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Home My WebLink About190-067Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov December 22, 2025 Mr. Greg Hobbs Regulatory Engineer ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Docket Number: OTH-23-030 Notice of Investigation - Closeout Sustained Casing Pressure KRU 3G-09 (PTD 190-067) Dear Mr. Hobbs: The Alaska Oil and Gas Conservation Commission (AOGCC) reviewed ConocoPhillips Alaska, Inc.’s (CPAI) response to the IA sustained casing pressure and the steps taken by CPAI to secure the well. CPAI has satisfied the request made in our December 5, 2023, notice of investigation. The AOGCC does not intend to pursue any further enforcement action regarding this violation. Sincerely, Jessie L. Chmielowski Gregory C. Wilson Commissioner Commissioner cc: Phoebe Brooks (AOGCC) Gregory C Wilson Digitally signed by Gregory C Wilson Date: 2025.12.22 08:20:00 -09'00' Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.12.22 08:36:36 -09'00' December 19, 2023 Jessie Chmielowski, Commissioner Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501 VIA EMAIL aogcc.reporting@alaska.gov and samantha.carlisle@alaska.gov Re: Docket Number OTH-23-030 Notice of Investigation Sustained Casing Pressure KRU 3G-09 (PTD 190-067) Dear Commissioner Chmielowski: This letter responds to the Alaska Oil and Gas Conservation Commission’s (AOGCC’s) letter dated December 5, 2023, received by ConocoPhillips Alaska, Inc. (CPAI) on December 6, 2023, regarding the sustained casing pressure event on KRU 3G-09 (PTD 190-067). Below is a narrative timeline. Following the timeline are CPAI’s answers to the questions in AOGCC’s December 5 letter. Timeline – Well KRU 3G-09 Well KRU 3G-09 (Well) is a gas lifted producer. The Well had been shut-in since September 18 for diagnostic work. On October 23, e-line operations identified a leak at 8375’ below the existing tubing patches. CPAI determined to pull existing patches and prepare the Well for rig work over (RWO). As part of the leak detect log (LDL) operations, diesel was pumped into the Well. After pumping, CPAI observed higher IA pressures (see Attachment 3 – TIO Plot). CPAI determined that LDL pumping had likely aggravated the leak. The Well remained shut-in while CPAI continued to monitor the Well’s IA pressure. On October 28, Well IA pressure exceeded 2000psi. CO 494, Rule 3 requires notification to the AOGCC if IA pressure exceeds 2000psi, and this notification was made on October 31. In its notification, CPAI stated that “[t]he plan is for Slickline to secure the well ASAP.” The slickline unit was scheduled to be on the Well November 6. CPAI decided on this plan, taking into account observed IA pressures and work scope and equipment constraints. On October 31, IA pressure reached 2250psi, which is 45.2% of published burst rating for the Well casing. CO 494, Rule 5 requires a separate notification to the AOGCC if IA pressure exceeds 45% of burst pressure. That separate notification to AOGCC was not made. Rule 5 also requires a 10- Will Earhart Well Integrity and Intervention Supv P. O. Box 100360 Anchorage, AK 99510-0360 Phone 907.265.1077 William.C.Earhart@ConocoPhillips.com 403 sundry approval for remedial operations on a Well exceeding 45% of published burst pressure. While CPAI informed AOGCC of the ongoing remedial operations on October 31, CPAI did not submit a sundry at that time. The slickline unit was scheduled to be on the Well November 6. However, from November 5 through November 11, weather conditions did not permit any slickline work to occur. On November 12, the slickline unit commenced operations on the Well. From November 12 to November 17, the slickline unit attempted to remove the Well patches but was unsuccessful. On November 17, a coil unit was mobilized to the Well. Well secure operations continued. On November 20, CPAI determined the sundry required by CO 494, Rule 5 had not been completed, and CPAI attempted to contact the AOGCC designated single point of contact for verbal approval. Those attempts were not successful. On November 21, CPAI continued attempts to contact the AOGCC single point of contact (multiple calls and a voicemail), but those attempts also were not successful. CPAI submitted a 10-403 sundry on November 21. In that submittal, CPAI characterized the operations on the well as an “emergency decision”. This was a reference to CO 494, Rule 5, which allows CPAI to conduct well operations without an approved sundry where “emergency corrective action” is required. In this case, the “emergency” was that IA pressure had continued to increase to 2850psi (57% of published burst pressure) and also that Well operations were already underway and nearly complete. At no time was there any imminent threat to life, health or safety. On November 22, AOGCC responded and discussed the ongoing work with CPAI. Later that day, a retrievable bridge plug was set at 9,708’, and the Well was secured. During all Well operations, CPAI continued to monitor IA pressures, which increased but at no time exceeded 60% of published burst pressure (see Attachment 3, TIO Plot). Response to OTH-23-030 Questions: 1. Provide well service reports for work conducted to secure the well from October 31, 2023, to the date the well was secured. See Attachment 1: Well Service Reports. 2. Provide a summary of events in timeline format from the time of the discovery of the sustained casing pressure to the securing of the well. See above timeline and Attachment 2. 3. Explain why the well was not secured “ASAP” as stated in the October 31, 2023, email notification. See above timeline and Attachment 2. The slickline unit was scheduled to be on the Well November 6, which CPAI believes was an appropriate plan in this case, taking into account observed IA pressures and work scope and equipment constraints. We recognize that “ASAP” in this context might have implied a more accelerated timeline than we intended to convey. 4. What is CPAI’s understanding of the need to submit a 10-403 sundry to run/pull patches on a gas lifted producer and to run a plug to secure the well? Per CO 261B, a 10-403 sundry is not required for pulling patches or running plugs in gas- lifted producers. A 10-404 completion report is required for patches installed in producing wells; however, no patch was installed here. Once the IA pressure exceeded 45% of published burst pressure, all wellwork (including pulling patches or running plugs) required an approved 10-403 per CO 494, Rule 5. 5. When did the IA casing pressure exceed 45% of the published burst pressure of the intermediate casing? Provide the TIO plot as well as a printout of daily average IA pressures with time. See above timeline and Attachment 2. See also Attachment 3, TIO plot. IA pressure exceeded 2241psi on October 31, 2023. 6. What is CPAI’s understanding of the need to report to the AOGCC when the IA pressure exceeds 45% of the published burst pressure of the intermediate casing? See above timeline and Attachment 2. CO 494, Rule 5 requires notification to the AOGCC when IA pressure exceeds 45% of the published burst rating. 7. Did CPAI attempt to bleed the sustained casing pressure? If so, provide the bleed record. CPAI did not attempt to bleed the Well (outside of wellwork) because diagnostic work had identified tubing leaks. 8. Why did CPAI wait until November 20, 2023, to consider the sustained casing pressure an emergency? See above timeline and Attachment 2. CPAI submitted a 10-403 sundry on November 21. In that submittal, CPAI characterized the operations on the well as an “emergency decision”. This was a reference to CO 494, Rule 5, which allows CPAI to conduct well operations without an approved sundry where “emergency corrective action” is required. In this case, the “emergency” was that IA pressure had continued to increase to 2850psi (57% of published burst pressure) and also that well operations were already underway and nearly complete. At no time was there any imminent threat to life, health or safety. 9. Email correspondence from CPAI on November 22, 2023, indicates efforts to contact CPAI’s primary contact at AOGCC were unsuccessful. Who else did CPAI attempt to contact? Describe CPAI’s procedures and contacts for emergency notifications. See above timeline and Attachment 2. CPAI attempted to contact (multiple calls and a voicemail to) the AOGCC single point of contact for Kuparuk well operations (Victoria Loepp). Those attempts were unsuccessful. In the future, CPAI proposes to work with the AOGCC to designate backup AOGCC personnel for such urgent communications if the normal single point of contact cannot be reached. Once that backup contact procedure is agreed with the AOGCC, CPAI will incorporate it into formal CPAI procedures. 10. Any other information that CPAI would like to provide concerning this matter. None at this time. In this case, CPAI acknowledges that we did not follow the notification and sundry approval procedures of CO 494, Rule 5. We have reemphasized the importance of this requirement to all CPAI drilling engineers. We are currently reviewing opportunities to enhance our daily surveillance automation to flag similar events and provide additional controls to the otherwise manual process of supporting CO 494, Rule 5. Please reach out to myself or Greg Hobbs for any further information regarding this matter. Sincerely, For: Will Earhart cc: Victoria Loepp (victoria.loepp@alaska.gov) Jim Regg, AOGCC (jim.regg@alaska.gov) Phoebe Brooks, AOGCC (phoebe.brooks@alaska.gov) Digitally signed by Greg Hobbs DN: OU=CPAI Wells, CN=Greg Hobbs , E=greg.s.hobbs@conocophillips.com Reason: I am the author of this document Location: 700 G Street, Anchorage AK Date: 2023.12.19 10:14:24-09'00' Foxit PDF Editor Version: 13.0.0 Greg Hobbs Attachment 1: Well Service Reports Attachment 2: Timeline Summary of Well Service Event DATE Event Notes 10/28/2023 Operations reported IA pressure at 2050 psi per the well walk pressures (Saturday) 10/30/2023 Well Work request for well secure sent to PE to place into Well Work Priority List. 10/31/2023 Reported 3G-09 SCP of the IA to AOGCC via email per SOP (within 3 business days) 10/31/2023 IA pressure exceeded 45% burst rating of the production casing. 11/4/2023 Schedule updated to send slickline Unit 764 to 3G-09 once completed with unit maintenance. Targeted mob on 11/6/23 11/5/2023 Limited slickline work able to be complete in GKA due to poor weather conditions 11/6/2023 All slickline units in GKA unable to work due to poor weather conditions 11/7/2023 All slickline units in GKA unable to work due to poor weather conditions 11/8/2023 All slickline units in GKA unable to work due to poor weather conditions 11/9/2023 All slickline units in GKA unable to work due to poor weather conditions 11/10/2023 All slickline units in GKA unable to work due to poor weather conditions 11/11/2023 All slickline units in GKA unable to work due to poor weather conditions 11/12/2023 Slickline rigged up on 3G-09 to execute secure. Successfully fished upper tubing patch with 0.125" wire. Attempted to fish deeper tubing patch. 11/13/2023 Slickline continued fishing attempts on second tubing patch with 0.125" wire. Experienced damage to toolstring and unable to keep grapple engaged. 11/14/2023 Slickline continued fishing attempts on tubing patch with 0.125" wire. Escalated to 0.160" wire for greater pulling strength. No success. 11/15/2023 Slickline continued fishing attempts on tubing patch with 0.160" wire. Tools staying engaged but unable to move fish uphole despite jarring. Decision made to escalate job to braided wire slickline unit from Deadhorse. 11/16/2023 Coordinated braided line unit from Pollard in Deadhorse. 11/17/2023 MIRU Pollard braided line unit. Attempt to fish deeper tubing patch but no success. Descision made to escalate job to service coil. 11/20/2023 CPAI determined a sundry was required for all subsequent wellwork per CO 494, Rule 5. CPAI D Freeborn attempted to contact V.Loepp to obtain verbal approval to proceed with intervention work. Unable to make contact on several attempts to office phone during business hours. Left voice message with details of the job scope. 11/20/2023 Service coil finished job on 1E-119 and mobilized to 3G-09. Arrived on location at 1800hr. Successfully fished deep tubing patch. RDMO back to 1E-102. 11/21/2023 Service coil finished job. RDMO back to 1E-102 at 0700hr. 11/21/2023 CPAI D Freeborn attempted again to make contact with V.Loepp to provide update on well status. Unable to make contact. Submitted 10-403 with job in progress. 11/22/2023 AOGCC M. Guhl responded to 10-403 submitted to clarify dates. V.Loepp contacted to discuss further details of the job scope. 11/22/2023 Slickline set RBP at 9,708' MD. WELL SECURED. 11/23/2023 Slickline removed dummy valve from station #7 to allow circ out. 11/24/2023 Pump crewed circed up well to corrision inhibited seawater and freeze protect. 3G-09 Timeline of events Attachment 3: 3G-09 90-day TIO Plot 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:Loepp, Victoria T (OGC) To:Hobbs, Greg S; Regg, James B (OGC) Cc:Christianson, Grace K (OGC); Carlisle, Samantha J (OGC) Subject:RE: Dockets OTH-23-030 and OTH-23-031 Date:Tuesday, December 12, 2023 12:10:05 PM Greg, Both response requests are approved as written below. Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent: Tuesday, December 12, 2023 12:06 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: Dockets OTH-23-030 and OTH-23-031 Victoria and Jim, Dockets OTH-23-030 and OTH-23-031 were received electronically on December 6, 2023. Docket OTH-23-030 is the Notice of Investigation for Sustained Casing Pressure on KRU 3G-09 (PTD 190-067). It requested responses within 7 days of receiving the letter of NOI. At this point we have gathered the data for the response and are working on finalizing the collation and presentation. While we are close, we are respectfully requesting that this response be due on December 20, 2023 instead of December 13, 2023. Docket OTH-23-031 is the Notice of Violation for a late well completion report on well KRU 2F- 18 (PTD 1961780). It requested a response within 14 days of receiving the NOV. Both dockets involved the same team and with the focus on gathering the information on the 3G-09 NOI, no work has been done to date on this docket. It is respectfully requested that this response be due on January 4, 2024 in consideration of the Christmas and New Years Holidays. Thank-you for the consideration of these requests. Greg Greg Hobbs, P.E. Regulatory Engineer | Wells Team ConocoPhillips Alaska Inc. Office: 907-263-4749 Cell: 907-231-0515 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov December 5, 2023 Certified Mail Return Receipt Requested 7018 0680 0002 2052 9570 Mr. Greg Hobbs Regulatory Engineer ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Docket Number: OTH-23-030 Notice of Investigation Sustained Casing Pressure KRU 3G-09 (PTD 190-067) Dear Mr. Hobbs: CPAI reported to the Alaska Oil and Gas Conservation Commission (AOGCC) on October 31, 2023, sustained casing pressure of the Inner Annulus (IA) of Kuparuk River Unit (KRU) 3G-09 (PTD 190-067). On or around November 2, 2023, the sustained casing pressure exceeded the AOGCC-required action pressure threshold of 45% of the burst pressure of the intermediate casing. On November 22, 2023, the well was secured. The AOGCC is reviewing ConocoPhillips Alaska, Inc.’s (CPAI) response to the IA sustained casing pressure and the steps taken by CPAI to secure the well. Within 7 days of receipt of this letter, CPAI is requested to provide responses to the following questions and the requested information: 1. Provide well service reports for work conducted to secure the well from October 31, 2023, to the date the well was secured. 2. Provide a summary of events in timeline format from the time of the discovery of the sustained casing pressure to the securing of the well. 3. Explain why the well was not secured “ASAP” as stated in the October 31, 2023, email notification. 4. What is CPAI’s understanding of the need to submit a 10-403 sundry to run/pull patches on a gas lifted producer and to run a plug to secure the well? Docket Number: OTH-23-030 Notice of Investigation December 5, 2023 Page 2 of 2 5. When did the IA casing pressure exceed 45% of the published burst pressure of the intermediate casing? Provide the TIO plot as well as a printout of daily average IA pressures with time. 6. What is CPAI’s understanding of the need to report to the AOGCC when the IA pressure exceeds 45% of the published burst pressure of the intermediate casing? 7. Did CPAI attempt to bleed the sustained casing pressure? If so, provide the bleed record. 8. Why did CPAI wait until November 20, 2023, to consider the sustained casing pressure an emergency? 9. Email correspondence from CPAI on November 22, 2023, indicates efforts to contact CPAI’s primary contact at AOGCC were unsuccessful. Who else did CPAI attempt to contact? Describe CPAI’s procedures and contacts for emergency notifications. 10. Any other information that CPAI would like to provide concerning this matter. This information request is made pursuant to 20 AAC 25.300. Questions regarding this notice should be directed to Victoria Loepp at victoria.loepp@alaska.gov or (907)793-1247. Sincerely, Jessie L. Chmielowski Commissioner cc: Jan Byrne (CPAI) Jim Regg (AOGCC) Phoebe Brooks (AOGCC) Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.12.05 15:12:19 -09'00' 190-067 T38918 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.13 08:09:57 -08'00' 190-067 T38904 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.12 12:52:46 -08'00' Originated: Delivered to:19-May-24 Alaska Oil & Gas Conservation Commiss 19May24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 1A-03 50-029-206150-00-00 181-088 Kuparuk River WL Plug FINAL FIELD 3-Feb-24 3S-22 50-10320446-00-00 203-011 Kuparuk River WL IBC-CBL FINAL FIELD 5-Feb-24 3M-05 50-103-20875-00-00 223-126 Kuparuk River WL Isealate FINAL FIELD 10-Feb-24 2F-15 50-029-21048-00-00 183-172 Kuparuk River WL Isealate FINAL FIELD 13-Feb-24 MT7-14A 50-103-20856-01-00 223-064 Greater Mooses Tooth WL PPROF FINAL FIELD 20-Feb-24 MT7-03A 50-103-20830-00-10 223-084 Greater Mooses Tooth WL PPROF FINAL FIELD 29-Feb-24 3G-27 50-103-20801-00-00 219-039 Kuparuk River WL TTiX IPROF FINAL FIELD 2-Apr-24 2W-17 50-029-23370-00-00 207-135 Kuparuk River WL PPROF FINAL FIELD 9-Apr-24 1E-23 50-029-20858-00-00 182-184 Kuparuk River WL IPROF FINAL FIELD 10-Apr-24 1E-01 50-029-20464-00-00 180-039 Kuparuk River WL IPROF FINAL FIELD 11-Apr-24 1D-37 50-029-22992-00-00 200-204 Kuparuk River WL PPROF FINAL FIELD 12-Apr-24 3G-09 50-103-20129-00-00 190-067 Kuparuk River WL Punch-Cut FINAL FIELD 13-Apr-24 2P-420 50-103-20391-00-00 201-182 Kuparuk River WL CIBP-Cut FINAL FIELD 15-Apr-24 CD4-536 50-103-20863-00-00 223-079 Colville River WL TTiX Sampling FINAL FIELD 18-Apr-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private Eset # T38800 T38801 T38802 T38803 T38816 T38817 T38818 T38819 T38820 T38821 T38822 T38824 T38823 T38825 3G-09 50-103-20129-00-00 190-067 Kuparuk River WL Punch-Cut FINAL FIELD 13-Apr-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.20 12:41:13 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10332'feet None feet true vertical 5988' feet 10035'feet Effective Depth measured 9999'feet 7104', 9472', 9578', 9698', 9862' feet true vertical 5869'feet 4424', 5630', 5682',5739', 5813' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" 3-1/2" L-80 L-80 9557' 9664' 5672' 5723' Packers and SSSV (type, measured and true vertical depth)7104' 9472' 9578' 9698' 9862' 4424' 5630' 5682' 5739' 5813' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 324-089 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: SLB BluePack Packer: SLB BluePack Packer: SLB BluePack Packer: Baker HB Retrievable Packer: Baker DB Permanent SSSV: None Shane Germann shane.germann@conocophillips.com (907) 263-4597Staff RWO/CTD Engineer 9754-9812', 9940-10010', 10048-10088' 5764-5791', 5846-5873', 5888-5903' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 330 Gas-Mcf MDSize 115' 3100 11602200 Well Shut-In 230 measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 190-067 50-103-20129-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025548, ADL0025547 Kuparuk River Field/ Kuparuk Oil Pool KRU 3G-09 Plugs Junk measured Length Production 10265' Casing 5977'10300' 4503' 115'Conductor Surface 16" 9-5/8" 79' 4538' 3079' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 2:02 pm, May 14, 2024 Digitally signed by Shane Germann DN: O=ConocoPhillips, CN=Shane Germann , E=shane.germann@conocophillips.com Reason: I have reviewed this document Location: Date: 2024.05.14 13:22:32-08'00' Foxit PDF Editor Version: 13.0.0 VTL 8/15/2024 RBDMS JSB 051524 DSR-5/14/24 Page 1/9 3G-09 Report Printed: 5/14/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/6/2024 00:00 4/6/2024 03:00 3.00 MIRU, MOVE MOB P PJSM, hook up jeep to pits and pull pits away from sub, clean up where pit sat at, Pull forward and change flat tire on service module 0.0 0.0 4/6/2024 03:00 4/6/2024 05:30 2.50 MIRU, MOVE MOB P Move sub base and pits from 3F pad to 3G pad Loader headed to 3G-pad. 0.0 0.0 4/6/2024 05:30 4/6/2024 08:30 3.00 MIRU, MOVE MOB P Rig on location, swap out HCR Valve Load well head adaptor, wellhead equipment, etc. Prep well for Rig and Service module Call Security and block traffic while spotting PJSM, w/crew 0.0 0.0 4/6/2024 08:30 4/6/2024 10:00 1.50 MIRU, MOVE RURD P Sub base on 3G pad, hang tree in cellar, line up sub with well 0.0 0.0 4/6/2024 10:00 4/6/2024 11:30 1.50 MIRU, MOVE RURD P Lay herculte and spot in service module 0.0 0.0 4/6/2024 11:30 4/6/2024 13:00 1.50 MIRU, MOVE RURD P Lay out herculite and set mats for pits Spot pits up to sub base, berm around sub and pits Secure stairs and landings 0.0 0.0 4/6/2024 13:00 4/6/2024 14:00 1.00 MIRU, MOVE RURD P R/U interconnect, R/U mud lines, B/D F/rig floor tp pits, check lines. Secure rig floor, connect the cement line, hang rig tongs, place XO's subs and elevators back on rack, remove leg brace. Complete pre acceptance checklist. 0.0 0.0 4/6/2024 14:00 4/6/2024 19:00 5.00 MIRU, WELCTL RURD P Load seawater in pits. finish installing hard line to kill tank. RU cellar to kill well. Grease crew on location to service choke and rig. Rig Accept at 14:00 Prep to Load and process 3 1/2" DP in pipe shed AOGCC Adam Earl waived witness for BOPE test. Initial pressures on well T/IA/OA: 50/75/0 psi 0.0 0.0 4/6/2024 19:00 4/6/2024 22:30 3.50 MIRU, WELCTL DISP P Pump 40 bbl deep clean pill follewed with 467 bbl 8.6 ppg seawater. ICP: 3BPM/480 psi FCP: 4BPM/728 psi 0.0 0.0 4/6/2024 22:30 4/6/2024 23:00 0.50 MIRU, WELCTL OWFF P Flow check well for 30 minutes. No flow. 0.0 0.0 4/6/2024 23:00 4/7/2024 00:00 1.00 MIRU, WHDBOP MPSP P Set BPV and chart 10 min 1000 psi test. 0.0 0.0 4/7/2024 00:00 4/7/2024 02:00 2.00 MIRU, WHDBOP NUND P Tie onto tree with bridge crane, remove nuts/studs and rack back tree. 0.0 0.0 4/7/2024 02:00 4/7/2024 05:00 3.00 MIRU, WHDBOP NUND P NU DSA, Verify hanger threads. Install test dart. Install BOPs. Install choke HCR and kill line.Torque bolts on DSA, BOPs, choke and kill. 0.0 0.0 4/7/2024 05:00 4/7/2024 05:30 0.50 MIRU, WHDBOP RURD P Fill stack and prep for BOP testing Obtain shell test 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 4/17/2024 Page 2/9 3G-09 Report Printed: 5/14/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/7/2024 05:30 4/7/2024 18:00 12.50 MIRU, WHDBOP BOPE P Start testing BOPE. Initial BOPE test, Tested BOPE at 250/3500 PSI for 5 Min each, Tested annular on 3-1/2" test joint, Fail/Pass on the high, UVBR's, LVBR's w/3-1/2" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, FOSV, and IBOP. Tested 3 -1/2" EUE FOSV Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Fail/pass choke HCR, Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=1600 PSI, after closure=1500 PSI, 200 PSI attained =2.5 sec, full recovery attained = 1 min 53 sec. UVBR's= 5 sec, Annular= 30 sec. Simulated blinds= 5 sec. LVBR’s=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 1095 PSI. Test gas detectors, PVT and flow show. Change to witnessed waived by AOGCC rep Adam Earl 0.0 0.0 4/7/2024 18:00 4/7/2024 18:30 0.50 COMPZN, RPCOMP RURD P Blow down & R/D testing equipment. Blow down surface lines. Empty stack. Pull blanking plug. Pull BPV. PU handling equipment for pulling completion. RU to pull completion. Move rig tongs to rig floor. RU power tongs. 0.0 0.0 4/7/2024 18:30 4/7/2024 21:30 3.00 COMPZN, RPCOMP PULL P Blow down surface lines. Empty stack. Pull blanking plug. Pull BPV. PU handling equipment for pulling completion. RU to pull completion. Move rig tongs to rig floor. RU power tongs. 0.0 0.0 4/7/2024 21:30 4/7/2024 22:00 0.50 COMPZN, RPCOMP THGR P BOLDS. PU to 115K, 20K over string weight. Pull tubiong hanger to the floor. RU spooler, LD landing joint. 0.0 0.0 4/7/2024 22:00 4/7/2024 23:30 1.50 COMPZN, RPCOMP PULL P LD tubing from 9660-9000 PUW 84K/ SOW 79K 9,660.0 9,000.0 4/7/2024 23:30 4/8/2024 00:00 0.50 COMPZN, RPCOMP SVRG P Service rig, grease blocks, top drive and draw works. 9,000.0 9,000.0 4/8/2024 00:00 4/8/2024 01:30 1.50 COMPZN, RPCOMP PULL P LD tubing from 9000-7939 PUW 78K/ SOW 73K 9,000.0 7,939.0 4/8/2024 01:30 4/8/2024 02:30 1.00 COMPZN, RPCOMP RURD P RD Spooling unit. Clean and clear rig floor. 7,939.0 7,939.0 4/8/2024 02:30 4/8/2024 12:00 9.50 COMPZN, RPCOMP PULL P Continue pulling 3.5" tubing from well, SSV, 7 GLM, and cut joint from well *** Note: WellTech Cut Joint 12.90' 7,939.0 0.0 4/8/2024 12:00 4/8/2024 14:00 2.00 COMPZN, RPCOMP PULL P Empty pipe shed of remaining 3.5" tubing Load remaining DP 17 jts 0.0 0.0 4/8/2024 14:00 4/8/2024 14:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #1 w/Baker G-lock RPB, Mod L Retrieving Head, XO Sub, pup joint, and XO sub 0.0 22.8 4/8/2024 14:30 4/8/2024 15:30 1.00 COMPZN, RPCOMP TRIP P TIH on stands, bring pump online break circulation 135 gpm/3 bpm/120 psi PUW=50k, SOW=50k 22.8 1,064.0 Rig: NABORS 7ES RIG RELEASE DATE 4/17/2024 Page 3/9 3G-09 Report Printed: 5/14/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/8/2024 15:30 4/8/2024 16:30 1.00 COMPZN, RPCOMP MPSP P Set Packer @ COE 1,030', work pipe 15k release PUH 1,018', close upper pipe rams, line up to P/T Chart 1,000 psi test on G-lock. 1,064.0 1,030.0 4/8/2024 16:30 4/8/2024 17:30 1.00 COMPZN, RPCOMP TRIP P TOOH on stands, F/1,030' T/Surface 1,030.0 0.0 4/8/2024 17:30 4/8/2024 18:30 1.00 COMPZN, RPCOMP BHAH P L/D RPB Running tools Clean rig floor, send down hanger to the ground 0.0 0.0 4/8/2024 18:30 4/8/2024 20:00 1.50 COMPZN, RPCOMP NUND P Nipple down BOPE and secure on post 0.0 0.0 4/8/2024 20:00 4/8/2024 20:30 0.50 COMPZN, RPCOMP NUND P R/D Tubing head 0.0 0.0 4/8/2024 20:30 4/8/2024 23:30 3.00 COMPZN, RPCOMP NUND P RU Hydra-tight and Grow casing 28.25" Total growth. Remove tubing head and remove from cellar. 0.0 0.0 4/8/2024 23:30 4/9/2024 00:00 0.50 COMPZN, RPCOMP SVRG P Service rig, grease blocks and C/O Blackjak 0.0 0.0 4/9/2024 00:00 4/9/2024 03:00 3.00 COMPZN, RPCOMP NUND P Remove tubing head. MU spear and pull 125K over Block weight to set slips in tension.RU Wachs cutter and cut off 44" of excess casing. 28.25 total growth then stretched 15.75" more. RD wachs cutter. 0.0 0.0 4/9/2024 03:00 4/9/2024 05:30 2.50 COMPZN, RPCOMP NUND P MU Cameron CXS tubing head. Test void 3000 psi for 15 minutes. 0.0 0.0 4/9/2024 05:30 4/9/2024 08:00 2.50 COMPZN, RPCOMP NUND P NU BOP's. 0.0 0.0 4/9/2024 08:00 4/9/2024 09:00 1.00 COMPZN, RPCOMP BOPE P PT breaks 250 low/3000 high. Good test. 0.0 0.0 4/9/2024 09:00 4/9/2024 10:00 1.00 COMPZN, RPCOMP MPSP P Pull test plug, set WR ID=6.25". LD test joint and blow down choke and kill lines. 0.0 0.0 4/9/2024 10:00 4/9/2024 12:30 2.50 COMPZN, RPCOMP MPSP P MU G-plug retrieving tool and RIH top RBP at 1020'. Pull G-plug out of the hole. UP WT 50K 0.0 0.0 4/9/2024 12:30 4/9/2024 13:00 0.50 COMPZN, RPCOMP CLEN P Clean and clear rig floor 0.0 0.0 4/9/2024 13:00 4/9/2024 15:00 2.00 COMPZN, RPCOMP BHAH P PU BHA #3 dress off mill, casing scraper, string mills, string magnets and jars. UPW 55K/ DNW 55K 0.0 280.0 4/9/2024 15:00 4/10/2024 00:00 9.00 COMPZN, RPCOMP PULD P RIH F/280' T/9,120' picking up singles from pipe shed 145K UP 90K DN 280.0 9,120.0 4/10/2024 00:00 4/10/2024 00:45 0.75 COMPZN, RPCOMP PULD P RIH F/9,120' T/9,625' 150K UP 95K DN Note: at 9,489' take 10K DN, wipe spot 9,120.0 9,625.0 4/10/2024 00:45 4/10/2024 02:00 1.25 COMPZN, RPCOMP REAM P Wash Ream down F/9,625' T/9659' 50 RPM 6.5 - 7K TQ 118K Rot WT 2 BPM 280 PSI 5 BPM 1260 PSI Clean off 3 1/2" TBG stump - pick up dry tag at 9,659' - 3 1/2" TBG stump at 9,650' 9,625.0 9,659.0 4/10/2024 02:00 4/10/2024 02:45 0.75 COMPZN, RPCOMP CIRC P Pump 44 BBL Hi vis sweep @ 7.3 BPM 1975 PSI, lay down 3 joints DP T/9,564' Load and process 3 1/2" tubing in pipe shed 9,659.0 9,564.0 Rig: NABORS 7ES RIG RELEASE DATE 4/17/2024 Page 4/9 3G-09 Report Printed: 5/14/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/10/2024 02:45 4/10/2024 03:15 0.50 COMPZN, RPCOMP OWFF P Flow check - B/D top drive 9,564.0 9,564.0 4/10/2024 03:15 4/10/2024 06:00 2.75 COMPZN, RPCOMP SLPC P Slip and cut drilling line Service rig 9,564.0 9,564.0 4/10/2024 06:00 4/10/2024 16:00 10.00 COMPZN, RPCOMP PUTB P Load and process 3 1/2" tubing in pipe shed 9,564.0 9,564.0 4/10/2024 16:00 4/11/2024 00:00 8.00 COMPZN, RPCOMP PULD P POOH Kitty Wells style F/9,564' T/974' 50K UP/DN 9,564.0 974.0 4/11/2024 00:00 4/11/2024 00:30 0.50 COMPZN, RPCOMP PULD P POOH L/D DP F/974' T/280' 974.0 280.0 4/11/2024 00:30 4/11/2024 00:45 0.25 COMPZN, RPCOMP OWFF P Flow check 280.0 280.0 4/11/2024 00:45 4/11/2024 02:30 1.75 COMPZN, RPCOMP BHAH P L/D BHA #3 clean magnets and boot baskets Clean clear rig floor 280.0 0.0 4/11/2024 02:30 4/11/2024 05:30 3.00 COMPZN, RPCOMP RURD P Pull wear ring, prep pipe shed for running TBG R/U to run 3 1/2" EUE completion 0.0 0.0 4/11/2024 05:30 4/11/2024 20:45 15.25 COMPZN, RPCOMP PUTB P Run 3-1/2" EUE completion T/9,624' 90K UP 65K DN 0.0 9,624.0 4/11/2024 20:45 4/11/2024 21:30 0.75 COMPZN, RPCOMP PUTB P Locate tubing stump @ 3 BPM 230 PSI See pump PSI increase to 300 @ 9,651', slack off shear pins in over shot W/10K DN, continue to slack off T/9,656' no go out, set DN 5K, pick up confirm tag depth W/10K DN 9,624.0 9,656.0 4/11/2024 21:30 4/11/2024 22:00 0.50 COMPZN, RPCOMP HOSO P L/D 3 JTS TBG, M/U 2.05' space out pup and JT #305 T/9,626' 9,656.0 9,626.0 4/11/2024 22:00 4/11/2024 23:00 1.00 COMPZN, RPCOMP THGR P M/U circulating hose, hanger and landing JT 9,626.0 9,626.0 4/11/2024 23:00 4/12/2024 00:00 1.00 COMPZN, RPCOMP DISP P Slack off T/9,648' Pump 8.6 PPG CI Brine @ 3 BPM 300 PSI 9,626.0 9,626.0 4/12/2024 00:00 4/12/2024 01:45 1.75 COMPZN, RPCOMP DISP P Pump 328 BBLS 8.6 PPG CI Brine @ 3 BPM 300 PSI 9,626.0 9,626.0 4/12/2024 01:45 4/12/2024 02:15 0.50 COMPZN, RPCOMP RURD P Drain stack, blow down all lines 9,626.0 9,626.0 4/12/2024 02:15 4/12/2024 02:45 0.50 COMPZN, RPCOMP THGR P Slack off land out TBG in wellhead at 9,655', RILDS 95K UP 65K DN 9,626.0 9,655.0 4/12/2024 02:45 4/12/2024 03:15 0.50 COMPZN, RPCOMP PRTS P Drop ball and rod with 1 5/16" OD ball Pressure up to 3500 PSI to set packer and test TBG F/30 min OA = 0 Pressure up to 3600 PSI on TBG, bleed to 2500 PSI in 1 min, PSI up on TBG to 3600 PSI bleed to 1200 PSI in 3 min, IA stay at 0 PSI, open IA to atmosphere have fluid coming out of IA Walk lines notice no sensor on IA - install sensor on IA, PSI up on TBG to 500, IA go to 500 PSI also 9,655.0 9,655.0 4/12/2024 03:15 4/12/2024 06:30 3.25 COMPZN, RPCOMP WAIT T Call out slick line unit to push ball and rod to bottom. 9,655.0 9,655.0 4/12/2024 06:30 4/12/2024 10:00 3.50 COMPZN, RPCOMP SLKL T RU SL and RIH W/2.67" drift, tag B&R at 3850' and push it to bottom. POOH with slick line, R/U test TBG to 500 PSI confirm ball and rod on seat 9,655.0 9,655.0 4/12/2024 10:00 4/12/2024 10:30 0.50 COMPZN, RPCOMP SLKL T RD SL. 9,655.0 9,655.0 Rig: NABORS 7ES RIG RELEASE DATE 4/17/2024 Page 5/9 3G-09 Report Printed: 5/14/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/12/2024 10:30 4/12/2024 11:15 0.75 COMPZN, RPCOMP PRTS P Pressure up to 3500 psi to set packer and hold and chart for 30 minutes. Good test. Bleed off tubing pressure to 1500 psi and attempt to pressure up on IA to 2500 PSI 9,655.0 9,655.0 4/12/2024 11:15 4/12/2024 13:30 2.25 COMPZN, RPCOMP PRTS T Attempt to pressure up on IA to 2500 PSI, IA not holding pressure, Pressure bleed down to 1100 psi. TBG hold at 1600 PSI, pressure up to 2500 PSI 7 times each test have same bleed off rate. Trouble shoot surface equipment. Call town and discuss plan forward. 9,655.0 9,655.0 4/12/2024 13:30 4/12/2024 17:00 3.50 COMPZN, RPCOMP WAIT T Call Eline out to rig to cut TBG Rebuild secondary demco circ valve, BD all lines, unload shed, BOLDS on hanger, start loading 309 jts DP in the shed for next run in the hole. Strap and tally. 9,655.0 9,655.0 4/12/2024 17:00 4/12/2024 19:15 2.25 COMPZN, RPCOMP ELNE T Spot Eline unit, bring up tools to floor, pick up to set TBG with 20K over and realized the top of the TBG was to tall, reland TBG, L/D landing JT, make up 3 1/2" TBG pup joints for a shorter landing joint to get top lower for a better working height. 9,655.0 9,655.0 4/12/2024 19:15 4/12/2024 20:15 1.00 COMPZN, RPCOMP ELNE T P/U pull to 120K on hook, set slips at 115K = 20K over PJSM, finish rigging up Eline and make up 2" CCL and RCT 9,655.0 9,655.0 4/12/2024 20:15 4/12/2024 20:45 0.50 COMPZN, RPCOMP ELNE T RIH with Eline with a CCL and a 2" RCT 9.90' from CCL to RCT Tag up at 2,800' set down repeat 5 times tag up same 9,655.0 9,655.0 4/12/2024 20:45 4/12/2024 22:30 1.75 COMPZN, RPCOMP ELNE T POOH, change out tool configuration Add weight bars and rollers, replace centralizers for some that are not as big or stiff 9,655.0 9,655.0 4/12/2024 22:30 4/12/2024 23:30 1.00 COMPZN, RPCOMP ELNE T RIH with Eline T/9,620' W/2" CCL and 2" RCT = 9.90' 1500# UP 380# DN 9,655.0 9,655.0 4/12/2024 23:30 4/13/2024 00:00 0.50 COMPZN, RPCOMP CPBO T Coralate for cut Locate collar at 9,537' Cut TBG at 9,547' from Nabors 7ES RKB Adjusted cut depth from Doyon 14 @ 9,556.33' 9,655.0 9,655.0 4/13/2024 00:00 4/13/2024 01:45 1.75 COMPZN, RPCOMP ELNE T POOH W/Eline Break down tools 9,655.0 9,655.0 4/13/2024 01:45 4/13/2024 02:30 0.75 COMPZN, RPCOMP PUTB T P/U to see if tubing cut P/U to 140K on hook = 45K over, pipe not cut Work pipe up to 120 -135K on hook while redressing cutter tool Reland hanger, lay down tubing pup joints pick up landing joint due to collar at rotary table for setting slips with more tension on tubing for cut P/U T/140K, set slips with 45K over 9,655.0 9,655.0 Rig: NABORS 7ES RIG RELEASE DATE 4/17/2024 Page 6/9 3G-09 Report Printed: 5/14/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/13/2024 02:30 4/13/2024 05:15 2.75 COMPZN, RPCOMP ELNE T Make up 2" RCT, function tools on surface, anchor arms not functioning AK Eline does not have another anchor on slope R/D AK Eline to get SLB Eline unit with a 2.625" chemical cutter 9,655.0 9,655.0 4/13/2024 05:15 4/13/2024 10:00 4.75 COMPZN, RPCOMP WAIT T Wait on SLB Eline to get to location. Pulled the landing joint and installed just enough pup joints to get to the rig floor and installed FOSV. Pulled the string in tension 115K hook load, 20 K over string weight and set in slips. 9,655.0 9,655.0 4/13/2024 10:00 4/13/2024 10:30 0.50 COMPZN, RPCOMP SFTY T SLB on location. Held prejob safety meeting. 9,655.0 9,655.0 4/13/2024 10:30 4/13/2024 14:00 3.50 COMPZN, RPCOMP ELNE T RU SLB E-line to perfom a tubing punch. BHA length 38.46 dwith 5' of guns to shoot at 9545' to 9550'. BHA consist of puncher, GR/CCL and 2 sets of rollers. Max OD is 2.2" for the rollers. 9,655.0 9,655.0 4/13/2024 14:00 4/13/2024 15:15 1.25 COMPZN, RPCOMP ELNE T Start to RIH with Wireline at 14:00. 9,655.0 9,655.0 4/13/2024 15:15 4/13/2024 16:15 1.00 COMPZN, RPCOMP ELNE T Fire tubing punch at 15:15. Shots from 9545'- to 9550'. POOH with E-line. 9,655.0 9,655.0 4/13/2024 16:15 4/13/2024 18:00 1.75 COMPZN, RPCOMP DISP T Displace CI seawater with seawater at 3.6 BPM 825 PSI 9,655.0 9,655.0 4/13/2024 18:00 4/13/2024 21:00 3.00 COMPZN, RPCOMP ELNE T PJSM, make up Welltech cutter and finish R/U Eline MU Welltec BHA to SLB Eline, Function test tool on surface, CCL to cutter = 18.00' RIH T/9600' 1525# UP, 700# DN 9,655.0 9,655.0 4/13/2024 21:00 4/13/2024 21:15 0.25 COMPZN, RPCOMP CPBO T Coralate depth for cut Locate collar's at 9,594', 9,537', 9,507' Cut TBG @ 9,533' Loose 300# line tensionindicating cut Adjusted cut depth from Doyon 14 RKB = 9542.33' 9,655.0 9,655.0 4/13/2024 21:15 4/13/2024 23:15 2.00 COMPZN, RPCOMP ELNE T POOH with Eline, Break down Welltec cutter and SLBG tools Cutter knifes show 3.70" sweep 9,655.0 9,655.0 4/13/2024 23:15 4/13/2024 23:45 0.50 COMPZN, RPCOMP ELNE T P/U to insure TBG cut 95K UP Finish R/D Eline and clear floor 9,655.0 9,552.0 4/13/2024 23:45 4/14/2024 00:00 0.25 COMPZN, RPCOMP PULL T Pull hanger to rig floor and lay down, break apart and lay down pups 9,552.0 9,523.0 4/14/2024 00:00 4/14/2024 00:30 0.50 COMPZN, RPCOMP PULL T Break apart and lay down 3 1/2" pup joints that were used for landing joint to cut tubing 9,523.0 9,523.0 4/14/2024 00:30 4/14/2024 09:00 8.50 COMPZN, RPCOMP TRIP T POOH standing back 3 1/2" TBG F/9,523' T/cut joint. Cut joint =14.70' Change out seal rings and lay down GLM 9,523.0 0.0 4/14/2024 09:00 4/14/2024 09:30 0.50 COMPZN, RPCOMP RURD T Clean and clear rig floor, RD TBG tongs, hoses, change elevators and haul off oily waste. Install wear ring ID=6.375", OD=7", lenght 6.5" and RI 2 LDS. 0.0 0.0 4/14/2024 09:30 4/14/2024 13:00 3.50 COMPZN, RPCOMP PULD T PU DP signaling in to 2006.2', UPW=50K, DNW=50K. Set packer. 0.0 2,006.2 Rig: NABORS 7ES RIG RELEASE DATE 4/17/2024 Page 7/9 3G-09 Report Printed: 5/14/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/14/2024 13:00 4/14/2024 14:00 1.00 COMPZN, RPCOMP PRTS T PT the 7" casing T/2500 PSI F/15 min good test from 2000' to surface OA PSI at start = 0 PSI, OA PSI @ 2500 on IA = 15 PSI, bled back to zero after test First try bled off pretty fast so we swapped out the Gauge on the OA, and the Sensator on the IA. BHA bottm depth 2006.2' COE on packer at 2000'. 2,006.2 2,006.2 4/14/2024 14:00 4/14/2024 19:30 5.50 COMPZN, RPCOMP PULD T PU DP signaling in F/2005' T/7,018'' 117K UP 85K DN 2,006.2 7,018.0 4/14/2024 19:30 4/14/2024 20:30 1.00 COMPZN, RPCOMP PRTS T Set packer @ 7,000' C.O.E. Test 7" casing T/2500 PSI 15 min OA @ start = 0 PSI, OA with 2600 PSI on IA = 17 PSI PSI up to 2600 on IA , bleed to 2500 in 23 min, confirn not the leak that was seen before Unset packer, blow down lines Pump 2.3 BBLS, bleed back 2.3 BBLS 7,018.0 7,018.0 4/14/2024 20:30 4/14/2024 23:30 3.00 COMPZN, RPCOMP PULD T Single in hole F/7,018' T/9,533' 155K UP 90K DN Tag 3 1/2" TBG stump at 9,533' - rerun numbers on 3 1/2" TBG tally find that the set depth was 10' off, making TBG cut at 9,533' 7,018.0 9,533.0 4/14/2024 23:30 4/15/2024 00:00 0.50 COMPZN, RPCOMP PRTS T Set packer @ 9,529' - C.O.E. @ 9,523.11' R/U to test CSG 9,533.0 9,529.0 4/15/2024 00:00 4/15/2024 00:30 0.50 COMPZN, RPCOMP PRTS T Test casing from 9,523' Attempt to test casing to 2500 PSI Get to 2600 PSI, bled to 1500 PSI in 2 1/2 min OA = 0 at start, OA = 10 with 2600 PSI on IA 9,529.0 9,529.0 4/15/2024 00:30 4/15/2024 03:00 2.50 COMPZN, RPCOMP PULD T POOH, lay down DP to shed, testing 7" casing T/8,879' Test 7" casing at C.O.E. 9,438', 9,342', 9,247', 9,058', 8,869' Lost a total of 9 BBLS to hole 9,529.0 8,879.0 4/15/2024 03:00 4/15/2024 03:45 0.75 COMPZN, RPCOMP OWFF T After testing at 8,869', observe ~130 PSI on IA gauge, bleed off, open rams Flow check, slight flow due to loss of fluid trying to test casing, go static in 20 min Blow down lines 8,879.0 8,879.0 4/15/2024 03:45 4/15/2024 04:15 0.50 COMPZN, RPCOMP TRIP T POOH F/8,879' T/8,058' 8,879.0 8,058.0 4/15/2024 04:15 4/15/2024 05:00 0.75 COMPZN, RPCOMP PRTS T Set packer at 8,046' COE Test CSG to 2150 PSI - lose 100 PSI in 15 min Bleed off, pressure up to 2600 PSI lose 500 PSI in 5 min Bleed off pressure open rams 8,058.0 8,058.0 4/15/2024 05:00 4/15/2024 05:15 0.25 COMPZN, RPCOMP TRIP T POOH F/8,058' T/7,585' 8,058.0 7,585.0 Rig: NABORS 7ES RIG RELEASE DATE 4/17/2024 Page 8/9 3G-09 Report Printed: 5/14/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/15/2024 05:15 4/15/2024 05:30 0.25 COMPZN, RPCOMP PRTS T Set packer at 7,575'' COE Test casing to 2600 PSI lose 200 PSI in 4 min Bleed off 7,585.0 7,585.0 4/15/2024 05:30 4/15/2024 06:00 0.50 COMPZN, RPCOMP TRIP T POOH F/7,585' T/7,302' Set packer at 7,292' COE PPOOH set packer at 7,197' COE 7,585.0 7,207.0 4/15/2024 06:00 4/15/2024 06:30 0.50 COMPZN, RPCOMP PRTS T Set packer at 7,197' COE Test casing to 2500 PSI F/30 min 7,207.0 7,207.0 4/15/2024 06:30 4/15/2024 07:30 1.00 COMPZN, RPCOMP TRIP T TIH with DP from Derrick 7207' T/8815' PUW 145K/SOW 115K 7,207.0 8,815.0 4/15/2024 07:30 4/15/2024 11:30 4.00 COMPZN, RPCOMP PULD T LD DP to pipe shed 8,815.0 4,054.0 4/15/2024 11:30 4/15/2024 12:00 0.50 COMPZN, RPCOMP SVRG T Service Rig grease crown, blocks, black jack, draw works and roughneck. 4,054.0 4,054.0 4/15/2024 12:00 4/15/2024 16:00 4.00 COMPZN, RPCOMP PULD T Finish LD DP F/4054' T/0 4,054.0 0.0 4/15/2024 16:00 4/15/2024 16:30 0.50 COMPZN, RPCOMP RURD T Remove wear ring 0.0 0.0 4/15/2024 16:30 4/15/2024 19:30 3.00 COMPZN, RPCOMP RURD T Clean/prep rig floor, load jewlry in shed and rework the tally. 0.0 0.0 4/15/2024 19:30 4/16/2024 00:00 4.50 COMPZN, RPCOMP PUTB T MU Completion and start in the hole. Max 90 fpm. T/2,485' 55K UP 50K DN 0.0 2,485.0 4/16/2024 00:00 4/16/2024 08:15 8.25 COMPZN, RPCOMP PUTB T RIH W/3 1/2" completion as per detail F/2,485' T/9,495' 90K UP 65K DN 2,485.0 9,495.0 4/16/2024 08:15 4/16/2024 08:45 0.50 COMPZN, RPCOMP HOSO T Locate 3 1/2" tubing stump @ 3 BPM 260 PSI Locate pins at 18.5' in JT #302 shear at 12K DN, slack off no go at 24' in JT #302, set DN 10K, pick up slack off confirm tag depth @ 9,543.87' mule shoe depth 9,495.0 9,543.0 4/16/2024 08:45 4/16/2024 09:30 0.75 COMPZN, RPCOMP HOSO T Lay down JTS 302, 301, and 300, pick up 10.20', 10,18' and 4.10' pup JTS and JT #300 T/9519' 9,543.0 9,519.0 4/16/2024 09:30 4/16/2024 10:30 1.00 COMPZN, RPCOMP THGR T M/U TBG hanger, landing JT and circulating lines 9,519.0 9,519.0 4/16/2024 10:30 4/16/2024 12:30 2.00 COMPZN, RPCOMP DISP T PJSM, pump 300 BBLS CI seawater @ 3 BPM 275 PSI 9,519.0 9,519.0 4/16/2024 12:30 4/16/2024 13:15 0.75 COMPZN, RPCOMP THGR T Land TBG, RILDS 9,519.0 9,548.0 4/16/2024 13:15 4/16/2024 13:45 0.50 COMPZN, RPCOMP RURD T Drop 1 5/16" ball and rod with 2" rollers R/U test TBG and IA 9,548.0 9,548.0 4/16/2024 13:45 4/16/2024 15:00 1.25 COMPZN, RPCOMP PRTS T Pressure up to 3800 in 500 PSI steps as per SLBG to set packer Test TBG T/3500 PSI F/30 min Start PSI OA = 10, IA = 150, TBG = 3820 15 Min PSI OA =10, IA = 150, TBG = 3820 30 Min PSI OA = 10, IA = 150, TBG = 3820 9,548.0 9,548.0 Rig: NABORS 7ES RIG RELEASE DATE 4/17/2024 Page 9/9 3G-09 Report Printed: 5/14/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/16/2024 15:00 4/16/2024 15:45 0.75 COMPZN, RPCOMP PRTS T Bleed TBG to 1690 PSI Test IA T/2500 PSI F/30 Min Start PSI OA = 50, IA = 2600, TBG = 1950 15 Min PSI OA = 50 PSI, IA = 2600, TBG = 1950 30 Min PSI OA = 50 PSI, IA = 2600, TBG = 1950 Shear out SOV, confirm flow path with 3 BPM 450 PSI 9,548.0 9,548.0 4/16/2024 15:45 4/16/2024 16:00 0.25 COMPZN, RPCOMP RURD P R/D and B/D lines, lay down landing joint 9,548.0 0.0 4/16/2024 16:00 4/16/2024 16:30 0.50 COMPZN, RPCOMP MPSP P Test H-BPV Test from below T/1000 PSI F/10 min 0.0 0.0 4/16/2024 16:30 4/16/2024 18:00 1.50 COMPZN, RPCOMP RURD P B/D and rig down all lines 0.0 0.0 4/16/2024 18:00 4/16/2024 20:00 2.00 COMPZN, WHDBOP RURD P CO lower pipe rams to fixed 7-5/8" 0.0 0.0 4/16/2024 20:00 4/17/2024 00:00 4.00 COMPZN, WHDBOP RURD P Perform BWM Open all door cavities inspect all rams and seals. record condition and close doors and torques to spec. 0.0 0.0 4/17/2024 00:00 4/17/2024 02:00 2.00 COMPZN, WHDBOP RURD P Complete BWM Torque bolts on BOP stack 0.0 0.0 4/17/2024 02:00 4/17/2024 04:00 2.00 COMPZN, WHDBOP NUND P Remove flow nipple. Rack stack back on pedestal. 0.0 0.0 4/17/2024 04:00 4/17/2024 06:30 2.50 COMPZN, WHDBOP PRTS P Install test dart in top of HP BPV. Install adpater and tree. Test TBG adapter to 5000 PSI for 10 minutes. 0.0 0.0 4/17/2024 06:30 4/17/2024 08:00 1.50 COMPZN, WHDBOP RURD P RU circulating lines and LRS 0.0 0.0 4/17/2024 08:00 4/17/2024 09:45 1.75 COMPZN, WHDBOP PRTS P Test Tree to 5000 PSI with LRS Notice SSSV closed - rig up fittings, open SSSV test tree to 5000 PSI 0.0 0.0 4/17/2024 09:45 4/17/2024 10:15 0.50 COMPZN, WHDBOP MPSP P Pull test dart and BPV 0.0 0.0 4/17/2024 10:15 4/17/2024 11:00 0.75 COMPZN, WHDBOP CIRC P LRS Pump 75 BBLs diesel down the IA taking returns to the kill tank. at 3 BPM @ 500 PSI. 0.0 0.0 4/17/2024 11:00 4/17/2024 12:00 1.00 COMPZN, WHDBOP FRZP P Shut in well, line up and blow down all lines Hook up jumper hose, line up and U- Tube well until PSI equalized SimOps - prep to move rig equipment and clean up cellar area 0.0 0.0 4/17/2024 12:00 4/17/2024 14:00 2.00 DEMOB, MOVE RURD P Shut in secure well, obtain final pressures on TBG,IA and OA Cont clean up in cellar area, prep rig for move 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 4/17/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Est. 89' of Fill) 9,999.0 3G-09 2/5/2019 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set GLD, Pulled B &R's, Pulled RHC's, Pulled Catcher & RBP 3G-09 5/2/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: HOLE FINDER FOUND LEAK IN PRODUCTION MANDREL @ 9,714' RKB 6/29/2017 pproven NOTE: ATTEMPTED PPROF, MAX TENSION 9880', POSSIBLE CORKSCREWED TUBING 5/31/2011 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.0 4,538.4 3,079.2 36.00 J-55 BTC PRODUCTION 7 6.28 35.0 10,300.0 5,976.8 26.00 J-55 BTC AB-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 33.2 Set Depth … 9,557.4 String Max No… 3 1/2 Set Depth … 5,671.8 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-M 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) 33.2 33.2 0.12 Hanger 7.010 Cameron CXS TBG Hanger W/3 1/2 EUEM Lift threads - 3" H Stlye BPV Camero n CXS 2.950 3,312.9 2,502.5 62.31 Mandrel – GAS LIFT 6.055 3 1/2" x 1.5" MMG GLM MMG SLB 2.920 5,661.9 3,662.3 56.90 Mandrel – GAS LIFT 5.940 3 1/2" x 1.5" MMG GLM MMG SLB 2.920 6,463.1 4,088.0 58.34 Mandrel – GAS LIFT 6.002 3 1/2" x 1.5" MMG GLM MMG SLB 2.920 7,044.3 4,392.4 58.42 Mandrel – GAS LIFT 6.025 3 1/2" x 1.5" MMG GLM MMG SLB 2.920 7,104.0 4,423.6 58.64 PACKER 6.276 3.5"x7" SLB BluePack Cut-To- Release packer SLB Bluepac k MAX 2.885 7,159.2 4,452.2 58.99 Mandrel – GAS LIFT 6.025 3 1/2" x 1.5" MMG GLM MMG SLB 2.920 9,472.1 5,630.4 60.84 PACKER 6.276 3.5"x7" SLB BluePack Cut-To- Release packer SLB Bluepac k MAX 2.885 9,529.2 5,658.2 61.10 Nipple - X 4.480 3.5" X Nipple 2.813" Halliburt on 2.813" Xnipple 2.813 9,550.6 5,668.5 61.23 Overshot 4.520 3-1/2" Poor Boy Non Sealing Overshot Baker Non sealing 2.960 Top (ftKB) 9,553.0 Set Depth … 9,664.3 String Max No… 3 1/2 Set Depth … 5,722.6 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-M 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) 9,578.3 5,681.8 61.41 PACKER 6.276 3.5"x7" SLB BluePack Cut-To- Release packer SLB Bluepac k MAX 2.885 9,635.9 5,709.2 61.74 Nipple - X 4.480 3.5" X Nipple 2.813" Halliburt on Xnipple 2.813 9,657.4 5,719.3 61.85 Overshot 4.520 3-1/2" Poor Boy Non Sealing Overshot Baker Non sealing 3.000 Top (ftKB) 9,660.0 Set Depth … 9,885.3 String Max No… 4 1/2 Set Depth … 5,822.9 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.20 Grade L-80 Top Connection BTC-MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,684.4 5,732.0 62.00 PBR 5.000 BAKER 10' STROKE PBR 3.000 9,698.0 5,738.5 62.07 PACKER 6.062 BAKER HB RETRIEVABLE PACKER 2.890 9,714.4 5,746.1 62.23 PRODUCTION 5.968 CAMCO MMG-W 2.867 9,732.6 5,754.5 62.42 BLAST RINGS 4.500 CARBIDE BLAST RINGS (3) 2.992 9,827.4 5,797.7 63.66 NIPPLE 4.540 AVA BPL NIPPLE 2.697 9,859.4 5,811.7 64.30 XO Reducing 3.500 CROSSOVER 3.5 x 2.875 2.875 9,860.2 5,812.1 64.32 SEAL ASSY 3.470 BAKER LOCATOR SEAL ASSEMBLY 2.406 9,862.2 5,812.9 64.36 PACKER 5.687 BAKER DB PERMANENT PACKER 3.250 9,865.8 5,814.5 64.43 SBE 4.250 BAKER SEAL BORE EXTENSION 3.250 9,876.9 5,819.3 64.66 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 9,884.6 5,822.5 64.81 SOS 3.750 BAKER SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 9,714.0 5,745.9 62.22 TUBING LEAK HOLE FINDER FOUND LEAK IN PRODUCTION MANDREL @ 9,714' RKB 6/29/2017 2.992 9,827.0 5,797.5 63.65 SLEEVE 2.75" AVA BPC SLEEVE 7/3/2017 10,035.0 5,882.9 67.84 FISH 1 1/2" OV Dropped in Hole 2/12/1995 0.000 3G-09, 5/14/2024 9:51:20 AM Vertical schematic (actual) PRODUCTION; 35.0-10,300.0 IPERF; 10,048.0-10,088.0 FISH; 10,035.0 APERF; 9,940.0-10,010.0 PACKER; 9,862.2 SLEEVE; 9,827.0 IPERF; 9,754.0-9,812.0 PRODUCTION; 9,714.4 TUBING LEAK; 9,714.0 PACKER; 9,698.0 Nipple - X; 9,635.9 PACKER; 9,578.3 Nipple - X; 9,529.2 PACKER; 9,472.1 Mandrel – GAS LIFT; 7,159.2 PACKER; 7,104.0 Mandrel – GAS LIFT; 7,044.3 Mandrel – GAS LIFT; 6,463.1 Mandrel – GAS LIFT; 5,661.8 SURFACE; 35.0-4,538.4 Mandrel – GAS LIFT; 3,312.9 CONDUCTOR; 36.0-115.0 Hanger; 33.2 KUP PROD KB-Grd (ft) 36.29 RR Date 6/14/1990 Other Elev… 3G-09 ... TD Act Btm (ftKB) 10,322.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032012900 Wellbore Status PROD Max Angle & MD Incl (°) 69.53 MD (ftKB) 10,129.99 WELLNAME WELLBORE3G-09 Annotation Last WO: End Date 4/17/2024 H2S (ppm) 80 Date 11/27/2016 Comment SSSV: LOCKED OUT Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,312.9 2,502.5 62.31 1 GAS LIFT GLV RK 1 1/2 1,235.0 4/30/2024 SLBG MMG 0.313 5,661.9 3,662.3 56.90 2 GAS LIFT DV RK 5.94 4/16/2024 SLBG MMG 6,463.1 4,088.0 58.34 3 GAS LIFT GLV RK 1 1/2 1,265.0 5/1/2024 SLBG MMG 0.375 7,044.3 4,392.4 58.42 4 GAS LIFT OV RK 1 1/2 4/30/2024 SLBG MMG 0.313 7,159.2 4,452.2 58.99 5 GAS LIFT DV RK 6.02 5 4/16/2024 SLBG MMG Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,754.0 9,812.0 5,764.4 5,790.8 C-4, UNIT B, 3G -09 10/11/1990 10.0 IPERF 60 deg. phasing; 4 1/2" Hollow Carrier 9,940.0 10,010.0 5,845.6 5,873.4 A-4, A-3, 3G-09 8/20/1991 8.0 APERF 90 deg. phasing; 2 1/8" DynaStrip Gun 10,048.0 10,088.0 5,887.8 5,902.5 A-2, 3G-09 10/11/1990 4.0 IPERF 180 deg. phasing; 4 1/2" Hollow Carrier 3G-09, 5/14/2024 9:51:21 AM Vertical schematic (actual) PRODUCTION; 35.0-10,300.0 IPERF; 10,048.0-10,088.0 FISH; 10,035.0 APERF; 9,940.0-10,010.0 PACKER; 9,862.2 SLEEVE; 9,827.0 IPERF; 9,754.0-9,812.0 PRODUCTION; 9,714.4 TUBING LEAK; 9,714.0 PACKER; 9,698.0 Nipple - X; 9,635.9 PACKER; 9,578.3 Nipple - X; 9,529.2 PACKER; 9,472.1 Mandrel – GAS LIFT; 7,159.2 PACKER; 7,104.0 Mandrel – GAS LIFT; 7,044.3 Mandrel – GAS LIFT; 6,463.1 Mandrel – GAS LIFT; 5,661.8 SURFACE; 35.0-4,538.4 Mandrel – GAS LIFT; 3,312.9 CONDUCTOR; 36.0-115.0 Hanger; 33.2 KUP PROD 3G-09 ... WELLNAME WELLBORE3G-09 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? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10300 10035' 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: 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: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 9754-9812' 9940-10010' 10048-10088' 10265' 5764-5791' 5846-5873' 5888-5903'3-1/2"x2-7/8" 7" 16" 9-5/8" 79' 4503' Perforation Depth MD (ft): MD 115' 3079' 115' 4538' 5977'10300 Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 5977 10088 5903 2609 None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025548, ADL0025547 190-067 P.O. Box 100360, Anchorage, AK 99510 50-103-20129-00-00 ConocoPhillips Alaska, Inc. KRU 3G-09 NoneKuparuk Oil PoolKuparuk River Field N/A Tubing Grade:Tubing MD (ft): Packer: 9698'MD/5738'TVD Packer: 9862'MD/5813'TVD SSSV: 1814'MD/1696'TVD Perforation Depth TVD (ft):Tubing Size: L-80 9885' 4/1/2024 Packer: Baker HB Packer: Baker DB SSSV: CAMCO TRDP 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Shane Germann shane.germann@conocophillips.com (907) 263-4597 CTD/RWO Engineer P s 66 t Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 324-089 By Kayla Junke at 2:31 pm, Feb 15, 2024 Digitally signed by Shane Germann DN: O=ConocoPhillips Alaska, CN=Shane Germann, E=shane.germann@cop.com Reason: I have reviewed this document Location: Date: 2024.02.15 10:08:39-09'00' Foxit PDF Editor Version: 13.0.0 5,98810,332* BOP test to 3000 psig Annular preventer test to 2500 psig Obsolete form. SFD VTL 2/26/2024 DSR-2/15/24 X 10-404 * Well Completion Rpt submitted 3/19/91 SFD X SFD 2/24/2024*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.02.26 15:45:25 -09'00'02/26/24 RBDMS JSB 022724 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 14, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Shane Germann Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 3G-09 (PTD# 190-067). Well 3G-09 was drilled and completed 1990 as a Kuparuk A/C sand producer. The well was patched in 2017 and again in 2019 to remediate tubing leaks. In 2023, the well failed a TIFL and subsequent diagnostics revealed a third tubing leak below the patches at approximately 8375' RKB. If you have any questions or require any further information, please contact me at +1-406-670-1939. In order to bring the well back online we request approval to proceed with a RWO to replace the tubing with new and stack a production packer. There is a moderate risk of seeing subsidence drift issues through the 7" casing on this well, so a contingency scope for a subsidence repair is also described in the summary section. Digitally signed by Shane Germann DN: O=ConocoPhillips Alaska, CN= Shane Germann, E=shane.germann@ cop.com Reason: I have reviewed this document Location: Date: 2024.02.15 10:09:04-09'00' Foxit PDF Editor Version: 13.0.0 3G-09 RWO Procedure Kuparuk Producer P&R Tubing PTD #190-067 Page 1 of 3 Pre-Rig Work 1. T-PPPOT, T-POT, IC-PPPOT, and IC-POT tests. 2. Pull tubing patches. 3. Measure SBHP. 4. Set RBP at 9705’ RKB. 5. CMIT-TxIA to 2500 psig. 6. Pull all GLVs and install DVs. Leave lowest GLM open for circulation point. 7. Cut tubing at ~9658’ RKB. 8. Prepare well within 48-96 hrs of rig arrival. Confirm no gas in OA, IA, or tubing. Rig Work MIRU 1. MIRU Nabors 7ES on 3G-09. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3,000 psi. Test annular 250/2,500 psi. Retrieve 3-1/2” Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to pre-rig cut at ~9658’ RKB a. Contingency: If not all tubing comes due to subsidence, then work additional steps below to clear buckled 7”, then pull remaining completion. i. RU Eline. ii. Set tubing down on cut stub. iii. Cut tubing at ~3000’. PU tubing again. iv. RIH and set IBP near 3000’ RKB in 7” casing between tubing sections. v. PT from above to confirm as barrier. vi. Dump sand on IBP through tubing again. vii. Set remaining tubing back down on IBP sand. viii. If can get completion out, RU Eline and log 7.0” casing for OA cement from Arctic Pack job. ix. Jump forward to SUBSIDENCE CONTINGENCY step (Cleanout Run 12, a.) Swap Tubing Spool 6. PU storm packer and set at ~100’. Test to 3,000 psi for 30 minutes. 7. ND BOPE and ND tubing spool. Install Cameron Type C Tubing Spool per Cameron. 8. The 7” casing is set on slips. If needed, RU hydratight and cut excess casing. Grow/stretch 7” casing as needed. Set 7” casing on slips. 9. Test Casing Hanger void and seals to 3,000 psi 10. NU BOPE and test break to 3,000 psi 11. Retrieve storm packer. Close annular and circulate surface to surface once unset. LD remaining tubing. Cleanout Run 12. Perform a Cleanout run if necessary based on tubing condition and dress off 3.5” tubing stub if necessary. a. SUBSIDENCE CONTINGENCY: If at any time we are unable to drift 7” casing i. RU eline for CBL log, log from ~3000’ up to locate TOC ii. RIH and set RBP or IBP in 7” below TOC. Confirm plug is set. Place 50’ of sand on top of RBP or IBP. (if not done previously) iii. Modify BOP stack for future 7” casing work (if not done for initial NU and testing) 3G-09 RWO Procedure Kuparuk Producer P&R Tubing PTD #190-067 Page 2 of 3 x Install 7” fixed pipe rams x Run Test plug & pressure test to 250/3000 psi iv. ND BOPE and ND tubing spool. Remove packoff. NU BOPE to production casing head. (unable to test BOPE flange break at this point due to removal of packoffs, will test as soon as 7” is out). x Grow/stretch and cut 7” casing at this point if not done previously v. RIH and cut 7” casing above TOC. TOOH. vi. Spear casing and POOH laying down casing. Install test plug and test flange break to 3000 psig. Remove test plug. x Pull any remaining 3.5” tubing set on top of IBP. Make additional 7” cut and pull as needed to clear adequate amount of 7” for re-tie-in of new 7”. vii. MU and utilize tandem string mills and cleanout BHA’s as needed to open up 9-5/8” surface casing to drift new 7” casing tie-back. viii. RIH and dress off 7” casing stump. ix. RIH with 7” Tie back with external casing patch and cementer. Test casing to 2500psig. x. Cement annulus of 7” x 9 5/8” Casing to surface. xi. Perform 30 minute no flow test, Split stack and land slips, cut excess casing and install IC packoffs. xii. NU new tubing head and BOP stack. x Test Flange break to 250/3000 psi xiii. Mill Cement/ plugs in cementer xiv. Circulate out sand and pull IBP(s). xv. Pull any remaining tubing if left in hole. Perform cleanout/dress-off runs for tubing stub as necessary. Install 3-½” Tubing with Stacked Packer 13. MU 3-1/2” completion with poorboy overshot, packer, nipples, and GLMs. RIH to tubing stub. 14. Once on depth, circulate CI brine, space out as needed, land hanger, RILDS, drop B&R, and set packer. 15. Pressure test tubing to 3,000 psig for 30 minutes and chart. 16. Pressure test inner annulus to 2,500 psig for 30 minutes and chart. ND BOP, NU Tree 17. Confirm pressure tests, then shear out SOV with pressure differential. 18. Install BPV. 19. ND BOPE. NU tree. 20. Pull BPV and freeze protect well 21. RDMO. Post-Rig Work 22. Run GLD. Pull any plugs or ball/rod used for setting packer. 3G-09 RWO Procedure Kuparuk Producer P&R Tubing PTD #190-067 Page 3 of 3 General Well info: Wellhead type/pressure rating: WKM Gen IV, 5M psi top flange x 3M bottom flange Production Engineer: Brian Lewis Reservoir Development Engineer: Lynn Aleshire Estimated Start Date: 4/1/2024 Workover Engineer: Shane Germann (406-670-1939 / shane.germann@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion to a pre-rig cut directly above the top packer, install a new 3-1/2” completion and stacked packer. Swap tubing spool. 7” casing subsidence repair contingency. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: CMIT-TxIA: Passed (2500 psig, 11/24/2023) MIT-OA: Passed (1800 psig, 12/18/2023) IC POT & PPPOT PASSED – 12/18/2023 TBG POT & PPPOT PASSED – 12/18/2023 MPSP: 2609 psi using 0.1 psi/ft gradient Static BHP: 2499 psi / 4369’ TVD measured on 09/22/2023+ 0.492 psi/ft estimated gradient between pressure measurement and top of perforations at 5,764’ TVD (3185 psi, 10.6 ppg) 10.6 ppg) Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Est. 89' of Fill) 9,999.0 3G-09 2/5/2019 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set RBP, left catcher w/ stinger on top. Pulled DMY, left open pocket 3G-09 11/23/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: HOLE FINDER FOUND LEAK IN PRODUCTION MANDREL @ 9,714' RKB 6/29/2017 pproven NOTE: ATTEMPTED PPROF, MAX TENSION 9880', POSSIBLE CORKSCREWED TUBING 5/31/2011 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.0 4,538.4 3,079.2 36.00 J-55 BTC PRODUCTION 7 6.28 35.0 10,300.0 5,976.8 26.00 J-55 BTC AB-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 33.2 Set Depth … 9,885.3 Set Depth … 5,822.8 String Max No… 3 1/2 Tubing Description TUBING 3.5"x2.875" @9860' Wt (lb/ft) 9.20 Grade L-80 Top Connection EUE-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) 33.2 33.2 0.12 HANGER 8.000 WKM GEN IV HANGER 3.500 1,814.4 1,696.4 40.50 SAFETY VLV 5.937 CAMCO TRDP-1A-SSA SAFETY VALVE (Locked Out 9/4/94) 2.812 3,115.3 2,411.4 62.46 GAS LIFT 5.620 MERLA TMPD 2.875 5,948.3 3,817.3 57.81 GAS LIFT 5.620 MERLA TMPD 2.875 6,936.7 4,335.9 58.35 GAS LIFT 5.620 MERLA TMPD 2.875 7,710.7 4,737.0 58.34 GAS LIFT 5.620 MERLA TMPD 2.875 8,513.9 5,154.2 59.40 GAS LIFT 5.620 MERLA TMPD 2.875 9,101.5 5,449.7 60.58 GAS LIFT 5.620 MERLA TMPD 2.875 9,635.0 5,708.8 61.74 GAS LIFT 5.793 CAMCO MMG-2 2.920 9,684.3 5,732.0 62.00 PBR 5.000 BAKER 10' STROKE PBR 3.000 9,698.0 5,738.4 62.07 PACKER 6.062 BAKER HB RETRIEVABLE PACKER 2.890 9,714.3 5,746.1 62.23 PRODUCTION 5.968 CAMCO MMG-W 2.867 9,732.5 5,754.5 62.41 BLAST RINGS 4.500 CARBIDE BLAST RINGS (3) 2.992 9,827.3 5,797.7 63.66 NIPPLE 4.540 AVA BPL NIPPLE 2.697 9,859.4 5,811.7 64.30 XO Reducing 3.500 CROSSOVER 3.5 x 2.875 2.875 9,860.1 5,812.0 64.32 SEAL ASSY 3.470 BAKER LOCATOR SEAL ASSEMBLY 2.406 9,862.1 5,812.9 64.36 PACKER 5.687 BAKER DB PERMANENT PACKER 3.250 9,865.8 5,814.5 64.43 SBE 4.250 BAKER SEAL BORE EXTENSION 3.250 9,876.8 5,819.2 64.65 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 9,884.5 5,822.5 64.81 SOS 3.750 BAKER SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,049.0 4,394.9 58.44 TUBING LEAK TUBING LEAK AT ~7049 8/31/2019 2.992 7,543.0 4,649.4 58.89 LEAK 7/21/2017 8,375.0 5,083.1 58.83 LEAK TBG LEAK IDENTIFIED BY EL AT 8375' RKB 10/23/2023 2.992 9,700.0 5,739.4 62.08 CATCHER Set Catcher w/ PIIP no-go stinger on top of RBP (OAL = 64") 11/22/2023 0.000 9,705.6 5,742.0 62.14 RBP Set 2.725 PIIP RBP mid- element @ 9708' (OAL = 7.96') TTS PIIP CPP3 5313/ CPEQ 35028 11/22/2023 0.000 9,714.0 5,745.9 62.22 TUBING LEAK HOLE FINDER FOUND LEAK IN PRODUCTION MANDREL @ 9,714' RKB 6/29/2017 2.992 9,827.0 5,797.5 63.65 SLEEVE 2.75" AVA BPC SLEEVE 7/3/2017 10,035.0 5,882.9 67.84 FISH 1 1/2" OV Dropped in Hole 2/12/1995 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,115.3 2,411.4 62.46 1 GAS LIFT DMY BK 1 0.0 9/26/2023 0.000 5,948.3 3,817.3 57.81 2 GAS LIFT DMY BK 1 0.0 9/26/2023 0.000 6,936.7 4,335.9 58.35 3 GAS LIFT DMY BK 1 0.0 9/26/2023 0.000 7,710.7 4,737.0 58.34 4 GAS LIFT DMY BK 1 0.0 7/21/2017 0.000 8,513.9 5,154.2 59.40 5 GAS LIFT DMY BK 1 0.0 7/15/2003 0.000 9,101.5 5,449.7 60.58 6 GAS LIFT DMY BK 1 0.0 7/26/1998 0.000 9,635.0 5,708.8 61.74 7 GAS LIFT OPEN 1 1/2 0.0 11/23/2023 1.500 9,714.3 5,746.1 62.23 8 PROD DMY RK 1 1/2 0.0 5/5/1995 0.000 3G-09, 11/24/2023 6:00:00 AM Vertical schematic (actual) PRODUCTION; 35.0-10,300.0 FLOAT SHOE; 10,298.2- 10,300.0 FLOAT COLLAR; 10,213.7- 10,215.3 IPERF; 10,048.0-10,088.0 FISH; 10,035.0 APERF; 9,940.0-10,010.0 SOS; 9,884.5 NIPPLE; 9,876.8 SBE; 9,865.7 PACKER; 9,862.1 SEAL ASSY; 9,860.1 NIPPLE; 9,827.3 SLEEVE; 9,827.0 IPERF; 9,754.0-9,812.0 PRODUCTION; 9,714.3 TUBING LEAK; 9,714.0 RBP; 9,705.6 CATCHER; 9,700.0 PACKER; 9,684.6-9,719.0 PACKER; 9,698.0 PBR; 9,684.3 GAS LIFT; 9,635.0 GAS LIFT; 9,101.5 GAS LIFT; 8,513.9 LEAK; 8,375.0 GAS LIFT; 7,710.7 TUBING LEAK; 7,049.0 GAS LIFT; 6,936.7 GAS LIFT; 5,948.3 SURFACE; 35.0-4,538.4 FLOAT SHOE; 4,536.7-4,538.4 FLOAT COLLAR; 4,456.1- 4,457.6 GAS LIFT; 3,115.3 SAFETY VLV; 1,814.4 CONDUCTOR; 36.0-115.0 HANGER; 35.0-39.7 HANGER; 33.2 KUP PROD KB-Grd (ft) 36.29 RR Date 6/14/1990 Other Elev… 3G-09 ... TD Act Btm (ftKB) 10,322.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032012900 Wellbore Status PROD Max Angle & MD Incl (°) 69.53 MD (ftKB) 10,129.99 WELLNAME WELLBORE3G-09 Annotation Last WO: End DateH2S (ppm) 80 Date 11/27/2016 Comment SSSV: LOCKED OUT Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,754.0 9,812.0 5,764.4 5,790.8 C-4, UNIT B, 3G -09 10/11/1990 10.0 IPERF 60 deg. phasing; 4 1/2" Hollow Carrier 9,940.0 10,010.0 5,845.6 5,873.4 A-4, A-3, 3G-09 8/20/1991 8.0 APERF 90 deg. phasing; 2 1/8" DynaStrip Gun 10,048.0 10,088.0 5,887.8 5,902.5 A-2, 3G-09 10/11/1990 4.0 IPERF 180 deg. phasing; 4 1/2" Hollow Carrier 3G-09, 11/24/2023 6:00:01 AM Vertical schematic (actual) PRODUCTION; 35.0-10,300.0 FLOAT SHOE; 10,298.2- 10,300.0 FLOAT COLLAR; 10,213.7- 10,215.3 IPERF; 10,048.0-10,088.0 FISH; 10,035.0 APERF; 9,940.0-10,010.0 SOS; 9,884.5 NIPPLE; 9,876.8 SBE; 9,865.7 PACKER; 9,862.1 SEAL ASSY; 9,860.1 NIPPLE; 9,827.3 SLEEVE; 9,827.0 IPERF; 9,754.0-9,812.0 PRODUCTION; 9,714.3 TUBING LEAK; 9,714.0 RBP; 9,705.6 CATCHER; 9,700.0 PACKER; 9,684.6-9,719.0 PACKER; 9,698.0 PBR; 9,684.3 GAS LIFT; 9,635.0 GAS LIFT; 9,101.5 GAS LIFT; 8,513.9 LEAK; 8,375.0 GAS LIFT; 7,710.7 TUBING LEAK; 7,049.0 GAS LIFT; 6,936.7 GAS LIFT; 5,948.3 SURFACE; 35.0-4,538.4 FLOAT SHOE; 4,536.7-4,538.4 FLOAT COLLAR; 4,456.1- 4,457.6 GAS LIFT; 3,115.3 SAFETY VLV; 1,814.4 CONDUCTOR; 36.0-115.0 HANGER; 35.0-39.7 HANGER; 33.2 KUP PROD 3G-09 ... WELLNAME WELLBORE3G-09 3G-09 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 115 115 16 15.06 62.5 H-40 Surface 4538 3079 9-5/8 8.92 36 J-55 BTC BTC Production 10300 5976 7 6.28 26 J-55 BTC BTC Tubing 9885 5822 3-1/2 2.99 9.2 L-80 EUEM EUEM PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco MMG gas lift mandrels @ 3278', 5620', 6430', 7005', 9547' RKB (approximate depths) Cut to Release Packer @ ~9603' RKB (4" ID) X-Nipple @ 9657' RKB (2.813" ID) 3-1/2" Non-sealing Overshot REMAINING COMPLETION LEFT IN HOLE 3-1/2" Tubing Stub @~9658' RKB Baker PBR @ 9684' RKB (4" sealbore) Baker HB Retrievable Packer @ 9697' RKB (2.89" ID) 3-1/2" Camco MMG GLM @ 9714' RKB 3-1/2" IPC tubing w/ Carbide Blast Rings AVA BPL Nipple @ 9827' RKB (2.75" ID) 3-1/2" to 2-7/8" reducing crossover @ 9859' RKB Baker Locator/Seal Assembly spaced out 1' above packer Baker 2-7/8" x 7" DB perm packer @ 9862 RKB Baker SBE @ 9865' RKB (3.25" ID) Camco D-nipple @ 7332' RKB (2.25" ID) Baker 2-7/8" SOS @ 9884' RKB Surface Casing Production/Intermediate Casing Conductor A-sand perfs 9940' - 10,088' RKB C-sand perfs 9754' - 9812' RKB Bl a s t Ri n g s 3G-09 Subsidence Contingency RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 115 115 16 15.06 62.5 H-40 Surface 4538 3079 9-5/8 8.92 36 J-55 BTC BTC Production 10300 5976 7 6.28 26 J-55 BTC BTC Tubing 9885 5822 3-1/2 2.99 9.2 L-80 EUEM EUEM PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco MMG gas lift mandrels @ 3278', 5620', 6430', 7005', 9547' RKB (approximate depths) Cut to Release Packer @ ~9603' RKB (4" ID) X-Nipple @ 9657' RKB (2.813" ID) 3-1/2" Non-sealing Overshot REMAINING COMPLETION LEFT IN HOLE 3-1/2" Tubing Stub @~9658' RKB Baker PBR @ 9684' RKB (4" sealbore) Baker HB Retrievable Packer @ 9697' RKB (2.89" ID) 3-1/2" Camco MMG GLM @ 9714' RKB 3-1/2" IPC tubing w/ Carbide Blast Rings AVA BPL Nipple @ 9827' RKB (2.75" ID) 3-1/2" to 2-7/8" reducing crossover @ 9859' RKB Baker Locator/Seal Assembly spaced out 1' above packer Baker 2-7/8" x 7" DB perm packer @ 9862 RKB Baker SBE @ 9865' RKB (3.25" ID) Camco D-nipple @ 7332' RKB (2.25" ID) Baker 2-7/8" SOS @ 9884' RKB Surface Casing Production/Intermediate Casing Conductor A-sand perfs 9940' - 10,088' RKB C-sand perfs 9754' - 9812' RKB Bl a s t Ri n g s est. TOC @ ~2090' 7" tie-back cemented to surface 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Secure well Development Exploratory 190-067 Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10300 feet 9705 feet true vertical 5977 feet N/A feet Effective Depth measured 10088 feet 9698 feet true vertical 5903 feet 5738 feet Perforation depth Measured depth 9754 -10088 feet True Vertical depth 5764 - 5903 feet Tubing (size, grade, measured and true vertical depth) 3.5 L-80 9860 MD 5813 TVD Packers and SSSV (type, measured and true vertical depth)Baker HB Retrievabl 9698 MD/ 5738 TVD Baker DB permanent 9862 MD/ 5813 TVD Camco TRDP-1A-SS1814 MD/1696 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Jan Byrne Contact Email:jan.byrne@conocophillip.com Authorized Title: Well Integrity Specialist Contact Phone: Collapse 597710300Production Liner 10265 Intermediate 16 9.625 measured TVDCasing Structural 4538 3079 11579 4503 115Conductor Surface STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 50-103-20129-00 Size N/A 5. Permit to Drill Number:4. Well Class Before Work: ADL0025548 and ADL0025547 Kuparuk/ Kuparuk River Oil 2. Operator Name: ConocoPhillips, Inc. Plugs Junk measured Length Burst N/A N/A N/AN/A P.O. Box 100360 Anchorage, Alaska 995123. Address: KRU 3G-09 measured true vertical Packer MD N/A Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 7 N/A N/AN/A 323-631 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG N/A Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 907-265-6471 Gas-Mcf N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) sp pp p p ck k k k ift tttttt nttttt e Fra O g g s g yyy 190 e 6. A y GGJ LLLLLL PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:20 pm, Dec 06, 2023 Digitally signed by Jan Byrne DN: OU=Well Integrity, O=AK Wells, CN=Jan Byrne, E =jan.byrne@conocophillips.com Reason: I am the author of this document Location: Anchorage tower Date: 2023.12.06 15:00:15-09'00' Foxit PDF Editor Version: 13.0.0 Jan Byrne 3G-09 Was reported for IA SCP on 10/31/23. Slickline began work to secure the well on 11/12/23 after a phase 3 weather condition which shut down field work for 3-5 days. Slickline was unable to remove the patches with .125 & .160 wire. Braided line was also unable to pull the patches. On 11/20/23 it was noted that the OA SCP had exceeded 45% of burst of the surface casing and a 10- 403 was submitted for the patch removal and secure work. Coil completed pulling the patches and Relay was able to set the RBP for secure. The wellbore was circulated out with corrosion inhibited seawater and diesel freeze protect and passed a CMIT TxIA. The well remains secure. Further information is forthcoming in the response to the notice of investigation. DATE WELL SUMMARYOPS 10/31/2023 3G-09 Victoria, KRU 3G-09 (PTD 190-067) is exhibiting Sustained Casing Pressure on the IA, currently at 2200 psi. The intermediate casing is 7¿, 26 lb/ft, J-55 which has a burst rating of 4980 psi (45% of burst is 2241 psi). In addition, there is 9-5/8¿, 36 lb/ft, J-55 surface casing with a burst rating of 3520 psi. The well has been shut in since September 18, 2023 due to a failed TIFL. An LDL was just completed which located an additional tubing leak below the existing patches. The plan is for Slickline to secure the well ASAP. Please let me know if you disagree or have any questions with this plan. 11/12/2023 3G-09 BRUSH n' FLUSH TBG TO 7043' RKB TBG OPEN 2.76", PULLED 2.72" P2P UPPER PATCH ASSEMBLY @ 7043' RKB, PULLED 2.72" LOWER P2P @ 7059' RKB, JARRED ON 2.72" P2P PATCH ASSEMBLY @ 7632' RKB FOR 30 MIN'S. (3 1/2 TTS PULLING TOOL LEFT IN HOLE) IN PROGRESS. 11/13/2023 3G-09 JAR ON PATCH @ 7632' RKB FOR 45 MIN'S, 3 1/2 TTS PULLING TOOL PULLED FREE WICKERS ON PULLING TOOL ROLLED. ATTEMPT TO ENGAGE 2.72" P2P WITH NEW 3 1/2 TTS PULLING TOOL FN DAMAGED. SET 3 1/2 RDW W/ 2.45" GRAPPLE UNABLE STAY ENGAGED IN FN. SET 3 1/2 RDW W/ 2.48" GRAPPLE IN 2.72" P2P @ 7632' RKB, JAR ON PATCH FOR 2 HR's WITH NO MOVEMENT. JOB IN PROGRESS. 11/14/2023 3G-09 JAR ON 2.72" P2P PATCH ASSEMBLY W/ .125 WIRE FOR 1 HR NO MOVEMENT, JAR ON PATCH ASSEMBLY @ 7632' RKB FOR 3 HR's W/ .160 WIRE NO MOVEMENT. IN PROGRESS. 11/15/2023 3G-09 JAR ON 2.72" P2P PATCH ASSEMBLY @ 7632' RKB FOR 2 HR"s WITH .160 WIRE @ 3000 LB. NO MOVEMENT. JOB SUSPENDED FOR PLAN FORWARD. ***NOTE - BAITED RDW SPEAR W/ 2.48" GRAPPLE LEFT IN HOLE*** 11/17/2023 3G-09 MADE TWO ATTEMPS TO PULL 2.72" PIIP PATCH ASSEMBLY @ 7632' RKB, 6000 LB OJ , 8000 LB STRAIGHT PULL, PULLED RDW GRAPPLE FREE @ 3200 LBS ON SECOND ATTEMPT, SUSPECT FISH-NECK SPLIT, RDMO BRAIDED LINE, WELL READY FOR PLAN FOWARD. 11/20/2023 3G-09 LATCHED UP AT 7602' PULLED 20 K OVER AND 1 JAR HIT PULLED FREE UPPER PACKER AND SPACER PIPE HAVE BEEN RECOVERED TAGGED LOWER PACKER AT 7627' TWO JAR HITS CAME FREE LOWER PACKER HAS BEEN RECOVERED ****JOB COMPLETE **** 11/21/2023 3G-09 Submitted 10-403 for intervention work with SCP in excess of 45% burst. 11/22/2023 3G-09 SET 2.72" P2P RBP (7.91' OAL) @ 9708 MID ELEMENT, SET CATCHER BASKET W/ P2P NO- GO BTM SUB ON RBP @ 9706' RKB 11/23/2023 3G-09 PULLED DV FROM STATION # 7 9635 RKB, ***CATCHER LEFT IN HOLE ON TOP OF P2P RBP (64" OAL)*** 11/24/2023 3G-09 CIRC OUT WELL, PUMPING DWN TBG TAKING RETURNS OUT IA TO PRODUCTION. 280 BBLS OF SW W/CRW FOLLOWED BY 80 BBLS OF DSL, U-TUBE FOR FREEZE PROTECT CMIT TxIA TO 2500 PSI. PASSED JOB COMPLETE Executive Summary Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Est. 89' of Fill) 9,999.0 3G-09 2/5/2019 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set RBP, left catcher w/ stinger on top. Pulled DMY, left open pocket 3G-09 11/23/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: HOLE FINDER FOUND LEAK IN PRODUCTION MANDREL @ 9,714' RKB 6/29/2017 pproven NOTE: ATTEMPTED PPROF, MAX TENSION 9880', POSSIBLE CORKSCREWED TUBING 5/31/2011 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.0 4,538.4 3,079.2 36.00 J-55 BTC PRODUCTION 7 6.28 35.0 10,300.0 5,976.8 26.00 J-55 BTC AB-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 33.2 Set Depth 9,885.3 Set Depth 5,822.8 String Max No 3 1/2 Tubing Description TUBING 3.5"x2.875" @9860' Wt (lb/ft) 9.20 Grade L-80 Top Connection EUE-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) 33.2 33.2 0.12 HANGER 8.000 WKM GEN IV HANGER 3.500 1,814.4 1,696.4 40.50 SAFETY VLV 5.937 CAMCO TRDP-1A-SSA SAFETY VALVE (Locked Out 9/4/94) 2.812 3,115.3 2,411.4 62.46 GAS LIFT 5.620 MERLA TMPD 2.875 5,948.3 3,817.3 57.81 GAS LIFT 5.620 MERLA TMPD 2.875 6,936.7 4,335.9 58.35 GAS LIFT 5.620 MERLA TMPD 2.875 7,710.7 4,737.0 58.34 GAS LIFT 5.620 MERLA TMPD 2.875 8,513.9 5,154.2 59.40 GAS LIFT 5.620 MERLA TMPD 2.875 9,101.5 5,449.7 60.58 GAS LIFT 5.620 MERLA TMPD 2.875 9,635.0 5,708.8 61.74 GAS LIFT 5.793 CAMCO MMG-2 2.920 9,684.3 5,732.0 62.00 PBR 5.000 BAKER 10' STROKE PBR 3.000 9,698.0 5,738.4 62.07 PACKER 6.062 BAKER HB RETRIEVABLE PACKER 2.890 9,714.3 5,746.1 62.23 PRODUCTION 5.968 CAMCO MMG-W 2.867 9,732.5 5,754.5 62.41 BLAST RINGS 4.500 CARBIDE BLAST RINGS (3) 2.992 9,827.3 5,797.7 63.66 NIPPLE 4.540 AVA BPL NIPPLE 2.697 9,859.4 5,811.7 64.30 XO Reducing 3.500 CROSSOVER 3.5 x 2.875 2.875 9,860.1 5,812.0 64.32 SEAL ASSY 3.470 BAKER LOCATOR SEAL ASSEMBLY 2.406 9,862.1 5,812.9 64.36 PACKER 5.687 BAKER DB PERMANENT PACKER 3.250 9,865.8 5,814.5 64.43 SBE 4.250 BAKER SEAL BORE EXTENSION 3.250 9,876.8 5,819.2 64.65 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 9,884.5 5,822.5 64.81 SOS 3.750 BAKER SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,049.0 4,394.9 58.44 TUBING LEAK TUBING LEAK AT ~7049 8/31/2019 2.992 7,543.0 4,649.4 58.89 LEAK 7/21/2017 8,375.0 5,083.1 58.83 LEAK TBG LEAK IDENTIFIED BY EL AT 8375' RKB 10/23/2023 2.992 9,700.0 5,739.4 62.08 CATCHER Set Catcher w/ PIIP no-go stinger on top of RBP (OAL = 64") 11/22/2023 0.000 9,705.6 5,742.0 62.14 RBP Set 2.725 PIIP RBP mid- element @ 9708' (OAL = 7.96') TTS PIIP CPP3 5313/ CPEQ 35028 11/22/2023 0.000 9,714.0 5,745.9 62.22 TUBING LEAK HOLE FINDER FOUND LEAK IN PRODUCTION MANDREL @ 9,714' RKB 6/29/2017 2.992 9,827.0 5,797.5 63.65 SLEEVE 2.75" AVA BPC SLEEVE 7/3/2017 10,035.0 5,882.9 67.84 FISH 1 1/2" OV Dropped in Hole 2/12/1995 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,115.3 2,411.4 62.46 1 GAS LIFT DMY BK 1 0.0 9/26/2023 0.000 5,948.3 3,817.3 57.81 2 GAS LIFT DMY BK 1 0.0 9/26/2023 0.000 6,936.7 4,335.9 58.35 3 GAS LIFT DMY BK 1 0.0 9/26/2023 0.000 7,710.7 4,737.0 58.34 4 GAS LIFT DMY BK 1 0.0 7/21/2017 0.000 8,513.9 5,154.2 59.40 5 GAS LIFT DMY BK 1 0.0 7/15/2003 0.000 9,101.5 5,449.7 60.58 6 GAS LIFT DMY BK 1 0.0 7/26/1998 0.000 9,635.0 5,708.8 61.74 7 GAS LIFT OPEN 1 1/2 0.0 11/23/2023 1.500 9,714.3 5,746.1 62.23 8 PROD DMY RK 1 1/2 0.0 5/5/1995 0.000 3G-09, 11/24/2023 6:00:00 AM Vertical schematic (actual) PRODUCTION; 35.0-10,300.0 FLOAT SHOE; 10,298.2- 10,300.0 FLOAT COLLAR; 10,213.7- 10,215.3 IPERF; 10,048.0-10,088.0 FISH; 10,035.0 APERF; 9,940.0-10,010.0 SOS; 9,884.5 NIPPLE; 9,876.8 SBE; 9,865.7 PACKER; 9,862.1 SEAL ASSY; 9,860.1 NIPPLE; 9,827.3 SLEEVE; 9,827.0 IPERF; 9,754.0-9,812.0 PRODUCTION; 9,714.3 TUBING LEAK; 9,714.0 RBP; 9,705.6 CATCHER; 9,700.0 PACKER; 9,684.6-9,719.0 PACKER; 9,698.0 PBR; 9,684.3 GAS LIFT; 9,635.0 GAS LIFT; 9,101.5 GAS LIFT; 8,513.9 LEAK; 8,375.0 GAS LIFT; 7,710.7 TUBING LEAK; 7,049.0 GAS LIFT; 6,936.7 GAS LIFT; 5,948.3 SURFACE; 35.0-4,538.4 FLOAT SHOE; 4,536.7-4,538.4 FLOAT COLLAR; 4,456.1- 4,457.6 GAS LIFT; 3,115.3 SAFETY VLV; 1,814.4 CONDUCTOR; 36.0-115.0 HANGER; 35.0-39.7 HANGER; 33.2 KUP PROD KB-Grd (ft) 36.29 RR Date 6/14/1990 Other Elev 3G-09 ... TD Act Btm (ftKB) 10,322.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032012900 Wellbore Status PROD Max Angle & MD Incl (°) 69.53 MD (ftKB) 10,129.99 WELLNAME WELLBORE3G-09 Annotation Last WO: End DateH2S (ppm) 80 Date 11/27/2016 Comment SSSV: LOCKED OUT Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,754.0 9,812.0 5,764.4 5,790.8 C-4, UNIT B, 3G -09 10/11/1990 10.0 IPERF 60 deg. phasing; 4 1/2" Hollow Carrier 9,940.0 10,010.0 5,845.6 5,873.4 A-4, A-3, 3G-09 8/20/1991 8.0 APERF 90 deg. phasing; 2 1/8" DynaStrip Gun 10,048.0 10,088.0 5,887.8 5,902.5 A-2, 3G-09 10/11/1990 4.0 IPERF 180 deg. phasing; 4 1/2" Hollow Carrier 3G-09, 11/24/2023 6:00:01 AM Vertical schematic (actual) PRODUCTION; 35.0-10,300.0 FLOAT SHOE; 10,298.2- 10,300.0 FLOAT COLLAR; 10,213.7- 10,215.3 IPERF; 10,048.0-10,088.0 FISH; 10,035.0 APERF; 9,940.0-10,010.0 SOS; 9,884.5 NIPPLE; 9,876.8 SBE; 9,865.7 PACKER; 9,862.1 SEAL ASSY; 9,860.1 NIPPLE; 9,827.3 SLEEVE; 9,827.0 IPERF; 9,754.0-9,812.0 PRODUCTION; 9,714.3 TUBING LEAK; 9,714.0 RBP; 9,705.6 CATCHER; 9,700.0 PACKER; 9,684.6-9,719.0 PACKER; 9,698.0 PBR; 9,684.3 GAS LIFT; 9,635.0 GAS LIFT; 9,101.5 GAS LIFT; 8,513.9 LEAK; 8,375.0 GAS LIFT; 7,710.7 TUBING LEAK; 7,049.0 GAS LIFT; 6,936.7 GAS LIFT; 5,948.3 SURFACE; 35.0-4,538.4 FLOAT SHOE; 4,536.7-4,538.4 FLOAT COLLAR; 4,456.1- 4,457.6 GAS LIFT; 3,115.3 SAFETY VLV; 1,814.4 CONDUCTOR; 36.0-115.0 HANGER; 35.0-39.7 HANGER; 33.2 KUP PROD 3G-09 ... WELLNAME WELLBORE3G-09 Originated: Delivered to:29ͲNovͲ23 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & PerforatingAttn.:Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska99501 Anchorage, Alaska 99518 Office: 907Ͳ275Ͳ2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concernstotheattention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # 12VͲ14 50Ͳ029Ͳ21294Ͳ00 n/a Kuparuk River Packer Setting Record FieldͲFinal 5ͲMarͲ23 0 1 22WͲ01 50Ͳ029Ͳ21273Ͳ00 n/a Kuparuk River Leak Detect Log FieldͲFinal 16ͲNovͲ23 0 1 32WͲ01 50Ͳ029Ͳ21273Ͳ00 908964770 Kuparuk River Multi Finger Caliper Field & Processed 16ͲNovͲ23 0 1 42WͲ01 50Ͳ029Ͳ21273Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 15ͲNovͲ23 0 1 53FͲ08 50Ͳ029Ͳ21464Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 5ͲJunͲ23 0 1 63GͲ09 50Ͳ103Ͳ20129Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 22ͲNovͲ23 0 1 73HͲ13A 50Ͳ103Ͳ20089Ͳ01 n/a Kuparuk River Leak Detect Log FieldͲFinal 17ͲNovͲ23 0 1 83HͲ13A 50Ͳ103Ͳ20089Ͳ01 908964771 Kuparuk River Multi Finger Caliper Field & Processed 18ͲNovͲ23 0 1 93HͲ13A 50Ͳ103Ͳ20089Ͳ01 n/a Kuparuk River Plug Setting Record FieldͲFinal 17ͲNovͲ23 0 1 10 3JͲ15 50Ͳ029Ͳ21497Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 1ͲOctͲ23 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: 1. 2V-14 PTD: 185-031 T38189 2. 2W-01 PTD: 185-010 T38190 3. 3F-08 PTD: 185-246 T38191 4. 3G-09 PTD: 190-067 T38192 5. 3H-13A PTD: 196-197 T38193 6. 3J-15 PTD: 185-289 T38194 12/1/2023 63GͲ09 50Ͳ103Ͳ20129Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 22ͲNovͲ23 0 1 Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.01 13:20:08 -09'00' 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Secure well 2. Operator Name:ConocoPhillips Alaska, Inc. 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:P.O. Box 100360 Stratigraphic Service 6. API Number: Anchorage, Alaska 99512 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?A Yes No 9. Property Designation (Lease Number):10. Field: Kuparuk River Oil Pool N/A 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10300 N/A 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: 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 9754-9812, 9940-10010, 10048- 10088 10265 5764-5791, 5846-5873, 5888- 5903 20-Nov-23 3.5 Packer- Baker HB Retrievable Packer- Baker DB Permanent SSSV- Camco TRDP-1A-SSA 7 16 9.625 79 4503 10300 115 3079 115 4538 5977 Length Size Proposed Pools: L-80 TVD Burst 9860 MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025548 Kuparuk River 190-067 50-103-20129-00 AOGCC USE ONLY Tubing Grade:Tubing MD (ft): Packer: 9698' MD & 5738' TVD Packer: 9862' MD & 5813' TVD Perforation Depth TVD (ft):Perforation Depth MD (ft): Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Dusty Freeborn dusty.freeborn@conocophillips.com 907-265-6218 Well Integrity Specialist KRU 3G-09 5977 10088 5903 N/A m n P 66 t ell N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Dusty Freeborn DN: OU=Well Integrity, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: Anchorage, Alaska Date: 2023.11.21 07:08:11-09'00' Foxit PDF Editor Version: 13.0.0 Dusty Freeborn 323-631 By Grace Christianson at 8:30 am, Nov 21, 2023 10-404 A.Dewhurst 22NOV23 and ADL0025547 VTL 11/22/2023 DSR-11/22/23JLC 11/22/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.11.22 11:44:12 -09'00'11/22/23 RBDMS JSB 112823 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 21 November 2023 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 3G-09 (PTD 190-067) to pull tubing patches and secure the well with a deep tubing plug to mitigate the sustained casing pressure of the inner annulus. Please contact me at 265-6218 if you have any questions. Sincerely, Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Digitally signed by Dusty Freeborn DN: OU=Well Integrity, O= ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: Anchorage, Alaska Date: 2023.11.21 07:07:43-09'00' Foxit PDF Editor Version: 13.0.0 Dusty Freeborn KRU 3G-09 (PTD# 190-067) Description Summary of Proposal Well Work Justification & Objectives: 3G-09 The latest LDL located a third tubing leak at 8375', below the two existing tubing patches. The well needs to be secured for LTSI/RWO. Risks/Job Concerns: Patch #1 from 7,043' to 7,059' (Min ID = 1.610") set 2019 Patch #2 from 7,632' to 7,657' (Min ID = 1.610") set 2017 3rd tubing leak at 8375' Leak in production mandrel at 9714' Will need throttle jumper rigged up from IA to production WSC reviewed 11/3/23 SRK WSC reviewed Rev1 11-17-23 KAL Steps: Relay or Slickline/Eline 1. Drift down to patches to verify patches will pull. Previous issues with Tar/Schmoo. 2. Pull P2P tubing patches from 7043' and 7632'. If wireline/braided line is unable to pull patch at 7632' then move to Coil. 3. Brush and flush tubing and drift to prep for RBP set. 4. Set RBP mid element at ~9708' (set in the upper half of the10' pup below packer due to the leak in the production mandrel at 9714'). 5. Set catcher and pull DV from 9635' (1.5", RK, 1998) if unable to pull move up and pull the next GLM's valve. 6. Circ out well pumping down tubing taking returns off the IA to production with 260 bbls seawater with 110 gallons CRW-132 followed by 80 bbls diesel. U-tube TxIA until fluids have equalized. 7. Perform CMIT TxIA to 2500 psi. Record TIOs. 8. Bleed down TxIA to ~500 psi. 9. RDMO, well to remain secure. Coil tubing unit 1. RIH to pull patch from 7632'. (currently left with RDW spear with 2.48" grapple). May use other spear options per onsite Wells supervisor's discreation. 2. If unable to pull upper P2P of patch with spear then move into milling the upper P2P until able to pull the remainder of the patch assembly. Mill option to be determined by onsite Wells supervisor and tool rep. Discuss with Jan Byrne 808-345-6886 as needed. 3. Once patch has been removed turn well back over to Relay to start at step #3. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Est. 89' of Fill) 9,999.0 3G-09 2/5/2019 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled Spear out of packer, noted damaged Packer FN 3G-09 11/17/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: HOLE FINDER FOUND LEAK IN PRODUCTION MANDREL @ 9,714' RKB 6/29/2017 pproven NOTE: ATTEMPTED PPROF, MAX TENSION 9880', POSSIBLE CORKSCREWED TUBING 5/31/2011 ninam NOTE: View Schematic w/ Alaska Schematic9.0 8/30/2010 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.0 4,538.4 3,079.2 36.00 J-55 BTC PRODUCTION 7 6.28 35.0 10,300.0 5,976.8 26.00 J-55 BTC AB-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 33.2 Set Depth … 9,885.3 Set Depth … 5,822.8 String Max No… 3 1/2 Tubing Description TUBING 3.5"x2.875" @9860' Wt (lb/ft) 9.20 Grade L-80 Top Connection EUE-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) 33.2 33.2 0.12 HANGER 8.000 WKM GEN IV HANGER 3.500 1,814.4 1,696.4 40.50 SAFETY VLV 5.937 CAMCO TRDP-1A-SSA SAFETY VALVE (Locked Out 9/4/94) 2.812 3,115.3 2,411.4 62.46 GAS LIFT 5.620 MERLA TMPD 2.875 5,948.3 3,817.3 57.81 GAS LIFT 5.620 MERLA TMPD 2.875 6,936.7 4,335.9 58.35 GAS LIFT 5.620 MERLA TMPD 2.875 7,710.7 4,737.0 58.34 GAS LIFT 5.620 MERLA TMPD 2.875 8,513.9 5,154.2 59.40 GAS LIFT 5.620 MERLA TMPD 2.875 9,101.5 5,449.7 60.58 GAS LIFT 5.620 MERLA TMPD 2.875 9,635.0 5,708.8 61.74 GAS LIFT 5.793 CAMCO MMG-2 2.920 9,684.3 5,732.0 62.00 PBR 5.000 BAKER 10' STROKE PBR 3.000 9,698.0 5,738.4 62.07 PACKER 6.062 BAKER HB RETRIEVABLE PACKER 2.890 9,714.3 5,746.1 62.23 PRODUCTION 5.968 CAMCO MMG-W 2.867 9,732.5 5,754.5 62.41 BLAST RINGS 4.500 CARBIDE BLAST RINGS (3) 2.992 9,827.3 5,797.7 63.66 NIPPLE 4.540 AVA BPL NIPPLE 2.697 9,859.4 5,811.7 64.30 XO Reducing 3.500 CROSSOVER 3.5 x 2.875 2.875 9,860.1 5,812.0 64.32 SEAL ASSY 3.470 BAKER LOCATOR SEAL ASSEMBLY 2.406 9,862.1 5,812.9 64.36 PACKER 5.687 BAKER DB PERMANENT PACKER 3.250 9,865.8 5,814.5 64.43 SBE 4.250 BAKER SEAL BORE EXTENSION 3.250 9,876.8 5,819.2 64.65 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 9,884.5 5,822.5 64.81 SOS 3.750 BAKER SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,049.0 4,394.9 58.44 TUBING LEAK TUBING LEAK AT ~7049 8/31/2019 2.992 7,543.0 4,649.4 58.89 LEAK 7/21/2017 7,632.0 4,695.8 58.46 PATCH - UPR PKR (ME) UPPER 2.72'' PARAGON PACKER, SPACER PIPE & ANCHOR LATCH SEAL ASSEMBLY ( SN: CPAL35062 ) (( OAL = 25.85 / MIN ID = 1.61'' ) **NOTE - Fishing neck on packer appears to be damaged and unable to stay latched up, may be split. *** CPP3 5121 7/23/2017 1.610 7,636.0 4,697.9 58.46 SPACER PIPE 2-1/16" SPACER PIPE, 10RD EUE, 20.49' OAL 7/23/2017 1.610 7,657.0 4,708.9 58.42 PATCH - LRW PKR (ME) 2.72'' PARAGON PIIP PACKER OAL = 4.01' MIN ID = 1.625'' CPP3 5041 7/22/2017 1.625 8,375.0 5,083.1 58.83 LEAK TBG LEAK IDENTIFIED BY EL AT 8375' RKB 10/23/2023 2.992 9,714.0 5,745.9 62.22 TUBING LEAK HOLE FINDER FOUND LEAK IN PRODUCTION MANDREL @ 9,714' RKB 6/29/2017 2.992 9,827.0 5,797.5 63.65 SLEEVE 2.75" AVA BPC SLEEVE 7/3/2017 10,035.0 5,882.9 67.84 FISH 1 1/2" OV Dropped in Hole 2/12/1995 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,115.3 2,411.4 62.46 1 GAS LIFT DMY BK 1 0.0 9/26/2023 0.000 5,948.3 3,817.3 57.81 2 GAS LIFT DMY BK 1 0.0 9/26/2023 0.000 6,936.7 4,335.9 58.35 3 GAS LIFT DMY BK 1 0.0 9/26/2023 0.000 7,710.7 4,737.0 58.34 4 GAS LIFT DMY BK 1 0.0 7/21/2017 0.000 8,513.9 5,154.2 59.40 5 GAS LIFT DMY BK 1 0.0 7/15/2003 0.000 3G-09, 11/19/2023 10:33:29 AM Vertical schematic (actual) PRODUCTION; 35.0-10,300.0 FLOAT SHOE; 10,298.2- 10,300.0 FLOAT COLLAR; 10,213.7- 10,215.3 IPERF; 10,048.0-10,088.0 FISH; 10,035.0 APERF; 9,940.0-10,010.0 SOS; 9,884.5 NIPPLE; 9,876.8 SBE; 9,865.7 PACKER; 9,862.1 SEAL ASSY; 9,860.1 NIPPLE; 9,827.3 SLEEVE; 9,827.0 IPERF; 9,754.0-9,812.0 PRODUCTION; 9,714.3 TUBING LEAK; 9,714.0 PACKER; 9,684.6-9,719.0 PACKER; 9,698.0 PBR; 9,684.3 GAS LIFT; 9,635.0 GAS LIFT; 9,101.5 GAS LIFT; 8,513.9 LEAK; 8,375.0 GAS LIFT; 7,710.7 PATCH - LRW PKR (ME); 7,657.0 SPACER PIPE; 7,636.0 PATCH - UPR PKR (ME); 7,632.0 TUBING LEAK; 7,049.0 GAS LIFT; 6,936.7 GAS LIFT; 5,948.3 SURFACE; 35.0-4,538.4 FLOAT SHOE; 4,536.7-4,538.4 FLOAT COLLAR; 4,456.1- 4,457.6 GAS LIFT; 3,115.3 SAFETY VLV; 1,814.4 CONDUCTOR; 36.0-115.0 HANGER; 35.0-39.7 HANGER; 33.2 KUP PROD KB-Grd (ft) 36.29 RR Date 6/14/1990 Other Elev… 3G-09 ... TD Act Btm (ftKB) 10,322.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032012900 Wellbore Status PROD Max Angle & MD Incl (°) 69.53 MD (ftKB) 10,129.99 WELLNAME WELLBORE3G-09 Annotation Last WO: End DateH2S (ppm) 80 Date 11/27/2016 Comment SSSV: LOCKED OUT 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) 9,101.5 5,449.7 60.58 6 GAS LIFT DMY BK 1 0.0 7/26/1998 0.000 9,635.0 5,708.8 61.74 7 GAS LIFT DMY RK 1 1/2 0.0 7/26/1998 0.000 9,714.3 5,746.1 62.23 8 PROD DMY RK 1 1/2 0.0 5/5/1995 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,754.0 9,812.0 5,764.4 5,790.8 C-4, UNIT B, 3G -09 10/11/1990 10.0 IPERF 60 deg. phasing; 4 1/2" Hollow Carrier 9,940.0 10,010.0 5,845.6 5,873.4 A-4, A-3, 3G-09 8/20/1991 8.0 APERF 90 deg. phasing; 2 1/8" DynaStrip Gun 10,048.0 10,088.0 5,887.8 5,902.5 A-2, 3G-09 10/11/1990 4.0 IPERF 180 deg. phasing; 4 1/2" Hollow Carrier 3G-09, 11/19/2023 10:33:31 AM Vertical schematic (actual) PRODUCTION; 35.0-10,300.0 FLOAT SHOE; 10,298.2- 10,300.0 FLOAT COLLAR; 10,213.7- 10,215.3 IPERF; 10,048.0-10,088.0 FISH; 10,035.0 APERF; 9,940.0-10,010.0 SOS; 9,884.5 NIPPLE; 9,876.8 SBE; 9,865.7 PACKER; 9,862.1 SEAL ASSY; 9,860.1 NIPPLE; 9,827.3 SLEEVE; 9,827.0 IPERF; 9,754.0-9,812.0 PRODUCTION; 9,714.3 TUBING LEAK; 9,714.0 PACKER; 9,684.6-9,719.0 PACKER; 9,698.0 PBR; 9,684.3 GAS LIFT; 9,635.0 GAS LIFT; 9,101.5 GAS LIFT; 8,513.9 LEAK; 8,375.0 GAS LIFT; 7,710.7 PATCH - LRW PKR (ME); 7,657.0 SPACER PIPE; 7,636.0 PATCH - UPR PKR (ME); 7,632.0 TUBING LEAK; 7,049.0 GAS LIFT; 6,936.7 GAS LIFT; 5,948.3 SURFACE; 35.0-4,538.4 FLOAT SHOE; 4,536.7-4,538.4 FLOAT COLLAR; 4,456.1- 4,457.6 GAS LIFT; 3,115.3 SAFETY VLV; 1,814.4 CONDUCTOR; 36.0-115.0 HANGER; 35.0-39.7 HANGER; 33.2 KUP PROD 3G-09 ... WELLNAME WELLBORE3G-09 WELL LOG TRANSMITTAL #905950513 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log and Packer Setting Records: 3G-09 Run Date: 08/31/2019 and 09/13/2019 19^00:7 3 123 9 September 20, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3G-09 Digital Data in LAS format, Digital Log file RECEIVED CD Rom 50-103-20129-00 SEP 2 4 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburtoon.com Date: Tl (N by Signed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS SEP 30 ❑9 1. Operations Abandon Plug Perforations tiL41ls'�� "e.ti Fracture Stimulate Pull Tubing Op fa`tibaa" ti. e Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing 11 Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: _Tubing Patch_ ❑� 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development ❑✓ Exploratory ❑ 190-067 3. Address: P. 0. Box 100360 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, Alaska 99510 50-103-20129-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025548 KRU 3G-09 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Ki ii River Field/Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 10300 feel Plugs measured N/A feet true vertical 5977 feel Junk measured N/A feet Effective Depth measured 10088 feel Packer measured 9,698 feet true vertical 5903 feet true vertical 5,738 feet Casing Length Size MD TVD Burst Collapse Conductor 79' 16" 115' 115' Surface 4503' 9.625" 4538' 3079' Production 10265' 7" 10300' 5977' Perforation depth Measured depth 9754-9812, 9940-10010, 10048-10088 feet True Vertical depth 5764-5791, 5846-5873, 5888-5903 feet Tubing (size, grade, measured and true vertical depth) 3.5" L-80 9860' 5812' 2.875" L-80 9885' 5822' Packers and SSSV (type, measured and true vertical depth) PATCH UPPER PACKER - 2.72" PARAGON 7043' MD 4392' TVD PATCH LOWER PACKER - 2.72" PARAGON 7059MD 4400' TVD PATCH UPPER PACKER - 2.72" PARAGON 7632' MD 4696' TVD PATCH LOWER PACKER - 2.72" PARAGON 7657' MD 4709' TVD PACKER - BAKER HB RETRIEVABLE 9698' MD 5738' TVD PACKER - BAKER DB PERMANENT 9862' MD 5813' TVD SSSV - CAMCO TRDP-IA-SSA 1814' MD 1696' TVD 12. Stimulation or cement squeeze summary: N/A 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: 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 nnc 25070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations ❑' Exploratory ❑ Develo ment p ❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Authorized Name: Sara Carlisle Contact Name: Rachel Kautz/Sara Carlisle Authorized Title: Well Integrity and Compliance Specialist Contact Email: n25491ailconocoohillips com -7 Authorized Signature: Date: ' I T J Contact Phone: 907-659-7126 Form 10-404 Revised4/2017 _ r_rr. �.�.rr......CiV'kir 9mrylir=�L4nk ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 17, 2019 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7"' Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch set across a known tubing leak in producer 3G-09 (PTD 190-067). Please contact Rachel Kautz or me at 659-7126 if you have any questions. Sincerely, 0'�t�'j cZti�j Sara Carlisle Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Date 3G-09 DESCRIPTION OF WORK COMPLETED After failing a TIFL indicated a tubing leak, 3G-09 was repaired by installing a through tubing patch above the existing tubing patch installed in 2017. The integrity of the patch was confirmed with a passing re-TIFL after the patch was installed. 08/15/19 (AC EVAL) : SI TIFI (FAILED DUE TO INFLOW & PRESSURE INCREASE). 08/31/19 09/12/19 09/13/19 09/17/19 SET TEST TOOL IN PATCH @ 7632' RKB. PERFORM LDL: IDENTIFY TBG LEAK @ _7049' RKB. LOG UP / DOWN PASS ACROSS LEAK AND STATION STOPS @ 7626', 7056'& 7046' RKB. TEST TOOL WAS ALSO LEAKING. PULLED TEST TOOL BRUSH n' FLUSH TBG TO 2.72" P2P @ 7632' RKB, BRUSH PATCH AREA FROM 7000' TO 7100' RKB, DRIFT TBG TO 71 00' W/ 2.72" x 24.08' DUMMY PATCH, SET 3 1/2 TTS TEST TOOL @ 7632' RKB. IN PROGRESS. PROTECT, PULLED 3 1/2 TTS TEST TOOL @ 7632' RKB. SET LOWER 2.72" P2P @ 7059' RKB. CMIT- TxIA TO 2500 PSI "PASS`. SET UPPER P2P PATCH ASSEMBLY @ 7043'. SET TTS TEST TOOL IN P2P @ 7043' RKB, MIT -T TO 2500 PSI *`PASS*". TTS TEST TOOL @ 7043' RKB CMIT- TxIA TO 2500 PSI (PASS) PRE T/I/0= 525/350/160 PRESSURE UP (3.25 BBLS) INITIAL T/I/0= 2500/2300/200 15 MIN T/1/0=2480/2280/200 30 MIN T/I/0= 2480/2280/2007 MIT -T TO 2500 PSI (PASS) MIT -T, PRE T/1/0= 600/400/160 PRESSURE UP (.5 BBLS) INITIAL T/I/0= 2525/450/160 15 MIN T/I/0= 2450/450/160 30 MIN T/I/0= 2440/450/160 Initial T/l/O = 200/1260/745, IA FL @ 6936' (st #3,OV) OA FL @ NS SI wellhead @ WV & double block AL. Stacked WHP's to TWO = SI 1130/1130/540 in 1 hour Bled AL line to 200 psi Bled IA to T/I/O = 1175/580/380 in 50 min, IA FL @ same location, 1 hour monitor. 15 min T/I/O = 1180/580/360 30 min TWO = 1190/580/350, IA FL @ same location 45 min T/l/O = 1195/580/340 60 min T/I/O = 1195/580/315, IA FL @ same location Final T/l/O = SI 1195/580/315 ConocoPhillips Alaske.hic, GAS GAS OF IPERF. 97VM.B120— PACKER', SBE: EGFR 10015.610W00� KUP PROD WELLNAME 3G-09 WELLBORE ir_()q Well Attributes Max Angle $MIR - TD FIeIE Name KUPAR UK RC' ER UN IT Wellbore APIIUM 501032012900 warevte Stdes —I l') MD(NNB Pet B[m iNN Bj PROD 9.53 10,129.99 10.3220 Comment SSSV:LOCKED M3S (ppmj Dete Mn...Ilan Entl Dah--rd(N) RI9 R.1— Del. OUT So 11/2 712 01 6 LAsI WO'. 36.29 6/14/1990 Last Tag Anocraron Depm lnxel Ene Dme wellbore vzIMM Dy Lasl Tag'. RK9 (Est 89'.1 FiIQ 9,999021512019 3C-09 zembaej Last Rev Reason Rev Beeson: wsrALL PA CH Mnmeron End mee WenMle last Matl By 912 412.19 a&os ronapw slots Make (ME) PIPE Com ' STATE OF ALASKA AL OIL AND GAS CONSERVATION COMM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations Li Fracture Stimulate ❑ Pull Tubing Li Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Tubing Patch El 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska,Inc. Development Q Exploratory ❑ 190-067 3.Address: P.O.Box 100360 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99510 50-103-20129-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025548 KRU 3G-09 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 10300 feel Plugs measured f f'f true vertical 5977 feel Junk measured feet AUG 0 7 :7_017 Effective Depth measured 10088 feet Packer measured feet true vertical 5903 feet true vertical feet A i.^', Y03%,,A,,: Casing Length Size MD TVD Burst Collapse Conductor 79' 16" 115' 115' Surface 4503' 9.625" 4538' 3079' Production 10265' 7" 10300' 5977' Perforation depth Measured depth 9754-9812,9940-10010, 10048-10088 feet True Vertical depth 5764-5791,5846-5873,5888-5903 feet Tubing(size,grade,measured and true vertical depth) 3.5" L-80 9860' 5812' 2.875" L-80 9885' 5822' Packers and SSSV(type,measured and true vertical depth) PATCH UPPER PACKER-2.72"PARAGON 7632'MD 4696'TVD PATCH LOWER PACKER-2.72"PARAGON 7657'MD 4709'TVD PACKER-BAKER HB RETRIEVABLE 9698'MD 5738'TVD PACKER-BAKER DB PERMANENT 9862'MD 5813'ND SSSV-CAMCO TRDP-IA-SSA 1814'MD 1696'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 5CANNE1 NOV 0 1 201Z 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 ❑., Exploratory ❑ Development❑., 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 ❑ 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: Authorized Name: Rachel Kautz Contact Name: Rachel Kautz/Travis Smith Authorized Title: Well Integrity Supervisor Contact Email: n2549conocophillips.com Authorized Signature: Date: rS/3//1. Contact Phone: 907-659-7126 V77— /'/&!J Form 10-404 Revised 4/2017 q/(0//7 RBDMS V-, A I!13 - 9 2017 Submit Original Only • • Nov RECEIVED ConocoPhillips n 2017 Alaska P.O. BOX 100360 AOGCC j"_/"`'��*" ANCHORAGE,ALASKA 99510-0360 J`�..1"�,1�.r August 3, 2017 Commissioner Hollis S. French Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner French, Enclosed please find the 10-404 Report of Sundry Operations for producer KRU 3G-09 (PTD 190-067) for a retrievable patch set in the tubing above the packer. The integrity of the patch was confirmed with mechanical integrity tests. Please call Travis Smith or myself at 659-7126 if you have any questions. Sincerely, Rachel Kautz Well Integrity Supervisor ConocoPhillips Alaska,Inc. • • Date Event Summary Executive 3G-09 is a gas lifted producer that was diagnosed with a tubing leak. A spinner log confirmed the tubing leak location at Summary 7643'RKB. A retrievable patch was set across the leak. Follow-up passing MITs confirmed integrity. 05/30/17 Diagnostic TIFL failed. 06/29/17 WITH HOLEFINDER FOUND LEAK BETWEEN 7710'&7614'RKB,PULLED OV @ 7710'RKB&REPLACED WITH DUMMY VALVE,RE-RAN HOLEFINDER,NARROWED DOWN LEAK BETWEEN 7,663'-7,636'RKB,PULLED CATCHER @ 9827'RKB, IN PROGRESS. 07/09/17 SET 2.72"PARAGON RBP w/AGGRESSIVE SLIPS(#CPP35127/EQ VLV#CPEQ35008)ME @ 9708'RKB.IDENTIFY LEAK @ APPROX 7643'RKB WITH TEMP/SPINNER.LRS&DHD TO COMBO MIT TBG x IA TO 2500&DDT. **CMIT TxIA results(PASS)"' Pre-MIT T/I/O=725/525/300 Pressured up T and IA with 3.4 bbls of diesel. Initial T/I/O=2525/2350/320 15 min T/I/O=2490/2300/320 (-35/-50/0) 30 min T/I/O=2480/2290/320 (-10/-10/0) PASS. 07/22/17 CHECK SET DV @ 7710'RKB;WITH HOLE FINDER CONFIRMED TBG INTEGRITY BELOW PACKER SET DEPTH. PULLED CATCHER @ 9827'RKB.SET LOWER 2.72"PARAGON PIIP PACKER MID ELEMENT @ 7657'RKB WITH CMDFIRE!SET 3"TTS TEST TOOL IN LOWER PACKER©7657'RKB;CMIT AGAINST TEST TOOL(INCONCLUSIVE) IN PROGRESS. 07/23/17 WITH MAXFIRE!SET UPPER 2.72"PARAGON PIIP PATCH ASSEMBLY MID ELEMENT @ 7632'RKB.MITT TBG TO 2500 PSI(PASS)MITIA 2500 PSI(PASS)JOB COMPLETE. BEGIN CMIT INITIAL T/1/0/FL=1275/1300/240/160 LRS PT TBG/IA TO 2500 PSI W/2.6 BBLS DSL START= 2500/2525/240/160 15 MINS=2440/2475/240/160 30 MINS=2435/2460/240/160 PASS BEGIN MITT INITIAL T/I/O/FL=1275/1325/240/160LRS PT TBG TO 2500 PSI W/.7 BBLS.START=2539/1360/240/160 15 MINS=2525/1360/240/160 30 MINS=2519/1360/240/0 PASS BEGIN MITIA INITIAL T/I/O/FL=1305/1330/240/150 START=1305/2505/240/150 15 MINS=1306/2454/240/150 30 MINS =1306/2445/240/150(PASS) KUP PROD • 3G-09 ConocoPhillips & Well Attributes Max Angle&MD TD Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Gcnrm ®ps 501032012900 KUPARUK RIVER UNIT PROD69.53 10,129.99 10,322.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 3G 09,7/25;2017220 03 PM -SSSV:LOCKED OUT 80 11/27/2016 Last WO: 36.29 6/14/1990 Veniaal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _. .. .......__ .. ......_.. _�r�_ Last Tag:RKB 9,989.0 6/26/2017 Rev Reason:H2S,TAG,SET CATCHER,GLV pproven 7/25/2017 HANGER 33.2 �� l- C/O,PULL CATCHER,LEAK,SET PATCH �� "1 dII1 Casing Strings yyu.nrw.,rr„e,n,rrwmm�a,ruuunuru�uafll} IIay,y Cas ng Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread J CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 35.0 4,538.4 3,079.2 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WVLen(I...Grade Top Thread f PRODUCTION 7 6.276 35.0 10,300.0 5,976.8 26.00 2-55 BTC AB- MOD CONDUCTOR;36.0-115.0 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 33.2 9,885.3 5,822.8 9.20 L-80 EUE-MOD SAFETY VLV;1,814.4 _0. 3.5"x2.875"@9860' Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT,3,115.3 33.2 33.2 0.12 HANGER WKM GEN IV HANGER 3.500 1,814.4 1,696.4 40.50 SAFETY VLV CAMCO TRDP-IA-SSA SAFETY VALVE(Locked Out 2.812 9/4/94) 9,684.3 5,732.0 62.00 PBR BAKER 10'STROKE PBR 3.000 9,698.0 5,738.4 62.07 PACKER BAKER HB RETRIEVABLE PACKER 2.890 SURFACE;35.0-4,538.4-+ 9,732.5 5,754.5 62.41 BLAST RINGS CARBIDE BLAST RINGS(3) 2.992 GAS LIFT;5,948.3 9,827.3 5,797.7 63.66 NIPPLE AVA BPL NIPPLE 2.697 9,859.4 5,811.7 64.30 XO Reducing CROSSOVER 3.5 x 2.875 2.875 GAS LIFT;6,936.7 9,860.1 5,812.0 64.32 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 2.406 9,862.1 5,812.9 64.36 PACKER BAKER DB PERMANENT PACKER 3.250 PATCH;7,632.0 9,865.6 5,814.5 64.43 SBE BAKER SEAL BORE EXTENSION 3.250 9,676.8 5,819.2 64.65 NIPPLE CAMCO D NIPPLE NO GO 2.250 PATCH;7,657.0 9,884.5 5,822.5 64.81 SOS BAKER SHEAR OUT SUB 2.441 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT;7,710.7 Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) GAS LIFT;8513.9 7,632.0 4,695.8 58.46 PATCH UPPER 2.72"PARAGON PACKER(SN; 7/23/2017 1.610 CPP35121)SPACER PIPE&ANCHOR LATCH SEAL ASSEMBLY(SN:CPAL35062)((OAL= GAS LIFT;9,101.5 25.85/MIN ID=1.61") 7,657.0 4,708.9 58.42 PATCH 2.72"PARAGON PIIP PACKER(SN CPP35041/ 7/22/2017 1.625 OAL=4.01'MIN ID=1.625") 111. 9,827.0 5,797.5 63.65 SLEEVE 2.75"AVA BPC SLEEVE 7/3/2017 GAS LIFT;9,635.0 • 10,035.0 5,882.9 67.84 FISH 1 1/2"OV Dropped in Fble 2/12/1995 0.000 Perforations&Slots Shot Dens 1 Top(TVD) Btm(TVD) (shots/f PER 9,68a.3 - Top(ftKB) Btm(ftKB) (ftKB) (RKB) Zone Date t) Type Com 9,754.0 9,812.0 5,764.4 5,790.8 C-4,UNIT B, 10/11/1990 10.0 IPERF 60 deg.phasing;41/2" PACKER;9,698.0 3G-09 Hollow Carder 9,940.0 10,010.0 5,845.6 5,873.4 A-4,A-3,3G- 8/20/1991 8.0 APERF 90 deg.phasing;21/8" • 09 DynaStdp Gun PRODUCTION;9,714.3 10,048.0 10,088.0 5,887.8 5,902.5 A-2,3G-09 10/11/1990 4.0 IPERF 180 deg.phasing;41/2" Hollow Carder s Mandrel Inserts IPERF;9,754.0-9,812.0-� I at ti on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sem Type Type (in) (psi) Run Date Com 1 3,115.3 2,411.4 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 7/1/2017 SLEEVE;9,827.01 2 5,948.3 3,817.3 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 7/1/2017 NIPPLE;9,827.3 1 3 6,936.7 4,335.9 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 7/1/2017 r Y 1 4 7,710.7 4,737.0 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 7/21/2017 I5 8,513.9 5,154.2 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 7/15/2003 6 9,101.5 5,449.7 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 7/26/1998 SEAL ASSY;9.660.1 L= 7 9,635.0 5,708.8 CAMCO MMG-2 11/2 GAS LIFT DMY RK 0.000 0.0 7/26/1998 1 8 9,714.3 5,746.1 CAMCO MMG-W 11/2 PROD DMY RK 0.000 0.0 5/5/1995 PACKER;9,862.1 Notes:General&Safety SBE;9,865.7 ,-�. End Date Annotation j8/30/2010 'NOTE:View Schematic w/Alaska Schematic9.0 5/31/2011 'NOTE:ATTEMPTED PPROF,MAX TENSION 9880',POSSIBLE CORKSCREWED TUBING NIPPLE;9,876.8 6/29/2017 NOTE:HOLE FINDER FOUND LEAK IN PRODUCTION MANDREL @ 9,714'RKB SOS;9,884.5 11. APERF;9,940.5-10015.0- FISH;10,030.0 __. IPERF;10,048.0-10,088.0- -4 PRODUCTION;35.0-10,300.0 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 2, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 DSE.P 1 i 2 01a RE: Gas Lift Survey: 3G -09 Run Date: 5/31/2011 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 3G-09 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20129 -00 t)t 9 4 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: /) 2-44 l ( Signed: L e t C.7 ConocoPhllips a P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Searriount: ~~~~ APR 0 5`°2010 ~~ & Gays cons. C'am'®~ Anc~rac ~~b -a~-7 3G-O`I r "~~.~ APB {~ ~~; Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRin. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped March 2 and 21, 2010. The corrosion inhibitor/sealant was pumped March 27, 28 and 29, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, MJ L veland ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/31/10 3a_ se_ 3c_ s~_ ~N_ sl_ ~.~_ inn sn ~ ~R pen~~ Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3A-02 50029214310000 1852050 Surface Na 26" n/a 4.25 3/29/2010 3A-04 50029214330000 1852070 SF n/a 26" n/a 4.25 3/29/2010 3A-07 50029214440000 1852230 SF n/a 25" n/a 4.25 3129!2010 3A-16 50029214920000 1852840 SF n/a 23" n/a 3.4 3/29/2010 3B-10 50029213660000 1851140 6'6" n/a 6'6" Na 25.5 3/28/2010 3C-11 50029213570000 1851020 SF Na 25" n/a 4.25 3/27/2010 3G-08 50103201280000. 1900650 SF 0.65 27" 3/2/10 5.52 3/28/2010 3G-09 50103201290000 1900670 SF 0.60 22" 3/2/10 4.67 3/28/201U 3G-22 50103201470000 1901420 SF n/a 22" n/a 4.25 3/28!2010 3H-01 50103200840000 1871100 SF Na 21" Na 4.25 3/28/2010 3H-03 50103200850000 1871110 17" 0.40 8" 3/21/10 1.7 3/28/2010 3H-14B 50103200920200 2050210 SF n/a 23" n/a 3.4 3/29/2010 31-02 50029215150000 1853080 SF Na 22" n/a 2.97 3/29/2010 31-10 50029219340000 1890370 39' 3.50 24" 3/21/10 3.4 3/29/2010 3J-04 50029214000000 1851650 SF Na 23" n/a 3.4 3/28/2010 3J-14 50029214960000 1852880 SF n/a 25" n/a 4.67 3/28/2010 3J-15 50029214970000 1852890 SF n/a 22" Na 3.4 3/28/2010 3M-05 50029217060000 1870250 SF Na 21" n/a 3.4 3/29/2010 3M-07 50029217080000 1870270 SF n/a 22" n/a 4.25 3/29/2010 30-09 50029218250000 1880610 SF n/a 23" Na 4.25 3/27/2010 30-16A 50029217960100 1880430 SF Na 22" Na 3.52 3!27/2010 3R-10A 50029222530100 1920310 SF n/a 21" Na 4.25 3/27/2010 3R-11 D 50029222480000 1920160 SF n/a 17" n/a 3.25 3/27/2010 3R-15 50029222580000 1920340 SF n/a 24" n/a 3.82 3/27/2010 3R-19 50029222690000 1920460 1" n/a 21" n/a 5.1 3/27/2010 3R-25 50029226220000 1951810 SF n/a 21" n/a 5.52 3/27/2010 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 8, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Gas Lift Survey: 3G -09 Run Date: 7/5/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3G -09 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20129 -00 O PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNIN G A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 273 -3527 Fax: 907 273 -3535 rafael.barreto@ 'i. ytor ami NOV o 5 2009 Date: Signed: 11aska Oil Gas Cons. Commission Anchoraoo KRU 3G-09 (PTD# 190-067) Re~ Of TxIA Communication • Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] ,~~c f~ f~ I~~, Sent: Saturday, September 12, 2009 2:56 PM ~~ To: Regg, James B(DOA); Maunder, Thomas E(DOA); Schwartz, Guy L(DOA) Cc: NSK Problem Well Supv; NSK We~l Integrity Proj; CPF3 Prod Engrs; CPF3 DS Lead Techs Subject: KRU 3G-09 (PTD# 190-067) Report Of TxIA Communication Attachments: 3G-09 Wellbore Schematic.pdf; 3G-09 TIO Plot.pdf Jim/Tom/Guy, i... Kuparuk gaslifted producer 3G-09 (PTD#190-067) is suspected of having TxIA communication based upon a failed dia nostic TIFL on 9/9/09. A gaslift valve is the likely source of communication so slicklme will troubleshoot a repair if possible. The well will be added to the SCP report and will be repaired or shut in by 10/7/09. Attached is a 90 day TIO plot and wellbore schematic. «3G-09 Welibore Schematic.pdf» «3G-09 TIO Plot.pdf» ~ Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 u~~G~.~~~~ , : ~ ,' _ ~~ ~,~C~ 11 /4/2009 ~ ~~-o~~ Well Name 3G-09 Notes: AUGGC Report of TxI.A Communication End Date 10;1: 2009 Days 120 Start Date 6'3'2009 Annular Communication Surveillance 1600 WHP 140 IAP OAP - - - - -- - -__ - 1400 WHT - . -------- _- 120 1200 100 1000 80 LL ~~ ~ 800 ~ i G a so s o - - o - 40 400 -- 200 - - - 20 ~ 0 Jun-09 Jul-09 Aug-09 Sep-09 Zsoo,~DGI ' ~MGI Z~ ~PWI o ° ' ~ 1500 ~.S W~ .. o ~ ,ooo ~ ~BLPD -- -- - -- - - -- - , i _ _ ,~n - -- ___ _ n ~ • _ _ _ _.,. . ~ KUP ~ 3G-09 ~ ~ cc~F~~t~ipS ~ ~ ~ ~ ~c~.,t~s ~ ~ ~~ ~ : , n ~a~i~ ~ ~~ ' ~ ~~ Wellbore APIIUWI Field Nama Wall Status Incl (°) MD (RKB) Act Btm (ttK8) ° ' 501032012900 KUPARUK RIVER UNIT PROD 69.53 10,129.99 10,322.0 ~ Comment H2S (ppm) Date Annotatlon End Date KB-Grd (R) Rlg Release Date e ~i,.~~ ,- ~ ,~;~~ . ~ SSSV: Locked Out 90 12/272008 Last WO: 36.29 6/14/1990 m'et~c. ue :: ~~. Mnotation Depth (RKB) End Drte Annotation Last Motl By End Date Last Tag: SLM 9 ,993.0 5/15/2009 Rev Reason: TAG FILL Imosbor 5/16/2009 ~'~~41 `~FII~ ~'_"_ " ; ~.-;' '.. i ,~' " r- ; :'' ` i `-r~.. : r 'i ~ .tr, i NY ~ ~ String OD String ID Set Depth Set Depth (ND~~ String Wt ~ Stnng CONDUCTOR 1 ~ ~ Caaing Dosoript~on (in) (in) Top (RKB) (RKB) (ftKB) (Ibs/ff) Orade Stnng Top Thrd , i+s CONDUCTOR 16 15.062 0.0 115.0 115.0 62.50 H-00 - SUFACE 95/8 8.765 0.0 4,538.0 3,W92 36.00 J-55 sareryvai~e, PRODUCTION 7 6.151 0.0 10,300A 5,976.8 26.00 J-55 1.814 " ~'U1?1 :~5~"~11 s4 9 6?Y~ ~ =ii `ii ~ ~s. 4 '? '- ~ t{ " 6 String OU String ID Set Depth Set Depth (ND) String Wt String TubingDescriptlon 0n) l~^) Top(ftKB) (RKB) (ftKB) (IbsM) Orede StringTOp7hrd cASUFT, TUBING 31/2 2.992 0.0 704A 9 739.1 5 9.30 J-55 EUEMOD 3,1i5 , , "" TUBING 3 12 2.992 9,704.0 9,862.0 S,S12.6 9.30 L-80 EUE MOD TUBING 27/8 2.441 9,862.0 9,885.0 5,822.7 6.50J-55 EUEMOD SUFACE, 4,538 - ~ther'#i~~{pls Afi3~~nr~i :-Tupin ~ ~ ~ ` F y ~ ~~nl~~~€~ieva~ii~"~f~fi e~c. '~~,.~.: „~ ~ - -- Top Depth GASLIFT - (TV~) ToplnCl , S.sqa Top (ftKB) ~ftKB) (°) Description Commant Run Date ID (in) - 1,814 1,697.6 45.01 Safery Valve Camco TRDP-tA-SSA' (LOCked Out 9/4/94) 10/14/1990 2.812 ' 3,115 2,412.0 63.18 GAS LIFT MERLA/fMPD/1/GLVBK/.125/1258/ CommenC STA 1 4/142003 2.875 GAS LIFT, 5,948 3,877.0 57.53 GAS LIFT MERLA/TMPDl1/GLV/B W.188/1333/ Comment: STA 2 7/74/2003 2.875 s,s3~ _ 6,937 4,335.9 58.05 GAS LIFT MERLA/TMPD/1/OV/BK/25// Comment; STA 3 7/13/2003 2.875 - 7,711 4,737.4 58.52 GAS LIFT MERLA/TMPD/1/DMY/BK/// CommenC STA 4 7/13/2002 2.875 - 8,514 5,153.8 58.91 GAS LIFT MERLA/TMPD/t/DMYBW// Comment: STA 5 7/15/2003 2.875 cAS uFr, 7.71 i ~a 9,101 5,449.3 60.59 GAS LIFT MERLA/iMPD/1/DMY/BK/U Commenk STA 6 7/26/1998 2.875 9,635 5,708.7 61J4 GASLIFT CAMCO/MMG-Z1.5/DMY/RK///Comment: STA7 7/26/1998 2.920 '' 9,684 5,731.9 62.00 PBR Baker 10' stroke PBR 10/14/1990 3.000 GASLIFT, 8.514 - J,BJH 5,738.4 62.07 PACKER Baker'HB'PACKER 10/14/1990 2.890 9,714 5,744.2 61.38 PRODUCTION CAMCO/MMG-Wl1.5/DMY/RK///CommenCCLOSEDSTAB 5/5/1995 2.867 ~ 9,827 5,797.4 63.65 NIPPLE AVA BPL nipple 10/14/1990 2.750 827 9 797.4 5 63.65 SLEEVE AVA; Set BPC 4/102007 4/10/2007 2.310 cns uFr, _ , , 9•~~~ 9 862 812 6 5 64 36 PACKER Baker'DB'PERMANENTPACKER 10/14/7990 3250 , . , . 9,877 5,819.2 64.66 NIPPLE Camco'D' Nipple NO GO 10/14/1990 2250 ' 9,884 5,822.3 64.80 SOS Baker 10/14/1990 2.441 cnsuFr. 9,fi35 ' - 9,885 5,822.7 64.82 TTL 10/14/1990 2.441 " 10,035 5,882J 67.84 FISH 1 12" OV Dropped in Hole 2/12/1995 0.000 Per~~liry bD(1S$&510tS ~ ~.` ~< ~ 7'„ ~i-r~ +~' ~- PBR, 9,884 .,~ < . Shot Top (ND) Btm (ND) Dens Top~RHB Bfm~RKB) (ttKB) (RKB) Zone Date (sh~•~ Type Comment 9,754 9,812 5,764.0 5,790.8 C -4, UNIT B, 10/11/1990 10.0 IPERF 60 deg. phasing; 4 1/2" Hollow 3 G-09 Carrier PACKER. 9,698 ~ ~4 ~ -~ ~ _ 9.940 10,010 5,845.1 5,873.4 A -4, A-3, 3G-09 8/20/1991 8.0 APERF 90 deg. phasmg; 2 1/8" DynaStrip f~ Gun 10,048 10,088 5,887.4 5,902.4 A -2, 3G-09 10/11/1990 4.0 IPERF 180 deg. phasing; 4 7/2" Hollow Cariier PRODUCTION, = 9.714 _ IPERF, ~ 9.754-9.812 ~ ta NIPPLE,9,B27 SLEEVE,9,827 PACKER.9,862 C - _~ ; ~ NIPPLE.9,877 ,, ~~. ~ i' . 505, 9,884 TTL,9,885 APERF, 9,940.10,010 FISN, 10,035 IPERF, ~' 10,04&10.088 ~ PRODUCTION. 10.300 TD, 10.322 11/28/06 ScbllmbBPgBP 1 c¡ 0- 0(0 ..-:r NO. 4054 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 \, Anchorage, AK 99501 <! Field: Kuparuk . Date BL Color CD Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth M1i'], ~,P 1,'" 9 "won \1'!tl~l" .. Well Job# Log Description 3B-13 11415652 PROD PROFILE WIDEFT 11/16/06 1 3S-07 11502019 SBHP SURVEY 11/19/06 1 3SJ10 11502020 SBHP SURVEY 11/19/06 1 1 E-24A 11502021 SBHP SURVEY 11/20/06 1 1 Y -23 11502022 PROD PROFILE WIDEFT 11/23/06 1 1H·17 11502023 SBHP SURVEY 11/24/06 1 1A-17 11502024 SBHP SURVEY 11/24/06 1 3G-Ð9 11486082 SBHP SURVEY 11/25/06 1 3B-08 11486081 SBHP SURVEY 11/25106 1 . Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ê-lL ~ g Sc~lIIIRbepge.. 11/10/06 NO. 4034 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth NO\! J. 3 2006 n. (~~~ ç;¡'mr;, eommi~n AnG"O~ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 /00 -O~7 Field: Kuparuk Well Date CD BL Color Job# Log Description 1 R·26 11416225 INJECTION PROFILE 10/23/06 1 1 R-22A 11416224 PROD PROFILE W/DEFT 10/22/06 1 2K,28 NIA INJECTION PROFILE 10/19/06 1 ~ 11415642 PROD PROFILE W/DEFT 10/24/06 1 11416226 INJECTION PROFILE 10/24/06 1 2P.-427 11415637 INJECTION PROFILE 10/20/06 1 2P-429 11415640 INJECTION PROFILE 10/22/06 1 1J·101 11445123 GLS 11/06/06 1 2P-432 11415644 INJECTION PROFILE 10/26/06 1 3G-09 11415645 PROD PROFILE W/DEFT 10/27/06 1 3K-19 11415648 INJECTION PROFILE 10/30/06 1 2W-12 11445122 PROD PROFILE W/DEFT 11/05/06 1 1R-19A 11416228 INJECTION PROFILE 10/27/06 1 3J·05 1141630 INJECTION PROFILE 10/28/06 1 1 D-04 11445121 PROD PROFILE W/DEFT 11/04/06 1 30-07 11416222 INJECTION PROFILE 10/20/06 1 2N..305 11416223 FLOWING BHP SURVEY 10/31/06 1 3A-12 11445120 GLS 11/03/06 1 2L-311 11415649 FLOWING BHP SURVEY 10/31/06 1 2L:-313 11445119 FLOWING BHP SURVEY 11/02/06 1 2Kp27 11416234 FLOWING BHP SURVEY 11/02/06 1 2L-307 11296734 FLOWING BHP SURVEY 11/04/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 3024 Company: Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 10/31/03 Field: Kuparuk Well Job # Log Description Date BL Color CD IY-19 ~B"I(~'?' PRODUCTION PROFILE/DEFT 10/09/03 3A-04 ~ ~;~-~'~ INJECTION PROFILE 10111/03 3B-03 ~ ~;~7'~(c~ tPRODUCTION PROFILE/DEFT 10113/03 3B-08 'I~?~-~-PRODUCTION PROFILE 10114103 3A-05 1 'PRODUCTION PROFILE 10/15/03 3B-06 ~ ~;~'~--)-(~)~--~_.~ PRODUCTION PROFILE 10116103 1 2T-21 i 1'~-~--~ -(~J"~LEAK DETECTION LOG 10/17/03 1 3B-04 'l~-~)/_~l PRODUCTION PROFILE/DEFT 10/~8103 1E'20 i~L'~ ~ SBHP SURVEY 10120/03 31-1~ )~'(~ LEAK DETECTION LOG 10125/03 1 3G-09 ~qO--(~t~o~7- 'PRODUCTION PROFILE 3G-~1 l ~0'0¥~ PRODUCTION PROFILE ~0127/03 11B-20 ~'~-'~,L~ PERF RECORD/STATIC SURVEY 10130/03 Please sign and return one copy of this transmital t0 Beth at the above address or fax to (907) 561-83~7. Thank you. ARCO Alaska, Inc. Kuparuk Operations Post Office Box 196105 Anchorage, Alaska 99519-6105 Telephone 907 659 2821 April 19, 1996 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate are multiple Applicaton for Sundry Approvals (Form 10-403) and in duplicate are multiple Reports of Sundry Well Operatic.ns (Form 10-404) on the following Kuparuk wells. Well Form Action 1 E- 11 10-403 (Other) Conversion 1F-16 10-403 (Other) Conversion 1 L-15 10-404 Stimulate 1Y-18 10-404 Perforate 1Y-18 10-404 Stimulate 2A-23 10-404 (Other) Conversion 2M-05 10-404 (Other) Conversion 2M-17 10-404 (Other) Conversion 2M-18 10-404 (Other) Conversion 3A-01 10-404 Stimulate 3F-03 10-404 (Other) Profile Mod 3F-04 10-404 (Other) Profile Mod 3G-09 10-404 Stimulate If you have any questions, please call me at 659-7226. Sincerely, M. E. Eck Attachments Well Files (attach only) File: FTR 041997 (w/o attach) File: FTR110196 (w/o attach) ARCO Alaska. Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown ~ Stimulate X Plugging Pull tubing ~ Alter casing ~ Repair well __ Perforate 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 X 4. Location of well at surface 2538' FNL, 170' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 1167' FSL, 1507' FEL, Sec. 25, T12N, R8E, UM;~*'~i i'"')~ ¢'~' ! i't'' ~"~ ~ /~:~;;'L ~ At effective depth ,~ i-'~ !! 6. Datum elevation (DF or KB) RKB 90 7. Unit or Property name Kuparuk River Unit 8. Well number 3G-09 9. Permit number/approval number 90-67 10. APl number 5o-1 03-201 29 1167 FSL, 1507' FEL, Sec. 25, T12N, R8E, UM At total depth 1196' FSL, 1288' FEL, Sec. 25, T12N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 10332 5984 feet Plugs (measured) feet None 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 9 7 5 8 true vertical 5 7 6 6 feet Junk (measured) feet None Casing Length Structural Conductor 11 5' Surface 45 3 3' Intermediate Production 1 0 2 8 4' Liner Perforation depth: measured 9754'-9812' true vertical 5764'-5790' Size Cemented Measured depth 1 6" 270 Sx AS I 1 1 5' 9-5/8" 1000 Sx AS III & 4538' 735 Sx Class G 7" 727 Sx Class G & 1 0 3 0 0' 235 Sx Class G Tail True vertical depth 115' 3079' 5977' , 9940'-1 0010', 10048'-10088' , 5846'-5873', 5887'-5902' Tubing (size, grade, and measured depth) 3-1/2" 9.3#, EUE, ABMOD, @9859' w/Tail 2-7/8" 6.5#, EUE, ABMOD .~.t958~6~;';~',~¢~'''~'-;'¢~;~''~'~'-''';''~' &,-,r-~,~: ;-,--: - :~ Packers and SSSV (type and measured depth) *'. ......... SSSV: Camco TRDP-1A-SSA (1814'), Packer: Baker (9684'), Packer: Baker Model DB (9862') 3. Stimulation or cement squeeze summary Re-Fracture "A" Sand on 09/14/95. Intervals treated (measured) 9940'-10010', 10048~d 0088' Treatment description including volumes used and final pressure Pumped 140 Mlbs 20/40, 12/18, & 10/14 ceramic proppant into formation, fp was 6151 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1 1 81 8 6 9 28 798 162 Subsequent to operation 3225 3296 88 1344 191 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 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. S igned~~" ~ ~'~ Title Wells Super intendant Form '10L404 Rev 06/15/88 Date ~,~~_//'~' SUBMIYIN DOPLICATE ARCO Alaska, inc. -~. '~,~. KUPARUK RIVER UNiT ~, WELL SERVICE REPORT ~' Kl(3G-09(W4-6' WELL JOB SCOPE JOB NUMBER 3G-09 FRAC. FRAC SUPPORT 0910951630.4 DATE DAILY WORK UNIT NUMBER 09/14/95 ASANDPREFRAC DAY OPERATION COMPLETE tSUCCESSFUL KEY PERSON SUPERVISOR 2 (~) Yes O No I (~) Yes O No DS-GAll I=GOS WILDER,., , RELB AFC# CC# DALLY COST AOOUM COST Si n~.,_,.,, ~ ~,)~ ESTIMATE 998458 230D. S36GL $121,690 $131,476 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann l lnitial Outer Annjt Final Outer Ann 650 PSI 1300 PS! 1450 PSI 500 PSll 0 PSII 0 PS! DAILY SUMMARY IPUMPED A SAND REFRAC USTNG 50 LB. GEL SYSTEM TAILING IN WITH 40 LB. GEL THE LAST 2 PROP. STAGES. PUMPED TO FLUSH. AVE. RATE 12 RPM AT 4500 PSIG. MAX. PRESS 6151 PSIG DURING CONDITIONING STAGE. TOTAL FLUID PUMPED 1332 BBLS. TOTAL PROP. INTO FORMATION 140,349 LBS. TIME 07:30 10:00 10:25 11 '05 12:45 14:15 15:00 LOG ENTRY DS MIRU, HELD SAFETY MTG. PRIMED UP PUMPS. PRESS. TESTED TO 9400 PSIG. PRE SET FORCE CLOSURE CHOKE TO 4 BPM AT 2200 PSIG. SET TREE SAVER. STARTED PUMPING CONDITIONING STAGE. AVE. RATE 15 BPM AT 5600 PSI. TOTAL FLUID PUMPED 275 BBLS. PUMPED 2102 LBS. 20/40 PROP. AT 1 PPG. PERFORMED FORCED CLOSURE. ISIP 1771 PS1. STARTED PUMPING DATA FRAC. AVE RATE 10 BPM AT 3400 PSI. TOTAL FLUID PUMPED 186 BBLSo ISIP 1789 PSI. STARTED PUMPING FRAC USING A 50 LB. SYSTEM TAIMNG IN WITH 40 LB. GEL THE LAST 2 SAND STAGES. AVF_ :lATE 12 BPM AT 4500 PSI. TOTAL FLUID PUMPED 871 BLS. TOTAL PROP. PUMPED 140,349 LBS. 20/40-3,588 LBS.)(12/18-126,538 LBS.)(10/14-11874 LBS.) PUMPED TO FLUSH. ISIP 2228 PSI. START RIGGING DOWN. RECOVERED ALL TREE SAVER RUBBERS. , RELEASED WELL TO DSO TO LEAVE SHUT TO WAIT ON SLICKLINF_ STATE Of ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION 0 R I ~ ~i ~ REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown Pull tubing Alter casing Stimulate Plugging ,, Perforate X Repair well Other 2. Name of Operator AR(~O Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 2538' FNL, 170' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 1167' FSL, 1507' FEL, Sec. 25, T12N, R8E, UM At effective depth 1167 FSL, 1507' FEL, Sec. 25, T12N, R8E, UM At total depth 1196' FSL, 1288' FEL, Sec. 25, T12N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 6, Datum elevation (DF or KB) ~)0' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3G-09 9. Permit numbedapproval number 90-67 10. APl number 50-103-20129 11. Field/Pool Kuparl~ ~i,~r,.Qi[ ,P~;)l,. ELl:! V [:L) feet Effective depth: measured true vertical Length 1O332' 5984' 9758' 5766' Size feet feet feet feet Cemented Plugs (measured) None Junk (measured) None Measured depth JAN 2 8 t992 Alaska 0ii & Gas Cons. Commission Anchorage True vertical depth 115' 16" 4538' 9-5/8" 1 0300' 7" Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 9990'-10010', true vertical 5866'-5873', Tubing (size, grade, and measured depth) 270SxASI 115' 115' 1000 Sx AS III & 4538' 3079' 735 Sx Class G 727 Sx Class G & 10300' 5977' 235 Sx Class G Tail 9965'-9990', 9940'-9965' 5856'-5866', 5846'-5856' 3-1/2" 9.3#, EUE, ABMOD, @9859' w/Tail 2-7/8" 6.5#, EUE, ABMOD @ 9885' Packers and SSSV (type and measured depth) SSSV: Camco TRDP-1A-SSA (1814'), Packer: Baker (9684'), Packer: Baker Model DB (9862') 13. Stimulation or cement squeeze summary Perforate 9940'-10010' Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure -1314- -795- -590- -230- -1278-~ -1084-~ -676- -200- Tubing Pressure -176- -152- 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector__ 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 09/12/90 Title Operations Engineer Date ///Z ar/?Z. SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company ,VELL C -RACTOR REMARKS JPBDT I/". :)-f . WELL SERVICE REPORT FIELD - DISTRICT- STATE (~P~R~I'~oN AT REPbF~:I'-'I'IME I A,,~ DATE D i ~- ~ ~?/ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ~ Visibility l Wind Vel. Weather i Temp. i Chill Factor i Report OF ~ o1= ,.,.,;I,-o '. SuD$~chaP/of Atlant:¢ .~ichhe~d ComD~. ; WELL SERVICE REPOF WELL · CONTRACTOR REMARKS .PBDT i FIELD - DISTRICT . STATE . DAYS DATE iOPERATION AT REPORT TIME CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ' ~Wind Vel. Weather i Temp. : Chill Factor j Visibility ~ Report i OF i OFI miles I ; . DIST: ORIG - NSK KOE FILES DS ENG KOE FILES DS FOREMAN NSK CENT FILES KUPARUK OPERATIONS ENGINEERING PERFORATION RECORD WELL NAME: .3 q.7 -o~' &,EN~. REP: TIED IN WITH: ~ D~ DATED ~/b/~ o ~ CBUCET, DATED COMPLETION ~AILS: ~/~'~ ~ % , - GUN INFO: ~/~" PYN~5~ 8PF: ~ , PHASING: o' , ORIENTATION: G~M ~:~o,~ , .HOLE SIZE ~. ~ ~ ~ ~, DATE: SERV. CO & ENG: PERF INTERyrAL: SAND /-/3 INT SAND INT SAND INT GUN PROPOSED PROPOSED GUN CCL CCL RUN PERFORATIONS PERFORATIONS LENGTH TO TOP SETTING NO. (md-D IL) (md-C ET) ( ft ) SHOT DEPTH COMMENTS TIME GUN SHOT qclctD -loo~b q~q0-tooto '~--0 OIL AND GAS CONSERVATION COl , ,, SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL ~] GAS [~] SUSPENDED [~] ABANDONED [--] SERVICE r=~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-67 3 Address 8 APl Numbe~ P.O. Box 100360r Anchorage, AK 99510-0360 50-103-20129 4 Location of wollatsurfaco ;~"'i!~:;';.~7'-"'-:-'"'~ E £ , 9 uniter Lease Name 2538' FNL, 170' FWL, SEC 24, T12N, RSE, UM ......... YEEll:IED KUPARUK RIVER ~1 , :'"":" ':: i 10 Well Number At Top Producing Interval ~'-~,~ '.~Z~ "' .~ ~..~ At Tota~ Depth "?~"~' .......~=~a=~ 0ii & Gas ,., ,~,,,.,... -- -'"0aS.L;:'''"nrmsS~'u~ 14 Fiaa and Poo~ 1196' FSL~ 1288' FELt SEC 25~ T12N~ RSE~ UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KS, DF, etc.) [ 6 Lease Designation a~.~],l~ KUPARUK RIVER OIL POOL RKB 90'[ ADL 25548 ALK 2662 12 Date Spudded 5/27/90. 13 Date T.D. Reached 6/05/90. 14 Date Comp. , Susp. or Aband.~ Ils water Depth' if OffshOre NA feet MSL 116 NO' Of cOmpletiOns 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 10332' MD, 5984' MVD 10213' MD, 5946'TVD YES ~ NO [--I 1814' feet MD 1600' APPROX 22 Type Electric or Other Logs Run EWR/CN//SFD/DGR/CET/CBL/GYRO 23 CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 270 SX AS I 9-5/8" 36# J-55 SURF 4538' 12-1/4" 1000 SX AS II1~ 735 SX CLASS G 7" 26# J-55 SURF 10300' 8-1/2" 727 SX CLASS G & 235 SX CLASS G TAIL 24 Perforations open to.Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE IDEPTH SET (MD) PACKER SET (MD) 3-1/2" X2-7/8" TAIL 9885' 9698', 9862' 9754'-9812' W/4-1/2" CSG GUN @ 10SPF MD 5764'-5790' TVD I 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 10048'-10088' W/4-1/2" CSG GUN @ 4SPF MD 5887'-5902' TVD DEPTH INTERVAL (MD) AMOUNT 8, KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD .k Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CC~TINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NNVE~ Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 9758' 5766' NA KUPARUK C Be'I-rOM 9810' 5790' KUPARUK A TOP 9911' 5834' KUPARUK A BOTTOM 10279' 5969' · 31. LIST OF ATTACHMENTS GYRO 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~~ Title AREA DRILLING ENGINEER Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO (, .... d Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial ReiN3rt" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior tO sl:~dding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. Field KUPARUK RIVER UNIT ICounty. parish or borough NORTH SLOPE Lease or Unit ADL: 25548 ALK: 2662 Title COMPLETION IState AK ell no. 3G-~9 Auth. or W.O. no. AK4966 Operator ARCO Spudded or W.O. begun SPUD Date and depth es of 8:00 a.m. 09/29/90 (14) TD: 0 PB:10218 SUPV:GB 09/30/90 (15) TD: 0 PB:10218 SUPV:GB 10/01/90 (16) TD: 0 PB:10218 SUPV:GB 10/02/90 (17) TD: 0 PB:10203 SUPV:GB 10/04/90 (19) TD: 0 PB:10203 SUPV:DB IDat. 05/27/90 IH°ur04:0 ARCO W.I. 55.252072 Pr or status if a W.O. The above is correct Signature Complete record for each day reported NORDIC 1 TIH W/BIT #1 7"@10315' MW:10.4 WBM MIRU, ACCEPT RIG @ 17:00 HRS,CLEAN PITS,RAISE AND PIN WINDWALLS,HOOK UP GUIDE- LINES,ND WELLHEAD,NU BOPE, SET TEST PLUG, TEST ALL BOPE EQUIPMENT TO 5000 PSI (EXCEPT ANNULAR) TEST ANNULAR TO 3000 PSI,TEST ALL LINES,VALVES,MANIFOLD, SET BOWL PROTECTOR, RU FLOOR TO RUN DP IN HOLE,MU 6-1/8" BIT/BUMPER SUB/12 4-3/4"DC TRIP IN HOLE DAILY:S48,977 CUM:$1,266,338 ETD:S1,266,338 EFC:$1,889,500 POOH 7"@10315' MW:10.5 WBM RIH W/BIT AND DC ON 3-1/2" DP TO 2100',CIRC OUT DIESEL AND BRINE CAP,RIH TO 5000',CIRC AND COND MUD, RIH TO 7000',BREAK CIRC @ 7000',1000 PSI, CIRC AND CONDITION MUD, PU DP AND RIH TO 8540',TOOK WT, CIRC BTMS UP,3.75 BPM, 1450 PSI, RIH TO 9319'P~AND TEST KELLY,DRLG CMT 9319-9387'BLOW DOWN AND STAND BACK KELLY, RU FLOOR TO POOH,POOH DAILY:S28,147 CUM:$1,294,485 ETD:S1,294,485 EFC:$1,889,500 DRLG CMT @ 9675' 7"@10315' MW:10.5 WBM POOH, LD BTM 12 JTS DP,LOAD PIPE SHED W/12 4-3/4" DC, PU SAME MU BHA #2,RIH W/ BHA ON 3-1/2" DP,PU KELLY, BREAK CIRC DRILLING CEMENT 9387-9675' DAILY:S130,877 CUM:$1,425,362 ETD:S1,425,362 EFC:$1,889,500 !~:~TO POOH 7"@10315' MW:10.5 WBM ~i~TO 9681', MIX&PUMP DRY JOB, RIG TO POOH, ADJ RIG ~S, SERVICE RIG, POOH, CHANGE BITS, TIH W/DC'S & 10 STDS DPg/ CUT DRILL LINE, FTIH W/ BIT#3, DRILL CMT F/9681'-9777', WASH & REAM CMT STRINGERS F/9777' TO 10190', CIRC HOLE CLEAN & COND MUD, NEW PBTD @ 10203' DOYON 14 RKB, BLOW DWN KELLY, SET BACK PUMP DRY JOB DAILY:S30,485 CUM:$1,455,847 ETD:S1,455,847 EFC:$1,889,500 R/U HLS TO RUN CBL/PET 7"@10315' MW:10.5 WBM TRIP OUT OF HOLE WITH BIT #3. TEST CSG WITH 3500 PSI FOR 30 MIN, LOST 75 PSI. FINISH POOH. M/U BIT #4RR AND 7" CSG SCRAPER, TIH. CIRC, DISPLACE MUD IN HOLE WITH 11.2 BRINE. POOH, L/D 12 DC. RU HLS WIRELINE TO RUN CBL/PET LOG. DAILY:S28,867 CUM:$1,484,714 ETD:S1,484,714 EFC:$1,889,500 For form preparation and distribution, see Procedures Manual, Section 10,~,,'~ Drilling, Pages 86 and 87. / STAND BACK KELLY 7"@10315' MW:ll.2 NaCl RIH W/ HLS CBL/PET TOOLS, UNABLE TO GET BELOW 9650', POOH. RIH W/ PET, UNABLE TO GET BELOW 9670', LOG UP 2000' TO TIE IN WITH PET OF 6/12/90. CORRECTED DEPTH 9695' WLM. GOOD CMT FROM MAX DEPTH TO 9583' WLM, POOH. (PET SHOWS 75 DEGREE DEVIATION AT STOPPING PT) RIH W/ CBL, STOPPED AT 9697 WLM. LOGGED UP TO TIE IN, SHOWED GOOD CMT TO 9543' WI/Vh POOH. 968~' WL~. LO.at, LIP DKILLING~T~. M/U AND RIH W/ BIT #4RR 7" CSG SCRAPE~, 2 JUNK BASKET~, BIT SUB, 6-1/8" TAPERED ~/~/*f D,Iling Supt. AR3B-459-1-D Number all dally well history forms consecutively as they are prepared for each well. IPage no. ARCO Ci Gas Company ,~, Daily Well History--interim Instructions: This form is used during drilling or workover operations, if testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all COreS. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. I) Submit "Interim" sheets when filled out but not less trecluently than every 30 days, or {2) on Wednesday of the week in which oiJ string is set. Submit weekly for workovers and following selting of oil string until completion. District IlCounty or Parish i State ARCO ALASKA INC. NORTH SLOPE AK Field L ...... Unit ~G/werl0~~' KUPARUK RIVER UNIT ADL:25548 ALK:2662 - Date and depth as of 8:00 a.m. 10/05/90 (20) TD: 0 PB:10203 SUPV:DB/SK 10/06/90 ( 21 TD: 0 PB:10203 SUPV:DB/SK 10/07/90 ( 22 TD: 0 PB:10203 SUPV:DB/SK 10/08/90 ( 22 TD: 0 PB:10203 SUPV:DB/SK The above is correct Signature Complete record for each day while drilling or workover in progress NORDIC 1 STRING MIL ON 12 4-3/4" DC. WASH AND REAM 9312'-10190' NO RESTRICTIONS OBSERVED. CIRC HOLE CLEAN, POOH, SET BACK KELLY. DAILY:S36,790 CUM:$1,521,504 ETD:S1,521,504 EFC:$1,889,500 R/D HLS 7"@10315' MW:ll.2 NaC1 SERVICE-RIG, POOH W/ DP AND BHA, LITTLE MATERIAL IN JB. R/U HLS, RUN CBL TO 10213' WLM (EWR 6/6/90). LOG UP TO 9700' WLM. LOG SHOWS GOOD BOND ABOVE C SAND, POOR BOND BELOW C SAND. POOH W/ CBL RIH W/ GYRO, LOG W/ GYRO. POOH W/ HLS. R/U LUBRICATOR, RIH W/ EZSV ON HLS. SET EZSV AT 9887' WLM POOH. TEST LUBRICATOR TO 600 PSI. RIH W/ PERF GUN, SHOOT SQUEEZE HOLES 9850-9852', 6 SPF, 60 DEGREE PHASING. POOH W/ HLS. PRESSURE UP TO TEST SQUEEZE HOLES. INJ RATE 0.75 BPM AT 1350 PSI. R/D HLS. DAILY:S41,678 CUM:$1,563,182 ETD:S1,563,182 EFC:$1,889,500 POH W/ 3-1/2" DP 7"@10315' MW:ll.2 NaC1 FINISH RD HLS, RU FLOW NIPPLE, RU TO RIH, MU HOWCO CHAMP 4 SQUEEZE PKR, RIH W/ PKR AND DP, SET PKR AT 9500', RU DS AND CIRC LINES, ESTABLISH INJECTION RATE, OPEN BYPASS, BATCH MIX CEMENT, PUMP 25 BBLS WATER - 31 BBLS CMT - 10 BBLS WATER - 1.5 BBLS BRIN, CLSOE BYPASS, INJECT LEAD WATER AND CEMENT UNTIL CEMENT1.5 BBLS BELOW PACKER, HESITATE AND SQUEEZE CMT AWAY, CIP AT 2000 HRS, RD DS, HOLD PRESS 4 HRS, BLEED OFF PRESSURE AND UNSEAT CHAMP 4 PKU, REVERSE CIRC 2 DP VOLUMES, RD CIRC LINES, PULL 20 STDS, MIX AND PUMP DRY JOB, CONT POH W/ 3-1/2" DP AND CHAMP 4 PKR DAILY:S94,116 CUM:$1,657,298 ETD:S1,657,298 EFC:$1,889,500 7"@10315' MW:ll.2 NaC1 CONT POH W/ DP, LAY DOWN SQUEEZE PKR, MU 6.125" BIT - BIT SUB - DC'S, RIH, SLIP AND CUT 50' OF DRILLING LINE, RIH AND TAG CMT AT 9507', KELLY UP AND BREAK CIRC, TEST CSG TO 2000 PSI AT 9500' (OK), DRILL SOFT CMT TO 9655', SERVICE DRLG RIG DRILL AHEAD, HARD CMT FROM 9655' TO 9872', COND BRINE, CIRC BTMS UP, PRSS TST CSG TO 2000 PSI, LOST 600 PSI, VERIFY SURFACE EQUIPMENT, FOUND ALL OK,' REPRE$SURE 2000 PSI, LOST 400 PSI IN ONE MINUTE, DPOP TO 1150 PSI IN 15 MIN DAILY:S60,712 CUM:$1,718,010 ETD:S1,718,010 EFC:$1,889,500 For form preparation and distribution see Procedures Manual Sect on 10, ~ POH W/ 3-1/2" DP 7"@10315' MW:ll.2 NaC1 RIG SEVICE AND FUNCTION BOP, VERIFY BP AT 9871', TST CSG TO 2000 PSI, PRESS BLEED TO 1550 PSI IN 15 MIN, BLOW DOWN KELLY POH, PULL WEAR RING, SET TST PLUG, BOP TST, RIH W/ 3-1/2" DP OPEN ENDED, TAGGED BP AT 9871', RIG UP HOWCO, BREAK CIRC, I~J P3.TE ! 99L/MTM Am 75~0 PSI. PU~ ~ BBLS WATER - 21 BBLS ~u~ _ o ~TC W~m~ -- 5q BBLS BRINE. ~QH 15 STDS, RIG UP TO ....... ~te t:it,~iG Up TO SQZ CMT, CLOSE Dp REV CIRC, V CIRC 1 DP VO Drilling Supt. AR3B-459-2-B ~,]aska Oii & t, as u0ns. Uu~m"~"~'erall daily well hislory , ........... lively ~ .- ~as {hey are prepared for each well. / ARCO Oi' .;as Company ~. Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number a11 drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerim" sheets until final completion. Report official or representative test on "Finel" 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. · County or Parish IState District I AR~% ATJA.qKA TNC NORTH SLOPE Field Lease or Unit ~{[~PART]K RTVFR [INIT ADL:25548 ALK:2662 Date and depth Complete reco,d for each day while drilling or workover in progress as of 8:00 a.m. 10/09/90 (24) TD: 0 PB:10203 SUPV:DB/SK 10/10/90 ( 25] TD: 0 PB:10203 SUPV:DB/SK 10/11/90 ( 26 TD: 0 PB:10203 SUPV:DB/SK 10/12/90 ( 27 TD: 0 PB:10203 SUPV:DB NQRDIC 1 RAMS, PRESS UP TO 2500 PSI, 2 BBLS DISPLACED, AFTER .5 HRS PRESS RELEASED, BLEED BACK 1-3/4 BBLS, RD HOWCO, POH W/ DP DAILY:S48,422 CUM:$1,766,432 ETD:S1,766,432 EFC:$1,889,500 CIRC. BOTTOMS UP 7"@10315' MW:ll.2 NaC1 RIG SERVICE, FUNCTION TST BOPE AND CROWN-O-MATCI, LAY DOWN 19 SINGLES, MU 6.125"BIT - BIT SUB - 22 DC'S - AND TIH, KELLY UP AND WASH FROM 9340'-9404', DRILL TO 9758', SERVICE RIG, CBU AT 9758', TST CSG TO 2000 PSI (OK), DRILL TO BRIDGE PLUG AT 9871', CBU, TST CSG TO 2000 PSI (OK), DRILL UP BP AT 9871', BLOW DOWN KELLY AND STAND BACK, PUSH DOWN BP TO PBD AT 10190', CBU DAILY:S33,434 CUM:$1,799,866 ETD:S1,799,866 EFC:$1,889,500 CIRC AND CONDITION BRINE 7"@10315' MW:ll.2 NaC1 CBU, LAY DOWN 15 JTS 3-1/2" DP, PIO 142 STDS, LAY DOWN 10 DC'S, STAND BACK 6 STD'S DC'S, MU BIT - 2 JUNK SUBS - SCRAPER - STRING MILL - 6 STD'S DC'S AND RIH W/ SAME, SLIP AND CUT 50' OF DRILLING LINE, PICK UP KELLYY AND REAM FROM 9404' TO 10190', DOUBLE REAM FROM 9404' TO 9871', COND AND FILTER BRINE DAILY:S28,147 CUM:$1,828,013 ETD:S1,828,013 EFC:$1,889,500 PERFORATING 7"@10315' MW:ll.2 NaC1 CONTINUE CIRC AND FLITERING BRINE, WEIGHT UP BRINE TO 11.2 PPG, POH AND STAND BACK 3-1/2" DP, LD DC'S AND BHA, RU HLS E-LINE, TEST LUBRICATOR, PERFORATE 'A' SAND, GUN #1 (20') - FROM 10088' TO 10068', GUN #2 (20') - FROM 10068' TO 10048', OUT OF HOLE W/ GUN #2 AT 0600 DAILY:S51,660 CUM:$1,879,673 ETD:S1,879,673 EFC:$1,889,500 RIH W/ 3-1/2" DP 7"@10315' MW:ll.2 NaC1/Br PERFORATE 'C' SAND WITH 4-1/2" CSG GUNS - 10 SPF - 60 DEG - 36 GRAM DP SHOTS, GUNS #3 AND #4 (20' EACH): FROM 9812' TO 9792', GUNS #5 AND #6 (20' EACH): FROM 9792' TO 9772', GUNS #7 AND #8 (18' EACH): FROM 9772' TO 9754', MU 6" GR/JB AND RIH TO 10010' (WORK ACROSS 'C' SAND PERFS AND PACKERS SETTING AREA, POH, RECOVER A FEW SMALL PIECES OF METAL AND SCALE,'MU PERM PKR AND TAILPIPE ASSEMBLY ON WL SETTING HEAD, RIH AND SET PKR AT 9862' WLM, POH, RD HLS E-LINE UNIT, RIH 79 STDS 3-1/2" DP, POH, LDDP, RIH REMAINDER OF DP DAILY:S108,517 CUM:$1,988,190 ETD:S1,988,190 EFC:$1,889,500 AK t Well no. G-09 The above is correct sign~' i t ~ ,Dele For ~orm preps¥~tJon a~d dJslrJbu~Jbn Drilling, Pages 86 a~ ~ ~ ~ JTitle Dr.!!!!ng Sjpt. AR3B-459-2-B Anchorago Number all daily well hislory forms consecutively as they are prepared for each well. Ir.. ARCO 01. Gas Company Daily Well History--Interim Instructiona: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem Jests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final campletion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less trequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and lotlowing setting ot oil string until completion. District Field K[~PARUK RIVE Oats and deptll as of 8:00 a.m. I Counly or Parish I NORTH SLOPE ALASKA INC, {Lease or Unit - ;R UNIT I ADL:25548 ALK:2662 Complete record for each day while drilling or workover in progress 10/13/90 ( 28 TD: 0 PB:10203 SUPV:DB 10/14/90 ( 29 TD: 0 PB:10203 SUPV:DB NORDIC 1 IState AK IweJl no. G-09 RUNNING 3-1/2" COMP ASSY 7"@10315' MW:ll.2 NaC1/Br SERVICE RIG, FUNCTION BOP, CHECK CROW-O-PLATIC, FINISH RIH 79 STDS 3-1/2" DP, POH AND LDDP, PULL WEAR BUSHING, RD SPINNERS CLEAR DP OUT OF PIPE SHED, RU FOSTER TONGS, LOAD 3-1/2" TBG IN PIPE SHED, DRIFT AND TALLY TBG, INSTALL SEAL RINGS, DRIFT GLM'S, PU AND MU BAKER LOCATOR/SEAL ASSEMBLY AND RUN 3-1/2~' COMP. ASSEMBLY, TEST CL TO 5000 PSI, TAG PERM. PKR AT 9862', STAB-IN AND LOCATE OUT, HAVE A LEAK, RETURNS REDUCED BY 1/2 WHEN STABBED-IN AND LOCATED OUT, PLAN TO VERIFY WHERE LEAK IS (SUSPECT 3/4" ORIFICE WITH CHECK VALVE) BY RU SL UNIT TO PULL 3/4" ORIFICE WITH CV AND SET DUMMY DAILY:S28,641 CUM:$2,016,831 ETD:S2,016,831 EFC:$I,889,500 RU OTIS SLICK LINE 7"@10315' MW:ll.1NaC1/Br REVERSE CIRC., SURGE TO CLOSE 3/4" CV, NO GOOD, REVERIFY STAB-IN, MARK PIPE AND SPACE, TEST CNTL LINE TO 5000 PSI WHEN MU TO HANGER, LAND HANGER AND RILDS, RU OTIS S-LINE, PULL 3/4" CV FROM GLM AT 9635', SET DV, PUT CHARGE PUMP ON HOLE, STILL CIRCULATES FREELY, RIH AND PULL 'BPI' SLEEVE FROM AVA NIPPLE AT 9827', RIH AND SET 'BIP' PLUG IN SAME AVA NIPPLE, PUT CHARGE PUMP ON HOLE, STILL cIRCULATES FREELY, VEIFIES LEAK IS ABOVE AVA NIPPLE AND SEAL ASSEMBLY IS OK, PULL 'BIP' PLUG, RE-SET 'BPI' SLEEVE IN AVA NIPPLE, RD SLICKLINE, RU HLS E-LINE, RIH WITH SPINNER/TEMP/CCL/GR TO 9870', CIRCULATE WITH CHARGE PUMP AND LOG UP, VERIFIED LEAK IN GLM AT 9635' (DUMMY NOT SET), LOG OUT AND CHECK OTHER JEWELRY, NOT OTHER LEAKS FOUND, RD HLS E-LINE AND RU OTIS S-LINE, (PLAN TO RE-SET DUMMY IN GLM AT 9635' AND PROCEED WITH SETTING PAKCER) DAILY:S32,147 CUM:$2,048,978 ETD:S2,048,978 EFG:$1,889,500 R CF iV D Gas Uons. L;om~'~'ssi¢'''' Anchorage The above ia correct S,g.atu¢."'* I [ For form prs~a~tion~and distri~tJon see Procedu~Manu~l Section 10,~ Drilling, Pag~ 87 O.r!!!ing Supt- AR38-459-2-B Number all daily well hislory forms consecutively as they are prepared lot each well. ARCO~ and Gas Company Daily Well History-Final Report Instructions: Prepare and submit, th~:~'.ll~4~ ~' o~ the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted' al~_=~-~tatlons are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report=cO~l~ ~ml:hlsentative test data in blocks provided. The "Final Report" form may be used tot reporting the entire operation if space is available. ~--~-7 % rAccounting cost center code District /State ARCO ALASKA INC. / AK I County or Parish I NORTH SLOPE Field JLease or Unit JWell no. KU?ARUK RIVER UNIT J ADL:25548 ALK:2662 3G109 J Title J COMPLETION Auth. or W.O. no. AK4966 OperatorARCO IA.R.Co. Spudded or W.O. begun ~ Date SPUD J 05/27/90 Date and depth Complete record for each day reported as of 8:00 a.m. NORDIC 1 10/15/90 (31) TD: 0 PB:10203 SUPV:DB Iotal number of wells (active or inactive) on thi% ost center prior to plugging and cc bandonment of this well .-~-.~ · ~-~- our I Prior status if a W.O. 04:00 J RIG RELEASED 7"@10315' MW:ll.1 NaC1/Br RIH W/ SETTING TOOL AND BRASS SHEAR STOCK IN CATCH. BEAT DOWN IN GLM AT 9635' TO DRIVE DUMMY INTO POCKET, STILL CIRCULATES WITH C~ARGE PUMP. POOH, PU NEW DUH_HY, RIH AND SET DUMMY IN GLM AT 9635'. POOH R/D OTIS. SET PACKER WITH 2500 PSI ON TUBING. SHEAR PBR W/ 100K# HOOK LOAD AND 1950 PSI IN TUBING. LAND TBG RILDS. TEST SSSV TO 1000 PSI, OK. R/U OTIS, RIH AND PULL DUMMY FROM GLM AT 9635'. RIH AND SET 48/64" ORIFICE CHECK VALVE IN GLM AT 9635'. SET BPV, ND BOPE, NU TREE. SHEAR SOS W/ 3400 PSI. REVERSE 12 BBL DIESEL INTO ANN~3LUS. INJECT 4 BBL DIESEL DONW TUBING AT 1200 PSI. RELEASE RIG @ 20:30 14-0CT-90. DAILY:S28,641 CUM:$2,077,619 ETD:S2,077,619 EFC:$1,889,500 Old TD J New TD J Date 072 PB Depth Released rig Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest lime Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective ~a~e [ corrected I __ . The above ia correct ITM prep~n~ .,~d distribulion,~ t ~ ' -- ....... = ----r For form see Procedures ~ ~ Section 10, ~ Drilling, Pages 86 and 87. AR3B-459-3-C INumber all daily well history forms consecutively as they are prepared for each well. · . i.:: i._;P DTH NO. r x ~0. ~ X 14 ~, 900:5~0. 55 4PO~389. PP ?O°P~ 8~900~$~0.8~ 490~0~. 04 ?O°PP' ~?,O~'' ¥1ClNIPY I'~ P Mt, ?0° PP' 4p', ~PP" ' I~0 °00'3p,855" /0 b". N.L.,,, FVt,&. 0.$. p~O P$$0' s$9' 00.9 $$.9 P$ $0'~ PPO' 40.4 ~4.0 Pb38'~ I?0' 07.8 $3.7 PO~O'~ 145' 47. g 854 P$30'~ IgO' 46.8 53,0 ~'~ ~0' 4?.~ ~.I ~'~ ?0' ~6.~ ~.I 8~J~'~ I~0' 46,6 ~.9 ~lOCO A&bSKA,/NC. ow~. NO. ' GREAT LAND DIRECTIONAL DRILLING, Client .... : ARCO ALASKA, INC. Field ..... : Kuparuk River Unit Well ...... : KRU 3G-9 (24-12-8) Section at: S,29.97,E Surveyor..: MIKE NAIRN RECORD 0~' SURVEY ORIGINAL 10/15/90 Computation...: RADIUS OF CURVATURE Survey Date...: 10/04/90 RKB Elevation.: 90.00 ft Job Number .... : AK1090G248 API Number .... : 50-103-20129 S MEAS INCLN C DEPTH ANGLE 7 100 0.36 7 200 0.45 7 300 1.47 7 400 4.72 7 500 8.68 VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE BEARING FROM-WELL-HEAD 100.0 10.0 -0.0 S 74.88 E 0.2 N 0.2 E 200.0 110.0 0.5 S 66.77 E 0.1 S 0.9 E 300.0 210.0 2.0 S 36.93 E 1.1 S 2.2 E 399.8 309.8 7.4 S 29.33 E 5.6 S 5.1 E 499.1 409.1 19.0 S 20.44 E 16.2 S 10.0 E CLOSURE DL DISTNCE BEARING /100 0.3 N 52.56 E 0.36 0.9 S 85.68 E 0.09 2.4 S 63.50 E 1.02 7.6 S 42.48 E 3.25 19.0 S 31.82 E 3.97 7 600 10.23 7 700 10.93 7 800 11.36 7 900 15.45 7 1000 19.81 597.8 507.8 35.2 S 17.91 E 31.7 S 15.4 E 696.1 606.1 53.1 S 15.97 E 49.3 S 20.8 E 794.2 704.2 71.7 S 14.53 E 67.9 S 25.9 E 891.4 801.4 94.0 S 13.20 E 90.4 S 31.4 E 986.7 896.7 123.0 S 12.64 E 119.9 S 38.2 E 35.3 S 25.96 E 1.55 53.5 S 22.88 E 0.70 72.7 S 20.85 E 0.43 95.7 S 19.16 E 4.09 125.9 S 17.67 E 4.36 7 1050 23.35 7 1100 26.36 7 1200 25.86 7 1300 26.28 7 1400 27.45 1033.2 943.2 140.6 S 13.40 E 137.8 S 42.3 E 1078.6 988.6 160.7 S 13.76 E 158.3 S 47.3 E 1168.4 1078.4 202.9 S 13.27 E 201.1 S 57.6 E 1258.2 1168.2 244.9 S 12.67 E 243.9 S 67.4 E 1347.4 1257.4 288.4 S 15.61 E 287.7 S 78.5 E 144.2 S 17.07 E 7.08 165.2 S 16.63 E 6.02 209.1 S 15.97 E 0.51 253.0 S 15.45 E 0.44 298.2 S 15.25 E 1.33 7 1500 29.07 7 1600 30.85 7 1700 35.26 7 1800 39.48 7 1900 46.58 1435.5 1345.5 334.2 S 14.44 E 333.4 S 90.7 E 1522.1 1432.1 382.4 S 15.53 E 381.7 S 103.6 E 1605.9 1515.9 435.5 S 18.19 E 433.8 S 119.5 E 1685.3 1595.3 494.9 S 17.66 E 491.6 S 138.1 E 1758.4 1668.4 561.8 S 20.46 E 556.0 S 160.4 E 345.5 S 15.22 E 1.64 395.5 S 15.19 E 1.80 450.0 S 15.39 E 4.50 510.6 S 15.70 E 4.23 578.7 S 16.09 E 7.25 7 2000 48.40 1826.0 1736.0 634.2 S 17.86 E 625.6 S 184.6 E 652.3 S 16.44 E 2.33 'Survey Codes: 7/GYRO ( KRU3G9G ) .,' KRU 3G-9 (24-12-8) S MEAS INCLN C DEPTH ANGLE 7 2100 50.15 7 2200 54.97 7 2300 60.18 7 2400 61.67 7 2500 59.90 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 1891.2 1801.2 708.8 1952.0 1862.0 787.8 2005.6 1915.6 872.1 2054.2 1964.2 959.5 2103.0 2013.0 1046.7 7 2600 57.85 2154.7 2064.7 7 2700 57.88 2207.9 2117.9 7 2800 59.71 2259.7 2169.7 7 2900 61.18 2309.0 2219.0 7 3000 61.35 2357.1 2267.1 RECORD OF SURVEY DIRECTION BEARING S 22.08 E S 26.16 E S 29.30 E S 29.13 E S 28.02 E RELATIVE-COORDINATES FROM-WELL-HEAD 696.9 S 210.5 E 769.3 S 242.9 E 844.0 S 282.2 E 920.2 S 324.8 E 996.9 S 366.6 E 1132.3 S 27.81 E 1072.5 S 406.6 E 1216.9 S 27.18 E 1147.6 S 445.7 E 1302.3 S 28.53 E 1223.3 S 485.7 E 1389.3 S 30.87 E 1298.8 S 528.8 E 1476.9 S 32.72 E 1373.3 S 575.0 E 7 3100 62.40 2404.2 2314.2 1565.0 7 3200 62.77 2450.3 2360.3 1653.8 7 3300 62.29 2496.4 2406.4 1742.5 7 3400 62.48 2542.7 2452.7 1831.1 7 3500 62.82 2588.7 2498.7 1919.9 7 3600 63.34 2634.0 2544.0 2009.0 7 3700 63.66 2678.6 2588.6 2098.5 7 3800 64.17 2722.5 2632.5 2188.3 7 3900 61.84 2767.9 2677.9 2277.4 7 4000 59.77 2816.7 2726.7 2364.7 7 4100 60.23 2866.7 2776.7 7 4200 60.65 2916.0 2826.0 7 4300 60.92 2964.8 2874.8 7 4400 61.25 3013.2 2923.2 7 4500 61.72 3060.9 2970.9 S 32.23 E 1447.7 S 622.3 E S 31.29 E 1523.2 S 669.1 E S 31.09 E 1599.1 S 715.0 E S 30.99 E 1675.0 S 760.7 E S 30.74 E 1751.3 S 806.3 E S 30.96 E S 30.79 E S 30.78 E S 31.08 E S 29.47 E 1827.8 S 852.0 E 1904.6 S 897.9 E 1981.8 S 943.9 E 2058.2 S 989.7 E 2133.6 S 1033.7 E S 29.35 E 2209.0 S 1076.2 E S 29.26 E 2284.9 S 1118.8 E S 29.26 E 2361.0 S 1161.4 E S 29.29 E 2437.4 S 1204.2 E S 28.53 E 2514.3 S 1246.7 E 2451.3 2538.3 2625.5 2713.1 2800.9 7 4600 61.66 3108.4 3018.4 2888.9 S 29.41 E 2591.3 S 1289.4 E Page 2 10/15/90 CLOSURE DL DISTNCE BEARING /100 727.9 S 16.81 E 3.04 806.7 S 17.52 E 5.54 889.9 S 18.49 E 5.72 975.9 S 19.44 E 1.50 1062.1 S 20.19 E 1.96 1147.0 S 20.76 E 2.06 1231.2 S 21.23 E 0.45 1316.2 S 21.66 E 2.09 1402.3 S 22.15 E 2.32 1488.8 S 22.72 E 1.43 1575.8 S 23.26 E 1.12 1663.7 S 23.71 E 0.83 1751.7 S 24.09 E 0.50 1839.7 S 24.42 E 0.21 1928.0 S 24.72 E 0.39 2016.6 S 24.99 E 0.55 2105.7 S 25.24 E 0.35 2195.1 S 25.47 E 0.51 2283.8 S 25.68 E 2.34 2370.8 S 25.85 E 2.39 2457.3 S 25.97 E 0.47 2544.1 S 26.09 E 0.43 2631.2 S 26.19 E 0.27 2718.7 S 26.29 E 0.33 2806.4 S 26.37 E 0.75 2894.4 S 26.45 E 0.68 ~Survey Codes: 7/GYRO KRU 3G-9 (24-12-8) S MEAS INCLN C DEPTH ANGLE 7 4700 61.41 7 4800 61.19 7 4900 60.71 7 5000 59.10 7 5100 57.78 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE RECORD OF SURVEY 3156.0 3066.0 2976.9 3204.0 3114.0 3064.6 3252.6 3162.6 3152.0 3302.7 3212,7 3238.5 3355.1 3265.1 3323.7 DIRECTION BEARING 29.69 E 28.62 E 30.17 E 29.98 E 30.03 E 7 5200 57.17 3408.9 3318.9 3408.0 S 30.41 E 7 5300 57.02 3463.2 3373.2 3492.0 S 31.29 E 7 5400 56.68 3517.9 3427.9 3575,7 S 31.72 E 7 5500 56.19 3573.1 3483.1 3658.9 S 32.40 E 7 5600 56.79 3628.4 3538.4 3742.2 S 32.47 E 7 5700 56.97 3683.0 3593.0 3825.9 S 31.64 E 7 5800 56.87 3737.6 3647.6 3909.7 S 32.41 E 7 5900 57.81 3791.5 3701.5 3993.8 S 31.70 E 7 6000 57.81 3844.8 3754.8 4078.4 S 32.04 E 7 6100 58.35 3897.7 3807.7 4163.2 S 31.48 E 4248.2 4333.4 4418.6 4503.8 4588.5 4673.6 4759.3 4844.6 4929.7 5014.9 7 6200 58.22 3950.3 3860.3 7 6300 58.50 4002.7 3912.7 7 6400 58.56 4054.9 3964.9 7 6500 58.21 4107.3 4017.3 7 6600 57.72 4160.4 4070.4 7 6700 59.00 4212.8 4122.8 7 6800 58.80 4264.5 4174.5 7 6900 58.39 4316.6 4226.6 7 7000 58.27 4369.1 4279.1 7 7100 58.62 4421.4 4331.4 S 31.61 E S 30.59 E S 30.65 E S 31.57 E S 31.56 E RELATIVE-COORDINATES FROM-WELL-HEAD 2667.8 S 1332.7 E 2744.4 S 1375.4 E 2820.6 S 1418.4 E 2895.4 S 1461.7 E 2969.2 S 1504.3 E 3042.1 S 1546.8 E 3114.2 S 1589.8 E 3185.6 S 1633.6 E 3256.2 S 1677.8 E 3326.5 S 1722.5 E Page 3 CLOSURE DISTNCE BEARING 2982.2 S 26.54 E 3069.8 S 26.62 E 3157.1 S 26.70 E 3243.5 S 26.79 E 3328.6 S 26.87 E lO/15/9o DL /lOO 0.33 0.85 1.27 1.62 1.32 3412.7 S 26.95 E 0.67 3496.5 S 27.04 E 0.64 3580.0 S 27.15 E 0.45 3663.0 S 27.26 E 0.68 3746.1 S 27.38 E 0.60 3397.5 S 1767.0 E 3829.5 S 27.48 E 3468.6 S 1811.4 E 3913.1 S 27.58 E 3539.9 S 1856.1 E 3997.0 S 27.67 E 3611.8 S 1900.8 E 4081.4 S 27.76 E 3684.0 S 1945.4 E 4166.1 S 27.84 E 3756.4 S 1989.9 E 3829.3 S 2033.9 E 3902.7 S 2077.4 E 3975.7 S 2121.4 E 4047.9 S 2165.7 E S 30.59 E 4120.8 S 2209.7 E S 30.74 E 4194.5 S 2253.3 E S 31.40 E 4267.6 S 2297.4 E S 31.67 E 4340.1 S 2341.9 E S 30.64 E 4413.0 S 2386.0 E 4486.8 S 2429.6 E 4251.0 S 27.91 E 4336.0 S 27.97 E 4421.2 S 28.03 E 4506.2 S 28.08 E 4590.8 S 28.15 E 4675.9 S 28.20 E 4761.4 S 28.25 E 4846.7 S 28.30 E 4931.6 S 28.35 E 5016.7 S 28.40 E 0.61 0.55 1.07 0.24 0.68 7 7200 59.24 4473.0 4383.0 5100.5 S 30.52 E ASurvey Codes: 7/GYRO 0.16 0.79 0.07 0.75 0.49 1.47 0.23 0.63 0.23 0.83 5102.3 S 28.44 E 0.63 KRU 3G-9 (24-12-8) S MEAS INCLN C DEPTH ANGLE 7 7300 58.96 7 7400 59.06 7 7500 59.17 7 7600 58.52 7 7700 58.34 7 7800 58.33 7 7900 58.12 7 8000 59.19 7 8100 59.28 7 8200 58.53 7 8300 58.15 7 8400 59.06 7 8500 59.45 7 8600 59.08 7 8700 59.28 7 8800 59.52 7 8900 60.45 7 9000 60.41 7 9100 60.58 7 9200 60.81 7 9300 61.03 7 9400 60.67 7 9500 60.91 7 9600 61.55 7 9700 62.08 7 9800 63.11 VERTICAL-DEPTHS BKB SUB-SEA 4524.4 4434.4 4575.9 4485.9 4627.2 4537.2 4679.0 4589.0 4731.3 4641.3 4783.8 4693.8 4836.5 4746.5 4888.5 4798.5 4939.6 4849.6 4991.3 4901.3 5043.8 4953.8 5095.9 5005.9 5147.0 5057.0 5198.1 5108.1 5249.3 5159.3 5300.2 5210.2 5350.2 5260.2 5399.6 5309.6 5448.8 5358.8 5497.8 5407.8 5546.4 5456.4 5595.1 5505.1 5643.9 5553.9 5692.0 5602.0 5739.3 5649.3 5785.3 5695.3 RECORD OF SURVEY SECTION DIRECTION RELATIVE-COORDINATES DISTNCE BEARING FROM-WELL-HEAD 5186.3 S 31.08 E 4560.5 S 2473.5 E 5272.0 S 31.29 E 4633.8 S 2517.9 E 5357.8 S 31.21 E 4707.2 S 2562.4 E 5443.4 S 31.48 E 4780.3 S 2606.9 E 5528.5 S 31.93 E 4852.7 S 2651.7 E Page 4 CLOSURE DISTNCE BEARING 5188.1 S 28.47 E 5273.7 S 28.52 E 5359.4 S 28.56 E 5444.9 S 28.61 E 5530.0 S 28.65 E 5613.6 S 32.10 E 4924.9 S 2696.8 E 5615.0 S 28.70 E 5698.5 S 32.78 E 4996.7 S 2742.4 E 5699.8 S 28.76 E 5783.9 S 31.84 E 5068.8 S 2788.1 E 5785.0 S 28.81 E 5869.7 S 32.14 E 5141.7 S 2833.6 E 5870.8 S 28.86 E 5955.3 S 32.70 E 5214.0 S 2879.5 E 5956.3 S 28.91 E 6040.3 S 33.00 E 5285.5 S 2925.7 E 6125.6 S 32.34 E 5357.4 S 2971.8 E 6211.4 S 31.50 E 5430.3 S 3017.2 E 6297.4 S 31.54 E 5503.6 S 3062.1 E 6383.2 S 31.76 E 5576.7 S 3107.2 E 6041.2 S 28.97 E 6126.4 S 29.02 E 6212.2 S 29.06 E 6298.1 S 29.09 E 6383.9 S 29.13 E lO/15/9o 6469.2 S 31.79 E 5649.9 S 3152.5 E 6469.9 S 29.16 E 6555.8 S 32.65 E 5723.1 S 3198.7 E 6556.3 S 29.20 E 6642.6 S 32.53 E 5796.4 S 3245.5 E 6643.2 S 29.25 E 6729.6 S 33.33 E 5869.4 S 3292.8 E 6730.0 S 29.29 E 6816.6 S 33.01 E 5942.4 S 3340.6 E 6817.0 S 29.34 E 6903.9 S 33.14 E 6015.7 S 3388.3 E 6904.2 S 29.39 E 6991.1 S 33.53 E 6088.6 S 3436.2 E 6991.4 S 29.44 E 7078.2 S 33.82 E 6161.3 S 3484.6 E 7078.4 S 29.49 E 7165.7 S 33.17 E 6234.4 S 3533.0 E 7165.9 S 29.54 E 7253.8 S 29.23 E 6309.7 S 3578.7 E 7254.0 S 29.56 E 7342.5 S 27.39 E 6387.9 S 3620.8 E 7342.7 S 29.55 E DL /lOO 0.50 0.18 0.12 0.68 0.37 0.12 0.53 1.28 0.24 0.85 0.44 1.03 0.73 0.37 0.26 0.24 1.14 0.10 0.63 0.34 0.24 0.47 0.33 0.81 3.12 1.79 ASurvey Codes: 7/GYRO KRU 3G-9 (24-12-8) S MEAS INCLN C DEPTH ANGLE 7 9900 65.12 7 10000 67.17 7 10100 69.08 7 10130 69.53 X 10322 69.53 VERTI Ci~L-DEPTHS BKB SUB-SEA SECTION DI STNCE RECORD OF SURVEY 5828.9 5738.9 7432.3 5869.4 5779.4 7523.5 5906.6 5816.6 7615.8 5917.2 5827.2 7643.7 5984.4 5894.4 7822.5 DIRECTION BEARING S 26.31 E S 24.80 E S 23.70 E S 23.47 E S 23.47 E RELATIVE-COORDINATES FROM-WELL-HEAD Page 5 CLOSURE DISTNCE BEARING lO/15/9o 6468.2 S 3661.4 E 7432.6 S 29.51 E 6550.7 S 3700.8 E 7523.8 S 29.46 E 6635.3 S 3739.0 E 7616.2 S 29.40 E 6661.0 S 3750.2 E 7644.1 S 29.38 E 6826.0 S 3821.8 E 7823.1 S 29.24 E DL /lOO 2.20 2.42 2.14 1.64 0.00 ~Survey Codes: 7/GYRO X/EXTRAPOLATED KRU 3G-9 (24-12-8) DATA Page INTERPOLATED FOR 100 FT SUBSEA INTERVAL 6 10/15/90 SUBSEA MEAS INCLN DEPTH DEPTH ANGLE 0 90 0.32 100 190 0.44 200 290 1.37 300 390 4.40 400 491 8.31 500 592 10.11 600 694 10.89 700 796 11.34 800 899 15.39 900 1004 20.06 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 1113 26.30 1224 25.96 1336 26.70 1448 28.23 1563 30.19 1681 34.41 1806 39.91 1946 47.42 2098 50.12 2269 58.59 2474 60.36 2666 57.87 2861 60.61 3069 62.08 3286 62.36 TVD MD-TVD VERT DIRECTION BKB DIFF CRRT BEARING 90 0 0 S 74.88 E 190 0 0 S 67.58 E 290 0 0 S 39.91 E 390 0 0 S 30.08 E 490 1 1 S 21.26 E 590 2 1 S 18.11 E 690 4 2 S 16.09 E 790 6 2 S 14.59 E 890 9 3 S 13.22 E 990 14 5 S 12.69 E 1090 23 9 S 13.70 E 1190 34 11 S 13.13 E 1290 46 11 S 13.72 E 1390 58 13 S 15.05 E 1490 73 15 S 15.12 E 1590 91 18 S 17.68 E 1690 116 25 S 17.83 E 1790 156 40 S 19.26 E 1890 208 52 S 22.00 E 1990 279 71 S 28.34 E 2090 384 105 S 28.31 E 2190 476 92 S 27.39 E 2290 571 95 S 29.96 E 2390 679 109 S 32.38 E 2490 796 117 S 31.12 E RELATIVE COORDINATES FROM WELL HEAD 0.13 N 0.17 E 0.04 S 0.81 E 0.91 S 2.02 E 4.94 S 4.73 E 14.91 S 9.53 E 30.37 S 15. O0 E 48 . 13 S 20.46 E 67.09 S 25.66 E 90.02 S 31.33 E 121.08 S 38.45 E 163.76 S 48.61 E 211.29 S 59.95 E 259.31 S 71.03 E 309.40 S 84.40 E 363.41 S 98.64 E 423.31 S 116.06 E 495.25 S 139.31 E 587.90 S 171.91 E 695.52 S 209.92 E 820.89 S 269.47 E 976.96 S 355.88 E 1122.36 S 432.68 E 1269.39 S 511.51 E 1424.92 S 607.90 E 1588.69 S 708.71 E 2500 3503 62.84 2590 913 117 S 30.75 E 1753.49 S 807.57 E KRU 3G-9 (24-12-8) Page 7 lO/15/9o DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA MEAS INCLN TVD MD-TVD VERT DIRECTION DEPTH DEPTH ANGLE BKB DIFF CRRT BEARING 2600 3726 63.79 2690 1036 123 S 30.79 E 2700 3946 60.89 2790 1156 120 S 30.34 E 2800 4147 60.43 2890 1257 101 S 29.31 E 2900 4352 61.09 2990 1362 105 S 29.28 E 3000 4561 61.68 3090 1471 109 S 29.07 E RELATIVE COORDINATES FROM WELL HEAD 1924.52 S 909.75 2092.97 S 1010.31 2244.69 S 1096.23 2400.63 S 1183.62 2561.62 S 1272.72 3100 4771 61.25 3190 1581 110 S 28.93 E 2722.00 S 1363.14 3200 4975 59.50 3290 1685 104 S 30.03 E 2876.86 S 1450.98 3300 5165 57.38 3390 1775 90 S 30.28 E 3016.77 S 1531.94 3400 5349 56.85 3490 1859 84 S 31.50 E 3149.34 S 1611.28 3500 5530 56.37 3590 1940 81 S 32.42 E 3277.49 S 1691.33 3600 5713 56.96 3690 2023 82 S 31.74 E 3406.69 S 1772.62 3700 5897 57.78 3790 2107 84 S 31.72 E 3537.83 S 1854.79 3800 6085 58.27 3890 2195 88 S 31.56 E 3673.34 S 1938.93 3900 6276 58.43 3990 2286 90 S 30.84 E 3811.54 S 2023.33 4000 6467 58.33 4090 2377 91 S 31.27 E 3951.73 S 2106.74 E E E E E 4100 6656 58.44 4190 2466 89 S 31.02 E 4088.51 S 2190.42 4200 6849 58.60 4290 2559 93 S 31.06 E 4230.45 S 2274.89 4300 7040 58.41 4390 2650 91 S 31.26 E 4369.00 S 2359.60 4400 7233 59.15 4490 2743 93 S 30.71 E 4511.24 S 2444.05 4500 7427 59.09 4590 2837 94 S 31.27 E 4653.94 S 2530.13 E E E E E 4600 7621 58.48 4690 2931 94 S 31.58 E 4795.63 S 2616.36 4700 7812 58.31 4790 3022 91 S 32.18 E 4933.42 S 2702.17 4800 8003 59.19 4890 3113 91 S 31.85 E 5071.01 S 2789.42 4900 8198 58.55 4990 3208 95 S 32.69 E 5212.25 S 2878.38 5000 8389 58.96 5090 3299 91 S 32.42 E 5349.13 S 2966.53 E E E E E 5100 8584 59.14 5190 3394 96 S 31.53 E 5492.06 S 3055.06 E KRU 3G-9 (24-12-8) Page DATA INTERPOLATED FOR 100 FT 8UBSEA INTERVAL 8 10/15/90 SUBSEA DEPTH 52OO 5300 5400 5500 5600 5700 5800 MEAS INCLN TVD MD-TVD VERT DIRECTION DEPTH ANGLE BKB DIFF CRRT BEARING 8780 59.47 5290 3490 96 S 31.78 E 8981 60.42 5390 3591 101 S 32.55 E 9184 60.77 5490 3694 103 S 33.06 E 9390 60.71 5590 3800 106 S 33.49 E 9596 61.52 5690 3906 106 S 33.20 E 9810 63.32 5790 4020 115 S 27.28 E 10054 68.21 5890 4164 144 S 24.20 E RELATIVE COORDINATES FROM WELL HEAD 5635.11 S 3143.38 E 5782.15 S 3236.44 E 5930.76 S 3332.96 E 6081.06 S 3431.23 E 6231.23 S 3530.96 E 6396.19 S 3625.05 E 6596.38 S 3721.68 E KRU 3G-9 (24-12-8) Page 9 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL lO/15/9o MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING 1000 19.81 987 897 123 S 12.64 E 120 S 2000 48.40 1826 1736 634 S 17.86 E 626 S 3000 61.35 2357 2267 1477 S 32.72 E 1373 S 4000 59.77 2817 2727 2365 S 29.47 E 2134 S 5000 59.10 3303 3213 3238 S 29.98 E 2895 S DL/ 100 38 E 126 S 17.67 E 4.4 185 E 652 S 16.44 E 2.3 575 E 1489 S 22.72 E 1.4 1034 E 2371 S 25.85 E 2.4 1462 E 3243 S 26.79 E 1.6 6000 57.81 3845 3755 4078 S 32.04 E 3612 7000 58.27 4369 4279 4930 S 31.67 E 4340 8000 59.19 4888 4798 5784 S 31.84 E 5069 9000 60.41 5400 5310 6643 S 32.53 E 5796 10000 67.17 5869 5779 7524 S 24.80 E 6551 1901E 4081 S 27.76 E 0.2 2342 E 4932 S 28.35 E 0.2 2788 E 5785 S 28.81 E 1.3 3246 E 6643 S 29.25 E 0.1 3701 E 7524 S 29.46 E 2.4 by GREAT LAND DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc. 10/15/90 Client .... : ARCO ALASKA, INC. Field ..... : Kuparuk River Unit Well ' KRU 3G-9 (24-12-8) Section at: S,29.97,E Surveyor..: MIKE NAIRN Computation...: RADIUS OF CURVATURE Survey Date...: 10/04/90 RKB Elevation.: 90.00 ft Job Number .... : AK1090G248 AP1 Number .... : 50-103-20129 INTERPOLATED MARKERS REPORT Surface Location: 2538 SNL 170 EWL S24 T12N R8E MARKER IDENTIFICATION KB 9-5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A PBTD BASE KUPARUK A 7" CASING TD MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD 0 0.00 0 -90 0 N 0.00 E 0 N 0 E 4538 61.70 3079 2989 2834 S 28.86 E 2544 S 1263 E 9758 62.68 5766 5676 7305 S 28.16 E 6355 S 3603 E 9810 63.31 5790 5700 7351 S 27.28 E 6396 S 3625 E 9911 65.35 5834 5744 7442 S 26.14 E 6477 S 3666 E 10213 69.53 5946 5856 7721 S 23.47 E 6732 S 3781 E 10279 69.53 5969 5879 7782 S 23.47 E 6789 S 3806 E 10300 69.53 5977 5887 7802 S 23.47 E 6807 S 3814 E 10322 69.53 5984 5894 7822 S 23.47 E 6826 S 3822 E <KB>O 750 ! t500 ~:~50 3oooi 3750 I 4500 5250 and Direct/ansi Drilling, Zn£. VERTICAL SECTION VIEW ARCO ALASKA, INC. KRU 3G-9 (24-~2-8) Section at: S 29.97 E TVD Scale.: ! inch = i500 feet Dep Scale.: 1 inch = 1500 feet Drawn .....: ~0/~5/90 tarker Identification MD TVD SECTN INCLN A) KB 0 0 0 0.00 B) TO J0322 5984 7822 69.53 6000 6750 7500 8250 9000 9750 750 0 750 i500 2250 3000 3750 4500 5250 6000 6750 7500 Sect:ion Departure Sreab Land Oirecbianal Orilllng. £n£. Marker Identification MD N/S A) K8 0 0 N 0 E B} TO 10322 6826 S 3822 E PLAN VIEW ARCO ALASKA. INC. KRU 3G-g CLOSURE .....: 7823 ft S DECLINATION.: 0.00 E SCALE ....... : t inch = 1t00 feet DRAWN ....... : 10/15/90 55O 0 55O ilO0 t650 ~750 3300 3850 4400 4950 5500 6050 6600 7i50 550 0 550 <- NEST ' EAST -> ilO0 i650 2200 2750 3300 3850 4400 4950 5500 6050 ......................... iNYENTORY LiST ~.UI._~LA..~ L~r'MLUL'~II.~L M,i~ I l-[qlRLb COMPLETION DATE / c,. ! /..c-/. /~o CO. CONTACT checlc off ~r' ii~t data as it is received.*list received date for 4'0:7. if -1.07 [* 3_/'/P/9~. I drilling histo~"! ~' su~ey[/ ! wellt~sts 'cored inte~a[s J core. analysis j~ d~ dit~ inte~ais . , I I i i , ,..,,-. -~nc i n,';,, i ' ,,,',-,-cn':,',,.o SCALE LUU ! I rE r'lkUll 111¢ i NO. [to the nearest footI [inchll §0'] ,, 1 ],~u'2:~/,~ ~ - _ .............. ! : ~~/~,~'/.e~o / 5" ~/~/~-- · ii I I I III ~Zl [ .... , ,, I ,1 .... ~l I ~ I I ,. ,'. , 1 ....... ARCO Alaska, inc. Date: February 8, 1991 Transmittal #: 8008 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-111 9 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 G- 13 Pulse Echo Cement Evaluation Log 1 1 - 1 3 - 9 0 6 0 0 0 - 91 8 7 3 G- 0 2 Acoustic Cement Bond Log 1 1 - 1 2 - 9 0 4 5 0 0- 6 5 4 7 3 G- 1 3 Acoustic Cement Bond Log 1 1 - 1 3 - 9 0 5 7 0 0- 9 2 0 0 3 G- 0 9 Acoustic Cement Bond Log 1 0 - 4 - 9 0 5 4 41 - 1 0,1 9 5 Receipt Drilling Acknowledge: ......................... Date: State of Alaska NSK ARCO Alaska, Inc. Date: February 4, 1991 Transmittal #: 8000 RETURNTO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATe-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 G-0 .9~.~ Pulse Echo Cement Evaluation Log 1 0- 3- 9 0 5 2 2 9- 9 6 8 2 3 G24X,~ Pulse Echo Cement Evaluation Log 1 1 - 1 5 - 9 0 6 6 9 8- 9 7 0 4 3 G- 04K' ~ Pulse Echo Cement Evaluation Log I 1 - 1 6 - 9 0 4 9 0 0- 79 3 9 3 G- 1 ~ ~ Pulse Echo Cement Evaluation Log 1 1 - 1 4 - 9 0 4 5 0 0 - 7 81 5 3 G - 22,X?j Pulse Echo Cement Evaluation Log 1 1 - 1 8 - 9 0 6 6 0 0 - 9 5 9 5 217~. - 8466-11 '513 3 G- Pulse Echo Cement Evaluation Log I 1 -2 3 9 0 3 G- 04~.7,~ Acoustic Cement Bond Log 1 1 - 1 6 - 9 0 4 8 9 2- 7 9 62 3 G - 22 ~,~ Acoustic Cement Bond Log 1 1 - 1 8 - 9 0 6 6 0 0 - 9 61 6 1L-22'~ Squeeze Record 1-20-91 9200-9800 Receipt Acknowledge' ~~ ...... Date' D r illi n g State of Alaska Alaska Oil & Gas Cor~s. Oomrnission Anchorage STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown X Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alask¢,, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 2538' FNL, 170' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 1500' FSL, 1350' FEL, Sec. 25, T12N, R8E, UM At effective depth NA At total depth 1122' FSL, 1189' FEL, Sec. 25, T12N, R8E, UM (approx) (approx) 12. Present well condition summary Total Depth: measured 10322' feet (approx) true vertical 5905' feet Effective depth: measured NA feet (approx) true vertical NA feet Plugs (measured) None Junk (measured) None 6. Datum elevation (DF or KB) RKB 90' feet 7. Unit or Property name Kuparuk River Unit 8. Well Number 3G-9 9. Permit number 90-67 10. APl number 50-1 03-201 29 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Length Size Structural Conductor 8 0' 1 6" Surface 4501' 9 5/8" Intermediate Production 1 0265' 7" Liner Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None Cemented Measured depth True vertical depth (approx) 115' 115' 1000 Sx AS III & 4538' 3064' 735 Sx Class G 727 Sx Class G 10300' 5898' & 235 Sx Class G tail i::: iiL ~... ¢:-.-. i '~ ~ ~-*¢;~ 13. Attachments Description summary of proposal _ Detailed operation program BOP sketch 14. Estimated date for commencing operation November, 1990 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. Si~]ned ~----/~-/,¢~, ~"//~ Title Area Drilling Engineer / FOR COMMISSION USE ONLY Date Conditions of approval' Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require Approved by the order of the Commission 10- Commissioner IApproval No. Form 10-403 Rev 06/15/88 LONNIE C. SMITH Approved Copy Retureect SUBMIT IN TRIPLICATE ARCO Oil anu Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Repeal" on the fimt 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 ICounty. parish or borough ARCO ALASKA INC. I NORTH SLOPw- Field , ILease or Unit KUPARUK RIVE[:[ I ~mflle ADL: 25548 ALK: 2662 Auth. or W.O. no. ' AK4966 I DRILLING IState AK ;I no. 3G-09 Operator ARCO Spudded or W.O. begun IDate IHour SPUD 05/27/90 04: 00 Date and depth Complete record for each day reported as of 8:00 a.m. DO¥ON 14 05/27/90 (1) TD: 322'( 322 SUPV:TAB 05/28/90 (2) TD: 3606' (3284) SUPV:TAB 05/29/90 (3) TD: 4558' ( 952) SUPV:TAB 05/30/90 (4) TD: 4456'( 0) SUPV:TAB 05/31/90 (5) TD: 4897'( 441) SUPV:TAB 06/01/90 (6) TD: 5563' ( 666) SUPV: RWS 06/02/90 (7) TD: 8349'(2786) 06/03/90 ( 8) TD: 9571' (1222) ARCO W.I. 55,8533 IPr or status if a W.O, DRLG MW: 0.0 VIS: 0 MOVE RIG, NU DIVERTER, CUT DRLG LINE,PU BHA, TEST DIVERTER, DRLG CEMENT IN COND. DRLG F/35 TO 125,ORIENT MWD,DRLG F/125 T/ 322. DAILY:S50,876 CUM:$50,876 DRLG DRLG F/322 T/3606 ETD:S50,876 EFC:$1,889,500 MW: 9.5 VIS: 61 DAILY:S57,892 CUM:$108,768 ETD:S108,768 EFC:$1,889,500 POH 9-5/8"@ 4456' MW: 9.8 VIS: 55 DRLG F/3606 T/4558,CBU, DROP SS,POH, TIGHT SPOT AT 2600-1700,CO BHA, RIH W/REAMER CIRC AND COND,DROP SS,POH,TIGHT SPOT 1800,WORK THROUGH SPOT,POH TO RUN CASING. DAILY:S54,499 CUM:$163,267 ETD:S163,267 EFC:$1,889,500 DRLG CMT 9-5/8"@ 4456' MW: 0.0 VIS: 0 LD BHA, SS2 DISCREPANCY WITH MWD,RUN 116 JTS OF 9.625 CASING,CIRC,CEMENT, ND DIVERTER, NU BOPE AND TEST, INSTALL WEAR RING, PU BHA, RIH,DRILLING FC AND CMT. DAILY:S240,532 CUM:$403,799 ETD:S403,799 EFC:$1,889,500 RIH W/ BIT # 3 9-5/8"@ 4456' MW: 9.7 VIS: 42 TAGGED FLOAT COLLAR, DRLG CMT, CBU, RUN MUTI GYRO~DPJ~ 10' NEW FORMATION, TEST TO 13.TEMW, DRLD TO 4897',CBU, DROP SS,POH, RUN BOSS GYRO, PU BIT %3 AND RIH. DAILY:S93,941 CUM:$497,740 ETD:S497,740 EFC:$1,889,500 DRLG 9-5/8"@ 4456' MW: 9.7 VIS: 42 FINISH RUNNING THE HOLE,WASH AND REAM F/4854T/4897,DRLG F/4897T/4942,CBU, POH, CHANGE OUT BHA, RIH W/ BIT%4,DRLG F/4942T/5142,CBU, POH,CO BHA,RIH W/ BIT%5,CUT AND SLIP DRLG LINE,DRLG F/5142T/5563. DAILY:S83,267 CUM:$581,007 ETD:S581,007 EFC:$1,889,500 9-5/8"@ 4456' MW: 9.6 VIS: 39 DRLG 8.5" HOLE DRLG F/5563 T/8349. DAILY:S59,165 CUM:$640,172 ETD:S640,172 EFC:$1,889,500 POH 9-5/8"@ 4456' MW: 9.9 VIS: 36 DPJ.43 11.8,OK, RIH,WASH TO 8538, CIRC OUT THICK MUD,DRLD F/8560-9572,CBU, POH TO CSG SHOE,CIRC. EMW TEST T/11.26 CONT POH. DAILY:S58,448 CUM:$698,620 ETD:S698,620 EFC:$1,889,500 The above is cor~ct For form preparation/a~ ~stribution,~....~ see Procedures Marf~.~4'. Section 10, Drilling. Pages 86 and 87. AR3B-459-1-D INumber all daily well history forms consecutively as they are prepared for eech well. iPage no. ARCO Oil an~ _as Company,~,,"~' Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting ot oil string until completion. District ,IC°unty or Parish IState ARCO ALASKA INC. I NORTH SLOPE Field J Lease or Unit J KRU 3G-09 Complete record for each day while drilling or workover in progress DO¥ON 1 4 KUPARUK RIVER Date and depth as of 8:00 a.m. 06/04/90 ( 9) TD: 9571'( 0 SUPV:RWS O6/O5/90 (10) AK PREP TO DRILL THE KUP 9-5/8"@ 4456' MW:10.6 VIS: 43 FINISH POH,RIH,HIT TIGHT SPOT AT 9390,REAM AND WASH, START LCM PILL, POH TO SHOE CUT AND SLIP DRLG LINE,TEST FORMATION TO ll.7#,RIH TO DRILL KUP. DAILY:S71,005 CUM:$769,625 ETD:S769,625 EFC:$1,889,500 DRLG 9-5/8"@ 4456' MW:ll.3 VIS: 47 TD:10255' ( 684 SUPV:RWS 06/06/90 (11) TD:10322' ( 67 SUPV:RWS 06/07/90 (12) TD:10322' ( 0 SUPV:T~iB WASH /REAM, CIRC AND WEIGHT UP,DRLG FROM 9571/10217,STARTED LOSING CIRC, LOST 300 BBLS,REGAINED CIRC,RESUMED DRLG F/10217T/10255. DAILY:S80,991 CUM:$850,616 ETD:S850,616 EFC:$1,889,500 POH F/ 7" CSG 9-5/8"@ 4456' MW:ll.2 VIS: 42 DRLD F/10255T/10273,MONITOR WELL FOR LOSS,POH TO CSG SHOE, SWABBED WELL, RIH, LOST RETURNS,CIRC AND COND, RIH,CIRC AND REAM, STOP PUMPING/MOVE PIPE/MIX NEW VOLUME,REAM F/10083T/10273,DRLD F/10273T/10322,CIRC AND COND,POH. DAILY:S70,420 CUM:$921,036 ETD:S921,036 EFC:$1,889,500 MIXING CEMENT 9-5/8"@ 4456' MW:ll.2 VIS: 40 PULL AND LDDP, STAND BACK 3 DC,RECOVER RLL, LDDC,PULL WEAR RING, RUN 7"CSG, CIRC AT 4500' AND 6500',LOST CIRC AT 9000',FINISH RUNNING CASING TO TD, ATTEMPT TO CIRC,MIXING MUD FOR CEMENT DISP. DAILY:S180,452 CUM:$1,101,488 ETD:S1,101,488 EFC:$1,889,500 Well no. The above is correct For form preparatioq,~d ~istribution ~ see Procedures Manba~ Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B Number all daily well hisloty forms consecutively as they are prepared for each well. IPage no. ARCO Oi, .,nd G~s Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also whe~ ope~*ations are suspended for an indefinite or appreciable length of time. On worKovers when an official test is not required upon completion, report completioI! and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District [State ARCO ALASKA INC. / AK Field County or Parish NORTH SLOPE ILease or Unit IADL: 25548 ALK: 2662 Title I DRILLING Well no. K~U 3G-09 KUPARUK RIVER Auth. or W.O. no. AK4966 Operator A.R.Co. W.I. ARCO 55.8533 Spudded or W.O. begun Date SPUD 05/27/90 Complete record for each day reposed DOYON 14 Date and depth as of 8:00 a.m. 06/08/90 (13) TD:10322 PB:10218 SUPV:TA~B I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our I Prior status if a W.O, I 04:00 RIG RELEASED 7"@10315' MW:ll.2 NaCl MIX AND PUMP CEMENT,ND FLOWLINE, ANNULUS FLOWING,WAITING ON FLOW TO STOP, ND BOPE,SET SLIPS,CUT CSG, INSTALL TEH_PORY TBG HEAD,ARCTIC PACK WELL. RELEASE RIG 1630 HRS, 6-7-90. DAILY:S115,873 CUM:$1,217,361 ETD:S1,217,361 EFC:$1,899,500 Old TD New TD Released rig Date IPB Depth Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P: C.P. Water % GOR Gravity Allowable Effective date corrected T, he above ivorrect sFe°~ 'l~/o~e~r:,Pe~r~nuaaln,'-%edic~Ir~nbU~i0°,n''~ / > - -- - t - Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. iPage no. Olvl.~on of AtlanllcRIchfleldCompa~¥ ARCO Alaska, Inc. Date: July 13, 1990 Transmittal Ct: 7814 RETURN TO: ARCO Alaska, Inc. ATTN: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1Y-30 3G-09 Pulse Echo Cement Evaluation(PET) 6-1 1 -9 0 Pulse Echo Cement Evaluation(PET) 6 - 1 2- 9 0 8276-9444 ~ 4200-7889 Receipt Acknowledged: DISTRIBUTION: fi CEIVED Date,~ ... UL l~d IYYO Alaska 0ii & Gas Co,s. Uummissioil Anchorage Drilling NSK Stat~,e',of Alaska(+Sep!~)~ ARCO Alaska, Inc. Date: JUne 15, 1990 Transmittal #: 7782 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. 3G-08 3G-08 3G-09 3G-09 Please acknowledge receipt and return Dual GR Compensated Neutron Porosity Simultaneaous Formation Density Electromagnetic Wave Resistivity Dual Gamma Ray Dual GR Compensated Neutron Porosity Simultaneaous Formation Density Electromagnetic Wave Resistivity 5-25-90 5-25-90 6-6-90 0 Dual Gamma Ray Formation Exposure time 3677-8759 3677-8759 4548-10322 4548-1O322 Receipt Acknowledged' DISTRIBUTION: D&M Drilling Franzen RECEIVED Date: .......... JUN 1 5 1990 Alaska Oil & Gas Cons. Commission Anchorage Vendor Package(Johnston) NSK State of Alaska(+Sepia) Todd Salat ARCO Alaska, Inc. Date: June 15, 1990 Transmittal #: 7781 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 G - 0 8 LIS Tape and Listing 5 - 3 1 - 9 0 # 9 0 - 0 5 - 1 8 3G-09 LIS Tape and Listing .7¢/ ~'/'~'/ 7- 6-11-90 AKRB90520 Receipt Acknowledged: RECEIVED JUN 1 5 1990 D a t,~Jaska 0J~-~'~'~rls. Commission Anchorage DISTRIBUTION: Lynn Goettinger May 24, 1990 Telecopy: (907)276-7542 P. J. Archey Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alas~ 99510-0360 Kuparuk River Unit 3G-09 A~RCO Alaska, Inc. Permit No. 90-67 Sur. Loc. 2538'F[~TL, 170'F~, Sec. 24, T12N, RSE, U~A. Btmho!e Loc. 1222'FSL, lI89'FEL, Sec. 25, T12N, RSE, U~{. Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced well. _The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. C. v. Chatrert~ Chai~an o f Alaska Oil and Gas Consolation Comission BY O~PDER OF ~E CO.fISSION dis Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. _ Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS,.,,ON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill __ lb. Type of Well Exploratory~ Stratigraphic Test -- Development Oil _X Re-Entry _ Deepen _ Service _ Development Gas __ Single Zone ~ Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 90', Pad 54' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25548 ALK 2662 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2538' FNL, 170' FWL, Sec. 24, T12N, R8E, UM Kuparuk River Unit At top of productive interval (TARGET) 8. Well number Number 1500' FSL, 1350' FEL, Sec. 25 , T12N, RSE, UM 3G-09 #U630610 At total depth 9. Approximate spud date Amount 1222' FSL, 1189' FEL, Sec 25, T12N, R8E, UM 05-28-90 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3G-08 10,287MD 1189' @ TD feel 22' at 540 feet 2560 5985VD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 300 feet Maximum hole angle 59° Maximum surface 1 825psig At total depth (TVD) 5700' 3500 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length k/D TVD IVD TVD (include sta~le data) 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' _+200 Cu. Ft. 12.25 9.625 36.0# J-55 BTC 4531 35' 35' 4531 3290' 1690 Cu. Ft. AS III & HF-ERW 740 Cu. Ft. Class G 8.5 7" 26.0# J-55 BTC 10287 35' 35' 10287 5985' 250Cu. Ft. ClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vedical depth Structural Intermediate Production Liner MAY :]9f!, Perforation depth: measured /~!~sk~ Oil & Gas Cons. C0mrnisSio~- true vertical . Anch0ra 20. Attachments Filing fee ~ Property plat ~ BOP Sketch X Diverter Sketch ~ Drilling program ~ Drilling fluid program X.Z._ Time vs depth plot __ Refraction analysis _ Seabed report _20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ U~'{"'%~ Title Area Drilling Engineer Date Commission Use Only Permit Number I APInumber I Appr°val date 05/2/-1'/901 See cover letter for ~ --~ ~ ~ 50- ,/~3-- 2-d~,/'<?r ~ other requirements Condi{ions of approval Samples required __Y e s .~'N o Mud Icg required__ Ye s :~ N o Hydrogen sulfide measures__ Yes ~ N o Directional survey required ,~Yes __ N o Required working pressure for BOPE ~ ~(' 3 M; ,_,j5 M' __ I 0 M' __ I 5 M Approved by ~ ~ Commissioner the commission Date Form 10-401 Rev. ~ / ./' in triplicate ARCO ALASKA, INC. PAD 3G, WELL No. 9 Kuperuk Field, Norfh Slope, Alosko EASTMAN CHRISTENSEN A Baker Hughes Co. RKB ELEVATION 90' SCALE= I" ' = I000 KOP 6 12 42 48 TVD=300 TMD=300 DEP=O BUILD 5°/100' B/PERMAFROST TVD=1605 TMD=I737 DEP=515 T/UGNU SANDS TVD=I790 TMD=2009 DEP=715 5457 EOC TVD= 1949~ TMD=2290 DEP=946 T/W SAK SANDS TVD=2410 TMD=3205 DEP=IT:55 B/W SAK SANDS TVD=2880 TMD=4135 DEP=2539 95/8"CSG PT TVD=5080 TMD=4531 DEP=2881 K-lO TVD=5290 TMD=4947 DEP= 5240 ,00 AVERAGE ANGLE -,-59 DEG 41 MIN K-5 TVD=4470 TMD= 7285 DEP=5258 T/ZONE C TVD=5710 TMD=9742 DEP=7379 T/ZONE A TVD=5761 TMD=9845 DEP=7467 TARGET CNTR TVD=5797 TMD=9914 DEP=7528 - B/KUP TVD=5884 TMD=IO, 087 DEP=7677 TD TVD=5985 TMD=IO,287 DEP= 7850 I I I I I t I I000 2000 3000 4000 5000 6000 7000 VERTICAL SECTION ARCO ALASKA, INC. PAD 3G, WELL No. 9 Kuparuk Field, Norfh Slope, Alaska EASTMAN CHRISTENSEN A Baker Hughes Co. HORIZONTAL PROJECTION SCALE: I"= I000' ~ I000 - 2000 - 3000 - 4000 - 5000 - 6000 - 7000 - SURFACE SURFACE LOCATION 2558' FNL, 170' FWL SEC 24, T12N, RBE S 29 DEG 58 MINE 7528' (TO TARGET) TARGET LOCATION 1500' FSL, 1550' FEL SEC 25, T12N, R8E TD LOCATION 1222' FSL, 1189' FEL SEC 25,TI2N,R 8E TARGET CNTR TVD= 5797 TMD= 9914 DEP = 7528 SOUTH 6522 EAST 3760 0 I000 2000 :3000 4000 WEST - EAST 2400 _ 2450 _ 2500 _ 2550 _ 2600 _ 2650 _ 2700 _ 1 O0 150 200 250 3;00 . .. , i,, I , I I i _ , d °.300 "\50C I 100 I 1,50 / ,,.'/~ 300 /1100 * 300 300 / / / "1 500 / 500 900 \ \ \ \ \ \ ?00 350 I "1700 400 I 450 I 5OO I _ 2400 _ 2450 .2500 _ 2550 _ 2600 _ 2650 200 250 300 :350 400 450 500 DRILLING FLUID PROGRAM (3G-09) Spud to 9-5/8" Drill out to surface casinc~ weiaht UD Density 8.6-10.0 8.6-9.3 PV 15-35 5-15 YP 15-35 5-8 Viscosity 50-100' 30-40 Initial Gel 5-15 2-4 10 Minute Gel 15-40 4-8 APl Filtrate 10-1 2 8-1 0 pH 9- 1 0 8.5-9 % Solids 10 +/- 4- 7 Weight up to TD 11.2 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 10-12 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1825 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 3G-09 is 3G-08. As designed, the minimum distance between the two wells would be 22' at 540'md. The wells would diverge from that point. Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3G PAD · . · , · . 7, . . 10. 11 12 13 14 15 16 17 18 19 20. Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. Fracture stimulate well. 21. Reperforate and add additional perfs. nUPARUK RIVER UN,, 20" DIVERTER SCHEMATIC I 6 5 I 4 I 5 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER SRE 2/6/ 7 'h I , 6 5 4 3 i2 13 5/8" 5000 l-,jI BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECKAND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACKAND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE BO'i-I'OM PIPE RAMS. TEST Bo'FrOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEKAND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 CHECK LIST FOR NEW WELL PERMITS ITEM A~ PROVE DATE (2) Loc. (~t~-hru 8) (8) (3) Admin~____ ~ 9. ~' (9~ th~ru 13) 10. (10 and 13) 12. 13. (4) Casg' ~.___~, ~"~3-9~ (14 thru 22) (23 thru 28) Company Is the permit fee attached .......................................... 2. Is well t~ 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 wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Lease & Well No. ~ZP~ YES NO ,, , 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover ail known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an exis:ing wellbore ............... Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a dive:re: system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~C)<I;O psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) OTHER .,~C. .~~ (29~ thru 31) (6) Add: Geoto gy: DWJ..,~~ Engine~ering: LCS BEW ~ rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential ore:pressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,, , Additional Remarks: Well Histo_ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX, No special'effort has been made to chronologically organize this category of information. ,o (NOTE: **** LIS READ **** MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 90/06/11 ORIGIN OF DATA: 3G-9 REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: RLL DATE: 90/06/07 ORIGIN OF DATA: 3G-9 TAPE NAME: KUPARUK CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: 3G9.MWD SERVICE NAME: RLL VERSION #: V 2.4 DATE: 90/06/11 MAX. RECORD LENGTH: 1024 FILE TYPE: MM PREVIOUS FILE NAME: ** COMMENTS ** COMPANY: ARCO ALASKA INC.// WELL: 3G-09// API:50-103-20129//DATE:06/07/90 LOCATION: 2538'FNL, 170' FEL, SEC. 24, TWP. 12N, RANGE 8E, NORTH SLOPE BOROUGH ALASKA, U.S.A.// RIG: DOYON 14// COMPANY REP.: BILLINGSLEY & SPRINGER // RLL ENGINEERS: WESLEY & MOORE // COMMENTS *** > NEUTRON AND DENSITY CALIPER CORRECTED, AND PROCESSED ASSUMING SS MATRIX @ 2.65 G/C3, FWS @ 14,545 ppm CL, MUD SALINITY @ 1400 ppm CL, FLUID DENSITY @ 1.0 G/C3, MUD DENSITY VARIABLE 9.4 -11.3 ppg, DATA FROM 4,400' TO 10,400'. ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# DEPT NFO MWD NF 1 MWD NN0 MWD NN1 MWD EWR MWD ROP MWD FXE MWD NPSC MWD GRC MWD RHOB MWD CAL MWD LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 OHMM 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 API 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 INCH 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS ~ · ~ID DEPT NFO MWD NFl MWD NN0 MWD NN1 MWD EWR MWD ROP MWD FXE MWD NPSC MWD GRC MWD RHOB MWD CAL MWD ORDER# FT 0 0 0 0 CTS 0 0 0 0 1 CTS 0 0 0 0 1 CTS 0 0 0 0 1 CTS 0 0 0 0 1 OHMM 0 0 0 0 1 FT/H 0 0 0 0 1 HOUR 0 0 0 0 1 P.U. 0 0 0 0 1 API 0 0 0 0 1 G/C3 0 0 0 0 1 INCH 0 0 0 0 1 4 4 4 4 4 4 4 4 4 4 4 4 0 0 0 0 0 0 0 0 0 0 0 0 1 1 1 1 1 1 1 1 1 1 1 1 68 68 68 68 68 68 68 68 68 68 68 68 ** DATA VERIFICATION (every 500 FT) ** DEPT NF0 NFl NN0 NN1 EWR FXE NPSC GRC RHOB CAL ROP 4400.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4500.000 427.829 418.319 2310.725 2284.908 83.042 -999.250 58.712 62.016 2.733 8.360 -999.250 5000.000 .509 656.234 669.766 2506.468 39.950 93.142 2.217 2507.744 6.312 8.720 71.278 5500.000 599.000 631.000 2488.000 .536 41.936 106.647 2.515 2552.000 3.861 8.570 305.859 6000.000 583.814 637.419 2547.209 .747 40.873 100.404 2.451 2577.675 3.072 8.610 276.228 6500.000 631.000 687.000 2632.000 .561 37.739 75.195 2.320 2632.000 3.745 8.610 233.789 7000.000 631.000 631.000 2424.000 .843 42.508 105.041 2.542 2504.000 2.035 8.610 205.371 7500.000 743.000 743.000 2728.000 .700 33.873 120.829 2.446 2616.-000 2.274 8.760 226.758 8000.000 615.000 623.000 2584.000 .647 40.854 113.749 2.349 2504.000 4.871 8.640 140.895 8500.000 687.000 687.000 2504.000 6.059 38.963 82.875 2.137 2440.000 4.729 8.940 180.971 9000.000 681.281 662.425 2602.281 .754 35.311 118.510 2.585 2583.982 5.115 9.130 165.554 9500.000 552.580 531.790 2212.742 1.111 48.157 119.637 2.281 2145.483 3.244 10.280 145.969 10000.000 687.874 732.379 2904.000 1.065 30.799 71.611 2.343 2936.000 22.522 8.670 117.603 ** 572 DATA RECORDS ** FROM 4400.00 TO 10400.00 FT ** FILE TRAILER** FILE NAME: 3G9.MWD SERVICE NAME: RLL VERSION #: V 2.4 DATE: 90/06/11 MAX. RECORD LENGTH: FILE TYPE: MM NEXT FILE NAME: 1024 ********** END OF FILE (EOF # 2) ********** ** TAPE TRAILER** SERVICE NAME: RLL DATE: 90/06/07 ORIGIN OF DATA: 3G-9 TAPE NAME: KUPARUK CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: DATE: 90/06/11 ORIGIN OF DATA: REEL NAME: ARCO CONTINUATION #: NEXT REEL NAME: COMMENTS: SSDS 3G-9 01 PETROLEUM COMPUTING INC.- LIS FORMAT