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Home My WebLink About203-0321. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Pull LT Packer 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11207' None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 1/23/2024 11111'2266' 3-1/2" Packer: Baker S-3 Perm Packer Packer: NS AK Mono-Pak LT Packer SSSV: Camco TRDP-4E Safety Valve (Locked out) Perforation Depth MD (ft): L-80 6209' 9096-9141' 9354' 2-3/8" 6576-6616' 7" Perforation Depth TVD (ft): 121' 6249' 6843'9393' 16" 9-5/8" 80' 8977' MD 121' 4488' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0028242 203-032 P.O. Box 100360, Anchorage, AK 99510 50-029-22932-60-00 Kuparuk River Field Kuparuk River Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 8919' MD and 6417' TVD 8840' MD and 6345' TVD 2019' MD and 1796' TVD Allen Eschete Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: allen.eschete@conocophillips.com (907) 265-6558 Interventions Engineer KRU 1C-15L1 6629' 11207' 6629' None N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 6638' By Grace Christianson at 7:55 am, Jan 11, 2024 Digitally signed by Allen Eschete DN: CN=Allen Eschete, E=Allen.Eschete@ ConocoPhillips.com Reason: I am the author of this document Location: Date: 2024.01.10 13:52:52-09'00' Foxit PDF Editor Version: 13.0.0 Allen Eschete DSR-2/15/24 SFD ADL0025649, VTL 02/15/2024 X SFD 1/12/2024 1400 X 10-404 JLC 2/15/2024 KRU 1C-15 (PTD 198-229), KRU 1C-15L1 (PTD203-032), KRU 1C-15L2 (PTD 222-029) Well Work Jus ca on & Objec ves 1C-15 is a dual lateral CTD injector. The L2 lateral was drilled in April 2023, and a liner top packer was set to shut o the original L1 and focus injec on into L2. Performance over the past year has been lackluster, and we want to reopen the L1 lateral to allow injec on into both zones. This procedure is to harvest a SBHP in the isolated L2 fault block to help diagnose performance in this zone, before pulling the LTP to allow WAG injec on into both laterals. Risks/Job Concerns Min ID (1.781") is Northern Solu ons AK Mono-Pak Liner Top Packer with 1.781" RX nipple @ 8840' RKB Last tag was in L2 during CT FCO. Note break in liner in L2 from 10,002' to 10,118' RKB Max inclina on and dog leg are given for L2 liner, no need to access these during this work. Slickline 1. Verify with PE that well has been SI for 3 days minimum (72 hours) 2. MIRU SL, D&T with bailer as deep as possible. Note tag depth, suspected reasons for high tag, nature of ll/bailer returns, and any other details in WSR, as applicable. 3. Obtain SBHP with dual SPARTEK gauges a) Perform 10 minute lubricator stop b) 30 minute stop @ 8840' RKB (6345' TVD) c) Pull up 100' TVD to 8728' RKB (6245' TVD) for 15 minute gradient stop d) Record ndings on WSR 4. Pull Northern Solu ons AK Mono-Pak Liner Top Packer from top of liner at 8840' RKB. 5. POOH, RD. Return well to DSO to BOL when ready. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 9,320.0 1C-15 12/7/2011 ninam Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Liner Top Packer 1C-15 3/30/2022 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 11/17/2010 ninam NOTE: 1C-15L1 DRILLED 4/15/03, 1C-15 PERFS LEFT OPEN 1C-15L1 4/15/2003 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 41.0 121.0 121.0 62.58 H-40 WELDED SURFACE 9 5/8 8.83 40.4 6,249.3 4,488.5 40.00 L-80 BTC PRODUCTION 7 6.28 38.5 9,392.7 26.00 L-80 ABM-BTC WINDOW L1 7 6.00 9,142.0 9,147.0 6,621.5 26.00 L-80 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.6 Set Depth 8,976.5 Set Depth 6,468.1 String Max No 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE ID (in) 2.99 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) 36.6 36.6 0.00 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 2,019.3 1,796.2 49.18 SAFETY VLV 5.250 CAMCO TRDP-4E SAFETY VALVE (LOCKED OUT 7/16/2004) 2.812 3,324.9 2,602.4 51.58 GAS LIFT 5.500 CAMCO KBMM 2.920 5,349.2 3,907.5 50.32 GAS LIFT 5.500 CAMCO KBMM 2.920 6,592.1 4,709.3 49.76 GAS LIFT 5.500 CAMCO KBMM 2.920 7,553.6 5,339.8 48.22 GAS LIFT 5.500 CAMCO KBMM 2.920 8,330.6 5,905.9 35.35 GAS LIFT 5.500 CAMCO KBMM 2.920 8,826.5 6,333.3 26.13 GAS LIFT 5.500 CAMCO MMM 2.371 8,876.2 6,377.9 26.07 NIPPLE 4.540 CAMCO W NIPPLE 2.812 8,919.3 6,416.7 26.08 PACKER 5.968 BAKER S-3 PERMANENT PACKER 3.875 8,964.5 6,457.3 25.98 NIPPLE 4.470 CAMCO D NIPPLE 2.75" ID - MILLED OUT TO 2.80" ID 2/5/2003 2.800 8,975.6 6,467.3 25.94 SOS 4.520 BAKER SHEAR OUT SUB 3.000 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) 8,840.0 6,345.4 26.05 PACKER Set NothernSolutions AK Mono-Pak Liner Top Packer w/ 1.781" RX nipple @ 8848' RKB (See Attachments) A2242 7201- R00 3/30/2022 1.781 PATCH SURF CSG PATCH install from bottom of starter head to top of pup collar 1' 11.5", used 9 5/8" 40 #, .395 pipe for patch material 4/10/2009 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,324.9 2,602.4 51.58 1 GAS LIFT DMY BK 1 0.0 7/16/2004 0.000 5,349.2 3,907.5 50.32 2 GAS LIFT DMY BK 1 0.0 7/16/2004 0.000 6,592.1 4,709.3 49.76 3 GAS LIFT DMY BK 1 0.0 7/16/2004 0.000 7,553.6 5,339.8 48.22 4 GAS LIFT DMY BK 1 0.0 7/16/2004 0.000 8,330.6 5,905.9 35.35 5 GAS LIFT DMY BK-5 1 0.0 2/12/2003 0.000 8,826.5 6,333.3 26.13 6 GAS LIFT DMY RK 1 1/2 0.0 7/16/2004 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,096.0 9,106.0 6,575.6 6,584.6 C-4, 1C-15 2/17/2002 6.0 APERF 2.5" HSD PJ Chgs, 60 deg phase 9,106.0 9,126.0 6,584.6 6,602.7 C-3, 1C-15 12/30/1998 4.0 IPERF 2.5" HC DP 9,126.0 9,141.0 6,602.7 6,616.2 C-3, 1C-15 2/17/2002 6.0 APERF 2.5" HSD PJ Chgs, 60 deg phase Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 9,096.0 9,142.0 1 FRAC 1/11/1999 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 9,141.0 9,390.0 6,616.2 Kickoff Plug cement plug bottom to 9141rkb 3/28/2003 1C-15, 1/9/2024 12:16:52 PM Vertical schematic (actual) L2 lateral; 8,953.0-12,235.0 PRODUCTION; 38.5-9,392.7 WINDOW L1; 9,142.0-9,147.0 LINER; 8,845.3-11,111.0 Kickoff Plug; 9,141.0 ftKB APERF; 9,126.0-9,141.0 FRAC; 9,096.0 IPERF; 9,106.0-9,126.0 WHIPSTOCK; 9,108.0 APERF; 9,096.0-9,106.0 PACKER; 8,919.3 PACKER; 8,840.0 GAS LIFT; 8,330.6 GAS LIFT; 7,553.6 GAS LIFT; 6,592.1 SURFACE; 40.4-6,249.3 GAS LIFT; 5,349.2 GAS LIFT; 3,324.9 SAFETY VLV; 2,019.3 CONDUCTOR; 41.0-121.0 KUP INJ KB-Grd (ft) 46.51 RR Date 12/15/199 8 Other Elev 1C-15 ... TD Act Btm (ftKB) 9,390.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292293200 Wellbore Status INJ Max Angle & MD Incl (°) 52.92 MD (ftKB) 2,783.33 WELLNAME WELLBORE1C-15 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: LOCKED OUT Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 9,348.0 1C-15L1 6/28/2019 hazenmc Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: CUT LINER 1C-15L1 2/4/2022 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: (Multi-Lat) 1C-15L1 DRILLED 4/15/2003, EXITS TO C-SANDS THRU ORIGINAL WELLBORE 1C-15 CMT PLUG 4/15/2003 lmosbor NOTE: EXITS TO C-SANDS THRU CMT PLUG IN 1C-15 WELLBORE; PRODUCE THRU BOTH LEGS 4/15/2003 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread LINER 2.38 1.92 8,845.3 11,111.0 4.43 L-80 STL 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) 9,108.0 6,586.4 25.80 WHIPSTOCK NS HEW 8.75' long Northern Solutions HE 3/16/2022 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) 8,845.3 6,350.2 26.05 DEPLOY 2.700 BAKER DEPLOYMENT SLEEVE w/ 3" GS 2.250 11,072.7 O-RING 1.380 BAKER O-RING SUB 1.000 11,105.4 XO THREAD 2.380 XO 1.920 11,108.9 XO THREAD 2.380 XO 1.900 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,344.0 11,075.0 C-3, C-4, C-3, 1C-15L1 4/12/2003 4.0 SLOTS SLOTTED LINER 1C-15L1, 1/9/2024 12:16:55 PM Vertical schematic (actual) LINER; 8,845.3-11,111.0 SLOTS; 10,344.0-11,075.0 PRODUCTION; 38.5-9,392.7 L2 lateral; 8,953.0-12,235.0 Kickoff Plug; 9,141.0 ftKB APERF; 9,126.0-9,141.0 FRAC; 9,096.0 IPERF; 9,106.0-9,126.0 WHIPSTOCK; 9,108.0 APERF; 9,096.0-9,106.0 PACKER; 8,919.3 PACKER; 8,840.0 GAS LIFT; 8,330.6 GAS LIFT; 7,553.6 GAS LIFT; 6,592.1 SURFACE; 40.4-6,249.3 GAS LIFT; 5,349.2 GAS LIFT; 3,324.9 SAFETY VLV; 2,019.3 CONDUCTOR; 41.0-121.0 KUP INJ KB-Grd (ft) 46.51 RR Date 12/15/199 8 Other Elev 1C-15L1 ... TD Act Btm (ftKB) 11,207.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292293260 Wellbore Status INJ Max Angle & MD Incl (°) 52.92 MD (ftKB) 2,783.33 WELLNAME WELLBORE1C-15 Annotation Last WO: End Date 4/13/2003 H2S (ppm) DateComment SSSV: LOCKED OUT Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L2 lateral 2 3/8 1.99 8,953.0 12,235.0 6,566.7 4.70 L-80 ST-L 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) 9,241.6 6,660.8 85.97 Swell Packer 2.700 Swell Packer - Reactive Reactive Swell Pkr. 1.686 10,118.5 6,588.3 85.52 Deployment Sleeve 2.375 NSAK 350-238, QCLL Receptical - L80 Northern Solutions 1.920 11,192.9 6,599.4 92.89 Deployment Sleeve 2.375 NSAK 350-238, QCLL Receptical - L80 Northern Solutions 1.920 1C-15L2, 1/9/2024 12:16:55 PM Vertical schematic (actual) L2 lateral; 8,953.0-12,235.0 PRODUCTION; 38.5-9,392.7 WINDOW L1; 9,142.0-9,147.0 LINER; 8,845.3-11,111.0 Kickoff Plug; 9,141.0 ftKB APERF; 9,126.0-9,141.0 FRAC; 9,096.0 IPERF; 9,106.0-9,126.0 WHIPSTOCK; 9,108.0 APERF; 9,096.0-9,106.0 PACKER; 8,919.3 PACKER; 8,840.0 GAS LIFT; 8,330.6 GAS LIFT; 7,553.6 GAS LIFT; 6,592.1 SURFACE; 40.4-6,249.3 GAS LIFT; 5,349.2 GAS LIFT; 3,324.9 SAFETY VLV; 2,019.3 CONDUCTOR; 41.0-121.0 KUP INJ KB-Grd (ft) 46.51 RR Date 12/15/199 8 Other Elev 1C-15L2 ... TD Act Btm (ftKB) 12,784.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292293261 Wellbore Status INJ Max Angle & MD Incl (°) 103.09 MD (ftKB) 9,278.41 WELLNAME WELLBORE1C-15 Annotation End DateH2S (ppm) DateComment 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: Pull LT Packer 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 11207'feet None feet true vertical 6629' feet None feet Effective Depth measured 11207'feet 8919'feet true vertical 6629' feet 6417' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 6468' TVD Packers and SSSV (type, measured and true vertical depth) 8919' MD 2019' MD 6417' TVD 1796' TVD 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: Kuparuk River 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: 6249' 4488' Burst Collapse Production Liner 9354' 2266' Casing 2-3/8" 11111' 6638' 6209' 121'Conductor Surface Intermediate 16" 9-5/8" 80' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-032 50-029-22932-60-00 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: ADL0028242, ADL0025649 Kuparuk River Field/ Kuparuk River Oil Pool KRU 1C-15L1 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 121' ~ ~~ INJECTOR ~~ ~ 324-010 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker S-3 Perm Packer SSSV: Camco TRDP-4E Sfty Vlv (locked out) Allen Echete allen.eschete@conocophillips.com (907) 265-6558Intervention Engineer Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 9393' 6843' 8977' MD 9096-9141', 10344' - 11075' 6576-6616', 6675' - 6641' By Grace Christianson at 3:04 pm, Apr 22, 2024 Digitally signed by Allen Eschete DN: CN=Allen Eschete, E=Allen.Eschete@ ConocoPhillips.com Reason: I am the author of this document Location: Date: 2024.04.22 08:36:05-08'00' Foxit PDF Editor Version: 13.0.0 Allen Eschete DSR-4/23/24 DTTMSTART JOBTYP SUMMARYOPS 3/7/2024 OPTIMIZE WELL DRIFT TBG W/ 2.5" CENT, 1.75" S-BAILER TO LINER TOP PACKER @ 8840' RKB, NO OBSTRUCTIONS FOUND. LDFN, JOB IN PROGRESS. 3/8/2024 OPTIMIZE WELL MEASURE SBHP 5005 psi @ 8840' RKB, DRIFTED TBG W/ 2.75" GAUGE RING TO LTP @ 8840' RKB. LDFN, JOB IN PROGRESS. 3/12/2024 OPTIMIZE WELL MADE ATTEMPT TO PULL LTP @ 8840' RKB, SHEARED PULLING TOOL. RDMO TEMP - 36. JOB IN PROGRESS. 3/15/2024 OPTIMIZE WELL ATTEMPT TO PULL LTP @ 8840' RKB, JOB IN PROGRESS 3/16/2024 OPTIMIZE WELL ATTEMPT TO PULL LTP @ 8840' RKB, JOB SUSPENDED, WIll RETURN WITH .160 WIRE. 3/26/2024 OPTIMIZE WELL ATTEMPT TO PULL LTP W/ .160 WIRE @ 8840'RKB. JOB IN PROGRESS 3/28/2024 OPTIMIZE WELL PULLED LINER TOP PACKER ASSEMBLY @ 8840'RKB, RECOVERED ELEMENT DEBRIS FROM 8840'RKB. JOB COMPLETE 1C-15 Remove Liner Top Packer Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 9,320.0 1C-15 12/7/2011 ninam Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled LTP 1C-15 3/28/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 11/17/2010 ninam NOTE: 1C-15L1 DRILLED 4/15/03, 1C-15 PERFS LEFT OPEN 1C-15L1 4/15/2003 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 41.0 121.0 121.0 62.58 H-40 WELDED SURFACE 9 5/8 8.83 40.4 6,249.3 4,488.5 40.00 L-80 BTC PRODUCTION 7 6.28 38.5 9,392.7 26.00 L-80 ABM-BTC WINDOW L1 7 6.00 9,142.0 9,147.0 6,621.5 26.00 L-80 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.6 Set Depth 8,976.5 Set Depth 6,468.1 String Max No 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE ID (in) 2.99 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) 36.6 36.6 0.00 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 2,019.3 1,796.2 49.18 SAFETY VLV 5.250 CAMCO TRDP-4E SAFETY VALVE (LOCKED OUT 7/16/2004) 2.812 3,324.9 2,602.4 51.58 GAS LIFT 5.500 CAMCO KBMM 2.920 5,349.2 3,907.5 50.32 GAS LIFT 5.500 CAMCO KBMM 2.920 6,592.1 4,709.3 49.76 GAS LIFT 5.500 CAMCO KBMM 2.920 7,553.6 5,339.8 48.22 GAS LIFT 5.500 CAMCO KBMM 2.920 8,330.6 5,905.9 35.35 GAS LIFT 5.500 CAMCO KBMM 2.920 8,826.5 6,333.3 26.13 GAS LIFT 5.500 CAMCO MMM 2.371 8,876.2 6,377.9 26.07 NIPPLE 4.540 CAMCO W NIPPLE 2.812 8,919.3 6,416.7 26.08 PACKER 5.968 BAKER S-3 PERMANENT PACKER 3.875 8,964.5 6,457.3 25.98 NIPPLE 4.470 CAMCO D NIPPLE 2.75" ID - MILLED OUT TO 2.80" ID 2/5/2003 2.800 8,975.6 6,467.3 25.94 SOS 4.520 BAKER SHEAR OUT SUB 3.000 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) PATCH SURF CSG PATCH install from bottom of starter head to top of pup collar 1' 11.5", used 9 5/8" 40 #, .395 pipe for patch material 4/10/2009 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,324.9 2,602.4 51.58 1 GAS LIFT DMY BK 1 0.0 7/16/2004 0.000 5,349.2 3,907.5 50.32 2 GAS LIFT DMY BK 1 0.0 7/16/2004 0.000 6,592.1 4,709.3 49.76 3 GAS LIFT DMY BK 1 0.0 7/16/2004 0.000 7,553.6 5,339.8 48.22 4 GAS LIFT DMY BK 1 0.0 7/16/2004 0.000 8,330.6 5,905.9 35.35 5 GAS LIFT DMY BK-5 1 0.0 2/12/2003 0.000 8,826.5 6,333.3 26.13 6 GAS LIFT DMY RK 1 1/2 0.0 7/16/2004 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,096.0 9,106.0 6,575.6 6,584.6 C-4, 1C-15 2/17/2002 6.0 APERF 2.5" HSD PJ Chgs, 60 deg phase 9,106.0 9,126.0 6,584.6 6,602.7 C-3, 1C-15 12/30/1998 4.0 IPERF 2.5" HC DP 9,126.0 9,141.0 6,602.7 6,616.2 C-3, 1C-15 2/17/2002 6.0 APERF 2.5" HSD PJ Chgs, 60 deg phase Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 9,096.0 9,142.0 1 FRAC 1/11/1999 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 9,141.0 9,390.0 6,616.2 Kickoff Plug cement plug bottom to 9141rkb 3/28/2003 1C-15, 4/16/2024 2:49:42 PM Vertical schematic (actual) L2 lateral; 8,953.0-12,235.0 PRODUCTION; 38.5-9,392.7 WINDOW L1; 9,142.0-9,147.0 LINER; 8,845.3-11,111.0 Kickoff Plug; 9,141.0 ftKB APERF; 9,126.0-9,141.0 FRAC; 9,096.0 IPERF; 9,106.0-9,126.0 WHIPSTOCK; 9,108.0 APERF; 9,096.0-9,106.0 PACKER; 8,919.3 GAS LIFT; 8,330.6 GAS LIFT; 7,553.6 GAS LIFT; 6,592.1 SURFACE; 40.4-6,249.3 GAS LIFT; 5,349.2 GAS LIFT; 3,324.9 SAFETY VLV; 2,019.3 CONDUCTOR; 41.0-121.0 KUP INJ KB-Grd (ft) 46.51 RR Date 12/15/199 8 Other Elev 1C-15 ... TD Act Btm (ftKB) 9,390.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292293200 Wellbore Status INJ Max Angle & MD Incl (°) 52.92 MD (ftKB) 2,783.33 WELLNAME WELLBORE1C-15 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: LOCKED OUT Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 9,348.0 1C-15L1 6/28/2019 hazenmc Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: CUT LINER 1C-15L1 2/4/2022 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: (Multi-Lat) 1C-15L1 DRILLED 4/15/2003, EXITS TO C-SANDS THRU ORIGINAL WELLBORE 1C-15 CMT PLUG 4/15/2003 lmosbor NOTE: EXITS TO C-SANDS THRU CMT PLUG IN 1C-15 WELLBORE; PRODUCE THRU BOTH LEGS 4/15/2003 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread LINER 2.38 1.92 8,845.3 11,111.0 4.43 L-80 STL 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) 9,108.0 6,586.4 25.80 WHIPSTOCK NS HEW 8.75' long Northern Solutions HE 3/16/2022 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) 8,845.3 6,350.2 26.05 DEPLOY 2.700 BAKER DEPLOYMENT SLEEVE w/ 3" GS 2.250 11,072.7 O-RING 1.380 BAKER O-RING SUB 1.000 11,105.4 XO THREAD 2.380 XO 1.920 11,108.9 XO THREAD 2.380 XO 1.900 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,344.0 11,075.0 C-3, C-4, C-3, 1C-15L1 4/12/2003 4.0 SLOTS SLOTTED LINER 1C-15L1, 4/16/2024 2:49:43 PM Vertical schematic (actual) LINER; 8,845.3-11,111.0 SLOTS; 10,344.0-11,075.0 L2 lateral; 8,953.0-12,235.0 PRODUCTION; 38.5-9,392.7 Kickoff Plug; 9,141.0 ftKB APERF; 9,126.0-9,141.0 FRAC; 9,096.0 IPERF; 9,106.0-9,126.0 WHIPSTOCK; 9,108.0 APERF; 9,096.0-9,106.0 PACKER; 8,919.3 GAS LIFT; 8,330.6 GAS LIFT; 7,553.6 GAS LIFT; 6,592.1 SURFACE; 40.4-6,249.3 GAS LIFT; 5,349.2 GAS LIFT; 3,324.9 SAFETY VLV; 2,019.3 CONDUCTOR; 41.0-121.0 KUP INJ KB-Grd (ft) 46.51 RR Date 12/15/199 8 Other Elev 1C-15L1 ... TD Act Btm (ftKB) 11,207.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292293260 Wellbore Status INJ Max Angle & MD Incl (°) 52.92 MD (ftKB) 2,783.33 WELLNAME WELLBORE1C-15 Annotation Last WO: End Date 4/13/2003 H2S (ppm) DateComment SSSV: LOCKED OUT Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L2 lateral 2 3/8 1.99 8,953.0 12,235.0 6,566.7 4.70 L-80 ST-L 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) 9,241.6 6,660.8 85.97 Swell Packer 2.700 Swell Packer - Reactive Reactive Swell Pkr. 1.686 10,118.5 6,588.3 85.52 Deployment Sleeve 2.375 NSAK 350-238, QCLL Receptical - L80 Northern Solutions 1.920 11,192.9 6,599.4 92.89 Deployment Sleeve 2.375 NSAK 350-238, QCLL Receptical - L80 Northern Solutions 1.920 1C-15L2, 4/16/2024 2:49:43 PM Vertical schematic (actual) L2 lateral; 8,953.0-12,235.0 PRODUCTION; 38.5-9,392.7 WINDOW L1; 9,142.0-9,147.0 LINER; 8,845.3-11,111.0 Kickoff Plug; 9,141.0 ftKB APERF; 9,126.0-9,141.0 FRAC; 9,096.0 IPERF; 9,106.0-9,126.0 WHIPSTOCK; 9,108.0 APERF; 9,096.0-9,106.0 PACKER; 8,919.3 GAS LIFT; 8,330.6 GAS LIFT; 7,553.6 GAS LIFT; 6,592.1 SURFACE; 40.4-6,249.3 GAS LIFT; 5,349.2 GAS LIFT; 3,324.9 SAFETY VLV; 2,019.3 CONDUCTOR; 41.0-121.0 KUP INJ KB-Grd (ft) 46.51 RR Date 12/15/199 8 Other Elev 1C-15L2 ... TD Act Btm (ftKB) 12,784.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292293261 Wellbore Status INJ Max Angle & MD Incl (°) 103.09 MD (ftKB) 9,278.41 WELLNAME WELLBORE1C-15 Annotation End DateH2S (ppm) DateComment TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop Kuparuk 1A-09 50-029-20669-00 181152_1A-09_IPROF_27May2022 1A-15 50-029-20711-00 182017_1A-15_iProf_02Jun2022 1A-22 50-029-22127-00 191003_1A-22_RBP-LSL_22June2022 191003_1A-22_SBHPS-RBP_09June2022 1B-101 50-029-23173-00 203133_1B-101_MechCut_24Jun2023 1B-14 50-029-22452-00 194030_1B-14_CHC_15Mar2022 194030_1B-14_RCT Cutter_24Feb2022 194030_1B-14_UPCT Cutter_20Jun2022 194030_1B-14_Whipstock_13Apr2022 19430_1B-14_CHC_21Mar2022 1C-09 50-029-20859-00 182185_1C-09_IPROF_15Jan2023 1C-133 50-029-23013-00 201077_1C-133_RBP_07Apr2022 1C-152 50-029-23548-00 215114_1C-152_IPROF_20Mar2023 1C-15L1 50-029-22932-60 203032_1C-15L1_CHC_04Feb2022 1D-01 50-029-20393-00 179059_1D-01_PPROF_25Jun2023 1of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38308 T38309 T38310 T38312 T38311 T38274 T38276 T38314 T38315 T38316 2/29/2024 1C-15L1 50-029-22932-60 203032_1C-15L1_CHC_04Feb2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:11:35 -09'00' • • ~~'~ -- , MICROFILMED 03/01/2008 DO NOT PLACE ,~`.-.. «~` '4 ~: ..k ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\CvrPgs_Inserts~Nlicrafilm Maricer.doc DATA SUBMITTA~h~~p~~~~-CE 5/10/2005 REPORT Permit to Drill 2030320 Well Name/No. KUPARUK RIV UNIT 1C-15L 1 Operator CONOCOPHILLlPS ALASKA INC Sp~ J-~A..ò-¿I J API No. 50-029-22932-60-00 MD 11207./ ND 6629,/' Completion Date 4/13/2003 Completion Status 1-01L Current Status WAGIN ~ --~-- REQUIRED INFORMATION Mud Log No Samples No Directional surve~ DATA INFORMATION Types Electric or Other Logs Run: MWD, GR Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ¡--- I I I I i i I I (data taken from Logs Portion of Master Well Data Maint) .---- Log Log Run Scale Media No Interval OH / Start Stop CH Rpt Directional Survey 9142 11207 5/15/2003 JD C Las 12408 Gamma Ray 9142 11207 Open 2/1 0/2004 Gamma Ray - MWD lED C Pdf 12408 Gamma Ray 5 9142 11207 Open 2/10/2004 Gamma Ray - MWD I O-og Gamma Ray 5 Blu 9142 11207 Open 2/10/2004 Gamma Ray - MWD ~~ Gamma Ray 9142 11207 Open 2/1 0/2004 Gamma Ray - MWD ~duction ~ c10g 15 Blu 1800 9122 Case 3/26/2004 Production Profile - PresslTemp/Gradio/CFS 'log ~ssure 15 Blu 1800 9122 Case 3/26/2004 Production Profile - PresslTemp/Gradio/CFS v1'Og 4perature 15 Blu 1800 9122 Case 3/26/2004 Production Profile - PresslTemp/Gradio/CFS ~Og ¿¢radiometer 15 Blu 1800 9122 Case 3/26/2004 Production Profile - L-______ PresslTemp/Gradio/CFS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 5/10/2005 Permit to Drill 2030320 Well Name/No. KUPARUK RIV UNIT 1C-15L 1 Operator CONOCOPHILLlPS ALASKA INC MD 11207 API No. 50-029-22932-60-00 TVD 6629 Completion Date 4/13/2003 Completion Status 1-01L Current Status WAGIN UIC Y Well Cored? ADDITIONAL INFORMATION yfù Daily History Received? Q,/N C2-N Formation Tops Chips Received? V 1 N Analysis Received? Comments: -- -------~- --- ~ J~ Date: Compliance Reviewed By: ,"-J / 3 Hj ~1- 1·;·?P~~tiq:nsR~rf6~êd: :.:i·...· ..··~b~r1dOTÇ1·.··· ../ ...... .....<, .":: ::AI~ørq~sih~Çr:: ··c~~fige~þpröv~q¡pr~gr~rr· :[]: ... 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 102' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION UPPER LATERAL . LEG UPPER LATERAL SLOTTED LINER Perioration depth: ) ) STATE OF ALASKA ¡ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS .. ........' ... Rep~ír~ell JJ.:. .. :' .....' '··.··;P91IT4bïOg D .. . . . ...... . ··PP~"~~.~þûtd9WdO·· .. .......·.~ti.fPyl~t:·P:..:.:9~~~L, .8,Prôd toMwÀG· ,". ·0 Waj:::~~_~j~;~~~~~~~~f: 0> >.. :e'\Jg.~ertôr@?hs;,tr, ... Perforate New Pool D . .. '"' .... .... .. . ........ . . '" . .. .. .. . .. . .. ." . . .. ... .. . . . . .. ..... ....... ... ........ .. .. , . . . ... . . .. .. ........ . . . . . . . . . . . . '" ... ... ........ ..... . . '¡¡<'~~ry~~~t7:!i::':O,· 5. Permit to Drill Number: 203-032 / 6. API Number: 50-029-22932-60 9. Well Name and Number: 1C-15L 1 10. Field/Pool(s): Kuparuk Oil Pool measured 11201' feet true vertical 6629' feet measured feet true vertical 6276' feet Length Size MD 121' 16" 121' 6141' 9-5/8" 6249' 9288' 7" 9390' 1499' 2-3/8" 10344' 761' 2-3/8" 11111' Plugs (measured) Junk (measured) TVD Burst Collapse 121' 4488' 6611' 6675' 6638' Measured depth: 10740-11099 true vertical depth: 6675-6640 :20/J/j Tubing (size, grade, and measured depth) 3-1/2" , L-80, 8977' MD. Packers & SSSV (type & measured depth) no packer SSSV= SSSV SSSV= 2019' 12.StimUläti6h .OrÖamarifsqÚéèiè somma.ry: Intervals treated (rneasured) N/A 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average ProductionorJnjection Data Gás~Mcf W ater~Bbl 89 794 1463 15. Well Class after proposed work: Exploratory D Development 0 Service 0 16. Well Status after proposed work: oilD GasD WAG0 GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run ~ Oil-Bbl 218 CasinqPressure TubinQPressure 267 25 1354 25 Daily Report of Well Operations _X WDSPLD Contact Printed Name /J Signature ß1. -orm 1 U- U4 Hevls d U Title Production Engineering Technic' ~Ä J Phone . fi51-7535 Date 77óZ¿yí:!> ¿v JUl ~ ~QR \ G \ N /-\ - ,',.;1111'"'' >; m'tjil'rl"'4 nl~ ..." Date Event Summary ') ') 1 C-15L 1 DESCRIPTION OF WORK COMPLETED SUMMARY 07/17/04ICompleted Producer to Injector Conversion. Commenced PWI injection l\ ; ,~ ! ;',",,!'; ,,~ ~-:~ : ~ , : '~t ~ ¡.. , JUL-29-2004 11:08 PHILLIPS AK INC ) . ConocoPhillips AI:~~:..lnç._ . ....... ,__ ..,,, API: 5Qº-~9229326() TÜBING SS$V Type: LOCKED OUT (0·8977. 00:3.500. 11:1:2.992) SURFACE (0.6249. 00:9.625. Wt40,OO) õlRODUOTION (0·9300. 00:7.000. W t:26. 00) NIP (8S"$-$$,.1. OD:4.S40) PACKER .., , (8918-8919, OO:e.900) NIP (S965-$96e. OO:4.470) 50S (8976-8977. OD::). ~OO} P~rf (9096-9106) P¡:rI' (910&e126) F'erf :10344-11111) ~.·~.I)' f.', ~. -11- =1= =1 '1= 1 907 265 6224 ) KRU P.03 1C-15L 1 Annular Fluid: 'Well Typð:'" PROD ,., Orig 4/1312003 Completion: Last W/O:" 4FÎ312003 ,__ Ref LQ!:J Ö~te: ." " TO: 1120.7.. ftKB ,.,. Mã~}!ol~.,AnQle; 105 deg (ã)J 0649 , . Anq!e @J TS; 26 deg.@ ~-~42 Angle @ TD: 96 deg @ 11207 Rev Reason; GLV design,"iock out SSSV Last J!pd~të:·-7123r.2004 Reference Lqq: 37' RKB LaJ't Taq¡, ,91"41 Last Tag Dat~:,,: ,~/3012003 Caslna String - ALL_STRINGS Description "" ... CONDUCTOR $V~FACE:." .,- PRODUCTION uppar Lat~r.ªï LeQ UPPêr La~ral Slotted Liner Tubing Strl,1)9 - TuéïNG :~~Ö""'" r' T~P P9rforatioñ!i~'s.r;.r'r)mary ". Interval TVD sose - 9106 6S76'"~65'SS 9106 - ~j26 -6585·6603 9126·9142 . 6603 - 6~17 Size 16.000 9.625 7.000 2.375 2.375 I9,p o if' o 8845 10344 Bottom nib Wt ,.~radë· , Thttlad 121 121 ~2.58 H..4b W~LDED 6249 4488 40.00 L;SO 8TC 9390 ,.~ 6751 26.00 L-8Ö' " ABM·61C 10344 -'6675 4.43 .. L-so STl 11111 66'38 4.43 I ,.. L-.ªØ· , STL I.. '~f:f?· I TVO j' ""Wt'" I GI'Çldê I ".. Thread 6469..,. . L__," 9.30 L-SQ. "" .....:', E;UE·SRD Zone Statµ~' Ft SPF, Date ""·,·~-TVP'e Comm8~f". 10 6 2/1712002 APERF 2.5" HSD PJ Chrgs 60 deg ".. ph .... 20 4 l?,30/f998 ¡PERF 2.5" HÇ DP 1 Eì S 2/17/2002 APERF 2.5" HSD þj Chrgs 60 dèg , .'_ ." ph '.'.. 767 4 .4/13/29.93 APERF SLOTT,~P ~!.~ER 1 OM~ . 1'1'1' 11 6675 ~ 6638 C-3,G~..6:~ Gas lift MãndrelsNálv$S " ,.. st MD lVD Man Man TyPe V Mfr V Type'''- ,lOD LatCh Þon. TRO ','" .~f.r 1 3325 2603 CAMCO KBMM 2 5349 3908 CAMêo" KBMM 3 6592 4 709 cA~fëõ K6MM 4 7s54"~5340 CAMeO KBMM 5~:: 8331 5906 CAMCO KBMM 68827 6334 CAMCO MMM other (PlugS, equip., etc.) :,J.~WELRY"" Depth TVD Type, . ,._ .n_.. DescI!ptloñ" 2019 1795 55$V CAMCÖ TRDP-4E (LOCKED qWT 7/16/20(4) Sa7S 837S.... ..__N.IFt 'CAMCO W·NIPPLE .. --. . S918 ",6Æ.1.ß. PAëKER" BAKER S~3 ~ËRMANENI.PACKË'R ".,&9ß_5. 6458 --ï'Hp CAMCO 'D' NIPPLE_-J~'llLED ÕÜT TO 2.80" ID 2/5/2003 8976"" 6468 50S 6AKËR SHEA8Pl,JT Sus" -GeñerafNcites ..." Date Nota.. . ....,.._ . . 'n_ ' .._. 4/1312003 UPPER LATEFfÄLLEG, DRILLEO 4/1512003, EXITS Tè)"ë~SANDS THROUGH ORIGINAL WËLLBORE 1C-15 CEMENT PLUG. 1C-15 PË8F$ ~ª!.IOPEN; WELL WILL PRODUÇ.!~ff39M BOTH LEGS GIv "Crt. \I --G'Lv DMY DMY DMY 0.125" 1263 O.15Er 1393 0.250' . ., 1422 '··Ò:250 0 0.000 0 . 0.000 0 Date Vlv Run Cmr:a,L 7/1612004 7/16f2004 7/1612004 7/18/2004 2/12/2003"""·- 7/16/20Q4 1,0 1,0 1.0 1.0 1.0 1.0 6K 8K BK BK B·K~~ RK ID 2.812 2.812 3.875 2.800 2.992 TOTAL P.03 ):{ECE\VED Á I "' STATE OF ALASKA /T ~...I ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 1 71004 V\::rs 6:£ APPLICATION FOR SUNDRY AP\~ROY A~ c' ~;, Commission (\' 20 MC 25.280 ~\aska O~i & h·8\$ ""on~~" ~ ~ o Suspend D Operation Shutdown 0 Perforate D :~I,p.S:hfWãlt~r D Annular Disp. 0 ,I D Repairwell D Plug perforations D Stimulate 0 TimèExtension D Other 0 D Pull Tubing D Perforate New Pool D Re-enterSuspeHdedWell 0 Convert to Inipr.tnr 5. Permit to Drill Number: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6629' Length 13.VVéllClassafterþroposed work: Exploratory···D Development 0 15. Well Status after proposed work: Oil D Gas D WAG 0 GINJ D Mechanical Integrity Test ~ Location Clearance D 4~~~of'. $-\Ç" Other: Co\N\" \\O-N:£. $../1 \Q:c.. U\r{ ~t\..\~ .', \' /. . YO\- f\ \0 d \S ,,"-:o\h<i.~ "" On: Subsequent Fo eq 7~ L\, Approved bi~, ~ 0 ~!M~lt~ A L ~~~~g~~~~ION Form 10-403 Revised 12/2003 ) 1. Type of Request: Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 37' 4.Currenl WeUClass: Developmenf_. 0 Stratigraphic D 8. Property Designation: ADL 028242 11. Total depth MD (ft): 11207' Casing Size MD CONDUCTOR 121' SURFACE 6147' PRODUCTION 9288' UIJPI::K LA II::RAL SLOTTFD INFR 767' 16" 121' 6249' 9142' 11111' 9-5/8" 7" 2-3/8" Perforation Depth MD (ft): 10.344'-11073' Packers and SSSV Type: Baker S-3 permanent SSSV= SSSV 12. Attachments: Description Summary of Proposal ~ Detailed Operations Program D BOPSketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Brian Sei~z .1 /., // Signature ~ /'l'-Uf/ Commission Use Only Perforation Depth TVD (ft): 667.5'-6640' Packers and SSSV MD (ft) pkr @ 8918' SSSV= 2019' 07/01/04 Date: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP Test 0 INSTRUCTIONS ON REVERSE Exploratory D Service D 203-032 6. API Number: 50-029-22932-60 9. Well Name and Number: 1C-15L1 TVD Burst Collapse Tubing Size: 3-1/2" Tubing Grade: L-80 Tubing MD (ft): 8977' Service 0 PluggedD WINJD Abandoned D WDSPL D Contact: Brian Seitz @ 265-6961 Title: Kuparuk Staff Engineer Phone ßi ~--6 96/ Date 6//1/ t?7 Sundry Number: .r-- 3G)1-d-3~ V 'Ii"" ., ~. \fi\.rot. !' . ft . rgHc ._,,- 1', . '~~ ...~" ".,-- ,~\\jN ~ 21 ,nn~\ Dare: tf1/~tf Submit in Duplicate ) ) ~ \~\~LtL KRU 1C-15 Conversion to Injection Backeround KRU lC-15 was drilled and completed as a C-sand producer in October of 1998. In April of 2003, the well was sidetracked with coiled tubing while preserving the original wellbore. After the sidetrack, the well was to be converted to MW AG injection to provide support to an area of declining production. The plan is to now complete the necessary facility work to convert the well and begin MW AG injection in July of 2004. Summary of Operations Surface slot 15 on DS-l C will be converted to MW AG service. Utilizing the standard existing Kuparuk MW AG well tie-in design, this project will tie in an MI and WI lateral with new hot taps on the headers. --.-,--.--- --.---- ) ) d()S-a~ d MECHANICAL INTEGRITY REPORT' '... :_ I G R E L E;. S ~: ~ OPER & FIELD C. \>~ 1:" \~\>Ck~'¥. WELL NUMBER \ <.. - \ 5" '- ~ ~?UD DA!E: : :T"!~LL DATA TD: \ \ +-01HD.. <o~~~<tTVD; :?BTD: 11]) TVD ~C?.ANIC;'~ INTEGRITY - P.lŒ.T 11 TVD i DV: MD ·Tvu ~~~~~ ~la "3 <6 TVD; :OP: ~ \'lC\ HD :::VD TVD i Set é t c;.s<;, \ '\ ~\~~~ \C)'"\~ \.\ - \ \ 0"'"\ "'!Þ:.. ; Perf~ to <::Þ \ \ ~ <61$,-\ -5 . - ,C "! '-\ '-\ +o~ ~~\\~(:~'\'" ~~'o\,,~ ~~, \ ~~1"\S" - \ <.a <0 "t \:) oN I Casin.g: ~Þ-... Shoe: HD :"':":1e::::- : d ~J~ Shoe: \\\\ \ ill) :-woi;::g: ~\I";) Packe:!:" <;s<;\~ HI) ::'ole S:'z e S \ l a.nå Annulus Press Test: ~p ; 15 min 3 0 min COtriIIlents: ----- MECHÞ~ICÞ~ INTEGRITY - PART 42 Cement Volumes :'. .Amt. Liner \:)~; Csg ~~._, ; DV ~~ . C¡¡¡t -JOl to cover perfs . ~c'f-.l.Ct'\.c..\\\~~\.~ "-f\\- ~~M..~~<J \W/~'C) \\~, ~~~ .,,~ci<-.t:.\ \~~~\ \~~\\\c0,,- \~~ttN~<L. Theoretical TOC .,.,~,-\\~\t.. ~ q \~\\~ ~-M.~t\o.~>r- c:.~~~ ~\T U c...~~\'i,,"..... .Ç6~ \ c.- \;; (\~~"ðd-':\" Q,~~\\-~ Cement Bond Log (Yes or No) V ; In AOGCC File ..J 3 J ~\;1 D~ CEL Evaluation, ~one above perfs 'co~ ö~. \c...-\ç\~ ~~rc:-\~~~ Prociu~tion Log: Type ¡Evaluation . ~~~~~~,>\cë.~\~,'~~ \'\D~\\.~ ~rox\vWt.~ o-\-~~r·-\-"'Cx.t\ CONCLUStÖNS: ~\\oort ~ . ? ar t : 1 : ?ar:: #2: \J..:t" 'D~~~ \<- \~~ . . .. lr'if1yy) ~ ~~-o~ Re: lC~15Map ) ) Subject: Re: IC-I5 Map From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Tue, 22 Jun 2004 07 :28 :48 -0800 To: "Seitz, Brian" <Brian.Seitz@conocophillips.com.> Thanks Brian, This will work, coupled with the spider plots I pulled from other wells in the area. This pretty well confirms that there are no penetrations "through the roof" within a 1/4 mile of either wellbore. I did receive the bond log as well. I will finish processing your applications. Tom Seitz, Brian wrote: Tom- Let me know if this map will suffice for the 1C-15 conversion to injection. Sandra Lemke forwarded the Cement Bond Log run on March 11, 2003, so I think we're covered. If you need additional information, please do no hesitate to call. Regards, Brian «lC-15L1 fig.ppt» I of 1 6/22/20047:29 AM .\ \ "-- W;24 ~ ~ ~ ' :"-23 \ ~ 4t- \ ---- ~ I fC-J6 I [Xl fC-fO ( /~ I j I I í ø - lr \ c..- \~ \.-1.. d 0 S-o ~J IC-IS with CTD Lateral \ ~ I ~ ~.. ~f{i1~0<~~;1~;'~f;l~I' )~¥¡~.;¡o~~.,.,... ... ~-~~~: J~-<;~~---' -·i: -:"0 ARC a Alaska, Inc. er...t.d by finçh For: u.oYD Dol. pl~lIed ; 2~-MGr-'II99 Plot R.r.rance i. 23 V,,"""" 15. CoordÎnatu or. in I..t rel....eII afat 123. True V.rlleal Dsp/h. are r.r.rmle. Est. RKB (P~aI '6). ... .... INTEQ Struoture : Pad 1 C Well : 23 FIeld : Kuparuk Rlv8l' UnIt Looatlon: North Slope. Alaska 4000 4400 4600 5200 5600 6600 7200 6000 6400 4800 4400 - ~, 4000 - 3600 - ~ \SL~ 1. ... " .. 6700 J ./ 6500 ./ 2800 - ~ 6300 W . ^ I 3200 - ,.-... -+- Q) Q) '+- '-' 6100 5900 5700 5500 5300 \ 5100 4900 4700 4500 4300 2000- 4100 3900 ,\A- 1 600 - , '\ \ 2400 - ..s:: -+- ~ o ~ 1200- 4500_ ..}?-09- 4100 43~0_ _- BOO - 370Q... _3~O~ __ - - .- 3300 _ ';5EO - ... - -:ID- - .- - 400 - _ 4500 4900 5300 57~ _ _ ~1~0 _ _ .!5~0~ Ær-------------- \ c......... ~ \.\ () () , East (feet) -> 7600 BODO 6400 8800 9200 9600 10000 10400 10600 11200 11 600 12000 12400 4800 300 6700 6300 6~~_ill] 5900 61~_ _ - - ... 5500_ _52.09- -- - - .- 5100 5300_ ...- _~o.£. __ _ - -- o - -r.].;""\ 41 00 4300 4500 .l:!...r- - - .... _ _ _ _04700 4900 51 00 5300 _ _ _ 400 - - - - -..... - -. - -o5~0~ 5700 5900 6100 6300 _ _ - - -........ ~-~-~--~-- , " ~ " BOO 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 BODO 8400 8800 9200 ¡:-n~t (fact) -> 9600 10000 10400 10800 11200 11600 12000 12400 BOO .~ ~" ." ,,~- . ,~. '.' J, ~ ~. - 4400 \ - 4000 .. 3600 - 3200 - 2800 ^ - 2400 I Z 0 ., .. 2000 -f- -=r ....... -+, - 1 600 f 0 -1200 - 800 - 400 - 0 - 400 03/05/04 Schlumberger NO. 3125 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job# Log Description Date BL Color CD -,' 1 C-190ôt'-:3 ·-ClJ.5 1E-34 /971/0 (¡ _1C-15L 1.~C?-lt3"). 2Z-1 0 ~h' J3~t. 2P-447g("'-=<) --It:) LJ \ 10709706 10709710 10709713 10696843 10696847 INJECTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE/DEFT PERF/SBHP 02116/04 02/21/04 02/25/04 02/26/04 03101/04 1 1 1 1 1 .---- Q:'- ("\ ;\- f\ 1 L- n ~ \bVL-t V L-tJ ~ .. ~-----.- SIGNED: "'é))l~';. "<"-~ \ _J'-_( C'-;~ ê::-_j~ DATE: < !\ n Iì " '1;1 U!'\ 4 [........ , n .~. '4 i .:-,;". L ~ L\,,/ . - i:},}i,...;,.'1 f",;J.? ~~~ ('f\flS Comm~M .'- _::-.;;~:~ ~.ì....:. ~~ -~~-\OI ~,U . J""~1\.':~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. An [,"horage Rß""n\~ ) ') 803--03~ Transmittal Form "1. IAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 1 C-15Ll Contains the following: 1 LDWO Compact Disc .#- / () ~I 08"" (Includes Oraphic Image files) 1 LDWO lister summary 1 blue line - OR/Directional Measured Depth Log 1 blueline - OR/Directional TVD Log LAC Job#: 462024 RECEIVED FEB 1 0 2004 Alaska Oi\ & Gas Cons. Commission Anchorage Sent By: Glen Horel ~ Received B~Ré'\ \. ~.N"-.~ ~::::::>('yy\ Date: Feb 9, 2004 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 ~~~~~ U~~~~;~;~~;~~~jJ .,.....'........................'....".'..'....,.....,...,....1 : ,...,"" ,,' '1I.IIÞ:It·~ r.a.m iii:': III' '~',I ',... """ .." I~r:~~::~."....'" ~~;,. ..., .... "'~;'~':.,,,,..:1.,.,,~~';..~. II ......,"... . .. ::~=;~~~I '::~:;:::';~; ,~_______~____________._______.._~_____n__ : ~.v".~.:1 ",,'Ot. ~~:{~ I:·."·"'., I i I i.. I I I . i .".' ~ ¡ ~·-~f::~---_·__·;_·- 1"':':':.1:1 I, (.~~, ¡'.': it:?: '0 . ~ ':'~- '___,.__ .~~__..h_.__·_·_.__ :r··::i{~ì~ ; ~ __.......n.'_"....,..·.·_._.., ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Multilateral 1. Status of Well IS! Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator ConocoPhillips 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1634' SNL, 1239' EWL, SEC. 12, T11 N, R10E, UM At top of productive interval 1050' NSL, 772' EWL, SEC. 06, T11 N, R11 E, UM X = 567035, Y = 5971330 10. Well Number At total depth 1319' NSL, 292' EWL, SEC. 06, T11N, R11E, UM X = 566553, Y = 5971595 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. F~~~a~~~ b~o~ool RKB = 101.5 ADL 028242 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp., or Aband. 4/5/2003 4/10/2003 4/13/2003 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 11207 6629 FT 11207 6629 FT IS! Yes 0 No 22. Type Electric or Other Logs Run MWO, GR Classification of Service Well 7. Permit Number 203-032 8. API Number 50- 029-22932-60 9. Unit or Lease Name X = 562247, Y = 5968605 Kuparuk Unit 1C-15L 1 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost 2019' MD 2020' (Approx.) "'I/w~~ fr7'1";I17:> /" ,I", 6J~.52 ,vI.> 23. CASING SIZE CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 121' 24" 9 cu yds High Early Surface 6249' 12-1/4" 850 sx AS III LW, 610 sx Class 'G' Surface 9142' 8-1/2" 178 sx Class 'G' 8845' 11111 3" Uncemented Slotted Liner <4r ~C)\\ð I ~~è)~\\\t""0 ~ ~"'r1 ~\ð ~ ~Ç:.,-\S - tC\ ~\.\~ " I -0' ç,cr ~~\\~ ~ \<.')3 "-\4 .. ,\ n ~ ~ ~ '5..c\\~ -\-(:'\ c::... ~t\(: 8; 24. Perforations open to Production (MD+ TVD of lap and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) 2-3/8" Slotted Section 3-1/2", 9.3#, L-80 8977' 16" 9-5/8" WT. PER FT. 62.58# 40# 26# 4.43# GRADE H-40 L-80 L-80 L-80 AMOUNT PUllED 7" 2-3/8" PACKER SET (MD) 8919' MO TVD 10344' - 11073' 6675' - 6640' MO TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9141' Set Kick Off Plug of approximately 4 Bbls of Cement, Drilled Ramp Freeze Protect well with Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) April 19, 2003 Gas Lift Date of Test Hours Tested PRODUCTION FOR Oll-BBl 4/19/2003 3.5 TEST PERIOD 1 ,768 Flow Tubing Casing Pressure CALCULATED Oll-BBL Press. 31 C 24-HoUR RATE GAs-McF 814 GAs-McF WATER-BBL 1,314 WATER-BBL CHOKE SIZE GAS-OIL RATIO 460 OIL GRAVITY-API (CORR) .,28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. , .< ~ I RECEIVED No core samples were taken. :-v ~\. i-~"\ r~~~ 1. ···.1.00. Atit~.. .~_..'.. ~.~; \su¡P1:\~· ~.." ·,t ~. &. .\1;.. , - ,~. '.~: ....,~o,I,!<..,..,', ..,~"". . ': ¿f:.1'{~~!..J ' '~IC\f'~,r« :,,' II,çr I: I:', f, r'~IC)jll),_¡\.~/"I.\), !~j,f', .,-,--.~;1,c-:~: 6p "~"~--oRIG NAL i\ i i ~'.: ~ ,"'!' ....c, "M"A',( 14 2003 Form 10-407 Rev. 07-01-80 ,Alaska 0;1 & Gas Cons. Commission ^nOOOfl1g6 Submit In Duplicate ') 29. Geologic Markers Marker Name Measured Depth Kuparuk C2 9152' Kuparuk C1 9220' Kuparuk B4 9258' Kuparuk B3 9311' Base B4 (invert) 9461' Base C1 (invert) 9634' Base C2 (invert) 10100' Base C3 (invert) 10539' Base C4 (invert) 1 0627' Top C3 (revert) 11021' Base C4 (invert) 11057' 31. List of Attachments: ') 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 6626' 6688' 6718' 6745' 6738' 6702' 6679' 6668' 6646' 6641' 6641' Summary of Pre-Rig Work and Daily Drilling Reports, Surveys 32. I ~erebY certify that the fo~oin: is true and correct to the best of my knowledge Signed Terrie Hubble -112J\1\.UL ~ Title Technical Assistant Date 05 -I 3 ·03 1 C-15L 1 203-032 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Ted Stagg, 564-4694 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 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 28: If no cores taken, indicate 'none'. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. Form 10-407 Rev. 07-01-80 Well: Field: API: Permit: Date Date 12/28/02 02/09/03 02/12/03 03/02/03 03/03/03 03/04/03 03/05/03 03/06/03 03/07/03 03/11/03 03/15/03 03/16/03 03/19/03 03/20103 03/28/03 03/30103 04/01/03 ) ) 1 C-15L 1 Kuparuk Unit 50-029-22932-60 203-032 Accept: Spud: Release: Rig: 04/02/03 04/05/03 04/13/03 Nordic #2 PRE-RIG WORK Comment MITOA -PASSED, POT & PPPOT-T -PASSED. FUNCTION TESTED SSSV (GOOD TEST). PULLED OV & SET DV @ 7554' RKB. ATTEMPTED TO LATCH ON GLV @ 8331' RKB, UNSUCCESSFUL. LIB SHOWS GLV STILL LOCATED IN BOTTOM POCKET. SHUT DOWN FOR PHASE II WEATHER. REMOVED 1" GLV @ 8331' RKB AND INSTALLED DV IN SAME. PULLED OV @ 6592' RKB. PULLED GLVS @ 3325' & 5349' RKB. SET DVS @ 3325',5349' & 6592' RKB. LOADED TBG & IA WI DSL. MITT 3000 PSI, GOOD. MITIA 3000 PSI, GOOD. CLEANED FILL TO 9,275' CTM WI SEAWATER, SLICK DIESEL, AND 2# XCD (EST. 150' OF RATHOLE). WELL FREEZE PROT'D WI DIESEL TO 2500'+. TAG FilL @ 9300' RKB. 158' RAT HOLE, COMPLETE. MITMV - FAILED. MITMV - FAILED. RUN SCMT FOR CTD PREP. CEMENT IS EXCELLENT FROM 9261' TO 8966' (TBG TAIL), TAGGED TO AT 92721. ATTEMPT TO DRIFT DOWN TO W- NIP. SAT DOWN @ 19921 WLM WORKED ASSORTED TOOLS THROUGH SSSV LARGEST OD 2.80" HAD TO BE WORKED THROUGH 1992' WLM & 1997' WLM, DUMPED SSSV & TAGGED FLAPPER @ 1997' WlM CONFER WI CWG. DRIFT DOWN TO W- NIP AT 8876' RKB WI 2.80 GAUGE. HAVING TO JAR DOWN THROUGH SSSV. DO A CLOSURE TEST ON SSSV, MONITOR TBG @ 0- PSI FOR 30 MIN. SET A 2.81" CS-A PLUG @ 1993' WLM PT TBG TO 1500# BLEED DOWN TO 0- PSI PRESSURE BACK UP TO 850# & OPEN SSSV TH. PULLED PLUG @ 2019' RKB. MIT-MV PASSED, MIT-SV PASSED. PERFORMED A CEMENT PLACEMENT PLUG FROM 9,125' CMD (E-LlNE SCMT LOG DATED 11-MAR-2003) TO 9,273' CORRECTED CTMD, WITH 17 PPG KICK OFF PLUG MATERIAL. WAS UNABLE TO ACHIEVE A PERF PLUG WITH THE 20 BBLS SALT PilL. LEAVE WELL FREEZE PROTECTED TO 1500' CTMD. RE-TAGGED CMT PLUG, @ 9141'RKB, EST. l' ABOVE BTM PERF, TIE IN TO SCMT LOG 3/11/02, NEW CORRECTION OF 3' COMPLETE. PUMP SAFECARB PILL INTO PERFORATIONS IN ATTEMPT TO PLUG THEM OFF. WHP DID NOT INCREASE, DISPLACED SAFECARB PilL WITH DIESEL, NO SUCCESS IN PLUGGING OF PERFS. ) ) BP Operations Sum maryReport Page 1 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-15 1 C-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/1/2003 Rig Release: 4/13/2003 Rig Number: 2 Spud Date: 4/2/2003 End: 4/13/2003 Date From -To Hours Task Code NPT Phase Description of Operations 4/2/2003 00:00 - 07:00 7.00 MOB P PRE Continue to move rig from 3N to 1 C pad. 07:00 - 08:00 1.00 RIGU P PRE Noticed pre-existing spill on pad near rig. Inspect same with CPF-1 reps/pad operator to document same before proceding. 08:00 - 11 :00 3.00 RIGU P PRE Spot rig over well. Shim rig due to un-level pad. Some clearance problems with cellar door. Held sim-ops planning meeting with Doyon 141 people. Accept rig at 1100 hrs on 11 :00 - 12:00 1.00 RIGU P PRE ND tree cap. NU BOPS. 12:00 - 15:00 3.00 RIGU P PRE Build cellar door addition with plywood etc to seal of cellar around flow lines. Continue to haul and spot equipment from 3N pad. 15:00 - 17:00 2.00 RIGU P PRE Spot and berm external fluid tanks. Spot and rig up camp. Establish comms through Milne pt base camp. 17:00 - 18:30 1.50 BOPSUB P PRE Test BOP equipment. 18:30 - 19:30 1.00 BOPSUB P PRE Hold pre-spud mtg in Ops Cab. CPF-1 19:30 - 23:00 3.50 BOPSUB P PRE Continue BOP test. AOGCC's Chuck Shieve waived witnessing BOP test. 23:00 - 00:00 1.00 KILL P DECOMP RUDS 4/3/2003 00:00 - 01 :00 1.00 KILL P DECOMP PJSM for CaC03 pill. Pumping and mixing strategy. Will start with 100 ppb formulation and stage up to 160 ppb. 01 :00 - 02:00 1.00 KILL P DECOMP Blend pill in batch mixer. Injection test 1.3 bpm 1550 psi increase rate to 1.4 and 1.5 No pressure increase. Looks like frac.gradient is low. Discussed with Dan Venhaus. Decided to proceed per plan. 02:00 - 05:00 3.00 KILL P DECOMP Pump 30 bbl pill with 160 ppb CaC03 and bullhead to formation with rig. 1.3 bpm at 1,050 psi. after 32 bbl of 43 bbl displacement slow rate to .75 bpm @ 900 psi. Hesitation squeeze perfortions. Shut-in with 1250 psi on well. Monitor pressure. 05:00 - 07:00 2.00 CLEAN P DECOMP Safety Stand down. Crews attending Safety Induction mtg at Milne pt facility. Continue to monitor WHP. 07:00 - 08:00 1.00 CLEAN P DECOMP Hold Pre spud mtg in ops cab with day crew. Discuss well plan, HSE issues, sim-ops plan, plan forward. 08:00 - 11 :00 3.00 CLEAN P DECOMP Clean out pits. Take on milling fluid. Have pad operator show crew how to operate SSSV. Close SSSV. Bled WHP to zero. Monitor well. SSSV holding. 11 :00 - 12:00 1.00 CLEAN P DECOMP Displace diesel from coil. Test e-line continuity. MU nozzle assembly. 12:00 - 14:30 2.50 CLEAN P DECOMP STab on well. Open SSSV. RIH (negative weight). Stop to check gooseneck alignment etc. No problem found. 14:30 - 16:00 1.50 CLEAN P DECOMP Wash to 9140'. Full returns with 11.0 ppg ECD. 2600 psi@ 1.56 bpm. Noted CaC03 in returns. Mud weight up to 8.9 ppg (from 8.7 ppg). 16:00 -18:15 2.25 CLEAN P DECOMP POOH with nozzle as per choke schedule. 18:15 -19:00 0.75 CLEAN P DECOMP Change out BHA forMilling BHA. 19:00 - 21 :00 2.00 CLEAN P DECOMP BIH to 2000' pressure to 900 psi and open SSSV. Continute to RIH to 9100' 21 :00 - 21 :30 0.50 CLEAN P DECOMP Log in correction = +6'. Tag at 9140'. 21 :30 - 23:00 1.50 CLEAN P DECOMP Directionally drill 1.5/1.5 bpm at 3,150 psi. FS= 2,800psi. WOB 1.7K 10.86 ECD ROP 27'. DH annular pressure = 3,670 psi, DH coil pressure = 4,468 psi.Drilled to 9180 reactive torque responce indicates that is casing. 23:00 - 00:00 1.00 CLEAN P DECOMP POH to 5500'. 4/4/2003 00:00 - 01 :00 1.00 CLEAN P DECOMP POH to 500' close SSSV. Continue to POH to surface. Printed: 4/14/2003 9:28:55 AM ) ) BP Op.erations SumrnaryRéport Page 2 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-15 1 C-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/1/2003 Rig Release: 4/13/2003 Rig Number: 2 Spud Date: 4/2/2003 End: 4/13/2003 Date From - To Hours Task Code NPT Phase Description of Operations 4/4/2003 01 :00 - 02:00 1.00 STWHIP P WEXIT PJSM. PU window mill with brass guide ring. 02:00 - 03:45 1.75 STWHIP P WEXIT RIH to 2000. Pressure up and Open SSSV. Continue to RIH to 9100' 03:45 - 04:00 0.25 STWHIP P WEXIT Tie in correction +4'. 04:00 - 07:00 3.00 STWHIP P WEXIT RIH 9140. Set down high bend motor will not go in hole. Orient 180 and ream down. 07:00 - 10:30 3.50 STWHIP P WEXIT Begin milling sequence at 9179'. 3000 psi@1.56 bpm. No WOB or motor work. 3684 psi BHP. Mill to 9180'. 10:30 - 13:45 3.25 STWHIP P WEXIT Continue time milling window sequence. Milling at 9182.1'. 3100 psi@1.6 bpm. No WOB or motor work. 13:45 - 14:30 0.75 STWHIP P WEXIT Mill ahead to 9184'. Not much WOB or mtr work. Metal on magnets. Sand in samples? Lots of clay, some cement. 14:30 - 15:00 0.50 STWHIP P WEXIT PU to top of ramp. RIH. Take wt at 9184.5', or 0.5' below where we stopped milling. (void in cement?) 15:00 - 15:30 0.50 STWHIP P WEXIT Pull up hole. Re-Iog grtie in from 9110'. Add 0.5' correction. 15:30 - 20:00 4.50 STWHIP P WEXIT RIH. Begin time mill sequence over again, starting at 9182' ( 2' below 1 st starting point) Inclination at bit 12 degrees. Bottoms up sample formation sand. It appears that we have exited casing in lowest perf interval when we oriented low side prior to starting the cement ramp. Discussed options with Ted Stagg and Dom Van Nostrand. Decided to PU building assembly. 20:00 - 20:20 0.33 STWHIP P WEXIT Pick up surveying thru window to confirm inclinations. 20:20 - 22:30 2.17 STWHIP P WEXIT POH to 550' close SSSV. Continue to POH to surface. 22:30 - 23:00 0.50 STWHIP P PROD1 Change out BHA for build section. 23:00 - 00:00 1.00 STWHIP P PROD1 RIH 4/5/2003 00:00 - 00:45 0.75 DRILL P PROD1 RIH 9100. 00:45 - 01 :00 0.25 DRILL P PROD1 Tie in +7' correction. 01 :00 - 02:00 1.00 DRILL P PROD1 1.5/1.5 BPM @ 3100 psi .FS 2740psi. Tag up at 9150 stalls ream to bottom. Had to shut down pump to get thru window. BHA sought 80L. 02:00 - 06:00 4.00 DRILL P PROD1 Directionally drill 1.7/1.7 bpm @3250 psi FS=2740 psi WOB 3K, ROP 5-30 ,DH annular pressure 3850 psi, DH tubing pressure 4140 psi. ECD 11.3 ppg. @6583'TVD. Drill to 9,260'. 06:00 - 10:15 4.25 DRILL P PROD1 Continue to drill build section. 3300 psi@1.6 bpm. 200-300 dpsi. 1:1 rtns. WOB:2-3K, ROP:20-30 fph. 3866 psi BHP. Drill to 9318'. 10:15 - 10:30 0.25 DRILL P PROD1 Short trip to window. Hole smooth. Pad evactuation drill initiated by Doyon 141. Comm channels worked well. Non-essential personnel muster at pad entrance. Drill ended at 10:15. 10:30 - 12:30 2.00 DRILL P PROD1 Drill ahead to 9336'. ROP: 10-20 fph. 12:30 - 22:30 10.00 DRILL P PROD1 Drill ahead to 9410'. 3000 psi@1.57 bpm. 200-300 dpsi. 2500-4000# WOB. ROP: 1 0-20 FPH. 3855 psi BHA, 11.2 ECD. Getting 40 deg/100 total dog leg rate. Max TVD reached: 6652' @ 90 deg.Continue to drill to 9,470'. POH for lateral assembly. 22:30 - 00:00 1.50 DRILL P PROD1 POH. Back ream thru window seen motor work at 9163 - 9155 and 9149 -9147. PU to 9,134. Attempt to RIH with pump on NO GO at 9153'. Shut down pump holding pressure on well. Orient 270. RIH thru window OK. Continue to POH. 4/6/2003 00:00 - 01 :00 1.00 DRILL P PROD1 Time change Printed: 4/14/2003 9:28:55 AM ) ) BP Operations ·SummaryReport PJSM POH to surface. Change out orienter, change bend in motor, Replace bit. Bit had 6-8 broken cutters, and was in poor condition. Likely damaged while pumping through window. Stab injector. RIH to SSSV. Pressure well to 800 psi. Open SSSV. Continue to RIH inaccordance with pumping schedule. Log in +6' correction. RIH orient low side without pump and with 900 psi shut in. No Problem thru window. Tight at 9,429' and 9,456'. Drill at 1.6/1.6 bpm at 3200 psi. FS = 3000psi. 320 psi DP, DH annular pressure 3890 psi, DH tubing pressure 4440 psi. WOB 3k. Drill to 9605'. Wiper trip to window. Hole smooth out. Hung up at a few spots running in. (9433', 9300', 9524') Elected not to ream unless necessary later on. Drilling ahead. 3240 psi@1.68 bpm 100 dpsi 1: 1 rtns WOB:1-1.5k# ROP:40-50 fph BHP:3910 psi ECD: 11.4 ppg. Appear to be in C sand at 9633'. Drill to 9800'. Short trip to window. Hole smooth. Bobble at 9430' while RIH. Drill ahead. 3250 psi@1.7 bpm 250 dpsi 1:1 rtns WOB: 1500-2500 ROP:60-80 fph. BHP:3900 psi ECD: 11.4 ppg. ROP slowed as we drilled up through section towards C1. Drill to 9975'. PROD1 Short trip to window. One bobble while POOH, several bobbles RIH (all small) PROD1 Directionally drill 1.4 /1.4 bpm @ 3200 psi. FS = 3050 psi. ECD 11.6 @ 6580 TVD WOB 2.6k , Up wt 21 K DN wt 2K DH annular presssure 3960 psi, DH tubing pressure 4410 psi. Drill to 1 0032'. PROD1 Continue to directionally drill 1.4/1.4 bpm @ 3200 psi. FS = 3050 psi. ECD 11.6 @ 6580 TVD WOB 2.6k , Up wt 21 K DN wt 2K DH annular presssure 3960 psi, DH tubing pressure 4410 psi. ROP slow. Getting goodweight to bit.Hole not sticky but lots of clay in samples 10000'. Maybe balling. Will sweep with 20 bbl pill with one drum of clayguard. Drill to 10080'. No Change. PROD1 Short trip to window. Trip out smooth. RIH. Trouble getting past 9582'. Had to ream several spots from 9580' to 9620'. This is in B4 just before C1 interface (picked at 9632'). Hole mostly smooth from 9632' to TD. PROD1 Drilling ahead. 3100 psi@1.53 bpm 200 dpsi 1:1 rtns WOB: 1.5k# ROP:40-60 fph BHP:3996 psi ECD: 11.7 ppg. Orienter cutting in and out. Experienced similar problems earlier this am. Drill to 10184'. Start displacing to new mud system. Solids were at 0.8 and system had 52 hrs & 1043' drilled. PROD1 Short trip to window once new mud is around. Tight spots from 9580' to 9620' on previous run in hole have cleaned up. Some minor bobbles around 9970'-80' PROD1 Drill ahead. 3050 psi@1.64 bpm 200-300 dpsi 1:1 rtns WOB:2-3k# ROP: 20-80 fph BHP:3920 psi ECD:11.5 Drill to 10355'. ROP highly variable. Still looking for fault. Drilling break at 10,396'. ROP increased to 65 fph. Drill to 10,400' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-15 1 C-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To Hours Task· Code NPT Phase 4/6/2003 02:00 - 02:15 0.25 DRILL P PROD1 02:15 - 02:30 0.25 DRILL P PROD1 02:30 - 04:20 1.83 DRILL P PROD1 04:20 - 04:40 0.33 DRILL P PROD1 04:40 - 04:50 0.17 DRILL P PROD1 04:50 - 08:30 3.67 DRILL P PROD1 08:30 - 09:15 0.75 DRILL P PROD1 09:15 - 13:00 3.75 DRILL P PROD1 13:00 - 13:45 0.75 DRILL P PROD1 13:45 - 17:30 3.75 DRILL P PROD1 17:30 - 18:00 0.50 DRILL P 18:00 - 00:00 6.00 DRILL P 4/7/2003 6.25 DRILL P 00:00 - 06:15 06:15 - 07:15 1.00 DRILL P 07:15 -12:15 5.00 DRILL P 12:15 - 13:30 1.25 DRILL P 13:30 - 19:30 6.00 DRILL P Start: 4/1/2003 Rig Release: 4/13/2003 Rig Number: 2 Spud Date: 4/2/2003 End: 4/13/2003 Description of Operations· Printed: 4/14/2003 9:28:55 AM ) ) BP Operations Summary Report Page40f 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-15 1 C-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/1/2003 Rig Release: 4/13/2003 Rig Number: 2 Spud Date: 4/2/2003 End: 4/13/2003 Date From - To Hours Task Code NPT Phase Descri ptionof Operations 4/7/2003 19:30 - 20:40 1.17 DRILL P PROD1 Wiper trip to window. Over pull at 10,331'. POH to 9404 motor work no overpull. RIH to 9976' bobble. Continue to RIH set down one time at 10,311'. 20:40 - 21 :55 1.25 DRILL P PROD1 Directionally drilling 1.7 1 1.7 bpm @ 3425 psi, FS = 3300 psi, WOB 1.7K, ROP 60-125, DH annulus pressure 3975 psi, DH tubing pressure 4515 psi. ECD 11.64 ppg. Drilled to 10432 with TF "0" losing inclination at bit. Drill to 10,472'. Still losing inclination. Currently in upper 2C sand. POH for more build. 21:55-22:10 0.25 DRILL P PROD1 POH to window. Shut down pump holding 900psi. Monitor well to determine if pressure beyond fault requires mud wt change. Well head 650 psi after 15 minutes. 22:10 - 00:00 1.83 DRILL P PROD1 POH following choke schedule. Close SSSV. POH to surface. 4/8/2003 00:00 - 01 :30 1.50 BOPSUR N WAIT PROD1 Wait on rig water driver went to wrong pad. BOP test better with cold water recommendation from lessons learned data base. Grease valves in preparation of BOP test. 01 :30 - 05:00 3.50 BOPSUR P PROD1 Test BOP's. Witnessed by Chuck Shieve AOGCC. 05:00 - 05:30 0.50 DRILL P PROD1 MU BHA with 1.7 motor. 05:30 - 07:30 2.00 DRILL P PROD1 RIH with HCC bi-center on 1.7 on motor. Bit is re-run from previous trip. Still in very good condition. 07:30 - 07:45 0.25 DRILL P PROD1 Log gr tie in. Add 2' correction. Tag up on window at 9148-50. TF:180. PU. RIH. Through window ok on 2nd try. 07:45 - 09:00 1.25 DRILL P PROD1 RIH circulating at 1.53 bpm. Hole mostly smooth. Several set downs from 9950' to 10350'. Able to work through ok. 09:00 - 11 :30 2.50 DRILL P PROD1 Drill ahead. 2900 psi@1.53 bpm. 100 dpsi 1: 1 rtns WOB: 1. 7k# ROP:100-130 fph. BHP: 3912 psi ECD:11.5 ppg. Building angle very fast. Drill to 10650'. 11 :30 - 13:00 1.50 DRILL P PROD1 Short trip to window. Hole mostly smooth. 13:00 - 17:30 4.50 DRILL P PROD1 Drill ahead. 2900 psi@1.53 bpm. 200 dpsi 1:1 rtns WOB:2-3k# ROP:variable BHP: 3912 psi ECD: 11.4 ppg. Drilling several hard streaks. Drill to 10802'. POH to dial down motor. 17:30 - 21 :00 3.50 DRILL P PROD1 POH to 550. Close SSSV monitor well. Well flowing. Cycle SSSV. No Flow. PJSM. POH to surface. 21 :00 - 21 :40 0.67 DRILL P PROD1 Change bent of motor to 1.4. 21 :40 - 23:30 1.83 DRILL P PROD1 RIH . Open SSSV. RIH following pumping schedule. 23:00 - 23:15 0.25 DRILL P PROD1 Tie in @ 9200' +6' correction. 23:15 - 00:00 0.75 DRILL P PROD1 RIH. Set down at 10,541 10,68010,720. Change TF and run thru. 4/9/2003 00:00 - 00: 15 0.25 DRILL P PROD1 RIH tag TD at 10,803. 00: 15 - 03:45 3.50 DRILL P PROD1 Directionally drill 1.53 1 1.33 bpm @ 3475 psi FS = 3300 psi. DH annular pressure 3963 psi, DH tubing pressure 4392 psi, EDC 11.7 ppg @ 6532 tvd , WOB .93K, ROP 9-95. drill to 10,880'. Attempt to pick up off bottom. No Go. Shut down pump. Relax pipe. Wellhead stabilized at 440 psi.= ECD 9.91 ppg. 03:45 - 04:00 0.25 DRILL P PROD1 Wait. Pull free 18k over. 04:00 - 07:30 3.50 DRILL P PROD1 Directionally drill 1.51 11.20 bpm @ 3200 psi FS-3070psi. DH annular pressure 3869 psL, DH tubing pressure 4246 psi, ECD 11.4 ppg, WOB 1.2k,Surface wt -9K, ROP 5-90. Hard siderite streak in 10915' - 10920' vicinity. Try to punch thru for 2 hours. 07:30 - 09:15 1.75 DRILL P PROD1 Wiper trip to window. RIH. Several set downs 10650 -10750, all wlo MW. Acts more like poor slide. Printed: 4/14/2003 9:28:55 AM ) ) BP . Operations. Summary. Report Page 50f 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-1 5 1 C-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/1/2003 Rig Release: 4/13/2003 Rig Number: 2 Spud Date: 4/2/2003 End: 4/13/2003 Date From - To Hours Task Code NPT Phase Description of Operations 4/912003 09:15 -14:30 5.25 DRILL P PROD1 RIH to TD 10920'. Tag with minimal MW. Attempt to drill with 1.5k WOB. Slow progress to 10932'. Mix and pump 60 bbls mud plus additional 5% Lubetex. About 5 bbls before pill hit bit, saw a drilling break -- drill 1 0932' - 10948' at 60 FPH. Then hit another hard spot. 14:30 - 16:30 2.00 DRILL P PROD1 Try punching through. Drill slow to 10955'. 16:30 - 20:00 3.50 DRILL P PROD1 POOH in accordance with the pumping schedule. Close SSSV. POH to surface. 20:00 - 20:20 0.33 DRILL P PROD1 Changeout bit and motor.Two nose cutters chipped badly. Three of the gage cutter had flats worn. Length of flats about2/3 cutter diameter. Set motor to 1.2 degree. 20:20 - 22:30 2.17 DRILL P PROD1 RIH open SSSV. RIH to 9980' 22:30 - 23:30 1.00 DRILL N RREP PROD1 Failure of reel gear box. Unable to POH. Disconnect chain drive on-driller side of reel. Spool back to window. Inspect gear box on off-driller side and change oil in same. Seems to ope rater fine with one motor. It maybe a bit slow on trip out of hole. 23:30 - 00:00 0.50 DRILL P PROD1 RIH. Reel operating on off-driller siCe motor. 4/10/2003 00:00 - 01 :00 1.00 DRILL P PROD1 RIH to 9100 tie in +5' correction. Set down at 9650, 10150, 10650,10810,10922, and 10940. most set downs were without motor work. RIH tag at 10963'. 01 :00 - 04:20 3.33 DRILL P PROD1 Directionally drill 1.54 11.14 bpm @ 3160psi, FS = 3000psi. DH annular pressure 3842 psi at 6535 tvd for a ECD11.35 ppg. DH tubing pressure 4324 psi. WOB .3K surface wt -8K. Reduce circulation rate 1.42/1.11 bpm. Seemed to improve WOB & ROP. Drill to 11,042' 04:20 - 06: 15 1.92 DRILL P PROD1 Adding lubtex to increase lub consentration from 4.5 % to 5.5. % Current lubricants about 3% lubtex and 1.5% Flo Lube. Directionally drill 1.43 1 1.06 bpm @ 2910 psi, FS = 2850 psi. DH annular pressure 3813 psi at 6546 tvd for a ECD11.24 ppg. DH tubing pressure 4162 psi. WOB .5K surface wt -9K. ROP 5-40 06:15 - 08:00 1.75 DRILL P PROD1 ROP increase at 11065' to 75 FPH with 400 Ib WOB. Drill to 11110'. OP to 30k after stacking. 08:00 - 09:00 1.00 DRILL P PROD1 Wiper trip to window. At 9410', MW, OP and PO with increased LC. Worked through. Pull above window. Open circ sub. Stop moving coil. 09:00 - 10:00 1.00 DRILL N SFAL PROD1 Remove reel drive motor for gear box repair. 09:45 - 11 :30 1.50 DRILL N SFAL PROD1 Bumped BHI power cable while removing drive motor. Unable to power-up downhole tools. Repair cable. SI pressure stable at 400 psi. Stay parked above window and circulate 1.5 BPM. 11 :30 - 12:30 1.00 DRILL P PROD1 RIH. Hole in good shape. A couple of set downs w/o MW but generally smooth. 12:30 -17:30 5.00 DRILL P PROD1 Drill with 500 Ib WOB at about 20 FPH, 50 psi motor diff. Stack frequently, followed by 30k - 40k OP. Apparently crossed another fault. Still in C3. Nose it up. Drill to revised TD of 11195'. 17:30 - 18:30 1.00 DRILL P PROD1 Wiper to window. 18:30 - 18:45 0.25 DRILL P PROD1 Tie -in correction +14'. 18:45 - 20:00 1.25 DRILL P PROD1 RIH. Set down 9,63010,440 and 10,880' PU and adjust TF to continue. Tag TD. Corrected TD = 11207'. 20:00 - 22:30 2.50 DRILL P PROD1 POH to 500'. Close SSSV. POH to surface. 22:30 - 23:00 0.50 DRILL P PROD1 LD BHA Printed: 4/14/2003 9:28:55 AM ) ) BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-15 1 C-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/1/2003 Rig Release: 4/13/2003 Rig Number: 2 Spud Date: 4/2/2003 End: 4/13/2003 Date From - To Hours Task Code NPT Phase Description of Operations 4/10/2003 23:00 - 00:00 1.00 DRILL P PROD1 PU logging tools. Memory GR/CCL/RES 4/11/2003 00:00 - 02:30 2.50 EVAL N DPRB PROD1 RIH . Pressure well to 700 psi. Open SSSV. Monitor well after 15 min wellhead pressure 399 psi. and still bleading off slowly. RIH to 8800'. 02:30 - 02:45 0.25 EVAL N DPRB PROD1 Log down to 9161 corrected to flag. NO GO. Notified Ted Stagg. POH. 02:45 - 02:50 0.08 EVAL N DPRB PROD1 Break circulation at 1 bpm. DH annulus pressure 3640 psi. ECD 10.76 ppg. 02:50 - 04:15 1.42 EVAL N DPRB PROD1 POH. Pressure up well. Close SSSV. POH to surface. Lost two 1/2" X .0625" X 15" brass berrillium bow spring arms. 04: 15 - 07:00 2.75 EVAL N DPRB PROD1 Discuss options. Decide to make second attempt without knuckle joint and without centralizers. Program logging tools. MU logging BHA. 07:00 - 07:45 0.75 EVAL N SFAL PROD1 Repair mechanical counter. 07:45 - 09:15 1.50 EVAL N DPRB PROD1 RIH. Correct depth at flag (+9'). RIH clean to 9164'. Tag here. Clean PU. 09:15 -11 :15 2.00 EVAL N DPRB PROD1 Try to work logging tool past this depth at different rates and speed, unable to work past 9166'.' Clean PU's each time. 11 : 15 - 12: 30 1.25 EVAL N DPRB PROD1 POOH. Close SSSV, bleed well above, POOH. 12:30 - 13:00 0.50 EVAL N DPRB PROD1 LD logging tools. 13:00 - 13:45 0.75 CLEAN P COMP MU drilling BHA (1.2 deg motor; used DS100). 13:45 - 16:00 2.25 CLEAN P COMP RIH low side thru window. No problem. Several set downs. PU and trip thru. No Hole deterioration. 16:00 - 17:00 1.00 CLEAN P COMP POH thru window. Shut down holding 400 psi. 17:00 - 20:30 3.50 CLEAN N HMAN COMP Wait on Formate Brine delivery. 20:30 - 21 :50 1.33 CLEAN P COMP RIH to condition hole set down at 10,650 10,710 11,024 11,084 No motor work. Orient to get thru. RIH to 11 ,202.PU losing ground. PU but can't go down. Work backwards to 11,025'. RIH to tag TD @11 ,202. 21 :50 - 22:45 0.92 CLEAN P COMP POH. Over pull15K at 10,520'. No motor work. Went down thru no problem. POH to 9,100'. 22:45 - 23:00 0.25 EVAL P COMP Tie -in log. Correction +8'. 23:00 - 00:00 1.00 CLEAN P COMP Circulate in 10.2 ppg kill weight brine. At 1.5 bpm while monitoring DH annulus pressure. We were able to maintain 1.5 bpm through out the circulation maintaining the ECD at 11.1 ppg i.e. typical drilling ECD. Reduction in viscosity offset the increase in hydrostatic as no pump rate reduction was necessary. Loss rate .2 bpm throught out kill. 4/12/2003 00:00 - 00:30 0.50 CLEAN P COMP Complete circulating in kill weight brine. 00:30 - 00:40 0.17 CASE P COMP Monitor well. No Flow. 00:40 - 02:00 1.33 CLEAN P COMP POH to surface. 02:00 - 02:10 0.17 CASE P COMP Monitor well. No flow. 02:10 - 02:30 0.33 CLEAN P COMP LD BHA. 02:30 - 04:30 2.00 CASE N HMAN COMP RU floor. Wait on BOT. Current static loss rate 5 bph. Average loss rate for four hours 9 bph. 04:30 - 06:30 2.00 CASE P COMP MU liner. 06:30 - 07:00 0.50 CASE P COMP Crew change/safety meeting. 07:00 - 09:15 2.25 CASE P COMP Finish MU 2-3/8" 4.43# L-80 STL lliner: 23 jts predrilled at 4 SPF and 48 joints blank, 09: 15 - 09:45 0.50 CASE C COMP Wait on longer deployment sleeve for future potential liner top packer. 09:45 - 11 :30 1.75 CASE P COMP MU liner deployment sleeve, GS spear, 8 joints of 2-3/8" OD x 1.0" ID collars. MU BHI equipment including EDC and DPS. Printed: 4/14/2003 9:28:55 AM ) ) BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-15 1 C-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/1/2003 Rig Release: 4/13/2003 Rig Number: 2 Spud Date: 4/2/2003 End: 4/13/2003 Date From - To Hours Task Code NPT Phase Description of Operations 4/12/2003 09:45 - 11 :30 1.75 CASE P COMP Lost 20 bbls of 10.2 brine to formation since starting to PU liner at 04:30 hrs. 11 :30 - 13:30 2.00 CASE P COMP RIH. Tag 9161'. Unable to work past. Lost 9 bbls of 10.2 brine to formation RIH. 13:30 - 15:00 1.50 CASE N OPRB COMP POOH. 15:00 - 16:30 1.50 CASE N OPRB COMP LO the drill collars, standback liner. Look at bullnose. A couple of metal looking dings near the center of the bullnose. 16:30 - 17:00 0.50 CASE N OPRB COMP MU bullnose guide on knuckle joint. 17:00 - 19:30 2.50 CASE N OPRB COMP MU 35 stands of liner. Stab GS. MU 8 joints of 2-3/8" collars. 19:30 - 21 :00 1.50 CASE N OPRB COMP RIH to window 26K up, 9K dn. Run thru window no problem. Set down 9,409 9,429 9,440 9,586. PU run thru varing the tripping speed to get thru. TIH to 9,900. Top of slots above window. 21 :00 - 22:40 1.67 CASE P COMP Circulate out kill weight brine with 8.7 ppg Flo Pro ( for lubricity). Static ECO 10.06 ppg. Circulate at 1.47bpm ECO 11.09 ppg. Turn corner with mud @ 11.15 ppg ECO. ECO remained at 11.1 to 11.2 ppg through out circulation without changing pump rate. 22:40 - 00:00 1.33 CASE P COMP Circulate across top of hole holding 400 psi with choke. RIH with 4K surface weight at 65 ftlmin. Set down at 10,539. Working liner from 10,539 to 10,875'. Pick up to breakover. RIH to stack out and wait for pipe to creep in hole 3-5'. OH ECO 1 0.17ppg with 450 surface wellhead pressure. 4/13/2003 00:00 - 01 :40 1.67 CASE P COMP Continue to work liner to 11,111' (11,136' mechanical) Cycled coil 170 cycles working liner down. After seven attempts @ 11,111' with no further progress called it good. This was the first depth that some progress was not made on subsequent attempts. Top of liner 8,845' (8,874' Mechanical). Nipple at 8866 corrected to tie in log. Circulate still No Go. 01:40 - 01 :50 0.17 CASE P COMP Pump down coil 1.3 bpm release from liner. 01 :50 - 03:30 1.67 CASE P COMP Circulate out 8.8 mud @ 1.3 bpm 1 1.1 bpm with 3% KCL water while keeping OH pressure constant 3,500 psi. ECO 11.5 ppg. 03:30 - 05:00 1.50 CASE P COMP POH holding 400 psi on well head. Close SSSV. 05:00 - 06:00 1.00 CASE P COMP LO Collars and Liner running tools. 06:00 - 06:30 0.50 WHSUR P COMP Tech limit/safety meeting. 06:30 - 07:00 0.50 WHSUR P COMP MU nozzle. 07:00 - 10:00 3.00 WHSUR P COMP RI H to 8800'. 10:00 - 11 :30 1.50 WHSUR P COMP Lay in diesel (has friction reducer in it) to surface at 115 FPM and 1.0 BPM (1: 1), starting with a WHP of 700 psi and ending with a WHP of 1200 psi. Well drank about 10 bbls while displacing. Return density still a little heavy (7.5 ppg ish), probably strung out the displacement a little. Bleed well to 900 psi and then RIH to 1000' wlo pumping and got a good steady stream of 6.8 ppg fluid back. Pull out wlo pumping. Close SSSV. 11 :30 - 12:00 0.50 WHSUR P COMP LO nozzle, cut CTC. 12:00 -12:15 0.25 RIGO P POST Safety meeting. 12:15 - 13:00 0.75 RIGO P POST Reverse KCL water for slack management 13:00 - 14:00 1.00 RIGO P POST Reverse 60/40 MeOH to freeze protect coil. Open swab momentarily to make sure FP gets across top of well and tree. 14:00 - 15:30 1.50 RIGO P POST Unstab pipe and suck to reel. Secure. Cleaning pits. Lower reel (Nordic request to move w/o reel) 15:30 - 17:00 1.50 RIGO P POST NO BOPE. NU and PT tree cap. Release rig 17:00 hrs Printed: 4/14/2003 9:28:55 AM ') ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-1 5 1 C-1 5 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/1/2003 Rig Release: 4/13/2003 Rig Number: 2 Spud Date: 4/2/2003 End: 4/13/2003 [Date From - To Hours Task Code NPT Phase Description of Operations 4/13/2003 15:30 - 17:00 1.50 RIGD P POST 4-13-03. Printed: 4/14/2003 9:28:55 AM ) ) III.. B s: BP Baker Hughes INTEQ Survey Report .....'................... I.N'l'.E.Q Company: Field: Site: Well: Wellpath: Phillips Alaska, Inc. Kuparuk River Unit KRU 1C Pad 1 C-15 1C-15L1 Date: 4/30/2003 Time: 10:52:45 Page: Co-ordinate(NE) Reference: Well: 1C-15, True North Vertical (TVD) Reference: 1C-15 RKB 101.5 Section (VS) Reference: Well (0.00N,O.00E,307.00Azi) Survey Calculation Method: Minimum Curvature Db: Sybase Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Site: KRU 1 C Pad UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5968605.00 ft 562247.20 ft Latitude: Longitude: North Reference: Grid Convergence: 70 19 29.107 N 149 29 42.918 W True 0.48 deg Well: 1C-15 Slot Name: Well Position: +N/-S 0.00 ft Northing: 5968605.00 ft Latitude: 70 19 29.107 N +E/-W 0.00 ft Easting : 562247.20 ft Longitude: 149 29 42.918 W Position Uncertainty: 0.00 ft Wellpath: 1C-15L 1 Drilled From: 1 C-1 5 500292293260 Tie-on Depth: 9142.00 ft Current Datum: 1C-15 RKB Height 101.50 ft Above System Datum: Mean Sea Level Magnetic Data: 3/19/2003 Declination: 25.50 deg Field Strength: 57502 nT Mag Dip Angle: 80.75 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 307.00 Survey Program for Definitive Wellpath Date: 4/30/2003 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft 121.00 9142.00 Magnetic Multishot (0) CB-MAG-MS Camera based mag multi shot 9142.00 11207.00 MWD MWD MWD - Standard Annotation MD TVD ft ft 9142.00 6617.07 KOP 11207.00 6629.43 TO Survey: MWD Start Date: 4/10/2003 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Survey MD Incl Azim TVD SSTVD N/S E/W MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/100ft 9142.00 25.87 70.09 6617.07 6515.57 1940.05 5585.56 5970591.12 567815.94 -3293.28 0.00 9172.29 15.15 66.61 6645.40 6543.90 1943.88 5595.43 5970595.04 567825.78 -3298.86 35.60 9200.15 26.85 63.52 6671.37 6569.87 1948.15 5604.44 5970599.38 567834.75 -3303.48 42.17 9229.11 35.95 57.26 6696.07 6594.57 1955.68 5617.47 5970607.02 567847.72 -3309.36 33.34 9258.69 46.65 44.04 6718.30 6616.80 1968.17 5632.32 5970619.63 567862.47 -3313.70 46.52 9291.80 60.86 41.60 6737.83 6636.33 1987.73 5650.39 5970639.34 567880.37 -3316.35 43.32 9321.79 74.97 38.27 6749.08 6647.58 2009.01 5668.15 5970660.76 567897.95 -3317.73 48.15 9351.47 89.29 34.94 6753.13 6651.63 2032.56 5685.62 5970684.45 567915.22 -3317.51 49.50 9386.79 94.64 23.11 6751.92 6650.42 2063.35 5702.71 5970715.39 567932.06 -3312.63 36.73 9414.51 101.73 13.61 6747.97 6646.47 2089.34 5711.36 5970741.44 567940.49 -3303.90 42.47 9439.67 102.66 359.89 6742.63 6641 .13 2113.70 5714.25 5970765.82 567943.17 -3291.55 53.42 9474.22 102.91 353.07 6734.97 6633.47 2147.31 5712.18 5970799.41 567940.83 -3269.67 19.26 ) BP ) Baker Hughes INTEQ Survey Report .....,...,...,...."........."...... INT.EQ Company: Phillips Alaska, Inc. Date: 4/30/2003 Time: 10:52:45 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1C-15, True North Site: KRU 1C Pad Vertical (TVD) Reference: 1C-15 RKB 101.5 Well: 1 C-15 Section (VS) Reference: Well (0.00N,O.00E,307.00Azi) Wellpath: 1C-15L1 Survey Calculation l\lethod: Minimum Curvature Db: Sybase Survey Azim TVD SSTVD N/S E/W MapN MapE VS DLS deg deg ft ft ft ft ft ft ft deg/100ft 9501.47 102.95 348.24 6728.87 6627.37 2173.50 5707.87 5970825.57 567936.30 -3250.46 17.28 9532.49 101.93 347.31 6722.19 6620.69 2203.11 5701.46 5970855.11 567929.64 -3227.52 4.40 9564.60 101.43 344.00 6715.69 6614.19 2233.57 5693.67 5970885.50 567921.60 -3202.97 10.21 9594.65 101.74 335.25 6709.64 6608.14 2261.14 5683.43 5970912.98 567911.13 -3178.20 28.54 9629.87 101.47 329.98 6702.55 6601.05 2291.76 5667.56 5970943.47 567895.02 -3147.1 0 14.68 9659.27 99.10 325.44 6697.30 6595.80 2316.20 5652.11 5970967.78 567879.37 -3120.05 17.20 9689.03 96.43 323.93 6693.28 6591.78 2340.26 5635.07 5970991.69 567862.12 -3091.96 10.28 9719.76 94.21 321.34 6690.43 6588.93 2364.57 5616.50 5971015.85 567843.36 -3062.50 11.07 9751.52 92.70 316.34 6688.51 6587.01 2388.43 5595.64 5971039.53 567822.30 -3031.48 16.42 9782.87 91.47 312.02 6687.37 6585.87 2410.26 5573.18 5971061.17 567799.66 -3000.41 14.32 9817.40 91.32 307.08 6686.53 6585.03 2432.23 5546.57 5971082.92 567772.88 -2965.93 14.31 9851.29 91.54 300.34 6685.69 6584.19 2451.02 5518.40 5971101.48 567744.56 -2932.13 19.89 9885.77 91.60 295.54 6684.74 6583.24 2467.17 5487.96 5971117.37 567713.99 -2898.10 13.92 9917.01 92.34 289.34 6683.67 6582.17 2479.08 5459.12 5971129.04 567685.05 -2867.90 19.98 9946.43 91.23 285.98 6682.75 6581.25 2488.00 5431.1 0 5971137.72 567656.96 -2840.16 12.02 9974.97 86.47 276.04 6683.32 6581.82 2493.44 5403.14 5971142.94 567628.96 -2814.55 38.60 10000.04 91.35 277.03 6683.80 6582.30 2496.30 5378.24 5971145.58 567604.04 -2792.95 19.86 10029.76 93.59 269.54 6682.52 6581.02 2498.00 5348.62 5971147.04 567574.41 -2768.27 26.28 10073.28 93.32 264.84 6679.89 6578.39 2495.87 5305.25 5971144.55 567531.06 -2734.91 10.80 10103.91 91.11 260.45 6678.71 6577.21 2491.95 5274.90 5971140.38 567500.75 -2713.03 16.04 10133.48 92.98 264.04 6677.65 6576.15 2487.96 5245.63 5971136.15 567471.51 -2692.05 13.68 10165.16 93.10 267.18 6675.97 6574.47 2485.54 5214.09 5971133.47 567439.99 -2668.32 9.90 10201.00 89.97 276.10 6675.01 6573.51 2486.57 5178.32 5971134.20 567404.22 -2639.13 26.36 10235.98 90.95 280.62 6674.73 6573.23 2491.65 5143.72 5971138.99 567369.58 -2608.44 13.22 10283.17 88.16 288.16 6675.10 6573.60 2503.37 5098.05 5971150.33 567323.82 -2564.92 17.03 10318.91 90.86 293.16 6675.40 6573.90 2515.97 5064.62 5971162.65 567290.29 -2530.64 15.90 10349.35 90.86 298.25 6674.95 6573.45 2529.17 5037.21 5971175.62 567262.77 -2500.80 16.72 10380.73 91.69 303.69 6674.25 6572.75 2545.31 5010.32 5971191.53 567235.75 -2469.61 17.53 10410.21 90.80 305.92 6673.61 6572.11 2562.13 4986.12 5971208.15 567211.42 -2440.16 8.14 10440.89 88.86 309.10 6673.70 6572.20 2580.81 4961.79 5971226.63 567186.93 -2409.49 12.14 10474.64 88.59 311.59 6674.45 6572.95 2602.65 4936.07 5971248.25 567161.04 -2375.81 7.42 10506.15 95.90 310.71 6673.21 6571.71 2623.35 4912.38 5971268.76 567137.18 -2344.43 23.37 10538.88 103.54 308.55 6667.69 6566.19 2643.92 4887.56 5971289.12 567112.19 -2312.23 24.23 10571.30 103.67 301.31 6660.06 6558.56 2661.95 4861.74 5971306.93 567086.23 -2280.76 21.71 10605.57 104.56 293.37 6651.69 6550.19 2677.20 4832.25 5971321.94 567056.62 -2248.03 22.62 10640.19 104.79 286.33 6642.91 6541.41 2688.57 4800.77 5971333.04 567025.05 -2216.05 19.68 10673.19 102.25 281.28 6635.19 6533.69 2696.21 4769.62 5971340.42 566993.84 -2186.57 16.75 10704.86 95.23 279.23 6630.38 6528.88 2701.78 4738.84 5971345.73 566963.02 -2158.64 23.07 10738.38 91.29 271.58 6628.47 6526.97 2704.92 4705.56 5971348.60 566929.71 -2130.16 25.63 10773.37 87.23 273.76 6628.92 6527.42 2706.55 4670.62 5971349.94 566894.76 -2101.28 13.17 10807.12 89.88 281.51 6629.77 6528.27 2711.03 4637.21 5971354.14 566861.32 -2071.90 24.26 10840.55 86.50 286.25 6630.83 6529.33 2719.04 4604.78 5971361.88 566828.83 -2041.18 17.41 10871.94 86.28 291.96 6632.81 6531.31 2729.29 4575.19 5971371.89 566799.16 -2011.38 18.17 10901.75 87.66 296.25 6634.38 6532.88 2741.45 4548.03 5971383.81 566771.90 -1982.37 15.10 10934.21 88.45 303.99 6635.49 6533.99 2757.71 4519.99 5971399.85 566743.73 -1950.19 23.95 10959.72 86.81 306.39 6636.54 6535.04 2772.40 4499.16 5971414.36 566722.78 -1924.72 11.39 10989.63 83.94 311.31 6638.95 6537.45 2791.09 4475.95 5971432.85 566699.42 -1894.93 19.00 11020.67 87.73 313.92 6641.21 6539.71 2812.05 4453.17 5971453.62 566676.47 -1864.13 14.81 11050.78 91.17 315.94 6641.50 6540.00 2833.31 4431.86 5971474.70 566654.99 -1834.32 13.25 11081 .71 94.30 322.17 6640.02 6538.52 2856.63 4411.63 5971497.85 566634.56 -1804.12 22.52 11114.57 93.21 323.34 6637.87 6536.37 2882.73 4391.78 5971523.78 566614.50 -1772.56 4.86 11140.14 95.47 319.70 6635.93 6534.43 2902.69 4375.92 5971543.60 566598.48 -1747.89 16.72 11158.42 95.60 319.52 6634.17 6532.67 2916.54 4364.13 5971557.36 566586.57 -1730.13 1.21 ) ) M..! BP Baker Hughes INTEQ Survey Report .....".....',...........,......... IN'l'.ßQ Company: Phillips Alaska, Inc. Field: Kuparuk River Unit Site: KRU 1 C Pad Well: 1C-15 Wellpath: 1C-15L 1 Date: 4/30/2003 Time: 10:52:45 Page: 3 Co-ordinate(NE) Reference: Well: 1C-15, True North Vertical (TVD) Reference: 1 C-15 RKB 101.5 Section (VS) Reference: Well (0.00N,O.00E,307.00Azi) Survey Calculation Method: Minimum Curvature Db: Sybase Survey 11207.00 95.60 319.52 6629.43 6527.93 2953.32 4332.75 5971593.87 566554.89 -1682.93 0.00 Phillips Alaska, Inc. WELLPATH DETAILS 1C·15L 1 500292293260 Parent Well path: 1C-15 Tie on MD: 9142.00 Rig: Nordic 2 Ref. Datum: 1C-15 RKB 101.500 V.Section Origin Origin Starting Angle +N/-S +E/-W From TVD 307.00' 0.00 0.00 0.00 REFERENCE INFORMATION Co-ordinate (N/E! Reference: Well Centre: 1C-15. True North Vertical (tVD Reference: System: Mean Sea Level Section (VS Reference: Slot - (O.OON,O.OOE) Measured Depth Reference: 1C-15 RKB 101.50 Calculation Method: Minimum Curvature ANNOTA nONS TVO MO Annotation 6515.57 9142.00 KOP 6527.93 11207.00 TO j~~!K::~r 1 ¡g:¡~'i~:~' F~ ·EJ-W Shape 6H~~ =~ ~~¿~~ ~ ~~ ~~~ :~~~ ~ :U~ fl!iH ~~ ~ 6150 - C .- 6200 = ~6250 - ï; 6300 a. ~6350 ¡6400 CJ 1:: 6450 Q) ~ 6500 ~6550 6600 6650 6700 6750 ! !~ ../ ConocòPhillips F&._ Øll'''-. ~.------~-~ INTE(~ D¡red.: (G071 267~6613 6a~_er Hughes ¡~~~~~ }~3~J~~·~~~;q·com T AM A é Wellpath: (1C-15/1C-15L1) LEGEND IC-15.1C-15L I.Plan #ß IC-15 (1C-15) 1C-15L1 Azimuths to True North Magnetic North: 25.50' Magnetic Field Strength: 57502nT Dip Angle: 80.75° Date: 3/19/2003 Model: BGGM2002 Created By: Bnj Polnis Date: 4/30/2003 CDniact !r:forrn3lion: West( - )/East( +) [1 DOft/in] -1/30/2003 10:51 AM ~ '-~ ) @.~®"?i re~ 1: ® -: ® @~r¡ ® ~ LIru.J r ~IJ Iru~Iru6))L~Iru AlASKA. OIL AND GAS CONSERVATION COltDlISSION / FRANK H. MURKOWSKI, GOVERNOR 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Kuparuk River Unit 1 C-15Ll BP Exploration (Alaska), Inc. Permit No: 203-032 Surface Location: 1634' SNL, 1239' EWL, Sec. 12, T11N, R10E, UM Bottomhole Location: 1358' NSL, 140' EWL, Sec. 06, T11N, RIlE, UM Dear Mr. Stagg; Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, . and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is for a new well bore segment of existing well KRU 1C-15, Permit No 198-229, API 50-029-22932. Production should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~.-~~~ Randy Ruedrich Commissioner BY ORDER ~~~'@E COMMISSION DA TED this~r' day of February, 2003 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section iAJl7 A- 2-{ 2- G, (l.-C c.."1 "5 Hole 3" ) STATE OF ALASKA ) ALASKA UIL AND GAS CONSERVATION COMMI~$ION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool RKB = 101.3 Kuparuk Oil Pool 6. Property Designation ADL 028242 7. Unit or Property Name Kuparuk Unit 8. Well Number /' 1C-15L 1 9. Approximate spud d~ 03/15/03 Amount $200,000.00 14. Number of acres in property 15. Proposed ~pth (MD and TVD) 2560 112501'MD / 64781 TVDss o 17. Anticipated pressure {s,;.e 20 AAC 25.035 (e) (2)} 105 Maximum surface 3350 psig, At total depth (TVD) 6500' / 4000 psig Setting Depth Top Bottom Quantity of Cement Lenath MD TVD MD TVD (include staae data) 23101 89401 6424' 11250' 6478' Uncemented Slotted Liner 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work 0 Drill II Redrill ORe-Entry 0 Deepen 2. Name of Operator ConocoPhillips 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 562247, Y = 5968605 1634' SNL, 1239' EWL, SEC. 12, T11N, R10E, UM At top of productive interval x = 567796, Y = 5970583 2961 NSL, 15261 EWL, SEC. 06, T11 N, R11 E, UM At total depth x = 566400, Y = 5971632 13581 NSL, 1401 EWL, SEC. 06, T11N, R11E, UM 12. Distance to nearest property line 13. Distance to nearest well / ADL 025649,140' MO No Close Approach 16. To be completed for deviated wells Kick Off Depth 91801 MD Maximum Hole Angle 18. Casing ~rogram Specifications Size Casina Weight Grade CouDlina 2-3/8" 4.6# L-80 ST-L Number 2S100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 9390 feet Plugs (measured) true vertical 6840 feet Effective depth: measured 9146 feet Junk (measured) true vertical 6621 feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner 1211 6249' 16" 9-5/8" 9 cu yds High Early 850 sx AS III LW, 610 sx Class IGI 1211 62491 121' 44881 93901 7" 178 sx Class 'GI 9390' 6840' \c: I Perforation depth: measured 9096' - 91421 true vertical 65761 - 6617' 20. Attachments II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch 'II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 1120 MC 25.050 Requirements Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By NamelNumber: Terrie Hubble, 564-4628 21.1S~;~:Y C:':i;œ:a~€ue and cor:~t:t~:::i;E~1gn:ineer Datef11~ Permit Number API Number Aj)P.r~va,I q~te~ See cover letter 2.0","-~ - () 32.. 50- 029-22932-60 ,·:~.·~~¿y/l'?:~ for other requirements Conditions of Approval: Samples Required 0 Yes 181 No Mud Log ReqŒred 0 Yes ~ No Hydrogen Sulfide Measures ß] Yes 0 No Directional Survey Required ~ Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU . . ,_ Other: /v'tr:~ t.~~~Afi.:t ðt.<.,.../,¿k, l~j 'Oc.~r...tdeo,.- i\v·j€.t,fÙ..,,- ç~-v-\J"L€ . ¡ ,~st Eo PE- te ~ço(.,-¡ ps.~. . . by ordet o.f . -/ /.V ;" .-> Approved By Original Siøn~..t;:Sy~~omml$a'oner /', ~ the commiSSion Date c.~/ ~:.--i J .r/,0> "5 Form 10-401 Rev. 12-01-85 Randy Rued~ ". I I '\ Ii Submit Iri'Triplicate ,". ~ ,.....~ ) ',) KRU 1 C-15L 1 CTD Sidetrack BackQround: KRU 1C-15 has been producing from frac'ed C Sand perfs. Declining production and the need for injection .\ su pport in this area have resulted in this plan to sidetrack 1 C-15 to the northwest while preserving the./"" &V,J original completion interval in 1 C-15. After a pre-production period, the well will be converted to MW ~ L ,....-' injection into both the original C sand perfs and into the C Sand interval of the new 1 C-15L 1 lateral. Summary of Operations: " Pre-sidetrack work will include an SCMT log to evaluate 7" liner cement quality for injection and for window /' milling requirements. Cement for the window exit will be placed with the well flowing in order to avoid damage to the existing perfs. Once cement is in place for the window, an acid soluble pill will be placed /~ across the existing perfs to protect them while drilling and completing the lateral. Reservoir pressure at the window will be 3,070 psi or 9.1 ppg. However, after crossing a fault mid-way through the polygon the reservoir pressure may be as high as 4,000 psi or 11.8 ppg. The sidetrack will be / drilled with the dynamic overbalanced technique, DOCTD, whereby a solids free drilling fluid of 8.7 ppg will be used in conjunction with choked returns resulting in a slight overbalance at the formation face while drilling and tripping. A kill weight fluid, up to 12.0 ppg, will be used during the completion phase. Phase 1: Prep work. Planned for completion by March 3, 2003. /' 1. Mechanical integrity testing has been done successfully 2. A fill clear out will be done to provide approx. 100 ft of sump below existing perfs. 3. An SCMæÔ....." will be run to confirm cement quality for injection service and for window milling. 4. Approx 4 s of 17 ppg cement will be placed in the sump below existing perfs for a cement ramp wi· ow. 5. A sized calcium carbonate pill will be placed across the existing perfs to isolate them during the drilling a completion of the new lateral. Phase 2: Mill window, Drill and Complete sidetrack: Planned for March 15,2003. Drilling coil will be used to mill the window at 9,180' MD (6550ss)from a cement ramp then drill and ./ complete the directional hole as per attached plan. Maximum hole angle will be 105 degrees. Mud Program: · Phase 1: Seawater / · Phase 2: Use DOCTD technique to mill with 2 ppb biozan in 2% KCI and drill with Flo-Pro (8.7 ppg). Completion fluid will be up to 12.0 ppg Kformate brine to maintain static overbalance while running liner. Disposal: · No annular injection on this well. · Class II liquids to KRU 1 R Pad Class II disposal well · Class II drill solids to Grind & Inject at PBU Drillsite 4 · Class I wastes will go to Pad 3 for disposal. Casing Program: / The production liner will be 2 3/8" ST-L pre-drilled from TD to approx. 10,000' MD (6,598ss) and solid liner from 10,000' MD to 8,940'MD (6,424 'ss). The liner will not be cemented. Both the new lateral and the existing perfs will be open for initial pre-production and later for MWAG injection. /' Well Control: · BOP diagram is attached. / · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. ') ) Directional ~ · See attached directional plan. Max. planned hole angle is 10 ego . Magnetic and inclination surveys will be taken every 30 ft. 0 gyro will be run. Logging · MWD Gamma Ray will be run in the open hole section. Resistivity log may be run in memory mode if needed to evaluate the B Sands. Hazards · Lost circulation risk from faulting is 10Y Losses to existing perfs will be controlled by an LCM pill. · 1 C-15 has produced H2S at 29 ppm. All H2S monitoring equipment will be operational. · Doyan 141 will be on the same Pad therefore simultaneous operations will be in progress. Reservoir Pressure / Res. press. near the window is estimated to be 3070 psi at 6485'ss (9.1 ppg emw). Max. surface pressure ~.r... gas (0.1 psi/ft) to surface is 2422 psi. However, the targ~~.t· .... al may be up to 4000 psi at 6500ss (Cft ppg) resulting in a maximum surface pressure with gas of~ psi. As done in the past at KRU by CTD, dynamically overbalanced cOiled~g drilling (DOCTD) techniques will be employed to address high reservoir pressure. Plans are to us 8 ppg drilling fluid in combination with annular friction losses and applied surface pressure to maintain . rbalanced reservoir conditions. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. / Using this technique with an underbalanced mud weight requires deployment of the BHA under trapped 'f wellhead pressure. Deployment will be accomplished utilizing the BOP pipe/slips (2-3/8" rams, see / ~~ attached BOP configuration). The annular preventer will act as a secondary containment during J-- deployment and not as a stripper. At least two times hole volume of kill weight fluid will be on location as a contingency. Once drilling is complete, the production liner will be deployed into the wellbore after killing the well with kill weight fluid. Operating parameters will be adjusted based on real-time bottom hole pressure measurements while drilling. · ) SAfET )OTES: H2S KRU 1 C-15L 1 Proposed ./ <it TRDP-4E 2019' 2.812" ID Minimum ID 2.75" @ D Nipple Maximum Hole Angle 53 deg. @ 2783' L ~ ST fvÐ 1VD 1 3325 2603 2 5349 3908 3 6592 4709 4 7554 5340 5 8331 5906 6 8827 6334 GAS LlFf MA.N:H3...S DEV TYÆ VLV LATOi FORT KBMv1 GI... V BK2 0 KBMv1 GI... V BK2 KBMv1 OV BK2 KBMv1 OV BK2 KBMv1 GI... V BK2 Mv1\/I avTY RK f)ô.TE 02/07/02 02/07/02 02/07/02 10/12/99 05/13/99 02/06/02 9 5/8" @ 6249' ~ I I 8965' W Nipple 2.812" ID ::8: ~ 8919' Baker S-3 Perm Packer Proposed top of 2 3/8" liner 8940' MD - ~ ) I I 3 1/2" 9.3# EUE 8RD tubing 2.992" ID 8965' Camco D Nipple 2.75" ID I 8976' SOS 2.992" ID - - 9096' Frac'ed perfs in C Sand Proposed Top of 17 ppg cmt. 9145' - - - 9142' I, \ i'¡ /' Proposed window 9180' MD \~ .~~ 23/8" ST.L . Iii ii, J "~'P-n"d 0\\ /' o 0 0 0 o 0 000 0 0 0 0 0 3" Open Hole 11,250' (6478ss) FILL 7" 26" L-80 AlB Mod Butt @ 9390' ~ Phillips Alaska, Inc. WELLPATH DETAI~ ......" tC·15L1 5002U:n3260 '.rent Wellpllth: 1C·15 Tie on MD: 11120.00 11.151: 1C·1511K8 101.5Oft 1tef'.D.tum; V.....tIon O.':8!ä ~~~ :=~ AnOIe 307.00' 0.00 0.00 0.00 REFERENCE INFORMATION Co-ordinate ~E! Reference: Well Centre: 1C·15. True North Vertical ( 0 Reference: System: Mean Sea Level Mea~:;Üeâ'h~J" ~::::~: ~~\5 Wi<~·O·~O~).50 Calculation Method: Minimum Curvahxe aKTlOH DETAIL. ... 110 lac ...., TVO +NI" .!J·W DL.. TP.c. Va..c T_I'I!. 'I 1120.00 25.80 70.1' I-4ls.n 1138.18 557'.54 0.00 0.00 ·3211.04 ! :ill~ ~:E *:~ :lli:~ l!*~ æi::v:t:~ ~::E :~~~:~ a ...:s.o... eo.OO 342'" "48.SO 2134.52 neZ.At 41.75 -10.00 ·3238.08 · 1480.'. 80.00 US... H48.50 21111." 5845.7' 12.00 ·80.00 ·3111.10 1 1551.73 ".00 nO.l3 H44.7I 2244.11 5814.8-4 12.00 -45.00 ·3133.04 · 10051.73 1".72 270.15 '513.21 2481.82 5208.30 12.00 .....00 ·2&81.27 · 10HI.73 ".78 30'."1 1500.... 25111.52 "115.34 12.00 15.00 ·2387.15 1010481.7.1104.7. 300.1' 1542.11 2642.15 4838.47 12.00 ....5.00 ·2274.81 U ~:;~:~~ :::~: ~;~:: :~::: ~~::~ :~:~:;: g::g .~;:~ :~J;::;~ 13 1t250.00 ".17 n5.35 8-477.'5 2"2.77 4171.51 12.00 eo.OO ·153ð.oe ANNOTATION' TARGET ŒU.....S TVO ND bllotaUoII N."..,. "" .N/-S +EI-W Shaç.e 1C-ISA ToU 6116.00 NM.50 <1110.13 Poir;I M115.77 0120.00 TIP 1C·I511 TJ3 6S19OO 2690.05 4131.13 Poio4 '_.75 0110.00 KOP 1C·15A T22 656000 26OOe.o .c91L01 Poõ:'II 1512.14 .104.00 3 1C--15A H.I 665000 211353 5636.56 Pon ......50 83.5.1. .. _.SO 0430'" 5 1548.SO 04110"0 . 6«4.70 0551.13 7 nU.28 10051.73 8 UaoM 10388.73 . 1542.71 104111.73 10 8510.20 10508.13 11 lSO'.De 10721.73 12 8477." 11250.00 TO 1C-15L Date: 2/11/2003 Contact Information: Direct {gO?'; 267~e.ß13 E-rnai: tJrij_potn¡s(@:nteq !NTEQ: {90Y} 2B?-f5:(;{"f.} Plan: Plan #4 (1C-15/PIan#4 Created By: Brij Patnis Azimuths to True North Magnetic North: 25.53° Magnetic Field Strength: 57501nT Dip Angle: 80.75° Date: 2/11/2003 Model: BGGM2002 T AM e- ~f;~;i 1 g: 1 ~l1 Plan #4 BI. liS I )0-" ! B. ConocoPhilli~ ilNTEQ _com H!J9~es Ba!<.er 3300 -2 .5 ~2 o ""' 2 600- - +2 - .c 1::2 o ~2 I :ë'2 .. ~ O2 en 2000 200 1900 1800 700 100 3200 3100 3000 2900 800 700 500 400 300 1600 6600 [I 4 ~ì r§j 6650 -·t- [1C-15A~U! 6700 ,-1Ç-15 (1C:155( -3350 -3300 -3250 -3200 -3150 -31 00 -3050 -3000 -2950 -2900 -2850 -2800 -2750 -2700 -2650 -2600 -2550 -2500 -2450 -2400 -2350 -2300 -2250 -2200 -2150 -2100 -2050 -2000 -1 950 -1900 -1850 -1800 -1750 -1700 -1650 -1600 -1550 -1500 -1450 -1400 Vertical Section at 307.000 [50ft/in] 2/11/2003 10:'19 AM Plan#41C-15L1LL!º-i \/ _._n~\+ _n_ / 1C-15A T4.41 West(-)/East(+) [100ftlin] 3600 3700 3800 3900 4000 4100 3~: 6000 6050 6100 _6150 C ~ 6200 1:2.6250 .c 'S. 6300 G) Q 6350 'iã CJ 6400 :e G) 6450 > G) 6500 2 ... 6550 ) BP ) Baker Hughes INTEQ Planning Report 1'0,1.............1." ~_............." INTEQ 1--è·~-~;;J;·~-··Philïi;~"A~~~~~:ïri·~.---~~_·---.._--"··----~-.--._..-----.-.-".-ë··--,·-·-·--··--D~~~~--···,-;ì-1-1'/2oo3"'~"---'--'--~i~~;"~1o':52~'53-'~--- .__.______.___.._.m;~~~~.---.~.-..~-.--~.-- : Field: . Kuparqk River Unit . . Co-ordinate(NE) Reference:WeJI:1 C-15,TrueNorth .. Site:KRU 1 C Pád . Vertical (TVD) Reference: System: Mean Sea LE~vel ¡Well: . tC-15.. .. SeCtion (VS)Reference: Well (O.00N,O.00E,307.00Azi) l_ Wellpath: Plan#41 C-15L! ___________ Survey C~lCul~!~~_~_!~~~~____~in~~~.~ Curvature . ~~:.~._~J1~~:._._ --- -'-- -~-_._,_.~.__._-'"---- ----------.---.--.--- ---_._----,-_._-,._--,---_.~ Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Site: KRU 1 C Pad UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Well: 5968605.00 ft 562247.20 ft 70 19 29.107 N 149 29 42.918 W True 0.48 deg Latitude: Longitude: North Reference: Grid Convergence: _._----~- 1 C-15 Slot Name: 0.00 ft Northing: 5968605.00 ft Latitude: 0.00 ft Easting: 562247.20 ft Longitude: 0.00 ft 70 19 29.107 N 149 29 42.918 W Well Position: +N/-S +E/-W Position Uncertainty: _~_.__.__._._..__.w~·_'"·.._.,.,_ __,___,,_..,._____._._._,._____.,_.._._____..._. -----_.~-------,- --.,.-.- _____._______._..____________"____.__~___._,__._..______~.,"___·..w_.__~ -"--_.._..._------_._,----_._._-_.__._.~-_.,,'--_._-,-----_._----_..__._.._._-_._-"-,,----_.._._-_.__._-----_._~---.---,-..-,--.-.--.-..-.--" -_...._---,_._~._-,,_._--_._._-~------_.~-,-,,_._._. Wellpath: Plan#4 1 C-15L 1 500292293260 Current Datum: 1C-15 RKB Magnetic Data: 2/11/2003 Field Strength: 57501 nT Vertical Section: Depth From (TVD) ft ______._"'_._...._,_~_ .--.----,0--".---...----- 0.00 --- ----_.~._---.- --~~_...~ --. Targets Drilled From: Tie-on Depth: Height 101.50 ft Above System Datum: Declination: Mag Dip Angle: +N/-S +E/-W ft ft _._~__._~__ _____·,___._._.__"_.______.____W".w___·___.__n._ ._,..."_____~__._ _.__..__,..___,_________ 0.00 0.00 1 C-15 9120.00 ft Mean Sea Level 25.53 deg 80.75 deg Direction deg 307.00 _._-_.-._._,-_.._-._~.,-._._-_._-_. .~_..__.,.~----_.,_.""._"~-~.__.,---~_._--,,_. --. ._--------. _.__.._~--_..._~-_._._.__._-_._-"_._-_.._~_.--..._,,-,,--~---"-,.-.-.--"..--.----.-----.------..,,-. -~--------~,._~._--._".__._._-_.._-_.,--'""-""_....~._.-_._"_.-.....,.__._._._-----~._-.~---...- "... -.- "..."-"_._--~-- . - -....- ...."_...._......--_..".._.........". ... .._. . -... w, __ .~. ,~_... ,._. r"""_ .. ._..____....._.."_ ,. _._.. ._."._.,._._._.. ow _."__"...._"__..__.."..~.__.._..__,_. _..."_._" ... .-'" ...... "." -.. - - Name Description TVD Dip. Dir. ft -. ----- -,- - ._~-- .,- ----.-... ----- -- --....-- 1C-15A T4.4 6478.00 1C-15L 1 T3.3 6519.00 1C-15A T2.2 6560.00 1C-15A T1.1 6650.00 Map Map <-- Latitude --> <-- Longitude --> +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec ft ft ft ft ~-_._-- --- --- -- - - .--- .--- ------ - ------..- .... ---".."_.- --.- _ _. ___._.__._____ ___ ____ ___.___ _ __. _. _ __ _. __ _ _w. ____._ 2988.80 4170.13 5971628.00 566392.00 70 19 58.491 N 149 27 41.151 W 2690.05 4737.73 5971334.00 566962.00 70 19 55.549 N 149 27 24.583 W 2600.60 4911.01 5971246.00 567136.00 70 19 54.668 N 149 27 19.525 W 2173.53 5636.56 5970825.00 567865.00 70 19 50.463 N 149 26 58.349 W Annotation '~"--'--'-"-- -----_._-_.---_._-----_..._--_._---~------------.._._..- --_..._~--~ -~-------~-_..,--------"--"._.,--_._--_...~-----------~-~----.--.---.""~-.~"-"---.--.-..-"------'- ---_._.__._..~-_. ~.. ...-----.- MD ft 9120.00 9180.00 9194.00 9365.89 9430.89 9480.89 I 9551.73 ¡ 10051.73 1110366.73 10461.73 ! 10596.73 , 10721.73 11250.00 TVD ft 6495.77 6549.75 6562.14 6648.50 6648.50 6648.50 6644.79 6593.28 6560.49 6542.71 6519.29 6509.06 6477.95 TIP KOP 3 4 5 6 7 8 9 10 11 12 TD - .------.----.-.-.- -------.-.-----.----------- --------.------ -----.----.-.-.--..---..-.- - .._-_._._---~--------_.-_._._-_._._- ') BP , Baker Hughes INTEQ Planning Repor~ . 8A HI' _·,··y·...··,W·....W\W'f·W""^""H.^'^. _____.____._~~_.__" ·"..___...__c· ._ ~~~~ ,'"..' _._"._.___.__~~.Þ"~_ ".._ ,_...._ .."_" "__..___. ."._._. ._...______....__.._____..__._.....~_._ .____._..._._._.~._._....____...~. __..~.~._ ____._., __....__.... ._ __, ._ _...__...... .._..._~__.. _,.._.~_.~.~._..__..__._.._...~___._,...~.__..~._.._____ _ _.' _.n_...' __v __ __...__.. ~__._._ INTEQ çompany: Phillips Alaska; Inc. Date: 2/11/2003 Time: 10:52:53 Page: 2 Field: KuparukRiverUnit. Co':ordinate(NE)Reference: Well.: tC-15, True North Site: KRU1C Pad Vertical (TVD) Reference: ßystern: Mean. Sea Level· Well: 1 C-15 Section (VS) Reference: VVell(0.OON,O.00E,307.00Azi) .~ell~~!~~_.~~~#4._~-1 ·~~L____.___._._.___.__..__._..___._.___._____._~urvey Cal~ula.!!.~~..~.~~.od: Minimu!T'···~u~~~.._____._ D~.:.__~yba_~_~____ Plan: Plan #4 New TO target T 4.4 Principal: Yes ----~-_.-_._--_.._,-------- Plan Section Information ------..-.--..-----.,---------.-- Date Composed: Version: Tied-to: .----.-.,...-....--.-'.------.-..----.--.------.-.-.--_.--.._---_.-- 2/11/2003 4 From: Definitive Path -----.---- --."'.----.-.-----"..-,.".,.--.....-"...-..--.,....,.-..--....---------..-- _..___._.~_.__'_.'L_..._._..~._.....~__.._..__. MD Incl Azim TVD +N/-S +E/-W DLS Build TiJrn TFO. Target ft . deg deg ft ft ft deg/100ft deg/1 OOft· deg/1 OQ.ft deg .....___.__._~.__.........___._..._._.__...._.~_____...'___'___"'_'~'_'_'__'_'_____'____"_'_'___'___"H_'""~'_'_'__""_""."""'_."_~'_'__"_"_'_'____"___.._.__..._.._'._H_..~..._........_...H__~.._._~_.___._.__.._._...._..____.....~_..__..__..._...__._._.__...._.___._. 9120.00 25.80 70.18 6495.77 1936.79 5576.54 0.00 0.00 0.00 0.00 9180.00 25.98 69.92 6549.75 1945.73 5601.17 0.35 0.30 -0.43 327.64 9194.00 29.56 60.65 6562.14 1948.48 5607.06 40.00 25.58 -66.19 305.50 9365.89 90.00 10.00 6648.50 2070.25 5667.00 41.75 35.16 -29.47 305.49 9430.89 90.00 342.86 6648.50 2134.52 5662.99 41.75 0.00 -41.75 -90.00 9480.89 90.00 336.86 6648.50 2181.44 5645.78 12.00 0.00 -12.00 -90.00 9551.73 96.00 330.83 6644.79 2244.89 5614.64 12.00 8.47 -8.52 -45.00 10051.73 94.72 270.55 6593.28 2486.92 5206.30 12.00 -0.26 -12.06 -88.00 10366.73 96.79 308.49 6560.49 2589.52 4916.34 12.00 0.66 12.05 85.00 10461.73 104.76 300.18 6542.71 2642.15 4839.47 12.00 8.38 -8.75 -45.00 10596.73 95.16 286.92 6519.29 2694.88 4717.91 12.00 -7.11 -9.83 -125.00 10721.73 94.18 271.90 6509.06 2715.18 4595.36 12.00 -0.78 -12.01 -93.10 11250.00 91.87 335.35 6477.95 2992.77 4178.58 12.00 -0.44 12.01 90.00 Survey MO ft 9120.00 9125.00 9145.81 9150.00 9175.00 9180.00 9191.54 9194.00 9200.00 9225.00 9250.00 9275.00 9300.00 9325.00 9350.00 9365.89 9375.00 9400.00 9425.00 9430.89 9450.00 9475.00 9480.89 9500.00 9525.00 9550.00 9551.73 9575.00 9600.00 9625.00 9650.00 9675.00 9700.00 9725.00 9750.00 -----..-----....-----.--..---...-.,--------....,...-..---.-..--,--..--.,.--.-....--".------------..--.-----...--.-,-,.".-....--.... _..._..,_....._----,-~"-_._,._,...,-_.'--_.,-_....._.,,..-.--...-...------...-,-------.-----..---,.----.---...-.--..--... [nel deg - --. .. --.- 25.80 25.81 25.88 25.89 25.96 25.98 28.89 29.56 31.08 38.41 46.79 55.72 64.97 74.40 83.93 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 91.62 93.74 95.85 96.00 96.09 96.17 96.23 96.28 96.31 96.32 96.32 96.29 Azim deg 70.18 70.16 70.07 70.05 69.94 69.92 62.12 60.65 56.70 43.58 34.33 27.39 21.82 17.03 12.68 10.00 6.20 355.76 345.32 342.86 340.57 337.57 336.86 335.24 333.11 330.98 330.83 328.02 325.01 321.99 318.97 315.95 312.94 309.92 306.90 SSTVD ft 6495.77 6500.27 6519.00 6522.77 6545.26 . ... -.- - . - -- - .. -. -. -- .- -- ---'-" .---.---.,---.--.--- N/S E/W MapN MapE VS DLS ft ft ft ft ft deg/100ft - ._________ .._____~_. _.,.__ ._.__., ...__ ___ _.. ______ .~____ ____._~__,__ _--__-0- __'n' 1936.79 5576.54 5970587.79 567806.95 -3288.04 0.00 1937.53 5578.59 5970588.55 567808.99 -3289.23 0.35 1940.61 5587.12 5970591.70 567817.50 -3294.18 0.35 1941.24 5588.84 5970592.34 567819.21 -3295.18 0.35 1944.98 5599.11 5970596.17 567829.45 -3301.13 0.35 TIP MWD 1C-15L 1 MWD MWD 6549.75 6560.00 6562.14 6567.32 6587.88 6606.28 6621.93 6634.29 6642.96 6647.66 6648.50 6648.50 6648.50 6648.50 6648.50 6648.50 6648.50 6648.50 6648.23 6647.06 6644.97 6644.79 6642.34 6639.67 6636.97 6634.24 6631.50 6628.75 6625.99 6623.25 1945.73 1947.90 1948.48 1950.05 1959.25 1972.43 1989.17 2008.91 2031.00 2054.70 2070.25 2079.27 2104.23 2128.86 2134.52 2152.67 2176.01 2181.44 2198.91 2221.38 2243.39 2244.89 2264.81 2285.54 2305.52 2324.68 2342.99 2360.39 2376.83 2392.26 5601.17 5606.01 5607.06 5609.65 5620.43 5630.95 5640.87 5649.85 5657.61 5663.88 5667.00 5668.28 5668.71 5664.60 5662.99 5656.99 5648.06 5645.78 5638.03 5627.15 5615.48 5614.64 5602.87 5589.16 5574.38 5558.56 5541.77 5524.03 5505.40 5485.93 5970596.93 5970599.15 5970599.73 5970601.33 5970610.61 5970623.88 5970640.70 5970660.51 5970682.66 5970706.41 5970721.99 5970731.02 5970755.98 5970780.57 5970786.22 5970804.31 5970827.58 5970832.99 5970850.38 5970872.77 5970894.67 5970896.17 5970915.99 5970936.60 5970956.45 5970975.49 5970993.65 5971010.90 5971027.18 5971042.46 567831.50 567836.33 567837.37 567839.94 567850.64 567861.06 567870.83 567879.66 567887.23 567893.30 567896.29 567897.50 567897.72 567893.41 567891.75 567885.60 567876.48 567874.16 567866.26 567855.20 567843.34 567842.49 567830.56 567816.67 567801.73 567785.76 567768.81 567750.93 567732.17 567712.57 -3302.32 0.35 -3304.88 ~O.OO -3305.38 /40.00 -3306.49 41.75 -3309.57 41.75 -3310.04 -3307.88 -3303.18 -3296.08 -3286.83 -3279.96 -3275.55 -3260.87 -3242.78 -3238.08 -3222.37 -3201.19 -3196.10 -3179.39 -3157.18 -3134.62 -3133.04 -3111.65 -3088.23 -3064.40 -3040.24 -3015.80 -2991.17 -2966.40 -2941.56 41.75 41.75 41.75 41.75 41.75 41.75 41.75 41.75 41.75 41.75 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 ~,,_,__.________._._ ...__,.....__________________·....'.n ___.,__.__.____,__._.__.. ___ ,___.'''.._ _._....________..____.______.,__ _..""________..__.__....____ ___,,_,__,~.__.___,___ .._~._,_ _,.____~._______ ._._ ,.__ TFO deg 0.00 327.64 327.66 327.74 327.76 Tool - -- ---... - -.- 327.86 KOP 305.50 1C-15A T 312.42 3 305.49 MWD 308.91 MWD 319.72 MWD 326.56 MWD 330.92 MWD 333.69 MWD 335.35 MWD 336.18 4 270.00 MWD 270.00 MWD 270.00 MWD 270.00 5 270.00 MWD 270.00 MWD 270.00 6 315.00 MWD 314.98 MWD 314.88 MWD 314.70 7 272.00 MWD 271.70 MWD 271.38 MWD 271.06 MWD 270.73 MWD 270.40 MWD 270.06 MWD 269.73 MWD -~ -~---------~ ') BP .. ) 8A HUGIIIS Baker Hughes INTEQ Planning Report M, ",·wy,y·.···.~... U,,'''^w.w.u'^.......v^JM.v INTEQ [....--.---............ ...-- _..--- .~.. -.-:....-- .....-_.. .......- - ... .--.-. .. .. ~. '__"". ,...._.._ ._h.~...._·_..··h..~ .n ~.__..__..____._.___ _.._._.n._.____._..._¥__,,_......_.__......__._._.____._...·..____._. _.._.__._.. m..._....._.._..._..___ ...... ..-.~.-_.,..",." -.-- ".._.........._.._--~- ..--.---.... -.... ...... --'--" -~~. '.. Company: Phillips Alaska, Inc; Date: 2/11/2003 Time: .10:52:53 Page: 3 Field: Kuparqk River Unit Co~rdinate(NE) Reference: Well: 1 C-15, True North I Site: KRU1C Pad Vertical (TVD) Reference: System: Mean Sea Level WeJl: 10-15 Section (VS) Referencë: Well (O.00N,O.00E,307.00Azi) Wellpath: Plan#41C-15L 1 Survey Calculation Method: Minimum Curvature Db: Sybase __.~_______.~.__~_____._..__~____~__~________.~__.__...____________.._.__.~___.__.__w_.__~__~__ ----_._-----_.._---~------_..._-_._-_..._--_._._~- Survey ,...__.._____.____....,.___.__..___...__.._._._...___.___........__.._....."_....__.__._._.__,,___..._,,~__..__,,.__.._..~._._...'__,_.~_.....·.··_·_·._._.._.___,__·.·_··........·M_.__·...._·__..__.._...__.___._,_,__,_____.,._._.~_._..._._..._,._..._._.....__.....__...._._"_......,,~,_._.._._.._..._..._.,,..._.__................._...~_ MD Incl Azim SSTVD N/S E/W . MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/100ft deg .....---...-......-..- .._......~........ ............-...-..-....-.....-..............-..---.......,...-.._........~ .............._.._._._...._...___._......_._n...._..._._._...._.........._._.m...._..........._.._...._...._.n.._..._.._...._._.............._....._ .... ._..__n_._m....._......._.._m.._..___......_....~_._......_.._.............._._......_._.._....._......_...__.._._._....._._.m.__............__.. 9775.00 96.25 303.88 6620.52 2406.65 5465.67 5971056.68 567692.20 -2916.72 12.00 269.40 MWD 9800.00 96.20 300.86 6617.80 2419.96 5444.69 5971069.81 567671.11 -2891.95 12.00 269.07 MWD 9825.00 96.12 297.85 6615.12 2432.14 5423.02 5971081.81 567649.35 -2867.32 12.00 268.74 MWD 9850.00 96.03 294.83 6612.47 2443.17 5400.75 5971092.65 567626.98 -2842.89 12.00 268.42 MWD 9875.00 95.92 291.82 6609.87 2453.02 5377.92 5971102.30 567604.07 -2818.74 12.00 268.10 MWD 9900.00 95.80 288.80 6607.31 2461.65 5354.60 5971110.74 567580.69 -2794.92 12.00 267.79 MWD 9925.00 95.66 285.79 6604.82 2469.04 5330.85 5971117.94 567556.88 -2771.50 12.00 267.48 MWD 9950.00 95.51 282.78 6602.38 2475.18 5306.74 5971123.88 567532.72 -2748.55 12.00 267.18 MWD 9975.00 95.33 279.77 6600.02 2480.05 5282.34 5971128.54 567508.28 -2726.13 12.00 266.88 MWD 10000.00 95.15 276.77 6597.74 2483.63 5257.70 5971131.92 567483.62 -2704.30 12.00 266.60 MWD 10025.00 94.95 273.76 6595.54 2485.91 5232.91 5971133.99 567458.81 -2683.13 12.00 266.32 MWD 10050.00 94.74 270.76 6593.43 2486.90 5208.02 5971134.77 567433.92 -2662.66 12.00 266.06 MWD 10051.73 94.72 270.55 6593.28 2486.92 5206.30 5971134.78 567432.19 -2661.27 12.00 265.81 8 10075.00 94.96 273.34 6591.32 2487.70 5183.13 5971135.37 567409.02 -2642.29 12.00 85.00 MWD 10100.00 95.20 276.34 6589.10 2489.81 5158.32 5971137.27 567384.19 -2621.21 12.00 85.24 MWD 10125.00 95.43 279.35 6586.79 2493.20 5133.66 5971140.46 567359.51 -2599.48 12.00 85.50 MWD 10150.00 95.64 282.36 6584.37 2497.89 5109.22 5971144.94 567335.04 -2577.14 12.00 85.78 MWD 10175.00 95.84 285.36 6581.87 2503.85 5085.08 5971150.70 567310.85 -2554.27 12.00 86.07 MWD 10200.00 96.02 288.37 6579.29 2511.06 5061.28 5971157.72 567287.00 -2530.93 12.00 86.37 MWD 10225.00 96.19 291.39 6576.63 2519.51 5037.91 5971165.97 567263.56 -2507.17 12.00 86.68 MWD 10250.00 96.34 294.40 6573.90 2529.18 5015.02 5971175.45 567240.59 -2483.07 12.00 87.00 MWD 10275.00 96.47 297.42 6571.11 2540.03 4992.67 5971186.12 567218.16 -2458.70 12.00 87.33 MWD 10300.00 96.58 300.44 6568.27 2552.05 4970.94 5971197.95 567196.32 -2434.11 12.00 87.67 MWD 10325.00 96.68 303.45 6565.39 2565.18 4949.87 5971210.91 567175.15 -2409.37 12.00 88.01 MWD 10350.00 96.75 306.47 6562.46 2579.41 4929.52 5971224.96 567154.69 -2384.56 12.00 88.36 MWD 10366.73 96.79 308.49 6560.49 2589.52 4916.34 5971234.96 567141.42 -2367.95 12.00 88.71 9 10375.00 97.49 307.79 6559.46 2594.59 4909.89 5971239.98 567134.93 -2359.75 12.00 315.00 MWD 10400.00 99.61 305.63 6555.74 2609.37 4890.07 5971254.59 567114.99 -2335.03 12.00 314.91 MWD 10425.00 101.71 303.45 6551.12 2623.30 4869.84 5971268.35 567094.65 -2310.49 12.00 314.59 MWD 10450.00 103.79 301.24 6545.60 2636.34 4849.24 5971281.22 567073.94 -2286.19 12.00 314.19 MWD 10461.73 104.76 300.18 6542.71 2642.15 4839.47 5971286.94 567064.12 -2274.89 12.00 313.70 10 10475.00 103.84 298.84 6539.43 2648.48 4828.28 5971293.18 567052.88 -2262.14 12.00 235.00 MWD 10500.00 102.09 296.34 6533.82 2659.76 4806.69 5971304.28 567031.20 -2238.11 12.00 234.67 MWD 10525.00 100.32 293.87 6528.96 2670.16 4784.48 5971314.50 567008.91 -2214.11 12.00 234.11 MWD 10550.00 98.54 291.43 6524.87 2679.66 4761.72 5971323.80 566986.08 -2190.22 12.00 233.63 MWD 10575.00 96.73 289.01 6521.55 2688.22 4738.47 5971332.17 566962.76 -2166.50 12.00 233.23 MWD 10596.73 95.16 286.92 6519.29 2694.88 4717.91 5971338.66 566942.15 -2146.07 12.00 232.90 11 10600.00 95.14 286.53 6519.00 2695.82 4714.80 5971339.58 566939.02 -2143.02 12.00 266.90 MWD 10625.00 94.96 283.52 6516.80 2702.27 4690.75 5971345.83 566914.92 -2119.93 12.00 266.86 MWD 10650.00 94.78 280.51 6514.68 2707.46 4666.39 5971350.81 566890.52 -2097.35 12.00 266.60 MWD 10675.00 94.58 277.51 6512.64 2711.36 4641.78 5971354.51 566865.89 -2075.35 12.00 266.34 MWD 10700.00 94.37 274.51 6510.68 2713.97 4617.00 5971356.91 566841.09 -2053.99 12.00 266.10 MWD 10721.73 94.18 271.90 6509.06 2715.18 4595.36 5971357.94 566819.44 -2035.98 12.00 265.87 12 10725.00 94.18 272.29 6508.83 2715.30 4592.10 5971358.04 566816.19 -2033.31 12.00 90.00 MWD 10750.00 94.17 275.30 6507.00 2716.95 4567.23 5971359.48 566791.30 -2012.45 12.00 90.03 MWD 10775.00 94.15 278.31 6505.19 2719.91 4542.4 7 5971362.23 566766.52 -1990.90 12.00 90.25 MWD 10800.00 94.12 281.32 6503.39 2724.16 4517.91 5971366.27 566741.92 -1968.72 12.00 90.47 MWD 10825.00 94.08 284.32 6501.60 2729.69 4493.59 5971371.61 566717.57 -1945.98 12.00 90.68 MWD 10850.00 94.03 287.33 6499.83 2736.49 4469.60 5971378.21 566693.53 -1922.72 12.00 90.90 MWD 10875.00 93.97 290.34 6498.09 2744.54 4446.00 5971386.06 566669.86 -1899.03 12.00 91.11 MWD 10900.00 93.89 293.34 6496.37 2753.82 4422.86 5971395.15 566646.64 -1874.96 12.00 91.32 MWD 10925.00 93.81 296.35 6494.69 2764.30 4400.22 5971405.44 566623.92 -1850.58 12.00 91.53 MWD -----.--_._--. ....-. -.-.-- - --..-.----.. ,,-_..------ --.- -.------,--.. _._- -.-.--,,-,,--.-- ..--..--------- - _.___..____. u_ ......... I-·-·-···-·_··-·:·---.·~·--·-····-'-···-"·"-·-_·:··_~·""'-'-,-"~._''''-----'- . Company: Phillips Alaska, Inc, Field: . Kuparuk River Unit Site: KRU 1 C Pad Well: 1C-15 Wellpath: Plan#41C:"15L 1 ---------- Survey _...__.~---_.._.~_.__._~-..--_...._._._.._...,._-_..,--,,-.....-----,,-...-..- 'MD Incl . Azim ft deg deg ...._.~.____......._.._.__...h~.. .._~_.__..h...._._...__ .. ......--...-.-..-......¥- 10950.00 93.71 299.36 10975.00 93.60 302.36 11000.00 93.49 305.36 11025.00 93.36 308.37 11050.00 93.23 311.37 11075.00 93.09 314.37 11100.00 92.93 317.37 11125.00 92.77 320.37 11150.00 92.61 323.37 11175.00 92.43 326.37 11200.00 92.25 329.36 11225.00 92.06 332.36 11250.00 91.87 335.35 ) BP ) Baker Hughes INTEQ Planning Report .....^ V·" "'..y·.wn"""...'·w,.......,..".,,,,,,,.."" INTEQ ...n_....'_,.._...~~..~__.~_.., ._..._,..._..__,,,_~_.._~,..~_._..__.__.._..__..._ ._.._.....~_."_..___.._.__.._._,,.,..__...._.._.__.._.___m__.~ .._..~.v_.__."_".__,_.._.. . '___~_"~'¥","_._~.~,,,,..,_,,.~._.,,. '__.~_M.._"_~.'_._._"'_.____._.._._...._... ._._.___... . .. . Date:. 2/11/2003 Time: 10:52:53 Page: 4 Co,..ordinate(NE) Reference: Well:.1 C-15; True North Vertical (TVD) Reference: . System: Mean Sea Level Section(VS) Reference: Well (O.OON,0.OOE,307.00Azi) SurveyCalculatiön Method: Minimum Curvature . Db: Sybase --~_._-~--_._----~-.--- ._-~-------- --.,.---.....-.---.-- ......~.._-_._---.~.._---...-....._._--_..-.-"_.._-_.._---~.._-..__..__.. ..-..---...-..-.-.--.-....-----..-----,-,--.--.--.--,....-.--.- SSTVD N/S E/W MapN MapE VS DLS TFO Tool ft ft ft ft ft ft deg/100ft .deg ._.__n_~_._..._h_.._._._ .._."_·_........_...~......_,_··_.·_.........m......_.__·_·..·..__·.~·____........___.__..._. ..._.__....-........-..........._...._. ......-...---.-...........-...- ~--....._.__...-.._._...-.-._._.~_._......__.._...---_.._-...-.-....-.--........-..---....--....-.........-.......-..-.--~---~ 6493.06 2775.95 4378.17 5971416.91 566601.78 -1825.95 12.00 91.73 MWD 6491.46 2788.75 4356.76 5971429.52 566580.26 -1801.15 12.00 91.93 MWD 6489.91 2802.65 4336.04 5971443.25 566559.43 -1776.24 12.00 92.12 MWD 6488.42 6486.98 6485.61 6484.29 6483.05 2817.62 4316.07 5971458.05 566539.34 -1751.29 12.00 92.30 MWD 2833.62 4296.92 5971473.89 566520.06 -1726.36 12.00 92.48 MWD 2850.60 4278.63 5971490.71 566501.63 -1701.53 12.00 92.65 MWD 2868.51 4261.25 5971508.48 566484.10 -1676.87 12.00 92.82 MWD 2887.32 4244.82 5971527.15 566467.52 -1652.44 12.00 92.98 MWD 2906.96 4229.40 5971546.66 566451.94 -1628.30 12.00 93.13 MWD 2927.38 -4215.03 5971566.96 566437.40 -1604.53 12.00 93.27 MWD 2948.53 4201.75 5971588.00 566423.94 -1581. 19 12.00 93.40 MWD 2970.35 4189.58 5971609.71 566411.60 -1558.35 12.00 93.52 MWD 2992.77 4178.58 5971632.04 566400.41 -1536.06 12.00 93.63 TD ---------------------- 6481.87 6480.77 6479.75 6478.81 6477.95 --_..-------_._------~--_._----_.._,-------_.__._--_.------- ) BOP-Tree Well I l UIIII ~ I rl I I Rig Floor I I rU'¥riA,ti:îuiä1" J [7 1116' 5000 pSI BOP's 10 = 706" srtncfshËia~ ' ror : ~.~. ~: III 1'/4 Tum LT Valve ~ 2 "Combi 1 , . -JOT. .. I I I 7~/1€'5000PSlRX-4e II~~~X~" I Ki'~in~I11I~ ~ · 11~~~~~r 121/16~ 5000 psi RX·24 ~ I .. JQ'f I.; . {""ï'~'c¡;mtit"'l ~ . . ~ to"{ : 17, 1/16": 5.Q()P þsi. (f\)(h46) .()r I ..J ~ 41/16" $()()Opsl(~~39) ~-':\ .. ~ I . (':~;~I\I\~I\ "~)" ; I-".'I~IIII'I ~~- · FIowT6fI:~ Y '.' . "f" . ~ : f:' .:.' .' .<~ ,:' }; . I f10w line 1 r.l-' ·l";·..· :l~'- t"~~ ·:~O·· . "::. :;.,; lC~ ·ð :~~:::t~ ft~~fu1~~~~ l···"i;·:::··(·þ···············~ r::;'~:: ~~: ~~~~, ~ :'," 1 ~·,{:<~~~~;~\-IlOJ'_· , . . '." . : .~~ .~;~;t-"'~,. . ~.;...j .. ~§ :*~~1-:s;.,\~~~1-:~ ~. ... . ~ ~"~"~=-'i'(,""$. ...~.~~~t~,,, : I. Base Flan~e I i:iÌ¡1r" lð"'~"'^^ . " ." ~ C\l\J\J :pSt .: I, I I, ~ 1 ]-tHCR ' ..... L-J I. t 1 . I I I ~ - ::¡:::¡¡\! I ... .:::;:;::: I 11( Cho.ke. Une '/ I [ I /i I I Tree Size I I I I Page 1 ) KB Elevation ~ I lubrk.~.ator 10 c 6375' wiih 6" Otìs Uníans (,:' 1/16" 5000 ~ISI. R):-46 I Swab Valve I ssv I Master Valve I - ~ Deçemþerf19,4P02<' *t1t***1,i~*~***.*$1 00.00*** NQT1'".Yf.Llfa A J ~:S:.:~~~¡:;:~"'··"'·!f1 ;;" i~>c[+7{~::~:;;~~~¡~;~~~,t·1~ AMOUNT No.P 055002 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 41'2 H NET VENDOR DISCOUNT P055002 12/19/2002 CHECK NO. DATE II' 0 5 5 0 0 2 II' I: 0... ~ 2 0 ~ a '1 5 I: 0 ~ 2 ? a ~ b IIa ALASKA OIL & GAS CONSERVATIQN 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK99501 TO THE ORDER OF: DATE' /..ß<.'....;fJ t:..'.............."'... 'I' .....~....... .. .. r. - ~~d..'1" PAY: BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK 99519-6612 NATIONAL CITY BANK Ashland', Qhio TOTAL ~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. ~ . k n', & c,- . ,"'"., ",... ,,_'...,,; _. .__ 1-\la8 'a uJI c:cUi, Li;i/S, 00i¡HH1::i;;;iUJ¡ A,nCn0;~¡ge "'" ¡"¡--'¡-, " '. {''In '7 ¡--ï- '" ,'\ ¿ '.", , .-., ,.' --- oj _. JU'J Q E (. C , \f !: ~D ß \ <,", L ~ 11 ~.,; ä ,e,\'SL\ PERMIT TO DRILL FEE 12/19/2002 INV# CK121702K GROSS DESCRIPTION INVOICE I CREDIT MEMO DATE P055002 '') ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARA GRAPH S TO BE INCLUDED IN TRANSMITTAL LETTER WELLNAMEÆq /r:-'.Iç/ / PTD# 7~..? - ð ð 2.- CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL v (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new well bore segment of existing well!)! q, I Co - J 5 Permit Nolt¡q.?~ lAPI No. So-oz9-.2..2.#!f J.2...- Production should continue to be reported as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/1 0/02 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. (Companv 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. (Service Well Only) GEOLOGY APPR DATE ~¿~? (Exploratory Only) WELL PERMIT CHECKLIST COMPAN~". _¡i,J/;~ELL NAME~4' / r:. -I ~ ¿ / PROGRAM: Exp _ Dev X Redrll _ Re-Enter _ Serv _ Well bore seg K FIELD & POOL ~ 1ít>/~^ INIT CLASS .A-o~.... / -0,// GEOL AREA 'íf?,-,a UNIT# /II?;'} ON/OFF SHORE CJ-tJ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . p, N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N A::J, ~ ¿ __~.., 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N ~ ~Ä.J 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . \\f) N (Service Well Only) 13. Well located w/in area & strata authorized by injection order #_ ~.Y /UrA ~ (Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . . . .. 7 ~ ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . ¥---N- 16. Surface casing protects all known USDWs. . . . . . . . . . Y-N- A i {1- 17. CMT vol adequate to circulate on conductor & surf csg. . . . -¥-N- ,.... I{ . 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . - ¥ N - ..J. . 19. CMT will cover all known productive horizons. . . . . . . . . . ~ N - ~t£n. uJ . 20. Casing designs adequate for C, T, B & permafrost. . . . . . . N S ,... L 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . . : N l/T LA- L 22. If a re-drill, has a 10-403 for abandonment been approved. .. ~' AI/A-. . L-OV-l "Wtv{ 23. Adequate wellbore separation proposed.. . . . . . . . . . . . N 24. If diverter required, does it meet regulations. . . . . . . . . . - rJ./k i\ 1 j 25. Drilling fluid program schematic & equip list adequate. . . . . (j2 N /tltt.¢" Mlt-i g. 7 ppc.;. !) ~tirlL/lt..a C {)4U Oa.{4,¿1...Û . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . t1Z N P \ APPR DATE 27. BOPE press rating appropriate; test to '!boo psig. ~ N fJ1"Ç. 3'%'0 p~¡' ([.J pfJtj..J /. L J J 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . ~ VJ~ z.. z..lR /0 ~ 29. Work will occur without operation shutdown. . . . . . . . . . . ,N 30. Is presence ofH2S gas probable.. . . . . . . . . . . . . . . . N 31. Mechanical condition of wells within AOR verified. . . . . . . . . All,+-- v::JJ ~J'l'q ~( APPR DATE { 32. Permit can be issued wlo hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . .. ...... 36. Contact namelphone for weekly progress reports. ...... ( GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: Commentsllnstructions: RP¿ TM JH JR SP RR /' MW DS O~, 2.7; 0.3 SFD_ WA Rev: 2/25/03 \well_perm it_checklist ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to sim,plify finding infonnation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~03 --Ô0~ ) ') **** REEL HEADER **** MWD 04/02/08 ~U¡D~ f, . BHI 01 LIS Customer Format Tape 462024 01 RECEIVED FEB 1 0 2004 Alaska Oil & Gas Cons. Commission Anchorage **** TAPE HEADER **** MWD 04/02/03 2.375" CTK *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ~Version Information VERSo WRAP. ~Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 9111.0000: STOP.FT 11207.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NUMBER: ~Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 12 TOWN.N 11N RANG. 10E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 101.5 DMF KB EKB .F 101.5 EDF .F N/A EGL .F 0.0 Remark File Version 1.000 Extract File: ldwg.las 1.20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value ConocoPhillips Alaska, Inc. 1C-15L1 Kuparuk River Unit 70 deg 19' 29.107" N 149 deg 29' 42.918" W North Slope Alaska Baker Hughes INTEQ 2.375" CTK 10-Apr-03 500292293260 Description ------------------------------- Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level ~ --....:. " ~~ f\\ \~ ) ') 9142 DIRECTIONAL PRESSTEQ I Casing Depth Other Services Line 1 Other Services Line 2 CASE.F OSl . OS2 . -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data presented is Realtime data. (4) Well 1C-15L1 was kicked off as a sidetrack to well 1C-15 at 9142' MD (6616' SSTVD) . (5) Baker Hughes Inteq utilized CoilTrak downhole tools and ADVANTAGE surface system. (6) Tools ran in the string included CCL, Electrical Disconnect and Circulating sub, a Drilling Performance Sub (inner and outer downhole pressure, downhole weight on bit, downhole temperature), a Gamma and Directional Sub, and an Orienting Sub with a near bit inclination sensor. (7) The data presented here is final. A block shift was done to match a tie-in point on the PDC curve at 9150' MD. This approach was used ,due to the limited overlap with the PDC curve (SWS). (8) The interval from 11179' MD (6531' SSTVD) to 11207' MD (6528' SSTVD) was not logged due to sensor bit offset at TD. MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-AAPI units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth (SSTVD), feet SENSOR RUN 2 3 4 5 6 7 8 OFFSETS: GAMMA 30.47 ft. 30.20 ft. 27.85 ft. 27.83 ft. 27.83 ft. 27.83 ft. 27.83 ft. DIRECTIONAL 31.32 ft. 31. 05 ft. 28.70 ft. 28.68 ft. 28.70 ft. 28.70 ft. 28.70 ft. CURVE SHIFT DATA OBSERVED, ACTUAL, 9149.6, 9149.19, EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 DISPLACEMENT -0.415039 75 records... 10 bytes 132 bytes *** INFORMATION TABLE: CONS MNEM VALU ) ') ------------------------------------ WDFN LCC CN WN FN COUN STAT mwd.xtf 150 ConocoPhillips (Alaska) Inc. 1C-15L1 Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** ! !! !! ! ! !! !! ! ! !! !! !! Remark File Version 1.000 The data presented here is final. A block shift was done to match a tie-in point on the PDC curve at 9150 MD. This approach was used due to the limited overlap with the PDC curve (SWS). *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP GR ROP GRAX ROPS 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 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: 84 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 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 ------- 8 Total Data Records: 50 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 9111. 000000 11207.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 59 records... ') Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT raw.xtf 150 ConocoPhillips (Alaska) lC-15Ll Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!! !! !!!!!!!! !!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CRAN DIMT CNAM ODEP ---------------------------------------------------- GRAX ROPS GRAX ROPS GRAX ROPS 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 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: 84 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 2 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 2 68 ROPS MWD Total Data Records: Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units **** FILE TRAILER **** ) 1 F/HR 100 9110.500000 11206.500000 0.250000 feet Tape Subfile: 3 109 records... Minimum record length: Maximum record length: **** TAPE TRAILER **** MWD 04/02/03 462024 01 **** REEL TRAILER **** MWD 04/02/08 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: 54 bytes 4124 bytes 2 records... 132 bytes 132 bytes 4 ------- ) 4 8 ) ) Tape Subfile 1 is type: LIS ) ) Tape Subfile 2 is type: LIS DEPTH GR ROP 9111.0000 39.7423 -999.2500 9111. 5000 41. 9422 -999.2500 9200.0000 143.9361 39.2469 9300.0000 118.5332 16.9628 9400.0000 124.2171 11.0373 9500.0000 104.2055 54.7538 9600.0000 134.1715 34.2494 9700.0000 130.5844 45.2727 9800.0000 142.6756 78.0355 9900.0000 154.9139 74.6752 10000.0000 127.0427 34.4701 10100.0000 119.3377 35.5841 10200.0000 134.4869 82.5989 10300.0000 134.0630 64.0309 10400.0000 114.2771 67.8589 10500.0000 96.4145 108.8344 10600.0000 66.1687 88.6134 10700.0000 57.8707 101.0108 10800.0000 70.1334 80.0754 10900.0000 68.9639 70.7898 11000.0000 62.4232 51.3163 11100.0000 75.8849 27.9555 11200.0000 -999.2500 31. 4728 11207.0000 -999.2500 -999.2500 Tape File Start Depth 9111. 000000 Tape File End Depth 11207.000000 Tape File Level Spacing 0.500000 Tape File Depth Units feet " " ) ) Tape Subfile 3 is type: LIS DEPTH GRAX ROPS 9110.5000 -999.2500 -999.2500 9110.7500 -999.2500 -999.2500 9200.0000 140.9900 36.7300 9300.0000 114.7100 16.8000 9400.0000 122.9600 9.5500 9500.0000 109.1500 56.6400 9600.0000 131. 0300 33.2800 9700.0000 131. 4900 44.7000 9800.0000 138.1400 79.1600 9900.0000 143.5300 75.1200 10000.0000 130.0300 27.8500 10100.0000 117.7200 60.3200 10200.0000 129.8900 83.2700 10300.0000 132.5500 64.1000 10400.0000 110.9300 68.0500 10500.0000 96.6600 109.2800 10600.0000 71.0900 88.6400 10700.0000 58.7300 102.3500 10800.0000 -999.2500 81.7600 10900.0000 71.1700 89.7800 11000.0000 61. 5000 48.4300 11100.0000 78.1100 30.8700 11200.0000 -999.2500 27.3500 11206.5000 -999.2500 32.6000 Tape File Start Depth 9110.500000 Tape File End Depth 11206.500000 Tape File Level Spacing 0.250000 Tape File Depth Units feet ) ) Tape Subfile 4 is type: LIS