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Home My WebLink About181-0051. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Polymer Flood Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7753'feet 7190'feet true vertical 7049'feet 7189'feet Effective Depth measured 7190'feet 6814', 6907', 7172'feet true vertical 6585'feet 6267', 6348', 6570'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" x 4-1/2" J-55 7202' MD 6595' TVD Packers and SSSV (type, measured and true vertical depth) 6814' MD 6907' MD 7172' MD 1824' MD 6267' TVD 6348' TVD 6570' TVD 1819' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Authorized Title: 2784' 2695' Burst Collapse Production Liner 7692' Casing 7025'7723' 2749' 75'Conductor Surface Intermediate 16" 10-3/4" 41' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 181-005 50-029-20550-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025649 Kuparuk River Field/ Kuparuk River Oil Pool KRU 1C-05 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 75' ~~~ INJECTOR ~~ ~ 323-585 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Brown HB Retvbl PackerPacker: Baker FHL Packer Packer:Baker FB-1 Packer SSSV: Camco TRDP-1A-SSA Sfty Vlv Surveillance Reservoir Engineer 6970-6972', 7046-7118', 7442-7454', 7466-7488' 6402-6404', 6466-6526', 6792-6802', 6812-6830' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Contact Name: Cody Keith Contact Email:cody.d.keith@conocophillips.com Contact Phone: 263-4120 By Grace Christianson at 8:18 am, Jan 17, 2024 Cody Keith Digitally signed by Cody Keith Date: 2024.01.16 11:28:38 -09'00' RBDMS JSB 012324 DSR-1/26/24 1C-05 Polymer Injectivity Test – DAILY SUMMARY 11/29/2023 Begin equipment set-up on 1C pad 11/30/2023 Continue set-up on 1C pad 12/1/2023 Continue set-up on 1C pad 12/2/2023 Continue set-up on 1C pad 12/3/2023 Continue set-up on 1C pad. Two upright tanks and manifold, choke trailer, polymer storage, and polymer slicing unit have been placed. 12/4/2023 Continue set-up on 1C pad 12/5/2023 Continue set-up on 1C pad 12/6/2023 Continue set-up on 1C pad 12/7/2023 Walkdown of set-up to verify connections complete and function tested. Start-up delayed for polymer slicing unit technical difficulties. 12/8/2023 Troubleshoot polymer slicing unit technical difficulties. 12/9/2023 Troubleshoot polymer slicing unit technical difficulties. 12/10/2023 Troubleshoot polymer slicing unit technical difficulties. 12/11/2023 Troubleshoot polymer slicing unit technical difficulties. 12/12/2023 Troubleshoot polymer slicing unit technical difficulties. 12/13/2023 Troubleshoot polymer slicing unit technical difficulties. Attempt start-up, able to inject water-only at <2000 bwpd for approximately 1 hour, encounter polymer slicing unit technical difficulties. Continue troubleshooting. 12/14/2023 Troubleshoot polymer slicing unit technical difficulties. Begin 1900 bwpd water-only injection at 13:00. Begin mixing polymer at 20:30. 12/15/2023 Continue full-time 1000 ppm polymer injection ~1900 bwpd. Viscosity samples ~7.5 cp. 12/16/2023 Continue full-time 1000 ppm polymer injection ~1900 bwpd. Viscosity samples ~10.5 cp. 12/17/2023 Continue 1000 ppm polymer injection ~1900 bwpd until 12:00 pm. Viscosity samples ~10 cp. Begin water-only flush at 12:00 pm, ~1900 bwpd. 12/18/2023 Continue water-only flush until 1:00 am, ~1900 bwpd. Shut-in and freeze protect 1C-05, 20 bbl diesel. 12/19 – 12/24/2023 1C-05 SI for pressure-fall off test. 12/25/2023 BOL 6:10 am for normal produced water injection service. Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: SLM 7,079.01C-05 9/7/2015 lehallf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled & Re-set MCX & gauges.1C-05 11/30/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.012/6/2010 ninam NOTE: Mandrel @ 6755 - Pack-Off; Requires 1 5/8" JD to Pull. 12/6/2010 ninam NOTE: WORKOVER 4/15/1985 osborl Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1615.06 34.0 75.0 75.065.00 H-40 WELDED SURFACE 10 3/49.9533.52,782.4 2,695.5 45.50 K-55 BUTT PRODUCTION 7 6.28 31.2 7,723.3 7,024.6 26.00 K-55 BUTT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 27.8 Set Depth … 6,862.1 Set Depth … 6,308.8 String Max No… 3 1/2 Tubing Description TUBING WO 1990 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 27.827.80.02 HANGER 8.000 FMC TUBING HANGER 3.500 1,824.4 1,819.4 12.23 SAFETY VLV 5.937 CAMCO TRDP-1A-SSA SAFETY VALVE 2.813 6,754.7 6,214.026.84 GAS LIFT 5.750CAMCOMMG-22.920 6,798.8 6,253.2 27.73 PBR 5.625 BAKER PBR 2.813 6,814.0 6,266.6 28.06 PACKER 6.156 BROWN HB RETRIEVABLE PACKER 2.891 6,820.2 6,272.1 28.20 NIPPLE 4.520 OTIS X NIPPLE 2.813 6,853.2 6,301.1 28.95 Packoff Assy 5.750 TRI-STATE PACKOFF ASSEMBLY GUIDE STABBED INTO ORIGINAL COMPLETION 3.500 Top (ftKB) 6,857.2 Set Depth … 7,202.3 Set Depth … 6,595.3 String Max No… 4 1/2 Tubing Description TUBING WO 1985 Wt (lb/ft) 9.30 Grade J-55 Top Connection FL4S ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,881.0 6,325.4 29.57 SBR 5.880 BAKER SBR 5.000 6,907.3 6,348.1 30.15 PACKER 5.968 BAKER FHL PACKER 3.000 6,944.7 6,380.3 30.89 INJECTION 5.750 CAMCO MMG-2 2.920 7,016.06,441.032.40 INJECTION5.750CAMCOMMG-22.920 7,024.16,447.932.60 BLAST RINGS 4.500 CARBIDE BLAST RINGS 2.992 7,152.5 6,554.4 34.58 INJECTION5.750CAMCOMMG-22.920 7,170.9 6,569.6 34.61 LOCATOR 4.500 BAKER COLLAR LOCATOR 3.000 7,171.7 6,570.2 34.61 PACKER 5.875 BAKER FB-1 PACKER 4.000 7,175.0 6,572.9 34.61 SBE 5.000 BAKER SEAL BORE EXTENSION 4.000 7,190.26,585.4 34.64NIPPLE 4.540CAMCO D NIPPLE NO GO 2.750 7,201.86,594.934.66 WLEG3.500 BAKER WIRELINE RE-ENTRY GUIDE 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,820.06,271.928.20 GAUGES2.813" MCX INJECTION VALVE & TANDEM SPARTEK GAUGES (94" OAL) Programed for 1 second sample rate. 11/30/2023 0.000 7,189.06,584.4 34.63 FISH 2 5/8" WA Chem. Cutter Left in tail pipe above CA-2 plug from workover 3/11/1990 0.000 7,190.2 6,585.4 34.64 PLUG CAMCO CA-2 PLUG 3/11/1990 0.000 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) 6,754.7 6,214.026.84 1 GAS LIFT DMY RK 1 1/20.08/31/1991 0.000 6,944.7 6,380.330.89 2 INJ HFCVRKP 1 1/20.08/17/2019 Full Open 0.000 7,016.06,441.032.40 3 INJ HFCVRKP 1 1/20.08/17/2019 Full Open 0.000 7,152.5 6,554.4 34.58 4 INJ DMY RK 1 1/20.03/26/1990 Close d 0.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 6,970.0 6,972.0 6,402.0 6,403.7 UNIT D, 1C-05 4/29/1985 4.0 APERF 90 deg phase; 2 1/16" Rigid Jet 7,046.0 7,118.0 6,466.3 6,526.0 C-4, C-3, 1C-05 2/27/1981 12.0 IPERF 5" Vann Guns 7,442.0 7,454.0 6,792.1 6,802.0 A-5, 1C-05 4/29/1985 4.0 APERF 90 deg phase; 2 1/16" Rigid Jet 1C-05, 1/12/2024 1:04:51 PM Vertical schematic (actual) PRODUCTION; 31.2-7,723.3 APERF; 7,466.0-7,488.0 APERF; 7,442.0-7,454.0 PLUG; 7,190.2 FISH; 7,189.0 PACKER; 7,171.7 INJECTION; 7,152.5 IPERF; 7,046.0-7,118.0 INJECTION; 7,016.0 APERF; 6,970.0-6,972.0 INJECTION; 6,944.7 PACKER; 6,907.3 GAUGES; 6,820.0 PACKER; 6,814.0 GAS LIFT; 6,754.7 SURFACE; 33.5-2,782.4 SAFETY VLV; 1,824.4 CONDUCTOR; 34.0-75.0 KUP INJ KB-Grd (ft) 39.01 RR Date 2/27/1981 Other Elev… 1C-05 ... TD Act Btm (ftKB) 7,753.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292055000 Wellbore Status INJ Max Angle & MD Incl (°) 35.00 MD (ftKB) 7,300.00 WELLNAME WELLBORE Annotation Last WO: End Date 3/11/1990 H2S (ppm)DateComment SSSV: TRDP Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 7,466.0 7,488.0 6,811.9 6,830.0 A-4, 1C-05 4/28/1985 4.0 APERF 90 deg phase; 2 1/16" Rigid Jet 1C-05, 1/12/2024 1:04:53 PM Vertical schematic (actual) PRODUCTION; 31.2-7,723.3 APERF; 7,466.0-7,488.0 APERF; 7,442.0-7,454.0 PLUG; 7,190.2 FISH; 7,189.0 PACKER; 7,171.7 INJECTION; 7,152.5 IPERF; 7,046.0-7,118.0 INJECTION; 7,016.0 APERF; 6,970.0-6,972.0 INJECTION; 6,944.7 PACKER; 6,907.3 GAUGES; 6,820.0 PACKER; 6,814.0 GAS LIFT; 6,754.7 SURFACE; 33.5-2,782.4 SAFETY VLV; 1,824.4 CONDUCTOR; 34.0-75.0 KUP INJ 1C-05 ... WELLNAME WELLBORE 1 Regg, James B (OGC) From:CPF1 Prod Engr <n1269@conocophillips.com> Sent:Wednesday, December 13, 2023 4:55 PM To:Regg, James B (OGC) Cc:Well Integrity Specialist CPF1 & CPF3; NSK Prod Engr Specialist; CPF1 DS Lead Techs; CPF1 Ops Supv; Braun, Michael; Keith, Cody; Becia, Adam C Subject:Defeated LPP on well 1C-05 (PTD# 181-005) 12/09/2023 Good afternoon Jim, The low pressure pilot (LPP) on well 1C‐05 (PTD# 181‐005) was defeated on 12/09/2023 and will remain defeated while pumping a polymer injection trial until 12/19/2023. The polymer injection has started today 12/13/2023 and it will be a 24hr manned operation with hourly walk‐downs of the hardline and wellhead. The LPP has been tagged and the status is recorded in the “Drill Site Defeated Safety Device Log.” The AOGCC will be notified when the LPP function is returned to normal. Please let me know if you have any questions. Thank you, Production Engineer – GKA (CPF1) ConocoPhillips | Alaska, Inc Office: 907.265.1027 | Mobile: 907.302.8214 Dmitry.Shchekotov@ConocoPhillips.com You don't often get email from n1269@conocophillips.com. Learn why this is important 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. KRU 1C-05PTD 1810050 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Polymer Flood 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7753'7189' Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 12/1/2023 3-1/2" x 4-1/2" Packer: Brown HB Rtrvbl Packer Packer: Baker FHL Packer Packer: Baker FB-1 Packer SSSV: Camco TRDP-1A-SSA Sfty Vlv Perforation Depth MD (ft): J-55 2749' 6970-6972', 7046-7118', 7442-7454', 7466-7488' 7692' 6402-6404', 6466-6526', 6792- 6802', 6812-6830' 7" Perforation Depth TVD (ft): 75' 2782' 7025'7723' 16" 10-3/4" 41' 7202' MD 75' 2695' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025649 181-005 P.O. Box 100360, Anchorage, AK 99510 50-029-20550-00-00 Kuparuk River Field Kuparuk River Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6814' MD and 6267' TVD 6907' MD and 6348' TVD 7172' MD and 6570' TVD 1824' MD and 1819' TVD Cody Keith Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: cody.d.keith@conocophillips.com (907) 263-4120 Surveillance Reservoir Engineer KRU 1C-05 7049' 7190' 6585' 7190' N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:38 am, Oct 27, 2023 Cody Keith Digitally signed by Cody Keith Date: 2023.10.27 07:56:30 -08'00' 323-585 SFD 10/30/2023 DSR-11/2/23 10-404 VTL 11/14/2023*&:JLC 11/15/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.11.15 14:30:52 -09'00'11/15/23 RBDMS JSB 111623 1C-05 Polymer Injection Trial Objecve The objec ve of the trial is to iden fy injec vity of 1C-05 while pumping 10 cP polymer to inform future economic modeling. Procedure Set equipment on 1C pad following all COP standards o 4 Tanks and Manifold o Choke Trailer o Polymer slicing unit (PSU) o Waste tank o Chemical injec on skid (O2 scavenger) o Polymer storage Hook equipment up and check for func onality HSE and facility walkdowns Start-up PSU on water only Pump 10 cP polymer solu on down injector monitoring pressure, /owrate, and viscosity Pump 24 hours / 7 days a week for 2 weeks Shut-in well for pressure fall o2 Rig down move out Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: SLM 7,079.0 1C-05 9/7/2015 lehallf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled MCX Valve & Gauges 1C-05 3/31/2023 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.012/6/2010 ninam NOTE: Mandrel @ 6755 - Pack-Off; Requires 1 5/8" JD to Pull. 12/6/2010 ninam NOTE: WORKOVER 4/15/1985 osborl Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1615.06 34.0 75.0 75.065.00 H-40 WELDED SURFACE 10 3/49.9533.52,782.4 2,695.5 45.50 K-55 BUTT PRODUCTION 7 6.28 31.2 7,723.3 7,024.626.00 K-55 BUTT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 27.8 Set Depth … 6,862.1 Set Depth … 6,308.8 String Max No… 3 1/2 Tubing Description TUBING WO 1990 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 27.8 27.8 0.02 HANGER 8.000 FMC TUBING HANGER 3.500 1,824.4 1,819.4 12.23 SAFETY VLV 5.937 CAMCO TRDP-1A-SSA SAFETY VALVE 2.813 6,754.7 6,214.0 26.84 GAS LIFT 5.750 CAMCO MMG-2 2.920 6,798.8 6,253.2 27.73 PBR 5.625 BAKER PBR 2.813 6,814.0 6,266.6 28.06 PACKER 6.156 BROWN HB RETRIEVABLE PACKER 2.891 6,820.2 6,272.1 28.20 NIPPLE 4.520 OTIS X NIPPLE 2.813 6,853.26,301.128.95 Packoff Assy 5.750 TRI-STATE PACKOFF ASSEMBLY GUIDE STABBED INTO ORIGINAL COMPLETION 3.500 Top (ftKB) 6,857.2 Set Depth … 7,202.3 Set Depth … 6,595.3 String Max No… 4 1/2 Tubing Description TUBING WO 1985 Wt (lb/ft) 9.30 Grade J-55 Top Connection FL4S ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,881.0 6,325.4 29.57 SBR 5.880 BAKER SBR 5.000 6,907.3 6,348.1 30.15 PACKER 5.968 BAKER FHL PACKER 3.000 6,944.7 6,380.330.89 INJECTION5.750CAMCOMMG-22.920 7,016.06,441.032.40 INJECTION5.750CAMCOMMG-22.920 7,024.16,447.932.60 BLAST RINGS 4.500 CARBIDE BLAST RINGS 2.992 7,152.5 6,554.4 34.58 INJECTION 5.750 CAMCO MMG-2 2.920 7,170.9 6,569.6 34.61 LOCATOR 4.500 BAKER COLLAR LOCATOR 3.000 7,171.7 6,570.2 34.61 PACKER 5.875 BAKER FB-1 PACKER 4.000 7,175.0 6,572.9 34.61 SBE 5.000 BAKER SEAL BORE EXTENSION 4.000 7,190.2 6,585.4 34.64 NIPPLE 4.540 CAMCO D NIPPLE NO GO 2.750 7,201.86,594.934.66 WLEG3.500 BAKER WIRELINE RE-ENTRY GUIDE 2.992 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) 7,189.0 6,584.4 34.63 FISH 2 5/8" WA Chem. Cutter Left in tail pipe above CA-2 plug from workover 3/11/1990 0.000 7,190.2 6,585.4 34.64 PLUG CAMCO CA-2 PLUG 3/11/1990 0.000 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) 6,754.7 6,214.026.84 1 GAS LIFT DMY RK 1 1/20.08/31/1991 0.000 6,944.7 6,380.330.89 2 INJ HFCVRKP 1 1/20.08/17/2019 Full Open 0.000 7,016.0 6,441.0 32.40 3 INJ HFCVRKP 1 1/2 0.08/17/2019 Full Open 0.000 7,152.5 6,554.4 34.58 4 INJ DMY RK 1 1/2 0.03/26/1990 Close d 0.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 6,970.06,972.06,402.06,403.7 UNIT D, 1C-054/29/19854.0 APERF 90 deg phase; 2 1/16" Rigid Jet 7,046.0 7,118.06,466.36,526.0C-4, C-3, 1C-05 2/27/1981 12.0 IPERF 5" Vann Guns 7,442.0 7,454.06,792.16,802.0 A-5, 1C-054/29/19854.0 APERF 90 deg phase; 2 1/16" Rigid Jet 7,466.0 7,488.0 6,811.9 6,830.0 A-4, 1C-05 4/28/1985 4.0 APERF 90 deg phase; 2 1/16" Rigid Jet 1C-05, 10/26/2023 5:54:54 PM Vertical schematic (actual) PRODUCTION; 31.2-7,723.3 APERF; 7,466.0-7,488.0 APERF; 7,442.0-7,454.0 PLUG; 7,190.2 FISH; 7,189.0 PACKER; 7,171.7 INJECTION; 7,152.5 IPERF; 7,046.0-7,118.0 INJECTION; 7,016.0 APERF; 6,970.0-6,972.0 INJECTION; 6,944.7 PACKER; 6,907.3 PACKER; 6,814.0 GAS LIFT; 6,754.7 SURFACE; 33.5-2,782.4 SAFETY VLV; 1,824.4 CONDUCTOR; 34.0-75.0 KUP INJ KB-Grd (ft) 39.01 RR Date 2/27/1981 Other Elev… 1C-05 ... TD Act Btm (ftKB) 7,753.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292055000 Wellbore Status INJ Max Angle & MD Incl (°) 35.00 MD (ftKB) 7,300.00 WELLNAME WELLBORE Annotation Last WO: End Date 3/11/1990 H2S (ppm)DateComment SSSV: TRDP MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, June 14, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Matt Herrera P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1C-05 KUPARUK RIV UNIT 1C-05 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/14/2022 1C-05 50-029-20550-00-00 181-005-0 W SPT 6266 1810050 1566 2448 2450 2453 2459 487 547 540 537 4YRTST P Matt Herrera 5/17/2022 MIT-IA Performed to 1800 PSI Per Operations 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 1C-05 Inspection Date: Tubing OA Packer Depth 890 1800 1715 1705IA 45 Min 60 Min Rel Insp Num: Insp Num:mitMFH220518130440 BBL Pumped:1.2 BBL Returned:0.9 Tuesday, June 14, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.14 13:49:01 -08'00' Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Tuesday, September 15, 2020 8:02 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 1C-05 (PTD 181-OOSUpdate Attachments: 1 C -OS 90 day TIO trend 9.15.20.pdf Chris, KRU 1C-05 (PTD 181-005) was reported on 8/16/20 for exhibiting suspect IAx0A communication. DHD was mobilized to the well and Re -energized the inner casing pack off with graphite sealant and bled the OA pressure below the IA pressure to establish a healthy differential pressure. The well was then placed on a 30 day monitor period and did not exhibit any signs of annular communication. CPAI intends to return the well to 'normal' status at this time. A 90 day TIO trend is attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 W E LLS TEAM ConocAphinips Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Sunday, August 16, 2020 7:56 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 1C-05 (PTD181-005) Report of suspect annular communication Attachments: 1 C-05.pdf; 1 C-05 90 day TIO trend 8.16.2020.pdf Chris, KRU 1C-05 (PTD 181-005) was reported by Operations to be exhibiting suspect IAxOA communication. DHD will be mobilized to the well to perform initial diagnostics and establish a healthy pressure differential between the two annuli after which a 30 day monitor will be started. The proper paperwork for continued injection or corrective action will be submitted upon completion of the monitor period. A 90 day TIO trend and wellbore schematic are attached. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 WELLS TEAM cw+oc�u+� • MEMORANDA? State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,May 16,2018 TO: Jim Regg P.I.Supervisor l (2.4 Cet( J ( SUBJECT: Mechanical Integrity Tests 1 CONOCOPHILLIPS ALASKA,INC. 1C-05 FROM: Austin McLeod KUPARUK RIV UNIT IC-05 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1C-05 API Well Number 50-029-20550-00-00 Inspector Name: Austin McLeod Permit Number: 181-005-0 Inspection Date: 5/13/2018 Insp Num: mitSAMl80514080020 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min --- ----- -- Well 1C-05 [Type Inj W 'TVD j 6266 -1 Tubing 2280 - 2280 2280 - 2280 - PTD-1— 1810050 !Type Test SPT Test psi 1566 IA 670 , 1745 -1 1680 - 1660 BBL Pumped: 1.6 BBL Returned: 1.6 OA 316 - 382 I 379 _ 377 - Interval 4YRTST P/F P ✓ Notes: MIT-IA %OW JUN 0 1201B WednesdaY,May 16,2018 Page 1 of 1 C~ MEMORANDUM To~ Jim Regg '~ P.I. Supervisor ~~~~( ~~~~~~~ FROM: John Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, May 25, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 C-OS KUPARUK RIV UNIT 1C-OS Src: Inspector NON-CONFIDENTIAL Reviewed By: P.LSuprv JPl~- Comm Well Name: KUPARUK RIV UNIT 1C-OS API Well Number: 50-029-20550-00-00 Inspector Name: John Crisp Insp Num: mitJCr100523165916 Permit Number: 181-005-0 Inspection Date: 5/21/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1c--os ~ype Inj. ' w TVD P.T.D 1810050 T pe eTe eSt SPT ~ TCSt pSl ---- -1 IriteCVal 4YRTST per, 6z66 ~ Ip 1566 ~ QA ~--~--- P ,/ Tubing soo~ zzoo 180 I, 210 --- ~ 850 851 ~ z13o 210 ~ - 849 zloo ~~ 200 -- 848 i. Notes: 5.3 bbls pumped for test. No problems witnessed. p' ~: Tuesday, May 25, 2010 Page 1 of 1 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg ,/'} I I P.I. Supervisor J<\ef1 5 i c( I c<v DATE: Tuesday, May 09, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA rNC IC-05 KUPARUK RIV UNIT IC-05 ·ø~ Q:;,\,;' 0 \ FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv-¡¡:SR Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT lC-05 API Well Number 50-029-20550-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ060508175315 Permit Number: 181-005-0 Inspection Date: 5/8/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -~-------.--- ! _._~~- I I Well i IC-O) ¡Type Inj. I W i TVD ! 6267 IA 1125 2640 2620 2620 i P. T. i 1810050 TypeTest i SPT i Test psi i 1566.75 OA , ! i I 280 300 300 300 Tubing i ~ Interval 4YRTST P/F P 1820 1821 1822 1822 Notes 2.9 bbls diesel pumped, 1 well house inspected; no exceptions noted. 'ªC~'\!NEL '" 1'\ ')nnfi ..1 10 L~ -' J , . Tuesday, May 09, 2006 Page I of I e e ConocoPhillips Alaska, Inc. KRU 1C-05 11 C-05 , API: 500292055000 Well Tvpe: INJ Anele (õ) TS: 33 dea (õ) 7044 SSSV Type: TRDP Orig 2/27/1981 Angle @ TD: 34 deg @ 7753 sssv ¡La Completion: (1824-1825, Annular Fluid: Last W/O: 3/11/1990 Rev Reason: CV C/O OD:3.500) Reference Loe: Ref Loa Date: Last Update: 3/28/2006 Last Taa: 7105 TD: 7753 ftKB Last Taa Date: 7/25/2004 Max Hole Anale: 35 dea (õ) 7300 II Casina Strine - ALL STRINGS Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 75 75 65.00 H-40 SURFACE 10.750 0 2782 2695 45.50 K-55 I PRODUCTION 7.000 0 7723 7024 26.00 K-55 PBR ill Tubina Strine - TUBING (TUBING STRING (õ) 6854' on Down Left in Hole f/ Previous Completion (6799-6800, OD, 3. 500) Size Top 1 Bottom I TVD I Wt I Grade I Thread 3.500 0 I 6854 I 6302 I 9.30 1 J-55 1 EUE 8RD MOD 3.500 6854 1 7203 1 6596 I 9.30 1 J-55 I EUE 8RD MOD PKR Perforations Summary (6814-6815. Interval TVD Zone Status Ft SPF Date Type Comment 00:6.156) 6970 - 6972 6402 - 6404 Open 2 4 4/29/1985 APERF 90 deg phase; 2 1/16" Rigid ' Jet 7046 - 7118 6466 - 6526 C-4,C-3 Open 72 12 2/27/1981 IPERF 5" Vann Guns NIP 7442 - 7454 6792 - 6802 A-5 Closed 12 4 4/29/1985 APERF 90 deg phase; 2 1/16" Rigid (6820-6821, Jet 00:3.500) 7466 - 7488 6812 - 6830 A-4 Closed 22 4 4/28/1985 APERF 90 deg phase; 2 1/16" Rigid Jet TUBING Gas Lift MandrelsNalves (0-6854. St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv 00:3.500, 10:2.992) Mfr Run Cmnt 1 I 67551 62141 Cameo 1 MMG-2 [ DMY 1 1.5 1 RK 1 0.000 I 0 18/31/1991 (1) 1. PACK-OFF; Reauires 1 518" JD to Pull. , , Iniection MandrelsNalves PKR St MD TVD Man Man Type V Mfr V Type I V OD Latch Port TRO Date Vlv (6907-6908, 00:6.156) Mfr Run Cmnt 2 6945 6380 Cameo MMG-2 MMH HFCV 1.5 RK 0.000 0 3/25/2006 Open 3 7016 6441 Cameo MMG-2 MMH HFCV 1.5 RK 0.000 0 3/25/2006 Open 4 7153 6555 Cameo MMG-2 MMH DMY 1.5 RK 0.000 0 3/26/1990 Closed Injection Other (I lues, eauip., etc.) - JEWELRY MandrelNalve 2 Depth TVD Tvpe Description ID (6945-6946, 1824 1819 SSSV Cameo TRDP-1A-SSA 2.813 Perf - - 6799 6253 PBR Baker 2.813 (6970-6972) - - 6814 6267 PKR Baker 'HB' RETR. 2.891 - - 6820 6272 NIP Otis 'X' 2.813 6853 6301 PACKOFF Tri State 'HP' Pack Off Assembly; Run on 3/9/90 3.000 Injection 6854 6302 TOP CUT Top of 3 1/2" Cut-Off Tbg Stub 2.992 MandrelNalve OFF STUB 3 6907 6348 PKR Baker 'FHL' 3.000 (7016-7017, 7172 6570 PKR Baker 'FB-1' 4.000 - - - - 7178 6575 SOS Baker 2.992 - - 7190 6585 PLUG Cameo CA-2 Plug 0.000 - - 7190 6585 NIP Cameo 'D' Nipple NO GO 2.750 - - 7202 6595 TTL 2.992 Fish - FISH Depth 1 Description 1 Comment 7189 12 5/8" WA Chem. Cutter 1 Left in tail pipe above CA-2 plug from workover General Notes Date [Note PKR 3/9/1990 I TUBING STRING @ 6854' on Down Left in Hole f/ Previous Completion (4/15/85) (7172-7173, , 00:6.15Q) Tri-State HP Pack Off AssemblY Run on 3/9/90 (õ) 6853' 50S I (7178-7179, 00:3.500) I I I 25/8"WA I Chem. Cutter (7189-7190, 00:2.625) Perf - - (7442-7454) - f-- - f-- Perf = = ~ (7466-7488) - - - - MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O Taylor Chairman DATE: June 16, 2002 THRU: Tom Maunder /~(.~)'l~J1 P.I. Supervisor FROM: Chuck Scheve Petroleum InsPector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests Phillips 1C Pad KRU Kuparuk Packer Depth Pretest Initial 15 Min. 30 Min. P.T.D.I 181-005 Notes: WellI 1C-10I Type testI P I Testpsil 1567 ICasingl ~050I 2050I 2000I 2000I P/F I --P Typelnj.I F i~.~ I Tubingl 1900 I 1900 I 1900 I 1900 Ilntervall 4 Type testI P I Testpsil 1587 ICasingI 900 I 20251 19751 ~9501 P/F I --P Notes: Well P.T.D. Notes: Well Notes: Notes: IType Inj. Type test IType Inj. Type test Type Inj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Phillips 1C Pad in the Kuparuk River Field and witnessed the routine 4-Year MIT on wells 1 C-05 and 1C- 10. The pretest tubing and casing pressures were observed and found to be stable. The standard annulus pressure test was then performed vCith both wells demonstrating good mechanical integrity. M.I.T.'s performed: _2 Number of Failures: _0 Attachments: Total Time during tests: 2 hour cc: MIT report form 5/12/00 L.G. MIT KRU 1C Pad 6-16-02 CS.xls 6/20/2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 94 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 service__x Kuparuk Unit .... , 4. Location of well at surface 8. Well number 1441' FNL, 4319' FEL, Sec. 12, T11N, R10E, UM (asp's 561965, 5968793) 1C-05 At top of productive interval 9. Permit number / approval number 926' FSL, 1251' FWL, Sec. 1, T11 N, R10E, UM 181-005/ At effective depth 10. APl number 50-029-20550 At total depth 11. Field / Pool 3964' FNL, 3921' FEL, Sec. 1, T11N, R10E, UM (asp's562338, 5971554) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 7753 feet Plugs (measured) true vertical 7049 feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 75' 16" 200 sx PF 75' 75' SURFACE 2688' 10-3/4" 29s5 sx AS U 2782' 2695' PRODUCTION 7629' 7" 48o sx C~ass G & 250 sx AS ~ 7723' 7024' Tubing (size, grade, and measured depth) i~ii~! i~i~i~i~i~i ~i i~! ~iii~i~ii~ii~ii.i~i~i~ i~::i~!ii~ ::!iii!iiiii!iiiii!:iiiii? iiiii~.~ {~ & :.:.:.:.: :.:.: :.:.:.:.:.:.:.:.:.:-:.:.:.:.'.:.::: :.'.:.: :.:.:: :.:: :.:: :.:.: :.: :.:: :.: :.: :: .... :..:: :.:: .... :..:..: ........ · · .:.. ;' ' · :':' ':' · ' ' :' · ':':: :-:':-:-; :':':':':';'? :':':':~- ~ ~ -- ~ 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X [ :: ~[i :ii;:: : :iG:~s:i:;.; :i::i~: ;SU:~P~i~i:i:?i?i-'ii~i:;i~i:i-::i::iS~i~ilX-::;WKGil~i~tl; ~ :;...,.;.;.~;- .;.;-~;.; ;. ;.;. ~; --;-; ;-'~; .... ;..;. ..... ;..:.:.....:. :....~ ....... ...: ..... ;;;-;: ...... ;; 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions?. Cail Jeff Spencer 659- 7226 Signed ~ ,.~,~___. Title Production Engineering Supervisor Date , Jeff A. S~ncer Prepared by Robert Christensen 659-7535 , Form 10-404 Rev 06/15/88 · ORIGINAL RBDlUlS BFL SUBMIT IN DUPLICATE lC-05 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary · '. '.'." STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Pull tubing ,, X Alter casing Stimulate __ Plugging Perforate Repair well X Pull tubing Other 2. Name of Operator ARCO Alaska,, lng. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1448' FNL, 6967' FWL, Sec. 12, T11N, R10E, UM At top of productive interval 926' FSL, 1251' FWL, Sec. 1, T11N, R10E, UM At effective depth 908' FSL, 1246' FWL, Sec. 1, T11N, R910, UM At total depth 1312' FSL, 1362' FWL, Sec. 1, T11N, R10E, UM 5. Type of Well: Development Exploratory Stratigraphic Service 12. Present well condition summary Total Depth: measured true vertical 7 7 5 3' feet Plugs (measured) 7 0 4 9' feet 6. Datum elevation (DF or KB) 94' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 1C-5 9. Permit number/approval number ~1-5/~0-117 10. APl number 50-02~-210550 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7 5 2 0' true vertical 6856' feet Junk (measured) feet Casing Length Size Structural 7 5' 1 6" Conductor Surface 2 6 8 8' Intermediate Production 7629' 7" Liner Perforation depth: measured 6970'-6972' true vertical 6401 '-6403' Cemented 200 Sx PERMAFROST 10-3/4" 2985 sx AS III 480 sx Class G & 1250 s× AS I Measured depth True vertical depth 75'm d 75'tvd 2782'md 2695'tvd 7723'md 7024'tvd , 7046'-7118', 7442'-7454', 7466'-7488' , 6466'-6526', 6792'-6802', 6811'-6830' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 TBG W/ TAIL @ 7202' Packers and SSSV (type and measured depth) Brown "HB" Pkr ~ 6814'~ Baker "FB-I" Pkr ~1 7172'~ Camco 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Reoresentative Daily Averaae Production or I~]emion Data 14. Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Water Injector ~ Daily Report of Well Operations X Oil ~ Gas Suspended ! 17. ! hereby certify that the foregoing is true and correct to the best of my knowledge. Service y Form 10-404 Rev 05/17/89 Title Area Drilling Engineer Date .~/2.~//,~'~..~ SUBMIT IN DUPLICATE ARCO Oil an~d Gas Company Well History- Initial Report - Dali! Illltltlclfoltl: Prepare and submit the "la#iai Raiment" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to elxlddlng. Ntould be summarized on the form giving inclusive dates only. District ARCO A~ASKA INC. KUPARUK RIVER UNIT County. parish or borough NORTH SLOPE Lease or Unit ADL: 25649 Title WORKOVER Field lC-5 IWell no. Auth. or W.O. no. AK4796 Operator ARCO W.O. 3/5/90 02:30 Date and depth as of 8:00 a.m. 03~05/90 ( TD: 0 PB: 7626 SUPV:DB 03/06/90 ( TD: 0 PB: 7626 SUPV:DB 03/07/90 ( TD: 0 PB: 7626 SUPV:DB 03/08/90 ( TD: 0 PB: 7626 SUPV:DB 03/09/90 ( TD: 0 PB: 7626 SUPV:DB IARCO w.i. 55.0000 Prior status if a W.O. Complete record for each day reported NORDIC 1 RU LINES, PREP TO KILL WELL MW: 0.0 MOVE R'IG FROM KRU STATE #2, ACCEPT RIG AT 0230 3/5/90, RU LINES, FILL PITS, PULL BPV, PREP TO KILL WELL DAILY:S31,863 CUM:$31,863 ETD:S31,863 EFC:$310,000 RU TO RIH W/CHEM. CUTTER MW:12.2 LSND CONT. RU LINES, CIRC. 50 BBL WATER DOWN TBG FOLLOWED BY 12.2 MUD, AFTER MUD AROUND TBG AND CSG PRESS ZERO, BLED ARCTIC PAK ANNULUS, SET BPV, ND TREE, NU BOPE AND TEST TO 3000 PSI, BOLDS, PULL 150K ON TBG HGR, HGR MOVED BUT SBR WOULD NOT RELEASE, LOAD PIPE SHED W/ 3-1/2" DP, RU E-LINE, PREP TO RIH W/ 2-5/8" CHEM CUTTER DAILY:S88,444 CUM:$120,307 ETD:S120,307 EFC:$310,000 MW:12.2 LSND RIH W/2-5/8" CHEM CUTTER, CUT TBG BETWEEN SBR AND GLM, POH, PULL OUT OF ROPE SOCKET AT SSSV, CONT. POH, RD E-LINE, PULL TBG HGR TO FLOOR, RU & CIRC GAS OUT POH W/ 3-1/2" TBG, COLLARS HANGING UP IN TBG SPOOL, REPOSITION RIG, CONT.POH, PU OVERSHOT BHA AND 3-1/2" DP, RIH DAILY:S38,647 CUM:$158,954 ETD:S158,954 EFC:$310,000 . .~i~i;'CBU, PREP TO RUN STORM PKR MW:12.2 LSND {::~iON~. T[H W/ OVERSHOT, ENGAGE TBG STUB @6842, JAR & PULL ON ~;, NO MOVEMENT, RELEASE OS, POH LD BHA, PU RBP, TIH ON :~i:,SET ~P AT 6soo, TES~ CSG TO 2500 PSI W/12.3 PPG ~OD - OK, CBU, PREP TO RUN STORM PKR DAILY:S28,843 CUM:$187,797 ETD:Si87,797 EFC:$310,000 RIH W/COMPLETION ASSMB. MW:12.3 LSND CONT. CBU, PULL 3 STDS DP, PU BAKER STORM PKR, ATTEMPT TO SET, UNABLE TO RUN BELOW CSG HGR, POH, PU RTTS W/STORM VALVE, RIH, SET RTTS AT 83', RELEASE FROM RTTS, POH, ND BOPE, ND TBG SPOOL, REPLACE 7" PACKOFFS, NU TBG SPOOL, NU BOPE, TEST BOPE TO 3000 PSI, RIH AND RELEASE RTTS, CIRC., POH, LD RTTS, RIH AND RELEASE RBP, POH LDDP AND BHA, MU COMPLETION ASSEMBLY AND RIH DAILY:S40,942 CUM:$228,739 ETD:S228,739 EFC:$310,000 The above is correct Joate / . AR3B-459-1-D JNumber all daily well history forms consecutively as they are prepared for each well. iPage no. ARCO Oil a,,d)Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District Field ARCO ALASKA INC. ICounty or Parish State NORTH SLOPE AK Lease or Unit ADL: 25649 lC-5 KUPARUK RIVER UNIT IWell no. Date and depth as of 8:00 a,m. 03/10/90 ( TD: 0 PB: 7626 SUPV:DB Complete record for each day while drilling or workover in progress NORDIC 1 POH W/LIB ON SLICKLINE MW: 8.0 DIESEL CONT. RIH W/ COMPLETION ASSEMBLY, LOCATE TRISTATE PACKOFF ASSEMBLY ON TBG STUB, PRESSURE TBG TO 2500 PSI TO SET PKR, PRESSURE ANNULUS TO 1100 PSI TO ENSURE PKR SET, PU AND SHEAR PBR, SPACE OUT, MU TBG HGR & CONTROL LINE, TEST CONTROL LINE TO 5000 PSI, RELAND TBG, RILDS, PRESSURE TEST SSSV, SET BPV, ND BOPE, NU TREE, TEST TREE TO 5000 PSI, TEST ANNULUS TO 2500 PSI, PUMP 125 WATER SPACER, DISPLACE WELL TO DIESEL, RU SLICKLINE, RIH W/ 2.5" LIB, WOULD NOT GO BELOW TBG STUB, ?OH DAILY:S51,212 CUM:$279,951 ETD:S279,951 EFC:$310,000 The above is correct For form preparation ~1 (~str~-~ution ~ see Procedures Manu~l ~Bection 10, Drilling, Pages 86 ank~-~7 AR3B-459-2-B INumber all daily well history forms consecutively as they are prepared for each well. IPage no. ARCO L,' nd Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is ~lot required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District I ~e ARCO ALASKA INC. County or Parish I NORTH SLOPE I Lease or Unit KUPARUK RIVER UNIT I Auth. orW.O, no. Title ADL: 25649 lC-5 I AK4796 ] WORKOVER IWell no. Field Operator A.R.Co. W.I. ARCO ]Date 55. 0000 Spudded or W.O. begun W.O. I 3/5/90 Date and depth as of 8:00 a.m. 03/11/90 ( TD: 0 PB: 7626 SUPV:DB Complete record for each day reposed NORDIC 1 ITotal number of wells (active or inactive) on this ]cost center prior to plugging and I labandonment of this well I IHour IPrior status if a W.O. o2~3o I RIG RELEASED MW: 8.0 DIESEL CONT. POH W/ LIB ON SLICK. LINE, RIM W/ 2.25" LIB, STOP AT 7090 (BELOW TBG STUB), POH, NO CLEAR IMPRESSION, RIH W/2.3" SWEDGE TO 7091', POH, RIH W/ 2" RS PULLING TOOL, STOPPED AT GLM AT 6755, POH, RECOVERED CV, RIH, STOPPED AT GLM BELOW PKR, POE, RECONFIGURE TOOL STRING, RIH, STOPPED AT 7090, POE, RIE W/ DRIVEDOWN BAILER, STOPPED AT 7092, POE, RECOVERED THICK MUD, RIM W/BAILER, STOPPED AT 7102, POE, RECOVERED THICK MUD, RIE W/ BAILER, STOPPED AT 7102, POH, RECOVERED THICK MUD, RIE W/SUCTION TYPE BAILER, STOPPED AT 7080, POH, RECOVERED THICK MUD, RIH W/DRIVEDOWN BAILER, STOPPED AT 7105, POH, RECOVERED THICK MUD, RIH W/ DV ON SETTING TOOL, SET DV IN GLM AT 6755, POH, RD SLICKLINE, PRESSURE TEST ANNULUS TO 2500 PSI - OK, RIG RELEASED DAILY:S48,481 CUM:$328,432 ETD:S328,432 EFC:$310,000 Old TD Released rig Classifications (oil, gas, etc.) Producing method Potential test data New TD Date IPB Depth Kind of rig JType completion (single, dual, etc.) Official reservoir name(s) Well no. Date Reservoir Producing Interval Oil or gasTest time Production Dil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For ,~ preparetio,~[nd-distribution. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. iPage no. DIviIiO(~ Q! Atllnth:RiehfleldComplny A .... _~_ OIL AND GAS CONSERVATION COM. ' '~ION APPLIL;ATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon 2. Name of Operator Suspend _ Operation Shutdown _ Re-enter suspended well_ Repair well X Plugging _ Time extension ..,. Stimulate _ Perforate , Other _ 6. Datum elevation (DF or KB) ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Alter casing _ Change approved program _ Pull tubing X Variance 5. Type of Well: Development '~. Exploratory _ ServiceStratigraphic ~ 4. Location of well at surface 1448' FNL, 6967' FWL, Sec. 12, T11N, R10E, UM At top of productive interval 926' FSL, 1251' FWL, Sec. 1, T11N, R10E, UM At effectiVe depth 94' RKB 7. Unit or Property name Kuparuk River Unit At total depth 1312' FSL, 1362' FWL, Sec. 1, T11N, R10E, UM 12. Present well condition summary Total Depth: measured 7 7 5 3 feet true vertical 7 0 4 9 feet feet 8. Well number 1C-5 9. Permit number 81-5 10. APl number 50-029-20550 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) None Effective depth: measured 7520 feet Junk (measured) None true vertical 6 8 5 6 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 75' 1 6" 200 Sx Permafrost 75' 75' Surface 2782' 1 0-3/4" 2985 Sx AS II 2782' 2695' Intermediate Production 7 72 3' 7" 480 Sx Class G & 7 7 2 3' 7 0 24' Liner 250 Sx AS I Perforation depth: measured 6970'-6972', 7046'-7118', 7442'-7454', 7466'-748DC("CI\/EF~ true vertical 6401'-6403', 6466'-6526'., 6792'-6802', 6811'-6830' Tubing (size, grade, and measured depth 3-1/2", 9.3#, J-55 EUE 8rd AB mod tbg w/ tail @ 7202' Packers and SSSV (type and measured depth) 0ii & ¢~aS C0rlSo Baker FHL pkr @ 6907', Baker FB-1 pkr @ 7.172', Camco TRDP SSSV @ 1913' Anch0r~<;e, 13. Attachments Description summary of proposal X Detailed operation program _ BOP sketch Proposed workover will repair minor tubing X 7" communication. 14. Estimated date for commencing operation 15. Status of well classification as: March 1~0 Oil ~ Gas Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Area Drilling Engineer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Mechanical Integrity Test ~ Approved by the order of the Commission Form 10-403 Rev 06/15/88 Location clearance Subsequent form require ~~0~L SIGNEO BY IE C. SMITH ItAppr°va~l[~'- Commissioner Date SUBMIT IN TRIPLICATE ~,UMMARY KUPARUK RIVER UNIT 1C-5 Workover Summary Kuparuk Well 1C-5 will be worked over to repair tubing X 7" communication. The leak is small and the well passed a MIT on 4/17/88. However, the well was on gas injection and the 7" annulus pressure did eventually build to pressures greater than 2000 psi. The well was shut-in awaiting a workover to repair the leak. Pressure testing with plugs at different depths indicated the leak is at the packer. The proposed workover will repair the packer leak by installing another packer above the faulty one. PROCEDURE · . . ,, . . . . ,, 10. 11. 12. 13. 14. MIRU Nordic #1. Displace tubing and annulus with 12.3 ppg mud to kill well. Set BPV, ND tree, NU BOPs. Pull BPV and test BOPs. Pull 3-1/2" tubing above upper packer. RIH with RTTS. Set RTTS at _+ 6700' and pressure test 7" ca~ A. If casing does not pressure test, locate leak with RTTS. Repair as required. B. If casing passes pressure test, continue with workover. Hang off drillpipe and RTTS with storm packer. Pressure test storm packer. ND BOPs. ND wellhead and changeout 7" casing packoffs. NU BOPs and POH with storm packer, drillpipe, and RTTS. Run new completion assembly including: - locater assembly to stab into old SBR above FHL packer - new Baker HB retrievable packer and PBR - one GLM with DV above HB packer Stab locater assembly into SBR above FHL packer· Pressure annulus to 500 psi to verify position. Pressure up tubing to set upper HB packer. Pressure test annulus to verify packer is set. ND BOPS. NU tree. Reverse circulate to replace mud in annulus and tubing with diesel. Replace CV with DV and perform State-winessed MIT for injectors. Set BPV. RD and release rig. 11 5000 PSI BOP STACK 6 5 4 3 lC-5 1. 10-3/4" CASING HEAD 11" -3000 PSI FLANGE 2. TUBING HEAD 11" - 3000 PSI X 7 1/6" - 5000 PSI 3. CROSSOVER SPOOL 7 1/6" - 5000 PSI X 11" - 5000 PSI 4. 11" - 5000 PSI BLIND RAMS 5. 11" - 5000 PSI PIPE RAMS 6. 11" - 5000 PSI ANNULAR ACCUMULATOR CAPACITy TEST 1 . CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST FILL BOP STACK AND MANIFOLD WITH BRINE. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 6. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 7. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 8. OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. 9. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 1 0. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF BRINE AND ALL VALVES ARE SET IN THE DRILLING POSITION. 1 1. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. 14. SIGN AND SEND TO DRILUNG SUPERVISOR. 15. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. NORDIC SRE 9/89 KUPARUK WELL lC-05 APl #: SPUD DATE: ORIGINAL RKB: 500~ ADL LEASE: 25649 PERMIT #: 02/08/81 COMPLETION DATE: 02/27/81 WORKOVER DATE: ~URFACE LOCATION: 1448'FNL961"FWL, SEC12,T11N,R10E TOP OF KUPARUK: 908'FSL,12M'FWL, SEC1 ,T11N,R10E TD LOCATION: 131ZFSL,136ZFWL, SEC1,T11N,R10E All ~ am MD-RKB to top of equilamm unleei othem~ noted 94 28 PAD ELEVATION: CASING arid TUBING DETAILS J SIZE WEIGHT GRADE DEPTH 1~" ~ H-40 76 10.76' 4&M K-M 27~2 T' 20 K.66 7723 3.S' 9.3~ J-M 7179 LINER DETAILS SIZE WEIGHT GRADE TOP BTM 7626 685O TUBING JEWELRY ITEM TYPE ID DEPTH SSSV CAMCO TRDP-1A 2.812' 1889 SSR BAKER SBR 2.813' 6857 PKR BAKER FI4 6884 PKR BAKER FB 7148 NOGO CAMCO 'D 2.75' 7166 SHROUT BAKER 7178 t~ ;~ ~11 ~ ~fth o.(- bo~o,,~ ?~cJc~r MISC. DATA DESCRIPTION DEPTH KICK OFF POINT: 1500 MAX HOLE ANGLE: 35 des 7300 HOLE ANGLE THRU KUP: 35 des LAST TAG DATE: 02/01/86 7541 RATHOLE: 53 ft )F~H/OBSTRUCTION: 7528 .; TUBING SPOOL: WELLTYPE: L STN DEPTH MANDREL 1 230~ CAMCO 2 324~ CAMCO 3 4376 CAMCO 6 _'4~ · CAMCO $ 6618 cAMCO MM(3.2 7 ~ C~ MMG~ 8 8992 CAMCO MNIG..2 6 7129 CAMCO MMG-2 ,id IIi 81q35 04/15/85 61 GAS UFT and FLOW INFORMATION VALVE SIZE 1' 1' 1' 1' 1' 1.5' 1.5' 1.5' PORT SIZE .0V .0V .OV .OV .0V .OV .OV .OV PERFORATION DATA INTERVAL ZONE FT SPF 6970-6972 C 2 4 7046-7118 C 72 12 7442-7454 A 12 4 7466-7488 A 22 4 PHASE COMMENTS DA 2' TBG GUN REVISION DATE: 06/26/85 RF~SON: ARCO Alaska, Inc. Date: February 23, 1989 Transmittal #: 7432 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. BOx 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 F- 1 5 Kupaurk Fluid Level Report 1 2- 0 3 - 8 7 3 N - 1 8 Kupaurk Fluid Level Report 1 2 - 1 8 - 8 7 3 F- 01 Kupaurk Fluid Level Report 8-29-87 3 F- 0 2 Kupaurk Fluid Level Report 8-29-87 3 F- 0 9 Kupaurk Fluid Level Report 8-29-87 3 F-06 Kupaurk Fluid Level Report 8-29-87 3 F- 1 0 Kupaurk Fluid Level Report 8-29-87 3 F-1 I Kupaurk Fluid Level Report 8-29-87 3 F- 1 5 Kupaurk Fluid Level Report 8-29-87 3 F-1 4 Kupaurk Fluid Level Report 8-29-87 3 N- 1 0 Kupaurk Fluid Level Report 5-18.87 3 N-06 Kupaurk Fluid Level Report 5-22-87 3 N-09 Kupaurk Fluid Level Report 5-21-87 31 - 0 1 Kupaurk Fluid Level Report 4-24-87 3 N- 1 1 Kupaurk Fluid Level Report 4-15-87 3 N- 1 4 Kupaurk Fluid Level Report 4-13-87 3 F- 0 8 Kupaurk Fluid Level Report 4-14-87 3 N-01 Kupaurk Fluid Level Report 4-20-87 3 N - 1 4 Kupaurk Fluid Level Report I 2- 0 4 - 8 7 3 F- 1 5 Kupaurk Fluid Level Report 2-02-89 3 F.- 1 5 Kuparuk Well Pressure Report 8-27-87 3 F- 1 3 Kuparuk Well Pressure Report 8-27-87 3 F- 1 5 Bottom-Hole Pressure Survey 8-25-87 1 B- 0 5 Kuapruk Well Pressure Report 2-20-89 1 E- 2 5 Kuparuk Fluid Level Report 2-19-89 3 B-1 1 Kupaurk Fluid Level Report 2-20-89 3 A- 0 3 Kupaurk Fluid Level Report 2-21-89 3 H - 01 Kupaurk Fluid Level Report 2-21-89 2Z-1 9 Kupaurk Fluid Level Report 2-20-89 31-1 2 Kupaurk Fluid Level Report 2-20-89 1 E-08 Kupaurk Fluid Level Report 2-19-89 3 M - 1 8 Kupaurk Fluid Level Report 2-15-89 Casing Casing Tubing Tubing TUbing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Sand 'C' Sand 'C' BHP Amerada Casing Casing Casing Casing Tubing mubin~ Casin~[ Casin~ '~'/c/~°ra£e C°r~r~issio,. 3 H- 01 Kupaurk Fluid ·Level Report 2-15-89 Casing 3 B - 1 3 Kupaurk Fluid Level Report 2-17-89 Casing 1 E-29 Kupaurk Fluid Level Report -~ 2-15-89 Casing 1C-05 Kupaurk Fluid Level Report 2-18-89 Casing/Tubing 3M-1~7 Kupaurk Fluid Level Report 2-16-89 Casing 2Z-20 Kupaurk Fluid Level Report 2-18-89 Tubing 30-10 Kupaurk Fluid Level Report 2-16-89 Casing 31-1 2 Kupaurk Fluid Level Report 2-20-89 Tubing 3 H - 1 0 BHP Report 2-13-89 BHP Receipt Acknowledged' - .......................... Date: ............ DISTRIBUTION: D&M State of Alaska SAPC Unocal Mobil Chevron -.. · · . .~2, CO,,;3' -_ AnC/7orage C°~7,77/s~¢Or~ ATTACHMENT I I Drill Site lA Well No. 1A-4 1A-5 1A-7 1A-9 1A-11 1A-12 1A-14 1A-15 1A-16A KUPARUK RIVER UNIT Production Logs FEBRUARY 19, 1986 Lo9 Date Drill 7/6/83 10/29/83 2/8/82 5/7/82 1/25/82 3/23/83 1/19/83 3/21/83 3/.8/82 4/1/82 6/5/82 5/11/82 6/8/82 lB Site Well No. Lo9 Date 1B-1 12/26/81 1B-2 6/25/81 1B-3 11/16-18/81 3/12/82 1B-6 11/18/81 9/10/82 1B-7 11/23/81 1B-8 12/28/81 8/4/82 1B-9 6/24/82 8/3/84 Dril 1 Si te lC Well No. 1C-1 1C-2 1C-3 lC-4 1C-6 1C-7 1C-8 ' .. Log Date 5/9/81. 5/8/81 7/13/81 11/8/81 3/9/81 2/26/81 ": 11/30/81 5/19/81 5/21/81 Drill Site Well No. Lo9 Date 1D 1D-1 · 1/80 5/23/83 tD-3 8/5/80 1D-4 7/30/80 8/13/80 1D-5 6/11/81 1D-6 6/9/81 1D-7 6/8/81 5110178 Attachment Page 2 ' Drill Site 1H Drill Site lq Well No. 1H-3 1H-4 1H-6 1H-7 1H-8 Well No. Log Date 8/16/82 8/13/82 6/21/82 7/20/82 7/22/82 Log Date Drill Site Well No. 1E 1E-lA 1E-2 1E-3 1E-4 1E-5 1E-6 1E-7 1E-8 1E-12 !E-15 1E-16 1E-17 1E-20 1E-24 1E-25 1E-26 1E-27 1E-28 1E-29 1E-30 Lo.q Date 8/19/81 8/17/81 1/17/84 10/18/81 11/7/81 8/4/80 9/2/81 11/5/81 10/27/81 10/21/81 11/12/82 10/28/81 8/28/81 11/1/81 11/28/84 8/26/82 8/29/82 9/1/82 5/7/83 2/17/83 1/17/83 1/13/83 10/31/82 10/27/82 6/13/83 10/18/82 7/18/83 10/16/82 Drill Site 1G Well No. 1G-1 1G-2 1G-3 1G-4 1G-5 1G-7 1G-8 Lo9 Date Drill Site Well No. 9/7/82 1F 1F-1 9/25/82 1F-2 9/28/82 1F-3 12/8/84 1F-4 10/13/82 1F-5 11/12/82 1F-6 3/12/83 1F-7 11/19/85 ~ ~~'0~ 1/22/83J~..,J. ~ ~ ,,. Log Date 2/19/83 2/3/83 1/31/83 5/29/83 10/25/82 10/28/82 11/19/82 5/7/83 Attachment Page 3' Drill Site Well No. Log Date 1Y 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 .3/4/84 ~6/18/83 1Y-4 7/2/83 1Y-5 6/29/83 1Y-6 6/27/83 1Y-8 6/22/83 1Y-9 6/20/83 ~l[?~ 5 / 10 / 83 ~. 11/21/83 ~7/28/'85~ 1Y-12 5/25/83 1Y-13 5/27/83 1Y-14 5/13/83 5/18/83 1Y'15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site Well No. 2C Log Date 2C-4 2/19/85 2/28/85 2C-7 10/15/84 Drill Site Well No. Log Date 2Z' ~ 7/10/83 2Z-2 ': 6/24/83 7/19/83 2Z-3 ' 8/5/83 2Z-4 7/12/83 2Z-6 7127183 2Z-7 7/28/83 2Z-8 8/3/83 VLF:pg'O052 ',..-" Alaska Oil & Ds Cons. Com~..!::' Anchorage Drill Site lA Wel 1 No. ~ 1A-4 "~1A-5 '~1A-7 ~1A-9 "1A-11 '~1A-12 "~IA- 14 '~ 1A-15 ',,1A-16A ATTACHMENT I I KUPARUK RIVER UNIT Production Logs Log Date 7/6/83 10/29/83 2/8/82~ ~ 5/7/82/'~ 1/25/82-~ '-- 3/23/83 / ~. · 1/19/83") -'- 3/21/83 ,"~ " 318182 4/1/82 6/5/82 5111182~ .~ Drill Site Well No. Log Date '"'18-1 12/26/81 ~18-2 6/25/81 '-18-3 11/16-18/81"-7 ~,~ ~ - 3/12/82/ ~-18-6 11/18/81~ 9/10/82/ "18-7 11/23/81 ;. '- 18-8 12/28/81'-,~ '~ 8/4/82/ '-18-9 6/24/82- 'x~ 8~3~84 ':~ 18 Drill Site 1C Wel 1 No. \ '~c-~ '"'1C-2 "1C-3 ',~1C-4 ~~1C-5 '~1C-6 '~1C-7 '~. 1C-8 Log-Date 5/9/81 5/8/81 7/13/81 11/8/81'> 3/9/81/ 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site Well No. Log Date 1D '"~1D-1 1/80 ~-> ~' 5/23/83/ '~1D-3 8/5/80 1D-4 ~7/30/80~ ~ 8/13/80/ ~, ~1D-5 6/11/81 ~1D-6 6/9/81 '~1D-7 6/8/81 %JlD-S (WS-8) 5/10/78 'RECEIVED FEB 2 1 1986 Alaska 011 & Gas Cons. Comndssk)n Anchorage ARCO Alaska, Inc. ~ Post Office Box{00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 9, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton. Attached is our notice of intention to convert Kuparuk well lC-5 to a gas injector. If you have any questions, please call me at 263-4212. field T. Mark Drumm Kuparuk Operations Coordinator TMD:ps. File Attachment (In Triplicate) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ ") STATE OF ALASKA ~} ALASKA OIL AND GAS CONSERVATION COrvi'M ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL []X 2. Name of Operator 7. Permit No. ARCO ALASKA, I NC. 81 -05 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-20550 967' OTHER [] 4. Location of Well SURFACE LOCAl' ION' '1'11N, R10E, 1448' FNL, FWL, Sec. 12, UM 5. Elevation in feet (indicate KB, DF, etc.) 94' (RKB) 6. Lease Designation and Serial No. ADL 25649 ALK 0467 9. Unit or Lease Name KUPARUK R! VER UN ! T 10. Well Number 1C-5 11. Field and Pool KUPARUK RIVER F I ELD KUPARUK RIVER OIL POOL 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans ~ Repairs Made [] Other [] [] Other ~ Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that Kuparuk well 1C-5 be converted from a production to a gas injection well. The well was worked over in April of 1985 to allow water to be produced from the "A" sand. Prior to being worked over, the well was a "C" sand producer. Gas injection will be into both the "A" and "C" sands. ANT ! C I PATED START DATE. NOVEMBER 1, 1985 0il & ~s Cons. Gom~ss~on knc~om~e 14.1 hereby certify that the foregoing is true and correct to the best of n~l~P~ Signed ~.~/ ~ (~,~'~, Title OPERATIONS COORDINATOR The space below for Commission use Date 10/9/85 Conditions of Approval, if any: Approved by 91tll~tllA~ Still[i) B'Y L614111£ C. SLttltt COMMISSIONER By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Oil and Gas Company Well History- Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations ere started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska I County. parish or borough I North Slope Borough Field I Lease or Unit Kuparuk River IITm' ADL 25649 Auth, or W.O. no. AFE Cap 604283 I Recompletion WWS #1 API 50-029-20550 IState Alaska IWell no. 1C-5 W/O Operator ARCO Alaska, Inc. Spudded or W.O. begun JDate IHour Recomplete 4/10/85 Date and depth as of 8:00 a.m. 41o9185 4/lO/85 '4/11/85 4/12/85 . .. 4/13/85 thru 4115185 4/16/85 4/17/85 Complete record for each day reported 7" @ 7723' 7528' PBTD, RU flow tank 9.8 ppg Brine Accept rig @ 2100 hfs, 4/10/85. 2100 hrs. Att to pull BPV. ARCO w.i. 56.24% Prior status if a W.O. 7" @ 7723' 7528' PBTD, Circ Wt. 12.5, PV 30, YP 22, PH 10, WL 9.5, Sol 18 Pull BPV. Displ well w/12.5 ppg mud. Set BPV. ND 7" @ 7723' 7528' PBTD, NU BOPE Wt. 13.0, PV 25, YP 24, PH 10, WL 8.4, Sol 20.5 RU WL. RIH w/2" gun, 4 SPF, perf f/6972'-6970'. tree, NU & tst BOPE. 7" @ 7723' 7528' PBTD, PU 3½" DP Wt. 13.2, PV 25, YP 26, PH 10, WL 8.5, Sol 2i NU BOPE & tst. POE w/3½" tbg. PU Otis ret~:~S:.tl, RIH w/DP. 7" @ 7723' 7528' PBTD, POH w/fsh Wt..13.3+, PV 21, YP 24, PH 10, WL 9.0, Sol 21 RIH, jar pkr free, POH w/pkr & tailpipe assy. RIH w/BP on DP, set @ 6950'. ND BOPE. ND tbg spool. NU new tbg spool. NU BOPE & tst. RIH to retrv BP, TOH & LD retrv BP. TIH w/bit to 7378', wsh fill to 7520', TOH. TIH w/fsh'g assy, tag Vann gun fsh @ 7520', latch & POH w/fsh. 7" @ 7723' 7618' PBTD, RIH w/FB-1 pkr Wt. 13.3+, PV 29, YP 12, PH 8.0, WL 9.2, Sol 20 POH w/fsh. RU WL, RIH w/permpkr & tailpipe assy. 7" @ 7723' 7618' PBTD, NU tree Wt~ 13.3, PV 29, YP 11, PH 8.0, WL 9.2, Sol 20 E D string. Set upper pkr, sheared PBR. Lnd tbg. Set BP¥.~ BOPE, NU tree. Top pkr @ 6907', "D" Nipple @ 7190', Tailpipe @ 72o2'. Pkr J U L 0 1985. Alaska 0il & Gas Co~..~,~m~ss~on Anchorage OG The above la correct For form preparation and distribution, see Procedures Manual. Section Drilling, Pages 86 and 87. Date { Title 5110185 Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Filial Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting State cost center code Alaska District County or Parish Alaska North Slope Borough Field Lease or Unit Kuparuk River ADL 25649 Auth. or W.O. no, ITte AFE Cap 604283 I RecomPletion J Well no. lC-5 W/O WWS #1 Operator ARCO Alaska, Inc. Spudded or W.O. begun Recomplete Date and depth Complete record for each day reported as of 8:00 a~m, 4/18/85 API 50-029-20550 A.R.Co. W.I. [Total number of wells (active or inactive) on this Icost center prior to plugging and 56.24% Jabandonment of this well Date JHour I Prior status if a W.O. 4/10/85 ! 2100 hrs. Tst SSSV. Set BPV. RR @ 7" @ 7723' 7618' PBTD, RR Crude/Diesel NU & tst tree. Displ well to crude. 1230 hfs, 4/17/85. Old TD Released rig 1230 hrs. Classifications (oil, gas, etc.) O,ll Producing method Flowing Potential test data New TD PB Depth 7618' PBTD Date K nd of rig 4/17/85 Rotary IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk $~3P, d S Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable ~ JE~fl~ctiv~la~e U J"'"' corrected . U L 0 .~ 1985 The above is correct Signature '~- J-~ ~ For form preparation and distribut#n, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. JOate 5/10/85 JT.le Alaska Oil & Gas Cons. ~ssion ARCO Alaska, Inc. Post Office B~.../00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: !0- 0 2- 85 Ti{ANSMI?TAL N0:5376 ~.O ;~LASKA, iNC KU?ARUK OPEkATiUNS ENGINLEkING i<ECO ~S CLEKK ATO-!Z15B P.O. k~OX 100360 'ANChOk/~.GE, AK 99510 :-c~.:~D;.;~.~_,~. HE.~Lbi.h Aks '.,'kin FOLLOWING ZT~MS. PLbAS~ ACKHO%~LED~E ~C~I~,·, ...... = ~I'~D ku~Ul~ ONE SIC!4~D COPY OF T]iiS TRANSI'~ITTAL. X=I~ 'A~S~Z',D PH'E~UHE BUILD-UP 0~-24-85 . ;D~,',,[~.' ~.~.'-T ~[, .' '-'~i '.' k'~' m '-:,, L'T D~' '~ .' '-- .?~'1' ~V , .-~ .3-~ ~c.-28-o~ - . .. $ ,N~ O.IS ~-zU . 09-0~-85 STATIC 'A' SF2~D OTIS 2-9 09-07-85 S?ATiC 'A' S~'~D '~ 09-04-85 .... 'C' E!~D CAMCO F-D 08--!7-~5 PBU '~' SAND BAK~R/LYNES ' ~-5 08-~7-35 :'-5 08-17-85 PB'j :A&C~'' SAND BAKER/LYNES DiSTIKiSGTIOi~: AE* DF, iLLiNG 'W. PASAER CU:~KiL!< L. JOilLSTON EXXON EVRON~ [,~OBi L* PHiLLIP£ OIL* ~ F~.* KSK CLEkK J. RATHMELL* :' ~r .... ...., .t,. & a .i,. ~ SOhlC* UNION~- K'. TUL-N/VAULT ARCC' Alaska. Inc. is a Subsidiary of At;anticRichfieidComDenv RETURN TO: ARCO Alaska. Inc. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 ARC° ALASKa, INC. DATE: 09-18-85 TRANSMITTAL NO: 5358 KUPARUK OPERATIUNS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEKE~ITB ARE ThE FOLLOWING ITEm, S. PLEASE ACKNOWLEDGE R~CEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. PRESSURE DATA ~_~QU~NCE OF EVENTS lA-3 C1 SAND PBU 08-11-85 DRESSER ATLAS -~B-2 PBU C-1 SAND 08-05-85 DRESSER A?LAS '~'1C-5 PBU 07-29-~5 DRESSER ATLAS -'--2H-1 A SAND POST FRAC PBU 08-24-85 DRESSER ATLAS SEQUENCE OF EVENTS FROM W~LL SEi~VIC~ R~PORTS ~IG-11 SlShP & HISC. 09-09-85 1G-.ll SIBHP & MISC. 09-10-85 CAMCO CAMCO KU~-.~RUK WELL PRESSURE k~PORT ~'.NVELOPE DATA ~'~ 1B-~ PBU C-1 SAND 08-05-85 1C-~ PBU 07-29/30-85 DRESSER ATLAS DRESSER ATLAS RECEIPT ACKNOWLEDGED: BPAE* B. CUR/{I~R CHEVRON* D & ~]* DRILLING L. JOHNSTON MOBIL* NSK CLEP, K DISTKISUTION: W. PASRER EXXON PHILLIPS OIL* J. RAT~MELL* Alask~. DATE STATE OF ALASKA* SOHIO* UNIUN* K. TULIN/VAULT ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieidComl~any ARCO Alaska, In~' ~ Post Offic,~ _~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-2 1-85 TKANSMITTAL NO: 5296 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK · ATO-1115B P.O. BOX 100360 ANCHOkAGE, AK 99510 TRANSblITTED HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. SEQUENCE OF EVENTS FROM WELL SERVICE REPORTS PRESSURE DATA '~1C-4 ~" 07-23-85 '-~ 1C-5" 07-29-85 '~1C-5,'" 07-30-85 '~IC- 6 ~ 07-25-85 '"~iC- 6 '~ 07-24-85 ~lD-8 07-30-85 ~ 1H-3' '. 07-30-85 ---'lR-5' 07-05-85 ~--11~- 6" 07-06-85 ~'lR-8 07-U~-85 1Y-10' 07-27-85 1Y-11-~ 07-28-85 2A-2 ." 07-04-85 2S-13' 07-30-85 2U-14' 06-30-85 2U-14~'' 07-01-85 2U-15' 07-08-85 2V-2 07-27-85 2V-2.. 07-28-85 2W-7'- 07-26-85 ~'2W-7' 07-27-85 2X-15' 07-09-85 2X-15" 07-04-85 2Z-l' 07-05-85 ~'2Z-6' 04-08-85 ~'3B-7 -' 06-27-85 3B-8~' 06-28-85 3B-8~ 06-27-85 '~ 3B-9 J 07-18-85 3B-11 07-20-85 3B-12' 07-21-85 3C-11-~ 07-29-85 STATIC BHP PBU PBU STATIC BHP STATIC BHP STATIC BHP STATIC BHP ~RP & MISC. BHP & MISC. STATIC BHP & miSC. STATIC BHP END OF PBU 'C' SAND STATIC BHP PRESSUkE DATA 'A' SAND PBU 'A' SAND PBU PRESSURE TEST & HI,C. 'A' SAND PBU 'A' SAND PBU 'A' SAND ONLY PBU 'A' SAND PBU FLOWING BHP & FLUID I.D. FLOWING BHP & TEMPERATURE BHP SURVEY & MISC. STATIC BHP STATIC BHP & MISC. STATIC BHP & MISC. BHP & MISC. STATIC BHP & MISC. BHP SURVEY & MISC. STATIC BliP & MISC. STATIC BHP ~ MISC. RECEIPT ACKNOWLLDGED: BPAL'* B. CURRIER CHEVRON* D & ~1' DISTRIBUTION: DRILLING W. PAStiER L. JOHNSTON EXXON MOBIL* PHILLIPS OIL* NbK CLEkK J. RATRMELL* ' ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany CAMCO DRESSER ATLAS DRESSER ATLAS CAMCO CAMCO CAMCO 'CAMCO CAMCO CAMCO CAMCO CAMCO DRESSER ATLAS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS CAMCO CAMCO OTIS CAMCO CAMCO CAMCO CAMCO c co ..... ' ~'"~,. UOr;/rrlJssJorl STAT~ OF 'AL'ASKA* SOHIO* UNION* K · TULIN/VAULT RETURN TO: ~RAESMITTED IG-15 [Y-11 ARCO Alaska, Inc. ~% Post Office E.]0360 · Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ~%.::. ARCO ALASKA, INC. - KUPAKUK OPERATIONS RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 HEREWITH ARE THE RETUF, N ONE SIGNED ~LECE IPT AND PRESSURE FINALS DRESSER ATLAS ,. lC-5 PBU ' 07-29-85 lC-9 TUBING PRESSURE 07-24-85 FLOWING PRESSURE GRADIENT 07-30-85 FLOWING PRESSURE & PBU 07-28-85 P~U 08-3 / 4-8 PBU 0~-01-85 FLOW ING BOTTOHHOLE PRESSURE 08-04-85 ., '. DATE: 08-16-~5 ~ TRANSMITTAL NO: 5267 ENGINEERING FOLLOWING ITF~S . COPY OF THIS PLEASE ACKNOWLEDGE TRANSMITTAL. J~CEIPT ACKNO;4LEDGED: PAE* · CURRIER HEVRON* & M* DISTKIBUTION: DRILLING W. PASHER L. JOHNSTON EXXON MOBIL* PHILLIPS OIL* NSK CLERK J. RATHMELL* 1985 0il & ~as Cons. Oommissior~ Anchorage STATE OF ALASKA* -'SOHIO* UNION* K .TULIN/VAULT ARCO Alaska, Inc. is · Subsidiary of AtlanticRIchfieldCompany ARCO 'Alaska, Inc.~ Post Office Bo,, i00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 JUly 2, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for the following wells- 1C-5 2V-5 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU10/L43 Encl osu res RECEIVED JUL 0 1 B5 A~aska O~l & Gas Cons, Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ' STATE Of ALASKA ' 'ALASKAL ~) AND GAS CONSERVATION C° ')/llSSlON · . WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-5 3. Address. 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20550 4. Location of well at surface 9. Unit or Lease Name 1448' FNL, 967' FWL, Sec.12, T11N, R10E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 926' FSL, 1251' FWL, Sec.l, T11N, R10E, UM 1C-5 At Total Depth 11. Field and Pool 1312' FSL, 1362' FWL, Sec.l, T11N, R10E, UM Kuparuk River Field I 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk Ri ver 0i l Pool 94' RKB ADL. 25649 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 02/08/81 02/22/81 02/27/81I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 7753'MD,7049'TVD 7520'MD,6856'TVD YES i-~X NO [] 1913 feet MD 1650' (approx) · , 22. Type Electric or Other Logs Run D IL/GR/BHCS, CBL/VDL/NGT, FDC/CNL/NGT/Cal, CBL/VDL/GR/CCL, GR/CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65.0# H-40 Surf 75' 24" 200 sx Permafrost 10-3/~" 45.5# K-55 Surf 2782' 13-3/4" 2985 sx AS I I 7" 26.0# K-55 Surf 7723' 8-3/4" 480 sx Class G & 250 s~ AS I 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) 7046' - 7118' w/12 spf 3-1/2" 7202' '7172' & 6907' · 6970'- 6972' w/4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD.) AMOUNT& KIND OF MATERIAL USED , N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 12/16/81 F1 owing Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 2/27/81 17.5 TEST PERIOD I~ 1580 550 -- 40/64 348 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 360 -- 24-HOUR RATE II~ 2320 807 -- 22.4 28. / CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED J U L 0 ,~ ]985 Alaska 0il & Gas Cons. C0,~mJssJ0n Anchorage ,,, Form 10407 JNN2/WC53 Submit in duplicate Rev. 7-140 CONTINUED ON REVERSE SIDE NAME , Include interval tested, pressure data, a~[ fluids recover'ed ar,~ gravity, MEAS. DEPTH TRUE VERT; DEPTH. ,,'GOR and,time of each phase.~' · '. Top Kuparuk 70~6~ ·, 6~66' N/A ~se Kuparuk 7560 . - : . . ; · ~ : ~ . ' :. '. . . ,. . · , ,. ',. ,.: . . . ,. '"'~" '~ ' "" '. . , : ,; ;' ' ' ,7 ' ' ,' , '~ - "' . ...t .. 31. LIST OF ATTACHMENTS , . ~ .., ' ' :. -" . 32. I hereby certify that the.foregoing is t~ue and correct t0 the best of my knowledge . ,. ,. .- Signed ~~ ~ .Title ~.,~o~, _..,., .... INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevatiOn is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval tO be separately produced!, showing the data pertinent to such interval.' ' Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. ) Post Office Box'~'00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 25, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: lC-5 Dear Mr. Chatterton: Enclosed is a Subsequent Sundry Report for the subject well. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRUIO/L02 Enclosure RECEIVED j u N 2 ~.~ 1985 A1ask~ Oil & Gas Cons. Commission Anchorage, ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~..i~ AND GAS CONSERVATION CC '~VIISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL'(] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-5 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20550 OTHER [] 4. Location of Well Surface: 1448' FNL, 967' FWL, Sec.12, TllN, RIOE, UM 6. Lease Designation and Serial No. ADL 25649 ALK 467 5. Elevation in feet (indicate KB, DF, etc.) RKB 94' 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1C-5 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly sta~e all pertinent details §nd give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig ~ 2100 hrs, 4/10/85. Killed well. Perf'd f/6970' - 6972'; bullheaded 6 bbls mud into perfs. Observed well - static. ND tree. NU BOPE & tstd to 3000 psi - ok. Pul led 3-1/2" tubing. Recovered pkr & tailpipe. Tstd 7" csg to 1000 psi - ok. Set FB-1 pkr ~ 7148'WLM. Ran 3-1/2" completion assy w/tail ~ 7202' FB-1 pkr ~ 7172', FHL pkr @ 6907', & SSSV ~ 1913'. Set BPV. ND BOPE. NU tree & tstd - ok. Disp well w/diesel & crude. Secured well & released rig ~ 1230 hrs, 04/17/85. RECEIVED JUN 2 ~ 1985 Alaska 0it & Gas C0rts. C..mm~sst0n'~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space ~low for Commission use Title Assnela~ ~nnln~r Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 GRUg/SN09 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska. Inc( Post Office~.,,x 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 June 24, 1985 ~4r. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr, Chatterton: Attached in duplicate are subsequent notices following wells at the Kuparuk River Field: We l I Action Date Performed 1A-3 Fracture 5/30/85 1A-4 Fracture 6/1/85 1C-5 Perforate 4 / 27/.85 1E-3 Perforate 3 / 28 / 85 1E-3 Fracture 4/3/85 1E-4 Perforate 4/20/85 1E-4 Fracture 5/7/85 1E-1 6 Fracture 4/1 4/85 1E-1 7 Fracture 3 / 26 / 85 1E-29 Fracture 4/1 2 / 85 1F-1 6 Perforate 4/11/85 1F-1 6 Fracture 4/1 5/85 1G-1 Fracture 4/1/85 1L-1 5 Fracture 3/31/85 1L-1 6 Fracture 3/31/85 1Q-1 Fracture 5/31/85 1Q-4 Acidize 5/17/85 1Q-4 Fracture 5/31/85 1Q-5 Fracture 5/1/85 1Q-6 Fracture 4/1 9 / 85 1Q-7 Fracture 4/27/85 1Q-7 Ac id i ze 5/26/85 2C-1 0 Perforate 4/21 / 85 2D'3 Ac idi ze 5/11/85 2W-1 3 Acidi ze 5/20/85 2X-1 2 Acidi ze 5/1 2/85 on the If you have any questions, please call T, M. Drun'~n Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) me at 263-4212. RECEIVED Alaska Oil & Eas Cons. C0rnmL~.;0n Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichh~. :C. ompany (' STATE OF ALASKA O('M ALASKA OIL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 81-05 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50-029-20550 4. Location of Well SURFACE LOCATION: 1448' FNL, 967' FWL, Sec. TllN, R10E, UM 6. Lease Designation and Serial No. ADL 25649 ALK 0467 5. Elevation in feet (indicate KB, DF, etc.) 94' (RKB) 12. 12, 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1C-5 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations i~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On April 27, 1985, the "A" sands of Kuparuk well 1C-5 were perforated for production. After testing the lubricator to 3000 psi, the well was shot with a wireline conveyed gun. Interval (MD): 7442-7454 (4 SPF) 7466-7488 RECEIVED JUN 2 6 ]985 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. KUPARUK Signed ,,~. ,,'/'/~:;,,~--, ~)~ Title OPERATIONS COORDINATOR The space below for Commission use Conditions of Approval, if any: 6/19/85 By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc./~'[ Post Office Bbx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Aoril 22, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton- Attached is our notice of intention to perforate Kuparuk field well 1C-5. If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ( STATE O~: ALASKA C~0MM ALASKA OIL AND GAS cONSERVATION ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER i-3 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 1448' FNL, 967' FWL, Sec. 12, UM 4. Location of Well SURFACE LOCAT ! ON: TllN, R10E, 5. Elevation in feet (indicate KB, DF, etc.) 94' (RKB) 12. 7. Permit No. 81 -05 8. APl Number 50- 029-20550 9. Unit or Lease Name KUPARUK RIVER UN I T 10. Well Number 1C-5 6. Lease Designation and Serial No. ADL 25649 ALK 0467 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 11. Field and Pool KUPARUK RIVER F I ELD KUPARUK RIVER OIL POOL NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "A" sand in Kuparuk well 1C-5 be perforated for water production. Procedures call for the well to be perforated with a wi rel ina conveyed gun under a lubricator. Proposed Intervals (MD): 7442-7454' (4 SPF) 7455-7494' 7506-7510' ANTICIPATED START DATE: APRIL 23, 1985 Work R~e~ ~- RECEIVED APR 2 2 1985 Alaska 0il & Gas Cons. Commission Anchorage certify that the foregoing is true and correct to the best of my knowledge. Signed . , ? Title OPERAT IONS COORD ! NATOR The space below for Commission use Date 4/22/85 Conditions of Approval, if any: Approved by Form 10-403 Rev. 7-1-80 COMMISSIONER Approved Copy ~urned BY Order of /L- ~--~---~-- the Corem ission Date ......... Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, ( Post Office Box 100360 Anchorage, Alaska, 99510-0360 Telephone 907 276 1215 March 27, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1C-5 Dear Mr. Chatterton: .Enclosed is the Sundry Notice for the subject well. We propose to convert well 1C-5 to a selective single gas injector. Your earliest consideration of our request in this matter is very much appreciated, as work on the above well is scheduled to begin April 3, 1985. If you have any questions, please call K. L. Bonzo at 263-4967. Sincerely, A~~~?~~ea ~ling Engineer JBK/KLB/tw SN/L021 Enclosure RECEIVED 2 8 mtn5 0[t & Gas Guns. Commission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany (A 'O ~u STATE OF ALASKA ALASK IL AND GAS CONSERVATION MMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE LLx~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchoraqe~ AK 99510 4. Location of Well Surface: 1~+~8' FNL, 967' FWL, Sec.12, T11N, R10E, UN 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 7. Permit No. 81-05 8. APl Number 50- N29-90550 9. Unit or Lease Name Kup=_ruk ~!:,er Unit 10. Well Number ! C,5 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool RKB 12. ADL 256~.9 AL.v. ':67 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [~ Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing ~* Other ~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to convert well 1C-5 to a selective single gas injector. The procedure will be as fol 1 ows: 1. Well will be killed with 12.5 ppg mud. 2. Current completion assembly will be pulled. 3. The well will be recompleted as a selective single gas injector and 5000# wellhead equipment will be installed. 4. After the rig is released, an acid and/or frac job will be done. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally~'ested each trip. A non-freezing fluid will be left in all uncemented annuli within the · permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: April 3, 1985 R£CE VED ,AR 2 8 1985 Alaska 0il & Gas Cons. C0mrnissJ0n Anchorage 14. I hereb¥/e~rtif)t that the foregoing is true and correct to the best of my knowledge. Signed/ / Title Area Drillinq Engineer The space' wGo~n~F~'~n%s;' ' ' Conditions of Approval, if any: Approved by Approved Co~¥ Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 (KLB) SN/0~I Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc, ':. -; ';c:,: _~.'- 277 5~S7 Date: 8/16/84 Transmittal No: 4686 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 /~nsmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. PBU SURVEYS/Pressure Analysis lC-1 Static BHP 1C-5 " " 1C-6 Gas Disp. lC-7 PBU 1C-9 C"r~'alloff Test 1C_lO.~n~ ,, ,, 1D-1 Static BHP 1D-5 Falloff Test 1E-12 Flow BHP/GLV 1E-17 Static BHP 1E-18 " " 1E-24 Injectivity 4/12/84 Camco 4/13/84 " 5/16/84 Otis 4/20~21 Camco 4/29/84 " 5/06/84 " 4/19/84 " 4/29/84 Otis 7/01/8484 Camco 1/8-11/84 Otis 1/o3/84 " 6/21-22/84 " 2F-8 T Log PBU 2F-11 Initial PBU 2F-12 Initial Well 2F-13 " " 2F-14 PBU 2F-15 PBU State /cat Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE 5/06/84 Otis 5/22/84 Camco 5/15/84 '" 5/14/84 Otis 5/03/84 " 4/26/84 Camco D&M DISTRIBUTION W.V. Pasher Drilling Geology Mobil G. Phillips Phillips Oil J.J. Rathmell State of Alaska · Sohio Union Chevron NSK Operations R&D Well Files KUPARUK ~ i NEER ! KG TRA~$',I ITrAL #~ D. W. Bose/Shelby J. Matthews Transmitted herewith are the fol lc~]incj- PLEASE I',.O1"E: BL- BLUELINE, S- SEPIA, F- F! ~A, T- TAPE, ~-~]~~.. IZ_ASE pZII'~,I',I REC_.E i Fq' TO:. A~ ALASI~, ! NC_.. ' '>: ' ATrN: SI-lEi_BY J. M~I]I-t~,S - ATO/1115-B P. O. BOX 100360 AI',IOtOR,~E, AK. 99510 AClantic Ritchfield Company Arco Alaska, Inc. TRAN S~[[TTAL To: Wm.. Van Al'en/Sate of AK . . · Date: 31 AUgust, 1983 From: EXTENSION/EXPLORATION' -. Transmitted herewith are the following: Mud logs from the following wells' lA-5'~'. ' 8-11-81 1A-8-~West Sak 12) 7-22-78 lB-5 ~(West Sak 7) 1C-4 '~ 1C-6' 1D-4J 1D-B~West Sak~ 8) 1F_SJ- 1G-4~ 1H_3I~ 1H-6j 1Y-14j 2C-6 j 2C-7~~ 2X-2 f 2Z-4-,~' "11-27-77 ~ 1-1-81 ~ 2-9-81 .3-1r81 12-31-79 4-7-78 8-20-82 10-12-82 7-24-82 . 5-19-82 2-4'83 7-8-83 6-29-83 7-2-83 6-10-83 · Also'iincluded is an expanded· core-log from well 2X-2,-'7-2-83. A blueli'ne copy and.a Sepia is provided for each well.. · .~.. eipt Acknowledge: . . / [~turn receipt, to: Arco Alaska, Inc. Attn: Xg~X~aY~ E. MCAlister 1~.0. BOX 100360 Anchorage, AK 99510 . · Da te: Prepared by: B.BY~ne ARCO Alaska, InC. B~I Post Office 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 7, 1983 Mr. Harry W. Kugler State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1C-5 Mud Logs Dear Mr. Kugler' Enclosed are copies of the ~mud logs as you requested in your letter dated March 31, 1983. If you have any questions, please call me at 263-4944. ~ Sincrely, Gruber Associate Engineer JGL53' 1 lm Enclosures ARCO Alaska, inc. is a subsidiary of AtlanticRichfieldCompany ~arch 29, !9~3 Mr. P. A. VanDusen ARCO Alaska, Inc. P. O. Box 36O Anchor~ye, Alaska 99510 Dear Mr. VanDusen: s Kuparuk 25649 #50-029-20550 ~ condition of approval of the permit to drill the subject well was sub~ttal of a m~d log. This was indicated on the Form 10-40! and also in our cover letter indicating approval. In our cover letter the re~irement of a mud log was further e~phasized by referen.ce to your letter, of January 21, 19~1, a'nd specifying that of those tte~ under safety as~.~s, under B the it~ ~s to ~ ~d logs'=. Review of material in the two year old file. on this well fails to show receipt of the required mud log. We r~quest that you please submit 'the mud 1o9 at your earliest ~onvenience. Natty W. Kug C~/Ssioner Eric losure: l~Z:vdl PLEASE' NOI'E: BL- BIAJEr. ~7NE, S - SEPIA, F- FYrNI, T- TAPE, PC - PH(JiE/X)PY ANCHORAGE, AK. 995!0~ ~ Alaska KUPAP. UK F2qGINE'~.RING William VanAlen FR~: D. W. Bose/Lorie L. Johnson Transmitted her~¢ith are the following: PT.FASE NOTE: BL- BIfJEL~, S- SEPIA, F- FIIbI, T- TAPE, % Alaska Oil & Gas Cons. Anchorage .. ylPT. ACKN(X~ AJxT~ : PI~ASE RETURN RECEIPT TO: ARCO ALASKA, INC. ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORA~GE, AK. 99510 " AC' STATE OF ALASKA ~',~ - ALASK L AND GAS CONSERVATION C .... , ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL FXI GAS [] SUSPENDED [] ABANDONED [-]. SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-05 3. Address 8. APl Number P.0.Box 360, Anchorage, AK 99510 50- 029-20550 4. Location of well at surface 1/+qS'FNL, 967'FWL, Sec 12, T11N, RIOE, UM 9. Unit or Lease Name Kuparuk 256~9 At Top Producing lnterval 926'FSL, 1251'FWL, Sec 1, T11N, R10E, DM 10. WellNumber lC-5 At Total Depth 1312'FSL, 1362'FWL, Sec 1, T11N, RIOE, UM 11, Field and Pool Kuparuk River FieId ' 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 9/+' RKB ADL 256/+9 Kuparuk River OiI PooI 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. [ 15. Water Depth, if offshore 116. No. of Completions 2/8/81 2/22/81 2/27/81I -- feet MSLI 1 17. Total Depth (MD+TVD)7753, 70/+9' 18.Plug Back Depth (MD+TVD)7626, 69/+/+ ' YES19' Directional Surveyc~ NO [] I20' Depth where SSsV set1873 feet MD I21' Thickness Of PermafrOst1650 (approx.) 22. Type Electric or Other Logs Run DIL/GR/BHCS, CBL/VDL/NGT, FDC/CNL/NGT/CAL, CBL/VDL/GR/CCL, GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 1~" ~5# H-40 Surf. 75" 2/+" 200 sx Permafrost . 10 3//+" 45.5# K-55 Surf 2782' 13 3/4 2985 sx AS II 7" 26# K-55 Surf ' 7723' ,. 8 3//+" /+80 sx Class G 24. Perforations bpen ~o PrelUbct~on (MD+TVD of Top and Bottom and 25. TUBING RECORD . interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7046'-7118' w/12 SPF 3 1/2" 7033' 6958' , 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD)~ AMOUNT& KIND OF MATERIAL USED . N/A 27. pRODucTIoN TEST Date First Production . , Method o,f Operation (Flowing, gas lift, etD.) Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAs-McF WATER-DEL CHOKE SIZE IGAS-OILRATIO ?/27/8117.5 TEST?ER!OD~ ,.. 580 550_.I · FIo~V Tul~ing casing Pressure CAECULAfi:ED O!,L-BBL GAS-MCF WATER-DEL OIL GRAVITy-APl .(corr) Press.:~O.. _- 24-HOUR 'RATE ~ ~ :' ' ..... 23.20 807_ .; .... . 22,/+ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A :' ' :" -- · -' ~ MAR' 1 5 1982 " " ' ' ' " "~'~' ' N~OilS,~asC°ns' .... ~ ..... ,,' , A,~chorag~- Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE EoLoGIC MARKERS FORMATION TESTS ' NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. · ! , Top Kuparuk River Form. 70~6 ' 6/I.66 ' Base Kuparuk River Form. 7560' 6889' · . · . 31. LIST OF ATTACHMENTS ,, 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '.~IX (~.~~ Title Area 0pSo Fn.qr. Date i~R 10'lg~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which'elevation is used as reference '(where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and. 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24:Show the producing intervals for only the interval reported in item 27,?~ubmit 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 cement- ing and the location of the cementing tool. Item 27: .Method of .Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc/f Post OfficL~, 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 30, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservati on Commi ssi on 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 14-9A DS 16-3 DS 1 6-4 DS 16-8 DS 16-9 DS 16-12 C-4 C-5 C-6 15-22 Confidential Dear Sir: Enclosed please find: · The Completion Reports & Gyroscopic Surveys for DS 15-22 (T-l), DS 16-3, DS 16-8, DS 16-9, DS 16-12, C-4, C-5, C-6. Please note that DS 15-22 (T-l) is CONFIDENTIAL. 2. The Completion Report and Multishot Survey for DS 14-9A. , The Completion Report for DS 16-4. An updated Completion Report and Gyroscopic Survey will be submitted as soon as data becomes available. Sincerely, P. A. VanDusen District Drill.ing Engineer PAV/KJG:sp Attachments E£EIVED MAY - 1 1981 Oil & Gas Cons, Commission Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanlicRichfieldCompany · - ~ STATE OF ALASKA ~t ALASKA -~'LAND GAS CONSERVATION C . MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL)~ GAS I--], SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-05 , 3. Address -- 8. APl Number P.O. Box 360 Anchorage, 'AK 99510 5o- 029-20550 4. Location of well at surface 9. Unit or Lease Name 1448'FNL, 967'FWL, Sec 12, T11N, R10E, UN Kuparuk 25649 At Top Producing Interval 10. Well Number 926'FSL, 1251'FWL, Sec 1, T11N R10E, UR C-5 At Total Depth 11. Field and Pool 1312'FSL, 1362'FWL, Sec 1, T11N, R10E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 94' RKB ADL 26549 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp or Aband. 15. Water Depth, if offshore 116. No. of Completions 2/8/81 2/22/81 2/27/81 ':" -- feet MSLt 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19] Directional Survey 20. De~th where SSSV set I 21. Thickness of Permafrost 7753'MD 7049'TVD 7626'MD 6944'TVD YES[~X NOD 1873 feetMDI 1650 (approx) 22. Type Electric or Other Logs Run DIL/GR/BHCS. CBL/VDL/NGT. FDC/CNL/NGT/Cal, CBL/VDL/GR/CCL, GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED . 16" 65# H-40 .qurf 7~' 24" 200 sx Permafrost lrl_'q/zl,, zl~;_~ K-gE gurf 27B2' ]3-3/4" 2985 SX AS II 7. ?~ !<-_:;~ .qurf 7723' 8-3/4" 480 sx Class G , , 24. Per. forations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7046'-7118' w/12 spf .~-1/?" 7033' 6947' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED ; · · , N/^ · . .. · ., 27. PRODUCTION TEST D~te First' Production .... Method of Operation (Flowing, gas lift, etc.) N/A . Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO .. '. TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVI-~'~P~ (,¢_orr) Press. : 24-HOUR RATE~1~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. MAy ' ' Alaska Oil & N / A A~Chorag-~ , ,., Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. · GEOLOGIc MARKERS FORMATION TESTS' NAME .... Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH 'GOR,'and time of each phase. .... T. Kuparuk 7043' 6463' N/A T. Up. Sand 7043' 6463' B. Up. Sand 7233' 6620' T. Low. Sand 7433' 6784' D. Low. Sand 7563' 6891' B. Kuparuk 7563' 6891' . ~ , .. ll~n§ History, CyroS¢opi¢ ~Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge -. INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. · Item '1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. . Item 16 and 24: If this well is completed for separate production from more than one interval (multiple ::Completion), so'state in item 16, and in item 24 show the producing intervals for only the interval reported · in item 27. Submit a separate fOrm for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of OPeration: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Fnrm 10-407 .... ' .............. C-5 DRILLING HISTORY Spudded well @ 1930 hrs, 2/8/81. NU diverter system &' 20" Hydrill. Drld 13-3/4" hole to 2797'. Ran multishot. Ran 67 its 10-3/4" 45.5# K-55 Butt csg w/shoe @ 2782'. Cmtd csg..w/2985 sx 15.2 ppg AS II cmt. ND 20" Hydrill & diverter system. Set"lO-3/4'' pkoff & tstd to 20~00 psi - ok. NU BOPE & tstd to ~3000 psi - ok. Changed over to oil base mud. Cleaned out cmt to FC @ 2697'. Tstd csg to 1500 psi - ok. Drld cmt to 2782'. Tstd csg to 1500 psi - ok. Drld FS & 10' of form. Tstd form to 12.5 ppg EMW - ok. Drld 8-3/4" hole to 7753' Circ &' cond for logs. Ran DIL/GR/BHCS, CBL/VDL/NGT & FDC/CNL/NGT~CAL. Ran 165 jts 7" 26# K-55 Butt csg w/shoe @ 7723'. Cmtd csg w/480 sx 14.7 ppg Class G cmt. Pumped 297 bbls NaC1/NaBr down 7" csg to bump plug @ 7626' PBTD. Set 7" pkoff & tstd to 3000 psi - ok. Ran Gyro/CCL & CBL/VDL/GR/CCL. Ran 3½" completion string w/tail pipe @ 7033' & pkr @ 6947'. Ran GR/CCL & Arctic packed 10-3/4" x 7" annulus w/300 bbl H~O, 250 sx AS I cmt & 108 bbls Arctic pack. Reverse circ & dis- placed NaC1/NaB1 w/258 bbl diesel. Tstd Arctic pack to 1000 psi - ok. Set pkr & tstd to 3000 psi - ok. ND BOPE. NU tree & tstd to 3000 psi - ok. Tstd tbg to 3000 psi - ok. RU perf equip & tstd - ok. Perfd 7046-7118' w/12 spf. Flow tstd well. Tstd tree to 3000 psi. Secured well & released rig @ 2330 hrs, 2/27/81. ~ The cellar was monitored constantly for gas bubbles throughout the drilling process. A significant reduction in cellar gas bubbling was observed. This was largely due to the use of an insulated conduc- tor. A squirrel cage fan was also used to vent any cellar gas that might exist. 1111 East 80th Anchorage, Alaska 99502 Phone 349-3541 Telex: 25-364 World Leader in Service to the Oil Industry ,.~ 0 ' '. .':"?o:2th S_!o~e :OPil] i~' .,. ..... (~ .:]ne~..~-~~.,~ ~. ..... .pIease find our ~.:yro Survey on KunsPuk 0-2' a!on~ :;ith our ~Zertica! Section and Horizontal ~:ie~:~~ also '~nclos~d :ou will f~nd the GS.o .F~!m F~,:~!: and. Calculations. if any othep in:~o~ma~ion .... is n~,'~,.,;~ please call .~::. you for using Scientific D~ilting !nter~ational and 'pl,~as~ call . SLnce~eLz i,'iana~:e r MAy ...~ 1981 Alaska Oil & Gas Cons. C°r~?n~ission ADChorage COMPLETION REPORT ARCO ALASKA INC GYROSCOPIC SURVEY RADIUS OF CURVATURE METHOD OF COMPUTATION COMPUTED FOR SDC BY FM LINDSEY 8 ASSOC 3 APR 81 KUPARUK KB EL EV 94. FT, JOB NO 5436-MSG RECORD OF SURVEY TRUE MEAS, DRIFT VERTICAL SUB DRIFT DEPTH ANGLE DEPTH SEA DIREC D M DEG, 0 0 0 0,00 -94,00 N O,OOE 100 0 5 99,99 5.99 N21,63W 200 0 30 199,99 105.99 S13.45E 300 0 45 299.99 205.99 S48.18E 400 0 15 399.98 305.98 N66.75E 500 0 15 499,98 405,98 N72,15W 600 0 30 599.98 505,98 S81.05E 700 0 30 699.98 605.98 N26.03E 800 0 30 799.97 705.97 N 2.86W 900 0 30 899.97 805.97 N22.76W 1000 0 30 999.96 905.96 S86.06E 1100 0 30 1099.96 1005.96 S85.56E 1200 0 45 1199.96 1105.96 N67.51W 1300 0 40 1299.95 1205.95 N14.38W 1400 0 45 1399.94 1305.94 N49.78W 1500 5 24 1499,77 1405.77 N45,58W 1600 8 45 1598.99 1504.99 N28,20W 1700 11 15 1697.46 1603.46 N13.13W 1800 11 30 1795.50 1701,50 N21,O5W 1900 14 30 1892,92 1798,92 N18,16W 2000 16 45 1989.22 1895,22 N12,11W 2100 18 49 2084.44 1990,44 -N 0.76W 2200 22 0 2178.14 2084.14 N 4,43E 2~00 23 49 2270.24 2176.24 N 7,51E 2400 26 15 2360.84 2266.84 N 6.58E TOTAL COORDINATES 0,00 S 0,00 W 0.07 N 0,01 W 0'03 S 0,~3 W 0-95 S 0,21 E 1.08. S 1,02 E 0,75 S 1,01 E 0.32 S 1.11 E 0.05 N 1.83 E 0,89 N 2.01 E 1.74 N 1,81 E 2.33 N 2.24 E 2.2? N 3.11 E 3.01N 3.29 E 3.91N 2,50 E 4,94 N 1,86 E 8.56 N 2,11 W 18.38 N 9.48 W 34,58 N 15.59 W 53,42 N 21.38 W 74,61 N 28.93 W 100,59 N 35.96 W 130,90 N 39,38 W 165.75 N 38,27 W 204,47 N 34,22 W 246,48 N 29.02 W CLOSURES DISTANCE ANGLE D M 0,00 S 0 0 0 W 0,07 N 10 48 59 W 0,33 S 84 44 23 W 0,97 1,49 $ 43 26 54 E 1.26 ~ 53 29 46 E 1,16 1,83 N 88 23 56 E 2.20 N 65 57 24 '2.51N 46 12 0 E 3.23 N 43 49 20 3.85' N 53 51 41 E 4.46 N 47 30 19 4.65 N 32 39 13 5.28 N 20 38 18 E 8.82 N 13 51 11W 20.69 N 27 17 10 W 37.94 N 24 16 15 W 57,54 N 21 49 4 80,02 N 21 11 49 W 106,83 N 19 40 26 w 136.70 N 16 44 45 W 170,11 N 13 0 6 W 207,32 N 9 30 2 W 248.18 N 6 42 58 W DOG LEG SEVERITY DEG/iOOFT 0,000 0,083 0.417 0.250 0,468 0.250 0.594 0,250 0,173 0.851 0,004 0,252 0,084 0.084 4,667 3,356 2.565 0,402 3.005 2.305 2,396 3.250 1,901 2.424 S~CTIO,. JISTANC~ 0.00 -0.07 -0.91 -0.93 -0.59 -0.16 0.31 1.17 1,98 2.63 2.69 4.23 5.16 8,18 16.86 32.03 49.86 69.76 94.q~ 124.01 158.67 197,58 Z39,89 ARCQ KUPARUK C-5 GYROSCOPIC SURVEY JOB NO 5436-MSG 3 APR 81 .. RECORD OF SURVEY MEAS, DRIFT DEPTH ANGLE D M 2500 28 45 2600 29 45 2700 29 30 2800 29 30 2900 29 30 3000 29 15 3100 29 0 3200 29 45 3300 30 0 3400 30 4 35OO 3O 15 3600 30 30 3700 30 45 38OO 3O 3O 3900 30 54 4000 31 0 4100 30 54 4200 30 34 4300 30 15 4400 30 15 4500 30 0 4600 30 15 4700 29 54 4800 29 24 4900 29 4 5000 28 49 5100 28 30 52'00 28 0 5300 27 15 TRUE VERTICAL DEPTH 2449,53 2536,78 2623,71 2710,74 2797,78 2884,92 2972,28 3059.42 3146.13 3232,70 3319,15 3405,43 3491.48 3577,53 3663.51 3749,26 3835,02 3920,96 4007,19 4093,58 4180.07 4266,56 4353,09 4439,99 4527,24 4614.73 4702e47 4790e56 4879,16 SUB SEA 2355,53 2442.78 2529,7I 2616.74 2703,78 2790.92 2878.28 2965.42 3052,13 3138.70 3225.15 3311.43 3397,48 3483.53 3569,51 3655.26 3741,02 3826,96 3913,19 3999,58 4086.07 4172,56 4259,09 4345,99 4433,24 4520.73 4608.47 4696.56 4785,16 DRIFT DIREC DEG. N 8.43E N 7.73E N 7.88E N 7.81E N 7.43E N 6,63E NIO.O1E N 9.1.3E N 9.25E N 8-21E N 9.48E NlO,58E N 9,80E N 9.80E NlO,15E N 9.01E N 9,36E N 9.56E NlO.71E N12,05E N 9,95E Nll,OSE N 9.18E N 8,28E NlO.58E NlO,98E NiO,IOE N11,50E Nll,80E TOTAL COORDINATES C L 0 DISTANCE SORES ANGLE D M 292.25 N 22.99 W 293.15 N 340.63 N 16.12 W 341,01N 389.60 N 9.40 W 389.71 N 438.38 N 2.68 W 438.39 N 487.19 N 3,85 E 487.20 N 535,87 N 9.85 E 535.96 N 584.02 N 16,90 E 584,27 N 632'39 N 25.06 E 632.89 N 681-56 N 33,02 E 682.36 N 731.04 N 40.62 E 732.17 N 780.70'N 48,35 E 782.19 N 830,49 N 57,16 E 832.45 N 880,63 N 66,17 E 883.11 N 930.82 N 74.84 E 933.83 N 981.12 N 83,69 E 984.68' N 031,84 N 92,25 E 1035,96 N 082.62 N 100.47 E 1087.27 N 133.06 N 108.88 E 1138.27 N 182,89 N 117,79 E 1188,74 N 232.28 N 127J74 E 1238.88 N 281.54 N 137.31 E 1288.88 N 330,89 N 146.47 E 1338.92 N 380,23 N 155,29 E 1388,94 N 429.15 N 162.81 E 1438,391N 477,35 N 170,8.1 E 1487.19 N 524.91 N 179.87 E 1535.48 N 572.07 N i88.65 E 1583.35 N 618,56 N 197.52 E 1630.57 N 663.97 N 206.88 E 1676e79 N DOG LEG SEVERITY DEG/IOOFT 4 29 54 W 242 35 W 1 22 59 w 0 21 i W 0 27 10 .F- l 3 14 E 1 39 28 E 2 16 10 E 2 46 25 E 3 10 49 E 33238E 3 56 14 E 4 17 50 E 4 35 49 E 4 52 32 E 5 6 32 E 518 7 E .5 29 20 E 541 13 E 555 5 E 6 6 57 E 6 16 50 E 6 25 10 E 6 29 .56 E 6 35 43 E 643 38 E 6 50 34 E 6 57 27 E 7 5 14 E 2.536 1'015 0.k53 0,033 0,189 0.315 0.834 0,781 0,252 0.273 0.362 0.378 0,323 0.250 0,427 0,312 0,124 0,337 0,443 0,672 0.581 0.381 0.578 0,545 0,638 0,267 0.389 0,588 0.753 SECTION ~ISTANCE ~34.9. 364,35 433.59 482.83 531.88 PSOe54 6g9.58 679.38 729.44 779.69 830.22 881.13 932.05 983.09 10~4.52 1085.95 1137.06 1157,66 1237,95 12@8.08 1338,22 1338.32 1437,6i 1~86.65 1535.02 15u2.gb 1630.23 1676.51 ARCQ KUPARUK C-5 GYROSCOPIC SURVEY JOB NO 5436-MSG 3 APR 81 " XRECORDOF SURVEY TRUE MEAS. DRIFT VERTICAL SUB ~ DRIFT DEPTH ANGLE DEPTH SEA DIREC D M DEG, TOTAL COORDINATES 5400 23 45 4969,41 4875,41 N 3.61E 1706,59 N 212,65 E 5500 23 30 5061.03 4967.03 N 2.70W 1746.65 N 212,97 E 5600 24 30 5152.38 5058,38 N 6.71W 1787.17 N 209.63 E 5700 24 49 5243,25 5149,25 N 6,53W 1828,63 N 204,82 E 5800 25 4 5333,92 5239,92 N 5.30W 1870.60 N 200,47 E 5900 24 0 5424,88 5330,88 N 3,68W 1912,01 N 197,21 E 6000 23 34 5516.38 5422,38' N O,20W 1952,32 N 195.85 E 6100 22 4 5608,54 5514,54 N 8,76E 1990.97 N 198.74 E 6200 21 49 5701,29 5607,29 N 6.88E 2028,02 N 203.83 E 6300 21 30 5794e22 5700,22 N 9.10E 2064.58 N 208,97 E 6400 21 '4 5887.40 5793.40 Nll,51E 2100.30 N 215.46 E 6500 21 0 5980,73 5886.73 N 9,61~ 2135,59 N 222.05 E 6600 23 0 6073,44 5979,44 N14,15E 2172,24 N 229,76 E 6700 25 45 6164,52 6070,52 N13.05E 2212.35 N 239,46 E 6800 27 45 6253,81 6159,81 N16.43E 2255.87 N 250,91 E 6900 30 0 6341,38 6247,38 N14,18E 2302.4~ N 263,66 E 7000 32 0 6427,09 6333.09 N16,90E 2352.05 N 277.46 E 7100 34 30 6510,71 6416,71 N16,85E 240~.52 N 293.37 E 7200 34 39 6593,04 6499.04 N16.25E 2458.93 N 309,54 E 7'300 35 0 6675.12 6581.12 N16.43E 2513.74 N 325.61E 7400 34 45 6757,16 6663,16 N15.70E 2568.68 N 341.44 E 7500 3~ 30 6839,45 6745,45 N15,00E 2623.48 N 356,48 E 7600 34 4. 6922,07 6828,07 N15.65E 2677.81 N 371,37 E THE 'FOLLOWING INFORMATION IS EXTRAPOLATED TO TD 7753C34 4 7048,79 6954,79 -N15,65E 2760,37 N 394,50 E C L 0 $ U DISTANCE RES ANGLE D M S 1719,79 N 7 6 10 1759.58 N 6 57 6 1799,43 N 6 41 24 1840,07 N 6 23 27 1881.31 N 6 7 1 1922,15 N 5 53 20 1962.12 N 5 43 43 2000.87 N 5 42 2 2038,24 N 5 44 2075.13 N 5 45 46 2111.32 N, 5 51 26 2147,11 N 5 56 9 2184.36 N 6 2 16 2225,27 N 6 10 39 226'9,78 N 6 20 48 2317,49 N 6 31 58 2368.36" N 6 43 40 2422.35 N 6 57 22 2476.33 N 7 10 30 2534.74 N 7 22 50 2591,28 N 7 34 17 2647.58 N 7 44 17 2703,44 N 7 53 44 ., 2788,42 N 8 8 0 DOG LEG SEVERITY DEG/100FT SECTION DISTANC~ 3.743 1719,52-~ 1.035 1799,2. 1,215 1798.85 0.335 1839,21 0.334 1880.15 1,i16 t920.68 0,696 1960.39 1,964 1999.07 0.361 2036.46 0.447 2073,36 0.521 2109,66 0,25~ 2145,53 2,116 2182,90 2.758 2233.98 2.i30 Z~68,68 2,319 2316.58 2,141 2367.65 2,500 2421,84 0,256 2477,99 0.339 2534,52 0.345 2591,15 0,336 2647,52 0,~64 2703,42 E 0,000 2788,42 BOTTOM HOLE CLOSURE Z788,42 FEET AT N 8 8 0 E ARCO KUPARUK C-5 GYROSCOPIC SURVEY dOB NO 5436-MSG 3 APR 81 .- INTERPOLATED TRUE VERTICAL DEPTHS, COORDINATES AND CLOSURES FOR GIVEN DEPTHS TRUE CODE MEASURED VERTICAL TOTAL COORDINATES C L 0 $ O R E NAME DEPTH DEPTH DISTANCE ANGLE D M S SUB SEA K-13 3912 3673.81 987,19 N 84.75 E W,SAK SD-T 4024 3769.84 1044.05 N 94,18 E W.SAK SD-B 4182 3905.48 1124.05 N 107,03 E K-10 4950 4570,96 1501.22 N 175,02 E K-5 5790 5324,87 1866.39 N 201,15 E K-4 6286 5781,21 2059.53 N 207.86 E K-3 6385 5873,41 2095,02 N 214.25 E K-2 6559 6035.59 2156,94 N 225,99 E KGRS-B 6774 6230,75 2244.36 N 247.51 E K-1 6887 6330,10 2296.23 N 261,83 E KRS1-D 7008 6433.87 2356.14 N 278,63 E TK KRSi-C 7043 6463.34 2374,28 N 283.83 E TUS KRS1-C 7043 6463.34 2374,28 N 283,83 E KRS1-B 7069 6485.04 2388,04 N 287.78 E KRS1-A 7134 6538,72 2423,04 N 298,69 E BUS KRS2 7233 6620.17 2476.99 N 314.72 E TIDAL SHAL 7249 6633.31 2485,76 N 317.24 E TLS KRS3-D 7433 6784.29 2586,83 N 346.30 E KRS'3-C 7441 6790.87 2591.23 N 347,48 E KRS3-B 7463 6808,98 2603,30 N 350,71 E KRS3-A 7497 6836,98 2621,93 N 355.70 E BLS KI SHA 7563 6891.46 2657.82 N 365,68 E BK KIN SHA 7563 6891.46 2657.82 N 365.68 E PLUG BACK 7626 6943.61 2691.88 N 375,14 E TD 7753 7048,79 2760.37 N 394.50 E 990.82 N 4 54 25 E 3579.81 1048.29 N 5 9 17 E 3675.84 1129.13 N 5 26 21 E 3811,48 1511.39 N 6 39 0 E 4476.96 1877,20 N 6 9 4 E 5230.87 2069,99 N 5 45 48 E 5687,21 2105,95 N 5 50 21 E .5779.41 2168.75 N 5 58 53 E 5941.59 2257,96 N 6 17 35 E 6136.75 2311.11 N 6 30 18 E 6236.10 2372,56 N 6 44 39 E 6339,87 2391.19 N 6 49 1 E 6369.34 2391,19 N 6 49 1 E 6369.34 2409-32 N 6 52 17 E 6391,04 2441,38 N 7 1 38 E 6444.72 2496.90 N 7 14 28 ~ 6526,17 2505,93 N 7 16 22 E 6539,31 2609,91 N' 7 37 29 E 6690.29 2614.42 N 7 38 16 E 6696.87 2626.82 N 7 40 21 E 6714.98 2645e94 N 7 43 33 E 6742,98 2682.86 N 7 50 2 E 6797,46 · 2682,86 N 7 50 2 E 6797.46 2717.89 N 7 56 1 E 6849.61 2788.42 N 8 8 0 E 6954.79 ARCO KUPARUK C-5 GYROSCOPIC SURVEY JOB NO 5436-MSG MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, 3 APR 81 TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTI-ON TOTAL COORDINATES 194 194. 100 0 294 294. 200 0 394 394, 300 0 494 494, 400 0 594 594, 500 0 694 694, 600 0 794 794, 700 0 894 894, 800 0 994 994, 900 0 1094 1094, 1000 0 1194 1194. 1100 0 1294 1294. 1200 0 1394 1394. 1300 0 1494 1494. 1400 0 1595 1594, 1500 0 1696 1694, 1600 2 1798 1794e 1700 4 1901 1894. · 1800 7 2005 1994. 1900 10 2110 2094. 2000 16 2217 '2194, 2100 23 2326 2294, 2200 32 2437 2394, 2300 43 2551 2494. 2400 56 2666 2594, 2500 72 2781 2694, 2600 87 2896 2794, 2700 102 3010 2894, 2800 116 3125 2994, 2900 130 3240 3094, 3000. 145 3355 3194. 3100 161 B471 3294, 3200 176 3587 3394, 3300 192 3703 3494, 3400 209 3819 3594, 3500 225 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 2 2 3 3 6 7 9 11 13 16 15 15 14 14 15 16 16 17 16 0.00 N 0.90 S 1.10 S 1.30 S 0.33 S 0.00 N 0.68 N 1.69 N 2,33 N 2,27 N 1.54 N 3.85 N 4e89 N 8,22 N % 17,77 N 33.86 N 53,06 N 74,84 N 102,01 N,. 134,15 N 172.15 N 215.03 N 263,01 N 316.68 N 372e98 N 429e 07 N 485,13 N 540,73 N 595,93 N 651.95 N 708.76 N 766.25 N 823.94 N 882,10 N 940,36 N 0,32 W 0,15 E 1,00 E 1,27 E 1,07 E 1,81 E 2,35 E 1,84 E 2,19 E 3,06 E 3,22 E 2,53 E 1,93 E 1.66 W 9.03 W 15,35 W 21,22 W 29,01 W 36,26 W 39,37 W 37,79 W 32,94 W 27,17 W 19,67 W 12.15 W 4e56 W 3,05 E 10.38 E 18.97 E 28.16 E 37,19 E 45.79 E 55,53 E 66,40 E 76,37 E ARCO KUPARUK C-5 GYROSCOPIC SURVEY JOB NO 5436-NSG MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. 3 APR 81 TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 3935 3694. 3600 241 16 4052 3794. 3700 258 17 4169 3894. 3800 275 17 4285 3994. 3900 291 16 4400 4094, 4000 306 15 4516 4194. 4100 322 16 4632 4294. 4200 338 16 4747 4394. 4300 353 15 4862 4494. 4400 368 15 4976 4594. 4500 382 14 5090 4694. 4600 396 14 5204 4794. 4700 410 14 5317 4894. 4800 423 13 5427 4994, 4900 433 10 5536 5094. 5000 441 8 5646 5194e 5100 '451 10 5756 5294, 5200 461 10 5866 5394, 5300 472 11 5976 5494, 5400 482 10 6084 5594, 5500 490 8 6192 5694, 5600 498 8 6300 5794, 5700 506 8 6407 5894, 5800 513 7 6514 5994, 5900 520 7 6622 6094, 6000 528 8 6733 6194. 6100 538 10 6846 6294. 6200 551 13 6961 6394, 6300 567 16 7080 6494. 6400 585 18 7201 6594. 6500 607 22 7323 6694. 6600 629 22 7445 6794, 6700 651 22 7566 6894. 6800 672 21 7687 6994, 6900 693 21 998,84 N 1058,27 N 1117,33 N 1175,38 N 1232,28 N 1289,44 N 1346,57 N 1403,30 N 1459ell N 1513.60 N 1567,44 N 1620,35 N 1671.40 N 1717.37 N 1761,09 N 1806,10 N 1852,05 N 1898,11 N 1942,52 N 1984,98 N 2025.10 N 2064.51 N 2102.77 N 2140,58 N 2180.69 N 2226.46 N 86.76 E 96,44 E 105,96 E 115,90 E 127.74 E 138,59 E 149e43 E 158,85 E 157.35 E 177,21 E 187,37 g 197,86 E 208.23 E 213.34 E 212,28 E 207.64 E 202,47 g 198,38 E 196,22 E 197,77 ~ 202,98 ~ 208.64 E 215e94 E 222,87 E 231,85 E 242,85 E 2276,69 N '!~. 256,70 E 2332.50 N 2393,93 N 2459.47 N 2526.4.2 N 2593,31 N 2659.45 N 2724e79 N 271,50 E 289,47 E 309,70 E 329.22 E 348,04 E 366.12 E 383.96 E ARCO KUPARUK C-5 GYROSCOPIC SURVEY JOB NO 5436-MSG 3 APR 81 " INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH, TRUE MEASURED VERTICAL SUB DEPTH DEPTH SEA TOTAL COORDINATES 1000 999, 2000 1989, 3000 2884, 4000 3749, 5000 4614, 6000 5516, 7000 6427. 905, 2.33 N 2,2~+ E 1895. 100.61 N 35.90 W 2790, 535.93 N '9,40 E 3655, 1031,84 N 92,18 E 4'520, 1525.00 N 179,22 E 5422. 1952.32 N 196.16 E 6333, 2352,18 N 276.99 E HORIZONTAL VIEW ARCO ALASKA INC. KUPARUK C-5 GYROSCOPIC SURVEY RADIUS ,~)F (~,VATLRE SCALE I = I APRIL 6, 1981 · ' TVD = 7049' 6eoo J TMD= 7755' ~oo . 5200 I 4800' ~1~¢~ 12 4400 ~°°° ~17 '-"°°t/~ '/ ,~oo-/- I, .oo+/~ ;, cO00 ~/.____..t · ~,..--- 9 6 7~ TIIN,RIOE,U.M. ALL DEPTHS SHOWN ARE TVD SURFACE LOCATION IS SEC. 12, TI IN,R IOE, U.M 448' SNL ,967'EWL 400 VERTICAl_ SECTION ARCO ALASKA INC. KUPARUK C-5 GYROSCOPIC SURVEY RADIUS OF CURVATURE SCALE I"= I000' APRIL 6, 1981 8O0 1200 -~$600 . k ~ 5200 5600' ~400 TVD: 7049' TMD = 775~' Check Form for timely compliance with our regulations. Operator, Wel 1 Name ~d Number Reports and Materials to be received by: ~[te Required I Date Received Remarks Completion Rc~ort Yes Core Chips Well History I __ Yes Samples Core Description Registered Survey Plat Inclination Survey ,:', .... . ......... ,Directional Survey- ~'""h y_.'~_.~_ ~'""" , .... :,. __ . .......... __ .~ ........ _..?._.__?. .... 5'-/-~( ................. ~, __,// '%..¢."' %,, _ ....... ,,,"J .......... ~. ......... - .... , · Drill Stem Test Reports Production Test Reports Logs Run t Yes .., .. .:, .:,,?~ ....... . .... . .:./ ...... 6 From: J. J. Pawelek / I_mo Lasl Transmitted herewith are the following: Please note: BL - Blueline; S - Sepia, F - Film, T - Tape RES ENO ~ ! 1-~-i~o,,j~ '~ ,,2 EN~" ? 3 ENG 4 ENG 2 ~E~ ! :30E!OLZ _.~__ST~T TEc ~ I 51AT TEC ~N~E~: RE2URN REC'EIFr TO: ARCO Alaska, Inc. Attn. Leo Lash / AFA-311 P. O. Box 360 Anchorage, AK 99510 RECEIVEI) APR 1 ? 1981 Oil & Gas Cons. Commission Anchorage March 24, 1981 Mr. Hoyle Hamilton Alaska Oil & Gas Conservation Commission 3001. Porcupine Drive Anchorage, AK 99501 Subject · DS 2-15 DS 6-16 DS 6- 12 DS 6-11 DS 3-18 DS 6-14 DS DS DS DS DS DS 13-12 6-10 6-9 6-13 2-18 2-16 DS 2-17 DS 16-8 DS 16-9 Lake St. Kuparuk. #1 C-5 Dear S ir' Enclosed please find- 1) The Well Completion Reports for DS DS 6-9, DS 6-10, DS 6-11, DS 6-12, 6-14, DS 6-16 & Lake St. #1. 2-15, DS 3-18, DS 6-13, DS 2) The Subsequent Sundries for DS 2-15, DS 2-17, & 2-18. 3) The Monthly Report of Drilling Operation 16-8, 'DS 16-9 & Kuparuk C-5. Sincerely, P.A. Van Dusen Dist. Drlg. Eng. Attachments 2-16, DS for DS 13-12, DS 'I ' STATE OF ALASKA ALASKA(.' .L AND GAS CONSERVATION C(" IMISSlON MONTHLY REPORT OF DRILLING AND INORKOVER OI I=P. ATION$ 1. Drilling well C~ Workover operation [] :2. Name of operator 7. Permit No. Atlantic Richfield Company 81-5 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 99510 50_029-20550 4. Location of Well at surface 1448'FNL, 967'FWL, Sec 12, TllN, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 94' RKB 6. Lease Designation and Serial No. ADL 25649 For the Month of. Februar~v ,19 81 9. Unit or Lease Name Kuparuk 25649 10. Well No. C-5 11. Field and Pool '- Prudhoe Ba~v Field Kuparuk River 0il Pool 2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1930 hrs, 2/08/81. Drld 8-3/4" hole to 7753' Completed well @ 2330 hfs, 2/27/81. (See Drilling History, attached) TD (7626' PBTD). 13. Casing or liner run and quantities of cement, results of pressur9 tests 16" 65#/ft, H-40 insulated conductor to 75'. Cmtd w/200 sx Permafrost. 1,0,~3/4", 45.5 #/ft, K-55 csg w/shoe @ 2782' Cmtd w/2985 sx AS II. 7 26#/ft, K-55 csg w/shoe @ 7723'. Cmtd ~/480 sx Class G. (See attached Drilling History) 14. Coting resume and brief description n/a 15. Logs run and depth where run DIL/GR/BHCS, CBL/VDL/NGT, FDC/CNL/NGT/CAL, Gyro/CCL, CBL/VDL/GR/CCL, GR/CCL. ~16. DST data, perforating data, shows of H2S, miscellaneous data Perfd f/7046-7118' w/12 spf. 17. I hereby certify that the foregojs true and correct to the best of my knowledge. NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate R~t 7-1J:~C) , C-5 DRILLING HISTORY Spudded well @ 1930 hrs, 2/8/81. NU diverter system & 20" Hydrill. Drld 13-3/4" hole to 2797'. Ran multishot. Ran 67 its 10-3/4" 45.5# K-55 Butt csg w/shoe @ 2782'. Cmtd csg w/2985 sx 15.2 ppg AS II cmt. ND 20" Hydrill & diverter system. Set 10-3/4" pkoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Changed over to ~oil base mud. Cleaned out cmt to FC @ 2697'. Tstd csg to 1500 psi ok Drld cmt to 2782'. Tstd csg to 1500 psi - ok. Drld FS & 1~' o~ form. Tstd form i~° 12.5 ppg EMW - ok. Drld 8-3/4" hole to 7753' Circ & cond for logs. Ran DIL/GR/BHCS, CBL/VDL/NGT & FDC/CNL/NGT~CAL. Ran 165 jts 7" 26# K-55 Butt csg w/shoe @ 7723'. Cmtd csg w/480 sx 14.7 ppg Class G cmt. Pumped 297 bbls NaC1/NaBr down 7" csg to bump plug @ 7626' PBTD. Set 7" pkoff & tstd to 3000 psi - ok. Ran Gyro/CCL & CBL/VDL/GR/CCL. Ran 3½" completion string w/tail pipe @ 7033' & pkr @ 6947'. Ran GR/CCL & Arctic packed 10-3/4" x 7" annulus w/300 bbl H?O, 250 sx AS I cmt & 108 bbls Arctic pack. Reverse circ & dis- placed NaC1/NaB1 w/258 bbl diesel. Tstd Arctic pack to 1000 psi - ok. Set pkr & tstd to 3000 psi - ok. ND BOPE. NU tree & tstd to 3000 psi - ok. Tstd tbg to 3000 psi - ok. RU perf equip & tstd - ok. Perfd 7046-7118' w/12 spf. Flow tstd well. (Wireline tool was dropped in hole. Top of fish @ 7037'.) Tstd tree to 3000 psi. Secured well & released rig @ 2330 hrs, 2/27/81. NOTE- The cellar was monitored constantly for gas bubbles throughout the drilling process. A significant reduction in cellar gas bubbling was observed. This was largely due to the use of an insulated conduc- tor. A squirrel cage fan was also used to vent any cellar gas that might exist. J NORTH SLOPE ENGINEFR_ING From: J. J. Pawelek / Leo Lash ~.T. xa-,,m: ..~p~,~ C-~%~ Transmitted herewith are the following: Please note: BL - Blueline, S - Sepia, F - Film, T - Tape [ i co:~,~x ~ j R!.--$ E~ ~.~ ] ~',~'G ~ 3 i:~f..~ ' -- l.,,-I 1 ..-.~0. '~';' Z 0 L ST.&I TE CONFER: FILF: ,__ RECEI EI '- MAR 2 3 19811 RECEI. FI' ACKNOWLEDGtE): /' ..... :,, DATE: ~ V~i iiI i i1~'111 i ~ E ~ ~~ ~: ~O~as~., ~c. Attn. Leo Lash / AFA-311 P. O. Box 360 Anchorage, AK 99510 Transmitted herewith are the following: Please note: t~L- Blumline, S- Sepia, F- Film, T - Tape o . E RE2IIRN RECEIPT TO: ARCO Alaska, Inc. Attn. Leo Lash / AFA-311 P. O. Box 360 Anchorage, AK 99510 MAt? 1 ? 1981 0il & 8as Cons. ~chorage C°mr~i,~ion Date: ~ ~_~~~~------------ Transmitted herewith are the follOwing: Please note: BL - Blueline, S - Sepia, g,, FO.C ~. c~~ F - Film, T - Tape ~_,ASE ARCO Alaska, Inc. Attn..Leo Lash / AFA-311 p. O. Box 360 Anchorage, AK 99510 · ~RECF. IVEI)~ . MAR 1 ;;' 1981 Alaska Oil & Gas Cons. Commission Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilton/~qr'-) Chairman ~~..~ , / /. ; Thru: Lonnie C. Smith Commissioner Doug Amos /~ u~i Petroleum Inspector February 18, 1981 Witness BOPE Test on ARCO 'S KUPARUK C-5 WELL, Sec. 1, Ti/N, R10E, UM Permit No. 81-5 on Rowan Rig No. 34. .F~iday February 13, 1980: I departed my residence at 5:30 am for a 7:00 am departure on Wien flight %71 arriving at Prudhoe Bay 10:00 am. I arrived Rowan Rig 34 at 12.'00 pm. Saturday February 14, 1981~ The BOPE test commenced @ 6:00 pm '~a .... was concluded at 9~O0 pm. I filled out an A.O.G.C.C. BOPE test report which is attached. Also attached is a sketch and brief summa~-y of the conductor pipe set to try and eliminate the gas bubbling problem which has occuDed previously on "C" pad. There was no gas bubbling in the cellar of this well. In summary, I witnessed the BOPE test on ARCO'S KUPARUK C-5 well on Rowan Rig No. 34, I filled out an A.O.G.C.C. BOPE test report, it along with a sketch and summary of the conduct pipe program are attached. DA ~mm 4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Date F~ /~j/~/ Operator ~R~O Representative Wel 1 ~M~mm~ ~o ~ Pe rmi t # ~ / Location: Sec / T//A/ R 7~6 M ~,~, /~#Casing Set @ 2 7~Z ft. Drilling Contractor ~¢~/~ Rig # '~¢ Representative Location, General Wel 1 Sign ~' General Housekeeping ~' Reserve pit Rig ~/~' BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pres sure ACCUMULATOR SYSTEM Full Charge Pressure ~Z~ psig Pressure After Closure /~7~ psig 200 psig Above Precharge Attained: mil ~ sec Full Charge Pressure Attained: ~ min~ sec N2 /~ ~~ 2/~ /~; psig ~' Controls: Master ~ Remote ~ Blinds switch cover ~'~ Kelly and Floor Safety Valves Upper KellY, / Lower Kelly / Bal 1 Type Inside BOP / Test Pres sure Choke Manifold No. Valves Test Pressure ~D Test Pressure ~~ Test Pressure ~D Test Pressure No. flanges Adjustable Chokes / Hydrauically operated choke / Test Results: Failures ~/~A~ Test Time ~ hrs. ~ Repair or Replacement of failed equipment to be made within days and Inspector/Commission office notified. Remarks: ~-,~E~ ~/~ ~ ~5, ~4~;~/~ /~ ~/~6 ~,~ Distribution orig. - LO&GCC cc - Operator cc - Supervisor Inspector .... I! ...... ~ ......... i 'I". .... I'i ....... i I't January 27, 1981 Mr. P. A. Van Dusen District Drilling Engineer ARCO Oil and Gas Company P.O. Box 360 Anchor age, Alas ka 99510 Re: Kuparuk C-5 Atlantic Richfield Company Permit No. 81-5 Sur. Loc.= 1448'FNL 967'FEL Sec. 12, TllN, R10E, UM. BottomhOle Loc.~ 1320'FSL & 1320'FWL Sec. l, TilN, R10E, UM. Dear Mr. Van Dusen= Enclosed is the approved application for permit to drill the above referenced well. A mud log and a directional survey are required. If available, a tape containing the digitized log information shall be sub- mitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Due to the occurance of small amounts of gas surfacing inside and/or outside of the cellar of the previous four wells drilled ~.rom thais drill site~ the following additional items are required as conditions of this permit~ 1. from P. A. Van Dusen's letter of January 21, 1981 (at- tached), all items of Technical and Safety aspects listed as "1. Safety, A., B., C., and D" except under B. item must be "mug logs"; 2. all items from Mr. Van Dusen's letter listed as "2.-- operational changes-- , A., B., C., D., and E.; 3. run a cement bond log from surface to the 10 3/4" casing seat; and January 27 1981 Mr. P. A. Van Du( . ARCO Oil & Gas -~,.~ Sak %20 4. maintain the cellar bottom free of any sealing material so that any further gas surfacing may be confined within the eel lar- Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadro~ous fish. Operations in these areas are subject to AS 16.$0.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator~s office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution' Control Act, as amended.- Prior to commencing operations you .may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, ~ocal Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. TO aid us In scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spud.ded. We would also like to be notified so that a repre- sentative of the c~mission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment., please give this office adequate advance notification so that we may have a witness present. Very truly ~urs, ~h Commissioner B_~ ORDER OF THE CO~fl~iSS~ON Alaska O~1 & Gas Co.nservat~on Commission Eno losure cc~ Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. Department of Labo. r.~ Supervisor, Labor Law Compliance Division w/o encl. ARCO Oil and Gas Company Norlh Slope D~,'''~ '-t Posl Office Bo~ 0 Anchorage, Alaska 99.510 Telephone 907 277 5637 'i January 21, 1981 Mr. Lonnie C. Smith Commissioner State of Alaska Division of Oil & Gas Dept. of Natural Resources 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' Gas Bubbling in Cellars of Kuparuk C Pad Wells Dear Lonnie' Thank you for your letter of January 12 citing the gas bubble situation in the cellars of our C Pad wells in the Kuparuk. ARCO is very concerned about this matter. I want to assure you that we have been doing everything within our power to bring about a speedy solution to the situation. It is our intent to drill and complete the C Pad wells and all other wells drilled by this District in a safe, professional manner. Since the gas flow on CPF-1, C Pad is the first time we have witnessed gas bubbling of this nature in the Kuparuk, In order to establish the facts as accurately as possible on the C Pad wells, we have compiled a pertinent history for C-1, C-2, C-3 and C-4, which is attached to this letter. The source of the gas as seen on our mud log run on C-4 appears to be from two coal intervals at 1200' and 1400'. It is possible that some lesser stringers are located at shallower depths, such as the carbonaceous material seen at +880' It is our opinion that the gas is in the hydrate state--associated either With or directly next to these coal intervals and are located in the permafrost. The base of the permafrost in these wells is around 16'25'. The gas is created by decomposition of the hydrate into its components which are water and methane. This decomposi- tion is triggered by either one or both; an increase in tempera- ture usually around 60°F minimum and/or a decrease in pressure. There is a molecular increase in volume of about 6 to 7 as the hydrate changes from a frozen state to gas and then again the normal increase in volume as the gas rises to the surface. RECEIVED ARCO Oil end Gas Company is a Division ol Atlantic F!ichlieldComf:,any JAN 2 2 1981 Alaska, Oil & O~s 6ons. 6ommlsslori ^nc,borage Mr. Lonnie C. Smith January 21, 1981 Page 2 Consequently, a few small amounts of hydrates can generate a large amount of gas to the surface. This appears to agree with what is happening as we drill these wells. There is at first small bubbling as very small sections might be encountered above 1000'. Increased bubbling is then seen as the 1200' and 1400' coals are drilled with a fairly steady gas count as the rest of the surface hole is drilled. Cementing the surface pipe and the resulting temperature increase due to the hydration of the cement again causes the bubbles to increase and gradually as the remainder of the hole is drilled, bubbling diminishes. The mud log fairly well substantiates this information. Gas samples have been taken using both a sniffer and a syringe. Two samples taken right at the surface of the cellar mud indicate' First Sample' 10 units of Methane, .1% content Second Sample- 15 units of Methane, .15% content The reason that the gas bubbles are able to travel to the surface outside the conductor ~pipe and outside the surface pipe is pro- bably as follows' We have known for some time that there is a thaw area around the wells in the permafrost region. How great this thaw diameter is depends on the temperature of the fluids being used to drill and the rate they are being circulated or produced. In the case of these wells, t'he drilling muds are usually in the range of 60°-95° and the cements are in the area of 50°F. We do not at this time ha've information as to what diameter these fluids would thaw the permafrost but it is fair to say that some thawing does take place. Consequently, as the surface hole is drilled the mud warms the 16" surface conductor casing and the cement sheathe around that casing which begins to thaw the permafrost immediately next to the cement. Once thawed there can be water channels throughout that interval. Following along with this line of thinking, the 10-3/4" surface.pipe is then set and cemented. As seen on the cement bond log for C-1 and ¢-3, the bond up to about 1700' shows to be good to the casing and formation. However, above that point is the permafrost and the warm drilling muds tend to thaw out the permafrost behind the 10-3/4" cement. If the hydrates are covered by this pipe they too are thawed and liber- ated. Theoretically, then, gas that is liberated at any point in the permafrost may rise on the backside of the casing and come up through melted permafrost channels. One of two things can then happen: 1) The well freezes back and the hydrate stops decompos- ing, or 2) the well thaws to a diameter far enough back that it reaches thermal equilibrium with the well bore with either a drilling or producing situation and ceases to decompose. The bubbles may further tend to travel outside the pipe because it is RECEIVED JAN2 2 1981 Alaska .0il & Gas Cons. Commlssic Mr. Lonnie C. Smith January 21, 1981 Page 3 normal to have an eroded section underneath the conductor pipe, i.e. significantly larger than the 16" conductor pipe x 24" conductor hole. Therefore, before setting surface pipe, rising gas bubbles have a choice of travelling up the smaller 16" X drill pipe annulus with the mud or collecting in the larger void at the 16" shoe and travelling up thawed permafrost channels on the outside of the conductor pipe. Next, after surface pipe is set, then the gas bubbles that tend to rise on the outside of the 10-3/4" annulus in the melted permafrost area are diverted to the outside of the conductor pipe since the 16" x 10-3/4" annulus is cemented sol id. Although we do have the problem of some gas bubbling outside the conductor pipe, the cement bond to pipe and formation below 1700' (below the permafrost) shows good bond. This provides a safe casing shoe to continue drilling to the hydrocarbon reservoirs that are below the surface casing.. In addition, this casing shoe is tested on every well drilled before proceeding deeper. Also, this surface casing shoe and the production casing is again tied together with cement downsqueezed during the Arctic Pack operation of the 7" x 10-3/4" annulus. We have developed the following plan to address future drilling both from the technical and safety asPects: 1. Safety A. To remove any potentially dangerous gasses, we will install an enclosure around the cellar area with a fan vented flexible hose (all explosion-proof) to be vented to the atmosphere. This should create a nega- tive pressure on this area venting it of all gaseous products. B · In addition, we will run mud logs or gas sensing devices on these types of wells until the situation is resolved. C. Constant surveillance and monitoring will be recorded to note if bubbling occurs and where it .occurs. De Accurate sampling will be undertaken to accurately analyze the type and concentration of the gas. This will include gas sniffer equipment on a continuous basis in the cellar region. 2. The following operational changes will be made in an effort to reduce or eliminate gas bubbles: RECEIVED JAN 2 2 1981 Alaska Oil & Gas Cons. Comm/s$/or~ Anchorage Mr. Lonnie C. Smith January 21, 1981 Page 4 A. The conductor pipe and hole size and design for the next well is being evaluated to optimize good cementing qualities and optimize insulation of that region. B. Our mud temperatures will be reduced to approximately 40-45°F. This should eliminate or to a great extent reduce the decomposition of the hydrate. To bring the mud temperatures this low will require a special re- frigeration system which we are now designing. Con- tinuous monitoring of inlet and outlet mud temperatures during all drilling. Ce D, E . Run the mud logging or gas sensing service as described under safety. Evaluate improved surface cementing techniques. Cement content and temperature will be closely evaluated to improve bond and minimize decomposition during hydra- tion. Mud cooling inside the casing during cement hydration and setting may be done. Another conductor hole will be dug (they are dug dry) in the C Pad area and cuttings evaluated for hydrate content. 3. The following areas are being studied with our technical representatives in the Plano Research Lab. The timing on these studies has not yet been set but we expect they will take at least a few months. Al B , Improved conductor pipe design such as insulated con- ductor pipe and larger diameter pipe or holes.,. The effects of long-term production on current wells that have already been drilled and newly designed wells yet to be drilled. C. We are requesting our local Geophysical group to review the seismic work in all new Kuparuk development areas. The emphasis here will be to look for and possibly predetermine that hydrates may or may not be present. In summary, we are looking into all of the areas that we can think of at this time. If you should have any additional questions on the Kuparuk C Pad wells, please let us know. I would point out that this problem has been isolated to the C Pad area and not RECEIVED JAN 2 2 1.981 Alaska, Oil & Gas Cons. Commission Anchorage ~qr. tonnie,C' Smith january 21 1981 page 5 ~e problem ~u~arU~ ''~'~ need to u~'j~a ~nforma~'~_,,ost you . -~ ~n the else~er~ nroper ~, nn~ck~Y a~,~ manner area. . of cna~p.~_ ~rm~ts ~he result~ P. ~. ~a~OUse" o~str~ct Drilling Engineer .cs Rttachments RECEIVED JAN 2 2 1981 Alaska Oil & Gas Cons. Commission Anchorage PERTINENT WELL HISTORY KUPARUK C-1 A. Conductor Hole Size: 24", Depth 74' Conductor Pipe: 16" with seam cut length and strap welded over seam (for easy burst during freeze back) Cement Conductor: 422 sx Arcticset II. Water Temp 50°F Cellar: 6' diameter 5' deep Pad: 5' deep B. Mud Temperatures & Depths' DePth Pit Temp °F Flowline Temp °F 695 93 89 1525 92 94 2410 High High 2815 High' High Ce First report of bubbles outside the 16" conductor occurred [a 1876'. Found cellar eroded (probably a result of thawed area near surface) Filled void with 133 sx Arcticset II, 14.6 ppg. Bubbles decreased to 20% of original level after cementing cellar. D. Ran 10-3/4" casing to 2798'. Cemented with 35 bbls spacer, 1380 sx Fondu and 250 sx Arcticset II. No cement returns to surface and there- fore did a top job with 115 sx Arcticset II. E. Ran a CBL on the 10-3/4" cement job to determine the top of cement. GoOd pipe and formation bond from 2700' up to +1800'. Fair pipe bond and poor formation bond up to 1500'. Poor to no bond to surface. F. Remainder of well the bubbling continued at a very low level in the cellar. After moving the rig off location the bubbling stopped. JAN 2. 2 1,981 Alaska Oil & GaS Cons. Commission' Anchorage PERTINENT WELL HISTORY KUPARUK C-2 A. Conductor Hole Size: 24", Depth 74' Conductor Pipe: 16" with seam cut length and strap welded over seam (for easy burst during squeeze back) Cement Conductor: 295 sx Arcticset II Cellar: 6' diameter 5' deep, Pad: 5' deep B. Mud Temperatures & Depths- Depth Pit Temp °F Flow Line Temp °F 1200 - 72 1708 64 66 2568 69 71 2775 70 73 C. Gas cut mud was encountered at 1170' but all gas was controlled inside the rig mud system.. ' D. 10-3/4" surface casing set at 2758'. Cemented with 1350 sx Fondu followed by 250 sx Arcticset II cement. C_e_ment returns were not received to the surface. A top job .of 250 sx ArcticSet II was per- formed. E. First bubbles appeared outside the 16" conductor after the surface pipe was cemented. Bubbling outside the 16" continued throughout the re- mainder of the well at a reduced rate and stopped shortly after the rig moved off. F. No CBL was run on the 10-3/4" surface cement job. PERTINENT WELL HISTORY KUPARUK C-3 A. Conductor Hole Size: 24", Depth 74' Conductor Pipe: 16" with seam cut length and strap welded over seam (for easy burst during freeze back). Cement Conductor: 181 sx Arcticset. Water temp 50°F Cellar: 6' diameter, 5' deep. Pad: 5' deep B. Mud Temperatures & Depths: Depth Pit Temp °F Flow Line Temp °F 521 69 65 1190 64 61 1732 72 7O 2440 74 69 3235 70 72 C. Large concentrations of gas were noted at 1168' when the flow line mud was cut from 9.9 to 8.4 ppg. This gas was all handled within the rig mud system. Gas bubbling outside the 16" conductor occurred on C-3 to a much lesser extent than C-1 and C-2. It is uncear if bubbling began before or after the 10-3/4" casing was set and cemented. Bubbling continued throughout the well on a diminishing basis. This well was directionally deviated by jet drilling creating low penetration and high circulation rates through the permafrost zones. D. 10-3/4" casing was set at 3214'. Cemented with a spacer, 1500 sx of Fondu cement, 250 sx of Arcticset II. Cement was circulated to the surface. E. A cement bond log was run and indicated good cement pipe and formation bond up to approximately 1550', fair pipe bond to 700' and a poor bond to the surface. Very little formation bond is seen above 1100'. F. Some increase in bubbling was noted at 10-3/4" cementing time. The remainder of the well the bubbling diminished and was slowly bubbling after moving the rig off location 12/31/80. PERTINENT WELL HISTORY KUPARUK C-4 A. Conductor Hole Size: 30"; Depth: 80' Size: 20" conductor shot weakened by Dresser Atlas (for easy burst during freeze back) Cement Conductor: 245 sx Arcticset II Cellar: 6' diameter, 5' deep; Pad: 5' thick B. Mud Temperatures & Depths Dep.th Pit Temp °F Flow Line Temp °F 492 50 52 1500 58 56 2114 62 65 2925 58 59 C · 13-3/8" casing run to 2910'. Cemented with 1800 sx Fondu followed by 300 sx Arcticset II. Good cement returns. D. Mud log run from surface. First indication of gas was at 1200'. Gas counts of 1100 units were recorded in this area. From there to 2900' the gas count generally diminished to about 100-'200 units. E. All initial gas was handled in the conventional drilling manner. The first bubbles to be observed outside the 20" conductor were after 13-3/8" casing was cemented and in place. Bubbling has continued but on a diminishing basis. F. A cement bond log was run on the 13-3/8" casing cement job. ARCO Oil and Gas pany North Slope l~,o~rict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 6, 1981 Mr. Hoyle Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Kuparuk C-5 Dear Sir: Please find enclosed' 1) The Application for Permit to Drill with the $100.00 drilling fee. 2) The as-built drawing. 3) A diagram and description of the surface hole diverter system. 4) A diagram and description of the BOP equipment. 5) A horizontal projection of the wellbore. 6) A vertical projection of the wellbore. Sincerely, P. A. VanDusen District Drilling Engineer PAV'sp Enclosures 0il ~ G~s Cons. c0mmissi0~ ARCO Oil and Gas Company is a Division of AtlentlcRichfieldCompany Form 10-401 REV. 9-1-78 la. TYPE OF WORK STATE OF ALASKA SUBMIT IN T rE (Other instructK . ,n reverse side) ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL OR DEEPEN DRILL J~J DEEPEN b. TYPE OF WELL WELL WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Company SINGLE[--"1 MULTIPLE RECEIVED 3. ADDRESS OF OPERATOR P.O. Box 360, Anchorage, Alaska 99510 iA?q-:: 198! 4. LOCATION OF WELL At surface Alaska Oil & Gas Cons. Commissio 1448' FNL, 967' FWL, Sec 12, TllN, RIOE, [Jtq Anchorage At proposed prod. zone 6450' SS, 1320' FSL~ 1320' FWL, Sec l, TllN, RIOE~ UM 13. DISTANCE IN MILES AND DI~ON FROM NEAREST TOWN OR POST OFFICE* 30 miles NW of Deadhorse :5. 50-029-20550 6. LEASE DESIGNATION AND SERIAL NO. ADL 25649 7. IF INDIAN, ALLOTrEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Kuparuk 25649 9. WELL NO. C-5 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Kuparuk River Oi' Ill. SEC., T., R., M., (BOTTOM Poo' HOLE OBJECTIVE) Sec 1, TllN, RIOE, UM 12. 14. BOND INFORMATION: Oil and Gas Bond vo~ Statewides=etya.d/orNo, 8011-38-40 (Federal Insurance Co.) 15. DISTANCE FROM PROPOSED * ( .~ ~ 16. No. OF ACRES IN LEASE LOCATION TO NEAREST 38321% s u r PROPERTY OR LEASE LINE, FT. (~so,on~est~g,u~t,~an, 3960" (prod zone) 2560 18. DISTANCE FROM PROPOSED LOCATION 19. PROPOSED DEPTH TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 120' (surf) 3733' (prod zone) 6959' TVD 21. ELEVATIONS (Show whether DF, RT, CE, etc.) 55' (approx)GL RKB 94" (approx) 23. PROPOSED CASING AND CEMENTING PROGRAM ~anount $500,000 17. NO,ACRES ASSIGNED TO THIS WELL 320 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START February lO, 1981 SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement 24" 16" 65 H-40' 80 +_ MD ~m~ to surface - approx 200 ft3_ 13-3/4" 10-3/4" 45.5 K-55BTC 2788_~+ MD umt to surface- aPpro~ 3000 ft~ 8-3/4" 7" 26 K-55BTC 7799 + 'Cmt with approx 715- ~ft primary -' -407 ft3 secondary Arctic Pack from +__ 2000' MD to s !rf. Atlantic Richfield Company proposes to drill a Prudhoe Bay Kuparuk River Oil Pool develop- ment well to approxmimately + 7799' MD, + 6959' TVD. Selected intervals will be logged. A 20" x 2000 psi annular divert-er will be i-nstalled on the 16" conductor while drilling the surface hole. A 13-5/8" 5000 psi RSRRA BOPE stack will be installed on the surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig. Expected maximum surface pressure will be 2920 psig. The well will be completed with 3½" 9.2# J-55 buttress tubing. Nonfreezing fluids will be left on uncemented annul i thru the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon conclusion of job. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen dlrectionally, give pertinent data on subiurface locations and measured and true vertical depths. Give blowout preventer program. 24. I hereby certiJg_.~hat ~ is Trend Correct SIGNED ~d: ~~ _t~4~-~__ DATI~.~.~_~ ~,.~ District Orillinq Eng. (This space for State office use) CONDITIONS OF APPROVAL, IF ANY: SAMPLES AND CORE CHIPS REQUIRED ] M~DLOG [] YES ~ NO . YES '.],-NO DIRECTIONAL SURVEY REQUIRED ~YES [] NO OTHER REQUIREMENTS: See our cover letter & P.A. Van Dusens letter of 01/21/81 attached. A.P.I. NUMERICAL CODE PERMIT NO. 1981 ~' /,~ ,,~ ,, APPROVAL DATE January 27, APPROVED BY ,~//~'~ TITLE Commissioner DATE ~ *See Instruction On Reverse Side WELL ~1 Y = ~,968,~22,~6 ~.~"' , ' '""J~-. x = OO562 ~75 O5 ;, .,,:' .-.., ~..; ... , ', LONG = l&~°';9:}J~2g}': = · = 562 27; 78 '"L '~:~''' Nc..~:-7,~'.':' .",... ' " '-'"'-" , "-- X 0° 3" ~ ~ [c? ,i" ' ". LAT = 7 1~'28.9~. ...... LONG = ]~9°29~2~20~'' '.-~:~:~ .'.,,;,~z,~L~ ~ -~ -.. ~-., ,.., .,,.'",2T4' · WELL :~3 Y .= ~,S68,~55'.,~2 I HEREBY CERTIFY THAT I AH X - ~62 172,.58 PROPERLY REGISTERED AND LICENSED LAT = 70°19~2~..6t0'' TO PRACTICE LAND SURVEYING IN LONG = 1~°2~.08~'' THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN AS- WELL .'~ Y = z,~68,722.93 BUILT SURVEY HADE BY HE, AND X = ~6,e.072..98 THAT ALL DIHENStONS AND OTHER' LAT = ,O 19t30.27 ' DETAILS ARE CORRECT, AS OF- / LONG -= ~9°29'~Z 97g" DATE i ~/~O WELL '5 Y = 5,968.788.~1 WELL z'7 Y = 5,968.921.!6 x -= 56;.273.00 x = g61,772.~3 o LAT. = '-,e,:'",,,~-1'~ 3e_., . ,93~" LAT : 70019` 320256" LONG = ig~°2c~qn,3'/8'' LONG = 1~9o23'56.G89'' WELL .:'r~ " 5,968 8[,- na WELL :-"8' Y ~ 968 987.86 L. AT = 7C,°~.:2~3~ ,:'~8" LAT = 70°19~2~92e', LOtIC = ~9°29'53,79t'' LONG = 1~9o29'~9.608'' .... ii I iii ~ i il I i , ....................... _ AtlanlicRi~hfieidCompany ~ DATE. ~DRAWING No: NORTH AMERICAN PRODUCING DIVISION . 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I-..~-z ................. b ...... · ~ ~ ' ' ! =--,'I--------~7 ...... ~---r-~_TT- T- : .... T--~I --- .... :-'1- ........ . [ ........ ~- ...................... ----t-' ? i-2 ~ , -- ; ! . ' ' [ , 7']" : ' ' ~ I ~ , , ,L / ~--+- . ' ' -~ ' ~ ' ~. ~ ' ~ ~. ' ' - , ~ : , I . --~1 ...... ,_z_ ~--.--------t-"- ....... t ......... ~ .................. * .............. =--"t'"'=' ................ ~ .......... .... : ...... ~ ......... I'~ ...... ?k ..... :-.-- ~ ......... ~- ...... --~- .... ,-_~_z--__.~~ ._i.. ...... ~rRRCO OIL-AND GAS f~PRD. C~'.-WEL~;NO:,-'5-:PROP( ~KUPARUK FIELD,-HORT~-$LO~E~-RLRSKR IN. FEET i (TO TRRGET ! BRSE--PERHRFROSl BUILD 9-DEG. PER.-IDO :-CIq, SZNG POZNT T:TVD-2'?O0-~88 DEP.14.- RVERRGE flNGLE:'_-.'_9!:_DEG ..48 HIN K-S TVD-52641TTJ~S805 OEP. t99'/ -* ::IRGET- (TOP KUP-SRNDS{ -THO=791 t 0EP=2790 -' ..-- 1. 16" Bradenhead 2. 16" 2000 PSI x lC" 3000 PSI casing head 3. lC" 3000 PSI tubing head 4. lC" 3000 PSI x 13-5/8" 5000 PSI adapter spool 5.. 13-5/8" 5000 PSI pipe rams 6. 13-5/8" 5000 PSI drilling spool w/choke and kill lines 7. 13-5/8" 5000 PSI pipe rams 8. 13-5/8" 5000 PSI blind rams 9. 13-5/8" 5000 PSI annular ACC~IULATOR CAPACITY TEST 1. CHECK AND FILL ACCUNULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUHULATOR PRESSURE IS 3000 PSI W[~H~ISOO.-PS[,.DO~!IISTREAI4 OF THE REGULATOR.,_- 3. O§S~R'VE"TI~.tE~HEd CLOSE ALL UNITS SII.IULTA~;c~ OUSLY AND RECORD THE TIME AND PRESSURE RE~AIN- ING AFTER ALL UNITS ARE CLOSED WITH CHARGi~;G PUMP OFF. 4. RECORD ON IADC REPORT. THE ACCEPTABLE LC~ER LIMIT IS 45 SECO;;DS CLOSING TIHE AND 1200 PSI ~F~IAINING PRESSURE. . 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RE- TRACTED. PREDETERJ. IINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN I~; LOCK DOWN SCREWS IN HEAD. 3. . CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVESi' ON NA;i I FOLD. 4. TEST ALL CO~,iPONE~(TS TO 250 PSI AND HOLD FOR lO MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR lO MINUTES. BLEED TO ZERO PSI. 6. ,OPEN ANNULAR PREVE[ITER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR l0 HI ~(UTES. 8. CLOSE VALVES DIRECTLY UPSTREAH OF CHOKES. BLEED DOWNSTRE~',I PRESSURE TO ZERO PSI TO TEST VALVES. TEST RD1AINI~;G UNTESTED NANIFOLD VALVES, IF ANY, ~ITH 3000 PSI UPSTREA"I OF VALVE AND ZERO PSI DOWNSTREAH. BLEED SYSTE,'.! TO ZERO PSt. 9. OPEN TOP SET OF PIPE RANS AND CLOSE BOTTC:.! SET OF PIPE RA,qS. lO. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR lO HI,lUTES. BLEED TO ZERO PSI. 11. OPEri BOTTO;,1 SET OF PIPE RAHS. BACK OFF RUN- NI~;G JOI~IT A;ID PULL OUT OF HOLE. CLOSE -3LI~;D R,a~IS A~(D TEST TO 3000 PSI FOR lO III~;UTES. BLEED TO ZERO PSI. 12. OPE:( BLI~D RA;,IS A~;D RECOVER TEST PLUG. :.;AKE -SURE HA;IIFOLD A:;D LI:;ES ARE FULL CF ARCTIC DIESEL A~;D ALL VALVES ARE SET IN CRILL[SG POS I T I 13. TEST STA~IOPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS A;JD I:;SIDE BOP TO 30CO PSI '~[TH KCC;tEY PL~,IP. I5. RECORD TEST I.';FST-J.!ATIC'( 0:4 BLC'~CUT P.qEYE~;TER TEST FG2,'! SIG~ A~,D SE:.D TO DRILL"" VISCR. 16. PE~FC.~Jl CC",2LETE ~CPE TEST O:.CE A ~;EEK F~:;CTIO:;,qLL'! OPE.=,ATE E, CPE 2AILY. Surface DiVerter System' 1. 16" Bradenhead. 2. 16" x'20" 2000 psi double studded adapter. 2. 20" 2000 psi drilling spool w/lO" side outlets. 4. lO" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell nipple. '. . -'Maintenance & Ope.. t..i.o (- . 1. Upon initial installation close annular I preventer and verify that ball valves ! have opened properly. '. I 2. Close annular preventer and blow air ~ . through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually over- ride and close ball valve to upwind diverter line...Do not shut in'well under any circumstances. 16" Conductor Oil & Gas Cons. Commission Anchora99 COMPANY: U.S.A. 1~i0~ AVeHUE OF THE STAR~ - LOS ANGF. LEt~. CALIFOtIiII,,'-. In re' Letter of Non-Ob jet Deviation of Wells ( 11AAC22 . 050) PRO:')UC!'!ON DE. PAR= MEt.~T WESTLFiN DI~'I~;[ON Arco Oll and Gas Company North Slope District P.O. Box 360 Anchorage, Alaska 99510 'iN overuse r - 4 ~ - 1'9'8 0 Attention' Mr. Sylvester R. Jaime Gentlemen' By ].etters dated September 24 and October 22, 1980, you have advised Exxon Corporation that you propose to directiona].ly deviate three of your developmen~wells as follows' Well No. C-1 dri].].ed from a surface location 1650 feet SNL, 1364 fee'[; EWL, Section 12, TI.].N, R10E, U.M. will be deviated to a bottom hole location 1320 feet SNL, 1320 feet NEL, Section 12, ,IN, R].OE, U.M. ~"~~].led~~ from a surface location 1381 feet SNL, 967 -'--~-~WL, ~-~%ion ].2, TllN, R10E, U.M. will be deviated to a bottom hole location at 1320 feet SNL, 1320 feet WEL, Section 1~ TllN, RiOE, U.M. Well No. D-2 dri].]ed from a surface location 117 feet North and 601 fee~ West from the SE Corner of Section 14, TllN, R10E, U.~{. wi].], be de'vfated to a bottom hole location 1320 feet SNL and 1320 %¥EL, Sect ion ].3, TllN, RIOE, U Exxon Corpora-Lion, beinK one of the lessees under State of Alaska Oil and Gas Lease ADI.,-.~82-t2 covering lands which offset on the east the above-descr.~bed Sections 1, 12 and 13, TllN, R10E, U.M., comes within the definition o:[ "an affected operator" set forth in 11AAC22.050. As such an affected operator, Exxon Corporation does not object to the above-described deviations of the well in which it is to occur. '-You may use this ~s; a letter of non-objection I'or t~e-purpbses eT 11AAC22. 050. Very truly yours, ?,: 'F r F ! V EXXON CORPORATION !/._ /h- _ t_ ...z . !ts ~torne~ in' Mobil Oil Corporation /_.,~¢F --~/~j,, ¢, ~O~:/~,j¢~"' P.O. BOX 5444 /,,..,,' DENVER, COLORADO 80217 October 20, 1980 Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 LETTER OF NON-OBJECTION ARCO OIL AND GAS LEASE ADL 25651 NORTH SLOPE ALASKA Gentlemen: We have received correspondence from Atlantic Richfield Company advising of their intent to directionally drill three wells on the captioned lease as follows: Well No. Bottom Hole Location C-1 6-5,. D-2 1320' SNL, 1320' WEL, Sec. 12-TllN-R10E, UM t3'20' SNA, 1320'~, sec'; 1-TtlN-R10~ 1320' SNL, 1320' WEL, Sec. 13-TllN-R10E, UM Mobil owns an interest of 50 percent in two leases (ADL #28243 and ADL #47449) which will be affected by the proposed action. Pursuant to 11 AAC 22.050 this is to advise Mobil Oil Corporation does not object to the proposed drilling. JLDouglass/nb Yours very truly, L. C. Case Division Regulatory Engineer cc: ARCO Oil and Gas Co. Box 360 Anchorage, AL 99510 Attn: Sylvester R. Jaime OCT S 1980 CHECK LIST FOR NEW WR. LT, PERMITS Item Approve Date (1) Fee (4) Casg. ~~_ (5) BOPE ~ Yes 1.2. IsiS wellthe permitto be feelocatedattachedin a defined .......................... pool i .............. . 3. Is a registered survey plat attached ................................ 4. Is well located proper distance frcm property line 5. Is well located proper distance frcm other wells .................... 6. Is sufficient undedicated acreage available in this pool ............ 7. Is well to be deviated .............................................. 8. Is operator the only affected party ................................. 9. Gan permit be approved t:efore ten-day wait .......................... 10. IX~s operator have a Ir>nd in force · . .... 11. Is a conservation order needed ............................ .......... .,, 12. Is administrative' approval needed ................................... No 13. Is conductor string provided ........................................ 14. Is enough cement used to circulate on conductor and surface ....... 15 Will cement tie in surface and intermediate or production strings 16. Will cement cover all kno%au productive horizons .................... 17. Will surface casing protect fresh water zones ...................... 18. Will all casing give adequate safety in collapse, tension and burst..~ 19. Does BOPE have sufficient pressure rating - Test to ~ oo psig Approval Reccmmended: Additional Requirements: Lease & Well No. ~~.k- Remarks~ HWK LCS ~BEW~ rev: 03/05/80 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting .Process but is part of the history file. T° 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 APPENDIXi .. No special'effort has been made to chronologically organize this category of information. .o VV VV VV VV VV VV VV VV VV VV VV VV VV VV VV EEEEEEEEEE RRRRRR?R VV EEEEEEEEEE RRRRRRRR V'V EE RR R~ VV EE RR RR VV EE RR RR YV EE RR RR VV EEEEEEEE RRRRRRRR VV EEEEEEEE RRRRRRRR VV EE RR RR VV EE RR RR VV EE RR RR VV EE RR RR EEEEEEEEEE ~R RR EEEEEEEE. EE RR RR IIIIII IIIIII I I II II II II iiiiiii IIIII Ff'FFFFEB'FF FFFI~-FFBFFF FF FF FFFFFFB'F FFFFFFFB FF FF FF FF FF FF YY YY YY YY YY YY YY YY YY YY Y¥ YY YY YY YY YY YY YY YY 000000 000000 222222 000000 000000 222222 O0 O0 O0 O0 22 22 O0 O0 O0 O0 22 22 0 0000 O0 0000 22 0 . 0000 O0 0000 22 O0 O0 O0 O0 O0 O0 22 O0 O0 O0 O0 O0 O0 22 0000 O0 0000 O0 22 0000 O0 0000 O0 22 O0 O0 O0 O0 22 O0 00000 000000 2222222222 00000 000000 2222222222 *START* USER PCAL [10707,61427] OOB SHIP SEQ' 209] DATE 07-APR-81 MONITOR SWS KL/OE40 NOV-80. *START* FILE: DSKH:VERIFY.O02<057>[10707.6/427] CREATED: 07-APR-8! 04:10:22 PRINTED: 07.,APR-81 04:27:35' ' ' ' QUEUE SWITCHES: /FILE:FORT /COPIES:/ /SPACING:t /LIMIT:I23 /FORMS:NORMAL 04:26:40 LiS YE[~SI[)N 15.HO1 79/03/26 SCHLUb!BERGER COMPUTING CENTER 10707,61427 LENGTH: 132 B~TES REEL DAME: P.C.A.L. SERVICE NAME: EDIT R~EL CONTINUATION NUMBER: O1 PREVIOUS REEL NAME: CfiNMENTS: LIS FORMAT CUSTOMER TAPE DATE: 811 41 7 TAPE HEADER I, ENGTH: 132 B~TES TAPE NAME: 61427 SERVICE NAME: EDIT TAPE C[)NTIMUATION NUMBER: PREVIOUS T~PE NAME: TAPE CUMMENTS OIL RI}N ~ 1, L£iGGED CASING LOGGFR BlT SI%E FL{lID IN THE HOLE -- VI SC = PH -- FLUID LOSS -- RUN IN COMBO WITH BHC. 21-FEB-81 DATE: Bi/ 4/ 7 10.75 IN. a 2782 FT. 8.750 OIL BASE 10.50 58.00 0.0 ~. I 00 ~L I-I/2 STANDOFFS USED. POROSITY MATRIX : SANDSTONE ~" HOLD ~'INDER USED. FILE EEgDER LENGTH' 62 ByTL.S ~ ILE NAME: EDIT 001 ~!AXlMU~ PHYSICAL RECORD LENGTH: PREV]£')[IS FILE NAMk: COMPANY : ATLANTIC RICHFIELD C WEDI~ : C-5 FIEI,D : KUPARUK PANGF: : IOE TOWNSHIP : 11 N COUNTY : N.O~TH SLOPE 1024 BYTES RECEIVED APR 1 ? 1981 Oil & Gas Cons. Commls61ol{ ' ~chorago TATE~ EMSITY AbASKA 800. DATA ~'OP}~IaT SPECiEICATIOM I~ENGTH: 690 BYTES LNTIqY BI, OC~S: TYPE 0 SIZE REP CODE ENTRY 1 66 0 D~TBi'~! SPECI~~ICAirIUN BLOCKS NAMg UNIT AP1 APl' ,AP1 AP1 FILE SIZE SAM R~,P PROCESS INDICATORS FT 0 0 0 0 OH~M 7 12 46 £]HMP! 7 ! 2 44 GAPi 7 31 32 0 IN 42 28 1 0 G/C~ 42 44 0 0 PU 42 68 3 0 0 G/C3 42 35 I 0 0 C/C 42 42 1 0 0 CPS 42 34 92 O 0 CPS 42 34 93 0 0 GAP[ 0 O 0 0 0 GAPI 60 31 32 0 0 US/F 60 52 32 0 0 PC T 0 0 0 0 0 PPa 0 0 0 0 0 pP,.a 0 0 0 0 0 USER DEFINED OUTPBT ARRAY' OUTPUT ILD AT 2 OUTPUT ILN AT OUTPUT GF~ AT 4 OUTPUT CALl AT 5 OUTPUT DF'HO AT 6 OUTPUT NPHI AT' 7 OUTPUT R~OD AT 8 OUTPUT NEAT AT 9 OUTPIIT NCNI. AT 10 OUTPUT OUTP~IT SGR AT OUTPUT GR AT ~3 OUTPllT DT AT 14 OUTPUT P(JTA AT 15 OUTP~IT ~]H~N AT 16 OUTPUT THOR AT 17 0 4 1 68 0 4 1 68 0 4 1 68 0 4 I 68 0 4 1 68 0 4 1 68 4 I 68 4 1 68 4 t 68 4 1 68 4 1. 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1. 68 4 1 68 DEPTH 7780.000 7700.000 7600.000 7500.000 7400.000 7300.000 7200.000 7100.000 1000.000 6900.000 6800.000 gNEi~ONIC 115 D DRHO NCNB DT iI,D DRHO NCNb DT I DRHO NCNB DT ILD DR}lO NCNb DT 1LD DRHO NCNL, DT ILD DRHO NCNb DT 1 LD DRHO NCNL DT ILO DR}tO NCNL DT 1 Li') DRHO NCNB DT I I,D DR}tO NCNL DT ILD NCNL DT VALUE MNEMONIC VAhUE MNEMONIC 2154.000 FC~L 528 500 SGR 97.750 POmA 0~O2~ URAN 2.725 1BM 2.809 GR 0.008 NPHI 38 086 RHOB 2206.000 f'CNL 596~O00 SGR 97.750 POTA 0.028 URAN 2.387 IBM 2.453 GR 0.003 NPHI 44.092 MHOB ,937.000 ~,CNL 502.000 105'000 POTA 04.02 - URAN 3.723 ILM 3.R85 GR 0.025 NPHI 26.318 RHOB 2390.000 FCNL 853,500 SGM 92.375 POTA 0.014 URAN 3 760 ,IbM 3.873 GM -0: 001 NPHI~ 2.9 :'736 RHOB 2454 000 VC~L ,, 832.000 90: 1'88 POTA O. 019 URAN 4.133 ILM 4.211 GR 0.014 NPHI 3.t.!05 MHOB 2598.000 FCNL 795.000 : SGR 94..000 POTA 0.019 URAN 3 002 IbM 3. 156 GR. 0:003 NPHI 27 ~734 RHOB 2510.000 FCNL 865.500 SGR 88.750 POTA 0' 023 URAN 7.5t6 ibm 7.508 GR 0.001 NPHI 25.146 RHOB 2926-000 FCNL 1106;O00 SGR 89.750 POTA 0.011 URAN 1.665 ILM 1.705 GR 0'01.7 NPHI 42.822 RHOB 1959.000 FCNL 482.750 SGR 113.750 POTA O,'O30 URAN 1.436 IBM 1'673 GR -999.300 NPHI -999.~00 RHO0 9~.9 300 SGM -999.300 FCNL - g 88.375 POTA -999:~00 U~AN VASUE 81.000 1.989 98.250 7.680 91.688 2.443 84.750 2.271 85.813 2.398 70.!88 1.113 61.188 2.438 53.781 3.004 69.938 2.453 59.719 1.837 75.000 2.379 59.094 2.045 78.188 2.467 67.125 2.902 52.625 2.348 40.563 1.664 106.938 2.414 93.688 3.477 75.563 -999.300 -999.300 -999.300 2.252 IBM 2.313 GR 123.625 -999.300 NPHI -999.300 ~HOB -999.300 -999,300 FCNL -999.300 fiGR -999.300 108'750 POTA ~999.]00 UMAN -999.300 MN EMONIC CALl NRAT GR THOR CALI NRAT GM THUM CALl NRAT GR THOM CALl NPAT GR THOR CALI NRAT GR THOR CALl NRAT GM THOR CALl NRAT GR THOM CALI NRAT THOR CALI NRAT GR THOR CA6I NRAT GR THOR CALl NRAT GR THOR VAL 8 3 -999 9 8 3 -999 12 8 3 -999 11 8 2 -999 7 8 2 -999 10 9 2 -999 8 9 2 -999 8 8 -99~ 6 9 3 -999 13 -999 -999 -999 9 -999 -999 -999 UE .750 .707 .250 .758 .547 .205 .250 .836 .570 .539 .250 .492 .656 .508 .250 .988 .758 .744 .250 .398 .055 .992 .250 .352 .141 .643 .250 .586 .852 .445 .250 .602 .242 .525 .250 .648 .359 .300 .250 .300 .383 .300 .250 .300 - DEPTH 6700.000 6600.0O0 6500.000 6400.000 6300.000 6200.000 6100.000 6000,000 5900.000 5800.000 5700.000 MNE~'~ON IC I ILD DPHO NCNL DT ILD NCNL DT IbD DRHO NCNL DT ILD DR}tO NCNL DT I LD DRHO NCNL DT I LD DRH[J NCNL DT I LD DRHO NCNL DT ILD DRHO NCNL DT 1 LD DRHO NCNL DT iLL DRH [) NCNL DT I I.,D DRHO N C N L DT VALUE MNEMONIC VALUE . 2.379 1Lt4 . 2 393 999.300 NPHI ~. 999:300 -999 300 FCNL :999.300 113: 375 POTA . 999 . 300 2.t21 iL~ 2.186 :999 300 NPHI :990 ~JO0 999: 300 FC~:L ,,, 999: 300 121.563 POTA -999.~00 2,494 ILM 2~ 611 -99923.00 NPHI -99~,:300 -999.300 FCNL -999 300 105,375 POTA '999:300 2.088 ILM 2 1,93 -999.300 NPHI :999i300 -999.300 FCNL ..... ~999 300 114.000 POTA -999.300 . 1.446 ILM . 1 438 ' 999,300 NPHI .'999:300 -999.300 FCNL -999.300 115.563 POTA '999.300 2.639 2999 300 ,999: 300 114.000 ILM 2.709 NPHI :909.300 ~CN5 ...... 999.30'0 POTA '9~9.~00 . 1.578 IbM 1.545 ...999.300 NPH1 "'999.t00 -999. 300 FCNL -999.:t00 1 ~I ,006 POTA -999. 300 1.507 ILM 1.436 -999.300 NPHI :999,~00 -999,300 FCNL 999~300 110.1~ POTA -99q.300 2.~84 iLM 2.486 -999,3OO NPH! -999.3OO -999.300 FCNL :9q9,300 104.750 POTA 9q9.300 1.921t ILM 1 930 -099.300 NPHI -909i300 -999.300 FCNL -9-99 300 117.750 POTA -999.300 2.014 ILM ? 033 -999.300 NPHI -999:300 -999.300 FCNL -999.300 110,750 POTA '999,300 MNEMONIC GR ORAN GR RHOB URAN G~ RHOB ORAN GR RHOB ORAN GR RHOB URAN GR RHOB SGR ORAN GR HOB GR URAN GR RHOB GR RHOB SGR ORAN GR RHOB SGR ORAN GR RHOB URAN VALUE 196.250 -999.300 -999.300 -999.300 161.875 -999.300 -999.300 -999.300 85.938 -999.300 -999.300 -999.300 120.688 -999.300 -999.300 -999.300 105.938 -999.300 -999.300 -999.300 126.500 -999.300 -999.300 -999.300 156.875 -999.300 -999.300 -999.300 146.625 -999.300 -999.300 -999.300 13~.500 -99 .300 -999.300 -999.300 171.625 -999.300 -999..300 -999 300 104.125 -999.300 -999.300 -999.]00 MNEMON CALl NRAT GR THOR CAbI NRAT GR THOR CALl NRAT GR THOR CALI NRAT GR THOR CALl NRAT GR THOR CALl NRAT GR THOR CALl NRAT GR THOR CALl NRAT GR THOR CALI NRAT GR THOR CALl NRAT GR THOR CALl NRAT GR THOR lC VALUE 9.141 -999.300 -999.250 -999.300 9.289 -999.]00 -999.250 -999.300 9.20] -999.300 -999.250 -999.300 9.000 -999.300 -999.250 -999.300 9.023 -999.300 -999.250 -999.300 9.227 -999.300 -999.250 -999.300 8.977 -999.300 -999.250 -999.300 9.148 -999.300 -999.250 -999.300 9.125 -999.300 -999.250 -999.]00 9.930 -999,300 -999,250 -999,300 9.898 -999.300 -999.250 -999.300 D E P T H 5600. 000 5500.000 5400.000 5300.000 5200.000 5!00.000 5000.000 4900,000 4800.000 4700,000 4600.000 NNEHONIC II~D DRHO NCNL DT ILD DRHO NCNL DT ILD DRHO NCNL DT ILD DRHO NCNL DT II,D DRHO NCNL DT ILD DRHO NCNL DT I I,D DRHO NCNL ILD DP, HO NCNb DT i DRHO NCNL DT ILD DRHO NCNL DT II, D DRHO NCNb DT VALUE MNEH[INIC VAL!IE MNE~.ONIC 1.861 -999.300 -999,,300 106~000 ILM 1.858 GR NPHI -999.300 RHOB FCNL -999.300 POTA -999.300 URAN 1.935 :999.300 ' 999 ' 300 108,188 IbM 1.927 GR NPHI :999.300 RHOB FCNL ....... 9991300 8GR POTA -999.300 URAN . 2 408 o9923oo -999 300 1032563 Ih~ . 2.357 GR NPHI ,,,999i300 RHO8 FCNL 2999 ]00 8GR POTA ,,,999~]00 URAN 2.553 ~.LM 2,549 GR :999 300 NPHI :999.300 RHOB ,, 999~300 FCNL ,,,999. 300 SGR 1. 02 · 1. 88 POTA -999,300 URAN 2 965 · ILM . 2 893 GR -999: 3'00 NPHI ,,999: 300 ' RHOB -999. 300 FCNL :999 300 SGR 10'2.0OO POTA ...... 9992300 URAN 3.816 ILM 3,990 GR ~999.300 NPHI -999 300 RHOB ,999o300 fCNL '999:300 88.375 POTA -999.300 DRAM ,54.ooo Fc,= v, ooo sc;, 2.260 ILM 2.203 GR -0.001 NPHI 46.289 RHOB 1.964.000 FCNL 428.500 5GR 114.000 POTA 0.021 URAN 3.80.3 ILM 3.750 G~ -0.002 NPHI ]9.404 RHOB 2116.000 f'CNL 552.000 8GR 1. I0.563 POTA 0,028 URAN 3.818 IbM 3.717 GR Q-O.Oll NPHI 42.236 RHOB 1.~75.000 FCNL 489.500 SGR 1!3.188 POTA 0.028 URAN ].4~2 II.,M ].344 GR 0.008 NPHI {3.555 RHOB 2021.000 FCNL 505.250 8GR 1.17'563 Pf]TA 0.02I URAN VALU 81. -999. -999. -999. 82. -999. -999. -999. 84. -999. -999. -999. 83 -999 -999 -999 71 -999 -999 -999 64 -999 -999 -999 78 2 59 1 94 2 80 3 85 2 73 1 94 2 77 3 71 2 60 2 75O 300 3OO 3OO 500 300 300 300 063 300 300 300 .063 .300 .300 ·300 .313 .300 .300 .300 .875 .300 .300 ·300 .000 .221 .469 .434 .750 .332 .063 .795 .500 .250 .375 .979 .625 .305 .625 .188 .268 .438 .488 MNEMONIC CALl NRAT GR THOR CALl NRAT GR THOR CAbI NRAT GR THOR CALl NRAT GR THOR CALl NRAT GR THOR CALl NRAT GR THOR CA[,I NRAT GR THO~ CALl NRAT GR THOR CALl NRAT GR THOR CALl NRAT GR THOR CALl NRAT GR THOR VALU m -999. -999. -999. . -999. -999. -999. 617 300 250 300 930 300 250 300 8.867 -999.300 -999.250 -999.300 9 -999 -999 -999 9 -999 -999 -999 9 -999 -999 -999 9 3 -999 9 9 3 -999 9 10 3 -999 9 9 3 -999 8 10 3 -999 8 .414 .300 ,250 .]00 ,469 ,300 .250 .300 .508 .300 .250 .300 .523 .021 .250 .664 .602 ,746 ,250 · .320 ,258 .4!8 .250 .422 .648 ·523 ,250 .109 .016 ,629 ,250 ·078 D g P ? H 4500.000 q400. 000 4300.000 4200.000 4100.000 4000.000 3800.000 3700.000 3600.000 3500.000 MNgf, q(~.N IC II,D DRH[) NC N L DT ILD NCNB DT I LD D R H O NCN[, DT I L D DRHO NCNL DT iLD DRHO NCNb DT I LD DRHO NCNb DT II~D DRHO NCNL DT ILD DRHO NCNL DT ILl) DR, IlO NCNL DT ] LO DRHU NCNb DT I LD DRHO NCNb DT VALUE 2.365 0.016 1679.oon 125.188 7.816 0.010 2023.O00 109.37% 8.547 -0.000 2041.000 127.563 6.121. 0.006 2092.000 110.563 26 719 -o:oo2 21 ]. 2.000 123.750 8.008 -0.00! 2029.000 108.000 10.89! 0.012 2.350.000 89.56~ 6.859 -0 008 2 8:ooo 135.5oo 7.695 0.000 2007.000 11.8.375 8.102 0.000 2037,000 129.000 9.828 0.004 2035.000 123.188 MNEHQN lC ILM NPHI FCNL POTA IbM NPHI FCNL POTA ILM NPHI FCNL POTA NPHI FCNL POTA 1LM NPHI FCNL POTA ILM NPHI FCNL POTA NPHI FCNL POTA iL~ NPHI FCNL POTA IL~ FCNL POTA ILM NPHI FCNL PUTA NPH! FCNL POTA V A. LiJE 2 27 46:921 4~2.750 0.024 7.445 ~,8 184 s4 :soo 0.019 7 906 43:506 5O0 6.n08 36.279 627.000 0.015 27.281 42.090 598.000 O.013 7.508 38.965 540~500 0.024 lo.383 30.176 891.000 0,010 6.941 40 967 603:500 0.o16 7.426 42.725 526.000 0.016 7.898 ]7.939 599.500 O.009 9. 46.191 52~:000010 MNEMONIC GR RHOB SGR bRAN GR RHOB URAN GR 8GR bRAN GR RHOB URAN GR RHOB URAN GR RHOB URAN GR RHOE SGR ORAN GR RHOB SGR bRAN GR EHOB SGR URAN GR RHOB SGR bRAN GR RHO~ 6GR bRAN VALUE 78.563 2.293 67.813 1.477 61.438 2.170 5].094 2.027 61.281 2.170 47.281 1.190 62.719 2.326 55.156 2.229 43.375 2.164 39.406 1.1.64 83.563 2.]89 70.375 2.87J 2,43¢ 37.906 1.666 47.250 2.088 38.844 2.314 66.688 2.27] 62.438 3.523 45.531 2.146 39.000 53.469 2,1.84 44,219 2.275 MNEMONIC CALl NRAT GR THOR CALl NRAT GR THOR CALl NRAT GR THOM CAbI NRAT GR THOR CAbI NRAT GR THt)R CALl NRAT GR THOR CALl NRAT GR THOR CALl NRAT GR THOR CALl NRAT GR THOR CALl NRAT GR THOR CALl NPAT GR THOR VALUE 9.602 3.783 -999.250 10.906 9.883 3.318 -999.250 7.191 9.289 3.564 -999.250 7.047 9.477 3.180 -999.250 8.945 9.117 3.473 -999.250 6.316 9.648 3.342 -999.250 9.188 9.391 2.824 -999.250 5.094 9.734 3.461 -999.250 3.244 9.211 3.516 -999.750 8.672 9.45~3 3. ?70 -999.250 4.703 9.047 3.693 -999.250 6.730 DEPTH tqNE.MQNIC VALUE -MNFMONIC VALUE 3400.000 ILD DRHO NCNL DT 8.742 iLM 8.375 -0.005 NPHI 42-383 2038.000 FCNL 538,500 134,375 POTA O.011 3300.000 iLD DRHO NCNL DT 7.402 -0,006 1910.000 165.000 ILM 7.418 NPHI 47 217 FCNL 490[000 PUTA 0.O08 3200.000 ILD DRHO NCNL DT 3 ! 00. 000 ILD DRHO NCNL DT 7.586 ILM 7.207 -0 004 NPHI 43,164 2128~000 FCNL ' 56IIO00 ~28.500 POTA 0.020 ~000.000 ILD .8 ·086 ILM DRHO 0-007 NPHI NCNL 1927 000 FCNL 479,750 DT 128~750 POTA 0iOi3 2900.000 ~ ILD DRHO NCNL DT 6.043 ILM 6'39I -0.001 NPHI 45.313 15'79,000 FCNL 382;250 0.014 2~00.000 ILD DRHO NCNL DT .10q ILM 5.699 ~.602 NPHI 55-713 1675 000 FCNL 342.500 141~000 POTA 0~018 2760.000 It, D -999.250 ILM '999.250 DRHO 2999 250 NPHI -9~925 000 NCNL ,,.q99~250' FONL ..... 999:250 DT -999. 250 POTA -999. ~50 MNEMONIC GR RHOB ORAN GR SGR URAN GR RHQB SGR ORAN GR HHOB URAN SGR ORAN GR RHOB URAN GR RHOB 8GR ORAN GR RHOB ORAN VALU 42. 2. 38. 1. 31. 2. 25. 0. 32. 2. 31. 0. 55. 2. 42. 0. 52. 2. 45. 1. 54. 2. 44. 2. 62. 2. 50. 1. -999. -999· -999. -999. 750 092 938 768 734 045 703 947 344 133 969 783 188 111 625 754 188 090 281 558 625 107 781 248 781 176 7lq 500 250 250 250 250 MNEMON lC CA6I NRAT GR THOR CALl NRAT GR T H [) R CAbI NRAT G~ THOR CALl NRAT GR THOR CAbI NRAT GR THOR CALl MRAT GR THOR CALI NRAT GR THOR CALl NRAT GR THOR VALI] · 3. -999. 5. · 3. -999. 4. · 3. -999. 6. · 3. -999. 5. · 3. -999. 6. · 3. -999. 5. 10. 4. -999. -999 -999 -999 -999 03 48 2.5 96 32 77 25 46 11 52 25 23 42 55 61 53 57 25 73 94 72 25 59 50 34 25 96 25 25 25 25 DATA NUMBER, ~JF RECUR. DS: 718 LENGTH OF RECORDS: 958 BYTES LENGTH (IF LAST RECURD: 210 BruTES FILE TRAILER LENGTH: 62 BYTES FILE NAME: EDIT .001 MAXIMBM PHYSICAL RECURD LENGTH: NEXT FI[dE NAME: 1024 BYTES EOF TAPE TPAILER LENGTH: 132 BYTES TAPE NAME: 61427 SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: NEXT TAPE NAME: CF]MMENTS: DATE: 81/ 4/ 7