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Home My WebLink About183-064Originated: Delivered to:5-Nov-25Alaska Oil & Gas Conservation Commiss05Nov25-NR !"#$$%$ !&$$'($)*%+ ($)*%,-.WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED3T-730 50-103-20907-00-00 225-010 Kuparuk River WL TTiX-IPROF FINAL FIELD 6-Oct-253J-03 50-029-21399-00-00 185-164 Kuparuk River WL PPROF FINAL FIELD 7-Oct-252X-01 50-029-20963-00-00 183-084 Kuparuk River WL IPROF FINAL FIELD 10-Oct-252Z-07 50-029-20946-00-00 183-064 Kuparuk River WL CBP FINAL FIELD 11-Oct-252Z-03 50-029-20964-00-00 183-085 Kuparuk River WL IPROF FINAL FIELD 14-Oct-253R-17 50-029-22242-00-00 192-005 Kuparuk River WL LDL FINAL FIELD 16-Oct-253S-722 50-103-20886-00-00 224-066 Kuparuk River WL TTiX-IPROF FINAL FIELD 20-Oct-252U-06 50-029-21282-00-00 185-019 Kuparuk River WL RBP FINAL FIELD 25-Oct-253T-731 50-103-20905-00-00 224-156 Kuparuk River WL Cutter FINAL FIELD 2-Nov-25Transmittal Receipt//////////////////////////////// 0///////////////////////////////// + ! 1Please return via courier or sign/scan and email a copy to Schlumberger."2"3 +45 %TRANSMITTAL DATETRANSMITTAL #1 67 8" ! - +"8#!(3 . 8)"3 8#!9 3 : 8" +868 8 "8#!;" " 3 - 3" 3""+ 3 + <+3!% T41052T41053T41054T41055T41056T41057T41058T41059T410602Z-0750-029-20946-00-00183-064Kuparuk RiverWLCBPFINAL FIELD11-Oct-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.11.05 12:45:23 -09'00' From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 2Z-07 (PTD183-064) Sundry Amendment Request Date:Thursday, September 11, 2025 1:47:41 PM Attachments:image003.png From: Lau, Jack J (OGC) Sent: Thursday, September 11, 2025 1:47 PM To: Bronga, Jaime <jaime.bronga@conocophillips.com> Subject: FW: KRU 2Z-07 (PTD183-064) Sundry Amendment Request Jaime, see my comments in blue Jack 1. CPAI believes we can meet the intention of CO 736 without passing an MIT-T subsequent to repair and every 2 years. CPAI will attempt an MIT-T post repair, if this fails, CPAI will conduct a leak detection log with a spinner and temperature sub and compare the temperature baseline to temperature injection passes to verify no fluid is exiting the casing into the HRZ between the repair cement bottom and the original production packer. Fluid exiting the tubing into the Kuparuk C sand by way of the original production packer and tubing leaks is acceptable and only impacts production. CPAI proposes to conduct this style of log every 2 years in lieu of the MIT-T requested in CO 736. The proposed post repair steps are below for review. Approved 2. If the MIT-T passes, CPAI suggests we conduct CMIT-TxIA and MIT-T every 2 years instead of an MIT-IA and MIT-T. This well is a gas lifted well and a CMIT-TxIA and MIT-T will achieve the same results without the need to dummy the gas lift valves bi annually. Approved 3. Additionally, as the Sundry references complying with CO 736, CPAI requests clarification on the application of Rule 3 to this well. Does the AOGCC require a review of the this well in the annual reservoir surveillance report? Do not include From: Bronga, Jaime <Jaime.Bronga@conocophillips.com> Sent: Wednesday, September 3, 2025 11:33 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Automation, AK Wells <akwellsautomation@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2Z-07 (PTD183-064) Sundry Amendment Request 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. Well Name: 2Z-07 Facility: CPF2 PTD: 183-064 Well Type: Prod AA Number (if applicable): Internal Waiver (Yes/No if applicable): Type of Issue: Variance Request Maximum Pressure (if applicable): Date of Occurrence (if applicable): Hi Jack, CPAI received Sundry #325-480 from the AOGCC for KRU 2Z-07 with guidance to follow CO 736. As mentioned, the intention of the cement repair is to replace the production packer with a cement packer. 4. CPAI believes we can meet the intention of CO 736 without passing an MIT-T subsequent to repair and every 2 years. CPAI will attempt an MIT-T post repair, if this fails, CPAI will conduct a leak detection log with a spinner and temperature sub and compare the temperature baseline to temperature injection passes to verify no fluid is exiting the casing into the HRZ between the repair cement bottom and the original production packer. Fluid exiting the tubing into the Kuparuk C sand by way of the original production packer and tubing leaks is acceptable and only impacts production. CPAI proposes to conduct this style of log every 2 years in lieu of the MIT-T requested in CO 736. The proposed post repair steps are below for review. 5. If the MIT-T passes, CPAI suggests we conduct CMIT-TxIA and MIT-T every 2 years instead of an MIT-IA and MIT-T. This well is a gas lifted well and a CMIT-TxIA and MIT-T will achieve the same results without the need to dummy the gas lift valves bi annually. 6. Additionally, as the Sundry references complying with CO 736, CPAI requests clarification on the application of Rule 3 to this well. Does the AOGCC require a review of the this well in the annual reservoir surveillance report? Relay and FB 1. Log CBL from 8400 to 7000’ rkb to find TOC and quality of cement. 2. Obtain SBHP (Should be A sand only) for 30 minutes at ~8400’ rkb. a. The before and after SBHP should show a change if we are no longer in communication with the C sand. 3. Set hole finder below the production packer and perform MIT-T to 1500 psi. a. Between 8262’ and 8292’ rkb. 4. If fails, document a LLR and confirm CMIT-TxIA also fails. a. Before the cement job, a CMIT-TxIA with the plug at this depth had LLR to formation of 0.38 bpm at 2000 psi b. If CMIT-TxIA passes, reattempt the MIT-T. 5. If the CMIT-TxIA fails then set an RBP at 8270’ rkb and run a memory LDL with temperature and spinner. i. Stage 1: CMIT-TxIA style with fluid going to formation. Comparison to original LDL looking for leaks from casing to HRZ formation vs casing through packer. ii. Stage 2: MIT-T style with fluid being bled off the IA to verify if any leak path through the IA cement. (Tubing pumping at 2000 psi, IA bled to 0 psi.) – Assumes MIT-IA has already passed in DHD steps. iii. This will be for the AOGCC showing no fluid movement through cement and no fluid into the HRZ. 6. If the MIT-T with the plug below the packer failed, use the hole finder to move up hole to achieve a good MIT-T. 7. Call PE or Jaime Bronga to discuss results and if proceed with more diagnostics. a. The cement above the packer will provide a well integrity production packer if the MIT-IA passes and the LDL does not show any fluid exiting the casing between the bottom of the cement and the top of the original Production Packer. If the MIT-T with shallower hole finder set depth pass the path may allow C sand water inflow which if the deeper MIT-T fails at a high enough LLR will be undesirable from a production standpoint but not an integrity issue. We intend to patch the tubing leaks if we are concerned about water production from the C sand. 8. Send Jaime Bronga the CBL log to review with the AOGCC before proceeding with the next rig up. SL 1. Call AOGCC with 24 hours notice for State Witnessed MIT-IA and MIT-T to 1500 psi. 2. Set RBP at 8270’ rkb (Must be Between 8262’ and 8292’ rkb) 3. State Witnessed MIT-IA to 1500 psi 4. State Witnessed MIT-T to 1500 psi (if the pre MIT-T passed). a. If the pre MIT-T failed, then Jaime Bronga to review the LDL results with the AOGCC for approval. 5. Set live design: Depth (ft md)Valve Type TRO (psi) 2765 GLV 1272 5330 GLV 1314 6524 GLV 1309 7093 OV 0 9. Confirm good valve sets with hole finder. Proposed Bi Annual Testing 1. If original MIT-T passed: a. MIT-T to 1500 psi every 2 years b. CMIT-TxIA to 1500 psi every 2 years (this is a gas lifted well). 2. If original MIT-T did not pass: a. MIT-IA to 1500 psi every 2 years b. Set plug below tubing leaks and perform temperature overlay style LDL every 2 years. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 A.Dewhurst 28AUG25 X 10-404 AOGCC witnessed MIT-T post-cement with plug set below lowest tubing leak and or tubing punch. AOGCC witnessed MITIA post-cement. Send CBL results to the AOGCC. Compliance with CO 736 including mechanical integrity tests of the tubing and IA every two years. JJL 8/27/25 DSR-8/19/25JLC 8/28/2025 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.08.28 16:34:41 -08'00'08/28/25 RBDMS JSB 082925 Total cement to pump 24 bbls pumpable Cement Type / Weight Class G 15.8 ppg batch mixed Field blend to by equal to lab +/- 0.1 ppg Requires latex additive for gas block. Slurry Temperature 80° to 110° F Fluid Loss 80 100 cc/30 mins or API FL of 160 200 mls Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 4 hours Originated: Delivered to:18-Jun-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 TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 2P-419 50-103-20483-00 910080528 Kuparuk River Multi Finger Caliper Field & Processed 7-Jun-25 0 12 2P-429 50-103-20378-00 910080397 Kuparuk River Multi Finger Caliper Field & Processed 8-Jun-25 0 13 2T-38A 50-103-20229-01 910106462 Kuparuk River Plug Setting Record Field- Final 8-Jun-25 0 14 2Z-07 50-029-20946-00 910026798 Kuparuk River Plug Setting Record Field- Final 10-May-25 0 15 3K-20 50-029-23019-00 910080196 Kuparuk River Packer Setting Record Field- Final 18-May-25 0 16 3N-12 50-029-21582-00 910080396 Kuparuk River Multi Finger Caliper Field & Processed 3-Jun-25 0 17 3N-12 50-029-21582-00 910080396 Kuparuk River Plug Setting Record Field- Final 3-Jun-25 0 18 3N-12 50-029-21582-00 910080396 Kuparuk River Plug Setting Record Field- Final 4-Jun-25 0 19 3N-12 50-029-21582-00 910080396 Kuparuk River Plug Setting Record Field- Final 6-Jun-25 0 110PLEASE 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:T40597T40598T40599T40600T40601T40602T40602T40602T40602204-017201-102197-205183-064201-088186-0796/20/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.06.20 08:47:18 -08'00'183-0642Z-0750-029-20946-00 910026798Kuparuk RiverPlug Setting RecordField- Final10-May-2501 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-08-18_22113_KRU_2Z-07_18-Aug-23_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22113 KRU 2Z-07 50-029-20946-00 LeakPoint Survey 18-Aug-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 183-064 T37953 8/28/2023 Kayla Junke Digitally signed by Kayla Junke Date: 2023.08.28 12:29:34 -08'00' 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: 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 8853'feet None feet true vertical 6302' feet 8630', 8649'feet Effective Depth measured 8550'feet 8210', 8262', 8442'feet true vertical feet 5755', 5798', 5791'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" x 2-7/8" J-55 8470' MD 5972' TVD Packers and SSSV (type, measured and true vertical depth) 8210' MD 8262' MD 8442' MD 1816' MD 5755' TVD 5798' TVD 5791' TVD 1670' 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: 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: 2633' 2216' Burst Collapse Production Liner 8779' Casing 6268'8813' 2594' 107'Conductor Surface Intermediate 16" 10-3/4" 67' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 183-064 50-029-20946-00-00 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: ADL0025653 Kuparuk River Field/ Kuparuk River Oil Pool KRU 2Z-07 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 107' ~ ~~ Well Remains Shut-In ~~ ~ N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: P2P Patch Packer Packer: P2P Patch Packer Packer: Otis WD Perm Packer SSSV: Camco TRDP-1A Sfty Valve Dusty Freeborn dusty.freeborn@conocophillips.com (907) 659-7224Senior Well Integrity Specialist 8351-8412', 8513-8521', 8533-8568' 5872-5923', 6009-6016', 6026-6056' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Samantha Carlisle at 8:13 am, Feb 13, 2023 Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: Eagle River, AlaskaDate: 2023.02.13 07:28:22-09'00' Foxit PDF Editor Version: 12.0.1 Dusty Freeborn P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 13, 2023 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch set across a known tubing leak in producer KRU 2Z-07 (PTD 183-064). Please contact me at 659-7224 if you have any questions. Sincerely, Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN= Dusty Freeborn, E=dusty.freeborn@ conocophillips.com Reason: I am the author of this document Location: Eagle River, Alaska Date: 2023.02.13 07:27:55-09'00' Foxit PDF Editor Version: 12.0.1 Dusty Freeborn DTTMSTART JOBTYP SUMMARYOPS 12/30/2022 ACQUIRE DATA SET 1.5'' DMY VLV W/RM LATCH ST#7 @ 8181'RKB. OBTAIN PASSING CMIT TO 2500PSI. W/HOLEFINDER OBTAIN GOOD TBG TEST @ 8216'RKB. PULLED 3.5''TTS TEST TOOL FROM LOWER P2P @ 8256'RKB, READY FOR NEW UPPER PATCH. 1/15/2023 ACQUIRE DATA SET 2.70" PBR SPACER ANCHOR LATCH (OAL 31.63' / SN: CPPBR35036 / CPAL35199) @ 8230' RKB. RAN 3 1/2 TTS TEST TOOL TO 2.70" PBD @ 8270' RKB CMIT TBG x IA 2500 PSI (PASS). SET 2.72" P2P (MID ELEMENT @ 8212.2), SPACER EXPANSION JOINT, & ANCHOR LATCH (OAL 15.78' CLOSED ****OPEN 24.78' SN; CPP35349 / CPEJ27203 / CPAL35135) @ 8209.82' RKB. RAN 3 1/2 TTS TEST TOOL IN UPPER P2P @ 8210' RKB MIT TBG 2500 PSI (PASS), CMIT TBG x IA 2500 PSI (PASS). JOB COMPLETE. 2Z-07 Tubing Patch Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Est. 18' of Fill) 8,550.0 2Z-07 7/29/2022 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Installed GLD 2Z-07 2/4/2023 zembaej 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 40.0 107.0 107.0 62.50 H-40 WELDED SURFACE 10 3/4 9.95 39.0 2,633.4 2,216.1 45.50 K-55 BTC PRODUCTION 7 6.28 34.3 8,813.0 6,267.9 26.00 K-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 31.4 Set Depth 8,469.9 Set Depth 5,972.3 String Ma 3 1/2 Tubing Description TUBING 3.5" x 2.875" @8459' Wt (lb/ft) 9.20 Grade J-55 Top Connection BTC AB-MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.4 31.4 0.00 HANGER 8.000 FMC GEN II TUBING HANGER 3.500 1,816.5 1,670.2 37.29 SAFETY VLV 5.937 CAMCO TRDP-1A SAFETY VALVE 2.812 2,765.7 2,292.9 54.99 GAS LIFT 5.540 OTIS WBD 2.897 5,330.7 3,703.4 50.94 GAS LIFT 5.540 OTIS WBD 2.897 6,524.0 4,516.9 44.37 GAS LIFT 5.540 OTIS WBD 2.897 7,093.9 4,922.2 44.03 GAS LIFT 5.540 OTIS WBD 2.897 7,539.1 5,245.1 43.70 GAS LIFT 5.540 OTIS WBD 2.897 7,922.2 5,527.2 39.92 GAS LIFT 5.940 OTIS WBD 2.897 8,181.4 5,732.2 35.53 GAS LIFT 5.940 OTIS LBX 2.907 8,228.1 5,770.4 34.83 SBR 5.625 OTIS SBR 2.937 8,253.4 5,791.2 34.45 PACKER 5.937 OTIS RRH RETRIEVABLE PACKER 2.867 8,292.8 5,823.8 33.86 Mandrel PROD 5.390 CAMCO KBUG 2.920 8,336.5 5,860.2 33.48 BLAST RINGS 4.500 BLAST RINGS (3) 2.992 8,434.1 5,942.0 32.40 NIPPLE 4.540 AVA BPL PORTED NIPPLE 2.750 8,441.0 5,947.8 32.28 SEAL ASSY 4.000 OTIS LOCATOR SEAL ASSEMBLY 3.000 8,442.0 5,948.7 32.26 PACKER 5.937 OTIS WD PERMANENT PACKER 2.867 8,445.4 5,951.5 32.21 SBE 4.250 SEAL BORE EXTENSION W/ CROSSOVER 3.5 x 2.875, ID 2.441, #6.5, J-55, EUE8RD 3.250 8,459.1 5,963.1 31.97 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 8,469.2 5,971.7 31.79 SOS 3.625 OTIS SHEAR OUT SUB. TTL ELMD @ 8468' ON SWS PPROF 10/16/2005 2.375 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,209.8 5,755.4 35.10 PACKER - PATCH - UPR 2.725" P2P (MID ELEMENT @ 8,212.0'), SPACER PIPE, EXPANSION JOINT, & ANCHOR LATCH (24.78' OAL W/ EXPANSION JOINT FULLY OPEN) TTS P2P CPP3 5349 1/15/2023 1.625 8,213.4 5,758.3 35.05 ANCHOR LATCH ON SPACER PIPE SPACER PIPE, EXPANSION JOINT (PINNED TO 2000#), & ANCHOR LATCH CONNECTED TO UPPER P2P. TTS EXP JOINT & ANCHO R LATCH CPEJ 27203 /CPAL 35135 1/15/2023 1.600 8,228.0 5,770.3 34.83 LEAK - TUBING LEAK IDENTIFIED BY EL LDL AT 8228' RKB 8/28/2022 2.992 8,230.7 5,772.5 34.79 PBR PBR, SPACER PIPE, & ANCHOR LATCH (31.6' OAL)- -USE TTS PULLING TOOL TO RECOVER. TTS PBR CPPB R3503 6/CPA L3519 9 1/15/2023 1.600 8,246.0 5,785.1 34.56 LEAK - TUBING LEAK IDENTIFIED BY EL LDL AT 8246' RKB 8/28/2022 2.992 8,252.0 5,790.0 34.47 LEAK - TUBING LEAK IDENTIFIED BY EL LDL AT 8252' RKB 8/28/2022 2.992 8,261.6 5,797.9 34.33 PACKER - PATCH - LWR 3-1/2" LWR PIIP MID- ELEMENT AT 8264' RKB, OAL 4.01' TTS PIIP CPP3 5303 9/22/2022 1.625 8,434.0 5,941.9 32.41 ISO-SLEEVE 2.75" AVA TPI NEW STYLE SLEEVE 7/30/2022 2.310 8,630.0 6,109.8 30.25 FISH FISH 1" GLV W/LATCH SPRNG & WOBBLE RING - HAS FALLEN DOWNHOLE FROM 7540' 1/17/2002 0.000 8,649.0 6,126.2 30.25 FISH 2 - 28' Perf Guns in Hole 5/22/1983 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) 2,765.7 2,292.9 54.99 1 GAS LIFT GLV BK 1 1,272.0 2/3/2023 OTIS WBD 0.156 5,330.7 3,703.4 50.94 2 GAS LIFT GLV BK 1 1,314.0 2/4/2023 OTIS WBD 0.188 6,524.0 4,516.9 44.37 3 GAS LIFT GLV BK 1 1,309.0 2/2/2023 OTIS WBD 0.188 7,093.9 4,922.2 44.03 4 GAS LIFT OV BK 1 0.0 2/2/2023 OTIS WBD 0.250 2Z-07, 2/9/2023 12:23:28 PM Vertical schematic (actual) PRODUCTION; 34.4-8,813.0 FISH; 8,649.0 FISH; 8,630.0 IPERF; 8,533.0-8,568.0 IPERF; 8,513.0-8,521.0 PACKER; 8,442.0 ISO-SLEEVE; 8,434.0 RPERF; 8,411.0-8,412.0 FRAC; 8,351.0 RPERF; 8,351.0-8,411.0 Mandrel PROD; 8,292.8 PACKER - PATCH - LWR; 8,261.5 PACKER; 8,253.4 LEAK - TUBING; 8,252.0 LEAK - TUBING; 8,246.0 PBR; 8,230.7 LEAK - TUBING; 8,228.0 ANCHOR LATCH ON SPACER PIPE; 8,213.4 PACKER - PATCH - UPR; 8,209.8 GAS LIFT; 8,181.4 GAS LIFT; 7,922.2 GAS LIFT; 7,539.1 GAS LIFT; 7,093.9 GAS LIFT; 6,524.0 GAS LIFT; 5,330.7 GAS LIFT; 2,765.7 SURFACE; 39.0-2,633.4 SAFETY VLV; 1,816.5 CONDUCTOR; 40.0-107.0 KUP PROD KB-Grd (ft) 39.01 RR Date 5/23/1983 Other Elev 2Z-07 ... TD Act Btm (ftKB) 9,911.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292094600 Wellbore Status PROD Max Angle & MD Incl (°) 58.75 MD (ftKB) 3,400.00 WELLNAME WELLBORE2Z-07 Annotation Last WO: End Date 4/22/1987 H2S (ppm) 60 Date 12/2/2016 Comment SSSV: TRDP 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) 7,539.1 5,245.1 43.70 5 GAS LIFT DMY BK 1 0.0 7/21/2009 OTIS WBD 0.000 7,922.2 5,527.2 39.92 6 GAS LIFT DMY BK-2 1 0.0 4/22/1987 OTIS WBD 0.000 8,181.4 5,732.2 35.53 7 GAS LIFT DMY RM 1 1/2 0.0 12/30/2022 OTIS LBX 0.000 8,292.8 5,823.8 33.86 8 PROD DMY BK 1 0.0 7/30/2022 CAMCO KBUG 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,351.0 8,411.0 5,872.3 5,922.5 C-4, UNIT B, 2Z- 07 4/22/1987 12.0 RPERF 5" Dressler Atlas, 120 deg ph 8,411.0 8,412.0 5,922.5 5,923.4 UNIT B, 2Z-07 5/22/1983 4.0 RPERF 5" Dressler Atlas,120 deg ph 8,513.0 8,521.0 6,009.1 6,015.9 A-5, 2Z-07 5/22/1983 12.0 IPERF 5" Dressler Atlas,120 deg ph 8,533.0 8,568.0 6,026.2 6,056.3 A-4, 2Z-07 5/22/1983 12.0 IPERF 5" Dressler Atlas,120 deg ph Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 8,351.0 8,412.0 1 FRAC 2/28/2001 0.0 0.00 0.00 2Z-07, 2/9/2023 12:23:29 PM Vertical schematic (actual) PRODUCTION; 34.4-8,813.0 FISH; 8,649.0 FISH; 8,630.0 IPERF; 8,533.0-8,568.0 IPERF; 8,513.0-8,521.0 PACKER; 8,442.0 ISO-SLEEVE; 8,434.0 RPERF; 8,411.0-8,412.0 FRAC; 8,351.0 RPERF; 8,351.0-8,411.0 Mandrel PROD; 8,292.8 PACKER - PATCH - LWR; 8,261.5 PACKER; 8,253.4 LEAK - TUBING; 8,252.0 LEAK - TUBING; 8,246.0 PBR; 8,230.7 LEAK - TUBING; 8,228.0 ANCHOR LATCH ON SPACER PIPE; 8,213.4 PACKER - PATCH - UPR; 8,209.8 GAS LIFT; 8,181.4 GAS LIFT; 7,922.2 GAS LIFT; 7,539.1 GAS LIFT; 7,093.9 GAS LIFT; 6,524.0 GAS LIFT; 5,330.7 GAS LIFT; 2,765.7 SURFACE; 39.0-2,633.4 SAFETY VLV; 1,816.5 CONDUCTOR; 40.0-107.0 KUP PROD 2Z-07 ... WELLNAME WELLBORE2Z-07 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-08-28_15867_KRU_2Z-07_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15867 KRU 2Z-07 50-029-209460-00 Caliper Survey w/ Log Data 28-Aug-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:183-064 T36965 Kayla Junke Digitally signed by Kayla Junke Date: 2022.09.01 11:05:20 -08'00' 0641 RECEIVED • • 151' FEB 02 2016 WELL LOG TRANSMITTAL#903010635 GCC To: Alaska Oil and Gas Conservation Comm. January 29, 2016 Attn.: Makana Bender DATA LOGGED 333 West 7th Avenue, Suite 100 2../ I2O14 K BENDER Anchorage, Alaska 99501 RE: Production Profile: 2Z-07 Run Date: 12/23/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2Z-07 Digital Data in LAS format,Digital Log Image file, Interpretation Report 1 CD Rom 50-029-20946-00 Production Profile Log 1 Color Log 50-029-20946-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / ' A,2-"ztiv / • • '13- oiiiets94-1s4 WELL LOG TRANSMITTAL#902784849 DATA LOGGED tl/So/2015 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. November 20, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SY RE: Production Profile: 2Z-07 Run Date: 9/28/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2Z-07 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-20946-00 Production Profile Log 1 Color Log 50-029-20946-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 1))Aget-isek-,17) 6,-Acedt 14119 110 • 061A G11 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. December 6, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Production Profile: 2Z-07 SCANNED , r, Run Date: 10/28/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2Z-07 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-20946-00 Production Profile Log 1 Color Log 50-029-20946-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: l Ziy9 1i Signed: 1144 ge Project Well History File~er Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. _ 0 RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. D Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: : [] Logs of various kinds NOTES: [] Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Scanning Preparation BY: BEVERLY BREN Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: (0~" PA~--~"'~:OUNT MATCHES NUMBER IN SCANNING PREPARATION: .~ YES Stage 2 IF NO IN STAGE 'l, PAGE(S) DISCREPANCIES WERE FOUND: YES BY: BEVERLY BREN VINCEN~'-~ MARIA LOWELL (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) NO NO DATE: ',., ~ / RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is/ General Notes or Comments about this file: Quality Checked • 0 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 28, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 2Z -07 Run Date: 9/25/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2Z -07 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 029 - 20946 -00 Production Profile Log �� NOV 15 WD 1 Color Log 50- 029 - 20946 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood (�I� 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.w6 -6 t'lrb�ft Cc7 - a Date: Signed: LI) • COI'1 ~ . . ocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 31, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 • SEP 0 ~ 2009 Al~~k~ Qel ~ C~~ ~~n~. ~Co 'ssion Anchov~ ~3"~~~ ~~- ~ `] w ~,~r,~ s.; ~~.. ~ ' ( k.~w~~ . t ~. ~4 e31.. . '_ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRi~. 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 treatrnents took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 15~' and 23rd 2009, and the corrosion inhibitor/sealant was pumped August 27~', 28;~ and 29th 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~ ~~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • r,=~ ~~~ ~'E, Pw~ ,r~ ~~~G~ r t}~~ ~ ~~ arr~ ConocoPhillips Alaska Inc. ~6~.i~P,`~ F7~~ E-°? ~-`',4? "a.si3~~. ~~~M~~CC~(3k'B P.~a'etu~~F9~L€^ ,1~q:F Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field eil Name PI # TD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor , ~ Corrosion inhibitod sealant date bbls ft al 1J-03 50029230020000 2010240 22" N/A 22" N/A 4.1 8/29/2009 1J-09 50029230060000 2010440 28" N/A 28" N/A 6.2 8/29/2009 1J-10 5002923~100000 2010710 12" N/A 12" N/A 2.3 8/29/2009 1J-133 50029233150000 2061060 3' N/A 3' N/A 23.8 S/30/2009 3G-24 50103201450000 1901340 18" N/A 18" N/A 5.1 8/30/2009 1A-19 50029221110000 1901610 30" N/A 30" N!A 3.8 8/30/2009 2Z-04 50029209650000 1830860 19" ~ N/A 19" N/A 3.5 8/30/2009 2Z-05 50029209560000 1830760 12" N/A 12" N/A 2.1 8/30/2009 2Z-07 50029209460000 1830640 9" N/A 9" N/A 8.5 8l30/2009 2Z-15 50029213620000 1851080 9" N/A 9" N/A 2.8 2Z-21 50029218770000 1881250 3' N/A 3' N/A 19.6 8/30/2009 1J 3G 1A & 2ZPAD 2Z-07 (PTD 183-064) Report of~ailed TIFL • Page 1 of 1 ~ Regg, James B (DOA) From: NSK Probiem Well Supv [n1617@conocophillips.com] Sent: Saturday, July 11, 2009 12:53 PM To: Maunder, Thomas E(DOA); Regg, James B(DOA) Cc: Schwartz, Guy L(DOA); NSK Problem Well Supv Subject: 2Z-07 (PTD 183-064) Report of failed TIFL ~ Attachments: 2Z-07 schematic.pdf; 2Z-07 90 day TIO plot.jpg Tom, Jim, Guy / Kuparuk gas lifted producer 2Z-07 (PTD 183-064) failed a diagnostic TIFL on 07/09/09. The well was shut in rior to the test. The TIO prior to the test was 2000/1890/640. A ea ing GLV is suspec e. Siickline will troubleshoot the-Z~C~`s and repair if possible. ~ Attached is a schematic and a 90 day TIO plot. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 .~ ~'~,«. ~.~: .~ i~ ^ `; . ~ ~~~ .:'~~~. «2Z-07 schematic.pdf» «2Z-07 90 day TIO plot.jpg» 8/31 /2009 KRU 2 Z-07 PTD 183-064 7/ 11 /2009 TIO Pressures TIUO P I ot - 2Z-07 2000 1500 ~ . .~ . . . . . . . . . . . . . . . . . . . . . . . . . . . ~. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ~I . . . . . . . . . . . . . . . . l. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ~ a 1000 500 0 -{+++~ 11-Apr-09 24-Apr-09 07-May-09 20-May-09 02-Jun-09 15-Jun-09 28-Jun-09 Date 200 ~ 150 a E a~ 100 ~ Y O S v 50 0 ~ KU P ~ 2Z-07 Cc?n+~CaiF'hil~ips ~ y~L ~~ ~.~~~4~Y~ _ , 5 :~'.3.ttY, ik h &_a"+~#i ~..= ~ ~S#5~~ ~,, y~ ,n _ _ ~~~'~ Wellpore APUIIWI Fleld Name WeIlStatus Prodllnj Type Incl (°) MD (ftKB) Act Bdn ((tl(B) 500292094600 K UPARUK RIVER UNIT PROD 58.75 3,400.00 9,911.0 Comment H2S (ppm) Date Annofation End Date KB-Grtl (R) Rig Release Data SSSV: TRDP 115 7/1/2008 Last WO: 4@2/1987 39.01 5/23/1983 we[~~. n --n ~~:tat t o ~:~ a _ Spfi9~na..~. •~ ~ Annotation Depth (ftKB) End Date Annomtion End Date Last Tag: SLM 8 ,546.0 11/15/2008 Rev Reason: TAG FILL, SE T SLEEVE 11/17/2008 ~"8~tn ~„~t-fa11 S ~ ' i~ ~.~, ~~ . ,`' ,` ~~:- ;~+'-p`,~r~ ~ A,~ '~~' l ry' ~ ' ~ ~ : ~ ` ~ j St ng OD Sbing ID . Set Depth Set Deplh (ND) StrinB Wt . _. Stnng CONDUC70 , CasingDescription (~n) (In) 7op((tKB) ((tKB) (ftKB) (I6sMt) Gratle gU~nBTopThrd ~ CONDUCTOR 16 15.062 0.0 107.0 107.0 62.50 H-40 SURFACE 10 3/4 9.794 0.0 2,633.0 2,215.6 45.50 K-55 SAFETV VLV, `~ PRODUCTION 7 6.151 0.0 9,911.0 26.00 J-55 t,81fi ~`ub~+~ '~tr€n s ~ ~ ,~ _ ''a~' i ;~ " ~r ~ ~ ~ ~ ~ , . .. ~ St ing OD 6tring ID Set Depth Set Depth (ND) String Wt String SURFACE, 2,fi33 Tu6ing Dascription (in) Qn) Top (HKB) (~B) (HKB) ~IbsiFt) Grede 54ing Top Thrtl TUBING 3 1/2 2.867 0.0 8,445.0 5,9512 9.30 J-55 BTC AB MOD GASLIFT~ ~~~~n~I1Q~~F ~~~~~1{~~ ,~'~M~~ '~~~~~~[il~YfBkl~~~1;~~~4 ~`ny IIII~.f . „ "~p'~.:. Z,~68 Top Depth -_ (ND) Top Incl Top ((tKB) (HKB) (°) DescrfOtlon Comment Run Date ID (in) 6AS 4FT 1,816.0 1,668.4 37.06 SAFETY VLV Camco TRDP-1A 4/22/1987 2.812 , e,a3i 2,766.0 2,293.0 55.00 GAS LIFT OTIS/3 1/2 X 1/1/GLV/BK/.156/1290/ Comment: STA 1 3/10/2007 2.897 - 5,331.0 3,703.9 50.94 GAS LIFT OTIS/31/2 X V1/GLVlBKl.t88/1326/ Comment STA2 3/10/2001 2.897 6,524.0 4,516.8 44.37 GAS LIFT OTIS/3 1/2 X 1/1/GLV/BW.188/1318/ Comment: STA 3 3I10/2001 2.897 GASLIFT, s,sza ],OS4.O 4,922.2 44.OO GASLIFT OTIS/31/2X1/1/DMY/BW//Comment:STA4 6/28/1997 2.897 - 7,539.0 5,245.4 44.46 GAS LIFT OTIS/3 V2 X 1/1/GLV/BK/25/7431/ Comment: STA 5 1/17/2002 2.897 7,540.0 5,246.1 44.45 FISH FISH 1" GLV W/LATCH SPRNG & WOBBIE RING 1/17(2002 0.000 GAS~LI~F a ~,gpp,0 5,527.1 39.92 GAS LIFT OTIS/3 1/2 X 7/t/DMV/BK-2/f/ CommenC STA 6 4/22/1987 2.697 8,181.0 5,731.9 35.54 GAS LIFT OTIS/3 1/2 X 1 1/2 LBX~1.5/OV/RM/.250 Comment STA 7 1/17/2002 2.907 '~ 8,228.0 5,770.3 3429 SBR Otis 4/2?J1987 2.960 GASLIFT, 7 539 B,PS$.O 5,790.9 34.10 PACKER Ofis'RRH' 4/22/1987 2.970 , - 8,293.0 5,824.0 33.80 PRODUCTION CAMCO/KBUCa/1/DMY/BK-2/// Comment: CLOSED, STA 8 3/21/7999 2.875 FISH, 7.540 8,434.0 5,941.9 37.91 NIPPLE AVA'BPL' Nipple 4/22/1987 2.750 " 8,434.0 5,941.9 31.91 SLEEVE-O SET 275" AVA TPC NEW STYLE SLEEVE 11/16/2008 2.310 _ 8,442.0 5,9487 31.83 PACKER Otis'WD' 4/22/1987 4.000 GAS LIFT, 922 7 B,AM1S.O 5,9512 31.80 XO SEAL BORE EXTENSION w/CROSSOVER TO 2 7/8" 4122/1987 2.875 . 8,459.0 5,963.1 31.66 NIPPLE Camco'D' Nipple NO GO 4/22/1987 2.250 ~ a 8,488.0 5,970.7 31.57 XO 4/2211987 3.500 GASLIFT, 8,181 $,M1BS.O 5,9~~.6 3~.$6 $~$ ~tIS 4~22/198~ 2.992 8,470.0 5,972.4 31.55 TTL 4/2211987 2.992 - 8,649.0 6, 726.2 30.25 FISH 2- 28' Perf Guns in Hole 5/22/1983 ~ ' ",~ ~, ! i ~ - ~ - ~' ~ x r _ T &BR.8.228 f~~{}.~~~(~ ~ t A e _ ' r i ' ,r& 4., Shot Top (ND) etm (ND) Dens ~ Top (ftKB) Btm (ftKB) (ftK6) (ftKB) Zone Date (sh~^ Type Comment --~ 8,351.0 8,411.0 5,872.4 5,922.6 C -0, UNIT B, 4/22/1987 12.0 RPERF 5" Dressler Atlas, 120 deg ph PACKER, 8,253 ~~~ 2 Z-Q] ~ ~` 8,411.0 8,412.0 5,922.6 5,923.4 U NIT B, 2Z-07 5/27J1983 4.0 RPERF 5" Dressler Atlas,120 deg ph - 8,513.0 8,521.0 6,009.'1 6,016.0 A -5, 2Z-07 5@7Jt983 12.0 IPERF 5" DresslerAtlas,120 deg ph PRODUCTION, 8,293 $,$33.0 8,568.0 6,026.3 6,056.4 A -4, 2Z-07 5/22It983 12.0 IPERF 5" DresslerAtlas,120 deg ph S#i ula fi~~-~ ~ :a." ~~~tnt~ ~ g ,. ~ n~s . .= ' ~s~ < i i _ a~ 4.i g r ~.~ ~' dt. _ , sd5 ~ , _ -~;~ x• = -_~~ RPERF, ~ Bolto~ll 8,351-a,a11 Min Top Max Bdn Top Depth Depth FRAC, 8,35i Depth Depth (ND) (ND) ~ (ftK6) (ftKB) (ftK8) (HKBI Type Date Comment RPERF, 8 411-8 412 $,3S'I.O 8,412.0 5,872.4 5,923.4 F RAC 7J28/2001 'C SAND FRAC , , ~ NIPPIE, 8,434 ' SLEEVE-O, 8,430 PACKER, 8,442 XO, 8,6q5 NIPP~E, 8,459 PUP, 8,4fi0 XO, 8,468 505, 8,469 TTL.8.4]0 °~.~_~ __._ ._. IPERF, ...__ ................. ..... 8,513-8,521 ... .. . IPERF, _ ..................... ....... ~ ^ 8,533-8,Sfi8 ~~-~: ~, ~ '. ' . FISH,8,649 -- PRO~UCTION, ', 9.911 T0. 9.811 05/12/09 ~... rya: rrr.%"' Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # .g i. ~ ~~ 'w _ ~. ~~ pY ~. ~ X009 ~lask~ iii ~~~ ~~~~. ~~r~ig~i~~ ~r3~hOr~g~ Log Description NO.5228 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 3A-18 AYS4-00069 PERF/SBHP SURVEY l 04/26/09 1 1 3C-08 B146-00033 GLS $ = / 04/21/09 1 1 2M-25 B146-00034 GRlTEMP LOG (9!- 04/22/09 1 1 1R-19A AYS4-00065 SBHP SURVEY -r G " `"'" 3~ 04/23/09 1 1 3G-13 AYS4-00067 SBHP SURVEY ! 04/24/09 1 1 3G-05 AYS4-00066 SBHP SURVEY 04/24/09 1 1 3F-07 B14B-00038 SBHP SURVEY - ~ 04/24/09 1 1 3F-08 B14B-00037 SBHP SURVEY = _ 04/24/09 1 1 3M-25A B14B-00040 SBHP SURVEY - 3 04/25/09 1 1 3K-08 8146-00039 SBHP SURVEY C/ 04/25/09 1 1 2N-318A AWJI-00026 MEM BHP SURVEY 04/27/09 1 1 2Z-07 8146-00045 SBHP SURVEY - 04/29/09 1 1 2Z-01A B14B-00044 SBHP SURVEY ~-~ ~ (~ 04/29/09 1 1 3K-102 ANHY-00080 GLS 04/30/09 1 1 2W-06 B04C-00036 PRODUCTION PROFILE 05/02/09 1 1 2W-12 604C-00037 PRODUCTION PROFILE p 05/03/09 1 1 3C-02 B04C-00045 POWERCUTTER W/SBHP SURVEY- 05/09/09 1 1 1J-120 604C-00043 GLS ~ ® Q 05/08/09 1 1 31-11 B04C-00044 SMALL TBG PUNCH W/SBHP 05/08/09 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. u • ~~ 1 ~~.lil~~~~~s~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTIJ: Beth Well Job # __ .. ~ ~ ~r ~ ~ ~~m~ ,~ ~-~- ~~ Log Description Company: Alaska Oil 8~ Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 11!16/07 3J-16 11850468 INJECTION PROFILE ~ "~ 11/02/07 1 1J-122 11745241 MEM PROD PROFILE _ -3-U 11/03/07 1 1C-26 11745244 MEM INJECTION PROFILE v ~ I 11/09107 1 2Z-07 11850476 PRODUCTION PROFILE 11/11/07 1 1Y-01 11839683 INJECTION PROFILE 11/15/07 1 1Y-24AL1 11837535 LDL p 11/15/07 1 V Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • C~ ~•~ 10/31/05 Schlumberger NO. 3513 Schlumberger -DCS 2525 Gambell Street, Suite 400 SCANNED NOV 2 :1 2005 Com pany: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 AUn: Helen Warman ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk -- Well Job# Log Description Date BL Color CD 1R-16 11015756 PRODUCTION PROFILE 10/24/05 1 2X-10 11015758 PRODUCTION PROFILE 10/26/05 1 1D-128 11015759 INJECTION PROFILE 10/27/05 1 3J-06 11072927 SBHP SURVEY 10/30/05 1 3J-07 A 11072926 SBHP SURVEY 10/30/05 1 2Z-29 11072924 PRODUCTION PROFILE 10/28/05 1 1A-02 11022938 INJECTION PROFILE 10/18/05 1 1 Q-26 11022937 PRODUCTION PROFILE 10/17/05 1 1G-16 11015753 INJECTION PROFILE 10/21/05 1 2A-08 11015755 INJECTION PROFILE 10/23/05 1 2G-15 11072919 PRODUCTION PROFILE 10/23/05 1 2N-329 11022935 PRODUCTION PROFILE 10/15/05 1 t/ 2Z-07 11022936 PRODUCTION PROFILE 10/16/05 1 3G-02 11056697 PRODUCTION PROFILE 09/20/05 1 2B-03A 11015749 PRODUCTION PROFILE 10/05/05 1 3N-09 (REDO) 11015722 PRODUCTION PROFILE 08/29/05 1 ~' 2C-04 11022934 INJECTION PROFILE 10/14/05 1 ~M-07 (REDO) 11015737 INJECTION PROFILE 09/26/05 1 2A-01 A 11072922 INJECTION PROFILE 10/26/05 1 1R-10 11015757 INJECTION PROFILE 10/25/05 1 2Z-08 11072920 INJECTION PROFILE 10/24/05 1 1 E-170 11015750 USIT 10/19/05 1 1J-154 11022931 USIT 10/12/05 1 2F-03 11015763 INJECTION PROFILE 10/31/05 1 SIGNED: íU ßJL¡, DATE: ) f/IJuv ~6-~1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . 'O:~ ~~ 'Ðb:«i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1990' FSL, 286' FEL, Sec.11, T11N, R9E, UM At top of productive interval 1438' FNL, 1324' FEL, Sec.13, T11N, R9E, UM At effective depth At total depth 1626' FNL, 1147' FEL, Sec.13, T11N, R9E, UM 5. Type of Well: Development _X Explorato~ StratigraPhic__ Service__ (asp's 529420, 5966750) (asp's 533678, 5963340) (asp's 533856, 5963153) 6. Datum elevation (DF or KB feet) RKB 106 feet 7. Unit or Property name Kuparuk Unit 8. Well number 2Z-07 9. Permitnumber/approvalnumber 183-064 10. APInumber 50-029-20946 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 73' SURF CASING 2527' PROD CASING 8705' 8853 feet Plugs (measured) 6302 feet 8490 feet Junk (measured) 5989 feet Fill Cleanout to 8490' MD (3/8/01) Size Cemented Measured Depth True vertical Depth 16" 340 Sx AS II 73' 73' 10-3/4" 1200 SxAS III & 300 Sx 2633' 2216' AS I 7" 550 Sx CIG & 250 AS I 9911' 6266' Perforation depth: measured 8351 - 8412'; 851 3 - 8521'; 8533 - 8568' true vertical 5872 - 5923'; 6009 - 6016'; 6026 - 6056' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 Tubing @ 8470' MD. Packers & SSSV (type & measured depth) RECEIVED APR 09 2001 ~,laska 0il & Gas Or,ms. C0rnmis.sio~ Ar:c;horage Otis 'RRH' Packer @ 8253' MD; Otis 'WD' Packer @ 8442' MD. Oamco TRDP-1A @ 1816' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation 401 Subsequent to operation 1236 Representative Da y Avera,qe Production or Iniection Data Gas-Mc~ Water-Bbl 1178 497 2101 1552 Casing Pressure Tubing Pressure - 205 253 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Form 10-404 Rev 06/15/88 · Signed ~'e 265-6471 ~'~ SUBMIT IN DUPLICATE 2Z-07 DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT 2/24/01: RIH & tagged Fill at 8558' MD. 2/26/01- RU & pumped gelled sand slurry containing 1600 lbs of 20/40 mesh sand, to place an isolation sand plug across the open 'A' sand perforation intervals located at: 8513 - 8521' MD 8533 - 8568' MD 2/27/01- RIH & tagged sand plug at 8486' MD. Dump bailed a Sluggit cap onto top of sand plug. RD. 2/28/01: MIRU & PT equipment. Attempted to pump a Hydraulic Fracture Treatment through the 'C' sand perforation intervals located above the sand plug at: 8351 -8412' MD Pumped Breakdown w/400 bbls of 20# Linear Gel, followed by Shutdown. ISIP @ 2130. Pump Scour stage w/125 bbls of 50# Crosslinked Gel, followed by 50 bbls of Scour slurry w/1 ppa 16/20 mesh proppant, followed by 98 bbls 20# Gelled Flush, followed by Shutdown. ISIP @ 2250. Resumed pumping Data Frac w/40 bbls of 50# Crosslinked Gel @ 15 bpm, followed by 17 bbls of 50# Crosslinked Gel @ 5 bpm/7500 whp, then Shutdown. Well pressured out; couldn't pump into well. RD. 3/2/01: RIH w/CT & jetted proppant & sand plug from well to 8400' MD. 3/4/01' Performed a 'C' sand injectivity test to 2 bpm @ 2000 psi. 3/6/01: MIRU & PT equipment. Pumped an Acid Treatment followed by a Hydraulic Fracture Treatment through the 'C' sand perforation interval above the sand plug (listed above). Pumped 50 bbls of 12% DAD Acid, followed by 50 bbls NH4CI Water, followed by Shutdown for 3 minute soak. Resumed pumping 30 bbls of 20# Gel @ 17 bpm & 6700 psi, followed by Shutdown. ISIP @ 1986. Pumped Breakdown w/295 bbls of Water @ 15 bpm, followed by Shutdown. ISIP @ 2013. Pumped Scour stage w/100 bbls of 50# Crosslinked Gel, followed by 50 bbls of Scour slurry w/2160 lbs of 16/20 mesh proppant @ 15 bpm, followed by 98 bbls of 20# Gelled Flush, followed by SD. ISIP @ 2011. Resumed pumping Data Frac w/100 bbls of 50# Crosslinked Gel @ 15 bpm, followed by 75 bbls of 20# Gel followed by Shutdown. ISIP @ 2298. Resumed pumping Frac w/250 bbls of 50# Crosslinked Gelled Pad @ 15 bpm, followed by Gelled slurry stages w/proppant ramped in at 2 to 10 ppa stages, followed by 28 bbls 20# Gel Flush, followed by SD. Placed a total of 76,059 lbs of proppant into the formation. Rigged down. 3/8/01' RIH w/CT & jetted proppant from well to 8490' MD. Returned well to production w/gas lift & obtained a valid well test. A . MEMORANDUM · TO: THRU' FROM' State of Alaska Alaska Oil and Gas Conservation Commission Julie HueSser, ' DATE' December 1, 2000 CommisSioner Tom MaUnder, ,~~ P. I. Supervisor %'~ ~. ~ Chuck~Scheve; SUBJECT: Petroleum Inspector . Safety Valve Tests Kuparuk River Unit 2Z Pad Friday, December 1, 2000: I traveled to the Kuparuk River Field and witnessed the semi annual safety Valve syStem testing ~on 2Z Pad. As the attached AOGCc Safety Valve SYstem Test Report indicates I witnessed the. testing of 12 wells and 24 compOnents with two failures observed. The surface safety-valve on Wells 2Z-7 and 2Z,10 had slow leaks when pressure tested. These two valves will be Serviced and retested by the operator. ' Earnie Barndt conducted the testing today he demonstrated good test procedure and was a pleasure to WOrk with . SUmmary:. I witnessed the~semi annUal SVS testing at 2Z Pad in the Kuparuk River Field, KRU 2Z Pad, 12 wells, 24 components, 2 failures 8.3% failure rate Attachment: SVS KRU 2Z Pad 12,1,00 CS X. UnclaSsified Confidential (Unclassified if doc. Removed) sVs KRU 2Z Pad 12-1-00 CS.doc AlaSka Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Operator Rep: Emie Barndt AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: FieldFLlnit~ad: Kupauk / KRU / 2Z Pad ' Separator psi: LPS 100 HPS 12/1/00 Well Permit Separ Set . L/P Test Test Test Date Oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code Passed CAS or CYCL~ 12Z-01 1830730 100 70 70 P P OIL 2Z-02 18308001 2Z-03 1830850 2Z-04 ' 1830860 2Z-05 1830760 100 .70i 70 P P OIL 2Z-06 1830770 3700 2000 2000 P ~ P WAG 2Z-07 1830640 100 70 65 P 4 OIL 2Z-08 1830380 2Z-09 '1851360 2Z-10 1851370 100 70 70 P 4 OIL 2Z-11 1851380 2Z-12A 1951480 100 70 50 P P OIL 2Z- 13 1851060 2Z-14 1851070 2Z-15 -1851080 3700! 2000 ' 1700 P P WAG ,, 2Z-16 1851090 2Z-18 1881330 100 70 65 P P OIL 2Z-19 1881300 100 70: 65P P OIL 2Z-20 1881240 100 70 100 P P ' O1~ 2Z-21 1881250 100 70 70 P P OIL 2Z-22 1 1941470~ ,, 2Z-23 1950100 2Z-29 1881290! 100 70 70 P P OIL '2Z-WS1 1851580 Wells: 12 Components: 24 Failures: 2 Failure Rate: 8.3% E39o var Remarks: .Surface Safety Valves On wells 7 & 10 had slow leaks when pressure tested. They ar serviced and retested by the Operator. Pad 12-1-00 CS.xls · , ' STATE OF ALASKA ~ ~ ~ OILAND G/~ CONSERVATION COMMIoo;ON r~. ~ ~:~, !~:~'~' ~ REPORT OF SU eration Performed: Operation Shutdown Stimulate * Plugging P rfc Pull tubing Alter casing Repair well 2. Name of Operator 5. Type of Well: Development )~ ARCO Alaska. Inc. Exploratory _ 3. Address Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510 Service _ 4. Location of well at surface 1990' FSL, 286' FEL, Sec. 11, T11N, R9E, UM At top of productive interval 1438' FNL, 1324' FEL, Sec. 13, T11N, R9E, UM At effective depth 1551' FNL, 1217' FEL, Sec. 13, T11N, R9E, UM At total depth 1626' FSL, 1147' FEL, Sec. 13, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8853' 6302' feet Plugs (measured) feet Other 6. Datum elevation (DF or KB) 106' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2Z-7 ~-- feet 9. Permit number/approval number 63-64 10. APl number 50-029-20946 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 8 6 4 9' true vertical 61 2 6' feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 73' 16" 2633' 10-3/4" 8811' 7" measured 8533'-8568', true vertical 6026'-6056', Cemented Measured depth True vertical depth 340 Sx AS II 7 3' 73' 1200 Sx AS III & 2633' 221 5' 300 Sx AS I 550 Sx Class G 8811' 250 Sx AS I 8513'-8521', 8351'-8411' 6009'-6016', 5872'-5922' Tubing (size, grade, and measured depth) 3.5", 9.3#, J55 BTC tbg @ 8276' 6257' R. ECEIV[ D ~laska Oil & (Sas cons, Packers and SSSV (type and measured depth) 20 Anch0raget Otis 'RRH' pkr @ 8253', Otis 'WD' pkr @ 8442', Camco TRDP-1A SSSV @ .... 13. Stimulation or cement squeeze summary Fracture Stimulation Intervals treated (measured) Kuparuk 'A' Sands Treatment description including volumes used and final pressure 1004 bbls GW/39 bbls Diesel/798 Gal Additives/190r600# of pro@pant/FTP=5085 psi 14. Reoresentative Daily Average Production 9r In!ection Data OiI-Bbl Gas-Md 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 X 590 611 3 750 1269~-, 36 254 500 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 219 208 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Form 10-404 Rev 09/12/90 o,,,. SUBMIT IN DUPLICATE ARCO Alaska, Subsidiary of Atlantic Richfield Comps-,,; WELL · IPBDT CONTRACTOR WELL SERVICE REPORT FIELD- DISTRICT- STATE ~DAYS i DATE OPERATION AT REPORT TIME C..O~PLET~ REMARKS oq~x) P/T lS~...KStl~ 'rD 35~ PSi t2ql t=L~SH D .xt- 6,~ 2.5 15~, 25 6a. ~ PSI' tzq$ NOV 1 6 !992 Alaska Ull & Gas Cons. Comra[$sto-[~. _. _ · W~.LL.~ 5,Soo Aq~ I~Tg 2~ I~O~, ~bt~S, eL. 3'~ BDt- CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knoll REMARKS CONTINUED: DESCRIPTION DALLY ACCUM. TOTAL CAMCO OTIS SCHLUMBERGER DRESSER-ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER ,, B. J. HUGHES Roustabouts Diesel Methanol ., Supervision Pre-Job Safety M~t'ing ' AFE . ,, TOTAL FIELD'ESTIMATE ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 5, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. W(~ll Action Anticipated Start Date 3H-1 0 Conversion June, 1989 2Z-04 Storm Ck. March, 1989 2F-07 Refracture July, 1989 31-1-04 Acidize June, 1989 2Z-07 Acidize May, 1989 3B-02 Tbg. Leak June, 1989 3K-15 Stimulate June, 1989 2Z-29 Acidize June, 1989 If you have any questions, please call me at 265-6840. Sincerely, G. B. Smallwood Senior Operations Engineer ARCC .Cl.'~5,~a -'-nc..s a SuDs*diary o! AllanlicRir. hlieidOompanv STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Operation Shutdown__ Stimulate X Plugging Perforate Pull tubing Alter casing 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 _ Service Location of well at surface 1990' FSL, 286' FEL, Sec. 11, T11N, R9E, UM At top of productive interval 1438' FNL, 1324' FEL, Sec. 13, T11N, R9E, UM At effective depth 1551' FNL, 1217' FEL, Sec. 13, T11N, R9E, UM At total depth 1626' FNL, 1147' FEL, Sec. 13, TllN, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8853' 6302' feet feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 1 7. Unit or Property name Kuparuk River Unit feet 8. Well number~ 2Z-07 ~/~ ~ ~ ~.'-r~ 9. Permit number/approval number 83-64 10. APl number 5o-029-20946 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 8 6 4 9' true vertical 6126' feet feet Junk (measured) 5" csg gun, Top 8649' (28 ' Long) Casing Length Size Structural Conductor 7 3' 1 6" Surface 2 63 3' 1 0 - 3 / 4" Intermediat Production 881 1 ' 7" Liner Perforation depth: measured true vertical Cemented Measured depth True vertical depth 340 Sx A.S. II 73' 73' 1200 Sx A.S. III & 2633' 221 5' 300 Sx Class "ASI" 550 Sx Class "G" 881 1' 250 Sx A.S. I 8513'-8521', 8351'-8411' 6009'-601 6', 5872'-5922' 8533'-8568', 6026'-6056', Tubing (size, grade, and measured depth) 3 1/2", J-55 BTC tbg @ 8276' MD Packers and SSSV (type and measured depth) Packer: OTIS RH pkr@ 8251', CAMCO TRDP-1A SSSV@ 2005' MD 13. Attachments Acidize C Sand Description summary of proposal _ Detailed operation program BOP sket(~h X 14. Estimated date for commencing operation May 17, 1989 16. If proposal was verbally approved Name of approver L. Smith Date approved 3/22/89 15. Status of well classification as: Oil X Gas _ Service Suspended 17. I hereby certify that th~ foregoin~,~ true Signed ,,,~ correct to the best of my knowledge. Title Sr. Operations Engineering FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity m BOP Test M Location clearance~ Mechanical Integrity Test m Subsequent form require Approved by the order of the Commission ORIGINAL SIGNED LONNIE C. SMIT~ IApproval No. l Approved CoPY Returned Commissioner Date ~--~'~ Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE ,/ Kuparuk Well 2Z-07 C Sand Acid Stimulation Procedure Charge Code 230DS28ZL ISOLATE A SAND , 2. 3. 4. 5. 6. 7 MIRU slickline unit. Pressure test lubricator. Pull AVA commingling sleeve. RIH with blanking plug. Set in 'D' nipple at 8459' MD-RKB. POOH. Run AVA blanking sleeve. Pressure test blanking plug. Pull blanking sleeve and RIH with commingling sleeve. POOH and RDMO slickline unit. Allow well to stabilize and obtain C Sand only test. ACID WASH C SANDS . 9. 10. 11. Shut-in well. MIRU CTU, Transports, Nitrogen, and Pumps. Pressure test equipment. Titrate 12% HCL. RIH with CTU to 8434' MD-RKB and pump 5 BBLS xylene, 5 BBLS straight 12% HCL acid, and 50 BBLS nitrified 12% HCL acid at 1 BPM. NOTE: Nitrify with 200 SCF per BBL. 12. 13. Displace with 5 BBLS diesel and purge coiled tubing with nitrogen. Immediately return well to production. Nitrogen lift if necessary. NOTE: A. Operation Engineering should take the following flowback samples: (1) After first spent acid passes sample point. (2) At midpoint of spent acid passing sample point. (3) After final spent acid passes sample point. B. Samples should be analyzed for concentration of Fe+3, Fe+2, and PH. Send results to Jay Stratton, ATO-1136. 14. 15. RDMO CTU, Transports, Nitrogen, and Pumps. After well stabilizes, obtain a 24 hour C Sand only test. 16. 17. 18. 19. 20. 21. MIRU slickline unit. Pressure test lubricator. Pull AVA isolation sleeve. RIH and pull blanking plug in 'D' nipple at 8459' MD-RKB. Run AVA blanking sleeve. Pressure test blanking plug. RDMO slickline unit. Open well to production. After well stabilizes, obtain a 24 hour A/C production test. AFICO Alaska Inc. Is a subsldla~ of Atlantic Richfield C4~npan¥ AR3B-6OO1.A 6 5 1. 5000 PSI ?" WELLHF. AD CONNECTOR FLANGE 2. 5000 PSI 4.1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSi 4 1/6" SHEAR RAMS 5. 5000 PSi 4 1/6" BLIND RAIDS 6. 5000 PSi 4 1/16" STUFFING BOX COILED TUelNO UNIT- BOP ~O, UIPME'HT STATE OF ALASKA ~ ALASKAOIL AND GAS CONSERVATION C~,MMISSION ~ WI=LL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-64 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20946 4. Location of well at surface 9. Unit or Lease Name 1990' FSL, 286' FEL, Sec.ll, TllN, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1438' FNL, 1324' FEL, Sec.13, TllN, R9E, UM 2Z-7 At Total Depth 11. Field and Pool 1626' FNL, 1147' FEL, Sec.13, TllN, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 106' ADL 25653 ALK 2579 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 05/10/83 05/19/83 05/23/83* N/A 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 8853'MD, 6302'TVD 8649'MD, 6126'TVD YES [~ NO [] 1816' feetMDI 1400' (approx.) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR/FDC/CNL/Cal D I.L/FDC/CNL, BHCS, CBL/GR/CCL, Gyro, CET 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 73' 24" 340 sx AS II 10-3/4" 45.5# K-55 Surf 2633' 13-1/2" 1200 sx AS Ill & 300 sx AS I 7" 26.0# K-55 Surf 8811' 8-3/4" 550 sx Class G & 250 sx AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8533'-8568'MD 12 spf, 120° phasing 3-1/2" 8470' 8253' & 8442' 8513'-8521'MD 12 spf, 120° phasing 8351 '-8411 'MD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 6026'-6056'TVD 8478'-8480' 150 sx Class G 6009'-6016'TVD 8473'-8475' 200 sx Class G 5872'-5922'TVD See attached Adden. Jum. dated 5/19/87. for fracture dat. 27.N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested pRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE ~I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Alaska 0~) & Gas O~s. Oommissior~ * NOTE: Workover performed & well reperforated 4/23/87. Fractured well ~/18/87. Form 10~,O7 Rev. 7-1-80 WC264 :DAN I CONTINUED ON REVERSE SIDE Submit in duplicate // .. 29. i -: 30. .. GEOLOGIC MARK[?~5 '~ORMATION TESTS _ _- NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 8352' 587:3' N/A Base Upper Sand 8412' 5923' Top Lower Sand 8502' 6000' Base Lower Sand 8630' 6110' 31. LIST OF ATTACHMENTS Addendum (dated 5/19/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed v-')q_._, ~("f~ t.~/,L~._? Title Associate 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 ADDENDUM WELL: 2Z-7 5/18/87 Frac Kuparuk "A" sand perfs 8513'-8521', 8533'-8568' in eight stages per procedure dated 4/29/87 as follows: Stage 1: (Spear) w/40 bbls 140° diesel 10% Musol @ 5 BPM, 2000-2251 psi Stage 2: (Flush) w/13 bbls gel diesel @ 5 BPM, 2251-2690 psi iStage 3: (Pad) 35 bbls gel diesel @ 20 BPM, 2690-3038 psi Stage 4: (100 mesh) 35 bbls gel diesel 1/2# 100 mesh @ 20 BPM, 3038 - 2874 psi Stage 5: (Spacer) 70 bbls gel diesel 20/25 @ 2874 - 3284 psi Stage 6: (3#) 15 bbls gel diesel 3# 20/40 @ 25 BPM, 3284 - 2990 psi Stage 7: (8#) 44 bbls gel diesel 8# 20/40 @ 25 BPM 2990 - 2770 psi Stage 8: (Flush) 74 bbls gel diesel @ 25 BPM, 2770 - 3026 psi Underflush 1 bbl. (Low pressues probably due to hole in csg @ 8500'.) Fluid to Recover: Sand in Zone: Avg Pressure: Sand in Csg: 386 bbls 700# 100 mesh & 11,400# 20/40 3000 psi Drilling Supervisor Da~e 1. Status of Well Classification of Service Well OIL E~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .... 2. Name of Operator 7. Permit Number / ARCO Alaska, Inc, 83-64 3. Address 8. APl Number P. 0, Box 100360, Anchorage, AK 99510 50- 029-20946 4. Location of well at surface 9. Unit or Lease Name 1990' FSL, 286' FEL, Sec.11, T11N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1438' FNL, 1324' FEL, Sec.13, TllN, R9E, UM 2Z-7 At Total Depth 11. Field and Pool 1626' FNL, 1147' FEL, Sec.13, TllN, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk Ri ver 0i 1 Pool RKB 106' ADL 25653 ALK 2579 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 05/10/83 05/19/83 05/23/83* N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+l-VD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8853'MD, 6302'TVD 8649'MD, 6126'TVD YES [~ NO [] 1816' feet MDI 1400' (approx.) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR/FDC/CNL/Cal, D IL/FDC/CNL, BHCS, CBL/GR/CCL, Gyro, CET 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# U-40 Surf 73' 24" 340 sx AS II 10-3/4" 45.5# K-55 Surf 2633' 13-1/2" 1200 sx AS Ill & 300 sx AS I 7" 26.0# K-55 Surf 8811' 8-3/4" 550 sx Class G & 250 sx AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8533'-8568'MD 12 spf, 120° phasing 3-1/2" 8470' 8253' & 8442' 8513'-8521'MD 12 spf, 120° phasing 8351 '-8411 'MD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 6026'-6056'TVD 8478'-8480' 150 sx Class G 6009'-6016'TVD 8473'-8475' 200 sx Class G 5872 ' -5922 'TVD 27.N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ,~l~S~ :~,~ .¢ ,, .... .~. " ;'. -,,' h, 't b-L~.~ * NOTE: Workover performed & well reperforated 4/23/87, STATE OF ALASKA '~'- ~f j~^ ~/ ALASKA OIL AND GAS CONSERVATION O~,MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO Form 10-407 Rev. 7-1-80 WC264: DAN I CONTINUED ON REVERSE SIDE Submit in duplicate GEOLOGIC MARKERS - · · ....... · :-. ~--6RMATION'TESTS -: ~ . :'~' . . , :~ ? · . -.. ~ - : ~..- . : . - _ - · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. . Top Upper Sand 8352' 5873, N/A . Base UPper sand 8412' 5923' Top Lower Sand 8502' 6000' ' Base Lower Sand 8630' 6110' · . . : . . · .. . ! · 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge · ' : :. _~, .; Signed ~,,~ [')1~'~/~(,_.: Title Associate Engi neet 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- lng 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 STATE OF ALASKA ~ ALAS OIL AND GAS CONSERVATION COM,. .,SION REPORT OF SUNDRY WELL OPERATIONS Feet 1. Operations performed: Operation shutdown Alter Casing ~'er Stimulate '...-i Plugging [] REPERFORATE/WORKOVER Perforate [] Pull tubing 2. Name of Operator ARCO Alaska. Inc 3. Address P.0. Box 100360 Anchorage~ AK '99510-0360 4. Location of well at surface 1990' FSL, 286' FEL, Sec.11, T11N, R9E, UPI At top of productive interval 1438' FNL, 1324' FEL, Sec.13, T11N, RgE, UPI At effective depth 1536' FNL, 1231' FEL, 5ec.13, T11N, RgE, UPI At total depth 1626' FNL~ 1147' FEL~ Sec.13~ T11N, RgE~ UN 11. Present well condition summary Total depth: measured 8853 'HD true vertical 6302 ' TVD Effective depth: measured 8649'MD true vertical 6126'TVD Casing Length Size Conductor 73' 16" Surface 2633 ' 10-3/4" Production 8811 ' 7" 5. Datum elevation (DF or KB) RKR 106' 6. Unit or Property name Kuparuk River Unit 7. Well number 2Z-7 8. Approval number RR-6~ 9. APl number 50-- n~,~-~n,~,~ 10. Pool Kuparuk River Oi] Po91 feet Plugs (measured) None feet feet Junk (measured) feet Cemented 340 sx AS II 1200 sx AS III & 300 sx AS I 550 sx Class G & 250 sx AS I Perforation depth: measured 8533'-8568' 8513 '-8521 ', 8351 '-8411 ' , true vertical 6026 ' -6056 ', 6009 ' -6016 ', 5872 ' -5922 ' Tubing (size, grade and measured depth) 3-1/2", J-55 BTC tbg ~ 8470' Packers and SSSV (type and measured depth) RRH pkr ~ 8253', WD pkr ~ 8442', & TRDP-1A SSSV ~ 1816' 12. Stimulation or cement squeeze summary Intervals treated (measured) 8478'-8480', 8473'-8475' Treatment description including volumes used and final pressure 150 sx Class G, 200 sx Class G 5 1/2" Csg Gun, Top @ 8649' (28' long), Junk ~ 8608' N/A 13. Prior to well operation Subsequent to operation Measured depth 73'MD 2633 'MD 8811 'MD True Vertical depth 73'TVD 2215'TVD 6257'TVD RECEIVED Alaska 0il & Gas Cons. C0mmissi0rl Anchorage Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 14. Attachments (Workover Wel 1 Histor,~,) Daily Report of Well Operations AJ Copies of Logs and Surveys Run ~. 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ Title Associate Engineer Signed Form 10-404 Rev. 12-1-85 (Dani) SW02/24 Tubing Pressure Date Submit in Duplicate ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFEAK2408 Nordic #1 Operator ARCO Alaska, Inc. Spudded or W.O. begun Workover Date and depth as of 8:00 a.m. 4/08/87 4/09/87 4/10/87 l~unty, parish or borough - North Slope Borough I LeaseorUnit ADL 25653 ITitle Recompletion API 50-029-20946 JSlate JDate JHour 4/8/87 'Complete record for each day reported 0015 hrs. IARCO W.I. Prior status if a W.O. 7" @ 8811' ~_~&~~ PBTD <0'> R/U to kill well 8.9 ppg brine in pits MIRU Nordic #1. Accept rig @ 0015 hrs, 4/8/87. Pull equalizing prong f/blanking plug and pull blanking plug f/8265' w/slickline. 7" @ 8811' ZJ~PBTD (0') R/U to shear SBR 9.4 ppg NaC1 Killed well w/9.4 ppg brine and Litesal pill. ND tree, NU and test BOP. 7" @ 8811' ¢Z/~~2~' PBTD POH w/tubing 9.4 ppg brine Attempt to shear SBR. Cut tubing @ 8210' collars to AB mod. 4/11/87 7" @ 8811' thru 4/13/87 9.4 ppg NaC1 Brine 4/14/87 . POH and change Alaska IWell no. 2z-7 56.24% Fin POH & chg out colts to AB-Mod. RIH w/OS, tag pkr @ 8203', wrk over & jar, sheared SBR, POH, LD OS & SBR. RIH w/retrv'g tl, wsh over SBR stick, well started to flow, CBU. Latch pkr @ 8251', wrk string, CBU, POH slow; hole swabbing. Rotate & wrk pkr, cont POH & LD pkr. RU Schl, RIH w/CET, log 8600'-8300'. RU & perf f/8478'-8480'. Make GR/JB rn to 8602'. MU EZSV BP & set on WL @ 8500'. Set EZSV retnr @ 8440'. MU stinger, RIH to 8440', cmt w/150 sx C1 "G & sqz thru CR w/final press of 1750 psi. POH 5 stds, CBU. MU RTTS & storm choke, POH 50 stds, set RTTS. ~7" @ 8811' ~bq~....137-vz~ PBTD, POH 9.4 ppg NaC1 Brine Set RTTS & tst ann to 1000 psi. ND BOPE, NU tbg head. Tst BOPE. RIH, retry RTTS, POH. TIH w/bit, tag cmt @ 8400', DO cmt, EZSV & cmt to BP @ 8503', circ hole cln, POH. The~O'OVe is correct fO[ form prei;~ation and_ dis'~ribu~..~ see Procedufe.~'Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill slem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lnterin~" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish Alaska I North Slope Borough Field ILease or Unit Kuparuk River I ADL 25653 Date and deptrt Complete record for each day while drilling or workover in progress as of 8:00 a.m. 4/15/87 4/16/87 4/17/87 thru 4/20/87 4/21/87 State 4/22/87 7" @ 8811' ~ PBTD, RIH w/EZSV stringer 9.4 ppg NaC1 Brine Cont POH. PU & RIH w/R-3 pkr, set @ 8450'. Press up tbg to 2000 psi; bled to 1200 psi/10 min. Set R-3 pkr @ 8300', tst backside to 3000 psi; lk'd thru DP. POH & LD R-3 pkr. RU Schl, rn CET log f/8491'-8250'. Perf f/8473'-8475'. Make GR/JB rn to 8500'. RIH w/EZSV retnr, set @ 8425'. RD Schl. RIH w/stinger on 3½" DP. 7" @ 8811' ~-z~6' PBTD, POOH 9.4 ppg NaC1 Brine RIH w/stinger, tst ins to 4000 psi. Est IR, sqz 150 sx C1 "G" w/5% KC1, 8.5% D-60 & .2% D-46 into perfs. Rev out 1 bbl cmt. POOH, LD stinger. RIH w/bit/JB, DO EZSV & cmt to 8500', ¢irc hole cln, POOH. Alaska 7" @ 8811' ~rT~' PBTD, TIH 9.4 ppg NaC1 Brine Fin TOH. TIH w/scrpr, C&C, POH. RIH w/RTTS, set @ 8430', tst perfs; bled off 500 psi/30 min. RU & sqz perfs w/50 sx Cl "G". Final press = 3900 psi. Rev out ± 2 bbls cmt, POOH w/RTTS. RIH w/bit/JB to 8397', drl firm cmt f/8397'-8500', circ hole cln, POOH. RIH w/scrpr to 8500', CBU, POOH. RIH w/RTTS, tst sqz perfs; no tst. Tst BP @ 8503'; leaking. Tst ann @ 8305' to 2000 psi; OK, POOH. TIH w/BP, set @ 8499'. Set retrvl pkr @ 8483', tst to 2000 psi; No tst. Reset pkr & retst; no tst. Att to rel BP w/o success. POOH w/retrv pkr. TIH w/retrv'g tl, latch onto BP, POOH. RIH w/bit & JB, DO BP, push to btm, CBU, POOH. PU scrpr & TIH. 7" @ 8811' ~ PBTD, POOH w/RTTS 9.4 ppg NaC1 Brine TIH w/scrpr to 8604', CBU, POH. RU Schl, rn CET f/8600'-8300'; indicates hole @ 8500'. MU WL BP, RIH, set @ 8495', RD Schl. RIH w/RTTS to 8496', att to tst BP; no tst. POH to PU bit. 7" @ 8811' ~ PBTD, Perf 9.4 ppg NaC1 Brine POOH w/RTTS. TIH, drl BP. Cln out to 8608', CBU. Displ well w/cln brine. POOH, LD BHA. RU lubr, tst to 1000 psi. Perf 8381'-8411' & 8351'-8381' @ 4 SPF. IWell no. 27.-7 The~13e~ is correct Fo f p p~ra~c ' ' see Procedure~anual Section 10, DriLling, Pages 86 and 87 Date ITitle Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an o~ficial test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting Ihe entire operation if space is available. District ICounty or Parish Alaska Fie~d ILease or Unit Kuparuk River Auth. or W.O. no. ~Title I AFE AK2408 Spudded or W.O~ begun Workover Nordic #1 Operator A.R.Co. W.I. ARCO Alaska, Inc. Date 4/23/87 Date and depth as of 8:00 a.m. 4/24/87 Complete record for each day reported North Slope Borough ADL 25653 Recompletion IAccounting cost center code State Alaska no. 2Z-7 AP1 50-029-20946 [Total number of wells (active or inactive) on this 56.24Z Icost center prior to plugging and Jabandonment of this well JHour J Prlor status if s W.O. 4/8/87 / 0015 hrs. I ! 2" @ 8811' ~4qq_.~_._' PBS, Set 9.4 ppg NaC1 Brine Make JB/GR rn to 8610'. RIH & set WD ?kr @ 8442', RD Schl. RU & rn 3½", 9.2#, J-55 BTC compl string w/SSSV @ 1816', RRH retrv pkr @ 8253' WD perm pkr @ 8442', TT @ 8470'. ND BOPE, NU & tst tree @ 250/5000 psi; OK. Displ brine w/255 bbls diesel. Tst tbg to 1000 psi w/ann open. 7" @ 8811' 8~' PBTD, RR 6.9 ppg Diesel Set BPV. RR @ 0700 hrs, 4/23/87. Old TD I New TD I PB Depth I Released rig J Date ~ Kind ofrig 0700 hrs. I 4/23/87 I Classifications (oil, gas, etc.) ~ Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 8726' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable !Effective date corrected _. Th e,,~is correct For form prep~l~ti~n and distribut~o'~o~, see Procedurca~.M~nual, Section 10. Drilling, Pages 86 and 87. Date ITitle Drilling Supervisor ARCO Alaska, Inc - Post Office x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: May 12, 1987 Transmittal # 5976 RETURN TO: ARCO Alaska, Inc. Attn: 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. 2Z-7 3K-9A 3K-8 3K-17 iA-10 3Q-16 lA-2 3Q-15 3M-6 3M-2 3M-5 3M-7 3M-4 3M-3 3M-1 2Z-5 2Z-5 CET Log 4-20-87 8275-8597 CBL 11-14-86 5408-7460 CET 11-15-86 7148-8376 CET 11-15-86 7940-9400 CET 11-21-86 8650-8936 CBL 12-20-86 5349-7173 CET 12-21-86 7095-7781 CBL 12-20-86 5453-7360 CBL 4-30-87 5300-7312 CBL 4z28-87 6500-8295 CBL 4-28-87 6200-8795 CBL 4-30-87 6300-8359 CBL 4-28-87 7950-9845 CBL 4-28-87 5800-7933 CBL 4-28-87 4900-7187 Squeeze & Plug/Retainer Record 4-30-87 8090-8144 CET 4-30-87 7000-8324 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil SAPC /' ///~e~:Oil & Gas ConS. Commission ~._~ - - Anchorage ?~-s~ate .of Mas~ (+sepia) ~ BPAE Chevron Union Vault (film) ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 ~Z-'7 TO: RE: Receipt of the following material which was transmitted via ~k~c~;k~ is hereby acknowledged: QUANT I TY DESCRIPTION RECEIVED: DATED: Copy sent to sender YES~ NO""~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 30, 1987 Transmittal # 5966 Return to: Transmitted receipt and ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1ll9 P.O. Box 100360 Anchorage, AK 99510-0360 herewith are the following items. Please acknowledge return one signed copy of this transmittal. 3N-7 CET 4-1-86 6202-7597 3N-6 CET 4-1-86 6061-7583 3N-11 CET 4-22-86 7600-8675 3N-12 CET 4-29-86 6396-7965 3N-10 CET 4-14-86 7462-9130 3J-16 CET 3-29-86 7704-8727 3J-15 CET 3-29-86 7400-8398 1A-8 CET 1-5-86 5755-6154 2Z-7 CET 4-14-87 8250-8491 2Z-7 CET 4-12-87 8246-8595 2Z-7 Squeeze & Retainer Record 2Z-7 Squeeze, 4-15-87 8250-8491 BP & Retainer Record 4-12-87 8290-8588 Alaska Oil & ~as C~ns.'uommiss/or~ Anch0ra~ Receipt Acknowledged: DISTRIBUTION: NSK Drilling Chevron Mobil Date: ?'State of Alaska' (* sepia) SAPC Unocal Vault ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany BPAE (film) /-'" STATE OF ALASKA ALASI.,... OIL AND GAS CONSERVATION COMrv,...$1ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon.~ Suspend ~ Operation Shutdown ~ Re-enter suspended well ~ Alter casin,g,/r~RCO[~.~(2,¥) Time extension ~ Change approved program ~ Plugging ~ Stimulate ~.. Pull tubing ,~Amend order ~ Perforate ~,~ Other~ ~// 2. Name of Operator ARCO Alaska~ Inco 3. Address P. 0, Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1990' FSL, 286' FEL, At top of productive interval 1438' FNL, 1324' At effective depth 1551 ' FNL, 1217' At total depth 1626' FNL, 1147' 11. Present well condition summary Total depth: measured true vertical Sec.11, T11N, R9E, UM FEL, Sec.13, T11N, R9E, UM FEL, Sec.13, T11N, R9E, UM FEL~ Sec.13~ TllN~ RgE~ UM 8853 'MD feet 6302 ' TVD feet 5. Datum elevation(DF or KB) RK~ 10§' 6. Uniter Property name Kuparuk River Unit 7. Well number 2Z -7 8. Permit number 83 -64 9. APl number 50_029-20946 fee( 10. Pool Kuparuk River Oil Pool Plugs (measured) None Effective depth: measured 8649 ' MD true vertical 6126'TVD Casing Length Size Conductor 73 ' 1 6" Surface 2633 ' 1 0-3/4" Production 8811 ' 7" feet feet Junk (measured) Cemented Measured depth 340 sx AS II 73'MD 1200 sx AS I I I & 2633'MD 300 sx A5 I 550 sx Class G & 8811 'MD 250 sx AS I Perforation depth: measured 8533'-8568', 8513'-8521 ', 8351 '-8411 ' true vertical 6026'-6056', 6009'-6016', 5872'-5922' Tubing (size, grade and measured depth) 3-1/2", J-55 BTC tbg @ 8276' Packers and SSSV (type and measured depth) Otis RH pkr @ 8251', Camco TRDP-1A SSSV @ 2005' 5" csg gun, Top ~ 8649' (28' long) ~ue Verticaldepth 73'TVD 2215'TVD 6257'TVD 12.Attachments Description summary of proposal [] Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation April 4, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~/}/~t,./ ._~,t~,~,,~/t.L,~/ Title Associate Engineer Date Commission Use Only 5A2/36 ,~. approval Notify commission so representative may witness I Approval Conditions of No. ~2~/ ~ Plug integrity ~ BOP Test ~ Location clearance~ /~ ~p~oved t ~:,~ .,~: ; - '~:~:~ by order of ~,~ , Commissioner the commission Date ~ Approved by Form 10-403 Rev 12-1-85 Submit in triplicate Kuparuk Well 2Z-7 Conversion to Selective Single & Hydraulic Fracture Preliminary Procedure 1. RU wireline. Obtain BHP. 2. Move in and rig up workover rig. Kill well. 3. Nipple down tree. Nipple up and test BOPE. 4. Shear out of SBR. POB with tubing. Change out collars to AB MOD while POOB. 5. GIB with packer retrieving tool on 3½" drill pipe. Retrieve packer. 6. Run CBT. Squeeze as required. Reperforate if necessary. 7. GIB with bit and casing scraper. Circulate well clean. POB. 8. Set RBP and test casing. Change out tubing spool to 5000 psi equipment. 9. Pull RBP. 10. Run 3½" selective single completion. 11. ND BOPE. NU tree and test.~ 12. Displace well to diesel. 13. Secure well and release rig. 14. Fracture the 'A' sand as required. Completion Fluid: NaC1/NaBr Brine Anticipated Bottom Hole Pressure: 2900 psi · DPROC/2Z-~/ih ANNULAR PREVENTER § PIPE RAHS 4 BLIND RAHS 5 TUBIN6 HEAD 1, 16" CONDUCTOR SWAGED TO 10-3/4" 2. 11"-:$000 PSI STARTING HEAD ~. ! 1 "-:$000 PSI X 7-1 / 16"-5000 PSI TUBING HEAD 4. 7-1/16" - 5000 PSI PIPE RAMS 5. 7-1/t6" - 5000 PSI BLIND RAMS 6. 7-1/16" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID, 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 11500 PSl DOWNSTREAM OF THE REGULATOR. :$. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT, THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL, 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD, RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5, INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS, 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES, BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES, TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY. WITH :$000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI, 9, OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES, BLEED TO ZERO PSI, 10. OPEN BLIND RAMS AND RECOVER TEST PLUG, MAKE SURE MANIFOLD AND LINES ARE FULL OF AP. CTIC DIESEL AND ALL VALVES AI~E SET IN THE DRILLING POSITION, i 1. TEST STANDPIPE VALVES TO 3000 PSt. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP, 1:$. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. i4. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. JG JULY 28, 1986 .-..~.~ ~,~ . .~ --...,,1., A-F[AcHMEN'[ II FEBRUARY 19, 1956 7/6/83 lA-4 10/29/83 lA-7 5/7/82 1/25/$2 lA-9 3/23/83 1~-11 1/19/83 3/21/~3 1A-12 ~II/82 1A-14 iA-is 6/S/~Z 6/8/82 lC-1 1C-2 1C-3 1C-Z~ 1C-5 1C-6 1C-7 1C-B ' .. 15-1 15-2 15-3 18-6 15-7 1B-B 18-9 519181. 518181 7/13/81 11/8/81 319181 2126181 11/30/81 51191B1 5/21/$1 lZ/26/81 6/25/B1 3/12/82 11/18/B1 9/10/82 11/23/81 12/28/81 8/4/82 6/24/82 8/3/84 10-3 1D-5 1D-6 19-7 O.~k,,l~_B · '1/8o 5/23/83 815180 7/30/80 8/13/80 61915~ 618181 5110178 Attachment II ~- Page 2 Drill Site 1H Drill Site lQ Well No. Log Date 1H-3 8/16/82 1H-4 8/13/82 1H-6 6/21/82 1H-7 7/20/82 1H-8 7/22/82 Well No. Lo9 Date Drill Site Well No. Log Date 1E 1E-lA 1E-2 1E-3 1E-4 1E-5 1E-6 1E-7 1E-8 1E-12 1E-15 1E-16 1E-17 1E-20 1E-24 1E-25 1E-26 1E-27 1E-28 1E-29 1E-30 8/19/81 8/17/81 1/17/84 10/18/81 11/7/81 8/4/80 9/2/81 11/5/81 10/27/81 10/21/81 11/12/82 8/28/81~Q/~;.]~1 10/28/81 8/28/81 11/1/81 11/28/84 8/26/82 8/29/82 9/1/82 5/7/83 2/17/83 1/17/83 1/13/83 10/31/82 10/27/82 6/13/83 10/18/82 7/18/83 10/16/82 Drill Site 16 Well No. Log Date 16-1 16-2 16-3 16-4 16-5 t6-7 16-8 Drill Site Well No. 9/7/82 9/25/82 9/28/82 12/8/84 10/13/82 11/12/82 3/12/83 1F 1F-1 1F-2 1F-3 1F-4 1F-5 1F-6 1F-7 Log Date 2/19/83 2/3/83 1/31/83 5/29/83 10/25/82 10/28/82 11/19/82 5/7/83 Attachment . Page 3 Drill Site tY Well No. Log Date 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 3/4/84 ~6/18/83 1Y-4 7/2/83 1Y-5 6/29/83 1Y-6 6/27/83 1Y-8 6/22/83 1Y-9 6/20/83 ~1Y_-~11~ 5/10/83 .~. 11/21/83 1Y-12 5/25/83 !Y-13 5/27/83 1Y-14 5/13/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site Well No. Log Date 2C 2C-4 2/19/85 2/28/85 2C-7 10/15/84 ~2C: 16.~ 12t t1'/85 Drill Site 2Z' Well No. Lo9 Date ~2Z~ 7/10/83 ~/22i85 2Z-2 : 6/24/83 7/19/83 2Z-3 8/5/83 2Z-4 7/12/83 2Z-6 7/27/83 2Z-7 7/28/83 2Z-8 8/3/83 VLF:pg-O052 R C ED · . ...:!['_ Alaska 0~1 & Gas Co~s Co,..~.,, Anchoreae Page 3 · Dri 11 Si te 1Y Well No. ~- 1Y-1 '1Y-2 -~ 1Y-3 ~1Y-4 Y-6 .'"1~-8 ?"1Y-9 ~1Y-11 1Y-12 ~ 1Y-13 ~1Y-14 '~1Y-I5 ~ 1Y-16 Log Date .~0/21/83/ 6/10/83-~ ",,,3/4/84 / ~6/18/83 % 7/2/83 ",~6/29/83 ~6/27/83 ~6/22/83 "6/20/83 *- '~5/10/83'~ ~11/21/83/ %5/25/83 ',~5/27/83 ~5/13/83~-~ '"5/18/83/ ' "~5/29/83 "~5/30/83' '"10/23/83 '~ Drill Site Well No. Lo9 Date 2Z "2Z-1 -,2Z-2 ~ '"'2Z-3 '~2Z-4 ~2Z-6 '-27-7 "~2Z-8 7/I0/83 6/24/83',x. 7/19/83/ 815183 7/12/83 7/27/83 7/28/83 8/3/8.3 Drill Site Well No. ,Log Date 2C -- 2c-4 '~2/~/88 ~ 2/28/85/ 'x~- 2C-7 %~10/15/84 .! VLF'pg'O029 RECEIVED FEB 2 1 1~8B Al~k~ 011 & ~a~ Con~ Anchorage ARCO, ~, !nc. Post Off!ce Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 06-24-85 TFJtNSMITTAL NO-5227 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1!!5B P.O. BOX 100360 AUCIIOIIAGE, AK 99510 T F~d4S M IT RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. KUPARUK ~,ZELL ?RESSURE REPORT ENVELOPE DATA 1B-3x. 04-21-85 PBU BOTH SD. CAMCO iC-4x. 04-25-25 SB!IP BOTH SD. CAMCO 1!!-3,, 03-06=85 PBU BOTII SD. CAMCO 1Q-l-. 05-26-'-35 SBHP 'A' SD. CAMCO !Q-2-~ 05-26-85 SBItP 'A' SD. CAMCO lQ-3~- 05-18-85 SEHP 'A' SD. CAMCO lQ-4-, 05-14-85 SB!ip BOTH SD. CAMCO 10.-5,. 05-06-85 SBIIP 'C' SD. CAMCO 1Q-6-~ 0'-23-$5 SCHP CAMCO !Q-7% 04-17-85 SGHP 'A' SD. CAMCO 1Q-S'-. 04-03-85 SBHP 'A' SD. CAMCO 2A-2x. 0=-~7-$5~ _ ~jBI{D.. '",. ' SD . OTIS 2A-4-~ 05-11-85 SBIIP 'A' SD. CAMCO 2C-5x 04-23-85 PBU 'A: SD. BAKER NORTH SLOPE 2C-9"' 04-06-$5 SP~IiP 'A' SD. OTIS 2C-!0x. 04-40-85 SBIIP BOTH SD. OTIS 2C-1i~. 03-29-85 SB!IP 'A' SD. OTiS 2C-12x 03-2" o . , , o-o 5 SBqP C SD. OTIS 2C-14x, 04-23-U5 PBU 'A' SD. OTIS a BAKER 2C- 1'- 0--i-29-85 2!i-i .. 05-23-85 2I{-1 '- 05-27-85 2H-2'- 05-23-35 2:I-3-. 05-23-85 2!!-4 x 05-23-85 2V-9-- 0..-: ~' "8-85 2V-!0-, 05-17-85 ?.V-il '- 05-12-85 2V-!2-- 05-i4-85 ~-~ 6-85 2X-2 -- 0o _ .]X-2'- 06-14-85 .iX-5 '- 06-12-$ 5 2Z-6' 04-08-85 ,..2Z'~-7:~ ,- 0 4-2 .~_,~o o 5 · ~,... ,-. T2,£ TED HEREWITII ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE CAMCO CAMCO OTIS CAMCO OTIS OTIS OTIS OTIS OTIS 04-01-85 ACi~4OWLE BCE OTIS OTIS OTIS OTIS BAKER NOTH SLOPE OTIS Di STIU/~UT-iON: -- CURIIiE:.i I,. J,'..~[i NS'FON E X ;,.'ON '!iEVRON*' NOL~ i [,* PIIILLIPS OIL* '.'4* ....~'c",', C a,.-~,," ~.~r~ ,.- j r~ ,~-~.:.,~r ,' , . :\l I -' Anc>.crzze ARCO Alaska, I~'~' Pos~ Office Box 360 - ' Anchorage, Alaska 99510 Telephone 907 277 5637 :' ~; .... ,':", ' 0 -i .... 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':" 't "' ''"''F:' ~.{ U/" '/:i ' -.::-.: ,.., ~;;/:i i'"-.! ;(.'-" t..I -... ~ .._. - (;., ...:' .~. ARCO Alas~(a. ARCO Alaska, inc. Post Office B~ I00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DA'¥F ....,,-~ :>"'-.. i ':'-85.~ 'f' R A N S H I '1' 'F A L N 0: ~;; i 8 '? ;:E'Ft. IRN 1'0: AF;tCO AL..A,."71<A, IN[i,, Al'TN: RECORI)S C I.. E:' I:;,: I< ATO-t t i FSB F:',O,, I;:OX t Ah~C..I"IOF,:A(;E, Al< 9S>~t 0 1' R,q N,.? N I l' T IZ I) H IZ R r-i; W I T H A R IL.'. T I-I E..] I::' 0 I_. I... 0 I,O I H ]:;.: IE C [; i I-':' ]' ih i',,I D I:;: E 'I' U I:;.:/',I 0 i,/I'-:' ,S: I [:, N E: D C 0 F:' Y 0 I-':' LI :;' R / 5,' E (~ U r...] N C E 0 F;' E: V E N l',.$' ( 0 i',l E: C 0 I:;'Y 0 i:"' E A C I-'1 ) 13 i--i- 1 S ,$' B H I.':' ( H I ,.9 C, A [; ]" I V :.:.!U--t S; ,.gBI.-II::' (HISC ,, . ACI']:V ....")V-''),,-..RIJIJ.. . 'C' ,S'AND. ONLY '..".V .... 4 TURNAF;,'[)Ui',II) (:-;-A,.S' IN 2 W.-. I 7.4. I) I I.T. 5' E I... B R Ii..." A I< D 0 W N 2. W-.-t 5 F:'BLJ 'C' ,S'ANi) ONL..Y ,:.:W .... i3 F'BU 'C' SAND ONI..Y :.:~X..-t 0 "A' SAND F:'BU 2X .... iO ENI) PBU/TCL 2. Z --. ? F:' B U 2Z-7 F'BU COi'iF:'LETIDN II'Y) ITY )' BHF:' ,J IE C T I 0 N 0 'F I ,S' 0 1' I O'r I S B A I< I'..':. R B ,, ,.J ,, I"1U rG I-'I.IE 5' 01'I .S' 0 T l $ C A M C 0 CAMCO B AK I:" R nl~cr~ t.l.~l.-~ In¢ ;,: m q.d.¢iH,"~.,. ~f Aflpntir'Pir-hfir-ld(']nmn~nv ARCO Alaska, inc~.... Post Offic[ x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 12/12/84 Transmittal No: 4909 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 .- itted here~%th are the following items. Please acknowledge receipt and return one signed copy of this transmittal. PBU. SURVEYS - Torque. Turn ~/2X-1 11/30- 12/02/84 .- :'/ 1F-1 6/08 - 6/09/84 / 2Z-7 ~2/02 - 12/04/84 #64009 #63140 #63138 Otis ~ 2Z-5 11/29/84 2C-8 11/26/84 z/' 2X-5 11/27/84' 1E-19 11/10/84 1E-21 11/10/84 ./1E-23 11/11/84 /IE-27 11/11/84 /cat Receipt Acknowledged: B. Currier BPAE Chevron D & M Date: DISTRIBUTION Drilling Geology Mobil NSK Ops. W. Pasher G. Phillips Phillips Oil J. Rathmell State of AK Sohio Union Well Files ARCO Alaska, Inc. Anc!~p~agc,. Alaska 99510 Te~,:.phone 907 277' 5637 Date: 9~/11/84 Transmittal No: 4719 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 ~~Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. PBU SURVEYS/PRESSURE ANALYSIS 2Z-7 w/8/17/84 Run 1 Lynes ,,, 2B-7 / 8/17/84 i<~~ 2B-9 8/17/84 '" 07/84 Lynes Lynes Camco Camco SEQUENCE OF EVENTS 8/18,19/84 P~U~ 8/17-19/84 '~' ~ 7/08/84 Falloff Test 7/12/84 " " lB-5''~ 12/15/84 Otis 12/16/84 Static BHP 1C-4-'" 12/17/84 . 1C-6 12/29/84 Otis Otis 12/17/84 " " 12/29/84 " " 1D-7 ~""~ 12/19/84 Otis 12/19/84 " " 1D-4'~'-' 12/18/84 Otis 12/18/84 " " /cat Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE Chevron DISTRIBUTION D&M Date: ](.. i 0 - 1~ Alaska 0il & Gas Cons. Commission Anchorage Pasher C.R. Smith Drilling Geology Mobil G. Phillips Phillips Oil J.J. Rathmell State of Alaska Sohio Union NSK Operations R &D Well Files KUPARUK DNK31NEERI 1~ -ItR/NN.%tITTAL # ~C)-~/ TO: William VanAlen ~4- D.W. Bose/Shelby J. ~,~atthews Transmitted herewith are the following' "~-'- 'LU~ PLEASE IxOTE:(,~ - B F - Fi LM, T -TAPE, PC- PhOT~PY cd_( ~ ALASKA, INC_.. "' " ATn, l. SHEI_I3Y J. I~,~TTt-I~VS - A ,-fl?..!.! 11 P. O. BOX 100360 .'..,.. A~,AGE, AK. 99510 / KL1P~UK ~ I NEERI Ix.lC; TRANSMITTAL TO: Wi i i am VanA! en ~4: D.W. Bose/Shelby J. Matthews Transmitted herewith are the followincj- PLEASE ~: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, -F~~~ ~,,/I~E RET1JRN RECEi PT TO: Alaska Oil & Gas Oons, DATE: Anchor age ARGO ALASKA, Ik~. ATTN: SHEU3Y J. MATRtB~ - ATO/1115-B P. O. BOX 100360 ~~AGE, AK. 9951O Ig. JP/~RUK EKD 1 NEERi TRANSMITTAL TO: William VanAlen ~,4: D.W. Bose/Shelby J. Matthec/s '7- DATE: ~"~- ~"'? \~IELL I ~,¥~t,/£- Transmitted herewith are the followincj- PLEASE kD-I-E- BL .- BLUELI NE, S - SEPIA, F - F I LM, <T , TAPE', PC - ~PY. · ¢"-'/ · . /~,~ ACKN~¥1R'X3ED: PLEASE RETURN REC_.EI PT TO: ~ ALASKA, INC. . . Al-l-N: SHELBY J. ~NkTTt-I~ - ATO/1115-B P. O. BOX 100360 ,A,NC]-E:RAGE, AK. 9951O KIJP/~R1JK ENG I NEERII',,G TP, ANS 41"FrAL TO- William VanAlen ~4: D.W. Bose/Shelby J. Matthews Transmitted herewith are the foliowincj' PLEASE NOTE:~~F- FILM, T- TAPE, PC- PHOTO(OPY A~: ~E~Y ! P. O. ~X 100360 ~~E, ~. 99510 Alaska 0il & 6as 0ohs. 6ommissioB Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 28, 1983 . Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Well Completion Reports Dear Mr. Chatterton- Enclosed are completion reports and gyroscopic surveys for the fol lowing well s' 1Y-4 2Z-7 2Z-8 If you have any questions, please call JoAnn Gruber at 263-4944. Sincerely, P. A. VanDusen District Drilling Engineer PAV/GRU3L56-sm Enclosures RECEIVED JUL - ] ]983 0il & Gas Gens. Commis~r~ Anchorage STATE OF ALASKA ALASKf:: _ ;L AND GAS CONSERVATION C,, ,MISSION WELL COMPLETION OR RECOMPLETION'REPORT AND LOG 1. Status of Well Classification of Service Well oILX~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-64 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20946 4. Location of well at surface 9. Unit or Lease Name 1990' FSL, 286' FEL, Sec. 11, T11N, R9E, UM .L~ ~ Kuparuk River Unit At Top Producing Interval ILOCATjON~] -10. Well Number 1438' FNL, 1324' FEL, Sec. 13, T11N, R9E, UN VE[~IFIED . 2Z-7 At Total Depth Svrt:. 1 1. Field and Pool 1626' FNL, 1147' FEL, Sec. 13, TllN, R9E, UM JB.H.__~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 106' RKBIADL 25653 ALK 2579 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. [15. Water Depth, if offshore 116. No. of Completions 05/10/83 05/19/83 05/23/83I N/A feet MS LJ 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth whereSSSV set 21. Thickness of Permafrost 8853'MD,6302'TVD 8649'MD,6126'TVD YESES] NO []I 2005 feet MD 1400' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/SP/GR/FDC/CNL/Cal~ D IL/FOC/CNL, BHCS, CBL/GR/CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i6" 6Z.b# H-40 5urf 73' 24" 340 sx AS II 10-3/4" 45.5# K-55 Surf 2633' 13-1/2" 1200 sx AS Ill & 300 SX A,~ I 7" 26.0# K-55 Surf 8811' 8-3/4" 550 sx Class G & 250 sx /,S I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8533 ' -8568 ' 3-1/2" 8276 ' 8251 ' 8513'-8521' 12 spf, 120° phase 8351 '-8411 ' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KI'NDOF MATERIAL USED ,,. N/A 27. N/A PRODUCTION TEST Date First ProdUction J Method of Operation (Flowing, gas'lift, etc.) I Date of Test Hours Tested .PRODUCTION FOR OILoBBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~' Flow Tubing Casing Pressure CALCULATED~I~ OIL:BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None I ECEIVED J u L '- Alaska Oil & Gas Cons. Commission Anchorage 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 recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 8:352' 5873' N/A Base Upper Sand 8412' 5923' Top Lower Sand 8502' 6000' Base Lower Sand 8630' 6110' 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Area Drilling Engr. 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". , · · : :.: ~ · :::. :,: :::::::::::::::::::::: ::~b:L :: :.&~r:r:x:: ,::: ::~:::h::::..: :,::::~Y. ::~:r?, ':~V:::::::r.~:'~"x.r~'.V,'~::qlu $ r.:'.x+x .::.: :h~r~: :: ::::::::::::::::::::::: :~?;'.:::'.::::::::: ::: :::: :: :u~ ?:~ ~ ~:?.~:: ~u~?:~::~f.~?.? ~::::?~.~:':~:?~::;~:::::.~.~:~f~::~??::.~;?~::~?:~?;~::::::~ ~?~??::::::::::::::::::::::::::::::::::::::?~::~:~??::~::::::~::::~::?.~:~::~:~:~:~::~:~:::::~:~::~::~::~::~::~:~::~.~:~:~:~::~::~::~::~::~::~::~:~::~::~::~::~::~:~:~i~::~:~:~:~:~:~:~:~::~::~::~:~:~::~::~::~::~::~:~::~::~:~::~::~::~::~::~::~:~::~::~::~::~::~::~::~::~::~:~:~::~:~:~::~::::~::~::~::~::~::~.:~:~:~::~:~:~:~:~:~:~:~::::::::::~:~:~::~::~::~::~:~::~::~::~:~:~;~ ARCO ALASKA ]:IqCOF(F'OF~A'I'ED ~ ~~ ~ ..... ~ I]A]"E OF' SURVEY "l'lq:i..llE SUB--SEA C:CII..IRSE CCiI_IRSE DOG-L. EG I"OTAL I"]ii.::']A::-3 LIRI?:[I VI=];:;;T I CAL.. VERT I CAL I I".ICL.. 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'..:.)3 5864. 18 S 1849.75 E 'I"OF' LOWER '.::;AND i..'~::~:7f:!; /_-,,:':',?'15. 62 624i..'~. 62 6044. :5,'4 S 1893.50 E TOTAL DEF'TH DRILLER © ® 0 2 Z-:I.~: F3 ( :-':ECd 1 T 1 1 N I:.'~()':..'~1--.[ ) :.5..: T R f-'-~ T I G R ~ P H I F: S U ?1M A R ¥ ~ ) FROM ;--.' T--C.:i31flF'E1TE~ F:R'CiC/RAifl - 'SF'ERR'~" '"'..E;I_IN 'THREE D I P1ENS I FINAL RAD I US OF C:LIRVATLIF(E. I]f~"l"~q CAI_CLI[_~TION ~-~ND INTERF'OLATION BY R~DILIS; OF C:LIRVi-~TLIRE MAY (.")6, 1783 ,_lOB NUMBER AK'-BO-::-:OCx3'.:.> KELLY BI_I::;HING ELEV. = lOd,. O0 FT. ' I -1000.00 TBUE NORTH Arco Alaska, Inc. Our Boss Gyroscopic Survey Job No. AK-BO-30039 Well: 2Z-8 (SEC 11 TllN R09E) Kuparuk Field North Slope, Alaska Survey Date: May 8, 1983 Operator: Sellers Surface Location 1937 FSL 258 FEL 1000. O0 Scale: 1" = 1000' 0.00 .. -2000~ -- ooo. \\~ 6334.46' @ \~~17° 23' E -4000 O0 _ -5000'00~\~ _6000.00~9375 --7000. O0 HORIZONTRL JECTION C 0.00 Arco Alaska, Inco Our Boss Gyroscopic Survey Job No. AK-BO-30039 Well: 2Z-8 (SEC 11 TllN R09E) Kuparuk Field North Slope, Alaska Survey Date: May 8, 1983 Operator: Sellers Scale: 1" = 1500' 500.00 3000. O0 4500. O0 6000. O0 6334.46' @ S 17° 23' E 9°75.~ G 7500. O0 I 1500.00 3000.00 4500.00 6000.00 7500.00 VERTICAL PRO JEC.T I ON ARCO .ALASKA, INC~. F'AD 2Z, WELL NO: ? GMS ~IOB NO: AO583GO144 ° ~ ' ALASKA KUPARUK FIELD, NORTH oLDFE, GM':J~..O=87..20.~.. ND, ~;URVE~OR.: ..... ~.E~ERKORNIM ILLER.~..~DA.TE.RUN GYRO NO: 306, CAMERA NO: 148,5, 0-~0 DEG A/U NO: 113~5 FORESIE~HT: N 14 43.5 E SUR~EY TAKEN-FROM ..ROTARY .~ VERTICAL. SEE:TION E:ALC:ULA ~u.~,.~I N ,4 PE"f ROLA N[:i C'(')MI~INY ................................................................................................. REE:.ORD~-. OF --.SURVEY RADIUS OF. CURVATURE METHOD : ARCCI ALASKA, INC:. C:OMPUTATION PAGE NO. 1 PAD 2Z, WELL-NO: 7 "GMS ,JOB.-,NO, AOS83G0144 I::r't'ME ............................... DATE- ~,:' : 54: KUF'ARUK FIELD, NORTH SLOPE, ALASKA 11 57 14-dIJN-83 :...TRUE ' : MEA.SLIREEI DRIFT DRIFT COLIRCdE VERTICAL VERTICAL SLIBSEA R E C: T A N O U L A R C L 0 .'E_-; U R E DOGLEG ~DEF'TH ANOLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E $ DI'.:;TANC:E DIRECTION :_:;EVERITY ..FEET D M D FEET- FEET FEET FEE..¥.......................................... FEET ........................................ FEET- ..................... £I ........ M .............. DG/iOOF]' 0. 0 0 0 O. 0.00 0.00 -106.00 0.00 0.00 0.00 0 0 0.00 100, ...... 0 0 .............. 0 ............................. 100, .................. t 00.~ 00 ......................... 0,'00 .................. 6'~ 00 ........................ 0~ '00 ............................ 0 ~. 00 ...................................... 400. 0 0 0 300. 400.00, 0.00 294.00 0.00 ' 0;00 0.00 0 0 0.00 ~._00'. 0 1~,= S 84. W 100. 500.00 -0.16 394.00 0.02 S 0.22 W 0.22 S 84 0 W 0.~ , lc:' ,"~ e'~,- ., .-,.'-. ~ ~') 6AO I 45 S 66 .. E 100. ,...,9~,.~ 0,..47 ........... 493.,.98 ........ ~ ................... z'-~'"~'.~--.o ;., 42...--.W 700. 6 15 S 64 E 100, 699.71 7.26 593.71 ' 4.24 S 5.90 E ' 7.27 S 54 18 E 4. ..~ 800. 10.. 30 S 66 E ................ t 00., ......... 798,~ 62' ................. 21,45 ........... &92,. 62-..: ..................... 10... 40,.,-.S ................ 1.9 .. 10-,E . . ~.9¢..82 44.15 789.82 20.07 S 40 33 E 45.05 E: 63 33 E 6.00 '~>AO. 16 30 S 65 E 100. c. = 1000. ~.~o 0 ' S 62 E 100. 990.. 19 76.45 884.19 34.78 S 69.82 E 78.00 S 63 ..,~1 E 5.59 1200. 31 45 S 61E 1300. 33 30 .... S.60, E 1 1400. 36 15 $ 60 E 1 1500. 37 30 S 60 E 1 1~00. 36 15 S,58 E I 1700 '-'= 0 S 5c~ E , .",.j. . 1168.4 77.45 $ 149.18 E 1252. .10 E 1334. 72 .61 E 1414.71 .~8 E 3 01E At.~f:TRC)LANEC'(A,:I::~,:NY 100· 1575.99 452.10 1469.99 223.93 S 398.68 E 168.09 S 62 :34 E 5.02 221,-~,-97 ....... ~.,,62 4 E 1 83 27-~.12, S 61 38 E 2.75 339.10 S ~,1 21 E 1.25 39. ~--~ 6 ........... ,_-,./~ 1 O.E t.,7:3 457.26 :,~' 60 41E 1.38 1800.. 36 45 S.58 E ............. 100, ..... 16~57.02 ..... -~10.,33 ...... 1551..02 ........... 254-.~4.-.-$ ......... 448.64,..-,E ......... .-5-1-.~..82 ...... 1900. 4C) C) S~.~'., E 10C). 1735.40 572.07 1629.40 287.44 E: 501 .28 E 577·84 S 60 10 E ~,~,. ~s, 5_ c,._7 74 E 644:38 :3 59 57 E 3.50 3~. 72 S =~ . . 2000. 43 30 S 58 E 100. 1810. O0 638.30 1704. O0 '~"? 2100. · .... 46-.-45 .....S-58-..E t00~ 2200. 48 45 S 58 E 100. 1947.78 782.39 1841.78 399.49 S 680.60 E 789.18 S 59 35 E 2.00 2300. 50 45.-$--57E ............... t00.. ........ 201.2..-3~ ........ 858..,.~7 ....... 1906...~9 ........ 440...4~---$ ....... 744.-~7.-E. 865~46 ..... $..:,59---24-E ....... 2....1.4 2400. 51 45 S 57 E 100. 2074.98 936.07 1968.98 482.97 S 810.37 E 943.38 S 59 12 E 1.00 2500. 52 30 S 56 E 100· 2136.37 1014.76 2030.37 526.54 S 87~.20 E 1022·23 S 59 0 E 1.09 2600. ~4~ ~---56-E .............. 100. ..... 21~6.-38 ...... 1094,57 ...... 2090,-38 ..... 57.1-,.27--S ...... --942.5t---.~----~102~-1-2-- S-.58---47--E ............ 1-..25 2700. 54 3C) S 56 E 100· 2254.'~8 1175.41 2148.98 616.58 S 1009.69 E 1183.06 S 58 ~'-=, ~ E 0.75 .......... 2800.. .... ~,5.-.-t~5 ~S-. 5.5 -. E ........... 1.00. ...... 2-31-2-.-52 .... 1-25:Z,05 , 220~-.52---~'2~-90--S !07-7~-O-~--E---1-2~~-58-23-E ..... -1..~1~1~_. · ""'l .~ · · i i · -.-.~00. 57 0 S 54 E lO0 2368 25 1340 00 2262 25 711 11 S 1144.68 E 1347.58 S 58 9 E 1..94 :3000. 57 0 .S 53 E 100. 2422.72 1423.84 2316.72 761.00 S 1212.10 E 1431.19 S 57 5:3 E 0.84 ....... 3100.. .....~ 7.-45 .....S- ~.L~ E ................. 100.- .....2476.~.3 1508.05 ..... 2370..~3 -8.1--1 ..~:~--E:---1279.-3&-E 1515-~12---~--3~-E ........... 0..~5 · ARCO ALASKA, INC. COMPUTATION pAGE NO. ' 2 F'AD, 2Z, WELL.,,.NO: .6 M,_-, dUB--NO. AO583G()1,44 KUPARUK FIELD, NORTH SLOF'E, ALASKA 11: 54: 57 14-dUN-83 ...................................................................................................................................................................... TRUE ................................................................................................................................................................................................................ : ' NEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITy .FEET D M D FEET ............... i FEET F.EET EEE~ ............ : EEE~ EEE~_..................... D ......... ~ ........ DGZIOOFT 3200. 57 45 S 52 E 100. 2529.99 1592.61 2423.99 863.17 S 1346.46 E 1599.38 S 57 20 E 0.85 3300. ......... 5~ ............. 0 ........... S.,.,51,,...E .............................. 100 ................ 2583..90 3400. 58 45 S 51 E 100. 2637.08 1761.50 2531.08 968.89 S 1478.18 E 1767.42 S 56,4~ E 1.75 3500. 58 30 S 50 E 100. 2689.14 1846.85 2583.14 1023.20 S. 1544.06 E 1852.31 S 56 28 E 0.89 3600. ............ 58 .......... 0 .......... S....Ag,.-E 1.00 ................. 3700. ~,7 45 S 49 E 100. 2794.94 2016.36 2688.94 1133.98 S 1672.63 E 2020.80 S 55 3:--:00 = = '-' ' . ..... ;~7-. 4.J ........... ~-..-4,3- E 1.00.. .............. 2848..30..: ........ 2.1.00 ....77 ................ 27 ~ 2..30 ...... 1..1,90., 02-8 ...... ~-735.9,~-,E ..... 2,~O,A~7,Q--S.-..55-34.,-. E ............0,. 85 3900 57 45 S 48 E 100 2901 66 -,'~'5 13 2795 66 1246.61 E; . . · . , . ~c .... 1798.8~ E 2188.56 S 55 17 E 0 00 . ~ , "s= 0 E 0 00 4000 57 45 , S 48 E 100. 2955.02 2269.49 2849.02 130:3.20 S 1861.67 E 2272 48 o ~.:, . 4100. 58,..,1,~ ......... S~,48 ,. E ...................... 100. ........ 3008..01 ........... 2354.-08 ..... 2902.01 ...... 1359.. 95,-,.,~ ........ 192.4..,70--E ..... 235&....bT 0.50._, 4200. 57 4~ S 48 E 10 4300. ....... 57.45 ............... S,,.48.-E 1 4400. 57 30 $ 49 E 4.500. 57 0 S 49 E 1 4600. 56.-15 S~49 E 10 3061. Oi'~ · ~ ' , 1416.69 o 1 .. ,:..7. E 3114. 2440.91 S 54 31 E 0.50 252A~-S~5 .......S-5A....18.,E .......... 0..00 2608.99 S 54 7 E 0.88 2692.77 S 53 57 E 0.50 2775..~8 .......... ........... 0..75 A ~:'rROLANE CO^4I~NY . 4700. 56 0 S 49 E 100 3332 76 2857 60 ~2~6.76 1~9~..68 S 2302.98 E 2858.72 S 53 4C~ E 0.25 4800, .55.45 S.49. E 100., 3388,86 .........2940,26 ........... 3282,86 ........ 1747.,~...-.S .......23~5,.46...E .......... 2~4.1-,.23 ............. S-..53.-..32. E .......... 0,.25 ..... 4900, 55 30 S 50 E 100, 3445,32 3022,72 3339,32 1801,59 S 2428,22 E 3023,57 S 53 26 E 0,86 5000,. 54 1~ S 48 E 100, 3502,85 3104,38 3396,85 1855,24 S 2489,94 E 3105,11 :S 53 19 E 2,06 5100,-- 53.30 ...... $--48--.E ..................... t-00,- .......... 3~bt-.,-8t ......... 3184.,.~5 ..... 34~.,-.81 .... 1.~0~,..2~.--$ ~54~.,97--E .... 31.85,.~5.--~S:53-1-1---£ .......... 0.,-~ 5200, 52 15 S 48 E 100, 3622,16 3264,48 3516,16 1962,64 S' 260~,22 E 3264,96 S 53 3 E 1.25 5300, 51 15 $.48 E ~ ....... 1.00,- ....3684,07 ..... 3342,81 ....... 3575,..07 ..... 2015,19-S .... ~6~7,58.E ..... 3343-,-1~ ...... S-.52-56.E ..... 1.,.00 5400, 50 15 S 49 E 100, 3747,34 3420,10 3641,34 2066,50 S 2725,58 E 3420,41 S 52 50 E 1,26 5500, 49 15 $ 49 E 100, 3811,95 3496,32 3705,95 2116,57 S 2783,18 E 3496,56 $ 52 45 E 1,00 5600, 49-15 -$ 49 E ........ 100, 3877,23 .... 3571,96 ...... 377-1,--23 ...... 2166,27--$ .... 2840,35-E .... 3572,.1~.---S--52---40-.E ..... 0,00 5700. 48 45 S 49 E 100. 3942.83 3647.33 3836.83 2215.79 S 2897.31 E 3647.48 S 52 36 E 0.50 cr,--,~).-. .... · . · _ · _.o.,.,. 47:30 $ 49 E 100 -4009.58 372-1. 68 ..... 3903.58---22L-",4.6-~.-$ ..... 295:3 50-E .... 3721.-.-. 7-~ ..... -S---5~.-.31-E .........-1..25 5900. 47 30 S 49 E 100. 4077.14 3795.30 3971.14 2313.00 S 3009.15 E 3795.39 S 52 27 E 0.00 6000. 46 15 S 49 E 100. 4145.50 3868.18 4039.50 2360.8~ S 3064.23 E 3868.24 S 52 23 E 1.25 6100., .4S .1D ~; DO E ........ 100..--421~,28 .... 393~.74 .... 4109.28 ..... 2407.41--8 ..... ~1-tS..70-E~89~-78~Ep-D2--20 E .... 1..2:3. ARCO ALASKA, INC COMPUTATION PAGE NO. 3 PAD,2Z, WELL"NO: 7"GMS dOB-~NO~ AD583G0144 ~ TIME ............................... DATE KUPARUK FIELD, NORTH SLOPE, ALASKA 11:54:57 14-dUN-83 .............................................................................................................................................. TRUE ..................................................................................................................................................................................................................................................................... . MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N.G U L A R C L.,O S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E' S DISTANCE DIRECTION SEVERITY FEET D M D FEET FEET FEET FEET FEET FEET D ............ M ............. DG/,i-OOFT 6200. 45 0 S 50 E 100. 4285.83 4010.55 417.9.83 2452.'96 8 3172.98 E 4010.5'9 S 52 18 E 0.25 6300, 44 50" E 100, 4356',"85 .......... 4080, '9 t 4250'' 85 .......... 2498~' '"'S ........ 3'2'~6, '9 t-'-"E ........ 408'(")"~"98 ........... S'"-'52 D"'E .......... 0',,"50 6400'. 44 30 8 50 E 100. 4428.18 4150..95 4322.18 2543.26 8 3280.60 E 4150..97 S 52 13 E 0.00 6500. 44 15 S 50 E 100. 447.9.66 4220.85 437~3.66 2588.22 S 3334';18 E 4220.85 S 52 11 E 0.25 6600, 44 '4~ '50 E 1'00'' 4570~'98 ......... 42.90.""8.9 .......... 4464'.'98 ....... "~6:3:3',"2'7"'.S ........... ~3387'~"87-E ........... 42'90-,"8~ .......... 8'-~'2 ........... E 0,'"50 6700. 44 45 S 49 E 100. ' 4642.00 4361.22 4536.00 2678..99 S 3441.40 E 4361.~ ..~ ~,~ 6 El 0 6900. 44 45 S 49, E 100. 4783.73 4502.13 4677.73 2771.57 S 3547.90 E 4502.13 S 52 0 E O. 25 7000. 44 30 S 4.9 E 100, 4854. ~0 4572.27 4748. ~0 2817. ~5 S 3600,. ~ 1 E 4572.28 S 51 57 E O. 2P; 7100, .... 44 ....... 0 ........... S ""4~""'E' 100'~ .............. 4~26"~"53 ....... 4641' ~'-95 ............. 4820~".53---'~86~.-43'-'S ........... 8653, ~8'-E ........... 464.t..,--~7- ....... S,.,,.,5. t ...~ ,.E 0,,,~0 10, 1 14~.98.4i 5070. 5143. 5216.~7 7200. 44 0 $ 48 E 7300- .... 43. 15 $..48.E 7400. 43, 0 S 46 E 7500. 43 30 S 46 E 7600. 44 0 8.46,,E 1 100 290.9.4& S 3705,60 E 4711.31 S 51 52 E 0.6~ 21 .88 E 4780~-..1~ ...... $,...-~1..48E ........... 0.7~, .87 E 4848.27 S 51 44 E 1~3~ .16 E 4.916.45 S 51 40 E 0.50 .90 E 498~,~--2~ ..... 0-.~0 7700. 43 15 S 46 E 100. 5361.30 5053.70 '5255.30 3145.81S 3.955.53 E 5053.94 S 51 30 E 0.75 7800..42 0 S. 46 E ......... 100. ..... 5434.88 ~121.04 ....... ~328.88 ....... 3t~2-.8~,---S ....... 4004..24-E ........... ~.~2-1-,..3~ ...... ~.-.51..-..-2~-.E .......... 1,.25 7900. 40 15 S 45 E 100. 5510.20 5186.37 5404.20 3238..94 S 4051.15 E 5186.77 $ 51 21E 1.87 8000. 38 45 S 45 E 100. 5587.'36 524.9.50 5481.36 3283.92 $ 4096.13 E 5249.~.9 S 51 17 E 1.50 ..... 8100.- ........ 86.,.-48 .......... $--46--E t-00-.~ .... ~66L-~.-43 .......... ~3.1~,.~1---,5~0.-4~ ,~.~6~8~-$-.~4i-~-7.9--~ ..... ~S~t.~0 -S-~,~.I~I~.~-E ..........~-.-0~ 8200. 35 15 S 45 E 100. 5747.33 5368.70 5641.33 3368.02 S 4181.72 E 5369.3.9 S 51 9 E 1.~ t 8300.. 33.45 .... $-45.E .............. 100. ........ 5829.-74 ....... 5424..-91 5723.74 ........ 3408,07-$ .... 4221.-..77-.E 5425~71---~.--51 .... 5-.E ......... 1..50 8400. 33 0 S 44 E 100. 5913.24 547.9.44 5807.24 3447.31S 4260.32 E 5480.36 S'51 1E 0.93 8500. 31 15 S 43 E 100. 5997.93 5532.03 58.91.93 3485.88 S 4296.93 E 5533.08 S 50 57 E 1.83 8600.. .... 30..-15 S-43.E ........... 100.---6083.87 ..... 5582,52 .... 5~77.87-.--3523.28-$ ...... 4331-.8~ ....... ~58:~-72--~$-50---53--.E ........ 1.-,00 I PROJECTED TO PBTD - 8649 MD 8649. 30 15 S 43 E 4~. 6126.20 5606.89 6020.20 3541.33 S 4348.63 E 5608.17 S 50 51E 0.00 .... PROJECTED-.TO---TD.~ 8853-MD ....................................................... ,. ARCO ALASKA, INC. COMPUTATION pAGE NO. 4 PAD ,.2Z, ......WELL .....NO: ....... 7....GMS ........... JOB.-.NO: ...... AO583GO 1.44 Z TI-ME- ..............DA.T.E ,~ ......... :' t .... IFARUK FIELD, NORTH SLOPE ALASKA 11: 54:57 14-JUN-83 ......................................................... ~ ............................................... ~ ............... ~ ..................... TRUE .............................................................................................................................................................................................................................................................................................................. ' MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A.R C L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY FEET D ....... M D ~EE~ ..................... ~EET ~EET ~EE~ ......................................................... ~EE~ ~EE~ .......................... D ........ M .............. DG~,IOO~T ,~d._,.=.. :'-:0 15 S 43 E 204 ' 6302.42 5708 38 61~6 42 361/., 4'~ 8 4418.72 E 5710.00 S '50 42 E 0,00 FINAL CLOSURE - DIRECTION: S 50 DEGS 42 MINS 5 ,SECS E D I STANCE: ............................ 57.10,.,..00 .....F.,EET. -) -AReZ~O. ALASKA ~ I NE~. PAD 2Z~ WELL NO: 7 GMS ~IOB NO: AO583G0144 KUPARUK FIELD~ NORTH SLOPE, ALASKA GMS 0-8720 'MD,'-'E;LIRVEYOR: PEFFERKORN/MILLER- DATE- RUN: 21-MAY-83 . ~:~o 0-'~0 DEG A/U NO: 1135 GYRO NO. 306, CAMERA NO: 1~.~ FORESIGHT: N 14 43.5 E SURVEY TAKEN-FROM ROTARY ................................................. , A F-'L-z"ffz~Oi.,ANE C( i)MPANY ARC:O ALASKA, INC. COMPUTATION PAD 2Z, WELL-- NO: .... 7- OMS ......... dOB-.-NO: A058300144 -T-IMF KIJF'ARLIK FIELD, NORTH SLOPE, ALASKA 11: 56: 04 14-.JUN-83 PAGE NO. 1 · , MARKER .................................. TRUE ......................... SUBSEA C:ODE MEASURED VERTICAL MD-TVD VERTICAL R E C T A N G LI L A R C L 0 S LI R E VERTICAL NAME DEPTH DEPTH BIFF DEPTH C 0 0 R D I N A T E S DISTANCE DIRECTION THICKNESS ........ FEET .............. FEET ....... FEET ........ FEET ..... FEEI FEET ,B---N .............................. TOP UPPER SANDS 8352.00 5873.16 2478.8 5767.16 3428.48 S 4241.82 E 5454.12 S 51 3 E BASE U~FER.-~.ANDc ....... ~ .... 841.2.00--5923.-41-2488.~ ....... 581.7...4i ....... 3451..~4S-.-42~4 72-.E ...... 548~.-~8 ..... ~--51 ...... 1-...E ................. TOP LOWER SANDS 8502.00 5999.65 2502.4 5893.65 3486.63 S 4297.62 E ~..~.09 S 50 57 E BASE LOWER c-~,ANBo~- 8630.00 6109.78 2520.2 6003.78 3534.33 S 4342.10 E 5598.6~ S 50 51E A F)[:'TR(}L,~NE' C:(:)A4F)ANY Suggested form to be inserted in each "Active"' well folder to check for timely compliance with our regulations. Operato~, ~W-e~Jm~ ~n~'d Number Reports and Materials to be received by: : Required Date Received Remarks Completion Report Yes 7-- Well History Yes/ ~ · .Core Chips Core Description ,.//,.4,4' e_ ---------- ~'~'~ ~ ' Registered Survey Plat y~3 ~--/.. · Inclination Survey ,4?,? Drill Stem Test Reports ' Production Test Reports ye ~ "::"'Digitized Data yC¢_ 7 '- ~ '~---~ 1. Type of Request: · .,.~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMi'&SiON REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown__ Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska, !nc. 3. Address P. 4. O. Box 100360, Anchorage, AK 99510 Location of well at surface 1990' FSL, 286' FEL, Sec. 11, T11N At top of productive interval 1438' FNL, 1324' FEL, Sec. 13, T11N, At effective depth 1551' FNL, 1217' FEL, Sec. 13, T11N, At total depth 1626' FNL, 1147' FEL, Sec. 13, T11N, 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service , R9E, UM R9E, UM R9E, UM R9E, UM 12. Present well condition summary Total Depth: measured 8 8 5 3' true vertical 6302' 6. Datum elevation (DF or KB) RKB 106' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2Z-07 ~ ~/,,, 9. Permit number/approval number 83-64 / 1,,"¢~/.. - /. 10. APl number s0-029-20946 11. Field/Pool Kuparuk River Oil Pool feet feet Plugs (measured) Effective depth: measured 8 6 4 9' true vertical 6 1 2 6' feet feet Junk (measured) 5" csg gun, Top 8649' (28 ' Long) Casing Length Structural Conductor 7 3' Surface 2 6 3 3' Intermediat Production 8 8 1 1 Liner Perforation depth: measured true vertical Size Cemented Measured depth 1 6" 340 Sx A.S. II 10-3/4" 1200 SxA.S. III & 300 Sx Class "ASI" 7" 550 Sx Class "G" 250 Sx A.S. I 73' 2633' 8811' 8533'-8568', 8513'-8521', 8351'-8411' MD 6026'-6056', 6009'-6016', 5872'-5922' TVD Tubing (size, grade, and measured depth) 3 1/2", J-55 BTC tbg @ 8276' MD Packers and SSSV (type and measured depth) Packer: OTIS RH pkr@ 8251', CAMCO TRDP-1A SSSV@ 2005' MD 13. Stimulation or cement squeeze summary True vertical depth 73' 2215' 6257' R ECEiVED o 7 Intervals treated (measured) 8 3 5 1 ' - 8 4 1 1 ' Aiaska Oil & Gas Cons. Treatment description including volumes used and final pressure Anchorage 5 bbls xylene, 5 bbls 12 % hcl, 50 bbl nitrified 12 % hcl, final pressure 3500 psi 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 309 250 25 1400 1385 1 100 3 1 1350 16. Status of well classification as: Oil X Gas Suspended Service Tubing Pressure 196 200 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~2~,./~../~ .~'l.4,'/'~-~"~Ti'tle Sr. Operations Engineering Form 16-404 Ra~0¢/15/8~ SUBMIT (N DUPLIC,~TE ARCO Alaska, In,.~. ~ Subsidiary of Atlantic Richfield Company WELL IPBDT CONTRACTOR REMARKS IFIELD- DISTRICT- STATE OPi::I~I'ATION'AT REPORT TIME WELL SERVICE REPORT /J C/D S~'/~', , Z,4 C2q 1o P'~ .3~0~ '~ o73c, /o ,5"~ z.] oo - [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK 2Z-7 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 0400 hrs, 05/10-/83. Drld 13-1/2" hole to 2640'. Ran DIL/SFL/SP/GR/FDC/CNL/Cal f/2648'-112' Ran 64 jts 10-3/4" 45.5# K-55 BTC csg w/shoe @ 2633'. Cmtd 10-3/4" csg w/1200 sx Arctic Set III, 300 sx AS I. Bumped plug w/2000 psi - ok. ND 20" Hydril & diverter. Well flowing, pumped 90 sx AS I. Stopped backflow. NU csg head & drilling spool. NU BOPE & tstd to 3000 psi - ok (witnessed by AOGCC rep). Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW. Drld 8-3/4" hole to 8800'. Reamed tight hole f/8600' to 8800'. Ran DIL/FDC/CNL f/8800'-2633'. Ran BHCS f/8800' to 2633'. Drld 8-3/4" hole to 8853' TD as of 05/19/83. Circ. & cond hole. Ran 224 jts 7" 26#/ft K-55 BTC csg w/shoe @ 8811'. Cmtd 7" csg w/550 sx Class "G" cmt. Bumped plug & tstd csg to 3000 psi - ok. Cut 7" csg. Set 7" packoff & tbg hea~l & tstd 7" packoff to 3000 psi. NU BOPE. Arctic packed 10-3/4" x 7" annulus. Ran CBL f/8726'-2000'. Ran CBL/GR/CCL 2928' to surf. Ran Gyro f/surf to 8650'. Perforated well. f/8548'-8568 f/8533'-8548 f/8513'-8521 f/8391'-8411 f/8371'-8391 f/8351'-8371 w/5" 12 spf 120° phase - all shots fired Ran 3-1/2" completion assy w/tail @ 8276' & pkr @ 8251'. ND BOPE. NU tree & tstd to 3000 psi - ok. Displaced well to diesel. Dropped ball & set pkr. Closed SSSV @ 2005'. Secured well & released rig @ 1400 hrs, 05/23/83. HILL/DH25 06/14/83 RECEIVED J U L - i 1983 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 15, 1983 Mr. C. V. Chatterton' Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton- Enclosed are the Monthly State Reports for the following wells' * West Sak SWPT //1 * Ciri Wolf Lake 1A-4 1Y-4 1Y-5 1Y-6 1Y-7 1Y-8 1E-14 2Z-1 2Z-2 2Z-3 2Z-6 2Z-7 2Z-8 * Due to the confidential material contained in these reports, please handle and file in a confidential manner. Thank you. Sincerely, P. A. VanDusen District Drill ing Engineer PAV/SH7'sm Attachments STATE OF ALASKA ALASKA ~.~_ AND GAS CONSERVATION CC_~tVllSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPER ,TION$ 1. Drilling wellx[~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-64 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20946 4. Location of Well atsurface 1990' FSL, 286' FEL, Sec. 11, T11N, RgE, UN 5. Elevation in feet (indicate KB, DF, etc.) PAD 72' ~ 106' RKB 6. Lease Designation and Serial No. ADL 25653 ALK 2579 (bottom hole) 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2Z-7 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. May , 19 83 12. Depth at Spudded tstd 1 0 TD. Ra Perfora rel ease SEE DR I end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks well ~ 0400 hfs, 05/10/83. Drld 13-1/2" hole to 2640'. -3/ n, ted d r LLI Ran logs. Ran, cmtd &- 4" csg. Drld 8-3/4" hole to 8800'. Ran logs. Contd drlg 8-3/4" hole to 8853' cmtd & tstd 7" csg. Arctic packed 10-3/4" x 7" annulus. Ran logs. Ran Gyro. well. Ran 3-1/2" completion assy. Displ well to diesel. Secured well & ig @ 1400 hrs, 05/23/83. NG HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 10-3/4" 45.5#/ft K-55 BTC csg w/shoe @ 2633'. Cmtd w/1200 sx AS III, 300 sx AS 7" 26#/ft K-55 BTC csg w/shoe ~ 8811'. Cmtd w/550 sx Class "G" cmt. 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/SP/GR/FDC/CNL/Cal f/2648'-112' DIL/FDC/CNL f/8800' to 2633' BHCS f/8800' to 2633' CBL f/8726'-2000' CBL/GR/CCL f/2928' to surf. 6. DST data, perforating data, shows of H2S, miscellaneous data f/8548 -8568 f/8533 -8548 f/8513 -8521 f/8391 -8411 f/8371 -8391 f/8351 -8371 w/12 spf 5" 120° phasing JUN .... Alaska OJJ & Gas Cor~s. Commission A~chorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED '/~-// u / - ~ ............. ~ -"= ...... be Z NOTE--Repo~ on Yhis fo/l~n is required for each calendar month, regardless of the status of operations, and must ,,,ed in duplicate with the Alaska Oil and Gas/~onservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rnv 7-1-RE~ . _ 2Z-7 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 0400 hrs, 05/10-/83. Drld 13-1/2" hole to 2640'. Ran DIL/SFL/SP/GR/FDC/CNL/Cal f/2648'-112' Ran 64 jts 10-3/4" 45.5# K-55 BTC csg w/shoe @ 2633'. Cmtd 10-3/4" csg w/1200 sx Arctic Set III, 300 sx AS I. Bumped plug w/2000 psi - ok. ND 20" Hydril & diverter. Well flowing, pumped 90 sx AS I. Stopped backflow. NU csg head & drilling spool. NU BOPE & tstd to 3000 psi - ok (witnessed by AOGCC rep). Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd cs§ to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW. Drld 8-3/4" hole to 8800'. Reamed tight hole f/8600' to 8800'. Ran DIL/FDC/CNL f/8800'-2633'. Ran BHCS f/8800' to 2633'. Drld 8-3/4" hole to 8853' TD as of 05/19/83. Circ. & cond hole. Ran 224 jts 7" 26#/ft K-55 BTC csg w/shoe @ 8811'. Cmtd 7" csg w/550 sx Class "G" cmt. Bumped plug & tstd csg to 3000 psi - ok. Cut 7" csg. Set 7" packoff & tbg head & tstd 7" packoff to 3000 psi. NU BOPE. Arctic packed 10-3/4" x 7" annulus. Ran CBL f/8726'-2000'. Ran CBL/GR/CCL 2928' to surf. Ran Gyro f/surf to 8650'. Perforated well. f/8548'-8568 f/8533'-8548 f/8513'-8521 f/8391'-8411 f/8371'-8391 f/8351'-8371 w/5" 12 spf 120° phase - all shots fired Ran 3-1/2" completion assy w/tail @ 8276' & pkr @ 8251'. ND BOPE. NU tree & tstd to 3000 psi - ok. Displaced well to diesel. Dropped ball & set pkr. Closed SSSV @ 2005'. Secured well & released rig @ 1400 hrs, 05/23/83. HILL/DH25 06/14/83 JUN ,:,~ U.,J Anchorage MEMORANDUM State f Alaska TO: C. V/_. on DATE: May 16, 19 83 Chairman . / .. THRU: Lonnie C. Smith ~ FILE NO~ FROM: Commissioner Bobby Foster -~- ~" ~ .P.~t r o le,.lm Inspector TELEPHONE NO: SUBJECT: Witness BOPE Test On ARCO's 2Z-7 Sec. i1, TIIN, RgE UM Permit ~ 83-64 .T.h..u.rs.day, May 1_2, !983.: I traveled this date to Prudhoe Bay to witness the upcoming BOPE test on ARCO's 2Z-7. The test began at 10:30 p.m. and was concluded at 12.-30 a.m. 5-13-83. As the attached BOPE test report shows there were no failures. In. summary, I witnessed the BOPE test on ARCO's 2Z-7. 02-001AfRev. 10/79) STATE o~.' AbabrW ALASKA Oil -GAS (IDNSERVATION C(/qMIS$ION B.O.~..B. Inspection Rqcort Location: Sec / / Pril linq Contractor Location, General_ Well Sign_ Ceneral ;:Tekeepin ~eserve BOPE Stack Annular Preventer~ . Blind Rams ---/ ACCL~UIATOR SYSTEM Full Charge Pressure.,~~O psig Pressure After Closure/~/&~5' psig Pump incr. Clos. pres.-200 ps ig -- Full Charge Pressure Attained: . ..~ Controls: Master ~t~__5~_ ' '1 Test Pres sure ! ! m~_~sec. rain.sec. Choke Line Valves H.C.R. Valve Kill Line Valves~ Remote~~ Blinds switch cover?~5 Kelly and Floor Safety Valves · Upper Kelly , /, Test Pressure Check Valve, -. / ~r Kelly /.. Test Pressure Ball Type_ /. . Test Pressure Inside BOP / Test Pres sire Choke Manifol~est Pressure, No. Valves /~_. No. flanges_ ~ k~justable Chokes / / Hydrauically operated choke Test Time_' ~ -hrs.~ days and Test Results: Failures. Repair or Replacement of failed equipment to be made within Inspector/Commission office gotified. Remarks:. _~--~,-.~- ~ Distribution orig. - AO&fEC ~ ~ cc - Operator cc - Supervisor Ins . ~. April 18, 1983 Mr. Jeffrey B. Kewin Senior Drilling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Kuparuk River Unit 2Z-7 ARCO Alaska, Inc. Permit No. 83-64 Eur Loc 1990'FSL, 286'F~, Sec ~1 _~1!I=~ RgE b~~ Btmhole Loc. 1508'FNL, 4203'F5~, Sec. 13, TII~, R9E, UM. Dear !'~r. Kewin: Enclosed is the approved application for permit to drill the above referenced well. ~f coring is conducted,, a one cubic inch ch~ from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. ~ny rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to cov~mencing. operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter .3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, ~apter 70) and by the Federal Water Pollution Control Act, as amended. Prior to com~nencing operations you may be contacted by a representative of the Department of Environmental Conservation. : To aid us in. scheduling field work, please, notify this office 24 hours prior to commencin~ installation of the blowout Mr. Jeffrey B. Ke~in Kuparuk River Unit 2Z-7 -2- April 18, 1983 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. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, C. V. Chatterton Chairman of MY Alaska Oil and Gas Conservation Commission Enc lo sure cc: Department of Fish & Game, Habitat Section w/o encl. DePartment of Environmental Conservation w/o encl. be ARCO Alaska, Inc. Post Office Anchorage, Alaska 99510 Telephone 907 277 5637 April 12, 1983 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' Kuparuk 2Z-7 Dear Mr. Chatterton' Enclosed are' o An application for Permit to Drill Kuparuk 2Z-7, along with a $100 application fee. o A diagram showing the proposed horizontal and vertical projections of the wellbore. o A wellbore proximity map for Kuparuk Wells 2Z-7 and 2Z-8. ° A wellbore crossing analysis for Kuparuk 2Z-7 and its offset, 2Z-8. ° A diagram and description of the surface hole diverter system. ° Diagrams and descriptions of the BOP equipment. o An as-built diagram of 2Z-Pad. We estimate spudding this well on May 3, 1983. If you have any questions, please call me at 263-4970. Sincerely, *A'~~~r APF ' Enclosures I PO8 ~a~ka O~l & Gas Con~ Anchorage inc. is ;I ~,ubsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OTL AND GAS CONSERVATION CO'mlVIlSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC SINGLE ZONE [] MULTI LEZONE 2. Name of operator ARCO Alaska, Inc. 3. Address P.O. Box 360, Anchorage, Alaska 99510 9. Unit or lease name Kuparuk River Unit 4. Location of well at surface 1990'FSL, 286'FEL, Sec. At top of proposed producing interval 1223'FNL, 3837'FWL, Sec. At total depth 1508'FNL, 4203'FWL, Sec. 11, T11N, R9E, UM 13, T11N, R9E, UM 13, T11N, R9E, UM Pad 72', RKB 106' AD 25653 ALK 2579 (bottom hole 12. Bond information (see 20 AAC 25.025) Federal Insurance C0. Type Statewide Surety and/or number 8088-26-27 10. Well number 2Z-7 11. Field and pool Kuparuk River Field Kuparuk River 0il P001 Amount $500,000 13. Distance and direction from nearest town 14. I;)ist~ince to ri, vi]rest property or lease line Well pa~n crosses 30 mi. NW of Deadhorse 16. ProPosed depth (MD & TVD) 8741'MD, 6221'TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 500 feet. 21 m il es feet 'i?. N:]l'r~eKo"'f aci-Xes i:~ :ease fe~t 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 50 o (see 20 AAC 25.035 (c) (2) (5. Distance to nearest drilling or completed ' well 2Z-8 (@ 500' ) feet Il~z~pproximate spud date 0~,/03/83 ~ .0_x~_~.~.~- 2671 psig@ 80OF Surface 2999 psig@ 5825 ft. TD (TVD) SIZE Hole Casing Weight 24" ::[6" 65# ]13½" 0-3/4" 45.5# 8-3/4" 7" 26# 22. Describe proposed program: Proposed Casing Liner and Cementing Program CASING AND LINER Grade Coupling Welded H-40 BTC K-55 J-55 BTC HF-ERW Length SETTING DEPTH 2500' MD TOP TVD 80' 35' J 35' 33' i 33' I I 31' I 31' 8710' MD BOTTOM TVD I 115'I 1!5' 2533' !2200' 8741' 16221' I I QUANTITY OF CEMENT (include stage data) 250 cf + 1400~× AS TTT & 250sx AS I ~42sx Class G Extended t31sx Class G Neat Estimated TOC=3015' ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approx. 8741'MD (6221'TVD). .iSelected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while ~drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for iannular). Expected maximum surface pressure is 2671 psig. Pressure calculations are based on current reservoir Ipressure. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. ~iThe well will be completed with 3-1/2", 9.2#, J-55 Buttress tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and :reported on subsequent reports. A downhole safety valve will be installed and tested upon completion of the job. iThe 7" cement will be calculated to fill to 500' above the West Sak, or 500' above the shallowest hydrocarbons. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge The space / CONDITIONS OF APPROVAL DATE Samples required Mud Icg required [~YES ~UO I-lYES Permit number Approval date ~ ~~~~.~~/~,~ 83 APPROVED Bh~_~ Form ~0401 Directional Survey required APl number [~¥ES UNO 50-- O"~-"~C' ~ Y (~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE ~"~'4~ ~ ~ 1983 by order of the Commission Submit in triplicate .......... , ........... i .............. , .......... '"' 5_'";' ,' ..... i-; ...... :_3-i-YT-'Y, 7~-i':%L-~ ......... =--!--~-V-, -~-' ;! ;; 1.5 : ;"I' ;'-! i ~:~ :-:"'--:--:: :'~ :: :'~}~:':':'-' ~'-':':-::' - H'~}R't'-7iO'~T:~:L--~'F'R~J-Fe-~T-~-; .... 7-=?+--~-'=-~'~ i:-~ ~: ~;~ ........................................................ ~.~~ '¢~ ::_::.x: i':.::-::.':':: ::: :.:_: ':.:'-X ..... ::x:s~~-'''-~~~c~~~- ~ ' ~ =~-~'=~---~ 1~ · ~ · ~--: ~ ~:. ~:'~ ;;~'-~ ~ ~ ~:~:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::..:.~:..~..~ ..... :--: ......... =+=-= .... ~.-- ~ ~ ~ ~_~ .X'.:_ ; ;~ , '~! ~;;-- ~~'. ..... : ~'~-~ : I' -' ' ! ~ .................. ;-: .... ='::-=~=- - ~ ~ ~ "~' - . · ' ~ .... ~ ......... ~-- · : :--- ~ ~ . ............................... ; .... ., . --v'~-, ~'~'~-:' : ~'/~ ~ ~:~ -?,~-~-.-----~~ ~ ~ ~ ~ ~ ~ , ~--~T~~!~ ~ ~:~--~___'_~ L~ ~ ~_~_. '-'-~ ........................ ~"~-~- -~:~'-~---:~==,~ ~i ?,,~ ,~i ~ -~ ~;~; ~X ~: I, ' ~ ~ . ' ~ ~ ' '"" : ' ' -~-~ ~ ~ ~ ~ , ; ~ ~ ~ i i ~ ~ ~ ~ ,. --4 ~ i ~ : .~.~ i ~ , ~ ~ i ' i i ! ~ ~ ~ ' , ~ ~ i : .__~ ......... ~.+__~ ..... :_~_ . . , ~ ~, ~ i~ - : ~-.~--~ ; ~ ~ ~ ~ ; X:..- -+~---:--~-+-~oO~-~ ....... ~--'-= . , , . ~ ~' TM " , ~'..~, , ~ ~ ~. ;~ ~: ; : ' ~ i i : ~ ~ i i i i i i i i i i : ~ ~ '. i ~ i ':~, ~ i i ~ .... '"' '"" ~'~ ~ ~ ~ ~ ~i~i ~''a: ~ : ~ : ; -- Kuparuk 2Z-7/2Z-8 Analysis of Wellbore Crossings From surface to a depth of 500', Kuparuk Well 2Z-7 will be 60' away from well 2Z-8; 60' corresponds to the surface well spacing. The kick-off depth in both wells is 500'. Below this depth~ the directional paths of the two wells diverge. The cones of uncertainty for these two wells (calculated at a depth of 500') do not overlap. Because the cones of uncertainty do not overlap and the directional paths diverge below 500', no specific measures will be taken to avoid a wellbore collision. PO8 APR i 5 Oil & Gas Con,~, Commission Anchorago !. 16" - 2000 ~sf TanK~ s.-.- ~n~ ~ _~ 2. Tankco quick connect assy. . ~ x 20 £000 psi ~eu~e ~.~e~- 4. 20" 2000 ~si dril'in~ s~coi w~O'' sTM outlets. 5. !0" Pall valves, hydraulically acc~acec, w/lO" lines to reserve pit. Valves automatically upon closure --~, _.,,.~=~ 'ar preventer. 6. 20" 2000 psi annular preventer. 7. 20" bell nipple. I. Maintenance & ODera~ion 1. Upon initial installation close annular preventer and verify that ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid flow ~o surface is If necessary, manually overrioe ano close ball valve to upwind diverter line. Do not shut in well under anS circums:ances. 16" Conductor BLIND RAHS · i .s . {,--"-' Illl 4. '~-6/8' - 5~ psi x 13-618' - 5~ psi ~11t~ 8. 1~6/8s ~ ffi ~st bi t~ ~ 11. 12. 13. 14. 15. 16. BLI1N'D ~ - {. ) I. 16' - 2tX)O ~s~ 74n~c3 sr.~t-t~nO h~ld 6. Z3-5/8" - S~ psi x s~i 9. ~8" - ~ psi ~S/~ - ~ psi 1. Of, DC ANO ~l.J. AO:XI4I. ATO~ P.E.~[VOIi~ 1'0 PIKMqR I,~ blITH HYDRAULIC FLUIOo ~ THAT ACCUfIfl. ATOR ~ 15 ~ PSI x.r,r,r,r,r,r,r,r,r~o PSI OOklISTRF. A~ OF ~ PIgJLATOR. 3. ~ TXM~ ~EN CLOSE AIL UglTS SII~.TANg)I~Y A.I} ~ TI~ TIME ANO I~~ ~U~I#I~ AFr~ AIL UNITS Af~ CL~ WITH C3.1A~IN~ ~ Off=. · IS 4~ ,~ O.O~ING ~ AW )J~O l~l R~MAINIZlG PI~. ED. PR~]~'TZ~XN~ OE]r~ THAT T~T i~.l.~ WILl. SEAT YALYES OI P,~IIIFOLO. 4. TEST All. ~~Trs TO 250 PSI ~ ).X.O ~ i0 #INIrI'ES. S. INO~.~ ~ TO laO0 ~I AM= ~ F~ 10 ~1~. 7. l~ _1~"~___~__~1~ TO 30~ PSI AXO HOLD'FOR 10 PI[JIIT~3. 8. CLOS~ YALYF. S 0IRECTL¥ UPS'TREN4 OF (DIll. 8LE~) REMAINING UNTESTED MANIIN~ VALYES, IF ~ ~I UPI'rl~.AM OF YALYE A/lO ZERO PSI T~" ~ OF PIPE PJ~IS ANO O.O~E ~ SET OF RAMS. OPEN 8OTT~ SET OF PIPE P,A~. 8~CX OFF ~NNING JOINT AND PULL QUT DF HOL£. ~OS£ 8LIND RAMS ANO ~ TO ~0OO PSI FOR lO MINUTES. BL.J~ TO Z~O PSI. OPeN 81. INO RAMS AND R~COVLq T~T PLU~. MAIC~ MANIFOLD AND LINE A~ FUt. L OF A~IC DIF~E3. AND AIL VALVES ARE SET IN DRILLING PO$lTI0g. 'IF. STSTANOPIPE VALVES TO 3000 PSI. 1~ ~,~J.Y C~ AaO INSIDE 8QP TO 30130 PSI WITH .3,,, s.o ','o TIDNALLY OP~RAI~ i:~ i:: .-.80"E:~ V ~ ~'~ DALLY· 10. 11. 13. 14. IS. 16. 75.~ · o 4 · · !1 12 49th ' II VICINITY MAP ,':Emi. __ I _ I ,--- L AT. 314' LAT, ~g' ~T. ~61' LAT. ~33'FFC LAT, ~T7'fEL 5966 69~.$54 69667~,T57 5 R9~O. !~Oi F 5966801. 395 ~[9[492.750 Z04~' 5~364.787 52~0~6.4~ 5~9074.4~a 1876' I.~' P~L 5R9130,6~ · ~T~S ' t. ~k{.L ¥ 8: X C00R011~ATES ARE 2.0t~TAH~[S ~SECTION [.tNt~ GEODETIC. ~. Y ~ ~ COOEOIN~T~ ARE ON I~ONU~NT~ AT. 1 ~.~-t A~' LO~TION OF CPF-I e. VERTIC, A~ CONTROL EA%KO ON 3~'5 8Y L~ ii, ARCO Alaska, Inc, pe~J~t ~mth Sio~e ~rlt~lh~ AS' BUt LOC ~TION CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc ~' thru 8) (.9~ thru 11) (4) C a sg /~7~ ~/-/~- ~ --'(12 thru 20) (5) BOPE ,,~ (21 thru 24) 1 10. 11. YES NO 1. Is the permit fee attached .......................................... / 2. Is well to be located in a defined pool ............................ 3. Is well located proper distance from property line ..... .,/~.,--~--, -__ 4. Is well located proper distance from other wells .... ]' '~'' 5. Is sufficient undedicated acreage available in this pool ........ z'.~ 6. Is well to be deviated and is well bore plat included ... ~i~.~... 7. Is operator the only affected party ........................ 8. Can permit be approved before ten-day wait .... Does operator have a bond in force ................................... Is a conservation order needed ...................................... Is administrative approval needed ................................... 12. Is 13. Is 14. Wil 15. Wil 16. Wil 17. Wil 18. Is 19. Is 20. Is 21. 22. 23. 24. 25. conductor string provided ...................................... enough cement used to circulate on conductor and ~urface . 1 cement tie in surface and intermediate or production strings ... ~_~ 1 cement cover all known productive horizons ................. 1 surface casing protect fresh water zones .. ~.~ .............. 1 all casing give adequate safety in collapsel tension and burst. this well to be kicked off from an existing wellbore ............. ~-~ old wellbore abandonment procedure included on 10-403 ............ adequate well bore separation proposed ........................... Is a diverter system required ............... ~ Are necessary diagrams of diverter ~ ~O~ ~ip~;'~t~ed 1.11]~ " Do~s BOPE have sufficient pressure rating - Test to ~.~b~ psig ... /API (F 78) ' Does the choke manifold comply w RP-53 eb ................... Additional requirements ............................................. REMARKS Additional Remarks: H z Geolog;~.' _,.Engineering HWK ~ LCS . B,EW WVA~ JKT '~ HJH rev: 12/06/82' INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE / /) o o,;' Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXl No Special'effort has been made to chronologically organize this category of information. .o I.~'T~ ThPF V~RIFI. C~TION UISTI~ ~\rp 010.H02 VRRTFIC,~T'irDt,~ LISTTr,~G P,~GF.. 1, ~* TAPE MFADFR ** SERVICE ~!~MM :SERVIC DATE :83/06/30 3RIC, I~? I~PE NAME :829R :~NTINU~TI()~ ~ DREVIOUS TAPE ** ~ILR BEADEP' FILE N A N'~E :SF, RVlC, 001 SERVICE NA~E VERSIO~ # DA, TE : FILE TYPE IJI~IT TYPE CATE SIZE CODE' 000 000 016 06~ 000 000 004 065 000 000 008 065 000 000 002 065 000 nO0 004 065 000 000 002 065 000 000 008 065 000 000 006 065 060 000 004 ~ SCH b t,.,t ~ {,~ E:RCED * ******************************************************************************* iTATF = At,~SKA JOB ~Ji~t:~E~ aT ACC: 6829~ ~UN #2, DATE LOGGKD: L, DP: HCH SIZE DENSITY FI, UI 0 LOSS 3,000 M 66,0 DF 3,330 ~ 66,0 DF 3,460 M 66 0 DF 1,440 0 1.4,~,0 DF ~ATR]X SANDST{3~M 'PHIS LISTING REPRESE~!TS A ~ERGE OF RI~R []NE AND ~I~N T]NO ******************************************************************************* riPE FI, III r) 31T )ENSITY ;ISCOSITY FLUID Lr'!SS ******************************************************************************** DATA FORNAT ~ECORD ** TYPE S1ZM PwPR CODE 4 ! 66 @ 4 73 60 9 4 65 ,lIN 0 1 66 0 SPECIFICATION BLOCKS SERVICE SERVICE UMIT APl API APl API FILE SIZE PROCF. SS SAMPLE REP~, ID OR'DER ~ Y.,,OG TYPE CLASS ~,OD ~O, LEVEL COD~; { .~VP 010,H02 VFWlFICATIO~* LISTIt~(; P~GF 4 ~AT FDN GAPT 49, 31 32 (') 0 4 ? 0 0 0 0 4 0 .4 0 4 0 I 68 D~PT SP NPHI FCNL DEPT SP NPH! FCNL RNR~ DEPT SP NP~I DEPT N P ~ ! FCNL DEPT DEPT SP RNR~ DEP T SP NPHI, FCNI. RNR A 8822. 5000 SFI,!i -999 2500 GR 48 :;4375 DRH[) 451 2500 CAI,I 3 996! .~ ,~ 00 0000 SFI.,U 50".1562 GR 48,4~75 DRHO 451,2500 CALl 3,9961 8700 4B 4 ~600 -36 565 8500 -37 34 608 8.4,00 '72 2 9 966 8300 -31 4~ 41.0 4 8200, -39 -999 -999 -999 0000 SF[,U 0000 GR 0469 DRHO 9..500 CAI,'[ 1523 0000 SFI, U 0000 GR 65~ ll f.)R HO O0 CALl 8008 0000 5313 0820 50O0 CALl 0:508 0000 SFLU 0625 ~R 58:9:8 DRHO 0000 CALl 0313: ,4375 : 2500 2500 2500 -999 2500 .. .,7500 0,0405 ~HO~ ~,7500 C~ 3,3691 87,0000 0,0405 RHOg 6,5664 3,7520 II...~ 93,6R75 DT 0 Q322 RHOH ~!12734 GR 5,4922 83,0000 DT 1953 ¢;p 28,8906 : II.d,l ,9687 'DT 4~,06:69 ~HO~ '2,7~:66 120;7500 OW :'4063 -999 ,:2:50(). RHI[]B 10'007~7 GD =999,2500 ILD '~99,2500 GR 1 B35n NCNL 2,3189 ILD 99,1B75 G~ 1,8350 NCNL 93.7500 ~.iPiT 2,3438 109,5625 2,3340 NCNL 123,7500 3,9062 ILD 97,5625 GR 2,4042~ NCNL ~8,7,D00 NRAT 3,2832 I L D 91 ' 1.875 G~ g~. 75 N~AT ' 9 R5,3750 GR · 0,313 ~RA? 661 ! ~bD N' C N L 'NR~T 11.4, ILD G~ N C N L NRA T -999,2500 -999,2500 1804,0000 3,6445 2,453i 87,0000 1804,0000 3,6445 2,3027 93,6875 ~709,0000 2150: 0000 3.t895 0957 6250 ,0000 185],0352 27,8750 49 ' 9687 293~,0000 ,7500 ,630:9 12~, 7500 1B21,O0:O0 ,8437 2,05:86 0625 103, -999,2500 '999,,2500 ,VP 010,H02 VE'RIFIC,nTI'O~ l,I$'rI~¢; PAGE 5 )~PT ~100,0000 SFL[) ~P -41 fi000 GR ~PHI -999~~250(! DRB(t rCNI. -999 2500 C ~I.. ! ~NR~ -999 2500 3EPT 8000 ~P -48 qPHI -999 FCNI, -999 ~N~ {% -999 0000 SFLU 00O0 GP 2500 DRHO 2500 CAL! 2500 DEPT 7900,0000 SFLU SP -44,0313 GR NPRI -999,2500 ~'CN[, -999.2500 CALI DEPT 7800 SP -48 NPH! -999 FCNL -999 8BRA -999 0000 SFI~t) 0313 GR 2500 DRHO 2500 CALl 2500 DEPT 7700,0000 SFLU SP -45,5000 G8 NPMI -999,2500 DRHO FCNI~ -999,~500 CALl RNRA -999.2500 DEPT 7600,0000 SP -44,0313 GR FCNT. -999.2500 CILI RNRA -999,2500 DE'PT SP NPHI 3,9863 904,0000 -999,2500 9.8750 .DEPT SP NP H ! 4.5977 2)7,5000 DT 10,0156 6.2891 IbM ~5~1.~50 DT -999,2500 ~O~ 10,0078 ~ DEPT SP NPHI FCNL 6,1094 91.8125 -909.2500 10.2~69 4,~99~ 125, 250 DT -999,2500 9.7500 ~, 8398 .I:t, ~ .8750 DT -9999,2500.5781 GuRHC')R -999,2500 DR:HO '999,2500 CALl -999, ~500 ;.3,3887II~g 130,0000 bT t'~.~734 C~ 7400 -999 '999 7300,0000 :SFLI! 3,0:566 ::I'L~ -48,0313 GR 179,8750 -:999~2500: D~:HO:-999,~500 -999'~500 CAlf! 9,5~1~ G~ 999,~50) 2.5820 ILl) 117,0~00 GR -999.2500 NCNI, 209,2500 N~AT 3.3203 129,0000 GR '999.2500 NCNL 260,5000 2,0430 111.0000 GR -999.2500 NCNL 125,5625 N~AT 4,5625 100.0000 Ge -999.2500 NC~L 107.1875 N~A? 3.4883 ILD 1,11.7500 GR -999,2500 NCNb 134.7500 N~AT ,0000 IR - 999,2500 N C N 1o7.1~50 3,1'406 ,ILD 1t9,1. R75 GP "999,2500 NCNL, !13.9375 NRAT 4 ,5625 GR -9, 99,2500 N C ,N !48.6~50 NP. AT 2,3867 105,3750 GR -999,]500 NCNI., 162. 750 NPAT 2,492~ 204,0000 -999,2500 -999,2500 3,3184 237,5000 -999,2500 -999,2500 1,~94i 125, 250 -999,2500 -999,2500 4,60½6 91,81 5 '999,2500 -999,2500 =999,]500 999, 500 ~,5059 11 , 8?5O -999,2500 -999,2500 3,2051 ,.130,0000 999,2'500 -099,2500 3' 6680 123,3125 "99~,2500 -999,2500 ,5371 17 ,8750 -999,2500 -999,2500 ~VP 010,H02 VFRIFICATIO~I I,I,qTING P~GE 6 )EPT 7100 3P -48 ~PHI -999 rCNL -999 ~NRA -999 0000 SFI.,U 5313 G~ 2500 DRNO 2500 C.ILI 2500 )EPT 7~00.0000 SFf. U SP 46.5313 GR VPHI -999, H o FCNL 500 CAI. I RNRA 999,2500 ~EPT 6900 SP -58 gPHI -999 FCNL -999 RNRA -999 DBPT 6800 SP NPHI -99~ FCNL RNRA -999 DEPT 670~ NPHI -999 FCNi. -Og9 RNRA -999 D~PT 6600 SP -6o NPH ! ,- ENRA '999 N:'P H I ' 9 =99 FCN! -999 RNR A '999: 9EPT 6~00 SP 57 NPH! -999 FCNL -999 RNRA -99:9 0000 SFLU 0313 O~ 2500 DRHO 2500 CAI.,I 2500 0OO0 SFLU 0313 GR 500 DRHO 500 CAI...! 2500 g O00 SFbU 313 GR 2500 2500 2500 0000 SFL~ 0313 ~R ~.500DRHO 500 C~LI ~500 2500 0000 SFLU 5000 GR 2500 3,4~05 IL~i 175.7500 PT -909'2500 RHOR 9.5078 GR 3,537l 104.3125 -g99 ~500 10:39~ (;~ 3 5098 IL~ 9~:8750 BT -909 2500 P~O~ '9:7656 GR 4,3711 IL~ o9.5000 D? -999,2500 RHO~; 9,7031 GR 25078 ILt,~ · ,8125 PT '999,2500 RHO~ 2.2617 111,5625 -999 2500 ~CNL 186:8750 2,7266 II.D !03.7500 GR -999,2500 NCNL 116.5000 NRAT 3,0254 93.7500 GR '999.2500 NCNL ~5.~750 3.8242 90,0000 GR -999,2500 93.5625 NRAT 2,4648 99,0000 GR '999,2500 NCNI,, 83,0625 NPA. T 2,3613 175,7500 '999.2~00 '999, O0 2,761.7 104,3125 '999.2500 '999.2500 3,0527 92,8750 -999,2500 -999,2500 3,7148 99,5000 -999,2500 -999.2500 2 5537 96i8! 5 -999 ~500 -999, 500 4,5078 l!~ 3,240~ IhD .],2246 101,6250 Dr 95,7500 G~ 1.0~ 6250 -99~,~500 PMO[~ -099,2500 ~CNL -99 12500 .6172 G~ 115,5000 NPAT -9g9,~500 q~ 6504 I~,~ ' 9.375 DT -999*2:50:0~:H06 9,8906 .8750 DT 9,2500 "999.~67~ GR 2,8633 100,0000 "999,~500 NCNb ~00. 500 1.01'0!3'77500 (';Ir'DR '' - 9 99, '2 ;5, 0 14,4,1250 :2,423a I,LD .107;nnOO G~ 999,250(, NCSL q3,9375 N'RAT 9375 -999,2500 -999,2500 '999, O0 ~,:4590 '999,2500 -999,2500 ,vp 0.10,H02 YE,~IFICATIO,~ L!$T.]'NG PAGE 7 )EPT 6300 ;P -56 IPW.I -999 '*CNX, -999 ~MRA -999 )EP? 6200 ~p -6O ~PH! -999 ~CNL -999 ~NRA -999 )EPT 6100 5P -60 ~PHI -999 ~CNL -999 .~MRA -999 )EPT 6000 SP -60 MPM! -999 FCNL -999 RNRA -999 DEPT 5900 SP -66 NPHI -999 FCN[, -999 RMRA -999 DEPT 5.800 SP -68 N P -999 FC~I..[ -999 RMR~ -999 DEPT FCNL DEPT N P H ! -999 -999 -999 -999 0000 SFL{.] 3,7246 5313 GR 96,~750 2500 DRHO -999,2500 2500 CAb! 9.9].4~. 25OO ,0000 SFLU 3,1895 ,0000 G~ 97,7500 DT ,2500 DRHO -999,2500 ~HOB e2500 CALI 10,2969 GE .2500 0000 SFLll 3,3633 I[,M 53{3 GR 9~,6250 DT 2500 DRHO -999,2500 RHf3B 2500 C~LT 10,42].9 ¢~ 2500 0000 SFLU 4,9023 9687 GE 96.1250 2500 DRHO -999,2500 RHOB 2500 CALl 9,8906 250O 0000 SFLU 3,5898 2500 DRHO -999,2500 2500 ChL[ ]0,~64~ 2500 00005625 GRSFLU 9 ,~ 9434 ~. ,3750 PT 2500 DRH~ :-999'2500 2500 CAI; 10,4922 2500 00:00 SFI,U 4,7148ILM 0625 G~ 81,5000 DT .500 C~[.;I ~..0,1797 GR 2500 i'5,.I0:i:6 IbM 69,0000 BT -999,2500 10,3594 2500,: 0,.60'099z~ ~ .... 6F'SB: t,U 504 ,, 2695968.7 2500 CAbi i. 0.4531 2500 2,5039 ILD 107,0000 GR -999,2500 ~CNb ~5,2500 2 8027 It,O ~03:1875 GR -999,2500 NCNL 98,6~75 N~AT 2,5527 ILD 109,7500 GR -999,2500. NCNL J. 06,6875 f, IRAT 4,0352 IbP 97,0000 GP -999,2500 NCNI., 2,8340 IhD 108.3750 9 1875 NPAT 2 8984 ILD 108' ,7500 G~ -999,2500 NCNb 83,9375 NRAT 10 '8:00%4 lbo ,5625 G~ "999.2500 NCNL ~0.06~5 ~rhT 4,2:695 It, D 103. 5625 GR 999 . .(.,~ I.., 47 ,~R;~ T 2,5469 96,]750 '999,2500 -999,2500 2,8633 97,7500 '999,2500 -999,2500 2 6094 -999, 500 '999'2500 3 9687 -999,2500 -999,2500 93, -99 2S00 -9999:2500 90, 0 -999, ' -999,2500 -999, 6~,TM ,0000 -999,2500 -999,2500 3,8:4:18' 50,9687 '999,2500 -999,2500 ,Vp 010,Iq02 YMRIFIC.hTION UISTING ~A~E ~ )MPT 5400 0000 SFL~! ;P -84i5000 GR IPHT -9992500 rbR HI] ,'CNL -999 2500 CALl ~?R~ -999,2500 )£PT 5.]oo}oooo ;P 97 5000 GR ~PHI -999 2500 DRHO rCNL -9992500 C'AI~ I ~MRA -999 ~500 )EPT 5200 ~PHT -999 ~CNL -999 ~NRA -999 97 999 qPHT ~CNL 99 RNRA -999 DEPT 5000 SP -19 NPHI -999 FCNL -999 RNRA -999 DEPT 4~00 NPH! -999 ~CNI,, -999 RNRA -999 DEPT 4800 SP '31 NPHI 'q'9~: R~YRA. ,,999 DEPT 47:00 SD .-37 NPHT 999 FCNY., -999 RMRA -999 DEPT 460'0 8P -34 NPHI -999 FCNL -999 RNRA -999 4 6719 IbM 3,3906 It, D 11 1: 3125 [)T 114.0000 GD -999' 2500 RHaB -999,2500 ~C~L 13:0391 (;R 114,3750 NRAT 5.5820 IbM 4,1523 IbD 94,5000 DT 110,5625 GR -999.~500 ~HOB -999,2500 NCNt, 12,7969 GR lP0,7500 ~4R~T 0000 SFLI} 4.4844 Ib~ 3,93]55 ILD 5625 GR 80,5000 D? }07,1~75 GR 2500 DRHC -999,2500 RHOB -999,2500 NCNb 2500 C~L! 12.5859 GR 77,5625 ~'~RAT 2500 ,0000 SFLU 3,9629 Ib~ 3,1113 IGD ,0625 (IR 90,5625 DT 11,5,7500 GR ,~500 DRHO -999.~500 RHIDB -999,2500 NCNL ,2500 C~I,,I 1.2,8203 GR 106,1250 NRAT .2500 , 313 GR 87,56 5 DT 119,56~5 ~R ,2500 DRHO -¢~99,2500 RHOB -999,2500 NCNb ,2500 CA, LI 13,2656 GP 78,3~.25 NRAT ,2500 00005313 SFbUGR .6SV5 DT° -[la'25oo NC~I, 2500 DRHO -99':9,2500 RH B 99, 2500 CALl 2500 , ,5625 GR -999,25:0:0 RHO.~ -999, 13,7500 GR aS. ~75 HRAT 25:00~ ' U OOO0 : SFL' 4"57:42 ILM : 5,4609 II,D 031,3 ~R 9S~06'25D~ .126'0000 ~R. 2500 DRMO -~99,2500 iRHOB 999,2500 NCNb 2500 C~I,I' 1.3.257~ ¢;R ~9~8125 ~RAT 2500 3.i, 3 (;~, 75 ;12'50 DT , ].:2' 9'!41 G~ 90,~125 ~RAT 25 O0 3 5234 111:3125 -999,2500 -999,2500 4,439~ 94, 000 -999,2500 -999,2500 O4:2422 5000 -999.2500 -999.2500 3,3262 90,5625 -999,2500 -999,2500 $,5.391 8 ,5625 -999,2500 -999,2500 3,8301 81,6875 -999,:2500 -999,2500 6,0156 . 70,3750 999,~500 ,,999. ~500 -999., 2500 -999,2~00 4,9t80 75,1250 '999,2500 '999,2500 ,VD 010,H02 V~RIFICATIC)N t, lSq'lNG PIGE g ~EP* 4500 ;P tPHI 45. 'Chi., 547 tNR A 3 )EPT 4400 ;P -40 ti)HI 35 0000 SKLU 5313 GR 4102 DRHO 0000 C.~I,I 7461 0000 SFLU 5313 GR 8398 DRHO 000o CALl 7539 )EPT 4.300],0000 SFLU ~P 4 ,0313 GR {PHI 4¢:3125 DRHO ?CNL 56 0000 CAI,I ~NRA 4,2227 )EPT 4,200 5P ,.45 qPHI 42 rCNL 497 ~NRA 4 )EPT ~NRA 5P PH ~ DEPT SP RNR A DEPT N:P H ! ~ C b{ L RNR~, 8P R:~R A 5000 3750 D T 8! .... 0093 RHOn 12 6563 6,5859 IbM 0,02 ] 5 RHOR 3,2656 0313 GR 0410 DRHO 0000 CALl 0742 7.7305 70.9375 PT 0,0151 RHO~ 12,7500 GR 8 2266 69' ,0000 DT 00.0000 4!4 5313 441,0000 4,4961 SFLU 6,~547 IL~ DRHO ~,0181 ~H[]B 94.53 GR CALl 1 ,~, 4000 -58 42 614 3 0000 $'FbU ~0,000:0 IbM 9687 GR 54.62'50 DT 773'4 DRHO ~"9,q687z 0012:9 RHOB 5000 CALI , , 6?77 42 474 4 1.406 0i000SFLU ~,9844 5313 GR R , 2 2 DRHO 0000 CALl 0000 $'FLU 5313 GR 49~0 0000 6 0,35 )T 6:;)5 O: I 4'37' 5 D T 7t313 .9375 DT 16,0938 G~ 9.5625 !.!7.0000 ?,1387 70,2500 7,6172 121,5625 2 1250 77~0625 ILD I I,,D NCN l, ~RAT 7.9.114 124,0000 2,1113 ~8.]750 I bD NCNb NRAT 7,2734 129,1250 2,2363 77,8750 I h D GR N C N L 5 12i 84]7 ILD 3750 GR 2402 NCNL, 5625 NRAT 1 ~@; 375n 2,2:441 NC'Nb ~0,2500 N~AT 1. I16,5000 ,7500 6],2:'461NCNb .843? t~IRAT ~,5469 1.2 ,187~ : ,2:734 NCNb 7 ,5000 NR. AT 9,1797 ~0.3750 2050,0000 3,8379 9,2109 73,7500 2~94,0000 3,324~ · 9,6719 70,9375 2396,0000 3,8359 :1094 oo0o 00006992 70 87 lOBi' ,0000 ,8164 ,375 0 6250 223!:0000 701~ ,320,3 ~., 7500 964,0000 ,72~5 2140 000:0 3 6133 ,¥P 0!0.H02 VERIFIC~TlflN LISTING PAGE 10 )EPT 3600 0000 SFLU ;P -56!031.3 GR lPHI 44 1.406 DRHO ;CNI., 475,5000 CAI-I {NR.A 4,30~6 )EPT 3~00,0000 ~P 73.6875 4PHI 39.8437 ~CNL 639,5000 CALl tN~fi 3.R047 )~PT 3400 0000 SFI,U ~P -53i5313 GR !PHI 49 0~34 DRHO ~CNL 409 2500 C~LI ~RA '4.3359 )EPT 3300 ~P -52 gPHI 48 ?CNL 398 RNRA 4 0000 8FLU 5313 0957 750O CALl 2070 DEPT 3200,9~000 SFLU 5P -53,~,.,13 G~ ~PHI 42,3340 DRHO RNIRA?CNL 46~:0000. 0469 C~L! I)'EP T 3100 SP -59 DEPT 3000 SP -65 F C N Y,, 468 RMRA 4 DEPT N:PH! 38 FCNL 5R5 RNR~ 3 g 4375 0,0195 13,3516 15.4375 Ib!~ 42.9687 -0 0044 15~9719 8 0078 60!3750 DT 0 0381, 11 1.71~ DEPT 2800 SP -SR NPNI 46 FCNL 40B R:NRA 4 8,9766 Ib~ 79,2500 DT O,0103 RHOB 11,6563 GR ~5 DT ' 0073 RHOB 0, 1 3,4 14.1. 0000 SFbU 5311] G~ 293 DRHO 500 CALl 339~ 6'....,6875 DT ,0176: RHOB 1~;046'0 GP 0000 5625 3359 14, :09 l'b~' 57 2 ~7 DT 1 '0:1:66 RH3~ ,5~59 O~ O0 0S~LU 5625 GR 8789 ,00:7:3 RH:OB · · , ,,1953 0000 :$FLU: : 10,9297 6563GR 7~85 [)Ri'lC] 0 ,017.6 3008 I L ~ D T 8 257R 2,1914 61.7500 I I., D NCNI~ 15,6406 140.3750 2.0077 37,3!,25 II,,P 7.8320 132,0000 2.2070 65.1875 I [,O GR NCNL NKAT 10,~!09 t33, 000 2,1992 R3,1250 ILD GR NCNL NRA. T 10 7969 13~' ,5000 77'~090 . 250 GR NCNL ].30' 5O onoo N C N L I LO NCNb '17:,:34381LD 147,375(3 GR :2,'0605: NCNb 34.3750 N~A~ 9 132~ 67i0000 2050 0000 3,7871 15,~609 42, 687 2434,0000 3,6152 8,6484 60,3750 !776.0000 4.0000 12,2266 79,2500 1.679,0000 ],9590 I ,8203 71,0625 1887], 0000 12,69844 69, 875 .7422 4~" 6563 ,2187 203~, 00:00: ,8047 1:7 32 227.1 )00 " ~19 1.7:5~,0000 ,94,73 )EPT rCNI, 5P ~PHI FCNL FCN I, DEPT SP NPH! FCNL RNRA DEPT NPH! FCNL RN~A DEPT SP NPH I F C N h RNRA NPH I FC. NL RNR ~ OEPT SP NPH! FCNL P600 000o -61 6875 42 7246 483 2500 4 0313 SFLU DRHn C~I,I 2500 -74 445 4 2400 -55 43 424 4 0000 ,2500 ,7988 .2500 ,3438 0000 2813 9941 oooo 1~75 ORHO CAL! GR DRHO C~bI 30 4 0000 () 3 ! 3 5410 5000 6719 cS, FLU R 2200 -51 44 53O 3 ,0000 5313 3848 5000 9844 SFLU DR:HO CA [,I 71(10 0000 '77 3750 52 40 3 4 5195 53, 062 : DRH{, ,8008 1900 -67 53 347 4 CALT 0,0234 RHO~ 18.9531 GR 20.31~5 Ih~ 56,9062 BT -0.0093 RHOE [3.3906 GR 22.3125 51.5313 PT -0,0029 13,~437 20,0313 ~5,7813 DT 0.0215 14.5~{59 9, ]150 IbM 67 · 25 DT o~, 0078 RHOB 14,632~ GR 6 09:4 X 1, ~ 16.3 ! 2~ DT 49, '0'0176 RHOB 13, ~90fi 16, ~75,0 15~. ~9,..;68'7 DT .:0',0,:0~0: :R~O~ 13,0781 G , ':21,:9 0103 41,41, 9,9062 ILD 152,7500 GR 2,0684 NCNI, 74,5000 NRAT 19 6406 ILD -99922500 GR 2. 0254 NCNb 56,9062 NRAT 19 4063 -999:2500 GR 2 ~215 NCNL 51~3~3 NRAT 18.9844 II,,D -999.2500 GR 2.027] NCNL 4,5,7813 hIRAT 9~,4063 ILD ,2500 GR 2,0898 NCNI., 6'7,8125 NRAT -g~, 0 :2 1 ] NCNb ,2 0 ~ 49'31125 NRAT I;6:2'344 2500 GR -999,9.785 NCNL 4~,9687 N~AT 9,78'91 I L D '099,2500g GR NCNL N R A T 21,218:7 ILD -999,2500 GR ' 2.0:078 NCNL 53.1.250 NRAT 11,5547 73,6875 1610.0000 4.2891 2500 1949 0000 37070 16.1188 ~999, 500 935,0000 3,7813 , O0 1777,0000 3.8105 ,2'30o 6~9,0000 4,3984 ,,I:oooo 81.25 -9~9, {. 821 , 0000 ,2~78 176~,:0000 ,3594 22,'~875 -999, 500 1666,0000 4,3242 ~VP 0~.0,H02 VERIFICATION LIST]lNG PAG.F, 12 DEPT 1700 5P ~PHI 44 ?CNL 474 0000 500O 0918 2500 OOOO D£PT 1~00,0000 SFLU SP 60 2813 GR NPHI 50:B789 DRHO FCNL 3H3,5000 CALI RNRA. 4,5~34 DEPT 1500 SP -52 NPH! 71 FCNL 221 RNRA 5 0000 SFLU 7813 GR 9727 DRHO 8750 CALI 8906 DEPT 1..400, ~000 SFLU SP 57, 313 GR NPHI 51,3672 DRHO FCN,.. 3644:0000 CALl RNRA 4727 D~PT I~00 SP ~73 NPH:I 71 rent, 221 RNRA 5 DEPT 1200 SP -62 ~PH~ 49 FCN1, 297 43 0000 Ib~ 45i2813 DT "0 0176 RHOB 1.3 3984, G~ DE{PT ~100 SP F ..'L~ 369 47,5625 IL~ 40,4063 DT '0,0210 RHO~ 14,7422 G~ 57 9375 IbM 45' .0,8125 BT 17,0117 R~OB ,3281 G~ D~PT 1000 SP -70 N:PHI mO FCNL 3~0 29,5469 24,0000 bT ?0 0200 RHOB .4~0000 GR 63,7188 DT "0,00~4 P'HOB 14'3750 CR 0000 5625 4355 7500 ~RHO A[.,I 6602 ~8,687:5 {3'093~ DT -0'0088 14,7656 32:6:, 2500 ILM .,43, I~75 ~10,:0039 P:HO:B: ,3750 CR 0000 SFL. U : : :::27:, 45.31: IbM 281,3 gR 65,6~50 DT 5000 CaLI 15 4, 063 Ca 3633 000 1211 39,9062 II, I) -099,2500 GR 2 0215 NCHL 45~2~1,3 ~RAT 49,3438 XLD -999,2500 GR 1,9854 NCNb 40,4063 NRAT 47,5000 -999,2500 GR 2,0098 NCNL 45,81.25 NRAT 32 1250 II,,D -999!2500 G~ 1 3408 NCNB 24 0000 NRAT R ,0703 NCNL 6 ;71 88 NRAT 36,2187 '999,2500 41,5703 NCNb ,0938 NRAT 208,0000 &~D -999,2500 ,l.a;5 NRAT '2~,06:25 -999,2500 GR 65,6250 iiRRT 38,9687 -999,2500 1963,0000 3,9023 52,0313 -999,2500 1897,0000 3,8184 45,5938 ~999,2500 735,0000 4,2656 . 29, 56 , o :oooo 3477 24,~62 ,~999, ~ O0 ,6250 2500 1477 ' ,0000 4~,269§ 999, 664 .210, 1750 999, ~0 )Fp'r qO0.OOO0 SwLU ~PHI 47,4609 D~Hf) rCNI, 340,0000 ClI.,I ~NRA 4,9023 )EPT RO0 ~P VPH! 59 rCNL 268 )EPT ~P ?CNL DEPT NPHT RNRA DEPT NPH.I FCN L RNRA NPH~ FCNL R NRA NPH I FCNL RIVRA SP DEPT SP NPH ,T tONI., R N R A 139.5000 IL~ 5!,5313 P'r 0,0034 RHOB 21,3750 Gw 0000 SFLU 77,0000 II..~ 5313 Ge 61.o3.!3 D? 3750 ORHO 0,001 5 RHC]P 2500 CALI 18, I 094 GR 0586 700.0000 SFI,,U 75.0000 It,~ 2 1'67:8125 GR 51,5000 DT 5 3184 D~.HO 0,0283 RHO~ ?6°0000 C~LI 10,7344 600 -71 58 285 4 0000 SFBU 167,3750 0000 G~ 48,5313 7402 DR,O 0.0576 5000 C~[..I {7.0938 5586 5OO -q2 55 309 4 0000 srl, u 130,1250 I. Lg 7500 GR 66,6875 DT 3711 DRHO 0,01.,~7 R,OB 0000 CALl 14.61.72 GR 4688 57 255 5 0000 SFLU 124.,6875 8750 GR 62,5'625 D r 14,,0' 0073 ~,0~ ,1250 6n ~961 300 '116 45 414 4 0000 SF:LU 3125 OR 1, 797 200, '189, 55, . 250 ¢,,,~ . 322:3 DR,Iq 3 "'0. 2500 C~[.,I 14' 0313 ~I00 63 232 5 8a.75oo II,D -qg9.2500 GR 2,0410 NCNL 51,5313 NRA? 45.4375 ILD -999,2500 G~ 2.0195 NCNt, 61.03~3 NEAT 39 1875 -999~2500 2 03~1. NCNb 51:5o6o 67,3750 ILD -909.2500 G~ 1,6992 NCNb 48,5313 NRAT 29,8750 -999,2500 GR 2,0020 NCNL 66,6875 NRAT '9 , 625 ILD 50O G~ 2,064L~ NCNL 62,5625 NRAT 46, i 562 '999,2500 OR 5~' I~:30 NCNLT ,, ,093R N'~A. 16,{094 !bD -99g;2500 GR 5~,9873 NCN][i ' 8437 NRA7 '999. O0 (,R 1 , 627:9 NC~!L 29,1719 IqRAT 111,8750 '999,2500 1668,0000 4,1797 59,9687 -999,2500 1358 0000 4:7578 492,52{13 -99 , 2500 . 4 :oooo 35i6 93,~625 -999, 500 1302,0000 4,6953 34,4688 -999,2500 1,381,0000 4,441a 58,8750 -999 2500 1401 ' ,0000 ,5234 102,7500 -.999;2500 ,0000 '8652 o 4:oooo 4453 2.000,0000 999,2800 120], 0000 .9062 ~VP 010.~02 VERT..FICATI[~,' lISTING PAGF ~.4 )EPT 87 0000 SFLU ~P ;43i031~ C',R {PHi 67 6270 rCN[, 48 5250 2000,O00U 20,5313 -0,5059 15,5703 ~ERVIC~ NAM~ PII.,F TYPE: ~EXT FII.E 4,2,461 1ED -909,2500 GR 1,9248 NCNb 20,5313 NRAT ?OO0 0000 -999~2500 1277,0000 5,1484 ** TAPE TRAIbER DATE :83/06/30 DRIGIN ;0000 TAP~ NA~E :8298 CONTINI.tATXGN # :01 N~XT TAPE NAME : COMMENTS :TAPE COMMENTS ~E~VICE NA~E, :S~RVIC DATE :83/06/30 :RIGIN EEL ~E :REEL C~NTI.NUATION ~ :01 NEXT REEL NA~E : CO~ENT$ :REEL COMM~;N~