The URL can be used to link to this page

Home My WebLink About208-1221. 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: OA Cement 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? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 14297'None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: 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 263-3782 Senior Well Interventions Engineer CRU CD2-469 4053' 6461' 3813' 6461' N/A 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: Mark.Shulman@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6383' MD and 3777' TVD 3586' MD and 2456' TVD Mark Shulman STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380075 208-122 P.O. Box 100360, Anchorage, AK 99510 50-103-2058-00-00 Colville River Field Qannik Oil Pool ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Qannik Oil Pool TVD Burst 7246' MD 114' 2390' 4085' 114' 3454' 16" 10-3/4" 77' 7-5/8"7362' 3418' 7396' 7393-14201' Alternating Solid/ Slotted Pipe 3-1/2" 4085-4059' Alternating Solid/ Slotted Pipe Perforation Depth TVD (ft): 4/1/2025 14205'6980' 4-1/2" x 3-1/2" 4059' Packer: Baker Premier Packer SSSV: Camco TRMAXX-5E SSSV Perforation Depth MD (ft): L-80 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:44 am, Mar 13, 2025 325-140 Mark Shulman Digitally signed by Mark Shulman Date: 2025.03.12 13:58:08 -08'00' SFD 3/18/2025 50-103-20580-00-00 SFD VTL 4/3/2025 DSR-3/24/25 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.08 14:35:19 -08'00'04/08/25 RBDMS JSB 040925 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 11, 2025 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Sincerely, Mark Shulman WNS Well Integrity Engineer ConocoPhillips Alaska Inc. Mark.Shulman@conocophillips.com We are requesting to withdraw the approved sundry 325-005 for CRU CD2-469 (PTD 208-122). Please find the enclosed the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. for OA cementing. The goal of the cementing is to mitigate the pressure source and potentially repair the surface casing leak. Please contact me at (907) 263-3782 if you have any questions. Mark Shulman Digitally signed by Mark Shulman Date: 2025.03.12 13:48:03 -08'00' CD4-05 Cement Shoe Page 1 Date: Mar. 11, 2025 Subject: CD2-469 OA Cement Shoe Procedure: Prepared By: Mark Shulman, 263-3782 Objective Down squeeze 10-3/4”x 7-5/8” OA to cement surface casing shoe to surface. Cement Volume Calculations: x Volume in 10-3/4”x 7-5/8” annulus: (3,455 ft) x (0.0397 bbl/ft) = 138 bbl x Excess: 276 bbl x Total volume: 138 + 276 = 414 bbl CRU CD2-469 (PTD#208-122) is a producer that was originally drilled and completed in 2008. The well is currently shut-in for a surface casing leak. CD2-469 needs a surface casing repair. CD2-469’s OA maintains a pressure of +400 psi and surfaced liquids when we completed the injectivity test. The goal of the OA cementing is to control the OA pressure by pumping an OA cement shoe to surface. Procedure 1. Verify 10-403 Sundry form has been approved for OA cement job. 2. Contact Cement Pumping Services to schedule the OA cement job and allow time for pilot testing. 3. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 4. Install 1502 union and valves on the OA. Rig up hardline to the OA with an option to divert to open top tank for wash up. 5. Ensure Valve crew services OA valves and any additional hardline valves installed for cementing job. 6. Install containment into cellar to contain any returns from surface casing leak. Ensure vac truck on location with cement containment to take returns from surface casing leak from pumping operations. 7. MIRU cement pumping equipment and rig up 2” hardline to the circulation skid. Stage equipment to minimize pumping stop time between stages. 8. Be sure to monitor around wellhead, wellhouse, and conductor top during OA pumping. There is a known surface casing leaks near the surface. During the OA injectivity testing returns were observed at the conductor. 9. PT lines and surface equipment to 3,000 psi. 10. Pump the OA shoe. a. Complete an Injectivity test up to 1500 psi. and ensure OA will take injection. CD2-469 Cement Shoe Page 2 b. At the beginning of the job, increase the pump pressure as necessary to break over on injection. Do not exceed 1,000 psi. c. Once the OA breaks over pump at maximum possible rate without exceeding maximum pressure of 1,000 psi. When cement gets to the shoe (138 bbls pump total after starting on cement), slow pumps to a maximum of 1 BPM or 500 psi. With 10 bbls of cement past the shoe (148 bbls after starting cement), shut- down pumps and watch pressure. Perform a 15-minute hesitation, then attempt to slowly squeeze another 10 bbls at minimum rate. i. If OA does not catch pressure after 160 bbls are pumped in OA, stop pumping cement and swap to pump 90 bbls of diesel in OA to FP and keep the shoe open and contact production engineer and WI engineer. d. Use cement composition on page #3. e. Pump Schedule: i. 10 bbls hot diesel per Wells Supv. ii. 65 bbls 90oF hot freshwater for flush of the OA. iii. 20 bbls CW100 surfactant wash iv. 10 bbls freshwater spacer v. 15 bbls 15.8# Class G cement (neat) vi. 414 bbls 15.8# Class G cement with 2 lbs/bbl of CemNet and gas blocker. 1. if well locks up while pumping cement, go to next step. 11. Close annulus, open the cement clean up line, and circulate to tanks to wash up tree and surface equipment. Top off OA with diesel for freeze protection. 12. Do not bleed the OA. Monitor the conductor top and downspout and vac out fluids if needed. 13. Wash up cementing equipment, RDMO. 14. Send OA cement shoe field blend UCA results to mark.shulman@conocophillips.com 15. After the cement cures for 72 hours, perform OA drawdown test. 16. If DDT passes DHD to drop string line and verify top of cement. 17. Report well work to AOGCC on 10-404 form. CD2-469 Cement Shoe Page 3 Cement Composition: Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,269.0 CD2-469 2/15/2010 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set OV, Post Circ CD2-469 10/13/2024 boehmbh Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 12/5/2008 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR Insulated 16 15.25 37.0 114.0 114.0 62.50 H-40 Welded SURFACE 10 3/4 9.95 36.4 3,454.4 2,390.4 45.50 L-80 BTC-M INTERMEDIATE 7 5/8 6.87 34.3 7,396.2 4,084.9 29.70 L-80 BTCM LINER 3 1/2 2.99 7,224.6 14,205.0 4,058.7 9.30 L-80 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 31.1 Set Depth … 3,571.9 Set Depth … 2,449.2 String Max No… 4 1/2 Tubing Description VIT TUBING Wt (lb/ft) Grade L-80 Top Connection IBTM ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.1 HANGER 10.850 FMC 4 1/2" Tbg hanger w/ 2.28' pup FMC 4.500 135.1 135.1 0.28 XO 4.5x3.5" 4.500 XO's - 3 1/2" IBT to EUE- 3 1/2" EUE (P) X 4 1/2" IBTM (B) 2- XO's 3.958 Top (ftKB) 3,571.9 Set Depth … 7,246.1 Set Depth … 4,068.4 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection IBTM 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) 3,585.8 2,456.1 60.37 SAFETY VLV 5.916 3 1/2" Camco TRMAXX-5E SSSV w/ 2.813" profile S/N # CXS0024 Schlumb erger TRMAX X-5E 2.812 5,577.1 3,391.6 61.59 GAS LIFT 5.390 Camco 3 1/2" x 1" KBMG GLM w/dummy 5.390" OD x 2.920" ID CAMCO KBMG 2.920 6,294.1 3,736.4 63.20 GAS LIFT 5.390 Camco 3 1/2" x 1" KBMG GLM w/DCK-2 Shear BEK-5 5.390" OD x 2.920" ID CAMCO KBMG 2.920 6,383.2 3,777.3 62.26 PACKER 7.600 Baker 3.5" x 7 5/8" Premier Packer 6.58" OD x 2.87" ID 2.870 6,461.9 3,813.6 63.07 NIPPLE 3.940 HES XN Nipple Halliburt on XN w/ RHC 2.750 7,245.1 4,068.3 81.00 WLEG 3.500 WLEG 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,461.0 3,813.2 63.06 PLUG 2.81" PXN PLUG (OAL = 89") 10/11/2024 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) 5,577.1 3,391.6 61.59 1 GAS LIFT DMY BEK 1 0.0 11/29/2008 0.000 6,294.1 3,736.4 63.20 2 GAS LIFT OV BK 1 0.0 10/13/2024 0.250 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,224.6 4,065.0 80.47 SLEEVE 6.440 Baker "HR" Liner Setting Sleeve 6.44 OD x 5.00 ID 5.000 7,237.3 4,067.1 80.80 NIPPLE 6.120 Baker "RS" Packoff Seal Nipple 6.12 OD x 4.91 ID 4.910 7,249.7 4,069.0 81.16 XO 5.570 XO - 5 1/2" L-80 BTC x 4 1/2" L-80 SLHT 5.57 OD x 3.95 ID 3.950 7,264.7 4,071.2 81.71 XO 4.500 XO - 4 1/2" SLHT x 3 1/2" SLHT 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,392.6 7,424.0 4,084.6 4,086.6 11/28/2008 32.0 SLOTS Alternating solid/slotted pipe 7,576.4 8,734.6 4,090.8 4,093.3 11/28/2008 32.0 SLOTS Alternating solid/slotted pipe 9,499.4 10,748.6 4,084.8 4,080.9 11/28/2008 32.0 SLOTS Alternating solid/slotted pipe 10,963.6 11,775.6 4,080.2 4,071.7 11/28/2008 32.0 SLOTS Alternating solid/slotted pipe 12,175.1 12,705.7 4,066.9 4,064.8 11/28/2008 32.0 SLOTS Alternating solid/slotted pipe 12,859.4 13,360.4 4,065.1 4,072.6 11/28/2008 32.0 SLOTS Alternating solid/slotted pipe 13,575.5 14,201.4 4,072.8 4,058.9 11/28/2008 32.0 SLOTS Alternating solid/slotted pipe HORIZONTAL, CD2-469, 3/12/2025 11:42:04 AM Vertical schematic (actual) LINER; 7,224.6-14,205.0 SLOTS; 13,575.5-14,201.4 SLOTS; 12,859.4-13,360.4 SLOTS; 12,175.1-12,705.7 SLOTS; 10,963.6-11,775.6 SLOTS; 9,499.4-10,748.6 SLOTS; 7,576.4-8,734.6 SLOTS; 7,392.6-7,424.0 INTERMEDIATE; 34.3-7,396.2 PLUG; 6,461.0 PACKER; 6,383.2 GAS LIFT; 6,294.1 GAS LIFT; 5,577.1 SAFETY VLV; 3,585.8 SURFACE; 36.4-3,454.4 CONDUCTOR Insulated; 37.0- 114.0 WNS PROD KB-Grd (ft) 44.30 RR Date 12/1/2008 Other Elev… CD2-469 ... TD Act Btm (ftKB) 14,297.0 Well Attributes Field Name QANNIK Wellbore API/UWI 501032058000 Wellbore Status PROD Max Angle & MD Incl (°) 93.63 MD (ftKB) 14,234.63 WELLNAME WELLBORECD2-469 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:AOGCC Permitting (CED sponsored) To:Brooks, James S (OGC) Subject:FW: CRU CD2-469 (PTD 208-122) 10-403 OA Cement Date:Wednesday, March 12, 2025 4:22:04 PM Attachments:CRU CD2-469 OA Cement 10-403si.pdf Please note withdrawal request for this sundry 325-005. Thank you, Grace From: Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Sent: Wednesday, March 12, 2025 2:54 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>; Shulman, Mark <Mark.Shulman@conocophillips.com> Subject: CRU CD2-469 (PTD 208-122) 10-403 OA Cement Hello, I have attached a new 10-403 for CRU CD2-469 (PTD 208-122) OA Cement. We are requesting to withdraw Approved Sundry # 325-005 for this well, and are submitting the attached 10-403 as a replacement. Please let me know if you need any additional information. Thank you , Amy Amy A. Conklin, Well Integrity Analyst ConocoPhillips Alaska 700 G St, ATO 1307 Anchorage, AK 99501 (907) 265-1484 amy.a.conklin@conocophillips.com RBDMS JSB 031325 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 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 14,297'N/A Casing Collapse Conductor Surface Intermediate Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: 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 7,393' - 14,201' 3 1/2" 4,085' - 4059' SSSV: 3 1/2" Camco TRMAXX-5E SSSV 2/1/2025 14,205'6,980' 4 1/2" x 3 1/2" 4,059' Packer: Baker 3.5" x 7 5/8" Premier Packer 16" (insulated) 10 3/4" 77' 7 5/8"7,362' 3,418' 114' 2,390 4,085' 114' 3,454' 7,396' Length Size Proposed Pools: L-80 TVD Burst 7,246' MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380075 208-122 P.O. Box 100630, Anchorage, Alaska 99508 50-103-20580-00-00 ConocoPhillips Alaska, Inc. AOGCC USE ONLY Tubing Grade: Tubing MD (ft):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 Other: SC Repair COLVILLE RIV QANN CD2-469 QANNIK OILCOLVILLE RIVER N/A 4,053'6,461' SSSV: 3,586' MD / 2,456' TVD Packer: 6,383' MD / 3,777' TVD Well Integrity Field Supervisor Brennen Green & Roger Mouser N1927@conocophillips.com (907) 659-7506 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Coldiron at 7:38 am, Jan 09, 2025 325-005 Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@ conocophillips.com Reason: I am the author of this document Location: Date: 2025.01.09 06:49:42-09'00' Foxit PDF Editor Version: 13.0.0 Brennen Green Prior to welding, well shall be secured with a plug and verified with pressure test. Verify tubing, production casing, and packoff integrity prior to welding - done. SFD 1/21/2025JJL 1/21/25 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.01.27 16:15:29 -09'00'01/27/25 RBDMS JSB 012925 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 8, 2025 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Please find enclosed the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding well ALP CD2-469 (PTD 208-122) to repair the Surface Casing leak. Please contact Brennen Green or Roger Mouser at 659-7506 if you have any questions. Sincerely, Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E= n1927@conocophillips.com Reason: I am the author of this document Location: Date: 2025.01.09 06:48:30-09'00' Foxit PDF Editor Version: 13.0.0 Brennen Green P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ConocoPhillips Alaska, Inc. ALPINE WELL CD2-469 (PTD 208-122) SUNDRY NOTICE 10-403 APPROVAL REQUEST January This application for Sundry approval for Alpine well CD2-469 is for the inspection and repair of surface casing with a suspected surface casing leak at. Subsequent diagnostics indicate that the leak is relatively shallow (~9’ below the OA valve). ConocoPhillips requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will require the following general steps (with photo documentation): 1. Secure the well as needed with mechanical plug in the tubing. 2. Remove the floor grate, well house, flow lines, and other equipment as necessary from around the wellhead. 3. Remove gravel around well head and excavate to ~24’. 4. Install nitrogen purge equipment for the conductor and OA (if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary. Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. 8. Perform a pressure test to confirm no fluid to surface. 9. Install anti-corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill as needed with gravel around the wellhead. 12. Remove plug(s) and return the well to service. 13. File 10-404 with the AOGCC post repair. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,269.0 CD2-469 2/15/2010 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set OV, Post Circ CD2-469 10/13/2024 boehmbh Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 12/5/2008 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR Insulated 16 15.25 37.0 114.0 114.0 62.50 H-40 Welded SURFACE 10 3/4 9.95 36.4 3,454.4 2,390.4 45.50 L-80 BTC-M INTERMEDIATE 7 5/8 6.87 34.3 7,396.2 4,084.9 29.70 L-80 BTCM LINER 3 1/2 2.99 7,224.6 14,205.0 4,058.7 9.30 L-80 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 31.1 Set Depth … 3,571.9 Set Depth … 2,449.2 String Max No… 4 1/2 Tubing Description VIT TUBING Wt (lb/ft) Grade L-80 Top Connection IBTM ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.1 HANGER 10.850 FMC 4 1/2" Tbg hanger w/ 2.28' pup FMC 4.500 135.1 135.1 0.28 XO 4.5x3.5" 4.500 XO's - 3 1/2" IBT to EUE- 3 1/2" EUE (P) X 4 1/2" IBTM (B) 2- XO's 3.958 Top (ftKB) 3,571.9 Set Depth … 7,246.1 Set Depth … 4,068.4 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection IBTM 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) 3,585.8 2,456.1 60.37 SAFETY VLV 5.916 3 1/2" Camco TRMAXX-5E SSSV w/ 2.813" profile S/N # CXS0024 Schlumb erger TRMAX X-5E 2.812 5,577.1 3,391.6 61.59 GAS LIFT 5.390 Camco 3 1/2" x 1" KBMG GLM w/dummy 5.390" OD x 2.920" ID CAMCO KBMG 2.920 6,294.1 3,736.4 63.20 GAS LIFT 5.390 Camco 3 1/2" x 1" KBMG GLM w/DCK-2 Shear BEK-5 5.390" OD x 2.920" ID CAMCO KBMG 2.920 6,383.2 3,777.3 62.26 PACKER 7.600 Baker 3.5" x 7 5/8" Premier Packer 6.58" OD x 2.87" ID 2.870 6,461.9 3,813.6 63.07 NIPPLE 3.940 HES XN Nipple Halliburt on XN w/ RHC 2.750 7,245.1 4,068.3 81.00 WLEG 3.500 WLEG 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,461.0 3,813.2 63.06 PLUG 2.81" PXN PLUG (OAL = 89") 10/11/2024 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) 5,577.1 3,391.6 61.59 1 GAS LIFT DMY BEK 1 0.0 11/29/2008 0.000 6,294.1 3,736.4 63.20 2 GAS LIFT OV BK 1 0.0 10/13/2024 0.250 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,224.6 4,065.0 80.47 SLEEVE 6.440 Baker "HR" Liner Setting Sleeve 6.44 OD x 5.00 ID 5.000 7,237.3 4,067.1 80.80 NIPPLE 6.120 Baker "RS" Packoff Seal Nipple 6.12 OD x 4.91 ID 4.910 7,249.7 4,069.0 81.16 XO 5.570 XO - 5 1/2" L-80 BTC x 4 1/2" L-80 SLHT 5.57 OD x 3.95 ID 3.950 7,264.7 4,071.2 81.71 XO 4.500 XO - 4 1/2" SLHT x 3 1/2" SLHT 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,392.6 7,424.0 4,084.6 4,086.6 11/28/2008 32.0 SLOTS Alternating solid/slotted pipe 7,576.4 8,734.6 4,090.8 4,093.3 11/28/2008 32.0 SLOTS Alternating solid/slotted pipe 9,499.4 10,748.6 4,084.8 4,080.9 11/28/2008 32.0 SLOTS Alternating solid/slotted pipe 10,963.6 11,775.6 4,080.2 4,071.7 11/28/2008 32.0 SLOTS Alternating solid/slotted pipe 12,175.1 12,705.7 4,066.9 4,064.8 11/28/2008 32.0 SLOTS Alternating solid/slotted pipe 12,859.4 13,360.4 4,065.1 4,072.6 11/28/2008 32.0 SLOTS Alternating solid/slotted pipe 13,575.5 14,201.4 4,072.8 4,058.9 11/28/2008 32.0 SLOTS Alternating solid/slotted pipe HORIZONTAL, CD2-469, 10/15/2024 12:31:23 PM Vertical schematic (actual) LINER; 7,224.6-14,205.0 SLOTS; 13,575.5-14,201.4 SLOTS; 12,859.4-13,360.4 SLOTS; 12,175.1-12,705.7 SLOTS; 10,963.6-11,775.6 SLOTS; 9,499.4-10,748.6 SLOTS; 7,576.4-8,734.6 SLOTS; 7,392.6-7,424.0 INTERMEDIATE; 34.3-7,396.2 PLUG; 6,461.0 PACKER; 6,383.2 GAS LIFT; 6,294.1 GAS LIFT; 5,577.1 SAFETY VLV; 3,585.8 SURFACE; 36.4-3,454.4 CONDUCTOR Insulated; 37.0- 114.0 WNS PROD KB-Grd (ft) 44.30 RR Date 12/1/2008 Other Elev… CD2-469 ... TD Act Btm (ftKB) 14,297.0 Well Attributes Field Name QANNIK Wellbore API/UWI 501032058000 Wellbore Status PROD Max Angle & MD Incl (°) 93.63 MD (ftKB) 14,234.63 WELLNAME WELLBORECD2-469 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP 1 Christianson, Grace K (OGC) From:Lau, Jack J (OGC) Sent:Monday, January 27, 2025 3:53 PM To:Christianson, Grace K (OGC) Subject:FW: [EXTERNAL]CD2-469 PTD 208-122 Surface Casing Repair I would like to include this email. From: NSK Well Integrity Field Supv <N1927@conocophillips.com> Sent: Tuesday, January 14, 2025 3:08 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Shulman, Mark <Mark.Shulman@conocophillips.com>; Packer, J.Brett <J.Brett.Packer@conocophillips.com>; Mouser, Roger (ASRC Energy Services) <Roger.Mouser@contractor.conocophillips.com> Subject: RE: [EXTERNAL]CD2-469 PTD 208-122 Surface Casing Repair Hello, Jack, No. We maintain the atmosphere in the OA at O2 <5% or the LELs <10% using a Nitrogen purge. The OA Ʋuid level will be a minimum of 2’ below the welding zone. Brennen From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Tuesday, January 14, 2025 1:50 PM To: NSK Well Integrity Field Supv <N1927@conocophillips.com> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Shulman, Mark <Mark.Shulman@conocophillips.com>; Packer, J.Brett <J.Brett.Packer@conocophillips.com>; Mouser, Roger (ASRC Energy Services) <Roger.Mouser@contractor.conocophillips.com> Subject: RE: [EXTERNAL]CD2-469 PTD 208-122 Surface Casing Repair Thanks Brennen, Will the diesel be displaced with a non-Ʋammable Ʋuid in the OA? Jack From: NSK Well Integrity Field Supv <N1927@conocophillips.com> Sent: Monday, January 13, 2025 3:08 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Shulman, Mark <Mark.Shulman@conocophillips.com>; Packer, J.Brett <J.Brett.Packer@conocophillips.com>; Mouser, Roger (ASRC Energy Services) <Roger.Mouser@contractor.conocophillips.com> Subject: RE: [EXTERNAL]CD2-469 PTD 208-122 Surface Casing Repair CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Good afternoon, Jack, Please see the responses to your questions below. x Include details on how the well will be secured and veriƱed (e.g. plug at XXXX’ and MITT) o There is a T plug at 6,461’ and passed a CMIT T x IA and passing CDDT TxIA. They then reset the OV and passed an MIT-T. x Provide details on tubing, casing, wellhead, and packer integrity. (e.g. last MITT, MITIA, MITOA) o Passed a CMIT TxIA to 2500 psi, CDDT TxIA to 0 psi, and MIT-T to 2500 psi to on 10/13/24. Passed a T, IA, and OA DDT to 0 psi on 10/14/24 x Include pressure testing details to prove well barriers (e.g. MITT, MITIA, PPPOT-T & IC) o Please see above MIT and DDT information. SBMS Passed, T POT Passed to 0 psi, T PPPOT Passed to 5000 psi , Upper MTM Failed, Lower MTM Passed , IC POT Passed , IC PPPOT Passed to 3000 psi on 10/7/24. x Current Ʋuid types and levels in the tubing and annuli. o OA FL @ Surface 1/10/25 (diesel @ surface). T and IA Circ’ed out with 5 bbl of meth, followed by 280 bbl of sea water and 85 bbl of diesel and u-tubed on 10/12/24. x Does the OA have an open shoe? o Yes x How will hydrocarbons be isolated for the repair? What will the Ʋuid types and levels be in the OA when executing repair? o Downhole plug and kill weight (as needed). OA FL will be a minimum of 2’ below the weld area. x Will the repair include welding? If so what mitigations will be in place? o Yes. Engineering design and Nitrogen purging. x For trenching and shoring what protocol are you using? o Engineering design and shielding system (trench box). If you have any more questions, feel free to reach out. Brennen Green / Roger Mouser CPAI WI Field Supervisor Office (907) 659-7506 Cell (907) 943-1055 N1927@ COP.com From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Monday, January 13, 2025 12:08 PM To: NSK Well Integrity Field Supv <N1927@conocophillips.com> 3 Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: [EXTERNAL]CD2-469 PTD 208-122 Surface Casing Repair CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Brennen or Roger, Currently reviewing your surface casing repair sundry for CD2-469. Please provide the following detail. x Include details on how the well will be secured and veriƱed (e.g. plug at XXXX’ and MITT) x Provide details on tubing, casing, wellhead, and packer integrity. (e.g. last MITT, MITIA, MITOA) x Include pressure testing details to prove well barriers (e.g. MITT, MITIA, PPPOT-T & IC) x Current Ʋuid types and levels in the tubing and annuli. x Does the OA have an open shoe? x How will hydrocarbons be isolated for the repair? What will the Ʋuid types and levels be in the OA when executing repair? x Will the repair include welding? If so what mitigations will be in place? x For trenching and shoring what protocol are you using? Jack Lau Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission (907) 793-1244 OƯice (907) 227-2760 Cell