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Home My WebLink About203-0421. 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 JP to GL 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 13626'feet None feet true vertical 3771' feet None feet Effective Depth measured 13626'feet 7027', 7086'feet true vertical 3771' 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' 6224' Casing 3599' 3768' 7007' 13580' 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 203-042 50-029-23144-60-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025638, ADL0025649 Kuparuk River Field/ West Sak Oil Pool KRU 1C-178L1 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) 5 Gas-Mcf MD 1075 Size 110' 10 240010 25 350675 360 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 Slotted Liner:7413-13493' Slotted Liner: 3715-3762' 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 1:03 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=USReason: I am the author of this document Location: Date: 2024.05.29 11:24:01-08'00' 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 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 JP to GL 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 13626'feet None feet true vertical 3771'feet None feet Effective Depth measured 13626'feet 7027', 7086'feet true vertical 3771'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 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 Slotted Liner:7413-13493' Slotted Liner: 3715-3762' 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 measured TVD 5-1/2" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-042 50-029-23144-60-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025638, ADL0025649 Kuparuk River Field/ West Sak Oil Pool KRU 1C-178L1 Plugs Junk measured Length Slotted Liner Liner 6981' 6224' Casing 3599' 3768' 7007' 13580' 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 Kayla Junke at 11:34 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 Image ~ ,bject Well History File C"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. ~03 - OY-d..-. Well History File Identifier Organizing (done) o Two-sided 11I111111I111111111 D Rescan Needed 1 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: D Logs of various kinds: NOTES: BY: Helen C Maria ) D Other:: 'I Date:~' 5'" 0& I J JAA.éJ /5/ V f I Project Proofing 1- Scanning Preparation ;l ... x 30 = {¡O IN,~ Date: 7. ~ fJS" /5/ " + ~'6 = TOTþ"L PAGES ~ g (Count c o~ no. inclu~over sheet) ~ Á ð.. Date- Ö t) 6 /5/ r 1'1 I 1 ¡, BY: Helen~ BY: Helen (Maria) BY: Production Scanning Stage 1 Page Count from Scanned File: Ló q (Count does include CO;? sheet) Page Count Matches Number in Scanning Preparation: V YE~ . ~ NO . J Helen(""~) Date: 1. S- 05 /s/ tin If NO in stage 1 page(s) discrepancies were found: YES' NO Stage 1 BY: Helen Maria Date: /5/ 1111111111111111111 11I111111111111111I Iln Date: /5/ Quality Checked 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: • ~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~ ~ ~QO9 REPORT OF SUNDRY WELL OPERATIONS ~ _ ~_,,,, rnmmissiofa 1. Operations Pertormed: Abandon ^ Repair Well ^~ ~ Piug Perforations ^ Stimulate ^1~~85K~ t err ^ Alter Casin g Q Pull Tubing ~ • Perforate New Pool ^ AtiCIlOCBtJS Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ Exploratory ^ 203-042 / ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23144-60 - 7. KB Elevation (ft): 9. Well Name and Number: RKB 8T 1 C-178L1 ' 8. Property Designation: ~~C ~~~ 3~ ~'~ Q ' 10. Field/Pool(s): , ADL 25649 i ~ g ~2,r;.~ Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 13626' • feet true vertical 3771' feet Plugs (measured) 7135' Effective Depth measured 13579' feet Junk (measured) true vertical 3767' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 110' 110' SURFACE 7705' 7-5/8" 7733' 3770' PROD. LINER 6223' 4.5" 13579' 3767' Tieback Liner 7044' S-1/2" 7072' 3620' ...mot ,~,~ 1YIr~r`~ .~1 ~~~r'~= ~ ~~!~~~ Perforation depth: Measured depth: 7413'-13493' ~~ CR~~Ct- ~~~ ~ \ ~~ true vertical depth: 3715'-3762' . ~ c. c..C+~SCc C. ~ -~h~s oc.~MC~~- ~s ~n~ Tubing (size, grade, and measured depth) tubing in main wellbore, , MD. ^~e~C SyhCS~ ~~rC wo~~ ~ c~v ~~~ ~^ ` C_ \~ p Packers &SSSV (type & measured depth) no packer t~ (~ \~j~ ~ ~ `~hS l ~- TDV~ZVL'S CI.CyU t~'~0 no SSSV 12. Stimulation or cement squeeze summary: ~^ t-Mvk~~ ~ Intervals treated (measured) not applicable ~ / , l~ 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 NIA if C.O. Exempt: 309-119 contact Brett Packer @ 265-6845 Printed Name Bre P a cker tt Title Wells Engineer -/ ~ Signature -~5` ~ ~ ~ - Phone: 265-6845 ~ ~~© ~ Date ~l yC/+ Pre a b Sha n All u -Drake 263-4612 Form 10-404 Revised 04/2006 7 ~ .. s + 'e Submit Original Only ~' 6 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 ~Packgr ~DriICing aZ'WelCs 'Worfyver~Engineer 'Work# (907) 265-6845 CeQ# (907) 230-8377 5/21 /2009 2-7/8" 6.5#, LAO, EUE fird Motl. 2.441" ID, Tubing String Conocol'hi I lips 2.347" Dritt West Sak 7-5/8" Injector :495' MD-2.312" DS Nipple ~ ~-~ ~~ :' j4006'MD-GLM, Cam<o 2-7/6"x1"KBGM-M Dual Lateral Completion ~ /6893' MD -GLM, Camco 2-718" x 1" KBGM-M Surface-6962' MD, WO_09 5-%" Casing. 15.5#, .6945' MD -Fluted Wire Protector, 4.61" OD LAO, BTCM w/SCC 6946' MD - CMU Sliding Sleeve, w/ 2.250" D Prorik 6950' MD-Fluted Wire Protector, 4.61" OD 69fi 5' MD -Zlebel Gauge Carrier 7003' MD -Bottom of Seal Assembly 4.00" Seal OD 2.992" ID 8956' MD, Crossover 2-718" X 3-1/2" 6958' -6676' MD.Tubing 7-1l2" 9.3#, LAO 7072' MO -Bottom of Seal Assembly 4.75" Seal OD 3.875" ID 6965' MD-SBE 4.00" ID, 5.50" OD. 20' long i 7004' -7048' MD,TUbing 4-1/2" 12.6#, LAO, IBTM 7056' MD - PBR 3.875" ID, 5.50" OD, 20' long 7109' MD - 3.75" DB Nipple ~~ 'D' Sand Lateral 7086' MD - 4-112" X 7518" S-3 7336' MD- Bottom of WLEG 5967' MD -Mill Out Extension ~~ D-sand Window @ 7359' MD, 3703' ND, 75° Inc d.54" ID, 5.54" OD 4-112" 12.6#, LAO, DWC, Slotted liner s 7373' MD -liner Swivel, 4-112" ~" 7356' MD - 4-112" X 7SI8', j ~ 13559' MD - 3-112" Bent Joint Model'B' HOOK Hanger ~~~` ~~-____~~_--- 13580' MD-3-112" Guide Shoe TD (d 13650' MD, 3785 TVD, 90° Inc / 5-112" X 7SI8" ZXP I Liner Top Packer j with Hold Downs / 5-112" X 7518" Flez Lock \ Liner Hanger Liner Hanger! Packer Assembly at -- 7402' MD As Completed N~UG ES Baker Oil Tnols 'B' Sand Lateral d-112" 12.6#, L50, DWC Slotted Liner ,73244' MD-4-112" Eccentric Guide Shoe -~~--~~TD ~ 13280' MD, 3810 ND, 89° Ine 7-518" Casing Shoe, Set at ~ 7739' MD, 3773 ND, 87° Inc 13210' MD - 4" Blank Liner with Y." weep hole • • Baker Nughes 2003. This document may not be reproduced or dlstrlbuhd. In whole w In part, In any brm or by any means Nectronlc or mechanical. Including pholocopying, recording, or by any Inlormatlon storage and retrieval syshm now knovm or hereafter Invented, wltliout written permission hom Baker Hughes Inc. • ConocoPhiiGps ( ~ '~ ~Ii:)i\.y I. i I ____ellCmfig t-_97811, 42712(1095:Sy:07 AM _., - $C3emey9i' .AG9al.. HANGER. 27 T ~ ~" ~... CONDUCTOR, 30-110 NIPPLE, 495 --- -- I GAS LIFT, - ~ 1 4,006 GAS LIFT. 6,693 CenVaNZer, _ 6,965 SLEEVE, 6.966 CentraNZer, 6.950 GAUGE, 6,565------ - 2Y±~ SEAL ASSY,_ 6.983 3 '~1 PeR, T,05fi - - PRODUCTbN, 26-],07T PACKER, 7,066 KUP ~ 1C-178L1 ~ ttribute tPVU WI s Fieltl Name __ _ _ _ _ _ _ Well Status IMax Angle & MD ;TD Inc! (°) MD (ftKe) Act Bim (ftKB) 32314460 WEST SAK PRODUCING 9549 7,66591 13.626.0 H2S (ppm) (Date Annotation End Date ~KB-Grd (N) IRig Release Da IPPLE I 60 1/1/2009 Last WOE I 34.31 ~~ 5!1/2003 n De th NKB End Dale p ( I Annotation End Date j IRev Reason' WORKOVER I 4/27/2009 I $~rln S n g -- g -- p( I ~~~ To str Str p ( e p ( TV ~~~ S t D $e g Str g ..IString TOp Thrd 01 ~ ~Str t ~~ Slottetl 4 1l2 3.96A ],35f 2 ~ 13,279 8 751 j L 80 SHLT 12. O - _-, - n Hole (Wireline retrieva Top Depth' ble plugs, v I alves, pumps, fish, etc.) --__. (fVD) Top Intl (flKB) (°I Descriotion ~ Comment Run Data ID Ii LEG LINER Btm NIPPLE, 7,109 :,., G11~ ~ - PLUG. ],135 - _.µ. " .. - W LEG. 7,335 - HANGER. _ _ _ 7,356 Mandrel C SLEEVE. 7,401 - - - Stn Top (NKB) BUSHING. ~' 1 4,005.9 7,414 ~ ) NIPPLE, 7,416 . ~ 2 6,$93.1 MANGER.-~ g y~. ],d19 - I 33 , xo.z4za-~ - .r.~ LOCATOR._ ~ 7.704 - - SURFACE, I 28-].733 IPERF, 7.700-13179 -. - IPERF, ` ),413-t 3,493 B SAND Sloned _ ~ ~ Liner.- ] 402-13.244 D-SAND Sloaed -- ' Liner, - 7.356-13.280 -_-~ XO, 13,558 -~ ~ ' TD (1C-178Li), 13,626 Commetk I Port OD ~ ~ Valve Latch Size TRO Run ~ Model lint Serv Type Type (in) (psi) Run D 1 _ Cam KBMG-M 1 GAS LIFT DMY BK-5 0.000 0.0 4/222009 (KBMG-M 1 GAS LIFT DMY BK-5 0.000 0.0 422/2009 f~ illi~ Wel I: 1 C-178 2009 RWO COMPLETION 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'/a", 6.5 ppf, L-80, 8rd EUE • 2.313" DS-nipple. . Baker 2'/e" CMD w/ 2.25" D profile. • Ziebel Gauge. • 3'/2' 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) Conductor: 16", 62.5#, H-40 at 110' Surface Casina: 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 Type 4006' 2498' 2-7/8" KBMG, 1" 6893' 3561' 2-7/8" KBMG, 1" Directional: Max Incline: 92° @ 11208' Max Dogleg: 8.7° @ 1505' Last Updated: 19-May-09 Updated by: JBP ConocoPh~ilips Time Log & Summary tNelNlew Web Reporting Report 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 Comment Dur S. Depth E Depth Phase Code Subcode T Date From To 4/17/2009 ._ _ 24 hr Summary Move Nordic Rig 3 f/ 3K-35 to 1C-178. MIRU over 1C-178, accept rig, Berm up and set auxiliary 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 auxiliary equipment: Accept 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 WELCTL 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 psi 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 WELCTL OWFF P 61ow 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. Page 1 of S r r~ Time Logs Dots From To Dur S. De th E: De fh Phase Code Subcode T Comment - 04:30 05:30 - 1.00 COMPZ WELCTL 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, install blanking plug. NU BOPE 15:30 00:00 8.50 COMPZ RPCOM PRTS P Pressure test ROPE 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" completion 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 PUTS 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 psi for 10 minutes -test 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 tubing head. NU new casing head and tubin head. PageZafS Time Logs ~ Date _ From To D_ ur S. De th- E. De th Phase :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 w151/2, 15.5# Inner Liner f/ 5,263' to 7,083' and No-go. 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 -due to CSG Couplings in annular. 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 Welt En leer. 00:00 00:30 0.50 7,083 COMPZ RPCOM THGR P RIH w/and Land Hanger. 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 psi 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 strip . 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 up 5-1/2" casing, 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 EQRP T Inspected gauge and wire, gauge was bad, spliced in back-up gauge which also does not work properly, notified WeII 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'. Page3af5 Time Logs Date From To - Dur S. Deoth E: Depth Phase Code Subcode T Comment 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 line 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 hangerw/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 psi/30 min on chart, good tests. 21:00 21:30 0.50 0 0 COMPZ RPCOM SEQP P Blow down circ lines and R17, 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. Page 4 a# 5 Time Logs _ Date From To Dur S. Depth- E: De th-Phase Code Subcode T Comment 01:30 07:30 6.00 0 0 COMPZ RPCOM OTHR Flushed all surface lines, cleaned trip tank, pits and shakers, RD mud shack, moved tanks. Clean out cellar and root rig back off wellsite. Nordic Rig 3 released from 1C-178 on 4-23-2009 07:30 am. PageSofS Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Prod Engr Specialist [n1139@conocophillips.comj Sent: Friday, March 27, 2009 5:09 PM To: Maunder, Thomas E (DOA) Subject: Attachments: 1 C-178 Planned Completion Schematic.pdf lC'" ~~1~ t-..{~.. ~ ~~"~~ 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 P,~\~cvc~i C~<c~~ t~'~~ °tiC'~ tA-~ ConocoPhillips Alaska, Inc. ~^ ~ Greater Kuparuk Area ~ ~: `~~ ~., Production Engineering Specialist Office (907) 659-7535 NSK-69 Pager (907)659-7000 (924) `~~~~ l --CSC (~ 1 This email may contain confidential information. If you receive this a-mail in error, please notify the sender and delete this email immediately. ~~;'~:~~~ ~P~ ~ f UGC 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, I 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 Tne Assy, Tutdrg HNysr, (493-0005) Velm Gray Gen I,1-12', w/ 4.1KIg' (47&5770), Valco Gray MCA Top Connection; 41?,1260, L-00 IBT-Mad lore dorm, Gen I'Produxr w0h &W Penabator (10e4-0133 or 10640109) forTEC wke. Tubing Fieaa ~~ (:) Joirtls Tubing, spacial t4lfbd to 7.120' (503-5120)Velm Gray, Gen 1,11' API SM flenpe up. (1) Pntga Nlppb, l-t2• Games DB w/ 3.077 No- ' Go Rvflb, IBT-Mod, se( at •%500 MD (x) Je'arfs Tubing (1) Gas L1R MarMnl, (1082-2035) CAMCQ /-12' x t' Model KBG2 w0h DCK3 shear valor IrutaOed, pinned to shay when annula7 pressure b 2500 psi greater Bun tudny pnssun, 412' I8T Pin x Ph, w0h 8 foo11-12' XO Pups, top and Dotlom, set a(+!- 210D R TVD. (s) Jolyds Tubing Insubbd Conductor Casinp, l6', API SL X58 (11 Gas L114 Nbndnl, (1062-2035) CAMCO 4-12' x 1' Modell®G2 with dutnmy vatic 1.000 Wf, (~ +F' MD Inshlletl, ht/2' IBT An x Ph, w0h 8 foo141(Y XO Pups, tap end bottom. (1) Joird Tubing (1) Pressure Gauge, Dlsehtisrge, Baker Gaurdlen (1) Jolyd Tubing 9-7/8" HDIe Sail Angle: (1) SIIdIng slee~,e warn promo, Baker Moeei'CMU' w/ 3.012' 88 degrees Camca tlo Go pnfle, IIiT-Mod <t0833420), w0h 8 n pups and reilaf slat subs top and Dotlom wltlr (1) ,let pump lnMaOed alter rig nlsasa, (1) Joint Tubing WeaOterlad 4'Reverse C6cu/anon, Oxv Nazzb, e>or 7hoet with mp xD ro cAMCG cock Tubing String: 4-112", (1) Prsssun Gauge, trdaka, Baker GauNhn 12.6 #, L-8D, IBT,AB (2) Joirds Tubing Modiited (1054-2463) (1) PBR with Seal Assembly, 17 0 Hoke, Model tb-47, 1.12• L- BO 037-Mod, 6 0 hand(mg pups instsDed an tap. n .v ,// (1) Ratrlavabb Paeksr AsswnWy, Bekar Premkr, (D 3.07, 4 L(nen, svsry othr S ~ tp 1? L-00187-Mod, 6 R trMrmg pps kMelled o0 top and botlorr~ ~)olyd slotted (025' ~, (1) Probb Nipple, CAMCO Model D8, 3.70' Packlrrp Ban, x z' x e per raa), L%^, 12.fift, L00, Hook Htngb,~8t_karModel B. 7.510" x 1-X', /-1? L-00 I8T-Mad Box, se(af 70 deg maximum Indinalbn. SIJiT Mein Bon Drip = 5.315' MI011 10 fl harld0ny pups. Lalenl Bon DrIR =3.176' - - kl Joinm Tubksg and tubing Pups _ (1) Wtra Ibts FiNy Galda, 41 Q' L-00 IBT~Mod Box. ro be spaced out+/• 15 above Crook hargn ` 1 ^y ` Gook Mlnkraze 7.5/0' Caskq expown =_____ ______ --____ --- - -- --- - --- --_-__ ____-_ - --- -- --- coilwork ~3p ~l 3~a a~~ ti-©5 _ ~ ~ ______ ______ ______ ____=_ ____=_ ' ~ ~9~ ~'~ - - -wi_na~ ~ iisa'~MD / 3703' TVD ~ ~~~~-~, J ~y , ~^ `~ b 7518', 29.78 L-00, BTCM Casing Si1oe ~ 7695' MD 13770' TVD , Sat ~ 08 degrees TD 9-7/0' hob Rotating Fbxlok Liner Hanger @ +!- 7,300' Reamer Shoe Reamer shoe 63:' Upper kHeral 7D ~ 13700 A!D/37q ,~D 63:'LOwer Iafera7 'ro ~ ,3,700 MD/3805 7YD ~~ ~ M . = m m~0 3 N ~ c O ~ ~ ~ m F a °' v aV o Y ~ a. r N c m q m ~aN '~~ I • • -~,_ --=---,. ~~~ 03/01/2008 D4 NOT PLACE .._ '., ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc J J{N~ DATA SUBMITTAL COMPLIANCE REPORT 6/27/2005 Permit to Drill 2030420 Well Name/No. KUPARUK RIV U WSAK 1C-178L1 Operator CONOCOPHILLlPS ALASKA INC ~c..d If lJp~ðO') API No. 50-029-23144-60-00 MD 13626 ,- TVD 3771 , Completion Date 5/1/2003 Completion Status 1-01L UIC N ..--- -- - --- ---- ------- - ------ REQUIRED INFORMATION Mud Log No Samples No -- ----------. -- ----- -- ------------ DATA INFORMATION Types Electric or Other Logs Run: GRlRes Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name Current Status 1-01L Directional Su~ Ye0 (data taken from Logs Portion of Master Well Data Maint) ,~./ Interval OH 1 Start Stop CH ,---~_._---~ Log Log Run Scale Media No ~c Lis 12031 LIS Verification I C 12031 Induction/Resistivity I ! I~ C 12031 I nd uction/Resistivity -Rpt C Lis 12032 LIS Verification ~ C 12032 I nd uction/Resistivity I ¡ i Æ> C 12032 I nd uction/Resistivity ~'pt C Lis 12033 LIS Verification ~ C 12033 I nd uction/Resistivity I I / i.,{D C 12033 I nd uction/Resistivity 25 25 25 25 25 25 - -- ---.---- Well Cores/Samples Information: Name Interval Start Stop Received Comments 1,2,5-8 2559 13626 Open 6/20/2003 Final 120 13626 Open 6/20/2003 RWD - Multiple Propagation Resistivity, Gamma Ray Final 120 3735 Open 6/20/2003 RWD - Multiple Propagation Resistivity, Gamma Ray 1,2,5 2559 7637 Open 6/20/2003 PB1 Final 120 7637 Open 6/20/2003 RWD - Multiple Propagation Resistivity, Gamma Ray - PB1 Final 120 3722 Open 6/20/2003 RWD - Multiple Propagation Resistivity, Gamma Ray - PB1 - 1,2,5,6 2559 9962 Open 6/20/2003 PB2 Final 120 9962 Open 6/20/2003 RWD - Multiple Propagation Resistivity, Gamma Ray - PB2 Final 120 3735 Open 6/20/2003 RWD - Multiple Propagation Resistivity, Gamma Ray - PB2 Sample Set Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 6/27/2005 Permit to Drill 2030420 Well Name/No. KUPARUK RIV U WSAK 1 C-178L 1 Operator CONOCOPHILLlPS ALASKA INC MD 13626 NO 3771 Completion Date 5/1/2003 Completion Status 1-01L Current Status 1-01L ADDITIONAL INFORMATION Well Cored? v0 Chips Received? Y / N ~N (iyN Daily History Received? Formation Tops Analysis Received? ~ --- --~ - --- --~ ----------- ---- Comments: -~ ---- -~-- L Date: -- -- ---- - ------ Compliance Reviewed By: API No. 50-029-23144-60-00 UIC N '-' Â 'l' ~ ~ÀÒ\)j· ~ ) Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells ConocriP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 June 25, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Reports for 1C-178 and 1C-178L 1 (APD # 203-041 and 203-042) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk wells 1 C-178 and 1 C-178L 1. If you have any questions regarding this matter, please contact me at 265-6830 or Steve McKeever at 265-6826. Sincerely, ~.~ \~. ~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad ORIGINAL ') ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil [] Gas U Plugged 0 Abandoned 0 20AAC 25.105 No. of Completions _ WINJ 0 WDSPl 0 GINJ 0 2. Operator Name: 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: 503' FSL, 1273' FWL, Sec. 2, T11 N, R 1OE, UM Total Depth: 1399' FSL, 315' FWL, Sec. 35, T12N, R10E, UM 4b. location of Well (State Base Plane Coordinates): Surface: x- 562202 y- TPI: x- 556982 y- Total Depth: x- 555971 y- 18. Directional Survey: Yes [] No 0 5968735 5970700 5976867 Zone-4 Zone-4 Zone- 4 21. logs Run: GR/Res 22. Suspended 0 WAG D 20AAC 25.110 Other 5. Date Comp., Susp., or Aband.: May 1 , 2003 6. Date Spudded: April 18, 2003 i' 7. Date TD Reached: April 25, 2003 8. KB Elevation (ft): 87' AMSL 9. Plug Back Depth (MD + TVD): 13579' MD 1 3767' TVD 10. Total Depth (MD + TVD): 13626' MD 1 3771' TVD 11. Depth where SSSV set: Land Nipple @ 498' 19. Water Depth, if Offshore: N/A feet MSL 1b. Well Class: Development [] Exploratory D Service D Stratigraphic Test D 12. Permit to Drill Number: 203-042 1 13. API Number: 50-029-23144-60 14. Well Name and Number: 1C-178 L1 15. Field/Pool(s): Kuparuk River Field West Sak Oil Pool 16. Property Designation: ADL 25649 1 25638 17. land Use Permit: ALK 467 / 463 20. Thickness of Permafrost: 1924' vertical CASING SIZE GRADE B L-80 L-80 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 Lite, 276 sx Class G 7356' 13579' 6.75" slotted liner WT. PER FT. 62.5# 29.7# 12.6# 16" 7.625" 4.5" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): slotted liner '~···t~ . ~;'¿~~º3 ~;lh:':~c... 24. SIZE 4.5" AMOUNT PUllED TUBING RECORD DEPTH SET (MD) 7336' PACKER SET (MD) 7086' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A 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 Oll-BBl GAS-MCF WATER-BBl 6/21/2003 12 hours Test Period --> 1937 437 5 Flow Tubing Casing Pressure Calculated Oll-BBl GAS-MCF WATER-BBl press. 334 psi 2340 psi 24-Hour Rate -> 3874 874 10 27. CORE DATA CHOKE SIZE GAS-Oil RATIO 226 100% Oil GRAVITY - API (corr) not available Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". NONE Form 1 0-407 Revised 2/2003 ~DMS BFL (0[/ JUL \)~. lnoîONTI'ß'~tS+NEA L RECE~VE.D :)1003 JUL 0.;· {, Alaska Oil & Gas CUì:. , COfnïnissiQn Ailchorag~, Submit in duplicate 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-178L1 PB 1 TD ~lff .~ ð 7 r> 1/ ~&-ht.- 1C-178L1 PB2 TD NIA 9962' 3738' 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. RECE/V JUL 0 2 2003 Alaska Oil & Gas Cons. An.r.~fltrJie Contact: Steve McKeever @ 265-6826 Printed t-{afl1.i ~homa\s t. Signature \ -- t ~ Title: r<hQne Kuparuk Drillinq Team Leader Date ?({/l> j 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-Altemating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the ìnterval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 1 0-407 Revised 2/2003 ORIGINAL ) ) E)Øl1qç()Phillip~.Alaska Operátidr1SSUI11r11äry . Report Page 1öfto Set bk std of HWDP - P/U 3 NMCSDP - Ck connection torque on MWD & Mud motor - Re scribe. Drill, Slide & Survey 9.875" hole fl 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 fl 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 fl 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 61 k, Rot wt 74k, Torq on bUm 3k ft-Ibs, off bttm 2k ft-Ibs 0.50 DRILL SFTY SURFAC Rig evac drill wI 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 fl 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 61k, 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 fl 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-178 Common Well Name: 1 C-178 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Dåte From .~ To HoÙrs CÖde SUb Phåse Code __~___~~__.h___ 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: DescriptiÓn ÓfOþèràtiÓns ----~.._._-- 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 ..) ) 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 G rou p: Day Light saving Time- Set clock ahead 1 hour Cut drill line (61' cut) - Service Top Drive & Draworks TIH wi 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 wi 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 wI 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 4-5kft-lbsMudwt9.1+, Vis 115. ....AvgROP 142fph 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, TO 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 wI BAROLlFT. WOB-10-25K, RPM-150, Pump-3,350 psi @ 592 gpm, UWT-125K, DWT-63K, TQ off/on-7-8/10 ft-Ib. ART=8.0 hr, AST=O hr. Drill 9.875" hole wI 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 Date From- To Hours Code Sub Code 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 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 wI HWDP - No problems - No excess overpull LID BHA #1 LID BHA #1 - LID 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 Frorn..; To Hours Code Sub Description of Oþerations 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, On 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, On 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, On wt 59k, Rot wt 87k, T orq 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, XC, 3 NMCSDP, Fit sub, Stab - On 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: 4/1 0/2003 08:15 - 12:00 12:00 - 15:45 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: . DescriptionofÖperations 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 cIa bttm rams to 4" - cIa 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. cIa 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 I 10 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 cIa 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, Dn 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 11 Ok, Dn 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, Dn 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. hNoteh Built 100 bbls of mud for 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 12003 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 CEMENTDSHO 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: 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 Houts Code· Sub Code 4/12/2003 12:00 - 00:00 12.00 DRILL DRLG PROD 4/13/2003 00:00 - 12:00 12.00 DRILL DRLG PROD Start: 4/4/2003 Rig Release: 5/1/2003 Rig Number: Spud Date: 4/2/2003 End: 5/1/2003 Group: 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 f/ 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 3-10k, 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 w/ 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 fl 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 81 k, 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 (8-10k) 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 t/12931. 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 t/13280. 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: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-178 1 C-178 ROT - DRILLING n1334@ppco.com Doyon 141 . . Sub Hours, Code Code Start: 4/4/2003 Rig Release: 5/1/2003 Rig Number: Spud Date: 4/2/2003 End: 5/1/2003 Group: 4/15/2003 4/16/2003 18:00 - 00:00 00:00 - 02:00 02:00 - 05:30 05:30 - 07:30 07:30 - 08:00 08:00 - 14:15 14:15 - 18:30 18:30 - 19:30 6.00 DRILL 2.00 DRILL 3.50 DRILL 2.00 DRILL 0.50 CASE 6.25 CASE 4.25 CASE 1.00 CASE TRIP CIRC TRIP PULD RURD PULR RUNL RUNL PROD PROD PROD PROD CMPL TN CMPL TN CMPL TN CMPL TN 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 TO 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 TD, 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 f/7361 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 110k SOW 55k RW 84k SPR #1 20 SPM 590# 40 SPM 880# TO 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: 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 Sub Code 4/20/2003 00:00 - 08:00 8.00 DRILL DRLH PROD 2.8 AST 1.9. 08:00 - 09:00 1.00 DRILL TRIP PROD Pump out from 9962' to 9040' for sidetrack. 09:00 - 00:00 15.00 DRILL DRLH PROD Drlg. new hole from 9050' to 10198' TVD 3770'. ART 5.5 AST 2.9 PUW 113k SOW 53k RW 84k TQ 8.5k on 6.5k off SPR 20 spm 520 PP 40 spm 840 PP MW 9.2. 4/21/2003 00:00 - 05:45 5.75 DRILL DRLH PROD Drlg. horizontal hole from 10198 to 10681'. 05:45 - 06:30 0.75 DRILL OTHR PROD Survey-trouble shoot mwd. 06:30 - 07:00 0.50 DRI LL DRLH PROD 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 07:00 - 08:00 1.00 DRILL CIRC PROD Circ. condition mud to 9.4#-check for flow. 08:00 - 11 :00 3.00 DRILL TRIP PROD Pump out of hole to 7684'. Check torque & drag. 11 :00 - 12:30 1.50 DRILL OTHR PROD Mad pass from 7650 to 7550' to check mwd tool. 12:30 - 16:00 3.50 DRILL TRIP PROD Check for flow pump pill & poh. 16:00 - 16:45 0.75 DRILL OTHR PROD Stand back bha. 16:45 - 17:30 0.75 DRILL OTHR PROD Down load mwd. 17:30 - 19:00 1.50 DRILL PULD PROD Lay down failed mpr tool-pick up standby mpr & directional collar. 19:00 - 19:45 0.75 DRILL OTHR PROD Program mwd. 19:45 - 20:30 0.75 DRILL OTHR PROD Make up bha-agitator-shock sub-xo-shallow pulse test mwd. 20:30 - 23:00 2.50 DRILL TRIP PROD RIH to 6914'. 23:00 - 23:15 0.25 DRILL OTHR PROD Change out worn lotad sub on stand #72. 23:15 - 00:00 0.75 DRILL CIRC PROD Pump ep lube csg. treatment pill @ 7300'.80 spm @ 2000 psi. 4/22/2003 00:00 - 00:30 0.50 DRILL OTHR PROD Service top drive-blocks & rig. 00:30 - 02:00 1.50 DRILL TRIP PROD RIH from 7300' to 1 0779-inspect lotads. 02:00 - 02:30 0.50 DRILL CIRC PROD Circ. & survey. 02:30 - 04:45 2.25 DRILL OTHR PROD Mad pass log from 10776 to 10525'. 04:45 - 05:00 0.25 DRILL TRIP PROD RIH to 10779'. 05:00 - 21 :30 16.50 DRILL DRLH PROD Drlg. from 10779' to 11900'. TVD 3791' ADT 5.6 ART 4.2 AST 1.3 PUW 128k SOW 60k RW 90k TQ 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 21 :30 - 23:00 1.50 DRILL CIRC PROD Pump hi vis weighted sweep & cbu. 23:00 - 00:00 1.00 DRILL WIPR PROD Pump out of hole @ drlg. rate fl wiper trip from 11900' to 11225'. 4/23/2003 00:00 - 01 :30 1.50 DRILL WIPR PROD Pump out from 10645 to 9710'-set back hwdp. 01 :30 - 02:30 1.00 DRILL WIPR PROD RI H from 9710' to 11900'. 02:30 - 06:00 3.50 DRILL CIRC PROD Circ. drop gyro & pump down same followed wi dry job. 06:00 - 13:30 7.50 DRILL TRIP PROD POH taking gyro shots to bha. 13:30 - 14:30 1.00 DRILL PULD PROD 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. 14:30 - 15:00 0.50 DRILL OTHR PROD Down load mwd & clean floor. 15:00 - 15:30 0.50 DRILL PULD PROD Lay down 2 part mwd & mud motor. 15:30 - 16:00 0.50 WELCTL BOPE PROD Pull wear ring-install test plug-rig up for bope test. 16:00 - 19:30 3.50 WELCTL BOPE PROD Test bope 250-5000# (witness test waived by aogcc.) 19:30 - 19:45 0.25 WELCTL BOPE PROD Install wear ring & rilds. 19:45 - 22:00 2.25 DRILL PULD PROD Make up bha #8-new mwd-program same-pulse test-install baffle 95' above bit. 22:00 - 00:00 2.00 DRILL TRIP PROD RIH to 5900'. 4/24/2003 00:00 - 01 :00 1.00 DRILL TRIP PROD RIH survey @ 7264' & 7357'. 01:00 - 01:15 0.25 DRILL OTHR PROD Service top drive & blocks. 01 :15 - 05:30 4.25 DRILL TRIP PROD RIH surveys @ 7 446-7539-7636-7734-7830-7926-8491-8975-9458-9941-1 0425-1 0908- 11392-11836. 05:30 - 08:45 3.25 DRILL CIRC PROD CBU-circ. pull 1 stand per hr. to 11637'. Printed: 6/25/2003 11 :01 :40 AM ) ) ConocoPhillips .Alaska Oþ~rationsSI.l mrnê:lryReport 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 From~To Hours Code · Sub Description of Operations Cdde 4/24/2003 08:45 - 09:45 1.00 DRILL TRIP PROD POH from 11637' to 10960'. 09:45 - 10:00 0.25 DRILL TRIP PROD RIH w/ hwdp to 11885'. 10:00 - 11 :00 1.00 DRILL CIRC PROD Circ. hole. 11 :00 - 00:00 13.00 DRILL DRLH PROD Drlg. horizontal hole L2 from 11900' to 12709'. (TVD 3799') AST .9 ART 4.8 ADT 5.7 PUW 140k SOW 54k RW 92k TO 9.5k on 9koff WOB 2/5k SPM 72 RPM 90 GPM 257 PP 1700# SPR #2 20spm 510# 30 spm 660#. 4/25/2003 00:00 - 07:30 7.50 DRILL DRLH PROD Drlg. horizontal hole L 1 from 12709' to 13110'. 07:30 - 09:30 2.00 DRILL TRIP PROD POH to 1 0969'-check for flow-stand back hwdp. 09:30 - 11 :00 1.50 DRILL TRIP PROD RIH w/ 10 stands 4" dp-put 10 stands hwdp on top. (Trip to move hwdp back up hole for drilling wt.) 11 :00 - 21 :00 10.00 DRILL DRLH PROD Drlg. horizontal hole from 13110' to 13626'. TVD 3813' AST .5 ART 7.6 ADT 8.1 PUW 150k SOW 35k RW 92k TO 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. 21 :00 - 21 :45 0.75 DRILL CIRC PROD Circ. for trip to stand back hwdp. 21 :45 - 22:30 0.75 DRILL TRIP PROD Pump out @ drlg. rate from 13626' to 13089' (back ream) 22:30 - 00:00 1.50 DRILL TRIP PROD POH on elevators w/ spiral wt. push pipe from 13089' to 12120'. 4/26/2003 00:00 - 01 :00 1.00 DRILL TRIP PROD RIH from 12120' to 13026'. 01 :00 - 01 :45 0.75 DRILL TRIP PROD Rotate & pump in hole from 13026' to 13626'. 01 :45 - 02:30 0.75 DRILL CIRC PROD Circ. condition hole to poh taking surveys. 02:30 - 17:00 14.50 DRILL TRIP PROD Pump & rotate out to 11900'. Survey as from 11900' to 7380 as directed-wipe sidetrack from 9060 'to 9040'. Pull thru window to 7300'. 17:00 - 17:45 0.75 DRILL CIRC PROD Pump weighted sweep & circ. to surface. 17:45 - 19:00 1.25 RIGMNT RSRV PROD Slip & cut 90' drlg. line-service top drive-blocks & inspect saver sub while evaluating surveys. 19:00 - 19:45 0.75 DRILL SURV PROD Pump & displace E-P lube sweep into 7 5/8" csg. 19:45 - 22:30 2.75 DRILL SURV PROD Orient hi-side & rih to 12766' on dp for E-Line gyro run. 22:30 - 00:00 1.50 DRILL SURV PROD Circ. & reciprocate while hanging sheave & rigging up E-Line. PJSM 4/27/2003 00:00 - 01 :00 1.00 DRILL SURV PROD PJSM-orient mwd & rig up to run gyro. 01 :00 - 06:30 5.50 DRILL SURV PROD Run gyro on sws E Line-pull same & rig down sws. 06:30 - 07:30 1.00 DRILL TRIP PROD RIH from 12776 to 13626'. 07:30 - 08:00 0.50 DRILL CIRC PROD Circ. bottoms up to shoe. 08:00 - 14:00 6.00 DRILL TRIP PROD Backream out of hole to 7300'. 14:00 - 15:30 1.50 DRILL CIRC PROD CBU X 2-monitor well-pump pill. 15:30 - 18:00 2.50 DRILL TRIP PROD POH to bha. 18:00 - 19:30 1.50 DRILL PULD PROD Lay down bha #8-down load mwd. 19:30 - 20:30 1.00 WINDOWPULD CMPL TN Pick up & make up whipstock retrieving tools. 20:30 - 21 :00 0.50 WINDOWfRIP CMPL TN RIH 10 stands swdc,s. 21 :00 - 21 :30 0.50 WINDOWfRIP CMPL TN Pick up 15 jts. 4" hwdp-single in hole. 21 :30 - 23:30 2.00 WINDOWfRIP CMPL TN RIH-SLM-no correction. 23:30 - 23:45 0.25 WINDOWOTHR CMPL TN Latch onto whipstock-shear @ 70k overpull. 23:45 - 00:00 0.25 WINDOWCIRC CMPL TN CBU. 4/28/2003 00:00 - 02:00 2.00 WINDOWCIRC CMPL TN CBU after releasing whipstock. Spot EP lube pill-check for flow-pump dry job-drop dp drift. 02:00 - 08:00 6.00 WINDOWfRIP CMPL TN POH slow-hole swabbing-check for flow. 08:00 - 09:00 1.00 WINDOWPULD CMPL TN Retrieve whipstock-lay down baker tools. 09:00 - 15:00 6.00 CASE PULR CMPL TN PJSM-rig up & run 205 jts. 4.5" Solid & slotted liner as per program. Make up flanged hook hanger. 15:00 - 21 :30 6.50 CASE RUNL CMPL TN RIH w/ liner on dp. 21 :30 - 22:00 0.50 CASE OTHR CMPL TN Engage hook hanger @ 7373' . PUW 138k SOW 71 k Prior to hooking hanger. 22:00 - 23:00 1.00 CASE OTHR CMPLTN 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 HoursCöde Sub·· . Phase 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 CMPLTN 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 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 CMPL TN 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 SEOT 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 Start: 4/4/2003 Rig Release: 5/1/2003 Rig Number: Spud Date: 4/2/2003 End: 5/1/2003 Group: Description of Operations 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 - LID 62 stds Dp ( + 1 LoT AD sublstd ) & LID 45 jts HWDP LID running tools ( Make all service breaks) TIH wI 67 stds DP out of derrick TOH - LID DP (LID 60 jts) Con't LID DP TIH wI 20 stds DP out of derrick TOH LID 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 TI H 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" LID 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 fl 10 min - Test 7.625" X 4.5"Ann to 3000 psi fl 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 B PV 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: 1 C-178 1 C-178 ROT - DRILLING n1334@ppco.com Doyon 141 ... .... .... Sub Hours Code Code Start: 4/4/2003 Rig Release: 5/1/2003 Rig Number: Spud Date: 4/2/2003 End: 5/1/2003 Group: From-To Phase· . . Description of Operations . 5/1/2003 06:00 - 07:30 1.50 CMPL TN NUND CMPL TN Tbg ...... Rig Release off 1 C - 178 @ 0730 hrs 05/01/2003 ........ Printed: 6/25/2003 11 :01 :40 AM ') ) 1C-178L1 DIRECTIONAL SURVEY API 500292314460 Survey Type: GYROSCOPIC Company: Survey Date: Survey Top: 0' MD Survey Btm: 13,626' MD Kickoff Depth: 1,224' MD Avg. Angle below KOP: 770 Max. Dogleg: 35.80/100' @ 7,366' MD Max. Angle: 95.50 @ 7,666' MD MD TVD SS CORR SS INCLINE AZIMUTH DOGLEG ASP X ASPY 0 0.00 87.20 87.20 0.00 0.00 0.0 562,201.8 5,968,734.9 110 110.00 -22.80 -22.80 0.00 0.00 0.0 562,201.8 5,968,734.9 204 204.01 -116.81 -116.81 0.64 42.75 0.7 562,202.2 5,968,735.3 297 296.78 -209.58 -209.58 0.44 306.45 0.9 562,202.3 5,968,735.9 389 389.10 -301.90 -301.90 3.02 258.54 3.0 562,199.6 5,968,735.6 483 482.47 -395.27 -395.27 4.73 259.52 1.8 562,193.4 5,968,734.3 571 570.78 -483.58 -483.58 5.90 246.99 1.9 562,185.6 5,968,731.8 668 666.11 -578.91 -578.91 8.39 247.99 2.6 562,174.6 5,968,727.2 759 756.30 -669.10 -669.10 10.98 249.39 2.8 562,160.3 5,968,721.5 851 846.36 -759.16 -759.16 11.98 249.19 1.1 562,143.3 5,968,714.9 944 937.07 -849.87 -849.87 15.29 248.62 3.6 562,122.8 5,968,706.8 1,036 1,024.61 -937.41 -937.41 20.57 249.72 5.8 562,096.4 5,968,696.5 1,130 1,110.78 -1,023.58 -1,023.58 26.41 255.42 6.7 562,060.7 5,968,685.2 1,224 1,193.67 -1,106.47 -1,106.47 29.51 263.23 5.1 562,017.6 5,968,676.9 1,320 1,275.96 -1,188.76 -1,188.76 32.25 266.52 3.4 561,968.7 5,968,672.2 1,413 1,351.58 -1 ,264.38 -1 ,264.38 38.17 269.94 6.7 561,915.4 5,968,670.2 1,505 1,420.94 -1,333.74 -1,333.74 45.11 275.94 8.6 561,853.9 5,968,673.1 1,598 1,484.45 -1,397.25 -1,397.25 48.14 279.13 4.1 561,787.2 5,968,681.4 1,692 1,544.86 -1,457.66 -1,457.66 51.64 282.20 4.5 561,716.6 5,968,694.1 1,786 1,600.39 -1,513.19 -1,513.19 56.53 285.16 5.8 561,642.0 5,968,711.7 1,879 1,646.33 -1,559.13 -1,559.13 64.00 287.48 8.4 561,564.7 5,968,733.7 1,973 1,686.17 -1,598.97 -1,598.97 66.05 287.25 2.2 561,482.8 5,968,758.5 2,066 1,723.71 -1,636.51 -1,636.51 66.20 288.20 1.0 561,401.9 5,968,783.7 2,159 1,761.09 -1,673.89 -1,673.89 66.51 288.63 0.5 561,320.6 5,968,810.0 2,252 1,798.84 -1,711.64 -1,711.64 65.15 288.82 1.5 561,240.8 5,968,836.3 2,345 1,837.89 -1,750.69 -1,750.69 65.53 288.20 0.7 561,159.9 5,968,862.6 2,438 1,875.62 -1,788.42 -1,788.42 66.79 287.90 1.4 561,078.5 5,968,888.4 2,531 1,912.58 -1 ,825.38 -1,825.38 66.01 288.74 1.2 560,998.0 5,968,914.3 2,627 1,951.70 -1 ,864.50 -1,864.50 65.81 288.56 0.3 560,914.8 5,968,941.6 2,732 1,994.36 -1,907.16 -1,907.16 66.43 290.11 1.5 560,823.6 5,968,972.8 2,827 2,032.14 -1,944.94 -1,944.94 66.62 290.73 0.6 560,741.9 5,969,002.5 2,914 2,066.57 -1,979.37 -1,979.37 66.73 289.78 1.0 560,666.7 5,969,029.5 3,005 2,103.13 -2,015.93 -2,015.93 66.11 288.45 1.5 560,587.4 5,969,056.3 3,098 2,140.18 -2,052.98 -2,052.98 66.89 287.35 1.4 560,506.1 5,969,081.8 3,191 2,176.83 -2,089.63 -2,089.63 66.85 286.24 1.1 560,423.7 5,969,105.9 3,286 2,213.93 -2,126.73 -2,126.73 66.88 285.13 1.1 560,339.9 5,969,128.7 3,380 2,251.10 -2,163.90 -2,163.90 66.77 284.69 0.4 560,255.8 5,969,150.3 3,475 2,288.44 -2,201.24 -2,201.24 66.75 285.09 0.4 560,171.6 5,969,172.0 3,566 2,324.37 -2,237.17 -2,237.17 66.71 284.63 0.5 560,090.7 5,969,192.7 3,662 2,362.34 -2,275.14 -2,275.14 66.77 284.52 0.1 560,005.0 5,969,214.2 3,755 2,399.12 -2,311.92 -2,311.92 66.79 284.66 0.1 559,921.9 5,969,235.1 3,849 2,435.89 -2,348.69 -2,348.69 66.78 283.37 1.3 559,838.5 5,969,255.2 3,942 2,472.78 -2,385.58 -2,385.58 66.72 284.59 1.2 559,755.1 5,969,275.3 4,036 2,509.44 -2,422.24 -2,422.24 67.36 284.93 0.8 559,671.2 5,969,296.6 4,130 2,545.60 -2,458.40 -2,458.40 67.18 286.57 1.6 559,588.0 5,969,319.3 4,223 2,581.80 -2,494.60 -2,494.60 67.14 286.71 0.1 559,505.4 5,969,343.3 4,316 2,618.01 -2,530.81 -2,530.81 67.11 285.53 1.2 559,422.7 5,969,366.4 4,409 2,654.15 -2,566.95 -2,566.95 67.31 286.05 0.6 559,339.8 5,969,389.1 4,503 2,690.40 -2,603.20 -2,603.20 67.25 287.60 1.5 559,256.7 5,969,413.5 4,596 2,726.32 -2,639.12 -2,639.12 67.07 287.55 0.2 559,175.2 5,969,438.6 4,690 2,762.95 -2,675.75 -2,675.75 67.29 287.73 0.3 559,092.0 5,969,464.3 4,783 2,798.71 -2,711.51 -2,711.51 67.32 288.04 0.3 559,010.4 5,969,489.9 4,877 2,834.02 -2,746.82 -2,746.82 68.55 291.47 3.6 558,928.3 5,969,518.6 4,970 2,868.41 -2,781.21 -2,781.21 68.38 292.90 1.4 558,847.3 5,969,550.9 5,063 2,902.63 -2,815.43 -2,815.43 68.40 291 .79 1.1 558,767.1 5,969,583.0 Page 1 of 6 ) ) 1C-178l1 DIRECTIONAL SURVEY MD TVD SS CORR SS INCLINE AZIMUTH DOGLEG ASP X ASPY 5,157 2,937.25 -2,850.05 -2,850.05 68.34 292.35 0.6 558,686.0 5,969,615.2 5,249 2,971.23 -2,884.03 -2,884.03 68.41 293.92 1.6 558,606.9 5,969,648.2 5,345 3,006.51 -2,919.31 -2,919.31 68.37 294.67 0.7 558,525.4 5,969,684.2 5,438 3,040.62 -2,953.42 -2,953.42 68.41 296.06 1.4 558,447.3 5,969,720.4 5,531 3,075.05 -2,987.85 -2,987.85 68.32 296.55 0.5 558,369.2 5,969,758.2 5,625 3,109.50 -3,022.30 -3,022.30 68.44 296.10 0.5 558,290.9 5,969,796.1 5,717 3,143.47 -3,056.27 -3,056.27 68.45 294.60 1.5 558,212.9 5,969,832.3 5,811 3,178.01 -3,090.81 -3,090.81 68.41 294.01 0.6 558,133.0 5,969,867.6 5,905 3,212.74 -3,125.54 -3,125.54 68.14 293.54 0.6 558,052.9 5,969,902.1 5,998 3,247.37 -3,160.17 -3,160.17 68.34 293.29 0.3 557,973.0 5,969,935.9 6,092 3,281.72 -3,194.52 -3,194.52 68.46 295.46 2.2 557,893.7 5,969,971.0 6,186 3,315.53 -3,228.33 -3,228.33 69.27 297.04 1.8 557,815.0 5,970,009.1 6,279 3,348.22 -3,261.02 -3,261.02 69.60 299.44 2.4 557,737.9 5,970,049.6 6,372 3,380.78 -3,293.58 -3,293.58 69.56 300.46 1.0 557,661.8 5,970,092.7 6,465 3,413.27 -3,326.07 -3,326.07 69.66 300.34 0.2 557,586.0 5,970,136.3 6,559 3,445.95 -3,358.75 -3,358.75 69.62 300.15 0.2 557,509.6 5,970,180.0 6,652 3,478.36 -3,391.16 -3,391.16 69.66 300.01 0.2 557,433.6 5,970,223.2 6,745 3,510.76 -3,423.56 -3,423.56 69.59 303.55 3.6 557,359.1 5,970,268.5 6,839 3,542.80 -3,455.60 -3,455.60 70.31 307.15 3.7 557,287.1 5,970,318.6 6,933 3,574.10 -3,486.90 -3,486.90 70.73 310.68 3.6 557,217.9 5,970,373.6 7,026 3,605.17 -3,517.97 -3,517.97 70.44 316.42 5.8 557,153.6 5,970,433.7 7,119 3,635.57 -3,548.37 -3,548.37 71.52 323.15 6.9 557,096.2 5,970,500.5 7,213 3,663.76 -3,576.56 -3,576.56 73.52 329.87 7.2 557,046.3 5,970,574.6 7,306 3,689.11 -3,601.91 -3,601.91 74.83 334.53 5.0 557,003.9 5,970,653.4 7,361 3,703.42 -3,616.22 -3,616.22 75.13 336.98 4.3 556,981.7 5,970,701.8 7,367 3,704.76 -3,617.56 -3,617.56 76.62 338.31 35.83 556,979.6 5,970,706.7 7,382 3,708.24 -3,621.04 -3,621.04 76.89 338.46 2.0 556,974.0 5,970,720.4 7,400 3,712.20 -3,625.00 -3,625.00 77.69 337.77 5.8 556,967.3 5,970,736.6 7,417 3,715.56 -3,628.36 -3,628.36 79.66 336.87 12.6 556,960.7 5,970,752.1 7,432 3,718.23 -3,631.03 -3,631.03 79.72 337.29 2.8 556,954.9 5,970,765.5 7,449 3,721.32 -3,634.12 -3,634.12 79.97 338.13 4.9 556,948.3 5,970,781.4 7,467 3,724.27 -3,637.07 -3,637.07 80.70 338.63 5.0 556,941.7 5,970,797.5 7,482 3,726.53 -3,639.33 -3,639.33 81.77 339.27 8.4 556,936.4 5,970,811.1 7,499 3,728.82 -3,641.62 -3,641.62 82.99 340.43 9.7 556,930.3 5,970,827.1 7,517 3,730.84 -3,643.64 -3,643.64 84.10 341 .44 8.3 556,924.3 5,970,844.0 7,532 3,732.14 -3,644.94 -3,644.94 85.98 342.86 15.7 556,919.6 5,970,858.2 7,549 3,733.18 -3,645.98 -3,645.98 86.82 344.58 11.5 556,914.9 5,970,874.0 7,566 3,734.06 -3,646.86 -3,646.86 87.48 345.70 7.4 556,910.2 5,970,891.0 7,582 3,734.57 -3,647.37 -3,647.37 88.82 346.77 10.8 556,906.3 5,970,906.4 7,600 3,734.33 -3,647.13 -3,647.13 92.73 348.68 24.58 556,902.4 5,970,923.6 7,617 3,733.18 -3,645.98 -3,645.98 94.94 349.59 13.9 556,899.0 5,970,940.5 7,619 3,733.02 -3,645.82 -3,645.82 95.03 349.67 6.7 556,898.7 5,970,942.2 7,641 3,731.09 -3,643.89 -3,643.89 95.05 349.96 1.3 556,894.6 5,970,963.8 7,666 3,728.78 -3,641.58 -3,641.58 95.49 350.07 1.8 556,890.1 5,970,988.4 7,690 3,726.76 -3,639.56 -3,639.56 94.33 350.33 5.0 556,885.9 5,971,011.6 7,716 3,725.02 -3,637.82 -3,637.82 93.13 350.71 4.7 556,881.3 5,971,037.8 7,741 3,723.75 -3,636.55 -3,636.55 92.87 350.87 1.3 556,877.2 5,971,061.7 7,767 3,722.47 -3,635.27 -3,635.27 92.78 350.83 0.4 556,872.9 5,971,087.3 7,791 3,721.24 -3,634.04 -3,634.04 92.94 350.66 1.0 556,868.7 5,971,111.6 7,816 3,719.88 -3,632.68 -3,632.68 93.27 350.73 1.3 556,864.5 5,971,136.3 7,840 3,718.47 -3,631.27 -3,631.27 93.62 350.68 1.5 556,860.5 5,971,159.4 7,866 3,716.88 -3,629.68 -3,629.68 93.19 350.85 1.7 556,856.0 5,971,185.6 7,891 3,715.88 -3,628.68 -3,628.68 91.55 351.43 7.2 556,852.1 5,971,209.5 7,916 3,715.31 -3,628.11 -3,628.11 91.00 351.82 2.6 556,848.1 5,971,235.0 7,941 3,714.91 -3,627.71 -3,627.71 90.86 352.13 1.4 556,844.5 5,971,259.3 7,966 3,714.46 -3,627.26 -3,627.26 91.20 352.36 1.6 556,840.8 5,971,284.4 7,989 3,714.04 -3,626.84 -3,626.84 90.86 352.25 1.6 556,837.5 5,971,307.2 8,016 3,713.75 -3,626.55 -3,626.55 90.39 352.18 1.8 556,833.7 5,971,333.5 8,040 3,713.54 -3,626.34 -3,626.34 90.59 352.44 1.4 556,830.3 5,971,357.6 8,067 3,713.30 -3,626.10 -3,626.10 90.45 352.63 0.9 556,826.7 5,971,383.5 8,091 3,713.05 -3,625.85 -3,625.85 90.70 352.75 1.1 556,823.3 5,971,408.2 8,117 3,712.93 -3,625.73 -3,625.73 89.86 352.86 3.3 556,819.9 5,971 ,433.5 8,139 3,713.17 -3,625.97 -3,625.97 88.92 352.74 4.2 556,816.9 5,971,455.7 8,166 3,713.65 -3,626.45 -3,626.45 89.02 352.88 0.7 556,813.3 5,971,482.0 8,190 3,714.06 -3,626.86 -3,626.86 89.00 353.06 0.8 556,810.2 5,971,505.8 Page 2 of 6 ) ) 1C-178L1 DIRECTIONAL SURVEY MD TVD SS CORR S5 INCLINE AZIMUTH DOGLEG ASP X ASPY 8,216 3,714.62 -3,627.42 -3,627.42 88.51 353.32 2.1 556,806.9 5,971,531.6 8,241 3,715.31 -3,628.11 -3,628.11 88.33 353.68 1.6 556,803.8 5,971,556.6 8,267 3,715.88 -3,628.68 -3,628.68 89.09 354.45 4.3 556,801.0 5,971,581.9 8,292 3,716.06 -3,628.86 -3,628.86 90.10 355.32 5.3 556,798.5 5,971,607.1 8,316 3,715.93 -3,628.73 -3,628.73 90.52 355.63 2.1 556,796.4 5,971,631.5 8,341 3,715.84 -3,628.64 -3,628.64 89.88 355.81 2.7 556,794.3 5,971,656.4 8,366 3,715.84 -3,628.64 -3,628.64 90.10 356.05 1.3 556,792.4 5,971,681.3 8,390 3,715.88 -3,628.68 -3,628.68 89.73 356.13 1.6 556,790.5 5,971,705.1 8,416 3,715.95 -3,628.75 -3,628.75 89.95 356.42 1.4 556,788.6 5,971,730.9 8,440 3,715.97 -3,628.77 -3,628.77 89.95 356.47 0.2 556,786.9 5,971,755.1 8,466 3,715.92 -3,628.72 -3,628.72 90.26 355.84 2.7 556,785.0 5,971,780.9 8,491 3,715.74 -3,628.54 -3,628.54 90.59 355.54 1.8 556,782.9 5,971,805.6 8,516 3,715.57 -3,628.37 -3,628.37 90.18 355.65 1.7 556,780.8 5,971,830.7 8,541 3,715.45 -3,628.25 -3,628.25 90.39 355.96 1.5 556,778.8 5,971,855.4 8,566 3,715.24 -3,628.04 -3,628.04 90.59 355.82 1.0 556,776.8 5,971,880.4 8,592 3,715.30 -3,628.10 -3,628.10 89.13 354.54 7.6 556,774.4 5,971,905.9 8,616 3,715.95 -3,628.75 -3,628.75 87.84 353.56 6.6 556,771.7 5,971,930.2 8,641 3,716.89 -3,629.69 -3,629.69 87.80 353.44 0.5 556,768.7 5,971,954.6 8,666 3,717.57 -3,630.37 -3,630.37 89.13 353.64 5.3 556,765.6 5,971,979.6 8,666 3,717.58 -3,630.38 -3,630.38 89.06 353.64 17.5 556,765.6 5,971,980.0 8,692 3,717.80 -3,630.60 -3,630.60 89.94 353.68 3.5 556,762.6 5,972,005.1 8,717 3,717.92 -3,630.72 -3,630.72 89.53 353.60 1.7 556,759.6 5,972,030.1 8,740 3,718.18 -3,630.98 -3,630.98 89.19 353.53 1.5 556,756.8 5,972,053.2 8,766 3,718.28 -3,631.08 -3,631.08 90.37 353.57 4.6 556,753.7 5,972,078.8 8,766 3,718.28 -3,631.08 -3,631.08 90.39 353.56 4.5 556,753.6 5,972,079.3 8,791 3,718.03 -3,630.83 -3,630.83 90.78 353.51 1.6 556,750.7 5,972,103.6 8,817 3,717.79 -3,630.59 -3,630.59 90.27 353.28 2.2 556,747.5 5,972,129.2 8,842 3,717.90 -3,630.70 -3,630.70 89.23 353.30 4.2 556,744.4 5,972,154.0 8,867 3,718.01 -3,630.81 -3,630.81 90.27 353.48 4.2 556,741.3 5,972,178.9 8,892 3,717.88 -3,630.68 -3,630.68 90.34 353.29 0.8 556,738.2 5,972,203.8 8,917 3,717.92 -3,630.72 -3,630.72 89.49 353.42 3.5 556,735.1 5,972,228.4 8,941 3,718.36 -3,631.16 -3,631.16 88.43 352.82 5.0 556,732.0 5,972,252.5 8,966 3,719.20 -3,632.00 -3,632.00 87.68 351.28 6.9 556,728.4 5,972,276.9 8,991 3,720.13 -3,632.93 -3,632.93 88.04 350.66 2.9 556,724.2 5,972,301.6 9,016 3,720.91 -3,633.71 -3,633.71 88.39 350.90 1.7 556,720.0 5,972,326.4 9,017 3,720.94 -3,633.74 -3,633.74 88.39 350.88 2.0 556,719.8 5,972,327.4 9,042 3,721.82 -3,634.62 -3,634.62 87.64 350.88 3.0 556,715.6 5,972,352.3 9,067 3,723.11 -3,635.91 -3,635.91 86.42 350.69 5.0 556,711.4 5,972,376.8 9,090 3,724.71 -3,637.51 -3,637.51 85.76 350.80 2.9 556,707.5 5,972,399.8 9,116 3,726.58 -3,639.38 -3,639.38 85.77 351 .22 1.7 556,703.3 5,972,424.7 9,118 3,726.72 -3,639.52 -3,639.52 85.99 351 .26 11.2 556,703.0 5,972,426.7 9,142 3,728.24 -3,641.04 -3,641.04 86.91 351.97 4.7 556,699.2 5,972,451.0 9,167 3,729.43 -3,642.23 -3,642.23 87.53 352.69 3.9 556,695.8 5,972,475.3 9,168 3,729.46 -3,642.26 -3,642.26 87.51 352.70 3.7 556,695.7 5,972,475.9 9,192 3,730.43 -3,643.23 -3,643.23 87.99 352.91 2.1 556,692.4 5,972,500.2 9,217 3,731.09 -3,643.89 -3,643.89 88.94 353.38 4.3 556,689.2 5,972,524.7 9,217 3,731.10 -3,643.90 -3,643.90 88.92 353.38 3.3 556,689.2 5,972,525.3 9,242 3,731.42 -3,644.22 -3,644.22 89.63 353.68 3.1 556,686.1 5,972,550.1 9,267 3,731.43 -3,644.23 -3,644.23 90.30 354.03 3.1 556,683.3 5,972,574.5 9,267 3,731.43 -3,644.23 -3,644.23 90.21 354.02 18.1 556,683.3 5,972,575.0 9,292 3,731.30 -3,644.10 -3,644.10 90.37 354.25 1.1 556,680.5 5,972,599.7 9,317 3,731.12 -3,643.92 -3,643.92 90.49 354.23 0.5 556,677.8 5,972,624.2 9,342 3,730.97 -3,643.77 -3,643.77 90.22 354.49 1.5 556,675.2 5,972,648.7 9,366 3,730.85 -3,643.65 -3,643.65 90.34 354.83 1.5 556,672.7 5,972,673.2 9,367 3,730.84 -3,643.64 -3,643.64 90.43 354.87 9.9 556,672.6 5,972,674.2 9,392 3,730.52 -3,643.32 -3,643.32 91.04 355.16 2.7 556,670.3 5,972,698.8 9,417 3,730.09 -3,642.89 -3,642.89 90.93 355.36 0.9 556,668.0 5,972,723.9 9,442 3,729.61 -3,642.41 -3,642.41 91.30 355.58 1.8 556,665.8 5,972,748.4 9,466 3,729.09 -3,641.89 -3,641.89 91.09 355.68 0.9 556,663.7 5,972,773.0 9,479 3,728.81 -3,641.61 -3,641.61 91.37 355.73 2.2 556,662.7 5,972,785.9 9,500 3,728.41 -3,641.21 -3,641.21 90.86 356.01 2.8 556,661.0 5,972,806.6 9,516 3,728.22 -3,641.02 -3,641.02 90.59 355.79 2.3 556,659.8 5,972,822.0 9,517 3,728.21 -3,641.01 -3,641.01 90.43 355.76 18.1 556,659.7 5,972,822.9 9,523 3,728.16 -3,640.96 -3,640.96 90.46 355.51 3.8 556,659.1 5,972,829.6 9,542 3,728.09 -3,640.89 -3,640.89 89.96 355.05 3.7 556,657.5 5,972,847.8 Page 3 of 6 ) ) 1C-178L1 DIRECTIONAL SURVEY MD TVD SS CORR SS INCLINE AZIMUTH DOGLEG ASP X ASPY 9,566 3,728.15 -3,640.95 -3,640.95 89.77 354.78 1.3 556,655.1 5,972,872.6 9,589 3,728.21 -3,641.01 -3,641.01 89.93 354.97 1.1 556,652.9 5,972,894.9 9,617 3,728.28 -3,641.08 -3,641.08 89.78 355.10 0.7 556,650.2 5,972,922.5 9,638 3,728.36 -3,641.16 -3,641.16 89.79 355.20 0.5 556,648.2 5,972,944.1 9,666 3,728.50 -3,641.30 -3,641.30 89.64 355.43 1.0 556,645.7 5,972,971.6 9,688 3,728.72 -3,641.52 -3,641.52 89.23 355.68 2.1 556,643.8 5,972,994.0 9,717 3,729.02 -3,641.82 -3,641.82 89.55 355.04 2.5 556,641.3 5,973,022.2 9,738 3,729.17 -3,641.97 -3,641.97 89.65 354.60 2.2 556,639.2 5,973,042.9 9,766 3,729.43 -3,642.23 -3,642.23 89.31 354.42 1.4 556,636.3 5,973,071.4 9,787 3,729.70 -3,642.50 -3,642.50 89.24 354.43 0.3 556,634.0 5,973,092.5 9,816 3,730.27 -3,643.07 -3,643.07 88.47 354.55 2.7 556,631.0 5,973,121.0 9,840 3,730.93 -3,643.73 -3,643.73 88.34 354.78 1.1 556,628.6 5,973,144.6 9,867 3,731.81 -3,644.61 -3,644.61 87.94 354.93 1.6 556,626.0 5,973,171.6 9,890 3,732.56 -3,645.36 -3,645.36 88.28 355.14 1.8 556,623.8 5,973,194.2 9,917 3,733.01 -3,645.81 -3,645.81 89.82 355.19 5.7 556,621.3 5,973,221.3 9,939 3,732.93 -3,645.73 -3,645.73 90.60 355.23 3.5 556,619.3 5,973,243.3 9,967 3,732.72 -3,645.52 -3,645.52 90.27 355.53 1.6 556,616.8 5,973,271.3 9,988 3,732.54 -3,645.34 -3,645.34 90.69 355.68 2.1 556,615.0 5,973,292.5 10,017 3,732.45 -3,645.25 -3,645.25 89.69 355.25 3.8 556,612.5 5,973,320.8 10,038 3,732.70 -3,645.50 -3,645.50 89.00 354.38 5.1 556,610.4 5,973,342.4 10,066 3,733.22 -3,646.02 -3,646.02 88.86 352.92 5.3 556,607.1 5,973,369.9 10,089 3,733.59 -3,646.39 -3,646.39 89.31 352.68 2.2 556,604.0 5,973,392.9 10,117 3,733.79 -3,646.59 -3,646.59 89.86 352.71 2.0 556,600.3 5,973,420.0 10,139 3,733.79 -3,646.59 -3,646.59 90.15 353.00 1.9 556,597.3 5,973,442.0 10,167 3,733.70 -3,646.50 -3,646.50 90.20 353.21 0.8 556,593.7 5,973,469.8 10,188 3,733.66 -3,646.46 -3,646.46 90.04 353.27 0.8 556,591.1 5,973,490.7 10,217 3,733.38 -3,646.18 -3,646.18 91.08 353.02 3.7 556,587.4 5,973,519.1 10,239 3,733.22 -3,646.02 -3,646.02 89.73 352.07 7.3 556,584.3 5,973,541.4 10,267 3,733.57 -3,646.37 -3,646.37 88.83 351 .18 4.6 556,580.1 5,973,568.7 10,290 3,734.05 -3,646.85 -3,646.85 88.77 351 .16 0.3 556,576.3 5,973,591.4 10,317 3,734.65 -3,647.45 -3,647.45 88.71 351.21 0.3 556,572.0 5,973,618.2 10,338 3,734.98 -3,647.78 -3,647.78 89.51 351 .18 3.8 556,568.5 5,973,639.2 10,365 3,734.91 -3,647.71 -3,647.71 90.78 351.07 4.7 556,564.1 5,973,666.0 10,388 3,734.50 -3,647.30 -3,647.30 91.26 351 .24 2.2 556,560.4 5,973,688.7 10,417 3,733.88 -3,646.68 -3,646.68 91.25 351.52 1.0 556,555.9 5,973,716.8 1 0,439 3,733.52 -3,646.32 -3,646.32 90.66 351.66 2.8 556,552.5 5,973,738.3 10,466 3,733.20 -3,646.00 -3,646.00 90.67 351 .64 0.1 556,548.3 5,973,765.7 10,490 3,732.99 -3,645.79 -3,645.79 90.35 351 .63 1.4 556,544.7 5,973,788.6 10,517 3,732.82 -3,645.62 -3,645.62 90.37 351.29 1.3 556,540.5 5,973,815.3 10,540 3,732.82 -3,645.62 -3,645.62 89.64 350.58 4.4 556,536.7 5,973,837.9 10,567 3,733.21 -3,646.01 -3,646.01 88.71 350.24 3.6 556,531.9 5,973,864.8 10,588 3,733.63 -3,646.43 -3,646.43 89.06 349.98 2.0 556,528.0 5,973,886.1 10,616 3,733.58 -3,646.38 -3,646.38 91.15 349.72 7.5 556,522.9 5,973,913.6 10,640 3,732.91 -3,645.71 -3,645.71 92.17 349.90 4.5 556,518.5 5,973,936.5 10,666 3,732.01 -3,644.81 -3,644.81 91.68 349.37 2.7 556,513.5 5,973,962.7 10,689 3,731.84 -3,644.64 -3,644.64 89.18 347.57 13.6 556,508.8 5,973,984.9 10,717 3,732.27 -3,645.07 -3,645.07 89.03 346.87 2.6 556,502.4 5,974,011.9 10,741 3,732.74 -3,645.54 -3,645.54 88.72 346.73 1.4 556,496.8 5,974,035.0 10,767 3,733.21 -3,646.01 -3,646.01 89.23 346.92 2.1 556,490.6 5,974,060.5 10,790 3,733.31 -3,646.11 -3,646.11 90.26 347.03 4.6 556,485.3 5,974,082.6 10,817 3,733.23 -3,646.03 -3,646.03 90.09 347.29 1.1 556,479.0 5,974,109.2 10,838 3,733.25 -3,646.05 -3,646.05 89.80 347.37 1.4 556,474.2 5,974,130.0 10,866 3,733.45 -3,646.25 -3,646.25 89.37 347.62 1.8 556,467.9 5,974,157.4 10,890 3,733.61 -3,646.41 -3,646.41 89.84 347.94 2.4 556,462.6 5,974,180.6 10,917 3,733.71 -3,646.51 -3,646.51 89.71 348.22 1.2 556,456.9 5,974,206.5 10,939 3,733.72 -3,646.52 -3,646.52 90.22 348.91 3.9 556,452.4 5,974,228.1 10,967 3,733.50 -3,646.30 -3,646.30 90.70 349.81 3.7 556,447.0 5,974,255.3 10,991 3,733.30 -3,646.10 -3,646.10 90.24 350.03 2.1 556,442.6 5,974,279.0 11,017 3,733.23 -3,646.03 -3,646.03 90.07 350.44 1.7 556,438.0 5,974,304.7 11,040 3,733.00 -3,645.80 -3,645.80 91.10 350.94 5.0 556,434.1 5,974,327.1 11,067 3,732.33 -3,645.13 -3,645.13 91.69 351 .38 2.7 556,429.7 5,974,354.1 11,088 3,731.84 -3,644.64 -3,644.64 90.94 350.83 4.4 556,426.2 5,974,375.2 11,116 3,731.40 -3,644.20 -3,644.20 90.87 350.42 1.5 556,421.4 5,974,402.7 11 , 140 3,731.04 -3,643.84 -3,643.84 90.86 350.85 1.8 556,417.4 5,974,426.0 11,166 3,730.68 -3,643.48 -3,643.48 90.71 350.99 0.8 556,413.0 5,974,452.1 Page 4 of 6 ) ') 1C-178L1 DIRECTIONAL SURVEY MD TVD SS CORR SS INCLINE AZIMUTH DOGLEG ASP X ASPY 11 ,1 89 3,730.69 -3,643.49 -3,643.49 89.25 351.16 6.5 556,409.3 5,974,474.5 11,217 3,731.40 -3,644.20 -3,644.20 87.81 351.86 5.8 556,405.0 5,974,501.9 11,241 3,732.28 -3,645.08 -3,645.08 88.05 352.61 3.2 556,401.5 5,974,525.9 11 ,267 3,732.92 -3,645.72 -3,645.72 89.11 353.39 5.1 556,398.1 5,974,551.5 11 ,290 3,733.36 -3,646.16 -3,646.16 88.65 353.83 2.8 556,395.4 5,974,574.0 11 ,317 3,734.39 -3,647.19 -3,647.19 86.96 353.59 6.3 556,392.2 5,974,600.8 11 ,341 3,735.75 -3,648.55 -3,648.55 86.59 353.72 1.6 556,389.4 5,974,624.7 11 ,367 3,737.33 -3,650.13 -3,650.13 86.54 353.60 0.5 556,386.3 5,974,650.8 11 ,392 3,738.93 -3,651.73 -3,651.73 86.19 353.89 1.8 556,383.3 5,974,675.8 11,417 3,740.51 -3,653.31 -3,653.31 86.47 354.36 2.2 556,380.6 5,974,700.3 11 ,440 3,741.56 -3,654.36 -3,654.36 88.25 354.68 7.9 556,378.2 5,974,723.0 11 ,467 3,742.40 -3,655.20 -3,655.20 88.17 354.84 0.7 556,375.5 5,974,749.7 11,491 3,743.22 -3,656.02 -3,656.02 88.01 355.23 1.7 556,373.2 5,974,774.1 11,517 3,743.88 -3,656.68 -3,656.68 89.07 355.15 4.1 556,370.9 5,974,799.8 11,539 3,744.07 -3,656.87 -3,656.87 89.98 354.73 4.5 556,368.7 5,974,822.2 11 ,567 3,744.08 -3,656.88 -3,656.88 89.96 354.68 0.2 556,365.9 5,974,849.3 11 ,590 3,744.19 -3,656.99 -3,656.99 89.52 355.03 2.4 556,363.7 5,974,872.4 11,616 3,744.27 -3,657.07 -3,657.07 90.12 354.78 2.5 556,361.1 5,974,898.2 11,640 3,744.24 -3,657.04 -3,657.04 90.02 354.53 1.1 556,358.7 5,974,922.6 11 ,667 3,744.08 -3,656.88 -3,656.88 90.70 354.27 2.8 556,355.9 5,974,948.6 11 ,690 3,743.72 -3,656.52 -3,656.52 91.09 353.68 3.1 556,353.3 5,974,971.5 11,716 3,743.34 -3,656.14 -3,656.14 90.56 353.63 2.0 556,350.1 5,974,997.9 11,741 3,742.98 -3,655.78 -3,655.78 91.10 353.74 2.2 556,347.2 5,975,022.5 11,766 3,742.46 -3,655.26 -3,655.26 91.24 353.79 0.6 556,344.2 5,975,047.7 11 ,790 3,741.96 -3,654.76 -3,654.76 91.24 353.93 0.6 556,341.6 5,975,070.8 11,817 3,741.39 -3,654.19 -3,654.19 91.18 353.80 0.5 556,338.5 5,975,097.6 11 ,841 3,740.99 -3,653.79 -3,653.79 90.71 353.81 2.0 556,335.7 5,975,121.4 11 ,866 3,740.83 -3,653.63 -3,653.63 90.00 353.69 2.8 556,332.7 5,975,146.6 11,867 3,740.83 -3,653.63 -3,653.63 89.99 353.67 2.0 556,332.6 5,975,147.7 11,893 3,740.63 -3,653.43 -3,653.43 90.87 352.30 6.2 556,329.1 5,975,173.7 11,917 3,740.30 -3,653.10 -3,653.10 90.77 351.76 2.4 556,325.7 5,975,196.9 11,932 3,740.07 -3,652.87 -3,652.87 90.92 351.71 1.0 556,323.4 5,975,212.2 11,950 3,739.73 -3,652.53 -3,652.53 91.27 351.91 2.3 556,320.7 5,975,229.9 11 ,966 3,739.36 -3,652.16 -3,652.16 91.29 351 .68 1.4 556,318.2 5,975,246.1 11 ,969 3,739.29 -3,652.09 -3,652.09 91.50 351.64 7.9 556,317.8 5,975,248.7 11,986 3,738.92 -3,651.72 -3,651.72 91.05 351.21 3.8 556,315.2 5,975,265.1 12,003 3,738.63 -3,651.43 -3,651.43 90.87 350.93 1.9 556,312.3 5,975,282.3 12,011 3,738.55 -3,651.35 -3,651.35 90.33 350.84 6.9 556,311.0 5,975,290.1 12,026 3,738.44 -3,651.24 -3,651.24 90.52 349.42 9.7 556,308.3 5,975,304.7 12,078 3,738.62 -3,651.42 -3,651.42 89.08 352.24 6.1 556,299.6 5,975,356.2 12,122 3,739.57 -3,652.37 -3,652.37 88.44 350.82 3.5 556,292.7 5,975,399.8 12,172 3,741.19 -3,653.99 -3,653.99 87.79 351.92 2.6 556,284.9 5,975,448.4 12,217 3,742.99 -3,655.79 -3,655.79 87.64 348.61 7.3 556,276.9 5,975,492.8 12,267 3,744.61 -3,657.41 -3,657.41 88.65 350.83 4.9 556,267.6 5,975,542.0 12,314 3,745.85 -3,658.65 -3,658.65 88.37 349.55 2.8 556,259.1 5,975,588.9 12,363 3,746.58 -3,659.38 -3,659.38 89.88 347.84 4.7 556,249.3 5,975,636.0 12,409 3,746.57 -3,659.37 -3,659.37 90.15 346.43 3.1 556,238.6 5,975,680.9 12,456 3,746.90 -3,659.70 -3,659.70 89.05 348.11 4.3 556,227.9 5,975,726.6 12,509 3,748.23 -3,661.03 -3,661.03 88.07 346.80 3.1 556,216.0 5,975,778.1 12,542 3,749.61 -3,662.41 -3,662.41 87.15 346.94 2.8 556,208.2 5,975,810.4 12,605 3,752.10 -3,664.90 -3,664.90 88.34 349.64 4.7 556,194.8 5,975,872.2 12,652 3,753.11 -3,665.91 -3,665.91 89.23 347.51 4.9 556,185.0 5,975,918.6 12,700 3,753.38 -3,666.18 -3,666.18 90.12 348.59 2.9 556,174.8 5,975,965.1 12,751 3,753.13 -3,665.93 -3,665.93 90.43 348.15 1.1 556,164.0 5,976,015.3 12,797 3,752.55 -3,665.35 -3,665.35 91.01 348.69 1.7 556,154.4 5,976,060.3 12,849 3,751.44 -3,664.24 -3,664.24 91 .44 348.70 0.8 556,143.9 5,976,110.9 12,894 3,750.34 -3,663.14 -3,663.14 91.38 348.56 0.3 556,134.7 5,976,154.5 12,945 3,749.18 -3,661.98 -3,661.98 91.22 348.53 0.3 556,124.2 5,976,204.4 12,990 3,748.33 -3,661.13 -3,661.13 90.91 349.95 3.2 556,115.3 5,976,249.2 13,043 3,747.37 -3,660.17 -3,660.17 91.20 350.17 0.7 556,105.9 5,976,300.5 13,052 3,747.16 -3,659.96 -3,659.96 91.38 347.49 29.25 556,104.0 5,976,309.4 13,088 3,746.28 -3,659.08 -3,659.08 91.41 347.03 1.3 556,095.7 5,976,344.7 13,089 3,746.24 -3,659.04 -3,659.04 91 .44 346.65 24.6 556,095.4 5,976,346.2 13,115 3,745.74 -3,658.54 -3,658.54 90.80 348.53 7.8 556,089.7 5,976,371.0 13,141 3,745.58 -3,658.38 -3,658.38 89.91 347.70 4.7 556,084.2 5,976,396.0 Page 5 of 6 ) ) 1C-178L1 DIRECTIONAL SURVEY MD TVD SS CORR SS INCLINE AZIMUTH DOGLEG ASP X ASPY 13,1 85 3,746.22 -3,659.02 -3,659.02 88.44 346.16 4.8 556,073.8 5,976,439.0 13,236 3,748.41 -3,661.21 -3,661.21 86.63 345.84 3.6 556,061.1 5,976,488.4 13,281 3,751.18 -3,663.98 -3,663.98 86.35 346.30 1.2 556,049.9 5,976,532.2 13,334 3,754.24 -3,667.04 -3,667.04 86.96 346.22 1.2 556,037.0 5,976,583.0 13,379 3,756.52 -3,669.32 -3,669.32 87.22 349.23 6.7 556,027.1 5,976,626.7 13,429 3,758.78 -3,671.58 -3,671.58 87.67 346.43 5.6 556,016.0 5,976,676.1 13,475 3,760.99 -3,673.79 -3,673.79 86.78 349.34 6.7 556,006.1 5,976,720.6 13,529 3,764.16 -3,676.96 -3,676.96 86.45 345.65 6.9 555,994.0 5,976,772.8 13,573 3,767.23 -3,680.03 -3,680.03 85.70 346.84 3.1 555,983.0 5,976,816.3 13,626 3,771.17 -3,683.97 -3,683.97 85.70 346.84 0.0 555,970.7 5,976,867.1 Page 6 of 6 ) ) Transmittal Form "~i. BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie O\oSO Referenc~ \ -1 C-178 \ 0'- lJ 00 \ 0- d03-()~C-178Ll)(7 ~. O~ ~ Cf\ 1 C-178LIPBl '(7 O-:/-' ~cL?- lC-178LlPB2 )f} ___....~.._..__....___.._......'a.._.._..__.....'_...._..._ ..,.._.___...__~.._._...._..____......._..._.,.......,....".._._,_,......~.._..........._.._..._...___._ ..,..-............--..-.-..--..-......-.......-".....,,-......-.........,.,,-.--...-......--....-....--...-.... ...._"....._..._,....,~.,.._-_....._..,-~- ..,........,......,.-"........._......"-,................ ~...".,..__........--_..._......_, 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 PtLc.-~. I ~ 2..... -=-_.__._....______.__....._.__._..=:=-==-_--2!!::.___....-=-=_=_..____..____=-_ Sent By: Glen Horel Date: June 18, 2003 --... . Received By: ~.("')'-... 1. ~~ 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 20 2003 I\¡a~ka U;¡ ¡It GEl!.' CO/'l[¡. CommìaBion /\m~t!Oraye Idl.q~bl~.:"~.~~".'~ J , I...·'·'." ...,...'II ..... III "'. n.', ", .., ..... ~i:~[i~lf i · _.n ¡. ~._.._--_._~ .....---.---..--..."".---. .~~~-~~~,~~~;~~:-~:-~ ~~~::;'~~';"7~:-:~-, 'lGJ! ¡ Wk.,,.. tt:.'(~;~,':.' ..M.....'...·. t·"~~~,, : !D.: ~:~ i .. I' r- . ~ ~ --' I l~ L_.._.______u__. ) Transmittal Form ) '&1. BAKER HUGHES i I !II."'''' '''''''~~_J I, ...,...,.....,.,........,." " IWI'IIW'~ 'WM .0 ,,~ I"", .: ... ... ... _._~------_... f'IIIIIr~ ~ ,~ ..., ~:. .." ,.,. ... 01< .,. 0'.' _.....--_..~....._..__.-._.,.... ... ......... .,,_.. IWW"'I .......... 11'11:' To: Anchorage GEOScience Center ,.........,,, "".... INTEQ AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 3 -01-\ \ lC-178- ~O -OL.\~ lC-178Ll ð0:3 -oq 7- 1C-178LIPBl~P~ -0\ ð- lC-178LIPB2 eJ-O ,.'::':::':'.. .'.'.""'" "". !i 'ë~~tai~~'the following material for each wellbore II listed above: j¡ II 1 LDWG Compact Disc !I (Includes Graphic Image files) ¡i 1 LDWG lister summary Ii (¡I 1 blueline - MPR Measured Depth Log I¡ ,I 1 blueline - MPR TVD Log Ii il P II 11 Po..Jca-r- 2. tY( ~ Ii il LAC Job#: 428169 ;,1, Date: June 18, 2003 Sent By: Glen Horel Received B~~ 1Y\~'-O ~~ Da te: 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 l· 'I, i '.-~~ ::~ '. :.~_\ ~, :t'. ~:.....: (':~~: [(.;:. t \ /. ~f~':;, r,): I J' J () ( I' "', ", ' \.11... ¡.. I. J en,) ....,.. . " c.,.; i¡¡nL::::¡':;: i , !". I : ~ 'I. . 't ~ ...... Ii'. ...., ~\o ~~-_......"~~~ ... ~.._."'.~.. ._--_.._~.....'... ~.."" WIll " ., _".10 ..,. ... ..,.. ... ......',... . .". "II" ..' ". .'"M._...._._~..~..__.... ....,,_. n...... ..,,_~... .".,.'" -.0:1 w. 1'" _1..1,' '"........."...,......."."... '" 0 .." "h ......u,·,. . ... o ....... r .----·--:=.-:.-=::.'::='=;=0 I .,~:' ¡ ~::z;:. .....'"':, . ",...~:=r_........;... _...'"....,~. ..- ...~,..._:... ... \........: ·....·..-r'···..·,··.. ... ..."..... ('.. -:'... ... ... .~.... '."~ . ~ ... . ~':-~~:'.~~~ .:'~~~~ I I [~--------- .f" ~'. ) :¡ !Æ~!Æ~~~!Æ ~~!Æ~E AT,ASIiA. OIL AND GAS CONSERVATION COMMISSION April 24, 2003 S. K. Allsup-Drake Phillips Petroleum Company 700 G STREET A TO 1530 ANCHORAGE, AK 99501 Dear Sharon, ,) ~ D3~~ocj d FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is a refund of the permit fee (check# 1029) for Well KPR 1 C-178L 1. Please refer to 20 AAC 25.005 (e). This is a multi-lateral permit that does not require the $100 permit fee. Sincerely, ~k¿~.>·/ Linda S. Berg a Administrative Manager Enclosures RECEIVED MAR 1 2 2003 ·"""ouaGasGœs.OIIIJ ~ ,....,. ,.dØ8118 S. K. ALLSUP-DRAKE 1029 PHILLIPS PETROLEUM COMPANY £ 700 G ST. ATO 1530 ANCHORAGE AK 99501 DATE ¡{~?' 12/ 2£()3 62~14/311 P4V TO THE S~.hr:: ()r': Intfsrf/- /Rcx::;..:::« I $ /0tJ ,/1/·') . ORDEROF_;.,JTUv , I. r, .~ /. ( . .1.../,-,- _.,--,.. ... 1/') /, I . , t;, -J C-J, It· { ,''''~ ! /. A _.,,'- ~ f'C--- fL-vv-Jfv-¿.G..J '-' ~ ~¿:,,( ¡rOc -'ÓÒLLARS ill ~~:::' ~ ~.... CHASE Chase Manhallan Sank USA, N.A. Valid Up To 5000 Dollars . , 200W"neCIayCerë,D,._.,Ic.DElt711 ....j / I ... ( .. I /;, ,..--, k' -t-·;, " f.f / ) ;> . /)/î.Þ/.;~ Æ~1~7~~~~" MEMO I: 0 3 ¡ ¡ 0 0 ¡ I. I.': 2 ~ 8 0000 I. 2 ? 2 5 ? II· .0 2 11 i fJC.~ I C - ~ tðj-.I J?-JÞ"- þ~ ' ßþvld r'--Ivr~ ~Jf&¿ yt!!- ~ zÞ 1111 C. ZS:aJ~~ ~ .1:J ß ~. 3r2.5 ~03 ~. ) 72. Temporary shutdown of drilling or completion operations 75. Other wells in designated areas 80. Annular disposal of drilling waste ~o AAC 25.005 PERMIT TO DRILL. ~ (a) Before drilling or redrilling a well or re-entering an abandoned well, a person shall submit and obtain the commission's approval of an application for a Permit to Drill (Form 10-401). If: after drilling a well, a person wishes immediately to redrill below the structural or conductor casing to a new bottom-hole location not requiring a spacing exception under 20 AAC 25.055, the person may request oral approval from the commission to avoid interruption of operations. If oral approval is obtained, the name of the representative of the commission who provided oral approval 'and the date of the· approval must be included on the application for a Permit to Drill, which must be submitted by the commission's next working day for final approval by the commission. (b) The commission will classify a well as (1) exploratory; (2) development, either oil or gas; (3) service; or ( 4) stratigraphic test. (c) 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: (1) a fee of$100 payable to the State of AlaskalAOGCC; (2) a plat identifying the property and the property's owners and showing (A) the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines; (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the. top of each objective formation and at total depth; and (D) other information required by 20 AAC 25.050' (b); (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; ( 4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential swface pressure based on a methane gradient; (B) data on potential gas zones; and 2 I I I I I I I ~ I I I I I I I I I I I .'" '-' (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030 (f); (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre-perforated liner, or screen to be installed; (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035 (h)(2); (8) a drilling fluid program, including a diagram and description .of the drilling fluid system, as required by 20 AAC 25.033; (9) for an exploratory or stratigraphic test ·well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25~033 (f); (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061 (a); (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061 (b); (12) evidence showing that the requirements of20 AAC 25.025 have been met; (13) a copy of the proposed drilling program; (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well. (d) For a well that is to be intentionally deviated, the requirements of 20 AAC 25.050 (b) must be met. (e) If a well has multiple well branches, each branch requires a separate Permit to Drill. If multiple well branches are proposed from a single conductor, surface, or production casing, the applicant shall designate one branch as the primary wellbore and include all information required under (c) of this section with the application for a Permit to Drill for that -branch. For each subsequent well branch, the application for a Permit to Drill need only include information under ( c) of this section that is unique.to that branch and need not include the $100 fee. (t) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. (g) If drilling operations are not commenced with 24 months after the commission approves an application for a Permit to Drill, the Permit to Drill expires. 3 ~~]~E ~ ') f ~~~~~~IÆ ') \ ~ FRANK H. MURKOWSKI, GOVERNOR AT,ASKA. OIL AlQ) GAS CONSERVATION COJDIISSION 333 W. TH 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 lC-178 and lC-178Ll 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 lC-178 and lC-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 lC-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, f)_~ L,L./( ~ Sarah Palin Chair BY ORDER OF THE COMMISSION DATED this!!..1 day of April, 2003 cc: Department ofFish and Game, Habitat Section Department of Environmental Conservation Exploration, Production and Refineries Section (ê) r:.-:J fM ~-;> '[ ~ c. [h1;, ,ç: ~ ,) !Æ ~~.~ ~ ~~!Æ \~,:.::.... -E J~] ALASKA. OIL AND GA.4ii CONSERVATION COMMISSION Randy Thol11as Kuparuk Drilling Team Leader ConocoPhillips Alaska P. O. Box 100360 Anchorage, Alaska 99510-0360 ~\ ,) FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Unit 1 C-178Ll ConocoPhillips Alaska Pennit No: 203-042 Surface Location: 1503' FN'L, 1195' FWL, SEC. 12, TIIN, RI0E, UM BottOlllhole Location: 1490'FSL, 149, FWL, SEC. 35, T12N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for penllit to drill the above referenced development well. This pen11it to drill does not exempt you frOln obtaining additional pennits or approvals required by law fr0111 other govenmlental agencies, and does not authorize conducting drilling operations until all other required penuits and approvals have been issued. In addition, the Conlmission reserves the right to withdraw the permit in the event it was erroneously issued. Operations n1ust be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the COlumission 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 Coml11ission order, or the tenus and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Comlnission to witness any required test. Contact the COlllmission's North Slope petroleu111 field inspector at 659-3607 (pager). Sincerely, krL¡ d..ad<- ~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this < ~ day of March, 2003 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 6. Property Designation ADL 25649 & 25638 ALK 467 & 463 7. Unit or property Name Kuparuk River Unit 8. Well number 1C-178 L 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 1332 psig At total depth (TVD) 1740 psig Setting Depth MAR 1 2 2003 A~Oil&GasCons. CommisSion ~ Anchorage 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid program 0Time vs depth plot Qefraction analysis o Seabed report 020 AAC 25.050 requirements 0 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Steve McKeever 265-6826 Signed ~~ -,-_L \ ~ ~. Thorn: -, ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1b. Type of well. Exploratory U Stratigraphic Test Service 0 Development Gas 0 Single Zone 5. Datum elevation (DF or KB) RKB = 87 feet AMSL 1 a. Type of work: Drill Ld Redrill 0 Re-entry ODeepen 0 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, T11N, R10E, UM At top of productivè interval 499' FSL, 1282' FWL, Sec. 2, T11N, R10E, UM At total depth 1490' FSL, 149' FWL, Sec. 35, T12N, R10E, UM 12. Distance to nearest property line 13. Distance to nearest well 149'· @ TD feet 1 C-04 35' @ 1100' 16. To be completed for deviated wells Kickoff depth: 77'9 '1'3'11 MD 18. Casing program ¿j size feet Maximum hole angle 93° Top Hole Specifications Grade Coupling MD Bottom TVD Casing Weight MD Length TVD 6.75" 4.5" 12.6# L-80 SLHT 7349' 6378' 3702' 13727' 3747' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured true vertical feet feet Plugs (measured) Effective Depth: measured true vertical feet feet Junk (measured) Casing Conductor Surface o Length Size Cemented Measured depth Perforation depth: measured true vertical Title: Kuparuk Drilling Team Leader Commission Use Only Permit Number . l I API number . // /. Approval da~ I~/ I ~ 2-D3-Óì~ 50- CJ2f/.- 23/'7Y·...0(j Ò3IL~ "../ Conditions of approval Samples required 0 Yes ~ No Mud log required Hydrogen sulfide measures [ ] Yes [RI No Directional survey required Required working pressure for BOPE 02M; 0 3M; 0 5M; 0 10M; 0 Other: T-v> ~~" P E f-c S-OCÐ psl. k""l ~c4. '\ ~ D by order of Approved by Commissioner the commission Form 10-401 Rev. 12/1/85· 0, /1'J"i, t ç /¡' " I¥ r~¡ ~ I ;/ ,} /~ ~ ~4'~' ~/~~/lOD3 U D Development Oil Ld Multiple Zone 0 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 depth (MD and TV D) 13727' MD / 3747' TVD Quantity of Cement (include stage data) Slotted liner - no cement True Vertical depth RECEIVED -3/ { <-ID '3 Date PrAn;::m~r/ hv RhAmn AI1f::/m-nrAkA Yes see cover letter for other requirements U Yes ~ No o No Date D 3/4/0] Submit in triplicate ) Apr }n for Permit to Drill, We1l1C-178 L 1 " Revision No.O Saved: 11-Mar-03 Permit It - West Sak Well #1 C-178 L 1 Application for Permit to Drill Document Ml)ximizE Well ValUE 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. Drill i ng FI u id Program .......... .............................. ... ...... ........... ...... ..... ........... ........... 5 Requirements of 20 AAC 25.005(c)(B) ................................................................................................... 5 Upper Lateral Mud Program (6% KCI .BARADRILn)............................................................................ 5 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................... ........................... ................ ............... ........ ............5 10. Seismic Analysis.................... ......... ......... ... ........ ............ .......... .... .... ............. .... ...... 5 Requirements of 20 AAC 25.005 (c)(10) .......................................................... .......................... ............5 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (c)(11) ............... ............................................................. ....... ............. 5 12. Evidence of Bond i ng .......................... ......... .... ... ..... .............. ......... ............. .... ..... ... 6 Requirements of 20 AAC 25.005 (c)(12) .............................................................. .................................. 6 O R'" ~ j~... ..( " .f A,. , I ' {; ¡;...'.: ,\:'? ~ " ..!J" ì Ii, \ '.,' ,r lJ'"'~ ï .' ~II ,} ..~ . / or-_~i.I:!!1 1 C-178 L 1 PERMIT IT.doc Page 1 of 7 Printed: 11-Mar-03 ) App )n for Permit to Drill, Well 1 C-178 L 1 . Revision No.O Saved: 11-Mar-03 13. Proposed Drilling Program .....................................................................................6 Requirements of 20 AAC 25.005 (c)(13) .... ................................ ........... .............. ...... ............................. 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c}(14) ................................................................................................6 15. A tta c h m e nts ............................................................................................................. 7 Attachment 1 Directional Plan (4 pages) ................................................................................................7 Attachment 2 Drilling Hazards Summary (1 Page)... ........... .................... ......... ...... .......... ...................... 7 Attachment 3 Well Schematic (2 pages) ... ................................ .................. ............ ......................... ...... 7 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identitìed by a unique name desìgnated by the operator and a unique API number as:.signed by the commis..<,ïÒn under 20 AAC 2!i:040(b). For a well with multiple well brafìä]e5~ each brandJ mw;t sirmlady be identified by a unique name and API flumber by adding a suffix to the name designated for the well by the operator and to the number i6"'5igned to the well by tile cvm¡TJi5/sion The well for which this Application is submitted will be designated as lC-178 L1. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An applicatio/7 for a Permit to Dr/II must be r1ccompanied by each of the fòllowing item~ except fòr an Item already 0/7 tile with the commission and Identified in the application: (2) a plat Identifÿing It]e property and the property~., owners and s1lowing (A)the coordinates of the proposed location of the well at the sl.JJface/ at the top of eacÝJ objective formation and at total depth, referenced to govemmental section line5~ (8) the coordinates of'the plVposed location of the well at the surfacel referenced to the state plane coorcflí7ate sy..çtem tor this :.,7:ate as maintained by the National Geodetic !:Jurvey in the National OceanIc and Atmospheric Administrat¡Òn; (C) the proposed 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 "D" Sand) NGS Coordinates Northings: 5,970,696 499' FSL, 1282' FWL, Section 2, TllN, Rl0E, UM Eastings: 556,992 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 7348 3702 3615 Location at Total Depth NGS Coordinates Northings: 5,976,957 Eastings: 555,804 1490' FSL, 149' FWL, Section 35, T12N, Rl0E, UM Measured Depth, RKB: 13,727 Total Vertical Depth, RKB: 3,747 Total Vertical Depth, 55: 3,660 and (D) other information required by 20 AAC 25.0S0(b); O Fil'" ,('''¡. ,r. ". .".' . :' " ..7 ;1 ,; \ I \i1 I: : <ill.: ;. ""I' //1 '", ... ï '1:>1 ¡ ,I ~ r~ L 1C-178 L1 PERMIT IT. doc Page 2 of 7 Printed: 11-Mar-03 ) App )n for Permit to Drill, We1l1C-178 L 1 , Revision No.O Saved: 11-Mar-03 Requirements of 20 AAC 25.050(b) If a well is to be intentionally dev/~'}te~ the application for a Pe/mit to Drill (Fonn 10··401) mllst (1) include a plat~ drawn to a suitable scale, showing the path of the proposed we//bore, including a/I aqjacent we//bores within 200 feet of any portion of the propo!:>"'Od we/~· Please see Attachment 1: Directional Plan and (2) for all wells wit/7ín 200 feet or the proposed wel/bore (A) list the names of tile operators of' those well~ to the extent that those names are known or discoverable in pub/íc record~ and show that each named operator has been furnished a l.:vPY of the application by celtifìed ma/~· or (B) state that 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 Drill mu.t;t be accompanied by each of the followfi1g Hems, except for an item already on file with the commission ami identified /n the app/k..-ation: (3) a diagram and desaiption or the blowout prevention equipment (SOPE) as required by 20 AAC 25: (}35~ 20 AAC 25: 036, or 20 AAC 25:(}3~ as appliCë~ble/ An API 13-5/8" x 5,000 psi BOP stack will be utilized to drill and complete welllC-178 L1. 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 to Drill must be accompanied by each of the following items, except lor an item already on file wIth the commission and Identified 1Í1 the application: {4) li7formation on drilling hazard<;, including (A) the max/mum downhole pressure tl7at may be encountered, aiteria llsed to determine it, and max/mum potential .':>ì}dace pre5:c,ï.lre ba5"ed on a methane gradient; The expected reservoir pressures in the West Sak sands in the lC-178 Ll 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 =(3702 ft)(0.47 - 0.11 psi/ft) = 1332 psi (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data C'Oncermi1g potential causes of 170le problems !:J1Jc/7 as abnormally geo·pressured strata, lost circulation ZOne~ and zones that have a propensity for dIfferential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a PermIt to Dnll must be accompanied by each of the following Items, except for an item already on file wIth the commission and Identified Ii] the application: (5) a description of the procedure lor conducting formation integnty test~ as required under 20 MC 25. 030(!); 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. The formation integrity of the II 1·" ·'~G I ~I¡ 11 L L .¡.u 1~X·:}.,"'\, ~ r ,,~. 14 !'I .:~ lJ'j 1C-178 L 1 PERMIT IT. doc Page 3 of 7 Printed: 11-Mar-03 ') App )n for Permit to Drill, We1l1C-178 L 1 Revision No.O Saved: 11-Mar-03 West Sak D sand is expected to be the same as that of the B sand, so no formation integrity test is planned during lC-178 Ll operations 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for i~ Pef7l71t to Drill must be accompanied by each of the following Items~ except fòr an Item already on file with the commÎ..fision and identifìed in the application: (6) a complete proposed caslÌ7g and cementìng program as required by 20 MC 25. 03~ and a description of'any slotted lìner~ pre- perforated liner; Of'screen to be ìnstalled,· 6-3/4" Lower Lateral (lC-178) 4-1/2 6-3/4" slotted Upper Lateral (lC-178 L1) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An applìcation for a Perrmt to Drill mlJ~t be accompanied by eaä7 of the following item~ except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter !7ystem as required by 20 MC 25~035~ unless this' requirement is waived by the commis:.çion under 20 MC 25.035(17)(2)/ Casing and Cementing Program See also Attachment 4: Cement Summary Hole Size (in) 24 Top MD/TVD (ft) 28 / 28 Btm MD/TVD (ft) 138 / 138 Csg/Tbg 00 (in) 16 Weight (Iblft) 62.5 Length (ft) 110 Grade H-40 Connection Welded 7-5/8 9-7/8 28 / 28 7747 / 3768 BTCM 29.7 L-80 7719 4-1/2 slotted 6350 7384/ 3711 13734 / 3806 12.6 L-80 SLHT 12.6 7349/ 3702 13727 / 3747 SLHT 6378 L-80 No diverter system will be utilized during lC-178 Ll operations. O ]i Pi ~ '/ i1 L . ,,. ¡ li l J\., ;4 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 1C-178 L 1 PERMIT IT. doc Page 4 of 7 Printed: 11-Mar-03 ') Apr }n for Permit to Drill, We1l1C-178 L 1 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 Drill must be accompanied by each of the fò//owing item~ except for an item alreðdy on tHe wIth the commi....,-sion and Identified in the application: (8) ('] drilling fluid progrc-1m/ inäudli7g ('] diagram and description of the drilling fluid system/ as required by 20 AAC 25. 033; Drilling will be done with muds having the following properties over the listed intervals: Upper Lateral Mud Program (6% 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 c-1pplication fòr a Penmt to Drill mU::,7 be accompanied by ec-1cl7 oftl7e fbllowti7g Item.~ except for an item already on fï/e with the commi"isiol7 and identified in the applicatìon: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25: 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 Perrmt to Drill mU!:Jt be aex;ompanied by each of the following ¡tem~ except tor an Item already on file with the cvmmission and Identitìed in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis 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 application for a PermIt to Drill must be accompanied by each of the ¡òllowing item~ except for an item already on file with the commission and ¡dentlfled in the application: (1.1) for a well dnlled from an offshore platform~ mobile bottom-founded structure~ jack-up rig/ or floating drilling vessel, an analysis of seabed cvnditions as required by 20 AAC 25.061(b),' Not applicable: Application is not for an offshore well. O R ~ l"", I ,", LA l 1,/ l;~:.~. . Y'.. i ?J... . 3 J ¡J 'J iI··' " ..' , ~.J , ~ 1C-178 L1 PERMIT IT. doc Page 5 of 7 Printed: 11-Mar-03 ) Apr ~n for Permit to Drill, Well 1 C-178 L 1 I Revision No.O Saved: 11-Mar-03 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following item~ except tor an item already on fìle wIth the commission and Identified JÍ7 the application: (12) evidence showing that the requirements of 20 MC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application tor a Permit to Drill must be accompanied by each ot the tollowing Items, except tor an Item a/ready on file with the c:vmmission and identified in the applk.:-ation: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematics. This procedure will begin upon completion of the lower lateral, lC-178 1. Run and set Baker Window Master whipstock system, at window point of 7,349' MD / 3,702' TVD, just into / the top of the D sa nd. 2. Displace wellbore to used Baradril'N fluid from the lower lateral. 3. Mill window. POOH. 4. Pick up 6-3/4" drilling assembly with LWD, MWD, and annular pressure logging tools. RIH. /' 5. Change over to clean BaraDril'N drilling mud. 6. Continue to directionally drill to TD of D sand lateral at 13,727' MD / 3,747' TVD. POOH. /'" 7. POOH, back reaming out of lateral. RIH to TD and displace open hole to clean mud. POOH. 8. RIH with whipstock retrieval tool. Retrieve whipstock and POOH 9. PU and run 4-1/2" slotted Liner. r'/ 10. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 11. Release hanger running tool. POOH, laying down drill pipe as required. 12. Make up tubing tail and completion equipment as required and RIH to depth. 13. 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 14. 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. 15. Set BPV and move rig off. 16. Rig up wire line unit. Pull BPV. Set dummy valve in place of RP shear valve in top mandrel. Perform MIT pr~te t;ests of tubing and annulus (Tubing and annulus to 3500 psi). 17. Pull RHC plug from nipple below packer. Open CMU sliding sleeve. Set Weatherford jet pump in CMU profile. Rig down wire line unit. 18. 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 tor a Permit to Drill mustc be accompanied by each of the following item~ except for an item already on file wIth the commission and identified in the application: ORe~" G,II¡ ~I f! ..: ¡,. ~ l ,,¡¡¡, N, ':ì ~ ~': ". ¡ . , & Ii¡./. ,1 .. ,¡ ",,¡¡y 1 C-178 L 1 PERMIT IT.doc Page 6 of 7 Printed: 11-Mar-03 ) APr}n for Permit to Drill, We1l1C-178 L1 Revision No.O Saved: 11-Mar-03 (14) a general dfJSaiption ot'how the operator plans to dispose oldrillti1g mud and cuttli1gS and a statement ot' whether the operator intends to request authorization under 20 AAC 25:080 f'Or an annular disposal operation in the wel/./ Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 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. 15. Attachments Attachment 1 Directional Plan (4 pages) Attachment 2 Drilling Hazards Summary (1 Page) Attachment 3 Well Schematic (2 pages) I!..)·~ ¡r:, ': , .'. ,7 ~ L '",{ .. ; ^ .~ I' " ~ J I, ,1' (. ·.1" ,i "j 'r,., t, .' N t I!&:,'¡ $ 5 ~ J, . 1C-178 L1 PERMIT IT. doc Page 7 of 7 Printed: 11-Mar-03 Grid Lat Long Page 1 of 3 ) ) ConocoPhillips Alaska, Inc. Pad 1C 178 slot #178 Kuparuk River Uni t North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref Our ref License 1C-178 D-Lat Vers#2.b prop5355 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, w14 9 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 Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Or-:>.· : ~I i .' . f~ ~ ,~~'\ 1'·1 / ..~ \ ..,~ ,./ ~j .~ '~'¡ ~ ~ ) ) ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 1 Pad 1C,178 Your ref : 1C-178 D-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 Northing COO RDINATES 7349.00 74.00 335.00 3702.14 2003.62N 5194.70W 556991.41 5970696.29 n70 19 50.09 w149 32 15.87 7361.00 75.65 335.98 3705.28 2014.16N 5199.50W 556986.52 5970706.79 n70 19 50.19 w149 32 16.01 7379.00 75.65 335.98 3709.74 2030.08N 5206.60W 556979.29 5970722.66 n70 19 50.35 w149 32 16.22 7400.00 77.81 338.04 3714.56 2048.90N 5214.58W 556971.16 5970741. 41 n70 19 50.53 w149 32 16.45 7500.00 88.25 347.45 3726.71 2143.48N 5243.86W 556941. 11 5970835.74 n70 19 51. 46 w149 32 17 .31 7516.70 90.00 349.00 3726.96 2159.82N 5247.27W 556937.57 5970852.05 n70 19 51. 62 w149 32 17 .41 7539.88 93.00 350.24 3726.36 2182.62N 5251.44W 556933.21 5970874.81 n70 19 51.85 w149 32 17 .53 7675.00 93.00 350.24 3719.28 2315.60N 5274.31W 556909.26 5971007.58 n70 19 53.16 w149 32 18.20 7732.89 90.25 350.24 3717.64 2372.63N 5284.12W 556898.99 5971064.52 n70 19 53.72 w149 32 18.49 7748.89 89.49 350.24 3717.68 2388.39N 5286.84W 556896.15 5971080.27 n70 19 53.87 w149 32 18.57 7800.00 89.49 350.24 3718.13 2438.76N 5295.50W 556887.08 5971130.55 n70 19 54.37 w149 32 18.82 7900.00 89.49 350.24 3719.02 2537.31N 5312.45W 556869.33 5971228.95 n70 19 55.34 w149 32 19.32 8000.00 89.49 350.24 3719.91 2635.85N 5329.40W 556851. 58 5971327.35 n70 19 56.30 w149 32 19.81 8100.00 89.49 350.24 3720.81 2734.40N 5346.36W 556833.82 5971425.75 n70 19 57.27 w149 32 20.31 8200.00 89.49 350.24 3721.70 2832.95N 5363.31W 556816.07 5971524.15 n70 19 58.24 w149 32 20.81 8300.00 89.49 350.24 3722.59 2931. 50N 5380.26W 556798.32 5971622.55 n70 19 59.21 w149 32 21.30 8400.00 89.49 350.24 3723.48 3030.05N 5397.22W 556780.57 5971720.94 n70 20 00.18 w149 32 21.80 8500.00 89.49 350.24 3724.37 3128.60N 5414.17W 556762.82 5971819.34 n70 20 01. 15 w149 32 22.30 8600.00 89.49 350.24 3725.26 3227.15N 5431.12W 556745.06 5971917.74 n70 20 02.12 w149 32 22.79 8700.00 89.49 350.24 3726.15 3325.69N 5448.08W 556727.31 5972016.14 n70 20 03.09 w149 32 23.29 8800.00 89.49 350.24 3727.05 3424.24N 5465.03W 556709.56 5972114.53 n70 20 04.06 w149 32 23.79 8900.00 89.49 350.24 3727.94 3522.79N 5481. 99W 556691. 80 5972212.93 n70 20 05.03 w149 32 24.28 9000.00 89.49 350.24 3728.83 3621.34N 5498.94W 556674.05 5972311.33 n70 20 06.00 w149 32 24.78 9100.00 89.49 350.24 3729.72 3719.89N 5515.90W 556656.29 5972409.73 n70 20 06.96 w149 32 25.28 9200.00 89.49 350.24 3730.62 3818.43N 5532.85W 556638.54 5972508.12 n70 20 07.93 w149 32 25.77 9300.00 89.49 350.24 3731.51 3916.98N 5549.81W 556620.78 5972606.52 n70 20 08.90 w149 32 26.27 9400.00 89.49 350.24 3732.40 4015.53N 5566.77W 556603.03 5972704.92 n70 20 09.87 w149 32 26.77 9500.00 89.49 350.24 3733.30 4114.08N 5583.72W 556585.27 5972803.32 n70 20 10.84 w149 32 27.27 9600.00 89.49 350.24 3734.19 4212.62N 5600.68W 556567.52 5972901.71 n70 20 11.81 w149 32 27.76 9700.00 89.49 350.24 3735.08 4311.17N 5617.64W 556549.76 5973000.11 n70 20 12.78 w149 32 28.26 9800.00 89.49 350.24 3735.98 4409.72N 5634.60W 556532.00 5973098.51 n70 20 13.75 w149 32 28.76 9900.00 89.49 350.24 3736.87 4508.27N 5651. 55W 556514.25 5973196.90 n70 20 14.72 w149 32 29.25 10000.00 89.49 350.24 3737.77 4606.82N 5668.51W 556496.49 5973295.30 n70 20 15.69 w149 32 29.75 10100.00 89.49 350.24 3738.66 4705.36N 5685.47W 556478.73 5973393.70 n70 20 16.66 w149 32 30.25 10200.00 89.49 350.24 3739.56 4803.91N 5702.43W 556460.97 5973492.09 n70 20 17.62 w149 32 30.74 10249.38 89.49 350.24 3740.00 4852.57N 5710.81W 556452.20 5973540.68 n70 20 18.10 w149 32 30.99 10249.40 89.49 350.24 3740.00 4852.59N 5710.81W 556452.20 5973540.70 n70 20 18.10 w149 32 30.99 10270.99 89.85 349.70 3740.12 4873.86N 5714.57W 556448.27 5973561.93 n70 20 18.31 w149 32 31.10 10500.00 89.85 349.70 3740.71 5099.17N 5755.51W 556405.50 5973786.89 n70 20 20.53 w149 32 32.30 11000.00 89.85 349.70 3741.99 5591.11N 5844.91W 556312.12 5974278.04 n70 20 25.37 w149 32 34.92 11500.00 89.85 349.70 3743.27 6083.06N 5934.30W 556218.74 5974769.19 n70 20 30.20 w149 32 37.54 12000.00 89.85 349.70 3744.55 6575.00N 6023.69W 556125.36 5975260.34 n70 20 35.04 w149 32 40.16 12500.00 89.85 349.70 3745.83 7066.94N 6113.08W 556031.98 5975751.50 n70 20 39.88 w149 32 42.78 12568.39 89.85 349.70 3746.00 7134.23N 6125.31W 556019.20 5975818.68 n70 20 40.54 w149 32 43.14 12568.41 89.85 349.70 3746.00 7134.25N 6125.31W 556019.20 5975818.70 n70 20 40.54 w149 32 43.14 12571.85 89.93 349.77 3746.01 7137.63N 6125.93W 556018.56 5975822.07 n70 20 40.57 w149 32 43.16 13000.00 89.93 349.77 3746.53 7558.98N 6201.97W 555939.11 5976242.75 n70 20 44.72 w149 32 45.39 13500.00 89.93 349.77 3747.14 8051.03N 6290.77W 555846.32 5976734.01 n70 20 49.56 w149 32 47.99 13727.20 89.93 349.77 3747.42 8274.62N 6331.12W 555804.15 5976957.24 n70 20 51. 76 w149 32 49.18 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 10418.84 on azimuth 322.58 degrees from wellhead. Total Dogleg for wellpath is 28.70 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 Grid Lat Long Page 2 of3 On F..... ... t".;i \,~; rU q t, i, :~ ~ J :'.:!: ) ConocoPhillips Alaska, Inc. Pad 1C,178 Kuparuk River Unit,North Slope, Alaska MD TVD ----------------------------------------------------------------------------------------------------------- 7349.00 3702.14 7361.00 3705.28 7379.00 3709.74 7539.88 3726.36 7675.00 3719.28 7748.89 3717.68 10249.38 3740.00 10249.40 3740.00 10270.99 3740.12 12568.39 3746.00 12568.41 3746.00 12571. 85 3746.01 13727.20 3747.42 Target name ') PROPOSAL LISTING Page 2 Your ref 1C-178 D-Lat Vers#2. b Last revised : 24-Feb-2003 Comments in wellpath ==:tI================== Rectangular Coords. 2003.62N 2014.16N 2030.08N 2182.62N 2315.60N 2388.39N 4852.57N 4852.59N 4873.86N 7134.23N 7134.25N 7137.63N 8274.62N Comment 5194.70W Top Whipstock Face 5199.50W Base Whipstock Face 5206.60W KOP-End Milled Hole 5251. 44W EOC 5274.31W Begin Drop 5286.84W EOD 5710.81W Begin Curve 5710.81W W7 D Midpt Reloc'd Tgt 5714.57W EOC 6125.31W Build 6125.31W W7 D 5000' Reloc' d Tgt 6125.93W EOC 6331.12W TD - Casing Pt. Targets associated with this wellpath ====================================== Geographic Location T.V.D. Rectangular Coordinates -- - -- -- -- - - --- -- - --- - - - -- - ----- -- - --- - - --- - ---- -- - - -- - ------ - -- - - - - -- - - -- -- - - --- -- - - -- -- ---- - - - -- -- - --- - - -- Revised 1C-178 Top D Sand Tg W7 D Midpt Reloc'd T 556452.200,5973540.700,0.0000 W7 D 5000' Reloc'd T 556019.200,5975818.700,0.0000 W7 D Toe Reloc'd Tgt 555726.200,5977369.700,124102 Grid Lat Long Page 3 of3 3702.00 3740.00 3746.00 3748.00 2003.17N 4852.59N 7134.25N 8687.73N O ~' · ,"',\ · !" q 11 Ii;' ..;" . ~ .} . \ 't l' . H i \,;1 J j J /':1 ôd 5194.49W 5710.81W 6125.31W 6405.72W ll-Sep-2002 5-Dec-2002 5-Dec-2002 5-Dec-2002 CJ ::t] "'--. - tt'- ~-'""""-~~~ .---.. +- Q) ~ '-" £ Q Q) o o :Ë Q) > Q) 2 I- I v Crected by b'T\ic'1oC Pot Refere1ce :5 1 C-', 78 D-Lc~ VersR2.b. Coordi"1olcs ere j" fee: 'c~e"cncc s:o: H~ 78. Vc,tical Depths arc reference RKB (Qoyon . /...). ~iii3 f<Aj(fIt - I~T¡::Q 2100 - .3000 - .3300 - «0C,\(P0o\e oc,'<- ocY:.~è ",'è c.'è ~\ ~-0\Çéf~Ò O<::! " en/' 'V< '\ o~o"t0' oc, \<' ~ 0er:>;<;,. o'V .._~ .3600 .!£!Ð -'I ,,900 - 1.;>00 - T - -- r --r---- -1 2700 .3300 .3600 3000 .3900 4200 ConocoPhillips Alaska, Inc. Structure : Pad 1 C Well: 178 Field : Kuparuk River Unit Location: North Slope, 349.91 AZIMUTH 9256' (TO D-LATERAL TD) "~*P!ane of Proposal**" G;{J.'" . <' 0"'c¿'o<:, 4500 4800 5iOO 51,00 5700 6300 6900 7200 6000 6600 Vertical Section (feet) -> Azimuth 349.91 with reference 0.00 N, 0.00 E from slot #178 7500 'V<"""~~-- r_-_-,:..ol-&II.. _ "'- " ..~ .~ ..I' ~ .r-Ii .1" ID- ~~~ .~...~. = Ii = ¡:-~ 00~Ò oc, ~ 7800 8100 8400 8700 ',-- .--- «\..- ¡Po, c,0 ,\'V ~ [ill] 9000 9.300 9600 ) lC-178 Ll Drillinq Hazards Summarï '~ ,J (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3/4" Open Hole / 4-1/2" Liner Interval Low I Mitigation StrateClY 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), Pumping out Hazard Abnormal Reservoir Pressu re Stuck Pipe Risk Level Low Lost Circulation Hole Swabbing on Trips Low Moderate '0 (~~ - -- " \. Ii ~ , 1 1C-178 L 1 Drilling Hazards Summary. doc prepared by Steve McKeever 3/10/2003 3:26 PM g J o n ~, ::r -- - - -. -c '" en"'tJ ::r_ CD 0) CD ::s c::; ~ :E ~':"~ a. m ~. ~ C').... ~: ~ocn f c:.g ~ :g Ci) :E CD !:t. CD ..,0= --¡- ::s ~ iI~' en C') CD n ~ ..,::r-.... CCDOO CD 3 ....0) Q) .... = Õ· CA ~C/) 3CD ~;;:è§"O Q)C/)~êi1 ~g.~-g ~3CÞêi1 oQ)CÞo.. 8~~~ . .-\1\\t "e~ at\C sebert' See Sheet 1 for Casing Details y ~ Runnina Order: (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 (CPAl). (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 3-1/2 IF Box up '"~_~dS Top of Window at +1- 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) 4-1/2 in x 6-1/4 in Weatherford SpiraGlider per joint on the remainder of the liner, with NO stop collars. ~' ------ ------ ------ ------ ------ ------ D ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ 6-3/4" Open Hole TD: +1-13,727' MD /3,747' TVD Lower Liner Top Set @ +1- 7,384' MD /3,711' TVD Surface I Production Casing 7-5/S" 29.7# L-SO BTC Mod Sm@ 7'74~~:~~~;~~~~;~=~=~=~=~1 See Sheet 2 for Lower Lateral Liner Details Tree Assy, (476-5770), Vetco Gray Gen I "Producer" '\ þ ) 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 OB w/3.875" No- Go Profile, IBT-Mod, set at +/- 500' MO (x) Joints Tubing 1C-178 As Built: Eastings: 562,201.72 Northings: 5,968,735.16 Pad Elevation: 59.2' AMSL Tubing Head Assy (503-5120) Vetco Gray, Gen 1,11" API 5M flange up. Doyon Rig 141 RKB @ 0' Elevation: 87.2' AMSL (1) Gas Lift Mandrel, (1062-2035) CAMCO 4-1/2" x 1" Model KBG-2 with OCK-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 TVO. (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 deg rees (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 I Pressure Gauge, Intake, Baker 925 Gaurdian (1) Joint Tubing "'C (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, (10 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 10ft handling pups. (x) Joints Tubing and tubing pups Control Line 1 TEC wire for Gaurdian Gauges, held in place with Canon Clamps on every coupling ref Sc e Hook Hanger, Baker Model B, 7-5/8" x 4-%", ---?' Main Bore Drift = 5.315" ~ Lateral Bore Drift = 3.875" -t (1) Wire line Entry Guide, 4-1/2" L-80 IBT-Mod Box, to be spaced out +/- 15' above hook hanger ~___ J...__I/ ------- ------ ------- ------ ------- 1 Goal: Minimize 7-5/8" Casing exposure for coil work 7-5/8", 29.7#, L-80, BTCM Casing Shoe @ 7695' MD / 3770' TVD Set @ 89 degrees TD 9-7/8" hole k-,--==/IJ ~ -r \ Both laterals: 4-1/2",12.6#, L80, SLHT liners, every - other joint slotted with 0.25" x 2" slots, 8 slots per foot. Lower Liner Top Set @ +/- 7,384' MD /3,711' TVD Conoc~hillips West Sak Production Well 1 C-178 Planned Completion Schematic Sheet,~ ~(4:, !~t?ing Details Jf:' ., l I-.it\' ',' ,I , i ,~\.a.¡ ~ j J '.,:JI Sheet 4 of 4 prepared by Steve McKeever Permit Schematic 3/10/2003 ~ "- RECEIVED MAR 1 2 2003 A~OiIaGas_. ~ ~ I4dMa,¡ g ~ " S. K. AllSUP-DRAKE 1029 PHILLIPS PETROLEUM COMPANY f:L I 700G ST. ATO 1530 , l;2 ZCC;;> ANCHORAGEAK 99501 DATE. .åvÞ£t. ( / :/ 62-141311 PAYTOìHE ~.I-tJ-rC /'(:: lfLtts. '-rif /4~r::;!~.F.Á> I $ I'/"V' 1"1() ORDER OF~. / ,~Ii i/ v. '. ~'? ',- .-''--'.. . (V\..., 1..-/ ,~_ ,P--- I / / ~ ! /J / --~.-{/ p¡¿. fU+-kd OU~ "--A//OOÖOCLARS 6:) ~.. CHASE Cha$e Manhattan Bank USA. N.A. Valid Up To 5000 Dol/ars . . '~",Q'''<>~,",. -., ~'"'' ... I . .'.'/ './ "W" /' / , .// ___) . . MEMO /.)1í{i>;;"-dí~7-,l~L ~ 1:0:1 · 100 ¡ I, 1,1: i! *80000 I, 2? 25 ?/I' .0 2 c¡ / l'.'~;Y¿AS..H_ KKu( I C-j' /6 L/ J(a¡¡"- /hU ð~¡/Id ~-/vr"-- ~ ,Jj6¿ ,...¿. fz ¡pMC. 2S:tf)S-G) ~ ß1 3·2.5 .03 ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME J:R tJ. 1 (!, -/7 i" L - / PTD# 203 - 6 if 2-- CHECK WHAT APPLIES ADD-ONS /(OPTIONS) TI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellbore segment of existing well k' £kI- It!... -17 ? . .-4&J () Permit No, Lb.1-ðý/ API No. S"'o.-oz",-.23/t./f 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). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\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. ~~~;.~EB~I~i~,f:..ç.~!~~ COMPANY ConocoPhillips FIELD & POOL 490150 - KUPARUK RIVER, WEST SAK ADMINISTRATION APPR SFD DATE 3/25/2003 (For Service Well Only) (For Service Well Only) (For Service Well Only) ENGINEERING APPR WGA ~GrÂ;- DATE 3/26/2003 GEOLOGY (For Service Well Only) APPR SFD DATE 3/25/2003 WELL NAME KUPARUK RIV U WSAK 1C-178L 1 PROGRAM Exploratory (EXP) Initial Classrrype DEV /1-0IL GEOL AREA 890 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 wellbore 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. ACM P 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 wellbore 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 ...................... 5000 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] ................................ GEOLOGY: ENGINEERING: RES. ENGINEERING: COMMISSION: RPC: WGA: X MJW: RR: SFD:SFD TEM: JDH: DTS: 03lulo.] SP: Development (DEV) ~ Redrill UNIT No. 011160 Service (SER) Well bore seg ~ Annular disposal para req ON/OFF SHORE On Per 20 MC 25.005 (e), fee not required as this is a susequent branch of well 1 C-178. Check should be returned. Surface and top productive interval in ADL 025649; TD in ADL 025638. Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes NA Not Applicable NA Not Applicable NA Not Applicable NA Not Applicable NA Not Applicable NA NA Not Applicable NA Not Applicable No Slotted liner. Yes Yes Doyon 141. NA Not Applicable Yes NA Not Applicable Yes Max MW 9.3 ppg. Yes Yes MSP 1332 psi. Yes Yes No NA Not Applicable ( ( Yes Steve McKeever, ConocoPh: No H2S is known in West Sak Oil, but rig is equipped with sensors/alarms & H2S readily scavenger available. 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 Com ments/I nstructions ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting 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 APPEN,DIX. No special effort has been made to chronologically organize this category of information. ') **** REEL HEADER **** LDWG 03/06/18 AWS 01 **** TAPE HEADER **** LDWG 03/06/18 01 *** LIS COMMENT RECORD *** )fJ03~O~~ éfð 3 !!!!!!!!!!!!!!!!!!! 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 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 1 C. MEYER F. HERBERT MWD RUN 6 6 C. MEYER D. WESTER # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING ~\s~.,~,~ lC-178Ll 500292314460 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 18-JUN-03 MWD RUN 2 2 C. WONG D. GLADDEN MWD RUN 7 7 F. WENDLER D. HElM MWD RUN 5 5 S. TUFTON D. WESTER MWD RUN 8 8 S. TUFTON F. HERBERT 12 I1N 10E 87.20 59.20 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) .... '... ..... ~ -" ~'.- \. '... ~ - 'I ¡" . ."'t.. . . ) # REMARKS: 3RD STRING PRODUCTION STRING 9.875 6.750 7361.0 13626.0 Tape Subfile: 1 PER CONOCOPHILLIPS ALASKA REQUEST, THE GAMMA RAY 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 - 3724' TVD). (3) Baker Hughes INTEQ sidetrack runs 5 through 8 utilized Multiple Propagation Resistivity (MPR) and Gamma Ray services in a steerable assembly from 7359 - 13626 feet MD (3703 - 3771' TVD). REMARKS: (1) Commenced LWD logging at 2688 feet MD (1977' TVD) (2) Depth of 7 5/8" Casing Window-Logger: 7376 feet MD (3707' TVD) Depth of 7 5/8" Casing Window-Driller:7375 feet MD (3707' TVD) Top of 7 5/8" Casing Window: 7361 feet MD (3703' TVD) Bottom of 7 5/8" Casing Window: 7375 feet MD ( 37 0 7' TVD ) 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 7375 feet MD (3707' TVD). (3) Commenced LWD logging at 7375 feet MD (3707' TVD). (4) Commenced drilling sidetrack 2 (run 6, 1C-178L1PB2 & 1C-178L1) at 7440 feet MD (3720' TVD). (5) Spiral borehole conditions resulting in adverse cyclic resistivity responses are evident below 7900 feet MD ( 3716' TVD). (6) Commenced drilling final sidetrack (run 6, 1C-178L1) at 9050 feet MD (3722' TVD). (7) The interval from 10747 to 10778 feet MD (3733-3733' TVD) was logged up to 22.4 hours after being drilled due to a trip for an MWD failure. (8) The interval from 11869 to 11900 feet MD (3741-3740' TVD) was logged up to 37.9 hours after being drilled due to a trip out of the hole for a Gyro run. (9) The interval from 13592 to 13626 feet MD (3769-3771' TVD) was not logged due to sensor-bit offset at TD. $ 99 records... Minimum record length: Maximum record length: 8 bytes 132 bytes LDWG .001 **** FILE HEADER **** 0.0 0.0 0.0 0.0 GRAM RPD RPM RPS GR RPD RPM RPS GR RPD RPM RPS ODEP ---------------------------------------------------- *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM lc178Ll 5.xtf 150 ConocoPhillips Alaska, Inc. lC-178Ll Kuparuk River North Slope Alaska WDFN LCC CN WN FN COUN STAT ------------------------------------ *** INFORMATION TABLE: CONS MNEM VALU $ 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 7375' MD due to the change in resistivity tools. MERGE BASE 7375.0 7440.0 10747.0 11869.0 13626.0 MERGE TOP 2559.0 7375.0 7440.0 10747.0 11869.0 BIT RUN NO 2 5 6 7 8 # REMARKS: BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- STOP DEPTH 13626.0 START DEPTH 2559.0 clipped curves; all bit runs merged. .5000 LDWG File Version 1.000 Extract File: FILEOOl.HED ) 1 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ *** *** LIS COMMENT RECORD ') # 1024 ) ) 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 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 OHIvIM 4 4 3 RPM MWD 68 1 OHIvIM 4 4 4 RPS MWD 68 1 OHIvIM 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 Total Data Records: 791 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2559.000000 13626.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 839 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** ! ! !!! ! !! !! !!!! ! !!!! LDWG File Version 1.000 ) ) ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: FILEOll.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUJYJMARY VENDOR TOOL CODE MWD $ 2 log header data for each bit run in separate files. 2 .2500 START DEPTH 2559.0 STOP DEPTH 7375.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO 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): # 09-APR-03 MSB 18704 6. 75 ATK MEMORY 7739.0 2559.0 7375.0 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 presented for run 1. This wellbore was sidetracked off this bit run beginning at 7359' MD. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) REMARKS: ) ) 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) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 1c178L1.xtf 150 ConocoPhillips Alaska, I 1C-178L1 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 TOOL NUMBER SDS 34690 MPR 1150 75.1 94.8 MSB 18704 4.75 MPR MEMORY 7440.0 7375.0 7440.0 o 18-APR-03 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DIR DIRECTIONAL MPR MULT. PROP. RESIST. # # 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 7440.0 START DEPTH 7375.0 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. 5 .2500 3 ! ! !!! !!! ! !!! !! ! !! !! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE012.HED *** LIS COMMENT RECORD *** 1024 LDWG .003 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 783 records... Tape Subfile: 3 **** FILE TRAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2559.000000 7375.000000 0.250000 689 Total Data Records: 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 ) ) ) GRAM $ SRIG 60365 GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.750 7375.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Baradril-N 8.95 .0 .0 14000 .0 .000 .000 .000 .000 75.0 .0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 5 (MWD Run 5) . GR/MPR This wellbore was sidetracked off this bit run (5) at 7440 feet MD. Bit run 5 continues deeper on the 1C-178L1PB1 wellbore. 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 1c178L1.xtf 150 ConocoPhillips Alaska, I 1C-178L1 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: 14 Tape File Start Depth 7375.000000 Tape File End Depth 7440.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet **** FILE TRAILER **** Tape Subfile: 4 116 records... Minimum record length: 8 bytes 88.0 .0 .0 .0 .000 .000 .000 .000 Baradril 9.15 .0 .0 30000 .0 6.750 7375.0 TOOL NUMBER SDS 1363 MPR 1074 SRIG 5318 84.5 94.8 MSB 18704 4.75 MPR MEMORY 10778.0 7440.0 10747.0 o 21-APR-03 # 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 10747.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ START DEPTH 7440.0 log header data for each bit run in separate files. 6 .2500 4 !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: FILE013.HED *** LIS COMMENT RECORD *** 1024 LDWG .004 **** FILE HEADER **** 4124 bytes Maximum record length: ) ) ) ) NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 6 (MWD Run 6). 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 lc178Ll.xtf 150 ConocoPhillips Alaska, I lC-178Ll Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM RPCL RPSL RPCH RPSH RACL RASL RACH RASH ROPS RPTH TCDM GRAM RPCL RPSL RPCH RPSH RACL RASL RACH RASH ROPS RPTH TCDM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 GRAM RPD RPM RPS RPX RACLM RACSLM RACHM RACSHM ROPS RPTHM TCDM * 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 log header data for each bit run in separate files. 7 .2500 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: 5 !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! ! !!!! !!! !! !!! ! !!!! Extract File: FILE014.HED *** LIS COMMENT RECORD *** 1024 LDWG .005 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 796 records... Tape Subfile: 5 **** FILE TRAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7440.000000 10747.000000 0.250000 697 Total Data Records: 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 0.250 * F FRAME SPACE = 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 ) ) ) # FILE Sm1MARY VENDOR TOOL CODE START DEPTH MWD 10747.0 $ STOP DEPTH 11869.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. 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): # ) 22-APR-03 MSB 18704 4.75 MPR MEMORY 11900.0 10747.0 11869.0 o 85.6 91. 0 TOOL NUMBER SDS 1363 MPR 1150 SRIG 60365 6.750 7375.0 Baradril 9.45 .0 .0 40000 .0 .000 .000 .000 .000 83.0 .0 .0 .0 .00 .000 .0 o BIT RUN 7 (MWD Run 7) . GR/MPR CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWÐ-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: REMARKS: ) 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 lc178Ll.xtf 150 ConocoPhillips Alaska, I lC-178Ll 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 TOOL NUMBER SDS 7027 85.7 91.4 MSB 18704 4.75 MPR MEMORY 13626.0 11869.0 13626.0 o 25-APR-03 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DIR DIRECTIONAL # # 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 13626.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ START DEPTH 11869.0 log header data for each bit run in separate files. 8 .2500 6 ! ! !!!! ! !! !!! !!! !!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE015.HED *** LIS COMMENT RECORD *** 1024 LDWG .006 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 336 records... Tape Subfile: 6 **** FILE TRAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 10747.000000 11869.000000 0.250000 237 Total Data Records: 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 ) ) MPR GRAM $ # ) MULT. PROP. 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): # REMARKS: # ) MPR 1023 SRIG 5269 6.750 7375.0 Baradril 9.35 .0 .0 45000 .0 .000 .000 .000 .000 83.0 .0 .0 .0 .00 .000 .0 o BIT RUN 8 (MWD Run 8). 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 lc178L1.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1C-178Ll FN Kuparuk River COUN North Slope STAT 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: 370 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 11869.000000 13626.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 7 469 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes ) **** TAPE TRAILER **** LDWG 03/06/18 01 **** REEL TRAILER **** LDWG 03/06/18 AWS 01 Tape Subfile: 8 Minimum record length: Maximum record length: ) 2 records... 132 bytes 132 bytes ) c9ô,3 -o~ ~ IB03~ **** REEL HEADER **** LDWG 03/06/17 AWS 01 **** TAPE HEADER **** LDWG 03/06/17 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 lC-178LlPBl 500292314470 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 17-JUN-03 JOB NQMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 1 C. MEYER F. HERBERT MWD RUN 2 2 C. WONG D. GLADDEN MWD RUN 5 5 C. MEYER D. WESTER # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 IlN 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 :':1' I.."~ ~~~:"':.-" .i".t¡',~ ~ \. ~'.~ :,:rl-~~ ~ ~.:.:. .'. . "~l :...' -'."". PER CONOCOPHILLIPS ALASKA REQUEST, THE G~~"RÄ.}':~· ~.".-;; ,; ;.,' ~"'" 9.875 6.750 7361.0 7637.0 # REMARKS: ~] :,-:: ~ ('~~ .'~~~ J~_ ,,.(.. ~~~\\f'\.~ !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: FILE001.HED FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # *** LIS COMMENT RECORD *** 1024 LDWG .001 **** FILE HEADER **** 8 bytes 132 bytes Minimum record length: Maximum record length: 82 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 sidetrack run 5 utilized Multiple Propagation Resistivity (MPR) and Gamma Ray services in a steerable assembly from 7359 - 7637 feet MD (3703 - 3707' TVD). REMARKS: (1) Commenced LWD logging at 2688 feet MD (1977' TVD) (2) Depth of 7 5/8" Casing Window-Logger: 7376 feet MD (3707' TVD) Depth of 7 5/8" Casing Window-Driller:7375 feet MD (3707' TVD) Top of 7 5/8" Casing Window: 7361 feet MD (3703' TVD) Bottom of 7 5/8" Casing Window: 7375 feet MD (3707' TVD) 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 7376 feet MD (3707' TVD). (3) Commenced LWD logging at 7375 feet MD (3707' TVD). (4) The interval from 7606 to 7637 feet MD (3711-3707' TVD) was not logged due to sensor-bit offset at TD. $ ) ) ) ) FILE SUMMARY PBU TOOL CODE MWD $ START DEPTH 2559.0 STOP DEPTH 7637.0 # 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 5 MERGE TOP 2559.0 7375.0 MERGE BASE 7375.0 7637.0 # 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 7375' MD due to the change in resistivity tools. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT lc178pbl 5.xtf 150 - ConocoPhillips Alaska, Inc. lC-178LlPBl 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 ONE DEPTH PER FRAME MSB 18704 6.75 ATK MEMORY 7739.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): 09-APR-03 STOP DEPTH 7375.0 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: 408 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 7637.000000 0.500000 363 Total Data Records: 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 ) , ) 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): REMARKS: # ) 2559.0 7375.0 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 presented for run 1. This wellbore was sidetracked off this bit run beginning at 7359' MD. 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) $ *** INFORMATION TABLE: CONS MNEM VALU WDFN 1c178pb1.xtf -------------------------------- ) LCC CN WN FN COUN STAT 150 ConocoPhillips Alaska, I lC-178LIPBl 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: 689 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2559.000000 7375.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 783 records... Minimum record length: 8 bytes 75.0 .0 .0 .0 .000 .000 .000 .000 Baradril-N 8.95 .0 .0 14000 .0 6.750 7375.0 TOOL NUMBER SDS 34690 MPR 1150 SRIG 60365 75.1 94.8 MSB 18704 4.75 MPR MEMORY 7637.0 7375.0 7637.0 o 18-APR-03 # 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 7637.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUJVJMARY VENDOR TOOL CODE MWD $ START DEPTH 7375.0 log header data for each bit run in separate files. 5 .2500 3 ! !!!!!!!!! !! !!! ! !!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE012.HED *** LIS COMMENT RECORD *** 1024 LDWG .003 **** FILE HEADER **** 4124 bytes Maximum record length: ) ) ,) NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 5 (MWD Run 5) . 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 lcl78pbl.xtf 150 ConocoPhillips Alaska, I lC-178LIPBl Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM RPCL RPSL RPCH RPSH RACL RASL RACH RASH ROPS RPTH TCDM GRAM RPCL RPSL RPCH RPSH RACL RASL RACH RASH ROPS RPTH TCDM GRAM RPD RPM RPS RPX RACLM RACSLM RACHM RACSHM ROPS RPTHM TCDM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 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: 56 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7375.000000 7637.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 155 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 03/06/17 01 **** REEL TRAILER **** LDWG 03/06/17 AWS 01 ) Tape Subfile: 5 Minimum record length: Maximum record length: ) 2 records... 132 bytes 132 bytes ¡¡", J OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) MWD RUN 5 5 S. TUFT ON D. WESTER MWD RUN 87.20 59.20 12 IlN 10E MWD RUN 2 2 C. WONG D. GLADDEN MWD RUN lC-178LlPB2 500292314471 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 17-JUN-03 éj03--üL-! ~ 1 &0 3~~ .,..., ç:--' ~ 'b~\~\~ 1ST STRING 2ND STRING # WELL CASING RECORD # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MWD RUN 1 1 C. MEYER F. HERBERT MWD RUN 6 6 C. MEYER D. WESTER LDWG File Version 1.000 Extract File: LISTAPE.HED ) JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! TAPE HEADER KUPARUK RIVER UNIT MWD /MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA *** *** LIS COMMENT RECORD 01 **** TAPE HEADER **** LDWG 03/06/17 AWS 01 **** REEL HEADER **** LDWG 03/06/17 , \"L, ) ) # REMARKS: 3RD STRING PRODUCTION STRING 7361. 0 9962.0 Tape Subfile: 1 9.875 6.750 PER CONOCOPHILLIPS ALASKA REQUEST, THE GAMMA RAY 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 - 3724' TVD). (3) Baker Hughes INTEQ sidetrack runs 5 & 6 utilized Multiple Propagation Resistivity (MPR) and Gamma Ray services in a steerable assembly from 7359 - 9962 feet MD (3703 - 3738' TVD). REMARKS: (1) Commenced LWD logging at 2688 feet MD (1977' TVD) (2) Depth of 7 5/8" Casing Window-Logger: 7376 feet MD (3707' TVD) Depth of 7 5/8" Casing Window-Driller: 7375 feet MD (3707' TVD) Top of 7 5/8" Casing Window: 7361 feet MD (3703' TVD) Bottom of 7 5/8" Casing Window: 7375 feet MD ( 37 07' TVD ) 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 7375 feet MD (3707' TVD). (3) Commenced LWD logging at 7375 feet MD (3707' TVD). (4) Commenced drilling sidetrack 2 (run 6) at 7440 feet MD (3720' TVD). (5) Spiral borehole conditions resulting in adverse cyclic resistivity responses are evident below 7900 feet MD (3716' TVD). (6) The interval from 9931 to 9962 feet MD (3737-3738' TVD) was not logged due to sensor-bit offset at TD. $ 91 records... Minimum record length: Maximum record length: 8 bytes 132 bytes LDWG .001 **** FILE HEADER **** 1024 *** LIS COMMENT RECORD *** 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) ODEP ---------------------------------------------------- *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM lc178pb2_5.xtf 150 ConocoPhillips Alaska, Inc. lC-178LlPB2 Kuparuk River North Slope Alaska WDFN LCC CN WN FN COUN STAT ------------------------------------ *** INFORMATION TABLE: CONS MNEM VALU # $ 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 7375' MD due to the change in resistivity tools. MERGE BASE 7375.0 7440.0 9962.0 MERGE TOP 2559.0 7375.0 7440.0 BIT RUN NO 2 5 6 # REMARKS: BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- STOP DEPTH 9962.0 START DEPTH 2559.0 clipped curves; all bit runs merged. .5000 LDWG File Version 1.000 Extract File: FILEOOl.HED ) 1 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ ) STOP DEPTH START DEPTH FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE log header data for each bit run in separate files. 2 .2500 2 !!!!! !!!!! !!! !! ! !!! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: FILEOll.HED *** LIS COMMENT RECORD *** 1024 LDWG .002 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 575 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 9962.000000 0.500000 529 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 0.500 * F FRAME SPACE = 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 ) ) MWD $ 2559.0 7375.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO 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): # ) 09-APR-03 MSB 18704 6.75 ATK MEMORY 7739.0 2559.0 7375.0 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 presented for run 1. This wellbore was sidetracked off this bit run beginning at 7359' MD. 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) REMARKS: ) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT lcl78pb2.xtf 150 ConocoPhillips Alaska, I lC-178LIPB2 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: 689 Baradril-N 8.95 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): # 6.750 7375.0 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # TOOL NUMBER SDS 34690 MPR 1150 SRIG 60365 BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. RESIST. GAMMA RAY TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ # 75.1 94.8 # 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: MSB 18704 4.75 MPR MEMORY 7440.0 7375.0 7440.0 o 18-APR-03 STOP DEPTH 7440.0 START DEPTH 7375.0 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. 5 .2500 3 !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !! !!! ! ! !! !! !! ! ! !!!! Extract File: FILE012.HED *** LIS COMMENT RECORD *** 1024 LDWG .003 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 783 records... Tape Subfile: 3 **** FILE TRAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2559.000000 7375.000000 0.250000 ) 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: # ) .0 .0 14000 .0 .000 .000 .000 .000 75.0 .0 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): o # REMARKS: # .0 BIT RUN 5 (MWD Run 5) . GR/MPR This wellbore was sidetracked off this bit run (5) at 7440 feet MD. Bit run 5 continues deeper on the lC-178LlPBl wellbore. 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 lc178pb2.xtf 150 ConocoPhillips Alaska, I lC-178LlPB2 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 OH:MM: 4 4 3 RPSL MWD 68 1 OH:MM: 4 4 4 RPCH MWD 68 1 OH:MM: 4 4 5 RPSH MWD 68 1 OH:MM: 4 4 6 RACL MWD 68 1 OH:MM: 4 4 7 RASL MWD 68 1 OH:MM: 4 4 8 RACH MWD 68 1 OH:MM: 4 4 9 RASH MWD 68 1 OH:MM: 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: 14 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7375.000000 7440.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 116 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .004 1024 o .0 .00 .000 88.0 .0 .0 .0 .000 .000 .000 .000 Baradril-N 9.20 .0 .0 30000 .0 6.750 7375.0 TOOL NUMBER SDS 1363 MPR 1074 SRIG 5318 75.1 94.8 MSB 18704 4.75 MPR MEMORY 9962.0 7440.0 9962.0 o 20-APR-03 BIT RUN 6 (MWD Run 6). GR/MPR REMARKS: # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # 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 9962.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ START DEPTH 7440.0 log header data for each bit run in separate files. 6 .2500 4 !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: FILE013.HED *** LIS COMMENT RECORD *** ) ') ) 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 lc178pb2.xtf 150 ConocoPhillips Alaska, I lC-178LlPB2 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: 531 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7440.000000 9962.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 5 630 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 03/06/17 01 **** REEL TRAILER **** LDWG 03/06/17 AWS 01 Tape Subfile: 6 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes