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204-212
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: Marcit Conformance Trtmnt 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 13750'feet None feet true vertical 6631' feet None feet Effective Depth measured 13750'feet 10401'feet true vertical 6631' feet 6277' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 10420' MD 6287' TVD Packers and SSSV (type, measured and true vertical depth) 10401' MD N/A 6277' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker SLZXP Liner Top Packer SSSV:None Allen Eschete allen.eschete@conocophillips.com (907) 265-6558Interventions Engineer Slotted Liner: 11157-12491', 12618-12762', 12984-13537' Slotted Liner: 6596-6586', 6590-6594', 6593-6620' 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 115' ~ ~~ INJECTOR ~~ ~ measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-212 50-029-22946-61-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0028243 Kuparuk River Field/ Kuparuk River Oil Pool KRU 1D-11L2 Plugs Junk measured Length Production Liner 10534' 2584' Casing 6362' 2-7/8" 10565' 13550' 6620' 6780' 115'Conductor Surface Intermediate 16" 9-5/8" 80' 6814' 4404' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Kuparuk River Oil Pool By Grace Christianson at 2:59 pm, May 22, 2023 Digitally signed by Allen Eschete DN: CN=Allen Eschete, E=Allen.Eschete@ ConocoPhillips.com Reason: I have reviewed this document Location: Date: 2023.05.22 10:26:06-08'00' Foxit PDF Editor Version: 12.0.1 Allen Eschete DTTMSTART JOBTYP SUMMARYOPS 3/29/2023 SUPPORT OTHER OPERATIONS PULLED 4.5" SLIP STOP & CHOKE @ 541' RKB; BRUSH n' FLUSHED D-NIPPLE @ 11,008' RKB; SET 2.25" CA-2 PLUG @ 11,008' RKB. READY FOR E-LINE IPROF.ttttt 4/1/2023 SUPPORT OTHER OPERATIONS PERFORM INJECTION PROFILE. WELL INJECTING AT 6250 BWPD, 900 PSI. PERFORM UP/DOWN PASS AND VERIFY ALL INJECTION IS GOING INTO LATERAL 2, CONFIRMED PLUG IN LATERAL 1 IS HOLDING (NO INJECTION INTO L1). JOB COMPLETE 4/19/2023 SUPPORT OTHER OPERATIONS Continue rigging up, spotting up equipment. Stage liquid and dry product. Troubleshoot generator issues. Perform safety / operations pre job walk down. Freeze protect 1D-11 flow line and 1D-10 tubing. Fill tank farm tanks with seawater from process line. Flood SNF mixing unit. Calibrate gel mixer, verify skid function. Performed step rate test, start 4000 ppm Marcit non cross linked, SNF skid unable to deliver mixed product at rate to LRS pump. Troubleshoot issue. 200 bbl polymer injected. No cross linker. - In Progress- 4/20/2023 SUPPORT OTHER OPERATIONS Continue to troubleshoot SNF skid mixing issues. Replace automated mixing tank valve, adjust marcit mother solution concentration and dilution pump ratios, trial changes on non cross linked gel, begin to pump stage #1, 4000 ppm Marcit polymer with Chromic Acetate cross linker @ maximum rate, skid performance limited, of 3 bpm. Totals - 3,199 bbls 4k gel stage one, WH 1,225 psi. - In Progress- 4/21/2023 SUPPORT OTHER OPERATIONS Pumped 3,650 bbls, 4k ppm Marcit gel in stage #1. Well head climbed from 1,225 to 1,300 psi, total gel pumped in stage one is 6,849 bbls. Main generator powering NSF skid started shutting down @ 22:00. Trouble shoot and restart multiple times. 1D-28 and 1D-41 floc tests both negative. - In Progress- 4/22/2023 SUPPORT OTHER OPERATIONS Continue to troubleshoot generator with nights field mechanic with no success. Flush and FP X-linked Marcit from surface with 120 bbl's diesel. Request replacement generator. Wrap and heat additional surface lines. Spot replacement generator and stand by for electricians to disconnect / reconnect. Electricians determined replacement generator not compatible with bolt up connections. Stand by for days field mechanic. Mechanic restarted generator, test run for 1 hr, energize NSF skid, test run. On line with 4000 ppm Marcit to establish injection. Pumped remaining 4000 ppm cross linked stage #1 - 7,639 bbls. Start pumping stage two, 5000 ppm Marcit 1D-28 and 1D-41 floc tests both negative. Total stage #2, 2,063 bbls - total vol. treatment 9,701 bbls - In Progress- 4/23/2023 SUPPORT OTHER OPERATIONS Pumped 4,230 bbls, 5k ppm Marcit gel in stage #2. Well head climbed from 1,475 to 1,550 psi. 1D-28 and 1D-41 floc tests both negative. Total stage #2, 6,293 bbls - total vol. treatment 13,931 bbls - In Progress- 4/24/2023 SUPPORT OTHER OPERATIONS Completed stage two, 7,804 bbls 5000 ppm Marcit. Completed stage three, 798 bbls 6000 ppm Marcit. Started stage four, 8000 ppm Marcit. Total stage #4, 1,293 bbls - total vol. treatment 17,534 bbls. Well head built from 1,325 psi to 1,450 psi during stage #4. 1D-28 and 1D-41 floc tests both negative. - In Progress- 4/25/2023 SUPPORT OTHER OPERATIONS Completed stage four, 2,108 bbls total of 8,000 ppm Marcit. Started final stage five, 10,000 ppm Marcit. Total stage #5, 1,205 bbls - total vol. treatment 19,553 bbls. Well head built from 1,500 psi to 1,700 psi during stage #4 & 5. 1D-28 and 1D-41 floc tests both negative. - In Progress- 1D-11 Marcit Treatment 4/26/2023 SUPPORT OTHER OPERATIONS Pumped stage five, 10,000 ppm Marcit to completion. Flushed Marcit with 147 bbls water and 35 bbls diesel FP. Contacted PE to flag well 'do not inject'. FP seawater header flow line on 1D-10 with 10 bbls MetOH. Vac our surface lines, upright tanks and SNF skid. Job complete. Begin rig down of treating equipment. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 10,962.0 1D-11 7/26/2005 n1894 Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled Choke & Set 2.25" CA-2 Plug 1D-11 3/29/2023 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: MULTI-LATERAL WELL: MAIN LEG, PRODUCING THRU 1D-11 PERFS ABOVE L1 & L2 WINDOWS 11/22/2004 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 35.0 115.0 115.0 62.58 H-40 WELDED SURFACE 9 5/8 8.70 34.7 6,814.5 4,403.6 40.00 L-80 BTC PRODUCTION 7 6.28 30.4 10,564.6 6,362.5 26.00 L-80 BTC WINDOW L2 5 1/2 4.00 10,925.0 10,935.0 6,561.6 WINDOW L1 5 1/2 4.00 11,011.0 11,021.0 6,608.8 LINER 4 1/2 3.96 10,401.4 11,234.0 2.00 L-80 IBT Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 28.7 Set Depth 10,420.0 Set Depth 6,287.1 String Ma 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection ABT MOD ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 28.7 28.7 0.11 HANGER 10.850 FMC GENV TUBING HANGER 4.500 541.4 541.1 5.66 NIPPLE 6.062 CAMCO 'DB' NIPPLE 3.813 10,353.0 6,252.3 58.64 GAS LIFT 5.800 CAMCO KBG-2- LS 3.650 10,397.3 6,275.3 58.81 NIPPLE 5.200 OTIS 'X' NIPPLE 3.813 10,406.3 6,280.0 58.78 LOCATOR 5.125 BAKER LOCATOR 3.000 10,407.5 6,280.6 58.78 SEAL ASSY 4.750 BAKER 192-47 CASING SEAL ASSEMBLY 3.875 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) 10,353.0 6,252.3 58.64 1 Gas Lift DMY BTM 1 0.0 7/23/2018 High Seal Packi ng 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) 10,401.4 6,277.4 58.80 PACKER 6.450 BAKER SLZXP LINER TOP PACKER / HANGER / PBR 4.790 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,907.0 10,927.0 6,546.4 6,557.3 C-4, 1D-11 11/19/1999 4.0 IPERF 2 7/8" HC, DP, 180 deg phase, +/- 90 deg, low side 10,960.0 10,980.0 6,575.3 6,586.2 C-4, 1D-11 11/19/1999 4.0 Blocked PERFS blocked by L1 Straddle Assy 11,031.0 11,041.0 6,614.3 6,619.8 C-2, 1D-11 10/10/2004 6.0 Blocked PERFS blocked by L1 Straddle Assy 11,065.0 11,085.0 6,633.1 6,644.2 C-1, 1D-11 10/10/2004 6.0 Blocked PERFS blocked by L1 Straddle Assy 1D-11, 5/16/2023 4:35:35 PM Vertical schematic (actual) LINER; 10,401.4-11,234.0 Blocked; 11,065.0-11,085.0 Blocked; 11,031.0-11,041.0 WINDOW L1; 11,011.0-11,021.0 LINER L1 w/Straddle Assy; 10,953.8-13,037.0 TUBING PLUG; 11,008.0 Blocked; 10,960.0-10,980.0 WINDOW L2; 10,925.0-10,935.0 IPERF; 10,907.0-10,927.0 PRODUCTION; 30.4-10,564.6 NIPPLE; 10,397.3 GAS LIFT; 10,353.0 SURFACE; 34.7-6,814.5 NIPPLE; 541.4 CONDUCTOR; 35.0-115.0 KUP INJ KB-Grd (ft) RR Date 10/26/199 9 Other Elev 1D-11 ... TD Act Btm (ftKB) 11,234.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292294600 Wellbore Status INJ Max Angle & MD Incl (°) 60.48 MD (ftKB) 7,659.28 WELLNAME WELLBORE1D-11 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 10,962.0 1D-11L1 7/26/2005 n1894 Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Replaced DV @ 10,353' RKB 1D-11L1 7/23/2018 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: TRI-LATERAL WELL w/2 CTD LEGS w/SLOTTED LINERS 11/22/2004 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread LINER L1 w/Straddle Assy 2 7/8 2.44 10,953.8 13,037.0 6,640.6 6.50 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) 11,008.0 6,601.6 56.60 TUBING PLUG 2.25" CA-2 Plug (27" OAL) 3/29/2023 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,953.8 6,571.9 56.85 PACKER 3.688 TIW KS-WS PACKER @ TOP OF STRADDLE ASSEMBLY 10953' TO 11023' 2.375 11,008.1 6,601.7 56.60 NIPPLE 3.680 CAMCO 'D' NIPPLE 2.250 11,011.5 6,603.5 56.59 DEPLOY 3.700 BAKER DEPLOYMENT SLEEVE w/GS PROFILE 3.000 11,017.3 6,606.7 56.57 PACKER 3.700 BAKER KB LINER TOP PACKER 2.560 11,023.8 6,610.3 57.34 DEPLOY 3.700 BAKER DEPLOYMENT SUB 3.000 11,029.6 6,613.4 58.53 XO Reducing 3.515 CROSSOVER REDUCING 3.5x2.875" 2.380 13,002.4 6,639.0 86.69 O-RING 2.937 BTT O-RING SUB 1.625 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 11,031.0 13,002.0 6,614.1 6,639.0 C-1, C-2, 1D- 11L1 11/9/2004 8.0 SLOTS Slotted Liner, 90 deg orient 1D-11L1, 5/16/2023 4:35:35 PM Vertical schematic (actual) LINER L1 w/Straddle Assy; 10,953.8-13,037.0 SLOTS; 11,031.0-13,002.0 LINER; 10,401.4-11,234.0 WINDOW L1; 11,011.0-11,021.0 TUBING PLUG; 11,008.0 Blocked; 10,960.0-10,980.0 WINDOW L2; 10,925.0-10,935.0 IPERF; 10,907.0-10,927.0 PRODUCTION; 30.4-10,564.6 NIPPLE; 10,397.3 GAS LIFT; 10,353.0 SURFACE; 34.7-6,814.5 NIPPLE; 541.4 CONDUCTOR; 35.0-115.0 KUP INJ KB-Grd (ft) RR Date 10/26/199 9 Other Elev 1D-11L1 ... TD Act Btm (ftKB) 13,700.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292294660 Wellbore Status INJ Max Angle & MD Incl (°) 97.91 MD (ftKB) 11,784.61 WELLNAME WELLBORE1D-11 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 10,962.0 1D-11L2 7/26/2005 n1894 Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set DH Choke & Slip Stop 1D-11L2 4/6/2022 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: MULTI-LATERAL WELL: MAIN LEG, w/2 CTD LEGS L1 & L2 w/SLOTTED LINERS 11/22/2004 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread LINER L2 2 7/8 2.44 10,965.8 13,550.0 6,620.2 6.50 L-80 STL 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) 10,965.8 6,577.5 61.62 DEPLOY 3.650 BAKER DEPLOYMENT SUB 2.380 13,537.3 6,619.9 88.31 O-RING 2.895 BAKER O-RING SUB 1.625 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 11,157.0 12,491.0 6,595.9 6,585.6 C-3, C-4, 1D- 11L2 11/19/2004 8.0 SLOTS Slotted Liner, 90 deg orient 12,618.0 12,762.0 6,589.6 6,593.6 C-4, 1D-11L2 11/19/2004 8.0 SLOTS Slotted Liner, 90 deg orient 12,984.0 13,537.0 6,592.4 6,619.9 C-4, C-3, 1D- 11L2 11/19/2004 8.0 SLOTS Slotted Liner, 90 deg orient 1D-11L2, 5/16/2023 4:35:36 PM Vertical schematic (actual) LINER L2; 10,965.8-13,550.0 SLOTS; 12,984.0-13,537.0 SLOTS; 12,618.0-12,762.0 SLOTS; 11,157.0-12,491.0 LINER; 10,401.4-11,234.0 WINDOW L2; 10,925.0-10,935.0 IPERF; 10,907.0-10,927.0 PRODUCTION; 30.4-10,564.6 NIPPLE; 10,397.3 GAS LIFT; 10,353.0 SURFACE; 34.7-6,814.5 NIPPLE; 541.4 CONDUCTOR; 35.0-115.0 KUP INJ KB-Grd (ft) RR Date 10/26/199 9 Other Elev 1D-11L2 ... TD Act Btm (ftKB) 13,750.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292294661 Wellbore Status INJ Max Angle & MD Incl (°) 97.40 MD (ftKB) 11,622.83 WELLNAME WELLBORE1D-11 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from n1269@conocophillips.com. Learn why this is important From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Defeated LPP/SSV on CPAI well 1D-11 (PTD#199-072 ) with Laterals L1 and L2 (PTD#s 204-211/212) on 3/7/22 Date:Tuesday, March 8, 2022 5:43:43 PM Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: CPF1 Prod Engr <n1269@conocophillips.com> Sent: Tuesday, March 8, 2022 6:09 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs <n1140@conocophillips.com>; Braun, Michael (Alaska) <Michael.Braun@conocophillips.com>; NSK Optimization Engr <n2046@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; CPF1 Prod Engr <n1269@conocophillips.com>; Martin, Kenneth Lloyd <K.L.Martin@conocophillips.com>; CPF1 DS Operators <n1275@conocophillips.com> Subject: RE: Defeated LPP/SSV on CPAI well 1D-11 (PTD#199-072 ) with Laterals L1 and L2 (PTD#s 204-211/212) on 3/7/22 Jim, The low pressure pilot (LPP) on well 1D-11 (PTD#199-072 ) with laterals 1D-11L1 and 1D-11L2 (PTD#s 204-211/212) was defeated last night (3/8/22 17:50) when returned to injection post- slickline work. The well is currently injecting 3100 BWPD at 300 psi wellhead pressure. The LPP has been tagged and status recorded in the “Facility Defeated Safety Device Log.” The AOGCC will be notified when the LPP function is returned to normal, in accordance with “Administrative Approval No. CO 432D.009.” Please let us know if you have any questions. Thank you, Kenneth Martin for Will Parker CPF1 PRODUCTION ENGINEER OFFICE: (907) 659-7493 Kenneth Lloyd Martin Production Engineering Regional Advisor (907) 659-7525 P STATE OF ALASKA ALA.. ,OIL AND GAS CONSERVATION COMh ION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell �— Marcit Gel p r Plug Perforations r Perforate r Other � Alter Casing �" Pull Tubing Stimulate-Frac Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 204-212 • 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service go-: 50-029-22946-61' 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 28243 , 1D-11L2 ' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool ' 11.Present Well Condition Summary: Total Depth measured 13750 feet Plugs(measured) none true vertical 6631 feet Junk(measured) none Effective Depth measured 13535 feet Packer(measured) 10401 true vertical 6618 feet (true vertical) 6277 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 115 115 SURFACE 6780 9.625 6815 4404 PRODUCTION 10534 7 10565 6363 RECEIVED LINER L2 2584 2.875 13550 6620 NOV 13 2013 Perforation depth: Measured depth: 11157-12491, 12618-12762, 12984-13537 AOGCC True Vertical Depth: 6596-6586,6590-6594,6592-6620 SCANNED JAI, / 2011 Tubing(size,grade,MD,and ND) 4.5, L-80, 10420 MD,6287 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER SLZXP LINER TOP PACKER @ 10401 MD and 6277 ND NIPPLE-CAMCO DB NIPPLE @ 541 MD and 541 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): see attached summary for Marcit Gel operations Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation _ 5000 391 Subsequent to operation 550 775 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service p% Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG P., GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-512 Contact John Braden ta(�,263-4536 Email John.C.Braden@conocophillips.com Printed Nam/ 2.i/ 2._.__Johh Braden Title Staff Drillsite Petroleum Engineer Signature �y Phone:263-4536 Date 'Z tow 13 NOV 2 1 <; 1/19 PI Form 10-404 Revised 10/2012 Submit Original Only KUP INJ • 1 D-11 L2 • ConocoPhillips 08 Well Attributes Max Angle&MD TD Alaska,Inc. Wel!bore API/UWI Field Name Wellbors Status Inc!I°) MD(ftKB) Act Otto(ftKB) tanoorealapa 500292294661 KUPARUK RIVER UNIT INJ 97.40 11,622.83 13,750.0 ••• - Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1D-11L2,10/14/20137:2805AM SSSV:NIPPLE Last WO: f 10/26/1999 VMUCaI achama6c(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 10,962.0 7/26/2005 Rev Reason:SET PLUG IN L1 osborl 10/14/2013 HANGER;28.7� Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth)ftKB) Set Depth(TVD)... WULen(I...Grade Top Thread LINER L2 2 7/8 2.441 10,965.8 13,550.0 6,620.2 6.50 L-80 STL Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Inc!r) Item Des Com (in) 10,965.8 6,577.5 61.62 DEPLOY BAKER DEPLOYMENT SUB 2.380 13,537.3 6,619.9 88.31 0-RING BAKER 0-RING SUB 1.625 Perforations&Slots ---. -- ------ - Shot CONDUCTOR;35.0115.0 • I Dens • Top(TVD) Btm(TVD) (shotsff Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 11,157.0 12,491.0 6,595.9' 6,585.6 C-3,C-4,10- 11/19/2004- 8.0 SLOTS Slotted Liner,90 deg • 11L2 orient NIPPLE;541.4 ill� 12,618.0 12,762.0 6,589.6 6,593.6 C-4,1D-11 L2 11/19/2004 8.0 SLOTS Sr tined Liner,90 deg 12,984.0 13,537.0 6,592.4 6,619.9 C-4,C-3,1D- 11/19/2004 8.0 SLOTS Slotted Liner,90 deg 11L2 orient Notes:General&Safety End Date Annotation 11/22/2004 NOTE:MULTI-LATERAL WELL:MAIN LEG,w/2 CTD LEGS L1 8 L2 w/SLOTTED LINERS 1/8/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 I SURFACE,34.7-6,814.5-• • GAS LIFT;10,3510 `1 NNW NIPPLE;10,3973 say: MON E -.f LOCATOR;10,406.3 SEAL ASSY,10,407.5 //tt dB El PRODUCTION;304-10,564.6- IPERF;10,907.0-10.927.0 LINER;10,401.4-11,2340 WINDOW L2;10,925.0-10,935.0A SLOTS;11,157.0-12.491.0 • • • SLOTS;12,618.0-12,762.0 • SLOTS;12.984.0-13,537.0 LINER L2,10,965.8.13,550.0 1D-11L2 Well Work Summary DATE SUMMARY 6/3/2013 (MISC) IC-POT(PASSED) IC-PPPOT(PASSED)CHARGE IA WITH DIESEL TO 1000 PSI TO ESTABLISH IA/OA DIFFERENTIAL. 10/3/2013 LRS PUMPED 500bb1s WATER&50bbls DIESEL DOWN TUBING & FREEZE PROTECT FLOWLINE W/ 10bbls METH 10/4/2013 RAN 2.30" DRIFT& BRUSH TO D-NIP IN LATERAL 1 @ 11008' RKB, SET 2.25"CA-2 PLUG IN D-NIP IN LATERAL 1 @ 11008' RKB, RAN LEAK DETECT STRING TO CA-2 PLUG, SAW NO FLOW GOING PAST PLUG, IN PROGRESS 10/5/2013 SET 3.81"XX PLUG IN X-NIP @ 10397' RKB, MIT-T @ 2500psi FAILED, EQUALIZE & PULLED 3.81"XX PLUG FROM 10397' RKB, IN PROGRESS 10/6/2013 BRUSH & FLUSH TUBING W/ 130bbls DIESEL& BRUSH W/3.75"GAUGE RING, SET 3.81"XX PLUG IN X-NIP @ 10397' RKB, MIT-T @ 2500psi PASSED, MIT-IA @ 2500psi PASSED, EQUALIZED 3.81"XX PLUG @ 10397' RKB, IN PROGRESS 10/7/2013 PULLED 3.81"XX PLUG FROM X-NIP @ 10397' RKB, JOB COMPLETE 10/18/2013 Continued rigging up. Conducted Pre-job Safety Meeting with CPF1, Wells, Tiorco, ASRC, etc. Performed final rig-up and pump checks. Shut-in 1D-10 and 1D-11. Freeze protect flowline for 1D-11 and production tubing for 1D-10. Proceeded with Step-Rate Injectivity System Testing with 1D-10 lined up over to 1D-11. 10/19/2013 Completed Step-rate Injectivity Test: 1875-bwpd @ 392-psi; 2680-bwpd @ 387-psi; 3750- bwpd @ 391-psi; and 5000-bwpd @ 391-psi. Extended injection while waiting on new high- pressure flow meter for the injection line. 10/20/2013 Attempted to repair/replace high pressure flow meters. Shut in injection and freeze protected 1D-11 tubing and 1D-10 flowline. 10/21/2013 Repaired high-pressure flow meter and re-rigged treating iron. Pressure tested system 4000- psi. Began injecting produced water 3450-bwpd. After two tubing-volume flush, came online with Tiorco to begin 3000-ppm stage pump adding 1150-bpd 12000-ppm Marcit gel to the injection stream, 650-psi WHP. Total away at the time of report: 137-bbl polymer;464-bbl PW. 10/22/2013 Continued 3000-ppm stage, pumping Marcit gel 1100-bpd gel (12000-ppm polymer); 3300- bwpd PW; 995-psi WHP. Cumulative pumped in well: 4428-bbl. 10/23/2013 Continued 3000-ppm stage, pumping Marcit gel 1140-bpd gel (12000-ppm polymer); 3300- bwpd PW; 1140-psi WHP. Cumulative pumped in well: 8749-bbl. 10/24/2013 Continued 3000-ppm stage, pumping Marcit gel 1100-bpd gel (12000-ppm polymer); 3300- bwpd PW; 1095-psi WHP. At noon, begin 5000-ppm stage: lowered PW injection rate to 2200-bwpd; increased polymer concentration to 15000-ppm; 1226-psi WHP. Cumulative pumped in well: 12851-bbl. 10/25/2013 Continued 5000-ppm stage, pumping Marcit gel 1100-bpd gel (15000-ppm polymer); 2250- bwpd PW; 1200-psi WHP. Cumulative pumped in well: 16752-bbl. 10/26/2013 Continued 5000-ppm stage, pumping Marcit gel 1050-bpd gel (15000-ppm polymer); 2100- bwpd PW; 1380-psi WHP. Cumulative pumped in well: 18238-bbl. 10/27/2013 Completed 5000-ppm stage, pumping 7786-bbl Marcit gel (15000-ppm polymer): 1000-bpd gel and 2100-bwpd PW; 1406-psi WHP. Completed 7000-ppm stage, pumping 490-bbl Marcit gel (15000-ppm polymer): 1000-bpd gel and 1250-bwpd PW; 1730-psi WHP. Completed 10000-ppm stage, pumping 187-bbl Marcit gel (15000-ppm polymer): 1000-bpd gel and 575-bwpd PW; 2000-psi WHP. Flushed with 168-bbl PW and 38-bbl diesel freeze protect. Cumulative pumped in well: 20683-bbl. 10/28/2013 RDMO Tiorco. 11■11111111011111=11111111■11r1111111111111111=1. 0,14,\��j,,s THE STATE Alaska Oil and Gas -�,`'1� 1' °fALASI�:A Conservation Commission GOVERNOR SEAN PARNELL �rh 333 West Seventh Avenue Off, Q. Anchorage, Alaska 99501-3572 ALAS �y i Main: 907.279.1433 SCANNED NO n 2 20tr1 Fax: 907.276.7542 , John Braden Staff Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. � P.O. Box 100360 gaa`,rC' Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1D-11L2 Sundry Number: 313-512 Dear Mr. Braden: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /3471.44.)$L— Cathy P. oerster ��// Chair, Commissioner �fTw DATED this( day of September, 2013. Encl. STATE OF ALASKA RECEIVED - AllikA OIL AND GAS CONSERVATION COMNIOION a~P 2 4 2013 APPLICATION FOR SUNDRY APPROVALS DLL 2/Z� i 20 AAC 25.280 A : 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved R-ogram r Suspend r Rug Perforations r Perf orate r Pull Tubing r A^ rum Extension r Operational Shutdown Re-enter Susp.Well r Stimulate "Alter casing Other: Ji qrt k/ L7 GA NV 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: V� {3 ConocoPhillips Alaska, Inc. Exploratory r Development r 204-212 ' Ot'2G4 3.Address: Stratigraphic r Service 1 • 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-22946-61 - 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r; 1D-11L2 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 28243 . Kuparuk River Field/Kuparuk River Oil Pool ` 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): ' 13750 6631 • 13535' ' 6618' ' none none Casing Length Size MD ND Burst Collapse CONDUCTOR 80 16 115' 115' SURFACE 6780 9.625 6815' 4404' PRODUCTION 10534 7 10565' 6363' LINER L2 2584 2.875 13550' 6620' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11157-12491,12618-12762,12984-13537 6596-6586,6590-6594,6592-6620 4.5 L-80 10406 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER SLZXP LINER TOP PACKER MD=10401 TVD=6277 NIPPLE -CAMCO'DS'NIPPLE MD=541 TVD=541 • 12.Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service For' 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/8/2013 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG W. Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Braden©263-4536 Email: John.C.Braden@conocophillips.com Printed Name �h Brade Title: Staff Drillsite Petroleum Engineer Signature Phone:263-4536 Dated 2/, Zai3 Commission Use Only Sundry Number: /� Conditions of approval: Notify Commission so that a representative may witness ' -- 5'a L Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r RBr MS OCT 1 0 204' Other: Spacing Exception Required? Yes El No a Subsequent Form Required: Oar 4_04. APPROVED BY Q —7 / Approved by: COMMISSIONER THE COMMISSION Date: ! "Z /" Approved a I tipn v I d orAl2 months from the date of approval. Form 10-403(Revised 10/2012) I H Submit Form and Attachmen in Duplicate ;�1\� 111,E 4/u/13 , ` \\\ • • KRU 1D-11 L2 ,, /14.6 .P?A PTD 204-212-0,API 50-029-22946-61-00 Marcit Gel Treatment fog/if-''re- °- JUSTIFICATION: Rapid communication to 3 wells indicates high potential for void space conduit flow which we suspect is down L2 based on high%flow from profiles and%recovery of tracer. Attenuating flow into this channel is expected to improve sweep efficiency in this injection pattern. 1. Set a positive plug in the Cameo D nipple (ID- 2.25") at- 11,008 ft MD to isolate Lateral 1. 2. Test each rate in the following order: 1.3 BPM, 1.9 BPM, 2.6 BPM and 3.5 BPM 3. Move in and rig up PU23 polymer mixing equipment. 4. Pump treatment according to table below: Target Concentration Design PU 23 Rate Treatment Water Supply Treatment Target Polymer PU23 Polymer (ppm) Volume(bbl) (bpd) Rate(bpd) Rate(bpd) Rate(bpm) (#/day) Concentration(ppm) 3000 18000 1250 5000 3750.0 3.47 5245 12000 5000 13500 1250 3750 2500.0 2.60 6556 15000 7000 9000 1250 2679 1429 1.86 6556 15000 10000 4500 1250 1875 625.0 1.30 6556 15000 Total 45000 5. Evaluate pressure changes over time to target final pump rate and pressure of- 2500 BWPD at a stable WHP of- 1500 psi. 6. Displace the final stage of Marcit Gel with- 148 Bbls of PW from tanks, and 38 Bbls of Diesel for surface freeze protection to 2500'. 7. Continue to monitor all pressures for 30 to 60 min. 8. Leave the well SI for more than 4 days. 9. After the well has remained SI for the desired gel cure period. Bring the injection system on line starting at 25% and increasing to 50%,then 75% of desired rate. 10. MIRU and pull the isolation plug from the L1 lateral. 11. Resume injection at the rate established prior to pulling the Ll lateral plug and note the change in pressure. 12. Allow this rate to stabilize for one week and then schedule anli injection profile to determine the injection split between L1 and L2. r �-° KUP 1 D-11 L2 a ConOCOPhilliP5 01 Well Attributes Max Angle&MD TD I�aSk Its WellboreAPWWI Field Name Well Status Ind)°) MD(RKB) Act Btm(RKB) 500292294661 KUPARUK RIVER UNIT !NJ 97.40 11,622.83 13,750.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date SSSV:NIPPLE Last WO: 10/26/1999 Well Config:-10-11L2 4/12/2013 2.28 10 PM -- . Schematic-Actual Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag. 10,962.0 7/26/2005 Rev Reason:WELL REVIEW osborl 4/12/2013 Casing Strings HANGER,29 Casing Description String 0... String ID...Top(SOB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd LINER L2 2 7/8 2.441 10,965.8 13,550.0 6,620,3 6.50 L-80 STL Liner Details Top Depth' " (TVD) Top Inol Nomi... Top(RKB) (RKB) (°) Item Description Comment ID(in) 10,965.8 6,576.9 61.62 DEPLOY BAKER DEPLOYMENT SUB 2.380 13,537.3 6,619.9 88.50 0-RING BAKER 0-RING SUB 1.625 ICI ',, fl Perforations&Slots Shot Top(TVD) Btm(TVD) Dens Top(RKB)Btm(EKE) (EKE) (RKB) Zone Date ($h... Type Comment CONDUCTOR 35-115 11,157.0 12,491.0 6,595.9 6,585.6 C-3,C-4, 11/192004 8.0 SLOTS Slotted Liner,90 deg orient 1D-11L2 12,618.0 12,762.0 6,589.6 6,593.6 C-4,1D-11L2 11/19/2004 8.0 SLOTS Slotted Liner,90 deg orient 12,984.0 13,537.0 6,591.9 6,619.9 C-4,C-3, 11/19/2004 8.0 SLOTS Slotted Liner,90 deg orient NIPPLE,541 a,.j 3,',- 1D-11L2 Notes:General&Safety End Date Annotation 11/22/2004 NOTE:MULTI-LATERAL WELL:MAIN LEG,w/2 CTD LEGS L1&L2 w/SLOTTED LINERS 1/8/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SURFACE, - 35-6,814 GAS LIFT, 10,353 CHOKE,10,397 a NIPPLE,10,397 T LOCATOR, 10.406 SEAL 10,4 ASS0, 07 PRODUCTION, , 30-10,565 IPERF, 10907-10,927 WINDOW L2, 10 92510,935\ -- LINER, \ 10,401-11,234 SLOTS, 11,157-12,491 9 It SLOTS, 12,618-12,762 — 1 8 _ Mandrel D etails __I (..... Top Depth Top Port (TVD) 1001 OD Valve Latch Size TRO Run N...Top(ttKB) (ftKB) (°) Make Model (in) Sery Type Type (in) (psi) Run Date Corn...4 1 10,353.0 6,252.3 58.64 CAMCO KBG-2-LS 1 Gas Lift DMY BTM 0.000 0.0 9/4/2005 3 SLOTS, 12,98413,537 LINER L2. 10,96513,550 A . TD(1D-11L2), 13,750 • • JILjZ Regg, James B (DOA) PTO Z Y z l z o From: CPF1 Prod Engr [n1269 @conocophillips.com] Sent: Sunday, January 08, 2012 3:18 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Prod Engr & Optimization Supv; NSK Prod Engr Specialist; CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1 Prod Engr Subject: LPP /SSV Returned to Service for 1D-11 (PTD #s 199 -072, 204 -211 and 204 -212) today, 01/08/2012 Tom / Jim, The low pressure pilot (LPP) on injector 1D-11 (PTD #s 199 -072, 204 -211 an . 204 -212)) as returned to service today 01/08/2012 after the well was swapped to MI. The wellhead injection pressur .1. no s a.ilize above the setting of the low pressure pilot after the well was put into PWI service on 12/25/11. The pilot had been defeated on 12/24/2011 in accordance with "Administrative Approval No. CO 432D.009." Please let me know if you have any questions. David Lagerlef /Dan Bearden CPF1 Production Engineers n1269 F C �E 'iC 659 -7493 pager 659 -7000 765 1 • • ~~~p~-~y Robert Christensen ~'° ~J Production Engineering Specialist. Greater Kuparuk Unit , NSK-69 ,~ L~~~ PO Box 196105 ConocoPh i I I i ps ~ ~ ~ ~ Anchorage, AK 99519-6105 Phone: (907)659-7535 F1~c~S~c3 ~l~ gv L z4 '~i;t t;~v'~"81tt"S1SSI~~c: 659-7314 ~1C1C~~1 ".; ~ :.,~~~ November 13, 2008 o~~' ~~ ~- Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7`" Ave. Ste. 100 ,.~ ~ ~;~~: ~~ ~~~~ Anchorage, AK 99501 ''~~~ Dear Mr. Maunder, ConocoPhillips Alaska, Inc. has begun Gas Injection is association with the Kuparuk River Oil Pool 1D FOR Expansion. Enclosed you will find 10-404 Report of Sundry Well Operation for ConocoPhillips Alaska, Inc. for Wells 1 D-O5, 1 D-06, 1 D-10, 1 D-11, 1 D-11 L 1, and 1 D-11 L2. This report records the commencement ofwater-alternating-gas injection service. If you have any questions regarding this matter, please contact myself at 659-7535. Sincerely, Robert D. Christensen Attachments ~~, 4 ~~ _~~._ ~ . • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPER/~ETIONS 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^ 1 D EORX Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ ~~ ~~,c~ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ~ COnocoPhllhps Alaska, InC. Development ^ Exploratory ^ ~ 204-212 ' ¢~~~'' 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22 946-61 7. KB Elevation (ft): 9. Well Name and Number: RKB 106' 1 D-11 L2 8. Property Designation: 10. Field/Pool(s): ADL 028243 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 13750' - feet true vertical 6631' ~ feet Plugs (measured) Effective Depth measured 13535 feet Junk (measured) true vertical 6617 feet Casing Length Size MD ND Burst Collapse CONDUCTOR 115' 16" 115' 115' SURFACE 6708' 9-5/8" 6814' 4403' PRODUCTION 10458' 7" 10564' 6362' PRODUCTION 534' 4-1/2" 10935' 6561' SLOTTED LINER 2570' 2-7/8" 13537 6620' L2 WINDOW 1' 4-1/2" 10936 6562' Perforation depth: Measured depth: 11157'-12491'; 12618'-12762 ; 12984'-13537' true vertical depth: 6596'-6586'; 6590'-6594'; 6593'-6620' Tubing (size, grade, and measured depth) L-80, L-80, 10415' MD. Packers &SSSV (type & measured depth) Packer =Baker 7 x 4-1/2 SLZXP Packer = 10409' SSSV =Nipple SSSV = 541' 12. Stimulation or cement squeeze summa ry: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 5514 663 1839 Subsequent to operation 5563 480 1739 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service^ ' Daily Report of Well Operations X 16. Well Status after proposed work: Oil^ Gas^ WAGQ , GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: N/A contact Bob Christensen/Vacant Printed Nam D. ~stensen Title Production Engineering Technician Signature ~ - Phone: 659-7535 Date ~~ ~ 3 /l /7 `~ Form 10-404 Revised 04/2004 ~ ~ ° ' t ~ ~~~'~a~ ~;~, [~~~ ~~ ~0~~ Submit Ori I Only ~~~~C~ • 1 D-11 L2 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/23/08 Commenced 1D EORX WAGIN Injection 07/29/06 1 D-11 State Witnessed (John Crisp) 4 -Year MITIA- passed, Initial T/I/0= 125/460/250, Pressured up IA to 1870 psi. Start MITIA T/I/0= 130/1870/400, 15 min. T/I/0= 130/1850/400, 30 min. T/I/0= 130/1850/400, Final T/I/0= 130/460/250 • ConocoPhillips Alaska, Inc. KRU 1 D-11 L2 ~- 1D-11L2 API: 500292294661 Well T e: INJ An l TS 57 d 10902 TUBING (o-1oa1s, { _ SSSV Type: _ -- NIPPLE - yp - - _ Orig 11/20/2004 e : Angle @ TD: e _ -- - 86 deg @ 13750 oo:asoo, Com letion: ID:3.958) Annular Fluid: Last W/O: Rev Reason: FORMAT UPDATE Reference Log: _ - Ref Lo Date: -- Last U date: 12/27/2007 Last Tag:. 10962 TD: 13750 ftKB Last Ta Date: 7/26/2005 Max Hole An le: 97 de 11623 Casin OMM ON S S G - ~ Descrl lion ~ Size To Bottom ND Wt Grade Thread D To colvD 6 ooo o 115 115 62.58 HP40 WELDE SURFACE __ 9.625 0 6814 4403 40.00 L-80 BTC PRODUCTION 7.000 0 10564 6362 26.00 L-80 BTC PRODUCTION -- - 4.500 10401 11234 6593 12.60 L-80 IBT WINDOW L2 - 4.500 10935 - 10936 6562 0.00 Casin Sg trin9_-_LI NER L A TERAL L2 ~ SPF SLOTTED LIN ER _ Description _ Size Top Bottom TVD V1It Grade Thread L2 Blank Liner _ 2.875 _- _ 10967 11158 6596 6.50 L-80 STL L2 Slotted Liner 2.441 11158 12492 6586 6.50 L-80 STL L2 Blank Liner 2.441 12492 12618 6590 6.50 L-80 STL L2 Slotted Liner 2.441 12618 12763 6594 6.50 L-80 STL L2 Blank Liner _ 2.441 12763 12985 6593 6.50 L-80 STL L2 Slotted Liner 2.441 12985 13537 __ 6620 6.50 L-80 STL Tobin Strin -TUBING Size Top Bottom TVD - - - Wt _ _ Grade Thread _ 4.500 0 10415 6285 12.60 _ L-80 -- IBT Perforations Summa -; Interval TVD Zone - Status Ft SPF Date Type_ Comment -- 11157 - 12491 ---- 6596 - 6586 - C-3,C-4,C_-4 1334 8 11/19/2004 IPERF - - Slotted Liner 90 de -- g orient 12618 - 12762 6590 - 6594 C-4 144 8 11/19/2004 - IPERF _ _ Slotted Liner 90 de g orient 12984 - 13537 6593 - 6620 C-4 C-3 553 8 11/19/2004 IPERF , Slotted Liner, 90 de orient Gas Lift MandrelsNalve s • • • St MD TVD Man Mir 1 - Man Type - V Mfr V Type - V OD Latch Port - T TRO Date Run - Vlv • • mnt • • 1 10353 6252 -- CAMCO - KBG-2-LS - DMY 1.0 BTM 0.000 0 9/4/2005 De lo Sub MOD p y (loess-1oss7, Other lu s, a ui ., et c.~_- L2 LIN ER DET AIL oD:3sso) Depth TVD Type Descrl tfon ID 10945 6567 OPEN OPEN HOLE SIDETRACK FROM 1D-11 LINER TO TOP OF L2 LINER @ 0.000 H_ OLE 10951' 10966 6577 De to Sub L2 LINER BAKER DEPLOYMENT SUB 2.380 L2 Blank Oth l i Liner - er ugs, a u .,-etc _ . -COMPLETION (1oss7-n15e, -I _Depth TVD Type __.__ ____ _ Description ID oD:z.e75, - 541 541 NIP _ CAMCO DB NIPPLE 3.813 'RODUCTION 10397 6275 NIP _ OTIS'X' NIPPLE 3.812 (10401-1123x ~ 10397 6275 CHOKE 1/2"CHOKE ON 4.5" X-LOCK set 2/26/2007 0.500 , oD:a.soo, 10407_ 6280 SEAL BAKER SEAL ASSEMBLY 192-47 3.875 Pert - 10409 6281 PACKER BAKER PACKER 7" x4.5" SL ZXP LINER TOP PACKER 3.875 ;,,157-,zas,> I I General Notes - Date Note 1/2_2_/200 NOTE: MULTI-LATERL WELL: MAIN LEG, w/2 CTD LEGS L1 & L2 w/SLOTTED LINERS LZ Slotted I I Liner (17158-12492, OD:2.441, Wt:6.50) L2 Blank Liner (12492-12818, I I OD:2.441, - Perf ;12618-12762) L2 Slotted Liner (12818-12763, - OD:2.441, I I Wt:6.50) - I I L2 Blank Liner _ (12763-12985, I I OD:2.441, - Perf ;12984-13537) L2 Slotted Liner (12985-13537, OD:2.441, I I Wt:6.50) ~ • _~:~,: 1 -. 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFichetCbrPgs_Insertst141icrofilm M~rker.doc . Transmittal Form . r'ill BAKEl HUGHES 11--~':~~~_'::",I: _ _ ----'-----~;-::-~::-~-~~::-,-::-::--:·-~::-"~---------l r I I.u:...-., _.. - ~ .,; ,'...., i. '-" INTEQ ... !._",. _.. -, ',,/ ~, ,Th' To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Helen Warman Reference: ID-llL2PB1- Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) I LDWG lister summary I bluelines - MPR-DIR _ md Log 1 bluelines - MPR-DIR_tvd Log ...; Anchorage GEOScience Center !~~~ +2":' ~:-:-:-I !I !I II H II , I II I ¡ ! i i II 11 !I II Ii Iì II ,:¡ iQ\NNB) JAN 0 B 20D7 LAC Job#: 784055 Sent By: Cosetta Todirica Received By: c..J~ Date: Dec. 8, 2006 Date: ~ IS¡ a7 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 ():¡:~ GOLf - Q I:J- ¡:t: l/..( :!Þ3 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 I i I I I I I I I I ! ... I ~_mY0õ;_n_n___ni ...." ·,t ,,, ""-'" ",.,., .",., ,.", ~-~-~_._._----- - ..> ., ,..... ;;¿ (::) b oLe..- DATA SUBMITTAL COMPLIANCE REPORT 11/27/2006 ) N'ò tI ~ V Jlo.J ~.. API No. 50-029-22946-61-00 Permit to Drill 2042120 Operator CONOCOPHILLlPS ALASKA INC Well NamelNo. KUPARUK RIV UNIT 1D-11L2 MD 6628 Completion Date Current Stat~~_~_~.---= Directional su~__...~ 11/20/2004 Completion Status 1-01L 13750 TVD --~- .- ~,._------"._-- REQUIRED INFORMATION Mud Log No Samples No ---_......,~ DATA INFORMATION Types Electric or Other Logs Run: MWD GR / RES Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Electr Data Digital Dataset R/ Mod'Fnnt Number Name 14246 I nd uction/Resistivity og 14246 I nd uction/Resistivity ~ 14246 LIS Verification feu, 14246 I nd uction/Resistivity og 14247 I nd uction/Resistivity og 14247 I ndu ction/Resistivity i~ 14247 LIS Verification I~LiS 14247 I nd uction/Resistivity ~ Well Cores/Samples Information: Interval Start Stop --'-~.---~-- 10946 12091 Log Log Scale Media Mþ 25 Blu TV!> 2 Blu Run No OH/ CH Received Comments Open 11/17/200S--¡;ß1 MD MPR GR13~NoV=-1 I 2004 ; 12091 Open 11/17/2006 PB1 TVD MPR, GR 13- Nov-2004 12091 Open 11/17/2006 PB1 LIS Veri, GR, ROP7- Nov-2006 Open 11/17/2006 PB1 LIS Veri GR, ROP w/Graphics I MD MPR, GR 18-Nov-2004 i TVD MPR, GR 18-Nov- I' 2004 13750 Open 11/17/2006 LIS Veri GR, ROP 6-Nov- . 2006 . __.,. ·1' Open 11/17/2006 LIS Veri w/GraPhiC~ . ~ 10946 10946 o o J\ P 25 Blu Tv]) 2 Blu 10946 10946 13750 Open 11/17/2006 13750 Open 11/17/2006 10946 o o Name Interval Start Stop Sample Set Number Comments Sent Received ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? ~/ ~ Chips Received? ~ Formation Tops Analysis Received? ~ -'~"-~~ -----~ -'-~~_.~-- Comments: . . DATA SUBMITTAL COMPLIANCE REPORT 11/27/2006 Permit to Drill 2042120 Well Name/No. KUPARUK RIV UNIT 1D-11L2 Operator CONOCOPHILLlPS ALASKA INC API No. 50-029-22946-61-00 MD 13750 TVD 6628 Completion Date 11/20/2004 Completion Status 1-01L Current Status WAGIN UIC Y . . - ... . .. .. ~-=~ Compliance Reviewed By: Date: ~,:]....JlL¡ ~~ . . Transmittal Form . . I.I=-:===- r---"·-"'~-. ·..·..·"'-·....1 .,·~''!~,·;'''''w,··.-_'. Fíìßff~f~~1 "·"~.~I ""~' .' ',.<I'.,w ;,-¡._:'...-:.':' .... , ' I ¡ I . I 1.."\ ' I j! I 1 I i ; I : I i I INTEQ To: Attention: '&ill BAKER HUGHES Ancborage GEOScience Center AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Helen Warman Reference: ID-llLl, ID-llL2, ID-llL2PBl II I ¡ I ¡ Contains the following: 3 LDWG Compact Disc (Includes Graphic Image files) 3 LDWG lister summary 3 bluelines - MPR-DIR _ md Log 3 bluelines - MPR-DIR_tvd Log LAC Job#: 784055 ,I Sent By: Cosetta, ~.odirica II { Received By: Q. l/LiL---.-'"'' ., DatÇ;'g~f':)~è~dt: J '\ ,,,,,,,, ""'# :b" ,Î ·1 1~=, Date: ]1. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & R~fûRNING OR FAXING YOUR COpy FAX: (907) 267-6623 ! \T(~ ..)-"--" 9ld :9 OL...{ - W,Ø; '¥c jL.¡ dL / 0 t:t, Ii-{ ;)Lll- . )'1 {\¡:> eLl' -::::) II cl 11...1:'1 J..J1< -' ._~ J ',,/ " ,;::,j ¡ () Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ,.:,..,,, I , ...,,,,,'" ~~-1,1E:~; ""ì~~ e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS J, 2. Operator Name: ConocoPhillips Alaska, Inc. 3, Address: P. O. Box 100360, Anchorage, Alaska 99510 7, KB Elevation (ft): RKB 106' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION PROD. CASING WINDOW L2 l' Perforation depth: ~1 6. API Number: 50-029-22946-61 9. Well Name and Number: 10-11 L2 10. Field/Poo/(s): Kuparuk River Field I Kuparuk Oil Pool measured 13750' feet true vertical 6629' feet measured 13535' feet true vertical 6617' feet Length Size MD 115' 16" 115' 6708' 9-5/8" 6814' 10458' 7" 1 0564' 833' 5.5" 11234' 4-1/2" 10936' Measured depth: 10945'-13535' true vertical depth: 6567'-6617' Plugs (measured) Junk (measured) rvD Burst Collapse 115' 4403' 6362' 6727' 6562' Tubing (size, grade, and measured depth) 4-112" , L-80, 10415' MD, RBDMS BFl SEP 1 5 2005 Packers & sssv (type & measured depth) no packer SSSV= NIP SSSV= 541' Form 10-404 Revised 04/2004 Submit Original Only e 1D-11L2 DESCRIPTION OF WORK COMPLETED SUMMARY e Date Event Summary 9/9/200sICommenced Water Injection cycle . $1r~1JŒ (ID~ ~~~~æ~ . AI/ASIiA OIL AlQ) GAS CONSERVATION COMMISSION FRANK H. MURKOW5KI, GOVERNOR 333 W, pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brian Seitz Kuparuk Staff Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska Re: Kuparuk 1D-11L2 Sundry Number: 305-210 Dear Mr. Seitz: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decis' to Superior Court unless rehearing has been requested. DATED this 1/day of August, 2005 Encl. ... . STATE OF ALASKA CfJ:}1t0~ RECE/VEDi ALASKA OIL AND GAS CONSERVATION COMMISSION AU G 0 1 2005 ~(') APPLICATION FOR SUNDRY APPROVAL Alaska Oil & Gas Cons C ' . . 20 MC 25 280 . omm'SSlon a . 1, Type of Request: Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Waiver 0 'Öt~~r 0 0 0 0 0 0 to convert to Alter casing Repair well Plug Perforations Stimulate Time Extension injector Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 2, Operator Name: 4, Current Well Class: 5, Permit to Drill Number: ConocoPhillips Alaska, Inc, Development 0 Exploratory 0 204-212 3, Address: Stratigraphic 0 Service 0 6, API Number: p, O. Box 100360, Anchorage, AK 50-029-22946-61 7, KB Elevation (ft): 9, Well Name and Number: RKB 105,5' 10-11 L2 8. Property Designation: 10, Field/Pool(s): ADL 28243, ALK 3814 Kuparuk River Field 1 Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (It): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13750' 6628' 13535' 6618' Casing Length Size MD rvD Burst Collapse CONDUCTOR 115' 16" 115' 115' SURFACE 6708' 9-5/8" 6814' 4403' PRODUCTION 10458' 7" 10564' 6362' PRODUCTION 538' 4-1/2" 10939' 6564' SLOTTED LINER 2584' 2-7/8" 13535' 6618' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11143'-12477', 12603'-12748', 12970'-13522' 6597'-6583', 6587'-6591', 6590'-6617' 4-1/2" L-80 10420' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER pkr= 10401' no SSSV 12, Attachments: Description Summary of Proposal 0 13, Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14, Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1-Sep-05 Oil 0 Gas 0 Plugged 0 Abandoned 0 16, Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 17, I hereby certify that the foregoing is true and correct to the best of my knowledge, Contact: Brian Seitz @ 265-6961 Printed Name Brian Seitz ~Á Title: Kuparuk Staff Engineer Signature ~ Phone ,16>=-ófÞ¿1 Date "7 /¡;Þ-.J~.1- ""'V "YV / v Commission Use Only Sundry Number: - Conditions of approval: Notify Commission so that a representative may witness ,;3¿, S -.:;-/ p Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ~ Location C n - Other: 00 r..oRtr~\~\"~ j RBDMS BFl AUG 0 3 2005 '\ð<!.,,~\~~~ *1f'<J'/~ S'b",q?71æ/:JL\ APPROVED BY D,æ ø-Mt' Approved bŸt: ""/ CO]l4lv1\S.SIQ~ I " , ^ ,THE COMMISSION Form 10-403 ~d 11/2~4 lJ r\ ¡ tJ! I\J ¡~ L sUbJin D~Plicate . . r KRU 1 D-11, 1 D-11 L 1, & 1 D-11 L2 Conversion to Injection Backl!round KRU ID-ll was drilled and completed as a C-sand injector in October of 1999 to support offset producers ID-12 and ID-30. The well remained on water injection until November of2004, when the ID-IILI and ID-IIL2 horizontal laterals were drilled with coiled tubing while preserving the original wellbore. After the coiled tubing sidetrack, the well was put on pre-production at an initial rate of 5500 BOPD and 35% water cut. Production rates have since declined to 2000 BOPD at a 62% water cut and without gas lift capabilities, the well is having difficulty sustaining flow. In addition, a new offset producing well (lD-28) has since been drilled and requires injection support. The plan is to now complete the necessary facility work to convert the well back to its originally intended service of water injection to support offset producers ID-12, ID-28, and ID-30. A CBL run on 11/19/99 indicates good cement across and above the pay interval. The last MITIA for ID-l1 was performed on 10/19/04 as part ofpre-CTD diagnostics. The well passed the MITIA. Summary of Operations Necessary piping and instrumentation will be put back in place to convert surface slot 11 on DS-ID back to water injection service. Proposed wellwork is limited to changing out the OV at 10,353' rkb with a DV and perform an MITIA per AOGCC requirements. . STATE OF ALASKA _ ALAS. IL AND GAS CONSERVATION CO~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG DEC 3 02004 IVED , ,..,., .., f', ð'1~.-,._.... ","" " 1a. Well Status: !HI Oil o Gas o Plugged o Abandoned o Suspended o WAG ""., ....1'....,_... ....~"" IU. yytm vlé1~::¡. 20AAC 25,105 20AAC 25,110 !HI Develo~WtOrl!tt.xploratory DGINJ DWINJ o WDSPL No. of Completions One Other o Stratigraphic o Service 2, Operator Name: 5. Date Comp" Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc, 11/20/2004 204-212 3, Address: 6. Date Spudded 13. API Number P,O, Box 196612, Anchorage, Alaska 99519-6612 11/11/2004 50- 029-22946-61-00 4a, Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 11/18/2004 Kuparuk 1D-11L2 586' SNL, 601' WEL. SEC, 23, T11 N, R10E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 2760' NSL, 2830' WEL, SEC. 19, T11N, R11E, UM 105.5' Prudhoe Bay Field I Kuparuk River Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 2758' NSL, 94'WEL, SEC, 19, T11N, R11E, UM 13535 + 6618 Ft 4b, Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 560491 y- 5959079 Zone- ASP4 13750 + 6628 Ft ADL 028243 TPI: x- 568518 y- 5957214 Zone- ASP4 11. Depth where SSSV set 17, Land Use Permit: Total Depth: x- 571254 y- 5957237 Zone- ASP4 NIA MD 18. Directional Survey 19. Water depth, if offshore 20. Thickness of Permafrost !HI Yes DNo NI A MSL 1900' (Approx.) 21, Logs Run: MWD GR 1 RES l22. CASING, LINER AND CEMENTING RECORD CÄ$ING SETTING DEPTH' MD , SETTING I EP"TH TVD HotE ÄM()I.IW SIZE WT. PER FT. GRADE TOP I BOTTOM TOP BOTTOM SIZE PUI,;I.:ED 16" 62.5# H-40 Surface 115' Surface 115' 20" 9 cu yds HiQh Early 9-5/8" 40# L-80 Surface 6814' Surface 4396' 12-1/4" 760 sx AS tillite, 710 sx Class 'G' 7" 26# L-80 Surface 10565' Surface 6355' 8-1/2" 1220 sx Class 'G' 4-1/2" 12.6# L-80 10401 ' 10939' 6270' 6564' 6-1/8" 140 sx Class 'G' 2-7/8" 6.5# L-80 10951' 13535' 6570' 6618' 4·1/8" x 3·3/4" Uncemented Slotted liner 23. Perforations op'en to Production (MD + TVD of To,e and 24. Tua!NGREcORD Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Slotted Section 4-1/2", 12.6#, L-80 1 0420' 10401' MD TVD MD TVD 11143' - 12477' 6597' - 6583' 25. AçID,FRAGTqRE¥,CEMENT $au!:E4E, .ETP. 12603' -12748' 6587' - 6591' 12970' - 13522' 6590' - 6617' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAl.: USED Freeze Protect wI Approximately 120 Bbls Diesel 26, PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): November 28,2004 Gas lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF W A TER-BBI.: CHOKE SIZE I GAS-OIl.: RATIO 12/5/2004 24 TEST PERIOD ... 5625 6034 3096 1073 Flow Tubing Casing Pressure CALCULATED ... 011.:-8BL GAs-MCF WATER-BBL OIL GRAVITY-API (CORR) Press. 56C 625 24-HoUR RATE 5625 6034 3096 27, CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ¡......':';'.'.. RBDMS BFl ¡ COI,':! .....,..,,"t ,IAN 0 J. 2005 Noo ¡~~~ ,.:.". "'\ J Š I A LJ { (,1= : ~~.J ¡ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28, GEOLOGIC MARKE " 29. FORMATION TESTS ~ NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Kuparuk C3 10986' 6586' None Kuparuk C3 11721 ' 6589' Kuparuk C3 13392' 6612' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31, I ~erebY certify that the fOr~g .is true and correct to the best of my knowledge, Signed Terrie HUbble.-/fß JlJ Title Technical Assistant Date Kuparuk 1 D-11 L2 204-212 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / A roval No. Drilling Engineer: Dan Venhaus, 263-4372 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments, ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00), ITEM 20: True vertical thickness, ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval), ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None", ITEM 29: List all test information. If none, state "None", Form 10-407 Revised 12/2003 Submit Original Only pa.ge 1 of 19 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 10/31/2004 11/112004 10-11 1 0-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 From - To Hours Task Code NPT Phase 05:00 - 07:30 2.50 MOB P PRE 07:30 - 16:30 9.00 BOPSU P PRE 16:30 - 22:00 5.50 BOPSU P PRE 22:00 - 22:20 0.33 RIGU P WEXIT 22:20 - 22:45 0.42 RIGU P WEXIT 22:45 - 23:45 1.00 RIGU P WEXIT 23:45 - 00:00 0.25 RIGU P WEXIT 00:00 - 01 :30 1.50 RIGU P WEXIT 01 :30 - 02:00 0.50 RIGU P WEXIT 02:00 - 05:00 3.00 RIGU P WEXIT 05:00 - 06:30 1.50 RIGU P WEXIT '06:30 - 09:00 2.50 STWHIP P ,WEXIT I i 09:00 - 11 :15 2.25 STWHIP P !WEXIT 11:15 - 11:55 0.67 STWHIP P WEXIT 11 :55 - 13:55 2.00 STWHIP P WEXIT 13:55 - 15:00 1.08 STWHIP P WEXIT 15:00 - 16:45 1.75 STWHIP P WEXIT 16:45 - 17:55 1.17 STWHIP P WEXIT 17:55 - 20:00 2.08 STWHIP P WEXIT 20:00 - 20:35 0.58 STWHIP P WEXIT 20:35 - 21 :05 0.50 STWHIP P WEXIT 21 :05 - 23:30 2.42 STWHIP P WEXIT 23:30 - 00:00 0.50 STWHIP P WEXIT 11/212004 00:00 - 01 :00 1.00 STWHIP P WEXIT 01 :00 - 01 :45 0.75 STWHIP P WEXIT 01 :45 - 03:45 2.00 STWHIP P WEXIT 03:45 - 06:00 2.25 STWHIP P WEXIT 06:00 - 12:15 6.25 STWHIP P WEXIT Start: Rig Release: Rig Number: 10/29/2004 11/20/2004 2 Spud Date: 10/29/2004 End: 11/20/2004 Description of Operations Move off 10-32 into center of Pad. Mise welding work in cellar. I Move over 1 D-11 and set down NU BOPE, Spot mise equipment. Continue work on CT I component conversion to 2-3/8'. Fill pits wI 290 bbls seawater ¡Test BOPE, Witnessed by AOGCC I PJSM for pulling coil to the injector. '¡ Pull coil to injector Cut coil and remove grapple. Cut E line and seal conductor. Install connector. Reverse circulate to fill coil SW with methanolleed. Continue to fill coil reverse circulating pumping slack. Blow back coil. ,Cut Coil back to Eline and rehead. PT connector, inner reel ! valve & hardline to 4000 psi. I Change out upper quick connect blind for galled thread, Cut off i 60' of slickline and rehead : DSO open SSV. Pressure deploy 3.80' used window mill, BHI i straight motor, PWD sub wI 945 psi. Open SV and MV wI 122.5. IA 200, OA 370 i RIH wI BHA #1 holding 1000 psi whp initial while circ SW 11,7/2000 and displace well bore fluids to tiger tank. Red bp I based on strapped return rate. Red RIH speed at 8000' to !aO'/min 1,7711620 wI 600 psi. Wt chk @ 9600' 39k, 2.7k wI ¡I 500 psi. Swap to 2% KCI w/2 ppb biozan 2.0/1850. RIH to 11130' and no obstructions seen I Bleed OA from 580 and IA from 680 to 100 psi ea PUH 47k Circ biozan to mill. Divert returns thru MM and recip lover 11000-11050' 2.73/2.70/2920 wI 500 psi whp, 3668 psi i DHP (ECD not working). Circ an extra 40 bbls wI 400 psi bp at 13588 psi DHP ,POOH 2.7/2860 following pressure schedule and had mini 10verpuII at 10928' wI MW. RBIH, clean. Backream and saw nothing. Resume POOH following pressure schedule Pressure undeploy wI 720 psi initial/430 psi final LD cleanout BHA. Reconfigure BHI BHA. Add 3 SWS pips to WS and set in hole Repair injector chain press hyd leak Pressure deploy WS assy wI 41 0 psi RIH wI BHA #2 following pressure schedule to 10875' Tie -in -15' correction. RIH to 11020. Hold 450 psi at surface. Orient high side. Close ECD. Pressure coil to 3915 to set WS. Stack out 2K to confirm WS is set. Open EDC POH following pressure schedule. Lock in 700 psi. PJSM pressure Pressure undeploy WS setting BHA. Pressure undeploy WS setting BHA. LO WS setting BHA and PU window milling BHA. Pressure deploy window milling BHA. RIH following pressure schedule. Tag at 11016.2'. Correctto 11020.0' and flag. Begin milling window 2.71/2.85/3200 PVT 444 Returns were as low as 8.1 ppg until BU holding 400 psi whp, ECD 11.1, dhp 3750. Red whp to 150 psi after density and rate back to normal 2.69/2930, Printed: 1112212004 10:22:51 AM Page 2 of 19 BP Operations Summary Report WEXIT ECD 10.43, dhp 3607 PVT 440 Having trouble sliding and frequent stalls when parked-mud on the way HOS warm up KWF in uprights 111020.4' Start displacement to 8.6# mud. Had 3k incr in str wt after mud to surface. Still slow progress, but not stalling, Red IWhP to 100 psi 2.7/3140 wI 10,36 ECD, 3480 dhp 11021,0' Making steady progress. Are probably further along than the depth shows due to the numerous pickups earlier Continue milling window from 11022.6' 2.7/2.7 2950FS 250 MW Ann=3490 WHP=1oo Continuing to mill window, Driller reports metal filings on magnets. Catch a sample for the Goo to examine. Pit vol=367 I[ bbls, IAP=570 psi, OAP=480 psi. 2.72/2.76/3240 psi. Free spin = 2970 psi at 2.7 bpm with mud in the hole. 11026.4', Goo reports a very small amount of formation sand I in the sample, consistent with the C sand we expect to exit in, Stall at 11026.6', (Bottom of window?) 111027,5', Continued slow ROP. No distinct break at expected bottom of window at 11026,0'. Suspect we are in open hole. i Getting formation in cuttings. Drill 8' of rathole. 18' of rathole achieved. Ream/Backream window. Clean I' screens and catch a bottoms up sample. Sample shows good sand cuttings, Dry drift window. Passed up and down slick. POOH to lay down window milling BHA, Continue POH with window milling BHA. Tag up at surface. Trap 700 psi on wellhead. Hold PJSM re: pressure undeploymenVredeployment. SWS/Nordic proceedures reviewed step by step. Undeploy window milling BHA. (BHA #3). D0261 window mill recovered at 3,80" go, 3.79" No-Go, and showing a swirl pattern on the center of the bit face as expected. The string mill (used) recovered at 3.77" Go, 3.76" No-Go. Reconfigure BHI coiltrack BHA. Pressure deply BHA #4: Smith M09 3.75" bit, 3.0 deg BHI X-treme mud motor, BHI MWD tool. RIH with BHA #4 to drill build section. Tie GR tie-in, Missed marker on first pass. Start higher up. +35' correction. RIH tagged at 11037' dw wt=34k up wt=12k. Start drilling build section holding HS toolface in/out=2.65/2.68 FS=2830 MW= 2-500psi ECD=10.67 Ann=36oo whp=200 rop=20-3Ofph Drill to 11102' 88deg at bit estimating we will land 2' high to to plan, PROD1 TOH. Trap 500psi and SD pump just above window, open EDC. Continue TOH following pressure schedule. Pressure had bleed down to 286psi by the time EDC was closed and pumps started back on line. Hold PJSM and review procedures for Pressure Undeployment. Discuss plan for adding another 7' of lubricator to facilitate deployment of next BHA in 1 step which will include Res tool. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-11 1 D-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date NPT Phase From - To Hours 11/2/2004 06:00 - 12:15 6.25 STWHIP P 12:15 - 14:00 1,75 STWHIP P WEXIT 14:00 - 16:30 2.50 STWHIP P WEXIT 16:30 - 18:30 2,00 STWHIP P WEXIT 18:30 - 19:30 1.00 STWHIP P WEXIT 19:30 - 20:30 1,00 STWHIP P WEXIT 20:30 - 21 :30 1,00 STWHIP P WEXIT 21 :30 - 22:50 1.33 STWHIP P WEXIT 22:50 - 00:00 1,17 STWHIP P WEXIT 11/3/2004 00:00 - 01 :00 1.00 STWHIP P WEXIT 01 :00 - 01 :20 0.33 STWHIP P WEXIT 01 :20 - 02:40 1,33 STWHIP P WEXIT 02:40 - 03:30 0,83 DRILL P PROD1 03:30 - 05:00 1.50 DRILL P PROD1 05:00 - 07:00 2.00 DRILL P PROD1 07:00 - 08:00 1.00 DRILL P PROD1 08:00 - 10:10 2.17 DRILL P PROD1 10:10 - 12:00 1.83 DRILL P Start: Rig Release: Rig Number: Spud Date: 10/29/2004 End: 11/20/2004 10/29/2004 11/20/2004 2 Description of Operatións Printed: 1112212004 10:22:51 AM BP OperatiôAsSummary Report Page 3 of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-11 1 0-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 1 0/29/2004 11 /20/2004 2 Spud Date: 10/29/2004 End: 11/20/2004 Date From - To Hours Task Code NPT Phase Description of Operations 11/312004 10:10-12:00 1.83 DRILL P PROD1 At surface trap 560psi on well and SD pump. 12:00 - 13:30 1.50 DRILL P PROD1 Pressure undeploy BHA #4 following SOP's, 13:30 - 14:30 1,00 DRILL P PROD1 UD BHA #4 and prep BHA #5, I 14:30 - 15:10 I 0,67 DRILL P PROD1 Held monthly p, Hyatt safety and performance review, 15:10 - 15:45 0,58 DRILL P PROD1 Continue prep of BHA #5, 15:45 - 17:30 1,75 DRILL P PROD1 Add additional 10' to lubricator. P/U BHA #5 (81.78') using pressure deployment SOP's, (Bit,motor,FVS in the hole. Make-up remaining componets (68,77') in 2 sections split between PC's and EDC) Wellhead pressure 410psi 17:30 - 19:35 2.08 DRILL P PROD1 RIH following pressure schedule, 19:35 - 20:05 0.50 DRILL P PROD1 Log tie in pass over GR charecter in original well at 10906'. Make -27' correction, 20:05 - 21 :00 0,92 DRILL P PROD1 Make MAD pass for missing RES data, 21 :00 - 23:00 2,00 DRILL P PROD1 Tagged up 5' early, Begin drilling lateral section, Free spin = I 3000 psi at 2,7 bpm, Pit vol=365 bbls. WHP=120 psi. BHP=3550 psi. IAP=340 psi, OAP=380 psi, Drilling at 2,65/2,65/3360 psi. Slow drilling, 23:00 - 23:10 0.171 DRILL P PROD1 Wiper trip to window, 23:10 - 00:00 0.83 DRILL P PROD1 Free spin now 2870 psi at 2,73 bpm. Continued hard drilling. Goo reports he does not expect much siderite in the sands in this interval. 11/4/2004 00:00 - 03:00 3,00 DRILL P PROD1 Drill ahead, Slow ratty drilling. ROP=10-30 fph. 2.75/2.85/3200 psi, IAP=620 psi, OAP=360 psi. Pit vol=365 bbls. WHP=100 psi. BHP=3557 psi. ECD=10,5 ppg. 03:00 - 04:00 1,00 DRILL P PROD1 ROP improving slightly, ROP=40-80 fph. 04:00 - 04:25 0.42 DRILL P PROD1 Wiper trip to the window, Clean both ways. 04:25 - 06:55 2,50 DRILL P PROD1 Resume drilling, ROP slow again, We seem to be hitting occasional hard stringers, Possible siderite? Drilled to 11400'. 06:55 - 06:55 24,00 DRILL P PROD1 Revised window & WS depths based on last nights tie-in: TOW & WS= 11021' BOW= 11027' RA tag= 11030' BOWS", 11034' 06:55 - 08:55 2.00 DRILL P PROD1 Drilling ahead f/11400' Prate= 2.61/2.63 mud wt in/out= 8.65/8.70 pit vol= 360 bbls FS=2750psi MW=2-5OOpsi wob= 2-4k ECD=10.5 Ann=3547 whp=1oo IAP=745 OAP=435 pulwt=38k dn/wt=9k Drilled to 11460'. 08:55 - 09:25 0.50 DRILL P PROD1 Wiper trip to window. No problems, 09:25 - 13:15 3.83 DRILL P PROD1 Drill ahead f/11460' 2.6/2,6 full returns 2780 FS 2-50Opsi MW ECD=10.62 Ann=36oo Numerous siderite streaks. Drilled to 11516' 13:15 - 13:30 0.25 DRILL P PROD1 Wiper trip to window. 13:30 - 17:00 3.50 DRILL P PROD1 Drill ahead f/11516' 2.612.6 FS=28oo MW=3-6oo Pvol=340 Drilled to 11592' 17:00 - 18:30 1.50 DRILL P PROD1 Continue drilling ahead. 2.64/2,68 8.6318.69 Pvol=341 2850 psi free-spin at 2,54 bpm. ROP generally still poor, 20-40 fph. 18:30 - 19:15 0.75 DRILL P PROD1 Free spin = 2790 psi at 2,54 bpm. Make wiper trip up inside tubing. Clean PU off bottom. IAP=315 psi, OAP=330 psi. WHP=1oo psi. BHP=3560 psi. Pit vol=340 psi. Pump 15 bbls of high vis sweep to clean hole, Open EDC at window. 19:15 - 21:30 2,25 DRILL P PROD1 Log MAD pass up at 180 fph from 11060' accross RA tag to Printed: 11122/2004 10:22:51 AM Page 4 of 19 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-11 1 0-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 10/29/2004 Rig Release: 11/20/2004 Rig Number: 2 Spud Date: 10/29/2004 End: 11/20/2004 10700'. Pump pressures with EDC open are 2670 psi at 2.51 bpm. (100 psi WHP), Continue wiper pass up to 9500', then back in the hole. Geo caught bottoms up sample of sweep we pumped at start of wiper. No Siderite evident in sample at all. Relog tie in pass down accross RA tag. Make + 10' correction. Resume drilling. Free spin 2970 psi at 2.57 bpm. IAP=336 psi, OAP=360 psi. Pit vol=320 bbls, Drilling at 2.57/2.57/3490 psi. Drilling took off after wiper trip, Making 100+ fph! DD has been drilling at a high side tool face since 18:00. We are not getting any build at all. POOH to change motor to a bigger AKO. Continue POH for bigger bend motor. PJSM re: undeploying and redeploying BHA. Undeploy BHA #5 following procedure, Bit had clay in water courses, 1 plugged nozzle, and was graded 1,1, Bit in mostly good condition, had 1 cutter on pilot section of bit wom about 50%. Gauge section and rest of pilot in good shape, Make up BHA #6. New Hycalog DS 1 00 bicenter bit. New X-treme mud motor with 1.8 deg AKO, same MWD tool as previous run. RIH with BHA #6. Log tie-in at RA tag. -4' correction RIH to bottom. Directionally drilled ahead f/11697' with HS toolface. Unable to build any angle with 1.8 deg motor. Appear to be 'bumping' up against harder formation, Held tabletop Fire and Rig Evacuation drills, tested rig evac alarm system. TOH for 2.0 deg motor and M-09 bit Hold PJSM for Pressure Undeployment. Trap 590psi below rams. Pressure undeploy BHA #6. Pressure had dropped to 380psi. Make changes to motor. Pressure deploy BHA #7 (81,69'). 320psi on well. Surface test tools - okay. RIH with BHA #7, 2.2 deg motor and M09 bit. Log tie-in -22' RIH to bottom Resume drilling. Free spin=3050 psi at 2.72 bpm. Drilling at 2.71/2.72/3384 psi. ROP=30 fph. Pit Vol=306 bbls. IAP=170 psi, OAP=340 psi. BHP=3655 psi, WHP=11 0 psi. TF=O deg. Trying to build hole angle up thru hard streak. NB Incl=90.8 deg. PROD1 Had hard drilling for 40', then ROP picked up. May be thru hard streak:. Getting good builds with this BHA, start rolling tool face over to 60R to avoid getting too much Inc. PROD1 Rnallnc at bit=96 degrees, We have achieved the desired build. Dog legs=25 deg/100. POOH to pick up bicenter bit and drop motor AKO. Open EDC at the window, and pump at full rate COH. PROD1 PJSM re: undeployldeploy BHA. PROD1 Undeploy BHA #7, following step by step proceedure. Date From - To Hours Task Code NPT 11/4/2004 19:15 - 21 :30 2,25 RILL P PROD1 21:30 - 22:15 0,75 DRILL P PROD1 22:15 - 22:50 0,58 DRILL P PROD1 22:50 - 23:30 0.67 DRILL P PROD1 23:30 - 00:00 0,50 DRILL P PROD1 11/5/2004 00:00 - 01 :50 1,83 DRILL P PROD1 01:50 - 02:10 0.33 DRILL P PROD1 02:10 - 03:30 1,33 DRILL P PROD1 03:30 - 05:10 1,67 DRILL P PROD1 I 05:10 - 07:15 2,08 DRILL Ip PROD1 07:15 - 07:40 0.42 DRILL Ip PROD1 07:40 - 08:00 0,33 DRILL P PROD1 08:00 - 09: 15 1.25 DRILL P PROD1 09:15 - 12:00 2,75 DRILL P PROD1 12:00 - 13:20 1,33 DRILL P PROD1 13:20 - 13:50 0,50 DRILL P PROD1 13:50 - 15:00 1,17 DRILL P PROD1 15:00 - 17:15 2.25 DRILL P PROD1 17:15 - 17:35 0,33 DRILL P PROD1 17:35 - 18:00 0.42 DRILL P PROD1 18:00 - 18:50 0,83 DRILL P PROD1 18:50 - 20:40 1,83 DRILL P 20:40 - 22:45 2,08 DRILL P 22:45 - 23:00 23:00 - 00:00 0,25 DRILL P 1.00 DRILL P Description of Operations Printed: 11/22/2004 10:22:51 AM Page 5 of 19 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 10-11 1 0-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To Hours Task Code NPT 11/612004 00:00 - 00:30 0.50 DRILL P PROD1 00:30 - 02:00 1,50 DRILL P PROD1 i 02:00 - 04:00 2,00 i DRILL P PROD1 i 04:00 - 04:20 0,331 DRILL P PROD1 I 04:20 - 05:00 0,671 DRILL P PROD1 I 05:00 - 07:45 2,75 ¡DRILL P PROD1 ì 07:45 - 09:00 1,25 DRILL P PROD1 09:00 - 11 :00 2,OO! DRILL P PROD1 11 :00 - 13:30 2,50 ¡DRILL P PROD1 I 13:30 - 16:30 3,001 DRILL P PROD1 I I I 16:30 - 17:30 1,00 I DRILL P PROD1 I 17:30 - 18:50 1,331 DRILL P PROD1 ì 18:50 - 20:00 1,d DRILL P PROD1 20:00 - 21 :35 1,581 DRILL 0,75 DRILL PROD1 P PROD1 21 :35 - 22:20 P 22:20 - 00:00 1.67 DRILL P PROD1 Start: 10/29/2004 Rig Release: 11/20/2004 Rig Number: 2 Spud Date: 10/29/2004 End: 11/20/2004 Description of Operations Continue to lay down BHA #7. Bit recovered all balled up in the water courses with clay, Graded 1,1, No apparent damage. MU BHA #8, Adjust motor to 1,5 deg AKO, Pickup rebuilt Hughes bicenter bit. RIH with BHA #8, BHA working electronically, Coil frozen from injector to reel house, RIH to thaw coil. Not pumping while RIH. Holding 700 psi while RIH. Log tie in pass over RA tag. Make -13' correction. Kick on pumps, ice plug is thawed, Drop WHP holding 3500 psi down hole. Run thru window, Shut EDC, RIH to TD. Free spin 2950 psi at 2.52 bpm, whp=100 psi. Had to ream down from 11775' to TD. This was the 3,75" hole from the last run, Resume drilling. 2,57/2.5/3500 psi. IAP=70 psi, OAP=300 psi. Pit vol=301 bbls. ROP=60 fph, Completely different drilling here in the C2, Smoother with fewer stalls, Good weight transfers. Steady 60'/hr w/2k wob ECD=10,84 Ann=3655 FS=2oo0 MW 2-300 Wiper to window. 52k off bottom. 33k normal P/U dwn wt= 8k No problems Drill ahead f/12000', 2.53/2,568,68/8,73 FS=2910 MW=2-400 Pvol=297 OA=420 IA=295 ROP=60-70/hr 2-3k WOB Extended wiper trip to 9000', Sticky off bottom. 36k normal. No problems. Drill ahead f/12148' to 12208', Small communication problem with tools, Reboot and resume drilling, 1:1 returns 60-70'/hr. Continue drilling f/12245' and start mud swap, Old: 2.56/2.50 8.7418.76 FS=2980 MW=3-400 ECD=10,92 Ann=3684 OA=295 IA=325 Wiper trip 34k up wt. Clean up to window, Clean back to bottom. Free spin pressure is 3020 psi at 2,52 bpm, Begin drilling lateral section. 2.53/2.59/3180 psi. ROP=80 fph. Mud swap complete. Pit volume=367 bbls. IAP=160 psi, OAP=220 psi. WHP=1oo psi. BHP=3590 psi. Drilled 6', and had a drilling break, Drilling took off at 150 fph. Wiper trip to shoe. Clean PU off bottom at 35 klbs, Pump 15 bbls of high vis sweep off bottom. Clean back to bottom. Resume drilling lateral section, ROP=140 fph. We appear to be back up agaist that hard streak seen earlier in the well. Trying to drop angle. TF straight down, and well bore incl is building slowly. (Formation dip). We may have to trip for a bigger motor again if it is needed to drop down thru this stuff. Continue drilling with 180 deg tool face, trying to munch our way down thru the hard stuff. ROP intermittant and slow. 11/7/2004 0.17 DRILL P Finally broke thru, and started getting our INC drops, Continue drilling ahead. PROD1 Continue drilling. ROP=130 fph, Below hard streak, and getting good INC response. PROD1 Pump 15 bbls high vis sweep. Make wiper trip. Clean in open 00:00 - 00:10 00:10 - 02:00 1.83 DRILL P Printed: 11/2212004 10:22:51 AM BP Operations Summary Report Page 6 of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-11 1 D-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 10/29/2004 11/20/2004 2 Spud Date: 10/29/2004 End: 11/20/2004 Date From.. To Hours Task Code NPT Phase Description of Operations 11/7/2004 00:10 - 02:00 1.83 DRILL P PROD1 hole on trip up. Open EDC, pump at full rate in tubing. Pulled up to 9500'. Ran back down to window. 02:00 - 02:20 0,33 DRILL P PROD1 Log tie in pass over RA tag, Make +23' correction, 02:20 - 03: 15 0,92 DRILL P PROD1 Continue back to bottom to resume drilling, Ultra clean to bottom. 03:15 - 05:15 2.00 DRILL P PROD1 Resume drilling lateral section. Free spin 3050 psi at 2,52 bpm. Drilling at 2.52/2.51/3300 psi. Pit vol=370 bbls, IAP=380 psi, OAP=355 psi. WHP=100 psi, BHP=3680 psi. ROP=100 fph. 05:15 - 07:05 1.83 DRILL P PROD1 Wiper trip to the window. Minor drag at 12550 and 12600'. 07:05 - 07:45 0.67 DRILL P PROD1 Drill ahead from 12750'. 2.57/2,6 FS=31 00 MW=2-300 8.7/8.7 ECD=11.00 Ann=3724 Pvol=357 07:45 - 08:00 0.25 DRILL P PROD1 Small awiper trip back to 12650', Looks good, 08:00 . 08:50 0.83 DRILL P PROD1 Drill ahead f/12824' 150'/hr wlLS TF having trouble dropping angle. Slow down ROP to 40'/hr. Town group deciding on plan forward if unable to drop angle, 08:50 - 11 :25 2.58 DRILL P PROD1 Wiper trip to window and tie-in +7' correction, Hole in good shape. 11:25-12:30 1.08 DRILL P PROD1 Continue drilling ahead f/12824' with LS TF and controlled ROP at 30'/hr. Unable to drop hole angle, 12:30 - 15:20 2.83 DRILL P PROD1 TOH for higher bend motor and 3-3/4" M-09 bit 15:20 - 15:30 0.17 DRILL P PROD1 PJSM for Pressure Undeployment of BHA #8 15:30 - 16:30 1,00 DRILL P PROD1 Undeploy BHA 16:30 - 16:50 0,33 DRILL P PROD1 Make adjustments to motor. 16:50 - 18:10 1.33 DRILL P PROD1 Pressure deploy BHA #9 18:10 - 19:30 1,33 DRILL P PROD1 RIH with BHA #9, 2.0 deg motor AKO, Smith M09 bit, Full MWD + Resistivity. Follow pressure schedule while RIH. 19:30 - 20:40 1,17 DRILL P PROD1 Log tie in pass over RA tag. Make -18' correction, 20:40 - 21 :35 0,92 DRILL P PROD1 Shut EDC, run in to TD to resume drilling, 21:35 - 23:00 1.42 DRILL Ip PROD1 Resume drilling lateral section. Free spin = 3100 psi at 2,57 bpm. Drilling at 2.56/2.59/3200 psi. IAP=304 psi, OAP=320 psi. Pit vol=310 bbls. BHP=3700 psi. WHP=100 psi. TF=150L. ROP=30 fph. Trying to chomp our way thru the hard stringer. Current near bit Inc=90,5, 23:00 - 23:30 0.50 DRILL P PROD1 Thru the hard streak, and able to get INC's as we need them. NB Inc=86 degrees. Diving down as per plan. 23:30 - 00:00 0.50 DRILL N DFAL PROD1 MWD tool survay package not working. All surveys are out of tolerance. Try surveys with pumps off, no good, Pull up hole to last good survey and repeat, no good. Continue to muck about trying to get things to work. 11/8/2004 00:00-01:15 1.25 DRILL N DFAL PROD1 Continue troubleshooting downhole MWD equipment. The tools appear to be working, but are giving surveys that are out of tolerance. The MWD engineer reports that the NOAA reports that there is a solar flare at the present time, and this can effect their magnatometer, giving spurious readings, He suggests that tripping for a new tool may not fix the problem. Call town engineer to discuss. Decide to drill ahead with INC only, as this is not effected by the magnetic interference. If the tool begins to work, we will do off bottom surveys for the missing data. 225' remaining before TD. 01:15 - 03:10 1.92 DRILL P PROD1 Resume drilling. NB INC=86 deg. Tool face=90L. ROPis variable from 10-80 fph. 03:10 - 04:10 1.00 DRILL P PROD1 Wiper trip to shoe. Clean PU off bottom. Printed: 11/2212004 10:22:51 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11/8/2004 11/9/2004 BP Operations Summary Rep.ort 1 0-11 1 0-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Page 7 of 19 Start: Rig Release: Rig Number: Spud Date: 10/29/2004 End: 11/20/2004 10/29/2004 11/20/2004 2 Date From -To Hours Task Code NPT' Phase Description of Operations 04:10 - 05:25 05:25 - 09:45 09:45 - 10:30 10:30 - 11 :45 11 :45 - 12:10 12:10 - 13:30 13:30 - 15:00 15:00 - 15:15 15:15 - 17:00 17:00 - 18:15 18:15 - 18:30 18:30 - 18:55 18:55 - 20:00 20:00 - 20:30 20:30 - 21 :35 21:35 - 22:15 22:15 - 00:00 00:00 - 00:10 00:10 - 00:25 00:25 - 01 :30 1,25 DRILL P 4,33 DRILL P 0.75 DRILL P 1.25 DRILL P 0.42 DRILL P 1,33 DRILL P 1,50 DRILL P 0.25 DRILL P 1.75 DRILL P 1.25 DRILL P 0.25 DRILL P 0.42 DRILL P 1.08 DRILL P 0.50 DRILL P 1.08 DRILL P 0.67 DRILL P 1.75 DRILL P 0.17 DRILL P 0.25 DRILL P 1.08 DRILL P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PR001 PR001 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Continue wiper trip back in the hole, Set down at 12617', picked up and got thru ok. Set down at 12995', picked up and got thru ok. Clean rest of way to bottom, Resume drilling lateral section, ROP slow and intermittant, 10-80 fph, 2.54/2,58 FS=3050 MW=150 WOB=2,5k rop=8-10'lhr. Drilling break at 13137' Drilling ahead 2.54/2.55 no losses 2k wob 50-60'/hr drilled to 13160'. Wiper trip to window Log tie-in +9' correction. RIH setdown at 13110' Drill ahead f/13160' 2.612.6 FS=3050 MW=250 2k wob 50-60'/hr ECD=11.09 Ann= 3760 Drilled to 13190 rop slowed down to 30-40'lhr. <10'lhr after 13195'. Drill to 13199', Make 200' wiper trip Drill ahead <1 O'lhr rechecking logs and samples looking for zone B. Drill ahead at 13207' pumping hi-vis sweep. I Drilling ahead with very slow ROP in what we expect is the B ¡zone, ROP=O-10 fph. Free spin pressure 2950 psi at 2.3 bpm, i IAP=616 psi, OAP=420 psi. Pit vol=260 bbls, WHP=99 psi. I BHP=3714 psi. INC=87 deg. BHI MWD tools are working correctly, and NOAA confirms that the solar flare that was effecting our MWD tools earlier today has subsided, We will have good survey data for the bottom 225' interval. , Town goo has called TD. Pump 20 bbls high vis sweep, ITD depth 13224'. Sweep to bit. Begin wiper trip. Clean PU off bottom. Slightly ratty at 12970'. Wiper up to 12000', Continue wiper trip to bottom, start new 8.6 ppg flowpro mud down hole. Mud has 6% lubetex and 10 ppb kla-gard. Weight bobble at 13115' on way back in hole. PU, orient to as drilled tool face and got thru it. Clean rest of way to bottom, Surface RIH string weight at TD=4500 Ibs. POOH laying in new mud in open hole. Clean PU off bottom at 39 klbs. Clean up to window. Stop at the window, open the EDC. Circulate bottoms up at max rate to clean the wellbore of cuttings and swap to KWF, Pumping 10.5 ppg KWF. KWF reads 10.27 ppg on in MM meter. Catch a sample and weight it on the mud scale in the pits. It reads 10.495 ppg. POOH pumping at 1.5 bpm, replacing KWF voidage. Paint EOP flags at 10900', and 8900' on way ooH. Note - EOP flags are for a BHA tied in in the Down direction. Continue POH with last drilling BHA. Circulating KWF at 1 bpm. Tag up. Catch a sample of retumed KWF, check weight, and it weighs 10.4 heavy on the mud scale. SO pumps, make no flow check while holding PJSM re: laying down BHA, and picking up liner. Check for flow again. No flow observed. Break injector and stand back. Lay down BHA #9. Bit recovered all balled up on the gauge with clay again. Bit graded 2,2, wear. No chipped Printed: 1112212004 10:22:51 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Page 8 of 19 BP Ø:fi)èrations Summary Report 1 0-11 1 0-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 10/29/2004 Rig Release: 11/20/2004 Rig Number: 2 Spud Date: 10/29/2004 End: 11/20/2004 Date From - To Hours Task Code NPT Phase Description of Operations 11/9/2004 00:25 - 01 :30 01 :30 - 02:00 02:00 - 04:30 04:30 - 05:20 05:20 - 07:00 07:00 - 07:20 , i 07:20 - 08:10 I 08:10 - 09:00 09:00 - 09: 1 0 09:10 - 11 :35 11 :35 - 12:00 12:00 - 12:35 12:35 - 15:05 15:05 - 15:40 15:40 - 15:50 15:50 - 16:20 16:20 - 16:55 16:55 - 19:00 1.08 DRILL P 0,50 RUNCO 2,50 RUNCO 0.83 RUNCO 2.08 RUNCO PROD1 ¡¡cutters, RUNCMP Check fluid level. It is just below stack. Well does not appear I I to be taking any fluid. MUlReconfigure BHI BHA to run liner. RUNCMP i MU 2-7/8" liner BHA for L 1 lateral. BHA as follows: Guide shoe : - 1 solid joint - 0 ring sub - 69 joints predrilled liner - xlo - Baker I Deployment Slv, Overall length of liner = 2013.16', RUNCMP II RIH with liner on coil tubing. MU BHi tools to liner. Stab , injector, RUNCMP I RIH with liner, running tools and BHi tools (2056.33') EDC open I pumping min rate, Stop at 1 st flag 8900' EOP make -28' ! correction, Up wt at window 39k RUNCMP . RIH with liner RIH wt 14.7k @ TOW no indication at window. RIH at 125'/min 11500' 112900wt., >148'/min, 12000' I , 11000#, 12500' I 9800#, at depth 13028' 6500# Pick up to 13018'liner set depth 58k up wt, Get BHi tools in neutral wt RUNCMP Circulate at min rate while BHi trys to close EDC, Okay closed, Pump at 1.5 bpm pressure up to 3300psi pick up 54k SD pump RIH put in compression then pick up with pump on, liner released, up wt 33k. RUNCMP Pick up and log tie-in, -13' correction. RUNCMP RIH tag TOL at 10996'. Good enough. Bottom of 2-7/8" liner at :13009'. RUNCMP iTOH, Will change out BHi's EDC and pick-up the BTT KB ¡ packer assembly, RUNCMP ! UD BTT liner running tools. Change out BHi's EDC. RUNCMP I Make up BHA #11, to set Baker KB liner top packer. RUNCMP . RIH with Baker KB liner top packer, EDC is open. RUNCMP Log tie in pass down at GR spike at 10907'. Make a -17' correction. RUNCMP i Ease down hole. RIH weight = 12700 Ibs, WOB sensor = -370 i Ibs. Weight check just above liner top = 35 klbs. Ease down, 'I' and did not tag anything by 11015'. Nothing indicated on . downhole WOB sensor. Something is wrong. PU clean at 35 ¡ klbs. Need to do another tie in pass. RUNCMP I Log tie in pass again over same GR spike in down direction. ,Pretty much right on depth. Make a correction of +0,5', RUNCMP I Ease in the hole again looking for the liner. WOB sensor = -2001bs, Tagged up on top of liner at 11019' (Locator sub, Bottom of stinger actually at 11026'). WOB sensor =-4000 Ibs, ¡confirming we are on the liner. PU, retag to ensure stinger is in seal assembly. Tagged up again on top of liner at 11019'. Set 2500 Ibs down weight according to WOB sensor. PU to hanging weight, then 2' more. Close EDC. Pressure up to 1800 psi. Stack out on packer. Set down at 11017' with 8 klbs on DHWOB, confirming that the packer is set. Pressure up to 4500 psi to release from tool. PU at 39 klbs. RIH, and tagged up on top of packer. Stack 5000 Ibs on packer. Confirmed set. No go locator is at 11017'. Top of Baker KB liner top packer is 11006.54'. RUNCMP POOH to pick up straddle assembly. Printed: 1112212004 10:22:51 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date BP Operations Summary Report 1 0-11 1 0-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 From - To Hours Task COde NPT Phase 11/9/2004 119:00 - 19:45 119:45 - 21 :00 i I 121 :00 - 23:45 i 23:45 - 00:00 , 11/10/2004 i 00:00 - 00:45 00:45 - 03:00 : 03:00 - 04:00 i i 04:00 - 06:40 i 06:40 - 06:42 ,06:42 - 06:50 i ; 06:50 - 08:50 108:50 - 09:30 I 109:30 - 11:00 I I 111 :00 - 11 :25 11 :25 - 11 :30 11 :30 - 11 :40 11 :40 - 12:30 12:30 - 13:00 13:00 - 13:10 13:10 - 15:45 115:45 - 18:00 18:00 - 00:00 0.75 1,25 2.75 0,25 0.75 2,25 RUNCO 1.00 RUNCO 2.67 STWHIP P 0.03 STWHIP P 0.13 STWHIP P 2.00 STWHIP P 0.67 STWHIP P 1.50 STWHIP P 0.42 STWHIP P 0.08 STWHIP P 0.17 STWHIP P 0.83 STWHIP P 0.50 STWHIP P 0.17 STWHIP P 2.58 STWHIP P 2.25 STWHIP P 6.00 STWHIP P Start: Rig Release: Rig Number: Spud Date: 10/29/2004 End: 11/20/2004 10/29/2004 11/20/2004 2 Description RUNCMP At surface. Get off well. Unstab coil. LD Baker packer setting tool. RUNCMP MU 2-7/8" straddle assembly with Weatherford 4-1/2" KS packer assembly and Baker seal assembly, Drift same. MU Inteq MWD tools and scribe to whipstock setting lug on KS packer. Stab coil. Get on well. RUNCMP RIH. Tie into EOP flag at 11800'. Subtract 16' correction. 39k# up, 11 k# dn wt, RUNCMP Log gr tie in to verify depth. Log from 10810'. Add l' correction, RUNCMP RIH. Slow to 5 fpm at 11000'. Bottom out locator on KB packer at 11013', Set 4k# dn wt. PU to 39k# and l' additional foot for space out, with btm of seal assembly at 1109.5'. Close EDC, Circulate down coil to pressure set packer. Pressure to 4700 psi. Shut in pump, Pressure dropped 200-300 psi, now able to circulate. Hold circ rate & 4300 psi for 10 minutes. Set down 3K, PU and shear off of packer at 40k# up wt. RUNCMP RUNCMP WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Straddle assy length: 57,3', Top of Weatherford 4-1/2" KS packer: 10954, Locator lug oriented to 165 R. Pull out of hole, Fill hole through EDC, At surface, Get off well, LD packer setting tools. MU whipstock tray on running tool BHA. RIH with whipstock, Tie in to flag (-20 correction) RIH to set WS tray RIW 13.4k set down @ 10952' & stack out 2' 3.5k down PU and sheared out @ 44k WS Tray set at 15 deg L, POOH filing hole down coil Top of whipstock tray is 10941.6'. Face of WS tray is oriented 15 L. At surface shut down pump and perform no-flow test No flow test good. LD & LO Weatherford WS Tray Running Tools Perform Slack Management (14 runs on this CTC), Cut off CTC & secure wire, back pump, MU Hydraulic cutter & cut pipe (cut 26') RD cutter & Circ coil over bung hole. Test wire (tested @ 59.6 ohms) MU Dimple Connector PT CTC to 35k, good test. Circulate coil at ,5 bbls/min to keep from freezing MU BHI Upper Quick Connect MU Window Milling BHA PT coil connector & upper QC to 4k MU Coil to BHA and RIH Tag top of whipstock at 10963'. Make -21.4' correction to get on depth to top of WS/Pinch point. Begin milling window. Start used 8.6 ppg mud down hole. Swapping out 10.5 ppg KWF. Free spin = 3750 psi, IAP=105 psi, OAP=370 psi. Milling at 6 min/0.1', getting good drill offs each tenth. Mill ahead at 1 fph. 3700 psi @ 2.8 in/2.8 out fs. 100-300 dpsi. WHP/BHP/ECD: 5513650/10.91. PVT: 265 bbl. Continue to time mill. No stalls, good weight transfer. Mill to Printed: 11/2212004 10:22:51 þJJo Page 10 of 19 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-ll 1 D-ll REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 1 0/29/2004 Rig Release: 11/20/2004 Rig Number: 2 Spud Date: 10/29/2004 End: 11/20/2004 Date From - To Hours Task Code Description of Operations Top of window & ws: 10941,6 Btm window: 10948, Continue time milling window/formation to 10952', Lots of metal on magnets. Mill formation to 10959, Verify lots of sand in btms up sample. Ream and back ream window at 0.5 fpm, Dry drift down. Window smooth. POOH as per pressure schedule, Open EDC, Paint EOP flag at 10800. Continue out of hole, At surface. Standby for crewchange, PJSM re: undeploy/deploy BHA, Trap 700 psi on well, Undeploy BHA #13, Had good center wear on the mill. Both mills gauged 3,80 go, 3.79' no-go. Reconfigure BH assembly for drilling build section, PU and deploy BHA with Smith M09, and 2.4 deg BHI mud motor. No RES in this BHA. We will pick it up on lateral BHA. RIH with BHA #14, Log tie in pass down over K10 marker at 10736'. Make a -24' correction. RIH thru the window slick, Free spin = 3100 psi at 2.61 bpm. BHP=3750 psi with 0 psi on surface choke, (New mud). Tag bottom at 10956'. Begin drilling at 2,66/2.67/3300 psi. ROP=30 fph. PROD2 Well is landed at 6494,5' TVD and 11060' MD. PU to window, open EDC. Make MAD pass over GR spike at 10905' and RA tag. Corrected depths of window are; Top of window=10938,6' Bottom of Window=10945,O' RA tag=10940.8', POOH to pick up lateral section BHA. Follow pressure schedule. At surface. Maintain 800 psi WHP, Hold PJSM to review un-deploy procedure, Un-deploy build assembly. WHP bled down to 600 psi before shutting in master. MU resistivity tool to Inteq BHA. Test same. 1,2 extreme mtr with HTC bicenter bit & resistivity. Pressure deploy BHA. Found 453 psi WHP after opening master valve. Run in hole. Maintain WHP as per pressure schedule. Continue to RIH with lateral drilling assembly. Log gr tie in from 10950'. Subtract -26' correction. RIH to get on depth for mad pass, Several set downs in build section. Tag up several times at 11020. Make several ream passes down. Finally work to 11060'. Back ream to window to condition hole. Hold TF to high side. 2650 psi @ 2.2.in/2.2 out fs. WHP/BHP/EDC: 250/3650/10.9, Hole cleaned up after two up/down passes. PROD2 Log mad pass up from TD for reistivity data. 150 fph logging speed. 11/10/2004 18:00-00:00 6,00 STWHIP P WEXIT 11/11/2004 00:00 - 00:45 0,75 STWHIP P WEXIT 00:45 - 02: 15 1,50 STWHIP P WEXIT 02:15 - 03:30 1,25 STWHIP P WEXIT 03:30 - 05:45 2,25 STWHIP P WEXIT 05:45 - 06:00 0,25 STWHIP P WEXIT 06:00 - 06:20 0,33 STWHIP P WEXIT 06:20 - 08:15 1,92 STWHIP P WEXIT 08:15 - 10:15 2,00 DRILL P PROD2 10:15-12:10 1,92 DRILL P PROD2 12:10 - 12:35 0.42 DRILL P PROD2 12:35 - 16:15 DRILL P PROD2 16:15 - 17:00 0.75 DRILL P 17:00 - 18:30 1.50 DRILL P PROD2 18:30 - 20:00 1.50 DRILL P PROD2 20:00 - 21 :00 1.00 DRILL P PROD2 21 :00 - 23:15 2,25 DRILL P PROD2 23:15 - 00:00 0,75 DRILL P PROD2 11/1212004 00:00 - 01 :15 1,25 DRILL P PROD2 01:15 - 01 :30 0,25 DRILL P PROD2 01 :30 - 02:30 1,00 DRILL P PROD2 02:30 - 03:15 0.75 DRILL P 10949'. Printed: t 1/2212004 10:22:51 AM BP Operations Summary Ref)ort Page 11 of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-11 1 0-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 10/29/2004 Rig Release: 11/20/2004 Rig Number: 2 Spud Date: 10/29/2004 End: 11/20/2004 Date From -To Hours Task Code NPT Phase Description of Operations 11112/2004 03:15 - 03:30 0.25 DRILL P PROD2 Re-Iog gr tie in due to 6' change during clean out/logging pass, Add 4' correction, 03:30 - 05:20 1.83 DRILL P PROD2 Drill ahead from 11060, 3200 psi @ 2,52 in/2,59 out fs, 100 dpsi. WOB: 1-2k#. ROP: 100-120 fph, TF: 75L. WHPIBHP/ECD: 44/3510/10.42. IA:11 psi OA: 334 psi. PVT: 393 bbls. 05:20 - 05:40 0,33 DRILL P PROD2 Wiper trip to window 05:40 - 08:00 2,33 DRILL P PROD2 Drill ahead. Plan to drop TVD by 6', Pit vol=393 bbls. IAP=120 psi, OAP=398 bbls. Free spin = 2900 psi at 2,5 bpm. Drilling ahead at 2.53/2.55/3100 psi. BHP=3550 psi. ROP=100 fph. 08:00 - 08:25 0.42 DRILL P PROD2 Wiper trip to the window. Clean PU off bottom at 39 klbs, and clean to the window. 08:25 - 09:20 0,92 DRILL P PROD2 Log MAD pass for resistivity data in build section in down direction. 09:20 - 09:35 0,25 DRILL P PROD2 Continue back to bottom, 09:35 - 11 :25 1.83 DRILL P PROD2 Resume drilling. 2.612.6/3190 psi. TF=90R, ROP=130 fph, BHP=35oo psi. Pit vol=386 bbls, 11 :25 - 12:00 0,58 DRILL P PROD2 Wiper trip to window. Clean PU off bottom at 37000 Ibs, 12:00 - 13:35 1.58 DRILL P PROD2 Resume drilling. 2.612,6/3500 psi. Pit vol=383 bbls. BHP=3590 psi. IAP=290 psi, OAP=450 psi. ROP=150 fph, 13:35 - 15:20 1.75 DRILL P PROD2 Long wiper to 9500'. Pump 15 bbls of high vis sweep, Clean off bottom at 39 klbs. Clean in open hole to the window, Open the EDC, clean up to 9500', RIH to window. Shut EDC, Run back to bottom clean, High vis sweep really unloaded alot of cuttings when it got to surface. We need to continue an occasional long wiper trip with high vis sweep to keep the hole clean. 15:20 - 18:00 2.67 DRILL P PROD2 Resume drilling lateral section. 2.58/2.64/3220 psi. ROP=120 fph. BHA=3611 psi. ECD=10,76 ppg. IAP=350,OAP=450 psi. Pit Vol=368 bbls. (Lost some mud off the end of the shaker when we got that last sweep back.) 18:00 - 19:30 1.50 DRILL P PROD2 Wiper trip to window (10960), Pump hi-vis sweep around. 37k# up, 11 k# dn wt. Hole smooth. Monitor sweep rlns, 19:30 - 22:45 3.25 DRILL P PROD2 Drill ahead. 3250 psi @ 2.5 in/2.5 out fs. 250-450 dpsi. WOB: 3-4k#. ROP: 10-100 fph (hard spots). WHP/BHP/ECD: 5113700110.7 ppg. IAlOA: 396/450 psi. PVT: 330 bbls, Continue to climb at 96.7 deg inc, Tf: 45L to 165L. Erratic drilling. Numerous stalls. 22:45 - 23:45 1.00 DRILL P PROD2 Wiper trip to window. Circ 10 bbls hi-vis sweep, Hole smooth while pulling out. 23:45 - 00:00 0,25 DRILL P PROD2 Log gr tie in. Subtract 6' correction, 11/13/2004 00:00 - 01:00 1.00 DRILL P PROD2 Complete wiper trip. Hole smooth in and out. Sweep brought a lot of solids to surface. 01 :00 - 02:30 1.50 DRILL P PROD2 Drill ahead. 3400 psi @ 2.63 in/2.50 out fs. 200-300 dpsi. WOB: 3-4K# ROP: 10 fph. WHP/BHP/ECD: 4013640110.88 PVT: 228. TF: 165R. Drilling very slOw. Bit may be worn out. Good WOB, but not much motor work. Losing 0.15 bpm to formation. Begin to level out climb. ROP dropped to zero. Begin displacement to new mud system. 02:30 - 03:15 0.75 DRILL P PROD2 Wiper trip to window while displacing to new mud. 03:15 - 04:45 1.50 DRILL P PROD2 At window. Open EDC. Circulate OQH holding WHP as per schedule. Printed: 11/2212004 10:22:51 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date Page 12 of 19 BP Operations Summary Report 1 0-11 1 0-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 From - To Hours Task Code NPT Phase 11/13/2004 04:45 - 05:00 0.25 DRILL P 05:00 - 06:00 1.00 DRILL P 06:00 - 06:15 0,25 DRILL P 06:15 - 07:00 0.75 DRILL P 07:00 - 11 :00 11 :00 - 11 :40 PROD2 PROD2 PROD2 I PROD2 4.00 BOPSU P PROD2 0.67 BOPSU P PROD2 11:40 -13:15 1.58 DRILL P PROD2 13:15 - 15:15 2.00 DRILL P PROD2 15:15 - 15:45 0.50 DRILL P PROD2 15:45 - 16:20 0.58 DRILL P PROD2 16:20 - 17:30 1.17 DRILL P PROD2 17:30 - 20:00 2.50 DRILL P PROD2 20:00 - 22:30 2.50 DRILL N DPRB PROD2 22:30 - 22:45 0.25 DRILL N DPRB PROD2 22:45 - 00:00 1.25 DRILL N DPRB PROD2 11/14/2004 00:00 - 00:30 0.50 STKOH N DPRB PROD2 00:30 - 01 :30 1.00 STKOH N DPRB PROD2 01 :30 - 02:30 1.00 STKOH N DPRB PROD2 02:30 - 05:00 2.50 STKOH N DPRB PROD2 05:00 - 05:15 0.25 STKOH N DPRB PROD2 05:15 - 06:15 1.00 STKOH N DPRB PROD2 06:15 - 17:15 11.00 STKOH N DPRB PROD2 07:15 - 08:30 1.25 STKOH N DPRB PROD2 Start: 10/29/2004 Rig Release: 11/20/2004 Rig Number: 2 Spud Date: 10/29/2004 End: 11/20/2004 , , Description of Operations Hold PJSM to review un-deploy procedure. Un-deploy lateral BHA. Safety meeting for crew change and prior to resuming undeploying BHA. Continue to undeploy BHA #16. Geologist reports lots of siderite in cuttings. Bit recovered graded 2,2 in gauge. It looked like it should still drill fine. The bit was not balled up with clay when recovered. Perform Bi weekly BOP test. Witness of the test waived by AOGCC, Chuck Sheve. Weekly safety drill. Fire drill and Rig Evacuation to muster area. Good response to announcement of rig evacuation on the radio and squawk box. 100% participation. Discussion at the muster area to review proper proceedures and response to an actual incident. Tool box discussion about BHA deployment, then Deploy BHA #17. Hycalog DS49 bit with full Tuff Edge cutters, 1,2 degree motor, MWD tool with RES. RIH with BHA #17. Log tie in pass over RA tag in whipstock. Make a -26' correction. Run thru window. Shut EDC. Run to bottom. No problems RIH, clean hole all the way. Free spin pressure with new mud = 3680 psi at 2,44 bpm, IAP=14 psi, OAP=320 psi. BHP=3806 psi. ECD=11.36 ppg, Tag bottom at 12008'. Begin drilling at 2.44/2.18/3850, Slow ROP in ratty stuff. Drill ahead, 3700 psi @ 2.49 in/2.28 out. 200-400 dpsi. WOB: 3-5K#. ROP: 20-120 fph. WHP/BHP/ECD:40/3790/11 ,3, PVT: 273 bbls TF:135R. Continue to break build to start down trend. Drill ahead, but not dropping any angle. Geo reports we are into 0 interval. Discuss with town. Will need to sidetrack. Wiper trip toward window. Pump hi-vis sweep. Open EDC at window. Circ out of hole at 2.5 bpm, Bump up and set BHA at un-deploy depth. Leave 900 psi on well. Shut rams. Hold PJSM in ops cab with crew. Discuss un-deploy procedure, Un-deploy lateral BHA. Continue to un-deploy lateral BHA. Re-configure MWD tool string. Remove resistivity tool. Change out orienter. Test tools. Pressure deploy sidetrack BHA WHP bled down to 305 psi from 900 psi. RIH following pressure schedule. Log gr tie in from 10950. Subtract 25'. RIH to begin sidetracking at depth discussed with town, 10915'. Make first down reaming pass from 11900'-11915', TF=140R, at 15 fph. Pit vol=416 bbls@06:15. IAP=11 psi, OAP=314 psi. BHP=3806 psi. Choke is open. ECD=11.34 ppg. Pump pressure is 3713 psi at 2.55 bpm. Reaming at 2.55/2,32/3713 psi. We appear to be losing mud at about 15 bbllhr. Downhole WOB=800 Ibs. RIH CT weight=7700 Ibs. Make second down reaming pass from 11900'-11915'. Pit Printed: 1112212004 10:22:51 AM Page 13 of 19 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-11 1 0-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To HOl.II'S Task Code NPT Phase 11/14/2004 07:15 - 08:30 1.25 STKOH N DPRB PROD2 08:30 - 09:00 0.50 STKOH N DPRB I PROD2 09:00 - 10:00 1,00 STKOH N DPRB PROD2 10:00 - 11 :00 1.00 STKOH N DPRB PROD2 11 :00 - 12:00 1.00 STKOH N DPRB PROD2 12:00 - 13:00 1.00 STKOH N DPRB PROD2 13:00 - 13:25 0.42 STKOH N DPRB PROD2 I 13:25 - 13:55 0.50 STKOH N DPRB PROD2 13:55 - 16:20 2.42 STKOH N DPRB PROD2 16:20 - 16:35 0.25 STKOH N DPRB PROD2 16:35 - 18:00 1.42 STKOH N DPRB PROD2 18:00 - 18:30 0.50 STKOH N DPRB PROD2 18:30 - 19:30 1.00 STKOH N DPRB PROD2 19:30 - 20:45 1.25 STKOH N DPRB PROD2 20:45 - 22:45 2.00 STKOH N DPRB PROD2 22:45 - 23:00 0.25 STKOH N PROD2 23:00 - 00:00 1.00 STKOH N PROD2 11/15/2004 00:00 - 02:15 2.25 STKOH N STUC PROD2 Start: 1 0/29/2004 Rig Release: 11/20/2004 Rig Number: 2 Spud Date: 10/29/2004 End: 11/20/2004 Description of Operations volume at 07:15=401 bbls. Still losing 15 bbl/hr. Downhole WOB = -570 Ibs. RIH CT weight=88oo Ibs. Less motor work and downhole WOB on this down pass. May have established the trough on the first down pass, Stop at 11915', Stationary drill for 1/2 hour. Free spin=3615 psi (New mud, lower LSRV), Pit vol=380 bbls. We have lost 36 bbls in the last 2:15 hrs, about 15 bbls/hr. Drill at 1fph. Drill at 2 fph Drill at 3 fph. Starting to see some weight on DHWOB (600 lbS)' Attempt to drill ahead. Stacking weight, with no increase on ! DHWOB, PU, Drop pump rate to 3/4 bpm. RIH, Motor work land WOB to 3500 Ibs at 11916'. We have a lip at 11916', and I it apears that we are not getting good weight transfer at low I ROP, (Note a new, reconditioned mud system with 5% lubetx I is in the hole now), PU, kick on pumps to full rate. RIH. TF=160R. RIH at 150 fph from 11910'. Free spin 3520 psi at 12.5 bpm. Stop at 11916.8' when we got a little motor work. Begin drilling at 15 fph. Getting stick/slip with the BHA. Very I apparent from string weight and DHWOB sensor. ¡Got 1700 Ibs DHWOB, and 3620 Ibs on coil pressure, Looks ¡like we have a sidetrack. Continue at 20 fph. Roll TF around to 90R, ROP to 40 fph, Pit vol = 346 bbls. (Added an additional 60 I bbls), NB INC down to 87 degrees. Confirmed sidetracked. II· Sidetrack completed, POOH for lateral section BHA. Clean PU off of bottom. Clean in open hole to the window. POOH in ,cased hole following the pressure schedule. , Safety meeting re: undeploy BHA. Discuss proceedure step by step, Pressure undeploy BHA #18, sidetrack BHA. Hold PJSM with crew. Review and discuss procedure. Assign rig floor tasks, MU and test Inteq tools with resistivity added to string, Pressure deploy lateral BHA #19 (1.2 mtr wI resist & HTC bi-center). WHP: 240 psi. RIH following pressure schedule. Log gr tie from 10950'. Subtract 24 foot correction. Close EDC. Wiper trip to TD. Maintain TF as drilled while RIH, Weight check while orienting to 145R. 40k# up, 11k# dn. RIH, Circ at 0,75 bpm. Set down at 11928. PU. Pipe stuck. Bit stalled. Able to circulate ok. Check R60 ST sidetrack bit. It is iust slightly undergauge.(2.745') Order 50 bbls slick diesel to location. Down hole WOB active through full range while cycling pipe (-7k to + 1 Ok), Able to orient from stop to stop ok. Strong indications we are bit stuck. Pull and push max (-6k# to + 80k#). Rest hole. Pressure up back side and pull. No effect. Try pressuring up backside to 1500 psi and pulling max, several times. No effect. Printed: 1112212004 10:22:51 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Page 14 of 19 BP Qperations Summary Report Start: 10/29/2004 Rig Release: 11/20/2004 Rig Number: 2 Phase 1 1 0-11 1 0-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 11/15/2004 00:00 - 02: 15 Date From - To Hours Task Code NPT STUC PROD2 2,25 STKOH N 02:15 - 02:30 0.25 STKOH N STUC PROD2 02:30 - 07:00 4.50 STKOH N WAIT PROD2 07:00 - 07:45 0.75 STKOH N WAIT PROD2 07:45 - 11 :00 11 :00 - 11 :45 11 :45 - 12:10 12:10- 12:30 12:30 - 13:00 13:00 - 13:10 13:10 - 17:30 17:30 - 18:45 3.25 STKOH N 0.75 STKOH N WAIT PROD2 WAIT PROD2 0.42 STKOH N WAIT PROD2 0,33 DRILL N WAIT PROD2 0.50 DRILL N 0.17 DRilL P WAIT PROD2 PROD2 4.33 DRILL P PROD2 1.25 DRILL P PROD2 Spud Date: 10/29/2004 End: 11/20/2004 Description of Operations Open EDC to circulate at max rate. Circulate at 2.6 bpm @ 3400 psi. 2,1 bpm out. Pull 80K. Circulate btms up while waiting on diesel. I· Hold PJSM to discuss circulating diesel. Pull to 81 K, BHA came free, Kuparuk in Phase 3 conditions, POOH to casing. Circulate at min rate while holding whp. Crew change and safety meeting to disucus plan forward in Phase 3 conditions. The rig hands are instructed to only do activities to keep the operation safe, warm, and lighted. All other non critical tasks are to be defered until the weather ! moderates, The current wind speed is 40 mph gusting to 55 I mph, There is 205 bbls of mud in the pits, with another 290 bbls on a vac truck on location. Wait on weather, dry watching rig. Kuparuk Security announces the weather condition is now PHase 2 in the CPF1 operating area, with Phase 3 on the drillsites. Contact the CPF1 Lead Tech, the Lead Wells Supervisor - Brian O'Dell, and the BP Drilling HSE Advisor. Discuss the situation. It is within BP and CPAl's operating policy that as long as the pad is kept clear with the rig forklift, i the rig may resume normal operations for Phase 2 weather conditions, Hold hazard assessment with BP Co rep, SWS team leader, Nordic Toolpusher. Discuss hazards and mitigations to hazards. Discuss Phase change with crew, and plan forward. We will resume normal Phase 2 operations. However, no permited work will be attempted. (i.e. No hot work, confined space entry, etc,) Note fluid loss rate to formation at a pump rate of 0.5 bpm was 5 bph, Log tie in pass over RA tag in whipstock at 10941'. Make a +8' correction, RIH to resume drilling, RIH clean in open hole. Free spin pressure = 3750 psi at 2.64 bpm. BHP=3794 psi, 11.29 ECD. 2.64/2.52 bpm. Losing fluid still. Pit vol=183 bbls with 290 bbls on a vac truck next to the rig. RIH slow thru sidetrack interval. RIH string weight=93oo Ibs. RIH WOB=6oo Ibs. Didn't see any set downs or motor work in sidetrack interval. Tag up within l' of where bottom was left on the sidetrack at 11956'. Resume drilling lateral section of hole. Catch a bottoms up sample of when we first tagged to see if there are any brass cuttings in the sample, Geologist reports 1 small fleck of brass in sample. Draw your own conclusions. IAP=130 psi, OAP=400 psi. BHP=3697 psi. ECD=11.03 ppg. Pit vol=401 bbls. Wiper trip to shoe. Clean PU off bottom. Hole smooth in both directions. Printed: 11122/2004 10:22:51 AM 1 0-11 1 0-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 From - To I Hours Task Code 18:45 - 22:0-;¡- 3,25 DRILL P I ! Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/15/2004 22:00 - 23:30 23:30 - 00:00 11/16/2004 00:00 - 01:45 BP Operations Summary Report Page 15 of 19 Start: 10/29/2004 Rig Release: 11/20/2004 Rig Number: 2 Spud Date: 10/29/2004 End: 11/20/2004 Description of Operations 1,50 I DRILL P 0,50 DRILL P 1,75 DRILL P PROD2 Drill ahead, 3480 psi @ 2,54 in/2.50 out. 200-400 dpsi. INCUAZ: 88,8/96,2 WOB: 2-4K#. ROP: 3()..90 fph. WHP/BHP/EDC: 4813730/11,13, IA/OA/ PVT: 190/416/382 bbls, Variable drilling due to alternating soft intervals and hard spots, Good weight transfer. PROD2 Wiper trip to 10960', Circulate 10 bbl hi-vis sweep. Hole very smooth, both directions, Sidetrack area also very smooth. PROD2 Drill ahead to 12310', PROD2 Drill ahead, 3550 psi @ 2,61 in/2.40 out. 200-400 dpsi. INC/AZ: 89,2/78.6 WOB: 0.5-1,5K#. ROP: 30-90 fph. WHP/BHP/EDC: 4013766/11,17, IA/OA/ PVT: 304/452/275 bbls. 101 :45 - 03:30 1,75 DRILL P PROD2 03:30 - 03:45 0,25 DRILL P PROD2 03:45 - 04:15 0,50 DRILL P PROD2 04:15 - 05:15 1.00 DRILL P PROD2 05:15 - 06:30 06:30 - 08:30 08:30 - 10:15 I I 10:15 - 12:00 ¡ 12:00 - 14:50 1,25 DRILL P Driving conditions improved to Phase 1 Wiper trip to window, Pump 10 bbls hi-vis sweep. Trip to 9500'. RIH. Log gr tie in. Add 8' correction, Continue wiper trip to TD, Hole very smooth in both directions. Drill ahead, 3600 psi @ 2,61 in/2.40 out. 200-400 dpsi. INC/AZ: 88.3/90,7 WOB: 2-3.5K#. ROP: 80-100 fph. WHP/BHP/EDC: 44/3786111,28, PVT: 249 bbls. Continue to hold 88-89 deg inc, PROD2 100% losses at 12565', Continue drilling ahead to generate cuttings to stop losses, 220 bbls in the pits. 290 bbls on a vac truck next to the rig. Call for 2 more vac trucks of new mud, and send to MI plant in Deadhorse ASAP. PROD2 Wiper trip to the window, 40 klbs PU off bottom. Clean. PROD2 Resume drilling, Free spin 3700 psi at 2.7 bpm. Drilling at 2.7/2.2/3827 psi. Losses much better. Only losing about 30 bbllhr. IAP=230 psi, OAP=400 psi. BHP=3690 psi. 2 Vac trucks are in route from MI. PROD2 Wiper trip to the window. PU was 40 klbs off bottom. Clean up to the window, and no problems at the OH sidetrack, PROD2 Drill ahead, 3450 psi @ 2,53 in/2.15 out. 300-400 dpsi. Inc/Az: 88.7/97.9 WOB: 2-3,5K#. ROP: 8()..100 fph. WHP/BHP/EDC: 44/3715111,05. PVT: 249 bbls. Continue to hold 87-88 deg inc, 2,00 DRILL P 1.75 DRILL P 1,75 DRILL P 2,83 DRILL P Lost 95% rtns at 12860', Continue to drill ahead. Returns slowty increasing, Assume we are filling loss zone with fluid and/or cuttings, Two full vac trucks with new mud on location. Make frequent wiper trips past loss zone to help minimize local cuttings build up, Wiper trip to 9000'. Pump hi-vis sweep from btm. POOH at 28 fpm. Pull through window at min rate. Pump 2nd hi-vis sweep from 9000', Open EDC. Log gr tie in. Add 7' correction. Continue wiper trip to bottom, Drill ahead from tag at 12905' 2.5/1.94/3300/1 OOL wI open choke at 3668 psi DHP, 10.88 ECD wI slow initial progress. Drilled into another rubble zone (based on MW) at 12930' and started losing 2.0 bprn. PUH w/12k overpull. RBIH and resume drilling 2.310.313000 ECD 10.27 and started losing 14:50 - 17:10 2.33 DRILL P PROD2 17:10 - 17:40 0.50 DRILL P PROD2 17:40 - 18:40 1.00 DRILL P PROD2 18:40 - 20:50 2.17 DRILL P PROD2 Printed: 11122/2004 10:22:51 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BP Operations Summary Report Page 16 of 19 1 D-11 1 D-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 10/29/2004 Rig Release: 11/20/2004 Rig Number: 2 Spud Date: 10/29/2004 End: 11/20/2004 Date From - To Hours Task Code NPT Pha.se 11/16/2004 18:40 - 20:50 2.17 DRILL P PROD2 20:50 - 22:50 22:50 - 23:40 23:40 - 00:00 11/17/2004 00:00 - 00:45 00:45 - 01:15 01:15-03:45, 03:45 - 08:00 08:00 - 10:30 10:30 - 10:451 10:45 - 12:15 12:15 - 19:10 19:10-21:00 21 :00 - 22:45 Description of Operations 2,001 DRILL P 0,83 DRILL P angle at 11 OL. Push on it at LS TF to get back to plan and penetration rate increased to 1 OO'/hr while returns improved to 2.67/1.22/3400 10,57 ECD, Drill to 13050', pump 10 bbls sweep PROD2 Wiper to window, clean both ways PROD2 Drill ahead from tag at 13050' 2,5/1,35/3300/120L wI open choke at 3576 psi DHP, 10,64 ECD at 100'/hr to 13130' and progress slowed to zero PROD2 Drill from 13130' w/-10k surface wt, 2k wob with very slow progress PROD2 Continue drilling in a shale (may be C4/C3 interface) PROD2 Drill ahead in sand 2,53/1.47/3220/130L wI open choke at 3591 psi DHP, 10.68 ECD at 100'/hr at 88 deg to 13200' PROD2 Wiper to window was clean except for setdown and stall at 12850' wI correct TF Resistivity shows major loss zones clearly at 12565', 12845' and 12930' and also indicates minor loss zones at 11810', 11885' and 12300' where minor MW and wt loss occurred PROD2 Drill ahead from tag at 13201' 2.54/1,64/3300/120L wI open choke at 3583 psi DHP, 10,66 ECD at 1 OO'lhr at 87 deg. Swap to right at 13250' and stacking due to TF change PROD2 Wiper trip to 9000'. Pump hi-vis sweep at 12300 and 9000. Note lots of "extra" cuttings in sweeps, Seem to be helping, but not sure how much is being left behind in tangent section, PROD2 Open ECD. Log gr tie in. Add 7' correction. PROD2 Continue wiper trip to bottom, Hole continues to be very smooth in and out. PROD2 Drill ahead from 13308'. 2950 psi@ 2.54 in/2.20 out fs. 20D-400 dpsi. WOB: 3,5-4,5k#. ROP: variable due to hard spots. InclAz: 86.3/83,1, WHP/BHP/ECD: 33/3496/10.38. IAlOAlPVT: -2/337/345 bbls. Finally broke through hard spot at 13018, ROP up to 100 fph with several stalls. Bit is likely still ok, Continue holding 85-86 deg inc to continue drilling down through section. Swap to left at 13440', drill to 13450' 2,5/2,0, but P rate is too slow for last 150' drilled. Pump 20 bbl sweep PROD2 Wiper to window at 2,7 bpm-a little tite first 50' due to TF change PROD2 POOH to check BHA following modified pressure schedule (based on retums) at 2.8 bpm-minimal 'extra' solids seen at shaker. Tag up wI 2.78/2,6/3450 wI 320 psi bp. Trap 500 psi and shut rams Pressure undeploy wI 327 psi Fin undeployand LD drilling assy, Bit was starting to ring on nose and had chipped and worn cutters 3-3-1 Changeout BHA components MU new Hycalog bi bit on fresh 1,2 deg BHI motor and pressure deploy MWD assy wI resistivity with 308 psi on well RIH wI BHA #20 while circ thru EDC @ 0.6/1200 holding 300 psibp Log tie-in down from 10950', corr -26' Continue wiper trip to bottom. Hole very smooth in both directions. 0,33 DRILL P 0,75 DRILL 0,50 I DRILL 2.50 ¡DRILL , I i i 4,251 DRILL 2,501 DRILL Ip P P P P ¡ 0,251 DRILL P 1,50 ¡DRILL P 6,92 DRILL P 1.83 DRILL P 1.75 DRILL P 22:45 - 00:00 1.25 DRILL P PROD2 11/18/2004 00:00 - 00:45 0.75 DRILL P PROD2 00:45 - 02:00 1.25 DRILL P PROD2 02:00 - 03:15 1.25 ORILL P PROD2 03:15 - 05:15 2,00 DRILL P PROD2 05:15 - 05:30 0.25 DRILL P PROD2 05:30 - 07:00 1,50 DRILL P PROD2 Printed: 1112212004 10:22:51 AM BP Operations Summary Report Page 17 of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-11 1 D-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 10/29/2004 Rig Release: 11/20/2004 Rig Number: 2 Spud Date: 10/29/2004 End: 11/20/2004 Date From - To Hours Task Code NPT Description of Operations 11/18/2004 07:00 - 09:30 2,50 DRILL P PROD2 Drill ahead from 13449'. 3100 psi@ 2.60 in/2.00 out fs. 200-400 dpsi. WOB: 1.0-2.0k#, ROP: variable due to hard spots. InclAz: 86.3/98,2. WHP/BHP/ECD: 33/3560110.57. I IAJOAJPVT: 62/360/182 bbls, I Drill ahead through alternating hard & soft streaks, Take on I fresh mud to replace losses to formation, Hycalog bit 3.00 I DRILL penetrating hard spots quite well, but having trouble dropping angle with this BHA. 09:30 - 12:30 P PROD2 Wiper trip to window. Pump 10 bbl hi-vis sweep, Hole I continues to be smooth, except for a set down while RIH at i 13482'. Worked through and back reamed same. I 12:30 - 16:45 4,251 DRILL P PROD2 Drill ahead from 13600'. 3150 psi@ 2,55 in/2,1 out fs, 200-400 dpsi. WOB: 1.0-3,Ok#, ROP: variable due to hard spots. InclAz: 88.3/98,3. WHP/BHP/ECD: 3713689/10.62. IAJOAJPVT: 149/388/302 bbls. I Continue trying to drop angle, TF low side, but BHA not 1,501 DRILL dropping much. Finally get down to 85 deg at 13670'. 16:45 - 18:15 P PROD2 Wiper trip to window. Pump 10 bbl hi-vis sweep, BHI tools quit I about 500' oft TD. Continue wiper to window, clean 18:15 - 19:40 1.421 DRILL N DFAL PROD2 Park at 10918' and circ thru bit 2,0/1.92/2320,0.610,53/1400 wI 200 psi bp while check BHI connectors at reel PVT 381, Reel connectors okay, so assume a tool short in hole. Confirm plan ahead and will call this TD (13750'/6525' TVD in C3), Flag CT. Order vac trucks for KWF/returns and release 2 full trucks wI 8.6# fresh mud 19:40 - 21:15 1,581 DRILL N WAIT PROD2 Wiper at 30'/min to 8000' at 2,8/2,5/3340 while pump 39 bbl hi vis sweep and while wo vac trucks 21:15 - 23:45 2,50 ¡ DRILL N WAIT PROD2 RBIH wI vac trucks on location, start moving fluids out/in. Find , that the 10.5 ppg KWF is really 10,3 ppg which should still give 0.251 DRILL 100 psi OB 23:45 - 00:00 P PROD2 Begin displacement to 10.3 ppg used mud while fin RIH to window 11/19/2004 00:00 - 00:20 0,33 DRILL P PROD2 Fin displ mud in CT while RIH to 10920' 00:20 - 02:30 2,171 DRILL P PROD2 POOH from window displacing 8.6# mud to 10,3# used Formate based FloPro at 2.0 bpm, Lost 90 bbls on trip. Chk for flow-none, PVT 216 02:30 - 03: 15 0.75 DRILL P PROD2 LD drilling BHA. Found short at UQC, LQC and somewhere in tool. Fill hole and check loss rate at 15 bph PVT 203 03:15 - 04:45 1.50 RUNCMP SI at swab to find short in MWD tool string (and put together a working version) before running liner, Found short at DBV. Check e-line and determine okay. Set injector on legs Mobilize MI to build additional 1 0,2 ppg mud 04:45 - 05:00 0,25 RUNCO RUNCMP RU to run liner 05:00 - 05:15 0.25 RUNCO RUNCMP Safety mtg re: run liner 05:15 - 06:00 0,75 RUNCO RUNCMP Open swab. Fill hole wI 7 bbls PVT 196 MU 2-7/8' shoe, 10' pup jt, O-ring sub, 87 jts 2-7/8' 6.5# L-80 STL predrilled (@ 8 hpf) and solid liner 06:00 - 06: 15 0.25 RUNCO RUNCMP Hold PJSM with crew coming on tour. 06:15 - 09:15 3,00 RUNCO RUNCMP Continue to MU liner assembly. Continue to monitor and fill hole. 09:15 - 10:00 0,75 RUNCO RUNCMP MU Inteq mwd tools and Baker GS spear assy, Total BHA length: 2627'. Stab coil. Get on well. 10:00 - 11 :30 1.50 RUNCO RUNCMP RIH with liner assembly. Printed: 11/2212004 10:22:51 AM Date Frornd-To Hours Task Code NPT 11/19/2004 11:30 -12:00 0,50 RUNCO 12:00 - 14:30 2,50 RUNCO ! I I I i I I 14:30 - 15:45 1.25 RUNCOt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15:30 - 16:00 16:00 - 16:40 16:40 - 17:00 17:00 - 17:30 17:30 - 19:15 19:15 - 19:45 19:45 - 23:15 23:15 - 23:30 23:30 - 00:00 11/20/2004 00:00 - 00:20 00:20 - 02: 10 02:10 - 02:45 BP Operations Summary Report Page 18 of 19 1 0-11 1 0-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Spud Date: 10/29/2004 End: 11/20/2004 Start: 10/29/2004 Rig Release: 11/20/2004 Rig Number: 2 Phase of Operations ! 0,50 RUNCO~ I RUNCMP Log gr tie in from 10670', Subtract 16' correction. GR peak on MWD log at 8144'. RUNCMP Continue to RIH. 15K# dn wt at window, RIH at 35 fpm, Past side track area ok (11915/12091). Dn wt: 12k#, Set down at 12892 (near loss zone), PU wt: 52k#, Continue to RIH at 51 fpm. Set down at 13425'. Work pipe down to 13475', Circulate to warm up coil. Work down to 13507', Note EOP flag which should be at 13463 16' deep at 13472, Need to correct -11'. RUNCMP Circulate down coil and backside at 600 psi. Circulate 25 bbls, WHP: 750 psi. Work pipe. No progress. Pump down backside again. 725 psi@ 2,11 bpm, Pump 25 bbls, Work pipe. Ran in hole to 13534'. Circ down back side again, 645 psi WHP @ 2.33 bpm. Work pipe, Gain another 5' to 13540', Circ down back side. Work pipe to 13541'. Circ down back side again, PU and RIH while pumping, RIH to 13550' , DFAL RUNCMP Pump to get off GS. Unable to release at 2,75 bpm, Try several times. Unable to get off at various weights and pump rates. GS may be in a bind in build section. Pull up hole above window to 13515'. Able to get off easily, but cannot push liner back down without latching back up and pumping down the backside, RUNCMP Log gr tie in to verify depth, from 13310', Add 2' correction, RUNCMP RIH. White EOP flag is at 10849' as per gr tie in., Latch back onto liner at 10936'. RIH to 10951', This is the straight section of hole below the window, before build section doglegs, Pump at 2.5 bpm. PU at get off liner. RUNCMP Log gr tie in again to re-verify liner top depth, Add l' correction. Re-tag liner top at 10951 '. Liner top: 10951' Liner shoe: 13535' RUNCMP Pull out of hole with liner running assembly, Fill across top of well losing 10 extra bbls Phz 1 RUNCMP LD drilling BHA. PVT 162 Found flat spots on CTC and CT that require removal. Fill hole, SI swab RUNCMP RU and pump slack back using rig water. Blow back CT wI air. Cut off 34' CT. Install CTC and PT 42k. Install BHI head. Load WF tools to floor. PT CTC 4000 psi Phz 2 Kuparuk RUNCMP Safety mtg re: MU BHA RUNCMP MU WS retrieval assy Pump slack forward wI mud in bung hole RUNCMP Fin MU WS retrival assy (OS wI box tap + motor + jars) RUNCMP RIH wI BHA #22 RUNCMP 10850' 36.Ok, 13.7k Start pump 1.85/1875 and caught retums after 10 bbls. RIH 1.0/1040 at 10'/min looking for TOWS and found it at exact normal corr of -26' at 10964.5', Stack 5k and incr rate to 1.5 bpm. SD pump and PUH and no fish. RIH 1.211200 at 9'/min to tag/stall and stack 5k. PU w/4k over and motor stalled at 1.5 bpm. Immediately stack 8k to 10967.7' wI 2.0 bpm. SD pump, PUH to 58k and had sharp wt loss back to 36.5k. This would be normal for 18k shear pins 0,671 RUNCO~ 0.33 RUNCOr-}f> ! i 0,50 RUNCO!\fP i ! 1.75 RUNCO~ i I I 0.50 RUNCO~ I 3.50 RUNCO~ I 0.25 RUNCOJp 0.50 RUNCO~ 0.33 STCTPL I P 1.83 STCTPL I P 0.58 STCTPL P I I Printed: 11/2212004 10:22:51 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From 11/20/2004 02:45 - 04:00 Page 1 9 of 19 BP Operations Summary Report 1 D-11 1 D-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 1,25 STCTPL P Hours Task Code NPT Phase RUNCMP 04:00 - 04:15 0,25 STCTPL P 04:15 - 04:40 0.42 STCTPL P 04:40 - 05:15 0.58 STCTPL P 05:15 - 05:35 0.33 WHSUR P 05:35 - 08:00 2.42 WHSUR P 08:00 - 10:30 2.50 WHSUR P 10:30 - 12:00 1.50 WHSUR P 12:00 - 15:00 3.00 WHSUR P 15:00 - 16:30 1.50 WHSUR P 16:30 - 18:00 1.50 WHSUR P 18:00 - 21 :00 3.00 WHSUR P RUNCMP RUNCMP RUNCMP POST POST POST POST POST POST POST POST Start: 10/29/2004 Rig Release: 11/20/2004 Rig Number: 2 Spud Date: 10/29/2004 End: 11/20/2004 Description of Operations POOH filling from BS and SI wI pump at 0,5/100 psi-ECD shows 9.85-10.2 ppg to 5000' Phz 2 Kup and GPB Generators SD at 2777'. Restart gen's Fin POOH. Chk for flow-still taking fluid, but not as much LD fishing BHA wI WS assy intact. SI swab. Break down tool string and load out fishing tools MU nozzle BHA RIH to window to freeze protect and underbalance well bore. POOH chasing mud from well with diesel. Take diesel mud interface outside. Estimate 120 bbls diesel in tbg from 9000', Phz 1/2 Blow down reel with N2. Unstab coil and secure on reel. Clean pits, Prep to remove reel from rig for move, I Lay down lubricator from derrick and store in pipe shed, Continue to prep reelför removal. Haul off unsed tubulars, Load reel onto low boy trailer. Fin dig out after Phz 2 ND BOPE and load out. NU tree cap and PT Phz 1 RREL @ 2100 hrs 11/20/2004 Printed: 1112212004 10:22:51 AM . BP-GDB Baker Hughes INTEQ Survey Report . .,a: INTEQ 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 bggm2004 Site: KRU 10 Pad UNITED STATES: North Slope Site Position: Northing: 5959249.42 ft Latitude: 70 17 57,217 N From: Map Easting: 560670.61 ft Longitude: 149 30 31.143 W Position Uncertainty: 0,00 ft North Reference: True Ground Level: 0,00 ft Grid Convergence: 0,46 deg Well: 10-11 Slot Name: 10-11 Well Position: +N/-S -167,98 ft Northing: 5959080,00 ft Latitude: 70 17 55,565 N +E/-W -181,19 ft Easting : 560490,80 ft Longitude: 149 30 36.425 W Position Uncertainty: 0,00 ft Wellpath: 1D-11L2 500292294661 Current Datum: 1D-11 Magnetic Data: 11/9/2004 Field Strength: 57582 nT Vertical Section: Depth From (TVD) ft 0,00 +N/-S ft 0,00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0,00 1O-11L2PB1 11915,81 ft Mean Sea Level 24,58 deg 80,75 deg Direction deg 93,00 Height 105,50 ft Survey Program for Definitive Wellpath Date: 12/3/2004 Validated: Yes Actual From To Survey ft ft 100,00 6500,00 6555,00 10904,00 10938,58 11898,69 11915,81 13750,00 Version: 5 Toolcode Tool Name Gyro (100,00-6500,00) (0) Mag MS (6555.00-11234,00) (0) MWD (10938,58-12091,00) (3) MWD (11915,81-13750,00) BOSS-GYRO EMS MWD MWD Sperry-Sun BOSS gyro multishot EMS - Standard MWD - Standard MWD - Standard Annotation 10904,00 11898,69 11915,81 13750,00 6544,74 6573,02 6572.17 6628,54 Window TIP KOP TD Survey: MWD CoilTrak Company: Baker Hughes INTEQ Tool: MWD;MWD - Standard Start Date: 11/18/2004 Engineer: Tied-to: From: Definitive Path . BP-GDB Baker Hughes INTEQ Survey Report . ... ...... 1NT&Q 10904,00 57,10 102,68 6544,74 6439.24 -1920,15 7941,63 5957224,02 568446,87 8031,24 0,00 0,00 11898,69 91,86 72,24 6573.02 6467.52 -1904.44 8910,62 5957247,53 569415.61 8998,08 4,53 314,37 11915,81 93,80 72,85 6572,17 6466,67 -1899,31 8926,93 5957252,79 569431,87 9014,10 11,88 17,42 11945,72 89,06 83,61 6571.43 6465,93 -1893.22 8956,15 5957259,11 569461,04 9042,96 39,29 113,58 11975,33 89,43 86,06 6571.82 6466,32 -1890,56 8985,64 5957262,01 569490.50 9072.27 8,37 81,43 12008.85 88,20 89,69 6572.51 6467.01 -1889,31 9019.12 5957263,52 569523,97 9105,64 11,43 108,75 12040,92 87,95 92,03 6573,59 6468,09 -1889,79 9051,17 5957263,30 569556,02 9137,67 7,33 96,14 12072,89 88.48 95,17 6574,58 6469,08 -1891,80 9083,05 5957261,55 569587.92 9169,62 9,96 80.47 12105,30 88,32 92,86 6575,49 6469,99 -1894,07 9115,37 5957259,54 569620,25 9202,01 7,14 266,00 12135,72 89,55 90,24 6576,05 6470,55 -1894,89 9145.77 5957258,96 569650,65 9232,41 9,51 295,12 12163,84 89,58 84,91 6576,27 6470,77 -1893,70 9173,85 5957260.38 569678,72 9260,39 18,95 270,30 12196,12 87,50 79,95 6577,09 6471,59 -1889,45 9205,83 5957264,89 569710,66 9292,1 ° 16.66 247,19 12228,77 89,03 76,69 6578,08 6472,58 -1882,85 9237.79 5957271,75 569742,56 9323,67 11,03 295,10 12255,00 89.25 78,61 6578.47 6472,97 -1877.24 9263,40 5957277,56 569768,13 9348,96 7,37 83,48 12285,02 91.88 84,17 6578,18 6472,68 -1872,75 9293,07 5957282,29 569797,75 9378,35 20,49 64,68 12323,00 88,21 84,61 6578,15 6472,65 -1869,03 9330,86 5957286,31 569835,51 9415,89 9,73 173,16 12358,01 87,07 87,63 6579,59 6474,09 -1866,67 9365.76 5957288,96 569870,38 9450,62 9,21 110,75 12393,63 88,27 90,57 6581,04 6475,54 -1866,11 9401,34 5957289,80 569905,95 9486,12 8,91 67,84 12429,22 87,84 91.78 6582,24 6476,74 -1866,84 9436,90 5957289,36 569941,52 9521,67 3.61 109,59 12461,78 89,59 92,08 6582,97 6477.47 -1867,93 9469.43 5957288,52 569974,05 9554,21 5.45 9,73 12493,57 87,56 88,14 6583,77 6478,27 -1868,00 9501,20 5957288,72 570005,82 9585,95 13,94 242,70 12525,03 88,02 85,62 6584,98 6479,48 -1866.28 9532,59 5957290,68 570037,19 9617,20 8.14 280,30 12559,55 87,13 80,13 6586,44 6480,94 -1862,01 9566,80 5957295.23 570071,36 9651,14 16,10 260,67 12591,30 89,71 80,95 6587,32 6481,82 -1856,79 9598,1 ° 5957300,70 570102,62 9682,13 8,53 17,64 12621,18 88,79 80,67 6587,71 6482,21 -1852,02 9627,60 5957305,71 570132,07 9711,33 3,22 196.92 12654.55 86,88 83.65 6588,97 6483,47 -1847.47 9660,63 5957310,52 570165,06 9744,08 10.60 122.73 12687,67 88,57 87.91 6590,28 6484,78 -1845,04 9693,62 5957313,22 570198,03 9776,90 13.83 68.44 12722,81 88,88 91,98 6591,07 6485,57 -1845,01 9728,75 5957313,54 570233,15 9811,97 11,61 85.69 12752,99 89,52 96,28 6591.49 6485.99 -1847,18 9758,84 5957311,61 570263,25 9842,14 14.40 81,57 12787.28 88,12 99.46 6592,19 6486,69 -1851,87 9792,79 5957307,19 570297,24 9876,29 10,13 113,79 12820,67 90.20 98,42 6592.68 6487,18 -1857,06 9825,77 5957302,27 570330,26 9909,50 6,96 333.43 12849.43 92,84 98,82 6591,92 6486,42 -1861,37 9854,19 5957298,19 570358,71 9938,10 9.28 8,61 12876,38 90,05 97.44 6591,24 6485,74 -1865,18 9880,86 5957294,59 570385.41 9964,94 11,55 206,33 12906,58 91,37 97,57 6590,87 6485,37 -1869,12 9910,80 5957290,89 570415,37 9995,04 4,39 5,62 12942,33 90,94 95.86 6590,15 6484,65 -1873,30 9946,30 5957287,00 570450,90 10030,71 4,93 255,90 12974,61 88,85 95,80 6590,20 6484,70 -1876,58 9978.41 5957283.98 570483,03 10062,94 6.48 181,64 13003,37 87,00 94,39 6591,25 6485,75 -1879,13 10007,03 5957281,65 570511,67 10091.66 8,09 217,27 13035.84 88,67 95,20 6592.47 6486,97 -1881,84 10039,36 5957279.20 570544,02 10124,09 5,72 25,88 13066.43 87,99 94,04 6593,36 6487.86 -1884,31 10069,84 5957276,99 570574,52 10154,66 4,39 239,59 13102,02 87,40 91,10 6594,80 6489,30 -1885,90 10105,36 5957275,68 570610,05 10190,21 8.42 258,59 13133,47 89,10 89,90 6595,76 6490,26 -1886,18 10136,79 5957275,66 570641.48 10221,62 6.62 324.77 13165,70 87,04 89,99 6596,84 6491.34 -1886.14 10169,00 5957275,95 570673.68 10253,78 6.40 177,50 13197,23 88,85 86.95 6597.97 6492.47 -1885,30 10200,50 5957277,04 570705,16 10285,19 11.22 300,72 13228,26 86,30 83,05 6599,29 6493.79 -1882,60 10231.37 5957279,99 570736,01 10315,88 15,01 236,73 13264.70 86.49 82,61 6601,58 6496.08 -1878,06 10267,46 5957284,82 570772,06 10351,68 1,31 293,38 13290,61 86,95 86,35 6603,06 6497,56 -1875.58 10293,20 5957287,51 570797.78 10377,25 14,52 83,09 13319,73 83,28 88,04 6605,54 6500,04 -1874.16 10322.17 5957289,17 570826.73 10406,11 13,87 155.42 13350,61 84,48 92.73 6608,83 6503,33 -1874.36 10352,87 5957289,21 570857,43 10436,78 15.59 75,83 13383,85 86,15 98,15 6611,55 6506,05 -1877.50 10385,83 5957286,33 570890,41 10469,86 17,01 73,06 13413.45 84.45 102,12 6613,98 6508.48 -1882.69 10414,87 5957281,38 570919,48 10499,13 14,55 113.40 13446,90 91,76 105.45 6615,08 6509,58 -1890,65 10447,31 5957273,68 570951,99 10531,94 24,01 24,56 13477.13 87,01 101,26 6615.41 6509,91 -1897,63 10476,70 5957266,94 570981.43 10561,66 20,95 221.41 13505,07 87.49 98,83 6616,75 6511.25 -1902,50 10504,18 5957262,29 571008.95 10589,36 8,86 281,13 . BP-GDB Baker Hughes INTEQ Survey Report . .,a: INTßQ 13535,07 88,29 97,73 6617,85 6512.35 -1906,82 10533,85 5957258.21 571038,65 10619,21 4,53 306,02 13565,65 88.60 97,83 6618,68 6513.18 -1910,96 10564.14 5957254,32 571068,96 10649,67 1,07 17.87 13601,35 88,73 99,85 6619,51 6514,01 -1916,44 10599,40 5957249,12 571104,27 10685,17 5,67 86.34 13632,54 87,43 99,85 6620,56 6515,06 -1921,77 10630,11 5957244,03 571135,02 10716,12 4,17 180,00 13661.50 85,65 98,81 6622,31 6516,81 -1926,46 10658,64 5957239,58 571163,57 10744,85 7,12 210,22 13690,29 86,02 96,97 6624.40 6518.90 -1930,40 10687,08 5957235,87 571192.04 10773,46 6,50 281.33 13750,00 86,02 96,97 6628,54 6523,04 -1937.63 10746,20 5957229,11 571251,22 10832,88 0,00 0,00 Survey: MWD (10-11/1D-1112) Created By: Bnj Potnís Date; 12f3/2004 ~ ~AM Azimuths to True North Magnetic North: 24,58' Magnetic Fieid Strength: 57582nT Dip Angle: 80,75' Date: 11/9/2004 Modei: bggm2004 Alaska, -- WELLPATH DETAILS Nordic 2 Ref. 1[)·11 105,5011 V.Section Origin Origin Angle +NI.s +E!~W 93,00' 0,00 0,00 0,00 REFERENCE INFORMATION late (N/I cal(TVI ,tion(Vi 'ad Dep Calculi JNOTATIC TVD MD . BP-GDB Baker Hughes INTEQ Survey Report . ... -- INTJi.Q Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: KRU 1 D Pad UNITED STATES: North Slope Site Position: Northing: 5959249.42 ft Latitude: 70 17 57,217 N From: Map Easting: 560670,61 ft Longitude: 149 30 31,143 W Position Uncertainty: 0,00 ft North Reference: True Ground Level: 0,00 ft Grid Convergence: 0,46 deg Well: 10-11 Slot Name: 10-11 Well Position: +N/-S -167,98 ft Northing: 5959080.00 ft Latitude: 70 17 55,565 N +E/-W -181,19 ft Easting : 560490,80 ft Longitude: 149 30 36,425 W Position Uncertainty: 0,00 ft Wellpath: 1O-11L2PB1 500292294670 Current Datum: 1 D-11 Magnetic Data: 11/9/2004 Field Strength: 57582 nT Vertical Section: Depth From (TVD) ft 0,00 +N/-S ft 0,00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +EI-W ft 0,00 10-11 10938.58 ft Mean Sea Level 24,58 deg 80,75 deg Direction deg 101,43 Height 105,50 ft Survey Program for Definitive Wellpath Date: 12/3/2004 Validated: Yes Actual From To Survey ft ft 100,00 6500.00 6555,00 10904.00 10938,58 12091,00 Version: 4 Toolcode Tool Name Gyro (100,00-6500,00) (0) Mag MS (6555,00-11234,00) (0) MWD (10938,58-12091,00) BOSS-GYRO EMS MWD Sperry-Sun BOSS gyro multishot EMS - Standard MWD - Standard Annotation 10904,00 10938,58 12091,00 6544,74 6563,56 6552,90 TIP KOP TD Survey: MWD CoilTrak Company: Baker Hughes INTEQ Tool: MWD;MWD - Standard Start Date: 11/13/2004 Engineer: Tied-to: From: Definitive Path . BP-GDB Baker Hughes INTEQ Survey Report . -.I: INTEQ 10904,00 57,10 102,68 6544,74 6439,24 -1920.15 7941,63 5957224,02 568446,87 8164,66 0.00 0,00 10938,58 56,93 102,56 6563,56 6458,06 -1926,49 7969,93 5957217,91 568475,22 8193,66 0.57 210,60 10954,55 58,12 102,02 6572,14 6466,64 -1929,35 7983,10 5957215,15 568488,40 8207,13 7.98 338,91 10981,56 66.53 100,76 6584,67 6479,17 -1934,06 8006,53 5957210,63 568511,87 8231,03 31.41 352,14 11015,94 77,24 106,54 6595.35 6489,85 -1941,81 8038,21 5957203,14 568543,61 8263,62 35,00 28,11 11045,82 86,30 101,07 6599,63 6494,13 -1948,84 8066,89 5957196,34 568572,34 8293,12 35,31 328,70 11075,75 91,30 98,38 6600,26 6494,76 -1953,89 8096,37 5957191,53 568601,86 8323,02 18,97 331,68 11104,30 93,36 95,15 6599,10 6493.60 -1957,25 8124,69 5957188,39 568630,20 8351,45 13,41 302,61 11133,24 93,18 91,34 6597,44 6491,94 -1958,89 8153,53 5957186.99 568659,05 8380,04 13,16 267.40 11159.43 92,72 89,86 6596,10 6490,60 -1959,16 8179,69 5957186,93 568685,21 8405,73 5,91 252,75 11191,39 91,76 86,07 6594,85 6489.35 -1958,03 8211,59 5957188,32 568717,10 8436,78 12,22 255,85 11221,70 91,73 83,19 6593,92 6488.42 -1955,19 8241,75 5957191.40 568747,23 8465,78 9,50 269,45 11254,95 92,66 79,28 6592,65 6487,15 -1950,13 8274,59 5957196,72 568780,02 8496.95 12,08 283,46 11293,02 89,92 76,93 6591,79 6486,29 -1942.29 8311,82 5957204,86 568817,19 8531,90 9,48 220,64 11335,57 86,52 80,24 6593,11 6487,61 -1933.87 8353,50 5957213,61 568858,79 8571,08 11,15 135,82 11365,96 86,73 79,77 6594,90 6489,40 -1928,60 8383,37 5957219,12 568888,62 8599,32 1,69 294,10 11397,66 86,98 77.08 6596.64 6491,14 -1922,25 8414,38 5957225,72 568919,57 8628.45 8,51 275,24 11431,75 86.24 82,27 6598,66 6493,16 -1916,16 8447,85 5957232,09 568952,99 8660,04 15,35 98,28 11461,44 84,93 86,07 6600,95 6495.45 -1913,15 8477,29 5957235,33 568982,40 8688,31 13,50 109,21 11497,21 85,68 90,68 6603.88 6498,38 -1912,14 8512,92 5957236,63 569018,02 8723,02 13,01 80,92 11533,37 91,49 91.47 6604,77 6499,27 -1912,82 8549,04 5957236,24 569054,14 8758,57 16,22 7,75 11563.25 91,80 88,93 6603,91 6498.41 -1912,92 8578,91 5957236,37 569084,00 8787,86 8,56 277,00 11591,91 94,97 87,16 6602,22 6496,72 -1911,95 8607,50 5957237,58 569112,58 8815,69 12,66 330,91 11622,84 97.40 85,17 6598,89 6493,39 -1909,89 8638.17 5957239,88 569143,24 8845,35 10,13 320,95 11653,07 95,88 89,25 6595,39 6489,89 -1908.43 8668.16 5957241,58 569173,21 8874,45 14,32 110,31 11680,32 95,09 93,55 6592,78 6487.28 -1909,09 8695,27 5957241,14 569200,32 8901,16 15,97 100,25 11711,22 94,89 97,69 6590,09 6484,59 -1912,11 8725,90 5957238,37 569230,97 8931,77 13,36 92,59 11744,85 95,33 96,00 6587,10 6481,60 -1916,10 8759,15 5957234,65 569264,25 8965.16 5,17 284,72 11774,00 96,72 93,24 6584,04 6478,54 -1918,44 8788,04 5957232,54 569293,16 8993,94 10,55 297,00 11809,83 97,11 88,91 6579,72 6474,22 -1919,10 8823,60 5957232,16 569328,71 9028,92 12.05 275.44 11839,84 96,10 82,95 6576,27 6470,77 -1916,99 8853,32 5957234,52 569358,41 9057,63 20,01 260,67 11869,63 92,32 77,64 6574,08 6468,58 -1911,98 8882,59 5957239,76 569387,64 9085,33 21,84 234,70 11898,69 91,86 72,24 6573,02 6467,52 -1904.44 8910,62 5957247,53 569415,61 9111,31 18,64 265,23 11928,54 95,24 73,30 6571,17 6465,67 -1895,61 8939,07 5957256,58 569443,98 9137.45 11,86 17,35 11960,24 96,26 68,07 6567,99 6462,49 -1885,18 8968,83 5957267,25 569473,65 9164,54 16,73 281,34 11990,15 97,12 66,22 6564,51 6459,01 -1873,65 8996,20 5957279,00 569500,93 9189,09 6,78 295,19 12026,27 96,50 70,06 6560.22 6454,72 -1860,30 9029.48 5957292.62 569534,09 9219,06 10,69 99,00 12091,00 96,50 70,06 6552,90 644 7.40 -1838,36 9089,94 5957315,04 569594,37 9273,97 0,00 0,00 Survey: MWD (1D~11j1D-11L2) Date: 12/3/2004 WELLPATH DETAILS 1D·11L2 500292294661 Nordic :2 1[ ·11 1( V.Section Origin Angle +Nl-S 93,00· 0,00 0,00 0,00 REFERENCE INFORMATION AM . . . ConocoPhllllps Alaska. Inc. . KRU 1 D-11 10-11 API: 500292294600 Well Tvoe: PROD Anale (â) TS: 57 dea (â) 10902 SSSV Type: NIPPLE Orig 10/26/1999 Angle @ TO: 56 deg @ 11234 Completion: Annular Fluid: Last W/O: Rev Reason: CTD 2 Lateral Lee¡s NIP (541-542, Reference Log: Ref Log Date: Last Update: 121712004 00:5,200) Last TaQ: 11136 TD: 11234 ftKB lUBING Last Taa Date: 101512004 Max Hole Anale: 60 dea (â) 7659 (0-10415. Casino Strino - ALL STRINGS 00:4,500, Description Size Top Bottom TVD Wt Grade Thread ID:3,958) "ROOUCTION CONDUCTOR 16,000 0 115 115 62.58 H-40 WELDED (0-10564 , SURFACE 9.625 0 6814 4404 40.00 L-80 BTC 00:7,000. PRODUCTION 7.000 0 10564 6362 26.00 L-80 BTC W1:26,OO) PRODUCTION 4,500 10401 11234 11234 12.60 L-80 IBT Tubina Strina - TUBING Size 1 Top I Bottom I TVD I Wt I Grade I Thread 4.500 1 0 I 10415 I 6285 I 12.60 I L-80 I IBT Perforations Summary GasUfI D~ "œNa TVD Zone Status Ft SPF Date Type Comment mdrellDummy 10907 - 10927 6546 - 6557 C-4 20 4 11/19/1999 IPERF 2718" He, DP, 180 deg Valve 1 ~10353-10354, I phase +1- 90 dee¡, low side 00:5,985) 10960 - 10980 6575 - 6586 C-4 20 4 11/19/1999 IPERF PERFS blocked by Lateral L 1 Straddle Assembly 11031 - 11041 6614 - 6620 C-2 10 6 10/1012004 APERF 27/8" HSD PJ 11065-11085 6633 - 6644 C-1 20 6 10/1012004 APERF 27/8" HSD PJ Gas Lift MandrelsNalves St I MD I TVD I ~~ Man Type I VMfr I V Type I V OD I Latch I Port I TRO I Date I VIv Run Cmnt NIP - 1 1103531 62521 CAMeO I KBG-2-LS I I DMY I 1.0 1 BTM I 0,000 1 0 111/151199!:j ~10397-10398, Other (1Iuas. E auip. etcJ - JEWELRY 00:5,200) Depth TVD Type Description ID 541 541 NIP CAMeO DB 3,813 10397 6275 NIP OTIS X 3,812 10407 6280 SEAL BAKER Seal Assemblv 192-47 3,875 10409 6281 PKR BAKER Packer 7 x 4.5 SLZXP Dackerlhanaer 3,875 10960 6575 Straddle STRADDLE ASSEMBLY LOCATED BETWEEN CTD L 1 & L2, BLOCKING 2.370 Assembly PERFS @ 10960'-10980'. REMNNING 10-11 PERFS PRODUCING 'ROOUCTlON III 1119/2004 General Notes :10401-11234, Date I Note 00:4,500, 1/22/ 2004 TRI-LA TERL WELL w/2 CTD LEGS w/SLOTTED LINERS PKR . ~10409-10410, 00:4,500) Perf :10907-10927) Perf :10960-10980) Straddle ........- Assembly :10980-10980, 00:3,680) Perf :11031-11041) Perf :11065-11085) RE: KRU ID-ll and ID-32 L1: Request for wI. from monthly testing e \\)- \ \ \~~-O ~J, - \ \ L \. ;)O~,,;}\ \ ... \ \ \.. d.. dO'1:'"d'\ð \~ ,- "'=> "2) G()O - \ ~ ~ -~J',-1- .)ù4-\c;Ç Subject: RE: KRU ID-II and ID-32 LI: Request for waiver from monthly testing From: "Seitz, Brian" <Brian.Seitz@conocophillips.com> Date: Wed, 27 Oct 200409:22:43 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us>, "Venhaus, Dan E" <Dan.E. Venhau8@conocophillips.com> CC: John D Hartz <jack_hartz@admin.state.ak.us>, Steve McMains <steve _ mcmains@admin.state.ak.us>, "Johnstone, Sam" <Sam.Johnstone@conocophillips.com>, "Lamar Gantt (E-mail)..<gantt11@bp.com> Thanks Tom. Dan & Lamar - please note that this applies to 1 D-32 as well with regards to how to file the completions report. Brian -----Original Message----- From: Thomas Maunder (mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, October 27,20049:16 AM To: Seitz, Brian Cc: John D Hartz; Steve McMains Subject: Re: KRU 1D-11 and 1D-32 L1: Request for waiver from monthly testing Brian, With regard to the plan to produce ID-II, LI and L2 for some 3 to 6 months, when the lateral completion reports (form 4078) are submitted they should show the completion as I-oil. This will make sure the production record is established appropriately. When CP AI has determined it time to convert to injector, then 403s should be submitted to provide notice and request approval of the conversion. I hope this answers your question. Tom Maunder, PE AOGCC Seitz, Brian wrote: Thanks Tom. I appreciate the quick turn-around on this one. Brian -----Original Message----- From: Thomas Maunder [~~~)to:tom maunder@admin.state.~.us] Sent: Thursday, September 30, 2004 3:17 PM To: Seitz, Brian Cc: ~ck hartz@admin.state.ak.us¡ CPFl Prod Engr Subject: Re: KRU 1D-ll and 1D-32 L1: Request for waiver from monthly testing Brian, Jack and I have discussed your proposal and find it acceptable. I have received the sundries for the wells and will include a copy of this email with them. Please call with any questions. Tom Maunder, PE AOGCC · RE: KRU ID-II and ID-32 Ll: Request for waiver rrom monthly testing e Seitz, Brian wrote: Tom- ConocoPhillips is evaluating the temporary conversion of two Kuparuk water injection wells, KRU 1D-11 and KRU 1D-32 L1, to production. While on production, both wells will be tied into the production header. However, tying into the test header to allow for well testing through the DS-1D test facility is likely to add significant cost and delay to a project that is short term in nature. As such, we request a waiver from the monthly well testing requirement for the estimated 3-6 months that these two wells will be on production. We propose testing the wells through a temporary test skid every other month during the production period. KRU 1D-11 is a current water injector perforated in only the C4 sands. We plan to perforate oil bearing C1 sands and evaluate its productivity in support of other development planned in the area. Depending upon results of the C1 test, perforations may also be added in the C3 sands. Production is expected to last no longer than 6 months. An Application for Sundry Approval for the temporary conversion to production will be filed today. KRU 1D-32 is a current water injector scheduled to be sidetracked as 1D-30 L1 with coiled tubing in October. Following the coiled tubing sidetrack, we plan to flow test the well and if results are encouraging, put it on production for a period expected to last no longer than 6 months. A permit to drill and an Application for Sundry Approval for the temporary conversion to production will be filed this week. Please contact me if you wish to discuss our plans for these wells or require additional detail. Regards, Brian Seitz Kuparuk CPF-1 Lead Engineer (907) 265-6961 e ~1f~1fŒ lID~ ~~~~æ~ . AI¡ASIiA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mark Johnson CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Kuparuk 1D-11L2 BP Exploration (Alaska) Inc. Permit No: 204-212 Surface Location: 4695' NSL, 601' WEL, SEC. 23, T11N, RlOE, UM Bottomhole Location: 2768' NSL, 5150' WEL, SEC. 20, T11N, RIlE, UM Dear Mr. Johnson: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 1 D-11, Permit No. 199-072, API 50-029-22946-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill 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. 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 Commissio witness any required test. Contact the Commission's petroleum field inspector 7) 6 - 7 (pager). BY ORDER OF THE COMM N DATED this-.L day 0 er, Z.OQ4 _ Þ ()1M.1ø8V" cc: Department ofFish & Game, Habitat Section w/o encI. Department of Environmental Conservation w/o encI. OCT '2 2 2004 Á \J &v.> 1a. Type of work o Drill II Redrill rb. Current Well Class o Exploratory o "~V'é16~nltöhf..Ojf/;;13I 'MUlti~Zbríff:;;,':' ORe-Entry o Stratigraphic Test B Service o Development ~"igr§ÏQ,Qle Zone 2. Operator Name: 5. Bond: 181 Blanket o Single Well 11. Well Name and NUmber: BP Exploration (Alaska) Inc. Bond No. 2S100302630-277 Kuparuk 1D-11L2 3. Address: 6, Proposed Depth: 12. Field I Pool(s): P.O, Box 196612, Anchorage, Alaska 99519-6612 MD 14000' TVD 6515' Prudhoe Bay Field I Kuparuk 4a, Location of Well (Governmental Section): 7. Property Designation: River Pool Surface: ADL 028243 4695' NSL, 601' WEL. SEC, 23, T11N, R10E, UM /' Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2715' NSL, 2907'WEL, SEC. 19, T11N, R11E, UM 10/29/04 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2768' NSL, 5150' WEL, SEC. 20, T11N, R11E, UM , 2560 5920' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: x- 560491 ;' y- 5959080 r Zone- ASP4 (Height above GL): feet 2870' away from 1 D-30L 1 ~ 105.50' 16. Deviated Wells: Kickoff Depth: 10935 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 95 deQrees Downhole: 3383 . Surface: 2732 - 111, ... ça~ingprogram: .......... Specifications .... (C;f/ .. Size Tip )~, """. . Hole Casino Weicht Grade Couplina Lenath MD TVD MD TVD (includinc staae data) 4-1/8" x 3·3/4" 2-7/8" 6.16# L-80 STL 3060' 10940' 6456' 14000' 6515' Pre Drilled Liner 19. PRESENT WEl.L CQNDITION·SUMMARY (To be e<>O'Ipfeteq.forReqrifIAfl,jDR&'éntryQpe[atiOhs) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft): Junk (measured): 13200 6525 None 13200 6525 None ""'<>è¡........ ...... '.)' Lél'1g1h Size . ., .'. .··i....·..... ...........,.... . · MD. ···.TVD ~ I Conductor 115' 16" 9 cu vds High Early 115' 115' ~ r 6814' 9-5/8" 760 sx AS III Lite, 710 sx Class 'G' 6814' 4396' In Production 10565' 7" 220 sx Class 'G' 10565' 6355' LinF!r 833' 4-1/2" 140 sx Class 'G' 10401' - 11234' 6270' - 6720' Liner (L 1) 2200' 2-7/8" Pre Drilled Liner 11000' - 13200' 6492' - 6525' Perforation Depth MD (ft): 10907' - 11085' perfOration Depth TVD (ft): 6539' - 6637' 20. Attachments o Filing Fee, $100 181 BOP Sketch 181 Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report 181 Drilling Fluid Program IS 20 AAC 25,050 Requirements 21, Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Venhaus, 263-4372 Printed Name Mark Johnson .--.. Title CT Drilling Engineer /}i¿-,~ Ó.~U Prepared By Name/Number: Signature - 564-5666 Date Sondra Stewman, 564-4750 rllone ....~.... .. . ... ./ ,// '." ..... '. .'. Permit To Drill <I '.1 A~umber: Permit APpr~ I ~ee cover letter for Number: :;J.C;:; - Z f Z- 50- 029-22946-61-00 Date: other requirements Conditions of Approval: Samples Required D Yes ~No Mud Log Requireè:l DYes gNo Hydrogen Sulfide Measures ~Yes D No Directional Survey Required ~Yes DNo OIh., ":25 ~ "-">*"'.. \>\c>.,,~, íM:J~ -\<c.". ~..,,~~ \ £... \ 4 ~<:}....(~, ,- \j\J f 1 ~ J ,,~,\;~~<-c..Ð~ ~ I ~ \~ d- ~, Aooroved B: U~).?t ,., ; Ii I r í APPROVED BY Ilt/,(/ THE COMMISSION Date Form 10-401 Revised 06/20 ~ '. . ' , ~ i s{¡br1fit In Öu Jicate . STATE OF ALASKA I ALASKA OIL AND GAS CONSERVATION C ìMISSION PERMIT TO DRILL 20 AAC 25 005 p . . KRU 1D-11L2 Permit Summary Summary of Operations: Coiled tubing drilling will drill 2 laterals in injector KRU ID-ll using Dynamically Overbalanced pressure drilling technique (DOBCTD, see description below). This horizontal laterals will target Kuparuk C sand reserves for injection. The Kuparuk C Sand perforations in the existing well, ID-ll, will be retained. -(~, ~ <\ CTD Drill and Complete ID-llLl & ID-llL2 proeram: Planned for Oct 29. 2004 1. Pre CTD MIT -lA, MIT -OA 2. Pre CTO Calipeft~-1I2" liner 3. Pre CTD drift tubing/liner with dummy whipstock 4. MIRU Nordic 2. NU 7-1116" BOPE, test. 5. Set 4-112" LSX whipstock @ 11020' md. 6. Mill 3.80" window at 11020' md and 10' of openhole. 7. Drill 4-118" bicenter hole horizontal lateral from window to -13200' TD targeting Kuparuk ClIC2 sands. 8. Complete with 2 7/8" re-drilled liner fro D 13200', up into the 4-112" liner to -11000' . 9. Set Weatherford KSWS pac er - 10945' md 10. Stab into KSWS packer with retrievable 4-112" whipstock, targeting top of whipstock @ 10935' md. 11. Mill 3.80" window at 10935' rod and 10' of openhole. / 12. Drill 4-118" bicenter hole horizontal lateral from window to -14000' TD targeting Kuparuk C3/C4 sands. r' 13. Complete with 2 7/8" pre-drilled liner from TO 14000', fu 5' -1 0' outside the 4-112" casing exit -10940' . 14. Pull 4-1/2" retrievable whipstock @ 10935' rod. IS. ND BOPE. RDMO Nordic 2. 16. Post CTD rig -Run GL Vs. Perform short-term production test prior to injection service. Mud Program: · Step 6: 8.7 ppg Potassium-Formate biozan brine · Steps 7, 9-12: Potassium-Formate based PIo-Pro (8.7 ppg) ./ · Steps 8 & 13: Viscosified potassium formate KWF (10.6 ppg) Disposal: · No annular injection on this well. · Class IT liquids to KRU lR Pad Class IT disposal well · Class IT drill solids to Grind & Inject at PBU Drillsite 4 · Class I wastes will go to Pad 3 for disposal. Casing Program: · ID-llLl: 27/8",6.16#, L-80, STL pre-drilled liner from 13200' md to l1ooo' md · ID-IIL2: 27/8",6.16#, L-80, STL pre-drilled liner from 14000' md to 10940' md ./ Well Control: · Two wellbore volumes (-520 bbls) of KWF will be location during drilling operations. · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plans for 1 D-I1L2 · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. ,,' · The nearest well to ID-11L2 is 1D-30Ll which is offset by 2870''- The KRU boundary is 5920' away from ID-I1L2. Logging ¡ · A MWD Gamma Ray and Resistivity will be run. · KRU 1 D-11 L2 Permit su.ary Hazards · No mapped faults in the planned well path; lost circulation risk is medium based on C sand drilling results this year. High pressure is not expected due to lack of faulting. ,/ · WelllD-ll has a H2S reading of 3 ppm. ID is an H2S pad, the highest H2S measurement on the pad is /' 120ppm. All H2S monitoring equipment will be operational. r Reservoir Pressure t" · The latest Shut in bottom hole pressure is approximately 3383 psi at 6508' TVD, 10.0 ppg EMW. Max. surface pressure with gas (0.1 psi/ft) to surface is 2732 psi. " DOBCTD Pressure Drilling Dynamically overbalanced pressure drilling (DOBCTD) techniques will be employed to provide constant bottom hole pressure by using 8.7 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long wellbores. 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 will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the BHA will be accomplished utilizing the BOP pipe/slips (2-3/8" rams, see attached BOP configuration). This well does not have a tubing retrievable sub-surface safety valve. The annular preventer will act as a secondary containment during deployment and not as a stripper. Estimated reservoir pressure: 3383 psi at 6508' TVD, 10.0 ppg EMW. / Expected annular friction losses while circulating: 650 psi Planned mud density: 8.7 ppg equates to 2944 psi hydrostatic bottom hole pressure. / While circulating 8.7 ppg fluid, bottom hole circulating pressure is estimated to be 3594 psi or 10.6 ppg ECD When circulation is stopped, a minimum of 650 psi surface pressure will be applied to maintain constant ,/ BHP. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The production liner will be deployed by swapping the wellbore to the KWF that not only overbalances the well but is found to work best with the exposed shales during the drilling operation (minimum weight = 10.3 ppg for overbalance) eAK PíD ðOfY . Conoc;OPhlllips Al8 lka, Inc. . KRU 1 D-11 10"11 ......'. i·.·....C ..... ........ ........... .... ...... API: 500292294600 Well TyDS: INJ Anole (â) TS: 57 dea (â) 10902 .¡ SSSV Type: NIPPLE Orig 10/26/1999 Angle @ TD: 56 deg @ 11234 ; Comøletlon: Annular Fluid: Last W/O: Rey Reason: Drift & Tao. PERF NIP (541-542. Reference Loa: Ref Loa Date: Last UDdate: 10/13/2004 00:5.200) Last Tao: 11136 TD: 11234 ftKB TUBING Last Tag Date: 10/5/2004 Max Hole 60 deg @ 7659 (0-10415. Anale: 00:4.500. ..·.·....i"i.··.. .i. ',. ..··..·.'-C·.···'·· '. .,...... 'iC .,. ........ ..C ". 10:3,958) 'ROOUCTlON DescrlDtlon Size TOD Bottom TVD Wt Grade Thread (0-10564. SURFACE 9.625 0 6814 4404 40.00 L-80 BTC 00:7,000. ..... PRODUCTION 7.000 0 10564 6362 26.00 L-SO BTC Wt26,oo) CONDUCTOR 16.000 0 115 115 62.5S H-40 WELDED ... DDnnl~ 4.500 10401 11234 11234 12.60 L-SO IBT ." .···y·..i.. ...,y. Ii.ii'" ..iii"ii······ .,y. C '·.C.' .... Size Too I Bottom I TVD I Wt Grade Thread 4.500 I 0 I 10415 I 6285 I 12.60 L-SO IBT Gas Lift f'.êi'fôi'ãtlóns··Siiiiìiiìài'Yj ........ i·.;I 'y .....................................................;" ..... . .., .. ii ......'.}.. ................ IndrellDummy Interval TVD Zone Status Ft SPF Date TyDS Comment Val", 1 :10353-10354. 1 0907 - 1 0927 6546 - 6557 C-4 20 4 1/19/199~ IPERF 2 7/S" HC. DP, 1S0 deg 00:5,985) phase, +/- 90 deg, low side .' 10960 - 10980 6575 - 6586 C-4 20 4 1/19/199~ IPERF 21/2" HC. DP, 1S0 deg phase, +/- 90 deg, low side .... 11031 - 11041 6614 - 6620 C-2 10 6 0/10/200.4 APERF 2 7/S" HSD PJ NIP 11065 - 110S5 6633 - 6644 C-1 20 6 0/1 0/200.4 APERF 2 7/S" HSD PJ :10397-10398. 00:5,200) ..... ·.i. ..i, ......,.... ......·i i m. St I MD TVD Man Man Type VMfr V Type VOD Latch I Port I TRO I Date VJv Mfr Run Cmnt 1 110353 6252 CAMCO KGB-2-LS DMY 1.0 BTM I 0.000 I 0 . ·m .'c i'c ." ·iii.·.··· ......... ...'........ ..... .... ',ii' i. " i DeDth TVD TyDS DescriDtion ID 541 541 NIP CAMCO DB 3.S13 'RooucnON ... 10397 6275 NIP OTIS X 3.S12 10407 i SEAL BAKER Seal Assembly 192-47 3.S75 :10401-11234. 10409 PKR BAKER Packer 7 x 4.5 SLZXP oackerlhanaer 3.S75 00:4.500. ··i···.·.,·..···. ·.'ci··'..·· ...... i.·...' e.i····.·..· ...... i' ·."i .......... Date Note 2/23/1999 Taaoed hYdrates (â)43S3' WLM PKR :10409-10410. AdpeFf's jtJ-I/-lJ'I 00:4,500) Perf IJ¡03¡1-lIjOL//' ez ,ñ-!erVd¿ :10907-10927) /1,06$1- 1/, OgS' tl ; Y/ftr 1/ tf// Perf :10960-10980) Perf :11031-11041) - - - Perf :11065-11085) KRU 1 D-11 L 1 & L2 Injector Proposed Completion Conoc6Phillips Alaska, Inc. E. 4-1/2" Cameo DB nipple. 3.813" min ID at 541' MD D. 4-1/2" 12.6# L-80 IBT Mod Tubing . 9-5/8" 401 L-80 0 6814" C. 4-W Cameo KGB-2-LS GLM at 10353' MD B. 4-W Halliburton X nipple, 3.812" min ID @ 10397' MD A. Baker SLZXP liner top packer/hanger/seal assembly at 10407' MD 7" 261 L-80 0 10564 MD' C4 Sand perfs 2·7/8" liner top @ +1-10940' MD 4-1/8" open hole 1 D-11 L2 Lateral TD @ 1 O'md L2 KOP 10935' MD Window In 4-112" 0 0 . 0 0 . 0 0 0 0 0 0 . 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 . 0 0 0 0 0 . . 0 . 0 0 0 0 0 0 . Weatherford KSWS perm packer +1-10945' D 2-7/8" pre-drilled liner, 8 holeslft. 3/8" hole size C4 Sand perfs 2-7/8" liner top @ +1-11000'MD L 1 KOP 110Zð MD 4-1/8" openhoJe 1 D-11 L1, TD @ 13%00' md . . 0 . 0 0 . 0 0 . 0 0 0 0 0 0 . 0 C1/C2 . Sands 0 0 0 0 0 . . 0 . . 0 0 0 . . . . . 0 0 . 0 . 0 0 0 0 0 0 0 4-Y.z" LSX WS 4-112" 12.61 L-80 Fill 2-7/8" pre-drilled liner. 8 holeslft. 3/8" hole size 011234 MD' DEV 10/19/04 . . BP-GDB Baker Hughes INTEQ Planning Report Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datnm: NAD27 (Clarke 1866) Sys Datnm: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: KRU 10 Pad UNITED STATES: North Slope Site Position: Northing: 5959249.42 ft Latitude: 70 17 57,217 N From: Map Easting: 560670,61 ft Longitude: 149 30 31,143 W Position Uncertainty: 0,00 ft North Reference: True Gronnd Level: 0,00 ft Grid Convergence: 0.46 deg Well: 10-11 Slot Name: 10-11 Well Position: +N/-S -167,98 ft Northing: 5959080,00 ft Latitnde: 70 17 55,565 N +E/-W -181,19 ft Easting : 560490.80 ft Longitude: 149 30 36.425 W Position Uncertainty: 0,00 ft Wellpath: Plan#310-11L2 500292294661 Current Datum: 10-11 Magnetic Data: 10/22/2004 Field Strength: 57580 nT Vertical Section: Depth From (TVD) ft 0,00 Targets Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0,00 10-11 10904,00 ft Mean Sea Level 24,60 deg 80,75 deg Direction deg 93,00 Height 105,50 ft +N/-S ft 0,00 1 D-11 L2 T3,2 6445,00 -1859,90 8753,31 5957290.79 569257,96 70 17 37,223 N 149 26 21,319 W 10-11L2 T3,3 6464.00 -1867,23 9660,37 5957290,77 570164,96 70 1737,140N 149 25 54,884 W 10-11 L2 T3.4 6495,00 -1873,08 10385.41 5957290,75 570889,96 70 17 37,073 N 149 25 33.754 W 1O-11L2 T3,1 6497,00 -1945,54 8211,55 5957200,80 568716,95 70 17 36,387 N 149 2637,111 W 1O-11L2T3,5 6515,00 -1877,85 10975.45 5957290,73 571479,96 70 17 37,018 N 149 25 16,558 W Annotation 10904,00 10935,00 10955,00 11085,51 11335,51 11685,51 11760,51 11935.51 12185.51 12435,51 12685,51 12935,51 13185,51 13385,51 13635,51 13885,51 14000.00 6439,24 6456.11 6466,77 6495.49 6471.49 6446.67 6444.93 6447,00 6453,25 6458,67 6463.36 6472,55 6485,63 6494,86 6504.43 6511.94 6515,03 TIP KOP end 9 OLS I begin 29 DLS end 29 DLS I begin 12 OLS 5 6 7 8 9 10 11 12 13 14 15 16 TO . BP-GDB Baker Hughes INTEQ Planning Report . 10904,00 57,10 102,68 6439,24 -1920,15 7941,63 0,00 0,00 0,00 0,00 10935,00 56,94 102,57 6456,11 -1925,83 7967,01 0,60 -0,52 -0,35 209,94 10955,00 58,68 102,02 6466,77 -1929.44 7983,54 9,00 8,70 -2,73 -15,00 11085,51 95,50 92,84 6495.48 -1944,84 8107.48 29,00 28,21 -7,03 -15,00 11335,51 95,26 62,71 6471.49 -1892,75 8347,89 12,00 -0,10 -12,05 271,00 11685,51 92,51 104,72 6446,67 -1855,60 8687,18 12,00 -0,79 12,00 92,10 11760,51 90,16 96,03 6444,93 -1869,10 8760,86 12,00 -3,13 -11,59 255,00 11935,51 88,50 75,10 6447,00 -1855,64 89 4,35 12,00 -0,95 -11,96 265.40 12185,51 88,70 105,11 6453,25 -1856,08 91 1.42 12,00 0,08 12,00 90,00 12435,51 88,87 75,10 6458,67 -1856,52 94 8,51 12,00 0,07 -12,00 -90,00 12685,51 89,03 105,10 6463,36 -1856,96 96 5,62 12,00 0,06 12.00 90,00 12935,51 86,86 75,16 6472,55 -1857,57 99 2,61 12,00 -0,87 -11,98 265.40 13185,51 87,28 105,20 6485,64 -1858,35 101 9.41 12,00 0,17 12,01 90,00 13385,51 87,51 81,17 6494,86 -1869,37 103 7.43 12,00 0,12 -12,01 -90,00 13635,51 88,20 111,19 6504,43 -1895,97 106 2,96 12,00 0.27 12,01 89,30 13885,51 88.44 81,18 6511,94 -1922,57 108 8,57 12,00 0,10 -12,00 -90,00 14000,00 88,48 94,92 6515,03 -1918,68 109 2,67 12,00 0,04 12,00 90,00 Survey 10950,00 58,24 102,16 6464,15 -1928,54 5957215,93 568484,67 8069,37 9,00 345,22 MWD 10955,00 58,68 102,02 6466,77 -1929.44 5957215,07 568488,85 8073,58 9,00 345,22 end 9 10975,00 64.29 100,36 6476,31 -1932,84 5957211,81 568506,11 8090.97 29,00 345,00 MWD 11000,00 71,33 98.49 6485,75 -1936,62 5957208,21 568528,96 8113,96 29,00 345,80 MWD 11025,00 78,39 96,77 6492,27 -1939,81 5957205,21 568552,88 8137,99 29,00 346,50 MWD 11050,00 85.46 95,13 6495,78 -1942,37 80 2,10 5957202,85 568577,50 8162,70 29,00 346,95 MWD 11075,00 92,53 93,52 6496,22 -1944,26 80 7,01 5957201,16 568602.42 8187,67 29,00 347,19 MWD 11085,51 95,50 92,84 6495.48 -1944,84 81 7.48 5957200,67 568612,90 8198,16 29,00 347,21 end 29 11100,00 95,53 91,10 6494,09 -1945,33 81 1,89 5957200,29 568627,31 8212,57 12,00 271,00 MWD 11125,00 95.56 88,08 6491,68 -1945,16 81 6,77 5957200,66 568652,18 8237.41 12,00 270,83 MWD 11150,00 95,58 85,07 6489,25 -1943,67 1,61 5957202,35 568677,00 8262,13 12,00 270,54 MWD 11175,00 95,59 82,06 6486,81 -1940,88 5957205,34 568701.70 8286,67 12,00 270,25 MWD 11200,00 95,58 79,04 6484,38 -1936,80 5957209,62 568726,20 8310,97 12,00 269,95 MWD 11225,00 95,55 76,03 6481,95 -1931.43 5957215,18 568750.45 8334,95 12,00 269,66 MWD 11250,00 95,51 73,01 6479,54 -1924,79 5957222,02 568774,37 8358,54 12,00 269,37 MWD 11275,00 95.46 70,00 6477,15 -1916,89 5957230,10 568797,90 8381,70 12,00 269,08 MWD 11300,00 95,39 66,99 6474,79 -1907,77 5957239.41 568820,98 8404,34 12,00 268.79 MWD 11325,00 95,30 63,98 6472.46 -1897.44 5957249,92 568843,54 8426.41 12,00 268,51 MWD 11335,51 95,26 62,71 6471.49 -1892,75 5957254,69 568852,86 8435,51 12,00 268,22 5 11350,00 95,19 64.45 6470,17 -1886,33 5957261.21 568865,72 8448,07 12,00 92,10 MWD 11375,00 95,07 67.46 6467,94 -1876,19 838 .55 5957271,53 568888,37 8470,25 12,00 92,26 MWD 11400,00 94,93 70.47 6465,76 -1867,25 840 .79 5957280,66 568911,54 8492,99 12,00 92,53 MWD 11425,00 94,78 73.48 6463,64 -1859,54 843 .47 5957288,55 568935,16 8516,24 12,00 92,79 MWD 11450,00 94,61 76.48 6461,59 -1853,08 8454,54 5957295,20 568959,17 8539,93 12,00 93,04 MWD 11475,00 94.43 79.49 6459,62 -1847,90 8478,91 5957300.58 568983,50 8564,00 12,00 93,29 MWD 11500,00 94.24 82.49 6457,73 -1843,99 8503,53 5957304,69 569008,08 8588,38 12,00 93,53 MWD 11525,00 94,04 85.49 6455,92 -1841,38 8528,32 5957307,50 569032,85 8613,01 12,00 93.76 MWD . BP-GDB Baker Hughes INTEQ Planning Report . 11550,00 93,83 88.49 6454,21 -1840,08 8553,23 5957309,00 569057,74 8637,81 12,00 93,97 MWD 11575,00 93,60 91.49 6452,59 -1840,07 8578,17 5957309,21 569082,68 8662,72 12,00 94,18 MWD 11600,00 93,37 94.49 6451,07 -1841.37 8603,09 5957308,11 569107,61 8687,67 12,00 94,37 MWD 11625,00 93,13 97.48 6449,65 -1843,97 8627,91 5957305,71 569132.44 8712,59 12,00 94,55 MWD 11650,00 92,88 100.47 6448,34 -1847,87 8652,57 5957302,01 569157,13 8737.42 12,00 94,72 MWD 11675,00 92,62 103.47 6447,14 -1853,05 8676,99 5957297,03 569181,59 8762,08 12,00 94,88 MWD 11685,51 92,51 104,72 6446,67 -1855,60 8687,18 5957294,56 569191,80 8772,39 12,00 95,02 6 11700,00 92,06 103,04 6446,10 -1859,08 8701,23 5957291,20 569205,88 8786,60 12,00 255,00 MWD 11725,00 91,27 100,15 6445,37 -1864,10 8725,71 5957286,37 569230,39 8811,31 12,00 254,93 MWD 11750,00 90.49 97.25 6444,99 -1867,88 8750.41 5957282,79 569255,13 8836,18 12,00 254,85 MWD 11760,51 90,16 96,03 6444,93 -1869,10 8760,86 5957281,66 569265,58 8846,67 12,00 254,80 7 11775,00 90,02 94,30 6444,91 -1870.40 8775.28 5957280.47 569280,01 8861,15 12,00 265.40 MWD 11800,00 89,78 91,31 6444,95 -1871.62 8800,25 5957279.45 569304,99 8886,14 12,00 265.40 MWD 11825,00 89,54 88,32 6445,10 -1871,54 8825.25 5957279,73 569329,98 8911,10 12,00 265.40 MWD 11850,00 89,30 85,33 6445,35 -1870,16 8850,20 5957281,32 569354,92 8935,95 12,00 265.42 MWD 11875,00 89,06 82,34 6445,71 -1867.47 8875,05 5957284.20 569379,75 8960,63 12,00 265.45 MWD 11900,00 88,83 79,35 6446,17 -1863,50 8899,73 5957288,38 569404,39 8985,06 12,00 265.49 MWD 11925,00 88,60 76,35 6446,74 -1858,24 8924,16 5957293,83 569428,77 9009,18 12,00 265,55 MWD 11935,51 88,50 75,10 6447,00 -1855,64 8934,35 5957296,50 569438,94 9019.22 12,00 265,62 8 11950,00 88,50 76,84 6447,38 -1852,13 8948,39 5957300,13 569452,95 9033,06 12,00 90,00 MWD 11975,00 88,50 79,84 6448,04 -1847,08 8972,87 5957305.38 569477,38 9057,24 12,00 89,95 MWD 12000,00 88,51 82,84 6448,69 -1843,32 8997,57 5957309,34 569502,05 9081,71 12,00 89,88 MWD 12025,00 88,53 85,84 6449,33 -1840,85 9022.44 5957312,00 569526,90 9106.41 12,00 89,80 MWD 12050,00 88,54 88,84 6449,97 -1839,69 9047.40 5957313,37 569551,85 9131.28 12,00 89,72 MWD 12075,00 88,56 91,84 6450,60 -1839,84 9072,39 5957313.42 569576,83 9156,24 12,00 89,64 MWD 12100,00 88,59 94,84 6451,23 -1841,30 9097,33 5957312,16 569601,79 9181,23 12,00 89,57 MWD 12125,00 88,62 97,84 6451,84 -1844,06 9122,17 5957309,60 569626,64 9206,18 12,00 89.49 MWD 12150,00 88,65 100,84 6452.43 -1848,11 9146,83 5957305.75 569651,33 9231.02 12,00 89.42 MWD 12175,00 88,68 103,84 6453,01 -1853.45 9171,24 5957300,60 569675,78 9255,68 12,00 89,35 MWD 12185,51 88,70 105,11 6453.25 -1856,08 9181.42 5957298,06 569685,98 9265,98 12,00 89,28 9 12200,00 88,70 103,37 6453,58 -1859,64 9195.46 5957294.61 569700,05 9280,18 12,00 270.00 MWD 12225,00 88,70 100,37 6454,15 -1864,78 9219,91 5957289,67 569724,54 9304,87 12,00 270,04 MWD 12250,00 88,71 97,36 6454,71 -1868,63 9244,61 5957286,01 569749,26 9329,73 12,00 270,11 MWD 12275,00 88,72 94,36 6455,27 -1871,19 9269.47 5957283,66 569774,14 9354,69 12,00 270,18 MWD 12300,00 88.74 91,36 6455,83 -1872.44 9294.43 5957282.61 569799,11 9379,68 12,00 270,24 MWD 12325,00 88,76 88,36 6456,37 -1872,38 9319.42 5957282,88 569824,09 9404,64 12,00 270,31 MWD 12350,00 88,78 85,36 6456,91 -1871,01 9344,37 5957284.44 569849,03 9429,49 12,00 270,37 MWD 12375,00 88,80 82,36 6457.44 -1868,34 9369,22 5957287.32 569873,86 9454,16 12,00 270.44 MWD 12400.00 88,83 79,36 6457,96 -1864,37 9393,89 5957291.48 569898,50 9478,59 12,00 270,50 MWD 12425,00 88,86 76,36 6458.46 -1859,11 9418,33 5957296,93 569922,88 9502,72 12.00 270,56 MWD 12435,51 88,87 75,10 6458,67 -1856,52 9428,51 5957299,61 569933,05 9512,76 12,00 270.62 10 12450,00 88,88 76,84 6458,95 -1853,01 9442,56 5957303,23 569947,07 9526.60 12,00 90,00 MWD 12475,00 88.88 79,84 6459.44 -1847,96 9467,04 5957308.48 569971,50 9550,78 12,00 89,97 MWD 12500,00 88,88 82,84 6459,93 -1844,19 9491,75 5957312.44 569996,18 9575,26 12,00 89,91 MWD 12525,00 88,89 85,84 6460.42 -1841,73 9516,62 5957315,11 570021,02 9599,97 12,00 89,85 MWD 12550.00 88,91 88,84 6460.90 -1840,57 9541,58 5957316.47 570045,98 9624,84 12,00 89,79 MWD 12575,00 88,92 91,84 6461,37 -1840,71 9566,58 5957316,52 570070,97 9649,80 12,00 89,73 MWD 12600,00 88,94 94,84 6461,84 -1842,17 9591,53 5957315,27 570095,92 9674,79 12,00 89,68 MWD 12625,00 88,96 97,84 6462,29 -1844.93 9616,37 5957312,71 570120,78 9699,74 12,00 89.62 MWD 12650,00 88,99 100,84 6462,74 -1848,99 9641,03 5957308,85 570145.47 9724,58 12,00 89,56 MWD 12675,00 89,01 103,84 6463,18 -1854,33 9665.44 5957303.70 570169,93 9749,25 12,00 89,51 MWD 12685,51 89,03 105,10 6463,36 -1856,96 9675,62 5957301,16 570180.13 9759,55 12,00 89.46 11 12700.00 88,89 103,37 6463,62 -1860,52 9689,66 5957297,71 570194,19 9773.75 12,00 265.40 MWD . BP-GDB Baker Hughes INTEQ Planning Report . 12725,00 88,65 100,38 6464,16 -1865,66 9714,12 5957292.77 570218,69 9798.45 12,00 265.43 MWD 12750,00 88.42 97,39 6464,80 -1869,52 9738,81 5957289,11 570243.41 9823,30 12,00 265,50 MWD 12775,00 88.19 94,39 6465,54 -1872,08 9763,66 5957286.74 570268,28 9848,26 12,00 265,57 MWD 12800,00 87,96 91.40 6466,38 -1873,35 9788,61 5957285,68 570293,24 9873,24 12,00 265,66 MWD 12825,00 87,74 88.41 6467,32 -1873,31 9813,59 5957285,92 570318,21 9898,18 12,00 265,76 MWD 12850,00 87,53 85.41 6468,35 -1871,96 9838,53 5957287.47 570343,14 9923,02 12,00 265,87 MWD 12875,00 87,32 82.42 6469.47 -1869,31 9863,36 5957290,32 570367,94 9947,68 12,00 266,00 MWD 12900,00 87,13 79.42 6470,68 -1865,37 9888,02 5957294.46 570392,56 9972.09 12,00 266,13 MWD 12925,00 86,94 76.42 6471,98 -1860,15 9912.43 5957299.88 570416,93 9996.20 12,00 266.28 MWD 12935,51 86,86 75,16 6472,55 -1857,57 9922,61 5957302,53 570427,09 10006,23 12,00 266.43 12 12950,00 86,86 76.90 6473,34 -1854,08 9936,64 5957306,14 570441,09 10020,06 12,00 90,00 MWD 12975,00 86,87 79,91 6474,71 -1849,06 9961,09 5957311,35 570465,50 10044.21 12,00 89,90 MWD 13000,00 86,89 82,91 6476,07 -1845,33 9985,77 5957315,28 570490,14 10068,66 12,00 89,74 MWD 13025,00 86,91 85,91 6477,42 -1842,90 10010,61 5957317,91 570514,96 10093,34 12,00 89,58 MWD 13050,00 86,95 88,92 6478,76 -1841,78 10035,55 5957319,23 570539,89 10118,19 12,00 89.41 MWD 13075,00 86,99 91,92 6480,09 -1841,96 10060,51 5957319,25 570564,85 10143,12 12,00 89,25 MWD 13100,00 87,04 94,93 6481,39 -1843.45 10085.43 5957317,96 570589,77 10168,09 12,00 89,09 MWD 13125,00 87,10 97,93 6482,66 -1846,25 10110,24 5957315,37 570614,60 10193,01 12,00 88,94 MWD 13150,00 87,17 100,93 6483,91 -1850,34 10134.87 5957311.47 570639,26 10217,82 12,00 88,78 MWD 13175,00 87,24 103,93 6485,13 -1855,71 10159,25 5957306,30 570663.68 10242,45 12,00 88,63 MWD 13185,51 87,28 105,20 6485,64 -1858,35 10169.41 5957303,74 570673,87 10252.73 12,00 88.49 13 13200,00 87,28 103.46 6486,32 -1861,93 10183.43 5957300,27 570687,91 10266,92 12,00 270,00 MWD 13225,00 87.29 100.45 6487,51 -1867,11 10207,86 5957295,29 570712,38 10291,59 12,00 270,08 MWD 13250.00 87,30 97.45 6488,69 -1870,99 10232,52 5957291,61 570737,07 10316,42 12,00 270.22 MWD 13275,00 87,33 94.45 6489,86 -1873,58 10257,36 5957289,22 570761,92 10341,36 12,00 270,37 MWD 13300,00 87,36 91.44 6491,02 -1874,86 10282,30 5957288,14 570786.87 10366,33 12,00 270,51 MWD 13325,00 87,39 88.44 6492,16 -1874.84 10307,27 5957288,36 570811,84 10391,26 12,00 270,65 MWD 13350,00 87.44 85.44 6493,29 -1873.51 10332,20 5957289,90 570836,76 10416,09 12,00 270,78 MWD 13375,00 87.49 82.44 6494.40 -1870,87 10357,04 5957292,73 570861,57 10440,76 12,00 270,92 MWD 13385,51 87.51 81,17 6494,86 -1869,37 10367.43 5957294,31 570871,95 10451,06 12,00 271,05 14 13400,00 87,54 82,91 6495.48 -1867,37 10381,76 5957296.43 570886,26 10465.27 12,00 89,30 MWD 13425,00 87,58 85,92 6496,55 -1864,94 10406,62 5957299,06 570911,10 10489,96 12,00 89,22 MWD 13450,00 87,63 88,92 6497,59 -1863,81 10431,57 5957300,39 570936,03 10514,82 12,00 89,10 MWD 13475,00 87,69 91,92 6498,61 -1863,99 10456,55 5957300,41 570961.01 10539.77 12,00 88,97 MWD 13500,00 87.75 94,92 6499,61 -1865.48 10481.48 5957299,12 570985.95 10564,75 12,00 88,85 MWD 13525.00 87,82 97,92 6500,57 -1868.28 10506,30 5957296,52 571010.79 10589,68 12,00 88,73 MWD 13550,00 87.90 100,92 6501,51 -1872,37 10530,94 5957292,63 571035.46 10614.50 12,00 88,61 MWD 13575,00 87,98 103,93 6502.41 -1877,74 10555,34 5957287.46 571059.90 10639,15 12.00 88,50 MWD 13600,00 88,06 106,93 6503,27 -1884,39 10579.42 5957281,01 571084,03 10663,54 12,00 88,39 MWD 13625,00 88,16 109,93 6504,10 -1892,28 10603,12 5957273,30 571107,80 10687,63 12,00 88.29 MWD 13635,51 88.20 111.19 6504.43 -1895,97 10612,96 5957269,69 571117,66 10697,65 12,00 88,19 15 13650,00 88,20 109.45 6504,89 -1901,00 10626,54 5957264,77 571131,28 10711.47 12.00 270,00 MWD 13675,00 88,20 106.45 6505,67 -1908,70 10650,31 5957257,27 571155,11 10735,61 12,00 270,05 MWD 13700,00 88,21 1 03.45 6506.45 -1915,14 10674.45 5957251,02 571179.30 10760,05 12,00 270,15 MWD 13725,00 88,23 100.44 6507,23 -1920,32 10698,89 5957246,04 571203.78 10784,73 12,00 270,24 MWD 13750,00 88,25 97.44 6508,00 -1924.20 10723,58 5957242,36 571228.49 10809,58 12,00 270,34 MWD 13775,00 88,27 94.44 6508,76 -1926,79 10748.43 5957239,97 571253,36 10834,54 12,00 270.43 MWD 13800,00 88.30 91.44 6509,50 -1928,07 10773,38 5957238,89 571278,32 10859,52 12.00 270,52 MWD 13825.00 88.34 88.44 6510,24 -1928,04 10798,37 5957239,12 571303,30 10884.47 12,00 270,61 MWD 13850,00 88.38 85.44 6510,95 -1926,71 10823,32 5957240,65 571328.24 10909,32 12,00 270,70 MWD 13875,00 88.42 82.44 6511,65 -1924,07 10848.17 5957243.49 571353.06 10934,00 12,00 270.78 MWD 13885,51 88.44 81,18 6511,94 -1922,57 10858,57 5957245,07 571363.45 10944.31 12,00 270,87 16 . BP-GDB Baker Hughes INTEQ Planning Report . 13900,00 88.44 82,91 6512,33 -1920,57 10872,91 5957247,19 571377.77 10958,52 12,00 90,00 MWD 13925,00 88.44 85,92 6513,01 -1918,14 10897,78 5957249,83 571402,62 10983.23 12,00 89,95 MWD 13950,00 88.45 88,92 6513,69 -1917,01 10922,74 5957251,15 571427,57 11008,10 12,00 89,87 MWD 13975,00 88.47 91,92 6514,36 -1917,19 10947.73 5957251,17 571452.55 11033,06 12,00 89,79 MWD 14000,00 88.48 94,92 6515,03 -1918,68 10972.67 5957249.88 571477.51 11058,05 12,00 89,71 TD . . AM Plan: Plan #3 (1D-11/Plan#3 10-11L2 Created By: Bni Potni Date: 10122/2004 Contact ¡nfor~na! Snk{;1' HU~lhe "r""'" , ,-"'CT;"', , , ':"r':"'""r~;--',['Tj'I' I' ,;"'1 r''''l , 8600 8700 8800 8900 9000 9100 9200 9300 9400 9500 9600 9700 9800 990010000101001020010300104001050010600107001080010900 West{. )/East{ +) [100ftli 5001160011700 Azimuths to True North Ma9netic North: 24,60" Magnetic Field Strength: 57580nT Dip Angle: 80,75" Date: 10/22/2004 Model: bggm2004 000111001120011300114001 SECTION DETAILS +NI.. +EI.W "'20.15 ~=:!: :i!::! -1855.64 ~=:: ~::;::; .1858.:s/J -18611.37 -1895.17 ::= liD 1_ Azj TYD 4.0057.10102.61 MD.Z4 '35.0058.114 102.57 8458.11 55.00 58.68 ,oz.02 0466.77 085.51 H.50 112.84 8495.48 335.518.26 62.71 8471.48 685.5' H.51 104.72 6446.67 760.51 to.1. ".03 N4433 935.51 aa.so 75.10 6447.00 185.5188.70 105.11 6453.Z5 435.5, ..17 75.10 11458.87 885.5' 119.G3 105.10 64&3.38 1:15.5'88.88 78.18 8472.55 185.5' 87.28 1ÐS.20 6485.84 385.11187.51 81.17 84114.&6 635.51 88.20 111.1It 8504.43 ....... .. 0... DD. ., 000.00...48 IMlodttåM: TYD MD Annotation '.39.2' 6458.11 ....,77 8495.49 647'.49 8446.87 .......3 8447.00 6453,26 6458.87 6463.36 8472.55 8485.63 ........ '504.43 6511.94 6515.03 ,,, '", np 10 KO,. 10· end' DLS J b.8ln 29 ~ ;nd 29 DLS I "'.gln 12 · , · · ,. " ,. " " " . ii'''' '-'-r-- I ." ""1 :1, ¡' 7900 8000 8100 8200 8300 8400 8500 8600 8700 8800 8900 9000 9100 9200 9300 9400 9500 9600 9700 9800 9900100001010010200103001040010500106001070010800109001 Vertical Section at 93.00· [100ft/in] T 4M LEGEND ~g:n f~~~iJ 1D- Plan#3 10-11 L2 Ptan#3 ConocoPhillips Alaska, Inc1 WELL..T. .ETAlLS onocJ"'Phillip; Pt..nlt3 1 D-11 L2 500292294681 ParentWell,.tbl ,...., Tie on MD; 10904.,00 lUg; Nonllc2 Ref.D.lunI; 1D-11 105.5Oft Y...ettlNl ~,,!: ~=,.; :=I~ Angl. 93.00' .,.. .... .,.. -. C-1 æ 0-1' o ~-1" - .:t.-1I .c: 1:: 0-1900 ~ ",,;,.21 -- .c: ';,2 o en -2, REFERENCE INFORMATION WeIICentre:1[}'11, True North ~r~~{b.~g~~~ö~¡eVel 1D-11 105,50 Minimum ClXVature TF.... va_ G.GG 8G31.24 ~~:: ::::: ·1s.oG 81118.115 171.00 1435.51 12.1G 1772.39 H.OO 11841.I5Y 65.40 110.,..22 H.OO '2115.98 :-.:: m~ 65.40 10001.23 :::: ;=~~ 11I.30 1Ð611Y.85 --- ..DlTAA1Q!!I8.OS .ow·S .Ë/_W ·1~.90 8753.31 ~ißi:H :Hf!~ñ Co-ordinate (NÆ) Reference: V~~~~J ~:~:~:~ Measured Depth Reference: Calculation Method: 56' -. C æ571 o 058C ... ... .c: 59C .. f60c CI iii 61 0 U :e 6201 ( I > 6300:1 ( Ii 264 ... 651 Plan: Plan #3 (1 D-ll IPlan#3 1 D-ll L2) o 10000 10500 11000 11500 12000 12500 13000 13500 14000 Measured Depth [ft] 500 ,.-.., ~ . L..-I ~ 400 0 .~ ~ a ~ r/) 300 (j) b ~ (j) u 0 200 ~ (j) b . ~ (j) U 100 ID-II (ID-11) ID-II (Plan#4ID-IILI) Plan: Plan #3 (lD-lI/Plan#3 lD-lIL2) o 10000 10500 11000 11500 12000 12500 13000 13500 14000 10000 ,--, ~ L-....I . ~ 8000 0 ...... ~ a ff 6000 r/l (1) ~ -s (1) u 4000 0 ~ (1) Jj ~ . (1) U 2000 Measured Depth [ft ] ID-II (lD-II) ID-30 (lD-30LI) ID-ll (Plan#4 ID-llLI) ID-32 (lD-32) ID-30 (lD-30) ID-32 (Plan#7 ID-32LI) . BP-GDB Anticollision Report . Plan #3 Identical to Lamar's Plan #3 Yes Date Composed: Version: Tied-to: 10/22/2004 1 From: Definitive Path Summary KRU 1D Pad KRU 1D Pad KRU 1D Pad KRU 1D Pad KRU 1D Pad KRU 1D Pad 1D-11 10-11 1 D-30 1 D-30 1 D-32 1 D-32 10-11 V1 10940,00 10940,00 Plan#41O-11L1 V1 Plan 12204,18 12180,00 1 D-30 V1 10938,57 11590,00 1O-30L1 V3 10938,57 11590,00 10-32 V1 10935,57 12940,00 Plan#71D-32L1 V7 Plan 10935,57 12940,00 0,02 145,51 2869,99 2869,99 5052,00 5052,00 No Reference Casings No Reference Casings No Reference Casings No Reference Casings No Reference Casings No Reference Casings Site: KRU 1 D Pad Well: 1D-11 Wellpath: 1D-11 V1 Rule Assigned: Major Risk Inter-Site Error: 0,00 ft 10940,00 6564,32 10940,00 6564,34 246,33 246,37 102.43 0,00 0,02 FAIL 10950,00 6569,65 10950,00 6569,80 246,33 246,39 269,16 167,00 0,18 No Reference Casings 10959,98 6574,80 10960,00 6575,27 246,31 246,39 269,05 167.46 0,55 No Reference Casings 10969,89 6579,54 10970,00 6580,75 246,23 246,32 268,19 167.42 1,39 No Reference Casings 10979.70 6583,80 10980,00 6586.23 246,11 246.22 267.48 167.49 2,73 No Reference Casings 10989,36 6587,58 10990,00 6591.72 245,95 246,08 266,88 167,61 4,57 No Reference Casings 10998,81 6590,86 11000,00 6597,22 245,76 245,91 266,33 167,75 6,88 No Reference Casings 11008,03 6593,67 11010,00 6602,72 245,54 245.70 265.79 167,87 9,66 No Reference Casings 11016,99 6596,00 11020,00 6608,23 245,29 245.48 265.25 167,94 12,88 No Reference Casings 11025,66 6597,90 11030,00 6613,74 245,03 245,24 264,72 168,00 16,52 No Reference Casings 11034,02 6599,39 11040,00 6619,26 244,76 244,98 264,20 168,03 20,57 No Reference Casings 11042,06 6600,50 11050,00 6624,78 244.48 244.72 263,69 168,05 25,00 No Reference Casings 11049,77 6601.26 11060,00 6630,31 244,20 244.46 263,19 168,05 29,79 No Reference Casings 11057,15 6601,72 11070,00 6635,84 243,91 244,19 262,70 168.03 34.91 No Reference Casings 11064,20 6601,91 11080,00 6641,37 243,63 243,93 262,22 168,01 40,35 No Reference Casings 11070,93 6601.86 11090,00 6646,91 243,36 243,68 261.76 167,97 46,08 No Reference Casings 11077,33 6601,60 11100,00 6652.46 243,09 243.43 261,30 167,93 52,08 No Reference Casings 11083.43 6601,17 11110,00 6658,00 242,83 243,20 260,83 167,85 58,35 No Reference Casings 11090,28 6600,53 11120,00 6663,56 242,28 242,69 259,96 167,69 64,81 No Reference Casings 11097,63 6599,82 11130,00 6669,11 241,57 242,00 258,81 167.43 71,32 No Reference Casings 11104,91 6599,12 11140,00 6674,67 240,77 241,25 257,60 167.09 77,88 No Reference Casings 11112,12 6598.42 11150,00 6680,24 239,92 240.45 256,33 166,70 84.47 No Reference Casings 11119,27 6597,73 11160,00 6685,80 239,09 239,61 255,04 166,26 91,09 No Reference Casings 11126,35 6597,05 11170,00 6691,37 238.22 238,72 253,72 165.80 97,76 No Reference Casings 11133,36 6596,37 11180,00 6696,94 237,22 237.79 252.41 165,33 1 04.46 No Reference Casings 11140,30 6595,69 11190,00 6702,51 236,23 236,82 251,10 164,86 111,19 No Reference Casings 11147,17 6595,02 11200,00 6708,08 235,24 235,81 249,79 164,38 117,96 No Reference Casings 11153,98 6594,36 11210,00 6713,65 234,17 234,76 248.49 163,90 124,76 No Reference Casings 11160.71 6593,71 11220,00 6719,22 233,03 233,68 247.19 163.42 131,59 No Reference Casings . BP-GDB Anticollision Report . 10940,00 6564,32 10940,00 6564,34 246,33 246,33 102.43 0,00 0,02 FAIL 10950,00 6569,65 10950,00 6569,80 246,33 246,35 269,16 167,00 0,18 No Reference Casings 10959,98 6574,80 10960,00 6575.27 246,31 246,33 269,05 167.46 0,55 No Reference Casings 10969,89 6579,54 10970,00 6580,75 246,23 246,26 268.19 167.42 1,39 No Reference Casings 10979,70 6583,80 10980,00 6586,23 246,11 246,15 267.48 167.49 2,73 No Reference Casings 10989,36 6587,58 10990,00 6591,72 245,95 246,00 266,88 167,61 4,57 No Reference Casings 10998,81 6590,86 11000,00 6597,22 245,76 245,82 266,33 167,75 6,88 No Reference Casings 11008,03 6593,67 11010,00 6602,72 245,54 245,59 265,79 167,87 9,66 No Reference Casings 11016,99 6596,00 11020,00 6608.23 245,29 245,35 265,25 167,95 12,88 No Reference Casings 11025,69 6597,91 11030,00 6613,68 245,03 245,09 264,65 167,93 16.45 No Reference Casings 11034,14 6599.41 11040,00 6618,99 244,76 244,81 263,97 167,81 20.28 No Reference Casings 11042.45 6600,54 11050,00 6623,89 244.47 244,52 263,06 167.44 24,09 No Reference Casings 11050.73 6601,34 11060,00 6628,10 244,16 244,22 261,83 166,75 27,58 No Reference Casings 11058,98 6601,79 11070,00 6631,59 243,84 243,90 260,36 165,81 30,75 No Reference Casings 11067,20 6601,91 11080,00 6634,32 243,51 243,57 258,69 164,67 33,60 No Reference Casings 11075.40 6601,70 11090,00 6636,30 243,17 243,23 256,84 163,35 36,15 No Reference Casings 11083,56 6601,16 11100,00 6637,50 242,82 242,89 254,82 161,85 38,38 No Reference Casings 11092,73 6600,29 11110,00 6637,91 242,05 242,14 252,02 160,05 40,21 No Reference Casings 11102,23 6599,38 11120,00 6637,56 241,08 241,18 248,57 157.74 41.44 No Reference Casings 11111,63 6598.4 7 11130,00 6636,93 239,98 240,13 244,72 155,02 42,63 No Reference Casings 11120,89 6597,57 11140,00 6636,30 238,90 239,01 240,57 151,99 44,07 No Reference Casings 11129,99 6596.69 11150,00 6635,67 237,70 237,82 236,22 148,74 45,82 No Reference Casings 11138,92 6595,83 11160,00 6635,05 236.42 236,57 231.76 145,36 47,90 No Reference Casings 11147,64 6594,98 11170,00 6634.42 235,17 235.27 227,27 141,92 50,35 No Reference Casings 11156,16 6594,15 11180,00 6633,80 233,80 233.92 222.84 138,51 53,19 No Reference Casings 11164,45 6593,34 11190,00 6633,18 232.40 232,54 218,51 135,19 56.42 No Reference Casings 11172,51 6592,56 11200,00 6632,56 231,04 231,14 214,36 132,00 60,06 No Reference Casings 11180,32 6591,79 11210,00 6631,94 229,59 229,71 210.41 128,99 64.10 No Reference Casings 11187,88 6591,06 11220,00 6631,33 228,13 228,27 206,68 126,18 68,54 No Reference Casings 11195,32 6590,33 11230,00 6630,71 226.69 226,80 203,28 123,67 73,17 No Reference Casings 11202.71 6589,62 11240,00 6630,10 225,19 225,28 200,20 121.48 77.89 No Reference Casings 11210,05 6588,90 11250.00 6629.48 223,59 223,73 197,38 119,56 82,66 No Reference Casings 11217,35 6588,19 11260,00 6628,87 222,00 222,13 194,80 117,85 87.48 No Reference Casings 11224.60 6587.49 11270,00 6628,26 220.41 220.48 192.42 116,34 92,31 No Reference Casings 11231,81 6586,80 11280,00 6627,65 218,68 218,80 190,20 114,99 97,16 No Reference Casings 11238,98 6586.10 11290,00 6627,04 216,94 217,08 188.12 113.78 102,02 No Reference Casings 11246.10 6585.42 11300,00 6626.44 215.22 215,32 186.17 112,68 106,86 No Reference Casings 11253.19 6584,74 11310,00 6625,83 213.43 213,52 184,32 111,69 111,69 No Reference Casings 11260.25 6584,06 11320,00 6625,23 211,56 211,69 182,57 110.79 116.50 No Reference Casings 11267.27 6583,39 11330,00 6624,63 209,69 209,82 180,91 109,97 121.29 No Reference Casings 11274,25 6582,72 11340,00 6624,04 207,84 207,92 179,31 109,22 126,05 No Reference Casings 11281.20 6582,06 11350,00 6623.44 205,86 205,98 177.79 108,53 130,77 No Reference Casings 11288.12 6581.41 11360,00 6622,85 203,87 204,00 176,32 107.90 135.46 No Reference Casings 11295,01 6580,76 11370,00 6622,27 201,89 202,00 174.90 107.31 140,11 No Reference Casings . BP-GDB Anticollision Report . 11301,87 6580,11 11380,00 6621,69 199,87 199,96 173,53 106,77 144,72 No Reference Casings 11308,70 6579.47 11390,00 6621,11 197,76 197,89 172,21 106,27 149,28 No Reference Casings 11315,50 6578,84 11400,00 6620,54 195,66 195,78 170,92 105,80 153,80 No Reference Casings 11322,28 6578,21 11410,00 6619,97 193,56 193,65 169,67 105,37 158,27 No Reference Casings 11329,03 6577,59 11420,00 6619.41 191.41 191.49 168.45 104,96 162,69 No Reference Casings 11336,01 6576,95 11430,00 6618,85 189.47 189,54 167,36 104,59 167,06 No Reference Casings 11349,90 6575,68 11440,00 6618,30 193,99 194,06 168,92 104.48 171,17 No Reference Casings 11364,27 6574,39 11450,00 6617,75 198.44 198,57 170,59 104.42 174,84 No Reference Casings 11379,09 6573,08 11460,00 6617,21 202,93 203,04 172,36 104.41 178,04 No Reference Casings 11394,30 6571,75 11470,00 6616,68 207,30 207.43 174.23 104.45 180,76 No Reference Casings 11409,84 6570.42 11480,00 6616,15 211,56 211,70 176,18 104,53 182,98 No Reference Casings 11425,66 6569,09 11490,00 6615,63 215,74 215,82 178,21 104,65 184,70 No Reference Casings 11441,68 6567,77 11500,00 6615,11 219,62 219.76 180.29 104,81 185,88 No Reference Casings 11457,83 6566.47 11510,00 6614,61 223,35 223.49 182.43 105,00 186,55 No Reference Casings 11474,02 6565,20 11520,00 6614,11 226,89 226,98 184,61 105,24 186,68 No Reference Casings 11490,18 6563.96 11530,00 6613,62 230,05 230,20 186,82 105,50 186,28 No Reference Casings 11506,24 6562.77 11540,00 6613,13 233,01 233,15 189.05 105,81 185,35 No Reference Casings 11522,12 6561.63 11550,00 6612,66 235,69 235,81 191,30 106,15 183,90 No Reference Casings 11537.74 6560.54 11560,00 6612,19 238,01 238,17 193,55 106,53 181,94 No Reference Casings 11553,04 6559,51 11570,00 6611,73 240,13 240.25 195,81 106,95 179.49 No Reference Casings 11568,10 6558,53 11580,00 6611,27 241,90 242,05 198,06 107,39 176,81 No Reference Casings 11582,97 6557,59 11590,00 6610,82 243.44 243,60 200,29 107.84 174,03 No Reference Casings 11597,65 6556,71 11600,00 6610,36 244,79 244,90 202.50 108.30 171,17 No Reference Casings 11612,14 6555,87 11610,00 6609,91 245,79 245,95 204,71 108,77 168,22 No Reference Casings 11626.44 6555,07 11620,00 6609.45 246,68 246,78 206,90 109,25 165,19 No Reference Casings 11640,56 6554,32 11630,00 6609,00 247,22 247,38 209,09 109,74 162,08 No Reference Casings 11654,49 6553,62 11640,00 6608,55 247.63 247,76 211,26 110,25 158,91 No Reference Casings 11668,23 6552,96 11650,00 6608.10 247.79 247,93 213.43 110.77 155,66 No Reference Casings 11681,78 6552.34 11660,00 6607.65 247,82 247,91 215,59 111,31 152.35 No Reference Casings 11690,93 6551,94 11670,00 6607,20 247,85 247,95 215,87 111,77 149,08 No Reference Casings 11698.53 6551,65 11680,00 6606,76 247,93 248,01 215,39 112,17 146,11 No Reference Casings 11706,26 6551,38 11690.00 6606,31 247,89 248,02 214,84 112.53 143.46 No Reference Casings 11714,10 6551,15 11700,00 6605,87 247,82 247,97 214,24 112,83 141,12 No Reference Casings 11722,04 6550,94 11710,00 6605.43 247,74 247,85 213,56 113,07 139,11 No Reference Casings 11730,06 6550,77 11720,00 6605,00 247,54 247,67 212,81 113,25 137.41 No Reference Casings 11738.15 6550,63 11730.00 6604,57 247.27 247.42 211,99 113,36 136,04 No Reference Casings 11746.29 6550,52 11740,00 6604,14 246,99 247,10 211,08 113.40 135,00 No Reference Casings 11754.46 6550.45 11750,00 6603,71 246,63 246,71 210,1 ° 113,37 134,28 No Reference Casings 11762,60 6550.42 11760,00 6603.29 246,17 246,26 209,04 113,26 133,88 No Reference Casings 11770,61 6550.41 11770.00 6602,87 245,64 245,73 207,91 113.08 133,83 No Reference Casings 11778.60 6550.4 1 11780,00 6602.46 245,03 245,14 206,71 112,84 134,12 No Reference Casings 11786,56 6550.41 11790,00 6602,05 244,33 244.48 205.45 112,53 134,75 No Reference Casings 11794.48 6550.43 11800,00 6601.64 243,63 243.75 204,14 112.17 135,74 No Reference Casings 11802.33 6550.46 11810,00 6601,24 242,88 242,97 202,78 111.75 137.06 No Reference Casings 11810,11 6550,50 11820.00 6600,84 241,99 242,14 201,38 111.28 138,73 No Reference Casings 11817.84 6550,55 11830.00 6600,46 241,10 241,24 199,99 110,81 140,50 No Reference Casings 11825.56 6550,60 11840,00 6600,10 240,21 240,28 198,62 110,36 142,23 No Reference Casings 11833,26 6550,67 11850,00 6599,75 239,13 239,27 197,27 109,94 143.93 No Reference Casings 11840,94 6550,75 11860,00 6599.42 238,05 238,19 195,94 109,53 145.60 No Reference Casings 11848,60 6550.84 11870,00 6599.11 236,98 237,06 194,64 109,14 147,23 No Reference Casings 11856,25 6550.93 11880,00 6598,83 235,74 235.87 193,35 108,77 148,82 No Reference Casings . BP-GDB Anticollision Report . II 11863,89 6551,04 11890.00 6598,56 234.48 234,62 192,09 108.42 150.38 No Reference Casings 11871,50 6551,16 11900,00 6598,30 233,21 233,32 190,84 108,09 151,90 No Reference Casings 11879,11 6551,28 11910,00 6598,07 231,85 231,96 189,61 107,77 153,38 No Reference Casings 11886,69 6551.42 11920,00 6597,86 230.40 230,54 188.40 107.46 154,82 No Reference Casings 11894,27 6551,56 11930,00 6597,67 228,95 229,07 187,20 107,17 156,22 No Reference Casings 11901,83 6551,71 11940,00 6597,50 227,46 227,55 186,02 106,89 157,57 No Reference Casings 11909,38 6551,87 11950,00 6597,34 225,83 225,97 184,86 106,63 158,89 No Reference Casings 11916,92 6552,04 11960,00 6597,21 224,21 224,34 183,71 106,38 160,16 No Reference Casings 11924.45 6552,22 11970,00 6597,1 ° 222,59 222,66 182,57 106.15 161,39 No Reference Casings 11931,96 6552.41 11980,00 6597,00 220,85 220,93 181.45 105,92 162,58 No Reference Casings 11943,31 6552,71 11990,00 6596,93 221,87 221,97 181,71 105,68 163,66 No Reference Casings 11958,21 6553,1 ° 12000,00 6596,87 225,25 225,39 183,28 105.46 164,30 No Reference Casings 11973.16 6553.49 12010,00 6596,84 228,52 228,61 184,91 105.29 164.44 No Reference Casings 11988,11 6553,88 12020,00 6596,83 231.46 231,61 186,59 105,18 164,10 No Reference Casings 12003,03 6554,26 12030,00 6596,83 234,27 234,37 188,30 105,10 163,52 No Reference Casings 12017,92 6554,65 12040,00 6596,86 236,76 236,90 190,02 105,03 162.84 No Reference Casings 12032.76 6555,03 12050,00 6596,91 239,06 239,20 191,75 104,98 162.07 No Reference Casings 12047,55 6555.41 12060,00 6596,97 241,16 241.26 193.49 104,95 161.21 No Reference Casings 12062,29 6555,78 12070,00 6597,06 242,92 243,08 195,25 104,93 160,26 No Reference Casings 12076.97 6556,15 12080,00 6597,17 244,57 244,67 197.01 104,93 159.22 No Reference Casings 12091,59 6556,52 12090,00 6597.29 245,87 246,02 198,78 104,95 158,09 No Reference Casings 12106,14 6556,88 12100,00 6597.44 247,00 247,13 200,57 104,99 156,87 No Reference Casings 12120,61 6557,23 12110,00 6597,61 247,89 248,02 202,36 105,05 155,56 No Reference Casings 12135,00 6557,58 12120,00 6597,79 248,52 248,67 204,17 105,12 154,18 No Reference Casings 12149,31 6557,92 12130,00 6598,00 249,02 249,1 ° 205,98 105,22 152,71 No Reference Casings 12163,54 6558,25 12140,00 6598,22 249,14 249,30 207,81 105.34 151,16 No Reference Casings 12177.67 6558,58 12150,00 6598.47 249,20 249,28 209,64 105.48 149,54 No Reference Casings 12188,87 6558,83 12160,00 6598,73 249,16 249,25 210,36 105,66 147.88 No Reference Casings 12196,50 6559,00 12170,00 6599,02 249,28 249,37 209,64 105,85 146,51 No Reference Casings 12204,18 6559.18 12180,00 6599,32 249,32 249.43 208,88 106.02 145,51 No Reference Casings 12211,90 6559,35 12190,00 6599,64 249.27 249.43 208,09 106,15 144,86 No Reference Casings 12219,64 6559.53 12200,00 6599,98 249,23 249,36 207,26 106,25 144,57 No Reference Casings 12227,39 6559,70 12210,00 6600,34 249,12 249.22 206.40 106,32 144,64 No Reference Casings 12235.12 6559,88 12220,00 6600,72 248,87 249,02 205,50 106,35 145,08 No Reference Casings 12242.83 6560,05 12230,00 6601,11 248,61 248,75 204,58 106,35 145,87 No Reference Casings 12250,51 6560,22 12240,00 6601,53 248.35 248.43 203,62 106.32 147,03 No Reference Casings 12258.12 6560,39 12250.00 6601,96 247.89 248,04 202,64 106,25 148.54 No Reference Casings 12265,67 6560.56 12260.00 6602.41 247.44 247,59 201,64 106.16 150.40 No Reference Casings 12273,14 6560,73 12270,00 6602,88 246,99 247,09 200.62 106.04 152,61 No Reference Casings 12280,56 6560,90 12280,00 6603,35 246.40 246.53 199,61 105,91 154.90 No Reference Casings 12287,97 6561,06 12290,00 6603,82 245.76 245,92 198,60 105,79 157.14 No Reference Casings 12295,36 6561,22 12300,00 6604,29 245,12 245,24 197,61 105.69 159,34 No Reference Casings 12302,73 6561,39 12310,00 6604,77 244.40 244,51 196,62 105.59 161.48 No Reference Casings 12310,09 6561.55 12320,00 6605,24 243,57 243.73 195,65 105.50 163.57 No Reference Casings 12317.43 6561,71 12330,00 6605,71 242,74 242,88 194,68 105.41 165,61 No Reference Casings 12324,76 6561.87 12340,00 6606,18 241,91 241,99 193,72 105,33 167,60 No Reference Casings 12332,07 6562,03 12350,00 6606.64 240,89 241,04 192,78 105.26 169,53 No Reference Casings 12339.37 6562.18 12360.00 6607.11 239.87 240,03 191.84 105.20 171.41 No Reference Casings 12346.66 6562,34 12370,00 6607,57 238,85 238,97 190,90 105,14 173,24 No Reference Casings 12353,93 6562.49 12380,00 6608,03 237,74 237,86 189,98 105,09 175,01 No Reference Casings . BP-GDB Anticollision Report . 12361,19 6562,65 12390,00 6608.49 236,53 236,69 189,06 105,04 176,73 No Reference Casings 12368.44 6562,80 12400,00 6608,95 235,33 235.47 188,14 105,00 178,39 No Reference Casings 12375,68 6562,95 12410,00 6609.40 234,11 234.20 187,24 104,96 180,00 No Reference Casings 12382,91 6563,1 ° 12420,00 6609,85 232,73 232,88 186,34 104,93 181,55 No Reference Casings 12390,12 6563,25 12430,00 6610,30 231,35 231,51 185.44 104,90 183,05 No Reference Casings 12397,33 6563.40 12440,00 6610,75 229,97 230,09 184,55 104,87 184.49 No Reference Casings 12404,53 6563,55 12450,00 6611,19 228,49 228,61 183,67 104,85 185,87 No Reference Casings 12411.72 6563,69 12460,00 6611,63 226,93 227,09 182,79 104,84 187,19 No Reference Casings 12418,90 6563,84 12470,00 6612,06 225,38 225,52 181,92 104,83 188.46 No Reference Casings 12426,07 6563,98 12480,00 6612,49 223,81 223,90 181,05 104,82 189,67 No Reference Casings 12433,24 6564,12 12490,00 6612,91 222,14 222,23 180,19 104.82 190,83 No Reference Casings 12446,60 6564,39 12500.00 6613,34 224,25 224,35 181.22 104.79 191,81 No Reference Casings 12462,94 6564,71 12510,00 6613,75 227,90 228,06 183,17 104,78 192,29 No Reference Casings 12479,31 6565,03 12520.00 6614,16 231,38 231,51 185,17 104,81 192,24 No Reference Casings 12495,65 6565,35 12530,00 6614,57 234,55 234,68 187,18 104,87 191,92 No Reference Casings 12511,96 6565,66 12540,00 6614,98 237.40 237,57 189.20 104,93 191.47 No Reference Casings 12528.22 6565,98 12550,00 6615,39 240,06 240,18 191.23 105,00 190,90 No Reference Casings 12544.43 6566.29 12560.00 6615,80 242,36 242,51 193,26 105,09 190,20 No Reference Casings 12560.57 6566,60 12570,00 6616,21 244,38 244,55 195,30 105,19 189,38 No Reference Casings 12576,64 6566,90 12580,00 6616,62 246,19 246,30 197,34 105,30 188.44 No Reference Casings 12592,62 6567,20 12590,00 6617,02 247,61 247,77 199,38 105.42 187,37 No Reference Casings 12608,52 6567.49 12600,00 6617.43 248,79 248,96 201.42 105.56 186,19 No Reference Casings 12624,32 6567,78 12610,00 6617,83 249,77 249,86 203.47 105.71 184,90 No Reference Casings 12640,01 6568,06 12620,00 6618.23 250,33 250,49 205,51 105,87 183.49 No Reference Casings 12655,59 6568,34 12630,00 6618,63 250,71 250,85 207,56 106,05 181,98 No Reference Casings 12671,06 6568,61 12640,00 6619,03 250,82 250,95 209,60 106.24 180,35 No Reference Casings 12685,93 6568,86 12650,00 6619.42 250,73 250,81 211,50 106.44 178,63 No Reference Casings 12693,24 6568,99 12660,00 6619,82 250,86 250,96 210,86 106,69 177,04 No Reference Casings 12700,61 6569,13 12670,00 6620,21 250,97 251,06 210,19 106,89 175,80 No Reference Casings 12708,03 6569,28 12680,00 6620,58 250,94 251,10 209.47 107,06 174,90 No Reference Casings 12715.48 6569.44 12690,00 6620,94 250,91 251,07 208,71 107,19 174,34 No Reference Casings 12722,94 6569.61 12700,00 6621.28 250,88 250,99 207,89 107,27 174,11 No Reference Casings 12730.41 6569.79 12710.00 6621,61 250,71 250,85 207,04 107,31 174,22 No Reference Casings 12737,87 6569,98 12720,00 6621,91 250.48 250,64 206,14 107,30 174,68 No Reference Casings 12745,30 6570,17 12730,00 6622,19 250,25 250.38 205,20 107,25 175.47 No Reference Casings 12752,70 6570,37 12740,00 6622,46 249,94 250,06 204,22 107,16 176,59 No Reference Casings 12760,04 6570,58 12750.00 6622,70 249.52 249,68 203,21 107,03 178,05 No Reference Casings 12767,32 6570.80 12760.00 6622,93 249,09 249.25 202,17 106,86 179,85 No Reference Casings 12774,52 6571,03 12770,00 6623,14 248,68 248,77 201,1 ° 106,65 181,97 No Reference Casings 12781,68 6571,26 12780.00 6623,34 248,08 248,23 200,03 1 06.44 184,17 No Reference Casings 12788,82 6571.49 12790,00 6623,54 247.47 247,64 198,97 106,23 186,31 No Reference Casings 12795,95 6571,74 12800,00 6623,74 246,87 247,00 197,92 106.03 188.39 No Reference Casings 12803,07 6571,99 12810.00 6623,94 246,18 246,30 196,87 105,84 190.42 No Reference Casings 12810.17 6572.25 12820.00 6624,13 245,39 245,55 195,84 105,66 192,39 No Reference Casings 12817,26 6572,52 12830.00 6624,33 244.60 244,75 194,81 105.48 194,30 No Reference Casings 12824,34 6572,79 12840.00 6624,53 243,80 243,90 193,79 105,31 196,15 No Reference Casings 12831.40 6573,07 12850,00 6624,73 242,85 243,00 192.78 105,14 197,94 No Reference Casings 12838.45 6573,36 12860.00 6624,93 241,87 242,05 191,78 104,98 199.67 No Reference Casings 12845.49 6573,66 12870.00 6625,12 240,90 241,04 190,78 104,82 201,35 No Reference Casings 12852.52 6573,96 12880.00 6625,32 239,87 239,99 189,78 104,67 202,96 No Reference Casings 12859,54 6574,27 12890,00 6625,51 238,72 238.88 188,80 104,53 204.51 No Reference Casings . BP-GDB Anticollision Report . 12866,55 6574.58 12900,00 6625.71 237.57 237,73 187,81 104,38 206,00 No Reference Casings 12873,55 6574,90 12910,00 6625.90 236.42 236,53 186,84 104,25 207.43 No Reference Casings 12880,53 6575,23 12920,00 6626,09 235,13 235.28 185,87 104,11 208,79 No Reference Casings 12887,52 6575.57 12930,00 6626.28 233,81 233,98 184,90 103,98 210,09 No Reference Casings 12894.49 6575,91 12940.00 6626.47 232.49 232,64 183,94 103,86 211,34 No Reference Casings 12901.45 6576,26 12950,00 6626,65 231,13 231,24 182,98 103,74 212,52 No Reference Casings 12908.41 6576,61 12960,00 6626,84 229,64 229,80 182,03 103,62 213,63 No Reference Casings 12915,36 6576,97 12970,00 6627,02 228,15 228,32 181,08 103,50 214,68 No Reference Casings 12922.30 6577.33 12980.00 6627.20 226,66 226.78 180,13 103,39 215,67 No Reference Casings 12929.24 6577,71 12990,00 6627,38 225,10 225,21 179,19 103.28 216,60 No Reference Casings 12937,19 6578.14 13000,00 6627.56 224.04 224,15 178,52 103,16 217.46 No Reference Casings 12955,14 6579,12 13010,00 6627,74 228,23 228,38 180.43 102,91 217,96 No Reference Casings 12973,14 6580,11 13020,00 6627,91 232,17 232,29 182,37 102,69 217,89 No Reference Casings 12991,12 6581,09 13030,00 6628.08 235,70 235,87 184,34 102,50 217.53 No Reference Casings 13009,06 6582.06 13040,00 6628,26 238,94 239,12 186,31 102,31 217,00 No Reference Casings 13026,95 6583,03 13050,00 6628.43 241.89 242,02 188,28 102,13 216,30 No Reference Casings 13044,78 6583,99 13060,00 6628,60 244.42 244,57 190,26 101.97 215.45 No Reference Casings 13062,52 6584,93 13070,00 6628,78 246,59 246,78 192,24 101,82 214.45 No Reference Casings 13080,16 6585,86 13080,00 6628,95 248.48 248,63 194.22 101.67 213,28 No Reference Casings 13097,69 6586,77 13090,00 6629.12 250,02 250,14 196,19 1 ° 1,54 211,97 No Reference Casings 13115,10 6587,66 13100.00 6629,29 251,13 251,31 198,16 101.42 210,50 No Reference Casings 13132,38 6588,54 13110.00 6629.46 251,97 252,14 200,13 101,31 208,88 No Reference Casings 13149,50 6589.39 13120,00 6629,63 252,53 252,64 202,09 101,22 207,12 No Reference Casings 13166.47 6590,22 13130,00 6629,80 252,64 252,81 204,04 101,13 205,22 No Reference Casings 13183.27 6591.03 13140,00 6629,97 252,57 252,67 205,99 101,06 203,18 No Reference Casings 13191,51 6591.42 13150,00 6630.14 252.66 252,78 205,58 101,11 201,19 No Reference Casings 13198,50 6591,75 13160,00 6630,30 252,80 252,90 204,79 101,15 199.53 No Reference Casings 13205,53 6592,09 13170,00 6630.47 252,82 252,97 203,97 101,18 198.22 No Reference Casings 13212,61 6592.42 13180,00 6630,63 252,81 252,99 203,12 101,18 197,26 No Reference Casings 13219.71 6592,76 13190,00 6630.79 252,80 252,95 202.26 101,17 196,64 No Reference Casings 13226,83 6593,09 13200,00 6630,96 252,74 252,86 201,36 101,13 196,38 No Reference Casings Site: KRU 10 Pad Well: 1 D-30 Rule Assigned: Major Risk WelIpath: 10-30 V1 Inter-Site Error: 0,00 ft 10938,57 6563,55 11590,00 6456,00 246,32 135,96 189,92 87.45 2869,99 FAIL 10943,31 6566,10 11600,00 6460,52 246,33 135,94 189,85 87,51 2873,54 No Reference Casings 10948,05 6568,62 11610,00 6465,04 246,33 135,92 189,79 87,57 2877,15 No Reference Casings 10952.77 6571.10 11620.00 6469,54 246,33 135,90 189,72 87,63 2880,80 No Reference Casings 10956.16 6572.87 11630,00 6474,03 246,33 135,83 189,64 87.71 2884,51 No Reference Casings 10958,37 6573,99 11640,00 6478,52 246,32 135,72 189,54 87.81 2888.27 No Reference Casings 10960,00 6574,81 11650,00 6483,00 246,31 135,68 189.47 87,88 2892,09 No Reference Casings 10962.76 6576,17 11660,00 6487.47 246,29 135.50 189,35 87,99 2895,97 No Reference Casings 10964,94 6577,22 11670,00 6491,94 246,27 135,39 189.26 88,09 2899.87 No Reference Casings 10967.12 6578,26 11680,00 6496.42 246,25 135.27 189,17 88,18 2903,77 No Reference Casings 10970,00 6579,59 11690,00 6500,91 246,23 135.08 189,05 88,29 2907.66 No Reference Casings 10971.47 6580,25 11700,00 6505.41 246.21 135.04 189,00 88,36 2911,56 No Reference Casings 10973,64 6581,22 11710,00 6509,92 246.18 134,92 188,91 88.44 2915.45 No Reference Casings 10975,80 6582,16 11720.00 6514.44 246,16 134.80 188,83 88,53 2919.34 No Reference Casings . BP-GDB Anticollision Report . 10977,96 6583,07 11730,00 6518,96 246,13 134.68 188.75 88,62 2923,24 No Reference Casings 10980,00 6583,92 11740,00 6523,50 246,1 ° 134,57 188,67 88,70 2927,13 No Reference Casings 10982,26 6584,84 11750,00 6528,04 246,07 134.44 188,59 88,79 2931,02 No Reference Casings 10984,39 6585,69 11760,00 6532,59 246,03 134,32 188,51 88,88 2934.91 No Reference Casings 10986,52 6586,51 11770,00 6537,14 246,00 134,20 188.44 88,96 2938,85 No Reference Casings 10990,00 6587,81 11780,00 6541,70 245,94 133,91 188,30 89,08 2942,83 No Reference Casings 10990,00 6587,81 11790,00 6546,26 245,94 134,05 188,33 89,11 2946,86 No Reference Casings 10992,81 6588,82 11800,00 6550,82 245,88 133,84 188,22 89,22 2950,94 No Reference Casings 10994,88 6589,54 11810,00 6555,38 245,84 133,73 188,16 89,30 2955,06 No Reference Casings 10996,93 6590,24 11820,00 6559,95 245.79 133,61 188,09 89,38 2959,22 No Reference Casings 11000,00 6591.25 11830,00 6564,52 245,73 133,37 187,98 89.49 2963,44 No Reference Casings 11000,00 6591,25 11840,00 6569,09 245.73 133,51 188,01 89,52 2967,69 No Reference Casings 11003,00 6592,18 11850,00 6573,67 245,66 133,28 187,90 89,63 2971,99 No Reference Casings 11004,99 6592,78 11860.00 6578,24 245,61 133,17 187,85 89,71 2976,34 No Reference Casings 11006,96 6593,36 11870,00 6582,81 245,56 133,07 187,79 89,79 2980,71 No Reference Casings 11010,00 6594,21 11880,00 6587,37 245.49 132,84 187,68 89,89 2985,12 No Reference Casings 11010,00 6594,21 11890,00 6591,92 245.49 132,97 187,72 89,94 2989,57 No Reference Casings 11012,80 6594,96 11900,00 6596.47 245.41 132,76 187,63 90,03 2994,05 No Reference Casings 11014,71 6595.45 11910,00 6601,01 245,36 132,67 187,57 90,11 2998,56 No Reference Casings 11016,61 6595,91 11920,00 6605,55 245,30 132,58 187,52 90,19 3003,11 No Reference Casings 11020,00 6596,70 11930,00 6610,08 245,21 132,31 187.40 90,30 3007,70 No Reference Casings 11020,00 6596.70 11940,00 6614,61 245,21 132.44 187.45 90,35 3012,31 No Reference Casings 11022,21 6597,19 11950,00 6619,12 245,14 132,31 187.38 90.43 3016,96 No Reference Casings 11024,04 6597,57 11960,00 6623,62 245,08 132,23 187,34 90,51 3021,65 No Reference Casings 11025,86 6597,94 11970,00 6628,08 245,03 132,15 187.29 90,59 3026,36 No Reference Casings 11027,66 6598.29 11980,00 6632,51 244.97 132,08 187,25 90,66 3031,11 No Reference Casings 11030,00 6598,72 11990,00 6636,94 244,90 131,94 187,18 90,75 3035,89 No Reference Casings 11030,00 6598,72 12000,00 6641.37 244,90 132,07 187,23 90,80 3040,68 No Reference Casings 11032,99 6599,22 12010,00 6645,80 244,79 131,86 187,13 90,89 3045,49 No Reference Casings 11034,73 6599,50 12020,00 6650,23 244,73 131,80 187,09 90,97 3050,33 No Reference Casings 11036.46 6599,76 12030,00 6654,66 244,68 131,74 187,05 91,04 3055,18 No Reference Casings 11040,00 6600,24 12040,00 6659.09 244,56 131.49 186,91 91,14 3060,06 No Reference Casings Site: KRU 1D Pad Well: 1 D-30 Rule Assigued: Major Risk Wellpath: 1D-30L 1 V3 Inter-Site Error: 0.00 ft 10938,57 6563,55 11590,00 6456.00 246,32 135,95 189,92 87.45 2869,99 FAIL 10943,31 6566,10 11600,00 6460,52 246,33 135,93 189,85 87,51 2873,54 No Reference Casings 10948,05 6568,62 11610.00 6465,04 246,33 135,91 189,79 87,57 2877,15 No Reference Casings 10952,77 6571,10 11620,00 6469,54 246,33 135,89 189,72 87,63 2880,80 No Reference Casings 10956,16 6572,87 11630,00 6474,03 246,33 135,82 189,64 87,71 2884,51 No Reference Casings 10958.37 6573,99 11640,00 6478,52 246,32 135.72 189,54 87,81 2888,27 No Reference Casings 10960,00 6574,81 11650,00 6483.00 246,31 135,67 189.47 87,88 2892,09 No Reference Casings 10962.76 6576,17 11660,00 6487.47 246.29 135,49 189,35 87,99 2895,97 No Reference Casings 10964,94 6577.22 11670,00 6491,94 246,27 135,34 189,26 88,09 2899,87 No Reference Casings 10967,12 6578,26 11680,00 6496.42 246,25 135,19 189.17 88,18 2903,77 No Reference Casings 10970,00 6579,59 11690,00 6500,91 246,23 134,96 189,05 88,29 2907,66 No Reference Casings 10971.47 6580,25 11700,00 6505.41 246,21 134.88 189,00 88,36 2911,56 No Reference Casings . BP-GDB AntÎcolJision Report . 10973,64 6581.22 11710,00 6509,92 246,18 134,73 188,91 88.44 2915,45 No Reference Casings 10975,81 6582,16 11720,00 6514,29 246,16 134,54 188,83 88,53 2919,30 No Reference Casings 10977,99 6583,09 11730,00 6518,38 246,13 134,35 188,73 88,61 2923,07 No Reference Casings 10980,00 6583,92 11740,00 6522,18 246,1 ° 134,18 188,64 88,67 2926,74 No Reference Casings 10982,36 6584,88 11750,00 6525,70 246,06 133,97 188,53 88,74 2930,31 No Reference Casings 10984,56 6585,75 11760,00 6528,98 246,03 133,77 188.42 88,80 2933,77 No Reference Casings 10986.77 6586,60 11770,00 6532,01 245,99 133,58 188,31 88,85 2937,12 No Reference Casings 10990,00 6587,81 11780,00 6534,79 245,94 133,27 188.14 88,93 2940,36 No Reference Casings 10990,00 6587,81 11790,00 6537,32 245,94 133,34 188,12 88,91 2943.47 No Reference Casings 10993.42 6589,04 11800,00 6539,61 245,87 133.D1 187,94 88,98 2946.46 No Reference Casings 10995,65 6589,81 11810,00 6541.66 245,82 132,82 187,81 89,01 2949,32 No Reference Casings 10997,89 6590,56 11820,00 6543,54 245,77 132,63 187,68 89,04 2952,03 No Reference Casings 11000,00 6591,25 11830,00 6545,26 245,73 132.45 187,55 89,06 2954,58 No Reference Casings 11002.40 6592,00 11840,00 6546,81 245,67 132,24 187.40 89,08 2956,97 No Reference Casings 11004,66 6592,69 11850,00 6548,21 245,62 132,05 187,26 89,10 2959,20 No Reference Casings 11006.94 6593.35 11860,00 6549.49 245.56 131,86 187,12 89,12 2961,22 No Reference Casings 11010,00 6594,21 11870,00 6550,80 245.49 131,59 186,93 89,15 2962,89 No Reference Casings 11011,57 6594,63 11880,00 6552,13 245.44 131.48 186,83 89,15 2964,19 No Reference Casings 11013,90 6595,24 11890,00 6553.44 245,38 131,29 186,68 89,17 2965,27 No Reference Casings 11016.24 6595,82 11900,00 6554,64 245,31 131,10 186,54 89,18 2966,51 No Reference Casings 11020,00 6596,70 11910,00 6555,69 245,21 130.76 186,32 89.22 2967,96 No Reference Casings 11020,00 6596,70 11920,00 6556,63 245,21 130,84 186,29 89.19 2969,60 No Reference Casings 11023,21 6597.40 11930,00 6557,54 245,11 130,56 186,10 89,22 2971,51 No Reference Casings 11025,52 6597,87 11940,00 6558,41 245,04 130,38 185,96 89.23 2973,68 No Reference Casings 11027.82 6598,32 11950,00 6559,25 244,96 130.21 185,82 89,24 2976,13 No Reference Casings 11030,00 6598,72 11960,00 6560,10 244,90 130,05 185.68 89,25 2978,87 No Reference Casings 11032,36 6599,12 11970,00 6560,95 244,82 129,88 185,54 89,26 2981,93 No Reference Casings 11034,61 6599,48 11980,00 6561,82 244,74 129,72 185.40 89.27 2985.25 No Reference Casings 11036,86 6599,82 11990,00 6562.69 244,66 129,56 185.27 89,28 2988.46 No Reference Casings 11040,00 6600,24 12000,00 6563,56 244,56 129.32 185,08 89,30 2991,48 No Reference Casings 11040,00 6600,24 12010,00 6564.44 244,56 129,39 185,07 89,30 2994,29 No Reference Casings 11043.72 6600,69 12020.00 6565,33 244.42 129,10 184,86 89,32 2996,88 No Reference Casings 11046,03 6600,93 12030,00 6566,24 244,33 128,95 184,72 89,34 2999,20 No Reference Casings 11048,36 6601,14 12040.00 6567,18 244,25 128,81 184,59 89,35 3001,24 No Reference Casings 11050,00 6601,28 12050,00 6568,14 244,19 128.74 184.49 89,37 3003,02 No Reference Casings 11053,05 6601,50 12060,00 6569,19 244,07 128.54 184,32 89,39 3004,60 No Reference Casings 11055,39 6601,64 12070,00 6570,31 243.98 128.41 184,19 89.41 3005,98 No Reference Casings 11057,74 6601,75 12080,00 6571.48 243,89 128.28 184,06 89.43 3007,17 No Reference Casings 11060,00 6601,83 12090,00 6572.44 243,80 128,17 183,93 89.44 3008,28 No Reference Casings 11062.44 6601,89 12100,00 6573,12 243,70 128,05 183,78 89.46 3009,32 No Reference Casings 11064,80 6601,91 12110,00 6573,51 243,61 127,94 183,64 89.46 3010,30 No Reference Casings 11067,15 6601.91 12120,00 6573,68 243.51 127,83 183.49 89.47 3011,03 No Reference Casings 11070,00 6601,88 12130,00 6573,65 243.40 127,70 183,31 89.47 3011.46 No Reference Casings 11071,88 6601,83 12140,00 6573.44 243,32 127,64 183.19 89.46 3011,60 No Reference Casings 11074,24 6601.75 12150,00 6573,27 243.22 127.55 183.03 89.46 3011.54 No Reference Casings 11076,60 6601,64 12160,00 6573.22 243,12 127.47 182.88 89.46 3011,29 No Reference Casings 11080.00 6601,44 12170,00 6573,26 242,98 127,33 182,66 89.46 3010,89 No Reference Casings 11081.30 6601,35 12180,00 6573,37 242,92 127.33 182,59 89.47 3010,55 No Reference Casings 11083,65 6601,16 12190,00 6573,52 242,82 127,27 182.44 89.48 3010,37 No Reference Casings 11085,51 6600.98 12200.00 6573,71 242.74 127.24 182,33 89.49 3010,34 No Reference Casings 11085.51 6600,98 12210,00 6573.94 242,74 127.32 182,35 89.51 3010,50 No Reference Casings . BP-GDB Anticollision Report . 11085,51 6600,98 12220,00 6574,15 242,74 127.41 182,38 89,53 3010,99 No Reference Casings 11085,51 6600,98 12230,00 6574,34 242,74 127,50 182.40 89,55 3011,81 No Reference Casings 11091,21 6600.44 12240,00 6574,52 242,19 126,67 181,67 89,51 3012,92 No Reference Casings 11092,56 6600,31 12250,00 6574,68 242,06 126,54 181,51 89,51 3014,35 No Reference Casings 11093,90 6600,18 12260,00 6574,82 241,93 126.41 181,35 89,52 3016,09 No Reference Casings 11100,00 6599,59 12270,00 6574,93 241,34 125.48 180,57 89,47 3018.15 No Reference Casings 11100,00 6599,59 12280,00 6575,03 241,34 125,57 180,59 89,49 3020.40 No Reference Casings 11100,00 6599,59 12290,00 6575,09 241,34 125,66 180,61 89,51 3022,88 No Reference Casings 11100,00 6599,59 12300,00 6575,13 241,34 125,74 180,63 89,53 3025,59 No Reference Casings 11100.00 6599,59 12310,00 6575,14 241,34 125,83 180,64 89,55 3028,50 No Reference Casings 11100.00 6599,59 12320,00 6575,13 241,34 125,91 180,66 89,56 3031,36 No Reference Casings 11100,00 6599,59 12330,00 6575,08 241,34 126.00 180,68 89.58 3034.01 No Reference Casings 11100,00 6599,59 12340,00 6575,01 241,34 126,08 180,69 89,60 3036.46 No Reference Casings 11100,00 6599,59 12350,00 6574,90 241,34 126,17 180,71 89,61 3038,70 No Reference Casings 11100,00 6599,59 12360,00 6574,78 241,34 126,26 180,73 89,63 3040,73 No Reference Casings 11100,00 6599,59 12370,00 6574,70 241,34 126,34 180,74 89,65 3042,56 No Reference Casings 11109,69 6598,66 12380,00 6574,67 240,21 124.79 179.48 89,55 3044,05 No Reference Casings 11111,03 6598,53 12390,00 6574,68 240,05 124,65 179,32 89,55 3045.42 No Reference Casings 11112,37 6598.40 12400,00 6574,67 239,89 124,50 179,16 89,56 3046,54 No Reference Casings 11113,71 6598,27 12410,00 6574,59 239,74 124,36 179,00 89,56 3047.40 No Reference Casings 11115.06 6598,14 12420,00 6574.42 239,58 124,21 178,84 89.56 3048,00 No Reference Casings 11125.00 6597.18 12430,00 6574,18 238.41 122,54 177,54 89.45 3048.43 No Reference Casings 11125,00 6597,18 12440,00 6573,94 238,41 122,63 177,55 89.47 3048.49 No Reference Casings 11125,00 6597,18 12450,00 6573.75 238.41 122,72 177,57 89.48 3048,31 No Reference Casings 11125,00 . 6597,18 12460,00 6573,63 238,41 122,81 177,58 89,50 3047,90 No Reference Casings 11125,00 6597,18 12470,00 6573,53 238.41 122,90 177,60 89,51 3047.24 No Reference Casings 11125,00 6597,18 12480,00 6573,35 238.41 122,99 177,61 89,53 3046,27 No Reference Casings 11125,00 6597,18 12490.00 6573,08 238.41 123,08 177.63 89,54 3045,00 No Reference Casings 11125,00 6597,18 12500,00 6572,73 238.41 123,17 177,64 89,55 3043.43 No Reference Casings 11125,00 6597,18 12510,00 6572.31 238.41 123,25 177.65 89,56 3041,64 No Reference Casings 11125,00 6597,18 12520.00 6571,82 238.41 123,34 177.66 89.57 3039.63 No Reference Casings 11125,00 6597,18 12530,00 6571,26 238.41 123.43 177.66 89,58 3037.41 No Reference Casings 11125,00 6597,18 12540,00 6570,65 238.41 123,51 177,67 89,58 3034,97 No Reference Casings 11125,00 6597.18 12550,00 6570,00 238.41 123,60 177,67 89,59 3032,28 No Reference Casings 11125,00 6597.18 12560,00 6569,32 238.41 123,69 177,68 89,59 3029,37 No Reference Casings 11135,03 6596,20 12570,00 6568,59 236,98 121,95 176,35 89.48 3026,09 No Reference Casings 11136.32 6596,08 12580,00 6567,90 236,79 121,79 176.19 89.47 3022,89 No Reference Casings 11137,62 6595,95 12590,00 6567,32 236,61 121,64 176,02 89.46 3019,94 No Reference Casings 11138,94 6595,82 12600,00 6566,86 236.42 121.48 175,85 89,45 3017,27 No Reference Casings 11140.26 6595.69 12610,00 6566.47 236.23 121.32 175.69 89.45 3014.89 No Reference Casings 11150.00 6594,75 12620,00 6566,02 234,84 119,56 174.41 89,34 3012,91 No Reference Casings 11150,00 6594,75 12630,00 6565,52 234,84 119,65 174.42 89,35 3011,15 No Reference Casings 11150,00 6594,75 12640,00 6565,05 234,84 119.74 174.43 89.36 3009,66 No Reference Casings 11150,00 6594,75 12650,00 6564,83 234,84 119,83 174.44 89,37 3008,32 No Reference Casings 11150,00 6594,75 12660,00 6564,86 234,84 119,92 174.46 89.39 3007. 11 No Reference Casings 11150,00 6594,75 12670,00 6564,98 234,84 120,02 174.48 89.41 3006,16 No Reference Casings 11150,00 6594,75 12680,00 6565,13 234,84 120.11 174,50 89.43 3005.52 No Reference Casings 11150,00 6594,75 12690,00 6565,32 234,84 120.20 174,53 89.45 3005,18 No Reference Casings 11150.00 6594.75 12700,00 6565,56 234,84 120.29 174,55 89.48 3005,16 No Reference Casings 11150,00 6594,75 12710,00 6565,90 234,84 120,39 174,57 89,50 3005,51 No Reference Casings 11150.00 6594.75 12720,00 6566,36 234,84 120.48 174,60 89,53 3006,21 No Reference Casings . BP-GDB Anticollision Report . 11150,00 6594,75 12730,00 6566,90 234,84 120,57 174,63 89,56 3007.29 No Reference Casings 11150,00 6594,75 12740,00 6567.42 234,84 120,67 174,66 89,59 3008,74 No Reference Casings 11150,00 6594,75 12750,00 6567.88 234,84 120,76 174,68 89,61 3010,58 No Reference Casings 11160,50 6593,73 12760,00 6568,29 233,07 118,81 173,32 89,52 3012,65 No Reference Casings 11161,81 6593,60 12770,00 6568,65 232,85 118,65 173,17 89,53 3015,18 No Reference Casings 11163,11 6593.47 12780,00 6568,96 232,63 118.48 173,03 89,54 3018,02 No Reference Casings 11164,39 6593,35 12790,00 6569,24 232.41 118,32 172,88 89,54 3021,16 No Reference Casings 11175,00 6592,31 12800,00 6569.47 230,62 116,27 171,50 89.44 3024,72 No Reference Casings 11175,00 6592,31 12810,00 6569,67 230,62 116,36 171,52 89.46 3028,51 No Reference Casings 11175,00 6592,31 12820,00 6569,86 230,62 116.45 171,54 89.48 3032,66 No Reference Casings 11175,00 6592,31 12830,00 6570,02 230,62 116,54 171,56 89,50 3036,99 No Reference Casings 11175,00 6592,31 12840,00 6570,19 230,62 116,63 171,58 89,52 3041,21 No Reference Casings 11175,00 6592,31 12850,00 6570,35 230,62 116,71 171,60 89,55 3045,32 No Reference Casings 11175,00 6592,31 12860,00 6570,51 230,62 116,80 171,62 89,57 3049,31 No Reference Casings 11175,00 6592,31 12870,00 6570,66 230,62 116,89 171,64 89,59 3053,18 No Reference Casings 11175,00 6592,31 12880,00 6570,70 230,62 116,98 171,66 89,60 3056,90 No Reference Casings 11175,00 6592,31 12890,00 6570,57 230,62 117,07 171,67 89,62 3060.43 No Reference Casings 11175,00 6592,31 12900,00 6570.27 230,62 117,17 171,69 89,63 3063,76 No Reference Casings 11175,00 6592,31 12910,00 6569,92 230,62 117.26 171.70 89,64 3066,84 No Reference Casings 11175.00 6592,31 12920,00 6569,60 230,62 117,35 171,71 89,65 3069,62 No Reference Casings 11175,00 6592,31 12930,00 6569,31 230,62 117.45 171,72 89,67 3072,12 No Reference Casings 11175,00 6592,31 12940,00 6569,01 230,62 117,54 171,73 89,68 3074,35 No Reference Casings 11184,55 6591,38 12950,00 6568,68 228.77 115,66 170,48 89,58 3076,22 No Reference Casings 11185,87 6591,25 12960,00 6568.32 228,52 115.48 170,32 89,57 3077,94 No Reference Casings 11187,19 6591,13 12970,00 6567,90 228.26 115,30 170,16 89,57 3079.49 No Reference Casings 11188,52 6591,00 12980,00 6567.42 228,00 115,12 169.99 89,56 3080,86 No Reference Casings 11189,85 6590,87 12990,00 6566,87 227,74 114,93 169.82 89,56 3081,98 No Reference Casings 11200.00 6589,88 13000,00 6566,26 225,78 112,86 168.48 89.44 3082,85 No Reference Casings 11200,00 6589,88 13010,00 6565,58 225,78 112,96 168.49 89,45 3083,25 No Reference Casings 11200,00 6589,88 13020,00 6564,85 225,78 113,06 168.49 89.45 3083,33 No Reference Casings 11200,00 6589,88 13030,00 6564,09 225,78 113,15 168,50 89.46 3083.17 No Reference Casings 11200,00 6589,88 13040,00 6563,32 225,78 113,25 168,50 89.46 3082,77 No Reference Casings 11200,00 6589,88 13050,00 6562,56 225,78 113,35 168,51 89.46 3082,18 No Reference Casings 11200,00 6589,88 13060,00 6561,87 225,78 113.44 168,51 89.47 3081,52 No Reference Casings 11200,00 6589,88 13070,00 6561,25 225,78 113,54 168,52 89.48 3080,79 No Reference Casings 11200,00 6589,88 13080,00 6560,66 225,78 113,64 168,52 89.48 3080,15 No Reference Casings 11200.00 6589,88 13090,00 6560,00 225,78 113,74 168,53 89.49 3079,87 No Reference Casings 11200,00 6589,88 13100,00 6559.27 225,78 113,83 168,54 89.49 3079,96 No Reference Casings 11200,00 6589,88 13110,00 6558,51 225,78 113,93 168,54 89,50 3080.42 No Reference Casings 11825.00 6550,60 13120,00 6557,77 240.29 128,86 178.47 90,15 3080,16 No Reference Casings 11825,00 6550,60 13130,00 6557,04 240,29 128,95 178.45 90,13 3079,39 No Reference Casings 11825,00 6550,60 13140,00 6556,36 240.29 129,05 178.44 90,12 3078.96 No Reference Casings 11825,00 6550,60 13150,00 6555,76 240,29 129,15 178.42 90,10 3078,88 No Reference Casings 11825,00 6550,60 13160,00 6555,25 240,29 129,25 178.41 90,09 3079,12 No Reference Casings 11825,00 6550,60 13170,00 6554,79 240,29 129,35 178.40 90,08 3079,71 No Reference Casings 11825,00 6550.60 13180,00 6554,27 240,29 129.45 178,39 90,07 3080,71 No Reference Casings 11825,00 6550,60 13190,00 6553,68 240,29 129,55 178,38 90,06 3082.11 No Reference Casings 11825,00 6550,60 13200.00 6553.07 240,29 129,65 178,37 90.05 3083,89 No Reference Casings 11825,00 6550,60 13210.00 6552,56 240,29 129,75 178,36 90,04 3085,95 No Reference Casings 11825,00 6550,60 13220,00 6552,15 240,29 129,84 178,35 90.03 3088.27 No Reference Casings 11825.00 6550,60 13230,00 6551,86 240,29 129,94 178,34 90,02 3090,85 No Reference Casings . BP-GDB Anticollision Report . 11825,00 6550,60 13240,00 6551,67 240.29 130,04 178,33 90,01 3093,62 No Reference Casings 11825,00 6550,60 13250,00 6551,57 240,29 130,14 178,33 90,01 3096,56 No Reference Casings 11835,55 6550.69 13260,00 6551,57 238,81 128,31 177,08 90,02 3099,54 No Reference Casings 11836,83 6550,71 13270,00 6551,48 238,63 128,17 176,92 90,02 3102.49 No Reference Casings 11838,12 6550,72 13280,00 6551,25 238.45 128,03 176,76 90,01 3105,17 No Reference Casings 11839.41 6550,73 13290,00 6550,87 238.26 127,88 176,60 90,01 3107,59 No Reference Casings 11850,00 6550,85 13300,00 6550,35 236,78 125,97 175,34 90,01 3109,85 No Reference Casings 11850,00 6550,85 13310,00 6549,69 236,78 126,07 175,32 90,00 3111,72 No Reference Casings 12275,00 6560,77 13320,00 6548,90 246,88 139.20 184,14 89,78 3113,13 No Reference Casings 12275,00 6560.77 13330,00 6548,01 246,88 139,30 184,12 89,76 3113,12 No Reference Casings 12275,00 6560,77 13340,00 6547,12 246,88 139.40 184,10 89,74 3112,77 No Reference Casings 12275.00 6560.77 13350,00 6546,21 246,88 139,50 184.08 89,71 3112,09 No Reference Casings 12275.00 6560,77 13360,00 6545,29 246,88 139,60 184,06 89,69 3111,06 No Reference Casings 12275,00 6560,77 13370,00 6544,28 246,88 139,70 184,03 89,67 3109,68 No Reference Casings 12285,68 6561,01 13380,00 6543,19 245,96 138,15 182,76 89,68 3107.81 No Reference Casings 12286,97 6561,04 13390,00 6542,04 245,84 138,04 182,58 89,65 3105,68 No Reference Casings 12288,25 6561,07 13400,00 6540,96 245,73 137,94 182.41 89,63 3103,20 No Reference Casings 12289,52 6561,09 13410,00 6539,94 245,62 137,83 182,23 89,61 3100,37 No Reference Casings 12300,00 6561,33 13420,00 6538,98 244,71 136,22 180,98 89,62 3097,30 No Reference Casings 12300,00 6561,33 13430,00 6538,1 ° 244,71 136,31 180,96 89,60 3093,83 No Reference Casings 12300,00 6561,33 13440,00 6537.29 244,71 136.41 180,94 89,58 3090,08 No Reference Casings 12300,00 6561,33 13450,00 6536,56 244,71 136,50 180,92 89,56 3086,14 No Reference Casings 12300,00 6561,33 13460,00 6535,93 244,71 136,59 180,91 89,54 3082.42 No Reference Casings 12300,00 6561,33 13470,00 6535.40 244,71 136,69 180,89 89,53 3078,99 No Reference Casings 12300,00 6561,33 13480,00 6534,97 244,71 136,78 180,88 89,52 3075,87 No Reference Casings 12300,00 6561,33 13490,00 6534,64 244,71 136,88 180,87 89,51 3073.16 No Reference Casings 12300,00 6561,33 13500,00 6534.42 244,71 136,98 180,86 89,50 3070,88 No Reference Casings 12300,00 6561,33 13510,00 6534,30 244,71 137,07 180,86 89.49 3069,03 No Reference Casings 12300,00 6561,33 13520,00 6534,16 244,71 137,18 180,85 89.49 3067,62 No Reference Casings 12300,00 6561,33 13530,00 6533,97 244,71 137,28 180,84 89.48 3066,65 No Reference Casings 12300,00 6561,33 13540,00 6533,72 244,71 137,38 180,83 89.47 3066,12 No Reference Casings 12300,00 6561,33 13550,00 6533,52 244,71 137.48 180,82 89.46 3066,03 No Reference Casings 12300.00 6561,33 13560,00 6533,40 244,71 137,59 180,82 89.45 3066,36 No Reference Casings 12310.22 6561,55 13570,00 6533,35 243,56 135,98 179,61 89.48 3066,99 No Reference Casings 12311,56 6561,58 13580,00 6533,37 243,40 135,85 179.45 89.48 3068,14 No Reference Casings 12312,89 6561,61 13590,00 6533.40 243,25 135,73 179,29 89.48 3069.70 No Reference Casings 12314,21 6561,64 13600.00 6533.46 243.10 135,60 179,14 89.48 3071,67 No Reference Casings 12315,52 6561,67 13610.00 6533,55 242,96 135.48 178,98 89.48 3074,01 No Reference Casings 12325,00 6561,87 13620,00 6533,73 241,88 133,91 177.87 89,50 3076.68 No Reference Casings 12325,00 6561.87 13630,00 6533,98 241,88 134,01 177,87 89,51 3079,50 No Reference Casings 12325.00 6561.87 13640,00 6534,26 241,88 134,11 177.87 89,51 3082,39 No Reference Casings 12325.00 6561.87 13650,00 6534.44 241,88 134,21 177.87 89,51 3084.94 No Reference Casings 12325,00 6561.87 13660,00 6534,52 241,88 134,32 177,87 89.50 3087.14 No Reference Casings 12325,00 6561.87 13670,00 6534.49 241,88 134.42 177,86 89,50 3088.97 No Reference Casings 12325.00 6561.87 13680,00 6534,37 241,88 134,52 177,86 89.49 3090,52 No Reference Casings 12325,00 6561.87 13690,00 6534,24 241,88 134,63 177,85 89.49 3092,07 No Reference Casings 12325,00 6561.87 13700,00 6534,12 241,88 134,74 177,85 89.48 3093,64 No Reference Casings 12325,00 6561,87 13710,00 6533,99 241,88 134.84 177,84 89.48 3095,25 No Reference Casings . BP-GDB Anticollision Report . 10935,57 6561,92 12940,00 6176,14 246,32 137,81 187,34 84,79 5052,00 FAIL 10938,69 6563,61 12950,00 6180,07 246,32 137,73 187,31 84,84 5058,79 No Reference Casings 10941,80 6565,29 12960,00 6184,01 246,33 137,64 187,28 84,90 5065,57 No Reference Casings 10944,91 6566,95 12970,00 6187,95 246,33 137,55 187,25 84,95 5072,36 No Reference Casings 10948,01 6568,60 12980,00 6191,89 246,33 137.46 187,21 85,00 5079,15 No Reference Casings 10951,11 6570,23 12990,00 6195,83 246,33 137,37 187,18 85,05 5085,93 No Reference Casings 10954,20 6571,85 13000,00 6199,78 246,33 137.28 187,15 85,10 5092,72 No Reference Casings 10955,98 6572,77 13010,00 6203,73 246,33 137,13 187,11 85,17 5099.51 No Reference Casings 10957,29 6573.45 13020,00 6207,69 246,32 136,96 187,06 85,24 5106.30 No Reference Casings 10958,60 6574,11 13030,00 6211,65 246,31 136,79 187,02 85,30 5113.11 No Reference Casings 10960,00 6574,81 13040,00 6215,62 246,31 136,60 186,97 85,37 5119,92 No Reference Casings 10960,00 6574,81 13050,00 6219,59 246,31 136,70 186,98 85,38 5126,73 No Reference Casings 10962,51 6576,05 13060,00 6223,57 246,29 136,27 186,88 85.50 5133,55 No Reference Casings 10963,80 6576,67 13070,00 6227,55 246,28 136,1 ° 186,84 85,57 5140,38 No Reference Casings I 10965,08 6577,29 13080,00 6231,54 246,27 135,93 186,79 85,63 5147.22 No Reference Casings 10966,36 6577,90 13090,00 6235,54 246,26 135,76 186,75 85,69 5154,06 No Reference Casings 10967,64 6578,50 13100.00 6239,54 246,25 135,59 186,71 85,76 5160,92 No Reference Casings 10970,00 6579,59 13110.00 6243,54 246,23 135.18 186,62 85,86 5167,79 No Reference Casings 10970,00 6579,59 13120.00 6247,55 246,23 135,28 186,63 85,87 5174,67 No Reference Casings 10970,00 6579,59 13130,00 6251,56 246.23 135,38 186,65 85,89 5181,58 No Reference Casings 10972,66 6580,78 13140,00 6255,57 246,19 134,90 186,55 86,00 5188,50 No Reference Casings 10973,90 6581,33 13150,00 6259,59 246,18 134,73 186,51 86,06 5195.44 No Reference Casings 10975,12 6581,86 13160,00 6263,61 246,16 134,56 186.47 86,12 5202,39 No Reference Casings 10976,35 6582,39 13170,00 6267,63 246,15 134,39 186.44 86,18 5209,37 No Reference Casings 10977,56 6582,90 13180,00 6271,66 246,13 134.23 186.40 86,24 5216,36 No Reference Casings 10980,00 6583,92 13190,00 6275,69 246,10 133,79 186,31 86,34 5223.36 No Reference Casings 10980,00 6583,92 13200,00 6279,73 246,1 ° 133,89 186,33 86,36 5230,37 No Reference Casings 10980,00 6583,92 13210,00 6283,78 246,1 ° 133,98 186,35 86,37 5237,38 No Reference Casings 10980,00 6583,92 13220,00 6287,83 246,1 ° 134,08 186,36 86,39 5244.40 No Reference Casings 10983,53 6585,35 13230.00 6291,89 246.04 133,40 186,22 86,52 5251.40 No Reference Casings 10984,70 6585,81 13240,00 6295,96 246,03 133,24 186,19 86,58 5258.42 No Reference Casings 10985,88 6586,26 13250,00 6300,03 246,01 133,08 186,16 86,64 5265.43 No Reference Casings 10987,05 6586,71 13260,01 6304,12 245,99 132,92 186,13 86,69 5272.45 No Reference Casings 10990,00 6587.81 13270,00 6308,20 245,94 132,37 186.01 86,79 5279.45 No Reference Casings 10990,00 6587,81 13280,00 6312,29 245,94 132.4 7 186,03 86,82 5286.44 No Reference Casings 10990,00 6587,81 13290,00 6316,38 245,94 132,56 186,06 86,84 5293.43 No Reference Casings 10990,00 6587.81 13300.00 632û.48 245,94 132,66 186,08 86,86 5300.40 No Reference Casings 10992,83 6588,83 13310,00 6324,58 245,88 132,14 185,97 86,96 5307.36 No Reference Casings 10993,98 6589,23 13320.00 6328,69 245,86 131,98 185,94 87,01 5314,31 No Reference Casings 10995,12 6589.63 13330.00 6332,80 245,83 131.83 185,91 87,07 5321,25 No Reference Casings 10996,27 6590,02 13340.00 6336,91 245,81 131,68 185,88 87,12 5328,17 No Reference Casings 10997.41 6590.40 13350,00 6341,02 245,78 131,52 185,85 87,17 5335,09 No Reference Casings 11000,00 6591,25 13360,00 6345,14 245,73 131,06 185,74 87,26 5341.99 No Reference Casings 11000,00 6591,25 13370,00 6349,26 245,73 131,15 185,77 87,28 5348,89 No Reference Casings 11000.00 6591,25 13380,00 6353,39 245,73 131.25 185.80 87,31 5355,77 No Reference Casings 11000,00 6591,25 13390,00 6357,52 245.73 131,34 185,82 87,33 5362,64 No Reference Casings 11003,05 6592.20 13400.00 6361,65 245,66 130,78 185,70 87.43 5369,51 No Reference Casings 11004,16 6592,54 13410,00 6365,79 245,63 130,64 185,67 87.48 5376,40 No Reference Casings 11005,27 6592.87 13420,00 6369,93 245,60 130,49 185,64 87.53 5383,29 No Reference Casings 11006,36 6593,19 13430,00 6374,07 245,58 130,35 185,62 87,58 5390,20 No Reference Casings 11010,00 6594,21 13440,00 6378.22 245.49 129,68 185.46 87,67 5397,11 No Reference Casings . BP-GDB Anticollision Report . 11010,00 6594,21 13450,00 6382,37 245.49 129,77 185.49 87,70 5404,04 No Reference Casings 11010,00 6594,21 13460,00 6386,53 245.49 129,87 185,52 87,73 5410,97 No Reference Casings 11010,00 6594,21 13470.00 6390,69 245.49 129,96 185,55 87,76 5417,91 No Reference Casings 11010,00 6594,21 13480.00 6394,86 245.49 130,05 185,57 87,79 5424,87 No Reference Casings 11012,79 6594,95 13490,00 6399,02 245.41 129,56 185.46 87,87 5431,83 No Reference Casings 11013,84 6595,22 13500,00 6403,19 245,38 129.44 185.44 87,92 5438,79 No Reference Casings 11014,88 6595.49 13510,00 6407,35 245,35 129,31 185,42 87,97 5445,77 No Reference Casings 11015,91 6595,74 13520,00 6411,51 245,32 129,19 185,39 88,01 5452,75 No Reference Casings 11016,94 6595,99 13530,00 6415,68 245,29 129,07 185,37 88,06 5459,75 No Reference Casings 11020,00 6596,70 13540,00 6419,83 245,21 128,54 185,24 88,14 5466,75 No Reference Casings 11020,00 6596,70 13550,00 6423,99 245,21 128,63 185.27 88,17 5473,75 No Reference Casings 11020,00 6596.70 13560,00 6428,15 245,21 128,72 185,30 88,20 5480,76 No Reference Casings 11020,00 6596,70 13570,00 6432.30 245,21 128,81 185,33 88,23 5487,78 No Reference Casings 11020,00 6596.70 13580,00 6436.45 245,21 128.90 185,37 88,27 5494,81 No Reference Casings 11022,96 6597,35 13590,00 6440,61 245,12 128.40 185.24 88,34 5501,84 No Reference Casings 11023,94 6597,55 13600.00 6444,79 245.09 128,30 185,22 88,39 5508.87 No Reference Casings 11024,91 6597,75 13610,00 6448,97 245,05 128,20 185,20 88,43 5515,91 No Reference Casings 11025,88 6597,94 13620.00 6453.18 245,02 128,10 185,19 88.48 5522,95 No Reference Casings 11026,84 6598,13 13630,00 6457,39 244,99 128,00 185,17 88,52 5530.00 No Reference Casings 11030,00 6598,72 13640,00 6461,62 244.90 127,49 185,03 88,60 5537,05 No Reference Casings 11030,00 6598,72 13650,00 6465,86 244,90 127,57 185,06 88,63 5544,10 No Reference Casings 11030,00 6598,72 13660,00 6470.11 244,90 127,66 185,1 ° 88,67 5551,15 No Reference Casings 11030,00 6598,72 13670.00 6474,38 244,90 127,75 185,13 88,70 5558,21 No Reference Casings 11030,00 6598,72 13680.00 6478,66 244,90 127,84 185,17 88,74 5565,27 No Reference Casings 11030,00 6598,72 13690,00 6482,93 244.90 127,92 185,20 88,77 5572.35 No Reference Casings 11033,35 6599,28 13700,00 6487,19 244,78 127,39 185,06 88,84 5579.43 No Reference Casings 11034.26 6599.43 13710,00 6491.44 244,75 127,31 185,04 88,89 5586,54 No Reference Casings 11035,15 6599,56 13720,00 6495,69 244,72 127,23 185,03 88,93 5593,66 No Reference Casings 11036,04 6599.70 13730,00 6499,92 244,69 127,16 185,01 88,98 5600,80 No Reference Casings 11036,92 6599.83 13740.00 6504,14 244,66 127,08 185,00 89,02 5607,95 No Reference Casings 11040,00 6600,24 13750,00 6508,35 244,56 126,63 184,86 89,09 5615,12 No Reference Casings 11040,00 6600,24 13760,00 6512,55 244,56 126,72 184.90 89,12 5622,31 No Reference Casings 11040,00 6600,24 13770,00 6516,74 244,56 126,80 184,93 89,16 5629,50 No Reference Casings 11040,00 6600.24 13780.00 6520.94 244,56 126.89 184,97 89.19 5636.71 No Reference Casings 11040.00 6600,24 13790,00 6525,15 244,56 126,97 185,01 89.23 5643,92 No Reference Casings 11040,00 6600,24 13800,00 6529,38 244,56 127,05 185,04 89,27 5651,13 No Reference Casings 11042,91 6600.60 13810,00 6533.62 244.45 126.64 184.91 89,33 5658,33 No Reference Casings 11043,74 6600,69 13820.00 6537.87 244.42 126,59 184,90 89,37 5665.54 No Reference Casings 11044,56 6600,78 13830,00 6542,14 244.39 126,54 184,89 89.42 5672.75 No Reference Casings 11045,38 6600,86 13840,00 6546.42 244.36 126.49 184.88 89.46 5679.97 No Reference Casings 11046,19 6600,94 13850.00 6550,71 244.33 126.44 184,88 89,50 5687.18 No Reference Casings 11047,00 6601,02 13860,00 6555,02 244,30 126,39 184,87 89.55 5694,39 No Reference Casings 11050,00 6601,28 13870.00 6559,34 244,19 126,01 184,73 89,60 5701,61 No Reference Casings 11050,00 6601,28 13880.00 6563,68 244,19 126,09 184.77 89,64 5708,82 No Reference Casings 11050,00 6601,28 13890.00 6568.03 244.19 126,17 184,81 89,68 5716,04 No Reference Casings 11050,00 6601,28 13900,00 6572,39 244,19 126,26 184,85 89,72 5723,25 No Reference Casings 11050,00 6601,28 13910,00 6576.76 244,19 126,34 184,89 89,76 5730.46 No Reference Casings 11050,00 6601.28 13920,00 6581,15 244,19 126.42 184,93 89,80 5737,67 No Reference Casings 11050,00 6601,28 13930,00 6585.55 244,19 126,50 184,97 89,84 5744,89 No Reference Casings 11053,23 6601,51 13940.00 6589,97 244,06 126,1 ° 184,81 89,90 5752,09 No Reference Casings 11053,98 6601,56 13950,00 6594.40 244,03 126,07 184,81 89,94 5759,30 No Reference Casings . BP-GDB Anticollision Report . It 11054,73 6601,60 13960,00 6598,84 244,01 126,05 184,81 89,98 5766,50 No Reference Casings 11055.47 6601,64 13970,00 6603,29 243,98 126,02 184,80 90,03 5773,71 No Reference Casings 11056,21 6601,68 13980,00 6607,76 243,95 126,00 184,80 90,07 5780,91 No Reference Casings 11056,95 6601,71 13990,00 6612,22 243,92 125,98 184,80 90,11 5788,11 No Reference Casings 11060,00 6601,83 14000,00 6616,70 243,80 125,66 184,65 90,16 5795,31 No Reference Casings 11060,00 6601,83 14010,00 6621.18 243,80 125,74 184,69 90,21 5802,51 No Reference Casings 11060,00 6601,83 14020,00 6625.67 243,80 125,82 184,73 90,25 5809,70 No Reference Casings 11060,00 6601,83 14030,00 6630,17 243,80 125,90 184,77 90,29 5816,90 No Reference Casings 11060,00 6601,83 14040.00 6634,67 243,80 125,99 184,82 90,33 5824,09 No Reference Casings 11060,00 6601,83 14050,00 6639,18 243,80 126,07 184,86 90,37 5831.28 No Reference Casings 11060,00 6601,83 14060,00 6643,70 243,80 126,15 184,90 90.42 5838.47 No Reference Casings 11060,00 6601,83 14070,00 6648.25 243.80 126,23 184,94 90.46 5845,65 No Reference Casings 11063,33 6601,90 14080,00 6652,84 243.67 125.89 184,78 90.51 5852,83 No Reference Casings 11064,01 6601,91 14090,00 6657.44 243,64 125,89 184,78 90,55 5860,03 No Reference Casings 11064,69 6601,91 14100.00 6662,03 243,61 125,89 184,78 90,60 5867,23 No Reference Casings 11065,36 6601,92 14110,00 6666,63 243,58 125,89 184,78 90,64 5874.43 No Reference Casings 11066.02 6601,92 14120,00 6671,22 243,56 125,89 184,78 90,69 5881,65 No Reference Casings 11066,68 6601,92 14130,00 6675,82 243,53 125,90 184,79 90,73 5888,87 No Reference Casings Site: KRU 10 Pad Well: 1 0-32 Rule Assigned: Major Risk Wellpath: P/an#7 1 0-32L 1 V7 Plan: Plan #7 V1 Inter-Site Error: 0,00 ft 10935,57 6561,92 12940,00 6176,14 246,32 137,78 187,34 84,79 5052,00 FAIL 10938,69 6563,61 12950,00 6180,07 246,32 137.69 187.31 84,84 5058,79 No Reference Casings 10941,80 6565.29 12960.00 6184.01 246.33 137.61 187.28 84,90 5065.57 No Reference Casings 10944,91 6566,95 12970,00 6187.95 246,33 137,52 187,25 84,95 5072,36 No Reference Casings 10948,01 6568,60 12980,00 6191,89 246,33 137.43 187,21 85,00 5079,15 No Reference Casings 10951,11 6570.23 12990,00 6195.83 246,33 137,34 187,18 85.05 5085,93 No Reference Casings 10954.20 6571,85 13000,00 6199.78 246,33 137.24 187.15 85,10 5092,72 No Reference Casings 10955,98 6572,77 13010,00 6203,73 246.33 137,09 187,11 85,17 5099,51 No Reference Casings 10957.29 6573.45 13020,00 6207,69 246.32 136,93 187.06 85,24 5106,30 No Reference Casings 10958,60 6574,11 13030,00 6211,65 246,31 136.75 187,02 85,30 5113,11 No Reference Casings 10960,00 6574,81 13040.00 6215,62 246,31 136.56 186,97 85,37 5119,92 No Reference Casings 10960,00 6574,81 13050.00 6219.59 246,31 136,67 186,98 85,38 5126,73 No Reference Casings 10962.51 6576,05 13060,00 6223,57 246,29 136,24 186,88 85,50 5133,55 No Reference Casings 10963.80 6576,67 13070,00 6227,55 246,28 136,07 186,84 85,57 5140,38 No Reference Casings 10965,08 6577.29 13080,00 6231,54 246,27 135,90 186,79 85,63 5147,22 No Reference Casings 10966,36 6577,90 13090,00 6235,54 246,26 135,73 186,75 85,69 5154,06 No Reference Casings 10967,64 6578,50 13100,00 6239,54 246,25 135,56 186,71 85,76 5160,92 No Reference Casings 10970,00 6579,59 13110,00 6243,54 246,23 135.15 186,62 85,86 5167,79 No Reference Casings 10970,00 6579,59 13120,00 6247,55 246,23 135,25 186,63 85,87 5174,67 No Reference Casings 10970,00 6579,59 13130,00 6251,56 246,23 135,35 186,65 85,89 5181,58 No Reference Casings 10972,66 6580,78 13140,00 6255,57 246,19 134.87 186,55 86,00 5188,50 No Reference Casings 10973,90 6581,33 13150,00 6259,59 246,18 134.70 186,51 86.06 5195.44 No Reference Casings 10975,12 6581.86 13160,00 6263.61 246,16 134.53 186.47 86,12 5202,39 No Reference Casings 10976,35 6582,39 13170,00 6267.63 246.15 134,36 186.44 86,18 5209,37 No Reference Casings 10977.56 6582,90 13180,00 6271,66 246.13 134,20 186.40 86.24 5216,36 No Reference Casings 10980,00 6583,92 13190,00 6275,69 246,1 ° 133.76 186,31 86,34 5223,36 No Reference Casings 10980,00 6583,92 13200,00 6279,73 246,1 ° 133,86 186,33 86,36 5230,37 No Reference Casings . BP-GDB Anticollision Report . 10980,00 6583,92 13210,00 6283,78 246,10 133,95 186,35 86,37 5237,38 No Reference Casings 10980,00 6583,92 13220,00 6287,83 246,10 134,05 186,36 86,39 5244.40 No Reference Casings 10983,53 6585,35 13230,00 6291,89 246,04 133,37 186,22 86,52 5251.40 No Reference Casings 10984,70 6585,81 13240,00 6295,96 246,03 133,21 186,19 86,58 5258.42 No Reference Casings 10985,88 6586,26 13250,00 6300,03 246,01 133,05 186,16 86,64 5265.43 No Reference Casings 10987,05 6586,71 13260,01 6304,12 245,99 132,89 186,13 86,69 5272.45 No Reference Casings 10990,00 6587,81 13270,00 6308.20 245,94 132,34 186,01 86,79 5279.45 No Reference Casings 10990,00 6587,81 13280,00 6312,29 245,94 132.44 186,03 86,82 5286.44 No Reference Casings 10990,00 6587,81 13290,00 6316,38 245,94 132,53 186,06 86,84 5293.43 No Reference Casings 10990,00 6587,81 13300,00 6320.48 245,94 132,63 186,08 86,86 5300.40 No Reference Casings 10992,83 6588,83 13310,00 6324,58 245,88 132,11 185,97 86,96 5307,36 No Reference Casings 10993,98 6589,23 13320,00 6328,69 245,86 131,95 185,94 87,01 5314,31 No Reference Casings 10995,12 6589,63 13330,00 6332,80 245,83 131,80 185,91 87,07 5321.25 No Reference Casings 10996,27 6590,02 13340,00 6336,91 245,81 131,65 185,88 87,12 5328,17 No Reference Casings 10997.41 6590.40 13350,00 6341.02 245,78 131,50 185,85 87,17 5335,09 No Reference Casings 11000,00 6591,25 13360,00 6345,14 245,73 131,03 185,74 87.26 5341,99 No Reference Casings 11000,00 6591,25 13370,00 6349,26 245,73 131,12 185,77 87.28 5348,89 No Reference Casings 11000,00 6591,25 13380,00 6353,39 245.73 131,22 185,80 87,31 5355,77 No Reference Casings 11000,00 6591.25 13390,00 6357,52 245.73 131,31 185,82 87,33 5362,64 No Reference Casings 11003,05 6592,20 13400,00 6361,65 245,66 130,75 185,70 87.43 5369,51 No Reference Casings 11004,16 6592,54 13410,00 6365,79 245,63 130,61 185,67 87.48 5376.40 No Reference Casings 11005,27 6592,87 13420,00 6369,93 245,60 130.47 185,64 87,53 5383,29 No Reference Casings 11006,36 6593,19 13430,00 6374,07 245,58 130,33 185,62 87,58 5390.20 No Reference Casings 11010,00 6594,21 13440,00 6378,22 245.49 129,65 185.46 87,67 5397,11 No Reference Casings 11010,00 6594.21 13450,00 6382,37 245.49 129,75 185.49 87,70 5404,04 No Reference Casings 11010,00 6594,21 13460,00 6386,53 245.49 129,84 185,52 87,73 5410,97 No Reference Casings 11010,00 6594,21 13470,00 6390,69 245.49 129,93 185,55 87,76 5417,91 No Reference Casings 11010,00 6594.21 13480,00 6394,86 245.49 130,03 185,57 87,79 5424,87 No Reference Casings 11012,79 6594,95 13490,00 6399,02 245.41 129,53 185.46 87,87 5431,83 No Reference Casings 11013,84 6595,22 13500,00 6403,19 245,38 129.41 185,44 87,92 5438,79 No Reference Casings 11014,88 6595.49 13510,00 6407,35 245,35 129,29 185.42 87,97 5445,77 No Reference Casings 11015,91 6595,74 13520,00 6411,51 245,32 129,16 185,39 88,01 5452,75 No Reference Casings 11016,94 6595,99 13530,00 6415,68 245,29 129,05 185,37 88,06 5459,75 No Reference Casings 11020,00 6596,70 13540,00 6419,83 245,21 128,52 185,24 88,14 5466,75 No Reference Casings 11020,00 6596,70 13550,00 6423,99 245,21 128,61 185,27 88,17 5473,75 No Reference Casings 11020,00 6596,70 13560,00 6428.15 245.21 128,70 185,30 88,20 5480,76 No Reference Casings 11020,00 6596,70 13570,00 6432,30 245,21 128,79 185,33 88,23 5487,78 No Reference Casings 11020,00 6596,70 13580,00 6436.45 245,21 128.88 185,37 88,27 5494,81 No Reference Casings 11022,96 6597,35 13590,00 6440,61 245,12 128,38 185,24 88,34 5501,84 No Reference Casings 11023,94 6597,55 13600,00 6444,79 245,09 128,27 185,22 88,39 5508,87 No Reference Casings 11024,91 6597,75 13610,00 6448,97 245,05 128,17 185,20 88.43 5515,91 No Reference Casings 11025,88 6597,94 13620,00 6453,18 245,02 128.07 185,19 88.48 5522,95 No Reference Casings 11026,84 6598,13 13630,00 6457,39 244,99 127.97 185.17 88,52 5530,00 No Reference Casings 11030,00 6598,72 13640,00 6461,62 244.90 127.46 185,03 88,60 5537,05 No Reference Casings 11030,00 6598,72 13650,00 6465,86 244.90 127,55 185,06 88,63 5544,10 No Reference Casings 11030,00 6598,72 13660,00 6470.11 244,90 127,64 185,10 88,67 5551,15 No Reference Casings 11030,00 6598,72 13670,00 6474,38 244,90 127.72 185,13 88,70 5558,21 No Reference Casings 11030,00 6598,72 13680,00 6478.66 244,90 127,80 185,17 88,74 5565,27 No Reference Casings 11030,00 6598,72 13690,00 6482,93 244,90 127,87 185,20 88,77 5572.35 No Reference Casings 11033,35 6599,28 13700,00 6487,19 244,78 127.31 185,06 88,84 5579.43 No Reference Casings 11034.26 6599.43 13710,00 6491.44 244,75 127,21 185,04 88,89 5586,54 No Reference Casings . BP-GDB Anticollision Report . 11035,15 6599,56 13720,00 6495,69 244,72 127,12 185,03 88,93 5593,66 No Reference Casings 11036,04 6599,70 13730,00 6499,92 244,69 127,02 185,01 88,98 5600,80 No Reference Casings 11036,92 6599,83 13740,00 6504,14 244,66 126,93 185,00 89,02 5607,95 No Reference Casings 11040,00 6600,24 13750,00 6508,35 244,56 126.46 184,86 89,09 5615,12 No Reference Casings 11040,00 6600,24 13760,00 6512,55 244,56 126,52 184,90 89,12 5622,31 No Reference Casings 11040,00 6600,24 13770,00 6516,74 244,56 126,58 184,93 89,16 5629,50 No Reference Casings 11040.00 6600,24 13780,00 6520,94 244,56 126,63 184,97 89,19 5636,71 No Reference Casings 11040,00 6600,24 13790,00 6525,15 244,56 126,68 185,01 89,23 5643,92 No Reference Casings 11040,00 6600,24 13800,00 6529,38 244,56 126,72 185,04 89,27 5651,13 No Reference Casings 11042,91 6600,60 13810,00 6533,62 244.45 126,27 184,91 89,33 5658,33 No Reference Casings 11043,74 6600,69 13820,00 6537,87 244.42 126,18 184,90 89,37 5665,54 No Reference Casings 11044,57 6600,78 13830,00 6542,09 244,39 126,09 184,89 89.41 5672,76 No Reference Casings 11045.40 6600,86 13840,00 6546,17 244,36 126,00 184,88 89.46 5680,00 No Reference Casings 11046,25 6600,95 13850,00 6550,05 244,33 125,91 184,87 89,50 5687,18 No Reference Casings 11050,00 6601,28 13860,00 6553,70 244,19 125,38 184,67 89,55 5694,26 No Reference Casings 11050,00 6601,28 13870,00 6557,1 ° 244,19 125,43 184,70 89,58 5701,22 No Reference Casings 11050,00 6601,28 13880,00 6560,27 244,19 125.49 184,73 89,60 5708,06 No Reference Casings 11050,00 6601,28 13890,00 6563,22 244,19 125,54 184,76 89,63 5714.74 No Reference Casings 11050,00 6601,28 13900,00 6565,97 244,19 125,60 184,78 89,65 5721,24 No Reference Casings 11050,00 6601,28 13910,00 6568,50 244,19 125,66 184,80 89,67 5727,56 No Reference Casings 11053,06 6601,50 13920,00 6570,82 244,07 125,27 184.63 89.70 5733.68 No Reference Casings 11054,14 6601,57 13930,00 6572,92 244,03 125,18 184,58 89,72 5739,60 No Reference Casings 11055,25 6601,63 13940,00 6574,80 243,99 125,09 184,53 89,74 5745,31 No Reference Casings 11056,38 6601,69 13950,00 6576.45 243,94 125,00 184.48 89,76 5750,80 No Reference Casings 11060,00 6601,83 13960,00 6577.88 243,80 124,59 184,26 89,78 5756,06 No Reference Casings 11060,00 6601,83 13970,00 6579,08 243,80 124,66 184,27 89,79 5761,08 No Reference Casings 11060,00 6601,83 13980,00 6580,05 243,80 124,73 184,28 89,79 5765,87 No Reference Casings 11060,00 6601,83 13990,00 6580,92 243,80 124,81 184,28 89,80 5770.45 No Reference Casings 11060,00 6601,83 14000,00 6581,78 243,80 124,88 184,29 89,81 5774,86 No Reference Casings 11063,54 6601,90 14010,00 6582,62 243,66 124,52 184,08 89,82 5779,09 No Reference Casings 11064.77 6601.91 14020,00 6583.46 243,61 124.45 184,01 89,83 5783,14 No Reference Casings 11066,01 6601.92 14030,00 6584,28 243,56 124,38 183,93 89,84 5787,01 No Reference Casings 11070,00 6601,88 14040,00 6585,10 243.40 124,03 183,68 89,84 5790,71 No Reference Casings 11070,00 6601,88 14050,00 6585,90 243.40 124,11 183,69 89,85 5794,22 No Reference Casings 11070,00 6601,88 14060,00 6586,70 243.40 124,19 183,70 89,86 5797,55 No Reference Casings 11070,00 6601,88 14070,00 6587.47 243.40 124.27 183,71 89,87 5800,69 No Reference Casings 11070.00 6601,88 14080,00 6588.24 243.40 124,35 183,72 89,88 5803,66 No Reference Casings 11073,62 6601,78 14090,00 6589,00 243,24 124,07 183.49 89,88 5806.43 No Reference Casings 11074,91 6601.72 14100,00 6589,74 243,19 124,04 183.42 89,89 5809,01 No Reference Casings 11076,20 6601,66 14110,00 6590.47 243,14 124,01 183,34 89,90 5811.41 No Reference Casings 11080.00 6601.44 14120,00 6591,18 242,98 123,78 183,10 89,90 5813,63 No Reference Casings 11080,00 6601.44 14130,00 6591,88 242,98 123,86 183.11 89.91 5815,64 No Reference Casings 11080,00 6601.44 14140,00 6592,57 242,98 123,95 183,12 89,92 5817.47 No Reference Casings 11081.40 6601,34 14150,00 6593,24 242,92 123,93 183,04 89,93 5819.11 No Reference Casings 11082.71 6601,23 14160,00 6593,90 242,86 123,92 182,96 89,94 5820,56 No Reference Casings 11084,01 6601,12 14170,00 6594.54 242,81 123.91 182,89 89,95 5821,81 No Reference Casings 11085,51 6600,98 14180,00 6595,16 242,74 123,90 182,80 89.95 5822,88 No Reference Casings 11085,51 6600.98 14190,00 6595,78 242,74 123,99 182,81 89.97 5823.75 No Reference Casings 11085,51 6600,98 14200.00 6596,37 242,74 124,08 182,83 89,98 5824.43 No Reference Casings 11085,51 6600,98 14210,00 6596,95 242,74 124.16 182,84 90,00 5824,91 No Reference Casings 11085,51 6600,98 14220,00 6597,51 242,74 124.25 182,86 90,01 5825,21 No Reference Casings . BP-GDB Anticollision Report . 11085,51 6600,98 14230,00 6598,05 242,74 124,34 182,87 90,03 5825,31 No Reference Casings 11085,51 6600,98 14240,00 6598,58 242,74 124.43 182,89 90,04 5825.23 No Reference Casings 11085,51 6600,98 14250,00 6599,09 242,74 124,51 182,90 90,06 5824,95 No Reference Casings 11085,51 6600,98 14260,00 6599,58 242,74 124.60 182,91 90,07 5824.48 No Reference Casings 11092,14 6600,35 14270,00 6600,06 242,1 ° 123,13 182,05 90,01 5823.77 No Reference Casings 11092,89 6600,28 14280,00 6600,50 242,03 123,04 181,97 90,01 5823,14 No Reference Casings 11093,64 6600,21 14290,00 6600,89 241,96 122,95 181,88 90,02 5822,74 No Reference Casings 11100,00 6599,59 14300,00 6601,22 241,34 121,52 181,05 89,96 5822,58 No Reference Casings 11100,00 6599.59 14310,00 6601,51 241,34 121,61 181,07 89,97 5822,60 No Reference Casings 11100.00 6599.59 14320.00 6601.74 241.34 121,70 181,08 89,98 5822,84 No Reference Casings 11100,00 6599,59 14330,00 6601,92 241,34 121,79 181,09 89,99 5823,31 No Reference Casings 11100,00 6599,59 14340,00 6602,06 241,34 121,88 181,10 90,00 5823,99 No Reference Casings 11100,00 6599,59 14350,00 6602,14 241,34 121,97 181,11 90,01 5824,89 No Reference Casings 11100,00 6599,59 14360,00 6602,16 241,34 122,06 181,12 90,02 5826,01 No Reference Casings 11100,00 6599,59 14370,00 6602,14 241,34 122,15 181,13 90,03 5827,34 No Reference Casings 11100,00 6599,59 14380,00 6602,07 241,34 122.23 181,14 90,04 5828,90 No Reference Casings 11100,00 6599,59 14390,00 6601,95 241,34 122,32 181,15 90,05 5830,60 No Reference Casings 11100,00 6599,59 14400,00 6601,81 241,34 122,41 181,15 90,06 5832,15 No Reference Casings 11100,00 6599,59 14410,00 6601,66 241,34 122,50 181,16 90,06 5833,52 No Reference Casings 11100,00 6599,59 14420,00 6601.49 241,34 122,59 181,17 90,07 5834,69 No Reference Casings 11100,00 6599,59 14430,00 6601,31 241,34 122,68 181,18 90,08 5835,67 No Reference Casings 11100,00 6599,59 14440.00 6601.11 241,34 122,77 181,18 90,09 5836.46 No Reference Casings 11100.00 6599,59 14450.00 6600.90 241,34 122,86 181,19 90,09 5837,05 No Reference Casings 11100.00 6599,59 14460,00 6600,68 241,34 122,95 181,20 90.10 5837.46 No Reference Casings 11100,00 6599.59 14470,00 6600.44 241,34 123,04 181.21 90,11 5837,67 No Reference Casings 11100,00 6599.59 14480,00 6600,19 241,34 123,14 181.21 90,12 5837,69 No Reference Casings 11100,00 6599,59 14490,00 6599,92 241,34 123,23 181,22 90,12 5837,52 No Reference Casings 11100,00 6599,59 14500,00 6599,64 241,34 123,32 181,23 90,13 5837,16 No Reference Casings 11100,00 6599,59 14510,00 6599,35 241,34 123.41 181,23 90,14 5836,61 No Reference Casings 11110,90 6598,54 14520,00 6599,04 240,07 120,85 179,80 90,02 5835,73 No Reference Casings 11111,65 6598.4 7 14530,00 6598,72 239,98 120,76 179,71 90,01 5834,78 No Reference Casings 11112,40 6598.40 14540.00 6598,39 239,89 120,66 179,61 90,01 5833,63 No Reference Casings 11113,15 6598,32 14550,00 6598,05 239,80 120,57 179,52 90,01 5832,29 No Reference Casings 11113,90 6598,25 14560,00 6597,69 239.72 120.47 179.43 90.00 5830.76 No Reference Casings 11125,00 6597,18 14570,00 6597,32 238.41 117,80 177,97 89,88 5829.40 No Reference Casings 11125,00 6597,18 14580,00 6596,94 238.41 117,89 177,97 89,89 5828,12 No Reference Casings 11125,00 6597,18 14590.00 6596,54 238.41 117,98 177.98 89,89 5827,07 No Reference Casings 11125,00 6597,18 14600,00 6596,14 238.41 118,07 177.98 89,90 5826.24 No Reference Casings 11125,00 6597,18 14610.00 6595,73 238.41 118,16 177,99 89,90 5825,64 No Reference Casings 11125,00 6597,18 14620,00 6595,31 238.41 118,26 177,99 89,91 5825.27 No Reference Casings 11125,00 6597.18 14630,00 6594,87 238.41 118,35 178,00 89,91 5825,12 No Reference Casings 11125,00 6597,18 14640.00 6594.43 238.41 118.44 178,00 89,92 5825.20 No Reference Casings 11125,00 6597,18 14650.00 6593,98 238.41 118,53 178,01 89,92 5825,50 No Reference Casings 11125,00 6597.18 14660,00 6593,52 238.41 118,63 178,01 89,93 5826,03 No Reference Casings 11125,00 6597,18 14670,00 6593,05 238.41 118,72 178,02 89,93 5826,79 No Reference Casings 11125,00 6597,18 14680,00 6592,57 238.41 118,81 178.02 89,94 5827.77 No Reference Casings 11125,00 6597.18 14690,00 6592,08 238.41 118,91 178,03 89,94 5828,97 No Reference Casings 11125,00 6597.18 14700,00 6591,59 238.41 119,00 178,03 89,95 5830.41 No Reference Casings 11125,00 6597,18 14710,00 6591,08 238.41 119,1 ° 178,04 89,95 5832,06 No Reference Casings 11125,00 6597,18 14720,00 6590,57 238.41 119,19 178,04 89,96 5833,94 No Reference Casings 11125,00 6597,18 14730,00 6590,05 238.41 119,28 178,05 89,96 5836,03 No Reference Casings . BP-GDB Anticollision Report . 11125,00 6597,18 14740,00 6589,52 238.41 119,37 178,05 89,97 5838,35 No Reference Casings 11125,00 6597,18 14750,00 6588,99 238.41 119.47 178,05 89,97 5840,89 No Reference Casings 11125,00 6597,18 14760,00 6588.44 238.41 119,56 178,06 89,97 5843,64 No Reference Casings 11125,00 6597,18 14770,00 6587,92 238.41 119,65 178,06 89,98 5846,39 No Reference Casings 11125,00 6597,18 14780,00 6587.42 238,41 119,75 178,07 89,98 5848,94 No Reference Casings 11125,00 6597,18 14790,00 6586,95 238.41 119,84 178,07 89.99 5851,32 No Reference Casings 11125,00 6597,18 14800,00 6586,51 238.41 119,93 178,08 89,99 5853,50 No Reference Casings 11125,00 6597,18 14810,00 6586,10 238.41 120,03 178,08 90,00 5855,50 No Reference Casings 11125,00 6597,18 14820,00 6585,72 238,41 120,12 178,09 90,00 5857,32 No Reference Casings 11125,00 6597,18 14830,00 6585,37 238.41 120,22 178,09 90,01 5858,95 No Reference Casings 11125,00 6597,18 14840,00 6585,05 238.41 120,31 178,10 90,01 5860,38 No Reference Casings 11125,00 6597,18 14850,00 6584.76 238.41 120.41 178,11 90,02 5861,64 No Reference Casings 11136,24 6596,09 14860,00 6584,50 236,81 117,64 176,63 89,90 5862,55 No Reference Casings 11136,99 6596,01 14870,00 6584,28 236,70 117,55 176,53 89,90 5863.41 No Reference Casings 11137,74 6595,94 14880,00 6584,06 236,59 117.45 176.44 89,89 5864,07 No Reference Casings 11138.49 6595,87 14890,00 6583,85 236.48 117,35 176,35 89,89 5864,53 No Reference Casings 11150,00 6594,75 14900,00 6583,64 234,84 114.45 174,83 89,76 5864,94 No Reference Casings 11150,00 6594,75 14910,00 6583.42 234,84 114,55 174,84 89,77 5865,00 No Reference Casings 11150,00 6594,75 14920,00 6583,21 234,84 114,64 174,85 89,78 5864,87 No Reference Casings 11150,00 6594.75 14930,00 6583,00 234,84 114,74 174,86 89,79 5864,55 No Reference Casings 11150,00 6594,75 14940,00 6582,79 234,84 114,84 174,86 89,79 5864,03 No Reference Casings 11150,00 6594,75 14950,00 6582,58 234,84 114,93 174,87 89,80 5863,33 No Reference Casings 11150,00 6594,75 14960,00 6582,37 234,84 115,03 174,88 89,81 5862.43 No Reference Casings 11150,00 6594,75 14970,00 6582,16 234,84 115,13 174,89 89,82 5861,58 No Reference Casings 11150,00 6594,75 14980,00 6581,95 234,84 115,22 174,89 89,82 5860,96 No Reference Casings 11150,00 6594,75 14990,00 6581,74 234,84 115.32 174,90 89,83 5860,56 No Reference Casings 11150,00 6594,75 15000,00 6581,53 234,84 115.42 174,91 89.84 5860,39 No Reference Casings 11150,00 6594,75 15010,00 6581,32 234,84 115,52 174,92 89,85 5860,45 No Reference Casings 11150,00 6594,75 15020,00 6581.11 234,84 115,62 174,92 89,85 5860,73 No Reference Casings 11150,00 6594,75 15030,00 6580,90 234.84 115,71 174,93 89,86 5861,24 No Reference Casings 11150,00 6594,75 15040,00 6580,70 234,84 115,81 174,94 89,87 5861,97 No Reference Casings 11150,00 6594,75 15050,00 6580.49 234,84 115,91 174,95 89,88 5862,93 No Reference Casings 11150,00 6594.75 15060,00 6580,28 234,84 116,01 174,95 89,88 5864,12 No Reference Casings 11150,00 6594,75 15070,00 6580,08 234,84 116,11 174,96 89,89 5865,53 No Reference Casings 11150,00 6594,75 15080,00 6579,87 234,84 116,21 174,97 89,90 5867.16 No Reference Casings 11150,00 6594,75 15090,00 6579,67 234,84 116,31 174,98 89,91 5869,02 No Reference Casings 11150,00 6594,75 15100,00 6579.47 234,84 116.41 174,98 89,91 5871.09 No Reference Casings 11150,00 6594,75 15110,00 6579,27 234,84 116,50 174,99 89,92 5873,39 No Reference Casings 11150,00 6594,75 15120,00 6579,07 234,84 116,60 175,00 89,93 5875,91 No Reference Casings 11150.00 6594,75 15130,00 6578,87 234.84 116,70 175,01 89,94 5878,64 No Reference Casings 11150,00 6594,75 15140,00 6578.68 234,84 116,80 175,01 89,94 5881,60 No Reference Casings 11150,00 6594,75 15150,00 6578.48 234,84 116,90 175,02 89,95 5884,76 No Reference Casings 11150,00 6594,75 15160,00 6578.29 234,84 116,99 175,03 89,96 5888.14 No Reference Casings 11150,00 6594,75 15170.00 6578,1 ° 234,84 117,09 175.03 89,96 5891,73 No Reference Casings 11150,00 6594,75 15180,00 6577.91 234,84 117,18 175.04 89,97 5895,53 No Reference Casings 11150,00 6594,75 15190,00 6577.73 234.84 117,28 175,05 89,98 5899,54 No Reference Casings 11161,25 6593,65 15200,00 6577,54 232,94 114.38 173,57 89,85 5903,39 No Reference Casings 11161,94 6593,58 15210,00 6577,35 232,82 114.29 173.48 89,85 5907,18 No Reference Casings 11162,64 6593,52 15220.00 6577,17 232.71 114,20 173.40 89,85 5910,80 No Reference Casings 11163,34 6593,45 15230.00 6576.98 232,59 114.11 173,31 89,85 5914.23 No Reference Casings . BP-GDB Anticollision Report . 11164,04 6593,38 15240,00 6576,80 232.47 114,02 173,23 89,85 5917.48 No Reference Casings 11175,00 6592,31 15250,00 6576,61 230,62 111,14 171,78 89,73 5920,66 No Reference Casings 11175,00 6592,31 15260,00 6576.43 230,62 111,24 171,79 89,73 5923,52 No Reference Casings 11175,00 6592.31 15270,00 6576,25 230,62 111,34 171,80 89,74 5926,20 No Reference Casings 11175,00 6592,31 15280,00 6576,06 230,62 111.44 171,81 89,75 5928,69 No Reference Casings 11175,00 6592,31 15290,00 6575,88 230,62 111,54 171,81 89,76 5930.99 No Reference Casings 11175,00 6592,31 15300,00 6575,70 230.62 111.64 171,82 89,76 5933,11 No Reference Casings 11175,00 6592,31 15310,00 6575,52 230,62 111.74 171,83 89,77 5935,03 No Reference Casings 11175,00 6592,31 15320,00 6575,34 230,62 111,84 171,84 89,78 5936,77 No Reference Casings 11175,00 6592,31 15330,00 6575,16 230,62 111,94 171,84 89,79 5938,32 No Reference Casings 11175,00 6592,31 15340,00 6574,98 230,62 112,05 171,85 89,79 5939,67 No Reference Casings 11175,00 6592,31 15350,00 6574,81 230,62 112,15 171,86 89,80 5940,83 No Reference Casings 11175,00 6592,31 15360,00 6574,63 230,62 112,25 171,87 89,81 5941,81 No Reference Casings 11175,00 6592,31 15370,00 6574.46 230.62 112,36 171.87 89,82 5942,59 No Reference Casings 11175,00 6592,31 15380,00 6574,29 230,62 112.46 171,88 89,83 5943,17 No Reference Casings 11175,00 6592,31 15390,00 6574,12 230,62 112,56 171,89 89,83 5943,57 No Reference Casings 11175,00 6592,31 15400,00 6573,95 230,62 112,67 171,90 89,84 5943,77 No Reference Casings 11175,00 6592,31 15410,00 6573,78 230,62 112,77 171,90 89,85 5943,78 No Reference Casings 11175,00 6592,31 15420,00 6573,61 230.62 112.87 171.91 89,86 5943,60 No Reference Casings 11175,00 6592,31 15430,00 6573.45 230,62 112,98 171,92 89,86 5943,23 No Reference Casings 11175,00 6592,31 15440,00 6573,29 230,62 113,08 171,93 89,87 5942,66 No Reference Casings 11175,00 6592,31 15450,00 6573,12 230,62 113,18 171,94 89,88 5941,90 No Reference Casings 11175,00 6592,31 15460,00 6572.92 230,62 113,28 171,94 89,89 5940,95 No Reference Casings 11175,00 6592,31 15470,00 6572,70 230,62 113,39 171,95 89,89 5939,81 No Reference Casings 11175,00 6592,31 15480,00 6572.46 230,62 113.49 171,96 89,90 5938.48 No Reference Casings 12300,00 6561,33 15490,00 6572,20 244,71 132,72 181.49 90,12 5936,94 No Reference Casings 12300,00 6561,33 15500,00 6571,92 244,71 132,82 181.48 90,12 5933,44 No Reference Casings 12300,00 6561,33 15510,00 6571.62 244,71 132,91 181.48 90.11 5929,76 No Reference Casings 12300,00 6561,33 15520,00 6571.29 244.71 133,01 181.47 90.11 5925,91 No Reference Casings 12300,00 6561,33 15530,00 6570,95 244.71 133.10 181.47 90.10 5921,87 No Reference Casings 12300,00 6561,33 15540,00 6570,59 244,71 133,20 181.46 90,10 5917,89 No Reference Casings 12300,00 6561,33 15550,00 6570,22 244,71 133.29 181.46 90,09 5914,1 ° No Reference Casings 12300,00 6561,33 15560,00 6569,85 244,71 133,39 181.45 90,09 5910,53 No Reference Casings 12300,00 6561,33 15570,00 6569.47 244,71 133.48 181.45 90,08 5907,17 No Reference Casings 12300,00 6561,33 15580,00 6569,08 244,71 133,58 181.44 90,08 5904,02 No Reference Casings 12300,00 6561,33 15590,00 6568,68 244,71 133,68 181.43 90,07 5901,09 No Reference Casings 12300,00 6561,33 15600,00 6568,28 244,71 133.77 181.43 90,06 5898,37 No Reference Casings 12300,00 6561,33 15610,00 6567,87 244,71 133,88 181.42 90,06 5895,88 No Reference Casings 12300,00 6561,33 15620,00 6567.45 244.71 133,98 181.42 90,05 5893,60 No Reference Casings 12300,00 6561,33 15630,00 6567,03 244,71 134,08 181.41 90.05 5891,54 No Reference Casings 12300,00 6561,33 15640,00 6566,60 244,71 134,18 181.40 90,04 5889,70 No Reference Casings 12300,00 6561,33 15650,00 6566.16 244,71 134,28 181.40 90,03 5888,09 No Reference Casings 12300,00 6561,33 15660,00 6565.72 244,71 134,39 181,39 90,03 5886.70 No Reference Casings 12300,00 6561,33 15670,00 6565.27 244,71 134.49 181,38 90,02 5885,53 No Reference Casings 12300,00 6561,33 15680,00 6564,82 244,71 134.60 181,38 90,01 5884,59 No Reference Casings 12311,35 6561,57 15690.00 6564,36 243.43 131,93 180,04 90.04 5883,73 No Reference Casings 12312,09 6561,59 15700,00 6563,90 243.34 131,85 179,94 90,03 5883,22 No Reference Casings 12312,84 6561,61 15710,00 6563.43 243,26 131.77 179,85 90,03 5882.93 No Reference Casings 12313,59 6561,62 15720,00 6562,96 243,17 131,69 179.76 90,02 5882.87 No Reference Casings 12325,00 6561,87 15730,00 6562.48 241,88 128,92 178.41 90,05 5883,17 No Reference Casings 12325,00 6561.87 15740,00 6562,00 241,88 129,03 178.40 90,04 5883,54 No Reference Casings . BP-GDB Anticollision Report . 12325,00 6561,87 15750,00 6561,51 241,88 129,14 178.40 90,03 5884,14 No Reference Casings 12325,00 6561,87 15760,00 6561,02 241,88 129,25 178,39 90,03 5884,97 No Reference Casings 12325,00 6561,87 15770,00 6560,53 241,88 129,36 178,38 90,02 5886,02 No Reference Casings 12325,00 6561,87 15780,00 6560,03 241,88 129.47 178,37 90,01 5887,29 No Reference Casings 12325,00 6561,87 15790,00 6559,53 241,88 129,57 178,37 90,00 5888,79 No Reference Casings 12325,00 6561,87 15800,00 6559,03 241,88 129,68 178,36 90,00 5890,51 No Reference Casings 12325,00 6561,87 15810,00 6558,52 241,88 129,79 178,35 89,99 5892.46 No Reference Casings 12325,00 6561,87 15820,00 6558,01 241,88 129,90 178,35 89,98 5894,62 No Reference Casings 12325,00 6561,87 15830,00 6557,50 241,88 130,00 178,34 89,98 5897,01 No Reference Casings 12325,00 6561,87 15840,00 6556,99 241,88 130,11 178,33 89,97 5899,61 No Reference Casings 12325,00 6561,87 15850,00 6556.48 241,88 130,22 178,33 89,96 5902.43 No Reference Casings 12325,00 6561,87 15860,00 6555,96 241,88 130,32 178,32 89,96 5905.47 No Reference Casings 12325,00 6561,87 15870.00 6555.44 241,88 130.43 178,31 89.95 5908,72 No Reference Casings 12325,00 6561,87 15880.00 6554,92 241,88 130,53 178,30 89.94 5912,18 No Reference Casings 12325,00 6561,87 15890,00 6554.40 241,88 130,63 178,30 89,94 5915,86 No Reference Casings 12325,00 6561,87 15900,00 6553,88 241,88 130,74 178,29 89,93 5919,74 No Reference Casings 12325,00 6561,87 15910,00 6553,36 241,88 130,84 178,28 89,92 5923,83 No Reference Casings 12325,00 6561,87 15920,00 6552,84 241.88 130.94 178,28 89,91 5928,12 No Reference Casings 12325,00 6561,87 15930,00 6552,31 241,88 131,04 178,27 89,91 5932,61 No Reference Casings . BOP-Tree . .. . .. . . . . . 11II ::=¡=~,c9~"¡¡~~\!!ílli .."...,." ~71116"5000 n<>rRX46 ,., :""0':- .:~:~:~:~:~:~:~:~:~:::~:~:~r:~:\ ......:-. ::..;::::..:, -::..:",:,:: :;< '.".:. -'::':':" ::~~. ./..::.,:-: -'~:"':" -.:: :. ::.: .:. .... ". Well Rig Floor ~ f~~$QØÞ.¡:wn< ~ ~ ~ I I1t4;ri.@t.tV$Y~. I ~ ~ Swab Valve , Tree Size , SSV I ~ Master Valve ~ ~ Base Flange , ~ Page 1 e e AA.I ID--l\ I q9 ~ 012- \ \) -\\ L- ~ dÒ4.-ð-\' 1Þ )t>- \ \ L d-- dù4-ð \::: HEC1lANICAL INTEGRITY REPORT . SPUD DATE: ~ OPER & FIELD 101 z.Þ J 0} ~ \-'7"£LL NUMBER AAI I D-I\ µù 10)9-012. RIG RELEASE: WELL DATA TD: I )"z.,34 lID hîl~ TVD. PBTD: 1t16-b MD TVD Z:I-~ Casing:~" L-'~O Shoe: loS"-bS MD TVDI DV: MD ·TVD 12-.b~ (0 11z.,~1- TVD I Liner: -4ï¿' ¡.:- ßO Shoe: Jo -10 J ;wit TOP: MD TVD Tubing :-1~~' Packer 10--\01 MD Hole Size ð'h.. and b ·17£ " TVD, Set at I Perfs IOqo'i )04 z..o to lo~8 0 " MECHANICAL INTEGRITY - PART #1 Annulus Press Test: IP J 15 min . 30 min Comments: /" MECHANICAL INTEGRITY - PART 12 . Cement Volumes: Amt. Liner \10 6)l t:, I Csg Z2D~G:, I DV l:lt. · . D~?>I ~I L.F Cmt vol to cover perfs 5 . 0 -u. ..3 '/8 ~ .1~46 ~""'LÇ [p2-3.... -/I bb}c. o~ 51 to t c:;)) + (\t 2..3 -4 - IO~07. \ )( .0805'""-:::' 3 J. 3 s)<. '4" b~ ~ ,0"''''2,. Uf.t£Theoretical Toe Ç! ,~S'o· -:..' D8DS S1/£-t"- lo9o--=J - ! 40 - 3'·3 \J ~17 Cement Bond Log (Yes or No)~' '-Be.. . ) -:- . 08 oS'" J::: 955_1 I In AOGCC File..'~6rí . , . CBL Evaluation, zone above perfs t..O~ IN~"AI. 90d) - 105'40 boob BON.):) B'1oo' " I é..>t,-,,*u;.N1 1301"1:) ~.3o:::) - T]:) . Produc.tion Log: Type I Evaluation CONCLUSIONS: Part #1: Part 12: i"\1 I 5 IN [) 1c...A 7£..D WM I /"112-000 . . rev. OS/20/87 C.028 1(;-1 \ 1\ l N . KRU lD-llL2 Proposed Injector Pre-drilled liner . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME K£?< /-.1)-/( ¿ Z- PTD# 2úcf-z/'z Tbe permit is for a new weJJbpresegment of existing weD ;::/Zk( /' D. - /1 ~ . l ¡,., Permit No/99..ð7t:API No. So ~Oz7.'-Z27 q; (If API number· - - . ,sbouJd continue to be reponed as Jast two, (2) digits a fun~~~t), 'of tbe ,.original API number, stated are between 60-69) above. '7"'. / . , ..J-þt~J ec.. t7~' ' , PILOT HOLE)n accordance witb 20 AAC 25.005(f), all (PH) records, data and Jogs acquired ,for tbe pilot boJe must be dearJy differentiated In both name (name on permit plus PH) " and API number (50 - 70/80) from records, data and logs acquired for we)) (name on permit). Development V Service CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL ¿/ SPACING EXCEPTION DRY DITCH SAMPLE " Exploration Stratigraphic "CLUE". -Gò p,r. Jj V'-> Tbe permit is approved subject ·to fuD , compJiance with 20 AAC 25.,OS5~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spa cing ex cep1ion. (CompanY Name) assumes tbe liability of any protest to tbe spacing ,exception tbat may occur. AlJ dry ditcb sample sets submitted to the Commission must be in nO greater than 30' sample intervals from below tbe permafrost or from wbere samples are first caught and 10' sample h:iter:vals through target zones. " Field & Pool KUPARUK RIVER. KUPARUK RV OIL - 490100 Well Name: KUPARUK RIV UNIT 1 D-11 L2 Program SER Well bore seg ~ COPHILLlPS ALASKA INC Initial ClasslType SERIPEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal D - Administration Permit fee attached. - - - - - - - - - - - - .NA Ml,lltilate(al. well segment; Jee.waived per .20 AAC25,P05(e) - - - - - - 2 Lease number .appropriate. . . . . . . - - - - - - - - · . Yes Ml,lltilateral. well.segment:. top produ.ctiv.ejnterval alJd. TO in ADL .0282~3 . . 3 .U.nique well.n.ame.a!ld lJumb.er . . . . . . . . . . . . - . . . . . . . . . . . . . . . . . . . . .Yes . -. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 4 Well .located in.ad.efjnedpool . . - - - - - - - - - - - - - - . Yes Kup,aru!< Rive( Oil. ~o.ol. governed by Con.servatip!l Order No, 4328 . . . . . - - - - - - - - - 5 Well .located prpper .distance from driJIing I,Initb.ol,lnd.ary . . . · . .Yes - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - 6 WellJocated proper .distance. from other wells. - - - - - - Yes - - - - - - - - - - - - - - 7 .S.u{ficientacreageaYailable in. dJillil1g unjt. - - - - - . .Yes - - - - - - - - - - - - - - - - - - - - 8 Jfdeviated, js. weJlbore pla!.incJu.ded . .Yes - - - - - -- - - - - - - - - - - - 9 .Operator only affected party . - - - - - - - - - · . .Yes - - - - - - - - - - - - - - - - - - -- - - - -- - - - - - - - - - - - 10 .Ope(ator has.appropriate.b.ond inJorce. . . . . - . . . . . . . . . . . . . . . . . . . . . . . . .Yes . -, - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 11 Permit c.a!l be issued without co.nservation order. . . . . . . . . .Yes - - - - - - - - - - - - - - - - - - - - - - - - - - -- Appr Date 12 Permit c.a!l be issued without admilJistratilleapprpvaJ . . . - - - - - - - - - - - · . Yes - - - - - - - - -- . SFD 10/25/2004 13 Can permit be approved before 15-day wait Yes 14 Well .located within area andstrataal,lthorized by.l!ljectiol1 Order # (put 10# in. comm.e!lts). (For .Yes Area Injectio.n.Qrder NO,.2B - - - - - - - - - - - - - 15 AJI welJs.wit]1i.nJl4_mil.e.area.of reyiew ide!ltifi!!d (F9r servjce.w.ell only) . . . . . . _ . . . . . . . .Yes Non.e. . . . _ _ _ . _ _ . . . . . . . . . - -. - - - - . - . . . . . . . . . . . . . . . - . . . . . - - - - - - . - - - - 16 PJe-produced i!ljec!or; duration.oJ pre-prodl,lction less. tha" 3 months. (For.service well onJy) . . No - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 17 AGMPfinding .of Con.siste!lcyhas bee.njs.s!Jed. for,this pr.oiect . .NA Ml,lltilater.al well.segment . . - - - - - -~ Engineering 18 .C.o!lductor string.PJovided . . . - - - - - NA Condl,lGtor jnstaJled. i!l j D-.11 (199-072),. 19 .S!Jrfacecas.ing.pJotec.ts. alLknown. USOWs . NA All aquiJers exempted 40 cm 147..103(b)(3). . . . - - - - - - - - - - - 20 .CMT v.ol adequate. to circ.ulate. o.nconductor. & su.rf.csg . . . · NA Surtace ca.si.ng inst<alJe.djn 10-H.. . . - - - - - - - - - - - - - - - - - - - - - - - - - - 21 .CMT v.ol adeQu.ate to tie-inJQng .string to.surf csg. NA Production. c.asil1g set in l.D~ 11, . - - - - - - - - - 22 CMTwill coyer.aJl !<no.w.n.productiYe hori~on.s. . · No Slotte.d Jil1er .compleUo!l plal1l1ed. - - - - - - - - - - 23 .C.asi!lg desig!ls. adeQuate fpr C,.T. B.&.pern:Jafrpst . . . . . . .Yes. - - - - - - - - - - - - - - - - - - - - - - - - - 24 .Adequate.tan.l<age.oJ re.serve pit. . . . .Yes. Rig is.equippe.d.with steelpjts, No rese.l'le.pjtplanned, AU waste to.Class JI.w.ells., . . - - - - - 25 Jfa.re-drilt has.a. 10:4.03 fOJ abandonment bee!l apPJoved . . · NA. - - - - - - - - - - - - - - - - - - - - 26 .Adequate .weUbore s.eparatjo.n proposed. . . - . . . - . . . . - . - . . . - . . . .Yes.. . . _ prOJJ:imity an<alysis perf.orme.d, Near!!st w~lJb.ore.is 1,.1 lateral. :--25' tvd .below and_ 20P'.sPl,lth pf wellpath.. . . . . 27 Jf.diverter Jeq.uiJed, does. it.meet reguJations. . . . - - - - - .NA BOP alre.ady in place.. . . . - - - - -- - - - - - - - - - - - - Appr Date 28 .DJilIiog fJujdprogram sc.hematic.& eq!JipJistadequate. . . . . . . . . . · .Yes. BI:I~ exp!!cted at.1 0.0 .EMW.. ~lal1 to .use dynamic oveJbaJa.nce with 8..7: ppgJluidaod 650psLat surtace.. . . . TEM 10/26/2004 29 .BOPEs,do.they meetr!!guJation . . . - - - - -- . . .Yes. - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - -- - - - - - ~~7V1.. \0 b.v 30 .BOPE,press rati!lg appropriate; .test to .(put ps.ig in .comments). Yes. Reservoir MASP calcuJa.tedat 27:32 psi, MASPcircuJatil1g 3600 psi. 450PpsLBQP test pla!lne~t 31 Choke manifold compJies. w/APLRf>-53 (May 64) - - - - Yes.. . - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - -- - - - - - - 32 Work will occ!Jr withoutoperatjon .shutdown. . - - -- - - - -- Yes. . - - - - - - - - - - - -- 33 .Is. presence. of H2S gas. prob.able. . . . - - - - - - - - - - Yes.. . 1:125 is. present on 1 D pad, Mud .shouJd. pJecJude H2S on rig, . Rig is .eQuipp.ed with sensors and. aJarms,. . 34 Mecha.nicalcOlJdjUo!l pf wells wi.thin AOR yeriJied (For.s.ervice welJ only) .Yes. No wells withio area otrelliew. . MotheJb.ore eval!Jated 117100 and. approved, . . . . . - - - -- Geology 35 Permit ca!l be issued wlo. hydr.ogen. s.ulfide meaS!Jres. . . · No.. AlthOl,lgho.nly.3.ppm.H2S.have b.eelJ meas.ureJJjI11Q-1 t. other.1D.c~ad.weJls have meas.ure.d.belween 36. & 1Q2.p. 36 .D.ata.PJeselJted on. pote.ntiaI9veJpres.sl,lre .zones. · .Yes. E:xpected resel'lojr pre.ssuJe i.sJO,P ppg E:MW, wiJI be drilled with. 8,7: ppg.mud.and con.stantbottomhoJe.presSl,lre Appr Date 37 .Sei.smicanalysjs. of shallow gas.zPoes. . .NA. tocompens.ate for reduc.ed m.ud weight SFD 10/25/2004 38 .Seabedconditi911 survey (if Off-s.h.ore) . . . . . NA 139 . Conta.ct nam.elp]1QneJor.weekly progres.s.reports [exploratory .only] NA.. . - Geologic Date: Engineering Date Date Commissioner Commissioner tJ\S 0\1.7/4- /¡f¡~y . . 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 simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 0:tc!"'- f)ö4 - d(~ · REViSE COP'/ **** REEL HEADER **** LDWG 06/12/07 AWS 01 **** TAPE HEADER **** LDWG 06/12/06 01 *** LIS COMMENT RECORD *** . RECE.NEO OEC 2 8 7.00Ô comm\sSiOO ..O\\&~ !!!!! !!!!!!!!!!!!!! LDWG File Version 1.000 !!! !!!!!!!!!!!!!!!! Extract File: LISTAPE.HED TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 5 Z. AHMED G. GOODRICH # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING 4TH STRING PRODUCTION STRING # ;t: IL/303 7l1D-11L2PB1 (' 500292294670 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 06-DEC-06 MWD RUN 6 6 D. BARBA G. SARBER 23 11N 10E 105.50 00.00 00.00 OPEN HOLE CASING BIT SIZE (IN) SIZE (IN) 16.000 9.625 7.000 4.500 4.125 MWD RUN 7 7 E. AGUIRRE G. GOODRICH DRILLERS DEPTH (FT) 115.0 6814.0 10564.0 10946.0 12091.0 . . REMARKS: PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 17' 55.565" LONG: W149 DEG 30' 36.425" LOG MEASURED FROM K.B. AT 105.5 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data are real time data. (4) Baker Hughes INTEQ utilized Coiltrak downhole tools and the Advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, a Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (inner and outer downhole pressure, downhole weight on bit), a Gamma and Directional Sub, Ultra Slim Resistivity Sub and a Hydraulic Orienting Sub, with a Near Bit Inclination Sensor. (6) Data presented here is final and was not depth adjusted to a PDC (Primary Depth Control) log. The INTEQ Gamma Ray is the PDC (7) through a milled window for well 1D-11L2PB1. The 1D-11L2PB1 wellbore was drilled from 1D-11 in 4.5" liner. Top of window 10938.6 ft. MD (6457.8 ft. SSTVD) Bottom of window 10946.0 ft. MD (6481.8 ft. SSTVD) (8) The interval from 12049 ft. to 12091 ft. MD (6451.8 ft. to 6447 ft. SSTVD)was not logged due to bit to sensor offset. (9) The 1D-11L2PB1 wellbore was tied to 1D-11 at 10907 ft. MD (6440.8 ft. SSTVD). $ Tape Subfile: 1 76 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** · . !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE001.HED FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 10946.0 STOP DEPTH 12091.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 5 6 7 MERGE TOP 10946.0 11021. 0 11990.0 MERGE BASE 11021. 0 11990.0 12091. 0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT 1D-11L2PB1 5.xtf 150 ConocoPhillips Alaska, Inc. 1D-1IL2PB1 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 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: 36 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 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPS MWD 68 1 OHMM 4 4 4 RAD MWD 68 1 OHMM 4 4 5 RAS MWD 68 1 OHMM 4 4 6 ROP MWD 68 1 FPHR 4 4 ------- 24 Total Data Records: 64 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 10946.000000 12091.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 106 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! !! ! ! ! ! ! ! !!!!!!!!!!!!!!!!!! ! LDWG File Version 1.000 Extract File: FILE011.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 log header data for each bit run in separate files. 5 .2500 START DEPTH 10946.0 STOP DEPTH 11021.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: 11-NOV-04 ADVANTAGE . DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE MPR GRAM DIR $ BOTTOM) TOOL TYPE MULT. PROP. GAMMA RAY DIRECTIONAL RESIST. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . 3 CTK MEMORY 11060.0 10946.0 11021. 0 o 57.8 79.8 TOOL NUMBER 10023579 10079134 10079128 4.125 10946.0 Flo-Pro 8.70 .0 .0 28500 .0 .000 .000 .000 .000 100.0 .0 .0 .0 .00 .000 .0 o BIT RUN 5 (MWD Run 5). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWÐ-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 1D-1IL2PB1. xtf 150 ConocoPhillips Alaska, I 1D-11L2PB1 Kuparuk River North Slope Alaska . . *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 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: 36 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 6 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 ------- 24 Total Data Records: 9 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 10946.000000 11021.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 91 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 · . *** LIS COMMENT RECORD *** !!!!!! !!!!!!!!!!!!! LDWG File Version 1.000 ! !!!!!!!!!!!!!!!!!! Extract File: FILE012.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 3 log header data for each bit run in separate files. 6 .2500 START DEPTH 11021. 0 STOP DEPTH 11990.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE MPR GRAM DIR $ BOTTOM) TOOL TYPE MULT. PROP. GAMMA RAY DIRECTIONAL RESIST. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: BIT RUN 6 (MWD Run 6). GR/MPR. CURVE GLOSSARY: 12-NOV-04 ADVANTAGE 3 CTK MEMORY 12029.0 11021. 0 11990.0 o 57.1 97.4 TOOL NUMBER 10023579 10079134 10079128 4.125 10946.0 Flo-Pro 8.70 .0 .0 38500 .0 .000 .000 .000 .000 113.0 .0 .0 .0 .00 .000 .0 o . . GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 1D-1IL2PB1.xtf 150 ConocoPhillips Alaska, I 1D-1IL2PB1 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 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: 36 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 6 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 ------- 24 Total Data Records: 108 . . Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 11021.000000 11990.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 190 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .004 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!! !!!!!!!!!!!!!!!! Extract File: FILE013.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 4 log header data for each bit run in separate files. 7 .2500 START DEPTH 11990.0 STOP DEPTH 12091. 0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 14-NOV-04 ADVANTAGE 3 CTK MEMORY 12091. 0 11990.0 12091. 0 o 96.5 96.5 # TOOL STRING (TOP TO VENDOR TOOL CODE MPR GRAM DIR $ BOTTOM) TOOL TYPE MULT. PROP. GAMMA RAY DIRECTIONAL RESIST. TOOL NUMBER 10023579 10079134 10079128 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.125 10946.0 # BOREHOLE CONDITIONS MUD TYPE: Flo-Pro . . MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 8.7 .0 .0 25000 .0 .000 .000 .000 .000 113.0 .0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 7 (MWD Run 7) . GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 1D-11L2PB1.xtf 150 ConocoPhillips Alaska, I 1D-1IL2PB1 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 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: 36 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 6 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 ------- 24 Total Data Records: 12 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 11990.000000 12091.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 5 94 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 06/12/06 01 **** REEL TRAILER **** LDWG 06/12/07 AWS 01 Tape Subfile: 6 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes . **** REEL HEADER **** LDWG 06/11/06 AWS 01 **** TAPE HEADER **** LDWG 06/11/06 01 *** LIS COMMENT RECORD *** . !!!!!!!!!! !!!!!! !!! LDWG File Version 1.0DO !! !!!!!!! !!!!!!!!!! Extract File: LISTAPE.HED TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 5 Z. AHMED G. GOODRICH MWD RUN 9 9 E. AGUIRRE G. GOODRICH # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING ~l8 UTe.. Ç)öL/ - ~ t1- l-Id'I'1- 1D-11L2 500292294661 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 06-NOV-06 MWD RUN 6 6 D. BARBA G. SARBER MWD RUN 10 10 D. BARBA G. GOODRICH MWD RUN 8 8 T. STURDIVANT G. SARBER 23 11N 10E 105.50 00.00 00.00 OPEN HOLE CASING BIT SIZE (IN) SIZE (IN) 16.000 9.625 DRILLERS DEPTH (FT) 115.0 6814.0 . . 3RD STRING 4TH STRING PRODUCTION STRING 7.000 4.500 10564.0 11234.0 13750.0 4.125 # REMARKS: PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 17' 55.565" LONG: W149 DEG 30' 36.425" LOG MEASURED FROM K.B. AT 105.5 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data are real time data. (4) Baker Hughes INTEQ utilized Coiltrak downhole tools and the Advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, a Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (inner and outer downhole pressure, downhole weight on bit, and vibration stick-slip), a Gamma and Directional Sub, and Hydraulic Orienting Sub with a near bit inclination sensor. (6) Data presented here is final and was not depth adjusted to a PDC (Primary Depth Control) log. The INTEQ Gamma Ray is the PDC for well 1D-11L2. (7) The sidetrack was drilled from 1D-11 through a milled window in 4.5" liner. Top of window 10938.6 ft. MD (6457.8 ft. SSTVD) Bottom of window 10946.0 ft. MD (6481.8 ft. SSTVD) (8) The interval from 13718 ft. to 13750 ft. MD (6522.7 ft. to 6524.9 ft. SSTVD)was not logged due to bit to sensor offset. (9) Tied to 1D-11 at 10907 ft. MD (6440.8 ft. SSTVD). (10) The well 1D-11L2 was kicked off from the well 1D- 11L2PB1 at 11915 ft. MD (6466 ft. SSTVD). $ Tape Subfile: 1 84 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 . . 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!! !!!!!!!!! Extract File: FILEOOl.HED FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 10946.0 STOP DEPTH 13750.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ BIT RUN NO 5 6 8 9 10 MERGE TOP 10946.0 11021.0 11871. 0 11926.0 13417.0 MERGE BASE 11021.0 11871. 0 11926.0 13417.0 13750.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT ID-IIL2 5.xtf 150 conocoPhillips Alaska, Inc. ID-11L2 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 ROP ROP ROPA 0.0 . . * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 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: 36 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 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPS MWD 68 1 OHMM 4 4 4 RAD MWD 68 1 OHMM 4 4 5 RAS MWD 68 1 OHMM 4 4 6 ROP MWD 68 1 FPHR 4 4 ------- 24 Total Data Records: 156 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 10946.000000 13749.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 200 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! LDWG File Version 1.000 Extract File: FILEOll.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: 2 log header data for each bit run in separate files. 5 .2500 . # FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 10946.0 $ STOP DEPTH 11021. 0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE MPR GRAM DIR $ BOTTOM) TOOL TYPE MULT. PROP. RESIST. GAMMA RAY DIRECTIONAL # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . 11-NOV-04 ADVANTAGE 3 CTK MEMORY 11060.0 10946.0 11021. 0 o 57.8 79.8 TOOL NUMBER 10023579 10079134 10079128 4.125 10946.0 Flo-Pro 8.70 .0 .0 28500 .0 .000 .000 .000 .000 100.0 .0 .0 .0 .00 .000 .0 o BIT RUN 5 (MWD Run 5) . GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: # *** INFORMATION TABLE: CONS . . MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT ID-11L2.xtf 150 ConocoPhillips Alaska, I ID-l1L2 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN D IMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 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: 36 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 6 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 ------- 24 Total Data Records: 9 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 10946.000000 11021.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 91 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes . **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!! !!!!!!! LDWG File Version 1.000 !!!!!!!!!! !!!!!!!!! Extract File: FILE012.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 3 . log header data for each bit run in separate files. 6 .2500 START DEPTH 11021. 0 STOP DEPTH 11871. 0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE MPR GRAM DIR $ BOTTOM) TOOL TYPE MULT. PROP. GAMMA RAY DIRECTIONAL RESIST. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL 12-NOV-04 ADVANTAGE 3 CTK MEMORY 11900.0 11021.0 11871. 0 o 57.1 97.4 TOOL NUMBER 10023579 10079134 10079128 4.125 10946.0 Flo-pro 8.70 .0 .0 38500 .0 .000 .000 .000 .000 113.0 .0 .0 .0 . . MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 6 (MWD Run 6). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT ID-IIL2.xtf 150 ConocoPhillips Alaska, I ID-llL2 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 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: 36 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 6 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAP I 4 4 . 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 ------- 24 Total Data Records: 95 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 11021.000000 11871.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 177 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .004 1024 *** LIS COMMENT RECORD *** !!!!!!!!!! !!!!!!!!! LDWG File Version 1.000 !!!!!!!!! !!!!!!!!!! Extract File: FILE013.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 4 . log header data for each bit run in separate files. 8 .2500 START DEPTH 11871. 0 STOP DEPTH 11926.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MPR MULT. PROP. RESIST. 14-NOV-04 ADVANTAGE 3 CTK MEMORY 11955.0 11871.0 11926.0 o 88.2 89.1 TOOL NUMBER 10023579 . GRAM DIR $ GAMMA RAY DIRECTIONAL # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . 10079134 10079128 4.125 10946.0 Flo-Pro 8.75 .0 .0 26000 .0 .000 .000 .000 .000 109.0 .0 .0 .0 .00 .000 .0 o BIT RUN 8 (MWD Run 8). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT ID-IIL2.xtf 150 ConocoPhillips Alaska, I ID-IIL2 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) . . Data record type is: 0 Datum Frame Size is: 28 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: 36 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 6 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 ------- 24 Total Data Records: 7 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 11871.000000 11926.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 5 89 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .005 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! LDWG File Version 1.000 Extract File: FILE014.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # 5 log header data for each bit run in separate files. 9 .2500 MNEM . FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 11926.0 $ STOP DEPTH 13417.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE MPR GRAM DIR $ BOTTOM) TOOL TYPE MULT. PROP. GAMMA RAY DIRECTIONAL RESIST. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . 17-NOV-04 ADVANTAGE 3 CTK MEMORY 13449.0 11926.0 13417.0 o 83.3 92.8 TOOL NUMBER 10023579 10079134 10079128 4.125 10946.0 Flo-Pro 8.70 .0 .0 28600 .0 .000 .000 .000 .000 115.0 .0 .0 .0 .00 .000 .0 o BIT RUN 9 (MWD Run 9). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: # *** INFORMATION TABLE: CONS VALU . . -------------------------------- WDFN LCC CN WN FN COUN STAT ID-IIL2.xtf 150 ConocoPhillips Alaska, I ID-11L2 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 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: 36 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 6 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 ------- 24 Total Data Records: 166 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 11926.000000 13417.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 6 248 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes . **** FILE HEADER **** LDWG .006 1024 *** LIS COMMENT RECORD *** ! !!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!! !!!!!!!!!!!!!!!! Extract File: FILEOI5.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 6 . log header data for each bit run in separate files. 10 .2500 START DEPTH 13417.0 STOP DEPTH 13750.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE MPR GRAM DIR $ BOTTOM) TOOL TYPE MULT. PROP. GAMMA RAY DIRECTIONAL RESIST. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: 19-NOV-04 ADVANTAGE 3 CTK MEMORY 13750.0 13417.0 13750.0 o 85.7 88.7 TOOL NUMBER 10023579 10079134 10079128 4.125 10946.0 Flo-Pro 8.70 .0 .0 27800 .0 .000 .000 .000 .000 115.0 .0 .0 .0 . . MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 10 (MWD Run 10). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT ID-IIL2.xtf 150 ConocoPhillips Alaska, I ID-llL2 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 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: 36 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 6 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 . . 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 ------- 24 Total Data Records: 37 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 13417.000000 13748.750000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 7 119 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 06/11/06 01 **** REEL TRAILER **** LDWG 06/11/06 AWS 01 Tape Subfile: 8 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes . **** REEL HEADER **** LDWG 06/11/07 AWS 01 **** TAPE HEADER **** LDWG 07/11/06 01 *** LIS COMMENT RECORD *** . !!!! !!!! !!!!!!!!!!! LDWG File Version 1.000 !!!!!! !!!!!!!!!!!!! Extract File: LISTAPE.HED TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 5 Z. AHMED G. GOODRICH # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 2ND STRING 3RD STRING 4TH STRING PRODUCTION STRING 4.125 # 'dld U Ie. SOL! - ~ tf I'-{Ji..tf¡ 1D-IIL2PBl 500292294680 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 07-NOV-06 MWD RUN 6 6 D. BARBA G. SARBER 23 llN IDE 105.50 00.00 00.00 CASING SIZE (IN) 16.000 9.625 7.000 4.500 MWD RUN 7 7 T. STURDIVANT G. GOODRICH DRILLERS DEPTH (FT) 115.0 6814.0 10564.0 10946.0 10946.0 . . REMARKS: PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 17' 55.565" LONG: W149 DEG 30' 36.425" LOG MEASURED FROM K.B. AT 105.5 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data are real time data. (4) Baker Hughes INTEQ utilized Coiltrak downhole tools and the Advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, a Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (inner and outer downhole pressure, downhole weight on bit, and vibration stick-slip), a Gamma and Directional Sub, and Hydraulic Orienting Sub with a near bit inclination sensor. (6) Data presented here is final and was not depth adjusted to a PDC (Primary Depth Control) log. The INTEQ Gamma Ray is the PDC for well 1D-11L2PB1. (7) The sidetrack was drilled from 1D-11 through a milled window in 4.5" liner. Top of window 10938.6 ft. MD (6457.8 ft. SSTVD) Bottom of window 10946.0 ft. MD (6481.8 ft. SSTVD) (8) The interval from 12049 ft. to 12091 ft. MD (6451.8 ft. to 6447.0 ft. SSTVD)was not logged due to bit (9) $ to sensor offset. Tied to 1D-11 at 10907 ft. MD (6440.8 ft. SSTVD). Tape Subfile: 1 77 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** · . !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILEOOl.HED FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 10946.0 STOP DEPTH 12091. 0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 5 6 7 MERGE TOP 10946.0 11021. 0 11990.0 MERGE BASE 11021.0 11990.0 12091. 0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT ID-IIL2PBI 5.xtf 150 ConocoPhillips Alaska, Inc. ID-l1L2PBI Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 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: 36 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 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPS MWD 68 1 OHMM 4 4 4 RAD MWD 68 1 OHMM 4 4 5 RAS MWD 68 1 OHMM 4 4 6 ROP MWD 68 1 FPHR 4 4 ------- 24 Total Data Records: 64 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 10946.000000 12090.500000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 106 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!! !!!!!!!!! LDWG File Version 1.000 !!!!!!!!!! !!!!!!!!! Extract File: FILE011.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 log header data for each bit run in separate files. 5 .2500 START DEPTH 10946.0 STOP DEPTH 11021. 0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: 11-NOV-04 ADVANTAGE . DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE MPR GRAM DIR $ BOTTOM) TOOL TYPE MULT. PROP. GAMMA RAY DIRECTIONAL RESIST. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . 3 CTK MEMORY 11060.0 10946.0 11021. 0 o 57.8 79.8 TOOL NUMBER 10023579 10079134 10079128 4.125 10946.0 Flo-Pro 8.70 .0 .0 28500 .0 .000 .000 .000 .000 100.0 .0 .0 .0 .00 .000 .0 o BIT RUN 5 (MWD Run 5) . GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT ID-IIL2PBI.xtf 150 ConocoPhillips Alaska, I ID-11L2PBl Kuparuk River North Slope Alaska . . *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 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: 36 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 6 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 ------- 24 Total Data Records: 9 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 10946.000000 11021.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 91 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 · . *** LIS COMMENT RECORD *** !!!!!!!!! !!!!!!!!!! LDWG File Version 1.000 !!! !!!! !!!!!!!!!!!! Extract File: FILE012.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 3 log header data for each bit run in separate files. 6 .2500 START DEPTH 11021. 0 STOP DEPTH 11990.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE MPR GRAM DIR $ BOTTOM) TOOL TYPE MULT. PROP. GAMMA RAY DIRECTIONAL RESIST. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: . MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: BIT RUN 6 (MWD Run 6). GR/MPR. CURVE GLOSSARY: 12-NOV-04 ADVANTAGE 3 CTK MEMORY 12029.0 11021. 0 11990.0 o 57.1 97.4 TOOL NUMBER 10023579 10079134 10079128 4.125 10946.0 Flo-pro 8.70 .0 .0 38500 .0 .000 .000 .000 .000 113.0 .0 .0 .0 .00 .000 .0 o . . GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 1D-llL2PB1.xtf 150 ConocoPhillips Alaska, I 1D-llL2PB1 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 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: 36 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 6 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 ------- 24 Total Data Records: 108 . . Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 11021.000000 11990.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 190 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .004 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!! !!!!!!!!!! Extract File: FILEOI3.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 4 log header data for each bit run in separate files. 7 .2500 START DEPTH 11990.0 STOP DEPTH 12091. 0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 14-NOV-04 ADVANTAGE 3 CTK MEMORY 12091. 0 11990.0 12091. 0 o 96.5 96.5 # TOOL STRING (TOP TO VENDOR TOOL CODE MPR GRAM DIR $ BOTTOM) TOOL TYPE MULT. PROP. GAMMA RAY DIRECTIONAL RESIST. TOOL NUMBER 10023579 10079134 10079128 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.125 10946.0 # BOREHOLE CONDITIONS MUD TYPE: Flo-Pro . . MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 8.7 .0 .0 25000 .0 .000 .000 .000 .000 113.0 .0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 7 (MWD Run 7) . GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT ID-IIL2PBl.xtf 150 ConocoPhillips Alaska, I ID-11L2PBl Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 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: 36 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 6 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 ------- 24 Total Data Records: 12 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 11990.000000 12090.250000 0.250000 teet **** FILE TRAILER **** Tape Subtile: 5 94 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 07/11/06 01 **** REEL TRAILER **** LDWG 06/11/07 AWS 01 Tape Subtile: 6 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes
