / 23. After mud conditioned for cement job .Mud wt = 9.2 PPG, Viscosity = 39, PV =12, 15:45 - 17:30 1.75 CEMEN PUMP INTRM1 Turn Rig over to Dowell lines. Dowell pumped 10 bbls CW 100 at 8.3 ppg at rate of 4.7 bpm @ 230 psi, Pressure tested lines to 3,500 psi, Then pumped 40 add. bbls of CW 100 at rate of 4.5 bpm @ 170 psi, Pumped 50 bbls of MudPush at 11.0 ppg at rate of 4.7 bpm @ 215 psi, Dropped btm plug then pumped 144 bbls, (370 sxs - 25% over caliper) of DeepCrete cmt at 12.5 ppg, 2.25 yield with additives, avg 5.6 bpm at 275 psi, Reciprocated pipe with full returns 15' to 20'. Drop top plug and Dowell kicked top plug out with 10 bbls fresh water, @5 BPM -200 PSI. Rig displaced cement with 8.9 ppg OBM, Bumped plug after pumping 287.5 bbls MOBM (96% pump eff.) 2867 Strokes, avg 6.8 bpm while displacing cmt, Observed lift pressure f/ 500 psi to 800 psi prior to slowing pump rate to 3 bpm, Slowed pump rate to 3 bpm @ 500 psi with 10 bbls left to pump and bumped plug to 1250 psi. CIP at 1730 hrs, 1-14-06. Reciprocated pipe 15' to 20' until MudPUSH at shoe, then recip. 10' until Cmt at shoe, then recip. 10' until last 30 bbls, then recip. 5' until last 10 bbls then stopped pipe, Landed csg with Shoe @ 6350', Float Collar @ 6264', Calc TOC @ 3355', Had full returns thru out job. Well static after shut down. 17:30 - 18:00 0.50 CEMEN PUMP INTRMI Check Float Equipment. Held, no bleed back. Rig down casing equipment. 18:00 - 20:00 2.00 WELCT NUND INTRM1 PJSM with crew. Discuss Safety and procedure to complete 7 5/8" casing run. Nipple down BOP stack and .raise. Set 7 5/8" emergency slips as per Vetco Gray rep, with 75K overpull on casing. 20:00 - 21:00 1.00 WELCT OTHR INTRM1 Suck out all MOBM in 7 5/8" casing down to 40'. Rig up WACHS casing Printed: 2/13/2006 12:29:18 PM ConocoPhillips Alaska .Operations Summary Report Legal Well Name: 1 J-166 Common Well Name: 1 J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Start: 1 /7/2006 Rig Release: 2/11 /2006 Rig Number: Page 7 of 25 Spud Date: 1/8/2006 End: 2/11 /2006 Group: Date From.- To Hours Code :Code Phase Description of Operations 1/14/2006 20:00 - 21:00 1.00 WELCT OTHR INTRM1 cutter. Make beveled cut on 7 5/8" CSG, and dress same. Joint # 148 - length left in well = 38.56'. Cut off piece = 5.02'. POOH, breakout & lay down pups. 21:00 - 21:45 0.75 WELCT OTHR INTRM1 Install 7 5/8" pack-off as per Vetco rep. 21:45 - 22:30 0.75 WELCT NUND INTRM1 Nipple up BOP stack & well head flange. 22:30 - 23:00 0.50 WELCT BOPE INTRM1 Rig up test pump & lines. Test inner & outer seals on packoff, and the flange connection to 5000 PSI - 15 minutes. 23:00 - 23:30 0.50 WELCT OTHR INTRM1 Install wear bushing with landing joint. ID of wear bushing = 9.125". 23:30 - 00:00 0.50 DRILL FIT INTRM1 Rig up lines and test chart for LOT test & infectivity test on the 10 3/4" x 7 5/8" annulus at 2368' MD. 1/15/2006 00:00 - 01:00 1.00 DRILL FIT INTRM1 PJSM. Perform LOT & Infectivity test on the 10 3/4" x 7 5/8" annulus @ 2368'. Test to 13.1 PPG EMW and hold 10 minute shut in test. Record all on chart. Pump 30 BBLS water down annulus @ 3 BPM - 520 PSI. SIMOPS: Install Schlumberger MWD standpipe sensor. 01:00 - 06:00 5.00 DRILL PULD INTRM1 RU & pick up 90 joints of 4" Drill pipe with super sliders on them. Re-position, inspect and re-torque all sliders while run in hole. 06:00 - 07:00 1.00 DRILL PULD INTRM1 POOH racking back 30 stands of 4" DP with super sliders. SIMOPS: Inject 80 more barrels of water down the 10 3/4" x 7 5!8" annulus for flush @ 3 BPM - 510 PSI. Rig up Little Red services, pump 90 bBLS of freeze protect diesel down annulus @ 3 BPM. Shut in annulus. 07:00 - 07:30 0.50 DRILL PULD INTRM1 Clean & clear floor area. 07:30 - 10:30 3.00 DRILL PULD INTRM1 Make up 15 stands of Hybrid Push pipe running in hole. Hybrid = 2 -4 3/4" Drill Collars + 1-4" DP per stand. 10:30 - 12:00 1.50 DRILL PULD INTRM1 Re-position 4" HWDP in Derrick. POOH racking back 15 stands of Hybrid push pipe. Crew change. 12:00 - 12:30 0.50 DRILL PULD INTRM1 PJSM with crew & SWS. Discuss Safey issues and procedure for ~ making up Schlumberger BHA. Pick up 6 3/4" Hycalog RSX711M-A2 bit with 2 x11's, 2 x 12' jets (.58'), 4 3/4" BIAS Unit w! 22 restrictor (2.96'), 4 15/16" Control Collar (10.36'), 5" PD XO (1.17'), 5" Reciever (4.92'), 4 314" Flex XO (2.36'), 4 11/16" Periscope (25.01'), 4 3/4" Impulse MWD assembly (33.87'). Note: Bit = #3 RR1 with starting hours of 66.25 HRS from 1J-101 A Lateral. 12:30 - 12:45 0.25 DRILL PULD INTRM1 Test Power Drive @ Surface with 62 SPM - 220 GPM - 450 PSI. Good. 12:45 - 13:30 0.75 DRILL PULD INTRM1 Continue MU remaining BHA, 5 1/4" Bypass Sub /Float Sub (2.35'), 3 - 4 314" NonMag Flex Drill Collars (92.51'), 4 7/8" XO Sub (1.65'), 4 314" Drilling Jars (28.81') and 2 joints 4" HWDP (60.48'). Total BHA = 357.80' 13:30 - 14:00 0.50 DRILL TRIP INTRM1 Trip in hole with singles 4" DP from pipe shed to 670'. 14:00 - 14:15 0.25 DRILL DEQT INTRM1 Perform Shallow hole pulse test on MWD assembly @ 300 GPM - 1200 PSI. Good test. 14:15 - 18:00 3.75 DRILL TRIP INTRM1 Continue trip in hole from 670' - 6264' (5594'). Tag Float collar @ 6264' DPM. 18:00 - 19:15 1.25 CASE DEQT INTRM1 Pull back to 6245'. Rig up casing test egipment & lines. Test 7 5/8" Casing to 3000 PSI - 30 minutes. Recorded on chart. Good test. Bleed pressures and rig down equipment. 19:15 - 22:15 3.00 CEMEN DSHO INTRM1 Drill out float equipment @ 6264', firm cement to shoe @ 6350', and 21' of new hole to 6376', at 320 GPM - 2225 PSI. Torque @ 3-5K. ART = .28 HRS. PU WT = 97K, SO WT = 70K. 22:15 - 22:45 0.50 DRILL CIRC INTRM1 Circulate Bottoms up @ 321 GPM-s - 2225 PSI, until shakers clean. Mud wt in /out = 8.7+. YP = 18, Gels -18 / 23. Obtai clean hole ECD @ 9.91 PPG. Condition mud for LOT. Blow down Top Drive. Pull 1 stand. 22:45 - 23:45 1.00 DRILL LOT INTRM1 Fill lines & Perform LOT on the 7 5/8" casing shoe @ 6350' MD, 3650 TVD. Test to leak off at 1259 PSI = 15.3 PPG Equivalent Mud Weight. Printed: 2/13/2006 12:29:18 PM ConocoPhillips Alaska Page 8 of 25 Operations Summary Report Legal Well Name: 1 J-166 Common Well Name: 1J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase Spud Date: 1 /8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11!2006 Group: Rig Number: Description of Operations 1/15/2006 122:45 - 23:45 1.001 DRILL I LOT INTRM1 23:45 - 00:00 I 0.251 DRILL I TRIP I PROD ~ 1/16/2006 100:00 - 12:00 I 12.00 ~ DRILL ~ DRLG ~ PROD 12:00 - 00:00 I 12.001 DRILL I DRLG I PROD 1/17/2006 100:00 - 12:00 I 12.001 DRILL I DRLG I PROD 12:00 - 00:00 12.00 DRILL DRLG PROD 1/18/2006 100:00 - 12:00 I 12.001 DRILL I DRLG I PROD Held 10 minute shut in, observe shut in pressure bled from 860 PSI to 712 PSI. Bleed all pressure. Rig down equipment & lines. Pick up 1 stand & TIH back to 6376'. PU WT = 97K, SO WT = 70K, ROT WT = 70K Torque on = 3-7K, Torque off = 5K ECD = 9.91 PPG, Jar HRS = .28, Bit HRs = .28, MAX gas = 25 BTU's. Drill 6 3/4" hole in the A Lateral from 6376' - 7425' (1049'). MD. TVD = ..3656'. ADT = 7.94 HRS,Total ADT = 8.22 HRS. PU WT = 105K, SO WT = 70K, ROT WT = 85K. Torque on/off bottom = 5.5K. Pumps - 345 GPM's - 2500 PSI. RPM's = 160. WOB = 3-5K. Total Bit HRS = 8.23 HRS. Total Jar HRS = 8.22. Mud Wt = 8.75 PPG, Visc = 76,YP = 18, Gels @ 21 / 28. Survey @ 7301' MD, 3656' TVD, 90 Deg INC, .52 Deg AZ. ECD = 10.32 PPG, Max gas = 140 Units. Observed drilling through concretions from 6384' -6400' (16'), 6409'-6414'(5'), 6570'-6586' (16'), 6591'-6600' (9'),6920' - 6937' (17'), 7054' -7058' (4'),7255' - 7263' (8'), and 7400'-7406' (6'). Obtain Slow pump rates @ 7176' MD, 3657 TVD. Pump #1 - 20 SPM - 320 PSI, 30 SPM - 440 PSI. Pump #2 - 20 SPM - 330 PSI, 30 SPM - 450 PSI. Continue Drill 6 3/4" hole in the A Lateral from 7425' - 8478' (1053'). MD. TVD = 3655'. ADT = 7.69 HRS,Total ADT = 15.91 HRS. PU WT = 116K, SO WT = 63K, ROT WT = 82K. Torque on/off bottom = 6-7K. Pumps - 350 GPM's - 2750 PSI. RPM's = 160. WOB = 2-10K. Total Bit HRS = 7.69 HRS. Total Jar HRS = 15.91. Mud Wt = 8.75 PPG, Visc = 68,YP = 18, Gels @ 21 128. Survey @ 8329' MD, 3655' TVD, 90 Deg INC, 1.51 Deg AZ. ECD = 10.35 PPG, Max gas = 92 Units. Observed drilling through concretions from 8021' -8025' (4'), 8415'-8420'(5'), 8473'-8483' (10'). Obtain Slow pump rates @ 8390' MD, 3655 TVD. Pump #1 - 20 SPM - 370 PSI, 30 SPM - 480 PSI. Pump #2 - 20 SPM - 410 PSI, 30 SPM - 500 PSI. Total K-Revs on Super Sliders for the day = 26524 HRS. Drill 6 3/4" hole in the A Lateral from 8478' - 9566' (1088'). MD. ND = 3692'. ADT = 7.91 HRS,Total ADT =23.82 HRS. PU WT = 120K, SO WT = 60K, ROT WT = 85K. Torque on/off bottom = 6.5K. Pumps - 335 GPM's - 2700 PSI. RPM's = 160. WOB = 3-10K. Total Bit HRS =23.82 HRS. Total Jar HRS = 23.82. Mud Wt = 8.75 PPG, Visc = 60,YP = 16, Gels @ 16 / 23. ECD = 10.38 PPG, Max gas = 167 Units. Observed drilling through concretions from 8469' -8485' (16'), 8643'-8658'(15'), 9100'-9110' (10'), 9488'-9502' (14'), 9533' - 9535' (2'). Obtain Slow pump rates @ 9418' MD, 3687 TVD. Pump #1 - 20 SPM - 350 PSI, 30 SPM - 480 PSI. Pumped hi-vis sweep @ 9415' and observed 5% increase in cuttings over the shakers. Continue Drill 6 3/4" hole in the A Lateral from 9566' - 10543' (977'). MD. TVD = 3711'. ADT =7.88 HRS,Total ADT = 31.70 HRS. PU WT = 126K, SO WT = 47K, ROT WT = 82K. Torque on/off bottom = 6K. Pumps - 320 GPM's - 2700 PSI. RPM's = 160. WOB = 3-10K. Total Bit HRS = 31.70 HRS. Total Jar HRS = 31.70. Mud Wt = 8.75 PPG, Visc = 64,YP = 17, Gels @ 19 / 24. ECD = 10.91 PPG, Max gas = 102 Units. Obtain Slow pump rates @ 10353' MD, 3734' TVD. Pump #1 - 25 SPM - 460 PSI, 35 SPM - 630 PSI. Pump #2 - 25 SPM - 470 PSI, 35 SPM - 610 PSI. Drill 6 3/4" hole in the A Lateral from 10543' - 11462' (919') MD. TVD = 3669'. ADT = 8.17HRS,Total ADT =39.87 HRS. PU WT = 135K, SO WT = 49K, ROT WT = 88K. Torque on/off bottom = 7.5K. Pumps - 320 Printed: 2/13/2006 12:29:18 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 J-166 Common Well Name: 1 J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 1/18/2006 00:00 - 12:00 12.00 DRILL DRLG PROD 12:00 - 00:00 I 12.001 DRILL I DRLG I PROD 11/19/2006 100:00 - 03:00 I 3.001 DRILL I DRLG I PROD 03:00 - 07:00 ~ 4.00 ~ DRILL ~ CIRC ~ PROD 07:00 - 08:30 ~ 1.50 ~ DRILL ~ CIRC ~ PROD 08:30 - 12:00 I 3.501 DRILL I TRIP I PROD 12:00 - 13:15 1.25 DRILL TRIP PROD 13:15 - 14:45 1.50 WELLS EORP PROD 14:45 - 17:00 2.25 DRILL TRIP PROD 17:00 - 18:00 1.00 DRILL PULD PROD 18:00 - 20:15 I 2.251 CMPLTNI RURD I CMPLTN 20:15 - 00:00 1 /20/2006 00:00 - 00:15 00:15 - 00:45 3.751 CASE I RUNC I CMPLTN 0.25 CASE SFTY CMPLTN 0.50 CASE RURD CMPLTN 00:45 - 03:30 03:30 - 04:30 04:30 - 05:00 05:00 - 11:00 2.751 CASE I PULR I CMPLTN 1.001 CASE I PULR I CMPLTN 0.50 CASE RURD CMPLTN 6.00 CASE RUNL CMPLTN 11:00 - 12:00 I 1.001 CASE I DEOT I CMPLTN Page 9 of 25 Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations GPM's - 3300 PSI. RPM's = 160. WOB = 3-12K. Total Bit HRS =106.37 HRS. Total Jar HRS =39.87. Mud Wt = 8.75 PPG, Visc = 64 ECD = 10.91 PPG, Max gas = 165 Units. Observed drilling through concretions from 10675-10691' (16'), 11059-11067' (8'), 11093-11103' (10'), 11216-11225' (9'), 11269-11300' (31'). Obtain Slow pump rates @ 11279' MD, 3656' TVD. Pump #1 - 25 SPM - 500 PSI, 35 SPM - 660 PSI. Pump #2 - 25 SPM - 510 PSI, 35 SPM -670 PSI. Continue Drill 6 3/4" hole in the A Lateral from 11462'-12461' (999') MD. TVD = 3705'. ADT =8.12 HRS,Total ADT = 47.99 HRS. PU WT = 155K, SO WT = 50K, ROT WT = 101 K. Torque on/off bottom =5K/8K. Pumps - 315 GPM's - 3500 PSI. RPM's = 160. WOB = 3-10K. Total Bit HRS = 114.5 HRS. Total Jar HRS = 47.99. Mud Wt = 8.75 PPG, Visc = 64 ECD = 11.31 PPG, Max gas = 94 Units. Observed drilling through concretions from 11980-11983' (3'), 11992-11995' (3'), 12051-12065' (14'), 12088-12090' (2'), 12416-12435' (19'). Obtain Slow pump rates @ 12276' MD, 3693' TVD. Pump #1 - 25 SPM - 600 PSI, 35 SPM - 790 PSI. Pump #2 - 25 SPM - 580 PSI, 35 SPM - 780 PSI. Total K-Revs=173,414 Drilled from 12,461' to 12,853' MD / 3,724' TVD. ADT=2.05 TDT=50.04 Jar Hours=50.04 PUW=175K SOW=60K ROT= 110K TQon/off=8K Max Gas=101 Units ECD=11.56 Pumped hi-vis weighted sweep @ 338 gpm, 4100 psi. Pumped total 22188 stks. Final ECD=11.20 Held PJSM for displacement to SFOBM. Displaced well to SFOBM. SPRs, L/D single, dropped 1 7/8" rabbit. SPR#1=25stk/620psi, 35stk/780psi SPR#2=25stk/620psi, 35stk/790psi @ 12,822' MD 3,722' TVD 8.7 MW. POOH from 12,826' to 9,515'. Start PUW=190K SOW=40K End PUW=140K SOW=45K Cont'd to POOH from 9,515' to 6,338'. Serviced TD, slipped and cut 76' drill line. POOH from 6,338' to 357'. LID BHA, rack back 2 stds HWDP w/jars, L/D NMFDCs, MWD, Periscope tool, break bit, UD Powerdrive. Cleared rig floor, R!U csg equip, loaded pipe shed 4 1/2" balnks and slots, Sim-Ops, R/D Schlumberger. RIH w/ 4 1/2" slotted liner. Ran 120 jts to 3739'. PUW=68K SOW=64K Held PJSM and reviewed liner detail. P/U liner pups to rig floor. R/U back-up casing tongs, as others had washed out hyd. valve. Cont'd to run 4.5" liner as per detail. Ran a total of 64 jts blank pipe and 172 jts slotted liner (4.5", L-80 12.6# IBT) with 2 pups. PUW=83K SOW=60K Make up XO Bushing, Casing Seal Bore Ext, Flexlock Liner Hanger, RS Packoff Seal nipple, and HRD ZXP Liner Top PKR, with BOT running tools. Total BHA length of liner assembly = 7359.98'. PU WT = 85K, SO WT = 60K. R/D Doyon casing equip. Continue RIH with Liner on Drill Pipe from7360' - 12840' with no problems. Get PUW=180K SOW=60K. Drop 1 7/16" ball, Position liner w/ shoe Printed: 2/13/2006 12:29:18 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 1 /20/2006 11:00 - 12:00 1 J-166 1 J-166 ROT -DRILLING n 1334@ppco. com Doyon141 Hours .Code Code Phase 1.00 CASE DEOT CMPLTN 12:00 - 14:45 2.75 DRILL TRIP CMPLTN 14:45 - 15:15 0.50 DRILL PULD CMPLTN 15:15 - 15:30 0.25 DRILL RIRD CMPLTN 15:30 - 15:45 0.25 WINDO ULD PROD2 15:45 - 18:30 2.75 WINDO ULD PROD2 18:30 - 21:15 2.75 WINDO RIP PROD2 21:15 - 23:00 1.75 WINDO THR PROD2 23:00 - 00:00 1.00 WINDO RIP PROD2 1/21/2006 00:00 - 00:15 0.25 WINDO ETW PROD2 00:15 - 01:15 1.00 WINDO IRC PROD2 01:15 - 05:45 4.50 WINDO TWP PROD2 05:45 - 07:15 1.50 WINDO TWP PROD2 07:15 - 09:45 2.50 WINDO RIP PROD2 09:45 - 11:00 1.25 WINDO ULD PROD2 11:00 - 12:00 1.00 DRILL OTHR PROD2 12:00 - 13:00 1.00 DRILL OTHR PROD2 13:00 - 14:00 1.00 WELCT BOPE PROD2 14:00 - 15:00 1.00 WELCT BOPE PROD2 15:00 - 19:30 4.50 WELCT BOPE PROD2 i 19:30 - 23:00 3.50 WELCT BOPE PROD2 23:00 - 23:30 0.50 DRILL OTHR PROD2 23:30 - 00:00 0.50 RIGMNT RSRV PROD2 1/22/2006 00:00 - 01:30 1.50 DRILL PULD PROD2 01:30 - 03:00 1.50 DRILL PULD PROD2 03:00 - 03:30 0.50 DRILL PULD PROD2 03:30 - 04:15 0.75 DRILL DEOT PROD2 04:15 - 05:15 I 1.OO DRILL ~ TRIP ~ PROD2 Page 10 of 25 Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations @ 12840' & top of liner @ 5480.02'. Circa ball down w/ 3 BPM and pressure up to set .Set down 55K to set slips as per BOT rep, continue pressure up to 4000 PSI, to complete setting PKR. Bleed pressure, Rig up and pressure test down annulus to test PKR at 1000 PSI - 10 Minutes. Blow down Top Drive and Kill Line. Monitor well -Static. PUW=130K SOW=100K after setting ZXP. Monitored well and POOH. Lay down liner running tools. Clear & clean rig floor. P/U whipstock and associated BHA from beaverslide. P/U and M/U whipstock BHA. TIH from 388' to 4,570'. Shallow tested MWD w/ 80 spm 1150 psi @ 1,789' (good test). MAD passed from 4,570' to 4,725' w/ 80 spm and 2200 psi. TIH from 4,725' to 5,372'. PUW=115K SOW=95K. TIH from 5,372' to 5,480' MD. Orient whipstock @ 5 deg left of high-side and set trip anchor, sheared off bolt w/ 60 K downweight. PUW=125K SOW=90K ROT=109K TQ=3-7K. Held PJSM and displaced well to MOBM @ 80 spm, 2200 psi. SPR#1=25stksl350psi, 35stks/550psi SPR#2=25stksl370psi, 35stks/530psi Milled window from 5,380' to 5,392'. Milled 20' of gauge hole to total depth of 5,422'. Pumped 30 bbl weighted hi-vis sweep and worked mill through window. Rotated through window w/ pumps on 8 times. Repeated sliding 4 more times, sliding w/o pumps 2 times. PUW=120K SOW=90K Monitored well, static. Pumped dry job and POOH from 5,422' to 286'. UD BHA. SIB 2 stds push pipe, UD 2 bumper subs. Plugged in and downloaded MWD. Cont'd to UD BHA including: TM HOC, MWD, DM HOC, NMFS, 1 jt 3.5" HWDP, upper mill (in gauge), lower mill and window mill. Pulled wear bushing, cleaned rig floor, C/O elevators. R/U and flush stack w/ stack washer after milling operations. R/U and begin to test BOPE. Valve #13 on manifold failed along with HCR choke valve. Began to repair equipment. Removed and rebuilt choke valve bonnet assy. on #13. Removed bonnet on HCR choke and C/O seals and seat assy. Tested BOPE w! low pressure test @ 250 psi and high @ 3500 psi. Tested annular, top 3.5"X6" rams, blinds, IBOP, lower IBOP, dart valve, floor valve, manual choke and kill, HCR choke and kill. Choke manifold valves 1-14. Performed accumulator test 3000 psi decreased to 1800 psi with all elements closed (3 min 25 sec recovery time to 3000 psi). Five nitrogen bottles showed avg. pressure of 2100 psi. R/D test equip. Witnessing of test waived by J. Spaulding of AOGCC. Set wear bushing. Inspected saver sub and serviced T/D. M/U BHA. Uploaded MWD tools Cont'd to M/U BHA. Shallow tested MWD @ 453'. Rotated to break-in seals on Geo-Pilot tool w/ 80 spm, 20 rpm, 1200 psi. RIH from 453' to 2,239' MD and filled pipe. Shallow-tested to ensure L~ W ~~ a~ ~O' F'riflt2tl: 2/13/2006 12:Zy:'I S YM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 J-166 Common Well Name: 1 J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code t 1/22/2006 04:15 - 05:15 1.00 DRILL TRIP PROD2 05:15 - 06:45 1.50 DRILL TRIP PROD2 06:45 - 08:45 2.00 DRILL DEOT PROD2 08:45 - 12:00 3.25 DRILL DRLH PROD2 12:00 - 00:00 ~ 12.00 ~ DRILL ~ DRLH ~ PROD2 1/23/2006 ~ 00:00 - 12:00 ~ 12.00 ~ DRILL ~ DRLH ~ PROD2 12:00 - 00:00 ~ 12.00 ~ DRILL ~ DRLH ~ PROD2 1/24/2006 00:00 - 10:30 10.501 DRILL DRLH ~ PROD2 Page 11 of 25 Spud Date: 1 /8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations downlink w/ Geo-Pilot. Cont'd to RIH from 2,239' to 5,322'. Washed down to 5,422' w/ 80 spm @ 2000 psi. Ran through window w/ no problems. Trouble-shot MWD smart tools. Drilled from 5,422' to 5,490' MD / 3,514' TVD ART=ADT=2.8 hrs Jar hrs=52.90 PUW=102K SOW=65K ROT=85K TOon/off=5K ECD=9.71 Calc clean hole ECD=9.75 Max Gas=51 units SPR #1=25stk/340psi, 35stk/500psi SPR #2=25stk/350psi, 35stk/510psi @ 5,490' MD / 3,516' TVD EMW= g.7+ Concretion depths: 5465-5476' (12') Drilled from 5,490' to 6,790' MD ! 3,521' TVD ART=ADT=9.1 hrs Jar hrs=62 PUW=117K SOW=64K ROT=82K TOonloff=5K/5.5K ECD=10.28 Calc clean hole ECD=9.75 Max Gas=48 units SPR#1=25stk/420psi, 35stk/590psi SPR #2=25stk/440psi, 35stk/610psi @ 6,534' MD / 3,510' TVD EMW= g.7+ Concretion depths: 5466-5488' (12'), 5489-5493' (4'), 5531-5534' (3'), 5670-5685' (15'), 5706-5724' (18'), 5787-5788' (1'), 5873-5880' (7'), 5946-5967' (21'), 6564-6567' (3'), 6652-6661' (9'), 6671-6677' (6'). Drill 6 3/4" B Lateral w/ Sperry-Sun GeoPiolt from 6790' - 7793' (1003') MD. ND = 3515'. ADT = 9.6 hrs. PU WT = 116K, SO WT = 60K, ROT WT = 81 K. Torque on/off bottom = 5.5/6.OK. Pumps - 330 GPM's - 2700 PSI. RPM's = 140. WOB = 3-15K. Total Bit HRS =21.5 hrs. Total Jar HRS = 71.6. Mud Wt = 8.75 PPG, Visc = 72, ECD = 10.25 PPG, Max gas = 47 Units. Observed drilling through concretions from 6950'-6960', 7047'-7055', 7062'-7070', 7202'-7204', 7548'-7553', 7589'-7590', 7620'-7630', 7637'-7639', 7640'-7648', 7729', 7746', 7749'-7762', 7776'-7778'. Obtain Slow pump rates @ 7374' MD, 3525' ND. Pump #1 - 25 SPM - 460 PSI, 35 SPM - 650 PSI. Pump #2 - 25 SPM - 440 PSI, 35 SPM -570 PSI. Drill 6 3/4" B Lateral w/ Sperry-Sun GeoPiolt from 7793' - 8723' (930') MD. ND = 3522'. ADT = 9.45 hrs. PU WT = 130K, SO WT = 50K, ROT WT = 82K. Torque on/off bottom = 6.5K. Pumps - 330 GPM's - 2800 PSI. RPM's = 120. WOB = 3-15K. Total Bit HRS =30.95 hrs. Total Jar HRS = 81.05. Mud Wt = 8.70 PPG, Visc = 72, ECD = 10.83 PPG, Max gas = 47 Units. Observed drilling through concretions from 7781'-7795', 7820'-7829', 7970'-7974', 8030'-8032', 8056'-8061', 8445'-8447', 8473'-8478', 8480'-8495', 8541'-8549', 8568'-8573', 8584'-8590', 8599'-8604', 8624'-8629', 8682'-8689'. Obtain Slow pump rates @ 8496' MD, 3527' ND. Pump #1 - 25 SPM - 490 PSI, 35 SPM - 650 PSI. Pump #2 - 25 SPM - 510 PSI, 35 SPM -670 PSI. Pumped 35 bbl Hi-vis weight sweep @ 8483' w/ 10% increase in cuttings. K-REV's 44852 (6 stands on sliders in hole) Drill 6 3/4" B Lateral w/ Sperry-Sun GeoPiolt from 8723' - 9617' (991') MD. TVD = 3541'. ADT = 8.9 hrs. PU WT = 130K, SO WT = 55K, ROT WT = 82K. Torque on/off bottom = 7/6.OK. Pumps - 330 GPM's - 2900 PSI. RPM's = 120. WOB = 5-15K. Total Bit HRS =21.5 hrs. Total Jar HRS = 90.04 Mud Wt = 8.75 PPG, Visc = 79, ECD = 11.19 PPG, Max gas = 457 Units. Observed drilling through concretions from 8727'-8732', 8769'-8773', 8792'-8801', 8849'-8871', 8883'-8895', Printed: 2!13/2006 12:29:18 PM ConocoPhillips Alaska Page 12 of 25 Operations Summary Report Legal Well Name: 1 J-166 Common Well Name: 1J-166 Spud Date: 1/8/2006 Event Name: ROT -DRILLING Start: 1/7/2006 End: 2/11/2006 Contractor Name: n1334@ppco.com Rig Release: 2/11/2006 Group: Rig Name: Doyon 141 Rig Number: Date ' From - To Hours Code !Code Phase Description of Operations 1/24/2006 100:00 - 10:30 I 10.501 DRILL I DRLH 10:30 - 12:00 1.50 DRILL CIRC 12:00 - 12:45 0.75 DRILL CIRC 12:45 - 19:30 6.751 DRILL OTHR 19:30 - 22:00 2.50 DRILL DRLH 22:00 - 00:00 2.00 DRILL DRLH 1/25/2006 00:00 - 08:00 8.00 DRILL DRLH 08:00 - 08:30 0.50 DRILL CIRC 08:30 - 12:00 3.501 DRILL ~ DRLH 12:00 - 00:00 12.00 I DRILL DRLH 1!26/2006 00:00 - 09:45 9.751 DRILL i DRLH PROD2 8904'-8911', 8941'-8955', 8981'-8995', 9078'-9084', 9259'-9260', 9290'-9292'. Obtain Slow pump rates @ 9430' MD, 3537' TVD. Pump #1 - 25 SPM - 600 PSI, 35 SPM - 790 PSI. Pump #2 - 25 SPM - 620 PSI, 35 SPM -800 PSI. PROD2 Wait on geology decision from town. PROD2 Worked pipe from 9527'-9617' while waiting on geology to evaluate log data w/ 84 spm, 2600 psi, 120 rpm, TO off=6K Pulled up to 9340' to begin sidetracking operations. PROD2 Cut groove and trough from 9340' to 9380'. Time drilled to 9389'. Checked for sidetrack, no good. Pulled up to 9383' and cut trough. Time drilled again to 9389'. ADT=3.49 hrs. PROD2 Drilled from 9389' to 9617'. ADT=1.75 hrs. PROD2 Drill 6 3/4" B Lateral w/ Sperry-Sun GeoPiolt from 9617' - 9714' (97') MD. ND = 3566'. ADT = 1.25 hrs. PU WT = 135K, SO WT = 55K, ROT WT = 82K. Torque on/off bottom = 6/7.OK. Pumps - 330 GPM's - 3050 PSI. RPM's = 120. WOB = 4-15K. Total Bit HRS before sidetrack =43.43 hrs. Total Jar HRS = 98.28ud Wt = 8.75 PPG, Visc = 74, ECD = 11.19 PPG, Max gas = 43 Units. Observed drilling through concretions from 9598'-9601', 9615'-9626', 9672'-9686'. Obtain Slow pump rates @ 9430' MD, 3537' TVD. Pump #1 - 25 SPM - 600 PSI, 35 SPM - 790 PSI. Pump #2 - 25 SPM - 620 PSI, 35 SPM -800 PSI. Krevs=187393 PROD2 Drill 6 3/4" B Lateral w! Sperry-Sun GeoPiolt from 9714' - 10458' (744') MD. TVD = 3555'. ART=6.4 PROD2 Wait on geology decision from town. Circa @ 57 spm, 200 gpm, 1600 psi, 100 rpm, TO off=6K. PROD2 Drill 6 3/4" B Lateral w/ Sperry-Sun GeoPiolt from 10458' - 10755' (297') MD/ 3555' TVD. ADT =2.1 hrs. Total Bit HRS =54.93 hrs. Total Jar HRS =106.8 PU WT = 140K, SO WT = OK, ROT WT = 80K. TQ on/off=7/6.5K. Pumps - 330 GPM's - 3250 PSI. RPMs = 120. WOB = 5-15K. Mud Wt = 8.75 PPG, Visc = 79, ECD = 11.76 PPG, Max gas = 54 Units. Observed drilling through concretions from 9760'-9775', 9780'-9784', 9796'-9800', 9804'-9810', 9867'-9870', 9883'-9886', 9897'-9901', 9944'-9952', 10034'-10037', 10053'-10065'. SPR#1=25stk/680psi,35stk/790psi SPR#2=25spm/680psi,35stk/850psi @ 10458 MD/ 3555 TVD PROD2 Drill 6 3/4" B Lateral w/ Sperry-Sun GeoPiolt from 10755' - 11745' (990') MD / 3542' TVD. Pumped a 30 bbl hi-vis weighted sweep @ 10,739' and observed a 10% increase in cuttings across the shakers. Total Bit HRS=63.96. Total Jar HRS =115.81 ADT =9.03 hrs. PU WT = 170K, SO WT = OK, ROT WT = 90K. TQ on/off = 8.5/8 Pumps - 330 GPM's - 3600 PSI. RPM's = 120. WOB = 4-16K. Mud Wt = 8.75 PPG, Visc = 72, ECD = 11.94 PPG, Max gas = 52 Units. Observed drilling through concretions from 10768'-10772', 10804'-10807', 11075'-11076', 11105'-11106', 11110'-11112', 11116'-11120', 11123'-11126', 11136'-11138', 11149'-11157', 11163'-11178', 11185'-11190', 11200'-11208', 11248'-11253', 11263'-11270', 11290'-11294', 11510'-11518', 11521'-11533' SPR#1=25stk/680psi,35stk/850psi SPR#2=25spm/670psi,35stk/850psi @ 11381 MD/ 3533TVD KREVs=335868 PROD2 Drill 6 3/4" B Lateral w/ Sperry-Sun GeoPiolt from 11,745' - 12,524' rrmcea: zn sizuue lZ Yya C YM ConocoPhillips Alaska Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Operations Summary Report 1 J-166 1 J-166 ROT -DRILLING n 1334@ppco. com Doyon141 Date From - To Hours Code Sub Code Phase , 1/26/2006 00:00 - 09:45 9.75 DRILL DRLH PROD2 09:45 - 10:15 0.50 DRILL CIRC PROD2 10:15 - 12:00 1.75 DRILL DRLH PROD2 12:00 - 16:45 I 4.751 DRILL I DRLH I PROD2 16:45 - 18:30 1.75 DRILL CIRC PROD2 18:30 - 18:45 0.25 DRILL OBSV PROD2 18:45 - 00:00 5.25 DRILL WIPR PROD2 1/27/2006 00:00 - 05:15 5.25 DRILL WIPR PROD2 05:15 - 06:15 I 1.001 DRILL I CIRC I PROD2 06:15 - 09:30 3.251 DRILL WIPR PROD2 09:30 - 12:00 ~ 2.50 ~ DRILL ~ WIPR ~ PROD2 12:00 - 12:45 0.75 DRILL WIPR PROD2 12:45 - 15:30 2.75 DRILL CIRC PROD2 15:30 - 16:45 1.25 DRILL CIRC PROD2 16:45 - 17:00 0.25 DRILL OBSV PROD2 17:00 - 21:30 4.50 DRILL TRIP PROD2 21:30 - 21:45 0.25 DRILL OBSV PROD2 Start: 1 /7/2006 Rig Release: 2/11/2006 Rig Number: Page 13 of 25 I Spud Date: 1/8/2006 End: 2/11 /2006 Group: Description of Operations (779') MD. TVD = 3566'. ART=7.43 PUW=165K SOW=O ROT=107K Wait on geology decision from town. Pumped 30 bbl weighted hi-vis sweep @ 93 spm, 330 gpm. t'~'~ ~ Drill 6 314" B Lateral w/ Sperry-Sun GeoPiolt from 12,524' - 1,7„09"'(176') MD/ 3583' TVD. ADT =1.02 hrs TDT=8.45. Total Bit HRS =75.41 hrs. Total Jar HRS =124.3 PU WT = 170K, SO WT = OK, ROT WT =105K. TO on/off=8.9/8.5K. Pumps - 330 GPM's - 4000 PSI. RPMs = 120. WOB = 5-15K. Mud Wt = 8.75 PPG, Visc = 72, ECD = 12.05 PPG, Max gas = 40 Units. Observed drilling through concretions from 12015'-12021', 12056'-12062', 12146'-12154', 12159'-12162', 12207'-12219', 12257'-12261', 12268'-12281', 12546'-12550'. SPR#1=25stk/730psi,35stk/920psi SPR#2=25spml730psi,35stk/920psi @ 12524 MD/ 3566 TVD Drill 6 3/4" B Lateral w/ Sperry-Sun GeoPiolt from 12700' - 12952' (252') MD / 3591' TVD. Pumped a 30 bbl hi-vis weighted sweep @ 12,745' and observed a 50% increase in cuttings across the shakers. (Pumped another sweep @ 12,952' and observed 100% increase in cuttings. ECD prior to 1st sweep=11.89 after last sweep =11.45) Total Bit HRS=79.5. Total Jar HRS =128.4 ADT =4.09 hrs. PU WT = 205K, SO WT = OK, ROT WT = 111 K. TO on/off = 10.5/9K Pumps - 330 GPM's - 4050 PSI. RPM's = 120. WOB = 4-15K. Mud Wt = 8.75 PPG, Visc = 67, ECD = 12.01 PPG, Max gas = 41 Units. Observed drilling through concretions from 12843'-12854', 12861'-12868', 12905'-12918', 12935'-12938'. KREVs=158305 Pumped hi-vis sweep @ 12,952' and 2X BU w/ 90 spm, 4000 psi, 140 rpm, and TOoff=8K. Garnered SPRs. Observed well, static. SPR#1=25stk/700psi,35stk/910psi SPR#2=25spm/730psi,35stk/940psi @ 12952 MD/ 3591 TVD BROOH from 12,952' to 9,620' w/ 140 rpm, 3500 psi, 330 gpm. BROOH from 9,620' to window @ 5,380' w/ 140 rpm, 330 gpm, 3000 psi. Pumped weighted hi-vis sweep @ 5,380' w/ 330 gpm, 2200 psi. Observed a negligible 5% increase in cuttings. Monitored well, static. RIH from 5,380' to 10,368' where SOW=O. Washed through a bridge @ 9,246'. Washed and reamed from 10,368' to 12,290' w/ 248 gpm, 2800 psi, 120 rpm, TO=7.5K. PUW=155K SOW=45K ROT=110K Washed and reamed from 12,290' to 12,952' Pumped a 35 bbl weighted hi-vs sweep followed by 3 BUs @ 85 spm, 302 gpm, 3900 psi, 140 rpm, TO=8.5K Displaced to SFOBM w/ 85 spm, 302 psi, 3900 psi, 120 rpm, TO=8.5. PUW=190K SOW=OK ROT=112K Garnered SPRs. Monitored well, static. Dropped 1 7/8" rabbit. SPR#2=25stk/550psi, 35stk/830psi @ 12,952' MD/ 3592' TVD w/ 8.8 PPG SFOBM. POOH from 12,952' to above window @ 5,347'. Observed well, static. Printed: 2/13/2008 12:29:18 PM ConocoPhillips Alaska Page 14 of 25 Operations Summary Report Legal Well Name: 1 J-166 Common Well Name: 1J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Sub ', Code'. 1 /27/2006 21:45 - 00:00 1 /28/2006 00:00 - 00:15 00:15 - 01:00 01:00 - 01:45 01:45 - 02:15 02:15 - 02:45 02:45 - 05:45 05:45 - 06:00 06:00 - 06:45 06:45 - 09:45 09:45 - 11:15 11:15 - 12:00 12:00 - 12:30 12:30 - 16:30 16:30 - 17:00 17:00 - 18:30 18:30 - 19:45 'I 19:45 - 21:45 ~i 22:45 - 00:00 1 /29/2006 00:00 - 02:00 2.251 DRILL (TRIP Phase PROD2 0.251 DRILL I PULD PROD2 0.75 DRILL OTHR PROD2 0.75 DRILL PULD PROD2 0.50 DRILL PULD PROD2 0.50 WINDO ULD CMPLT2 3.001 WINDOWfRIP I CMPLT2 0.251 WINDOWTRIP CMPLT2 0.75 WINDO IRC CMPLT2 3.00 WINDO RIP CMPLT2 1.50 WINDO ULD CMPLT2 0.75 WINDO ULD CMPLT2 0.50 CASE RURD CMPLT2 4.00 CASE RUNC CMPLT2 0.50 CASE RUNC CMPLT2 1.501 CASE RUNC CMPLT2 1.251 CASE I RUNL I CMPLT2 2.001 CASE ~ RUNL ~ CMPLT2 1.251 CASE I RUNL I CMPLT2 2.00 CMPLTN OTHR ~ CMPLT2 02:00 - 02:30 02:30 - 03:00 03:00 - 04:45 04:45 - 07:00 Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations POOH from 5,347' to BHA @ 369'. KREVs=218619 Rack back 2 stds HWDP w/jars, 1 std NMFDCs. UD BHA SMT sub, flt sub. Downloaded MWD. Cont'd to UD BHA including: DM HOC, NMFDC, Geo-pilot, and bit. Cleaned and cleared rig floor. L/D BHA tools. M/U BHA including: 1 jt 3.5" HWDP, hook, flt sub, bumper sub, oil jars, XO, and 3 stds push pipe. RIH retorquing super sliders on the way in (90 total). RIH to 5,333'. PUW=130 SOW=95 Washed down to 5,386' and attempted to hook whipstock. Turned 1!4 turn 3 times and hooked on 4th try. Pulled 50K over; jars fired w/ no release. Second try pulled 60K over; jars fired w/ release and shear of trip anchor. PUW=140K Pulled up to 5,363' and CBU @ 56 spm, 200 gpm, 950 psi. POOH from 5,363' to 61'. UD XO, oil jars, bumper sub, float sub, 1 jt 3.5" HWDP, hook. UD whipstock debris sub, shear disc sub, bottom trip anchor blanking sub, flex jt, 2 jts 3.5" DP, unloader sub, locator sub w/seal unit. Cleared and cleaned rig floor. R/U to run 4 1/2" liner in "B" Lateral. Held PJSM. Ran 4 1/2" liner to 5,591'. Tagged up on "D" Lateral ZXP. Pulled up to 5,365'. Attempted to go through window, no luck. Turn 90 deg, try again -through window @ 5380+'. Cont'd to run liner from window to 7,500'. PUW=83K SOW=60K PJSM. Discuss safety issues and procedure for making up Slim Hole MWD assmy. Make up Baker Model B1 FHH Hook Hanger assembly, pups, with crossoverjoint, Casing Swivel, running and setting tools. Make up Ball seat shear sub and Slimhole MWD assembly, oriented 180 DEG from Hook on hanger. Ran in 2 stds and SHT MWD equip. PUW=84K SOW=62K TIH on DP to 11,636'. Slack-off weight nearly equal to block weight. PUW=137 SOW=36K Worked pipe to 12,727' with very little down weight. PUW=185 SOW=36-38K Cont'd to RIH w/ DP and very little down weight. Oriented hook to high side and worked liner to 12,919' w/ the hook 10' past the window. Pulled up and re-oriented hook, set hook @ 5394' (2' low) and 29? right of highside (whipstock for window milling set @ 5? left ofhigh-side). Pulled up and re-hooked to verify with same toolface and depth. Top of hook assembly @ 5,377.27' and bottom of hook assembly @ 5,394.13'. PUW=185K SOW=40K 0.50 CMPLTN OTHR CMPLT2 Dropped ball and pumped down w/ 2 bpm, 680 psi. Ball bumped @ 511 stks and pressured up to 3500 psi. Released from hook, continued to pressure up to 4200 psi to shear out ball seat. 0.50 CMPLTN CIRC CMPLT2 Racked back 1 std push pipe, UD 1jt 4" DP. CBU w/ 70 spm, 1300 psi, 247 gpm. 1.75 RIGMNT RSRV CMPLT2 Slipped and cut drilling line, serviced top drive, inspected saver sub. 2.25 CMPLTN TRIP CMPLT2 TOOH from 5,254' to 56'. Trip out displacements Calc=42.21 bbls Printed: 2/13/2006 12:29:18 PM ConocoPhillips Alaska Page 15 of 25 Operations Summary Report Legal Well Name: 1 J-166 Common W ell Name: 1 J-166 Spud Date: 1/8/2006 Event Nam e: ROT -D RILLING Start: 1/7/2006 End: 2/11/2006 'Contractor Name: n 1334@ ppco.co m Rig Release: 2/11./2006 Group: Rig Name: Doyon 1 41 Rig Number: Date - To From Hours ~ Code Cod Phase Description of Operations . . e '..1/29/2006 04:45 - 07:00 2.25 CMPLTN TRIP CMPLT2 Actual=48.0 bbls. 07:00 - 08:00 1.00 CMPLTN PULD CMPLT2 L/D BHA, liner running tool, slim hole MWD. 08:00 - 09:45 1.75 RIGMNT RGRP CMPLT2 C/O saver sub. 09:45 - 10:15 0.50 CMPLTN RURD CMPLT2 R/U casing equip. 10:15 - 12:00 1.75 CMPLTN PULD CMPLT2 Held PJSM. M/U LEM to 430.2'. Baker Seal assembly (3.26'), Crossoverjoint IBT x STL (43.04'), 4 1/2" IBT pup (30.88'), Camco "DB" Nipple 3.563" ID (1.55'), 4 1/2" IBT JNT (31.38'), 4 1/2" IBT pups (9.83), LEM assembly (35.93'), 7 - JNTs of 4 1/2" IBT (215.49'), 4 1/2" IBT pup (3.82'), Baker Casing Swivel (2.82'), XO Bushing (1.40'), 109-47 Casing Seal Bore receptacle (19.69'), ZXP Liner Top Packer (19.03'). Total tools to stay in hole 417.2'. 12:00 - 14:30 2.50 CMPLTN TRIP CMPLT2 TIH w! LEM assy. from 430' to 5,521'. PUW=133K SOW=100K Good indication of latch up w! 35K over on downweight. Pulled up gently w/ 5K overpull to 138K. Set down 40K. LEM in place with top @ 5367.22'. Top of ZXP packer element @ 5104.38'. 14:30 - 15:00 0.50 CMPLTN PCKR CMPLT2 Dropped 1.75" ball and pumped down w/ 30 spm, 350 psi. Seated ball and pressured up to 2200 psi release pressure. Slowly pressure up to 4400 psi. Bled pressure to zero. Release from LEM. 15:00 - 15:30 0.50 CMPLTN PCKR CMPLT2 Tested ZXP packer to 1000 psi for 5 mins. P!U 8' with PUW=128K down from 133K. Verify top of ZXP @ 5104 with tag. POOH to 5039'. 15:30 - 16:00 0.50 CMPLTN CIRC CMPLT2 CBU w/ 1300 psi, 70 spm. Monitored well, static. 16:00 - 18:00 2.00 CMPLTN TRIP CMPLT2 POOH from 5039' to 42'. Trip out displacements Calc=44 bbls Actual=47.0 bbls. 18:00 - 18:45 0.75 CMPLTN PULD CMPLT2 L/D running tool. Cleaned and cleared rig floor. 18:45 - 21:45 3.00 WINDO ULD PROD3 P/U and M/U whipstock and mill BHA. Uploaded MWD, SHT MWD w! 82 spm, 291 gpm, 900 psi. 21:45 - 00:00 2.25 WINDO RIP PROD3 TIH from 466' to 3,362'. PUW=84K SOW=74K 1/30!2006 00:00 - 01:15 1.25 WINDO RIP PROD3 Made MAD pass from 4,660' to 4,690'. Oriented 15? left of high side. 01:15 - 01:45 0.50 WINDO ETW PROD3 RIH to 4,997' and oriented @ 15? left of high side w/ 86 spm, 300 gpm, 2450 psi. Tagged ZXP @ 5104'. Set trip anchor w/ 20K down weight. Pulled up to 130K to confirm setting. Whipstock set @ 18? left of high side. Set down w/ 50K down weight to shear bolt. Mill @ 5,005' for window cutting. 01:45 - 02:30 0.75 WINDO IRC PROD3 Held PJSM and displaced well to MOBM. Garnered SPRs. SPR#1=25stk/340psi, 35stkl490psi SPR#2=25stk/350psi, 35stk/500psi @ 5046' MD / 3423' TVD 8.8+MW 02:30 - 06:15 3.75 WINDO CML PROD3 Milling from 5,005' to 5046'. Milled window from 5,005' to 5,017' + 20' of gauged hole to 5037'. TD= 5,046' Milled w/ 80 spm, 2400 psi, 120 rpm. TOW=5,005' BOW=5,017" 06:15 - 07:15 1.00 WINDO IRC PROD3 Worked mill through window w/ 120 rpm, 86 spm, 300 gpm, 2400 psi. Rotated through window up and down 6 times. Slid through window twice w/ pumps on, no problems. 07:15 - 09:30 2.25 WINDO RIP PROD3 Monitored well, static. Pumped dry job and POOH from 5,046' to 98'. PUW=125K SOW=90K prior to POOH. 09:30 - 10:45 1.25 WINDO ULD PROD3 UD mill, XO, bumper sub, downloaded MWD, TM, MWD, DM, F/S, 1 jt 3.5" HWDP, window mill, lower and upper mill (upper mill in gauge). Removed mill and BHA from rig floor. 10:45 - 12:15 1.50 WELLS EQRP PROD3 Drained stack after milling operations. Pulled wear bushing. R/IU and flushed stack. RID stack washer. 12:15 - 12:30 0.25 WINDO ULD PROD3 L/D milling BHA from rig floor. Printed: zn aizoos 1Z:Ly:1tl F'M ConocoPhillips Alaska Page 16 of 25 -.Operations Summary Report Legal Well Name: 1J-166 Common Well Name: 1J-166 Spud Date: 1/8/2006 Event Name: ROT -DRILLING Start: 1/7/2006 End: 2/11!2006 Contractor Name: n1334@ppco.com Rig Release: 2/11/2006 Group: Rig Name: Doyon 141 Rig Number: Date .From - To Hours Code Code Phase I Description of Operations 1!30/2006 12:30 - 15:30 3.00 WELCT BOPE PROD3 R/U and test BOP stack, HCR's & manual valves. Test Choke mainfold valves 1-14, upper & lower IBOP valves, floor safety valve & dart valve.All tests 250 PSI Low / 3500 PSI High. Recorded on chart. Accumulator test: Starting=3000 psi Ending=1900 psi after all elements closed. Recovery time=3 min 4 sec. Nitrogen bottle pressure=2100 psi Chuck Shieve with AOGCC waived witness of test. Tested gas alarms and PVT and high flow alarms. R/D test equipment. 15:30 - 15:45 0.25 WELLS EQRP PROD3 Set wear bushing. 15:45 - 18:00 2.25 DRILL PULD PROD3 P/U and M/U BHA #9 including: bit, geo-pilot, pony collar, DM, smart stab, slimphase, PWD, TM, NM F/S, stab. Uploaded MWD. Cont'd M/U NM flex DCs, XO, 2 std HWDP, jars, .Broke in geo-pilot bearings and SHT MWD w/ 84 spm, 1400 psi. 18:00 - 20:00 2.00 DRILL TRIP PROD3 TIH from 369' to 4,949'. Went through window, and TIH to 5,036'. Reamed to 5,046' w/ 90 rpm, 84 spm, 2100 psi, TQ=4K. PUW=91 K SOW=75K 20:00 - 00:00 4.00 DRILL DRLH PROD3 Drilled from 5,046' to 5,506' MD / 3,460' TVD. ADT=2.51 hrs. Jar hrs=125.89 PUW=107K SOW=65K ROT=80K TQon/off=5/4.5K Max Gas=149 Units Max ECD=10.09 SPR#1=25stk/380psi, 35stk/550psi SPR#2=25stk/390psi, 35stk/560psi @ 5133' MD / 3441' TVD 8.9+MW 1/31/2006 00:00 - 12:00 12.00 DRILL DRLH PROD3 Drilled from 5,506' to 7188' MD ! 3,465' TVD. ADT=8.12 hrs. Jar hrs=136.52 PUW=110K, SOW=60K, ROT=80K, TQon/off=6K, 6K Max Gas=184 Units. Max ECD=10.24 SPR#1=25stk/420psi, 35stk/610psi SPR#2=25stk/460psi, 35stk/600psi @ 7094' MD ! 3447' TVD 8.8+MW Concretions @ 5713'-5722' (9'), 5757'-5761'(4'), 5769'-5774'(5'), 5787'-5789'(2'), 6039'-6040'(1'), 6981'-6984'(3'), 6993'-6998'(5'). Total concretions this tour = 29'. 12:00 - 16:45 4.75 DRILL DRLH PROD3 Drilled from 7,188' to 7,530' MD / 3,448' TVD. ADT=4.17 hrs. Jar hrs=140.69 PUW=108K, SOW=60K, ROT=80K, TQon/off=6K, 6K Max Gas=81 Units. Max ECD=10.26 SPR#1=25stk/420psi, 35stk/580psi SPR#2=25stk/430psi, 35stk/600psi @ 7530' MD / 3448' TVD 8.7+MW Concretions @ 7453'-7474' (19'), 7481'-7499'(18'), 7506'-7528'(22'). Total concretions this tour = 59'. Last survey @ 7494.91' MD, 3451.91 TVD, INC = 89.81 DEG, AZ = 352.77 DEG. 16:45 - 17:00 0.25 DRILL DRLH PROD3 Pump up surveys. Obtain SPR's. Monitor well -static. 17:00 - 17:45 0.75 DRILL TRIP PROD3 POOH on elevators from 7530'-7191' (339'). Observe hole not taking proper fill. 17:45 - 20:30 2.75 DRILL TRIP PROD3 BROOH from 7191' - 5136' (2055'), @ 92 SPM, 326 GPM, and 2500 PSI. Pull assembly through window @ 5005' with no issues up to 4949'. 20:30 - 22:30 2.00 DRILL TRIP PROD3 Monitor well -static. POOH 15 stands. observed well 3 BBLS behind in fill. Continue POOH to 2735'. Hole fill good, well static. Calcualted displacement = 29.5 BBLs. 22:30 - 00:00 1.50 DRILL PULD PROD3 Rack back 4" HWDP, Drilling Jars, and 1 stand Non Mag Flex Drill Collars. Plug in and download MWD assembly. Printed: 2!1312006 12:29:18 PM ConocoPhillips Alaska Page 17 of 25 Operations Summary Report Legal Well Name: 1 J-166 Common Well Name: 1J-166 Spud Date: 1/8/2006 Event Name: ROT -DRILLING Start: 1/7/2006 End: 2/11/2006 Contractor Name: n1334@ppco.com Rig Release: 2/11/2006 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Code Phase 2/1!2006 00:00 - 00:30 0.50 DRILL PULD PROD3 00:30 - 01:30 1.00 DRILL PULD PROD3 01:30 - 02:45 1.25 DRILL OTHR PROD3 02:45 - 03:15 0.50 DRILL TRIP PROD3 03:15 - 03:45 0.50 DRILL OTHR PROD3 03:45 - 06:45 3.00 DRILL TRIP PROD3 06:45 - 12:00 ~ 5.25 ~ DRILL ~ DRLH ~ PROD3 12:00 - 17:00 5.00 DRILL I DRLH PROD3 17:00 - 18:00 1.001 DRILL WIPR ~ PROD3 18:00 - 21:45 I 3.751 DRILL I DRLH I PROD3 21:45 - 23:00 1.25 DRILL DRLH PROD3 23:00 - 00:00 1.00 DRILL DRLH PROD3 Description of Operations I~ Continue POOH, Breakout & lay down BHA. Lay down NM IBS 'Stabilizer (5.30'), NM Float Sub (2.41'), 4 3/4" TM HOC (11.28'),4 3/4" PWD Tool (10.78'), 4 3/4" Slimphase 4 w/ DGR &RES (24.51'), 4 3/4" Smart Stabilizer (3.59'), 4 3/4" DM HOC (8.55'), GP Non MAg Flex Pony Collar (11.54'), 5200 Geo Pilot #002 (16.19') & 6 3/4" Hycalog CRXE 1005H+ bit. Inspected bit & gauged to a 1 / 1, we will rerun. Observed bearing pack in Geo -Pilot seized up. Housing would not spin freely. Make up BHA #9. Make up 6 3/4" Hycalog bit (5RR1) on backup 5200 Geo-Pilot (16.19'), NM IBS Stabilizer (5.30'), NM Float Sub (2.41'), 4 3/4" TM HOC (11.28'),4 3/4" PWD Tool (10.78'), 4 3/4" Slimphase 4 w/ DGR &RES (24.51'), 4 3/4" Smart Stabilizer (3.59'), 4 3/4" DM HOC (8.55'), GP Non MAg Flex Pony Collar (11.54'). Plug in and upload MWD assembly. Trip in hole to 1304'. Picking up 3 -Non Mag Flex Drill collars (92.70'), Crossover (1.61'), 3 - 4" HWDP (90.77'), 4 3/4" Drilling jars (28.81'), & 2 - 4" HWDP (60.48'). Total BHA = 369.79' Rig up and perform Shallow pulse test on MWD assembly. Good test. Break in seals on Geo-Pilot, downlink same. All tests good. Continue trip in hole from 1304' - 7530' (6226'). Wash from 7471' - 7530' at 94 SPM, 330 GPM, 2750 PSI, Rotating 50 RPM's with 6K torque. Continue Directional drilling from 7,530' to 7,845' MD / 3,452' TVD. ADT=4.00 hrs. Jar hrs=144.69 PUW=110K, SOW=56K, ROT=80K, TOon/off=6K, 6K Max Gas=43 Units. Max ECD=10.09 Concretions @ 7540'-7555' (15'), 7560'-7562'(2'), 7595'-7604'(9'), 7650'-7660' (10'),665'-7670' (5'),7749'-7824'(75'). Total concretions this tour = 116'. Last survey @ 7494.91' MD, 3451.91 TVD, INC = 89.81 DEG, AZ = 352.77 DEG. Continue Directional drilling from 7845' to 8359' MD / 3455' TVD. ADT=4.52 hrs. Jar hrs=149.91 PUW=114K, SOW=56K, ROT=80K, TOon/off=6K, 6K Max Gas=46 Units. Max ECD=10.47 SPR#1=25stk/450psi, 35stk/640psi SPR#2=25stk/450psi, 35stk/620psi @ 8030' MD / 3441' TVD 8.7 MW Concretions @ 7834'-7855' (21'), 7869'-7890'(21'), 8009'-8022'(13'), 8132'-8136' (4'), 8150'-8158' (8'). Total concretions this tour = 67'. Last survey @ 8359' MD, 3455 TVD, INC = 86.25 DEG, AZ = 352.59 DEG. Geologist decided to pull back and sidetrack as we were out of zone. BROOH from 8359' - 7845' (514') for sidetrack. Back ream at 93 SPM - 330 GPM -2850 PSI, 120 RPM's with 6.5K torque. No hole issues. Cut trough from 7845' - 7855' (10'). NOTE: We have 21 feet of concretions on either side of picked sidetrack point. Trough hole @ 330 GPM"s 2850 SPI, 120 RPM's, and 6K torque. Begin time drilling @ 3 minutes per inch from 7855' -7869' observing no change in inclination and indication of falling back in OLD hole. Pull back to old hole @ 7845'. Once again, cut trough from 7845' - 7855' at same parameters as above. PU WT = 110K, SO WT = 56K, ROT WT =80K. TO = 6K. Time drill from 7855'-7856' at 4 minutes per inch, as per DD. ADT = .7 Printed: 2/13/2006 12:29:18 PM ConocoPhillips Alaska Page 18 of 25 Operations Summary Report Legal Well Name: 1 J-166 Common W ell Name: 1J-166 Spud Date: 1/8/2006 Event Nam e: ROT -D RILLING Start: 1/7/2006 End: 2/11/2006 Contractor Name: n1334@ ppco.co m Rig Release: 2/11/2006 Group: Rig Name: Doyon 1 41 Rig Number: Date From - To Hours Code Sub Phase ' Description of Operations .Code 2/1/2006 23:00 - 00:00 1.00 DRILL DRLH PROD3 HRS. TVD = 3452'. 2/2/2006 00:00 - 04:30 4.50 DRILL DRLH PROD3 Continue time drill @ 4 minutes per inch from 7856' - 7870' (14'). Observed inclination @ 92 Degrees indicating bit being in Old Hole. Note: we have a 21' concretion on each side of the attempted sidetrack point. We need to make at least 10' of hole to obtain a good survey. 04:30 - 05:00 0.50 DRILL WIPR PROD3 Pull back up hole to 7658' after dicussing with DD & Geologist to a better sidetrack point. PU WT = 110K, SO WT = 56K. 05:00 - 06:00 1.00 DRILL DRLH PROD3 Work drill string and cut trough from 7670'-7680', at 100 RPM's, 94 SPM, 330 GPM, 2700 PSI with 6K torque. 06:00 - 12:00 6.00 DRILL DRLH PROD3 Time drill from 7680' until verified kicked off and good survey indications. Continue Directional Drill 6 3/4" hole in the "D" lateral to 7835' MD. 3473' TVD. ART = 5.11 HRS. PU WT = 110k, SO WT = 65K, ROT WT = 80K. MAx gas observed = 37 BTU's, Torque on /off bottom = 6K. Max ECD = 10.0 PPG. Jar HRS = 149.80 WOB = 0-2K, 110 RPM's, Pump at 93 SPM, 330 GPM & 2700 PSI. 12:00 - 15:30 3.50 DRILL DRLH PROD3 Continue Directional drilling from 7835' to 8359' MD / 3,472' TVD. ADT=2.91 hrs. PUW=112K, SOW=55K, ROT=80K, TQ on/off=6.5K, 6.5K Max Gas=64 Units. Max ECD=10.80 Concretions @ 7888'-7889' (1'). NOTE: 8359' =last Hole depth before sidetrack. 15:30 - 19:30 4.00 DRILL DRLH PROD3 Continue Directional drilling from 8359' to 8860' MD ! 3478' TVD. ADT=3.09 hrs. Total Jar hrs=156.09 Total ADT = 6.29 HRS PUW=120K, SOW=50K, ROT=80K, TQ on/off=6.5K, 6.5K Max Gas=64 Units. Max ECD=11.65 SPR#1=25stk/480psi, 35stk/650psi SPR#2=25stkl490psi, 35stk/650psi @ 8901' MD / 3479' TVD 8.7 MW Concretions @ 8563'-8568' (5'), 8604'-8609'(5'), 8611'-8613'(2'), 8620'-8622' (2'), 8839'-8844' (5'). Total concretions this tour = 20'. Last survey @ 8835' MD, 3475 TVD, INC = 86.43 DEG, AZ = 358.74 Total K-revs for the day = 27014 19:30 - 20:00 0.50 DRILL DRLH PROD3 Trouble shooting Geo-Pilot Assembly. Indications are Geo-Pilot is not holding desired tool face. Repeat trouble shooting attempts. 20:00 - 20:30 0.50 DRILL DRLH PROD3 Continue Directional Drill From 8860' - 8901 (41'), while trouble shooting Geo-Pilot Assembly. Indications are Geo-Pilot is not recognizing commands and will not hole desired tool face. Suspect internal electronics failure as per DD. Repeat trouble shooting attempts with no success. 20:30 - 21:00 0.50 DRILL WIPR PROD3 Obtain Slow pump rates. Monitor well -static. 21:00 - 00:00 3.00 DRILL WIPR PROD3 Attempt to POOH on elevators, observe well swabbing. BROOH to 6817 (2084') @ 93 SPM , 330 GPM, 2800 PSI, 120 RPM's with ti.SK torque @ 60 -75 ft/ hr. 2!3/2006 00:00 - 02:00 2.00 DRILL WIPR PROD3 Continue BROOH from 6817' - 5150' (1667'). Pull drilling assembly through window area @ 5005' with no issues. 02:00 - 04:00 2.00 DRILL TRIP PROD3 Continue POOH on elevators observing hole taking proper fill. Rack back 4" HWDP, Drilling Jars, and 1 stand Non Mag Flex Drill Collars. 04:00 - 05:00 1.00 DRILL OTHR PROD3 Plug in and down load MWD assembly. 05:00 - 06:00 1.00 DRILL PULD PROD3 POOH, breakout & lay down BHA #9. Lay down Lay down NM IBS Stabilizer (5.30'), NM Float Sub (2.41'), 4 3/4" TM HOC (11.28'),4 3/4" PWD Tool (10.78'), 4 314" Slimphase 4 w/ DGR & RES (24.51'), 4 3/4" Smart Stabilizer (3.59'), 4 314" DM HOC (8.55'), GP Non MAg Flex Pony Collar (11.54'), 5200 Geo Pilot #002 (16.19') & 6 3/4" Hycalog CRXE 1005H+ bit. Inspected bit & gauged to a 1 / 1/ WT / A / X / I / NO Printed: 2/13/2006 12:29:18 PM ConocoPhillips Alaska Page ~ 9 of 25 Operations Summary Report Legal Well Name: 1 J-166 Common W ell Name: 1J-166 Spud Date: 1/8/2006 Event Nam e: ROT -D RILLING Start: 1/7/2006 End: 2/11/2006 Contractor Name: n1334@ ppco.co m Rig Release: 2/11/2006 Group: Rig Name: Doyon 1 41 Rig Number: Date From - To Hours Code Code Phase ~ Description of Operations 2/3/2006 05:00 - 06:00 1.00 DRILL PULD PROD3 / DTF. 06:00 - 06:30 0.50 DRILL PULD PROD3 Clean & Clear floor area. Send tools outside. 06:30 - 08:00 1.50 DRILL PULD PROD3 PJSM, Discuss safety issues and procedure for BHA make up. Make up BHA #10. MU 6 3/4" Security FSF2641 bit w/ 3 x 21 Jets TFA = 1.015sq in (1.27'), 5200 Geo Pilot #002 (16.22'), NM IBS Stabilizer (5.30'), NM Float Sub (2.41'), 4 314" TM HOC (11.28'),4 3/4" PWD Tool (10.78'), 4 314" Slimphase 4 w/ DGR & RES (24.51'), 4 3/4" Smart Stabilizer (3.59'), 4 3/4" DM HOC (8.55'), GP Non MAg Flex Pony Collar (11.54'). 08:00 - 09:15 1.25 DRILL OTHR PROD3 Plug in and Up Load MWD assembly. 09:15 - 09:30 0.25 DRILL TRIP PROD3 Trip in hole making up 4" HWDP, Drilling Jars, and 1 stand Non Mag Flex Drill Collars. Total BHA = 369.82'. 09:30 - 10:00 0.50 DRILL OTHR PROD3 Perform Shallow pulse test and break in Geo-Pilot bearings @ 81 SPM, 290 GPM, 1300 PSI, and 50 RPM's. Good test. 10:00 - 12:00 2.00 DRILL TRIP PROD3 Trip in hole from 455' - 4949' (4504'). PU WT = 90k, SO WT = 70K. 12:00 - 12:30 0.50 DRILL TRIP PROD3 PJSM, crew change -new crew. Fill drill string, and inspect saver sub on Top Drive. 12:30 - 15:00 2.50 DRILL TRIP PROD3 Continue trip in hole from 4949' - 8901' (3952'). Observe hole taking proper hole fill. Work assembly through window area with no issues. Continue RIH to 8873' MD. Wash & ream from 8873' - 8901'. Shoot survey @ 8873'. 15:00 - 00:00 9.00 DRILL DRLH PROD3 Continue Directional drilling from 8901' to 9750' MD / 3493' TVD. ADT=6.05 hrs. Total Jar hrs=162.14 Total ADT = 6.05 HRS PUW=125K, SOW=50K, ROT=85K, TQ onloff=ti.5K, 6.5K Max Gas=138 Units. Max ECD=10.45 SPR#1=25stk/ 530psi, 35stk/ 730psi SPR#2=25stk/ 530psi, 35stk/ 730psi @ 9244' MD / 3486' TVD 8.7 MW Concretions @ 8900'-8903' (3'), 9112'-9116'(4'), 9359'-9364'(5'), 9365'-9374' (9'), 9376'-9383' (7'), 9399'-9401' (5'), 9407'-9411' (4'), 9420'-9430' (10'), 9574'-9579' (4'), 9581'-9588' (7'), 9590'-9595' (5'). Total concretions this tour = 61'. Last survey @ 9675' MD, 3492 TVD, INC = 89.98 DEG, AZ = 354.87 Total K-revs for the day = 89530 2/4/2006 00:00 - 01:30 1.50 DRILL DRLH PROD3 Continue Directionakl Drill 6 3/4" D lateral from 9750' - 9898'. (148'). ART = 1.08 HRS. 01:30 - 02:00 0.50 DRILL DRLH PROD3 Trouble Shoot MWD. Could not get a good signal, and surveys were false & misleading. Repeat survey attempts until verifying tool working correctly and we had good surveys. 02:00 - 12:00 10.00 DRILL DRLH PROD3 Continue Directional drilling from 9898' to 10926' MD / 3455' TVD. ADT=7.63 hrs. Total Jar hrs=176.90 Total ADT = 8.71 HRS, Total Bit Hrs = 14.76. PUW= 125K, SOW= 40K, ROT= 80K, TQ on/off=7K, 6K Max Gas=88 Units. Max ECD=11.55 SPR#1=25stk/ 600psi, 35stk/ 790psi SPR#2=25stk/620psi, 35stk! 800psi @ 10269' MD / 3460' TVD 8.7+ MW Concretions @ 9574'-9579' (5'), 9581'-9588'(7'), 9590'-9595'(5'), 9740'-9755' (15'), 9758'-9778' (20'), 9932'-9935' (3'), 10164'-10169' (5'), 10251'-10255' (4'), 10391'-10409' (18'), 10468'-10470' (2'), 10560'-10571' (11'), 10678'-10685" (7'). Total concretions this tour = 102'. Pump A 30 BBL Hi Visc Weighted sweep @ 10552', observed a 5% increase in cuttings upon return. Survey @ 10422' MD, 3453 TVD, INC = 89.01 DEG, AZ = .96 NOTE :Drilled through a Fault @ 10160' MD, 3469' TVD, with an 81' Throw up. Printed: 2!1312006 12:29:18 PM ConocoPhillips Alaska Page 20 of 25 Operations Summary Report Legal Well Name: 1 J-166 Common Well Name: 1J-166 Spud Date: 1/8/2006 Event Name: ROT -DRILLING Start: 1/7/2006 End: 2/11/2006 Contractor Name: n1334@ppco.com Rig Release: 2/11/2006 Group: Rig Name: Doyon 141 Rig Number: Date 12/4/2006 12/5/2006 From - To Hours ~ Code Sub Code 02:00 - 12:00 10.00 DRILL DRLH 12:00 - 00:00 12.00 DRILL DRLH Phase PROD3 PROD3 00:00 - 12:00 I 12.001 DRILL I DRLH I PROD3 12:00 - 13:45 13:45 - 15:30 15:30 - 00:00 2/6/2006 100:00 - 02:15 02:15 - 03:30 03:30 - 04:45 1.751 DRILL I DRLH I PROD3 1.751 DRILL I CIRC I PROD3 8.501 DRILL WIPR PROD3 2.251 DRILL I WIPR I PROD3 1.251 DRILL I CIRC I PROD3 1.25 ~ RIGMNT~ RSRV I PROD3 04:45 - 07:30 2.75 DRILL WIPR PROD3 07:30 - 12:00 4.50 DRILL REAM PROD3 Description of Operations Continue Directional drilling from 10926' to 12000' MD ! 3489' TVD. ADT=8.09 hrs. Total Jar hrs=184.99 Total ADT = 16.80 HRS, Total Bit HRS = 22.85. PUW= 145K, SOW= 35K, ROT= 95K, TO on/off=9-10K, 8K Max Gas=61 Units. Max ECD=11.51 SPR#1=25stk/ 680psi, 35stk/830psi SPR#2=25stk/ 630psi, 35stk/850psi @ 11292' MD / 3467' TVD. 8.7+ MW Concretions @ 11010'-11017' (7'), 11220'-11225' (5'), 11350'-11357 ' (7'), 11475'-11481' (6'), 11485'-11493' (8'), ,11555'-11561' (6'), 11566'-11573' (7'), 11590'-11594' (4'), 11708'-11716' (8'). Total concretions this tour = 58'. Pump A 30 BBL Hi Visc Weighted sweep @ 11473', observed a 20% increase in cuttings upon return. Survey @ 11892' MD, 3488 TVD, INC = 88.61 DEG, AZ = 1.08 Total K-revs for the day = 74338 Continue Directional drilling from 12000 ' to 12866' MD / 3525' TVD. ADT=8.97 hrs. Total Jar hrs=193.96 Total ADT = 25.77 HRS, Total Bit HRS = 31.82. PUW= 177K, SOW= 35K, ROT= 106K, TQ on/off=9-10K, 9.5K Max Gas=163 Units. Max ECD=11.75 SPR#1=25stk/ 740psi, 35stk/ 900psi SPR#2=25stk/ 760psi, 35stk/ 910psi @ 12198' MD / 3479' TVD. 8.7+ MW Concretions @ 12003'-12018' (15'), 12023'-12037' (14'), 12039'-12058' (19'), 12556'-12559' (3'), 12566'-12570' (4'), 12611'-12614' (3'), 12670'-12676' (8'), 12708'-12717' (9'). Total concretions this tour = 73'. Continue Directional drilling from 12866 ' to 12994' MD / 3530' TVD. Well TD'd as per Geologist & Directional Driller. ADT=1.76 hrs. Total Jar hrs=195.72 Total ADT = 27.53 HRS, Total Bit HRS = 33.58. PUW= 180K, SOW= 35K, ROT= 110K, TO on/off=9-10K, 9.5K Max Gas=155 Units. Max ECD=11.80 8.7+ MW. Concretions @ 12936'-12940' (4'), 12946'-12954' (8'). Total concretions this tour = 12'. Survey @ 12994' MD, 3530.64 TVD, 86.99 Deg INC., 3.93 Deg AZ. Total K-revs for the day = 120717. Total AVG ROP for bit = 122' FUHr Reciprocate & Rotate Drill String while CBU 2 times @ 300 GPM - 3900 PSI. Pump up final survey. Montor well -static. BROOH form 12994' - 7004' (5990'). Back ream at rates of 20 - 80 ft/minute @ 330 GPM - 3900 PSI to start, and then 2800 PSI at 7004'. 120 RPM's, with 7K - 9K torque. Continue BROOH at rates of 60 - 80 ft/minute @ 330 GPM - 2800 PSI at 120 RPM's, with 7K - 9K torque. Pulled assembly through window area with no issues. Pump a 30 BBL Hi Vis Weighted sweep, and circulate 3 bottoms up to verify clean hole conditions. Pump @ 330 GPM - 2550 PSI. Observed 5-10 % increase in cutting upon return of sweep. PJSM, Discuss safety issues and procedure for Slip & Cut. Slip & Cut 68' of drilling line. Inspect brakes & Top Drive. Trip back in hole on elevators, until run out of downweight @ 10087'. Observed good hole conditions and no issues. Make up Top Drive on each stand and wash & ream from 10087' - 12928' (2841'). Pump @ 44 SPM -1000 PSI Rotating @ 100 RPM's with Printed: 2/13/2006 12:29:18 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 J-166 Common Well Name: 1J-166 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Sub ' Phase Code 2/6/2006 07:30 - 12:00 4.50 DRILL REAM PROD3 12:00 - 14:45 I 2.751 DRILL I CIRC I PROD3 14:45 - 16:00 I 1.251 DRILL I CIRC I PROD3 16:00 - 22:00 6.001 DRILL (TRIP PROD3 22:00 - 23:30 I 1.501 DRILL I PULD I PROD3 23:30 - 00:00 0.50 DRILL OTHR CMPLT3 2/7/2006 00:00 - 00:15 0.25 DRILL SURV CMPLT3 00:15 - 01:15 1.00 DRILL PULD CMPLT3 01:15 - 02:15 I 1.001 DRILL I PULD I CMPLT3 02:15 - 02:30 0.251 DRILL i PULD CMPLT3 02:30 - 06:45 i 4.25 ~ DRILL ~ TRIP ~ CMPLT3 06:45 - 07:15 I 0.501 DRILL I I CMPLT3 07:15 - 07:45 I 0.501 DRILL I CIRC I CMPLT3 07:45 - 11:00 3.251 DRILL ~ TRIP i CMPLT3 11:00 - 12:00 ~ 1.001 DRILL ~ PULD ~ CMPLT3 12:00 - 13:00 I 1.001 DRILL PULD CMPLT3 13:00 - 13:45 I 0.751 CASE I RURD I CMPLT3 Page 21 of 25 Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations 7K Torque. We were able to TIH on elevators from 11294' - 11496' (202') with 35 - 40K downweight, and no pump or rotation needed. Continue wash & ream from 12928'-12994' MD (66') 3530' TVD. Pump a 30 BBL Hi Vis Weighted sweep, and circulate 3 bottoms up to verify clean hole conditions While reciprocat & rotate drill string. Pump @ 82 SPM -300 GPM, 4000 PSI. 120 RPM's, 7-8K torque. PU WT = 180K, SO WT = 35K, Rotating WT = 105K. Monitor well -static. Held PJSM. Discussed Safety & Spill Issues. ,Assigned a Spill Champion for Displacement. Displace well with 8.7 PPG SFMOBM @ 300 GPM - 3950 PSI. Observe drill string torque up and stalled@ 11 K, 100 strokes short of displacement. Finish Displacement. Suspect difference in Lubricity from MOBM would not allow free rotation without excessive torque. POOH on elevators from 12994' - 369'. (12625'). Observed pulling up to 40K over at times initially off bottom, and hole taking proper fill. No issues while POOH. Breakout & lay down BHA # 10. Layed down 4" HWDP, Drilling Jars, and 1 stand Non Mag Flex Drill Collars, Stabilizer & Float Collar. Plug in and down load MWD assembly. Total K-Revs = 46783 Continue Download MWD assembly. Breakout & lay down remaining BHA #10. Lay down 6 3/4" Security FSF2641 bit w/ 3 x 21 Jets TFA = 1.015sq in (1.27'), 5200 Geo Pilot #002 (16.22'), NM IBS Stabilizer (5.30'), NM Float Sub (2.41'), 4 314" TM HOC (11.28'),4 3/4" PWD Tool (10.78'), 4 3/4" Slimphase 4 w/ DGR & RES (24.51'), 4 3/4" Smart Stabilizer (3.59'), 4 3/4" DM HOC (8.55'), GP Non MAg Flex Pony Collar (11.54'). Grade Bit @ 1 / 1 / ER / A/X/I/NO/TD. Clear & Clean rig Floor Area. Pull 31 Lo-Tads to floor. Held PJSM. Discuss Safety issues and installation of Lo-Tads. Make up BHA # 11. MU Baker Retrieving Hook (7.50'), 1 - jnt of 3 1/2" HWDP (28.84'), 4 3/4" Float Sub (2.41'), 4 3!4" Bumper Jar (7.87'), 4 3/4" Oil Jar (11.14'), Crossover (1.04') and 3 -stands of Hybrid Push Pipe (270.06'). Trip in hole from 328' -5000' (4672'). Install 31 total Lo-Tads on stands while RIH. PU WT = 128K, SO WT =98K. Observe hole taking proper fill. Locate & wash retrieving slot pumping @ 4 BPM - 700 PSI. Attempt to engage slot. Work drill string installing 3/4 RH turns in string until observe engaged whipstock slot. Pull up to verify and fire jars with 75K overpull, whipstock free. Increase in upweight 5K. Pull up 30' no swabbing observed. Circulate bottoms up @ 7 BPM - 72 SPM - 1400 PSI. No gas or fluid loss Monitor well -static. POOH from 4972' -328' (4644'). Observe hole taking proper Hole fill. Rack back 3 stands of Hybrid Push pipe, Breakout & lay down retrieving Hook BHA. Layed down Baker Retrieving Hook (7.50'), 1 -jnt of 3 1/2" HWDP (28.84'), 4 3/4" Float Sub (2.41'), 4 3/4" Bumper Jar (7.87'), 4 314" Oil Jar (11.14'), Crossover (1.04') Breakout & Lay down Whipstock and space out assembly. Inspect Whipstock slide. Indications of milling full 12' on slide. Seals looked good. Clear & Clean rig floor area. Pull tools to floor. RU Liner running tools. Printed: 2!1312006 12:29:18 PM ConocoPhillips Alaska Page 22 of 25 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 2/7/2006 13:45 - 17:30 1 J-166 1 J-166 ROT -DRILLING n1334@ppco.com Doyon141 Hours Code I Sub Code 3.75 CASE ~ RUNC Phase Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: 17:30 - 18:15 18:15 - 22:00 22:00 - 00:00 2/8/2006 00:00 - 00:15 00:15 - 00:45 00:45 - 02:30 02:30 - 03:00 03:00 - 06:00 06:00 - 07:00 07:00 - 07:30 07:30 - 12:00 12:00 - 15:00 CMPLT3 0.75 RIGMNT RGRP CMPLT3 3.75 CASE RUNC CMPLT3 2.001 CASE I RUNC I CMPLT3 0.251 CASE I RUNC I CMPLT3 0.501 CASE RUNL I CMPLT3 1.751 CASE I RUNL I CMPLT3 0.501 CASE I RUNL I CMPLT3 Description of Operations PJSM, Discuss Safety Issues and procedure to run 4 1/2" Liner assembly. Make up 31/2" Bent joint with Guide shoe & crossover. Continue RIH picking up 4 1/2" liner. Avg. make up torque = 3500 ft/Ibs. Install total of 250 Hydroform Centralizers on each joint except constrictorjnts. Constrictors installed as to be spaced out at 10505', 9806', 8565', 8347', 8005', and 7825'. Total Slotted joints ran = 217, length = 6681.05'. Total Blank joints ran = 39. Total length = 1204.07'. 192 total stop rings run on first 160 joints, and last 32 joints. Trouble shoot hydraulic problem with Power Tongs. Motor failed. Lay down bad tings, and RU backup set. Continue run 4 112" Liner to 7960'. PU WT = 86K, SO WT = 55K. Obtain TAD parameters every 10 joints on TIH. PJSM. Discuss Safety issues and procedure for making up Slimhole MWD assembly. Pull tools to floor and RU tongs. Make up Slimhole MWD assembly as per MWD & BOT hands. Orient MWD to 180 Degrees out from Hook Hanger hook. Continnue Making up Slim Hole MWD Assembly, and Hook Hanger. PU WT = 87K, SO WT = 60K. Pick up 1 stand of DP, pertorm shallow pulse test @ 33 SPM, 117 GPM, 600 PSI. Good test. Continue run liner on Drill pipe from 7960' - 8359' (399'). Observed Guide shoe tracked ion to Old hole and bottomed out. Set down 10K. POOH with 5 stands of Drilll pipe, and stand back 3 stands of 4 1/2" liner. With guide shoe above kick off point, rotate 3.5 right hand turns in liner. PU WT = 97K, SO WT = 55K. Run in hole with 4 1/2" liner from derrick and continue with Drill Pipe. NOTE: We did not breakout MWD asembly as it was stood back in Derrick with Hook Hanger. Observed Guide shoe assembly in new hole. 3.00 CASE RUNL CMPLT3 Continue RIH with liner on drill pipe from 8444' - 12906'. No issues running through fault area at 10160'. Tagged bridge at 12906'. PU WT = 187K. 1.00 CASE RUNL CMPLT3 Work string to observe getting past bridge area, and continue to RIH, observing weight falling off, and having to pick up and work through spots. Locate bottom of window @ 5019', working string to allow Hook Hanger to Hook. Obtain good MWD reading @ 20 Deg. L, set Hook on window @ 5019' MD, and observe survey @ 8 deg. L two times. PU 20', turn string 180 Deg. Work torque to Hook ,and slack off 8' past bottom of window. Observe difficulty in moving string as the weight did not allow us to move freely. Pull up hole 30'. Install 180 Deg turn in string. Work torque down to Hook. MWD survey at 8 Deg. Left. Set Hook Hanger with better movement in string as we worked it, observing MWD survey @ 6 Deg Right when set. Repeat same operation with the same 6 Deg. Right survey 2 times to confirm definite Hook Hanger Hooked on window @ 5019' MD = 2' Low . UP & Down weights while working string 175-200K up, 50 -30K down. 0.50 CASE RUNC CMPLT3 Rig up, drop 29/32" ball. Pump ball down @ 3 BPM - 700 PSI until observe ball seated @ 448 strokes. Bring pressure up to 2950 PSI, wait 3 minutes, continue bring pressure up to 4200 PSI to shear ball seat. Bleed all pressures. Pick up to verify free of Hook Hanger and loss of weight. PU WT = 125K, SO WT = 105K. 4.50 CMPLTN TRIP CMPLT3 POOH with Drill pipe, inspecting & removing all Lo-Tads, and Super Sliders. Racking back drill pipe in derrick to drain. Crew Change 3.00 CMPLTN TRIP CMPLT3 Continue POOH standing back DP, inspecting and removing all Printed: 2/13/2006 12:29:18 PM ConocoPhillips Alaska Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date I From - To Operations Summary Report 1 J-166 1 J-166 ROT -DRILLING n1334@ppco.com Doyon 141 Hours Code Sub Phase Gode 12/8/2006 112:00 - 15:00 I 3.001 CMPLTNI TRIP I CMPLT3 15:00 - 15:45 0.75 CMPLTN SFTY CMPLT3 15:45 - 17:00 1.25 CMPLTN TRIP CMPLT3 17:00 - 18:00 I 1.001 CMPLTNI TRIP I CMPLT3 18:00 - 18:30 I 0.501 CMPLTNI OTHR I CMPLT3 18:30 - 19:30 I 1.001 CMPLTNI SFTY I CMPLT3 19:30 - 20:00 I 0.501 CMPLTNI OTHR ~ CMPLT3 20:00 - 00:00 4.00 CMPLTN OTHR CMPLT3 2/9/2006 00:00 - 09:15 9.25 CMPLTN OTHR CMPLT3 09:15 - 09:45 0.50 CMPLTN OTHR CMPLT3 09:45 - 10:00 0.25 CMPLTN OTHR CMPLT3 10:00 - 10:15 0.25 CMPLTN OTHR CMPLT3 10:15 - 11:15 1.00 CMPLTN PULD CMPLT3 11:15 - 12:00 0.75 CMPLTN PULD CMPLT3 12:00 - 15:45 3.75 CMPLTN PULD CMPLT3 15:45 - 17:30 1.75 CMPLTN PULD CMPLT3 17:30 - 18:00 0.50 CMPLTN NUND CMPLT3 18:00 - 00:00 6.00 CMPLTN RUNT CMPLT3 12/10/2006 00:00 - 00:30 I 0.501 CMPLTNI RUNT CMPLT3 00:30 - 01:00 0.501 CMPLTNI RUNT ~ CMPLT3 01:00 - 02:30 ~ 1.50 ~ CMPLTNI RUNT ~ CMPLT3 Page 23 of 25 Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Description of Operations Lo-Tads & Super Sliders. Floor hand pinched fingers between Iron Roughneck, and Stump. Send hand to Medic immediately. Safety stand down on rig. Review & investigate incident with crew. Lay down last Lo-Tad. Stand back last stand. Clean off all Lo-Tads for SPCC, load & send outside. Clean off all sliders and send outside. Clear & clean floor area. Rig up, Breakout, inspect & lay down all Liner running tools and MWD assembly. All tools looked good. Rig up Mouse hole for laying down drill string. PJSM. Discuss safety issues and procedure for laying down drill pipe from derick. Incident investigation of accident on floor. Re-enact accident and inspect all equipment. All day & night supervisors participated. Discuss accident & prevention with crew. Change out hinge pins on doors of Iron Roughneck. Pull barrells of thread protectors to floor, rig up floor area and pipe shed to lay down drill pipe. Lay down dril pipe from derrick. PJSM. Discuss Safety issues and procedure to lay down DP using mousehole.. Continue lay down 74 stands of DP, 15 Stands of Hybrid Push Pipe, and 7 stands of 4" HWDP. Clear & Clean rig floor area. Send tools out. PJSM. Discuss safety issues and forward plan with crew. Changing out Geo-Span unit, Rigging up 4 1/2" Liner running equipment, & Running 4 1/2" Tbg in hole. Change out Geo-span unit on rig floor. Send old one to town for inspection. Rig up 4 1/2" Tubing running equipment. Double stack tongs. Run 4 1/2" Tubing in hole to 300'. Crew Change PJSM, with crew. Discuss Safety issues and forward plan as above. Continue RIH with a total of 123 joints of 4 1/2" tubing. POOH, rack back 41 stands of 4 1/2" tubing. 123 joints. Rig up bushing puller. BOLDS & pull wear bushing. Pull Centrilift equipment to rig floor. Stack, count & record clamps. PJSM with entire rig team &centrilift. Discuss safety issues including well control, and all pinch points & lifting procedures for equipment. Pull ESP cable to floor and hang sheave. Make up Baker Centrilift 5.62" OD 418 HP KMHFER 2610 Motor (33.85'), with 4.60" A-Well pump gauge (2.11') and 6" OD centralizer (2.00'). MU 5.13" Tandem Seal Section GSB 3 DB AB/HSN PFSA (13.80'),5.13" OD TTC Crossover w/ Screen Intake with 4-1/2" IBT pup (20.43'). Install oil, and CPAI witness free rotation of motor, utilizing CPAI checklist for installation of ESP assembly. SIMOPS: Change out mud pump liners to 6" in #1 pump. PJSM with entire rig team &centrilift. Discuss safety issues including well control, and all pinch points & lifting procedures for equipment.Continue running ESP Completion. Pick up #1 & #2 joints of 4 1/2" tubing.Start to PU A-Well Discharge Pressure sub. Observed that the OD of the Discharge Pressure sub measured at 6 3/8" OD. The ESP line OD = 5/8" Total = 7" OD. 7 5/8 casing ID = 6.875". Discuss options with town. Decision to run completion without it. Lay down Pressure sub & send out. Install 4 1/2" pup joint in place of Pressure sub. 9.87' long. Secure & plug unused "I" Line from A-well pump. Printed: 2/13/2006 12:29:18 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 1 J-166 1 J-166 ROT -DRILLING n1334@ppco.com Doyon141 Page 24 of 25 Spud Date: 1/8/2006 Start: 1/7/2006 End: 2/11/2006 Rig Release: 2/11/2006 Group: Rig Number: Date From - To Hours Code Code I Phase 2/10/2006 02:30 - 03:00 03:00 - 04:30 04:30 - 05:00 05:00 - 06:15 06:15 - 07:00 07:00 - 07:30 07:30 - 12:00 12:00 - 14:00 14:00 - 16:45 16:45 - 20:15 20:15 - 21:00 i 21:00 - 00:00 2/11 /2006 00:00 - 01:30 01:30 - 02:15 03:30 - 04:15 04:15 - 04:30 Description of Operations - - - -- 0.50 CMPLTN RUNT CMPLT3 Conduct Insulation test on ESP Line. Good Test. 1.50 CMPLTN RUNT CMPLT3 Continue RIH with 4 1/2" tubing. Install GLM's # 1 & #2 to be positioned in well at depths of 3215' & 2606' as planned. Avg Make up torque on tubiing = 3000 Ft / lbs. 0.50 CMPLTN RUNT CMPLT3 Conduct Insulation test on ESP Line. A-well Representative indicated a bad test, but advised continu running in hole as he believed the test unit he used was faulty. He repaired unit while continue RIH. 1.25 CMPLTN RUNT CMPLT3 Continue RIH with 4 1/2" tubing to 1775' . 0.75 CMPLTN RUNT CMPLT3 Conduct Insulation test on ESP Line. A-well Representative indicated a bad test, after repairing test unit and verifying bad test on A-Well pump. Recommend POOH to A-Well Pump. 0.50 CMPLTN PULD CMPLT3 PJSM. Discuss safety issue & procedure on POOH, and prepare matting boards with pit liner for ESP line, for Spill prevention. 4.50 CMPLTN PULD CMPLT3 POOH with 4 1/2" ESP completion tubing. Removing all Clamps, SS Bands. Standing back tubing in Derrick, and lay down GLM's. Disconnect ESP line from motor. Attempt to break out centrailizer, threads galled. Remove A-Well Pump Gauge. Crew Change. Observe "1" line was damaged when initially clamped up to motor assembly. 2.00 CMPLTN PULD CMPLT3 Continue remove A-Well Pump gauge from Motor. Remove unused & damaged "I" line. Install new A-Well Gauge & Centralizer. Service Motor. Re-attach ESP line, service seals, and test equipment. RIH with Motor Assembly. 2.75 CMPLTN RUNT CMPLT3 Pick up 2 joints of 4 1/2" tubing from shed, 10' pup. RIH making up GLM's as mentioned above, installing cannon clamps on every other joint of tubing as per Centrilift Rep. RIH back to 1775'. 3.50 CMPLTN RUNT CMPLT3 Continue RIH with ESP conpletion assembly on 4 1/2" Tbg. Install Cannon Clamps on every other joint as per Centrilift Rep. Pick up GLM's #3 & #4, spaced out to be located in well at 148', and 94' as planned. 0.75 CMPLTN RUNT CMPLT3 Pick up landing joint. MU Vetco Gray 11" x 4 1/2" Hanger with 4.909" MCA top with 4 1/2" tubing joint made up on it, (30.00'). Install TWC into hanger for RIH. MAke up joint to string and obtain UP WT = 82K, SO WT = 68K. Located hanger close to floor for Slice as per Centrilift Rep. Used a total of 68 Cannon Clamps, 4 stainless steel bands, 3 Protectolizers, and 2 Flat Guards. 3.00 CMPLTN RUNT CMPLT3 Splice ESP cable to hanger pigtail as per Centrilift Rep. SIMOPS:. Clear & Clean Floor area. Lay down all tubing running equipment. Count used clamps. Lay down Sheave with unused ESP line. Clean up all pit liner on matting boards and prepare Spooling unit for removal. Observed NO SPILLS on ground from ESP line & Spooling Unit. 1.50 CMPLTN RUNT CMPLTN Continue Splice ESP cable to hanger pigtail as per Centrilift Rep. SIMOPS:. Clear & Clean Floor area. Lay down all tubing running equipment. Count used clamps. Lay down Sheave with unused ESP line. Rig down Spooling unit, prepare to move unit. 0.75 CMPLTN RUNT CMPLTN Make up Pigtail ESP to Penetrator on Hanger. Band line to tubing 7 perform Insulation test on ESP line. Good test. RIH land Tbg Hanger as per Vetco Gray Rep. UP WT =82K, SO WT = 70K. Ensure hanger seated. RILDS. Perform packoff tests on upper & lower packoff seals. Test to 250 PSI LOW, 5000 PSI High. 10 Minutes each. Witnessed by Co. Rep. 0.75 CMPLTN NUND CMPLTN Nipple down BOP stack, lines and Flow nipple. 0.25 CMPLTN NUND CMPLTN Perform insulation test on ESP line after Nipple Down. Good Test. Nnntea: zn3rzooe ~z:zy:~a rm ConocoPhillips Alaska Page 25 of 25 Operations Summary Report Legal Well Name: 1 J-166 Common Well Name: 1J-166 Spud Date: 1/8/2006 Event Name: ROT -DRILLING Start: 1/7/2006 End: 2/11/2006 Contractor Name: n1334@ppco.com Rig Release: 2/11/2006 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code ~ Code Phase Description of Operations 2/11!2006 04:30 - 06:30 2.00 CMPLTN NUND CMPLTN Nipple up Adapter Flange & Tree. Install Actuator valve. Perform Insulation test on ESP line afrter NU. Final test. Good. 06:30 - 07:00 0.50 CMPLTN NUND CMPLTN Fill Tree with Diesel. Rig test equipment & test tree to 250 PSI LOW, 5000 PSI High. Good Test. 07:00 - 07:30 0.50 CMPLTN FRZP CMPLTN PJSM with crew and Little Red Hot Oil Reps. Discuss Safety issues and procedure to pump freeze protect Diesel as well as Spill prevention. Rig up Little Red, test lines to 2500 PSI. Good test. SIMOPS: Rig up Scaffold in cellar. Pull TWC. 07:30 - 08:30 1.00 CMPLTN FRZP CMPLTN Freeze protect well by pumping 180 BBLS of Diesel down annulus with returns to tubing, and pits. Pump at 4 BPM - 1175 PSI. 08:30 - 09:00 0.50 CMPLTN FRZP CMPLTN Blow down & rig down Little Red. Secure Tree closing valves. 09:00 - 10:00 1.00 CMPLTN OTHR CMPLTN Rig up Lubricator & install BPV as per Vetco Gray Rep. Rig down Lubricator & Scaffold. Clean out cellar area with Super Sucker. 10:00 - 11:15 1.25 MOVE DMOB MOVE Clean out Rockwasher & last pit. Prepare Rig for Move. 11:15 - 12:00 0.75 MOVE DMOB MOVE Blow down all Steam, water lines, and disconnect all neccessary Hydraulic, air, water, and steam lines. Rig Released at 1200 HRS for move Rig to 1 J-159. Printetl: 2/13/2D06 12:29:18 PM Halliburton Company;; Global Report i'um~,:ui}~: C~nocoPhillips Alaska Inc. Uarc: 313/~OOo I'imc: 15.06.27 Pair. 1 Picl~l: Kupanik River Unit (~~~-urdinaitclAFj It cli•rrncr WeIL 1J-166, True North ~1ih•: Kuparuk 1J Pad ~~cr~iril~I'V~Il) Ncf ~~rcncc: 9J-16GL1: 1G9-0 ~~ cll: 1 J-166 tiectiun (~~S) ]tcfi~rc ncc: Well (O.OON,QOOE.O OOf1za ~Jcll~~ath: 1J-166L'I ~tiurvc}~ ('alculatiun ~1cUux1: Muilmum Curvature Ub: 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 19 27 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: Kuparuk 1J Pad Site Position: Northing: 5945919.64 ft Latitude: 70 15 46.258 N From: Map Easting: 558789.95 ft Longitude: 149 31 29.007 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.45 deg Well: 1J-166 Slot Name: Well Position: +N/-S -227.23 ft Northing: 5945691.74 ft Latitude: 70 15 44.023 N +E/-W -89.01 ft Easting : 558702.73 ft Longitude: 149 31 31.597 W Position Uncertainty: 0.00 ft Wellpath: 1J-166L1 Drilled From: 1J-166L1P61 Tie-on Depth: 9300.88 ft Current Datum: 1J-166L1: Height 109.00 ft Above System D atum: Mean Sea Level Magnetic Data: 1/6/2006 Declination: 24.22 deg Field Strength: 57564 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 0.00 Survey Program for Definitive Wellpath Date: 3/3/2006 Validated: No Version: 3 Actual From To Survey Toolcode Tool Name ft ft 50.00 723.00 1 J-166 gyro (50.00-723.00) (0) CB-GYRO-SS Camera based gyro single shot 755.46 5347.17 1 J-166 (755.46-6312.36) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5380.00 9300.88 1J-166L1 PB1 (5380.00-9582.35) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9389.00 12890.00 1J-166L1 (9389.00-12890 .00) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey Jill ]ncl 1aim llD S ~sT1D 1';ti I~:r1J ~lapA 11apt; l'nol ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00. 5945691.74 558702.73. TIE LINE 50.00 0.11 163.00 50.00 -59.00 -0.02 0.01 5945691.72 558702.74 CB-GYRO-SS 100.00 0.22 163.87 100.00 -9.00 -0.16 0.05 5945691.58 558702.78 CB-GYRO-SS 200.00 0.16 96.82 200.00 91.00 -0.36 0.24 5945691.38 558702.97 CB-GYRO-SS 300.00 0.15 129.50 300.00 191.00 -0.46 0.48 5945691.28 558703.21 CB-GYRO-SS 400.00 0.22 89.10 400.00 291.00 -0.54 0.77 5945691.21 558703.51 CB-GYRO-SS 448.00 0.37 50.51 448.00 339.00 -0.44 0.98 5945691.31 558703.72 CB-GYRO-SS 540.00 0.70 272.11 540.00 431.00 -0.23 0.65. 5945691.52 558703.38 CB-GYRO-SS 630.00 4.15 258.63 629.90 520.90 -0.85 -3.09 5945690.86 558699.64 CB-GYRO-SS 723.00 9.11 253.90 722.25 613.25 -3.56 -13.47 5945688.08 558689.29 CB-GYRO-SS 755.46 10.23 253.96 754.25 645.25 -5.07 -18.71 5945686.53 558684.06 MWD+IFR-AK-CAZ-SC 800.29 11.50 250.47 798.28 689.28 -7.66 -26.75 5945683.87 558676.04 MWD+IFR-AK-CAZ-SC 844.21 11.01 247.29 841.35 732.35 -10.74 -34.74 5945680.73 558668.07 MWD+IFR-AK-CAZ-SC 934.25 12.79 252.02 929.46 820.46 -17.14 -52.16 5945674.19 558650.71 MWD+IFR-AK-CAZ-SC 1025.65 14.38 250.54 1018.30 909.30 -24.05 -72.48 5945667.13 558630.44 MWD+IFR-AK-CAZ-SC 1123.61 16.73 248.45 1112.66 1003.66 -33.28 -97.07 5945657.71 558605.93 MWD+IFR-AK-CAZ-SC Halliburton Company.:.,;. Global Report ('omp;ui~: ConoeoPhillipsAlaska Inc. Ilan: ?'3/2006 lime: 15'.06'27 Pa;;c: ? Field; Ku paruk Riwer U nit Cu-un linatc(\I.) K cfercnrc: Well: 1J-166, True North Silt: Ku paruk 1J Paci ~"crtic af (ll I)) ltcf crcucc: IJ -166L1: 169.0 ~4cII: iJ -16E ticcliu n I1~~1 Ilcfcrc nc~~: W211 i0 00N.0.00E.0 OOAzi) 1~ellpa~li: 1J -166L1 Suroc }~~alculatiun ~te[lu~d: Mi nimum Curvatu re Ilh: Oracle ~uicr~ Ill lucl ,1iim 7 AD titi~s "F~'U ~ 1i,ti I~:'11 ~~la~iS ~lapl: Trwl ft dey deg ft ft ft ft ft ft 1218.57 18.46 251.58 1203.18 1094.18 -43.05 -124.05 5945647.73 558579.03 MWD+IFR-AK-CAZ-SC 1312.43 23.25 251.77 1290.86 1181.86 -53.55 -155.76 5945636.99 558547.41 MWD+IFR-AK-CAZ-SC 1405.28 26.40 251.15 1375.12 1266.12 -65.95 -192.71 5945624.29 558510.56 MWD+IFR-AK-CAZ-SC 1496.25 29.08 251.96 1455.63 1346.63 -79.34 -232.88 5945610.60 558470.50 MWD+IFR-AK-CAZ-SC 1588.67 31.16 251.74 1535.57 1426.57 -93.78 -276.95 5945595.81 558426.55 . MWD+IFR-AK-CAZ-SC 1681.66 31.48 250.28 1615.01 1506.01 -109.52 -322.65 5945579.72 558380.98 MWD+IFR-AK-CAZ-SC 1774.60 29.77 250.85 1694.98 1585.98 -125.27 -367.29 5945563.62 558336.46 MWD+IFR-AK-CAZ-SC 1866.00 31.26 251.58 1773.72 1664.72 -140.21 -411.23 5945548.34 558292.65 MWD+IFR-AK-CAZ-SC 1959.32 33.33 252.47 1852.60 1743.60 -155.59 -458.65 5945532.60 558245.35 MWD+IFR-AK-CAZ-SC 2052.31 33.19 251.09 1930.36 1821.36 -171.53 -507.09 5945516.28 558197.04 MWD+IFR-AK-CAZ-SC 2144.84 33.32 258.24 2007.77 1898.77 -184.92 -555.95 5945502.51 558148.29 MWD+IFR-AK-CAZ-SC 2237.05 34.20 266.36 2084.47 1975.47 -191.73 -606.64 5945495.30 558097.66 MWD+IFR-AK-CAZ-SC 2328.42 32.70 266.73 2160.70 2051.70 -194.77 -656.91 5945491.87 558047.42 MWD+IFR-AK-CAZ-SC 2425.32 34.42 273.37 2241.47 2132.47 -194.65 -710.40 5945491.57 557993.94 MWD+IFR-AK-CAZ-SC 2452.74 34.40 276.43 2264.10 2155.10 -193.33 -725.84 5945492.77 557978.49 MWD+IFR-AK-CAZ-SC 2546.43 35.67 281.89 2340.83 2231.83 -184.74 -778.88 5945500.95 557925.39 MWD+IFR-AK-CAZ-SC 2639.81 36.99 286.70 2416.07 2307.07 -171.05 -832.44 5945514.22 557871.73 MWD+IFR-AK-CAZ-SC 2734.07 40.43 293.17 2489.64 2380.64 -150.86 -887.74 5945533.98 557816.27 MWD+IFR-AK-CAZ-SC 2827.46 44.92 296.60 2558.29 2449.29 -124.17 -945.10 5945560.22 557758.71 MWD+IFR-AK-CAZ-SC 2916.42 48.89 302.39 2619.09 2510.09 -92.12 -1001.53 5945591.82 557702.04 MWD+IFR-AK-CAZ-SC 3013.64 51.39 304.85 2681.40 2572.40 -50.79 -1063.65 5945632.67 557639.61 MWD+IFR-AK-CAZ-SC 3107.78 54.97 308.08 2737.82 2628.82 -5.98 -1124.20 5945677.00 557578.72 MWD+IFR-AK-CAZ-SC 3212.63 63.29 312.15 2791.58 2682.58 52.05 -1192.86 5945734.48 557509.62 MWD+IFR-AK-CAZ-SC 3293.01 67.08 314.30 2825.32 2716.32. 102.02 -1245.99 5945784.03 557456.10 MWD+IFR-AK-CAZ-SC 3387.01 67.12 314.00 2861.89 2752.89 162.33 -1308.12 5945843.85 557393.51 MWD+IFR-AK-CAZ-SC 3480.85 67.18 316.43 2898.34 2789.34 223.70 -1369.03 5945904.74 557332.13 MWD+IFR-AK-CAZ-SC 3574.21 67.77 317.21 2934.10 2825.10 286.59 -1428.04 5945967.16 557272.63 MWD+IFR-AK-CAZ-SC 3668.21 67.15 317.80 2970.14 2861.14 350.60 -1486.69 5946030.71 557213.49 MWD+IFR-AK-CAZ-SC 3759.77 67.37 317.37 3005.53 - 2896.53 412.94 -1543.65 5946092.60 557156.06 MWD+IFR-AK-CAZ-SC 3854.31 66.02 318.81 3042.93 2933.93 477.55 -1601.65 5946156.74 557097.56 MWD+IFR-AK-CAZ-SC 3948.54 66.04 318.80 3081.21 2972.21 542.34 -1658.36 5946221.08 557040.36 MWD+IFR-AK-CAZ-SC 4042.25 66.49 317.82 3118.93 3009.93 606.40 -1715.41 5946284.69 556982.81 MWD+IFR-AK-CAZ-SC 4135.67 67.17 319.34 3155.69 3046.69 670.80 -1772.22 5946348.64 556925.50 MWD+IFR-AK-CAZ-SC 4229.40 66.96 324.69 3192.24 3083.24 738.80 -1825.33 5946416.22 556871.87 MWD+IFR-AK-CAZ-SC 4323.14 69.48 329.50 3227.04 3118.04 811.87 -1872.57 5946488.91 556824.07 MWD+IFR-AK-CAZ-SC 4416.59 72.03 335.04 3257.86 3148.86 889.94 -1913.57 5946566.65 556782.47 MWD+IFR-AK-CAZ-SC 4509.82 71.51 339.57 3287.04 3178.04 971.60 -1947.73 5946648.04 556747.67 MWD+IFR-AK-CAZ-SC 4602.46 72.84 348.30 3315.44 3206.44 1056.26 -1972.08 5946732.49 556722.66 MWD+IFR-AK-CAZ-SC 4695.65 74.40 352.02 3341.73 3232.73 1144.33 -1987.35 5946820.44 556706.72 MWD+IFR-AK-CAZ-SC 4789.72 74.94 355.52 3366.61 3257.61 1234.50 -1997.19 5946910.52 556696.17 MWD+IFR-AK-CAZ-SC 4882.78 76.89 358.45 3389.26 3280.26 1324.63 -2001.92 5947000.59 556690.74 MWD+IFR-AK-CAZ-SC 4976.26 78.15 1.69 3409.47 3300.47 1415.88 -2001.80 5947091.84 556690.14 MWD+IFR-AK-CAZ-SC 5067.31 78.03 1.76 3428.26 3319.26 1504.93 -1999.12 5947180.90 556692.13 MWD+IFR-AK-CAZ-SC 5161.52 76.62 2.33 3448.93 3339.93 1596.79 -1995.84 5947272.76 556694.69 MWD+IFR-AK-CAZ-SC 5255.35 76.64 1.74 3470.62 3361.62 1688.01 -1992.60 5947364.01 556697.22 MWD+IFR-AK-CAZ-SC 5347.17 79.46 1.37 3489.63 3380.63 1777.80 -1990.17 5947453.80 556698.96 MWD+IFR-AK-CAZ-SC - 5380.00 79.70 1.88 3495.57 3386.57 1810.08 -1989.25 5947486.08 556699.62 MWD+IFR-AK-CAZ-SC 5471.19 85.36 4.15 3507.42 3398.42 1900.32 -1984.49 5947576.35 556703.68 MWD+IFR-AK-CAZ-SC 5564.75 90.15 4.52 3511.09 3402.09 1993.52 -1977.42 5947669.59 556710.02 MWD+IFR-AK-CAZ-SC 5658.65 92.00 7.25 3509.33 3400.33 2086.89 -1967.80 5947763.03 556718.91 MWD+IFR-AK-CAZ-SC 5751.74 90.44 7.10 3507.34 .3398.34 2179.23 -1956.17 5947855.45 556729.82 MWD+IFR-AK-CAZ-SC 5845.54 89.89 6.40 3507.07 3398.07 2272.38 -1945.15 5947948.67 556740.11 MWD+IFR-AK-CAZ-SC 5939.31 90.33 8.89 3506.89 3397.89 2365.31 -1932.67 5948041.68 556751.86 MWD+IFR-AK-CAZ-SC Halliburton Company.,; Global Report C'onip:ui}" Conocr,Phillips Alaska Inc. I)atc ~ °~~3~2006 Time: 15'.06'.27 Pnc: 3 I~icld: Ku panik River U nit Cu-u rdinau(6F.) R clcrcucr: Well_ 1J-166. True North Sitc: Ku paruk 1J Nad ~cru ~,il f I~~I1) Rcfc,cucc: 1J -166L1~ 109.0 ~FcIL• 1J -1t36 ~crti on 1~~1 Hc(e~c ncc; Well ~QOON O OOE,000Azi) 1~'ellp:uh: 1J- 166L1 Sur~ ccl~:ilculatiun ~Irth~nl: Mi nimum Curvatu re Ilh: Oracle Fur~c~ ~I1) Intl lzim C1U tiffs lll) 1~,ti 4:111" \la~iV 11>ihl~; lonl ft deg deg ft ft ft ft ft ft 6032.18 90.64 8.25 3506.11 3397.11 2457.14 -1918.84 5948133.61 556764.98 MWD+IFR-AK-CAZ-SC 6126.56 89.21 9.38 3506.23 3397.23 2550.40 -1904.37 5948226.97 556778.72 MWD+IFR-AK-CAZ-SC 6218.80 89.59 10.28 3507.20 3398.20 2641.28 -1888.63 5948317.96 556793.75 MWD+IFR-AK-CAZ-SC 6313.08 90.33 7.03 3507.26 3398.26 2734.47 -1874.44 5948411.25 556807.21 MWD+IFR-AK-CAZ-SC 6405.52 89.77 7.20 3507.18 3398.18 2826.20 -1862.99 5948503.06 556817.94 MWD+IFR-AK-CAZ-SC 6499.15 88.16 2.26 3508.88 3399.88 2919.46 -1855.27 5948596.37 556824.93 MWD+IFR-AK-CAZ-SC 6592.25 88.04 357.96 3511.96 3402.96 3012.49 -1855.09 5948689.39 556824.39 MWD+IFR-AK-CAZ-SC 6685.99 87.23 350.16 3515.84 3406.84 3105.57 -1864.78 5948782.39 . 556813.98 MWD+IFR-AK-CAZ-SC 6778.76 87.92 350.76 3519.76 3410.76 3196.98 -1880.14 5948873.66 556797.91 MWD+IFR-AK-CAZ-SC 6871.79 90.40 355.41 3521.13 3412.13 3289.29 -1891.33 5948965.87 556786.00 MWD+IFR-AK-CAZ-SC 6965.26 90.39 355.86 3520.48 3411.48 3382.49 -1898.45 5949059.00 556778.16 MWD+IFR-AK-CAZ-SC 7059.18 91.57 357.97 3518.88 3409.88 3476.25 -1903.50 5949152.71 556772.37 MWD+IFR-AK-CAZ-SC 7152.37 88.21 2.40 3519.06 3410.06 3569.40 -1903.20 5949245.85 556771.95 MWD+IFR-AK-CAZ-SC 7245.72 88.41 5.39 3521.81 3412.81 3662.49 -1896.86 5949338.98 556777.56 MWD+IFR-AK-CAZ-SC 7339.27 90.40 7.23 3522.78 3413.78 3755.45 -1886.58 5949432.01 556787.11 MWD+IFR-AK-CAZ-SC 7432.58 90.76 5.36 3521.84 3412.84 3848.19 -1876.35 5949524.82 556796.62 MWD+IFR-AK-CAZ-SC 7526.08 91.07 2.54 3520.34 3411.34 3941.45 -1869.91 5949618.11 556802.33 MWD+IFR-AK-CAZ-SC 7619.85 92.37 359.81 3517.53 3408.53 4035.15 -1867.99 5949711.82 556803.52 MWD+IFR-AK-CAZ-SC 7713.05 90.63 355.82 3515.09 3406.09 4128.22 -1871.54 5949804.85 556799.24 MWD+IFR-AK-CAZ-SC 7808.78 91.26 356.84 3513.51 3404.51 4223.74 -1877.67 5949900.31 556792.37 MWD+IFR-AK-CAZ-SC 7901.09 88.83 358.92 3513.44 3404.44 4315.98 -1881.08 5949992.51 556788.24 MWD+IFR-AK-CAZ-SC 7995.18 89.90 3.76 3514.48 3405.48 4410.01 -1878.88 5950086.54 556789.71 MWD+IFR-AK-CAZ-SC 8089.21 90.74 7.27 3513.95 3404.95 4503.59 -1869.85 5950180.18 556798.01 MWD+IFR-AK-CAZ-SC 8181.21 91.01 6.43 3512.55 3403.55 4594.92 -1858.88 5950271.59 556808.27 MWD+IFR-AK-CAZ-SC 8274.54 88.96 0.79 3512.57 3403.57 4688.02 -1853.00 5950364.72 556813.42 MWD+IFR-AK-CAZ-SC 8368.09 86.54 356.14 3516.25 3407.25 4781.43 -1855.50 5950458.10 556810.19 MWD+IFR-AK-CAZ-SC 8460.63 87.56 356.65 3521.01 3412.01 4873.66 -1861.31 5950550.28 556803.66 MWD+IFR-AK-CAZ-SC 8554.10 90.65 357.77 3522.47 3413.47 4967.00 -1865.86 5950643.57. 556798.39 MWD+IFR-AK-CAZ-SC 8647.50 89.77 357.48 3522.13 3413.13 5060.32 -1869.73 5950736.84 556793.79 MWD+IFR-AK-CAZ-SC 8740.14 88.28 0.94 3523.70 3414.70 5152.92 -1871.01 5950829.42 556791.79 MWD+IFR-AK-CAZ-SC 8832.29 88.79 2.39 3526.06 3417.06 5245.00 -1868.33 5950921.51 556793.75 MWD+IFR-AK-CAZ-SC 8926.27 87.23 1.76 3529.32 3420.32 5338.85 -1864.93 5951015.38 556796.42 MWD+IFR-AK-CAZ-SC 9020.36 90.35 0.78 3531.31 3422.31 5432.89 -1862.85 5951109.42 556797.77 MWD+IFR-AK-CAZ-SC 9113.19 90.76 0.76 3530.41 3421.41 5525.71 -1861.60 5951202.23 556798.29 MWD+IFR-AK-CAZ-SC 9207.63 88.53 359.03 3531.00 3422.00 5620.13 -1861.77 5951296.65 556797.38 MWD+IFR-AK-CAZ-SC 9300.88 88.47 359.39 3533.44 3424.44 5713.34 -1863.06 5951389.84 556795.37 MWD+IFR-AK-CAZ-SC 9389.00 87.01 358.53 3536.91 3427.91 5801.38 -1864.66 5951477.85 556793.09 MWD+IFR-AK-CAZ-SC 9490.20 85.19 2.01 3543.80 3434.80 5902.32 -1864.18 5951578.78 556792.77 MWD+IFR-AK-CAZ-SC 9582.89 84.70 2.52 3551.96 3442.96 5994.58 -1860.54 5951671.06 556795.70 MWD+IFR-AK-CAZ-SC 9676.31 86.76 3.51 3558.92 3449.92 6087.60 -1855.63 5951764.11 556799.88 MWD+IFR-AK-CAZ-SC 9769.19 85.25 2.90 3565.39 3456.39 6180.11 -1850.45 5951856.64 556804.33 MWD+IFR-AK-CAZ-SC 9860.68 88.80 3.99 3570.14 3461.14 6271.30 -1844.96 5951947.86 556809.11 MWD+IFR-AK-CAZ-SC 9955.46 88.29 1.66 3572.55 3463.55 6365.92 -1840.29 5952042.51 556813.04 MWD+IFR-AK-CAZ-SC 10047.91 88.17 357.71 3575.40 3466.40 6458.31 -1840.80 5952134.88 556811.82 MWD+IFR-AK-CAZ-SC 10141.84 89.22 357.22 3577.54 3468.54 6552.12 -1844.95 5952228.65 556806.93 MWD+IFR-AK-CAZ-SC 10235.71 88.97 357.12 3579.02 3470.02 6645.86 -1849.59 5952322.35 556801.57 MWD+IFR-AK-CAZ-SC 10329.12 96.00 1.31 3574.98 3465.98 6739.10 -1850.88 5952415.56 556799.56 MWD+IFR-AK-CAZ-SC 10422.56 99.97 1.65 3562.00 3453.00 6831.58 -1848.49 5952508.05 556801.22 MWD+IFR-AK-CAZ-SC 10515.59 98.31 2.38 3547.22. 3438.22 6923.37 -1845.26 5952599.85 .556803.74 MWD+IFR-AK-CAZ-SC 10609.03 95.44 2.86 3536.04 3427.04 7016.03 -1841.02 5952692.53 .556807.26 MWD+IFR-AK-CAZ-SC 10702.44 92.97 2.03 3529.19 3420.19 7109.10 -1837.04 5952785.62 556810.50 MWD+IFR-AK-CAZ-SC 10795.91 92.05 0.01 3525.09 3416.09 7202.46 -1835.38 5952878.98 556811.44 MWD+IFR-AK-CAZ-SC Halliburton Company ;~ Global Report (~~uulrui}~: ConoroPhillips Alaska Inc. hats-: 3/3;2006 Time: 15C62i Pae: ~ Ficl~l: Ku paruk Rlver U nit (~i-ur din-itcl~l~:1 IZc lcrcncc: lNelf- 1J-166_ True North ~ilc: Kuparuk 1J Pad ~crnc ;il ("f~l)) Kcfc rencc: 1J- 166L1. 169.0 11c11: 1J-166 ~ccliu n (~~,5) l2rfcrc ucc We ll (O.OON.000E O OOAzi'! ~1dlpalh: 1 J-166L1 Surect~ ('alrulation ~lcrhod: Min imum Curvatur e Uh: Oracle tiurce~ 111) Lu•1 ,~iiw 7 ~ D tivti ~Il~l) ~ \-~ L1~1 V:y~A ~IaE~I~; ~h~ii>I ft deg deg ft f? ft ft ft ft 10890.62 90.81 358.48 3522.73 3413.73 7297.13 -1836.63 5952973.63 556809.45 MWD+IFR-AK-CAZ-SC 10984.77 91.82 356.20 3520.57 3411.57 7391.14 -1841.00 5953067.60 556804.35 MWD+IFR-AK-CAZ-SC 11075.50 88.39 355.38 3520.40 3411.40 7481.61 -1847.66 5953158.00 556796.99 MWD+IFR-AK-CAZ-SC 11161.33 87.73 354.74 3523.31 3414.31 7567.07 -1855.04 5953243.40 556788.93 MWD+IFR-AK-CAZ-SC 11255.15 87.42 356.74 3527.28 3418.28 7660.55 -1862.01 5953336.80 556781.24 MWD+IFR-AK-CAZ-SC 11346.09 89.23 1.79 3529.94 3420.94 7751.41 -1863.17 5953427.64 556779.37 MWD+IFR-AK-CAZ-SC 11436.61 89.59 1.82 3530.87 3421.87 7841.88 -1860.32 5953518.12 556781.52 MWD+IFR-AK-CAZ-SC 11528.88 90.71 1.72 3530.63 3421.63 7934.10 -1857.47 5953610.36 556783.65 MWD+IFR-AK-CAZ-SC 11619.76 87.47 4.53 3532.07 3423.07 8024.81 -1852.52 5953701.10 556787.89 MWD+IFR-AK-CAZ-SC 11709.38 89.10 359.32 3534.76 3425.76 8114.31 -1849.51 5953790.60 556790.20 MWD+IFR-AK-CAZ-SC 11799.66 87.91 0.08 3537.11 3428.11 8204.55 -1849.98 5953880.84 556789.02 MWD+IFR-AK-CAZ-SC 11889.37 85.92 358.71 3541.94 3432.94 8294.12 -1850.93 5953970.38 556787.38 MWD+IFR-AK-CAZ-SC 11979.16 86.32 4.37 3548.02 3439.02 8383.64 -1848.52 5954059.91 556789.09 MWD+IFR-AK-CAZ-SC 12072.21 86.81 3.03 3553.60 3444.60 8476.32 -1842.53 5954152.63 556794.36 MWD+IFR-AK-CAZ-SC 12163.05 88.30 357.29 3557.47 3448.47 8567.04 -1842.28 5954243.34 556793.90 MWD+IFR-AK-CAZ-SC 12250.67 88.54 0.27 3559.89 3450.89 8654.60 -1844.14 5954330.87 556791.36 MWD+IFR-AK-CAZ-SC 12343.53 88.66 3.19 3562.16 3453.16 8747.38 -1841.34 5954423.66 556793.44 MWD+IFR-AK-CAZ-SC 12434.50 88.66 1.83 3564.29 3455.29 .8838.23 -1837.36 5954514.53 556796.71 MWD+IFR-AK-CAZ-SC 12526.50 87.35 1.93 3567.49 3458.49 8930.13 -1834.34 5954606.44 556799.01 MWD+IFR-AK-CAZ-SC 12618.23 84.62 359.66 3573.91 3464.91 9021.61 -1833.07 5954697.92 556799.57 MWD+IFR-AK-CAZ-SC 12709.72 88.62 359.21 3579.31 3470.31 9112.91 -1833.97 5954789.21 556797.96 MWD+IFR-AK-CAZ-SC 12799.00 85.43 358.86 3583.94 3474.94 9202.05 -1835.47 5954878.32 556795.76 MWD+IFR-AK-CAZ-SC 12890.00 87.37 359.66 3589.65 3480.65 9292.86 -1836.64 5954969.11 556793.88 MWD+IFR-AK-CAZ-SC ~ 12952.00 87.37 359.66 3592.50 - 3483.50 9354.79 -1837.01 5955031.03 556793.03 PROJECTED to TD Halliburton Company,. Global Report Cnnip,ui~°: ConocoPhi!fips Alaska Inc. Datc: 3~'3%?006 I~inre: 15:00:22 Pat:c: 1 l~icld: Kuparuk River Unit Cu-urdiuatcl~~~'.) Rc Crmuc~~: Well: 1J-1 o6. Irue North ~tiitc: Kuparuk 1J Pad ~crlical (lll)) hc(c rcncc: 1J-166L1 109.0 ~~cll: 1J-165 ~cciiun (~S11LcR~rc ncc VVell (O OON.QOOE.O-OOAziI 11'clllxuh: 1J-166L~IPB1 Sung l ;ilcul:~tiun ~Ictlroil: Mirimum Curvatu re Ube 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 Model: bggm2005 Site: Kuparuk 1J Pad Site Position: Northing: 594b919.64 ft Latitude: 70 15 46.258 N From: Map Easting: 558789.95 ft Longitude: 149 31 29.007 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergen ce: 0.45 deg Well: 1 J-166 Slot Name: Well Position: +N/-S -227.23 ft Northing: 5945691.74 ft Latitude: 70 15 44.023 N +E/-W -89.01 ft Easting : 558702.73 ft Longitude: 149 31 31.597 W Position Uncertainty: 0.00 ft W ellpath: 1 J-166L1 PB1 Drilled From: 1 J-166 500292329170 Tie-on Depth: 5347.17 ft Current Datum: 1J-166L1 : Height 109.00 ft Above System Datum: Mean Sea Level Magnetic Data: 1/6/2006 Declination: 24.22 deg Field Strength: 57564 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 0.00 Survey Program for Definitive Wellpath Date: 3/3/2006 Validated: No Version: 3 Actual From To Survey Toolcode Tool Name ft ft 50.00 723.00 1J-166 gyro (50.00-723.00) (0) CB-GYRO-SS Camera based gyro single shot 755.46 5347.17 1J-166 (755.46-6312.36) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5380.00 9582.35 1J-166L1 P61 (5380.00-9582.35) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey ~ ~ ,Mini \1D Incl l'FII S c. f~~U V;ti l~:i~~ 11ap,A ~lapl~_ luol ft deg deg ft ft ~ ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945691.74 558702.73 TIE LINE 50.00 0.11 163.00 50.00 -59.00 -0.02 0.01 5945691.72 558702.74 CB-GYRO-SS 100.00 0.22 163.87 100.00 -9.00 -0.16 0.05 5945691.58 558702.78 CB-GYRO-SS 200.00 0.16 96.82 200.00 91.00 -0.36 0.24 5945691.38 558702.97 CB-GYRO-SS 300.00 0.15 129.50 300.00 191.00 -0.46 0.48 5945691.28 558703.21 CB-GYRO-SS 400.00 0.22 89.10 400.00 291.00 -0.54 0.77 5945691.21 558703.51 CB-GYRO-SS 448.00 0.37 50.51 448.00 339.00 -0.44 0.98 5945691.31 558703.72 CB-GYRO-SS 540.00 0.70 272.11 540.00 431.00 -0.23 0.65 5945691.52 558703.38 CB-GYRO-SS 630.00 4.15 258.63 629.90 520.90 -0.85 -3.09 5945690.86 558699.64 CB-GYRO-SS 723.00 9.11 253.90 722.25 613.25 -3.56 -13.47 5945688.08 558689.29 CB-GYRO-SS 755.46 10.23 253.96 754.25 645.25 -5.07 -18.71 5945686.53 558684.06 MWD+IFR-AK-CAZ-SC 800.29 11.50 250.47 798.28 689.28 -7.66 -26.75 5945683.87 558676.04 MWD+IFR-AK-CAZ-SC 844.21 11.01 247.29 841.35 732.35 -10.74 -34.74 5945680.73 558668.07 MWD+IFR-AK-CAZ-SC 934.25 12.79 252.02 929.46 820.46 -17.14 -52.16 5945674.19 558650.71 MWD+IFR-AK-CAZ-SC 1025.65 14.38 250.54 1018.30 909.30 -24.05 -72.48 5945667.13 558630.44 MWD+IFR-AK-CAZ-SC 1123.61 16.73 248.45 1112.66 1003.66 -33.28 -97.07 5945657.71 558605.93. MWD+IFR-AK-CAZ-SC 1218.57 18.46 251.58 1203.18 1094.18 -43.05 -124.05 5945647.73 558579.03 MWD+IFR-AK-CAZ-SC Halliburton Company,,: Global Report C'~uu~~sn}~: ConocoPhillips Alaska Inc_ l)atc: ~%3i~006 Cinu: 15 C0~22 Pa«c: 3 I~icld: Kuparuk K(ve r Unit Cu-nr~ linst<<.AI'~ R cfrrcncr: W eil IJ-i~6 true North ,1ilc: Kup2ruH: 1J P ad ~'crtir il I~f4U) Kcf crcncc: 1J -166L1 109-0 ~1 cll: 1 J-166 Sectiu u <<~ti1 Ncfcrc nrr. W ell (O.OON.O.OOE,O.OOAzi) ~l~cllpnlic 1 J-166L1P61 ~in~~~cq (altula~inn 1lcttunl: Mi nimum Curvatu re Uh: Oracle ~uncti~ \11) luel Biro llU S~SIIU \;S I~~l' ~1;~1~A ~lapF: ~fnul ft deg deg ft ft ft ft ft ft 1312.43 23.25 251.77 1290.86 1181.86 -53.55 -155.76 5945636.99 558547.41 MWD+IFR-AK-CAZ-SC 1405.28 26.40 251.15 1375.12 1266.12 -65.95 -192.71 5945624.29 558510.56 MWD+IFR-AK-CAZ-SC 1496.25 29.08 251.96 1455.63 1346.63 -79.34 -232.88 5945610.60 558470.50 MWD+IFR-AK-CAZ-SC 1588.67 31.16 251.74 1535.57 1426.57 -93.78 -276.95 5945595.81 558426.55 MWD+IFR-AK-CAZ-SC 1681.66 31.48 250.28 1615.01 1506.01 -109.52 -322.65 5945579.72 558380.98 MWD+IFR-AK-CAZ-SC 1774.60 29.77 250.85 1694.98 1585.98 -125.27 -367.29 5945563.62 558336.46 MWD+IFR-AK-CAZ-SC 1866.00 31.26 251.58 1773.72 1664.72 -140.21 -411.23 5945548.34 558292.65 MWD+IFR-AK-CAZ-SC 1959.32 33.33 252.47 1852.60 1743.60 -155.59 -458.65 5945532.60 558245.35 MWD+IFR-AK-CAZ-SC 2052.31 33.19 251.09 1930.36 1821.36 -171.53 -507.09 5945516.28 558197.04 MWD+IFR-AK-CAZ-SC 2144.84 33.32 258.24 2007.77 1898.77 -184.92 -555.95 5945502.51 558148.29 . MWD+IFR-AK-CAZ-SC 2237.05 34.20 266.36 2084.47 1975.47 -191.73 -606.64 5945495.30 558097.66 MWD+IFR-AK-CAZ-SC 2328.42 32.70 266.73 2160.70 2051.70 -194.77 -656.91 5945491.87 558047.42 MWD+IFR-AK-CAZ-SC 2425.32 34.42 273.37 2241.47 2132.47 -194.65 -710.40 5945491.57 557993.94 MWD+IFR-AK-CAZ-SC 2452.74 34.40 276.43 2264.10 2155.10 -193.33 -725.84 5945492.77 557978.49 MWD+IFR-AK-CAZ-SC 2546.43 35.67 281.89 2340.83 2231.83 -184.74 -778.88 5945500.95 557925.39 MWD+IFR-AK-CAZ-SC 2639.81 36.99 286.70 2416.07 2307.07 -171.05 -832.44 5945514.22 557871.73 MWD+IFR-AK-CAZ-SC 2734.07 40.43 293.17 2489.64 2380.64 -150.86 -887.74 5945533.98 557816.27 MWD+IFR-AK-CAZ-SC 2827.46 44.92 296.60 2558.29 2449.29 -124.17 -945.10 5945560.22 557758.71 MWD+IFR-AK-CAZ-SC 2916.42 48.89 302.39 2619.09 2510.09 -92.12 -1001.53 5945591.82 557702.04 MWD+IFR-AK-CAZ-SC 3013.64 51.39 304.85 2681.40 2572.40 -50.79 -1063.65 5945632.67 557639.61 MWD+IFR-AK-CAZ-SC 3107.78 54.97 308.08 2737.82 2628.82 -5.98 -1124.20 5945677.00 557578.72 MWD+IFR-AK-CAZ-SC 3212.63 63.29 312.15 2791.58 2682.58 52.05 -1192.86 5945734.48 557509.62 MWD+IFR-AK-CAZ-SC 3293.01 67.08 314.30 2825.32 2716.32 102.02 -1245.99 5945784.03 557456.10 MWD+IFR-AK-CAZ-SC 3387.01 67.12 314.00 2861.89 2752.89 162.33 -1308.12 5945843.85 557393.51 MWD+IFR-AK-CAZ-SC 3480.85 67.18 316.43 2898.34 2789.34 223.70 -1369.03 5945904.74 557332.13 MWD+IFR-AK-CAZ-SC 3574.21 67.77 317.21 2934.10 2825.10 286.59 -1428.04 5945967:16 557272.63 MWD+IFR-AK-CAZ-SC 3668.21 67.15 317.80 2970.14 2861.14 350.60 -1486.69 5946030.71 557213.49 MWD+IFR-AK-CAZ-SC 3759.77 67.37 317.37 3005.53 2896.53 412.94 -1543.65 5946092.60 557156.06 MWD+IFR-AK-CAZ-SC 3854.31 66.02 318.81 3042.93 2933.93 477.55 -1601.65 5946156.74 557097.56 MWD+IFR-AK-CAZ-SC 3948.54 66.04 318.80 3081.21 2972.21 542.34 -1658.36 5946221.08 557040.36 MWD+IFR-AK-CAZ-SC 4042.25 66.49 317.82 3118.93 3009.93 606.40 -1715.41 5946284.69 556982.81 MWD+IFR-AK-CAZ-SC 4135.67 67.17 319.34 3155.69 3046.69 670.80 -1772.22 5946348.64 556925.50 MWD+IFR-AK-CAZ-SC 4229.40 66.96 324.69 3192.24 3083.24 738.80 -1825.33 5946416.22 556871.87 MWD+IFR-AK-CAZ-SC 4323.14 69.48 329.50 3227.04 3118.04 811.87 -1872.57 5946488.91 556824.07 MWD+IFR-AK-CAZ-SC 4416.59 72.03 335.04 3257.86 3148.86 889.94 -1913.57 5946566.65 556782.47 MWD+IFR-AK-CAZ-SC 4509.82 71.51 339.57 3287.04 3178.04 971.60 -1947.73 5946648.04 556747.67 MWD+IFR-AK-CAZ-SC 4602.46 72.84 348.30 3315.44 3206.44 1056.26 -1972.08 5946732.49 556722.66 MWD+IFR-AK-CAZ-SC 4695.65 74.40 352.02 3341.73 3232.73 1144.33 -1987.35 5946820.44 556706.72 MWD+IFR-AK-CAZ-SC 4789.72 74.94 355.52 3366.61 3257.61 1234.50 -1997.19 5946910.52 556696.17 MWD+IFR-AK-CAZ-SC 4882.78 76.89 358.45 3389.26 3280.26 1324.63 -2001.92 5947000.59 556690.74 MWD+IFR-AK-CAZ-SC 4976.26 78.15 1.69 3409.47 3300.47 1415.88 -2001.80 5947091.84 556690.14 MWD+IFR-AK-CAZ-SC 5067.31 78.03 1.76 3428.26 3319.26 1504.93 -1999.12 5947180.90 556692.13 MWD+IFR-AK-CAZ-SC 5161.52 76.62 2.33 3448.93 3339.93 1596.79 -1995.84 5947272.76 556694.69 MWD+IFR-AK-CAZ-SC 5255.35 76.64 1.74 3470.62 3361.62 1688.01 -1992.60 5947364.01 556697.22 MWD+IFR-AK-CAZ-SC 5347.17 79.46 1.37 3489.63 3380.63 1777.80 -1990.17 5947453.80 556698.96 MWD+IFR-AK-CAZ-SC 5380.00 79.70 1.88 3495.57 3386.57 1810.08 -1989.25 5947486.08 556699.62 MWD+IFR-AK-CAZ-SC 5471.19 85.36 4.15 3507.42 3398.42 1900.32 -1984.49 5947576.35 556703.68 MWD+IFR-AK-CAZ-SC 5564.75 90.15 4.52 3511.09 3402.09 1993.52 -1977.42 5947669.59 556710.02 MWD+IFR-AK-CAZ-SC 5658.65 92.00 7.25 3509.33 3400.33 2086.89 -1967.80 .5947763.03 556718.91 MWD+IFR-AK-CAZ-SC 5751.74 90.44 7.10 3507.34 3398.34 2179.23 -1956.17 5947855.45 556729.82 MWD+-FR-AK-CAZ-SC 5845.54 89.89 6.40 3507.07 3398.07 2272.38 -1945.15 5947948.67 556740.11 MWD+IFR-AK-CAZ-SC 5939.31 90.33 8.89 3506.89 3397.89 2365.31 -1932.67 5948041.68 556751.86 MWD+IFR-AK-CAZ-SC 6032.18 90.64 8.25 3506.11 3397.11 2457.14 -1918.84 5948133.61 556764.98 MWD+IFR-AK-CAZ-SC. Halliburton Company; Global Report (`onip,u«: C~noccPhillipsAlaska Inc. Ihitc : 3/3/2006 time: 15:00'22 Ps,r. 3 Field: Kupanik River U nit (~~~-o nliu>iu~~AF) R cli~rcncr. W ell. 1J-166. Trua North ~tiitc: Kuparuk iJ Pad ~'cr~i cal (l'~UI Kcferrncc: 1J -166L1 109.0 ~~cll: i J-166 Secti on (~S) Kcfcrc nrc: W ell ~O OON,0.00E O.ODAzii ~~cllpailc 1 J-166L1PB1 Surc c~~ (~alculatiun ~Icthod: Mi nimum Curvatu re Ilh: Oracle tinnr~ ~IU lucl Aziw ~h~U S~ti l~'1) 1r,ti I~:/~1' 1ln~iS Vaipl~: ~fnnl ft deg deg ft ft ft ft rt ft 6126.56 89.21 9.38 3506.23 3397.23 2550.40 -1904.37 5948226.97 556778.72 MWD+IFR-AK-CAZ-SC 6218.80 89.59 10.28 3507.20 3398.20 2641.28 -1888.63 5948317.96 556793.75 MWD+IFR-AK-CAZ-SC 6313.08 90.33 7.03 3507.26 3398.26 2734.47 -1874.44 5948411.25 556807.21 MWD+IFR-AK-CAZ-SC 6405.52 89.77 7.20 3507.18 3398.18 2826.20 -1862.99 5948503.06 556817.94 MWD+IFR-AK-CAZ-SC 6499.15 88.16 2.26 3508.88 3399.88 2919.46 -1855.27 5948596.37 556824.93 MWD+IFR-AK-CAZ-SC 6592.25 88.04 357.96 3511.96 3402.96 3012.49 -1855.09 5948689.39 556824.39 MWD+IFR-AK-CAZ-SC 6685.99 87.23 350.16 3515.84 3406.84 3105.57 -1864.78 5948782.39 556813.98 MWD+IFR-AK-CAZ-SC 6778.76 87.92 350.76 3519.76 3410.76 3196.98 -1880.14 5948873.66 556797.91 MWD+IFR-AK-CAZ-SC 6871.79 90.40 355.41 3521.13 3412.13 3289.29 -1891.33 5948965.87 556786.00 MWD+IFR-AK-CAZ-SC 6965.26 90.39 355.86 3520.48 3411.48 3382.49 -1898.45 5949059.00 556778.16 MWD+IFR-AK-CAZ-SC 7059.18 91.57 357.97 3518.88 3409.88 3476.25 -1903:50 5949152.71 556772.37 MWD+IFR-AK-CAZ-SC 7152.37 88.21 2.40 3519.06 3410.06 3569.40 -1903.20 5949245.85 556771.95 MWD+IFR-AK-CAZ-SC 7245.72 88.41 5.39 3521.81 3412.81 3662.49 -1896.86 5949338.98 556777.56 MWD+IFR-AK-CAZ-SC 7339.27 90.40 7.23 3522.78 3413.78 3755.45 -1886.58 5949432.01 556787.11 MWD+IFR-AK-CAZ-SC 7432.58 90.76 5.36 3521.84 3412.84 3848.19 -1876.35 5949524.82 556796.62 MWD+IFR-AK-CAZ-SC 7526.08 91.07 2.54 3520.34 3411.34 3941.45 -1869.91 5949618.11 556802.33 MWD+IFR-AK-CAZ-SC 7619.85 92.37 359.81 3517.53 3408.53 4035.15 -1867.99 5949711.82 556803.52 MWD+IFR-AK-CAZ-SC 7713.05 90.63 355.82 3515.09 3406:09 4128.22 -1871.54 5949804.85 556799.24 MWD+IFR-AK-CAZ-SC 7808.78 91.26 356.84 3513.51 3404.51 4223.74 -1877.67 5949900.31 556792.37 MWD+IFR-AK-CAZ-SC 7901.09 88.83 358.92 3513.44 3404.44 4315.98 -1881.08 5949992.51 556788.24 MWD+IFR-AK-CAZ-SC 7995.18 89.90 3.76 3514.48 3405.48 4410.01 -1878.88 5950086.54 556789.71 MWD+IFR-AK-CAZ-SC 8089.21 .90.74 7.27 3513.95 3404.95 4503.59 -1869.85 5950180.18 556798.01 MWD+IFR-AK-CAZ-SC 8181.21 91.01 6.43 3512.55 3403.55 4594.92 -1858.88 5950271.59 556808.27 MWD+IFR-AK-CAZ-SC 8274.54 88.96 0.79 3512.57 3403.57 4688.02 -1853.00 5950364.72 556813.42 MWD+IFR-AK-CAZ-SC 8368.09 86.54 356.14 3516.25 3407.25 4781.43 -1855.50 5950458.10 556810.19 MWD+IFR-AK-CAZ-SC 8460.63 87.56 356.65 3521.01 3412.01 4873.66 -1861.31 5950550.28 556803.66 MWD+IFR-AK-CAZ-SC 8554.10 90.65 357.77 3522.47 3413.47 4967.00 -1865.86 5950643.57 556798.39 MWD+IFR-AK-CAZ-SC 8647.50 89.77 357.48 3522.13 3413.13 5060.32 -1869.73 5950736.84 556793.79 MWD+IFR-AK-CAZ-SC 8740.14 88.28 0.94 3523.70 3414.70 5152.92 -1871.01 5950829.42 556791.79 MWD+IFR-AK-CAZ-SC 8832.29 88.79 2.39 3526.06 3417.06 5245.00 -1868.33 5950921.51 556793.75 MWD+IFR-AK-CAZ-SC 8926.27 87.23 1.76 3529.32 3420.32 5338.85 -1864.93 5951015.38 556796.42 MWD+IFR-AK-CAZ-SC 9020.36 90.35 0.78 3531.31 3422.31 5432.89 -1862.85 5951109.42 556797.77 MWD+IFR-AK-CAZ-SC 9113.19 90.76 0.76 3530.41 3421.41 5525.71 -1861.60 5951202.23 556798.29 MWD+IFR-AK-CAZ-SC 9207.63 88.53 359.03 3531.00 3422.00 5620.13 -1861.77 5951296.65 556797.38 MWD+IFR-AK-CAZ-SC 9300.88 88.47 359.39 3533.44 3424.44 5713.34 -1863.06 8951389.84 556795.37 MWD+IFR-AK-CAZ-SC 9394.63 86.92 358.48 3537.21 3428.21 5807.00 -1864.80 5951483.47 556792.90 MWD+IFR-AK-CAZ-SC 9488.58 88.36 358.89 3541.08 3432.08 5900.84 -1866.95 5951577.28 556790.01 MWD+IFR-AK-CAZ-SC 9582.35 90.46 358.37 3542.04 3433.04 5994.57 -1869.19 5951670.98 556787.04 MWD+IFR-AK-CAZ-SC 9618.00 90.46 358.37 3541.76 3432.76 6030.21 -1870.21 5951706.61 556785.75 PROJECTED to TD ~ =="°h ~ ~ 1, % ~ ~ I ~ ~ ~ ~ ' ;' FRANK H. MURKOWSKI, GOVERNOR r OI~ ~ u017 333 W. 7T" AVENUE, SUITE 100 CO1~T5EIZQA'1`I011T COMMIS5IOIQ ANCHORAGE, ALASKA 99501-3539 ,~ PHONE (907) 279-1433 Randy Thomas Fax (907) 276-7542 Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: West Sak 1J-166L1 ConocoPhillips Alaska, Inc. Permit No: 205-199 Surface Location: 1880' FSL, 2508' FEL, Sec. 35, T11N, RlOE, UM Bottomhole Location: 675' FSL, 948' FWL, Sec. 23, T11N, RlOE, 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-166 Permit No 205-198, API No.50-029-23291-00. Production should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager). 205-199 ``~'~ Sincerely Chairman DATED this ~~day of December, 2005 Orman cc: Department of Fish 8~ Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~ ff~~ ALASKA OIL AND GAS CONSERVATION COMMIS N W j~,~ PERMIT TO DRILL I 20 AAC 25.005 w q~C 0 5 2005 Aln~~~ ~~A dos Cons. Cot1N'nl55ifl~i 1 a. Type of Work: Drill / Redrill -- 1 b. Current Well Class: Exploratory Development Oil / one ^ Re-entry ^ Stratigraphic Test ^ Service ^ Development Gas ^ Single Zone Q 2. Operator Name: 5. Bond: / Blanket Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 ` 1J-166L1 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 12945' TVD: 3588' ~ Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 1880' FSL, 2508' FEL, Sec. 35, T11 N, R10E, UM ADL 25661 & 25650 • West Sak Oil Pool ' Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1607' FNL, 793' FWL, Sec. 35, T11N, R10E UM ALK 471 & 468 1/1/2006 Total Depth: 9. Acres in Property: 14. Distance to r • ,~,~i/es ~a IEIC ~ 675' FSL, 948' FWL, Sec. 23, T11 N, R10E, UM ~ 2560 Nearest Property: ~Bo~u~ 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest , Surface: x- 558703 ~ y- 5945692 ~ Zone- 4 (Height above GL): 28' RKB feet Well within Pool: 1 D-127 ,sal' @ 12980' 16. Deviated wells: Kickoff depth: 5368 ~ ft. 17. Maximum Anticipated Pressures in psig (see zo aaC z5.o35) Maximum Hole Angle: gg° deg Downhole: 1615 psig ~ Surface: 1220 psig 18. Casing Program Setting Depth Quantity of Cement Specifications Bottom T f k Size op c. . or sac s Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" x 34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCRETE 13.5" 10.75" 45.5# L-80 BTC 2360' 28' 28' 2360' 2183' 460 sx ASLite, 170 sx DeepCRETE 7- 8" L-8 TC 28' TE 6.75" 4.5" 12.6# L-80 IBTM 7577' 5368' 3489' 12945' 3588' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Perforation Depth TVD (ft): Perforation Depth MD (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 Q 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~_~`"~- ~ Phone •Z-6S G~ 3~ Date ~ c (2 3/05' -~ P e r haron Ails D k Commission Use Only Permit to Drill ~^'~/~ ~ 9 API Number: Q~/ //\ 50 0 ~~ '~ ~ 2 / ~( Permit Approval ~® Date: •~ ~ ®~ See cover letter for other requirements Number: J / / - % p~,J , Conditions of approval ^ N Y ^ o es No~ Mud log required a ples required Yes Hy rogen sulfide measures Yes ^ No ~ Directional survey required Yes ~' No ^ Other: 3 -~->;,5 ~~t APPROVED BY - ~~ /'~S / . THE COMMISSION Date: ~~ / (~ Approv s~ a~ /~" 1=nrm 1n-4n1 ised 06/2004 'e.a" E \ ~ °wi 5 ~ ! l ~ ~~ ~ ~P ubmit in Duplicate AK Lion for Permit to Drill, Well 1J-166 L1 ~/ Revision No.O Saved: 28-Nov-05 Permit It -West Sak Well #1J-166 L1 Application for Permit to Drill Document M {t x i rri i x p V1ell Value Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (t7 ....................................................................................................... 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-166L1 PERMIT IT.doc Page 1 of 6 Printed: 28-Nov-05 OR~G~NAL A~ lion for Permit to Drill, Well 1 J-166 L1 Revision No.O Saved: 28-Nov-05 13. Proposed Drilling Program ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments ............................................................................................................. 6 Attachment 1 Directional Plan ................................................................................................................ 6 Attachment 2 Drilling Hazards Summary ............................................................................................... 6 Attachment 3 Well Schematic ................................................................................................................ 6 1. Well Name Requirements of 20 AAC 25.005 (fl Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with mu/tip/e well branches, each branch must similar/y be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as iJ-166 L1. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Dri/l must be accompanied by each of the fol%wing items, except for an item a/ready on file with the commission and identified in the application: (2) a p/at identifying the property and the properly'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 governments/section lines (B) the coordinates of the proposed location of the wel/ at the surface, referenced to the state p/ane coordinate system for this state as maintained by the Nations/ Geodetic Survey in the Nationa/ Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at tots/ depth; Location at Surface 1,880' FSL 2 508' FEL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 109.0' AMSL Norfhings: 5,945,692Eastings; 558,703 Pad Elevation 81.0' AMSL Location at Top of Productive Interval 1,607' FNL, 793' FWL, Section 35, T11N, R10E West Sak "B" Sand ASP Zone 4 NAD 27 Coordinates Measured De th RKB; 5,368 Northings: 5,947,469 Eastings: 556,707 Total l/erticalDe th, RKB: 3 489 Total I/ertica/ De th SS.• 3,380 Location at Total De th 675' FSL, 948' FWL, Section 23, T11N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 12, 945 Northings: 5,955,031 Eastings: 556,796 Total ~erticalDe th, RKB: 3 588 ~ Total I/ertical De th, SS.• 3,479 and (O) other information required by 20 AAC 25.050(b); 7J-166L1 PERMIT IT doc Page 2 of 6 Printed: 28-Nov-05 ORIGINAL 4'6~` AK tion for Permit to Drill, Well 1 J-166 L1 ~% Revision No.O Saved: 28-Nov-05 Requirements of 20 AAC 25.050(b) If a well is to be intentional/y deviated, the application for a Permit to Dri/1(form i0-40i) must (1) include a p/at, drawn to a suitab/e sca/e, showing the path of the proposed wellbore, inc/uding all adjacent we//bores within 200 feet of any portion of the proposed we/% Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed we//bore (A) list the names of the operators of those we/ls, to the extent that those names are known or discoverab/e in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the on/y afi`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 Drill must be accompanied by each of the fo/%wing items, except for an item a/ready on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applccab/e; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-166 L1. 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 app/ication for a Permit to Dril/ must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified /n the application: (4) information on drilling hazards, inc/uding (A) the maximum downhoJe pressure that maybe encountered, criteria used to determine it, and maximum potentia/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 °B" sand formation is 1,220 psi, calculated thusly: MPSP = (3,588 ft TVD)(0.45 - 0.11 psi/ft) = 1,220 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% prob/ems such as abnormal/y geo pressured strata, lost circulation zones, and zones that have a propensity for differentia/sticking; Please see Attachment 2: 1J-166 L1 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the fol%w/ng items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); The parent wellbore, 1J-166, will be completed with 7-5/8" intermediate casing landed in the West Sak A- ~ Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the'~Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 1J-166L1 PERM/T/T.doc Page 3 of 6 Printed: 28-Nov-05 ORIGINAL ,_~ A~ '.ion for Permit to Drill, Well 1J-166 L1 `«...~ Revision No.O Saved: 28-Nov-05 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Ori//must be accompanied by each of the fol%wing items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre- perforated lined or screen to be installed; Casin and Cementin Pro ram Hole Top Btm Csg/Tbg Size Weigh Length MD/TVD MD/TVD OD in in t Ib/ft Grade Connection ft) ft) (ft) Cement Program 4-1/2 6-3/4" A Sand 12.6 L-80 IBTM 7,383 5,458 / 3,501 12,841 / 3,733 Slotted- no cement sl ed Lateral (1J-16 4-1/2 6-3/4" B Sand 12. L-80 IB ,577 5,36 89 12,945 J 3,588 Slotted- no cement slotted Lateral (1J-166 Li) ~'~~5 Et~~ - /2 - /4" D Sa 12.6 L- 0 IBTM 7,947 ,033 / 3, 2 980 / 31 , Slo ed- no cement slotted Lateral (1J-166 L2) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Dri/l must be accompanied by each of the fol%wing items, except for an item a/ready on file with the commission and identified in the application: (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 1J-166 Li. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application 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 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 Ib/900 std 15 - 25 Yield Point cP) 18.28 HTHP Fluid loss (ml/30 min @ 200psi & 150° <4.0 Oil /Water Ratio 70 / 30 Electrical Stabilit 650-900 i Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 1J-166L1 PERMITIT.doc Page 4 of 6 Printed: 28-Nov-05 ORIGINAI AF `ion for Permit to Drill, Well 1 J-166 L1 `~' Revision No.O Saved:28-Nov-05 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application For a Permit to Drill must be accompanied by each of the fol%wing items, except for an item a/ready on file with the commission and identified in the application: (9) for an exp/oratory or stratigraphic test wel% a tabu/ation setting out the depths ofpredicted abnormally geo pressured strata as required by 20 AAC 25.0330; Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(90) An application for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item a/ready on file with the commission and identified in the application: (10) for an exp/oratory or stratigraphic test wel% 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)(77) An application for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item a/ready on fi/e with the commission and identified in the application: (i1) for a well dri/led from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vess% an analysis ofseabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item a/ready on fl/e with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the 1J-166 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of +/- 5,368' MD / 3,489' TVD, the top of the B 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 B sand lateral at +/- 12,945' MD / 3,588' TVD, as per directional plan. 5. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4-1/2" slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POOH. 1J-166L1 PERMIT IT.doc Page 5 of 6 Printed: 28-Nov-05 nRiriniAi A~ `.ion for Permit to Drill, Well 1 J-166 L1 Revision No.O Saved: 28-Nov-05 10. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. 11. POOH and prepare to drill the ~~D" sand lateral 1J-166 L2. 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/l mustc be accompanied by each of the fol%wing items, except for an item a/ready on file with the comm/ssion and identified in the application: (14) a general description of how the operator p/ans to dispose of drilling mud and cuKrngs and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the wel%; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on iJ Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on iJ Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 1J-166L1 PERM/T/T.doc Page 6 of 6 Printed: 28-Nov-05 ORIGINAL 1J-166 Drilling Hazardsummary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud weight. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out, backreaming 1J-166L1 Drilling Hazards Summary.doc /~ ~ ~ prepared by Shane Cloninger ~~°i 11/16/2005 11:24 AM ~~ ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-166 1J-166 L1 Plan: 1J-166 L1 (wp07) Proposal Report 04 November, 2005 HA~...L1B~R'"~"~C~N gperry Qrillin~ Services ORIGINAL pUm ~ ~ ~voOQ f~iuSf~ 0 F y a ggyg W 1LCfM-YF~»>Y~~S D $ ~~~p~~~~lppRC~Og tbp~~tp~pp O ~~~N N~~'~YfNN g8888888888Cy5pp "'mow ONO ^a^~M~NN n~M'~Ii! LL M!! 11''11 2~Nn arl lon row~~ v OD N N O G1~~ V1N~ra m e: - J N" MIA ~ 2N~nv p ponon ~O~oOw O OI OD 2 aOM~~ Q N N ~ U QOOOO~oo ~ ~ ~ W N N M M 0 Z ~ N M V >p C ~ p d J C rm~ 3 Y Y ~ ~- r 7~'~J ~ r ~ ~ 7 ~ ` t0 Y Ya$~ V ,+~+ N d C o`~33a a` F cyi O J ~, p m c O J n O 3 >_ N n J OU. ~ 3 N J p ~o co to O w ~ ~ ~ d W O O J ~ ~ J o c c ~O !0 l0 a a N N M p t °m ID Y O! d d N a~i C7 U J W Z M N U (n v rn aS J m p M rn m J N 3 = ¢ °' _ oG8 n a F _ _ O o ~ ° V O ° m ~ ~ oL8! ~ ~ O o V o n 3 1D °° 0881 ~ J O m o 008 i O O °° . , ~ o ~ n ~ O ~ ' ' ~ O n In oL8 J ~ M O p `~ ~ ~ n O O O 3 p O n r ~ __ _ - _ _ ~, I~ J O ta_ On Ip N eLB ~ s v ~- ~ ~ p J 0 O O a ~ ( 0 m Iwn ~ a68: a `a n M o 2 O ~ O 3 ~ ~ ~ ~ n J rn !:: n ~ 0 e69 3 ~ o lLL ~ ~ ~ J Q ~ a88 ~ °o ° v p N O a •~ H 3 O m O d M H O ° v d L J O ~ J (Op ~ e06: N r ? ° O o ~ /` ') O J M 9 W J O ~ O M ~O _ _ uj _ - - „ ` t0 ~ C_ O O O O C O U a~ ~_ _ O ~j - _ _ ', N 0 m ~ - ~__ '006'. °o 008! 0 N _ _ _ _ _ _ _ _ _ _ _ _ _ _ _;_ _ _ _ _ _ _ '~ p 1 - - - - - a 1l ' O 0 ~~~ o ~ ' m a ~ ~ ! ~ ~ ~ ', 1 C y, i c N O O - O ~ M o~ 9 ~~ N M n°y O ; ~ O ~ O M C ', ', '. ~ O O O O O O O f O O O O ~ O O O O O O O O O O O O O 1 O ~ O 4'1 O O O ~ O O O ~ O ~ I l /wn N O N i nnni 1 uuian in~nia 4 N M M V n ani i ~ N ~ (1I-~I(;iI\II~I ~,. Project: Kuparuk River Unit ~OtlOCO~ll~~1 5 P Site: Kuparuk 1J Pad 1os2s Ai l Well: Plan 1J-166 as u~ Wellbore: 1J-166 L1 Plan: 1J-166 L1 (wp07) loooo a vz" L1: BHL @ 12945ft MD, 3588ft TVD : 675ft FSL & 948ft FWL --Sec 23 - T11N - R10E x375 1J-166 L1 T11 Tce (wp07) - - - o° 8750 1J-166 L1 T10 (Wp07) CASING DETAILS 0° No ND MD Name Size _ _ _ _ 1J-166 Li T9 (wp07) - - _ °° 1 80.00 80.00 20" 20 40 ~ 5384^ 7 8~a s s48s 44 ssse 8125 . . 4 3588.00 12944.97 4 1/2" 4-112 1J-166 L1 T8 (wp07) °° 7500 1J-166 L1 T7 (wp07) o° Li :Possible Upthrown Fault, 10180ft MD, 3571ft TVD 6875 1J-166 L1 T6 (wp07) s25o o° L1 : Possible Downthrown Fault, 9560ft MD, 3543ft TVD. 1J-166 L1 T5 (wp07)i 5625 o° 1J-166 L1 T4 (wp07) - - - - c 5000 0 p^ N 1J-166 L1 T3 (wp07) °° a37s L1 : Continue GeoSteering in WSAK B, 6053ft MD, 3505ft TVD 0 Z 1J-166 L1 T2 (wp07) 3750 L o L1: Sail @ 90.3° Inc : 5688ft MD, 3507ft TVD to o° 3125 1J-166 L1 T1 (wp07) zsoo Li :End 30' Rathole -Begin 5°/100ft Build, 5410ft MD, 3496ft TVD~ s° . 1875 __ ----"- L1:BOW @5380ftMD,3491ftTVD lT 3° 1250 360° L1 : TOW @ 5368ft MD, 3489ft TVD - 1607ft FNL & 793ft FWL -Sec 35 - T11 N - R10E ,~.~o 625 T //~ 20" o° ~ 0 M ~ ~ Azimuths to True North ~ ~ Magnetic North: 24.22° o -625 Magnetic Field Strength: 57563.OnT Dip Angle: 80.77° Date: 12!31 /2005 10 3/4" Model: BGGM2005 -1250 -4375 -3750 -3125 -2500 -1875 -1250 -625 0 625 1250 1875 2500 3125 3750 4375 West - /East + 1250 ft/in UKl~IIVHL / ~' Halliburton Company ` HALL1tgUl~t't~N ConOCt7Phllllps Planning Report -Geographic -- -- Alaska Sperry Drilling Servlce~s Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1 J-166 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Slte: Kuparuk 1J Pad North Reference: True Well: Plan 1J-166 Survey Calculation Method: Minimum Curvature Wellbore: 1J-166 L1 Design: 1J-166 L1 (wp07) Protect Kuparuk River Unit, North Slope Alaska, United States ~ I Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor -.__. Well Plan 1J-166 Well Position +N/-S 0.00 ft Northing: 5,945,691.74 ft Latitude: 70° 15' 44.023" N +E/-W 0.00 ft Easting: 558,702.73 ft Longitude: 149° 31' 31.597" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft W le I ob re _ 1J-166 L1 T Magnetlas Model Name Sample Date Declination Dip Angle Field Strength BGGM2004 11/28/2004 24.53 80.72 57,579 Design Audit Notes: Version: Vertical Section: 1J-166 L1 (wp07) Phase: PLAN Depth From (TVD) +N/-S (ft) (ft) 28.00 0.00 Tie On Depth: +E/-W Direction (ft) (°) 0.00 0.00 5,368.39 11/4/2005 5:17:22PM ORIGINAL COMPASS 2003.118uild 48 ~/ ~`~' Halliburton Company ~' HALLiBURTi~N ~011000 PFlI~~lpS Planning Report -Geographic ~~ ---~--- ~ -~-° __.n .._ Alaska Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-166 Company: ConocoPhillips Alaska{Kuparuk). TVD Reference: Planning RKB @ 109.o0ft (Doyon 141 (28+81p Project: Kuparuk River UniT MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-166 Survey Calculation Method: Minimum Curvature Welibore: 1J-166 L1 Design: 1J-166 L1 (wp07) Plan Summary .Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W .Rate Rate Rate ° TFO (ft) (,) (°) (ft) (ft) (ft) (°/100ft) (°l100ft) /100ft) ( ~°) 5,368.39 80.00 2.51 3,489.44 1,792.51 -1,981.24 0.00 0.00 0.00 0.00 5,380.39 81.91 2.51 3,491.32 1,804.35 -1,980.72 15.90 15.90 0.00 0.00 5,410.39 81.91 2.51 3,495.55 1,834.02 -1,979.42 0.00 0.00 0.00 0.00 5,566.83 89.73 2.51 3,506.94 1,989.77 -1,972.59 5.00 5.00 0.00 360.00 5,687.59 90.30 8.52 3,506.91 2,109.92 -1,960.99 5.00 0.47 4.98 84.59 6,053.52 90.30 8.52 3,505.00 2,471.81 -1,906.77 0.00 0.00 0.00 0.00 6,323.23 89.73 0.45 3,504.93 2,740.47 -1,885.69 3.00 -0.21 -2.99 -94.03 7,823.23 89.73 0.45 3,512.00 4,240.40 -1,873.91 0.00 0.00 0.00 0.00 7,883.02 87.94 0.45 3,513.22 4,300.17 -1,873.44 3.00 -3.00 -0.01 -179.89 8,293.56 87.94 0.45 3,528.00 4,710.43 -1,870.25 0.00 0.00 0.00 0.00 8,341.75 89.38 0.45 3,529.13 4,758.61 -1,869.87 3.00 3.00 0.00 0.01 8,793.65 89.38 0.45 3,534.00 5,210.47 -1,866.35 0.00 0.00 0.00 0.00 8,851.15 91.11 0.45 3,533.75 5,267.96 -1,865.90 3.00 3.00 0.00 0.00 8,993.70 91.11 0.45 3,531.00 5,410.48 -1,864.79 0.00 0.00 0.00 0.00 9,077.25 88.60 0.45 3,531.21 5,494.02 -1,864.14 3.00 -3.00 0.00 180.00 9,559.90 88.60 0.45 3,543.00 5,976.52 -1,860.38 0.00 0.00 0.00 0.00 9,608.70 87.14 0.45 3,544.81 6,025.27 -1,860.00 3.00 -3.00 0.00 -179.99 10,085.19 87.14 0.45 3,568.62 6,501.16 -1,856.29 0.00 0.00 0.00 0.00 10,180.63 90.00 0.45 3,571.00 6,596.56 -1,855.54 3.00 3.00 0.00 0.07 10,386.87 99.28 0.44 3,554.33 6,801.89 -1,853.94 4.50 4.50 0.00 -0.04 10,572.01 99.28 0.44 3,524.48 6,984.60 -1,852.53 0.00 0.00 0.00 0.00 10,838.24 87.30 0.45 3,509.22 7,249.90 -1,850.46 4.50 -4.50 0.00 179.97 11,088.24 87.30 0.45 3,521.00 7,499.62 -1,848.50 0.00 0.00 0.00 0.00 11,209.49 89.72 0.45 3,524.15 7,620.81 -1,847.55 2.00 2.00 0.00 -0.09 11,595.35 89.72 0.45 3,526.00 8,006.65 -1,844.55 0.00 0.00 0.00 0.00 11,678.26 88.07 0.45 3,527.60 8,089.55 -1,843.90 2.00 -2.00 0.00 179.98 11,986.58 88.07 0.45 3,538.00 8,397.68 -1,841.50 0.00 0.00 0.00 0.00 12,042.11 86.96 0.45 3,540.41 8,453.15 -1,841.07 2.00 -2.00 0.00 -180.00 12,486.31 86.96 0.45 3,564.00 8,896.71 -1,837.61 0.00 0.00 0.00 0.00 12,488.55 87.00 0.45 3,564.12 8,898.95 -1,837.59 2.00 2.00 0.00 0.00 12,944.98 87.00 0.45 3,588.00 9,354.74 -1,834.04 0.00 0.00 0.00 0.00 11/42005 5.~17:22PM Page 3 of 8 COMPASS 2003.118uiid 48 ORIGINAL ~~ ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company:. ConocoPhiilips Alaska (Kuparuk) .Project: Kuparuk River Unit: Site: Kuparuk 1J Pad Well: PIan1J-166 Wellbore; 1J-166 L1 Design:. 1J-16Ei L1 (wp07) Planned Survey 1J-166 L1 (wp07) Halliburton Company °~°-' HALI.1BUi~TC3N Planning Report -Geographic ...--, _,. ~_.__ _._.__._ _......__, Sperry Drilling Services Local Co-ordinate Reference: Well Plan 1J-166 TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) North R®ference: True ' Survey Calculation Method: Minimum Curvature ~ Map Map MD inclination Azimuth TVD SSTVD +N!-S +ELW Northing Fasting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 5,368.39 80.00 2.51 3,489.44 3,380.44 1,792.51 -1,981.24 5,947,468.58 556,707.77 0.00 1,792.51 i L1 : TOW C~3 5388ft MD, 3489ft TVD -1ti07ft FNL & 793ft FWL -Sec 35 - T11N - R10E -West Sak B - 7 5/8" 5,380.39 81.91 2.51 3,491.32 3,382.32 1,804.35 -1,980.72 5,947,480.42 556,708.19 15.90 1,804.35 L1 : BOW ~ 5380 ft MD, 3491ft TVD 5,400.00 81.91 2.51 3,494.08 3,385.08 1,823.74 -1,979.87 5,947,499.82 556,708.89 0.00 1,823.74 5,410.39 81.91 2.51 3,495.55 3,386.55 1,834.02 -1,979.42 5,947,510.10 556,709.26 0.00 1,834.02 L1 : End 30' Rathole -Begin 5°/100ft Build, 5410ft MD, 3495ft TVD 5,500.00 86.39 2.51 3,504.68 3,395.68 1,923.05 -1,975.52 5,947,599.15 556,712.47 5.00 1,923.05 5,566.83 89.73 2.51 3,506.94 3,397.94 1,989.77 -1,972.59 5,947,665.89 556,714.88 5.00 1,989.77 5,600.00 89.89 4.16 3,507.06 3,398.06 2,022.88 -1,970.66 5,947,699.01 556,716.55 5.00 2,022.88 5,687.59 90.30 8.52 3,506.91 3,397.91 2,109.92 -1,960.99 5,947,786.11 556,725.54 5.00 2,109.92 5,688.00 90.30 8.52 3,506.91 3,397.91 2,110.32 -1,960.93 5,947,786.51 556,725.60 0.00 2,110.32 L1: Sail (8J 90.3° Inc : 5688ft MD, 3507ft TVD 5,700.00 90.30 8.52 3,506.85 3,397.85 2,122.19 -1,959.15 5,947,798.39 556,727.28 0.00 2,122.19 5,800.00 90.30 8.52 3,506.33 3,397.33 2,221.08 -1,944.33 5,947,897.39 556,741.33 0.00 2,221.08 5,900.00 90.30 8.52 3,505.80 3,396.80 2,319.98 -1,929.52 5,947,996.38 556,755.37 0.00 2,319.98 6,000.00 90.30 8.52 3,505.28 3,396.28 2,418.87 -1,914.70 5,948,095.38 556,769.42 0.00 2,418.87 6,053.24 90.30 8.52 3,505.00 3,396.00 2,471.53 -1,906.81 5,948,148.09 556,776.89 0.00 2,471.53 L7 : Continue GeoSteering In WSAK B, 8053ft MD, 3505ft TVD 6,053.52 90.30 8.52 3,505.00 3,396.00 2,471.81 -1,906.77 5,948,148.37 556,776.93 0.00 2,471.81 6,100.00 90.20 7.13 3,504.80 3,395.80 2,517.85 -1,900.44 5,948,194.46 556,782.90 3.00 2,517.85 6,200.00 89.99 4.14 3,504.63 3,395.63 2,617.35 -1,890.62 5,948,294.02 556,791.94 3.00 2,617.35 6,300.00 89.78 1.15 3,504.83 3,395.83 2,717.24 -1,886.02 5,948,393.93 556,795.77 3.00 2,717.24 6,323.23 89.73 0.45 3,504.93 3,395.93 2,740.47 -1,885.69 5,948,417.16 556,795.91 3.00 2,740.47 6,400.00 89.73 0.45 3,505.29 3,396.29 2,817.23 -1,885.09 5,948,493.92 556,795.92 0.00 2,817.23 6,500.00 89.73 0.45 3,505.76 3,396.76 2,917.23 -1,884.30 5,948,593.91 556,795.92 0.00 2,917.23 6,600.00 89.73 0.45 3,506.24 3,397.24 3,017.22 -1,883.52 5,948,693.90 556,795.93 0.00 3,017.22 6,700.00 89.73 0.45 3,506.71 3,397.71 3,117.22 -1,882.73 5,948,793.89 556,795.94 0.00 3,117.22 6,800.00 89.73 0.45 3,507.18 3,398.18 3,217.21 -1,881.95 5,948,893.88 556,795.94 0.00 3,217.21 6,900.00 89.73 0.45 3,507.65 3,398.65 3,317.21 -1,881.16 5,948,993.87 556,795.95 0.00 3,317.21 7,000.00 89.73 0.45 3,508.12 3,399.12 3,417.20 -1,880.38 5,949,093.85 556,795.95 0.00 3,417.20 7,100.00 89.73 0.45 3,508.59 3,399.59 3,517.20 -1,879.59 5,949,193.84 556,795.96 0.00 3,517.20 7,200.00 89.73 0.45 3,509.06 3,400.06 3,617.20 -1,878.81 5,949,293.83 556,795.96 0.00 3,617.20 7,300.00 89.73 0.45 3,509.53 3,400.53 3,717.19 -1,878.02 5,949,393.82 556,795.97 0.00 3,717.19 7,400.00 89.73 0.45 3,510.01 3,401.01 3,817.19 -1,877.24 5,949,493.81 556,795.98 0.00 3,817.19 7,500.00 89.73 0.45 3,510.48 3,401.48 3,917.18 -1,876.45 5,949,593.80 556,795.98 0.00 3,917.18 7,600.00 89.73 0.45 3,510.95 3,401.95 4,017.18 -1,875.67 5,949,693.79 556,795.99 0.00 4,017.18 7,700.00 89.73 0.45 3,511.42 3,402.42 4,117.18 -1,874.88 5,949,793.78 556,795.99 0.00 4,117.18 7,800.00 89.73 0.45 3,511.89 3,402.89 4,217.17 -1,874.09 5,949,893.77 556,796.00 0.00 4,217.17 7,823.23 89.73 0.45 3,512.00 3,403.00 4,240.40 -1,873.91 5,949,917.00 556,796.00 0.00 4,240.40 1J-186 L1 T1 (wp07j 7,883.02 87.94 0.45 3,513.22 3,404.22 4,300.17 -1,873.44 5,949,976.76 556,796.00 3.00 4,300.17 7,900.00 87.94 0.45 3,513.83 3,404.83 4,317.14 -1,873.31 5,949,993.73 556,796.00 0.00 4,317.14 8,000.00 87.94 0.45 3,517.43 3,408.43 4,417.07 -1,872.53 5,950,093.66 556,796.00 0.00 4,417.07 8,100.00 87.94 0.45 3,521.03 3,412.03 4,517.01 -1,871.75 5,950,193.58 556,796.00 0.00 4,517.01 8,200.00 87.94 0.45 3,524.63 3,415.63 4,616.94_ -1,870.98 5,950,293.51 556,796.00 0.00 4,616.94 11/4/2005 5:17.~22PM Page 4 of 8 COMPASS 2003.11 Build 48 ORIGINAL ~/ '~--' Halliburton Company ConocoPhilllps Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit.. Slte: Kuparuk 1J Pad Well: Plan 1J-166 Wel Ibore: 1 J-166 L1 Design: 1J-166 L1 (wp07) ~~ 1-iALL1BUi~TCiN Sperry Drilling Sorvices Local Co-ordinate Reference: Well Plan 1J-166 TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference:. Planning RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey 1J-166 L1 (wp07) MD Inclination Azimuth TVD SSTVD +N/-S +E/-W (ft) (°) (°) (ft) (ft) (ft) (ft) 8,293.56 87.94 0.45 3,528.00 3,419.00 4,710.43 -1,870.25 1J-166 L1 T2 (wp07) 8,300.00 88.13 0.45 3,528.22 3,419.22 4,716.87 -1,870.20 8,341.75 89.38 0.45 3,529.13 3,420.13 4,758.61 -1,869.87 8,400.00 89.38 0.45 3,529.76 3,420.76 4,816.85 -1,869.42 8,500.00 89.38 0.45 3,530.83 3,421.83 4,916.84 -1,868.64 8,600.00 89.38 0.45 3,531.91 3,422.91 5,016.84 -1,867.86 8,700.00 89.38 0.45 3,532.99 3,423.99 5,116.83 -1,867.08 8,793.65 89.38 0.45 3,534.00 3,425.00 5,210.47 -1,866.35 1J-166 L1 T3 (wp07) 8,800.00 89.57 0.45 3,534.06 3,425.06 5,216.82 -1,866.30 8,851.15 91.11 0.45 3,533.75 3,424.75 5,267.96 -1,865.90 8,900.00 91.11 0.45 3,532.81 3,423.81 5,316.80 -1,865.52 8,993.70 91.11 0.45 3,531.00 3,422.00 5,410.48 -1,864.79 1J-166 L1 T4 (wp07) 9,000.00 90.92 0.45 3,530.89 3,421.89 5,416.78 -1,864.74 9,077.25 88.60 0.45 3,531.21 3,422.21 5,494.02 -1,864.14 9,100.00 88.60 0.45 3,531.77 3,422.77 5,516.77 -1,863.96 9,200.00 88.60 0.45 3,534.21 3,425.21 5,616.73 -1,863.18 9,300.00 88.60 0.45 3,536.65 3,427.65 5,716.70 -1,862.40 9,400.00 88.60 0.45 3,539.09 3,430.09 5,816.67 -1,861.62 9,500.00 88.60 0.45 3,541.54 3,432.54 5,916.64 -1,860.84 9,559.90 88.60 0.45 3,543.00 3,434.00 5,976.52 -1,860.38 L1 : Posslble Downthrown Fault, 9560ft MD, 3543ft TVD -1 J-166 L1 T5 (wp07) 9,600.00 87.40 0.45 3,544.40 3,435.40 6,016.59 -1,860.06 9,608.70 87.14 0.45 3,544.81 3,435.81 6,025.27 -1,860.00 9,700.00 87.14 0.45 3,549.38 3,440.38 6,116.46 -1,859.29 9,800.00 87.14 0.45 3,554.37 3,445.37 6,216.33 -1,858.51 9,900.00 87.14 0.45 3,559.37 3,450.37 6,316.21 -1,857.73 10,000.00 87.14 0.45 3,564.36 3,455.36 6,416.08 -1,856.95 10,085.19 87.14 0.45 3,568.62 3,459.62 6,501.16 -1,856.29 10,100.00 87.58 0.45 3,569.30 3,460.30 6,515.95 -1,856.17 10,180.00 89.98 0.45 3,571.00 3,462.00 6,595.93 -1,855.55 L1 : Posslble Upthrown Fault, 10180ft MD, 3571ft TVD Map Map Northing Easting DLSEV Vert Section (ft) (ft) (°/1OOft) (ft) 5,950,387.00 556,796.00 0.00 4,710.43 5,950,393.44 556,796.00 2.98 4,716.87 5,950,435.17 556,796.00 3.00 4,758.61 5,950,493.41 556,796.00 0.00 4,816.85 5,950,593.40 556,796.00 0.00 4,916.84 5,950,693.38 556,796.00 0.00 5,016.84 5,950,793.37 556,796.00 0.00 5,116.83 5,950,887.00 556,796.00 0.00 5,210.47 5,950,893.35 556,796.00 2.98 5,216.82 5,950,944.49 556,796.00 3.00 5,267.96 5,950,993.33 556,796.00 0.00 5,316.80 5,951,087.00 556,796.00 0.00 5,410.48 5,951,093.30 556,796.00 2.98 5,416.78 5,951,170.54 556,796.00 3.00 5,494.02 5,951,193.28 556,796.00 0.00 5,516.77 5,951,293.24 556,796.00 0.00 5,616.73 5,951,393.20 556,796.00 0.00 5,716.70 5,951,493.16 556,796.00 0.00 5,816.67 5,951,593.12 556,796.00 0.00 5,916.64 5,951,653.00 556,796.00 0.00 5,976.52 5,951,693.07 556,796.00 3.00 6,016.59 5,951,701.75 556,796.00 3.00 6,025.27 5,951,792.93 556,796.00 0.00 6,116.46 5,951,892.80 556,796.00 0.00 6,216.33 5,951,992.67 556,796.00 0.00 6,316.21 5,952,092.53 556,796.00 0.00 6,416.08 5,952,177.61 556,796.00 0.00 6,501.16 5,952,192.40 556,796.00 2.99 6,515.95 5,952,272.37 556,796.00 3.00 6,595.93 10,180.63 90.00 0.45 3,571.00 3,462.00 6,596.56 -1,855.54 5,952,273.00 556,796.00 3.00 6,596.56 1J-166 L1 T6 (wp07) 10,200.00 90.87 0.45 3,570.85 3,461.85 6,615.93 -1,855.39 5,952,292.37 556,796.00 4.49 6,615.93 10,300.00 95.37 0.45 3,565.41 3,456.41 6,715.75 -1,854.61 5,952,392.18 556,796.00 4.50 6,715.75 10,386.87 99.28 0.44 3,554.33 3,445.33 6,801.89 -1,853.94 5,952,478.32 556,796.00 4.50 6,801.89 10,400.00 99.28 0.44 3,552.22 3,443.22 6,814.85 -1,853.84 5,952,491.27 556,796.00 0.00 6,814.85 10,500.00 99.28 0.44 3,536.09 3,427.09 6,913.54 -1,853.08 5,952,589.96 556,795.99 0.00 6,913.54 10,572.01 99.28 0.44 3,524.48 3,415.48 6,984.60 -1,852.53 5,952,661.01 556,795.99 0.00 6,984.60 10,600.00 98.02 0.44 3,520.27 3,411.27 7,012.27 -1,852.32 5,952,688.68 556,795.99 4.49 7,012.27 10,700.00 93.52 0.45 3,51021 3,401.21 7,111.74 -1,851.54 5,952,788.14 556,795.98 4.50 7,111.74 10,800.00 89.02 0.45 3,508.00 3,399.00 7,211.68 -1,850.76 5,952,888.08 556,795.98 4.50 7,211.68 10,838.24 87.30 0.45 3,50922 3,400.22 7,249.90 -1,850.46 5,952,926.30 556,795.99 4.51 7,249.90 10,900.00 87.30 0.45 3,512.13 3,403.13 7,311.59 -1,849.98 5,952,987.98 556,795.99 0.00 7,311.59 11/42005 5:17:22PM Page 5 of 8 COMPASS 2003.11 Build 48 ORIGINP.I_ `~ Halliburton Company Conocc~Phlllips Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Slte: Kuparuk 1J Pad Well: Plan 1J-166 Wellbore: 1J-166 L1 Design: 1J-166 L1 (wp07) HALLiBURTC'~N Sperry polling Sanrltes Local Co-ordinate Reference: Well Plan 1J-166 TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey 1J-166 L1 (wp07) Map. Map MD Inclination Azimuth TVD SSTVD +N/-S +E/.W Northing Easting DLSEV Vort Section (ft) (°) (°) (n) (ft) lft) (ft) (ft) (~) (°I100ft) (ft) 11,000.00 87.30 0.45 3,516.84 3,407.84 7,411.48 -1,849.19 5,953,087.86 556,795.99 0.00 7,411.48 11,088.24 87.30 0.45 3,521.00 3,412.00 7,499.62 -1,848.50 5,953,176.00 556,796.00 0.00 7,499.62 1J-188 L1 T7 (wp07) 11,100.00 87.53 0.45 3,521.53 3,412.53 7,511.36 -1,848.41 5,953,187.74 556,796.00 1.99 7,511.36 11,200.00 89.54 0.45 3,524.09 3,415.09 7,611.32 -1,847.63 5,953,287.70 556,796.00 2.00 7,611.32 11,209.49 89.72 0.45 3,524.15 3,415.15 7,620.81 -1,847.55 5,953,297.18 556,796.00 2.00 7,620.81 11,300.00 89.72 0.45 3,524.58 3,415.58 7,711.32 -1,846.85 5,953,387.69 556,796.00 0.00 7,711.32 11,400.00 89.72 0.45 3,525.06 3,416.06 7,811.31 -1,846.07 5,953,487.67 556,796.00 0.00 7,811.31 11,500.00 89.72 0.45 3,525.54 3,416.54 7,911.31 -1,845.29 5,953,587.66 556,796.00 0.00 7,911.31 11,595.35 89.72 0.45 3,526.00 3,417.00 8,006.65 -1,844.55 5,953,683.00 556,796.00 0.00 8,006.65 1J-166 L1 T8 (wp07) 11,600.00 89.63 0.45 3,526.03 3,417.03 8,011.30 -1,844.51 5,953,687.65 556,796.00 1.98 8,011.30 11,678.26 88.07 0.45 3,527.60 3,418.60 8,089.55 -1,843.90 5,953,765.89 556,796.00 2.00 8,089.55 11,700.00 88.07 0.45 3,528.33 3,419.33 8,111.27 -1,843.73 5,953,787.61 556,796.00 0.00 8,111.27 11,800.00 88.07 0.45 3,531.71 3,422.71 8,211.21 -1,842.95 5,953,887.55 556,796.00 0.00 8,211.21 11,900.00 88.07 0.45 3,535.08 3,426.08 8,311.15 -1,842.18 5,953,987.48 556,796.00 0.00 8,311.15 11,986.58 $8.07 0.45 3,538.00 3,429.00 8,397.68 -1,841.50 5,954,074.00 556,796.00 0.00 8,397.68 1J-188 L1 T9 (wp07) 12,000.00 87.80 0.45 3,538.48 3,429.48 8,411.09 -1,841.40 5,954,087.41 556,796.00 1.99 8,411.09 12,042.11 86.96 0.45 3,540.41 3,431.41 8,453.15 -1,841.07 5,954,129.47 556,796.00 2.00 8,453.15 12,100.00 86.96 0.45 3,543.49 3,434.49 8,510.96 -1,840.62 5,954,187.28 556,796.00 0.00 8,510.96 12,200.00 86.96 0.45 3,548.80 3,439.80 8,610.82 -1,839.84 5,954,287.13 556,796.00 0.00 8,610.82 12,300.00 86.96 0.45 3,554.11 3,445.11 8,710.67 -1,839.06 5,954,386.98 556,796.00 0.00 8,710.67 12,400.00 86.96 0.45 3,559.42 3,450.42 8,810.53 -1,838.28 5,954,486.82 556,796.00 0.00 8,810.53 12,486.31 86.96 0.45 3,564.00 3,455.00 8,896.71 -1,837.61 5,954,573.00 556,796.00 0.00 8,896.71 1J-186 L1 T10 (wp07) 12,488.55 87.00 0.45 3,564.12 3,455.12 8,898.95 -1,837.59 5,954,575.24 556,796.00 2.00 8,898.95 12,500.00 87.00 0.45 3,564.72 3,455.72 8,910.39 -1,837.50 5,954,586.67 556,796.00 0.00 8,910.39 12,600.00 87.00 0.45 3,569.95 3,460.95 9,010.25 -1,836.72 5,954,686.53 556,796.00 0.00 9,010.25 12,700.00 87.00 0.45 3,575.18 3,466.18 9,110.11 -1,835.95 5,954,786.38 556,796.00 0.00 9,110.11 12,800.00 87.00 0.45 3,580.41 3,471.41 9,209.97 -1,835.17 5,954,886.23 556,796.00 0.00 9,209.97 12,900.00 87.00 0.45 3,585.65 3,476.65 9,309.82 -1,834.39 5,954,986.09 556,796.00 0.00 9,309.82 12,944.98 87.00 0.45 3,588.00 3,479.00 9,354.74 -1,834.04 5,955,031.00 556,796.00 0.00 9,354.74 L1: BHL ~ 72945ft MD, 3588ft TVD : 875ft FSL & 948ft FWL --Sec 23 - T11 N - R10E - 41/2" -1J-188 L1 T11 Toe (wp07) 11/4/2005 5:17:22PM Page 6 of 8 COMPASS 2003.11 Build 48 ORIGINAL `°-% Halliburton Company `~.-~' wA~Lr~tuQTOicu Colnoc+~Ph~llips Planning Report -Geographic - Alaska Sporty DrilUng Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Weli Plan 1J-166 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+g1)) Project: Kuparuk River Unif MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+g1)) Site: Kuparuk 1J Pad North Reference: True WeIL• Pian 1J-166. Survey Calculation Method: Minimum Curvature Wellbore: 1J-166 L1 Design: 1J-166 L1 (wp07) Geologic Targets 1J-166 L1 TVD Target Name +N/-S +El-W Northing Fasting Ift) -Shape ft ft (ft) (ft) 3,564.00 1J-166 L1 T10 (wp07) 8,896.71 -1,837.61 5,954,573.00 556,796.00 - Point 3,512.00 1J-166 L1 T1 (wp07) 4,240.40 -1,873.91 5,949,917.00 556,796.00 - Point 3,531.00 1J-166 L1 T4 (wp07) 5,410.48 -1,864.79 5,951,087.00 556,796.00 - Point 3,526.00 1J-166 L1 T8 fwp07) 8,006.65 -1,844.55 5,953,683.00 556,796.00 - Point 3,588.00 1J-166 L7 T11 Toe (wp07) 9,354.74 -1,834.04 5,955,031.00 556,796.00 - Point 3,534.00 1J-166 L1 T3 (wp07) 5,210.47 -1,866.35 5,950,887.00 556,796.00 - Point 3,538.00 1J-166 L1 T9 (wp07) 8,397.68 -1,841.50 5,954,074.00 556,796.00 - Point 3,528.00 1J-166 L1 T2 (wp07) 4,710.43 -1,870.25 5,950,387.00 556,796.00 - Point 3,521.00 1J-166 L1 T7 (wp07) 7,499.62 -1,848.50 5,953,176.00 556,796.00 - Point 3,543.00 1J-166 L1 T5(wp07) 5,976.52 -1,860.38 5,951,653.00 556,796.00 - Point 3,571.00 1J-166 L1 T6 (wp07) 6,596.56 -1,855.54 5,952,273.00 556,796.00 - Point Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) (") (") 80.00 80.00 20 26 2,359.67 2,183.00 10-314 13-1l2 5,368.40 3,489.44 7-518 9-7/8 12,944.97 3,588.00 4-112 6-314 11/4/2005 5:17:22PM Page 7 of 8 COMPASS 2003.118ui1d 48 ~ ""~ Halliburton Company ConocOPh111~ps Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Company: ConocoPhillipsAlaska.(Kuparuk) TVDReference: P~oJect: Kuparuk River Unit. MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plarr 1J-166. Survey Calculation Method: Wellbore: 1J-166 L1 Design: 1J-166 L1 (wp07) Prognosed Formation Intersection Points ~ Measured Depth Inclination Azimuth 1,564.10 32.54 250.00 1,712.37 32.54 250.00 2,057.54 32.54 250.00 2,359.67 34.74 267.80 3,455.75 66.68 318.11 4,001.42 66.68 318.11 4,207.29 67.30 323.72 4,500.12 70.06 339.15 5,020.06 77.00 2.51 5,206.76 77.00 2.51 5,368.39 80.00 2.51 Sperry Drilling Senrlaes Well Plan 1J-166 Planning RKB @ 109:OOft (Doyon 141 (28+81)) Planning RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature Vertical Depth +N/-E +E/-W (ft) (ft) (ft) Name 1,514.00 -89.18 -245.01 Permafrost 1,639.00 -116.45 -319.94 T3 1,930.00 -179.94 -494.39 K15 2,183.00 -219.24 -653.82 T3+550 2,863.00 207.21 -1,342.07 Ugnu C 3,079.00 580.24 -1,676.66 Ugnu B 3,160.00 724.15 -1,799.44 Ugnu A 3,267.00 962.97 -1,929.05 K13 3,413.00 1,453.02 -1,996.12 West Sak D 3,455.00 1,634.76 -1,988.16 West Sak C 3,489.44 1,792.51 -1,981.24 West Sak B 11/4/2005 5:17:22PM Page 8 of 8 COMPASS 2003.11 Build 48 ORIGINAL ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-166 1 J-166 L1 Anticollision Summary 04 November, 2005 Sperry Drilling Servl~es OR161NAL ~ ``~--' Halliburton Company ~~ HA1.L~gtJ~11Tt~IV ConocoPhllhps Anticollision Report ~•°~- ~-~~ °W Alaska Sperry Drilling Sewices Company: ConocoPhillips Alaska{Kuparuk) Project: KuparuKRiverUnit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-166 Well Error: O.OOft Reference Wellbore- 1J-166 L1 Reference Design: 1J-166 L1 (wp07) LocaLCo-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well Plan 1J-166 Planning RKB @ 109.OOft (Doyon 141 (28+81)) Planning RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature 2.57 sigma EDM 2003.11 Single User Db Offset Datum __ . Reference 1J-166 L1 (wp07) Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 50.OOft Error Model: ISCWSA Depth Range: 5,368.39 to 12,944.98ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,481.31ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 11/3/2005 From To (ft) (ft) Survey (Wellbore) 28.00 800.00 1J-166 (wp07) (1J-166) 800.00 5,368.39 1J-166 (wp07) (1J-166) 5,368.39 12,944.98 1J-166 L1 (wp07) (1J-166 L1) Tool Name Description CB-GYRO-SS Camera based gyro single shot MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary Reference Offset Centre to No•Go Allowable Measured. Measured Centre .Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well •Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 1 E Pad 1E-105-1E-105-1E-105 12,920.97 11,550.00 1,280.59 259.01 1,021.57 Pass-Major Risk 1 E-105 - 1 E-105L1 - 1 E-105L1 10,926.39 13,529.00 1,272.65 257.93 1,014.72 Pass -Major Risk 1 E-105 - 1 E-105L2 - 1 E-105L2 12,151.97 12,300.00 1,301.33 246.66 1,054.67 Pass -Major Risk 1 E-105 - 1 E-105P62 - 1 E-105PB2 12,277.29 12,208.00 1,262.10 253.38 1,008.71 Pass -Major Risk 'Kuparuk9J Pad 1J-03 - 1J-03 - 1J-03 Out of range 1J-09 - 1J-09 - 1J-09 7,190.72 5,550.00 879.33 158.64 720.69 Pass -Major Risk 1J-10 - 1J-10 - 1J-10 5,370.43 5,550.00 1,384.87 107.62 1,277.25 Pass -Major Risk 1 J-168 - 1 J-168 - 1 J-168 Rig Out of range 1J-168 - 1J-168 L1 - 1J-168 L1 Rig Out of range 1 J-168 - 1 J-168 L2 - 1 J-168 L2 Out of range 1 J-168 - 1 J-168 L2 P61 - 1 J-168 L2 P61 Rig Out of range Plan 1J-109 -Plan 1J-109 - 1J-109 (wp01) BHI Out of range Plan 1J-115 (L9) -Plan 1J-L9 Lat A -Plan 1J-L9 L Out of range Plan 1J-118 (L10) -Plan 1J-L10 Lat A -Plan 1 J-L' Out of range Plan 1J-120 (L11) -Plan 1 J-L11 Lat A -Plan 1J-L' Out of range Plan 1J-122 (L12) -Plan 1 J-L12 Lat A -Plan 1J-L' Out of range Plan 1J-124 (L13) -Plan 1 J-L13 Lat A -Plan 1J-L' Out of range Plan 1J-127 (L8) -Plan 1J-L8 LatA -Plan 1J-L8 L<' Out of range Plan 1J-150 (Ugnu Disposal) -Plan 1J-UgnuDispc 6,576.33 4,950.00 741.58 119.87 621.71 Pass -Major Risk Plan 1J-164 - 1J-164 - 1J-164 (wp07) 12,555.22 11,403.54 1,279.94 301.84 978.11 Pass -Major Risk Plan 1J-164 - 1J-164 L1 - 1J-164 L1 (wp07) 12,643.09 11,485.60 1,266.83 337.01 929.82 Pass -Major Risk Plan 1J-164 - 1J-164 L2 - 1J-164 L2 (wp07) 12,669.86 11,507.42 1,266.18 341.58 924.60 Pass -Major Risk Plan 1J-170 -Plan 1J-170 - 1J-170 (wp01) 5,386.06 7,750.00 1,281.37 125.88 1,155.49 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 11/4!2005 5:39:25PM Page 2 of 2 COMPASS 2003.11 Build 48 ORIGINAL SURVEY PROGRAM Date: 20(x.11-02700:00:00 ValidatM: Yex Version: Dcp[h Fmm Depth To Sun~c7/Plan Tool 28.INI 8%.00 CB-CYR0.5S 8(111.011 536tt,J9 MWD+IFR-AK-CAZSC 516839 1294J.98 IJ-166 LI (xp117) MWD+IFR-AK-CAZSC NAD 27 ASP Zone 4 : WELL DETAILS: Plan 1J-166 ANTI-COLLISION SETTINGS Ground Level: 81.00 Irrterpolation Method: MD Imerval: 503tations +WS +E/-W Nonhing Easting Latittude Longitude Depth Range From: 6368.39 To 12944.98 0.00 0.00 5945691.74 558702.73 70°15'44.023N 149°31'31.597W Maximum Range:1481.30656428891 Reference: Plan: iJ-156 L1 (wp07) 330 0 270 180 ConocoPhillips Alaska (Kuparuk) Drilling & Wells Slot West Sak Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surtace: Elliptical COnic Warning Methotl: Rules Basetl 300 60 1 1 5 270 90 1 1 240 120 2 25 210 150 30 18 0 Travelling Cylinder Azimuth (TFO+AZ I) ~°) vs Centre [o Centre Separafion 115 ft/in) Travelling Cylinder Azimuth (TFO+A7.1) ~°~ vs Centre to Centre Separation ~ ISO ft/ink REFERENCE INFORMATION Coordinate (N/E) Reference: Well Plan tJ-166, True Nonh Vertical (ND) Reference: Planning RKB ~ t09.00k (DOyon 141 (28+ei)) Section (VS)Reference: Slot-(O.OON, O.OOE) Measured Depth Reference: Planning RKB @ 109.OOft (DOyon 141 (28+Bt)) Calculation Methotl: Minimum Curvature From Colour To MD 56CTx3N DE)RIL6 see ao iM k~ rvo .ws .61w oLw Trare vse~ r~l D 250 1 6380.39 80.00 2 6380.19 8191 3 6110.39 8181 261 3d88.M 1)9261 -1%130 3.61 ]19132 18°6.35 -1%0.]2 261 3495.66 1834.02 ~19)9A2 600 15.% 0.00 0.00 1M2.61 0.00 1001.% 0.00 1831.02 25D 5DD d 6688.83 88.)3 6 668).69 %.% 261 3606.91 1%9.]] 19]2.69 8.62 350fi.91 2109.92 -1%0.99 6.00 6.00 380.00 1989.7] 06.69 2109.92 8 606361 %.30 B.fi2 3606.00 2111.81 1906.]] 0.00 0.00 21)1.01 500 75D ) 8323.23 89.]3 0 TBYJ.23 89.)3 O.d6 3606.93 T)d0.4] -1886.69 Od6 %1200 4200.60 -18]3.91 3.00 0.00 86.03 2]10A] 0.00 1210A0 1J-1%L1 T11wp0]) 750 1000 9 ]883.02 01.94 m az%.6s H].e1 0.16 3513]3 4300.1) -18]3N 0.46 %2e.ao nm.aT -1H]o.26 5.00 o.oa -1]9.89 1300.1) o.o0 1no.43 va%uTZ hmon 1DOD 1250 11 8361.]6 89.38 11 ~%65 89.30 605 3629.iJ 6]68.61 -i%9.0] 60.5 3631.00 6210 d] Ae68.36 3.00 0.00 0.01 1158.61 600 521001 1.11%L1T]I.moTl 1250 1500 13 0061.15 91.11 +s as%.)a 91.11 16 %n.% %so 605 3533]5 6261.% -1886.80 a.4s 363100 Mode n%a.)e 6u 3s31.r u94.o2 n%d.1d 3.00 o.o0 3.00 000 5281.% 60o u1618 +J-+asu Td lw9o)1 1%.00 6191.m 15DD 175D 18 9%e.% 88.60 1) 98%.)0 8].16 0.16 ]613.00 %]6.62 -1880.38 O.1fi 3661.81 fi026.2] -1060.00 0.00 3.00 0.00 69]6.62 1J-186 L1 TS hweTl -1]9.99 fi0251] 175D 2DDD 19 1000619 BT.Id 19 101 %.83 %.00 20 103%8) %.28 016 366882 6601.16 -18%.29 0.46 36]1.00 6596.% -+e66.6/ OM 3666.33 fi%1.89 -1%3.96 0.00 3.00 0.60 0.00 fi501.16 0.01 65%.fi6 11186 L1 76119907) L.01 fi801.89 2000 --"~-~_----- 3000 n i~ss.u wao o:/Na 36~os zz )z~i9.m ne%6o.4~s aw 1)s.si izas.smo 3000 4000 23 t1H%a H).3o 2d 112%.L9 89.M o.1s 36z1.oo rs%.az -1H1e.6o 0.16 362a1s ]820.81 -1011.% 600 200 ooe )s%.ez 1.116e L1 n1wo)1 8.09 1620.81 4DDD SDDD % 116%.% 89.]2 26 118]0.% 80.0] 2] 119%.% 80.°1 0.06 362fi.00 8006.85 -1811.56 °.0.5 362).80 8088.% -18U.% O.d6 3W8.00 838).88 -184160 600 200 0.00 0.00 800685 1J-188 L1 TB M19907) 1]998 8089 Efi 000 8391.68 1J-166 L1 T91wG0)) SDDD 6DDD % 12W2.11 %.% 20 120%.31 %.% 60.5 36/0A1 8063.16 -18610] 0.16 3fi6a00 00%.]1 -tW].fit 2.% 0.% -18600 8163.15 0.00 88%.]1 1J-168 L1 710 (wpoll 6DDD 7DDD >D 1N88.% 8).00 31 12941.% 8].00 O.d6 3fi61.i2 88%.95 .1831.68 606 3608.00 8361.]4 -1836.01 2.00 0.00 0.00 80%.% 0.00 9351.10 11188 Lt 711 TOe IxW71 7000 8000 8000 --- ---- 9000 9000 10000 10000 11000 11000 12000 12000 0 Insulated Conductor Casing, 20", 94#, K55 x O ~ ' 34", 0.312" WT r~1i JS{J x +/- 80' MD ~. .~ m F'1 F ~t'~ ~ W ~ ~ " S o ~~° g+ 9 ., ~ ~ n' z §o i~ a~ '~ n a~~' ~~ti~~ 10-3/4", 68#, L-80, BTC, R3 ~ rr 2,360' MD / 2,183' TVD ~~ a. 34.7 degrees 1'D 13-3/8" hole Top of Ugnu C 3,456' MD / 2,863' TVD i Wellhead /Tubing dead /Tree, 10-3/4" x 4-''/z", 5,000 ksi Tubing String: 4-I/2", 12.6 #, L-80, IBTM Top of West Sak B n ~ 5,355' MD /3,487' TVD LaY ral Entry Module #I (LEM), Baker, with seal bore and ZXP packer above. Top of West Sak A ~ _ ~ 5,579' MD / 3,526' TVD Tubing, 4-'/:" IBTM, from LEM to A2 Liner, with seal stem and CAMCO 3.562" "DB" nipple. Seal bore and ZXP packer for A2 liner +/- 90' below "B" window 7-5/8", 40#, L-80, BTCM, R3 Csg 6,288' MD / 3,645' TVD ~ 84 degrees TD 9-5/8" hole (1)Gas l,i ft Mandrel, CAMCO 4-I/2"xl" ModeIKBG- 2, one (1) set ril 2,400' MD, 2,216' TVD. _ (1) Gas LiR Mandrel, CAMCO4-I/2" x I" Model KBG- 2, one (I) set at < 72 deg, 4,700' MD, 3,331' TVD. Electric Submersible Pump, CentriliR 418 BP motor, with F'C6000 wireline deployed pump. Bottom a[ 5,000' MD, 3,408' TVD 166 L2 "D" Sand Window rt 5,033'MD/3,416'TVD 77 degrees "D" Liner, 4-I/2", 12.8#, L80, BTCM, R3 1J-166 L2: (0.125" x 2.5" slots, 32 per foot, 5.9 % open area) 6-3/4" D sand lateral _ TD 12,980' MD / 3,531' TVD Angle 87.15 de~ees -146 L I "B" S ~r~,36 ' / 3,489' TV -166 L I ~ fees mer, 4-I/2", 12.8 .80, BTCM, R3 6-3/4" "B" sand a _ _ ~~ •* (0.125" x 2.5" slots, 32 per foot, 5.9%open area) TD 12,945' MD / 3,588' TVD • ~ Angle 87 degrees • i I J-166: finer, 4-I/2", 12.8#, L80, 6-3/4 A2 s lateral -~ BTCM, R3 slotted and' D 12,841' 3,733 VD ~ corrsrricerrs.~u r.~~r rrtlon l1 ogle 88.85 de~ees TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TR.4N~~S~~vIITTAL LETTER WELL NAME /~C~~:x. ~ ~r~~~ (~0 PTD# ~ S~ ~ ! / CHECK WHAT ADD-ONS "CLUE" i ' APPLIES {OPTIONS) MULTI (The permit is for~~a,.new weltbore segment of LATERAL existing welt ~<~~=~c, s'~ =,Ol°~ I Permit No,7~S--/`~'$ API No..~o - 029- ~?32~,~ (If API number ~ Production should continue to be re orted as f w ! P , 'fast two (Z) digits a function of the original API number stated f are between 60-69) 1 above. ; / 2 ' p.OS~ PILOT HOLE ; In accordance with ZO AAC 25.005(f), alt (PI~C} ~ records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) i j and API number (50 70/80) from records, data and togs acquired ~ for well (name on permit). 1 SPACL~iG The permit is approved subject to full EXCEPTION ~ compliance with ZO AAC 25.055. Approval to i I i' perforate and producelinieet is contingent ;upon issuance of a conservation order ~ approving a spacing exception. r (Company Name) assumes ~ 'the liability of any protest to the spacing ~ ~ exception that may occur. ~ DRY DITCH AIt dry ditch sample sets submitted to the ~ SAMPLE 'Commission must be in no greater than 30' ~ r sample intervals from below the permafrost j or from where samples are f rst caught and j j 10' sample intervals through target zones. Rev: 04/01/05 C\j ody\transmittal_checklist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL-490150 Well Name: KUPARUK RIV U WSAK 1J-166L1 Program DEV Well bore seg C~ PTD#:2051990 Company CONOCOPHILLIPS ALASKA INC DEV / PEND GeoArea 890 Unit 11170 On/Off Shore On Annular Disposal ',J Initial Class(fype Administration ! 1 Permitfee attached . _ - ... _ NA_ . _ - - -West Sak B Sand multilateral well segment; fee waived per 20 AAC 25.005(e), ~! 2 Lease number appropriate- - - _ - - - . - .. - - - - - Yes - _ Surface location and to - rod_uctive interval in ADL 025661;. TD in ADL 025650.- ... - pp ! 3 Uniquewell_nameandnumber-- ------ - -- -------- - ---- -Yes.---- ---- -------- --- - - --- - --- -- - -- -- -- 4 Well located in.a,defnedpool- . _ ... _ Yes - ... - . . KRU WestSakOil Pool, oyerned_b Conservation-Order No, 4068- . - _ g y ', 5 Well located proper distance from drilling unit.boundary_ - - . Yes Well is more than,500 feet from an external property line. ..... - !, 6 Well located proper distance from other wells- .. _ - - - - . - - _ Yes No restrictions as-to well spacing in CO.4066._ I; 7 Sufficient acreage available in_drilling unit- - .. - - - _ - .. - Yes No restrictions as-to well spacing except that no_pay shall be opened in a well closer . _ _ - _ - . - ', 8 If deviated, is-wellbore plat_included - - - - - - - - - - - - - - - - - -- - -- - - - - - - - - - -Yes - - _ _ - _ than 500 feet to_an exte[nal_prope[ty1ine.- - . - . - ... - . - 9 Operator only affected party--------- --------------------- ---------Yes___ __ - - j 10 Ope[atorhas_appropriate-bond in force ---- - ---------- --- - ---- Yes-- -- -- --- --- ---- --- - - --- --- --- --- --- - ~i 11 Permit. can be issued without cons@ryationorder___________________ _________Yes-.---- --_---___-__-_-_-__..-._-.._...-.-..__ Appr Date ~ 12 Permit-can be issued without administrative_approval _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - _ - - - - FD 12/812005 ~ 13 Can permit be approved before 15-day wait Yes S 14 Well located within area and strata authorized by Injection Orde[ # (putlO# in-co mments)-(For. NA. - - - - . - .. - - - _ - . _ . - - - - . - - ... - ' 15 All wells within!/4-mile area ofreyiewidentifed(Forservicewellonly)______ _________NA--.___. --___-__________--.--------------- ----------------------------------- 16 Pre-produced injector; duration of pre p[oduction less than.3 months-(For service well only) NA- ACMP-Findingof COnsistency_hasbee_nissued.forthisp[oject---------- --------- NA___-.. ---_-.-__--_.._______-_-...._...----___ Engineering 18 Conductorstring_provided-------------------------------- ---------NA___--_. _COn_ductor_setinmotherbore,_1J,166(205-198).-__-.-,--___..----..--....--_-.-_-..---. i 19 Surface casingprotects all knpwn USDWs - . - - ...... - - NA- _ _ - ... All aquifers exempted, 40 CFR 147.102_ (b)j3)._ _ - - - - - . - - _ . - 20 CMT-voladeguate_tocirculate on conductor-&surf_csg_________-.--- --..---_NA._..--- _Surfacecasingset in motherbore-------------------------___-_-_-.-----.-_--. 21 CMT-vo[adequ_ate_totie-[n long string to surfcsg___---__---_------ ---------NA___..-_ .Production_casingset in motherbore._________ ___ .---.----.---_-___--__-.__- 22 CMT-will coyer all know_n-productiyehorizons____---------------- - ------- No___.-_ _Slottedlinercompletionplanned,-____---,..---- __-.----------.-_---__- ----.. 23 Casing designs adequate for- C, T B &.permafrost--- - - - - - -- - - - - - - - -- - - - - - - - NA_ . - - _ - _ Motherbore met design [equi[ements._ NA for slotted Iinec- . - - _ - - _ _ - - - ------------------ 24 Adequate tankage.or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes _ - _ _ - -Rig is_equipped with steelpits. -No reserve_pitplanned, All waste to approved annulus or disposal well. 25 If-a-re-drill,has.a.10~03for abandonment been approved ............. ......... NA,______ ----__----__-____----__.._.---___.-_----_--._--.___--__-___---_ 26 Adequate wellbore separationproposed- - - - - - - - - - - - - - - - - - - - - - -- - - - - - - -- -Yes _ _ _ - _ . -Proximity. analysis perfom?ed, Nearest branch is A section X20' tvd below. - _ _ - - - - - - - - - - _ - _ _ - _ - - - - _ 27 Ifd]verterrequired,doesitmeetregulations_____--------------_ -_-...... NA---__-- .BOPstackwillalready_be in place,______________--.___------.--__----__-------_- Appr Date 28 Drilling fluid. program sehematic.& equip lisladequate_ - - - - - - - - - - - - -Yes . - _ - - - .Maximum expected fo[mation pressure 8,7_EMW.- Planned MW 8:9ppg. _ TEM 12!1312005 29 BOPEs,-tlo they meetregulation . _ _ _ _ ... Yes _ _ _ _ _ _ _ _ _ _ ___ _ _ ________ _ _ _ _ _ _ _ Q~ ~ 30 BOPE-press rating appropriate; test t_o-(put psig in comments)- - - - - - - - - - - - - - - - - - - - Yes _ _ _ - - . - MASP calculated at 1220psi, 3000-psi-BOP test-proposed.- - - - - _ _ _ - . , - - - _ _ _ _ .. _ _ _ _ _ _ .. _ _ _ _ _ 31 Choke-manifold complies wIAPI_RP-53 (May 94)_ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ - - 32 Work willoccu[withoutoperationshutdow.n______________________ __ Yes___._, ___-..-___--___-..___.-____---_-_.-__-..__.-._-..--._-..__.--___ _.__ 33 Is presence-of H2S gas probable - - - -- - - - - - - - - - - - - - - - - - - - - - - - - --- - - - - - No_ _ _ _ . - . _ Slight. f12S-is reported in_ offset wells. Mud should preclude H2S on rigs, Rig has sensors and zlarms, - - . - _ - . 34 Mechanical condition of wells withinAORyerifled(Forservicewellon_ly) ..... ......... NA-______ _._- -_-_---__-,-_____ ______________ ____ Geology 35 Pe[mitcan be issued w/o hydrogen_sulfide measures - - - - - ------- - - - - -- - - - - - -Yes - - .. - - -Nearest wells in_ pool, 1 D-127 & 1D-131- measured 2 & 8-ppm.in 2002 &_2004,- - _ . - .. - _ - - - _ - . 36 Data-presented on potential oyerpressur_e zones- ... - . - - - Yes - - - _ _ -respectively.-Expected_rese_rvoi_r pressure is 8Jppg EMW; will be drilled with .... . .... . . . . . . .. . .. . Appr Date 37 Seismic analysis ofshallow gas.zones- - - _ - _ - - - - . - - - - - - - - - - -- - - - - NA_ - . - - - - - 8.6 ppq oil,based_mud, Mitigation measures-discuss-in Drilling Hazards section, - - . - - SFD 12!8/2005 38 Seabed condition survey-(if off-shore) _ - - - - - - - - - --- - - -- N_A_ 39 Contact namelphone far weekly-progress reports [exploratory only] _ _ _ _ _ _ _ _ _ _ _ _ _ ___ NA_ _ _ . _ _ - - - - - _ _ - . - - _ _ - _ - _ _ _ _ . _ . _ _ _ . _ - - Geologic Engineering P lic Date: Date ' West Sak B Sand multilateral well segment. Date Commissioner: ner Commissione : ~~ ~. ~,` Well History File APPENDIX Inforrnaiion of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 'JV~~ Sperry-Sun Dri"~1"ing Services '` LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue May 02 09:10:27 2006 p~vv ~ ~ U Reel Header Service name .............LISTPE Date .....................06/05/02 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Tape Header Service name .............LISTPE Date .....................06/05/02 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-166 Ll API NUMBER: 500292329160 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: Ol-MAY-06 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 4 JOB NUMBER: MW0004149018 MW0004149018 MW0004149018 LOGGING ENGINEER: P. ORTH T. CALVIN T. CALVIN OPERATOR WITNESS: D. GLADDEN D. GLADDEN D. GLADDEN MWD RUN 5 JOB NUMBER: MW0004149018 LOGGING ENGINEER: T. CALVIN OPERATOR WITNESS: D. GLADDEN SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: 10E FNL: FSL: 1880 FEL: 2508 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SI~'' (IN) 1ST STRING 9.875 2ND STRING 6.750 3RD STRING PRODUCTION STRING REMARKS: SIZE (IN) DEPTH (FT) ~`°'~°'~ 10.750 2368.0 7.875 6350.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK EXITING THE 1J-166 L1 PB1 WELLBORE AT 9389'MD/3537'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,4,5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 4 & 5 ALSO INCLUDED AT-BIT INCLINATION (ABI) AND GEOPILOT ROTARY STEERABLE BHA (GP) THE PURPOSE OF MWD RUN 3 WAS TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. ONLY SROP DATA ARE PRESENTED FOR RUN 3. 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 1-5 REPRESENT WELL 1J-166 Ll WITH API#:50-029-23291-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12952'MD/3592'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. S File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER : 1 ~~"' EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 2331.0 FET 2350.0 RPM 2350.0 RPS 2350.0 RPD 2350.0 RPX 2350.0 ROP 2378.5 all bit runs merged. STOP DEPTH 12894.5 12901.5 12901.5 12901.5 12901.5 12901.5 12952.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 2331.0 5380.5 3 5381.0 5422.0 4 5422.0 9389.0 5 9389.5 12952.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 2331 12952 7641.5 21243 2331 12952 RPD MWD OHMM 1.21 2000 63.8966 21104 2350 12901.5 RPM MWD OHMM 3.53 2000 52.2706 21104 2350 12901.5 RPS MWD OHMM 4.09 2000 47.2152 21104 2350 12901.5 RPX MWD OHMM 4.1 2000 56.891 21104 2350 12901.5 FET MWD HOUR 0.18 222.15 1.11255 21104 2350 12901.5 GR MWD API 23.81 116.11 62.6617 21128 2331 12894.5 ROP MWD FT/H 0.44 461.05 193.011 21148 2378.5 12952 First Reading For Entire File..........2331 Last Reading For Entire File...........12952 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2331.0 5380.0 RPD 2350.0 5380.0 RPX 2350.0 5380.0 RPM 2350.0 5380.0 FET 2350.0 5380.0 RPS 2350.0 5380.0 gOp 2378.5 5380.5 LOG HEADER DATA DATE LOGGED: 13-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5380.0 TOP LOG INTERVAL (FT) 2378.0 BOTTOM LOG INTERVAL (FT) 5380.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 34.4 MAXIMUM ANGLE: 82.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 163686 EWR4 ELECTROMAG. RESIS. 4 56933 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER' S CASING DEPTI~"" ~'~'T) 2368. 0 ~/ BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G) 9.25 MUD VISCOSITY (S) 59.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 100 FLUID LOSS (C3) 4.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.900 60.0 MUD AT MAX CIRCULATING TERMPERATURE : 1.580 116.0 MUD FILTRATE AT MT: 3.500 60.0 MUD CAKE AT MT: 3.000 60.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .1IN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size N sam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2331 5380.5 3855.75 6100 2331 5380.5 RPD MWD020 OHMM 1.21 2000 20.3094 6061 2350 5380 RPM MWD020 OHMM 3.53 1073.44 13.4695 6061 2350 5380 RPS MWD020 OHMM 4.09 64.65 12.6567 6061 2350 5380 RPX MWD020 OHMM 4.1 47.78 11.6406 6061 2350 5380 FET MWD020 HOUR 0.18 53.06 0.995471 6061 2350 5380 GR MWD020 API 23.81 114.32 69.1836 6099 2331 5380 ROP MWD020 FT/H 6.22 461.05 201.988 6005 2378.5 5380.5 First Reading For Entire File..........2331 Last Reading For Entire File...........5380.5 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 5381.0 5422.0 LOG HEADER DATA DATE LOGGED: 21-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5422.0 TOP LOG INTERVAL (FT) 5380.0 BOTTOM LOG INTERVAL (FT) 5422.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: •0 MAXIMUM ANGLE: •0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6350.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 78.0 MUD PH: •0 MUD CHLORIDES (PPM): 101500 FLUID LOSS (C3) 1.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 77.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL ~~°`°'' MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 Name Service Unit Min Max DEPT FT 5381 5422 ROP MWD030 FT/H 2.54 75.5 Mean Nsam 5401.5 83 28.626 83 First Reading 5381 5381 Last Reading 5422 5422 First Reading For Entire File..........5381 Last Reading For Entire File...........5422 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5380.5 9389.0 FET 5380.5 9389.0 RPX 5380.5 9389.0 RPM 5380.5 9389.0 RPD 5380.5 9389.0 RPS 5380.5 9389.0 ROP 5422.5 9389.0 LO G HEADER DATA DATE LOGGED: 24-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9389.0 TOP LOG INTERVAL (FT) 5422.0 BOTTOM LOG INTERVAL (FT) 9389.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.4 MAXIMUM ANGLE: 92.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 EWR4 Electromag Resis. 4 59475 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6350.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 71.0 MUD PH: •0 MUD CHLORIDES (PPM): 25000 FLUID LOSS (C3) 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 118.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value .............`'°°:''.......-999 ~~--'' Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5380.5 9389 7384.75 8018 5380.5 9389 RPD MWD040 OHMM 7.68 2000 81.258 8018 5380.5 9389 RPM MWD040 OHMM 8.2 2000 72.0095 8018 5380.5 9389 RPS MWD040 OHMM 8.14 298.91 66.9742 8018 5380.5 9389 RPX MWD040 OHMM 7.82 567.78 83.8765 8018 5380.5 9389 FET MWD040 HOUR 0.18 222.15 1.60038 8018 5380.5 9389 GR MWD040 API 26.32 116.11 58.6656 8018 5380.5 9389 ROP MWD040 FT/H 2.47 313.69 206.001 7934 5422.5 9389 First Reading For Entire File..........5380.5 Last Reading For Entire File...........9389 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 9389.5 12901.5 GR 9389.5 12894.5 RPD 9389.5 12901.5 FET 9389.5 12901.5 RPM 9 3 8 9. 5'°'"°"J 12 9 01 . 5 ROP 9389.5 12952.0 RPS 9389.5 12901.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 26-JAN-06 Insite 66.37 Memory 12952.0 9389.0 12952.0 84.6 98.3 TOOL NUMBER 160788 59475 6.750 6350.0 Mineral Oil Base 8.80 71.0 .0 28000 3.2 .000 .0 .000 126.0 .000 .0 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD 0 5 0 OHMM "'"~ 1 6 8 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9389.5 12952 11170.8 7126 9389.5 12952 RPD MWD050 OHMM 4.62 2000 81.6871 7025 9389.5 12901.5 RPM MWD050 OHMM 4.37 2000 63.2182 7025 9389.5 12901.5 RPS MWD050 OHMM 5.02 2000 54.4794 7025 9389.5 12901.5 RPX MWD050 OHMM 5.37 2000 65.1319 7025 9389.5 12901.5 FET MWD050 HOUR 0.19 11.3 0.656771 7025 9389.5 12901.5 GR MWD050 API 29.25 114.6 61.5581 7011 9389.5 12894.5 ROP MWD050 FT/H 0.44 3 18.71 172.899 7126 9389.5 12952 First Reading For Entire File..........9389.5 Last Reading For Entire File...........12952 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/05/02 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................06/05/02 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library Physical EOF Physical EOF Scientific Technical Services Scientific Technical Services End Of LIS File