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Home My WebLink About189-025Originated: Delivered to:17-Jan-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 3B-04 50-029-21323-00 909740412 Kuparuk River Plug Setting Record Field- Final 3-Jan-25 0 12 3H-21 50-103-20094-00 909740216 Kuparuk River Multi Finger Caliper Field & Processed 5-Jan-25 0 13 3H-21 50-103-20094-00 909740216 Kuparuk River Plug Setting Record Field- Final 6-Jan-25 0 14 3H-33A 50-103-20578-01 909740217 Kuparuk River Plug Setting Record Field- Final 29-Dec-24 0 15 3I-13 50-029-21923-00 909619504 Kuparuk River Packer Setting Record Field- Final 2-Nov-24 0 16 3I-13 50-029-21923-00 909619504 Kuparuk River Packer Setting Record Field- Final 3-Nov-24 0 17 3K-24 50-029-22935-00 909619038 Kuparuk River Multi Finger Caliper Field & Processed 7-Nov-24 0 18 3K-24 50-029-22935-00 909619503 Kuparuk River Plug Setting Record Field- Final 30-Oct-24 0 19 3Q-14A 50-029-21665-01 909740219 Kuparuk River Leak Detect Log Field- Final 8-Dec-24 0 110 3Q-14A 50-029-21665-01 909740219 Kuparuk River Multi Finger Caliper Field & Processed 9-Dec-24 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T40008T40009T40009T40010T40011T40011T40012T40012185-061188-008209-103189-025198-249214-082T40013T400131/23/202553I-1350-029-21923-00909619504Kuparuk RiverPacker Setting RecordField- Final2-Nov-240163I-1350-029-21923-00909619504Kuparuk RiverPacker Setting RecordField- Final3-Nov-2401209 103189-025198 249Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.01.23 15:18:26 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Convert to PROD/Tubing Patch 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 7700'feet None feet true vertical 6475' feet None feet Effective Depth measured 7173' feet 5875', 5897', 7108', 7136', 7143' feet true vertical 6086'feet 5125', 5141', 6039', 6060', 6064' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 2-7/8" J-55 7208' MD 6112' TVD Packers and SSSV (type, measured and true vertical depth) 5875' MD 5897' MD 7108' MD 7136' MD 7143' MD 1791' MD 5125' TVD 5141' TVD 6039' TVD 6060' TVD 6064' TVD 1791' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 3523' 3382' Burst Collapse Production Liner 7650' Casing 6463'7683' 3488' 116'Conductor Surface Intermediate 16" 9-5/8" 80' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 189-025 50-029-21923-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025631 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3I-13 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) Producer- remains off line Gas-Mcf MD ~ Size 116' ~~~ INJECTOR ~~ ` 324-560 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: PIIP Patch Packer Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: AVA RHS Rtvbl Packer Packer: PIIP Patch Packer SSSV: Otis Series 10 TR SSSV Shelby Sumrall shelby.sumrall@conocophillips.com (907) 265-6678 Well Integrity Specialist 7335-7349', 7356-7390', 7400-7437' 6206-6216', 6222-6247', 6254-6281' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 2:37 pm, Nov 14, 2024 Digitally signed by Shelby Sumrall DN: OU=Alaska, O=Conocophillips, CN=Shelby Sumrall, E=Shelby.Sumrall@conocophillips.com Reason: I am the author of this document Location: Anchorage Alaska Date: 2024.11.14 12:35:14-09'00' Foxit PDF Editor Version: 13.0.0 Shelby Sumrall RBDMS JSB 032725 DSR-3/28/25JJL 4/9/25 DTTMSTART JOBTYP SUMMARYOPS 10/30/2024 ACQUIRE DATA 2.25" PUMP BAILER SAT DOWN @ ~7129' RKB' RECOVERD 30" COURSE SAND IN BAILER...IN PROGRESS 10/31/2024 ACQUIRE DATA BAILED FILL FROM 7138' RKB TO 7173' RKB, PULLED CA-2 EQUALIZE PRONG @ 7136' RKB....IN PROGRESS 11/1/2024 ACQUIRE DATA PULLED CA-2 PLUG BODY FROM 7173' RKB, B&F TBG AT PATCH DEPTHS W/ 40 BBLS HOT DIESEL, TROUBESHOOT T x IA COMMUNICATION.....IN PROGRESS 11/2/2024 ACQUIRE DATA DRIFTED CLEAN W/ 2.29" DMY PACKER DRIFT TO 2.25" NIPPLE @ 7173' RKB, SET LOWER 2-7/8 P2P MID ELEMENT @ 7145' RKB (CPP287093), PASSING 2650 PSI CMIT TxIA, DRIFTED CLEAN WITH 2.29" x 32' DMY UPPER PATCH DRIFT... IN PROGRESS 11/3/2024 ACQUIRE DATA SET UPPER 2.29" P2P PATCH SECTION @7111' RKB, (ser# CPP287050, CPTJ228008, CPAL287064, CP287093), (LIH=27.39) PASSING 2500 PSI T x IA CMIT, SET LOWER 2.29" P2P PACKER @ 5899' RKB (ser#CPP287090) (LIH=3.55').....IN PROGRESS 11/7/2024 ACQUIRE DATA STAND BY FOR SNOW REMOVAL, STAGE EQUIPMENT FOR JOB IN AM. IN PROGRESS. 11/8/2024 ACQUIRE DATA SET 2 7/8 TTS TEST TOOL IN 2.29" LOWER P2P @ 5896' RKB CMIT TBG x IA 2500 PSI (PASS), PULLED 2 7/8 TTS TEST TOOL @ 5896' RKB, SET UPPER 2.29" P2P SPACER ANCHOR LATCH @ 5877' RKB (CE) TOP @ 5874.86' RKB (SN: CPP287092 / CPAL287062), MIT IA 3000 PSI (PASS). JOB COMPLETE 3I-13 Tubing Patch Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,416.0 3I-13 12/28/2018 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Tbg Patches 3I-13 11/8/2024 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 1/1/2010 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 116.0 116.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 35.0 3,523.5 3,382.1 36.00 J-55 BTC PRODUCTION 7 6.28 33.0 7,682.6 6,462.8 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 31.0 Set Depth … 7,208.0 Set Depth … 6,112.3 String Max No… 2 7/8 Tubing Description TUBING Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE8rdABM OD ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.0 31.0 0.19 HANGER 8.100 2 7/8" FMC Tubing Hanger w/ Pup jt FMC 2.441 1,791.5 1,790.9 2.36 SAFETY VLV 4.760 2 7/8" OTIS Series 10 TR SSSV Otis Series 10 2.313 3,285.0 3,199.4 36.91 GAS LIFT 4.750 2 7/8" MERLA TMPD GLM w/ 1" DV w/ BK2 latch Merla TMPD 2.375 7,075.4 6,014.5 42.36 GAS LIFT 5.460 2 7/8" MERLA TGPD GLM w/ 1 1/2" AVA CV w/ TG latch Merla TGPD 2.375 7,121.9 6,048.8 42.45 PBR 4.750 AVA PBR w/ Hydraulic release AVA 2.312 7,136.5 6,059.6 42.49 PACKER 6.151 7" x 2 7/8" AVA RHS RETV Pkr pinned for 60 M LBS AVA RHS 2.347 7,173.3 6,086.7 42.58 NIPPLE 3.670 2 7/8" CAMCO 'D' Nipple w/ 2.250" Profile ID Camco D 2.250 7,207.4 6,111.8 42.62 SOS 3.750 2 7/8" AVA Shear Out Sub AVA 2.441 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) 5,874.9 5,124.9 43.37 PACKER - PATCH - UPR 2.29" PIIP UPPER PACKER MID-ELEMENT AT 5877' RKB WITH ANCHOR LATCH & SPACER PIPE, OAL = 22.04' TTS PIIP CPP2 87092 11/8/2024 1.375 5,878.1 5,127.3 43.33 SPACER PIPE 2-1/16" P-110 SPACER PIPE WITH ANCHOR LATCH CPAL 28706 2 11/8/2024 1.375 5,888.0 5,134.5 43.22 LEAK - TUBING TBG LEAK IDENTIFIED BY LDL AT 5888' RKB 6/25/2023 2.441 5,896.9 5,140.9 43.12 PACKER - PATCH - LWR 2.29" PIIP LOWER PACKER, MOE = 5899' RKB, OAL = 3.55' TTS PIIP CPP2 87090 11/3/2024 1.375 7,108.4 6,038.9 42.42 PACKER - PATCH - UPR 2.29" PIIP UPPER PACKER ASSEMBLY MID-ELEMENT AT 7110.54' RKB WITH ANCHOR LATCH & SPACER PIPE W/ EXPANSION JNT, OAL = 34.46 TTS PIIP CPP2 87050 11/3/2024 1.375 7,112.0 6,041.5 42.43 ANCHOR LATCH ON SPACER PIPE ANCHOR LATCH, SPACER- PIPE W/ EXPANSION JNT CPAL 28706 4, CPTJ 22800 8 11/3/2024 1.380 7,142.9 6,064.3 42.51 PACKER - PATCH - LWR 2.29" PIIP LOWER PACKER W/ W-LEG, MOE = 7145', OAL = 3.55' TTS PIIP CPP2 87093 11/2/2024 1.375 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,285.0 3,199.4 36.91 1 GAS LIFT DMY BK 1 0.0 2/10/1990 0.000 7,075.4 6,014.5 42.36 2 GAS LIFT DMY RK WI Pkg 1 1/2 0.0 10/22/1997 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,335.0 7,349.0 6,206.1 6,216.4 A-3, 3I-13 11/9/1989 6.0 APERF Zero deg. phasing 7,356.0 7,390.0 6,221.6 6,246.8 A-2, 3I-13 11/9/1989 6.0 APERF 2 1/8" SIlver Jet; deg. ph 7,400.0 7,437.0 6,254.2 6,281.5 A-1, 3I-13 5/19/1989 6.0 IPERF 90 deg. ph; SOS 4.5" HSD 3I-13, 11/14/2024 7:16:56 AM Vertical schematic (actual) PRODUCTION; 33.0-7,682.6 FLOAT SHOE; 7,680.7-7,682.6 IPERF; 7,400.0-7,437.0 APERF; 7,356.0-7,390.0 APERF; 7,335.0-7,349.0 SOS; 7,207.4 NIPPLE; 7,173.3 PACKER - PATCH - LWR; 7,142.9 PACKER; 7,136.5 PBR; 7,121.9 ANCHOR LATCH ON SPACER PIPE; 7,112.0 PACKER - PATCH - UPR; 7,108.4 GAS LIFT; 7,075.4 PACKER - PATCH - LWR; 5,896.9 LEAK - TUBING; 5,888.0 SPACER PIPE; 5,878.1 PACKER - PATCH - UPR; 5,874.9 SURFACE; 35.0-3,523.5 FLOAT SHOE; 3,521.7-3,523.5 GAS LIFT; 3,285.0 SAFETY VLV; 1,791.5 CONDUCTOR; 36.0-116.0 HANGER; 35.0-39.2 HANGER; 31.0 KUP PROD KB-Grd (ft) 35.91 RR Date 3/19/1989 Other Elev… 3I-13 ... TD Act Btm (ftKB) 7,708.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292192300 Wellbore Status PROD Max Angle & MD Incl (°) 44.22 MD (ftKB) 5,800.00 WELLNAME WELLBORE3I-13 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP 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 Other: Convert WINJ to PROD, Tubing Patches 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?N/A KRU 3I-13 Yes No 9. Property Designation (Lease Number):10. Field: KRU Kuparuk River Oil Kuparuk River Oil 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7700 6475 7173 6086 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:Shelby Sumrall Contact Email: Contact Phone: 907-265-6678 Authorized Title: Well Integrity Specialist 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 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: Length AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 7136 MD/ 6060 TVD & 1791 MD/ 1791 TVD Shelby.Sumrall@conocophillips.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025631 189-025 P.O. Box 1000360, Anchorage, Alaska 99510 50-029-21923-00-00 ConocoPhillips Alaska, Inc Size Proposed Pools: PRESENT WELL CONDITION SUMMARY TVD Burst 7208 MD 116 3382 116 3523 64637683 16 9.625 80 3488 7335-7437 7650 6206-6282 7 Perforation Depth TVD (ft): 10/10/2024 2.875 Packer: AVA RHS RETV Packer SSSV: Otis Series 10 TR SSSV Perforation Depth MD (ft): J-55 m n P 1 6 5 6 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Shelby Sumrall DN: OU=Alaska, O=Conocophillips, CN=Shelby Sumrall, E= Shelby.Sumrall@conocophillips.com Reason: I am the author of this document Location: Anchorage Alaska Date: 2024.09.27 11:59:24-08'00' Foxit PDF Editor Version: 13.0.0 Shelby Sumrall 324-560 By Grace Christianson at 12:48 pm, Sep 27, 2024 10-404 SFD 10/4/2024 Convert WINJ to PRODC DSR-9/27/24VTL 10/21/2024*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.10.21 11:34:09 -08'00'10/21/24 RBDMS JSB 102224 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 27, 2024 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 3I-13 (PTD 189-025) to convert injector to producer and set two retrievable tubing patches to allow the well to be used for an extended flowback. If you need additional information, please contact us at 265-6678. Sincerely, Shelby Sumrall Well Integrity Specialist ConocoPhillips Alaska, Inc. Well Work JusƟĮcaƟon & ObjecƟves (and date required if appropriate): 3I-13 is a LTSI well that has been shut in since February 7, 2020. The IAP increased above DNE on January 4, 2023 aŌer which Slickline secured the well with a CA-2 plug. A CMIT TxIA passed and a TxIA LLR of 14 GPM at ~2100 psi was acquired. A LDL and caliper was run June 26, 2023, idenƟfying a tubing leak at 5888' RKB and a suspect PBR leak at 7130' RKB. Since that Ɵme a review for a potenƟal RST of 3I-11A has taken place and determined the downhole pressure makes the project un-drillable. The overall plan is to convert oīset injector (3I-13) to producƟon for an extended Ňowback (18-24 months) to de-pressure the formaƟon to acceptable pressures for drilling. The objecƟve of this WWR is to patch the suspect PBR leak at 7130' RKB and the known tubing leak at 5888' RKB to repair the T x IA in preparaƟon for the extended Ňowback. Risks/Job Concerns (Include DriŌ informaƟon on high deviaƟon wells, or wells with tag issues): Need approved 10-403 from AOGCC prior to work 2.875" tubing string Passed CMIT to 3000 psi on 1/7/23 Suspect leak at PBR LDL idenƟĮed tubing leak at 5888' RKB LDL sat down at 7163' RKB (~10' above CA-2 plug) on 6/25/23 Steps(Author: please include SSSV notes and note any future work required to capture rate beneĮt listed above (include esƟmated days/units in cost)): Relay or Slickline/Eline 1. RIH to pull CA-2 plug at 7173' RKB. 2. RIH to brush and Ňush patch seƫng areas around 5877' - 5899' & 7115' - 7145' RKB. 3. DriŌ tubing down to ~7150' RKB with dummy patch 2.29" OD x 34' OAL. 4. RIH with lower P2P and set mid element at 7145' RKB. 5. SƟng into lower P2P with test tool and perform CMIT TxIA to 2500 psi. Record pre, iniƟal, 15 min & 30 min TIO's. Pull test tool. 6. RIH with upper patch assembly and sƟng into anchor latch. The patch should be 30' element to element seƫng the upper P2P at 7115' RKB. 7. SƟng into upper P2P with test tool and perform CMIT T x IA to 2500 psi. Record pre, iniƟal, 15 min & 30 min TIO's. Pull test tool. 8. RIH with lower P2P and set mid element at 5899' RKB. 9. SƟng into lower P2P with test tool and perform CMIT TxIA to 2500 psi. Record pre, iniƟal, 15 min & 30 min TIO's. Pull test tool. 10. RIH with upper patch assembly and sƟng into anchor latch. The patch should be 22' element to element seƫng the upper P2P at 5877' RKB. 11. Perform MIT-IA to 2500 psi (Good to go up to 3000 psi on MITIA if needed to achieve 500 psi DP with tubing during test). Record pre, iniƟal, 15 min & 30 min TIO's. 12. RDMO, turn well over to OperaƟons to be BOL for extended Ňowback. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,416.0 3I-13 12/28/2018 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Annotate Tbg Leak 3I-13 6/25/2023 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 1/1/2010 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 116.0 116.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 35.0 3,523.5 3,382.1 36.00 J-55 BTC PRODUCTION 7 6.28 33.0 7,682.6 6,462.8 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 31.0 Set Depth … 7,208.0 Set Depth … 6,112.3 String Ma… 2 7/8 Tubing Description TUBING Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE8rdABMO D ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.0 31.0 0.19 HANGER 8.100 2 7/8" FMC Tubing Hanger w/ Pup jt FMC 2.441 1,791.5 1,790.9 2.36 SAFETY VLV 4.760 2 7/8" OTIS Series 10 TR SSSV Otis Series 10 2.313 3,285.0 3,199.4 36.91 GAS LIFT 4.750 2 7/8" MERLA TMPD GLM w/ 1" DV w/ BK2 latch Merla TMPD 2.375 7,075.4 6,014.5 42.36 GAS LIFT 5.460 2 7/8" MERLA TGPD GLM w/ 1 1/2" AVA CV w/ TG latch Merla TGPD 2.375 7,121.9 6,048.8 42.45 PBR 4.750 AVA PBR w/ Hydraulic release AVA 2.312 7,136.5 6,059.6 42.49 PACKER 6.151 7" x 2 7/8" AVA RHS RETV Pkr pinned for 60 M LBS AVA RHS 2.347 7,173.3 6,086.7 42.58 NIPPLE 3.670 2 7/8" CAMCO 'D' Nipple w/ 2.250" Profile ID Camco D 2.250 7,207.4 6,111.8 42.62 SOS 3.750 2 7/8" AVA Shear Out Sub AVA 2.441 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) 5,888.0 5,134.5 43.22 LEAK - TUBING TBG LEAK IDENTIFIED BY LDL AT 5888' RKB 6/25/2023 2.441 7,173.0 6,086.5 42.58 TUBING PLUG 2.25" CA-2 Plug Camco CA-2 1/7/2023 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) 3,285.0 3,199.4 36.91 1 GAS LIFT DMY BK 1 0.0 2/10/1990 0.000 7,075.4 6,014.5 42.36 2 GAS LIFT DMY RK WI Pkg 1 1/2 0.0 10/22/1997 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,335.0 7,349.0 6,206.1 6,216.4 A-3, 3I-13 11/9/1989 6.0 APERF Zero deg. phasing 7,356.0 7,390.0 6,221.6 6,246.8 A-2, 3I-13 11/9/1989 6.0 APERF 2 1/8" SIlver Jet; deg. ph 7,400.0 7,437.0 6,254.2 6,281.5 A-1, 3I-13 5/19/1989 6.0 IPERF 90 deg. ph; SOS 4.5" HSD 3I-13, 6/25/2023 4:49:20 PM Vertical schematic (actual) PRODUCTION; 33.0-7,682.6 FLOAT SHOE; 7,680.7-7,682.6 IPERF; 7,400.0-7,437.0 APERF; 7,356.0-7,390.0 APERF; 7,335.0-7,349.0 SOS; 7,207.4 NIPPLE; 7,173.3 TUBING PLUG; 7,173.0 PACKER; 7,136.5 PBR; 7,121.9 GAS LIFT; 7,075.4 LEAK - TUBING; 5,888.0 SURFACE; 35.0-3,523.5 FLOAT SHOE; 3,521.7-3,523.5 GAS LIFT; 3,285.0 SAFETY VLV; 1,791.5 CONDUCTOR; 36.0-116.0 HANGER; 35.0-39.2 HANGER; 31.0 KUP INJ KB-Grd (ft) 35.91 RR Date 3/19/1989 Other Elev… 3I-13 ... TD Act Btm (ftKB) 7,708.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292192300 Wellbore Status INJ Max Angle & MD Incl (°) 44.22 MD (ftKB) 5,800.00 WELLNAME WELLBORE3I-13 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 3I-13 (PTD 189-025) Report of suspect IA pressure increase Date:Tuesday, January 10, 2023 9:03:36 AM Attachments:AnnComm Surveillance TIO for 3I-13.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Wednesday, January 4, 2023 7:46 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3I-13 (PTD 189-025) Report of suspect IA pressure increase Chris, KRU 3I-13 (PTD 189-025) was reported by Operations to have a suspect IA pressure increase yesterday. The well has been shut in since Feb 2, 2020. The plan is to set a tubing plug and perform initial diagnostics after which a plan will be formulated. Any required paperwork for continued injection or corrective action will be submitted once a plan forward has been determined. A 90 day TIO trend and wellbore schematic are attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 (isd) ainssaid d d d 4 4 [0�75W Ja Od9} ale'd ba -i D -E ZOZ TC -1 D -E Z0Z 6Z-Zi-zzaZ 9Z-Zi-ZZOZ £Z-Zi-zzcz aZ-Zi-zzaZ LI-Z11-ZZaZ tri-Zi-zzaZ TI-ZZ-zzaz 80-zT-ZZOZ 5a-Zi-zzaZ Za-ZS-zzaZ 6Z-ii-ZZOZ 9Z-ii-zzOZ £Z-ii-ZZOZ az-ti-zzaz S Ll-ii-zzaZ bT-i�-zzOZ il-ii-ZZOZ 9a-Si-ZZOZ SQ-ii-ZZOZ za-Ell -zzOZ a�-Di-ZZOZ LZ-Di-ZZOZ bZ-DiZZOZ TZ-DS-ZZOZ 9l-DZ-zzaZ Si-Di-zZOZ ZT-Di-zzaZ 60-Di-zZOZ 9O-Di-ZZOZ 3I-13 90 -Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING /t-\ KUP INA) WELLNIAME 31-13 WELLBORE 31-13 ConocciPhillips Alaska, Inc. TD Well Attributed; Max AnMD mKB' F,eIE Name WNIbpa APIIUWI WeIIWre sam" 7,125 5,800, 0 Act B1m (IIKB) KUPARUK RIVER UNIT 500292192300 INJ 4.22 5,800.00 Comment No's (ppm) DRe Annommon End Data KB,3MNo IISV:TRDP Last WO: 35.91 Rq Susanne, Ga@ T1911989 N-13, 11Y18/A1680n TAM Last Tag Vneal"hamme, lacing Annotation DeptblM(BI End Data Wellbore Lad Shear By .......... ........... HANGER: 310— CO NDUCTOR: 99.0.1180 SAFETY VW; 1.791.6 GAS LIFT: a,2as.a SURFACE', 35.03,5Z1.5� GAS LIFT; .W5.4 PeR'. ).1as PA`KEN'TIM,5 NIPPLE', 7,1733- 17]3505:7.2oz4 505. 7.2N.4 APERF', 7,Ar6 oV73a80— APERF,],WLRRaa00� IPERF',),4C0.0-743T.0� PRODUCTION. 3SLV7a6La _.... Last Tag: RKB ],418.0 1212812018 31-13 leugusp Last Rev Reason Ammonium Entl Dale WNlhore tvt Mctl By Rev Reason: Tag 12128121118 31-13 tOrgusp Casing Strings Casing Deacrlptlm OD llnl ID ll nl Top duard SO Depla(IIKB) Srt D"RVDI... wuLen (I... Gra it Top Tareatl CONDUCTOR 16 1506 36.0 116.0 1160 62.50 A WELDED Co.... De—ipticn OD pre ID on) I Top HNKB) I Said De"'3Dept"V.' IMLen(I... Oraae Tap Thread N`N-' G3. SURFACE 9518 883 35.0 3,523.5 3,382.1 36.00 J-55 BTC Caama.—ipliamOD ord ID and Top(M(61 Set Depth HNNBl art DapM(TVDI... Apan(I... Grade Top Theme! PRODUCTION ] 6.28 33.0 ],682.6 6,462.8 26.00 J-55 BTC Tubing Strings Tubing DescNptian RUIng Ma... ID (nl Top (BKBI Srt"Im IS- Sem Depth (... Wtged) Grade TOPConnMbn TUBING 2]18 2.44 31.0 ],208.0 6,112.3 6.50 J-55 EUE8rdABMOD Completion Details Top Me) Top Incl Nominal 1,(IIKBI 11MBl (•I pan, Dea com ID(In) 31.0 31.0 0.19 HANGER 2]18" FMC Tubing Hanger wl Pup jt 2.441 1,791.5 1,790.9 2.36 SAFETYVLV 27dE OTIS Series lO TR SSSV 2.313 7,121.9 6,048.8 42.45 PBR AVA PBR wl Hydraulic release 2.312 ],136.5 8,059.8 42.49 PACKER T'x2]18" AVA RHS HEW Par pinned for 60 M LBS 2.347 71]3.3 6,086.7 42.58 NIPPLE 2]18" CAMCO'D'Nipple wl 2.250'Profile ID 2.250 ),20).4 6,111A 42,62 SOS 2718-AVA Shear Out Sub 2.441 Perforations & Slots snw Deno Tap ITV D) Burn(TV (.I.Top IRKS) BIm nIKB) VKB) (IIKB) fink. Zona Dab ) Type Com ],3350 ],349.0 6,208.1 6,218.4 A-3,31-13 111911989 6.0 APERF Zero deg. phasing ],356.0 ],390.0 6,221.6 6,246.8 A-2,31-13 1VW1989 6.0 APERF 2118"SINer Jet: deg. pA ),400.0 ),43).0 6,254.2 6,281.5 A-1, 31-13 5/1911989 6.0 (PERF 90 deg. ph. 505 4.5- HID Mandrel Inserts at all N Top(ND) Varye Lurch POR Sixe TRO Run Toppron IBKB) Mane Madtl OD(m) Sery Type lin) (Wi)LRD- T'P. C13,285.0 3,199.4 Meda TMPD 1 GASLIR DMY BK 0.000 0.02 ),0]5.4 6,014.5 Metla TGPD 1112 GAI LIR DMY RK 0.000 0.0) W Pkg Notes: General & Safety End Data Annolatlan 111/2010 NOTE: VIEW SCHEMATIC wlAlaska Schematic9G MEMORANDUM State of Alaska Inspection Date: 9/16/2019 Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday, October 9, 2019 P.I. Supervisor /?1-/m' (�`jj %15 SUBJECT: Mechanical Integrity Tests / ConocoPhillips Alaska, Inc. 31-13 31-13 FROM: Jett' Jones KUPARUK RIV UNIT 3I-13 Petroleum Inspector 2750 - Src: Inspector 2750 Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 31-13 API Well Number 50-029-21923-00,00 Inspector Name: Jeff Jones Permit Number: 189-025-0 Inspection Date: 9/16/2019 Insp Num: miU]I91009081602 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 31-13 Type Inj W TVD 6059 'Tubing 2750 - 2750 - 2750 �- 27550' PTD a9ozso -Type Test SPT Test psi 55155 IA sao z000 - 1900 -' laso BBL Pumped: 1.9 - BBL Returned: 1.6 OA 510 baa W - 640 - Interval avRTST p/p P Notes- l well inspected, no exceptions noted. Wednesday, October 9, 2019 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,July 08,2015 TO: Jim Regg {� P.I.Supervisor \ 7 71 41 I S SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3I-13 FROM: John Crisp KUPARUK RIV UNIT 31-13 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry (S� NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 31-13 API Well Number 50-029-21923-00-00 Inspector Name: John Crisp Permit Number: 189-025-0 Inspection Date: 7/3/2015 Insp Num: mitJCr150707104451 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well! 3113 Type Inj ,FW-TVD 6059 - Tubing 2850 - 2850 2850 ! 2850 . PTD 1890250 Type Test!SPT Test psi 1515 IA 770 I 2100 2070 " 2065 " Interval 4YRTST —P/F P I OA 200 320 -- 320 320 - Notes: 2 3 bbls pumped for test SCANNED Wednesday,July 08,2015 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 19, 2011 P.I. Supervisor ` TO: Jim Rp , t J SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3I -13 FROM: John Crisp KUPARUK RIV UNIT 3I -13 Petroleum Inspector Src: Inspector Reviewed By P.I. Supry Jae-- - NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 31 -13 API Well Number: 50- 029 - 21923 -00 -00 Inspector Name: John Crisp Insp Num: mitJCr110717145542 Permit Number: 189 -025 -0 Inspection Date: 7/16/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min._ Well 31 -13 p • Inj. I TVD 6059 ° - IA 14 3230 - 3101 3065 3056 ' P.T.D1 1890250 • 1TypeTest SPT L Test psi 1514 • OA 520 920 920 910 910 Interval P/F P - Tubing 2860 2850 2850 2850 2850 Notes: 3.8 bbls pumped for test. Test witnessed for 45 minutes because test gauges still on the well before annulus bleed. k C, Tuesday, July 19, 2011 Page 1 of 1 ConocoPhillips ~as~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 17, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 • ', ~ ~; ,. ~~%. ~Y ~ a ti. ~ ~~ ~ ~ 1' ~ e r~~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped Apri17~' , 2009. The corrosion inhibitor/sealant was pumped April 15~' and 16~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 4/17/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 31-01 185-307 58' 10.10 4' 1" 4/7/2009 4.40 4/15/2009 31-03 185-309 69 '8" 10.20 4' 3" 4/7/2009 8.50 4/15/2009 31-04 185-310 26' 4" 4.10 2' 4R/2009 3.40 4/15/2009 31-05 186-036 76' 12.70 3' 6" 4/7/2009 8.50 4/15/2009 31-08 186-040 8' 6" 1.20 1' 9" 4/7/2009 3.40 4/15/2009 31-09 186-055 40' 5.10 1' 9" 4/7/2009 3.40 4/15/2009 31-11 189-035 1' 9" N/A N/A N/A 2.60 4/16/2009 31-12 186-060 44' 6.80 1' 11" 4/7/2009 2.60 4/16/2009 31-13 189-025 SF N/A N/A N/A 2.50 4/16/2009 31-14 186-062 77' 11.30 2' 11" 4/7/2009 8.50 4/16/2009 31-16 189-022 24' 3.54 1' 7" 4/7/2009 2.30 4/16/2009 31-17 189-024 37' 3.64 1' 7" 4/7/2009 2.00 4/16/2009 . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk / KRU /31 07/31/07 Greenwood/lves/ Bates Chuck Scheve - ( Waived) - Fog and rig move \iÖ q' O;1-b Packer Depth Pretest Initial 15 Min. 30 Min. Well!3I-02 I Type Inj. I W TVD I 6,228' TubinQ 2770 2770 2770 2770 Interval I 4 P.T.D.!1853080 I Type test I P Test psil 1557 Casino 925 2020 2010 2010 P/FI P Notes: OA 190 210 210 210 Well 131-06 I Type Ini.1 W TVD I 6,064' TubinQ 2700 2700 2700 2700 I nterval 4 P.T.D.!1890380 I Typetestl P Test psil 1516 Casing 790 2060 2000 1990 P/FI P Notes: OA 680 840 840 840 Well!3I-07 I Type In¡.1 W TVD I 6,119' Tubing 2900 2900 2900 2900 I nterval 4 P.T.D.!1860390 I Typetestl P Test psi I 1529. 75 Casino 100 2050 2010 2000 P/FI P Notes: OA 400 500 500 500 Well 131-09 Type Ini.1 N TVD I 6,156' TubinQ 2330 2350 2350 2350 I nterval 4 P.T.D.!1860550 I Typetestl P Test psi I 1539 Casing 830 1880 1870 1870 P/FI P Notes: S/I for pressure management OA 200 230 230 230 Well!3I-12 I Type Ini.1 W TVD I 5,031' Tubino 2650 2650 2650 2650 I ntervall 4 P.T.D.!1860600 I Type testl P Test psi I 1500 Casing 775 2030 2020 2020 P/FI P Notes: OA 210 230 230 230 We1l131-13 I Type Ini.1 W TVD I 6,059' Tubing 2670 2670 2670 2670 Interval I 4 P.T.D.!1890250 I Type test I P Test psi11514.75 Casing 1160 2080 2030 2025 P/FI P Notes: OA 780 890 880 880 Welll3l-14 I Type Ini.1 W TVD I 6,092' Tubino 2570 2560 2560 2560 Interval 4 P.T.D.!1860620 I Typetestl P Test psil 1523 Casing 820 2060 2030 2020 P/FI P Notes: OA 90 150 150 150 welll3l-16 I Type Ini.1 W TVD I 5,940' Tubing 2900 2900 2900 2900 Interval 4 P .T.D.!1 890220 I Type test \ P Test psil 1500 Casing 700 1920 1860 1920 P/FI P Notes: OA 460 620 620 620 D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1105 M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer sU1SCANNEDA U G 0 6 2007 A = Temperature Anomaly Survey D = Differential Temperature Test I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= other (describe in notes) ..« ~... !.u..· ...:. 2007-0731_MIT _KRU_31-16.xls MEMORANDtJM State of Alaska Alaska Oil and Ga~ Conservation Commission TO: Jim Regg P.I. Supervisor -;' ~ 711 '?I {iI, N1/¡ ()A TE: Wednesday. July l-t, 200..¡ SlIBJECT: t-.1echanlcallnlegrlty Tests CONOCOPHILLlPS ALASK.A TNC 31-13 FROM: Lou Grimaldi Petroleum Inspector KUPARUK RIV UNIT 31-13 Src: Inspector Re\'iewed By: P.I. Suprv -.--TIß-- Comm NON-CONFIDENTIAL \Vell Name: KUPARUK RIV UNIT 31-13 Insp Num: mitLGO"¡071312362"¡ Rei Insp Num: API 'Veil Number: 50-0~9-~1923-00-00 Permit Number: 189-025-0 Inspector Name: Lou Grimaldi Inspection Date: 7/13/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. \Ve II 31-13 Type Inj. p I TV]) I 6475 1.-\ 700 17~0 1665 ]650 I P.T. 1890~50 TypeTest SPT I Test psi I 151-1.75 0:\ 5~O 650 640 6-10 Interval -1YRTST PfF p Tubing ~900 ~900 ~9(10 2900 Notes: Good test. no problems. Wednesday, July 14,2004 Page I of I MEMORANDUM TO: THRU: FROM: Dan Seamount CommiSsioner Blair Wondzell ~.~ P.I. Supervisor ~.(~, Jeff Jones. v' ~ ~- Petroleum InspectOr State of Alaska Alaska Oil and Gas Conservation Commission DATE: Sept. 1,2000 SUBJECT: Mechanical Integrity Tests Phillips Alaska Inc. 31 Pad 31-02, 31-06, 31-07, 31-09, 31-12, 31-13, 31-14, 31-16 KRUIKuparuk River Field NON- CONFIDENTIAL WellJ 31-02 P.T.D.J 1853080 Notes: Well J 31-06 P.T.D.J 1890380 P 1860390 Notes: WellJ 31-09 P.T.D.J 1860550 Notes: We, J 31-12 P,T.D. J 1860600 Notes: WellJ 31-13 P.T.D. J 1890250 Notes: WellJ 31-14 P.T.D.J 1860620 Notes: WellJ 31'16 P.T.D.J 1890720 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. JType~nj.J SI T.V.D. J 6228 JTubingJ 2920J 2920J 2920J 2920 J lntervalJ 4 TypetestJ. P. JTestpsiJ 1557 J CasingJ .lOOO i 181o I 181o I 18oo I P/F I P JTypelnj. J' S J T.V.D. I ~0~ IT"~Jngl 2~00 I 2~00l 2g00l 2~00 J~nterva~J 4 TypetestJ P JTestpsiJ 1516 J CasingJ 980 1184o118oo1179o1 P/F J P JTypelnj. J S J T.V.D. J 6119 J TubingJ 2850 J 2850 J 2850 J 2850 JlntervalJ 4 JTypetestJ P JTestpsiJ 1530 J casingJ 1180 J 1720 J 1700 J 1700 J P/F J P J Typelnj. J S J TiV. D:J 6156 JTubingJ 2850 J 2850J 2850J 2850 J lntervalJ 4 1 TypetestJ P JTestpsiJ 1539 J CasingJ 1050 I 1800 I 1790 I 1785I PIE J P · JTypelni.j .S JT'V'D' I S03~ J TubingJ 2880 J 2900J 2900J 2900 Jlntervall 4 ' JTyPetestJ P J TestpsiJ 1258 JcasingJ 76oI ~8~o I ~eso I ~85o I P/F J P JTypelnj. J S J T.V.D. J 6059 JTubingJ 2950J 2950J 295O J'2950 J~nterva~J 4 TyPetestJ P JTestpSiJ 1515 J CasingJ 700 I 1830 I 1790 I 1780 I P/F I P' J Type~ni.j S J T.V.D. I S092 ITubi"gl 2880J 2880I 2880I 2~80 I~nt~r~l 4 JTypetestJ P JTestpsiJ 1523 J CasingJ 1320 J 1640 J 1610 J 1610 J P/F J P J Typelnj. J N J T.V.D. J 5940 JTubingJ 1280 J 1280 J 128oj 1280 J lntervalJ 4' T~petestJ P JTestpsiJ 1485 J CasingJ 1200 J 1860 J 1740 J 1730 J P/F J P Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus MonitOdng 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 Vadance W-- Test during Workover O= Other (describe in notes) Test's Details Friday, Sept. l_a 2000: I traveled to Pltillips Alaska Inc.'s KRU 3I pad to wimcss the 4 year MIT's on wells # 02, 06, 07, 09, 12, 13, 14, 16. jerry Dethlefs was thc PlA rep. In charge of testing. The standard annulus pressure test was performed with all eight wells.passing the 30 minute pressure test. SUmmary.: I witnessed eight successful MIT's on PIA's KRU 3I Pad. .I.T.'s Performed: 8_ . Number of Failures: Attachments: Well schematics O Total Time dudng tests: 3 hrs cc'- MIT report form 5/12/00 L.G. MIT KRU 31 9-1-00 JJ.xls 9/5/00 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 24 2000 P M C:LORI'uMFILM. DOC E E L E W A T E R IA L U N D E TH IS M A R K ER R WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION SEPTEMBER 8, 1993 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 PAUL WHITE ARCO ALASKA INC. P O BOX 100360 ANCHORAGE, ALASKA 99510-0360 DEAR MR. WHITE, OUR FILES INDICATE THAT ARCO ALASKA INC. IS THE OPERATOR OF THE FOLLOWING WELLS MENTIONED IN THIS LETTER. WE ARE REVEIWING OUR WELL PRODUCTION FILES AND FOUND SOME WELL STATUS ARE INCORRECT AND THAT 404 SUNDRY WELL OPERATION FORMS ARE MISSING FROM OUR WELL FILES. SOME 403 (SUNDRY APPROVALS) HAVE BEEN APPROVED FOR WORK ON THESE WELLS AND OUR FILES DO NOT REFLECT THAT THE WORK WAS ACCOMPLISHED. · WOULD YOU PLEASE LOOK INTO THESE WELL SUNDRYS SO WE CAN CLOSE THEM OUT BY SUBMITTING THE APPROPRIATE 404 FORM WITH ATTACHMENTS FOR THE COMPLETED WORK. THESE WELLS CURRENTLY HAVE A STATUS OF, DEV 1-OIL, AND HAVE BEEN WATER INJECTORS OR WAGIN SINCE MAY 1993. WELLNAME PERMIT KUPARUK RIVER UNIT 2M-2 KUPARUK RIVER UNIT 2M-4 KUPARUK RIVER UNIT 2M-6 KUPARUK RIVER UNIT 2M-9 KUPARUK RIVER UNIT 2M-30 KUPARUK RIVER UNIT 31-13 92-0083 92-0093 92-0077 92-0079 92-0084 89-0025 I AM FORWARDING THIS LETTER AS A RECORD FOR YOU AND ME. THANKS FOR THE QUICK RESPONSE ON THESE REPORTS. SINCERELY, STEVE MCMAINS STATISTICAL TECHNICIAN STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate Plugging Perforate Repair well Pull tubing Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service LoCation of well at surface 115' FSL, 85' FEL, Sec. 36, T13N, R8E, UM At top of productive interval 1246' FNL, 1455' FWL, At effective depth 1373' FNL, 1268' FWL, At total depth 1410' FNL, 1215' FWL, Sec. 6, T12N, R9E, UM Sec. 6, T12N, R9E, UM Sec. 6, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) 76' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 31-13 9. Permit number/approval number 9-898 ~¢[ -zS 10. APl number 5o-029-21923 11. Field/Pool Kuparuk River Oil Pool 7700' feet Plugs (measured) None 6475' feet Effective depth: measured 7605' feet Junk (measured) None true vertical 6405' feet Casing Length Size Cemented Structural Conductor 80' I 6" 291 Sx CS II Surface 348 9' 9 - 5 / 8" 1085 Sx AS III & Intermediate 360 Sx Class "G" Production 7650' 7" 200 Sx Class "G" & Liner 175 Sx AS I Perforation depth: measured 7336'-7350', 7358'-7390', 7400'-7437' true vertical 6207'-621 7', 6223'-6247', 6254'-6282' Tubing (size, grade, and measured depth) 2 7/8", 6.5# J-55 AB mod. tubing with tail set @ 7208' MD Packers and SSSV (type and measured depth) Otis 10 TR SSSV @ 1791' MD; AVA RHS pkr @ 7136' MD Measured depth True vertical depth 115' 115' 3524' 3383' 7683' 6462' 13. Stimulation or cement squeeze summary convert well from oil producer to water injector Intervals treated (measured) ' ~i~ska .0il & Gas Cons, C0mmissio.rt Treatment description including volumes used and final pressure 14. Pressure Reoresentative Daily Average Production or Injection D~t~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Prior to well operation Subsequent to operation 315 553 0 1100 145 0 0 4000 1000 2300 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations Oil Gas Suspended 17. I hereb,~ certify that the foregoing is true and correct to the best of my knowledge. Signed'~'T i~ .~. ~/V~ Title Senior Operations Engineer Form 10-404 Rev 06/15/88 Service X SUBMIT IN DUPLICATE ,) ALASIA OIL/dB (aS COIIEI~TIIII CIlRJSlll Jommc~ _ _MEre, ,w usr ~FIoId · P ,- PIIJlXiC~ IIIJ~i IU CBI',/Irl mi" S~ ADDENDUM WELL 31-13 6/17/89 Frac Kuparuk "A" sand perfs 7400'-7437' @ 4 spf in eight stages as follows. Stage Stage Stage Stage Stage Stage Stage Stage Fluid to recover: Sand in zone: Sand in csg: Avg pressure: 1: Pmp 43 bbls 145 deg Diesel w/5% Musol @ 4-5 bpm 3270-3220 psi 2: Prop 150 bbls Gel Water (RXL40) prepad @ 12-20 bpm 6080-5010 psi 3:Pmp 900 bbls Gel Water pad @ 20-20.5 bbm 5480-4790 psi 4:Prop 37 bbls Gel Water w/2 ppg 20/40 Carbolite @ 20.5-20 bb14790-5070 psi 5:Pmp 34 bbls Gel Water w/4 ppg 20/40 Carbolite @ 20 bpm 5070-5360 psi 6: Prop 95 bbls Gel Water w/6 ppg 20/40 Carbolite @ 20-17.5 bpm 5360-6350 psi 7: Pmp 192 bbls Gel Water w/8 ppg 20/40 Carbolite @ 17.5-19-16.5 bpm 6350-6600-720( 8: Pmp 26 bbls Gel Water flush and 20 bbls Slick Diesel flush @ 16.5 bpm 7200-4670 1,497 bbls 96,300 lbs 805 lbs 5100 psi Drilling~Supervisor Date STATE OF ALASKA ~ AL~,~KA OIL AND GAS CONSERVATION CUlv,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~ GAS E~ SUSPENDED [~ ABANDONED E~ SERVICE r'~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 89-25 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-21923 4 Location of well at surface ~" ............ '1 9 Unit or Lease Name 115' FSL, 85' FEL, SEC 36, T13N, R8E UM -- - ~ '. Vi:,.:.i~:~) ~ KUPARUK RIVER UNIT At Top Producing ,n_t~erva{!M~ '~', ' ~'/~-~/~/o~' ~ i! SU r';i~ 10 Well Number 11 Field and Pool ~ 1410' FNL, ~ FWL, SEC~, T12N, ROE UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 76'I ADL: 25631 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 116 No. of Completions MARCH 13 1989 MARCH 18 1989 MAY 21 1989 NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set I 21 Thickness of permafrost 7700' MD & 6475' TVD 7605' MD & 6405' TVD YES [~ NO ~ 1791' feet MDI 1650' (approximate) 22 Type Electric or Other Logs Run DIL,SFL, GR,CAL,SP,FDC,CNL, CBL,GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 291 SX CS II 9 5/8" 36# J-55 SURF 3524' 12-3/4" 1085 SX AS III & 360 SX CLASS G 7" 26# J-55 SURF 7683' 8-1/2" 200 SX CLASS G & 175 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 IMD) 2-7/8", J-55 7208' 7136' 7400'-7437' MD, 4-1/2" W/4 SPF 6254' - 6281' TVD 7356'-7390' MD, 2-1/8" W/6 SPF 6221' - 6246' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 7335'-7349' MD, 2-1/8" W/6 SPF 6206' - 6216' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7400'- 7437' 96,300 lbs 20/40 CARBOLITE 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD =~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATI: ~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. - ~ . . .:., /, '' .~ . · /,; ; .',: .... Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, ME. AS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP KUPARUK C 7270' 6157' NA BOTTOM KUPARUK C 7298' 6178' TOP KUPARUK A 7322' 6196' BOTTOM KUPARUK A 7464' 6301' 31, LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~//~7~'~J .~ ~ Title AREA DRILLING ENGINEER Date 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 rlpl I I_,L. I I~/I~a= I= PlU'I May 8, 1989 Mr. Brit Brown Drilling Manager ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Boss Gyroscopic Survey Job No. AK-BO-90041 Well: 31-13 Field: Kuparuk Survey Date: April 17, 1989 Operator: T. McGuire Mr. Brown-. Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. As per A. Thompson, copies have been sent to UNOCAL and SAPC. Thank you for giving us this opportunity to be of service. Sincerely, Ken Broussard District Manager Directional Services Enclosure Gas Cons, Commission Anchorage 8537 Corbin Drive (99507) · RO. Box 231649 · Anchorage, Alaska 99523 (907) 267-0200 · Fax (907) 522-3432 A Baroid Company ARC:O ALASKA, INC. 31 - 13 KUF'ARL~K FIELD ALARKA .................................. L---:F'E_R.RY.__-.SL!N_~.EL.L_ _..:;-.i!.-.!R.'VEY I N_6 r:!--,!MPAN¥ ........................................... PAGE ANCHORAGE ALASKA ............ .C_: 0 MP__L. !_T AT I !i.,.N.._DA TE .... MAY.,:...,"':' 19,,'--:'-.-.,. _. DATE OF SLIRVEY APRIL 17, ....... BO:.---_::_~: GYRq:~_;!--.;OF'!C SUR.VEY. ,JOB NLIMBER Ai<-BO-90C)41 KELLY BUSHING ELEV. = OF'ERATOR-MCGU I RE VER T I C AE'--S-E EiT I ON ',:i~tL CULA TED- ~-L.'~., N"]Z'~ '-Uq E6']S-~J'~E ' - -- 1 '.~ 8'.--,' 76.00 F T. TRUE . ~E~'.=;HRED .... (/~R T I C:AL £PTH DEPTH ~ UB-~_.EA .......... COLiRSE ........ COURSE VERT I CAL I NCL I NAT I I_-iN D I RECT I ON DEPTH BEG M I N DEGREE:=~ DOG-LEG TOTAL ........... ':--;EVER i TY REL. TAN _d._ILAR COORD I NATES DEG/100 NORI'H/SOLITH EAST/WEL=:T VERT I CAL :=; E C T I 0 N 10£) 100.00 200 199.79 300 2~.~8 400 399.97 500 4~.~5 24.00 0 :36 :_:', 88 .89 E 0 .60 c).. 01 ._.c. 1'..".:,". 'T,,. 9.C) 47 .=,"" ,=,'-"=._,. :30 E 0 .1'~ 0 .08 '.'='; · -.~ .-~ .-~ ,- o .-s .-) S ~ ....-,. ,...¢',..,0 .-F,.,..'":' ._,'=' E: :'::_. 6 'P E 0 . C) 9 0..,;..... '-"-"-' '?,,7 0 57 ,.:: 7:=: :'::9 E 0 1":' (") 47 S 4 .....=,. W 5 I ":: S 76.69 E C). 11 C). :-':4 S 6(I)0 5'.-7,' 9. ".-.".~ 3 700 699.91 ............ ~.C.!9.., 7.9'~. By' '- 'Po(:) 8'.~9.87 1000 999.84 1100 10'.-.? :-~. 82 ,J.-'-.-'~ 9:3 I 12 'F.; 72 .... ,0 E · T., -'Z, . . 6=~.._91 1 10 S 68 69 E · 723. -"' 8:.~ I 10 S 67.50 E 0.18 1.37 S O. 09 2.06 S O. 03 ........ 0.02 3.61 S 0.15 4.52 S O. 17 .___~.5.61 S r).. F,o._. E -0.46 I. 7:--: E -1.._~ o' 3. 18 E -2.72 4.74 E -3.99 6.45 E -5.33 8.34 E -6.77 10.31 E -8.19 !2..__,22.._E._ ...... ._ -9.5:3 i4. i4 E , -10.87 16.04 E -12, 14 ,-, -) ..-_~ ;' ,L~_= ...... _E, -1 42 , ]-~f . :; 1200 ~1199.78 1300 .~!:i 129~,74 1400 : 1399.70 1500 1499.64 1600 15~9.58 1700 169~.51 1800 1799'43 1900 18~.34 142:3.64 1 55 :=,'-' 48.69 E O. '-'~4 12. o4'-' S 27 .67* E -18.86 ' ='-":' ='" ..... '7' '-' '-' 45 19 E 0 18 14 72 .:,o .:,(.).-,'.~._-'~"-' E -2(].. 01 ~ ..I ~ ~,. ~10 .~, - '9':' ~ _ k_ ._ ~ c~. 17.38 S ':"-' ':'/- 16= .... 1 '2 1'-' S 44.10 E ] '~' . . 1723.4:3 2 '"'" '-~ ' '~'/'-' == 44 39 E 0 t5 :=, =0. 35 66 E '~"" ~: · . , z :, -zZ. 27. 182:3.34 ~ ""~' '-"-' ¢' oc, S 45 69 E 0 19 1 S '-"-' ~.:, .:,o, 7 t E -23.57 ,--m.!:~ E ............ =24"' ~.Z__ 2(:)50 2100 . 21~o 22C) 0 ...... · -' ..:, fu) (.) .....2,._, ~.) 2400 · -' 4.iL 43 7.5 E -<'.~ 76 4.5.4.5 E -26, 42 ............ 4. /__. ._i_..¢:... E .......... .~_£!6 ..... 44 '""~ . ,:,,;~ E - 24.01 41 '-"= . ,:,._, E -20.40 _ _. :37.47 E ................ =1~.....4!-2 ....... · --m i -- . · ..:, 1 F,(') E -8 87 ~:'-"-'._-,. 75 E -0 .5C) 1.4 /-/-E .... '-.-'.k._l'-' ARCO ALASKA, INC. :31-13 I<UPARUK FIELD ALASKA _LSPE8 .R_Y=~UN__W. Et_-._.L_ :: SL!BNJEY ~ Nj._-.,_'... ANCHORAGE ALASKA vER-T i E: A-L-'-~E L:: T I i:] N'-'~::iAI~]:':U LA ~--E !~'' "~-E~, N G'-"i::L]_-, ::]:CFRE E.AGE 2 DATE OF :=;URVEY APRIL 17, 1'P89 B 0 S_i F!..G_' Y_R 0 :;; C r! P_I. !.--.~ . S LI R v E ¥ ...................... JOB NUMBER AK-BO-'.~Oc)41 KELLY BLISHING ELEV. = 76.00 FT. OF'ERATOR-MF:GU I RE ................ TRUE__ MEASURED VERT I CAL CF'TH DEF'TH .~!!-!B.- SE_A. .......... _CO!.-.!R':_-=!E .......... COL.!RSE ............ DOG, .L..E. G_' ................. T 9 T A_L_ .................... VERT I CAL I NCL I NAT I ON D I RECT I ON SEVER I TY RECTANGULAR C:OIDRD I NATE'.--; DEPTH BEG M I N DEGREES DEG/100 NORTH/:--;OUTH EAST/WEST VERT I CAL SECT I ON 2700 2686. 2800 2780. :2900 2871. :3000 2960. :3100 3200 27 .... :~'4-1'~.?. 27 :_=:6 2.:-; 15.86 86 2610.86 __ 06 2704.06 :-=:2 2795.32 3.9 2884.3.9 :3046.68 2970.6:_::, :31 '-'C . ~,.) 27 3054.27 19.94 16 37 S 71.89 W 1.9 42 S 71. 0 W 22 45 S 70.80 W 25 2'P S 72.60 W """-' 34 '=' 70 c') W :32 6 S 71.:--:9 W 34 26 S 70.8.9 W · :,._-, .) 0._-~ ~. 11 . 26 :'::400 '-"-"-"--? ,-6 ..., ... ,-.,; · '-' :3:300 3:364.50 2 C.' ..... ?.._ .:,6 .)o ._-,4._-,o. 7:~!_ :3700 --'= " .:,._, ! :_~. 26 · :,o JO .:,._,o7.68 ':' 91 1 c-,"-'~: 46 ':' :'::2A. 74 W :'~59.52 · ~-' ~ ~ ................ , . . '-'. ....... .- -. ................... r_;=.'-- ....'---. "-' :E:i 1'-"-' '-'~ 379 74 W 4.21 45 .... ,-,.:,..-' ._l S . * . '-'":' ':' 441 4.5 14 486 79 · ::,..':,o 2(')A .~... d,.. d:. m..m . -- I . . .... ' '":"-' ' ~:'"" '"" ?,' '-' '""'-' ~5 ":'; 34 ·_ t) _. _7:;_,. ........... ~.-..-'.! !-! -..?!.-_', _ .::'. .......... -_-. !2:.:..: ,.. p.-',___.W .... ,6.., o. 14 619 7:3 0 16 '"%~'26 "" =' ~ 0.27 .--,,'-,(' .-,,-, o_ .... .~,:, ). 4,--, .'::; (:,27.7:3 N 6,=,6, ~2 o; OU . 4000 4100 4. 2:0 C) .... 43 0 0 4400 45(:)<:) 4600 4700 0.79 332.05 S 750.46 W 0.2~ :3!158.86 S 810.95 W 0,.5~ ................ ~::~6.,1.~ ...........~71,C!7 N ........... 0.58 413.96 S 93(3.49 W C) "'"' , ..=.,,47 W ..oo 442 41 S 411.:: 48 4(.')37 40 41 .~, 6 ..... ..~y W o.41 471.47 S 1")~'--' ,. ~.~.. 27 W 418:::._ 51 4112. ~17, 41 43 ...... '=' 6,4 8.9 W 1..:1'-' 50(.') L.-'W'- - S 1107 76 W 4263.1..- '-~' 41 ,_ 7 .12 41 45 S 64 .6 (:) W 0 .20 ._,zo= '~''-' .6.9 '.S 1167 . '-?; ,_-,'-' W 4900 4411.87 5000 '-'= ' '- 44,:,._,, '--::"-.?.. 44(.)Y, .9.9 42 17 ::,"" /_-,4 .6.9 W 0 5100 5200 5300 5400 ................ 7_.~.2 ,_Z.~.._ 818..98 ,'_--:85.02 1016.49 1081, .95 .._~. 1RZ, 5'.--' ..... 1213.5 '.-.-~ 1280.12 13._4_6 ,_~. 45%9 '-'-)5 .... 44,:,:..:, '-= 42 18 '-' 64.,=,(.) W 0 ~..-, .-, ,%, .-)~. ~ 4 :, .:, .:,. 4 .-, .., 7. '-' '- '-" 2 7 ,:,'..-' 4.. S 64 50 W 0 47(.')7 '-'= . .:,._, 46 :'::_ 1 . :~:_ ~_ 4:2 ._~ .-.":'._.'"" 6, 4 .50 W 0 4-78C) 57 .47!.')4 =; ................. .... 7 42_ 5!-:.: ..... '.._-:-.!._.64.: 1413, 72 1 ~'='C). · ~o. 81 ? 07 64:3, 4'P :-'; 141 C' '-"--~ ' ' · :'" '~-' .............................. .f.....~ :...._~ .......... ":'~ 672 '-'~ ,.._._ . .:,._ :E; 1471 ,21 14 16.15.42 41 701 ~':' '.S 1 ~':":-' '-"-' .........· _ ._, , :,,:, 14 16:3:3 . 15 I I 7 :::C) 84. ::: 15 c~ ::: ,:, ~ W 1751,21 ANCHORAGE ALASKA __60MP.UTAT ! C!N. DATE MAY 2, 198'? ARr:n ALA._KA, INC: :':: I - 13 KUF'ARUK FIELD ALA F;F:.':A VERT I cAL sEcT-I-°N-' CALCULATE~--ALi]NG -'i::LoSLi'Ri~ ............... __ PA~E .....2, .... DATE OF SLIRVEY APRIL 17 1':¢R':¢ _. B[!~... G;YB.C!SC:CHF' I C:_FJL!R.VEY_ ......... ._lOB NUMBER Ai<-BO-':.-.,O,O, 41 I<ELLY BUSHING ELEV. -= 7/_-,. 00, FT. __ _0F'ER.'~..TJ.--.!R,f_!.!--.:C:!g] I BE ............................. .................. T.RuE .......... SUB_-,~;EA .............. C: .L-! L! R_' _S E .... MEA'.=:URED VERT I L:AL VERT I C:AL I NCL I NAT I I_-IN ZPTH DEPTH DEPTH DEG M I N _ CC!URSE ......... DOG._,LEG D I REF:T I ON .'_--;EVER I TY DEGREE:S DEG/100 T.!QTAL ............................. '-T" i:: ...... " RE _.TANL.,LILAR CI.-JOR[I I NATES VERT I CAL NORTH/F;OUTH EAST/WEST SECT I ON · _,._, .)U 4o._,.:,. 47 4777· 47 4o .-'4 .=, 64.60 W L). 44 7/--.(-'). 2,"-. '.=; 1 ,:,' .... ~'=:-,, (:,5 W '=/ ' ' '-'.'~ '. '-' 78':.-,'. 77 :.=; 1717.67 W :_-, ,'-, L) L) 4'P26, 15 4o..U 15 43 21 .=, 64.50 W A. O'P ."i7AA 49';-¢:.E=:. '-='- '=':',' ":' '=' "-' '- ' '= - '-, ,- ' ,-- · _, '.-.~4922 .... _-. .......... _- -J .' _ _ 4--:_ .4. ~_~ __ -_-,__64, I Y H U, ..,0 o 1 Y. c, 1 .:, 177'?, 81 W ~:=:OF~ .=, C) 7 ¢, . ~ C) 49'.~4 ~(') 44 13 c. 63 :=:9 W 0 47 '-'='") '' ':' '-' '-' ...............· -, . ,=, .-, ~- · ( )'.:' ._, 1 o 4 .,:. :30 W .~ 9 c') (') 5142 84 ...,¢.)66= ' ,'-, o /. -.-., '=' ':4 · · o 4 4:3 5 _, .... · __l · · I__l I__ · ..... · 6. 000 F,'--, 15, 91 =" '=' ._,1:'::9 91 43 1 6,1 60 W (') /_-,'.-.-~ 91:3 03 S 1:;~64.28 W .............................. ~..%~'- .I. . --, · · m . ................. 6100 =..s,o,.-~ 47 5213 47 42 ~, .-'-- ...... . 14 ._,'=' 61 .50 W 0 .7'~ 9. 4 .-=,_..=,0'-" S~:'--"U ..-'-'._"~'-' , o..-,'---' '--' W 6~..)0 ~=, :6(: ~,0 W 0 7S/ '-'¢')'-"-' '-"---~ ~,.-',~.~o 75 · ~.-,o,-; 75 41 4'.".-~ 977, 75 S . .-',.'. W Mm · .'. # ~4 .-m 181'.~. 62 1888.25 1957, 1~ 2026.62 2095.64 2163. :-}1 2231,64 2298, 56 6300 5438,31 6400 5512.83 6500 5587.12 6600 5661.30 7000 '='"= ':"' '-"--' ._m .'/._m ~, · 7100 6032.16 5362.31 41 · 45 S 60.10 W 0.27 ~,plO. 5436 '-""-' o.:, 41 .~"-: S '::' '-" ...... , Y. 60 W 0 · :2:6 1044. 5511. 12 42 ,_-,'~' ._-.'-' ='....,'-'.':.". 0 W 0, 47 107:3. · =;. ='--":: 30 42 = ,.,_,c ..... , S. _.,_,.=;:-~: 19, ..W O, ,.. 4 5659.6,0 41 ' 56 S:57,:60 W :0,4:.3 ::: 1148, =: ",~ c/) '-, . :' ,-',' :"-= ' . ;":' .-. .:,.,7,:~,....C 4~: :: ~: ; ..... =, ,.,7.!0 N: 0,,:'7: 1: i: C~_|~'L--~ : : 'TI : ' : ~' : ~'---~ ~ ::'---~ ::.:,,~ oo,j_t_. :: ~,~...:: ...5.._.: ~.::;..._s,6. ,:+0 ~ .: u..40: · ?,:::82 '-"-' - : '~4 ~ '-'5'--' · ..'.-'~ q.Z 14 S ~,6 19 li13- 3 .~, ,."',~ ~_ ,, - - . . .-, ,:~ · ..; ..,,_-,. 16 4Z ~4 .'=: 56 0 ~ ~ 0';~-~2 1 ..- .-. 6,. 77 S __'.21.~0, 27__N_ .... '2:~~L 27 S 2197·94 W ~ 2431.77 44 S 2255· 49 W 2498.60 ':":' '=' 23 '- '--' 5 ~ 5 ~ '='') '.'.'"4 S:: 2:369.43 W 2632~ 22:' ............... .~~.!~ ...... 66 S 25:37 · 'F¢4 gl 28:2;2.36 21 ~-.: 259:3 · 8:_:: gl 28'.~9.27 7 ~ 0 7400 7500 - 7~,-, .... · ._ ._1 7(:,AO · 770,F~ HORIZONTAL DISPLACEMENT = 610._,. ,=,.., 6U....v.o.., 4.4 .',; .-, ...,~.,./-, .~L ~ .... iZ,..-, ... 1 .-,:34.16 .:, .,- 64 .-/· 77 W ..- :~A6 4-- ~ .T., ' . .":, -_.~ ~, ~ ,-. ,4::_ - ' " ........... ~ .~ ..-:, ,=. .-., c:: ~ .-~ '~-.-' . 617.v.6.~ 6,100.6~ 4.._ 1~:, o ._,5.8~_ ~ .~ ...... ')~,41 1._,7~., 16 .:. ~.70..:,,,.,7 W .=,0._-,:~,46 . .?., C:' .-., . -'., . ~ .-.~ : . ~.. m::r~__ .... '~ ~ - - ,-. .-, .- - .- /_-,~:,..:,. 6.,. 6177.6.~ 4.,. 16 .-,.-,.-,./--.(~ ~ ...... .j ~14 1410. L)/:..:. ,'.761. 14 W ;~ 100..'::-'5 · ],.-., ~m:= ";' ~" ~ ~ ") '$"--" '-' ~ ~ '--, . .~ ~ ' ,:, '-., ' ,-' ,-.,0 .- ' ~ 6 .... .,:.7,._..:, 6.....,1,o.., 4.,.. ,,..-.- .='.-, .-' - .-* '~ ~ .... ~L7 144,~,.,:..'U' ...-, .,:..,;.,16,/-',_4 t4 .~l.6Z.'~)'=.~ _ .............. ;.., ";% ............................... ; ~ .................................................................... . ' ' . . . _'2, - -") .'; . ~-. I~ ~._ I~_ ' ~ C: " ~--..' ' '-"-' '-' '-"-' '-,'-, ' ' 6o64.47 6.. ,-,o. 47 4.. ~./_', .=,,-',-'. =-,(-) L~ ;.~/ ~l~ql .'. 146,7 · ._',._', .=, ..',--,44.41 W ._',~'.(J)(.). ,.,6 o4u 1 ....... 6 .... -.=,, .-',.-, 4~ ._',4 .=,._,=J.._,u ~i ~4 14o6, 47 .=, ~,=, 7~:...'c, W .~4._~4.1 ( ~ ,.4. c'! '-,,:?,-, C'/ '-, '", ,-' ='~- ~ ,,-:'--, ,-, ,-. .-,,- .-,,-, .- .-'-,.-.-, - .-, ',474.; 7 ,S.:, .-. ,=,.: 7 4.,:. o4 .=,.,. ,.. ,¢) Jif O, O0 · ,.,:4, 7o .=, .' ?.' ,-, ,.) .',.:,U .' :"4:-'~(.')1 24 FEET AT oUUTH 62 DEG "~"' · · .~'.'Y MIN. HE;ST AT MD = 7700 THE i~iALC:LIL~i-T l 0N PR'-~I~:'~'D'i"~E~:" '~'RE ~ASED"'"C~N '":i:H-~ ........ L.=,Ei%'':' LF-i .................. THREE; ................... DIMEN.:,I_,NAL'-'"'-i' ........ RADILI._-,: ....... '::' uF ~- ...... L..URVATLIRE-: ....... ' .............. ; ................... METHuD.' ........................ ARCO ALAoKA~ INC. 31 ,...1_ :3 i<UF'ARUK FIELD ~.~iPEBB¥_-~UB_BF. LL~WBVEY.I NC.~_g-;QIT1P_ANY ...... ANCHORAGE ALASKA DATE OF SURVEY APRIL 17, 1989 .............. C~L:~M F'U TB T I ON _PA T.E. ............ MAY c..., l'F,8'~ ____F_' ~A]~ E 4 :: KELLY BLISHING ELEV. = 76.00 FT. OPERATnR-MCC~U I RE INTERPOLATED VALUE:S FOR EVEN 1000 FEET OF MEASURED DEPTH TRLIE SLIB-SEA TOTAL ( _A.'_--:URED VERT I CAL VERT I CAL RECTANGULAR F:OOR[~ I NATE:E: MD-TVD VERT I CAL PEF'TH ......... DEPTH .......... D.E_F..'_!.H ...... N,Z! T ....... _ .[!! F_F_.E_.RE.N..C_E ........ !::'_--!RR~CT_! r]~ .................... 0 0.0 0 - 7 6.0 0 0.0 0 0.0 0 0.0 0 1000 9'P?,. 84 ........ 'P23, 84 ............... ~..,. 5~ :S ........... 1 ~,, O~ E ......... 0 ~ .16 _ ............ 0~!.~ ........... 2 0 0 0 1 .... ~.:, I ~ ~.:, ~ ...... - . -. , ..,... S 41 ':~::: E 0 77 A 61 :3000 2 - .-. 4000 .. ,.. 5000 ~'-'~ '- '- 1 ._,47.4z W ~ 14 01 '~'P]O '-'~' ~c,~. ;~ ~ 44A'~ 9'~ 614 78 c- .:, ,: -=, . . I ._1 ,-- i ~ -- i 1 ~.. 1 'R64 '-"-' 6 0 0 0 ~ '~ ~ ~ 7 0. ] ''"' . ~, _. . .. ._ . ~o W 784 (')'~ '~' 7000 ...... 57~58 ~ ~._c,:~ ._,,~.o~=°'-'"' ...................... ~.:,'-"-' ~ .............................. ~'-'~'-'._,c,. o,=,z ~- '-'.:, ~ -J .? 7'-' ~ '-' . 'Fzq N ~ 04 ~ .77 ~:_,(,.~'-'~' ' ~ ....... .......................... 7 7 0 0 6 4 7 4. 'P 7 A .... THE CALCLILATInN F'ROREDLIRE::; ARE BASED FIN ]'HE I I.':;E OF THREE DIMENSICINAL RADILIS OF CURVATLIRE METHOD. ARCO ALASKA, INC. 3I=1:3 KUPARUK FIELD ALASKA ...... .COMPUTATI C!!~._ DATE ..... MAY 2, 1'?:--:9 ..................................... E'AOE ..... 5.. DATE OF SURVEY APRIL 17, 1Sy:3'F~ ,_lOB NUMBER AK-BO-9A041 KELLY BI_k=:HING EL. EV. = .... OE~ERA TQR_-. M)D]l.,J I RE... 76. r~O FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH :ASURED DEPTH TRUE SUB-SEA TOTAL VERT I CAL VERT I CAL RECTANGULAR COORD I NATES: MD-TVD VERT I CAL .._ DE.F'TH ....... DEF,_T~t_ .......... .NQRTH/'.=:L-.!L!.T!:~. ....... ~A:---iT./.w.~ST ........ [!!.F~FERE. NCE ....... rLQRREC:TICqxJ ................ 0 0.00 -76. O0 0.00 O. AO O. 00 .......... '_76 ............. 7/=,._ 00 ...... !}..._ C)!:! ................... _C.!_..!.:! 1__:.~!...O. 27._..E_ .............. _Q._ .C!£_) ............. 0,00 176 176 00 1 r)('). 00 0 C) 5 '-' . . ..... =. 1 40 E 0.01 0 01 276 276 00 200.00 0 18 S ':' 81 E 0. ')'-' (..~ 0 01 i m -'-m :'::76 :=:76 0C) '-"" . .:.(.)(.). O0 0 :=."~ c. 4 'R ~ ........ , E 0. ]'-' (..:, 0 01 476 476.00 576 576.00 676 676.00 776 776.00 876 876.00 976 976.00 · 400.00 0.74 S · .,(: t.) O0 1 '-"-' S · . . · 606).00 1.88'S 700. O0 ...'-' 6,4 ;=,'-' 800 O0 :=: 43 ':' ':? F)O. 00 1076 1076.00 :::: :::::'1000. O0 1176 1176. oo . i:1100' oo 1276 1276' O0 · O0 6.02 E 0.04 0,01 7.86 E 0.06 O.Cz :: 9. ':'-~ E O. 0:--: 0~.02 11.77 E 0.11 0.02 1'~.j . 68 E 0.1'-'._-~ 0 .u...' '-' 1376 1376.00 1 :-~, ' '. ._ (.)U 00 1476 147/_-,. 00 1400.00 5 00 500 00 1576 1._76. 1 . 1676.00 1600 ~ 00 1776.00 1700 ' 00 16,76 1776 4.27 S 1_5, .=;,'=~._ .. E A, 1-'=._, ~A2 04 17,-.,4 E ':::::' ': 0-:1,7 0,:02 :,: ~. :,i'~ .. :: 1 :... 76 E 9.8'2 :.=; 24.61 E 0.29 0.05 11.81 S 27.0.9 E 0.34 0.05 14 1 '-' ,.E; 29 '--, '-~- (')/- ..: . c ._, E _ (__}.~..4. 0 0.. ..... ,_ .... 16.72 S 32.22 E 0.47 ::: 0.07 : 19.57 S :34.98 E 0.55 0.08 ARCO ALASI<A, INC. 31-13 I<UF'ARUK FIEE1];' ALA::.;KA C'F ..... SHN ANCHORAGE ALASKA t--.;!;!MPL,.!TAT I ON_ PATE MAY 2, 198.9 DATE OF SLIRVEY APRIL 17, ._'I~,B-' N'-LIM~-'~R Al<-.Z ~i]-'F-"O, 041 KELLY BU'.qHING ELEV. = OF'ERATL-~R-MC:GLI I RE 76. c) o FT. i,_. INTERPOLATED VALLE.,, FOR EVEN 100 FEET OF SI_lB-SEA DEPTH TRUE ."_;UB-SEA TOTAL ( .ASURED VERT I CAL VERT I RAL RECTANGULAR F':Of]RD I NATES MD-TVD VERT I F:AL DEF'TH_ ........... DEPTH ...... [!.E..PTH ........ .N. ti R T H ../. ~.---i _O LJ T H ....... _E.A_'..'_:i_T/_W E L:-: .T__ ~! I F F E R.E'.N_ P E .......... !} F!_R ~..EX.'T..Z ON__ 1876 1.976 2076 2176 2277 2378 2583 268::: 27%5 1876.00 1.976.00 2076.00 2000.00 2.9. l'F* S 44.73 E 0.86 O. ':' 176.00 ':'100 00 '-"-' '-'1'-' . ,=,._, E 0 9:=: 0 2376.00 '-"-' ' C 27. ~ ~ E ~ c, ":'57/- C)0 .-,,_:- -)(- - - ~c, '-,'T.., · . ...... .-. ,..,(..). 00 70 W 7 4 '7 :3. '- -' ............... -. :-'~ ,_Ii--, 2676 00 26,00 00 6, 8 47 '=' 46, 04 W 1'-' 4:3 5.01 277/_-,. 00 2700.00 81.01 :'; o~.'-"-' :30 W 19. .6, 0 7.12 · .' ,=,00.00 ~.,. :3017 2~7/_-,. 00 ~'""-~ L] O' 00 111 .91 '=' 17:3 '-"-' . . ._, . ,.,._-, W 41 . 84 1'--'-. 64 ..,L4. 77 '-' 134 '"' - · :, ._-, 0 76,. 00 '-' ' ' c '-"-' c '-"--' .:,00 J 00 1 '-' 1 51 S ~.:, .~ W 61 16 : --,~,_ '-"-' ~/-_: ...... ..* 176 ,"' .................. 00 .~':: 10 Q ,%'~0 .......... ;15.~, ,"' ,-.-,;~c, ,-..=, '-' '-' '-' '-' ::: 27/-,, 0 (] :--: 200 00 17.9 = '=' --, z ,.--~ .-, ..., 1 ..:,,_-, .-. · ..:,4 W 106 · 74 '-'/' ~,=, 71 -- -- m # · -, ~ "2, ":, '-, '-, '1 ' '"':, '-~ - 4._1 14 1 ..... ""'-' · .:,... 15 ..... 76. (:) 0 '-' .'9 · .:,..:,L (..i, 00 20.9 '--,'.'9 -':,c,,. · '-, ..'- · · ..._ ."m ·.mm~...~.. -- -- · · ._,.:, 4 74 W 17.~ '::',.~ :~ 4.3 :=: 242 ,,,4 '-' '='"'" 27/-',, '-'"':' '-' .: ..:,.,: .:, 6,1 '--' 03 W '~' ' '-' '-' .,.'. 0 o · .=, 1 34. '--' ''~' ,,,, .', 0 .... '=: . 33 '.310 /.-,6 S 700. :=:9 W 242 64 ._4 12 11 2't-.~_~ .95 'Fy'..) · "::/-. 4 c:',' :'::47A, (')c) :'::40C). ' :2:7:34 .-,,.,76.00 ":'= ' ' o;.::,00. O0 ._,6L (.) 00 3'21"" 36,76 00 '--' ')' m'", · mm ARCO ALASKA, INC. 31-13 KUPARUK FIELD ALASKA ~-:iPERRY:SL!N I,,,IELL._ ..~iURVEY I N~COMF'AN¥ ............................................ _I::;AGE.__7__ ~ ANCHORAGE ALASKA DATE OF oURVEY AF'RIL 17, 198'.--/ COMP_UT. AT.I MAY 2, 1'F.~:=-:9 ,JOB NLIMBER AK-BO-90041 KELLY BI_ISHING ELEV. = ......... C! F: E _R_ ' .A_ T_!DR= M~!_! ! 76.00 F T · INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEF'TH ......... TRUE- _:ASLIRED VERT I CAL DEPTH DEF'TH ._,L B-sEA TOTAL VERT I CAL RECTANGULAR COORD I NATES MD-TVD VERT I CAL _ D_EF'TM .... NORTH./_F-j.¢H._~TH ...... E~:~iT_/W_E_L=.iT.. E~!EFERENCE COR. R_'ECT~I_0N 4052 3776 · 00 3700.00 345.94 S 782. (' '-' 41 o= 3876.00 :=:800 .... '""-' , :='/- '=' ':'~ O0 ,.~,:,.,::. 13 .'_:' . .... ..- ..... W ..... ¢.~,, o_! ........................................... ~_ ..................................................... 4317 4450 4583 4717 4851 4986 5121 5257 5393 3976.00 4076.00 4176.00 4276.00: 4376.00 4476.00 3900 00 419 Fo 94 . · . .x_, S 1 11 W 5 90 c- 4 0 0 0.0 0 4 ~ 6 . ~, 1019.. 0 'F~ W 4100.00 495. =~ '-' . · J:..:. 1097 66 W 4200.00 · : 4300.00 4400, 00 4576. 4676. 4776. 00 00 00 · .~7_, 16 '-"- 52 309.45 '-"-' 30 341.97 32.5:2 374.32 32.35 407 24 ':'"" '-'-' .... · .::~. ......... 441 · 26 '34.02 475.70 34.44 ~lt._O., 5~! ..... -- '-' 4 ~, 0 U. 00 4600.00 470 C). 00 64./. 71 S 689.00 c.'-' 729.01 '.--', 4876. 4976 · 5076. 00 O0 O0 4800; 00 4 ~0(.). O0 ,..,0 .) 0 00 769.40::S .:.: 810.18 S ~., ~t ..* . ~., . ,/=, .=, ..., O 5476.00 5400.00 1027 '="' ' 6405 5.~'~' 00 550(3 O0 107:3 ~.5 "'' 1423·51 W 545· 70 1506.12 W 581.24 · _, .-.~U. 00 W ~7 7.5 1674~90 W 655.01 1760.30 W 692.69 1931.46 W 769.40 2013.08 W 805.80 2091.93 W ........... ;~!~ 44 2169.45 W 874.54 2246.86 W 909.00 ""= 20 ."~..I . · :,.J · · :. =., 51 37.26 :37.68 :37.73 '='/- 40 :34.10 34.46 ANCHORAGE ALASKA ~RCO ~LASKA, ~NC. :31. ! :3 .................................................... ~;;L] M. ~ U T ~T.~ !:!N __D~ TE KLIPARUK F!ELi~ HAY ALASKA __ .. PAGE 8_ _ BATE OF SURVEY APRIL 17 ',J-~DB NUMBER AK-BOZ:-':,~li!,',~ ~-- KEI_LY BUSHING ELEV. = 76.0¢} FT. OPERRTOR-MCOU I RE INTERPOLATED VALUES FOR EVEN 1(]0 FEET OF SUB-SEA DEPTH ( -]ASURED VERT I CAL VERT I CAL RECTANGULAR COORD I NATES: MD-TVD VERT I CAL DEF'TH DEF'TH DEF'TH NORTH / :--;OI_ITH EAST/WEST D I FFERENF:E CORRECT I ON '=" /- _ .. .--'.} :37 .661 '? ._,~,7 ~-,. 00 .=l,/:,0¢}. 00 11 '-'¢. :S 6754 5776.00 5700.00 1168.44 S 6889 5876.00 7024 5':.-~76.00 7159 6076.00 72'.-T~5 6176.00 7430 6276.00 7565 6376. O0 2324.01 W 943.80 34.80 2400.07 W 'P78.33 34.5:_;3 5800.00 1217.6¢} S 2475.84 W 1013.07 34.75 5'~00.00 1267.63 S 2551.35 W 1048.00 :34. '73 6000.00 1318.67 S 2627.05 W 1083.41 35.41 6100.00 1370.31 S 2702.85 W 1119.10 35. 6200.00 1421.56 S 2777.93 W 1154.24 35.14 6300.00 1473.:31 S 2853.11 W 1189.63 :35.39 '!"..H.E_'.. !.--.LA.L.!.-,iUL..AT ~.q..N ~.F.:.R'g!C_:.E...EJL!R.E.S LISE A .L_.I.N_E.A.R.' ..... !.N_T.E_BF.'PLRT! !:! N .... B _E _T W. EE_N_ ............................................... L._-, OF RURVATURE) PO1;NT8 THE NEARE:--:T ..) FOOT MD (FROM RAD! I'-- ARCO ALASKA, INC. ~I-13 KLIF'ARUK FIELD ALASKA '.,~,;F'EF~RY~SL!IN .NELL. :::~LI !R~EY I NG ._ C:C!MF'AN.Y .................................. F_,~G~_ ~ _ ANCHORAGE ALASKA DATE OF SURVEY APRIL 17, 1~89 ..................... C:QMFL~T~.T I ON_PATE ........................................ MAY~,'-' 1'P89 JOB NUMBER AK-BO-'~0041. KELLY BUS:HING ELEV. = 76.00 FT. ............... ~J F~g F~ T ~B c H G~SU ! BE INTERPOLATED VALUES FOR :E;PECIAL SURVEY POINTS TRUE SLIB-SEA TOTAL ( SASURED VERT I CAL VERT I CAL RECTANGULAR COORD I NATES DEPTH. .... DEPTH .......... .D_E.I::' .T._H. ........ .N_E!RTH / :_S!~]L!TH ........... E. A.L--!T/WEST .......... M~R.~!~:ER ............................. 7270 61 ._ 7, 42 60,_-, 1 ,42 1360, :.~]' S .,:.6,;.,,:,, 8'.~ W TOP KLIPARUI< C 7'.2?8 ......... .C.",_~_ 7~-_ 14_. 6! "-' . ____. ............... ' ....... I '" c~..-. ! 4 137_1___4..(.~__S_' ...... 2704 46 W B~=,.F_._.K!_JE._A_B__~I~, C 7322 61 '.-} 5.91 6119.91 '="-' ' ,_, 1 .:,,=, C). 47 S; 2717. © 1 W T 0 P K U P A R U K A 7464 6300.9A ; '"'-' . . ._ :,.....'-4 96 14:34.42 :S 2796 66 W BASE KLIF'ARLIK A 7600 64A1..:,.:,'-":' 6.:,'-"-'~....:,.:_~.:,'- '-' 14,=,¢,'-". 47.=,'-' 2:372 .26 W '-'I'.:,L RVEY DEPTH -,:_-, ~.,::, ,:- .-, -, 7605 6405.01 632':~ 01 148,--,. zE, 7._ 05 W PBTD · . : ~ -~m ~ !' : ' 7700 6474 97 6398.97 1._~4.7~:S 2928 01 W TD DERIVED USING D IL DEPTHS AND SPERRY '.:_:LIN 'SURVEY DATA COORD I NATES MARKER ....... ': ~!'~'' MEASURED'~'DEPTH ~:'i--'--TVD ':~ : " BKB BKB SUB-SEA .: · ~: THICKNE...=, "~i WITH REF.- TO WELLHEAO~':~ VERT I CAL ( OR I G I N- 115FSL 85FEL ) ' SEC :3~' :" T13NI:;. RO,:.,E '~ '~' '~::~:' · ' TOP KUFARLK C BASE KLIFARLIK C 7270 6157.42 6081.42 7298 6178.14 6102.14 1360.82S 1371.40S 2704.46W TOP KUPARUK A BASE KUF'ARLIK A PBTD TD -._'7:--:'')'')~.~. · 619,.,, ~1 6115~, gl. 7464 6300.96 6224.96 7605 6405.01 /_-,:32'F~. 01 7700 6474.97 e,o' '-'""'~.-.-,:,. 97 1380.47'.-'; 'C 2717;~!81W ~ ::~il 1434.42S 2796; 66W ' 148:3..~::~:_~ 2875. oc, W 1524 78S '.)9'.)'~ 01W t) FROM LINEAR EXTRAPOLATION:BELOW DEEPEST STATION. . 2) COMPUTER PROGRAM - SPERRY:::. SUN THREE.:: DIMENSIONAL ~ RADII I:~ :~L-iF::. CURVATURE:i ' i. ..... [.!_AT__A _.¢_:~_L~_-'_:UL__A__T! ON_.A_..N_D_ .. I NTERP_O. EA~_I.O_N_,_B_%~.R.~8.~ OF. CL!~_.ES_T._LJB~ .... ,:_. __ ._. SPERRY -SUN .. 5CRLE KUPRRUK FIELO 31-13 RK-80-90041 :- 1 INCH TO 500.00 / 500.0 ARCO RLRSKR, INC. APRIL l?. 1989 TRUE NORTH -~obo. oo -~5bo. oo -~obo. oo -tsbo. oo -tobo. oo -sob. oo 7'700 --500.00 --1000.00 --1500.00 '-2000.00 HOB I Zi3NTI::::IL PF1EIJECT I ON SPERRY -SUN 0.00 5CRLE :- 1 INCH TO 1500.00 / 1500.0 KUPRRUK FIELD 31-13 RK-BO-90041 ARCO RLRSKR. INC. APRIL 17. ~999 1500.00 3000.00 4500.00 6000.00 8474.9~ 7500.00 m ~ 7700 15b0.00 30bO. O0 I 4,500. O0 VERT I CI::::IL PROJECT I ON STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate Plugging Perforate X Repair well Pull tubing Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory __ Stratigraphic m Service Location of well at surface 115' FSL, 85' FEL, Sec. 36, T13N, R8E, UM At top of productive interval 1246' FNL, 1455' FWL, Sec. 6, T12N, R9E, UM At effective depth 1373' FNL, 1268' FWL, Sec. 6, T12N, R9E, UM At total depth 141.0' FNL, 1215' FWL, Sec. 6~ T12N, R9E, UM 6. Datum elevation (DF or KB) 76' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number ;31-13 feet ,, 12. Present well condition summary Total Depth: measured 7 7 0 0' true vertical 6475' 9. Permit number/approval number 9-1032 10. APl number 50-029-21923 11. Field/Pool Kuparuk River Oil Pool feet feet Plugs (measured) None Effective depth: measured 7 6 0 5' feet true vertical 6405' feet Junk (measured) None Casing Length Size Structural Conductor 8 0' 1 6" Surface 3 4 8 9' 9 - 5 / 8" Intermediate Production 7650' 7" Liner Perforation depth: measured 7336'-7350', true vertical 6207'-6217', Tubing (size, grade, and measured depth) Cemented 291 Sx CS II 1085 Sx AS III & 360 Sx Class "G" 200 Sx Class "G" & 175 S x AS I Measured depth True vertical depth 115' 115' 3524' 3383' 7683' 6462' 7358'-7390', 7400'-7437' 6223'-6247', 6254'-6282' 2 7/8", 6.5# J-55 AB mod. tubing with tail set @ 7208' MD Packers and SSSV (type and measured depth) Otis 10 TR SSSV @ 1791' MD; AVA RHS pkr @ 7136' MD 13. stimulation or cement squeeze summary initial perforations in upper A sand Intervals treated (measured) 7336'-7350', 7358'-7390' Treatment description including volumes used and final pressure Perforated at 6 spf with 0° phasing 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation , Subsequent to operation 284 330 0 1060 164 323 372 0 1 060 1 60 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas m Suspended m Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed //~'~.~ ~ ~~ ./J~c~ Title Senior Operations Engineer Form 10-404 Rev/ 06/15/88 SUBMIT IN DUPLICATE RCO Alaska, Subsidiary of Atlantic Richfield Coml~an. WELL ~"qNTRACTOR HEMARKS tFIELD - DISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPORT J DAYS I. DATE I ~ /i-9-~9 1~3c> i3. o.o.H. CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Report °F °F miles JWind Vel. ~Signed STATE OF ALASKA AI~.~XA OIL AND GAS CONSERVATION COMMISSION ~ ~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate__ Pull tubing_ Variance _ Perforate ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 115' FSL, 85' FEL, SEC,. 36,T13N, R8E, UM At top of productive interval 1246' FNL, 1455' FWL, Sec. 6, T12N, R8E, UM At effective depth 1373' FNL, 1268' FWL, Sec.6, T12N, R8E, UM At total depth 1410' FNL, 1215' FWL, Sec. 6, T12N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 7700' 6475' 76O5' 6405' feet feet feet feet Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) RKB 76 7. Unit or Property name Kuparuk River Unit feet 8. Well number 31-13 9. Permit number 89-25/9-268 10. APl number 5o-029-21 923 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 13. Casing Length Structural Conductor 8 0' Surface 3 4 8 9' Intermediate Production 8 2 0 8' Liner Perforation depth: measured 74OO'-7437' true vertical 6254'-6281' Tubing (size, grade, and measured depth Size 16" 9 5/8" 7" Cemented Measured depth True vertical depth 291 Sx CS II 1 15' 115' 1085 Sx AS III & 3524' 3383' 360 Sx Class G 200 Sx Class G 7 6 8 3' 6 4 6 2' 175 Sx AS I 2 7/8" J-55 set at 7208' Packers and SSSV (type and measured depth) AVA RHS PACKER @ 7136', OTIS 10 TR SSSV @ 1791 Attachments Description summary of proposal_ Add perforations to the A Sand interval 14. Estimated date for commencing operation NOVEMBER 1989 16. If proposal was verbally approved Name of approver //~ ,/~,'~v ~ ~ r'~ Date approved Detailed operation program X BOP sketch 15. Status of well classification as: Oil × Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to thp,, best of my knowledge. ' ,./// - FOR COMMISSIONfdSE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance Mechanical Integrity Test_ Subsequent form Approved by the order of the Commission ...... ~,~-~ 81GNED BY I~11 LO~ ..... E C,. SMITH Form 10-403 Rev 5/03/89 r'--'equire 10-~ ~xpproved C~oP¥ Returneo .. ~ ~, SUBMIT IN TRIPLICATE lAppr°val N°'~-~ ._.//d,.~~ I Kuparuk Well 31-13 Application for Sundry Approval November 2, 1989 . The estimated BHP is 2200 psig at-6200' ss based on data taken on 9/28/89. 2. No workover fluids will be required for perforating. . There will be a lubricator with a 5000 psig rated BOP used during the perforating work. Through Tubing Perforating Procedure Kuparuk Well 31-13 AFE #AK4125 1. MIRU perforating unit and pressure test equipment. 2. Shut in well. 3. RIH and tag fill. POOH. *** NOTE *** If the tag is at a depth of 7420' MD RKB or deeper, no cleanout is necessary. Otherwise, a CTU cleanout should be performed prior to perforated 4. RDMO Slickline unit. 5. MIRU perforating unit and pressure test equipment. 6. RIH with 2-1/8" through tubing perforating gun and tie in depths with the following logs: DIL/SFL dated (3/18/89) CBL dated (4/17/89) 7. Open well at choke for a 300 psig underbalanced condition and retie in depths. Once well is retied in, perforate the following interval at 6 SPF (0° phasing): o , 10. 7336'- 7350' MD RKB 7358'- 7390' MD RKB *** NOTE *** (A3 Sand) (A2 Sand) Any of the following charges are acceptable for Well 31-13: Vendor Atlas Wireline Silverjet (2-1/8") 16.0 grams Halliburton Dynastrip (2-1/8") 20.5 grams Schlumberger Enerjet (2-1/8") 13.5 grams Shut in well/POOH. RDMO perforating unit. Return well to production. L 2 1. 5000 PSI 7" WELLHF..AD CONNE:CTOR F'LANGE 2. ~)00 PSI WIRE:LINE RAMS C~'ARIABL£ SIZE) :3. ~X)O PSI 4 1/6" LUBRIG~TOR 4. ~ PSI ¢ 1/6" IrLOW TUBE PACK-orr IdlREI,.I_I~_ BOP EQUI~NT -.. STATE OF A~ 2-,._,-,SKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program ~_ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate__ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development ~X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 115' FSL, 85' FEL, SEC. 36,T13N, R8E, UM At top of productive interval 1246' FNL, 1455' FWL, Sec. 6, T12N, R8E, UM At effective depth 1373' FNL, 1268' FWL, Sec.6, T12N, R8E, UM At total depth 1410' FNL, 1215' FWL, Sec. 6, T12N, R8E, UM 12. 13. 14. 16. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 8 0' Surface 3 4 8 9' Intermediate Production 8 2 0 8' Liner Perforation depth: 7 7 0 0' feet 6 4 7 5' feet 7605' feet 6 4 0 5' feet Size 16" 9 5/8" 7" 6. Datum elevation (DF or KB) RKB 76 7. Unit or Property name Kuparuk River Unit 8. Well number 31-13 feet 9. Permit number 89-25/9-268 10. APl number 50-029-21 923 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth 291 Sx CS II 1 15' 1 15' 1085 Sx AS III & 3524' 3383' 360 Sx Class G 200 Sx Class G 7 6 8 3' 6 4 6 2' 175 Sx AS I measured 7400'-7437' true vertical 6254'-6281' Tubing (size, grade, and measured depth 2 7/8" J-55 set at 7208' Packers and SSSV (type and measured depth) AVA RHS PACKER @ 7136', OTIS 10 TR SSSV @ 1791 Attachments Description summary of proposal _ Convert well from oil producer to water injector Estimated date for commencing operation NOVEMBER 1989 If proposal was verbally approved Name of approver Date approved Detailed operation program X BOP sketch 15, Status of well classification as: Oil × Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSIOM USE ONLY Conditions of approval: Plug integrity _ BOP Test Mechanical Integrity Test_ Notify Commission so representative may witness Location clearance Subsequent form Approved by' the order of the Commission Form 10-403 Rev 5/03/89 SIGNED BY e R~,,'!ITH IApproval __ I require 10- .......... ,,~,r~ Copy ........ Commissioner Date SUBMIT IN TRIPLICATE Well 31-13 Conversion to Water Injection . . . Wireline BOPE will be used in conversion of the well to water injection. The static bottomhole reservoir pressure is estimated to be 2900 psig based on recent measurements in adjacent wells. No workover fluids will be used. 3 1. .5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PS1 WlRELINE RAMS (VARIABLE SIZE) 5. 5000 PSI 4 1/6" LUBRICATOR 4. .5000 PSI 4 1/6" FLOW TUBE PACK-OFF bi ! REL ! NE BOP EGU ! PHENT ALA,... ,A OIL AND GAS CONSERVATION COMMIS~.,.)N REPORT OF SUNDRY WELL OPERATIOI t 5 1 N/t. [ ¥ 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Pull tubing __ Alter casing __ Repair well __ 2. NameofOperator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. Location of well at surface Perforate .~_ Pull tubing __ Other ~ C o m p 1 e t e i5. Type of Well: Development Exploratory Stratigraphic 9951 -0360 Service 115' FSL, 85' At top of productive interval 1246' FNL, 1455' At effective depth 1373' FNL, 1268' At total depth 1410' FNL, 1215' 6. Datum elevation (DF or KB) RKB 76 ' feet FEL, Sec.36, T13N, R8E, UM FWL, Sec.6, T12N, R8E, UM FWL, Sec.6, T12N, R8E, UM FWL, Sec.6, T12N, RSE, UM 7. Unit or Property name Kuparuk River Unit 8. Well number 31-13 9. Permit number/approval number 89-25/9-268 10. APl number 50-- 029-21923 11. Field/Pool Kuparuk River Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 7700' MDfeet 6475' TV~eet 7605' MDfe~ 6405' TV¢eet Plugs (measured) Junk (measured) None None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 7400'-7437' true vertical 6254 ' -6281 ' Length Size Cemented 80 ' I 6" 3489 ' 9-5/8" 8208 ' 7" Measured depth 291 sx CS II 115'MD 1085 sx AS III & 3524'MD 360 sx Class G 200 sx Class G & 7683'MD 175 sx AS I Tubing (size. grade, and measured depth) 2-7/8", 6.5#, J-55, w/tail @ 7208' MD Packers and SSSV (type and measured depth) Otis 10 TR SSSV @ 1791' MD, AVA RHS ret pkr 0 7136' MD 13. Stimulation or cement squeeze summary I nteNrv/a~s treated (measured) True vertical depth 115'TVD 3383'TVD 6462'TVD RECEIVED JUE o 7 ,i~0;,~ Oii & Gas Cons..~0mrriis. sil.Orl ~r~chorage ,' .......... Treatment description including volumes used and final pressure 14. N/A Representative Daily Average Production or Injection Data Oit-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil _~ Gas_ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~j(~ TitleArea Drilling Engineer Date Form 10-404 Rev 06/15/88 / SW01/5 SUBMIT IN DUPLICATE ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "lnitill Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District lCounty, parish or borough ARCO ALASKA INC. Ii NORTH SLOPE Field Lease or Unit KUPARUK RIVER UNIT ADL: 25631 Auth. or W.O. no. ~Title AK4125 I COMPLETIONS JSta~( 31-13 Well no, ARCO API: 50-029-21923 Operator ACCEPTED 05/19/89 18:00 ARCOW.I. IOate IHour Pr or status f NORDIC i I I Complete record for each day reposed RIH WITH COMPLETION. 7"0 7682' MW:10.1NACL/BR N/D TREE N/U AND TEST BOP.R/U SCHLUM AND PERF F/ 7400-7437 WITH 4-1/2" 4SPF 90 DEGREE PHASING GUNS. R/U AND RUN 2-7/8" COMPLETION DAILY:S41,946 CUM:$746,776 ETD:S746,776 EFC:$1,370,000 Spudded or W.O, begun Date and depth as°fS:~e01~/20/89 ( PB: 7605 SUPV:LP 05/21/89 ( TD: 7700 PB: 7605 SUPV:LP N/D BOP AND N/U TREE. 7"0 7682' MW:10.1 NACL/BR RUN 2-7/8" COMPLETION. M/U HANGER, TEST CONTROL LINE TO 5000 PSI. SET PACKER WITH 1500 PSI, PRESS UP AND TEST TUIBING WITH 2500 PSI. PRESS ANNULUS TO 1500 PSI AND RELEASE PBR W/ 9,000# P/U OVER STING WT. PRESS ANNULUS TO SHEAR OUT CK VALVE. COULD NOT SHEAR-PRESS LEAKING BY VALVE. PULL CK VALVE WITH SLICKLINE. REPLACE WITH DUt~Y VALVE. TEST CASING TO 2500 PSI-OK. ATTEMPT TO TEST TBG- LEAKING PAST BALL? SET STANDING VALVE IN D NIPPLE. TEST TBG TO 2500 PSI-OK. PULL DUt~4Y VALVE AND REPLACE WITH ORIFICE VALVE.TEST SSSV TO 2500 PSI-OK. ATT. TO PULL STANDING VALVE FROM D NIPPLE. FOUND ORIFICE VALVE ON TOP OF STANDING VALVE. PULL ORIFICE VALVE AND SET IN MANDREL. PULL STANDING VALVE. PRESSURE UP ON TUBING TO SHEAR OUT SOS. CHASE SAblE WITH SINKER BARS TO INSURE BALL IS SHEARED OUT.SET BPV, N/D BOP, AND N/U TREE. OTIS SSSV 0 1791', AVA RHS PKR 0 7136' TUBING TAIL 07208' DAILY:S124,547 CUM:$871,323 ETD:S871,323 EFC:$1,370,000 a W.O. RECEIVED Jasi(a 0/1 & Gas Cons. C0rnr~]is$i0r~ Anchorage The above is correct Signatur~ ~ For form preparation Fhl[I distribution, see Procedures Manu[~J,,_.iSection 10, Drilling, Pages 86 and'3"'/, Date I Title AR3B-459-1-D Number all daily well history forms consecutively as they are prepared for each we . iPage no, ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Ral3~rt" 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 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. j Accounting coat center code District St at oj~,{ ARCO ALASKA INC. IWell no. ICounty or Parish NORTH SLOPE ~Lease or Unit KUPAROK RIVER UNIT I ADL: 25631 31-13 ITitle I COMPLETIONS Auth. or W.O. no. AK4125 A.R.Co. w.I. 05/19/89 NORDIC I jDate Complete record for each day reported 0) RIG RELEASED ARco Operator &CCEPTED Spudded or W.O. begun Date and depth as of 8:00 a.~).5/22/89 ( PB: 7605 SUPV: LP 50-029-21923 Iotal number of wells (active or inactive) on this est ceJS(tr(~Oior to plugging and I bandonment of this well I our I Prior status if a W.O, I 7"@ 7682' MW: 6.8 DIESEL T~T TR~ ~';D ['ACI~ C~ TC ~000 PSI. PULL TEST PLUG. DISPLACE WITH 265 BBL DIESEL. SET BPV, SECURE WELL AND RELEASE RIG. SITP 1000 PSI, SICP 0 PSI. RIG RELEASED AT 0930HR 5/21/89. DAILY:S16,905 CUM:$888,228 ETD:S888,228 EFC:$1,370,000 Old TD PB Depth Released rig Kind of rig New TD Date Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) I Producing method I Official reservoir name(s) I Potential test data The above is correct Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. !C P Water % GOR !Gravity iAllowable Effective date corrected _. Drilling, Pages 86 and 87. Number all daily well history forms consecutively I Page no. "~ as they are prepared for each well. AR3B-459-3-C Dl~lNon of AtlantlcRIchfleldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown ~ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate ~ Change approved program __ Pull tubing ~ Variance __ Perforate ~ Other 2. Name of Operator ARCO Alaska, Inco 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development .,. Exploratory __ Stratigraphic ~ Service __ 4. Location of well at surface 115' FSL, 85' FEL, 5ec.36, T13N, R8E, UM At top of productive interval 1180' FNL, 1500' FWL, Sec. 6, T12N, R9E, UN (approx) At effective depth 1368' FNL, 1921' FWL, Sec. 6, T12N, Rgw, UN (approx) At total dep_th 1404' FNL, 1974' FWL, Sec. 6, T12N, RgW, UM (approx) 6. Datum elevation (DF or KB) RKB 116' 7, Unit or Property name Kuparuk River Unit 8. Well number 31-13 9. Permit number 89-25 10. APl number 50-- 029-21923 11. Field/Pool Kuparuk River Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth' measured true vertical 7700 'MD feet 6470 ' TVD feet 7605 ' MD 6400 ' TVD feet feet Plugs (measured) Junk (measured) None None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 3489 ' 8208' measured None true vertical None Size 1 6" 9-5/8" 7" Cemented Measured depth 291' sx CS II 1085 sx AS III & 360 sx Class G 200 sx Class G 115'MD 3524'MD 7683' MD True vertical depth 115'TVD 3382'TVD 6457'TVD Tubing (size, grade, and measured depth) None Packers and SSSV (type and measu;¢d depth) Rone 13. Attachments Well History Description summary of proposal Detailed operations program BOP sketch __ 14. Estimated date for commencing operation May 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ..¢_ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed F-,.~' ~ Title Area Drilling Engr. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10- - Approved C~opY ORIGINAl_ SIGNED BY ~Returne° Approved by order of the Commissic~ONNIE C. SMITH ~missioner Form 10-403 Rev 06/15/88 Date 066/SA4 I Appr°val N°' ¢-,~ ~ Date SUBMIT IN TRIPLICATE ARCO Oil ~,.J Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the 'lnltill Reporl" on tho first Wednesday after a well is spudded or workover operations are Itarted. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ICounty, parish or borough ARCO ALASKA INC. I NORTH SLOPE Field ILease or Unit KUPARUK RIVER UNIT I ADL: 25631 Auth. or W.O. no ITM AK4125 I DRILL API: 50-029-21923 Operator ARCO StetL 31-13 [Well no. Spudded or W.O. begun IDate IH°ur SPUD 03/13/89 19:30 Date and depth Complete record for each day reported as of 8:00 a.m. DOYON 14 IARCO W I 55,8533 Prior status if a W.O. 03/14/89 ( TD: 1245'( 1 SUPV:EEV 03/15/89 ( TD: 3536'( 2 SUPV:EEV 03/16/89 ( TD: 3550'( SUPV:ZR 03/17/89 ( TD: 6695'( 3 SUPV:ZR 03/18/89 ( ~ TD: 7700' ( 1, SUPV:ZR 03/19/89 ( TD: 7700'( SUPV:ZR t) Z45) Z) ;-91) ~) 14) ) 45) ~) )05) ;) o) DRILLING MW: 9.5 VIS: 67 MOVE RIG FROM 31-16. N/U AND TEST 20" DIVERTER SYSTEM. SPUD IN AT 1930 HR 3/13/89. DRILL F/115' TO 1245' DAILY:S62,265 CUM:$62,265 ETD:S62,265 EFC:$1,370,000 SHORT TRIP TO HWDP MW: 9.3 VIS: 42 DRILL 1245 TO 3536, CBU AND PUMP PILL, SHORT TRIP TO HWDP. DAILY:S48,516 CUM:$110,781 ETD:S110,781 EFC:$1,370,000 DRILLING CEMENT 9-5/8"@ 3524' MW: 8.4 VIS: 30 DRILL TO 3550. CBU, SURVEY AND POOH. R/U AND RUN 9-5/8" CSG FS @ 3524'. R/U DOWELL. CIRC AND CONDITION MUD AND CEMENT W/1085 SX AS III, 360 SX CLASS G. N/D DIVERTER AND NIPPLE UP AND TEST BOP. P/U BHA AND RIH. TEST CASING TO 2000PSI. DRILL OUT CEMENT. DAILY:S211,715 CUM:$322,496 ETD:S323,379 EFC:$1,369,117 DRILLING 9-5/8"@ 3524' MW: 9.3 VIS: 32 TEST CASING TO 12.5. DRILL CMT, FS AND 10 NEW FORM. TEST SHOE TO 12.5 PPG EMW JUG TEST. DRILL FROM 3560 TO 6695. DAILY:S69,926 CUM:$392,422 ETD:S386,469 EFC:$1,375,953 LOGGING 9-5/8"@ 3524' MW:10.0 ViS: 39 DRILL 6695-7700. CCM AND SHORT TRIP TO LOG. POOH. L/D BHA. R/U SCHLUM AND LOG W/DIL/SFL/GR/SP/FDC/CNL/CAL DAILY:S56,322 CUM:$448,744 ETD:S442,791 EFC:$1,375,953 RUNNING 7" CASING 7"@ 7682' MW:10.1 VIS: 41 TAKE SIDEWALL CORES. M/U BHA AND RIH. REAM/WASH FROM 7570-7700'. CBU AND COND HOLE TO RUN CASING. PUMP AND SPOT DIESEL PILL. POOH WITH 5 STANDS-HOLE VERY TIGHT. RIH TO BOTTOM. POOH L/D DP. PULL WEAR BUSHING. R/U AND RUN 7" CASING W/SHOE @ 7683'. DAILY:S111,039 CUM:$559,783 ETD:S553,830 EFC:$1,375,953 The above is cor/e~ct Signature ~'t i ~ For form preparatio~"-~nd distributi(~, see Procedures M~I, Section 10, Drilling, Pages 86 a~d 87. Ddlllng Supt. AR3B-459-1-D INumber all dally well histo~7 forms consecutively ss they are prepared for each well. iPage no. ARCO (. 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, "Final Report" should be submitted also when operations are suspended for an Indefinite or appreciable length of time. On workovera when an official test Is not required upon completion, repod completion and representative lest data in blocks provided. The "Final Repod" form may be used for reporting the entire operation if space is available. J Accountlng cost center code ~co ~as~ i.c. I NORTH SLOPE I ~L: 25631 ~-1~ KUPARUK RIVER UNIT Auth. or W.O. no. ITitle AK4125 I DRILL Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 03/20/89 ( TD: 7700 PB: SUPV:ZR API: 50-029-2 ],9~3 AR.Co. W.I. Il-oral number of wells (active or inactive) on this~ Icost center prior to plugging and 55. 8533 labandonment of this well Date Hour I Prior status if a W.O. I 03/13/89 19:30 Complete record for each day reported DOYON 14 RIG RELEASED 7"@ 7682' MW: 0.0 LSND RU DOWELL. PUMPED 10 BBLS CW100, 20 BBLS SPACER 3000. CMTED W/ 200 SXS OF CLASS "G" CMT AT 15.8 PPG. CIP AT 10:00 HRS, 3/19/89. ND FLOWLINE, CHOKE- LINE, BOPE STACK. SET CSG SLIPS. M1%KE ROUGH CUT. LD LANDING JT, MADE FINAL CUT. INSTALL TBG SPOOL, PACK-OFF. TEST TO 3000 PSI. OK. DISP W/ 75 BBL DIESEL CAP. RIG RELASED AT 15:00 HRS, 3/19/89. DAILY:S145,047 CUM:$704,830 ETD:S704,830 EFC:$1,370,000 Old TD New TD Released rig Date Classifications (oil, gas, etc.) IPB Depth Kind of rig Type completion (single. dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length 'Choke size T,P. C.P. Water % GOR Gravity Allowable Effective date corrected :ihgen abo~,~ ....... t Date -- I Title ~.,~~/ ~ ,//c//~ 9, DrillinO Supt. Drilling, Pages 86 and 87. AR3B-459-3-C INumber all dally well history forms consecutively ,- ~v' ?~i~,- las they are prepared for each well. iPage no. Dlvl'~on of Afl~ntlcfllchfleldCompany ARCO Alaska, Inc. Date: April 5, 1989 Transmittal Ct: 7453 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. 31 - 1 6 OH Edit Tape and Listing 3 - 1 7 - 8 9 # 7 3 1 9 0 31 - 1 3 OH Edit Tape and Listing 3 - 2 9 - 8 9 Ct 7 3 2 0 9 31 - 1 7 OH Edit Tape and Listing 3 - 3 1 - 8 9 ct 7 3 2 4 7 Receipt Acknowledged' Alas[;a Oil & ~s Co~s. Commissiou ........................... Date: .... -- ....... OISTRIBUTION: State of Alaska Lynn Goettinger ARCO Alaska, Inc. Date: April 5, 1989 Transmittal #: 7455 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATe-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; -17 2" & 5" Porosity FDC 3-26-89 6630-7270 -1 7 2" & 5" Raw FDC 3-26-89 6630-7270 - 1 7 Cyberlook 3-26- 89 6650-7250 -1 7 2" Dual Induction - SFL 3-26-89 1 000-7294 -1 7 5" Dual Induction - SFL 3-26-89 1000-7294 -1 3 Core Summary 3-1 8-89 4829-6478 -13 2" & 5" Porosity FDC 3-18-89 7100-7670 -1 3 2" & 5" Raw FDC 3-1 8-89 71 00-7670 -1 3 5" Dual Induction - SFL 3-1 8-89 3522-7700 -13 2" Dual Induction- SFL 3-18-89 3522-7700 - 1' 3 Cyberlook 3- 1 8- 89 71 00-7600 Receipt Acknowledged: ........................... Date- - - .. Anchorage DISTRIBUTION: NSK Franzen Drilling D&M State of Alaska (+sepia) ID:DOYON RIG 1~ TEL NO:B59-?693 ST/,,Tg OF ALAS AL^SY¢, Oil. & CAS CONSERYAT]O)~ CDHH]SS]ON ~372 PO1 Dri21in Contractor! LgcatSon, C, eneral. ~-' Well C, enerhl Hbu~ekeeping_~ z~ B~g Reserve Pit Trip Tank · _.{~ Pit Cauge .,, Audio 'Annular P~eventer__14 Pipe Ram~ Blind Rams 'Choke Line Yalves Kill Line Check Valve ~£~/t0_o0 ,' - .. ~ s~ .3 oo.o ..... Test Results: Failures Repair or Replacement of failed equipment ¢om~i~sion office notified. ~emark~: ~_ R~p~esent atJve~~ ~3 %.6 _ Permit ~__~-~ S .......... ACCUI~LATOR SYSTEM Full Cha~Ee P~essure_~60 psi~ Pressure A{ter Closurm_~ Pump inet, c]os. pies. 200 Full Charge Pressure Attained:___ ~...~tn~7 sec. Controls: Master O~ ~Remote ~Mlind$ switch cover ,- __ Ke_~ly and Floor Safety~ Valves Upper Kelly_~i~T~st Pressure. Lowe'r Kelly.~_~ ._Test Pressure~~~ -..~ Ball Type ......... ~_.__Test Pressure~~~~, Ins/de BOP ..... ~...ffest Pressure_~~~ No. flanges .... ~ Adjustable Chokes ~. ,~.K Te~t T~ ~.hrs. ' to-he made within days and Inspector/ Distribution cc - Operator cc - Supervisor February 22, 1989 Telecopy: (907)276-7542 Mr. P. J. Archey Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3I- 13 ~RCO Alaska, Inc. · Permit No. 89-25 Sur. Loc. ll5'FSL, 85'FEL, Sec. 36, T13N, RSE, UM. Btmhole Loc. 1314'FNL, 1227'FWL, Sec. 6, T12N, R9E, UM. Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. k~, "~ ' \ I~'~':-'~?. Chat~n of Alaska Oil ~nd Gas Conservation Co~ission BY ORDER OF ~E COmmISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. "-" STATE OF ALASKA ALASKA (J,L AND GAS CONSERVATION COIvlMISSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill I~' Redrill E;]I lb. Type of well. Exploratory [] Stratigraphic Test [] .,Development Oil Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone I~' Multiple Zone I_1 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska~ Inc. Pad 40' KB 76 feet (uparuk River Field 3. Address 6. Property Designation (uparuk River Oil Pool p n n~,Y ~ nn~n An~-hnrnnc, Ak' qqc, ln_n~n AF)I 2RCfil AI.K 2564 4. Location of welt a~ surface ~ ' 7. Unit or property Name 11. Type Bond(see 20 AAC 25.02S) Kuparuk River Unit Statewide tFoSp 8.5 'F. EL-- Sec 36 T1 3N R8E UM 11/~t' Ldf prooucz~ve i'nterva' ' ' ' 8. Well nu .mber Number llSOt'FNL'A 1500'FWL, Sec. 6, T12N, RDE, UM 31-13 No. U-630610 total depth 9. Approximate spud date Amount 1314'FNL, 1227'FWL, Sec. 6~ T12N~ RDE~ UM 02/26/89 $200~000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in prc~perty' 15. Proposed depth (MD and TVD) property line Well 31-12 7640'MD ~ Tn 1777, feet ~ _,,,~.~=~¢_~. :~,,, feet 2b. 37 6465'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 2115' feet Maximum holeangl~1-9° Maxirnumsurface 2000 psig At total depth (TVD) 6126 3000 psig 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 37' 37' 117' 117' +200 cf 12-1/4" 9-5/8" 36.0# J-55 BTC 3475' 37' 37' 3512' 3391 ' 738 sx CS II I I-F-ERW 359 sx Class G 8-1/2" 7" 26.0# J-55 BTC 7604' 36' 36' 7640' 6465' 200 sx Class G ~ F-ERW 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor,~,F, EIVEp Surface ?~ ~ Intermediate Production ~ L . Liner ~-!~iaska,0il & Gas Cons~ C0mmissb::, Perforation depth: measured ; ~.,',~, ~ncho age true vertical 20. Attachments Filing/fee Property plat ~ BOP Sketch [~ Diverter Sketch I~¢ Drilling program ~ Drilling fluid program ~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge ¢ ~ ~'~¢..e.y Title Area Drilling Engineer Date Signed ["'/ Commission Use Only i ( J T Z) PD~ /~¢e2cover letter Permit Number APl number Approval date ~'?-.~ ~ 50-02. '~- ~ / ~---3 02/22/89 for other requirements Conditions of approval Samples required [] Yes ~ No Mud Icg required Lq Yes ~ No Hydrogen sulfide measures [] Ye~~No Directional survey required /~Yes [] No R equiredwork~~/~~ ~~ .~~ F1 10M; F1 15M ~'~~ Other: by order of Approved by ( /~ .. Commissioner the commission Date Form 10-401 Rev. SubCl/t GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. MIRU. 2. Install FMC diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8~" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. 23. Perforate remaining zones. ! h SHALE ~HAKF. R~ STI :~TIR STIR MUD CLEANIIII CENTRIFUGI TYPICAL MUD SYSTEM SCHEMATIC Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casin~ ~,o Weight Up 9.,O-9.8 8.7-9.2 Weight Up to TD 9.9 PV 15-30 5-15 11-16 YP 20-40 8-12 8-12 Viscosity 50-1 O0 35-40 35-50 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate AP1 20 10-20 pH 9-I0 9.5-10.5 9.0-10.5 % Solids 10'_ 4-7 12-15 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 127' of departure, there are no well bores within 200' of this proposed well. JTZ/14 ih In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. ], [.~'V'.~,.? ARCO ALASKA, [ne. Pad 3I, Wel I No, 13; Revised Pr'oposal Kupar'uk Field, No.th Slope, Alaska 1 000._ 2000 _ 3000 _ 4000_ 5000 _ 6000 _ TO00 RKB ELEVATION, ?6' B/ PERHAFROST TVD-1 651 KOP TVD'2115 THD=2115 DEP--O :s T/ UGNU SNDS TVD-2216 THD=2216 DEP-3 g BUILD 3 DEG I 5 PER 1 oo FT T/ 14 SAK SNDS TVD-2791 THD'--2806 DEP-124 33 39 K-12 TVD=3191 THD=3258 DEP=332 EOC TVD=3390 THD=3510 DEP-488 9 5/8" CSG PT TVD'-'3391 THD-3512 DEP-489 K-lO TVD-3466 THD-3613 DEP-556 TVD-4526 TMD-5036 DEP-1506 AVERAGE 41 DEO ANOLE 52 HI N TAROET TVD-6126 THD~7185 DEP-2940 T/ ZONE A TVD-6206 THD=?292 DEP-3011 B/ KUP SNDS ?VD=6316 THD-7440 DEP-3110 TD (LOG PT) ?VD-6465 THD-7640 DEP=3243 I 1 000 VERTICAL I 2000 SEC T I ON 3000 4000 HORIZONTAL SCALE 1 IN. PROJECTION = !000 FEET 1 000 z 0 _ ~ 1 000 _ TD LOCAT [ OH' 1314' FNL. 1227' FWL SEC, 6. T12N. RgE 2OOO TARGET LOCAT [ ON ~ 1180' FNL. I~' FWL SEC. 6. T12N. RG4E ARO0 ALASKA, I no · Pmd 3I. Well No, 1~ Revleed Pr'opomal Kuperuk Field. Nor'th Slope. Almmkm WEST-EAST 4000 3000 2000 1 000 0 I I I TARGET TVD-6126 TIID-? 185 DEP*.,2940 SOUTH 1295 WEST 2e39 SURFACE S 63 DEG 52 HI N W 2940' (TO TARGET) 1 000 ! SURFACE LOCATION~ 115' FSL. 85' FEL SEC. 36. TI3N. ReE KUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC DESCRIPTION 1, 16' CONDUCTOR 2. FMC SLIP~3N WELD STARTING HEAD 3, FMC DIVERTER ASSEMBLY WITH TWO 2-1/16' 2000 PSI BALL VALVES 4. 20' 2000 PSI DRILLING SPOOL W110' OUTLETS 5. 10' HCR BALL VALVES W/10' DIV~ LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CX:)NT1R~ I ;n TO ACHIEVE DOWNWIND DIVERSION. 6. 20' 2000 PS1 ANNUl. AR PREVENTER ARCO ALASKA, INC., REQUESTS APPROVAL (3= THIS D~=RTER SYSTEM AS A V~.q~ FROM 20AAC25.035(b) MAINTENANCE & OPERATION I ! 1. UI::~N INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED, OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES 7 G 4 ~ ~J~T ~ PLUg Zg ~TH ~t,N~l~G_J~ lN L~K~/~~ ~ 4. P~E~gt~E L~ TO 2gO I~Z ~ I.a.D ~'~R ~0 ~IN, Z~- gLEED I=~lEg~.l~ TO 0 pljZ. LII"~ V,aLVE,~ CI..C~: TCP Pll:~ I~ ~ ~ V,N.v'E,S CN KIlL ~ ~ I. ll~, s'rlcp 4, ~ 8. ~ TCP P]:I:~ ~ NqD CL~ BOI"T~ PIPE ~ =~ '~ ~URVEY SCALE: I' = I MILE ~L NOTES _ ~ I, C~Dt~TES ARE A.S.E, ZONE 4. 2.~CTION LINE DISTANCES ARE TRUE. ~ ~ZONTAL POSITIONS BASED ON ON-PAD CONTROL ~R L.H.D. ~ ASSOC. 4. VE~ICAL POSITIONS BASED ON TBM 3[ - 4 PER LHD & ASSOC. ~ ~& ELEVAT~NS INTERPOLATED FROM S/C DWG. CED- RlXX - 3050 rev. ~ LOCATED IN PROTRACTED SEC.31,TI3 N~ RgE~ U. MER. LOCATED IN PROT~TED ~C.~TI~ ~ R 8E~ U. MER. , 1- Y= 6,007,285.50 LAT. 70°25'52.059~'' 9- Y= 6,007,121.00 LAT. 70"25'50.443~ X= 508,056.44 LONG. 149056'03.596" X= 507,867.91 LONG. 149~56'09.134" 179' FWL, 345' FSL 0G. 33.6', PAD 39.9' 180' FSL, 10' FEL 0G. 35.0', PAD 39.9' 2- Y= 6,007,269.06 LAT. 70°25'51.8978'' 10- Y= 6,007,104.59 LAT. 70°25'50.2821" X= 508,037.66 LONG. 149°56'04.148" X= 507,849.11 LONG. [49~56'09.686" 160' FWL, 328' FSL 0G. 33.7', PAD 39.9' 164' FSL, 29' FEL 0G. 35.0, PAD 40.0 3- Y= 6,007,252.70 LAT. 70°25'51.7370'' 11- Y= 6,007,088.16 LAT. 70°25'50.1206'' X= 508,018.80 LONG. 149°56'04.702'' X= 507,830.23 LONG. 149°56'10.240'' 141' FWL, 312' FSL 0G. 33.7', PAD 40.0' 147' FSL, 48' FEL 0G. 35.0, PAD 40.~ 4- Y= 6,007,236.23 LAT. 70°25'51.5752'' 12- Y= 6,007,071.76 LAT. 70°25'49.9595" X= 507,999.99 LONG. 149056'05.255 X= 507,811.32 LONG. 149°56'10.796'' 122' FWL, 295' FSL 0G. 33.8', PAD 40.0' 131' FSL, 66' FEL 0G. 35.0, PAD 40.1 5- Y= 6,007,219.81 LAT. 70°25'51.4139" 13- Y= 6,007,055.32 LAT. 70°25'49.7981'' ' X= 507,981.16 LONG. 149°56'05,808'' X= 507,79Z.36 LONG. 149°56'11.353" 104' FWL, 279' FSL 0G. 33.9', PAD 40.0' 115' FSL, 85' FEL 0G. 35.0', PAD 40.1' 6- Y= 6,007,203.20 LAT. 70°25'51.2507'' 14- Y= 6,007,038.82 LAT. 70025'49.6359'' . X= 507,962.12 LONG. 149056'06.367" X= 507,773.63 LONG. 149°56'11.903'' 85' FWL, 262' FSL 0G. 34.0', PAD 39.9' 98' FSL, IC4' FEL 0G. 35.0, PAD 40.1' 7- Y= 6,007,186.78 LAT. 70°25'51.0895'' 15- Y= 6,007,022.A2 LAT. 70025'49.4749" X= 507,943.27 LONG. 149056'06.920" X= 5C7,754.83 LONG. !49°56'12.455" 66' FWL, 246' FSL 0G. 34.2', PAD 39.8" .82' FSL, 123' FEL 0G. 35.0', PAD 40.2' 8- Y= 6,007,170.37 LAT. 70°25'50.9282'' 16- Y= 6,007,006.02 LAT. 70°25'49.3137'' X= 507,924.40 LONG. 149°56'07.475'' X= 507,736.04 LONG. 149056'13.007'' I 47' FWL, 230' FSL 0G. 34.5', PAD 39.8' 65' FSL, ~42' FEL CG. 35.0', PAD 40.2' a i i i ,,, CERT!~tC ATE OF ~ RVEYOR : i H~R[~Y ;~ FY T~AT I AM PROP[~LY MADE BY ME OR ~N~R MY SUPERVISION, AND ~.~ .~e .. , ~, ,, , ~.- . ~.~ oo..~:~ ~.:.4a I,,~w,w. DRILL SITE 5Z CONDUCTOR ~~ ~c~~ AS-BUILT LOCATIONS t~*"-- ~SArcr,c Boulevard, Suite 20~. ~nchorage, ,~laska ~9503 tissue AS SHOWN i ' i .... I"~' II 25O 200 - 150 _ I 100 _ J I I .50 _ I 0 _ J $0 350 ,, I 350 300 250 200 1 50 1 O0 50 _ k'38 * 5 / / / '"1'3 I 3OO / 5 13 d.5 I ' 14 15 16 10 11 12 14 15 16 250 200 150 100 5O 0 5O _ 250 _ 200 _ 150 _ 100 _ 5O _0 _ 5O STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: THE APPLICATION OF ARCO ) ALASKA, INC. for an order ) granting an exception to ) Rule 4(c) of Conservation ) Order No. 173 for wells to ) be drilled from 15 drill ) pads in the Kuparuk River ) Field. ) ':'.!CHORAGE ..... Conserval:ion Order No. 209 Kuparuk River Field Kuparuk River Oil Pool May 23, 1985 IT APPEARING THAT: · ARCO Alaska, Inc., by letter dated April 30, 1985, requested the Alaska Oil and Gas Conservation Commis- sion to issue an order granting an exception to Rule 4(c) of Conservation Order No. 173 to allow surface casing to be set as deep as 4150 feet true vertical depth in development wells to be drilled from drilling pads 1R, 2A, 2H, 2T, 3A, 3B, 3C, 3F, ~3%, 3J, 3K, 3M, 3N, 30 and 3Q. · Notice of public hearing was published in the Anchorage Times on May 7, 1985. ® There were no protests to the request set forth in the notice of public hearing. FIND INGS: · The Ugnu sands and the West Sak sands are hydrocarbon- bearing and potential reservoirs in some areas of the Kuparuk River Field. · The West Sak sands are or could be hydrocarbon-bearing in the ~rea of drilling pads 1R, 2A, 2H, 2T, 3A, 3B, 3C, 3F, 3I, 3J, 3K, 3M, 3N, 30 and 3Q. ~ The oil in the West Sak and Ugnu sands has a low solution GOR and has no known gas-oil contact. Conservation Page 3 May 23, 1985 r No. 209 NOW, THEREFORE, .IT IS ORDERED: Development wells to be drilled to the Kuparuk River Oil Pool on drilling pads iR, 2A, 2H, 2T, 3A, 3B, 3C, 3F, 3I, 3J, 3K, 3M, 3N, 30 and 3Q may be drilled to a maximum 4150 feet true vertical depth before surface casing is set provided that conductor casing is set and cemented in accord with Conservation Order No. 173, a diverter system is used in accord with 20 AAC 25.035(b)(1) and a drilling fluid of at least 9.0 pounds per gallon is used in the drilling. DONE at Anchorage, Alaska and dated May 23, 1985 C:'V Chatterton~ Alaska Oil and Gas Conservation Commission Ha~ry W Kugler, Commzssioner Alaska Oil and Gas Conservation Commission L'O'nnie C. Smi~,~G~mm~ r Alaska Oil and Gas Conservation Commission CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE Fee ' PC 1. (2) Loc (8) · (9 thru13~ 10. (10 and 13) 12. 13. (4) Casg (14 thru 22) (23 thru 28) 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. For ( 6> OTHER ,~,Pc'"'_ F~oz/~s~ 2 9. (29 thru 31)--~ 30. 31. (6) Add: ~,.~'~/. ~ ~. · '7- & e 32. Geo lo gM: Engin~ee~ring: rev: 01/30/89 6.011 Lease & Well No..~.~_. ~qZ~- Z~{/ .~' I~/? YES NO REMARKS - Company Is the permit fee attached .......................... .. .... ... ... eeeeeee 2. Is well to be located in a defined pool ............................. ~ 3. Is well located proper distance from property line .................. AP 4. Is well located proper distance from other wells .................... ~-- "' 5. Is sufficient undedicated acreage available in this pool ............ ../~ 6. Is well to be deviated and is wellbore plat included ................ ~ 7. Is operator the only affected party ................................. A~ ' 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ...................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to 3o~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones~ · eeleee®eeeeeeeeee Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented . Additional requirements ............................................. ~ Additional Remarks": INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ~0 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. ****************************** .,.,.,..... .,',..,,, FIELD NA~g : STATE : ASASKA BOROUGH : NORTH SbOPE APl NU~BE~ : 50-029-21923-00 REFER.~NCE NO : 73209 LIS Ta~e Verification List. i, nq Schlumberger AlasKa Computln~ Center 30-MAR-1989 i6~39 : EEL NAME : 73209 CONTINUATION # PREVIOUS REEL COMMENT : A~C[ ALASKA INC,,KUPARUK ,3 I ***~ TAPE HEA DF;... SERVICE NA~E : EDIT DATE : 89/0]/30 RIGIN :. F~IC ~p~:'NAM~: : 73209 CQ~INUATION ~ : 1 PREVIO'aS TAPE : COMMENT ~ ARCO ALASKA INC,,KUPARUK ,3 **** FIrE HEADER FILE ~ME ~ EDIT 001 SERVICE : F~IC VERSION : 00lA02 DATE : 89/03/30 MAX REC SIZE : 1096 FISE TYPE : bO LAST FILE SCHLUMBERGER WE~ SERVICES COMPANY NAME: ARCO ALASKA INC, W~LL: 3 I - 13 FIELD: KUPARUK BOROUGH: NORTH SLOPE STATE: ALASKA AP[ NUMBER: 50-029-21923-00 LOCATION: 115' FSL, 85' FEb SECTION: 36 TOWNSHIP: 13N PERMANENT DATUM: MSL LOG MEASURED FROM RKB O, ELEVATION: O, ABOVE PERMANENT RANGE: BE DATUM LIS Tape Verification bAsting SchlUmberger AlasKa ComP~ting Center 30-MAR-1989 16:39 ELEVATIO, S OATE bOGGED '~D DRILLER: TD ~OGGER. C SING I ~ KB: 76, DF: 75. Gbl 40. !.~-MA.R~89 7 04, 7708, 9 5/8 ~ DRILLER [.EP~H OF 3524 AND LOGGER DEPTH OF 3522 · B, !T' SiZE t: 8 1/2 TYPE FLUID DE!-N~iOLE: bSNO PO~Y SITY: 9.299999 VISCOSITYI 9, ~UD RES!S~IVlTY. 5,38 T'I..~ CIE~JLATION ENDED: 2~.60 T~E L. OGCER oN ~OTTO~:' 050 MAXIMUM TEM=P RECORDED: 142, [,O~G~NG ENGINEER: ~I~NESS: TOOL NUMBERS: ~GC-JC-3109 PGC-JC-O00 DIC-DA-1006 G, ~ARBER Z, UNJE/B, BEAL CNC-A-1238 PGS-HB*508 DIS-EC-1100 FIELD REMARKS: I 1/2" STANDOFFS AND A 2' HOLE FINDER USED ON THE DIL, NEUTRON MATRIX = SAND, CORRECTION = CA I ~R. DATE JOB STARTED: 29-MAR-89 jOB REFERENCE NO: 73209 LDP/ANA: R. SINES FILE - EDIT,O01 ARCO ABASKA 1NC, K~PARUK 3 I - 13 50-029-21923-00 DATA SAMPLED EVERY -,5000 ~EET TOOLS INCLUDEO- LIS Tape Verification Listing Schlumberger AlasKa Computing Center 30-MAR-Igsg 16~3g * DIT-D * ~oc * CNT-A , Ga IN CASING ******************************************************************************* PAG~I 3 TA...iLE TYPE TUNI VALU DEFI CN ARCO A~ASKAINC, Comp FN ~UPARUK Fie~ aell WN NATI COUN Fb SgCT RANG LATI APIN 31-13 USA ABASKA NORTH SLOPE G SARBER 7~209 5 "029'21923'00 Nation State or Province County Field"Location ~ectio~ fownshlp Range Latitude 6ongltude Engineer's Name Service order Numoer API Serial Number TABLE TYPE : CURV DEFI IL-Dee¥ Rosistivl~ IL-Bed um Reslsti ty SFLU SFL ~naveraged SP Spontaneous Potential GR Gamma Ray IENS Tension DPHI Densit~ Porosity RHOB Bulk O nslty DRHO Delta rho FFDC Far MOL Count Rate NFOC Near MDC Count Rate CAbI Caliper GR Gamma Ray TENS Tension NPHI ~MUTRON POROSITY TNPH THERMAL NEUIRON POROSITY YNRA CALIBRATEO THERMAL NEUTRON RATIO NPO~ N~UTRON POROSITY OUTPUT FROM AN APPLICATION PROGRAM LIS Tape verification Listing Schlumberger AlasKa Computing Center 30-NAR-1989 16139 DEF! RC~T RAw CORRECTED NEAR THERMAL COUNTS RCF~' RA~ CORRECTED ~AR '~ ER~AL COUNI,~ CNTC CO ' ' ..... M RR~CTED NEAR :'HE~ AL COUNTS amma Ray ADI Caliper ~NS Tension ~ Ray on PAGE: ** DATA FORMAT SPECIFICATION RECDRD SET TYPE - 64EB ** '''''''''' ~ ~3''"'"''''''' ~'""'TYPE CODE 2 66 0 ] 73 4 66 5 66 6 73 7 65 9 65 1~ 66 9 12 68 13 66 ~4 65 F1 15 66 68 16 66 I 0 66 0 ** SET NAME SERV UNIT ID DEPT FT 5 ILD DIL OHMM 5 ILM DIL OHMM 5 SFLU OIL OHMM 5 SP DIL MV 5 GR DIL GAPI 5 TENS DIL L~ 5 DPH! FDC P~ 5 RMOB FDC G/C3 5 DRHO FDC G/C3 5 TYPE = CHAN *, ERVICE AP1 RDER # LOG 'r ~8428 O0 000 O0 0 1 ! 1 4 68 48428 07 120 46 0 1 ! 1 4 68 48428 07 !20 44 0 1 I I 4 68 48428 07 220 O1 0 X I 1 4 68 48428 07 010 OX 0 ~ I 1 4 68 48428 07 310 O1 0 1 1 1 4 68 48428 07 635 21 0 I 1 ~ 4 68 48428 07 635 21 0 ~ 1 1 4 68 48428 07 350 02 0 1 1 1 4 68 48428 07 356 01 0 i ! 1 4 68 AP1 APl APl FILE NUMB NUmB SIZE REPR PROCESS YPE CLASS MOD NUMB 5A~P ELEM CODE (HEX) 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 bis Tape verification biSti_ng Sc~lumbe'rger AlasKa Computi. Center 30~MAR-1989 16~3g ID ORDER # 50G TYPE CLASS MDD NUMB SAMP ELEM CODE (HEX) FFDC FDC CPS 28 07 354 02 0 I ! ! 4 68 0000000000 O1 0 28 1 ~. FDC GAPI 548428 07 310 Ol 0 21 0 1 TENS FDC LB 548428 07 ii!! i!! PU 548428 07 ~00 PU 548428 07 O0 O0 0 54842 0 O1 ~P~ ~'g PU 54842~ 077 420 890 O0 O0 ~1, RCNT C~L CPS 548.428 07 420 01 0 RCFT CNb CPS 548428 07 420 Ol 0 CNTC CN5 CPS 548428 07 420 CFTC C'~L ' s CP~. 548428 07 420 Ol 0 1 C~! C~!b IN 548428 O. ~ 01 G~ CHh CAPI 548428 07 310 Ol O I 1 1 1 1 I 1 ! I 1 I 1 i ! 1 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 .. 68 0000000000 4 68 0000000000 4 68 0000000000 68 0000000000 68 0000000000 4 68 0000000000 DEPT SP DIL RHOB FDC CALI FDC TN~H,CNL RCfT,CNG CALI.CNL DEPT SP RHOB FDC CALl FDC TNPt~ CNL RCFT~.CNL CALI.CNL DEPT, SP.DI5 RHOB.FDC CALI.FDC TNPH.CNL RCFT,CNL CALI,CNL DEPT SP DIL RHOB FDC CALl FDC 7Z~3,500 g~ooo '999.250 DRHO -99 250 TNR~ -999.250 CNTC -999,250 TENS 7700,000 '65,125 GR 2,393 DR~O 2,066 GR 33,101 TNRA 609,956 CDTC 2,066 TENS. 7600 000 -23 516 2 537 8 609 38 374 530 970 8 609 7500.000 -23.7!9 2.454 8.453 ILD, TNRA" GR, DRHO, OR, DIL OIL FDC FDC CNL CNL DIb DI.b FDC FDC CNb OIL DIb FDC FDC CNL FDC FDC 2 788 gl 875 -999 2bO -999 250 -999 250 -999 250 -999 250 875 0.I~3 91.875 2,]42 2000, 17 3914,000 99: 0 0,078 99,500 3,146 !986.990 4004,000 3,0~7 98.875 0 093 98~875 TENS FFDC TENS CFTC GR TENS. FFDC. TENS. NPDR. CFTC. IbM, TENS. FFDC, TENS. CFIC. ILN, TENS. FFDC, TENS, ,t)Ib 2, 09 SFL ,OIL 1570,g00 DP,~ FDC -999.250 NFDC FDC -999'250 NPMI CNL -999'250 RCNT CNL -999,250 GR C~L -999.250 TENS DIL FDC FDC CNL CNL CHh O I L FDC FDC CHh FDC FDC 2 819 3914 000 748 500 3914 000 33 101 692 219 -999 250 ~ 044 4004 000 448 250 4004 000 39 220 615 098 -999 250 3.129 3950,000 570,000 3950.000 FDC FDC CNL . 3O -999 250 -999 250 -999 250 -999 250 -999.250 SFLU,DIL DPhI,FDC NFDC,FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CHL 3,093 15,564 775.500 40,361 1958 235 91:875 -999.250 SFLU.DIb DPHI.FDC NFDC.FDC NPHI.C~L RCNT,C~L GR,CNL TENS,CML 622,500 :36,572 1908'944 ' 99.500 999'250 SFLU,DIL DPHI,FDC NFDC,FDC NPHI,CNb 3,759 11.854 680,000 '45,776 LiS Tape Verification~ Listing SChlumberger~ Alaska ComPuting Center TNPM,CN5 42,045 TNRA,CNb RCF ~,.CN~ 490,507 CNTC CNb CAS. ,CN5 8,453 TEN$,CN& DEPT 'D RHOB,FDC RCFT~CNb C~LI,CNL 7400 000 -2~ 016 389 @ 719 ILL GR D~O FDC ,Ga F~C CN~C CNb TENS CNh DEPT, SP'DI~ RHOBiFDC CASI;FDC TNP~CNL RCFT,d~b CAbI.CNL 7300 000 -20 891 2 512 @ 719 34 029 724 619 8 71 9 ILD,DIL GR,D!b DRHO;FDC .NGR,FDC ~RA,CN5 CNTC,CN~ TENS;CNG TNPH RCFT DIL FDC CNb CNb CNb 7200 000 -I~ 188 331 8 555 44 600 422,172 8,555 GR DI.b ORMO FDC GR FDC TMRA CNb C~TC CNb ~ENS CNb DEPT SP RHOB CAbI TNPH RCFT CALl FDC FDC CNb 7100,000 '!1,039 2,428 8,758 41,673 458,814 8.758 IbD GR ORHO FDC GR FDC TNRA CNL CNTC CNL TENS CNb DEPT, SP,DIb RHOB.FDC CALI FDC TNPH:CN'L RCFT,CNG CALI,CNL io.ooo ~92,805 9,250 '999 250 '999 250 '999 250 '999 250 IbD,DIL GR,DIb DRHO,FDC GR,FDC TNRA,CN~ CNTC,CN~ TENS,CNL DEPT. C~bI,FDC TN~M,CNL PCFT.C~L CALI.CNL 6900,000 9,016 :999 250 .999:250 -999,~50 -999,250 GR.DIb DRHO'FDC GR.FOC TNRA,CNb CNTC.CNL ~gNS,CNb 30-MAR-1989 16:39 1983,636 NPOR CNb 9~0 CF ~C,CNb 395 .:000 GR,CHL 7 76 0 25~7 3544 250 ~g~s 000 FDC 812 NPOR OhO 000 CNr~ C~5 4 0 ~41 39000, Ob3 TENS,DIL 012 FFDC,[DC 063 TENS;foe 958 NPOR;CNb 058 CFTC~CNb oo0 GR;CHb 10~ 0 109 3 '!5 TENS I4 'FFDC 375 TENS 'i24 NPOR 30 CFIC O0 GR OIL FDC CNb CH5 2 15 113,603 3,6 3 36i,~ oO TENS DIb FFDC FDC TENS FDC NPOR CNb CFtC GR CH~ 2 088 1!0 438 -999 250 -999 250 -999 250 -999 250 -999 250 IbM,Olb EN$,DIb FDC,FDC TEN$,FDC NPOR,CN& CFIC,CNL GR,CHL 3,300 176 375 '999 250 "999 250 '999 250 -999 250 -999 250 IbM,DIL TEN$,DIL FFDC,FDC TENS FDC NPOR:CNb CF~C,CNL GR,CHL 44,032 RCNT ,CNb .574, !59 CNL 999,250 CML 7 707 3544 FDC 533 FDC 3544 28 CNb CN~ CBL 3900'000 ~PHI;FDC 405~000 NFDC~FDC ;000 ~P~I.C~b ,336 RC~T,CNL .814,321 ~ GR,C~L 999~250 ~ENS.CML i,597 SFLU DIL o ;ooo '34,500 NFDC ~DC 3704,000 NPM! CNL 45;147 RCNT CNL ~.401 G~ CNb - .250 TENS C~L 2 300 SFbU.DIL 3614 ~00 DPHI,FDC 521 O0 ~FDC*FDC 3614 000 NPHI,CNL 41 o~b ~c~,c~ -999 250 -TENS,CHL 2,138 SFbU,DIb -99 250 NFDC,FDC -99~,250 NP~I'CN~ :99 ,250 RCNT,CNL .9 :2so 3 363 SFLO,DIL 3894[000 DPHI FDC -999 250 NFDC:FDC -999,250 NPMI.C~L -999,250 RCNT,CNL -999,250 GR.CNL -999,250 TEN$,ChL PAGE. 50 9 228 3O ~ 3 2699 5O 6 128 54~ 350 500 32 40~ 2399 79I 8) 063 -999 250 i,593 ;soo 49,054 1619~249 109,~75 -999,250 2 6'30 000 45 806 1779 010 11~ 063 -99 250 2 452 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 3,982 -999,250 -999,250 -999,250 -999,250 -999,250 '999,250 bis Tape Verification Listing SChlUmberger AlasKa Comp~tin .g Center DEPT, RHOB'FDC CAbI,FDC TNPH,.CNL RCFT,CNb CALI,CNb 6800 00o .-21 313 999 250 -999 250 -999 250 -.999 250 -999 250 IbD OIL DR DC T N R CNTC CNb '~ENS CNL DEPT R~OB CALl T'NPH T RCF.~ CALl. ,FDC' FDC CNb CNb 6700,000 '999'250 '9991250 '999;250 "999,250 "999"250 IbD Lib GR DRHO FDC GR FDC TNRA CNb CNTC C b TENS CNL DEPT, CAb! RCFT CALI FDC FDC CNL Ct~b CNb 6600,000 .25,313 -999,250 -999,250 -999,250 -999,250 -999.250 ibD,DIL GR,DIL DRHO,FDC GR,FDC TN b TC,CNb NS,CNb DEPT, SP,DIh RHOB,~DC CALl,MDC TNpH,CNb RCFT,CNL CALI,CNL 6500 000 -21 141 -999 250 -999,250 -999 250 -999 250 -999 250 ILO OIL GR DIb DRHO FDC GR FDC TNRA CNL CNTC,CNL TENS,CNL DEPT, SP.DIL RHOB FDC CALl FDC TNPH CNL RCFT CNb CALl CNb 6400 000 -24 547 -999,250 -999,250 -999,250 -999,250 -999.250 I[,D.DIb GR DIb DRMO FDC GR FDC TNRA CNb CNTC CNL TENS CNL OEPT SP RHOB FDC CALl FDC TNpH CML RCFT,CNb 6300,000 '36.750 2,463 9.398 32,771 683,319 9.398 ibD,DIL GR,DIL DRHO,FDC GR,FDC TNRA,CNb CNTC,CNb TENS,CNL DEPT SP C~bI FDC TNPH CNb NCFT,CNL CAL!,CNL ~00,000 32,844 2,429 10,133 38,074 569,138 10.133 IbO,DIb GR,DIL DRHO.FDC GR FDC TNRA CNL CNTC CNb T~N$ CNb 30-MAR-19B9 16139 PAGE~ 183,560 IbM,OIL 4~ -99 '250 TENS FDC -999 -99~: ' ~50 NPOR,CNL -999 -999,250 CF1C~CNL -999 -999,250 GR,CHI, -999 -9 3 784 154 5~0 -999 2'0 '999 2~0 -999 250 -999 250 -999 250 TE.S FFDC 3 ]460 999 969 SFLU,DIL ooo D I' 'DC 250 · ~ .... CNL 250 RC~T,CNL 250 250 'tENS'CHL 3,B54 IbM,Dlb .12 ;59o -999,250 FFD~;FDC :999;2~0 TENS,FDC -999,250 CFfC,CN~ 250 NFDC ,~DC 2999~ .999,250 NP~I,CNL :999,250 RCNT'CNL 999,250 , GR,CNL -999,250 fENSiC~L 4 '999 °999 ~99 -999 -999 ~50 ~0 50 -999 -999 -999 -999 -999 211 25O 25O 5O 50 ~50 FFOC, FDC TENS FDC NPOR CNb CFTC CNL GR CHL 5 053 3430 000 -999 250 -999 250 -999 250 -999 ~50 -999 50 NFDC,FDC RCNT'CNL GR,CN~ TENS,CHb .996'2~2 .99~ '250 ,250 -999,250 '99~,250 ,250 999 -999 -999 -999 -999 46 250 250 50 250 IbM TENS FFDC FDC TENS FDC NPOR CNL CFTC CNL GR CHb 3,551 SFbU DI~ .999,250 NFDC FDC .999,250 NPHI .~50 RCNT -999,250 GR CNL -999,250 TENS CML 4 375 -999 250 -999 250 -999 250 -999 250 -99g 250 -999 250 4 106 0 106 3 2251 3214 3 017 188 074 078 000 TENS,OIL FFDC,FDC TENS,FDC NPOR,CNb CF2'C,CND GR,CMb 4 646 SFbU,OI~ 3214 000 DPHI,FDC 463 250 NFDC.FDC 3214 000 NPHI.CNL 33 379 RC~T.CNL 773,487 GR.CNL -999.~50 TE~S.CHL 5 090 11 351 577 000 34 070 2170 725 106 186 -999 250 4.1!8 101.313 0,022 101,313 3,363 2116,908 3090.000 !LM,DIb TENS,OIL FFDC,FDC TENS,FDC NPOR,CNb CFTC,CNb GR,CHL 4.092 SFLU.DIb 3090,000 DPHI'FDC 510.750 NFDC.FDC 3090,000 NPhI,CNb 36.904 RCNT.CNL 645.438 GR,CNL '999.250 TENS.CHL 3 790 13 424 599 000 38 250 2128 304 10~ 313 -99 250 AO-~AR-1989 16:39 PAGE: 8 5P RNOB FDC Cab! RCFT CNL CAS!.CNL SP' .DIL RHOB.,FD~ CAbI,FDC RCFT,CNL DEPT, SP,DIb CASI.fDC TN'P}~ CNL RCFT' .CNb DEPT, SP,DI5 RMOB,FDC CALI.FDC TNPH,CNb RCFT,CNL CAbI.CNb DEPT, SP.DIL RHOB.FDC CAbI.FDC TNPH CML RCFT:CNL CALl.CML DEPT. SP,DIL RHOB,FDC CALI.FDC TN~D.CNL RC.T,C~L 6100,000 '49.031 ,454 ,172 36,4!8 667,830 9,172 6~00,000 78,875 397 5900 000 -43 656 1~ 482 594 35 935 604 902 10 594 5800 000 -44 469 -999 250 -999 250 -999 ~50 -999 50 -999.250 570O 000 -46 969 -999 250 -999 250 -999 250 -999 250 -999 250 5600.000 -36 719 -999:250 -999.250 -999,250 -999,250 -999,250 5500,000 -38,469 -999,250 -999.250 -999 250 -999:250 Center ILO DIb GR DIb DRMO FDC GR FDC TNRA CNb CNTC CNb TENS CNL GR DIL DRHO FDC GR FDC CMTC CNL TENS CNb IbD,DIb GR,DIb ORHO,FDC GR'FDC T TENS.CNh GR,DIL DRH£~,FDC GR.FDC TNRA,CNL CNTC,CNb TENS,CNL IbD OIL GR DRHO FDC GR FDC TNRA CNb CNTC CNb TENS,CNL IhO.DIb GR,DIb DRHO,FDC GR.FDC CNT CNL ILD.OIb GR DIL DRHO FDC OR FDC C~TC CNL 4 450 92 313 9~ 0~0 · 313 23~ 096 835 3054 000 5,317 ·0;002 2663,380 3080,000 10~ 0~5 875 o 219~ 627 2980 000 !.12 9'8 -999 250 -999 250 -999 250 -999 250 -999 250 958 I0 3~3 -999 ~ -999 ~0 -999 0 -999 250 2.833 105,~3 -999, 0 '999,250 '999. 0 -999,250 2,907 110,688 '999,~50 '999. 50 '999 250 '999:250 TENS'DIL 3054. FFDC GR CHL ~999 TENS FFDC TENS ~POR CFTC .CNb 953 CHL -999 TENS FFDC TENS NPOR CFTC DIb 4 Dib 2980 ~ C 507 FDC 2980 CNL 693 ,CM~ -999 IbM TENS FFDC TENS NPOR CFTC OR DIL ~030 FDC 999 FDC -999 CN~ -99~ CN~ -99 CHh -999 IbM.DIb TENS,DIb FFOC.FDC TEN$.FDC NPOR,CNL CFTC,CNb GR,CHb 3 3060 -999 -999 -999 -999 -999 IbM,OIL TENS.DIL FFDC,FDC TENS,FDC NPOR:~Nb CFTC Nb GR,CHL 500 aFDC FDC 000 NP~I Cab 448 RCNT CmL 696 GR CNL 250 TENS.CHL TENS:DIG FFDC,FDC TENS.FDC NPORCNb CFTC:CNb 714 SFb_U,D.IL 000 DP~I, FDC 00 NFDC.FOC O0 NPMI.~' 072 RC~T ~0 GR' ,CNL 250 TENS,CHh 'U ~IL 092 SFL , oo0 DP~, DC 500 NFDC'FDC 000 N'~HI.~CNL 6 3 ~GR'CNL 2~9 RCmT;CNL 250 TENS'CtiL 4,601 11'849 8O7 -999.250 510 SFbU" 250 ~FDC.F' 250 NPBI'CNb 250 RCNT,CNL 250 GR.C~L 25O TE~S.CML 574 30 2485 62 -999 967 SFLU,DIb 000 DPHI,FDC 250 NFDC,FDC 250 NPHX.CNL 250 RCNT.CNL 250 GR.CNL 250 TE~S.CHL 2 847 SFLU.DIL 3044!000 DPHI,FDC -999 250 NFDC.FDC -999 250 NPMI.CNL :~99i250 ~CNT.CN~ 99 250 GR.CNL -999 250 TEN$.CHL . 3.745 999.250 -999 250 -999 250 -999,250 -999.250 -999.250 0 2970. 9 -999 -999: 4 -999 -999 -999 -999 -999 -999 576 25O 25O 25O 250 25O 25O 2.915 '999,250 '999,250 '999.250 '999.250 '999.250 '999.250 914 5FLU.O1L 000 DPHI.FDC 250 NFDC,FDC 250 NPHI.CNL 250 RCNT.CNL 250 GR,CNL 3.061 '999,250 '999,250 '999,250 '999,250 "999.250 bis Tape Verification 5istSng Schlumberger AlasKa Computing Center CALI.C~L -999,250 TENS,Cab DEPT, 5~00 ~P,DIb '43 R~OB,FDC '999 CAL!,FDC -999 TUPH,C~b -999 RCFT,C~5 ~999 CALI.CNL 999 000 469 GR 25O 5 0 GR 50 TaRA 250 C~.TC 2'50 TE"5 FDC FDC CUb D~T, 5300 oP~DIL -55 RHUB~FDC '999 -999 FDC ~UP~C~L -999 RCFT,C~L -999 CALI~C~L -999 000 ILD 500 GR 250 250 GR 250 T~R4 250 Ca~C 250 TEUS FDC FDC CUb Cab DEPT, 5200,000 SP,DIb -73 ~750 GR RHOB, FDC -999 ]~50 DRMO C.~LI.fDC -999,250 GR TaPS'Cab -999,250 RCF'.[, CML -999,250 CNTC CALl,Cab -999,250 TENS OIL FDC F~C Ca5 CUb OEPT, 51.00 SP,Olb -45 RMOB.FOC -999 CAbI,FOC -999 TNPM,C~L -999 RCFT CNL -999 CALl:Cab -999 000 lbo 438 GR 250 ORHO 250 GR 250 TaRA 250 CNTC 250 TENS DIb FDC FOC cab Cab CNt~ DEPT. 5000 SP.DID -42 RHOB.FDC -999 CALI.FDC -999 TNP}{.C~L -999 RCFT.CNL -999 CALl.CML -999 000 IbD 000 GR 250 DRHO 250 GR 250 TaRA 25O CN~C 250 TENS FDC FOC CNb Cab Cab OEPT. 4900 SP,OIL '39 RMOM.FDC '999 CALI,FDC -999 TNPH.CNL -999 RCFT,CNL -999 CALI.CNL -999 16:39 DEPT. 4800 SP.Dlb -5~ RMOB.FDC -999 CALI'FOC -999 TNPM.CNL -999 -999.250 GR,CML 29 v; 25O 999 ~ 250 -999;250 -999, 3 '999. -999~ 999 TENS FDC NPOR CNL Cab ooo TSNS,O~ 250 FFDC;FOC 250 TEN$,FDC 250 NPOR~CNL ~0 CF~C,CNL ~50' GR,C~L 3,925 3' 750 9,250 999'250 -99 2~0 o 1,658 '9 .~50 '999. 50 '999,~0 "999, 0 '999.250 2 120 -999 -999 -999 -999 -999 .000 IbD,~Ib 2 500 GR, Ib 98 :250 ORHO.FDC -999 ,250 GR.FDC -999 ,250 TaRA,Cab -999 ,250 CNTC,CNL -999 ,250 TENS.Cab -999 ~ENS'DIL FFDC,FDC TENS,FDC NPOR;CNb CFTC;Cab GR,CHL 000 lbO, '750 GR, 250 DRHO, 250 ~a, 250 TN~A, TEN5 FFDC TENS NPOR CFTC GR DDII~ FDC FDC cab Cab CML FDC FOC cab 27 25O 250 250 250 250 IbM FFDC FDC TE~$ FDC CFtC,Cab GR,CHL ~o 25o 25O .50 IbM,OlD TENS FFDC:FDC TEN$,FDC NPOR,CNb CFTC,Cab GR.CHL 2,736 97,2b0 '999.250 '999,250 '999,250 IbM.OIL TEN$,DZL FFDC,FDC TENS,FDC NPOR.CNL PAGEI -999.250 TEN$.CHL 000 D~NI,FOC 999' 25~0 N~DC,FbC -999, .CNL -999, 250 TENS,C~L 3.552 SFt~D.DIL '9 ,~ .FDC 2 !4 O0 DPHI -999.. 50 NFDC'FDC -999,~5Q NP~!.CNL -999.250 RCNT'CNL -999. iO .CNL '999, ,CML 3 2.780 999 -999 -999 -999 -999 " U DIL 858 000 DP~,FDC 250 ~oc.Foc 250 RCNTiCNL 250 GR.CNL 250 TENS,C~L 2874 -999 -999 -999 -999 -999 .669 SFbU,DIL .000 DP~,FDC .250 NFDC.FDC ,250 NPMI.CNL '250 RC~I'CNL .250 ~ .c~ .250 TENS,CML 2 2844 -999 -99 -999 -999 226 SFbU,DIL 000 OP~I.FDC 250 aFDC FDC 250 RPhI:C~b 250 RCNT.CNL 250 GR Cab 250 TENS:CML 2930. -999. -999. -999. -999, -999. 140 SFLU,DI~ 000 DPeX FD~ 250 NFDC:FD 250 NPRI.CML 250 RCNT.CNL 250 GR.CNL 250 T~N$.CHL , 2864. '999. '999 =999: 704 SFLU,DI]~ 000 DPHI,FDC 250 NFDC.FDC 250 NPHI.CNL 250 RCNT.CNL -999.250 3,183 4,227 ' ,250 '999,250 '999,250 ' 0 '999,25 '999,250 3 917 '999 250 -999 250 -999 250 -999 250 -999 1 605 -999 250 -999 250 -999.250 -999,250 -999,250 -999'250 1.957 -999,250 '999,250 -999.250 -999.250 ~999,250 999.250 1.904 99,250 -999,250 -999,250 -999,250 -999.250 2,606 '999,250 '999,250 '999,250 '999,250 LIS 1~ape Verification bi. sting Schlumserger"AlasKa ComPuting Center RCFT.CNb -999,250 CNTC,CNL CASI.CNL -9991250 ~EN$.CNb OEPT. 4700 LSP;DIh -56 RHOB,FDC -999 CALI,F?C -999 TNPM,CNL -999 RCFT;C~h -999 CAhI2CNh -999 000 ILD 7~1 GR 50 DRHO 50 GR 50 TNRA 5O C~?C 25O ~EN$ DC CNb CNL CNU R. BOB CA5I RCFT C~G! 4600,000 IhD, ,FDC -999,25.0 DRHO ,FDC -999,250 GR CNL -999"250 TNRA CNL -999;250 CNTC CNb -999.250 TENS DIL FDC CNb 30-MAR-1989 16:39 3,049 99,063 ~999,~250 999;250 -999,!b0 03' .11, ..999, -999~ -999 -999 -999 DEPT, 4500,000 ILD,O!~ SHOB.FDC '999~250 DRHO,~DC '999 CALI,FDC -999'250 GR;FDC -999 TNPH~CNb -999,~50 TNRA,CNb -999 RCFT,~NL -999'250 CNTC.CNL -999 CALI,CNL -999,250 TENS;CNL -999 DEFT, 4400,000 SP,DIL -56,031 GR RHOB FDC -999,250 DRHO C~LI' .FDC -999,250 GR TNPH CNL "999,250 TNRA RCFT' CAbi,CNL '999,250 CNTC .CNb -999,250 TENS OIL DIb FDC FDC CNI~ CNb CNL DEFT, SP DiL RHOBiFDC CALIFDC TNPH.CNL RCFT,CNb C~bI.CN~ OIL D I b FDC FDC CNb CNb CNb 4 oo 21 -999 -999 -999 -999 -999 OIL DIb FDC FDC tnb CNL CNL 000 ILD, 2297 250 G 250 CNT 250 TEN ,DIb .OIL FDC :FDC DEPT. 4~0,000 ILD SP.OIL 9.766 GR R~OB FDC -999 250 ORHO C~5I:FDC -999:250 OR TNPH CNG -999 250 TNRA RCFT' ' .CNL -999,250 CNTC C~LI.CNb '999.250 TENS GR FDC FDC OEPT. 4100.000 ILO SP'DIb -20.766 G~ RHOB.FDC -999,250 ORHO C~LI.FDC -999,250 GR TENS,DtL 0 FFDC,FDC 0 TENS,FDC 50 NPOR,~Nb 50 CFTC.CNL 50 GR,C L 2~0 250 TENS 2~0 NPOR 20 CFTC 250 GR DC CNb CNb C b 3 97 ..999 -999 -999 -99 .9999 0 5 TENS 2bO FFOC ] 50 TENS 2~0 NPOR 0 CFTC 250 GR OIL FDC FDC CNb CNb CIib 3 109 -999 -999 -999 -999 -999 598 375 TENS 250 FFDC 250 TENS 50 NPOR 50 CFtC 250 GR, DIL FDC FDC CNb CNL CHi. 3 100 -999 -999 -999 -999 -999 648 ILM 000 TENS 250 FFDC 250 TENS 250 NPOR CFTC 50 GR, FDC FDC CNb CNL CHh 4,625 94,750 -999,250 -999,250 ILM, TENS. FFDC, TENS, OIL DIL FDC FOC PAGE: GR.CNL ,250, ~E~S.C~L -999,250 -999~250 2. 987 SFbU 2764,000 DPMI ~999,2~0 NFDC 999.250 NPHI 0~ FDC ~D CNL ',866 -999~250 -999,250 '999,2.50 '999,250 '999.250 ;999. '999. '999, '999. '999' 12SFUU.DIL 0'0 DPHI'FDC 250 NFDC,FDC 250 NP~I,CNL 250 RC~T,CNb 250 "GR,CNL 250 TENS.CH~ 4,006 -999~250 -999,~50 '999, 50 -999,250 -999,250 -999,250 ~634 Z 999 999 999 -999 220 SFLD.DIU o00 DPM!;FDC 50 NFDC,FDC 25~ RCNT,CNL 25 GR,CNL 250 TENS.CHL 3,112 -999,250 -999.250 '999+250 -999,250 :999,250 999.250 3 2594 -999 -999 -9 -999 378 SFLO.DIb 000 DPHI,FDC NP}~I,CNb G ,CNL 250 TENS,CHL 3,306 -999,250 '999,250 -999,250 -999,250 -999,250 -999.250 3 2534 -999 -999 -999 -999 -999 480 SFLU,DiL 000 DPHI.FDC 250 NFDC.FOC 250 NPBI.CNL 250 RCN~,CNL 250 GR,CNL 250 TENS.CML 3,295 ~999 25O 999:250 :~99,250 99,250 -999.250 -999.250 , 2714 -999 -999 -999 -999 -999. 498 SFbU.DIL 000 DPHI,FDC 250 NFDC,FDC 250 NPMI,CNL 250 RCNT.CNL 250 GR.CNL 250 TENS,ChL 3,414 -999.250 -999,250 -999,250 -999,250 -999,250 -999.250 4 99 -999 434 SFLO,DIL O00 DPMI,~'DC 250 hFDC FDC 250 ~p~z:c~ 4.111 -999.250 -999,250 '999,250 10 LIS Tape Verification bisting Schlumberger ~las~a COmputing Center DEPT. 4000,000 ILO HSP,DI~ -2!;500 GR Ri~OB.FDC -999;2:50 DRHO CAnI.FDC -999,250 GR TNPH'CNb '999'250 TNR~ RCFT,CNL '999,250 TE[.S C~L~.CNL -999,250 DC FDC CNL Nb DEPT. SP DIL RMOB FDC CAhI F"'DC TNPH CNn RCFT C~5I CNn 3900 -999 -999 -999 -999 000 DRHO 25O 250 0 CNTC ~D¢ CNL CNb CNb _HSP~DIb TNP~'C~L RCFT.CNb CALI.CNL 3800 999 000 IbD. 500 GR, 250 DRHO~ 250 GR, 250 TNRA, ]50 C~TC. 50 TENS. FDC FDC CN5 Cs[, DEPT SP CALI TNP8 RCFT CALl FDC FDC CNL CNh 3700 -28 -999 -999 -999 -999 -999 000 ILD, 266 GR' 250 DRHO, 250 GR, 250 TNRA' 250 CNTC, 250 TENS, OIL FDC FDC CNn CNb DEPT. SP.DIb RHOB.FDC CAbI FDC RCFT,CN~ 3600 -2~ -999 -999 -999 -999 -999 ,000 ILO, ,016 GR, ,250 DRHO; .250 GR, ,250 TNRA, ,250 CNTC, ,250 TENS, OIL Din FDC FDC CNb CNh CNb DEPT. SF.DIb RHOB'FDC CALI.FDC TNPH.CNL RCFT.CN[. CAbI.CSL 3500 -999 -999 -999 -999 -999 .000 ,500 GR ,250 DRHO .250 GR ,250 TNRA ,250 CNTC ,250 TENS FDC FDC CNL CNb 30-MAR-I989 16~39 '999,250 NPOR,CNL ~ 999,250 OR. 4,5~7 .999.250 -999;250 -999,250 999, 50 5,!48 .104' 50 ~999'2 -999 5 452 9 -99~ 875 25o ~99 -99~ 250 250. -g99 250 2 958 110 188 -999 50 -999 ~50 -999 50 -999 250 -999 250 :433 9 563 '999'~50 '999, ~0 "999,250 '999, 0 28 ~41 6s ~8 -999 250 ~999 250 -999 250 -999 250 -999 250 FDC ~ENS,FDC NPOR,CNL CF~C,CN[, GR.CHL IbM,DIn TENS,DI~ FFDC,FDC TE!8,FDC NPOR;CNb ,CNn ILl. DIn TENS FFDC FDC TENS F NPOR CN5 CF~'C CNn GR IbM OIL TENS DIL FFDC FDC TENS FDC NPOR CNL CFTC CNL GR CHh IbM,DIn TENS.DIn FFDC.FDC TENS'FDC NPOR:~Nb CF~;CN~,b ILM,DIL TENS.DIb FFDC.FDC TENS.FDC NPOR.CNL CFTC,CNL GR,CHL -999.250 RC~T.CNb -999.250 .. GR..CN~ '999.250 IEN$*CHL 4 .2.464 999 ,.,999 .,999 00.DPH! FOC 50 NFDC 4 233 -999 -999 '999 999 967 SFL~ 50 N~DC FOC CML 5 ~334 999 -999 -999 -999 -999 352 SFLU,DXL 000 DPH!*FDC 250 NFDC.FDC 25~ ' RCN~,CNL ~ ~0 25, 250 TENS,CML 2 !1.44 '999 -999 -999 -999 -999 884 SFbO.DIL 000 DPHI,FOC 250 NFDC,FDC 250 NPBI,CNL 250 RCNT,CNL 250 , GR.CNL 250 TENS,CML 2124 -999 -999 -999 -999 101 225 SF~U,DIb 000 DPH! FDC 250 NFDC:FDC 250 ~PBI,CNL 250 RCNT,CN~ 250 GR,CN~ 000 TENS,CML 2000, 2150, -999, -999. -999, -999. 59. 000 SFLU.DIb 000 DPHI,FDC 250 NFDC,FDC 250 RCNT NL 250 GR,CNL 219 TENS.CM~ PAGE: 11 -999,250 "999,250 '999.250 3.844 '999,~50 '999.250 -999,250 -999~250 '999. 5.009 25O 25O "999 250 '999 250 50 5.183 999'250 -999;250 -999,250 -999,250 2,402 -999,250 '999.250 '999,250 '999.250 -999,250 '999.250 2,954 "999,250 '999,250 -999 250 '999 250 -999 250 2124 000 2000,000 -999.250 -999.250 -999.250 '999,~50 '999. 50 2270,000 LIS Tape verification hlsting SchlUmberger AlasKa ComPuting Center DEPT CAb1 ?NPH RCFT CAb! ,FDC ,FDC CN 6 CNb CNG 3400 000 -~99 250 - 99 250 '999 250 '999 250 '999 250 '999 250 IGD DIG GR OIh DRHO FDC GR FDC TNRA CNG CNTC CNG TENS CNL DEPT RHOB .AhI NPH RCFT CAb! FDC FDC CN6 CNG CNb 3300,000 '999,250 '999,250 999,250 '999,250 '999,250 ILD GR OIL DRHO FDC GR FDC TNRA CN6 CNTC CN6 TENS CN6 DEPT. SP,Olb RHOB~FDC C~LI,FDC T!iPH,CNb RCFTeCN6 CALI.CML 3200,000 '999,250 '999,250 -999;250 -999,250 -999,250 -999;250 I.~D,DI6 DRHO~FDC ,GR, DC T~'~RA~NL CNTC,CNL TEllS,CNG D HSP,DIL R. OB,FDC C~bI,FDC TNPH,CNL RCFT,CNL CALI.CNL ~00,000 99,250 '999,250 -999,250 -999,250 '999,250 -999.250 GR DIL DRHO FDC GR FDC TNRA CN6 CNTC CN6 TENS CNb DE'PT, SP,DIL RHOB.FDC CALI'FDC TNPH,CNL RCFT,CN6 CAbI,C~b 3000 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 ILO GR DI6 DRHO FDC GR FDC TNRA CN6 CNTC.CNL TEN$.CNb DEPT, SP,OIb RHOB,FDC CAbI,FDC TNPH.CN6 RCFT,CNb CALI,CNL 2900 000 '999 250 '999 250 '999 250 '999 250 '999,250 '999,250 IbD GR DRHO FDC GR FDC ~NRA CN6 CNTC,CNb TEN$,CNL DEPT,Dib RHOB,FDC ALIFDC NPH~CN6 RCFT.C~L CAbI,C~L 2800,000 '999,250 '999,250 -999.250 999,250 999,250 999.250 iLD.OIL GR,DIL DRHO,FDC GR,FDC ~NRA,CN6 CNTC.CNL ~CNS'CN~ 30-MAR-1959 16:39 -999 -999 -999 -999 -999 ~999 -999 IGM'DI6 TENS~DIG 5O FFDC;FD¢ 50 TENS,FDC 5O NPOR,CND 50 GR~' -999 !50 -999 -999 -999 0 '999 0 -999 8 -999 I6~ DC FDC IEN$ FDC POR CNG .CNL '999 -999 "999 -999 "999 250 2 0 25O 250 250 250 IbM,DIb TENS,DIL FFDC;FDC TENS,FDC NPOR;CNb GR,CH~ -999 -999 -999 -999 -9 -99~ 250 5O 5O 5O ~D¢:FDC ~EN$ ~DC NPOR CN~ CFTC CN6 GR -999,~0 -999, 0 ~99 250 o '99 250 TENS FFDC FDC TENS FDC NPOR CN~ GR '999, 0 '999'~0 -999.250 -999 ~50 -999 50 -999 250 -999 250 IbM 016 TENS DIL FFDC FDC TENS FOC NPOR CNb CFTC CNL GR CHh -999 250 250 -999 250 -999 250 '999 250 -999 250 IbM OIL TENS OIL FFDC FDC TENS FDC NPOR CNb CFTC CN6 GR CHL -999 ,DIL ) ,DPHI~f'DC ) NFDC,FDC 250 SFbU.DIL 250 DPHI~FOC 250 NFDC::FDC CNL -999.250 SFbU -999.250 DPH! -999~250 NFDC -999,250 NPH! -999,250 RENT -999;250 OR 62,250 TENS , ,'Nb ,CN~ ,CHh -999 250 SFLU,DIL -999 250 DPMI,FDC -999 250 NFDC,FDC -999 250 NP~I,CN~ -999 250 RCNT~CN~ -999 250 GR,CNL 54 969 TEN,.CML -999 250 SFLU.DIL -999 250 DPHI,FDC -999 250 NFDC,FDC -999 250 NPBI,~NL -999 250 RENT, N~ -99~ 250 GR.CN~ 4 094 TENS.CHL -999 250 SFbU,DI6 -~99 250 DPHI,FDC - 99 250 NFDC,FDC -999 250 NPBI.CN6 -999 250 RCNT'CNL -999 250 GR,CNL 35 906 T~N$,CHL -999,250 -999.250 :999,250 .999,250 999,250 '999,250 61,844 SFL~,D!6 DPHI FDC NFDC FDC NPHI CNL RCN~ CNL GR END T~S:CHb -999 ,250 50 50 50 O0 '999.250 '999.250 '999;250 '999,250 "999'250 2160'000 '999,250 '999,250 '999,250 -999, i990,000 -999,250 -999,250 -999,250 :999;250 ~999,250 .999,250 1950;000 -999,250 -999,250 -999.250 -999 250 -999 250 191 O0 -999 250 -999 250 -999 250 -999 250 -999 250 -9~9 250 1875 000 LIS Tape verification bistlng SchlUmberger Alaska Co~Puting Center EPT, 2700,000 I~D.DIb -999 HSP;DIL -999,250 GR;DtL -999 ,'.OB;fDC -999,250 DRHO,FDC ~999 C~5I,FDC -999.250 GR.FDC 999 TNPH,CNL -999.250 TNRA'CNL -999 RCFT,CNL -999;250 CNTC,CNL :999 CALI2CNL -999.250 TEN$;CNL 999 /)..;.PT 2000,000 I, LD. DI~ SP~DI5 -999;250 GR;DIL RMOB;FDC -999'250 ORHO'FDC CALI;FDC -999; 250 GR;FD~ TNPH,CN[~ -999,250 TNRA,CNI~ RCFT, CML -999; 250 CNTC,CNi~ CALI'CNL -999.250 TENS'CNL DEPT, RHOB,FDC CADI,FDC RCFT;CNL CA~I,CNb FDC TNPH ~NG CAbI CNL OEPT SP TNPH CNb RCFT CNL CA~I,CNL OEPT SP DIb RHOB FDC CALl FDC rNPH CNG RCFT CNL CALI CNb DEPT, SP.DIb RHO~'FDC CADI.FDC ~NPH CNb ~500 000 999 250 2999 250 999 250 -99~ 250 -999 250 ~40 000 99~ 250 -999 250 -999 250 -999 250 -999 250 -999 250 2300 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 2200 000 -999 250 -999 250 -999 250 -999 250 -999 250 '999.250 2100,000 '999.250 -999,250 '999,250 '999.250 -999,250 ILD DIb GR DRHO ~DC GR ~DC ~NRA, CN5 CNTC, CND TENS CNL IbD OIL GR DIG DRHO FDC GR FDC TNRA CNb CNTC CNb TENS CNL ILO,OIL GR.DIL DRMO FDC GR FDC TNRA CND CNTC CNb TENS CNG IbD,DIb GR.DIb DRHO FDC GR FDC TNRA CNL CNTC CNb TENS CNL ILD.OIL GR.DIL DRHO.FDC GR.FDC TNRA,CNL CNTC,CNL 30-MAR-~989 16~39 ,2 0 TENS 50 FFD 50 TEN~ ~0 NPOR 50 CFTC ~50 GR DC CNG CNG ~CMb -999.250 Ib~ -999;250 TENS -999;250 FFDC FDC -999~250 TENS FDC -999'2~0 NPOR -999"250 CFTC -999,250 GR '999,250 IbM,Dlb -999.250 TEN$'DIL -999'250 FFDC,FOC -9~9'250 TENS~FDC '999,,250 NPOR~CNb -9~9'250 CF~C'CNL -999'250 GR,CML -999 '999 -9 -999 58 TENS 250 ~FDC 250 TENS 250 NPOR 250 CFTC 250 GR DIG OiL FDC FDC CNL CNL CHh -999 250 -999 -9 250 999 50 -999 250 ILS DIb TENS FFDC FDC TENS FDC NPOR CNL CFTC CNL GR,CH~ -999 -999 -999 -999 -999 -999 -999 50 50 250 250 250 250 250 TENS.DIL FFDC'FDC TEN$,FDC NPOR,CNG CFTC,CNb GR,CHL '999,250 "999,250 "999.250 999. 50 999. 50 TEN$'DIL FFDC.FDC TEN$.FDC NPOR,CNL CFTC.CUb PAGEI -999 -999 ' "999 -999 50: SFbO 50 D'PHI '06 'tENS -999 -999 -999 '999 -999 '999 -999,250 SFLD -999,.2~0 DPHI -999;2'0 NFDC -999.250 NPBI :999,250 RCNT 999;250 GR 50.219 TENS -999 -999 -999 -999 -999 -999 31 ..DID ;FDC ,Foe 'CN 'CN5 OIL FDC DC 250 SFLU,DI~ 250 DPHI.FDC 250 NFDC;FDC 250 NPHI,CNL 250 RCNT,CN.L 250 GR.CNL 969 TE~$'CHL -999 250 SFLU DIL -999 250 DPHI:FDC -999 250 NFDC FDC -999 250 NPH! CN~ -999 250 RC~T CN~ -999 250 GR CNL 32 063 TENS CHL '999 250 SFLU.DIL -999 250 DPHI,FDC '999 250 NFDC.FDC -999 250 NPMI.CNL '999 250 RC~T,C~L -999 250 ~R.CNL 32 469 TENS,CML '999 250 SFLU.DIL -999 250 DPhI.FDC -999 250 NFDC.FDC '999 250 NPBI,CNL -999 250 RCNT,CNL -999 250 GR.CNL 250 50 1,7' ,000 '999,250 -999,250 '999,250 -999;250 -999'250 -9996250 1830,000 -999,,250 '999'2 0 '999'2~0 '999~ 1745,000 -999, -999,~ 0 '999, '999, !695,000 -999 250 -999 250 -999 250 -999 250 1605 O00 '999,150 =999, 50 -999,250 -999,250 -999,250 -999,250 1585.000 '999, '999,~50 '999, 50 '999~250 '999,250 13 bis Tape Verification Listing Schlumberger'AlasKa ComPuting Center CALI.CNL -999,250 TENS,CNG DFPT R~OB C~LI 2000,000 ILO DIG -999,250 GR FDC -999'250 DRHO FDC -999,250 GR CNG -999,250 TNRA CN5 -999,250 CNTC CNL -999,250 TENS OIL FDC F CNb CNL DEPT, R~ C~LI, CALl 30-MAR-1989 16:39 -999,250 GR.CHL 1999 ..... 999 -999 -999 -999 -999 250 -999 250 !900,000 ILD,DIL -999 GR ,DI~ 250 Olh ~999~ -999 FDC 999~250 DRHO'FDC -999 FQC -999~R50 GR,FDC -999 CNL '999,250 TNRA;CN5 -999 :999; 0 C T ;C L -999 CN~ 999,250 TENS~CNL -999 FDC FDC CNG CNG CNL SP,DI5 RHOB;FDC C~LI,FDC TNPH;C~L C. LI,CML FOC FDC CNG CNG 1800 -999 -999 -999 -g99 999 000 50 GR 50 ORHO 250 GR 250 TNRA 250 CNTC 250 TENS DIG DIG FDC FDC CNG CNG CNG OEPT, C~bI RCFr CAbI 1700 -999 -999 -999 -999 -999 -999 DEPT RH~ DI.L . FDC CALI FDC TNPH CNb RCFT,C~L C~LI,CNL 000 ILO 250 GR 250 DRHO 250 GR 250 TNRA 25O CNTC 250 TENS 600,000 ILO,DIG 999,250 GR,DIL 999,250 DRHO,FDC -999 250 GR,FDC -999,250 TNRA,CNb -999,250 CNTC,CNb -999,250 TENS,CNG ,OIL ,DIG ,FDC ,FDC ,CNG ,CNG ,CNG DFPT, SP,DIb RHOB,FDC CALI,FDC TNPH,CNL RCFT,CNL CALI~CNL ~500 -999 -999 -999 -999 -999 -999 .000 ILO 250 GR 25O DRHO 250 GR 250 TNRA 250 CNTC 250 TENS :DIG DIG .FDC ,FDC ,CNG 1400 -999 -999 -999 -999 ,000 ILO ,250 GR ,250 DRHO '250 Ga ,250 ]!NRA DEPT, SP,DIL RHOB,FDC CAbI,FDC TNpH,CNb -999 250 -999 250 -999 250 99~ 25 'g9~ 250 '99 2~0 -999 250 -99~ 250 -99 250 -999 250 -999 250 -999 250 =999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999,250 -999,250 -999,250 -999,250 -999,250 IbM D:XL TENS FDC NPOR CNG CF'IC CNG GR CHL OIL DI IbM,OIL FFDC;FDC ENS', 'DC 'N GR~CHL ILS DID FDC ~DC TENS FDC NPOR CN~ CF~ CNG CHG TENS,DIG FFDC FDC TENS FDC NPOR CNG CFT~ CNG G CHL I~M OIL TENS FFDC FDC TENS FDC NPOR CNG CFIC GR,CHb IbM,DIG TENS DIG FFDC:FDC TENS,FDC NPOR,CNL PAGg: 41,969 '999 250 &FLU -999 36 -999 -999 -999 -999 TEN$,CHL FDC FDC CNL ,C~I., ~CHL '" U 250 $~L ,OI~ 250 DPHI,FD~ 250 NFDC*FD. ~50 NPHI'CN~ 50 RCNT,CNL 250 GR,CNL 250 TENS,ChL -999 250 · 0 -999 25. -999 250 '999;250 '999;250 -999,250 29;500 -999 250 =999 250 -999 250 -999 250 '999 250 0 52 -999 250 -999 ~50 -999 50 -999 250 -999 250 -999 250 45 344 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 22 594 :999,250 .999'250 .999,250 999,250 .999,250 SFLU,DIL D~H!,FDC N~DC,FDC RCNT'CNL ., 'CHL SFLU,DIL DPHI,FDC NFDC,FDC NP~I,CNb RCNT,CNL GR'CNL TENS;CML SFbO,OIL DPMI,FDC NFDC,FDC GR,CNL TEN$,CHL SFLU,DIL DPMI,FDC NFDC.FDC NPHI,CNb RCNT,CNL GR CNL TENS:CHL SFLU,DIL DPHI,FDC NFDC,FDC NPHI,CNL RCNT,CNL 1530,000 '99 250 2'0 -999 250 '999 50 "999 ~6 -999 50 '999 I$~ 2 0 -999,250 -999 250 250 1445 000 -999 ]50 999 250 -999 250 ~395 000 -999 250 -999 250 -999 250 -999 -999 2 0 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 1340 000 :999,250 999'250 -999,250 '999,250 '999,250 14 LiS. Tape Verification bistln~ Schlumberger AlasKa Computing Center RCFT,CNb -999,250 CNTC,CNL CALI.CNL '999;250 TEN$;CNL DEPT RCFT CAbI 1300 DIb -999 FDC -999 FDC -999 CNb -999 CNL -999 CNL -999~ 00 IbD,DIL 50 GR,DIb ~50 DRMO,FDC 250 GR.FDC 250 TNRA.CNb 250 CNTC,CNL 250 TENS;CNL DEPT, RCFT,CNL C~b.I;CN'b ~200,000 999.250 '5 -999.2 0 '999;250 -999,250 -999,250 -999;250 GR;OIb OR~O,FDC GR,FDC TNRA'CNb CNTC,CNL TENS,CNb DEPT Sp DIL C~bI FDC RCFT CNL CAbI C~L ~100,000 999.250 -99 .250 -99~.250 -999.250 -999.250 -999.250 IbD,OIh DRHO,FDC GR,FDC TNRA'CNb CMTC.CNL TEN$1CNL DEPT, SP'DIb RMOB,FDC CALI.FDC T~PH.CNL RCFT,CNL CALI.CNb 1000,000 '999.250 '99 50 '999,250 '999,250 '999.250 GR.DIL DRHO,FDC GR.FDC TNRA,CNL CNTC,CNL TENS,CNL OEP? SP RMOB FDC CAbI FDC TNPH CNL RCFT CNL CALI CNL 900,000 -999.250 -999,250 -999,250 -999,250 -999.250 -999.250 ILO GR,DIb DRHO,FDC GR.FDC TNRA,CNL CMTC,CNL TENS.CNL OGPU, SP,OIL RHOB,FDC CALI,FDC TNPH CNb RCFT:CNL CALI,CNL 897 000 -999:250 -999 250 -999 250 -999 250 -999 250 '999,250 IbD,DIL GR,DIL DRHO,FDC GR.FDC TNRA,CNL CNTC.CNL TEN$.CNL ** END OF DATA 30-MAR~1989 16:39 ,,,999,250 CFTC.CNL -999.250 GR.CHt~ -999,250 .GR,CNL 34,656 TE~S,CBL '999,2~0 TI~M,D!L -999,2 0 ~E~'S~D1L '999, 0 FFDC.FDC -999 -999' 0 TENS;FDC -999 -999, 0 OR~CN~ 999 -999, 0 TC,CNL ~999 -999, 0 GR.CH~ 41. 250 SFbU,DIL 250 DPHI.FDC FDC,FDC 250 RCNT.CN~ 250 GR,CNL 500 ~ig~$~CH~ 999.250 Ib~ 0~ :999.~50 999;~50 TENS DIL :999,250 :999,2~0 ~FDC FDC ,999,~50 ~eOC,F~C 250 NPMI. 999;250 ~ENS FDC =999, CNL ~999, CNb ~999'250 -999~ CN~ 999;250 -999; ,0 GR, C~L 48.8i~ -999 -999 -999 -999 -999 -999 -999 '5 TENS; 2'i0 FFDC,FDC 250 TENS,FDC 250 NPOR.CNb 250 250 GR;CHL -999 250 SFLU,DIL -999:250 DPHI,FDC .999;250 ~FDC.FDC .999,250 NPMI.CNL -999.250 RCNT.CNL -999,250 GR.CNL 37,594 'rENS.CHL -999 -999 999 '999 ''0 OIL -999~ 250 TENS,DIL -999, 250 FFDC,FDC 250 TENS,FDC -99 250 NPOR,CNb -999 250 CFTC.CNb -999 250 GR,CHL 24 ] 50 SFLU,D1L 50 DPHI,FDC 250 ~FDC.FDC 250 NPHI CNL 50 RCNT,CN~ 50 GR,CNL 469 TE~$.CHL '999.~50 '999. 50 '999 250 '999 250 999 50 '999 250 ILS OiL '999 TENS:DIL -999 FFDC,FDC -999 TENS,FDC '999 NPOR.CNb '999 CFTC.CNb -999 GR.CHL 34 250 SFLU.DI~ 250 DPHI.FDC 250 NFDC.FDC 250 NPHI.CNL 250 RCNT.CNL 250 GR.CNL 563 TE~$.CHL -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 IbM,OIL TEN$,DIL FFDC.FDC TEN$.FDC NPOR.CNL CFTC,CNL GR,CHL -999 250 SFLU.DI~ '999 250 DPH! FDC '999 250 NFDC:FDC '999 250 NPMI.CNb -999 250 RCkT.CNL -999 250 G~.CNL 36 188 TENS.CHL PAGEI i5 -999 1305 '999' '999, '999, : 1300'000 -99~ 250 25' -99 00~ 1255 -999; :.' '999, '999, 123 ,000 '999 250 '999 250 '999 '999 250 -999 250 1195 000 99 0 -999 5 -999 ]500 -999 2~0 -999 2 0 1170 000 '999, -99 , 0 '999,250 -999,250 1170,000 bls Tape Verification Ltstin~ SchlumBerger AlasKa Computin~ Center **** FILE TRAILER : EDIT ,00i : FbIC YE~SION : DArE : 89/03/30 : 096 LASTFILE 30-MAR-I989 t6:39 PAGEI 16 **** FILE HEAOER **** II, hE NA~E I EDIT ,002 ERViCB : YER~ION : 00lA02 DAT ; 89'/0]/3o ILE TYPE : LO LAST FI:bE : FILE - EDIT,O02 * ARCO ALASKA !NC, ~ KUPARUK * 3 I - 13 * 50-029-21923-00 * DATA SAMPLED EVERY -,1000 FEET * TOOLS INCLUDED - * FOC * CNT-A/D/H , ****************************************************************************** T~BLE TYPE : CONS CN ARCO ALASKA iNC, Company Name FN KUPARUK Field Name .N 3 I - 13 ~ell Name NATI USA Nation STAT ALASKA State or Province COUN NORTH SLOPE County Fb 115' FSL, 85' FEb Field Location SECT 36 Section LIS Ta~e Verification bistin $chlum erger AlasKa Computin~ Center 30-MAR-198g 16~39 PAGES 17 fUNI YAbU DEFI TOWN t3N Township de ONG SON 73 209 Se: APIN 50'029-21923-00 AP TABLE TYPE : CURV DEFI PH! Denslt~ Poroslt¥ BOB Bul~ O~nsit~ DRHO Delta tho FFDC Far F ~ ,'DC Count Rate NFDC Near FDC Count Rate CALl Caliper GR Gamma Ray T~NS Tension NPHI NEUTRON POROSITY TNpH THERMAL NEUTRON POROSITY TNRA CALIBRATED THERMA~ NEUTRON,RATI[] P . NPOR NEUTRON POROSITY OUTPUT FROM .AN A PLICATION PROGRA~ RCNT RAW CORRECTED NEAR T~ER~AL COUNI$ RCFT RAW CORRECTED FAR THERMAL COUNTS CNTC CURRECTED NEAR THERMAL COUNTS CFTC CORRECTED FAR THER~ ~AL COUNTS GR Gamma Ray CASI Caliper TENS Tension DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VAbUE I 66 0 2 66 0 3 73 ~0 4 66 1 5 66 6 73 7 65 8 68 0,099 bis Tape Verification [,isting Schlumberger AlasKa COmPuting Center 30-MAR-1989 i6:39 i¸8 9 65 FI 11 66 13 12 68 13 66 14 65 FT 15 66 68 6 66 I 66 ** SET T'~PE - CHAN ** N~ME SERV API APl API bPI FIbE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE [BE:X) -----------------------------------;------------------~--------------------~--DEPT FT 54842 8 00 O0 2 1 68 000000: 0 o 2 i ~ 4 68 oooo ooooo 68 oooo~ooooo DPH! FDH R~O8 FDH DR~OFDH FFDC FDH NFDC CALIFDH GR FDH TENS FDH NPHI CNH TNPH CNM TNRA CNH NPOR CNH RCNT CNM RCFT CNH CNTC CNH CFTC CNH GR CNH CAL! CNH PU 548428 07 G/C] 548428 07 ~50 02 0 2 1 1 4 G/C3 548428 07 35b 01 0 2 1 I 4 CPS 548428 07 354 02 0 2 1 1 4 CPS 548428 07 354 01 0 2 1 I 4 IN 548428 07 280 01 0 2 i I 4 GAPI 548428 07 2i0 O1 0 2 1 1 4 h~ 548428 07 635 21 0 2 I 1 4 4:0 o 4 CPS 548428 07 420 Ol 0 2 I 1 4 CP~ 548428 07 420 O! 0 2 ~ I 4 07 o 4 68 0000000000 68 0000000000 0000000000 6.8 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 6B 0000000000 68 0000000000 68 0000000000 68 0000000000 0000000000 68 0000000000 68 0000000000 DATA DEP~, FFDC.FDH TgN$ FDH CFTC.CNH DEPT, FFDC.FDH TEN$.FDH NPO~.CNH CFTC,CNN 7723,800 487.750 2054,000 35,848 b63.213 7700,000 487,750 3874,000 35,848 663,213 DPHI NFDC NPHI RCNT GR DPH.I. NFDC NPHI R C N T GR ,FDH .FDH ,CNH ,CNH ,CNH .FDH .FOB ,CNH .CNH 11.286 606,500 35,366 2029,768 11,2S6 606,500 35,~66 2029. 68 107,1~8 CALI TNPH RCFT CALI FDH 2.464 DRHO.FDH FDH 9.828 GR.FDH CNH ]5.848 TNRA.CNH CNH 584,396 CN~C.CNH CNH 9.828 TEN$.CN~ 0.039 107.188 3.180 2073.386 2054.000 0.039 107.188 3 180 2073:3~8 3874,000 bis Tape Verification Listing SchlUmberger AlasKa ComputinH Center 30-MAR-19~9 16~39 PAGE: 19 DEPT, 7600,000 DPH ;FDH T NS,FDH ,000 NPHI,CNM N OR,CNH ,530 RCNT,CNH CFTC,CNH 571,055 GR,CN~ D~PT, FFDC. FDH TENS FDH CF~fC CNH FFDCiFDH TEN~,FDH CFTC.C~H DEPT, FFDC~FDH TENS,FDH NPOR.CNH CFTC.CNH DEPT FFDC:FDH TENS,FDH ~POR.CNH CFTC.CNH TENS FDH NPOR CNH CFTC CNH 7500~ 000 603 000 38OO 000 45 45~ 575 718 7400,000 573,.500 3570;000 3!,1t7 982'896 7300,000 534~000 4034~,000 31,430 835;535 72(0.000 522,000 3570,000 45,150 465,701 7i47 899 566 5OO 3620 000 46 2]5 487 313 DPHX FDH NFDC FDH NPHf CNH RCNT GR CNH DPHI FDH NFDC FDH NPHI CNH RCNT CNH GR DP8I.FOH NFDC,FDH NPhI,CN~ RCNT,CNH GR.CNH DPHI FDH NFDC FDH NPHI CNH RCNT CiH GR CNM DPHI.FDH NFDC,FDH NPHI,CNH RCNT,CNH GR.CNH 7,.. ~i RHOB FDH 602.000 CALl FD~ 40,139 INP}! CN~ 1906~057 'RCFT CNH 110,438 CALl,CHH 16.021 RHOB,FD~ 653,000 CALX ~ FDH 18e8~636 RCFT,...... '~ 102,563 CA~I.CN~ 614 O0 CALI 676 994 125 CALI FDH FDH 14,5005' 5~6'11 75 i 375 CALI. TNPH, CALl' FDH CNH 13 610 1693 121 486 5OO 12 HO, AL~, TNP , RCF~, CALl, ~DH CNH CNH 17 594 45 1681 9O 58 750 RHOB, CALI, TNPH, REFT, CALl, FDH FDH CNH CN~ CN~ 2,5!9 DRHO,FDH ;664 GI~.FO~ 39;543 TN~A.CNB 561~791 CN~C.CN~ .664 TENS.CNh ~,386 DRHO,FDIi 43:508 GR'FDH 606 CNTC ~ CNH 508 TENS.CNH 3O 84O 8 376 DRHO.FDh 68O 6R,FDH 332 TNRA.C.~.,H CNTC, 08 TEN$.CNh 2,384 9,047 3i,951 734,761 9,047 DRHO,FDH ~ . GR,FDH TN~A,CNH CNTC.CNH TENS.CNH ~ 427 5~7 45 654 5 8 DRHO,FDH GR,FDH ,T, NRA.CNU CNTC*CNH TENS.CNH 2 365 45. 474,133 8,422 DRHO.FD~ GR.FD~ ?NRA.CNh CNTC.C~h TENS.CNH 3 34b 188.8 I34 3874,000 0,047 102,563 3,731 2027.884 3800,000 7~ '016 i125 2,866 2672.$19 357O · UO0 '0,004 75,375 2;744 2374~174 4034.000 0 O3O 121 375 3 827 1714 114 357O 00o 0.001 90,750 3,634 1790.748 3620,000 ENO OF DATA **** FILE TRAILER FIbE NAME : EDIT .002 SERVICE : FLIC VERSION : 001A02 DATE : 89/03/30 MAX REC SIZE : 1096 FILE TYPE : bO LAST FILE : LIS 'rape verification Listing Schlumberger AlasKa Computing Center 30-~AR-~9~9 ~6:39 PAGE: 20 SERVICE NA~E : EDIT CON~INUA~IO... ~ : I PREVIOUS TAPE : CO~.MENT : ARCO ALASKA INC,,KUPA~UK v3 'I - 13,50-029-21923-00 **** REEL TRAIbER SERVICE NAME : EDIT DATE : 89/03/30 : FbIC : 73209 PREVIOUS REEL : COMMENT : ARCO ALASKA INC,,KUPARUK ,3 I - 13,50-029-21923-00