The URL can be used to link to this page

Home My WebLink About217-155MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, October 16, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD5-23 COLVILLE RIV UNIT CD5-23 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2025 CD5-23 50-103-20761-00-00 217-155-0 G SPT 7338 2171550 3900 3599 3599 3601 3600 125 145 147 145 REQVAR P Bob Noble 8/31/2025 MIT-IA to max injection pressure as per AIO 18E.004. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:COLVILLE RIV UNIT CD5-23 Inspection Date: Tubing OA Packer Depth 1400 4200 4103 4083IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250904152234 BBL Pumped:2.7 BBL Returned:2.7 Thursday, October 16, 2025 Page 1 of 1            CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD5-23 (PTD: 217-155) 30 day gas injection monitor AOGCC Notification Date:Tuesday, August 19, 2025 8:13:21 AM Attachments:image001.png EXTERNALRe CRU CD5-23 (PTD 217-155).msg From: Shulman, Mark <Mark.Shulman@conocophillips.com> Sent: Monday, August 18, 2025 4:53 PM To: Automation, AK Wells <akwellsautomation@conocophillips.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Subject: CRU CD5-23 (PTD: 217-155) 30 day gas injection monitor AOGCC Notification Well Name: CRU CD5-23 Facility: WNS PTD: 217-155 Well Type: Injector AA Number (if applicable): AIO 18E.004 Internal Waiver (Yes/No if applicable): Type of Issue: Plan forward Maximum Pressure (if applicable): Date of Occurrence (if applicable): 08/16/25 Chris, CRU CD5-23 is a waivered gas injector and has begun it’s 30-day gas injection monitor on 8/16/25. CD5-23 passed an MIT-IA (2,500 psi on 7/2/25). Additionally, you have approved the 30-day monitor post repair of failed MIT-IA, as per waiver requirement (see attached email of your approval and well repair). The 30-day gas injection will be complete on 09/17/25. Thanks, Mark Mark Shulman WNS Sr. Well Integrity Engineer ConocoPhillips Alaska Mark.Shulman@conocophillips.com Office (907) 263-3782 Mobile (602) 513-0775 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. 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. From:Wallace, Chris D (OGC) To:WNS Wells Integrity Eng Cc:Livingston, Erica J Subject:[EXTERNAL]Re: CRU CD5-23 (PTD 217-155) Date:Thursday, July 24, 2025 9:10:44 AM Attachments:image001.png Mark, Your request to restart injection is approved. Regards, Chris From: WNS Wells Integrity Eng <WNSIntegrity@conocophillips.com> Sent: Wednesday, July 23, 2025 11:00:13 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: CRU CD5-23 (PTD 217-155) Chris, CRU CD5-23 (PTD# 217-155) was repaired and passed a MIT-IA (2,500 psi) and MIT-T (3,300 psi) on 7/2/25 (please see attached 10-426 form). CPAI plans to bring the well back on gas injection and start a 30-day gas injection monitor. Please note that Line #9 condition of the waiver AIO 18E.004, requires AOGCC’s approval to bring the well back on injection (please see attached waiver above). 9) After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; If you agree with the plan, please respond to this email, and we will bring the well online and begin the 30-day monitor. Attached is the 90-day TIO plot and wellbore schematic. Please let me know if you have any questions. Thanks, Mark Shulman From: WNS Integrity Sent: Monday, March 10, 2025 2:02 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: CRU CD5-23 (PTD 217-155) Chris, CRU CD5-23 (PTD# 217-155) failed a diagnostic MIT-IA on 3/8/2025. Please note this well is a waivered WAG injector (AIO 18E.004) on a 30 day monitor (see email below). The well has been shut in and initial diagnostics are ongoing. Depending on results, proper notifications will be made as needed. Attached is the 90 day TIO plot and wellbore schematic. Let me know if you have any questions or disagree with this plan. Thanks, Mark From: WNS Integrity Sent: Monday, March 3, 2025 6:52 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: CRU CD5-23 (PTD 217-155) Chris, CRU CD5-23 (PTD 217-155) is a waivered WAG injector (AIO 18E.004). On 3/2/25, the well’s IA exceed the allowable operating pressure of 2,400 psi while on gas injection likely due to a choke change. The max pressure was 2,406 psi, the IA was bled down to 2050 psi and stable. CD5-23 passed an MIT-IA to 4,200 psi on 4/14/2024. The 90 day TIO is attached. CPAI would like to put the well online for a 30-day monitor on gas. Depending on 30-day monitor results, proper notifications will be made as needed. Let me know if you have any questions or disagree with this plan. Thanks, Mark Mark Shulman WNS Well Integrity Engineer ConocoPhillips Alaska Mark.Shulman@conocophillips.com Office (907) 263-3782 Mobile (602) 513-0775 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD5-23 (PTD 217-155) Date:Monday, July 28, 2025 8:46:45 AM Attachments:image001.png CD5-23 10-426 07-02-25.xlsx CD5-23 aio18E.004.pdf AnnComm Surveillance TIO for CD5-23.pdf From: WNS Wells Integrity Eng <WNSIntegrity@conocophillips.com> Sent: Wednesday, July 23, 2025 11:00 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: CRU CD5-23 (PTD 217-155) Chris, CRU CD5-23 (PTD# 217-155) was repaired and passed a MIT-IA (2,500 psi) and MIT-T (3,300 psi) on 7/2/25 (please see attached 10-426 form). CPAI plans to bring the well back on gas injection and start a 30-day gas injection monitor. Please note that Line #9 condition of the waiver AIO 18E.004, requires AOGCC’s approval to bring the well back on injection (please see attached waiver above). 9) After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; If you agree with the plan, please respond to this email, and we will bring the well online and begin the 30-day monitor. Attached is the 90-day TIO plot and wellbore schematic. Please let me know if you have any questions. Thanks, Mark Shulman From: WNS Integrity Sent: Monday, March 10, 2025 2:02 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: CRU CD5-23 (PTD 217-155) Chris, CRU CD5-23 (PTD# 217-155) failed a diagnostic MIT-IA on 3/8/2025. Please note this well is a waivered WAG injector (AIO 18E.004) on a 30 day monitor (see email below). The well has been shut in and initial diagnostics are ongoing. Depending on results, proper notifications will be made as needed. Attached is the 90 day TIO plot and wellbore schematic. Let me know if you have any questions or disagree with this plan. Thanks, Mark From: WNS Integrity Sent: Monday, March 3, 2025 6:52 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: CRU CD5-23 (PTD 217-155) Chris, CRU CD5-23 (PTD 217-155) is a waivered WAG injector (AIO 18E.004). On 3/2/25, the well’s IA exceed the allowable operating pressure of 2,400 psi while on gas injection likely due to a choke change. The max pressure was 2,406 psi, the IA was bled down to 2050 psi and stable. CD5-23 passed an MIT-IA to 4,200 psi on 4/14/2024. The 90 day TIO is attached. CPAI would like to put the well online for a 30-day monitor on gas. Depending on 30-day monitor results, proper notifications will be made as needed. Let me know if you have any questions or disagree with this plan. Thanks, Mark Mark Shulman WNS Well Integrity Engineer ConocoPhillips Alaska Mark.Shulman@conocophillips.com Office (907) 263-3782 Mobile (602) 513-0775 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 217-155 Type Inj W Tubing 2850 2850 2850 2850 Type Test P Packer TVD 7338 BBL Pump 1.2 IA 995 2530 2490 2490 Interval O Test psi 1835 BBL Return OA 80 80 80 80 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 217-155 Type Inj W Tubing 2850 3275 3225 3225 Type Test P Packer TVD 7338 BBL Pump 2.6 IA 1050 1075 1075 1075 Interval O Test psi 1835 BBL Return OA 75 75 75 75 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:Non witnessed MIT-T diagnostic test repeated to 3300 psi. Notes: Notes: ConocoPhillips Alaska Inc, Alpine / CRU / CD5 Pad Gray Rainey 07/02/25 Notes:Non-witnessed MIT-IA diagnostic test to 2500 psi. Notes: Notes: Notes: Form 10-426 (Revised 01/2017)CD5-23 10-426 07-02-25 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 18E.004 Ms. Kathleen Dodson Well Integrity Specialist ConocoPhillips Alaska, Inc. P.O. Box 1000360 Anchorage, AK 99510 Re: Docket Number: AIO-23-003 Request for Administrative Approval to Area Injection Order 18E; Water Alternating Gas Injection Colville River Unit (CRU) CD5-23 (PTD 2171550), Alpine Oil Pool Dear Ms. Dodson: By emailed letter dated February 21, 2023, ConocoPhillips Alaska, Inc. (CPAI) requested administrative approval to continue water alternating gas(WAG) injection with a known tubing by inner annulus (TxIA) pressure communication. In accordance with 20AAC 25.556(d), the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS, subject to conditions, CPAI’s request for administrative approval to continue WAG injection in the subject well. CPAI reported a potential TxIA pressure communication to AOGCC on February 7, 2022, while the well was on miscible injectant (MI)/gas injection. CPAI requested and AOGCC approved a monitoring and diagnostics period on water. CPAI performed diagnostics including a failing mechanical integrity test (MIT) of the inner annulus and the well was shut in. On January 17, 2023, CPAI performed additional diagnostics including a passing non state-witnessed MIT of the inner annulus (to a test pressure of 4,140 psi which is greater than the anticipated gas injection pressure of 3,800 psi). This indicates that CD5-23 exhibits at least two competent barriers to the release of well pressure. CPAI maintains live transmitters on the inner and outer annulus and alarm and remote shut down functions in the Supervisory Control and Data Acquisition (SCADA) system that create layers of protection from an over-pressure event. AOGCC believes CPAI can safely manage the TxIA communication with periodic pressure bleeds by maintaining the inner annulus to a pressure not to exceed 2,400 psi and the outer annulus not to exceed 1,000 psi. Accordingly, the AOGCC believes that the well’s condition does not compromise overall well integrity so as to threaten human safety or the environment. AIO 18E.004 March 2, 2023 Page 2 of 2 AOGCC’s approval to continue WAG injection in CRU CD5-23 is conditioned upon the following: 1) CPAI shall record wellhead pressures and injection rate daily; 2) CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report; 3) CPAI shall perform a MIT of the inner annulus every two years to the greater of the maximum anticipated injection pressure or 0.25 x packer TVD, but not less than 1,500 psi; 4) CPAI shall limit the well’s inner annulus operating pressure to 2,400 psi during gas injection and 2,000 psi during water injection. Audible control room alarms shall be set at or below these limits; 5) CPAI shall limit the well’s outer annulus operating pressure to 1,000 psi. Audible control room alarms shall be set at or below these limits; 6) CPAI shall monitor the inner and outer annulus pressures in real time with its SCADA system; 7) CPAI shall maintain the injection line choke and surface safety valve (SSV) remote shut down capability. During gas injection, the IA protocols will include a drill site operator alarm set at 2,200 psi, and a high alarm set at 2,400 psi that will prompt the control room Board Operator to remotely shut in the choke or SSV; 8) CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 9) After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 10) The next required MIT is to be before or during the month of August 2023. This is to align with the agreed upon CPAI Underground Injection Control MIT permanent test schedule for pad testing. DONE at Anchorage, Alaska and dated March 2, 2023. Brett W. Huber, Sr Jessie L. Chmielowski Chair, Commissioner Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.03.02 11:13:23 -09'00' Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.03.02 11:22:19 -09'00' CD5-23 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING CD5-23 2025-04-30 110.0 1010 900.0 OA CD5-23 2025-06-29 1320.0 980 -340.0 IA Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: SET A-1 INJ VALVE ON A 4.5" P2P W/ MID ELEMENT @ 2050' RKB CD5-23 7/9/2025 raineg Notes: General & Safety Annotation End Date Last Mod By NOTE: COIL MILLED OUT X -LOCK. NIPPLE AT 2070' IS LIKELY DAMAGED. SEE ATTACHMENTS.3/22/2024 rmoore22 NOTE: RUNNING NECK AND FISHING SWIVELED OFF DV IN STA #2. WOBBLE RING & SPRING RECOVERED. 2/9/2018 claytg Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR2019.12 33.3 115.0 115.094.00 H-40 Welded SURFACE 10 3/4 9.95 37.0 2,219.6 2,179.0 45.50 L-80 Hyd 563 INTERMEDIATE 7 5/8 6.88 34.0 8,620.8 7,444.3 29.70 L80 Hyd563 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 31.0 Set Depth… 8,946.5 Set Depth… 7,485.1 String Max No… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection H563 ID (in) 3.96 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) 31.0 31.0 0.00 HANGER 11.000 FMC 4-1/2" Tubing Hanger H563 FMC TC-EMS 11"x5" 3.958 2,070.9 2,039.2 20.13 NIPPLE 5.030 NIPPLE,LANDING,4 1/2",X,3.813", HYD563 (likely damaged. see note above) HES X 3.813 3,583.3 3,453.8 21.12 GAS LIFT 6.473 GLM KBMG,Camco,4 1/2" X 1",H563 SLB Camco KBMG3.860 5,882.0 5,595.5 21.05 GAS LIFT 6.473 GLM KBMG,Camco,4 1/2" X 1",H563 SLB Camco KBMG3.860 6,398.3 6,077.2 21.08 GAS LIFT 6.473 GLM KBMG,Camco,4 1/2" X 1",H563 SLB Camco KBMG3.860 8,129.3 7,337.8 70.77 PACKER 6.620 Baker permanent production packer 4.5" TC-II x 7 5/8" 29# BakerPremier 3.870 8,183.1 7,354.7 72.57 NIPPLE 5.030 NIPPLE,LANDING,4 1/2",X,3.813", HYD563 ***POLISH BORE DAMAGED*** HES X 3.813 8,227.7 7,367.5 74.04 NIPPLE 5.030 NIPPLE,LANDING,4 1/2",3.813" XN, 3.725" No-go HYD563 ***NIPPLE MILLED OUT TO 3.80" PRE-CTD 1/12/20*** HES XN 3.800 8,231.0 7,368.4 74.13 LINER 4.500 CROSSOVER,4 1/2"HYD563 X TXP,BP,24" 3.958 8,232.9 7,368.9 74.18 LINER 4.500 Tubing,4 1/2",12.6#,L80, TXP 3.958 8,941.3 7,484.6 84.20 SHOE 4.500 Orange Peel Shoe (MILLED OUT FROM 1.00" TO 3.70" ON 3/23/2018) 3.700 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) 2,047.02,016.7 20.03 INJ VALVE 4.5" A-1 INJECTION VALVE ON P2P (MID-ELEMENT @ 2050' RKB (SN# HWS-210, 1.25" BEAN, OAL = 84" 7/9/2025 1.250 8,750.0 7,461.3 82.46 4-1/2" BOT Mono-bore XL tray Whipstock 4-1/2" BOT Mono-bore XL tray Whipstock 2/23/2020 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) 3,583.3 3,453.8 21.12 1 GAS LIFT DMY BK 1 0.0 1/13/20190.000 5,882.0 5,595.5 21.05 2 GAS LIFT DMY No Latch 1 0.0 2/8/2018 No Latch 0.000 6,398.3 6,077.2 21.08 3 GAS LIFT DMY BK 1 0.06/11/20250.000 HORIZONTAL, CD5-23, 7/10/2025 6:19:24 AM Vertical schematic (actual) X O SHOE; 8,941.3 PERF PUP; 8,930.6 4-1/2" BOT Mono-bore XL tray Whipstock ; 8,750.0 OPEN HOLE; 8,621.0-27,430.0 INTERMEDIATE; 34.0-8,620.8 NIPPLE; 8,227.7 NIPPLE; 8,183.1 XO THREADS; 8,133.5 PACKER; 8,129.3 XO THREADS; 8,121.5 GAS LIFT; 6,398.3 GAS LIFT; 5,882.0 GAS LIFT; 3,583.3 SURFACE; 37.0-2,219.6 NIPPLE; 2,070.9 INJ VALVE; 2,047.0 CONDUCTOR; 33.3-115.0 HANGER; 31.0 WNS INJ KB-Grd (ft) 36.55 RR Date 1/24/2018 Other Elev… CD5-23 ... TD Act Btm (ftKB) 27,430.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032076100 Wellbore Status INJ Max Angle & MD Incl (°) 94.15 MD (ftKB) 19,914.56 WELLNAME WELLBORE Annotation LAST WO: End DateH2S (ppm)DateComment SSSV: NIPPLE CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD5-23 (PTD 217-155) Date:Monday, July 28, 2025 8:46:40 AM Attachments:image001.png From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Thursday, July 24, 2025 9:11 AM To: WNS Wells Integrity Eng <WNSIntegrity@conocophillips.com> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: Re: CRU CD5-23 (PTD 217-155) Mark, Your request to restart injection is approved. Regards, Chris From: WNS Wells Integrity Eng <WNSIntegrity@conocophillips.com> Sent: Wednesday, July 23, 2025 11:00:13 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: CRU CD5-23 (PTD 217-155) Chris, CRU CD5-23 (PTD# 217-155) was repaired and passed a MIT-IA (2,500 psi) and MIT-T (3,300 psi) on 7/2/25 (please see attached 10-426 form). CPAI plans to bring the well back on gas injection and start a 30-day gas injection monitor. Please note that Line #9 condition of the waiver AIO 18E.004, requires AOGCC’s approval to bring the well back on injection (please see attached waiver above). 9) After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; If you agree with the plan, please respond to this email, and we will bring the well online and begin the 30-day monitor. Attached is the 90-day TIO plot and wellbore schematic. Please let me know if you have any questions. Thanks, Mark Shulman From: WNS Integrity Sent: Monday, March 10, 2025 2:02 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: CRU CD5-23 (PTD 217-155) Chris, CRU CD5-23 (PTD# 217-155) failed a diagnostic MIT-IA on 3/8/2025. Please note this well is a waivered WAG injector (AIO 18E.004) on a 30 day monitor (see email below). The well has been shut in and initial diagnostics are ongoing. Depending on results, proper notifications will be made as needed. Attached is the 90 day TIO plot and wellbore schematic. Let me know if you have any questions or disagree with this plan. Thanks, Mark From: WNS Integrity Sent: Monday, March 3, 2025 6:52 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: CRU CD5-23 (PTD 217-155) Chris, CRU CD5-23 (PTD 217-155) is a waivered WAG injector (AIO 18E.004). On 3/2/25, the well’s IA exceed the allowable operating pressure of 2,400 psi while on gas injection likely due to a choke change. The max pressure was 2,406 psi, the IA was bled down to 2050 psi and stable. CD5-23 passed an MIT-IA to 4,200 psi on 4/14/2024. The 90 day TIO is attached. CPAI would like to put the well online for a 30-day monitor on gas. Depending on 30-day monitor results, proper notifications will be made as needed. Let me know if you have any questions or disagree with this plan. Thanks, Mark Mark Shulman WNS Well Integrity Engineer ConocoPhillips Alaska Mark.Shulman@conocophillips.com Office (907) 263-3782 Mobile (602) 513-0775 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Date: May 27, 2025 FFROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC 700 G Street 333 W.7th Ave., Suite 100 Anchorage AK 99501 Anchorage, Alaska DATA TRANSMITTAL Kuparuk River Unit/Field Well API #PTD #Comments 1H-112 50029237870100 2240320 3B-16A 50029212890100 2231250 2B-03B 50029211510200 2230800 2M-39 50103207950000 2181710 3S-612 50103207770000 2181110 3S-611 50103207740000 2181030 1H-108B 50029236080200 2180820 1H-110 50029236010000 2180310 1H-116 50029235940000 2180120 2S-06 50103207470000 2160850 2M-37 50103207450000 2160820 1D-39 50029229970000 2002160 1D-40A 50029229690100 2001900 2N-302 50103203800000 2011150 1R-03A 50029214060100 2000210 3H-37 50103208220000 2191940 2S-09A 50103207490100 2161280 T40450 T40451 T40452 T40453 T40454 T40455 T40456 T40457 T40458 T40459 T40460 T40461 T40462 T40463 T40464 T40465 T40466 By Gavin Gluyas at 1:15 pm, May 28, 2025 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Colville River Unit/Field Well API # PTD # Comments CD5-31 50103208280000 2210020 CD5-96 50103208110000 2191620 CD4-499 50103208100000 2191610 CD5-26 50103208060000 2191070 CD5-98 50103208030000 2190590 CD5-24 50103207990000 2190060 CD5-23 50103207610000 2171550 CD5-19 50103207600000 2171210 CD5-22 50103207590000 2170890 CD5-316 50103207560000 2170400 CD3-111A 50103205260100 2170040 CD3-198 50103206370000 2110240 CD4-24 50103206020000 2090970 CD4-26 50103206000000 2090490 CD2-15 50103203860000 2011590 CD2-12 50103204550000 2030730 CD4-214 50103205370000 2061450 CD4-17 50103205340000 2061180 CD2-73 50103205900000 2081960 T40467 T40468 T40469 T40470 T40471 T40472 T40473 T40474 T40475 T40476 T40477 T40478 T40479 T40480 T40481 T40482 T40483 T40484 T40487 CD5-23 50103207610000 2171550 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Greater Mooses Tooth Unit/Field Well API # PTD # Comments MT7-99 50103208450000 2221020 T40485 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD5-23 (PTD 217-155) Date:Monday, March 10, 2025 2:20:06 PM Attachments:image001.png AnnComm Surveillance TIO for CD5-23.pdf From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Monday, March 10, 2025 2:02 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: CRU CD5-23 (PTD 217-155) Chris, CRU CD5-23 (PTD# 217-155) failed a diagnostic MIT-IA on 3/8/2025. Please note this well is a waivered WAG injector (AIO 18E.004) on a 30 day monitor (see email below). The well has been shut in and initial diagnostics are ongoing. Depending on results, proper notifications will be made as needed. Attached is the 90 day TIO plot and wellbore schematic. Let me know if you have any questions or disagree with this plan. Thanks, Mark From: WNS Integrity Sent: Monday, March 3, 2025 6:52 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: CRU CD5-23 (PTD 217-155) Chris, CRU CD5-23 (PTD 217-155) is a waivered WAG injector (AIO 18E.004). On 3/2/25, the well’s IA exceed the allowable operating pressure of 2,400 psi while on gas injection likely due to a choke change. The max pressure was 2,406 psi, the IA was bled down to 2050 psi and stable. CD5-23 passed an MIT-IA to 4,200 psi on 4/14/2024. The 90 day TIO is attached. CPAI would like to put the well online for a 30-day monitor on gas. Depending on 30-day monitor results, proper notifications will be made as needed. Let me know if you have any questions or disagree with this plan. Thanks, Mark Mark Shulman WNS Well Integrity Engineer ConocoPhillips Alaska Mark.Shulman@conocophillips.com Office (907) 263-3782 Mobile (602) 513-0775 CD5-23 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING CD5-23 2025-03-05 2138 538 -1600 IA CD5-23 2025-03-08 1035 500 -535 IA Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Updated to reflect X-Lock / A-1 fish CD5-23 12/12/2023 famaj Notes: General & Safety Annotation End Date Last Mod By NOTE: COIL MILLED OUT X -LOCK. NIPPLE AT 2070' IS LIKELY COMPRIMISED. SEE ATTACHMENTS. 3/22/2024 rmoore22 NOTE: RUNNING NECK AND FISHING SWIVELED OFF DV IN STA #2. WOBBLE RING & SPRING RECOVERED. 2/9/2018 claytg 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 20 19.12 33.3 115.0 115.0 94.00 H-40 Welded SURFACE 10 3/4 9.95 37.0 2,219.6 2,179.0 45.50 L-80 Hyd 563 INTERMEDIATE 7 5/8 6.88 34.0 8,620.8 7,444.3 29.70 L80 Hyd563 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 31.0 Set Depth … 8,946.5 Set Depth … 7,485.1 String Max No… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection H563 ID (in) 3.96 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) 31.0 31.0 0.00 HANGER 11.000 FMC 4-1/2" Tubing Hanger H563 FMC TC-EMS 11"x5" 3.958 2,070.9 2,039.2 20.13 NIPPLE 5.030 NIPPLE,LANDING,4 1/2",X,3.813", HYD563 HES X 3.813 3,583.3 3,453.8 21.12 GAS LIFT 6.473 GLM KBMG,Camco,4 1/2" X 1",H563 SLB Camco KBMG 3.860 5,882.0 5,595.5 21.05 GAS LIFT 6.473 GLM KBMG,Camco,4 1/2" X 1",H563 SLB Camco KBMG 3.860 6,398.3 6,077.2 21.08 GAS LIFT 6.473 GLM KBMG,Camco,4 1/2" X 1",H563 SLB Camco KBMG 3.860 8,129.3 7,337.8 70.77 PACKER 6.620 Baker permanent production packer 4.5" TC-II x 7 5/8" 29# Baker Premier 3.870 8,183.1 7,354.7 72.57 NIPPLE 5.030 NIPPLE,LANDING,4 1/2",X,3.813", HYD563 ***POLISH BORE DAMAGED*** HES X 3.813 8,227.7 7,367.5 74.04 NIPPLE 5.030 NIPPLE,LANDING,4 1/2",3.813" XN, 3.725" No-go HYD563 ***NIPPLED MILLED OUT TO 3.80" PRE-CTD 1/12/20*** HES XN 3.800 8,231.0 7,368.4 74.13 LINER 4.500 CROSSOVER,4 1/2"HYD563 X TXP,BP,24" 3.958 8,232.9 7,368.9 74.18 LINER 4.500 Tubing,4 1/2",12.6#,L80, TXP 3.958 8,941.3 7,484.6 84.20 SHOE 4.500 Orange Peel Shoe (MILLED OUT FROM 1.00" TO 3.70" ON 3/23/2018) 3.700 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,750.0 7,461.3 82.46 4-1/2" BOT Mono-bore XL tray Whipstock 4-1/2" BOT Mono-bore XL tray Whipstock 2/23/2020 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) 3,583.3 3,453.8 21.12 1 GAS LIFT DMY BK 1 0.0 1/13/2019 0.000 5,882.0 5,595.5 21.05 2 GAS LIFT DMY No Latch 1 0.0 2/8/2018 No Latch 0.000 6,398.3 6,077.2 21.08 3 GAS LIFT DMY BK 1 0.0 11/4/2023 0.000 HORIZONTAL, CD5-23, 3/24/2024 8:38:51 AM Vertical schematic (actual) X O 4-1/2" BOT Mono-bore XL tray Whipstock ; 8,750.0 OPEN HOLE; 8,621.0-27,430.0 INTERMEDIATE; 34.0-8,620.8 NIPPLE; 8,227.7 NIPPLE; 8,183.1 PACKER; 8,129.3 GAS LIFT; 6,398.3 GAS LIFT; 5,882.0 GAS LIFT; 3,583.3 SURFACE; 37.0-2,219.6 NIPPLE; 2,070.9 CONDUCTOR; 33.3-115.0 HANGER; 31.0 WNS INJ KB-Grd (ft) 36.55 RR Date 1/24/2018 Other Elev… CD5-23 ... TD Act Btm (ftKB) 27,430.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032076100 Wellbore Status INJ Max Angle & MD Incl (°) 94.15 MD (ftKB) 19,914.56 WELLNAME WELLBORECD5-23 Annotation LAST WO: End DateH2S (ppm) DateComment SSSV: NIPPLE CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD5-23 (PTD 217-155) Date:Tuesday, March 4, 2025 9:39:59 AM Attachments:image001.png AnnComm Surveillance TIO for CD5-23.pdf From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Monday, March 3, 2025 6:52 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: CRU CD5-23 (PTD 217-155) Chris, CRU CD5-23 (PTD 217-155) is a waivered WAG injector (AIO 18E.004). On 3/2/25, the well’s IA exceed the allowable operating pressure of 2,400 psi while on gas injection likely due to a choke change. The max pressure was 2,406 psi, the IA was bled down to 2050 psi and stable. CD5-23 passed an MIT-IA to 4,200 psi on 4/14/2024. The 90 day TIO is attached. CPAI would like to put the well online for a 30-day monitor on gas. Depending on 30-day monitor results, proper notifications will be made as needed. Let me know if you have any questions or disagree with this plan. Thanks, Mark Mark Shulman WNS Well Integrity Engineer ConocoPhillips Alaska Mark.Shulman@conocophillips.com Office (907) 263-3782 Mobile (602) 513-0775 CD5-23 90-Day Bleed HistoryWELL DATE STR-PRES END-PRES DIF-PRES CASING Last Rev Reason Annotation Wellbore End Date Last Mod ByRev Reason: Updated to reflect X-Lock / A-1 fish CD5-23 12/12/2023 famajNotes: General & Safety Annotation End Date Last Mod ByNOTE: COIL MILLED OUT X -LOCK. NIPPLE AT 2070' IS LIKELY COMPRIMISED. SEE ATTACHMENTS. 3/22/2024 rmoore22NOTE: RUNNING NECK AND FISHING SWIVELED OFF DV IN STA #2. WOBBLE RING & SPRING RECOVERED. 2/9/2018 claytgCasing StringsCsg Des OD (in) ID (in) Top (ftKB)Set Depth (ftKB)Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top ThreadCONDUCTOR 20 19.12 33.3 115.0 115.0 94.00 H-40 WeldedSURFACE 10 3/4 9.95 37.0 2,219.6 2,179.0 45.50 L-80 Hyd 563INTERMEDIATE 7 5/8 6.88 34.0 8,620.8 7,444.3 29.70 L80 Hyd563 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 31.0 Set Depth … 8,946.5 Set Depth … 7,485.1 String Max No… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection H563 ID (in) 3.96 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) 31.0 31.0 0.00 HANGER 11.000 FMC 4-1/2" Tubing Hanger H563 FMC TC-EMS 11"x5" 3.958 2,070.9 2,039.2 20.13 NIPPLE 5.030 NIPPLE,LANDING,4 1/2",X,3.813", HYD563 HES X 3.813 3,583.3 3,453.8 21.12 GAS LIFT 6.473 GLM KBMG,Camco,4 1/2" X 1",H563 SLB Camco KBMG 3.860 5,882.0 5,595.5 21.05 GAS LIFT 6.473 GLM KBMG,Camco,4 1/2" X 1",H563 SLB Camco KBMG 3.860 6,398.3 6,077.2 21.08 GAS LIFT 6.473 GLM KBMG,Camco,4 1/2" X 1",H563 SLB Camco KBMG 3.860 8,129.3 7,337.8 70.77 PACKER 6.620 Baker permanent production packer 4.5" TC-II x 7 5/8" 29# Baker Premier 3.870 8,183.1 7,354.7 72.57 NIPPLE 5.030 NIPPLE,LANDING,4 1/2",X,3.813", HYD563 ***POLISH BORE DAMAGED*** HES X 3.813 8,227.7 7,367.5 74.04 NIPPLE 5.030 NIPPLE,LANDING,4 1/2",3.813" XN, 3.725" No-go HYD563 ***NIPPLED MILLED OUT TO 3.80" PRE-CTD 1/12/20*** HES XN 3.800 8,231.0 7,368.4 74.13 LINER 4.500 CROSSOVER,4 1/2"HYD563 X TXP,BP,24" 3.958 8,232.9 7,368.9 74.18 LINER 4.500 Tubing,4 1/2",12.6#,L80, TXP 3.958 8,941.3 7,484.6 84.20 SHOE 4.500 Orange Peel Shoe (MILLED OUT FROM 1.00" TO 3.70" ON 3/23/2018) 3.700 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,750.0 7,461.3 82.46 4-1/2" BOT Mono-bore XL tray Whipstock 4-1/2" BOT Mono-bore XL tray Whipstock 2/23/2020 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) 3,583.3 3,453.8 21.12 1 GAS LIFT DMY BK 1 0.0 1/13/2019 0.000 5,882.0 5,595.5 21.05 2 GAS LIFT DMY No Latch 1 0.0 2/8/2018 No Latch 0.000 6,398.3 6,077.2 21.08 3 GAS LIFT DMY BK 1 0.0 11/4/2023 0.000 HORIZONTAL, CD5-23, 3/24/2024 8:38:51 AMVertical schematic (actual) X O 4-1/2" BOT Mono-bore XL tray Whipstock ; 8,750.0 OPEN HOLE; 8,621.0-27,430.0 INTERMEDIATE; 34.0-8,620.8 NIPPLE; 8,227.7 NIPPLE; 8,183.1 PACKER; 8,129.3 GAS LIFT; 6,398.3 GAS LIFT; 5,882.0 GAS LIFT; 3,583.3 SURFACE; 37.0-2,219.6 NIPPLE; 2,070.9 CONDUCTOR; 33.3-115.0 HANGER; 31.0 WNS INJ KB-Grd (ft)36.55 RR Date1/24/2018 Other Elev…CD5-23...TDAct Btm (ftKB)27,430.0Well AttributesField NameALPINE Wellbore API/UWI501032076100 Wellbore StatusINJ Max Angle & MDIncl (°)94.15 MD (ftKB)19,914.56WELLNAME WELLBORECD5-23AnnotationLAST WO:End DateH2S (ppm) DateCommentSSSV: NIPPLE Originated: Delivered to:5-Jul-24 Alaska Oil & Gas Conservation Commiss 05Jul24-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 CD4-586 50-103-20857-00-00 223-046 Colville River WL TTiX-PPROF FINAL FIELD 3-Mar-24 CD4-536 50-103-20863-00-00 223-079 Colville River WL TTiX-PPROF FINAL FIELD 7-Mar-24 2M-12 50-103-20181-00-00 192-090 Kuparuk River WL SCMT FINAL FIELD 8-Mar-24 1B-16A 50-029-22457-01-00 218-155 Kuparuk River WL RST FINAL FIELD 9-Mar-24 CD4-588 50-103-20853-00-00 223-029 Colville River WL TTiX-PPROF FINAL FIELD 22-Mar-24 CD5-23 50-103-20761-00-00 217-155 Colville River WL Packer Setting FINAL FIELD 24-Mar-24 3F-08 50-029-21464-00-00 185-246 Kuparuk River WL SCMT FINAL FIELD 30-Mar-24 2M-03 50-103-20160-00-00 191-141 Kuparuk River WL SCMT FINAL FIELD 31-Mar-24 2B-14 50-029-21143-00-00 184-111 Kuparuk River WL WFL FINAL FIELD 3-Apr-24 2T-41 50-103-20675-00-00 213-146 Kuparuk River WL PPROF FINAL FIELD 7-Apr-24 MT7-03A 50-103-20830-01-00 223-084 Greater Mooses Tooth WL TTiX-Fiber FINAL FIELD 22-May-24 MT7-01 50-103-20832-00-00 221052 Greater Mooses Tooth WL TTiX-Fiber FINAL FIELD 27-May-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 T39122 T39123 T39124 T39125 T39126 T39127 T39128 T39129 T39130 T39131 T39132 T39133 CD5-23 50-103-20761-00-00 217-155 Colville River WL Packer Setting FINAL FIELD 24-Mar-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.05 10:30:21 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, May 22, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD5-23 COLVILLE RIV UNIT CD5-23 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/22/2024 CD5-23 50-103-20761-00-00 217-155-0 W SPT 7338 2171550 4000 1897 1897 1897 1897 150 160 160 160 REQVAR P Brian Bixby 4/14/2024 MITIA to MAIP as per AIO 18E.004 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:COLVILLE RIV UNIT CD5-23 Inspection Date: Tubing OA Packer Depth 700 4200 4120 4100IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB240415154810 BBL Pumped:3.5 BBL Returned:3.5 Wednesday, May 22, 2024 Page 1 of 1           CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD5-23(PTD# 217-155) IA Suspect Date:Wednesday, May 1, 2024 8:20:29 AM From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Tuesday, April 30, 2024 3:58 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: CRU CD5-23(PTD# 217-155) IA Suspect Chris, The 30-day monitor on CD5-23 will finish tomorrow (May 1st). The well is stable and has passed a MIT-IA. CPAI will return the well to its waivered status. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Senior Well Integrity Engineer ConocoPhillips Alaska | AK Intervention & Integrity O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com From: WNS Integrity Sent: Thursday, November 16, 2023 10:20 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU CD5-23(PTD# 217-155) IA Suspect Chris, Additional diagnostics have been completed. CPAI would like to bring the well online for a 30-day monitor on water. Depending on 30-day monitor results, proper notifications will be made as needed. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Senior Well Integrity Engineer ConocoPhillips Alaska | AK Intervention & Integrity O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com From: WNS Integrity Sent: Tuesday, August 22, 2023 3:30 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD5-23(PTD# 217-155) IA Suspect Chris, CRU CD5-23 (PTD# 217-155) is failing a diagnostic MIT-IA. The well has been shut it and initial diagnostics are ongoing. Depending on results, proper notifications will be made as needed. Attached is the 90 day TIO plot and wellbore schematic. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Senior Well Integrity Engineer ConocoPhillips Alaska | Wells Engineering O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD5-23(PTD# 217-155) IA Suspect Date:Monday, November 20, 2023 9:34:26 AM From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Thursday, November 16, 2023 10:20 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU CD5-23(PTD# 217-155) IA Suspect Chris, Additional diagnostics have been completed. CPAI would like to bring the well online for a 30-day monitor on water. Depending on 30-day monitor results, proper notifications will be made as needed. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Senior Well Integrity Engineer ConocoPhillips Alaska | AK Intervention & Integrity O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com From: WNS Integrity Sent: Tuesday, August 22, 2023 3:30 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD5-23(PTD# 217-155) IA Suspect Chris, CRU CD5-23 (PTD# 217-155) is failing a diagnostic MIT-IA. The well has been shut it and initial diagnostics are ongoing. Depending on results, proper notifications will be made as needed. Attached is the 90 day TIO plot and wellbore schematic. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Senior Well Integrity Engineer C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-10-05_25950_CRU_CD5-23_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15950 CRU CD5-23 50-103-20761-00 LeakPoint Survey 05-Oct-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 217-155 T38045 10/11/2023 Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.11 08:45:51 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-09-27_21168_CRU_CD5-23_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21168 CRU CD5-23 50-103-20761-00 Caliper Survey w/ Log Data 27-Sep-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 217-155 T38025 10/3/2023 Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.03 10:47:34 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD5-23(PTD# 217-155) IA Suspect Date:Tuesday, August 22, 2023 4:06:04 PM Attachments:AnnComm Surveillance TIO for CD5-23.pdf From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Tuesday, August 22, 2023 3:30 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD5-23(PTD# 217-155) IA Suspect Chris, CRU CD5-23 (PTD# 217-155) is failing a diagnostic MIT-IA. The well has been shut it and initial diagnostics are ongoing. Depending on results, proper notifications will be made as needed. Attached is the 90 day TIO plot and wellbore schematic. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Senior Well Integrity Engineer ConocoPhillips Alaska | Wells Engineering O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com CD5-23 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING CD5-23 2023-06-26 2160.0 900 -1260.0 IA CD5-23 2023-06-27 2170.0 1080 -1090.0 IA CD5-23 2023-07-09 999.0 617 -382.0 OA CD5-23 2023-07-12 2215.0 1975 -240.0 IA CD5-23 2023-08-08 2066.0 1553 -513.0 IA Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Circ out w/brine, Pull/Set Injection Valve CD5-23 5/6/2023 rmoore22 Notes: General & Safety Annotation End Date Last Mod By NOTE: CONVERTED f/ PROD TO INJECTOR 1/16/2019 claytg NOTE: RUNNING NECK AND FISHING SWIVELED OFF DV IN STA #2. WOBBLE RING & SPRING RECOVERED. 2/9/2018 claytg 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 20 19.12 33.3 115.0 115.0 94.00 H-40 Welded SURFACE 10 3/4 9.95 37.0 2,219.6 2,179.0 45.50 L-80 Hyd 563 INTERMEDIATE 7 5/8 6.88 34.0 8,620.8 7,444.3 29.70 L80 Hyd563 Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 31.0 Set Depth … 8,946.5 Set Depth … 7,485.1 String Ma… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection H563 ID (in) 3.96 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) 31.0 31.0 0.00 HANGER 11.000 FMC 4-1/2" Tubing Hanger H563 FMC TC-EMS 11"x5" 3.958 2,070.9 2,039.2 20.13 NIPPLE 5.030 NIPPLE,LANDING,4 1/2",X,3.813", HYD563 HES X 3.813 3,583.3 3,453.8 21.12 GAS LIFT 6.473 GLM KBMG,Camco,4 1/2" X 1",H563 SLB Camco KBMG 3.860 5,882.0 5,595.5 21.05 GAS LIFT 6.473 GLM KBMG,Camco,4 1/2" X 1",H563 SLB Camco KBMG 3.860 6,398.3 6,077.2 21.08 GAS LIFT 6.473 GLM KBMG,Camco,4 1/2" X 1",H563 SLB Camco KBMG 3.860 8,129.3 7,337.8 70.77 PACKER 6.620 Baker permanent production packer 4.5" TC-II x 7 5/8" 29# Baker Premier 3.870 8,183.1 7,354.7 72.57 NIPPLE 5.030 NIPPLE,LANDING,4 1/2",X,3.813", HYD563 ***POLISH BORE DAMAGED*** HES X 3.813 8,227.7 7,367.5 74.04 NIPPLE 5.030 NIPPLE,LANDING,4 1/2",3.813" XN, 3.725" No-go HYD563 ***NIPPLED MILLED OUT TO 3.80" PRE-CTD 1/12/20*** HES XN 3.800 8,231.0 7,368.4 74.13 LINER 4.500 CROSSOVER,4 1/2"HYD563 X TXP,BP,24" 3.958 8,232.9 7,368.9 74.18 LINER 4.500 Tubing,4 1/2",12.6#,L80, TXP 3.958 8,941.3 7,484.6 84.20 SHOE 4.500 Orange Peel Shoe (MILLED OUT FROM 1.00" TO 3.70" ON 3/23/2018) 3.700 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) 2,070.9 2,039.2 20.13 INJ VALVE 4.5" MCX INJ VALVE (SN:4281676-3 w/ 1.563" BEAN) ON 3.813" X-LOCK 5/5/2023 1.563 8,750.0 7,461.3 82.46 4-1/2" BOT Mono-bore XL tray Whipstock 4-1/2" BOT Mono-bore XL tray Whipstock 2/23/2020 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) 3,583.3 3,453.8 21.12 1 GAS LIFT DMY BK-5 1 1/13/2019 Schlumb erger Camco BK-5 5,882.0 5,595.5 21.05 2 GAS LIFT DMY BK-5 1 1/21/2018 No Latch Schlumb erger Camco BK-5 6,398.3 6,077.2 21.08 3 GAS LIFT DMY BK-5 1 6/20/2020 Schlumb erger Camco DCK-2 HORIZONTAL, CD5-23, 6/11/2023 5:32:01 PM Vertical schematic (actual) X O 4-1/2" BOT Mono-bore XL tray Whipstock ; 8,750.0 OPEN HOLE; 8,621.0-27,430.0 INTERMEDIATE; 34.0-8,620.8 NIPPLE; 8,227.7 NIPPLE; 8,183.1 PACKER; 8,129.3 GAS LIFT; 6,398.3 GAS LIFT; 5,882.0 GAS LIFT; 3,583.3 SURFACE; 37.0-2,219.6 INJ VALVE; 2,070.9 NIPPLE; 2,070.9 CONDUCTOR; 33.3-115.0 HANGER; 31.0 WNS INJ KB-Grd (ft) 36.55 RR Date 1/24/2018 Other Elev… CD5-23 ... TD Act Btm (ftKB) 27,430.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032076100 Wellbore Status INJ Max Angle & MD Incl (°) 94.15 MD (ftKB) 19,914.56 WELLNAME WELLBORECD5-23 Annotation LAST WO: End DateH2S (ppm) DateComment SSSV: NIPPLE 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. You don't often get email from wnsintegrity@conocophillips.com. Learn why this is important From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD5-23 (PTD#217-155-0) high IA pressure update Date:Wednesday, February 22, 2023 8:28:58 AM Attachments:image001.png From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Tuesday, February 21, 2023 4:59 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU CD5-23 (PTD#217-155-0) high IA pressure update Chris- CRU CD5-23 (PTD # 217-155-0) has completed the 30 day monitor period. An AA application has been submitted to allow for continued water and gas injection with known TxIA communication. CPAI intends to keep the well online during the application process. Please let me know if you have any questions or disagree with the plan. Thanks, Kate Dodson | Well Integrity Specalist ConocoPhillips Alaska | Wells Engineering O: 907-265-6181 | M: 435-640-7200 | WNSIntegrity@conocophillips.com From: Well Integrity Specialist CPF2 Sent: Friday, January 13, 2023 9:59 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: RE: CRU CD5-23 (PTD#217-155-0) high IA pressure update Chris- CPAI has discovered a significant benefit to maintaining gas injection into CRU CD5-23 (PTD # 217- 155-0) and will be pursuing an AA to allow both water and gas injection with known TxIA communication while injecting gas. CPAI intends to perform the diagnostics required to meet the CPAI criteria for this type of waiver. While doing so, the well will remain on water injection until it is changed to gas injection for a 30 day monitor period to ensure the IA will remain under the “do not exceed” pressure. At the completion of the diagnostics and monitor period, CPAI will submit the AA application, if the criteria is met, for continued water and gas injection with known TxIA communication. If the criteria is not met, an AA application for continued water injection only will be submitted at that time. Attached is a copy of the current 90 day TIO plot and well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Smith, Travis T Sent: Monday, February 7, 2022 2:59 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD5-23 (PTD#217-155-0) High IA Pressure Chris— CRU well CD5-23 (PTD#217-155-0) has exhibited TxIA communication while on MI injection. Our intent is to WAG the well back to water injection for a 30-day monitoring period as soon as practical. While on water injection service we will conduct standard DHD diagnostics. Based on these results we will propose a path forward to either waiver the well for water-only injection service or attempt a repair to return the well to WAG injection service. Please let me know if you have any questions or disagree with the plan. Travis Smith WNS Intervention & Integrity Engineer 907-670-4014 Travis.T.Smith@conocophillips.com CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD5-23 (PTD#217-155-0) high IA pressure update Date:Tuesday, January 17, 2023 8:30:43 AM Attachments:image001.png AnnComm Surveillance TIO for CD5-23.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Friday, January 13, 2023 9:59 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: RE: CRU CD5-23 (PTD#217-155-0) high IA pressure update Chris- CPAI has discovered a significant benefit to maintaining gas injection into CRU CD5-23 (PTD # 217- 155-0) and will be pursuing an AA to allow both water and gas injection with known TxIA communication while injecting gas. CPAI intends to perform the diagnostics required to meet the CPAI criteria for this type of waiver. While doing so, the well will remain on water injection until it is changed to gas injection for a 30 day monitor period to ensure the IA will remain under the “do not exceed” pressure. At the completion of the diagnostics and monitor period, CPAI will submit the AA application, if the criteria is met, for continued water and gas injection with known TxIA communication. If the criteria is not met, an AA application for continued water injection only will be submitted at that time. Attached is a copy of the current 90 day TIO plot and well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Smith, Travis T Sent: Monday, February 7, 2022 2:59 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD5-23 (PTD#217-155-0) High IA Pressure Chris— CRU well CD5-23 (PTD#217-155-0) has exhibited TxIA communication while on MI injection. Our intent is to WAG the well back to water injection for a 30-day monitoring period as soon as practical. While on water injection service we will conduct standard DHD diagnostics. Based on these results we will propose a path forward to either waiver the well for water-only injection service or attempt a repair to return the well to WAG injection service. Please let me know if you have any questions or disagree with the plan. Travis Smith WNS Intervention & Integrity Engineer 907-670-4014 Travis.T.Smith@conocophillips.com I (46ap) aanleJadlUBLL (LSd] ajnssaAd W=Osw An Od9) a;ea E-1-10-EZOZ 0I -10-E 2O Z LO-ZO-EZOZ bO-iO-EZOZ IO-[O-EZOZ 6Z-Zi-ZZOZ 9Z-Fi-F20Z EZ-Zi-ZZOZ OZ-Zi-ZZOZ LI-Zi-ZZOZ tri-Zi-2Z0Z it-Fi-2202 ac-Zi-ZZOZ SO-Zi-ZZOZ ZO-Zi-22OZ 6Z-11-EZOZ v 9Z-ii-ZZOZ £Z-ii-2ZOZ a.z-ii-Fzaz Ll -ii -2202 VT-ii-ZZOZ I L-ii-ZZOZ 80 -ii -2202 SO-ii-Z.ZOZ ZO-ii-ZZOZ OS-Oi-LZOZ LZ-Oi-ZZOZ bZ-Oi-220Z iZ-Oi-ZZOZ SI-Oi-ZZOZ 5I-OL-22OZ O O O O O O O C1 O O (LSd] ajnssaAd W=Osw An Od9) a;ea E-1-10-EZOZ 0I -10-E 2O Z LO-ZO-EZOZ bO-iO-EZOZ IO-[O-EZOZ 6Z-Zi-ZZOZ 9Z-Fi-F20Z EZ-Zi-ZZOZ OZ-Zi-ZZOZ LI-Zi-ZZOZ tri-Zi-2Z0Z it-Fi-2202 ac-Zi-ZZOZ SO-Zi-ZZOZ ZO-Zi-22OZ 6Z-11-EZOZ v 9Z-ii-ZZOZ £Z-ii-2ZOZ a.z-ii-Fzaz Ll -ii -2202 VT-ii-ZZOZ I L-ii-ZZOZ 80 -ii -2202 SO-ii-Z.ZOZ ZO-ii-ZZOZ OS-Oi-LZOZ LZ-Oi-ZZOZ bZ-Oi-220Z iZ-Oi-ZZOZ SI-Oi-ZZOZ 5I-OL-22OZ CONDUCTOR: 0As LIFT OPEN W ELLS WNS INJ WELLNAME CDS-23 WELLBORE CDS-23 Well Attributes I Max AngleB MD TO FIeN Name WNIboreAPWWI Wellhore Statue Icl (°) Mn(IIKBI MBtm(ftKB) ALPINE 1 207 1 IN .15 19,914.56 2],430.0 CommentX35(ppm) Gate MmiNicn End DNe KBGN (11)RR Date o1M1erEle- LASTWO 3655 112412018 Annotation W.Man, End Data Last Mod By Rev Reason: Set Gauges 1 QU,15 1 101142022 Oben Notes: General S Safety Annotation Ena Dale LutMM ey NOTE'. CONVERTED V PROD TO INJECTOR 111fi12019 claylg NOTE. RUNNING NECK AND FISHING SWIVELED OFF DV IN STA#2. WOBBLE RING 8 SPRING &912018 claytg RECOVERED. Casing Strings Cai,q Descnptim OD lin) ID lin) Tap lflKBl SN CeptM1 16.. set DeptR.. Ilii 11Wft1 Orale Top CcnnMion CONDUCTOR 20 19.12 33.3 115.0 115.0 94.00 H40 Welded "'I'SDescriplicn OD (in) ID (int Tap(.KB1 Set E -i lft... Set 13.0h .. WHLenllWftl Grade Top Connection SURFACE 10314 9.95 3].0 2,219.6 2,179.0 45.50 LA0 Hyd 563 Casing DescripOm OD(m) ID (in? Tap IXKEN unpin IM1... Depin whLen(IWrt) Come TopCmnxtion INTERMEDIATE 7m I ka ] 518 6.88 34.0 8,620.8 ],444.3 29.70 L80 Hyd5fi3 Tubing Strings: string max indicates LONGEST segment of string Top lrtKe) set Depth... siring Ma._ Tuemg Description sot Depth lftlush W10Wft) Doae Top conn ID (in) 31.0 ],485.1 4112 Tubing -Production 8,946.5 12.60 L-80 HSfi3 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... 00 Top ITVD) Toping Nominal Top ItIKB) IXu.) 11 Xem Des (in) Com Make Model ID (I.) 31.0 31.0 0.00 HANGER 11.000 FMC 4-112' Tubing Hanger H563 FMC TC -EMS 3.958 11"x5" 2,070.9 2,039.2 20.13 NIPPLE 5.030 NIPPLELANDING,41Z,X,3.81T% HES X 3.813 HYD5fi3 3,583.3 3,453.8 2112 GAS LIFT 6.473 GLM KBMG,Camw,4112" X SLB KBMG 3.860 1',1563 Camco 5,882.0 5,595.5 21.05 GAS LIFT 6.473 GLM KBMG,Camw,4112" X SLB KBMG 3.860 1',1563 Camco 6,398.3 6,077.2 21.08 GAS LIFT 6.473 GLM KBMG,Camw,4112" X SLB KBMG 3.860 1',1563 Camco 8,129.3 7,337.8 70.77 PACKER 6.620 Baker permanent production packer Baker Premier 3.870 4.5"T611 x]518"29# 6,183.1 7,3543 72.57 NIPPLE 5.030 NIPPLETANDING,417',X,3.813", HES X 3.813 HYD563 -POLISH BORE DAMAGED"" 8,22].] ],36].5 74.04 NIPPLE 5.030 NIPPLE,LANDING,4112",3.813"XN, HES XN 3.800 3.]25" Nolo HYD563 "'NIPPLED MILLED OUT TO 3.80" PRE -CTD 1112120"` 8,231.0 7,368.4 74.13 LINER 4.500 CROSSOVER,4112'HYD563 X 3.958 TXP,BP,24" 8,232.9 7,368.9 74.18 LINER 4.500 Tubing,4112",12.69,LBO, TXP 3.958 8,941.3 7,484.6 84.20 SHOE 4.500 Orange Peel Shoe (MILLED OUT 3.700 FROM 1.00" TO 3.70" ON 312312018) Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top ITVD) Tap(ftKB) (ftKR) Topincll°) Dea Com Make Mctlel SN mlln) 8,183.1 7,3543 72.58 GAUGES 3.813'X -lock (no packing) Flow Sparked 80640 0.000 Thm Sub, Shock, Dual Gauges I 08093 4 8,750.0 7,461.3 82.46 4 -la' BOT 4-1YY'BOT Monti XL tray Mono -bore XL Whipstock tray Whipstock Mandrel Inserts : excludes pulled inserts s aI TOp5K.3 TOMB) Top Incg2 o^ No Valve LartachTYPw Type OD (ln) TRO Run Ipsq RunFarmCom Make MOtlN Not Ste lin) 3,583.3 3,453.8 3,46 21.12 LI GAS LIFT MY DMV BKS 1 111312019 Schlumb BNS eager Cando 5,882.0 5,595.5 21.05 2 GAS LIFT DMV BKS 1 112112018 No Schlumb BKS Latch erger Camco 6,398.3 6,OT7.2 21.08 3 GAS LIFT DMV BKS 1 &'2012020 Schlumb UCK-2 similar Camco CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD5-23 (PTD#217-155-0) High IA Pressure Date:Tuesday, February 15, 2022 8:11:17 AM From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Tuesday, February 15, 2022 7:52 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU CD5-23 (PTD#217-155-0) High IA Pressure Chris— An update on CRU well CD5-23 (PTD#217-155-0). The well was WAG’d to water injection and DHD performed diagnostics per the below plan. The MITIA failed, and the well has been shut-in and freeze-protected. We will perform further diagnostics and notify you with the appropriate paperwork when we are prepared with a path forward to repair the well. Please let me know if you have any questions or disagree with the plan. Thanks, Travis From: Smith, Travis T Sent: Monday, February 7, 2022 2:59 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD5-23 (PTD#217-155-0) High IA Pressure Chris— CRU well CD5-23 (PTD#217-155-0) has exhibited TxIA communication while on MI injection. Our intent is to WAG the well back to water injection for a 30-day monitoring period as soon as practical. While on water injection service we will conduct standard DHD diagnostics. Based on these results we will propose a path forward to either waiver the well for water-only injection service or attempt a repair to return the well to WAG injection service. Please let me know if you have any questions or disagree with the plan. Travis Smith WNS Intervention & Integrity Engineer 907-670-4014 Travis.T.Smith@conocophillips.com Wallace, Chris D (CED) From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Friday, April 16, 2021 1:44 PM To: Wallace, Chris D (CED) Cc: Earhart, Will C Subject: RE: CRU injector CD5-23 (PTD# 217-155-0) Attachments: CD5-23 90 -Day TIO.pdf -� Chris— CRU injector CD5-23 (PTD# 217-155-0) completed the extended monitoring period today. The IA behavior has not exhibited problematic behavior. Our intent is to return the well to Normal status, and manage it through our standard process for WAG injectors. A 90 -day TIO plot is attached. Please let me know if you have any questions or disagree with the plan forward. Thanks, Travis From: Smith, Travis T Sent: Tuesday, March 16, 202110:37 AM To: 'Wallace, Chris D (DOA)' <chris.waIlace @alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU injector CD5-23 (PTD# 217-155-0) Chris— CRU injector CD5-23 (PTD# 217-155-0) was WAG'd to MI injection on February 15, 2021. Per our earlier communication, it was placed on a 30 -day monitoring period during this next MI cycle to watch for signs of IA pressurization. Thus far, the IA has not exhibited problematic behavior. Gradually increasing injection rates, however, did necessitate a thermal/rate related bleed of the IA during the monitoring period. Our intent is to extend the monitoring period by another 30 -days to confirm the pressure is indeed stable. If communication is evident the well will be shut in. Please let me know if you have any questions or disagree with the plan forward. Thanks, Travis Travis Smith WNS Intervention & Integrity Engineer 907-659-4014 Travis.T.Smith@conocophillips.com Wallace, Chris D (CED) From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Tuesday, March 16, 2021 10:37 AM To: Wallace, Chris D (CED) Cc: Earhart, Will C Subject: CRU injector CD5-23 (PTD# 217-155-0) Chris— CRU injector CD5-23 (PTD# 217-155-0) was WAG'd to MI injection on February 15, 2021. Per our earlier communication, it was placed on a 30 -day monitoring period during this next MI cycle to watch for signs of IA pressurization. Thus far, the IA has not exhibited problematic behavior. Gradually increasing injection rates, however, did necessitate a thermal/rate related bleed of the IA during the monitoring period. Our intent is to extend the monitoring period by another 30 -days to confirm the pressure is indeed stable. If communication is evident the well will be shut in. Please let me know if you have any questions or disagree with the plan forward. Thanks, Travis Travis Smith WNS Intervention & Integrity Engineer 907-659-4014 Travis.T.Smith@conocophillips.com Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Saturday, August 1, 2020 3:08 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: RE: CRU MI CD5-23 (PTD 217-155) Update on Suspect IA Pressurization Attachments: CD5-23.pdf,, CD5-23 90 Day TIO Plot 8-1-20.pdf Chris, CRU injector CD5-23 (PTD 217-155) has been on a 30 day monitor on water injection to see if the IA would exhibit signs of communication following a failing MITIA on 5/27/20 and subsequent diagnostics that could not find a communication path. During this water injection monitor, the IA showed no signs of communication; its fluctuations were all thermally - induced. It is our intention to put the well on a 30 day monitor while on MI injection to see if the IA exhibits signs of communication. The well will remain on water injection until MI makes sense within the voidage management plan for the area. Attached are the 90 day TIO plot and schematic. Please let me know if you have any questions or disagree with the path forward. Regards, Stephanie Pilch / alt: Sara Carlisle CPF3 & Alpine Well Integrity & Compliance Specialist ConocoPhillips Alaska Office: (907) 659-7126 From: Well Integrity Compliance Specialist WNS & CPF3 t: Tuesday, June 23, 2020 9:17 AM To: Walace, Chris D (CED) <chris.wallace @alaska.gov> Cc: CPA Weks Supt <n1030@conocophillips.com> Subject: CRU D5-23 (PTD 217-155) Update on Suspect IA Pressurization Good Morning Chris, Work began last week to set up CRU CD - (PTD 217-155) for logging and diagnostics to identify the source of the failed MIT -IA on 5/27/20. In attempts to secure well with a tubing plug, we repeated an MIT -T and MIT -IA for diagnostic purposes and both tests passed. We procekled to open a GLM pocket as a circulation point and bullhead down the IA to verify no blockage existed causing the previo failed MIT -IA to pass. This was successful, and an MIT -IA was repeated and passed to 3300 psi. We would like to progress logging to identify the source of the failing MIT-IA;lwever, we cannot log if the well is not exhibiting annular communication. Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Tuesday, June 23, 2020 9:17 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: CRU MI CD5-23 (PTD 217-155) Update on Suspect IA Pressurization Attachments: CD5-23 90 -Day TIO 6.23.20.pdf; CD5-23.pdf,, CD5-23 10-426 6.20.20.xlsx Good Morning Chris, Work began last week to set up CRU CD5-23 (PTD 217-155) for logging and diagnostics to identify the source of the failed MIT -IA on 5/27/20. In attempts to secure the well with a tubing plug, we repeated an MIT -T and MIT -IA for diagnostic purposes and both tests passed. We proceeded to open a GLM pocket as a circulation point and bullhead down the IA to verify no blockage existed causing the previously failed MIT -IA to pass. This was successful, and an MIT -IA was repeated and passed to 3300 psi. We would like to progress logging to identify the source of the failing MIT -IA; However, we cannot log if the well is not exhibiting annular communication. If a leak exists, it is possibly thermally activated, so CPA[ intends to bring the well online in water -only injection service for a 30 -day monitor period to verify if the IA pressurization still exists. If the IA pressurizes, we intend to repeat the MIT -IA while online, and will then immediately shut in the well if it fails. If a failing MIT -IA occurs, the plan would be to organize the logistics to get the well ready to log, return the well to injection for the purpose of activating the leak, log, then shut the well back in. If the MIT -IA passes or does not exhibit further pressurization, we will update you with a plan forward at the end of the monitor period. Please let me know if you have any questions or disagree with the path forward. I've attached the most recent passing MIT -IA, schematic, and 90 -day TIO plot. Sincerely, ,Sa-ralCcE,YI P Ofejkrw) I stPpha+u& Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n25490cop.com Cell: 907-331-7514 1 sara.e.carlisle0con com From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Thursday, May 28, 2020 5:26 PM To: Wallace, Chris D (CED) <chris.waIlace @alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: RE: CRU MI CD5-23 (PTD 217-155) Report of Suspect IA Pressurization Chris, Yesterday CRU CD5-23 (PTD 217-155) failed its MITIA. It was shut in and freeze protected. Our plan is to pursue diagnostics to locate and repair the leak. Please let me know if you have any questions or disagree with the plan forward. Attached are the schematic and 90 day TIO trend. Regards, Stephanie Pilch / alt: Sara Carlisle CPF3 & Alpine Well Integrity & Compliance Specialist ConocoPhillips Alaska Office: (907) 659-7126 From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Monday, May 25, 2020 8:50 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: CPA Wells Supt <n1030taconocophillips.com> Subject: RE: CRU MI CD5-23 (PTD 217-155) Report of Suspect IA Pressurization Good Evening Chris, The ongoing monitor on CRU MI injector CD5-23 (PTD 217-155) has shown that the IA pressure trend is deviating from thermal trends. We intend to WAG the well to water as a result of evident TxIA communication while in gas -injection service. We're mobilizing DHD to Alpine tomorrow and intend to finish diagnostics on the well before converting it to water injection so that we can perform diagnostics in the state that it's presently leaking. As soon as these diagnostics are complete (we expect within the week), the well will be WAG'd to water and will being a 30 -day monitor. Please let us know if you have any questions or disagree with the plan forward. Attached is a schematic and 90 -day TIO. Sincerely, Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhil►ipsAlaska Office: 907-659-7126 1 n2549Pcon com Cell: 907-331-7514 1 sara.e.carlisleCilcop com From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Sunday, May 17, 2020 7:25 PM To: Wallace, Chris D (CED) <chris.wallacePalaska.gov>; CPA Wells Supt <n1030Pconocophillips.com> Subject: CRU MI CD5-23 (PTD 217-155) Report of Suspect IA Pressurization Good Evening Chris, CRU MI injector CD5-23 (PTD 217-155) has been observed to have suspect IA pressurization while in gas injection service. CPAI intends to bleed the inner annulus pressure, perform initial diagnostics, and conduct a 30 -day monitor to understand if the pressurization is thermal in nature. If the pressure trend clearly deviates from thermal behavior during the monitor, the well will be converted to water injection service for a 30 -day monitor (or shut in if operationally necessary) and an update on the plan forward for diagnostics/repair will be sent at that time. Please let us know if you have any questions or disagree with the plan forward. Attached is a schematic and 90 -day TIO. Sincerely, Sa-wCasrUsI& (j'fwAitv) I stP.pha eif Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549@cop.com Cell: 907-331-7514 1 sara.e.carlisle@col2.com Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WINS & CPF3 <n2549@conocophillips.com> Sent: Thursday, May 28, 2020 5:26 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: RE: CRU MI CD5-23 (PTD 217-155) Report of Suspect IA Pressurization Attachments: CD5-23 Schematic.pdf, CD5-23 90 Day TIO 5-28-20.pdf Chris, Yesterday CRU CD5-23 (PTD 217-155) failed its MITIA. It was shut in and freeze protected. Our plan is to pursue diagnostics to locate and repair the leak. Please let me know if you have any questions or disagree with the plan forward. Attached are the schematic and 90 day TIO trend. Regards, Stephanie Pilch / alt: Sara Carlisle CPF3 & Alpine Well Integrity & Compliance Specialist ConocoPhillips Alaska Office: (907) 659-7126 From: Well Integrity Compliance Specialist WINS & CPF3 Sent: Monday, May 25, 2020 8:50 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: RE: CRU MI CD5-23 (PTD 217-155) Report of Suspect IA Pressurization Good Evening Chris, The ongoing monitor on CRU MI injector CD5-23 (PTD 217-155) has shown that the IA pressure trend is deviating from thermal trends. We intend to WAG the well to water as a result of evident TxIA communication while in gas -injection service. We're mobilizing DHD to Alpine tomorrow and intend to finish diagnostics on the well before converting it to water injection so that we can perform diagnostics in the state that it's presently leaking. As soon as these diagnostics are complete (we expect within the week), the well will be WAG'd to water and will being a 30 -day monitor. Please let us know if you have any questions or disagree with the plan forward. Attached is a schematic and 90 -day TIO. Sincerely, Scwa1Ca,rUA&0("k4v)/St-e-pt'LameU Pddv Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549(@cop.com Cell: 907-331-7514 1 sara.e.carlisleRcop.com From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Sunday, May 17, 2020 7:25 PM To: Wallace, Chris D (CED) <chris.waIlace @alaska.¢ov>; CPA Wells Supt <n1030@conocophillips.com> Subject: CRU MI CD5-23 (PTD 217-155) Report of Suspect IA Pressurization Good Evening Chris, CRU MI injector CDS-23 (PTD 217-155) has been observed to have suspect IA pressurization while in gas injection service. CPAI intends to bleed the inner annulus pressure, perform initial diagnostics, and conduct a 30 -day monitor to understand if the pressurization is thermal in nature. If the pressure trend clearly deviates from thermal behavior during the monitor, the well will be converted to water injection service for a 30 -day monitor (or shut in if operationally necessary) and an update on the plan forward for diagnostics/repair will be sent at that time. Please let us know if you have any questions or disagree with the plan forward. Attached is a schematic and 90 -day TIO. Sincerely, SarcvCa i&j1&(}fe4kifv) /StP.Pha4U.PiMJV Well Integrity & Compliance Specialist, WINS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549@co .com Cell: 907-331-7514 1 sara.e.carlisle@cop.com Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Monday, May 25, 2020 8:50 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: RE: CRU MI CD5-23 (PTD 217-155) Report of Suspect IA Pressurization Attachments: CD5-23.pdf; CD5-23 90 -Day TIO S.25.20.pdf Good Evening Chris, The ongoing monitor on CRU MI injector CD5-23 (PTD 217-155) has shown that the IA pressure trend is deviating from thermal trends. We intend to WAG the well to water as a result of evident TxIA communication while in gas -injection service. We're mobilizing DHD to Alpine tomorrow and intend to finish diagnostics on the well before converting it to water injection so that we can perform diagnostics in the state that it's presently leaking. As soon as these diagnostics are complete (we expect within the week), the well will be WAG'd to water and will being a 30 -day monitor. Please let us know if you have any questions or disagree with the plan forward. Attached is a schematic and 90 -day TIO. Sincerely, Scwa,Cm-Usle/ (HeskCw) /St-epha4'1 P PdCk Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549Cc�cop corn Cell: 907-331-7514 1 sara.e.carlisleC@cop.com From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Sunday, May 17, 2020 7:25 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov>; CPA Wells Supt <n1030@conocophillips.com> Subject: CRU MI C135-23 (PTD 217-155) Report of Suspect IA Pressurization Good Evening Chris, CRU MI injector CD5-23 (PTD 217-155) has been observed to have suspect IA pressurization while in gas injection service. CPAI intends to bleed the inner annulus pressure, perform initial diagnostics, and conduct a 30 -day monitor to understand if the pressurization is thermal in nature. If the pressure trend clearly deviates from thermal behavior during the monitor, the well will be converted to water injection service for a 30 -day monitor (or shut in if operationally necessary) and an update on the plan forward for diagnostics/repair will be sent at that time. Please let us know if you have any questions or disagree with the plan forward. Attached is a schematic and 90 -day TIO. Sincerely, Scwa, Ca rbt 9& (}Ee4k6w) / stepha sM, t a clv Well Integrity & Compliance Specialist, WNS & CPF3 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Sunday, May 17, 2020 7:25 PM To: Wallace, Chris D (CED); CPA Wells Supt Subject: CRU MI CD5-23 (PTD 217-155) Report of Suspect IA Pressurization Attachments: CD5-23.pdf, CD5-23 90 -Day TIO 5.17.20.pdf Good Evening Chris, CRU MI injector CD5-23 (PTD 217-155) has been observed to have suspect IA pressurization while in gas injection service. CPAI intends to bleed the inner annulus pressure, perform initial diagnostics, and conduct a 30 -day monitor to understand if the pressurization is thermal in nature. If the pressure trend clearly deviates from thermal behavior during the monitor, the well will be converted to water injection service for a 30 -day monitor (or shut in if operationally necessary) and an update on the plan forward for diagnostics/repair will be sent at that time. Please let us know if you have any questions or disagree with the plan forward. Attached is a schematic and 90 -day TIO. Sincerely, Scwa, Ca rUil& (HeOi*0 / Stepl' a+vY & Padv Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n25490cop.com Cell: 907-331-7514 1 sara.e.carlisle@cop.com Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Tuesday, April 21, 2020 6:05 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: CRU CD5-23 (PTD 217-155) Report of OA Sustained Casing Pressure Attachments: CD5-23 90 -Day TIO.pdf, CD5-23.pdf Dear Chris, CRU MI injector CD5-23 (PTD 217-155) was recently reported to have an OA pressure of 1068 psi on 4/19/20. We believe the recent pressurization is due to recent increased injection temperatures and intend for the well to remain online. Operations has bled the OA pressure and it is presently at 300 psi. The 10-3/4" 45.5 Ib/ft. L-80 surface casing has a burst rating of 5210 psi (45% is 2344 psi). A 90 -day TIO trend and wellbore schematic are attached. Please let us know if you disagree or have any questions with this plan. Sincerely, Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n25490cop.com Cell: 907-331-7514 1 sara.e.carlisle0cop.com ! " # " $ %& ' ()! * '$ +, !- ., +, /0/10*- 0 2+ - " ' $ /*3450 ! *3550 ! % $ /*3450 63/. *3550 *3556 !2 !2 + 733 -4188 ,#60 63.4*89$ *34618:$ ; :+ '3 -<% #=<% % 9!%! $>)!63/.89$ *35568:$9$/ B7 ' ) + - 5 B 1" ; $ ' " %& ' $ , ' (" ; C "$, C C)!D >,>C '!!2 %& D !C 7 $% % .0*#/(5#41.* 5 =&005(033 ; ..10 10#05#/0*(#00#00 6"!! %,< ,<),!$C!% :)!99))! / ! ;3)4" ="; 1 $ ! ! ; "#$ % %&' $( ) * +,$ $,- $. + $ $ D; /0-#& "# !$> 6/ /0 88 189$ 18 )!% 9%$)% 6316* *12688 63(/89$ *4448 > % /365 052488 /3//089$ /*.8 !2 $ ' )E $ 9 : # 1001 # 066 56/( 4 +B /0/10*03/10*3F/1/65- #= C #9 " #= # # .16 *.0 /4* 7! 7 % % % $ ")!D"C *)' ' '; 121 !!" On behalf of ohlinjj 4/7/20 By Samantha Carlisle at 12:39 pm, Apr 08, 2020 RBDMS HEW 4/10/2020 DSR-4/8/2020VTL 4/10/20 SFD 4/10/2020 20" 94# H-40 shoe @ 115' MD 10-3/4" 45.5# L-80 shoe @ 2220' MD CD5-23 Final CTD Schematic 4-1/2" 12.6# L-80 Tubing Landing Nipple @ 2071' MD (3.813" ID) Camco Mandrels @ 3583', 5882', 6398' MD Baker Perm. Packer @ 8129' MD Landing Nipple @ 8183' MD (3.813" ID) Landing Nipple @ 8228' MD (3.725" ID) 7-5/8" 29.7# L-80 shoe @ 8621' MD Nipple 4-1/2" Monobore Nipple Whipstock @ 8750' MD 4-1/2" 12.6# L-80 shoe @ 8947 MD ------------------------------- I D5 -23L1 D= 12,687' MD llet= 9350' MD -1/4" Open -hole CD5-23L1-01 TD= 11,001' MD 4-1/4" Open -hole Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By LAST TAG:CD5-23 jennalt Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set MCX Inj Valve 3/8/2020 CD5-23 boehmbh Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.12 Top (ftKB) 33.3 Set Depth (ftKB) 115.0 Set Depth (TVD)… 115.0 Wt/Len (l… 94.00 Grade H-40 Top Thread Welded Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 37.0 Set Depth (ftKB) 2,219.6 Set Depth (TVD)… 2,179.0 Wt/Len (l… 45.50 Grade L-80 Top Thread Hyd 563 Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.88 Top (ftKB) 34.0 Set Depth (ftKB) 8,620.8 Set Depth (TVD)… 7,444.3 Wt/Len (l… 29.70 Grade L80 Top Thread Hyd563 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 31.0 Set Depth (ft… 8,946.5 Set Depth (TVD) (… 7,485.1 Wt (lb/ft) 12.60 Grade L-80 Top Connection H563 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 31.0 31.0 0.00 HANGER FMC 4-1/2" Tubing Hanger H563 3.958 2,070.9 2,039.2 20.13 NIPPLE NIPPLE,LANDING,4 1/2",X,3.813", HYD563 3.813 8,129.3 7,337.8 70.77 PACKER Baker permanent production packer 4.5" TC-II x 7 5/8" 29# 3.870 8,183.1 7,354.7 72.57 NIPPLE NIPPLE,LANDING,4 1/2",X,3.813", HYD563 3.813 8,227.7 7,367.5 74.04 NIPPLE NIPPLE,LANDING,4 1/2",3.813" XN, 3.725" No-go HYD563 3.725 8,231.0 7,368.4 74.13 LINER CROSSOVER,4 1/2"HYD563 X TXP,BP,24" 3.958 8,232.9 7,368.9 74.18 LINER Tubing,4 1/2",12.6#,L80, TXP 3.958 8,941.3 7,484.6 84.20 SHOE Orange Peel Shoe (MILLED OUT FROM 1.00" TO 3.70" ON 3/23/2018) 3.700 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in) 2,070.9 2,039.2 20.13 INJ VALVE 4.5" MCX INJ VALVE (SN:4281676-4) ON 3.813" X- LOCK 3/8/2020 1.563 8,750.0 7,461.3 82.46 4-1/2" BOT Mono-bore XL tray Whipstock 4-1/2" BOT Mono-bore XL tray Whipstock 2/23/2020 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 3,583.3 3,453.8 SLB Camco KBMG 1 GAS LIFT DMY BK-5 1/13/2019 2 5,882.0 5,595.5 SLB Camco KBMG 1 GAS LIFT DMY BK-5 1/21/2018 No Latch 3 6,398.3 6,077.2 SLB Camco KBMG 1 GAS LIFT DMY BK-5 1/16/2019 Notes: General & Safety End Date Annotation 1/16/2019 NOTE: CONVERTED f/ PROD TO INJECTOR 2/9/2018 NOTE: RUNNING NECK AND FISHING SWIVELED OFF DV IN STA #2. WOBBLE RING & SPRING RECOVERED. HORIZONTAL, CD5-23, 4/6/2020 3:30:33 PM Vertical schematic (actual) X O OPEN HOLE; 8,621.0-27,430.0 SHOE; 8,941.3 PERF PUP; 8,930.6 4-1/2" BOT Mono-bore XL tray Whipstock ; 8,750.0 INTERMEDIATE; 34.0-8,620.8 NIPPLE; 8,227.7 NIPPLE; 8,183.1 XO THREADS; 8,133.5 PACKER; 8,129.3 XO THREADS; 8,121.5 GAS LIFT; 6,398.3 GAS LIFT; 5,882.0 GAS LIFT; 3,583.3 SURFACE; 37.0-2,219.6 INJ VALVE; 2,070.9 NIPPLE; 2,070.9 CONDUCTOR; 33.3-115.0 HANGER; 31.0 WNS INJ KB-Grd (ft) 36.55 Rig Release Date 1/24/2018 CD5-23 ... TD Act Btm (ftKB) 27,430.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032076100 Wellbore Status INJ Max Angle & MD Incl (°) 94.15 MD (ftKB) 19,914.56 WELLNAME WELLBORE Annotation LAST WO: End DateH2S (ppm)DateComment SSSV: NIPPLE Page 1/15 CD5-23 Report Printed: 4/5/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/19/2020 18:00 2/20/2020 00:00 6.00 DEMOB WHDBOP RURD P Remove front of tiger tank dike, bed truck on location, remove tiger tank from dike. NES tire guy on locaton, check and air up tires in preparation of Rig Move, Load out remaining fluid from rig pits, blow down steam lines, continue pre-move checklist, crane broke down call out mechanic, grader broke down. Crane up and running remove CD5-23 wellhouse and stage out of rig path. grader on location, prep location for rig, continue unloading pits 0.0 0.0 2/20/2020 00:00 2/20/2020 00:30 0.50 DEMOB WHDBOP RURD P Continue unloading fluid from rig pits, prep well for rig, and secure cellar flooring, NES trucks on location 0.0 0.0 2/20/2020 00:30 2/20/2020 02:30 2.00 DEMOB WHDBOP RURD T Wait on vac truck to return for final load. PJSM with Rig crew and operators, vac truck experienced mechanical failure on pony motor at 10 acre pad, mech dispatched from Deadhorse. work unloading NaBr or milling fluid to get truck empty to unload last load of New Mud from rig. 0.0 2/20/2020 02:30 2/20/2020 06:00 3.50 DEMOB WHDBOP RURD T Mobilize vac truck to CD1 mud plant to offload NaBr into upright, 2/20/2020 06:00 2/20/2020 08:00 2.00 DEMOB WHDBOP DMOB P Crew change, Vac truck for last load of mud on location 06:00, spot in and off load while PJSM with NES rig move crew. Pits to jack, spot sow, pull mats. 0.0 0.0 2/20/2020 08:00 2/20/2020 08:30 0.50 MIRU MOVE MOB P Move service mod off well, back to edge of pad. 0.0 0.0 2/20/2020 08:30 2/20/2020 09:18 0.80 MIRU MOVE MOB P Sub to jack, spot sow, pull mats, open barn doors, pull sub off well, move rig down pad. 0.0 0.0 2/20/2020 09:18 2/20/2020 10:00 0.70 MIRU MOVE MOB P Back rig over well CD5-23i, spot up, place mats, set sub on mats, rig off so, measure and spot inner mats for service mod. 0.0 0.0 2/20/2020 10:00 2/20/2020 10:54 0.90 MIRU MOVE MOB P Spot service mod next to Sub, spot outer mats, set down, rig off sow. 0.0 0.0 2/20/2020 10:54 2/20/2020 13:00 2.10 MIRU WHDBOP RURD P Extend PUTZ, hook up comms, stage Tioga on cellar, set stack - 4 point, square up with turnbuckles. 0.0 0.0 2/20/2020 13:00 2/20/2020 15:00 2.00 MIRU WHDBOP RURD P String haywire, attach to CTC, PJSM, pull test to 900 psi on tugger *** Note: Rig Accept @ 13:00 hrs 0.0 0.0 2/20/2020 15:00 2/20/2020 18:00 3.00 SLOT WELLPR CTOP P Secure coil to reel, cut off CTC, hang reel in slings 0.0 0.0 2/20/2020 18:00 2/20/2020 19:00 1.00 SLOT WELLPR CTOP P Remove stripper from INJH, clean, inspect, and swap out 2" Brass to 2- 3/8" Brass. 0.0 0.0 2/20/2020 19:00 2/20/2020 19:30 0.50 SLOT WELLPR CTOP P NES on location, PJSM with crew 0.0 0.0 2/20/2020 19:30 2/20/2020 20:15 0.75 SLOT WELLPR CTOP P Remove King Pin/Booster, open bombay doors, Load out 2" coiled tubing reel *** Note: 2" String #53724/Spool #16631 0.0 0.0 Rig: NABORS CDR3-AC Page 2/15 CD5-23 Report Printed: 4/5/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/20/2020 20:15 2/20/2020 20:45 0.50 SLOT WELLPR CTOP P Bring in, and set 2-3/8" reel *** Note: 2-3/8" String #5770 (SLB)/Spool #DR209503 0.0 0.0 2/20/2020 20:45 2/20/2020 21:45 1.00 SLOT WELLPR CTOP P Install King Pin/Booster, close bombay doors and secure, lay down spill dike on bombay doors. set reel into saddle clamps. 0.0 0.0 2/20/2020 21:45 2/20/2020 22:21 0.60 SLOT WELLPR CTOP P Install stripper and hook up hydraulic lines 0.0 0.0 2/20/2020 22:21 2/20/2020 23:21 1.00 SLOT WELLPR CTOP P Swap out 2" gripper blocks to 2-3/8" gripper blocks 0.0 0.0 2/20/2020 23:21 2/21/2020 00:00 0.65 SLOT WELLPR CTOP P Swap out INJH Gooseneck rollers 0.0 0.0 2/21/2020 00:00 2/21/2020 03:00 3.00 SLOT WELLPR CTOP P Finish swapping out gripper blocks and goose neck rollers, and inspect. 0.0 0.0 2/21/2020 03:00 2/21/2020 06:00 3.00 SLOT WELLPR CTOP P Continue securing saddle clamps and torque to spec, install inner reel iron as per RP. 0.0 0.0 2/21/2020 06:00 2/21/2020 08:00 2.00 SLOT WELLPR CTOP P test wire - good. Install pressure bulkhead, string rope for haywire pull. 0.0 0.0 2/21/2020 08:00 2/21/2020 16:00 8.00 SLOT WELLPR CTOP P Swap BOP rams, and horses head rollers, secure inner reel iron, 0.0 0.0 2/21/2020 16:00 2/21/2020 18:00 2.00 SLOT WELLPR CTOP P Crew change, cleared inside reel ice and snow, installed grapple and cable, placed tugger into sheave, 0.0 0.0 2/21/2020 18:00 2/21/2020 19:45 1.75 SLOT WELLPR CTOP P PJSM, pull test grapple and re-torque, Stab coiled tubing into INJH, trimmed coil (5.0') 0.0 0.0 2/21/2020 19:45 2/21/2020 20:45 1.00 SLOT WELLPR CTOP P PJSM, RU LRS, PT line 2,500 psi, load 5 bbl into reel 0.0 0.0 2/21/2020 20:45 2/21/2020 21:21 0.60 SLOT WELLPR CTOP P Vacate fluid from hose, secure costumer line, RD LRS 0.0 0.0 2/21/2020 21:21 2/21/2020 23:21 2.00 SLOT WELLPR CTOP P Swap out lubricator riser for height adjustment, obtain RKB's measurments 0.0 0.0 2/21/2020 23:21 2/22/2020 00:00 0.65 MIRU WHDBOP RURD P Grease and fluid pack surface lines and BOP stack, perform shell test 4,500 psi 0.0 0.0 2/22/2020 00:00 2/22/2020 00:42 0.70 MIRU WHDBOP BOPE P Test BOP's (250 psi low / 4500 psi high, annular to 2500 psi), witness waived by Austin Mcleod of the AOGCC Swab 1 and 2 not holding Grease both, swab#1 pass, geese swab #2 - pass 0.0 0.0 2/22/2020 00:42 2/22/2020 04:12 3.50 MIRU WHDBOP BOPE P Test 1. Swab 2 Test 2. Blind/Shear, BOP TV2, Charlie 4, 5, 8, &12 Test 3. BOP TV 1, Charlie 3, 7, & 11 Test 4. Manual choke D & Super choke C Test 5. Romeo 3, Bleeder 3, Tango 2, Charlie 2, & 10 Test 6. Charlie 1, 9, Bravo 5, and Tango 1 – install TIW test joint Test 7. Lower 2-3/8"” pipe slip rams, TIW #1, Romeo 1, Bleeder 1 0.0 0.0 Rig: NABORS CDR3-AC Page 3/15 CD5-23 Report Printed: 4/5/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/22/2020 04:12 2/22/2020 07:12 3.00 MIRU WHDBOP BOPE T Test 7. Lower 2-3/8"” pipe slip rams, TIW #1, Romeo 1, Bleeder 1 Trouble with test, trouble shooting leak path, pull and reset test joint, attempt high side still leaking. Attempt to test 3" rams, fail, pull test joint break down, clean and dope fittings, re torque, start test 0.0 0.0 2/22/2020 07:12 2/22/2020 08:00 0.80 MIRU WHDBOP BOPE P Test 11. 3 ” pipe slip rams, TIW#2 Test 7. Lower 2-3/8"” pipe slip rams, TIW #1, Romeo 1, Bleeder 1 Test 8. Annular BOP 0.0 0.0 2/22/2020 08:00 2/22/2020 09:00 1.00 MIRU WHDBOP BOPE T B8 grease , B8 fail 0.0 0.0 2/22/2020 09:00 2/22/2020 11:00 2.00 MIRU WHDBOP BOPE P Test 10. Bravo 7 -9:12-9:43 Test 11. 3 ” pipe slip rams, TIW#2 - 9:47 - 10:06 Test 12. Draw down accumulator- accumulator pressure 3100 psi, stabilized pressure 2,350 psi, time to 200 psi increase 19 sec, entire recovery 45 sec,N2 4 bottle average 1900 psi. Tested all gas alarms 0.0 0.0 2/22/2020 11:00 2/22/2020 12:48 1.80 MIRU WHDBOP CTOP P Skid cart, test wire, 56 Ohhms & greater than 2k MeggaOhms, install CTC and nozzle - install CT counter on horses head. Working in parralell to swap out failed B8 0.0 0.0 2/22/2020 12:48 2/22/2020 13:12 0.40 MIRU WHDBOP BOPE T Continue to swap out B8 0.0 0.0 2/22/2020 13:12 2/22/2020 14:00 0.80 MIRU WHDBOP CTOP P Start loading reel with seawater over the drain to keep moving forward while continuing to swap out B8 in parralel. S/D with 10 bbls sea water away 0.0 0.0 2/22/2020 14:00 2/22/2020 15:12 1.20 MIRU WHDBOP BOPE T Complete swap out of B8, re flood stack. Test B8 - fail, suspect leaking at MM valves, grease valves and close blinds 0.0 0.0 2/22/2020 15:12 2/22/2020 15:30 0.30 MIRU WHDBOP BOPE P Test B8 0.0 0.0 2/22/2020 15:30 2/22/2020 19:18 3.80 MIRU WHDBOP PRTS P PT tiger tank line to 2500 psi - good. Install QTS and fill coil. 0.0 0.0 2/22/2020 19:18 2/22/2020 19:48 0.50 MIRU WHDBOP CTOP P Test inner reel valve and pac-off (good) 0.0 0.0 2/22/2020 19:48 2/22/2020 20:06 0.30 MIRU WHDBOP CTOP P RD testing equipment, 0.0 0.0 2/22/2020 20:06 2/22/2020 20:24 0.30 MIRU WHDBOP CTOP P Shut down, break off INJH check wire and install big hole nozzle 0.0 0.0 2/22/2020 20:24 2/22/2020 20:54 0.50 MIRU WHDBOP CTOP P Line up to reverse, bring both mud pumps online at 2 bpm each 4 bpm, heard movement 20-30 seconds, shut down pump, bring pumps online again up to 4 bpm no movement heard, brake off INJH and remove nozzle 0.0 0.0 2/22/2020 20:54 2/22/2020 23:06 2.20 MIRU WHDBOP CTOP P RU cutter, issues MU Otis connector, cut coil to a mule shoe, continue MU cutter, cut coil, found wire at 8', brake off cutter, boot wire, 0.0 0.0 Rig: NABORS CDR3-AC Page 4/15 CD5-23 Report Printed: 4/5/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/22/2020 23:06 2/22/2020 23:24 0.30 MIRU WHDBOP CTOP P Re-boot wire, stab INJH, perform second slack attempt up to 4 bpm 4,931 psi, no movement observed, unstab INJH, 0.0 0.0 2/22/2020 23:24 2/23/2020 00:00 0.61 MIRU WHDBOP CTOP P MU CTC 0.0 0.0 2/23/2020 00:00 2/23/2020 00:30 0.50 MIRU WHDBOP CTOP P Continue MU CTC, pull test to 35 k 0.0 0.0 2/23/2020 00:30 2/23/2020 01:42 1.20 MIRU WHDBOP CTOP P Re-head BHI UQ, and test eline >2000/58.6 megOhms 0.0 0.0 2/23/2020 01:42 2/23/2020 02:18 0.60 MIRU WHDBOP CTOP P PT BHI UQ to 4,000 psi. leak at pull plate connection, shut down re-torque, PT 4000 psi (good) 0.0 0.0 2/23/2020 02:18 2/23/2020 02:48 0.50 MIRU WHDBOP CTOP P MU Nozzle, pump 1 coil volume forward, while pre-loading PDL 0.0 0.0 2/23/2020 02:48 2/23/2020 03:30 0.70 MIRU WHDBOP CTOP P Finish up pre-loading PDL, load BOT 4-1/2" MB XL WS 0.0 0.0 2/23/2020 03:30 2/23/2020 06:36 3.10 PROD1 RPEQPT PULD P PD, WS setting assembly, issue with PDL, mechanic call to increase hydraulic pressure in order to lift 3" tool string. Continue to PD BHA #1. Space out low, double ball valves buried on first attempt. Complete PD. 0.0 82.3 2/23/2020 06:36 2/23/2020 07:00 0.40 PROD1 RPEQPT TRIP P RIH, large WOB increase, Park coil, PU, Park, WOB moving with pressure, not true WOB. Pumping seawater taking returns to the tiger tank. 82.3 112.0 2/23/2020 07:00 2/23/2020 07:42 0.70 PROD1 RPEQPT CTOP P Park @ 1500' and adjust CT gooseneck alignment and first roller PU, RIH, PU, RIH 112.0 1,622.0 2/23/2020 07:42 2/23/2020 09:54 2.20 PROD1 RPEQPT TRIP P Cntinue to RIH 1,622.0 7,873.0 2/23/2020 09:54 2/23/2020 10:12 0.30 PROD1 RPEQPT DLOG P Tie in to the K1 for a -10' correction 7,873.0 7,917.0 2/23/2020 10:12 2/23/2020 11:54 1.70 PROD1 RPEQPT CTOP P RIHa few feet, stripper leaking, park pipe, increase stripper pressure, still leaking, close annular, bleed off and no flow test above annular, PJSM, replace side door stripper inner elements - 2-3/8 eroded to 2-5/8" ID by rusty pipe. PT upper void annular to stripper - good, open bag, 7,917.0 7,948.0 2/23/2020 11:54 2/23/2020 12:18 0.40 PROD1 RPEQPT TRIP P RIH to 8900' bit depth - drift run 7,948.0 8,900.0 2/23/2020 12:18 2/23/2020 12:36 0.30 PROD1 RPEQPT TRIP P PUH to logging depth - jet whipstock setting area at 2 bpm. 8,900.0 8,165.0 2/23/2020 12:36 2/23/2020 13:30 0.90 PROD1 RPEQPT DLOG P Log CCL from 8100 to 8830 8,165.0 8,900.0 2/23/2020 13:30 2/23/2020 14:18 0.80 PROD1 RPEQPT TRIP P PUH to 8765.72' bit depth, WS tray oriented 150 ° ROHS Confer w engineering, close EDC. PU Wt 46 k lbs, down weight 23k lbs, online w pump at 0.5 bpm, shear at 3400 psi, 2820 diff, WOBclimbed to 5.7 k lbs. ***Set TOWS @ 8750' tray oriented 150° ROHS, SD 2 k lbs. 8,900.0 8,765.7 2/23/2020 14:18 2/23/2020 16:00 1.70 PROD1 RPEQPT TRIP P POOH Park at 7161' to align goose neck, continue out of hole. 8,765.7 72.1 Rig: NABORS CDR3-AC **Set TOW S @ 8750' tray oriented 150° ROHS, MEMORANDUM TO: Jim Regg P.I. Supervisor Re, ( 4(23j7,v FROM: Austin McLeod Petroleum Inspector Well Name COLVILLE RIV UNIT CDS-23 Insp Num: mitSAM200405182944 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, April 6, 2020 SUBJECT: Mechanical Integrity Tests ConocaPhillips Alaska, Inc. CD5-23 COLVILLE RIV UNIT C135-23 See: Inspector Reviewed By: P.I. Sup" Comm API Well Number 50-103-20761-00-00 Inspector Name: Austin McLeod Permit Number: 217-155-0 Inspection Date: 4/5/2020 Monday, April 6, 2020 Page 1 01 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well co5-23 Type Inj TVD 7338 'Tubing 8 xv3837- 3838 PTD 2171550 Type Test SPT 'Test psi 1834 ' IA 1180 00 180 - 2170 - BBL Pumped: 1.2 BBL Returned: I OA 900 975 e75 975 Interval OTBER Notes: Post initial injection. PTD 2200100; CD5-23L1. PTD 2200110; CD5-23L I-01 Monday, April 6, 2020 Page 1 01 1 THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger CTD Team Lead ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD5-23 Permit to Drill Number: 217-155 Sundry Number: 319-589 Dear Mr. Ohlinger: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Price DATED this day of January, 2020. RBDMSL�JAN 0 6 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ,F=C8��1 /6 1.m6. DEC 3 t 29 01-S //3 AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing E]Change ppf Program❑ Plug for Redrill ElPerforate New Pool ElRe-enterSusp Well ElAlter Casing Other: ZQ284•B Whipstock EZ . 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: /h ILL )( ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service 217-155 ' 3. Address: 6. API Number: PO Box 100360, Anchorage, AK 99510 50-103-20761-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A CRU CD5-23 Will planned perforations require a spacing exception? Yes ❑ No ❑' 9. Property Designation (Lease Number): 10. Field/Pool(s): ASRC-NPR1, ASRC-NPR2, ASRC-NPR3, ASRC-NPRd I Colville River Unit / Alpine Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 27,430' 7330' 27,430' 7330' 3871 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 20" 115' 115' Surface 2183' 10.75" 2220' 2179' Production 8587' 17.625" 8621' 17444' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Open Hole 8621'- 27,430' Open Hole 7444' - 7330' 4-1/2" L-80 8947' Packers and SSSV Type: Baker Permanent Production Packer 4.5" TC- Packers and SSSV MD (ft) and TVD (ft): 8129' MD, 7338' TVD II x 7 5/8" 29#, No SSSV No SSSV 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: 7 -Jan -20 Commencing Operations: OIL F] WINJ F] WDSPL E] Suspended ❑ GAS ❑ WAG ❑✓ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: James Ohlinger Contact Name: Shane Germann Authorized Title: Staff CTD Engineer Contact Email: Shane.Germann COP.com Contact Phone: 907-203-4597 Authorized Signature: Date: /.� .�/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 0043 — Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: � ) �s� r�t1 ,✓� '4BDMS 474- JAN 0 6 2020 Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE ` COMMISSION Date: /—.? ZD Submit Form and Form 10- d application is valid for 12 months fr the date of approval. Duplicate plicate /.2,, 'may ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 31, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits sundry application to set a whipstock and mill XN-nipple to drill two laterals out of the CRU CD5-23 (PTD# 217-155) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in early February 2020. The objective will be to drill two laterals, CRU CD5-23L1, and CD5-231_1-01 targeting the Alpine A and C -sand intervals. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to the sundry application are the following documents: — Sundry Application Form (10-403) for CD5-23 — Operations Summary in support of the 10-403 Sundry Application — Current Wellbore Schematic — Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4597. Sinc rely, 2--t— Shane Germann Coiled Tubing Drilling Engineer ConocoPhillips Alaska CRU CD5-23 (PTD: 217-155) CTD Summary for Sundry Summary of Operations: CRU well CD5-23 is an Alpine A -Sand injector equipped with 4-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the A and C -sands to the south of CD5-23. The laterals will increase A and C -sand resource recovery and throughput. Prior to CTD rig up, service coil will mill out the 3.725" XN-nipple at 8228' MD to 3.80" ID. CDR3 will set a mechanical whipstock (4-1/2" monobore) inside the 4-1/2" tubing at the planned kick off point of 8750' MD. The CD5-23L1 lateral will exit through the 4-1/2" tubing at 8750' MD and drill to a planned TD at 13,350' MD, targeting the A sand to the south. The lateral will be completed with 2-7/8" slotted liner from TD up to 9300' MD with an aluminum billet for kicking off. The CD5-23L1-01 lateral will kick off at 9300' MD and drill to a planned TD of 13,250' MD targeting the C sand to the south. It will be completed with 2-7/8" slotted liner from TD up into the 4-1/2" tubing at 8740' MD with a deployment sleeve and seal bore assembly. CTD Drill and Complete CD5-23 Laterals: Pre -CTD Work �� C . 1. RU Slickline: Dummy whipstock drift. SBHP 2. RU CTU: Mill out XN-Nipple to 3.80" ID, cleanout if fill is encountered. 3. Prep site for Nabors CDR3-AC. ��J 1 Rig Work /� `'v" �F 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. I 2. Set top of 4-1/2" monobore whipstock at 8750' MD 3. CD5-23L1 Lateral (A sand - South) a. Mill 3.80" window at 8750' MD. b. Drill 4-1/4" bi-center lateral to TD of 13,350' MD. (� c. Run 2-7/8" slotted liner with an aluminum billet from TD up to 9300' MD. 4. CD5-23L1-01 Lateral (C sand - South) o a. Kickoff of the aluminum billet at 9300' MD. b. Drill 4-1/4" bi-center lateral to TD of 13,250' MD. c. Run 2-7/8" slotted liner with deployment sleeve and seal bore from TD up to 8740' MD. 5. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CRD3-AC. Post -Rig Work 1. Return to production Page 1 of 1 12/31/2019 PA WINS INJ WELLNAME CDS-23 WELLBORE CDS-23 ConocoPhillipS Wall Attributes Max Angle &AID TO vas". Inc, FleI6 Name Wellbore gPllUWI Wellbore 5letua Icq°I MOIttKB) Pc[Blm (fiKBI LPINE 1 32 ] 1 INJ .15 19,914.56 27.430.0 Comment H38 (ppml Date Mnom"n SpDato KB.LrE (RI 0.10 Ralsa8 Date SSSV:NIPPLE LAST WO: 3855 1I24I2018 X00.12...1 LPSay 11I1gram..:0 ;a3AM Last Tag Venitsimpamebc(aquell Anroration DISMISS.) End Data rsllbnn 1 WI Mod By LAST TAG: C.1 jenna8 Last Rev Reason HwcSR', a10 Mnm.6on end wm welmon ta.e Moe By Rev Reas.R: Pre CTD - Drift&SBHP .1.1.2019 W523 Claym Casing Strings ........_.._..........,._..�._...._. _................. ---- - ' CasingDeacon Ilan OD In ID In To RKB Set De tb RKR 5110¢ m ND.. VXILm 11... Grade P I I 1 1 P I 1 P I 1 P 1 1 Top Thread CONDUCTOR 20 10.12 33.3 1Y5.0 115.0 94.00 H40 Welded CUIng assumption 00(m) 10 (in) Top dcal SH Depth IhKBI Sat Depm IND).,. iti I1... Gnda Tapnoted SURFACE 10314 9.95 37.0 2,219.11 2,1>9,0 48.50 1-60 1-1y1563 CUIng Dncd0l0n OD(In) ID(Iry Top IBKBI SN Depth(XKB) SO Depth(ND)... YASOO ll... Omit. Tap Thnatl INTERMEDIATE 7518 5.88 34.0 8,620.8 ],444.3 29.70 160 Hyd563 ..................... .......... _._.........__...................__. ......._....... Casing Description 00grd ID(Inl Tap IRKB) SMDemh(nKB) SM Depth Rapt.. W114n D... games 1,01apad OPEN HOLE 6314 8,621.0 2],4309 Tubing Strings Tubing Description gWng Ma...ID0n1 Top (aKB) Sm Daplh l0... $et Depm (WD)(L.. W15Nb) pnEe iop Connection Tubing 4112 3.96 31.0 8,946.5 ],465.1 12.80 LA0 H563 CONDUCTOR-, aa.a.115.o Completion Details Top IND) Top Incl Nominal Top(XKBI (RKB) P) Nem Des Com ID pin) 31.0 31.0 0,00 HANGER FMC 4-112" Tubing Hanger H563 3.958 x1PPL[rzoTRe INA VALVE],0108 2,070.9 2,039.2 20.13 NIPPLE NIPPLE,LANDING.412',X,3.813'. WD563 3.813 8,129.3 ],33].8 70.77 PACKER Baker permanent production packer 4.5-TGIIx7518"29@ 3.870 8,183.1 7,354.7 7857 NIPPLE NIPPLE,IANDING,4 ill",$3,813", MYD563 3,813 8,227.7 7,387.5 74.04 NIPPLE NIPPLE,LANDING,4112",3.813"XN, 3.M'Na-90 HYD563 3.725 8,231.0 7,388,4 74.13 LINER CROSSOVER,4112"HYD563 X TXPRP,24" 3.958 8,232.9 7,368.9 74.18 LINER Tubh ,41IT',12.6N,LBe TXP 3958 8,9,11.3 7,484.6 84.20 SHOE Orang9Feel Shoe(MILLED OUT FROM 1.00" TO 170"ON 3.700 SURFACE; 3Ta$.91a6� 31232018) 1 Other In Hole ( imline retrievable plugs, valves, pumps, fish, etc.) TopIRKB) Top lost -1- OAS LIFT:3ausl Top IBKBI (RK8) 1•) Des Com Run Dan 1.) 2,0]0.9 2,0382 20.131NJVALVtc 4.5ceCX INJ VALVE (SNF281676-1)ON 3.813"X- 11/12201 1.583 LOCK 9 Mandrel Inserts 81 aB N ToDType LNch ToB3.51 ) Date)3.46 Make Nadel OD(In) Ssry Type Type Pod) TRO Run (m IWII Run Co. DAs upT: S.Ki.B 1 3,583.3 3,453.8 SLB HBMG 1 GAS LIFT DMY BKS ig 111312019 Cam. 2 5,882.0 5,595.5 SLB KBMG 1 GAS LIFT DMY BK5 112112018 No Camm Latch 3 6,398.3 6.077.2 SLB KBMG 1 GAS LIFT DMV BK -5 1/162019 German GASUPTaaglig Not": General &.Safety End Dale I ..MHon 2192018 NOTE: RUNNING NECK AND FISHING SWIVELED OFF DV IN STA g2. WOBBLE RING B SPRING RECOVERED. 111&2019 NOTE: CONVERTED b PROD TO INJECTOR NOTE: x.TrvaFws:e trzt5 PPCKEP %Rsa MTHREuOS. 0.1335 MPPIE:B,1&1.1 rl' ' � NIPPLE', 9.rzTa.T I.ERMEDMTE; aa.08,fii0.6 PERFmP: b930.6 II 3110E: 941 II1l OPEN WILE; 5,831.aa7.a90.9 0 ; R\ /\ j eco j \ \ { \ / \ \ { \ ! \ E / k \ - \ - \ 0 0 R\ /\ prD 2 / 7 - l 5� Loepp, Victoria T (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Sunday, December 15, 2019 3:14 PM To: Loepp, Victoria T (CED); Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: CD5-23 (PTD 217-155) and CD5-25 (PTD 217-161) Conductor Water Follow Up Flag: Follow up Flag Status: Flagged Victoria/Chris, Operations reported that CRU wells CD5-23 (PTD 217-155) and CD5-25 (PTD 217-161) recently started flowing water to surface through the surface casing by conductor annulus. Both wells appear to be flowing less than half a barrel of water per day. CPAI suspects this water to be from the same shallow source water that was initially encountered on CDS-313 (PTD 215-084). We will take initial samples for analysis and collect water at the wellhead to monitor the flow volume. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 MEMORANDUM State of Alaska Packer Alaska Oil and Gas Conservation Commission TO: Jim ReBg DATE: Thursday, August 15, 2019 PA. Supervisor Lligl, SUBJECT: Mechanical Integrity Tests t ( 1 ConocoPhillips Alaska, Inc. I834 - CD5-23 FROM: Jeff Jones COLVILLe RIV UNIT CD5-23 Petroleum Inspector Sre: Inspector z 7 BBL Returned: Reviewed By: 2.7 OA P.I. Supry I J1>✓"r�?� �' NON -CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD5-23 API Well Number 50-103-20761-00-00 Inspector Name: Jeff Jones Insp Num: mit1J 190814104739 Permit Number: 217-155-0 Inspection Date: 8/2/2019 - Rel Insp Num: Pretest Initial 15 Min 30 Min a5 Min 60 Min 1418 - '419 2418 2418 - 620 5110 -� 30+0 3040 - 350 590 590 Thursday, August 15, 2019 Page 1 of 1 Packer Depth Well PTD CD5-23 2171550 Type Inj -Type Test SP -I TVD Test psi 2338 Tubing IA I834 - — — BBL BBPumped. z 7 BBL Returned: 2.7 OA -- i 4YRTST P/F 1 1, — L Notes: I well inspected, no exceptions noted. Pretest Initial 15 Min 30 Min a5 Min 60 Min 1418 - '419 2418 2418 - 620 5110 -� 30+0 3040 - 350 590 590 Thursday, August 15, 2019 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS REECEIVED FEB 0 4 2019 1. Operations Abandon LJ Plug Perforations LJ Fracture Stimulate LJ Pull Tubing Li Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Convert to WAG injection❑✓ 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development ❑✓ Exploratory ❑ 217-155-0 3. Address: PO Box 100360, Anchorage, AK, 99510 Stratigraphic ❑ Service ❑ 6. API Number: 50-103-20761-00 7. Property Designation (Lease Number): 8. Well Name and Number: ASRC-NPR), ASRC-NPR2, ASRC-NPR3, ASRC-NPR4 CRU CD5-23 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Colville River Unit / Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 27430 feet Plugs measured N/A feet true vertical 7330 feet Junk measured N/A feet Effective Depth measured 27430 feet Packer measured 8129 feet true vertical 7330 feet true vertical 7338 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 20" 115• 115' Surface 2183' 10.75" 2220' 2179' Intermediate 8587' 7.625" 8621' 7444' Production Liner Perforation depth Measured depth 8621'- 27430' feet True Vertical depth 7444'-7330' feet Tubing (size, grade, measured and true vertical depth) 4.5" L-80 8947' 7485' Packers and SSSV (type, measured and true vertical depth) Packer Baker 4.5" TC -II x 7 5/8" 29# 8129' 7338' SSSV 3.81" MCX INJ VALVE 2070' 2038' 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl E Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation:450 950 0 1325 375 Subsequent to operation: IN/A N/A 11000 N/A 1300 14. Attachments (required per 20 AAc 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations ❑' Exploratory ❑ Development ❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG Q 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: i -s7- Authorized Name: David Neville Contact Name: David Neville Authorized Title: Production Engineer Contact Email: Davitl.J.Neville(ovlcoo cem /(SStttaaff Authorized Signature: w 2/+/I ,�j Date. Contact Phone: 265-6220 1,vr-c 2/17-//9 Form 10-404 Revised 4/2017 RBDMSJ,FFB 1 12019 Submit Original Only WN$ INJ WELLNAME CD5-23 WELLBORE CD5-23 ConocoPhillips Well Attributes Max Angle & MD TO Alaska, IRC. Fleltl Nama WeIWon APWat WHlpole Slaws 1•) Mp MKB) Aq 00n(Ras) ALPINE 5010320M100 INJ .15 19.91456 2].430.0 CMIMNI NSB loom) Wb Mwlatlon En¢DM KBON DD qp R4Msas MM BSSV: NIPPLE /ABT WO: 36.55 12/2018 HOR60NTAL-Cry., 111--NB:¢,]9AN Last Tag VaNul,rJemalc lecuw) Mnq¢11on gpMIRNe BM BeM ah0pon feel MOC Br /AST TAG: CD523 MmnaB - NWDEA 3,o Last Rev Reason wMmwe tan MoeN Amw MI. zu,DM Rev Reason: DonVM well hom PW io lnJema 1/162019 ODS -23 Idrg d"IngStrings �lan pp11n) /DIN) Top IM(BI Sal.0 (flKB) /lel0 IND/... G.40 we TM4vE �51CONDUCTOR CONDUCTOR 20 19.12 JJ.3 115.0 1150 i0 WeMetl Culw peacrlpllan DD flip) M0.) TWHAKB) BM De�In INKS) Btl Ml MOI...d. Tw Tnraad SURFACE 40314 Sal 37.0 2,219.6 2,179.0 80 -y r Caslre DolcdSon o01N1 ID IN) TOP mon 9alR ln..I SN DepIM1 irp.) Tw Tnlase INTERMEDIATE 7518 888 34.0 8,620.8 ],444.3 0 H1dS43 1�30LW L Irg onanpnal oD4n1 Io1N) Tw110al EIwp0(nKB) sx oagn (N01... iper TOP mna¢ OPEN HOLE 63/4 8.6210 2].430.0 Tubing Strings LONDVfirOR: Ai1115.0 T,bl,R-Opmon SI Ma... ID M) TepMI,,, eel DspM IR. Sat Dean lNpH... WIMbT) oMe ieOLonnecllon Tubing 412 3.96 31.0 8,946.5 7,485.1 12.60 L-00 H563 Completion Details TOP IND) TopNvl Nemlml TW lnnei I'M IS nem Des Lom 10(M) 31.0 31.0 0.00 HANGER FMC 4-0? TURN HmlMer H563 1958 NMpLERpme Iw vav9, 2.oroo ,0x1.9 2,039.2 211.13 NIPPLE NIPPLE.1-ANDING.412'X.3.81T. HYD583 3.813 ,129.3 ],33].8 ]0.77 PACKER Baker permanent pp KIm rl packer .STC -II x]5/8'29# 3.870 ,163.1 7,3547 M.57 NIPPLE NIPPLELANDING.91?,%,4813', HY0563 3.813 J,367.5 74.04 NIPPLE NIPPLE,LANDING.4 N7,3.813'XN, 3.]27 Nog0HYD%3 374 entU 388A 7.13 LINER CR0SSOVER61 HYD583%TXP,EW.24' 3.958 8.2379 ],368.9 74.18 LINER Tubing.4 V7,12.1 ,TXP 3.958 8.WH 7484.6 84.MTH-OE Orange Peel BDm(MILLED OMMOM1.00' T 3.7tPON 7 3232018) Other In Hole (Wireline retrievable plugs, valves, pumps, fish, aft.) TaPINp) Top Incl Tw InKBI InNBI 1'I Des LOm Run peN ID Mn) GAS UFT; AMM 2.0]00 2,038.3 20.121NJ VALVE 3.51'MCX IW VALVE(SNA0669999, 15' ORIFICE) 111812018 0.000 Mandrel Inserts a aB Nt3.M.3 (Ran Mane Kil MW) III IN..'m Val. . POR. 1ROIMIM RunoM can 1 3,453.8 SLB KBMG DMY BKS 1/132019 Camra2 5,595 ]GASUFT 11FT DMY BKS 1I21rz018 ND Cemw 4M 3 6.DJJ.2 SLB KBMIJ i GAS LIFT DMY K-5 Ul 2019 Cameo Notes: General S Safety cA9 un;e,¢aaa nd DMv Annowaal 0'" AN2018 NOTE RUNNING NECK AND FISHING SWIVELED OFF DV IN STA #2. WOBBLE RINGa SPRING RECOVERED. NOTE: CONVERTED 9PROD TO INJECTOR NOTE: XO THREADS: 9,121.5 PACER; a1HI3 W TItltFAp9; 4.Iy.5 NPPLE; 9,1911 MPPIE; 9,3311 ixlERAaDInTe; x o4.a2o.e II PERFMP,9.W11.8 6NOF 9.., I lilt l OPEN MCLE'9,y1 b21.U2.p �r ConocoPllilllps Well History CDS-23:501032076100:2/1/2019 Date Event 1/16/2019 SET DV @ 6398' RKB. 30 MNI MIT -IA TO 3000 psi. **PASS**. PULLED 3.81" XN PLUG WITH GAUGES @ 8228' RKB. PSI = 2489 @ 167* F (UPLOAD DATA TO "S" DRIVE / ALP/ TEMP). SET 3.81" MCX [NJ VLV (S/N: 4086999-1) ON X -LOCK @ 2071' RKB. COMPLETE. 1/15/2019 CIRC -OUT. PUMPED 200 BBLS SW, 90 BBLS DSL DOWN TBG TAKING RETURNS UP IA TO TIGER TANKS. U -TUBE TBG/IA FOR FREEZE PROTECT. JOB COMPLETE. 1/13/2019 WEATHER DELAYED START. PULL GLV @ 3583' RKB. REPLACE w/ DMY VLV. PULLED OV @ 6398' RKB. **LEFT POCKET OPEN**. READY FOR CIRC OUT. 1/11/2019 RECOVERED 3.81" XXN PLUG ASSY @ 5629' RKB. (PLUG WAS PACKED WITH PARAFFIN, 1 XN KEY MISSING, EXPANDER MANDREL EGGED & KEY HOUSING DAMAGED). RECOVER MISSING XN KEY WITH MAGNET. 30 MIN SURVEY STOP @ 7600' RKB. SET 3.81" XXN PLUG w/ FILL EXT, SOFT SET & DUAL SPARTEK GAUGES PROGRAMMED @ 1 SEC SAMPLE RATE (SN: 79365 / 79563) @ 8228' RKB, BATTERIES CONNECTED @ 15:39/ OAL= 100"). **TEST PLUG TO 1000 psi**. IN PROGRESS. 1/10/2019 VERIFY 3.81" XXN PLUG IS PRE-SET IN THE BOTTOM OF THE IST GLM @ 3583' RKB W/ 3.795" LIB. ATTEMPT TO PULL PLUG ASSY @ 3583' RKB. JAR TOTAL OF 2.25 HRS NO MOVEMENT. IN PROGRESS.. 1/9/2019 DRIFT w/ 3.79" G -RING & BRUSH TO GLM @ 3583' RKB WHILE PUMPING HOT CRUDE. WAS UNABLE TO PASS GLM. TBG PRESSURED UP TO 2500 PSI AFTER 36 BBL'S PUMPED. LAY DOWN EQUIPMENT DUE TO -35* TEMPS. IN PROGRESS 1/7/2019 DRIFT TBG TO XN NIP @ 8227' RKB w/ 3.78" GRING. ATTEMPT TO SET 3.81" XXN PLUG w/ GAUGES, TOOLS BECAME TEMPORARILY DETAINED IN PARAFFIN @ 356' RKB. PUMPED 150 BBLS HOT CRUDE & WORKED TOOLS DWN TO GLM @ 3583' RKB TO COME FREE. LEFT PLUG IN TBG WHILE WORKING TOOLS FREE. IN PROGRESS MEMORANDUM State of Alaska Insp Num: mitGDC190128180641 Alaska Oil and Gas Conservation Commission TO: Jim Regg epp��y L i Iq I I DATE: Tuesday, January 29, 2019 P.I. Supervisor 17-4 SUBJECT: Mechanical Integrity Tests l CONOCOPHILLIPS ALASKA, INC. Type Ini CD5-23 FROM: Guy Cook COLVILLE RIV UNIT C135-23 Petroleum Inspector 1340 1340 -1 Src: Inspector Reviewed By: 2171550 "Type , P.I. Supry Jf�z— NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD5-23 API Well Number 50-103-20761-00-00 Inspector Name: Guy Cook Permit Number: 217-155-0 Inspection Date: 1/28/2019 Insp Num: mitGDC190128180641 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Wel C135-23 Type Ini w TVD 7338 Tubings 1340 IA 170 _ 1340 1340 -1 1340 PTD 2171550 "Type Test SPT Test psi 1834 _-2120 '-I 2070 - 2060 BBL Pumped: 2.1 BBL Returned: 2 OA30 895 890 860 Interval MITAL P/F P Notes: Initial MIT -IA post conversion to injector per Sundry 318-552�'A Little Red Services pump truck and calibrated gauges from DHD were used for testing. ice' Tuesday, January 29, 2019 Page I of I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED VR 19 2018 1. Operations Abandon Ll Plug Perforations Fracture Stimulate LJ Pull Tubing Ll Operations shutdown LJ Performed: Suspend ❑ Perforate ElOther Stimulate❑ Alter Casing El Crh,nge Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: _Inj to Prod_ ❑� 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development p ❑ Exploratory ❑ Stratigraphic ❑ Service ❑r 217-155-0 3. Address: 6. API Number: P.O. Box 100360 Anchorage, AK, 99510-0360 50-103-20761-00 7. Property Designation (Lease Number): 8. Well Name and Number: ASRC-NPR1, ASRC-NPR2, ASRC-NPR3, ASRC-NPR4 CRU CD5-23 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): None Colville River Field / Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 27430 feet Plugs measured None feet true vertical 7330 feet Junk measured None feet Effective Depth measured 27430 feet Packer measured 8129 feet true vertical 7330 feet true vertical 7338 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 20" 115' 115' Surface 2183' 10 3/4" 2220' 2179' Intermediate 8587' 7 5/8" 8621' 7444' Production Liner Perforation depth Measured depth 8621' - 27430' feet True Vertical depth 7444' - 7330' feet Tubing (size, grade, measured and true vertical depth) 4 1/2" L-80 8946' 7485' Packers and SSSV (type, measured and true vertical depth) BAKER PERMANENT PACKER 4/5" TC -II X 7 5/8" 291E 8129'17338' 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl I Casing Pressure Tubing Pressure Prior to well operation: 0 0 10 10 10 Subsequent to operation: 1771 658 132 11527 1255 14. Attachments (required per 20 AAc 25.010, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations ❑' Exploratory ❑ Development0 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: David Neville Contact Name: Authorized Title: Production Engineer Contact Email: Cal ^ ,, Authorized Signature: wV,/I l "^ Date: a /I Contact Phone: rrl- -4/26/�B RBDMS4APR 2 3 2018 Form 10-404 Revised 4/2017 s yf2 4 Submit Original Only Date Event Summary 1/26/2018 CIRC - OUT TBG & IA / PUMPED 290 BBLS DOWN THE TBG AND UP THE IA TAKING RETURNS TO A TIGER TANK / JOB COMPLETE 1/26/20181 PULLED BALL &ROD @ 8227' RKB. PULLED 1" SOV @ 6398' RKB. IN PROGRESS 2/8/201 SET 1" OV (5/16" PORT) @ 6398' RKB. PULLED 1" DGLV @ 3583' RKB, REPLACED w/ GLV (3/16" PORT, TRO= 1821). MEASURED BTM HOLE PRESSURE w/ DUAL SPARTEK GAUGES @ 8100' RKB (3433 psi @ 162* F). PULLED 3.81" RHC PLUG BODY @ 8227' RKB. COMPLETE rUiwrtu ZU BBLS UKUDt UUWN PRODUCTION F/L LINE AND 3 BBLS DIESEL DOWN TEST F/L TO FREEZE PROTECT. PUMPED 120 BBLS 170* CRUDE DOWN TBG TO HOT FLUSH (JOB COMPLETE) GAUGE TBG w/ 3.78" TO 8228' RKB. SET SLIP STOP CATCHER @ 6489' RKB. ATTEMPT TO PULL DV @ 5872' RKB. RETRIEVED RUNNING NECK AND FISHING NECK. (SPRING, WOBBLE RING, NO-GO & DGLV STILL IN HOLE). RAN 1.25" LIB. OBTAINED PICTURE B OF CLEAN NO-GO. ** IN PROGRESS** VVI i n nULrruvur_rc VrrarY LEAK IS UV (a_) bJUb' KKB. P I BELOW STA #2 DV w/ NO LATCH, GOOD. PULL AND REPLACE OV IN KIND @ 6398' RKB (OV WAS FLOW CUT & DEBRIS IN CHECK). REPLACE GLV @ 3583' RKB w/ NEW (TRO=1850 psi). PULL CATCHER @ 6489' RKB (RECOVERED WOBBLE RING & SPRING LOST ON 2-8-18). JOB COMPLETE 2111/20181 PUMPED 250 BBLS HOT CRUDE DOWN TBG (JOB COMPLETE) HOT FUSH TBG, TEST AND PRODUCTION HEADER / PUMPED 45 BBLS 180*F CRUDE DOWN TBG, 20 BBLS 180*F CRUDE DOWN EACH HEADER / JOB COMPLETE RIH WITH WEATHERFORD MOTOR AND 3.7" CRAYOLA MILL, TAG ORANGE PEEL SHOE AT 8941' RKB, MILL DOWN TO 8943' AND FIND THAT WE CANNOT STALL THE MOTOR, POOH TO FIND CIRCULATION SUB WAS SHIFTED OPEN JOB IN PROGRESS. WNS F 1D �/r'pl'�1 n Well Attributes C O" tka.IIc W IlhPre FPUNM A= Alaska. Inc Fnmezmelm n O CD5-23 HORIZONTAL- CGIGO. A Ipaja&Ia PMJP.S� 112412U18 Last Tag ____...._...........__............................_...... A""ob'I°G" oepm lnx i, Eno Dae Lint Wey LAST TA : ennalt Last Rev Reason HANGER, 310 nnoetlo" End ae La:L By Rev Resew Install GLVO 3252018 DPraven Casing Strings on U. (In) I UnI rop lnxel a+pepmm al see pawn I-. WIILen ll... cnoe TopT regio 20 19.124 33.3 115.0 115.0 94.00 H40 Welded n Op Inl (In 1 I -111Sef pewp BI SM pepm DVOt., en a... Or»e Top n3 10314 9.950 310 2.219.6 2,1]9.0 45.50 L -BO Hyd ODUn m Iln1 TPp se pepm IRxel seL Depm I M I wuun n._ Mee op meadE JS/8 6.875 34.0 8,620.8 ],4443 2910 LBO Hyd563 1g;A00 Tubing Strings ...._.................................. ............. T"bine 0a[[n"An slnne a... 1p lml TOp (KKel sn pepf m.. sal wL jNp)L..w Upel Orae, Top Cennectl"n Tubing 412 3.958 31.0 8946.5 1,465.1 12.60 6-80 H563 Completion Details TOP (NG) Top mn N"mlml Top(RKB) MIKE) rl lam wa Com corn) 310 31.0 0.00 HANGER FMC 4-il Tubing Hanger H563 3.958 CONpT.TOR:SS.11150 2,010.9 2,0392 20.13 NIPPLE NIPPLE,LANDING,412",X,3.g13",HYD563 3813 8,1293 ],331.8 701] PACKER Baker permanenl RITH1. .11 packer 4.5"TC-II x7 W'29a 3.870 8,183.1 7,3M7 )2.57 NIPPLE NIPPLE,IANDING,412",X,3.813",HYD563 3.813 NIPPLE: Z. 8.227.7 1,36).5 7404 NIPPLE NIPPLE,LANDING, 12',3.813" XN, 3.] 25" N HHYD563 .725 8.2310 ],368.4 74.13 LINER CROSSOVER,412"HYD563 X TXPA 24° 058 8232.9 ],368.9 74.18 LINER TUN o9.4112',12.Bp, O, TXP 8888 8,941.3 7484.6 84.20 rHOE Orange Peel Shoe (MILLED OUT FROM IUrn TO 3,70"ON 100 312312018) Mandrel Inserts st an sueF/.CE: 3].oz,z+ve� N Top TUal Tap MKB) MKBI MaM Model Vehre lath OD LIn) Sery Type Typ port grt, TqO RIPnj do (psi) Be. Dam Com 3,5833 31453.8 SUB KBMG Cameo 1 GAS LIFT GLV BK -5 0188 1,990.0 32512018 crs LIFT EBw3 2 5,862.0 5,595.5 SLB KBMG Camw 1 GAS LIFT DMY BK -5 1121 018 No e1cN 3 6,398.3 80]1.2 SLB KBMG amen 1 GAS LIFT OV BK -5 0250 0.0 3252018 Notes: General b Safety End Owe AnnobHon 25121 NOT RUNNING NECK AND FISHING SWIVELED OFF DV IN STA d2. WOBBLE RING A 9PRING RECOVERED. NOTE: GAS LIFT, S,BPZ 0 GAS LIFT', a ase 3 xOTRREAGs;3,1215 pA `UaLs'.2 s XO THREADS, 3,133.5 NIW{E;a,193+ NIPPLE; AM INTEP.SSUNTF'..,A a PERF PUP, a¢9a BHOq E.,3