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Home My WebLink About182-051MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 16, 2026 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1E-11 KUPARUK RIV UNIT 1E-11 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/16/2026 1E-11 50-029-20787-00-00 182-051-0 W SPT 6060 1820510 1515 2245 2242 2231 2233 560 625 628 628 INITAL P Austin McLeod 12/26/2025 MITIA 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-11 Inspection Date: Tubing OA Packer Depth 790 1780 1760 1750IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM251227122626 BBL Pumped:1 BBL Returned:1 Friday, January 16, 2026 Page 1 of 1            From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL]FW: KRU 1E-11 (PTD 182-051) AA cancellation request Date:Thursday, November 20, 2025 8:45:51 AM From: Wallace, Chris D (OGC) Sent: Thursday, November 20, 2025 8:37 AM To: 'NSK Wells Integrity Eng CPF1 & CPF3' <n1617@conocophillips.com> Subject: RE: [EXTERNAL]FW: KRU 1E-11 (PTD 182-051) AA cancellation request Shelby, AOGCC periodically updates our regulations and in 2023 AOGCC proposed to modify 20 AAC 25.412 to have injectors tested to the maximum injection pressure. This regulation change was not adopted, and so you are technically correct that cancelling the AA would put the well back into routine testing criteria as you describe below. It is my preference to always test a well with a MITIA to the potential maximum pressure that the well would see if a tubing rupture were to pressurize the IA. Without the regulatory authority to require the test to maximum injection pressure, your plan to cancel the AA and then test to the lower pressure would be allowable. I will continue to process the cancellation request without the witnessed MITIA, and time will tell how the well performs. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: NSK Wells Integrity Eng CPF1 & CPF3 <n1617@conocophillips.com> Sent: Wednesday, November 19, 2025 4:51 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL]FW: KRU 1E-11 (PTD 182-051) AA cancellation request Chris, 1E-11 has not been brought on injection yet post RWO. After the well is brought on injection and stable we plan to conduct a witnessed MITIA on a 10-426. Currently with AIO 2C.053 in place we are required for that test pressure to be to maximum anticipated injection pressure ~3300 psi on that initial witnessed MITIA post RWO. With the T x IA on gas issue fixed during the RWO we have been requesting AIO cancellation before that initial witnessed MITIA post RWO so our test pressure is based off of packer TVD instead of to maximum anticipated injection pressure unnecessarily. Very similar scenario to 1E-22 last month. 10/23/25 Submitted AA cancellation request for AIO 2B.078. 10/23/25 1E-22 brought on injection post RWO. 10/29/25 Received approved AIO 2B.078 cancellation. 11/2/25 Conducted a witnessed MITIA to 2200 psi that passed. I requested the cancellation of AIO 2C.053 on 1E-11 before the initial witnessed MITIA post RWO was conducted, believing AIO 2C.053 is no longer relevant with the RWO repair and was attempting to avoid putting the extra stress on the casing testing to maximum anticipated injection pressure if it wasn’t necessary. Please let me know if you disagree with that train of thought or prefer the initial witnessed MITIA post RWO to still be to maximum anticipated injection pressure before cancellation is considered. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Wednesday, November 19, 2025 2:45 PM To: NSK Wells Integrity Eng CPF1 & CPF3 <n1617@conocophillips.com> Subject: [EXTERNAL]FW: KRU 1E-11 (PTD 182-051) AA cancellation request 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. Shelby, We have received this application and are processing. I see we have received the 10-404 for this well work but I do not have a witnessed/waived witnessed MITIA on Form 10-426? Please provide this or explanation why this is not part of the cancellation request. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: NSK Wells Integrity Eng CPF1 & CPF3 <n1617@conocophillips.com> Sent: Tuesday, November 18, 2025 12:33 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Buck, Brian R <Brian.R.Buck@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Subject: KRU 1E-11 (PTD 182-051) AA cancellation request All, I’ve attached an AA cancellation request for KRU 1E-11 (PTD 182-051) (AIO 2C.053). The well recently completed a RWO (sundry 325-485) which repaired the previous annular communication issues. Please let me know if you need any additional information. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: 1E-11 (PTD: 182-051; Sundry: 325-485) RWO to Repair Tubing Leaks/Leaking Packer Date:Wednesday, October 15, 2025 5:02:42 PM From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Wednesday, October 15, 2025 5:01 PM To: Manning, Leslie <Leslie.Manning@conocophillips.com> Cc: Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Zwarich, Nola R <Nola.R.Zwarich@conocophillips.com> Subject: Re: 1E-11 (PTD: 182-051; Sundry: 325-485) RWO to Repair Tubing Leaks/Leaking Packer Leslie, Your plan outlined below is approved (verbal). Please ensure a sundry application for change of approved procedure is submitted to the AOGCC within 3 days. Thanks, Jack From: Manning, Leslie <Leslie.Manning@conocophillips.com> Sent: Wednesday, October 15, 2025 4:56 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Zwarich, Nola R <Nola.R.Zwarich@conocophillips.com> Subject: 1E-11 (PTD: 182-051; Sundry: 325-485) RWO to Repair Tubing Leaks/Leaking Packer Jack – Per our conversation, we are currently on step 3 of the attached sundry with Primary Barrier = KWF to surface (10.5 ppg – static since 0300, 10/15/2025) and Secondary Barrier = tree/BPV/packoffs. Below are the proposed steps we discussed. Proposed Plan Forward: •Install elbow at IA valve to visually monitor KWF level throughout operation (maintain ability to mate up kill line – to bullhead through IA valve in well control scenario) •ND tree (BPV installed and tested) •RU Cameron Casing Jacks •Allow tubing head adapter (THA) to grow •If growth above LDS (Start of Sundry deviation) • Back out LDS and allow tubing hanger to grow • RD Cameron casing jacks • ND THA • Cut tubing/control line & casing as needed to allow NU BOPs • Pull tbg hanger (if not cut) to floor • LD 2 joints of tubing & secure control to tubing • Drop off tubing • If casing growth above bowl, Remove tubing head • RIH spear 7”, stretch casing, cut excess, re-land casing in emergency slips, release spear • NU tubing head – test casing packoffs •NU BOPs (and Install test plug if growth occurred) – Test to 3000 psi (End of Sundry deviation) Please reach out with any further questions. Awaiting your approval to proceed as described. Leslie Manning Sr. CTD/RWO Engineer ConocoPhillips Alaska Cell: 512.755.6782 Office: 907.263.3731 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Wednesday, October 15, 2025 7:32 AM To: Manning, Leslie <Leslie.Manning@conocophillips.com> Cc: Coberly, Jonathan <Jonathan.Coberly@conocophillips.com> Subject: [EXTERNAL]RE: Inform: 1E-11 (PTD: 182-051; Sundry: 325-485) RWO to Repair Tubing Leaks/Leaking Packer 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. 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. Thank you for the update Leslie. Jack From: Manning, Leslie <Leslie.Manning@conocophillips.com> Sent: Wednesday, October 15, 2025 6:27 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Coberly, Jonathan <Jonathan.Coberly@conocophillips.com> Subject: Inform: 1E-11 (PTD: 182-051; Sundry: 325-485) RWO to Repair Tubing Leaks/Leaking Packer Jack – While attempting to ND the adapter on Kuparuk WAG Injector 1E-11i (RWO to Repair Tubing Leaks/Leaking Packer), we encountered another occurrence of tubing hanger growth. The growth was identified with the previously established method and the well currently has a well-managed KWF primary barrier. BPV and tubing packoff are in place; however, the tubing packoff is considered to be compromised. We are working to reseat the adapter flange and T-PPPOT to re-confirm it as a barrier as we develop our plan forward. We will communicate our plan once it is developed. Please reach out with any questions. Leslie Manning Sr. CTD/RWO Engineer ConocoPhillips Alaska Cell: 512.755.6782 Office: 907.263.3731 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): 8754'2709 8149' 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: 907-545-1144 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 Brian Glasheen brian.glasheen@conocophillips.com RWO Engineer Subsequent Form Required: Suspension Expiration Date: J-55 J-55 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" 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: 8723' Burst 2804' AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 7491'MD/6020'TVD 7558'MD/6060'TVD 7951'MD/6298'TVD 1952'MD/1819'TVD 7558' 7973' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025651 182-051 P.O. Box 100360, Anchorage, AK 99510 50-029-20787-00-00 ConocoPhillips Alaska, Inc Will perfs require a spacing exception due to property boundaries? 80'80' 2835' 8723' 16" 10-3/4" 48' 2476' 8/29/2025 3-1/2" 4" BAKER HB Retrievable BAKER FHL Retrievable BAKER FB-1 Permanent SSSV: CAMCO TRDP 1A-SSA Perforation Depth MD (ft): 6810'7523'6039'7523' KRU 1E-11 7708-7794' 7996-8008' 8028-8056' 8061-8076' 8692' 6150-6202' 6326-6333' 6346-6363' 6366-6375' m n P 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 10:42 am, Aug 18, 2025 Digitally signed by Brian Glasheen DN: OU=RWO's, O=ConocoPhillips, CN=Brian Glasheen, E=brian.glasheen@ conocophillips.com Reason: I am the author of this document Location: Date: 2025.08.18 09:31:59-08'00' Foxit PDF Editor Version: 13.1.6 Brian Glasheen 325-485 10-404 X AOGCC witnessed BOP and annular test to 3000 psi. Variance to 20 AAC 25.412 for packer setting depth is approved with packer set below the top of the HRZ confining zone, see attachment (top of HRZ at 7205' MD). DSR-8/19/25 X JJL 8/18/25 A.Dewhurst 18AUG25JLC 8/19/2025 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.08.20 10:15:54 -08'00'08/20/25 RBDMS JSB 082225 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 15, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Brian Glasheen Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Injectorr 1E-11 (PTD# 182-051). Well 1E-11 was drilled and completed in 1982 as a gas lift Kuparuk producer .RWO installed new tubing 1991.Converted to a WAG injector 1996.The well has multiple holes in the tubing and a packer leak that will require a rig to pull and replace the tubing. If you have any questions or require any further information, please contact me at +907-545-1144 The 3-1/2” upper completion will be pulled from a pre-rig cut. New 3-1/2” completion including gas tight connections, a non-sealing overshot and a stacked packer will be installed. If a casing leak is found above TOC at ~ 7201' and its not packer leaking a 5.5'' cemented tie back will be installed. A variance is requested to 20 AAC 25.412 for packer setting depth. 1E-11 Kuparuk Injector Tubing Swap PTD: 182-051 x-11Page 1 of 2 PPre-Rig Work 1. T-PPPOT and T-POT, IC-PPPOT and IC-POT tests 2. DMY all GLM and leave lowest GLM open for circulating 3. Tubing cut at ~7455’ RKB above the packer. 4. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 1E-11. 2. Circulate well to SW. Record shut-in pressures on the T & IA. If pressure is observed, bleed off pressure and complete 30-minute NFT. KWF will be used as needed if mechanical barrier does not pass 30-minute NFT. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND tree, NU BOPE and test to 250/3000 psi. Test annular 250/3000 psi. Retrieve 3-1/2” Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to the pre-rig cut. Install 3-1/2” Completion 6. RIH to tubing stub and dress off stub as needed. Perform casing cleanout runs as needed. 7. MU Test packer and RIH to 7445’ test casing to 3000 psi. a. If MIT fails POOH to 7250’ test casing to 3000 psi i. If test at ~7250’ fails establish LLR ii. Prepare well for a 5.5’’ Cemented tie back. View Proposed WBS attached. iii. BOP stack will have to be broken to add a new spool to accommodate 5.5’’ casing. A 7’’ plug/storm packer will be set prior to breaking the stack and adding new spool. iv. Test break as soon as practical once test plug can be installed. 8. MU new 3-1/2” completion with non-sealing overshot, packer, nipple profile, and GLM. RIH to tubing stub. 9. Once on depth, space out as needed. Circulate corrosion inhibited fluid. 10. Land tubing hanger, RILDS, PT packoffs and set packer. 11. Pressure test tubing to 3,500 PSI. 12. Pressure test IA to 3,000 PSI. ND BOP, NU Tree 13. Shear out SOV with pressure differential. 14. Install BPV and test. ND BOPE. NU tree. 15. Pull BPV and freeze protect well. 16. RDMO. Post-Rig Work 1. DMY GLM. *Cement 5.5" tie-back to surface per WBS - JJL 1E-11 Kuparuk Injector Tubing Swap PTD: 182-051 x-11Page 2 of 2 2. Pull any plugs and ball/rod used for setting packer. 3. Pull RPB set at 7522. 4. MIT-IA after stabilized injection GGeneral Well Information: Estimated Start Date: 8/29/2025 Current Operations: Shut-In, secured with plug below packer Well Type: Injector Wellhead Type: FMC GenIII, 11” 3M casing head top flange. 7-1/16” 5M tubing head top flange. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Static BHP: 3329 psi / 6200 TVD measured on 3/27/25 MPSP: 2709 psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 3-1/2” completion to a pre-rig cut. Install a new 3-1/2” completion with a stacked packer. Personnel: Workover Engineer: Brian Glasheen (907-545-1144 / Brian.Glasheen@conocophillips.com) 1E-11 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 80 80 16 15.06 65 h-40 Welded Welded Surface 2835 2475 10/3/4. 9.95 45 k-55 BTC BTC Production/ Intermediate 8723 6790 7 6.28 26 k-55 BTC BTC Liner #N/A #N/A #N/A #N/A #N/A #N/A #N/A #N/A Tubing 7455.. 3.5 2.99 9.3 l-80 HDY563 HDY563 PROPOSED COMPLETION 3-1/2" 9.3# L-80 HDR563Tubing to surface 3-1/2" x 1-1/2" Gas Lift Mandrels @ TBD 3-1/2" x 7" Packer @ ~7355' RKB 3-1/2" X landing nipple (2.813" min ID) 3-1/2" Non-sealing Overshot REMAINING COMPLETION LEFT IN HOLE Packer @ 7491' RKB Packer @ 7557' RKB Packer @ 7950' RKB Nipple @7965 ' RKB (2.75" ID) SOS @ 7972' RKB Surface Casing Production Casing A-sand perfs C-Sand Perfs Conductor 7210' !" # # $% &'!(" 1E-11 Proposed RWO Tieback Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 80 80 16 15.06 65 h-40 Welded Welded Surface 2835 2475 10/3/4. 9.95 45 k-55 BTC BTC Production/ Intermediate 8723 6790 7 6.28 26 k-55 BTC BTC Liner 7455 5.5 15.5 l-80 BTC BTC Tubing 7455.. 3.5 2.99 9.3 l-80 HDR563 HDR563 PROPOSED COMPLETION 3-1/2" 9.3# L-80 HDR563 Tubing to surface 3-1/2" x 1-1/2" Gas Lift Mandrels @ TBD Seals PROPOSED Tie BackCOMPLETION 5-1/2" 15.5# L-80 EUE 8rd casing to surface 3-1/2" PBR (4'' ID) 4-1/2'' NCS sleeve 3-1/2" x 7" Packer @ ~7355' RKB 3-1/2" X landing nipple (2.813" min ID) 3-1/2" Non-sealing Overshot REMAINING COMPLETION LEFT IN HOLE Packer @ 7491' RKB Packer @ 7557' RKB Packer @ 7950' RKB Nipple @7965 ' RKB (2.75" ID) SOS @ 7972' RKB Surface Casing Production Casing A-sand perfs C-Sand Perfs Conductor 7210' !" # # $% &'!(" ()*&"" Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,052.0 1E-11 3/27/2025 bworthi1 Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set RBP 1E-11 5/3/2025 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: Waivered for TxIA on gas injection. Water-only injection 11/27/2017 pproven NOTE: Drilling Rig RKB discrepancy beween 1982 original TBG and 1991 workover TBG 4/4/1991 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 32.0 80.0 80.0 65.00 H-40 WELDED SURFACE 10 3/4 9.95 31.3 2,835.1 2,475.5 45.50 K-55 BTC PRODUCTION 7 6.28 30.5 8,723.0 6,790.3 26.00 K-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 35.0 Set Depth … 7,557.8 Set Depth … 6,059.6 String Max No… 3 1/2 Tubing Description TUBING WO 1991 Wt (lb/ft) 9.20 Grade J-55 Top Connection BUTT AB- MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 35.0 35.0 0.13 HANGER 8.000 FMC GEN III HANGER 3.500 1,952.2 1,818.8 41.84 SAFETY VLV 5.937 CAMCO TRDP-1A-SSA SAFETY VALVE (LOCKED OUT FLAPPER 5/18/12) 2.812 1,999.0 1,853.2 43.32 GAS LIFT 5.390 CAMCO KBUG 2.867 3,971.9 3,330.3 40.23 GAS LIFT 5.390 CAMCO KBUG 2.867 5,482.1 4,512.4 36.21 GAS LIFT 5.390 CAMCO KBUG 2.867 6,587.4 5,398.6 41.25 GAS LIFT 5.390 CAMCO KBUG 2.867 7,423.6 5,980.2 53.34 GAS LIFT 5.390 CAMCO MMG-2 2.867 7,475.8 6,011.2 53.79 PBR 5.125 BAKER PBR w/ 10' STROKE 3.000 7,491.0 6,020.2 53.92 PACKER 6.062 BAKER HB RETRIEVABLE PACKER 2.880 7,532.1 6,044.3 53.80 SBR 5.625 BAKER SBR 4.437 Top (ftKB) 7,557.8 Set Depth … 7,973.3 Set Depth … 6,311.9 String Max No… 4 Tubing Description TUBING Original Wt (lb/ft) 9.20 Grade J-55 Top Connection FL4S ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,557.8 6,059.5 53.63 PACKER 6.150 BAKER FHL RETRIEVABLE PACKER 3.000 7,595.9 6,082.2 53.39 INJECTION 5.390 CAMCO KBUG 2.867 7,662.1 6,122.0 52.79 INJECTION 5.390 CAMCO KBUG 2.867 7,700.4 6,145.3 52.43 BLAST RINGS 4.000 BLAST RINGS (OAL=96') 2.992 7,929.0 6,284.8 52.18 INJECTION 5.390 CAMCO KBUG 2.867 7,950.1 6,297.7 52.18 SEAL ASSY 4.500 BAKER LOCATOR SEAL ASSEMBLY 3.000 7,950.6 6,298.1 52.18 PACKER 6.150 BAKER FB-1 PERMANENT PACKER 2.875 7,953.1 6,299.6 52.18 SBE 5.625 BAKER SEAL BORE EXTENSION 2.937 7,965.8 6,307.3 52.18 NIPPLE 4.520 CAMCO D NIPPLE NO GO 2.750 7,972.5 6,311.5 52.18 SOS 3.500 BAKER SHEAR OUT SUB 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,338.0 5,208.5 39.05 LEAK - TUBING leak @ 6338 11/20/2018 7,452.0 5,997.1 53.58 LEAK - TUBING E/L IDENTIFIED LEAK @ 7452' ELM 8/11/2011 7,522.6 6,038.7 53.86 RBP 3-1/2" P2P RBP MID- ELEMENT AT 7525' RKB, OAL 6.46' TTS P2P CPP3 5282/ CPEQ 35024 5/3/2025 0.000 7,640.0 6,108.6 52.99 LEAK - TUBING LEAK or LEAKING INJ MANDREL 9/22/04 9/25/2004 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) 1,999.0 1,853.2 43.32 1 GAS LIFT DMY BK 1 0.0 5/20/1996 1:00 0.000 3,971.9 3,330.3 40.23 2 GAS LIFT DMY BK 1 0.0 5/20/1996 12:30 0.000 5,482.1 4,512.4 36.21 3 GAS LIFT DMY BK 1 0.0 5/20/1996 3:30 0.000 6,587.4 5,398.6 41.25 4 GAS LIFT DMY BK 1 0.0 4/4/1991 4:00 0.000 7,423.6 5,980.2 53.34 5 GAS LIFT OPEN 1 1/2 0.0 10/9/2016 0.000 7,595.9 6,082.2 53.39 6 INJ HFCV BK 1 0.0 6/3/2009 3:00 0.000 7,662.1 6,122.0 52.79 7 INJ HFCV BK 1 0.0 6/3/2009 1:00 0.000 7,929.0 6,284.8 52.18 8 INJ HFCV BK 1 0.0 6/3/2009 10:00 0.000 1E-11, 5/4/2025 8:04:33 AM Vertical schematic (actual) PRODUCTION; 30.5-8,723.0 FLOAT SHOE; 8,721.1-8,723.0 FLOAT COLLAR; 8,678.0- 8,679.4 FISH; 8,149.0 RPERF; 8,061.0-8,076.0 RPERF; 8,028.0-8,056.0 RPERF; 7,996.0-8,008.0 SOS; 7,972.5 NIPPLE; 7,965.8 SBE; 7,953.1 PACKER; 7,950.6 SEAL ASSY; 7,950.1 INJECTION; 7,929.0 IPERF; 7,708.0-7,794.0 INJECTION; 7,662.1 LEAK - TUBING; 7,640.0 INJECTION; 7,595.9 PACKER; 7,557.8 SBR; 7,532.1 RBP; 7,522.6 PACKER; 7,491.0 PBR; 7,475.8 LEAK - TUBING; 7,452.0 GAS LIFT; 7,423.6 GAS LIFT; 6,587.4 LEAK - TUBING; 6,338.0 GAS LIFT; 5,482.1 GAS LIFT; 3,972.0 STAGE COLLAR; 3,256.4- 3,259.7 SURFACE; 31.3-2,835.1 FLOAT SHOE; 2,833.2-2,835.1 FLOAT COLLAR; 2,747.8- 2,749.4 GAS LIFT; 1,999.0 SAFETY VLV; 1,952.2 CONDUCTOR; 32.0-80.0 HANGER; 35.0 HANGER; 31.3-34.8 KUP INJ KB-Grd (ft) 40.71 RR Date 5/10/1982 Other Elev… 1E-11 ... TD Act Btm (ftKB) 8,754.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292078700 Wellbore Status INJ Max Angle & MD Incl (°) 54.00 MD (ftKB) 7,500.00 WELLNAME WELLBORE1E-11 Annotation Last WO: End Date 4/4/1991 H2S (ppm) DateComment SSSV: Flapper Locked Out Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,708.0 7,794.0 6,149.9 6,202.3 C-4, C-3, C-2, C- 1, 1E-11 5/10/1982 4.0 IPERF 7,996.0 8,008.0 6,325.9 6,333.2 A-5, 1E-11 2/1/1985 8.0 RPERF Original Perf 5/10/82 8,028.0 8,056.0 6,345.5 6,362.8 A-4, 1E-11 2/1/1985 8.0 RPERF Original Perf 5/10/82 8,061.0 8,076.0 6,365.9 6,375.3 A-4, 1E-11 2/1/1985 8.0 RPERF Original Perf 5/10/82 1E-11, 5/4/2025 8:04:34 AM Vertical schematic (actual) PRODUCTION; 30.5-8,723.0 FLOAT SHOE; 8,721.1-8,723.0 FLOAT COLLAR; 8,678.0- 8,679.4 FISH; 8,149.0 RPERF; 8,061.0-8,076.0 RPERF; 8,028.0-8,056.0 RPERF; 7,996.0-8,008.0 SOS; 7,972.5 NIPPLE; 7,965.8 SBE; 7,953.1 PACKER; 7,950.6 SEAL ASSY; 7,950.1 INJECTION; 7,929.0 IPERF; 7,708.0-7,794.0 INJECTION; 7,662.1 LEAK - TUBING; 7,640.0 INJECTION; 7,595.9 PACKER; 7,557.8 SBR; 7,532.1 RBP; 7,522.6 PACKER; 7,491.0 PBR; 7,475.8 LEAK - TUBING; 7,452.0 GAS LIFT; 7,423.6 GAS LIFT; 6,587.4 LEAK - TUBING; 6,338.0 GAS LIFT; 5,482.1 GAS LIFT; 3,972.0 STAGE COLLAR; 3,256.4- 3,259.7 SURFACE; 31.3-2,835.1 FLOAT SHOE; 2,833.2-2,835.1 FLOAT COLLAR; 2,747.8- 2,749.4 GAS LIFT; 1,999.0 SAFETY VLV; 1,952.2 CONDUCTOR; 32.0-80.0 HANGER; 35.0 HANGER; 31.3-34.8 KUP INJ 1E-11 ... WELLNAME WELLBORE1E-11 1 Christianson, Grace K (OGC) From:Glasheen, Brian <Brian.Glasheen@conocophillips.com> Sent:Monday, August 18, 2025 2:12 PM To:Lau, Jack J (OGC) Subject:RE: [EXTERNAL]RE: KRU 1E-11 10-403 Jack, Packer will be set below the top of HRZ in all cases. Top HRZ: 7205 MD Base HRZ: 7488 MD 2 3 Thanks, Brian Glasheen RWO ENGR 907-545-1144 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Monday, August 18, 2025 1:16 PM To: Glasheen, Brian <Brian.Glasheen@conocophillips.com> Subject: [EXTERNAL]RE: KRU 1E-11 10-403 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 Brian, To approve your variance request for packer depth, please provide formation top info including conƱning zone thickness and depths. “The packer must be placed within 200 feet measured depth above the top of the perforations, unless the commission approves a diƯerent placement depth as the commission considers appropriate given the thickness and depth of the conƱning zone.” Jack From: Glasheen, Brian <Brian.Glasheen@conocophillips.com > Sent: Monday, August 18, 2025 10:06 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: FW: KRU 1E-11 10-403 Morning, This one is going to come up sooner than I would hope. I wanted to give you a heads up on it to make sure you agree with the contingency plan. Because it’s an injector we have to do things a little di Ưerent so I want to make sure you are comfortable with the plan. Thanks, Brian Glasheen RWO ENGR 907-545-1144 From: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Sent: Monday, August 18, 2025 9:43 AM 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. 4 To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com >; Conklin, Amy A <Amy.A.Conklin@conocophillips.com >; Glasheen, Brian <Brian.Glasheen@conocophillips.com > Subject: KRU 1E-11 10-403 Hello – See attached 10-403 for KRU 1E-11. Please let me know If you need additional information. Thank you, Jenna Originated: Delivered to:7-May-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 1E-04 50-103-21852-00 910026680 Kuparuk River Leak Detect Log Field- Final 4-May-25 0 12 1E-11 50-029-20787-00 910026795 Kuparuk River Leak Detect Log Field- Final 3-May-25 0 13 1E-11 50-029-20787-00 910026795 Kuparuk River Plug Setting Record Field- Final 3-May-25 0 14 1E-36 50-029-22927-00 910026794 Kuparuk River Multi Finger Caliper Field & Processed 29-Apr-25 0 15 2F-12 50-029-21097-00 909990397 Kuparuk River Radial Bond Record Field- Final 16-Apr-25 0 16 3M-19 50-029-21737-00 909953646 Kuparuk River Leak Detect Log Field- Final 27-Apr-25 0 178910PLEASE 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:T40363T40364T40364T40365T40366T40367180-057182-051198-213184-043187-0645/8/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.05.08 10:12:05 -08'00'182-05121E-1150-029-20787-00 910026795Kuparuk RiverLeak Detect LogField- Final3-May-250131E-1150-029-20787-00 910026795Kuparuk RiverPlug Setting RecordField- Final3-May-2501 Originated: Delivered to:10-Apr-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-24 50-029-22984-00 909933118 Kuparuk River Leak Detect Log with ACX Field & Processed 24-Mar-25 0 1 2 1E-04 50-029-20478-00 909915381 Kuparuk River Multi Finger Caliper Field & Processed 24-Mar-25 0 1 3 1E-04 50-029-20478-00 909915381 Kuparuk River Plug Setting Record Field- Final 25-Mar-25 0 1 4 1E-04 50-029-20478-00 909915381 Kuparuk River SBHP Record Field- Final 24-Mar-25 0 1 5 1E-11 50-029-20787-00 909938097 Kuparuk River Leak Detect Log with ACX Field & Processed 9-Mar-25 0 1 6 1E-11 50-029-20787-00 909953630 Kuparuk River Multi Finger Caliper Field & Processed 29-Mar-25 0 1 7 1E-11 50-029-20787-00 909953630 Kuparuk River Plug Setting Record Field- Final 29-Mar-25 0 1 8 1E-11 50-029-20787-00 909953630 Kuparuk River SBHP Record Field- Final 27-Mar-25 0 1 9 1H-01 50-029-22330-00 909916110 Kuparuk River Packer Setting Record Field- Final 9-Mar-25 0 1 10 1Y-27 50-029-22379-00 909915690 Kuparuk River Leak Detect Log Field- Final 22-Mar-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: 200-181 182-057 182--051 193-006 193-088 T40306 T40307 T40307 T40307T40308 T40308 T40308 T40308 T40309 T40310 4/10/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.10 14:24:17 -08'00' 51E-11 50-029-20787-00 909938097 Kuparuk River Leak Detect Log with ACX Field & Processed 9-Mar-25 0 1 61E-11 50-029-20787-00 909953630 Kuparuk River Multi Finger Caliper Field & Processed 29-Mar-25 0 1 71E-11 50-029-20787-00 909953630 Kuparuk River Plug Setting Record Field- Final 29-Mar-25 0 1 81E-11 50-029-20787-00 909953630 Kuparuk River SBHP Record Field- Final 27-Mar-25 0 1 182--051 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-11 (PTD 182-051) Report of High IA Pressure Date:Monday, March 17, 2025 3:23:26 PM Attachments:1E-11 90 Dat TIO Plot & Schematic.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Monday, March 17, 2025 3:11 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 1E-11 (PTD 182-051) Report of High IA Pressure Chris, KRU 1E-11 (PTD 182-051) was reported by DHD Saturday 3/15/25 to have an IA pressure of 2034 psi. The 7” 26 lb/ft, J-55 has a burst rating of 4980 psi (45% burst rating = 2241 psi). 1E-11 is a LTSI well that CPAI had recently conducted diagnostics on for a possible rig workover. Post diagnostics the IA started to exhibit elevated pressure. The tubing and IA has been bled with well pressures currently at T/I/O = 571/604/15. CPAI plans to pull the RBP at 7518’ MD, collect a current SBHP, re-set the RBP and circ in heavier fluids to manage the surface pressures. Attached is a 90 day TIO plot and wellbore schematic 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 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,052.0 1E-11 4/14/2022 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set RBP 1E-11 3/1/2025 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: Waivered for TxIA on gas injection. Water-only injection 11/27/2017 pproven NOTE: Drilling Rig RKB discrepancy beween 1982 original TBG and 1991 workover TBG 4/4/1991 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 32.0 80.0 80.0 65.00 H-40 WELDED SURFACE 10 3/4 9.95 31.3 2,835.1 2,475.5 45.50 K-55 BTC PRODUCTION 7 6.28 30.5 8,723.0 6,790.3 26.00 K-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 35.0 Set Depth … 7,557.8 Set Depth … 6,059.6 String Max No… 3 1/2 Tubing Description TUBING WO 1991 Wt (lb/ft) 9.20 Grade J-55 Top Connection BUTT AB- MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 35.0 35.0 0.13 HANGER 8.000 FMC GEN III HANGER 3.500 1,952.2 1,818.8 41.84 SAFETY VLV 5.937 CAMCO TRDP-1A-SSA SAFETY VALVE (LOCKED OUT FLAPPER 5/18/12) 2.812 1,999.0 1,853.2 43.32 GAS LIFT 5.390 CAMCO KBUG 2.867 3,971.9 3,330.3 40.23 GAS LIFT 5.390 CAMCO KBUG 2.867 5,482.1 4,512.4 36.21 GAS LIFT 5.390 CAMCO KBUG 2.867 6,587.4 5,398.6 41.25 GAS LIFT 5.390 CAMCO KBUG 2.867 7,423.6 5,980.2 53.34 GAS LIFT 5.390 CAMCO MMG-2 2.867 7,475.8 6,011.2 53.79 PBR 5.125 BAKER PBR w/ 10' STROKE 3.000 7,491.0 6,020.2 53.92 PACKER 6.062 BAKER HB RETRIEVABLE PACKER 2.880 7,532.1 6,044.3 53.80 SBR 5.625 BAKER SBR 4.437 Top (ftKB) 7,557.8 Set Depth … 7,973.3 Set Depth … 6,311.9 String Max No… 4 Tubing Description TUBING Original Wt (lb/ft) 9.20 Grade J-55 Top Connection FL4S ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,557.8 6,059.5 53.63 PACKER 6.150 BAKER FHL RETRIEVABLE PACKER 3.000 7,595.9 6,082.2 53.39 INJECTION 5.390 CAMCO KBUG 2.867 7,662.1 6,122.0 52.79 INJECTION 5.390 CAMCO KBUG 2.867 7,700.4 6,145.3 52.43 BLAST RINGS 4.000 BLAST RINGS (OAL=96') 2.992 7,929.0 6,284.8 52.18 INJECTION 5.390 CAMCO KBUG 2.867 7,950.1 6,297.7 52.18 SEAL ASSY 4.500 BAKER LOCATOR SEAL ASSEMBLY 3.000 7,950.6 6,298.1 52.18 PACKER 6.150 BAKER FB-1 PERMANENT PACKER 2.875 7,953.1 6,299.6 52.18 SBE 5.625 BAKER SEAL BORE EXTENSION 2.937 7,965.8 6,307.3 52.18 NIPPLE 4.520 CAMCO D NIPPLE NO GO 2.750 7,972.5 6,311.5 52.18 SOS 3.500 BAKER SHEAR OUT SUB 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,338.0 5,208.5 39.05 LEAK - TUBING leak @ 6338 11/20/2018 7,452.0 5,997.1 53.58 LEAK - TUBING E/L IDENTIFIED LEAK @ 7452' ELM 8/11/2011 7,518.6 6,036.4 53.88 RBP 3-1/2" P2P RBP MID- ELEMENT AT 7521' RKB, OAL 6.45' TTS P2P CPP3 5373/ CPEQ 35067 3/1/2025 0.000 7,640.0 6,108.6 52.99 LEAK - TUBING LEAK or LEAKING INJ MANDREL 9/22/04 9/25/2004 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) 1,999.0 1,853.2 43.32 1 GAS LIFT DMY BK 1 0.0 5/20/1996 1:00 0.000 3,971.9 3,330.3 40.23 2 GAS LIFT DMY BK 1 0.0 5/20/1996 12:30 0.000 5,482.1 4,512.4 36.21 3 GAS LIFT DMY BK 1 0.0 5/20/1996 3:30 0.000 6,587.4 5,398.6 41.25 4 GAS LIFT DMY BK 1 0.0 4/4/1991 4:00 0.000 7,423.6 5,980.2 53.34 5 GAS LIFT OPEN 1 1/2 0.0 10/9/2016 0.000 7,595.9 6,082.2 53.39 6 INJ HFCV BK 1 0.0 6/3/2009 3:00 0.000 7,662.1 6,122.0 52.79 7 INJ HFCV BK 1 0.0 6/3/2009 1:00 0.000 7,929.0 6,284.8 52.18 8 INJ HFCV BK 1 0.0 6/3/2009 10:00 0.000 1E-11, 3/2/2025 10:14:11 AM Vertical schematic (actual) PRODUCTION; 30.5-8,723.0 FLOAT SHOE; 8,721.1-8,723.0 FLOAT COLLAR; 8,678.0- 8,679.4 FISH; 8,149.0 RPERF; 8,061.0-8,076.0 RPERF; 8,028.0-8,056.0 RPERF; 7,996.0-8,008.0 SOS; 7,972.5 NIPPLE; 7,965.8 SBE; 7,953.1 PACKER; 7,950.6 SEAL ASSY; 7,950.1 INJECTION; 7,929.0 IPERF; 7,708.0-7,794.0 INJECTION; 7,662.1 LEAK - TUBING; 7,640.0 INJECTION; 7,595.9 PACKER; 7,557.8 SBR; 7,532.1 RBP; 7,518.5 PACKER; 7,491.0 PBR; 7,475.8 LEAK - TUBING; 7,452.0 GAS LIFT; 7,423.6 GAS LIFT; 6,587.4 LEAK - TUBING; 6,338.0 GAS LIFT; 5,482.1 GAS LIFT; 3,972.0 STAGE COLLAR; 3,256.4- 3,259.7 SURFACE; 31.3-2,835.1 FLOAT SHOE; 2,833.2-2,835.1 FLOAT COLLAR; 2,747.8- 2,749.4 GAS LIFT; 1,999.0 SAFETY VLV; 1,952.2 CONDUCTOR; 32.0-80.0 HANGER; 35.0 HANGER; 31.3-34.8 KUP INJ KB-Grd (ft) 40.71 RR Date 5/10/1982 Other Elev… 1E-11 ... TD Act Btm (ftKB) 8,754.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292078700 Wellbore Status INJ Max Angle & MD Incl (°) 54.00 MD (ftKB) 7,500.00 WELLNAME WELLBORE1E-11 Annotation Last WO: End Date 4/4/1991 H2S (ppm) DateComment SSSV: Flapper Locked Out Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,708.0 7,794.0 6,149.9 6,202.3 C-4, C-3, C-2, C- 1, 1E-11 5/10/1982 4.0 IPERF 7,996.0 8,008.0 6,325.9 6,333.2 A-5, 1E-11 2/1/1985 8.0 RPERF Original Perf 5/10/82 8,028.0 8,056.0 6,345.5 6,362.8 A-4, 1E-11 2/1/1985 8.0 RPERF Original Perf 5/10/82 8,061.0 8,076.0 6,365.9 6,375.3 A-4, 1E-11 2/1/1985 8.0 RPERF Original Perf 5/10/82 1E-11, 3/2/2025 10:14:12 AM Vertical schematic (actual) PRODUCTION; 30.5-8,723.0 FLOAT SHOE; 8,721.1-8,723.0 FLOAT COLLAR; 8,678.0- 8,679.4 FISH; 8,149.0 RPERF; 8,061.0-8,076.0 RPERF; 8,028.0-8,056.0 RPERF; 7,996.0-8,008.0 SOS; 7,972.5 NIPPLE; 7,965.8 SBE; 7,953.1 PACKER; 7,950.6 SEAL ASSY; 7,950.1 INJECTION; 7,929.0 IPERF; 7,708.0-7,794.0 INJECTION; 7,662.1 LEAK - TUBING; 7,640.0 INJECTION; 7,595.9 PACKER; 7,557.8 SBR; 7,532.1 RBP; 7,518.5 PACKER; 7,491.0 PBR; 7,475.8 LEAK - TUBING; 7,452.0 GAS LIFT; 7,423.6 GAS LIFT; 6,587.4 LEAK - TUBING; 6,338.0 GAS LIFT; 5,482.1 GAS LIFT; 3,972.0 STAGE COLLAR; 3,256.4- 3,259.7 SURFACE; 31.3-2,835.1 FLOAT SHOE; 2,833.2-2,835.1 FLOAT COLLAR; 2,747.8- 2,749.4 GAS LIFT; 1,999.0 SAFETY VLV; 1,952.2 CONDUCTOR; 32.0-80.0 HANGER; 35.0 HANGER; 31.3-34.8 KUP INJ 1E-11 ... WELLNAME WELLBORE1E-11 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' 1E-11 50-029-20787-00 909890720 Kuparuk River Leak Detect Log Field- Final 1-Mar-25 0 1 61E-11 50-029-20787-00 909890665 Kuparuk River Plug Setting Record Field- Final 1-Mar-25 0 1 71E-11 50-029-20787-00 909890665 Kuparuk River Plug Setting Record Field- Final 28-Feb-25 0 1 182-051 • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Thursday,June 14, 2018 6:20 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU 1E-11 (PTD 182-051) Update and plan forward Attachments: MIT KRU 1E PAD 06-10-18.xlsx; 1E-11 90 day TIO trend 6-14-18.JPG Chris, KRU water injector 1E-11 (PTD 182-051) (AIO 2C.053)was reported on May 11, 2018 for suspect IA pressure increase. The monitor period is ending and although the well passes MIT-IA's the well continued to exhibit an unexplained slow IA pressure increase throughout the monitor period. The well is to be shut in and freeze protected as soon as possible. Any required paper work will be submitted once a plan has been developed. A 90 day TIO trend and 10-426 are attached. Please let us known if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 scANNED JUN 2 0 alb iNIWELLS TEAM conocvo`iittaaps 1 • MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,June 12,2018 Jim Regg P.I.Supervisor f P�1 (7115-11g SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1E-11 FROM: Adam Earl KUPARUK RIV UNIT 1E-11 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv '!j NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1E-11 API Well Number 50-029-20787-00-00 Inspector Name: Adam Earl Permit Number: 182-051-0 Inspection Date: 6/10/2018 Insp Num: mitAGE180611091330 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1E-11 Type Inj W "TVD 6060 - Tubing 2614 2586 - 2615 2615 - PTD 1820510 Type Test SPT Test psi 3000 " IA 860 3275 3080 - 3050 BBL Pumped: 4.2 ' BBL Returned: 3.5 OA 235 ' 300 - 300 - 300 Interval REQVAR P/F P Notes: MIT-IA tested as per AIO 2C.053 to max ant.Inj.Pressure JUN 2 z Zulu Tuesday,June 12,2018 Page I of 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Friday, May 11, 2018 8:39 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU 1E-11 (PTD 182-051) Report of suspect IA pressure increase Attachments: 1 E-11.pdf; 1E-11 90 day TIO trend 5-11-18.JPG Chris, KRU water injector 1E-11(PTD 182-051) (AIO 2C.053)was flagged in a problem well report and upon review of the TI trends is exhibiting a suspect IA pressure increase. The plan is for DHD to perform initial diagnostics including an MITI , pack off tests, and bleeding down IA pressure for a 30 day monitor period. Any required paper work will be submitte upon completion of the monitor period or if an alternate plan is developed. A wellbore schematic and 90 day TIO tre d are attached. Please let us know if you disagree with this plan or have any questions. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 WELLS TEAM • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission J I DATE: Tuesday,November 28,2017 TO: JimRegg P.I.Supervisor4q 12'1 itll7 SUBJECT: Mechanical Integrity Tests ( ( CONOCOPHILLIPS ALASKA,INC. 1E-11 FROM: Jeff Jones KUPARUK RIV UNIT 1E-11 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1E-11 API Well Number 50-029-20787-00-00 Inspector Name: Jeff Jones Permit Number: 182-051-0 Inspection Date: 11/11/2017 Insp Num: mitJJ171111141303 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1E-11 ' 1Type Inj W- TVD 6060 . Tubing 2237 2243 ' 2246 2243 ' PTD 1820510 ' iType Test SPT !Test psi 1515 IA 650 3270 - 3120 - 3070 - BBL Pumped: 4.7 BBL Returned: j 4.1 OA 260 300 - 300 • 300 Interval OTHER P/F P ✓ Notes: Post tubing patch per sundry 317-192. MARSCANNED I7 0 {t t i Tuesday,November 28,2017 Page 1 of 1 STATE OF ALASKA RECEIVED ALRSKA OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS NOV 17 2017 1.Operations Abandor❑ Plug Perforations ❑ Fracture Stimulates Pull Tubing ❑ Operations shutdown ❑ Performed: Suspenc❑ Perforate ❑ Other Stimulate❑ Alter Casing ❑ A 0 2. ed Program ❑ Plug for Redril❑ erforate New Pool ❑ Repair Well❑ Re-enter Susp Well ❑ Other: ystNo ❑✓ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 182-051 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service ❑✓ 6.API Number: 99510 50-029-20787-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025651 KRU 1E-11 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8,754 feet Plugs measured None feet true vertical 6,810 feet Junk measured None feet Effective Depth measured 8032' feet Packer measured 8, 7470, 7471, 7 feet true vertical 6346' feet true vertical 3, 6008, 6008, E feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 feet 16 " 80' MD SURFACE 2,804 feet 10 3/4" 2,835' MD PRODUCTION 8,693 feet 7 " 8,723' MD {.r "iite 2 2-u JEWELERY TYPE MD depth MD&TVD feet Composite Tubing(size,grade,measured and true vertical depth) 3.5" J-55 7,973' MD 6,311'TVD Packers and SSSV(type,measured and true vertical depth) PATCH- UPPER-WFT 2.72"WIDEPAK I 7,428' MD 5,983'TVD PATCH-MIDDLE-SO TIEBACK(SN: CI 7,470' MD 6,008'TVD PATCH-2.72"WFT WIDEPAK PKR(#CP 7,471' MD 6,008'TVD PACKER-BAKER HB RETRIEVABLE PA 7,491' MD 6,020'TVD SAFETY VLV-CAMCO TRDP-1A-SSA S/ 1,952' MD 1,819'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14.Attachments(required per 20 AAc 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑✓ Exploratory ❑ Development ❑ p ❑ Service ❑✓ Stratigraphic Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-192 Contact Name: Jan Byrne Authorized Name:Jan Byrne Authorized Title: Well Integrity Supervisor Contact Email: N1617@conocophillips.com Authorized Signature: �- 0...___, Date: 11/15/2017 Contact Phone: 907-659-7224 Kn.- /7 /9-117 ipt t �17n7 RBDMS /,(/[27.'1 1 7 2017 Form 10-404 Revised 4/2017 Submit Original Only • RECEIVED NOV 17 2017 ConocoPhillips AOGCC Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 November 15th, 2017 Commissioner Hollis S. French Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner French: Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well KRU 1E-11 (PTD 182-051) for tubing patch repair. If you need additional information, please contact us at your convenience. Sincerely, Jan By e/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 (WELLS TEAM • • 1E-11 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary A 43', 3.5"Weatherford retrievable patch was set from 7428'to 7471' to return integrity to the tubing. Passing MITs were performed against the lower and upper packer and a State Witnessed MITIA passed on 11-11-17 to 3270 psi. Work completed is copied below. 9/5/2017 SET 2.72"WFT WIDEPAK PKR (#CP350012) MID ELEM @ 7471' RKB. SET TEST TOOL IN LOWER PACKER& CMIT(PASS) SET SO TIEBACK, SPACER PIPE &ANCHOR @ 7470' RKB. SET TEST TOOL IN TIEBACK&CMIT (PASS) IN PROGRESS. Against lower pkr: BEGIN CMIT. INITIAL T/1/0/FL = 1350/1400/20/1300 LRS PT TO 2500 PSI W/4.7 BBLS START= 2500/2575/20/1300 15 MINS =2445/2510/20/1300 30 MINS = 2425/2490/20/1300 PASS. Against tie back section: BEGIN CMIT INITIAL T/1/0/FL= 1300/1425/20/1300 LRS PT W/4.8 BBLS START=2500/2640/20/1300 15 MINS =2460/2590/20/1300 30 MINS = 2430/2550/20/1300 45 MINS = 2415/2550/20/1300 RE TEST. PUMP .3 BBLS START= 2550/2700/20/1300 15 MINS = 2540/2690/20/1300 30 MINS = 2540/2690/20/1300 ( PASS) 9/6/2017 WITH CMDFIRE! SET UPPER 2.72"WIDE PACK PACKER PATCH ASSEMBLY MID ELEMENT @ 7432.6' RKB. MIT IA TO 3000 PSI ( PASS ) JOB COMPLETE. **MITIA pass after set upper packer: preTIO=1245/1523/27, initial=1245/3025/28, 15min=1247/2960/27, 30min=1246/2946/27** pumped 5.25 bbls 11/11/2017 (SW) STATE WITNESSED (JEFF JONES) POST PATCH AA PREP MITIA PASSED TO 3270 PSI. Initial T/I/O/OO = 2237/650/260/0 IA FL @ SF. LRS pressured IA to 3270 psi with 4.7 bbls T/I/O/OO = 2243/3270/300/0 15 min T/I/O/OO = 2246/3120/300/0 (-150 psi). 30 min T/I/O/OO = 2243/3070/300/0 (-50 psi). Bled IA to 650 psi in 3 min 4.1 bbls back continue to bleed to 500 psi. Final T/I/O/OO = 2243/500/250/0. • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq(a.alaska.gov AOGCC.Inspectors(cilalaska.gov phoebe.brooks(a�alaska.gov chris.wallaceaalaska.gov OPERATOR: ConocoPhillips Alaska Inc, FIELD/UNIT/PAD: Kuparuk/KRU/1 E Pad DATE: 11/11/17 OPERATOR REP: VanCamp/Greene AOGCC REP: Jeff Jones Well 1E-11 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1820510 Type Inj W Tubing 2237 2243 2246 2243 Type Test P Packer TVD 6060 BBL Pump 4.7 IA 650 3270 3120 3070 Interval 0 Test psi 1515 BBL Return 4.1 OA 260 300 300 300 Result P Notes: MITIA post patch per Sundry#317-192 Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Rump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT KRU 1E-11 11-11-17.xlsx KUP INJ • 1E-11 ConocoP,rl t, il hps a `t Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status Incl 7) MD(ftKB) Act Btm(MB) -...,<.."rvni, 500292078700 KUPARUK RIVER UNIT INJ 54.00 7,500.00 8,754.0 ..- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-11,11/15/2017 3:22:43 PM SSSV:Flapper Locked Out Last WO: 4/4/1991 40.71 5/10/1982 Vertical schematr(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date -- - - -- - - - -- - - Last Tag:RKB 8,056.0 7/5/2017 Rev Reason:UPDATED PULLED PATCH on pproven 11/15/2017 6/27/2017 I) Casing Strings IF Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TOO)... Wt/Len(I...Grade Top Thread y CONDUCTOR 16 15.060 32.0 80.0 80.0 65.00 H-40 WELDED HANGER;355 11101 Casing Description OD(in) ID(In) Top(RKB) Set Depth(ftKB) Set Depth(ND)...WULen(I...Grade Top Thread ' .1.mo""5ttA�SURFACE 103/4 9.950 31.3 2,835.1 2,475.5 45.50 K-55 BTC 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 30.5 8,723.0 6,790.3 26.00 K-55 BTC -M.A.cONDUCTOR;32.0.00.0 --"1 J.vu+.0.Tubing Strings _. Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..°Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING WO 1991 31/2 2.992 35.0 7,557.8 6,059.6 9.20 J-55 BUTT AB-MOD SAFETY VLV;1,952.2WA Completion Details i Nominal ID Top(ftKB) Top(ND)(ftKB) Top Ind(*) Item Des Com (in) GAS LIFT;1,999.0 i', 35.0 35.0 0.13 HANGER FMC GEN III HANGER 3.500 1,952.2 1,818.8 41.84 SAFETY VLV CAMCO TRDP-IA-SSA SAFETY VALVE(LOCKED OUT 2.812 FLAPPER 5/18/12) 7,475.8 6,011.2 53.79 PBR BAKER PBR w/10'STROKE 3.000 7,491.0 6,020.2 53.92 PACKER BAKER HB RETRIEVABLE PACKER 2.880 SURFACE;31.3-2,835.1-, • - 7,532.1 6,044.3 53.80 SBR BAKER SBR 4.437 Tubing Description String Ma...ID(in) Top(ftKB) -Set Depth(ft..'Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING Original 4 2.992 7,557.8 7,973.3 6,311.9 9.20 J-55 FL4S Completion Details Nominal ID GAS LIFT;3,972.0 " Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 7,557.8 6,059.5 53.63 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 GAS LIFT;5,482.1 7,700.4 6,145.3 52.43 BLAST RINGS BLAST RINGS(OAL=96') 2.992 GAS LIFT;6,587.4 F. 7,950.1 6,297.7 52.18 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 7,950.6 6,298.1 52.18 PACKER -BAKER FB-1 PERMANENT PACKER 2.875 7,953.1 6,299.6 52.18 SBE 'BAKER SEAL BORE EXTENSION 2.937 GAS LIFT;7,423.6 7,965.8 6,307.3 52.18 NIPPLE CAMCO D NIPPLE NO GO 2.750 PATCH-UPPER;7,428.0 : 7,972.5- 6,311.5- 52.18 SOS BAKER SHEAR OUT SUB 2.992 • I Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) _._ 7,428.0 5,982.8 53.38 PATCH- WFT 2.72"WIDEPAK PACKER(SN;CP350045) 9/6/2017 1.750 UPPER 6.02'x 2.375"SPACER PIPE&SO TIRBACK STINGERT(SN:CPTB3508)OAL=13.22'/MIN ID =1.75" PATCH;7,4710 i-I 7,470.0 6,007.8 53.74 PATCH- SO TIEBACK(SN:CPTB35038)24.15'x 2.375" 9/5/2017 1.750 - MIDDLE SPACER PIPE&WP RS ANCHOR(SN: PATCH-MIDDLE;7,470.0 CPS350096)OAL=27.91'/MIN ID 1.75" P06;7,475.8, I �1_° 7,471.0 6,008.3 53.75 PATCH 2.72"WFT WIDEPAK PKR(#CP350012/1.81"ID/ 9/5/2017 1.810 5.2'OAL) ,.n,. PACKER;7,491.0 ' ..El.. Perforations&Slots Shot Dens Top(TVO) Btm(11/13) (5600510 Top(RKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com SBR;7,532.1-- i1 7,708.0 7,794.0 6,149.9 6,202.3 C-4,C-3,C-2, 5/10/1982 4.0 IPERF C-1,1E-11 PACKER;7,557.8- 7,996.0 8,008.0 6,325.9 6,333.2 A-5,1E-11 2/1/1985 8.0 RPERF Original Pert 5/10/82 8,028.0 8,056.0 6,345.5 6,362.8 A-4,1E-11 2/1/1985 8.0 RPERF Original Perf500/82 INJECTION;7,595.9 - 8,061.0 8,076.0 6,365.9 6,375.3 A-4,1E-11 2/1/1985 8.0 RPERF 'Original Perf5/10/82 INJECTION;7,662.1 _ Mandrel Inserts St aU on Top(ND) Valve Latch Port Size TRO Run - N Top(ftKB) (ftKB) Make Model OD(in) Sent Type Type (in) (psi) Run Date Com IPERF;7,708.0-7,794.0- ..--- 1 1,999.0 1,853.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/20/1996 1:00 _ 2 3,971.9 3,330.3 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0'5/20/1996 12:30 1• 3 5,482.1 4,512.4 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/20/1996 3:30 4 6,587.4 5,398.6 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/4/1991 4:00 5 7,423.6 5,980.2 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/8/2016 <_ 6 7,595.9 6,082.2 CAMCO KBUG 1 INJ HFCV BK 0.000 0.0 6/3(2009 3:00 INJECTION;7,929.0 7 7,662.1 6,122.0 CAMCO KBUG 1 INJ HFCV BK 0.000 0.0 6/3/2009 1:00 __ 8 7,929.0 6,284.8 CAMCO KBUG 1 INJ HFCV BK 0.000 0.0 6/3/2009 10:00 SEAL ASSY;7,950.1 PACKER;7,950.6 - • Notes:General&Safety End Date Annotation SBE;7,953.1Itai '` 4/4/1991 NOTE:Drilling Rig RKB discrepancy beween 1982 original TBG and 1991 workover TBG 9/25/2004 NOTE:E-LINE DOCUMENTED MANDREL LEAK @ 7640' NIPPLE;7,965.8` 8/25/2010 NOTE:View Schematic w/Alaska Schematic9.0 IN 8/11/2011 NOTE:E/L IDENTIFIED LEAK @ 7452'ELM SOS;7,972.5 r' RPERF;7,996.0-8,008.0-- •--- - ,996.0-8,008.0- RPERF;8,028.0-8,056.0 RPERF;8,061.0-8,076.0-- FISH;8,149.0 PRODUCTION;30.5-8,723.0 • • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Thursday, November 16, 2017 6:57 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Well Integrity Supv CPF1 and 2 Subject: KRU 1E-11 (PTD 182-051) Update and plan forward Attachments: 1E-11 90 day TIO trend 11-15-17.JPG; MIT KRU 1E-11 11-11-17.xlsx Chris, KRU injection well 1E-11(PTD 182-051)As per previous correspondence the well was exhibiting TxIA communication on miscible injection. A gas rated patch was installed in attempt to repair the issue. After various iterations of the patch were attempted without success the well was WAG'd to water for a monitor period during which the well exhibited no signs of TxIA. A passing State Witnessed MIT-IA was performed on November 11th, 2017. As such CPA is applying for AA approval to continue water only injection. The AA request is in the mail and the plan is to leave the well online while the AA is being processed. Attached is a 90 day TIO trend and 10-426. Please let us know if you disagree with this plan or have any questions. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 jpiWELLS TEAM ConoaPhillips SCM d 1 S • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Friday, October 13, 2017 10:11 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Well Integrity Supv CPF1 and 2 Subject: KRU injector 1E-11 (PTD# 182-051) Update and plan forward Attachments: 1E-11 90 day TIO trend 10-13-17.JPG Chris, KRU WAG injector 1E-11 (PTD# 182-051) has exhibited IA pressure increase during the 30 day monitor period while on gas injection post tubing patch installation (sundry#317-192). The plan at this point is to WAG the well to water injection as soon as possible. The well will be monitored for 30 days to confirm integrity while on water injection after which an AA application will be submitted for continued water injection only. In addition once the well has stabilized while on water injection a State Witnessed MITIA will be scheduled and the 10-404 will be submitted as per summary details of sundry#317-192. A 90 day TIO trend is attached. Please let us know if you disagree or have any questions, Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 4F1WELLS TEAM Corwco` hamps 1 Loepp. Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Sunday,August 13, 2017 5:26 PM To: NSK Well Integrity Supv CPF1 and 2 Subject: Re: KRU 1E-11 (PTD 182-051,sundry 317-192)sundry question Kelly, Approval is granted for the increase in patch length. Thanx, Victoria SC N$E 1 « � �::�. Sent from my iPhone On Aug 13, 2017,at 10:54 AM, NSK Well Integrity Supv CPF1 and 2<n1617@conocophillips.com wrote: Victoria, We have an approved sundry(#317-192)for pulling and replacing a retrievable tubing patch in KRU WAG injector 1E-11(PTD 182-051)over a known leak at 7452' . In the proposal,we specified a 25'one- trip patch to be used for the replacement. We attempted to set the patch a couple of times with no success. The MITIA failed both times. Another caliper was run,which identified the joint that we are attempting to set the patch in to be corroded more than the surrounding tubing to be. Therefore we would like to extend the patch out to 37',instead of the originally planned 25',to be able to find good pipe in which to set the patch packers. Due to its new length, it will also need to be run in 3 sections. I wanted to confirm with you that we can proceed with the job under the existing approved sundry. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907)659-7224 Mobile Phone(907)943-0170 1 Sicsto ILL LOG 11114S TRANSMITTAL PROACTIVE DIAGNOSTIC SERVICES, INC. RECEIVED DATA LOGGED 7/l7/2017 M.K. BENDER JUL 132017 To: AOGCC AOGCC Makana Bender 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 SOWED G 0 3 2017 1) Caliper Report 07-Jul-17 3H-26 1 Report /CD 50-103-20208-00 2) Caliper Report 06-Jul-17 1E-11 1 Report /CD 50-029-20787-00 Signed : //t✓w 5L.eøc.eékDate : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE(a MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheetsTonocoPhillips_Transmit.docx • R CEIVED 315'0 JUL 13 2017 Memory Multi-Finger Caliper Log Results Summary AOGCC Company: ConocoPhillips Alaska, Inc. Well: 1E-11 Log Date: July 6, 2017 Field: Kuparuk Log No.: 12793 State: Alaska Run No.: 1 API No. 50-029-20787-00 Pipe Description: 3.5 inch 9.2 lb. J-55 BUTT ABMOD Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 7,548 Ft. (MD) Inspection Type : Corrosive and Mechanical Damage Inspection COMMENTS : This caliper data is tied into the top of GLM 5 at 7,423.6 feet(Driller's Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage, particularly around the Baker HB Retrievable Packer where a patch will be set. The caliper recordings indicate the 3.5 inch tubing appears to be in good condition in the vicinity of the Packer with the exception of a 57%wall penetration at an isolated pit in joint 240 (7,454 ft). A 3-D log plot of the caliper recordings from 7,420 feet to 7,548 feet(end of log) is included in this report. The caliper recordings indicate the remainder of the 3.5 inch tubing logged appears to be in good to fair condition, with wall penetrations ranging from 20%to 27%wall thickness in 12 of the 252 joints logged. Recorded damage appears as isolated pitting and a line of pits. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the tubing logged. This is the second time a PDS caliper has been run in this well and the 3.5 inch tubing has been logged. A comparison of the current and previous log (August 11, 2011) indicates little, if any increase in corrosive damage, with the exception of the 57%wall penetration in joint 240 during the time between logs. A graph illustrating the difference in maximum recorded wall penetrations on a joint-by-joint basis between logs is included in this report. MAXIMUM RECORDED WALL PENETRATIONS : e ;ript on Percept VI,EiPer rktr<tio., r Isolated Pitting 57 240 7,454 Ft. (MD) Line of Pits 27 180 5,589 Ft. (MD) Isolated Pitting 24 122 3,796 Ft. (MD) Line of Pits 24 159 4,947 Ft. (MD) Line of Pits 22 179 5,563 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 5%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the tubing logged. R. Holden &C. Goerdt C. Waldrop E. Zemba F r!d Engineer A 1.3lyst(s 2, ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalysis@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • 0 117-J-r - PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1E-11 Date : July 6, 2017 Description : Detail of Caliper Recordings Across Proposed Patch Setting interval. Comments Depth Maximum Penetration Nominal I.D. 3-D Log Image Map I 1ft 100ft 0 % 100 2 5 inches 3.5 0° 0° 90° 180° 270° 0° Maximum I.D. I I 2.5 inches 3.5 Minimum I.D. I I 2.5 inches 3.5 • • Pup , 1 , --,-. I 111 7425 GLM 5(Latch @ rAsi 7430 x . ,—.1.---.....— Pup --I. tl - 7440 1 -- 7445 _ - _ 7450 --...:-...2 Joint 240 t =- Isolated Pitting :—- 57%Wall - ------ Penetration 0 l. _;_.--- 1 7460 7465 I .,:.-.. — . d --- R - -r--= 7470 __ /__ --— _ -1 1, Pup J I Pup - - .-...-.:-,,•, 7475 I -:__ 7480 1 1 ....-.=_ Baker PBR _-_.. 7A.Stc I 0 0 '4& - • i i•-.,-...--_____ _ , ..- H: ... . 7490 - - — _ ...-..-..a.....• Moi........-.......rnia.1.10......1 __ Baker HB Retrievable A _ Packer ..... --- 7495 Pup 1111111111, .11= 111111% 7500 MEI '7 '1 MON -1: _.;.... 7505 111 _- 7+ - Min ...t.:.. '..-. :--- III ......-. "...". -.......• ...1... ',:i.:, t_ 7510 IIME11 , Joint 241 III Eli Jas.,4 r-t. 111111ti ___ —. ....=_ , a., 7520 11111114 ..... -..., .., 7525 ill -.... ....r.". ''" .1.1/ ....-. .- dif,•••• •••••.••NOMMOSI 11111131 - : :17-i-'"1:- -.w.......... ...- ...". 1111111li Pup MIMI _ 7530 III . Baker SBR / II ..., -.. ,. 7535 it-- ii-- 0[1.- — 1 7540 -- , II -=_-: I Pup iii —- Pup III / Minimum I.D. I I 2.5 inches 3.5 Maximum I.D. I I 2.5 inches 3.5 Comments Depth Maximum Penetration Nominal I.D. 3-D Log Image Map I--- _..... ----. I I I i41ft 100ft 0 % 100 2.5 inches 3.5 0° 0° 90° 180° 270° 0° • • Maximum Recorded Penetration Comparison To Previous Well: 1E-11 Survey Date: July 6, 2017 Field: Kuparuk Previous Date: August 11,2011 Company: ConocoPhillips Alaska,Inc. Tool Type: UW MFC 24 No.214320 Country: USA Tubing: 3.5"9.2 lb J-55 BUTT ABMOD Overlay Difference Maximum Recorded Penetration(mils) Difference in Maximum Penetration(mils) 0 50 100 150 200 250 -200 -100 0 100 200 0.1 - 0.1 ' 9 . 9' 19 19 29 29 39" 39 49 ! - 49; 59 -. - 594— GLM 1 65 65 75 75 85 85 95 95 1051 10- 115 1- E 11-i 7 p Z GI_M_ 125 Z 12 - 0 134 - 0 13A 144 '- 1"� 154 164 16 s.- cLMs 174 17' 183 183 193 193 203 203 GLM 4 212.1 112.E.- 222 '222 222 232 23 '-^^5 2393 639.3 241.3 -41 3 -34 -17 0 17 34 July 6,2017 •August 11,2011 Approximate Corrosion Rate(mpy) Corrosion Rate(mpy) Top 10 Jts. Overall Average 5 -1 Median 4 -1 • • Correlation of Recorded Damage to Borehole Profile U Pipe 1 3.5 in (28.9'-7,547.8') Well: 1 E-11 Field: Kuparuk Company: ConocoPhillips Alaska,Inc. Country: USA Survey Date: July 6,2017 ■ Approx.Tool Deviation . Approx.Borehole Profile 1 32 J 25 - 774 50 _ 1,546 GLM 1 1111116. 75 2,342 100 3,108 GLM 2 125 3,873 .E Z -c Q- 0 150 4,643 • GLM 3 175 5,417 200 6,187 GLM 4 225 6,958 GLM 5 241.4 7,547 0 50 100 Damage Profile(%wall)/Tool Deviation (degrees) Bottom of Survey=241.4 • • PDS Report Overview 114-73 �►� Body Region Analysis Well: 1 E-11 Survey Date: July 6,2017 Field: Kuparuk Tool Type: UW MFC 24 No.214320 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 3.5 in. 9.2 ppf J-55 BUTT ABMOD Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.2 ppf J-55 BUTT ABMOD 2.992 in. 29 ft. 7,548 ft. Penetration(%wall) Damage Profile(%wall) 250 am Penetration body Metal loss body 0 50 100 0.1 200 150 100 49 50 GLM 1 (2:00) 0 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analyzed(total=252) 95 239 12 1 0 Damage Configuration(body) GLM 2(12:00) 60 144 40 GLM 3 (4:00) 20 193 GLM 4 (4:00) 0 Isolated General Line Other Hole/ — Pitting Corrosion Corrosion Damage Pos.Hole — GLM 5 (2:00) 239.3 Number of joints damaged(total=82) 51 0 31 0 0 Bottom of Survey=241.4 • • 11111 CI WO, PDS Report Joint Tabulation Sheet Well: 1E-11 Survey Date: July 6,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.2 ppf J-55 BUTT ABMOD Tubing 2.992 in. 0.254 in. 29 ft 7,548 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 0.1 29 0 0.02 6 0 2.98 Pup I 1 32 0 0.02 7 3 2.95 1 1.1 62 0 0.03 12 3 2.94 Pup 2 64 0 0.02 8 2 2.95 3 96 0 0.02 7 2 2.97 4 126 0 0.03 11 2 2.94 II 5 155 0 0.03 12 2 2.96 r 6 187 0 0.02 8 3 2.95 MI 7 218 0 0.02 7 2 2.94 1 8 248 0 0.04 16 2 2.95 Shallow Pitting. mo 9 278 0 0.02 9 2 2.98 • 10 308 0 0.03 10 3 2.98 11 337 0 0.02 7 2 2.95il 12 368 0 0.02 7 2 2.95 13 400 0 0.02 8 3 2.96 14 431 0 0.03 11 3 2.97 15 463 0 0.02 9 2 2.94 1 16 494 0 0.02 9 3 2.94 • 17 525 0 0.02 8 3 2.96 Is 18 555 0 0.02 7 2 2.95 1 19 586 0 0.02 8 2 2.95 II 20 618 0 0.02 9 2 2.95 • 21 649 0 0.02 8 2 2.95 22 679 0 0.02 7 2 2.95 • 23 711 0 0.02 9 2 2.95 • 24 742 0 0.03 11 3 2.94 • 25 774 0 0.02 7 2 2.96 • 26 804 0 0.02 9 2 2.93 • 27 834 0 0.02 9 2 2.98 • 28 864 0 0.02 7 2 2.96 I 29 895 0 . 0.02 9 3 2.94 • 30 927 0 0.02 7 2 2.96 1 31 957 0 0.03 11 2 2.96 r 32 988 0 0.02 8 4 2.95 33 1018 0 0.02 9 3 2.96 34 1050 0 _ 0.03 10 4 2.95 • 35 1081 0 0.04 17 3 2.94 Shallow Pitting. mm 36 1111 0 0.02 7 3 2.95 1 37 1142 0 0.02 9 2 2.95 • 38 1173 0 0.02 7 2 2.94 39 1205 0 0.04 14 2 2.96 NI 40 123 5 0 0.03 10 2 2.96 • 41 126 7 0 0.03 11 3 2.95 C 42 1298 0 0.02 9 3 2.95 43 1330 0 0.03 11 3 2.97 • 44 1361 0 0.04 17 3 2.93 Shallow Pitting. in 45 1390 0 0.03 13 2 2.95 • 46 1421 0 0.05 18 2 2.95 Shallow Pitting. 47 1452 0 0.03 13 3 2.97 48 1483 0 0.02 7 3 2.97 r IPenetration Body Metal Loss Body Page 1 • • PDS Report Joint Tabulation Sheet Well: 1 E-11 Survey Date: July 6,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.2 ppf J-55 BUTT ABMOD Tubing 2.992 in. 0.254 in. 29 ft 7,548 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 49 1515 0 0.03 . 12 3 2.95 ■ 50 1546 0 0.03 11 3 2.97 ■ 51 1576 0 0.04 14 2 2.96 ■ 52 1605 0 0.03 11 4 2.96 ■ 53 163 6 0 0.03 11 3 2.95 54 166 7 0 0.02 8 2 2.94 55 1698 0 0.03 13 3 2.96 ■ 56 1729 0 0.04 14 2 2.93 Lt. Deposits. 57 1760 0 0.03 12 2 2.96 58 1791 0 0.04 15 2 2.92 Shallow Line of Pits.Lt. Deposits. 59 1822 0 0.05 19 2 2.94 Shallow Pitting. 60 1852 0 0.03 13 2 2.96 61 1884 0 0.04 15 3 2.96 Shallow Pitting. ■ 62 1916 0 0.04 16 2 2.96 Shallow Pitting. 62.1 1947 0 0.01 2 0 2.95 Pup 62.2 1949 0 0 0 0 2.81 CAMCO TRDP-1A-SSA SAFETY VALVE 62.3 1960 0 0.01 4 1 2.97 Pup 63 1964 0 0.04 17 2 2.97 Shallow Line of Pits. 63.1 1996 0 0 0 0 2.84 GLM 1 (LATCH @ 2:00) 64 2002 0 0.04 15 2 2.98 Shallow Pitting. 65 2033 0 0.03 13 2 2.95 66 2062 0 0.05 21 2 2.96 Line of Pits. 67 2094 0 0.04 15 3 2.95 Shallow Pitting. 68 2125 0 0.03 11 3 2.95 69 215 7 0 0.03 13 3 2.97 70 2187 0 0.05 19 3 2.93 Shallow Line of Pits. ■ 71 2217 0 0.03 13 3 2.97 ■ 72 2249 0 0.03 11 2 2.95 73 2281 0 0.03 10 3 2.95 ■ 74 2310 0 0.05 20 2 2.96 Isolated Pitting. ■ 75 2342 0 0.04 15 2 2.94 Shallow Line of Pits. ■ 76 2373 0 0.03 12 2 2.96 77 2403 0 0.04 17 2 2.93 Shallow Pitting. Lt.Deposits. 78 2433 0 0.04 14 2 2.95 79 2464 0 0.04 16 2 2.95 Shallow Line of Pits. 80 2495 0 0.04 14 3 2.98 81 2526 0 0.04 . 14 4 2.94 ■ 82 2557 0 0.04 15 2 2.94 Shallow Line of Pits. 83 2588 0 0.04 15 2 2.96 Shallow Pitting. 84 2618 0 0.04 14 3 2.94 85 2647 0 0.04 17 2 2.94 Shallow Line of Pits. 86 2677 0 0.04 15 2 2.97 Shallow Line of Pits. 87 2708 0 0.03 13 2 2.96 88 2739 0 0.04 15 3 2.96 Shallow Pitting. ■ 89 2769 0 0.04 15 2 2.95 Shallow Pitting. 90 2800 0 0.05 19 4 2.95 Shallow Line of Pits. ■ 91 2830 0 0.04 14 2 2.95 92 2862 0 0.04 15 3 2.95 Shallow Pitting. 93 2893 0 0.04 16 2 2.97 Shallow Pitting. 94 2924 0 0.04 15 3 2.97 Shallow Pitting. IPenetration Body Metal Loss Body Page 2 411/ • PDS Report Joint Tabulation Sheet Well: 1 E-11 Survey Date: July 6,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.2 ppf J-55 BUTT ABMOD Tubing 2.992 in. 0.254 in. 29 ft. 7,548 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 95 2954 0 0.03 13 2 2.97 ■ 96 2985 0 0.05 18 2 2.95 Shallow Line of Pits. ■ 97 3015 0 0.04 15 3 2.95 Shallow Pitting. 98 3045 0 0.03 10 2 2.95 99 3076 0 0.04 14 2 2.96 ■ 100 3108 0 0.04 16 2 2.95 Shallow Pitting. ■ 101 3139 0 0.05 19 3 2.97 Shallow Pitting. ■ 102 3171 0 0.03 12 2 2.96 ■ 103 3201 0 0.04 15 2 2.98 Shallow Pitting. ■ 104 3233 0 0.04 15 2 2.93 Shallow Pitting. 105 3261 0 0.02 9 3 2.97 106 3291 0 0.03 10 2 2.96 ■ 107 3322 0 0.04 17 2 2.94 Shallow Pitting. ■ 108 3354 0 0.03 13 2 2.95 ■ 109 3384 0 0.05 21 2 2.96 Isolated Pitting. 110 3416 0 0.02 8 2 2.96 111 3447 0 0.03 10 2 2.95 112 3477 0 0.04 16 3 2.96 Shallow Pitting. ■ 113 3509 0 0.03 10 3 2.96111 114 3540 0 0.03 10 2 , 2.96 • 115 3570 0 0.03 10 2 2.94 • 116 3599 0 0.03 11 2 2.95 117 3631 0 0.02 8 2 2.95 118 3660 0 0.04 14 2 2.96 ■ 119 3691 0 0.03 12 2 2.95 ■ 120 3722 0 0.03 12 2 2.93 ■ 121 3751 0 0.05 19 2 2.95 Shallow Line of Pits. ■ 122 3781 0.05 0.06 24 2 2.94 Isolated Pitting. ■ 123 3812 0 0.04 14 2 2.95 ■ 124 3844 0 0.04 14 2 2.95 ■ 125 3873 0 0.03 11 2 2.93 ■ 126 3905 0 0.03 10 3 2.92 Lt. Deposits. ■ 127 3936 0 0.04 14 3 2.93 Lt. Deposits. 127.1 3967 0 0 0 0 2.88 GLM 2(LATCH @ 12:00) 128 3973 0 0.04 15 2 2.96 Shallow Pitting. ■ 129 4005 0 0.03 11 2 2.98 ■ 130 4034 0 0.05 18 2 2.95 Shallow Pitting. ■ 131 4064 0 0.05 20 2 2.96 Line of Pits. ■ 132 4096 0 0.05 18 3 2.97 Shallow Line of Pits. ■ 133 412 7 0 0.03 13 2 2.95 ■ 134 4158 0 0.03 13 2 2.95 ■ 135 4189 0,04 0.04 15 2 2.95 Shallow Pitting. ■ 136 4217 0 0.03 13 3 2.95 ■ 137 4248 0 0.04 14 2 2.95 ■ 138 4278 0.04 0.05 19 2 2.96 Shallow Line of Pits. ■ 139 4309 0 0.04 15 2 2.94 Shallow Line of Pits. ■ 140 4341 0 0.05 19 2 2.96 Shallow Pitting. ■ 141 4370 0 0.04 15 2 2.95 Shallow Pitting, ■ 142 4399 0 0.05 19 3 2.96 Shallow Pitting. ■ 143 4429 0.04 0.04 16 3 2.97 Shallow Pitting. IPenetration Body Metal Loss Body Page 3 • • 11.1 PDS Report Joint Tabulation Sheet Well: 1 E-11 Survey Date: July 6,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.2 ppf J-55 BUTT ABMOD Tubing 2.992 in. 0.254 in. 29 ft 7,548 ft. Joint jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 144 4461 0 0.05 20 2 2.97 Line of Pits. ■ 145 4491 0 0.04 15 2 2.95 Shallow Line of Pits. 146 4520 0 0.04 15 3 2.91 Shallow Pitting. Lt.Deposits. ■ 147 4552 0 0.03 11 2 2.95 148 4582 0 0.05 20 2 2.98 Line of Pits. 149 4613 0 0.05 19 2 2.96 Shallow Pitting. 150 4643 0 0.04 15 2 2.92 Shallow Pitting. Lt.Deposits. 151 4674 0 0.03 13 2 2.95 152 4706 0 0.05 18 4 2.96 Shallow Pitting. ■ 153 473 7 0 0.03 11 3 2.96 ■ 154 4766 0 0.03 12 2 2.97 155 479 7 0 0.03 11 2 2.96 156 482 8 0 0.03 12 2 2.94 157 4859 0 0.02 9 2 2.97 158 4891 0 0.03 11 2 2.96 159 4923 0 0.06 24 3 2.94 Line of Pits. 160 4955 0 0.04 14 2 2.97 161 4985 0 0.06 22 2 2.95 Isolated Pitting. 162 5016 0 0.04 17 2 2.95 Shallow Pitting. 163 5048 0 0.03 11 2 2.97 164 5076 0 0.03 11 3 2.97 165 5107 0 0.04 15 3 2.96 Shallow Pitting. 166 5138 0 0.04 17 3 2.96 Shallow Line of Pits. 167 5169 0 0.03 12 2 2.94 168 5199 0 0.02 8 2 2.95 • 169 5230 0 0.02 8 3 2.95 • 170 5263 0 0.04 15 2 2.97 Shallow Pitting. 171 5294 0 0.04 15 4 2.96 Shallow Line of Pits. ■ 172 5325 0 0.04 16 2 2.95 Shallow Line of Pits. 173 5356 0 0.04 17 4 2.94 Shallow Line of Pits. ■ 174 5386 0 0.04 15 3 2.96 Shallow Pitting. ■ 175 5417 0 0.04 16 2 2.96 Shallow Line of Pits. ■ 176 5449 0 0.04 14 2 2.95 176.1 5480 0 0 0 0 2.89 GLM 3(LATCH @ 4:00) 177 5486 0 0.03 . 13 3 2.94 • 178 5517 0 0.04 14 3 2.94 ■ 179 5547 0 0.06 22 3 2.92 Line of Pits. Lt.Deposits. ■ 180 5578 0 0.07 27 2 2.95 Line of Pits. 181 5607 0 0.04 14 2 2.96 182 5639 0 0.04 15 2 2.95 Shallow Pitting. 183 5669 0 0.04 17 2 2.93 Shallow Line of Pits. 184 5699 0.04 0.05 20 2 2.95 Isolated Pitting. 185 5730 0 0.03 13 2 2.95 186 5760 0 0.04 14 2 2.94 187 5791 0 0.03 11 2 2.95 188 5821 0 0.04 15 2 2.95 Shallow Pitting. 189 5851 0 0.04 14 2 2.95 190 5881 0 0.03 12 2 2.94 191 5910 0 0.04 14 2 2.92 Lt. Deposits. 192 5941 0 0.03 11 2 2.95 IPenetration Body Metal Loss Body Page 4 • • .L.RS PDS Report Joint Tabulation Sheet Well: 1E-11 Survey Date: July 6,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.2 ppf J-55 BUTT ABMOD Tubing 2.992 in. 0.254 in. 29 ft 7,548 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 193 5972 0 0.04 14 1 2.95 ■ 194 6003 0 0.04 14 2 2.94 ■ 195 6033 0 0.03 12 3 2.96 ■ 196 6065 0 0.03 13 2 2.94 ■ 197 6096 0 0.03 11 2 2.95 198 612 8 0 0.02 7 2 2.943 199 6158 0 0.02 9 2 2.93 Lt. Deposits. 200 618 7 0 0.04 14 2 2.95 201 6219 0 0.02 6 2 2.95 202 6251 0 0.02 8 2 2.92 Lt. Deposits. 203 6279 , 0 0.04 14 3 2.92 Lt. Deposits. ■ 204 6309 0 0.04 15 2 2.95 Shallow Pitting. ■ 205 6340 0 0.03 10 2 2.95 r 206 6369 0 0.03 13 2 2.96 ■ 207 6397 0 0.03 12 3 2.94 ■ 208 6429 0 0.03 13 2 2.89 Lt. Deposits. 209 6460 0 0.02 9 2 2.91 Lt. Deposits. 210 6491 0 0.03 11 2 2.96 ■ 211 6523 0 0.03 10 2 2.94 ■ 212 6554 0 0.04 14 4 2.93 212.1 6584 0 0 0 0 2.88 GLM 4(LATCH @ 4:00) 213 6591 0 0.03 11 2 2.93 Lt. Deposits. ■ 214 6622 0 0.04 15 3 2.95 Shallow Line of Pits. 215 6651 0 0.02 9 2 2.91 Lt. Deposits. 216 6681 0 0.04 15 2 2.92 Shallow Pitting. Lt.Deposits. ■� 217 6712 0 0.03 10 2 2.93 Lt. Deposits. ■� 218 6744 0 0.03 13 2 2.95 ■ 219 6776 0 0.03 12 2 2.93 Lt. Deposits. 220 6806 0 0.02 9 2 2.92 Lt. Deposits. 221 6836 0 0.04 14 3 2.94 ■ 222 6868 0 0.04 15 5 2.96 Shallow Pitting. ■ 223 6899 0 0.04 17 3 2.95 Shallow Pitting. ■ 224 6928 0 0.03 12 3 2.94 ■ 225 6958 0 0.03 13 2 2.95 ■ 226 6990 0 0.03 13 2 2.95 ■ 227 7020 0 0.04 15 2 2.95 Shallow Pitting. ■ 228 7051 0 0.03 12 2 2.95 ■ 229 7082 0 0.03 11 2 2.95 ■ 230 7112 0 0.03 11 2 2.95 ■ 231 7143 0 0.03 13 2 2.96 ■ 232 7174 0 0.04 15 2 2.91 Shallow Line of Pits.Lt. Deposits. ■ 233 7205 0 0.03 11 3 2.96 ■ 234 7234 0 0.03 12 2 2.95 ■ 235 7265 0 0.03 10 2 2.94 ■ 236 7295 0 0.03 11 3 2.97 ■ 237 7326 0 0.04 14 2 2.96 ■ 238 7357 0 0.04 14 2 2.90 Lt. Deposits. ■ 239 7386 0 0.03 13 2 2.94 ■ 239.1 7416 0 0.03 12 2 2.94 Pup 239.2 7424 0 0 0 0 2.89 GLM 5(LATCH @ 2:00) IPenetration Body Metal Loss Body Page 5 • i ~ PDS Report Joint Tabulation Sheet Well: 1E-11 Survey Date: July 6,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.2 ppf J-55 BUTT ABMOD Tubing 2.992 in. 0.254 in. 29 ft 7,548 ft. Joint it.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 239.3 7431 0 0.02 6 1 2.93 Pup Lt. Deposits. 240 7437 0 0.15 57 4 2.91 Isolated Pitting. Lt.Deposits. rr11111M 240.1 7469 0 0.02 8 0 2.94 Pup 240.2 7473 0 0.01 4 0 2.91 Pup Lt. Deposits. 1 240.3 7475 0 0 0 0 2.95 BAKER PBR 240.4 7490 0 0 0 0 2.86 BAKER HB RETRIEVABLE PACKER 240.5 7497 0 0.00 0 0 2.93 Pup 241 7498 0 0.02 9 3 2.96 241.1 7527 0.05 0.04 15 1 2.95 Pup Shallow Line of Pits. 241,2 7531 0 0 0 0 2.78 BAKER SBR 241.3 7538 0 0.02 6 1 2.94 Pup 241.4 7547 0 0 0 0 2.95 PUP IPenetration Body Metal Loss Body Page 6 • • PDS Report Cross Sections m Well: 1 E-11 Survey Date: July 6,2017 Field: Kuparuk Tool Type: UW MFC 24 No.214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.2 ppf J-55 BUTT ABMOD Analyst: C.Waldrop Cross Section for Joint 240 at depth 7,453.800 ft. Tool speed=47 • Nominal ID=2.992 Nominal OD=3.5 Remaining wall area=96% • Tool deviation=52° 1 Finger=9 Penetration=0.146 in. Isolated Pitting 0.15 in.=57%Wall Penetration HIGH SIDE=UP • S PDS Report Cross Sections VS„ Well: 1 E-11 Survey Date: July 6,2017 Field: Kuparuk Tool Type: UW MFC 24 No.214320 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.2 ppf J-55 BUTT ABMOD Analyst: C.Waldrop Cross Section for Joint 180 at depth 5,589.100 ft. Tool speed= 54 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area=98% Tool deviation=33° / 1 1 rr� Finger=6 Penetration=0.069 in. Line of Pits 0.07 in.=27%Wall Penetration HIGH SIDE=UP KUP INJ • 1E-11 ConocoPhillips ' °- , Well Attributes Max Angle&MD TD Alaska,Inc. x, Wellbore API/UWI Field Name Wellbore Status ncl CI MD(ftKB) Act Btm(ftKB) cmocoesiMps 500292078700 KUPARUK RIVER UNIT INJ 54.00 7,500.00 8,754.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1E-11,10/11/20161105.57 AM SSSV:Flapper Locked Out _ Last WO: 4/4/1991 40.71 5/10/1982 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date .......Last Tag'SLM 8,032.0 8/4/2014 Rev Reason:GLV C/O pproven 10/11/2016 I I Casing Strings f Casing Description 05(in) ID(in) Top(ftK8) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.060 32.0 80.0 80.0 65.00 H-40 WELDED ��pI�� HANGER;35.0 II'.HIA7'11 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Aar �.,uu uuw SURFACE 10 3/4 9.950 31.3 2,835.1 2,475.5 45.50 K-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len It...Grade Top Thread PRODUCTION 7 6.276 30.5 8,723.0 6,790.3 26.00 K-55 BTC - °.CONDUOTOR;32.0-80.0 / ',,,n.a,,.Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)I...Wt(lb/ft) Grade Top Connection TUBING WO 1991 31/2 2.992 35.0 7,557.8 6,059.6 9.20 J-55 BUTT AB-MOD SAFETY VLV;1,952.2 Completion Details Nominal ID _.-) Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 35.0 35.0 0.13 HANGER FMC GEN III HANGER 3.500 GAS LIFT;1,999.0 1,952.1 1,818.8 41.84 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE(LOCKED OUT 2.812 FLAPPER 5/18/12) 7,475.8 6,011.2 53.79 PBR BAKER PBR w/10'STROKE 3.000 7,491.0 6,020.2 53.92 PACKER BAKER HB RETRIEVABLE PACKER 2.880 SURFACE;31.3-2.835.1-+ 7,532.1 6,044.3 53.80 SBR BAKER SBR 4.437 ;, Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)I...Wt(lb/ft) Grade Top Connection TUBING Original 4 2.992 7,557,8 7,973.3 6,311.9 9.20 J-55 FL4S Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Cont (in) GAS LIFT;3,972.0 7,557.8 6,059.5 53.63 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 7,700.4 6,145.3 52.43 BLAST RINGS BLAST RINGS(OAL=96) 2.992 GAS LIFT;5,482.1 - 7,950.1 6,297.7 52.18 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 GAS UFT;6'587.4 7,950.6 6,298.1- 52.18 PACKER BAKER FB-1 PERMANENT PACKER 2.875 -- 7,953.1 6,299.6 52.18 SBE BAKER SEAL BORE EXTENSION 2.937 GAS LIFT;7,423.6 7,965.8 6,307.3 52.18 NIPPLE CAMCO D NIPPLE NO GO 2.750 • 7.972.5 6.311.5 52.18 SOS BAKER SHEAR OUT SUB 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl PACKER;7,440.1 - -- Top(ftKB) (ftKB) C) Des Com Run Date ID(in) +I 7,440.1 5,990.0 53.48 PACKER UPPER WEATHERFORD ER PACKER 3/2/2013 1.750 PATCH;7,442.9 ,4-111 PACKER;7,4619 - . 11 7442.9 5,991.7 53.51 PATCH PATCH,SPACER PIPE,SNAP LATCH ASSEMBLY 3/2/2013 1.750 7,461.9 6,002.9 53.67 PACKER LOWER WEATHERFORD ER PACKER 1/8/2013 1.750 ii Perforations&Slots PBR,7475.8 J Shot Dens Top(TVD) Btm(TED) (shots/f PACKER,7,491.0 Top(ftKB) Bim(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,708.0 7,794.0 6,149.9 6,202.3 C-4,C-3,C-2, 5/10/1982 4.0 (PERF • C-1,1E-11 7,996.0 8,008.0 6,325.9 6,333.2 A-5,1E-11 2/1/1985 8.0 RPERF Original Pert 5/10/82 SBR,7,532.1 1 8,028.0 8,056.0 6,345.5 6,362.8 A-4,1E-11 2/1/1985 8.0 RPERF Original Pert 5/10/82 8,061.0 8,076.0 6,365.9 6,375.3 A-4,1E-11 2/1/1985 8.0 RPERF Original Pert 5/10/82 PACKER;7,557.8 Mandrel Inserts St INJECTION;7,595.9 ati Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model 05(in) Sery Type Type (in) (pal) Run Date Com INJECTION;7,662.1 { 1,999.0 1,853.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/20/1996 1:00 Mt 2 3,971.9 3,330.3 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/20/1996 12:30 • I _ 3 5,482.1 4,512.4 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/20/1996 3:30 IPERF;7,708.x7,794.0- 4 6,587.4 5,398.6 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/4/1991 4:00 5 7,423.6 5,980.2 CAMCO MMG-2 11/2 GAS LIFT DMY RK 0.000 0.0 10/8/2016 6 7,595.9 6,082.2 CAMCO KBUG 1 INJ HFCV BK 0.000 0.0 6/3/2009 3:00 7 7,662.1 6,122.0 CAMCO KBUG 1 INJ HFCV BK 0.000' 0.0 6/3/2009 1:00 8 7,929.0 6,284.8 CAMCO KBUG 1 INJ HFCV BK 0.000 0.0 6/3/2009 -10:00 a Notes:General&Safety INJECTION;7.929.0 - End Date Annotation 4/4/1991 NOTE:Drilling Rig RKB discrepancy beween 1982 original TBG and 1991 workover TBG SEAL ASSY,7,950.1 9/25/2004 NOTE:E-LINE DOCUMENTED MANDREL LEAK @ 7640' PACKER;7,950.6 8/25/2010 NOTE:View Schematic w/Alaska Schematic9.0 SBE,7,953.1 - St' 8/11/2011 NOTE:E/L IDENTIFIED LEAK e 7452'ELM 1 NIPPLE;7,965.8 V. I SOS;7,972.5 illi RPERF;7,996.0-6008.0- I RPERF;8,028.0-8,056.0-- I RPERF;8,061.0-8,076.0 FISH;8.149.0 PRODUCTION;30.5-8,723.0 • • • VOF To ,6. THE STATE Alaska Oil and Gas �►-s- �, of e TT ee cc 11 � � Conservation Commission ALIZ�JJ�lA 5}fix 333 West Seventh Avenue t GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ' Main: 907.279.1433 OF ALASY'P Fax: 907.276.7542 www.aogcc.alaska.gov Brent Rogers NSK Well Integrity Supervisor ti �> ConocoPhillips Alaska, Inc. o��'� P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1E-11 Permit to Drill Number: 182-051 Sundry Number: 317-192 Dear Mr. Rogers: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy '. Foerster ,c� Chair DATED this /7' ray of May, 2017. RBDMS ,V MAY 1 9 2017 • • • RECEIVED STATE OF ALASKA MAY 1 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well 0 , Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved pproved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter CasingI{✓� ❑ Other: �Tubing patc 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory ❑ Development L 1820510 - 3.Address: r} Stratigraphic ❑ Service i,LJ 6.API Number: P.O.Box 100360,Anchcorage,Alaska 99510 4 50-029207870000 • 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 / KRU 1 E-11 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 0025651 • Kuparuk River Unit/Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8754'- 6810' , 8032' • 6348' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 80' 80' Surface 2804' 10 3/4" 2835' 2476' Intermediate Production 8692' 7" 8723' 6790' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Intervals from 7708'-8076' Intervals from 6150'-6375' 3 1/2" J-55 7558' Packers and SSSV Type: Baker HB Retrievable Packer Packers and SSSV MD(ft)and TVD(ft):- HB=7491'MD,6020'TVD Baker FHL Retrievable Packer ,.FHL=7558'MD,6060'TVD Camco TRDP 1A-SSA SSSV Baker FB-1 Permanent Packer SSSV=1952'MD,1819'TVD .. FB-1=7951'MD,6298'TVD 12.Attachments: Proposal Summary U Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 0 ti 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 10-Jun-17 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0 • GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Brent Rogers Brent Rogers/KellyL Contact Name: ons Lyons Authorized Title: NSK Well Integrity Supervisor Contact Email: N1617(c�conocophillips.com r. Contact Phone: 659-7224 Authorized Signature: / Date: 9-May-17 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: S17- \2. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ 4 j 1:4 k t Other: Post Initial Injection MIT Req'd? Yes ErNo ❑ RBDMS t MAY 1 9 2017 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: Fri -— --0 4 p95iti,7 APPROVEDBYApproved by:tn p ( �-y/� COMMISSIONER THE COMMISSION Date:S./7 - /7 eka S'il / VForm 10-403 Revised 4/2017 RIGJa ppplllArLiapvalid for 12 months from the date of approval. Attachments in Duplicate • ConocoPhillips RECEIVED Alaska MAY 11 2017 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC May 9, 2017 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West '7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 1E-11 (PTD 182-051). The request is for approval to test and replace tubing patch equipment to repair a tubing leak above the top packer. Please call Kelly Lyons or myself at 659-7224 if you have any questions. Sincerely, Brent Rogers Well Integrity Supervisor Attachments • • ConocoPhillips Alaska,Inc. Kuparuk Well 1E-11 (PTD 182-051) SUNDRY NOTICE 10-403 TUBING REPAIR 05/09/17 This Sundry is a request for approval to repair ConocoPhillips (CPA) Kuparuk Well 1E-11 (PTD 182-051) by pulling the existing tubing patch and replacing it with a different style. In December 2016, the original patch was identified as leaking. The existing tubing patch was pulled and replaced at that time. Diagnostics have identified further communication on gas injection and the suspicion is the patch is leaking to gas only. The plan is to pull the existing patch, set a different style of retrievable patch over the leak point,perform a 30 day gas injection test period, conduct a witnessed MITIA, and return the well to normal WAG injection. REPAIR PLAN 1. Pull 22' 3.5"retrievable patch assembly from 7440' —7462' 2. Set 25' 3.5" One trip retrievable patch over the leak at 7452'. 3. Perform pre-injection MITIA 4. Bring on gas injection for a 30 day test. a. WAG back to water early if there are signs of communication. b. Submit AA for water only injection. 5. MIT as per AOGCC requirements (0.25 x TVD to packer). 6. Submit 10-404 post-repair. NSK Problem Well Supervisor �. ., KUP INJ 0 IE-11 ' CAnDCOPhillIp$ ? Well Attributes Max Angle&MD TD Alaska,Inc„ Wellbore API/ NI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) { �yut�»'' 500292078700 KUPARUK RIVER UNIT INJ 54.00 7,500.00 8,754.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-11,10/11201611;05:57 AM SSSV:Flapper Locked Out Last WO: 4/4/1991 40.71 5/10/1982 Venical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date --- ---,.- --- ---- --.._.Last Tag:SLM 8,032.0 8/4/2014 Rev Reason:GLV C/O pproven 10/11/2016 Fasing; togs t, Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread CONDUCTOR 16 15.060 32.0 80.0 80.0 65.00 H-40 WELDED HANGER;35.0 IIT,• )'Il Casing Description 'OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD).,.Wt/Len(I...Grade Top Thread SURFACE 10 3/4 9.950 31.3 2,835 1 2,475.5 45.50 K-55 BTC I I I., I I I I Casing Description OD(in) ID('n) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread PRODUCTION 7 6 276 30 5 8,723.0 6 790 3 26 00 K-55 BTC CONDUCTOR;3z.0-eo.o• Tubing':Strings -, '. .. - ` Tubing Description String Ma...ID(in) Top(8KB) Set Depth(ft.Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING WO 1991 3 1/2 2.992 35.0 7,557.8 6,059.6 9.20 J-55 BUTT AB MOD SAFETY VLV;1,952 2 LF. Completion Details . . lL FR Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Nominal ID Com (in) 35.0 35.0 0.13 HANGER FMC GEN III HANGER 3.500 GAS LIFT;1,9990 ig 1,952.2 1,818.8 41.84 SAFETY VLVCAMCO TRDP-1A-SSA SAFETY VALVE(LOCKED OUT 2.812 FLAPPER 5/18/12) I I 7,475.8 6,011.2 53.79 PBR BAKER PBR w/10'STROKE 3.000 7,491.0 6,020.2 53.92 PACKER BAKER HB RETRIEVABLE PACKER 2.880 SURFACE;31.3-2,835.1- 7,532.1 6,044.3 53.80 SBR BAKER SBR 4.437 1 I Tubing Description !String Ma...I ID(in) !Top(ftKB) Set Depth(ft..1 Set Depth(TVD)(...IWt(Ibttt) (Grade I Top Connection 1 TUBING Original 4 2.992 7,557.8 7,973.31 6,311.9 9.20 J-55 FL4S Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT;3,972.0 �I'. 7,557.8 6,059.5 53.63 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 7,700.4 6,145.3 52.43 BLAST RINGS BLAST RINGS(OAL=96) 2.992 GAS LIFT;5,482.1 ill1 7,950.1 6,297.7 52.18 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 GAS LIFT;6,5874 II4 7,950.6 6,298.1 52.18 PACKER BAKER FB-1 PERMANENT PACKER 2.875 7,953.1 6,299.6 52.18 SBE BAKER SEAL BORE EXTENSION 2.937 GAS LIFT;7423.6 7,965.8 6,307.3 52.18 NIPPLE CAMCO D NIPPLE NO GO 2.750 I7,972.5 6,311.5 52.18 SOS BAKER SHEAR OUT SUB 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) . Top(TVD) Top Incl PACKER;7,440.1 _r- Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 7,440.1 5,990.0 53.48 PACKER UPPER WEATHERFORD ER PACKER 3/2/2013 1.750 PATCH;7,442.9 'MI' PACKER;7,461.9 7,442.9 5,991.7 53.51 PATCH PATCH,SPACER PIPE,SNAP LATCH ASSEMBLY 3/2/2013 1.750 111 7,461.9 6,002.9 53.67 PACKER LOWER WEATHERFORD ER PACKER 1/8/2013 1.750 Perforations8 Slots PBR,7,475.8 .. Shot Dens Top(TVD) Btm(TVD) (shots/1 PACKER,7,491.0 ... ... Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,708.0 7,794.0 6,149.9 6,202.3 C-4,C-3,C-2, 5/10/1982 4.0 (PERF ii C-1,1E-11 7,996.0 8,008.0 6,325.9 6,333.2 A-5,1E-11 2/1/1985 8.0 RPERF Original Pert 5/10/82 SBR;7,532.1 S 1 8,028.0 8,056.0 6,345.5 6,362.8 A-4,1E-11 2/1/1985 8.0 RPERF Original Perf 5/10/82 8,061.0 8,076.0 6,365.• 6,375.3 A-4,1E-11 2/1/1985 8.0 RPERF Original Per(5/10/82 PACKER,7,557.8 .-' ' ' ' Mandrel Inserts I It St INJECTION,75959 - ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Corn INJECTION,7,662.1 ;_ 1 1,999.0 1,853.2 CAMCO BUG 1 GAS LIFT DMY BK 0.000 0.0 5/20/1996 1:00 2 3,971.9 3,330.3 CAMCO BUG 1 GAS LIFT DMY BK 0.000 0.0 5/20/1996 12:30 I I 3 5,482.1 4,512.4 CAMCO BUG 1 GAS LIFT DMY BK 0.000 0.0 5/20/1996 3:30 IPERF;7,708.0-7,794.0 4 6,587.4 5,398.6 CAMCO BUG 1 GAS LIFT DMY BK 0.000 0.0 4/4/1991 4:00 5 7,423.6 5,980.2 CAMCO MG-2 11/2 GAS LIFT DMY RK 0.000 0.0 10/8/2016 6 7,595.9 6,082.2 CAMCO BUG 1 INJ HFCV BK 0.000 0.0 6/3/2009 3:00 7 7,662.1 6,122.0 CAMCO KBUG 1 INJ HFCV BK 0.000 0.0 6/3/2009 1:00 8 7,929.0 6,284.8 CAMCO KBUG 1 INJ HFCV BK 0.000 0.0 6/3/2009 10:00 Notes:General 8,Safety ` INJECTION,7,9290 L■Z_ End Date Annotation - 4/4/1991 NOTE:Drilling Rig RKB discrepancy beween 1982 original TBG and 1991 workover TBG `' SEAL ASSY;7,950.1 • 9/25/2004 NOTE:E-LINE DOCUMENTED MANDREL LEAK 5 7640' PACKER;7,950.6 8/25/2010 NOTE:View Schematic w/Alaska Schematic9.0 SBB 7,953.1 •`•• - 8/11/2011 NOTE:E/L IDENTIFIED LEAK 5 7452'ELM NIPPLE,7,965.8 I SOS;7,972.5 RPERF;7,996.0-8,008.0 RPERF;8,028.0-8,056.0-.. RPERF;8,061 0-8,076.0 FISH,8,149.0 PRODUCTION,30.5-8,723 0 • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Wednesday,April 12, 2017 9:52 AM To: NSK Well Integrity Supv CPF1 and 2 Cc: Senden, R.Tyler Subject: RE: Pre-emptive report of abnormally high number of IA bleeds 1E-11 (PTD 182-051) update 3-20-17 Brent, Your request to keep the well on water only injection prior to Sundry tubing patch work is approved for up to 60 days. If due to unforeseen circumstances an extension of time is required,an email request with an updated TIO and schedule should be sent. Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone),(907)276-7542(fax),chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: NSK Well Integrity Supv CPF1 and 2 [mailto:n1617@conocophillips.com] SCANNED APR 2 0 2017 Sent:Wednesday,April 12,2017 9:24 AM To:Wallace,Chris D (DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com>; NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Subject: RE: Pre-emptive report of abnormally high number of IA bleeds 1E-11 (PTD 182-051) update 3-20-17 Chris, Following up on the status and a change of plans with this well. The well was WAG'd to PWI on 03/21/17. DHD did some diagnostics including bleeding the IA down and degassing the charged fluid and performing another passing MITIA on 03/31/17. The IA pressure has been stable following the MITIA as seen in the attached TIO plot for the previous month. The tubing patch in this well was pulled and reset under Sundry#316-637 back in February 2017. Prior to pulling and resetting the patch,the IA was circulated out with clean fluid. After the current patch was set,the well had been on gas injection only for 18 days when the IA pressure anomaly was identified. The belief is that the patch is potentially the source of the gas only leak. It is ConocoPhillips intent to pull and replace the existing patch with a different style one trip patch assembly that is rated to be gas tight. A 10-403 will be submitted for the pull and replace of this patch style. This patch has a better gas rating than the current patch system and also is one piece taking out the anchor latch as a possible leak point. Manufacturing and current estimated delivery date is 8 weeks out. ConocoPhillips requests to leave the well on water injection until the time the patch can be pulled and replaced without applying for an AA at this time. Following the replacement a diagnostic MITIA to prove up integrity will be done,the well would be WAG'd back to gas for a 30 day test to see if the new patch solved the issue. Following the test period,a witnessed test will be performed and either the well returned to normal injection status or if communication continues,the well would be WAG'd back to water and an AA would be submitted at that time. 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Monday, March 20, 2017 9:58 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: Pre-emptive report of abnormally high number of IA bleeds 1E-11 (PTD 182-051) update 3-20-17 Attachments: 1E-11 90 day TIO 3-20-17.PNG 1E-11 has continued to display IA repressurization while on gas injection after an additional 2 more bleeds were performed since the well was reported last Thursday. CPAI plans to WAG the well back to water as soon as possible. After stabilization is reached,we intend to perform an MITIA and packoff tests to confirm there have been no changes to the integrity of the tubing. Following the DHD tests,the well will be put on a 30 day monitor. Pending a successful water injection monitor period and passing MIT,we intend to submit an AA application. If the well fails the MIT,the well will be shut in as soon as possible. Please let me know if you disagree with the plan forward. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk one (907) 659-7224 Mobile hPhone (907)943-0170 sot%�g Ei1 From: NSK Well Integrity Supv CPF1 and 2 Sent:Thursday, March 16, 2017 5:09 PM To: 'chris.wallace@alaska.gov'<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: Pre-emptive report of abnormally high number of IA bleeds 1E-11(PTD 182-051) 3-16-17 Chris, Kuparuk WAG injector 1E-11 (PTD 182-051)) has needed its IA to be bled multiple times since being WAG'ed to gas injection on March 3, 2017. There have been major temperature and injection rate changes. Therefore at this point,the IA repressurization is believed to be thermally induced. However, because of the abnormally high number of bleeds,the well will monitored under heightened scrutiny for the next 30 days. If the well becomes suspected of displaying TxIA annular communication it will be reported at that time. Please let me know if you disagree with the plan forward. Attached is a 90 day TIO plot. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Mobile Phone(907)943-0170 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Thursday, March 16, 2017 5:09 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: Pre-emptive report of abnormally high number of IA bleeds 1E-11 (PTD 182-051) 3-16-17 Attachments: 1E-11 90 day TIO 3-16-17.PNG Chris, Kuparuk WAG injector 1E-11 (PTD 182-051)) has needed its IA to be bled multiple times since being WAG'ed to gas injection on March 3, 2017. There have been major temperature and injection rate changes. Therefore at this point,the IA repressurization is believed to be thermally induced. However, because of the abnormally high number of bleeds,the well will monitored under heightened scrutiny for the next 30 days. If the well becomes suspected of displaying TxIA annular communication it will be reported at that time. Please let me know if you disagree with the plan forward. Attached is a 90 day TIO plot. Kelly Lyons/ Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907) 943-0170 SCANNED MAR 2 4 2017 W U) (.) V) C!) V) U w :�CI N O Lr 1lJ W W W W III 111 U1 V N Ceo) 2 - o f c, Jn : S , G N W Cr `. u O I CZ. •1 C) L 0' r. 0) Of u) .1 r., , (1, n, W Ca c uJ C. 0) CZ. C, O O U U C. u.U Com) 01 0 I"- C, 1 UU, a — N N .- e- F u7 h- A N C'- f~ C-- ,_ N r, of r. I"' ni c' rl 0 J J U I w Li, U1 U1 UI w W 11.1 i UU) ,M N O O �ap G Cl G o '4 Q) co r co r-- ^- I I I 1 I I I 4 1 vs - aa r�. fs :7:7R I ria L tic u_ i'411.1 Rs 2 Q) IL V ei V C CS ti r.. m U O M m ' C E Usir ~ t4 1 N Z C ~ e- QIrL 1-- 4111I ) cO CD r• r 1 0 � a• A ( CLI CO I IIII , I I I a) Lco Em { I H LI 6 O GOOOO OO U :i I' n Z • R Q 1f, OO Ifi Q 1f, G 1fl G If, 3.110 CANS iw N `7 `7 ,,,-i Cr) CV CJ '''° �sd 5cnOw • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,February 27,2017 TO: Jim Regg �t� P.I.Supervisor N`>v^- SUBJECT: Mechanical Integrity Tests '� CONOCOPHILLIPS ALASKA INC 3\7i\'4 ' 1E-11 FROM: Chuck Scheve KUPARUK RIV UNIT 1E-11 Petroleum Inspector Src: Inspector Reviewed By: 1 P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1E-11 API Well Number 50-029-20787-00-00 Inspector Name: Chuck Scheve Permit Number: 182-051-0 Inspection Date: 2/20/2017 Insp Num: mitCS170220162043 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1E-11 Type Inj W TVD 6060 .../Tubing 2437 2433 2439 2449 2457 2444 PTD 1820510 Type Test SPT Test psi 1515 IA 1400 3300 3100 3000 2960 2940 BBL Pumped: 3.1 BBL Returned: 1.7 OA 210 220 220 220 220 220 Interval OTHER P/F P ,ve Notes: Test post tubing patch Sundry#316-637 SCANNED APR 2 8 2017, Monday,February 27,2017 Page 1 of 1 STATE OF ALASKA ' ALA"OIL AND GAS CONSERVATION COIV SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r RugPerforations Pull Tubing Fracture Stimulate �" Operations shutdown �' Performed. Suspend r Perforate r Other Stimulate Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool fl Repair Well r Re-enter Susp Well fl Other: tbg patch 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development f Exploratory ' 182-0510 3.Address: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service 6.API Number: 9 50-029-20787-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025651 KRU 1E-11 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/ Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8754 feet Plugs(measured) None true vertical 6810 feet Junk(measured) None Effective Depth measured 8032 feet Packer(measured) 7440, 7443, 7462, 7491, 7558 true vertical 6348 feet (true vertical) 5990, 5992, 6003, 6020, 6060 Casing Length Size MD TVD Burst Collapse CONDUCTOR 48' 16 80' 80' SURFACE 2804' 10 3/4 2835' 2475' PRODUCTION 8693' 7 8723' 6790' RECEIVED Perforation depth: Measured depth: 7708-7794, 7996-8008, 8028-8056, 8061-8076 FEB 2 7 2017 True Vertical Depth: 6150-6202, 6326-6333,6346-6363, 6366-6375 AOGCO Tubing(size,grade,MD,and TVD) 3 1/2 ,J-55, 7973 MD, 6311 TVD Packers&SSSV(type,MD,and TVD) SAFETY VLV=CAMCO TRDP-1A-SSA(LOCKED OUT FLAPPER)@ 1952 MD& 1819 TVD PACKER= UPPER WEATHERFORD ER PACKER©7440 MD and 5990 TVD PATCH=PATCH, SPACER PIPE, SNAP LATCH ASSEMBLY @ 7443 MD and 5992 TVD PACKER=LOWER WEATHERFORD ER PACKER @ 7462 MD and 6003 TVD PACKER= BAKER HB RETRIEVABLE PACKER @ 7491 MD and 6020 TVD PACKER=BAKER FHL RETRIEVABLE PACKER @ 7558 MD and 6060 ND 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): SCANNED e 1 Treatment descriptions including volumes used and final pressure: ANNE® r' . 1 J. 2017 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 17 Exploratory fl Development r Service ' Stratigraphic r Copies of Logs and Surveys Run r16.Well Status after work: Oil fl Gas r WDSPL f ' Printed and Bectronic Fracture Stimulation Data r GSTOR fl WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-637 Contact Kelly Lyons/Brent Rogers Email: n1617cconocophillips.com Printed Name Ily Lyons Title: NSK Well Integrity Supervisor Signature Phone:659-7224 Date 2-24-17 Form 10-404 R vi ed 5/2015 v?i- 3/2 V J 7-- Submit Original Only /49/7 RBDMS L" FEB 2 7 2017 S • ConocoPhillips Alaska RECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 FEB 272017 AOGCC February 24, 2017 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 1E-11 (PTD 182-051) for a retrievable patch pulled and reset in the tubing above the packer. Please call Brent Rogers or myself at 659-7224 if you have any questions. Sincerely, Kelly Lyons Well Integrity Supervisor Attachments • 1E-11 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/12/16 (AC EVAL) : MITIA(FAILED). IA-LLR @ 2900 psi (6.6 GPM). Initial T/I/O/OO = SI 960/1250/40/0. T FL @ SF. IA FL @ SF. Pressured IA to 2900 psi w/ 1.5 bbls diesel. Unable to pressure IA above 2900 psi. Pump an additional 1.2 bbls to confirm pressure stabilized while pumping (2.7 bbls total pumped). Continue pumping to establish LLR. IA LLR Starting T/I/O/OO = 960/2900/40/0. 1 min T/I/O/OO = 960/2900/40/0. (6.5 gal.) 1 min T/I/O/OO = 960/2880/40/0. (6.6 gal.) 1 min T/I/O/OO = 960/2850/40/0. (6.6 gal.) 1 min T/I/O/OO = 960/2825/40/0. (6.7 gal.) 1 min T/I/O/OO = 960/2800/40/0. (6.7 gal.) Average IA-LLR 6.6 gpm. Shut pump down. 15 min T/I/O/OO = 960/2190/40/0 (-610). Bled IA to 1250 psi in 3 min (fluid). Final T/I/O/OO = SI 960/1250/40/0. 12/11/16 MIRU. RIH WITH SLIM LDL TOOLSTRING. PERFORM BASELINE PASS FROM SURFACE TO 7500' KB AT 120 FPM. LRS PRESSURE UP IA TO 3000 PSI. ESTABLISH LLR OF .2 BPM AT 3000 PSI. PUMP 10 BBLS AWAY. PERFORM STOP COUNT AT 7525' KB. PERFORM DYNAMIC PASS FROM 7525' KB -SURFACE AT 120 FPM. NO CHANGE IN SPINNER. NOT ABLE TO DETERMINE LEAK LOCATION FROM TEMPERATURE OVERLAY. LRS ESTABLISH NEW LLR = 0.1 BPM @ 3000 PSI AND LLR = 0.25 BPM @ 3500 PSI. RDMO. JOB COMPLETE. Further processing of logs determined anomaly at existing patch in hole. 01/27/17 DRIFTED 2.79"TO 7440' RKB. PULLED UPPER WFT PACKER AND SPACER ASSEMBLY @ 7440' RKB. SET ER TEST TOOL IN LOWER PKR @ 7462' RKB. PERFORMED CMIT @ 3000 PSI. **PASSED**. BRUSH AND FLUSHED 7390' TO 7425' SLM. SET UPPER PATCH ASSY @ 7439' RKB. MIT-IA @ 3000 PSI **FAILED** IN PROGRESS. BEGIN CMIT @ 3000 PSI. PRE=1450/1350/40 PUMPED 3.9 BBLS INITIAL=3000/2550/40 15 MIN=2900/2450/40 30 MIN=2875/2450/40 PASSED. 01/28/17 TESTED UPPER PACKER @ 7439' RKB; PASSED. PERFORMED MIT-IA @ 3000 PSI; FAILED. PULLED UPPER WFT PACKER AND SPACER PIPE ASSY @ 7439' RKB. WFT CONFIRMED SNAP-LATCH HAD NOT ENGAGED LOWER PACKER. SET NEW WFT UPPER PATCH ASSY @ 7439' RKB. PERFORMED MIT-IA @ 3000 PSI; FAILED. IN PROGRESS. ER TEST TOOL TO 7409' SLM. PRESSURE TUBING TO 3000 PSI TEST GOOD after patch reset. WHILE PERFORMING MIT-IA @ 3000 PSI; FAILED IN 6 MINUTES. BUMP MIT-IA TO 3000 PSI MUSITPLE TIMES. CONTINUES TO FALL OFF LESS EACH TIME. 1ST TIME IA PASSED IT LOST 100 PSI. IN 15 MIN THEN 100 PSI IN 2ND 15 MIN. BUMP TO 3000 PSI. LOST 90 PSI IN 15 MIN AND 80 PSI IN 30 MIN • 1E-11 • DESCRIPTION gO�Fpy WORK COMPLETED 01/29/17 MIT-IA @ 3000 PSI; FAILED. PULLEQ UPPEFZ ER PACKER ASSY© 7439' RKB. PULLED LOWER ER PACKER @ 7462' RKB. BRUSH AND FLUSHED 7370'TO 7440' SLM. A NEW LOWER PACKER WILL NEED TO BE SET BY SMART LINE MIT-IA; @ 3000 PSI; FAILED. C-MIT T x IA @ 3000 PSI. PRE=1225/1300/30 PUMPED 3 BBLS INITIAL=3020/2725/30 15 MIN=2955/2660/30 30 MIN=2915/2630/30 FAILED 02/03/17 BRUSH 'N FLUSH PATCH INTERVAL FROM 7375'-7475' SLM. SET 2.72" LOWER ER PACKER @ 7463' RKB. CMIT 3000 PSI AGAINST TEST TOOL IN LOWER PACKER ( IN CONCLUSIVE )WILL RETEST IN AM. IN PROGRESS. BEGIN CMIT 3000 PSI. INITIAL T/I/O/OOA= 1100/900/40/OLRS PUMP 2.5 BBLS DSL. START = 3100/2925/40/0 15 MINS = 3050/2890/40/0 30 MINS = 3040/2860/40/0 45 MINS = 3020/2845/40/0 FAIL. RU LRS TO IA. RE TEST. START= 3300/3000/40/0 15 MINS = 3240/2910/0/50 30 MINS = 3180/2875/40/0 FAIL. 02/04/17 CMIT 3000 PSI AGAINST TEST TOOL SET IN LOWER PACKER ( PASS ) SET UPPER 2.72" ER PACKER, SPACER PIPE & LATCH ASSEMBLY(20' OAL ) © 7443' RKB. MITT-TBG 3000 PSI AGAINST TEST TOOL SET IN UPPER PACKER (PASS) MIT-IA 3000 PSI ( PASS ) JOB COMPLETE. BEGIN CMIT, INITIAL T/I/O = 1150/875/25 PUMP 3.2 BBLS START= 3050/2950/40 15 MINS = 2925/2850/40 30 MINS =2875/2840/40 PASS. BEGIN MITT 3000 PSI. INITIAL T/I/O/OO = 1000/825/40/0 LRS PT TBG TO 3000 PSI W/ .8 BBLS DSL. START= 3040/890/40/0 15 MINS = 2940/890/40/0 30 MINS =2910/890/40/0 PASS. BLEED TBG BACK TO 1500 PSI. RU LRS TO IA. BEGIN MITxIA 3000 PSI. INITIAL T/I/O/OO = 1500/975/50/0 START= 1725/3000/50/0 15 MINS = 1725/2860/50/0 20 1725/2825/50/0 PASS. 02/20/17 (SW) Chuck Scheve post patch MITIA Passed to 3300 psi. Initial T/I/O/OO = 2437/1400/210/0, IA FL @ SF. LRS pressured IA with 3.1 bbl diesel to T/I/O/OO = 2433/3300/220/0 15 min monitor: 2439/3100/220/0 (-200 psi). 30 min monitor: 2449/3000/220/0 (-100 psi). 45 min monitor: 2457/2960/220/0 (-40 psi). 60 min monitor: 2444/2940/220/0 (-20 psi). LRS bled IA(fluid) to 1400 psi (1.65 bbl). LRS continued bleeding IA for total of 4 min to T/I/O/OO =2441/800/210/0 Final T/I/O/OO =2441/800/210/0 Executive Summary An existing retrievable Weatherford tubing patch, covering a known leak at 7452', was found to be leaking. The patch was pulled and a new 22'Weatherford retrievable tbg patch reset. The patch integrity was confirmed with a passing AOGCC-witnessed MITIA. r. KUP INJ 1E-11 ConocoPhillips imWell Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status 1 ncl(°) MD(500) Act Btm(ftKB) optynpa 500292078700 KUPARUK RIVER UNIT INJ 54.00 7,500.00 8,754.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-11,10/11/2016 1155,57 AM SSSV:Flapper Locked Out Last WO: 4/4/1991 40.71 5/10/1982 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date .....- ---Last Tag:SLM 8,032.0 8/4/2014 Rev Reason:GLV C/O pproven 10/11/2016 I,i �l asing rings (, Casing Description OD(in) ID(in) Top MB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread CONDUCTOR 16 15.060 32.0 80.0 80.0 65.00 H-40 WELDED HANGER,35.0 planarill Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread SURFACE 103/4 9.950 31.3 2,835.1 2,475.5 45.50 K-55 BTC 1111111 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...•WVLen(I...Grade Top Thread PRODUCTION 7 6.276 30.5 8,723.0 6,790.3 26.00 K-55 ETC Tubin Strin s CONDUCTOR;32.0-80.0- g g Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING WO 1991 31/2 2.992 35.0 7,557.8 6,059.6 9.20 J-55 BUTT AB-MOD SAFETY VLV;1,9522 1 t Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°1 Item Des Com (in) 35.0 35.0 0.13 HANGER FMC GEN III HANGER 3.500 GAS LIFT;1,999.0 1,952.2 1,818.8 41.84 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE(LOCKED OUT 2.812 FLAPPER 5/18/12) I I 7,475.8 6,0112 53.79 PBR BAKER PBR w/10'STROKE 3.000 7,491.0 6,020.2 53.92 PACKER BAKER HB RETRIEVABLE PACKER 2.880 SURFACE;31.3-2,e351- 7,532.1 6,044.3 53.80 SBR BAKER SBR 4.437 I I Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection 1 } TUBING Original 4 2.992 7,557.8 7,973.3 6,311.9 9.20 J-55 FL4S Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT;3,972.0 111 7,557.8 6,059.5 53.63 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 7,700.4 6,145.3 52.43 BLAST RINGS BLAST RINGS(OAL=961 2.992 GAS LIFT;5,482.1111 11 7,950.1 6,297.7 52.18 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 GAS LIFT;6,587.4 7,950.6 6,298.1 52.18 PACKER BAKER FB-1 PERMANENT PACKER 2.875 11 7,953.1 6,299.6 52.18 SBE BAKER SEAL BORE EXTENSION 2.937 GAS LIFT;7,423.6IIII 7,965.8 6,307.3 52.18 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,972.5 6,311.5 52.18 SOS BAKER SHEAR OUT SUB 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl PACKER;7,440.1 `g-- Top(91(13) (ftKB) (°) Des Com Run Date ID(in) (� 7,440.1 5,990.0 53.48 PACKER UPPER WEATHERFORD ER PACKER 3/2/2013 1.750 PATCH;7,442.9 'I �� PACKER;7,461.8 7,442.9 5,991.7 53.51 PATCH PATCH,SPACER PIPE,SNAP LATCH ASSEMBLY 3/2/2013 1.750 • 7,461.9 6,002.9 53.67 PACKER LOWER WEATHERFORD ER PACKER 1/8/2013 1.750 Perforations&Slots PBR;7,475.8 Dens Top(TVD) Btm(NShot D) (shotn/f PACKER;7,491.0 ' . Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com S 7,708.0 7,794.0 6,149.9 6,202.3 C-4,C-3,C-2, 5/10/1982 4.0 IPERF M C-1,1E-11 • 7,996.0 8,008.0 6,325.9 6,333.2 A-5,1E-11 2/1/1985 8.0 RPERF Original Pert 5/10/82 SBR;7,532.1 8,028.0 8,056.0 6,345.5 6,362.8 A-4,1E-11 2/1/1985 8.0 RPERF Original Pert 5/10/82 .� 8,061.0 8,076.0 6,365.9 6,375.3 A-4,1E-11 2/1/1985 8.0 RPERF Original Perf 5/10/82 PACKER;7,557.8 Ma riff rel Inserts St INJECTION;7,595.9 i on Top(ND) Valve Latch Port Sine TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sent Type Type (in) (psi) Run Date Com INJECTION;7,662.1 - i' 1,999.0 1,853.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/20/1996 1:00 2 3,971.9 3,330.3 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/20/1996 12:30 5,482.1 4,512.4 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/20/1996 3:30 (PERF;7,7080-7,794.0- I 6,587.4 5,398.6 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/4/1991 4:00 7,423.6 5,980.2 CAMCO MMG-2 11/2 GAS LIFT DMY RK 6 7,595.9 6,082.2 CAMCO KBUG 0.000 0.0 10/8/2016 1 INJ HFCV BK 0.000 0.0 6/3/2009 3:00 7 7,662.1 6,122.0 CAMCO KBUG 1 INJ HFCV BK 0.000 0.0 6/3/2009 1:00 8 7,929.0 6,284.8 CAMCO KBUG 1 INJ HFCV BK 0.000 0.0 6/3/2009 10:00 I Notes:General&Safety INJECTION;7,929.0 ila- End Date Annotation I, 4/4/1991 NOTE:Drilling Rig RKB discrepancy beween 1982 original TBG and 1991 workover TBG SEAL ASSY;7.50.1 9/25/2004 NOTE E-LINE DOCUMENTED MANDREL LEAK @ 7640' PACKER;7,950.6 °1°, 8/25/2010 NOTE:View Schematic w/Alaska Schematic9.0 SBE;7,953.1 - - 1 8/11/2011 NOTE:EL IDENTIFIED LEAK @17452'ELM I NIPPLE;7,965.8 AI SOS;7,972.5 i RPERF;7,996.0-8,008.0- RPERF;8,028.0-8,056.0 RPERF;8,061.0-5076.0-- FISH;8,149.0 ( PRODUCTION;30.5-8,723.0 0 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq(rialaska.gov: AOGCC.InspectorstStalaska.gov phoebe.brooks(Malaska.aov chris.wallacetWalaska.ciov OPERATOR: ConocoPhillips Alaska Inc, FIELD/UNIT/PAD: Kuparuk/KRU/1 E Pad DATE: 02/20/17 OPERATOR REP: Beck/Van Camp AOGCC REP: Chuck Scheve Well 1E-11 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1820510 Type Inj W Tubing 2437 2433 2439 2449 2457 2444 Type Test P Packer TVD 6060 BBL Pump 3.1 IA 1400 3300 3100 3000 2960 2940 Interval 0 Test psi 1515 BBL Return 1.7 OA 210 220 220 220 220 220 Result P Notes: MITIA per Sundry#316-637 Post Patch Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In] Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In] Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In] Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In] Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT KRU 1E-11 02-20-17.xlsx • e ,oF 7.4 0,14, k i,/,�4), THE STATE Alaska Oil and Gas N � of A LAsKA Conservation Commission :�� 1 1 Sr z �� 333 West Seventh Avenue iil GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OSA ;SQ. Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Brent Rogers NSK Well Integrity Supervisor �� 1 MAR �� ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1E-11 Permit to Drill Number: 182-051 Sundry Number: 316-637 Dear Mr. Rogers: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, .._,q_t /(;):te...4‹ Cathy P. oerster Chair DATED this 4 day of January, 2017. RBDMS LA-- JAI 2 6 2017 • S RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 2 2 2016 APPLICATION FOR SUNDRY APPROVALS 0-7-5 1• 41-ti7 20 AAC 25.280 g 1.Type of Request: Abandon PlugPerforations Fracture Stimulate r � Repair Well 170 Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Plug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Other: Tubing patch P- 2. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 182-0510 " 3.Address: Alaska 99510 Stratigraphic r Service 17, P. O. Box 100360,Anchorage, 6.API Number: 50-029-20787-00 " 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require spacing exception? Yes r No 17 KRU 1 E-11 " 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025651 ' Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8754 • 6810 " 8032' 6348' Casing Length Size MD TVD Burst Collapse CONDUCTOR 48' 16 80' 80' SURFACE 2804' 10 3/4 2835' 2476' PRODUCTION 8693' 7 8723' 6790' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7708-7794,7996-8008,8028-8056,8061-8076 . 6150-6202,6326-6333,6346-6363,6366-6375 3 1/2 J-55 7973 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SAFETY VLV=CAMCO TRDP-1A-SSA SAFETY VALVE(LOCKED OUT FLAPPER 5/18/12) MD=1952 TVD=1819" PACKER=BAKER HB RETRIEVABLE PACKER MD=7491 TVD=6020 . PACKER=BAKER FHL RETRIEVABLE PACKER MD=7558 TVD=6060 , 12.Attachments: proposal Summary p WellBore Schematic 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service 17, 14.Estimated Date for 15. Well Status after proposed work: 12/23/16 Commencing Operations: OIL r WIND r vvDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG 17 • GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdow n r Abandoned r 17.I hereby certify that the foregoing is true Contact: Brent Rogers/Kelly Lyons Printed Name Brent Rogers Phone:659-7535 Email: N1617(Cr�conocophillips.com Title: NSK Well Integrity Supervisor 3(4.4 Signature Date: December 19,2016 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: `Ci2 _ -37 Plug Integrity r BOP Test r Mechanical Integrity Test IV Location Clearance r Other: i'4 f- ' 141%4 Post Initial Injection MIT Req'd? Yes No r RBDMS JAN L 6 201/ Spacing Exception Required? Yes r No r✓ Subsequent Form Required: /9 — /1-o if- Approved U P20,....c„pli APPROVEDBYApproved by' COMMISSIONER THE COMMISSION Date: l id, .,„ rc vrt `/ 1� II ,�A`�� Submit Form and Form 10-403 Revised 11/2015 UA p VeceiplicIti{rrjfor 12 months from the date of approval. Attachments in Duplicate • RECEIVED ConocoPhiIIips DFC 2 2 2016 Alaska C P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 December 19, 2016 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 1E-11 (PTD 182-051). The request is for approval to test and replace tubing patch equipment as needed. f Please call Kelly Lyons or myself at 659-7224 or Jan Byrne/Dusty Freeborn at 659- 7126 if you have any questions. Sincerely, I Brent Rogers Well Integrity Supervisor Attachments • S ConocoPhillips Alaska,Inc. Kuparuk Well 1E-11 (PTD 182-051) SUNDRY NOTICE 10-403 TUBING REPAIR 12/19/16 This Sundry is a request for approval to repair ConocoPhillips (CPA) Kuparuk Well 1E-11 (PTD 182-051) by troubleshooting an existing tubing patch and replacing equipment as necessary. On August 20, 2011,the AOGCC was initially notified of suspecte d TxIA communicat jgn. Diagnostics have identified a tubing to IA leak at 7452' which is approximately 40' above the top packer. The plan is to pull the upper patch assembly, test the remaining patch equipment and replace only as needed. If the entire patch needs to be pulled, a plug will be set to_confirm production casing integrity prior to moving forward. REPAIR PLAN Slickline 1) Confirm there is an approved Sundry prior to starting this work. 2) Drift and gauge tubing down to top of patch for pulling @ 7440'. 3) RIH and pull WFT ER packer patch assembly @ 7440'. 4) Set ER test tool in lower patch packer @ 7461'. 5) Perform CMIT TxIA to 3000 psi. Record initial, 15 min, 30 min TIO pressures. 6) If CMIT passes: 1) Pull ER test tool @ same. 2) Have WFT add 1'to the spacer pipe length. 3) Reset Upper ER packer assembly with longer spacer pipe with WFT NEST tool if available. 4) Perform MITIA to 3000 psi. Record initial, 15 min, 30 min TIO pressures. 5) If MITIA passes, give well back to DSO to return to injection. Well will need SW MITIA when thermally stabilized. 6) Troubleshoot if MITIA fails to confirm if upper packer is set. 7) If CMIT fails: 1) Pull ER test tool @ same. 2) Pull lower ER packer. 3) Set WFT Iso-plug with NEST tool @—7515' (middle of full joint below upper packer) NSK Problem Well Supervisor • • 4) Perform CMIT TxIA to 3000 psi. Record initial, 15 min, 30 min TIO pressures. 5) Troubleshoot if CMIT fails. 6) Assuming CMIT passes pull Iso-plug @ same. 7) Reset lower ER packer 1' deeper(mid element to be 7462'). (May need DSL or E-Line for this step) 8) Set ER test tool in lower packer. 9) Perform CMIT TxIA to 3000 psi. Record initial, 15 min, 30 min TIO pressures. 10)Pull ER test tool @ same. 11)Have WFT add 2'to the spacer pipe length. 12)Set new upper ER packer assembly with longer spacer pipe. 13)Perform MITIA to 3000 psi. Record initial, 15 min, 30 min TIO pressures. 14)Troubleshoot any failures. 15)Give well back to DSO to return to injection. Well will need SW MITIA when thermally stabilized. NSK Problem Well Supervisor KUP INJ • 1E-11 ConocaPhiIlips '# _ Well Attributes Max Angle&MD TD d' .... Wellbore API/DWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) AleSka,IOC. canocovHiulps,, 500292078700 KUPARUK RIVER UNIT INJ 54.00 7,500.00 8,754.0 w ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(It) 'Rig Release Date 1E-M10111/2016 11.05:57 AM SSSV:Flapper Locked Out Last WO: 4/4/1991 40.71 5/10/1982 Vesical schematic(actuap Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,032.0 8/4/2014 Rev Reason:GLV C/O pproven 10/11/2016 II Iif Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.060 32.0 80.0 80.0 65.00 H-40 WELDED HANGER;35.0 11167 41 Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread aun.SURFACE 10 3/4 9.950 31 3 2,835 1 2,475.5 45.50 K-55 BTC IN Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 30.5 8,723.0 6,790 3 26.00 K-55 BTC MtiCONDUCTOR,3z.a-so0• .�Tubing Strings Tubing Description String Ma.,,ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...WI(lb/rt) Grade Top Connection IF TUBING WO 1991 1 31/21 2.9921 35.01 7,557.81 6,059.61 9.201 J-55 I BUTT AB-MOD SAFETY VLV,1952.2 ®al Completion Details.: Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 11. 35.0 35.0 0.13 HANGER FMC GEN III HANGER 3.500 GAS LIFT,1,999.0 1 1,952.2 1,818.8 41.84 SAFETY VLV CAMCO TRDP-IA-SSA SAFETY VALVE(LOCKED OUT 2.812 FLAPPER 5/18/12) I 7,475.8 6,011.2 53.79 PBR BAKER PBR w/10'STROKE 3.000 7,491.0 6,020.2 53.92 PACKER BAKER HB RETRIEVABLE PACKER 2.880 SURFACE;31.3-2,835.1--. 7,532.1 6,044.3 53.80 SBR BAKER SBR 4.437 Tubing Description 'String Ma...'ID(in) 'Top(ftKB) -Set Depth(ft..'Set Depth(TVD)(...'Wt(lbmt) (Grade 1 Top Connection TUBING Original 4 2.992 7,557.8 7,973.3 6,311.9 9.20 J-55 FL4S Completion Details Nominal ID Top(ftKB) Top(TVD)(11KB) Top Incl(') Item Des Com (in) GAS LIFT;3,9720 7,557.8 6,059.5 53.63 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 7,700.4 6,145.3 52.43 BLAST RINGS BLAST RINGS(OAL=96') 2.992 GAS LIFT;5,482.1 IF 7,950.1 6,297.7 52.18 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 GAS LIFT,6,587.4 2 7,950.6 6,298.1 52.16 PACKER BAKER FB-1 PERMANENT PACKER 2.875 IlL 7,953.1 6,299.6 52.18 SBE BAKER SEAL BORE EXTENSION 2.937 GAS LIFT;74236 ' 7,965.8 6,307.3 52.18 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,972.5 6,311.5 52.18 SOS BAKER SHEAR OUT SUB 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl PACKER 7440.1 - .0 T Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) `I-y- 7,440.1 5,990.0 53.48 PACKER UPPER WEATHERFORD ER PACKER 3/2/2013 1.750 PATCH 7,442.9 I�R't,.. 1 _ PACKER,7,461.6 7,442.9 5,991.7 53.51 PATCH PATCH,SPACER PIPE,SNAP LATCH ASSEMBLY 3/2/2013 1.750 (N a 7,461.9 6,002.9 53.67 PACKER LOWER WEATHERFORD ER PACKER 1/8/2013 1.750 Perforations&Slots PBR;7,475.8 Li i Shot Dens Top(ND) Btm(ND) (shots/f PACKER;7,461.0 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,708.0 7,794.0 6,149.9 6,202.3 C-4,C-3,C-2, 5/10/1982 4.0 IPERF C-1,1E-11 7,996.0 8,008.0 6,325.9 6,333.2 A-5,1E-11 2/1/1985 8.0 RPERF Onginal Pert5/10/82 SBR;7,532.1 8,028.0 8,056.0 6,345.5 6,362.6 A-4,1E-11 2/1/1985 8.0 RPERF Original Perf 5/10/82 8,061.0 8,076.0 6,365.9 6,375.3 A-4,1E-11 2/1/1985 8.0 RPERF Original Pert 5/10/82 PACKER;7,557.8 "" `" Mandrel Inserts E. st INJECTION;7,595.9 ge.- ati I on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Ser/ Type Type (in) (psi) Run Date Com INJECTION;7,662.1 - 1' 1,999.0 1,853.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/20/1996 1:00 `1 2 3,971.9 3,330.3 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/20/1996 12:30 3 5,482.1 4,512.4 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/20/1996 3:30 IPERF;7,7138.0-7,794 4 6,587.4 5,398.6 CAMCO KBUG 1 GAS LIFT DMY BK - 0.000 0.0 4/4/1991 4:00 _ 5 7,423.6 5,980.2 CAMCO MMG-2 11/2 GAS LIFT DMY RK 0.000 0.0 10/8/2016 II 6 7,595.9 6,082.2 CAMCO KBUG 1 INJ HFCV BK 0.000 0.0 6/3/2009 3:00 I 7 7,662.1 6,122.0 CAMCO KBUG 1 INJ HFCV BK 0.000 0.0 6/3/2009 1:00 8 7,929.0 6,284.8 CAMCO KBUG 1 INJ HFCV BK 0.000 0.0 6/3/2009 10:00 Notes:General 8'Safety INJECTION;7,929.0 r End Date Annotation 4/4/1991 NOTE:Drilling Rig RKB discrepancy beween 1982 original TBG and 1991 workover TBG SEAL ASSY;7,950.1 •-• 9/25/2004 NOTE:E-LINE DOCUMENTED MANDREL LEAK©7640' PACKER,7,950.6 6/25/2010 NOTE:View Schematic w/Alaska Schematic9.0 SBE;7,953.1 V. 8/11/2011 NOTE:E/L IDENTIFIED LEAK©7452'ELM NIPPLE,7965.8 I SOS;7.972.5 -- RPERF;7,996.0-8,008 0--. 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C ( kn ,C V N 4 C r0 GJ (o OM a cta Q H a` a Q • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Thursday, September 08, 2016 3:16 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: Report of IA pressure anomaly KRU WAG injector 1E-11 (PTD 182-051)9-4-16 update 9-8-16 Chris, The MITIA on 1E-11 was performed yesterday and it failed based on ConocoPhillips' more stringent pass/fail criteria. The test was bumped up several times and with each successive pressuring up,the numbers got tighter, but still could not pass a test. Based on the way the pressures behaved during the test,we believe at this point that the failure is due to gas entrainment in the annulus fluid. The injector had been on gas injection for several months earlier this year during the winter. There may have been a slow gas leak which went undetected. There was gas in the packoff void and we had to torque several tubing lock down screws in order to achieve passing packoff tests yesterday. So that may have been the point of communication which allowed the gas to migrate over to the annulus. Plan forward is to circulate out the annulus fluid with fresh fluid and repeat the MITIA while offline. If the MITIA passes,we will return the well to water injection for a 30 day monitor. If the MITIA continues to fail,we will proceed with well intervention diagnostics as needed with appropriate paperwork when a path forward for return to injection is established. A followup email will be provided at the conclusion of the monitor if the MITIA passes and we return the well to injection. Please let me know if you disagree with the path forward. Kelly Lyons/Brent Rogers < ° Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Mobile Phone(907)943-0170 SCANNED JAN 2 . ?Cid. r• • SK Problem Well Supv Sent:Sun..,, eptember 04, 2016 3:54 PM To:Wallace, Chris IOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.T - enden • conoco.hilli.s.com> Subject: Report of IA pressure an. ••aly KRU WAG injector 1E-11 (PTD 182-051)9-4-16 Chris, KRU WAG injector 1E-11(PTD 182-051) is experien '•_: an IA pressure anomaly while on water injection with repeated recent bleeds needed when either nearing its DNE or to - ablish a sufficient dP across the tubing and annulus. The most recent bleed occurred yesterday. While thermal fluctua '•ns have played a role in the well's behavior,a closer review of the TIO plot indicates that there may also be a very slow ' 'dercurrent TxIA communication issue as well. Plan forward is to obtain an MITIA and packoff tests with DHD. I •e MITIA fails,the well will be shut in and freeze protected as soon as possible. If the MITIA passes,we will then monit. he well for 30 days while on water injection. A followup email will be provided at the conclusion of the monitor. Plea - let me know if you disagree with the plan. Attached are the most recent 90 day TIO plot and schematic. N„N • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Sunday, September 04, 2016 3:54 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of IA pressure anomaly KRU WAG injector 1E-11 (PTD 182-051) 9-4-16 Attachments: 1E-11 schematic.pdf; 1E-11 90 day TIO 9-4-16.PNG Chris, KRU WAG injector 1E-11 (PTD 182-051) is experiencing an IA pressure anomaly while on water injection with repeated recent bleeds needed when either nearing its DNE or to establish a sufficient dP across the tubing and annulus. The most recent bleed occurred yesterday. While thermal fluctuations have played a role in the well's behavior, a closer review of the TIO plot indicates that there may also be a very slow undercurrent TxIA communication issue as well. Plan forward is to obtain an MITIA and packoff tests with DHD. If the MITIA fails,the well will be shut in and freeze protected as soon as possible. If the MITIA passes, we will then monitor the well for 30 days while on water injection. A followup email will be provided at the conclusion of the monitor. Please let me know if you disagree with the plan. Attached are the most recent 90 day TIO plot and schematic. Kelly Lyons/ Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907) 943-0170 SCANNED JAN 2 7 2017 W • '..-- > > r.• ':.-. illU 1Y Ll (i) N N U) tn LI EC EC EC a a Ce V1 W W W w W W cnW all se- O u du . cs sal Ns ^O01 01 IA- '''" O o` w - _ N W O d O 43 0 0 n t3 GO b ``f - co u!) al Y 4L at 0 yr 0 0 0 W Ct. o d r-cZ 0 o N ci N .r r N W IC IC u'r ti1 1,11 0 0 0 0 0 CA dl L'! `n a r n 4:1 O I J J W LLl W W W LL1 yW O el( NI 0,.- ' 0 Bap O O O O .- .., .- .- .- CN 4J r. CC, Ill 41 1Ll 1 1 I 1 I I 1 I I a - sr 1n cn co co - o •-,- ar ar vs /` u-) co Q - Q1 4S cD tD ID < < 110 co LI%. ;cn c o :CI CD IC go C L . ._, /I 7 i N RI 4.1 C cD _N Q - C '7 13: r r r o o 01 Ni' r - LL • t0 -ch, LILU 1C> ,_ t0 - 1 1 t 5 a a a I I so 1. 41 II ! ' I � PJ O o o O o o OD LI 8 N R N R L Q Q O y1 O yr O yJ OdIA ana m- r'0 isd en ow` WELL LOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. April 19, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED D14/24/204 ATA LOGGED K.BENDER APR' 29 2013 AA�..sv C y7 RE: Injection Profile : 1E-11 Run Date: 10/18/2015 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-11 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-20787-00 Injection Profile Log 1 Color Log 50-029-20787-00 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. SNE Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: m/itga-fruL,c/i) o_e4ceat Imac. ect Well History File Cover ~e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. L ~c~ {~_~ Well History File Identifier Organizing {do,~) RESCAN [] Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: DIGITAL DATA OVERSIZED (Scannable) [] Diskettes, No, [] Maps: [] Other, No/Type [] Other items scannable by large scanner OVERSIZED (Non-Scannable) BEVERLY ROBIN VINCENT~MARIA WINDY Project Proofing BY; ~__.~V~ER~ ROBIN VINCENT SHERYL MARIA WINDY Scanning Preparation x 30 = BY: BEVERLY ROBIN VINCENT SHERYL~'~INDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: BEVERL~ VINCENT SHERYL MARIA WINDY Stage 2 BY~ (SCANNING I$ COMPLETE AT THIS POINT UNLE~ SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALIT~ , GRAYSCALE OR COLOR IMAGES ) [] Logs of vadous kinds [] Other YES NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: / YES NO BEVERLY ROBIN VINCE~'~--~ARIA WINDY DATE~,~, ? ~ y/{ ~///~{~ ,.~/.~ III IIIIIIIIIII II III ReScanned (individual page [special a~el~tion] ~calming completed) RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: /S/ Quality Checked (do.e) 12110/02Rev3NOTScanned.wpd MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg .,---7-" 4(3b t 5 DATE: Tuesday,April 30,2013 P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IE-11 FROM: Jeff Turkington KUPARUK RIV UNIT 1E-1I Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Well Name KUPARUK RIV UNIT 1E-I1 API Well Number 50-029-20787-00-00 Inspector Name: Jeff Turkington Permit Number: 182-051-0 Inspection Date: 3/23/2013 Insp Num: mitJAT130324071550 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well f 1E-11 - Type Inj w TVD 6060 IA 1120 3000 2780 2740 1 PTD 1820510 Type Testi P Test psi OA , 'I� Interval (describe notes) g1 2220 I 1515 30 30 Other descnbein notes I I ' �P/F Pa" I Tubin MO zzzo 2220 2220 I I L_ Notes: Test required by sundry#311-286 due to patch at 7443'.Operator retested due to CPAI requirement not to have more than 5%loss in first 15 min.or half that in the next 15 min. SCANNED FEB 2 5 2014 Tuesday,April 30,2013 Page 1 of 1 STATE OF ALASKA AOKA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell 17 Plug Perforations r Perforate r Other r Set tubing patch Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program r Operat.Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. _ Development r Exploratory r — 182-051 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-20787-00 , 7.Property Designation(Lease Number): ,. 8.Well Name and Number: ADL0025651 1E-11 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 1,e- 11. Present Well Condition Summary: Total Depth measured 8754 feet Plugs(measured) None true vertical 6810 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 7440,7443,7462,7491,7558,7951 true vertical 0 feet (true vertical) 5990, 5992,6003,6020,6060,6298 Casing Length Size MD TVD Burst Collapse CONDUCTOR 48 16 80 80 SURFACE 2804 10.75 2835 2475 PRODUCTION 8693 7 8723 6790 RECEIVED SCANNEo AUG 0J. 2013 APR 2 3 2013 Perforation depth: Measured depth: 7708'-7794',7996'-8076' True Vertical Depth: 6150'-6202',6326-6375' AOGCC Tubing(size,grade, MD,and TVD) 3.5,J-55,7973 MD,6311 TVD Packers&SSSV(type,MD,and ND) PACKER-UPPER WEATHERFORD ER PACKER @ 7440 MD and 5990 ND PATCH-PATCH,SPACER PIPE,SNAP LATCH ASSEMBLY @ 7443 MD and 5992 ND PACKER-LOWER WEATHERFORD ER PACKER @ 7462 MD and 6003 ND PACKER-BAKER HB RETRIEVABLE PACKER @ 7491 MD and 6020 ND PACKER-BAKER FHL RETRIEVABLE PACKER @ 7558 MD and 6060 ND PACKER-BAKER FB-1 PERMANENT PACKER @ 7951 MD and 6298 ND 12.Stimulation or cement squeeze summary: NA Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-WI- Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations x '/ GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 311-286 Contact Kelly Lyons/Brent Roque) Email n1617@conocophillips.com Printed Name ,ceJy{ions ,.,.-/ Title Problem Wells Supervisor Signature .. ,,' �j221/>."~ Phone:659-7224 Date 11_1 1, / e Form 10-404 Revised 'F072012 ,, r RBDMS APR 2 3 201 Submit Original Only • • RECEIVED lov ConocoPhillips APR 2 3 2013 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 19, 2013 Mr. Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Seamount: Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 1E-11 (PTD 182-051) for a retrievable patch set in the tubing above the packer. Please call Brent Rogers or myself @ 659-7224 if you have any questions. Sincerely (. Kelly Lyon' ConocoPhillips Problem Wells Supervisor Enclosures • 1E-11 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/11/11 LEAK DETECT LOG AND MIT-24 CALIPER LOG. SUSPECTED LEAK ZONE FOUND AT 7452'WHILE LRS PUMPING 0.16 BPM DIESEL DOWN IA @ 2400 PSI. LOG MIT-24 CALIPER FROM 7973' TO SURFACE WITH APPROX 10' MISSING DATA ABOVE GLV#1 DUE TO TOOL STUCK AT SSSV, HAD TO CLOSE ARMS TO GO DOWN. 01/08/13 PERFORM SETTING WEATHERFORD ERP WITH BAKER#10 SETTING TOOL. CORRELATED ERP SETTING TO TUBING TALLY AS PER COMPANY REP REQUEST. SET ERP MID ELEMENT @ 7461'. ***READY FOR SLICKLINE*** 03/01/13 SET ER TEST TOOL IN PKR @ 7458' RKB. CMIT 2500 PSI, PASSED. READY FOR PATCH. IN PROGRESS. ***PERFROM CMIT, INITAL T/I/0=1400/1450/OPRESSURE TO 2500, T/I/O=2500/2560/0, AFTER 15 MIN., T/I/0=2400/2480/0, AFTER 30 MINS, T/I/0=2380/2450/0 PASS, BLEED PRESSURE BACK TO 1400,*** 03/02/13 SET WEATHERFORD UPPER ER PATCH ASS'Y(18.96' OAL). SET ER TEST TOOL @ 7913' SLM. MIT TBG 2500 PSI, PASSED. ATTEMPTED MIT IA, FAILED. PULLED TEST TOOL. IN PROGRESS. **MITT TBG TO 2500, INITIAL T/I/0=1400/1400/0, PRESSURE TBG TO 2500, T/I/0=2500/1450/0, AFTER 15 MINS, T/I/0=2450/1450/0, AFTER 30 MINS, T/1/0=2450/1450/0 PASS, BLEED TBG TO 2000 PSI, RIG LRS TO IA, PT, INITIAL T/I/0= 2100/1450/0, PRESSURE TO 2500 ON IA, AFTER 15 MINS, IA LOST 150 PSI, TBG CAME UP TO 2300 PSI, FAIL, CONFER w/CWG, POOH, OOH w/TEST TOOL, BLEED IA TO 1450** 03/03/13 MIT IA 2500 PSI, PASSED. COMPLETE. ***MITIA pass: preTI0=1350/1578/0, initial T10=1350/2500/0, 15min=1350/2407/0, 30min=1350/2371/0*** 03/23/13 (SW) MIT-IA PASSED to 3000 psi. (Witnessed by Chuck Scheve). IA FL= NS. Initial T/I/0= 2220/1120/30 LRS rigged to IA. Pressured IA to 3000 psi with 2.7 bbls diesel. T/I/0= 2220/3000/30 15 min-2220/2780/30 30 min-2220/2740/30. PASSED STATE TEST. Re-MIT-IA PASSED to 3000 psi. (Done to meet CPAI criteria) IA FL @ SF. Initial T/I/O/00= 2220/2740/30 Pressured IA to 3000 psi with 0.2 bbls diesel. T/I/O/00= 2220/3000/30 15 min-2220/2870/30 30 min-2220/2820/30 Bled back IA to 630 psi. Final T/I/0= 2220/630/30 Summary Set 22'Weatherford retrievable tubing patch from 7440'-7462'. State witnessed MITIA passed demonstrating integrity. S • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 October 26, RECENED lOV 02NO11 Commissioner Dan Seamount Alaska Oil and Gas Commission Alaska OH & Gas Cons. Commission 333 West 7 Avenue, Suite 100 PYYwi+{'IU[ r�'y Anchorage, AK 99501 1-C33.— 05 Y�� 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 9/11 and, 9/12, 2011. The corrosion inhibitor /sealant was pumped 10/15, 10/16, 10/17 and, 10/18, 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, _ yy Fr 011 / l it ' 1. �rG��✓� ' Martin Walters • ConocoPhillips Well Integrity Projects Supervisor 0 ! ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 10/26111 1A,1B,1C,1D, 1E & 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 -22 50029221270000 1910030 SF N/A 18" N/A 2.55 10/18/2011 _ WSW -01 50029205370000 1801400 20" N/A 20" N/A 2.5 10/16/2011 WSW -02 50029208120000 1821370 2'10" N/A 2'10" N/A 6 10/16/2011 WSW -03 50029208170000 1821420 12" 1.00 20" 09/11/2011 4.25 10/16/2011 WSW -07 50029208610000 1821880 SF N/A 19" N/A 1 10/17/2011 1C -170 50029231540000 2030780 19'3" 1.20 10" 09/11/2011 18.74 10/15/2011 1C -174 50029231400000 2030270 7' 1.00 8" 09/11/2011 14.8 10/15/2011 1C -190 50029231360000 2030030 9'4" 1.50 8" 09/11/2011 _ 15.2 10/16/2011 10-08 50029220266000 1770530 52" 1.20 6" 5/28/2011 3.8 10/15/2011 1D-12 50029229480000 1990840 18" N/A 18" N/A 3.4 , 10/15/2011 1D -41 50029232880000 2051880 16" N/A 16" N/A 3.55 10/15/2011 1D-123 50029229140000 1981700 11'5" 2.30 5" 09/12/2011 4.4 , 10/15/2011 �j 1E -11 50029207870000 1820510 22 N/A 15" N/A 1.2 10/17/2011 I / _ 1Y -09 50029209350000 , 1830520 7' _ 2.00 5" 09/12/2011 1.7 10/18/2011 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 24, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT) /Leak Detect Log: 1E- 11 Run Date: 8/11/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1E- 11 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 20787 -00 q SigS PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: Al- " 'tt 1 Signed: it Git-1 l got 1)s • • S: IMF E F , SEAN PARNELL, GOVERNOR ALASKA. OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COl1'I1IIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Kelly Lyons Problem Wells Supervisor n5 t ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E-11 Sundry Number: 311 -286 Dear Ms. Lyons: %VINO SEP 2 3 2011 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, a Daniel T. Seamount, Jr. %d Chair DATED this day of September, 2011. Encl. • STATE OF ALASKA •ti~ te ' , 1( CE �i ED ALASKA, AND GAS CONSERVATION COMMI SI B SEP 2 0 2011 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Alaska Oil & Gas Cons. Con-mission 1 . Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell r . Change Appp 4 r Suspend r Plug Perforations r Perforate r Pull Tubing r Time Extenion r Operational Shutdow n r Re -enter Susp. Well r Stimulate A fter casing g r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 182 -051 • 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 20787 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r 1E - • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0025651 • Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8754 • 6810 Casing Length Size MD TVD Burst Collapse CONDUCTOR 48 16 80' 80' SURFACE 2804 13 2835' 2475' PRODUCTION 8693 7 8723' 6790' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7708' 7794', 7996' - 8076' 6150' - 6202', 6326 3.5 J - 7973 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER HB RETRIEVABLE PACKER MD= 7491 TVD= 6020 PACKER - BAKER FHL RETRIEVABLE PACKER MD= 7558 TVD= 6060 PACKER - BAKER FB -1 PERMANENT PACKER MD= 7951 TVD= 6298 No SSSV 12. Attachments: Description Summary of Proposal p 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service ri 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 9/26/2011 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r . Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true andd wrreef to the best of my knowledge. Contact: Brent Rogers /Kelly Lyons Printed Name .yOnS .. Title: Problem Wells Supervisor Signature f ' � ' Phone: 659 -7224 Date 09/18/11 Commission Use Only _ Sundry Number: 5, (-3810 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test P Location Clearance r Other: Subsequent Form Required: /0 °' 1 /0 1. i . 4 APPROVED BY Approved by: / COMMISSIONER THE COMMISSION Date: qii...2.,t1 �zl�� F A I orm 10 -403 Revised S SEP 2 220' , y ' 1G1NAL Submit in Duplicate a 11 et ( ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 September 18, 2011 RECENED aEP 2 0 ?P Mr. Dan Seamount Alaska Oil & Gas Cons. Commission Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Mr.Seamount, I i Enclosed please find the 10 -403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 1E -11 (PTD 182 -051). The request is for approval to patch a tubing leak above the top packer. Please call Brent Rogers or myself at 659 -7224 or M J Loveland / Martin Walters at 659- 7043 if you have any questions. Sincere ; Kelly Lyo Problem Wells Supervisor Attachments • • ConocoPhillips Alaska, Inc. Kuparuk Well 1E -11 (PTD 182 -051) SUNDRY NOTICE 10 -403 TUBING REPAIR 09/18/11 This Sundry is a request for approval to repair ConocoPhillips (CPA) Kuparuk Well 1E -11 (PTD 182 -051) with a tubing patch. On August 20, 2011, the AOGCC was initially notified of suspected TxIA communication. Diagnostics have identified a tubing to IA leak at 7452' which is approximately 40' above the top packer. The plan is to set a retrievable patch over the leak , point, conduct an MITIA, and return the well to normal WAG injection. REPAIR PLAN 1. Set 20' 3.5" retrievable patch over the leak at 7452'. 2. MIT as per AOGCC requirements (0.25 x TVD to packer). 3. Submit 10 -404 post- repair. NSK Problem Well Supervisor • • WELL LOG TRANSMITTAL PROAcnvE DiAgnosric SERVICES, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 , F.. r ` ' . , AUG (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : RECEIVED ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road AUG 19 2011 Suite C Anchorage, AK 99518 OW & Gas Cons. Commissbn Fax: (907) 245 -8952 Anchorage 1) Caliper Report 13- Aug -11 1 C-10 1 Report / CD 50- 029- 20865 -00 2) Caliper Report 11- Aug-11 1 E -11 1 Report / CD 50- 029 - 20787 -00 l Signed : t Date : �`4 ?•AS ( Print Name: Vd-0 CS V, t c� PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 - 8951 FAx: (907)245 - 8952 E -MAIL : PDSANCHORAGEC Th EMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives\ Distdhution\ TransmittalSheets \ConocoPhillips_Transmit.docx 1 • • 1 - Multi- Finger Caliper Log Results Summary ' Company: Conoco Phillips Alaska, Inc. Well: 1E -11 P Log Date: August 11, 2011 Field: Kuparuk I Log No.: 10258427 ZX70 State: Alaska AP Run No.: 1 API No.: 50- 029 - 20787 -00 Pipet Desc.: 3.5 " 9.2 Ib. J -55 BUTT AB -MOD Top Log Intvll.: Surface Pipet Use: Tubing Bot. Log Intvll.: 7,971 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage COMMENTS : 1 This caliper log is correlated to the well schematic dated April 16, 2011. This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage U during operations to detect a suspected hole. An LDL run immediately before the caliper indicated a suspected leak at 7,452'. The caliper recordings in the vicinity of the suspected leak interval do not indicate any significant internal corrosive or mechanical damage. A 3 -D log plot across the area of the suspected hole is included in this report. I The caliper recordings indicate the 3.5" tubing appears to be in good to poor condition, with a maximum wall penetration of 46% recorded in joint 246 at 7,713'. Additional wall penetrations ranging from 20% to 40% are I recorded in 113 of 268 joints logged. Recorded damage appears in the forms of shallow apparent erosion and intermittent isolated pitting. Cross - sectional wall loss of 17% and 16% is recorded in areas of apparent shallow erosion at 1,922' and at 1,974' respectively. Light deposits restrict the I.D. to 2.67" at 7,657'. I During logging operations the caliper became lodged in GLM 1 and was unable to be pulled free. The HES engineer closed the fingers at 2,004' to free the tool and reopened the caliper fingers at 1,984; just below the SSS V, resulting in a momentary loss of coverage within this interval. 1 The summary report is an interpretation of data provided by Halliburton Well Services. 3.5" TUBING - MAXIMUM RECORDED WALL PENETRATIONS: 1 Isolated Pitting ( 46 %) Jt. 246 @ 7,713 Ft. (MD) Isolated Pitting ( 38 %) Jt. 252.3 @ 7,948 Ft. (MD) I I solated Pitting ( 37%) Jt. 252 @ 7,891 Ft. (MD) Isolated Pitting ( 35 %) Jt. 249 @ 7,793 Ft. (MD) Isolated Pitting (33 %) Jt. 248 @ 7,773 Ft. (MD) 1 3.5" TUBING - MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: Apparent Erosion ( 17 %) Jt. 61 @ 1,922 Ft. (MD) I Apparent Erosion ( 16%) Jt. 62.3 @ Jt. 43 @ 1,974 Ft. (MD) Apparent Erosion (15 %j 1,345 Ft. (MD) Apparent Erosion ( 15 %) Jt. 103 @ 3,236 Ft. (MD) Apparent Erosion ( 15 %) Jt. 80 @ 2,514 Ft. (MD) 1 ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS©rnemoryiog.com 1 Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 i l gi__ d 1 • 1 1 3.5" TUBING - MAXIMUM RECORDED ID RESTRICTIONS: Deposits Minimum I.D. = 2.67" Jt. 19 @ 7,657 Ft. (MD) 1 Deposits Minimum I.D. = 2.68" Jt. 19 @ 7,618 Ft. (MD) No other significant I.D. restrictions are recorded throughout the tubing logged. 1 1 Mandrel Orientation 1E - ConocoPhillips Alaska, Inc. Kuparuk August 11, 2011 I Joint No. Tool Deviation Mandrel No. Latch Orientation - 63.1 43 1 (GLM) 1:00 127.1 41 2 12:30 1 176.1 37 3 3:30 212.1 42 4 4:00 239.2 54 5 1:30 1 242.1 244.1 54 1 (Inj) 2 3:00 53 1:00 255.2 50 3 10:00 1 1 1 1 1 1 1 Field Engineer: J. Conrad Analyst: C. Lucasan Witness: B. Boehme I ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS @memorylog.com 1 Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 1 • • I 16:3S PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1E -11 Date : August 11, 2011 1 Description : Details of Caliper Recordings Across The Location of A Suspected Mole Comments Depth Max. Penetration Maximum I.D. 3-0 Log Image Map �4F�Ili 1ft:175ft 0 % 100 2.5 inches 3.5 0° 0° 90° 180° 270° 0° Minimum I.D. I I 2.5 inches 3.5 I i Nominal I.D. 2.5 inches 3.5 Jt 239 1 ■■■!0■■■ ::-.,:, ,-:: , - 1 7410 1 l 111 IIII .11111.1111Wil __ "Ill 1111111111111,111111 Pup Jt 239.1 ■ ■ ■ ■LE�-. 7420 ••• ■[` —•� ` _ I ____:�___7� GLM 5 - �m11��a i•MM�i�•■ - A I 7430 - - -- .�� ---- Pup Jt 239.2 ■ ■■ ■mom in . : t .` ■it�■ ■■ _ I 7440 — Lt iu ■■■ ..� L■ ■■ _ ; ■ ■ ■ ■Etii■ ■■ r = I Jt 240 7450 ■■ ■■��I11■■ ' ■ ■ ■ ■I�� Across The Area E`� M. ■ ■<EL of Suspected ■■■ ■ Leak 1111111111111 MN 7460 1111111111111111 1 11111111111111• [ _; IM - ■ s_� ■■■M Iffinlabliatil Pup Jt 240.1 7470 ■ ■ ■■ ■ ■■ ■PAR — ' i I Pup Jt 240.2 .� .1•• I ■■ ■■C V1 - ■■■■N 11■ ■■N 1 ■ ■ ■itE11■ ■ ■■ PBR 7480 111111111:11MiniMMEN matt!■■■ m ■mmEr� ■ ■ ■ ■ . IMINIIIIIILTIIIIIMIMI ■ _ Packer 7490 - - , ---- II ■ _ ■■■■■'I■■ . - Pup – MINN iI■ ■ 1 ■ 1 . • 1 Correlation of Recorded Damage to Borehole Profile ■ Pipe 1 3.5 in (47.4' - 7971.0 Well: 1 E -11 I Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: August 11, 2011 1 1 ■ Approx. Tool Deviation ■ Approx. Borehole Profile I 1 50 J a 25 790 I - 50 __= 1558 1 GI .M 1 , - — 75 2351 100 3117 I GI M 2 E 125 3880 • Z c 0 150 4648 a, < 0 I GLM 3 5421 • 1 200 - 6189 GLM 4 1 225 6958 GLM 5 Al AN 250 7820 I 252.8 7971 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) 1 Bottom of Survey = 252.8 1 1 • 1 ® S Minimum Diameter Profile 1 Well: 1E -11 Survey Date: August 11, 2011 I Field: Kuparuk Tool: UW MFC 24 Ext No. Company: ConocoPhillips Alaska, Inc. Tool Size: 10000429 (HAL) Country: USA Tubing I.D.: 1.69 inches 2.992 inches 1 Minimum Measured Diameters (In.) 1.69 1.89 2.09 2.29 2.49 2.69 2.89 0.1 13 1 20 27 34 T . 41 I ae 1 55 _F,, 62 I 65 I. 72 I ,. 79 , 86 i I 93 100 I 107 i_ , 114 I II r a. 121 127 1 E i I 7 134 Z I C 141 I . 148 !_ 155 I' 162 I. 1 169 176 182 189 I 196 203 210 216 223 230 237 ( • 1 240 241 243 _ 111 249 — 252 1 1 1 0 0 1 PDS Report Overview C.—WS Body Region Analysis I Well: 1E-11 Survey Date: August 11, 2011 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 10000429 (HAL) I Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.2 ppf J -55 BUTT A13- MOD Analyst: C. Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. I 3.5 in. 9.2 ppf J -55 BUTT AB- MOD 2.992 in. 3.5 in. 6.0 in. 6.0 in. 1 Penetration(% wall) Damage Profile (% wall) 200 ---- Penetration body Metal loss body I 150 0 50 100 II mom 100 50 — '11.11111.- Ill - - A 49 1 0 GI_M 1 0 to 20 to 40 to over 20% 40% 85% 85% I Number of joints analysed (total = 268) 154 113 1 0 97 I GLM 2 - Damage Configuration ( body ) 14 - 200 150 GLM 3 100 II 19 A 50 GLM 4 — 111 0 Isolated General Line Other Hole/ — - _ Pitting Corrosion Corrosion Damage Pos. Hole GLM 5 INN 4 241 11111 Number of joints damaged (total = 262) Ni I 8 Bottom 88 0 0 174 0 of Survey = 252.8 1 1 1 1 • • I PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in. 9.2 ppf J -55 BUTT AB- MOD Well: 1 E -11 I Body Wall: 0.254 in. Field: Kuparuk Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. Country: USA Survey Date: August 11, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 0.1 47 0.04 0.04 17 8 3.00 Pup Shallow Apparent Erosion. i 1 50 _ 0 0.04 16 5 2.97 Shallow Apparent Erosion. ■ 1.1 81 0.04 0.04 16 7 2.97 Pup Shallow Apparent Erosion. 1 2 83 0.03 0.04 16 6 2.97 Shallow Apparent Erosion. II I 3 114 0.04 0.05 19 9 2.98 Shallow Apparent Erosion. 4 144 0 0.04 16 5 2.96 Shallow Apparent Erosion. 1 5 173 0.05 0.06 23 11 3.00 Apparent Erosion. 6 205 0.03 0.05 21 8 2.98 Apparent Erosion. 1 I 7 235 0.03 0.04 17 6 2.98 Shallow Apparent Erosion. r, 8 265 0.04 0.04 17 7 2.96 Shallow Apparent Erosion. g 9 295 0.06 0.06 24 13 3.01 Apparent Erosion. 10 325 0.06 0.07 26 14 3.00 Apparent Erosion. I 1 1 354 0.04 0.05 19 8 2.96 Shallow Apparent Erosion. i 12 385 0.04 0.05 19 9 2.98 Shallow Apparent Erosion. i 13 416 0.04 0.04 16 9 2.99 Shallow Apparent Erosion. 14 448 0.05 0.05 21 12 2.99 Apparent Erosion. 15 480 0.04 0.04 16 8 2.98 Shallow Apparent Erosion. 1 I 16 510 0.04 0.06 23 11 3.00 Apparent Erosion. 17 541 0.04 0.05 21 10 3.00 Apparent Erosion. 18 572 0.04 0.04 17 8 2.98 Shallow Apparent Erosion. 1 19 603 0.04 0.05 19 7 2.99 Shallow Apparent Erosion. 1 I 20 634 0.04 0.04 17 8 2.99 Shallow Apparent Erosion. i 21 665 0.04 0.04 17 2.99 Shallow Apparent Erosion. t 22 695 0.04 0.05 19 8 2.99 Shallow Apparent Erosion. I 23 727 0.05 0.05 21 9 2.98 Apparent Erosion. I 24 758 0.04 0.05 19 9 2.98 Shallow Apparent Erosion. 25 790 0.04 0.05 21 9 2.99 Apparent Erosion. 26 820 0.04 0.06 23 9 2.98 Apparent Erosion. 27 850 0.07 0.07 28 14 3.01 Apparent Erosion. I 28 880 0.04 0.05 19 10 3.00 Shallow Apparent Erosion. 29 910 0.05 0.06 23 12 3.00 Apparent Erosion. 30 942 0.04 0.05 19 10 2.99 Shallow Apparent Erosion. 31 972 0.04 0.05 19 11 2.99 Shallow Apparent Erosion. 32 1003 0.04 0.05 21 10 3.00 Apparent Erosion. I 33 1033 0.05 0.06 24 13 3.00 Apparent Erosion. 34 1065 0.04 0.06 23 12 3.00 Apparent Erosion. 35 1095 0.04 0.04 17 7 2.96 Shallow Apparent Erosion. 1 36 1126 0.03 0.04 16 7 2.99 Shallow Apparent Erosion. 1 I 37 1157 0.04 0.04 17 8 2.98 Shallow Apparent Erosion. 38 1187 0.05 0.05 19 8 2.97 Shallow Apparent Erosion. i 39 1219 0.05 0.06 24 13 3.00 Apparent Erosion. 40 1249 0.05 0.06 23 11 3.00 Apparent Erosion. I 41 1280 0.04 0.05 21 10 2.99 Apparent Erosion. 42 1312 0.04 0.05 19 11 2.99 Shallow Apparent Erosion. 43 1343 0.05 0.07 26 15 3.00 Apparent Erosion. 44 1374 0.03 0.03 12 4 2.96 Shallow Apparent Erosion. ■ 45 1404 0.04 0.05 19 9 2.99 Shallow Apparent Erosion. I 46 1434 0.04 0.05 19 8 2.99 Shallow Apparent Erosion. i 47 1465 0.05 0.06 23 14 3.02 Apparent Erosion. 48 1496 0.05 0.05 21 13 3.01 Apparent Erosion. I "'Penetration Body Metal Loss Body Page 1 1 1 1 0 • PDS REPORT JOINT TABULATION SHEET I . Pipe: 3.5 in. 9.2 ppf J -55 BU IT AB- MOD Well: 1 E -11 Body Wall: 0.254 in. Field: Kuparuk I Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. Country: USA .Survey Date: August 11, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 49 1528 0.04 , 0.04 14 6 2.96 Shallow Apparent Erosion. 50 1558 0.04 0.04 17 11 3.00 Shallow Apparent Erosion. 51 1589 0.05 0.05 21 11 2.99 Apparent Erosion. 52 1617 0.03 0.04 17 10 2.99 Shallow Apparent Erosion. I 53 1649 0.04 0.04 17 9 2.98 Shallow Apparent Erosion. 54 1680 0.03 0.04 14 7 2.96 Shallow Apparent Erosion. 55 1711 0.04 0.05 21 11 2.99 Apparent Erosion. 56 1741 0 0.04 16 6 2.97 Shallow Apparent Erosion. 1 I 57 1772 0.05 0.06 24 13 2.89 Apparent Erosion. Lt. Deposits. 58 1803 0.04 0.05 21 11 2.96 Apparent Erosion. 59 1834 0.04 0.04 16 9 2.98 Shallow Apparent Erosion. 60 1864 0.04 0.06 23 14 3.00 Apparent Erosion. I 61 1896 0.06 0.07 26 17 3.02 Apparent Erosion. 62 1928 0.05 0.06 24 14 3.00 Apparent Erosion. 62.1 1958 0.04 0.04 14 9 2.97 Pup Shallow Apparent Erosion. 62.2 1961 0 0 0 0 2.81 Camco TRDP -1 A SSA SSSV 1 62.3 1971 0.05 0.06 23 16 2.99 Pup Apparent Erosion. I 63 1976 (1.05 0.05 21 12 2.99 Caliper Fingers Closed 63.1 2006 0 0 0 0 2.95 GLM 1 (Latch @ 1:00) 1 64 2013 0.06 0.07 28 1 :1 2.99 Apparent Erosion. 65 2045 0.05 0.06 23 8 2.97 Apparent Erosion. i I 66 2073 0.04 0.06 23 10 , 2.98 Apparent Erosion. 67 2105 0.06 0.07 26 13 2.99 Apparent Erosion. 68 2136 0.06 0.07 26 13 2.99 Apparent Erosion. 69 2167 0.05 0.06 23 11 2.99 Apparent Erosion. 70 2198 (1.05 0.07 28 9 2.95 Apparent Erosion. 71 2227 0.05 0.06 24 11 2.99 Apparent Erosion. 72 2259 0.04 0.05 19 7 2.97 Shallow Apparent Erosion. 1 73 2291 0.04 0.05 21 8 2.97 Apparent Erosion. 1 74 2320 0.04 0.05 21 10 2.98 Apparent Erosion. I 75 2351 0.04 0.06 23 8 2.81 Apparent Erosion. Lt. Deposits. i 76 2382 0.05 0.07 26 11 2.99 Apparent Erosion. 77 2412 0.04 0.04 17 7 2.97 Shallow Apparent Erosion. 1 78 2443 0.13 0.05 19 9 2.97 Shallow Apparent Erosion. I 79 2473 0.05 0.05 21 10 2.97 Apparent Erosion. 80 2505 0.06 0.06 24 15 3.00 Apparent Erosion. 81 2535 0.04 0.07 26 14 2.99 Apparent Erosion. 82 2566 0 0.04 17 7 2.96 Shallow Apparent Erosion. i I 83 2597 0.05 0.06 23 13 2.99 Apparent Erosion. 84 2627 0 0.04 16 7 2.95 Shallow Pitting. i 85 2656 0.04 0.04 17 9 2.96 Shallow Apparent Erosion. 86 2686 0.04 0.05 21 12 2.99 Apparent Erosion. I 87 2717 0.04 0.04 17 11 2.99 Shallow Apparent Erosion. 88 2748 0.04 0.06 24 11 2.98 Apparent Erosion. 89 2779 0.04 0.05 19 11 2.98 Shallow Apparent Erosion. 90 2809 0.04 0.05 19 9 2.96 Shallow Pitting. 91 2840 0.04 0.05 19 10 2.98 Shallow Line Corrosion. I 92 2871 0.04 0.04 17 9 2.98 2902 0.04 0.05 19 12 2.99 Shallow Apparent 29 pp arent Erosion. 94 2933 0.05 0.06 23 13 2.98 Apparent Erosion. I Penettb0 n Me tal Loss Body Page 2 1 1 1 0 • 1 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in. 9.2 ppf J -55 BUTT AB- MOD Well: 1 E -11 I Body Wall: 0.254 in. Field: Kuparuk Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. Country: USA Survey Date: August 11, 2011 1 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upsel Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 95 2963 0.04 0.05 19 11 2.98 Shallow Apparent Erosion. 96 2994 0.03 0.04 14 7 2.96 Shallow Apparent Erosion. til 97 3025 0.04 0.05 21 10 2.97 Apparent Erosion. ■ 98 3053 0.04 0.05 21 11 2.97 Apparent Erosion. ■ I 99 3085 0.04 0.05 21 12 2.99 Apparent Erosion. IN 100 3117 0.05 0.05 19 11 2.98 Shallow Apparent Erosion. ■ 101 3148 0.05 0.05 21 13 3.00 Apparent Erosion. or 102 3179 0.05 0.05 21 11 2.98 Apparent Erosion. ■ I 103 3209 0.05 0.06 24 15 3.00 Apparent Erosion. 104 3241 0.04 0.04 14 7 2.96 Shallow Pitting. .1 105 3270 0.04 0.05 19 12 2.99 Shallow Apparent Erosion. ■ 106 3299 0.04 0.05 21 9 2.97 Apparent Erosion. I 107 3330 0.04 0.04 17 8 2.96 Shallow Pitting. i 108 3362 0.04 0.04 16 7 2.98 Shallow Line of Pits. r 109 3392 0.04 0.04 17 11 2.98 Shallow Apparent Erosion. 110 3424 0.04 0.05 21 9 2.99 Apparent Erosion. IN I 111 3454 0.04 0.05 19 10 2.97 Shallow Apparent Erosion. IN 3485 0.04 0.06 24 11 2.98 Apparent Frosion. on 113 3516 0.04 0.05 19 10 2.98 Shallow Corrosion. ■ 114 3547 0.04 0.05 21 10 2.98 Corrosion. 115 3577 0 0.04 16 6 2.96 Shallow Line of Pits. .3 I 116 3606 0.04 0.04 17 8 2.96 Shallow Line of Pits. i 117 3637 0.05 0.05 21 11 2.98 Apparent Erosion. ■ 118 3667 0.04 0.06 24 11 2.98 Corrosion. ■ 119 3697 (1.04 0.05 19 9 2.95 Shallow Apparent Erosion. I 120 3729 0.04 0.04 16 7 2.96 Shallow Apparent Erosion. �� 121 3758 0.04 0.06 23 10 2.98 Isolated Pitting. ■ 122 3788 0.03 0.05 19 8 2.97 Shallow Pitting. r■ 123 3819 0.04 0.06 24 11 2.98 Corrosion. I 124 3851 0.04 0.04 17 8 2.99 Shallow Apparent Erosion. 125 3880 0.04 0.04 16 7 2.97 Shallow Line of Pits. 126 3911 0.04 0.04 17 7 2.96 Shallow Apparent Erosion. r 127 3942 0 0.04 16 6 2.96 Shallow Line of Pits. 127.1 3973 0 0 0 0 2.91 GLM 2 (Latch @ 12:30) d I 128 3980 0.04 0.04 17 9 2.98 Shallow Apparent Erosion. 129 4011 0.04 0.06 24 12 3.00 Apparent Erosion. ■ 130 4041 0.04 0.05 19 9 2.97 Shallow Pitting. i■ 131 4070 0.04 0.05 19 9 2.98 Shallow Line of Pits. IN I 132 4102 0.04 0.06 24 11 2.99 Apparent Erosion. ■ 133 4133 0.04 0.05 21 8 2.96 Apparent Erosion. r 134 4164 0.03 0.04 17 7 2.97 Shallow Line of Pits. r � 135 4195 0.03 0.04 16 7 2.97 Shallow Line of Pits. I 136 4223 0.04 0.06 24 10 2.98 Apparent Erosion. ■ 137 4254 0.03 0.06 23 5 2.97 Line of Pits. u 138 4284 0.03 0.05 21 7 2.98 Line of Pits. IN 139 4315 0.04 0.06 23 9 2.97 Line of Pits. • 140 4346 0.05 0.06 23 11 2.98 Apparent Erosion. I 141 4375 0.04 0.04 17 8 2.97 Shallow Apparent Erosion. 142 4405 0.0 > 0.04 17 9 2.98 Shallow Apparent Erosion. 13 143 4435 0.06 0.06 24 13 3.00 Apparent Erosion. I l Penetratlon Metal Loss Body Page 3 1 1 • • ' PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in. 9.2 ppf J -55 BUTT AB- MOD Well: 1 E -11 I Body WaII: 0.254 in. Field: Kuparuk Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. Country: USA Survey Date: August 11, 2011 I Joint Jt. Depth Pen. Pen. Peri. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 144 4466 0.04 0.07 26 11 2.99 Apparent Erosion. ■ 145 4496 0.04 0.05 21 7 2.98 Isolated Pitting. u 146 4525 0.04 0.07 30 10 2.94 Apparent Erosion. ■ 147 4557 0.04 0.05 19 7 2.97 Shallow Line of Pits. ms I 148 4587 0.06 0.05 21 11 2.99 Apparent Erosion. 149 4617 0.03 0.04 14 7 2.97 Shallow Line of Pits. .3 150 4648 0.04 0.05 19 4 2.95 Shallow Line of Pits. ■■ 151 4679 0.03 0.05 19 7 2.96 Shallow Line of Pits. IN I 152 4711 0.04 0.06 24 12 2.98 Apparent Erosion. • 153 4741 0.05 0.05 21 1 1 2.99 Apparent Erosion. ■ 154 4771 0.05 0.05 21 1 1 2.98 Apparent Erosion. 155 4802 0.04 0.04 16 7 2.97 Shallow Pitting. ■3 I 156 4833 0.03 0.06 24 7 2.96 Line of Pits. .. 157 4863 0.04 0.05 21 10 2.99 Isolated Pitting. 158 4895 0.04 0.04 16 7 2.96 Shallow Pitting. 3 159 4927 0.0 3 0.05 21 6 2.96 Line of Pits. IN I 160 4959 0.04 0.05 19 10 2.99 Shallow Apparent Erosion. 161 4989 0.03 0.04 16 5 2.96 Shallow Line of Pits. ■ 162 5020 0.04 0.04 17 9 2.97 Shallow Line of Pits. r 163 5052 0.04 0.06 23 11 2.99 Apparent Erosion. ■ 164 5080 0.05 0.07 26 11 2.98 Apparent Erosion. ■ I 165 5111 0.04 0.06 24 8 2.98 Line of Pits. r■ 166 5142 0.04 0.07 28 10 2.98 Apparent Erosion. 167 5173 0.04 0.04 17 8 2.96 Shallow Line of Pits. r 168 5203 0 0.04 14 6 2.96 Shallow Line of Pits. ■ I 169 5234 0.04 0.04 17 10 2.99 Shallow Apparent Erosion. 170 5267 0.04 0.05 21 9 2.99 Apparent Erosion. ■ 171 5297 0.04 0.05 19 9 2.97 Shallow Apparent Erosion. i 172 5328 0.04 0.04 17 7 2.97 Shallow Apparent Erosion. �� I 173 5359 0.03 0.05 19 7 2.97 Shallow Line of Pits. r■ 174 5390 0.04 0.06 23 9 2.98 Apparent Erosion. ■ 175 5421 0.04 0.06 24 8 2.99 Apparent Erosion. w 176 5452 0.04 0.06 23 7 2.97 Line of Pits. 176.1 5483 0 0 0 0 2.92 GLM 3 (Latch @ 3:30) III I 177 5489 0 0.04 16 4 2.96 Shallow Line of Pits. ■ 178 5519 0 0.04 14 6 2.97 Shallow Line of Pits. i 179 5550 0.03 0.06 23 6 2.95 Isolated Pitting. u■ 180 5581 0 0.06 23 7 2.97 Isolated Pitting. 1 I 181 5609 0.03 0.04 17 6 2.97 Shallow Line of Pits. ■ 182 5641 0 0.04 16 4 2.93 Shallow Line of Pits. ■ 183 5671 0.03 0.04 17 4 2.96 Shallow Line of Pits. • 184 5702 0.03 0.04 16 5 2.90 Shallow Line of Pits. Lt. Deposits. ■ 185 5732 0 0.03 12 3 2.95 Shallow Pitting. ■ 186 5762 0 0.04 16 4 2.94 Shallow Line of Pits. ■ 187 5793 0 0.04 14 4 2.96 Shallow Line of Pits. ■ 188 5823 0 0.04 14 5 2.96 Shallow Line of Pits. ■ 189 5853 0.03 0.04 16 6 2.95 Shallow Line of Pits. 1 I 190 5882 0 0.03 12 4 2.96 Shallow Line of Pits. ■ 191 5912 0 0.03 12 3 2.95 Shallow Pitting. ■ 192 5944 0.04 0.04 17 6 2.96 Shallow Line of Pits. I Prat M enet e n Loss ion Body Page 4 1 1 1 • • 1 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in. 9.2 ppf J -55 BUTT AB- MOD Well: 1 E -11 I Body Wall: 0.254 in. Field: Kuparuk Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. Country: USA Survey Date: August 11, 2011 1 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 193 5973 0.03 0.03 12 4 2.97 Shallow Pitting. ■ 194 6005 0 0.04 14 4 2.95 Shallow Pitting. ■ 195 6035 0.04 0.04 16 6 2.97 Shallow Line of Pits. • 196 6066 0.04 0.04 16 6 2.97 Shallow Line of Pits. ■ I 197 6097 0.04 0.04 16 5 2.96 Shallow Line of Pits. ■ 198 6129 0 0.04 14 3 2.96 Shallow Line of Pits. g 199 6159 0 0.02 9 1 2.94 200 6189 0.04 0.04 16 5 2.97 Shallow Line of Pits. g I 201 6221 0.03 0.04 14 4 2.96 Shallow Line of Pits. • 202 6252 0 0.04 14 2 2.93 Shallow Pitting. ■ 203 6280 0.05 0.05 21 9 2.99 Apparent Erosion. 204 6311 0.03 0.04 16 5 2.96 Shallow Pitting. ■ I 205 6341 0.04 0.04 16 6 2.96 Shallow Line of Pits. ■ 206 6370 0.05 0.05 19 7 2.97 Shallow Apparent Erosion. i 207 6398 0.04 0.05 19 7 2.95 Shallow Apparent Erosion. g 208 6430 0.06 0.04 16 4 2.96 Shallow Line of Pits. ■ I 209 6461 0.04 0.04 16 6 2.93 Shallow Line of Pits. • 210 6492 0.04 0.05 19 8 2.97 Shallow Apparent Erosion. i 211 6524 0.04 0.03 12 2.96 Shallow Pitting. ■ 212 6554 0.03 0.06 24 8 2.95 Isolated Pitting. 212.1 6586 0 0 0 0 2.89 GLM 4 (Latch @ 4:00) 1 213 6592 0.04 0.05 19 5 2.95 Shallow Pitting. • 214 6622 0.05 0.07 26 9 2.96 Apparent Erosion. 215 6651 0.03 0.04 16 4 2.93 Shallow Line of Pits. • 216 6682 0.04 0.06 24 5 2.93 Isolated Pitting. • I 217 6712 0.04 0.04 16 4 2.94 Shallow Line of Pits. ■ 218 6744 0.03 0.04 17 6 2.93 Shallow Line of Pits. Lt. Deposits. ■ 219 6776 0.03 0.03 12 3 2.95 Shallow Pitting. ■ 220 6806 0.04 0.04 17 6 2.95 Shallow Apparent Erosion. ■ I 221 6836 0.04 0.04 17 7 2.95 Shallow Apparent Erosion. 222 6867 0.04 0.05 21 11 2.96 Isolated Pitting. 223 6898 0.04 0.05 19 9 2.97 Shallow Apparent Erosion. 224 6928 0.03 0.05 19 5 2.96 Shallow Line of Pits. • 225 6958 0.05 0.06 23 9 2.98 Apparent Erosion. I 226 6989 0.04 0.05 19 8 2.96 Shallow Pitting. 227 7020 0.04 0.05 19 7 2.97 Shallow Apparent Erosion. i 1 228 7050 0.04 0.04 17 7 2.96 Shallow Apparent Erosion. ■ 229 7081 0.04 0.04 17 6 2.96 Shallow Apparent Erosion. • 1 230 7112 0.03 0.04 16 6 2.96 Shallow Apparent Erosion. ■ 231 7142 0.05 0.05 19 8 2.96 Shallow Apparent Erosion. 232 7173 0.04 0.06 24 4 2.92 Isolated Pitting. Lt. Deposits. ■ 233 7204 0.04 0.04 17 7 , 2.97 Shallow Apparent Erosion. 1 I 234 7234 0.03 0.04 , 14 4 2.96 Shallow Line of Pits. • 235 7265 0.03 0.04 16 5 2.94 Shallow Line of Pits. • 236 7294 0.04 0.06 23 9 2.97 Apparent Erosion. 237 7325 0.05 0.06 23 10 2.97 Apparent Erosion. 238 7356 0.04 0.04 14 4 2.95 Shallow Line of Pits. • 1 239 7385 0.04 0.04 14 4 2.96 Shallow Line of Pits. • 239.1 7416 0.03 0.03 12 3 2.94 Pup Shallow Line of Pits. 239.2 7421 0 0 0 0 2.88 _ GLM 5 (Latch @ 1:30) I Prtion Bo Metal a Loss Body Page 5 1 1 1 • • I PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in. 9.2 ppf J -55 BUTT AB- MOD Well: 1 E -11 Body Wall: 0.254 in. Field: Kuparuk I Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. Country: USA Survey Date: August 11, 2011 1 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 239.3 7430 0 0.02 9 1 2.95 Pup II 240 7436 0.07 0.07 28 7 2.90 Isolated Pitting. Lt. Deposits. r 240.1 7468 0 0.03 12 2 2.96 Pup Shallow Line of Pits. 240.2 7472 0 0.03 10 2 2.95 Pup I 240.3 7474 0 0 0 0 3.00 Baker PBR with 10' Stroke 240.4 7487 0 0 0 0 2.88 Baker HB Retrievable Packer 240.5 7495 0 0.02 9 1 2.95 Pup • 241 7497 0.04 0.04 17 7 2.96 Shallow Apparent Erosion. 1 I 241.1 7526 0.05 0.06 23 7 2.95 Pup Apparent Erosion. 241.2 7530 0 0 0 0 4.44 Baker SBR 241.3 7537 0.04 0.03 12 2 2.96 Pup Shallow Line of Pits. ■ 241.4 7547 0.03 0.03 12 4 2.96 Pup Shallow Line of Pits. ■ I 241.5 7556 0.04 0.03 12 1 2.96 Pup Shallow Line of Pits. 241.6 7558 0 0 0 0 3.00 Baker FHL Retrievable Packer 242 7566 0.05 0.05 21 6 2.93 Apparent Erosion. Lt. Deposits. 242.1 7596 0 0 0 0 2.91 INI 1 (Latch @ 3:00) 243 7602 0.04 0.04 17 5 2.68 Shallow Apparent Erosion. Deposits. ■ I 244 7633 0.04 0.05 21 5 2.67 Apparent Erosion. Deposits. 244.1 7662 0 0 0 0 2.86 INI 2 (Latch @ 1:00) 245 7667 0.04 0.06 24 6 2.94 Apparent Erosion. 1 246 7700 0.06 0.12 46 10 2.95 Isolated Pitting. I 247 7729 0.05 0.05 21 6 2.87 Apparent Erosion. Lt. Deposits. 248 7761 0.04 0.08 33 7 2.98 Isolated Pitting. i 249 7791 0.06 0.09 35 13 2.81 Isolated Pitting. Lt. Deposits. 250 7820 0.04 0.06 24 8 2.94 Apparent Erosion. 1 1 251 7852 0 0.04 17 1 2.91 Shallow Line of Pits. Lt. Deposits. 252 7882 0.05 0.09 37 14 2.95 Isolated Pitting. 252.1 7914 0.05 0.07 30 9 2.97 Pup Apparent Erosion. 252.2 7929 0 0 0 0 2.90 INI 3 (Latch @ 10:00) I 252.3 7935 0.04 0.10 39 10 2.94 Pup Isolated Pitting. 252.4 7951 0 0 0 0 3.00 Baker Locator Seal Assv 252.5 7958 0 0 0 0 2.88 Baker FB-1 Packer 252.6 7967 0 0 0 0 2.75 Camco D Nipple 252.7 7968 0.03 0.03 10 3 2.94 Pup I 252.8 7971 0 0 0 0 2.99 SOS I Penetration Body Metal Loss Body 1 1 1 1 1 Page 6 1 1 1 • • 1 ill:Ps PDS Report Cross Sections 1 Well: 1E-11 Survey Date: August 11, 2011 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.2 ppf J -55 BUTT AB- MOD Analyst: C. Lucasan 1 1 Cross Section for Joint 246 at depth 7712.530 ft Tool speed = 50 I Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 91°/0 '� ` `�` Tool deviation = 52° 1 r /, 1 ...--- / \ Finger = 5 Penetration = 0.115 in. Isolated Pitting 0.17 ins. = 46% Wall Penetration HIGH SIDE = UP 1 II II 1 1 1 • • 1 PDS Report Cross Sections 1 Well: 1E-11 Survey Date: August 11, 2011 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.2 ppf J -55 BUTT AB- MOD Analyst: C. Lucasan 1 1 Cross Section for Joint 252.3 at depth 7947.650 ft Tool speed = 49 I Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 90% Tool deviation = 49° 1 / \ 1 7 1 1 i 1 I i 1 1 1 ...--- 0°11111/ 1 1 1 Finger = 10 Penetration = 0.098 in. Isolated Pitting 0.10 ins. = 38% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 1 0 • 1 14;. PDS Report Cross Sections 1 Well: S 1 E-1; Survey Date: August 11, 2011 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.2 ppf J-55 BUTT AB- MOD Analyst: C. Lucasan 1 1 Cross Section for Joint 61 at depth 1921.640 ft Tool speed = 51 I Nominal ID = 2.992 Nominal ll 3.5 '' -■mss` Remaining g wall wall arr ea = 83% 1 Tool deviation = 39° ( \ \I 1 1 r \ i 1 \ / / 1 N 7 1 Finger = 4 Penetration = 0.058 in. Apparent Errosion 17% Cross - sectional Wall Loss HIGH SIDE = UP 1 r 1 1 1 1 • 0 1 S PDS Report Cross Sections I Well: 1E -11 Survey Date: August 11, 2011 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.2 ppf J -55 BUTT AB- MOD Analyst: C. Lucasan 1 1 Cross Section for Joint 62.3 at depth 1974.050 ft Tool speed = 43 I Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 84% `� ` Tool deviation = 41° 1 / \ 1 1 1 1 1 \ 1 \NNI411144 —,...../. I \/ 1 Finger = 10 Penetration = 0.053 in. Apparent Errosion 16% Cross - sectional Wall Loss HIGH SIDE = UP 1 1 1 1 1 r • 1 41: . . . PDS Report Cross Sections I Well: 1 E -11 Survey Date: August 11, 2011 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.2 ppf J -55 BUTT AB- MOD Analyst: C. Lucasan 1 1 Cross Section for Joint 244 at depth 7656.930 ft Tool speed = 50 I Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 96% Tool deviation = 52° 1 1 % -\ 1 111 \\ 1 N, / i -. 1 1 Minimum I.D. = 2.665 in. Deposits Minimum I.D. = 2.67 in. HIGH SIDE = UP 1 1 1 1 1 1 • • PDS Report Cross Sections 1 Well: 1E-11 Survey Date: August 11, 2011 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.2 ppf J -55 BUTT AB- MOD Analyst: C. Lucasan 1 1 Cross Section for Joint 243 at depth 7617.960 ft Tool speed = 50 I Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 99% Tool deviation = 51° 1 41 / �, i f / 1 \ 1 1 I I Minimum I.D. = 2.679 ins Deposits Minimum I.D. = 2.68 in. HIGH SIDE = UP 1 1 1 1 I KUP 1E-11 ConocoPhillips Attributes 11 lingle & MD TD Wellbore API/UWI [Field Name Well Status Ind (1 MD (9KB) Act Btrn gfKB) 500292078700 1 KUPARUK RIVER UNIT INJ 54.00 7.500.00 8,754.0 Comment H2S (ppm) Dale Annotation End Date KB-Qd (ft) Rig Release Date SSSV: Well C0013 -1e -ii 4/1012011 Actual 8ss:0s AM Common TRDP Last WO: 4/4/1991 40.71 5/10/1982 smematic - ,s Annotation Depth (RY(B) End Date Annotation Last Mod ... End Date Last Tag: SLM 8,075.0 5/25/2009 Rev Reason: FORMAT UPDATE Imoshor 4/16/2011 Casing Strings Casing Description String 0... String ID ... Top (11KB) Set Depth (T... Set Depth (TVD) ... String Wt... Skiing... String Top Thrd CONDUCTOR 16 15.060 32.0 80.0 80 65.00 H -00 WELDED Casing Description Siring 0... String ID ... Top (RKB) Set Depth g... Set Depth (IVO) ._ String WL.. String ... String Top Thai SURFACE 103/4 9.794 31.3 2,835.1 2,474.9 45.50 K - 55 BTC HANGER 35 Casing Description String 0... String ID... Top (RKB) Set Depth g... Sri Depth (TVD)..2 String Wt... String... String Top Thrd t PRODUCTION 7 6.151 30.5 8,723.0 6,790.3 26.00 K -55 BTC I Tubing Strings Tubing Description String 0... String ID ._ Top (11103) Set Depth g_. Set Depth (TVD) ... Shi g WL_ String... String Top Thrd CONDUCTOR. TUBING 3 1/2 2.992 35.0 7,557.8 6,059.7 9.20 J BUTT AB-MOD 32 Completion Details Top Depm SAFETY VLV, (1VD) Top Ind (RKB) (R Naml... 1,952 1 KB) (°) Rem Description Comment ID (In) I 35.0 35.0 0.43 HANGER FMC GEN III HANGER 3.500 1,952.2 1,8193 4337 SAFETY VLV CAMCO TRDP -1A -SSA SAFETY VALVE 2. 812 GAS LET, 1.399 7,475.8 6,011.3 54.15 PBR BAKER PBR w/ 10' STROKE 3.000 7,491.0 6,020.2 54.06 PACKER BAKER HB RETRIEVABLE PACKER 2.880 7,532.1 6,044.7 54.00 SBR BAKER SBR 4.437 I Tubing Description String 0... String ID... Top MKS) Set Depth R... Set Depth (TVD)... String Wt... String... String Top Bird SURFACE, TUBING Original 4 ' 2.992 7,557.8 7,973.3 6,312.0 9.20 J-55 FL4S 31 -2.835 Completion Details Top Depth (TVD) Top Ind Noml... Top (RKB) MKB) (°) Rem Description Comment ID (in) 7,557.8 6,059.7 53.76 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 7,700.4 6,145.7 52.82 BLAST RINGS 96 BLAST RINGS 2.992 GAS ,9 3.972 7,950.1 6,298.0 52.62 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 7,950.6 6,298.3 52.61 PACKER BAKER FB -1 PERMANENT PACKER 2.875 GAS LIFT, 5.482 7,953.1 6,299.8 52.59 SBE BAKER SEAL BORE EXTENSION 2.937 Gas LET. 7,965.8 6,307.5 52.48 NIPPLE CAMCO D NIPPLE NO GO 2.750 s,5s7 7,972.5 6,311.6 52.42 SOS BAKER SHEAR OUT SUB 2.992 Perforations & Slots GAS LET. Shot 1 7424 Top (TVD) Min (TVD) pens Top (RIUS) Wm (11K13) (M) MB/ Zone Dace Oh- Type Comment 7,708.0 7,794.0 6,150_3 6,202.3 C-4, C -3, C-2, 5/10/1982 4.0 IPERF C -1, 1E -11 7,996.0 8,008.0 6,325.9 6,333.2 A-5, 1E -11 2/1/1985 8.0 RPERF Original Pert 5/10/82 I PBR 7476 8,028.0 8,056.0 6,3455 6,362.8 A-4, 1E -11 2/1/1985 8.0 RPERF Original Perf 5/10/82 8,061.0 8,076.0 6,365.9 6,3753 A-4, 1E -11 2/1/1985 8.0 RPERF Original Perf 5 /10/82 PACKER, 7491 Notes: General & Safety End Date Annotation 9/25/2004 NOTE: E -LINE DOCUMENTED MANDREL LEAK @ 7640' i 8/25/2010 NOTE View Schematic w/ Alaska Schematic9.0 SBR, 7,532 I [ PACKER, 7,558 IN.ECT I . V 596 1 7.596 TT 1 ��[ _, 7,662 ,62 IPERF, 1 7,708-7,794 IF I IN,ECTION, 7.929 SEAL ASSY. 7,950 PACKER, 7,951 SSE, 7,953 ) NIPPLE. 7,968 i _ Mandrel Details SOS, 7,973 Top Deem Top 1.011 (TVD) Inc/ to Valve Lads Size TRO Run RPERF, Stn Top (111(B) MKS/ (1 Make Nadel (in) Sery Type Ty (In) Ipsl Run Date Com.. 996 1 1,999.0 1,853.2 43.35 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/20/1996 2 3,972.0 3,330.4 40.86 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/20/1996 i RPERF, II ll 3 5,482.1 4,512.4 36.21 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/20/1996 8.0288958 6,081 RPERF -0,076 II II 4 6,5874 5,398.6 41.30 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/4/1991 5 7,423.6 5,981.1 54.48 CAMCO MMG -2 1 12 GAS LIFT DMY RK '0.000 0.0 5/20/1996 FISH. 8,149 Z 1 7,595.9 6,082.2 53.40 CAMCO KBUG 1 INJ HFCV BK 0.000 0.0 6/3/2009 II 2 7,662.1 6,122.0 52.79 CAMCO KBUG 1 INJ HFCV BK 0.000 0.0 6/3/2009 3 7,929.0 6,285.4 52.80 CAMCO KBUG 1 INJ HFCV BK 0.000 0.0 6/3/2009 PRODUCTION. 30-8.723N . ■ TD. 8,756 MEMORANDUM To: Jim Regg P.I. Supervisor FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 14, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC lE-1 ] KUPARUK RIV UNIT 1E-11 Src: Inspector NON-CONFIDENTIAL • Reviewed By: P.I. Suprv Comm Well Name: KUPARUK RIV UNIT 1E-11 Insp Num: mitRCN100627133019 Rel Insp Num: API Well Number: s0-029-20787-00-00 Permit Number: 182-051-0 Inspector Name: Bob Noble Inspection Date: 6/24/2010 Packer Depth Pretest Initial IS Min. 30 Min. 45 Min. 60 Min. Well P.T.D IEaI '~ Iszoslo Type Inj. TypeTest N SPT TVD Test psi bozo IA ~ taro OA soo o lslo 0 I7~o 0 Iz6o 0 Interval aYRTST p/F P Tubing 2ozs 2ozs 2ozs zozs Notes: ~ t~. r~~~~- fit- ~~;~~ Wednesday, July 14, 2010 Page 1 of 1 • 5~ Brooks, Phoebe L (DOA) From: Regg, James B (DOA) Sent: Tuesday, July 13, 2010 2:57 PM To: Brooks, Phoebe L (DOA) Subject: RE: KRU 1 E pad MITIA 062410 Info provided by CPAI on 8!12/2008 as part of Packer TVD project confirmed the following: KRU 1 E-11 PTD 182-051 -- Packer TVD = 6020 ft U - (PTD 182-163) -- Packer TVD = t Please adjust RBDMS to reflect these revisions. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Brooks, Phoebe L (DOA) Sent: Tuesday, June 29, 2010 8:48 AM To: Regg, James B (DOA) Subject: FW: KRU lE pad MITIA 062410 Hi 1im, I emailed Conoco about the differing Packer TVD's and it sounds like they are firm on the figures reported. I checked the well history and didn't see any reports that could have changed the figures. I looked at the last MIT report (prior to this one) in RBDMS and both the operator and inspector reported the same numbers below (not what is currently in RBDMS) sa I'm wondering if I should change our figures to match the operator's? Thank you, Phaebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Tuesday, June 29, 2010 8:41 AM To: Brooks, Phoebe L (DOA) Subject: RE: KRU lE pad MITIA 062410 Phoebe, The packer depths are as CoP reported I re checked them myself this morning. I unintentionally left the P's of the report for 1 E-112 and 1 E-119. I'm covering 3 jobs this week and clearly not very well. Thanks • MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 From: Brooks, Phoebe L (DOA) [mailto:phoebe.brooks@alaska.gov] Sent: Monday, June 28, 2010 10:23 AM To: NSK Problem Well Supv Subject: RE: KRU 1E pad MITIA 062410 • MJ, Will you please verify the Packer TVD for the following wells: * 1E-11 PTD #1820510 - 6020' reported, 6008' in our database • 1E-23 PTD #1821840 - 5907` reported, 6124' in our database • 1E-27 PTD #1821630 - 5888' reported, 5858' in our database Also, wells 1E-112 through 1E-119 were missing the test type, I'm assuming Standard Pressure Test "P"? Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Friday, June 25, 2010 2:12 PM To: Regg, James B (DOA); Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Cc: NSK Problem Well Supv Subject: KRU 1E pad MITIA 062410 Attached please find the 4 year MITIA's completed at KRU DS1 E yesterday and witnessed by Bob Noble. Let me know if you have any questions. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 Page 1 of 3 Regg, James B (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Tuesday, August 12, 2008 12:05 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: RE: Packer TVD Attachments: Copy of pkr_depth_edits_CPAI_data COP edit 8-12-08.x1s; AOGCC 1 of 5.zip Jim, Enclosed are the results of our investigation into the few wells with remaining discrepancies over top packer depth. I have found errors in COPs data in roughly half of the wells you submitted. Those wells are marked in a column that I have added to your original spreadsheet with OK. I will make the required changes to our database to fix those depths. The information confirming the packer depths is contained in the attached folder for your convenience. COPs recorded top packer depth on roughly half the wells does not agree with the States data. I have added supporting documentation for these wells to the attached folder. Please see the returned modified spreadsheet, the attachments, and the comments below. Due to the size of the attachments and the restrictions of our system I'll have to break it into segments and send in subsequent a-mails to follow. Let me know if you have any questions Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 Wells in question: 30-16 -COP agrees with the States PKR MD and TVD of 7648' and 6325' respectively. 1 J-180 -COP agrees with the States PKR MD and TVD of 9996' and 3291' respectively. 3M-12 -COP contends the top packer MD and TVD to be 9994' and 6122' respectively. I've enclosed a PDF scan of the 8-19-87 tubing tally,completion report, and schematic which I believe to be the most current. The tally indicates the Camco HRP-1-SP packer was set at 9993.69 MD. 1A-05 - - I'm unaware of a pending workover on 1A-05 at this time. The well currently has PKR MD and TVD of 6745' and 5922' respectively. Most recent schematic, tubing tally and completion report are in the attachments. There has been some recent tubing patch work completed on the well but no tubing has been pulled and replaced. I've a call in to the drill site engineer in town to confirm future plans for this well. If it is worked over in the near future any new packer depths should be covered in the sundry process. 1 R-13 -I've researched the packer depth and our schematic does not agree with the workover performed. Our schematic lists the packer at 7880'. The tubing tally and 10-404 from the workover correctly identify the packer at 7878' MD. I've submitted our schematic internally to be updated to reflect the correct packer depth. 2L-329 -COP agrees with the States PKR MD and TVD of 5467' and 4898' respectively. 7/13/2010 • Page 2 of 3 2X-04 -COP contends the top packer MD and ND to be 6919' and 5306' respectively.~`ve included the tubing tally, schematic, and 10-404 report of sundry operations from the latest workover. 18-09 -COP agrees with the States PKR MD and ND of 7745' and 6241' respectively. 1Y-05 -COP contends the top packer MD and ND to be 6250' and 5853' respectively. I've included the tubing tally, schematic, and 10-404 report of sundry operations from the latest workover. I've also included a 10-403 sundry request that we submitted with and incorrectly identified packer MD. I'm assuming the error was initiated in the sundry and propagated forward. 3F-04 -COP agrees with the States PKR MD and ND of 6167' and 5729' respectively. 1 E-11 -COP contends the top packer MD and ND to be 7491' and 6020' respectively. I've included a daily report of rig activities, tubing tally, notice of troubled well, and schematic. It appears as if the well was worked over, added a stacker packer, in order to fracture stimulate the well. I found a state witnessed BOP test during the time of the work over but I can not find any supporting well completion report or 10-404 sundry report to support the tally information. 1 E-114 - COP agrees with the States PKR MD and ND of 7414' and 3479' respectively. 1 L-21 DPN -COP contends the top packer MD and ND to be 11275' and 5769' respectively. Included are the well schematic, tubing tally, well completion report and the 10-404 WINJ to WAG. 2A-01 -COP contends the top packer MD and ND to be 7122' and 5796' respectively. Included are the well schematic, tubing tally and well completion report. 1 H-19 -COP contends the top packer MD and ND to be 8242' and 6370' respectively. Included are the well schematic, tubing tally and well completion report. 2B-09 -COP contends the top packer MD and ND to be 6904' and 5805' respectively. Included are the well schematic, tubing tally and well completion report. 1 C-117 - COP agrees with the States PKR MD and ND of 4460' and 3685' respectively. 2C-03 - COP agrees with the States PKR MD and ND of 7020' and 5608' respectively. 1 R-04 - COP agrees with the States PKR MD and ND of 7706' and 6303' respectively. 1 E-104 - COP agrees with the States PKR MD and ND of 5564' and 3351' respectively. 1A-14 - COP agrees with the States PKR MD and ND of 7113' and 6013' respectively. 1C-133 -COP contends the top packer MD and ND to be 3951' and 3669' respectively. Included are the well schematic, tubing & casing tally and well completion report. 1 E-27 -COP contends the top packer MD and ND to be 5966' and 5888' respectively. Included are the well schematic, tubing tally and well completion report. 2P-434 -COP contends the top packer MD and ND to be 5525' and 5129' respectively. Included are the well schematic, tubing tally, survey and well completion report. 1 E-117 -COP agrees with the States PKR MD and ND of 9369' and 3338' respectively. 2T-217A -Apparently the only issue with this well was it's status. The 10-404 sundry of conversion to injection was mailed 7130/08. I don't believe there were any questions regarding packer depth. 7/13/2010 • . Page 3 of 3 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, July 22, 2008 2:27 PM To: NSK Well Integrity Proj Cc: Fleckenstein, Robert J (DOA) Subject: Packer TVD Perry -Thank you for all the work you/others have done to help us close this project out. We are getting real close. Attached is the list of wells that we still are reviewing and could use another look by you. I've added a column of remarks that hopefully helps. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 7/13/2010 • ~~ \ KRU 1 E-11 ~~ ~ Cono~coPhillips Alaska, (nc. ~;~ u ~ r u~irvu ~ LINtN oE~rai~~ No ~ ~~G ~~~~ ~~ DRILL 5. ~~" I/ ARCO Alaska, InC. \j DATE ,--~~~'~9~~ Subsidiary of AllantlcRlchHeldCompany Page _. / Of 2 ~nwn~e~ ITEMS COMPLETE DISCRIPTION OF EQUIPMENT RUN LENGTH DEPTH ' ~ 00 00 ~ 00 l" ",t ~ ~~~-~ ~ -- ~~--,~6~,~G -- 79,_ .5 ZQ~~~ y . _ __ .~ Ir N _ _ r O ..~ ~ I i ., ' . -~ ~ - .~2 0.~~~ 9- w o , • ,, ' o • . , . / ,r ~ ~~ ~I~ r d I~7 ~..~ • // -- ~`~ y .• - - o ,.. .. ~ ~ .- ~ir____~~~Q1Ps~YOkt-. 4r''s, B. .3''sD S' "' o D ~,~ ~ , . s.~ . ., •, . /. ,~ ~,-, "'~ T .9a I ~~ .. ,, D ~ T - a 7 BOTTOM OF TUBING TAIL Remarks O O ..... • SING I TUBING I LINER D~ f, ~. DRILL SITE ~~'/~ uJo?~txlE~2 ARCO Alaska, Inc. ~~ DATE - ~o- 23-8y SubsiCiuy of AllinhCgiChlltltlCompi~y Page _ ~ OI pages KITEMS COMPLETE DISCRIPTION OF EQUIPMENT R UN LENGTH OEPTN C Eo~~ s .i~,.. ~ ~, . ~ it/_. /.~,. /, r. _ ... _ -. .. D N v0 TVQisl6.. .t}^ L.~'i ~ N ~ a ~TvB,.r C 3 ~~Z~Tr ~ G4 r ~J4S -3 ~ -SS ~ rc ~a .+, o ~ 7'v Q, ~G- ~ ~~ Q,,Z+~ T C ~• D v N 'r"' ~ -~~ i7r~.•~ .~w........_._.._..-H4~ z"' r-s~"' ,e rc A 8 ~, oQ Pu P ,7 ~r ~v T' '1~AKFR,. ~rAG A•SSPM A ~y w 1s ems,... e C ~.aL. L ~ ~ ~~ r-v •~ ~ E4 E A ~AX~R 1 ~- 0 ~ ~ c ~ rL" ~ z ~ T SS Q TG ~ err"' C.4~rCo `~ " nJ 3 , w ~ ' ~„ C v J"cn~ 7" q ~iQ_ R ouT u ~iN~ _ Tb sOTTOM OF TUBING TAIL. Remarks ^~~' 3 a s~ u~'1D 2x11 ~ ~ 7 ~ ~-~ 1 " ~-/ ~b ~ P c n~ yi ~ ~ 7'y ~ L ~~ ~ y ~ cri( F~ T ~B~X y G sf10 Q po.+,,g.~~ ~r~.y~C `".it d r-~ ~ -s ~ 3 7 ~ 33 ~ ~ ~'~ ~D Zi 7" ~ [rw o o ,,,,.- ARCO PM t i 8 ,. .~ Y99 ~ _ 3a 9p .7~ 7 5( . 0 A 2L .,..~.'` ~s~ b3 ° Goa 9 ~- 07 (/O'~" ~~~ ~ ~8 (o ~ _ ~ O ? r /5° x'76 96 .7 ~ 9~ ~ 06 A ~ 7 93.z w. .~ o +~ s y~ •,/~ ~N,Z'p p3L J L 3 9~ r~ ~'s f S`r ~s' i •7 S3q~a `~_.L_. ~ ! _ _ ow,J wT-ys.~~. Z?s' ~ ~,ZsC ~~c='p ~_R~ • ARCO Alaska, Inc. „ Daily C 'rpletionlWorkover Report AFE N G Report No. Date: Completion Days/Est. Supv. Ini . ' Well TO ~~~ ~ PBD ~ Top t Fill ~ ~ ~ SL..•~c Contractor ~ • Dail Cosl Y Completion Cost O eration at 0600 Cumulativ Well Cost Est. Cum. Cost Inter diete IPr fiction Csg. ~ Production Liner ~ perroraled Intey 4 7 Q • ''„~ ~r Rig Accept Rig Release Surface Csg. Pressure Last sg. Test (Ipsi w/ ~ ppg. N0. Liner ize SPM GPM psi Slow Pump Ra18 Slow Pump psi Pump Data No. Liner ize SPM 4PM psi Slow Pump Rate Slow Pump psi Fl i Fluid yp~ Overbalance (psi) Daily Loss (bbls) Total Loss Dai~ Cost C m. Cost u d Dale Weighl Vis. PV/YP Chlorides Fluid Loss Temp. (Pit E.S. (DBM) o/% Wtr Bil No. Size Make Type Serial No. Jets Doplh In Depth Out Flg. Hrs. ROP RPM WI. Condition Rerunnable7 Bit No. Size Make Type Serial No, Jets Depth In Depth Out Ftg. Hrs. ROP RPM Wt. Condition Rerunnable? Time Hours Code Operations From 0600 To 0600 y -- / Oa ~ l ~ // ~ eo ~s": ~' Se ~ ~~'R ~~ ~ s • . :z / . o /z. a _ ~ .. z~~~__c~~ ~ ,.~~,r ~s ~ ~ ~~~,. ~.a.. s . _ ~ sss • ~ ~~~ ,~~~ _ ~os~ //~ ~ ~ ~- o~ ~a.l _ o --- A ~ ~ ~ ~ e// c1'~c t ~~ ~ _ ...... ..___..._.,...-----.... ~ ~y ~ ~ ~--ice-t -- I ~L•~~ ~+ SL~ r~ w~l liZL.L~.~-~-~~~~~~~ BNf, Description .. _______._ _.. .... _... _.__.. _._____T._.. _. BHA No.: Drillpipe Data (Top To Bottom) OD Weight Grade Connection Class Length BHA Length: Dale LastlnsRectetl: Hours On Jars: Accident? (YIN) G~ S Name ~ vv Employer rn G Rpt. FiI d~ (V/N) c Inj on Data Fuel 8 Water Injection Well: Rate: Pressure: Fuel O Location Fuel Used Source; Volume : Type Fluid: Fuel Received Fuel Source w Orl. Water On dlion Drl. Wat r U Drl. Water Received L Orl, Water Source -/ Potable Wat ocation Potable r Used Daily Volume: Cumulative Volume: Potable Water Received Potable ater Source CUtling9 DATA ~ Weather Dela Personnel Salet BOP Qata Pady: ~ T Temperalurn _ ARCO ^ ~ / Lasl BOP T 1 Last BO Drill / Cumulative: Wind Speod ~ Contractor Last H~ Drill Last ire Dri Storage Site: Chill Factor Service Last Saf ry tq. Last Spill Drill Wall Name: ~ Dale: Other Spill ( I N ~ ~ rr Volume (Gals.) Signed: 7o1a1 ~ Type Spill Report Fitetl? Time Hours Code Operations From 0600 To 0600 I s • WELL: PRODUCTION DATA: INJECTION DATA: Notice of Kuparuk River Unit Troubled Well WELL TYPF,; P DATE: 11-5.9 RATE ~9~BOPD WATER CUT 096 RATE N/A BWPD/MCFD GOR _ 38 - G/L RATE 430_MCFD PRESSURES: PROD CASING SURFACE CASING TUBING ANNULUS ANNULUS Prod./Inj.: ,PSI „~275~SI 175 PSI Stint In: ¢QQ_PSI 130(LPSI 175 -PSI REASON FOR NOTICE: I,eakin¢ 7'_packer at 753$ - A Sand x C Sand Communication? Yes ~.. No (if .yes, give summary of problem. Specific information on file.) Prefrac operations and E-line leak detection show 7" packer lealring at ?539' RKB. Tubing by Prod. Casing Annnins Communication? Yes ___,___ N o ~_ (It yes, give snmmary of problem. Specific information on file.) Prod. Casing by Snrfaee Casing Communieation? Yes ~_ (If yes, give summary of problem. Specific information on tile.) IMPORTANT CONSIDERATIONS/COMMENTS: PLAN OF ACTION/CONDITIONS OF WAIVER: Require Waiver? Yes ~i.r.. Grant Waiver to Continue Operations: Shut in Well Pending orkover or Other Work: Production oreman OPERATIONS ENGINEERING COMMENTS: FOR WAIVEit TO .CONTINUE OPERATIONS ONLY: Production Superintendent . cc: T. M. Drnmm - ANO - I2th Floor Prodnction `Foreman - Prodnction Supervisor Operations Engineering -Prodnction Superintendent ..Operations 1Hanagsr File:... 2ai:S (FORMS)KRU TrouEled weUa&11:11/5/90:Pa=e 1 N o ~_ No Prodnction Supervisor Date: `! . ._ ~~~ ._ z~9.S~<'-'; c 06/08/07 Schlumbepger NO. 4286 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 1 200'7 ,'\41'!1;t!i!!\(~1iè!f1j;;BDG(jn~.cnmlIji~iGANNED JUN 1 4 2007 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk ~'Ÿ . (J-XC!... 11[;;) -O~-;'I Well Job # Log Description ····Date·"··· BL Color CD 2L-321 11629010 MULTI-FINGER CASING INSPECTION 05/12/07 1 2C-16 11629008 PPROF/LDL 05/10/07 1 2G-11 11638863 PRODUCTION PROFILE 05/05/07 1 1C-125 N/A MEM INJECTION PROFILE 05/05/07 1 2D-13 11638861 PRODUCTION PROFILE 05/03/07 1 2D-08 11638862 PRODUCTION PROFILE 05/04/07 1 2G-09 11638864 PRODUCTION PROFILE 05/06/07 1 2N-349A 11629004 RST/ WFL 05/04/07 1 3H-19 11638867 PRODUCTION PROFILE 05/09/07 1 1Q-10 11628771 MEM PRODUCTION PROFILE 05/03/07 1 1 E-11 11629012 INJECTION PROFILE 05/14/07 1 2L-321 11665439 USIT OS/25/07 1 2V -OBA 11629013 PMIT 05/15/07 1 1 J-160 11632704 PRODUCTION PROFILE 03/19/07 1 1H-07 11665436 SBHP SURVEY OS/20/07 1 2F -11 11665434 PRODUCTION PROFILE 05/19/07 1 2X-07 11665433 INJECTION PROFILE 05/18/07 1 1 B-01 11665432 PRODUCTION PROFILE 05/17/07 1 2X-01 11637338 INJECTION PROFILE 05/15/07 1 2Z-29 11665438 PRODUCTION PROFILE OS/22/07 1 1H-22 11637339 INJECTION PROFILE 05/16/07 1 1Y-11 11632708 INJECTION PROFILE OS/23/07 1 1G-03 11637336 INJECTION PROFILE 05/14/07 1 1A-23 11665443 MEM PRODUCTION PROFILE OS/29/07 1 1 F-08 11665435 SBHP SURVEY OS/20/07 1 1J-170 11632709 INJECTION PROFILE OS/24/07 1 10-109 N/A INJECTION PROFILE 05/13/07 1 12M-24 11665440 SBHP SURVEY OS/28/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Recrcr e:--:> 00 K-vc. P.I. Supervisor \ 7 ì I ¡CJI'~ j V[ l¿utµ DATE; Wednesday, June 07, 2006 SUBJECT; Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC lE-ll KUPARUK RIV UNIT lE-ll Src; Inspector ¿ Ö'G \ \~r Reviewed By: P.I. Supr~~ Comm FROM; Chuck Scheve Petroleum Inspector NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT IE-II API Well Number 50-029-20787-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS06060 5134 729 Permit Number: 182-051-0 Inspection Date: 6/4/2006 Rei Insp N um Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -- i I --~ Well I lE-ll ¡Type Inj. I w I 'TVD 6020 I fA 1250 2330 2300 2280 i P.T. ! 1820510 !TypeTest! SPT Test psi 1505 OA 'I 60 100 I 100 100 ! t I I Interval 4YRTST P/F P Tubing 2200 2200 2200 2200 I I ,~ Notes Pretest pressures were observed and found stable, Well demonstrated good mechanical integriy s;."J:!,~'P.'¡¡:;;íi tt,;1Vq"é" t;·r~~c-[..:.; 2 S Wednesday, June 07, 2006 Page I of I Schlumberger NO. 3231 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 1 0/06/04 Company: Alaska Oil & Gas Cons Comm Attn: Robin Deason 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL J,otf-f):3( J 1E-119 10884033 SCMT 1 0/04/04 / cro - t) :3 if /1 L-09 10802915 PRODUCTION PROFILE W/DEFT 07/26/04 1 /?'5- ~:31 J2V-14 10884026 PRODUCTION PROFILE W/DEFT 09/27/04 1 / 8'~- /Â I 2K-02 10884027 PRODUCTION PROFILE W/DEFT 09/28/04 1 / q ~ - It/iiJ 3J-17 10884031 PRODUCTION PROFILE 10/02104 1 /<65- :2.23 . 3A-07 10884030 INJECTION PROFILE 10/01/04 1 /80 -057 J 1E-04 10884023 INJECTION PROFILE 09/24/04 1 1 E-11 10884024 INJECTION PROFILE 09/25/04 1 / Yot - t:J5¡ J 2H-12 10884022 PRODUCTION PROFILE 09/23/04 1 /<g5 - ~(p~ C.f" tNED: /1 j¡~ Kuparuk Color CD 1 ~ SCANNED NOV 0 5 2004 DATE: ¿/r)f Please sign and retur 0 e copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. clds to. 18d -OS( WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 Anchorage. Alaska 99501 RE: Distribution - Final Print{s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford,1)( 77497 WELL DATE loG TYPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT[S) REPORT OR BLUE LINE Open Hole 1 1 E-11 2-26-04 Res. Eva!. CH )c91-J ~~ 1 1 Mech. CH Caliper Survey 1 Rpt or 2 Color Signed: "".~~ ~ ~ ~ ~ ->-- /r'" ~ RECEIVED Date: Print Name: ~'Þ.R 2 2 2004 Alaska Oil & Gas Cons. ComniIIion Anchorage PRoACTivE DiAGNOSTic SERviCES, INC., PO Box 1 }69 STAffoRd IX 77477 Phone:(28l) 565-9085 Fax:(28l) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com ~~~'(\\~ ARCO Alaska, Inc./'1[ Post Office Bo~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 18, 1990 Mr. L. C. Smith, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Attached in triplicate are multiple Applications for Sundry Approvals on the fOllowing Kuparuk wells. Well 1E-11 2W-10 2W-14 Action Stimulate Other Other If you have any questions, please call me at 263-4241. Anticipated Start Date October 1990 November, 1990 November, 1990 Sincerely, P. S. White Senior Operations Engineer CC: J. R. Brandstetter ATe 1120 L. Perini ATe 1130 S. M. Renke ATe 1126 KeEl .4-9 w/o attachments ARCO Alaska, inc. is a Subsidiary of Atlar~HcRichfieldCompany ~'~ STATE OFALASKA " ~ ~'~ i ~ i t~ ~ i_ ALA~,,,A OILAND GAS CONSERVATION COMM 'ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ Plugging _ Time extension _ Stimulate X Pull tubing _ Variance _ 2. Name of Operator ~ 5. Type of Well: Development X ARCO Alaska. Inc. Exploratory _ 3. Address Stratigraphic _ P. O. BOX 100360, Anchorage, AK 99510 Service _ 4. Location of well at surface 923' FSL, 811' FEL, Sec. 16, T11N, R10E, UM At top of productive interval 1749' FNL, 1175' FWL, Sec. 16, T11N, R10E, At effective depth 1140 FNL, 638' FWL, Sec. 16, T11N, R1OE, UM At total depth 1140' FNL, 638' FWL, Sec. 16, T11N, R10E, UM 12. Present well condition summary Total Depth: measured 8754' feet Pl~C~Ored) true vertical 6 81 0' feet Perforate Other 6. Datum elevation (DF or KB) RKB 106 7. Unit or Property name t(uparuk River Unit feet 8. Well number 1E-11 9. Permit number 82-[;1 10. APl number 50-029-207~7 11. Field/Pool Kuparuk River Field ,.~,~aruk River Oil Pool Effective depth: measured 8622' feet Junk (measured) true vertical 6724' feet Casing Length Size Cemented Structural Conductor 78' 1 6" 211 Sx AS II Surface 2835' 10 3/4" 1250 Sx AS III Intermediate & 250 Sx AS II Production 8 7 2 3' 7" 1075 Sx Class G Liner Perforation depth: measured 7708'-7794', 7996'-8008', true vertical 61 50'-6202', 6326'-6333', Measured depth True ve~ical depth 78' 78' 2835' 2475' 8723' 6790' 8028'-8056', 8061'-8076' MD 6346'-6380', 6366'-6375' TVD Tubing (size, grade, and measured depth) 3 1/2" 9.3# J-55 @ 7955' Packers and SSSV (type and measured depth) Camco TRDP-1A SSSV @ 1941', Baker FHL Packer @ 7539', Baker FB-1 packer @ 7932' 13. Attachments Description summary of proposal _ Detailed operation program X~ BOP sketch Fracture A Sand 14. Estimated date for commencing operation 15. October 1~)0 Oil x 16. If proposal was verbally approved Name of approver Date approved Service 17, I he,~2.~.Kt~t t? f:7.,~ng.is true and correct to the best of my knowledge.~ Signed ~ ~/v-~, .. v--.-- ~---.. Title Senior Operations Engineer FOR COMMISSION USE ONLY Status of well classification as: Gas _ Suspended _ Date I -I' Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test _ Subsequent form require 10-~ Original Signed By David W. Johnston Approved by order of the Commission Commissioner Form 10-403 Rev 09/12/90 Approved Copy Ij:[etu~ IApproval No. Date IO SUBMIT IN TRIPLICATE 1. 2. 3. 4. 5. . 7. 8. 9. 10. 1 1. Pull standing valve. 1. 2. 3. 4. 5 6. 1E-11 Refrac Procedure Charge code: AFE K81760 Tag fill. Last tag was at 8112' with the lowest perforation at 8076'. Pull CV's at 7577', 7643' and 7910'. Replace CV's with DV's. 'l'est A sando Run 48 hour PBU with I amarada and I panex bomb. Confer with KOE before continuing with program. Pull GLV's at 1988°, 3957', 5471', 6574', and 7499'. Run DV's in the top 4 stations then load annulus with 200 bbls of diesel. Run DV in GLM at 7499'. Insure DV's are set by pressuring 3.5" x 7" annulus to 1000 psi. Run standing valve to D Nipple at 7947' and pressure test tubing .to 2500 psi. Rig up frac equipment. Pressure annulus to 3500 psi. RECEIVED Perform onsite QC procedures. Alaska Oil & Gas Cor~s, Commi, ssi~ :Anchorage Frac well per the attached pump schedule with gelled water. Expected treating pressure is 5000 psi. Frac gradient is 0.78 psi/ff. Max treating pressure on pad is 7500 psi. Max treating pressure on proppant is 6000 psi. Shut-in well overnight and insure gel has broken. Tag fill and clean out as necessary. RetUrn well to production, increasing rate to maximum over a two-day period. Obtain a well test. 1E-11 REFRACTURE TREATMENT AFE #K81760 WELL SPECIFICATIONS Wellhead GLM's GLM's (~) C (1") Packer (Baker FH) Packer (Baker FB) "NOGO" (CAMCO 'D') Tubing Tail A Sand Perforations 4 SPF Tagged Full PBTD Maximum Hole Angle Hole Angle Across Perfs Tubing Casing Flush to top of A Sand Perfs · TVD Depth to Top A Sand Perf NOTE: All Depths are MD-RKB 5000 psi MAWHP 1 941 1988', 3957', 5471', 6574, 7499 7577', 7643', 7910' 7539' 7932' 7947' 7955' 7996'-8008', 8028'-8056', 8061'-8076' 8112' 8622' 53° at 7400' 52° 3-1/2 9.21blft 7", 26.0 Ib/ft 71 bbl 6263' (1) (2) FRACTURING FLUID SPECIFICATIONS Base fluid to be clean fresh water with 2% KCl and Biocide added. Water samples to be taken from each tank prior to job and checked (actual tests will be worked out with vendor once selected). A 40# HPG fluid with a ~ Borate crosslinker is recommended. Options include: DS YF240D Halliburton Hybor BJ Titan Terra Frac RXL II B or Terra Frac II R-4 Anchorage STAGE -FLUID DESCRIPTION 1E-11 Refrac Pump Schedule CLEAN VOLUME PUMP RATE PROP. CONC. PROPP~ PROPPANT WT ~-'_S ~'~,,t PPG DESCRIPTION DIRTY VOLUME S'rG/OUM HIT PERFS BBI. S _ GW PRE PAD 150.0 25 0 150 150 71 Shut down for ISIP GW PAD 800.0 2 5 0 GW w/2 PPG 45.9 2 5 2 GW wi4 PPG 42.5 25 4 GW wi6 PPG 47.5 2 5 6 GW wi8 PPG 51.8 2 5 8 GW wi10 PPG 41.6 25 10 GW w112 PPG 32.7 26 12 G_n FLI. JC~ 69.0 +SV 2 5 0 TOTAL DIESEL IN PAD = TOTAL GELLED WATER = TOTAL GELLED DIESEL FOR FLUSH = 44,4 BEllS, 1167.6 ~ 69.0 BBLS +SV NOTES: Stage2 through 4 are gelled water with 5% Diesels .- 0 12/18 M CARBO-LITE 3860 12/18 M CARBO-LITE 7141 12/18 M CARBO-LITE 11958 12/18 M CARBO-LITE 17389 12/18 M CARBO-LITE i 7491 12/18 M CAI:lBO-LIfE 16483 -- 0 12/18 M CAREK)-U-I~. - 74,322 LB6 [ · 800 I 950 50 I 1000 50 11050 60 I 1110 70 I 1180 60 I 1240 50 / 1290 69 I 1359 10;t · 1071 1121 1181 1251 1311 13~61~ Stage 2 is gelled water with 40lbs/1000 gal silica flour. Stages2 through 8 are Gelled Water with enough breaker for an 8 hour break. . , . Stage 9 should include a volume adjustment for surface equipment between the ~ead ~ dmlMmMM,lind Io~ tmnpmature breaker (6 hour b~ This job is intentionally underflushed by 2 bbls. The Mender tub should be by~ , All water-basad fluids should be maintained at 90~ Fee the surface. Diesel should be maintained at 70° to. 90° F on the surl ~ace. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor (.~\ DATE: July 11, 2002 Chair SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder Phillips Alaska P.I. Supervisor t_.~ O'''~ 1 E Pad 1E-11,1E-13,1E-15,1E-27 FROM: John Crisp Kuparuk River Field Petroleum Inspector Kuparuk River Unit NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. ] we,,] 1E-11 IType,nj.I s I T.V.D. 16020 I TUbingl 2400 12400 12400 12340 linterVa, i 4 ] ,,iP.T.D.I 1820510 ITypetestl , P Imestpsil 1505 I CasingI 2175I 2850 12820I 2800 I P/F I -PI Notes: 1 bbl. pumped for test pressure. / WellI 1E-13 I Typelnj. I N I T.V.D. I 6000 [Tubing I 1225 I "i225 I 1225 I 1225 J lntervalI 4 ~ '"P,T.D,I 1820780 ITypetestl P' ITestpsil 1523' I Casingl 0 1:'1830 I 1778 I. '176° I P/F I P| Notes: 5 bbls, pumped for test pressure, / WellI 1E-15 I Typelnj, I N I T.V,D. 16066 I Tubing I 1350 I 1050 11350 11350I,.terV~,l 4 I ' P.T.D.I 1821020 ITypetestI P I Testpsil 1517 I Casing. I 1450'. I 2000' I 1970 I 1960 I PIE I -P I Notes: 5 bbls. pumped for test pressure. I '" WellI 1E-27 I Typelnj, I ' N I T.V,D, I 5088 ITUbing 12700 12700 [ 2700 1"2700 I lntervall 4 ' P.T.O.I 1821100 ITypetestl P ITestpsi, I 1500 ICaSingl '1300 1'2280~:,il 2260 I 2260 I P/F I P-- Notes: 1/2 bbl. pumped for test pressure, " WellI I Type Inj, P,T,D, I Type test Notes: Type INJ. Fluid Codes F = FRESH WATER IN J. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P- Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details 4 MIT's performed, no failures witnessed. Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'S performed: 4 Attachments: Number of Failures: _0 Total Time during tests: 4 hrs. cc: MIT report form 5/12/00 L.G. MIT PAl 1Eb 07-11-02jc,xls 7/24/2002 STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK Operation Shutdown~ Stimulate ~ Plugging Pull tubing Alter casing Repair well 5. Type of Well: Development __ Exploratory Stratigraphic 99510 Service X 4. Location of well at surface 923' FSL, 811' FEL, Sec. 16, T11N, R10E, UM At top of productive interval 1749' FNL, 1175' FWL, Sec. 16, T11N, R10E, UM At effective depth 1219' FNL, 700' FWL, Sec. 16, T11N, R10E, UM At total depth 1140' FNL, 638' FWL, Sec. 16, T11N, R10E, UM 12. Present well condition summary Total Depth: Perforate Other X 6. Datum elevation (DF or KB) RKB 106 7. Unit or Property name Kuparuk River Unit 8. Well number 1E-11 9. Permit number/approval number 82-51/96-083 10. APl number 5o-029-20787 11. Field/Pool Kuparuk River Field/Oil Pool feet measured 8754 feet Plugs (measured) None true vertical 6810 feet ORIGINAL Effective depth: measured 8622 feet true vertical 6742 feet Junk (measured) Vann Gun @ 8149' Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 7 8' 1 6" 211 SX AS II 7 8' 7 8' Surface 2802' 10 3/4" 1250 SX AS III & 2835' 2475' Intermediate 250 SX AS II Production 8 6 9 2' 7" 1075 SX Class G 8 7 2 3' 6 7 9 0' Liner Perforation depth: measured 7708'-7794', 7996'-8008', 8028'-8056', 8061 '-8076' true vertical 6150'-6202', 6326'-6333', 6346'-6380', 6366'-6375' Tubing (size, grade, and measured depth) 3.5", 9.2#, J-55 @ 7892' Packers and SSSV (type and measured depth) PKR: Baker FB-I@ 7932', Baker FHL@ 7537', Baker HB@ 7471'; SSSV: Carnl~l~11~l~ rt~952' 3. Stimulation or cement squeeze summary Converted oil producer to WAG injector. ~' Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 14. 0CT 1 5 1996 Naska 011 & Sas Cons. Commission Representative Daily Avera.qe Production or Iniection Data Jl~uragu OiI-Bbl Gas-Md Water-Bbl ,Casing Pressure Tubing Pressure Prior to well operation 175 100 1400 980 130 Subsequent to operation 0 0 600 1250 2400 15. Attachments Wellbore schematic Copies of Logs and Surveys run ~ Daily Report of Well Operations __ 16. Status of well classification as: Oil Gas Suspended __ Service WAG Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~,,Z~.,~,~,~~ Title Wells Superintendent Form 1/~'~04 he~"o6/15'f~ ,/ Date _/~ .~.y~"~'~ SUBMIT IN DUPLICATE ARCO Al~=Ka,( Inc. Kuparuk Operations Post Office Box 196105 Anchorage, Alaska 99519-6105 Clint Chapman Engineering Technician Kuparuk Wells Team NSK-69 Phone: 659-7285 Fax: 659-7314 April 12, 1996 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached are sundry approval applications for conversion of 1 F-16, and 1 E-11 from production to water injection. These items are being faxed to enable the approval process to get a quick start as the Drillsite engineer is most anxious to start getting water in the ground. Original signed documents are being sent thru the mail and should arrive in a few days. If additional information is needed, please call, Sincerely, Clint Chapman RECEIVED ,APR 1 5 1996 Al~,ska Oil & (~as Cons. Commission · Anchorage ARCO Alaska. Inc. is a Subsidiary of Atlantic Richfield Company 1. Type of Request: 2. Name of Operator ^ co. ,ss, APPLICATION FOR SUNDRY APPROVALS Abandon_ Suspend _ Operation Shutdown _ Re-enter suspended well Alter casing _ Repair well Plugging _ Time extension Stimulate Change approved program X Pull tubing _ 5. Type of Well: Development ARCO Alaska. Inc. Exploratory 3, Address I Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510I Service 4. Location of well at surface 923' FSL, 811' FEL, Sec. 16, T11N, R10E, UM Variance Perforate Other 6. Datum elevation (DF or KB) RKB 105,7 7. Unit or Property name Kuparuk River Unit 8. Well number 1E-11 feet At top of productive interval 1749' FNL, 1175' FWL, Sec. 16, T11N, R10E, At effective depth 1219' FNL, 700' FWL, Sec. 16, T11N, R10E, UM At total depth 1.140' FNL~ 638' FWL,.Sec. 16, T11N~ R10E~ UM 12. Present well condition summary Total Depth: measured 8 7 5 4 feet true vertical 6810 feet 9. Permit number 83~5.1 ,~10. APl number 50-029-20787 , 11, Field/Pool <uparuk River Field / Oil Pool Plugs (measured) None Effective depth: measured 8 6 2 2 feet true vertical 6 7 2 4 feet Junk (measured) Top of Vann Gun @ 8149' Casing Length Size Structural Conductor 7 8' 1 6" Surface 2 83 5' 1 0- 3 / 4" Intermediate Production 8723' 7" Liner Perforation depth: measured 7708'-7794', true vertical 6150'-6202', Cemented Measured depth True vertical depth 211 Sx AS II 78' 78' 1250 Sx AS III & 2835' 2475' 250 SX ASll 1075 Sx Class G 8 72 3' 6 79 0' 8061'-8076' 6366'-6375' 7996'-8008', 6326'-633.3', 8028'-8056', 6346'-6363', Tubing (size, grade, and measured depth) 3.5", 9.2#, J-55 @ 7955' Packers and SSSV (type and measured depth) Pkr' Baker FB-1 @ 7932', Baker FHL @ 7537', Baker HB @ ~471'; SSSV: Camco TRDP-1A @ 1952'... :13, Attachments Description summary of proposal ~ Detailed operation program _ BOP sketch _ Convert oil producer to water injector. 14. Estimated date for commencing operation 115, Status of well classification as: May 1, 1996 I Oil w Gas~ Suspended._ 16. If proposal was verbally approved Name of approver Date approved 117' '1 hereby Certify fi)at ihe' i0regoin_g is true'and "correct t° ti'{e b~st' of my knowledge. Si~lned' Title Wells Superintendent FOR COMMISSION USE ONLY ..Service_Water In!ect0.r ....... ..... Dar.e. ~-~///'///~' ~- Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Location clearance Mechanical Integrity Test ,~ Subsequent form require Approved by order of the Commission oaglnal Signed By David W. Johnston Form 10-403 Rev 06/15/88 IApprovaJ No. 10-~ed Copy APR 1 5 1996 Alsska 0il & Gas Cons. Commission Anchorage Attachment 1 Conversion to Water Iniection Kuparuk Well 1E-11 ARCO Alaska requests approval to convert Well 1E-11 from an oil producer to a water iniector. This well wilt be operated as a Class ii UIC well in compliance with Area Iniection Order No. 2. Water will be iniected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 6150' and 6375' TVD. This interval correlates with the strata found in ARCO's West Sak River State Welt No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this iniection order. A Mechanical integrity Test will be pedormed before iniection 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. In addition to the technical data provided on Form 10-403, please note that two cement squeezes have been performed on this well. The specifics of these squeezes are listed below: 5/7/82 7674'-7676' 10/17~84 7910'-7912' ~ze VOlume 41 bbls Class G 200 Sx ClasS G RECEIVED APR 1 ~ !996 Alaska Oil & (~s Cons, OommJssJor~ 1. Operations Performed: 2. Name of Operator J.. '" STATE OF ALASKA OIL AND GAS ~RVATION COM ON REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Other 5. Type of Well' 6. Datum elevation (DF or KB) ARCO Alaska. Ino, 3. Address P. O. Box 100360, Anchorage, AK 99510 Development ~X Exploratory _ Stratigraphic _ __ Location of well at surface 923' FSL, 811' FEL, Sec. 16, T11N, R10E, UM At top of productive interval 1749' FNL, 1175' FWL, Sec. 16, T11N, R10E, UM At effective depth 1140' FNL, 638' FWL, Sec. 16, T11N, R10E, UM At total depth 1140' FNLr 638' FWL~ Sec. 16r T11N~ R10E~ UM 12. Present well condition summary Total Depth: measured true vertical 8 754 feet 6 81 0 feet RKB 106 7. Unit or Property name Kuparuk River Unit 8. Well number 1E-11 9. Permit number/approval number 82-51/90-791 10. APl number 50-029-20787 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None I feet Effective depth: measured 8 62 2 true vertical6742 feet feet Junk (measured) Vann Gun @ 8149' Casing Length Size Structural Conductor 7 8' 1 6" Surface 283 5' 10 Intermediate Production 86 9 3' 7" Liner Perforation depth: measured 7708'-7794', true vertical 6150'-6202', 3/4" Cemented 211 SX AS II 1250 SX AS III & 250 SX AS II 1075 SX Class G 7996'-8008', 6326'-6333', 8028'-8056', 6346'-6380', Tubing (size, grade, and measured depth) 3.5", 9.2#, J-55 @ 7892' Packers and SSSV (type and measured depth) PKR: Baker FHL ~ 7499'; S$SV: Camco TRDP-1A @ 1902' 13. Stimulation or cement squeeze summary Refractured "A" sand on 4/30/91. Intervals treated (measured) "A" Sand @ 7980'-8156'. Treatment description including volumes used and final pressure 14. Measureddepth 78' 2835' 8723' True vertical depth 78' 2475' 6790' 8061 '-8076' 6366'-6375' RECEIVED &las~_..0il & Gas Cons. CommissiOn ~ncho.rage Frac - pumped 76,700 lbs of 12/18 carbolite and 1645 Bbls of fluid; 3400 psi on 7". Reoresentative Daily Average Production or In!ection Dat.~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 175 1 00 1400 1400 200 Subsequent to operation 15, Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 1100 1200 100 1000 140 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Title SUBMIT IN DUPLICATE ARCO Alaska, Inc. % WELL SERVICE REPORT Sub$i(lil~/of ~ Atl.ntJc Richfield Comp~ ( DISTRICT- STA.~, DAYS [DATE [OPERATION AT RE~~[~~.~ Report 'F 'F miles · knots iSign,d ~ff~Oii.otu". ~,Tl~,tl0l'8.0~8 ....... ' MEMORAI ,.)UM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO: Lonnie C. Smi~~~ Commissioner DATE: April 25, 1991 FILE NO: LG4 2 5- 2 TELEPHONE NO: THRU: FROM: Louis R. Grimaldi ~~ Petroleum Inspector SUBJECT: BOP Test ARCO KRU 1g-ll Kuparuk Rv Unit Workover Wednesday 4/3/91: I witnessed a BOP test on Nordic Rig #1 Performing a w0~kover on well #1E-11 for ARCO CPF#I in the Kuparuk River Field.. The test went well with no failures. The rig crew gave me the impression that they performed these tests almost daily (Note: Every member of the crew knew the procedure). The Nordic rig is one of the older rigs operating but its equipment is kept in top shape and the hands take pride in this fact. In summary: I was impressed by the results of the BOP test. There were no failures and Nordic rig #1 is in good shape for the workover. *It should b~",~ffed that the blowdown line far exceeds API RP53 requirements. Attachment. 02-001A (Rev. 6/89) 20/11/MEMOl.PM3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CONHISSION BOPE Inspection Report' DATE Reserve pit Audio I HUD SYSTEHS~ Trip tank V~/~I Pit gauge Flow monitor Gas detectors BOPE STACK~ Annular preventer.., Ptpe rams Blind rams ~ Choke line valves , , , HCR valve KII1 ltne valves Check valve Test Pressure TEST~ Int tlal.~:' #eekly , 'Other Permtt I~ ~'~'~'"', ~' / TEST RESULTS~ Casing set @ // Rep, J-g~3~ ~'~--~)~ ACcuHu~TOR SYSTB4 ~ Full charge pressure..., Press after closure ps' ps¸ Pump Incr clos press 200 pstg min Full charge press attained ./ , mln (~ Controls~ Haster Remote ~*'Bltnd switch cover KELLY AND FLOOR SAFETY VALVES t Upper Kelly · Lower Kelly Ball type Inside BOP Choke manifold Number valves Test pressure Test pressure Test pressure Test pressure Test pressure Number flanges ..~C~ , AdJus. table chokes , / Hydrau!ically operated choke / Failures (~ Test time / //~ hrs/ Repair or replacement of failed equipment to be made wlthtn / days. Notify the Inspector, and follow with wrltten/FAXed verification to Commission office. Distrlbutlon~ orlg - AOGCC c - Operator c - Supervisor C.OOq (rev O5/IO/90) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing . Alter casing Stimulate X Plugging Perforate _ Repair well Other 2. Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 923' FSL, 811' FEL, Sec. 16, T11N, R10E, UM At top of productive interval 1749' FNL, 1175' FWL, Sec. 16, T11N, R10E, UM At effective depth 1140' FNL, 638' FWL, Sec. 16, T11N, R10E, UM At total depth 1140' FNL~ 638' FWL~ Sec. 16~ T11N~ R10E~ UM 12. Present well condition summary Total Depth: measured 8 75 4' feet true vertical 6810' feet Plugs (measured) 6. Datum elevation (DF or KB) 106' RKB 7. Unit or Property name Kuparuk River Unit [eet 8. Well number 1E-11 Produ(~er 9. Permit number/approval number 82-51 /~' -~11 .~ ~-?~1 10. APl number 50-029-20787 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 8 6 2 2' feet true vertical 6724' feet Junk (measured) Casing Length Size Structural Conductor 78' 1 6" Surface 283 5' 10 Intermediate Production 8723' 7" Liner Perforation depth: measured 7708'-7794', true vertical 3/4" Cemented Measured depth True vertical depth 211 Sx AS II 78' 78' 1250 Sx AS III & 2835' 2475' 250 Sx AS II 1075 Sx Class G 8 72 3' 6 79 0' 7996'-8008', 8028'-8056', 6150'-6202' 6326'-6333' 6346'-6360', 6366'-6375'~. Tubing (size, grade, and measured depth) ' ' .~l~,~. ~~j~V ~ ~-t ],~,,~] 3 1/2", 9.3#, J-55, @ 7955' I Packers and SSSV (type and measured depth) · · ~'- '..~ .~a$ CoJ~& ~~ef~m iCamco TRDP-1A SSSV @ 1941'~ Baker FHL Packer @ 7539'~ Baker FB-1 Packer at~'~C~01a~ ~ '~'~ 13. Stimulation or cement squeeze summary Intervals treated (measured) 7708'-7794' Treatment description including volumes used and final pressure 80 bbl 12% HCL, Shut in press 750 psi 14. Reoresentative Daily Average Production or In!ectiorl Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 450 230 20 900 20O Subsequent to operation 550 230 20 800 120 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run~ Water Injector ~ Daily Report of Well Operations X.. Oil . X... Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 Service SUBMIT IN DUPLICATE ARCO Alaska, Inc, Subsidiary of Atlantic Richfield Company · WELL /E-// CONTRACTOR REMARKS .... WELL SERVICE REPORT iPBDT I FIELD- DISTRICT- STATE IOPEfiATi'O~I AT REPORT :rIME IDAYS } 1DATE I -Pot H '7'- KUPARUK OPERATIONS ENGINEERING I-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ' JTemp'chill FactOr i vlslbilityReport 'F .... 'F! miles J Wind Vel. ARCO Alaska, Subsidiary of Atlantic Richfield Company WELL PBDT I FIELD - DISTRICT- STATE /E -// I - / ,r'd~°,,~,~'~,K' CONTRACTOR/,~/.,~iX/,E-) (~~ /~~~PERATION AT RE~RT TiME REMARKS WELL SERVICE REPORT /0oo /4_/5' CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WELL 1E 11 APl 1~. SPUD DATE:, ORIGINAL RI<B: AIX ~ PERMIT I: .. COI41~..E~ DATE: 05/1~ WORKOVER DATE: 8~I:IF~ LOC, A~ 9~3'F~ll'~le,TllN~1~ TOP OF IOJP~ 174~1175'F~SEC16,TllN,R10E TI) LOCATION: 1140'FNLa3rFWI.,SEC16,T11N,R10E 10~ ~ ~POOL: 35 PAD ELEVATION: 72 SIZE WEIGI.fl' GRADE TOP BTM VALVE PORT '!'t 19~1~!~.; 1" 0.187GLV a ~ 1- o.1 _at6Lv ,-~ ~ 1" 0.1a7GLV 4 667'4 1" 0.187GLV 7#t 1" 0.ta7GLV i ~ 1 ' .CV ~-- 7'.~ 71#, 1". .tV t 7910 1 · .CV TUBING JEWELRY TYPE. 113' DEFrH C.M4CX3TFE)I~IA Ul~' I~, BAKER FI.I 753~ · MI~. DATA DESCRIPTION KICK OFF I:<)INT: MAX HOU= ANGLE: ~ TAG DATE: 12/0~ 17 It V~NG~ OEPTH 8149 8622 6618 PEFIFOFIATION DATA I~VAL ZONE FT SPF 770t-7794 C 86 4 7996-8008___ A 12 8 6O26,6O66 A 28 8 8Q61-6079 A 15 8 PHASE COMMENTS REPERFED2-1-t REPERFED2-1-t REPERFED2-14 Alaska Oil & Gas Anchorage REVISION DATE: 05/16/89 REASON: O,t8. t. I1~? I. tNE M'IJ efllll : "" ..... ,G~-'w,r,---' LOQ. L~. gQ. It 1.~)000PS1?" W[LLHF, AD GONNCC'I'OR FLANG£ :2. ~)000PSIWtR£LtN£ RAIDS ,3. 5000 PS14 1/6" LUBRICATOR 4.5000 PSi4 1/6" FLOW 1UB£ p,.cK-orr 2 HIREL,,,I,NE BOP EOUIPHENT ARCO Alaska, Ir(r' Pos! Oflic~ *r~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 8, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 'Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatlerton: Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well Action ^rlticipated Start Date 2 X- 1 2 Scale Sqz. June, 1989 2A- 1 5 Scale Sqz. June, 1989 2A-09 Scale Sqz. July, 1989 3 H- 0 3 Acidize June, 1989 3 H- 1 4 Acidize June, 1989 2 U - 1 2 ' Scale Sqz. June, 1989 2 W- 0 7 Scale Sqz. June, 1989 3 J- 0 6 Fracture June, 1989 3 J - 0 2 Fracture June, 1989 3A- 1 0 Perforate June, 1989 1 E- 0 6 Acidize June, 1989 tE-11 Acidize June, 1989 1 E- 1 5 Acidize June, 1989 If you have any questions, please call me at 265-6840. Sincerely, G. B. Smallwood Senior Operations Engineer ARCO Alaska, Inc. is a Subsidiary o! AllanlicRichlieldCompany RECEIVED ! 1989 ;AJaska.OJl & Gas Cons. Commission '~ .~chorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Alter casing _ Change approved program _ 2. Name of Operator ARCO Alaska. In{;, 3. Address Suspend _ Operation Shutdown Repair well _ P. O. Box 100360, Anchorage, AK 99510 Plugging _ Pull tubing _ 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 923' FSL, 811' FEL, Sec. 16, T11N, R10E, UM At top of productive interval 1749' FNL, 1175' FWL, Sec. 16, T11N, R10E, UM At effective depth 1140' FNL, 638' FWL, Sec.16, T11N, R10E, UM At total depth 1140' FNL~ 638' FWL~ Sec.16~ T11N~ R10E~ UM 12. Present well condition summary Total Depth: measured 8754 feet true vertical 6810 feet _ Re-enter suspended well _ Time extension _ Stimulate ~ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) Plugs (measured) RKB 106 7. Unit or Property name Kuparuk River Unit feet 8. Well number.~ 1E-11 [/~ 9. Permit number 82-51 10. APl number $0-029-20787 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured 8622 feet Junk (measured) true vertical 6724 feet Casing Length Structural Conductor 7 8' Su dace 2 8 3 5' Intermediate Production 8 7 2 3' Liner Perforation depth: measured 7708'-7794', true vertical 61 50'-6202', Size Cemented 16" 211 SxASII 10 3/4" 1250 Sx AS III & 250 Sx AS II 7" 1075 Sx Class G Measured depth True vertical depth 78' 78' 283 5' 2475' 8723' 6790' 7996'-8008', 6326'-6333', 8028'-8056', 8061'-8076'M D 6346'-6380', 6366'-6375' TVD Tubing (size, grade, and measured depth 3 1/2" 9.3# J-55 @ 7955' Packers and SSSV (type and measured depth) Camco TRDP-1A SSSV @ 1941'~ Baker FHL Packer@ 7539', Baker FB-1 packer @ 7932' i'3. Attachments Description summary of proposal X Detailed operation program _ X BOP sketch 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil _~X Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~42-~t/~ .~_)~-~~i,e Senior Operations EnginoOrFoR COMMISSiON USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test m Subsequent form require Approved b)/ the order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH IApproval No. ?....,_~_.// ' .kpp~'.oveC~ Copy a,e Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE Well 1 E-11 C Sand Acid Treatment General Descri.Dtion: Well 1E-11 is currently a combined A and C Sand oil producer. Proposed downhole stimulation work will reduce near wellbore damage to increase well productivity from the C Sand. The proposed work will utilize a pump truck, coiled tubing and surface lines to spot the acid across the C Sand perforations. The surface lines will be pressure tested to 4000 psi against 5000 psi tree valves. The static bottomhole pressure around Well 1E-11 is estimated to be 3000 psi at 6200'SS (combined A & C Sands) based on wellhead pressures and fluid levels taken in offset wells. Procedure Blank off A Sand: 1. MIRU Slickline. Pressure test lubricator. 2. RIH with blanking plug. Set in NOGO at 7947 FT MD-RKB. 3. POOH and RDMO Slickline. Open well to production. 4. Allow stabilization and obtain C Sand only test. Acidize C Sand: 1. MIRU CTU, Transports, Nitrogen, and Pumps. Pressure test equipment. 2. Titrate 12% HCL(10% < HCL<14% Acceptable). Obtain sample from tanks for total iron analysis. 3. RIH with CTU to 7575 FT MD-RKB and spot 10 BBLS diesel, 5 BBLS straight acid, and 80 BBLS nitrified acid across circulating valves. A. Pump 10 barrels diesel. B. Pump 5 barrels straight acid. C. Pump remaining 80 BBLS nitrified acid at a rate of 1.0 BPM. (1) Nitrify with 200 SCF per BBL nitrogen. 4. Displace with 5 BBLS diesel and purge coiled tubing with nitrogen. 5. Immediately return well to production. Nitrogen lift if necessary. A. Operations Engineering should take the following flowback samples. ( 1 ) After first spent acid passes sample point. (2) At midpoint of spent acid passing sample point. ( 3 ) After final spent acid passes sample point. B. Samples should be analyzed for concentration of total iron, and PH. Send results to Jay Stratton. 6. RDMO CTU, Transports, Nitrogen, and Pumps. 7. Allow stabilization and obtain a C Sand only test. Ooen A Sand 1. MIRU Slickline. Pressure test lubricator. 2. RIH and pull blanking plug in NOGO at 7947 FT MD-RKB. 3. POOH and RDMO Slickline. Open well to production. 4. Allow stabilization and obtain A/C test. 6 5 4 3 2 1. 5000 PSI ?" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PiPE RAIDS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS. 4, 5000 PSI 4 1/6" SHEAR RAIDS 5, 5000 PSI 4 1/6" BLIND RAIDS 6. 5000 PSi 4 1/16" STUFFING BOX CO]LED TUB UN,, ,] T BOP iiiii ii iiiii iii EOU]PHENT STATE Of ALASKA ~ ALASKA ~i'_ AND GAS CONSERVATION CO( ,/IlSSION , WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS I'-I SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO A1 aska, Inc. 82-51 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20787 4. Location of well at surface 9. Unit or Lease Name 923' FSL, 811' FEL, Sec.16, TllN, R10E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1749' FNL, 1175' FWL, Sec.16, TllN, R10E, UM 1E-11 At Total Depth 11. Field and Pool 1140' FNL, 638' FWL, Sec.16, 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 105.7' RKBI ADL 25651, ALK 469 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 04/21/82 05/03/82 05/10/82 N/A feet MS LI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8754'MD,6810'TVD 8622'MD,6724'TVD YES [] NO [] 1902 feet MDI 1900' (Approx) .. 22. Type Electric or Other Logs Run D IL/SP/GR/SFL/FDC/CNL/Cal , Gyro/CBL, GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 78' 24" 211 sx AS I I 10-3/4" 45.5# K-55 Surf 2835' 13-1/2" 1250 sx AS Iii & 250's) ~AS II. 7" 26.0# K-55 Surf 8723' 8-3/4" 1075 sx Class G · 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) 'SIZE DEPTH SET (MD) PACKER SET (MD) 7708' - 7794't ' 3-i/2" 7955' 7932' & 7~00' 7996' - 8008' ~/4 spf 8028' - 8056'/ 26. ACID, FRACTURE, CEMENTSOUEEZE,ETc. 8061' - 8076' DEPTH INTERVAL. (MD) AMOUNT& KIND OF MATERIAL USED , 7674' - 7676' 41 bbl Class C crn~ (4 spf ) 7910' - 7912' 200 sx C~._=ss C (4 spf) .' 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-QILRATIO TEST PERIOD II~ I Flow Tubing Casing Pressure CALCULATED .1~ 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 , ~s~a Oit & 6~s Cons. C0m~ts~,e~ GRU 3/WC32 ATtchol'a..ge Form 10-407 Submit in duplicatE~ Rev. 7-1-80 CONTINUED ON REVERSE SIDE 1~ 29. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand 30. GEOLOGIC MARKERS MEAS. DEPTH 7706' 7826' 7980' 8156' TRUE VERT. DEPTH 6148' 6221' 6315' 6424' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Wnrl~nver We!,l, Hi sf_ory 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10407 ARCO Oil and Gas Company ( Well History - Initial Report - Daily Inatructiona: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to Spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk Auth. or W.O. no. ICounty. parish or borough North Slope Borough ILaaseADL #25651 or Unit ITitle Completion State Alaska Pool 102 AP1 50-029-20787 Operator ARCO Alaska, Inc. Spudded or W.O. begun IDate Complete I Date and depth as of 8:00 a.m. 10/12/8/+ 10/13/84 10/14/84 10115184 10/16/84 10/17/84 10/18/84 Complete record for each day reported 2100 Hrs. JHour 10/11/82 ARCO W.I. · 56 24I Prior status if a W.O. 7" @ 8723' 8622' PBTD, Kill well 9.9 ppg NaClg/NaBr Accept ri~ @'2100 hfs, 10/11/82. 7" @ 8723' 8622' PBTD, Well SI 9.9 ppg NaC1 Prep, to kill well. RU BJ, pmp 60 bbls CaClg/carbonate pill. Kill well. RU & displ ann w/brine; pmp turbo charge~ caught fire. SI well. Damage confined to #2 pmp engine. 7" @ 8723' 8622' PBTD, Tst BOPE 9.9 ppg NaC1 Observe well. RU & displ well dn 7" x 3½" ann out 3½" tbg. Spot 50 bbl CaCi? carbonate pill & bullhead into formation. tree, NU & tst BOPE. ND 7" @ 8723' 8622' PBTD, Chg tbg colrs 9.9 ppg NaC1 Tst BOPE. Pull tbg hsr. Mod. POOH, chg tbg colts to 3½" BTC AB 7" @ 8622' 8149' Top of Vann .gun, POOH w/pkr 9.9 ppg NaC1 PU Bkr retrv'g tl, RIH, unseat pkr, circ out gas, POOH w/pkr. 7" @ 8622' 8149' Top of Vann gun, Prep f/sqz 9.9 ppg NaC1 LD pkr. RU DA, make GR/JB rns. PU BP, RIH, set @ 7975'. RIH w/perf gun, perf 7910'-7912' @ 4 SPF. RIH w/CR, set @ 7825', RD DA. RIH w/stab-in on DP. RU BJ f/sqz. 7" @ 8622' 8149' Top of Vann gun, DO cmt 9.9 ppg NaC1 Pmp 200 sx C1 "G" w/.4% D-22 & .1% D-6 w/final rate psi. Pull out of. retnr, rev circ, CBU, POOH & ~ to DO cmt. The above is correct S,gnatu For form p~'ep~ration and distribu~on see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date ] Title 3/16/87 Drilling Supervisor ARCO Oil and Gas Company Daily Well History--Interim Instructio.s: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work pedormed. Number ail drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strinG until completion. District Field Alaska North Slope Borough IState Alaska Kuparuk Date and del3th as of 8:00 a.m. County or Parish Lease or Unit ADL #25651 Complete record for each day while drilling or workover in progress Well no. 1E-11 10/19/84 lO/2O/84 10/21/84 10/22/84 10/23/84 10/24/84 The above is correct 7" @ 8149' 8149' PBTD, LD scrprs 9.9 ppg NaC1 DO CR & BP. RIH to PBTD, chase BP, CBU, POOH, LD DD. RIH w/7" csg scrprs & boot bskts to 8149', circ. Displ well over to cln fluid; no fluid loss. POOH, LD scrprs. 7" @ 8149' 8149' PBTD, Chg wellhead 9.9 ppg NaC1 RIH w/RTTS to 7577', set & tst 7" csg to 3000 psi; OK. RIH & set RTTS @ 79', tst "A" sand to 1100 psi; press drop to 800 psi/10 min. Rel RTTS, POOH. RIH w/BP, set & tst csg to 1000 psi, POOH w/DP. Chg wellhead to 5000 psi equip. 7" @ 8149' 8149' ?BTD, RIH w/GR/JB 9.9 ppg NaC1 Tst BOPE. RIH, tst 7" csg to 3500 psi; OK. RIH below BP, CBU, POOH, LD DP; BP not on retrv'g tl. RU DA & RIH w/GR/JB. 7" @ 8149' 8149' PBTD, POOH, LD DP 9.9 ppg NaC1 RIH, locate BP @ 2585', chase plug dnhole to 7102', tls stopped. POOH, RD DA. RIH w/DP to 7160', set BP. Rel plug, pull up hole 60', set & rel plug. POOH w/BP to 3150', set & rel BP. POOH, did not get BP. RIH w/retrv'g tl, POOH w/BP. 7" @ 8149' 8149' PBTD, Kill well 9.9 ppg NaCl Fin POOH, LD DP. RU DA, make GR/JB rn. 7932' WLM. RIH w/compl string. RIH w/FB-1 pkr, set @ 7" @ 8149' 8149' PBTD Vann Guns, Set BPV Diese;cride Rn 3½", 9.2#, J-55 BTC AB-Mod tbg w/tail @ 7955', FHL pkr @ 7500', FB-1 pkr @ 7932' WLM & SSSV @ 1902'. ND BOPE. NU & tst tree; OK. Displ well w/30 bbls diesel & 220 bbls crude. RU to set BPV. see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate ITitle 3/16/87 ARCO Oil and Gas Company Daily Well History-Final Report I m Instructions: Prepare and submit the "Final Rel3ort" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ~County or Parish I Alaska Field ~Lease or Unit I Kuparuk Auth. or W.O. no. I Title Accounting cost center code State North Slope Borough Alaska l Well no. ADL #25651 I 1E-11 Completion Pool 102 API 50-029-20787 Operator IA.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun ~Date Complete [ 2100 Hrs. I otal number of wells (active or inactive) on this cst center prior to plugging and ~ bandonment of this well I our I Prior status if a W.O. I 10/11/82 Date and depth as of 8:00 a.m. lO/25/84 Complete record for each day reported 7" @ 8149' 8149' PBTD Vann Guns Crude Set BPV. RR @ 0300 hfs, 10/25/84. Old TD Released rig 0300 Hfs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data JNew TD Date I PB Depth Kind of rig 10/25/84 Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands 8149' Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO ALaska, In(/r'~ Post Office 8ox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 8/3U/~5 TkANSMITTAL NO: 5234A TO: A,<CO ALASKa, INC. KUPARUK t~PEkATIOh$ ENGINL~:~tING RECORDS CLERK ATO- 1115$ P.O. BOX 100360 ANCI~JkAGE, AK 99510 TItANSHITTLD lii~REWITn ~%ltlj 'l']~E FOLLOWIN(J ITEMb. RECEIPT AND RETUI~I4 ONE SIGNLD COPY OF SEwUENCE OF EVENTS 1G-4 PI{ESSURE- DATA 1F-2 PRESSU~{E DATA 17'-4 PRESSURE DATA 1F-S PRESSURE DATA 1F-7 PRESSURE DATA I ["- 5 PRESSURE DATA IF-7' P~ESSURE DATA 1 i"- 3 P~ESSUhE DATA 1g-ll PREbSUHU DATA I~-6 P~IEU5 UHE DATA IS-5 PRLGSU ItU DATA !g-ll PREbSU~ DATA -U-5 PRESSURE DATA - A bAND PUU - FALLOFF C bAND - A SAND PI~U - PUU COblCINED PLEASE ACKi~ OWLEDGE THIS TRANSMITTAL. 4127/85 3/ 8/85 1/22/85 1/22/85 /2 /85 4/21/85 4/21/~5 4/21/85 31 8/s5 5/ 7/85 4/27/85 31 /3o/ 5 CEIPT ACKNOWLEDGLD: ~VkON x- ~ bl.~' DRILLING blOB I L" N~K CLEkK DISTtilI~UT1ON: W. PAbHER LXXO[~ PHILLIPS OIL ~ J. kATHMELL ^ STATE O[" ALASKA SOHIO ~ UNION ~- K. TULIN/VAULT RETURN ,TO: DATE: 06-19-85 TRANSMITTAL NO: 5230 PAGE 1 OF 2 ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO- 1 ! 15B P.O. 'BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HERE%4ITH .ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AMD RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. SEQUENCE OF EVENTS FROM WELL SERVICE REPORTS PRESSURE, FLUID, AND ACID lB-1 SBHP 0 lB-2 SBHP- 0 lB-4 SBHP 0 lB-4 PRE-WORKOVER 0 ID-8 SBHP 0 1E-lA TUBING LEAK 0 1E-5 COMP PBU ETC. 0 DATA (ONE COPY OF EACH) 5-3 0-85 CAMCO 5-30-85 CAMCO 5-16- 8 5 CAMCO 5-24 -85 CAMCO 4-2 9-85 CAMCO 5-03 -85 CAMCO 4-28-8 5 CAMCO 1E-tl LEUTERT BI{ SMPL 06-02-85 OTIS 1E-23 SBHP 05-22-85 CAMCO !E-23 SBHP 05-23-85 CAMCO iE-27 TEMP/SPIN-LEAK 05-03-85 CAMCO 1E-27 TUBING LEAK 05-04-85 CAMCO 1G-6 PRESSURE FALL- 05-0 7-8 5 CAMCO OFF 1H-6 SBHP 04-2 9-8 5 CAMCO 1L-5 PBU W/E-LINE 04-27-85 CAMCO 1L-5 PBU 04-29-85 CAMCO lQ-1 ISIP 05-30-85 B.J.HUGHES !Q-! SBHP 'A'~DS 05-26-85 CAMCO !Q-3 TAG FILL BHP 05 -18 -85 CAMCO iQ-4 SBHP 'C' SD ETC 05-10-85 CAMCO lQ-4 SBHP ETC 05-14-85 CAMCO lQ-4 ACID JOB 05-17-85 NOWSCO/B . J. HUGHES lQ-5 ISIP. 'ZEST 04-29-85 B.J. HUGHES lQ-7 ACID JOB 05-26-85 NOWSCO/DOWELL !Q-9 'C' SD PBU 05-12-85 CAMCO !Q-9 PBU 'C'SD ETC 05-13-85 CAMCO 1Y-12 FALL-OFF TEST 05-05-85 CAMCO 2A-2 BHP 05-27-85 OTIS 2A-4 '~ ' ~' ..~ SD BHP 05-10-o5 CAMCO 2A-4 'A'SD BHP 05-09-85 CAMCO 2A-4 'A'SD BHP 05-11-85 CAMCO 2A-5 SBHP 05-0 5-8 5 CAMCO ***CONTINUED ON THE FOLLOWING PAGE*** _RECEIPT ACKNOWLEDGED: ~ g/S~fl{ IB UT ION: BPAE* DRILLING W. PASHER B. CURRIER L. JOHNSTON EXXON CHEVRON* MOBIL* PHILLIPS OIL* D & M.~' NSK CLERK J. P~ATHMELL4~ .,~ ~. 5-- ~' DATE: ".%~-'STATE OF ALASKA~ SOHIO* . UNION* K ~r~z z~'~/VAULT ARCO A{aska, inc. is a Subsidiary of AtlerHicRichfieldCompany ARCO Alaska, Inc Post Offic:~ ~ 10036(~ * Anchorage; ,.~laska 99510-0360 Telephone 907 276 1215 DATE: APRIL ~'~ t985 TRANSMITTAL NO' ~-t48 n'~TL!RN TO' ARCO A ^ ° 'A: I L.,-~ !'-. NC ATTN: RECORDE CLERK AT.r.!--1 t t 5B F'.O. BOY i 0C:,S6C:, ¢",NC:HORAC-,.E, Al'..'. 9'95' t 'l"l"::.,'.'t-~.!,'.'..'..i"iI'FT~: .... HE:.F:,'I::'I.JT-' r:'_ ..... ' "", ' "" ' ........ I,--i Al-"(,_ THE F'OI_I..Fil.d]:U. 6 I'f'Er'l,~ FI_E.~-i,~E AC, I( WL_E. DGE I::F.(..*.EZF'T AND RE:TUF..:N ONE ,."7. IGHED COPY OF TI-IIZ TRANSMI'FTAL. ,:OE, IN"f'IERMITTIENT LIFT F'RE_'.?.~UF;:E ,'::'..OE,."F'RC)D I_OG & 'A' S'AND F'I--'~LJ JC).F:,/F'BU (I,,I.,.TIA-L F'F,'.ES'S'I. JF:.'E) ,~OE/F'[-:U £OE,;F'BU ,~ C). E/F'F:U ~OIE/'C' $~N:. F'F;LI ~OE/~'BI--IF' - 'A' & 'C' SAND~ ~TATIC BHF' DATA STATIC BHP DATA ~TATIC BHF' DATA ~TATIC BHP DATA ~TATIC BI-.iF' DATA 5'TATIC BHF' DATA ..~T,..,TICBHF' DATA :~TAT:[C BHF' DATA ~'FATZ~ BHP D~T~ ~TATIC BHF' DATA 5'TATIC :.:,~'I'IP DATA cSTATZC BHF' DATA ,~TATZC BHF, DATA '~ ~F' 37TATZC B,'-, DATA 5:TAT~C,~.~BI'IP ....f~ATA ,~TATZC BHF' DATA gTAT~C BHP DATA ,~TATZC BHF' DATA ~:TATZC BHF' D~TA ,~TATZC BHF' DATA Y!'~TIC BI-IP DATA ~TATZC BHF' D~TA .S'URVEY T u T .T. 0i 7 - F.~. ' '~. ~'-~E DF, tILLING W F'AS'HER "'.' C.t.!RRIER L ,n,..,,,.~ -.'"Tn X~ EX,,ON *-' ~. ~ <.i ~,.~l I1'~} t~.--II.. '-. .h,=VF:ON NO[-:Z L F'HZLLIPS' OI'L ::? .'% H F,!.~K CLERK J, RATHHE"LL ARCO Alaska, Inc. is a Subsidiary of AllanlicR|cfllleldCompany 416-7/85 ],/t t/85 ,. 2/26/85 .. ¥12/85 3/~/85 ~/',!/85 ~/t ~,/85 t/24/85 t/24/8~, S/~/85 ~/2/85 ~/2/85 ~i2185 S/t 9/85 ~/24 f ,/.24/~5 ~ _,~ ~, _ t/3t t/t t t/24/85 t/2., f/20/85 RECEIVED APR 2 5 1985 Alaska Oil & Gas Cons. Co~missjon DATE' Anch°r~c ~ OF AI~ U N I 0 N K.T~LIN/VAULT ARcO Alaska, .... inc.[~'~ Post Olfice 100360 AnchOrage, Alaska 99510-0360 Telephone 907 276 1215 i":'.:,' [: {ii :' ~ '"" :, ~_ :--:.~ I( A, ][ h! C: · ., i:-~ T'"" i'~ "' ....... '; , · - r,, ,:: L, 0 i", I, S' C L. IE I:;; I( Fi'¥ {] .... i 1,-i .['~ ~.'.' · , r', ,-; 'r-, ;', ,,., ~ '.," ~., F;~ , ,..,, .',:',u,,. t Ot .... , ..... . · · I l ..............l 'T' I':' [" , I:;:. I .; I:. !-,J ]. I 1--I ~ R 1]~. T I"1F:' F:' f'~ l... I... n'... ,.~,~ T N F;;E;'[i. IF:,'N ()iq["' :.~ Z (;Nil.{) COI::'Y ., (~ STATE OF ALASKA ~' ALASKA OIL AND GAS CONSERVATION C MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL []X OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 923' FSL, 811' FEL, SEC. 16, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 105.7' (RKB) 12. 7. Permit No. 82-51 8. APl Number 50- 029-20787 9. Unit or Lease Name KUPARUK RIVER 10. Well Number 1E-11 11. Field and Pool KUPARUK RIVER 6. Lease Designation and Serial No. K U P A R U K R I V E R ADL 25651, ALK 469 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data UNIT FIELD OIL NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations EX 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 February 1, 1985, the "A" sands of Kuparuk well 1E-11 were re-perforated. After testing the lubricator to 2500 psi, the was shot with a wireline conveyed gun. Interval (MD)' 7996-8008' (4SPF) 8028-8056' 8061-8076' well RECEIVED 14. I hereby certify that the foregoing is true and correct to the best of my ~(nov~l~e~jK Signed /~,d/~,~~/_.,l..~ Title 0 P E R A T I 0 N S The space below for Commission use COORDINATOR 3/28/85 Date 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, I,~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 1, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached in duplicate are subsequent notices following wells at the Kuparuk River Field: on the Well 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 / 13 / 85 1E-20 Stress Frac 3/19/85 1E-20 Fracture 3/23/85 1E-22 Fracture 3 / 22 / 85 1E-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 Conver s i on 3 / 12 / 85 2A-5 Conve rs i on 3 / 12 / 85 2A-6 Conver s i on 3 / 12 / 85 2A-7 Convers i on 3 / 12 / 85 2C-4 Reper f 2 / 23 / 85 2D-4 Reper f 2 / 2 / 85 2V-8A Convers i on 2X-8 Per fora t i on 1 / 27 / 85 If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany ~ .... STATE OF ALASKA (~ ALASKA OIL AND GAS CONSERVATION C MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 82-51 3. Address 8. APl Number P. 0. BOX 100360, ANCHORAGE, 99510 50-029-20787 ALASKA 4. Location of Well SURFACE LOCATION' 923' FSL, 811' FEL, SEC. 16, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 105.7' (RKB) 12. 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1E-11 11. Field and Pool KUPARUK 6. Lease Designation and Serial No. KU P A R U K ADL 25651, ALK 469 P00I 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 I--I' Alter Casing [] Perforations L~J 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 February 7, 1985, 'the "A" sands of Kuparuk well 1E-11 were hydraulically fractured and propped to improve production. The treatment consisted of 300 BBLS of gelled water as pad and carrying fluid and 14,910 LBS of 12/20 sand as proppant. 51 BBLS of gelled diesel was used as a flush. Prior to pumping, equipment and lines were tested to 5920 psi. RECEIVED A R :$ !9 8 5 Anchora(je 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _ . j Title 0 P [ R ^1 1 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, Ir~' Post Offic'~ Jox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 ~. C t:)F' Y !:) F' ARCO Alaska, In . Post Office Box 1479 Anchorage, Alaska 99510 Telephone 907 277 5637 January 25, 1985 Mr. C. V. Chatte Alaska Oil and G 3001 Porcupine D Anchorage, AK rton, Chairman as Conservation rive 99501 Dear Mr. Chatterton' Attached are ou Field well 1E-7 1E-20. If you have any Commission r notices of intention to fracture Kuparuk and re-perforate wells 1E-7, 1E-8, 1E-11 and questions, please call me at 263-4253. Mike L. Laue KuParuk Operations Coordinator MLL/kmc Attachment (In Triplicate) t? ECEI VED JAIV 2 5 1985 Alaska Oil &.Gaf Cons. Commission ~nChorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA IL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 923' FSL, 811' FEL, SEC. 16, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 105,7' (RKB) 12. 7. Permit No. 82-51 8. APl Number 50- 029-20787 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1E-11 11. Field and Pool KUPARUK RIVER FIELD 6. Lease Designation and Serial No. KU P A R U K R I V E R 01 L ADI 25651: ALK 469 P001 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 X~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "A" sand in Kuparuk well 1E-11 be re-perforated to enhance subsequent stimilation. Procedures call the well to be perforated with a wireline conveyed gun under a lubricator. for Proposed Intervals (MD). 7996'-8008' (4 SPF) 8028'-8056' 8061 '-8076' ANTICIPATED START DATE. January 28, 1985 14. I hereby certify that the foregoing, is true and correct to the best of my knowledge. Signed ~ J Title OPERATIONS. COORDINATOR The space below for Commission use 1/25/85 Date Conditions of Approval, if any: Approved by COMMISSIONER Returnea} By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate J ARCO Alaska, Inc. [ Post Office BOx 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 2, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 1E-11 Dear Mr. Chatterton' Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU3/L27 Enclosures If RECEIVED JAN 0 9 1885 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA (' ALASKA OIL AN.D GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Na~)f Ogera~or h'l asKa, Inc. 3. Ad~l.res~. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 923' FSL, 811' FEL, Sec.16, T11N, R10E, UH 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 105.7' RKB ADL 25651 ALK 469 12. 7. Permit No. 82-51 8. APl Number 50-- 029-20787 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1E-11 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 ~ 2100 hrs, 10/11/84. Killed well. Set BPV. ND tree. NU BOPE & tstd to 3000 psi - ok. Pullec tubing hanger and tubing. Retrieved pkr. Set bridge plug ~ 7975'. Perf'd 7910' - 7912' w/4 spf. Set cmt retainer ~ 7825'. Pumped & squeezed 200 sx Class G cmt. Drld cmt, retainer and bridge plug. Set RTTS and tstd 7" csg to 3000 psi - ok. Set RTTS ~ 79'. Pressured "A" Sand to 1100 psi - dropped to 800 psi in 10 minutes (no returns from 3-1/2" x 7" annulus). Tstd 7" csg to 3500 psi - ok. RIH & set FB-1 pkr ~ 7932'WLM. Ran 3-1/2" completion assy w/tail ~ 7955', FHL pkr ~ 7500' & SSSV @ 1902'. Set pkr. ND BOPE. NU tree & tstd - ok. Disp well w/30 bbls diesel & 220 bbls crude. Set BPV. Secured well & released rig ~ 0300 hrs, 10/25/84. RECEIVED N 0 9 1985 Alaska 0il & Gas Cons. Commission Anchorage 14. i hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,I~('~~/ ~/_)~' Title Associate Engineer The space belov~ for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Form 10-403 GRU3/SN08 Rev. 7-1-80 Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate /~RCO Ataska, tn~:' '~ post Otfice~ ~.~0 borage, Alasga 99510 ~elep.v,. November 13, 1984 V. chatterton' chairman' Mr. C. oil and Gas conservation Commissl°n AlaSka 3001 porcupine Drive .Anchorage ' AK 99501 Dear Mr. Chattert°n: are our notices of intention to fracture Attached Field wells: follOwing KuparU;E_5' 1E-8, 1E-11, 1E-18' .questlonS please call me at 263-4253' KuparUk operations coord~nat°r MLL/kmc Attachment (In Triplicate) the RECEIVED NOV Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska- thC* is a subSldlafY ot At~'antlcRtchlleidC°mpan¥ '~,'~ STATE OF ALASKA ~f ALAS OILAND GAS CONSERVATION ~MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL IJ( OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 82-51 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-20787 4. Location of Well SURFACE LOCATION: 923' FSL, TllN, R10E, UM 811' FEL, SEC. 16, 5. Elevation in feet (indicate KB, DF, etc.) 105.7' (RKB) 12. I6. Lease Designation and Serial No. ADL 25651, ALK 469 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1E-11 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 [~X Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that~the "A" sand in Kuparuk well 1E-11 be hydraulically fractured and propped to improve production. The treatment uses gelled water as the pad and carrying fluid and 12/20 sand as the proppant. Lines and equipment will be pressure tested to 5000 psi prior to starting job. Pre-post frac logs are included in the treatment program. Fluid: Gelled Water 363 BBLS Gelled Diesel 51 BBLS 12/20 Sand 14,910 LBS RECEIVED NOV ! Proppant: ANTICIPATED START DATE: November 16, 1984 Alaska 0i~ & Gas 00ns. Commission Anchorag~ 9.~~t Work R~~ 14. I h is true and corroct to the best of KUPARUK 11/13/84 '[~, ~-~'~~ OPE~TIONS COORDINATOR Date Signed Title The spac~ ~ommission use Conditions of Approval, if any: .Approved ~eturne~ By Order of COMMISSIONER the Commission Approved by Form 10-403 Rev. 7-1-80 Submit "Intentions" ir] Triplicate and "Subsequent Reports" ir] Duplicate ARCO Alaska, ~ Post Offk,,. c~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 28, 1984 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 1E-11 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. We propose to convert 1E-11 to a selective single completion. Since we expect to start this work on October 4, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. c~rely, dBK/d~/tw GRU1/L65 Enclosures RECE]VED Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATIO MISSION SUNDRY NOTICES AND REPORTS ON WELLS 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: 923' FSL, 811' FEL, Sec.16, T11N, R10E, UN 7. Permit No. 82-51 8. APl Number 50-- 029-20787 9. Unit or Lease Name 10. Well Number 1E-11 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 105.7' I ADL 25651 ALK 469 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing I--] 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). ARCO Alaska, Inc., proposes to convert well 1E-11 to a selective single completion. The procedure will be as follows: 1. Well will be killed w/brine. Weight to be determined after running pressure bomb. 2. Current completion assembly will be pulled. 3. A cement squeeze will be performed to provide zone isolation between A & C Sand. 4. A retrievable Packer will be run to test casing integrity. 5. The well will be completed as a selective single and 5000# wellhead equipment will be installed. RECEIVED P 8 1984 Alaska 0il & Gas Cons. Anchorage 6. 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 uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: October 4, 1984 14. I hereby~y ~hat the foregoing is true and correct t0 the be~.f /Z ~~~ Title Area Drilling Engineer S ioned k The spac~o~or ~mission use Condit~ns ~ Approval, if any: Date Approved by Returnea/ By Order of COMMISSIONER the Commission Date Form 10-403 GRU1/SN63 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office"~r 360 Anchorage, ~k._ ska 99510 Telephone 907 277 5637 November 22, 1982 C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Please find attached the well completion reports for the following producing/injecting wells: 1B-9GI 1H-3 1B-10GI 1H-4 1B-11GI 1H-6 1E-11 1H-7 1E-14 1H-8 1E-15 Very truly yours, Area Operations Engineer slz Attachment cc: L. M. Sellers E. A. Simonsen R. L. Stramp H. C. Vickers AN0-332 W/attachments AFA-311 w/attachments AST-308 w/attachments AFA-326 w/o attachments ARCO Alaska. Inc, is a Subsidiary of AtlanticRichfieldCompany WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~( GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 8Z-51 3. Address 8. APl Number P.0.Box 360, Anchorage, AK 99510 50- 029-20787 4. Location of well at surface ~23: FSL~ 8]]: FEL, Sec 'i6~ I'I'IN~ H'IUI-~ UM 9. Unit or Lease Name Kuparuk River Unih AtTopRroducinglnterval 1749' FNL, 1175' FWL, See 16, T11N, RIOE, UM lO. WellNumber 1E-11 At Total Depth 1140' FNL, 638' FWL, Sec 16, T11N, RIOE, UM 11. Field and Rool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 105.7' RKBI ADL 25651 ALK 469 Kuparuk River Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore I 16. No. of Completions 4/21/82 5/3/82 5/10/82~ N/A feetMSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth v~here SSSV set I 21. Thickness of Permafrost 875/*' 6810' 8622' 6724' YESI-~ NO[]I 2077' feetMDI 1900' (approx) 22. Type Electric or Other Logs Run DIL/SP/GR/SFL/FDC/CNL/Cal, Gyro/CaL, GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD ' CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD /~ AMOUNT PULLED 16" 62.5# H-40 Surf 78' 24" 211 sx AS II¢c~Xe ' 10 3/4" 45.5# K-55 SUrf 2835' 13 1/2" 1250 sx AS III AS II 7" 26# K-55 Surf 87.23' 8 3/4" ..1.075 sx Class , Inent 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) 7708-7794' 3 1/2" 7631' 7571' 7996-8008' '. [ 8028-8056' w/4 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8061-8076, DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 76'74-7676 .. 11 bbl ClaSs G Cemenf-"" ,: . . · , · ., 27. PRODUCTION TLS'T ' ' ' Date· Fi.rst Production Method of Operation (Flowing, gas lift, etc.) ' - F1o in ' .~. , : .. 5/18/82 I w g .... Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAs-OIL RATIO 5/17/82 ' 15.4 TESTPERIOD ~ '3.78.3 2~2 48/64 Flow Tubing. Casing PreSsure CALCULAT..ED O'I-L-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 175 24-HOURRATEI1~!," 604 '". · . , · .-- " 356: : -- ::22,4 28. COP E DATA , -Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A "' ':Y':' "'" : '"" ' " : · · Alaska Oil&" ' ~, , - ' ':, ..' .. , . ~as Con°. C0r~r~ts$~0r~ ·: ,... , . Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk N/A River Form 7706' 6148' · I! Base Kuparuk River Form· 8155' 6425' 31. LIST OF ATTACHMENTS N/A 32. I hereby certify that the foregoing is true and correct to the best of my knowledge S,gned ~.~.~~~'~ T,t.eArea 0ps' En§r' Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (Where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item .16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item lB, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. item 28: If no cores taken, indicate "none". Form 10-407 William VanAlen D. W. Bose/Lorie L. Johnson Transmitted her~eith are the following: PLWASE NOTE:~~F_ FILM, T- TAPE, PC- PHfTICCOPY RSEEIPT ACKhKYWI,~DGED: LEASERE%tIRN RECEIPT TO: ARCO ALASKA, INC. A%TN: LORIE. L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK. 99510 KUPARUK ENGINEERING TO: Transmitted herewith are the following: PLEASE NOTE: F - FILM, T - TAPE · RECE I~~KNOWLEDGED: P~ASE RETURN RECEIPT TO: DATE: Alaska 0il & Gas Cons. Commission .ARCO ALASKA, INC. Anchorage ATTN: LORIE T,. JOHNSON - AFA/31]L P. O. BOX 360 ANCHORAGE, AK 99510 ARCO Alaska, Inc. Post Office Bc .~0 Anchorage, Alaska 99510 Telephone 907 ~!77 June 8, 1982 v Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for May on these drill sites' 1-9 13-26 2-21 14-17 2-22 14-22 2-24 15-5 13-21 15-6 13-22 1H-6 13-24 1E-12 Also enclosed is a well completion report for Kuparuk 1E-11. Sincerely, P. A. Van Dusen Regional Drilling Engineer PAV/JG'llm Enclosures GRU1/Li$ RE£EIVED Alaska Oil & Gas COns 4nchorag~ C°m,~ission ARCO Alaska. h~ i~ ,* r.,*b-,i(linry of AllanlicRichli,.ldConlpany ALAS ~,,_AND GAS CONSERVATION ~ ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well · OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator ' 7. Permit Number ARCO /Ltaska, Inc 82-51 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 50_029-20787 4. Location of well at ~urface ~.'~:· 9. Unit or Lease Name 923' FSL, 811' FEL, Sec. 16, T11N, RIOE, UNIL~"~"v'~'-;I VE~tF~O i Kuparuk River Field At Top Producing IntervalI ~-----'1 ~Surf ~,_ ~' [ 10. Well Number 1749'At TotaIFNL'Depth 1175' FWL, Sec. 16, T11N, R10E, UH.t~lh'.?'. F~__~__J_.__. 1E-11 11. Field and Pool 1140' FNL, 638' FWL, Sec. 16, T11N, RIOE, UH Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 105.7' RKBI ADL 25651 ALK /469 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 04/21/82 05/0:~/82 05/10/82I 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 -8754~MD, 6810'TVD 8622'MD, 6724'TVD YESK--'] NO[]I 2077' feetMD 1900' (approx) 22. Type Electric or Other Logs Run DIL/SP/GR/SFL/FDC/CNL/Cal, Gyro/CBL, GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SUrf 7'8'· 2.zm 211 sx AS ]:! · 10-:~/4" 45.5# K-55 Surf 28:~5' '1:~-1/2" 1250 sx AS ]:TI & 250 sx AS ]:T 7" " 26.0# K-55 Surf' 872:~' .'8-:~/4" 1075 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and .25. TUBING RECORD · ,,ipterval, size and numbe~) ' ' ' SIZE DEPTH SET (MD) PACKER SET (MD) 7708'-7794', :~-1/2" 76:~1' 7571 ' 7996' -8008' 8028' -8056' w/4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8061 '-8076' ' ' 767'4~'-'7676' ' 41 'bbl Class G Cmt , (4 spt) 27. ~T/A ' ' ' PRODUCTION TEST· I Date First Production Method of Operation (Flowing, gas lift, etc.) DateofTest Hours Tested PRODUCTION FOR OIL-DEL GAS-McF WATER-DEL : cHOKEsIzE I GAs-oILRATIO T, EST PERIOD I~I ' Flow ~ubing' Casing Pressure' CA·LCU?~,TED,..~ oIL.-BBL GAS-~MCF, WATER:-BBL OIL GRAVITY-APl (corri · 24,,Ho0'R ,RATE · 28. " ' ' CORE DATA"' ,, , .. · Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. , -,' ',' ,. RECEIVED None · '"' : " '" " ' " JUN -91982 · :, Gas Cons. Commission Alaska Oil & Anchorage Form 10-407 GPU7/Al/2/:~ Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 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 7706' 6148' N/A Base Upper Sand 7826' 6221' Top Lower Sand 7980' 6315' Base Lower Sand 8156' 642fl' ., 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 /Z-f/ Title Sr. Drillinq Enq.r Date --./ /._.. /v _ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this. well is completed for separate production from more than~one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 DS 1E-11 Drilling History NU hydril & diverter. Spudded well @ 2330 hrs, 04/21/82. Drld 13-1/2" hole to 2855'. Ran 70 jts 10-3/4" 45.5#/ft, K-55, csg w/shoe @ 2835'. Cmtd 10-3/4" csg w/1250 sx Arctic Set III & 250 sx Arctic Set II. ND hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 EMW - ok. Chg over to polymer mud. Drld 8-3/4" hole to 8401'. Ran DIL/SP/GR SFL/FDC/CNL/Cal. Cont drlg 8-3/4" hole to 8754' TD (05/03/82). Ran 210 jts 7", 26#/ft, K-55 BTC csg w/shoe @ 8723'. Wellbore packed off. Worked csg w/o returns. Performed leakoff tst: @ 1450 psi well broke back to 1350 & took fluid @ i BPM; @ 1600 psi well taking fluid @ 4 BPM. Cmtd 7" csg w/1075 sx Class G cmt. Instld 7" packoff & tstd to 3000 psi - ok. Drld cmt to 8622' PBTD. Tstd csg to 1500 psi - ok. Ran Gyro/CBL. Perf'd 7674'-7676' w/4 SPF - 90° phasing. Set retainer @ 7531'. Press. ann to 1000 psi - tstd lines to 3000 psi - ok. Mix 41 bbl slurry @ 15.8 ppg Class G, yield = 1.15. Squeeze. Final squeeze press = 1400 psi. Drld cmt, retainer & more cmt to 7681'. Tstd csg to 1000 psi - ok. Disp well to NaC1/NaBr. Ran 3-1/2" perf completion assy w/tail @ 7631' & pkr @ 7571'. Ran GR/CCL. Tstd tbg hanger & packoff to 3000 psi. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well to diesel. Tstd 3-1/2" x 7" annulus to 1500 psi - ok. Fired guns. Dropped ball & set pkr. Instld tree cap & tstd to 3000 psi - ok. Set SSSV @ 2077'. Secured well & released rig @ 2400 hrs, 05/10/82. 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''i ~ i i ~:' : : 'e~: ''~' :i i i ileali i~ii~ ~ iii i ill!~i !~i i ~ ~ i ~ ::'~i~i ' ' ~ ;~1''~i!!i~ ~:' !'ii''!;: '' ~:~i~ i i i "'ii' !~! ~i]~ ~i i ~ ~ ii ~ii~ ~i ~'' ~:~'~i' ~ ~ ~!~i:''' ~::' '~iii ~ i ~''~i~ ' ~i ~!i ;] i ~ i ~ ~ ! ~ ~ ~ ¢ ~ i ~ i ~ i~ i i~&'' ~ ! !'"! ~ "~ i ~ ~ ~'~i i ~ ~ i~ ~i~il] ~ ~ ] ~ ; ~ ~i~i] ~ ~ ~ ~ ~ ~ ~! ~ i~ ~ii~ ~' ''"':~ ~ i ~ ~::~ ::*"~ !~ i~ ~ i ~ ~ ~ ~ ~ il ~ ~ ~ ~ Jill! ~ ~ iii ~ 3545 30()6, C~O 2?/00,00 687.27 N 1415, 30 W 53'~'. 71 3682 3;I. 06,,00 3000.00 727.22 N 1499,87 W 576,67 :¢:~;:;;~:;::;:~;:;~:;~;¢~;:~;~;~¢:~;;~::~:~;:::::~::~;~::¢:;~;~;:~:~¢::~¢~:~¢~;~¢~ .:,:.:.:.:;:;.:.:.:;,:.:;;.:.:.~;(~:.~:.~:;~:.:(~:~.:.:.:.:::.....:.:::;:.:.:.:.:.:;:.::.::..;;;.:::.:;;:.::::::~;~:.~:;::::=================================================2:.;:;;~.;`:;~:.~;:~.:::::::::::::::::::::::::::;;.;.~;;;;%.:;;;.:;.:.%.:;;;;;;`.~ .................................... ~..::.....::..~:.~::.., ...................... · .............. ~:~ ................. .:::~:.:.:~ ................. ~:::::::-.:~ .............. ::.:::~::::~%.~ ............ I ............................... ::::::::::::::::::::::::::::::::::::: ~.::~:.:;::::::~ ..................................... ~:~ ................ ~: ~::-:::::~::::~: · ............. ...... ................ .......... ........ ....... .......... ....................... ................ ........ ......................... ............ 433() 3606.00 3500, 00 ' lO0'~', 49 N t795, 25 W 724, 68 ,::, 4--,. W 7._ .~., c, ~ 44 ........ :~ :::: :~ 7¢~6 ,, 00 ~:6o¢~... O0 ~ 072, 2 ~ .N ~ '-' ~: .:,'-'r.~ 9'~ SF"'EF~RY-'-SUN WELL .S;URVEYINr~ COMF'ANY PAGE'~ 7 ANCHORAGE ALASI<A ARCO AI._A.::,I-,..~,,.~:, INK:. DATE' Ot:.- SURVE-"V MAY · -. -. ,'. -' ~ r~...... ,. · .... , , ........ , ........... :u.:~.~....:...~...~ .......... ~.., .. -, · .=. .... ~. ~...... . ...--.. -. -.....~ .~..~...........:~-.,x~..,:~:.:..:~,.......~ :.......~...........-:.....~ ......... - .............................................. I NTERF'OI..,ATED VALLE.::, FOR EVEN 100 FEET OF SUB-SEA [EF IH 4587 :380/_-,. 00 3700.00 11 :::4. '.-]5 N 1 :i:':'P5.40 W 781.14 28.24 .................................. ............. !5:225 4306.00 4200.00 I441.1/=, N 214/.-,. 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OC}. 2140 .1/=,. N 286:2 .7.'_-] W l'--'z- ":'= _,.,=. 46, :::A .79 "~ SF'ERR ' '"'II' ~ ~ ~ .... .:,..N WELL SLIRVEYING COMF'ANY PAGE ANCHORAGE ALASKA ARCO AI_..A:E;I'::;~., INC,, DATE OF SURVEY MAY 6 1c'-''''' , . - ¢ .::; .~:~:. :.;;~ :::: .. :~;~ .~ ::~:::.: .'~ :.::;:; ~ · ;,- (.'% j.~:::. ::':::;::::::: ~';~'~" ';] :"~ !'~[ '~ ~[[~'~'~'[~'[i'~'~]';~]~7' :~ ? ~ ' -:~": ~' ~ :" '" '"~": '"'"' '"." ~ .-~ ................. [:'[" ............. i':'x'''' :~;~:..~,~].]~i~.:~K~??~]~????~v.~v~.~v~..~:~h~':~?K~Lv~?~??L~?~v~?~?i~:~??~K~i~Lv~i~:~v:~v~v~ ~iv~?~v:~v:~:~:v~h~::v~.~:~:v~:L:~L~v~v?~h~??~v~v~:hv~v~v~:;?:~:~:~;~]~ ~;:;~;:~¢~:~?;.:~t~;;;t~;:;~::~:~;~::~;;~;~;~:~::~;~:;;~i~i;~:~:~i~:::~:~:~;~?~i~:~:~:~:~:~:i::~i~i~i~:i:~:~;:~:~:;:~:i::i~:i~i~:~:i::~:i~:i::;~::~:i~:~::~:i::;;~:i::~:~:~i~;~:~i~':::::::::::::::::::::::::~:::~:::~:~:::::::::~::::::::~::::~:~::~::::~:~:::::~:::~:~:~::~:~::;:~::::::~::~::~::~:;~:~:~:::~:~::~:~:::~::~:~::~::~:~:~::~:~:~:~:~:~;:::~:~:~:~::::~:~:~:~::~:~:~:~:~:~:~:~:~:~:~:~:~::~:~:::~:~::~;~:~:~:~::;:~:~::~:~;:~:~:~:::~:~:~:~:~:~:~]:~i:~:;.~¢'K~:~::~:~:~i~::Z:~;~:~:~::::~:;;~:C~:pl ............................................................................................................................................... INTERPOLATED VALLIE.:, FL R EVEN I FEET .:,LB-::,EA DEPTH Lil:::.t"' I I'1 l..IL':.l-' I i-1 L~.I-' I I"1 I\IUIN i !'1/::;UU i I-t I:::F4::; ! / WI:::.::; ! D J. k k t:.lNb_lXlL:tr. L:LIF(I"~...L; I J.,LIN 7'.:)64 6.:,0 .:, ,, O0 6200.00 .-' 7._ 7.64 N .:,4._',4, 11 W .,", ~ ,--, : · :, -"- · -'~- -'- . ........ *, ;~- ;.".- -.'.........'t..-fi-. ........................... :?..:('~.~,~,~.-' ....... :';..-' ....... ' .'. .......... --.-.-..--..:,.-~.~.~Z-.-.'.-.-~.,-.-.-.-.~ ~.-.-.-.-..'.-'..-.-.-.-.-..-.-.-...-.-.-.-.-.-,---- :;iiiii:j iljEi~!ijl]iiiiii!!i:i]E]!iliE!ili]iiii!!!!!!i!!!!!]!~ ~;~! j;~:j:i:]~:]:i:?i:i:i:i;i:]:~:!']:J:i:i:!:!:~:!:J::;i:!:! ========================================================================================================================================================================================================================================================================================================== x<<+:,/+ ?'~xccc<~c::~<+ x<<:>xxx;x::p:~::: '--' ~;::[ '"" '1 ,.. 7 .... "--' c:, 7 .... 4. 6 c, C 9 ......., .'.'5 7 /-, 7 (/;':: ~;"' ..:, ..'. :16, o..:,'-' '-' lq ..:, o ._','-"-'"' 1 SF"E:IRF:W-'"SUN WE'LL SL.II::~VEYIIqG COI'iI-:-'ANV :PAGE"? ANL. I.-IUR~L E AL_A. SKA .=, .IR ~ E ~ P'IA Y 6 19:i3'2 ARCO ALASKA~ IhlE:. DATE OF '"'1" · ' , · --, .......................... i" ;" ~ · -~ .................. '"'."-'"'"."'"'"".' .................................. ~- ........ : ......... ~ · ' · ':: ':~ .~ -. 4; ~. -...:.:.:... z-. -.:.. :~ ..--~...;,:... :.:..:.:.:.:.:.~:.:..: ............. ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::: ::.:;::.::::::;::::-::: ::: :::::::::::::::::::::::::::::::::::::::::::::: Llk'b_..l~¢--I I L,If(--L4f-4b.N I '--' "' '" .=,URVEY Pr]IN]':=; II',ITERF'OLA]'ED VAt_LIES FOR .:,FEU]:AL '~' -' - .. _ · ~':': :'::!~:':': ~ i':': F':':~:! :':': ~!:'i]i ~iiiiiii!H E !~ii H i:':!! :i:'~ "'"'F""! '"" :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ............................. .................................................................... ARCO ALASKA~ II\tC. ' ~ :~IE-11 (SEC16 ]'llN RIOE) MARKER ......... MEASLIRED DEPI"H I'VD THICKNESS WITH REF. TO WELLHEAD BKB BKB SLIB-SEA VERTICAL (ORIC~IN--. t~'23NSL. 81 1WEL) ................................................................................................. L.,..,..., ............................................................ : ............................................................................................................ ~-~........,.. ~ ..... ,.....]"~..'...:'..'-. ......... "'., .. ] '~. ......... r":~':. ::~ :::~"~"e~"~cf :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::~::~$$~:~]~:$~$~$$~:?~f::~::~:~N~:::~$::::~::$~:~::~::~%~$::::~::~:~;~::F~:~:~::::~::~::::::~:::~:~ F'IROM L.. INEAR EXTRAPOL. A]".101',1 BELOW DEEF-"EST STATION. '~.~.. ' I:.":I.".)MF'I..,ITI:i:~F;~ PRI.-JI]~R~M ::!;i::'El::d'q;Y '""1 - R~4[ ILl:::; OF CLIRVA]"L.IRE .:,_IN THREE DIMEN:--:IONAL "] . :i :::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::i:::::::~:~-:: :~: :~:::~:::i:~:::i:::.:~:::::::::::::::::::~:::::::::::::::::::~::::::::::::::::::::::::~::::::::::::::::::::::~:::::::::~:::::::::::~:::::~:~:~:~:::[:~:::~:::~:::::::~:~:~:::~:~:::i:~:::::[:~:~:~:[:~:~:~:~:~:~:~:~:~:~:~:[:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:i:~:~:~:~:~:i:~:~:~:~:~:~:~:~:~:~:~:~:~:~:i:i:~:~:~:~:~:~:[:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:i:~:~:[:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:[:~:~:~:~:~:~:~:~:~:~:~:~:~:~:[:~:~:~:~:~:~:~:~:~:~:~:~:[:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:i:~:~:~:~:~:~:~:~:[:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:i:~:~:~:~:~:~:i:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:i:~:~:~:~:~:~:~:~:~:~:~:~:~:::::~:~:~:~:~:~:~:~:~:~:~:~:~:::~:::~:~:~:~:~:::::::::::::::::::::: LIN i b_ l_ll- ::;IJHVL~Y COMI::'I...II"~T I ON DAI'E IdAY /:,~ 19i':32 JOB NUMBER ........................................................................................................................................................................... :-.-.--.-'....:: .............. '~: '~'T.:'... '..-.-~- ~......-:~ '. j+~' .-'..~.' ' :..-. ..... ';:~.'... '~'..- ......... ,,~,~...: ........ : ....... :? .~ ..... "~.~, ~..~ .................................................................................. 8754 TflQE NORTH -9000.00 -2000.00 ARCO Alaska, Inc. Our Boss Gyroscopic survey ~ Job No. Boss-16017 Well: #1 E-l! (SEC16 TllN R10E) Kuparuk Field North Slope, Alaska Survey Date: May 5, 1982 Operator: Blaine Baertsch Scale: 1:~ ~,~ 10.00' 000.00 -~obo. oo -2oho. oo -] oo HOR I Z ON-T FIL Surface Location ( 811~:L) ! -1000. O0 PROJECTION C O. OO ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No., Boss-16017 Well: ~1 E-11 (SECl6 TllN RIOE) Kuparuk Field North Slope-, Alaska Survey Date: May 5, 1982 Operator: Blaine Baertsch Scale: 1" = 1500' :tSO0, O0 3000. 4500. OQ. 6000. O0 5002.71' @ N49° 58,'W 8754 7500. O0 I ~sbo. oo ~oba. oc~ ,~ba. oo 6o~a. oo VERTICRL PROJECTION suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. ' '' -OperatOr [ ~1 i ~ame "~nd ~umber Reports and Materials to be received by: Required Date Received Remarks Completion Report Yes Well History Yes _Samples ,. ..... Mud Log /'V' , , , ,, Logs Run ~--~ Yes , .... , , ,,, KUPARUK ENGINEERZNG TO: TP~.NSMITTAL ~ ~~ Transmitted herewith are the following: D. ~.[. Bose/Ann Simonsen PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE RECEIVED " '" '~ ' ' "UN- 1982 · R EIPT ACKNO¥,LEDG /~~~~ D[A.T~. ' "~ ' ' · '.: ' '. Alaska Oil & Gao Cons. Commission YP'r,~AS~ 2S~U~N ~C~[2~ ~0: '. A~CO 'A~ASXA, Z~C Anchorage ' May 26, 1982 Mr. C. V. Chatterton Commi ss i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports - Kuparuk Dear Mr. Chatterton: EnclOsed are well completion reports For the following drillsites: 1A-16A (Sidetrack) 1E-9 1E-10 Also enclosed are monthly reports For April on these wells: 1E-11 1H-5 Sincerely, P.A. Van Dusen Regional Drilling Engineer PAV/JG:llm Enclosures GRU6/B4 ' STATE OF ALASKA ALASKA ~' AND GAS CONSERVATION C(~ ....... .iSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Drilling well Workover operation [] 2. Name of operator ARCO A1 aska~ Inc. 3. Address P. O. Box 560, Anchorage, AK 4. Location of Well at surface 923' FSL, 811' 99510 FEL, Sec. 16, TllN, R10E, IB4 5. Elevation in feet (indicate KB, DF, etc.) 105.7' RKB 6. Lease Designation and Serial No. ADL 25651, ALK 469 7. Permit No. 82 -51 8. APl Number so- 029-20787 9. Unit or Lease Name Kuparuk River Field 10. Well No. 1E-l] 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool- For the Month of April ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks · .Spudded well @ 2330 hrs, 04/21/82. Drld 13-1/2" hole to 2855'; ran, cmtd & tstd 10-3/4'" csg. Drld 8-3/4" bole to 8401' as of 04/30/82. See Drilling History 13. Casing or liner run and quantities of cement, results of pressure tests 16" 62 5#/ft }~40 conductor set @ 78' Cmtd w/211 sx AS II , · ~ , · · 10-3/4" 45 5#/ft K-55 w/shoe @ 2835' Cmtd w/1250 sx AS III & 250 sx AS II , · , · See Drilling History 14. Coring resume and brief description N/^ 15. Logs run and depth where run None to date. 16. DST data, perforating data, shows of H2S, miscellaneous data D :CE!Vr:n MAY 2 6 1982 Alaska 0ii & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. -~L~ Sr. Drilling Engineer SIGNE ~~~-i~ TITLE 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 Rev. 7-1-80 DS 1E-11 Drilling History NU hydril & diverter. Spudded well ~ 2330 hrs, 04/21/82. Drld 13-1/2" hole to 2855'. 70 jts 10-3/4" 45.5#/ft, K-55, csg w/shoe ~ 2835'. Cmtd 10-3/4" esg w/1250 sx Arctic Set III & 250 sx Arctic Set II. ND hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BORE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Chg over to polymer mud. Drld 8-3/4" hole to 8401' as of 04/30/82. OG:llm 05/20/82 MAY 2 5 1982 Alaska Oil & Gas Cons. Commissior~ Anchorage GRU6/A23 KUPARUK ENGINEERING TO: D. W. Bose/Ann Simonsen Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE EIPT ACKNOWLEDGED: · PLEASE RETURN RECEIPT ~0: 2. mE I, VED D~ 0il & Gas Cons. Commiss; '- nnchbrag~ ARCO- ALASKA, INC. .ATTN: ',ANN SIMONSEN - AFA/311 P. O. BOX 360 ANCHO~GE, AK 99510 TO: TRANSMITTAL # ~ /~/~d FROM: D. W. Bose/Ann Simonsen WELL NAME Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T~ TAPE . REC. F~IPT ACKNOWLEDGED-: . '[-.-"~-'.,/:~~ ,("~",.-t_--~-/"~("/<d:-,--,,~DATE':; '.~ PLEASE RETURN. RECEIPT TO: ARCO ALASKA, INC .... ~,~:""'~'b,-, " · kTTN: ANN SIMONSEN - AFA/31 P. O. BOX 360 '~ "'%' ANCHORAGE, .' AK 99510 KUPARUK ENGINEERING TRANSMITTAL # 7//~ _ TO' William Van Allen DATE' FROM' D.W. Bose/Shelby J. Matthews WELL NAME' _~ /_Ao~~ Transmitted herewith are the following- PLEASE NOTE' BL - BLUELINE, S - SEPIA, f - FILM, T - TAPE, ~C - PHOT-~'~oPY'/ RECEI PT ACKNOWLEDGED' ~//~PLEASE RETURN RECEIPT To: DATE: ' , -~~ ARCO ALASKA, INC. ~,t~:..:~O,i ':'~ ATTN: SHELBY j. MATTHEWS AFA/311 /t~:,..=,~a ...... .~,t P.O. BOX 360 ANCHORAGE, AK. 99510 April 9, 198~ bl~. Jeffrey B. Iiewin Senior Dril ling Engineer ARCO Alaska, Inc. P, O, Box 360 Anchorage, Alaska 99510 Re: l(uparuk River Field 1B-Il ARCO Alaska, Inc. Permit No. 82-51 5Ur. Loc, 811~FEL, 925tFSL, Sec 16, T~IN, R10E, UI~. Btmhole Loc. 4$31tFEL, 41{19'FSL, See 16, TllN, R10E, Ubi. Dear ~. aewin t Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050'(b)(5). i.f available, a tape containing the digitized Icg information shall be subraitted on all logs for copying except experimental logs, velocity surveys and dipuleter surveys. Many rivers in Alaska and their drainage systerus have been e~l.asSified as important for the spawning or migration of '"anadromoua fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Attic. lc'? and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter ?0) and by the Federal Water Pollution Control Act, as amended. Prior to ccmulenctng operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded.. We would also like to be notified so that a representative of the Commission may be present to witness I~ir, Jeffrey B. li{ewin Iiuparuk River Field ll~-ll -2- April 9, 19St testing of blowout preventer equipment before surface casing shoe is drilled, In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. .Ve ~y~.., t ru 1 y your s, C. V. Chatterton Chairman of BY ORD-?-~ OF THE COM,'&iS$;ON Alaska Oil and Gas Conservation Cor~ission Eno i o sure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. C~C ~; be ARCO Alaska, Inc.B~t¢".. Post Office 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 1, 1982 Mr. C. V. Chatterton Commi ssi oner St ate of A1 aska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1E-11 Dear Mr. Chatterton: Attached are: · An application for Permit to Drill Kuparuk 1E-11, along with a $100 application fee. · A diagram showing the proposed horizontal and vertical projection of the wellbore. · An as-built drawing of "E" pad indicating the proposed surface location. · A proximity map indicating the relative location of Kuparuk wells 1E-6, 1E-8, and 1E-10. · A determination of the maximum pressure to which BOP equipment could be subjected. · A diagram and description of the surface hole diverter system. · A diagram and description of the BOP equipment. To drill this well, a letter of non-objection will be required from an offset lease owner. This letter will be forwarded to your office in the near future. If you have any questions, please call me at 263-4970. Sincerely, Sr. Drilling Engineer JBK:JO/hrl Attachments cc: Mr. Ron Podboy ~ t/~s~al,~nc, isa Subsidiary of AtlanticRichfie~dCompany RECEIVED. APR 0 J 1982 Oil & Gas Cons. AnChorage Commi,asio A(] STATE OF ALASKA ALASK tL AND GAS CONSERVATION C['.,tMISSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~ DEVELOPMENT GAS [] 2. Name of operator RECEIVED [RCO Alaska, Inc. 3. Address P. O. Box 360, Anchorage, AK 99510 APR 0 1 1982 SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [~ MULTIPLE ZONE [] I4. Location of well at surface 811' FEL, 923' FSL, Sec. 16, T11N, RiOE, UMAlaska Oil & Gas Cons. Co~ 1 ~proposed producing interval Anchorage 86~EL, 3872' FSL, Sec. 16, T11N, RiOE, UM At total depth 4331' FEL, 4319' FSL, Sec. 16, T11N, RIOE, UN 9. Unit or lease name rni~ail~ilruk River Field 10. Well number 1E-11 11. Field and pool Kuparuk River Fi eld Kuparuk River Oil Pool 5. Elevation in feet (indicate KB, DF etc.) ! 6. Lease designation and serial no. 66.7' GL, 71.7 Pad, 105.7 RKB~DL 25651, ALK 469 12. Bond information (see 20 AAC 25.025) Federal Insurance Co. Type St atewi de surety and/or number Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line ]0 Mi. NW Deadh0rse miles At surface, 811' feet 16. Proposed depth (MD & TVD) 8665' MD, 6917' TVD feet 17. Number of acres in lease 2560' 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE41 20. Anticipated pressures o (see 20 AAC 25.035 (c) (2) 15. Distance to nearest drilling or completed ~o~)well 1062' TVD, 88' ,feet 18. Approximate spud date 05-18-82 8 ;2/b4 psig@8~) ~' Surface 3165 psig@6166 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUA'NTITY OF CEMENT Hole I Weight 24 / 65# 13-1/2 45.5# 8-3/4/ 7 26# ,22. Describe proposed program: Casing 16 10-3/4 Grade I COupling H-40 IWelded K'55 /BTC[ K-55 /BTCI Length MD TOP TVD 80' 32.7' 132.7' 2819' 30 9' 130 9' 8636' I 292' ~ . 129.2' M D BOTTOM TV D 113' ', 113' 2850' i 2500' I 8665' 16917' I i (include stage data) 150 cf ~- 1150sx AS III 250sx AS II 1350sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field, Kuparuk River Oil Pool develop- ment well to approximately 8665' MD, 6917' TVD. Selected intervals will be logged. A 20" 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8" RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 3si for annular). Expected maximum surface pressure will be 2764 psig based on cooling of a gas bubble rising at constant volume. The well will be completed with 3-1/2", 9.2#, J-55 buttress tubing. Non-freezing fluids will be left in uncemented annuli through the perma- frost ~interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon conclusion of the job. 23. I hereby certify~hat the foregoing is true and correct to the best of my knowledge S,GNED ~/~_~/__~_-~t///~. ~ T,TLE Sr. Dr l g. The space bey f~/"C~c~sio-~use/ CONDITIONS OF APPROVAL Engineer DATE Samples required r-lYES i~10 Permit number APPROVED BY Form 10-401 Rev. 7-1~80 ~ Oli~d~lq Mud log required [-1YES [~L~l O Approval date .,,.~ O~/82 Directional Survey required J~ES []NO APl number 5o- SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE ~_?T"~]_ 9, 1_-_08~ ~ by order of the Commission Submit in triplicate I I WELL #8 Y 5,'960,6OOo230 X = -. 549,889.825 LAT .-- 70°18T 110283" LONG = 149°35T45o185'' #7' Y X LAT LONG #6 #5 Y X LAT LONG Y LAT LONG //4 Y X LAT LONG #3. Y · '. X = 5,960,480.368 = 549,889.4.86 = 70918' 10. IO4" = 149o35, 45.219" .. · =' 5'~60~360;207 = · ~49 889.255- = .70 18~O8o923'' = 149o35.'45.249" = 5,960,240.410 =' 549':, 889.039 = 7OO18~ O7o744'' = 149°35t 450278" . = .5,960~,120.155 = 549,889 o818 · 7oO18I O6.561,, = 149035~45o279', . .. = 5~960', OOOo 596 = 549,889 o 506 #2 LAT =: 70°18'O5.386'' LONG = 149o35.~45.311'' ., X = 5,959,880.504 Y = 549,889.996 LAT = 70°18XO4o204'' LONG.= 149,35'45o320" · x - WELL #1 X': 5,959,760.244 · '~ Y''" 549,889.514 o - " ~. LAT'= 70°f8']030022'' ... --. LONG-. 149o35t45.358,, . -. . _ I:'I:IEI o~ ...... ~.~ ~- '. . --'PROPERLY- REGISTERED At~D LICENS~u ' . · 'TO PRACTICE LAND'SURVEYING IN ' ;~C-'~,,~T,.~;.;;-':, : THE STATE OF ALASKA AND THAT . ~' ., ..~, . ~ :~ ,, ~ .... ' ...... . ........... ~... **.. f. THIS PLAT REPRESENTS AN AS- ' BUILT-SURVEY MADE BY ME, AND ' "- -' THAT ALL.DIMENSIONS AND OTHER ~r~ OETA~LS A~ CO~ECT, AS OF: "' :. - .... - - . .... f'"). ~o. F::::: LLB ~- ~ L oOA,TI o ~ ~ A6' F~O t.LT~ · RAwIN No: 'AtlanticRichfieldCompany ~ ~DAT"~: ..... - ,. ALASKA DISTRICT' KUPARUK i ii i _ · ANTICIPATED PRESSURES Expected reservoir pressure in the Kuparuk interval has been determined to be 3165 psig from RFT and pressure build-up data. This pressure @ 6060' SS = 6166' TVD will be balanced by 9.87 ppg mud weight. Normal drilling practice calls for 10.4 ppg weight prior to penetration and during drilling of the Upper Kuparuk and remaining intervals. This will result in a 170 psi overbalance. It is anticipated the surface BOPE equipment could be subjected to a maximum of 2764 psi during drilling operations. Derivation assumes a gas kick at reser- voir temperature and pressure (158°F, 3165 psi), gas migration to the surface without expansion, and cooling to 80°F cellar temperature. This is well below the 5000 psig BOPE working pressure and less than the 3000 psi weekly test pressure. Pi = pressure initial (reservoir) Ti = temperature initial (reservoir) Vi = volume initial (reservoir) Pf = pressure final (surface) Tf = temperature final (surface) Vf = volume final (surface) PiVi = PfVf Ti Tf Since Vi = Vf, i.e., no expansion. Pi = Pf PiTf T--/ ~ff Then Pf - Ti = (3180 psia)(80°F + 460) (158°F + 460) Pf : 2779 psia: 2764 psig JO-hrl 03/31/82 ONI1/A18 APR 0 1 1982 Oil & Ga-~ Cons. Commi~ior~ Anchorag~ -® Surface Dive(~:'_-r System 1. 16" Bradenhead. 2. 16" x '20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. -20" bell ~ipple. APR 0 1 1982 Oil 8, Gas Cons. Commission /~,nchorag~ 16" Conductor . . aint na.nce'& Operation ~- ' 1. Upon initial installation close annular ! preventer and verify that ball valves ! h~ave opened properly. . I 2. Close annular preventer and blow air ~__ . through divert~r lines every 12 hours. 3' Close annular preventer in the event that gas or fluid flow to. surface is detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not shut in well under any circ~mstanc.es. IRNNULRR - PREVgENTOR/.j ( .. BLIND RRHS ) C ) 8 .< )7 { { ) P~PE RRHS .< ( ) PtPE RRH$ ) 5 13-5/8" 5000 PSI RSRRA BOP STACK ( leo . 10. 11. 12 .o 2. 3. 4. Be e 1. . S. 6. 7. 8. 13. 14. L 16" Bradenhead 16" 2000 PSI x 10" 3000 PSI casing head lO" 3000 PSI tubing head lO" 3000 PSI x 13-5/8" 5000 PSI adapter spool 13-5/8" 5000 PSI pipe rams 13-5/8" 5000 PSI drilling spool w/choke and ki I 1. 1 i nes 13-5/8" 5000 PSI pipe rams 13-5/8" 5000 PSI blind rams 13-5/8" 5000 PSI annular . 15. 16. .- ACCL~.IULATOR CAPACITY TEST . CHECK AND FILL ACCI~LATO~ RESERVOIR TO PROPER LEVEL wi'rd HYDRAULIC FLUID. ASSURE THAT ACCL~IULATOR PRESSURE IS 3OOO PSI WITH 1500 PSI DCr~STREAR OF THE REGULATOR. OBSERVE TIME THE/~ CLOSE A.t.l. UNITS SIMULTANE- OUSLY AND RECORD THE TIRE AND PRESSURE RB~IN- ING AFTER ALL U!IITS ARE CLOSED WITI-! CHARGING PUMP OFF. RECORD ON I ADC REPORT. 'TiE ACCEPTABLE LIMIT IS 45 SECO:;DS CLOSII~ TINE /U'(D ]200 PSI RE~LAINING PRESSURE. - 13-5/8' BOP STACI( TEST FILL BOP STACK A~(D MANIFOLD WITH ARCTIC DIESEL. CHECK THAT ALL HOLD DO~q SCREWS ARE FULLY RE- TRACTED. PREDEl~RMINE DEPll4 THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUt( Iii LOCK DOWN SCRD2S IN HEAD. CLOSE ANNULAR PREVEt(TER Alit) CHOKES A~tD BYPASS VALVES ON HANIFOLD. TEST ALL COMPONF.';TS TO 250 PSI AND HOLD FOR lO MINUTES. INCREASE PRESSUP~E TO 1800 PSI AND HOLD FOR l0 MINUTES. BLEED TO Z~O PSI. / O.PEN ANNULAR PREVF. tFFER AND CLOSE TOP SET OF / PIPE RAHS. ., / INCREASE PRESSURE TO 3(300 PSI AND ttOLD FOR lO MI NUTES. CLOSE VALVES. DIRFCTLY U'PS'tiREA~I OF 040XES. BLEED D[7,~NSTREA~4 PRESSb~,E TO ZERO PSI TO TEST VALVES. TEST Rr~.IAINING G'~FTESTED MAIIIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREN4 OF VALVE AND ZERO PSI D(7,4~'ISTI~,.F. AM. BLEED SYSTEM TO ZERO PSI. OPEN TOP SET OF PIPE ~ ~uND CLOSE BOTTOM SET OF PIPE RAMS. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR lO liINUTES. BLEED TO ZERO ~I. OPEN BOTTOH SET OF PIPE P, AMS. BACK OFF RUN- NING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR lO )-iINUTES. BLEED TO ZERO PSI. · OPEN BLIIID RAHS AND REKt~ TEST PLUG. MAKE SURE HANIFOLD AIiD LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLII;G POS I TI ON. TEST STANDPIPE VALVES TO 3000 PSI. TEST KELLY COCKS A~iO It(SIDE BOP TO 3000 PSI ~- - WITH KOO~EY PUNP. RECORD TEST INFO.~4ATION ON BL(7~OUT PREVEi(TER '. '.._ '. - TEST EOR~I SIGN AND SE~IB TO DRILLI~IG SUPER- - _'" VISOR. PERFORI. I COiPLETE BOPE IEST OtlCE A 14EEK ~tD - '- -' FUNCTI0~IALLY 0PEP. ATE BOPE DAII.Y ....... .. _.. -~- .. -= ..~CK LIST FOR NEW WELL PERMITS IT~ APPROVE (1) Fee (2) Loc · DATE 8) (3) Admin ~?~ ~~ thru Company 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. Does operator have a bond' in force .................. 10. Is a conservation order needed ...................... 11. Is administrative approval needed '. .................. (4) Casg~ ¢-~-~ 12. u 20) 13. 14' 15. 16. 17. 18. 19. 20. (5) BOPE~ Z.~;-~Z 21. --'~21 thru 24) 22. 23. 24. Lease & Well No. YES NO REMARKS (6) Ad d~.>~ r~-~2~) 25. 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, t~nslo~'~d bgrg;[ 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 and BOP equipment attached ...... '5~ Does BOPE haVe sufficient pressure rating - Test to .~c~ psig . Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. Additional Remarks: Geology: ' Engin~c~ring J ~~_ MT~:~' re / ' v/ 01/13/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. YP OIO,HO1 VgRI~ICATION LISTIN,~ PAG£ I * R~I:;L HEADER ## E;RV ].CE NAMB ," SERV~C A~'E, :82/05/11 R~GIN = EEL NAME :REEL ID ONT INU ~%,T ION # REVIOUS RFEL : TAPE HEADER .1 VP OIO.HOI VglaIFICATION LISTIt~2 PAGE #* iI-ECORD TYPE 047 ** ** RECORD TYPif 00,7 ** COMMENT& ** $C~bUMBERGEE ALASKA CDMPU~ING CENTER OB NUMBER AT ACC: 10707,65064 UN' #1, D~T'..I L,O,.,GED. 1 MA'¥"82 ,OTTOM DEPTH = 83177 VP OIO,HD1 YERIFICA?ION LISTING PAGE 3 H bUID LOSS M MC = 10,0 = 5,8 23 3,340 ~ 74 3,730 P 74 DF~ 3,150 ~ 74 EF ~,827 { ~41 DP A~RIX SANDS'lONE 0 : O~PT 8 ~ ~ 0 8 9 8 SP ~l:j ~:8~ ER 9~8i25 ~PHi 36~'8i'64' 9ROB 2,3770 3.3203 SP ~2(~60~4 G~ NP~i 3::~:~ 326:2 R~(3B 2'4785 ~ N 3.0840 GR ~c~ ~o,ooco ~'c~ :~;~ooo G~ S~OOO CALi ~:~0 0~006:3 2'619~ 2.4063 2 '9531 .0605 ;4023 3.5352 2.4844 3' 4336 .3457 ,3867 3.3281 2.2520 2.3965 3.1797 2.5820 6777 :oooo 3906 t44 1.2520 . 3184 ,3516 ,3418 3.2773 2.0703 5098 L~ P NCNb D~PT NCNb DEPT DEPT NCNb Gl{ NCNb DEPT NCNL DEPT NCNb EPT P 010.H01 VERIP~ICA311N LISTING 6200.0000 SFLU ;63.8750 GR 1i.2500 CALl 2338'00C0 FCNL 6100.0000 $'FLU -67.8750 GR 6000.0000 SFLU '64-12.. 0 G ' 109.1250 CALX 1.9434 111, 11. 627'OOO0 3 '4355 2.2773 I~ 1-8271 ILD 1.7568 148,1250 NPHi 4'0~2344 RHOB 2.3027 510.7578 DI{HO -O,0010 {',}RAY 3.5000 352~0C0 2.8086 ILN 2.5879 ILD 2,5332 109,1250 N PB I 31 ~54 30 RH, OB 2.3516 10.2969 DRHO O,O054 NRAT 219902 2290-00~0 FCNL 673-5000 5900-0000 5 LU '62.0625 O~ 5800.0000 SFLU -6C .BlS 5 Gi~ 85'1250 CALl 2274.00~0 i~'CNL 5.750~.O000 ,'SFLU ~1562 GR 108. 4375 CALl 2120.0000 FCNL 5600.0000 SFLU -53.84~ ~R 95.3750 CALl 2236.00C0 FCNL 5500.000~ SFLU '49.562 GR )3.3125 CALl 2274'0000 FCNL 5400.0D00 SFLU -5C.59~8 ,k 92.3125 CALl 2368-00~0 · FCNL 5~40.O000 ~FL~ .6250 GR ~.:'"',-. 8125 C AL ! 2! ,0000 FCNL 2,3281 IbN 2,.3848 lbo 91'1250 NP~iI 3S,20~0 DBHO 0.O142 2.1016 1LN 2. I719 iLD 1012656 DRHO 010II2 NRAT 655 ,=0000 2.3926 Ib~ 2,0723 ILD 2.1230 108~335 NPHI 40;3320 RHOB 2,3{25 IO ,4688 D~HO -O, O01.0 NRA2 3,4883 o a(oco 2.0645 ILM 2.1'504 ILD 2.3660 95,3750 NPBI . 37.7930 R~OB 2,3359 10;6172 DRHO 0,'0220 NRAT 3.3574 602 .O000 J_ 2.2P88 15N 2,3~65. 1LD ].4355 93;3~25 NPHI 36 i037i RHOB 10.3753 DRRO O,0068 NRA3 3.35.15 620250(0 9~.3125 NPBI 43.2617 ~, OB 2,2832 10.3359 DRHO 0,0078 RAT 3,6387 600 ~5000 ~::.. 9~.7.148 IbM 3.8516 ILD 3.9160 ~ 125 NPHI 3~ ,5234 BHOB 2.2695 10.2578 DRBO 0.~20 NRA3~ 3. 2578 669 ;;5 0 ( 0 ' ~ 2. 3867 2;3438 3 · 4277 2'1582 ~2.3281 '3125 i,Vp OiO.HO! 2300,0000 h . DEPT 510¢ ,C0(O ~["LU - ~.7930 ILM- 3.O215 SP ~7~5000 GR 8~'8125 NPBI 32~5195 RHOB GR 83.81 ~.5 CAL 1 ~.~ ,6563 DBHO ~ 0,0098 NRAT NCNL 23'38.0000 FCNL 6~9~0000 SP . '75,2500 GR .8.9,,2500 N P. YI I 35 .::5469 RHOB GR 89~2500 CALl 112i!72 'CRhO - 0;0244 NR;T NCN~ 22b0,0000 ~C L 635-5000 _ - '~ PAGE 3.1777 2.2598 3.1133 3.6602 .3535 .2617 3,7910 ~CNL 197~ ~0000 FCNL 49~ 00'00 ~ 3 '3867 NCNL 2332'0000 FCNL 607~0000 2 ~2344 3.2852 .2754 .5664 oso.oooo 4000.0000 SP NCNb 2244.00C0 FCNL 590-0000 D~PT 3~00.0000 Sf]~ 12-1797 ib~ lO, 2813~ St~ . 85~6250 GR 59,1250 NPBI 40~3809 RHOB Gl{ 59,1250: CALl 9.8905 DR-HO - 0,O151~ NRA~ s :oooo DEPT 3800.0000 SFLO 7~9570 lbH 8'382~ SP 108..56~5 -GR 59,68~5 NP.~i - 4t.0156: RHOB. G~ 59.6875 CALl 9 ~8'828 DRHO 0;04]0 NCNb 2056.00C0 FCNL . 545,0OO0 ' :':. OEPT 3700 , 0000 8FLU -12 ;0547 lb1~ 13-3047 1. D SP 'I02.3125 GR 6'9,( 835 NPHI 41~. 434 RHOB NRA2 PAGE 3.6,%99 9.4922 .3672 ,3945 9.6406 2.2168 3.4414 9.0703 .2363 .4746 13.3125 2.2285 3.5723 okpT 3600.0D00 SFLU 15.37-50 ILN :14,9844: 1LD - " ~ " NP SP .... 102,81~.5 ~R -48,1562 , :;:H ::.-,2:3 .... '.~: ': ...... . ::. GA 48 ~ 1562 CALl 9,7734 DRH0 -O;0034 NRA~ NCNb 2246-00~-0 FCNL 539.0OO0 DEPT 3500.0000 SPLU 15,2891 IbM ' t5.-7 266 !,.D SP ~118~0000 GR 38~'e250 N'PHI GR 38-6250 CALl 9,8125 DRHO -0.0063 NRA~ NCNb 2464,0000 ~ FCNL OEPT 3400'0000 OFLU 10,7891 R NCNb 2216,00C0 FCNL 608.0000 3300.0000 ~FLU t5,789.1 IbM 16,.2031 ibD -112.5000 GR '35.3125 NPEI 40 ~";715 RHGB 14.4922 0703 4453 3.3750 10.7656 .1387 .5371 16.4844 2.0508 3.5175 N.,.,Nb~C ' 2322.00~0 FCNL 623.5000 GR ~"._;31 25 CALl 1.1,1875 DRMO =0 ".... 0 ~ NRA]' 9.7344 0684 13.5859 2.1211 3.5918 iL)EPT 30DO.O~)O0 5FLU 5.'92'9'1 11,[4 bVP 010,N01 VERI~ICATION LISTING SP GB NCNL EPT P CNL, DEPT NCNL -84,0625 GR 75.6250 NP'HI 75;6250 CALl 9~t719 'ERHO 1778.0000 ~CNL 429,75 0 29oc ~o(o -S4:B12S OR 56 . 56 ~ 5 CAL .... 2562.0000 FCNL 5625 NPHI -1~( , 0381 Di~HO 596,5OOO 282i.5000 5FLU 1810,0000 .IbM 1567-0000 FCNL 320-2500 0093 4~'~016 ILD . 9746 RHOB ooo.oooo 4941 NI~;T PAGE .1602 ,8652 10.5469 2.1113 3,9355 10.0078 4180 · -.~ FILE TRAILER {~ NAME :8ERVIC. 00! ERVICi NAME DATE FILE T~PE NEX~ TAPE TRAILEB ** ~ SER lC tTRiGIN ~1070 APE NAME :65064 ** REEL TRAILER ** ::~ ER ViC IG'N· gELINA~E :REEL ID