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Home My WebLink About203-0411. 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: Convert to Jet Pump 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 13280'feet None feet true vertical 3811' feet None feet Effective Depth measured 13280'feet 7027', 7086'feet true vertical 3811' feet 3605', 3625' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" x 2-7/8" L-80 7336' MD 3697' TVD Packers and SSSV (type, measured and true vertical depth) 7027' MD 7086' MD N/A 3605' TVD 3625' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: West Sak Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 10 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker Premier Packer Packer: Baker S-3 Packer SSSV: None Will Parker will.parker@conocophillips.com (907) 265-6239Production Engineer 7704-13179' 3768-3809' 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) 5 Gas-Mcf MD 1075 Size 110' 10 240010 25 350675 360 measured TVD 5-1/2" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-041 50-029-23144-00-00 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: ADL0025638, ADL00225649 Kuparuk River Field/ West Sak Oil Pool KRU 1C-178 Plugs Junk measured Length Slotted Liner Liner 6981' 5842' Casing 3599' 3810' 7007' 13244' 7705' 110'Conductor Surface Tieback 16' 7-5/8" 76' 7733' 3770' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 1:10 pm, May 29, 2024 Digitally signed by Will Parker DN: CN=Will Parker, O=ConocoPhillips, OU=GKA Production Engineering, E=Will.Parker@ConocoPhillips.com, C=US Reason: I am the author of this document Location: Date: 2024.05.29 11:23:31-08'00' Foxit PDF Editor Version: 13.0.0 Will Parker DSR-5/29/24 RBDMS JSB 053024 DTTMSTART JOBTYP SUMMARYOPS 4/28/2024 OPTIMIZE WELL RAN 2.29" MILL & TAGGED HYDRATES @ 1318' CTMD, MILL/CLEAN DOWN TO 3600' BEFORE BREAKING FREE & DRY DRIFTING DOWN TO TOP OF SLIP STOP @ 6475' CTMD. PULLED SLIP STOP @ 6475' CTMD. CHANGED PACKOFF & RIH TO PULL POGLM (IN PROGRESS). 4/29/2024 OPTIMIZE WELL PULLED POGLM @ 6476' CTMD. READY FOR SLICKLINE. 5/19/2024 OPTIMIZE WELL DRIFT THRU THE CMU @ 6487' RKB W/ GAUGE RING. DISPLACED IA W/ 90 BBLS OF CISW & 40 BBLS OF DIESEL. SHIFT CMU CLOSED & ACHIEVED PASSING MITIA TO 3500 PSI. SHIFT CMU @ 6487' RKB BACK OPEN & SET 2" JET PUMP W/ SLIP STOP ON TOP. FUNCTION TESTED JET PUMP & SAW A POSITIVE PRESSURE RESPONSE ON THE TBG. JOB COMPLETE. ***LIH*** ***2" JET PUMP (9B RATIO) W/ SLOTTED ROCK SCREEN (SERIAL # CP-1180) & SOFT SET W/ SINGLE SPARTEK GAUGE (1 MIN SAMPLE RATE) (OAL-96", 2.29" NO-GO), 2.5" SLIP STOP (OAL-16", 2.25" OD)*** (GAUGE PLUG IN TIME 5/19/24 @ 13:10) 1C-178 Convert to Jet Pump Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1C-178 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cycled CMU, Set Jet pump assembly 1C-178 5/19/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: though all straigh-run joints and pups 1/12/2018 pproven NOTE: 5.5" Tie-Back Liner has a Polycore Ultratube plastic liner installed- 1/11/2018 pproven NOTE: View Schematic w/ Alaska Schematic9.0 4/27/2009 ninam NOTE: WORKOVER INCLUDED SETTING 5.5" INNER CSG STRING & NEW TUBING COMPLETION 4/27/2009 osborl NOTE: Surface CSG Patch, OAL=6'11", Mtls: 0.500 wall X65 , 0.365 wt (see 2/20/09 WSR) 2/20/2008 lmosbor NOTE: MULTILATERAL WELL - 1C-178 ( B/C-SANDS), 1C-178L1 (D-SAND) 4/29/2003 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 34.3 110.0 110.0 62.50 H-40 WELDED SURFACE 7 5/8 6.87 28.3 7,733.3 3,770.4 29.70 L-80 BTCM TIEBACK(2015) - Polycore Ultratube lining 5 1/2 4.30 26.4 7,007.0 3,598.8 17.00 L-80 BTC B-SAND Slotted Liner 4 1/2 3.96 7,401.5 13,243.8 3,809.9 12.60 L-80 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 26.9 Set Depth … 6,933.0 Set Depth … 3,574.2 String Max No… 2 7/8 Tubing Description Tubing – Production Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE8rd ID (in) 2.44 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) 26.8 26.8 0.00 HANGER 10.813 HANGER 5.688 6,487.2 3,420.9 69.65 SLEEVE 3.740 CMU SLIDING SLEEVE (CLOSED= 5/19/2024) (OPENED=5/19/2024) Baker CMU Sliding sleeve 2.250 6,892.6 3,560.8 70.55 GAUGE 4.160 SLB SPECIAL CLEARANCE GAUGE CARRIER MANDREL Camco SGM 2.398 6,913.6 3,567.8 70.64 LOCATOR 3.460 BAKER LOCATOR 2.400 6,914.7 3,568.2 70.65 SEAL ASSY 3.000 BAKER 80-32 SEAL ASSEMBLY Baker 80-32 Seal Assembl y 2.410 Top (ftKB) 6,978.5 Set Depth … 7,068.7 Set Depth … 3,619.3 String Max No… 5.03 Tubing Description Tubing – Production Wt (lb/ft) Grade L-80 Top Connection BTC ID (in) 4.00 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) 6,978.5 3,589.3 70.59 SETTING SLEEVE 6.400 BAKER HRDE LINER SETTING SLEEVE Baker HRDE 5.750 6,993.7 3,594.4 70.54 SBE 5.030 80-40 SEAL BORE RECEPTACLE Baker 80-40 4.000 7,027.0 3,605.5 70.45 PACKER 6.560 BAKER PREMIER PACKER Baker Premier 3.880 7,050.7 3,613.4 70.73 LOCATOR 5.200 BAKER LOCATOR Baker GBH-22 3.870 7,051.3 3,613.6 70.73 SEAL ASSY 4.730 GBH-22 LOCATING SEAL ASSY Baker GBH-22 3.870 Top (ftKB) 7,055.8 Set Depth … 7,335.6 Set Depth … 3,696.9 String Max No… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,055.8 3,615.1 70.79 PBR 5.500 PBR - SBR & SEAL ASSY RUN ON 4/22/2009 WORKOVER 5.5" PRODUCTION CSG STABBED INTO PBR BAKER 3.875 7,086.2 3,625.0 71.14 PACKER 6.620 BAKER S-3 PACKER 3.875 7,091.8 3,626.8 71.20 XO Enlarging 5.500 CROSSOVER 4.5" x 5" 4.500 7,098.3 3,628.9 71.28 XO Reducing 5.000 CROSSOVER 5" x 4.5" 4.500 7,108.6 3,632.2 71.40 NIPPLE 5.590 'DB' NIPPLE w/ NO GO PROFILE CAMCO 3.750 7,334.6 3,696.6 74.99 WLEG 5.210 WIRELINE ENTRY GUIDE 3.960 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) 6,487.0 3,420.8 69.65 JET PUMP SET 2.28''AVA NO-GO W/2''RC JET PUMP (RATIO=9B)W/SLOTTED ROCK SCREEN & SINGLE SPARTEK GAUGE (OAL 96") CP11 80 5/19/2024 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) 6,919.0 3,569.6 70.67 XO Reducing 5.063 4 ½'' 12.6# L-80 IBTM x 5½'' BTC Polycore Cross Over 3.938 6,976.9 3,588.8 70.59 XO Reducing 5.230 3 1/2 x 4 ½'' crossover 2.992 6,988.6 3,592.7 70.56 LOCATOR 5.200 LOCATOR 3.870 7,401.5 3,713.7 75.41 SLEEVE 6.390 HR SLEEVE w/ EXTENSION BAKER 5.010 7,414.2 3,716.9 75.65 BUSHING 5.540 BAKER BUSHING 4.950 7,415.9 3,717.3 75.69 NIPPLE 6.060 BAKER RS NIPPLE 4.875 7,428.1 3,720.3 75.92 XO Reducing 5.770 CROSSOVER 5.5" x 4.5" 3.940 1C-178, 5/29/2024 9:07:51 AM Vertical schematic (actual) B-SAND Slotted Liner; 7,401.5- 13,243.8 IPERF; 7,704.0-13,179.0 D-SAND Slotted Liner; 7,356.2- 13,579.8 SURFACE; 28.3-7,733.3 IPERF; 7,413.0-13,493.0 PACKER; 7,086.2 PACKER; 7,027.0 TIEBACK(2015) - Polycore Ultratube lining; 26.4-7,007.0 JET PUMP; 6,487.0 SLEEVE; 6,487.2 SLIP STOP; 6,485.0 CONDUCTOR; 34.3-110.0 HANGER; 26.9 KUP PROD KB-Grd (ft) 30.00 RR Date 5/27/2003 Other Elev… 1C-178 ... TD Act Btm (ftKB) 13,280.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292314400 Wellbore Status PROD Max Angle & MD Incl (°) 92.00 MD (ftKB) 11,208.01 WELLNAME WELLBORE1C-178 Annotation Last WO: End Date 5/25/2015 H2S (ppm) 40 Date 8/12/2016 Comment SSSV: NIPPLE Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,491.8 3,735.1 77.16 LOCATOR 4.990 BAKER LOCATOR SUB 3.510 13,209.5 3,809.4 89.35 XO Reducing 4.500 CROSSOVER 4.5" x 4" 4.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,704.0 13,179.0 3,767.7 3,809.2 WS B, WS B, WSC, 1C-178 4/16/2003 12.0 IPERF Alternating slotted/blank pipe - 30' joints w/8 holes/ft .25"x2.5"/slotted joint 1C-178, 5/29/2024 9:07:51 AM Vertical schematic (actual) B-SAND Slotted Liner; 7,401.5- 13,243.8 IPERF; 7,704.0-13,179.0 D-SAND Slotted Liner; 7,356.2- 13,579.8 SURFACE; 28.3-7,733.3 IPERF; 7,413.0-13,493.0 PACKER; 7,086.2 PACKER; 7,027.0 TIEBACK(2015) - Polycore Ultratube lining; 26.4-7,007.0 JET PUMP; 6,487.0 SLEEVE; 6,487.2 SLIP STOP; 6,485.0 CONDUCTOR; 34.3-110.0 HANGER; 26.9 KUP PROD 1C-178 ... WELLNAME WELLBORE1C-178 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1C-178L1 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: PULL C-LOCK & POGLM, SET C-LOCK, JET PUMP & ROCKSCREEN & 1/2" SLIP STOP on LOCK 1C-178L1 8/21/2017 pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 4/27/2009 ninam NOTE: WORKOVER INCLUDED SETTING 5.5" INNER CSG STRING & NEW TUBING COMPLETION 4/27/2009 pproven NOTE: Surface CSG Patch, OAL=6'11", Mtls: 0.500 wall X65 , 0.365 wt (see 2/20/09 WSR) 2/20/2008 lmosbor NOTE: MULTILATERAL WELL - 1C-178 ( B/C-SANDS), 1C-178L1 (D-SAND) 4/29/2003 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread D-SAND Slotted Liner 4 1/2 3.96 7,356.2 13,579.8 3,767.7 12.60 L-80 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) 7,373.0 3,706.3 76.74 SWIVEL 4.500 TORQUE-THRU SWIVEL 3.990 13,557.6 3,766.1 85.96 XO 4.5x3.5 4.500 3.500 13,559.1 3,766.2 85.94 BENT JT 3.500 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,413.0 13,493.0 3,714.9 3,762.0 WS D, 1C-178L1 4/16/2003 12.0 IPERF Alternating slotted/blank pipe - 30' joints w/8 holes/ft .25"x2.5"/slotted joint 1C-178L1, 5/29/2024 9:07:52 AM Vertical schematic (actual) D-SAND Slotted Liner; 7,356.2- 13,579.8 IPERF; 7,413.0-13,493.0 B-SAND Slotted Liner; 7,401.5- 13,243.8 SURFACE; 28.3-7,733.3 IPERF; 7,704.0-13,179.0 PACKER; 7,086.2 PACKER; 7,027.0 TIEBACK(2015) - Polycore Ultratube lining; 26.4-7,007.0 JET PUMP; 6,487.0 SLEEVE; 6,487.2 SLIP STOP; 6,485.0 CONDUCTOR; 34.3-110.0 HANGER; 26.9 KUP PROD KB-Grd (ft) 30.00 RR Date 5/27/2003 Other Elev… 1C-178L1 ... TD Act Btm (ftKB) 13,626.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292314460 Wellbore Status PROD Max Angle & MD Incl (°) 95.49 MD (ftKB) 7,665.91 WELLNAME WELLBORE1C-178 Annotation Last WO: End Date 5/25/2015 H2S (ppm) 40 Date 8/12/2016 Comment SSSV: NIPPLE 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Performed: Install Whipstock Perforate Other Stimulate Alter Casing Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops 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 13280'feet None feet true vertical 3811'feet None feet Effective Depth measured 13280'feet 7027', 7086'feet true vertical 3811'feet 3605', 3625'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" x 2-7/8" L-80 7336' MD 3697' TVD Packers and SSSV (type, measured and true vertical depth) 7027' MD 7086' MD N/A 3605' TVD 3625' 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: 7733' 3770' Burst Collapse Slotted Liner Liner 6981' 5842' Casing 3599' 3810' 7007' 13244' 7705' 110'Conductor Surface Tieback 16' 7-5/8" 76' measured TVD 5-1/2" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-041 50-029-23144-00-00 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: ADL0025638, ADL00225649 Kuparuk River Field/ West Sak Oil Pool KRU 1C-178 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) 60 Gas-Mcf MD 2350 Size 110' 1190 875335 60 3351190 335 N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 335 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker Premier Packer Packer: Baker S-3 Packer SSSV: None Will Parker will.parker@conocophillips.com 265-6239Production Engineer 7704-13179' 3768-3809' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Operations shutdown Change Approved Program Other: Convert to JP to GL By Kayla Junke at 11:31 am, May 24, 2023 DTTMSTART JOBTYP SUMMARYOPS 3/7/2023 REPAIR WELL PULLED 2.5" SLIP STOP & JET PUMP ASSEMBLY @ 6487' RKB (GAUGES UNDER JET PUMP SENT TO WIRELINE SHOP). JOB COMPLETE. 4/24/2023 REPAIR WELL FLUSHED IA WITH 70 BBLS OF DIESEL.SET 2.25" POGLM IN CMU SLIDING SLEEVE @ 6487' RKB (1" NON-RETRIEVABLE OV INSIDE, 5/16" PORT). SET SLIP STOP ON TOP OF POGLM @ 6487' RKB, GOOD DRAWDOWN TEST ON IA. JOB COMPLETE 1C-178 Convert to Gas Lift Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1C-178 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set POGLM 1C-178 4/24/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: though all straigh-run joints and pups 1/12/2018 pproven NOTE: 5.5" Tie-Back Liner has a Polycore Ultratube plastic liner installed- 1/11/2018 pproven NOTE: WORKOVER INCLUDED SETTING 5.5" INNER CSG STRING & NEW TUBING COMPLETION 4/27/2009 osborl NOTE: Surface CSG Patch, OAL=6'11", Mtls: 0.500 wall X65 , 0.365 wt (see 2/20/09 WSR) 2/20/2008 lmosbor NOTE: MULTILATERAL WELL - 1C-178 ( B/C-SANDS), 1C-178L1 (D-SAND) 4/29/2003 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 34.3 110.0 110.0 62.50 H-40 WELDED SURFACE 7 5/8 6.87 28.3 7,733.3 3,770.4 29.70 L-80 BTCM TIEBACK(2015) - Polycore Ultratube lining 5 1/2 4.30 26.4 7,007.0 3,598.8 17.00 L-80 BTC B-SAND Slotted Liner 4 1/2 3.96 7,401.5 13,243.8 3,809.9 12.60 L-80 SLHT Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 26.9 Set Depth 6,933.0 Set Depth 3,574.2 String Ma 2 7/8 Tubing Description Tubing Production Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE8rd ID (in) 2.44 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) 26.8 26.8 0.00 HANGER 10.813 HANGER 5.688 6,487.2 3,420.9 69.65 SLEEVE 3.740 BAKER CMU SLIDING SLEEVE (CLOSED= 6/17/2021) (OPENED=1/06/2022) Baker CMU Sliding sleeve 2.250 6,892.6 3,560.8 70.55 GAUGE 4.160 SLB SPECIAL CLEARANCE GAUGE CARRIER MANDREL Camco SGM 2.398 6,913.6 3,567.8 70.64 LOCATOR 3.460 BAKER LOCATOR 2.400 6,914.7 3,568.2 70.65 SEAL ASSY 3.000 BAKER 80-32 SEAL ASSEMBLY Baker 80-32 Seal Assembl y 2.410 Top (ftKB) 6,978.5 Set Depth 7,068.7 Set Depth 3,619.3 String Ma 5.03 Tubing Description Tubing Production Wt (lb/ft) Grade L-80 Top Connection BTC ID (in) 4.00 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) 6,978.5 3,589.3 70.59 SETTING SLEEVE 6.400 BAKER HRDE LINER SETTING SLEEVE Baker HRDE 5.750 6,993.7 3,594.4 70.54 SBE 5.030 BAKER 80-40 SEAL BORE RECEPTACLE Baker 80-40 4.000 7,027.0 3,605.5 70.45 PACKER 6.560 BAKER PREMIER PACKER Baker Premier 3.880 7,050.7 3,613.4 70.73 LOCATOR 5.200 BAKER LOCATOR Baker GBH-22 3.870 7,051.3 3,613.6 70.73 SEAL ASSY 4.730 BAKER GBH-22 LOCATING SEAL ASSEMBLY baker GBH-22 3.870 Top (ftKB) 7,055.8 Set Depth 7,335.6 Set Depth 3,696.9 String Ma 4 1/2 Tubing Description Tubing Production Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,055.8 3,615.1 70.79 PBR 5.500 BAKER PBR - SBR & SEAL ASSY RUN ON 4/22/2009 WORKOVER 5.5" PRODUCTION CSG STABBED INTO PBR 3.875 7,086.2 3,625.0 71.14 PACKER 6.620 BAKER S-3 PACKER 3.875 7,091.8 3,626.8 71.20 XO Enlarging 5.500 CROSSOVER 4.5" x 5" 4.500 7,098.3 3,628.9 71.28 XO Reducing 5.000 CROSSOVER 5" x 4.5" 4.500 7,108.6 3,632.2 71.40 NIPPLE 5.590 CAMCO 'DB' NIPPLE w/ NO GO PROFILE 3.750 7,334.6 3,696.6 74.99 WLEG 5.210 WIRELINE ENTRY GUIDE 3.960 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) 6,485.0 3,420.2 69.65 SLIP STOP Set slip stop on POGLM 4/24/2023 0.000 6,487.0 3,420.8 69.65 POGLM Set 2.25" POGLM (1" OV 5/16" port non-retrievable) 55" OAL 4/24/2023 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) 6,919.0 3,569.6 70.67 XO Reducing 5.063 4 ½'' 12.6# L-80 IBTM x 5½'' BTC Polycore Cross Over 3.938 6,976.9 3,588.8 70.59 XO Reducing 5.230 3 1/2 x 4 ½'' crossover 2.992 6,988.6 3,592.7 70.56 LOCATOR 5.200 LOCATOR 3.870 7,401.5 3,713.7 75.41 SLEEVE 6.390 BAKER HR SLEEVE w/ EXTENSION 5.010 7,414.2 3,716.9 75.65 BUSHING 5.540 BAKER BUSHING 4.950 7,415.9 3,717.3 75.69 NIPPLE 6.060 BAKER RS NIPPLE 4.875 1C-178, 5/15/2023 11:38:21 AM Vertical schematic (actual) B-SAND Slotted Liner; 7,401.5- 13,243.8 IPERF; 7,704.0-13,179.0 D-SAND Slotted Liner; 7,356.2- 13,579.8 SURFACE; 28.3-7,733.3 IPERF; 7,413.0-13,493.0 PACKER; 7,086.2 PACKER; 7,027.0 TIEBACK(2015) - Polycore Ultratube lining; 26.4-7,007.0 SLEEVE; 6,487.2 POGLM; 6,487.0 SLIP STOP; 6,485.0 CONDUCTOR; 34.3-110.0 HANGER; 26.9 KUP PROD KB-Grd (ft) 30.00 RR Date 5/27/2003 Other Elev 1C-178 ... TD Act Btm (ftKB) 13,280.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292314400 Wellbore Status PROD Max Angle & MD Incl (°) 92.00 MD (ftKB) 11,208.01 WELLNAME WELLBORE1C-178 Annotation Last WO: End Date 5/25/2015 H2S (ppm) 40 Date 8/12/2016 Comment SSSV: NIPPLE Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,428.1 3,720.3 75.92 XO Reducing 5.770 CROSSOVER 5.5" x 4.5" 3.940 7,491.8 3,735.1 77.16 LOCATOR 4.990 BAKER LOCATOR SUB 3.510 13,209.5 3,809.4 89.35 XO Reducing 4.500 CROSSOVER 4.5" x 4" 4.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,704.0 13,179.0 3,767.7 3,809.2 WS B, WS B, WSC, 1C-178 4/16/2003 12.0 IPERF Alternating slotted/blank pipe - 30' joints w/8 holes/ft .25"x2.5"/slotted joint 1C-178, 5/15/2023 11:38:22 AM Vertical schematic (actual) B-SAND Slotted Liner; 7,401.5- 13,243.8 IPERF; 7,704.0-13,179.0 D-SAND Slotted Liner; 7,356.2- 13,579.8 SURFACE; 28.3-7,733.3 IPERF; 7,413.0-13,493.0 PACKER; 7,086.2 PACKER; 7,027.0 TIEBACK(2015) - Polycore Ultratube lining; 26.4-7,007.0 SLEEVE; 6,487.2 POGLM; 6,487.0 SLIP STOP; 6,485.0 CONDUCTOR; 34.3-110.0 HANGER; 26.9 KUP PROD 1C-178 ... WELLNAME WELLBORE1C-178 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1C-178L1 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: PULL C-LOCK & POGLM, SET C-LOCK, JET PUMP & ROCKSCREEN & 1/2" SLIP STOP on LOCK 1C-178L1 8/21/2017 pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 4/27/2009 ninam NOTE: WORKOVER INCLUDED SETTING 5.5" INNER CSG STRING & NEW TUBING COMPLETION 4/27/2009 pproven NOTE: Surface CSG Patch, OAL=6'11", Mtls: 0.500 wall X65 , 0.365 wt (see 2/20/09 WSR) 2/20/2008 lmosbor NOTE: MULTILATERAL WELL - 1C-178 ( B/C-SANDS), 1C-178L1 (D-SAND) 4/29/2003 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread D-SAND Slotted Liner 4 1/2 3.96 7,356.2 13,579.8 3,767.7 12.60 L-80 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) 7,373.0 3,706.3 76.74 SWIVEL 4.500 TORQUE-THRU SWIVEL 3.990 13,557.6 3,766.1 85.96 XO 4.5x3.5 4.500 3.500 13,559.1 3,766.2 85.94 BENT JT 3.500 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,413.0 13,493.0 3,714.9 3,762.0 WS D, 1C-178L1 4/16/2003 12.0 IPERF Alternating slotted/blank pipe - 30' joints w/8 holes/ft .25"x2.5"/slotted joint 1C-178L1, 5/15/2023 11:38:22 AM Vertical schematic (actual) D-SAND Slotted Liner; 7,356.2- 13,579.8 IPERF; 7,413.0-13,493.0 B-SAND Slotted Liner; 7,401.5- 13,243.8 SURFACE; 28.3-7,733.3 IPERF; 7,704.0-13,179.0 PACKER; 7,086.2 PACKER; 7,027.0 TIEBACK(2015) - Polycore Ultratube lining; 26.4-7,007.0 SLEEVE; 6,487.2 POGLM; 6,487.0 SLIP STOP; 6,485.0 CONDUCTOR; 34.3-110.0 HANGER; 26.9 KUP PROD KB-Grd (ft) 30.00 RR Date 5/27/2003 Other Elev 1C-178L1 ... TD Act Btm (ftKB) 13,626.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292314460 Wellbore Status PROD Max Angle & MD Incl (°) 95.49 MD (ftKB) 7,665.91 WELLNAME WELLBORE1C-178 Annotation Last WO: End Date 5/25/2015 H2S (ppm) 40 Date 8/12/2016 Comment SSSV: NIPPLE ! " # " $ % & ' ()* + ,- . / 0*! 1-22/02)) (3342 5 .+ 6& !7 8"!! 3& 6& 92942572 :6 7 " . + /)982 !: /)8 !: , + /)982 5295;5280 /)8 /024;/)094 < :1( =5)52>?#/)53? @ :1( =/)508?#/)823? 6 A)) 7 9#5:8B &#82 03//? /45>? ( @6 .) 7 9 CA . * 6 7 !: / C 4" ( + . " ,- . + & . 0" ( % "+& , + % %*!' D &D% .!!: ,- ( !( A " ( , , (= 325#904#/54 5)295? 5)280? !: /)024? /)094? !: , , 5*. . .( >:9 5)225 /)9>> (#. D /)552 /)433 /)82 A A! & 50 5)524 038? 48>9? > 6C 9294252)9425)E9498/7 />5 F( :" ( 2 !: '( !: 0 54:8 4:9 F D#58 ,&F &F*&!+%!, @*!<<**! 92/#2> 42#293#9/>>#22#22 4 + !9 ! ! >" 1"( +&940>3)+&22940/8 93 + . *G + /29903 % #< /50 #1 ( 2/ 0/> /95 "*!'"% 90 " #1 ! 2 5)5// 1( ( 1(#/( !@ 03 " 2#>2> /:9292 " /2. By Samantha Carlisle at 9:44 am, Jul 14, 2021 Digitally signed by Toon Changklungdee DN: C=US, OU=Production Engineering, O=ConocoPhillips Alaska, CN=Toon Changklungdee, E=toon.changklungdee@conocophillips.com Reason: I have reviewed this document Location: ATO1314 Date: 2021.07.13 16:55:30-08'00' Toon Changklungdee DSR-7/14/21 RBDMS HEW 7/14/2021 VTL 8/4/21 SFD 7/16/2021 !"# !" $""%%$ &""$ '"&'#( $" &$ "$$" $ &"" " $) "&"!* $""+ "&" # & $ )' # & )'$',& -% ( .,"# & ) ""$" " % /0123450677 122689:;3/860<:45 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:1C-178 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set Jet Pump 1C-178 jleonar3 Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 34.3 Set Depth (ftKB) 110.0 Set Depth (TVD) … 110.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 28.3 Set Depth (ftKB) 7,733.3 Set Depth (TVD) … 3,770.4 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Casing Description TIEBACK(2015) - Polycore Ultratube lining OD (in) 5 1/2 ID (in) 4.30 Top (ftKB) 26.4 Set Depth (ftKB) 7,007.0 Set Depth (TVD) … 3,598.8 Wt/Len (l… 17.00 Grade L-80 Top Thread BTC Casing Description B-SAND Slotted Liner OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 7,401.5 Set Depth (ftKB) 13,243.8 Set Depth (TVD) … 3,809.9 Wt/Len (l… 12.60 Grade L-80 Top Thread SLHT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,401.5 3,713.7 75.41 SLEEVE BAKER HR SLEEVE w/ EXTENSION 5.010 7,414.2 3,716.9 75.65 BUSHING BAKER BUSHING 4.950 7,415.9 3,717.3 75.69 NIPPLE BAKER RS NIPPLE 4.875 7,418.7 3,718.0 75.74 HANGER BAKER FLEX LOCK HYDRUALIC ROTATING LINER HANGER 4.830 7,428.1 3,720.3 75.92 XO Reducing CROSSOVER 5.5" x 4.5" 3.940 7,491.8 3,735.1 77.16 LOCATOR BAKER LOCATOR SUB 3.510 13,209.5 3,809.4 89.35 XO Reducing CROSSOVER 4.5" x 4" 4.000 Tubing Strings Tubing Description TUBING - 2015 WO String Ma… 2 7/8 ID (in) 2.44 Top (ftKB) 26.9 Set Depth (ft… 6,933.0 Set Depth (TVD) (… 3,574.2 Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 26.8 26.8 0.00 HANGER HANGER 5.688 6,487.2 3,420.9 69.65 SLEEVE BAKER CMU SLIDING SLEEVE (OPENED=12/20/2019) (CLOSED= 6/17/2021) 2.250 6,892.6 3,560.8 70.55 GAUGE SLB SPECIAL CLEARANCE GAUGE CARRIER MANDREL 2.398 6,913.6 3,567.8 70.64 LOCATOR BAKER LOCATOR 2.400 6,914.7 3,568.2 70.65 SEAL ASSY BAKER 80-32 SEAL ASSEMBLY 2.410 Tubing Description TUBING - 2015 - STACK PACKER String Ma… 5.03 ID (in) 4.00 Top (ftKB) 6,978.5 Set Depth (ft… 7,068.7 Set Depth (TVD) (… 3,619.3 Wt (lb/ft) Grade L-80 Top Connection BTC Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,978.5 3,589.3 70.59 SETTING SLEEVE BAKER HRDE LINER SETTING SLEEVE 5.750 6,993.7 3,594.4 70.54 SBE BAKER 80-40 SEAL BORE RECEPTACLE 4.000 7,027.0 3,605.5 70.45 PACKER BAKER PREMIER PACKER 3.880 7,050.7 3,613.4 70.73 LOCATOR BAKER LOCATOR 3.870 7,051.3 3,613.6 70.73 SEAL ASSY BAKER GBH-22 LOCATING SEAL ASSEMBLY 3.870 Tubing Description TUBING - Original String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 7,055.8 Set Depth (ft… 7,335.6 Set Depth (TVD) (… 3,696.9 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,055.8 3,615.1 70.79 PBR BAKER PBR - SBR & SEAL ASSY RUN ON 4/22/2009 WORKOVER 5.5" PRODUCTION CSG STABBED INTO PBR 3.875 7,086.2 3,625.0 71.14 PACKER BAKER S-3 PACKER 3.875 7,091.8 3,626.8 71.20 XO Enlarging CROSSOVER 4.5" x 5" 4.500 7,098.3 3,628.9 71.28 XO Reducing CROSSOVER 5" x 4.5" 4.500 7,108.6 3,632.2 71.40 NIPPLE CAMCO 'DB' NIPPLE w/ NO GO PROFILE 3.750 7,334.6 3,696.6 74.99 WLEG WIRELINE ENTRY GUIDE 3.960 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 6,487.0 3,420.8 69.65 JET PUMP 2.25" NO GO W/ 2' RC JET PUMP AND SPARTEK GAUGE 6/16/2021 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,704.0 13,179.0 3,767.7 3,809.2 WS B, WS B, WSC, 1C-178 4/16/2003 12.0 IPERF Alternating slotted/blank pipe - 30' joints w/8 holes/ft .25"x2.5"/slotted joint Notes: General & Safety End Date Annotation 1/12/2018 NOTE: though all straigh-run joints and pups 1/11/2018 NOTE: 5.5" Tie-Back Liner has a Polycore Ultratube plastic liner installed- 4/27/2009 NOTE: View Schematic w/ Alaska Schematic9.0 4/27/2009 NOTE: WORKOVER INCLUDED SETTING 5.5" INNER CSG STRING & NEW TUBING COMPLETION 2/20/2008 NOTE: Surface CSG Patch, OAL=6'11", Mtls: 0.500 wall X65 , 0.365 wt (see 2/20/09 WSR) 4/29/2003 NOTE: MULTILATERAL WELL - 1C-178 ( B/C-SANDS), 1C-178L1 (D-SAND) 1C-178, 6/30/2021 4:10:07 PM Vertical schematic (actual) B-SAND Slotted Liner; 7,401.5- 13,243.8 IPERF; 7,704.0-13,179.0 D-SAND Slotted Liner; 7,356.2- 13,579.8 SURFACE; 28.3-7,733.3 IPERF; 7,413.0-13,493.0 PACKER; 7,086.2 PACKER; 7,027.0 TIEBACK(2015) - Polycore Ultratube lining; 26.4-7,007.0 SLEEVE; 6,487.2 CONDUCTOR; 34.3-110.0 HANGER; 26.9 KUP PROD KB-Grd (ft) 30.00 Rig Release Date 5/27/2003 1C-178 ... TD Act Btm (ftKB) 13,280.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292314400 Wellbore Status PROD Max Angle & MD Incl (°) 92.00 MD (ftKB) 11,208.01 WELLNAME WELLBORE1C-178 Annotation Last WO: End Date 5/25/2015 H2S (ppm) 40 Date 8/12/2016 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:1C-178L1 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: PULL C-LOCK & POGLM, SET C-LOCK, JET PUMP & ROCKSCREEN & 1/2" SLIP STOP on LOCK 8/21/2017 1C-178L1 pproven Casing Strings Casing Description D-SAND Slotted Liner OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 7,356.2 Set Depth (ftKB) 13,579.8 Set Depth (TVD) … 3,767.7 Wt/Len (l… 12.60 Grade L-80 Top Thread Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,356.2 3,702.2 75.10 HANGER FLANGED HOOK HANGER 5.630 7,373.0 3,706.3 76.74 SWIVEL TORQUE-THRU SWIVEL 3.990 13,557.6 3,766.1 85.96 XO 4.5x3.5 3.500 13,559.1 3,766.2 85.94 BENT JT 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,413.0 13,493.0 3,714.9 3,762.0 WS D, 1C- 178L1 4/16/2003 12.0 IPERF Alternating slotted/blank pipe - 30' joints w/8 holes/ft .25"x2.5"/slotted joint Notes: General & Safety End Date Annotation 4/27/2009 NOTE: View Schematic w/ Alaska Schematic9.0 4/27/2009 NOTE: WORKOVER INCLUDED SETTING 5.5" INNER CSG STRING & NEW TUBING COMPLETION 2/20/2008 NOTE: Surface CSG Patch, OAL=6'11", Mtls: 0.500 wall X65 , 0.365 wt (see 2/20/09 WSR) 4/29/2003 NOTE: MULTILATERAL WELL - 1C-178 ( B/C-SANDS), 1C-178L1 (D-SAND) 1C-178L1, 6/30/2021 4:10:08 PM Vertical schematic (actual) D-SAND Slotted Liner; 7,356.2- 13,579.8 IPERF; 7,413.0-13,493.0 B-SAND Slotted Liner; 7,401.5- 13,243.8 SURFACE; 28.3-7,733.3 IPERF; 7,704.0-13,179.0 PACKER; 7,086.2 PACKER; 7,027.0 TIEBACK(2015) - Polycore Ultratube lining; 26.4-7,007.0 SLEEVE; 6,487.2 CONDUCTOR; 34.3-110.0 HANGER; 26.9 KUP PROD KB-Grd (ft) 30.00 Rig Release Date 5/27/2003 1C-178L1 ... TD Act Btm (ftKB) 13,626.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292314460 Wellbore Status PROD Max Angle & MD Incl (°) 95.49 MD (ftKB) 7,665.91 WELLNAME WELLBORE1C-178 Annotation Last WO: End Date 5/25/2015 H2S (ppm) 40 Date 8/12/2016 Comment SSSV: NIPPLE 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: _Convert SPJP to Gas Lift ConocoPhillips Alaska, Inc.Development Exploratory 3. Address:Stratigraphic Service 6. API Number: P.O. Box 100360, Anchorage, Alaska 99510 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 13,280 feet N/A feet true vertical 3,811 feet N/A feet Effective Depth measured 13,246 feet 7027; 7086 ft true vertical 3,810 feet 3605; 3,625 ft Perforation depth Measured depth 7,704' - 13,179'feet True Vertical depth 3,768' - 3,809'feet Tubing (size, grade, measured and true vertical depth)4 1/2 L-80 7,336' 3,697' 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 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Stephanie Thomson Contact Name:Stephanie Thomson Authorized Title:Staff Petroleum Engineer Contact Email:stephanie.thomson@cop.com Contact Phone:907-263-4536 Burst 7,027' 7,086' N/A 3,605' 3,625' N/A Collapse N/A 4 1/2 7,007 13,244 Senior Engineer:Senior Res. Engineer: N/A 110 3,770 3,599 3,810 N/A Casing Structural N/A 16 7 5/8 5 1/2 Kuparuk River Field / West Sak Oil Pool Conductor Surface Production Authorized Signature with date: Authorized Name: Liner Length N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-186 262 Size 76 7,705 6,976 5,817 N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 326 Gas-Mcf measuredPlugs Junk measured N/A KRU 1C-178 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-041 50-029-23144-01-00 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: 181 Representative Daily Average Production or Injection Data 263282 Casing Pressure Tubing Pressure ADL 25649, ADL 0025638 208 Oil-Bbl measured true vertical Packer 2405 803 WINJ WAG 31 Water-Bbl MD N/A 110 7,733 Baker Premier Packer Baker S-3 Packer No SSSV 65 TVD t Fra O 203 6. A G L PG , R ft Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Digitally signed by Stephanie Thomson DN: C=US, OU=ConocoPhillips, O=GKA Base Production & Optimization, CN=Stephanie Thomson, E=stephanie.thomson@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-09-09 16:09:48 Foxit PhantomPDF Version: 10.0.0 Stephanie Thomson By Samantha Carlisle at 9:35 am, Sep 10, 2020 SFD 9/10/2020VTL 10/01/20 DSR-9/15/2020 50-029-23144-00-00 RBDMS HEW 9/10/2020 SFD 9/10/2020 1C-178 Well Events Summary Date Event Summary 4/25/2020 1C-178 SI & Freeze Protected for planned proration 7/1/2020 1C-178 brought online following planned proration and curtailment. 7/23/2020 1C-178 SI & Freeze Protected for planned CPF1 Turnaround 7/26/2020 1C-178 brought online 8/29/2020 1C-178 shut-in for well work to convert from jet pump to gas lift. Flushed IA w/ 65 bbls of diesel and loaded tubing with diesel. Pulled slip stop and jet pump. Set lock with POGLM with 5/16” orifice. Stacked gas on tubing with no change in IA pressure, indicating POGLM set. Set slip stop. 8/30/2020 Installed blind to water injection header, and removed blind to lift gas header. Completed instrumentation and automation checks. 1C-178 brought online on gas lift. 8/31/2020 1C-178 well test completed. Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:1C-178 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pulled Jet Pump & Set Poglm 8/29/2020 1C-178 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 34.3 Set Depth (ftKB) 110.0 Set Depth (TVD) … 110.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 28.3 Set Depth (ftKB) 7,733.3 Set Depth (TVD) … 3,770.4 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Casing Description TIEBACK(2015) - Polycore Ultratube lining OD (in) 5 1/2 ID (in) 4.30 Top (ftKB) 26.4 Set Depth (ftKB) 7,007.0 Set Depth (TVD) … 3,598.8 Wt/Len (l… 17.00 Grade L-80 Top Thread BTC Casing Description B-SAND Slotted Liner OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 7,401.5 Set Depth (ftKB) 13,243.8 Set Depth (TVD) … 3,809.9 Wt/Len (l… 12.60 Grade L-80 Top Thread SLHT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,401.5 3,713.7 75.41 SLEEVE BAKER HR SLEEVE w/ EXTENSION 5.010 7,414.2 3,716.9 75.65 BUSHING BAKER BUSHING 4.950 7,415.9 3,717.3 75.69 NIPPLE BAKER RS NIPPLE 4.875 7,418.7 3,718.0 75.74 HANGER BAKER FLEX LOCK HYDRUALIC ROTATING LINER HANGER 4.830 7,428.1 3,720.3 75.92 XO Reducing CROSSOVER 5.5" x 4.5" 3.940 7,491.8 3,735.1 77.16 LOCATOR BAKER LOCATOR SUB 3.510 13,209.5 3,809.4 89.35 XO Reducing CROSSOVER 4.5" x 4" 4.000 Tubing Strings Tubing Description TUBING - 2015 WO String Ma… 2 7/8 ID (in) 2.44 Top (ftKB) 26.9 Set Depth (ft… 6,933.0 Set Depth (TVD) (… 3,574.2 Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 26.8 26.8 0.00 HANGER HANGER 5.688 6,487.2 3,420.9 69.65 SLEEVE BAKER CMU SLIDING SLEEVE (OPENED=12/20/2019) 2.250 6,892.6 3,560.8 70.55 GAUGE SLB SPECIAL CLEARANCE GAUGE CARRIER MANDREL 2.398 6,913.6 3,567.8 70.64 LOCATOR BAKER LOCATOR 2.400 6,914.7 3,568.2 70.65 SEAL ASSY BAKER 80-32 SEAL ASSEMBLY 2.410 Tubing Description TUBING - 2015 - STACK PACKER String Ma… 5.03 ID (in) 4.00 Top (ftKB) 6,978.5 Set Depth (ft… 7,068.7 Set Depth (TVD) (… 3,619.3 Wt (lb/ft) Grade L-80 Top Connection BTC Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,978.5 3,589.3 70.59 SETTING SLEEVE BAKER HRDE LINER SETTING SLEEVE 5.750 6,993.7 3,594.4 70.54 SBE BAKER 80-40 SEAL BORE RECEPTACLE 4.000 7,027.0 3,605.5 70.45 PACKER BAKER PREMIER PACKER 3.880 7,050.7 3,613.4 70.73 LOCATOR BAKER LOCATOR 3.870 7,051.3 3,613.6 70.73 SEAL ASSY BAKER GBH-22 LOCATING SEAL ASSEMBLY 3.870 Tubing Description TUBING - Original String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 7,055.8 Set Depth (ft… 7,335.6 Set Depth (TVD) (… 3,696.9 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,055.8 3,615.1 70.79 PBR BAKER PBR - SBR & SEAL ASSY RUN ON 4/22/2009 WORKOVER 5.5" PRODUCTION CSG STABBED INTO PBR 3.875 7,086.2 3,625.0 71.14 PACKER BAKER S-3 PACKER 3.875 7,091.8 3,626.8 71.20 XO Enlarging CROSSOVER 4.5" x 5" 4.500 7,098.3 3,628.9 71.28 XO Reducing CROSSOVER 5" x 4.5" 4.500 7,108.6 3,632.2 71.40 NIPPLE CAMCO 'DB' NIPPLE w/ NO GO PROFILE 3.750 7,334.6 3,696.6 74.99 WLEG WIRELINE ENTRY GUIDE 3.960 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 6,486.0 3,420.5 69.65 2.25" Slip Stop 2.5" Slip Stop (19.2" OAL) 8/29/2020 6,487.2 3,420.9 69.65 2.25"C-Lock (No Keys) & Polgm 5/16" OV 2.25" C-Lock (No Keys) & POGLM (5/16'' OV) W/ 6 AVA SEALS ON 2.25'' C-LOCK (52" OAL) 8/29/2020 0.313 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,704.0 13,179.0 3,767.7 3,809.2 WS B, WS B, WSC, 1C-178 4/16/2003 12.0 IPERF Alternating slotted/blank pipe - 30' joints w/8 holes/ft .25"x2.5"/slotted joint Notes: General & Safety End Date Annotation 1/12/2018 NOTE: though all straigh-run joints and pups 1/11/2018 NOTE: 5.5" Tie-Back Liner has a Polycore Ultratube plastic liner installed- 4/27/2009 NOTE: View Schematic w/ Alaska Schematic9.0 4/27/2009 NOTE: WORKOVER INCLUDED SETTING 5.5" INNER CSG STRING & NEW TUBING COMPLETION 2/20/2008 NOTE: Surface CSG Patch, OAL=6'11", Mtls: 0.500 wall X65 , 0.365 wt (see 2/20/09 WSR) 4/29/2003 NOTE: MULTILATERAL WELL - 1C-178 ( B/C-SANDS), 1C-178L1 (D-SAND) 1C-178, 8/29/2020 6:55:34 PM Vertical schematic (actual) B-SAND Slotted Liner; 7,401.5- 13,243.8 IPERF; 7,704.0-13,179.0 D-SAND Slotted Liner; 7,356.2- 13,579.8 SURFACE; 28.3-7,733.3 IPERF; 7,413.0-13,493.0 WLEG; 7,334.6 NIPPLE; 7,108.6 PACKER; 7,086.2 PBR; 7,055.9 SEAL ASSY; 7,051.3 LOCATOR; 7,050.6 PACKER; 7,027.0 TIEBACK(2015) - Polycore Ultratube lining; 26.4-7,007.0 SBE; 6,993.7 SETTING SLEEVE; 6,978.5 SEAL ASSY; 6,914.7 LOCATOR; 6,913.6 XO Threads; 6,898.2 GAUGE; 6,892.6 XO Threads; 6,882.7 SLEEVE; 6,487.2 2.25"C-Lock (No Keys) & Polgm 5/16" OV; 6,487.2 2.25" Slip Stop; 6,486.0 CONDUCTOR; 34.3-110.0 HANGER; 26.9 KUP PROD KB-Grd (ft) 30.00 Rig Release Date 5/27/2003 1C-178 ... TD Act Btm (ftKB) 13,280.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292314400 Wellbore Status PROD Max Angle & MD Incl (°) 92.00 MD (ftKB) 11,208.01 WELLNAME WELLBORE1C-178 Annotation Last WO: End Date 5/25/2015 H2S (ppm) 40 Date 8/12/2016 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: Convert from SPJP to Gas Lift 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A KRU 1C-178 Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13,280 N/A Casing Collapse Conductor Surface Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Baker Premier Packer / No SSSV 7027 MD / 3605 TVD. No SSSV. 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Stephanie Thomson Contact Name:Stephanie Thomson Staff Petroleum Engineer Contact Email:stephanie.thomson@cop.com Contact Phone: 907-263-4536 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): 3,768-3,809 Perforation Depth TVD (ft):Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 25649, ADL 25638 203-041 P.O. Box 100360, Anchorage, Alaska 99510 50-029-23144-00 ConocoPhillips Alaska, Inc. Length Size 3,811 13,246 3,810 1,019 L-80 TVD Burst 7,336 MD 110 3,770 110 7,733 16 7 5/8 76 7,705 Perforation Depth MD (ft): 7,704-13,179 6,976 4 1/2 3,5995 1/2 N/A Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 5/1/2020 13,2445,817 4.5" 3,810 7,007 m n P 66 t s LiLiLiiLiLiLiLiLiLiLiLLLLLLLLfft Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Digitally signed by stephanie.thomson@conocophillips.com DN: CN=stephanie.thomson@conocophillips.com Reason: I am approving this document with my legally binding signature Location: your signing location here Date: 2020-04-30 15:41:57 Foxit PhantomPDF Version: 9.7.0 stephanie.thomson@ conocophillips.com By Jody Colombie at 4:14 pm, Apr 30, 2020 320-186 DLB 04/30/2020 DSR-4/30/2020 -00 DLB VTL 5/4/20 X 10-404 X C 5/4/2020 dts 4/4/2020 JLC 5/4/2020 Stephanie Thomson Staff Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501 Phone: (907) 263-4536 April 30, 2020 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 Dear Commissioner, Enclosed please find the 10-403 Application for Sundry Approval for the ConocoPhillips Alaska Inc well KRU 1C- 178 (PTD 203-041). The request is for approval to convert this producer from a surface powered jet pump (SPJP) to a gas lifted well. 1C-178 has a possible matrix bypass event (MBE) from 1C-174, and converting gas lift will allow better monitoring of changes in water cut to diagnose the MBE. The down hole conversion work includes pulling the jet pump, setting a pack-off gas lift mandrel with orifice valve in the sliding sleeve, performing the appropriate integrity testing. If you have any questions regarding this matter, please contact me via the details below. Sincerely, Stephanie Thomson Staff Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501 Phone: (907) 263-4536 Attachments: Sundry Application Proposed Steps Well Schematic Well Events Summary Digitally signed by stephanie.thomson@conocophillips.com DN: CN=stephanie.thomson@conocophillips.com Reason: I am approving this document with my legally binding signature Location: your signing location here Date: 2020-04-30 15:45:18 Foxit PhantomPDF Version: 9.7.0 stephanie.thomson@c onocophillips.com KRU 1C-178 DESCRIPTION SUMMARY OF PROPOSAL Jet Pump to Gas Lift Conversion for KRU 1C-178 CPAI proposes the following plan: 1. Install blind to water injection header and remove blind to lift gas header to connect individual well to lift gas. 2. Pull jet pump from sliding sleeve. 3. Flush the inner annulus with diesel to remove all produced water. 4. Set a pack-off gas lift mandrel with orifice valve in the CMU. Perform drawdown test. 5. Bring the well online on gas lift. 6. Submit 10-404 following conversion. Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:1C-178 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pulled Jet Pump, MITIA, Opend CMU, Installed Jet Pump 12/20/2019 1C-178 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 34.3 Set Depth (ftKB) 110.0 Set Depth (TVD) … 110.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 28.3 Set Depth (ftKB) 7,733.3 Set Depth (TVD) … 3,770.4 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Casing Description TIEBACK(2015) - Polycore Ultratube lining OD (in) 5 1/2 ID (in) 4.30 Top (ftKB) 26.4 Set Depth (ftKB) 7,007.0 Set Depth (TVD) … 3,598.8 Wt/Len (l… 17.00 Grade L-80 Top Thread BTC Casing Description B-SAND Slotted Liner OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 7,401.5 Set Depth (ftKB) 13,243.8 Set Depth (TVD) … 3,809.9 Wt/Len (l… 12.60 Grade L-80 Top Thread SLHT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,401.5 3,713.7 75.41 SLEEVE BAKER HR SLEEVE w/ EXTENSION 5.010 7,414.2 3,716.9 75.65 BUSHING BAKER BUSHING 4.950 7,415.9 3,717.3 75.69 NIPPLE BAKER RS NIPPLE 4.875 7,418.7 3,718.0 75.74 HANGER BAKER FLEX LOCK HYDRUALIC ROTATING LINER HANGER 4.830 7,428.1 3,720.3 75.92 XO Reducing CROSSOVER 5.5" x 4.5" 3.940 7,491.8 3,735.1 77.16 LOCATOR BAKER LOCATOR SUB 3.510 13,209.5 3,809.4 89.35 XO Reducing CROSSOVER 4.5" x 4" 4.000 Tubing Strings Tubing Description TUBING - 2015 WO String Ma… 2 7/8 ID (in) 2.44 Top (ftKB) 26.9 Set Depth (ft… 6,933.0 Set Depth (TVD) (… 3,574.2 Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 26.8 26.8 0.00 HANGER HANGER 5.688 6,487.2 3,420.9 69.65 SLEEVE BAKER CMU SLIDING SLEEVE (OPENED=12/20/2019) 2.250 6,892.6 3,560.8 70.55 GAUGE SLB SPECIAL CLEARANCE GAUGE CARRIER MANDREL 2.398 6,913.6 3,567.8 70.64 LOCATOR BAKER LOCATOR 2.400 6,914.7 3,568.2 70.65 SEAL ASSY BAKER 80-32 SEAL ASSEMBLY 2.410 Tubing Description TUBING - 2015 - STACK PACKER String Ma… 5.03 ID (in) 4.00 Top (ftKB) 6,978.5 Set Depth (ft… 7,068.7 Set Depth (TVD) (… 3,619.3 Wt (lb/ft) Grade L-80 Top Connection BTC Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,978.5 3,589.3 70.59 SETTING SLEEVE BAKER HRDE LINER SETTING SLEEVE 5.750 6,993.7 3,594.4 70.54 SBE BAKER 80-40 SEAL BORE RECEPTACLE 4.000 7,027.0 3,605.5 70.45 PACKER BAKER PREMIER PACKER 3.880 7,050.7 3,613.4 70.73 LOCATOR BAKER LOCATOR 3.870 7,051.3 3,613.6 70.73 SEAL ASSY BAKER GBH-22 LOCATING SEAL ASSEMBLY 3.870 Tubing Description TUBING - Original String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 7,055.8 Set Depth (ft… 7,335.6 Set Depth (TVD) (… 3,696.9 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,055.8 3,615.1 70.79 PBR BAKER PBR - SBR & SEAL ASSY RUN ON 4/22/2009 WORKOVER 5.5" PRODUCTION CSG STABBED INTO PBR 3.875 7,086.2 3,625.0 71.14 PACKER BAKER S-3 PACKER 3.875 7,091.8 3,626.8 71.20 XO Enlarging CROSSOVER 4.5" x 5" 4.500 7,098.3 3,628.9 71.28 XO Reducing CROSSOVER 5" x 4.5" 4.500 7,108.6 3,632.2 71.40 NIPPLE CAMCO 'DB' NIPPLE w/ NO GO PROFILE 3.750 7,334.6 3,696.6 74.99 WLEG WIRELINE ENTRY GUIDE 3.960 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 6,485.0 3,420.2 69.65 Slip Stop 2.5" SLIP STOP 12/20/201 9 6,487.0 3,420.8 69.65 Jet Pump 2.25" C-LOCK (NO KEYS) W/ 2" RC JET PUMP (9B RATIO ser# CP 0008) W/ AVA STINGER, FLOW THRU SUB, AND GAUGE. 119" OAL. 12/20/201 9 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,704.0 13,179.0 3,767.7 3,809.2 WS B, WS B, WSC, 1C-178 4/16/2003 12.0 IPERF Alternating slotted/blank pipe - 30' joints w/8 holes/ft .25"x2.5"/slotted joint Notes: General & Safety End Date Annotation 1/12/2018 NOTE: though all straigh-run joints and pups 1/11/2018 NOTE: 5.5" Tie-Back Liner has a Polycore Ultratube plastic liner installed- 4/27/2009 NOTE: View Schematic w/ Alaska Schematic9.0 1C-178, 12/21/2019 10:59:32 AM Vertical schematic (actual) B-SAND Slotted Liner; 7,401.5- 13,243.8 IPERF; 7,704.0-13,179.0 D-SAND Slotted Liner; 7,356.2- 13,579.8 SURFACE; 28.3-7,733.3 IPERF; 7,413.0-13,493.0 WLEG; 7,334.6 NIPPLE; 7,108.6 PACKER; 7,086.2 PBR; 7,055.9 SEAL ASSY; 7,051.3 LOCATOR; 7,050.6 PACKER; 7,027.0 TIEBACK(2015) - Polycore Ultratube lining; 26.4-7,007.0 SBE; 6,993.7 SETTING SLEEVE; 6,978.5 SEAL ASSY; 6,914.7 LOCATOR; 6,913.6 XO Threads; 6,898.2 GAUGE; 6,892.6 XO Threads; 6,882.7 Jet Pump; 6,487.0 SLEEVE; 6,487.2 Slip Stop; 6,485.0 CONDUCTOR; 34.3-110.0 HANGER; 26.9 KUP PROD KB-Grd (ft) 30.00 Rig Release Date 5/27/2003 1C-178 ... TD Act Btm (ftKB) 13,280.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292314400 Wellbore Status PROD Max Angle & MD Incl (°) 92.00 MD (ftKB) 11,208.01 WELLNAME WELLBORE1C-178 Annotation Last WO: End Date 5/25/2015 H2S (ppm) 40 Date 8/12/2016 Comment SSSV: NIPPLE 1C-178 Well Events Summary Date Event Summary 4/25/2020 1C-178 SI & Freeze Protected STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: RPPG MBE TREATMENT[] 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development Q Stratigraphic❑ Exploratory ❑ Service ❑ 203-041 3. Address: P. O. BOX 100360, Anchorage, 6. API Number: Alaska 99510 50-029-23144-00-00 7. Property Designation (Lease Number): a. Well Name and Number: ADL 25649, ADL 25638 KRU 1 C-178 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 13,280 feet Plugs measured None feet true vertical 3,811 feet Junk measured None feet Effective Depth measured 13,246 feet Packer measured 7027, 7086 feet true vertical 3,810 feet true vertical 3605, 3625 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 feet 16 110' MD 110' TVD SURFACE 7,70feet 7 186,985 TVD RECEIVELJ ROD INNER CS feet 5 5/2 " 7,007' MD 3599' TVD LOTTED LINER 5,842 feet 4 1/2 " 13,244' MD 3810' TVD OCT 17 2019 Perforation depth: Measured depth: 7704-13179 feet True Vertical depth: 3768-3809 feet AOGCC U Tubing (size, grade, measured and true vertical depth) 4,511 L-80 7,335' MD 3,697' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER PREMIER PACKER 7,027' MD 3,605' TVD PACKER - BAKER S-3 PACKER 7,086' MD 3,625' TVD SSSV -NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): NIA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: I SHUT-IN Subsequent to operation: I SHUT-IN 14. Attachments (required per20MC 25.D70, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations 21 Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Ej Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-362 Contact Name: John Peirce Authorized Name: John Peirce Contact Email: John.W.Peirce@cop.com Authorized Title: Sr. Wells Engineer *�Contact Authorized Signature: Phone: (907) 265-6471 Date: I e3 (I (o /-f,3 Form 10-404 devised 4/2017 ✓7Y -/0/Z Z//7Submit Original Only irG a//4 RRI]MS 401nrT 1) 4 1 C-178 OFFSET PRODUCER FOR 1 C-174 RPPG MBE TREATMENT DTTM JOBTYP SUMMARYOPS START 9/10/19 MISC. SET BAKER 2.50" IBP AT 8305' CTMD, RIH WITH DUMMY PERF GUN CAPACITY DRIFT (3.62" ODX10') DOWN TO 8250' CTMD, F/P TBG TO 5000' CTMD, SUSTAINMENT JOB IN PROGRESS. 9/19/19 MISC. RIH WITH 3.38" 6 SPF 3412 PF HMX 14.2 GM, .64" ENT HOLE 4.5" CAPACITY PENETRATION GUN DOWN TO IBP AT 8305', PU TO 8220' CTMD, DROP SUSTAINMENT .5' BALL, FIRED 5' GUN. OOH BALL RECOVERED, PERFORM WEEKLY BOP TEST. WELL READY FOR RPPG JOB. 9/26/19 MISC. PUMPED FULLBORE RPPG TO TARGET MBE (ESTIMATED 8200'MD): CAPACITY IBP IN WELL AT 8305' CTMD. PUMPED 715 -BBL TREATMENT SUSTAINMENT INCLUDING 135 -BBL 2% KCI PRE -FLUSH, FOLLOWED BY 457 -BBL SLURRY CONTAINING KCI PLUS 7800# RPPG PRODUCT. DISPLACED SLURRY TO MBE WITH 92.5 -BBL KCI AND 41 -BBL DIESEL FP. GAINED APPROXIMATELY 950 -PSI NET PRESSURE DURING TREATMENT PUMPING 1.5-4.0 BPM. KUP PROD WELLNAME 1C-178 WELLBORE 1C-178 Ca�owe6wcoP Well Attributes Max Angle & MD TO Phi�6ps Wellh regpgUW WallCoreB lus l MOI%HBI�gd BMI�flKB Alaska. Inc. 9LIWFFTae<K snnomwnnnn 1C-1Ta. lonsuc118e:st.AM Last Tag Var4a rdvnc lectu9) atl Annotator Degathr ) 1 End Data Wellbore LBy Last Tag: 1G-08 Imodborbor Last Rev Reason ........................ HARDER; Sea .. Annottlion I End Data wenhore mar MCtl ev Rev ReasonReplace Jet Pump I 1/62019 1C-178 Ifergusin Casing Strings Casing pes[riptlon CONDUCTOR Do (in) 16 10 (in) 15.06 Top(AnB) earn. lM1 MKS) 34.3 110.0 SM pepIM1 (NO)... WYLen II... Gratle Top TM1reatl 110.0 62.50 H40 WELDED Oaring Oeecrlptlon SURFACE _Op nig IO lin) 6.91 T'Ptaa) Set Dep.. DUE) 8.3 7333 17 Set depth lTVe)... YI %... Gard. Top TF.d 3,770.4 BTCM 1� TIEBJeornACK(20151� Polycore Ultmtube lining 51%2) 4.30) ISO 7,OOJ.Oth MKe) 26A 7,007.0 Set 3,5988M1 RVDA��wg O"IL-L-BOe IT BTC M1reaa CONOVCTOK: 3931100 Loring Deecrlptbn B -SAND SIo%etl Liner Op (In) 4112 ID lin 3.96 Top MKa) SM Depth gi ],401.5 13,2438 80 depth Trind.. WVLen I1... Gratle Tap TM1reatl 3,809.9 1260 L-80 SLHT SUP STOP: Silted Liner Details Nominal ID Top II1KB) Top (ND)(%KB) Top Incl l°) IRm pea Com (In) SLEEVE; S.a813 JETPUMP; &ae]p 7,4015 3,]13] ]541 SLEEVE BAKER HR SLEEVE w/EXTENSION 5.010 7,4142 3,716.9 7565 BUSHING BAKER BUSHING 4,950 Threm7,415.9 xoS; B,W27 .UGE UG', ,M2 xD TNW;fi,WBg 3,]1].3 75,69 NIPPLE BAKER RS NIPPLE 4.875 7418.7 3,]18.0 75.74 HANGER AER FLEX LO HYDRUALIC ROTATING 4.830 LINER HANGER 7,428,1 3,720.3 75.92 XO Reducing CROSSOVER 55"x4.5" 3.940 LOCATOR: 8, Ends 7, 91.8 3,]35.177.18 LOCATOR BAKERLOCATOR BOB 3.510 13,209.5 3,809.4 89.35 XO Redunng CROSSOVER 4.5"x4" 4.000 sPALAssr; 8.147 Tubing Strings Tubing Description Siring Ma.,, 1p(n) Tap IttKB) Bel DapiM1 ln.. Sel Oep[h (Np)I... Wt(ICM) G,ad Top Connaciwn TUBING -2015 WO 2718 244 26.9 6,933.0 3,5]42 6.50 L-80 EUEBrtl Completion Details BETTING SLEEVE; Sw&5 Top "Ul Tupmd Criminal Top ans) MR.) I°) Ikm Des Co. Iri (in) 268 28.8 0.00 HANGER HANGER 5,688 BE: SW.] 6,487.2 3,420.9 69.65 SLEEVE SA R MUSLIDIN LEEVE 2,250 nUmNNpomM- PaNmre (OPENED=4112/2018) 6,892.6 35608 70.55 1 GAUGE SLB SPECIAL CLEARANCE GAUGE CARRIER MANDREL 2.398 6,913.8 3,5628 70.64 LOCATOR BAKER LOCATOR 2.400 AACKER; 7,ano 6,914.7 3,568.2 ]0.65 SEAL ASSY BAKER 80.32 SEAL ASSEMBLY 2410 Tubi ng Dercri,.an Sbmg MO... ID TUBING -2015- 5.03 400 STACK PACKER (in) Tap 6,9]8.5 IttKB) B¢I DepIM1 IR. Bel 7,068,] 3,619.3 Depfb jryp)(... WtIIdR) Glatle L-80 Top COnnNtion BTC LOCATOR; 7.0a)0 Completion Details SEAL A35Y; 7,0619 PBgpA:S.9 Tap IND) Top Incl mi Nonal Tap (nKB) InKB) r) (N.D. Com ID lin) 6,978.5 3,589.3 70.59 SE LNG BAKER HEDE LINER SETTING SLEEVE 5750 SLEEVE PACKER', 1,W9.] 6,9937 3,594.4 70.54 SBE BAKER 8040 SEAL BORE RECEPTACLE 4,000 ],027.0 3,605.5 70.45 PACKER BAKER PREMIER PACKER 3.880 7,0503 3,6134 70.73 1 LOCATOR BAKER LOCATOR 3.870 .7,051.3 3,613.6 70.]3 IbEAL ASSY BAKER GBH -22 LOCATING SEAL ASSEMBLY 3870 NIPPLE, ;tdas Tubing Deenipbon Bmng Mp.. mpn) Top lilKe) sN DepM ln.. s¢t101 ITVD)L.. Wlpblfl Gr¢ae Top connMur TUBING -Original 4112 3,96 ],055.8 ],3356 3,696.9 12.60 L-80 IBTM WLEG7,W9.B Completion Detells Top nor Top Incl Nominal Top MIKE) MIKE) I°) IWm Des Co. 10 %n) 7,055.8 3,615.1 70.79 PBR BAKIEHPER- SB EAL ABBY RUN ON 4122/2009 38]5 WORKOVER 58 PRODUCTION CSG STABBED INTO PBR 7,0862 3,6250 71.14 PACKER BAKERS -3 PACKER 3,875 7091.8 3626.8 71.20 XO Enlarging CROSSOVER 4.5" x 5" 4.500 72983 3,6289 71.28 TO Reducing CROSSOVER S"x45" 4.500 71086 3632.2 7140 NIPPLE CAMCO'Do NIPPLE wI NO GO PROFILE 3750 7,3346 36966 74.99 WLEG WIRELINE ENTRY GUIDE 3.960 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Tap IND) Top Incl Top ITIKB) InKB) (') Oas Com on Data to (in) &4850 3,420.2 69.65 SLIP STOP 2.5^SLIP STOP in312019 6,48]0 3,420.8 69.fi5 JET PUMP 22 TOCK NOK W12 "R JE PUMP(to 1232019 RATIO Ser# CP 0008) WI AVA STINGER, FLOW THIRD IPELF', /.41S0.13483C BUB, AND GAUGE. DAL. Perforations & Slots seas eFACE, MS 7733.3 o_v rvouJ. I-mr,73583 13,579.9 REP Top ltlKe) Btm IttKB) his MD) MKS) Btm INO) MET LInkMZone Dab as (s ryolyn X Farm 7,704.0 13,09.0 3)67.7 3,809.2 WS B, WS WSC, 1C-178 4/162003 12.0 (PERF AlternaOngslo%edlblen Pip holes/fl a-30' joints w/8 25^x2.5-1slotted joint IPERF;],]01.0.131]8.0� Notes: General &Safety - - Ertl Dale AnC1 n 612912003 NOTE: MULTILATERAL WELL -IC -178(8/C -SANDS), IC-VBL1 (D -SAND) 2/20/2008 NOTE: Surface CSG Patch, 01 MEN: 0500 wall X65, 0.365 wt (see 2120109 WSRj 4272009 NOTE: View Schelnand w/Alaska Son emaloan 41012009 NOTE: WORKOVER INCLUDED SETTING S5" INNER CSG STRING & NEW TUBING COMPLETION BSANO soma finer. 7901S 13,] J,S 11112018 NOTE: 5.STie-Back Liner has a Pol °flLre DVdtuhe paBM1C liner InBN¢b 1112/2018 NOTE: though all staigh-run join and pups THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1C-178 Permit to Drill Number: 203-041 Sundry Number: 319-362 Dear Mr. Peirce: Alaska Oil and Gas Conservation Commission 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax 907.276.7542 www. a ogcc. a I asko. gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 401;e-e� Daniel T. Seamount, Jr. Commissioner DATED this `Sday of August, 2019. ABDMS4AUG 16 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AUG U 5 2019 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 ❑ Reenter Susp Well ❑ Alter Casing ❑ Other: RPPG MBE TRTMT3 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: COn000Phllll s Alaska Inc. Exploratory ❑ Development 17 Stratigraphic ❑ Service ❑ 203-041 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23144-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1C-178 Will planned perforations require a spacing exception? Yes ❑ No ID ' 9. Property Designation (Lease Number): 10. Field/Pool(s): , ADL 25649, ADL 25638 Kuparuk River Field /West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13,280' 3,811' 13246 3810 1200psi NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 76' 16" 110' 110' Surface 71705' 75/8 7,733' 3,770' Prod Inner CS 6,976' 51/2 7,007' 3,599' Liner 5,817' 41/2 1 13,244' 3,810' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7704.13179 3768-3809 4.500" L-80 7,336' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER = BAKER PREMIER PACKER 7027 MD and 3605 TVD SSSV = NONE N/A 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development p Service ❑ 14. Estimated Date for 9/1/2019 15. Well Status after proposed work: Commencing Operations: OIL O ' WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce Contact Name: John Peirce Authorized Title: Sr. Wells Engineer Contact Email: John.W.Peirce@cop.com Contact Phone: (907) 265.6471 W _ g Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 01 - 302 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 1/� V/ 3BDMS-1 AUG 1 6 2019 Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No Subsequent Form Required: �L APPROVED BY c� Approved by: COMMISSIONER THE COMMISSION Date. !J iii / / 1?"¢"9 ORIGINAL For 0-003 Revisad 4/2017 Approved application is valid for 12 months from the date of approval. Submit Form and Attachments In Duplicate �". 6/ r'� 2, 9/6 /iv Reformed Polymer Particle Gel Treatment of B Sand MBE from 1C-174 to 1C-178 1C-174 horizontal undulating injector (HUI) was drilled and completed in April 2003 with 4.5" tubing and 5.5" slotted liner. A West Sak D Sd Matrix Bypass Event occurred 3-8-07 between 1C-174 and 1C-178 producer. A 9-7-08 IPROF verified the MBE was deeper than 11400' RKB with estimated location at —11530' RKB to D Sand. On 5/5/09, 20 bbls of 8.6# Ultralight Cement Plug was pumped through a Cement Retainer set at 10735' RKB to isolate the MBE to 1C-178. This treatment allowed 1C-174 to return to service until a new MBE became evident in early 2018 from 1C-174 to 1C-178. An IPROF of 4/15/18 showed a possible MBE forming at —8100' RKB in a B Sand section of 1C-174. This feature took some split of total injection but it was not robust enough to treat yet with RPPG. A new IPROF of 7/19/19 now shows a mature B MBE exists at 8200' taking a majority of total injection. It has been verified that this MBE is in direct communication to 1C-178 horizontal producer. Per this procedure, an Inflatable Bridge Plug will be set in 1C-174 at 8305' RKB (target) in 5.5" Liner at the middle of a 128' section of blank liner, then a 5' perforation interval will be shot at 8210 - 8215' RKB (target) in a slotted liner joint near the MBE at 8200' RKB. Next, a fullbore RPPG job will be pumped to the B MBE, and then 1C-174 will be returned to injection to verify the MBE is sealed. Procedure Coil Tubing: 1) RIH with 2.50" OD Inflatable Bridge Plug on CT. Set IBP in blank 5.5" Liner section at —8305' RKB 2) RIH with 3.375" OD x 7' OAL Perf Gun on CT. Perf 5' OAL interval at 8215 - 8220' RKB (target), at 6 spf, 60 deg phasing, to provide large hole perforations of 0.5 - 0.75" diameter in 5.5" liner to enable easy RPPG slurry passage to the B MBE. POOH with pert gun. Verify all shots fired. 3) Pumping: Put 1C-174 on injection at 500 - 1000 BWPD at 6 - 12 hours before RPPG job, to start displacing gas head & Diesel FP from wellbore to B MBE, to ensure that the MBE is open, and that the well becomes liquid packed and free of hydrocarbon contaminants that can inhibit RPPG swelling and crosslinking. RU Mixing Van & pumping equipment. When ready to pump RPPG job, SI water injection to 1C-174 and swap to fullbore pumping 1 wellbore volume (135 bbls to MBE) of 2% ultraclean KCL Brine into 1C-174, followed by RPPG slurry at steady —2.4 bpm by adding 1 - 4 mm mesh RPPG to ultraclean 2% KCL Brine to make slurry concentration at 0.75 ppg added (target), and to place swelling RPPG into MBE within an hour. Continue pumping slurry —2.4 bpm at 0.75 ppg concentration until WHIP reaches 800 - 1000 psi, then swap from RPPG slurry to pumping 92 bbls 2% KCL Brine —2.4 bpm, followed by 41 bbls Diesel FP at —2.4 bpm to 2000' TVD, followed by Shutdown. Wait 48 hours for RPPG to fully swell and crosslink in the MBE to form a rigid amalgamated mass of non -flowing crosslinked gel before returning 1C-174 to injection or 1C-178 to production. 4) Coil Tubing: If post -MBE treatment evaluation indicates B MBE is sealed: RIH w/CT & pull IBP at 8305 RKB If post -MBE treatment evaluation indicates an MBE retreatment is needed, the IBP will be left set KUP PROD WELLNAME 1C-178 WELLBORE 1C-178 Ca�n�/-�y'tt� na'� �R/VVr11(II(t�S AlaSka.lrx. Well Attributes Max Angle 8 MD TO Fiala Name WeIIMre APVUWI WellMre stilus WESTEAK 500292316400 PROD n[I I°) Mo111x8 ACI Blm 1x1(8) 200 11.208.01 13280.0 Comment H251ppr) Jose ammuslon Ena Date NOG�tl Im us'mme"Datt SSSV'. NIPPLE 40 8/122016 Last WO'. 512512015 30.00 52712003 1G1]&, 7AYA1B3m:1]PM Last Tag ye'4ulrtli✓^+scl q pnnotatlonI Depthm%S) 1 End Dale yHIIDas East Moa By Last Tag: 1C -P nIOSDOr Last Rev Reason ........................ HuaGER. zsa CONDUCTOR: 31.11100 SLIP STOP.6 ass0 SLEEVELPP72 .1Ei PUMP a4a7D xp Turdectiri] GAUGE, e.aezo xoT %6.m2- LOCATOR185134 sEALAssr: care 7- SETTING aWaa NG Y &BE: B,m3.l T1EBAcpansl- Paro>e_ Ixeawailes":8.47,0070 PPLI(ER.70pr.a U0k ATOR;TDaaB SEAS AUSUP T E Prim; 7d559 PACRER: ].M8.3 NIPPLE.7,1N8 VALUS7331 (PERF: ]A1361a4m0 SVRFpealU iT]3}3 OsAND sop, L35sa 1357.9 IPEm;7,]a4013,1790_ aueO Balm ter, 7.401s ,2438 AnnoLron End ml¢ wellwre Fearsome, Rev Reason: Replace Jet Pump 11612019 1C-178 inargusp Casing Strings sites Ges¢npion CONDUCTOR wpnl 16 Up (in) Top(we) 15M 34.3 sol Depmmrc8l 1100 sol Dl EINP 110.0 ... wm en ll... 6250 Epea Hl rop Teresa WELDED Crile.Dldedieon SURFACE OD(nl 798 1011x1 Top III fi.87 MF3 Sal@qn BINB) ]733.3 selaapM HPI 3.004 WULen IL. 29.70 Graft [1 Top Thread BTCM Caslna D¢sotlptlon TI EBACK(2015)- POIychre Uldmube lining Oe (in) 512 ID (in) Top IIIKBI 4.30 264 a"dghU l 7,0070 Bat eepM IN01... 3,5988 NVLen( 1700 I. ads L-80 Top Thread BTC Casing Description B- SAND Slotted Liner ODlinl 4112 ID lin) Top llMB) 396 7,401.5 Set Des"UUKEU 13,243.8 set most lrvDl... 38099 wVLan IL. 12.60 Grape L-80 Top Thread SLHT Liner Details Nominal IS rop mKB) ToPEVDI(nnn[H9 Il B) Toplam C. oda C(m) ]401.5 3,7137 7541 SLEEVE BAKER HR SLEEVE .1 EXTENSION 5.010 7,4142 3,716.9 75.65 BUSHIN BAKER BUSHING 4.950 7,415.9 3,717.3 75.69 NIPPLE BAKER RS NIPPLE 4.075 7,4183 3,7180 ER ]574 F BAKERFLEXL K UALIC ROTATIN 4.030 LINER HANGER 7.4281 3,720.3 75.92 70Reaucing CROSSOVER 55"x4.5" .940 7,4918 3,735.1 77.16 LOCATOR BAKER LOCATOR SUB 3.510 132095 3,809.4 8995 NO Reducing CROSSOVER 45"x4° 4.000 Tubing Strings mems D¢a[riplion smno ma... man) rop(mre) se13¢pm (n.. set D¢pm INDI L-WtpLxll G(ae¢ Topconnecron TUBING -2015W0 2718 244 269 6,9330 3,96.2 550 L-80 EUEBrr Completion Details Top Dept To'MIl Nominal Top lnnBl lens) l°) Item Oes Com 10 Jim 26.8 268 000 HANGER HANGER 5.688 6487.2 34209 965 SLEEVE BAKER CMU SURING SLEEVE 2250 (OPENED=41122018) 6,892.6 3,560.8 ]0.55 GAUGE SLB SPECIAL CLEARANCE GAUGE CARRIER MANDREL 2398 Q913a 3,5618 7064 LOCATOR BAKER LOCATOR 2400 6,9143 3,568.2 7055 TEAL ASSV BAKER 8432 SEAL ASSEMBLY 2410 TUIR,q Desorption SNhq Ma... ID TUBING -2015- 503 4.00 STACK PACKER IMI TOPOVIBI 6,978.5 Bat DoMh ln. ].0683 a¢r Depth lrVD11... 3,819.3 Wt(1hW) James0Top L-80 Connectlon BTC Completion Details TOP lrv01 rop mal rvom,nal Top(nnB) Ione) (-I Ilam Dee Co. IDM) 6,978.5 3.5893 10.595ETTIN BAKER Al LINER SETTING SLEEVE 5.750 SLEEVE 6,9937 3,594.4 70.54 SBE BAKER BOJO SEAL BORE RECEPTACLE 4000 7,027.0 3,605.5 75.4-5 PACKER BAKER PREMIER PACKER 3.880 7,050] 3,6136 73 LOCATOR BAKER LOCATOR 3870 7,0513 3.6136 7.7 FEALASSY BAKER GBH -T2 LOCATING SEAL ASSEMBLY 387) Tubhq description Islas Ma... IS gel Top lnnB) BN Depth ltL aN Depth IND)l... W111WB GMo Top Connmem TUBING - Original 6112 3.96 7,0558 ],335.6 3698.9 12.60 LA0 IBTM Completion Details ea sa, Top IND) ToP Incl Nominal iopPast0558 lfln1l 1') Ikm 3¢s Cam ID,61 V IG N 41W409 3875 7,0558 3,615.1 70.19 PER WO PBR-SEE PSEAL RODUCTION WORKOVER 5.5" PRODUCTION CBG STABBED INTO PBR 7086.2 3 57 71.14 PACKER BAKER S-3 PACKER 3.875 7,0918 =3,2 71.20 X Enlarging CROSSOVER 4.5"x5^ 4.500 7098. 7120 TOReautlng CROSSOVER 5"x4.5" 4.5M 7,106.5 3632.2 7140 NIPPLE CANDO'El NIPPLE w/NO GO PROFILE 3.750 7,334.6 36966 74.99 WLEG WIRELINE ENTRY GUIDE 3.980 Other In Hole (Wireline retrievable pluga, valves, pumps, fish, etc.) T" BomI .,met Topime) We) fl oee Com Run am" ID ant 6.4850 3,420.2 69.65 SLIPSTOP 2.5' LIPBTOP 1123201 'e"O u 3,420.8 69.65 JET PUMP 0 225" CLOCK KEYS) W/ ' JET PUMP 8 12312019 RATIO sere CP 0008) W/ AVA STINGER, FLOW THIRD SUB, AND GAUGE. 119" OAL. Perforations 8 Slots T.pgft-7,7 B) e13,17 Top (rvD) (3x61 Bull 13801 LB. Dam snot cepa pnotent 1 Typo loom ],]04.0 . 13,1]9.0 376]] 3,8092 WS B. WS B, \NSC,1C-176 411102003 120 WERE AIter pipe-3025s2s haes/R.25"x2.5"/sDuetl Inlet ,-3in9girtspVblenk /sl Notes: General 8 Safety End Dow Annolloon 4/2912003 NOTEMULTILATERAL WELL -1G178(B/C-SANDS), 1C-1 WL1(D-SAND) 2/202008 NOTE' Surface OSG Patch, Mas' 0500 wall X55 0.365 w4 (see 220109 WSR) 42721H5 NOTE: View Schematic w/ Alaska Schematc9a 4272009 NOTEWORKOVER INCLUDED SETTING 55" INNER CSG STRING B NEW TUBING COMPLETION 11112018 NOTE: 5.5 Tie -Back Liner hes a Falycore Ulastube plastic linerinstalle0- VI NOTE: though all strai9h-hum join and PUPS STATE OF ALASKA AL :A OIL AND GAS CONSERVATION CON .SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing pi Operations Shutdown r Performed Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r✓' Re-enter Susp Well r Other: Run Jet Pump r� 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 203-041 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-029-23144-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25649,25638 14QV 14351A t(-115‘ 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 13280 feet Plugs(measured) none true vertical 3811 feet Junk(measured) none Effective Depth measured 13246 feet Packer(measured) 7027, 7086 true vertical 3810 feet (true vertical) 3606, 3625 Casing Length Size MD ND Burst Collapse CONDUCTOR 76 16 110 110 SURFACE 7705 7.625 7733 3770 PROD INNER CS 6976 5.5 7006 3598 PROD.LINER 5817 4.5 13244 3811 Perforation depth: Measured depth: 7704'-13179' RECEIVED True Vertical Depth: 3768'-3809' SCANNED ) I L 2 8 2 0 f t JUN 3 0 2 015 Tubing(size,grade,MD,and ND) 2.875, L-80,6933 MD, 3574 TVD AOGCC Packers&SSSV(type,MD,and ND) PACKER(LINER TOP)-BAKER PREMIER PACKER @ 7027 MD and 3606 ND PACKER-BAKER S-3 PACKER @ 7086 MD and 3625 ND NIPPLE-CAMCO DS NIPPLE @ 495 MD and 495 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured). no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25 070,25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations rd Exploratory r Development I• Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r VVINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt 315-194 Contact Travis Smith C , 2. -•450 Email Travis.T.Smith anconocophillips.com Printed Name T7s Smith Title Wells Engineer Signature /. Phone:265-6450 Date �� l 1114] /J RBDM JUL - 1 2015 tO.C---- Form 10-404 Revised 5/2015 Submit Original Only ConocoPhillips Time Log & Summary Welview Web Reporting Report Well Name: 1C-178 Rig Name: NABORS 9ES Job Type: RECOMPLETION Rig Accept: 5/27/2015 3:00:00 AM Rig Release: 6/7/2015 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/25/2015 24 hr Summary Move shop#2 and pits from 3F pad to 1C pad. Shuffle rig mats back into position for moving the sub. Move the sub 3.3 miles from 3F pad to the CPF3 access road Y. 00:00 03:00 3.00 0 0 MIRU MOVE RURD P Continue to prep the pits and sub to move. 03:00 17:00 14.00 0 0 MIRU MOVE MOB P Move shop#2 and pits from 3F pad to 1C pad. 17:00 19:00 2.00 0 0 MIRU MOVE MOB P Spot shop#2 and spot the pits by 1C-178. SimOps: Shuffle rig mats back into position for moving the sub 19:00 20:30 1.50 0 0 MIRU MOVE MOB P Continue to shuffle rig mats back into position for moving the sub. 20:30 00:00 3.50 0 0 MIRU MOVE MOB P Move the sub 3.3 miles from 3F pad to the CPF3 access road Y. 05/26/2015 Continue moving sub from 3F-10 to 1C-178 stop and wait for crew change and plane activity as per security. Sub on location at 1615 hrs 00:00 06:00 6.00 0 0 MIRU MOVE MOB P Move the sub 5.7 miles from the CPF3 access road Y to the Oliktok Y. 06:00 12:00 6.00 0 0 MIRU MOVE MOB P Move the sub from the Oliktok Y to 1R intersection hold for crew change as per security. 12:00 16:15 4.25 0 0 MIRU MOVE MOB P Move sub from 1R/1A Intersection to 1C pad arrive on location @ 1615 hrs. 16:15 18:30 2.25 0 0 MIRU MOVE MOB P Spot Sub over well. 18:30 22:00 3.50 0 0 MIRU MOVE MOB P Spot pits to Sub. 22:00 22:30 0.50 0 0 MIRU MOVE SFTY P PJSM for raising the derrick and cattle chute. 22:30 00:00 1.50 0 0 MIRU MOVE RURD P Raise the derrick and cattle chute. SIMOPS: hook up steam,work on rig acceptance checklist. 05/27/2015 Connect Service Lines.Work on Rig Acceptance Checklist. Prep pits for fluid.Take on 8.5 ppg Seawater to pits. Pull BPV. Kill Well. Set TWC. ND Tree. NU BOPE. Perform Initial BOPE test per AOGCC and CPAI with 2-7/8"and 5-1/2"test joints. Daily Losses: 113 bbls RIG ACCEPTED @ 03:00 RIG ON HIGHLINE @ 12:00 Page 1 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:00 3.00 I 0 0 MIRU MOVE RURD P Hook up electrical interconnects.Complete Berming around rig and equipment. Bridle Up. Hook Up top drive connections. Work on Rig acceptance checklist. RIG ACCEPTED @ 03:00 03:00 09:30 6.50 0 0 MIRU WELCTL RURD P Begin taking on 8.5 ppg seawater to pits. SIMOPS: Organize floor, complete interconnects, Roundtrip truck for more 8.5 ppg seawater. Rig Up Circulation lines in cellar for well kill. Install Choke House in hardline to Tiger Tank. PT surface equipment to 3500 psi. 09:30 10:15 0.75 0 0 MIRU WELCTL SEQP P Purge Tiger Tank Line and PT to 3000 psi. 10:15 12:00 1.75 0 0 MIRU WELCTL MPSP P Pick Up Lubricator and Make Up to tree. PT lubricator to 200 psi. Pull BPV. Lay Down Lubricator. OA=50 psi, IA=0 psi, Tbg=200 psi. 12:00 12:30 0.50 0 0 MIRU WELCTL SFTY P PJSM for well kill. 12:30 14:30 2.00 0 0 MIRU WELCTL KLWL P Kill well by circulating 242 bbls down tubing taking returns to Tiger Tank. 1340 bbls returned to tiger tank. 8.5 ppg Seawater(with 3% KCL), ICP 275 psi, FCP 115 psi. 14:30 15:00 0.50 0 0 MIRU WELCTL OWFF P Monitor well. IA and Tubing both on suction. 15:00 15:30 0.50 0 0 MIRU WHDBO MPSP P Set BPV. 15:30 17:00 1.50 0 0 MIRU WHDBO NUND P Nipple Down tree. 17:00 20:00 3.00 0 0 MIRU WHDBO NUND P Nipple Up BOPE. 20:00 20:30 0.50 0 0 MIRU WHDBO SFTY P PJSM with all crew members for testing BOPE. 20:30 21:30 1.00 0 0 MIRU WHDBO RURD P Rig Up test equipment. Pick Up and Make Up Test Joint, TIW, Dart,XO to make up to Vetco dart plug. Function Rams after NU of BOPE. Fill Stack and lines with water. Tighten leaking gland nut. 21:30 00:00 2.50 0 0 MIRU WHDBO BOPE P Conduct initial BOPE test to 250/3000 psi: test 2-7/8"x 5"VBR's (lower pipe rams)with 2-7/8"test joint;test 3-1/2"x 6"VBR's(upper pipe rams)with 5-1/2"test joint;test annular to 250/3000 with 5-1/2"and 2-7/8"test joints. The States right to witness was waived by AOGCC inspector Lou Grimaldi on 5/27/15 at 06:21 hours via email. 05/28/2015 Perform Initial BOPE test per AOGCC and CPAI with 2-7/8"and 5-1/2"test joints. Choke Valve#16 F/P, all other PASS.Accumulator 6 bottle avg 2041 psi.200 psi recovery 26 sec, Full Press 147 sec. Pull TWC. Pull 2-7/8"completion free. Reverse Circulate until clean. Lay Down 2-7/8"completion. Daily Losses: 233 bbls Page 2 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 05:00 5.00 0 0 MIRU WHDBO BOPE P Conduct initial BOPE test to 250/3000 psi: test 2-7/8"x 5"VBR's (lower pipe rams)with 2-7/8"test joint;test 3-1/2"x 6"VBR's(upper pipe rams)with 5-1/2"test joint;test annular to 250/3000 with 5-1/2"and 2-7/8"test joints. F/P on Valve#16, all other PASS. The States right to witness was waived by AOGCC inspector Lou Grimaldi on 5/27/15 at 06:21 hours via email. Conduct CPAI Koomey Draw Down Test: Pressures:Accumulator=290 psi; Manifold= 1500 psi;Annular= 850 psi.Accumulator after rams functioned= 1650 psi:200 psi=26 seconds; Full Pressure= 146 Seconds;6 Bottles avg=2041 psi 05:00 06:00 1.00 0 0 MIRU WHDBO RURD P Rig Down BOPE Testing Equipment. Blow Down Lines. 06:00 06:45 0.75 0 0 MIRU WHDBO MPSP P Pull TWC and Test Dart. Install Isolation sleeve. SIMOPS: Fill well with 20 bbls, no returns. 06:45 08:00 1.25 0 0 COMPZ RPCOM RURD P Rig Up Completion Handling Equipment. 08:00 08:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM with all workers for pulling completion and Laying Down. 08:15 23:30 15.25 7,003 0 COMPZ RPCOM PULL P Pull 2 7/8"tubing with tech wire. Tech wire inspected and spooled by Baker Centralift as it is spooled. Recovered 9 SS Bands and 221 Canon Clamps. 23:30 00:00 0.50 0 0 COMPZ RPCOM RURD P Lay Down Baker Tech Wire Spool. Rig Down 2 7/8"handling equipment. 05/29/2015 Pull and Lay Down 5.5"Liner. Process 5.5"Polycore Liner and Completion Equipment. Daily Losses:403 bbls 00:00 01:30 1.50 0 0 PROD1 CSGRC'RURD P Lay Down 2 7/8"handling equipment. Pick Up 5.5"handling equipment. SIMOPS: Clean and Clear Rig Floor. 01:30 02:00 0.50 0 7,047 PROD1 CSGRC'PULL P Pull 5.5"liner hanger free with minimal overpull. Up Wt= 120k. Observe Seals pull from SBE. 02:00 02:30 0.50 7,047 7,047 PROD1 CSGRC'RURD P Line up to circulate to the tiger tank. 02:30 03:30 1.00 7,047 7,407 PROD1 CSGRC'CIRC P Circulate 160 bbls taking returns to Tiger Tank. —50 bbls return to Tiger Tank.All returns Diesel. 03:30 03:45 0.25 7,047 7,047 PROD1 CSGRC'OWFF P Monitor Well.Well dead no fluid at surface. 03:45 04:30 0.75 7,047 7,047 PROD1 CSGRC'PULD P Lay Down Landing Joint and Circulating Equipment. Observe seal not go back into SBE during Lay Down of landing joint,do not try to put seals into SBE again. 04:30 14:00 9.50 7,047 0 PROD1 CSGRC'PULL P Pull and Lay Down 5.5"Casing Joints. Page 3 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 15:00 1.00 0 0 PROD1 CSGRC'RURD P Clean and Clear Rig Floor from lay down of 5.5"Casing Joints. 15:00 22:30 7.50 0 0 PROD1 CASING OTHR P Processing 5.5"Polycore casing joints outside pipeshed. 2.3" Drift stuck in 2nd pipe. Drift with 2.18" drift. Load in pipe shed as Drifted and processed. Mobilize Baker Completions equipment. 22:30 00:00 1.50 0 52 PROD1 CASING PUTB P Run 5.5"Casing per detail. 05/30/2015 Pick Up and RIH with 5.5"Polycore Liner. Locate 6.5'in on Joint 206. Backside will not hold fluid. Cannot observe change in pump pressure when seal stab into SBE. Backside will not hold pressure. Decions made to Lay Down 5.5"Polycore Casing string and mobilize test packer form Baker Hughes. Lay Down 5.5"Casing in shed. Daily Losses: 550 bbls 00:00 19:30 19.50 52 7,072 PROD1 CASING PUTB P Run 5.5"Casing per detail. Fill backside 10-12 bbls per hour.All pipe drifted in shed with 5.238"drift. Observe seals chatter into SBE. Fill backside with fluid, backside will not fill or hold fluid. Pull seal out and rotate and go back in and locate sam spot.Attempt to pump down backside, pump 18 bbls at increasing to 3 bbls per minute at 55 psi. Backside will not pressure up. Up Wt= 116k, Dn Wt=75k 19:30 23:00 3.50 7,072 7,022 PROD1 CASING CIRC X Pull up out of SBE and lay down joint 206. Pick Up 1 joint of Drill Pipe,TIW and Crossover. Stab back into SBE and locate. No change from previous, backside will not fill. Pull seals out of SBE. Pump 7 bbls per minute at 120 psi to establish returns at surface, slack off and stab into SBE, returns at surface stop but no pressure change. Shut pumps down, observe fluid on backside start to sink. Contact CPAI Engineer. Decision made to pull and Lay down 5.5" Casing string. Mobilize Test Packer for use from Baker Completions. 23:00 00:00 1.00 7,022 6,550 PROD1 CASING PULD X Lay Down 5.5"Polycore Casing in pipeshed. 05/31/2015 Lay Down 5.5"Casing in shed. Pick Up Test Packer and single in hole with Drill Pipe. Daily Losses: 106 bbls 00:00 13:00 13.00 6,550 0 PROD1 CASING PULD X Lay Down 5.5"Polycore Casing in pipeshed. Lay Down SBE and Seal Assembly in Pipeshed. 13:00 13:30 0.50 0 0 PROD1 CASING BOPE X Set Test Plug in wellhead. 13:30 13:45 0.25 0 0 PROD1 CASING SFTY X PJSM for Testing BOPE. 13:45 16:00 2.25 0 0 PROD1 CASING BOPE X Test Annular, Upper 3"x 6-1/2"VBR and 2-7/8"x 5"VBR with 4"test joint.All tests PASS. Page 4 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 16:30 0.50 0 0 PROD1 CASING BOPE X Rig Down test equipment and blow down lines. Lay down test joints and break out TIW. 16:30 16:45 0.25 0 0 PROD1 CASING SFTY X PJSM picking up Test Packer and SIH with Drill Pipe. 16:45 17:15 0.50 0 0 PROD1 CASING RURD X Set Wear Ring,4.36' length, 7"ID. 17:15 17:45 0.50 0 0 PROD1 CASING BHAH X Pick Up Test Packer per BH Rep 17:45 00:00 6.25 0 4,409 PROD1 CASING PULD X Single in hole picking up Drill Pipe from Pipe Shed. 06/01/2015 Single in hole with Drill Pipe. Establish returns and sting in. Backside will not hold fluid. Set test Packer above PBR to test Casing to 1800 psi. Trip out of hole with test packer. 00:00 05:30 5.50 4,409 7,061 PROD1 CASING PULD X Continue to single in hole picking up Drill Pipe from Pipe Shed. Locate at 17.5' in on joint 222(Top of PBR 7049'dpmd). Pull out of PBR and relocate to confirm. 05:30 06:30 1.00 7,061 7,061 PROD1 CASING CIRC X Pull out of PBR and circulate down Drill Pipe at 6 bpm until returns established. Returns seen at 61 bbls away(primarily diesel). Sting into PBR,observe returns stop, slow pumps to 3 bpm and observe Annulus fluid start sinking. Bring pumps back up to 6 bpm to fill hole. Pumps off and close bag to prepare for pressure test. Pump down backside building rate from 1/2 bpm to 3 bpm 160 psi achieved. No pressure held. 06:30 07:00 0.50 7,059 7,059 PROD1 CASING MPSP X Open bag and set test packer just above PBR. 07:00 07:30 0.50 7,059 7,059 PROD1 CASING PRTS X Close bag and pressure test Surface casing to 1800 psi for 15 min. GOOD test. Charted. 07:30 07:45 0.25 7,059 6,965 PROD1 CASING PULD X Pull out of hole Laying down 3 joints of drill pipe. Up Wt= 115k, Dn Wt= 86k 07:45 09:00 1.25 6,965 6,965 PROD1 CASING SLPC X Slip and Cut 91'of Drilling Line. 09:00 09:30 0.50 6,965 6,965 PROD1 CASING SVRG X Service Top Drive, Drawworks, Crown. 09:30 10:00 0.50 6,965 6,965 PROD1 CASING SFTY X AAR for laying down 5.5"casing with all workers and leaders. 10:00 11:00 1.00 6,965 6,965 PROD1 CASING WAIT T Waiting on decision for Plan Forward. 11:00 12:00 1.00 6,965 6,965 PROD1 CASING RURD X Rig Down power tongs, Line Spooler and Running equipment from rig floor. Clear Floor for tripping pipe. 12:00 17:00 5.00 6,965 29 PROD1 CASING TRIP X Trip out of hole standing Drill Pipe in derrick. 17:00 18:00 1.00 29 0 PROD1 CASING BHAH X Lay Down Test Packer and tools per Baker Completions Rep. Page 5 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 0 0 PROD1 CASING WAIT XT Waiting on Completion equipment to be delivered to Deadhorse Baker Shop form Alpine,then to be measured and bucked up by Baker Completions/Machine.Truck dispatched to Baker and standing by at Baker for equipment to be ready. 36/02/2015 Pick Up and TIH with Stacker Packer Assembly to 7,068'. Drop ball and set Premier packer.Test Packer to 1800 psi-good. POOH laying down drill pipe. Rig up to run in hole with 5.5"tie-back liner. RIH with tie-back string to 88'. Daily fluid lost to formation 228 bbls; Total 1894 bbls 00:00 01:30 1.50 0 0 PROD1 CASING WAIT X Waiting on Completion equipment to be delivered from Baker Completions in Deadhorse. 01:30 02:45 1.25 0 0 PROD1 CASING OTHR X Baker Equipment arrives and load into pipe shed. Process equipment in pipe shed and check dimensions and measurements. 02:45 03:15 0.50 0 0 PROD1 CASING SFTY X PJSM for picking up Stacker Packer completion,tailpipe and inner work string. 03:15 05:45 2.50 0 100 PROD1 CASING PUTB X Pick Up Seal Assmebly, Packer, Seal Bore Receptacle, Liner Setting Sleeve, Running tool and inner work string/stinger. 05:45 10:45 5.00 100 7,068 PROD1 CASING RCST X RIH with stacker packer assembly on drill pipe from 100'to 7,068'. PUW 115K, SOW 75K. 10:45 11:45 1.00 7,068 7,068 PROD1 CASING PACK X Drop 1"ball and pump on seat. Pressure up to 3000 psi to set packer. 11:45 13:00 1.25 7,068 7,068 PROD1 CASING PRTS X Rig up and test packer to 1800 psi for 15 minutes,good. 13:00 19:30 6.50 7,068 100 PROD1 CASING PULD X POOH laying down drill pipe. 19:30 20:30 1.00 100 0 PROD1 CASING BHAH X L/D liner running tool. 20:30 21:00 0.50 0 0 PROD1 CASING RURD P Pull Wear bushing. 21:00 22:00 1.00 0 0 PROD1 CASING RURD P Rig up to RIH with 5-1/2"Polycore Ultratube liner. Rig up GBR, Change out elevators. Load SBE in pipe shed. 22:00 00:00 2.00 0 88 PROD1 CASING PUTB P PJSM. Make up Seals, (1)4-1/2" IBTM tubing and SBE 06/03/2015 Continue to RIH with 5-1/2" Polycore Ultratube tie-back string to 7006.99, observe seals engage. Calculate space out. Rig up to RIH with 2-7/8"tubing. Make up 5-1/2"hanger and landing joint. Spot corrosion inhibited fluid and diesel for freeze protect on back side. Land 5-1/2"tie-back liner. RILDS. Daily fluid lost to formation 338 bbls, total lost 2232 bbls. 00:00 13:30 13.50 88 7,007 PROD1 CASING PUTB P RIH with 5-1/2"Polycore Ultratube liner to 7006.99 to no-go; observing seals engaging at 6993'. 13:30 14:00 0.50 7,007 7,007 PROD1 CASING PRTS P Close annular and PT 7-5/8"x 5-1/2" annular to 1000 psi-good. Page 6 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 15:00 1.00 6,977 6,977 PROD1 CASING HOSO P Calculate space out, lay down three joints. Pick up pup joints and full joint. -Send hanger and pup to Baker to pup up new Polycore Ultratube pup joint on bottom. 15:00 20:00 5.00 6,977 6,977 PROD1 CASING RURD P Rig down GBR and pipe handling equipment. Rig up Centrilift spooler and wire to prep for 2-7/8"completion run. Hang sheave in derrick. Prep rig floor for 2-7/8"run, load and count clamps. 20:00 20:30 0.50 6,977 6,977 PROD1 CASING HOSO P Pick up hanger to rig floor. Make up landing joint. 20:30 21:00 0.50 6,977 6,977 PROD1 CASING RURD P Rig up cement line for returns, spot in LRS. 21:00 23:30 2.50 6,977 6,995 PROD1 CASING CRIH P PJSM. Engage seals and fill back side. Pick up and observe fluid drop. Mark pipe. Close annular. Spot 75 bbls of corrosion inhibited brined followed by 45 bbls of diesel; Little Red Services performing pumping. Engage seals. Open annular. 23:30 00:00 0.50 6,955 7,007 PROD1 CASING HOSO P Land 5.5"liner. RILDS. 36/04/2015 Test hanger packoffs 250/5000-good. Test 5-1/2"x 7-5/8"OA to 1800 for 15 minutes-good. R/D 5-1/2" tools, Rig up and RIH with 2-7/8"completion as per detail; no go at 6940'. Space out. Rig up circulating equipment to landing joint. Daily fluid lost to formation 208 bbls. Total lost 2440 bbls. 00:00 00:30 0.50 0 0 PROD1 CASING PRTS P PT casing packoff 250/5000 for 10 minutes-good. 00:30 01:00 0.50 0 0 PROD1 CASING PRTS P Rig up and test 7-5/8"x 5-1/2"OA to 1800 for 15 minutes-pass. 01:00 02:30 1.50 0 0 PROD1 CASING RURD P Rig down Little Red Services. Rig down circulating equipment. Lay down landing joint. 02:30 03:30 1.00 0 0 COMPZ RPCOM RURD P Rig down GBR 5.5"tongs. Load GBR single stack tongs. M/U TIW. Clean and clear rig floor. Change out pipe handling equipment to 2-7/8". 03:30 04:45 1.25 0 0 COMPZ RPCOM RURD P Hang sheave and run TEC wire through. 04:45 21:30 16.75 0 6,940 COMPZ RPCOM PUTB P PJSM. Pick up and RIH with 2-7/8" completion as per detail check TEC wire every 1,000'; install cannon clamps on every collare. RIH to 6,940'and observe no-go with 10K WOB. Page 7 of 10 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 21:30 23:15 1.75 6,940 6,906 COMPZ RPCOM HOSO P Pick up out of seals and pump 2 bpm to attempt and see seals engage, unable to. No-go at same depth. Fill back side and pick up to observe fluid level drop when seals pull out to confirm depth. Calculate space out. Lay down partial plus two joints. Make up pup joint and full joint. 23:15 00:00 0.75 6,906 6,906 COMPZ RPCOM RURD P Make up circulation sub on top of landing joint. 36/05/2015 Make up hanger and landing joint. Rig up and reverse circulate 72 bbls of diesel for freeze protect, no returns. Bullhead 48 bbls down tubing. Bleed off IA pressure land tubing RILDS and test packoffs. Bleed off tubing pressure. Test IA to 3500 psi for 30 minutes-good, monitor tubing-static. Set TWC and test to 1000 psi for 5 minutes-good. Suck out stack, observe flow through TWC at 1 gallon per minute. 00:00 01:30 1.50 6,906 6,913 COMPZ RPCOM THGR P Make up hanger and landing joint. Set hanger above annular and close. 01:30 03:30 2.00 6,913 6,913 COMPZ RPCOM FRZP P PJSM freeze protect well with 72 bbls of diesel ag 1.5 bpm 400 psi, no returns. Test gauge wire with annular closed-good. 03:30 06:30 3.00 6,913 6,913 COMPZ RPCOM FRZP T Attempt to bleed off pressure from backside, 150 psi. Bleed down and built back up to 145 psi. Check tubing pressure, 0 psi. Bleed off 1 bbl pressure built back up to 130 psi. No pressure on tubing. Pump additional 9 bbls down backside to ensure diesel to tubing tail. 06:30 08:30 2.00 6,913 6,913 COMPZ RPCOM FRZP T Wait on additional diesel to balance the well. 08:30 11:00 2.50 6,913 6,913 COMPZ RPCOM FRZP T Rig up LRS and PT lines to 2500 psi. Bullhead 48 bbls down the tubing ICP 250 psi at 2 bpm, FCP 400 psi. Allow tubing and IA to equilize at 150 psi. 11:00 12:00 1.00 6,913 6,913 COMPZ RPCOM RURD T Rig up to take returns to kill tank. 12:00 14:00 2.00 6,933 6,933 COMPZ RPCOM THGR P Bleed pressure of IA and verify 0. Open annular and land hanger. RILDS. Test packoff 250/5000 for 10 minutes-good. 14:00 14:30 0.50 6,933 6,933 COMPZ RPCOM OWFF P Bleed tubing off to kill tank 29 bbls returned. 14:30 17:00 2.50 6,933 6,933 COMPZ RPCOM PRTS P Test IA to 3,500 psi for 30 minutes- good. Simops: monitor tubing, static. 17:00 18:00 1.00 6,933 6,933 COMPZ RPCOM RURD P Rig down circulating equipment and landing joint. 18:00 21:00 3.00 6,933 6,933 COMPZ WHDBO MPSP P Pull isolation sleeve. Set TWC and test to 1000 psi for 5 minutes-good. Suck out stack. Page 8 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 00:00 3.00 6,933 6,933 COMPZ WHDBO OWFF T Observe flow at 1 gallon per minute coming out of production valve. Shut in and confirm its the flow is bypassing the TWC. Discuss options with town. 36/06/2015 Discuss options with town. Order out lubricator extension rods from Deadhorse. Continue to monitor well, flowing by TWC at 1 gallon per minute. Load Lubricator extension rods, incorrect size for lubricator. Order out Lubricator from Deadhorse. Load lubricator and rig up. PT lubricator to 500 psi-good. 00:00 02:30 2.50 0 0 COMPZ WHDBO OWFF T Continue to observe well. Make up TWC retrieval tool to and engage poppet, no additional pressure seen below TWC, appears stable. Suck out stack and observe flow past TWC at 1 gallon per minute. 02:30 09:30 7.00 0 0 COMPZ WHDBO WAIT T Wait on lubricator extensions from dead horse to lubricate out TWC. Rig up dutch riser. Continue to monitor well, flow at 1 gallon per minute. 09:30 10:30 1.00 0 0 COMPZ WHDBO OTHR T Extension rods on location. Load lubricator and extensions. 10:30 11:30 1.00 0 0 COMPZ WHDBO WAIT T Lay down lubricator. Order out Lubricator from Deadhorse. Continue to monitor well; 1 gallon per minute flow past TWC. 11:30 21:30 10.00 0 0 COMPZ WHDBO WAIT T Wait on lubricator from Deadhorse while monitoring well. Clear flor of tools and equipment. General housekeeping. Prep for rig move 21:30 00:00 2.50 0 0 COMPZ WHDBO RURD T Load lubricator. Make up extensions and rig up to dutch riser. PT lubricator to 500 psi for 30 minutes. 06/07/2015 Lubricate out TWC. Bullhead 58 bbls of 8.6 ppg KWF. Monitor well. Set BPV. Perform Between Wells Maintenance on BOPE. N/D BOPE, N/U tree. Lubricate out BPV and lubricate in TWC. PT tree. Lubricate out TWC and freeze protect well with 40 bbls of diesel. Lubricate in BPV. Secure cellar. Prep for rig move. Rig released at 24:00 00:00 00:15 0.25 0 0 COMPZ WHDBO MPSP T Lubricate out TWC. 00:15 01:00 0.75 0 0 COMPZ WHDBO KLWL T Bullhead 58bbls of 8.6 ppg KWF staging pumps up to 3 bpm. FCP 300 psi. 01:00 01:30 0.50 0 0 COMPZ WHDBO OWFF T Monitor well, on vac. 01:30 03:00 1.50 0 0 COMPZ WHDBO OTHR T Rig down and lay down lubricator to pipe shed. Blow down choke and kill HCR. Rig down dutch riser. 03:00 10:00 7.00 0 COMPZ WHDBO SVRG P Perform BWM. Funtion annular and rams to inspect. Open ram doors and inspect all rubber element. 10:00 14:00 4.00 COMPZ WHDBO NUND P Nipple down BOPE and set back on stump 14:00 15:30 1.50 COMPZ WHDBO NUND P Nipple up tubing adapter,feed gauge wire through it. Meg and verify communcation with gauge mandrel. Nipple up tree. PT hanger voids 250/5000 psi-good. Page 9 of 10 r Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 17:15 1.75 COMPZ WHDBO MPSP P Lubricate out BPV. Lubricate in TWC. 17:15 17:45 0.50 COMPZ WHDBO PRTS P PT tree to 5000 psi-good. 17:45 18:00 0.25 COMPZ WHDBO MPSP P Lubricate out TWC. 18:00 18:45 0.75 COMPZ WHDBO FRZP P Freeze protect tubing with LRS, pumpe 40 bbls desiel 18:45 19:00 0.25 COMPZ WHDBO MPSP P Lubricate in BPV. Final pressures: IA-0; OA-0; Tubing 100 psi 19:00 20:30 1.50 DEMOB MOVE RURD P Secure well. clean cellar 20:30 00:00 3.50 DEMOB MOVE RURD P Prep for rig move. Blow down steam lines. Prep rig floor and bridle up. Finish cleaning pits. disconnecte interconnect. Prep Taylor camp,welding shop, electrical shop. Rig released at 24:00 Page 10 of 10 OF Ty THE STATE Alaska Oil and Gas fALAS�o Conservation Commission ".WA__=- 333 West Seventh Avenue 5 de GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 AL ASV' Fax: 907.276 7542 �n� www.aogcc.alaska.gov iCkti�° DRi? U Travis Smith Wells Engineer ConocoPhillips Alaska, Inc. ao , _ 041 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1C-178 Sundry Number: 315-194 Dear Mr. Smith: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster // Chair DATED this U day of April, 2015 Encl. RECEIVED A. KA OIL AND GAS CONSERVATION COW. Ci ,ION 'y1��16 APPLICATION FOR SUNDRY APPROVALS APR 0 2 2015 20 AAC 25.280 1.Type of Request: Abandon r Plug for Redrill r- Perforate New Pool r Repair w ell r - Change//VS;Q�v g m r- Suspend r• Plug Perforations r Fbrforate r Poll Tubing hr,7 , Time Extension r• Operational Shutdown r Re-enter Susp.Well r" Stimulate r• Alter casing r• 1-1,--'Other: 26�/etj��p 2.Operator Name: 4 Current Well Class: 5.Permit to Drill Number. ConocoPhillips Alaska, Inc.• Exploratory r Development ry• . 203-041 • 3.Address: Stratigraphic r• Service 6.API Number. P.0 Box 100360,Anchorage,Alaska 99510 50-029-23144-00 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes F No F.7 / KRU 1C-178 9.Property Designation(Lease Number). 10.Field/Pool(s): ADL 25649,25638, Kuparuk River Field/West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft). Plugs(measured): Junk(measured). 13280 . 3811 • 13246' • 3810' ' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 16 110' 110' SURFACE 7705 7.625 7733' 3770' PROD. LINER 5817 4.5 13244' 3811' TIEBACK LINER 7044 5.5 7072' 3620' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7704-13179 3768-3809 2.875 L-80 7003 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER S-3 PACKER MD=7086 TVD=3625 NIPPLE-CAMCO DS NIPPLE MD=495 TVD=495 • 12.Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r" Stratigraphic E Development r• Service 1 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/10/2015 Oil r' ' Gas r• WDSPL I— Suspended r 16.Verbal Approval: Date: WINJ r` GINJ r- WAG r Abandoned r• Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact- Travis Smith @ 265-6450 Email: Travis T.Smith(cilconocophillips.com Printed Name r-vi Sml OF Title: Wells Engineer Signature / /� � Phone:265-6450 Date ,//6.----------- Commission Use Only Sundry Number: 3 (640'1 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r• BOP Test IV;echanical Integrity Test r Location Clearance r- Other. /3op 71-c-5 f to 300 O f 5 (44P 5P 1 5 ?85 psi ) f}hi'7lJ/c rprc v - Fz'v- 12-51- 25?O X-5, Spacing Exception Required? Yes ❑ No iir Subsequent Form Required: I C- 4 ri 4 APPROVED BY Approved by: t'- COMMISSIONER THE COMMISSION Date: 4.- Zr - 1 5 VTL 4/Z/// A proved pplication Is valid tor 12 months from the date of approval. Form 10-403(Revised 10/2012) �� q��/'� Submit Form and Attachments in Duplicate ORIGINAL f--RBDMSc,)\ APR 2 2 2015 • a 3EC'i..WVED ConocoPhillips .,H 0 2 2015 Alaska P.O. BOX 100360 ADCC ANCHORAGE,ALASKA 99510-0360 March 31,2015 Commissioner Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner Foerster: ConocoPhillips hereby applies for an Application for Sundry Approval to workover the West Sak Producer 1C-178(PTD:203-041). Well 1C-178 is an B-and D-sand West Sak jet pump producer. In 2009 a 5 '/2"tie-back liner was installed to create a second barrier from energized fluids to formation. 1C-184 was shut-in September 2014 due to a leak in the 5 'h" tie-back liner. The well passes CMIT IAxOA showing that the tubing and original production casing has pressure integrity. The scope or the rig workover is to pull and replace the existing 5-'/z" tie-back liner with a 5-1/4" thermoplastic-lined tie-back liner (intended to mitigate the corrosion problem in the liner) and replace the 2-7/8"tubing. A jet pump will be installed post rig workover. i If you have any questions or require any further information,please contact me at 265-6450 or Travis.T.Smith@conocophillips.com. Sincerely, ,./7/K Travis Smith Wells Engineer ConocoPhillips Drilling&Wells 1C-178 Rig Workover Pull and Replace Tie-Back Liner and Upsize Tubing (PTD# 203-041) Current Status: The well is currently shut in with a leak in the tie-back liner. Scope of Work: Pull the existing 2-7/8" tubing, pull the existing 5-'/2" tie-back liner, run a new 5-V2" thermoplastic- lined tie-back liner,and run new 2-7/8"tubing. General Well info: MPSP: 785 psig(using 0.1 psi/ft gas gradient from reservoir to surface) Reservoir pressure/TVD: West Sak D—1,143 psi/3,583' TVD (6.1 ppg EMW)measured 10/11/2014. Wellhead type/pressure rating: Vetco Gray Horizontal Tree,5M Nabors#7ES BOP Configuration: Annular/Variable Pipe Ram /Blind Rams/Mud Cross/5 '/2"Pipe Ram MIT results: CMIT IAxOA—Passed 10/13/2014 MIT-IA—Failed 10/12/2014 Well Type: Producer Estimated Start Date: May 5,2015 Production Engineer: David Lagerlef/David Haakinson Workover Engineer: Travis Smith(265-6450/Travis.T.Smith@conocophillips.corn) Pre-Rig Work: 1. RU Slickline: Pull Jet Pump. Measure SBHP. Set BPV. RWO Procedure: 1. MIRU. Pull BPV.No-flow test. Circulate workover fluid as needed. 2. Install TWC. PT TWC from above. ND tree. NU BOPE. PT BOPE to 3,000 psig. Remove TWC. No-flow test. 3. BOLDS for tubing hanger. Pull tubing out of seal bore. If tubing does not pull:RU E-line,cut tubing above seals,RD E-line,and pull tubing out of seal bore. No-flow test. POOH laying down 2-7/8"tubing. 4. Reverse circulate to clean up the well. BOLDS for casing hanger. Pull 5-'/2"liner out of liner tie-back sleeve. No-flow test. POOH laying down liner. 5. MU new 5-V2"liner(with thermoplastic internal lining)and RIH to liner tie-back sleeve. Engage and space out liner.PU out of the tie-back sleeve. Freeze protect and corrosion inhibit the OA while stripping in the liner. Land tie-back liner mandrel. RILDS. 6. Drop ball and rod. PT the tie-back liner. PT the OA. 7. MU new 2-7A"tubing completion and RIH to the seal bore. Engage the seal bore and space out. PU out of seal bore. Corrosion inhibit and freeze protect the tubing and IA. Allow the tubing and IA to equalize. Land the tubing hanger.RILDS. 8. PT the tubing. PT the IA. No-flow test. 9. Set TWC. PT TWC from above. ND BOPE. NU tree. PT tree and packoffs. Pull the TWC. Set BPV. RDMO. Post-Rig Work: 1. Pull BPV. Open upper CMU. Run jet pump. Reset well houses and flow lines. Turn over to Operations. ' f KUP PROD 1C-178 ConocoPhillips Well Attributes Max Angle&MD TD • Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm((KB) Alaska,Inc. Ccmrolid- 500292314400 WEST SAK PROD 92.00 11,208.01 13,280.0 • ••• Comment H29(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-176,8/24/20149.17:11 AM SSSV:NIPPLE Last WO: 4/27/2009 34.31 5272003 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:Reset Jet Pump/Slipstop,Cycle hipshkf 8242014 .........................................................- Sliding Sleeve Casing Strings HANGER;26.9- 1'lip I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread p99 4 CONDUCTOR 16 15.062 34.3 110.0 110.0 62.50 H-40 WELDED `I6;ao" � Casing Description OD(in) ID(in) Top(ttKB) Set Depth(ftKB) Set Depth(ND)...WtILen(I...Grade ,Top Thread SURFACE 75/8 6.875 28.3 7,733.3 3,770.4 2970 L-80 BTCM 1I II Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I.,,Grade 'Top Thread 5.5"WO INNER CSG 5 12 4.950 27.0 7,077.0 3,622.0 15.50 L80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(L..Grade Top Thread ^■II� 8-SAND Slotted Liner 4 1/2 3.958 7,401.5 13,243.8 3,809.9 12.60 L-80 SLHT Liner Details ./� Nominal ID CONDUCTOR;34.3.110.0 Top(ftKB) Top(TVD)(MB) Top Incl C) Item Des Com (in) 7,401.5 3,713.7 75.41 SLEEVE BAKER HR SLEEVE w/EXTENSION - 5.010 NIPPLE;494.9 lel 7,414.2 3,716.9 75.65 BUSHING BAKER BUSHING 4.950 • 7,415.9 3,717.3 75.69 NIPPLE BAKER RS NIPPLE 4.875 GAS LIFT;4,006.9 a..: 7,418.7 3,718.0 75.74 HANGER BAKER FLEX LOCK HYDRUALIC ROTATING 4.830 al 7,491.8 LINER HANGER 7,428.1 3,720.3 75.92 XO Reducing CROSSOVER 5.5"x 4.5" 3.940 7,491.8 3,735.1 77.16 LOCATOR BAKER LOCATOR SUB 3.510 GAS LIFT;6,893.1 a; 13,209.5 3,809.4 89.35 XO Reducing CROSSOVER 4.5"x 4" 4.000 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(IN/tt) Grade Top Connection TUBING WO 27/8 2.441 26.9 7,002.8 3,597.4 6.50 L80 EUE 8RD SLIPSTOP;6,9450 Completion Details Centralizer;6,945.4 'it! Nominal ID JET PUMP;6,946.0 Top(ftKB) Top(ND)(ftKB) Top Incl(°I Item Des Com (in) SLEEVE-0;6,946.3' �• 26.9 26.9 0.00 HANGER CWCT-F6H 10.75"x4.5"TUBING HANGER 4.500 6 Centralizer. . 6,950.1494.9 494.6 4.89 NIPPLE CAMCO DS NIPPLE 2.312 118• 6,945.4 3,578.3 70.69 Centralizer FLUTED WIRE PROTECTOR SUB 2.500 El II 6,946.3 3,578.6 70.69 SLEEVE-0 CMU SLIDING SLEEVE w/D PROFILE-OPEN 2.250 r 8232014 GAUGE;6.9654 6,950.1 3,579.9 70.68 Centralizer FLUTED WIRE PROTECTOR SUB 2.500 I. 6,956.9 3,582.1 70.66 XO Enlarging CROSSOVER 2.875"x 3.5" 2.420 6,965.4 3,585.0 70.63 GAUGE ZIEBEL GAUGE CARRIER 2.800 6,982.5 3,590.7 70.58 SEAL ASSY SEAL ASSEMBLY w/LOCATOR(19.49'SEAL ASSY) 2.980 SEAL ASSY;6.982.5 Tubing Description String Ma...ID(in) Top(ftKB) [Set Depth(ft..Set Depth(TVD)(...Wt(Ibi t) Grade Top ComecOon TUBING-Original 4 1/2 3.958 7,055.81 7,335.6 3,696.9 12.60 L-80 IBTM al Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Corn (In) 7,055.8 3,615.1 70.79 PBR BAKER PBR-SBR 8 SEAL ASSY RUN ON 4/22/2009 3.875 WORKOVER 5.5"PRODUCTION CSG STABBED INTO PBR • 7,086.2 3,625.0 71.14 PACKER BAKER S-3 PACKER 3.875 7,091.8 3,626.8 71.20 XO Enlarging CROSSOVER 4.5"x 5" 5.500 PBR;7,055.9 rail 7,098.3 3,628.9 71.28 XO Reducing CROSSOVER 5"x 4.5" 4.500 5.5•WO INNER CSG;27.0- a 7,108.6 3,632.2 71.40 NIPPLE CAMCO'DB'NIPPLE w/NO GO PROFILE 3.750 7,077.0itt 7,334.6 3,696.6 74.99 WLEG WIRELINE ENTRY GUIDE 3.960 PACKER;7,0e62 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Ili Top(ND) Top Incl Top MKS) (ttKB) (°) Des Com Run Date ID(in) 1111 6,945.0 3,578.2 70.69 SLIPSTOP 2.5"SLIPSTOP 8/23/2014 lil 6,946.0 3,578.5 70.69 JET PUMP 2.25"C-LOCK ON 2"RC JET PUMP(SIN:CP-1165. 8/23/2014 ' 12A RATIO,OAL=51") NIPPLE,7,106.6 Perforations&Slots Shot Dens WLEG,73346 Top(ND) Btm(TVD) (shots/f Top(flKB) Btm(ftKB) TVD) (ftKB) Zone Date t) Type Com 7,704.0 13,179.0 3,767.7 3,809.2 WS B,WS B, 4/16/2003 12.0'IPERF Akernating slotted/blank WSC,1C-178 pipe-30'joints w/8 holes/ft.25"x2.5"/slotted i joint IBI Mandrel Inserts I.I.' a6 1 _ 11 I. On Top(TVD) Valve Latch Port Size TRO Run o 11 1111 No Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date in I Vii, 1 4,005.9 2,497.8 Camco KBMG- 1 GAS LIFT DMY BK-5 0.000- 0.0 4/22/2009 I a.[1 2 6,893.1 3,061.0 Camco KBMG- 1'GAS LIFT DMY BK-5 0.000 0.0 4/22/2009 .Iiii Notes:General&Safety IEnd Date Annotation "=1,;i 4/29/2003 NOTE:MULTILATERAL WELL-1C-178(B/C-SANDS),1C-178L1(D-SAND) IPERF;7,413.0-13,493.0 220/2008 NOTE:Surface CSG Patch,OAL=6'11",Mtls:0.500 wall X65,0.365 wl(see 2/20/09 WSR) 4/27/2009 -NOTE:WORKOVER INCLUDED SETTING 5.5"INNER CSG STRING&NEW TUBING COMPLETION SURFACE;28.3-7,733.3 1_ 4/27/2009 NOTE:WORKOVER INCLUDED SETTING 5.5"INNER CSG STRING 8 NEW TUBING COMPLETION D-SAND Slotted Liner;7,356.2- ■ 427/2009 'NOTE:View Schematic w/Alaska Schematic9.0 13,579.8 IPERF;7,704.0-13,179.0 B-SAND Slotted Liner;7,401.5- 13,243.8 Image ~ ,bject Well History File Ct,Jer Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. :;;;¿ Q "3 - O!J-l Well History File Identifier Organizing (done) o Two-sided 11I111111I111I11111 D Rescan Needed I RESCAN DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Color Items: D Greyscale Items: D Diskettes, No. D Other, NolType: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: o Logs of various kinds: NOTES: BY: Helen ~ D Other:: Date: 1/6/05 I Date: 7 Z t) ~5 /s/ r11f Project Proofing BY: Helen ~ Is! V\1-.0 Scanning Preparation ", ,.../., x 30 = {¿,D . + t L~ = TOTAL PAGES Z~-3 (Count d1 nolinclude cover s eet) IAA :J Date: 7 5' os- Is/ V VJ I I BY: Helen ~ Production Scanning Stage 1 Page Count from Scanned File: 7l/- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES NO Helen <: Mana J Date: 1/ S- / aç- Isl n1 J If NO in stage 1 page(s) discrepancies were found: YES NO BY: Stage 1 BY: Helen Maria Date: Isl 111111111111111111I 1111111111111111111 I Date: 15/ Quality Checked 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: • • WELL LOG TRANSMITTAL PROACTIVE DIAGNOSTIC SERVICES, INC_ To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2 - 1 900 Benson Blvd. Anchorage, Alaska 99508 and M u t 2 3 1U ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C t6 ''� _0 / - 3 Anchorage, AK 99518 Fax: (907) 245 -8952 003 -oqi ao9A// , o F 1 - ) Caliper Report 19- Apr -11 1 0-178 1 Report / EDE 50 -029- 2314) Caliper Report 23-Apr-11 3M -13 1 Report 2 f 0 Signed : _ . Date Print Name: =zr1 t.3 : PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 Fax: (907)245 -88952 E- MAIL: p'.£i5anci '@o'' iie .v',vrri WEBSRE: v'i v.rstem, orslocl.momrt C:\Documents and Settings \Diane Williams\Desktop\BP_Transmit docx I • • I Memory Multi- Finger Caliper • Log Results Summary 1 Company: ConocoPhillips Alaska, Inc. Well: 1C -178 Log Date: April 19, 2011 Field: Kuparuk (West Sak) I Log No.: 6299 State: Alaska Run No.: 4 (2 MIT) API No.: 50- 029 - 23144-00 Pipet Desc.: 2.875 in. 6.5 lb. L -80 8rd EUE Top Log Intvl.: Surface Pipet Use: Tubing Bot. Log Intvl.: 6,942 Ft. (MD) I Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : I This caliper data is tied into the top of the GLM 2 at 6,893 feet (Driller's Depth). This log was run to assess the condition of the 2.875 inch tubing with respect to corrosive and mechanical I damage. The 2.875 inch tubing logged appears to be in good condition with respect to internal corrosive and I mechanical damage, with no significant wall penetrations, areas of cross - sectional wall loss or I.D. restrictions recorded throughout the 2.875 inch tubing logged. This is the second time a PDS caliper has been run in this well and the first time this 2.875 inch tubing has I been logged. MAXIMUM RECORDED WALL PENETRATIONS : I No significant wall penetrations (> 12 %) are recorded throughout the 2.875 inch tubing logged. MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS : I No significant areas of cross - sectional wall loss (> 6 %) are recorded throughout the 2.875 inch tubing logged. MAXIMUM RECORDED ID RESTRICTIONS : I No significant I.D. restrictions are recorded throughout the 2.875 inch tubing logged. I I I I Field Engineer: D. Cain Analyst: HY. Yang Witness: C. Fitzpatrick I I ProActive Diagnostic Services, Inc. / P.C. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS @amemorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 063 -O <// OefY0 I • • Correlation of Recorded Damage to Borehole Profile I lie Pipe 1 2.875 in (7.1' - 6937.9') Well: 1C-178 Field: Kuparuk (West Sak) I Company: Country: ConocoPhillips Alaska, Inc. USA Survey Date: April 19, 2011 I I ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 7 I 3 25 4. 768 50 1 1551 I 75 2331 I I 100 p a 3114 v t c Z t III GLM 1 e- 125 �. 3899 a I 150 4711 J I 175 I 5498 I. 1 I 200 1 N 6284 I GLM 2 219.1 6938 0 50 100 I Damage Profile (% wall) / Tool Deviation (degrees) I Bottom of Survey = 219.1 I I I • • I PDS Report Overview alW3S Body Region Analysis I Well: 1C-178 Survey Date: April 19, 2011 Field: Kuparuk (West Sak) Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 2.875 ins 6.5 ppf L -80 EUE 8rd Analyst: HY. Yang Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 2.875 ins 6.5 ppf L -80 EUE 8rd 2.441 ins 2.875 ins 6.0 ins 6.0 ins I Penetration(% wall) D amage Profile (% wall) om 250 Penetration body mon Metal loss body 0 50 100 200 1 I 150 A 100 I 50 4 0 49 I 0 to 20% 20 to 40% 40 to 85% over I 85% Number of joints analysed (total = 226) I 226 0 0 0 A 99 1 I Damage Configuration ( body) A GLM 1 AI I 1474 I Isolated General Line Other Hole/ 197 Pitting Corrosion Corrosion Damage Pos. Hole Al Number of joints damaged (total = 0) GLM 2 I I 0 0 0 0 0 Bottom of Survey = 219.1 I I I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 2.875 in 6.5 ppf L -80 EUE 8rd Well: 1C-178 Body Wall: 0.217 in Field: Kuparuk (West Sak) I Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: April 19, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I i 7 0.03 0.02 10 1 2.42 1.1 40 0.03 0.02 9 4 2.43 Pup 1.2 42 0 0.02 8 3 2.41 Pup 2 45 0 0.02 8 2 2.41 3 76 0 0.01 6 1 2.42 4 108 0.04 0.01 7 1 2.43 5 140 0.03 0.02 10 2 2.43 6 172 0.03 0.02 10 3 2.42 7 203 0 0.02 7 1 2.42 I 8 235 0.03 0.02 9 3 2.42 9 267 0.03 0.02 10 2 2.42 10 299 0 0.02 8 3 2.42 11 331 0.03 0.03 , 12 4 2.41 I 12 362 0.03 0.03 12 2 2.42 13 393 0.03 0.02 9 2 2.40 14 424 0 0.02 9 2 2.40 15 453 0 0.02 7 2 2.42 I 15.1 485 0 0 0 0 2.31 Camco DS Nipple 16 486 0.03 0.02 10 2 2.40 17 518 0.03 0.02 7 2 2.42 18 549 0 0.02 9 2 2.42 19 581 0 0.02 9 2 2.42 I 20 613 0 0.02 9 2 2.41 21 642 0 0.02 7 2 2.43 22 674 0 0.02 7 I 2.40 23 705 0 0.02 8 2 2.41 I 24 737 0 0.03 12 3 2.40 25 768 0.03 0.03 12 1 2.43 26 800 0.03 0.02 10 3 2.40 27 832 0.03 0.02 10 3 2.41 I 28 864 0 0.02 9 2 2.43 29 895 0.03 0.02 10 4 2.39 30 927 0 0.02 9 2 2.41 31 959 0 0.02 8 2 2.41 32 990 0.03 0.02 8 2 2.40 I 33 1022 0 0.02 8 2 2.41 34 1052 0.03 0.03 12 5 2.38 35 1084 0.03 0.02 7 3 2.41 36 1115 0 0.02 11 4 2.41 I 37 1146 0.03 0.02 9 5 2.41 38 1177 0 0.01 6 1 2.42 39 1208 0 0.01 7 2 2.42 40 1237 0 0.01 7 1 2.42 I 41 1269 0.03 0.01 7 2 2.42 42 1301 0 0.01 7 2 2.42 43 1333 0.03 0.02 10 2 2.42 44 1364 0.03 0.02 9 4 2.41 I 45 1396 0 0.01 7 2 2.38 46 1426 0 0.02 9 1 2.41 47 1458 0 0.02 9 3 2.40 t I Metal Loss ion Body I Page 1 Penetra I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 2.875 in 6.5 ppf L -80 EUE 8rd Well: 1C-178 Body Wall: 0.217 in Field: Kuparuk (West Sak) I Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: April 19, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 48 1489 0 0.01 6 1 2.40 49 1520 0.03 0.03 12 2 2.41 ■ 50 1551 0.03 0.02 9 1 2.41 ■ 51 1583 0 0.02 10 2 2.41 • 52 1615 0 0.02 10 2 2.41 U 53 1646 0.04 0.02 11 2 2.41 54 1678 0 0.01 5 1 2.43 55 1710 0 0.02 8 3 2.42 56 1741 0.03 0.02 9 4 2.41 I 57 1771 0 0.01 6 1 2.43 58 1802 0.03 0.01 6 2 2.40 59 1833 0 0.01 7 1 2.41 60 1865 0 0.01 6 1 2.43 I 61 1895 U 0.01 7 2 2.40 62 1927 U.03 0.01 7 2 2.39 63 1959 0 0.01 7 3 2.40 64 1990 0.03 0.02 8 3 2.41 I 65 2021 0.03 0.01 7 1 2.41 66 2052 0 0.02 7 2 2.41 67 2082 0 0.01 7 1 2.40 68 2113 0 0.01 6 1 2.41 69 2145 0 0.02 8 2 2.39 I 70 2176 0.03 0.01 7 1 2.40 71 2207 0 0.01 7 2 2.40 72 2238 0 0.02 7 2 2.40 73 2270 0 0.02 8 2 2.39 I 74 2300 0 0.02 8 2 2.40 75 2331 0 0.01 6 3 2.39 76 2363 0 0.02 9 4 2.39 77 2394 0 0.01 7 1 2.41 I 78 2425 0 0.02 8 1 2.41 79 2456 0.03 0.02 10 3 2.40 80 2484 0 0.01 7 1 2.39 81 2516 0.03 0.02 10 I 2.40 82 2 548 0 0.02 9 1 2.41 I 83 2579 0.03 0.02 11 5 2.40 ■ 84 2611 0.03 0.03 12 1 2.38 85 2643 0.03 0.02 8 2 2.39 86 2674 0.03 0.02 8 2 2.40 I 87 2706 0 0.01 7 3 2.41 88 2738 0.03 0.02 9 2 2.40 89 2768 0 0.02 8 1 2.40 90 2800 0.03 0.03 12 2 2.40 I 91 2832 0 0.02 8 1 2.41 92 2864 0 0.01 7 2 2.41 93 2895 0 0.01 6 1 2.40 94 2927 0 0.02 8 2 2.40 95 2958 0 0.02 9 2 2.40 I 96 2989 0.03 0.03 12 2 2.38 97 3021 0 0.01 7 1 2.39 Penetration Body I I Metal Loss Body Page 2 I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 2.875 in 6.5 ppf L -80 EUE 8rd Well: 1C-178 Body Wall: 0.217 in Field: Kuparuk (West Sak) I Upset Wall: 0.217 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in USA Survey Date: April 19, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 98 3051 0 0.01 7 2 2.37 99 3082 0 0.02 7 2 2.40 100 3114 0.03 0.02 11 4 2.40 y, • 101 3146 0 0.01 7 4 2.41 0 102 3177 0 0.01 6 1 2.41 I 103 3209 0 0.01 7 3 2.40 104 3241 0.03 0.02 10 2 2.40 105 3272 0.03 0.02 9 3 2.38 106 3304 0 0.02 7 2 2.38 I 107 3335 0.03 0.02 8 3 2.39 108 3367 0.03 0.01 6 1 2.40 109 3399 0.03 0.02 11 1 2.39 110 3431 0 0.01 7 3 2.40 I 111 3462 0.03 0.03 12 2 2.40 112 3493 0 0.01 6 2 2.39 113 3525 0 0.02 11 3 2.40 114 3556 0 0.01 6 1 2.41 115 3587 0.03 0.02 11 4 2.40 116 3617 0.03 0.01 6 1 2.41 117 3648 0.03 0.02 10 2 2.38 118 3680 0 0.02 8 3 2.39 119 3711 0 0.02 10 2 2.40 I 120 3742 0 0.01 6 2 2.39 121 3772 0 0.01 6 2 2.40 122 3804 0 0.02 8 2 2.36 123 3835 0 0.02 9 I 2.38 1 124 3867 0 0.01 5 1 2.39 125 3899 0.03 0.01 7 1 2.39 126 3930 0 0.01 6 2 2.40 127 3962 0 0.02 11 5 2.38 I 127.1 3993 0 0.01 5 2 2.38 Pup 127.2 4002 0 0 0 0 2.33 GLM 1 (Latch @ 6:30) 127.3 4008 0.03 0.01 7 1 2.39 Pup 128 4016 0 0.01 7 2 2.39 129 4048 0.04 0.02 11 3 2.36 I 130 4079 0.03 0.02 8 1 2.39 131 4111 0.03 0.02 7 3 2.39 132 4142 0.03 0.01 6 1 2.39 133 4174 0.04 0.03 12 3 2.38 I 134 4206 0 0.01 6 2 2.39 135 4238 0.03 0.02 7 2 2.39 136 4270 0.03 0.02 8 2 2.40 137 4302 0 0.02 7 1 2.40 I 138 4333 0.03 0.01 7 3 2.40 139 4364 0.03 0.02 10 3 2.38 140 4396 0.04 0.01 7 2 2.39 141 4428 0 0.02 11 3 2.38 142 4460 0 0.02 7 2 2.39 I 143 4491 0 0.01 6 1 2.38 144 4523 0 0.02 9 2 2.39 rat I Metal Loss ion Body Page 3 Penet I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 2.875 in 6.5 ppf L -80 EUE 8rd Well: 1C-178 Body Wall: 0.217 in Field: Kuparuk (West Sak) I Upset Wall: 0.217 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in USA Survey Date: April 19, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % I c st I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 145 4554 0.03 0.02 8 1 2.38 146 4585 0 0.02 7 2 2.40 147 4616 0 0.02 7 1 2.40 148 4648 0.03 0.01 6 1 2.39 149 4679 0 0.01 5 1 2.41 . I 150 4711 0 0.02 7 1 2.39 151 4742 0.03 0.02 9 4 2.38 152 4772 0 0.03 12 5 2.38 153 4804 0.04 0.03 12 6 2.39 I 154 4836 0 0.02 8 4 2.39 155 4867 0 0.02 8 1 2.38 156 4899 0.03 0.02 10 4 2.39 157 4930 0 0.01 6 1 2.40 I 158 4960 159 4992 0 0.01 6 1 2.38 0 0.02 8 2 2.39 160 5024 0.04 0.03 12 2 2.38 161 5055 0.04 0.02 9 2 2.38 I 162 5087 0.03 0.02 11 2 2.37 163 5118 0.03 0.02 11 2 2.37 164 5151 0 0.03 12 2 2.38 165 5182 0.03 0.02 9 5 2.38 166 5214 0 0.02 8 5 2.39 I 167 5245 0 0.03 12 5 2.39 168 5276 0.03 0.02 8 2 2.39 169 5308 0 0.01 7 2 2.39 170 5339 0 0.02 10 1 2.37 I 171 5371 172 5402 0 0.01 6 1 2.41 0 0.02 11 2 2.37 173 5434 0.03 0.03 12 1 2.35 174 5466 0.03 0.02 8 1 2.40 I 175 5498 176 5529 0 0.02 8 1 2.41 0 0.02 8 5 2.38 177 5560 0.03 0.02 9 1 2.39 178 5592 0 0.02 11 4 2.38 179 5624 0 0.02 8 1 2.40 I 180 5656 0 0.02 8 2 2.38 181 5687 0 0.03 12 5 2.38 182 5719 0 0.02 8 1 2.38 183 5750 0.03 0.02 9 1 2.40 I 184 5782 0.03 0.03 12 1 2.39 185 5814 0 0.01 6 2 2.40 186 5845 0.03 0.02 11 5 2.38 187 5876 0 0.01 7 1 2.39 I 188 5907 0 0.01 6 I 2.40 189 5938 0.03 0.02 10 5 2.38 190 5969 0 0.01 6 1 2.41 191 6000 0.03 0.02 9 1 2.39 I 192 6032 0 0.02 , 8 3 2.38 193 6064 0 0.03 12 5 2.36 194 6094 0.03 0.03 12 6 2.35 r Penetration Body I Metal Loss Body Page 4 I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 2.875 in 6.5 ppf L -80 EUE 8rd Well: 1C-178 Body Wall: 0.217 in Field: Kuparuk (West Sak) Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA I ' Survey Date: April 19, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) °ice (Ins.) 0 50 100 I 195 6126 0.03 0.03 12 5 , 2.38 196 6158 0 0.01 5 1 2.38 197 6189 0.03 0.01 7 1 2.39 198 6221 0.03 0.02 8 2 2.38 199 6253 0 0.02 8 1 2.39 I 200 6284 0 0.02 9 3 2.39 201 6315 0.03 0.02 11 5 2.38 202 6347 0 0.02 8 2 2.37 203 6379 0 0.01 6 1 2.38 I 204 6410 205 6442 0 0.01 6 3 2.40 0 0.01 6 1 2.40 206 6473 0.03 0.02 10 4 2.39 207 6505 0 0.01 6 1 2.39 1 208 6536 0 0.02 8 2 2.38 209 6568 0.03 0.02 7 1 2.37 210 6599 0 0.02 10 1 2.39 211 6630 0.03 0.03 12 4 2.38 I 212 6662 0 0.01 6 1 2.40 213 6693 0 0.02 8 1 2.40 214 6725 0.04 0.02 11 2 2.39 215 6757 0 0.01 5 1 2.40 216 6788 0.03 0.01 6 1 2.40 I 217 6820 0.03 0.01 7 1 2.39 218 6851 0 0.02 8 2 2.39 218.1 6883 0 0.01 6 2 2.38 Pup 218.2 6893 0 0 0 0 2.31 GLM 2 (Latch @ 9:00) I 218.3 6899 0.03 0.01 6 2 2.39 Pup 219 6907 0 0.01 6 2 2.40 II 219.1 6938 0 0.02 10 6 2.37 Pup r Penetration Body II Metal Loss Body I I I 1 I Page 5 I KUP 1C -178 ConocoPhillips ' S Attributes ogle & MD T _ Wdlbore APIlUWI Field Name Well Stabs Ind (°) ND (RKB) Act Btm (Po(B) tnrlemn>itpa 500292314400 WESTSAK PROD 92.00 11,208.01 13,280.0 1 ""'" Comment H2S (ppm) Date Annotation End Date KB (R) Rig Release Date SSSV: NIPPLE 80 7/10/2009 Last WO: 4/27/2009 34.31 5/27/2003 well Confo. - 1C-178 4/2/2011 2 46 46 PM schematic- Aa�rel Annotation Depth (RKB) End Date Amo Last Nbtl End Date By Last Tag: Rev Reason: RESET JET PUMP Imosbor 10/11/2010 Casing Strings r Casing Description Slang 0... String ID ... Top (11KB) Set Depth (f... Set Depth (ND) ... Slang Wt.. String... String Top Thrd HANGER, 27 CONDUCTOR 16 15.062 34.3 110.0 110.0 62.50 H - 40 WELDED I t, _ Casing Description String 0... StrI g ID ._ Top (RI(13) Set Depth (f... Set Depth (ND) ... String Wt... String... String Top Thrd SURFACE 7 5/8 6.875 28.3 7,733.3 3,769.9 29.70 L BTCM Casing Description String 0... Sting ID ... Top (RIB) Set Depth (f... Set Depth (7VD)... Slang Wt... String... Slang Top med PRODUCTION 51/2 4.950 27.0 7,077.0 3,621.9 15.50 L80 BTCM Casing Description String 0... String ID ... Top (RIB) Set Depth (f... Set Depth (TVD) ... String Wt... String... Suing Top T B-SAND Sl otte d 41/2 3.958 7,401.5 13,243.8 3,809.9 12.60 L-80 SLHT Liner Liner De tails CONDUCTOR, Top Dep th 34 -110 (ND) Top 1114 NOmI._ NIPPLE, 495 Top (MB) (RKB) 0 Rem Description Comment ID (hi) 7,401.5 3,713.7 75.41 SLEEVE BAKER HR SLEEVE w /EXTENSION 5.010 ' 7,414.2 3,716.8 75.65 BUSHING BAKER BUSHING 4.950 GAS LIFT. 7,415.9 3,717.3 75.69 NIPPLE BAKER RS NIPPLE 4.875 a,00fi 7,418.7 3,717.9 75.74 HANGER BAKER FLEX LOCK HYDRUALIC ROTATING LINER HANGER 4.830 7,428.1 3,720.2 75.92 XO 5.5x4.5 3.940 7,491.8 3,735.1 77.16 LOCATOR BAKER LOCATOR SUB 3.510 1 GAS LIFT. 6,893 13,209.5 3,809.4 89.08 X04.5x4 4.000 Tubing Strings Tubing Description Slang 0... String ID ... Top (RIB) Set Depth (1 /.. Set Depth (1VD) ... Slang Wt.. Slang... Shang Top Thor Contralaer, TUBING 27/8 2.441 26.9 7,002.8 3,597.3 6.50 L80 EUE 8RD 6.945 JET PUMP. Completion Details 6,946 Top Depth SLEEVE- (ND) Top Intl Nani... 6,946 T M B) r Re m Descri on Comment ID (In) Centrelaer, Top (MB) pti 6.950 26.9 26.9 -0.57 HANGER Tubing Hanger CWCT -F6H 10 -3/4" x4 -1/2" 4.500 494.9 494.6 4.89 NIPPLE 2.312" Camco "DS" Nipple 2.312 ' 6,945.4 3,577.0 69.50 Centralizer Fluted Wire Protector Sub 2.500 6,946.3 3,577.3 69.51 SLEEVE -O "CMU" Sliding Sleeve w/D PROFILE - OPENED 6/3/2009 2.250 GAUGE, s ass 6,950.1 3,578.7 69.56 Centralizer Fluted Wire Protector Sub 2.500 6,956.9 3,581.1 69.64 XO - Enlarging X-Over 2 -7/8" 8RD EUE box x 3 -1 /2" 8RD EUE pin 2.420 6,965.4 3,584.2 I 69.74 GAUGE Ziebel Gauge Carrier w/ Gauge i 6,982.5 3,590.3 69.94 S ASSY Seal Assembly w/ Locator (19_49' seal assembly 2.980 SEAL ASSY, T ull Description Shin O._ lad ID ... Top RKB Set Depth (I... Set Depth ND) ... String Wt.. String String Top Thrd 6.963 n9 9 n9 oP ( ) R+t ( tm9 ^9 9 P TUBING - Original 41/2 3.958 7,055.9 7,335.6 3,695.7 12.60 L -80 IBTM Completion Details Top Depth I (ND) Top Intl Na (hi) Top INBI RKN (') am scriptl an Comment 4.500 6n) 7,055.9 3,615.0 70.79 PBR BAKER PBR - SBR & SEAL ASSY RUN ON 4/22/2009 WORKOVER 3.875 5.5" PRODUCTION CSG STABBED INTO PBR 7,086.2 3,624.9 71.14 PACKER 7,108.6 3,632.2 71.40 NIPPLE BAKER S-3 PACKER 3.875 CAMCO 'DB' NIPPLE w /NO GO PROFILE 3.750 I PBR. 7.056 7,334.6 3,695.4 74.11 WLEG WIRELINE ENTRY GUIDE 3.960 PRODUCr10N, Other In H ole / reline retrievable plugs, valves, pumps, fish, etc 27 -):V7 Top Depth PACKER, 7,086 (TVD) Top Intl Tap (R(B) I ( °) Desorption Canmeli Rum Date ND (in) 6,946.0 3 .577.2 6 9. 5 1 JET PUMP 2" RC JET PUMP (CP -1160, 12-A RATIO, #12 NOZZLE, 10/10/2010 0.000 I #12 THROAT, 50.75" OAL) 2" C -LOCK (PUMP TAKES MODIFIED FLOWTUBE) Perforations & Slots Sh NIPPLE. 7,109 Top ( ND) Bain CND) D enn I Top MKS) son (MB) IRKS) IRKS) zone Date (nh type Comment 7,704.0 13,179.0 3,767.7 3,809.2 WS B, WS B, 4/16/2003 12.0 IPERF Altematiig slotted/blank pipe -30' WLEG. 7.335 WSC, 1C -178 joints w/8 holes/ft .25 "x2.5" /slotted joim Notes: General & Safety End Dale Annotation I ' ' 4/29/2003 NOTE MULTILATERAL WELL -1C -178 ( B/CSANDS), 1C -178L1 (D-SAND) IR 22012008 NOTE: Surface CSG Patch, OAL= 6'11 ", Ms: 0.500 waN X65 , 0.365 wt (see 2/20/09 WSR) ■ 4/27/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 I SURFACE. - 28 -7,733 IPERF, 7,704-13,179 IPERF, II 7413 - 13.693 13493 - II B-SAND Slotted - ,44 7,401 2 C-I1 I TD (1 G128 3,280 0 D-SAND Slotted J J Liner. 7.356 -13580 Mandrel Details Top Depth Top Pon I .A i. (ND) Intl 00 Valve Latch Size 1RO Rum Stn Top (ro(B) (RKS) () Make Model (k Sery 1 YPe 1 YPe (In) (psi) Rim Date Cont. . 1 4,005.9 2,497.8 67.42 Camco KBMG-M 1 GAS LIFT DMY BK-S 0.000 0.0 4222009 2 6,893.1 3,560.9 70.55 Camco KBMG-M GAS LIFT DMY BK-5 0.000 0.0 4/22/2009 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS V 1. Operations Performed: Abandon ^ Repair Well ^ ~ Plug Perforations ^ Stimulate ^ ~~~~ ~ - 8 Alter Casing Q Pull Tubing Q . Perforate New Pool ^ Ant;h Waiver ^ Time Extension LJ- 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 ^ 203-041 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23144-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 8T r 1 C-178 8. Property Designation: 10. Field/Pool(s): ADL 25649 / 25638 Kuparuk River Field /West Sak Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 13280' feet true vertical 3811' , feet Plugs (measured) Effective Depth measured 13246' feet Junk (measured) true vertical 3810' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 110' 110' SURFACE 7705' 7-5/8" 7733' 3770' PROD. LINER 5817' 4-1/2" 13244' 3811' Tieback Liner 7044' 5-1/2" 7072' 3620' Perforation depth: Measured depth: 7704'-13179' ' ~f,~~,,~~~{ ~~l true vertical depth: 3767-3809 ° Tubing (size, grade, and measured depth) 2.875", L-80, 7003' MD. Packers & SSSV (type & measured depth) Baker Packer @ 7086' Camco'DS' landing nipple @ 495' 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 SI 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 Niq if C.O. Exempt: 309-119 contact Brett Packer @ 265-6845 Printed Name Bre~ker Title Wells Engineer ~~ 1/O ~ Signature '~ Phone: 265-6845 Date ` f Pre a b h ron Allsu Drake 263-4612 ~~ ~ ~ ~ ~~~ 1 ~ ~ZL" `~~ Form 10-404 Revised 04/2006. ~®~ ~ ~ t V /~ ~ Submit Original Only 1C-178 schematic • • Page 1 of 1 Maunder, Thomas E (DOA) From: Packer, Brett B [J.Brett.Packer@conocophillips.com] Sent: Wednesday, May 20, 2009 9:40 AM To: Maunder, Thomas E (DOA) Subject: 1 C-178 Multi-lateral Drawing Post-RWO (PTD#203-041) Attachments: Visio-FINAL 1C-178 SB DL WO-09.pdf Tom, I believe Sharon sent over the 10-404 for 1 C-178 yesterday, and after cleaning out my email today, I found this multi-lateral drawing to go with that, much better than my sketch. ,~ Brett Sacker ~DriR"ing ~'We[Cs 'WonE;gver Engineer 'Work# (907) 265-6845 CeIC# (907) 230-8377 5/21/2009 Tubing String 2-718" 6.5#, LAO, EUE 8rd Mod. 2.441" ID, 2.747" Dri/t 495' MD-2.312" DS Nipple 4006' MD -GLM. Camco 2-7/B" z 1" KBGM-M 6893' MD -GLM, Camco 2-7/8" X 1" KBGM-M Surtace -6982' MD, 5- ;" Casing. 15.Sp, 6945' MD -Fluted Wire Protector. 4.61" OD LAO. BTCM w/SCG ~ 6946' MD - CMU Sliding Sleeve, w/ 2.250" D Profile 6950' MD -Fluted Wire Protector, 4.61" OD 6965' MD -Ziebel Gauge Carrier 7003' MD -bottom of Seal Assembly 4.00" Seal OD 2.992" ID 6956' MD, Crossover 2-7/8" X 3-112"x''. / 6958' -6676' MD,Tubing 3-1/2" 9.3#, LAO 7072' MD -Bottom of Seal Assemoly 4.75" Seal OD 7.675" ID 6985' MD - SBE 4.00" ID, 5.50" OD, 20' long/ 7004' - 7048' MD,TUbing 4-1/2" 12.6#, LAO, IBTM , 7056' MD-PBR 3.875" ID, 5.50" OD 20' long 7096' MD -4-112" X 7SI8" S-7 5967' MD -Mill Out Extension 4.54" ID, S.Sd" OD 7756' MD - d-112" X 7SI8" Model 'B' HOOK Hanger 7109' MD - 7.79" OB Nipple ConocoPhillips West Sak 7-5/8" Injector 1 C-178 Dual Lateral Completion 1N0-09 'D' Sand Lateral As Completed sw~cER MUGXES Raker Oil Tools 7776' MD-Bottom of WLEG D-sand Window @ 7359' MD, 3703' TVD, 75° Inc 4-1/2" 12.6#, L-80, DWG, Slotted Liner ~/ / 7377 MD -liner Swivel, 4-1/12 13559' MD - 3-112" Bent Joint `~:- / \~`' ~='__ 13560' MD - 3-112" Guide Shoe TD ~ 13650' MD, 7785 TVD, 90° Inc 5-112" X 7SI8" ZXP ~ Liner Top Packer / with Hold Downs 5-112" X 7SI8" Flex Lock Liner Hanger Liner Hangerl Packer Assembly at ~ 7402' MD MD - 4-112" Eccentric Guide Shoe -- r iJ // T TD LID 13280' MD, 3810 TVD, 89° Inc 7-SIB" Casing Shoe, Set at ~ 7739' MD, 3773 TVD, 87° Inc 113210' MD - 4" Blank Liner with Y." weep hole BaRer Hughes 200]. This document may not 6e reproduced or distributed, In vhole or In part, In any brm or by any means Nectronlc or mechanical, including photocepying, recerding, or by any Informatlon sbrage antl rtM<val system now Imovm or hereafter Invented, ,a1NOU1 tsrlnen pertnlsslon from Baker Hughes Inc. toa]west saR rsrs°o°al Larerd c°mpiennn-mle<ror '. - to e- April 31. 240° ,., -ei - ..Ian r Y .,°i n. r -- .o.-H ..~-_ 'B' Sand Lateral 4-112" 12.6#, LAO, DWC Slotted / Liner • • ~` KU P • 1 C-178 Coi14COPIl1I{ip5 ` well Attributes Max Angle 8 MD ° TD ~riSr;i Wellbore API/UWI / Field Name (Well Status Intl ( ) MD (ftKB) Ad Btm (ftKB) 500292314400 ' WEST SAK PRODUCING 92.00 11,20801 13,280.0 Comment SSSV: NIPPLE i H2S (ppm) Date Annotation (End Date K8-Grtl (tt) 9Last WO. 34.31 0 60 2 Rig Release Dat 5/12003 ._ __ell COnfi~_ 1C~1Z. °4137/~ _. $rlt~legy,AClu Q095.4~32 AM al Annotation 'Dep Last Tag: 0 8 th (ftKB) End Date Annotation En Rev ~ I I ORKOVER tl Date 4/27/2009 Casing Strings _ Cas'ng Descript on String O String ID Top (ftKB) Sat Depth (f .Set Depth (ND) .. 'Str g W[.. ',Str ng Stnng Top Thrd - _ CONDUC TOR 16 15 062 30.0 110.0 110.0 - 62 50 H-40 WELDED Casing Description String O String ID ... Top (ftKB) Set Depth (f .Sat Depth (ND) .. (Str g Wt (String .. I String Top ThA SURFACE 7 5/8 6 875 28.3 7,733.3 3,769.9 29 70 L 80 BTCM HANGER. 2] ,, Cav ng Descrptron ~ String O (String ID .Top (ftKB) Set Depth (f .. Set Depth (TVD) .. -,Str ng Wt... (Str ng String Top ThA PRODUCTION ~` 51/2 4.950 26.0 7,077.0 3,621.9 15.50 L80 BTCM Casing Description ,String 0... (String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) .. String Wt... String ... String Top Thrd 6-SAND Slotted I 4 1/2 3.958 7,401.7 13,244.0 3,809.9 12.60 L-80 SHLT PATCH.>0 Liner . ,Tubing Strings ' .Tubing Description String 0... String ID ... Top (kK6) Set Depth (L.. Set Depth (ND) ... String Wt... String ._ .String Top Thrd TUBING 2 7/8 2441 I 26.9 I 7,002.8 - I 3.597.3 6.50 L80 EUE 8RD CONDUCTOR, ` ~ COmpletlOn Det - ails - 30-1 t0 L Top Depth j '~ NIPPLE 895 I (ND) Top Intl . Top (HKBj'~ (ftKB) (°) ' Item Description Comment ID (ir 26.9,1 26.91 -Q57.HANGER Tubing HangerCWCT-F6H 10-3/4"x4-12' ~~ 29.5 225 - - -0.SS~XO -Reducing X-Over 4-1/2" IBTM z 2-7/8" 8RD EUE- 2 M GAS LIFT. a,oo6 ~ 494.9 494.6 _ _-_._ 4.89 NIPPLE 2.312" Cameo "DS" Nipple 2.3' r 6,945.4 3,577.0 _ 69.50 Centralizer Flutetl Wire Protector Sub 2.5( 6,946.3 3,577.3 --_-_ 69.51 SLEEVE "CMU" Sliding Sleeve w/D PROFILE _. 2.2`. GAS LIFT. 6,950.1 3,578.7 69.56 Centralizer Fluted Wire Protector Sub 2. Sf 6,956.9 3,581.1 69.64 XO -Enlarging X-Over 2-7/8" SRD EUE box x 3-1/2" 8RD EUE pin 2.4: 6,965.4 3,584.2 - 69.74 GAUGE Ziebel Gauge Career w/ Gauge 6,982.5 3,590.3 69.94SEAL ASSY Seal Assembly w/ Locator (19.49'seal assembly 2.9E CenlreAZer, ~ Tubing Description String 0... String ID ... Top (ftKB) Set Dep[h (f... Set Depth (ND) ... String Wt... String ... String Top Thrd fi.9as TUBING-Original I 3695.7 12.60 L-80 41/2 3.958 I J,055.9 I 7,335.6 BTM SLEEVE, 6,966- Completion Det . . _. -. ails -.. cen,rau:er, 6 950 ~ ~~ To ih I~ _ _ _. -- , _, i (ND~ TOP Inc(; i,uoo.a o,olo.u~ ru.ro rorc 6.5'~PRODUCTION CSG STABBED INTO pgRcucwa v.vnr....r=~ ~, 7,086.2 i, 3,624.9 ii 71.14 PACKER BAKER S-3 PACKER GAUCE.6.96s- ~2-~ I~ 7, 108.6 3,632.2 71 401, NIPPLE CAMCO'DB' NIPPLE w/N0 GO PROFILE li 7,334.6 3,695.4 74.11WLEG WIRELINE ENTRY GUIDE - Other In Hole reline retrievable plugs, valves, pumps, fish, etc.) Top Depth ~ SEAL ASSV, 1 -~ 6.983 t--~ (TVD) ,Top Intl',. Top (kK8) (HKB) (°) Description Comment RunO -T 30 30.0'1 -0.54 PATCH ' 1 WELD 8" .500 upper wetlding band in no-go syle, 8" lower 2/20/20 0.500 wall X415 wedding band. Install 9 5/8" OD, L-80 casing (0.395" w[) Surface Casing patch that straddles surface casing collars. Total patch length from bottom of wellhead to lower most wedding band 6' 11" -set 2/20/2008 I 7.416 3,717.3 75.69 NIPPLE B/C-SAND BAKER RS NIPPLE 4/lti/"1003 4.8 /'. y 7,419 3,718.0 75.75 FIANGER B1C-SAND BAKER FLEX LOCK HYDRO ROTATING LINER 4/16/2003 4.83( PeR. ] 056 1 ~ HANGER :~ 7,428 3,720.1 75.92 XO B/C-SANDCROSSOVER T04.5" LINER 4/16/2003 3.94( PRODUCTION 2s-7,mi ~ 7,704 3,767.7 8426 LOCATOR BIC-SAND BAKER LOCATOR SUB 4/16/2003 351f PacKER. ],oas ~"'~ 13,242 3,809.9 89.08 SHOE B/C-SAND GUIDE SHOE 4" ROT SILVER BULLET 4/162003 3.95E _- -- W/ECCENTRIC NOTE (float tlnlled out) Perforations 8 Slots __ . snot --- Top (TVD) Btm (iVD)' Dens ~I ~ To ftKB Btm ftKB (kK8 ) Zone I Data lsh... Type Comment } I p7,704 13,179 3,767.7 3.809.21'WS B, WS B, 14/16/2003 12.0 IPERF ~ - --- - NIPPLE. 7,109- - ,.~1 6 I ~i,WSC, 1C-178 r Notes: General_& Safe Etta Dato Annotation _ -- .4/29/2003 NOTE MULTILATERAL WELL - 1C-178 (NiC-SANGS;, 1C-178L7 (D-SAND) PLUG. 7,135-.- - ^~ ___ _ _ _ 4/27/2009 ,NOTE: VIEW SCHEMATIC w/Alaska Schematic9_C WLEG, 7,335---- - MANGER.. I .......... .. .. ___ - - _- _- a --T'4R7 lass Mandrel Details f, - Top Depth Top ~ Port SLEEVE, 7A01 _ (TVD) Intl OD Valve latch Size TRO Run BUS'I04~ Stn Top (ftKB) (ftKB) (°) Make ~. Model (in) Serv TYPe Type tin) (psi) Run Date Cam... wPPLE.zns 1 4,005.9 2,497.867.42 Cameo !KBMG-M 1GAS LIFT 'DMY BK-5 0.000 004/22/2009 MANGER, ~\ ~ - p 6,893.11, 3,560.9 7(155 Cameo (KBMG-M 1 GAS LIFT (DMY IgK-5 00001 0.0 4/22/2009 %O. ],828 a I ~ I Linn, ],356-13.280 TD (1C-178), 13,280 ,I l +~ illy .,,; API: 500292314400 PTD: 203-041 Wellhead: Gray Horiz X-mas Tree: 4-1/8", 5K psi Lift Threads: 4.909" MCA BPV: 4" 'H' • Tubing = 2'/8', 6.5 ppf, L-80, 8rd EUE • 2.313" DS-nipple. • Baker 2%d' CMD w/ 2.25" D profile. . Ziebel Gauge. . 3'/" EUE SCC tubing. • Baker locator w/ 17' seal assy. . Casing = 5'/2',15.5 ppf, L-80, BTCM w/ SCC. • Crossover from 5'/2',15.5# BTCM. • 20' SBE. • Baker 80-40 Locator w/ 10' seal assy. (3.875" OD) Directional: Max Incline: 92° @ 11208' Max Dogleg: 8.7° @ 1505' 2009 RWO COMPLETION ~J Wel I: 1 C-178 Conductor: 16", 62.5#, H-40 at 110' Surface Casing: 7.625", 29.7#, L-80 to 7733' Tie-Back Liner: 5.5", 15.5#, L-80 BTCM to 7072' Slotted Liners: D-Sand: 4.5" to 13,579' B-Sand: 4.5" to 13,244' 2.25" D-profile sliding sleeve for jet pump at 6946' MD. Ziebel Downhole Gauge/Carrier at 6965' MD. Crossover to 5.5" BTCM. 20' SBE at 6984' MD. PBR at 7056' MD. ~- Baker S-3 Packer at 7.086'. Gas Lift Mandrels: MD TVD Tvpe 4006' 2498' 2-7/8" KBMG, 1" 6893' 3561' 2-7/8" KBMG, 1" Last Updated: 19-May-09 Updated by: JBP ummary ConocoPhillips Time Log & S u 1Net/view 1Mei7 Reparting Re po r i Well Name: 1C-178 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 4/17/2009 5:00:00 PM Rig Release: 4/23/2009 7:30:00 AM - - __ Time Logs - - __ _ - Date__ From To Dur __ S Depth E, Depth Phase Code Subcode T Comment __ _ __ 4/17/2009 2a hr Summary Move Nordic Rig 3 f/ 3K-35 to 1C-178. MIRU over 1C-178, accept rig, Berm up and set auxillary equipment. RU and Test Kill lines @ 250/3,000 psi. Kill well w/ 9.6 ppg Brine. Acce t Nordic Ri 3 onto 1C-178 at 17:00 on 4/17/09. 05:00 05:30 0.50 COMPZ RPCOM MOB P Drill site operator change out. 05:30 12:30 7.00 COMPZ RPCOM MOB P Moving rig from 3K-35 to 1C-178. 12:30 14:00 1.50 COMPZ RPCOM MOB P Stop at 1 R access road during fight arrival and de arture. 14:00 16:00 2.00 COMPZ RPCOM MOB P Move to 1C pad 16:00 20:30 4.50 COMPZ RPCOM RURD P Load Tree in cellar, MIRU and set down. Berm up and spot auxillary equipment. Acce t Nordic Rig 3 onto 1C-178 at 17:00 on 4/17/09. 20:30 21:00 0.50 COMPZ RPCOM OTHR P RU circ. lines f/ Well to Rig and to Kill Tank. 21:00 21:30 0.50 COMPZ RPCOM MPSP P PJSM, Lubricate out H-BPV. 21:30 00:00 2.50 COMPZ WELCTI CIRC P PJSM, Air check kill lines, Fill lines w/ 9.6 ppg and PT @ 250/3,000 psi. -Change out low torque valve @ tank. Re-test Kill line @ 250/3,000 psi.-No leaks. Open up well 10 psi on TBG and 490 si on IA. Begin pumping @ 4 bpm @ 60 psi w/ 9.6 ppg Brine down TBG w/ Full open Choke @ 160 psi. Pump 208 bbls before an fluid returns were seen. 4/18/2009 Continue to kill w/ 9.6 ppg Brine. Monitor well, Circ well back to rig pits. Monitor well. Set BPV, ND Tree and NU BOPE. Test BOPE 250/3,000 si. 00:00 02:00 2.00 COMPZ RPCOM CIRC P Continue to Circ another 200 bbls @ 5 bpm @ 60 psi. and 5 bpm @ 140 psi as 9.6 ppg KWF Surfaced. Pumped a total of 432 bbls, shutting down every 100 bbls and gauging the Kill Tank. 02:00 02:30 0.50 COMPZ WELCTt OWFF P Blow down Kill Tank Lines. Monitor well - 20 si on IA. 02:30 04:00 1.50 COMPZ WELCTL CIRC P CBU of 182 bbls. @ 2 bpm @ 80 psi and increase to 3 b m 130 si. 04:00 04:30 0.50 COMPZ WELCTI OWFF P Shut down and Monitor well. IA on vacum and TBG flowing as if out of balance. ~e®. ~® m~~~® Time Lomas - _ - - __ Date From To Dur S. De th E. De th Phase Code Subcode T Comment --_ 04:30 05:30 1.00 COMPZ WELCTI CIRC P Continue to Circ @ 2 bpm @ 60 psi taking returns to rig pits. Stage down slow) . 05:30 06:00 0.50 COMPZ WELCTL OWFF P Flow being observed up the tubing. 06:00 09:30 3.50 COMPZ WELCTL CIRC P Pump 20 bbl visc sweep, reverse circulate at 2 bpm @ 250 psi followed b hole volume of brine. 09:30 10:30 1.00 COMPZ WELCTL OWFF P Monitor well for flow. RD Circ lines and install BPV. 10:30 15:30 5.00 COMPZ RPCOM NUND P ND tree, instal- blanking plug. NU BOPE 15:30 00:00 8.50 COMPZ RPCOM PRTS P Pressure test BOPE 250/3000 psi. Test variables and annular with 2-7/8", 4-1/2"and 5-1/2" test 'oints. 4/19/2009 Continue to Test BOPE @ 250/3,000 psi. Unland hanger and Pull seals from PBR. POOH laying down 4 1/2 Decom letion. PU and MU 5 1/2 Inner Liner and Be in to RIH to 2,385'. 00:00 01:00 1.00 COMPZ WELCTL RGRP T Rebuild Choke manifold valves #9 and 10 -Due to corrosion. 01:00 01:30 0.50 COMPZ WELCTL BOPE P Retest Choke valves 9 and 10 -pass. 01:30 03:30 2.00 7,055 7,018 COMPZ RPCOM THGR P MU Landing jt, and install side port isolation sleeve. MU Top drive. Held PJSM, Unland hanger @ 240K Pull han er to ri floor w/ 105k u wt. 03:30 05:00 1.50 7,018 7,018 COMPZ RPCOM CIRC P Circulate @ 5 bpm @ 190 psi for 1.5 hole volume. 05:00 06:00 1.00 7,018 6,980 COMPZ RPCOM PULD P Disconnect TEC wire and RU to s ooler. LD han er and landin ~oint. 06:00 18:00 12.00 6,980 0 COMPZ RPCOM PULL P POOH with 4-1 /2" com letion spooling gauge wire. LD, tally and kick out tubing. All 237 Cannon Clamps were recovered along with all TEC Wire. 18:00 21:00 3.00 0 0 COMPZ RPCOM OTHR P Clean and clear Rig floor and Pipe shed. Prep to RIH w/ 5 1/2 Inner Liner. 21:00 00:00 3.00 0 2,385 COMPZ RPCOM PUTB P PJSM, PU and RIH w/ 5 1/2 15.5# Inner Liner to 2,385' 60K up wt, 55k do wt. 4/20/2009 Continue to RIH w/ 5 1/2 Inner Liner to 5,263'. PU and RIH w/ Baker Storm Pkr to 104' and set and PT. ND BOPE. Change out Uni Head. NU BOPE, Body test BOP @ 250/3,000 psi. Pull Storm Pkr. RIH w/Inner Liner. S ace out and S of Corossion inhibited KWF. 00:00 02:00 2.00 2,385 5,263 COMPZ RPCOM PUTB P Continue to PU and RIH w/ 5 1/2 15.5# Inner Liner to 5,263' 93K up wt, 59k do wt. 02:00 02:30 0.50 5,263 5,263 COMPZ RPCOM OTHR P Change over to DP Equip. 02:30 04:00 1.50 5,263 5,375 COMPZ RPCOM PULD P MU and RIH w/ Baker Storm PKR to 104' and Set w/Mule shoe @ 5,375'. PT to 2 000 si for 10 minute - ood. 04:00 07:00 3.00 5,375 5,375 COMPZ RPCOM NUND P Blow down Test Equip and ND BOPE. 07:00 12:00 5.00 5,375 5,375 COMPZ RPCOM NUND P ND tubin head. NU new casing head and tubin head. ~_ m~~. ~ ~sa~ 2 ~~ ~ Time Logs Date From To __ Dur S De th E. De th Pha e Code Subcode_ _ T Comment 12:00 15:30 3.50 5,375 5,375 COMPZ RPCOM NUND P NU BOPE: Install test plug and RU test lines. 15:30 16:30 1.00 5,375 5,375 COMPZ RPCOM PRTS P Test BOPE break 250/3000 psi. RD test lines. 16:30 18:00 1.50 5,375 5,263 COMPZ RPCOM PACK P RIH with DP and retreive storm acker. 18:00 20:30 2.50 5,263 7,083 COMPZ RPCOM PUTB P Continue to PU and RIH w/ 5 1/2, 15.5# In Liner f/ 5,263' to 7,083 and No- o. Pull out of PBR w/ seals 7,066'. 20:30 22:00 1.50 7,083 COMPZ RPCOM HOSO P Space out and MU Landing Hanger, w/ Landin JT. 22:00 00:00 2.00 COMPZ RPCOM CIRC P Unable to freeze Protect - d CSG Couolinas in anrZular. Circulate 125 bbls of 9.6 ppg Brine w/ 1 % by vol. CRW132 3 b m 220 si. 4/21 /2009 Land Hanger and RILDS. PT void to 5,000 psi. PT OA to 2,500 psi. Load, Rack, Drift and Tally 2 7/8 Completion String. RIH to 1,027'. Zeibel Gauge would not test, POOH CO gauge, still had bad test, cont RIH as er Well En leer. 00:00 00:30 0.50 7,083 COMPZ RPCOM THGR P RIH w/and Land Han er. 115k Up wt, 60k Dn wt. 00:30 01:00 0.50 7,083 7,083 COMPZ RPCOM OTHR P RILDS and Pressure Test Void to 5,000 si. 01:00 02:00 1.00 7,083 7,083 COMPZ RPCOM PRTS P Pressure test 5 1/2 x 7 5/8 annulus to 2 500 si for 30 minutes. -Good test. 02:00 08:00 6.00 0 0 COMPZ RPCOM OTHR P Continue to Load, Rack, Drift and Tall 2 7/8 Com letion strin . 08:00 10:30 2.50 0 0 COMPZ RPCOM FRZP P PJSM. Load 5-1/2" landing Jt. MU to hanger: RU Little Red and press test line. BOLDS. Press u 5-1/2" casin , POH until press falls off, close annular, pump 65 bbl of diesel down the IA. RIH land hanger, RILDS, test void to 5000 si. 10:30 13:00 2.50 0 0 COMPZ RPCOM PRTS P RU test lines. PT 5-1/2" x 7-5/8" annulus 250/2500 psi for 30 min. RD test lines. 13:00 14:00 1.00 0 0 COMPZ RPCOM OTHR P Blow down top drive, clean rig floor. 14:00 19:00 5.00 0 1,027 COMPZ RPCOM RCST P PU and RIH with 2 7/8" EUE completion to 1,027', tested Ziebel Gau a and had a bad test. 19:00 20:30 1.50 1,027 0 COMPZ RPCOM RCST T POOH to gauge carrier standing back tb . 20:30 23:00 2.50 0 0 COMPZ RPCOM EORP T Inspected gauge and wire, gauge was bad, spliced in back-up gauge which also does not work ro rl notified Well Engineer and decision made to cont RIH. 23:00 00:00 1.00 0 1,027 COMPZ RPCOM RCST T Cont RIH with gauge and tec-wire on 2 7/8" EUE from derrick to 1,027'. ~._ ~ F~~~y~: vt ~ s' Time Logs ___ Date From 7o Dur S. Depth _ E, D_~th Phase Code Subcod_e _T_ Comment __ I 4/22/2009 24 hr Summary RIH to 7,001'. Space out, Land Hanger and Spot Corrosion Inhibited brine and freeze protect diesel. PT TBG and IA. Set 2 wa check, ND BOPE, NU tree. 00:00 10:30 10.50 1,027 6,900 COMPZ RPCOM RCST P Cont RIH with 2 7/8" EUE completion from 1,027 to 6900' Initially, Ziebel downhole gauge would not test. Continued to test every 1000' while RIH. Gauge started testin at 4000'. 10:30 12:30 2.00 6,900 6,984 COMPZ RPCOM RCST P Up wt = 65 K#, down wt = 43 K#. RIH to 6985', down 10K# (all tubing wt). Pump down tubing at 1 bpm, pressures up to 220 psi and bleeds off. Made several attempts pull up hole and engaging into the PBR, turned tubing 1/4 turn twice, still sittin down at 6984' 12:30 15:00 2.50 6,984 6,984 COMPZ RPCOM CIRC P Mix 120 bbl brine w/ 1% Safelube. Circulte at 3 bpm @ 340 psi to load the IA with safelube. 15:00 15:30 0.50 6,984 7,004 COMPZ RPCOM RCST P RIH to 7004', sit down 10 K#. Pressure up tubing to 500 psi, PU ~19' and ressure falls off. 15:30 17:00 1.50 7,004 6,975 COMPZ RPCOM HOSO P PUH, PU space out pups. MU pups, tubing hanger, and landing joint. RU pump line. MU TEC wire penetration through hanger. Gauge test good. Up wt = 67 K#, down wt = 45 K#. Used 221 clam sand 10 SS Bands. 17:00 18:00 1.00 6,975 6,975 COMPZ RPCOM FRZP P PJSM. Press test Little Red pump tine to 2500 psi. Pump down the tubing taking returns up the IA: 63 bbl diesel 68 bbl of inhibited brine, 20 bbl of diesel at 5 bpm @ 1500 psi. Diesel freeze protect down to 4000' MD 2500' TVD in the tubin and IA. 18:00 19:00 1.00 6,975 7,003 COMPZ RPCOM HOSO P RIH land hanger w/4' spaceout. RILDS. test void to 5000 si. 19:00 21:00 2.00 0 0 COMPZ RPCOM PRTS P Press test tubing 1000 psi/15 min, IA 3500 si/30 min on chart, good tests. 21:00 21:30 0.50 0 0 COMPZ RPCOM SEQP P Blow down circ lines and RD, install 2 wa check. 21:30 22:30 1.00 0 0 COMPZ RPCOM NUND P ND BOP stack. 22:30 00:00 1.50 0 0 COMPZ RPCOM NUND P NU tree. 4/23/2009 Tested tree and void, final test Zeibel gauge, installed BPV, dressed tree, flushed all circ lines, cleaned all fluid aths and its for u -comin filtered sea-water work, RDMO well, started ri move to 2T Pad. 00:00 00:30 0.50 0 0 COMPZ RPCOM PRTS P Test tree and void at 250/5,000 psi, ood tests. 00:30 01:30 1.00 0 0 COMPZ RPCOM OTHR P Pull TWC and set BPV SITP = 0 psi, 5 1/2 IA = 0 psi, OA = 0 psi, dress tree clean cellar. ~~ _~ ~® ~_ t'~z~~ ~ o=' S ~ I ; ~ SARAH PAL/N, GOVERNOR ~SA OII/ A~D t7ra~7 {r 333 W. 7th AVENUE, SUITE 100 C01~TSEItQA7`IO1Q COAIDIISSIOI~T 1r ANCHORAGE, ALASKA 99501-3539 ~~ PHONE (907) 279-1433 FAX (907) 276-7542 Brett Packer Wells Engineer ConocoPhillips Alaska Inc. ;.y~~~~!1~~.~~~ ~. ~ ~ D~~ PO Box 100360 Anchorage AK 99510-0360 d~ ~~. Re: Kuparuk River Field, West Sak Oil Pool, 1C-178 Sundry Number: 309-119 Dear Mr. Packer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~ji' Cathy P. Foerster Commissioner DATED this ~~ day of month April, 2009 Encl. • STATE OF ALASKA • ~{,~Z- ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~2ECEI`JE al~~q APR 0 3 2009 S i1S. UP~tSi a 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ 8S a CC ((--~t Alter casing Q Repair well ^/ Plug Perforations ^ Stimulate ^ Time Exten§18ti"~~~ Change approved program ^ Pull Tubing ^/ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q . Exploratory ^ 203-041 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23144-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Y2S ^ NO Q 1C-178 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25649 / 25638 RKB 87' Kuparuk River Field /West Sak Oil Pool ` 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13280' 3811' ' 13246' 3810' 7392' Casing Length Size MD ND Burst Collapse CONDUCTOR g0' 16" 110' 110' SURFACE 7704' 7-5/8" 7734' 3770' LINER 5817' 4-1 /2" 13246' 3811' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7704'-13179' 3767'-3809' 4.5" L-80 7336' Packers and SSSV Type: Packers and SSSV MD (ft) Baker Packer @ 7086' Camco'DB' landing nipple @ 498' 13. Attachments: Description Summary of Proposal Q 14. Wefl Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q - Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat April 16, 2009 Oil ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer @ 265-6845 Printed Name Brett Packer Title: Wells Engineer Signature -~- ~" ~~~~ Phone 265-6845 Date ~ L Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness G - ~ - Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ w~~'`S ~' lVraFro ~~ Other: '~D'OC) QS ~ F'O.r.. ~'E.S~ ~ r}$~~ QS~t ri*t i~t Y`•4v ~ C~.t~t~S ~C~S-~C^ S `T Subsequent Form Required: ~~~ APPROVED BY _ / Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revis 2 0 ~ ~ a Submit in Duplicate ., • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 2, 2009 Commissioner State of Alaska ''" ~ :.~ Alaska Oil & Gas Conservation Commission '~$ o 333 West 7t~ Avenue Suite 100 ~ ~.~, ~ ~ ~~ - Anchorage, Alaska 99501 Fy ,~~;,~~, :as~~~ ~s.. .~ ~ ~.x/d r~ <~,~~ :. Dear Commissioner: ~ua~ra ~_~ ~nc~ora °ssiv ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry pproval to workover the West Sak Well 1 C-178 (PTD# 203-041). Well 1C-178 was drilled and completed in May 2003 as a West Sak dual lateral surface powered jet- pump producer. The well was first brought online the end of May and produced on jet-pump service for almost two years at which time it was temporarily converted to gas lift to confirm the water cut and determine how the well would flow on gas lift. It remained on gas lift for one year and then converted - back to jet pump service. 1 A semi-recent discovery of severe casing corrosion in two Tarn jet-pumped wells had raised concern for the possibility of similar corrosion issues in West Sakfet-pumped wells. 1 C-178 is one of the original four West Sak single casing jet-pumped wells along with 1 C-135, 1 C-170 and 1 C-184. Subsequent to the corrosion discovery at Tarn, apro-active workover on 1C-170 to pull the tubing and inspect the casing ~' revealed that we are not seeing the same corrosion issues similar to what was seen at Tarn. Nevertheless, new internal policy now dictates that we must have two barriers between any energized fluid (power fluid or gas lift) and the formation. Thus, the original four West Sak single casing jet-pumped wells were shut-in until such time that an inner string of 5'/" casing can be installed within the 75/" surface casing. The workover on 1 C-135 was successfully completed in July 2008 and 1 C-184 soon followed in August 2008. 1 C-178 is to be the third of the four wells to be worked over in this fashion. The proposed workover will pull the 4'/2' IBTM tubing, install an inner string of 5%" BTCM casing and re- complete the well with a 2%8" jet-pump/gas-lift completion. This Sundry is intended to document the proposed change to the casing structure as well as request approval to workover the well. The current SBHP is 1373 psi as recorded on the downhole gauges that are still operating. This equates to an EMW of 7.4 ppg. An IBP will be set in the tubing below the packer to isolate the well from the formation and 9.6 ppg brine will be used as a workover fluid. Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at 265-6845. Sincerely, ~~ V L Brett Packer Wells Engineer CPAI Drilling and Wells West Sak 1 C-178 General Workover Procedure PTD 203-041 Pre-Riq Work 1. Confirm CMU is open. (DONE 8/19/08) 2. Pull the IBP in the 75/8" casing at 7392'. ~-- 'e~s~-c,.`~.~~ ~ ~t~ ®~ '~ 3. Set 1-11/16" IBP in 4'h" tubing tail at 7135' RKB below the S-3 packer. Perform a pressure test and drawdown test on the IBP. 4. PT tubing & casing packoffs, function test LDS's. (DONE 3/29/09) 5. Set BPV. General Workover Procedure 1. Verify Sundry approval acquired. 2. MIRU Nordic #3. 3. Pull BPV. Load hole with 9.6 ppg brine. Set BPV. ND tree. 4. NU BOPE. Install blanking plug. Pressure test BOPE to 250/3000 psi • The current SBHP stabilized at 1373 psi at 6928' RKB (3573' TVD) during a pressure fall- off test according to the downhole gauge on 2/13/09 prior to setting the IBP. This equates to 7.4 ppg. The current IBP in the 75/8" casing will be pulled and an IBP will be set in the tubing tail to isolate the wellbore from the formation. 9.6 ppg brine will be used during this workover. The calculated maximum anticipated surface pressure assuming a gradient of 0.1 psi/ft is 1016 psi.) 5. Pull 4'/z" tubing from the PBR. 6. RIH w/ PBR seal assy and SBE on 5'h" BTCM casing. 7. During TIH, .set storm packer, ND BOP, ND tbg head and install additional casing head. NU tubing head and BOP stack. PT BOPE to 250/3000 psi. 8. POOH w/ storm packer, continue running 5'/" casing string. 9. Tag up on PBR, pull up & reverse circulate corrosion inhibited brine & freeze protect. 10. Space out and land 5'/s" casing. RILDS. PT 5'h" x 75/8" outer annulus to 2500 psi. 11. PU & RIH w/ 2'/8" gas lift/jet-pump completion w/ downhole gauge. 12. Sting into SBE, mark pipe, pull up and circulate in corrosion inhibited 9.6 ppg brine. Space out and land 2'/8" completion. RILDS. Pressure up tubing to 1000 psi and hold. Pressure test IA to 2500 psi. Ramp up IA to shear the SOV. 13. Set 2-way check. ND BOPE. NU tree and pressure test to 5000 psi. 14. Pull 2-way check, freeze protect with. diesel 15. Set BPV and RDMO workover rig. Post-Riq Work 1. Pull BPV 2. RU Slickline: Set catcher sub below bottom GLM. Pull the SOV and replace w/ a DV. Retrieve the catcher sub. Pull the IBP from 7135' MD. Open the CMU, set the jet pump. 3. Return to production. ~~ L r~ ill API: 500292314400 PTD: 203-041 Wellhead: Gray Horiz X-mas Tree: 4-1/8", 5K psi Lift Threads: 4.909" MCA BPV: 4" 'H' • Tubing = 2'/8', 6.5 ppf, L-80, 8rd EUE .2.313" DS-nipple at -500' • Baker 2'/8' CMD w/ 2.25" D profile at -6900' MD. • Ziebel Gauge at -6950' MD. • 3'/z' EUE SCC tubing. • Baker locator w/ 17' seal assy. at -7000' Proposed 5'/z' Inner Csg. String • Casing = 5%",15.5 ppf, L-80, BTCM w/ SCC. . Crossover from 5'/",15.5# BTCM. . 20' SBE at 7000' MD. • Baker 80-40 Locator w/ 10' seal assy. (3.875" OD) at -7050' MD Directional Max Incline: 92° @ 11208' Max Dogleg: 8.7° @ 1505' 2008 RWO PROPOSED COMPLETION • Well: 1 C-178 Conductor: 16", 62.5#, H-40 at 110' Surface Casina: 7.625", 29.7#, L-80 at 7734' New Inner Casing: 5.5", 15.5#, L-80 BTCM Perforated Liner: 4.5", 12.6#, L-80 SHLT to 13,244 Sliding sleeve for jet pump at -6900' Ziebel Downhole Gauge/Carrier Crossover to 5.5" BTCM 20' SBE PBR at 7056' Baker S-3 Packer at 7,086'. p ~ Gas Lift Mandrels: p MD TVD Tvpe p XX XX 2-7/8" KBMG, 1" p XX XX 2-7/8" KBMG, 1" O 0 O O O O O O Fill at: Last Updated: 1-Apr-09 TD: 13,280' RKB Updated by: JBP ConocoPhillip~ -M1.IaSKU, fIG. KUP Vell Attributes -- __ __ -_ 'ellbore APIIUWI Field Name Wall Statu 500292314400 WEST SAK ~PRODU( 1 C-178 Act Btm (kKB) 13,280 gig Release Datr 5/112003 HANGER. zs ~, '~ CONDUCTOR ~ 161 15.062 ~ 110 110.01 62.50 H-40 -~~~- 30 WELDED SURFACE - -- I 7518 6.875 - . 28 7,734 3,770.0 2970 L-80 ~IgTCM B-SAND Slotted I 41/2, 3.958 3A09.9 1260 L-80 7,429 13,244 SHLT Liner 1 Tubing Strings - - --- _ ~' Strang ID n I Stri OD ~ 9 - Set Depth Set Depth (TVD) String Wt String . CONDUCTOR, ' - - - Tubing Descnptwn ( I In i (in) Top (kKB) (kK6) (fiKB) (Ibsflt) Grade String TO p Thr< . - 110 (USING 41,'2 3.958' 26 7,336 3,696 12.60 L$0 IBTM NIPPLE,4s8 - Other In Hole (A ll Jewelry: Tubin g Run & Retrievable, Fish, etc.) - _--' - __ --_ - -... _ - ToP Depth IND) Top Inc! Top (kK6) (kKB) (°) Description Comment ~ Run Date ID (ir GAS3iF Z _ -__ 26 26.Oj -0.57~IHANGER ___ IVETO GRAY GEN t MCA TOP CONNECTOR 4/2912003 1 3.9f 30 ~ 0.54 PATCH W ELD 8" .500 upper wedding band in no-go style 8' lower 212 012 0 0 8 i 7.0( 0.500 wall X-65 wedding band. Install 9 5!8' OD, L-80 GAS uFT. s,a27 - casing (0.395" wt) Sudace Casing patch that stratltlles surface casing collars. Total patch length from bottom of I wellheatl to lower most wetlding bantl 6' 11" -set 2/20/2008 ~ 4981 497.7 4.93 NIPPLE CAMCO'DB' LANDING NIPPLE 4!29/2003 3.81 GAUGE, s,eet - {: ._..'~`•: ~ 3,752 2,397 8 6679 GAS LIFT CAMCO/KBG-211/GLV/BK/.156l1460! Comment: STA 1 '8/26/2008 3.9: 6,827 3,538.8 70.26 GAS LIFT CAMCO/KBG-211/OV/BK/.313/! Comment STA 2 8/20/2008 3.9F 6,881 3 556.9 70.50 GAUGE __ I~BAKER GAUGE CARRIER MODEL 925 4/29/2003 3.97 BUSHING, s.924 t § 6,924 3,571.3 70 69 BUSHING - BAKER PROTECTOR BUSHING - 4!29/2003 3.9: SLEEVE~c, _-_- 6,945 - 6.9251 3,571.6 70.69 SLEEVE-C jBAKER CMU SLIDING SLEEVE -CLOSED 6/25/2007 ~ _ 4!29/2003 i 3.81 " 6,9761 3,5880 69-86 GAUGE _ BAKER GAUGE CARRIER MODEL 925 '14!29/2003 3.97 7,057' 36134 70.73 SEAL ~!BAKER80-0O SEALASSEMBLY W/PBR 4/29/2003 ' 3.87 GAUGE SS7s - - ~,;~-~~ 1 7,056 3 615.0 70.79 PBR BAKER PBR 4/29/2003 ~ 3.81 ~ 7,086 3 624.8 71.14 PACKER BAKER PACKER W/MILLOUT EXTENSION, ID 4.54" 4/29/2003 3.87 SEAL, 7.051 - - 7,109 3 632.3 71.40 NIPPLE CAMCO'DB' NO GO NIPPLE 4/29!2003 3.7`. PBR, 7.oss--- -- 7,335 3,695.6 74.12~WLEG CAMCO WIREUNE GUIDE 14/29/2003 3.9E ~ 7,392 3,711.3 75.221BP SET BADER INFLATBLE BRIDGE PLUG IN 7 5/8" CSG 2/14/2009 0.0( .. _ @7392 ELM ON 2.14.2009 _ _ PACKER, 7.oss - 7,407 3,713.6 75.40 SLEEVE B!C-SAND SLEEVE '14/16/2003 5.01 7,4141 3,716.8 75.65~BUSHING ~BlC-SAND BAKER BUSHING ~4/16l2003 5.5< _ 7,416 3,717.3 75.69 NIPPLE B/C-SAND BAKER RS NIPPLE ;4/1fi12003 ~, 4.87 mPPLE. 7,109 - ---- 7,419 3,718.0 75.75~HANGER IBIC-SAND BAKER FLEX LOCK HYDRO ROTATING LINER 4/16/2003 4.85 HANGER !' WLEG, 7,335 - i i< 7,428 - 3,720.1 75.92 XO __ B/C-SANDCROSSOVER TO 4.5' LINER 4!16/2003 3.9~ - -- 7,704 3,767.7, 8426'~LOCATOR B!C-SAND BAKER LOCATOR SUB 4116!2003 3.51 13,242 3,A09.9 A9.08 SHOE BIC-SAND GUIDE SHOE 4" ROT SILVER BULLET I X4/16/2003 3.9f HANGER, _ W/ECCENTRIC NOTE (float tlrilletl out) ],356 ; _-__. - Perfora tions 8 Slots - _ _ _ snot IeP,7.3sz --- ToP (ND) Btm (TVD) Dens Top (ftKB) Bim (ftKBI (ftKB) (kKB) Zone Date (sh TyPe _--_ Co mment _ t 7,704 73,179 4/1612003 120~IPERF 3,767 7 3,809.2 WS B, WS B, 1 1 IWSG, IC-17$ SLEEVE,7p01 1- ~ ~ .-- - _--_ _ _. __- - ; . BUSHING. ~ Notes-General End Date & Safety _, - - _ Annotation - 7p14 - " 4/29/2003 NOTE- MULITLAI ERAL WELL- 1C-178 (B/C-SANDS), 1C-178L7 (DSAND) NIPPLE 7416 ~ '-`" ~ _-. ___. - HANGER, 7,a1g '~ F ~ ~ X0.7428 -'~" LOCATOR, 7 704 , SURFACE. 7,734 n IPERF, - 7.704~13.179 ~II ],413IP3.4 ] ~ D-SAND Sbttetl Lvrer. 13.55s I I ~. f J l 1C-178 Header Pressure (PTD~03-041) ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, April 13, 2009 11:22 AM To: 'Packer, Brett B' Subject: RE: 1 C-178 Header Pressure (PTD# 203-041) Brett, Thanks for the information. 3000 psi appears to be appropriate for the BOP test pressure. One other item, with these multi-lateral, horizontal wells, please include a horizontal drawing similar to what I have attached. Such a drawing greatly helps visualizing the well and planned work. Thanks in advance. Tom Maunder, PE AOGCC From: Packer, Brett B [mailto:J.Brett.Packer@conocophillips.com] Sent: Monday, April 13, 2009 10:39 AM To: Maunder, Thomas E (DOA) Subject: 1C-178 Header Pressure (PTD# 203-041) Tom, The power fluid supply to the 1 C jet-pump wells comes directly off our water injection header on 1 C pad. 1C Water Iniection Header~May 2002 -present) Currently: 2305 psi Avg: 2325 psi Max: 2743 psi (11 /21 /05) Min: 1456 psi Brett ~Pac~r ~Dri[Ixng aZ'Wells 'Workgver Engineer 'Work# (907) 265-6845 Cell# (907) 230-8377 4/13/2009 • • Tna fir' (Q6d770), Velm Gn7 Tuhlna Ilrgar, (1813005) Veto Grey Oen I, 41?, w/ f.aOP Gen 1'ProMroar ~~ Tap Comedon: 41?.1L6a, Lao BT-Mod bex down, rwp w.d Mb ~yyp (10840177 a 10640109) !er TBC wka ~~ (5015120) Velm hl Jobes Tubbrp, specY drrw b 7.t7e' Orgy, Gsf 1, 11' API aM tarps up. (1) p*o}ia NPOr, 41? Comm DB w/7.67a'llo~ ' Go Ptofle, 6rflod, ad n N• 500 bD hl .row Tubby m R.e un flaadral, c,oez-2oss> cAaacp 4,? x ,• naasl Asa wan oaw ar.r u1M Yelaled, Dbned b shsv Men amulp pr®raa b 2500 pt10r•nxMen QeYq pmesraa, 41? far PN x Ph, eiM 6 bo141? XO Pup, by and bafanr. en G.F 2100 6 TVD. W bbb Tubby bsugbd Caductor Caaby,lP, API SL 7056 (1) Bas l.al frrrdtel, (1062.2035) CA1AC0 41? x 1' Ibds1103G-2 wdn duomr vN.~e 1.000 Wr, ~ N•' MD babrod, 41? a7r PYr x PYI, MBi 6 bq 4•i? XO Pup, by end bolbrn (ll JoMa Tublrq 171 A^-e.e G~rae, Obr;bege, eks G.ardl.n (11 Jebd Tabby s•7/i^ Hole Sail Anglr. 68 de raes (71 sllarro sre.e wah P.ona. erw Mode) •CMV wr 7.6/r g canrm -b-Go proW,l6i-aaod (7083J120), wN 6 a pup nd referawl subs by eM Ooaom ,,,p, n1./.r Pump ww.d.R.r r!y r.1«ea n),leYd TOWry ~'p""a"'~I•Raws+e cicv/etbrr.fwr NOalr, Tubhtg Suing: 4-112", e,u r7ron, aeA rop xa b CAArCO LeG. ftl Pneaw~ ways. w~a. s.tar G.mmen 12.8 p, LaO, IBT,AB Modidad (7051-2163) 12) ~wraa rablry (1) PiR MM anal Aasrably. 17 t Baker Modtl aD~17, 41/2' 4 f0 !T- Moe, a f hanGep prpe Ywfafed m lop. ~/ (tl aaelee.br Pader Aeaerrfy, Bek.r PrsmW, PO a.n67, 4 b 7? Lao 6T- Mad, 6 f firbn0 pups M1YM on by W poMm Hook nrw. ; s.io.rHoa.l a 7aa-:4x~ ry l Aerie Mppie, CIIIACO Model 00. 7lf hcYirry Bare, 41? . MaN ea. Oril . amts L-6o rr~loe sox, ea n n dp n~se.n ,. yIM 1o f banehp pop. Lawral Bas Drlrt ~ 7.t7a' (:) Ja1Ma Tubby ~d fuaA Pop (11 wba bra Eery Golds, 4iQ' LaOIBT-IAod BaC b ne spaced aul N-1S ebore hook hrga 'w\ (` `}[[ cY ~ 1 ./ ,/ _ `~ " ` ~ ~•l Goat MlnMte 7 S2' GsN9 a~owre =_____ _=____ __ ------ ------ --= mi work ,~~~ ~ / r''I - - ao l w ~ ~ y, =~==a~ ?zs1~ Mo r w l n 3703'TVD ~ 1~.~-~,~ ra/r, 7n.re, L.tf, ITCH Ca7na sno. ®7aes Mo / 77rT TVD ae g a d.Q.« ro SaAr Uol. Rotating Flatdoh Liner Hanger ~ s/- 7,300' Lbws, ewny oMe pb+,loewd (ess- xT7aperrooq, 4x-,1z.a, L.f9. suer ~ ~ 1C - \`ZSs ~-'~ Rw , 1 ~.,^ ~~~ • • Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Prod Engr Specialist [n1139@conocophillips.com] Sent: Friday, March 27, 2009 5:09 PM To: Maunder, Thomas E (DOA) Subject: RE: 1 C-178 (203-041) Attachments: 1C-178 Planned Completion Schematic.pdf Tom, Attached is the Planned completion schematic. The IBP was set below the D sand lateral to isolate the lower B sand (mother bore). Bob Christensen / Darrell Humphrey ConocoPhillips Alaska, Inc. Greater Kuparuk Area ~~;, ;~~; A~~ ~~y •u ~o~~y Production Engineering Specialist Office (907) 659-7535 NSK-69 Pager (907) 659-7000 (924) This email may contain confidential information. If you receive this e-mail in error, please notify the sender and delete this email immediately. From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, March 27, 2009 3:01 PM To: NSK Prod Engr Specialist Subject: iC-178 (203-041) Bob, am reviewing the 404 for setting the IBP in this well. Since this well is horizontal and multi-lateral, the straight drawings are difficult to interpret. Can you provide a drawing similar to what was provided in the permit to drill? It appears that the intent was to shut off a portion of the well. What exactly was shut off? Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 4/1/2009 - -- eoovur SIle3e0 s~l4~l ~4-o b a0e4S Sd~I'~~dQ~DU~~ ~eexo~w o s~av~dvd ~ opeweyag uope~dwo~ peuue~d ~ . r~oraews BLL-D6 IIeM uop~npad ~IgS 3s0M /'~ 0 0 t~ ~ Ey ~ ~¢ $~g~ ~~g~ EE n ^ ,jt O 1'~~O N~nfi 'm d~®lg d~~13 ~_~ ~~ ~ oW 0 b VIII ~' UII nu ~ uu IIII n IIII Ijjjl pE IIII ~ VIII ¢ IIII IIII IIII J IIII IIII IIII IIII \ ~ `„ III IIII ~J v/J VIII IIII ~ ~ VIII IIII ~~~~ f r9 : `.mil C~zv~~ v Illu ~~~~ s, ~ ~ 3 ..~ iiiri 141 ./ liii iii ulll un nll uu nn un pl Un un qij Uu J ull uu IUII Ipl y 8 ~ 11111 1111 J $ ~ IIII IIII J gi~ 1 ~ ~ ~ / III IIII ~ 3 ~ a25 ~( J m~ g ~^ III ~~+ ~ ~~o n oga- c~~ .r ~~~ ~~ ivg 4 .k8 ^ 94 IIII IIII $ ~ i2 I I ~" $ 6~ n, uu ~~e ~$ }r~~x ~9 og °a~ nu viii ¢ ,p o t u° u° ~'Tdg g€ ~~ ~&~ +~ ~ c ~ ~ ~~ ~~ IIII ~Fi R° ~ 9 ~~- ~ 5 ~s~ 3 ~~ °>r 6 h mid x f `~ g S ~~o ~~ a ~~'~ ~ a~ ~~ 888 ~ ~~ SKI ~~~ = yc ay ~ p~R ~3~ Qg ~~ 6~ ?~~ # ~s Q~~ jig R a~ '~ ~~ ~;~ ~ ~a W „ ~ ~ ~~ ~4 ~l~ ~ 'w4~~, $? ~ y ~ ~ ~ x B €' w~ffi ~ ~~M ~ L`+p a ~~ g e ~ $8~ - S ~1~ ~ G~ ~ .~~ ~j ~ ~ _ ~U~ j ~ ~ ~ f ~ a ~.. ~ - 5 y ~~~ ~` ~ ~~~ ~ ~~ ~ rT a ~~ $ c3gg a =F3 ~ =c°o 3 =i~= © o ~. a~~ ~. r ~s~ ~~ I-sa ~ i~~ ,~~ iNA ~ + ~I ~ LL Y'~n w y ei /~ ~ I p. C OI N P IY..A 9. ICO ~~ ~ ~c~ ~ ~' 3~~ K >~ u iVQle'1 oo~g ~ r S_ m r~~ c S~~ ~ ~~C n~~ ~~ ~~~ a~ ~o0 135 ~~~ m N 3 ~'g e~~ _~ c~~ ~ ~~ oU a. _ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION O~A~ ~ ~ ~~~~ REPORT OF SUNDRY WELL OPERATIQ~~ ~,:, ~. ~,~ r~,~~ f'_nmmiceinr~ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Oth~~~hOraf~ ^ Isolate Zone Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2.Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ Exploratory ^ 203-041 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23144-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 8T 1 C-178 8. Property Designation: 10. Field/Pool(s): ADL 25649 / 25638 Kuparuk River Field /West Sak Oil Pool -- 11. Present Well Condition Summary: Total Depth measured 13280' • feet true vertical 3811' feet Plugs (measured) 7392 Effective Depth measured 13246 feet Junk (measured) true vertical 3810 feet Casing Length Size MD ND Burst Collapse CONDUCTOR 110' 16" 110 110' SURFACE 7705.73' 7-5/8" 7734' 3770' B-SAND SLOTTE 5815' 4-1/2" 13244 3810' ' ~\~ ' ~~ ~"~a~ ~©~ ~~~~ ' Perforation depth: Measured depth: 7704 -13179 Slotted Liner ~ ' ~ ~~ '-~~~ ~ J ~ ~ true vertical depth: 3767 - 3809 Slotted Liner C~- . - ~- ~f.;, 1cc ~~~ Tubing (size; grade, and measured depth) 4-1/2", L-80, 7336' MD. r.-ff`~,~~ Packers &SSSV (type & measured depth) Packer =Baker Packer w/ Millout extension 71 g6' SSSV =Nipple 498' 12. Stimulation or cement squeeze summary: ~, J ~~~ S ~ ~O ~~~,._~ Intervals treated (measured) ~~t d-~~ '~' y , I 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 0 0 0 1353 207 Subsequent to operation 0 0 0 1361 • 196 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NIA Contact B. Christensen/ D. Humphr y Printed Name o Chri to en Title Production Engineering Specialist Signature - Phone: 659-7535 Date ~/J _ Z~ Form 10-404 Revised 04!2004 rt Subr~Al~n p/ • 1 C-178 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02/14/09 SET BAKER INFLATABLE BRIDGE PLUG IN 7-5/8" CASING AT 7392'. TIED INTO SLB PPROF DATED 14-JUL-2005 WELLTEC TRACTOR RAN, ABLE TO FALL TO 7380' BEFORE TRACTORING DOWN. `, ~'~ KUP ~ 1C-178 COI'IOCOPIIillips Ytlell Attributes Max An le & MD TD AI3SIt2, 111; :. Wellbore A PIIUWI fle ltl Name Wall Status Protlll nJ Type Incl (°) MO (RKB) Act Btm (R KB) 500292314400 WEST SAK PRODUCING 92.00 11,208 13,280 Comment N23 (ppm) Data Annotation End Date K8-Grtl (ft) Rlg Release Dale SSSV: NIPPLE 60 111/2009 Last WO: 34.31 5/12003 Well Conti ' -1C-1 )S 2n6/10 Scnamatic-Actu 091'.18'.19 PM al Annotation Depth (RKB) Entl Date Annoatlon Entl Date Last Tag: Rev Reason: SET IBP 2178/2009 Casin Strin s string oo string ID sa o.pen sa o.ptn (rvo) srring wt so-ing Casing Descrlptlon (In) (In) Top (RKB) (ftK8) (RKB) (theft/) Gratle String To p Thrtl NANGER, zs CONDUCTOR 1 6 15.O1i2 30 110 110.0 62.50 H-40 WELDED SURFACE 75/ 8 6.875 28 7,734 3,770.0 29.70 L-80 BTCM 8-SAND Slotted 4 1/ 2 3.9:58 7,429 13,244 3,809.9 12.60 L-BO SHLT Liner Tubin Strln s String OD String ID Se[ Depth Sat Oepth (TVD) String W[ Siring CONDUCTOR, 110 Tubing Descrlptlon (In) (In) Top (ftK8) (RNB) (RKB) (Ibslft) Gratle String Top Thrtl TUBING 4 11 2 3.9:58 26 7,336 3,696 12.60 L-80 18TM NIPPLE. 496 Other In Hole A ll Jewel :Tubin Run 8 Retrievable Fish etc. Top Deptn (TVD) Top Incl IFT GAS Top (ftK8) (RKB) (•) Dsecrlptlon Comment Run Dats ID (In) L . 3.r5z 26 26.0 -0.57 H ANGER VETO GRAY GEN 1 MCA TOP CONNECTOR 4292003 3.958 30 30.0 -0.54 P ATCH WELD 8" .500 upper wedtling band in no-go style, 8" lower 2202008 7.000 0.500 wall X-65 wedding band. Install 9 5/8" OD, L-80 GAS uFr, s,ezT casing (0.395" wt) Surface Casing patch that straddles surface casing collars. Total patch Length from bottom of wellhead to lowermost wedding band 6' 11" -set 22021708 496 497.7 4.93 N IPPLE CAMCO'DB'LANDING NIPPLE 4292003 3.875 GquGE.6.ee1 ' ~ 3,752 2,397.8 66.79 G AS LIFT CAMCO/KBG-2/1/GLV/BK/.156/1460/ Comment STA 1 8262008 3.930 - 6,827 3,538.8 70.26 G AS LIFT CAMCO/KBG-2/1lOV/BK/.31311 Comment: STA 2 8202008 3.930 aUSHING 6,881 3,556.9 70.50 G AUGE BAKER GAUGE CARRIER MODEL 925 4292003 3.970 . 6.924 6,924 3,571.3 70.69 B USHING BAKER PROTECTOR BUSHING 4292003 3.920 SLEEVE~C. 8.925 6,925 3,571.6 70.69 S LEEVE-C BAKER CMU SLIDING SLEEVE -CLOSED 6252007 4292003 3.813 ~ 6,976 3,588.0 69.86 G AUGE BAKER GAUGE CARRIER MODEL 925 4292003 3.970 GquGE. e,9TS ' ~ 7,051 3,613.4 70.73 S EAL BAKER 80-00 SEAL ASSEMBLY WIPBR 4292003 3.875 7,056 3,615.0 70.79 P BR BAKER PBR 4292003 3.875 7,086 3,624.8 71.14 P ACKER BAKER PACKER W/MILLOUT EXTENSION, ID 4.54" 4292003 3.875 sEAL, T,osl 7,109 3,632.3 71.40 N IPPLE CAMCO'DB' NO GO NIPPLE 4292003 3.750 Pea, loss 7,335 3,695.6 74.12 W LEG CAMCO WIRELINE GUIDE 4292003 3.960 7,392 3,711.3 75.22 IB P SET BAKER INFLATBLE BRIDGE PLUG IN 7 5/8' CSG 2/142009 0.000 Q7392 ELM ON 2.14.2009 PgcKER. Toes 7,401 3,713.6 75.40 S LEEVE B/C-SAND SLEEVE 4/162003 5.010 7,414 3,716.8 75.65 B USHING 8/C-SAND BAKER BUSHING 4/162003 5.540 NIPPLE T /os 7,416 3,717.3 75.69 N IPPLE B/C-SAND BAKER RS NIPPLE 41762003 4.875 . ' 7,419 3,718.0 75.75 H ANGER B!C-SAND BAKER FLEX LOCK HYDRO ROTATING LINER 41162003 4.830 ( HANGER wLEC, T33s ~~ 7,428 3,720.1 75.92 X O 8/C-SANDCROSSOVER TO 4.5" LINER 4/162003 3.940 7,704 3,767.7 84.26 L OCATOR 8/C-SAND BAKER LOCATOR SUB 4/162003 3.510 13,242 3,809.9 89.08 S HOE BIC-SAND GUIDE SHOE 4" ROT SILVER BULLET 4/162003 3.958 HANGER. WIEGCENTRIC NOTE (float drilled out) 7,356 Perfora tions 8 Slots Shot IBP, 7,382 Top (TVD) etm (TVOI Dene Top IRKS) Btm (RKB) (RKB) (RKB) IDna Date (e6-' Typa Comment 7,704 13,179 3.767.7 3,809.2 W S B, WS B, 4 /16/2003 12.0 IPERF W SC. 1C-178 SLEEVE. x.401 1 Notes: General 8 Sale '., BUSHING Entl Data Annotation . r.4u t =- NIPPLE ] 416 ~ .. 4/292003 NOTE: MULTILATERAL WELL - 1C-178 (8!C-SANDS). iC-178L1 (D-SAND) , . HgNGER. L r 419 xo, T,4za a -_ LOCATOH. ~ n ~ 7 1,104 SURFACE, 1,13d IPERF. 7,]0413,119 ' IPERF, r,413-13,493 SNOE. 13.202 8-SAND Sbltetl ~ ~ j-~~-- Liner. 13,244 ~S 13.260 S, D-sANO slotma ~ ~ _~~ ~ Liner. 13.558 ~ I i •; ~ :. ~~' ~... ~.. ........ I f ,_ l w• ~~ KUP ~ 1C-178L1 W1 RI~.VrI tI~~IPS WBII Attributes Max An le 8 MD TD Aie~ka, III(:. WaIlDOre API/UWI Field Nama Well Statue Prod/In) Type Incl (°) MD (ftK8) Act Btm (ftN0) 500292314460 WEST SAK PRODUCING 95.49 7,666 13,626 ~ COmmant H23 (ppm) Date Annotaton Entl Date KB-Grd (ft) Rlg Release Data SSSV: NIPPLE 60 1/12009 Last WO: 31 34 5112003 Well -1C-178L1 x/1620091.18'.47 PM . Schsmatk-AGual Annotation Depth (ftK8) End Date Annotation Entl Date Last Tag: Rev Reason: SET IBP 2/162009 Casin Strin s Shing 00 S[ring ID Sat Dsplh Sat Depth (TVD) S[ring W[ S[ring Casing Description (In) (In) Top (RKB) (flN B) (ftK8) (IDSIfl) Grade String ToD Thrd HANGER, z6 D-SAND Slotted 4 1/ 2 3.958 6,856 13,558 3,766.1 12.60 L-BO SHL7 Liner Other In Hole All Jewai : Tubht Run $ Retrievable Fish etc. rop Dev[n (TVD) ToD Intl Top (RKB) (RKB) (•) Dncrlptlon Comment Run Dah ID (In) cor4DUCroR, 7,356 3,7D2.0 73.78 H ANGER D-SAND FLANGED HOOK HANGER FOR UPPER 4292003 5.630 11o LATERAL LEG LINER NIPPLE, 498 13,558 3,766.1 85.70 X O D-SAND LINER CROSSOVER 4292003 3.500 13.578 3,767.6 85.70 S HOE D-SAND LINER FLOAT SHOE, RAY OIL TOOL SILVER 4292003 3.958 BULLET W/ECCENTRIC NOSE G~i is ~ s Perfora tions 8 Slots snot Top (TVD) Btm (TVO) Dsns GAS LIFT. 8 827 Top (ftK8) 8tm (RKB) (RKB) (RKB) Zane Date (sh... Type Comment 7,413 13,493 3,714.9 3,762.0 W S D, 1C-178L7 41162003 12.0 IPERF Notes: tieneral d4 Sa End Dare Annotation GAUGE 8 881 4/292003 NOTE: MULTILATERAL WELL - 1C-178 (B!C-SANDS). 1C-178L1 (D-SAND) , , BUSHING. 8924 SLEEVE-C, 89x5 GAUGE. B 918 SEILL. 7,051 PBR. 7,056 PACKER, I,O86 NIPPLE. 1.109 ( WLEG. 7.335 HANGER. 7.358 l IBP. 7.392 SLEEVE, 7,401 -- - BUSHING. - 1 414 NIPPLE.1418- -J HANGER, - 1.419 xo. uze ~- LocnroR L)oe SURFACE, 1.131 IPERF. 7.704 13.119 ~. 1 PERF. i 1013-13.493 e-SANG sronaa i liner. 13.xa f - -` t _~, ' D-SAND 9lolted Liner. 1355 8 %0,13558 SHOE, 13,578 TD (1C-178L7). 13 828 • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 14, 2008 ~ ~ ~ '~ 1 Mr. Tom Maunder Alaska Oil & Gas Commission _ _ . 333 West 7th Avenue, Suite 100 ' ~~~ : ,.._ Anchorage, AK 99501 4~~~~~ ~~~ ~~ ~ ~oo~ b 3_ a ~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pum~ed August 20th -Sept 11th, 2008. The corrosion inhibitor/sealant was pumped Sept 12 - 13t ,2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off • ConocoPhillips Alaska Inc. Report of Sundry Operations (10-404) r)a4a Kuparuk Field 9/14/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbis ft al 1 C-178 203-041 8' 1.50 8" 9/11 /2008 4.68 9/12/2008 2F-17 196-204 12' 10" 2.25 8" 9/11/2008 7.65 9/12/2008 3R-20 192-022 9' 4" 1.50 16" 9/11/2008 1 Y-27 193-088 11' 9" 3.00 20" 8/24/2008 2.97 9/12/2008 1Y-29 188-091 41' 6.00 5' 8/20/2008 10.20 9/12/2008 1 Y-32 188-093 27' 8" 4.40 32" 8/20/2008 6.80 9/12/2008 1 Y-34 193-091 8' 1.10 27" 8/20/2008 5.95 9/12/2008 1 E-33 197-151 9' 6" 2.10 20" 8/24/2008 7.23 9/12/2008 1 E-104 204-227 7' 1.40 9" 8/24/2008 1.70 9/12/2008 2X-01 183-084 10" NA 10" NA 3.40 9/13/2008 2X-02 183-103 23" NA 23" NA 3.40 9/13/2008 2X-03 183-109 6" NA 6" NA 1.28 9/13/2008 2X-05 183-107 8" NA 8" NA 5.10 9/13/2008 2X-06 183-110 6" NA 6" NA 1.70 9/13/2008 2X-07 183-113 6" NA 6" NA 1.28 9/13/2008 ZX-08 183-114 6" NA 6" NA 1.28 9/13!2008 2X-17 195-171 6" NA 6" NA 1.70 9/13/2008 -~ .~ ~~ ~p -~s ~ ~, ~~~33 r~pa^, :~ ~ ~~ ~~ 'a iJ ii vii 9lltl~l~~f'~^°.'.''.. 9 1C-178 (PTD 2030410) Report of failed TIFL Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Saturday, July 12, 2008 12:50 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 1C-178 (PTD 2030410) Report of failed TIFL Attachments: 1C-178 schematic.pdf; 1C-178 90 day TI plot.jpg Tom, Jim • ~~~ Page 1 of 1 West Sak gas lifted producer 1C-178 (PTD 2030410) failed a diagnostic TIFL on 07/11/08 and will be added to the weekly SCP report. The TI prior to the TIFL was 220/940. A leaking GLV is suspected. Slickline will troubleshoot the GLV's and repair if possible. Attached is a 90 day TI plot and a schematic. Please let me know if you have any questions. «1 C-178 schematic.pdf» «1 C-178 90 day TI plot.jpg» Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 9/5/2008 KRU 1C-178 PTD 203-041 TII/O Piot -1 C-178 1200 1000 800 a. fi00 400 200 ,,,,, ~; ,: ~, ,-~ ~.. .Z~ .F\ r~~. ... ' fi 1r . tti . '~ .,~. I 4y .f,.. '~. ' i ....... .... ..... ,~t-~-~ O ~-++++ 12-Apr-08 25-Apr-08 08-May-08 21-May-08 03-Jun-O$ 16-Jun-08 29-Jun-08 Gate 200 180 • E d 100 ~ c~ r 80 0 • i* ~~ ~ ~ KRU 1 C-178 ~ Car~acaPhillps Alaska, Inc. 1C-1?8 - -- - TUBING (0-7336, OD:4.500, ID:3.958) ~ ~i [~ - API: 500292314400 Well T e: PROD - An le TS: _ ---- de SSSV T e: NIPPLE Ori Com letion: 5/1/2003 An le TD: 89 de 13280 Annular Fluid: Last W/O: Rev Reason: PULL PLUG, GLV C/O Reference Lo 28' RKB Ref Lo Date: Last U ate: 3/2/2008 Last Ta TD: 13626 ftK6 Last Taq Date: Max Hole Angle: 92 deq (o) 11208 Casing String - B/C-SAND LINER Alternating 30' sections of blank pipe & slotted liner) Description Size Top Bi,ttom TVD Wt Grade Thread Loww L deral .'I iterl Liner 4.500 74.2_9 1 ~.'~,t d I n -- 1.2. ~0 L-~'~u SHLT (~ ~, Casing String -ALL STRIN_ GS I Descri lion Size To Bottom TVD Wt Grade Thread SURFACE 7.625 0 7734 3770 29.70 L-80 BTCM rnNDI ICTnR 1R Onn 0 110 110 s2 sn H-4n WELDED i Tubing String -TUBING ' Size To Bottom TVD_ Wt _ Grade -~ - Thread ___ 4.SOG 0 7336 3697 ~ 12.60 I L-80 _ IGrP.t BUSHING (6924-6925, , I N : i i PerfOratlOrlS SUn1ma InteN l TVD _ Z St t FS SPF D _ T C _ OD:6.020) r~ t 1 11 a one us a at e e omment 7704.13179 3767-3809 WSB,WS 5475 99 4/16/2003 IPERF SLOTTE D LINER ~ ~ 1 B.WS C - -- - - Gas Lift Mandrels/Valves St MD TVD Man Mfr M an Type V Mfr V Type V OD Latch Port TRO Uate Run Vlv Cmnt 1 3752 2398 CAMCO KBG-2 GLV 1.0 BK 0.156 1460 2/28/2008 ' '_ -- 6827 - 3539 CAMCO - KBG-2 OV 1.0 BK 0.313 _ 0 2/28/2008 ,_! ~ Other_(plugs,~uip., etc.) - B/C-SAND LINE R DETAIL - SEAL 7401 3714 SLEEVE B/C-SAND SLEEVE (7051-7056, OD 5 500 - 7414 3717 BUSHING B/C-SAND BAKER BUSHING : . ) 7416 3717 NIP B/C-SAND BAKER RS NIPPLE - - 7419 3718 HANGER B/C-SAND BAKER FLEX LOCK HYDRO ROTATING LINER. HANGER '; 7428 3720 XO B/C-SANDCROSSOVER TO 4.5" LINER _~ 7430 3720 Blank Liner B/C-SAND BLANK LINER IN 30' SECTIONS, ALTERNATING WITH SLOTTED LINER 30' SECTIONS 7493 3735 Blank Liner B/C-SAND BLANK LINER IN 30' SECTIONS, ALTERNATING WITH SLOTTED LINER 30' SECTIONS 7704 3767 LOCATOR B/C-SAND BAKER LOCATOR SUB 13242 Other 3810 plugs, SHOE equip., etc B/C-SAND GUIDE SHOE 4" ROT SILVER BULLET W/ECCENTRIC NOTE (float drilled out) . -COMPLETION De th TVD _ T e - - -_ - Descri lion 10 10 PATCH WELD 8" .500 upper wedding band in no-go style, 8" lower 0.500 wall X-65 wedding band. Install 9 5/8" OD, L-80 casing (0.395" wt) Surface Casing patch that straddles surface casing collars. Total patch length from bottom of wellhead to lower most weddin band 6' 11" -set 2/20/2008 SURFACE - ~ r i 26 26 HANGER VETO GRAY GEN 1 MCA TOP CONNECTOR (0-7734, i 498 498 NIP CAMCO'DB' LANDING NIPPLE OD:7s25, ~ wt:2s.7o) I `, ' J 6881 3557 Gauge Carrier BAKER GAUGE CARRIER MODEL 925 -- 6976 3589 Gauge BAKER GAUGE CARRIER MODEL 925 3.970 Carrier I ~ I 7051 3613 SEAL BAKER 80-40 SEAL ASSEMBLY W/PBR 3.875 SLEEVE aolaata ' 7056 3615 PBR BAKER PBR 3.875 p , OD:s 2so) e ' 7086 3625 PACKER BAKER PACKER W/MILLOUT EXTENSION, ID 4.54" 3.875 . j ~ 7109 3632 NIP CAMCO'DB' NO GO NIPPLE 3.750 BUSHING ,4 - 7335 3697 WLEG CAMCO WIRELINE GUIDE 3.960 (741 a-7416, i 1 t ~ ~ ~. 7356 3702 -- HANGER D-SAND FLANGED HOOK H4NGEP FOR UPPER LATERAL LEr; LINER - - - 5 630 OD:5.540) General Notes _ _ Date Note NIP 4/29/2003 NOTE: MULTILATERAL WELL - 1C-178 (B/C-SANDS), 1C-178L1 (D-SAND) pays-7ats, - OD:6.060) i i XO - (7428-7430, OD:5.770) ~ I I Perf -- I 1 - ~ i (7704-13179) ~ ~~ ~ ~ - I ~ , _. ~~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 23, 2008 • ~~ BEd ~ 2~~? ~l~~l~a ~1i~ ~ ~~~ C~3~., ~r~t!at~~si~n l~r~~horags Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear. Mr. Maunder: Enclosed please find 10-404 Report of Sundry Well Operations & picture of repair for ConocoPhillips Alaska, Inc. well 1C-178 (PTD 203-041, Sundry #307-360). The report records the successful surface casing patch job Please call M.J. Loveland/Perry Klein at 659-7043 if you have any questions. Sincerely, ~~ "Perry Klein Well Integrity Project Supervisor ~~'~~ ~~R ~ ZaQ~ ~~B ~ STATE OF ALASKA ~~~$ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~ ~ SIR ~ ~t1 FOR"' ~O~If111t;4j0i1 REPORT OF SUNDRY WELL OPERATION ~~:.,,,,..,rt~ 1.Operations Performed: Abandon ^ Repair Wetl ^ Plug Perrorations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number. ConocoPhillipS Alaska, InC. Development ~ Exploratory ^ 203-041 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23144-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 8T - 1 G178 ` 8. Property Designation: 10. Field/Pool(s): ADL 25649/ 25638 ' Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 13280' ~ feet true vertical -3811' ~ feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 16" 110' 110' SURFACE 7647 7-5/8" 7734' 3770' LOWER LATERA 5815' 4-1/2" 13244' 3810' Perforation depth:. Measured depth: 7704' -.13179' Slotted liner true vertical depth: 3767' - 3809' Slotted liner Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7336' MD. Packers &SSSV (type & measured depth) Packer- Baker Packer w/Millout extension Packer= 7088' SSSV= Camco DB Landing Nipple SSSV= 498' 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 n/a n/a n/a n/a n/a Subsequent to operation n/a n!a n/a n/a n/a 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt 307-360 contact Brent Rogers/Martin Walters __ __ Printed Name Brent Rogers Title Problem Well Supervisor Signature Phone 659-7224 Date 2/22/8 Pre ared b Sharon Allsu Drake 2634612 Form 10-404 Revised 04/2004 ~°~~.~ i,~~.. F ;. 4~ ,» 2GOtt submit o,~~~~~~ • • 1 C-178 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/22/2007 2/19/2008 2/20/2008 2/21/2008 SET 3.813" DB BLANKING PLUG (44" OAL; EQ PRONG = 77" OAL W/ 1 3/4" F/NECK) AT 7109' RKB. Purged N2 across conductor stub (swamp gas) while welding, welded the top and bottom collars (didn't finish weld on bottom of lower collar). Then we placed the sleeve to be weld the Following day. SC patch weld -Complete. Purge nitrogen down annulus while welding. Patch Welded as per M.E. specs. Weld 8" 0.500 upper wedding band in no-go style, 8" lower 0.500 wall X-65 wedding band. Install 9-5/8" OD, L 80 casing (0.395" wt) SC patch that straddles SC collars. Total patch length from bottom of wellhead to lower most wedding band is 6' 11 ". MIT IA SC repair passed. Pressure up IA to - 1000 psi no leaks, pressure to 2000 psi no leaks, pressure to 3000 psi started MIT IA, Initial T/I = SI/0, start = SI/3000, 15 min. _ SI/2910, 30 min. = SI/2900, 45 min. SI/2890, 60 min. = SI/2890. Bleed down IA to 0. Final T/I = SI/0. Then wrapped SC with Denso wrap. 2/22/2008 Install 8 '4" of new 16" 0.375 conductor. ! ~ :°- e ,1L .rrf ~ n"r y .n.,! ~:, } z1' ':.~ ~ * ,. ,~:::. ^ i/7', .~.~ i,.E' ' . ~~ ' ~.; ,~ ,, ti;' ~ ! y t ~ r „k o ~~"~ ~ ~ .et ~ ~~ ~ ~ 'i w .h ,I ~. i 11 ~. ~ ~t; ~ r ~ y~, ~ f i ~ i I~~ti~ ~: ~ '~~~~~~ ~ ~ 1~"Rii '~ ^ ~ .3 ~ n ~ ~Zw44 r ~t i II ~ 1, ~~y~ f~Fy~~ ~,_ Ili +! t I Y. ~,~ _ ~_b ~.~ ar ~~,:, -~,... r T~ :c ~'_."~ .. ~'~ ~, w ~ ~~ jj w.~ : w , ~..~~ $ r '. ... ~ k.„~l ttr ;fw.~k , 1 it i, 1 ~t 11~ ~ip~~~tisf8 rp ,,. _~r ~~ r ~x , .~~ y fr' ~ ~~ ~ ~j - ~ .., , -~~ w ~, rk s ~" ~ ~ ~ 1. ~;~ 1.1. .. ~ i 1N' ~ ~ ~ •. ~~~; - .j ~~ wSP. „ i' {fi • ~.l _ ~ 1 __ ~..~ .. ~, r ~~~~"/ N ii _ ~~ f i ~~ a ,~ ~ ~ ~:, - ~ 'r u~ '~'~' A ~ ~„ i ry ~,R .~ +i~a • • MICROFILMED 03101 /2008 DO NOT PLACE '. ~,~ ~~ ` ANY NEW MATERIAL UNDER THIS. PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc ~~ ;. IfVGLL~ ~fd47 1"~,4/If5/Vl/~!"AL ProActive Diagnostic Services, Inc. To: AO(~C Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 • ~'~~;~~~~ JAN ~ `~ ?_008 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTI~ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaskaj, Inc. Petrotechnical Data Center Attn: Andy Farmer LR2-1 900 E. Benson Bhrd Anchorage, Alaska 99508 and ProActive Diagnostic Services., Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245-8951 1 ] MTT 2] Signed Print Name: 22-Dec-07 1 G178 ~d4 '~ '~'~ ~ ~ ~{a A ut ~ P a. ,~~ ~ _:~ Date . PROACTIVE DIAGNOSTIC SERVICES, tNC., 130 W. INiERNAT1oNJU. AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : ~dsanchoraaeCa7rtaenaorvtoe~com WEBSITE : www.avaera~orytoa.corn ~d3 -oil / 1 Report 50-029-2314400 D:\Master_Copy_~_PDSANC-20~edZ_Word\Distdbution\Tiansatittal_Sheeh+\Tianstnit_Original New.doc • • Memory MTT Log Results Summary Company: ConocoPhillips Alaska, Inc. Log Date: December 22, 2007 Log No.: 7208 Run No.: 3 (MTT) Pipet Desc.: 4.5" 12.61b. IBTM Pipet Use: Tubing Pipet Desc.: 7.625" 29.7 Ib. BTGM Pipet Use: Surface Casing Pipe3 Desc.: 16" 62.5 Ib. Welded Pipe3 Use: Conductor Well: 1 C-178 Field: Kuparuk State: Alaska API No.: 50-029-23144-00 Top log Intv11.: Surtace Bot. Log Intvl1.: 200 Ft. (MD) Top Log tntvll.: Surtace Bat. Log Intvl1.: 200 Ft. (MD) Top Log Intvll.: Surtace Bot. Log Intv11.: 110 Ft. (MD) Inspection Type : Cor-firmation of MTT Recordings made on 93-Oct-2007 COMMENTS ; The MTT data from this log has been tied into the Casing Hanger ~ 0' to core/ate to the previous MTT log of this well. This is the third log of this well made with the 12 Arm Magnetic Thickness Tool (MTT) over the top 200'.The second fog indicated a significant increase in metal loss just below the casing hanger relative to the first tog of this well. This third confirmation run has been made due to a combination of data quality concerns and recordings of what appear to be a substantial loss of metal to the second log of this well. The passes in this log were run at 15 fpm -half the normal logging speed of 30 fpm. The slower lagging speed appears to have had a significant positive effect on data quality and this log points to support for a significant increase in metal toss just below the casing hanger during the time between the first two logs -though less severe than indicated by the mutts of the second log. The MTT responds to the total thickness of metal of the 4.5" tubing and 7.625" surface casing, with some influence from the 16" conductor pipe. Passes at 8Hz, 10Hz and 12Hz were made at 15 fpm, with the 8Hz and 10Hz passes providing what appears to be high quality data sets with no data filtering required. INTERPRETATION OF MTT LOG RESULTS A log plot of the MTT recordings at 8Hz and 10Hz from surtace to 200', plus detailed sections of intervals showing the most significant damage recorded are included in this report. The Delta Metal Thickness (%) curve in these plots refers to total metal surrounding the MTT tool, which includes both the tubing and casing strings. 8 Hz Pass (1Sfpm) - A maximum of 29°~6 circumferential metal loss is recorded just below the mandrel hanger in the interval between 0' - 3'. A 4% circumferential metal loss is recorded in the interval between 5' and 7'. Circumferential metal loss of 2% to 4% is indicated over the interval from 64' to SO'. 10Hz Pass (15 fpm) - A maximum of 25°~ circumferential metal loss is recorded just below the mandrel hanger in the interval between 0' - 3'. A 3% circumferential metal loss is recorded in the interval between 5' and T. Circumferential metal loss of 2% to 3% is indicated over the interval from 64' to 80'. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 4.5", 7.625" and 16" pipe. If all of the metal loss is ProActive diagnostic Services, Inc. / P.O. Box 1359, Stafford, TX 77497 Phone: (281} or (888} 565-9085 Fax; (281} 565-1369 E-mask; PDS~memary4og.cai~ Prudhoe Bay Field Office Phone: {907} 659-2307 Fax: (907) 659-2314 ~i!~E~ 0 ~ ~0'~`~ ,~iaska CJiI tx C~as uc~r+~, t;c~~tnissir?r ~~~:hcrage ~D3- v`!/ specific to the 7.625" surface casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing or 16" conductor. Due to the concentric pipe strings in the tog interval, the MTT response is qualitative -indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in ' metal thickness occurs. In this log, the MTT was calibrated down hole (160'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 4.5" tubing, 7.625" casing, and 16" conductor pipe. t COMPARISON TO PREVIOUS MTT LOG RESULTS ' A comparison between the current log and first MTT log of the top 200' of this well (September 8, 2006) indicates a significant decrease in metal volume (from -17% to 25%} over the interval 0' - 3'. A maximum decrease in metal volume of 36% was indicated over this same interval in the second log of this well. This ' value appears to have been exaggerated (by about 5% to 10%}by data filtering that utilized some data recordings made inside the casing hanger. This comparison is derived from three successive passes made at 10Hz togging frequency. A log plot overlay of the average metal thicknesses recorded at 10Hz and the previous logs is included in this report. The 8Hz pass made at 15 fpm during this third MTT log appears to be of very high quality. The lower recording frequency (8Hz) should "look farther out" than the higher recording frequency (10Hz} and be more susceptible to influence by the 16-inch conductor pipe. The 8Hz pass made during this log run indicates a maximum decrease in metal volume of 29% in the interval just below the casing hanger (0' - 3'}, compared to 25% indicated by the 10 Hz pass. We believe that this pass further supports the documentation of a decrease in metal volume from about 17% to about 279/0 over the interval 0' - 3' since the first MTT log of this well made on September 8, 2006_ A log plot overlay of the average metal thicknesses recorded at 8Hz and the previous logs is included in this report. Field Engineer: 1Nm. McCrossan Analyst: M. Lawrence l J. Thompson / J. Burton Witness: R. Ober ProActive Diagnostic Services, Inc. t P,Q. Box 1369, Stafford, TX 77497 Phone: 1;281) or {888) 565-9085 Fax; (281) 565-1369 E-mail: FDS` memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 PnoAcdvE DLgnosdc SERVIcs,. Inc. Comparison to Previou~TT Logs Overlay December 22, 2007, October 13, 2007 and September 8, 2006 Database File: d:lwarrior\datal1c-1781comp.db Dataset Pathname: merge2 Presentation Format: 2.4 comp Dataset Creation: Wed Dec 2617:42:55 2007 Charted by: Depth in Feet scaled 1:100 -50Delta Mtl Thickness (12!07) (%) 50 -50Delta Mtl Thickness (10!07) (%) 50 -50Delta Mtl Thickness (09/06) (%) 50 -10 - Tree 5" ll C . o ar Hanger ~~ 10 .Jt. 1 20 4.5" Cot lar,~_ -~v- 40 7 62 5" C i Jt. 2 uar C - as . I -rt-t- o ng I Comparison to Previou~ITT Logs Overlay December 22, 2007, October 13, 2007 and September 8, 2006 a P~,i„E Inq»os,+c ScRVIc 6. Inc. Database File: d:lwarriorldatal1c-1781comp.db Dataset Pathname: merge1 Presentation Format: 24COMP~1 Dataset Creation: Wed Dec 616:58:25 2007 Charted by: Depth in Feet scaled 1:100 -50Delta Mtl Thickness (12/07) (%) 50 -50Delta Mtl Thickness (10/07) (%) 50 -50Delta Mtl Thickness (09!06) (%) 50 Tree -10 I I Hanger 5" (Collar~~ 10 20 4.5" Collar 40 Collar ~~ o~~~ 5~~~, ~~_ Magnetic Thickne,Log (10Hz) December 22, 2007 Database File: 1c-178.db Dataset Pathname: 10hz15.1 Presentation Format: 3 scale Dataset Creation: Wed Dec 2611:36:59 2007 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 1:50 0 MTT Frequency (Hz) 20 3 MTTP01 (rad) 13 -50 MPCMN (%) 50 -5.8 MTTP12 (rad) 4.2 0 Line Speed (ft/min) -200 Tree f 5" Col lar Hanger ~ = i e . n ,, 25% Me tal L oss ~ ~ - 3% Met al L oss 1 r Jt. 1 0 i i 2 5 0 MTT Frequency {Hz) 20 3 MTTP01 (rad) 13 -50 MPCMN (%) 50 -5.8 MTTP12 (rad) 4.2 0 Line Speed (ft/min) -200 Magnetic Thickne~Log (10Hz) P~~ ~~~ s<~~. ~ December 22, 2007 Database File: 1c-178.db Dataset Pathname: 10hz15.1 Presentation Format: 3 scale Dataset Creation: Wed Dec 2611:36:59 2007 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 1:150 0 MTT Frequency (Hz) 20 3 MTTP01 (rad) 13 -50 MPCMN (%} 50 -5.8 MTTP12 (rad) 4.2 0 Line Speed (ft/min) -200 Metal Jt. 1 20 40 Jt. 2 Collar 5" Metal Jt. 3 Metal Loss 80 5" Casing Collar ~" C:onar~ 100 Jt. 4 Bottom of 16" Conductor 120 I 4.5" CoHar~'~~ .625" Casing Collar Jt. 5 ' 140 ' ~ 4.5" Collar~'r~~ 160 ' Jt. 6 7.625" Casing Collar 180 r ~ .5" Collar~~ Jt. 7 200 r MTT Frequency (Hz) 20 0 MPCMN (%) 50 -50 Line Speed (ftlmin) X00 0 13 MTTP01 (rad) 3 42 MTTP1 ~ (rad) -5.8 ~~ o~ ~~~ ~~. Magnetic Thickn~ Log (8Hz} December 22, 2007 Database File: 1c-178ab.db Dataset Pathname: 8hz15.1 Presentation Format: 3 scale Dataset Creation: Wed Dec 2613:59:58 2007 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 1:50 0 MT T Frequency (H z) 20 3 MT TP01 (rad) 13 -5 0 MPCMN (%} 50 -5.8 MT TP12 (rad) 4.2 0 Li ne Speed (ft/mi n) -200 - ~ _ - - `_ --- - __ ..~ _ .=~ __ -; . _, r Tree - - _ __ - . _ - , __ ___ _ i ~ ~ , i i --i ' " H _ ~4.5 I 29% Co et llar l L ss anger ~.fi..~ - ~ ,_ ~ - i 4% Metal Loss I t Jt. 1 20 j 0 MTT Frequency {Hz) 20 3 MTTP01 (rad) 13 -50 MPCMN (%} 50 -5.8 MTTP12 (rad) 4.2 0 Line Speed (ft/min) -200 • KRU 1 C-178 ConocoPhillips Alaska, Inc. 10-178 API: 500292314400 Well T : PROD An le TS: d TUBING (a733s, SSSV Type: NIPPLE Orig C l ti 4/162003 Angle @ TD: 89 deg @ 13280 OD:4.500, ID:3.958) Annular Fluid: om o on: Last W/O: Rev Reason: CLOSE SLEEVE. NEW GLD Reference L : 28' RKB Ref L Dete: last U te: 8/72007 Last T TD: 13626 ftK6 Last Ta Date: Max Hole An le: 92 d 11208 Casin Strin - B/C-SAND LINER Alternati 30' sections of bla nk i 8 slott ed liner Descri lion Size T Bottom TV D Grade Thread Lower Lateral Slotted Liner 4.500 7429 13244 381 0 12.60 L-80 SHLT Casin Stri L STRINGS Daecri lion Size To Bottom Wt Grede Thread SURFACE 7.625 0 7734 3770 29.70 L-80 BTCM CONDUCTOR 16.000 0 110 110 62.50 H-40 WELDED tubi Stri -TUBING BUSHING (~y,sgl, Size To Bottom TV Grede Thread oD:s.020) 4.500 0 7336 3697 12.60 L-80 IBTM ~ ~ P ra io 3umm Interval TVD Zone Status Ft 8PF Date T Comment 7704 - 13179 3767 - 3809 WS B,WS B, WS C 5475 99 4/162003 IPERF SLOTTED LINER Gas Lift MandrelsNalves St MD TVD Man Mfr Men Type V Mfr V Type V OD latch Port TRO Date Run Vlv Cmnt 1 3752 2398 CAMCO KBG-2 GLV 1.0 BK 0.156 1450 625/2007 2 6827 3539 CAMCO KBG-2 OV 1.0 BK 0.313 0 6!252007 ~,~, ~ Other s ui .etc. -LOWE R LINER JEWS Y OD:5.500) De fh T Descri lion ID 7401 3714 PUP 4.830 7401 3714 SLEEVE 5.010 7414 3717 BUSHING BAKER BUSHING 7.875 7416 3717 NIP BAKER RS NIPPLE 4.875 7419 3718 HANGER BAKER FLEX LOCK HYDRO REOTATING LINER HANGER 4.830 7428 3720 XO XO TO 4.5" LINER 3.940 7430 3720 Bank Liner BLANK LINER IN 30' SECTIONS, ALTERNATING WITH SLOTTED LINER 30' SECTIONS 3.958 7493 3735 Blank Liner 3.510 7704 3767 LOCATOR BAKER LOCATOR SUB 3.510 13242 3810 SHOE GUIDE SHOE 4" ROT SILVER BULLET W/ECCENTRIC NOTE (float drilled 0.000 ou Other ui .etc. -COMP TION JEWELRY D th TVD T Descri lion ID SURFACE 26 26 HANGER VETO GRAY GEN 1 MCA TOP CONNECTOR 4.500 (an3a, 49g Ogg NIP CAMCO'DB' LANDING NIPPLE 3.875 ~~~j 6881 3557 Gauge Carrier BAKER GAUGE CARRIER MODEL 925 3.970 6924 3571 BUSHING BAKER PROTECTOR BUSHING 3.920 6925 3572 SLEEVE-C BAKER CMU SLIDING SLEEVE -CLOSED 6252007 3.813 SLEEVE I ' 6976 3589 Gouge Carrier BAKER GAUGE CARRIER MODEL 925 3.970 (7ao1-7414. 7051 3613 SEAL BAKER 80-40 SEAL ASSEMBLY W/PBR 3.875 o° s ~°> 7056 3615 PBR BAKER PBR 3.875 7086 3625 PACKER BAKER PACKER W/MILLOUT EXTENSION ID 4.54" 3.875 BUSHING (7414 741s 7109 3632 NIP CAMCO 'DB' NO GO NIPPLE 3.750 - ' OD:5.540) 7335 3697 WLEG CAMCO WIRELINE GUIDE 3.960 7356 3702 HANGER FLANGED HOOK HANGER FOR UPPER LATERAL LEG LINER 5.630 NIP Gener al Note s (7416-7419, oo s oso ~~ ~~ . . ) 4/292003 NOTE: MULTILATERAL WELL - 1C-178 (B/C-SANDS), 1C-178L1 (DSAND) xo pa28-7430, OD:5.770) ^ ^ Pert (7704.13179) ~ ~ I - ~ ~ ~ ~ ~ ~ Q SARAH PAL/N, GOVERNOR 0 CO~~'+Lt~~j~=O ~ -7 333 W 7th AVENUE, SUITE 100 1 L ii ~~`•••~~~111~~'///iii---777 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brent Rogers Problem Well Supervisor Conoco Phillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 t:',y~~$ ~~~ ~. ~~~~ Re: Kuparuk River Field, West Sak Oil Pool, 1 C-178 Sundry Number: 307-360 Dear Mr. Rogers: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ,~ day of December, 2007 Encl. ~U3'- lam{ ~ Sincerely, ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 28, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 1C-178 (PTD 2030410). The application is for approval to perform a proactive production casing excavation, inspection, and repair if needed on the well ' '~'`~ Please call Brent Rogers or Martin Walters at 659-7224 or Perry Klein or MJ Loveland at 659-7043 if you have any questions. Sincerely, d°7, /~~ Brent ogers Problem Well Supervisor ~~" ~lOV 2 ~ '~'~~' ~las9~a ili9 ~ Oas Oars:. x~~s~~sas~~~° ~nchora~~ D i~ r~~ t3 GP~12-~3~°~ R,~~ C STATE OF ALASKA ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION t ~~ ~a ~ ~ ~ ~~d~ APPLICATION FOR SUNDRY APPROVAI,~i~sk~ [~~1 ~ ~~~ a~ara~. ~mm~ss~~,~ 20 AAG 25.280 Anl<~~~al~ 1. Type Of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^/ ,- Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^/ Exploratory ^ 203-041 - 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23144-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS NO^ 1C-178 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25649! 25638' RKB 87' Kuparuk River Field /West Sak pil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13280' ~ 3811' ' Casing Length Size MD ND Burst Collapse CONDUCTOR 110' 16" 110' 110' SURFACE 7647 7-5/8" 7734' 3770' t LATERAL SLOTTE 5815' 4-1/2" 13244' 3810' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7704' - 13179' Slotted liner 3767' - 3809' Slotted liner 4-1/2" L-80 7336' Packers and SSSV Type: Packers and SSSV MD (ft) Packer= Baker Packer w/Millout extension Packer= 7086' SSSV= Camco DB Landing Nipple SSSV= 498' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Development Q Service ^ 15. Estimated Date for 16. Wetl Status after proposed work: Commencing Operations: 12/11/07 Oil 0 Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brent Rogers/Martin Walters Printed Name Brent Rogers Title: Problem Well Supervisor Signature Phone 659-7224 Date 11/28/07 Commission Use Onl Conditions of approval: Notify Commission so that a representative may witness Sun~~um~er: ~/~ --(- lLJ Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: ~~c~il ~~jQC~-"~OC~ ~~dQ~iC9~s ~ ~~~'~~'~ .. ~~"~1~- ~~~ ~ ~ 2~~~ Subsequent Form Required: ~~ t--~ v"~ / ~ ~~ V~~ 0~`T ~® K\ O ~ :~ C3~ {~-- APPROVED BY /~~ j ~~ Approved by: M SIO THE COMMISSION ~ Date: / J Form 10-403 Revised 06!2006 V -`~ ~( ~ K ~ {., ~ n) ~ ~ ~ ~ ~~~ Submit r D ~~ca~~ ConocoPhillips Alaska, Inc. Kuparuk Well 1C-178 (PTD 2030410) SUNDRY NOTICE 10-403 APPROVAL REQUEST November 28, 2007 This application for Sundry approval for Kuparuk (WestSak) well 1C-178 is for the proactive ~ inspection and possible repair of the production casing near surface. This well is a single casing surface powered jet pump well that has no surface casing. It was completed in 2003 and has been on surface power jet pump lift since 2006. This well is on a Drillsite that has a recent history of production casing leaks to surface. 1C-178 has shown no signs or indications of a production casing leak however ConocoPhillips requests approval to proactively excavate ~ 10', cut a window in the conductor and inspect the production casing in this well. If damage is present a patch will designed and installed. With approval, inspection and possible repair of the production casing will require the following general steps: 1. Safe-out the well as needed with a tubing tail plug. 2. Remove the floor grate and equipment from around the wellhead. 3. Remove the previous sealant treatment from the conductor. 4. Install nitrogen purge equipment for the conductor (and IA if needed) so that hot work may be conducted in a safe manner. 5. Cut away the conductor casing and remove cement around surface casing for inspection. A window will be cut in approximately the top ten feet of conductor to provide access to the production casing for inspection. Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine if patch or repair is needed to return the casing to operational integrity. 7. If a patch is required, QA/QC will verify the repair for a final integrity check. 8. Install anti-corrosion coating as specified by CPAI Corrosion Engineer. 9. Replace the conductor and fill the void with cement and top off with sealant. 10. Backfill as needed with gravel around the wellhead. 11. Remove plugs and return the well production. 12. File 10-404 with the AOGCC post re air. NSK Problem Well Supervisor 11/27/2007 '~ (77i ConocoPhillips Alaska, Inc. KRU 1 C-178 ~c-~7s API: 500292314400 Well Type: PROD An le TS: d TUBING 1o-733s, )D:a SOO -- -~ SSSV Type: _ __ -- -- NIPPLE -- Orig Com letion: _ 4/16/2003 -- Angle @ TD: 89 deg @ 13280 . , ID:3.958) Annular Fluid: Last W/O: Rev Reason: CLOSE SLEEVE, NEW GLD Reference L 28' RKB Ref L Date: Last U ate: 8/7/2007 Las t Ta TD: 13626 ftKB `` ~ _ Last Ta Date: Max Hole An le: 92 de 11208 Casing String - B/C-SAND LINER Alternating 30' sections of blank i e & slott ed liner _ Desorption . Size T~ Bottom ND Wt Grade Thread _ Lower Lateral Slotted Liner _ 4.500 _ 7429 13244 3810 12.60 L-80 SHLT Casin Strin -ALL STRINGS Description Size To Bottom TVD_ _ Wt Grade Thread SURFACE 7.625 0 7734 3770 29.70 - L-80 BTCM - CONDUCTOR - 16.000 0 - _ 110 110 62.50 H-40 WELDED 3USHING Tubin String -TUBING __ ,pa~yp5 . . --- - Slze __ To ~ Bottom 7VD Wt Grade _ _ Thread , >D:s.o2o) _ 4.500 _ -_ 0 - 7336 _ 3697 12.60 L-80 IBTM I I Perforations Summar / Interval _ TVD Zone _ Status Ft SPF Date T e Comment 7704 - 13179 3767 - 3809 WS B,WS B,WS C 5475 99 4/16/2003 IPERF SLOTTED LINER Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 3752 2398 CAMCO KBG-2 GLV 1.0 BK 0.156 1460 6/25/2007 2 6827 3539 CAMCO KBG-2 OV 1.0 BK 0.313 0 6/25/2007 ~5, i s~ lugs, a ui ., etc.) LOWER LINER JEWELRY Other )D:5.500) . Dee th TVD TYpe _ Descrf lion ID _ 7401 3714 ___ . _ PUP _ _ _ _ 4.830 7401 3714 SLEEVE 5.010 7414 3717 BUSHING BAKER BUSHING 7.875 7416 3717 NIP BAKER RS NIPPLE 4.875 7419 3718 HANGER BAKER FLEX LOCK HYDRO REOTATING LINER HANGER 4.830 7428 3720 XO XO TO 4.5" LINER 3.940 7430 3720 Blank Liner BLANK LINER IN 30' SECTIONS, ALTERNATING WITH SLOTTED LINER 30' SECTIONS 3.958 7493 3735 Blank Liner 3.510 7704 3767 LOCATOR BAKER LOCATOR SUB 3.510 13242 3810 SHOE GUIDE SHOE 4" ROT SILVER BULLET W/ECCENTRIC NOTE (float drilled 0.000 out Other plu s equip. etc.) -COMPLETION JEWELRY De th TVD T e Descri lion ID uRFACE 26 26 HANGER VETO GRAY GEN 1 MCA TOP CONNECTOR 4.500 to-773x• ~D 7 625 498 498 NIP CAMCO'DB' LANDING NIPPLE 3.875 : . , Nt:2s.7o) 6881 3557 Gauge Carrier BAKER GAUGE CARRIER MODEL 925 3.970 6924 3571 BUSHING BAKER PROTECTOR BUSHING 3.920 6925 3572 SLEEVE-C BAKER CMU SLIDING SLEEVE -CLOSED 6/25/2007 3.813 SLEEVE - I I 6976 3589 Gauge Carrier BAKER GAUGE CARRIER MODEL 925 3.970 got-7ata, 7 051 3613 SEAL BAKER 80-40 SEAL ASSEMBLY W/PBR 3.875 )D:s.29o) _ 7056 3615 . _ PBR BAKER PBR 3.875 7086 3625 PACKER BAKER PACKER W/MILLOUT EXTENSION, ID 4.54" 3.875 3USHING rta-7ats ~ 7 109 3632 NIP CAMCO'DB' NO GO NIPPLE 3.750 , )D:5.540) _ 7335 3697 . WLEG CAMCO WIRELINE GUIDE 3.960 7356 3702 HANGER FLANGED HOOK HANGER FOR UPPER LATERAL LEG LINER 5.630 NIP 'General Notes its-7at9, >DS oso Date Note ) . ' 4/29/2003 NOTE: MULTILATERAL WELL - 1C-178 (B/C-SANDS), 1C-178L1 (D-SAND) xo r28-7430, ~D:5.770) Perf )4-13179) 1 I 1 I 1 ~~; • • I~1l~~L LE?Ea' TR,4/USIVI/TT,4L ProActive Diagnostic Services, Inc. To: ADDCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907] 659-5102 RE : Cased Hale/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP E~loration (Alaska), Inc. Petrotechnical Data Center Attn: Andy Farmer LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and =~~~~ Nall ~ ~ 2007 ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road ~ _s Suite C ~~ %> U ~ Anchorage, AK 99518 Fa~c (907) 2458951 ,~'~'~ 1) Caliper Report / MTT 13-0ctr07 1 C-178 1 Report (Caliper Report delivered 10/24) 50-029-23144-00 2j , _ .~ ~ a Signed : Date : '' `' y, `'' Print Name: ~ 1,~ C i 5{-1 ~A ~- -1lL~ti ., ~ PROACTNE DIAGNOSTIC SERVICES, O1C., 1S0 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 98518 PHONE: (807)245-8851 FAX: {907)245-88952 E-MAIL: ~aels~~~~€sr~~e(~rr~e~®r3l~e~~~~? WEBSITE: nr~r~~v.~aerr€~rrl~a.~~r~ D:1Master_Copy_00 PDSANC-ZO~ac~Z_WordtDishibulion\T~ansnudal_Sheels~T,az~nit Onginsl_New.dce i~ • • Memory Ml"I' & multi-finger Caliper Log Results Summary Company: ConocoPhilllps Alaska, Inc. Log Date: October 13, 2007 Log Na.: 8644 Run No.: 1 (Caliper) / 2 (MTT) Pipet DeSC.: 4.5" 12.61b. IBTM Pipet Use: Tubing Pipet Desc.: 7.625" 29.71b. BTCM Pipet Use: Surtace Casing Pipe3 Desc.: 16" 62.5 Ib. Welded Pipe3 Use: Conductor Well: 1 C-178 Field; Kuparuk State: Alaska API No.: 50-029-23144-00 Top Log Intvl1.: Surface Bot. Log Intvl1.: 7,107 Ft. (MD) Top Log Intv11.: Surface Bot. Log Intvl1.: 7,105 Ft. (MD} Top Log Intvll.: Surface Bo#. Log Intvl1.: 710 Ft. (MD) Inspection Type : Corrosive 8 Mechanical Damage Inspection COMMENTS The Caliper data from this log is tied into GLM 2 ~ 6,827' (Drifter's Depth). The MTT data from this tag has been tied Into the Casing Hanger ~ 0' to correlate to the prerriaus MTT log of this welt. This is the first log of this weA made with the 40 Arm Caliper and the first log of this welt with the 12 Arm Magnetic Thickness Tool (MTT) over the interval 200' to 7,107'. This is the second log of the top 200' of this well made with the MTT. The caliper records internal features of the 4.5" tubing and the MTT responds to the total thickness of metal of the 4.5" tubing and 7.625" surface casing, with some influence from the 16' conductor pipe. INTERPR,~TAT10~1 OF CALIPER LOG RESULTS The caliper recordings indicate that the 4.5" tubing interval logged is in good condition with respect to corrosive damage. No significant wall penetrations {>20%), areas of significant cross-sectional metal loss, or significant I.D. restrictions are recorded. 4.5" TUBING -MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations {> 15%) are recorded. 4.5" TUBING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall loss (> 7%) are recorded. 4.5" TUBING -MAXIMUM RECORDED ID RESTRICTIONS: No significant LD. restrictions are recorded. INT~RPRETATIO OF MTT LOG RESULTS A fog plot of the MTT recordings from surtace to 200', plus detailed sections of intervals showing the most significant damage recorded are included in this report The Delta Metal Thickness (%) curve in these plots refers to total metal surrounding the MTT tool, which includes both the tubing and casing strings. n ProActive Diagnostic Services, Inc. / P,O. Box 1369, Stafford, TX 77497 Phone: (281) or {888) 565-9085 Fax: (281) 565-1369 E-mail: PDSrmemoryiog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: {907} 659-2314 ' ao3-~~ • ~ A maximum of 36% circumferential metal loss is recorded just below the mandrel hanger in the interval between 0' - 3'. A 4% circumferential metal loss is recorded in the interval between 5' and 7'. Circumferential metal loss of 2°r6 to 4% is indicated over the interval from 64` to 80'. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 4.5", 7.625" and 16" pipe. If all of the metal loss is specific to the 7.625" surface casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing or 16" conductor. Due to the concentric pipe strings in the log interval, the MTT response is qualitative -indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In #his flog, the MTT was calibrated down hole (85' ~ 3510'}, where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 4.5" tubing, 7.625" casing, and 16" conductor pipe. The original MTT data recorded in this well exhibited a high signal to noise ratio throughout the data set, and was high-pass filtered prior to being analyzed. While this filtering of the original data may have masked some high frequency isolated damage indications, it should have no significant eti'ed on the measurement of overall circumferential metal loss discussed in this analysis. COMPARISON TO PREVIOUS MTT LOG RESULTS A comparison between the current log and the previous MTT log of the top 200' of this well(September 8, 2006) indik~tes a significant decrease in metal volume over the interval (0' - 3'} and a slight decrease in metal volume over the interval (5' - 7'}and (64' - 80') as recorded by the MTT. A log plot overlay of the average metal thicknesses recorded by the MTT for the current and previous log is included in this report. Field Engineer. K. Miller Analyst: 8. Qi (caliper) /M. Lawrence & J. Burton (MTT) Witness: C, Fitzpatrick ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS~~memorylog.cam Prudhoe Bay Field Office Phone: (9C7) 659-2347 F=ax: (907) 659-2314 • PDS Report Overview '~: s. Body Region Analysis Well: 1C-178 Survey Date: October 13, 2007 Field: Kuparuk Tool Type: MFC 40 No. 30807 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: B. i Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 4.5 ins 12.6 f L-80 3.958 ins 4.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ,sue metal loss body 250 200 150 100 50 0 0 to 1 to 10 ro 1% 10% 20% 20 ro 40 ro over 40% 85% 85% Number of 'oints anal se d total = 237 pene. 16 219 2 loss 150 87 0 0 0 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole /pons pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 2 2 0 0 0 0 Damage Profile (% wall) ~ penetration body „~;~. metal bss body 0 50 100 GLM 2 i GLM 1 I Bottom of Survey = 224.6 Analysis Overview page 2 1 1 • • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 Well: 1 C-178 Body Wall: Upset WaU: 0.271 in Field: 0.271 in Company: Kuparuk ConoooPhiYips Alaska, Inc. Nominal I.D.: 3.958 in Country: Survey Date: USA October 13, 2007 Joint No. Jt. Depth (Ft.) I'e~n. Upset. (lns.) Pen. Body (Ins.) Pen. %, ~tet,~l Ic»s °'~ Min. LD. (Ins.) Comments 0 Damage Profile (%wall) 50 100 1 8 U 0.01 ~ I 3.91 38 l) 0.01 ~ I 3.93 3 69 U 0. 1 3 I 3.91 4 1 U 0.01 ; 1 3.91 5 13 U 0.01 ~ 1 3.91 6 161 U 0.01 ~ 1 3.91 7 19 U 0.01 ~1 1 3.92 8 23 U 0.0 3 1 3.91 9 254 U 0.01 ~; I 3.91 10 285 tt 0.01 -1 I 3.93 1 16 U .01 ? I 3. 2 1 347 U 0 01 3 1 3.88 13 37 U 0.01 -1 I 3.91 14 9 U 0.01 ~ 1 3.91 1 440 t I 0.0 ~ 1 .9 151 47 U 0.01 4 1 3.90 PUP 15 2 480 U 0 1 1 ~ I 3.88 a c La i le . 15 3 ll 0. 0 1 1 .92 P . 16 2 U 0.01 (, I 3.91 17 23 U 0.01 ~ I 3.9 18 554 ~~ 1 3 1 3.89 19 585 U 0. 1 4 1 3.90 20 616 tt 0.01 4 I 3.91 21 647 U 0.01 4 1 3.92 7 l) 1 4 I 23 709 tt 0.01 4 I 3.92 24 738 tt 0.01 ; 3 1 25 769 tt 0.01 ~ 1 3.91 800 U 0.01 ~ 1 3.92 27 832 tl 0.01 4 1 3.90 28 863 U 0.01 3 I 3.92 29 893 i t 0.01 ; 1 3.92 30 924 t t 0. 1 4 I 3.92 31 955 U 0.01 5 1 3.88 3 986 t 1 0.01 4 1 3. 0 33 1017 tl 0.01 4 1 3.91 1048 t) 0 1 4 ' 3. 7 35 1078 i ~ 0.01 4 1 3.90 36 1109 ~t 0.01 4 ? 3.91 37 1140 tt 0.01 4 1 3.92 3 39 1171 1203 U t t 0.01 0.01 4 3 I 1 3.88 3.90 40 2 4 ~) 0.01 3 ~' 3.91 41 1265 (? 0.01 4 1 3.92 42 1296 ~~ 0.01 (> ~ 3.8 43 1328 U 0.01 4 1 3.93 44 1359 t t 0.01 Z I 3.89 45 1390 U 0.01 4 I 3.90 46 14 1 (t 0.01 ; 1 47 1452 ~) 0.01 4 ? 3.87 Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABULATION SHEEP Pipe: 4.5 in 12.6 ppf L-80 WeU: 1C-178 Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: October 13, 2007 Joint No. Jt. Depth (FtJ I'c~n. Ulxe~t Ilnti.) Pen. Body (Ins.) I'e°n. °~ .Metal loss `;'~~ Min. LD. (Ins.) Comments Damage Profile ~%~'~I) 0 50 100 48 1 U 0.01 2 1 .91 49 1 13 t) 0. 1 4 1 3.91 0 1544 t~ 0.00 1 1 3.91 51 1575 t) 0 01 3 1 3.90 52 1607 t) .O1 3 1 .91 3 1638 c) 0.01 a I 3.91 54 1668 a 0.01 ~ 1 3.9 5 1699 U 0. 1 4 1 3.91 56 1 31 U .01 (~ ' 3.89 7 1762 U 0.01 ~> .91 58 17 3 U 0.00 1 1 3.90 59 1824 a 0. 1 2 1 .91 t 'ts. 60 1855 U 0 03 1 t) Z 3.89 61 1886 t ~ 0.01 s 1 3.88 62 1917 t) 0.01 ~ ' 3.90 63 19 t~ 0.01 ~1 ~' 3 1 L . De i 4 1976 U 0 3 88 65 007 t 1 0. 1 ~ .91 66 2037 tt .0 I .91 67 2069 a 0.01 4 2 3.91 68 2 00 t) 0.01 4 ~' 3.91 9 131 t) 0 5 ' 3.89 70 216 U 0. E; ' 3.91 71 2192 t) 0.01 ~ 2 3.90 7 t) 0.0 E, ' . 0 73 2254 U 0.01 S 1 3.87 74 2285 t) 0.01 4 ? 3 91 75 2316 t~ 0.01 7 2 3.88 76 347 U 1 3 2 3.91 77 2378 O 0.01 5 1 3.89 78 2409 c) 0.00 1 1 .91 79 2440 t) 0.01 ~~ ' 3.92 80 2471 U 0.00 I _' 3.91 81 2502 t) 0.01 4 ? 3.89 82 2533 t) 0.01 Z I 3.91 83 2564 a 0.01 4 1 3.91 84 2595 t) 3 1 .8 85 262 t) 0.01 4 2 3.90 86 2657 t) 0.00 1 2 3.91 87 2689 U 0.01 3 1 3.92 88 2720 l) 0.01 t _' 3.89 89 2752 t) 0. 1 5 1 3.90 90 2783 U 0.02 ~ I .90 91 2814 t~ 0.01 4 I 3.92 9 2845 U 0.01 ~' 1 3. 9 93 2875 t) 0.01 ~ ~ 3.91 94 907 l l 0.01 i 3 89 95 2937 a 0.01 4 ~ 3.89 96 969 a 0. 1 1 1 3.91 97 2999 ~ ~ 0.01 3 1 3.92 _ Penetration Body Metal Loss Body Page 2 ~ ~ PDS REPORT JOINT TABULATION SHEEP Pipe: 4.5 in 12.6 ppf L~0 Body Wall: 0.271 in Upset WaA: 0.271 in Nominal I.D.: 3.958 in WeN: 1 C-178 Field: Kuparuk Company: ConocoPhilips Alaska, Inc. Country: USA Survey Date: October 13, 2007 Joint No. Jt. Depth (Ft.) f'~~n. UF~Sr•l (In~.j Pen. Body (Ins.) Pcai. % Mct,rl Lr~,s .~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 98 3030 t) 0.00 1 _' 3.90 99 306 t) 0.01 4 I 3.9 1 3093 l) 0.02 7 7 3. 9 1 1 3124 U 0.01 ~ 3.89 10 3155 t) 0.01 ~ 3.91 103 3185 t) 0.00 1 _' 3.90 1 4 3216 U 0. 0 I I 3.90 105 3247 c) 0.01 3 I 3.91 10 3 8 l) 0.01 3 1 3.91 107 3309 tt 0.01 ~ 1 3.92 108 3340 U 0.01 ~ 1 3.90 10 3371 U 0.01 5 2 3. 9 110 3402 t ~ 0 01 > _' 3.89 111 433 !~ 001 ~ I .91 112 3464 ~ ~ 0.01 s I .92 113 3494 t l 0 00 1 I 3.91 114 3526 t) 0.0 2 1 3.92 115 3556 U 0.00 1 1 3.89 11 587 t~ 0. 1 ~ l 3.8 117 3618 t ~ 0.01 ? 3.86 11 3 49 U 0.01 5 ~ 3.87 119 3678 l) 0.0 ti Z 3.85 120 3710 l) 0. 1 4 ~ 3.89 120.1 3740 t) 0.01 ~ 3.92 PUP 20.2 74 0 U t1 N A 1 Lat 7:00 120.3 3753 U 0.02 I 3.90 PUP 121 3759 t) 0.01 3.90 122 3790 a 0.01 5 3.91 123 21 r) 0.01 -1 ~ 3.90 124 3852 n 0.03 l U 2 3.86 125 3884 t) 0.01 4 2 3.85 126 3915 t) 0.02 b 1 3.89 127 3945 U 0.02 ~ I 3.90 128 3976 U 0.00 1 1 3.91 129 7 U 0.01 3 2 3.90 130 4038 t) 0.01 ~ 2 3.90 131 4069 ~~ .0 7 1 3.89 132 4101 t ~ 0.01 ~; 1 3.91 13 4131 t ~ 0.01 i 1 3.90 134 4163 U 0.01 4 ? 3.91 13 4193 U 0.01 4 ~' 3.87 136 4222 U 0.01 ; 1 3.86 137 4254 U 0.01 -1 I 3.91 138 4285 U 0.01 3 Z 3.91 139 4316 U 0.01 3 1 3.92 140 4347 c ~ 0.01 > 1 3.91 141 4378 U 0.01 -1 1 3.85 142 4409 U 0.01 2 3.90 143 4439 U 0.01 I .89 144 4470 c 1 0.01 3.91 Penetration Body Metal Loss Body Page 3 u • • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 Body Wall: 0.271 in Upset Wall: 0.271 in Nominal LD.: 3.958 in Well: 1 C-178 Field: Kuparuk Company: ConocoPhilips Alaska, Inc. Country: USA Survey Date: October 13, 2007 Joint No. Jt. Depth (Ft.) PE~n. t ll~sc°f (Ins.) Pen. Body (Ins.) Pen. °/, ~~1c~i,il I ins ,- Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 14 4501 ~) 0.01 3 I 3.89 146 453 ~) 0 01 4 I .90 1 7 4563 t) .01 2 I 3.9 1 4594 U 0.0 4 1 3.90 149 4625 0 0.01 4 1 3.91 150 4656 t? .01 3 1 3.90 1 1 4687 ! t 0.01 5 1 3. 1 152 4719 ~) 0.01 2 1 3.90 15 4749 t o 0.01 3 2 3 89 154 47 tt 0.01 ~ I 3.89 155 4812 U 0.0 5 ~ 3.90 1 t t 0.0 3 I 3.91 157 4873 U 0.01 ~ 3.9 158 4904 t t 0.01 ~ 3.90 159 4935 U 0.01 -1 I 3. 1 160 4967 t) 0. 1 i 3.90 161 499 l) .01 4 ' 3. 16 503 t t .01 4 1 3.9 1 3 5060 U 0.01 4 I 3.91 1 5091 tt 0.01 ~ 2 3.90 1 5 5122 tt .01 t, 1 .91 166 5153 U 0.01 i 2 3.89 167 5185 0 0.01 3 1 3.84 168 5215 U 0.01 4 ? 3.84 169 5247 C) .0 7 1 3.91 170 5278 ~~ 0.02 6 ~' 3.90 171 5 09 U .01 ~ 1 .91 172 5340 U 0.01 5 I 3.87 173 5370 t) .01 I 3.91 174 5401 O 0.01 ~ I 3.92 175 43 t1 0.02 t3 3. 176 5463 t) 0.00 1 ~ 3.89 177 5495 U 0.01 4 ? 3.91 178 5525 O 0.01 ; 1 3.84 1 9 5555 (1 0.01 ~~ 1 3.89 180 5586 U 0.01 -1 1 3.91 1 5617 tt 0.01 1 3. 182 5648 t t 0.01 -1 I 3.91 183 5679 t t 0.01 2 ? 3 89 184 5710 U 0.00 1 1 3.91 185 57 1 U 0.01 ' ~' .91 186. 5772 a 0.01 4 I 3.90 187 5804 (t 0.01 ~ I 3.91 188 5834 t) 0.01 ~ I 3.91 1 5866 tt 0.01 4 I .9 190 5896 ~. t 0.01 -1 I 3.91 191 5928 i) 0.0 i ~ .84 192 5959 U 0.01 ~3 ~ 3.89 1 3 5991 U ,0 ~ u 3 194 6022 t~ 0.01 a tt 3.91 Penetration Body Metal Loss Body Page 4 • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L~0 Well: 1 C-178 Body Wall: 0.271 in Feld: Kuparuk Upset Wall: 0.271 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: October 13, 2007 Joint No. Jt. Depth (FL) Pen. Up~c~) (In>.) Pen. Body (Ins.) P~~n. % ~t~ i,il lu<s °~> Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 195 605 ~) 0.01 4 1 .90 196 6084 ~) 0.01 4 ~' 3.86 1 7 611 a 0.01 5 1 3.91 198 6144 l) 0.01 ~ 1 3.90 199 6175 U 0.01 4 3.90 00 6206 U 0.01 l I 3.90 201 6237 U 0.01 =1 I 3.91 202 6268 i) 0.01 -i I 3.90 203 6299 ~ t 0.01 ~ _ 3.88 204 6330 l) 0.01 4 I 3.91 205 6361 ~ ~ 0 O1 ~1 _ 3.91 206 6390 t) 0.01 -1 I 3.87 207 64 1 O 0.01 & I 3.89 2 8 452 )) 0.01 ~ I 3. 3 209 6483 i) 0.01 ~ I 3.91 210 6513 ~) 0.01 S I 3.91 211 654-4 )1 0.01 4 3.91 212 6576 (~ 0.01 3 I 3.9 13 6606 ~ 1 0.01 3 _ 3.89 214 6635 U 0.01 1 _' 3.90 21 667 c) 0.01 ~1 I 3.89 216 6697 O 0.01 3 i 3 91 217 6729 ~? .00 1 I 3.90 218 6760 ~) 0.01 ~ I 3.90 19 6791 ~) 001 i ~ 3. 0 219.1 6822 O 0.02 7 1 3.90 PUP 219.2 6827 O 0 U t1 N A GLM 2 Latch ~ 11:30 219.3 6835 U 0.02 6 1 3.90 PUP 220 6841 O 0.01 3 .90 220.1 6872 O 0.01 4 z 3.90 PUP 220.2 6881 t) 0 0 l) 3.97 Gau Carrier 221 6887 U 0.01 3 3 3.89 221.1 6919 l) 0.01 5 1 3.92 PUP 221.2 6924 ~) 0 0 i) 3.81 Sleeve-C 221. 6931 ~) 0.01 5 I 3.85 PUP t. De 'ts. 2 2 6937 l) 0.03 i 3 _' 3.91 Shallow itOn . 22 .1 69 8 ~) 0.03 1 i) I 3.89 PUP 222.2 6977 ~~ 0 0 11 3.97 Gau Carrier 23 6984 t) 0.02 ~) 2 3.9 224 7014 ~) 0.04 15 1 3.90 Shallow itUn . 2 4.1 7046 ~) 0.01 3 i ~ 3.89 PUP 224.2 7052 l) 0 0 ti 3.88 Seal 224.3 70 0 ~) 0 t) a 3.88 PBR 224.4 7077 l~ 0.01 5 I 3.92 PUP 24.5 7082 ~> 0 t~ ~~ 3.88 Packer 224.6 7101 a 0.01 4 I 3.89 PUP Penetration Body Metal Loss Body Page S • Average Recorded Metal Thickness Relative to Calibration Point Pipe 1 4.5 in (8.1' - 7100.5') Well: 1 C-178 Field: Kuparuk Company: ConocoPhillips Alaska, Inc Country: USA Survey Date: October 13, 2007 . D ecrease ^ In crease 1 25 8 769 50 1544 75 2316 100 3093 ~ v E GLM 1 Z 125 Y ~ 3884 t Y (' Q' Q 150 4656 175 5432 200 6206 GLM 2 224.6 7101 - 50% 0 5 0% C hange in Metal Thick ness (%) Bottom of Survey = 224.6 PreoAcrlvE DLignos~ic Scwvlca, Ine. Magnetic Thicknes~..og (10hz) October 13, 2007 Database File: d:\warriorldatal1c-178\data.db Dataset Pathname: 1/1/1ltop200 Presentation Format: 3SCALE~1 Dataset Creation: Thu Nov 01 11:08:58 2007 Charted by: Depth in Feet scaled 1:50 0 MTT Frequency (Hz) 20 3 MTTP01 (rad) 13 -50 Delta Metal Thickness 50 -5.8 MTTP12 (rad) 4-~ 0 Line Speed (ftJmin) -200 '. _- S Tree ~ ~ er Han - - 4.5" Col lar g - 3 6% Met al L oss ~~~ ~ ~- r~' 4% Met al L oss 4.5" Joint 1 20 i 0 MTT Frequency (Hz) 20 3 MTTP01 (rad) 13 -50 Delta Metal Thickness 50 -5.8 MTTP12 (rad) 4.2 0 Line Speed (ft/min) X00 t PwoAc~lre DGgnonic Scwvlcq. Inc. Magnetic Thickne~og (10hz) October 13, 2007 Database File: d:lwarriorldatal1c-1781data.db Dataset Pathname: 1hliltop200 Presentation Format: 3SCALE~1 Dataset Creation: Thu Nov 01 11:08:58 2007 Charted by: Depth in Feet scaled 1:50 0 MTT Frequency {Hz) 20 3 MTTP01 (rad) 13 -50 Delta Metal Thickness 50 -5.8 MTTP12 (rad) 4.2 0 Line Speed (ftlmin) -200 f 5" C ll f . ar o 3% Met al L oss ' 4.5" r Joint 3 4% M l L ' et a oss 1 S ~ 80 t ~ f 0 MTT Frequency (Hz) 20 3 MTTP01 (rad) 13 -50 Delta Metal Thickness 50 -5.8 MTTP12 (rad) 4.2 0 Line Speed (ftlmin) -200 Comparison to Previous~TT Log Overlay ~~ oak ~~~ ~~ October 13, 2007 and September 8, 2006 Database File: d:\warrior\datal1c-1781data.db Dataset Pathname: Kuparuk/1C178/run/_mpk1_ Presentation Format: 2.4 comp Dataset Creation: Wed Oct 31 17:50:38 X007 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness 1007 50 -50 Delta Metal Thickness `?006 50 ?0 H Casing Hanger and Tree giant Decrease in Metal Volume Indicated (0' - IDeclr_eas'e in Metal Volume Indicated (5' - 7') 10 ~0 30 40 Response 50 60 -{--~ 70 Decrease in Metal Volume Indicated (64' - 80' 80 • KRU 1 C-178 ConocoPhiilips Alaska, Inc. ~i~' ~ -»a API: 500292314400 Well T : PROD An le TS: TUBING SSSV T : NIPPLE Ori Com lotion: 4/162003 An le TD: 89 13280 (47338, OD:4.500, Annular Fluid: Last W/O: Rev Reason: GLV C/O, Set JET PUMP ID:3.958) Reference L 28' RKB Raf L Date: Last U te: 326/2006 Last Ta TD: 13626 f1K6 Last Ta Date: Max Hole An le: 92 d 11208 Casin 8irin -A LL STRINGS Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 110 110 62.50 H-40 WELDED SURFACE 7.625 0 7734 3770 29.70 L-80 BTCM Casin Str' -LOWER LATERAL LINER Alternatin 30' sections of blank 8 slotted finer Deac ' lion Size To Bottom TVD Wt Grade Thread Lower Lateral Slotted Liner 4.500 7429 13244 3810 12.60 L-80 SHLT Tub' Str' -TUBING Slze To Bottom TVD Wt Grade Thread 4.500 D 7336 3697 12.60 L-80 IBTM fiusrlwG Perforations Summ (6x24-6s25, Interval TVD Zone 3 Ft SPF Dete T C OD:6.020) 7704 - 13179 3767 -3809 WS B,WS BWSC 5475 99 4/162003 IPERF SLOTTED LINER r Gas Lift Me ndrels Nahfes St MD TVD Man M6 Men Type V Mfr V Type V OD Latch Port TRO Dete Run Vlv Cmnt 1 3752 2398 CAMCO KBG-2 DMY 1.0 BK 0.000 0 3/8/2006 2 6827 3539 CAMCO KBG-2 DMY 1.0 BK 0.000 0 3/812006 O r lu s i .etc. - C E N J Y De th TVD T Descri lion ID 26 26 HANGER VETO GRAY GEN 1 MCA TOP CONNECTOR 4.500 SEAL 498 498 NIP CAMCO 'DB' LANDING NIPPLE 3.875 (7051-7056, OD:5.500) 6881 3557 Gauge Carrier BAKER GAUGE CARRIER MODEL 925 3.970 6924 3571 BUSHING BAKER PROTECTOR BUSHING 3.920 6925 3572 PUMP DB-6 LOCK AND JET PUMP (SER.# PH-1041), ratio 14-A, NOZZLE #'14, THROAT ~r14 68" OAL set 3/13/2006 0.000 6925 3572 SLEEVE-C BAKER CMU SLING SLEEVE -CLOSE 4/9/2005 3.813 ', 6976 3589 Gauge Carrier BAKER GAUGE CARRIER MODEL 925 3.970 7051 3613 SEAL BAKER 80-40 SEAL ASSEMBLY W/PBR 3.875 7056 3615 PBR BAKER PBR 3.875 7086 3625 PACKER BAKER PACKER W/MILLOUT EXTENSION ID 484" 3.875 7109 3632 NIP CAMCO'DB' NO GO NIPPLE 3.750 7335 3697 WLEG CAMCO WIRELINE GUIDE 3.960 7356 3702 HANGER FLANGED HOOK HANGER FOR UPPER LATERAL LEG LINER 5.630 Other ui etc. - OWE IN LRY De th TVD T Deacri lion ID 7401 3714 PUP 4.830 R 7401 3714 SLEEVE 5.010 SU FACE (0.7734 7414 3717 BUSHING BAKER BUSHING 7.875 , Op:7.52g, 7416 3717 NIP BAKER RS NIPPLE 4.875 Wt29.70) 7419 3718 HANGER BAKER FLEX LOCK HYDRO REOTAT6JG LINER HANGER 4.830 7428 3720 XO XO TO 4.5" LINER 3.940 7430 3720 Blank Liner BLANK LINER IN 30' SECTIONS, ALTERNATING WRH SLOTTED LINER 30' SECTIONS 3.958 7493 3735 Blank Liner 3.510 ' ( 7704 3767 LOCATOR BAKER LOCATORS 3.510 SLEEVE 13242 3810 SHOE GUIDE SHOE 4" ROT SILVER BULLET W/ECCENTRIC NOTE fbat drill ou 0.000 (7401aa1a, oD:s z9o Gene I N . ) Dole Note BUSHING (741a-74t8, 4129/2003 MULTILATERAL PRODUCER WELL OD:5.540) TREE: ABB VETCO GRAY / HAORZT / 4 1/16" 5M (w/penetrator wire) TREE CAP CONNECTOR: 9" OTIS NIP (7416.7419, OD:6.060) XO (7428-7430, OD:5.770) ^ ^ Pert (7704-13179) ~ ~ I ~ ~ . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: A03CC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage. Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following: BP Exploration (Alaska). Inc. Petrotechnical Data Center Attn: Andy Fanner LR2 - 1 900 E. Benson Blvd. Anchorage. Alaska 99508 5(;f}NNED NOV .0 1 2007 and ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8951 c!)D3 -6¿¡! .¡:. (S-5"(P(j 1) 2) Caliper Report 13-Oct-07 1C178 1 Report / EDE 50-029-2314400 Signed: 1l.1i-- " Il ?f'fP ,(J -x Ldv! Print Name: f/tt ,¡'<,{-Ju...4.... !hiJL,.IAÙ..M. PRoACTIVE DIAGNOSTIC SERVICES, INc., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANcHORAGE, AI( 99618 PHONE: (907)245-8951 FAX: (907)245-88962 E-MAIL: pdsanchoraae@memoryloa.com WEBSITE : www.memorvloa.com D:\MasIor_ Copy _00 _PDSANC-2OxxIZ_ WordlDistributionlTransmittaC SheetsITI8IIS1IIÍt_ Original_New.doc I I I I I I I I I I I I I - . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. October 13, 2007 8644 1 4.5" 12.6 lb. L-80 Tubing 1C~178 Kuparuk Alaska 50-029-231#00 Surface 7,107 Ft. (MD) Well: Field: State: API No.: Top Log Intvl1.: Bot. Log IntvI1.: Inspection Type : COMMENTS: Corrosive & Mechanical Damage Inspection This log is tied Into the GLM 2 @ 6,827' (Driller's depth). This log was run to assess the condition of the 4.5" tubing with respect to corrosive and mechanical damage. The caliper recordings indicate that the 4.5" tUbing interval logged is in good condition with respect to corrosive damage. No significant wall penetrations (>20%), areas of significant cross-sectional metal loss, or significant 1.0. restrictions are recorded. 4.5" TUBING - MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 15%) are recorded. 4.5" TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall loss (> 7%) are recorded. 4.5" TUBING - MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded. R,ECEiVE OCT 2, 4 Z007 cf}()3 -d{ I "7t f f)6 (.. d Alaska Oil & Gas Cons. CommIssion Anchorage I Field Engineer: K. Miller Analyst: B. Qi Witness: C. Fitzpatric ProActive Diagnostic Services, Inc. l P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 I I I Well: Field: Company: 1 C-1 78 Kuparuk ConocoPhillips Alaska, Inc. USA I Tubing: Nom.OD 4.5 ins Weight 12.6 f Grade & Thread L-80 I Penetration and Metal loss (% wall) I penetration body metal loss body I 250 200 I 10 to 20 to 40 to over 200/0 40%, 85% 85% I o to 1% 1 to 10% I o o I Damage Configuration ( body) 10 I I I o isolated general line ring hole I poss pitting corrosion corrosion corrosion ¡bie hole I o I I PDS Repo Overview Region Analysis Survey Date: Tool Type: Tool Size: No. of Anal st: Nom'!D 3.958 ins October 13, 2007 MFC 40 No. 30807 2.75 40 B.Qi Nom. Upset 4.5 ins Upper len. 6.0 ins Lower len. 6.0 ins Damage Profile ("/0 wall) penetration body o 1 metal loss body 50 100 49 99 GLM2 197 GLM 1 Bottom of Survey = 224.6 Analysis Overview page 2 I I I I I I I I I I I I I I I JOINT LATION SH Pipe: Body Wall: Wall: to.: 4.5 in 12.6 0.271 in 0.271 in 3.958 in 1.-80 Well: 1C-178 Field: Kuparuk Company: Country: USA Date: October 13, 2007 Inc. I I I I I I Joint Jt. Depth Pc" Pen. PerL .'vlelal Min. .~ Profile No. 'I !.D. Comments wall) 0 50 100 1 8 Fm= 2 38 [ I 3 61} 1 4 100 II ¡ 1 3.91 5 130 3.91 6 161 0 3.91 '7 , 192 8 223 9 254 3.91 10 285 0 3.93 11 316 n 12 347 0 3. 13 ±=;=± OJH 1 3.91 14 0.01 ¡ 3.91 I 15 0.01 3.92 15.1 471 15.2 480 0 0 (] i Ie 15.3 483 0.00 I 3.92 PUP 16 492 n 0.Q1 I 3,<:11 17 523 1 3.92 18 554 2 3.89 19 585 3.90 20 616 3.9'1 21 647 3.92 22 f.7R 3.87 23 709 0 3.92 24 738 ( 3.91 25 769 3.91 26 8 27 832 28 863 0.01 3.92 29 893 0.01 1 3.92 30 924 0 om I 3.92 31 955 ( om 3.88 32 986 i 0.01 3.90 33 1017 ( om 3.91 34 1048 0.01 3.B7 35 1078 om 3.90 36 1109 om 3.91 37 1140 0.01 3.92 38 1171 0.01 ¡ 3.88 39 1203 0 0.01 3.90 40 1234 ( om 1.91 41 1265 0.01 3.92 42 1296 0.Q1 \ 3.85 43 1328 0.01 3.93 ~ 44 1359 0.01 3.89 45 1390 om 4 I 3.90 ~ 46 1421 0 ]]I I 1 1.88 47 1452 0 4 2 3.87 ~ Page 1 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT ULATION SHEET Pipe: Body Wall: Upset Wall: Nominal I.D.: 4.5 in 12.6 0.271 in 0.271 in 3.958 in L-30 Well: Reid: Country: Survey Date: K-173 Kupa !Uk ConocoPhiHips Alaska, Inc. USA October 13, 2007 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Pro file Nö. (Ft.) Body 1.0. Comments ('Yo wall) (Ins.) (Ins.) (Ins.) 0 50 100 48 1482 J 0.01 " 49 1513 ) 0.01 50 1544 J 0.00 ¡ 3.91 51 1575 0.01 j 3.90 52 1607 0.01 1 3.91 53 1638 0.01 1 3.91 54 1668 0.ü1 ~ 55 1699 0.ü1 56 1731 57 1762 0.01 58 1793 1ItII 59 1824 I 1 3.91 Lt. Deoosits. 60 1855 0 0.ü1 3.8~ 61 1886 I 62 1917 0.ü1 3.90 m 0.ü1 3.91 U. Deoosits. 64 1976 0.ü1 . 3.B8 65 2007 0.ü1 3.91 66 2037 I 0.00 3.91 67 2069 0 0.ü1 2 3.91 68 2100 0 0.01 2 3.91 69 2131 0.01 :> 3.89 70 2162 0.02 ¡ 2 3.91 71 2192 0.ü1 ~ I ~.87 I 72 iEtlJt 0.02 ¡ 73 001 74 2285 0 0.ü1 2 3.91 75 2316 0 0.01 2 3.88 76 2347 I 0.ü1 2 3.91 77 2378 I 0.01 3.89 78 2409 11 3.91 79 2440 3.92 80 2471 3.91 81 I 2502 3.89 82 2533 0.01 3.91 83 2564 0 0.ü1 4 I 3.91 84 2595 I) 0.01 1 3.89 85 2627 0 0.ü1 4 3.90 86 2657 () 0.00 191 87 2689 0 0.ü1 3.92 88 2720 I 0.ü1 3.89 89 2752 ¡ 0.ü1 3.90 90 2783 ¡ 0.02 3.90 91 2814 ¡ 0.01 3.92 92 2845 I 0.ü1 3.89 93 2875 I 0.01 3.91 94 2907 I 0.D1 3.89 95 2937 I 0.01 3.89 96 2969 I 0.ü1 3.91 97 2999 0 0.01 1 3.92 Body Metal Loss Body Page 2 I I I I I I I I I I I I I I I I I I I TABULATION SH Pipe: Body Wall: Upset Wail: Nomina! 1.0.: 4.5 in 12.6 0.271 in 0.271 in 3.958 in L-80 Wen: Field: Company: K-178 Alaska, ¡ne. USA October 2007 Joint Jt. Depth Pe" I Pen r;" Mé" Min. Profile No. W. Comments (Ins.) (Ins.) 0 50 100 QR I 3030 3.90 99 3062 f-- 3.92 100 3093 o 0.02 101 3124 0 0.01 102 3155 n ¿L 103 3185 0 0.00 2 104 3216 0.00 1 ~ 0.01 3.91 om 3.91 001 ! 3.92 108 0.01 I ±Ii 109 3371 t!± 110 340/ 0 ¡ 111 3433 0 112 '464 \) 0.01 ¡ 3.92 113 3494 n 0.00 I 3.91 3526 n 0.01 1 3.92 115 d 0.00 . 3.89 116 3587 0.01 3.89 117 3618 n 0.01 386 118 %49 0 0.01 3.87 119 3678 n 0.02 3.85 120 3710 n 0.01 ±f= 389 120.1 3740 Ii 3.92 PUP 120.2 3746 I N/A CI M 1 (L;¡tcn@ 7:0m 120.3 'I7~':¡ 3.90 PUP 121 3759 0 3.90 122 3790 0 3.91 1/, 38/1 3.90 124 3852 0.Q3 ìO 3.86 1/') 3884 0.01 3.85 126 3915 0.02 ! 3.89 127 3945 om ! 3.90 128 3976 0.00 3.91 129 0.01 3.90 130 iti= 0.01 3.90 131 4069 i 3.89 132 4101 1 3.91 133 4131 3.90 134 4163 3.91 135 4193 3.87 136 4222 í 0.01 3.86 137 4254 0 0.01 3.91 138 4285 ( 0.01 3.91 139 4316 I 001 3.92 140 4347 I 0.01 3.91 141 4378 ;:01 I ; 3.85 142 4409 3.90 143 4439 :tit 144 4470 ) 3 I I I I I I I I I I I I I I I I I I I 4.5 in 12.6 0.271 in 0.271 in 3.958 in l-8Q Joint Jt. Depth Pen. Pen. No. (ft.) Upset (ins.) 145 4501 ~ lAh 4532 TO"Tõ:õ1" 147 4'163 n I 0.Q1 ;; I ~¡ f I 0.01 1 4719 0 1 4749 0.Q1 154 4780 0.Q1 155 4812 0.Q1' ~ 156 4847 0.01 3.91 ¡~ '1 : I ~t:t ~:~ 160 4967 ~ 3.90 ~ ~~ ~g~~ 0 g:g~ ~.~~ 163 =5060 n 0.01 3.91 164 5091 n 0.01 3.90 165 5122 () 0.01 6! 3.91 166 5153 n 0.Q1 Ii 167 5185 0 0.01 168 5215 () 0.01 2 3.84 16q 5247' 0 i+ I 170 5278 I () I 2 171 'B09 0.Q1 3.91 172 Si40 1 I 3.87 173 5370 3.91 174 3.92 175 5432 I ß 3.84 176 5463 II 3.89 177 '1t1Q<; t1 3.91 178 '1 ", <¡ .~ 1 .1&.1.. rn79 555 "1 .:tfi2.. 1 586 0.1 3.91 161 5617 I 0.Q11 3.90 182 . 5648 I I 0.Q1 1 3.91 183 5679 ltim 2 i 184 5710 n 1 185 5741 ( 2 186 5772 I 0.Q1 187 5804 I om I 3.91 188 5834 0.01 3.91 189 5866 ¡ 3.90 190 5896 3.91 191 "928 3.84 192 5959 0.01 3.89 193 '1991 0111 3.93 194 6022 0.01 3.91 Pen. ! l\/lelt1 Min. 1.0. (!ns.) ¡=HI 3.90 3.91 I ''',- JOINT WeN: Field: Page 4 ULATION 1 G 178 Alaska, tne. USA October 13, 2007 Comments Profile wall) o 50 100 Meialloss Body I I I I I I I I I I I I I I I I I I I JOINT ULATION SH Wall: Upset WaD: Nomina! 1.0.: 4.5 in 12.6 0.271 in 0.271 in 3.958 in l-80 WeD: Field: 1 C-1 78 Kuparuk ConocoPhíUips USA October 13/ 2007 Inc. Survey Date: Joint Jt. Depth Pen. Pen. .ren:- I !'"lelal Min. '0' ! Profile No. 1.0. Comments ('Yo wall) (Ins.) (Ins.) (Ins.) 0 50 100 195 6053 Ll 3.90 196 6084- Hi;¡ 197 6113 198 1'>144 ~h175 3.90 6206 0.01 3.90 6237 0.01 1 202 6268 0.01 I ¡ 703 6799 204- 6330 1 205 6qhl n 1 II 206 6390 ( 7 II 207 h, ' 1 n 0.01 1 3.89 208 h ,2 0 10.01 -:1 1 3.93 209 63. í 3.91 210 6 13 01 3.91 ?11 f,5M 3.91 ?1) 6576 n O. 3.90 213 ~ n 0.01 ±t 3.89 214 f,635 n 0.D1 i1 3.90 215 6667 0:01 3.89 216 6697 0.D1 1 3]ld 217 6729 3 , 218 6760 3.90 219 6791 3.90 219.1 6822 3.90 PUP ? 19.2 68?7 N / A C:lM ?(latCh@ 11 :30Y ~ 6835 3.90 PUP 6841 3.90 220.1 6872 3.90 PUP 220.2 11881 o f I 3.97 Gau2e Carrier 221 6887 om 3.89 221.1 f.919 W 3.92 PUP 221.2 6924 1 3.81 Sleeve - C 221.3 6931 ¡ 3.85 PUP Lt. Dennsits. 222 6937 0.D31 ;) ! 3.91 Sha!low nitlino. 222.1 6968 0.03 'If 3.89 PUP 222.2 6977 0 n 3.97 GauOP Carrier 223 6984 ~ bk± 3.91 !II 224- 3.90 Shallow nitlinl!1. !II 22d.1 7046 ~ PUP 224-.2 7052 0- I Seal 224.3 I 7070 0 0 ¡ 3.88 PBR 224.4 7077 II 0.D1 3.92 PUP III 224.5 7082 n 0 t q.88 Packpr 224.6 7101 n om 4 ! 3.89 PUP Body Meta! Loss Body Page 5 I KRU 1 C-118 I I I I I I I SEAL (7001-7056, 00:5.500) I I I I I SLEEVE (7401-7414, 00:6.290) I BUSHING (7414-7416, 00:5.540) TREE: ASS VETCO 13M Y ¡ HAORZT I 4 1/16" 5M (w/pooetrator wire) TREE CAP CONNECTOR: 9" OTIS NIP (7415-7419, 00:6.060) I I XO (7428-7430, OD:5.770) I Peri (7704-13179) I I 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhi/lips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 87' . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Repair Well 0 Pull Tubing 0 Opera!. ShutdownD Other D Jet Pump to GL r o o Stimulate 0 Waiver 0 Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development [] q Stratigraphic 0 Time Extension Re-enter Suspended Well Exploratory Service o o 5. Permit to Drill Number: 203-041 6. API Number: 50-029-23144-00 9. Well Name and Number: 1C-178 f"" 8. Property Designation; ADL 25649 1 25638 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field 1 West Sak Oil Pool Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE LOWER LATERA PROD. CASING Perforation depth: measured 13280' , feet true vertical 3811' " feet measured 13246 " feet true vertical 3810 feet Length Size MD 110' 16" 110' 7647' 7-5/8" 7734' 5815' 4-1/2" 13244' Plugs (measured) Junk (measured) TVD Burst Collapse 110' 3770' 3810' Measured depth: 7704' - 13179' true vertical depth: 3767' -3809' i~ JUL 2 3 2007 Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7336' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIP SSSV= 498' 12. Stimulation or cement squeeze summary: RBDMS 8FL JUl 2 3 2007 Intervals treated (measured) none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 323 ' 180 297 1780 309 Subsequent to operation 496 161 1059 1045 259 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development D Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oilD ~ GasD WAG 0 GINJD WINJ 0 WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A ifC.O. Exempt: N/A Contact Robert D. Christensen Signature Title Phone Production Engineering Teèhnician 907-659-7535 Date r5 ~ g ð""1- lrn.b\ ~~~ ~þ 1·/'i-'Þ? ~ ~ ~ubmit Original Only Form 10-404 Revised 04/2004 . . 1 C-178 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 6/25/2007 DISPLACED IA W/108 BLS OF DIESEL. PULLED 3.813 DB LOCK W/ JET PUMP ( S.N. PA- 1056). CLOSED CMU @ 6925' RKB. MITIA TO 3000 PSI (PASSED). SET 3.75 CAT STANDING VALVE ( 27" OAL ) IN DB NIPPLE @ 7109' RKB. PULLED DGL V FROM ST A # 2 @ 6827' RKB. SET OGLV IN STA # 2 @ 6827' RKB. « IN PROGRESS ». 6/26/2007 PULLED DV @ 3752' RKB, REPLACED WITH GLV. PULLED CAT SV @ 7109' RKB. COMPLETE. 6/27/2007IwELL RETURNED TO PRODUCTION AS A GAS LIFTED OIL PRODUCER. . . Conoc~illips Alaska RECEIVED .JUL 1 0 2007 P.O. BOX 100360 ANCHORAGE, AlASKA 99510-0360 Alaska Oil & Gas Cons. Commission Anchorage July 6,2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~CANNED JUL 1 1 2001 , ' , a.Þ-Y 0 4 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please M.J. Loveland at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Project Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top oft Corrosion inhibitor/ Well Name PTD# cement DumDed cement date inhibitor sealant date ft bbls ft Qal 1C-125 201-199 11" na na 4.8 6/9/2007 1C-170 203-078 23" na na 14.5 6/9/2007 1C-174 203-027 28" na na 9 6/9/2007 1C-178 203-041 40" na na 16 61912007 1C-184 203-089 24" na na 10.4 6/9/2007 Kuparuk Field June 9,2007 . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 1 00 Anchorage, Alaska 99501 (907J 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8951 1) 1 Report 2) 1 Report 3) 1 Report 4) 5) 6) 7) Signed: Print Name: 1C - 135 MTT Log 8-Sep-06 ;)0 I - ÐÐÒ 1 C - 178 MTT Log 8-Sep-06 ÐD"3-ÒI...{1 V 1 C - 184 MTT Log 8-Sep-OB dó3-o'i>G) .,;:r 1'I.!!I,.~~EJiì) ~'Vû'-t'J'\:'!' -- if': ¡; 0, þ~ -- RECEIVED OCT 0 4 2006 Gate: ,< ~._~-- c'~ (ì-<.h V\ t? {}101, 1/1 /¿ QfA -\Jaska Oil & Gas Cons. Commission Anchorage PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: PDSANCHORAGE(él!MEMORYlOG.COM WEBS/TE : WWW.MEMORYlOG.COM D:\OO. PDSANC·20061Z. WordIDi.lribution\Trallsnulbl. S¡'CCI.\Trausmil. Origiuatdo.: I I I I I I I I I I I I I I I I I I I . fJo3 -04/1 . Memory Magnetic Thickness Tool Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1C-178 Log Date: September 8, 2006 Field: Kuparuk Log No. : 6602 State: Alaska Run No.: 1 API No.: 50-029-23144-00 Pipe1 Desc.: 4.5" 12.6 Ib L-80 Top Log Intv!.: Surface Pipe1 Use: Tubing Bot. Log Intv!.: 186 Ft. (MD) Pipe2 Desc.: 7.625" 29.7 Ib L-80 BTCM Top Log Intv!.: Surface Pipe2 Use: Production Casing Bot. Log Intv!.: 186 Ft. (MD) Pipe3 Desc.: 16" 62.5 lb. H-40 Welded Top Log Intv!.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intv!.: 117 Ft. (MD) Inspection Type: Assess External Corrosive Damage (Metal Loss) to Production Casing. COMMENTS: This MTT data is tied into the Tubing Hanger @ 0' Depth. This is the first log of this well with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total thickness of metal of the 4.5" tubing and 7.625" production casing, with some influence from the 16" conductor pipe. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (179'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 4.5" tubing, 7.625" casing, and 16" conductor pipe. INTERPRETATION OF MTT LOG RESULTS: The MTT log results cover the interval 0' - 186'. A log plot of the entire log interval, plus a detailed section of the interval showing damage is included in this report. The Delta Metal Thickness (%) curve in these plots refers to total metal surrounding the MTT tool and the results show one interval of metal loss in this log interval from the mandrel hanger to -8.5' below the mandrel hanger. A maximum of 17% circumferential metal loss is recorded in the interval between 0' and -8.5'. No other areas of significant metal loss are recorded throughout the interval logged. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 4.5", 7.625" and 16" pipe. If all of the metal loss is specific to the 7.625" production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 4.5" tubing or 16" conductor. I Field Engineer: N. Kesseru Witness: T. Sendon I RECEIVED Analyst M. Lawrence & J. Burton OCT 0 4 2006 ~ Oil & Gas Cons. Commission Anchorage c9ð3 -efi I I I I I I I I I I I I I I I I I I I I I ") ~S. p~ D!"GNOSTic SERvicES, INC. Database File: Dataset Pathname: Presentation Format: Dataset Creation: Charted by: Magnetic Thicknes d\warrior\data\ 1 c-i78\ 1 cil8.db Kuparuk/1 C178/run1/1 Ohz.1 2.6 scale Wed Sep 13 09:08:37 2006 by Calc Sondex Warrior V7.0 Depth in Feet scaled 1150 .. -50 Delta Metal Thickness (%) 50 o Line Speed (ftlmin) -200 -'- r--r-1 ~ ) - ) - - -'-. t-. --r~ -- ..~ -.- \;;;. ~r-- - ;> r-"r' ----- - - -.- Joint 2 ,...-r- f .625" Casing Collar .- --- -~..._- ....~._..- } -. ) '"- r- "'--':i;:-r ~'~"r -..c....-- ~ -. ,. .- ~r-" - ,.- - --",,------ -..-- - ~ J. ) ) ;> .1 ? --.)-" -- - '-,-" - Tree ~.~' ..-¡-.- o Metal Loss .- . -1'- "'- 7.625" Casing Collar . ~.¡-.- _____ mm_n_____... ~ __._m___ Joint 1 20 4.5" Collar I ~-_. ~.~._~ _m 40 4.5" Callan 00 __m__,,__ -t·-· ..._ _·__m__ Joint 3 80 . r-- -. ---,... ~~ ......7. ...6...2.....5'.'....C. .a.....si..n...g Collar j ii, ..~ " ·=~l. ~.5~¡c.ol:a¡ 9 .- r- r-- t- ._-~ r'-'- _n__ ,,- -... ........ -.. - -. 126 -6.2 -~ I I og (10Hz) MTTP01 (rad) MTTP12 (rad) 12.6 3.8 ~. I . ,'- ~ - ~. t I"'" :-- ., I r- ~ -; ¡-- :-- l ! r r- - r~ _. .. .- r-' .l'. '"::¡r.. II' V L .. -"-_nO r .- _: -r<2"" -" j ±t±_._ ;- = r-- ttt ~... ..,(_. .i l _m__ ____._m_ ¡- i- ____n_ .----- J I ._ m=:±t= i - -- -- - ~ !""" ~ r _.... ~.- .- _m... -::::fE"" ~ .- - r-- t EïÞf- -. t-- ~ I I I I I I I I I I I I I I I I I I I I \ -LJ -_.._ _mnJuJ r-~ . I ----.-.-.-¡.- .._-. .. ~ .... I Joint 4 I I 16" Conductor 100 ~ - ..-. , , I } j .~ ./J ~) ~-,._-_..- ) _mn '_,m,_ -. í I " c.~,~~ ---~- ). - ~b 120 - 4,5" Colla J I ) '+-:7.625" Casing Collar I I - '.~.. --+- Joint 5 140 . -'- - ~ .--- .- -. .~ ¡ M""'......4.5" Collal 160 I I _'___, --'-.- Joint 6 - 1--. -. . ~4I...-1.625" Casing Collar ( Þ I I i~ 180 I ) 45" Collar ~ I I ·50 Delta Metal Thickness (%) 50 o Line Speed (ftlmin) -200 - -;>-~ '0::, }; - ¡ I I -.. ~_._-- -_ m__ _m '- 0·-- r--- <:, .ç=.- -'-'C ~. ,'1' {I IJ I 1-- ,- '~-~-- ·H 4'- -'- =! ~ if- ~~1 ( \ 1= , I) (' f ( ! . -. /!.. / ) \, '> iij r;::. rf-" r ...I.or r-- 1-* 2 .......... r-- l-' rl"'~- J - .- ~. í þ- t -. ) ;- í 1 I -.1- ...-_ _.._ ---- -. r-' - --'- ~ r ~ .~ I... . ~ j t_1. í -'" "-> ;> t> v (~>~ r- g' ~ "::> >-- b r-' r> I,{"'-::' ..::::::> r J ~ " 2.6 -6,2 MTTP01 (rad) MTTP12 (rad) 12.6 3,8 I I I I I I I I I I I I I I I I I I I .C=> ~s. PRO~ DIAqNOST!C SERvlcE5, INC. Database File: Dataset Pathname: Presentation Format: Dataset Creation: Charted by: Magnetic Thicknes og (10Hz) d\warrior\data\1c-178\1 c178, db Kuparuk/1 C178/run1/1 Ohz,1 2.6 scale Wed Sep 13 09:08:37 2006 by Calc Sondex Warrior V70 Depth in Feet scaled 150 -50 Delta Metal Thickness (%) 50 o Line Speed (ftlmin) -200 fm <111--17% Metal Loss r:",,~, =~-='''''''''l76?5'' Casing Collar I I i "---- '-. 12.6 -6,2 MTTP01 (rad) MTTP12 (rad) 12.6 3.8 I Mandrel Han o , l. i ,='§ i .¿ '''''0;; Î"-~ '~"....., r'""'-., ~ 'r '","; / ¡;. 1 ,--..1 Cl, ???, -] ;;1;> ,~,.,~ "[i ~~~ s ." : '" ~ ,~ '- ~ I ! ~ +- Indication of Clean 7625" Casing , I I I ¡ I "" (-85' Below Mandrel Hanger) -'- -- --,,~~.- ;, I ~p !I' "c> I I ¿ '- p- , " f~Þ I - .~ - I ¡ I I ;> ii :> .' < - ,Joint 1 ) I 4.5" Tubing i ,,-. I I I I 1 I I I i 20 1 ¿ ? - .~ ¿'.' I 1 1 f 1 ;¡ ¡' } I I ( , I ¡ I ~ I ?/ , ? I ¡ ,.t" I I i ~'i I If':, ( ,¿ '''¡;:¡ 1\ :,,- ~ I ~ ~ Á 1 , ."!.. ~ ,C I J .'"':\ 13, ~ I ~/ ? (, t ¡ I t;k, L 4.5" Collar I r' , ~-----~----------- Delta Metal Thickness (%) 50 2.6 MTTP01 (rad) 12.6 Line Speed (ftlmin) -200 -6.2 MTTP12 (rad) 3.8 1~50 o I I I I I I I I I I I I I I I I I I I 1t:-1I8 KRU 1C-178 ruBING (0-7336, OD:4.500, ID:3.958) API: 500292314400 SSSV Type: NIPPLE Angle (ç¡) TS: d~ Angle@ TO: 89 deg @ 13280 Annular Fluid: Reference Log: 28' RKB Last T <!Q: Last T Date: Well Type: PROD Orig 4/16/2003 Completion: LastW/O: Ref Log Date: TO: 13626 ftKB MaxHole Angle: 92 deg @ 11208 Rev Reason: SET JET PUMP Last Update: 6/24/2006 esc¡jmion ..1 Size I CONDUCTOR ~l 16,000 .I SURFACE ~g Descril!tion Size ~ 4,500 1 ~ .1 Bottom I 4.500 I 0 1. 7336 1 BUSHING (6924·6925, OD:6.020) t!fIMD 1 I 3752 ~l 6827 SEAL (7051·7056, OD:5500) Depth 26 498 6881 SURFACE (0-7734, OD:7.625, Wt:29.70) SLEEVE (7401·7414, OD:6 .290) 7401 7401 7414 7416 7419 7428 7430 BUSHING (7414-7416, OD:5.540) JlJterval 7704 - 13179 6924 6925 6925 6976 7051 7056 7086 7109 7335 7356 3714 3714 3717 3717 3718 3720 3720 T qp J Bottom .I o 110.1 o 7734 J I Wt Grade I~ ~ 62.50 J H-40 .I ~ 29,70 L-80.1 BTCM lined J Wt -' Gradel Thread J 12.60 J l-80 J SHLT TVD 110 3770 T QQ. 7429 Bottom .J 13244 1 TVD 3810 TVO 3697 1 Wt 1. Grade I 1 12.60 1. l-80 1. Thread IBTM TVO I Zone 1 Status I Ft ISPFI Date I Type I 3767 - 3809 / ~~:s~S I /5475/ 99 14/1612003 IPERF 'SLOTTED LINER TVO Man Mfr 2398 CAMCO 3~39 CAMCO .f,. Man Type KBG-2 KBG-2 V Mfr V Type DMY OMY V 00 latch Port TAD o o ..Ii'll Date Run 31812006 ~Q06 Viv Cmnt 1.0 1.0 BK BK 0.000 0.000 TVO 26 498 3557 Type HANGER NIP Gauge Carrier BUSHING PUMP Descrmtion VETO GRAY GEN 1 MCA TOP CONNECTOR CAMCO 'DB' LANDING NIPPLE BAKER GAUGE CARRIER MODEL 925 10 4.500 3.875 3,970 3571 3572 BAKER PROTECTOR BUSHING 013-6 LOCK AND JET PUMP (SER# AR-1014), ratio 13-13, NOZZLE #13, THROA T #14, (69" OAL), set 6/23/2006 BAKER CMU SLIDING SLEEVE - CLOSED 4/9/2005 BAKER GAUGE CARRIER MODEL 925 3.920 0.000 3572 3589 SLEEVE-C Gauge Carrier SEAL BAKER 80-40 SEAL ASSEMBLY WfPBR PBR BAKER PBR PACKER BAKER PACKER W/MllLOUT EXTENSION, 104.54" NIP CAMCO 'DB' NO GO NIPPLE WLEG CAMCO WIRELlNE GUIDE HAN~~~ ~~~~;~F~~I~E~. FOR UPPER LATERAL U::li LINER e Description PUP SLEEVE BUSHING BAKER BUSHING NIP BAKER RS NIPPLE HANGER BAKER FLEX LOCK HYDRO REOTATING LINER HANGER XO XO TO 4,5" LINER Blank Liner BLANK LINER IN 30' SECTIONS, AL TERNA TING WITH SLOTTED LINER 30' SECTIONS ID 4.830 5.010 7,875 4,875 4.830 3.940 3.958 3.813 3.970 3613 3615 3625 3632 3697 3.875 3,875 3.875 3.750 3.960 5.630 7493 3735 Blank Liner 7704 3767 LOCATOR BAKER LOCATOR SUB 13242 3810 SHOE GUIDE SHOE 4" ROT SILVER BULLET WÆCCENTRIC NOTE (float drilled out) 3.510 3.510 0.000 NIP (7416-7419, OD:6.060) In¡",.. Date [HQte 4129/2003 MULTILATERAL PRODUCER WELL XO (7428-7430, OD:5.770) Perf (7704-13179) TREE: ABB VETCO GRAY 1 HAORZT 1 41/16" 5M (w/penetrator wire) TREE CAP CONNECTOR: 9" OTIS Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 87' 1. Operations Performed: STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS APR 0 6 2006 Abandon 0 Alter Casing 0 Repair Well 0 Pull Tubing 0 Ope rat. ShutdownD Stimulate 0 asks Oil ~ co' ~GL.to ~et Pump' ns. mISSIon Waiver 0 Time~80e Re-enter Suspended Well 0 5. Permit to Drill Number: Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 . Stratigraphic 0 Exploratory 0 Service 0 203-041 6. API Number: 50-029-23144-00 9. Well Name and Number: 1 C-178 8. Property Designation: ADL 25649 / 25638 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE LOWER LATERA PROD. CASING Perforation depth: 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool measured 13280' feet true vertical 3811' feet measured 13246 feet true vertical 3810 feet Length Size MD 110' 16" 110' 7647' 7-5/8" 7734' 5815' 4-1/2" 13244' Plugs (measured) Junk (measured) TVD Burst Collapse 110' 3770' 3810' Measured depth: 7704' - 13179' true vertical depth: 3767' - 3809' .,. ,'_ ". ',e' !:~-¡;.,"", ;~~"'1;;"~~¡¡;"1.-" WlI¡¡¡i~ "" ..=~> ., " 'jf¡ ilL J- ~ £-U~_l....\ Tubing (size, grade, and measured depth) 4-1/2" , L-BO, 7336' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIP SSSV= 498' " . 12. Stimulation or cement squeeze summary: Intervals treated (measured) none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 616 932 313 1115 292 Subsequent to operation 1204 495 471 1771 307 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 - Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 ,. GasD WAG 0 GINJD WINJ 0 WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O, Exempt Title Phone BFl APR 7 1006 r-~S~ ~ I<ntt ì Form 10404 Revised 0412004 1C-178 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 3/13/2006SET JET PUMP (68" OAL, SIN PH1041) ON 3.75" DB LOCK IN CMU AT 6925' RKB. 3/12/2006 DISPLACED TBG & CSG WITH 290 BBL DSL. COMBO MIT T x IA 2500 PSI, GOOD. PULLED PLUG. ATTEMPTED SET JET PUMP AT 7109' RKB. IN PROGRESS. - Schlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well ;;./' 2N-305 J () O· ì Jç J2N-308 I q<\ -Di~ ./2N-317 (q 3 ~ N], U'2G-06 13"'( - ~~J.. ../ 1 Y -04 Î 8 .~ - fi ~ l \,/3J-10 iri....l\~ J 2U-10 I~) - t )I.~ c-'1C-178 ~Q:)- t.<.f( Job# 11047348 11047344 11047345 11022913 11047351 11058227 11047352 11022908 ~-c 'h.\-O~.= ff'¡-='- C" .. C)'-''''h :;jJAhd\!t;t; 0CP J f, LUU~, Log Description Date SBHP SURVEY SBHP SURVEY SBHP SURVEY FLOWING BHP INJECTION PROFILE \} 'I L MULTI-FINGER CALIPER LOG PRODUCTION PROFILE W/DEFT PRODUCTION PROFILE WID EFT 07/25/05 07/24/05 07/24/05 07/20/05 07/27/05 07/18/05 07/28/05 07/14/05 I r ..'1 ! {;'!?\ // / / : /'Ii.li / I ' : I.. ¿ I , J I: !" . ¡,ljl11rt~..,.. (~/ /vt' f,--d SIGNED: NO. 3443 08/03/05 ~ff3- O'Lf I Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk DATE: BL Color CD -.,../ 1 1 1 1 1 1 1 1 ~ ~\. ......) {~\ -~..:,-. V"~ \i v Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ,J~ DATA SUBMITTAL COMPLIANCE REPORT 6/27/2005 Permit to Drill 2030410 Well Name/No. KUPARUK RIV U WSAK 1 C-178 Operator CONOCOPHILLlPS ALASKA INC sp~J. '1/Jp AOS;i API No. 50-029-23144-00-00 MD 13280/ TVD 3811 / Completion Date 5/1/2003'; Completion Status 1-01L Current Status 1-01L ~ ----------- REQUIRED INFORMATION Mud Log No Samples No Directional surve~Yes.-J ----------- DATA INFORMATION Types Electric or Other Logs Run: GRlRes Well Log Information: Logl Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint) -,~ Log Log Run Scale Media No Interval OH / Start Stop CH Received Comments I ~() ARpt :~ Þ. C-t:i'!f ~ 12030 LIS Verification 12030 Induction/Resistivity Name Interval Start Stop 1-3 2559 13280 Open 6/20/2003 MWD 25 Final 120 13280 Open 6/20/2003 RWD - Multiple Propagation Resistivity, Gamma Ray 25 Final 120 13280 Open 6/20/2003 RWD - Multiple Propagation Resistivity, Gamma Ray Sample Set Sent Received Number Comments /i~t~ 12030 Induction/Resistivity I "-- Well Cores/Samples Information: '- ADDITIONAL INFORMATION Y/~ Daily History Received? ~'/N ~N Well Cored? Chips Received? Y / N Formation Tops Analysis Received? ~ Comments: Compliance Reviewed By: ~ II Date: Â1j~:2Jro~- Re: CPAI West Sak well1C-178 (PTD 2030410) ) ) Subject: Re: CPAI West Sak we1l1C-178 (PTD 2030410) From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Tue, 29 Mar 2005 10:34:47 -0900 To: NSK Problem Well Supv <n1617@conocophillips.com> Brad, I have looked at the information regarding how this well has been authorized to produce. Gas lift was originally done shortly after the well was completed as well. Subject to your normal production well operating guidelines, we do not object to your keeping 1C-178 and 1C-178Ll producing under gas lift. Please keep us advised of any changes in the wells operating condition. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom, I would like to request a variance for well 1 C-178 to continue producing this well with gas lift. This well was originally slated to be run with a surface powered jet pump, but we would like to continue operation with gas lift until the offset injector has achieved water breakthrough. We have previously obtained a 30 day temporary gas lift variance which ends today 03-28-05. Thanks, Brad Gathman ConocoPhillips Alaska Inc. Problem Well Supervisor 907 -659-7224 1 of 1 3/29/2005 10:35 AM FW: CPA 1C-178 Temp Conversion to gas lift ) ) Subject: FW: CPA 1C-178 Temp Conversion to gas lift From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Sun, 27 Feb 2005 14:18:58 -0900 To: tom_maunder@admin.state.ak.us CC: NSK West Sak Prod Engr <n1638@conocophillips.com>, NSK Problem Well Supv <n 161 7@conocophillips.com> Tom: Today ConocoPhillips put 1 C-178 on temporary gaslift production. The test is not to exceed 30 days and you will be notified when the test is over. Please call if you have any questions. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907 -659-7224 -----Original Message----- From: NSK Problem Well Supv Sent: Tuesday, January 04, 2005 9:38 AM To: tom_maunder@admin.state.ak.us Subject: CPA 1B-101 & 1C-178 Temp Conversion to gas lift Tom, Wells 1 B-1 01 (PTD# 2031330) and 1 C-178 (PTD# 2030410) are surface powered jet pump wells. To verify the watercut, we intend for the wells to be converted to gas lift for a time not to exceed 30 days. We will notify you when the wells are converted to gas lift and when converted back to jet pump. Will this be acceptable? Thanks, Brad Gathman ConocoPhillips Alaska Inc. Problem Well Supervisor 907-659-7224 1 of 1 3/29/2005 10:31 AM 1 C-178 Production Test 2500.00 Liquid rates corrected to back out diesel pumped into flowline 2000.00 - ~ 1500.00 - ß\-\ \-\? .~'" BHFP range 1350 - 1370 psi Sensor at 6976' 1000.00 - --- 4fIt.--,_ _ ~_ A ~f'L>o. P ~--~~~ . "", -\-'^'- \"" ~,-- ~--&......~~~........ --~-- ".tfi:* ~ . ~s",~~~k 500.00 - -- - PTS BOPD ~PTS TOTAL FLUID, BPD ====- BHFP, PSI -GL RATE, MCFPD 0.00 - 5/30/03 14:24 5/30/03 16:48 5/30/03 19:12 5/30/0321:36 5/31/030:00 5/31/032:24 5/31/034:48 5/31/037:12 5/31/039:36 Date and Time ') STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Gas U Plugged D Abandoned 0 20AAC 25.105 No. of Completions _ Suspended 0 WAG 0 20AAC 25.110 Other 1a. Well Status: Oil 0 1 b. Well Class: Development 0 Exploratory D Service D Stratigraphic Test D 12. Permit to Drill Number: GINJ D 2. Operator Name: WINJ D WDSPL D 5. Date Comp., Susp., or Aband.: May 1, 2003 6. Date Spudded: April 4, 2003 7. Date TD Reached: April 15, 2003 8. KB Elevation (ft): 87' AMSL 9. Plug Back Depth (MD + TVD): 13246' MD 1 3810' TVD 10. Total Depth (MD + TVD): 13280' MD 1 3811' TVD ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 1503' FNL, 1195' FWL, Sec. 12, T11 N, R10E, UM At Top Productive Horizon: 786' FSL, 1181' FWL, Sec. 2, T11 N, R10E, UM Total Depth: 203-041 1 13. API Number: 50-029-23144-00 14. Well Name and Number: 1C-178 15. Field/Pool(s): Kuparuk River Field West Sak Oil Pool 1031' FSL, 190' FWL, Sec. 35, T12N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 562202 y- TPI: x- 556888 y- Total Depth: x- 555849 y- 18. Directional Survey: Yes 0 No D 16. Property Designation: ADL 25649 1 25638 Zone-4 Zone-4 5968735 5970982 5976498 11. Depth where SSSV set: Land Nipple @ 498' 17. Land Use Permit: ALK 467 1 463 Zone-4 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1924' vertical 21. Logs Run: GR/Res 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD Surface 138' 42" 172 sx ArcticCrete Surface 7733' 9.875" 691 sx AS III Lite, 276 sx Class G 7401' 13246' 6.75" slotted liner CASING SIZE WT. PER FT. 62.5# 29.7# 12.6# GRADE B L-80 L-80 AMOUNT PULLED 16" 7.625" 4.5" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): TUBING RECORD DEPTH SET (MD) 7336' 24. SIZE 4.5" PACKER SET (MD) 7086' 't .....-' . "..,...._" ·_,,'",·...·'0' ",," ~I COMPLET~()N ¡ § nil "no: 'I ~ . ,...¡..., · p;i, . -::2.f t - ~ ' ,. f' ~ ~ ¡ VER~::t~ ~~ L:::~:::::J slotted liner 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) May 31,2003 Jet Pump Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 6/21/2003 12 hours Test Period --> 1937 437 5 100% 226 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. 334 psi 2340 psi 24-Hour Rate -> 3874 874 10 not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). RECEiVED JUL 0 2 2003 Submit core chips; if none, state "none". NONE Alaska Oil & Gas COilS. Commission Am:horage Form 10-407 Revised 2/2003 CONTINUED ON REVERSE SIDE JUl 02. £\¡II:I ORIGINAL Submit in duplicate RBDMS Blfb GV 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 C~ 178 West Sak B West Sak C West Sak D 7663' 7530' 7359' 3763' 3743' 3703' N/A RECEIVE JUl 0 2 2003 Alaska Oi~ 8: 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: Steve McKeever @ 265-6826 Printed ~ . fLThoma8.[ Signature \ <:::..~~ \ \,~ Title: rhO"8 ,Kuparuk Drilling Team Leader Date 7( ( /~ '7 Prepared by Sharon Allsup-Drake INSTRUCTIONS 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 far 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: Flowìng, 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 1 0-407 Revised 2/2003 OR\G\NAL ) ) ConocoPhlllips Alaska Operations Summary Report Page 1 of 10 Set bk std of HWDP - P/U 3 NMCSDP - Ck connection torque on MWD & Mud motor - Re scribe. Drill, Slide & Survey 9.875" hole f/175' to 600' MD ( 598' TVD) WOB 3-15k, RPMs 60, PRate 550 gpm @ 130 spm, PP 1650, Up wt 52k, Dn wt 52k, Rot wt 52k, ART 2.8 hrs, AST 2.1 hrs Drill, Slide & Survey 9.875" hole f/600' to 1381' MD ( 1326' TVD) WOB 3-15k, RPMs 60, PRate 550 gpm @ 130 spm, PP 1800, Up wt 70k, Dn wt 68k, Rot wt 71 k, Torq on bttm 3k ft-Ibs, off bttm 1-3k ft-Ibs Mud wt 8.9 ppg, Vis 180 , ART 2.7 hrs, AST 4.7 hrs***Note Moderate show of gas hydrates @ 1185' MD 10.00 DRILL DRLG SURFAC Drill,Slide & Survey 9.875" hole f/1381' to 2175' MD (1767' TVD) ART 2.1 hrs, AST 5.4 hrs, WOB 25/35k, RPMs 60, Prate 650 gpm, PP 2750, Up wt 74k, Dn wt 61k, Rot wt 74k, Torq on bttm 3k ft-Ibs, off bttm 2k ft-Ibs 0.50 DRILL SFTY SURFAC Rig evac drill w/ all1C pad contractors & Security participating in a pad evac drill-** Note** Recip and Circu DP during drill with essential personell still on Rig. Report will be generated. 0.50 RIGMNT RGRP SURFAC Repair bleeder line on #2 mud pump. 1.00 DRILL DRLG SURFAC Drill,Slide & Survey 9.875" hole f/2175' to 2221' MD (1785' TVD) ART 0.2 hrs, AST 0.3 hrs, WOB 5/7k, RPMs 60, Prate 456 gpm, PP 1550, Up wt 74k, Dn wt 61 k, Rot wt 74k, Torq on bttm 3k ft-Ibs, off bttm 2k ft-Ibs 5.00 DRILL DRLG SURFAC Drill,Slide & Survey 9.875" hole f/2221' to 2688' MD (1976' TVD) ART 3.1 hrs, AST 0.4 hrs, WOB 5-15k, RPMs 60, Prate 650 gpm, PP 2900, Legal Well Name: 1 C-17 8 Common Well Name: 1 C-178 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From- To Hou rs Code Sub Phase Code 4/3/2003 00:00 - 00:30 0.50 MOVE MOVE MOVE 00:30 - 01 :45 1.25 MOVE MOVE MOVE 01:45-03:15 1.50 MOVE MOVE MOVE 03:15 - 05:30 2.25 MOVE MOVE MOVE 05:30 - 07:00 1.50 MOVE MOVE MOVE 07:00 - 09:00 2.00 MOVE MOVE MOVE 09:00 - 10:00 1.00 MOVE MOVE MOVE 10:00 - 12:00 2.00 DRILL RIRD RIGUP 12:00 - 13:30 1.50 DRILL RIGUP 13:30 - 16:00 2.50 DRILL RIRD RIGUP 16:00 - 16:15 0.25 DRILL SFTY RIGUP 16:15-21:30 5.25 DRILL PULD RIGUP 21 :30 - 23:00 1.50 DRILL PULD RIGUP 23:00 - 00:00 1.00 DRILL PULD SURFAC 4/4/2003 00:00 - 02: 15 2.25 DRILL PULD SURFAC 02:15 - 02:30 0.25 DRILL SFTY SURFAC 02:30 - 02:45 0.25 WELCTL BOPE SURFAC 02:45 - 03:00 0.25 RIGMNT OTHR SURFAC 03:00 - 03:15 0.25 DRILL CIRC SURFAC 03:15 - 04:00 0.75 DRILL DRLG SURFAC 04:00 - 06:00 2.00 DRILL PULD SURFAC 06:00 - 12:00 6.00 DRILL DRLG SURFAC 12:00 - 00:00 12.00 DRILL DRLG SURFAC 4/5/2003 00:00 - 10:00 10:00 - 10:30 10:30 - 11 :00 11 :00 - 12:00 12:00 - 17:00 Start: 4/4/2003 Rig Release: 5/1/2003 Rig Number: Spud Date: 4/2/2003 End: 5/1/2003 Group: De$cripticm of Operations Prep Rig for Move from 1C-174 to 1C-178. Move Pipe Sheds,Rock washer & Utility modules dn pads out of way. Move sub off 1C-174 and spot over 1C-178 conductor. Move in and spot Pits,Pumps,Motor & Boiler modules Spot & Berm Rock washer - Spot Pipe sheds Connect all Rig service lines between modules. Complete Rig Acceptance list. Accept Rig 10:00 hrs 4/3/03 - N/U Diverter system - Mix spud mud - Loading 4" DP into pipe shed Con't N/U Diverter - Mix Spud Mud - Load 4" DP into pipe shed. C/O Top Drive tools to 4" XT39 - Change saver sUb,grabs tong dies & stabbing guide. PJSM on P/U & Std BK DP review procedure,pinch points & identify known hazards P/U & Std BK 70 Stds 4" DP in derrick (App 6615') P/U & Std BK 29 jts HWDP + jars in derrick ( 10 stds) P/U & M/U BHA #1 - M/U Bit,motor,2 short NMCSDP ,MWD & orient to motor Con't P/U BHA #1 - P/U UBHO sub, orient, adj UBHO, P/U 1 std HWDP (Tag @ 110') Pre Spud meeting with co man, crew & all contractors. Review Hazards & discuss mitigation strategy. Fuction test Diverter System - Knife valve open in 10 seconds, diverter seal 26 seconds. System built to 200 psi 33 sec, full build in 3 min 19 sec. Level Sub - Shim sub on DS Flood conductor - Check diverter system for leaks Drill 9.875" hole 110' to 175' (Assy buried) Printed: 7/11/2003 3:35:36 PM ) ) Day Light saving Time- Set clock ahead 1 hour Cut drill line (61' cut) - Service Top Drive & Draworks TIH w/ HWDP - P/U Ghost Reamer - Run 1 std DP ** Note** Ghost reamer center is 1093' behind Bit. Pulse Test MWD "OK" - Blow down Top Drive TIH to 2590' (Took wt (10-15k) in spots thru permfrost 1000' to 1800') Wash and ream 2590' to 2688' - Heavy cutting discharge - CBU X 1.5 and cleaned up. Rotate 60 RPMs, Prate 320 gpm, mud very thick with cutting. Drill & Survey w/ AutoTrak 9.875" hole 2688' to 3054' MD (2123 TVD) ADT 2.0 hrs, WOB 10-20, RPMs 150, Prate 600 gpm, PP 3000 psi, Up wt 85k, Dn wt 60k, Rot wt 70k, Torq on bttm 2-7k ft-Ibs, Off bttm 2-3k ft-Ibs No problems - Dir. work & tools working well 12.00 DRILL DRLG SURFAC Drill & Survey w/ AutoTrak 9.875" hole 3054' to 4115' MD( 2540' TVD) ADT 7.9 hrs, WOB 10-20k, RPMs 150, Prate 625 gpm, PP 3250 psi, Up wt 100k, Dn wt 65k, Rot wt 76k, Torq on bttm 2-9k ft-Ibs, Off bttm 4-5k ft-Ibs Mud wt 9.1+, Vis 115. ** Avg Rap 142 fph No directional problems - Control is good - Baroid Models show clean hole. @ this time we have filled to 75% capacity 2.5 cutting bins with recycle cuttings. Drill 9-7/8" hole from 4,115'-5,203'. WOB-5-20K, RPM-150, Pump-3,200 psi @ 590 gpm, UWT-125K, DWT-60K, TQ off/on-6-7/9 ft-Ib. ART =18.2 hr, AST =0 hr. Drill ahead 9-7/8" hole from 5,203'-6,356, sweeping hole w/ BAROLlFT. WOB-10-25K, RPM-150, Pump-3,350 psi @ 592 gpm, UWT-125K, DWT-63K, TO off/on-7-8/10 ft-Ib. ART=8.0 hr, AST=O hr. Drill 9.875" hole w/ AutoTrak 6365' to 6806' MD - At this depth the bit stopped drilling. At the same time we began having some type megnetic interference. We were at the exact MD noted of a close crossing and it was decided to stop and evaluate all measurements and surveys. We had had some metal shaveing on shaker screens earlier but it was felt these were from the pryor "WASH OVER" job and still laying in system. 4.00 DRILL SURV SURFAC Stop Drilling to Evaluate Directional Information Pump 17 bbl 0.22 ppb 9.2 ppg Barolift sweep. Circu & Recip Drill Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-178 1 C-178 ROT - DRILLING n1334@ppco.com Doyon 141 Date From- To' HoU rs Code Sub Phase Cbdkr 4/5/2003 12:00 - 17:00 5.00 DRILL DRLG SURFAC 17:00 - 18:00 1.00 DRILL CIRC SURFAC 18:00 - 21 :00 3.00 DRILL TRIP SURFAC 21 :00 - 22:00 1.00 DRILL CIRC SURFAC 22:00 - 23:00 1.00 DRILL TRIP SURFAC 23:00 - 00:00 1.00 DRILL PULD SURFAC 4/6/2003 00:00 - 00:30 0.50 DRILL PULD SURFAC 00:30 - 02: 15 1.75 DRILL PULD SURFAC 02:15 - 03:15 1.00 DRILL OTHR SURFAC 03:15 - 04:45 1.50 RIGMNT RSRV SURFAC 04:45 - 05:30 0.75 DRILL TRIP SURFAC 05:30 - 06:15 0.75 DRILL DEOT SURFAC 06:15 - 07:15 1.00 DRILL TRIP SURFAC 07: 15 - 08:00 0.75 DRILL REAM SURFAC 08:00 - 12:00 4.00 DRILL DRLG SURFAC 12:00 - 00:00 4/7/2003 00:00 - 12:00 12.00 DRILL DRLG SURFAC 12:00 - 00:00 12.00 DRILL DRLG SURFAC 4/8/2003 00:00 - 06:00 6.00 DRILL DRLG SURFAC 06:00 - 10:00 Start: 4/4/2003 Rig Release: 5/1/2003 Rig Number: Spud Date: 4/2/2003 End: 5/1/2003 Group: DescriptionofÖperations . Up wt 72k, Dn wt 62k, Rot wt 70k, Torq on bttm 4k ft-Ibs, off bttm 3k ft-Ibs Mud wt 9.0 ppg, Vis 157 Circu & Pump Tandum sweeps - #1 sweep .25 ppb 20 bbl Barolift & follow after 800 stks ,#2 = 27 bbl weighted sweep @ 11.5 ppb. PRate 650 gpm, RPMs 60 (Baker Inteq max with this tool) Had a good to moderate show of cutting @ BUs. Bk Ream OOH 2689' to 1104' @ drilling rate, 650 gpm, 60 RPMs - No problems- @ HWDP hole unloading cutting. Circu hole clean due to high cutting load TOH on elevators w/ HWDP - No problems - No excess overpull UD BHA #1 UD BHA #1 - UD MWD, 2 NMCSDPs M/U BHA #2 - P/U AutoTrak,Bit, Initialize MWD, P/U 3 NMCSDPs,Stab, XO,Flt Printed: 6/25/2003 11 :01 :40 AM ) ) Legal Well Name: 1 C-178 Common Well Name: 1 C-178 Spud Date: 4/2/2003 Event Name: ROT - DRILLING Start: 4/4/2003 End: 5/1/2003 Contractor Name: n1334@ppco.com Rig Release: 5/1/2003 Group: Rig Name: Doyon 141 Rig Number: Date ·Frbm.·-To Hours . Code Sub Code 4/8/2003 06:00 - 10:00 4.00 DRILL SURV SURFAC string at all times. PR 510 gpm, RPMs 100, PP 3050. Circu 5 X BUs Confer with West Sak drilling team and review all figures. After all figures were checked and double checked the "ON SIGHT" directional teams figures showed the two wells to be 102' apart. These numbers were confirmed with West Sak team in Town. 10:00 - 12:00 2.00 DRILL DRLG SURFAC Drill 9.875" hole wI AutoTrak 6806' to 6978' MD (3589' TVD) ADT 5.8 hrs, WOB 5-30k, RPMs 150, PR 120 spm, 510 gpm, PP 3200psi, Up wt 135k, Dn wt 64k, Rot wt 92, Torq on bttm 6013k ft-Ibs, Off bttm 8k ft-Ibs, Mud wt 9.3 ppg, Vis 89 12:00 - 00:00 12.00 DRILL DRLG SURFAC Drill 9.875" hole wI AutoTrak 6978' to 7726' MD (3770' TVD) ADT 8.8 hrs, WOB 10-30k, RPMs 150, PR 120 spm, 510 gpm, PP 3400psi, Up wt 138k, Dn wt 59k, Rot wt 87k, Torq on bttm 6-12 ft-Ibs, Off bttm 9-11 k ft-Ibs, Mud wt 9.2+, Vis 90 Avg ROP for day 93.4 fph - No problems -Drilling going well. 4/9/2003 00:00 - 02:00 2.00 DRILL DRLG SURFAC Drill & Survey 9.625" hole wI AutoTrak 7726' to 7739'MD (3771' TVD)ADT 1.7 hrs, WOB 35-45k, RPMs 150, PR 510 gpm, PP 3250, Up wt 138k, Dn wt 59k, Rot wt 87k, Torq on bttm 6-15k ft-Ibs, Off bttm 9-11 k ft-Ibs, Mud wt 9.3+, Vis 90 02:00 - 06:00 4.00 DRILL CIRC SURFAC Pump 25 bbl .25ppg 11.9ppg Barolift sweep #1- Circu BUs X 3 - PR 120 spm, 510gpm, RPMs 150, Recip string full std at all times - Std Bk 1 std I hr- Shakers clean 06:00 - 08:00 2.00 DRILL TRIP SURFAC Bk Ream 15 stds OOH to 6234' , PR 400 gpm, 150 RPMs - No problems- No excess drag 08:00-11:15 3.25 DRILL CIRC SURFAC Pump 25 bbl .25ppg 11.9ppg Barolift sweep #2- Circu BUs X 3 - PR 120 spm, 510gpm, RPMs 150, Recip string full std at all times - Std Bk 1 std I hr Shakers clean -Shut dn - Monitor well -Static- Pump dry job - Blow dn Top Drive 11 :15 - 12:00 0.75 DRILL TRIP SURFAC TOH on elevators to 5200' - No problems - No excess drag 12:00 - 15:30 3.50 DRILL TRIP SURFAC TOH on elevators - Tight hole @ 3212 - Work and Ream until clean - Con't TOH 15:30 - 18:00 2.50 DRILL PULD SURFAC UD BHA - UD Ghost reamer (1/2" under guage) - Std Bk HWDP - UD 2 jts HWDP, jars, XO, 3 NMCSDP, Fit sub, Stab - Dn Load MWD - UD MWD, AutoTrak & Bit - Clear all tools from rig floor. 18:00 - 19:30 1.50 CASE RURD SURFAC R/U to Run 7.625' 29.7# L80 BTC-M - Dummy run hanger to head"OK" 19:30 - 19:45 0.25 CASE SFTY SURFAC PJSM - Review Csg running detail wI all crews - Discuss known hazards & pinch points 19:45 - 23:30 3.75 CASE RUNC SURFAC Run Csg - Run 70 jts 7.625" 29.7# L80 BTC-M to 3000' +1- - No problems- -Miinor tight spot @ 425' 23:30 - 00:00 0.50 CASE CIRC SURFAC Clrcu BU @ 3000' - Recip csg 25' - Work PR up slowly to 6 bpm 4/1 0/2003 00:00 - 00: 15 0.25 CASE CIRC SURFAC Con't CBU @ 3000' - PR 6 bpm, PP 300psi, Recip 12' - NEW CREW ,PJSM running csg - Review csg detail- review known hazards for this task. 00:15 - 03:45 3.50 CASE RUNC SURFAC Con't run 7.625" csg to 6035' - Slowed running speed because of short returns. After slowing running speed, displacement seems to be correct. 03:45 - 05:15 1.50 CASE CIRC SURFAC CBU @ 6035' - @ BUs had 1 O.Oppg wt, 150 vis mud to surface. Con't to circu until mud properties improved. Wt out 9.5+, Vis 89 05:15 - 07:30 2.25 CASE RUNC SURFAC Con't run 7.625" 29.7# L80 BTC-M to 7734' - Lost 30 bbls mud while running csg. 07:30 - 08:15 0.75 CASE RUNC SURFAC UD Frank's fill up tool- Blow dn Top Drive - RIU CMT head 08:15 - 12:00 3.75 CEMENT CI RC SURFAC Circu & Condition to CMT - Stage up pumps to 7 bpm, final rate 8 bpm Printed: 6/25/2003 11 :01 :40 AM .) ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-178 1 C-178 ROT - DRILLING n 1334@ ppco.com Doyon 141 · Hours .. Code Sub Code Start: 4/4/2003 Rig Release: 5/1/2003 Rig Number: Spud Date: 4/2/2003 End: 5/1/2003 Group: Description Of Operatiqns· 3.75 CEMENTCIRC SURFAC @ 480psi Hold PJSM while circu. Discussed CMT detail with Co Man, crew and all contractors. 3.75 CEMENT PUMP SURFAC Pump CMT job per well plan - Pump 10 bbls CW1 00 - Test lines to 3500 - Pump 40 bbls CW100,50 bbls Mudpush wI dye, Drop bttm plug, 526 bbls lead @ 10.7 ppg, 58 bbls Tail @ 15.8 ppg, Drop bttm plug, kick out plug wI 20 bbls water and turn over to rig. Rig displace @ 7 bpm, Bump plug wI 3,275 Stks, 1,500 PSI - Ck floats "Held" ** Note** Had 60 bbls good 10.7 ppg cmt to surface. CIP at 1440 Hrs. UD CMT head - UD Landing jt N/D Diverter System - Wash out annular Orient & N/U Vetco Gray ESPW 16" X 7.625" Csg Head - Test ODC overshot to 1200m psi fl 10 min "OK" N/U BOPs C/O bttm rams to 4" - C/O bails on Top Drive R/U to test BOPs - AOGCC rep John H. Crisp on site to witness test. Test BOPs & Choke manifold to 250 I 5000 psi, Test Annular to 250 I 3500 psi per CPAI testing policy. Con,t Test BOPs - Test BOP, Valves & choke manifold 250/5000 psi - Test Annular 250/3500. AOGCC rep John H. Crisp on site to witness test. Floor Weatherford 4" IBOP ( dart valve) failed to test. C/O valve and retest "OK" Pull test plug - Install wear bushing P/U Mach 1 XP motor(1.2 deg AKO)- M/U Bit, MWD, Scribe, plug in & initialize tool, P/U 3 NMCSDP, XO, 1 SWDP, Jars, 1 SWDP, std DP Pulse Test MWD "OK" - Blow dn Top Drive TIH picking up 4" DP singles from pipe shed. - Fill every 2500' Con't TIH picking up 4" DP singles from pipe shed to 7258' 0 TIH wI stds from derrick to 7569' Wash & Ream fl 7569' to 7645' ( Float collar) Circu BU - PR 195 gpm wI 1000 psi R/U & Test Csg to 2500 psi 110 min (Lost 10 psi after 10 min) Drlg FC,CMT, FS and 20' new hole to 7759' (CMT drilled meduim to firm in shoe track) Circu - Pump 40 bbl Hi Vis sweep ahead and C/O to 8.9 ppg Baradril-N mud R/U and preform FIT to 12.5 ppg - Apply 705 psi at surface wI 8.9 ppg mud (3771 TVD - 20 psi loss after 10 min = 12.5 EMW Drill, Slide & Survey 6.75" hole 7759' to 7908' MD (3776' TVD) ART 1.2 hrs AST 0.9 hrs, WOB 1/5k, RPMs 80, PR 250 gpm, PP 1040, Up wt 110k, On wt 70k, Rot wt 84k, Torq on bttm 6k, Off bttm 5k, SPR @ 7759' (3774' TVD) #2 @ 20 spm = 260 psi @ 40 spm = 470 psi. 12.00 DRILL DRLG PROD Drill,Slide & Survey 6.75" hole fl 7908' to 8655' MD (3775' TVD) ART 7.0 hrs, AST 1.2 hrs, WOB 3-15k, RPMs 80, PR 250 gpm, PP 1260 psi, Up wt 110k, On wt 68k, Rot wt 87k, Torq on bttm 7-8k ft-Ibs, off bttm 7k ft-Ibs, Mud wt 9.0+, Vis 46 - Good steady show of oil at shakers, No problems - All going well. 12.00 DRILL DRLG PROD Drill,Slide & Survey 6.75" hole fl 8655' to 9750' MD (3788' TVD) ART 6.1 hrs, AST 1.5 hrs, WOB 3-15k, RPMs 80, PR 250 gpm, PP 1300 psi, Up wt 11 Ok, On wt 58k, Rot wt 82k, Torq on bttm 9k ft-Ibs, off bttm 7k ft-Ibs, Mud wt 8.9+, Vis 45 - Steady oil show @ shakers - No directional control problems -All going well. **Note** Built 100 bbls of mud for 4/10/2003 08:15 - 12:00 12:00 - 15:45 15:45 - 16:15 0.50 CEMENT RURD SURFAC 16:15 - 18:00 1.75 WELCTL NUND 'SURFAC 18:00 - 18:45 0.75 WELCTL NUND SURFAC 18:45 - 21:15 2.50 WELCTL NUND SURFAC 21:15 - 22:45 1.50 WELCTL NUND SURFAC 22:45 - 23: 15 0.50 WELCTL BOPE SURFAC 23:15 - 00:00 0.75 WELCTL BOPE SURFAC 4/11/2003 00:00 - 03:30 3.50 WELCTL BOPE SURFAC 03:30 - 04:00 0.50 WELCTL BOPE SURFAC 04:00 - 07:00 3.00 DRILL PULD SURFAC 07:00 - 07:30 0.50 DRILL DEOT SURFAC 07:30 - 12:00 4.50 DRILL TRIP SURFAC 12:00 - 14:30 2.50 DRILL TRIP SURFAC 14:30 - 15:00 0.50 CEMENT COUT SURFAC 15:00 - 16:15 1.25 CEMENT COUT SURFAC 16:15 - 17:00 0.75 CEMENTOTHR SURFAC 17:00 - 18:15 1.25 CEMENT DSHO SURFAC 18:15 - 19:30 1.25 CEMENT DSHO SURFAC 19:30 - 20:15 0.75 CEMENT FIT SURFAC 20:15 - 00:00 3.75 DRILL DRLG PROD 4/12/2003 00:00 - 12:00 12:00 - 00:00 Printed: 6/25/2003 11 :01 :40 AM ") ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-178 1 C-178 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 4/4/2003 Rig Release: 5/1/2003 Rig Number: Spud Date: 4/2/2003 End: 5/1/2003 Group: Date ·Sub· From.; To .. HoUrs .code COdê 4/12/2003 12.00 DRILL DRLG PROD 12:00 - 00:00 4/13/2003 12.00 DRILL DRLG PROD 00:00 - 12:00 12:00 - 12:45 0.75 DRILL DRLG PROD 12:45 - 16:00 3.25 DRILL TRIP PROD 16:00 - 17:00 1.00 DRILL CIRC PROD 17:00 - 18:45 1.75 RIGMNT RSRV PROD 18:45 - 19:00 0.25 DRILL OBSV PROD 19:00 - 19:45 0.75 DRILL TRIP PROD 19:45 - 21 :00 1.25 DRILL TRIP PROD 21 :00 - 22:45 1.75 DRILL CIRC PROD 22:45 - 00:00 1.25 DRILL TRIP PROD 4/14/2003 00:00 - 00:45 0.75 DRILL TRIP PROD 00:45 - 01 :00 0.25 DRILL REAM PROD 01 :00 - 12:00 11.00 DRILL DRLG PROD 12:00 - 00:00 12.00 DRILL DRLG PROD 4/15/2003 00:00 - 03:30 3.50 DRILL DRLG PROD 03:30 - 04:00 0.50 DRILL DRLG PROD 04:00 - 05:00 1.00 DRILL TRIP PROD 05:00 - 06:00 1.00 DRILL DRLG PROD 06:00 - 12:00 6.00 DRILL DRLG PROD 12:00 - 12:45 0.75 DRILL CIRC PROD 12:45 - 14:15 1.50 DRILL TRIP PROD 14:15 - 15:00 0.75 DRILL TRIP PROD 15:00 - 18:00 3.00 DRILL CIRC PROD 18:00 - 00:00 6.00 DRILL TRIP PROD dilution of drill solids - Baroid rep is having additional 580 bbls built at Mud Plant for dilution of system. Drill,Slide & Survey 6.75" hole fl 9750' to 10,617' MD(3804' MD TVD) ART 5.8 hrs, AST 1.5 hrs, WOB 3-15k, RPMs 80, PR 250 gpm, PP 1600 psi, Up wt 120k, Dn wt 50k, Rot wt 87k, Torq on bttm 10k ft-Ibs, Off bttm 9k ft-Ibs, Mud wt 9.0 ppg, Vis 45. ** Note** Between 2:00 & 6:00 AM, 580 bbls new 9.0 ppg mud was blended to system for delution. Drill,Slide & Survey 6.75" hole f/ 10,617' to 10,712' MD(' 3806' TVD) ART 0.5 hrs, AST 0.0 hrs, WOB 3-1 Ok, RPMs 80, PR 250 gpm, PP 1600 psi, Up wt 125k, Dn wt 51k, Rot wt 85k, Torq on bttm 10k ft-Ibs, Off bttm 11 k ft-Ibs, Mud wt 9.1 + ppg, Vis 45. Back Ream OOH to 7738' - PR 250 gpm, 80 RPMs Circu BUs + , Blow Dn Top Drive Slip & Cut drillline(65' cut) - Service Top Drive - Ck Brake assy Observe well (Static) - Pump dry job - Blow dn Top Drive TOH on elevators to 6230' (Std #65 DP) TIH - Install 1 ea. Lo Tad roller sub per std to 7743' ** Note** First Lo Tad will be 6230' behind Bit. Circu Surface to Surface wi EP lube pill - Leave EP lube pill in top 920' of ANN to lube rollers on trip in. Con,t TIH - Install 1 ea. Lo Tad roller sub per std to 10,250' Con't TIH - P/U 1 ea. Lo Tad roller sub per std. to 10,652' Ream & Wash to Bttm @ 10,712' Drill,Slide & Survey 6.75" hole f/ 10,712' to 11,641' MD( 3794' TVD) ART 4.6 hrs, AST 0.9 hrs, WOB 3-8k, RPMs 80/90, PR 250 gpm, PP 1600 psi, Up wt 115k, Dn wt 53k, Rot wt 80k, Torq on bttm 8k ft-Ibs, Off bttm 7k ft-Ibs, Mud wt 9.1 + ppg, Vis 45. All going well - Per Baker DD, Lo Tad rollers do appear to help while sliding but we are getting low (8-1 Ok) on Dn Wt. Drill,Slide & Survey 6.75" hole fl 11641' to 12670' MD( 3800' TVD)ART 5.0 hrs, AST 1.4 hrs, WOB 3-8k, RPMs 80/90, PR 250 gpm, PP 1600 psi, Up wt 120k, Dn wt 46k, Rot wt 81k, Torq on bttm 9.5k ft-Ibs, Off bttm 8k ft-Ibs, Mud wt 9.0 ppg, Vis 44. All going well - Per Baker DD, Lo Tad rollers do appear to help while sliding but we are getting low (8-1 Ok) on Dn Wt. - It appears the Lo Tad rollers are helping while sliding to a good degree. Baker DD Chip Milchalk will prepare a report on his thoughts concerning Lo Tad roller subs. Drln f/12670 V12931. Attempt to slide failed, monitor well for TOOH for HWDP. POOH 11 stands dp. RIH w. 10 stands HWDP. Diluted with 560 bbl of new BaraDril-N fluid at 12600 when MBT exceeded 5 ppb. Drlg f12931 V13280. 3810 TVD. (New TD as per geologist, due to geological fault) ADT =4.0, ART =3.1, AST =0.9. Circ and Cond @ 80 rpm-250 gpm. Observe well-Backream out to HWDP (12862) @ 80 rpm-250 gpm-Blowdown top drive-POOH on elevators w/10 stands HWDP to 11934. TIH w\dp to 13280. Circ and Cond, pump hi vis sweep- clear sweep f/ pipe above dc's. Backream out of hole @ 80 rpm's-250 gpm - obtain TQ & Drag Data - Inspect Lo-Tads to 7742. Backreaming up wt=110k, elevator only up wt Printed: 6/25/2003 11 :01 :40 AM ') ) Legal Well Name: 1 C-178 Common Well Name: 1 C-178 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From-To Hours. ····Code Sub Code 4/15/2003 18:00 - 00:00 6.00 DRILL TRIP PROD 4/16/2003 00:00 - 02:00 2.00 DRILL CIRC PROD 02:00 - 05:30 3.50 DRILL TRIP PROD 05:30 - 07:30 2.00 DRILL PULD PROD 07:30 - 08:00 0.50 CASE RURD CMPL TN 08:00 - 14:15 6.25 CASE PULR CMPL TN 14:15 - 18:30 4.25 CASE RUNL CMPL TN 18:30 - 19:30 1.00 CASE RUNL CMPL TN Start: 4/4/2003 Rig Release: 5/1/2003 Rig Number: Spud Date: 4/2/2003 End: 5/1/2003 Group: ·De$criptionofOperåtiöns 4/17/2003 19:30 - 19:45 0.25 CASE RUNL CMPL TN 19:45 - 22:15 2.50 CASE RUNL CMPL TN 22:15 - 00:00 1.75 RIGMNT RSRV CMPL TN 00:00 - 02:00 2.00 WINDOWPULD CMPL TN 02:00 - 05:30 3.50 WINDOWTRIP CMPL TN 05:30 - 07:00 1.50 WINDOWOTHR CMPL TN 07:00 - 07:30 0.50 WINDOWTRIP CMPL TN 07:30 - 08:30 1.00 WINDOWSETW CMPL TN 08:30 - 12:15 3.75 WINDOWSTWP CMPL TN 12:15 - 13:45 1.50 WINDOWCIRC CMPL TN 13:45 - 16:30 2.75 WINDOWTRIP CMPL TN 16:30 - 18:15 1.75 WINDOWPULD CMPL TN 18:15 - 18:30 0.25 WINDOWCIRC CMPL TN 18:30 - 19:00 0.50 WELCTL BOPE CMPL TN 19:00 - 23:30 4.50 WELCTL BOPE CMPL TN 23:30 - 00:00 0.50 WELCTL BOPE CMPL TN 00:00 - 02:00 2.00 DRILL PULD PROD 02:00 - 04:30 2.50 DRILL TRIP PROD 04:30 - 06:30 2.00 DRILL CIRC PROD 06:30 - 10:45 4.25 DRILL DRLG PROD 10:45 - 11 :15 0.50 DRILL SURV PROD 11 : 15 - 11 :30 0.25 DRILL TRIP PROD 11 :30 - 12:45 1.25 DRILL CIRC PROD 12:45 - 16:30 3.75 DRILL TRIP PROD 16:30 - 19:30 3.00 DRILL PULD PROD 19:30 - 22:00 2.50 DRILL TRIP PROD 22:00 - 23:00 1.00 RIGMNT RSRV PROD 23:00 - 00:00 1.00 DRILL SURV PROD 00:00 - 01 :00 1.00 DRILL OTHR PROD 01 :00 - 00:00 23.00 DRILL DRLH PROD 4/18/2003 4/19/2003 4/20/2003 8.00 DRILL DRLH PROD 00:00 - 08:00 140k. Circ and condo Check for flow. Pump dry job, blow down top drive. POOH inspect LOT ADS. Download MWD data, lay down BHA. RU 4.5" liner running equipment. PJSM, run 4.5" liner (193 jts), MU locator sub and hanger. TIH, tagged btm at 13280. Pulled back, set liner from 7401 to 13244. Take TQ and drag data. Entire run on elevators, no rotation required. Drop ball, pumped 780 stks, ball on seat, pressured up to 1800, set hanger, set down 25k #, pressured up to 3100 to release from hanger, bleed off, PU free from liner, pressured up to 4000 psi to blowout ball, POOH. Pump dry job, blow dn top drive. TOOH, Id running tools. Service TO, blocks, lay down running tools. This completes this part of the well. Need to set up DIMS for next well section. Load MWD, PU whipstock assy. RIH slowly to 6929. Log f/3929 V6996. RIH V7403, orient whipstock. Set whipstock at 7403. Mill window fn361 V7387. Circ, pump hi vis sweep, circ BU @ 110 rpm-250gpm-1100 psi, observe well, pump dry job, blow down top drive. TOOH w/ dp. Stand back 10 stands HWDP, LD milling assy, clear floor. PU 1 jt DP, MU stack washer and run through stack clearing melal cuttings, LD wash assy. Pull wear ring and set test plug. RU and test BOPE, test annular 250 low, 3500 high f/ 5 min each, all other 250 low, 5000 high 5 min each, perform accumulator test. Pull test plug, set wear ring (BOPE test witness waived by John Crisp AOGCC) M/U BHA #5 -load mwd & run bha out of derrick. RIH to 7266'. Circ. EP mud lube sweep. Drlg. from 7381' to 7639'. Azmuth don;t look right. POH to 7494 for survey checks. Check surveys @ 7494' & 7559. POH to 7331', CBU-observe well-pump pill-blow down top drive. POH w/ bha #5. Lay down bha #5-change out mwd,s-adjust motor-orient & program mwd-rih w/ hwdp-pulse test mwd. RIH to 7204', Slip & cut 85' drlg. line-service top drive & blocks. RIH taking check shot surveys @ 7494' -7541' & 7590'. PUW 93k SOW 73k RW 85k ADT 2.3 Rotating .3 Sliding 2.0 Pull up from 7639' to 7397'. Cut trough @ 7473'. Drlg. Horizontal hole in L2 from 7473' to 9437'. ART 8.6 AST 4.5 ADT 13.1 PUW 11 Ok SOW 55k RW 84k SPR #1 20 SPM 590# 40 SPM 880# TQ on 8.5k off 7k MW 9.2# TVD 3733'. RPM 80 SPM 70 GPM 250 PP 1700# Drlg. horizontal hole L2 from 9437' to 9962. TVD 3750'. ADT 4.7 ART Printed: 6/25/2003 11:01:40 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-178 1 C-178 ROT - DRILLING n1334@ppco.com Doyon 141 Datè From.; To· HöiJrsGode î~Je Phase 4/20/2003 8.00 DRILL 1.00 DRILL 15.00 DRILL DRLH PROD TRIP PROD DRLH PROD 00:00 - 08:00 08:00 - 09:00 09:00 - 00:00 4/21/2003 00:00 - 05:45 5.75 DRILL DRLH PROD 05:45 - 06:30 0.75 DRILL OTHR PROD 06:30 - 07:00 0.50 DRILL DRLH PROD 07:00 - 08:00 1.00 DRILL CIRC PROD 08:00 - 11 :00 3.00 DRILL TRIP PROD 11 :00 - 12:30 1.50 DRILL OTHR PROD 12:30 - 16:00 3.50 DRILL TRIP PROD 16:00 - 16:45 0.75 DRILL OTHR PROD 16:45 - 17:30 0.75 DRILL OTHR PROD 17:30 - 19:00 1.50 DRILL PULD PROD 19:00 - 19:45 0.75 DRILL OTHR PROD 19:45 - 20:30 0.75 DRILL OTHR PROD 20:30 - 23:00 2.50 DRILL TRIP PROD 23:00 - 23: 15 0.25 DRILL OTHR PROD 23:15 - 00:00 0.75 DRILL CIRC PROD 00:00 - 00:30 0.50 DRILL OTHR PROD 00:30 - 02:00 1.50 DRILL TRIP PROD 02:00 - 02:30 0.50 DRILL CIRC PROD 02:30 - 04:45 2.25 DRILL OTHR PROD 04:45 - 05:00 0.25 DRILL TRIP PROD 05:00 - 21 :30 16.50 DRILL DRLH PROD 4/22/2003 21 :30 - 23:00 1.50 DRILL CIRC PROD 23:00 - 00:00 1.00 DRILL WIPR PROD 4/23/2003 00:00 - 01 :30 1.50 DRILL WIPR PROD 01 :30 - 02:30 1.00 DRILL WIPR PROD 02:30 - 06:00 3.50 DRILL CIRC PROD 06:00 - 13:30 7.50 DRILL TRIP PROD 13:30 - 14:30 1.00 DRILL PULD PROD 14:30 - 15:00 0.50 DRILL OTHR PROD 15:00 - 15:30 0.50 DRILL PULD PROD 15:30 - 16:00 0.50 WELCTL BOPE PROD 16:00 - 19:30 3.50 WELCTL BOPE PROD 19:30 - 19:45 0.25 WELCTL BOPE PROD 19:45 - 22:00 2.25 DRILL PULD PROD 22:00 - 00:00 2.00 DRILL TRIP PROD 4/24/2003 00:00 - 01 :00 1.00 DRILL TRIP PROD 01:00 - 01:15 0.25 DRILL OTHR PROD 01 :15 - 05:30 4.25 DRILL TRIP PROD 05:30 - 08:45 3.25 DRILL CIRC PROD Start: 4/4/2003 Rig Release: 5/1/2003 Rig Number: Spud Date: 4/2/2003 End: 5/1/2003 Group: Description.·ofOperations 2.8 AST 1.9. Pump out from 9962' to 9040' for sidetrack. Drlg. new hole from 9050' to 10198' TVD 3770'. ART 5.5 AST 2.9 PUW 113k SOW 53k RW 84k TO 8.5k on 6.5k off SPR 20 spm 520 PP 40 spm 840 PP MW 9.2. Drlg. horizontal hole from 10198 to 10681'. Survey-trouble shoot mwd. Drlg. from 10681 to 10779. TVD 3772' ADT 3.7 ART 2.7 AST 1.0 PUW 125k SOW 50k RW 85k TQ on 9k off 9k Circ. condition mud to 9.4#-check for flow. Pump out of hole to 7684'. Check torque & drag. Mad pass from 7650 to 7550' to check mwd tool. Check for flow pump pill & poh. Stand back bha. Down load mwd. Lay down failed mpr tool-pick up standby mpr & directional collar. Program mwd. Make up bha-agitator-shock sub-xo-shallow pulse test mwd. RIH to 6914'. Change out worn lotad sub on stand #72. Pump ep lube csg. treatment pill @ 7300'. 80 spm @ 2000 psi. Service top drive-blocks & rig. RIH from 7300' to 10779-inspect lotads. Circ. & survey. Mad pass log from 10776 to 10525'. RIH to 10779'. Drlg. from 10779' to 11900'. TVD 3791' ADT 5.6 ART 4.2 AST 1.3 PUW 128k SOW 60k RW 90k TO on 9k off 8k WOB 2-10k RPM 80 SPM 70 GPM 250 PP 2060# SPR #2 20 spm 520# 30 spm 700#. Surveys continue to showing TVD's converging on lower lateral Pump hi vis weighted sweep & cbu. Pump out of hole @ drlg. rate fl wiper trip from 11900' to 11225'. Pump out from 10645 to 971 O'-set back hwdp. RI H from 9710' to 11900'. Circ. drop gyro & pump down same followed wi dry job. POH taking gyro shots to bha. Lay down bha #7 stand back swdp-jars & recover gyro from top of agitator. Lay down agitator-shock sub-csdp & break bit. (Gyro failed assignment. Down load mwd & clean floor. Lay down 2 part mwd & mud motor. Pull wear ring-install test plug-rig up for bope test. Test bope 250-5000# (witness test waived byaogcc.) Install wear ring & rilds. Make up bha #8-new mwd-program same-pulse test-install baffle 95' above bit. RIH to 5900'. RIH survey @ 7264' & 7357'. Service top drive & blocks. RIH surveys @ 7 446-7539-7636-7734-7830-7926-8491-8975-9458-9941-1 0425-1 0908- 11392-11836. CBU-circ. pull 1 stand per hr. to 11637'. Printed: 6/25/2003 11 :01 :40 AM .) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 4/24/2003 4/25/2003 4/26/2003 4/27/2003 4/28/2003 1 C-178 1 C-178 ROT - DRILLING n1334@ppco.com Doyon 141 Date Sub Frorn~"o · Hours Çod~ Code Phase 08:45 - 09:45 09:45 - 10:00 10:00 - 11 :00 11 :00 - 00:00 00:00 - 07:30 07:30 - 09:30 09:30 - 11 :00 11 :00 - 21 :00 21 :00 - 21 :45 21 :45 - 22:30 22:30 - 00:00 00:00 - 01 :00 01 :00 - 01 :45 01 :45 - 02:30 02:30 - 17:00 17:00 - 17:45 17:45 - 19:00 19:00 - 19:45 19:45 - 22:30 22:30 - 00:00 00:00 - 01 :00 01 :00 - 06:30 06:30 - 07:30 07:30 - 08:00 08:00 - 14:00 14:00 - 15:30 15:30 - 18:00 18:00 - 19:30 19:30 - 20:30 20:30 - 21 :00 21 :00 - 21 :30 21 :30 - 23:30 23:30 - 23:45 23:45 - 00:00 00:00 - 02:00 02:00 - 08:00 08:00 - 09:00 09:00 - 15:00 15:00 - 21 :30 21 :30 - 22:00 22:00 - 23:00 1.00 DRILL 0.25 DRILL 1.00 DRILL 13.00 DRILL TRI P PROD TRIP PROD CI RC PROD DRLH PROD 7.50 DRILL 2.00 DRILL 1.50 DRILL DRLH PROD TRI P PROD TRI P PROD 10.00 DRILL DRLH PROD 0.75 DRILL 0.75 DRILL 1.50 DRILL 1.00 DRILL 0.75 DRILL 0.75 DRILL 14.50 DRILL CIRC TRIP TRIP TRIP TRIP CIRC TRIP PROD PROD PROD PROD PROD PROD PROD 0.75 DRILL CIRC PROD 1.25 RIGMNT RSRV PROD 0.75 DRILL SURV 2.75 DRILL SURV 1.50 DRILL SURV 1.00 DRILL SURV 5.50 DRILL SURV 1.00 DRILL TRIP 0.50 DRI LL CI RC 6.00 DRILL TRIP 1.50 DRILL CIRC 2.50 DRILL TRIP 1.50 DRILL PULD 1.00 WINDOWPULD 0.50 WINDOWTRIP 0.50 WINDOWTRIP 2.00 WINDOWTRIP 0.25 WINDOWOTHR 0.25 WINDOWCIRC 2.00 WINDOWCIRC PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN 6.00 WINDOWTRIP CMPL TN 1.00 WINDOWPULD CMPL TN 6.00 CASE PULR CMPL TN 6.50 CASE RUNL CMPL TN 0.50 CASE OTHR CMPL TN 1.00 CASE OTHR CMPL TN Start: 4/4/2003 Rig Release: 5/1/2003 Rig Number: Spud Date: 4/2/2003 End: 5/1/2003 Group: POH from 11637' to 1 0960'. RIH wI hwdp to 11885'. Circ. hole. Drlg. horizontal hole L2 from 11900' to 12709'. (TVD 3799') AST .9 ART 4.8 ADT 5.7 PUW 140k SOW 54k RW 92k TQ 9.5k on 9koff WOB 2/5k SPM 72 RPM 90 GPM 257 PP 1700# SPR #2 20spm 510# 30 spm 660#. Drlg. horizontal hole L 1 from 12709' to 13110'. POH to 10969'-check for flow-stand back hwdp. RIH w/1 0 stands 4" dp-put 10 stands hwdp on top. (Trip to move hwdp back up hole for drilling wt.) Drlg. horizontal hole from 13110' to 13626'. TVD 3813' AST .5 ART 7.6 ADT 8.1 PUW 150k SOW 35k RW 92k TQ on 11 k off 11 k WOB 2/8k RPM 100 SPM 72 GPM 257 PP 1820 SPR #1 20 spm 660# 30 spm 800# 9.4 mw. Circ. for trip to stand back hwdp. Pump out @ drlg. rate from 13626' to 13089' (back ream) POH on elevators wI spiral wt. push pipe from 13089' to 12120'. RIH from 12120' to 13026'. Rotate & pump in hole from 13026' to 13626'. Circ. condition hole to poh taking surveys. Pump & rotate out to 11900'. Survey as from 11900' to 7380 as directed-wipe sidetrack from 9060' to 9040'. Pull thru window to 7300'. Pump weighted sweep & circ. to surface. Slip & cut 90' drlg. line-service top drive-blocks & inspect saver sub while evaluating surveys. Pump & displace E-P lube sweep into 7 5/8" csg. Orient hi-side & rih to 12766' on dp for E-Line gyro run. Circ. & reciprocate while hanging sheave & rigging up E-Line. PJSM PJSM-orient mwd & rig up to run gyro. Run gyro on sws E Line-pull same & rig down sws. RIH from 12776 to 13626'. Circ. bottoms up to shoe. Backream out of hole to 7300'. CBU X 2-monitor well-pump pill. POH to bha. Lay down bha #8-down load mwd. Pick up & make up whipstock retrieving tools. RIH 10 stands swdc,s. Pick up 15 jts. 4" hwdp-single in hole. RIH-SLM-no correction. Latch onto whipstock-shear @ 70k overpull. CBU. CBU after releasing whipstock. Spot EP lube pill-check for flow-pump dry job-drop dp drift. POH slow-hole swabbing-check for flow. Retrieve whipstock-lay down baker tools. PJSM-rig up & run 205 jts. 4.5" Solid & slotted liner as per program. Make up flanged hook hanger. RIH wI liner on dp. Engage hook hanger @ 7373' . PUW 138k SOW 71 k Prior to hooking hanger. Pump ball on seat-release running tool-blow ball @ 3950#. Printed: 6/25/2003 11 :01 :40 AM ) ) Legal Well Name: 1 C-178 Common Well Name: 1 C-178 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From,;, To Hours< .< Gode SÜb Code· 4/28/2003 23:00 - 00:00 1.00 CASE CIRC CMPL TN 4/29/2003 00:00 - 00:30 0.50 CASE CIRC CMPL TN 00:30 - 08:00 7.50 CMPL TN PULD CMPL TN 08:00 - 08:30 0.50 CMPL TN PULD CMPL TN 08:30 - 10:30 2.00 CMPLTN TRIP CMPL TN 10:30 - 12:00 1.50 CMPL TN PULD CMPL TN 12:00 - 14:00 2.00 CMPL TN PULD CMPL TN 14:00 - 14:45 0.75 CMPL TN TRIP CMPL TN 14:45 -16:15 1.50 CMPL TN PULD CMPL TN 16:15 - 16:30 0.25 CMPL TN NUND CMPL TN 16:30 - 17:30 1.00 CMPL TN RURD CMPL TN 17:30 - 17:45 0.25 CMPL TN SFTY CMPL TN 17:45 - 22:00 4.25 CMPL TN RUNT CMPL TN Start: 4/4/2003 Rig Release: 5/1/2003 Rig Number: Spud Date: 4/2/2003 End: 5/1/2003 Group: 22:00 - 23:00 1.00 CMPL TN RUNT CMPL TN 23:00 - 00:00 1.00 CMPL TN RUNT CMPL TN 4/30/2003 00:00 - 09:00 9.00 CMPL TN RUNT CMPL TN 09:00 - 09:30 0.50 CMPL TN RURD CMPL TN 09:30 - 10:00 0.50 CMPL TN PCKR CMPL TN 10:00 - 12:30 2.50 CMPL TN PCKR CMPL TN 12:30 - 13:00 0.50 RIGMNT RSRV CMPL TN 13:00 - 14:30 1.50 WAlTON EOI P CMPL TN 14:30 - 15:15 0.75 CMPL TN RURD CMPL TN 15:15 - 16:30 1.25 CMPL TN RURD CMPL TN 16:30 - 17:45 1.25 CMPLTN SUN CMPL TN 17:45 - 18:30 0.75 CMPL TN PCKR CMPL TN 18:30 - 21 :00 2.50 CMPL TN RUNT CMPL TN 21 :00 - 22:30 1.50 CMPL TN DEOT CMPL TN 22:30 - 23:30 1.00 CMPL TN NUND CMPL TN 23:30 - 00:00 0.50 CMPL TN NUND CMPL TN 5/1/2003 00:00 - 01 :00 1.00 CMPL TN NUND CMPL TN 01 :00 - 02:00 1.00 CMPL TN SEQT CMPL TN 02:00 - 03:00 1.00 CMPL TN DEOT CMPL TN 03:00 - 04:30 1.50 CMPL TN FRZP CMPL TN 04:30 - 05:30 1.00 CMPL TN FRZP CMPL TN 05:30 - 06:00 0.50 CMPL TN NUND CMPL TN 06:00 - 07:30 1.50 CMPL TN NUND CMPL TN Pump hi-vis spacer & displace well wi 9.4# brine @ 7330' wi 70 spm @ 800#. (NOTE) Liner 103 blanks 102 slotted 205 centralizers. Displace well to 9.4ppg brine - Monitor well - Static TOH - UD 62 stds Dp (+ 1 LoTAD sub/std) & UD 45 jts HWDP UD running tools ( Make all service breaks) TIH wi 67 stds DP out of derrick TOH - UD DP (UD 60 jts) Con't UD DP TIH wi 20 stds DP out of derrick TOH UD DP (+ 4 LoTAD subs) R/U & Pull wear bushing R/U to Run Completion - Tbg tools & Reel PJSM - Review 4.5" Jet Pump Tbg running detail & hazards Run 4.5" 12.6# L80 IBT Tbg completion - While running jt #22 severed guage control line after getting hung on rotary hose clamp. Debrief crew as to how this happened - Make ajustments in running procedure - Re-position control line derrick sheave. Splice Guage control line (Splice @ 6502' MD) Con't Run 4.5" Completion Con't running 4.5" 12.6# L80 IBTM completion wi TEC wire - Cannon clamp on each jt. Total of 237 clamps run. Rig up to Circulate. Up wt=83K, DWT =65K. Drop Baker Ball & Rod - Ball will not seat Circu & displace 400 bbls New 9.4 ppg brine - Returns clean (Ball still never seated) Service Rig & Top Drive Wait on Slick Line unit & HES Co- Clean Pits - Inject old brine P/U HES tools to Rig floor R/U HES -Pump in sub, BOP & Lubricator - 5 Min PJSM TIH wi slickline tools to push Ball & Rod to Bttm - On seat @ 7104' WLD - RID HES R/U fluid lines - Up wt 83K, Dn wt 64K - Set packer wi 2550 psi @ 7086' - Test tbg to 2700 psi for 10 min "OK" UD 2 jts Tbg - M/U Hanger wi Jt - M/U Landing Jt - Make TEC wire conn @ hanger - Test "OK" - Land Tbg - Top of PBR @ 7051 - Space out 5' above No Go Test annulus to 1500 psi - Hold 10 min per well plan ( pumped up in 500 psi increments holding each test 5 min. The final test 1500 psi was held 10 min) Test was charted. Install BPV - N/D BOPs Prep well head for tree N/U Tree - Test TEC wire "OK" Test Tree 250/5000 psi 5 min "OK" - Pull TWC Test Tbg to 2000 psi f/10 min - Test 7.625" X 4.5"Ann to 3000 psi f/10 min "OK" - Bleed pressure off Tbg and shear RP valve @3753' - Test Circu @ 2 BPM = 800 psi - Shut down Freeze protect well - Pump 120 bbls diesel down Annulus Put Tbg and Annulus in communication and let U-tube - This gives 2850' MD in Tbg & Ann. freeze protection - Base Permafrost @2198' MD Install BPV Install Actuator valve on tree - Secure Tree & install all blinds and guages wi niddle valves - Clean cellar area - 250 psi on Ann, 0 psi on Printed: 6/25/2003 11 :01 :40 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . Date 1 C-178 1 C-178 ROT - DRILLING n1334@ppco.com Doyon 141 . Hours Code .. .SÜb · . ..... .... ... · Code Start: 4/4/2003 Rig Release: 5/1/2003 Rig Number: Spud Date: 4/2/2003 End: 5/1/2003 Group: From.; To 5/1/2003 06:00 - 07:30 1.50 CMPL TN NUND CMPL TN Tbg *** Rig Release off 1C - 178 @ 0730 hrs 05/01/2003 **** Printed: 6/2512003 11 :01 :40 AM Well 1 C-178 Directional Survey Page 1 of 5 We1l1C-178 Directional Survey (API 500292314400) I!f ...----. .. _u. .._u Survey Type: Company: Survey Date: Survey Top: O'MD Survey Btm: 13,280' MD ~- ..-.........-. ...~.... ~ .. ...... ... .. . .........-- . . ~... n. ___._n _ ___ ~...._ MD TVD SS INCLINE AZIMUTH DOGLEG SURV _DY SURV _DX 0.00 0.00 87.20 0.00 0.00 0.0 0.0 0.0 110.00 110.00 -22.80 0.00 0.00 0.0 0.0 0.0 204.00 204.00 -116.80 0.64 42.75 0.7 0.4 0.4 297.00 297.00 -209.80 0.44 306.45 0.9 1.0 0.4 389.00 388.95 -301.75 3.02 258.54 3.0 0.7 -2.2 483.00 482.73 -395.53 4.73 259.52 1.8 -0.5 -8.5 571.00 570.35 -483.15 5.90 246.99 1.9 -2.9 -16.2 668.00 666.59 -579.39 8.39 247.99 2.6 -7.5 -27.4 759.00 756.29 -669.09 10.98 249.39 2.9 -13.1 -41. 6 851.00 846.45 -759.25 11.98 249.19 1.1 -19.5 -58.8 944.00 936.82 -849.62 15.29 248.62 3.6 -27.4 -79.2 1,036.00 1,024.32 -937.12 20.57 249.72 5.8 -37.5 -105.7 1,130.00 1,110.50 -1,023.30 26.41 255.42 6.7 -48.5 -141.4 --' 1,224.00 1,193.55 -1, 106.35 29.51 263.23 5.1 -56.5 -184.7 1,320.00 1,275.94 -1,188.74 32.25 266.52 3.4 -60.8 - 233.7 1 ,413.00 1,351.90 -1,264.70 38.17 269.94 6.7 -62.3 -287.3 1,505.00 1,420.64 -1,333.44 45.11 275.94 8.7 -59.0 -348.2 1,598.00 1,484.51 -1,397.31 48.14 279.13 4.1 -50.1 -415.2 1,692.00 1,545.07 -1,457.87 51.64 282.20 4.5 -36.7 -485.8 1,786.00 1,600.20 -1,513.00 56.53 285.16 5.8 -18.7 -559.8 1,879.00 1,646.30 -1,559.10 64.00 287.48 8.3 4.1 -637.2 1,973.00 1,685.99 -1,598.79 66.05 287.25 2.2 29.5 -718.5 2,066.00 1,723.63 -1,636.43 66.20 288.20 1.0 55.4 -799.5 2,159.00 1,760.93 -1,673.73 66.51 288.63 0.5 82.3 -880.3 https:/ /www.conocophillipsalaska.com/atdb/Survey _Rpt.asp?W ellN ame= 1 C-178 6/25/2003 6/25/2003 https:/ /www.conocophillipsalaska.comlatdb/Survey _Rpt.asp?W ellN ame= 1 C-178 Well 1 C-178 Directional Survey Page 2 of 5 2,251.00 1,798.60 -1 ,711.40 65.15 288.82 1.5 109.2 -959.8 2,345.00 1,837.82 -1,750.62 65.53 288.20 0.7 136.4 -1,040.8 2,438.00 1,875.41 -1,788.21 66.79 287.90 1.4 162.7 -1,121.7 2,531.00 1,912.64 -1,825.44 66.01 288.74 1.2 189.5 -1,202.6 2,627.00 1,951.82 -1,864.62 65.81 288.56 0.3 217.5 -1,285.6 2,732.00 1,994.33 -1,907.13 66.43 290.11 1.5 249.3 -1,376.2 2,827.00 2,032.17 -1,944.97 66.62 290.73 0.6 279.7 -1,457.9 2,914.00 2,066.62 -1,979.42 66.73 289.78 1.0 307.4 -1,532.9 3,005.00 2,103.02 -2,015.82 66.11 288.45 1.5 334.7 -1,611.6 3,098.00 2,140.10 -2,052.90 66.89 287.35 1.4 360.9 -1,692.8 3,191. 00 2,176.63 -2,089.43 66.85 286.24 1.1 385.6 -1,774.7 3,286.00 2,213.96 -2,126.76 66.88 285.13 1.1 409.2 -1,858.8 '"-" 3,380.00 2,250.95 -2,163.75 66.77 284.69 0.5 431.5 -1,942.3 3,475.00 2,288.44 -2,201.24 66.75 285.09 0.4 453.9 -2,026.7 3,566.00 2,324.39 -2,237.19 66.71 284.63 0.5 475.3 -2,107.5 3,662.00 2,362.30 -2,275.10 66.77 284.52 0.1 497.5 -2,192.8 3,755.00 2,398.97 -2,311.77 66.79 284.66 0.1 519.0 -2,275.5 3,849.00 2,436.02 -2,348.82 66.78 283.37 1.3 540.0 -2,359.3 3,942.00 2,472.73 -2,385.53 66.72 284.59 1.2 560.6 -2,442.3 4,036.00 2,509.40 -2,422.20 67.36 284.93 0.8 582.7 -2,525.9 4,130.00 2,545.72 -2,458.52 67.18 286.57 1.6 606.2 -2,609.4 4,223.00 2,581.82 -2,494.62 67.14 286.71 0.2 630.7 -2,691.5 4,316.00 2,617.97 -2,530.77 67.11 285.53 1.2 654.5 -2,773.8 4,409.00 2,653.99 -2,566.79 67.31 286.05 0.6 677.9 -2,856.3 4,503.00 2,690.30 -2,603.10 67.25 287.60 1.5 703.0 -2,939.3 4,596.00 2,726.40 -2,639.20 67.07 287.55 0.2 728.8 -3,021.0 4,690.00 2,762.86 -2,675.66 67.29 287.73 0.3 755.1 -3,103.6 -- 4,783.00 2,798.74 -2,711.54 67.32 288.04 0.3 781.4 -3,185.2 4,877.00 2,834.06 -2,746.86 68.55 291.47 3.6 810.9 -3,267.2 4,970.00 2,868.20 -2,781.00 68.38 292.90 1.4 843.6 -3,347.3 5,063.00 2,902.45 -2,815.25 68.40 291. 79 1.1 876.4 -3,427.3 5,157.00 2,937.10 -2,849.90 68.34 292.35 0.6 909.3 -3,508.3 5,249.00 2,971.01 -2,883.81 68.41 293.92 1.6 942.9 -3,586.9 5,345.00 3,006.37 -2,919.17 68.37 294.67 0.7 979.6 -3,668.3 5,438.00 3,040.62 -2,953.42 68.41 296.06 1.4 1,016.6 -3,746.4 5,531.00 3,074.91 -2,987.71 68.32 296.55 0.5 1,054.9 -3,823.9 5,625.00 3,109.54 -3,022.34 68.44 296.10 0.5 1,093.7 -3,902.2 6/25/2003 https://www.conocophillipsalaska.comlatdb/Survey _Rpt. asp ?WellName= 1 C-178 Well 1 C-178 Directional Survey Page 3 of 5 5,717.00 3,143.34 -3,056.14 68.45 294.60 1.5 1,130.3 -3,979.5 5,811.00 3,177.90 -3,090.70 68.41 294.01 0.6 1,166.3 -4,059.2 5,905.00 3,212.69 -3,125.49 68.14 293.54 0.6 1,201.5 -4, 139.1 5,998.00 3,247.17 -3,159.97 68.34 293.29 0.3 1,235.8 -4,218.4 6,092.00 3,281.78 -3,194.58 68.46 295.46 2.2 1,271.9 -4,298.0 6,186.00 3,315.67 -3,228.47 69.27 297.04 1.8 1,310.7 -4,376.6 6,279.00 3,348.34 -3,261.14 69.60 299.44 2.4 1,351.9 -4,453.3 6,372.00 3,380.79 -3,293.59 69.56 300.46 1.0 1,395.4 -4,528.8 6,465.00 3,413.19 -3,325.99 69.66 300.34 0.2 1,439.5 -4,604.0 6,559.00 3,445.89 -3,358.69 69.62 300.15 0.2 1,483.9 -4,680.1 6,652.00 3,478.25 -3,391.05 69.66 300.01 0.2 1,527.6 -4,755.6 6,745.00 3,510.64 -3,423.44 69.59 303.55 3.6 1,573.5 -4,829.7 .~ 6,839.00 3,542.88 -3,455.68 70.31 307.15 3.7 1,624.6 -4,901.7 6,933.00 3,574.24 -3,487.04 70.73 310.68 3.6 1,680.2 -4,970.6 7,026.00 3,605.18 -3,517.98 70.44 316.42 5.8 1,740.6 -5,034.2 7, 119.00 3,635.52 -3,548.32 71.52 323.15 6.9 1,807.7 -5,090.9 7,213.00 3,663.78 -3,576.58 73.52 329.87 7.1 1,882.5 -5,140.3 7,306.00 3,689.15 -3,601.95 74.83 334.53 5.0 1,961.6 -5,182.0 7,399.00 3,713.08 -3,625.88 75.36 338.68 4.4 2,044.1 -5,217.7 7,492.00 3,735.18 -3,647.98 77.16 342.31 4.3 2,129.2 -5,247.8 7,586.00 3,752.47 -3,665.27 81.64 343.98 5.1 2,217.6 -5,274.6 7,679.00 3,764.98 -3,677.78 82.90 345.17 1.9 2,306.4 -5,299.1 7,692.00 3,766.49 -3,679.29 83.77 344.82 7.2 2,318.9 -5,302.4 7,768.00 3,772.70 -3,685.50 86.86 347.09 5.0 2,392.4 -5,320.8 7,861.00 3,775.62 -3,688.42 89.54 350.03 4.3 2,483.5 -5,339.2 7,955.00 3,775.50 -3,688.30 90.61 351.14 1.6 2,576.2 -5,354.6 8,047.00 3,775.45 -3,688.25 89.45 349.25 2.4 2,666.8 -5,370.3 '-' 8,142.00 3,775.27 -3,688.07 90.77 349.98 1.6 2,760.3 -5,387.4 8,237.00 3,775.27 -3,688.07 89.23 349.48 1.7 2,853.8 -5,404.3 8,329.00 3,775.77 -3,688.57 90.15 349.75 1.0 2,944.2 -5,420.9 8,422.00 3,775.32 -3,688.12 90.40 349.93 0.3 3,035.8 -5,437.3 8,514.00 3,774.51 -3,687.31 90.61 349.46 0.6 3,126.3 -5,453.8 8,608.00 3,775.35 -3,688.15 88.37 350.09 2.5 3,218.8 -5,470.5 8,701.00 3,775.97 -3,688.77 90.86 349.51 2.8 3,310.3 -5,486.9 8,795.00 3,775.74 -3,688.54 89.42 349.22 1.6 3,402.7 -5,504.3 8,889.00 3,777.40 -3,690.20 88.56 347.79 1.8 3,494.8 -5,523.0 8,983.00 3,778.18 -3,690.98 90.49 348.81 2.3 3,586.8 -5,542.1 6/25/2003 https:/ /www.conocophillipsalaska.comlatdb/Survey _Rpt. asp ?W ellN ame= 1 C-178 Well 1 C-178 Directional Survey Page 4 of 5 9,075.00 3,778.89 -3,691.69 88.62 347.93 2.3 3,676.9 -5,560.6 9,169.00 3,781.18 -3,693.98 88.59 347.29 0.7 3,768.7 -5,580.8 9,263.00 3,782.62 -3,695.42 89.66 349.71 2.8 3,860.8 -5,599.5 9,356.00 3,783.02 -3,695.82 89.85 350.46 0.8 3,952.4 -5,615.5 9,449.00 3,783.77 -3,696.57 89.23 350.30 0.7 4,044.1 -5,631.1 9,543.00 3,785.66 -3,698.46 88.46 350.51 0.9 4,136.8 -5,646.7 9,636.00 3,787.71 -3,700.51 89.02 352.74 2.5 4,228.8 -5,660.3 9,730.00 3,789.07 -3,701.87 89.32 352.31 0.6 4,321.9 -5,672.5 9,824.00 3,790.15 -3,702.95 89.36 352.89 0.6 4,415.2 -5,684.6 9,918.00 3,792.67 -3,705.47 87.57 349.84 3.8 4,508.0 -5,698.7 10,010.00 3,795.73 -3,708.53 88.62 350.54 1.4 4,598.6 -5,714.4 10,1 04.00 3,797.82 -3,710.62 88.83 350.63 0.2 4,691.4 -5,729.8 "- 10,198.00 3,799.58 -3,712.38 89.02 349.77 0.9 4,784.0 -5,745.8 10,289.00 3,800.24 -3,713.04 90.15 350.59 1.5 4,873.6 -5,761.3 10,382.00 3,799.92 -3,712.72 90.25 349.32 1.4 4,965.2 -5,777.5 10,478.00 3,800.46 -3,713.26 89.11 350.87 2.0 5,059.8 -5,794.0 10,556.00 3,802.03 -3,714.83 88.59 351.32 0.9 5,136.8 -5,806.1 10,666.00 3,804.62 -3,717.42 88.71 351.43 0.2 5,245.5 -5,822.6 10,725.00 3,805.68 -3,718.48 89.23 350.61 1.7 5,303.8 -5,831.8 10,820.00 3,806.39 -3,719.19 89.91 349.52 1.4 5,397.4 -5,848.2 10,917.00 3,805.71 -3,718.51 90.89 347.34 2.5 5,492.4 -5,867.6 11 ,0 11. 00 3,803.92 -3,716.72 91.29 346.41 1.1 5,583.9 -5,889.0 11 , 111. 00 3,801.32 -3,714.12 91.69 345.83 0.7 5,681.0 -5,912.9 11,208.00 3,798.20 -3,711.00 92.00 346.67 0.9 5,775.1 -5,936.0 11,305.00 3,795.00 -3,707.80 91.78 348.40 1.8 5,869.8 -5,956.9 11,401.00 3,793.51 -3,706.31 90.00 349.27 2.1 5,964.0 -5,975.5 11,498.00 3,793.54 -3,706.34 89.97 348.62 0.7 6,059.2 -5,994.1 ---' 11,595.00 3,793.72 -3,706.52 89.82 349.68 1.1 6,154.4 -6,012.4 11,692.00 3,794.00 -3,706.80 89.85 351.04 1.4 6,250.1 -6,028.6 11,788.00 3,794.34 -3,707.14 89.75 351.47 0.5 6,344.9 -6,043.2 11,885.00 3,794.94 -3,707.74 89.54 351.69 0.3 6,440.9 -6,057.4 11,981.00 3,795.69 -3,708.49 89.57 353.29 1.7 6,536.1 -6,069.9 12,075.00 3,795.94 -3,708.74 90.12 353.42 0.6 6,629.4 -6,080.8 12,172.00 3,795.97 -3,708.77 89.85 353.22 0.4 6,725.8 -6,092.1 12,271.00 3,796.13 -3,708.93 89.97 351.39 1.9 6,823.9 -6,105.4 12,368.00 3,796.23 -3,709.03 89.91 352.33 1.0 6,919.9 -6,119.1 12,464.00 3,796.33 -3,709.13 89.97 350.10 2.3 7,014.8 -6,133.8 Well 1 C-178 Directional Survey Page 5 of 5 12,561.00 3,797.35 -3,710.15 88.83 347.49 2.9 7,109.9 -6,152.6 12,657.00 3,799.85 -3,712.65 88.19 349.21 1.9 7,203.9 -6,172.0 12,754.00 3,802.58 -3,715.38 88.59 348.93 0.5 7,299.1 -6,190.4 12,849.00 3,805.37 -3,718.17 88.04 349.55 0.9 7,392.4 -6,208.1 12,904.00 3,807.21 -3,720.01 88.13 349.13 0.8 7,446.4 -6,218.3 12,996.00 3,809.10 -3,721.90 89.51 348.82 1.5 7,536.7 -6,235.9 13,092.00 3,809.23 -3,722.03 90.34 349.39 1.1 7,630.9 -6,254.0 13,185.00 3,809.25 -3,722.05 89.63 350.12 1.1 7,722.5 -6,270.5 13,233.00 3,809.79 -3,722.59 89.08 349.01 2.6 7,769.7 -6,279.2 13,280.00 3,810.54 -3,723.34 89.08 349.01 0.0 7,815.8 -6,288.2 -...' ~ https://www.conocophillipsalaska.comJatdb/Survey _Rpt.asp?WellName=IC-178 6/25/2003 ) ) Transmittal Form r'.. BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie O\o'lJO ReferencY-Î \ -1 C-178 '(7- IlJ 00 \ 0- ~03'~~C-178L1 )0- 00 "''1~~ lC-178LlPBl \ ~OP t)UJ 1C-178L1PB2 J u IT=:::::==="::'~::::::"····------'_··-··_"·---_·_-·-·--_·_··_-''''''-·'c·-.-·----··--.-'--'~------==.c:;:;:.'::::::;==..:::::=--==:í Ii Contains the following material for each wellbore i II II listed above: ¡ II I Ii i III: 1 LDWG Compact Disc !Ii,! I (Includes Graphic Image files) Ii 1 LDWG lister summary Ii II ¡! II !I !! 1 blueline - MPR Measured Depth Log II II 1 blueline - MPR TVD Log II '¡!I Ii II ¡: II ¡I I I Ii ! 11 Ii ¡ Ii LAC Job#: 428169 PtLc-~. I ,y£ L :1 i '---·,,·----,------..--------'--::.=::::.0=_==::::::.:=----·····---~--- __-=.,-º_-==-~=c==.:::"=c::::=:::.=.:;=1 Sent By: Glen Horel Date: June 18, 2003 Received B;~.C\ '- ~ J\~:LX..Q_0-~1V\ Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 RECEIVED JUN 2 0 2003 Alaska OH &. Ga~ Cons. Commisaion Anchorage -_.'------~-----~-----_._- IJ;~~~,,~,·,'~·,~~"..~, J II/III¥Y"II ...."., ;,..,': '~:,. 1o.1~ ~,.... :,' ", 'u .. 11"0 ~.~:.__.._-;;¡---_.._-~~--_:~--_:=~~ :~,,,.;;-" "',",::' I",·.~.", ,..., \.I".'" ,,..- "'......... -,.,.,,..,.,..- :....:~~ ) Transmittal Form INTEQ To: AOGCC 333 West ih Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 3 -oL\\ lC-178-- ~,03 _'OL\~ lC-178Ll ðO <.. 3 ...é)L\.~ lC-178L1PBl9-0'3 -cA ð- lC-178LIPB2 €)-D ) "i BAKER HUGHES , ' , i) RtfIA1P~-JOO'iIOOII[lTATSCAJ~_j 1 ............."....-........,...... .".. ~'"'I .......... ..I '~,:O¡ .1'RI',' ; , ~ Anchorage GEOScience Center Contains the following material for each wellbore listed above: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - MPR Measured Depth Log 1 blueline - MPR TVD Log LAC Job#: 428169 Po..c.kCLr- ?- '1 2~ Sent By: Glen Borel Received B~"--~ lV'\~,"O 0'<9~ Date: June 18,2003 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 :~t1¿~¿{"'~~' f.i,<~ ~:: ~F:~. ¡~ ~ \! ~,.: ~"'~, Ë '\ :~""'" ~~j:? ì~.......,: ~ ,:,T 1J,.,;o" v~ J (') ., " "'. ' , IU¡I~\ .' (} "'I f\' ¡') v ,,-- '" 1_ -,' ·t '.... '\ ,<:~~ ; f;. "..>~~:rnfnL~~t;tO~;l :.:" . . '~~~',:\:.::$.:~ c________.__n____ _._ [Fwd: lC-178 (PTD# 203-04 1/203-042) Prod Test] ) ) Subject: [Fwd: 1C-178 (PTD# 203-04 1 /203-042) Prod Test] From: Tom Maunder <tom _maunder@admin.state.ak.us> Date: Tue, 03 Jun 2003 15:00:03 -0800 To: John D Hartz <jack_hartz@admin.state.ak.us>, Steve Davies <steve_davies@admin.state.ak.us>, Jane Williamson <Jane_ Williamson@admin.state.ak.us> All, Enclosed is a gas lifted flow test that ConocoPPCo did on one of their West Sak wells. Wàsn't without its problems, however they had a fairly good time period with over 1500 bopd. FYI. Tom Content-Type: message/rfc822 Content-Encoding: 7bit 1 of 1 3/29/2005 10:30 AM Re: 1 C-178 (PTD# 203-04 1 /203-042) Prod Test ) ) Subject: Re: 1 C-178 (PTD# 203-04 1 / 203-042) Prod Test From: "NSK Problem Well Supv" <n1617@conocophillips.com> Date: Tue, 3 Jun 2003 14:35:25 -0800 To: tom_maunder@admin.state.ak.us Tom - Below is the information from the initial testing on KRU Well 1C-178 (PTD# 2030410). Call with any questions. Thanks, Nina Woods Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 Forwarded by NSK Problem Well Supv/PPCO on 06/03/2003 02;32 PM ----- NSK Full Field Prod Engr 06/03/2003 02;30 PM To; NSK Problem Well Supv/PPCO@Phillips cc; Subject; Re; 1C-178 (PTD# 203-04 1 / 203-042) Prod Test(Document link: NSK Problem Well Supv) Nina, Attached is the raw data for the flow testing on 1C-178. The spreadsheet contains data from PTS, AccuFlo tests in Setcim and a trend also setup in Setcim. I created a graph showing the highest steady flowing period during the test that lasted about 14 hours. During this time we were pumping 0.25 bpm of hot diesel into the production line upstream of PTS which helped the gas break out and lowered our back pressure. I backed out the diesel volume on the graph but not in the raw data. The PTS data also has notes giving brief descriptions of events that occurred during the entire testing period, May 24th to June 1st. We are currently in the process of completing the flow line and instrumentation hook up, which will take about 4 day, and slickline will then remove the GLD and run the jet pump. Jet pump assisted production will then be started with no plans of using gas lift for production or testing in the future. (See attached file: 1C-178 PROD TEST.xls) Jason Brink / Peter Nezaticky ConocoPhillips Alaska Inc. Kuparuk Fullfield / West Sak Production Engineers ph : ( 907 ) 659 - 7061 fax: ( 90 7 ) 6 5 9 - 7 3 14 1 of 3 3/29/2005 10:30 AM Re: 1 C-178 (PTD# 203-04 1 /203-042) Prod Test ) ) Tom Maunder <tom maunde:r'@admin. state. ak. us> ........................_............................................................................................................................................................... 05/08/2003 04:29 PM To: NSK Problem Well Supv/PPCO@Phillips cc: Subject: Re: 1C-178 (PTD# 203-04 1 / 203-042) Hi MJ, In a meeting held at the tower, different lift scenarios were discussed. You are correct about the "less than 30 days". In this case the well is always a producer. Gas lift has been used on other WS wells when the ESP has become inoperable, although I think the production has been via the annulus. In this case you will be in a more conventional mode, although there is only one casing between the gas and the earth but that string is cemented. Your proposal to use gas lift in a test mode is acceptable. We would appreciate if you or your colleagues would share the test information when it is gathered and processed. Good luck. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom, Newly drilled, multilateral well, 1C-178 (PTD# 203-041 / 203-042) is currently permitted for service as a producer with a jet pump as the artificial lift method. With your concurrence we would like to bring the well on-line as a gas lifted producer for two test. The first test would be for three days starting May 12th ending -May 14th (before the drilling rig moves closer to the well). The purpose of this test is to clean up the well and obtain rate data to support the remainder of the drilling program. The second test would be for no more than 30 days (starting May 28th) . The purpose of the second test is to continue to clean up the well, a obtain a good baseline of well tests and formation water cut data before putting it in jet pump service, and testing the viability of lift gas as a sustained artificial lift method for future development wells. 2of3 3/29/2005 10:30 AM Re: 1 C-178 (PTD# 203-04 1 /203-042) Prod Test ) ) In similar service change situations (ie back flowing in injection well) that were less than 30 days in length 10-403/404's were not required. However, we can supply those documents if required in this particular situation. Attached is a schematic from the drilling plan that gives an approximate picture of the well bore. (See attached file: 1C-178 Completion.vB.pdf) Please let me know if you have any questions or would like more information. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 ------------------------------------------------------------------------ Name: 1C-178 Completion.vB.pdf 1C-178 Completion.vB.pdf Type: Acrobat (application/pdf) Encoding: base64 (See attached file: tom_maunder.vcf) .~~:....~.ç-~..?~.. (¡>'I'º~...~.º~.~º~...~..../.~O~:º~~)...¡>~()~ .':I'~~t'~I11I. ,'tom maunder.vcf 30f3 3/29/2005 10:30 AM ~~!Æ~E ~. ) F !Æ~!Æ~~~!Æ ) ~ FRANK H. MURKOWSKI, GOVERNOR ATfASK&OILAND GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE,SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 April 4, 2003 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, AK 99510 RE: Waiver ofH2S Measures for Kuparuk River Unit 1C-178 and 1C-178L1 ConocoPhillips (Alaska), Inc. Permit Numbers: 203-041 and 203-042 Dear Mr. Thomas: H2S measures specified in 20 AAC 25.065 (c) are waived for Kuparuk River Unit wells 1C-178 and 1C-178L1. This waiver is based a conversation between Steve Davies and ConocoPhillips' representative, Mr. Steve McKeever. During this conversation, Mr. McKeever indicated: 1. H2S measurements in offset wells KRU lC-123 and 1C-135 (232 and 228 ppm, respectively) reported in the Greater Kuparuk Area H2S State Report, dated January, 2003, were due entirely to H2S contained in the jet-pump power fluid supply, and 2. No H2S has been detected in produced fluids from the West Sak reservoir. All other terms and conditions of Permit to Drill Numbers 203-041 and 203-042 remain in effect. Sincerely, ¡<,"-.~ L,L~ ~ Sarah Palin Chair BY ORDER OF THE COMMISSION DATED this !!J: day of April, 2003 cc: Department ofFish and Game, Habitat Section Department of Environmental Conservation Exploration, Production and Refineries Section 1...'-1 / ..,---' ) !Æ~fÆ~~~~ ) ~ ~!Ar~E ~ -E rJ FRANK H. MURKOWSKI, GOVERNOR ALASKA. OIL AND GAS CONSERVAnONCO~SSION Randy Thomas Kuparuk Drilling T earn Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage AK 99510 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276·7542 Re: Kuparuk River Unit lC-178 ConocoPhillips (Alaska), Inc. Permit No: 203-041 Surface Location: 1503' FNL, 1195' FWL, Sec. 12, TIIN, RI0E, UM Bottomhole Location: 1481' FSL, 100' FWL, Sec. 35, TI2N, RI0E, 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 frOln obtaining additional permits or approvals required by law froln other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit n1ay 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 North Slope petroleum field inspector at 659-3607 (pager). s~nc~ JD(} ~ ~ahP~r ~~. Chair BY ORDER OF THE COMMISSION DATED thisJ1 day of March, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Exploration, Production and Refineries Section ConocÓPhillips Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com March 12, 2003 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, West Sak Producer, 1C-178 & 1C-178 L1 Dear Commissioners: ConocoPhillips Alaska, lnc. hereby applies for Permits to Drill for an onshore production well, a multilateral horizontal well in the West Sak "8" and "0" sands. The main bore of the well will be designated 1C-178, and the lateral bore of the well will be designated 1C-178L1 Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 1C-178 is April 7, 2003. If you have any questions or require any further information, please contact Steve McKeever at 265- 6826. Sincerely, \'~\~ Randy Thomas Greater Kuparuk Area Drilling Team Leader RECEIVED MAR 1 2 2003 ,NaskaOil&GasGons. CommiSßlon Anchorclg6 ]\1 . . \ \ ".' \ ,."~ 9. Approximate spud date April 7, 2003 14. Number of acres in property 2560 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 1339 psig At total depth (TVD) 1748 psig Setting Depth ) STATE OF ALASKA ) A~ASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well. Exploratory U Stratigraphic Test Service D Development Gas D Single Zone 5. Datum elevation (DF or KB) RKB = 87 feet AMSL 1a. Type of work: Drill ~ Redrill U Re-entry DDeepen D 2. Name of Operator ConocoPhillips Alaska, 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1503' FNL, 1195' FWL, Sec. 12, T11 N, R10E, UM At top of productive interval 773' FSL, 1181' FWL, Sec. 2, T11 N, R10E, UM At total depth. 1481' FSL, 100' FWL, Sec. 35, T12N, R10E, UM 12. Distance to nearest property line 13. Distance to nearest well 100' @ TD feet 1 C-04 35' @ 1100' 16. To be completed for deviated wells Kickoff depth: 300 MD 18. Casing program size U D 6. Prop~rty Designation.. ADL 25649 & 25638 ALK 467 & 463 7. Unit or property Name Kuparuk River Unit 8. Well number 1 C-178 feet Maximum hole angle 90° if tT?(,q, Development Oil ~ Multiple Zone D 10. Field and Pool Kuparuk River Field West Sak Oil Pool 11. Type Bond (see 20 AAC 25.0251) Statewide Number #59-52-180 Amount $200,000 15. Proposed dépth (MD and TVD) 13734 ' MD / 3806 ' TVD Hole Casing Weight 24" 16" 62.5# 9.875" 7.625" 29.7# 6.75" 4.5" 12.6# Specifications Grade Coupling H-40 Weld L-80 BTCM L-80 SLHT Length 110' 7719' 6350' Top Bottom Quantity of Cement MD TVD MD TVD (include stage data) 28' 28' 138' 138' 225 cf ArcticCrete 28' 28' 7747' 3768' 690 sx AS III L & 280 sx Class G 7384' 3711' 13734' 3806' Slotted liner - no cement 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: feet feet Plugs (measured) measured true vertical Effective Depth: feet feet Junk (measured) measured true vertical Casing Conductor Surface o Length Size Cemented Measured depth True Vertical depth Perforation depth: measured true vertical RECEIVED MAR 1l 2003 AlasuOil& GasGons.CClllillor' AncIIOI'8Ø8 20. Attachments Filing fee [2] Property Plat D BOP Sketch D Diverter Sketch D Drilling program [2] Drilling fluid program [2] Time vs depth plot Qefraction analysis D Seabed report D 20 AAC 25.050 requirements [2] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Steve McKeever 265-6826 Date ~~ I, ~ (0 :3 Prp.n::m~rl hv .C:;hamn AIIslln-nrakp. Signed '\<-..c~ \... ~ Title: Kuparuk Drilling Team Leader R. Thomas , Commission Use Only Permit Number Ù i' /1 I API number . I J I / I Approval date'i~, J /1 )1".'"2 2D3 - '-f 50- Ó 2//- 2 31 'f Y ,- ex::::> &')/ v - ) Conqitions of approval Samples required D Yes ~ No Mud log required - Hydrogen sulfide measures 00 Yes D No Directional survey required IX] Yes Required working pressure for BOPE D2M; D 3M; D 5M; D 10M; D D Other: ~SOÜ\>-$'~ ""\. ,~(,...,\,j \-'\. ~ \> ~è5~ OrIginal Signed By ~""-,:ah PaP.n by order of Approved by Commissioner the commission Form 10-401 Rev. 12/1/85- O J'r\'~"J1 1/ Ll i r¡i¡~L_ Isee cover letter for other requirements U Yes OCJ No D No r-) J I Date ~1 (l / tJ~::; Submit in triplicate ) Ar'~'~ation for Permit to Drill, We1l1C-178 I , Revision No.O ¡ Saved: 11-Mar-03 Permit It - West Sak Well #1 C-178 Application for Permit to Drill Document M~ximizE Well "Iolul; Table of Contents 1. Well Name.............. ..... .......... .......... ..... .............. ............................... ...... .................. 2 Requirements of 20 AAC 25.005 (f).............. ...................... ........................ ...... ...................................... 2 2. Location Sum mary ....................... ............ ............... ..... .......... ... ....... ........... ...... ....... 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. Dri II i ng Hazards Information...... ................................ .......... ............................. ...... 3 Requirements of 20 AAC 25.005 (c)( 4) ....................................................... ...................... ..................... 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program .............................................................................4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information.... .... .......... .... ... ....... ........ ........ .................... ..... .......... 4 Requirements of 20 AAC 25.005(c)(7) ...................................................................................................4 8. Dri II i ng FI u id Program .... ...... ....... ........ ............. ....... .............. ...... ... ......................... 5 Requirements of 20 AAC 25. 005( c)(B) ......... ............ ....... ........... ........................................ .............. ...... 5 Surface Hole Mud Program.................................................................................................................... 5 Lateral Mud Program................................................................................................................ .............. 5 9. Abnormally Pressured Formation Information ......................................................5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis.......................... ..................... ................... ............. ....................... 6 Requirements of 20 AAC 25.005 (c)(10) .......................... .............. .......................... ........................ ...... 6 11. Seabed Condition Analysis .....................................................................................6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 12. Evidence of Bondi ng ......... ... ............... .... ................ ... .... ...... .......... ....... ............... ... 6 OJ ."¡'~'i ,1 Ll 'j~;".. 1C-178 PERMIT IT. doc Page 1 of 8 Printed: 11-Mar-03 ) Ar""~ation for Permit to Drill, We1l1C-178 , Revision No.O j Saved: 11-Mar-03 Requirements of 20 AAC 25.005 (c)(12) ................... ............................ ............................... .................. 6 13. Proposed Drilling Program .....................................................................................6 Requirements of 20 AAC 25.005 (c)(13) ................................................................ ........................... ..... 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14) ..... ......................................................... .................................. 7 15. Attach ments .................. ........... ... ........... ............ ....... .............. ...... ........ ....... ... ...... ... 8 Attachment 1 Directional Plan ...................... ...... .......... ................................................. ............ ............8 Attachment 2 Diagrams of the BOP / Diverter System........................... Error! Bookmark not defined. Attachment 3 Drilling Hazards Summary..... ........ .......... ....................................... ..................... ........~.... 8 Attachment 4 Cement Loads and CemCADE Summary....................................................................... 8 Attachment 5 Well Schematic................................................................................................................ 8 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name des"ignated by the operator and a unique API number assigned by tile commi,,:<;ion under 20 AAC 25: 040(b). For a well with multiple well branGf¡e~~ each brandl must similarly be identitied by a unique name and API number by adding a suffix to ttle name designated for the well by the operator and to the number assigned to the well by the commis!J"'ÌofJ. The well for which this Application is submitted will be designated as lC-178. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An ðpplication for a Permit to Drill must be accompanied by each of the following Items, except for an Item already 017 flk? with the comml<ision and identified in the applicatìon: (2) a plat identifying the property and tile property~<; owners and showing (A}t/le coordinates of" the proposed location of" the well at the surface, at the top of eaä7 objective formation and at total depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenæd to the state plane coordinate system far this state as maintained by the National Geodetic Survey in the National Oceanìc and Atmospl7edc AdmÚ7istration; (C) the propos-ed depth of the well at the top of each objective formation and at total depth; Location at Surface NGS Coordinates Northings: 5,968,735 Eastings: 562,202 1503' FNL, 1195' FWL, Section 12, TllN, Rl0E, UM RKB Elevation 87.2' AMSL Pad Elevation 59.2' AMSL Location at Top of Productive Interval (West Sak "8" Sand) NGS Coordinates Northings: 5,970,969 773' FSL, 1181' FWL, Section 2, TllN, Rl0E, UM Eastings: 556,889 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 7647 3760 3673 Location at Total Depth NGS Coordinates Northings: 5,976,948 Eastings: 555,755 1481' FSL, 100' FWL, Section 35, T12N, Rl0E, UM Measured Depth, RKB: 13,734 Total Vertical Depth, RKB: 3,806 Total Vertical Depth, 55: 3,719 C : GI:'NA~ 1C-178 PERMIT IT. doc Page 2 of 8 Printed: 11-Mar-03 , , Ar~';'€, ation for Permit to Drill, We1l1C-178 , Revision No.O Saved: 11-Mar-03 and (0) other information required by 20 MC 25:050(b)/ Requirements of 20 AAC 25.050(b) .If a well is to be intentionally deviate~ tile application f'Or a Perrmt to Dnll (Form .10-4(1) must (1) indude a plal~ drawn to a suitable scale, showing the paUl of tile proposed wellbore, induding all adjaænt wellbores wilNn 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) k;t the names of the operators of those well~ to the extent that thO!:j'e names are known or dI:<;coverable in public recordr;" and -,,"'how that each named operatar has been fumi.s17ed a copy of ttle application by certified mall; or (8) state lllat the applicant is the only affected owner: The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application .for a Permit to Olill mU5-t be accompanied by each of the following items, exæpt fvr an item already on file wlt!l the commis-sio{) and Identified li7 the application: (3) a diagram and descri¡..Jtion of the blowout prevention equipment (BOPE) as required by 20 MC 25.035.- 20 MC 25.036, or 20 MC 25.03~ as applicable; An API 13-5/8" x 5,000 psi BOP stack will be utilized to drill and complete welllC-178. Please see information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit ta Drill must be accompanied by each of tile following items'", exæpt for an item already on file wIth the GvmmiS':.c,iofl and identf.fìed in t!le application: (4) infol1nalion on cflil/ing hazards¡ including (A) the maxtinum downhole pressure that may be encountere(~ cntetia used to determine it and maxtinum potentÙ¡1 slllf¿1ce pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the lC-178 area vary from 0.43 to 0.47 psi/ft, or 8.2 to 8.8 ppg EMW (equivalent mud weight). These are pressures are predicted based on actual well test data from the nearby West Sak wells. 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 1339 psi, calculated thusly: MPSP =(3720 ft)(0.47 - 0.11 psi/ft) = 1339 psi (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-presslJred strata, lost circulation zones, and zones that have a propensity for differential stic.*ing; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items¡ except for an item already on file with the commission and Identified in the application: (5) a description of the procedure for conducting formation integrity test'i¡ as required under 20 AAC 25. 030(f); O'--·'GI"'1 · IV ii_ 1C-178 PERMIT IT. doc Page 3 of 8 Printed: 11-Mar-03 ) A'-\cation for Permit to Drill, Well 1 C-178 , Revision No.O , Saved: 11-Mar-03 lC-178 will be completed with 7-5/8" surface casing landed in the West Sak B-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 Phillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An applicatio/7 for a Permit to Dnll must be accompanied by each of the fòllowing item~ except for an item already 0/7 file wIth the commission and Identified 1i7 the application: (6) a (."omplete propo,':>-ed casing and cementing program as required by 20 AAC 25:030" and a description of any slotted liner~ pre" perforated lineI'¡, or !:'''Creen to be installed; 4-1/2 6-3/4" slotted Lower Lateral (lC- 178) 6-3/4" Upper Lateral (lC-178 Ll) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application f'Or a Permit to Drill must be accompanied by each of the following ¡tem5~ exæpt for an item already on file with the evmmi5:.c,ion and identitìed in the applkôtion: (7) a diagram and description of the diverter system as required by 20 AAC 25.035; unles'S this requirement is waived by the commission under 20 AAC 25,035(h)(2); Casing and Cementing Program See also Attachment 3: Cement Summary Hole Size (in) 24 Top MDITVD (It) 28 / 28 Btm MDITVD (ft) 138 / 138 CsglTbg 00 (in) 16 Weight (Iblft) 62.5 Length (ft) 110 Grade H-40 Connection Welded 7-5/8 9-7/8 29.7 L-80 BTCM 28 / 28 7747 / 3768 7719 12.6 L-80 SLHT 7384/ 3711 13734 I 3806 6350 4-1/2 slotted 12.6 L-80 SLHT 7349/ 3702 13727 / 3747 6378 Cement Program Cemented to surface with 225 cf ArcticCRETE Cemented to Surface with 690 sx ASLite Lead, 280 sx Class G Tail Slotted- no cement Slotted- no cement A 21-1/4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of 1C-178. Please see diagrams of the Doyon 141 diverter system on file with the Commission. J 'jIG" ¡ .~..' ft " ~ ¡\jt'L- 1C-178 PERMIT IT. doc Page 4 of 8 Printed: 11-Mar-03 I )' k'4çation for Permit to Drill, Well 1 C-178 ) Revision No.O , Saved: 11-Mar-03 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Dnll must be accompanied by each of the f'ollowing item~ except for an item already on file with tlm commission and Identified in the application: (8) a drilling fluid program" including a diagram and description of the drilling fluid system" as required by 20 MC 25. 033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Initial Value Final Value 8.5 ~9.4 150-200 150-200 Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscostiy (/b1100 sf) 10 second Gel Strength (/b1100 sf) 10 minute' Gel Strength (lb1100 sf) pH API Filtrate(cc) Solids (%) Base of Permafrost to Total Depth Initial Value Final Value ~9.4* 9.6 150 65-75 30-60 30-60 20-40 18- 30 8-15 11- 22 12-30 12-24 10-30 10-25 10-25 10-25 25-55 25-55 20-40 20-40 8-9 8-9 8-9 8-9 8-15 <8 <8 <8 5-8 5-8 5-8 6-11 *9.6 ppg if hydrates are encountered Lateral Mud Program (60/0 KCI BARADRILn) BID sand laterals Initial Value Final Value 9.3 9.3 45-60 45-60 Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscostiy (lb1100 sf) Tau 0 Chlorides pH API filtrate **HTHP filtrate MBT ***Solids ppb 18-25 18-25 8-14 8-14 4-7 30-32K 8-8.5 <6 <10 <5 <15 4-7 30-32K 8-8.5 <6 <10 <5 <15 ** HTHP to be run at 80° F ...... The drilled LGS Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Dnll must be accompanied by each of the following items" except for an item already 0/7 file wIth the commission and Identified Ii] the application: C ;'G¡'NA.. 1C-178 PERMIT IT. doc Page 5 of 8 Printed: 11-Mar-03 ) A"""'Ìf. ation for Permit to Drill, We1l1C-178 , Revision No.O , Saved: 11-Mar-03 (9) for an exploratory or stratlgrapNc test well, a tabulatIon settIng out the depths of predicted abnormally geo'·pressured strata as requIred by 20 MC 2.5: 033(f)/ Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanIed by each of the following item5~ exæpt tÒr an Hem already on file wittl the c.:vmfTll5:t,ion and identitìed in the application: (lO) lor an exploratory or stratigraphic test well¡ a sel51rJic retractIon or reflection analY51's as required by 20 MC 25.061(a)/ Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An applk<:1tion for a PermIt to Dlill must be accompanIed by eaäl of the following Item~ exccy.?t for an item already on tile with the commission and Identlfled In the applicatIon: (11) for a we/I !iIi/led from an offshore platfi:mn mobile bottom-founded structUf"e/ jack-up r'Í..ct or floatIng dnlllng vessf.::1, an analysIs of seabed evnditions as required by 20AAC 2S.061(b}" Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An applicatlon for a Pennit to Dlilf must be ac.:t:ompanied by each of the fvllowing item~ except fvr an item already on t71e with the C'OmmÎb"Sion and identified In the applicatIon: (12) eVIdence showIng that the requIrements of 20 AAC 25.025 {8onding}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An applicatIon tor a Pelmlt to Drill must be accompanied by each of" the foflowÙ7g Item.~ except for an Item already on tHe with the commi'isio/7 and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 16" x 30" insulated conductor to +/- 138' RKB. Weld landing ring on conductor. 2. Move in / rig up Doyon Rig 141. Install 21-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 9-7/8" hole to casing point at +/- 7747' MD / 3768' TVD as per directional plan. Run MWD, LWD tools as required for directional monitoring and data gathering. 4. Run and cement 7-5/8", 29.7#, L-80, BTC Mod casing to surface. Displace cement with mud and perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's and test to 5000 psi (annular preventer to 3500 psi) Notify AOGCC 24 hrs before test. 6. PU 6-3/4" PDC Bit and 4-3/4" drilling assembly, with MWD, LWD, and annular pressure logging tools. RIH, clean out cement to top of float equipment, pressure test casing to 3500 psi, for 30 minutes and record results. 7. Drill out cement and between 20' and 50' of new hole. Perform FIT to 12.0 ppg EMW, recording results. (ECD's modeled to be less than 11.8 ppg) 8. Directionally drill 6-3/4" hole to TD at +/- 13,734' MD / 3,806' TVD as per directional plan. 9. POOH, back reaming out of lateral. RIH to TD and displace open hole to clean mud. POOH. 10. PU and run 4-1/2" Slotted Liner. 11. Land liner, set liner hanger @ +/- 7,384' MD / 3,7111. POOH. OlGINA~ 1C-178 PERMIT IT. doc Page 6 of 8 Printed: 11-Mar-03 ) A'··'\ifation for Permit to Drill, We1l1C-178 } Revision No.O Saved: 11-Mar-03 Note: Remaining operations are covered under the lC-178 Ll Application for Permit to Drill, and are provided here for information only. 12. Run and set Baker WindowMaster whipstock system, at window point of 7,349' MD / 3,702' TVD, just into the top of the D sa nd. 13. Displace wellbore to used Baradril'N fluid from the lower lateral. 14. Mill window. POOH. 15. Pick up 6-3/4" drilling assembly with LWD, MWD, and annular pressure logging tools. RIH. 16. Change over to clean BaraDril'N drilling mud. 17. Continue to directionally drill to TD of D sand lateral at 13,727' MD / 3,747' TVD. POOH. 18. POOH, back reaming out of lateral. RIH to TD and displace open hole to clean mud. POOH. 19. RIH with whipstock retrieval tool. Retrieve whipstock and POOH 20. PU and run 4-1/2" slotted Liner. 21. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 22. Release hanger running tool. POOH, laying down drill pipe as required. 23. Make up tubing tail and completion equipment as required and RIH to depth. 24. Drop RHC plug and pump down to nipple below packer. Pressure tubing and set packer. Shear seal assembly from PBR, space out and land tubing in well head 25. Install BPV, nipple down stack, nipple up and test tree to 5,000 psi. Pull BPV. Test tubing to 3,500 psi for 10 minutes, recording results. Holding 1000 psi pressure on tubing, pressure test annulus to 3000 psi for 10 minutes, recording results. Continue to pressure annulus up and shear RP shear valve in top gas lift mandrel. Freeze protect well with diesel by pumping into annulus, taking returns from tubing and allowing to equalize. 26. Set BPV and move rig off. 27. Rig up wire line unit. Pull BPV. Set dummy valve in place of RP shear valve in top mandrel. Perform MIT pressure tests of tubing and annulus (Tubing and annulus to 3500 psi). 28. Pull RHC plug from nipple below packer. Open CMU sliding sleeve. Set Weatherford jet pump in CMU profile. Rig down wire line unit. 29. Initiate production and clean up well to tanks. Freeze protect well and turn well over to production. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Dnll mustc be accompanied by each of the fol/owing item!J~ exCt'''f)t tor an item already on tìle wIth the commission and Identified in the application: (14) a general desaiption or how the operator plans to dispose o{ dnlling mud and cuttings and a statement of whether the operator intend'i to request authorization under 20 MC 25.080 for an annular disposal operation lì7 the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on lC 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 lC 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 used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska does not intend to request authorization for the use of this well for annular disposal operations. 1C-178 PERMIT IT. doc Page 7 of 8 Printed: 11-Mar-03 ... j~G ,~, l L '11, ,¡Vi·~' ) 15. Attachments Attachment 1 Directional Plan (14 pages) Attachment 2 Drilling Hazards Summary (1 page) Attachment 3 Cement Loads and CemCADE Summary (1 page) Attachment 4 Well Schematic (4 pages) 0: G I ~ fA I .. J~;,/J ¡ <li~_ Ar'~ation for Permit to Drill, We1l1C-178 , Revision No.O ! Saved: 11-Mar-03 1C-178 PERMIT IT. doc Page 8 of 8 Printed: 11-Mar-03 1 C-178 B lateral Grid Lat Long Page 1 of 5 ) ) ConocoPhillips Alaska, Inc. Pad lC 178 slot #178 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref Our ref License lC-178 B-Lat Vers#2.b prop5354 Date printed Date created Last revised 24 -Feb-2003 3-Dec-2002 24 -Feb-2003 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 30.391,w149 29 44.214 Slot Grid coordinates are N 5968735.160, E 562201.720 Slot local coordinates are 1502.88 S 1196.02 E proj ection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ",.R· r,G II ~. '1. ' \1 " I .. 1 ... ~." I~ ,.~ ,~¡ I V . - ) ) ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 1 Pad 1C,178 Your ref : 1C-178 B-Lat Vers#2.b Kuparuk River Unit,North Slope, Alaska Last revised : 24-Feb-2003 Measured Inclin Azimuth True Vert R E C TANGULAR G RID COORDS G E 0 GRAPHIC Depth Degrees Degrees Depth COO RDINATES Easting/ Northin;,/ COO RDINATES ,- 0.00 0.00 250.00 0.00 O.OON O.OOE 562201.72 5968735.16 n70 19 30.39 w149 29 44.21 300.00 0.00 250.00 300.00 O.OON O.OOE 562201.72 5968735.16 n70 19 30.39 w149 29 44.21 400.00 2.00 250.00 399.98 0.60S 1. 64W 562200.09 5968734.55 n70 19 30.39 w149 29 44.26 500.00 4.00 250.00 499.84 2.398 6.56W 562195.18 5968732.72 n70 19 30.37 w149 29 44.41 600.00 6.00 250.00 599.45 5.37S 14.75W 562187.02 5968729.67 n70 19 30.34 w149 29 44.64 700.00 8.00 250.00 698.70 9.54S 26.2 OW 562175.60 5968725.41 n70 19 30.30 w149 29 44.98 800.00 10.00 250.00 797.47 14.898 40.90W 562160.95 5968719.94 n70 19 30.25 w149 29 45.41 900.00 15.00 250.00 895.06 22.298 61. 23W 562140.68 5968712.38 n70 19 30.17 w149 29 46.00 1000.00 20.00 250.00 990.41 32.57S 89. 48W 562112.52 5968701.87 n70 19 30.07 w149 29 46.83 1066.67 24.00 250.00 1052.21 41.11S 112.94W 562089.13 5968693.14 n70 19 29.99 w149 29 47.51 1083.33 25.00 250.00 1067.37 43.47S 119.44W 562082.65 5968690.72 n70 19 29.96 w149 29 47.70 1100.00 25.65 251. 78 1082.44 45.8 OS 126.17W 562075.94 5968688.34 n70 19 29.94 w149 29 47.90 1200.00 29.93 260.84 1170.92 56.558 In. 4 OW 562030.81 5968677.22 n70 19 29.84 w149 29 49.22 1300.00 34.67 267.72 1255.46 61.66S 224.49W 561977.76 5968671.68 n70 19 29.79 w149 29 50.77 1400.00 39.73 273.08 1335.10 61.08S 284.88W 561917.37 5968671.78 n70 19 29.79 w149 29 52.53 1500.00 44.98 277.40 1409.00 54.808 351. 90W 561850.31 5968677.51 n70 19 29.85 w149 29 54.49 1600.00 50.36 280.98 1476.33 42 . 9 OS 424.81W 561777.32 5968688.81 n70 19 29.97 w149 29 56.61 1700.00 55.84 284.04 1536.35 25.51S 502.82W 561699.18 5968705.56 n70 19 30.14 w149 29 58.89 1800.00 61.39 286.72 1588.42 2.828 585.07W 561616.75 5968727.58 n70 19 30.36 w149 30 01. 29 1811.00 62.00 287.00 1593.64 O.OlS 594.34W 561607.46 5968730.31 n70 19 30.39 w149 30 01.56 1877.67 66.00 287.00 1622.85 17 . 5 ON 651. 62W 561550.04 5968747.36 n70 19 30.56 w149 30 03.23 2000.00 66.00 287.00 1672.61 50.18N 758.50W 561442.91 5968779.16 n70 19 30.89 w149 30 06.35 2197.64 66.00 287.00 1753.00 102.96N 931.16W 561269.84 5968830.54 n70 19 31. 40 w149 30 11.39 2500.00 66.00 287.00 1875.98 183.72N 1195.31W 561005.07 5968909.14 n70 19 32.20 w149 30 19.10 2770.49 66,00 287,00 1986.00 255.97N 1431.62W 560768.20 5968979.46 n70 19 32.91 w149 30 26.00 3000.00 66.00 287.00 2079.35 317.27N 1632.13W 560567.22 5969039.12 n70 19 33.51 w149 30 31. 85 3463.82 66.00 287.00 2268.00 441.15N 2037.33W 560161.07 5969159.69 n70 19 34.73 w149 30 43.68 3500.00 66.00 287.00 2282.72 450.82N 2068.94W 560129.38 5969169.10 n70 19 34.83 w149 30 44.60 4000.00 66.00 287.00 2486.09 584.36N 2505.75W 559691. 54 5969299.08 n70 19 36.14 w149 30 57.36 4500.00 66.00 287.00 2689.45 71 7 . 91N 2942.57W 559253.70 5969429.06 n70 19 37.45 w149 31 10.11 4775.94 66.00 287.00 2801.69 791. 61N 3183.64W 559012.06 5969500.79 n70 19 38.18 w149 31 17.15 4800.00 66.37 287.97 2811.40 798.23N 3204.63W 558991.01 5969507.23 n70 19 38.24 w149 31 17.76 4900.00 67.96 291. 95 2850.23 829.70N 3291.22W 558904.18 5969538.00 n70 19 38.55 w149 31 20.29 4926.65 68.40 293.00 2860.13 839 . 16N 3314.09W 558881.24 5969547.27 n70 19 38.64 w149 31 20.95 5000.00 68.40 293.00 2887.13 865.81N 3376. 86W 558818.26 5969573.41 n70 19 38.90 w149 31 22.79 5500.00 68.40 293.00 3071.20 1047.45N 3804.79W 558388.90 5969751. 55 n70 19 40.69 w149 31 35.28 5627.14 68.40 293.00 3118.00 1093.64N 3913.61W 558279.73 5969796.85 n70 19 41.14 w149 31 38.46 6000.00 68.40 293.00 3255.26 1229.10N 4232.72W 557959.55 5969929.69 n70 19 42.47 w149 31 47.78 6025.94 68.40 293.00 3264.81 1238.52N 4254.93W 557937.27 5969938.94 n70 19 42.57 w149 31 48.42 6058.10 69.67 293.21 3276.31 1250.31N 4282.55W 557909.56 5969950.50 n70 19 42.68 w149 31 49.23 6324.89 69.67 293.21 3369.00 1348.91N 4512.47W 557678.86 5970047.21 n70 19 43.65 w149 31 55.94 6352.50 69.67 293.21 3378.59 1359.11N 4536.26W 557654.99 5970057.22 n70 19 43.75 w149 31 56.64 6400.00 69.65 295.24 3395.10 1377.39N 4576.88W 557614.23 5970075.16 n70 19 43.93 w149 31 57.83 6465.88 69.67 298.05 3418.00 1405.08N 4632.09W 557558.81 5970102.41 n70 19 44.20 w149 31 59.44 6500.00 69.70 299.50 3429.85 1420.49N 4660.13W 557530.64 5970117.58 n70 19 44.35 w149 32 00.26 6600.00 69.84 303.76 3464.44 1469.69N 4740.00W 557450.39 5970166.12 n70 19 44.84 w149 32 02.59 6700.00 70.09 308.01 3498.72 1524.75N 4816.09W 557373.86 5970220.56 n70 19 45.38 w149 32 04.81 6800.00 70.44 312.25 3532.50 1585.40N 4888.03W 557301.43 5970280.62 n70 19 45.98 w149 32 06.91 6900.00 70.88 316.46 3565.63 1651.34N 4955.48W 557233.46 5970346.01 n70 19 46.62 w149 32 08.88 7000.00 71.42 320. 65 3597.95 1722.27N 5018.10W 557170.26 5970416.41 n70 19 47.32 w149 32 10.71 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #178 and TVD from RKB (Doyon 141) (87.00 Ft above mean sea level). Bottom hole distance is 10442.16 on azimuth 322.34 degrees from wellhead. Total Dogleg for wellpath is 141. 67 degrees. Vertical section is from wellhead on azimuth 291.09 degrees. Grid is alaska - Zone 4. 1 C-178 B lateral Grid Lat Long Page 2 of 5 J J H r: l ~~·1 J1' , " ,( '"I ".~~. . . .r111~i~. ~ ~r .~' ~_ ) ) Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 2 Pad 1C,178 Your ref : 1C-178 B-Lat Vers#2. b Kuparuk River Unit, North Slope, Alaska Last revised : 24-Feb-2003 Measured Inclin Azimuth True Vert R E C TANGULAR G RID COORDS G E 0 GRAPH I C Depth Degrees Degrees Depth COO RDINATES Easting Northing COO RDINAT E S 7025.37 71.58 321. 71 3606.00 1741. 01N 5033.19W 557155.03 5970435.03 n70 19 47.51 w149 32 11.15 7100.00 72.06 324.81 3629.29 1797.82N 5075.59W 557112.17 5970491. 49 n70 19 48.06 w149 32 12.39 7200.00 72.78 328. 93 3659.51 1877.63N 5127.67W 557059.44 5970570.87 n70 19 48.85 w149 32 13.91 7300.00 73.58 333.03 3688.46 1961. 32N 5174.09W 557012.35 5970654.17 n70 19 49.67 w149 32 15.27 7348.47 74.00 335.00 3701.99 2003.16N 5194.48W 556991.62 5970695.83 n70 19 50.08 w149 32 15.87 7348.49 74.00 335.00 3702.00 2003.17N 5194.49W 556991. 62 5970695.85 n70 19 50.08 w149 32 15.87 7351.00 74.00 335.00 3702.69 2005.36N 5195.51W 556990.58 5970698.03 n70 19 50.10 w149 32 15.90 7400.00 75.58 336.63 3715.55 2048.49N 5214.87W 556970.86 5970741. 00 n70 19 50.53 w149 32 16.46 7500.00 78.85 339.90 3737.68 2139.06N 5250.96W 556934.05 5970831. 26 n70 19 51.42 w149 32 17 .52 7528.72 79.79 340.83 3743.00 2165.64N 5260.44W 556924.35 5970857.76 n70 19 51. 68 w149 32 17.79 7600.00 82.15 343.10 3754.19 2232.57N 5282.23W 556902.02 5970924.51 n70 19 52.34 w149 32 18.43 7647.21 83.71 344.59 3760.00 2277.57N 5295.27W 556888.62 5970969.39 n70 19 52.78 w149 32 18.81 7700.00 85.47 346.24 3764.98 2328.43N 5308.50W 556874.98 5971020.14 n70 19 53.28 w149 32 19.20 7747.21 87.04 347.71 3768.06 2374.32N 5319.11W 556863.99 5971065.94 n70 19 53.73 w149 32 19.51 7800.00 88.81 349.36 3769.97 2426.02N 5329.60W 556853.09 5971117.55 n70 19 54.24 w149 32 19.82 7817.81 89.40 349.91 3770.25 2443.54N 5332.80W 556849.74 5971135.03 n70 19 54.41 w149 32 19.91 7900.00 89.40 349.91 3771.11 2524.45N 5347.20W 556834.69 5971215.82 n70 19 55.21 w149 32 20.33 8000.00 89.40 349.91 3772 .16 2622.90N 5364.72W 556816.37 5971314.11 n70 19 56.18 w149 32 20.85 8100.00 89.40 349.91 3773.21 2721. 35N 5382.24W 556798.05 5971412.41 n70 19 57.15 w149 32 21.36 8200.00 89.40 349.91 3774.26 2819. 8 ON 5399.76W 556779.74 5971510.70 n70 19 58.11 w149 32 21.87 8300.00 89.40 349.91 3775.31 2918.25N 5417.28W 556761.42 5971608.99 n70 19 59.08 w149 32 22.38 8400.00 89.40 349.91 3776.36 3016.69N 5434.80W 556743.10 5971707.28 n70 20 00.05 w149 32 22.90 8500.00 89.40 349.91 3777.41 3115.14N 5452.32W 556724.78 5971805.58 n70 20 01.02 w149 32 23.41 8600.00 89.40 349.91 3778.46 3213.59N 5469.84W 556706.46 5971903.87 n70 20 01.99 w149 32 23.92 8700.00 89.40 349.91 3779.52 3312.04N 5487.36W 556688.15 5972002.16 n70 20 02.95 w149 32 24.44 8800.00 89.40 349.91 3780.57 3410.48N 5504.88W 556669.83 5972100.45 n70 20 03.92 w149 32 24.95 8900.00 89.40 349.91 3781. 62 3508.93N 5522.40W 556651. 51 5972198.75 n70 20 04.89 w149 32 25.46 9000.00 89.40 349.91 3782.68 3607.38N 5539.92W 556633.19 5972297.04 n70 20 05.86 w149 32 25.98 9100.00 89.39 349.91 3783.74 3705.83N 5557.44W 556614.87 5972395.33 n70 20 06.83 w149 32 26.49 9200.00 89.39 349.91 3784.79 3804.27N 5574.96W 556596.55 5972493.62 n70 20 07.79 w149 32 27.00 9300.00 89.39 349.91 3785.85 3902.72N 5592.49W 556578.23 5972591. 92 n70 20 08.76 w149 32 27.52 9400.00 89.39 349.91 3786.91 4001.17N 5610.01W 556559.91 5972690.21 n70 20 09.73 w149 32 28.03 9500.00 89.39 349.91 3787.97 4099.61N 5627.53W 556541. 59 5972788.50 n70 20 10.70 w149 32 28.54 9600.00 89.39 349.91 3789.03 4198.06N 5645.05W 556523.27 5972886.79 n70 20 11.67 w149 32 29.06 9700.00 89.39 349.91 3790.09 4296.51N 5662.58W 556504.95 5972985.08 n70 20 12.63 w149 32 29.57 9800.00 89.39 349,91 3791.15 4394.96N 5680.10W 556486.62 5973083.38 n70 20 13.60 w149 32 30.09 9900.00 89.39 349.91 3792.21 4493.40N 5697.62W 556468.30 5973181. 67 n70 20 14.57 w149 32 30.60 10000.00 89.39 349.91 3793.27 4591. 85N 5715.15W 556449.98 5973279.96 n70 20 15.54 w149 32 31.11 10100.00 89.39 349.91 3794.34 4690.30N 5732.67W 556431. 66 5973378.25 n70 20 16.51 w149 32 31. 63 10200.00 89.39 349.91 3795.40 4788.74N 5750.19W 556413.34 5973476.54 n70 20 17.48 w149 32 32.14 10256.40 89.39 349.91 3796.00 4844.27N 5760.08W 556403.00 5973531. 98 n70 20 18.02 w149 32 32.43 10256.42 89.39 349.91 3796.00 4844.29N 5760.08W 556403.00 5973532.00 n70 20 18.02 w149 32 32.43 10272.54 89.83 349.70 3796.11 4860.15N 5762.94W 556400.02 5973547.84 n70 20 18.18 w149 32 32.51 10500.00 89.83 349.70 3796.79 5083.95N 5803.59W 556357.54 5973771. 27 n70 20 20.38 w149 32 33.70 11000.00 89.83 349.70 3798.29 5575.89N 5892.97W 556264.18 5974262.43 n70 20 25.22 w149 32 36.32 11500.00 89.83 349.70 3799.78 6067.84N 5982.35W 556170.82 5974753.58 n70 20 30.05 w149 32 38.94 12000.00 89.83 349.70 3801.28 6559.78N 6071.73W 556077.45 5975244.74 n70 20 34.89 w149 32 41.56 12500.00 89.83 349.70 3802.77 7051.73N 6161. lOW 555984.09 5975735.89 n70 20 39.73 w149 32 44.18 12575.42 89.83 349.70 3803.00 7125.93N 6174.58W 555970.00 5975809.98 n70 20 40.46 w149 32 44.58 12575.44 89.83 349.70 3803.00 7125.95N 6174.59W 555970.00 5975810.00 n70 20 40.46 w149 32 44.58 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot 11178 and TVD from RKB (Doyon 141) (87.00 Ft above mean sea level). Bottom hole distance is 10442.16 on azimuth 322.34 degrees from wellhead. Total Dogleg for wellpath is 141.67 degrees. Vertical section is from wellhead on azimuth 291.09 degrees. 1 C-178 B lateral Grid Lat Long Page 3 of5 ... f1~ I " ! ~.ff l' I I ~" ': " I 'j II'í ~,~ 'I ¡J .,' J ¡ ,tM! ) ') Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ConocoPhillips Alaska, Inc. Pad 1C,178 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref: 1C-178 B-Lat Vers#2.b Last revised : 24-Feb-2003 Measured Inclin Azimuth True Vert R E C TAN G U L A R Depth Degrees Degrees Depth COO R DIN ATE S GRID COORDS Easting Northing GEOGRAPHIC COORDINATES 12577.79 89.85 349.77 3803.01 7128.27N 6175.01W 555969.56 5975812.31 n70 20 40.48 w149 32 44.59 13000.00 89.85 349.77 3804.11 7543.76N 6249.99W 555891. 21 5976227.14 n70 20 44.57 w149 32 46.79 13500.00 89.85 349.77 3805.42 8035.81N 6338.79W 555798.42 5976718.41 n70 20 49.41 w149 32 49.40 13734.09 89.85 349.77 3806.03 \¡/ 8266.18N 6380.36W 555754.98 59769~741 n70 20 51.67 w149 32 50.62 l .../ All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #178 and TVD from RKB (Doyon 141) (87.00 Ft above mean sea level). Bottom hole distance is 10442.16 on azimuth 322.34 degrees from wellhead. 1 C-178 B lateral Grid Lat Long Page 4 of5 I i Grr"~·1 i ..'j J' ,; \',,1 ,',~j.: " 9 If j ~ l','r,œ IIIØ ) ) Total Dogleg for wellpath is 141.67 degrees. Vertical section is from wellhead on azimuth 291.09 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ConocoPhillips Alaska, Inc. Pad 1C,178 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 4 Your ref 1C-178 B-Lat Vers#2.b Last revised : 24-Feb-2003 Comments in wellpath ===================== MD TVD Rectangular Coords. Comment - -- - - - - -- - - - -- - - - - - -- ---- - - - - --- - --- - --- ---- - -- - - - - -- - - - --- --- - --- - ---- - --- - - - -- - - - - --- - - - - -- - - -- - - - -- - - - -- 300.00 300.00 O.OON O.OOE KOP 800.00 797.47 14.89S 40.90W Build 5/100 1000.00 990.41 32.57S 89.48W Build 6/100 1083.33 1067.37 43.47S 119.44W Build/Turn 1877.67 1622.85 17.50N 651.62W EOC 2197.64 1753.00 102.96N 931.16W Base Permafrost 2770.49 1986.00 255.97N 1431.62W Top T-3 3463.82 2268.00 441.15N 2037.33W Top K-15 4775.94 2801. 69 791.61N 3183.64W Build/Turn 4926.65 2860.13 839.16N 3314.09W EOC 5627.14 3118.00 1093.64N 3913.61W Top Ugnu C 6025.94 3264.81 1238.52N 4254.93W Build 6058.10 3276.31 1250.31N 4282.55W EOC 6324.89 3369.00 1348.91N 4512.47W Top Ugnu B 6352.50 3378.59 1359.11N 4536.26W Beg. Final Bld/Turn 6465.88 3418.00 1405.08N 4632.09W Top Ugnu A 7025.37 3606.00 1741.01N 5033.19W K-13 7348.47 3701. 99 2003.16N 5194.48W EOC-Top W Sak D 7348.49 3702.00 2003.17N 5194.49W 1C-178 Top D Sand Tgt 7351. 00 3702.69 2005.36N 5195.51W Build/Turn 7528.72 3743.00 2165.64N 5260.44W Top West Sak C 7647.21 3760.00 2277.57N 5295.27W Top West Sak B 7747.21 3768.06 2374.32N 5319.11W 7 5/8" Casing Pt. 7817.81 3770.25 2443.54N 5332.80W EOC 10256.40 3796.00 4844.27N 5760.08W Build 10256.42 3796.00 4844.29N 5760.08W WS W7 B-MDPT TGT 03 DEC 02 10272.54 3796.11 4860.15N 5762.94W EOC 12575.42 3803.00 7125.93N 6174.58W Build 12575.44 3803.00 7125.95N 6174.59W WS W7 B-5000 TGT 03 DEC 02 12577.79 3803.01 7128.27N 6175.01W EOC 13734.09 3806.03 8266.18N 6380.36W TD - Casing Pt. Targets associated with this wellpath ::;:;;;==================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised - -- - - - - -- - - - -- - - - - -- - - - --- - - - - - - - - -- - - - - -- - ---- - - - - --- - - -- - - - --- - - --- - - -- -- ---- - - - - - -- - -- -- - - -- -- - -- -- - - --- 1C-178 Top D Sand Tg WS W7 B-MDPT TGT 03 556403.000,5973532.000,0.0000 WS W7 B-5000 TGT 03 555970.000,5975810.000,0.0000 WS W7 B-TOE RVSD 03 555677.000,5977361.000,0.0000 WS W7 B-HEEL RVSD 03 556890.000,5970895.000,0.0000 3702.00 3796.00 3803.00 3807.00 3768.00 2003.17N 4844.29N 7125.95N 8679.43N 2203.16N 5194.49W 5760.08W 6174.59W 6455.00W 5294.49W 11-Sep-2002 3-Dec-2002 3-Dec-2002 8-Jan-2001 8-Jan-2001 1 C-178 B lateral Grid Lat Long Page 5 of 5 II JIG ¡ ~ ,f iI " l' liV/\L ~ C ::t::J -- ~ -- < ~ r-- ".-.... +- Q) Q) '+- '--" _C +- 0... Q) o o o :..-= L Q) > Q) :::¡ L l- I V C'ea:ec by omichcel For: S McKeever fJate p'otted: 25-Feb-2003 P,ol ~cfcrcrcc :5 1C-178 8-Let Vers#2.b. Cocrdi~otes are ir. feet referepce s'ol #~ 7B. Verticcl Dep~rs ore reference R'(B (Doyon 141). 5:= UIo."SI HUGHES INTEQ o i ¡Estimated RKB KOP ! 2.00 /.,00 6,00 8.00 Elev: 87' -150 DLS: 2,00 deg Der í 00 ft 900 - Build 5/100 ,5.00 Buile 6/100 242~~938uild/Turn 39,73 50.36 6 1..39 EOC ~ 350 DLS: 6.00 deg per 100 ft ,800 - /750- TANGENT ANGLE 66 DEG 7700 - 3150 - .3600 - 1.050 - - - -------.---.--.------r 1.50 450 900 1350 Base Permafrost Top T-3 1800 ConocoPhillips Alaska, Inc. Structure : Pad 1 C Well: 178 Field: Kuparuk River Unit Location: North Slope, 291.09 AZIMUTH 8927' (TO B-LATERAL TD) xxxPJane of Proposa!**~ Top K-15 Bui'd/Turn 66.37 Erv' G ~0 . ,(fv \"\ v <Q xl> "\O<~ ,;}.òG \)0,0~,0rY- v ~ o x.. ° "\ o<~ eo" \)0,0 <Q "\oc:¿ !Q':J !Q~' a~ 10' ~'1- 1'" ':J'b 1':J' 2250 2700 3150 3600 4050 4500 4950 5400 \\. 00 " ß~ òßo, ç 00 1><- c-:. \)\/ {::> +-" \) S°'ic ~ G <Q «\._ "\0,\ v,0 \. SO~o'l-\"o, ,-OG:'"ò\ ~e~e"'\. GO'" v<Qv' R ~\'ò "\o"\o~ ':Ji(...0G 5850 6300 Vertical Section (feet) -> Azimuth 291.09 with reference 0.00 N, 0.00 E from slot #178 <Q0\tOG 6750 7200 ConocoPhillirs 7650 8100 0~ÒO(; 0~ . 8550 --- .~ «'-' .,,0, G<:Y' "\\) ii78Î 9000 9450 ) )- ,') ConocoPhillips Alaska, Inc. r'c~~:;;l~d"bŸ"'b'~¡~~','~'~i"'''F~'~';''''S''''M'~K'~'~;'~~"'¡ i Oat, pl,tt,d : 25-F,b-2003 ' Plot fi~((mmc:" i:J 1 C-178 B-Lot VtJr:.l#')"b. i CoordInates 01"0 In teet rotcl"ClncCl :¡Iot #176, I, ()' I Truo Vertical Dopth, arc ~i;ca RKB Doyon 141 .! ; ~I!:::::;:: ; , KUCI'I~S ' ,.",,,,...~~:.?,,,,.,,,,,,,.,,.,...,,,,,,,..,,,,,.,,,,,,,,..,,,,,i 8000 7500 7000 1.,____,_1._ l [3- Lot TD Location: J 1482' rSI." 1 00' FWL _~~~_~]~~!2-~~.~_~..~~. TO - Casing 6500 6000 I .,.__..L_'-_.__.L__1..__.I -- Casing Pl. EOÇ 7 5/8 Casing r t. "'I' Tap West Sak B \ lòp West Sgk C . l3uild¡lurn to EOC-'Top W Sok D K-13.. Structure : Pad 1 C Well : 178 Field : Kuparuk River Unit Location: North Slope, <- West (feet) 5500 5000 4500 4000 J500 JOOO I ___L____L.,...L,.,.__L___L_. I D-- Lot TO Location: 14·90' FSI_, 150' FWL SEC, 35, T12N, I~ 1 DE EOD Begin Drop EOC KOP-End Milled Hole Bose Whipstock Face Top Whipstock Face Top' Ugnu A * Beg, Final Bid/Turn Top Ugnu rt """. EOC , Build ¿_ Top Ugnu C [) 3 EOC 4< .. . Build/Turn ~- ~ IG IN,4L ~ I Conccè'Phillips 2500 2000 1500 1000 500 291.09 AZIMUTH 8927' (TO B-LAT TD) '''Plane of Proposal'" , ~, 1'\ ® i';i~~ TRUE ,(Os'- ..Top r< -; 5 ,\,:J ",0 ':)8 <;> <;Je( {\ () ç ~ A· 2 ..,\0 se I'\\-}¡\()\()() r <;)0 r,(, ,~ò 'Ö "J .. ~~~'0"~~~ ~o<;J ~ ?1. '2,t;)u [ SUR:-^CELÖÚTlO,~-:---: 150.3' !,",'J~, '",95' ,WL ! _~~.'_~_"'_~~.:".'__ ~~~r:, 500 9000 - 8500 - 8000 - 7500 - 7000 6500 - 6000 - 5500 - 5000 ^ I - 4-500 Z 0 :¡. - ~OOO :J ,.-..., -+. CD - J500 CD -I- '-" - .3000 - 2500 - 2000 - 1500 - 1000 - 500 - 0 - ~()C Jaker Hughes Incorporatt:J Anticollision Report (?oinpäny: .. F'iel (J : . ~efë~enceSi~e: . Refer:¢nce·WelI: .... . Re'eìence"'elIpath~ ConocôphiUlpsAlaska, Inc; ··Kuparuk River LJÖiL .. paq1 C . 1:78 . .. ·1C,.178BLätVers#2.b , , . ". .:"':". ."... .:.'... . ... .... :.. :... ...... .:.". :". .. :..:' . . CQ-ord¡~ªtt!(NE)·J1efer~Jiëe: Ve..tica)(TVJ)lbf~I'~~ëe.: NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 100.00 ft Depth Range: 0.00 to 13734.09 ft Maximum Radius: 10000.00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 12/31/2002 Validated: No Planned From To Survey ft ft 0.00 13734.09 Planned: 1C-178 BLat Vers #2. Version: 5 Toolcode Tool Name MWD+SAG+IFR MWD+SAG+IFR (AK) Casing Points MD ft 7348.49 13734,09 TVD· ft 3702.00 3806.03 J.)iaÍt1eter in 9.625 7.000 Hole Size in 12.250 8.500 95/8" 7" Summary <'";.;-'-----~-:-~;.;--'"-.-,.~-.. Offset Wë)lp:¡th· ,--;.;--------~-:-,..'";;,-..-> Reference Offset Ctr,Ctr 'No,.Go AlloWable Site. . ........ .. . Well .... ..... . WellpattJ MD MD . . Distance Area Deviation . Warning ft ft ft ft ft Pad 1 C 01 1 C-01 V2 390.28 400.00 272.98 7.40 265.58 Pass: Major Risk Pad 1 C 02 1 C-02 VO 590.50 600.00 163.65 10.76 152.90 Pass: Major Risk Pad 1 C 03 1 C-03 VO 799.51 800.00 77.60 14.85 62.82 Pass: Major Risk Pad 1 C 04 1 C-04 VO 1107.92 1100.00 35.08 22.21 12.99 Pass: Major Risk Pad 1C 05 1 C-05 VO 1330.50 1300.00 122.62 28.63 94.47 Pass: Major Risk Pad 1 C 06 1 C-06 VO 936.19 900.00 314.05 18.11 296.05 Pass: Major Risk Pad 1 C 07 1 C-07 VO 1796.05 1500.00 433.78 47.33 387.11 Pass: Major Risk Pad 1 C 08 1 C-08 VO 1828.53 1600.00 269.00 47.55 221.57 Pass: Major Risk Pad 1 C 09 1 C-09 VO 1890.27 1600.00 110.44 59.70 52.04 Pass: Major Risk Pad 1 C 10 1C-10 VO 1534.43 1400.00 221.33 36.19 187.21 Pass: Major Risk Pad 1 C 102 1C-102 V5 2396.46 1900.00 263.18 97.15 175.88 Pass: Major Risk Pad 1 C 102 1C-102L 1 V3 2396.46 1900.00 263.18 97.15 175.88 Pass: Major Risk Pad 1 C 104 1C-104 VO 6804.91 6300.00 100.00 81.04 52.79 Pass: Minor 1/200 Pad 1C 104 1C-104L 1 V1 6804.91 6300.00 100.00 81.04 52.79 Pass: Minor 1/200 Pad 1C 104 1C-104PB1 VO 6804.91 6300.00 100.00 81.04 52.79 Pass: Minor 1/200 Pad 1C 109 1C-109 VO 1877.50 1600.00 276.30 56.60 221.54 Pass: Major Risk Pad 1C 109 1C-109L 1 VO 1877.50 1600.00 276.30 56.60 221.54 Pass: Major Risk Pad 1C 111 1 C-111 VO 2593.05 2200.00 170.52 121.47 90.00 Pass: Major Risk Pad 1 C 11 1C-11 VO 1688.24 1300.00 615.29 44.89 572.36 Pass: Major Risk Pad 1 C 113 1C-113 VO Plan: 1C-113 1.00 1.00 446.42 No Offset Errors Pad 1 C 115 1C-115 VO Plan: 1C-115 1.00 1.00 422.63 No Offset Errors Pad 1 C 117 1C-117 VO 2016,58 1800.00 120.78 72.06 49.68 Pass: Major Risk Pad 1 C 119 1C-119 VO 2329.32 2000.00 306.15 104.45 217.52 Pass: Major Risk Pad 1 C 121 1C-121 VO 1632.43 1400.00 320.69 50.27 282.65 Pass: Major Risk Pad 1 C 12 1C-12 VO 1524.12 1500.00 422.70 44.31 379.32 Pass: Major Risk Pad 1 C 123 1C-123 VO 1563.36 1400.00 279.51 44.87 241.78 Pass: Major Risk Pad 1C 125 1C-125 VO 284.98 300.00 320.19 5.73 314.46 Pass: Major Risk Pad 1 C 127 1C-127 VO 1232.44 1100.00 318.82 31.51 293.64 Pass: Major Risk Pad 1 C 131 1C-131 VO 1295.69 1200.00 295.45 32.84 267.41 Pass: Major Risk Pad 1 C 13 1C-13 VO 1471.14 1400.00 187.06 33.65 153.54 Pass: Major Risk Pad 1 C 133 1C-133 VO 1255.65 1200.00 183.51 28.49 156.69 Pass: Major Risk Pad 1 C 135 1C-135 VO 192.98 200.00 268.78 3.83 264.95 Pass: Major Risk Pad 1 C 14 1C-14 VO 581.38 600.00 36.83 12.50 24.40 Pass: Major Risk Pad 1C 15 1C-15 VO 481 .17 500.00 133.67 9.51 124.16 Pass: Major Risk Pad 1 C 16 1C-16 VO 975.56 1000.00 231 .42 24.02 207.48 Pass: Major Risk Pad 1C 17 1C-17 VO 2267.39 1700.00 425.16 86.13 351.11 Pass: Major Risk Pad 1 C 172 1C-172 Vers#1.b VO Pia 802.54 800.00 113.35 15.54 97.83 Pass: Major Risk Pad 1 C 174 1C-174 Vers#2 V12 Plan 299.98 300.00 81.78 6.43 75.35 Pass: Major Risk Pad 1 C 178 1C-178 0 Lat Vers# 2.b 13733.49 13727.20 77.04 528.58 -291.89 FAIL: Major Risk Pad 1 C 18 1C-18 VO 1214.21 1200.00 84.91 24.85 60.45 Pass: Major Risk Pad 1 C 190 1C-190Vers#8 V4 Plan: 300.00 300.00 240.35 6.22 234.12 Pass: Major Risk Pad 1 C 19 1 C-D(19) Vers#O.a VO P 299.00 300.00 199.95 6.37 193.58 Pass: Major Risk Pad 1 C 22 1 C-22 VO Plan: 1 C-22 V 300.00 300.00 160.59 6.45 154.14 Pass: Major Risk Pad 1 C 23 1 C-23A V2 488.80 500.00 175,70 9.52 166.18 Pass: Major Risk j"'" ,..--., I G .t ;!~ r . 11 J ø' 11 n , , '~iÍVhL Jaker Hughes Incorporatt;J Anticollision Report Cømpany: GonocqPhillips .Âlaska,lnc. . Field: .. Kuparu~ River lJnit Refèrence Site: .. . .. '... . Päd1 C Ref¢renc~ Well': .... 178 . .. . Ref~nmce Wt\llpath: 1C~178 BLåtvefs#2!b 2/24/2003 · , ; . ",".." .. ",.. .. ...... . .. .' ..,. .. . Well:J78, Tru$North YV~lIh~(;1~(87') ~!~O < Reference' Offset ·Ctr;'Ctr No':'Go Allowable Site 1\1D 1\:1D Distance .. Area" . Deviation." '. ft. .. ft ft ft ft .. ... Pad 1 C 23 1C-23PB1 VO 488.80 500.00 175.70 9.52 166.18 Pass: Major Risk Pad 1 C 24 1C-24 VO 295.99 300.00 190.76 6.84 183.92 Pass: Major Risk Pad 1 C 25 1 C-25 VO 390.15 400.00 229.77 7.50 222.27 Pass: Major Risk Pad 1 C 26 1C-26 V2 292.00 300.00 244.92 5.77 239.15 Pass: Major Risk Pad 1 C 27 1 C-27 V1 389.28 400.00 264.74 7.63 257.14 Pass: Major Risk Pad 1C b (PB) 1 C-PB Vers#O.a VO Plan 397.08 400.00 80.29 8.26 72.06 Pass: Major Risk Pad 1 C c (B) 1C-B Vers#1b V4 Plan: 398.99 400.00 40.65 8.27 32.40 Pass: Major Risk Pad 1 C f (IB) 1 C-IB Vers#1.a VO Plan 396.12 400.00 121.36 8.24 113.15 Pass: Major Risk Pad 1 C WS-1 WS1 VO 10777.22 3800.00 733.98 262.27 474.30 Pass: Major Risk Pad 1 C WS-24 WS-24 VO Out of range J j,.f\ L"jAL 1'1 i l1l it. '~j · ~ - - 240 1900 B - - 200 1700 ~ 160 120 _<\0- .£<'0' \/" ¿À'/.J 0 8300 - ~300 /-900 /1100 40 ...8 " 700 ~ _ 300 <0 _Y _ _ - 700500 .. 5QO"'/\/"- _ 900 ''~,3ÓO __ ,/" 700 _.,-5ÔO &,000 ~300 - 80 ~ -+. CD ~ '----'" ^ I z o :::¡ ::J - 40 8300 " 900 - 80 @ .- 120 - 160 .- 200 - 240 - 280 -'iiD- //& /// 0),,-, 80 40 40 ConocoPhillics I I ~~ " 1300 /í.300 1 3g-@-~300 --~..-- sèJ300 700 " ;~aBO " 900 " 900 " 1100 " 1100 " 1300 / / //7/1100 80 ß300 ...500 /~ 300 / / ..900 j __,.>100 / pOO /x' d ~OO & ø L.Ycy ~@/ / / /900 ~ ,,"Í 1 00...,9'60 ~ 1309"-// ,/ , ,,~\,líÔO 1100 _1,9_02-':;;i~~''''-::':::=- _ _ _ _ _ _ _ _ _ _ ~1~~0_ _ _ __ -, ,-",~oo ..-~5000 ,~,-,HÒO __' ~ 300 __.--700 '1~ ~ 300 ,¥ / , ...-"700 e 300 f900 " /..-500 ç000 , ...-900 /' ..-5ð0 , ./700 / /700 -- ",.-900 ~ 1100 ,..,a--í,§(J(T 1700 ~3Ø0700 : 'BOO + 700 .'5Ó~00 ,..'";1-"_ ,/"-f~80 - - - 2 500 '" "'>.. - , ';;500 ¡i7OQ 2900 ' 190CY' ,'0 " ~ ...'700 -$-3'QQ 300,,,/ " 1100 é 300 ~--5'0d-, @300",~ H88 ',:" \~ 500 -$- 3Q.'?L 5 0 0 '" 2300 '8300 ~ 900 / ..'900 . 1';300 ,/ ¡900 ~ 2100 \ 700 -è-300 ~ 1700 . 1500 -'" 31 00 ", \ 900 ~ 1500 ~ 1 100\>,"', ','0 ' )IÇl2300 1100i '@ 120 200 280 400 480 320 360 440 160 240 <- West (feet) Field : Kuparuk River Unit Location: North Slope. Structure Pad 1 C Well : 178 ConocoPhillips Alaska, Inc. 0S~r'13ÓO ,- _I'--,-ß 1'100 .- .-.-.... ..9ÓÕ , 2 í 00 .-_ ----',- 1300 .... 1100 \ 700 8300 \ AooG .. 500 ~.7fJÓ/ 8300 '.900 " @fD ~30Q., 3300", _,,)470t] 'Y -a- /\ 4100 ... ßBOO ..50Ó \ 1300 '- \~ I ~~~5)' 'Ó' -~i~~ & ~\,1500 --~;O 520 600 560 í 300 2300 1100 '1500- --11... 900 "',~.1 100 ..-. 700 900 ". 1100 640 160 720 680 ~ " '0". , " 0f'(J' " Vertical Dcptt1s ere reference RKß (Doyon :ä~ BAJŒR ~ INTEl.! Coord:notcs ere in fecl reference siot 1178. C'ealed by bm'chael For: S McKeever Dete p'ctteo : 25-Feb-2003 Plol Reference is j C-178 B-Lct Vers#2.b. cD CD] 2500 1300 0:&. 0JJ.. ~ 2 ~OO ~ C) \/.1100 800 840 ~~--._~ -" ~~ ~~~ "~~ 1-"~ r--- t;':) -....- C ::0 C) =tJ ---. .. ("7>"-":>. ....: ~.J ~-"',"-.., ""'-- "Z -"&,---..:-"0.--=:::"'"';1 ~.... ~~ r--- ,680 0lf- 0JJJ <IIi] CrcolCC by bmichocl For: S ~{CKeever Dole p'olled : 25-Feb-2003 P:ot Reference is :C-i78 B-La~ Versj2.o. Cccroinates ere î., feet referen.ce 510'.: 617ô. True Ver.::col Oe;>~"'s ore refere"'ce Ri<B (Doyon ~g~ HUGHl!!S I NTH) 1640 1600 1520 lLBO 1560 - - ~ ¿'ODD , .2400 , , , , " '"..2300 ! 1800 1440 ~, fITg¡, ~ i '<!J W " -,-¡ m~ ~ ~ 1400 ", , '" 3600, " " 1800 . 3700 ConocoPhillips Alaska, Inc. Structure : Pad 1 C Well : 178 Field: Kuparuk River Unit Location: North Slope, --~.~---------_._-_._-------_.. <- West (feet) 1350 1200 1080 1000 1040 1150 1120 1320 1280 12LO ~"o I -' "', o ' '2 '''", QJ-_____ <0 --__,2600 ' ". -"'_" 1 700 , '" '~o -.....~~.. '" , , -" " -", '" - - -._1 ~OO - ::::,,~7~0 - - ____ ',-800 " --'--------____,f200 '" .,"-----. '.,1600 ------->--~,1 00 ----------- .----. -----L~_900 " -- 1900 ~----- ConocóPhillijJs 950 750 920 880 840 800 ~'" '-- " -" \~~_5_~0 \ 1400 --"-..._~:~JO' ", 2300 ------~';~~~::;'~-,-"-'-CÐ~ 360 ", I 320 " 1300 ~~ i ¡- 280 I ~ \,1200 L 240 1500 '", ", \\ 1100 '", 1 400 " " ,~ 1000 " '" , " 1300 '" " ~- - _ _ __ _ __ _ _ _~:~~2~~~: 80 -- - <Î7à'_ ~. 40 '-,,-_~500 -, , --- --4.1 800 '--.,.__:~ 400 -------17_90-- ___1.~~_~_ -----C@¡ [ 80 440 - 400 ,,~ - 200 ^ I z o ~ :J 150 120 ".--.... - CD CD -+- "--' ~ I- 0 I I r- 40 C ::t:J ~ ~~ ~!' ...~ ~-:-..~-, '--":..a f:.1"--CÕI!L :.:.~~ ¡,f<-- 5800 5600 I------.J.__I~___L__l~ I -' -' 0> a> ®®: l'il s 'V Created by bmichael For: S McKeever Dote plctted : 25-Feb-2003 Pto~ Refere~ce;s 1C-'I78 8-Lot VersH2.b. Coord;no'tes orc in feet reference slot fI~ 78. Vertical Depths ere refere"'1ce RKB (!Joyon ~='Yfj HUGMK I NTÞ:O 5400 5:;>0 0 4800 5000 Q), \ \ \ \ \ \ \ '. 3700 \ \ \ \ , , , , , , ""',"- ..·3S·00 ".. 3500 , . 5900 , ',,,5700 / / ~. ConocoPhillips Alaska, Inc. 4600 4400 4200 r0 "0'. 3900 .".'" 3700 ".... ?500 '''. 5500 , "'4.5300 3300 ........:3100 ~ ~ .<ßOO 3900 .....,. '" ,.3~00 3300 Structure: Pad 1 C Well: 178 Field : Kuparuk River Unit Location: North Slope, 4000 " ',¥,~~~O ·,.....?100 ".. '" ~900 ·--·-..~..?900 ~ ~....3~íOO 3100 " ~ 5500 \. 2500\. 2300 I- . '''', '-. 2900 . I' " ~. 5300\ '\.2900 r- í 600 "",2700 ¥ 2900 , ",,' " . 230G, I ···....(~?OO ...." 51QO'<::2> i . >7,.,.-,,4500 " '. '. --' ~ í 400 ....~. UIJ...... "'.... 2500 '~,2300 '<~2900 ¥ 2~_ ""'''' 4300 ¥ 2700,. '., ····..<:?5Q9 ' '.... 4 700 ~I "<::::>,~ 1 CO , ":". 0 i í 200 ··<::::::':;':?}'?..~.~90;"'''' ~300"" \\ "''¥.~5~00 t '__.. " "¥, 2100" \.1.90 76' ~ íOOO '''''''<:::':37'&fi'' . 2~00 " , I ". ~:':;'~0;;g0_"'",j~=:' f 800 '<··,.,~3ao-·"·~·.2?0?\ 1 OO~ ··"':::·,-..;,;ù":~o - - -....Z30C ',,,,~9CtJ 3'5Qo..:2~'9 8 p'....., ~' .~.' ". '0 701 400 l222t... 4' 00 ··-........~þoo --~....2100 : "" ?,;e ........:31.9_0...2900 - ~ - ~ - L,. ~-..r>"o· 0> -_ 200 -·--.......f.700 . ,,,:J:'.2. '_..f500 ~ 3700 '7& 1900 ···..·..¥f~~go,....~ 0 ~::/ ~ __h ...,.1J~ ~ r.o i L 200 <- West (feet) 3800 3600 I é I uQ¿;; 2800 2600 3400 3200 3000 I ~ 33QD. . .......... ¥ 3300/ /' ~ " -...,:r:00 ".".6300 . 29'~Ô~~», 6100 '.......3100 J' 3500 / " " 3100 >.,:900 /3700 ./3700 ~ ' :: ......,: ~ ~ ~ ~900 - - -._27°0 - - -__2.?OC 2900 2700 --- 2500 2300 ---~-- -. [2J &!J l- 0i10COPhillips 2400 2200 2000 1800 1600 í400 1200 1 , Q \Z, 2700 ~ \, 3700 ~ 3300 \,,,\3500 . 270.0 \. 2500 270~~>:900 " '-. " 31,90 "\ "".,,5700 \ '~ 3300 ¥ 2500 \\ 3100 "- 2100 - 2400 ~ - 2200 - 2000 - í800 ^ I z o J.. ::::J ,--.... -+-. CD CD -I- '--"" -- :"'ë~'~'~t~d"'b;"b';¡~h~'~'1 .. "F'~~';'''s'''iï~K'~'~~~'~''1 Dato plottad : 25-F'ob-2003 j Plot I~(tðrðnce is 1C'-178 !3-'Lat Vore~2.b. I ¡ Coordinolf:lt'l Qrd in reelt rflhtrancc IlIot 11178. 1 ¡True Vertical Depths ore reference RKß (Doyon 141).J I INT¡';Q ,,! 8800 8400 8000 7600 l___L..__l._ _L_l..__L_.--L.......L._,_L-,.L--L,...l_.....L.--.L___.L.,__l....._L__L_.1 IT2±] ) ") ConocoPhillips Alaska, Inc. Structure: Pad 1 C Well: 178 Field: Kuparuk River Unit Location: North Slope, <- West (feet) 1200 6800 6400 6000 5600 5200 4800 I _L_¡___,L__.J.__.L._I ~[illJ \ , \ , \ \ \ \ \ \ \ .~ \ \ \ \ \ \ \ \ \ \ , , \ \ \ , \ \ \ , \ \ , , 'I' \ \ , \ , \ \ \ \ \ \ \ \ \ , \ \ , \ 4400 4000 CI2:{. 6600 \. 6300 \ 6000 "'II 5700 \<:>400 \\~1 00 \<,800 I~I,·.U 9600 "'b900 ~, 500 6~~'~ \ u 1,,6600 \ ,6300 \ '..,6000 '. '.,5700 \ " ..,3600 ~.,. ~ O "'i (""1' ~f Al 1i~ hd¡~t [jJ] , '. 3900 ". ,3600 "",3300 '. 5400 3300 ~ ,~:':~:X~, ConocoPhillips 3600 3200 2800 2400 2000 L---.J---L_..,_.J_,.L.__ 8800 2700 - 8000 - 7600 - 7200 - 6800 -, 6~00 · 6000 6900 -- 5600 6600 6300 6000 - 4800 - 8400 · 5200 ^ I z o ::¡ :::J \ \~:oo \\:200 \\~,:oc \",\3600 \\\~300 " 3300 \,,\3000 _ 2800 ,,3600 . -'600 ~ 3600 [j]J '" 6~0~000 \. . "'.. <0 - 2400 3300 . ". 6300 ~ .. 33.0~( ",' 6000 1.><. - ~- 1.:- 2700,&, 0 - 2000 3000 ~Xð> · ~ï ï 1600 ~- L ~ 200 '. "",/~,~p,.~,6.00 '*.2100 , ... 300G...48:bO "'.. 2700 ", Q) ", r.~1 ~ r» tJ\)~ ~ ,.--.... -h CD CD -+ "--" - 4000 - 3600 · 3200 ) ConocoPhillips Alaska, Inc. ië;~~t~d¡;;¡;;~;~~;~¡;I'F~~';'SM'~ï{~~~~~! I Dol. plottod : 25-Fob-·2003 , I. ' ¡Plot Rt'!forenco IS 1C-178 ß-Lot Vors#'2..b. CoordinotCl:J ore irl feel rehm:nce ~Iot # 178. True VertIcal Depths are reference RKB (Doyon 141).: ft'ííii~ . 5f.1iv"Lt' INTI;O ..,..................."............,....,...."......... ".,......, Structure: Pad 1 C Well: 178 ConocoPhillips Field: Kuparuk River Unit Location: North Slope, Alaska .........-.......... ~,6 /fØioo ""1 350 ,34\0 " TRU[ NORTH ~ß; 'L 1- ~ 4ì _ 1-3:] ØSJ '>7"~ 0 * 15010 Cù """"" ØJ <9 / ~@" ............ .......... ............ '"''''''''''''""'", "Cù @ "4Ö'"'' ,," 20 330 1,/' , /// í§Y' .", "3'20 .- :::,j:9:;;2';~:{~~t . ..... . 3~ ~. 1 240 "'//1500 I'" 1",/ "''- 0....: .', 1230 '-,- ~u'., ...,,600 *,,' g,bo,<, "< 300 220 ''-',,-, \ '''''300' fì>-:... ' / ~, /' "'f~!e? '* 1200 30 50 <Y 60 290 ''', ",/~ .X/ '_"tH.1 i3.) \/\ ". ,,' ~'(I,~I 80 270 90 260 100 210 '''''-, 200',-, ~90 ~ "8 '" 02110 'ii ' 6WV ""'I~':'~ 0 3 *..-.~ T90 ...,,:SO ",' 0300 1 ;¿.o'fif) 460-' , \ \ ..../ "" .~S;cj' .4'1 "'.~:tJcJ.:)b4)Ü"j... ,oo'rr .."~,~"~< 156o:'~ 1 5 0 ~. ~'.-3¿[~~~ ?<o "'-1,,60 @J t!.0 '<ö "... 1500 .~ 250 " ' '0. '~'<í>- ~ \0'"'0 180 170 ~o:i:lcl ¡::;;cne Trove'iiiìg Cy!!ilder F-eet All depths shown ore MeosL.;red oeoHls on Re{erence Well ~J IrG f...~..! ~L ~ :'1 .. J i :;~ I '.J J ') ) lC-178 Drillinq Hazards Summarï (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 9-7/8" Open Hole / 7-5/8" Casina Interval Hazard Broach of Conductor Gas Hydrates Running Sands and Gravels Abnormal Reservoir Pressure Lost circulation Hole swabbing on trips Risk Level Low Low Moderate Low Low Moderate Mitigation Strategy Monitor cellar continuously during interval. Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Diverter drills, increased mud weight. Reduced pump rates, mud rheology, LCM Trip speeds, Proper hole filling (use of trip sheets), pumping out 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Abnormal Reservoir Pressure Stuck Pi pe Lost Circulation Hole Swabbing on Trips Risk Level Low Low Low Moderate I Mitiqation Strategy Stripping drills, Shut-in drills, Increased mud weiqht. Good hole cleaning, PWD Tools, Hole Opener, Decreased mud weiqht Reduced pump rates, Mud rheoloqy, LCM Trip speeds, Proper hole filling (use of trip sheets), Pumpinq out O f""· .. , '....." .,' .'''', r d ' ì '" , r ", ~ ¡,pi' J' G' ) J \J l'":j h. 1C-178 Drilling Hazards Summary. doc prepared by Steve McKeever 3/10/20032:58 PM Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 3/3/2003 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com ) 8ChI."PII' ··.···..·.·..::·.·...I~·.~.·æ~tÆ:mF······..~·~~:lii~:.i:M~¡ry··...9·q.~.·..:..~·.~$i·g!~.···i.:·.i·.·.·..i· ::.····:..:.:··:;·i.....·:.:øi9Vªr.ª.~r~ªþ~.~ª~ir)~!·· ... Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 6,700' MD. Lead Slurry Minimum pump time: 240 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.28 ft3/sk < Toe at Surface 3 0.9513 ft 1ft x (110') x 1.00 (no excess) = 0.2148ft31ft x (2075' -110') x 3.50 (250% excess) = 0.2148 ft31ft x (6700' - 2075') x 1.35 (35% excess) = 104.6 ft3 + 1477.3 ft3+ 1341.2ft3 = 2923.1 ft3 I 4.28 ft3/sk = Round up to 690 sks 104.6 ft3 1477.3 ft3 1341.2ft3 2923.1 ft3 683 s ks Have 180 sks of additional Lead on location fQr Top Out stage, if necessary. Previous esg. < 16",62.6# casing at 110' MD Tail Slurry Minimum pump time: 160 min. (pump. time plus 90 min.) 15.8 ppg Class G + 0.5%S1, 0.2%046, 0.3%D65, 0.4%D167 - 1.17 ft3/sk 0.2148 ft31ft x (7747' - 6700') x 1.35 (35% excess) = 0.2578 ft31ft x 80' (Shoe Joint) = 303.6 ft3 + 20.6 ft3 = 324.2 ft31 1.17 ft3/sk = Round up to 280 sks 303.6 ft3 20.6 ft3 324.2 ft3 277.1 sks < Base of Permafrost at 2,075' MD (1,703' TVD) BHST = 84°F, Estimated BHCT = 82°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 3 50 16.7 16.7 < Top of Tail at MudPUSH XL 6 50 8.3 25.0 6,700' MD Drop Bottom Plug 5.0 30.0 Lead Slurry 7 526 75.1 105.1 Tail Slurry 5 58 11.6 116.7 Drop Top Plug 5.0 121.7 Displacement 7 330 47.1 168.8 Slow Rate 3 22 7.3 176.1 < 7 5/8", 29.7# casing MUD REMOVAL in 97/8" OH Recommended Mud Properties: 9.6 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. TD at 7,747' MD (3,768' TVD) Spacer Properties: 10.5 ppg MudPUSH* XL, Pv ? 17-21, Ty ? 20-25 Centralizers: Recommend 1- Y2 per joint throughout tail slurry Mark of Schlumberger II r-. 'G n" J . L .' r¥ i\i f' r, I ~I~'\ii"i ') ) t 1C-178 As Built: t'ef Eastings: 562,201.72 \C Northings: 5,968,735.16 e11' Pad Elevation: 59.2' AMSL G Doyon Rig 141 RKB @ 0' Elevation: 87.2' AMSL Runnina Order (1) Float Shoe Joint, (1052-7839) Weatherford Model Conductor Casing 303 Float Shoe made up on a joint of casing. Shoe @ 138', 16", (1) Joint Thread Locked Casing,(1052-7841) 7-5/8", 62.5#, API 5L Grade B 29.7#, L-80, STCM. (1) Float Collar Joint, (1052-7840) Weatherford Model 402 Float Collar made up on a joint of casing. (x) Pup Joints Casing, 7-5/8", 29.7#, L-80, STCM, as needed to space out window joint (x) Joints Casing, (1052-7838) 7-5/8",29.7#, L-80, STCM (1) Casing Hanger, (1061-9525), Vetco Gray Gen 1, 7-5/8" (1) Landing Joint, 7-5/8",29.7#, with Vetco Gray MCA Thread on bottom Centralization: Weatherford 7-5/8" x 9-5/8" SpiraGlider Centralizers (1) held in place on stop collars 10 feet above shoe (0) No centralizer on next joint above shoe joint (1) per joint on next 27 joints. floating below a stop collar placed in the middle of each joint, with exception of window joint. Place NO centralizer on MD Angle TVD window joint. Description (RKB ft) (deg) (RKB ft) KOP 300 0 300 Proposed Window Depth: At top of Base Permafrost 2198 66 1753 "D" Sand, 7349' MD Top T-3 2770 66 1986 Top K-15 3464 66 2268 Top Ugnu C 5627 68 3118 Top Ugnu B 6325 70 3369 Top Ugnu A 6466 70 3418 K-13 7025 72 3606 EOC-Top W Sak D 7348 74 3702 Top of Whipstock 7349 74 3702 Base of Whipstoc~ 7361 74 3705 Top West Sak C 7529 80 3743 Top West Sak B 7647 84 3760 7-5/8", 29.7#, L-80, BTCM 7 5/8" Casing Pl 7747 87 3768 Casing Shoe @ 7,747' MD / 3,768' TVD Set @ 87 degrees TD 9-7/8" hole Conoc~illips West Sak Production Well 1 C-178 Planned Completion Schematic Sheet 1 j,'~ ,~~, 1'fi:r," sing Details I (1 J ¡.~ l' ~ m. Sheet 4 of 4 prepared by Steve McKeever Permit Schematic 3/512003 6' J o 8 -0.' ::T -- - - -. i en "'0 :T_ CD su CD ::s P"t'::s r---..NCD:E "'--J 0 0. CD =r::J~ 0 ~ ____.. 0 en r~)ï 3 ~ ~ 0'2. ---"-.. ~ CD :E ..~c '~~ ~ CD .-'----....., 0 = ~j"'~ ï ::s ~ :.~ :f en 0 Ii CD (") ~ .,:T..... CCDoo CD 3 P"t'SU Q) P"t' :: ñ' fA ~(I) ªéb ~;:;:ë§'"O Q)C/)~èiJ ",,00'"0 ,01 ~ " Q) 1\>3<bCiJ OQ)<bQ. 8?f~~ '" ¡te( Å<~C (\'\a.~\ SG Top of Whipstock to be @ +/-7,349' MD /3,702' TVD See Sheet 1 for Casing Details Runninv Ordpr: (1) Float shoel Ray Oil Tools Silver Bullet with eccentric nosel 4"1 9.5#1 SLHT box (PESI). (1) Joint blank linerl 4".9.5#1 L-801 SLHT. (CPAI) (1) Crossoverl (1062-9436) 4"1 9.5#1 SLHT Pin x 4-1/2"1 12.6#1 SLHT box (x) Joints slotted liner 1 4-1/2"1 12.6#1 L-801 SLHT1 with eight 0.25" x 2" slots per foot. (CPAI). alternating every other joint to the surface casing shoe with (x) Joints blank liner, 4-1/2"1 12.6#1 L-801 SLHT. (CPAI) (x) Joints blank liner, 4-1/2"1 12.6#1 L-801 SLHT1 inside the surface casing shoe. (CPAI) (1) Crossover, 4-1/2"1 12.6#1 SLHT pin x 5-1/2"1 Hydril 521 box. (CPAI) (1) Liner Hanger AssemblYI consisting of: (1) Liner Hangerl Baker Flexlockl 5-1/2" x 7-5/8"1 with 5-1/2"1 17#1 Hydril 521 pin x pin. (BOT) (1) Nipplel Baker RS1 5-1/2"1 Hydril 521 box x pin. (BOn (1) Crossoverl 5-1/2"1 14#1 Hydril 521 pin x pinl minimum 10 at least 4.947" (CPAI) (1) Liner setting sleeve with 10 foot tie-back extensionl 5-1/2"1 Hydril 521 box down (BOT) (1) Liner Running Tool AssemblYI Baker Model HRI with 3-V21F Box up --' Lower Liner Top Set @ +/- 7,384' MD / 3,711' TVD -~ Centralization: Run (1) 4" x 5-1/2" straight bladed centralizer on the shoe joint, placed 10 ft above the shoe, held in place with stop collars. Run (0) NO centralizer on the joint above the shoe joint. Run (1) 4-1/2" x 6-114" Weatherford SpiraGlider per joint on the remainder of the liner in open hole, with NO stop collars. ~ ------ ------ ------ ------ ------1 ------ ------ ------ ------ D ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ 6-3/4" Open Hole TD: +/- 13,734' MD / 3,806' TVD Surface / Production Casing 7-5/8" 29.7# L-80 BTC Mod Set @ 7,747' MD /3,768 TVD g :J o a -0' =r -- - - -. " (II en" ::r_ (1) Q) (1) :J ~:J< W(1)< o c. (1) CJ:¡:O~ ~.. 0 en =--3\-..., 3 Q) "--.'~ C "C " ç~: :"C ñ) :E ~.,-~ ~ -g ::t. (1) ...., 0 = ;Jr:J ~ ~-:~-<~.. -. en 0 ;- <~::..:J (") I ~ ...- (1)::r ~ r--'" (1) ...... c3co ~Q) Q) ~ :.: () fA ~(I) ~ëb ~:::;:c¡¡'"O Q) (I)~~ ..,00'"0 .P1~;;J\Q) 1\)3CÞ~ OQ)CÞQ. 8?5-~~ . "11"\ "e~ \G sebert' Runnina nrd~r: (1) Float shoe, Ray Oil Tools Silver Bullet with eccentric nose, 3-1/2 in, 9.2#, SLHT box (PESI). (1) Bent Pup Joint, (1063-3575) 3-1/2 in. 9.2#, L-80, SLHT. (CPAl. SAP ID#10633575). (1) Crossover, 3-1/2 in, 9.2#, SLHT pin x 4 in, 9.5#, SLHT Box (CPA I). (1) Joint liner, 4 in, 9.5#, L-80, SLHT (CPA I). (1) Crossover, (1062-9436) 4 in, 9.5#, SLHT pin x 4-1/2 in, 12.6#, SLHT Box (CPA I). (x) Joints slotted liner, 4-1/2 in, 12.6#, L-80, SLHT, with eight 0.25 in x 2 in slots per foot. (CPAI). alternating every other joint with (x) Joints blank liner, 4-1/2 in, 12.6#, L-80, SLHT. (CPAI) as required to reach: (2) Joints blank liner, 4-1/2 in, 12.6#, L-80, SLHT. (CPAI) (1) Crossover, 4-1/2 in, 12.6#, SLHT Pin x 4-1/2 in, 11.6#, BTC Box (CPAI) (1) Swivel Sub, Baker, 4-1/2 in, 11.6#, BTC Box x Pin (BOT) (1) Liner Hanger, (1063-7668) Baker Flanged Hook Hanger, Model B, Size 7-5/8 in x 4-1/2 in, 4-1/2 in 11.6#, BTC Pin Down (BOT) (1) Liner Running Tool Assembly, Baker Model HR, with 3-V2 IF Box up ~ See Sheet 1 for Casing Details ~ ~ Top of Window at +/- 7,349' MD, 3,702' TVD Centralization: Run (1) 4 in x 5-1/2 Straight Blade solid centralizer in on the 4 in shoe joint, placed in the middle, held in place with stop collars. Run (0) NO centralizer on the joint above the 4 in shoe joint. Run (1) 4-112 in x 6-1/4 in Weatherford Spira Glider per joint on the remainder of the liner, with NO stop collars. .~ ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ D ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ 6-3/4" Open Hole TD: +/-13,727' MD /3.747' TVD Suñace / Production Casing 7-5/S" 29.7# L-SO BTC Mod Set @ 7'74~~:~~~~~:~;:~=~=~=~=~1 See Sheet 2 for Lower Lateral Liner Details Lower Liner Top Set @ +/-7,384' MD /3,711' TVD Tree Assy, (476-5770), Vetco Gray Gen I "Producer" ) ') 1C-178 As Built: Eastings: 562,201.72 Northings: 5,968,735.16 Pad Elevation: 59.2' AMSL Window @ 7349' MD / 3702' TVD Tubing Hanger, (493-3005) Vetco Gray Gen 1,4-1/2", w/4.909" MCA Top Connection; 4-1/2",12.6#, L-80 IBT-Mod box down, with BIW Penetrator (1064-0133 or 1064-0109) for TEC wire. (x) Joints Tubing, special drifted to 3.920" (1) Profile Nipple, 4-1/2" Camco DB w/3.875" No- Go Profile, IBT-Mod, set at +/- 500' MD (x) Joints Tubing Doyon Rig 141 RKB @ 0' Elevation: 87.2' AMSL Tubing Head Assy (503-5120) Vetco Gray, Gen 1,11" API 5M flange up. (1) Gas Lift Mandrel, (1062-2035) CAMCO 4-1/2" x 1" Model KBG-2 with DCK-3 shear valve installed, pinned to shear when annular pressure is 2500 psi greater than tubing pressure, 4-1/2" IBT Pin x Pin, with 6 foot 4-1/2" XO Pups, top and bottom, set at +/- 2400 ft TVD. (x) Joints Tubing (1) Gas Lift Mandrel, (1062-2035) CAMCO 4-1/2" x 1" Model KBG-2 with dummy valve installed, 4-1/2" IBT Pin x Pin, with 6 foot 4-1/2" XO Pups, top and bottom. (1) Joint Tubing 9-7/8" Hole Sail Angle: 66 degrees (1) Sidemount / Pressure Gauge, Discharge, Baker 925 Gaurdian (1) Joint Tubing Tubing String: 4-1/2", 12.6 #, L-80, IBT,AB Modiifed (1054-2463) (1) Sliding Sleeve with Profile, Baker Model'CMU' w/3.812" Camco No-Go profile, IBT-Mod (1063-3420), with 6 ft pups and relief slot subs top and bottom. with (1) Jet Pump installed after rig release, Weatherford, 3" Reverse Circulation, #15 Nozzle, #16 Throat, with top XO to CAMCO 3.812 Lock. (1) Sidemount / Pressure Gauge, Intake, Baker 925 Gaurdian (1) Joint Tubing ,ef e G (2) Joints Tubing (1) PBR with Seal Assembly, 17 ft Baker Model 80-47, 4-1/2" L- 80 IBT- Mod, 6 ft handling pups installed on top. (1) Packer Assembly, Baker Premier, (ID 3.875), 4-1/2" L-80 IBT- Mod, 6 ft handling pups installed on top and bottom. (1) Profile Nipple, CAMCO Model DB, 3.75" Packing Bore, 4- 1/2" L-80 IBT-Mod Box, set at 72 deg maximum inclination (+/- 7100'). With 10 ft handling pups. (x) Joints Tubing and tubing pups Control Line / TEC wire for Gaurdian Gauges, held in place with Canon Clamps on every coupling -t Hook Hanger, Baker Model B, 7-5/S" x 4-%", ~ Main Bore Drift = 5.315" ---------- Lateral Bore Drift = 3.S75" (1) Wire line Entry Guide, 4-1/2" L-80 IBT-Mod Box, to be spaced out +/- 15' above hook hanger ~_ _ _ u_.¡/ ------- ------ ------- ------ ------- 1 Goal: Minimize 7-5/8" Casing exposure for coil work 7-5/S", 29.7#, L-SO, BTCM Casing Shoe @ 7695' MD / 3770' TVD Set@ S9 degrees TD 9-7/0" hole "= ~,- ~,- =/' j F- -r \ Both laterals: 4-1/2",12.6#, LSO, SLHT liners, every other joint slotted with 0.25" x 2" slots, S slots per foot. Lower Liner Top Set @ +/- 7,3S4' MD /3,711' TVD Conoc~illips West Sak Production Well 1 C-178 Planned Completion Schematic Sheet 4 of 4: Tubing Details O 1 ' ,~ Q , , ~ f~ .1 :1 .. ~ , ,\'! ,\ ¡ I "I Il~' d U Y !~':~ au, Sheet 4 of 4 prepared by Steve McKeever Permit Schematic 3/1012003 S. K. ALLSUP-DRAKE PHILLIPS PETROLEUM COMPANY 700 G ST. A TO 1530 ANCHORAGE AK 99501 1030 PAY TO THE ORDER OF 77/1 Ti::: {)f-' f~~,~-'/tç.,L.t~c I:+.'^.::/.:. ~ ,1 , . . j . .. .. . !..... /. , ") . .t<:... DATE,~.3::<.. "~ / "-;...~.J" .. -62-14/311 -- ~ /~~ -.¡ >L'~ ;, ¿ ~~" t- T¿ -, c' . J ,.:/ S~~~~, ' '-.../ "'," DOl-tARS Ii] ----------.--"-"-~---.-----~~::c,--~_______L~ __ ...... CHASE Chase Matlhaftan Batlk USA, N.A. Valid Up TO. .SOOO Dollars '" "''''M., ''"'" ~_ "..", ~ ,." .' :$ JViEMO_____. ,þ 1:0:1 · .00 "'1,1: 2 .BOOOO I, 2 7 25 7". ,Q :1 0 /,-. . ... c, _"', .,... -/ ..... '.;.,/ lilt' ,- RECEIVED MAR 1 2 2003 AIM.LeOU a GasGons. COOBniIIIort twØ'Ii' And1orclØ8 ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~y,--~ \ ~- \ ~ PTD# d",O''?-=> --' 0 '-\_ \ CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API num ber last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to, be reported as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on· permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\j ody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY ConocoPhillips FIELD & POOL 490150 - KUPARUK RIVER, WEST SAK KUPARUK RIV U WSAK 1C-178 DEV /1-0IL ADMINISTRATION APPR DATE SFD 3/14/2003 ) \ì-or Service Well Only) (For Service Well Only) (For Service Well Only) ENGINEERING APPR Xl',\'- DATE lM . ¡qj:-~/2003 (For Service Well Only) GEOLOGY APPR SFD DATE 3/14/2003 WELL NAME Initial Class/Type 1. Permit fee attached ...........................................................,....................................... 2. Lease number appropriate ... ... ... ..' '" ... ... ... .. . ... ... ... ... ... ,.. ... ... ... ... ... ... ... ,.. .., ... ... ... ... ... .. . 3. Unique well name and number .......................'............,..............,.......,.....,................. 4. Well located in a defined pool............ ...... ... ......... '" ...... ... ...... ... ...... ...... ....,.... ... ..' ...... . 5. Well located proper distance from drilling unit boundary ............ ...... ... ... ... ... ...... ... ... ... ...... 6. Well located proper distance from other wells ......... ..' ... .., ... ... ... .. . ...... ...... ...... .. . ... ... ...... .. 7. Sufficient acreage available in drilling unit...... ... ... ... ... ... .., '" ... ..' ...... ... ...... ......... ,.. ...... '" , 8. If deviated, is well bore plat included... .., ...... ...... ...... ... ... ... ,.. '" ... ... ...... ... .., .., ... ... ,.. ... ...." 9. Operator only affected party.., '" ... .., ... ... ... ... ... ... ... ... ... ... ... .., ... .., ... ... .., '" ... ... ... ... ... ... ... . 10. Operator has appropriate bond in force ................................,....................................... 11. Permit can be issued without conservation order .'. .,. ... ... ... ... ... .., '" .., ... '" ... '" ... .,. ... ... ...., 12. Permit can be issued without administrative approval... '" ... ... ... ... ... ... ... ... ... '.. ... ". ... ... ,.... 13. Can permit be approved before 15-day wait ... ... ... ... ... ... .,. ... ... ... ... ... ... ... .,. ..,.., ... ... ... .,. ... 14. Well located within area and strata authorized by Injection Order # 15. All wells within 1/4 mile area of review identified .....'..............'..............,......,................. 16. Pre-produced injector: duration of pre-production less than 3 months.,. .,. ... .,. ... ... ... '.. ... ..' ., 17. ACMP Finding of Consistency has been issued for this project...........,............................. 18. Conductor string provided ". ... ... ,.. ... .,. ... ... ... ... .., .,. ,..... ... ,..... ... ... .., ....., ... ,., ,.. ... ".... ..,.. 19. Surface casing protects all known USDWs ... ,.. ... '.. ... ...... ... ...... ... .., ... ...... ... ...... ...... ... ... , 20. CMT vol adequate to circulate on conductor & surf csg '" ... ... ... .,. ... ... .., ,.. ... ... ... .., ... ... ... '" 21, CMT vol adequate to tie-in long string to surf csg .......................................... ...... ,.. ... .., , 22. CMT will cover all known productive horizons ... ... ... ... ... ." '" ... ". ... ... ." '" ... ... ... ... ..' ... .., ,.. 23. Casing designs adequate for C, T, B & permafrost .., '.......'.....,............"......,...........,..,... 24. Adequate tankage or reserve pit...... ... ... ... '" ....,.... .., ... ,,, ... ... ... ... ...... ... '.. ...... ...... ... ...." 25, If a re-drill, has a 10-403 for abandonment been approved.........,...........,................,....... 26. Adequate well bore separation proposed ... '" .,. .,. ... .,. ... .., ... ... ." ,.. ... .., ,.. ... ... .,. ...... ... '" ..., 27. If diverter required, does it meet regulations ......... ...... ...... ...... ...... ...... ...... ....,....... '.. ..... 28, Drilling fluid program schematic & equip list adequate ... '" ... ... ." ... ... ." ... ... ... .,. ... ... .,. ... .... 29, BOPEs, do they meet regulation .,. ... .., ,.. ... ... ... ... .., ... ... ". ... ... .,. ... ... ... ,.. .., '" ... ." ... ... .,. ... 30. BOPE press rating appropriate; test to ...."................ 3500 psig ...... minimum....,..... 31. Choke manifold complies w/API RP-53 (May 84) ................................,.....',.................. 32, Work will occur without operation shutdown ... '" .., .., ... ... .., ... .,. .,. ... .., '" ... '" .,. '" .., .., ... ... ,., 33. Is presence of H2S gas probable ... ... .,. ... .., .., .,. ,.. .,. ... ... ... .,. ... ... ... .., '" ... ... .., '" .,. ,., ... ..,., 34, Mechanical condition of wells within AOR verified ,.. ... .,. ... ... ... .., ... ... ... ,.. ,.. .,. .,. ... ... .., ,.. ..., 35. Permit can be issued w/o hydrogen sulfide measures ... ... ... ... ,., ... ... ... ,.. ... .., ... ... ." ... .,. ..... 36. Data presented on potential overpressure zones.......................................,................... 37. Seismic analysis of shallow gas zones ...... ........, ....,.... ... ...... ...... ........................ .., ....,. 38. Seabed condition survey (if off-shore) ............................................,..................,......... 39. Contact name/phone for weekly progress reports [exploratory only] ...... ...... ......... ........... RPC: GEOLOGY: ENGINEERING: RES. ENGINEERING: COMMISSION: SFD:SFD WG~;~. .1:. MJW: ~ ,,/, TEM:' EM~C\ JDH: RR: DTS: (' '3 ) } 7/Ó ~ SP: ~~~ ....... ..... PROGRAM Exploratory (EXP) GEOL AREA 890 Annular disposal para req Development (DEV) UNIT No. X Redrill 011160 Service (SER) ON/OFF SHORE On Well bore seg Yes Yes Surface and top productive interval in ADL 025649: TO in ADL 025638. Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes NA Not Applicable NA Not Applicable NA Not Applicable NA Not Applicable Yes Yes CFR 147.102(b)(3) exempts all aquifers lying directly below and 1/4 mile beyond the boundaries of the Kuparuk River Field. Yes NA Not Applicable No slotted liner planned Yes NA No reserve pit planned. Rig is equipped with steel mud pits. Liquid waste in approved annulus. Solids to G&I or tested and reused. NA Not Applicable Yes Close approaches identified. Directional analysis looks complete. Yes Yes Pore pressure estimated at 8.2 to 8.8. Planned mw 9.4 to 9.6. Yes Yes MASP estimated at 1340 psi. ConocoPPCo practice is to test to 5000 psi. 3500 psi based on 3000 psi csg test. Yes Yes Yes Drilling mud should preclude H2S on surface. Rig is equiped with sensors and alarms. NA Not Applicable No WeIl1C-123, which lies 1 mile southeast of top of prod. Interval, measured 232 ppm H2S on 8-4-2002. NA Expected pressure gradients are 0.43 to 0.47 psi/ft based on offset well control NA Not Applicable NA Not Applicable NA Not Applicable Comments/Instructions ) ) Well History File APPENDIX Information of detailed nature that is not particularly gennane 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. ) ) J03 -oLI ~ 1803õ **** REEL HEADER **** LDWG 03/05/16 AWS 01 **** TAPE HEADER **** LDWG 03/05/15 01 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! !! !! ! ! !!! !!! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: LISTAPE.HED TAPE HEADER KUPARUK RIVER UNIT MWD /MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 1C-178 500292314400 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 15-MAY-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 1 C. MEYER F. HERBERT MWD RUN 2 2 C. WONG D. GLADDEN MWD RUN 3 3 S. TUFTON D. WESTER # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 11N 10E 87.20 59.20 # WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 9.875 6.750 7.625 7734.0 13280.0 # REMARKS: PER CONOCOPHILLIPS ALASKA REQUEST f THE GAMMA~~E(~E~\lt:D 1\ H\J V,,j! 2 0 ?nn7~ . I..'J VV ,. .' '~\-~~,~\ ~~ ¡;¡ask;;1 0;'; ~L Cons. CC;{¡Un¡S5:0n it\m~h orag.e clipped curves; all bit runs merged. .5000 1 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: LDWG File Version 1.000 Extract File: FILE001.HED *** *** LIS COMMENT RECORD 1024 LDWG .001 **** FILE HEADER **** 8 bytes 132 bytes Minimum record length: Maximum record length: 83 records... Tape Subfile: 1 CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 19' 30.391" LONG: W149 DEG 29' 44.214" LOG MEASURED FROM D.F. AT 87.2 FT. ABOVE PERM. DATUM (M. S .L.) . COMMENTS: (1) Baker Hughes INTEQ run 1 utilized NaviTrak Directional only services from 120 - 2688 feet MD (120 - 1977' TVD). (2) Baker Hughes INTEQ run 2 utilized AutoTrak RCLS (Rotary Closed Loop System) along with RNT (Reservoir Navigation Tool) Resistivity and MAP (Modular Advanced Pressure) services from 2688 - 7739 feet MD (1977 - 3772' TVD). (3) Baker Hughes INTEQ run 3 utilized Multiple Propagation Resistivity (MPR) and Gamma Ray services in a steerable assembly from 7739 - 13280 feet MD (3772 - 3811' TVD). REMARKS ,: (1) Commenced LWD logging at 2688 feet MD (1977' TVD) (2) The interval from 7708 to 7739 feet MD (3768-3771' TVD) was logged up to 62.1 hours after being drilled due to a trip out of the hole to change the BHA. Please note that due to the change in Resistivity tools, from RNT to MPR, that the presentation goes from 2 resistivity curves to 4 resistivity curves at 7734 feet MD (3770' TVD). (3) Depth of 7 5/8" Casing Shoe - Logger: 7736 feet MD ( 3771' TVD ) Depth of 7 5/8" Casing Shoe - Driller: 7734 feet MD ( 377 0' TVD) (4) The interval from 10680 to 10711 feet MD (3805-3805' TVD) was logged up to 13.8 hours after being drilled due to a short trip to pick up heavy weight pipe. (5) The interval from 13249 to 13280 feet MD (3810-3811 TVD) was not logged due to sensor-bit offset at TD. $ ) ) ) ) # FILE SUMMARY PBU TOOL CODE MWD $ START DEPTH 2559.0 STOP DEPTH 13280.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 2 3 MERGE TOP 2559.0 7739.0 MERGE BASE 7739.0 13280.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. The data curves RPM & RPX are empty (null) above 7734' MD due to the change in resistivity tools. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN 'WN FN COUN STAT lc178 5.xtf 150 ConocoPhillips Alaska, Inc. lC-178 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPD 0.0 RPM RPM RPM 0.0 RPS RPS RPS 0.0 RPX RPX RPX 0.0 ROP ROP ROPS 0.0 FET FET RPTH 0.0 MTEM MTEM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 28 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F MSB 18704 6.75 ATK MEMORY # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : 09-APR-03 STOP DEPTH 7707.0 START DEPTH 2559.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ log header data for each bit run in separate files. 2 .2500 2 ! ! !!! !! !! ! !!! !! ! !!! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: FILE011.HED *** LIS COMMENT RECORD *** 1024 LDWG .002 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 811 records... Tape Subfile: 2 **** FILE TRAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2559.000000 13280.000000 0.500000 766 Total Data Records: ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 ROP MWD 68 1 FPHR 4 4 7 FET MWD 68 1 HR 4 4 8 MTEM MWD 68 1 DEGF 4 4 ------- 32 ) ) ) 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 VENDOR TOOL CODE DIR RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAVI. RESIST. GAMMA RAY # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 7739.0 2559.0 7707.0 o 66.8 83.8 TOOL NUMBER SHE 17834 RNT 20046 RNT 20046 9.875 .0 Spud Mud 9.20 .0 .0 300 .0 .000 .000 .000 .000 108.0 .0 .0 .0 .00 .000 .0 o BIT RUN 2 (MWD Run 2) . GR/RNT (AutoTrak) MWD run 1 was directional only. Therefore no data is presnted for run 1. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VAL U -------------------------------- WDFN lc178.xtf LCC 150 ) CN WN FN COUN STAT ConocoPhillips Alaska, I 1C-178 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPCH RPCH RPS 0.0 RACL RACL RACLM 0.0 RACH RACH RACHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 28 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 736 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2559.000000 7707.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 828 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes 85.0 .0 .0 .0 .000 .000 .000 .000 Spud Mud 8.95 .0 .0 18000 .0 6.750 7734.0 TOOL NUMBER SDS 34690 MPR 1150 SRIG 60365 86.9 91. 8 MSB 18704 4.75 MPR MEMORY 13280.0 7707.0 13280.0 o 15-APR-03 NEUTRON TOOL # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. RESIST. GAMMA RAY TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ # # 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: STOP DEPTH 13280.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ START DEPTH 7707.0 log header data for each bit run in separate files. 3 .2500 3 !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE012.HED *** LIS COMMENT RECORD *** 1024 LDWG .003 **** FILE HEADER **** ) ) , . ) ) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): o # REMARKS: # .0 BIT RUN 3 (MWD Run 3) . GR!MPR CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT lc178.xtf 150 ConocoPhillips Alaska, I lC-178 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RACLM 0.0 RASL RASL RACSLM 0.0 RACH RACH RACHM 0.0 RASH RASH RACSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 ) ) Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 1174 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7707.000000 13280.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 1273 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 03/05/15 01 **** REEL TRAILER **** LDWG 03/05/16 AWS 01 ) Tape Subfile: 5 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes