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Home My WebLink About182-214MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, November 26, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1E-22 KUPARUK RIV UNIT 1E-22 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 11/26/2025 1E-22 50-029-20884-00-00 182-214-0 W SPT 5953 1822140 1500 1462 1464 1464 1464 11 11 11 11 INITAL P Bob Noble 11/2/2025 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1E-22 Inspection Date: Tubing OA Packer Depth 440 2200 2150 2145IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN251103153235 BBL Pumped:1.8 BBL Returned:1.7 Wednesday, November 26, 2025 Page 1 of 1          Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov October 7, 2025 Greg Hobbs Regulatory Engineer, Wells Team ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Docket Number OTH-25-045 Notice of Violation – BOPE Test Reporting Request for Information (RFI) Kuparuk River Unit 1E-22 (PTD 1822140) Dear Mr. Hobbs: The Alaska Oil and Gas Conservation Commission (AOGCC) has completed its review of ConocoPhillips Alaska Inc.’s October 7, 2025, letter responding to the subject notice of violation and information request. Actions taken should help to prevent recurrence of this violation. The AOGCC does not intend to pursue any further enforcement action regarding the late blowout prevention equipment test report. Sincerely, Jessie L. Chmielowski Gregory C. Wilson Commissioner Commissioner cc: Phoebe Brooks Gregory C Wilson Digitally signed by Gregory C Wilson Date: 2025.10.07 15:20:59 -08'00' Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.10.07 15:48:02 -08'00' October 7, 2025 Jessie Chmielowski Commissioner Alaska Oil and Gas Conservation Comm’n 333 West Seventh Avenue, Suite 100 Anchorage, Alaska 99501-3572 Gregory Wilson Commissioner Alaska Oil and Gas Conservation Comm’n 333 West Seventh Avenue, Suite 100 Anchorage, Alaska 99501-3572 VIA E-MAIL (samantha.coldiron@alaska.gov) Re: Docket No. OTH-25-045 Notice of Violation – BOPE Test Reporting KRU 1E-22 (PTD 1822140) Commissioners Chmielowski and Wilson: On September 30, 2025, the AOGCC sent a notice of violation and request for information to CPAI regarding the late submission of a BOPE test report on KRU well 1E-22. As AOGCC notes, the BOPE test was timely completed on September 8, 2025. However, the test report was not submitted to the AOGCC until eight days after the test, which is three days beyond the submission time requirement of 20 AAC 25.285(f)(6). In its notice, the AOGCC directs CPAI to “describe specific steps that have been or will be taken to prevent recurrence of this violation.” CPAI takes AOGCC compliance, including report submission compliance, seriously. We have reviewed our records for the last three years and this appears to be the only time we have submitted a late BOPE test report to the AOGCC during that period. We have reiterated the importance of timely AOGCC report submittals to all rig managers, and we are confident this problem will not recur. If there are further questions or requests, do not hesitate to reach out. Greg Hobbs, P.E. Regulatory Engineer, Wells Team 700 G Street, ATO 1504 Anchorage, AK 99501 (907) 263-4749 (office) Greg.S.Hobbs@conocophillips.com By Samantha Coldiron at 1:22 pm, Oct 07, 2025 2 Sincerely, Greg Hobbs Regulatory Engineer, Wells Team ConocoPhillips Alaska, Inc. Digitally signed by Greg Hobbs DN: OU=Regulatory Engineer, O= ConocoPhillips Alaska Wells, CN=Greg Hobbs, E=greg.s.hobbs@conocophillips.com Reason: I am the author of this document Location: Date: 2025.10.07 13:05:56-08'00' Foxit PDF Editor Version: 13.1.6 Greg Hobbs Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov September 30, 2025 CERTIFIED MAIL – RETURN RECEIPT REQUESTED 7018 0680 0002 2052 8009 Erika Livingston Wells Chief Engineer ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Docket Number OTH-25-045 Notice of Violation – BOPE Test Reporting Request for Information (RFI) Kuparuk River Unit 1E-22 (PTD 1822140) Dear Ms. Livingston: On September 26, 2025, the Alaska Oil and Gas Conservation Commission (AOGCC) received by electronic mail a blowout prevention equipment (BOPE) test report for workover operations conducted by Nabors 7ES. The report indicates testing was completed on September 18, 2025. Submittal of a BOPE Test Report to the AOGCC is required not later than five days after completion of a BOPE test. Refer to 20 AAC 25.285(f)(6). The test submittal requirements (distribution and date due relative to the completion of the test) are also detailed at the top of the BOPE Test Report, Form 10-424. Failure to timely submit a BOPE test report is a violation of AOGCC regulations. Within 7 days after receipt of this letter (next business day if the due date falls on a weekend or holiday), ConocoPhillips Alaska Inc. is requested to describe specific steps that have been or will be taken to prevent recurrence of this violation. The information request is made pursuant to 20 AAC 25.300. Failure to comply with this request will be an additional violation. The AOGCC reserves the right to pursue an enforcement action in this matter according to 20 AAC 25.535. Questions regarding this letter should be directed to Jim Regg at 907-793-1236. Docket Number: OTH-25-045 September 30, 2025 Page 2 of 2 Sincerely, Jessie L. Chmielowski Gregory C. Wilson Commissioner Commissioner cc: Victoria Loepp Jim Regg Phoebe Brooks Gregory C Wilson Digitally signed by Gregory C Wilson Date: 2025.09.30 09:29:50 -08'00'Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.09.30 11:40:20 -08'00' 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number): 10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9480'2869 None Casing Collapse Conductor Surface Production Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-265-6049 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 6510'8745'6246'9126' KRU 1E-22 8855-8958' 9112-9132' 9309' 6048-6123' 6235-6250' 9/1/2025 3-1/2" BAKER FHL HYD Retrievable BAKER FB-1 PERMANENT SSSV: CAMCO TRDP Perforation Depth MD (ft): 16" 10-3/4" 76' 2091' 110'110' 2449' 6406' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025651 182-214 P.O. Box 100360, Anchorage, AK 99510 50-029-20884-00-00 ConocoPhillips Alaska, Inc AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 8725'MD/5955'TVD 9020'MD/6168'TVD 2093'MD/1847'TVD 9044' Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Proposed Pools: 9341' Burst 2415' Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field TVD Perforation Depth TVD (ft): MD 7" Cy Eller cy.eller@conocophillips.com Associate CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: J-55 m n P s 1 6 5 6 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:07 pm, Aug 07, 2025 325-465 X JJL 8/18/25 10-404 X DSR-8/14/25 AOGCC witnessed BOP and Annular test to 3000 psi. Follow attached detailed procedure for removing the THA (as a mitigation against subsidence related growth). If upward force is encountered on TBA circulate in KWF per attachment. AOGCC witnessed MITIA post injection. A.Dewhurst 19AUG25JLC 8/19/2025 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.08.19 14:46:57 -08'00'08/19/25 RBDMS JSB 082025 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 6, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KRU 1E-22 (PTD# 182-214). Well 1E-22 was drilled and completed in January of 1983 by Rowan 34 as a Kuparuk A and C Sand producer. The well was worked over by Westward 1 in December of 1984 to install a selective completion and was online as a producer until it was converted to a water injector in July of 1998, and later a WAG injector in September of 2002. The well had a healthy life as an injector until 2012, when TxIA communication on gas injection began. The well was waivered for water only injection and brought back online until an IA pressure rise and failed an MIT-IA in January of 2025. A leak detect log was run and revealed tubing leaks at 7,708’ and 7,826’ RKB. To return the well to WAG injection, we are requesting approval to proceed with a rig workover. We plan to pull the 3-1/2” completion from a pre-rig cut above the upper packer, then verify drift of the 7” casing. If drift is not achieved, the damaged 7” casing will be cut and pulled, then new 7” production casing will be run, and the OA cemented to surface. Once the subsidence damage is repaired, a new 3-1/2” completion with a non-sealing overshot and stacked packer will be installed. If you have any questions or require any further information, please contact me at 907-265-6049. Cy Eller Rig Workover Engineer CPAI Drilling and Wells 1E-22 Kuparuk Injector Tubing Swap with Contingency Subsidence Repair PTD: 182-214 Pre-Rig Work Remaining 1. CMIT-TxIA to 3,000 psi against RBP at 8,744’ RKB 2. Set catcher on top of RBP 3. Cut tubing at ~8,679’ RKB 4. Prepare well for rig arrival Rig Work MIRU 1. MIRU Nabors 7ES on 1E-22. No BPV will be set for MIRU due to Nabors 7ES internal risk assessment. 2. Circulate seawater and complete 30-minute NFT. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3,000 psi. Test annular 250/3,000 psi. Retrieve 3-1/2” Completion 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing string and jewelry from pre-rig cut at ~8,679’ RKB. Casing Cleanout/Drift Run 6. MU cleanout/drift BHA, PU drillpipe and perform casing cleanout and tubing dress off run. a. If drift issues are observed, follow “7” Casing Subsidence Repair Contingency” section. 7” Casing Subsidence Repair Contingency 7. Set plug in 7” casing above SC shoe. PT to confirm plug is set. 8. ND BOPE, ND tubing head and grow casing as needed using subsidence de-tensioning system, pull casing in tension and set slips, NU new tubing head, NU BOPE. a. 7” casing is set on a mandrel hanger with a 3.45’ long pup. If casing slips cannot be set due to casing collar, continue with Step 10 to perform full subsidence repair. 9. MU drift BHA for new completion and RIH to SC shoe. b. If drift is achieved, skip ahead to Step 22. 10. RU E-Line and pull CBL from SC shoe to surface to identify TOC in OA. c. Calculated top of Arctic Pack cement is 2,017’ RKB. 11. RIH with open-ended drillpipe to plug. Dump sand on plug. 12. RIH and cut 7” casing above TOC. Shut in and circulate freeze protect out of OA as needed. 13. ND BOPE, ND tubing head. Spear 7” casing and remove casing slips. NU BOPE to casing head. a. BOPE flange break unable to be tested at this point. Flange break to be tested as soon as practical once test plug can be installed. 14. Pull and lay down 7” casing from cut. d. Make additional cuts in 7” casing to remove in sections as necessary. e. Test BOPE flange break once 7” casing is pulled. 15. RIH with mills to ensure drift for overshot casing patch, and cementer. Bore out 10-3/4” casing to create drift as necessary. 16. MU and RIH with overshot casing patch, cementer, and new 7” casing. 17. Engage overshot and PT casing against RBP to 2,500 psi. Page 1 of 3 *Follow attached THA unbolting procedure. - JJL 1E-22 Kuparuk Injector Tubing Swap with Contingency Subsidence Repair PTD: 182-214 Page 2 of 3 18. Cement 7” x 10-3/4” annulus to surface. 19. ND BOPE, set casing slips, cut excess 7” casing and install packoffs, NU tubing head and BOPE. Test breaks. 20. RIH and mill up cement and cementer plugs as necessary. Perform additional cleanout runs as necessary. 21. RIH and wash sand and debris from top of RBP. Retrieve RBP. Install New 3-1/2” Completion with Stacked Packer 22. MU new 3-1/2” completion with non-sealing overshot, nipple profile, packer, and GLM. RIH to tubing stub. 23. Once on depth, space out as needed. Circulate corrosion inhibited fluid. 24. Land tubing hanger, RILDS, drop ball and rod and set packer. 25. Pressure test tubing to 3,500 psi for 30 minutes. 26. Pressure test IA to 3,000 psi for 30 minutes. ND BOP, NU Tree 27. Confirm pressure tests, then shear out SOV. 28. Install BPV and test. ND BOPE. NU tree and PT packoffs. 29. Pull BPV and freeze protect well. 30. RDMO. Post-Rig Work 1. Pull SOV. Install new GLD. 2. Pull ball and rod used for setting packer. 3. Pull RBP and catcher. General Well Information: Estimated Start Date: 9/1/2025 Current Operations: Shut in Well Type: Injector Wellhead Type: FMC Gen III. 11” 3M casing head top flange. 7-1/16” 5M tubing head top flange. Scope of Work: Pull the existing 3-1/2” completion from pre-rig cut above the upper packer, perform 7” subsidence repair to obtain drift for new completion as needed, perform cleanout/dress off run as needed, then install a new 3-1/2” completion with stacked packer. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams 1E-22 Kuparuk Injector Tubing Swap with Contingency Subsidence Repair PTD: 182-214 Page 3 of 3 FFollowing subject to change with Pre-Rig Work: MIT Results: CMIT-TxIA: Passed (3,000 psi, 2/28/2025) MIT-OA: Passed (1,800 psi, 4/26/2025) Tubing POT & PPPOT: Passed (1/15/2025) IC POT & PPPOT: Passed (11/30/2024) Static BHP: 3,487 psi / 6,181’ TVD measured on 7/3/2024 MPSP: 2,869 psi using 0.1 psi/ft gradient Personnel: Workover Engineer: Cy Eller (907-265-6049 / Cy.Eller@conocophillips.com) Production Engineer: Banabas Dogah Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 9,126.0 1E-22 8/9/2019 jhansen8 Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull DV and Annotate Tbg Leaks 1E-22 2/27/2025 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL T x IA ON GAS INJECTION. **WATER ONLY INJECTION ALLOWED** 7/29/2013 osborl NOTE: DMY @ GLM #6 IS PERMANENT 8/26/2010 osborl NOTE: View Schematic w/ Alaska Schematic9.0 8/26/2010 ninam 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 15.25 34.0 110.0 110.0 65.00 H-40 WELDED SURFACE 10 3/4 9.95 33.6 2,448.7 2,091.1 45.50 K-55 BTC PRODUCTION 7 6.28 31.5 9,341.1 6,406.4 26.00 K-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 27.4 Set Depth … 9,044.1 String Max No… 3 1/2 Set Depth … 6,185.3 Tubing Description TUBING Wt (lb/ft) 9.20 Grade J-55 Top Connection BTC-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) 27.4 27.4 0.12 HANGER 8.000 FMC GEN III HANGER 3.500 2,092.6 1,847.4 44.68 SAFETY VLV 5.937 CAMCO TRDP-1A-ENC SAFETY VALVE (FLAPPER ONLY LOCKED OUT 5/26/2002) 2.813 2,164.8 1,898.3 45.60 GAS LIFT 5.390 CAMCO KBUG 2.920 5,091.8 3,622.1 55.85 GAS LIFT 5.390 CAMCO KBUG 2.920 6,573.8 4,480.5 51.55 GAS LIFT 5.390 CAMCO KBUG 2.920 8,001.9 5,417.8 38.98 GAS LIFT 5.390 CAMCO KBUG 2.920 8,657.1 5,906.5 44.93 GAS LIFT 5.390 CAMCO KBUG 2.920 8,698.9 5,936.1 44.98 SBR 4.000 BAKER ELA SEAL BORE RECEPTACLE 2.813 8,725.1 5,954.6 44.75 PACKER 6.156 BAKER FHL HYD RETRIEVABLE PACKER 2.891 8,762.0 5,980.9 44.42 PRODUCTION 5.390 CAMCO KBUG 2.920 8,826.9 6,027.6 43.91 PRODUCTION 5.390 CAMCO KBUG 2.920 8,834.8 6,033.2 43.86 BLAST RINGS 4.500 BLAST RINGS (5) 2.992 8,982.6 6,140.4 43.27 PRODUCTION 5.390 CAMCO KBUG 2.920 9,019.8 6,167.5 43.03 LOCATOR 4.000 BAKER LOCATOR SUB w/ 5' SEALS 3.000 9,020.3 6,167.9 43.03 PACKER 6.156 BAKER FB-1 PERMANENT PACKER 4.000 9,022.8 6,169.7 43.00 SBE 4.000 BAKER SEAL BORE EXTENSION 3.000 9,037.8 6,180.7 42.86 NIPPLE 4.540 CAMCO D NIPPLE NO GO 2.750 9,043.3 6,184.8 42.81 SOS 4.570 CAMCO SHEAR OUT SUB 3.015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,708.0 5,206.2 48.34 LEAK TBG LEAK IDENTIFIED BY LDL AT 7708' RKB 2/27/2025 2.992 7,826.0 5,287.0 45.00 LEAK TBG LEAK IDENTIFIED BY LDL AT 7826' RKB 2/27/2025 2.992 8,744.6 5,968.5 44.57 RBP 3-1/2" P2P RBP MID- ELEMENT AT 8747' RKB, OAL 7.24' TTS P2P CPP3 5174 2/3/2025 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) 2,164.8 1,898.3 45.60 1 GAS LIFT DMY BK 1 0.0 10/24/1995 0.000 5,091.8 3,622.1 55.85 2 GAS LIFT DMY BK 1 0.0 6/13/1993 0.000 6,573.8 4,480.5 51.55 3 GAS LIFT DMY BK 1 0.0 6/13/1993 0.000 8,001.9 5,417.8 38.98 4 GAS LIFT DMY BK 1 0.0 10/24/1997 0.000 8,657.1 5,906.5 44.93 5 GAS LIFT OPEN BK 1 0.0 2/27/2025 OPEN POCK ET 0.000 8,762.0 5,980.9 44.42 6 PROD DMY BK 1 0.0 12/20/1984 0.000 8,826.9 6,027.6 43.91 7 PROD DPHF CV BEK 1 0.0 7/3/2024 0.313 8,982.6 6,140.4 43.27 8 PROD DPHF CV BEK 1 0.0 8/15/2004 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,855.0 8,958.0 6,047.8 6,122.5 C-1, C-2, C-3, C- 4, 1E-22 1/10/1983 8.0 IPERF 9,112.0 9,132.0 6,235.4 6,250.3 A-5, 1E-22 1/10/1983 8.0 IPERF 1E-22, 8/6/2025 9:37:28 AM Vertical schematic (actual) PRODUCTION; 31.6-9,341.1 FLOAT SHOE; 9,339.2-9,341.1 FLOAT COLLAR; 9,260.0- 9,261.4 IPERF; 9,112.0-9,132.0 SOS; 9,043.3 NIPPLE; 9,037.8 SBE; 9,022.8 PACKER; 9,020.3 LOCATOR; 9,019.8 PRODUCTION; 8,982.6 IPERF; 8,855.0-8,958.0 PRODUCTION; 8,826.9 PRODUCTION; 8,762.0 RBP; 8,744.5 PACKER; 8,725.1 SBR; 8,698.8 GAS LIFT; 8,657.1 GAS LIFT; 8,001.9 LEAK; 7,826.0 LEAK; 7,708.0 Primary – Full Bore; 4,700.0 ftKB GAS LIFT; 6,573.7 GAS LIFT; 5,091.8 SURFACE; 33.7-2,448.7 FLOAT SHOE; 2,446.8-2,448.7 Squeeze – Behind Casing Squeeze; 2,017.0 ftKB FLOAT COLLAR; 2,365.5- 2,367.1 GAS LIFT; 2,164.7 SAFETY VLV; 2,092.6 Primary – Full Bore; 39.0 ftKB CONDUCTOR; 34.0-110.0 HANGER; 33.6-36.8 HANGER; 31.5-35.0 HANGER; 27.4 KUP INJ KB-Grd (ft) 39.00 RR Date 1/11/1983 Other Elev… 1E-22 ... TD Act Btm (ftKB) 9,480.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292088400 Wellbore Status INJ Max Angle & MD Incl (°) 60.42 MD (ftKB) 4,300.00 WELLNAME WELLBORE1E-22 Annotation Last WO: End Date 12/20/1984 H2S (ppm) DateComment SSSV: TRDP Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 39.0 2,449.0 39.0 2,091.3 Primary – Full Bore Lead 529 bbl 12 ppg Arctic Set III + Tail 41 bbl 15.7 ppg Arctic Set I **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=10.75 2,017.0 2,795.0 1,793.3 2,316.5 Squeeze – Behind Casing Squeeze Top Job 41 bbl 15.7 ppg Arctic Set I + Tail 98 bbl 7.3 ppg Arctic Pack-LW **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=7 4,700.0 9,341.0 3,394.4 6,406.3 Primary – Full Bore Lead 173 bbl 11.9 ppg Class G + Tail 72 bbl 15.8 ppg Class G ^^Csg OD=7 1E-22, 8/6/2025 9:37:29 AM Vertical schematic (actual) PRODUCTION; 31.6-9,341.1 FLOAT SHOE; 9,339.2-9,341.1 FLOAT COLLAR; 9,260.0- 9,261.4 IPERF; 9,112.0-9,132.0 SOS; 9,043.3 NIPPLE; 9,037.8 SBE; 9,022.8 PACKER; 9,020.3 LOCATOR; 9,019.8 PRODUCTION; 8,982.6 IPERF; 8,855.0-8,958.0 PRODUCTION; 8,826.9 PRODUCTION; 8,762.0 RBP; 8,744.5 PACKER; 8,725.1 SBR; 8,698.8 GAS LIFT; 8,657.1 GAS LIFT; 8,001.9 LEAK; 7,826.0 LEAK; 7,708.0 Primary – Full Bore; 4,700.0 ftKB GAS LIFT; 6,573.7 GAS LIFT; 5,091.8 SURFACE; 33.7-2,448.7 FLOAT SHOE; 2,446.8-2,448.7 Squeeze – Behind Casing Squeeze; 2,017.0 ftKB FLOAT COLLAR; 2,365.5- 2,367.1 GAS LIFT; 2,164.7 SAFETY VLV; 2,092.6 Primary – Full Bore; 39.0 ftKB CONDUCTOR; 34.0-110.0 HANGER; 33.6-36.8 HANGER; 31.5-35.0 HANGER; 27.4 KUP INJ 1E-22 ... WELLNAME WELLBORE1E-22 COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Conductor 110 110 16 15.25 65 H-40 WELDED Surface 2449 2091 10 3/4 9.95 45.5 K-55 BTC Production 9341 6406 7 6.28 26 K-55 BTC Tubing ~8680 ~5923 3 1/2 2.99 9.3 L-80 HYD563 1E-22 Proposed RWO Completion PROPOSED COMPLETION 3-1/2" 9.3# L-80 HYD563 Tubing to surface 3-1/2" x 1-1/2" Gas Lift Mandrel 3-1/2" x 7" Packer @ ~8600' RKB 3-1/2" X landing nipple (2.813" min ID) 3-1/2" Non-sealing Overshot REMAINING COMPLETION LEFT IN HOLE Baker SBR @ 8,699' RKB Baker FHL Packer @ 8,725' RKB Camco Production Mandrels @ 8,762' and 8,827' RKB Carbide Blast Rings Camco Production Mandrel @ 8,982' RKB Baker Locator Seal Assembly @ 9,019' RKB Baker FB-1 Permanent Packer @ 9,020' RKB Baker SBE @ 9,022' RKB Camco D Nipple @ 9,037' RKB Surface Casing 2449' MD Production Casing 9341' MD A-sand Perfs 9112' - 9132' MD C-Sand Perfs 8855' - 8958' MD Conductor Production Casing Estimated TOC: 4,700' RKB from 1/8/1993 CBL Surface Casing Estimated TOC: Surface Arctic Pack Cement Calculated TOC: 2017' RKB COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Conductor 110 110 16 15.25 65 H-40 WELDED Surface 2449 2091 10 3/4 9.95 45.5 K-55 BTC Production 9341 6406 7 6.28 26 K-55 BTC 7" Tie-Back ~1950 ~1750 7 6.28 26 L-80 HYD563 Tubing ~8680 ~5923 3 1/2 2.99 9.3 L-80 HYD563 1E-22 Contingency Proposed RWO Completion CONTINGENCY SUBSIDENCE REPAIR 7" 26# L-80 Casing to Surface 7" Cementer 7" Sealing Overshot Casing Patch PROPOSED COMPLETION 3-1/2" 9.3# L-80 HYD563 Tubing to surface 3-1/2" x 1-1/2" Gas Lift Mandrel 3-1/2" x 7" Packer @ ~8600' RKB 3-1/2" X landing nipple (2.813" min ID) 3-1/2" Non-sealing Overshot REMAINING COMPLETION LEFT IN HOLE Baker SBR @ 8,699' RKB Baker FHL Packer @ 8,725' RKB Camco Production Mandrels @ 8,762' and 8,827' RKB Carbide Blast Rings Camco Production Mandrel @ 8,982' RKB Baker Locator Seal Assembly @ 9,019' RKB Baker FB-1 Permanent Packer @ 9,020' RKB Baker SBE @ 9,022' RKB Camco D Nipple @ 9,037' RKB SOS @ 9,043' RKB Surface Casing 2449' MD Production Casing 9341' MD A-sand Perfs 9112' - 9132' MD C-Sand Perfs 8855' - 8958' MD Conductor Production Casing Estimated TOC: 4,700' RKB from 1/8/1993 CBL Surface Casing Estimated TOC: Surface Arctic Pack Cement Calculated TOC: 2017' RKB 1 From:Lau, Jack J (OGC) Sent:Monday, August 18, 2025 3:40 PM To:Lau, Jack J (OGC) Subject:RE: [EXTERNAL]KUPARUK RIV UNIT 1E-22 (182214) Condition of Approval Detailed procedure for removing the THA. "When ND tubing head adapter Ʋange, back oƯ nuts from the adapter Ʋange to ensure they can move. Tighten the nuts back up to make contact with the Ʋange face but allow them to remain loose. BackoƯ and retighten all nuts independently. Check the tightness of the loosened nuts after removing all but two and determine if force was transferred to the loosened nuts. Repeat this for the last nut. If at any time it is determined that force is found to be transferred back to the loosened nuts, STOP. Call RWO ENGR and swap well over to KWF before continue to ND. After ND is completed and BOP’s are installed the well can be swapped back to SW if mechanical barriers are in place and the well passes a 30 min no Ʋow to SW. If no additional tightness is observed, continue ND as planned." From: Eller, Cy <Cy.Eller@conocophillips.com> Sent: Monday, August 18, 2025 2:54 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: [EXTERNAL]KUPARUK RIV UNIT 1E-22 (182214) Hi Jack, I reached out to the wellhead vendor, and they are searching for a drawing for this wellhead. Historically we have not seen any issues with 7” casing growth when the casing is set on a mandrel hanger. Until we can provide a drawing to illustrate the hard shoulder on the 7” casing hanger and reducer bushing that will prevent upward movement towards the tubing hanger, I am okay with the COA’s from your previous email being included for 1E-22 and I will include the following verbiage in my detailed procedure for removing the THA. "When ND tubing head adapter Ʋange, back oƯ nuts from the adapter Ʋange to ensure they can move. Tighten the nuts back up to make contact with the Ʋange face but allow them to remain loose. BackoƯ and retighten all nuts independently. Check the tightness of the loosened nuts after removing all but two and determine if force was transferred to the loosened nuts. Repeat this for the last nut. If at any time it is determined that force is found to be transferred back to the loosened nuts, STOP. Call RWO ENGR and swap well over to KWF before continue to ND. After ND is completed and BOP’s are installed the well can be swapped back to SW if mechanical barriers are in place and the well passes a 30 min no Ʋow to SW. If no additional tightness is observed, continue ND as planned." Thank you, 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. 2 Cy Eller RWO/CTD Engineer ConocoPhillips Alaska OƯice: 907-265-6049 Cell: 907-232-4090 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Monday, August 18, 2025 1:21 PM To: Eller, Cy <Cy.Eller@conocophillips.com > Subject: [EXTERNAL]KUPARUK RIV UNIT 1E-22 (182214) CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Afternoon Cy, Just a reminder to send drawing and a short summary of wellhead showing the PC no goes upward on the its hanger preventing the casing from pushing upward on the tubing hanger like the FMC gen 3 and 4 (2M- 07) Thanks, Jack Lau Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission (907) 793-1244 OƯice (907) 227-2760 Cell Originated: Delivered to:7-Mar-25 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1A-20 50-029-22112-00 909816971 Kuparuk River Packer Setting Record Field- Final 16-Feb-25 0 1 2 1A-24 50-029-22984-00 909816969 Kuparuk River Multi Finger Caliper Field & Processed 12-Feb-25 0 1 3 1A-24 50-029-22984-00 909816969 Kuparuk River Plug Setting Record Field- Final 15-Feb-25 0 1 4 1C-156 50-029-23750-00 909809782 Kuparuk River Injection Profile Field & Processed 11-Jan-25 0 1 5 1E-11 50-029-20787-00 909890720 Kuparuk River Leak Detect Log Field- Final 1-Mar-25 0 1 6 1E-11 50-029-20787-00 909890665 Kuparuk River Plug Setting Record Field- Final 1-Mar-25 0 1 7 1E-11 50-029-20787-00 909890665 Kuparuk River Plug Setting Record Field- Final 28-Feb-25 0 1 8 1E-22 50-029-20884-00 909890664 Kuparuk River Leak Detect Log Field- Final 27-Feb-25 0 1 9 1Q-04 50-029-21250-00 909678506 Kuparuk River SBHP Record Field- Final 9-Nov-24 0 1 10 2B-11 50-029-21089-00 909890473 Kuparuk River Packer Setting Record Field- Final 21-Feb-25 0 1 PLEASE 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 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: T40190 T40191 T40191 T40192 T40193 T40193 T40193 T40194 T40195 T40196 190-162 200-181 223-023 182-051 182-214 184-234 184-035 3/7/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.03.07 10:25:17 -09'00' 182-214 1E-22 50-029-20884-00 909890664 Kuparuk River Leak Detect Log Field- Final 27-Feb-25 0 1 Originated: Delivered to:19-Feb-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 1A-20 50-029-22112-00 909816966 Kuparuk River Leak Detect Log Field- Final 23-Jan-25 0 12 1A-20 50-029-22112-00 909816966 Kuparuk River Multi Finger Caliper Field & Processed 22-Jan-25 0 13 1A-20 50-029-22112-00 909816966 Kuparuk River Plug Setting Record Field- Final 22-Jan-25 0 14 1D-38 50-029-22961-00 909594223 Kuparuk River Multi Finger Caliper Field & Processed 16-Jan-25 0 15 1E-17 50-029-20793-00 909817737 Kuparuk River Plug Setting Record Field- Final 4-Feb-25 0 16 1E-22 50-029-20884-00 909817740 Kuparuk River Multi Finger Caliper Field & Processed 2-Feb-25 0 17 1E-22 50-029-20884-00 909817740 Kuparuk River Plug Setting Record Field- Final 3-Feb-25 0 18 1H-01 50-029-22330-00 909817089 Kuparuk River Multi Finger Caliper Field & Processed 7-Feb-25 0 19 1H-01 50-029-22330-00 909817089 Kuparuk River Plug Setting Record Field- Final 7-Feb-25 0 110 1H-110 50-029-23601-00 909817451 Kuparuk River Plug Setting Record Field- Final 24-Jan-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T40111T40111T40111T40112T40113T40114T40114T40115T40115T40116190-162200-077182-116182-214193-006218-0312/20/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.02.20 11:39:57 -09'00'1E-2250-029-20884-00 909817740Kuparuk RiverMulti Finger CaliperField & Processed2-Feb-250171E-2250-029-20884-00 909817740Kuparuk RiverPlug Setting RecordField- Final3-Feb-2501T40114T40114182-214 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1E-22 (PTD 182-214) Report of suspect IA pressure increase Date:Tuesday, January 14, 2025 8:16:28 AM Attachments:1E-22 90 Day TIO Plot & Schematic.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Tuesday, January 14, 2025 7:27 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 1E-22 (PTD 182-214) Report of suspect IA pressure increase Chris, KRU 1E-22 (PTD 182-214) (AIO 2B.078) was reported by operations this morning for the IA increasing to 2125 psi, above MAOP. The DSO bled the IA pressure, but it quickly repressurized. The well was shut in and freeze protected 1/14/25. CPAI plans to have DHD perform initial diagnostics including pack off tests, a MITIA and an IA-DDT. If the MITIA fails, the well will remain shut in and be secured for further diagnostics. If the MITIA and IA-DDT pass, the well will be brought back on injection and set up for a 30-day monitor. Any proper paperwork for continued injection or corrective action will be submitted once diagnostics and monitor period are completed and a plan forward is determined. A 90-day TIO trend and schematic are attached for reference. Please let me know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 2500 2000 ul a � 1500 x v a` 1000 500 8000 7000 p 6000 u. U � 5000 ° 4000 a m 3090 v c 2000 1000 Pressure 5ummary for 1E-22 m m N m m H m a m N N m H a n 0 m m m N m m" v N 0 N m m" Q rl rl N N N m o 0 o 1 H r N N N m o 0 o H H H N N N m o 0 o 1i H 0 0 0 0 0 0 rl rl rl rl rl rl rl rl rl rl N N N N N N N N N N 0 y rl 9 rl N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N 0 0 0 0 0 0 0 0 o O o 0 0 0 0 4 0 0 0 0 0 0 0 o o 0 0 0 ry N N N N N N N N N N N N N N N N ry N N N N N N N N N N N N N N N N Date E H — IA PRESSURE — CA PRESSURE — TUBING PRESSURE (PSI) — TEMPERATURE(DEGF) — DRY GAS (MSCFD) — MI GAS (MSCFD) — PRODUCED WATER(BPD) — SEAWATER (BPD) KUP INJ WELLNAME 1E-22 WELLBORE 1E-22 ConocoPhillips Alaska, Inc. SAFETY FLOAT IPERE', AJI D6,ta20� FLOAT PRODOCTION: 31...1.1 Well Attributes I Max Angle&MD TD FIeM Name WNIbore APWWI Wellho,e Statue Icl (°) K PAR KRIVER NIT 22 IN 0,42 MO(IIKRI 4,300,00 MBtm(PRO, 9480.0 Comment X351ppm) Oate MmlNian Last WO: Entl Ost 1212011984 KBGN ed 39.00 RR Date 111111983 OIM1e, EIrv... Attenuation Depth IftKBI 1 WNlbore I End Dare Lag Mad By Last Tag: RKB 9, "LP ,E-22 I toole I jnonerna Last Rev Reason Annolalian WellWm End Data Lail Motl By Rev Reason: Pulled Plug wl gauges. Pulled SPGISet CV 1F22 I 'o,"U'4 letgusD Notes: General & Safety Annotation End Dart East Mod By NOTE: WAIVERED WELL T A IA ON GAS INJECTION. "WATER ONLY INJECTION ALLOWED" JI2 D,13 osbotl NOTE: DMY@ GEM Is IS PERMANENT 8oetwoo0 osbotl NOTE'. View Schematic wl Alaska Schematic9.0 812612010 ninam Casing Strings Cag Des Doing ID(in) Top(nK8) sal DaptM1 sN (.K.) ITVDI(ftKel Dr", W0.engWXl i Grade i op TM1read CONDUCTOR 1fi 15.25 I 34.0 1 110.0 1 1100 I 65.00 H-00 WELDED SURFACE ION41 9.951 33.6 2,4487 1 2,091.11 45.50 K55 BTC PRODUCTION J 1 U.28 1 31.5 1 9,341.11 6,4TUA I 26.00 I K-55 IBIG Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) s...'s- And D.,dr. String Mat 1,11-Tubing Desonl,rion -gets) Grade Top Connection ID (in) 27.4 9,W4.1 6,185.3 3112 TUBING 9.20 J-55 BTC-MCD 12.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top(Min Top FIVE) IXKB) T"pincl I,) Kern Dea oD NominY (in) Cam Make Model Nominal 10(in) 27.4 27.4 0.12 HANGER 8.000 FMC GEN III HANGER 3.500 2,092.6 1,84T.4 44.68 SAFETYVLV 5.937 CAMCO TRDP-IA-ENC SAFETY VALVE )FLAPPER ONLY LOCKED OUT 51262002) 2.813 2,164.8 1,898.3 45.60 GAS LIFT 5.390 CAMCO KBUG 2.920 51091.8 3,622.1 55.85 GAS LIFT 5.390 CAMCO KBUG 2.920 6,573.8 4,480.5 51.55 GAS LIFT 5.390 CAMCO KBUG 2.920 9,00119 5,417.8 38.98 GAS LIFT 5.390 CAMCO KBUG 2.920 8,657.1 5.906.5 44.93 GAS LIFT 5.390 CAMCO KBUG 2.920 8,698.9 5,936.1 44.98 SBR 4.000 BAKER EL4 SEAL BORE RECEPTACLE 2.813 8,725.1 5,954.E 44.75 PACKER 6.156 BAKER FHL HYD RETRIEVABLE PACKER 2.891 8,762.0 5,980.9 44.42 PRODUCTION 5.390 CAMCO KBUG 2.920 9,826.9 6,027.6 43.91 PRODUCTION 5.390 CAMCO KBUG 2.920 8,834.8 6,033.2 43.86 BLAST RINGS 4.500 BLAST RINGS(5) 2.992 8,982.6 6.140.4 43.27 PRODUCTION 5.390 CAMCO KBUG 2.920 9,019.8 6,167.5 43.03 LOCATOR 4.000 BAKER LOCATOR SUB wl R SEALS 3.000 9,020.3 6,167.9 43.03 PACKER 6.156 BAKER FBA PERMANENT PACKER 4.000 9,022.8 6,169.7 43.00 SBE 4.000 BAKER SEAL BORE EXTENSION 3.000 6031.8 6,1807 d2.86 NIPPLE d.540 CAMCNO ODNIPPLEGO 2.750 9,043.3 6184.8 4281 SOS 4.570 CAMCO SHEAR OUT SUB 3.015 Mandrel Inserts : excludes pulled inserts Top (6KB) ToMBI Top I45.60 st ai an N1 Sery Vvlve Type LastType Type OD (in) TRG Run (psi) RunDate Code Mahe MotlN PM S0.000 2,164.8 1,898 1,898.3 45.60 1 GAS LIFT DMY BK 1 0.0 10124I1995 0.000 5,091.8 3,6ZA1 55.85 2 GAS LIFT DMY BK 1 0.0 611311993 0.000 6,5n.8 4,480.5 51.55 3 GAS LIFT DMY BK 1 0.0 61130993 0.000 8,001.9 5,417.8 38.98 4 GAS LIFT DMY BK 1 0.0 10124A997 0.000 8,657.1 5,906.5 44.93 5 GAS LIFT DMY BK 1 0.0 1012511995 0.000 8762.0 5BW.9 44.42 6 PROD DMY BK 1 0.0 122011984 0.000 8,826.9 6,027.6 43.91 T PROD DPHF CV BEK 1 0.0 71312024 0.313 8,982.6 6140.4 43,27 8 PROD DPHF V BEK 1 00 8/150004 0,000 Perforations & Slots Top idlestBtm (BKB) TOP OVO) (BKB) Stm MD) (6KB) IInhW Zone Date Shot a piDenDen strong) Type Tom 8,855.0 I 8,958.0 5,041.8 6122.5 4 C-2,CJ, C- 4,1E-22 IPl WI983 8.0 IPERF 9,112.0 9,132.0 6,235.4 6,250.3 A5,1E-2 1110/1983 8.0 IPERF MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, July 22, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1E-22 KUPARUK RIV UNIT 1E-22 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2024 1E-22 50-029-20884-00-00 182-214-0 W SPT 5953 1822140 3000 1624 1626 1629 1629 285 450 450 450 REQVAR P Sully Sullivan 6/3/2024 Tested to 3000 psi per AIO 2B.078 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1E-22 Inspection Date: Tubing OA Packer Depth 540 3300 3195 3170IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240604104537 BBL Pumped:4.7 BBL Returned:4.5 Monday, July 22, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 999 99 9 9 9 9 AIO 2B.078 James B. Regg Digitally signed by James B. Regg Date: 2024.07.22 15:09:48 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1E-22 KUPARUK RIV UNIT 1E-22 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/20/2022 1E-22 50-029-20884-00-00 182-214-0 W SPT 5953 1822140 3000 2339 2340 2336 2330 627 822 820 815 REQVAR P Austin McLeod 6/5/2022 MITIA to MAIP. AIO 2B.078. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1E-22 Inspection Date: Tubing OA Packer Depth 180 3300 3170 3150IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220605190155 BBL Pumped:5.9 BBL Returned:5.7 Monday, June 20, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9AIO 2B.078. James B. Regg Digitally signed by James B. Regg Date: 2022.06.20 15:41:20 -08'00' MEMORANDUM TO: Jim Regg d P.I. Supervisor�,�" FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 8, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc IE -22 KUPARUK RIV UNIT 1&22 Ste: Inspector Reviewed By: P.I. Sup-v�j` Comm Well Name KUPARUK RN UNIT IE -22 API Well Number 50-029-20884-00-00 IUSp Num: mitSAM200607204543 Permit Number: 182-214-0 Rei Insp Nam: Inspector Name: Austin McLeod Inspection Date: 6/72020 v' Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min —�j—__--_�_—_� 9 Type Well IE-zz TYPe InJ W 'rpD 5953 TUbjI1 1096 1103 -E3155- r 1104 - _ PTD 1822140 Type 'fest SPT T¢St pSi 3000 TA 110 3300 ------- -- -. —_ BBL Pumped: 58 ' BBL Returned: 57 OA 495 550 550 - 548 ' Interval REQVAR p/F P Notes' 2 year MIT -IA to MAIP as per AIO 213,078. i Monday, June 8, 2020 Page 1 of 1 • MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,June 12,2018 TO: Jim Regg Z P.I.Supervisor ��el qi 5 V SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1E-22 FROM: Adam Earl KUPARUK RIV UNIT 1E-22 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IE-22 API Well Number 50-029-20884-00-00 Inspector Name: Adam Earl Permit Number: 182-214-0 Inspection Date: 6/9/2018 Insp Num: mitAGE180611084108 Rd Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1E-22 'Type Inj W TVD 5953 ' Tubing 1685 - 1685 " 1685 - 1685 I PTD 1 1822140 'Type Test SPT 1Test psi 3000 IA 760 3290 - 3185 - 3160 • BBL Pumped: 1 5.4 ' BBL Returned: 5.2 OA 430 - 575 - 565 • 563 Interval ; REQVAR P/F P Notes: tested as per AIO 2B.078 to max ant.Inj.Pressure SCANNED JUN 2 `L cu, Tuesday,June 12,2018 Page 1 of 1 IIT! u Y, • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Friday, March 9,2018 1:31 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: Report of unexplained rising OA pressure 1E-22 (PTD 182-214,AIO 2B.078) update 3-9-18 Attachments: 1E-22 90 day TIO 3-9-18.JPG; MIT KRU 1E-22 diagnostic MITs 2-9-18.xlsx Chris, 1E-22 is nearing the end of its 30 day monitor. The well passed an MITIA and MITOA on February 9, 2018. Apart from being particularly responsive to localized thermal changes,there has not been the resumption of the slow build up in OA pressure that the well was reported for last month. Therefore,the well will be returned to its normally waivered status, to be operated under AIO 26.078. If signs of communication are observed again in the future, it will be re-reported at that time. Please let us know if you disagree with path forward. Attached are the MIT form and latest 90 day TIO plot. Kelly Lyons/Jan Byrne satiNED " f Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 : NSK Well Integrity Supv CPF1 and 2 Sent: -: esday, February 07, 2018 1:12 PM To:Wallace, . D (DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<°. er.Senden@conocophillips.com> Subject: Report of unexplaine• ' OA pressure 1E-22 (PTD 182-214,AIO 2B.078) 2-7-18 Chris, KRU injector 1E-22 (PTD 182-214,AIO 26.078) is expe '-ncing an unexplained slow rise in OA pressure (^'500psi increase over the course of"'2.5 months.) The well is already waive -• for TxIA communication while on gas injection and is restricted to water-only injection. The initial suite of DHD diagn• 'cs will be pursued to include MITIA, MITOA/SCLD as needed and packoff testing. CPAI intends to leave the well on water i '-ction while diagnostics are completed and integrity of the wellbore is confirmed/denied. If passing tests are obtained, •- well will be left on a 30 day monitor and a follow-up email will be provided with path forward once that has been determi •• based on the well's response during the monitor period. Please let us know if you disagree with the plan or have an estions. Attached is the latest 90 day TIO plot. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 1 Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Wednesday, February 7, 2018 1:12 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of unexplained rising OA pressure 1E-22 (PTD 182-214,AI0 26.078) 2-7-18 Attachments: 1 E-22 90 day TIO 2-7-18.JPG Chris, KRU injector 1E-22 (PTD 182-214,AIO 26.078) is experiencing an unexplained slow rise in OA pressure ("S00psi increase over the course of^'2.5 months.) The well is already waivered for TxIA communication while on gas injection and is restricted to water-only injection. The initial suite of DHD diagnostics will be pursued to include MITIA, MITOA/SCLD as needed and packoff testing. CPAI intends to leave the well on water injection while diagnostics are completed and integrity of the wellbore is confirmed/denied. If passing tests are obtained,the well will be left on a 30 day monitor and a follow-up email will be provided with path forward once that has been determined based on the well's response during the monitor period. Please let us know if you disagree with the plan or have any questions. Attached is the latest 90 day TIO plot. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission —� DATE: Tuesday,January 10,2017 TO: Jim Regg �� I P.I.Supervisor � i7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1E-22 FROM: Chuck Scheve KUPARUK RIV UNIT 1E-22 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry -531'?-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1E-22 API Well Number 50-029-20884-00-00 Inspector Name: Chuck Scheve Permit Number: 182-214-0 Inspection Date: 1/8/2017 Insp Num: mitCS170109061220 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1E-22 ' Type Inj 1 W' TVD 5953 Tubing 1419 1420 ' 1419 - 1418 - PTD 1822140 ' Type Test SPT Test psi 3000 - IA 770 3300 - 3220 _ 3200 - BBL Pumped: BBL Returned: OA 589 740 - 733 728 - Interval L REQVAR P/F P Notes: Tested per AIO 2B.078 SCANNED AK) .017 Tuesday,January 10,2017 Page 1 of 1 \ z- 2�� 2_x.0 G"/ WELL LOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. April 19, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501RECEivett /1.11/2014, BENDER t M.K.BEN APR 29 2016 AOGCGRE: Injection Profile : 1E-22 Run Date: 11/10/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1E-22 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-20884-00 Injection Profile Log SCAMMED 1 Color Log 50-029-20884-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: ,L/value-ozos., / � ,/, • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,November 30,2015 TO: Jim Regg Kelt P.I.Supervisor ` elt I l`36 I5 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1E-22 FROM: Bob Noble KUPARUK RIV UNIT 1E-22 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv1 l&2- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1E-22 API Well Number 50-029-20884-00-00 Inspector Name: Bob Noble Permit Number: 182-214-0 Inspection Date: 11/20/2015 Insp Num: mitRCN151120175953 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1E-22 , Type Inj W 'TVD 5953 Tubing 1272 - 1273 - 1273 - 1274 PTD 1822140 - Type Test SPT Test psi 3000 , IA 869 3300 • 3210- 3180 - Interval REQVAR P/F P ✓ OA 461 . 492 - 498 501 - Notes: AIO 2B.078 MIT-IA required by variance to maximum anticipated injection pressure of 3000 psi SCANNED SEP 16 2016 Monday,November 30,2015 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,June 18,2013 Jim Regg P.I.Supervisor C q(7(7.44 15 SUBJECT: Mechanical Integrity Tests L CONOCOPHILLIPS ALASKA INC 1E-22 FROM: Jeff Turkington KUPARUK RIV UNIT 1E-22 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1E-22 API Well Number 50-029-20884-00-00 Inspector Name: Jeff Turkington Permit Number: 182-214-0 Inspection Date: 6/16/2013 Insp Num: mitJATI30616210139 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Type Inj jTVD IA 0 2850 IE-22 W 5953 i I 380 3000 2880 2850 Type Test 1822140 - ! yp SPT{Test psi 1500 OA 170 275 • { 260 275 - PTD —_- Interval OTHER P/F P Tubin g 1432 " 1430 1435 1435 - Notes: Application made for AA.7.0 bbl diesel to fill. SCANNED FEB 2 0 2014 Tuesday,June 18,2013 Page 1 of 1 • • Nov ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 ff Q � �f U June 27, 2011 �-- Commissioner Dan Seamount " Alaska Oil and Gas Commission � ,. Cit 3 33 West 7 Avenue, Suite 100 Anchorage, AK 99501 ' ,,,.osi Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped on 3/21, 5/9, 5/23 and 5/24, 2011. The corrosion inhibitor /sealant was pumped 6/18, 6/19, 6/20 and 6/21, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, MJ L veland ConocoPhillips Well Integrity Projects Supervisor • • I I ConocoPhillips Alaska Inc, Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 06/27/2011 1A,1B,1E,1L,1Q,1Y PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 1A -03 50029206150000 ' 1810880 16" N/A 23" N/A 1.7 6/20/2011 1A -04A 50029206210100 2001940 18" N/A 23" N/A 2.5 6/20/2011 1A -16RD 50029207130100 1820310 SF N/A 22" N/A 5 6/18/2011 1B -03 50029205880000 1810560 SF N/A 23" N/A 5 6/21/2011 1B-04 50029205950000 _ 1810650 _ 18" N/A 18" N/A 2.5 6/21 /2011 1B -05 50029202370000 1770010 _ 31" 6.40 2'9" 5/24/2011 6 6/21 /2011 1B -07 50029206160000 1810890 7'2" 1.00 _ 22" 5/9/2011 2.5 6/21/2011 1B -08A 50029206350100 _ 1971120 _ 18'8" N/A 29" N/A 4.5 6/21/2011 1B-09 50029206550000 _ 1811340 _ SF N/A 23" N/A 5 6/20/2011 1B -10 50029206560000 1811350 SF N/A 23" N/A 6 6/21/2011 1B-12 50029223650000 _ 1930610 13'4" 2.00 24" _ 5/9/2011 _ 6 6/21/2011 1B -101 50029231730000 2031330 3" N/A 22" N/A 1.7 i 6/21/2011 1B -102 50029231670000 2031220 112" 0.60 36" 5/9/2011 1.7 6/21/2011 1E-05 50029204790000 _ 1800580 _ 19" N/A 19" N/A 1.7 6/19/2011 1E-22 50029208840000 1822140 14" 1.75 17" 3/21/2011 1.7 6/19/2011 1E-23 50029208580000 _ 1821840 _ 58' 10.75 2'S" 5/23/2011 3.4 6/19/2011 1E -30 50029208140000 1821390 _ 15'5" 1.75 16" 3/21 /2011 2.5 6/19/2011 1E -105 50029232430000 2050060 20" N/A 20" N/A 6 6/19/2011 1L -16 50029212020000 1841810 14'9" 2.00 35" 5/23/2011 6 6/20/2011 1L-18 50029221450000 1910350 SF N/A 18" N/A 2.5 6/19/2011 1Q-24 50029225840000 1951210 7'8" 1.00 12" 5/9/2011 5 6/18/2011 1Y-02 50029209410000 1830590 40'10" 5.00 41" 5/9/2011 8.5 6/1 8/2011 ~ ~ ~~1 ~ ~- ~.~ Regg, James B (DOA) ~ ~ ~'~"-Z 1 ~ From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Saturday, June 26, 2010 9:59 AM To: Regg, James B (DOA); Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Subject: KRU 4 Yr and Variance MIT's Attachments: KRU 1 G-01 062510.x1s; KRU 2D-04 062510.x1s; KRU 1 E pad 062510.x1s ~.. J ~~, --'J , ~ --J ~J KRU 1G-01 KRU 2D-04 KRU 1E pad 062510,x1s (21 KB) 062510.x1s (21 KB) 062510.x1s (21 KB) Attached please find the State witnessed Variance required MIT's for 2D-04 and iG-O1 and State waived 4 year MIT's on DS1E. Let me know if you have any questions about the data. MJ Loveland well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 ~ f ~1 ~ 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: ConocoPhillips Alaska Inc. ~~~' ~(~~~lG FIELD /UNIT /PAD: Kuparuk /KRU / 1 E DATE: 06/25/10 OPERATOR REP: Ives/Mouser - ASRC AOGCC REP: Waived by Bob Noble Packer Depth Pretest Initial 15 Min. 30 Min. Well 1 E-21 Type Inj. W TVD 5,943' Tubing 2,000 2,000 2,000 2,000 Interval 4 P.T.D. 1830020 Type test P Test psi 1500 Casing 1,620 3,000 2,960 2,960 P/F P Notes: OA 80 80 80 80 Well 1E-22 % Type Inj. N ~ TVD ~ 5,955' Tubing 2,250 2,250 2,250 2,250 Interval 4 P.T.D. 1822140 T pe test P Test psi ~ 1500 Casin 740 2,920 ~ 2,880 2,850 ~ P/F P Notes: OA 490 520 520 520 Well 1 E-104 Type Inj. W TVD 3,351' Tubing 900 900 900 900 Interval 4 P.T.D. 2042270 Type test P Test psi 1500 Casin 61 2,000 1,980 1,960 P/F P Notes: 45 Min T/I/O = 900/1960/200 OA 190 200 200 200 Well 1 E-105 Type Inj. N TVD 3,515' Tubing 200 200 200 200 Interval 4 P.T.D. 2050060 Type test P Test psi 1500 Casing 100 2,000 1,940 1,920 P/F P Notes: OA 100 140 140 140 TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 KRU 1E pad 062510.x1s ~~ ~~ Schlumberger-DCS ,a~: 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # /? ,` ~~~ i ~ , ,, _ ,, N0.5035 Company: Alaska Oil & Gas Cons Comm ~ tit y ~ ~r, Attn: Christine Mahnken - ~,: J rY ~ , 333 West 7th Ave, Suite 100 ' '~~'''' `~ Anchorage, AK 99501 Field: Kuparuk Log Description Date BL Color CD 01 /08/09 3F-05 12115003 PRODUCTION "" ' 1E-22 12115008 PROFILE i ~>,3 -- ~~.lc ~ - l c', ~:~ INJECTION PROFILE ~ • 12/20/08 1 1 3F-12 12115008 (~. (, ~ ._~~ ~. ~ INJECTION PROFI " ~~ 12/24/08 1 1 1D-136 12115008 _-„~ -- ~ ~_ . <;~ ~~ LE , ,, <<"- 3 ' -, ./ ~:~ INJECTION PROFIL ' 12/25/08 1 1 3F-O6 3J-02 AZED-00003 12115008 ~ ~ E ,- ~ ;) ~ - - ~~ , - ~ L 1: ~~ PRODUCTION PROFILE j~`j"- r>~<: f<__ -_L .~_~ INJECTION PRO ~ ~- 12/26/08 12/27/08 1 1 1 1 2N-332 12096514 FILE ; ~ ~ ~;~ -: _ / (~.: ?~ ~ -. _ C. Ll - SBHP SURVEY ~ ~ 12/29/08 1 1 2N-323 AZED-00008 ~ .v _ :~< j-"/ i~'/ :_~ SBHP SURVEY ~ ~ '= ' " 12/30/08 1 1 2N-342 12096514 - --- ,~`, r j ~ ,~ /%<'j~ SBHP SURVEY - • ~ --~ 12/30/08 1 1 2N-302 AZED-00007 ~) ~ } .- / ; ~-,•, ~ - r ~~_/ SBHP SURVEY - - 12/30/08 1 1 2P-417 AZED-00012 ; T - ,_~ 1.-. I. > - L. . SBHP SURVEY • ~; - ' ' " 12/30/08 1 2V-03 12115000 ; -. ., ~ . ,; j __ ~_ -s. INJECTION PRO L - - 01/02/09 1 1 iR-13 AYS4-00019 FI E t} ~ - ~% INJECTION PROF ~ ' / ~ • 12/17/08 1 1 1 B-02 AYS4-00020 ILE ; _ i;':. ` - "" /• =) ~-(" ~~ INJECTION PRO ~ ~ 01/03/09 1 1 FILE ~ ~~~:.~ `, j., ,, ._1_=; _ ~-Ca. ~~~ 01/04/09 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. Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 106' .... 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: . '. RECE\VED STATE OF ALASKA APR 2 7 Z007 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIOMSOiI & Gas Cons. Commission ß Abandon 0 Alter Casing 0 Repair Well 0 Pull Tubing 0 Operat. ShutdownO Stimulate 0 Waiver 0 Time Extension Re-enter Suspended Well Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Exploratory 0 Service 0 5. Permit to Drill Number: 182-214 1 ,;' 6. API Number: 50-029-20884-00 -" 9. Well Name and Number: 1 E-22 ' ,AP (.. 1./i" S I ~ i- ?P.ø'/ 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool ' measured 9480' ' feet true vertical 6510' feet measured 9260 feet true vertical 6346 feet Length Size MD 110' 16" 110' 1987' 10-3/4" 2093' 9235' 7" 9341' Plugs (measured) Junk (measured) TVD Burst Collapse 110' 1848' 6406' Measured depth: 8855'-8958'; 9112'-9132' SCANNED MAY 0 2 2007 true vertical depth: 6048'-6123'; 6235'-6250' Tubing (size, grade, and measured depth) 3-1/2" , J-55, 9044' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'FHL' RETR.; BAKER 'FB-1' pkr= 8725'; 9020' SSSV= SSSV SSSV= 2093' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ 8970 ./ 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: OilO Gas 0 WAG 0 GlNJO WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A ifC.O. Exempt: N/A 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 4396 1150 1150 Casin Pressure Tubin Pressure 2046 3035 Daily Report of Well Operations _X Contact WDSPLO Title Phone 659-7535 Form 10-404 Revised 04/2004 RBDMS 8Ft MAYO 2. 2007 AJ7 t/5Þ' 07 Submit Oíiginal~ ..y" . 1 E-22 DESCRIPTION OF WORK COMPLETED SUMMARY . Date Event Summary / 09/05/02ICommenced WAG EOR Injection ,/ MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~K' "tP /,' ¡:'{í C,/I' " j, , 0'-'::./1 ;;:..,' ,c...;.,.... ( .. DATE: Wednesday, June 07, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IE-22 KUPARUK RIV LINIT IE-22 Src: Inspector ;' 'c).. \ \.\ \ct~ FROM: Chuck Scheve Petroleum Inspector Well Name: KUPARUK RIV UNIT 1E-n API Well Number 50-029-20884-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060605140253 Permit Number: 182-214-0 Inspection Date: 6/4/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I !Type Inj. I ~._- I ! ! 1E-22 wi TVD 5955 I IA 1175 2275 i 2250 2250 I , ---+ i I ! P.T. ! 1822140 iTypeTest I SPT I Test psi 1500 i OA I 200 ,j 200 ¡ 200 r 200 I Tubing i , t- 1650 1650 ! 1650 I 1650 Interval 4YRTST P/F P I I Notes Pretest pressures were observed and found stable, Well demonstrated good mechanical integriy NON-CONFIDENTIAL Reviewed By: P.l. Suprv ~~ Comm ¡)CÅ-~NEJ) JUN ,.-' 0, ~)nn}~ J.. :¡} L.'"," "",., Wednesday, June 07, 2006 Page 1 of 1 ~RCO Alas~, Inc, ~ ~ ~UPARUK RIVER UNI~ ' '= ~ ._~~ ~._:LL SERVICE REPORT ~ Kl(1E-22(W~S)) · WELL ' ~ JOG SCOPJ= " ' JOB NUMBER 1E-22 J' OTHER WELL MAINTENANCE 0306981823.3 DALLY WORK" UNiT NUMBER 03/09/98 SERVICE SSSV. PULL CHOKE, PiT TUBULARS 70175 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 (~) Yes O Noi (~).Yes O No HES-FELL SMITH , -FIELD AFC# CC# DAILY ~OST ACCUM COST Signed ..... ESTIMATE KAWWRK 230DS10EL $5,572 $5,572, Initial Tbs pres~' Final TbS' Press I'~ifial Inner Ann Final' Inner Ann I Initial Gu{er Ann I o.~r Ann' 2000 PS! 1500 PSI 2~0 ~S! 20~ PSiI 3~ PSII 300 PSI DAILY SUMMARY PULLED CHOKE @ 9038' RKB, TAGGED FILL @ 9172' RKB, 40' OF RAT HOLE BELOW BOTTOM PERFORATION O 9132' RKB, GOOD PRESSURE TEST ON TUBING AND 7" ANNULUS. ~ TIME 07:00 07:20 07:50 08:20 08:45 09:00 09:30 LOG ENTRY 09:45 ON LOCATION, TGSM: DESIGNATE MUSTER AREA, SWAB VALVE LEAKING, WELL HOUSE DOORS STUCK. MIRU HES AND APC PUMP TRUCK 1,875" STANDARD TOOLSTRING. Prr LINES AND LUBR. TO 2500 PSI, BEGIN PUMPING 20 BBLS DIESEL. SSSV CONTROL LINE @ 2000 PSI, TIED INTO CONTROL LINE, ATTEMPTED TO PUMP UP TO 5000 PSI. WILL NOT HOLD PRESSURE, KEEPS BLEEDING DOWN. BLEED CONTROL LINE DOWN TO 0 PSI HOLDING GOOD, NO INDICATION OF GAS IN CONTROL LINE. ATI'EMPTED CLOSURE TEST ON SSSV. DUMPED CONTROL LINE, TUBING WOULD NOT BLEED DOWN INDICAT FLAPPER WOULD NOT CLOSE. RIH W/3.5" FRICTION TOOL 58" NOGO TO KEYS, TO SSSV @ 20§8' WLM (2093' RKB) COULD NOT GET FLOW TUBE TO MOVE. SHEARED FRICTION TOOL, POOH A-FFEMPTED CLOSURE TEST, FLAPPER WOULD NOT CLOSE. RIH W/RE-PINNED FRICTION TOOL, RIH TO $SSV @ 2070' WLM (2093' RKB) COULD NOT GET FLOW TUBE TO MOVE, SHEARED FRICTION TOOL. POOH 10:00 ATTEMPTED CLOSURE TEST, WOULD NOT CLOSE, 10:20 RIG DOWN APC PUMP TRUCK, STAND BY FOR HOT OIL PUMP TRUCK. 10:50 11:30 12:OO 12:30 12:40 12:50 13:00 HOT OIL ON LOCATION MIRU, P/T TO 2500 PSI, BEGIN PUMPING 40 BBLS HOT DIESEL. RIH W/3.5" FRICTION TOOL TO 2070' WLM (2093' RKE), DID NOT SEE ANY FLOW TUBE MOVEMENT, SHEARED FRICTION TOOL POOH, CALL "Y" PAD TO VERIFY VALVE IS TRDP-1AENC AND CORRECT SPACING ON FRICTION TOOL_ VALVE CHECKED OUT TO BE TRDP-1AENC, SPACING CORRECT ON FRICTION TOOI~ RIH SAME FRICTION TOOL ASSY (3 STEEL PINS), SHEARED FRICTION TOOL, FLOW TUBE MAY HAVE MOVED UP. ATTEMPTED CLOSURE TEST, DUMPED CONTROL LINE, BLED TUBING DONE FROM 1500 PSI TO 500 PSI, MONITOR FOR 10 MIN. TUBING PRESSURE CLIMBING, UP FROM 500 PSI TO 1100 PSI, CHECK OUT TREE VALVES. SUSPECT WING VALVE IS LEAKING, 1100 PSI ON FLOWLINE ALSO, BLOCK IN PIT VALVE. BLEED TUBING PRESSURE DOWN TO 0 PSI AGAIN MONITOR FOR 10 MIN FOR CLOSURE TEST. GOOD CLOSURE TEST, REPRESSURE CONTROL LINE, HOT OIL ASSISTING TO OPEN SSSV, GOOD HYDRAULI( MOVEMENT ON CONTROL LINE. 13:05 CONTROL LINE STILL WILL NOT MAINTAIN PRESSURE, CONFER WITH WELLS GROUP SUPERVISOR. 13:30 RiG SSSV BACK UP TO PANEL & USE ENERPAC PUMP TO SUPPLY ACCUMULATOR. 13:45 RIH W! 3" GR TO PULL CR LOCK & CHOKE @ 9006' WLM (9038' RKB) POOH W/LOCK & CHOKE sERvicE COMPANY'- SERVICE .... DAILY COST ACCUM TOTAL ,, $463.00 $4.83.00 APC $700,00 $700.00 HALLIBU'RTOh ,., "' ..., $2,749;8g " ,$2,749.8~' . LI-i-rLE RED $1,040.00 $1,640,00 TOTAL I~'IELD ESTIMATE '' "$S,572.$9' $5~572.89 ARCO SUR. CASING (0-2093, OD:10.750, Wt:45.50) Alaska, Inc. SBR (8699-8700, OD:3.500) PKR (8725-8726, 0D:6.156) PKR (9020-9021, 0D:6.156) NO GO (9O38-9O39, 0D:3.500) TUBING (o-9044, 0D:3.500, ID:2.992) Perf (9112-9132) KRu 1 E-22 ! E.22 APl: 500292088400 SSSV Type: Camco Annular Fluid:I'TRDP-1A-ENC' Reference Log: Last Taq:19172 13/9/98 Last Tag Date: ca~ing string - CONDUCTOR Size I Top I Bottom 16.000 0 110 casing!string - SURFACE i Size I Top I Bottom 10.750 0 2093 well TYpe: INJ Odg Compltn: 11/11/83 I Last W/O:112/20/84 I Ref Log Date:I TD: 19480 ftKB Max Hole Angle:J60 deg @ 4300 Angle @ TS:J44 deg @ 8852 Angle @ TD:J42 deg @ 9480 I Rev Reason: PULLED CHOKE/TAGGED I FILL by vg Last Update: 13/11/98 TVD Wt Grade 110 65.00 H-40 TVD 1848 casing:sl~ring - PRODUCTION i Size I Top I Bottom TVD 7.000 o 9341 64O6 TUbing.String - TUBING. Size I Top I Bottom TVD 3.500 0 9044 6185 perfOratiOns summary ~ :. : Interval I TVD / Zone |StatuslFeetlSPFI Date ! Type 8855-8958I 6048-6123 ~,C-3,C-2,q I 103] 811/10/83J !9112-9132 6235-6250 / A-5 / I 201 811/10/83i Thread Wt Grade Thread 45.5o K-55 Wt Grade Thread 26.oo K-55 Wt Grade Thread 9.20 J-55 BTC-MOD IPC Comment Ga~ Lift! Mandrels~alve~ :. Stn MD 'DVD' Man I Man I I Mfr Type I I 21651 18981 Camco I 31/2X1 I I I [ KBUG 2] 50921 36221 Camco I 31/2X1 IKBUG 3 I 65741 44811 Camco I 31/2Xl I I / j KBUG 4 I 80021 5418l Camco I 31/2Xl I I I IKBUG 5 / 86571 59°61 Camco I 3 1/2X 1 ~ I I I KBUG prOdUction Mandrels~alves V Mfr VType V OD Latch Port TRO Date VIv I I I ]Run IComment DV I 1.0 BE 0.000 0 10/24/95 DV 1.0 BK 0.000 0 6/13/93I DV 1.0 BK 0.000 0r 6/13/93I DV 1.0 BK 0.0001 01 10/24/97j Stn MD TVD Man Man I VMfrI Mfr Type I 6 8762 5981 Camco 3 1/2X 1 7 8827 6028 Camco 3 1/2X 1 KBUG 8 8983 6141 Camco 3 1/2X 1 I I I I KBUG I I Other(Plugs, equiP,:et, i:) -:JEWELRY Depth TVDI Type 20931 1648i SSSV Camco TRDP-1A-ENC 86991 5936 J SBR Baker 'ELA' 87251 59551 PKR Baker 'FHL' RETR. 90201 61681 PKR Baker 'FB-I' 90381. 6181 I NO GO Camco 'D' Nipple 90431 61851 SHEAROUT Camco 90441 61851 TUBINGTAIL V Type ! V OD DV i 1.0 DV ! 1.0 DV 1.0 Latch Port TRO Date Vlv i Run Comment! BK 0.O60 0 12/20/84 ICI°sad I BK IO.OOO 0 412/86 [Closed BK o.ooo o[ 2/23/94 ICIosed Description ID 2.813 2.813 2.891 4.000 2.750 2.992 2.992 STATE OF ALASKA ALASff,/-~ OIL AND GAS CONSERVATION COMMIo~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Pedormed: Operation Shutdown__ Stimulate Pull tubing Alter casing Repair well Plugging__ Change Approved Program X Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 291' FSL, 225' FEL, Sec. 16, T11 N, R10E, UM At top of productive interval 1395' FSL, 1383' FEL, Sec. 22, T11N, R10E, UM At effective depth 1128' FSL, 1314' FEL, Sec. 22, T11 N, R10E, UM At total depth 986' FSL, 1278' FEL, Sec. 22, T11N, R10E, UM 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X Datum elevation (DF or KB) RKB 106 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 E-22 9. Permit number/approval number 82-214/398-179 10. APl number 50-029-20884 11. Field/Pool Kuparuk River Oil Field/Pool 12. Present well condition summary Total Depth: measured 9480 feet Plugs (measured) None true vertical 6508 feet Effective depth: measured 9260 feet true vertical 6344 feet Junk (measured) None Casing Length Size Cemented Measured depth Structural Conductor 80' 16" 266 Sx AS II 80' Surface 2415' 10 3/4" 1500 Sx AS III & 2449' True vertical depth 80' 2091' Intermediate 250 Sx AS I Production 9309' 7" 725 Sx Class G & 9341' Liner 250 Sx AS I Perforation depth: measured 8855'-8958', 9112'-9132' true vertical 6046'-6121 ', 6160'-6175' Tubing (size, grade, and measured depth) 3.5", 9.2#/ft., J-55 w/tail @ @ 9044' Packers and SSSV (type and measured depth) PKR: Baker FHL @ 8725' & Baker FB-1 @ 9020'; SSSV: CAMCO TRDP-1AENC @ 2093' 6404' 13. Stimulation or cement squeeze summary Conversion from producer to injector Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 200 3000 0 1300 0 0 1200 2200 Tubing Pressure 225 2660 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10- Title Wells Tech RECEIVED JAN 08 1999 SUBMIT IN DUPLICATE Oil & {3as Cons. Comml lon Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Alter casing w Change approved program X 2. Name of Operator: ARCO Alaska, Inc. Abandon _ Suspend __ Operation Shutdown __ Reenter suspended well__ Repair well w Plugging _ Time extension __ Stimulate __ Pull tubinq __ Vadance __ Perforate Other __ 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development X~ Exploratory ~ Stratagrapic ~ Service .__=. 6. Datum of elavation (DF or KB feet): I O6' RKB 7. Unit or Property: Kuparuk River Unit 8. Well number: 1 E-22 9. Permit number: 82-0214 10. APl number: 50-029-20884-00 4. Location of well at surface: 291' FSL, 225' FEL, Sec 16, T11 N, R10E, UM At top of productive interval: 1395' FSL, 1383' FEL, Sec 22, T11N, R10E, UM At effective depth: 1128' FSL, 1314' FEL, Sec 22, T11 N, R10E, UM At total depth: 986' FSL, 1278' FEL, Sec 22, T11 N. RIOE, UM 12. Present well condition summary 11. Field/Pooh Kuparuk River Field/Pool Total Depth: measured true vertical 9480 feet Plugs (measured) 6508 feet Effective Depth: measured true vertical 9260 feet Junk (measured) 6344 feet Casing Length Size Conductor 11 O' 16" Surface 2093' 10-3/4" Production 9341' 7" Liner Cemented Measured depth True vertical depth 266 sx AS II 11 O' 11 O' 1500sx AS III 2093' 1848 725 sx Class G & 9341' 6406 250 sx AS I Perforation Depth measured 8855'-8958', 9112'-9132' true vertical 6048'-6123', 6235'-6250' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, j-55, IPC Tubing @ 9044' MD. Packers and SSSV (type and measured depth) Baker FHL Packer @ 8725' MD; Baker FB-1 Packer @ 9022' MD; 3-1/2", Camco TRDP SSSV @ 2093' MD. 13. Attachments Description summary of proposal _X Detailed operations program 14. Estimated date for commencing operation Convert Oil Producer to WI- July, 1998 16. If proposal was verbally approved Name of approver Date approved BOP sketch_ 15, Status of well classification as: Oil _X Gas. __ I Service 17, I hereby certify that the forgoing is true and correct to the best of my knowledge. Suspended Signed .[,-~ ,,~"~ '~L'~¢/~-~OR COMMISSIoNTitle: Wells SuperindendentusE ONLY Conditions of approval: Notify Comission so representitive may witness Plug integrety_ BOP test Location clearance Mechanical integrety test .~ Approved by order of tb~(~ssioner Form 10-403 R~)~3e6hl'~/'~8 (~ Subse~quent form required 1 O- David W. Johnston Commissioner Date JApproval No. ~(~__ { ~ ? Date Attachment 1 Conversion to Water Injection Kuparuk Well 1 E-22 ARCO Alaska requests approval to convert Well 1E~22 from an oil producer to a water injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order No. 2. Water will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 6048' and 6250'. This interval correlates with the strata found in ARCO's West Sak River State Well No. I between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. ARCO Alaska, Inc. Post Office BOx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 29, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION 1E-22 Stimulate 1 H-17 Stimulate 1 H-19 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Sr. Engineer Kuparuk Petroleum Engineering RECEIVED OCT - 1 ')993 Alaska Oil & Gas Cons. Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-6003-C STATE OF ALASKA ALA,~KA OIL AND ~ CONSERVATION ~MI~:~ION 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 5. Type of Well: 6. Datum elevation (DF or KB) ' Development _~_ ARCO Alaska. Inc. Exploratory _ RKB 106 feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service Kuparuk River Unit 4. Location of well at surface 8. Well number 291' FSL, 225' FEL, Sec. 16, T11N, R10E, UM 1E-22 At top of productive interval 9. Permit number/approval number 1395' FSL, 1383' FEL, Sec. 22, T11N, R10E, UM 82-214 At effective depth 10. APl number 1128' FSL, 1314' FEL, Sec. 22, T11N, R10E, UM so-029-20884 At total depth 11. Field/Pool 986' FSL~ 1278' FEL~ Sec. 22~ T11N, R10EI UM Kuparuk River Oil Field/Pool 112. Present well condition summary Total Depth: measured 9 4 8 0 feet Plugs (measured) Nol3e true vertical 6508 feet Effective depth' measured 9 2 6 0 feet Junk (measured) None true vertical 6344 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' 1 6" 266 Sx AS II 8 0' 8 0' Surface 2415' 10 3/4" 1500 Sx AS III & 2449' 2091' Intermediate 250 Sx AS I Production 93 09' 7" 725 Sx Class G & 9 3 41' 6 4 04' Liner250sx ^s, R E ¢ E IV E D Perforation depth: measured 8855'-8958', 9112'-9132' true vertical 0CT - 1 199; 6046'-.61 21 ', 61 60'-61 75' Tubing (size, grade, and measured depth) ~.~a 0~t & GaS Cons. Commission 3.5", 9.2#/ft., J-55 w/ tail @ @ 9044' Anchorage Packers and SSSV (type and measured depth) PKR: Baker FHL @ 8725' & Baker FB-1 @ 9020'; SSSV: CAMCO TRDP-1AENC ~ 2093' 13. Stimulation or cement squeeze summary Refractured "A" sands on 6/17/93. Intervals treated (measured) 91 12'-9132' Treatment description including volumes used and final pressure Pumped 128 Mlbs of 16/20 & 12/18 ceramic proppant into formation~ fl:) was 5930 psi. 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 150 ~ 125 0 1300 225 Subsequent to operation 200 ~ 3000 0 1300 225 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil X Gas Suspended Service 17. I hereby,,.qertify that_the foregoing is true and correct to the best of my knowledge. Si~lned .~ Title Senior Engineer Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. O Subsidiary of Atlantic Richfield Company WELL DESCRIPYiON OF WORK ! E-22 "A" SAND REFRACTURE DATE 6/17/93 DAY 1 TIME 0700 0915 0925 0950 CONTRACTOR / KEY PERSON DOWE;.L GALLEGAS PBTD (RKB) ILAST TAG (RKB) - DATE 9260' ! 9148' 6-12-93 KUPARUK RIVER UNIT WELL SERVICE REPORT IAFC/CC# - SCA# [ 998093 [FIELD COST EST. [ACCUMULATED COST I $126,827 I $134,407 ISSSV TYPE / STATUS ICAMCO TRDP 1AENC OPEN LOG ENTRY MIRU DOWELL FRACTURE EQUIPMENT, VECO PUMP TRUCK. SURFACE IRON PRIMED AND PRESSURE TESTED TO 8800 PSI. HOLD SAFETY MTG W/ALL PERSONNEL, MATERIAL QC COMPLETE. PUMPED STIMULATION AS FOLLOWS: Pig.-1125, BBLS WF-20 @25-34 BPM 6400-5900 PSI 7" ANN. @ 3435 PI#-2 25 BBLS WF-20 @ 25 BPM 5050-4800 PSI. KUPA PI#-350 BBLS WF-20 @ 25 BPM FG = .80 CP = 4940 DF 143BBLS YF-140D 25BPM NO PROP 4897-5600 PSI BD 81 BBLS NXL-GW 25 BPM NO PROP 5600-4810 PSI S/DFORISIP=2489 FE=39% FG=.83 CP=4940 ~RUK PETRC)t F~ ~u c~,NE~iNG ,4780-4769 PSI. ~ PAD 215BBLS DXL-GW 25BPM 1PPA 95BBLS DXL-GW 25BPM 16/20 2PPA 71BBLS DXL-GW 25BPM 16/20 4PPA 71BBLS DXL-GW 25BPM 12/18 6PPA' 71 BBLS DXL-GW 25 BPM 12/18 8PPA 91BBLS DXL-GW 25BPM 12/18 10PPA 158 BBLS DXL-GW 25 BPM 12/18 FLUSH 20BBLS DXL-GW 23 BPM FLUSH 12BBLS NXL-GW -15BPM FLUSH 44 BBLS SLK-DS 10 BPM NO-PROP 4522-5600 PSI 5475-5200 5050-5030 PSI 5060-5160 PSI 5280-5550 PSI 5854-5850 PSI 5923-5930 PSI 6050 PSI 4320 PSI S/D FOR POST FRAC CALCS. 3850 PSI i330 CHECK THIS BLOCK IF SUMMARY IS CONTINUED ON BACK RECEIVED OCT - ! 1993 Anchorage LOAD TO RECOVER: 1210 BBLS, TOTAL PROP PUMPED: 129913# EFFE~ PROP: 127780~, PROP IN CSG: 2133# BLED 7" ANN TO 500 PSI, SECURE WELL, RD AND RELEASE DOWELL COMPL~-~E INCOMPLETE Attachment Page 2 · Drill Site 1H Wel 1 No. ~.-3 ~1H-4 ~.~. ~lH-6 ~1H-7 ~lH-8 Log Date 8/16/82 8/13/82 6/21/82 7/20/82 7/22/82 .. Drill Site Well No. Log Date 1E 1E-lA %8/19/81 1E-2 ~8/17/81'- 1E-3 "i0/18/81~, '-11/7/81/ .. '~8/4/80% _~ 1E-4~,[~.1 ~]E-7 ~/g8/8]~ ]E-8 ~8/28/8Z~ ]E-~5 ~/~6/8g 1E-16 ~/29/82 1E-17 ~9/1/82 1E-20 ~5/7/83 .1E-24 ~/17/83 1E-25 ~1/17/83 1E-26 ~1/13/83 1E-27 ~0/31/82 1E-28 ~10/27/82 ~ ~6/13/83 ~E-2g ~]0/]8/8~ ~7/]8/83 / 1E-30 ~0/16/82 Drill Site 1G Wel 1 No. '%lG-1 '~1G-2 "~1G-3 ~1G-4 % 1G-8 .Log Date 9/7/82 - 9/25/8~ 9/28/82 12/8/84/ 10/13/82 11/12/82 3/12/83 1/22/83 Dri 11 Si te Wel 1 No. Log Date 1F '~IF-1 2/19/83 %1F-2 2/3/83 ~1F-3 1/31/83 '~1F-4 5/29/83 ~1F-5 · 10/25/82 '~1F-6 10/28/82' '~ 1F-7 11/19/82x,~ ~ 5/7/83/2 ~/~% RECEiV "/, FEB 21 1986 Alaska 011 & Gas Cons. Commission Anchorage £ ARCO Alaska, Ir Post Office dox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 1, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Co.rnmission 3001 Porcupine Drive Anchorage, AK 99501 Oear Mr. Chatterton- Attached in duplicate are' subsequent notices following wells at the Kuparuk River Field' on Wel ! Action Date Performed 1E-6 Fracture 1/26/85 1E-7 Reper f 1E-7 Fracture 3/1/85 1E-8 Reper f 1/28/85 1E-11 Reper f 2 / 1 / 85 1E-11 Fracture 2/7/85 1E-1 8 Fracture 3 / 1 3 / 85 1E-20 Stress Frac 3/19/85 1E-20 Fracture 3 / 23 / 85 1E-22 Fracture 3 / 22 / 85 1 E-24 Fracture 3 / 22 / 85 1L-6 Fracture 2/2/85 1L-7 Fracture 1/30/85 1Q-9 Fracture 3/1 8/85 1Q-1 0 Fracture 3 / 5 / 85 1Q-12 Fracture 3/5/85 2A-3 Conversion 3/21/85 2A-4 Conversion 3/12/85 2A-5 Convers i on 3 / 12 / 85 2A-6 Conver s i on 3 / 12 / 85 2A-7 Conve rs ion 3/12/85 2C-4 Reper f 2 / 23 / 85 2D-4 Reper f 2 / 2 / 85 2V-8A Convers i op~ 2X-8 Per forat ion 1/27/85 If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) the ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichlieldCompany STATE OF ALASKA ALASKA uIL AND GAS CONSERVATION CU,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [~ OTHER [] 2. Name of Operator ARCO ALASKA, ]]NC. 3. Address P. O. BOX 360, ANCHORAGE, ALASKA 99510 UNIT 4. Location of Well SURFACE LOCATION' 291' FSL, 225' FEL, SEC. 16, T11N, RIOE, UM BOTT.OM HOLE LOCATION' 986' FSL, 1278' FEL SEC. 22, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 106' (RKB) 12. 6. Lease Designation and Serial No. ADL 25651, ALK 7. Permit No. 82-214 8. APl Number 5o- 029-208884 9. Unit or Lease Name KUPARUK RIVER 10. Well Number 1E-22 11, Field and Pool KUPARUK RIVER KUPARUK RIVER 469 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data FIELD OIL NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [~ Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On March 22, 1985, the "A" sands of Kuparuk well 1E-22 were hydraulically fractured and propped to improve production. treatment consisted of 295 BBLS of gelled water as pad and fluid and 13,230 LBS of 20/40 sand as proppant. 34 BBLS of diesel was used as a flush. The carrying gelled Prior to pumping, equipment and lines were tested to 6030 psi. 14.1 hereby certify that the foregoing is true and correct to the best of mY ~nL~l~dF~e~ Signed . - ~ Title 0 P E R A T I 0 N S The space below for Commission use COORDINATOR 3/27/85 Conditions of Approval, if any: By .Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. · Pos! Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 21, 1985 Mr. C. V. Chatte Alaska Oil and G 3001 Porcupine D Anchorage, AK rton, Chairman as Conservation rive 99501 Commi ssi on Dear Mr. Chatterton- Attached are our notices of intention following Kuparuk Field wells' 1E-22 and 1E-24 If you have any questions, please call me to fracture the at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) RECEIVED Anchorag~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION CO,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL []( OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 82-214 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 99510 5o- 029-208884 4. Location of Well SURFACE LOCATION' 291' FSL, 225' FEL, SEC. 16, T11N, RIOE, UM BOTTOM HOLE LOCATION' 986' FSL, 1278' FEL SEC. 22, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106' (RKB) I ADI 25651, ALK 469 12. 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1E-22 1 1. Field and Pool KUPARUK KUPARUK P001 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data RIVER FIELD RIVER OIL NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [~ Abandon [] Stimulation ['. Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is propos hydraulicall treatment us sand as the Lines and eq starting job ed that the "A" sand in Kuparuk well 1E-22 be y fractured and propped to improve production. The es gelled water as the pad and carrying fluid and 20/40 proppant. Diesel will be used as a flush. uipment will be pressure tested to 5000 psi prior to Pre-post Fluid' Proppant' frac logs are included in Gelled Water 335 BBLS Gelled Diesel 31 BBLS 20/40 sand 13,230 LBS the treatment program. RECEIVED ANTICIPATED START DATE. March 21, 1985 Alaska 0il & Gas Cons. Commission $'ut~e~t~.e.~t ¢,;o~k 1-te~o~-~ed Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed. /~~~'/~/~~ Title KUPARUK The space below for Commission use 0 P E RAT I 0 N S COORDINATOR Date 3/21/85 Conditions of Approval, if any: Approved by IRIIIIIIIU BT [ON,~IE C. SMITII. Approved Returrt~d By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, inc. Post Office Box 100360 Anchorage, Alaska 99510 TelephOne 907 276 1215 February 7, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT. Well Completion Reports Dear Mr. Chatterton. Enclosed are the Well Completion Reports and Workover Well Histories for the following wells- 1E-20 1E¥2-2~ 1E-24 If you have any questions, please call me at 263-4944. Sincerely, Associate Engineer JG/tw GRU4/L135 Enclosures RECEIVED F E B 0 8 IBB§ Alaska Oil & Gas Cons. Commisslon Anchorage STATE OF ALASKA ALASKA ~,,-L AND GAS CONSERVATION CO .... vllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-214 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20884 -- 4. Location of well at surface 9. Unit or Lease Name 291' FSL, 225' FEL, Sec.16, TllN, R10E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1395' FSL, 1383' FEL, Sec.22, TllN, R10E, UM 1E-22 At Total Depth 11. Field and Pool 986' FSL, 1278' FEL, Sec.22, TllN, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool 106' RKB ADL 25651, ALK 469 12. Date Spudded i3. DateT.D. Reached 14. Date Comp.,Susp. orAband. 15. Water Depth, if offshore [16. Ne. of Completions 1 2/26/82 01/05/83 01/10/83 N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set J 21. Thickness of Permafrost 9480'MD,GS08'TVD 9260'MD,6344'TVD YES [] NO [] 2093 feet MD} 1450' (Approx) 22. Type Electric or Other Logs Run D I L/SFL/SP/CR/Cal/FDC/CNL, CBL 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 80' 24" 266 sx AS II 10-3/4" 45.5# K-55 Surf 2449' 13-1/2" 1500 sx AS III & 250 s~ AS I 7" 26.0# K-55 Surf 9341' 8-3/4" 725 sx Class G & 250 s~ AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and .number) SIZE - DEPTH SET (MD) PACKER SET (MD) 9112' - 9132 3-1/2" 9044' 8725' 8855' - 8958' 8 spf, 120° phasing 26, ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 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 IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.l~ 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 R£C£1v£b Form 10-407 GRU3/WC31 Anchorage ~u~f~l~plicate 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 8853' 6044' N/A Base Upper Sand 8960' 611 2' Top Lower Sand 9092' 6219' Base Lower Sand 9223' 6316' I 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge (~~~L~L~-)~ Title Ass°clare Engineer Date Signed 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 (G L) 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 ARCO Oil and Gas Company Daily Well History-Final Report Insll'UCtione: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test ~S not required upon completion, report completion and_representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation ir space is avadable. Accounting cost center code t County or Parish Lease or Unil Kuparuk River ADL 25651 Auth. or W.O. no. ~Tille AFE Cap 304981/Exp 304972I Recompletion Oistrict Alaska Field State North Slope Borough Alaska Well no. 1E-22 W/O Westward 1 API Operator ARCo. W.I. ARCO Alaska, Inc. 56.24% Spudded or W O. begun Workover Date and depth as of 8:00 a.m. I ") //~'/ lO/. 12/08/84 thru 12/10/84 12/11/84 Complete Date 11/18/84 record for each day reported 7" @ 9341' 9260 11.5 POOH TIH, 7" @ 9260 11.5 Iotal number of wells (active or inactive) on this i pst center prior to plugging and ~ bandonment of this well I OUr I Prior status if a W.O. I 2100 hrs ' PBTD, 9480' TD, POOH w/FHL pkr NaC1/NaBr w/tbg string, repl colrs w/modified. rtl pkr. POOH w/pkr. 9341' ' PBTD, FB-1Pkr Top @ 9003', Rn compl string NaC1/NaBr PU Bkr releasing tl, POH, LD FHL Pkr. PU BP, TIH to 8800', set BP & tst csg to 1500 psi; OK, POOH. ND BOPE, NU 7", 5000# Gan III tbg spool. NU & tst BOPE to 5000 psi, tst csg to 3000 psi; OK. TIH, retrv Bkr BP, POOH. PU bit, TIH, wsh & rm f/9150'-9250' WWS RKB, circ@ 9260' PBTD, POOH. Rn 6.125" gage ring/JB to 9200', pull into tight spot @ 5900', pulled off of tl, left in hole. RIH w/10' 3-3/8" blank perf gun, chase fsh to 9238' WLM, POH. RIH w/6.125" gage ring/JB to 9100', POH. RIH w/Bkr FB-1WL set pkr & set @ 9003'. RU to rn compl string. 7" @ 9341' 9260' PBTD, FB-1Pkr Top @ 9003', RR Crude oil Rn compl string. MU SSSV, Cst contrl in to 5000 psi. Drop ball, space out, lnd tbg, shear SBR. Relnd tbg, inscl BPV. ND BOPE, NU & tst tree to 5000 psi. Tst ann to 2500 psi. Displ well w/30 bbl diesel & 315 bbls crude oil. Tst orifice to 2000 psi. Close SSSV & tst. Shear out ball w/4600 psi. Set BPV. RR @ 2300 hrs, 12/10/84. TT @ 9044', FB-i Pkr @ 9020', FHL Pkr @ 8725', SSSV @ 2093', "D" Nipple @ 9038' Old TD New TO PB Depth 9260' PBTD Released rig Date K nd of r g 2300 hfs 12/10/84 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Pr°ducti°rr~ ~" ~ i.,,, · ,, .. Oil on tesJ~lk E [ I~'sj~e~,~Y,E J~ Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable ' ~ ~ ~lf~iv~ corrected .... ~ UJl & Ga~ Cons. C0mmjs~10n ~e above is correct Signature For form properetion ad distribution, see Procedures Manuel. Section 10, Drilling. Pages 86 and 87. Oate IT(tie 12/19/84 Drilling Superintendent ARCO'Oil and Gas Company Well History - Initial Report - Dally II~.~'l~liml~: Pmpm~ end submit the "lfllU~l R~rt" on the first Wednesday alter · well is spudded or workover oper'tions ere starled. D,.lly wo~ prior to sPUdding ~hould be summarized on the form giving inclusive detes only. Olstd~ Alaska ~eld Kuparuk River Auth, or W.O. nc. AFE Cap 304981/Exp 304972 I~unW. ~ or ~ro~h North Slope Borough ilo--* ADL 25651 Unit Title Recompletion JState Alaska IWell no. 1E-22 W/O Westward 1 API Operator mARco W.,. 56.24% Prior status if a W.O. ARCO Alaska, Inc. Spudded o, w.o. begun ID-- IHou. Workover 11/18/84 2100 Hrs. Date and depth Complete record for each day reported as of 8:00 a.m. 11/19/84 11/20/84 11/21/84 11/22/84 thru 12101184 12/05/84 12/06/84 The above is correct Signature For form preperetlon anj~dl~tributlon, ~ee Procedures ManuaJ,~ectlon 10, Drilling, Pages 8~ and 87. 7" @ 9341 9260' PBTD, Chipping ice w/Camco Move to 1E-22. Rig accepted @ 2100 hrs, 11/18/84. Pulled BPV. Could not get below 508', Started in hole to pull dummy valve. POH. RIH w/ice chipper. Chip ice. 7" @ 9341' 9260' PBTD, Chipping ice w/Camco Work ice chipper from 509' to 606' Released Rig 7" @ 9341 9260' PBTD, RR RD Camco. Set FMC BPV, secured tree, RD celler. @ 0800 hrs, 11/20/84. 9260' PBDT Well secured Rig-up CTU. Test BOPE to 3000 psi. Pull BPV. Start in hole, tag ice plug 29'. Pump 2 bbls hot diesel, drop thru ice plug. TIH to 1820'. Circ tbg vol w/hot Nacl 80°, displace tbg w/hot diesel 140°, TOH w/CT, secure well. RU S/L. Rn 1-1/2" OD tls to 2120'. Rn 2.75" gage ring to 2120'. Bullhead 1 drum methanol dn tree. Rn & set FMC BPV on WL. Secure well. Wait on W/O rig. 7" @ 9341' 9260' PBD, 9480' TD, Circ out thru choke manifold 11.5 NaC1/NaBr Accept rig @ 2030 hfs, 12/4/84. Pull BPV. Pull dummy vlv @ 8679'. Bullhead 42 bbls BridgeSal pill into perfs, circ out well. Pull BPV. Pull 7" @ 9341' 9260' PBD, 9480' TD, POOH w/tbg string 11.5 NaC1/NaBr Set BPV, ND tree, NU BOPE &tst to 3000 psi. tbg hgr, POOH chg'g all colrs w/Mod BTC. IDem ] ~tle 1/31/85 RECEIVED FEB 0 8 1985 atas}ac~i~d&f~s Cons. Commission o/~ Anchorage Drilling Superintendent ARCO Alaska, Inc. ~ Post Office Bo,, 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 2, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Subsequent Sundry Reports - Various Wells Dear Mr. Chatterton- Enclosed are Subsequent Sundry Reports for the following wells- 1E-22 1E-25 2F-10 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU3/L26 Enclosures RECEIVED j 0 1985 Naska 0il & Gas Oorts. 6or,~mission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA tP~L AND GAS CONSERVATION CGMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 291' FSL, 225' FEL, Sec.16, T11N, RIOE, UM 7. Permit No. 82-214 8. APl Number 50-- 029-20884 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1E-22 5. Elevation in feet (indicate KB, DF, etc.) 106' RKB 12. I 6. Lease Designation and Serial No. ADL 25651 ALK 469 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other '~---- Pull Tubing [] Other [] Pulling Tubing ~]- (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig ~ 2030 hfs, 12/04/84. Pulled BPV. Killed well. Set BPV. ND tree. NU BOPE & tstd to 3000 psi - ok. Pulled tubing hanger. Pulled 3-1/2" tubing. Retrieved pkr. TIH & set retrievable bridge plug ~ 1700'; tstd csg to 1500 psi - ok. Set bridge plug ~ 8800' & tstd csg to 1500 psi - ok. Retrieved bridge plug. RIH & set FB-1 pkr @ 9003'. Ran 3-1/2" completion assy w/tail ~ 9044', FHL pkr @ 8725' & SSSV @ 2093'. Dropped ball & set pkr. ND BOPE. NU tree & tstd to 5000 psi - ok. Disp well w/diesel and crude oil. Set BPV. Secured well & released rig @ 2300 hrs, 12/10/84. RECEIVED ',ki 0 9 ]985 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~t',_, (~~ ,~~t_~' Title A ssoci ate Encji neet /i The space beloW/for Commission use L! Conditions of Approval, if any: Approved by Form 10-403 GRU3/SN09 By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate I:l~v 7-1-RQ and "Subsequent Reports" in Duplicate ARCO Alaska, Ir"-" Post Offic,.~ciox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 26, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 1E-22 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. We propose to convert 1E-22 to a selective single completion. Since we expect to start this work on November 1, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, (~r~eaB.~n/~. ~/~y_x~_O~g Engi noel JBK/JG/tw GRU2/L43 Enclosures RECEIVED ~tas~a Oil &AGas Cons. Cornr~ission ~nChorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION GOMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELLx~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 291' FSL, 225' FEL, Sec.16, T11N, R10E, UH 5. Elevation in feet (indicate KB, DF, etc.) RKB 106' 12. 7. Permit No. 82-214 8. APl Number 50-- 029-20884 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1E-22 11. Field and Pool Kuparuk River Field I 6. Lease Designation and Serial No. Kuparuk River 0il Pool ADL 25651 ALK 469 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' Perforate Stimulate Repair Well (Submit in Triplicate) (Submit in Duplicate) [] Alter Casing [] Perforations [] Altering Casing [] Abandon [] Stimulation [] Abandonment [] [] Change Plans [] Repairs Made [] Other [] Pull Tubing ~--~ Other ,~_~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee20 AAC 25.105-170). ARCO Alaska, Inc., proposes to convert well 1E-22 to a selective single completion. follows: The procedure will be as 1. Well will be killed with brine. Weight to be determined after running pressure bomb. 2. Current completion assembly will be pulled. 3. A retrievable packer will be run to test for zone isolation between the A and C sand, and to test casing integrity. A squeeze will be performed, if required. 4. The well will be completed as a selective single and 5000# wellhead equipment will be installed. 5. After the rig is released, an acid and/or frac job will be done. A 13-5/8", 5000-psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uneemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. ~ E C E IV E D Esti mated Start: November 1, 1984 Sul~quent Work Reported OCT 2 619 , ~,.~....~ u~l L~ 5as (;oas. commission Anchorage 14. I hereby ge~rtif~y that the foregoing is true and correct to the best of my knowledge. Signed Title Area Drilling Engineer The space ~/ef'~w c~/ Condition~ of Approval,/'[f any: Approved by ~pproved Cop;, Returned By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate Form 10-403 GRU2/SN24 ~, 7-1 and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Pos! Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 4, 1983 Mr. C. V. Chatterton State of Alaska Oil and G~s Conservation · 3001 Porcupine Drive Anchorage, AK 99501 Commission Dear Mr. Chatterton: Attached are subsequent reports of stimulations the following Kuparuk River Unit Wells: 1E-20 1E-21 1E-.22 1E-23 1E-24 1E-26 1F-7 1F-8 1G-4 1Y-14 If you have any questions, please call me at Charles K. House Kuparuk Operations Coordinator CKH/kmc Attachment (In Duplicate) cc: W. Crandall/T. Best R. Ruedrich R. May performed on 263-4527. ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 82-214 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 99510 50-029-208884 OTHER [] 4. Location of Well SURFACE LOCATION' 291' FSL, 225' FEL, SEC. 16, T11N, R10E, UM BOTTOM HOLE LOCATION' 986' FSL, 1278' FEL SEC. 22, T11N~ R10Es UM 5. Elevation in feet (indicate KB, DF, etc.) ! 6. Lease Designation and Serial No. 106' ~RKB) ! ' 12. 9. Unit or Lease Name KUPARUK R!VER UNIT 10. Well Number 1E-22 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL ADL 256~1; Al K 469 CheckAppropriateBoxTolndicateNatureofNotice, Report, orOtherData NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation )~ Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On April 19, 1983, Kuparuk River Unit Well 1E-22 was stimulated with 12.5% HC1 through coiled tubing. All surface lines and BOP's were pressure tested to 4000 psig. The maximum coiled tubing pressure observed was 3800 psig. Diesel was used to displace the acid. Nitrogen was injected via the coiled tubing and circulated intermittently with diesel to aid in cleanup. Following the cleanup period, the well was switched to the CPF. TOTAL AHOUNT USED' Acid 116 BBLS Nitrogen 1200 GALS Diesel 98 BBLS 13. COORDINATOR 14. I hereby certify ~r~at the f~regoing i,s tr~e and correct to the best of my knowledge. Signed ~ ~ TitleKUPARUK The space below for Commission use 0 P E RAT I 0 N S Conditions of Approval, if any: By Order of COMMISSIONER the Commission Date Approved by Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate KUPARUK EhE; ! NEERIF,E; TO: Wi l liam VanAI en Transmitted herewith' are the roi lowin9. ~4: D.W. Bose/Shelby J. Mat thews ¥¢ELL PLEASE KE)TE: BL - BLUEL 1 NE, S ' SEP i A, F F I LM, T.' - TAPE, ~/~LEASE REI'IJRN RECEIPT TO: Ak'ED ALASKA, I NE;. Alaska 0il & Gas Cons. Oommbsiorl ATTN: SHELBY J. MATTHD,-'¢S - ATO/111 5-B A~'}chorage P. O. BOX 100360 AJ',,E~IOP, AC;E, AK. 99510 KUPARUK ENGINEERING .-__ TO' William Van Alen TRANSMITTAL FROM' D.W. Bose/Shelby J. Matthews WELL NAME' ~ ~~ Transmitted hereWith are the following' · ~L~E, .~/~-~A, F- FILM, T TAPE, PC PHOTOCOPY PLEASE NOTE - - R~ ACKNOWLEDGED: . - ~LEASE _RETURN RECEIPT Td · Alaska 011 & L~as Colin. DATE' ARCO AL~ASKA, INC. .ATTN' SHELBY J. MATTHEWS - AFA/311 P.O. BOX 360 ANCHORAGE, AK. 99510 KUPARUK ENGINEERING TRANSMITTAL #,~--~ TO_' William V_an Allen FROM- D.W. Bose/Shelby J..Matthews WELL NAME- Transmitted herewith att r R/~~.IPT ACKNOWLEDGED: PLEASE RETURN RECEIPT TO: ~[aska Oil & Gas ~ , Cons, ARCO ALASKA, INC. ATTN: SHELBY J. MATTHEWS - AFA/311 P.O. BOX 360 ANCHORAGE, AK. 99510 Anchorago ARCO Alaska, Inc, Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 Apri! 14~ 1983 Chat Chatterton -State of Alaska Oil and Gas -Conservation 3001 Porcupine Drive Anchorage, AK 99501 Dear Chat· Commission Attached are notices of our Wells 1E-20, 1E-22, 1E-24 tubing. If you have. any 263-4527. intent to stimulate Kuparuk Unit and 1E-26 with acid via coiled questions, please call me at CharVes K. House Kuparuk Operations Coo r'd i' nato r CKH/kjc Attachment (In Triplicate) xc' W. L. Crandal 1/M. D. Schal 1 R. A. Ruedrich - ANO 332 H. C. Vickers - AFA 326 K.uparuk, North Slope STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 82-214 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 99510 50- 029-20884 4. Location of Well SURFACE LOCATION' 291' T11N, R10E, UM FSL, 225' FEL, SEC. 16, BOTTOM HOLE LOCATION' 986' FSL, 1278' FEL, SEC. 22, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106 ' (RKB) I ADL 25651, ALK 469 12. 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1E-22 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate j~ Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to acidize Kuparuk River Unit Well 1E-22 through coiled tubing to improve the well's productivity. The initial production test on this well indicated a high skin factor and a corresponding low flow efficiency. Other Kuparuk wells with similar characteristics have shown marked improvements following acid treatments. The treatment will consist of 4825 gals of 12% HC1 with mud and silt remover additives. The coiled tubing unit BOP's will be pressure tested to 4000 psig. The end of the coiled tubing will be positioned initially just below the lowermost perforations and then pulled up across the perforations as the acid is pumped. Pump pressure will be limited to 4000 psig and the tubing pressure will be limited to 1500 psig. Following the acid treatment, nitrogen will be injected through the coiled tubing and aid the cleanup. During cleanup the well will be produced to ta~k$.o.n.]~oc, ation. Following the cleanup the well will be produced to CPF1. i-~i!::.'!.i!~_'i~i:'!i::~! Expected start date' April 16, 1983 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,,"-'t!~:i'{~ ~ .... K U PARU K ,":'.: ::' :';~i~: Signed ~~~~ ~-~i~)~~Title OPERATIONS COORDINATOR Date The space below~r C~mmission ~e · 4 -/4 Conditions of Approval, if any: Approved by COMMISSIONER Approved Returned ~',~ ;:;.::'::?~L ~vo~. '~" ¥~" the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARcO Alaska, Inc. '~'"'~ Post Office B,. .,60 Anchorage, Alaska 99510 Telephone 907 277 5637 March 15, 1983 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil~& Gas Conservation Commi ss.ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton' Enclosed are monthly reports for February on these drill sites' 1-25 1E-18 7-20 1E-19 7-21 1G-5 12-15 1G-6 12-16 1Y-12 12-17 1Y-13 13-2A 1Y-14 15-3 1Y-15 CIRI Wolf Lake Well #1 Ravik State #1 A1 so enclosed are-well completion reports for' 1-24 1E-21 2-8. 1E-22 7-18 1F-1 7-19 1G-7 12-18 WSW-IO 13-9 WSW-11 1E-20 Tract Well 24-11-14 We also are including subsequent Sundry Reports for 2-8, 7-18, 12-18, and 13-9. ARCO Alaska, Inc] is a subsidiary o! AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~..¢L AND GAS CONSERVATION CE MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OILJ)~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-214 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20884 4. Location of well at surface 9. Unit or Lease Name 291' FSL, 225' FEL, Sec. 16, TllN, R10E, UM ~-'[~I-~-N,~ Kuparuk River Unit At Top Producing Interval I VERIFIED ! 10. Well Number 1395' FSL, 1:383' FEL, Sec. 22, TllN, R10E, UN lSurf. ~ 1E-22 AtTotal DepthIB'}~' I~ - 11. Field and Pool 986'- FSL, 1278' FEL, Sec. 22, TllN, R10E, UM~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 106' RKBI ADL 25651 ALK 469 12. Date Spudded 13. DateT. D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore i16. No- of Completions 1 2/26/82 01/05/83 01/10/83I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9480'MD,6508'TVD 9260'MD,6344'TVD YES IX] NO []I 2149 feet MD 1450' (Approx) 22. Type Electric or Other Logs Run D i L/SFL/SP/GR/Cal/FDC/CNL, CBL 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 80' 24" 266 sx AS II i0-3/4" 45.5# K-55 Surf 2449' 13-1/2" 1500 sx AS Ill & 250 sx AS I 7" 26.0# K-55 Surf 9341' 8-3/4" 725 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) 911 2 ' -9132 ' 3-1/2" 8772 ' 874:3 ' 8855'-8958' 8 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (FI0wing, gas lift, etc.} I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~low Tubing Casing Pressure CALCULATED..~ OIL-BBL GAS-MCF WATER-BBL OiL GRAVITY-APl (corr) " Pre~s. 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. None M,--~R . Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand GEOLOGIC MARKERS MEAS. DEPTH 8853' 8960' 9092' 9223' TRUE VERT. DEPTH 6044' 6122' 6219' 6316' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 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 Dri 1 l i ng Engr. 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". 1E-22 DRILLING HISTORY NU Hydril & Diverter. Spudded well @ 2130 hrs, 12/26/82. Drld 13-1/2" hole to 2475'. Ran 60 jts. 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2449'. Cmtd 10-3/4" csg w/1500 sx AS III & 250 sx AS I. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS, cmt & 7' new form. Tstd form to 12.5 ppg EMW- ok. Drld. 8-3/4" hole to 9480' TD (01/05/83). Ran DIL/SFL/SP/GR/Cal/FDC/CNL f/9469'. Ran 238 jts 7", 26.0#/ft, K-55, BTC csg w/shoe @ 9341'. Cmtd 7" csg w/375 sx Class G & 350 sx Columbia G. Instld 7" packoff & tstd to 3000 psi - ok. Ran CBL f/9260'-2000' - good bond. Arctic Packed 7" x 10-3/4" ann w/300 bbls H20, 250 sx AS I & 98 bbls Arctic Pack. Perf'd the following ~intervals w/8 spf, 120° phasing: 9112'-9132' 8938'=8958' 8918'-8938' 8897'-8918' 8876' 8897' 8855'-8876' Ran 3-1/2" completion assy w/tail @ 8772' pkr @ 8743' & SSSV @ 2149' ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well w/diesel. Dropped ball & set pkr. Closed SSSV. Set BPV. Secured well & released rig @ 1900 hrs, 01/10/83. JG' 1 lm 02/02/83 , I<UF'~RLIK -,.~":)~.::,c:~ ~,~ ~;,,~--:,, J~NLI~RY 09~ Z'~8~ .JOB NUMBER ~}:~-B0-30004 ~- ~:~ KELLY BUSHING ELEV. = 106.00 FT. ~~ ............ : .......................... , ..................... ,~..~ ......... ~,.~ ........... ~?..,~,~ ..... :,,,.,: ............... ,~,,: ............ , ............... , ..............., .......... ,,~,...,.:,..,..,..,,...~=,,.:,.::::::,,::= .......... :=~:::~:~::~::~ ........ ::~,,~,,:~ ,',~~,:~'~T,:::: ,: :., :. ::,,: ,,.,.,=. ................ :,,:,.,.:,.,,.::~,.:,,===,,=,,::,,:: ~.: :.::,',,:::=,~'.:~ ~, :~?:',.:~ ~'.:':?,:':'.',?.', :".'; ?~:',",~?~ ',::~ F?'.:'.:~:~ ',~:: ~::?. ',¥~ ', ¥,::':,'?,".:'.',' ,~ ?.','.:.:. ~:'.',',',~'.'.~?,¥,?~F ?, ~:':~:', ?::~::~:F?,:',',?, :: :: ~':~ ::~ ~/:~ ::/= ~ ~ ~ ~ ~ ~ ~ ~ ~,, ~::~ ~ ,,: ~ :: ::~:~::~~..~.~..~:~~ ................................................................. ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~ ......' ....................................................................................................... .... ' ........ ' '. '. :'_ _ ""'2':~ '~.' '~'"'=:'"~ " ........... _:'""-; 'J":T'"'"', ........... 5'=:"' 'J~": ~.:"", ........ "'"'~:=:"'".~ '"J'"'j"'"'~ ..................... ";" "'""J'"';" :'"~" ~ .............................................. ............................................................................ ' ....................................... ................. .~ ~. ............... ~ .......................................... ~l. :1~ ..................................... .~.. ~.i.. ~ I~ ~ ~.: ......................................................................... ~it...l~.~ ...................................................... ,~.~.:.~l.~.~: ~.~ ............................................................ ~ ~.l..?.:~:~ ......................................................................................................................... ~.~.~ ~.l ............................................................................................................................................... ~..........,.~ ............................ .. .............. ...?~....?.~.~.~.. ......................... : ............................................ MEASURED VERT IC:~L VERTICAL INCLINATION DIRECTION SEVERITY RECTaNGULaR COORDINATES VERTICAL ' DEPTH DEPTH DEPTH DEG MIN DEGREES DEG/IO0 NORTH/SOUTH E~ST/WEST SECTION :300 299.99 193.99 0 25 S 6. 0 W 0.18 400 399.99 293.99 0 30 S 25.39 E 0.26 0.14 E 1.3o 0.2";/ E 1.99 · '9 ~ ~'~ ~" /1 ~', ".~' i:::' '"::::::!~:;;. "::::::: :::::::::::::::::::::::::::::::::::::::::::::::: :: '::[ [" '? [~i:~i[i:!Ei:!ii:i:::~: 700 697.95 591.95 12 20 S 64.60 E 4.73 14.43 S 26.20 E 28.37 750 746.52 640.52 15 6 S 60.60 E 5.83 1.9..92 S 36.70 E 39.~3 ,~' ' ,-- ~ ~ ,--,,-, ~ ~ ~ 7 '~, .~ 4 Z ~] ~ ~, ~'~ ~ . ~' ~',~ ::?~:'?'~'~::'?:~"'~.::. ....... ~:,~,~'+'~,,.? ~?~':~:~"::"~ ?"~ ...:~ ::?. :: ~:.:.~. ,~ .... ,.. ~,'"'~' ~:~?~?'~::~:.:~'~: ........................ .................... ~' ~? ~'~.::~:.,~ ?~'¥?'~:?~?":~::~'::':'::~:~:'::~ :~::~::~:~'~':~.~.~ .............................. ................... ............................. ~.~.~:.:¥:::::~:~::. ~,: ~???:~??:.:::~?.~::~:.~:~' ::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::~'~:'?~::~: ?~'~?:~'~'::'::::'::'::::::'::'::'~:~::~::'?'='~:" ?:~?:::~?:~::~??:~.~?:??~?:.`:?:.~:~?~.::¥::~?:~::?:~~.:~?:~`~::??:~?:~:???:::~::::~::~~::::~::~:~:.~::~::~`~~A~::~ ~ ~ ~ ~ ~ ~~ ~ ~.~ ?:.: :: ?:,: ................................. .............................. ...................................................... : ...................... B .-=-~- ...... .--~,~J~- ............ ~-.. , .j~.' ....... ....... '~'~ ......~.;.. ~ ~.._.~,._.-~ ~ ~.~-~ ~.~.. / ~ ~ /~.~,v ~ ~v~w /~ 1000 980.71' 874.71 24 51 S 60.69 E 4.30 66.05 S 109.96 E 123.09 1100 1070.24 964.24 28 1 S 62. 0 E 3.21 87.37 S 14~.04 E 165.26 ~...::? .~::::.:'. :~ . ~.. ~..: ~" :: :..:. :¥...:. :.~.~: ~ .: ::~: :: :.::. ::~:,~: ..:: :~.~.::~.:: ::::~:.?.~. ~.:~;, .~::~:.~..:.:..~..':. :~ :::.~::~:.~ .:::.:~ ?:::.:;~:.:..:~ .?: ~?.::.~::~:.?::~?:?::::::::::::::::::::::::::::::::::::::::::::::.:~ ::?. ?.::~::~::::~?::~::~:.~.;:~::::~::~::~:::~?:~::~.:~:.::::::::::::::::::::::::::::::?:::~?~:~::~::~::~::~:~::~::~?:?:::~::~.:.:.::::.::~:~.:.~?:?::::~?~::~?:~::~::::~::~::~:::~::~?:?:~?:~?=??:?:?..~?~::::~:~::::::~.: ~ ~ ~ ::.. ::.': :: ::~ ~ ~:~ ~ 7~.:: :: ?~...: ~" ~ ~, ,:.~ 7:':?:?:: :~ .:::~.::: ::.~ ~?:': ?:~ :.::?~:~ ~?:~:::.~: :~?:.:~:. ?:~::~::~::':~ ::~:~ ~ ~ ~.~:~:::: ::::::::::::::::::::::::::::: :::: ~::?:~:::~?:~ ?:~?~:.~:::~:.:~ ~;::~?:~::~?:~: :: ~ ::~::~::~ ~ ~ ::~ :~ ~ ::~?: ~:::~:~ ~ :::: ~:: ~ ~:: ::::~::?:~ ~ ::~:~:.::~ ~:~::~K~:::~::::.:::::~:.~:::::::.:.~:.~ ~ :,~:~?~ '~'~. -- .... ~'~'"'~ ...... -~"~'~ ' '-~- --~ ~. ~ .' m .--'.~~ '~m ~ ~.~ ~,~ ~ ~1 ~'~ ~ ~ ~ I -~ ~ 600 ~ 480.22 1:374.22 38 33 S ~9.10 E O. 36 237. ~0 S 390.6~ E 4~9. ~ ~700 ~57.99 ~45~.99 39 20 S ~9.39 E 0.80 269.64 ~ 444.6~ E 4~.64 ,-, ~ - .-, - ,-, ~-.-,,-,- ,-, - - _ ~ ~ ,~ ~ ?~ .~-~ ~,~-~.-~ ~ ~. ~,~ n ~, ~ ...... ~/_ . ~.-.. ................ ~ u ~ ~ ~ ~,~ , 4~ ,~ ~. ~ .. ~] E ............... ~ ...... ~ ~.~.,..~ ...... ~ ....... '.", ....... ~?'~.~:'"'~?:~.::~L~.~,L'~"~"':;'~'~,~F~,~ ~"~.~..~.~,~, .~[~LI.U ....17c,(.I, ,=,4.' 1674. ~4 :+ .... .: 4..,.~:.:47.~:~'.:.:..:. :~::.,':',...~::::~.'~.~ ..~.~::~:?:?~:.~.?~..?::.?~:~?:~?~?:~??:~..:~.~..~:~.~:.~?.~?~?~:~:~?:~:?~ 2200 1922.6:3 1816.63 46 4 S 58.39 E 1 · 35 445.78 S 737.48 E 827.63 2300 19'F/1:17 1885.17 47 22 S 58.10 E 1.32 484.10 S 7~.:39 E 897.76 .. - ~,-, ~ ,-. ~=,-, .~ ,=,~ ,-~ ~ :~ . ~ ~.-, . ~. z . ,~ ...... :~ / ~. ? / __ ~ ....................... ~.~ .~..... ~; ~ ........................................... 2400 ........... 2n5:=: ..41 ................. 1 ..,.,,_ ~.. , .: ,.~ <UPARUK ..ANLIARY 0./, 1983 dOB NUMBER AK-BO-30004 ~LA.=,hA KELLY BUSHING ELEV. = ~E~SURED VERTiCaL VERTICAL [NOLZN~T[ON DIRECTION .:,EVER [ TY RECT~NOUL~R COORD] N~TE8 106. O0 FT. VERTICAL DEF'TH DEF'TH DEF'TH DEG MIN DEGREES PEG/lO0 NORTH/SOUTH EAST/WEST SECTION -\ ::'::::<::' .................. ": :' ?:~":~ ,~.:~':' '2'~.5:0.:.::...:' '''~ ':':: ?'::: ........: .'; :'":~::~'~: ! .: ~. ~ ..:: :[~:~';~:::',, ~:: .............. ........ : ~;;~; :,~ O' :a;~ ~:,~+~" :: ':: '~::'~;'.~:~ :.:: :::::::::::::::::::::::.:::<...:::: ::~ ~':;rt".~ ............. ::':':~: I"::: .~:: ~:; :::: ::.' .......... :~ ::: ;: :~: :''~:` m..: ''~';:'~ :::i~::',oS''' :~,':::::::~::~:':::I.:~ .. 2800 2319.48 2213.48 50 :33 S 57.10 E 0.91 684.13 S 1118.~7 E 1261.4~ 2900 2382.48 2276.48 51 21 S.56.39 E 0.97 726.71 S 118:3.~1 E 1336.78 ::::, ,:: .:..:.:::::: .~ ,~ .: ,:. :. :~,:: ~: ,.-,-.~ :,r~,~-:: :,., ~:.~,:,' ~ :: : ....... ~,,,..,, ::, ~ .......... 3400 ~i.o~. ~5 2576 .......... 9~ 54 ~ ._,o.~:'-' 69 E 0.""~7 '-=~._,6 55 ~ 1 s 10.69 E 1727.26 3500 2741 . :32 2635. :32 54' 29 S 53.19 E O. 57 1004. ~0 8 1575. '-22 E 1807.02 7 ~: ~... '~2: ~.~ '.:i' ::'~ .:::~ :'~T<:~[::~i~ :~ ~::~ B?':.~:.~:::'~::~ ~ ~[:::~:, ::::::::::::::::::::::::: 4000 :3024.19. 291 '"'' ,:, 19 ... 7 42 '""~1" ':' = '~' " . . :, ._ o . 0 E 1.43 _ 1 e~:o. 81 S 1900 .54 E . ~'-"-'. j ,. '~. 73 .) 4100 3077.22 2971.2:2 58 14 S 4:3.80 E 1.15 131:3.98 '3," '~, '~, 0 ,- ~'" '~"? "7Z ~ Q " g" ~:", ..... ..:~:-:..r:4~OO'?--:,...~,l-~-...Tv,- ..... ~.o=.~.,.7-~ ........ : ...... , .......... 4o.:: ..... ~.--,4.>.,-.t:~-....E :.. c::': :::..~.:::: ~i ). ;:::. '.:~, , ~ ' :-~," .-, ." ,':,~. ,:. =;'~ ...:.i :~17~..71 ~. oU7~,71 : 6o ,,_, :...,47.~.,U: :::::: .:T::~ ':4400 :'.': :::.:'. 3229. Cf1' ::: ':~ :.' ':~ 1'23 ~ 01 5':~ · .. 10 ~ F: .47; 0 ::,::: .,: .: ..: ,' :. ' .... :..:: .... ,' · '. .... -6:.,:. 4600 3336.79 :-::230.79 55 4700 3394. O0 :_::288.00 5;4 .?...,-.,-:4800 ........ 3452 '~'-- '-':' '- =' s"', .......... , ~ ..,-, ...... ¢..z, 46 ,..:~.J ....... ,_ ._'. · :::':::':.::" ':.:',q,T/r~}' .' .-,~_ ~' .-, ' - . ' ,-; * r..-:. .~] . ::'.:~::'..~...:: :-...~ .~. ,-,,.. o,~, ~ .~ ,. ! 5 ...: 406.1 .-, ,_ 4 ::ii:::i::{::.':.:; ::L'5000. ':' :'356.c/.77 '" .. .3468.77 ·._.=;~"._, /::" :':~1'O£L ...... -:::~:.26....2z~ ...... 3520..2C.- ............. .55 52.::00 :3681. '.-77 :2:517..'5.1.97 56 5300 37:36.88 3630. :_--:8 57 ................ 4Oo:_::791 .~": .... "'-"'": ~;'L-:' i.'.:: :ii:. i::!i: ::,,.: . · .. : ::: i:i i:' !{[:: :" :i:'. " ' 31 F.-; 4.:--: :a9 E 2 11 15'-29.87 S 22t:2.25 E 2723.22 40 ¢' 4:E: 6.9 E 0 86 1 6, oL~. 89 '" · ~.. 2:343 ~ · · ' .~':;n 'A' a-z :;."4-",' I.'z: ,- .:..':.':'::: ;", z ;:,.' :: ":'":: ':: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .... ~. '-r ..... -'""'""~;;; '"'-'T'r-'&" ~ 3"'--' I:~ ~.~"~'I~.,~ :22 S 4::: 3(] E 0.._,7 192'7 31 S 2647 64 E' 11.6,3 - - . m .. .-~ "'- 1 S 4.:::. 0 E A. 71 198:3.07 S 270~. 89 E 32'-24.83 0 0 0 KUPARUK ,JANUARY 09, 198:3 ,JOB NUMBER AK-BO-30004 ALASKA KELLY BUSHINO ELEV. = 106.00 FT. ~ ~ ~ I-I~,~~l~ ~ ~1 I ~,~ HEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANOULAR COORDINATES VERTICAL ' DEPTH DEF'TH DEPTH DEG HIN DEGREES, DEG/IO0 NORTH/SOUTH EAST/WEST SECTION __ ~::i~:i~::Y.~:~,i~'.h~'"":,,~"~ '~ ~:,":':":::'~i'.:~ :~,'. ::::~'~:~:~' "?' ~i',:~:' '~ :~::~:~:~i~i,:~',::'~':'~::': ':.~:,: ?~::~ ~,'.~:,:~ :/.~ C>L'"" ,~ .~:: :: ~',:~:~:':~ ~:,~i'~:~::::~ 5800 4016 07 ..~c . ~,/10.07 .-,4 40 $ 47.60~E 0.~7 2261.6~ S , 3017.14 E 3707.~1 5~00 4074.40 3968.40 ~'- · . . ~.J 56 S 47.50 E 0.73 231&.48 S 3077 07 E 3788 84 64.00 4:373.18 4267.18 52 33 S 47.10 E C).41 2~88.24 S 3371.7~ E ' 4188.41 6500 4434.27 4328.27 ~2 8 S 46.8~ E 0.4~ 2642.24 S "- 342~.70 E · 4267.36 ::!: ,,, ' , .'d,~:,.: ~, ~ '.:,: '.' :.::,:.: 'F ~ i. ~'~::~: ~:.:~ ~ ,::.~,%~::1~::': :.. :~'i,'::: '.::" :::i".:: ,, :.,,:~ :: :.' "'~ :i.:::~::.':: ;~i, .~ii. !~:~l~i~l~:~:""~, ~:"F"':iE'::: '":': ,':ii~'"'.i}i:}i'.ili:i~:~i~i~iE~!/~}~' "l~::'.>"::~i~:i~:i/,i~i~i'::~ ..... !'!"'ii~!iP"'i:'F':~!i~:'""~i~iiii~!~E~i:'"':'"':::"'::"": i ~:"'"~::i[~F"~!~i~:E~i~EE~i~:"':F" ~'W' :.,: ,,. .... ..- ..: ,:, ,:,~: ,, ,, .,,,. ....... , J., ,, ..:., x,,,,: ~...~ ,,, .....: ..... ,,: ,,.., : :.~:..f ::,. ,.,::x... ,, :.:, .,...,.,:,.,.:,,, ::.x.:, :.::,x. ;,'..,:.::',x.:. ':,:,:.:,:,;:..:.,:,.'.:,, :,..: ,:,'.,.::, .',:,::,:,:... ,.:.: .,,:,, ,:, ,,,;.:.,,:,:, :.:+:.,:.:,.:*: ........... ',,' ............. .............................................. ~ ..................... ~:....~:~:~:.~:~`~:~:.:.:~..~:.~:~:.:~:~:+:+:~x~.:~:.+~+.~.~:~:~;~x~x~..'.~;.~..~: ............................... ' ................................ 7000 4752.71 4646.71 48 37 S 28. O, E 4.50 _2938.94 S 3672~_._~ .......... 4650.05 . . ~' '~:~4 S 3707.16 E. 4723.35 7100 4817 59 4711 5'P 50 2m E; 26.30 E 2.~6 7600 5135.64 502~. 64 51 10 S 25.39 E O. 62 335:3.2'~ S 3876.45 E 5092.96 7700 5200'. 11 50'~4.11 48 33 S 23.30 E 3.07 3422. ~2 S 8~07. ~ E 5165.53 ~ .............. ~ ............... ~6~..~!~,~ ........ 5!~2~-0..!. .... ~-.~5~--~..-~~-~.~-.-~..~.~ ........ ~!.~ ..................... ..~j~.?C~.~.~.~ ......... ~ ............. ~.~::~-~-~ ~ ~.,...~ ................................. ~:.:.'..~:~c~.:'c ::..:~:.'.~:..:....~::.~....:~' ...~.~, :'.' . ~ ..:.'.. .......... :.".~ :~: ?'. .... ::.'~... ..... .~:.:. · :. ~'-~ ~ .... ~. . .. . .~..: .. .... .'::.~.x~: ~ :~.:.. ~:.~..' ....i..~-:~.c ~.'~ ~ ....... ~ '..~:~.~"~.?..~.~:~k~.~.~'.~..'..~'~= ..' '.":~h~:~i~:~ ........................ ~: .......... : :. :~?~:~,.. ~~ ~"_ ' ~ ~ :,~:~.=~:~:'.:::,..:'~ . 8200 556~. 54 5463.54 40 47 S 14.50 E I. 37 . 3741.76 S 4012.15 E 5470.56 8300 5644.81 5538.81 41 33 ~ 14.80 E O. 78 3805.45 S 4028.80 E 5528.67 0 0 0 KUP~RUI< . ALASKA .. ..... . ....... : ......... ,?...?:, .... .-.. .. ~: ...... '.:['.::,~ . . ....:: ..... : ~.. ~.~.,~ ........ .. ; .......~ ....... ~ ..... : ~ :: :::~ : ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::;:::'.'.:::',: :',::::::: :::::~:::: '.: ',:: ',:: ', ~:;:: ::: :;:: '. ~: ~'.: ', :::',: :'.: :'.~:¥,: ::',:'.:::'.:;',:::::?,::i:i:!',',:i: f,i:::::'.::'.: JOB NUMBER AK-BO-30004 KELLY BUSHIN~ ELEV, = 106.00 FT, ~'~,~D~I'~-- ~ ~'~1 I ~,~, .. ' . :;'?~"~'~V:'"~'~'~?~F~'~:;~'~:'~?"~"~'~'~'''''':/?''''~%'''''~ .......................................................................... ~....~..F...~..~3..~..~`~/..EF~.8..~?...~..i.~..~TE~.?..?/~.~.~7?:?:~.E::.?:.~.~.~.~.:~.~.~.~.:~.~.?/i.i.~.?/~.~.:/~E~.~.~.~.~.~.?~.~.~.~.??~.~../~.; ~;:: ;~; ~: ;~:;::: ::::::; ::;:~:~:S'; ;'""' ":'"'"':'"' 4"ff:"N f "~:'.r~ ;:: ::',::;~:r ::::::::::::::::::::::::: ~:]:~'.~ ~::::::~: :: ~: ;~ :~:: MEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY 'RECTANGULAR COORDINATES YERTICAL ' DEPTH DEF'TH DEPTH DEG MIN rJEGREE$..i~.:.,::.:..:, DEG/IOO NORTH/SOUTH .EAST/WEST' SECTION ,,)___ 8800 600&. 14 5~00.14 44 4 S 14.50 E 1 · O0 4140.40 ~ 4113.22 E 5832.1 ~ 8900 6078.34 5972.34 43 2~ S 14.&,0 E 0'59 ~: , 4207.37 S 4!30.&1 E 5893.19 ... :;....:....,.....u..... ..... .: :....:,.... ,:. ;.. :., :.: ;:.: ..:. ,::,:..4 :;.;: ...,..;.x.:.. ~,..xh...:.::x.;,,.: x :;:.....; :.:..... ~...,:........ ...... . ,.....~ :~ ~; ~E~':~ ~: {E~E:E ~ ~: ~ ~E ~i~i¢~E ~ ~;;?.EqEi~:8~;i~8~;~;~;~;~?.~;~'.~'.Eri;'.~:~{:~;Pm~f;i;~F~7~;~:~ ~ ~E~''{~E~(~:~8~iR~;i?i~i:i;i~i~:i:~;~:~:E;~E~L~i~E~.~:j~~EF~;~:E:~:~;i:i:i:~:~''~:~:~:;.~?.i:~i:i:i;it~:i:~?~:~i:::~:;~'.~''~.~:i~'', .... :"~'~,':E~h,..~::~',' :F',,' :,'~:::'~;~;~:~,;~:~;, ': ~;~ ,~::~? '"'.";::~F,~ti~;~>~:~' ,:~'''''~''; . .:;' 4' ':;,,, :,~;t::~,k4',,,,>,;, ,. ',... ,. ........... ~: ;. :.' ;:'.: '.::u::::~;n:;:; 94c)0 6448.34 6342.34 41 37 S 14.1 ~ E O' O0 4533.20 S 4213. ~7 E · 189.05 9480 6=,)~. 13 6402 13 41 37 S 14 19 E 0 O0 4584 73 S 4226.70 E 6235 76 :::. :.:,::::.::::. ::::::::::::::::::::::::::::::: .;:,: .:::::::::.:.::.:::...:.:.:::,..:.:..:,:;:::::::::::; .::::::::::.:,:::::::::.:;::.: .~:.::::::::~:.::~:'::.:::::::::::.::::::.:::::::::::::;:::::::~::::.~:~:~::::::::~:::::::~:::~:;::::::~:~:::::::~::'.:::~::.:~:~::::.::::::~:::::::::::::::~:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::;:::;:::::::::::::::::::::::~:::::::::::~::::;::::::~:::~::::::::::;:::::::::..~:~::::;:::::~:::~:::::::~:::~:~:~:::::::~::::::~:~:::::..:::~:~::'~ H. 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'"'"'"'" '~' '" '"'"'**' '"'"' 0 0 0 KUF'ARUK dANUARY 09, ALASKA KELLY BUSHING ELEV. = 106.00 FT. iT~HHH~H~HH~:TiHH{{HHHHH{~{H~iT~HT~HT~H~HHH{HT~ ~H HH "' ?,'"'"':'""','".""::'"":'~:'".:.', ::"'!:' ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::: ,,:¥. ~ :~ : .: ~:~ ~ : . . : :: .: :, :.:: ,, , ::: : , ~:~:~: : :~.: : v : , ~.:~:, :.: , :~: : ,:, ,:~::: .,:~:. , :: : :::~: .... , :::.:~:::::~.:~::~..:~:~:.~: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .......... ::::: ::::: :::::::: ::~:::::~:::::~:~:~:::~::~:~`:~p~:~:~:::~.:~::~:~:~"~":::::::~:~ :~ .: ~ ~<~::::.~:~:~%~:P~:'_~:~.~:~b. ~.~:~,~:~. ~ ::~ ~" ~. ~:~:~:~:~:~:~:::~:::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: "::~ ::, :::::::::::::::::::::::: ::::::::::::::::::::: ::::::::::::::: :::::::~::::: :::~:::::::::: :::::: :;:::: :::~?.:::::::::: :::::: :::::::::::::: ::::::::: :~: :::::~:: :::::::: ::::::::::::::::::::::::: :~::~:~ ~:~:~:~:~:: :::::::::::::::::::::::::::::::::::::::::::: :~ :~:~:~:T:~:~:~:~:~:~:~:~ ~:~:~ ~:~:~:~:::::~:::::~ :::: :::::::::::::::::::::: ~:: :~:~:~:~:~ ~:~:~:~:~:~:~:~:~:~:~.~:~:~:~:~ ~:~:~:~ :~:~:~:~T:~:~:~:~:~:::~:~::~:~ :::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::: ~. ~ ~:::::~:::~:~:::~:::~:~:~:~:::~:~ ::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~:::~ ~:~ ~:~:~:~:~:~:~:~:~:':~:~:~:~:~ ~:~',~:~:~ :~ :~:~:~:~:~:~:~:~:~:~:~:~:~:~:~ :~:~: ?~:~:~: ~:~:~:~:~:~: ~::: ::::::::::::::::::::::::::::::::::: ? :. P~; :~::: ~:~:::~:~:~:~:~:~:~:~:~ :~:~:~:~: ~::~: ~: ~: :~ ~!:~:'~: ~:~:~:::::',:: TRUE . SUB-~EA TOTAL MEASURED ,, VERTICAL VE~TICAL RECTANOULAR COORDINATE~ MD~TVD , VE~T!~AL.., ," .... ~ ......... ~ .............. c..~...~.>~..~,.~..+..'..~.,~ ............... ~ ....... ~... ~..,,~ .................. ~....~ ...... ~....~..,~.c..~>~ .,..~...,~,~.c.,~...~.c.,..,~.,~.,...~.~...~.~.~.~ '~' "~"'~-('~ ...... ~"~'~'""~ '~.'.~ ............ 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'"~"~",~W.:~:::.~:~:.~:.:.:::~~'" '~'~' ", ""~ "~'.~ .................. ~:~:"'~':' SO00 5415.5~ 530~. 5~ 3~ 18.5~ ~ ' ~78, 91 E 2584.4 ~ ~7, ~ 2. ~000 b151.05 ~045,05 .4273.84 S 4147,7~ E ~, 2848.~5 2~4,54 ...... c ........... .,. ,..,.,v...., v ........ · .............. ,"'"' ,~"":'"' '~:::.'."c ~" ' :::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ,::::::::::::: :::::::.:.:::.:::.:.::: :::::.:.::~:::: ::::~.,':, :::: ,.':.: ::::::: :.,':,..:,: .%,: :::::::::::::::::::::::: ::::.,::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::~: :: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .,....::,:.,,,,.::.~ ...... .:..~,~:::: ....... ::::::::::::::::::::: ...:..,~.::.:::.:.:.::::: :::::::::::::::::::::::::::::::::::::::::::::: KUPARUK ALASKA : ~'.J~'~l~l'~%,F__~l~ol Ihl_... I I~1 I ~1 I~1 I~T/Tkliw. :::::::::::::::::::::::::::::::::::::::::::::: ~: : ~ .: ~ : ~ ~?i ~g :.:.:.: :.x::~ :.:.:.:: :. :.:.::.:.: :.:. ::.:.: :.:: ..:~ ~ ~:.:: :~ ::::~:~:..~{ ~j:~:~::~.:.:~::q::.::::~.:q~:~ .~:~ :~¢~ ~:~ ~[~:~..~:~:~ ~ ~ ~ ~ , , ............................... ~ .............. ~HgR~ 0~, 1~ .... dOB ~H~B[R g~-BO-~O004 KELLY BUSHING ELEV. = 106.00 FI,. :306 :306, O0 200, O0 1.72 S O, 1.3 E O, 01 O. O0 :::,,:::::::::: ,,~,::. ,,:::: :::: :: :! : .:,, .:,.. : , .,v ,, ~ :::: ~:.::: : :, ,.:.. .,;:::, ,,,, ::::::::::::::::::::::::::::::::: ,.:::::::::.:::., ,, ,:::., :::::::::::::::::::::::::::: ;::"':'::' ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :[::,'..',::~::::..::::,.': :~:::: 812 806, O0 700, O0 2~. 11 S 51 . 75 E 6, 05. 3, 7~ ~ 18 ~06. O0 800. O0 4~, 36 ~ 82.25 E 12.57 6, 52 ~:~:~:~ :~ ~ ~. ~: :~:, ~:~:~,~:~? ........ :::::::::::::::::::::::::::::::::::::: ...................................................... .... ~..~..~ ....................... ~.l~...~ ....... ~ ......... ~ ................ ~.....~ ..... ~::~ .......... ~:~ ........................ ~. :~ .... ~::~ ............ ~ .......................................................................................................... ......................................................................... 1504 1406.00- 1300. O0 207.08 S 33c/. 52 E c28.89 1&.32 1506. O0 140(:). 00 248.05 S 408.26 E 126.97 :~.:?; ~ =========================== ~:.``~`~;;`~:::::::::;:;:::::;~:~:~:~::~:~;;;;::`:.;;::;~:::;;;;::::;:::;::~:~:~::~::~:~:;;~:~::~:;:::;:::;::~:::'~:``~:~:;:~;~:~:~;~:::~::`::::~:~:`:~;::~>:: :...~:.:~:~,~:~::~:: :: :.:::~: ~:~;.~:: :: ...:.:,'. ,~: ,........-.........................,...,...,...,:.........,..,.,,.,........,......,....,,, ................... ~.....:.: ...... :.: ....................... ~ ~ :::~:::: . ~ ~ ~ :::~ ::~:::::~;: ~ ::::::::: ~ ~ · I<UPARUK ALASKA TRUE SUB-SEA JANUARY 09, 1983 . TOTAL JOB NUMBER AI<-BO-30004 KELLY BUSHING ELEV. = 106.00 FT, i!~ [ i::iiii ~ i.:::i i)i l ii i~i::i[::': ~!)::i i:: i ii[iiiii!~!~i~i~ Wi[ ii: i ii::!ii ~ ~ ::~ ~ [ i i~ ~::i::iii::{ i i i i iii:. ::ii:::: !i ::i ::::::::::i ii ::::::::::::::::::::::::::::::::::::::::::::::::: i ii':i i:::::: ::i ::i:: i::::::::::i ::i i[::iiii ?:ii[ii ii MEASURED VERT I CAL VERT I CAL RECTANGULAR . COORD I NATES MDITVD [ ~ ~ [ [ : ~ ][ ~ [ ~ : ~ ~ [ [ ~ ~l''l:l~: }''['::~ ~:'': ~ ~ [ :~: : ~ } ~ : ~ [ { [ ] [ [ ~::'l':[::~::l:'::{l[::':'::[ ]::I[ ::::::::::::::::::::::::::::::::::: ~ ~: [:~ [: :{ ::[: ] ~:~ ]::I:[: {[~ [.::~: [::~:~::l:[::[: [::[T~[][~[[[:[ : : :[:[:~ ::::::::::::::::::::::::::::::::::::::::: :[::::'::] '':::: ....... : : : : : : : : :. : .::[:[]:;:: :. :::..::::::: .l':::::::::t..[ ,,,.,~ l, : : . . ~ .[ . : :: i . . ~ J:[it ?,l;i?::[:i(:[ f :[:i:i.':!:l~: Y~ ::~: i~[:i::::!]::[::;i]!(i[:]:[:i:i::[![[:[::~ ~ ~:~l]:~i:i~ ~i:i?li:li![![:[:!i[!ii~[[][![::!{:[}i[!}]~:!!::.~ ~ 'l '~'l~!]~:l::[[!i ~ !:i[i!!;!!:[:!]ii[i[!!}i!:i!{T:':T!i[ii:'[:i[]:[i[:' f:ii:!!]{{}l:i:~[!~: ~ [i~.''l!i ~[i:'! ~ ! ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 2471 2106·00 2000·00 551·28 S 9t2)7·58 E 365· 2623 2206. 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' ...................... ~ : * l':]~ '~'~:]: ~:~:~:'~ :T:~'~'~:T: '~:~:]:] :~:~:~: : ~:~'~:~:~'[:~:]:~: ~:] ]~:~:~' :~:~:~:]:~:]:~:~[:~ ~:~:]'~: ~ []~:~:~:~:~:~:~:~:~:{:~:] :{:~:~'~:~:]:~:~'~:~[~:~:~:]:~:~: :~' :{:{:~:~:~:~'~: :~: : :~[~: : : :~ ' '':~ ~]~':'::~T:~: '~: :~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 4545 3306.00' 3200.00 1570.03 $ ~,,.o"-~a~ 22 E 123~. 25 90·.25 4720 3406. O0 3300.00 1665.07 S 2356 . 68 E 1314.75 75 · 50 ' , _Zl. RRcy :~ .=,, A /-. _ ¢') (') A~~O ~7~. 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': '2':' i'~'!~'.} :'P, ii'.': ?'::{::!: :. :!'i{,!ii i:::,i:~':{ i"::< ~!'}'i ":c{il ':'R ;' '" :'? :'i v:',ii,~:'.il ::i :::: :i{.i . ~i:!'. i:: :i.~ ,: ': ! ~": !,.:i: '{ '3 :~ ,i ~ ~i ,'.~ ]' ~? '~': i-,, ~''',~ 5' :ii~i~' ~i :ilili} :: :' X' :::;~-:<"5' ~:: ~'~ 2;I}!i!'P:ii i': ii!:i': iiP:N~i~?:ii::~i.~ii~:~i~::!i!P:~!.:~?`~!.!:~P:P:~!~!.i~%.::~:}:~:3]?/::]P:.::', P::!'::R'}:::ii:,]}{ii'i 21P!YilP:i::iP:': P:'ii'i?i':i{R:i i?iP:i'!::i::::':'~::!Fi~:O:'iiYiliYiTii::'i]?:]lP:P:?/P/iP:iT!:iiii P:il]ilI ~:'~':::~S?::::R:',::,:: : :'":~::P,: "'::":: :d:' ;,': ::;: ':::h" .'.:": A':: :' :::,:: '. ,,: ==========================================' :k::: : :':~::~ ~:~:: ::::::::::::::::::::::::::::::::::: ~':: ": '' :,:::::~" ~. '. ~ ':?': .,",' :::: ;::~ '~ ":~ 'F"?. i: ? x:~C~ ~' :Nxxx ' ' ~ ~ : ~ hx: ::~.~:.~'~...,:{:~:k, ..~ ~', %,.,,'?.". , :' .......... ,,.~'~:':',:~ :::~::,:: ~`~:~.::;~::...:.~".~:.:~:~:`=~....:.:.~.i..~:~`~::~r.~Ni~m:~:~}..~::~(~::~`.~.::~.~::.~:.::.. =~ ...... '..~:::~'.~:N'.,S~:.r.{:::+,::~:~h~.,,:hh:~::~::: ...... ~:~:~:,~::~::::?,~:~::~:h:~::~::~:i:~,.::::: .: :: ~:~:~:~:~:~m~H~m~ KUPARLIK JANUARY (")e? icc..=, dOB NUMBER AK-BO-~.OOO4 ALASKA KELLY BUSHING ELEV. = 106. OO FT. II ._,LIB._ E.A TOI'AL TRUE c. _ q -~ MEASURED VERI' I CAL VERI' I C:AL REK:TAI9OLILAR COORD I NATES MD-TVD VERT I CAL C)' 0 ~ ..... .:._. ..... ~ ........... .~ ......... ,~., ........... ,, ,. . ~t,~..~.:~,, '.t.'. i~,,,~....,~.~ ....... ..t~ ....................... ..: ..... ~!~i"· ,: ........................... ' ........ ' ................... ~~2 ~E-':e.~ ~ "R ~,...., ' ' ,...-~PIP~t~T~, .,. ,...,N ,..,~ ~ = "' ' .... '"'~" '"'""""~' KUPARUK .JANUARY 0~, 1~83 ~IOB NUMBER 'AK-BO-30004 ALASKA KELLY BUSHING ELEV. = 10~.00 F.T. TRUE SUB-SEA TOTAL MEASURED VERTICAL gERTICAL RECTANGULAR COORDINATES . TI-I ' .T-. r'I ~., w ' w ,=."r h,i ,- c, · .. :~:~:~..~...~.~:~:~'.~.~:~:~:~:..~'~:~:~:~:~:..~:~:~:~:~.~:~:..~.~:~:~:~:~:~::~:~:~;[:~:::~:~:..:~:~:~:~:~:~:..:~:?.~:~:::~..:]:~;~: i:h!i :ii i:!: ~..: i ~: i i :i: i '. :ii:'..:.'!iiii::r:: ::i:: h i(.i ! h!:ii:!!: :;l:ri!:[i'L]!!i]!~! !:i:L m: t:r i :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :`:.:.~..:.`~:.::`.~.........`~....~...`:.7....??~`..`::....:..~..~....`::...::==''' ............. ':"'~'~:.~" .................. '"' '"'--'""U~_' .... "': ~"":' '-~-~,-:,',,." ~"'"---~.' ' ~' '"------~':~.: ".-,:L~'''''_ ""',.:_..L ':'"'~'."T2:: :"..L;LL! ,: '. ! ~'~...::.:!..::.":'": ........ ~L::.::..:.: ..... ! ........................... 9092 6218.56 · 6112.56 433,;. 38 $ 4163.29 E TOP LOWER SAND SURVEY DEPTH ~j Z~,T,: i~..~L.~ I J~J::~ ,n, b, ~ r', ,, ,, i~'~~'~i!'('~ ...... ii'~'t"!i'"~'""~ ......... i ...... '" ........ !; !!i!i :,i :;!::':::::iiiiiiii':!~ii!iii!!:'.i!::iiii!:/:':i!~::::!!!::iiii!ii!:, i! ~ii ~ !~ , i:~:~;~:.~!~ :::::::::::::::::::::::::: ::.:::: ::::::::::::::::::::::::::::: :: :::::::::::.::. :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::: :::::: :::::::::::::::::::::: 0 0 O." ~i~i~;/ji :.!., ~:: ~i! i:i ::; ::i~:J~iiii:: :; :. :/:ii!iii~:.! ;/X~ ::ii iiiiii::i::!i;~h?:i!i!!i?//:iil!;i!:?j ii'/:i :: !i i:/:il i i:: ~:~i~i~~iiiiii~!~iiiii~:iii!iiiiiiiiiiiii~iii~i:~ii~iii::~i::ii!~iiiiiii?~?~!$?:iiiiiiii$:i~iiiiiiii::ii::iii:~ ii ': ~:ii~i~iiiiii$i~i~i~$~:i~;iiiii~ii~::?:ii~ii~/;i~?/:iiiii~:~:~i::~://:i~:~:/~i~i~:ii:~i;?::~?;~?~ii::ii~ii~?:iii:.i~?:i?~?:i$iii~::iiiiii~ii?:?/:i~i~i~i~i~i~:~:iii :':!~ DERIVED USING DIL DEPTHS'.AND ,SPERRY ~UN SURVEY DATA H'.~:~h?.: ~?.~:?.'...:~:Hi~:~P~H:~: .1:~:~,~:?'.:P:'.'..'.:.,','.r..~.~.'~.',' :`~r~...~.:........:~?.::~.1~:P....?.~.~.~:.~.:.::..:.:.`:~..H.`.Hh~H~h~::~:i~.1:~H~p~:~ ?.i:~:~:~H :~: ~ ~ i H~: ~'"'"' '"~ ":'": :~ ~ ~ Hi~ ~ HHiHHH~H ~ H~HH~:~}}H~TM P?'?":::":~'"::~-:""?":::"'::~Hh~:~P~b~.1:~i.1:Ht~li~P$' ......... :" H ": ........ ~:H:i~.1H?"U":':.H?:P:"'" .'r.::-.::r:::-'"-+:?'"]'.:r,r.:::m~¥. :rj:::x: .. TOP UPPER SAND . 8853 .: ' 6044,24 : 5~3a.24 4176.07S 4122.45E '~' ,,.:~:'::::'::=~ :"':~;::::;; :::::::::::::::::::::::::::::::::::::::::::::::: ~: :~: ;'.::: ~'.; :l '.~':: ::~ ~:::,.::yw,:::::::::::::m',:~:;~:,.:','.'.:p:'.'.::~:~:p:;',::~:~::D:',~ ~::~ '.~'. ~:~: ~:~ ~: ~a¢~::~ ~:~ :!:D:~B:~D~i:~;~":~!~:D:ii~i: ~ Fi~ ~ ~ii~:::'.:~D::::~i::~'.~i'.:i'.~:i:::~i~:::: :$ ~x'.:::;:::::::::'.~'.:'.::: ~ ~::'. ~p.:~ :'.p: '.:'.::i: ea:~:i:~i;~:i:~?.i:~:?,i:{~'.!:~::.,,::i:k..:',;:: .:,{:i$?,H'.??, h ~ ,.:'.: h :.,,?.l:i,:x.;;~:.,.:: { ~ ~ k,~i~ ~ x:::?:~?:i ::i::~ :. ~ . .~::':~',: ~ .................... . ...................... .......... ...... :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .:::. ............................................ ¥,: :::::::::::::: ' :: ~:::::: ',: ' ,, .,::::: .' ; ' ::::::::::::::::::::::::::::: ;. ~. ::::::::::::::::::::::::::::::::::::::::::: ::::~: ;~ :::::~ :::~:: ::: "::..~: ::'~ ~":~:;::::' :' '::::t::P:::~:: ' "::. :, ::~:::::::' ,: '::::i~::::~:~$~:l~:~::~:~:~:::: ::?~:::::: ::::::::::::::::::::::::::::::::::::::::::::::: .... ::: : .;::::::. ,: :;' '::: ::::::::::::' ';:: ;:; .' ::': TOTAL DEPTH DRILLER ,,'9480 6508.1:3 6402.1:3 4584.73S 4226.70E ~i~i~ i!i!i~i~i~!~ki~F/:~:: iii!ii ii!i: [: i li~il!ili[i!iii ................ i i:;ii i:;i[ ~!iiii~ ii iii.,........., ~i~ i~ i i il i~i~iiii!~i~i ............... ii i! i:: i!i! ....:...: ~iil ~iii~i!':iiii .......... !ii iS !:: ~i i~!i i i iii ~ilili~! ~! iii ~i$/!i ~!ii~i~ i l!~i~i!!~ ih:i==::,~!:=:: ::::i::,:==== ;. ==: : ii ?~iii ..'..~i?i??~!i~i:~!~!:~!!!~i~!!~!?~i!~ill!::!!::?=:::i:~i::~::==:~:=:=::: :: ::.1 :::: .1;: ::::::::;i:: :1.1:! %:: :;:!:: :: ::: :::.1.1::.1;!:i:i: :::::::::::::::::::::::::::::::: :::::::::::::::::::::::::: :::::: :::: ::::.: :::;:;::: ::;:::: :::::::::::::::::::::::::: ::::::::::::::: !!:~!;i::!~::!;'~ ~ ~ i~[: ::1[ !}ii'~'~ii~ia ~il !:: !i i ii! ~ ~:~ilil }ii;iii ~'~:~ ~ ~ i~i '~ !! i?.~:~i:. !i~i'~!i!i::ii?:~ :~i!i!i!iil ~ ~ jill ~::i!!_'"i ~ i ii!ii::}i i~:~iiii~ii~ i~ ~ ~ i~i~! i iiiia?:il}i !iii?:!::i:,!!illili i?:!!ili::ili ::i Iii ii! iii ii ~ii!ii! !!!ii::ii ii i iii!~ill ii'ii ?: ? i iiaii?:ii !::!i!::!i! ::ii!i!i i li!iiiii?:ii i!i?: i i}ia!!!~i::!i!i !!!iiii~ili!i?:il i iilll i iiii?;ili:.i!i:,i?.i!i i iiiii!i !::?:~i !::!!~i ::ii! ii i i!i!i ::i:/:!i~!i ?.i!!!:,i!i!iiiii~?:iiiiiii !;:ii!i~i~i:i~i ~!~::~::~!~::. i~:~i~; !:i~:~ ?:~ !:i~i?,:,!ii::!i!~ ?:::ii fi! ::i!i!i? ? ::: ?.i! :. ::~?:!!~?::.?:.~!~?~.!::?:Si~!~?:~?.~?:<:~!~i:i~i~!ii!!i!::!iiiii i1~' _~IIR~,)P'V . I~KII I,'~.I::;,V ~"l~. ;.~.;.~.;.;.;..;.. · ~:~..~.;.~.; ~;.;.~: ~ .~ .~ ;x~, ~ ,~.~..~ :'~';:~; ;:~ :~:~ ~:. ~...~.:.:., :::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~.:.:.:...:.:.:.:. :.;.:.:.:.:.:.:::.: .:: :;:::$~::::::::::::::::~::~:::;.1:::~:~:::i$:~::::::::::::::::::::::::~:~.1~:::::~:~:~:::~:~:~:~:i:i:~:~:~:~:~:~:~:~:~:~:i:~::.~:~:~:~.1.1:~.1:~:~:~:~:~:::~:~::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::: _. _- . ._ ,- ~., . ..,...._ . . Our' Boss G'yruscopic Survey .... '*-' ..... Job No. AK-BO-30004. Well: #1E-22 (SEC 16 TllN R10E) ' · ~ . ~--; i~. -:-'~-,-.i--'".i,,'~-i/:. :i:!!';-/"7~,._-.~_ -~'.:-C';~::-.i .--.;.- -'- ~ ~ - _ - ~ <-. :--"L"..: ;-:':. ! '--..:'- ' ... - ":': :¢-' ' ~~ SlOpe, Alaska : -. ...... . -:,:_,._,:_.--¢--: !~'_ --_~._.~-- _ ,:-' -- , .- _.-_ .. . i 40o0~ oo - 9480. HORIZONTF~L PROJECT I"ON · 0 . ~-.- 8oom-oo, 2oho. oo 4oho. oo 6oho. oo VER T ~ CgL PR~IJECTIO~ eobo. oO Suggested form to be inserted in each "Active" well folder t° d:eck for timely compliance with our regulations. " ~ Ope-r~tor, Wel 1 ~ame and Number Reports and Materials to be received by: ~ --? Date Required Date Received Remarks ' · ., ! · .. Wel 1 History Yes _Samples .-, ~ , , , _ /lx -_h_ i 'i"i /,i' . Core Chips .f~ '~i'~,. Core Description ~../??'~?~ ~, ~J ' L.~. -.-- .. . ~ .% ,, · Registered Survey Plat ~. C ~., . /' Inclination Survey - Directional Survey ~ ..... -- , - / ',~' t. Drill Stun Test Reports Production Test s > . Logs Run-. Yes ...... , .- , ..... Digitized Data y~( '? .... 0 x~ .?'-)_.. - .. ..... ., '/":~ ~,~ ~:._,:.:., M. ,'-~-,l e... SCHLUMBEF OFFSHORE SERVICES 5000 GULF FREEWAY, P.O. BOX 2175 HOUSTON, TEXAS 77001, (713) 928-4000 PLEASE REPLY TO 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99502 February 17, 1983 Dear Customer, We have discovered an error in the Library Tapes for the following well: COMPANY NAME: ATLANTIC RICHFIELD COMPANY JOB NUMBER: 66254 Enclosed are replacement* tapes for the above listed well. Please destroy the original tapes you have already received and replace with these enclosed. We apologize for any in- convenience this has caused. Thank y o u, S.E. Log Analyst ~Correet ~nterval 8908~ - 8917~ to overlay bluelSne. ~., SEK: smm cc:distribution A DIVISION OF SCHLUMBERGER LIMITED Transmitted herewith are the following: PLWASE NOTE: BL - BI/3ELINE, $ - SEPIA, F - FII~~ PC - PH~PY ARCO AI. ASKA, INC. Alaska 0il & Gas Cons, CommJssior~ ATZ'N: ~ - AFA/3ZZ Anchorage P. o. ~x 3~o .~-~/, AN(/"/ORAGE, AK. 99510- Transmitted herewith are the follc~ing: - P~.~ASE NOTE~- Frr~I, T- TAPE~ PC- PHOICCOPY - ~ ~, INC. Alaska 0il & Gas Cons. Con]miss[or) AT~: '~[R~i~iI~ - AFA/311 Anchorage -A.,N(~ORAGE, AK. 99510 -- ARCO Alaska, Inc/'''~. Post Office .. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 10, 1983 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton- Enclosed are monthly reports for January on these drill sites' 1-24 1E-20 7-18 1E-21 7-19 1E-22 7-20 1F-1 12-17 1G-6 12-18 1G-7 13-9 1Y-13 13-98 WSW-IO WSW-11 Tract Well 24-11-14 CIRI Wolf Lake Well #1 Ravik State #1 A1 so enclosed are well completion reports for' 2-11' 1E-23 7-17 1F-2 12-19 1F-3 13-11 1G-8 13-21 WSW-8 13-24 WSW-9 The survey for 2-22 needs to be reran; a completion report for this well' will be submitted when an approved survey is received. We also are including subsequent Sundry Reports for 1-24A, 2-11, 13-21 (3 reports), and 13-24. ARCO A'laska. nc. is a subsidiary of AllanticRichfieldCompany , ~- STATE OF ALASKA ' ALASKAC. AND GAS CONSERVATION COl ,ISSION MONTHLY RERORT OF DltlLLINO WOI:IKOVEI:I OPE TION$ 1. Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 8 2 - 214 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 50- 029-20884 9. Unit or Lease Name Kuparuk River Unit 4. Location of Well atsurface 225'FEL, 291' FSL, Sec. 16, TllN, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 72' RKB ADL 25651 ALK 469 10. Well No. 1E-22 11. Field and Pool Kuparuk River Fie Id Kuparuk River Oil Pool For the MOnth of January ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 2130 hrs, 12/26/82. Drld 13-1/2" hole to 2475'; ran, cmtd & tstd 10-3/4" csg. Drld 8-3/4" hole to 9480'; ran logs. Ran, cmtd & tstd 7" csg. Ran CBL. Perf'd well. Ran 3-1/2" completion assembly. Secured well & released rig @ 1900 hrs, 01/10/83. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 10-3/4", 45.5#/ft, K-55, BTC csgw/shoe @ 2449'. Cmtd w/1500 sxAS III & 250 sxAS I. 7", 26.0#/ft~ K-55, BTC csg W/shoe @ 9341'. Cmtd w/725 sx Class G. SEE DRILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/SP/GR/Cal/FDC/CNL CBL f/9260 ' - 2000 ' f/9469' 6. DST data, perforating data, shows of H2S, miscellaneous data 9112'-9132' 8855'-8958' 8 spf, 120° phasing. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S,GNED ~~. ~-/~ T,TLE Area Drilling Engineer DATE ~2/~_~ NOTE--Re~rt ~n thi~orm is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and G~ Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~04 Submit in duplicate 1E-22 DRILLING HISTORY NU Hydril & Diverter. Spudded well @ 2130 hrs, 12/26/82. Drld 13-1/2" hole to 2475'. Ran 60 jts. 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2449'. Cmtd 10-3/4" csg w/1500 sx AS III & 250 sx AS I. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS, cmt & 7' new form. Tstd form to 12.5 ppg EMW - ok. Drld~ 8-3/4" hole to 9480' TD (01/05/83). Ran DIL/SFL/SP/GR/Cal/FDC/CNL f/9469'. Ran 238 jts 7",' 26.0#/ft, K-55, BTC csg w/shoe @ 9341'. Cmtd 7" csg w/375 sx Class G & 350 sx Columbia G. Instld 7" packoff & tstd to 3000 psi - ok. Ran CBL f/9260'-2000' - good bond. Arctic Packed 7" x 10-3/4" ann w/300 bbls H20, 250 sx AS I & 98 bbls Arctic Pack. Perf'd the following intervals w/8 spf, 120° phasing: 9112'-9132' 8938'-8958' 8918'-8938' 8897'-8918' 8876'-8897' 8855'-8876' Ran 3 1/2" completion assy w/tail @ 8772', pkr @ 8743' & SSSV @ 2149' ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well w/diesel. Dropped ball & set pkr. Closed SSSV. Set BPV. Secured well & released rig @ 1900 hrs, 01/10/83. JG- 1 lm 02/0z/83 KUPARUK F/~GINFERING TRA~S~TAL # ~ William VanAlen D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PT,VASE NOTE: BL - BI/33LINE, S - SEPIA, F - F!!~I,~PC - PHOTOCOPY , ~ ACKNfTNLSDG2D: yPIYASE ~ PdDCEIPT TO: P. O. BOX 360 & Gas Oo~s. Commi,~ior~ A/~CHO~, AK. 99510 Anchorage KUPARUK ENGINRR. RING TO: William VanAlen D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PI.FASE NOTE: BL - BIi3ELINE, S - SEPIA, F - FILM~ PC - PH~PY / ~I~ ACKNC~T.~F~D: ~I.F3~E P~ RtDCEIPT TO: ARCO ALASKA, INC. A%'I'N: LORIE L. JOHNSON - AFA/311 ?,laska (Iii & Gas Cons, P. O. BOX 360 ^l,cl~,oraf~e ANCHORAGE, AK. 99510 ARCO-Alaska,linc. ~ Post Office B,. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 13, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' .Enclosed are mOnthly reports for December on these drill sites' 1-24 13-14 1G-7 2:11 13-98 1G-8 7'-16 1E-22 WSW-8 7-17 1E-23 WSW-9 7-18 1E-24 WSW-iO 12-18 1F-2 Tract Well 24-11-14 12-19 1F-3 CIRI Wolf Lake Well #1 13-11 1F-4' A1 so enclosed are well completion reports for' 1-22 13-13 1-23 14-6 6-24 1C-1 7-15 1C-IOGI 12-20 1E-25 13-6 The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. We also are including subsequent Sundry Reports for 7-17, 13-6, 14-6 and 1C-1. Since the information on the Wolf Lake and Tract wells is of a confidential nature, we would appreciate it if you could store i't in a secure area. Sincerely, P. A. VanDusen District Drill ing Engineer PAV/JGL28'llm Attachments JAN 783- - AiasV,~ 0il & Gas Cons. C0rnmis$i0r~ Anchorage ARCO Alaska, Inc. is a subsidiary of AllanlicRichfieldCompany STATE OF ALASKA ALASKAC_ AND GAS CONSERVATION CO. ,IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well Workover operation [] Name of operator ARCO Alaska, Inc. 3. Address P.O. Box 360, Anchorage, Alaska 4. Location of Well at surface 225'FEL, 291'FSL, Sec. 5. Elevation in feet (indicate KB, DF, etc.) 72' RKB 99510 16, T11N, RIOE, UM 6. Lease Designation and Serial No. ADL 25651ALK 469 7. Permit No. '82-214 8. APl Number 5o- 029-20884 9. Unit or Lease Name Kuoaruk River Unit 10. Well' No. 1F-22 11. Field and Pool Kuparuk River Field Kuparuk River Oil P6ol For the Month of. December ,19. 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks ~/ Spudded well @ 2130 hrs, 12/26/82. Drld 13-1/2" hole to 2475'; ran, cmtd & tstd 10-3 4" csg. Drld 8-3/4" hole to 5132' as of 12/31/82. SEE DRILLING 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 @ 2449'. Cmtd w/1500 sx AS III & 250 sx AS I. SEE DRILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run None to date 1 6. DST data, perforating data, shows of H2S, miscellaneous data N/A RECEIVED JAN 4 i9B3 Alaska Oil & Gas Cons, Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED.--~g4'' '(~ -~...T~TiTLE Sr. Drilling Engineer DATE I-t - E 3, NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate 1E-22 DRILLING HISTORY NU Hydril & Diverter. Spudded well @ 2130 hrs, 12/26/82. Drld 13-1/2" hole to 2475'. Ran 60 jts. 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2449'. Cmtd 10-3/4" csg w/1500 sx AS III & 250 sx AS I. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS, cmt & 7' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-3/4" hole to 5132' as of 12/31/82. JG'ltc FO2 JAN i Alaska Oil & Gas Cons. Commission Anchorage MEMORANDUM State of ALASKA OIL ~D ~-GAS CONSERVATION COMMISSION _~,~, (./ .., FILE NO: .1. 0 8A/F THRU: Lonnie C. Smith ; TELEPHONE NO: ~ Commi ssioner FROM: SUBJECT: Edgar W. Sipple, P~troleum Inspector~ Alaska 6, 1982 Witness BOPE Test at ARCO's Kuparuk 1~-22 Sec. 16, TllN, R10E, MUM Permit No. 82-214 Rowan 34 k~edne_sday~_ De.cemb~r 29,_ 1982 - I traveled this date from Parker 141 (subject of another report) to ARCO Kuparuk 1E-22 Rowan Drilling Rig 34. The drilling rig was in the process of nippling up. The BOPE test com..Fenced at 9:20 p.m. and was concluded at 11:45 p.m. There %~re no failures. I filled out the A.O.G.C.C. BOPE test report which is attached. In summa~-f, I ~zitnessed the P~OPE test on ARCO's Kuparuk 1E-22, Ro%mn 34. ,BOPE Stack . ~nul a r Preventer-- Blind Pams 6ke~ Line Valves . ~7-~$~ ~ ~ -. H.C.R. Valve---- Ril 1 Line Valves-- Check Valve ALASKA C. & CAS CD~!SERVA'I'[( B.O.P.E. Inspection l-te[..~rt .. Well _ ~- tL ~it. ~ ~'~'~/~ ~tion: SecI$T'I~.R;O~ FI~ ' /~9. casin~ ~e["~'~~ ft. ~illinq ~n~a~or___~e~ Rig ~ ~Y Repre~ntative ~w .. ~tion, ~nera] . _ mtf ._ ' AcCb~UIA~R~YS'~' ' - .~. Well Sign . _~_~. ~11 0~Jrge.-' ~es~re Ceneral Hollering ~ .... ~esshre After C16kure /~ t:)~"psig~ ~ese~e pit .... ~_~ ~p. incr.' c,lOs~ pres. 200. ps~'~ '"; ~n ~f.sec , . ~ ~11Ch~'.',~e~$u~At.ta~;' .~ ~n~'sec. : z - .",' ~ · - Test ~es~e ~elly and Flor Safe%, val:v~s .' ~t~ a~O0 ~per Kelly .0~ ..Test. PresSu~:e:t~'~.(+.~~ . . , ..-...... . ~.~eo ~ur Kelly 01< Test ~es~e . . ..... ~0~o I~ide ~ O~ Test ~es~r~ ..... ~ooo - Choke ~nifold O~ Test ~essure ~ ~j~able Chokes /' _-" ~~ .Jt~ldraui~l ly operat~ ch~e Test Results: Failures ---' O-' - Test-Timp Repair or Replacement of failed oquipn~nt to be made within_ ~/~ ~days and ..~ ~ .- , inspecto~./...,,Cc~mi~Sion off ice n'otificd. Remarks, ~x,j ~'J --~F~ ~. _ Distribution .orig. - AO&I]2C cc - Operator cc' - Supervisor Ins~ctor~ December 23, 1982 ~x. Jeffrey B. Kewin Senior Drilling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, A1aska 99510. ~E 22 Re: Kuparuk River Unit .~- . ARCO Alaska, Inc. Pe~it No 82-214 ~ F~, Sur. Loc. 2z5' ~ 291'FSL, Sec 16, Tll~;:, R10E Btm~ole Loc. 4193'~WL, 4197'~qL, Sec. 22, TllN, R10E, Enclosed is the approved application for oermit to drill the above referenced well._ If coring is conducted, a one cubic inch chip from each foot of recovered core im requested. ~am..ples of well cuttings and a Io~ are not required. A continuous' directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing t~e digitized log information shall be subr0itted on all logs for. copying except exPerimental logs, velocity surveys and dipme~e~ surveys. rems have been ~ny rivers ~.n ~ ska and their drainage sys classified as important for the spa~ing or migration of anadromous fish. OPerations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (~--~ = ~s~a Administrative Code). '.Prior to commencing -.mn~ .~, = ......... ' ' by the habitat Coordinat°r~'s ooerations you may be contacte~ O~fice, Deo~rtm. ent of Fish and Game. Pollution of any water~ of the State is prohibited by AS 46, Chaoter 3 Article 7 and the regulations promulgated thereunder (Title 18, A~as~a Adsinistrativ~ Code, Chaoter 70) and by the as mnended. Prior to F~deral Water Po!~''~n Control Act, cor~ncing operations you may be contacted by a representative of the Department of Environ~mental Conservation. To aid us in scheduling field work, piea~e notify this office -4 orior to commencing installation of the blowout 2~ hours ~ ~ Mr. Jeffrey B. Kew~n Kuparuk River Unit 1E-22 -2- December 23, 1982 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, ~.ere a diverter system is required, please also notify thls~offtce 24 hours prior to commencing equipment installation so that the Commission may witness testing .before dritling betow the shoe of the conductor pipe. In the event of suspension or abandoDm~ent, please give this office adequate advance notification so that we may have a witness present, Very_ truly ~ your s, ~-C. V. ChattertOn Alaska Oil and Gas conservation Co~Isston Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. CVC: be. ARCO Alaska, Inc. Post Office [ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 15, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 1E-22 Dear Mr. Chatterton' Enclosed are' o An application for Permit to Drill Kuparuk 1E-22, along with a $100 application fee. o A diagram showing the proposed horizontal and vertical projections of the wellbore. o A proximity map indicating the relative location of Kuparuk wells 1E-23, 1E-24, 1E-25, 1E-3, and West Sak River State #2. o A discussion of wellbore crossings. o A diagram and description of the surface hole diverter system. o A diagram and description of the BOP equipment. o A map showing the location of the well, as built. Since we estimate spudding this well on December 29, 1982, your prompt approval will be appreciated. If you have any questions, please call me. at 263-4970. S';ncerely, /Senior Drilling Engineer JBK/JG:sm Enclosures GRU1/L7 RECEIVED DEC16 1§82 Aiask~ 0it & Gas Cons, Commission Anchorage ARCO Alaska. Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA O,L AND GAS CONSERVATION CO~,,,vllSSlON. PERMIT TO DRILL 20 AAC 25.O05 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 225' FEL, 291' FSL, Sec. 16, T11N, R10E, UN At top of proposed producing interval 3835' FWL, 3833' FNL, Sec. 22, T11N, RIOE, UN At total depth 4193' FWL, 4197' FNL, Sec. 22, T11N, RIOE, UM DEC 1 6 J982 /Uaska Oil & Gas Cons. Comrni,, Anchorage 5. Elevation in feet (indicate KB, DF etc.) PAD 72', RKB 106' 6. Lease designation and serial no. ADL 25651 ALK 469 9. Unit or lease name Kuparuk River Unit 10. Well number 1E-22 Field and pool Kuparuk River Field Kuparuk River Oil Pool 12. Bond information (see 20AAC25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 16. Proposed depth (MD & TVD) 9371' MD, 6476' TVD 14. Distance to nearest property or lease line At total depth, 1083 feet 13. Distance and direction from nearest town 30 Mi les NW of Deadhorse miles 17. Number of acres in lease feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 52 Ol (see 20 AAC 25.035 (c) (2) Proposed Casing, Liner and Cementing Program 15. Distance to nearest drilling or completed WestwSe~k River2~a~e4482, MD feet 18. Approximate spud date 12/29/82 21 2_560 _ psig@ _RO°F Surface 290? psig@ 6066 ft. TD (TVD) i Hole SIZE Casing Weight 24" 16" 65# i3-1/2" 10-3/4" 45.5# i 8-3/4" 7" 26# 22. Describe proposed program: CASING AND LINER Grade Coupling H-40 Welded K-55 I BTC K-55. IBTC Length 80' SETTING DEPTH MD TOP TVD 35' 35' 2511' 33' I 33' 31 ' I 31 ' 9340' MD BOTTOM TVD 115' 115' 2544'12200' I 9371' 16476' I I QUANTITY OF CEMENT (include stage data) 250 cf ~ 1200 sx AS III +250 sx AS I 850 sx Class "G" ~ iARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approx. 9371' MD, (6476' TVD). !Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor iwhile drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 10-3/4" surface ipipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi iforannular), maximum surface will be 2560 Pressure calculations based Expected pressure psig. are on icurrent reservoir pressure. Surface pressure calculated with unexpanded gas bubble at surface including itemperature effects. The well will be completed with 3-1/2", 9.2#, J-55 buttress tbg. Non-freezing fluids iwill be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within ithe Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested !upon completion of the job. See attached well crossing analysis. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge Samples required []YES '~;~] N O CONDITIONS OF APPROVAL Mud Icg required I Directional Survey required OYES ~0 L J~YES I-]NO DATE IAPI number 50- oz.~-~ ~,~'y Permit number . ,. (~f- Approval date [ SEE COVER LETTER FOR OTHER REQUIREMENTS by order of the Commission Form 10~01 GRU1/PD5 ~ ~ ~ Submit in triplicate Sooo ooo YE ~ooo SECT ON 000 "/.Ohorago CL'/r/~/sa.&l~ ANALYSIS OF 1E-22/1E-24, 1E-22/1E-23, AND 1E-22/WEST SAK RIVER STATE #2 WELL CROSSINGS NOTE: Refer to the attached Proximity Maps. 1E-22/1E-24 The proposed Well 1E-22 will pass within a distance of 85' (at a measured depth of 1089') of well 1E-24. This distance was calculated using the single-shot data for 1E-24 and assuming that well 1E-22 will be drilled directionally as planned. Well 1E-24 will have a cone of uncertainty of 8' in diameter at the depth at which the minimum distance occurs. Well 1E-22 will have an ellipse of uncertainty of 39' across its major axis at the depth of interest. The areas of uncertainty for the two wells will, therefore, not intersect. If survey data indicate that the areas of uncertainty will overlap, the Contingency Procedures outlined below will be used. 1E-22/1E-23 The proposed well 1E-22 will pass within a distance of 43' (at a measured depth of 920') of the proposed well 1E-23. This distance was calculated using, the proposed well-path data for 1E-23 and assuming that well 1E-22 will be drilled directionally as planned. Well 1E-23 will have a cone of uncertainty of 7' in diameter at the depth at which the minimum distance occurs. Well 1E-22 will have an ellipse of uncertainty of 28' across its major axis at the depth of interest. The areas of uncertainty for the two wells will, therefore, not intersect. If survey data indicate that the areas of uncertainty will overlap, the Contingency Procedures outlined below will be used. 1E-22/West Sak River State #2 The proposed well 1E-22 will pass within a distance of 27' (at a measured depth of 4482') of the plugged and abandoned well West Sak River State #2. This distance was calculated assuming West Sak River State #2 to be vertical and assuming that well 1E-22 will be drilled directionally as planned. West Sak River State #2 has a maximum cone of departure of 118' in diameter at the depth at which the minimum distance occurs. Well 1E-22 will have an ellipse of uncertainty of 375' across its major axis at the depth of interest. The areas of uncertainty for the two wells will, therefore, overlap by 220'. ¢ , Because the areas of uncertainty overlap,~A~RCO proposes~that an adequate amount of left lead (azimuth) be establ~-h~kicking-off 1E-22. A left lead angle of about 10° will avoid an overlap of the areas of uncertainty. ~! i~ ~ ~ ~ Gas 63ns. Oommissiori Contingency Procedures If survey data indicate that the areas of uncertainty will overlap, the following procedures will be used' 1. A deflection assembly will be run above the potential intersection to deflect the well in the appropriate direction. 2. All drilling parameters will be closely monitored until a safe crossing is made. 12/15/82 GRU2/A4 [CEIVL: DEC 1 5 ~982 Alaska 0il & Gas Cons, commission Anchorage Surface Diverter System 1. 16" Bradenhead. 2. 16" x 20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/10" side outlets. 4. 10" ball valves, hyraulically actuated, w/10" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell j~ipple. 16" Conductor that gas or fluid flow to surface is detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not shut in well under any circumstances. · Maintenance & Operation ~ 1. Upon initial installation close annular i preventer and verify that ball valves ! - have opened properly. i 2. Close annular preventer and blow air ~__ through diverter lines every 12 hours. 3. Close annular preventer in the event ~%5/8" 5000 PSt RSRRA BOP STACK~'''' RNNULRR · PREVENTOR 9 ( BLIND RRMS · 8 ) £ ) ) ( , L ) 7 { ) PIPE RRMS (, ) ) ( L L PIPE RRMS ] () () 3, 6. 7. 8. TBG - DEC e 14. ~as~a Oil & Gas Cons. Ancho~ag~ 1. 16" Bradenhead 2. 16" 2000 PSI x lO" 3000 PSI casing head 3. 10" 3000 PSI tubing head 4. 10" 3000 PSI x 13-5/8" 5000 PSI adapter spool 5. 13-5/8" 5000 PSI pipe rams 6. 13-5/8" 5000 PSI drilling spool w/choke and kill. lines 7. 13-5/8" 5000 PSI pipe rams 8. 13-5/8" 5000 PSI blind rams 9. 13-5/8" 5000 PSI annular . ACCL~,IULATOR CAPACITY TEST 1. · CHECK AND FILL ACCiRqULATOR RESERVOIR TO PROPER LEVEL WITd HYDRAULIC FLUID. 2. ASSURE THAT ACCCMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DC?~!,~LSTREAR OF THE REGULATOR. 3. OBSERVE TINE TH~ CLOSE ~J_L UNITS SIMULTA~;E- OUSLY AND RECORD THE TIME AND PRESSURE REHAIN- ING AFTER ALL UIIITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON IADC REPORT. THE ACCEPTABLE LO',4ER LIMIT IS 45 SECO:iDS CLOSING TIME AND 1200 PSI REHAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK ~{D MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD Dff~N SCREWS ARE FULLY RE- TRACTED. PREDETER,:,IItiE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCR~S IN HFAD. CLOSE ANNULAR PREVENTER A~D CHOKES A~ID BYPASS VALVES ON ~tA,qIFOLD. TEST ALL COMPOHD{TS TO 250 PSI AND HOLD FOR l0 MINUTES. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR l0 MINUTES. BLEED TO ZERO PSI. OPEN ANNULAR PFL.rV~iTER AND CLOSE TOP SET OF PIPE RAMS. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. CLOSE VALVES, DIPZCTLY UPSII:LEAH OF CHOKES. BLEED DO'RNSTREAR PRESSURE TO ZERO PSI TO TEST VALVES. TEST RDIAINING UNTESTED ~NIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTRE~.:-I OF VALVE AND ZERO PSI D~NSI~.~. BLEED SYSTEM TO ZERO PSI. - 9. OPEN TOP SET OF PIPE RAMS A~ND CLOSE BOTTOM SET OF PIPE Rgu~tS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR lQ MINUTES. BLEED TO ZERO PSI. l l. OPEN BOTTOH SET OF PIPE PJN%S. BACK OFF RUN- NING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RN, LSAND TEST TO 3000 PSI FOR 10 HINUTES. BLEED TO ZERO PSI. 12. OPEN BLI~tD RARS ~'~D RECOVER TEST PLUG. ,MAKE SURE HAtIIFOLD AIiD LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POS I TI ON. TEST STANDPIPE VALVES TO 3000 PSI. TEST KELLY COCKS Arid INSIDE BOP TO 3000 PSI WITH KOOi'dEY PUMP. RECORD TEST INFO,~qATION ON BLO'WOUT PREVE;ITER TEST F'O~! SIGN At(D SEND TO DRILLI;;G SUPER- VISOR. 16. PERFORI-I COMPLETE BOPE TEST O~;CE A WEEK A:iD FUNCTIO~LALLY OPERATE 80PE DAILY. i ~' '"' ~: ~ '---'* n ARCO Alaska, Inc. date' ~~ scale' drawn by' ~vcc~ dwg. ne. '~.~,~: llillllll ..i tall SMIVITOIS CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE thru 8) (1) Fee (2) Loc (3) Admin. '( '~9 thru / 2-15~R'~ 11) (4) ,CaSg ~ /.,~.-I,7...~,,z_ '(12 thru 20) (5)' BO PE ///J/c/ /.~ .]~_~_ (21 thru 24) (6) Add: Company ,...~""~ Lease & Well No. ® Is the permit fee attached ' e,?.~l, ee · · · · · · · · · · · · · I · · · I · i · e i ® e ® e i e i i e el il e 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 ............ 6. Is well to be deviated and is well bore plat included ..... .......... 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait .................. . ........ 9~ 10. 11. 12. 13. 14. 15. 16. I7. 18. 19. 20. 21. 22. 23. 24. 25. YES NO D op ha bond i force ' ' oes erator ve a n ,,,,,.........,,,...,..,.......,.. Is ti d d d . a conserva on or er nee e ................... .... ............ . Is administrative approval needed ................................... Is conductor String 'provided .............. ; ......................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons . . Will surface casing protect fresh water zones Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ..... Are necessary diagrams of diverter';~'~'~i~;' Does BOPE have sufficient pressure rating - Test to ~,z~ pSig .. ply /API ( 78)' Does the choke manifold corn w RP-53 Feb ................... REMARKS Additional requirements Geology: Engi~e ri.rig: ,.cs7_ EW WVA ~! J K ~TS~'~__ HJH ~ rev: 12/06/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not padiculady germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. mmm~m~mm~m~mm~mmm~ LIS T~.PE V~RIF!CA ON::I,!$!ING ,VP OlO,H02 VERIFICATION LISTING PAGE :* REEL HEADER ** ;ERVICE NAME :$ERVIC )ATE :83/02/16 )RIGIN : IEEL NAME :REEL ID :ONTINUATION # ~REVIOUS REEL :OMMENTS :REEL OMMENTS 6, TAPE HEADER ** ;ERVICE NAME :SERVIC )ATE ~83/02/16 )RIGIN :FS1A APE NAME .!ONTINUATIO~ # ~REVIOU$ T~PE :OMMENTS : APE COMMENTS ~.* FILE H.ADER :IbE NAME :SERVIC,O01 # )ATE ~ ~AXIMUM LENGTH : 1024 ~IbE TYPE : ~REVIOUS FiLE INFORMATION RECORDS ~NEM CONTENTS UNIT TYPE CATE SIZE CODE :N' ~ ATLANTIC RICHFIgbD CO, 000 000 022 065 ~N ~ I E"'22: 00:0 000 006 065 rN ~ KtIPARUK 0,00 000 008 065 ~ AN G~' l OE ['OW N 1 1 N ~CT~ 16 000 000 002 065 ~OUN: NORTH Sb()PE 000 000 012 065 ~T T~ ALASKA 000 : 000 006 0 5 :TRY. ,U.$,A' 000 000 006 66~ ~,: COMMENTS ** ( ,VP OlO,H02 VERIFICATION LISTING PAGE 2 ALASKA COMPUTING CENTER * ******************************************************************************* IOMPAN¥' c ATLANTIC RICHFIELD CONPANY 'ELL = IE'22 'IELD = ~UPARUK :OUNTY = NORTH SLOPE.BOROUGH iTATE = ALASKA lOB NUMOF. R AT ACC= 10707.66254 ~UN #1. DATE LOGGED= 6.,jAN.,83 ,DP:RF S ~ASING ~¥PE FLUID ~IT SIZE )ENSITY rI$CO$IT¥ ,H 'LUID LOSS 10 3/4" ~2446 LOW SOLIDS POLYMER 8 3/4" 1 O, 2 bB/G = 44 S 10,0 5,8 C3 RM = 2.9~ ~ ~0 DF RMF = 2, 0 DF R~C ~ 3,~ @ 70 DF R~, AT BHT = 1.64 ~ 152 DF ~ATRIX SANDSTONE ******************************************************************************** .VP 010,H02 VERIFICATION LISTING PAGE SCHLUMBERGER LOGS INCLUDED WITH THIS ~AGNETIC TAPE: DUAL INDUCTION SPHERICALLY FOCUSED LOG (DIL) FORMATION DENSITY COMPENSATED LOG (FDC) COMPENSATED NEUTRON LOG (CNL) GAM~A RAY LOG (OR) DATA FORMAT RECORD ** :NTRY BLOCKS TYPE SIZE REPR CODE ENTRY 4 ! 66 1 B 4 73 60 9 4 65 .lin 0 I 66 0 tATU~ SPECIFICATION B6OCKS ~NEM SERVICE SERViCe] UNIT ID ORDER # LOG::TYP:E CLASS MOD NO. )EPT FT 0 0 0 0 0 )RHO ND tHOB FDN tCNL FD ~ALI FDN ,R FDN [NRA F DN 4 PU 42 68 2 0 0 4 4 4 .... ::42: : ::0 0 ::: :: 0 0 4 AP1 API API APl FIbK SIZE PROCESS SA~PS~ REPR LEVEL CODE 68 1 I 6B I 68 1 6 B 1 ~8 DATA ,VP OlO,H02 VERIFIChTION LISTING PAGE 4 ,EPT 9500,5000 SFLU 2 8887 ILM ~P -2,5156 GR 118:0000 NPHI ,HOB 2,0215 NCNb 2152,0000 FCNL :R 118,0000 RNRA 3,5234 ~EPT 9400 0000 SFLO 2,2539 IbM ~P -20:6406 GR 108,4375 NPHI :HOB 2.3848 NCNb 1939,0000 FCNL ;R 108.4375 RNRA 3,9512 ~EPT 9300 0000 SFLU 2, ;P -21:3281 GR 101. ~HDB 2~94~12 NCNb 1989, ;R 101 75 RNRA 4, 5430 IbM 9375 NPHI 0000 FCNL 0156 ~EPT 9200,0000 SFLU 8,8281 IbM ;P -27,5156 GR 48,5625 NPHI IHOB 2.3438 NCNb 3670,0000 FCNL ;R 48,5625 RNRA 3,0273 )EPT 9!00.80000 SFLU ~, iP 22, 594 GR ? , [HOB 2,3789 NCNb 2614, ;R 79,3125 RNRA 3, )EPT 9000 ~HOB ;a 77 )gPT 8900 -46 ,R )EPT )EPT {P )EPT ~HOB ;R 2,2949 ILO 38,8672 DRHO 610,5000 CAbI 2,0938 40,9180 DRHO 490,5000 CALl {P ~HOB ,738 4 , 898 DRHO 495,2500 CAbI B 1875 IbP 2 DRMO 1212, CALl 117 IbM 125 NPHI 0000 FCNL 0098 5,2695 30,2734 DRHO 868,5000 CALl 0000 SFLU 531{.3: OR: :, 3 887 N C N b 5625: RN:RA 8906 I b {~ 185 5 6,2187 28,7598 DRHO 844.0(300 CALI 45,8750 54* 9062 NCNI~ :: 24'66,0000 RNRA 3;4453 FCNL ].,1250 : lb:l> ,9395 ~RHO 7!5,5000 CAbI 8800 0000 SFLU 8700,0'0:00 SFbU, :: : :l,4:7'46::,: :I:b:t4 -18,9687 GR 1'28,7500 NPHI 12'28'9128 NCNb: :1904,000:0 :,FCNL ,7500 RNRA 4,1445 2402 DRi, i'O 459,0000 CALl 0000 SFLU O0 00 RNRA 1,9658 ILM , 1,8965IBD ' ,2500 FCNL -999,2500 CALl · ,999,2500 8500, 0:00 :::$~LU "26,3750 GR -999,'2500 NCNI~:: :i . 3, ~723 .999,250(..) DRHO ~5()0 FCNL 999. 2500 CALI 2000,0000 0,1763 8,7500 1,9775 0,1147 9,7969 ,64, 56½ 10.8516 9,0391 0,1289 9,5234 5,2500 0,0278 9,9141 6,0313 9, '8750 7o:o 8 9,3359 .6084 0430 9609 ,1152 ,0254 10,I094 1,8506 ,250 ".882 0742 ,2500 9,9141 VP 010,H02 VERIFICATION [,ISTING PAGE 5 R 232,7500 RNRA -999,2500 EPT 8400,0000 SFLU P -24,7031 GR MOB -999,2500 NCNb R 141,7500 RNRA 2 2480 ILM 141:7500 NPHI -999,2500 FCNL -999.2500 1,7168 -999.2500 DRHO -999,2500 CALI EPT 8.~0~,0000 SFLU P 2 , OOOO GR }{OB 999,2500 NCNb R 118,0000 RNRA 3,5859 118.0000 NPHI '999.2500 FCNL -999.2500 2 4102 -999:2500 DRHO -999,2500 CALl EPT B200,O000 SFLU ,P -19,8125 GR HOB -999,2500 NCNb R 111.6875 RNRA 5,2305 IbM 111,6875 NPHI -999.2500 FCNb -999,2500 4.0156 ILD -999.2500 DRHO -999.2500 CAbI :H'EPT 8!00i0000 SFLU OB -999 2500 NCNb :R 159,7500 RNRA 5,4336 159,7500 NPHI -99~.2500 FCNL -99 ,2500 4,0820 '999,2500 DRHO -999,2500 CAbI ~EPT 8000 -3! ,R 165 0000 SFLU NCNb ,8750 RNRA 4,2148 .165,8750' NPHI 999;2500 FCNL -999,2500 3,4805 ILD -999,2500 DRHO -999.2500 CALI ~EPT 7~00 [HOB '999 ;R 137 0000 ~FLU :3 4oe C,R .1,37 2500 NCNb ', 999 5'000 RNRA '999 ,9062' IbM 5000 NPHI ,2500 :~C L ,25'00 999,2500 :CAbI )EPT 7800 ;P ~HOB 999 ;R 193 ,000!, SFLU 3 GR : .I'93 , N'CNL 999 ,] 1500 RNRA -999 2,3809 I[,D ~ NPHI '999,:2500 250 148 .4063'0000 : GRSFbU 14~ ,2500 NCNb "999' ,6250 RNRA '999 ,4:o23 z:L '6~50 N'PH! ,;25:00: ':FC:NL '2500 . ::2,9023 lP:D 999'2500 DRHO -999,2:500 CALl )EPT 7600 ~HOB -999 ;R 155 0000 SFLU 2 ,-531 GR ,2500NCNb .3750 ~164' ILM 2,0664 ILD 175:0:: NiPHI i-999,250:0 DRHO !500 FCNL -999,2500 CA/,I !EPT 75R0 ,P '25 !HOB -999: ,R 143 ,45'51 -999,2500 CALI )EPT '7400 ~P -23 '0000 SFLU 2 '5313GR ,1:6:6 Ib~ :i:iNPHI 2'5488 ':999,2500 1,4961 '999,2500 10,1094 1,8447 -999,2500 9,6328 4,3945 '999,2500 9,3125 -999, 9,7031 3,4609 -999,2500 10,9062 3047 -999:2500 4609 2,2461 -999,2500 9,3125 2,6953 -999,2500 9,4531 2,1973 -99~, 2500 .4375 , 2,4961 '999,2500 10,.7031 99~ '5840 ,2500: VP 010,H02 VERIFICATION LfSTING PAGe: 6 HOB -999 2500 NCNb -999,2500 FCNb R 166:5000 RNRA -999,2500 -999,2500 CAbI EPT 7~00 0000 SFLU 7,8906 IL~ P -20i5469 GR 64,4375 NPH] HOB -999 2500 NCNb -999,2500 FCNL .R 64,4375 RNRA -999,2500 3 7949 -999:2500 DRHO -999,2500 CALf .EPT 7200,0000 SFLU 2,1973 Ib~ .P -22,0469 GR 112.6875 NPHI HOB -999,2500 NCN[. -999.2500 FCNL ;R 112,6875 RNRA -999.2500 2,]262 ILD -999,2500 URHO '999,2500 CALl ,EPT 7~00,0000 SFLU 2 ILM ;P 20,7656 GR 88:32530509 NPHI :HOB -999 .2500 NCNb -999.,2500 FCNL '.R 88: 2500 RNRA -999,2500 2,5078 IbP '999,2500 DR, HO '999,2500 CALf ~EPT 7000 ;P -21 ~HOB -999 0000 SFbU 2.2598 IbM 3 GR 95,8125 NPBI 225~00 NCNb -999,2500 FCNL 8125 RNRA -999,2500 ,3906 -99 ,2500 DRHO '999,2500 CA. LI !:HOB -999 ,R 96 29 22027 IbD -99:25 0 DRHO -999,2500 C LI )EPT 6800 ;P -20 ~HOB -999 ;R 89 ,0000 SFLU 2,4980 Ib~t 7969 : 189::; 68:75 NPH ., g. soo ,6875 RNRA -'999,2500 . 2,6797 999,2500 '999,2500 CAbI ~HOB 99 ;R 10 ,0000 : SF5U ::: :2, ,~000 (;R 103; .2500 NCNb : "999, . ~500 RNRA '999. 2500 ~PHI 999,2500 DRHO 2500 ~C:Nb -999,2500 CALI 2500 )EPT 6600 ;P ' 21' tHOB -999 ;R 93: 0000 SFLU 2 ': :750: :OR: ':i93 ,2500 NCNb -999 · 37:50 RNRA :'999 , 8887 IbM 3,2578 IbD , :NPHI : :9:9~,2:500 DR~O ,~500 ~CNL 99 .2500 CALI ,2500 )EPT 6500 {P 21 !}{OB -999 ,R 90 '2500 N~N~ : ~.9.99 ,6875 RNRA 999 .681:6 I5'~ ,::~500 ~ CNL i2500 ..2,949215D -999,2500 DRHO -999,2500 CAbI )EPT 6400 'P ;R .0000 SFI.. J 3,1504 IbM 7656 91,6250::: 2500 -999,2500 FCNb b250 RNRA "999:,2500 2695 ILD 2500 .DRHO 2500 CALI )EPT 6300,0000 SfLU : : ,,3:,9531 IL, , g 4,253. IbD 10,7734 3,5039 '999,2500 9.2891 2,3867 '999 2500 9:9766 2,5977 '999,2500 9,4844 2.4395 '999,2500 9,2969 2,289~ -999,250 9,8359 7871 2'1500 -999. 9, '969 .99~:'9473 ,2500 9,6875 3,4453 -999,2500 9,1641 3,0918 '999,2500 B,9766 !,Bog '99 , 500 .Yi141 4,6211, VP 010.H02 VERIFZCATfON LfSTING PAGE 7 P -24,2B13 GH 96,5000 NPHI HOB -999,2500 NCNb -999,2500 FCNL R 96.5000 RNRA -999,2500 EPT 6200,0000 SFLU 3o8833 IBM P ''24,5156 GR 81,5000 NPH! HOB 999.2500 NCNb -999.2500 FCNL R 81.5000 RNRA -999,2500 'EPT 6100.0000 SFbU 3,1719 Ib~ .P -27,3750 GR 81,0625 NPHI .HOB -999,2500 NCNb -999,2500 FCNL ;R 81,0625 RNRA -999.2500 ,EPT 60.00.0000 $FbU 2 9219 IL~ ~CO -27.8906 Gl{ 1()2 i5000 NPHI B -999,2500 NCNb -999 2500 FCNb ;R 102,5000 RNRA -999,2500 ~EPT 5900,0000 SFLU ,P 27.3281 GR 100"0605 - 7500 NPHI ~,OB -999,2~00 NCNb -9:99g:2500 FCNL ;R 100,7 O0 RNRA -9 2500 ~EPT 5800,0000 SFLU 2,9258 IbM ;P '26,6,094 G:R 100,1875 NPN! [HOB -999~2500 NCNL =999.2500 FCNL ;R 100,1875 RNRA -999,2500 ~' 5.,700. ' 'U ~ EPT 0000 SF'L ~P 29,8437 GR I !HOB -999,2500 NC:NI~ ~:: FCNL .R 94.8125 RNRA ~EPT ~600 i OB 999 ;:R 86 ;P 24 tHOB 999 ;R 95 54.00 ,R ~999,2500 999,2500 CA~I 0430 999i2500 5oo DRHO CALI 4,2656 '999,2500 '999,2500 IbP ORHO CAbI 3,0938 -999,2500 -999.2500 ILD DRHO CALl 3 5762 -99912500 -999 2500 DRHO CALl .9.993'4102 .2.~0o -q99,2500 ILD ORHO CALI 4,61:72 -g99,2500 -999,2500 DRHO C Ab I ,53~3 GR :86:, 0000 N~HI ,25 0 NCNb -999'2500 FCNL ,0000 RNRA "'999 ~:'2:500 3,7246 9.250:0 .'9~9,2500 DRHO CALl ,0000~b{" J : 9~' 1562 2500 N.C.N:b ,.999 1250 RNRA '999 FC L :~,6i094 '99,,2500 ':9:99,.250:0 DRHO CALI ,0000 SFLU ., GR:. , NCNL ,9~75 RNR:A : ::'"':999' 25:00 : i LD D R H 0 CALl 5300,0000 SFL, O: -22,5000 GR ? 3750 RNRA 7910 DRHO 655.00:00 CAi~I -999,2500 8,7031 4,1016 '999,2500 10,2266 4,5469 '999,2500 11,7500 3,2500 '999,2500 12.2344 3,8789 '999,2500 11,2500 3,7207 "999,2500 10,9062 .99~ '7852 ,2500 II,0234 3,9805 12,02 ' 9:238 -999.2500 7266 6,9883 -999,2500 10,9844 3,7~22 0659 5938 ,VP OlO,H02 VERIFICATION LISTING PAGE ,EPT 5200 0000 SFLU 4 ~P -24:5313 GR 79 'HOB 2 2246~ NCNL 2208 ;R 79 3750 RNRA ~EPT 5~00 0000 SFLU 6 ;P -28:4531 GR 77 :HUB 2,2324 NCNL 2354 ;R 77,6250 RNRA ] }EPT 5000 0000 SFLU 9 ;P -34~1562 GR 73 IHOB 2,2324 NCNL 2088 ;R 73.5625 RNRA 3 .4961 ILH ]750 NPH! '0000 FCNL ,5840 .0195 ILM .6250 NPH! ,0000 FCNL .8164 .3281 ILia '5625 NPH! .0000 FCNL ,5742 )EPT 4800.0000 SFLU 8 ,P -33,27813 G. ]43 {HOB 2,2 93 NCNL 20 ;R 73.8125 RNRA 4 ~EPT 4700. 0000 ~FbO: 53 ,P -47,0313 GR, 50 ~HOB .1562 RNRA ;R 5.20,0.3, NCNL 23346: )EPT 4~ )EPT ~P 70, O0 SFLU 47 G:~: 70 I NCNL 2286 NRA 35;5625 GR 61 :::4 4300 -24 4200 -30 .1484 ,$125 NPHI ,0000 FCNL .2852 3EPT HOB 4.9883 ILD 36 6699 DRHO 616:0000 CALI 6,9609 ILD 37.4512 DRHO 616,5000 CALf 9,3750 ILD ~,6719 ~gMO 584.0000 CALl 5,7930 43,6523 ORHO 464,7500 CALl ,1562 ~PH! ,0000 ~CNL ~ 07'03 8,4375 40,8~03 DRMO 474.2500 CALI ,59'38 ,5:6:25NPHI ,0000 FCN'L .8477 40,03: 45,84 DRHO 573.5000 CALl 40 ~4688 ILD ,2969~L~ ':9687 ~0000 FCNL .23:0:5 ~:':625042r97::I:L~'PHI ,242:2 NCN:~: ' :2032,0000 8. C~L 6250 RNRA 4: ' 2187 ,0000 SFLU 6,T266 '76::56GR: :66'0000 f'CN'L ,2285 NCNL ,~8'75 8.4609 ILD 4:1,6504' DR[tO 597.5000 CALl. 8496 DRHO 48I', 500.0 CALI ILD CALl 5,4922 0.0376 11.i016 7,3672 0,0400 11,1875 10,8437 0 0171 10:0000 b,5039 0.0400 1.1,0781 10,1719 0.~48~ 10. 81 50,~62 O, 66 9.0~69 068 ~'0234 960 9 9,2109 1~'04..4q54 , 22 8,5703 0,0400 11.,0903 8.0859 90.0322 6094 VP OlO,H02 VERIFICATION LISTING PAGE 9 :EPT 4100,0000 SFLU 13 P -50.2187' GA 52 HOB 2,0840 NCNb 2408 ,R 52.1875 RNRA 'EPT 4000.0000 SFLU 6 ,P -25.2187 GR 81 .HOB 2,1797 NCNb 1817 ;R 81,4375 RNRA 5 ~EPT 3900.0000 8FLU 13 .P -43,1875 GR 53 IHOB 2,1211 NCNb 2.468 ;R 53,0313 RNRA 3 )EPT 3800,0000 SFLU 13 ;P -49,0313 GR 4 0 :HOB 2.0840 NCNb 2342 ;R 40,5000 RNRA 3 3700, 0000 SFbU ~ ~ ;P -41, ~HOB 2' I211 NCNb 2380 ;R 55,8437 RNRA 3 ;P )EPT HOB ?EPT ,R )EPT ;R ):EPT ~P :7813 IbM 1875 MPHI ,0000 FCNL ,4805 .1289 IL~ ,4375 NPHI .0000 FCNb ,0195 ,~0~72 IbM , 13 NPHI ,0000 FCNb ,6934 ,2656 ILM ,5000 NPHI ,0000 FCNb ,8887 ,~188 IbM , 43'; NPHI ,0000 rCNL .9824 6289 0:70.3 3~:00,0000 SFLU::: 1:i,0~.69 IbM 26~3438 GR 70,6875 NPHI 2,0801 NCNb :165:6,0'00'0' iFCNL 70.6875 RNRA 4' ~367 3~00,0000 SFLU 23 0000 :SFLU :: :::: 8,:9609:: IbM 7656 GR 63~ 0938 ~PHI 7051 0938RNRA 5'1602 3200,0000 'SF'LU 13, , IbM "44,5313 ::GR:': i.:i55,i 2,0938 NCNb 2526, 55.1875~ 3100, !000 S:}LU !::: :: 7'813 GR -41, .... N 2.0313 14,7969 ILD 40.4297 DRHO 691.5000 CAb! 7.7813 ILD 55,5664 DRHO 361.7500 CALI 12,2344 ILD 38,0371 ORHO 668.0000 CALI 4453 ILD 43:3594 U~HO 602.0000 CALI 4,7969 ,1172 DRHO 597.5000 CALI 8 48 455 6250 1934 DRHO 0 O0 0 CA b I 4~,bg38IbD: ,9727 DRHO 400'0000 CAL:I 5 7930 ILD 9766 DR:HO 5000 CALl 71, 3828 * 2363 DRHO ' 0 297.:250 CALl, 14 [016 ILD 3203 ~ibO 5039 DRMO 5000 CALl ~,5000 .0010 11,0313 8.9844 0.0313 10.9141 0225 9'8906 14 1562 '0~0020 9,3125 1~,7578 .0015 9.0391 9,7813 0,0313 10,2656 11,5391 0,0557 11.4688 6.3750 0,0322 10.6328 I~,:1094 ,0195 9.3125 15 "0 10 103,9531 - ,0020 I I, 0469 iVp 01.0,H02 VERIFICATION LISTING PAGE] 10 ;R '- 51,0938 RNRA 3.8496 ~EPT 3000 0000 SFLU 9 ;P -27:7656 GR 76 ~HOB 2 1602 NCNb 1801 ;R 76:2500 RNRA 4 0781 :2500 ,0000 FCNL .1875 )EPT 2900 0000 SFLU 8 ;P -28:2656 GR 86 [HOB 2,0723 NCNb 1869 ~R 86,0000 RNRA 4 ,3594 IbM .0000 NPHI .0000 FCNL ,8906 )EPT 2800 0000 SFLU 13 ;P -45:7813 GR 47 tHOB 2~0566 NCNL 2328 ;R 47 56,25 RNRA 3 3516 IbM 5625 NPHI 0000 FCNb 6934 !EPT 270~ 0000 SFbU 6 ,P '2v:0625 GR 68 {HOB 2,1582 NCNb 1755 IR 68.8750 RNRA 4 .6563 IbM ,8750 NPHI ,0000 FCN5 ,4141 {ROB 2,2305 NCNb iR 70. 1250 RNRA 4 :0703 IbM 1250 NPHI .0000 FCNL ,2109 ~)EPT 2500, :~P 6250 GR : 172 NCNb: :t'465 4063 R N R A 5 6:094'. IbM ;4063 N~HI 0000 : F:C 300 8 )EPT :2416 ~P '11 * RHOB 24.1 0000 SFLU ~92 IbM ~CN'L ~* FILE TRAILgR Fl'LB NAME :: :BER:VIC,O01 SERVICE ttiAME- * "', VERSION# DATE : MAXIMUM bENGT :: 1024 FILE TYPE NEXT FILE TAPE ORIGI, TRAILER ~FSIA 9,4063 43,4570 430.0000 g,2813 59.5703 382,0000 14,1016 38.7207 630,0000 4~.29 0 ,04~9 397.5000 8,5547 43 0000 2000,0000 75OO IbD DRHO CALl ILD DRHO CALl DRHO CAbI DRHO CAL.I DRHO CAbI LD ~RHO CALl DRHO CAL, I 10.7~44 0,0 88 10,9922 10 2656 -O!OO29 10 3984 15 4375 0!0034 12 0859 8 5547 0:0239 10,6484 10,~156 O, 12,867 12o, 5O0O 14 ,0122 .3047 17,5000 '0. 5078 9,7500 l VP 010,H02 VERIFICATION LISTING PAGE APE NAME : ONTINUATION # :01 EXT TAPE NAME : :OMMEflTS :TAPE COMMENTS :* RgEL TRAILER ** ,ERVICE NAME :$ERVIC ,ATE :83102116 ~RIGI~ : :EEb NAME ~REEb ID :ONTINUATION # ~01 IEXT REEL NAME : :OMMENTS :REEL COMMENTS EOF ********** ********** EOF