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Home My WebLink About199-072 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 1D-07 50-029-20430-00 179112_1D-07_SCMT_14Oct23 1D-11 50-029-22946-00 199072_1D-11_IPROF_04Apr2022 1D-117 50-029-22844-00 197237_1D-117_RBP_10Jun2022 1D-135 50-029-22816-00 197184_1D-135_LDL_05Jun2022 1D-30 50-029-22965-00 2000104_1D-30_Plug_11May2023 1D-34 50-029-22975-00 200143_1D-34_CHC_02Aug2022 1D-36 50-029-22973-00 200130_1D-36_RBP_19Jul2023 _1E-02 50-029-20472-00 180050_1E-02_CHC_29Mar2023 180050_1E-02_RBP_24Mar2023 _1E-102 50-029-23236-00 204231_1E-102_Pres-Temp_29Jul2023 _1E-12L1 50-029-20736-60 210004_1E-12_JetCutter_12Jun2022 210004_1E-12_MechCutter_06Jun2022 210004_1E-12_SBHPS-RBP-LDL_03Jun2022 2of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38317 T38318 T38321 T38322 T38323 T38324 T38325 T38326 T38327 T38328 2/29/2024 1D-11 50-029-22946-00 199072_1D-11_IPROF_04Apr2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:18:42 -09'00' 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. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1D-11 (PTD 199-072) Update and monitor extension Date:Wednesday, July 12, 2023 2:27:07 PM From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Wednesday, July 12, 2023 11:42 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: KRU 1D-11 (PTD 199-072) Update and monitor extension Chris— An update on the monitoring of KRU 1D-11 (PTD 199-072). Since it has been back on injection, the IA pressure behavior appears normal. Our intent is to return the well to normal injection status and monitor it through our routine processes of injection surveillance. Please let me know if you have any questions or disagree with the plan. Thanks, Travis (filling in for Jan Byrne) From: Byrne, Jan Sent: Wednesday, March 29, 2023 7:16 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1D-11 (PTD 199-072) Update and monitor extension Chris, KRU 1D-11 (PTD 199-072) was reported on 2/28/23 for suspect IA pressure fall off. Subsequent the report DHD performed a passing MITIA and pack off tests after which the IA pressure was elevated for the monitor period. There has been some pressure fluctuation, but overall the IA pressure has stabilized and does not appear to be decreasing. CPAI intends to extend the monitor period an additional 60 days to verify that the IA pressure remains stable. A TIO trend and 10-426 are attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 265-6471 Cell phone: (808) 345-6886 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. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1D-11 (PTD 199-072) Update and monitor extension Date:Thursday, March 30, 2023 8:06:34 AM Attachments:AnnComm Surveillance TIO for 1D-11.pdf MIT KRU 1D-11 diagnostic MITIA 3-1-23.xlsx From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Wednesday, March 29, 2023 7:16 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1D-11 (PTD 199-072) Update and monitor extension Chris, KRU 1D-11 (PTD 199-072) was reported on 2/28/23 for suspect IA pressure fall off. Subsequent the report DHD performed a passing MITIA and pack off tests after which the IA pressure was elevated for the monitor period. There has been some pressure fluctuation, but overall the IA pressure has stabilized and does not appear to be decreasing. CPAI intends to extend the monitor period an additional 60 days to verify that the IA pressure remains stable. A TIO trend and 10-426 are attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 265-6471 Cell phone: (808) 345-6886 1D-11 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 1D-11 2023-01-20 210 506 296 IA 1D-11 2023-02-22 139 762 623 IA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: 10,962.0 7/26/2005 1D-11 n1894 Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set DH Choke & Slip Stop 3/2/2021 1D-11 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 35.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (lb… 62.58 Grade H-40 Top Connection WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.70 Top (ftKB) 34.7 Set Depth (ftKB) 6,814.5 Set Depth (TVD) … 4,403.6 Wt/Len (lb… 40.00 Grade L-80 Top Connection BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 30.4 Set Depth (ftKB) 10,564.6 Set Depth (TVD) … 6,362.5 Wt/Len (lb… 26.00 Grade L-80 Top Connection BTC Casing Description WINDOW L2 OD (in) 5 1/2 ID (in) 4.00 Top (ftKB) 10,925.0 Set Depth (ftKB) 10,935.0 Set Depth (TVD) … 6,561.6 Wt/Len (lb…Grade Top Connection Casing Description WINDOW L1 OD (in) 5 1/2 ID (in) 4.00 Top (ftKB) 11,011.0 Set Depth (ftKB) 11,021.0 Set Depth (TVD) … 6,608.8 Wt/Len (lb…Grade Top Connection Casing Description LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 10,401.4 Set Depth (ftKB) 11,234.0 Set Depth (TVD) …Wt/Len (lb… 2.00 Grade L-80 Top Connection IBT Liner Details: excludes liner, pup, joints, casing, sub , shoe , float... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 10,401.4 6,277.4 58.80 PACKER BAKER SLZXP LINER TOP PACKER / HANGER / PBR 4.790 Tubing Strings: string max indicates LONGEST segment of string Tubing Description TUBING String … 4 1/2 ID (in) 3.96 Top (ftKB) 28.7 Set Depth (ft… 10,420.0 Set Depth (TVD… 6,287.1 Wt (lb/ft) 12.60 Grade L-80 Top Connection ABT MOD Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model 28.7 28.7 0.11 HANGER 4.500 10.850 541.4 541.1 5.66 NIPPLE 3.813 6.062 10,353.0 6,252.3 58.64 GAS LIFT 3.650 5.800 CAMCO KBG-2-LS 10,397.3 6,275.3 58.81 NIPPLE 3.813 5.200 10,406.3 6,280.0 58.78 LOCATOR 3.000 5.125 10,407.5 6,280.6 58.78 SEAL ASSY 3.875 4.750 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 539.9 539.6 5.61 SLIP STOP 4.5" SLIP STOP (20" OAL) 4/6/2022 1.750 541.4 541.1 5.66 CHOKE 3.83" NO-GO SUB WITH 1/2" CHOKE (G- FISH NECK) 27" OAL 4/6/2022 0.250 Mandrel Inserts : excludes pulled inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 10,353.0 6,252.3 58.64 1 Gas Lift DMY BTM 0.000 0.0 7/23/2018 High Seal Packi ng 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 Notes: General & Safety End Date Annotation 1/8/2009 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 11/22/2004 NOTE: MULTI-LATERAL WELL: MAIN LEG, PRODUCING THRU 1D-11 PERFS ABOVE L1 & L2 WINDOWS 1D-11, 4/7/2022 9:16:57 AM 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 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 SEAL ASSY; 10,407.5 LOCATOR; 10,406.3 NIPPLE; 10,397.3 GAS LIFT; 10,353.0 SURFACE; 34.7-6,814.5 CHOKE; 541.4 NIPPLE; 541.4 SLIP STOP; 539.9 CONDUCTOR; 35.0-115.0 HANGER; 28.7 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 Operations shutdownPull TubingFracture StimulatePlug PerforationsSusp Well Insp1. Operations Change Approved ProgramAlter CasingOther StimulatePerforateInstall WhipstockPerformed: Other: Marcit Conformance TrtmntCoiled Tubing OpsRepair WellPerforate New PoolMod Artificial Lift ExploratoryDevelopment 6. API Number:ServiceStratigraphic 8. Well Name and Number:7. Property Designation (Lease Number): 10. Field/Pool(s):9. Logs (List logs and submit electronic data per 20AAC25.071): 11. Present Well Condition Summary: measuredTotal Depth feet None feet feetNonefeettrue vertical Effective Depth measured feet 10401', 10954', 11017'feet feet6277', 6572', 6607'feettrue vertical Measured depthPerforation depth True Vertical depth 6287' TVD10420' MDL-804-1/2"Tubing (size, grade, measured and true vertical depth) 10401' MD, 10954' MD 11017' MDPackers and SSSV (type, measured and true vertical depth) N/A 6277' TVD, 6572' TVD 6607' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/ATreatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: StratigraphicServiceExploratory DevelopmentDaily Report of Well Operations WDSPLGasOil16. Well Status after work:Copies of Logs and Surveys Run GSTOR SPLUGSUSPGINJElectronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: Authorized Name and Contact Name:Digital Signature with Date: Contact Email: Contact Phone:Authorized Title: 4404'6814' CollapseBurst Production Liner 10534' Casing 6362' 4-1/2" 10565' 11234' 6780' 115'Conductor Surface Intermediate 16" 9-5/8" 80' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 199-072 50-029-22946-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0028243 Kuparuk River Field/ Kuparuk River Oil Pool KRU 1D-11 Plugs measuredJunk Length measured true vertical Packer Representative Daily Average Production or Injection Data Tubing PressureCasing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 115' ~~~ ~INJECTOR ~ ~ N/A Sr Res Eng:Sr Pet Geo:Sr Pet 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 Packer: TIW KS-WS Packer Packer: Baker KB LTP SSSV: None Allen Eschete allen.eschete@conocophillips.com (907) 265-6558Interventions Engineer 10907-10927' (Blocked Perfs: 10960-10980', 11031-11041', 11065-11085') 6546-6557' (Blocked perfs: 6575-6586', 6614-6620', 6633-6644') Submit in PDF format to aogcc.permitting@alaska.govDue Within 30 days of OperationsForm 10-404 Revised 10/2022 Kuparuk River Oil Pool 11234' 6727' 11234' 6727' 6727' By Grace Christianson at 2:54 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 10:56:22-08'00' 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 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1990720 Type Inj W Tubing 1945 1945 1945 1945 Type Test P Packer TVD 6281 BBL Pump 3.3 IA 675 3000 2985 2985 Interval O Test psi 3000 BBL Return OA 130 150 150 150 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 1D Pad VanCamp 03/01/23 Notes:Diagnostic MITIA Notes: 1D-11 Notes: Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)MIT KRU 1D-11 diagnostic MITIA 3-1-23 (002) 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. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1D-11 (PTD 199-072) Report of suspect IA pressure fall off Date:Tuesday, February 28, 2023 10:56:00 AM Attachments:AnnComm Surveillance TIO for 1D-11.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Tuesday, February 28, 2023 10:47 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1D-11 (PTD 199-072) Report of suspect IA pressure fall off Chris, KRU 1D-11 (PTD 199-072) is exhibiting suspect IA pressure fall off. Operations has recently pressured the IA up a couple times, but the IA pressure has exhibited a slow fall off. DHD will be mobilized to perform initial testing to include an MITIA, pack off tests and adjust the IA pressure for a 30 day monitor. Any required paperwork for continued injection or corrective action will be submitted once a plan forward has been determined. A 90 day TIO trend and wellbore schematic are attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 1D-11 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 1D-11 2023-01-20 210 506 296 IA 1D-11 2023-02-22 139 762 623 IA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: 10,962.0 7/26/2005 1D-11 n1894 Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set DH Choke & Slip Stop 3/2/2021 1D-11 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 35.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (lb… 62.58 Grade H-40 Top Connection WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.70 Top (ftKB) 34.7 Set Depth (ftKB) 6,814.5 Set Depth (TVD) … 4,403.6 Wt/Len (lb… 40.00 Grade L-80 Top Connection BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 30.4 Set Depth (ftKB) 10,564.6 Set Depth (TVD) … 6,362.5 Wt/Len (lb… 26.00 Grade L-80 Top Connection BTC Casing Description WINDOW L2 OD (in) 5 1/2 ID (in) 4.00 Top (ftKB) 10,925.0 Set Depth (ftKB) 10,935.0 Set Depth (TVD) … 6,561.6 Wt/Len (lb…Grade Top Connection Casing Description WINDOW L1 OD (in) 5 1/2 ID (in) 4.00 Top (ftKB) 11,011.0 Set Depth (ftKB) 11,021.0 Set Depth (TVD) … 6,608.8 Wt/Len (lb…Grade Top Connection Casing Description LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 10,401.4 Set Depth (ftKB) 11,234.0 Set Depth (TVD) …Wt/Len (lb… 2.00 Grade L-80 Top Connection IBT Liner Details: excludes liner, pup, joints, casing, sub , shoe , float... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 10,401.4 6,277.4 58.80 PACKER BAKER SLZXP LINER TOP PACKER / HANGER / PBR 4.790 Tubing Strings: string max indicates LONGEST segment of string Tubing Description TUBING String … 4 1/2 ID (in) 3.96 Top (ftKB) 28.7 Set Depth (ft… 10,420.0 Set Depth (TVD… 6,287.1 Wt (lb/ft) 12.60 Grade L-80 Top Connection ABT MOD Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model 28.7 28.7 0.11 HANGER 4.500 10.850 541.4 541.1 5.66 NIPPLE 3.813 6.062 10,353.0 6,252.3 58.64 GAS LIFT 3.650 5.800 CAMCO KBG-2-LS 10,397.3 6,275.3 58.81 NIPPLE 3.813 5.200 10,406.3 6,280.0 58.78 LOCATOR 3.000 5.125 10,407.5 6,280.6 58.78 SEAL ASSY 3.875 4.750 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 539.9 539.6 5.61 SLIP STOP 4.5" SLIP STOP (20" OAL) 4/6/2022 1.750 541.4 541.1 5.66 CHOKE 3.83" NO-GO SUB WITH 1/2" CHOKE (G- FISH NECK) 27" OAL 4/6/2022 0.250 Mandrel Inserts : excludes pulled inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 10,353.0 6,252.3 58.64 1 Gas Lift DMY BTM 0.000 0.0 7/23/2018 High Seal Packi ng 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 Notes: General & Safety End Date Annotation 1/8/2009 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 11/22/2004 NOTE: MULTI-LATERAL WELL: MAIN LEG, PRODUCING THRU 1D-11 PERFS ABOVE L1 & L2 WINDOWS 1D-11, 4/7/2022 9:16:57 AM 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 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 SEAL ASSY; 10,407.5 LOCATOR; 10,406.3 NIPPLE; 10,397.3 GAS LIFT; 10,353.0 SURFACE; 34.7-6,814.5 CHOKE; 541.4 NIPPLE; 541.4 SLIP STOP; 539.9 CONDUCTOR; 35.0-115.0 HANGER; 28.7 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 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 22, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1D-11 KUPARUK RIV UNIT 1D-11 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2022 1D-11 50-029-22946-00-00 199-072-0 G SPT 6281 1990720 1570 3270 3260 3250 3250 250 300 295 295 4YRTST P Guy Cook 7/10/2022 Testing completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1D-11 Inspection Date: Tubing OA Packer Depth 720 1975 1960 1960IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC220709074016 BBL Pumped:1.3 BBL Returned:1.3 Friday, July 22, 2022 Page 1 of 1 9 9 9 9 9 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.07.22 16:20:00 -08'00' 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 • Mck I 0—/ Regg, James B (DOA) PT l�7 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 and 204 -212)) was returned to service today 01/08/2012 after the well was swapped to MI. The wellhead injection pressure did not stabilize 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 659 -7493 pager 659 -7000 765 • • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, November 21, 2011 8:53 AM To: 'CPF1 Prod Engr' Cc: NSK Prod Engr & Optimization Supv; NSK Prod Engr Specialist; CPF1 DS Lead Techs; CPF1 Ops Supv Subject: RE: 1D-11 (PTD #199 -072) request for waiver Daniel, et al, Check out this link. It appears that a "general" administrative approval is in place for this situation in the Kuparuk River Oil Pool. http : / /doa_alaska.gov /ogc %orders /co /co400 499/co4_.32d -9.pdf Call or message with any questions. Tom Maunder, PE AOGCC From: CPF1 Prod Engr [mailto:n1269 @conocophillips.com] Sent: Sunday, November 20, 2011 4:02 PM To: Maunder, Thomas E (DOA) Cc: NSK Prod Engr & Optimization Supv; NSK Prod Engr Specialist; CPF1 DS Lead Techs; CPF1 Ops Supv Subject: 1D -11 (PTD #199 -072) request for waiver Tom, ConocoPhillips requests administrative approval under CO 432D to operate a Kuparuk water injection well with a defeated safety valve system. This request is similar to CO 406B administrative approval granted to the West Sak Pool. The LPP for dual - lateral injection well 1D-11 (PTD 4 1 & 204 -212) has been defeated due to low injection pressure as the well has been SI since 9/18/2011. During shut -in time, offset producers (high rate multi - laterals) remained online. We expect this fill -up period to be relatively short with injection pressure increasing above 700 psig within the next two weeks. This will allow us to re- engage the SVS system and return the well to normal operating conditions. This event is an anomaly within Kuparuk. The last event was when 1 D -03 was converted to injection service in July 2010. The well is currently injecting 7760 bwpd at 517 psig. I propose to keep you updated with rates and pressures. Thank you for your reply, Daniel Bearden /David Lagerlef CPF1 Production Engineers n1269 @conocophillips.com 907 - 659 -7493 $V." t. P i pager 907 - 659 -7000 #765 11/21/2011 • • lf IrE 1 :3 n SEAN PARNELL, GOVERNOR �r ALASKA OIL A11TI) GAS 333 W. 7th AVENUE. SUITE 100 CONSERVATION COMMISSION ANCHORAGE. ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL NO, CO 432D.009 Mr. Gary Targac Kuparuk Production Engineering & Optimization Supervisor ConocoPhillips Alaska P.O. Box 100360 Anchorage, AK 99510 -0360 RE: Conservation Order 432D Kuparuk River Field Kuparuk River Unit Kuparuk River Oil Pool Defeating Low Pressure Pilots on Water Injection Wells with Low Tubing Pressure Dear Mr. Targac: By electronic message dated October 12, 2010, ConocoPhillips Alaska ("CPA") requested approval to disable automatic shut -in equipment on Kuparuk River Unit (KRU) water injection well 1E -09 (1820280) due to surface pressure below the automatic shut -in equipment activation set point. Due to similar low surface pressure situations experienced with water injection wells in the shallower West Sak Oil Pool, on June 14, 2005 the Commission issued CO 406B.001 allowing relief similar to this request. While CPA specifically requested this approval for 1E -09, this is the second Kuparuk Pool water injection well that has experienced low surface pressure when placed in service. Since it is probable that additional wells may also need this relief, it is appropriate to consider your request as an Administrative Approval under Rule 12 of CO 432D. CO 432D Rule 5 (a) prescribes that "Each well shall be equipped with a Commission approved fail -safe automatic surface safety valve system (SVS)..." Rule 5 (b) requires that "The safety valve system (SVS) shall not be deactivated except during repairs, while engaged in active well work, or if the pad is manned." CPA recently initiated injection in newly completed multi - lateral well 1E -15A (2100130) that had been producing for a few months as well as 1E-09 which had not been active since February 2001. In both situations, the reservoir bottomhole pressure (BHP) had become reduced in the vicinity of the wellbore. With locally reduced BHP, when injection is started the surface pressure can be insufficient for the pressure sensor • • CO 432D.009 November 2, 2010 Page 2 of 3 controlling the SSV to function properly. To prevent the SVS from repeatedly functioning and shutting in the well, the pressure sensor (low - pressure pilot) must be defeated (prevented from functioning). CPA is requesting approval to defeat a given water injection well's low pressure pilot until the operating injection surface pressure reaches 700 psi. A localized reduction in BHP resulting from production from a specific well or from adjacent wells in the reservoir is not unusual. After water injection has been in operation for a while, the local BHP should increase giving sufficient surface pressure to allow the low- pressure pilot to operate properly. A check valve remains functional at all times to prevent flow from the well if the flowline were to be damaged. Granting CPA's request will not increase the risk to any fresh water since all aquifers have been exempted by EPA per 40 CFR 147.102 (b)(3). Now therefore, as provided by Rule 12 of CO No. 432D, it is ORDERED that Rule 5 (b) be amended to read as follows: b. The safety valve system (SVS) shall not be deactivated except during repairs, while engaged in active well work, or if the pad is manned. However, the Low Pressure Pilot may be defeated on Kuparuk Pool water injection wells when the surface injection pressure is less than 700 psi. Low pressure pilots on Kuparuk Pool water injection wells must be operable when the surface pressure exceeds 700 psi. The operator will notify the Commission via electronic mail when a specific well's Low Pressure Pilot is defeated and again when the pilot function is returned to normal If the SVS on a development well cannot be returned to service within 24 hours, the well must be shut in at the wellhead and at the manifold building. (Source CO 348 and C0432D.009) 1) Wells with a deactivated SVS shall be identified by a sign on the wellhead stating that the SVS has been deactivated and the date it was deactivated. (Source CO 348) 2) A list of wells with the SVS deactivated, the dates and reasons for deactivating, and the estimated re- activation dates must be maintained current and available for Commission inspection on request. (Sour - CO 348) . � •o,/ DONE at Anchorage, Alaska an• • _ . o tuber 2, 2010. te. 4,4 r •• pi a7 .f t v /9),,t aniel T. S - ount J* ', . ' 'Jr Cathy / Foerster Chair, C I issioner Comm loner Commissioner • CO 432D.009 November 2, 2010 Page 3 of 3 RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05,0110(a), within 20 clays alter written notice of the entry of this order or decision, or such further lime as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. lithe notice was mailed, then the period of time shall be 23 days, An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration , this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b). "[title questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period. the Iasi day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 23, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 1D-11 Run Date: 8/6/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1D -11 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50 -029- 22946 -00 Injection Profile Log 1 Color Log 50- 029 - 22946 -00 ; t': PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: oZ ' aJ t j Signed: &L Ctel MEMORANDUM TO: Jim Regg '~7 I P.I. Supervisor ~~~ 71 Z~ I { FROM: BOb Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Thursday, July 22, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC ID-11 KUPARUK RIV iJNIT ID-11 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~- Comm Well Name: KUPARUK RIV UNIT 1D-l i Insp Num: mitRCN100718153839 Rel Insp Num: API Well Number: 50-029-22946-00-00 Permit Number: 199-072-0 Inspector Name: Bob Noble Inspection Date: 7/16/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1Dal ~ Type Inj. N TVD 6281 ~' IA 824 2612 2571 2566 P.T.D 1990720- TypeTest SPT Test psi 2612 ~ OA 16 53 53 53 InterVal4YRTST per, P i Tubing 1900 1900 1900 1900 Notes: r ~i SS~` • y. Thursday, July 22, 2010 Page 1 of 1 • • ~ ~ ~ Robert Christensen Production Engineering Specialist. Greater Kuparuk Unit , NSK-69 ~ ~ ,~ ~~~~ PO Box 196105 ConocoPh ~ I I ~ ps ~ u v ~ Anchorage, f1KK 99519-6105 Phone: (907)659-7535 Alaska Q{~ ~ ~ <r ~ „)7 , s,,u`i~iii~~Sl~~c: 659-7314 Al1Cl i°J cits',-~~ November 13, 2008 ~ ti ~ ~J 1 1 `. Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commissiol~v~~`~` ~`F~. ~~ ~ 2Q~ 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 1 D 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 `~~s.>J~~L: s ~.~c~~ ~ `t ~-~~ sus ~ ~ o.~~-~~~ lZ'C~) Attachments 'y``'~c~ • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ~ : ~ D EORx Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ ,~ ^`.l~.~` 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ~F COnOCOPhIIIIpS Alaska, InC. Development ^ Exploratory ^ 199-072 1- 3. Address: Stratigraphic ^ Service^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22946-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 106' 1 D-11 8. Property Designation: 10. Field/Pool(s): ADL 028243 ~ Kuparuk River Field / Kuparuk Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 11234' feet true vertical 6727' feet Plugs (measured) Effective Depth measured 11136 feet Junk (measured) true vertical 6673 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 115' 16" 115' 115' SURFACE 6708' 9-5/8" 6814' 4403' PRODUCTION 10458' 7" 10564' 6362' PRODUCTION 833' 4-1/2" 11234' 6727' Perforation depth: Measured depth: 10907'-10927' true vertical depth: 6546'-6557' Tubing (size, grade, and measured depth) 4-1/2", L-80, 10415' MD. Packers &SSSV (type & measured depth) Packer =Baker 7 x 4-1/2" SLZXP Packer = 10409' SSSV =Nipple SS SV = 541' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-MCf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 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 N/A if C.O. Exempt: N/A contact Bob Christensen/Vacant Printed Name ob . C ensen Title Production Engineering Technician Signature - Phone: 659-7535 Date J ~ ~ ~ ®t~ Form 10-404 Revised 04/2004 v ~,,.~ ~,~~~~~ .. ~u /~ i~~ ~ Submit Origina Only ,~- l'~~~~c~` 1 D-11 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 NIP (541-542, OD:5.200) TUBING (0-10415, OD:4.500, ID:3.958) 'RODUCTION (0-10564, OD:7.000, Wt:26.00) Gas Lift IandreVDummy Valve 1 (10353-10354, OD:5.985) NIP (10397-10398, OD:5.200) CHOKE (10397-10398, OD:3.812) 'RDDUCTIDN (10401-11234, OD:4.500, PKR (1040910410, OD:4.500) Perf (10907-10927) 1 D-11 API: ----- 500292294600__ __ WeIlType_ -- - INJ An le TS: 57d 10902 SSSV Type: N_IP_P_L_E_ __ O_ rigCom Ip etion: 10/26!1999 An le TD: 56 d 11234 Annular Fluid: Last W/O: Rev Reason: Set CHOKE Reference L Ref L Date: Last U date: 3/29/2007 Last Tag: 10962'__ _ _ TD: 11234 ftKB Last Ta Date: 7/26/2005 Max Hole An le: 60 d 7659 Casin String -ALL S ___ Descri lion - - CONDUCTOR SURFACE TRINGS Size Tom Bottom TVD Wt Grade Thread - - - - 16.000 0 115 115 62.58 H-40 WELDED 9.625 0 6814 4404 40.00 L-80 BTC PRODUCTION 7.000 0 10564 6362 26.00 L-80 BTC PRODUCTION 4.500 10401 11234 11234 12.60 L-80 IBT WINDOW L2 4.500 _ __10935 10936 6562 0.00 WINDOW L1 4.500 11020 11021 6609 0.00 ubin Strln -TUBI NG Size To Bottom TVD Wt Grade Thread 4.500 0 10415 6285 12.60 L-80 IBT Pertorations Summa Interval TVD Zone Status Ft SPF Date T e Comment 10907 - 10927 6546 - 6557 C-4 20 4 11/19/1999 IPERF 2 7/8" HC, DP, 180 deg hase, +/- 90 d ,low side 10960 - 10980 6575 - 6586 C-4 20 4 11/19/1999 Blocked PERFS blocked by Lateral L1 Straddle Assembl 11031 - 11041 6614 - 6620 C-2 10 6 10/10/2004 Blocked PERFS blocked by Lateral L1 Straddle Assembl 11065 - 11085 6633 - 6644 C-1 20 6 10/10/2004 Blocked PERFS blocked by Lateral L1 Straddle Assembl Gas LiR Mandrels/Val ves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO 'Date Run Vlv Cmnt 1 10353 6252 CAMCO KBG-2-LS MOD DMY 1.0 BTM 0.000 0 9/4/2005 Other lu s, equ~., et_c.) -COMPLETION De th TVD Type Descri lion ID 541 541 NIP CAMCO DB 3.813 10397 6275 NIP OTIS X 3.812 10397 6275 CHOKE 1/2" CHOKE ON4.5" X-LOCK set 2/26/2007 0.500 10407 6280 SEAL BAKER Seal Assemb 192-47 3.875 10409 6281 PKR BAKER Packer 7 x 4.5 SLZXP acker/han er 3.875 10960 6575 Straddle Assembly STRADDLE ASSEMBLY LOCATED BETWEEN CTD L1 & L2, BLOCKING PERFS @ 10960'-10980'. REMAINING 1D-11 PERFS ABOVE L2 WINDOW PRODUCING 11/9/2004 2.370 General Not - es Date 1/22/200 Note NOTE: MULTI-LATERL WELL: MAIN LEG, PRODUCING THRU 1D-11 PERFS ABOVE L1 & L2 WINDOWS • .~~> ~~ Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 12, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~~~~~ NC~t ~ ~ 20Q7 ~,~~- Enclosed please find a spreadsheet with.a ist of wells from the I~uparuk field (KRi~e Each of these wells was found to have a void in the conductor. These voids were. filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top jobs were pumped on October 19, 2007 and the corrosion inhibitor/sealant was pumped on October 28, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or MJ Loveland at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Projects Supervisor ~1 a ~. _ ~~~' ~'~~~?I ~~3s~ ~~~ Ors . i~iP9'~$. - . sir', ...a„ • ~urfac~ Cassng by C®nduct®r Annulus ~er~ent, C®rr®saon inhmbitor, Sealant fop®off Rep®rt of Sundry Operati®ns (10-404) Kuparuk Fie6d Date 10/28/2007 Well Name PTQ # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 30-7 188-077 26' 4.2 10" 10/19/200? 3 10/28/2007 30-17 ..188-029 49'8" 7 16" .10/19/2007 5 10/28/2007 1D-11 199-072 4'1" n/a 4'1" Na 16.5 10/28/2007 ~".) .ft'i.! I· -"" , 'i~ / 03/05/07 Schlumbel'gel' NO. 4173 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 6CANNED MAR SO 2007 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite '100 Anchorage, AK 99501 1,'1) t. {-, 7mn t1f\fç () (;, U Iè..- iC¥1 - Ci~;;) Field: Kuparuk Well Job# BL Color CD Log Description Date 2G-03 11638824 INJECTION PROFILE 02/15/07 1 1R-08 11628971 INJECTION PROFILE 02/15/07 1 1 F -17 11638827 SBHP SURVEY 02/17/07 1 1 F-14 11638826 SBHP SURVEY 02/17/07 1 1 F-19 11638828 SBHP SURVEY 02/19/07 1 1C-13 11628977 SBHP SURVEY 02/19/07 1 1C-02 11628978 SBHP SURVEY 02/19/07 1 2M-02 11628979 INJECTION PROFILE 02/20/07 1 35-26 11638813 INJECTION PROFILE 01/21/07 1 1C-121 11665391 INJECTION PROFILE 02/05/07 1 1 J-180 11665390 U51T 02/06/07 1 3J-14 11638825 PROD PROFILE 02/16/07 1 1J-118 11665392 USIT 02/22/07 1 10-11 11665393 INJECTION PROFILE 02/24/07 1 2M-05 11665400 INJECTION PROFILE 03/01/07 1 2M-04 11665399 INJECTION PROFILE 03/01/07 1 1 F-13 11665401 INJECTION PROFILE 03/02/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 17<." c . . MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: DATE: Monday, July 31, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 10-11 KUPARUK RIV UNIT 10-1 I Jim Regg P.I. Supervisor ---- , 1/\ :>?¿/" 9 (,/3> 1,; iX.é -n ' FROM: John Crisp Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 10-11 Insp Num: mitJCr060730062632 ReI Insp N urn API Well Number 50-029-22946-00-00 lQq,..-o1 a-- Reviewed By: '-7'72- P.I. Suprv ,_) f:::>.' Comm Permit Number: 199-072-0 Inspector Name: John Crisp Inspection Date: 7/29/2006 Packer Depth Well 10-11 !Type Inj. I N TVD 6281 IA P.T. ¡ 1990720 ITypeTest i SPT Test psi 1570.25 OA , I Interval 4YRTST PIF P v-/ Tubing Notes 53 bbl's pumped for test. 460 1870 Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 1830 250 400 ._~ I~ lW IW .L--__----L__ c n \? \,1 Monday, July 31, 2006 1850 400 400 130 ,------------¡--------- ~---_._- Page I of I MEMORANDUM ) State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor Y ill ibie; '~í~ DATE: Tuesday, October 11,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC ID-II KUPARUK RIV UNIT ID-ll Src: Inspector (\/r Q./O \~,.\ FROM: John Spaulding Petroleum Inspector Well Name: KUPARUK RIV UNIT 10-11 Insp Num: miUS051006194213 Rei Insp N urn NON-CONFIDENTIAL API Well Number 50-029-22946-00-00 Permit Number: 199-072-0 Reviewed By: Ill, , ._ -;~ Il- P.I. Suprv '....JI32- (? t'~ Comm Inspector Name: John Spaulding Inspection Date: 10/6/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ID-II Type Inj. wi TVD 6280 IA U50 2520 2450 2420 2420 P.T. 1990720 TypeTest SPT I Test psi 1570 OA Interval INIT AL P/F P Tubing I Notes Observed IA for an initial 15 min. to confirm stabilization. Test fluid (diesel) was approx. 50 deg. F. I 1 '7 ?\}fJ~ sC$o\N~E( ~O'd Tuesday, October 11,2005 Page 1 of 1 ') / ."'?tJ 7:2 V Christensen, Robert D From: Sent: To: Subject: Allsup-Drake, Sharon K Monday, September 19, 2005 12:50 PM Christensen, Robert 0 1 0-11 RECEIVED OCT 11 Z005 Alaska Oil & Gas Cons. Commission Bob - Bob Fleckenstein called last Thursday asking about the sundry 10-404 you Mfþ8filqf).11, Apparently the daily work log didn't print out too well and he couldn't read it He requested a new copy, Can you send that to him? He also wanted the date of first injection and I gave that to him. Thanks, Sharon office phone: 263-4612 fax: 265-6224 \C\ '\' b'\ ð'" 5tANNED NOV 0 9 2005 þðb) \ tk b~(~ -'&i~( fìJ~lJ, þOI'f''tJ:ii- ~~~ s J ~ ' ,j. ~£Jìe/ eJ('f) r cJù It}¿n ~ t 11 {)<f1 t£ "rM I <6òí ~r-;$~SetA- Cp¡r:t:- ./ -- b 5'1--- t6 :56 1 Date Event Summary ) 1 D-11 DESCRIPTION OF WORK COMPLETED SUMMARY 9/9/200sICommenced Water Injection cycle ) 199!J7d.O 1 D-11 10-404 Sundry ) ) Subject: ID-11 10-404 Sundry From: CPF 1 Prod Engr <n 1269@conocophillips.com> \'. (JQ!",t/l~ Date: Wed, 21 Sep 2005 13:38:45 -0800 ',T~ '-I Tø: bob_fleckenstein@admin.state.ak.us . " " CC: N"SK Prod Engr'Tech <n1139@conocophillips.com>, "Allsup-Drake, ShElIonK" <Sharon.K.Allsup~ Drake@conocophillips.com>, ' Bob, Here is an electronic copy of the 10-404 for 1 D-11. The missing "Event Summary" page can be printed from "SUM" tab of the excel file. Let me know if you need any further information. «1D-1110-40409-13-05.xls» Mike Timmcke I Jim Stein Kuparuk CPF1 Production Engineers (907) 659-7493 1D-1110-404 Content-Description: 1D-11 10-40409-13-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 è~f;Þ~~,'~W~:;;~" (>E~) 'J) C) 2'O'D~:: ..:' \;j¡..\.~. ''Ç, 1\)~r...... ,)". ~ ((, 1...... .. J.... ,.r. 1 of 1 9/21/20052:10 PM ) ) E'''''fj'IV' ,'[""'" f¡'"'''\ I: .:, ~ ~:::I &~_~V SEP 1 5 Z005 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIONI§~I;,:,,: 1, Opera~i6ns p~!formed: Aband,qn ,0: , ," , """Aitet,ca~i,ng:O ,:,:~h~n~,~Äppr6v~q:Progran1 0 ,; 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 106' , . ~ep~ir Vy~,11 :0:, ., PU1l7U~irig . 0.'" ()Pèr~(Sh'útdownO, ,piug Perforations, [j , . ,- ", -.":.' . p~rfor,ateNeWPool 0<" p~rf()rate 0," ' A.CùrrentWeU StáfúS': ' D~vel¿pnient CI' strat¡g'~ap~jG [J &. Ga~, Con~," COI1~m¡s~¡If'i~"l] . : St,imul~te 0 ' , ()therArithD~,pil to WAG ':' 'Waiver 0 " ~.' , Time: ,Ëxt~risiòn ' 0 ' . Re-enter su'SPe,!1d~d: ~ell: :, 0, : . ..: Expl()ratory 0 , Service, 0 5. Permit to Drill Number: 199-072 1.J,Oë 1 ET 6. API Number: 50-029-22946-00 9. Well Name and Number: 1 0-11 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool Total Depth measured 11234' feet true vertical 6727' feet Plugs (measured) Effective Depth measured 11136' feet Junk (measured) true vertical 6673' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SURFACE 6708' 9-5/8" 6814' 4403' PRODUCTION 10458' 7" 10564' 6362' PROD. CASING 833' 5.5" 11234' 6727' WINDOW L2 l' 4-1/2" 1 0936' 6562' Perforation depth: Measured depth: 10907'-10927'; 10960'·10980'; 11031'·11041'; 11065'·11085' true vertical depth: 6546'·6557'; 6575'-6586'; 6614'·6620'; 6633'·6644' Tubing (size, grade, and measured depth) 4-1/2" L·80, 10415' MD. RBDMS BFl SEP ~ 5 2005 Packers & sssv (type & measured depth) pkr= BAKER PACKER 7 X 4.5 SLZXP PACKER/HANGER pkr= 10409' SSSV= NIP SSSV= 541' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil"Bbl Gas-Met Water-Bbl Prior to well operatio~ 208ß 2464 4327 Subsequent to operation 6368 14. Attachments 15. ""e,1I Cläss.after pr()pos~9 wqrk: .···CÖpiê$df,bc)gá::~hci'sÜ~¢ys'r~h·'····..·.··: . E;XÞ.l6râtöfý·:,·O'~ .·,.·Þ~Y~lqpmént D·, ,S~íYi~ei<0:"': l _.:~: ,~-.. :;'. ~ :·'·r?~¡!¥;oB~Þ9ff;~t'i'lf:JI..Op~.Œt,¡qn.~ .' ...........)(....' , ·,.'··..1.~..'Ij~II~~~tÙ~i·,~ft~I.P~þpè~~d,WØfk.: . " è.·' QHO' GásO' <WÀG.0, 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt ~.a7 ~?f?~<..ð'?~. Casing Pressure 1417 1371 Tubinç¡ Pressure j 255 287 " 'NP9P,"-O ?O?tict;'·ii....'..;'...~..'..:;.·.·.·..·.··.·.··'..·.... Rbb~~'~[)......~·hti~t7D$'ßn.... ,prin~èqNà~m~.' .',:,.,1{J;¿.i~·>..,:............·..·:.r ..............,...'", ...... , . .,·".C" . ." "'''', \ Signature "p.·..'..,....fp.·.....··,·...,'.d.'.'.'...'. 49.tiO..·...·.n... ·.'~h.g...·....·..i..:.f1.....·...·.,.e. ._.e.··...·.·.,:r.i.p.·...·.·~,'...:'.......v..........·.~e....,.'..···.ê:...h, ...º.··..·......ia.....·.n.'..'.:.,............"................" ".".....'.........'..,...,.....'.'..................... ,. '9Õt~6592i53'5'·····.·;; ,i._" 'DãfèO,' (} ~.Ii'·~ ,...,..... ".,",~¿,/~~J' Form 1 0-404 Revised 04/2004 Submit Original Only Date Event Summary ) 1 D-11 DESCRIPTION OF WORK COMPLETED SUMMARY 9/9/200sICommenced Water Injection cycle \ :' RE: ID-ll (PTD 1990720) Temp LLP variance request due to low w... ') ) Subject: RE: ID-ll (PTD 1990720) Temp LLP variance request due to low wellhead injection pressure From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Tue, 13 Sep 2005 08:10:10 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> CC: James Regg<jim_regg@admin.state.ak.us>, AOGCCNorth Slope Office <aogcc -prudhoe .;...bay@admin.state~ak.us> Tom, lD-11 water injector's LLP was placed back in service today. The injection wellhead pressure slowly increased over the weekend and is now at 1157 psi at 10300 BWPD. Please let me know if there are any questions. Marie McConnell Problem Well Supervisor 659-7224 -----Original Message----- From: CPF1 OS Lead Techs Sent: Tuesday, September 13, 2005 8:01 AM To: NSK Problem Well Supv; CPF1 Prod Engr Cc: CPFl Prod Supv Subject: RE: 10-11 (PTD 1990720) Temp LLP variance request due to low wellhead injection pressure Marie, we just increased water injection into 1 D-11.The injection pressure is at 11 OOpsi we have reset the LPP and will remove it from the SDL.Thanks for your help.DT -----Original Message----- From: NSK Problem Well Supv Sent: Friday, September 09, 2005 4:15 PM To: 'Thomas Maunder' Cc: James Regg; AOGCC North Slope Office; NSK Problem Well Supv Subject: RE: 10-11 (PTO 1990720) Temp LLP variance request due to low wellhead injection pressure Tom, Thanks for the quick response. The LLP's trip point is 500 psi. The production engineer expects the wellhead pressure to be greater than 500 psi in a few days. Will keep in touch. Marie McConnell Problem Well Supervisor 659-7224 :SCANj~~-,"\ .. , &;.[ SfP .1 0) 2noç -. ...:.. æ.ì _~r ,..I -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday, September 09, 2005 3:57 PM lof2 9/13/20058:12 AM RE: ID-ll (PTD 1990720) Temp LLP variance request due to low w... ') ) To: NSK Problem Well Supv Cc: James Regg; AOGCC North Slope Office Subject: Re: 10-11 (PTO 1990720) Temp LLP variance request due to low wellhead injection pressure Marie, It is acceptable to keep the well in service with the LPP defeated and no man watch. Please keep us advised regarding the tubing pressure performance. What is the trip value for the LPP?? Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 9/9/2005 3 :31 PM: Tom & Jim, 1 D-11 was just converted from pre-production to injection. The well was turned on injection today and the wellhead pressure is only 75 psi at an injection rate of 5500 BWPD. The SSV LLP on this water injector has been defeated to allow injection and the well is being man watched. The well passed an MITIA during the conversion wellwork and is planned for an AOGCC witnessed MITIA as soon as injection stabilizes within the next 30 days. The well is expected to pressure up in a few days to allow the LLP to be placed back in service. In the meantime, approval to leave the LLP pilot defeated without a 24 hr man watch is requested. Please let me know if there are any questions. Thanks, Marie McConnell Problem Well Supervisor 659-7224 20f2 9/13/2005 8:12 AM ~r~uŒ ) r¡ïì Ie /8\ ~ /M,'A\ ~ ~ ffi,,'8i lJ1Jlf Ii, ~Wæ)~W ) AJ1A~KA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279·1433 FAX (907) 276·7542 Brian Seitz Kuparuk Staff Engineer ConocoPhillips Alaska, In.c P.O. Box 100360 Anchorage, Alaska t qq--old- Re: Kuparuk ID-11 Sundry Number: 305-208 SCI\NNED AUG ü 2 2005 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 oliday or weekend. A person may not appeal a Commission decisio tluperior Court unless rehearing has been requested. óî ynncer y, I J _ . No hai~' DATED this Yday of August, 2005 Encl. Alter casing Abandon D D D CPJ 8-"b()~ STATE OF ALASKA ) ~~c~/~ /';,) ALASKA OIL AND GAS CONSERVATION COMMISSION "fa 4Ut; 0 I t:D APPLICATION FOR SUNDRY APPROVAL :lkao/7&G. ZOOS 20 AAC 25.280 4. 8$ Conr. Operation Shutdown D Perforate D Waiver /J¿-~ge Ötf~is. .0 Plug Perforations D Stimulate D Time Extension 0 ~o. conve~(glJ Injector Perforate New Pool D ) Repair well Suspend D D D 1. Type of Request: 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 7. KB Elevation (ft): RKB 106' 8. Property Designation: ADL 28243, ALK 3814 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 11234' 6727' 11136' Casing Length Size 4. Current Well Class: Development 0 Stratigraphic D Re-enter Suspended Well 5. Permit to Drill Number: Change approved program Pull Tubing Exploratory D Service D 199-072 6. API Number: 50-029-22946-00 9. Well Name and Number: 1 0-11 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6673' MD TVD Burst Collapse CONDUCTOR 115' 16" SURFACE 6708' 9-5/8" PRODUCTION 10458' 7" PRODUCTION 833' 4-1/2" 115' 115' 6814' 4403' 10564' 6362' 11234' 6727' Perforation Depth MD (ft): Perforation Depth TVD (ft): 10907'-10927', 10960'-10980', 11031 '-11 041', 11065'· 6546'-6557', 6575'-6586', 6614'-6620', 6633'-6644' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER PACKER 7 X 4.5 SLZXP PACKER/HANGER pkr= 10409' Camco DB nipple @ 541' 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development D 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1-Sep-05 Oil D Gas D 16. Verbal Approval: Date: WAG D GINJ D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Brian Seitz 73~ Tubing Size: 4-1/2" Tubing Grade: L-80 Tubing MD (ft): 1 0415' Service 0 Plugged D WINJ 0 Abandoned D WDSPL D Signature # Contact: Brian Seitz @ 265-6961 Title: Kuparuk Staff Engineer Phone .J6.J-=-ó,¿ I Date 7 ~.?~,-- Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .?ð::)-_df- Plug Integrity D BOP Test D Mechanical Integrity Test ~ Location CIp.::Uinco D ~f'() Þ.öQ.O~"~\¡\~~~ \~ft",~,~t?ð- ~9;19'J RBDMS BFL AUG 0 3 2005 ~ Other: ~/5 " Approveü b' . / y- /' ~ -'~ ~ Form 10-403 Revised 11/2004 o ~~GU~A L APPROVED BY THE COMMISSION f{D( Date: Submit in Duplicate ) ) KRU 1 D-11, 1 D-11 L 1, & 1 D-11 L2 Conversion to Injection Back2round 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 of 2004, 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 PFe-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 sustainin~ flow. In addition, a new offset producing well (ID-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 1 D-ll was performed on 10/19/04 as part of pre-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. ) ConocóP'hillips ) Dan Venhaus Wells Group CTD Engineer Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4372 February 7, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 REC IVED FEB 0 9 2005 Alaska Oil & Cons. Commission Anchorage Subject: Report of Sundry Well Operations for 1 D-11 (APD # 199-072) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations to convert the Kuparuk well 1 D-11 from an injector to a producer effective 11/20/04. If you have any questions regarding this matter, please contact me at 263-4372. Sincerely, W~~ D. Venhaus Wells Group CrD Engineer CPAI Drilling and Wells DV /skad SCANNED FEB 11 LDDS OR\G\NAL ') ') STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WEll OPERATIONS Repair Well D Pull Tubing D Operat. ShutdownD Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 106' 1. Operations Performed: Stimulate D Waiver D Other 0 Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 199-072 6. API Number: 50-029-22946-00 Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development - 0 Stratigraphic D to convert from injector to producer Exploratory D Service D 9. Well Name and Number: 10-11 8. Property Designation: ADL 28243, ALK 3814 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION PRODUCTION Perforation depth: measured 11234' feet true vertical 6727' feet measured 11136' feet true vertical 6673' feet Length Size MD 115' 16" 115' 6708' 9-5/8" 6814' 10458' 7" 10564' 833' 4-1/2" 11234' Plugs (measured) Junk (measured) TVD Burst Collapse 115' 4403' 6362' 6727' RECEIVED FEB 0 9 2005 Alaska Oi' & Ga$ Cons. Commission Anchorage Measured depth: 10907'-10927',10960'-10980',11031'-11041',11065'-11085' true vertical depth: 6546'-6557',6575'-6586', 6614'-6620', 6633'-6644' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 10415' MD. Packers & SSSV (type & measured depth) pkr= BAKER PACKER 7 X 4.5 SLZXP PACKER/HANGER pkr= 10409' Cameo DB nipple @ 541' 12. Stimulation or cement squeeze summary: Intervals treated (measured) n/a 13. Treatment descriptions including volumes used and final pressure: Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl TubinQ Pressure CasinQ Pressure Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run- Daily Report of Well Operations _X 15. Well Class after proposed work: Exploratory D Development 0 Service D 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: WDSPL D Contact Dan Venhaus @ 263-4372 Printed Name -- _....D~n veZiYs'~ Signature 01.....6 ,/:-".-./ - //"/~" ~;:-:~ Title Phone Coiled Tubing Engineer 907 -263-4372 Date KtSuMStfFre~ ~ht{°§ A~Drake 263-4612 ORIGINAL Form 10-404 Revised 04/2004 Submit Original Only Scblumbepgep Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well /~r'117z,. 1 D-11 I ~-:2,!J' 3A-11 I ~ Of;:¡ 2U-06 lYS-..2-~ ~ 3A-15 /~f "0 'If 3C-12 71z -ðl? 1A-15 I 'To .. t9 '!:II 1 L-09 Job# 10922472 10922478 10922477 10922479 10922482 10922481 10802915 Log Description INJECTION PROFILE INJECTION PROFILE PRODUCTION PROFILE INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE PROD PROFILE/DEFT (REDO-WELL SKETCH) , ./t¡{;;,,/tb- SÇANNEDDEC 2820~~ Date 10/11/04 10/16/04 10/15/04 10/16/04 10/19/04 10/18/04 07/26/04 NO. 3241 1 0/22/04 .(ç~ Company: Alaska Oil & Gas Cons Comm Attn: Robin Deason 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: BL DATE: Kuparuk .~. Color CD 1 1 1 1 1 1 1 '-"" IO/¿~1f Please sign and return ore opy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. RE: KRU ID-II and ID-32 LI: Request for, -)er ITom monthly testing ') \'\) - \ \ \ C\ ~ -0 '\ J~ - \ \ L 'l;¡O~--d \ \ -.. \ \ \... d... ~()~ -"a-\à \~ '-." ".J Q{)O- \ ~ ~ -~d,-1- ~Q4-\<iÇ 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 2004 09:22:43 -0800 To: Thomas Maunder <tom - maunder@admin.state.ak.us>, "Venhaus, Dan E" <Dan.E.Venhaus@conocophillips.com> CC: John D Hartz <jack_hartz@admin.state.ak.us>, Steve McMains <steve_mcmains@admin.state.ak.us>, "Johnstone, Sam" <SamJohnstone@conocophillips.com>, "Lamar Gantt (E-mail)..<ganttll@bp.com> Thanks Tom. Dan & Lamar - please note that this applies to 10-32 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, 2004 9:16 AM To: Seitz, Brian Cc: John D Hartz; Steve McMains Subject: Re: KRU 1D-11 and 1D-32 Ll: Request for waiver from monthly testing Brian, With regard to the plan to produce 1 D-II, L 1 and L2 for some 3 to 6 months, when the lateral completion reports (form 407s) 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. -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Thursday, September 30, 2004 3:17 PM To: Seitz, Brian Cc: jack hartz@admin.state.ak.us¡ CPF1 Prod Engr Subject: Re: KRU 1D-11 and 1D-32 L1: Request for waiver from monthly testing ~ c:> 0 ('oJ ~ 0 :;::::0- 0 Z Brian 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 Cì UJ Z Z ~ Ü (/) RE: KRU ID-II and ID-32 LI: Request for \. _.ler ITom monthly testing 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 STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 RepairWell 0 Plug Perforations 0 Stimulate 0 Other 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdownO Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 199-072/ 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 50-029-22946-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 106' 10-11 8. Property Designation: 10. FieldlPool(s): ADL 28243, ALK 3814 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 11234' feet true vertical 6727' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SURFACE 6708' 9-5/8" 6814' 4396' PRODUCTION 10458' 7" 10564' 6355' PRODUCTION 833' 4-1/2" 11234' 6727' Perforation depth: Measured depth: 10907'-10927',10960'-10980',11031'-11041',11065'-11085' REGEn/ED true vertical depth: 6539'-6550',6568'-6579',6614'-6620',6633'-6644' OCT 2 1 2004 Tubing (size, grade, and measured depth) 4-1/2' , L-80, 10415' MD. Alaska Oil & Gas Con;;. f"'n'" Packers & SSSV (type & measured depth) pkr= BAKER PACKER 7 X 4.5 SLZXP PACKER/HANGER pkr= 10409' Anchonwe '" Cameo DP npple @ 541' 12. Stimulation or cement squeeze summary: Intervals treated (measured) n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation n/a n/a shut-in -- n/a Subsequent to operation n/a n/a shut-in -- n/a 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run - Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilO Gas 0 WAG 0 GINJO WINJ0 WDSPLO 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name Mike looney Title Wells Group Team leader ( ~ Signature Ii d~ Phone Date /0 .~¿),r;/j //11 ">-J/ J\. p",nR",rJ hv ShRrnn AI'.<IJn:n'tik" PR.~-4fiIP I ~~ W>JìnS Form 10-404 Revised 04/2004 ORIGINAL ~ 10-11 Well Events Summary Date Summary 10/05/04 DRIFT TBG W /2.875" X 21' TO 11136' SLM.O [Tag, Perf] 10/06/04 OBTAINED SBHP @ 10,805' @ 3329 PSI, 135 DEG & 10,905' @ 3351 PSI RKBo [Pressure Data] 10/10/04 PERFORATED C SANDS 11031'-11041' AND 11065' -11085', 6 SPF WITH 27/8" HSD POWERJET. NO CHANGE IN THE WHTP POST PERF.O [Perf] Mike Mooney Wells Group Team Leader Drilling & Wells ConocÓPh iIIi ps P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 October 20, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 10-11 (APD # 199-072) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation operations on the Kuparuk well 1 0-11. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, 14. JI{~ M. Mooney Wells Group Team leader CPAI Drilling and Wells MM/skad RECEIVED OCT 2 1 2004 Alaska Oil & Gas Com. Com,n¡:;s¡..m Anchorage @Vfli\ 1 ~ íñHÞ. . I.~\ r.1 ,.í~\ ~ æ) U~U ~ WU LrJL~Lr~ù@) m li~\ ~ !,-~ \ LIl.J A.I~A.SIiA. OIL AlWD GAS CONSERVATION COMMISSION Brian Seitz Kuparuk Staff Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk 1D-11 Sundry: 304-365 Dear Mr. Seitz: 199.- ¿J 7;;)- FRANK H. MURKOWSKI, GOVERNOR 333 W. '?' AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 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 Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. ( Sí . Norman Chairman BY ORDER OF '9IE COMMISSION DATED this 12- day of October, 2004 Encl. SCANNED OCT 0 9 2004. ./ 1. Type of Request: Abandon SFP ~ 0 2 Ati* Oií (~ 'uð~ STATE OF ALASKA" Ancnoragl ALASKA OIL AND GAS CONSERVATION COMMISSION RE CE IVE lÝ APPLICATION FOR SUNDRY APPROVAL - /<Py~( 20 MC 25.280 SFP 3 0 2004 D Suspend D Operation Shu tdown D Perforate GtØ1 "'!aiver ij Annular DiSp..JJ D Alaska 011 & Gas ns. Cor¡¡¡u,,,::.¡VIi D Repair well D Plug Perforations Stimulate D Time Exten~on Other 0 D D D nc ge Temporarily Pull Tubing Perforate New Pool Re-enter Suspended Well Convert to Producer 5. Permit to Drill Number: 4. Current Well Class: Development 0 Stratigraphic D Exploratory D Service D 199-072 6. API Number: 50-029-22946-00 Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 106' 8. Property Designation: 9. Well Name and Number: 1 D-11 10. Field/Pool(s): Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6727' Length 11. Total depth MD (ft): 11234' Casing CONDUCTOR SURFACE PRODUCTION 115' 6708' Size MD TVD Burst Collapse 16" 115' 9-5/8" 6814' 7" 10564' 4-1/2" 11234' PRODUCTION 10458' 833' Tubing Size: 4-1/2" Tubing Grade: L-80 Tubing MD (ft): 10415' Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness '3~g:f)~~\ ~\,,\ \i¥\.~~ ~?~-S\-. Plug Integrity D BOP Test ~ Mechanical Integrity Test D Other: ~V\,ro\.JQ\"\ <;. 9 ~("(."'\O Cl~00',," \~~\\X~ (<C~~(O~-\.~-\-~~\~ ~\ \, 30 'I.. 3tP!J- Location Clearance D l OCT 07 0 E1~1~RA L NNED OCT 0 91~OO4UCTIONS ON REVERSE BY ORDER OF THE COMMISSION Date ,tJ!¡,4tf ~ Submit ik~a: KRU 1 D-11 Temporary Conversion to Production Back2round KRU ID-ll was drilled and completed as a C4-sand injector in October of 1999. The well is being evaluated as a coiled tubing sidetrack candidate to provide injection support to recently sidetracked ID-30 and a proposed new well scheduled to be drilled in late 2004 or early 2005. As part of the evaluation of the Cl-sand potential in the ID-ll area, ConocoPhillips proposes adding perforations in the C I-sand and flow testing the well. Pending results of the Cl-sand perforations, C3-sand perforations will also be evaluated. Should test results prove promising, ID-ll will remain on production for a period of 3-6 months and then returned to injection. Summary of Operations . Rig up coiled tubing and mill cement out of 4-1/2" liner to provide access to C 1- sand target . Rig up slickline and conduct pre e-line drift and tag . Rig up e-line and perforate C I-sands . Test well through temporary test facilities . If well unable to sustain production, add C3 perforations and retest . If well able to sustain viable production, tie into production header and test periodically through temporary test facilities . Convert back to water injection service at end of temporary production period SCANNED OCT 0 9 2004 Re: KRU 1D-11 and 1D-32 L1: Request for waiver ITom monthly testing Subject: Re: KRU ID-ll and 1D-32 L1: Request for waiver from monthly testing From: Thomas Maunder <tom - maunder@admin.state.ak.us> Date: Thu, 30 Sep 2004 15:17:07 -0800 To: "Seitz, Brian" <Brian.Seitz@conocophillips.com> CC: jack_hartz@admin.state.ak.us, CPFl Prod Engr <n1269@conocophillips.com> Brian, Jack and I have discussed your proposal and the sundries for the wells and will include Please call with any questions. Tom Maunder, PE AOGCC find it acceptable. I have received a copy of this email with them. Seitz, Brian wrote: Tom- ConocoPhillips is evaluating the temporary conversion of two Kuparuk water injection wells, KRU ID-l1 and KRU 1D-32 Ll, 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-ID 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-ll 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 ID-30 Ll 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 1 of 1 SCANNED OCT 0 9 2004 9/30/20043:17 PM ( ( Mike Mooney Wells Group Team Leader Drilling & Wells ConocJP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 December 19,2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1 D-11 (APD # 199-072) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 1 D-11. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, A~ ¡;f~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad StGÞ~ú\~~Er, ~ßJ\N 2 @ 2004 RECE\VED JAN 0 5 2004 A\aska Oi\ & Gas Cons. Commission Anchorage OR\G\NAL l ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Suspend D Operation Shutdown D Perforate D Variance D Annular Disp. 0 Alter Casing 0 Repair Well 0 Plug Perforations D Stimulate 0 Time Extension 0 Other 0 Change Approved Program D Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 199-072/ 3. Address: Stratigraphic D Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22946-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 106' 1 D-11 8. Property Designation: 10. Field/Pool(s): ADL 28243, ALK 3814 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 11234' feet true vertical 6727' feet Plugs (measured) Effective Depth measured 10907' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SURFACE 6708' 9-5/8" 6814' 4396' PRODUCTION 10458' 7" 10564' 6355' PRODUCTION 833' 4-1/2" 11234' 6727' Perforation depth: Measured depth: 10907'-10927',10960'-10980' true vertical depth: 6539'-6550',6568'-6579' RECEIVED) Tubing (size, grade, and measured depth) 4-1/2" , L-80, 10415' MD. JAN 0 5 2004 Alaska Oil & Gas Cons Commiss' Packers & SSSV (type & measured depth) pkr= BAKER PACKER 7 X 4.5 SLZXP PACKER/HANGER pkr= 10409' A h' Ion Cameo DP Nipple nipple @ 541' nc Drage 12. Stimulation or cement squeeze summary: Intervals treated (measured) 9800' Treatment descriptions including volumes used and final pressure: 720 bbls of seawater 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation - - - Subsequent to operation - - 521 - 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run - Exploratory D Development D Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilO GasD WAGD GINJD WINJ 0 WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name Mi e Mooney Title Wells Group Team leader Signature JJ All Phone Date tZlz z.-¡ó ~ fL'. 'v ,.",1 Pren~r¡:¡rl hv .c:haron Al/sun:Drnke 26.'~.4612 ~ \- J -- SF JAN 0 .., 1OO~ '...",', ..':.\iA."L.' I . oil "..',J" Form 10-404 Revised 2/2003. U K \ b \ \ 'J SUBMIT IN DUPLICATE ( ( ARCa Alaska, Inc.A GKA 1 D-11 1D-11 API: 500292294600 Well Type: SVC Anale@TS: 57 dea @ 10902 SSSV Tvoe: aria Completion: 10/26/99 Anale @ TD: 56 dea @. 11234 Annular Fluid: Last WID: Rev Reason: Corrections by ImO Reference Loa: Ref Loa Date: Last Update: 4/15/00 NIP (541.542, LastT aa: 10907 TD: 11234 ftKB 00:5.200) Last Taa Date: 4/3/00 Max Hole Anale: 60 dea @. 7659 TUBING Casing String - ALL (0-10415, Size Top Bottom TVD Wt Grade Thread 00:4.500, 16.000 0 115 115 62.58 H-40 WELDED 10:3.958) 9.625 0 6814 4396 40.00 L-80 BTC :J 7.000 0 10564 6355 26.00 L-80 BTC ROOUCTION 4.500 10401 11234 11234 12.60 L-80 IBT 6~~~~~: Tubing String -TUBING Wt:26.00) Size Top Bottom TVD Wt Grade Thread 4.500 0 I 10415 6277 12.60 L-80 I IBT PerforéltionsSummarv .. . . .. . ..... . Interval TVD Zone Status Feet SPF Date Type Comment 10907 - 6539 - 6550 C-4 20 4 1/19/9~ IPERF 27/8" HC, DP, 180 deg phase, +/- 90 10927 deg, low side 10960 - 6568 - 6579 C-4 20 4 1/19/9~ IPERF 2 1/2" HC, DP, 180 deg phase, +/- 90 10980 deg, low side Gas Lift andrei/Dummy Date I Vlv Valve 1 R C (10353-10354 un omment 00:5.985) 0 11/15/99 ID 3.81~ .-. _n__- -... --. :i.812 -- .n_... -.. 3.875 3.875 4383' WLM NIP (10397-10398, 00:5.200) :JROOUCTION (10401-11234, 00:4.500, PKR (10409-10410, 00:4.500) Perf - - (10907-10927) - - - - - - - - - - - - - - - - - - Perf - - (10960-10980) - - - - - - --- --- - - - - - - - - - - (' ( 1 D-11 Event History Date Comment 11/24/03 PUMP HPBD TO INCREASE INJECTION RATE INTO THE A SAND. PUMPED 720 BBLS OF 50 DEG SEAWATER @ MAX RATE POSSIBLE (6 BPM AVERAGE) @ 4000 PSI. PUMP 4 STAGES WITH 15 MIN SHUT DOWNS IN BETWEEN STAGES. [HPBD] Page 1 of 1 12/18/2003 Annular Disposal during the second quarter of 2003: h(1) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 3S-10 9972 100 0 10072 388 21204 31664 March April 3S-21, 3S-08, 3S-23 2003 2003 1C-22 21553 100 0 21653 0 27044 48697 March May 1C-190, 1C-174, 1C-.178, 1C-19 2003 2003 Puviaq #1 5063 100 0 5163 0 4731 9894 March April Puviaq 1 2003 2003 CD2-46 31393 100 0 31493 371 0 31864 April May 2003 CD2-51, CD2-12 2003 3S-16 31006 100 0 31106 357 0 31463 April May 2003 3S-23, 3S-17, 3S-06, 3S-16 2003 Hansen 1 47382 100 0 47482 0 67796 1 15278 January June 2003 Hansen, Hansen lA 2002 1C-19 31325 100 0 31425 0 0 31425 May 2003 June 2003 1C-184, 1C-170, 1c-172 3S-08B 31610 100 0 31710. 290 0 32000 May 2003 June 2003' 3S-24, 3S-03, 3S-19 CD2-19 30860 100 0 30960 377 0 31337 May 2003 June 2003 CD2-58, CD2-52 CD2-41 3900 100 0 4000 377 0 4377 June 2003 June 2003 CD2-20 3S-17A 4559 100 0 4659 361 5020 5020 June 2003 June 2003 3S-19 Total Volumes into Annuli for which Disposal Authorization Expired during the second ruarter 2003: Freeze Protect Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus CD2-17 17709 100 0 372 18181 Open, Freeze Protected May 2002 Feb 2003 CD2-08, CD2-48, CD2- 46 ' cD2'32 31337 100 0 379 31816 Open, Freeze Protected June 2002 July 2002 CD2-19, CD2-41, CD2- 23 CD2-50 31530 100 0" 370 32000 Open, Freeze Protected July 2002 Sept 2002 CD2-41, CD2-38 1D-11 ..... 32102 ............. 100 0 235 32437 Open, Freeze Protected May 2002 jUne 2002 1D-103 1C:.!,.8' ~' 32251 100 0 .... 373 32724 Open, Freeze Protected June 2002 July 2002 1C-104 "JUL 1 G 2003 Annular Disposal during the second quarter of 2002: h(1) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-15 10176 100 0 10276 371 10446 21093 March April CD2-25, CD2~50 2002 2002 2P-420 9479 100 0 9579 150 0 9729 April May 2002 2P-427, Heavenly 2002 2P-415A 26238 100 0 26338 52 4943 31333 March April 2P-431, 2P-422A, 2P-427, 2002 2002 Heavenly, Grizzly, 2P-441 CD2-49 27474 100 0 27574 386 0 27960 April May 2002 CD2-46, CD2-22, CD2-50 2002 CD2-17 14962 100 0 15062 372 0 15434 May 2002 June 2002 CD2-48, CD2-46 1D-11 32102 100 0 32202 235 0 32437 May 2002 June 20O2 1D-103 CD2-32 18536 100 0 18636 379 0 19015 June 2002 June 2002 CD2-19, CD2-41 1C-18 4176 100 0 4276 379 0 4655 June 2002 June 2002 1C-104 Total Volumes into Annuli £or which Disposal Authorization Expired during the second vuarter 2002: Freeze Protect Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 1J-09 24202 100 0 330 24632 Open, Freeze Protected May 2001 May 2001 1J-10 1C-17 33139 100 0 160 33399 Open, Freeze Protected May 2001 June 2001 1C-133, 1C-121, 1C- 123, 1C-127 CD2-42 33507 100 0 385 33992 Open, Freeze Protected June 2001 October CD2-24, CD2-33, CD2- 2001 15 2P-417 30965 100 0 887 31952 Open, Freeze Protected October March 2P-422, Grizzly, 2P-451, 2001 2002 2P-441, 2P-448, 2P- 422A, 2P-420 1C-27 31766 100 0 153 32019 Open, Freeze Protected June 2001 July 2001 1C-127, lC-117, 1C- 111, 1C-123 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 May 7, 2002 Ms. Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 Subject: 1D-11 Application for Sundry Approval Dear Commissioner: Phillips Alaska, Inc. hereby files this Application for Sundry Approval for annular disposal down the Kupamk 1D-11 well. This well has been permitted for annular disposal in April 2000 and expired in April 2001. Currently, there is 235 bbls disposed in the well. Sincerely, R. Thomas ~ Kuparuk Drilling Team Leader PAI Drilling If you have any questions regarding this matter, please contact Nicholas Pysz at 265-6831. RT/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ii TYpe of reque$ii Abandon ' ~Spend _ Operational shutdown _ Re-enter suspended well_ ' ....... Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other _X Change approved program _ Pull tubing _ Variance _ Perforate _ Annular Injection 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 105' feet 3. Address Exploratory_ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__X Kuparuk River Unit 4. Location of well at surface 8. Well number 586' FNL, 601' FEL, Sec. 23, T11N, R10E, UM (asp's: 560491,5959080) 1D-11 At top of productive interval 9. Permit number / approval number 2565' FNL, 2052' FWL, Sec. 19, T11 N, R11 E, UM 199-72 At effective depth 10. APl number 50-029-22946 At total depth 11. Field / Pool 2627' FNL, 2322' FWL, Sec. 19, T11 N, R11 E, UM (asp's: 568716, 5957165) Kuparuk River Field / Kuparuk River Pool 12. Present well condition summary Total depth: measured 11234 feet Plugs (measured) true vertical 6719 feet Effective depth: measured 10907 feet Junk (measured) true vertical 6546 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 16" 9 cu yds High Early 115' 115' Surface 6779' 9.625" 760 sx AS III Lite, 710 sx Class G 6814' 4396' Production 10534' 7" 220 sx Class G 10565' 6355' Liner 833' 4.5" 14o sx C~ass G 11234' 6719' true vertical 6568'-6579', 6539'-6550' Tubing (size, grade, and measured depth 4.5", 12.6#, L-80 @ 10415' Packers & $$$V (type & measured depth) Baker ~LZXP LT packer ~ 10409' 18. A~achments Description summa~ of proposal ~ Detailed ope~ations p~ogmm I ~efer to a~ached for LOT su~ace cement details and detail X morning ddlling ~epom test, c~sing sheets, schematic 14. Estimated date ~or commencing operation ~ 5. Status o~ ~ell classification 18. If proposal was verbally approved Oil ~ Gas Name of approve~ Date approved Se~ioe ~X 17. I hereby ce~i~ that the ~oregoing is t~ue and correct to the best of my knowledge. SignedR. T~~~~~~ Title: Kuparuk Drilling Team Leader Date Prepared by Sharon AIIsup-Drake FOR COMMISSION USE ONLY Conditions of approval: PlugNOtify Commission so representative may witneSSintegri~_ BOP Test __ Location clearance __IApproval n°~Z-/~ ~ Mechanical Integri~ Test __ Subsequent form required lO- ~.9maI ~gn~ By Approved by order of the Commission :~ammy ~Sl{ Tayi~ Commissioner Date ~/ Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE Annulus Disposal Transmittal Form A. Designation of the well or wells receiving drilling wastes: 1D-11 B. The depth to the base of freshwater aquifers and No Aquifers; Base Permafrost = +/- 1,561 TVD- permafrost, if present: RKB C. A stratigraphic description of the interval exposed to the From the 9-5/8" shoe to the cement top all that is open annulus and other information sufficient to support a open is shale or minor Campanian Sands. commission finding that the waste will be confined and will not come to the surface or contaminate freshwater: D. A list of all publicly recorded wells within one-quarter See attached map indicating one well within ~A mile and all publicly recorded water wells within one mile mile of the surface casing shoe of 1 D- 11. of the well to receive drilling waste: 1D-30 was an approved disposal well with 31722 bbls disposed of into the annulus. See attached sundry application. There are no potable water wells within one mile of 1D-11. E. Identify the types and maximum volume of waste to be Types of waste can be drilling mud, drilling disposed of and the estimated density of the waste slurry: cuttings, cement-contaminated drilling mud, completion fluids, diesel, formation fluids, and drilling rig domestic wastewater. Maximum volume to be pumped is 35,000 bbls. Estimated density of the waste slurry ranges from 9.2 to 9.5 ppg. Fo An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the casing casing shoe during annular disposal operations and shoe during disposal operations is 1,843 psi. calculations showing how this value was determined: See attached calculations page. Go Details that show the shoe of the outer casing is set below See attached: cement reports, LOT/FIT reports, the base of any freshwater aquifer and permafrost, if and casing reports for ID-II. present, and cemented with sufficient cement to provide zone isolation: H. Details that show the inner and outer casing strings have See attached: casing summary sheet and sufficient strength in collapse and burst to withstand calculation pages. anticipated pressure of disposal operations: Io Any additional data required by the Commission to confirm containment of drilling wastes: ARCO Alaska, Inc./ NIP (541-542, OD:5.200) TUBING (0-10415, OD:4.500, ID:3.958) ~RODUCTION (0-10564, OD:7.000, Wt:26.00) Gas Lift andrel/Dummy Valve 1 (10353-10354, OD:5.985) NIP (10397-10398, 0D:5.200) ~RODUCTION (10401-11234, OD:4.500, PKR (10409-10410, 0D:4.500) Perf (10907-10927) Perf (10960-1098O) GKA 1D-11 APl: 500292294600 Well Type: SVC Angle ~ TS:r57 deg @ 10902 SSSV Type: Orig Completion: 10/26/99 Angle @ TD:I56 deg @ 11234 Annular Fluid: Last W/O: Rev Reason: I Corrections by ImO Reference Log:I Ref Log Date: Last Update: 4/15/00 Last Tag: 10907 TD: 11234 ftKB Last Tag Date: 4/3/00 Max Hole Angle:160 deg @ 7659 I I ca~ihg Stri~ ~ ~:L size. Top Bottom TVD Wt Grade Thread 16.000 0 115 115 62.58 H-40 WELDED 9.625 0 6814 4396 40.00 L-80 BTC 7.000 I 0 10564 6355 26.00 L-80 BTC 4.500 I 10401 11234 11234 12.60 I L-S0 [ lBT ~ize ToP Bottom 'I'VD Wt Grade Thread 4.500 0 10415 6277 12.60 L-80 IBT P~rforati~S~a~ : : : : Interval TVD Zone Status Feet SPF] Date] Type Comment 10907 - 6539 - 6550 C--4 20 4 ~11/19/9~ IPERF 2 7/8" HC, DP, 180 deg phase, +/- 90 10927 | | deg, Iow side 10960 - 6568 - 6579 C-4 20 4 ~11/19/9~{ IPERF 2 1/2" HC, DP, 180 deg phase, +/- 90 10980 I | | I deg, Iow side .~ EiffM~drels/Val~S : : :. : ;tn MD ~D Man ' Man VMfr VType VOD Latch Port TRO Date Vlv Mfr Type I Run IComment 1 1103531 62451CAMCOI KGB-2-LS DMY 1.0 BTM 0.0001 01 11/15/99 I ~th~ (~ld~i ~iPi~ etc~) ~ ~EWEERY ::~ ~)epth WD :l'ype Description ID 541 541 NIP CAMCO DB 3.813 10397 6268 NIP OTIS X 3.812 10407 6273 SEAL BAKER Seal Assembly 192-47 3.875 10409 6274 PKR BAKER Packer 7 x 4.5 SLZXP packer/hanger I 3.875 G~n~ralN~t~ ;:: ; Date Note 12/23/99 Tagged hydrates @4383' WLM Created by bmichoel Date plotted: 9-May--2002 PIct Reference is PMSS <0-11234'>, Coordinates are in feet reference slot #11. True Vertical Depths ore reference rkb Pool ~6.i S¢ole C[fi'filS'"~-'T~J~-T~ ........................................................... Phillips Alaska, Inc. Structure : Pad 1D Well : 11 Field : Kuparuk River Unit Location : North Slope, Alaska East (feet) 30O0 3100 3200 3300 340O 3500 380O 3700 38OO 390O 40O0 4100 4200 4300 4400 4500 4600 4700 480O 4900 5000 5100 5200 5500 5400 550O 5600 57OO 5800 5900 100 ~ 0 ~ 100 II 200 ~ 400 500 600 ?OO 800 9OO 1000 ~oo _ -1200 _ -1300 - · 1400 · '1500 ~ soo 17oo 1800 1900 2OO0 . -2100 22O0 2300 _ -2400 · -2500 Phillips Alaska, Inc. Pad iD 11 slot #11 Kuparuk River Unit North Slope, Alaska HORIZONTAL PLANE CLEARANCE REPORT by Baker Hughes INTEQ Your ref : PMSS <0-11234'> Our ref : svy6036 License : Date printed : 9-May-2002 Date created : 11-Oct-1999 Last revised : 30-Dec-1999 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on 561086.901,5959669.520,999.00000,N Slot location is n70 17 55.555,w149 30 36.426 Slot Grid coordinates are N 5959078.967, E 560490.805 Slot local coordinates are 585.74 S 600.93 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 1325 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Phillips Alaska, Inc. CLEARANCE LISTING Page 2 Pad iD, Ii Your ref : PMSS <0-11234'> Kuparuk River Unit,North Slope, Alaska Last revised : 30-Dec-1999 Reference wellpath Object wellpath : PMSS IFR <0-12044'>,,30,Pad 1D Horiz Horiz Min'm M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing DistDist 6814.0 4395.9 1243.4S 4530.8E 7005.1 4395.9 2372.9S 4076.4E 201.9 1217.5 1185.5 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #11 and TVD from rkb Pool #6 (105.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 103.92 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Well 1D-11 Date 5/9/2002 TVD 4396 ft. Surface ,,,,, Intermediate Surface Casin~l Size 9.625 In, wt. 40.00 lbs. Grade L 80 Pburst @ 100% 5750 psi Pburst @ 85% 4888 psi Fluid Weigth on Backside 8.3 ppg Max Disposal Pressure 1500 psi Maximum Mud Weight = 23.1 ppg (to burst casing) Surface Casing Burst MMW = Pb@85%+(Fluid Weight on Backside)(.052)(TVD)-Max Disposal Press (.052)(TVD) Maximum Pressure at Surface Shoe Max Disposal MW 9.8 ppg Max Pressure at Surface Shoe = 1843 psi Max Pressure at Surface Shoe Max Press=Max Disposal Press+(Max Disposal MW)(.052)(TVD)-(Fluid Wt. On Backside)(.052)(TVD) Intermediate Casing Size 7.000 In. Wt. 26.00 lbs. Grade L 80 Pcollapse @ 100% 5410 psi Pcollapse @ 85% 4599 psi Gas Depth (TVD) 4396 ft. Gas Gradient 0.11 ppg Max Disposal Pressure 1500 psi Maximum Mud Weight = (to collapse casing) 15.7 ppg Intermediate Casing Collapse MMW = Pc@85%+(Gas Gradient)(Gas TVD)-Max Disposal Press (TVD)(.052) CASING TEST and FORMATION INTEGRITY TEST Well Name: 1 D-11 Date: 10/16/99 Supervisor: WhitlocldReynolds Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-5~8" 40#, L-80 BTC Casing Setting Depth: 6,814' TMD 4,396' TVD Hole Depth: 6,850' TMD 4,414' TVD Mud Weight: 8.5 ppg Length of Open Hole Section: 36' EMW = Leak-off Press. + Mud Weight 0.052 x TVD = 1,220 psi + 8.5 ppg 0.052 x 4,414' EMW for open hole section = 13.8 ppg Pump output = 0.0846 bps Fluid Pumped = 4.2 bbl 3,200 psi 3,100 psi 3,0[]0 psi 2,900 psi 2,800 psi 2,700 psi 2,600 psi 2.5O0 ps~ 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1,800 psi 1,700 psi 1,600 p~ 1,400 psi 1,300 psi 1,200 p~ 1,000 psi 900p~ 700 p~ 600p~ 100 psi 0 psi -.e-- LEAK-OFF TEST --e--CASING TEST .... ~_- LOT SHUT IN TIME ~-- CASING TEST SHUT IN TIME ~ TIME LINE I STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE ................ ..... .... , ............. ..... . 5stk'i 160 psi ................... ................. L.~.o...s.~.s. ...... A%o...p. sj._j i 5 stks 190 psi i 10 stks 410 psi .... i 15 stks 635 psi i 20 stks 850 psi ................ i _ .2..5_s_t.k..s. ..... .1.,.o_7_q.E.sj_,,, 30 stks 1,220 psi ................ .a- ............... .a. ................. 35 stks 1,045 psi ................ .a. ............... & ................. 40 stks 1,025 psi ................ ./- ............... z ................. .................... _%s.!.k_s. ..... !,..oJ.~.p..si.. 50 stks 1,010 esi i SHUT IN TIME j SHUT IN PRESSURE ........... : .... 1- ............... : .............. ':"i O.Omln ) ~ 1,010psi., ........... : .... 1' ............... *, ............. :---, 1.Omen j_ i 950ps~.1 20min i i 940~si i ..... _' ......... ~.. ............... ,~ ............... 30min ~ i 937 psi ..... ' ......... .~. ............. ~, ................. 40min i i 935 psi ._~_'. ......... ,a.. .............. a, ................. 5.0min ~ i 933 psi 60min i ~ 930 psi i.. .... '- ......... .a. .............. 4, ................. .... l:9__mLn_.i .............. L_!2_P_p_s.L.J 80m~n' ~ ~ 928psm , ~.-----' ......... .~- .............. f ............. ~---i 9.0min J I 926 psi .............. + ............... !---;;x;.--_--c;---I 10.0 minj. ......... I._.E~?...~!_..I 25 stks 1,100 psi ! ................. ~. ............... a ................. .,i -- I m ·t/ ~' ~ ~ 30stks ~ 1,310ps, ' I , · r ~ 35stks ~ 1,510ps~ ~ ~ ................ ~, ............... a ................. 40 stks 1,720 psi ! i. .....= .......... ~. ............... .i ................. 45 stks 1,050 psi 1 ~. ................ , ............... ,a ................. J .................... ~P_..s!k_s. .... ~ ,_.~Z.O.._,..~!.~ .................... .s..s.. _s~.s_ .... ~, ~..o.o...p..s..i...i 60 stks 2,630 psi ~ " ................... ..... ................... ZP._s_tk_s. ..... ~,.Lo_o___p..s!_l ! I I ,,,I SHUT IN TIME SHUT IN PRESSURE 1.0 min 3,080 psi ....................................2.0 rain §~b-~'-~-~[~'-'~ , [ 4.0min [ __~,pZo_p_s!_ i.._.~:.°...m.j.n.__.L .................. .3.:9Z.O.. p_si_ 6 0 mini 3,070 psi ..... -'_' .......... ~. ............... ,.~ ................. 70min : i 3,065 psi ..... _'.' .......... ~. ............... .a ................. 80min i : 3,060 psi ..... ~.'~ ......... ~. ............... ,a ................ 90min : i 3,060 psi ..... Z- ..... -. .... ). ............... -, ................. lOOmm , ~ 3,060 psi I ....... · , , . I i , b_l.5__.O_.m_.l.n__.L ............... :._3.,p.6_o..p.s_,..: 20 0 min i i 3,060 psi t. ..... -' ......... i. ............... .,i .................. 25 0 rain ~ ! 3,060 psi ..... :: .......... ~ ............... ! ................. ! 300min , , 3,060Dsi , ~ ..... .' .......... I- ............... -J ........... ' ..... NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: KRU 1 D-11 Date: 10/19/99 Supervisor: S.D. REYNOLDS Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-5/8", 40#, L-80 BTC Casing Setting Depth: 6,814' TMD 4,396' TVD Hole Depth: 10,494' TMD 6,319' TVD Mud Weight: 9.2 ppg Length of Open Hole Section: 3,680' EMW = Leak-off Press. + Mud Weight 0.052 x TVD = 975 psi + 9.2 ppg 0.052 x 6,319' EMW for open hole section = 12.2 ppg Pump output = 0.0846 bps Fluid Pumped = 6.8 bbl UJ 1,200 psi 1,100 psi '1,000 psi 900 psi 800 psi --e--. I_'EAK'-OFI~ TESLr ~. -'~-CASING TEST I '.;; ::;:'~: ;'. ..... ~>.~- LOT SHUT IN TIME ~ CASING TEST SHUT IN TIME .: .e,,,, ,,'*e" "'"""~ ~""""""" ~..... I ,,TIME UNE /~' i 500 psi J · 400 psi 0 psi ' ..... ~, ,o STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE ................ i----~--s-~---i ..... ~-~-a ..... i '-' ....... ................ ,'r~ ............... 5 stks tj ............ 80 psi; .... lj .......... [, ................ "- ............... * ................. ~ ................. t ............... I ......... , ........ j 10stks j 110psi j j , ................................................................... t ............... I j 15stks 160psi j , ! · j 20stks j 240ps] ...... . ......... .4- ............... 4 ................. · j 25 stks 320 psi j ................ .a. ............... .~ ................. 4 i i · ~ 30stks = 410psi 35 stks 520 psi 40 stks 620 psi J d. .t. ................. J 45 stks 720 pm ................ :--~'~-'a~-:----~--~-a .... 55 stks 920 psi 60 stks __..9__7..5_.p_s_! .... ....................- .S..S..s..t.k..s. ...... .9..7..s_p_.s.i .... ................ ~__-7..O--s--t-k--s- ...... ~.S.9_.p..s.! ................ '.,...7.~...s.!.k.s_ ...... ~_2..o_..p.s_i ' 80 stks 920 psi , ................ ~ i i i i SHUT IN TIME SHUT IN PRESSURE 1.0min j 575 psi j ~._2_: 9_m_.L"___l .............. i.__.s..4..°_._p~_~.._! _..3_:9...m. Ln.._L .............. i.__.s_.2..o..p..s_i___l 4.0 m_in__. J.L ............ b_.5..o.g_.p_s_b_l 5.0 min.__ '., ............. L ...4..9..o..p..s. b .] . i i . I 6.0mln = i 480pm j t.. .......... T ....~ ............ J ............. ';'"" 70mIn ; : 480 ps[ ~- ....: .....: ....,-I- .............. t ............. :---1 80mm ~ ~ 475ps] ,. ....- ......... ~ ............. · ................. . I J · i 9.0mln I ; 475pm ; · -- .............. *1- ...............t ................. 1 · i ' i 10.0m]n J I 475 ps] ................. i. ............... d ................. I ' I I [ ................. ~. ............... d ................. ~ L J ................. l ................ ~ ............... , J I l'-- ................. f ............... ! ................. i ................. f ............... i ................. i ! ! , . ................. t ................ , , , 1 ~ ................ t ............... 1 .................. , SHUT IN TIME j ;HUT IN PRESSURE ................. r ........................... '~' .... O.Omin : Ops] j ................. ~. ................................. 1.0 rain i i 2.0 rain 1 ~.0 rain i 4.0 min i : l "--~:~'~'i~-"[ ............... i ................. i '--'~:~'~-"f ............... '~ ................ i .... · ~'.~'~n~"-f ............... i ................. i '--~:~-~T~-"[ ............... i ................. i 9.0 min : , .i I. .......... ..~----~- ............... , ................. , 10.0 min : ' '"'~ ............. 5.0 min r ............... i ................. i i. ......... ..................................... k J 20.0 min i ' .--~:-9-~Ln--i ............... .i ................. 30 0 min : I ,,' NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 1 D-11 Reason(s) for test: Date: 3/22/00 Supervisor: Overstreet/Winfree [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-5/8" 40#, L-80 BTC Casing Setting Depth: 6,814' TMD Hole Depth: 4,396' TVD Mud Weight: 6.9 ppg Length of Open Hole Section: 6,850' TMD 4,414' TVD 36' EMW = Leak,off Press. + Mud Weight = 1,600 psi 0.052 x TVD 0.052 x 4,414' EMW for open hole section = 13.9 ppg + 6.9 ppg Pump output = 0.1000 bps Fluid Pumped = 5.0 bbl 3.200 psi 3.100 psi 3.0O0 psi ?"q(X) psi 2.800 psi 2.700 psi 2.6430 psi 2.500 ps~ 2.400 psi 2.300 psi ?.200 p~ 2.100 psi ?"000 psi 1.900 psi 1,8C]0 psi 1.700 psi 1.600 psi 1,500 psi 1,400 p~ 1,200 psi 1,100 psi 1,000 ~0psi 700 psi 400 ps~ 100 psi 0 psi ...... , , , , i i i i i -.e..-LEAK_OFF TEST -- -=-a--CASING TEST j ,/' -~s--LOT SHUT IN TIME .~I" /' . ~--CASING TEST SHUT IN TIME ~,~ ! TIME LINE .~ ~ ,. .......... " STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE .................... ..s..s_.~.s....l...~P.9.~.s.!_._: ................................................ 8 stks ._9_50_p. si . ............... £_!.8_.s_.t.k_s_.L.!,..4_5__o.__P_S!., .................. ?. ................... _~..3_s__t.k..s. ..... _',_,..s_O__O.__p..sj... 25 stks 1,550 psi j 28 stks 1,550 psi 30 stks 1,550 psi 33 stks 1,600 psi ................ +--3--{-s--tk--s- ...... .',.,..6_o..o...p._sj..! , 38 stks 1,550 psi 43 stks 1,500 psi , 45stks · 1.500 48 stks i 1,5o0 Esi , , ................ · ~ ................................ , i SHUT IN TIME SHUT IN PRESSURE 0.0 m~n ~ 1,500 ps~ 1.0 m~n , , 1,450 ps~ 2.0min ~ i 1,250psi 1 3.0 mini i 1,150 psi i · i i · 4.0mm , , 1,125~s~ L_~:P_.m.i.n._.± ........... l.J_,l_2..s_.p..s!_] 6.0 min i i 1,125 psi i 8.0min i i 1,125psi i 9.0m~n , ; 1,125ps~ ' I I I ~__J__o_...o..~,_n_, ................ ,,__.l.,.!.2..5_.p...s:__,, .................... ! .q ..s.t~_s_ ] __.e_ ! .o_ _p_sL_] ..................... .2..O...s.t.k..s.__j.._.~..S..O.. e..s/..] . . 30stks i 1,310psi ~ ,~ ................ t ............... i ............ '-';'-~.. .,, ............. ,..[...3..S.._s.t.k..s.__j...1._, .S.!9_.P__S. t.j .................... .4..o_ .s.t.k..s._ j ...~.,_7.2..0_. _p._s. [. j 45stks i 1,950psi i ................. ................. ........ ......... ................. ................. , I SHUT IN TIME SHUT IN PRESSURE ._..o:.o_?.j.n. ...................... .3.:j_9.9..p..sj_' .... 1....o...m.j.n. ...................... .3. ,. p..~_o...p..si... .....~:.o...n:.j.n_ ...................... ~,_~_p._.,j_ -~ _ _3:.o._.m.!n. ...................... .3.,.gY.S.__p..s!.. _..~:.o_~:'.n._.[ .................. ~ ,.oz_o_.p..s!.' ~ 5.0min i 3,070 psi q :::::::::::::::::::::::::::::::::::::::::::::::: ,.__._7....o...m_!n....[ .............. L.~ :.°_?.5_._P..S!..: ,_..8...o_._m. j.n....[ .............. ] _ _3_ ,_ _o_?.o_ p_s_i_ j [._. _9_..o...m_ j.n_...[ ............... j__3.: _o_6.o_ _p. _sj..j L.!o_:o_m.j_n_:, ............... j. _ .3_, _0_?.0_ _p_sj_ _ j i__~.5.:.O_..m.j.n_.[ ............... j.._3_ ._o.s._o._.p..sj..j 20.0 min ~ ~ 3,060 psi~ .......... ~ .... I- ............... 'I, ................. -I _..2._5:.o_~Ln__[ ............... L..3., .°..6.°. _ .P..si...~ ....3.o.:.o...m_in_ _L ................ i.._3_ ,_g.s..o__p._sj__.~ NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 1D-11 Date: 10/22/1999 Supervisor: Herbert/Reynolds Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 7", 26# L80 Casing Setting Depth: 10,564' TMD 6,355' TVD Hole Depth: 10,592' TMD 6,369' TVD Mud Weight: 10.8 ppg Length of Open Hole Section: 28' EMW = Leak-off Press. + Mud Weight 0.052 x TVD = 1,150 psi + 10.8 ppg 0.052 x 6,369' EMW for open hole section = 14.3 ppg Pump output = 0.0846 bps Fluid Pumped = 1.8 bbl 3,700 psi 3,600 psi 3,500 psi 3,400 psi 3,300 psi 3,200 psi 3,100 psi 3,000 psi 2,900 psi 2,800 psi 2,700 psi 2,600 psi 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1,900 psi 1,800 psi 1,700 psi 1,600 psi 1,500 psi 1,400 psi 1,3O0 psi 1,200 psi 1,100 psi 1,000 psi ~ ~CASING TEST ~ ~ ..... ~,~,,~ LOT SHUT IN TIME 800 psi, ~ ........ 500600 psiPSi ; ..... L 400 psi , 0 psi ~ STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE ..................... _o...s_t~.s. ......... 9...p. sj ..... .................... .S_..s!.k.s' ....... .7..S..p..s.! .... ................... J..0...s.t.k__s. ...... _4_ _0_ .0_ .p_ .s_ ! _ _ . ................... j..5...s.t~.s. ...... Z.7..s_.,..s.!... .................... .2..o...s.t~.s. ..... !d.o.9_.,.sj.., .................... .2.!..s.t~.s. ..... !d_S__o.._p.s.L ................ & ................................. ! ' SHUT IN TIME SHUT IN PRESSURE ....o...9...m.i..n' ...................... j.,.1.s..o...p.s.i.. ...J.._.o...m_i..n. ..................... !,j.s._o.__p_s.!__ .. ..2... .o.. .m_ [ .n_ ..................... !,j!o.._p_s.L .... .3_.._o...m. Ln- ...................... j_,j~.o...p.s.!.. ...~...o...m.[n.. ...................... .1.,j~.o._.p.s_!__ 5.0 min ~ 1,135 psi "'~.'6"r~[~' .................. ~-':~','i~'~'~i" ...Z.__o___m_[n____t ............... L!d_3__q._p_s_!__. ....8....o...m. Ln....[ ............... LJ...d.3..°...P.S.!.., 9.0 min I, i 1,125 psi ............ .----I. ............... ._j__o_._o___m__?___L ............... i__!,.!2_s.._p.s_,.. CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ..................... P..s..tk..s. ........ .9.P_s.! ..... .................... .S..s..t.k..s. ........ .S.0...p..s.[ .... ................... j__o__s_.t.k_.s_ ...... .3..2.s...p__sj__.. ................... j..s_.s..t~.s. ...... !.o.o..~.s!._ ................... .2.9..s..tks. ..... 1.:.°..s.9_"..s.! _ ................... .2..S..s.!~.s. .... J.,~.s.9..p..s.L' ................... ~9..s..t.k_s. ..... !.,.s..s.9.."..s.L. ................... ~.S..s..t~.s. .... j..,~.s..o..p..s.L' ................... _4__o..s._tks. .... ..2_,.2.!f..p_.s_L ................... .4..s..s..t~.s_ .... ..2.,ko.9_?..s.!.. ................... .S.p..s..t~.s' .... ..2:~p..O..p..s.!.. 55 stks 3,100 psi ................ L.~9..s..t.k..s...: ...~:~ P..o_,..s.,_ ................... .6..3_s..t.k..s... r ._.3.,.S. 9..O._p..s.[.~ ! ................ ,. ............... I .................. I I ! I SHUT IN TIME SHUT IN PRESSURE t ................................................... _..o...o...m.j.n. ...................... .3_,.5..o_.o.~_sj__ 1.0 min 3,500 psi ..................................2.0 min '~]~b'O'~['" .._.4....o...mj.n. ..................... ..3:.4.?.9..p..s.L' ___.~_...o_..mj.n_ ..................... .~.d.s..s_p..s_L 6.0 min . 3,485 psi ___.~_...o_..mj.n_ ................... ~ _ ..3.,_4__~_ _2__p_ .s.! _. 9.0 min i 3,482 psi "3'f:,'.'~';.fiT~"r ............... r"s';3i~'6"~;i-'~ ................ ~- ............... ~ ................ -I __j__5_..o__.m_j.n___~ ................ L_~..,~_7__o_ _p__s_!_ ,., .._2_g:_o_..m_j.n. .................. :.. ~.,.4..7..0. p..s.!..: 25.0 min i 3,460 psi i NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ARCO Alaska' Inc. C'asing Detail 7" intermediate casing Subsidiary of Atlantic Richfield Company WELL: 1 D- 11 Date: 10/20/1999 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Pool 6 RT to LDS = 30.36' TOPS 7" Landing Joint (RKB) 30.36 7" FMC GEN V FLUTED MANDREL HANGER 1.69 30.36 jts 3-252 7", 26#, L-80 BTC-MOD (250 jts) 10449.23 32.05 Gemeco Float Collar 1.31 10481.28 jts 1-2 7", 26#, L-80 BTC-MOD (2 jts) 80.54 10482.59 Gemeco Float Shoe 1.48 10563.13 BTM OF SHOE @ 10564.61 10564.61 TD of 8-1/2" hole = 10572' MD Leaving 8' of rat hole '24 Gemeco Bow Spring CENTRALIZERS 1/jt on jts 1-24 1 centralizer on stop collars on jts 1 & 2 22 centralizers on collars jts 3-24 Run 252 jts. Leave 14 jts in the pipe shed. Remarks: String Weights with Blocks: 305k Up, 145k Dn, 70k Blocks. Ran 252joints of casing.. Drifted casing with 6. 151 "plastic rabbit. Used Best-o-Life 2000 thread compound on all connections. Pool 6 Drilling Supervisor: Fred Herbert / Scoff Reynolds -- ARCO ALASKA INC CASING TALLY PAGE: 1 of 2 WELL: 1D-11 Kuparuk Unit RIG: Pool 6 CASING DESCRIPTION: 7" 26#, L-80, BTC Date: 10/20/1999 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 ,,, No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 iiii!iiii!~iiii~iiiiiii 26 42,74 51 39,72 76 43,01 101 43.21 126 43,17 151 42.41 176 38.09 2 iiii!i~!ii~!~!!!!!!i!i~i~ 27 42.30 52 42,68 77 42,62 102 42.82 127 41,05 152 42,48 177 39,75 3 i!.!.i!?!::~!::~i~!.i.::.i, 28 42,34 53 43,19 78 39,67 103 42,60 128 42.68 153 42,64 178 43.13 :.:,:.:.:.:,:.:,:.:.:,:.:.:.:.:;;.:.:,;, 4 i!ii?ii!~!~?iiii!! 29 41.01 54 34.98 79 42,69 10,~ 42.64 129 42,33 154 43.16 179 42,70 5 ii!i!iiii~i~!ii!iii!i!i 30 42.67 55 42.63 80 39,91 105 43,17 130 38,30 155 42,18 180 40.00 6 ~??~!ii~i~!i~ii?~! 31 43.01 56 42,67 81 42,62 106 39.89 13, 41.57 156 42,66 181 42,61 ~;.;.;.;.;.;.;.;.;.:.;.;.;-;-;.;.:.:.;.: 7 .ii,i:.i:.!~!~ii.ii,!.ii, 32 42.63 57 42,64 82 43,06 107 42.69 132 43.29 157 38,30 182 42,88 .................... 8 ?!ii!!~!~**~i:i!?:?iii 33 42.65 58 42,66 83 43,21 108 42.62 133 42,63 158 41.38 183 39,21 9 i:::ii.::!::i!~]!~i!.!i!i 34 42,61 59 41,91 84 42.83 109 43.98 134 43,16 159 39,48 184 42.68 lO.!.i.li!~iii!i~i.i.!ii 35 40.11 60 42,63 85 40,51 110 42,60 135 42,04 160 42.43 185 42.90 11 !.!.!.!i!~!~!.!,!.! 36 40.80 61 42,69 86 42.60 111 42,65 136 43.27 161 42,46 186 41,72 .................... 12i~ii!ii!iii!~i~i!ii!!i!ii 37 40.42 62 42.59 87 41,71 112 42.66 137! 42,68 162 42,68 187 38,90 13iiiiiiii~i~ii~iiiiiii 38 43.65 63 43,14 88 42,64 113 40.38 138 42.87 163 41.84 188 43,19 :.:.:.. · .:.;.:.; ...... :.;.;.;. 14.i!i!!i!ii~i~.i.?!!!!i 39 42.60 64 40.79 89 42,66 114 43,21 139 41,58 164 42.65 189 41.47 ..,....,.,...,.......-...-.,.....-...-., 15~!!iii!i~ii~i~i~iiiiiii~!~i!i: 40 42.56 65 42.70 90 42.65 115 42,67 140 41.97 165 42,28 190 42,30 16 i!iiii!i!~ii!ii~.!.iii!i 41 38.13 66 42.84 91 39.28 116 42,68 141 43,06 166 42.69 191 40.30 17 i::i::?:ii~!~(::iiE~?:i::iil 42 42.35 67 39,74 92 38,47 117 39,68 142 40.67 167 41.19 192 42,64 18 iii!iiiii~i!i~ii!i!i!i 43 41.23 68 43.02 93 37.48 118 43,26 143 43,05 168 41,86 193 42,12 19 i!iiiii?!i~iii~i~ii!?iiii 44 40,76 69 42,65 94 42,66 119 37,94 144 40,10 169 43,16 194 42,13 20i.i.i!~iii!i~i~!.i!.i.i 45 42,83 70 42,95 95 43.15 120 42.58 145 41.14 170 42.62 195 37,45 21 ?~iiiii~?~::~i~iii~i 46 42.71 71 42.89 96 42.63 121 42,65 146 42.62 171 43.37 1961 42,75 !. !i{ !.:.:,:. iiii i ~:....,: 22 :::::?:?:::::~i:::::::?:::: 47 43.02 72 42.62 97 42,89 122 39.62 147 36.48 172 43.05 197 42.64 23 iiiiiiii~i~iiiiiii' 48 39.20 73 43.15 98 42,64 123 42,66 148 42,63 173 39,88 198 42.64 '"T'T';';'"'"'"'"'"'"'"'"'"" iiiiiiiii iiiii !ili!ii 42.6 4]. 7 174 42.4 42.7 25 42,63 50 41,37 75 42,62 100 42.73 125 41,24 150 42,10 175 43.12 200 42,18 Tot 1045.08 Tot 1046.33 Tot 1050,92 Tot 1045.89 Tot 1052,93 Tot 1047.62 Tot 1052.45 Tot 1039.13 TOTAL LENGTH THIS PAGE = 8378.35 TOTAL JOINTS THIS PAGE = 200 DIRECTIONS: ARCO ALASKA INC CASING TALLY PAGE: :2 of :2 WELL NUMBER: Kuparuk Unit RIG: Pool 6 7" 26#, L-80, BTC DATE: Column9 Column 10 Column 11 Column 12 Column 13 Column 14 Column 15 Column 16 No Feet No Feet No Feet No! Feet No Feet No Feet No Feet No Feet 201 41.17 226 42,40 251 42.14 276 301 326 351 376 202 42.69 227 39,15 252 40,50 277 302 327 352 377 203 42.81 228 42,62 253 -4-2-;-89278 303 328 353 378 204 39,05 229 42,36 254 4-1--,-,-,-,-,-,-,-~2 279 304 329 354 379 205 41,48 230 42,66 255 48-,-,-,-,-,-,-,-,~2 280 305 330 355 380 206 38,99 231 41,03 256 ~ 281 306 331 356 381 207 40.75 232 42,63 257 -4-2-,-89282 307 332 357 382 208 43,06 233 40.06 258 ~ 283 308 333 358 383 209 41.70 234 42,49 259 ~ 284 309 334, 359 384~ 210 42,41 235 40.28 260 4-T-,-,-,-,-,-,-,-,~4 285 310 335 360 385 211 42.60 236 41.47 261 4-t-.-.-.-.-.-.-.-.~8 286 311! 336 361 386 212 41.18 237 39,95 262 -4-2-R-8 287 312; 337 362 387 213 39.79 238 43,28 263 ~ 288 313; 338 363 388 214 41,73 239 40,23 264 4-2¢~ 289 314 339 364 1389 215 42,23 240 41,10 265 -38-.-.-.-.-.-.-.-.~8 290 315 340 365 390 216 42,03 241 39,66 266 4-2¢~ 291 316 341 366 391 217 43.06 242 40,51 267 292 317 342 367 392 218 43,10 243 38,63 268 293 318 343 368 393 219 41,37 244 39,03 269 :294 319 344 369 394 2201 40.70 245 42,63 270 295 320 345 370 395 2211 39,26 246 42,85 271 !296 321 346 371 396 222! 42,63 247 41,19 272 297 322 347 372 397 2231 41,58 248 42,48 273 298 323 348 373 398 224! 42,60 249 42,08 274 299 324 349 374 399 225! 42.62 250 42,61 275 1300 325 350 375 400 Tot 1040.59 Tot 1033.38 Tot 672.44 Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE -- TOTAL LENGTH = 11124.76 TOTAL JOINTS THIS PAGE = TOTAL JOINTS = 266 Average Jt = 41.82 2746.41 66 DIRECTIONS: ARCO Alaska, Inc. Cementing Details Well Name: 1D-11 Report Date: 10/20/99 Report Number:. 13 Ri(~ Name: Pool 6 AFC No.: AK0026 Field: KRU Casing Size Hole Diameter: I Angle thru KRU: Shoe Depth: I LC Depth: % washout: 7 8.5 I N/A 10564 I 10481 Centralizers State type used, intervals covered and spacing Comments: " I Bow spring centralizer per joint on jt's 1-24. Centralizers installed stop collars on Joint I & 2 Mud Weight: PV(pfior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 9.3 20 17 25 18 Gels before: Gels after. Total Volume Circulated: 9112 718 1099 bbls , ,, Wash 0 Type: Volume: Weight: Comments: ARCO 20 8.4 Spacer 0 Type: Volume: Weight: Comments: ARCO Spacer 40 12.0 Lead Cement 0 Type: Mix wtr temp: No. of Sacks: { Weight: Yield: Comments: .... Additives: Additives: 0.1% DS00, 0.2% D46, 0.3% D65 ...... Displacement 0 Rate(before tail at shoe): I Rate(tail around shoe): Str. Wt. Up: Comments: 7 7 305 Reciprocation length: Reciprocation speed: Sir. Wt. Down: 20 10 fpm 145 , , Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 401.4 4O3 Calculated top of cement: CP: Bumped plug: Floats held: 9565 Date:lO/20/99 Yes Ye~ Time:21:40 Remarks:Casing went to Bttm wi no probems. Circ & cond @ 7 bpm wi I to I returns. Reclp casing until 10 bbls left on displacement. Slow rate to 3 bpm wi 10 bbls left on displacement. Full returns thru cement job. ,, Cement Company: I Rig Contractor: I ApprOved By: DS I POOL I Fred Herbert ARCO Alaska, Inc. Casing Detail 9-5/8" surface caSing WELL: 1 D- 11 DATE: ######## Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES · # ITEMS cOMpLETE DEscRIPTION OF EQUIPMENT RUN " LENGTH DEPTH ,,, Pool 6 RT to LDS = 34.70' TOPS 9-5/8"" Landing Joint (RKB) 34.70 9-5/8" FMC GEN V FLUTED MANDREL HANGER 1.60 34.70 jts 3-1:~6 9-5/8", 40#, L-g0 BTC-M~)D (174 jts) 6696.28 36.30 Gemeco Float Collar 1.53 6732.58 jts 1-2 9-5/8", 40#, L-80 BTC-MOD (2 jts) 78.67 6734.11 Gemeco Float Shoe 1.71 6812.78 BTM OF SHOE @ 6814.49 ,,, 6814.49 ,,, " TD of 12'-1/4" hole = 6830'MD Leaving 16' of rat hole 22 Gemeco Bow Spring CENTRALIZERS 1/jr on its 1-22 ,,, '1 Gemeco Bow Spring CENTRALIZER on jt 176 Run 176 jts. Leave 4 jts in the pipe shed. ,., ,,, I .. .. . "Remarks: Strin~ Weights with BloCks: xxxk Up, xxxk Dn' xxk Blocks. Ran xxx joints of casing, Drifted casing with 8.5" plastic rabbit. Used Best-o-Life 2000 thread compound on all connections. ARCO ALASKA INC CASING TALLY PAGE: 1 of 2 WELL: Kuparuk Unit RIG: Pool 6 TUBING DESCRIPTION: 9-5/8" 40#, L-80, BTC, R3, Class A DATE: ####### · , Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet II 1 39.23 26 37.91 51 38,68 76 37,04 .101 39.07 .126 38.62 .15.1 38.00 .176 37.55 2 39.34 27 37.40 52 38.71 77 39,41 .102 38.93 .127 39.13 .152 38,78 3 39.33 28 37.51 53 37.64 78 37.90 .103 36.44 .128 38.93 .153 39.15 5 39.23 30 36.75 55 40.59 80 39.12 .105 38.25 .130 38.86 .155 35.47 6 37.52 3.1 39,48 26 37,50 81 38,91 .106 39.21 .13.1 37,42 .126 39.30 .18.1 7 39.17 32. 37,93 27 38,8o 82. 37,63 .107 39.23 .132. 39,25 .127 34.34 .182 8 38.67 33 39.24 58 39.29 83 39.40 .108 37.83 .133 39.21 .158 37.19 .183 @ 38.52 34 36.55 59 39.25 84 37.67 .109 37.52 .134 39.23 .15§ 37.73 .184 10 35.30 35 38.23 60 39.23 85 38.97 .1.10 39.22 .135 39.22 .160 39.32 '185 '1.1 38.23 36 39.28 61 37.91 86 38.90 .1.1.1 38.87 .136 38.70 .16.1 39.67 .186 .12. 38.96 37 39.14 62. 40.65 87 39.40 .1.1:::) 39.12 .137 38.82 .162. 36.17 .187 .13 37,45 38 39.09 63 38.05 88 39.11 .1.13 39.39 .138 39.23 .183 38.72 .188 .14 36,69 3@ 38.89 64 38.94 8@ 36.60 .1.14 38.77 .139 35,35 .16,~ 39.56 .189 .15 38.67 40 39.03 65 37.72 90 38.10 .1.15 37.42 '140 39,12 .165 39.11 .190 ,,, 6 38.66 4.1 39.88 66 39.13 9.1 38.02 .1.16 40.04 .14.1 37.46 .166 38.41 .19.1 7 37.78 42 39.34 67 38.89 92 37.47 .1.17 36.99 .142 39.23 .167 39.31 .192 8 39.58 43 38.33 68 38.96 93 39,19 .1.18 39.22 .143 38.79 .168 39.25 .193 .19 36.21 44 37.35 69 39.26 94 38,82 .1.19 39.12 .144 39.12 .169 '39.50 .194 2.0 37.80 45 37.89 70 38.98 @5 39.38 .120 39.23 145 39.14 170 38.89 .195 1 37.54 46 39.23 7.1 37.73 96 38.93 .12.1 38.59 .146 39.13 .17.1 38.64 .196 2.2 37.90 47 35.94 72. 39.14 97 38,79 .122 38.33 .147 39.23 .172 39.23 .197 2.3 37.30 48 39.12 73 34.90 98 34.36 .12.3 39.14 .148 37.19 .173 39.11 ~98 ,, 2.4 39.43 4@ 38.93 74 38.93 99 39.11 .12.4 39.94 .149 38.53 .174 41.02 .199 2.5 39.42 50 38.17 75 38.57 .100 34.18 .125 39.12 150 37.43 .175 38.92 2.00 Tot 957.2.0 Tot 960,02 Tot 966.58 Tot 955.93 Tot 968.13 Tot 965.72 Tot 963.72 Tot 193.66 TOTAL LENGTH THIS PAGE = 6930.96 TOTAL JOINTS THIS PAGE = 180 DIRECTIONS: Jts 128,129,130 did not drift ARCO Alaska, Inc. Cementing Details Well Name: 1D-11 Report Date: 10/16/99 Report Number: 1 Rig Name: Pool 6 AFC No.: AK0026 Field: Kuparuk River Unit Centralizers State type used, intervals covered and spacing Comments: · Gemeco bowsprings 22 Bowspring cent. l~t on first 22 its. I bowspring cent on it. #176 Mud Weight: PV(prior cond): Pr(after cond): YP(prior cond): YP(after cond): Comments: 10 55 25 70 15 Gels before: Gels after. Total Volume Circulated: 21/80 4/6 1500 bbl Wash 0 Type: Volume: Weight: Comments: ARCO 22 8.3 Spacer 0 Type: Volume: Wei'ght: Comments: ARCO Spacer 50 10.5 Lead Cement 0 Type: I Mix wtr temp: No. of Sacks: Weight: Yield: Comments: AS III LiteI 70 760 10.5 4.44 Additives: 30% D53, .6% D46,1.5% D79, '1.5% S1, 50% D124, 9% D44 Tall Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: G 70 710 15.8 1.17 DS had difficulty mixing tall due to downspout In tub Additives: plugging. .2% D46, .3% D65,1% S1 Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 5.7 5.7 310 .. i Reciprocation length: Reciprocation speed: Str. Wt. Down: 130 30 140 Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 491 493 i , Calculated top of cement:. CP: Bumped plug: Floats held: Surfa ce Date: 10/14/99 No Yes Time:20:25 Remarks:Had to shut down cementing operation while pumping lead for failures In the Pool 6 cmt line. Shut down times were 15 minutes and 10 minutes. RIH wi 1" to 1020'. Performed top Job wi 194 bbl AS III lite ... Cement Company: DS IRig Contractor: POOL IApproved By: G.R. Whitlock/S.D. Reynolds DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Permit to Drill No. 1990720 Well Name/No. KUPARUK RIV UNIT 1D-11 Operator PHILLIPS ALASKA INC. APl No. 50-029-22946-00-00 MD 11234 TVD 6719 Completion Date 10/26/1999 Completion Status 1WINJ Current Status 1WINJ UIC Y _- 7 £~'~7 ~-_Z-2-- ~F~_-~ . VZ-~ -~ d ~ ....... ~ ~'~--. _£' ~. ~~5~ '~ ~'__£2~ .~£. ' ................................ REQUIRED INFORMATION Mud Log N_~o Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Lo[l/ Interval Data Digital Di[lital Lo[l Log Run OH / Dataset Type Media Format Name Scale Media No Start Stop CH Received Number Comments ....................................... -~:- b-G~,)-E~P,'~-~6 ................ ~5- ............... Fi-N-~ - -~4':~'9~ ....... 672o- -'6H- ...... :~/~8)2000 L.I~' DGR/CTN/SLD-TVD 125 FINAL 6338 6720 OH 3/28/2000 .J.,-"'"'UsIT ,2.) ~,~ <{ff 5 FINAL 9000 10540 CH 11/23/1999 BL(C) 10/23/99 DGR/EWR-MD 25 FINAL 6814 t 1234 OH 3/28/2000 RVY RPT 0 11234 OH 11/12/1999 SPERRY . L~'/ DGR/CTN/SLD-MD 125 FINAL 10531 10564 OH 3/28/2000 J.~,'~" GR/CCL 5 FINAL 10250 11080 CH 12/8/1999 11/19/99 ,,E'/''' INJP-PSP 5 FINAL 10790 11010 CH 9/15/2000 UIC ~ CBL ~§.~, qC~ 5 FINAL 10250 11080 CH 1/11/2000 BL(C) 11/19/99 ~ GR/CCL-PSP 5 FINAL 50 10500 CH 8/4/2(~00 Interval Dataset Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/~ Daily History Received? ~¢ N .Chips-Reevqv .efl?---~--..~/N Formation Tops Receuived? ~ N A n aly. sis-R.e~e[ved?-'-'--Y'/N Comments: Permit to Drill No. 1990720 DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Well Name/No. KUPARUK RIV UNIT 1D-11 Operator PHILL1PS ALASKA INC. AP1 No. 50-029-22946-00-00 MD 11234 TVD 6719 Completion Date 10/26/1999 Completion Status 1WINJ Current Status 1WINJ UIC Y Compliance Reviewed By: Date: Annular Disvosal durin the second quarter c r2001' h(1) h(2) 'h(3) ' Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date / 1C-17 33139 100 0 33239 0 33239 May01 Jun01 1C-133, 1C-121, 1C-123, 1C-127 ::, 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N-314, 1J-03 16904 100 0 17004 13120 30124 Mar 01 May 01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 18034 100 0 18134 0 18134 May 01 Jun 01 CD2-24 1C-27 3533 100 0 3633 0 3633 Jun 01 Jun 01 1C-127 Total Volumes into Annuli for which Dis ~osal Authorization Expired during the second quarter 2001' ~ ' Total Voiume ~ ~ Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume ,Status of Annulus ~ 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 ' 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- ~ 2000 35, CD1-32, CD1-24, CD1-22A, CD1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD 1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down CD1-34 only - CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CD1-NQ1 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 31,2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, Second Quarter, 2001 - REVISED Dear Ms. Mahan: Please find attached the revised report with the volumes disposed into surface casing by production casing annuli during the second quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the second quarter of 2001. We have revised the amount for CD2-42 because the original manifest incorrectly reported the CD2-24 annulus used for the disposal. Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader PM/skad CC; Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Annular Dis 9osal durin the second quarter o ~ 2001: h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume .Quarter Total Total Date Date 1C-17 33139 100 0 33239 0 33239 May01 JunOl 1c-133, ic-121, IC-I23, IC-127 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N-314, ,,. 1J-03 16904 100 0 17004 13120 30124 Mar 01 May 01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 .... CD2-42 18034 100 0 18134 0 18134 May 01 Jun 01 CD2.24 1C-27 3533 100 0 3633 0 3633 Jun 01 Jun 01 1C-127 , , Total Volumes into Annuli ~or which Disposal Authorization Expired during the second quarter 2001: · Total Voiume ' Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus · 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 ID-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- 2000 35, CD1-32, CD 1-24, CD1-22A, CD1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD 1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down CD1-34 only CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CD 1-NQ 1 ?oo -o/7 ° ° ITl PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 17, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, Second Quarter, 2001 Dear Ms. Mahan: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the second quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the second quarter of 2001. Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader RECEIVED PM/skad JUL 1 9 7001 CC: Marry Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files Alaska 0il & Gas Cons. Commission Anchorage Annular Dis ~osal durin the second quarter o 72001: h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-17 33139 100 0 33239 0 33239 May 01 Jun 01 1c-133, 1c-121, 1c-123, 1c-127 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N-314, 1J-03 16904 100 0 17004 13120 30124 Mar01 May01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 16902 100 0 17002 0 17002 May 01 Jun, 01 CD2-24 1C-27 3533 100 0 3633 0 3633 Jun 01 Jun 01 1C-127 Total Volumes into AnnuIi Cor which Disposal Authorization Expired during the second quarter 2001: Total Voiume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus ID-II 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- 2000 35, CD1-32, CD1-24, CD1-22A, CD1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD 1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down CD1-34 only CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CD1-NQ1 -' O 9/13/00 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 510 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia CD 1D-11 fl I ~.. INJECTION PROFILE 000901 I 1 2K-15 -- LEAK DETECTION LOG 000903 I 1 2V-14 PRODUCTION PROFILE 000907 I 1 3B-01 IA, t ~. INJECTION PROFILE 000831 I 1 3F-17 PROD PROFILE/GAS LIFT SURVEY 000904 I 1 3Q-15 tJM ¢.. INJECTION PROFILE 000902 I 1 2N-345 20101 CNTD l:t-- ~11 ~ 000~2~ I ~ ~ nrPr ITIE~ sip SlGNE DATE: ease sign and return one copy of this transmittal to Sherrie at the above address or fax to (907} 561-8317. ~Iq~WR~,/'~'t~. 7/27/00 Schlumberger NO. 367 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie comPany: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 1D- 11 GAMMA RAY/CCL LOG W/PSP 000'716 I 1 1R-02 PRODUCTION PROFILE 000718 I 1 2A-13 PRODUCTION PROFILE 000713 I 1 3F-19 PRODUCTION PROFILE 000717 I I ........... R CEJVj'D SIGNED:~~~ DATE: AUG 0 4 2000 Alaska Oil & Gas 60,qs. uommissi0n Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 25, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kupamk Area Annular Injection, Second Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the second quarter of 2000, as well as total-volumes injected into annuli for which injection authorization expired during the second quarter of 2000. Annular Injection during the second quarter of 2000: h(1)' h(2) ' h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 2N-341 20406 100 0 20506 0 20506 2L-313 4640 100 0 4740 12533 17273 CD1-40 108 100 0 208 32669 32877 CD1-23 16751 100 0 16851 17135 33986 / CDI-16 25 0 0 25 29025 29050 ~ CD1-32 82 100 0 182 33331 33513 5 CD1-38 11056 100 0 11156 9164 20320 CD1-27 32333 100 0 32433 381 32814 ,. 1L-28 5853 100 0 5953 3984 9937 ~ 1D-11 135 100 0 235 0 235 ? 1D-14 1337.6 100 0 1437.6 0 1437.6 / CD1-25 8141 100 0 8241 386 8627 ~ CD1-34 278 100 0 378 0 378 WELL LOG TRANSMITTAL To: State of Alaska March 28, 2000 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. qq, C~J' ~)- Anchorage, Alaska 99501 ~ RE: MWD Formation Evaluation Logs 1D-11, AK-MM-90162 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention of 2 Tun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way,/tiS, Anchorage, AK 99518 ID-Il: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22946-00 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22946-00 2"x 5"MD Neutron & Density Logs: 50-029-22946-00 2"x 5" TVD Neutron & Density Logs: 50-029-22946-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia RECElVfJ) Alaska Oil & Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 995!8 · 907-273-3500 · Fax: 907-273-3535 A Halliburton Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _X Annular Injection 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 586' FNL, 601' FEL, Sec. 23, T11 N, R10E, UM At top of productive interval 2565' FNL, 2052' FWL, Sec. 19, T11 N, R11 E, UM At effective depth At total depth 2627' FNL, 2322' FWL, Sec. 19, T11 N, R11 E, UM 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service __X 6. Datum elevation (DF or KB feet) RKB 105' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1D-11 9. Permitnumber/approvalnumber 199-72 10. APInumber 50-029-22946 11. Field / Pool Kuparuk River Field / Kuparuk River Pool 12. Present well condition summary Total depth: measured 11234 true vertical 6719 Effective depth: measured 11166 true vertical 6682 Casing Length Size Conductor 80' 16" Surface 6779' 9.625" Production 10534' 7" Liner 833' 4.5" feet Plugs (measured) feet feet Junk (measured) feet Cemented 9 cu yds High Early 760 sx AS III Lite, 710 sx Class G 220 sx Class G 140 sx Class G Measured Depth True vertical Depth 115' 115' 6814' 4396' 10565' 6355' 11234' 6719' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 10960'- 10980', 10907'-10927' 6568'-6579', 6539'-6550' 4.5", 12.6#, L-80 @ 10420' Baker SLZXP LT packer @ 10401' MAR 28 2000 13. Attachments Description summary of proposal__ Detailed operations program __ BOP sketch __ Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic __ XI 14. Estimated date for commencing operation March 31,2000 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Suspended __ Service __X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,-- E-, ~"~ Title: Drilling Engineering Supervisor G. c. Alvord FOR COMMISSION USE ONLY Questions? Carl Chip Alvord 265-6120 Date -~lZ7/"0 Prepared by Sharon Allsup-Drake "~.(2 ~" ~1 ~ Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test__ Subsequent form required,.,,(~r ORIGINAL SIGNED-BY Approved by order of the Commission Robert N. Chdstenson ,~ ,.,:ommissioner Form 10-403 Rev 06/15/88 · Approval SUBMIT IN TRIPLICATE ARCO Alaska, Inc. Casing Detail 7" intermediate casing Subsidiary of Atlantic Richfield Company WELL: 1 D- 11 Date: 10/20/1999 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Pool 6 RT to LDS = 30,36' TOPS 7" Landing Joint (RKB) 30,36 7" FMC GEN V FLUTED MANDREL HANGER 1,69 30,36 its 3-252 7", 26#, L-80 BTC-MOD (250 jts) 10449.23 32.05 Gemeco Float Collar 1.31 10481.28 jts 1-2 7". 26#. L-80 BTC-MOD (2 jts) 80,54 10482,59 Gemeco Float Shoe 1,48 10563,13 BTM OF SHOE @ 10564,61 10564,61 TD of 8-1/2" hole = 10572' MD Leaving 8' of rat hole 24 Gemeco Bow Spring CENTRALIZERS l/it on jts 1-24 1 centralizer on stop collars on jts 1 & 2 22 centralizers on collars jts 3-24 Run 252 jts. Leave 14 jts in the pipe shed. C!~ ,.'_~ G~s" ..... "' .... '"' Remarks: String Weights with Blocks: 305k Up. 145k Dn. 70k Blocks. Ran 252joints of casing. Drifted casing with 6. 151" plastic rabbit. Used Best-o-Life 2000 thread compound on all connections. Pool 6 Drilling Supervisor: Fred Herbert / Scott Reynolds ARCO Alaska, Inc. Cementing Details Well Name: 1D-11 Report Date: 10/20/99 Report Number: 13 Riq Name: Pool 6 AFC No.: AK0026 Field: KRU Casing Size Hole Diameter: Angle thru KRU: [ Shoe Depth: I LC Depth: % washout: 7 8.5 N/AI 10564I 10481 Centralizers State type used, intervals covered and spacing Comments: 1 Bow spring centralizer per joint on jt's 1-24. Centralizers installed stop collars on joint 1 & 2 Mud Weight: PV(pdor cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 9.3 20 17 25 18 Gels before: Gels after:. Total Volume Circulated: 9/12 7/8 1099 bbls Wash 0 Type: Volume: Weight: Comments: ARCO 20 8.4 Spacer 0 Type: Volume: Weight: Comments: ARCO Spacer 40 12.0 Lead Cement 0 Type: I Mix wtr temp: No. of Sacks: Weight: Yield: Comments: I Additives: Tail Cement 0 Type: I Mix wtr temp: No. of Sacks: Weight: Yield: Comments: GI 70 220 15.8 1.16 Additives: 0.1% D800, 0.2% D46, 0.3% D65 Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 7 7 305 Reciprocation length: !Reciprocation speed: Str. Wt. Down: 20 ; 10 fpm 145 Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 401.4 403 Calculated top of cement: CP: Bumped plug: I Floats held: 9565 Date:l 0/20/99 YesI Yes Time:21:40 Remarks:Casing went to Bttm w/no probems. Circ & cond @ 7 bpm wi I to I returns. Recip casing until 10 bbls left on displacement. Slow rate to 3 bpm wi 10 bbls left on displacement. Full returns thru cement job. Cement Company: I Rig Contractor: Approved By: DS I POOL Fred Herbert RECEIVED MAR 2 8 2000 Alaska Oil & Gas C~s. Com..nJ~Jor, Anchorage ARCO Alaska, Inc, Casing Detail 9-5/8" surface casing Subsidiary of Atlantic Richfield Company WELL: 1D-11 DATE: ######## 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Pool 6 RT to LDS = 34,70' TOPS 9-5/8" Landing Joint (RKB) 34.70 9-5/8" FMC GEN V FLUTED MANDREL HANGER 1.50 34.70 jts 3-176 9-5/8", 40#, L-80 BTC-MOD (174 jts) 6696.28 36.30 Gemeco Float Collar 1.53 6732.58 jts 1-2 9-5/8", 40#, L-80 BTC-MOD (2 jts) 78.67 6734.11 Gemeco Float Shoe 1.71 6812.78 BTM OF SHOE @ 6814.49 6814.49 TD of 12-1/4" hole -- 6830'MD Leaving 16' of rat hole 22 Gemeco Bow Spring CENTRALIZERS 1/jt on jts 1-22 1 Gemeco Bow Spring CENTRALIZER on jt 176 Run 176 jts. Leave 4 jts in the pipe shed. REr !v n P, 2000 Alaska 0il & Gas Cons. (~ommlss or, Remorks: String Weights with Blocks: xxxk Up, xxxk Dh, xxk Blocks. Ron xxx joints of cosing. Drifted cosing with 8.5" plosfic robbif. Used Best-o-Life 2000 thread compound on oll connections. ARCO Alaska, Inc. Cementing Details Well Name: 1D-11 Report Date: 10/16/99 Report Number: 1 Rig Name: Pool 6 AFC No.: AK0026 Field: Kuparuk River Unit Centralizers State type used, intervals covered and spacing Comments: 22 Sowspring cent. l/lit on first 22 jts. 1 bowspring cent on jt. #176 Gemeco bowsprings Mud Weight: PV(pdor cond): PV(after cond): I YP(prior cond): YP(after cond): Comments: 10 55 25I 70 15 Gels before: Gels after. Total Volume Circulated: 21/80 4/6 1500 bbl Wash 0 Type: Volume: Weight: Comments: ARCO 22 8.3 Spacer 0 Type: Volume: Weight: Comments: ARCO Spacer 50 10.5 Lead Cement 0 Type: I Mixwtrtemp: No. of Sacks:I Weight'. Yield: Comments: AS III Lite 70 760 10.5 4.44 Additives: 30% D53, .6% D46, 1.5% D79, 1.5% Sl, 50% D124, 9% D44 Comments: GI I I 170 710 15.8 1.17 DS had difficulty mixing tail due to downspout in tub Additives: plugging. .2% D46, .3% D65, 1% S1 Displacement 0 Rate(before tail at shoe): iRate(tail around shoe): Str. Wt. Up: Comments: 5.7 5.7 310 Reciprocation length: Reciprocation speed: Str. Wt. Down: 30 30 140 Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 491 493 Calculated top of cement: CP: Bumped plug: I Floats held: Surface Date:l 0/14/99 No[ Yes Time:20:25 Remarks:Had to shut down cementing operation while pumping lead for failures in the Pool 6 cmt line. Shut down times were 15 minutes and 10 minutes. RIH w/ 1" to 1020'. Performed top job wi 194 bbl AS III lite Cement Company: I Rig Contractor: Approved By: DS I POOL G.R. Whitlock/S.D. Reynolds CASING TEST and FORMATION INTEGRITY TEST Well Name: 1 D-11 Reason(s) for test: Date: 10/16/99 Supervisor: Whitlock/Reynolds [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-5/8" 40#, L-80 BTC Casing Setting Depth: 6,814' TMD Hole Depth: 4,396' TVD Mud Weight: 8.5 ppg Length of Open Hole Section: 6,850' TMD 4,414' TVD 36' EMW = Leak-off Press. + Mud Weight = 1,220 psi 0.052 x TVD 0.052 x 4,414' EMW for open hole section = 13.8 ppg + 8.5 ppg Pump output = 0.0846 bps Fluid Pumped = 4.2 bbl 3,200 psi 3,100 psi 3,000 psi 2,900 psi 2,800 psi 2,700 psi 2,600 psi 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1,900 psi 1,800 psi 1.700 psi 1,600 psi 1,500 psi 1,400 psi 1,300 psi 1,200 psi 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE ~ ................ ~ ................. ~ ~ ................ r ............... ...................... .0_.?_tk..s_ ......... _0___p_?_~ ............................ _0___s_t. _k.s____ ..................... .S_ .s__tk_ ?_ ....... _!~_0__e_s_! ........................ .S___s_t. _k.s____ L_ !6_.o.._p..s.L _~ ..................... _l_.O_.s__t.k_.s_ ....... _4j__o.p_.s.! ......................... _l__O___s_t.k..s._ j __. A6_.o_. _p_sj_ __ ! .................... _t _S_.s__t.k_.s_ ...... _6_~_5___p_sj ........................ _!_s_ __s_tk_ .s___ L_ .6_ .t .0___p. _sL__i ..................... _2..0_ .s_ _t.k_s_ ...... §.S..O_p..s.! ........................ _2_ _O_s_t.k..s. _. j... AS_O_. _p. _s_L _ j ..................... .2_§__s_.t.k_s_ ...... .t,__oz_o.__p._sl ....................... _2_.s_._s_tk..s_ j_..! ,_ta_.o__.p__s.Lj ..................... _~__0__s__t.k_.s_ ..... .!,__2_2__o__p_?_L ...................... ~ .0..?.t.k. ?... j...! ,.~.L0_..p..s_! ~ ..................... ~._S___s.t..k_.s. ..... ! ,.O_.4..5__p_.s_ '_,_ ....................... ~ S._.s_ t..k.?.__j...! ,.S__~..O._p_s. . ..................... _4__0__s__t_k__s_ ..... !,__o&s___p_?)_ ....................... _4__0__?_t_k__s___j___! ,_7. _2.0__ p_ ?. L: ..................... _4_ _5_ _s_ _t_k_ ?_ ..... .l_,..e~_p._s). ...................... .4_ _5_ _ _s_t_k_s_ _ _ ] _ _ 3_, _~_ _S.O_ _ _p_s! _] 50stks ~ 1,010psi , 50stks .................................................................... ~ 60 stks i 65 stks ..................................................................... ? ............... ................. I, , ! , .................................................................................... .................................................. I I SHUT IN TIME SHUT IN PRESSURE 0.0 min ................ ~ ................ · ................. ~ r ................ r ............... 1.0 min ', ................................................................................................ -. ..... r ............... I ............... ---1 ._ _2:_o__.m_;_n____:. ............... ~__BgZs__p_.s., , SHUT IN TIME: SHUT IN PRESSURE.__3_._o__.m_j.n____[ ............... j__~,9_!s__p_~. .... !:9_..m_L~___j ................ L__~.s_.o___p_s_!___j ~____5_.p__mj.n____,: ............... j__B_o.!o__p__s_i__] .__.2_:9__m._?.___L ............... L__9_4__o__p_s_L__j .___6:_o___m_j_n___[ ............... j__~,gZ_O__R_SZ_j .... .s_:9_.?_Ln.__l ............... j___.s__s_7_.p_.s_.,.__j .___7:_o___m_j_n____L ............... j__~:g_6_s_p_s.,__j .... J:9_..m_L"___.,' ............... i_ __.9_3_5_.p_.s_ ! ___ j L___8:_°__m_j_n____[ ............... j __ _3_ :9_6_°__ P_S_L j .... _5_- 9_..m_Ln___i ............... L_.9_~.s_.p_s_!___j [____9:_°___m_j_n____L ............... L__!°__._°_m_:_n___[ ............... j__~,9_6_°__R_s_:_j [ _ 1.5_ :.0_ __m_ J_n___ L ............... j __~,_9_6_0__ P__S_t _ j [___2_O__.o__DLn___[ ............... j ___s_,__o__6_o__ p_ _s_,__ j ' 25.0 mm : ] _3_,__0_6__0_ p__sj_ j __3.o__..o__.m__,_n___~ ................ L_.3_,_o._6.o__p__s_;_.i NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: KRU 1 D-11 Reason(s) for test: Date: 10/19/99 Supervisor: S.D. REYNOLDS [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-5/8", 40#, L-80 BTC Casing Setting Depth: 6,814' TMD Hole Depth: 4,396' TVD Mud Weight: 9.2 ppg Length of Open Hole Section: 10,494' TMD 6,319' TVD 3,680' EMW = Leak-off Press. + Mud Weight = 975 psi + 9.2 ppg 0.052 x TVD o.os2 x 6,319' EMW for open hole section = 12.2 ppg Pump output = 0.0846 bps Fluid Pumped = 6.8 bbl TIME LINE 1,200 psi 1,1 O0 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 1 O0 psi 0 psi · -e-- LEAK-OFF TEST ia--CASING TEST ::.,., LOT SHUT IN TIME ~-- CASING TEST SHUT IN TIME t TIME LINE STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE ...................... _0__s__tk_.s- ......... _0___p__s_~ ............................ _0_s_t_k_s_ ......... _0_p__s.i_ ..... ..................... _5__s__t.k_.s_ ......... Eo_._p_s.! ..... .................... !_O__s__tk_.s_ ...... !!_O___P_S_! ........................................................ .................... _~A_s__t_k_.s_ ...... !6_.o__p__s__, ......................................................... ..................... _2__0__s__t_k_.s_ ...... .2__4__0_._p_s_, ......................................................... .................... _2._5__s__t_k__s_ ....... ~9_.p_~_~ .... ..................... _~__0__s__t_k__s_ ...... _4_ ! _0_ ~_ _s_, ........................................................ i ................~ ............... ,1. ................. ,.i i. ~1 35 stks 520 psi ................................................. .................... _5__0__s__t_k__s_ ...... _8_.2_0_._p.s__~ ..................... _5_ _5__s__t_k__s_ ...... ~.2_.0_.p_.s__, .... .................... _Eo__s__t_k_s_ ...... ~Z§_.P_.S__~ .... .................... _6..s__s__tk__s_ ...... ~Z_5__p_.sj .... .................... Z.O_ .s!k_s_ ...... &5_ _0_ _p_ _s_ i .................... Z.S_~_tk__~_ ...... _9__2__°___P~L__ .................... _8_.O_.s__t.k__s_ ..... &2__o__p__s_L__ I i i ................................. i. ~ ................. ,.i i i ! , ! ! , ! SHUT IN TIME SHUT IN PRESSURE '---EiS-~i-~ ......................... -~-;~i ..... ! 1.0 min , i ................ .-~ ................................ ! ................................... ! r ................ r ............... ,-i ................. ..~ , ' ' 2.0 min SHUT IN TIME i SHUT IN PRESSURE 3.0 min ................ ~ ............... ~ ................. w ~ ................ ~ ............... ~ ............... .... .°_-P__.m_Ln___ ,~ ............... i___.9.2_.°_ppL__i .___9:9___m j?_ ..................................... , 1.0min ~ i 575 psi i ~ 5.0min ~ ............................................................................... 2.0min : i 540 psi i 6.0m~n ., ~ ........... ~ .... t ............... , ............. :---I ~ .......... -,- ..................... , ................. 1 ! 3.0 mln ! i 520 psi J L 7.0 mln , j ................................................................ I ............... I ................. , 4.0min .,' i 500 psi j ' 8.0m~n , , ................................................ "'---E~-~l-5---t ............... .... Z:_°_..m_!.n___]L ............... j____4__e__°__P_.s_L ] 8.0min : ! 475ps~ ! i ................ .1_ ............... ,,t ................. ~ 9.0min , : 475 psi : __ J__o_: _o___m_ Ln__.: ................ i____4_Z_S__p__s_,___ ,: 10.0 mln , , . ................ ~. ............... ..i ................. ..i 15.0 min ................ 1. ............... J ................. i 20.0 mln , , 25.0 mln : , , 30.0 mln NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 1D-11 Date: 3/22/00 Supervisor: Overstreet/Winfree Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-5/8" 40#, L-80 BTC Casing Setting Depth: 6,814' TMD 4,396' TVD Hole Depth: 6,850' TMD 4,414' TVD Mud Weight: 6.9 ppg Length of Open Hole Section: 36' EMW = Leak-off Press. + Mud Weight 0.052 x TVD = 1,600 psi + 6.9 ppg 0.052 x 4,414' EMW for open hole section = 13.9 ppg Pump output = 0.1000 bps Fluid Pumped = 5.0 bbl 3,200 psi 3,100 psi 3,000 psi 2,900 psi 2,800 psi 2,700 psi 2,600 psi 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1,900 psi 1,800 psi 1,700 psi 1,600 psi 1,,500 psi 1,400 psi 1,300 psi 1,200 psi 1.100 psi 1.000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 1 O0 psi 0 psi STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE . ................ .~ ................ .~ ................. .~ . ................. ~. ............... .~ ................. ...................... _O_.s__t.k_.s_ ....... &O__O_p_s_! ......................... _o_._s_t.k__s___j ..... _o__R_s! .... ...................... .5..s..t.k._s. ....... ~_o_.o_.p.sj .......................... _E __s_t. _k.s_ _i.._ !6__0__ _p_s__i._ ...................... .8_.s__t.k_.s_ ....... &E_o_~! ......................... j__o___s_t.k_.s___i___Ae__o___p__s_L__ ..................... !.~_.s__t.k_.s_ ..... !,__2_o__o___p__s_,_ ....................... _2__o___s_t_k_.s___i___AE.o_._p._s_L_j ..................... _t _S_.s__t.k..s_ ..... J_,_ _~_0_ _0_ _ _p_ _s_,_ ....................... _2__E __~_t.k. ~ __]__ J_,__t_o.o.. p..~.L ..................... _2__O_.s_.t.k_.s_ ..... !,_ _4_s__o__.p__s_,__. ..................... _2_ _3_s_ _t.k_s_ ..... !,__5_o__o__R_s_t_~ 25 stks 1,550 psi , ! ................ J .................................. 28 stks 1,550 psi ..................... .~..o__s._t.k..s. ..... !,._sAo..p..s_L. .................... _~__~__s__t_k__s_ ..... .b__6_o__o__p__sL_ .................... .~..S._s._t_k__s_ ..... !,._6.0..O___R_s&. .................... _~__~__s__t_k__s_ ..... .l_,._s_s__o__p__sL_' .................... .4__O__s._t_k__s_ ..... !,._s.o..o__R.S]_- .................... _4__~__s__t_k__s_ ..... _!,._s.o__o__p__sk_. .................... .4_ _S__s._t.k_.s_ ..... J_,_.s.o_.o._p_.sL_' .................... _4__~__s__t_k__s_ ..... _t,__s_o_.o__p__sk_. 50 stks 1,500 psi .................................................... ..................................................................................... .................... ]_o___s_t_k__s___j__.l_,_~j.O__R.S_L i ..................... ~ .s._.s_t.k._s.__j_. J_,_§.l_.O__ R .s_' ..................... _4__O___s_t_k__s___j__ J_,__7. _~.°__ p_s_L_, .................... _4__s___s_Lk__s___j__ J_,.9..s.°._ P_.S_L ~ 50 stks ! 2,170 psi ................. i" ............... '1 i 55stks i 2,400 psi ................. ................. ! __ _7_ _0_ __s_t_k_ _s__ _ L _3_, _1_ _0_0_ _ _P_ _s j_ _. I ................................. I .................. ................................. i .................. , [ ................ r ............... i .................. , , I ~ SHUT IN TIME SHUT IN PRESSURE i- ................................................. · -i ~ 1.0min i 3,080 psi i ................................. i __ .3_, _0._7.5_ _ .p__s.i , 7.0mln j j 3,065pm i ,~ ................................ I ................. I ,____e_._o___m_ j_n____L ............... .,, __ _3_, _0_6_ _0_ _ p_ _s j_ _ ,., k___P:_°___m_ J.n____k ............... j__ ] :9_ _6_°___p__s_:_ j L__~_o_:_o___m_ J_n___L ............... J__],9_6_P_P__Sj__j k__!_5_:_°___m_J?___[ ............... j__~, 9_6__o__p__s_:_j L__2_°_:_°___m_j_n___k ............... j___3_:p__6p_ P__S_,__j 25.0 m,n i ~ _3_,_9__6_0_ _P_?_L i ,_ _ _3_o_ :_o_ __m_ j_n__ j ................ L__s_:_o_6__o__R_S_L j NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY To: WELL LOG TRANSMFFTAL State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs March 21, 2000 1D-11, AK-MM-90162 1 LDWG formatted Disc with verification listing. API#: 50-029-22946-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSM1TF~ LETTER TO'THE ATTENTION OF: Sperry-Sun Drilling Service Atto: Jan Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 R CEIV£D Alaska Oil & Gas uons. uommt~$ion · ~ch0rag~ 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 A Halliburton Company 1/4/00 Schlumberger NO. 121081 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color ' Well Job # Log Description Date BL Sepia Print 1D-11 99464 CBL/GR/CCL 991119 I J/~,~ 11 ZOO0 SIGN ransmlttal DATE: ,qadu~Oil & Gas Coos. ComPri Please s,gn and return one copy to Sherrie at the above address or fax to (907) 561-8317~~ou. AAI ... I D ~ l \ 1c=:t9~o12- \ \) -\ \. '-\. dò4-ò-\ \ \b- \\ L ;)... ðù4-ò \;; HEClIANICAL INTEGRITY REPORT RIG RELEASE: t'C»)81'19 1°/ Ll>J"l'1 OPER & FIELD "TELL NUMBER Af\ , ~ù tJJ-I\ \~9-o72. . SPUD DATE: Z:Jc.~ Casing:':}" I-,go Shoe: JoS""-bS MD TVD, DV: ,:z.., b~ TO' Liner: -4ï¿' 1-"" ßO Shoe: 10 ~o J . J J'z..,~1- TVD, TOP: MD TVD -TVD WELL DATA TD: 't'2..34 MD b -:¡,c¡ TVD I PBTD: H' 6~ MD MD TVD Tubing: -1"~¿,..!' Packer Jo-'\ol MD , TVD, Set at )o-4ZD Hole Size ð'lz. and b .I'ZS II I Perfs loqoi , to 1098 c MECHANICAL INTEGRITY - PART #1 Annulus Press Test: IP I 15 min J 30 min Comments: ",.... MECHANICAL INTEGRITY - PART #2 . Cement Volumes : Amt. Liner \10 6~ f::, J Csg Z2D~<:' J DV Cmt vol to cover perfs Yz.. # . .o~~1 ~/l-F' 5 ' '0 -zk¡ ..3 '8 ~ .\':¡48 ~'.rLÇ' (J'~4- -111~&)x.o~~J +-to) +(u234 - JO~o~.\ x ,oBoÇ-=:. 31. 3 S)( ~v b~ ~ ,oq+2. "'7¿fTheoretical Toe G I~S'O' -:.. DBDS s~/~ 1090i- - ( J 40 - 31.3 \J ~'7 Cement Bond Log (Yes or No) Yi'~' '-8e- . I )-:- .o8oS--~ 9551 ~ - I ~n AOGCC File..'Ú6', t . CBL Evaluation, zone above perfs L.06t6Þ IN'T'ULvAJ,. 9D~ - 10540 6co.D ßOtJþ 8900''¡' ~)l.U::"y1..GN7 J30IVl:> 9300 - -,-;J"} . I Produc.tion Log: Type J Evaluation CONCLUSIONS: Part #1: ~art #2: fV\1 15 JNDIc...A7l.Ï') LùM /-=1 J 2-000 . SCANNED NO\! 0 5 2004 rev. OS/20/87 C.028 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 22, 1999 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: ID-Ii (Permit No. 199-72) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 1D-11. If there are any questions, please call 265-6120. Sincerely, G. C. Alvord Drilling Engineering Supervisor Kuparuk Drilling GCA/skad ORIGINAL RECEIVED Dr-~ 'gl¢~.~ 0i! ~ G.~s Cons. ~chorag~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil [] Gas [] Suspended [] Abandoned [] Service [] Injector 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 199-72 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ~,,~,,~,.,,,,~,~,~_ 50-029-22946 4. Locationofwellatsurface i ;I~ i:.!: i: !~.~-.~,~:. 9. Unit or Lease Name ' /¢r~/~¢~ !' ~i *r{ 10. Well Number Kuparuk River Unit 586'FNL, 601 FEL, Sec. 23, T11N, R10E, UM At Top Producing Interval 2565' FNL, 2052' FWL, Sec. 19, T11 N, R11 E, UM ! ' : !:';, ~ 1D-11 At Total Depth ._': : ~-.,.~,.,~,-~,~,.'~,.¢ 11. Field and Pool 2627' FNL, 2322' FWL, Sec. 19, T11N, R11E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Pool RKB 105 feetI ADL 28243 ALK 3814 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions October 8, 1999 October 23, 1999 October 26, 1999 I N/A feet MSL 1 17.1 Total 1234' Depth M D / (MD 671 + 9' TVD) TVD 18.1 Plug 1166' Back M D Depth / xx TVD (MD + TVD) YES 19. Directional [] Survey No [] 20. Depth N/A where SSSV set feel MD 21. Thickness 1 of 726' Permafrost 22. Type Electric or Other Logs Run GR/Res/Neu Dens, USIT, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO-I-I-OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H~40 Surface 115' 20" 9 cu yds High Early 9.625" 40# L-80 Surface 6814' 12.25" 760 sxAS III Lite, 710 sx Class G 7" 26# L-80 Surface 10565' 8.5" 22o sx Class G 4.5" 12.6# L-80 10401' 11234' 6.125" 14o sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 10420' 10401' 10960'-10980' MD 6568'-6579' TVD 4 spf 10907'-10927' MD 6539'-6550' TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press, psi 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. ORIGINAL Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH 10902' 11090' 11234' 11234' TRUE VERT. DEPTH 6536' 6640' 6720' 6720' 30. FORMATION TESTS Include interval tested, pressure dala, all fluids recovered and gravity. GOR, and time of each phase. Annulus left open - freeze protected with diesel. 31. LIST OF A'FI'ACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call William Lloyd 265-6531 Signed ,~~* ~ C~ Title Drillinq Engineering Supervisor Date J '" G.C. Alvord Prepared by Sharon AIIsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. RECEIVED Item 28: If no cores taken, indicate "none". Form 10-407 Anchora~le Date: 12/02/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-ii WELL_ID: AK0026 TYPE: STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:10/08/99 START COMP: RIG:P00L 6 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22946-00 10/08/99 (D1) TD/TVD: 287/287 SUPV:G.R. WHITLOCK MW: 8.9 VISC: 318 PV/YP: 48/51 (287) DRILLING $ 860' APIWL: 6.8 Move from 1D-14 to iD-ii. N/U diverter and function test. Drill from 100' to 287' 10/09/99 (D2) MW: 10.0 VISC: 254 PV/YP: 60/75 TD/TVD: 2416/2062 (2129) RIH AFTER SHORT TRIP SUPV:G.R. WHITLOCK/D. CUNNINGHAM Drill from 287' to 2416' APIWL: 5.8 10/10/99 (D3) MW: 10.0 VISC: 256 PV/YP: 64/99 APIWL: 4.8 TD/TVD: 4240/3037 (1824) DRILLING @ 4880' SUPV:G.R. WHITLOCK/D. CUNNINGHAM POOH. Tight spots 2040'-1970', 950'-800' Drill from 2416' to 4240' 10/11/99 (D4) MW: 10.0 VISC: 204 PV/YP: 49/57 TD/TVD: 5332/3611 (1092) DRILLING @ 5815' SUPV:G.R. WHITLOCK APIWL: 5.6 Drill from 4240' to 4500'. Replace shearbolt in auger. Drill from 4500' to 5274' Circ low vis sweep. Circ hole clean. POOH. Tight 3169' to 3100', 1293' to 1126' Hole took proper fill. W/R from 5206' to 5274'. CBU. Drill from 5274' to 5332' 10/12/99 (D5) MW: 10.2 VISC: 163 PV/YP: 49/50 APIWL: 4.6 TD/TVD: 6830/4404 (1498) SHORT TRIP TO HW SUPV:G.R. WHITLOCK/S.D. REYNOLDS Drill from 5332' to 6088' Work on washed out discharge strainer on #2 pump. Drill from 6088' to 6830'. CBU. 10/13/99 (D6) MW: 10.0 VISC: 68 PV/YP: 21/28 APIWL: 5.2 TD/TVD: 6830/4404 ( 0) RUNNING 9-5/8" SURFACE CASING SUPV:G.R. WHITLOCK/S.D. REYNOLDS Pump dry job. Circ and condition mud. Hold Safety meeting. Run 9-5/8" casing. 10/14/99 (D7) MW: 10.1 VISC: 64 PV/YP: 25/15 APIWL: 5.4 TD/TVD: 6830/4404 ( 0) RUNNING 1" SUPV: G.R. WHITLOCK/S. D. REYNOLDS Run 9-5/8" casing. Circ and condition mud for cement job. PJSM. Pump cement. RE6E~VED · 28 Date: 12/02/99 ARCO ALASKA INC. D~C £8 999 Page: 2 WELL SUMMARY REPORT ~,~QJI~ Gas Cons, Commission Anchorage 10/15/99 (D8) MW: 8.5 VISC: 47 PV/YP: 10/15 APIWL: 12.2 TD/TVD: 6830/4404 ( 0) RIH W/ 8-1/2" BHA SUPV:G.R. WHITLOCK/S.D. REYNOLDS RIH w/ 1" to 830' RKB. Circ water w/no cement in returns. RIH w/l" to 1020'. Pump slurry. NU wellhead and test to 1000 psi, OK. NU BOPE, set test plug and test BOPE to 250/3000 psi. 10/16/99 (D9) MW: 8.5 VISC: 45 PV/YP: 12/16 APIWL: 13.6 TD/TVD: 7248/4593 (418) DRILLING ~ 7630' SUPV:G.R. ?fHITLOCK/S.D. REYNOLDS Drill cement, float equipment and 20' of new hole. Run LOT to 13.77 ppg. Drill from 6850' to 7248'. 10/17/99 (D10) MW: 8.9 VISC: 49 PV/YP: 15/23 APIWL: 8.0 TD/TVD: 8652/5355 (1404) DRILLING AHEAD @ 8926' SUPV:G.R. WHITLOCK/S.D. REYNOLDS Drill from 7248' to 8652'. Pump HiVis barofiber sweep. CBU. 10/18/99 (Dll) MW: 9.1 VISC: 49 PV/YP: 17/25 APIWL: 6.2 TD/TVD:10065/6096 (1413) DRILLING ~ 10475' SUPV:G.R. WHITLOCK/S.D. REYNOLDS Finish circ. Pump dry job. POOH from 8652' to 6677'. No problems. Drill from 8652' to 10065'. 10/19/99 (D12) MW: 9.3 VISC: 49 PV/YP: 19/23 APIWL: 4.8 TD/TVD:10572/6359 (507) RUNNING 7" CASING. SUPV:FRED HERBERT/S.D. REYNOLDS Drill from 10065' to 10494'. CBU. Pump dry job. Perform OH LOT to 12.2 ppg EMW. Drill from 10494' to 10572'. Pump and circulate around HiVis barofiber sweep. Circulate until hole cleaned up. 10/20/99 (D13) MW: 9.3 VISC: 46 PV/YP: 17/18 APIWL: 5.0 TD/TVD:10572/6359 ( 0) LD 5" DP FROM DERRICK. SUPV:FRED HERBERT/S.D. REYNOLDS PJSM. Run 7" casing to 10564'.Pump cement. Install packoff and test to 5000 psi., OK. 10/21/99 (D14) MW: 10.8 VISC: 48 PV/YP: 23/22 APIWL: 4.6 TD/TVD:10572/6359 ( 0) PRESSURE TEST 7" CASING SUPV:FRED HERBERT/S.D. REYNOLDS Change bottom rams to 4" Change out 5" equipment on top drive. LD 5" DP.Test BOPE and choke manifold. Test hydril to 250/3500 psi. Rams & valves test to 250/5000 psi. Test choke manifold to 250/5000 psi. TIH with 4" DP. 10/22/99 (D15) MW: 10.8 VISC: 47 PV/YP: 24/20 APIWL: 3.8 TD/TVD:ll166/6682 ( 594) POOH TO RIIN USIT LOG. SUPV:FRED HERBERT/S.D. REYNOLDS TIH to 10476'. Tag cement stringers @ 10476'. Circ out cement contaminated mud. Test casing to 3500 psi. Drill Date: 12/02/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 plugs, float equipment and 20' new hole to 10592'. Circ, displace well w/10.8 mud. Perform FIT to 14.3 EMW. Drilling 6.125" hole from 10592' to 11166'. 10/23/99 (D16) MW: 10.9 VISC: 49 PV/YP: 26/23 APIWL: 4.2 TD/TVD:l1234/6720 ( 68) POOH TO RUN LINER SUPV:FRED HERBERT/S.D. REYNOLDS Drilling 6.125" hole from 11166' to 11234' Circ and cond for wiper trip. Pump densified, barofiber sweep. Monitor well, no flow. PJSM. Run USIT log. Cement top @ 9200'. 10/24/99 (D17) MW: 10.9 VISC: 45 PV/YP: 20/19 APIWL: 4.4 TD/TVD:l1234/6720 ( 0) POOH W/DP TO RUN COMPLETION SUPV:FRED HERBERT/S.D. REYNOLDS RIH. Hit tight hole e 10995' Wash & ream from 10995' to 11234' Circ and condition mud. Pump HiVis barofiber sweep. PJSM. Run 4.5" tubing. CBU. 10/25/99 (D18) MW: 10.9 VISC: 50 PV/YP: 27/24 APIWL: 4.5 TD/TVD:l1234/6720 ( 0) DISPLACING WITH SEA WATER. SUPV:FRED HERBERT/S.D. REYNOLDS Circ and cond for cement job. PJSM. Pump cement. Circ out cement & cement contaminated mud. Test casing to 2000 psi, OK. PJSM. Run seal assy 4.5" tubing. 10/26/99 (D19) TD/TVD:l1234/6720 ( SUPV:FRED HERBERT MW: 8.5 VISC: 28 PV/YP: 1/ 0 APIWL: 0.0 0) RIG RELEASED FROM iD-ii @ MIDNIGHT 10/26/99 Run 4.5" tubing. Freeze protect well. ND stack. Nil tree and test. Rig release $ midnight 10/26/99. RECEIVED DE...,,,. ,-v 28 1999 AJas~ 0ii & Gas Cons. Comm~ior~ Anchorage ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '~ K1(1D-11(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-11 DRILLING SUPPORT-CAPITAL 1030990549.1 DATE DAILY WORK UNIT NUMBER 11/19/99 CBL/PERF SWS - 2128 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR I NO YES SCHUDEL FIELD AFC# CC# Signed ESTIMATE 999324 230DS10DG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 650 PSI 0 PSI 400 PSI 0 PSI 0 PSII 0 PSI DAILY SUMMARY RAN BOND LOG W/SCMT, GOOD CEMENT TO LINER LAP. PERFED 10960-10980' W/2-1/2"HC (2-7/8" WOULDN'T GO. PERFED I 10907-10927' W/2-7/8" HC. TAG AT 11087' ELM[Tag, Perf] I TIME LOG ENTRY 08:00 MIRU UNIT 2158, DECKERT, BATES, GUMMINGER.SAFETY MEETING 09:00 PT LUB 3K PSI,RIH W/1 11/16 BOND TOOL/GR, MAX OD 1.7"X40'. 10:30 LOG CBL MAIN PASS & REPEAT, BHP=3480 WITH WHP OF 750.LOG 11087 (TD)-10400 CBL & GR/CCL 11087- 10250. 11:30 COMPLETED LOGGING POOH 12:30 CCH-RIG UP GUN AND CALL FOR RADIO SILENCE 13:15 RIH W/CCL-20' GUN, 2 7/8, 4 SPF 14:15 WHP AT 70 PSI. PUMPED UP TO 170 PSI FOR 500# UNDERBALANCE. DURING CBL, BHP AT 3480# W/750# ON WH. EXPECTED BHP IS 3400# PER PROCEDURE. BOTTOM OF TOOL HANGING UP AT 10,949'; MADE SEVERAL ATTEMPTS. 15:15 POOH W/2 7/8 GUN 16:15 RIH W/2.5" 4SPFX20' 17:30 TAG TD AT 11,087' ELM. 17:37 PUMPED WHP BACK TO 170#. SHOT 10960 TO 10980'. GOOD INDICATION AT SURFACE. PULLING EXCESS WT PUH. 17:46 PUH, WHP AT 700# 19:00 RIH W/2 7/8 4SPF 20:00 FIRED GUN -PERF 10907-10927 2 7/8 HSD 4 SPF RECEIVED 1999 Con . Cm'nmlss[Qn /mchorage North Slope Alaska Alaska State Plane 4 Kuparuk 1D, Slot 1D- 11 1D-11 Job No. AKMM90162, Surveyed: 25 October, 1999 OR GINAL SURVEY REPORT O, tVED 5 November, 1999 N~ ~ 2 D99 Alas~ Oil & Gas'~ns. Commission Your Ref: API-500292294600 Surface Coordinates: 5959078.99 N, 560490.78 E (70° 17' 55.5551" N, 149° 30' 36.4262" W) Kelly Bushing: 105.50ft above Mean Sea Level o R I L. L.. I N. ~ S IE R V I C ~ S Survey Ref: svy8891 Sperry-Sun Drilling Services Survey Report for 1D- 11 Your Ref: API-500292294600 Job No. AKMM90162, Surveyed: 25 October, 1999 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -105.50 0.00 115.00 0.000 0.000 9.50 115.00 152.06 0,720 344.030 46.56 152.06 232.06 0.290 70,810 126.56 232.06 320.17. 1,080 94.330 214.66 320.16 378.96 1.740 105.330 273.43 378.93 468.84 3.460 119.110 363.22 468.72 562.04 6,630 130.520 456.05 561.55 652.09 9,780 134.010 545,16 650.66 743.09 12.010 128.370 634.52 740.02 834.33 15.490 129.550 723.13 828.63 926.85 19.980 129.970 811.23 916.73 1017.89 23,580 126.910 895.76 1001.26 1112.02 25.310 126.790 981.45 1086.95 1204.91 27,810 126.600 1064.53 1170.03 1298.60 28.900 125.920 1146.98 1252.48 1392.17 30.130 123.660 1228.41 1333.91 1486.55 32,930 121.030 1308.85 1414.35 1580.37 35;800 117.780 1386.29 1491.79 1673.33 37.560 114,600 1460.85 1566.35 1765.06 39.440 112,740 1532.64 1638.14 1860.02 41.690 110,390 1604.78 1710.28 1953.82 44.840 109,100 1673.07 1778.57 2047.84 48,730 106,850 1737.44 1842.94 2141.82 52.090 104,480 1797.33 1902.83 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 5959078.99 N 560490,78 E 0.00 N 0.00 E 5959078.99 N 560490.78 E 0.22 N 0,06W 5959079.21 N 560490.71 E 0.77 N 0.01W 5959079.76 N 560490.76 E 0.78 N 1.03 E 5959079.78 N 560491.80 E 0.51 N 2.44 E 5959079.52 N 560493.22 E 1.17 S 6,13 E 5959077.87 N 560496.92 E 6.04 S 12.68 E 5959073.05 N 560503.50 E 14.73 S 22.13 E 5959064.44 N 560513.03 E 25.98 S 35.11 E 5959053,29 N 560526.10 E 39.64 S 51.96 E 5959039.77 N 560543.05 E 57.67 S 73.61 E 5959021.92 N 560564.85 E 78.60 S 100.10 E 5959001.20 N 560591.51 E 101.96 S 131.27 E 5958978.09 N 560622.86 E 126.77 S 164.57 E 5958953.54 N 560656.36 E 153.09 S 200.45 E 5958927.52 N 560692.46 E 179,37 S 238.31E 5958901.54 N 560730.53 E 205.73 S 280.02 E 5958875.52 N 560772.45 E 231.67 S 326.16 E 5958849.95 N 560818,80 E 256.14 S 375.99 E 5958825.88 N 560868.82 E 279.05 S 428.29 E 5958803.40 N 560921.30 E 301,71S 485.72 E 5958781.20 N 560978.91E 323,41S 546.22 E 5958759.99 N 561039.59 E 344.51 S 611.39 E 5958739,42 N 561104.92 E 364.02 S 681.12 E 5958720.46 N 561174.80 E Dogleg Rate (°/100ft) 0.000 1.943 0.951 0.933 1,208 2.023 3.551 3.54o 2,713 3.826 4.855 4.145 1.839 2.693 1.213 1.773 3.305 3.630 2,785 2,407 2,864 3,488 4.489 4.069 Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) Comment 0.00 0.00 -0.12 -0.20 0.81 2.25 6.23 13.76 25.03 40.34 59.97 85.33 116.08 151.96 190.26 231.42 274.49 321.32 372.36 426.61 482.88 544.08 608.03 676.36 748.73 Continued... 5 November, 1999 - 13:46 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D- 11 Your Ref: API-500292294600 Job No. AKMM90162, Surveyed: 25 October, 1999 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2235.73 54.650 102.220 1853.36 1958.86 2327.36 55.450 103.340 1905.86 2011.36 2418.83 54.960 103.660 1958.05 2063.55 2511.96 57.040 102.740 2010.13 2115.63 2606.71 58.480 100.720 2060.68 2166,18 2695.98 58.820 98.610 2107.12 2212.62 2795.47 57.980 102,170 2159.27 2264.77 2888.13 57.220 104.170 2208.92 2314.42 2979,96 56.610 104.420 2259.05 2364.55 3075.14 56.190 105.220 2311.72 2417.22 3169.62 57.420 106.030 2363.45 2468.95 3262.94 57.850 105.230 2413.40 2518.90 3354.49 57.030 105.640 2462.67 2568.17 3447.53 58.110 104.470 2512.57 2618.07 3539.14 58.310 102.750 2560.83 2666.33 3637.75 57.890 102.290 2612.94 2718.44 3731.24 58.640 102.720 2662.11 2767.61 3825.61 58.250 102.610 2711.50 2817.00 3920.45 57.460 102.150 2761.96 2867.46 4013.43 58.010 101.770 2811.60 2917.10 4107.03 57.160 100.860 2861.77 2967.27 4200.91 58.870 102.260 2911.50 3017.00 4295.53 58.830 102.020 2960.44 3065.94 4390.28 57.880 104.100 3010.16 3115.66 4485.17 57.330 102.470 3061.00 3166.50 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 381.40 S 754.43 E 5958703.68 N 561248.26 E 398.01S 827.67 E 5958687.65 N 561321.63 E 415.55 S 900.71 E 5958670.71 N 561394.81 E 433.17 S 975.88 E 5958653.69 N 561470.11E 449.45 S 1054.34 E 5958638.04 N 561548.70 E 462.24 S 1129.49 E 5958625.85 N 561623.95 E 477.51 S 1212.82 E 5958611.26 N 561707.40 E 495.33 S 1288.99 E 5958594.05 N 561783.72 E 514.33 $ 1363.55 E 5958575.66 N 561858.42 E 534.60 S 1440.19 E 5958556.00 N 561935.23 E 555.90 S 1516.33 E 5958535.31N 562011.53 E 577.14 S 1592.23 E 5958514.69 N 562087.61E 597.67 S 1666.61 E 5958494.75 N 562162.15 E 618.06 S 1742.44 E 5958474.97 N 562238.14 E 636.38 S 1818.12 E 5958457.26 N 562313.96 E 654.53 S 1899.85 E 5958439.77 N 562395.83 E 671.75 S 1977.47 E 5958423.18 N 562473.59 E 689.38 S 2055.93 E 5958406.18 N 562552.19 E 706.60 S 2134.36 E 5958389.59 N 562630.76 E 722.89 S 2211.28 E 5958373.92 N 562707.81 E 738.40 S 2288.76 E 5958359.04 N 562785.41 E 754.36 S 2366.76 E 5958343.70 N 562863.54 E 771.39 S 2445.93 E 5958327.31 N 562942.84 E 789.61 S 2524.50 E 5958309.73 N 563021.55 E 808.02 S 2602.47 E 5958291.94 N 563099.67 E Dogleg Rate (°ll00ft) 3.341 1.329 0.608 2.379 2.358 2.054 3.162 1,998 0.702 0.828 1.486 0.858 0.972 1.573 1.611 0.582 0.893 0,425 0.929 0.685 1.224 2.218 0.221 2.121 1.562 Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) Comment 824.08 899.17 974.28 1051.47 1131.55 1207.57 1292.12 1370.34 1447.28 1526.55 1605.57 1684.36 1761.49 1840.00 1917.87 2001.56 2081.04 2161.44 2241.71 2320.29 2399.22 2478.77 2559.71 2640.35 2720.47 Continued... 5 November, 1999 - 13:46 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D- 11 Your Reft AP1-500292294600 Job No. AKMM90162, Surveyed: 25 October, 1999 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) , 4579.59 57.840 101.120 3111.61 3217.11 4673.74 58.480 101.970 3161.28 3266.78 4767.68 57.940 101.280 3210.77 3316.27 4863.80 57.490 100.320 3262.11 3367.61 4956.66 59.040 102.390 3310.96 3416.46 5051.57 59.410 103.400 3359.52 3465.02 5146.05 58.970 99.660 3407.93 3513.43 5239.19 58.410 99.210 3456.33 3561.83 5332.86 57.940 103.820 3505.74 3611.24 5427.53 57.660 102.700 3556.19 3661.69 5520.84 57.440 103.760 3606.26 3711.76 5615.77 58.240 103.410 3656.79 3762.29 5710.11 57.580 103.330 3706.91 3812.41 5804.39 57.210 105.450 3757.71 3863.21 5897.06 58.770 106.540 3806.83 3912.33 5992.19 57.830 106.320 3856.82 3962.32 6086.87 57.820 103.450 3907.25 4012.75 6176.42 58.530 102.080 3954.47 4059.97 6271.04 57.920 103.420 4004.30 4109.80 6364.62 58.140 103.250 4053.84 4159.34 6460.56 57.610 103.440 4104.86 4210.36 6555.44 57.940 103.190 4155.46 4260.96 6650.35 57.860 102.200 4205.89 4311.39 6741.44 59.370 100.510 4253.33 4358.83 6903.07 58.810 99.680 4336.36 4441.86 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 824.31 S 2680.49 E 5958276.28 N 563177.82 E 840.32 S 2758.86 E 5958260.90 N 563256.31E 856.41 S 2837.06 E 5958245.44 N 563334.65 E 871.64 S 2916.88 E 5958230.86 N 563414.58 E 887.20 S 2994.30 E 5958215.92 N 563492.13 E 905.40 S 3073.79 E 5958198.36 N 563571.76 E 921.62 S 3153.27 E 5958182.78 N 563651.37 E 934.67 S 3231.77 E 5958170.37 N 563729.97 E 950.54 S 3309.73 E 5958155.12 N 563808.05 E 968.91 S 3387.70 E 5958137.38 N 563886.17 E 986.93 S 3464.35 E 5958119.97 N 563962.96 E 1005.81S 3542.46 E 5958101.73 N 564041,22 E 1024.29 S 3620.22 E 5958083.87 N 564119.13 E 1044.02 S 3697.15 E 5958064.76 N 564196.21E 1065.68 $ 3772.68 E 5958043.71N 564271.91E 1088.58 S 3850.31 E 5958021.44 N 564349.73 E 1109.16 S 3927.75 E 5958001.48 N 564427.33 E 1125.97 $ 4001.95 E 5957985.27 N 564501.67 E 1143.71S 4080.40 E 5957968.16 N 564580.26 E 1162.02 S 4157.65 E 5957950.47 N 564657.65 E 1180.78 S 4236.71E 5957932.35 N 564736.85 E 1199.26 S 4314.81 E 5957914.50 N 564815.11 E 1216.93 S 4393.25 E 5957897.46 N 564893.68 E 1232.23 S 4469.48 E 5957882.78 N 564970.04 E 1256.54 S 4606.01 E 5957859.57 N 565106.75 E Dogleg Rate (°/100ft) 1.322 1.025 0.849 0.965 2.526 0.994 3.431 0.729 4.211 1.044 0.987 0.899 0.703 1.934 1.957 1.008 2.566 1.523 1.366 0.281 0.577 0.413 0.888 2.293 0.560 Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) Comment 2800.12 2880.03 2959.81 3040.95 3119.83 3201.36 3282.42 3361.75 3441.23 3521.33 3600.06 3680.43 3760.35 3839.76 3918,29 3999.14 4079,26 4155.33 4235.75 4315.13 4396.37 4476.63 4557.01 4634.69 4773.05 Continued... 5 November, 1999 - 13:46 - 4 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D- 11 Your Ref: API-500292294600 Job No. AKMM90162, Surveyed: 25 October, 1999 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 6999.21 58.210 100.760 4386.58 4492.08 7094.75 57,230 99.850 4437.60 4543..10 7188.84 58.780 102.600 4487.46 4592.96 7282.83 58.290 105.650 4536.53 4642.03 7374.47 58.660 105.560 4584.45 4689.95 7467.94 58.320 103.270 4633.30 4738.80 7562.41 60.310 99,800 4681.52 4787.02 7659.30 60.480 99,390 4729.39 4834.89 7752.01 58.510 99.540 4776.45 4881.95 7849.04 57.590 100.360 4827.79 4933.29 7940.17 57.470 100.910 4876.72 4982.22 8032.40 57.420 101.860 4926.35 5031.85 8126,24 58.820 102.910 4975,91 5081.41 8223.44 58.490 103.310 5026,47 5131.97 8315.27 57.930 102,820 5074,85 5180.35 8410.08 59.130 102.000 5124.34 5229.84 8501.99 58,570 101.780 5171,89 5277.39 8593.85 59,070 102.260 5219.44 5324.94 8691.83 58.770 101,860 5270,03 5375.53 8783.83 59.180 102.890 5317.44 5422.94 8878.02 58.720 103.700 5366.03 5471.53 8969.89 58.480 103,680 5413.89 5519.39 9067.66 57.870 103.480 5465.45 5570.95 9154.68 58.510 103.760 5511.32 5616.82 9250.94 58.840 102.570 5561.36 5666.86 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1271.08 s 4686.69 E 5957845.67 N 565187.55 E 1285.54 S 4766.15 E 5957831.86 N 565267.13 E 1301.08 S 4844.41 E 5957816.94 N 565345.50 E 1320.64 S 4922.14 E 5957798.01 N 565423.39 E 1341.65 S 4997.38 E 5957777.61 N 565498.79 E 1361.49 S 5074.55 E 5957758.39 N 565576.12 E 1377.71 S 5154.13 E 5957742.82 N 565655.83 E 1391.75 S 5237.19 E 5957729.44 N 565739.01 E 1404.88 S 5315.98 E 5957716.94 N 565817.90 E 1419.10 S 5397.07 E 5957703.38 N 565899.10 E 1433.29 S 5472.63 E 5957689.80 N 565974.77 E 1448.64 S 5548.84 E 5957675.06 N 566051.10 E 1465.73 S 5626.67 E 5957658.60 N 566129.06 E 1484.56 S 5707.52 E 5957640.42 N 566210.06 E 1502.21S 5783.55 E 5957623.39 N 566286.23 E 1519.58 S 5862.52 E 5957606.65 N 566365.34 E 1535,79 $ 5939.49 E 5957591.06 N 566442.44 E 1552.16 S 6016.36 E 5957575.31 N 566519.44 E 1569.69 S 6098.42 E 5957558.44 N 566601.64 E 1586.59 S 6175.43 E 5957542.16 N 566678.78 E 1605.14 S 6253.96 E 5957524.24 N 566757.46 E 1623.70 S 6330.15 E 5957506.30 N 566833.79 E 1643.21S 6410.89 E 5957487.44 N 566914.69 E 1660.62 S 6482.76 E 5957470.61 N 566986.70 E 1679.35 S 6562.83 E 5957452.53 N 567066.91E Dogleg Rate (°ll00ft) 1.143 1.304 2.976 2.816 0.412 2.120 3.796 0.408 2.129 1.189 0.526 0.870 1.769 0.489 0.760 1.465 0.643 0.704 0.465 1.058 0.884 0.262 0.648 O.785 1.110 Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) Comment 4854.86 4935.47 5015.16 5095.32 5173.40 5253.08 5334.22 5418.22 5497.85 5579.98 5656.74 5734.40 5814.05 5897.06 5975.10 6055.93 6134.54 6213.09 6296.96 6375.76 6456.45 6534.87 6617.94 6691.88 6774.10 Continued... 5 November, 1999 - 13:46 - 5 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D- 11 Your Ref: API-500292294600 Job No. AKMM90162, Surveyed: 25 October, 1999 North Slope Alaska Measured Depth (ft) Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 9349.93 58.660 103.670 5612.72 5718.22 9445.28 57.230 101.150 5663.33 5768.83 9534.30 58.100 101.050 5710.94 5816.44 9628.02 59.050 101.670 5759.80 5865.30 9722.02 59.080 101.380 5808.13 5913.63 9818.26 58.900 100.970 5857.71 5963.21 9912.62 57.820 103.310 5907.21 6012.71 10008.67 57.200 103.560 5958.80 6064.30 10104.33 58.430 102.770 6009.76 6115.26 10200.10 58.800 101.530 6059.64 6165.14 10295.22 58.340 101.200 6109.24 6214.74 10389.18 58.830 102.590 6158.21 6263.71 10483.96 58.580 102.890 6207.45 6312.95 10514.47 58.600 102.460 6223.35 6328.85 10615.25 57.980 101.450 6276.32 6381.82 10712.66 57.400 101.990 6328.38 6433.88 10808.24 57.280 102.280 6379.96 6485.46 10904.21 57.100 102,680 6431.97 6537.47 11000.33 56.620 102.350 6484.51 6590.01 11096.25 56.330 102.400 6537.49 6642.99 11161.73 56.150 103.800 6573.88 6679.38 11234.00 56.150 103.800 6614.14 6719.64 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1698.55 S 6645.25 E 5957433.98 N 567149.48 E 1715.93 S 6724.15 E 5957417.24 N 567228.53 E 1730.41 S 6797.96 E 5957403.35 N 567302.45 E 1746.17 S 6876.37 E 5957388.23 N 567380.98 E 1762.28 S 6955.37 E 5957372.76 N 567460.11 E 1778.26 S 7036.29 E 5957357.42 N 567541.16 E 1795.15 S 7114.82 E 5957341.17 N 567619.82 E 1813.97 S 7193.62 E 5957322.99 N 567698.77 E 1832.40 $ 7272.45 E 5957305.19 N 567777.75 E 1849.61 S 7352.38 E 5957288.62 N 567857.81 E 1865.60 S 7431.95 E 5957273.27 N 567937.50 E 1882.13 S 7510.41 E 5957257.37 N 568016.10 E 1899.99 S 7589.40 E 5957240.15 N 568095.23 E 1905.71 S 7614.81 E 5957234.64 N 568120.68 E 1923.47 S 7698.68 E 5957217.55 N 568204.70 E 1940.19 S 7779.29 E 5957201.48 N 568285.44 E 1957.11 S 7857.96 E 5957185.20 N 568364.24 E 1974.54 $ 7936.72 E 5957168.40 N 568443.13 E 1991.98 $ 8015.29 E 5957151.60 N 568521.84 E 2009.11 S 8093.39 E 5957135.09 N 568600.08 E 2021.45 S 8146.41 E 5957123.18 N 568653.20 E 2035.77 S 8204.70 E 5957109.33 N 568711.60 E Dogleg Rate (°/100ft) 0.967 2.696 0.982 1.160 0.267 0.410 2.401 0.682 1.463 1.171 0.567 1.366 0.378 1.205 1.051 0.758 0.285 o.397 o.576 0.305 1.799 0.000 Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) Comment 6858.72 6939.49 7014.62 7o94.51 7175.o6 7257,45 7337.74 7418.75 7499.7o 7581.42 7662.5o 7742.63 7823.60 7849.64 7935.32 8017.58 8098.01 8178.65 8259.11 8339.o4 8393.47 8453.49 PROJECTED SURVEY Continued... 5 November, 1999 - 13:46 - 6 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D- 11 Your Ref: API-500292294600 Job No. AKMM90162, Surveyed: 25 October, 1999 North Slope Alaska Alaska State Plane 4 Kuparuk 1D All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 103.935° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11234.00ft., The Bottom Hole Displacement is 8453.49ft., in the Direction of 103.935° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 11234.00 6719.64 2035.77 S 8204.70 E PROJECTED SURVEY 5 November, 1999 - 13:46 - 7- DrillQuest Scbhunberger NO. 12992 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log DescriptiOn Date BL Sepia Print 1D-11 GR/COLLAR CORRELATION 991119 I 1 2T-19 PRODUCTION LOG 991118 I 1 31-12L1 Ut lc- INJ .PROF.-LATERAL LEG 991111 I 1 3J-8 / INJECTION PROFILE 991115 I 1 3K-13~ INJECTION PROFILE 991115 I 1 3K-23 PROD LOG/GASLIFT SURVEY 991122 I 1 3M-17 PROD/JEWELRY LOG 991122 I I an/n/n/~:h0r_a9e Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Th you. 12/2/99 Schlumberger NO. 12916 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 1G-10A STIM-STICK RECORD 991024 I 1 2C-02 t~ c_ INJECTION PROFILE 991028 I 1 2C-06 / INJECTION PROFILE 991029 I 1 2C-08g" INJECTION PROFILE 991030 I 1 1D-11 99413 USIT 991023 1 1D-14 Lx~C_. 99411 CBL 991022 I DATE: ' ' [ Please sign and return one copy of this transmittal to Sherrie at the above address or fax to Anchorage 11 / 10~99 08-Nov-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-11 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window I Kickoff Survey: Projected Survey: 0.00' MD 'MD ,234.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, : William T. Allen Survey Manager Attachment(s) RECEIVED ~',"~',/ 12 1999 Alaska 0il & Oas Cons. Commission ~c~orage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax' 907-273-3535 A Halliburton Company MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission Robert Christenson/~ ~ DATE: October 21, 1999 Chairman THRU: Blair Wondzell, ~ FILE NO: aa5gjtgf. DOC P. I. Supervisor(~to/~_O(gq FROM: Lawrence M Wade ~ SUBJECT: BOP Test Petroleum Inspector Poole 6 ~'~(1'" o'-I '~ October 21,1999: I traveled to Kupurak to witness a BOP test on Poole 6. They were drilling a Kupurak production well. In looking at the PTD I noticed that the 3M box was checked on the BOP test requirements. They had an FMC Gen. 5 casing hanger installed and in the drilling program a recommendation to test the BOP stack to 5000 psi. I talked to the company man and we decided to test to 5000. The test went well and the location clean and orderly. SUMMARY: Tested the BOP stack on Poole 6, 0 failures, Attachments: aa9gjtgf, xls 4 hours. cc; NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: 1 D-12 Casing Size: 7" Test: Initial Workover: DATE: Pool Rig No. 6 PTD # 99-72 Rig Ph.# ARCO Rep.: 1D-11 Rig Rep.: Set @ 10,564 Location: Sec. Weekly X Other 10/21/99 659/7562 Fred Herbert Darrell Green 28 T. 11N R. 10E Meridian UM Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location YES Standing Order Posted YES FLOOR SAFETY VALVES: Well Sign OK Upper Kelly / IBOP Drl. Rig OK Lower Kelly / I BOP 1 Hazard Sec. OK Ball Type Inside BOP Quan. Pressure 1 250/5000 250/5000 I 250/5000 1 250/5000 P/F ,P BOP STACK: Annular Preventer Pipe Rams 1 Lower Pipe Rams 1 Blind Rams 1 Choke Ln. Valves 1 HCR Valves 2 Kill Line Valves 1 Check Valve Quan. Test Press. 1 P/F 25~3500 P 250/5000 P 250/5000 P 25~5000 P 250/5000 P 250/5000 P 250/5000 P N/A CHOKE MANIFOLD: No. Valves 15 No. Flanges 30 Manual Chokes 1 Hydraulic Chokes 2 Test Pressure P/F I" so/s0OOl IP Functioned I P Functioned I P ACCUMULATOR SYSTEM: System Pressure 2900 I Pressure After Closure 1600 I MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 34 sec. Trip Tank OK OK System Pressure Attained 2 minutes 20 sec. Pit Level Indicators OK OK Blind Switch Covers: Master: OK Remote: OK Flow Indicator OK OK Nitgn. Btl's: 6 (~ 2000 Psi Meth Gas Detector OK OK Psig. H2S Gas Detector OK OK Number of Failures: 0 ,Test Time: 4.0 Hours. Number of valves tested 23 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: odg-Weli File c - Oper./Rig c - Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Larry Wade F1-021L (Rev. 12/94) aaggjtgf.)ds TON Y KNO WL ES, GO VERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 4, 1999 Randy Thomas Drilling Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99501-0360 Re: Kuparuk River Unit 1 D- 11 ARCO Alaska, Inc. Permit No: 99-72 Revised Sur Loc: 586'FNL, 601'FEL, Sec. 23, T11N, R10E, UM Btmhole Loc. 2572'FNL, 2138'FWL, Sec. 19, T11N, R11E, UM Dear Mr. Thomas: Enclosed is the approved revised application for permit to drill the above referenced well. The revision is for a change in bottom-hole location. The provisions of the original approved permit dated July 28, 1999 are in effect fbr this revision. S° I Robert N. Christenson, P.E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department ofFish & Game, Habitat Section W/o encl Department of Environmental Conservation w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type ofwork: Drill r~] Redrill FI I lb. Type ofwell. Exploratory ]~ StratigraphicTest [--'] Developm~ntOil rT'] ......... Re-entry FI Deepen 1~1I Service [~[ Development Gas I--'] Single Zone ]'~ Multiple Zone F] 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 35 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 28243 ALK 3814 Kuparuk River Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 586' FNL, 601' FEL, Sec. 23, T11N, R10E, UM Kuparuk River Unit Storewide At top of productive interval 8. Well number Number 2521' FNL, 1908' FWL, Sec. 19, T11 N, R11 E, UM 1D-11 #U-630610 At total depth 9. Approximate spud date Amount 2572' FNL, 2138' FWL, Sec. 19, T11 N, R11 E, UM October 3, 1999 $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 1908 @ Targc feet WS-08 16.5' @ 386' MD feet 2560 11025 ' MD/6613 'TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 250 MD Maximum hole angle 58° Maximum surface 2597 psig At total depth (TVD) 3081 psig 18. Casing program Setting Deplh size Specifications Top Bottom Quanti~ of Cement Hole Casin~l Wet,Iht Grade Couplin~l Len~lth MD TVD MD TVD (include stage data) 20" 16" 62.5# R-3 Weld 85' 35' 35' 120' 120' 230 sx ASI 12.25" 9.625" 40# L-80 BTC 6796' 35' 35' 6831' 4401' 840 sx AS III L & 770 sx Class G 8.5" 7" 26# L-80 BTC-Mod 10421' 35' 35' 10456' 6384' 220 sx Class G 6.125" 4.5" 12.6# L-80 ABToMod 719' 10306' 6234' 11025' 6613' 170 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Production~:~" E C E iV Liner Perforation depth: measured U ~ i b ii'~ ~ L '~" i'':i'; ~' ? '~999 true vertical Anchorage 20. Attachments Filing fee ~] Property Plat D BOP Sketch [~ Diverter Sketch r~ Drilling program Drilling fi,id program [~] Time vs depth plot I--[Refraction analysis F~ Seabed report E] 20 AAC 25.050 requirements 21. I hereb~.~fl.~ify that the foregoing is true and correct to the best of my knowledge Questions? Carl Wilfiam Lloyd 265-653 Rand~/Thomas prp. Dar~.d bv Sharon AII.sun-Drak~ Commission Use Chi} ~l~m I Approvaldate._ Seecoverletter Perm bet APl number --" 7 '~ 50- O ~_.._<~ -- 2- ~ ? ~" ~' "~::,,~.,-- ~' ¢ ,o, other requirements Conditions of approval Samples required [3Yes ~ No M.d,ogreq.ired r-lYes ~ No Hydroge, s,lfidemeasures ~:] Yes D~N° Directional surveyrequired ~ Yes BI No Required working pressure for BOPE E]2M; [~ 3M; F~ 5M; F~ 1OM; [3 E] Other: ORIGINAL SIGNED-BY Robert N. Chdstenson by order of Approved by Commissioner the commission Date / ~) '''' Form 10-401 Rev. 12/1/85 · Submit in triplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 September 23, 1999 Robert Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill: KRU 1D-11 Surface Location: 586' FNL, 601' FEL Sec 23 TllN R10E~ UM Target Location REVTSED: 2.521' FNL, 1908' FWL Sec. 19, T11N, RllE, Ut4 Bottom Hole Location REWSED: 2572' FNL, 2138' FWL Sec. 19, T11N, RllE, UM Dear Commissioner Christenson, ARCO Alaska, ]:nc. hereby applies for a Permit to Drill an onshore development well to the Kuparuk interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and further develop the production potential of the Kuparuk sands in the vicinity of 1D pad. Be advised this well had been previously permitted on July 28, 1999. The enclosed application is for a change in bottom hole location. The well is designated as a conventional _injection welJ using a 9 5/8" surface casing string, a 7" intermediate casing string, a 4 1/2" liner and 4-1/2" tubing. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 6) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 7) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 1) 8) 9) ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment will be functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. Due to the large volume of regional information available, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. The following are ARCO's designated contacts for reporting responsibilities to the Commission: Completion Report Technologist (20 AAC 25.070) Sharon AIIsup-Drake, Drilling 263-4612 2) Geologic Data and Logs Bill Raatz, Geologist (20 AAC 25.071) 263-4952 Divertor and BOP Diagrams for Pool 6 to be used for this well are on file with the AOGCC. 6531 or Chip Alvord at (907) 265-6120. The anticipated spud date for this well is October 3, 1999. ]:f you have any questions or require further information, please contact Bill Lloyd at (907)~ William BLLIbyd ~"- ~ Senior Drilling En~xe~ CC: Kuparuk 1D-11 Well File Chip Alvord ATO-1200 M_] Loveland NSK6 Robert Christenson Application for Permit to Drill - 1D-11 4 Drill and Case Plan for 1D-11 Kuparuk Producer General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 120' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. 3. Spud and directionally drill 12 1/4" hole to the surface casing point at 6831' MD/4401' TVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 9 5/8" 40# L80 BTC casing string to surface. · Employ lightweight permafrost cement lead slurry to assure cement returns to the surface in a one stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify AOGCC 24 hours before test 7. Make up 8 1/2" bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 8. Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town 9. Drill 8 1/2" hole to intermediate casing point at +10456' MD/6384' TVD · Perform a second LOT and determine an acceptable kick tolerance · If kick tolerance is acceptable, 8 1/2" hole will be drilled to TD · If kick tolerance is unacceptable, 7" casing will be run to top Kuparuk 10. Run and cement 7" 26# L80 BTC-Mod (if required from step #9). Run CBL log to insure cement integrity and zonal isolation. Steps 11-14 are only applicable if we are required to top set the Kuparuk with 7" casing 11. Make up 6 1/8" bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 12. Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town 13. Drill 6 1/8" hole to TD at 11025' MD/6613' TVD · Condition hole and mud for casing 14. Run and cement 4 1/2" 12.6# L80 ABT-Mod Liner 15. Make a cleanout run with bit and scrapers if necessary · Displace to filtered seawater · Pressure test well to 3000 psi for 30 minutes · Record results and fax to town 16. Run and land 4 1/2" tubing 17. Nipple down BOP's. Install production tree and pressure test same. 18. Secure well, release rig Robert Christenson Application for Permit to Drill - 1D-11 5 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU ID-I:[ Drilling Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel API Filtrate pH % Solids Spud to surface casing point Drill out to TD 9.5-10.2 ppg 16-26 25-35 200 - 300 9.5 - 10.6 ppg 6-20 5-20 35-50 20-30 15-40 7-15 9.5-10 ±10% 2-6 4-8 <6 through Kup 9.0-10 <11% Drilling Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Pit Level Indicator (Visual and Audio Alarm) Trip Tank Centrifuge Fluid Flow Sensor Degasser Fluid Agitators Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: rvlaximum anticipated surface pressure (HASP) while drilling the production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 2597 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (4401 ft)(0.70- 0.11) = 2,597 psi Based on offset well data, reservoir pressures in the Kuparuk sands in the vicinity of 1D pad are expected to be ~3,400 psi (0.53 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 10.6 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 6,464'. Target (Kuparuk C4) (3400+ 150)/(0.052'6464)= 10.6. Well Proximity Risks: The nearest well to 1D-11 is WS-8. The wells are 16.5' from each other at a depth of 386' HD. Drilling Area Risks: Drilling risks in the :[D-I:t area are surface interval hydrates, lost circulation and potential borehole instability in and below the permafrost formation. Hydrate risks will be minimized by the use of sufficient mud weights to allow for tripping of pipe, controlled drilling rates, and optimum rheological properties to safely appropriate gas breakout. Lost circulation will be addressed with lost circulation material (LCM) Robert Christenson Application for Permit to Drill - 1 D-11 6 Annular Pumpino Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1D-12 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We anticipate that ID-II will be requested to be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. All necessary documentation for the permitting of this well for annular injection will be provided after the well is completed. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300- 500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. Created by r[xse FOIl; Dote plotted; 23-Sep-1999 Plot Reference is 11 Vers[on ~6. Coordinates ore in feet reference slot t~11. True Vertical Depth:.o..~.el;erence rkb Pool 0 - 500 - 1000 - 1500 · ~-- 2000 2500 n 3000 · -- 5500 4000 4500 I 5000 5500 6000 6500 7000 ARCO Alaska, Inc. Sfrucfure: Pod 1D Well : 11 Field : Kuparuk River Unit Looafion : North Slope, Alaska SURFACE LOCATION: 586' FNL, 601' FEL SEC. 25, T11N, RIOE Easf (feet) -> 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 BO00 8500 RKB ELEVATION: 1 05' [0.75Begin 1.5 Beg/lO0' Build I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I Begin 43 Oeg Build & Turn to 130 Az Begin 1.5 Deg/lO0' Build ~{ 4.8g O0~s.. -Begin $ Deg Build ~ Turn [o 150 ~ 10.75 ~~~_~e~_~_~rn to 102.5 ~ 16,71 DLS: 5.00 deg per 100 ft - Begin 3 ~g Build ~ Turn to 102,5 ~ 52.96 DLS: 5.00 deg per 100 ft ~ Top of West Sak ~Bose of West Sak 38.19 Base of Permafros~ ~~Cosing 45.5954,70 Point ~ ~. 49.10 103.92 AZIMUTH ~x w-~°'~' 8026' (T0 TARGET) ***Plane of Proposal*** 58.17 DEG AVERAGE ANGLE Base of West Sak 9 5/8 Casing Point C80 JTARGET LOCATION: J 2521' FNL, 1908' FWL SEC. 19, T11N, R11E 250O C50 C40 C30 Base HRZ-7 Casing Pt C20 Top of Kuparuk D K-1 Torget-Top C4 Version #6 Top C~---'-% ..~~_. --.-,, Top C5 Top C1 ~ .3-1/2 Liner Top B Shale TD~-Cas, in9 Pt i i i i i i i i i i i i i i i i i i i i i ii i i i ~ i i i i 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 VerffcalSection(feel)-> Azlmufh 105,92 wlfh reference 0,00 N, 0,00 E from sial #11 500 t/3 --I- 1000 :3- 1500 .~- I V 2000 TD LOCATION: 2573' FNL, 2142' FWL SEC. 19, T11N, R11E J Created by rixse FOR: L[J3~D I Dote plotted: 25-Sep-1999 I Plot Reference rs 11 Version 1~6, I Coordinates ore in feet reference slot ~11. I True Vertical Depths ore reference rkb Pool ~6. ARCO Alaska, Inc. $trua4ure: Pad 1D Well : 11 Field: Kuparuk River Unlf Location: North Slope, Alaska Point Begin 1.5 Deg/lO0' B Begin 5 Deg Build & Begin 5 Deg Build & Base of Permafrost EOC Top of West Sa k Base of West Sak 9 5/8 Casing Point C80 C50 C40 C50 C20 Base HRZ-7 Casing P K-1 Top of Kuparuk D Target - Top C4 Top C3 To p C2 Top C1 Top B Shale ,TD-Casing Pt PROFILE MD 250.00 400.00 1200.00 1726.00 2425.18 5592.65 6451.54 6830.74 7198.56 8874.62 9582.74 10044.45 10296.61 10455.88 10590.49 1O727.O0 10742.17 10797.1 6 10842.66 10865.41 10882.47 11024.67 Inc 0.00 2.25 25.68 58.88 58.17 58.17 58.17 58.17 58.17 58.17 58.17 58.17 58.17 58.17 58.17 58.17 58.17 58.17 58.17 58.17 58.17 58.17 COMMEN Dir 0.00 90.00 50 O0 1546 02 47 02.47 02.47 02.47 02.47 02.47 02.47 02.47 02.47 02.47 02.47 02.47 02.47 02.47 02.47 02.47 TVD 250.00 599.96 1171.45 1616.00 2076.33 5748.00 4201.00 4401.00 4595.00 5479.00 5747.00 6096.00 6229.00 6515.00 6584.00 6456.00 6464.0O 6495.00 6517.00 6529.00 6538.00 6613.00 02.47 02.47 T DATA North 0.00 0.00 - 113.09 -252.96 -405.69 -986.94 - 1144.45 -1215.99 - 1281.44 -1588.81 - 1 681.99 -1803.34 - 1849.59 -1878.79 - 1905.48 -1928.52 -1931.50 -1941.38 -1949.72 -1955.90 -1957.03 -1985.10 East 0.00 2.94 155.66 595.94 889.38 3518.69 4231.19 4545.77 4850.90 6241.31 6662.84 7211.77 742O.96 7553.08 7664.75 7778.00 7790.58 7836.19 7875.94 7892.82 7906.97 8024.94 V. Sect 0.00 2.86 176.35 445.24 960.87 3652.78 4382.26 4704,52 501 6.72 6440.24 6871.80 7453.80 7647.97 7783.24 7897.57 8013.51 8026.4O 8073.10 8111.74 8131.07 8145.56 8266.33 Deg/lO0 0.00 1.50 3.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0,00 0.00 0.00 0.00 0.00 0,00 0.00 0.00: ICreoted by rixse FOR: LLOYD1 Date plotted: 23-Sep-1999 Plot Reference is 11 Version ~6. Coordinates ore tn feet reference slot ~11. True Vertical Depths are reference rkb Pool ~64 ARCO Alaska, Inc. Structure: Pod 1D Well : 11 Field : Kuparuk River Unit Location : North Slope, Alaska SURFACE LOCATION: L .586' FNL, 601' FEL SEC. 2.3, T11N, RIOE East (feet) -> 400 0 400 800 1200 1600 2000 2400 2800 ,.3200 3600 4000 4400 4BO0 5200 5600 6000 6400 6800 7200 7600 BO00 B400 I I J I I I I I I I I I I I I I I I I I I I I [ I I I I I I I I I I [ I I t I I I I I I I Begin 1.5 De§/lO0' Build Begin 5 Deg Build & Turn to 150 Az e'~Begin 5 Deg Build & Turn to 102.5 Az e of Permafrost ~c 103.92 AZIMUTH 8026' (TO TARGET) ***Plcne of Proposal*** 400 400 0 800 ~ :3- West Sak ~ ~ Base of West Sak '-~ '~'~'~-~_~ 9 5/8 Casing Point 1200 ~ q~ ~ ~ 2000 TD LOCATION: I 2573' FNL, 2142' FWL ~ ~ SEC. 19, T11N, R11E I TARGET LOCATION: 2521' FNL, 1908' FWL SEC. 19, T11N, R11E ARCO Alaska, Inc. Pad 1D 11 slot 11 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 11 Version#6 Our ref : prop3443 License : Date printed : 23-Sep-1999 Date created : 7-Jun-1999 Last revised : 23-Sep-1999 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is n70 17 55.553,w149 30 36.428 Slot Grid coordinates are N 5959078.720, E 560490.724 Slot local coordinates are 586.00 S 601.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. . Pad 1D.11 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 11 Version#6 Last revised : 23-Sep-1999 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S Dogleg Vert Deg/lOOft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 250.00 0.00 0.00 250.00 0.00 N 0.00 E 0.00 300.00 0.75 90.00 300.00 0.00 N 0.33 E 1.50 400.00 2.25 90.00 399.96 0.00 N 2.94 E 1.50 500.00 4.89 114.88 499.76 1.79 S 8.77 E 3.00 0.00 0.00 Begin 1.5 De9/lO0' Build 0.32 2.86 Begin 3 Deg Build & Turn to 130 Az 8.95 600.00 7.79 121.87 599.14 7.17 S 18.40 E 3.00 700.00 10.75 125.06 697.83 16.10 S 31.79 E 3.00 800.00 13.72 126.88 795.54 28.58 S 48.92 E 3.00 900.00 16.71 128.07 892.03 44.57 S 69.73 E 3.00 1000.00 19.70 128.90 987.01 64.02 S 94.17 E 3.00 19.58 34.73 54.36 78.41 106.81 1100.00 22.69 129.52 1080.24 86.88 S 122.17 E 3.00 1200.00 25.68 130.00 1171.45 113.09 S 153.66 E 3.00 1300.00 28.01 125.80 1260.67 140.76 S 189.31E 3.00 1400.00 30.44 122.21 1347.94 168.00 S 229.80 E 3.00 1500.00 32.96 119.11 1433.02 194.75 S 275.02 E 3.00 139.49 176.35 Begin 3 Deg Build & Turn to 102.5 Az 217.62 263.47 313.80 1600.00 35.55 116.41 1515.67 220.92 S 324.83 E 3.00 1700.00 38.19 114.03 1595.67 246.44 S 379.12 E 3.00 1726.00 38.88 113.46 1616.00 252.96 S 393.94 E 3.00 1800.00 40.87 111.92 1672.79 271.25 S 437.72 E 3.00 1900.00 43.59 110.02 1746.83 295.27 S 500.48 E 3.00 368.45 427.28 443.24 Base of Permafrost 490.13 556.82 2000.00 46.34 108.31 1817.58 318.44 S 567.22 E 3.00 2100.00 49.10 106.75 1884.86 340.70 S 637.77 E 3.00 2200.00 51.89 105.31 1948.46 361.99 S 711.92 E 3.00 2300.00 54.70 103.98 2008.23 382.25 S 789.48 E 3.00 2400.00 57.51 102.74 2063.99 401.41 S 870.23 E 3.00 627.18 701.01 778.11 858.26 941.25 2423.18 58.17 102.47 2076.33 405.69 S 889.38 E 3.00 2500.00 58.17 102.47 2116.85 419.78 S 953.11 E 0.00 3000.00 58.17 102.47 2380.56 511.48 S 1367.90 E 0.00 3500.00 58.17 102.47 2644.28 603.17 S 1782.68 E 0.00 4000.00 58.17 102.47 2907.99 694.86 S 2197.47 E 0.00 960.87 EOC 1026.12 1450.78 1875.44 2300.10 4500.00 58.17 102.47 3171.70 786.56 S 2612.25 E 0.00 2724 5000.00 58.17 102.47 3435.42 878.25 S 3027.04 E 0.00 3149 5500.00 58.17 102.47 3699.13 969.95 S 3441.82 E 0.00 3574 5592.65 58.17 102.47 3748.00 986.94 S 3518.69 E 0.00 3652 6000.00 58.17 102.47 3962.85 1061.64 S 3856.61 E 0.00 3998 .77 .43 .09 .78 Top of West Sak .75 6451.54 58.17 102.47 4201.00 1144.45 S 4231.19 E 0.00 4382 6500.00 58.17 102.47 4226.56 1153.33 S 4271.40 E 0.00 4423 6830.74 58.17 102.47 4401.00 1213.99 S 4545.77 E 0.00 4704 7000.00 58.17 102.47 4490.27 1245.03 S 4686.18 E 0.00 4848 7198.56 58.17 102.47 4595.00 1281.44 S 4850.90 E 0.00 5016 .26 Base of West Sak .42 .32 9 5/8" Casing Point .08 .72 C80 7500.00 58.17 102.47 4753.99 1336.72 S 5100.97 E 0.00 5272.74 8000.00 58.17 102.47 5017.70 1428.42 S 5515.75 E 0.00 5697.40 8500.00 58.17 102.47 5281.42 1520.11 S 5930.54 E 0.00 6122.06 8874.62 58.17 102.47 5479.00 1588.81 S 6241.31E 0.00 6440.24 C50 9000.00 58.17 102.47 5545.13 1611.80 S 6345.32 E 0.00 6546.73 9382.74 58.17 102.47 5747.00 1681.99 S 6662.84 E 0.00 6871.80 C40 9500.00 58.17 102.47 5808.84 1703.50 S 6760.11 E 0.00 6971.39 10000.00 58.17 102.47 6072.56 1795.19 S 7174.90 E 0.00 7396.05 10044.45 58.17 102.47 6096.00 1803.34 S 7211.77 E 0.00 7433.80 C30 10296.61 58.17 102.47 6229.00 1849.59 S 7420.96 E 0.00 7647.97 C20 All data is in feet unless otherwise stated. Coordinates from slot 11 and TVD from rkb Pool #6 (105.00 Ft above mean sea level). Bottom hole distance is 8266.34 on azimuth 103.88 degrees from wellhead. Total Dogleg for wellpath is 62.95 degrees. Vertical section is from wellhead on azimuth 103.92 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. .. Pad 1D,11 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTING Page 2 Your ref : 11 Version#6 Last revised : 23-Sep-1999 Dogleg Vert Deg/lOOft Sect 10455.88 58.17 102.47 6313.00 1878.79 S 7553.08 E 0.00 10500.00 58.17 102,47 6336.27 1886.89 S 7589.68 E 0.00 10590.49 58.17 102.47 6384.00 1903.48 S 7664.75 E 0.00 10727.00 58.17 102.47 6456.00 1928.52 S 7778.00 E 0.00 10742.17 58.17 102.47 6464.00 1931.30 S 7790.58 E 0.00 7783.24 Base HRZ-7" Casing Pt 7820.71 7897.57 K-1 8013.51 Top of Kuparuk D 8026.40 Target-Top C4 Version#6 10797.16 58.17 102.47 6493.00 1941.38 S 7836.19 E 0.00 8073.10 Top C3 10842.66 58.17 102.47 6517.00 1949.72 S 7873.94 E 0.00 8111.74 Top C2 10865.41 58.17 102.47 6529.00 1953.90 S 7892.82 E 0.00 8131.07 Top C1 10882.47 58.17 102.47 6538.00 1957.03 S 7906.97 E 0.00 8145.56 Top B Shale 11000.00 58.17 102.47 6599.99 1978.58 S 8004.47 E 0.00 8245.38 11024.67 58.17 102.47 6613.00 1983.10 S 8024.94 E 0.00 8266.33 TD-Casing Pt All data is in feet unless otherwise stated. Coordinates from slot 11 and TVD from rkb Pool ~6 (105.00 Ft above mean sea level). Bottom hole distance is 8266.34 on azimuth 103.88 degrees from wellhead. Total Dogleg for wellpath is 62.95 degrees. Vertical section is from wellhead on azimuth 103.92 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D, 11 Kuparuk River Unit,North Slope. Alaska PROPOSAL LISTING Page 3 Your ref : 11 Version#6 Last revised : 23-Sep-1999 Comments in wel 1 path MD TVD Rectangul ar Coords. Comment ....... ....... 400 O0 1200 O0 1726 O0 2423 18 5592 65 6451 54 6830 74 7198 56 8874 62 9382 74 10044.45 10296.61 10455.88 10590.49 10727.00 10742.17 10797.16 10842.66 10865.41 10882.47 11024.67 399.96 1171.45 1616.00 2076.33 3748.00 4201.00 4401.00 4595.00 5479.00 5747.00 6096.00 6229.00 6313.00 6384.00 6456.00 6464.00 6493.00 6517.00 6529.00 6538.00 6613.00 0 O0 113 09 252 96 405 69 986 94 1144 45 1213 99 1281.44 1588.81 1681.99 1803.34 1849.59 1878.79 1903.48 1928.52 1931 30 1941 38 1949 72 1953 90 1957 03 1983 10 N 2.94 E Begin 3 Deg Build & Turn to 130 Az S 153.66 E Begin 3 Deg Build & Turn to 102.5 Az S 393.94 E Base of Permafrost S 889.38 E EOC S 3518.69 E Top of West Sak S 4231.19 E Base of West Sak S 4545.77 E 9 5/8" Casing Point S 4850,90 E C80 S 6241.31E C50 S 6662.84 E C40 S 7211,77 E C30 S 7420.96 E C20 S 7553.08 E Base HRZ-7" Casing Pt S 7664.75 E K-1 S 7778.00 E Top of Kuparuk D S 7790.58 E Target-Top C4 Version#6 S 7836.19 E Top C3 S 7873.94 E Top C2 S 7892.82 E Top C1 S 7906.97 E Top B Shale S 8024.94 E TD-Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 6830.74 4401.00 1213.99S 4545.77E 9 5/8" Casing 0.00 0.00 O.OON O.OOE 10455.88 6313.00 1878.79S 7553.08E 7" Casing 0.00 0.00 O.OON O.OOE 11024.70 6613.00 1983.10S 8024.94E 3-1/2" Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised Target-Top C4 Versio 568296.000,5957211.000,-2.000 6464.00 1931.30S 7790.58E 9-Sep-1999 ARCO Alaska, Inc. .. Pad 1D,11 Kuparuk River Unit,North Slope, Alaska Depth Measured Inclin. Azimuth True Vert R E C T Degrees Degrees Depth C 0 0 R 0.00 0.00 0.00 0.00 0.00 250.00 0.00 0.00 250.00 0.00 300.00 0.75 90.00 300.00 0.00 400.00 2,25 90,00 399.96 0.00 500.00 4.89 114.88 499.76 1.79 600.00 7.79 12~.87 599.14 7.17 700.00 10.75 125.06 697.83 16.10 800.00 13.72 126.88 795.54 28.58 900.00 16.71 128.07 892.03 44.57 1000.00 19.70 128.90 987.01 64.02 1100.00 22.69 129,52 1080.24 86.88 1200.00 25.68 130.00 1171.45 113,09 1300.00 28.01 125,80 1260.67 140.76 1400.00 30.44 122.21 1347.94 168.00 1500.00 32.96 119.11 1433.02 194.75 1600.00 35.55 116,41 1515.67 220.92 1700.00 38.19 114.03 1595,67 246.44 1726.00 38.88 113.46 1616.00 252.96 1800.00 40.87 111.92 1672.79 271.25 1900,00 43.59 110.02 1746.83 295.27 2000.00 46.34 108.31 1817.58 318.44 2100.00 49.10 106.75 1884.86 340.70 2200.00 51.89 105.31 1948.46 361.99 2300.00 54.70 103.98 2008.23 382.25 2400,00 57.51 102.74 2063.99 401.41 2423.18 58.17 102.47 2076.33 405,69 2500.00 58.17 102.47 2116.85 419.78 3000.00 58.17 102.47 2380,56 511.48 3500.00 58.17 102.47 2644.28 603.17 4000.00 58.17 102.47 2907.99 694.86 PROPOSAL LISTING Page 1 Your ref : 11Version#6 Last revised : 23-Sep-1999 A N G U L A R Vert Ellipse Semi Axes Minor D I N A T E S Sect Major Minor Vert. Azi. N 0.00 E 0.00 0.00 0.00 0.00 N/A N 0.00 E 0.00 0.65 0.65 0.38 N/A N 0.33 E 0.32 0.78 0.78 0.45 N/A N 2.94 E 2.86 1.06 1.05 0.60 90.00 S 8.77 E 8.95 1.38 1.31 0.75 106.32 S 18.40 E 19.58 1.82 1.59 0.90 114.45 S 31.79 E 34.73 2.44 1.88 1.06 119.02 S 48.92 E 54.36 3.28 2.20 1.22 121.89 S 69.73 E 78.41 4.35 2.54 1.39 123.86 S 94.17 E 106.81 5.68 2.92 1.57 125.29 S 122.17 E 139.49 7.29 3.32 1.77 126.37 S 153.66 E 176.35 9.18 3.75 2.00 127.22 S 189.31 E 217.62 11.37 4.21 2.25 126.95 S 229.80 E 263.47 13.87 4.69 2.53 126.06 S 275.02 E 313.80 16.71 5.18 2.85 124.82 S 324.83 E 368.45 19.90 5.70 3.21 123.40 S 379.12 E 427.28 23.49 6.22 3.61 121.89 S 393.94 E 443.24 24.52 6.37 3.73 121.50 S 437.72 E 490.13 27.47 6.76 4.06 120.37 S 500.48 E 556.82 31.87 7.31 4.56 118.86 S 567.22 E 627.18 36.69 7.86 5.10 117.40 S 637.77 E 701.01 41.94 8.41 5.70 116.00 S 711.92 E 778.11 47.63 8.96 6,35 114.66 S 789.48 E 858,26 53.73 9.49 7.05 113.39 S 870.23 E 941.25 60.24 10.02 7.80 112.18 S 889.38 E 960.87 61.78 10.13 7.98 111.93 S 953,11 E 1026.12 66.89 10.53 8.57 111.17 S 1367,90 E 1450.78 100.49 13.06 12.47 108.17 S 1782.68 E 1875.44 134.38 15.57 16.39 106.70 S 2197.47 E 2300.10 168,38 18.07 20.33 105.83 4500.00 58.17 102.47 3171.70 786.56 S 2612.25 E 2724.77 202.43 20.57 24.27 105.25 5000.00 58.17 102.47 3435.42 878.25 S 3027.04 E 3149.43 236.52 23.08 28,22 104.85 5500,00 58.17 102.47 3699.13 969.95 S 3441.82 E 3574.09 270.63 25.59 32.17 104.54 5592.65 58,17 102.47 3748.00 986.94 S 3518.69 E 3652.78 276.95 26.05 32.90 104.50 6000.00 58.17 102.47 3962.85 1061.64 S 3856.61 E 3998.75 304.75 28.10 36.12 104.31 6451.54 58.17 102.47 4201.00 1144.45 S 4231.19 E 4382.26 335.57 30.37 39.69 104.14 6500.00 58.17 102.47 4226.56 1153.33 S 4271.40 E 4423.42 338.88 30.61 40.07 104.12 6830,74 58.17 102.47 4401,00 1213.99 S 4545.77 E 4704.32 361.46 32.27 42.69 104.02 7000.00 58.17 102.47 4490.27 1245.03 S 4686.18 E 4848.08 373.02 33.12 44.02 103.97 7198,56 58.17 102.47 4595,00 1281.44 S 4850.90 E 5016.72 386.57 34.12 45.59 103.92 7500.00 58.17 102.47 4753,99 1336.72 S 5100.97 E 5272.74 407.16 35.64 47.98 103.84 8000.00 58.17 102.47 5017.70 1428.42 S 5515.75 E 5697.40 441.30 38.16 51.93 103.73 8500.00 58.17 102.47 5281.42 1520.11 S 5930.54 E 6122.06 475.45 40.67 55.89 103.64 8874.62 58.17 102.47 5479,00 1588.81 S 6241.31E 6440.24 501.04 42.56 58.85 103.58 9000.00 58.17 102.47 5545.13 1611.80 S 6345.32 E 6546.73 509.60 43.19 59.84 103.56 9382.74 58.17 102.47 5747.00 1681.99 S 6662.84 E 6871.80 535.74 45.12 62.87 103.51 9500.00 58.17 102.47 5808,84 1703.50 S 6760.11E 6971.39 543,75 45.71 63.80 103.49 10000.00 58.17 102.47 6072.56 1795.19 S 7174,90 E 7396.05 577.90 48.23 67.76 103.43 10044.45 58.17 102.47 6096.00 1803.34 S 7211.77 E 7433.80 580.94 48.46 68.11 103.43 10296.61 58.17 102.47 6229.00 1849.59 S 7420.96 E 7647.97 598.17 49.73 70.10 103.40 All data is in feet unless otherwise stated. Coordinates from slot 11 and TVD from rkb Pool ~6 (105.00 Ft above mean sea level). Bottom hole distance is 8266.34 on azimuth 103.88 degrees from wellhead. Vertical section is from wellhead on azimuth 103.92 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. · Pad 1D,11 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTING Page 2 Your ref : 11 Version#6 Last revised : 23-Sep-1999 Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 10455.88 58.17 102.47 6313.00 1878.79 S 7553.08 E 7783.24 609.04 50.53 71.36 103.38 10500.00 58.17 102.47 6336.27 1886.89 S 7589.68 E 7820.71 612.06 50.75 71.71 103.38 10590.49 58.17 102.47 6384.00 1903.48 S 7664.75 E 7897.57 618.24 51.21 72.43 103.37 10727.00 58.17 102.47 6456.00 1928.52 S 7778.00 E 8013.51 627.57 51.90 73.51 103.36 10742.17 58.17 102.47 6464.00 1931.30 S 7790.58 E 8026.40 628.60 51.97 73.63 103.35 10797.16 58.17 102.47 6493.00 1941.38 S 7836.19 E 8073.10 632.36 52.25 74.06 103.35 10842.66 58.17 102.47 6517.00 1949.72 S 7873,94 E 8111.74 635.47 52.48 74.42 103.34 10865.41 58.17 102,47 6529.00 1953.90 S 7892.82 E 8131.07 637.02 52.59 74.60 103.34 10882.47 58.17 102,47 6538.00 1957.03 S 7906.97 E 8145,56 638.19 52.68 74.74 103.34 11000.00 58.17 102.47 6599.99 1978.58 S 8004.47 E 8245.38 646.21 53.27 75.67 103.33 11024.67 58.17 102.47 6613.00 1983.10 S 8024.94 E 8266.33 647.90 53.40 75.86 103.33 POSITION UNCERTAINTY SUMMARY .... Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 11025 ARCO (H.A. Mag) User specified 647.90 53.40 75.86 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. All data is in feet unless otherwise stated. Coordinates from slot 11 and TVD from rkb Pool #6 (105.00 Ft above mean sea level). Bottom hole distance is 8266.34 on azimuth 103.88 degrees from wellhead. Vertical section is from wellhead on azimuth 103.92 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. · Pad 1D, 11 Kuparuk River Unit. North Sl ope, A1 aska PROPOSAL LISTING Page 3 Your ref : 11 Version ~6 Last revised : 23-Sep-1999 Comments in wellpath MD TVD Rectangular Coords. Comment 250.00 400.00 1200.00 1726 O0 2423 18 5592 65 6451 54 6830 74 7198 56 8874 62 9382 74 10O44 45 10296 61 10455 88 10590.49 10727.00 10742.17 10797.16 10842.66 10865.41 10882.47 11024.67 O0 96 45 O0 33 O0 25O 399 1171 1616 2076 3748 4201 O0 4401 O0 4595 O0 5479 O0 5747 O0 6096.00 6229.00 6313.00 6384.00 6456.00 6464.00 6493.00 6517.00 6529.00 6538.00 6613.00 0.00 N 0.00 N 113.09 S 252.96 S 405.69 S 986.94 S 1144.45 S 1213.99 S 1281.44 S 1588.81 S 1681.99 S 1803.34 S 1849.59 S 1878.79 S 1903.48 S 1928.52 S 1931.30 S 1941.38 S 1949.72 S 1953.90 S 1957.03 S 1983.10 S 0.00 2.94 153.66 393.94 889.38 3518.69 4231.19 4545.77 4850.90 6241.31 6662.84 7211.77 7420.96 7553.08 7664 75 7778 O0 7790 58 7836 19 7873 94 7892 82 7906 97 8024 94 E Begin 1.5 Deg/lO0' Build E Begin 3 Deg Build & Turn to 130 Az E Begin 3 Deg Build & Turn to 102.5 Az E Base of Permafrost EEOC E Top of West Sak E Base of West Sak E 9 5/8" Casing Point E C80 E C50 E C40 E C30 E C20 E Base HRZ-7" Casing Pt E K-1 E Top of Kuparuk D E Target-Top C4 Version #6 E Top C3 E Top C2 E Top C1 E Top B Shale E TD-Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 6830.74 4401.00 1213.99S 4545.77E 9 5/8" Casing 0.00 0.00 O.OON O.OOE 10455.88 6313.00 1878.79S 7553.08E 7" Casing 0.00 0.00 O.OON O.OOE 11024.70 6613.00 1983.10S 8024.94E 3-1/2" Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised Target-Top C4 Versio 568296.000,5957211.000,-2.000 6464.00 1931.30S 7790.58E 9-Sep-1999 ARCO Alaska, Inc. Pad 1D, 11 Kuparuk River Unit,North Slope. A1 aska Measured Inclin Azimuth True Vert Depth Degrees Degrees Depth PROPOSAL LISTING Page 1 Your ref : 11 Version#6 Last revised : 23-Sep-1999 R E C T A N G U L A R Dogleg Vert C 0 0 R D I N A T E S Deg/lOOft Sect 0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 0.00 250.00 0.00 0.00 250.00 O.OON 0.OOE 0.00 0.00 300.00 0.75 90.00 300.00 O.OON 0.33E 1.50 0.32 400.00 2.25 90.00 399.96 O.OON 2.94E 1.50 2.86 500.00 4.89 114.88 499.76 1.79S 8.77E 3.00 8.95 600.00 7.79 121.87 599.14 7.17S 18.40E 3.00 19.58 700.00 10.75 125.06 697.83 16.10S 31.79E 3.00 34.73 800.00 13.72 126.88 795.54 28.58S 48.92E 3.00 54.36 900.00 16.71 128.07 892.03 44.57S 69.73E 3.00 78.41 1000.00 19.70 128.90 987.01 64.02S 94.17E 3.00 106.81 1100.00 22.69 129.52 1080.24 86.88S 122.17E 3.00 139.49 1200.00 25.68 130.00 1171.45 113.09S 153.66E 3.00 176.35 1300.00 28.01 125.80 1260.67 140.76S 189.31E 3.00 217.62 1400.00 30.44 122.21 1347.94 168.00S 229.80E 3.00 263.47 1500.00 32.96 119.11 1433.02 194.75S 275.02E 3.00 313.80 1600.00 35.55 116.41 1515.67 220.92S 324.83E 3.00 368.45 1700.00 38.19 114.03 1595.67 246.44S 379.12E 3.00 427.28 1726.00 38.88 113.46 1616.00 252.96S 393.94E 3.00 443.24 1800.00 40.87 111.92 1672.79 271.25S 437.72E 3.00 490.13 1900.00 43.59 110.02 1746.83 295.27S 500.48E 3.00 556.82 2000.00 46.34 108.31 1817.58 318.44S 567.22E 3.00 627.18 2100.00 49.10 106.75 1884.86 340.70S 637.77E 3.00 701.01 2200.00 51.89 105.31 1948.46 361.99S 711.92E 3.00 778.11 2300.00 54.70 103.98 2008.23 382.25S 789.48E 3.00 858.26 2400.00 57.51 102.74 2063.99 401.41S 870.23E 3.00 941.25 2423.18 58.17 102.47 2076.33 405.69S 889.38E 3.00 960.87 2500.00 58.17 102.47 2116.85 419.78S 953.11E 0.00 1026.12 3000.00 58.17 102.47 2380.56 511.48S 1367.90E 0.00 1450.78 3500.00 58.17 102.47 2644.28 603.17S 1782.68E O.OD 1875.44 4000.00 58.17 102.47 2907.99 694.86S 2197.47E 0.00 2300.10 4500.00 58.17 102.47 3171.70 786.56S 2612.25E 0.00 2724.77 5000.00 58.17 102.47 3435.42 878.25S 3027.04E 0.00 3149.43 5500.00 58.17 102.47 3699.13 969.95S 3441.82E 0.00 3574.09 5592.65 58.17 102.47 3748.00 986.94S 3518.69E 0.00 3652.78 6000.00 58.17 102.47 3962.85 1061.64S 3856.61E 0.00 3998.75 6451.54 58.17 102.47 4201.00 1144.45S 4231.19E 0.00 4382.26 6500.00 58.17 102.47 4226.56 1153.33S 4271.40E 0.00 4423.42 6830.74 58.17 102.47 4401.00 1213.99S 4545.77E D.O0 4704.32 7000.00 58.17 102.47 4490.27 1245.03S 4686.18E 0.00 4848.08 7198.56 58.17 102.47 4595.00 1281.44S 4850.90E 0.00 5016.72 7500.00 58.17 102.47 4753.99 1336.72S 5100.97E 0.00 5272.74 8000.00 58.17 102.47 5017.70 1428.42S 5515.75E 0.00 5697.40 8500.00 58.17 102.47 5281.42 1520.11S 5930.54E 0.00 6122.06 8874.62 58.17 102.47 5479.00 1588.81S 6241.31E 0.00 6440.24 9000.00 58.17 102.47 5545.13 1611.80S 6345.32E 0.00 6546.73 GR I D C OORDS Easting Northing 560490.72 5959078.72 560490.72 5959078.72 560491.05 5959078.72 560493.67 5959078.74 560499.51 5959077.00 560509.18 5959071.70 560522.64 5959062.88 560539.87 5959050.54 560560.81 5959034.72 560585.40 5959015.47 560613.59 5958992.84 560645.28 5958966.89 560681.15 5958939.52 560721.86 5958912.61 560767.29 5958886.23 560817.31 5958860.47 560871.80 5958835.39 560886.67 5958829.00 560930.59 5958811.07 560993.54 5958787.56 561060.46 5958764.93 561131.18 5958743.24 561205.50 5958722.56 561283.21 5958702.94 561364.11 5958684.43 561383.29 5958680.31 561447.12 5958666.74 561862.60 5958578.43 562278.08 5958490.12 562693.56 5958401.81 563109.04 5958313.50 563524.51 5958225.19 563939.99 5958136.88 564016.98 5958120.51 564355.47 5958048.57 564730.68 5957968.82 564770.95 5957960.26 565045.77 5957901.84 565186.42 5957871.95 565351.42 5957836.88 565601.90 5957783.64 566017.38 5957695.32 566432.86 5957607.01 566744.15 5957540.85 566848.33 5957518.70 9382.74 58.17 102.47 5747.00 1681.99S 6662.84E 0.00 6871.80 567166.38 5957451.10 9500.00 58.17 102.47 5808.84 1703.50S 6760.11E 0.00 6971.39 567263.81 5957430.39 10000.00 58.17 102.47 6072.56 1795.19S 7174.90E 0.00 7396.05 567679.29 5957342.08 10044.45 58.17 102.47 6096.00 1803.34S 7211.77E 0.00 7433.80 567716.22 5957334.23 10296.61 58.17 102.47 6229.00 1849.59S 7420.96E 0.00 7647.97 567925.76 5957289.69 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot 11 and TVD from rkb Pool ~6 (105.00 Ft above mean sea level). Bottom hole distance is 8266.34 on azimuth 103.88 degrees from wellhead. Total Dogleg for wellpath is 62.95 degrees. Vertical section is from wellhead on azimuth 103.92 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid ARCO Alaska, Inc. Pad 1D, 11 Kuparuk River Unit,North Slope, Alaska Measured Inclin Azimuth True Vert Depth Degrees Degrees Depth Presented by Baker Hugh~s INTEQr PROPOSAL LISTING Page 2 Your ref: 11 Version#6 Last revised : 23-Sep-1999 R E C TAN G U L A R Dogleg Vert G R I D C 0 0 R D S C 0 0 R D I N A T E S Deg/lOOft Sect Easting Northing 10455.88 58.17 102.47 6313.00 1878.79S 7553.08E 0.00 7783.24 10500.00 58.17 102.47 6336.27 1886.89S 7589.68E 0.00 7820.71 10590.49 58.17 102.47 6384.00 1903.48S 7664.75E 0.00 7897.57 10727.00 58.17 102.47 6456.00 1928.52S 7778.00E 0.00 8013.51 10742.17 58.17 102.47 6464.00 1931.30S 7790.58E 0.00 8026.40 10797.16 58.17 102.47 6493.00 1941.38S 7836.19E 0.00 8073.10 10842.66 58.17 102.47 6517.00 1949.72S 7873.94E 0.00 8111.74 10865.41 58.17 102.47 6529.00 1953.90S 7892.82E 0.00 8131.07 10882.47 58.17 102.47 6538.00 1957.03S 7906.97E 0.00 8145.56 11000.00 58.17 102.47 6599.99 1978.58S 8004.47E 0.00 8245.38 11024.67 58.17 102.47 6613.00 568058.10 5957261.57 568094.77 5957253.77 568169.96 5957237.79 568283.40 5957213.68 568296.00 5957211.00 568341.69 5957201.29 568379.50 5957193.25 568398.41 5957189.23 568412.59 5957186.22 568510.24 5957165.46 1983.10S 8024.94E 0.00 8266.33 568530.75 5957161.10 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot 11 and TVD from rkb Pool ~6 (105.00 Ft above mean sea level). Bottom hole distance is 8266.34 on azimuth 103.88 degrees from wellhead. Total Dogleg for wellpath is 62.95 degrees. Vertical section is from wellhead on azimuth 103.92 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hugh~s INTEQ~ · ARCO Alaska, Inc. Pad 1D,11 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 11 Version#6 Last revised : 23-Sep-1999 Comments in wellpath MD TVD Rectangular Coords. Comment 250 O0 400 O0 1200 O0 1726 O0 2423 18 5592 65 6451 54 6830 74 7198 56 8874 62 9382.74 10044.45 10296.61 10455.88 10590.49 10727.00 10742.17 10797.16 10842.66 10865.41 10882.47 11024.67 250 O0 399 96 1171 45 1616 O0 2076 33 3748 O0 4201 O0 4401.00 4595.00 5479.00 5747.00 6096.00 6229.00 6313.00 6384.00 6456.00 6464.00 6493.00 6517.00 6529.00 6538.00 6613.00 O.OON O.OOE Begin 1.5 Deg/lO0' Build O.OON 2.94E Begin 3 Deg Build & Turn to 130 Az 113.09S 153.66E Begin 3 Deg Build & Turn to 102.5 Az 252.96S 393.94E Base of Permafrost 405.69S 889.38E EOC 986.94S 3518.69E Top of West Sak 1144.45S 4231.19E Base of West Sak 1213.99S 4545.77E 9 5/8" Casing Point 1281.44S 4850.90E C80 1588.81S 6241.31E C50 1681.99S 6662.84E C40 1803.34S 7211.77E C30 1849.59S 7420.96E C20 1878.79S 7553.08E Base HRZ-7" Casing Pt 1903.48S 7664.75E K-1 1928.52S 7778.00E Top of Kuparuk D 1931.30S 7790.58E Target-Top C4 Version#6 1941.38S 7836.19E Top C3 1949.72S 7873.94E Top C2 1953.90S 7892.82E Top Cl 1957.03S 7906.97E Top B Shale 1983.10S 8024.94E TD-Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot I'VD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 6830.74 4401.00 1213.99S 4545.77E 9 5/8" Casing 0.00 0.00 O.OON O.OOE 10455.88 6313.00 1878.79S 7553.08E 7" Casing 0.00 0.00 O.OON O.OOE 11024.70 6613.00 1983.10S 8024.94E 3-1/2" Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised Target-Top C4 Versio 568296.000.5957211.000,-2.000 6464.00 1931.30S 7790.58E 9-Sep-1999 ARCO Alaska, Inc. Pad 1D 11 slot 11 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 11 Version#6 Our ref : prop3443 License : Date printed : 23-Sep-1999 Date created : 7-Jun-1999 Last revised : 23-Sep-1999 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is n70 17 55.553,w149 30 36.428 Slot Grid coordinates are N 5959078.720, E 560490.724 Slot local coordinates are 586.00 S 601.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wel 1 path Closest approach with 3-D Minimum Distance method Last revi PMSS <O-4590'>,,118,Pad 1D 2-Jun- sed Distance M.D. 1998 479.4 411.1 13-Nov-1997 222.0 400.0 2-Jun-1998 195.0 100.0 23-Apr-1999 3705.3 9640.0 28-0ct-1998 660.0 100.0 22-Sep-1998 555.0 160.0 29-Apr-1998 450.0 100.0 4-Aug-1992 702.8 400.0 2-Jun-1998 719.5 287.5 10-Dec-1997 822.8 400.0 11-Jun-1999 16.2 500.0 28-Apr-1998 23.1 500.0 2-Jun-1998 405.0 100.0 2-Jun-1998 435.0 100.0 2-Jun-1998 495,0 100.0 2-Jun-1998 645.0 100.0 2-Jun-1998 135.0 100.0 2-Jun-1998 60.0 371.4 6-Nov-1997 103.0 262.5 2-Jun-1998 180.0 100.0 4-Aug-1992 462.6 411.1 2-$un-1998 525.0 160.0 13-Aug-1998 583.0 0.0 2-Jun-1998 420.0 100.0 1-Ju1-1998 285.0 100.0 6-Ju1-1998 268.8 540.0 23-Ju1-1998 140.2 611.1 PGMS <0-8610'>,,6,Pad 1D PMSS <0-5462'>,,129,Pad 1D PGMS <0-8850'> 28-May-81,,MP I 17-ii-Ii,Pad 1D PMSS <0 - 7150'>,,108,Pad 1D PMSS <293 - 6866'>,,113,Pad 1D PMSS <556-7024'>,,9,Pad 1D PGMS <O-9783'>,.2,Pad 1D PMSS <381-6092'>,,105,Pad 1D PGMS <O-8365'>,,1,Pad 1D TOTCO Survey,,WS-8,Pad 1D PMSS <0 - 7340'>,,lO,Pad 1D PMSS <0-4414'>,,121,Pad 1D PMSS <0-4515'>,,119,Pad 1D PMSS <O-5205'>,,117,Pad 1D PMSS <0-4850'>,,109,Pad 1D PMSS <1957-5265'>,,133,Pad 1D PMSS <O-5015'>,,135,Pad 1D MSS <3311-8200'>,.7,Pad 1D PMSS <O-4778'>,,130,Pad 1D PGMS <0-7502'>,,4,Pad 1D PMSS <0-5142'>,,115,Pad 1D PGMS <0-8070'>,,3,Pad 1D PMSS <O-4530'>,,120,Pad 1D PMSS <0 - 6716'>,,126,Pad 1D PMSS <0 - 7432'>,,127,Pad 1D PMSS <0 - 6472'>,,131,Pad 1D Diverging from M.D. 411.1 400 444 9640 8980 160 100 400 287 400 500 50O 100 100 100 100 4444 371.4 262.5 100.0 411.1 160.0 371.4 100.0 100.0 555.6 611.1 PMSS <377 - 6224'>,,13' J 1D PMSS <467 - 5802'>,,132,Kad 1D PMSS <0 - 6580'>,,128,Pa~ 1D PMSS <0 - 5445'>,,122,Pad 1D PMSS <0 - 6270'>,,114,Pad 1D PMSS<O-7045'>,,111,Pad 1D GSS <O-173'>,,123,Pad 1D " PMSS <287-6055'>,,123,Pad 1D GSS <0.175'>,,116,Pad 1D PMSS <290-6245'>,,116,Pad 1D PMSS <294 - 8250'>,,112,Pad 1D PGMS <0-8930'>,,5,Pad 1D PMSS <0-5047'>,,124,Pad 1D PMSS <O-5126'>,,106,Pad 1D PMSS <291 - 5795'>,,125,Pad 1D PMSS <256 - 5973'>,,1lO,Pad 1D PMSS<245-5962'>DepthShiCted,,110,Pad 1D PMSS <O-????>,,12,Pad 1D PMSS <O-????>,,14,Pad 1D 3-Aug-1998 6-Aug-1998 17-Aug-1998 29-Aug-1998 2-Sep-1998 3-Sep-1998 4-Sep-1998 13-Sep-1998 8-Sep-1998 17-Sep-1998 21-Sep-1998 13-Nov-1997 2-Jun-1998 2-Jun-1998 19-Aug-1998 20-Sep-1999 22-Sep-1999 23-Sep-1999 23-Sep-1999 '75.0 108.0 '- 255.0 ~ 389.3 539.0 614.7 375.0 371.9 510.0 510.0 569.9 342.5 315.0 690.0 300.0 630.0 630.0 808.8 795.0 .100 622 100 0 400 0 420 0 400 0 160.0 411 1 100 0 100 0 200 0 300 0 100 0 100 0 100.0 lOO.O lOO.O 433.3 100.0 2 433.3 622.2 633.3 400.0 420.0 400.0 160.0 411.1 100.0 100.0 200.0 300.0 100.0 100.0 100.0 100.0 100.0 433.3 100.0 All Depths are RKB Pool Rig 6 1D-11 FMC Gen IV 9-5/8 x 7 9-5/8. ~~~ Mandrel Hange Base of permafrost at 1,726' MD / 1,616' TVD 12-1/4" Top of West Sak at 5,593' MD / 3,748' TVD Base of West Sak 6,452' MD / 4,201' TVD 9-5/8" 40 ppf L-80 BTC Surface Casing 6,831' MD / 4,401' TVD 8-1/2" Hole Baker 4.5" x 7" SLZXP LTP and Hanger w/PBR @ 10306' MD Weatherford Gemoco 7" Float Collar and Float Shoe Baker 4-1/2" Landing Collar, Float Collar and Float Shoe (1 jt. spacing between each) Completion Type 2 I I 16" Conductor Mud Weight in Surface hole: 10. 0 ppg by 1100' TVD 10.2 ppg by 1900' TVD Weatherford Gemoco 9-5/8" Float Collar and Float Shoe Mud Weight in Production hole 10.8 to 12.5 ppg i:i:!:! 7" 26 L-80 BTC Mod Csg i:i:i:i 10,456' MD / 6,384' TVD 4-1/2" 12.6#/ft ABT-Mod 9/23/1999 Completed 1D-11 FMC Gen V 9-5/8 x 7 x 41/2 Base of permafrost at 1,726' MD/1,61 6' TVD 12-1/4" Hole 9-5/8" 40 ppf L-80 BTC-Mod Surf. Csg. 6,831' MD / 4,401' TVD 81/2" Hole 4Y2" 12.6 ppf L-80 ABT-Mod w/15' seal bore extension tied into top of liner 7" 26 ppf L-80 BTC Intermediate· Csg. 10,456' MD / 6,384' TVD Baker 4.5" x 7" SLZXP LTP and Hanger. TOL @ 10306' MD/6234' TVD 6-1/8" Hole I ,,, · . . · :.:.: 3.81 ... .,.'.' · '.'.' SC~ .,, :.:.:. at 5~ .%... · , , ... · . . :.:.:. .,. ... · . . ;.;.:. .,, · . . .;.:.: · . . · , . · . . · . :-:.; · , :-:.: · . · , :.:.: . . · . . . . I :::::::: CA X:] X :::::::: ~:.;.:.:. CAMCO DB for iV 500' + MD Camco 4W'x 1" KBG-2 GLM 30 or Otis 3.812 X nipple ARCO Alaska, Inc. Kuparuk Unit Disbursement Account P.O. Box 102776 Anchorage, AK 99510-2776 PAY TO THE ORDER OF: 230099275 73-426 839 SEPTEMBER 8, 1999 0997587 STATE OF ALASKA . i!' ' : . ALASKA OIL &i:GA$ cONSERVATION COMMI ..,~ :~ 3001 PORCUPINE "DRIVE · ~'. ',. ' "'~' ' .~i' :i!' ,". ~i' . .... **~ ¥0i~ AFTER 90 DAYS : '..;. i, ~ EXACTLY ****~,.***** i00: DOLLARS AND' O0 CENTs:: ~*********** 100,00 The First National Blank of Chicago-0710 · .. Payable Through Republic Bank Shelbyville, Kentucky TRACE NUMBER: 230099275 ~' ;~ 3DO cicl ii ? 5~' ~:O,O, ~, c~o [, 8 ~ 8~_' OCtCt ? 513 ?~' TON Y KNO WL ES, G 0 VEFINOFI ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 28, 1999 Randv Thomas Drilling Engineering supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99501 Re; Kuparuk River Unit 1 D- 1 l ARCO Alaska. Inc. Permit No: 99-072 Sur Loc: 586'FNL. 601'FEL, Sec. 23. T11N. R10E. UM Btmhole Loc. 2320'FSL. 1394'FEL. Sec. 19. T11N. R11E. UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required bm' law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No. 1D-11. Please note that anv disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Dr/ll Site 1D must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35.000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one vear. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice ma3' bc given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson. P.E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC~ Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 . . la. Type of work: Drill [] Redrill [] lb. Type of well. Exploratory [;~' ~'i;~tigraphicTest• Develop~'entOii~ Re-entry [] Deepen [] Service [] Development Gas [] SingleZone [] Multiple Zone[] 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 35 feet 8. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0361 '~ADL 28243 ALK 3814 Kuparuk River Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 586' FNL, 601' FEL, Sec. 23, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 2401' FSL, 1740' FEL, Sec. 19, T11 N, R11 E, UM 1D-11 #U-630610 At total depth 9. Approximate spud date Amount 2320' FSL, 1394' FEL, Sec. 19, T11N, R11E, UM July 31, 1999 $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 1394 @ TargE feet WS-08 16.5' @ 386' MD feet 2560 12321 'MD/6645'TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 250 MD Maximum hole angle 62.5° Maximum surface 2598 psig At total depth (TVD) 3080 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD FVD (include stage data) 20" 16" 62.5# R-3 Weld 100' 35' 35' 135' 135' 230 sx ASl 12.25" 9.625" 40# L-80 BTC-Mod 7430' 35' 35' 7465' 4404' 840 sx AS III L & 770 sx Class G 8.5" 7" 26# L-80 BTC-Mod 11738' 35' 35' 11773' 6392' 220 sx Class G 6.125" 4.5" 12.6# L-80 ABT-Mod 698' 11623' 6323' 12321' 6645' 170 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: trumeasurede vertical feetfeet Plugs(measured) 0RIG!HAL Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor ,,', >ECEIVE Production Liner Perforation depth: measured Alaska 0il & Gas Con6. C0mmissier Anchorage true vertical 20. Attachments Filing fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Timevs depth plot [] Refraction analysis [] Seabed report [] 20 AAO 25.050 requirements [] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Wilfiam Lloyd 265-653 ~ ~.~ ¢ Title:DdllingEnginoeringSupervisor Date Signed ~ r ~.'TI~¢ pruners, ri OommissJon Use Onl~ Permit Number I APlnumber Approvald.,~e,,~ .., CE:/ [Seecoverletter o o,,- -_.. _. I,oro,,erre,u,,eme.,. Conditions of approval Samples required [] Yes '~ No Mud Icg required [] Yes ~, No Hydrogen sulfide measures [~ Yes [] No Directional survey required J~ Yes [] No Required working pressure for BOPE [] 2M; [] ~.~ [] EM; lOM;• [] Other: ORIGINAL SIGNED BY by order of ¢/. ~.. ~ .... ¢~' Robert N. Christenson Commissioner the commission Date Approved by Form 10-401 Rev. 12/1/85 · Submit in triplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 3uly 9, 1999 Robert Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 ORI®INAL Application for Permit to Drill: KRU 1D-11 Surface Location: 586' FNL, 601' FEL Sec 2:3 T11N R10E, UM Target Location: 2401' FSL, 1740' FEL Sec. 19, T11N, RllE, UM Bottom Hole Location: 2320' FSL, 1394' FEL Sec. 19, T11N, R11E, UM Dear Commissioner Christenson, ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the Kuparuk interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and further develop the production potential of the Kuparuk sands in the vicinity of 1D pad. The well is designated as a conventional injection well using a 9 5/8" surface casing string, a 7" intermediate casing string, a 4 1/2" liner and 4-1/2" tubing. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) 2) 3) 4) 5) 6) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A cOpy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment will be functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 'Alaska Oil & Gas Cons. commissior~ Anchorage Robert Christenson Application for Permit to Drill - 1D-11 Page 2 1) 10) Due to the large volume of regional information available, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. The following are ARCO's designated contacts for reporting responsibilities to the Commission: Completion Report Technologist (20 AAC 25.070) Sharon AIIsup-Drake, Drilling 263-4612 2) Geologic Data and Logs Bill Raatz, Geologist (20 AAC 25.071) 263-4952 The anticipated spud date for this well is July 31, 1999. If you have any questions or require further information, please contact Bill Lloyd at (907) 263-6531 or Chip Alvord at (907) 265-6120. Sincerely, William B. Lloyd Senior Drilling Engineer Kuparuk :I.C-:L8 Well File Chip Alvord ATO-1200 rvlj Loveland NSK6 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS Well KRU 1D-11 Drilling Fluid Properties: Density PV yp-' Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.5 - 10.2 ppg 16-26 25-35 100 - 120* 10-20 15-40 7-15 9.5- 10 +/- 10% Drill out to TD 9.5 - 11.0 ppg 6 - 20 5 - 20 35 - 50 2-6 4-8 < 6 through Kup 9.0- 10 <11% Drilling Fluid System: Pool Rig 6 Triple Derrick Shale Shakers Mud Cleaner, Desander, Desilter Centrifuge Degasser Flow Line Cleaner Pit Level Indicator (Visual / Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 100-150 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.o3~aska''~ & 6aS Cons. ^nchorago Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/fi) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 2598 psi. Therefore, Arco Alaska, Inc. will test the BOP equipment to 3500 psi after setting surface casing. MASP = (4404 ft)(0.70 - 0.11) = 2598 psi Based on offset well data, reservoir pressures in the Kuparuk sands in the vicinity of 1D Pad are expected to be -3475 psi (0.53 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 10.8 ppg would be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 6462'. Target (Kuparuk C4): (3475+150)/(0.052'6462)=10.8. Well Proximity Risks: The nearest existing well to 1D-11 is WS-8. As designed, the minimum distance between the two wells would be 16.5' at 386' MD. Drilling Area Risks: Drilling risks in the 1D-11 area are surface interval hydrates, lost circulation and potential borehole instability in and below the permafrost formation. Hydrate risks will be minimized by the use of sufficient mud weights to allow for tripping of pipe, controlled drilling rates, and optimum rheological properties to safely appropriate gas breakout. Lost circulation will be addressed with lost circulation material (LCM). Annular Pumpinq Operations: ARCO Alaska, Inc. !ncidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class !! disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The ID-:::t:[ surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. !f isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We anticipate that :[D-:[:[ will be requested to be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. All necessary documentation for the permitting of this well for annular injection will be provided after the well is completed. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300- 500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. ARCO Alaska, Inc. Drill and Case Plan for :!.D-11 Kuparuk Producer General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 120' RKB. Weld landing ring on conductor. 2. Hove in / rig up drilling rig. ~[nstall diverter & function test same. 3. Spud and directionally drill 12 1/4" hole to the surface casing point at 7465' MD/4404' TVD. Run iVlWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 9 5/8" 40# L80 BTC casing string to surface. · Employ lightweight permafrost cement lead slurry to assure cement returns to the surface in a one stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. · TAM Port Collar will be placed in the casing string at 1000' MD to be used in the event that cement does not reach the surface in the primary one stage job. 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify AOGCC 24 hours before test 7. Make up 8 1/2" bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 8. Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town 9. Drill 8 1/2" hole to intermediate casing point at +11650' HD/6381' -I-VD · Perform a second LOT and determine an acceptable kick tolerance · ~[f kick tolerance is acceptable, 8 1/2" hole will be drilled to TD · ]:f kick tolerance is unacceptable, 7" casing will be run to top Kuparuk 10. Run and cement 7" 26# L80 BTC-Mod (if required from step #9) Steps 11-14 are only applicable if we are required to top set the Kuparuk with 7" casing 11. Make up 6 1/8" bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 12. Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town 13. Drill 6 1/8" hole to TD at 12321' MD/6645' TVD · Condition hole and mud for casing 14. Run and cement 4 1/2" 12.6# L80 ABT-Hod Liner 15. Make a cleanout run with bit and scrapers if necessary · Displace to filtered seawater · Pressure test well to 3000 psi for 30 minutes · Record results and fax to town :16. Run and land 4 1/2" tubing with gas lift completion 17. Nipple down BOP's. ~[nstall production tree and pressure test same. 18. Secure wellf release rig All Depths are RKB Pool Rig 6 1D-11 Dri. and set Casing b I Mandrel Hange~'%'~-~ Base of permafrost at 1,81 3' MD / 1,685' TVD 12-1/4" Top of West Sak at 6,063' MD / 3,757' TVD Base of West Sak 7,032' MD / 4,204' TVD 9-5/8" 40 ppf L-80 BTC Surface Casing 7,465' MD / 4,404' TVD 8-1/2" Hole Baker 4.5" x 7" SLZXP LTP and tieback sleeve and HMC Liner Hanger w/PBR @ 11623' MD Weatherford Gemoco 7" Float Collar and Float Shoe Baker 4-1/2" Landing Collar, Float Collar and Float Shoe (1 jt. spacing between each) Completion Type 2 ,' ,' 16" Conductor Weatherford Gemoco 9-5/8" PORT Collar Standard Grade, BTC 1,000' MD / 987' TVD Mud Weight in Surface hole: 10. 0 ppg by 1100' TVD 10.2 ppg by 1900' TVD Weatherford Gemoco 9-5/8" Float Collar and Float Shoe Mud Weight in Production hole 10.8 to 12.5 ppg ii!iiii 7" 26 L-80 BTC Mod Csg i:i:i:: 11,773' MD / 6,392' TVD · ,o o. i'.' ;.- :-: :-; ,,.- 4-1/2" 12.6#/ft ABT-Mod 7/9/99 Completed 1D-11 FMC Prudhoe Gen V 9-5/8 x 51/2 x 31/2 Base of permafrost at ~iiiil 1,813' MD / 1,685' TVD .......-'-'"' 12-1/4" Hole Si:i: :.;-;.; Weath,,erford Gemoco _ :i:i: 9-5/8 PORT Collar ~::.. Standard Grade, BTC 9-5/8" 40 ppf L-80 BTC-Mod Surf. Csg. 7,465' MD / 4,404' TVD :.;.;.: 81/2" Hole 3Y2" 9.3 ppf L-80 8rd EUE tubing w/15' seal bore extension tied 7" 26 ppf L-80 BTC Intermediate· Csg. 11,773' MD / 6,392' TVD Baker 4·5" x 7" SLZXP LTP and Hanger. TOL@ 11623' MD/6323' TVD 6-1/8" Hole I ::.:.. 3.81 at 5¢ ;..'.;. · . . :::::: sid · . , ... · . . .., · . . · . . · . . · . , ,., :.:.:. · . . :.:.:. · . . · . . · . . :.:.:. ,.. · . . ... .., · . . I :::::::: CA :><3 b,< :::::::: ~__ :.:.:.:. .::, ....:1~:. -. CAMCO DB or Otis 31e for SCSSV +MD 4Y2" x 1" pocket GLM Camco 4Y2" x 1" side pocket GLM ;AMCO or Otis 3.813 nipple 3-1/2" Slimhole Completion 7/9/99 ARCO Alaska, Inc. Diverter Schematic Pool #6 21¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet Flowline 21¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. POOL #6 13-5/8" 5,000 PSI BOP COMPONENTS 3" 5,000 psi WP OCT [__l MANUAL GATE KILL LINE ~,[_j 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator E~ / J F- BSA 13-5/8" 5,000 psi WP / x 11" 3,000 psi WP --~ 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi WP Shaffer GATE VALVE rm~T~~raulic actuator 13-5/8" 5,000 psi WP DRILLING SPOOL w/two 3" 5M psi WP outlets SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams 5OO 1000 150O 2000 2500 -,I-- I~ ,5000 ,,5500 o-- ,-I,-- 4000 4500 I ¥ 5000 5500 6OOO 65OO 7000 ARCO Alaska, Inc. Created by rixse FOR: LLOYD I Struature : Pad 1D Well : 11 Date plotted: 8-dul-lgg9 Plot Reference rs 11 Version 1~3- I Fleld: Kuparuk River Unit Location : Nor-th Slope, Alaska Coordinates are M feet reference slot 11. True Vertical Depths ore reference rkb Paol ~6.I I PROFILE COMMENT DATA ~ I I Point MD Inc Dir WD North East V, Sect Deg/lO RKB ELEVATION: 105' Begin 1.5 Deg/lO0' B 250,00 0.00 0.00 250,00 0.00 0,00 0,00 0,00 Begin 3 Deg/lO0' Bui 400,00 2.25 90,00 599,96 0.00 2,94 2,86 1,50 0.75 Begin 1.5 Deg/lO0' Build Base of Permafrost 1813,3,5 41.49 111.15 1685,00 -253.72 452,23 500,4;5 5,0(~ BegM 3 Deg/lO0' Build & Turn t. EOC 2545,21 62.52 103.01 2133.51 -416.25 1001.36 1072.61 3.00 t7.78 Top of West Sak 6063.09 62.52 103.01 5757,00 -1118.62 4042,15 4192.89 0.00 15.47 Base of West Sak 7051.67 62.52 103.01 4204.00 -1512.01 4879.58 5052.01 O.O01 19,35 DLS: 5.00 deg per 100 ft 9 5/8 Casing Point 7465.04 62.52 10;5.01 4404.00 -1398.54 5255.98 5456.40 0.00 ~,~ 24,§1 C80 7920.08 62.52 103.01 4614,00 -1489.39 5647,31 5840,01 '~ 50.05 C50 9850.75 62.52 105.01 5505.00 -1874.86 7516.14 7552.47 Y. OOJ k55.51 C40 10431,47 62.52 103,01 577;3.00 -1990,81 7818.10 8067.55 0.00! "X. 41.11 Base of Permafrost C30 11183,57 62,52 103.01 6120,00 -2140.95 8468,03 8754,47 0,00 "'~6'~92 55 C20 11475.90 62.52 103.01 6255.00 -2199.34 8720.89 8993.94 0.00 58 31 ~' EOC Base HRZ 11627.58 62.52 103.01 6525.00 -2229.62 8852.00 9128.47 0.00 K-1 11772.76 62.52 103.01 6592.00 -2258.61 8977.49 9257.24 0.00 Top of Kuparuk D 11917.94 62.52 105.01 6459.00 -2287.59 9102.98 9386.01 0.00 Top C4 11924.44 62,52 103.01 6462,00 -2288.89 9108.60 9391.78 0.00 ~. Top C5 11982.94 62.52 103.01 6489,00 -2500.57 9159.17 9445.67 0.00 Top C2 12050.61 62.52 10;5.01 6511,00 -2510.09 9200.37 9485.96 0.00 Top C1 12045.78 62.52 105.01 6518.00 -2513,.12 921;5.48 9499.41 0.00 Top B Shale 12086.95 62.52 105.01 6537.00 -2321.34 9249,07 9555.95 0.00 TD - Casln§ Pt 12520.95 62.52 103.01 6644.99 -2568.06 9451.53 9745.48 0.00 ~ Top of West Sak 104. i i AZIMUTH Base of West Sak 9388' TO TARGET as 9 5/8 Casing Point ***Plane of Proposal*** AVERAGE AN ~LF, ~ C80 ¢-~ ~ ...... C40 C30 p of Kuporuk D :.5i" "--';" TARGET C4 TVD=6460 TMD=l1920 DEP=9388 ~ T°gr~C~4c3C2"~'o" :~ ~ PTap. C1 , :' TD - CQsing P~ Top B Shale i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i 0 500 1000 1500 2000 2500 3000 5500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 Vertical Section (feet) -> Azt'mufh 104.11 with reference 0.00 N, 0.00 E from slot 11 Created by rixee FOR: LLOYD Onte plotted: 8-Ju1-1999 Plot Reference ~e 11 Version t~3. Coord;notes ore ~n feet reference slot 11. ITrue Vertical Depth ...... fe ...... kb Pool ~6. I ,m: ARCO Alaska, Inc. Struature; Pod 1D Well : 11 Field : Kuporuk Rlver Unit Location : North Slope, Alaska PROFILE COMMENT DATA - .... Point MB Inc Bit TVD North East V. Sect Beg/10C ;Begin 1.5 Dog/lO0' B 250.00 0.00 0.00 250.00 0,00 0.00 0.00 0.0¢ Beg;n 3 Dog/lO0' Bul 400.00 2.25 90.00 ,399,96 0,00 2.94 2,86 1.5C Base of Permafrost 1815.53 41.49 111.15 1685.00 -255.72 452.25 500.43 3.0C EOC 2545.21 62,52 103.01 2153.51 -416.25 1001.56 1072.61 3.0(; Top of West Sak 6065.09 62.52 103,01 3757.00 - 1118.62 4042.15 4192.89 0.00 Base of West Sak 7051.67 62,52 105.01 4204.00 -1312.01 4879.38 5052.01 0,00 9 5/B Casing Point 7465.04 62.52 103.01 4404.00 -1598.54 5253.98 5436.40 0.00 C80 7920.08 62.52 103.01 4614.00 - 1489,39 5647.,31 5840.01 0.00 C50 C40 C50 C20 Base HRZ K-1 Top of Kuparuk D Top C4 Top CD Top C2 Top C1 Top 0 Shale TD - Co~ing Pt 9850.75 62,52 103.01 5505.00 -1674.86 7516.14 7552.47 0.00 10451.47 62.52 103.01 5775.00 -1990.81 7818.10 8067.55 0.00 11185.57 62.52 105.01 6120.00 -2140.95 8468.05 8754.47 0.00 11475.90 62.52 105.01 6255.00 -2199.54 8720.89 8995,94 0.00 11627.58 62.52 103.01 6525.00 -2229.62 8852.00 9128,47 0.00 11772.76 62.52 103,01 6392.00 -2258.61 8977.49 9257.24 0.00 11917.94 62.52 103.01 6459.00 -2287.59 9102.98 9386.01 0.00 11924~44 62,52 103,01 6462,00 -2288.89 9108,60 9391.78 0.00 11982.94 62.52 103,01 6489.00 -2500.57 9159.17 9443.67 0.00 12030.61 62.52 103.01 6511.00 -2310,09 9200.37 9485.96 0.00 12045.78 62,52 103.01 6518.00 -2513.12 9213.48 9499,41 0.00 12086,95 62.52 103,01 5557.00 -2521.54 9249.07 9535.93 0.00 12320.95 62.52 103,01 5644.99 -2368.06 9451.33 9743.48 0,00 East (feet) -> 0 500 1000 1500 2000 2500 5000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ( ~~~Bose oegin 3 Deg/lO0' Build & Turn f Permofrost EST. SURFACE LOCATION: I 586' FNL, 601' FEL SEC. 25, TllN, RIOE 0 TARGET LOCATION: ~ 500 2401' FSL, 1740' FEL SEC. 19, T11N, R11E 0 '~'~ 1000 "'-~~West Sok -~- ~ Bose of West Sak ] 0~.0~ a~ ' Point 2500 Target - 6460.00 Tvd, 2288.03 S, 9104.85 E TB LOCATION: 3000 2520' FSL, 1594' FEL SEC. 19, T11N, RllE Creotsd by r{xse FOR: LLOYD Dote plotted: 8-Ju{-1999 Plot Reference is 11 Version Coord~notee ore in feet reference slot 11. True Vsrt{co{ Depths ore reference rkb Poe{ ~i! ARCO Alaska, Inc. Structure: Pad 1D Well : 11 Field: Kuparuk River Unit Louation: North Slope, Alaska 8O 40 20 ~) 0 ~- ~0 0 40 6o 8o lOO 120 East (feet) -> 80 60 40 20 0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 I I I I { .~ I I I { I I I I I I I I I I I I I I I I I I I I I I 11 O0 500 I --- ~500 ~ ~ ~700 { -~ 500 ~ -~ 6300 ~' ~00 1 I ~ ~ 700 o~ ~00 5500 ~ ~ ~ 4~00 ' ~00 ~ 500 ~ ~ 3300 [ ~ ~ I 1500~ ~ I 1900 ~ ~ ~ ~ ~ 9001 ~ ~ ~ 700 ~ ~ 1700 ~ N 500 900 ~ ~ g00 ~ %N 1100 k X 50( x~ ~oo ~ x ~ x ~ 500 k N ~00 k ~ ~ 700 ~ 900 %1100 X X 1 lO0 1900 11oo \ \ ~ \ 2100 ~ 700 t80 60 700 -,. 700 .. \\\ XXX ~ 100 i i / i i 260 280 300 20 8' ' 2'0 ' ' ' 2'0 ' '0 , , , i i , , , , , , i , , , 0 60 4.0 0 4 60 80 100 120 140 160 180 200 220 240 Eost (feet) -> 120 Creoted by rlxse FOR: LLOY])1 Dote plotted: 8-Jul-19gg I Plot Reference ~s 11 Version ~3. I Coordinates are in feet reference slot 11. I True Vert~col Depths ore reference rkb Pool ~6.~ ARCO Alaska, Inc. Structure : Pad 1D Well : 11 Field: Kuparuk River Unit Location : North Slope, Alaska 8Ot 120 16O 200 240 280 320 [ ~60 V 400 440 480 52O 56O Easf (feel) -> 120 160 200 240 280 320 560 400 440 480 520 560 600 640 680 720 760 800 840 880 920 960 I I I I J I I I I I I I I I I I I I I I I I I I I i I I I I I I I I I I I I I I I I I ~ ~oo ~ -~ 900% ~ ~ ' ~ ~ ~ ~ ~ ~ ~ N 1500~ ~ '~ ~~900~ ~ ~ . O0 ~_ ~ -- ~ %1700 '~ ~ N~ 1500 NX NN- '~'-- '~- ~ ~ 2500 ~ ~'~ 2300 ~ X x 1300~ X ~ ~ ~ X k k k ~ ~ 1300 ~ 1300 ~ k k k x ~ I I I I I I I I I I I I I I I t I I I I I I I I I I I I 120 160 200 240 280 320 560 400 440 480 520 560 600 640 680 720 760 800 840 880 920 960 Eosf (feel) -> 80 120 160 200 240 0 280 '~' 320 360 I V 40O 440 480 52O 560 ICreoted by dxee FOR: LLOYD1 Date plotted : 8-Ju1-1999 I Plot Reference is 11 Version ~3. I Coordinates ore ~n feet reference slot 11. I True Vert;col Depths ore reference rkb Pool 1~6./ I ARCO Alaska, Inc. Structure: Pad lO Well : 11 Field: Kuporuk River Unlf Location : North Slope, Alaska East (feel) 900 I000 11 O0 1200 1500 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 5000 200 ~ ~ ~3300 3500 ~ ~ ~ ~~00 5900 4100 500 O0 1100 X X X N X N ~ ~ ~ ~ 5500 1 ~00 I [ I [ I I I I I [ I I [ t [ I [ ] [ [ I I I I [ ~ [ [ [ ] [ [ [ [ [ [ ~ I ] [ [ I [ 900 1000 11 O0 1200 1300 1400 1500 1600 1700 1800 1900 2000 21 O0 2200 2500 2400 2500 2600 2700 2800 2900 3000 East (feet) -> 50O 500 700 800 1 o0 2oo ii 500 4OO 500 0 600 ~ 7OO --4- 800 I v 900 1000 1100 1200 1300 I Created by dxse FOR: LLOYD1 Dote plotted: 8-Ju1-1999 I Plot Reference is 11 Version ~3. I Coord;notes ore ]n feet reference slot 11. I True Vertical Depths ore reference rkb Pool Iii I 8O0 400 400 800 1200 t- 1600 ,.i,,i 0 tJ') 2000 I 2400 2800 5200 ,5600 4O0O ARCO Alaska, Inc. Structure: Pad iD Well : 11 Field: Kuparuk River Unit Location: North Slope, Alaska Ec~sf (feet) -> 2400 2800 5200 5600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 8400 8800 9200 9600 10000 10400 10800 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I o - _ -- 5 oo 61oo -- 51 O0 5600 41 O0 4 600 51 O0 \ 310Ok\ \ 3600% 5100 \ % 5100 ~ ~,3600 3100 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 2400 2800 3200 5600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 8400 8800 g200 9600 10000 10400 10800 East (feet) -> 800 400 400 800 1200 0 1600 ii. 2000 ~-~ I 2400 2800 5200 5600 4000 ARCO Alaska. Inc. Pad iD 11 slot 11 Kuparuk Ri ver Unit North Slope, Alaska PROPOSAL LISTING INCLUDING ~SITION UNCERTAINTIES by Baker Hughes INTEQ You~ ref : 11 Version #3 Our ref : prop3443 License : Date printed : 8-Ju1-1999 Date created : 7-Jun-1999 Last re_vised : 8-Ju1-1999 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is n70 17 55.553,w149 30 36.428 Slot Grid coordinates are N 5959078.720. E 560490.724 Slot local coordinates are 586.00 S 601.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Pad 10.11 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 0.00 0.00 0.00 0.00 250.00 0.00 0.00 250.00 300.00 0.75 90.00 300.00 400.00 2.25 go.o0 399.96 500.00 5,19 100.00 499.74 600.00 7.78 113.74 599.10 700.00 10.59 120.46 697.81 800.00 13,47 124.36 795.61 900.00 16.40 126.89 892.22 1000.00 19.35 128.68 987.38 1100.00 22.32 130.00 1080.83 1200.00 24.81 125.80 1172.49 1300.00 27.39 122.34 1262.29 1400.00 30,05 119.44 1349.99 1500.00 32.76 116.98 1435.33 1600.00 35.51 114.85 1518.10 1700.00 38.30 113.00 1598.05 1800.00 41.11 111.36 1674.98 1813.33 41.49 111,15 1685.00 1900.00 43.94 109.89 1748.67 2000.00 46.79 108.57 1818.92 2100.00 49.66 107.37 1885.54 2200.00 52.53 106.27 1948.34 2300.00 55.41 105.24 2007.15 2400.00 58.31 104.29 2061.82 2500.00 61.20 103.39 2112.19 2545.21 62.52 103.01 2133.51 3000.00 62.52 103.01 2343.39 3500.00 62.52 103.01 2574.14 4000.00 62.52 103.01 2804.89 4500.00 62.52 103.01 3035.64 5000.00 62.52 103.01 3266.39 5500.00 62.52 103.01 3497.14 6000.00 62.52 103.01 3727.89 6063.09 62.52 103.01 3757.00 6500.00 62.52 103.01 3958.63 7000.00 62.52 103.01 4189.38 7031.67 62.52 103.01 4204.00 7465.04 62.52 103.01 4404.00 7500.00 62.52 I03.01 4420.13 7920.08 62.52 103.01 4614.00 8000.00 62.52 103.01 4650.88 8500.00 62.52 103.01 4881.63 9000.00 62.52 103.01 5112.38 9500.00 62.52 103.01 5343.13 9850.75 62.52 103.01 5505.00 10000.00 62.52 103.01 5573.88 10431.47 62.52 103.01 5773.00 10500.00 62.52 103.01 5804.63 11000,00 62.52 103,01 6035.37 RECTANGULAR COORDINATES PROPOSAL LISTING Page 1 Your ref : 11 Version#3 Last revised : 8-Ju1-1999 Dogleg Vert Deg/lOOft Sect 0.00 N 0.00 E 0.00 0.00 N 0.00 E 0.00 0.00 N 0.33 E 1.50 0.00 N 2.94 E 1.50 0.79 S 9.36 E 3.00 0.00 0.00 Begin 1.5 Deg/lO0' Build 0.32 2.86 Begin 3 Deg/lO0' Build & Turn 9.27 4.30 S 20.01 E 3.00 20.46 11.68 S 34.13 E 3,00 35.95 22.91S 51.67 E 3.00 55.69 37.97 S 72.58 E 3.00 79.65 56.81 S 96.82 E 3.00 107.74 79.37 S 124.30 103.85 S 155.87 128.44 S 192.32 153.05 S 233.57 177.64 S 279.50 202.12 S 329,98 '226.44S 384.87 250.53 S 444.03 253.72 S 452.23 274.31 S 507.29 E 3.00 139.90 E 3.00 176.48 E 3.00 217.83 E 3.00 263.83 E 3.00 314.36 E 3,00 369,29 E 3.00 428.45 E 3.00 491.70 E 3.00 500.43 Base of Permafrost E 3.00 558.85 297.73 S 574.48 E 3,00 629.71 320.72 S 645.41 E 3.00 704.11 343.22 S 719.89 E 3.00 781.83 365.16 S 797.72 E 3,00 862.66 386.49 S 878.68 E 3.00 946.38 407.15 S 962.55 E 3.00 1032.75 416.25 S 1001.36 E 3,00 1072.61EOC 507.05 S 1394.47 E 0.00 1476.00 606.88 S 1826.66 E 0.00 1919.49 706.71 S 2258.85 E 0.00 2362.98 806.54 S 2691.05 E 0.00 2806.47 906.37 S 3123.24 E 0.00 3249.96 1006.20 S 3555.43 E 0.00 3693.45 1106.03 S 3987.62 E 0.00 4136.94 1118.62 S 4042.15 E 0.00 4192.89 Top of West Sak 1205.86 S 4419.81E 0.00 4580.42 1305.69 S 4852.00 E 0.00 5023.91 1312.01 S 4879.38 E 0.00 5052.01 Base of West Sak 1398.54 S 5253.98 E 0.00 5436.40 9 5/8' Casing Point 1405.51 S 5284.19 E 0.00 5467.40 1489.39 S 5647.31 E 0.00 5840.01 C80 1505.34 S 5716.38 E 0.00 5910.89 1605.17 S 6148.57 E 0.00 6354.38 1705.00 S 6580.76 E 0.00 6797.87 1804.83 S 7012.96 E 0.00 7241.36 1874.86 S 7316.14 E 0.00 7552.47 C50 1904.66 S 7445.15 E 0.00 7684.85 1990.81S 7818.10 E 0,00 8067.55 C40 2004.49 S 7877.34 E 0.00 8128.34 2104.32 S 8309.53 E 0.00 8571.83 All data is in feet unless otherwise stated. Coordinates from slot 1! and TVD from rkb Pool #6 (ICf. O0 Ft above mean sea level). Bottom hole distance is 9743.50 on azimuth 104.~~ degrees from wellhead. Total Dogleg for wellpath is 66,6/ degrees. Vertical section is from wellhead on azimc~n 104.11 degrees. Calculation uses the minimum curvature method. Presented bv~ Baker Hughes T'-~ ~ :~ ARCO Alaska, Inc. Pad 10,11 Kuparuk River Unit,North Slope. Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 11183.37 62.52 103.01 6120.00 11475.90 62.52 103.01 6255.00 11500.00 62.52 103.01 6266.12 11627.58 62.52 103.01 6325.00 11772.76 62.52 103.01 6392.00 11917.94 62.52 103.01 6459.00 11920.10 62.52 103.01 6460.00 11924.44 62.52 103.01 6462.00 11982.94 62.52 103.01 6489.00 12000.00 62.52 103.01 6496.87 12030.61 62.52 103.01 6511.00 12045.78 62.52 103.01 6518.00 12086.95 62.52 103.01 6537.00 12320.95 62.52 103.01 6644.99 12320.97 62.52 103.01 6645.00 RECTANGULAR COORDINATES 2140.93 S 8468.03 2199.34 S 8720.89 2204.15 S 8741.72 2229.62 S 8852.00 2268.61 S 8977.49 2287.59 S 9102.98 2288.03 S 9104.85 2288.89 S 9108.60 2300.57 S 9159.17 2303.98 S 9173.91 2310.09 S 9200.37 2313.12 S 9213.48 2321.34 S 9249.07 236B.06 S 9451.33 2368.06 S 9451.35 PROPOSAL LISTING Page 2 Your ref : 11 Version#3 Last revised : 8-~1-1999 Dogleg Vert Deg/lOOft Sect E 0.00 8734.47 C30 E 0.00 8993.94 C20 E 0.00 9015.31 E 0.00 9128.47 Base HRZ E 0.00 9257.24 K-1 E 0.00 9386.01 Top of Kuparuk D E 0.00 9387.94 10-11 23-Jun-99 E 0.00 9391.78 Top C4 E 0.00 9443.67 Top C3 E 0.00 9458.80 E 0.00 9485.96 Top C2 E 0.00 9499.41 Top C1 E 0.00 9535.93 Top B Shale E 0.00 9743.48 TD - Casing Pt E 0.00 9743.50 Ail data is in feet unless otherwise stated. Coordinates from ~!ot 11 and TVD from rkb Pool ~6 (105.09 Ft above mean sea level). Bottom hole distance is 9743.50 on azimuth i04.07 degrees from wellhead. Total Dogleg for weii~ath is 66.61 degrees. Vertical section is from we!itead on azimuth !04.11 degrees. Calculation uses the minimum curvature method. Presented by~.~r Hughes !NTEQ ARCO Alaska, Inc. Pad 1D.11 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 11 Version#3 Last revised : 8-Ju1-1999 Conm~ents i n wel 1 path MD TVD Rectangular Coords. Co~l~nt 250.00 250.00 0.00 N 0.00 E Begin 1.5 Deg/lO0' Build 400.00 399.96 0.00 N 2.94 E Begin 3 Deg/lO0' Build & Turn 1813.33 1685.00 253.72 S 452.23 E 2545.21 2133.51 416.25 S 1001.36 E 6063.09 3757.00 1118.62 S 4042.15 E 7031.67 4204.00 1312,01 S 4879.38 E 7465.04 4404.00 1398.54 S 5253.98 E 7920.08 4614.00 1489,39 S 5647,31E 9850.75 5505,00 1874,86 S 7316.14 E 10431.47 5773.00 1990,81 S 7818.10 E 11183.37 6120.00 2140.93 S 8468.03 E 11475.90 6255.00 2199,34 S 8720.89 E 11627.58 6325.00 2229,62 S 8852.00 E 11772.76 6392.00 2258,61 S 8977.49 E 11917.94 6459.00 2287,59 S 9102,98 E 11920.10 6460.00 2288.03 S 9104.85 E 11924.44 6462.00 2288.89 S 9108.60 E 11982.94 6489,00 2300.57 S 9159.17 E 12030.61 6511.00 2310,09 S 9200.37 E 12045.78 6518.00 2313.12 S 9213.48 E 12086.95 6537.00 2321.34 S 9249,07 E 12320.95 6644.99 2368.06 S 9451.33 E Base of Permafrost EOC Top of West Sak Base of West Sak 9 5/8" Casing Point C80 C50 C40 C30 C20 Base HRZ K-1 Top of Kuparuk D 1D-11 23-Jun-99 Top C4 Top C3 Top C2 Top C1 Top B Shale TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot ~E) Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 7465.04 4404.00 1398.54S 5253.98E 9 5/8' Casing 0.00 0.00 O.OON O.OOE 12321.00 6645.00 2368.06S 9451.35E 7" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1D-11 23-Jun-99 569613.000,5956865.000,2.0000 6460.00 2288.D3S 9104.85E 23-Jun-1999 A;rj3 A1 aska, Inc. Pad 10,11 Kuparuk River Unit,North Slope, Alaska ~.SPOSAL LISTING Page 1 Your ref : 11 Version #3 Last revised : 8- Jul-1999 Measured Inclin Azimuth True Vert R E C TAN G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lO0~ Sect Easting Northing 0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 0.00 560490.72 5959078.72 250.00 0.00 0.00 250.00 O.OON O.OOE 0.00 0,00 560490.72 5959078.72 300.00 0.75 90.00 300.00 O,OON 0.33E 1.50 0,32 560491.05 5959078.72 400.00 2.25 90.00 399.96 O.OON 2.94E 1.50 2.86 560493.67 5959078.74 500.00 5.19 I00.00 499.74 0.79S 9.36E 3.00 9.27 560500.09 5959078,01 600.00 7.78 113.74 599.10 4.30S 20.01E 3.00 20.46 560510.77 5959074.59 700.00 10.59 I20.46 697.81 11.68S 34.13E 3.00 35.95 560524.94 5959067.32 800.00 13.47 124.36 795.61 22.91S 51.67E 3.00 55.69 560542.57 5959056.23 900.00 16.40 126.89 892.22 37.97S 72.58E 3.00 79.65 560563.61 5959041.34 1000.00 19.35 128.68 987.38 56.81S 96.82E 3.00 107.74 560587.99 5959022.71 1100.00 22.32 130.00 1080.83 79.37S 124.30E 3.00 !39.90 560615.66 5959000.37 1200.00 24.81 I25.80 1172.49 103.85S 155.87E 3.00 176.48 560647.42 5958976.15 1300.00 27.39 t22.34 1262.29 128.44S 192.32E 3.00 217.83 560684.07 5958951.87 1400.00 30.05 119.44 1349.99 153.05S 233.57E 3.00 263.83 560725.51 5958927.59 1500.00 32.76 116.98~ 1435.33 177.64S 279.50E 3.00 314.36 560771.63 5958903.38 1600.00 35.51 114.85 1518.10 202.12S 329.98E 3.00 369.29 560822.30 5958879.30 1700.00 38.30 113.00 1598.05 226.44S 384.87E 3.00 428.45 560877.39 5958855.44 1800.00 41.11 111.36 1674.98 250.53S 444.03E 3.00 491.70 560936.73 5958831.84 1813.33 41.49 111.15 1685.00 253.72S 452.23E 3.00 500.43 560944.96 5958828.71 1900.00 43.94 109.89 1748.67 274.31S 507.29E 3.00 558.85 561000.18 5958808.57 2000.00 46.79 108.57 1818.92 297.73S 574.48E 3.00 529.71 561067.55 5958785.70 2100.00 49.66 107.37 1885.54 320.72S 645.41E 3.00 704.11 561138.66 5958763.29 2200.00 52.53 106.27 1948.34 343.22S 719.89E 3.00 781.83 561213.31 5958741.40 2300.00 55.41 105.24 2007.15 365.16S 797.72E 3.00 862.66 561291.31 5958720.09 2400.00 58.31 104.29 2061.82 386.49S 878.68E 3.00 946.38 561372.43 5958699.42 2500.00 61.20 103.39 2112.19 407.15S 962.55E 3.00 1032.75 561456.46 5958679.45 2545.21 62.52 103.01 2133.51 416.25S 1001.36E 3.00 i072.61 561495.34 5958670.67 3000.00 62.52 103.01 2343.39 507.05S 1394.47E 0.00 !476.00 561889.14 5958583.07 3500.00 62.52 103.01 2574.14 606.88S 1826.66E O.O0 1919.49 562322.09 5958486.77 4000.00 62.52 103.01 2804.89 706.71S 2258.85E 0.00 2362.98 562755.03 5958390.46 4500.00 62.52 103.01 3035.64 806.54S 2691.05E 0.00 2806.47 563187.98 5958294.16 5000.00 62.52 103.01 3266.39 906.37S 3123.24E 0.00 3249.96 563620.93 5958197.86 5500.00 62.52 103.01 3497.14 1006.20S 3555.43E 0.00 3693.45 564053.87 5958101.55 6000.00 62.52 103.01 3727.89 1106.03S 3987.62E 0.00 4136.94 564486.82 5958005.25 6063.09 62.52 103.01 3757.00 1118.62S 4042.15E 0.00 4192.89 564541.45 5957993.10 6500.00 62.52 103.01 3958.63 1205.86S 4419.81E 0.00 4580.42 564919.77 5957908.95 7000.00 62.52 103.01 4189.38 1305.69S 4852.00E 0.00 5023.91 565352.71 5957812.64 7031.67 62.52 103.01 4204.00 1312.01S 4879.38E 0.00 5052.01 565380.14 5957806.54 7465.04 62.52 103.01 4404.00 1398.54S 5253.98E 0.00 5436.40 565755.39 5957723.07 7500.00 62.52 103.01 4420.13 1405.51S 5284.19E 0.00 5467.40 565785.66 5957716.34 7920.08 62.52 103.01 4614.00 1489.39S 5647.31E D.O0 5840.01 566149.41 5957635,43 8000.00 62.52 103.01 4650.88 1505.34S 5716.38E 0.00 5910.89 566218.61 5957620.04 8500.00 62.52 103.01 4881.63 1605.17S 6148.57E 0.00 6354.38 566651.55 5957523.73 9000.00 62.52 t03.01 5112.38 1705.00S 6580.76E 0.00 6797.87 567084.50 5957427.43 9500.00 62.52 103.01 5343.13 1804.83S 7012.96E O.O0 7241.36 567517.45 5957331.13 9850.75 62.52 103.01 5505.00 1874.86S 7316.14E 0.00 7552.47 567821.16 5957263.57 10000.00 62.52 103.01 5573.88 1904.66S 7445.15E 0.00 7684.B5 567950.39 5957234.82 10431.47 62.52 103.01 5773.00 1990.81S 7818.10E 0.00 8067.55 568324.00 5957151.72 10500.00 62.52 103.01 5804.63 2004.49S 7877.34E 0.00 ~128.34 568383.34 5957138.52 11000.00 62.52 103.01 6035.37 2104.32S 8309.53E 0.00 $S71.83 568816.29 5957042.22 data in feet unless otherwise stated. Calcu!atie? "ses minimum curvature method. :oordinates from slot 1! and TVD from rkb Pool ~ (!C~.~0 Ft above mean sea level). Bottom hole distance is 9743.50 on azimuth !04.~~ degrees from wellhead. T~. ~ ~ Dogleg for well~o~n~' is 66. ~i ~agrees. Vertical section is from wellhead on aziF..tn 104.11 degrees. Grid is alaska - Zone ± Grid coordinates in FEET and computed using t~ ~]!arke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad iD,Ii Kuparuk River Unit,North Slope, A1 Measured Inclin Azimuth True Vert Depth Degrees Degrees Depth 11183.37 62.52 103.01 6120.00 11475.90 62.52 103.01 6255.00 11500.00 62.52 103.01 6266.12 11627.58 62.52 103.01 6325.00 11772.76 62.52 103.01 6392.00 11917.94 62.52 103.01 6459.00 11920.10 62.52 103.01 6460.00 11924.44 62.52 103.01 6462.00 11982.94 62.52 103.01 6489.00 12000.00 62.52 103.01 6496.87 12030.61 62.52 103.01 6511.00 12045.78 62.52 103.01 6518.00 12086.95 62.52 103.01 6537.00 12320.95 62.52 103.01 6644.99 12320.97 62.52 103.01 6645.00 aska PROPOSAL LISTING Page 2 Your ref : 11 Version#3 Last revised : 8-2u1-1999 R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S C 0 0 R D I N A T E S Deg/lOOft Sect Easting Northing 2140.93S 8468.03E 0.00 8734.47 568975.07 5957006.90 2199.34S 8720.89E 0.00 8993.94 569228.36 5956950.56 2204.15S 8741.72E 0.00 9015.31 569249.24 5956945.91 2229.62S 8852.00E 0.00 9128.47 569359.70 5956921.34 2258.61S 8977.49E 0.00 9257.24 569485.41 5956893.38 2287.59S 9102.98E 0.00 9386.01 569611.12 5956865.42 2288.03S 9104.85E 0.00 9387.94 569613.00 5956865.00 2288.89S 9108.60E 0.00 9391.78 569616.75 5956864.17 2300.57S 9159.17E 0.00 9443.67 569667.41 5956852.90 2303.98S 9173.91E 0.00 9458.80 569682.18 5956849.61 2310.09S 9200.37E 0.00 9485.96 569708.69 5956843.72 2313.12S 9213.48E 0.00 9499.41 569721.82 5956840.79 2321.34S 9249.07E 0.00 9535.93 569757.47 5956832.86 2368.06S 9451.33E 0.00 9743.48 569960.09 5956787.79 2368.06S 9451.35E 0.00 9743.50 569960.11 5956787.79 All data in feet ~nless otherwise stated. Calculation uses minimum curvature method. Coordinates fro~ slot 1! and ~D from rkb Pool #6 (105.00 Ft above mean sea level). Bottom hcle distance is 9743.50 on azimuth 104.07 degrees from ,ellhead. Total Dogleg for welipath is 66.6! degrees. Ver~-cai section is from wellhead on azimuth !04.11 degrees. Grid is alaska - Zone 4. Grid cec-~inates in FEET a~d com~uted ~sing the Clarke - 1866 s~heroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,11 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref: 11 Version #3 Last revised : 8-Ju1-1999 Comments i n wel 1 path , , MD TVD Rectangul ar Coords. Comment ~so.oo~5o.oo "~]~N O.OOE ~. 1.S ~g~O0' Bu~d 400.00 399.96 O.OON 2.94E Begin 3 Deg/lO0' Build & Turn 1813.33 1685.00 253.72S 452.23E Base of Permafrost 2545.21 2133.51 416.25S 1001.36E EOC 6063.09 3757.00 1118.62S 4042.15E Top of West Sak 7031.67 4204.00 1312.01S 4879.38E Base of West Sak 7465.04 4404.00 1398.54S 5253.98E 9 5/8" Casing Point 7920.08 4614.00 1489.39S 5647.31E C80 9850.75 5505.00 1874.86S 7316.14E C50 10431.47 5773.00 1990.81S 7818.10E C40 11183.37 6120.00 2140.93S 8468.03E C30 11475.90 6255.00 2199.34S 8720.89E C20 11627.58 6325.00 2229.62S 8852.00E Base HRZ 11772.76 6392.00 2258.61S 8977.49E K-1 11917.94 6459.00 2287.59S 9102.98E Top of Kuparuk D 11920.10 6460.00 2288.03S 9104.85E 1D-11 23-Jun-99 11924.44 6462.00 2288.89S 9108.60E Top C4 11982.94 6489.00 2300.57S 9159.17E TOP C3 12030.61 6511.00 2310.09S 9200.37E Top C2 12045.78 6518.00 2313.12S 9213.48E TOP C1 12086.95 6537.00 2321.34S 9249.07E Top B Shale 12320.95 6644.99 2368.06S 9451.33E TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bat MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 7465.04 4404.00 1398.54S 5253.98E 9 5/8" Casing 0.00 0.00 O.OON O.OOE 12321.00 6645.00 2368.06S 9451.35E 7" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised ...... ...... ..... ....... AACO Alaska, Inc. Pad 10,11 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T Depth Degrees Degrees Depth C 0 0 R ANGULAR DINATES ~ROPOSAL LISTING Page 1 Your ref : 11 Version#3 :~st revised : 8-Ju1-1999 Vent Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 0.00 0.00 0.00 0.00 0.00 N 0.00 E O.DE~ 0.00 0.00 0.00 N/A 250.00 0.00 0.00 250.00 0.00 N 0.00 E O.O~ 0.65 0.65 0.38 N/A 300.00 0.75 90.00 300.00 0.00 N 0.33 E 0.3~ 0.78 0.78 0.45 N/A 400.00 2.25 90.00 399.96 0.00 N 2.94 E 2.86 1.06 1.05 0.60 90.00 500.00 5.19 100.00 499.74 0.79 S 9.36 E 9.~7 1.39 1.31 0.75 96.69 600.00 7.78 113.74 599.10 4.30 S 20.01 E 20.~ 1.84 1.59 0.90 105.35 700.00 10.59 120.46 697.81 11.68 S 34.13 E 35.~ 2.45 1.88 1.06 111.68 800.00 13.47 124.36 795.61 22.91 S 51.67 E 55.6} 3.27 2.20 1.22 116.22 900.00 16.40 126.89 892.22 37.97 S 72.58 E 79.~ 4.32 2.54 1.39 119.57 1000.00 19.35 128.68 987.38 56.81 S 96.82 E 107.7z 5.62 2.91 1.57 122.12 1100.00 22.32 130.00 1080.83 79.37 S 124.30 E 139.9~ 7.18 3.31 1.77 124.11 1200.00 24.81 125.80 1172.49 103.85 S 155.87 E 176.48 9.03 3.74 1.99 124.53 1300.00 27.39 122.34 1262.29 128.44 S 192.32 E 217.~ 11.19 4.19 2.23 124.11 1400.00 30.05 119.44 1349.99 153.05 S 233.57 E 263.~ 13.68 4.66 2.51 123.23 1500.00 32.76 116.98 1435.33 177.64 S 279.50 E 314.36 16.53 5.15 2.82 122.10 1600.00 35.51 114.85 1518.10 202.12 S 329.98 E 369.~ 19.75 5.67 3.18 120.86 1700.00 38.30 113.00 1598.05 226.44 S 384.87 E 428.4~ 23.38 6.19 3.58 119.58 1800.00 41.11 111.36 1674.98 250.53 S 444.03 E 491.75 27.43 6.73 4.03 118.31 1813.33 41.49 111.15 1685.00 253.72 S 452.23 E 500.43 28.02 6.81 4.09 118.14 1900.00 43.94 109.89 1748.67 274.31S 507.29 E 558.85 31.90 7.28 4.53 117.07 2000.00 46.79 108.57 1818.92 297.73 S 574.48 E 629.F~ 36.81 7.83 5.08 115.88 2100.00 49.66 107.37 1885.54 320.72 S 645.41 E 704.1! 42.16 8.37 5.69 114.75 2200.00 52.53 106.27 1948.34 343.22 S 719.89 E 781.~ 47.95 8.91 6.35 113.68 2300.00 55.41 105.24 2007.15 365.16 S 797.72 E 862.~ 54.16 9.44 7.06 112.67 2400.00 58.31 104.29 2061.82 386.49 S 878.68 E 946.33 60.79 9.95 7.82 111.72 2500.00 61.20 103.39 2112.19 407.15 S 962.55 E 1032.~ 67.81 10.44 8.64 110.82 2545.21 62.52 103.01 2133.51 416.25 S 1001.36 E 1072.6Z 71.07 10.66 9.02 110.45 3000.00 62.52 103.01 2343.39 507.05 S 1394.47 E 1476.DC 104.12 12.80 12.86 108.02 3500.00 62.52 103.01 2574.14 606.88 S 1826.66 E 1919.4~ 140.73 15.13 17.12 106.69 4000.00 62.52 103.01 2804.89 706.71 S 2258.85 E 2362.9E 177.46 17.45 21.39 105.91 4500.00 62.52 103.01 3035.64 806.54 S 2691.05 E 2806.47 214.25 19.77 25.67 105.41 5000.00 62.52 103.01 3266.39 906.37 S 3123.24 E 3249.96 251.06 22.09 29.95 105.05 5500.00 62.52 103.01 3497.14 1006.20 S 3555.43 E 3693.45 287.90 24.40 34.24 104.78 6000.00 62.52 103.01 3727.89 1106.03 S 3987.62 E 4136.94 324.74 26.72 38.52 104.58 6063.09 62.52 103.01 3757.00 1118.62 S 4042.15 E 4192.8~ 329.40 27.01 39.07 104.56 6500.00 62.52 103.01 3958.63 1205.86 S 4419,81 E 4580.42 361.60 29.03 42.81 104.42 7000.00 62.52 103.01 4189.38 1305.69 S 4852.00 E 5023.91 398.46 31.35 47.10 104.29 7031.67 62.52 103.01 4204.00 1312.01 S 4879.38 E 5052.0! 400.80 31.50 47.37 104.28 7465.04 62.52 103.01 4404.00 - 1398.54 S 5253.98 E 5436.4C 432.75 33.51 51.09 104.19 7500.00 62.52 103.01 4420.13 1405.51 S 5284.19 E 5467.4C 435.33 33.67 51.39 104.18 7920.08 62.52 103.01 4614.00 1489.39 S 5647.31 E 5840.01 466.31 35.62 55.00 104.10 8000.00 62.52 103.01 4650.88 1505.34 S 5716.38 E 5910.8~ 472.20 35.99 55.68 104.09 8500.00 62.52 103.01 4881.63 1605.17 S 6148.57 E 6354.3E 509.07 38.31 59.98 104.01 9000.00 62.52 103.01 5112.38 1705.00 S 6580.76 E 6797.87 545.95 40.63 64.27 103.94 9500.00 62.52 103.01 5343.13 1804.83 S 7012.96 E 7241.36 582.83 42.95 68.56 103.88 9850.75 62.52 103.01 5505.00 1874.86 S 7316.14 E 7552.47 608.70 44.57 71.57 103.84 10000.00 62.52 103.01 5573.88 1904.66 S 7445.15 E 7684.8E 619.71 45.27 72.85 103.83 10431.47 62.52 103.01 5773.00 1990.81 S 7818.10 E 8067.5~ 651.53 47.27 76.55 103.79 10500.00 62.52 103.01 5804.63 2004.49 S 7877.34 E 8128.C~ 656.59 47.59 77.14 103.78 11000.00 62.52 103.01 6035.37 2104.32 S 8309.53 E 8571.8~ 693.47 49.91 81.43 103.74 Ali data is in feet unless otherv-se stated. Coordinates from slot 1i and TVD from rkb Pool ~ (Z~'~.~O Ft above mean sea level). Bottom hole distance is 9743.50 on azimuth 10~.~ degrees from wellhead. Vertical section is from wellhead on az~_:h 104.11 degrees. Calculation uses the minimum cur~:~re method. Presented by Baker Hughes ]'?EQ ARCO Alaska, Inc. Pad ID,Ii Kuparuk River Unit,North Sl.c~e, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth RECTANGULAR Vert COORDINATES Sect 11183.37 62.52 103.01 6120.00 2140.93 11475.90 62.52 103.01 6255.00 2199.34 11500.00 62.52 103.01 6266.12 2204.15 11627.58 62.52 103.01 6325.00 2229.62 11772.76 62.52 103.01 6392.00 2258.61 11917.94 62.52 103.01 6459.00 2287.59 11920.10 62.52 103.01 6460.00 2288.03 11924.44 62.52 103.01 6462.00 2288.89 11982.94 62.52 103.01 6489.00 2300.57 12000.00 62.52 103.01 6496.87 2303.98 12030.61 62.52 103.01 6511.00 2310.09 12045.78 62.52 103.01 6518.00 2313.12 12086.95 62.52 103.01 6537.00 2321.34 12320.95 62.52 103.01 6644.99 2368.06 12320.97 62.52 103.01 6645.00 2368.06 PROPOSAL LISTING Page 2 Your ref : 11 Version#3 Last revised : 8-Ju1-1999 Ellipse Semi Axes Minor Major Minor Vert. Azi. S 8468.03 E 8734.47 706.99 50.76 83.01 103.73 S 8720.89 E 8993.94 728.57 52.12 85.52 103.70 S 8741.72 E 9015.31 730.35 52.23 85.73 103.70 S 8852.00 E 9128.47 739.76 52.82 86.82 103.69 S 8977.49 E 9257.24 750.47 53.50 88.07 103.68 S 9102.98 E 9386.01 761.18 54.17 89.31 103.67 S 9104.85 E 9387.94 761.34 54.18 89.33 103.67 S 9108.60 E 9391.78 761.66 54.20 89.37 103.67 S 9159.17 E 9443.67 765.97 54.47 89.87 103.67 S 9173.91 E 9458.80 767.23 54.55 90.02 103.67 S 9200.37 E 9485.96 769.49 54.69 90.28 103.67 S 9213.48 E 9499.41 770.61 54.76 90.41 103.67 S 9249.07 E 9535.93 773.65 54.95 90.77 103.66 S 9451.33 E 9743.48 790.91 56.04 92.77 103.65 S 9451.35 E 9743.50 790.91 56.04 92.77 103.65 POSITION UNCERTAINTY SUMMARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 12321 ARCO (H.A. Mag) ........... User specified 790.91 56.04 92.77 i Ellipse dimensions are half axis. 2 Casing dimensions are not included. 3 Ellipses are calculated on 2.58 standard deviations. 4 Uncertainty calculations start at drill depth zero. 5 Surface position uncertainty is not included. 6 Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. Al! data is in feet unless otherwise stated. Coordinates fr~s slot 11 and ~VD from rkb Pool #6 (105.©0 Ft above mean sea level). Bottom h~-ie distance is 9743.50 on azimuth 104.07 degrees from wellhead. Ve-s~cal section Is from wellhead on azimuth i04.11 degreas. Calculation uses the minimum curvature method. Presented by Baker Hughes iNTEQ ARCO Alaska, Inc. Pad ID, 11 Kuparuk River Unit,North Slope, Alaska PRO,AL LISTING Page 3 Your ref : 11 Version #3 Last revised : 8-Ju1-1999 Co~lnents in wellpath HD TVD Rectangular Coords. r.x~m~ent 250.00 250.00 0.00 N 0.00 E Begin 1.5 Deg/lO0' Build 400.00 399.96 0.00 N 2.94 E Begin 3 Deg/lOO' Build & Turn 1813.33 1685.00 253.72 S 452.23 E ~se of Permafrost 2545.21 2133.51 416.25 S 1001.36 EEOC 6063.09 3757.00 1118.62 S 4042.15 E Top of West Sak 7031.67 4204.00 1312.01S 4879.38 E Base of West Sak 7465.04 4404.00 1398.54 S 5253.98 E 9 5/8" Casing Point 7920.08 4614.00 1489.39 S 5647.31E ~0 9850.75 5505.00 1874.86 S 7316.14 E C50 10431.47 5773.00 1990.81S 7818.10 E C40 11183.37 6120.00 2140.93 S 8468.03 E C30 11475.90 6255.00 2199.34 S 8720.89 E C20 11627.58 6325.00 2229.62 S 8852.00 E Base HRZ 11772.76 6392.00 2258.61S 8977.49 E K-1 11917.94 6459.00 2287.59 S 9102.98 E Top of Kuparuk D 11920.10 6460.00 2288.03 S 9104.85 E 1D-11 23-Jun-99 11924.44 6462.00 2288.89 S 9108.60 E Top C4 11982.94 644)9.00' 2300.57 S 9159.17 E Top C3 12030.61 6511.00 2310.09 S 9200.37 E Top C2 12045.78 6518.00 2313.12 S 9213.48 E Top C1 12086.95 6537.00 2321.34 S 9249.07 E Top B Shale 12320.95 6644.99 2368.06 S 9451.33 ETD - Casing Pt Casing_ positions in string 'A' Top MD Top lt/D Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 7465.04 4404.00 1398.54S 5253.98E 9 5/8' Casing 0.00 0.00 O.OON O.OOE 2321.00 6645.00 2368.06S 9451.35E 7" Casing Targets associated with this wel 1 path Target name Geographic Locatimq T.V.D. Rectangular Coordinates Revised ...... ...... ..... ....... ARCO Alaska, Inc. Pad 1D 11 slot 11 Kuparuk River Unit North Slope, A1 aska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 11 Version#3 Our ref : prop3443 License : Date printed : 8-Ju1-1999 Date created : 7-Jun-1999 Last revised : 8-~u1-1999 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is n70 17 55.553,w149 30 36.428 Slot Grid coordinates are N 5959078.720, E 560490.724 Slot local coordinates are 586.00 S 601.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <291 - 5795'> PMSS <556-7024'> PMSS <0-4590'>, PGMS <0-9783'> PMSS <0-5126'>, PMSS <381-6092'> PGMS <0-8365'> PMSS <0-5047'>, PGMS <0-8930'> PMSS <0 - 7150'> ,,125,Pad 1D ,,9,Pad 1D 118,Pad 1D ,2,Pad 1D 106,Pad 1D ,105,Pad 1D ,1,Pad 1D 124,Pad 1D ,5,Pad 1D ,108,Pad 1D PMSS <256 - 5973'>,,1lO,Pad 1D PMSS <294 - 8250'>,,112,Pad 1D PMSS <290-6245'>,,116,Pad 1D GSS <0-175'>,,116,Pad 1D PMSS <293 - 6866'>,,113,Pad 1D PMSS <287-6055'>,,123,Pad 1D GSS <O-173'>,,123,Pad 1D PMSS<O-7045'>,,lll,Pad 1D PMSS <0 - 6270'>, 114,Pad 1D PMSS <0 - 5445'>, 122,Pad 1D PMSS <0 - 6580'>, 128,Pad 1D PMSS <467 - 5802'> ,132,Pad 1D PMSS <377 - 6224'> ,134,Pad 1D PMSS <0 - 6472'>, 131,Pad 1D PMSS <0 - 7432'>,,127,Pad 1D PMSS <0 - 6716'>,,126,Pad 1D PMSS <O-4530'>,,120,Pad 1D Closest approach with 3-D Last revised Distance Minimum Distance method M.D. Diverging from M.D. 19-Aug-1998 300.0 100.0 29-Apr-1998 450.0 100.0 2-$un-1998 479.4 411.1 4-Aug-1992 702.8 400.0 2-~un-1998 690.0 100.0 2-~un-1998 719.5 287.5 10-Dec-1997 822.8 411.1 2-Jun-1998 315.0 100.0 13-Nov-1997 342.5 300.0 28-0ct-1998 660.0 100.0 5-0ct-1998 630.0 100.0 21-Sep-1998 569.9 200.0 17-Sep-1998 510.0 100.0 8-Sep-1998 510.0 100.0 22-Sep-1998 555.0 160.0 13-Sep-1998 371.9 411.1 4-Sep-1998 375.0 160.0 3-Sep-1998 614.7 400.0 2-Sep-1998 538.9 444.4 29-Aug-1998 389.3 411.1 17-Aug-1998 255.0 655.6 6-Aug-1998 106.9 622.2 3-Aug-1998 75.0 466.7 23-Jul-1998 138.8 611.1 6-~u1-1998 267.1 577.8 1-~u1-1998 285.0 100.0 2-2un-1998 420.0 100.0 100.0 100.0 411.1 400.0 100.0 287.5 411.1 100.0 300 0 100 0 100 0 200 0 100 0 100 0 160 0 411 1 160 0 400 0 444 4 411 1 7860 0 622 2 466 7 611 1 577 8 411 1 100 0 PGMS <O-8070'>,,3,Pad PMSS <0-5142'>,,115,Pad i¢ PGMS <O-7502'>,,4,Pad 1D PMSS <O-4778'>,,130,Pad 1D PMSS <O-5462'>,,129,Pad 1D MSS <3311-8200'>,,7,Pad 1D PGMS <O-8610'>,,6,Pad 1D PMSS <O-5015'>,,135,Pad 1D PMSS <1957-5265'>,,133,Pad 1D PMSS <O-4850'>,,109,Pad 1D PMSS <O-5205'>,,117,Pad 1D PMSS <O-4515'>,,119,Pad 1D PMSS <O-4414'>,,121,Pad 1D 13-Aug-1998 2-Jun-1998 4-Aug-1992 2-Jun-1998 2-~un-1998 6-Nov-1997 13-Nov-1997 2-Jun-1998 2-Jun-1998 2-~un-1998 2-~un-1998 2-Jun-1998 2-~un-1998 PGMS <0-8850'> 28-May-81,,MP i 17-ii-ii,Pad 1D 23-Apr-1999 TOTCO Survey,,WS-8,Pad 1D 11-$un-1999 PMSS <0 - 7340'>,,lO,Pad 1D 28-Apr-1998 583.0 525.0 462.5 180.0 194.4 103.0 222.0 60.0 135.0 645.0 495.0 435.0 405.0 3767.2 16.5 21.7 0.0 160.0 411.1 100.0 522.2 262.5 400.0 371.4 100.0 100.0 100.0 100.0 100.0 10100.0 385.7 544.4 371.4 160.0 411.1 100.0 522 2 262 5 400 0 371 4 511 1 100 0 100 0 100 0 100 0 10100 0 385 7 1533 3 ARCO Alaska, Inc. Kuparuk Unit Disbursement Account P.O. Box 102776 Anchorage, AK 99510-2776 230097395 73-426 839 0997587 JUNE 22, 1999 PAY TO THE : ,.i:i' '.: :.,'~i~, ORDER OF: ALASKA DEPT OF REVENUE ::~ii ":::~'ii'~::, :~::, :~ ALASKA OIL~& i':GAS CONSERVATION COMMI · :~ .... "' 3001 PORCU:PiNE',.DRIVE. :: :!~:**'* '!:. VOID AFTER 90 DAYS *** r:' ',~/' . i; , ~: i · i. EXACTLY **********~";.00 ~'~DOLLARS AND O0 ~CENTS~ $*********** 100.00 ii.:i :,:, ' :;':!: : .:"'i: ";i' ::ii': ' '::;' ' !" " ' The First National Bank of Chicago-0710 Payable Through Republic Bank Shelbyville, Kentucky TRACE NUMBER: 230097395 ,' aSOOCi7 5q 5,' ,:Oa :~qO[, ar. a~: WELL PERMIT CHECKLIST COMPANY .., .,~..---~_./.~ INIT CLASS ADMINISTRATION FIELD & POOL N N Y'N N N 1 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. WELL NAME/~,ffZ,~l/,J'-// PROGRAM: exp ~ GEOL AREA · Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ ( If deviated, is wellbore plat included ............... (~ ~.~ Operator only affected party ................... 4 Operator has appropriate bond in force ............. /,"~ Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... dev ~ redrll ~ serv ~ wellbore seg ann. disposal para req ~ 'ENGINEERING GEOLOGY 14. Conductor string provided ................... ~' Y(~.~) N 15. Surface casing protects all known USDWs ........... ~ N 16. CMT vol adequate to circulate on conductor & surf csg ..... N 17. CMT vol adequate to tie-in long string to surf csg ........ N 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... ANNULAR DISPOSAL UNIT# '////_~'"C~ ON/OFF SHORE ~),,'~ APPR DATE 22. Adequate wellbore separation proposed ............. -('Y')N 23. If diveder required, does it meet regulations .......... ~~1- Y N 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ ..--. ~..?.\-~ ~-,~.,,. ~-¥~.,-,-¥~,c,\ %"~ %~,~%~ c~,~., V~._~V.~,.,,~ ~ 26. BOPE press rating appropriate; test to ~::¢:~C~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... (,Z) N 29. Is presenc_e_ of H2S gas probable ................. Y 30. PeF~t can be issued w/o hydrogen sulfide measures ..... Y N 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. ..,/-"Y N /'/_//,/ ,~ / , 33. Seabed condition survey (if off-shore) ............ 34. Contact name/phone for weekly progress reports [explora.~r~y only] Y N proper cementing records, this plan 35. With (A) will contain waste in a suitable receiving zone; ....... ' Y N (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or'20 AAC 25.412. Y N Y N Y N GE.OL_~: ENGINEERING: UIC/Annular COMMISSION: c:\m soffice\wordian\diana\checklist WELL PERMIT CHECKLIST COMPANY ~ ~")',C I~ WELL NAME K u, 10 ~! f PROGRAM: exp __ dev ~__ serv __ wellbore seg __ann. disposal para req .__ FIELD & POOL INIT CLASS ADMINISTRATION ~rN-EERING 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... APPR DATE GEOL AREA N N N N ( N 14. Conductor string provided ................... '~ N 15. Surface casing protects all known USDWs ........... ~ N 16. CMT vol adequate to circulate on conductor & surf csg ..... ~ N 17. CMT vol adequate to tie-in long string to surf csg ........ Y N 18. CMT will cover all known productive horizons .......... ~_~ N 19. Casing designs adequate for C, T, B & permafrost ....... I~.~.' N 20. Adequate tankage or reserve pit ................. d~_.2 N 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. ~ N 23. If diverter required, does it meet regulations .......... C_~ N 24. Drilling fluid program schematic & equip list adequate ..... (~ N 25. BOPEs, do they meet regulation ................ ¢~ N 26. BOPE press rating appropriate; test to ~ (3~ psig. (~3¢~ N 27. Choke manifold complies w/APl RP-53 (May 84) ........ ._~ N 28. Work will occur without operation shutdown ........... L_y) N 29. Is presence of H2S gas probable ................. ~ N ~' ~' r0 UNIT# / (' / _//y ¢._) ON/OFF SHORE GEOLOGY A~.~P R DATE ANNULAR DISPOSAL APPR DATE 30. Permit can be issued w/o hydrogen sulfide measures... ~ N 31. Data presented on potential overp~ . Y N ,~ ,,, 32. Seismic anal~~ 33. Seabed con_~_djti~:~'d~-ey (if off-shore) ............. Y N 34. C me/phone for weekly progress reports [exploratory only] Y N 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... / ./~, (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N G E O.L_iQ_.~_Y: ENGINEERIr,CG: UlC/Annular COMMISSION: ~ ? BEW ~ '7'/'{~ WM DWJ ~ JDH .--'-'-,...-~ RNC ' CO ~ Comments/Instructions: c:\msoffice\wordian\diana\checklist Well Histo.ry 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. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Mar 17 15:39:30 2000 Reel Header Service name ............. LISTPE Date ..................... 00/03/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/03/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 3 AK-MM-90162 T. MCGUIRE F. HERBERT 1ST STRING 2ND STRING 3RD STRING iD-Ii 500292294600 Arco Alaska Inc. Sperry Sun 16-MAR-00 MWD RUN 4 AK-MM-90162 T. MCGUIRE F. HERBERT 23 lin 10E 586 601 .00 105.50 70.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 16.000 120.0 8.500 9.625 6814.0 6.125 7.000 10564.0 RECEIVED M/ R 'J 000 Alaska 011 & Gas (.;b;~, uummission Anchorage PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURE DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1-2 ARE DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS. 4. MWD RUN 4 IS DIRECTIONAL WITH DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY {CTN), AND STABILIZED LITHO-DENSITY (SLD). 5. SLD SLIDE REFERS TO SLD TOOL DEPTH DURING STEERING INTERVALS. 6. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE EMAIL FROM D. SCHWARTZ OF ARCO ALASKA, INC. ON 02/07/00. SPERRY-SUN MWD LOG DATA IS CONSIDERED PDC. 7. MWD RUNS 1-4 REPRESENT WELL 1D-II WITH API#: 50-029-22946-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11234'MD, 6720'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SS MATRIX FIXED-HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNPE = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. PARAMETERS USED IN PROCESSING POROSITY LOGS: HOLE SIZE: 6.125" MUD WEIGHT: 10.7-10.8 PPG MUD SALINITY: 450 PPM CHLORIDES FOPdViATION WATER SALINITY: 13000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP NCNT FCNT NPHI FET RPD RPM RPX RPS PEF DRHO RHOB $ START DEPTH 6732 0 6830 0 10554 0 10554 0 10554 0 10554 0 10554 0 10554 0 10554 0 10554 0 10555 0 10573 0 10573 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: STOP DEPTH 11179 5 11233 0 11142 5 11142 5 11142 5 11186 5 11186 5 11186 5 11186 5 11186 5 11158 0 11158 0 11158 0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 3 6732.0 10572.0 4 10572.0 11233.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS ~D OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD PU-S 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 RHOB MWD G/CM 4 1 68 DRHO MWD G/CM 4 1 68 PEF MWD BARN 4 1 68 4 8 12 16 20 24 28 32 36 40 44 48 52 2 3 4 5 6 7 8 9 10 11 12 13 14 Name Service Unit Min Max DEPT FT 6732 11233 ROP MWD FT/H 0.09 410.41 GR MWD API 32.56 417.74 RPX MWD OHMM 1.67 1747.69 RPS MWD OHMM 1.71 1616.94 RPM MWD OHMM 1.84 2000 RPD MWD OHMM 0.83 2000 FET MWD HOUR 0.542 68.7202 NPHI MWD PU-S 17.39 58.03 FCNT MWD CNTS 140.8 806.9 NCNT MWD CNTS 15515.8 34020.9 RHOB MWD G/CM 2.25 3 DRHO MWD G/CM -0.09 0.27 PEF MWD BARN 3.67 14.75 Mean 8982.5 115.887 132.806 8.11888 9.53265 56.008 37.4106 3.14898 36.3402 315.753 21664.5 2.43987 0.051503 5.9637 Nsam 9003 8807 8896 1266 1266 1266 1266 1266 1178 1178 1178 1171 1171 1207 First Reading 6732 6830 6732 10554 10554 10554 10554 10554 10554 10554 10554 10573 10573 10555 Last Reading 11233 11233 11179 5 11186 5 11186 5 11186 5 11186 5 11186 5 11142 5 11142 5 11142 5 11158 11158 11158 First Reading For Entire File .......... 6732 Last Reading For Entire File ........... 11233 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 6732.0 ROP 6830.0 $ 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: STOP DEPTH 10530.5 10572.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 19-OCT-99 Insite 630.91 Memory 10572.0 57.2 60.5 TOOL NUMBER P1362HGV6 8.500 6814.0 LSND 9.10 49.0 8.0 4OO 6.2 .000 .000 .000 .000 .0 138.2 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 6732 10572 8652 7681 ROP MWD030 FT/H 0.09 410.41 124.666 7485 GR MWD030 API 32.56 417.74 135.533 7598 First Reading 6732 6830 6732 Last Reading 10572 10572 10530.5 First Reading For Entire File .......... 6732 Last Reading For Entire File ........... 10572 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR NCNT FCNT NPHI FET RPD RPS RPX RPM PEF ROP RHOB DRHO $ 10531 0 10554 0 10554 0 10554 0 10554 0 10554 0 10554 0 10554 0 10554 0 10555 0 10572 5 10573 0 10573 0 STOP DEPTH 11179 5 11142 5 11142 5 11142 5 11186 5 11186 5 11186 5 11186 5 11186 5 11158 0 11233 0 11158 0 11158 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 DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 23-OCT-99 Insite 0.41 Memory 11234.0 56.2 58.0 TOOL NUMBER P1367NLM4 P1367NLM4 P1367NLM4 P1367NLM4 6.125 10564.0 LSND 10.80 47.0 9.0 450 3.8 1.200 .599 1.750 2.600 68.0 143.0 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 RPS MWD040 RPM MWD040 RPD MWD040 FET MWD040 NPHI MWD040 FCNT MWD040 NCNT MWD040 RHOB MWD040 DRHO MWD040 PEF MWD040 OHMM 4 t 68 OHMM 4 1 68 OHMM 4 1 68 OHMM 4 1 68 HOUR 4 1 68 PU - 4 1 68 CNTS 4 1 68 CNTS 4 1 68 G/CM 4 1 68 G/CM 4 1 68 BARN 4 1 68 12 16 20 24 28 32 36 40 44 48 52 4 5 6 7 8 9 10 11 12 13 14 Name Service Unit DEPT FT ROP MWD040 FT/H GR MWD040 API RPX MWD040 OHMM RPS MWD040 OHMM RPM MWD040 OHMM RPD MWD040 OHMM FET MWD040 HOUR NPHI MWD040 PU - FCNT MWD040 CNTS NCNT MWD040 CNTS RHOB MWD040 G/CM DRHO MWD040 G/CM PEF MWD040 BARN Min Max 10531 11233 1 136.6 42.51 244.84 1.67 1747.69 1.71 1616.94 1.84 2000 0.83 2000 0.542 68.7202 17.39 58.03 140.8 806.9 15515.8 34020.9 2.25 3 -0.09 0.27 3.67 14.75 Mean Nsam 10882 1405 66.1784 1322 116.841 1298 8.11888 1266 9.53265 1266 56.008 1266 37.4106 1266 3.14898 1266 36.3402 1178 315.753 1178 21664.5 1178 2.43987 1171 0.051503 1171 5.9637 1207 First Reading 10531 10572.5 10531 10554 10554 10554 10554 10554 10554 10554 10554 10573 10573 10555 Last Reading 11233 11233 11179 5 11186 5 11186 5 11186 5 11186 5 11186 5 11142 5 11142 5 11142 5 11158 11158 11158 First Reading For Entire File .......... 10531 Last Reading For Entire File ........... 11233 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/03/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 00/03/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File