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Home My WebLink About169-063Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/21/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260121 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 16RD 50133205540100 207125 12/3/2025 AK E-LINE PPROF T41253 BRU 211-35 50283201890000 223050 11/7/2025 AK E-LINE Perf T41254 BRU 213-26 50283201920000 223069 11/23/2025 AK E-LINE Perf T41255 BRU 213-26T 50283202040000 225038 11/4/2025 AK E-LINE Perf T41256 BRU 241-34S 50283201980000 224077 11/9/2025 AK E-LINE Perf T41257 BRU 241-34T 50283201810000 220052 11/6/2025 AK E-LINE Perf T41258 BRU 244-27 50283201850000 222038 12/13/2025 AK E-LINE Perf T41259 BRU 244-27 50283201850000 222038 12/19/2025 AK E-LINE StripGun T41259 GP ST 17586 9 50733204480000 193062 11/13/2025 AK E-LINE Perf T41260 IRU 241-01 50283201840000 221076 12/21/2025 AK E-LINE Perf T41261 IRU 241-01 50283201840000 221076 12/30/2025 AK E-LINE Perf T41261 IRU 241-01 50283201840000 221076 12/16/2025 AK E-LINE Plug T41261 IRU 241-01 50283201840000 221076 11/26/2025 AK E-LINE Plug/Perf T41261 KALOTSA 01 50133206570000 216132 11/19/2025 AK E-LINE Perf T41262 KBU 31-18 50133206490000 215024 11/8/2025 AK E-LINE Drift/PPROF T41263 KU 12-17 50133205770000 208089 11/14/2025 AK E-LINE StimGun T41264 LRU C-01RD 50283200610100 201168 11/27/2025 AK E-LINE RCT/Perf T41265 MPI 2-32 50029220840000 190119 12/10/2025 AK E-LINE LDL T41266 MPI 2-38 50029220900000 190129 12/5/2025 AK E-LINE LDL T41267 MPU H-16 50029232270000 204190 12/3/2025 AK E-LINE CBL T41268 MPU H-16 50029232270000 204190 11/19/2025 AK E-LINE TubingCut T41268 MPU I-14 50029232140000 204119 11/13/2025 AK E-LINE CBL T41269 NCIU A-06A 50883200260100 225071 11/28/2025 AK E-LINE Perf/Plug T41270 NCIU A-08 50883200280000 169063 12/2/2025 AK E-LINE GPT T41271 NCIU A-19 50883201940000 224026 12/16/2025 AK E-LINE GPT T41272 NCIU A-19 50883201940000 224026 12/12/2025 AK E-LINE GPT/Perf/Plug T41272 NCIU A-19 50883201940000 224026 12/17/2025 AK E-LINE Perf T41272 NCIU A-21A 50883201990100 225075 12/30/2025 AK E-LINE PPROF T41273 OP19-T1N 50029234910000 213068 11/19/2025 AK E-LINE TubingPunch T41274 NCIU A-08 50883200280000 169063 12/2/2025 AK E-LINE GPT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.21 13:56:35 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PCU D-10 50283202080000 225082 12/9/2025 AK E-LINE Perf T41275 SCU 322C-04 50133101040100 215217 12/4/2025 AK E-LINE TubingPunch T41276 SRU 222-33 50133207150000 223100 12/7/2025 AK E-LINE Plug T41277 SU 43-10 50133207390000 225107 11/26/2025 AK E-LINE CBL T41278 TBU A-12RD 50733200760100 171029 11/29/2025 AK E-LINE Perf T41279 TBU D-24A 50733202240100 174064 12/2/2025 AK E-LINE TubingPunch T41280 TBU D-24A 50733202240100 174064 11/21/2025 AK E-LINE TubingPunch T41280 TBU M-10 50733205880000 209154 11/15/2025 AK E-LINE Perf T41281 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.21 13:56:51 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, April 11, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC A-08 N COOK INLET UNIT A-08 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/11/2024 A-08 50-883-20028-00-00 169-063-0 W SPT 3249 1690630 1500 0 0 0 0 0 0 0 0 INITAL P Kam StJohn 3/7/2024 MIT-IA; convert to WDSPL (Sundry 324-019) 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:N COOK INLET UNIT A-08 Inspection Date: Tubing OA Packer Depth 0 1710 1694 1681IA 0 0 45 Min 1669 60 Min Rel Insp Num: Insp Num:mitKPS240307174201 BBL Pumped:1.3 BBL Returned:0.7 Thursday, April 11, 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. You don't often get email from casey.morse@hilcorp.com. Learn why this is important From:Wallace, Chris D (OGC) To:Brooks, Phoebe L (OGC); AOGCC Records (CED sponsored) Subject:FW: Tyonek Platform NCIU A-08 Temperature Survey (PTD #1690630) Date:Wednesday, March 27, 2024 1:49:13 PM Attachments:NCIU A-8 Static 03-21-24.pdf From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Wednesday, March 27, 2024 9:34 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: Tyonek Platform NCIU A-08 Temperature Survey (PTD #1690630) Mr. Wallace, NCIU A-08 (PTD 1690630) was converted to a Class II disposal well in accordance with Sundry 323- 110, Sundry 324-019, and DIO 46. Per Rule 6 of DIO 46, Hilcorp is required to perform a baseline temperature survey and a subsequent temperature survey one month after injection begins to delineate the receiving zone of the injected fluids. A baseline temperature survey was conducted on 3/29/2023, injection began on 2/28/2024, and a subsequent temperature survey was conducted on 3/21/2024. The attached survey shows the comparison of the 2023 baseline and the recent survey from 3/21/2024. The temperature profiles confirm that all the injected fluids are being contained in the approved strata. Please let me know if you have any questions or require additional information. Thank you, Casey Morse Well Integrity Engineer Hilcorp Alaska, LLC (907) 777-8322 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Well: Field:03/21/2024HilcorpNCIU A-8 Tyonek Plt 30 40 50 60 70 80 0 500 1000 1500 2000 2500 3000 3500 4000 4500 0 250 500 750 1000 1250 1500 Temperature (Deg. F)Depth (feet) RKBPressure (psia) Pressure 24 Perfs PKR Press 23 Temperature 24 Temp 23 Pressure-Temperature Profile 1. RIH 2023 vs 2024 2. Static Report date: 3/26/2024 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. You don't often get email from casey.morse@hilcorp.com. Learn why this is important From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] RE: Tyonek NCIU A-08 / DIO 46 (PTD 1690630) Date:Tuesday, January 23, 2024 8:22:43 AM From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Wednesday, January 17, 2024 3:20 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com> Subject: RE: [EXTERNAL] RE: Tyonek NCIU A-08 / DIO 46 (PTD 1690630) Thank you, Chris. I will get a 10-403 sent in shortly to request changing the well to WDSPL. While pulling together the backup material for the 10-403 request, I realized that I mixed up some of the dates referenced below in my email. Just for clarification, we performed the temperature survey on the morning of 3/29/23, then began the injection test later that day and completed it on 3/30/23. Regards, Casey Morse Well Integrity Engineer Hilcorp Alaska, LLC (907) 777-8322 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Wednesday, January 17, 2024 8:46 AM To: Casey Morse <Casey.Morse@hilcorp.com> Cc: Juanita Lovett <jlovett@hilcorp.com> Subject: [EXTERNAL] RE: Tyonek NCIU A-08 / DIO 46 (PTD 1690630) Casey, This all looks good. When I check our database I see the well is still designated as 1-GAS. I see Sundry 323-110 was amended (by AOGCC) to be an injectivity test and not to actually convert the well as this was pre DIO 46 being issued. A separate sundry application 10-403 should be made to change the well to a WDSPL well. It can make mention of these steps performed previously as required by DIO 46. 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 casey.morse@hilcorp.com. Learn why this is important Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Tuesday, January 16, 2024 8:51 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com> Subject: Tyonek NCIU A-08 / DIO 46 Chris, Thanks for taking the time to discuss with me the requirements for starting injection on Tyonek NCIU A-08 as described in DIO 46 a couple weeks ago. Below are some follow-up items that came out of that discussion. As it pertains to DIO 46, Rule 6 states: The operator shall run a baseline temperature log and perform a baseline step-rate test prior to initial injection. A subsequent temperature log must be run one month after injection begins to delineate the receiving zone of the injected fluids. Hilcorp performed a temperature survey on 3/29/23, and we believe this survey accurately reflects the baseline temperature profile in the wellbore. Per Rule 6, Hilcorp will perform a subsequent temperature survey after one month of injection to delineate the receiving zone of the injected fluids. Hilcorp proposes to submit the results of the subsequent temperature survey overlayed with the temperature profile obtained on 3/29/23 for comparison. Hilcorp performed an injectivity test on 3/21/23. This test was performed using the installed injection equipment on the platform and reflected normal operating conditions for the system for both rate and pressure. During this injection cycle, pressures started at approximately 1700 psi and stabilized at approximately 1450 psi with a steady rate around 1 bpm. The injection test lasted for 28 hours and provides compelling evidence that we immediately approached radial flow, and the formation was not fractured during this period. The injection pump on the Tyonek is limited to a pressure of 2200 psi by the installed PSV, and the pump was operating fully open during the injection test. The pressure response observed throughout the injection test suggests that we did not induce fractures. As such, Hilcorp requests that the 3/21/23 injection test be accepted in lieu of an additional step-rate test to satisfy DIO 46 rule #6. DIO 46, Rule 4 states: The mechanical integrity of NCIU A-08 must be demonstrated before injection begins and before returning the well to service following a workover affecting mechanical integrity. An AOGCC-witnessed mechanical integrity test must be performed after injection is commenced for the first time in the well, to be scheduled when injection conditions (temperature, pressure, rate, etc.) have stabilized. Hilcorp performed MIT-IA on 3/20/23 as part of the workover activities described in Sundry 323- 110. Hilcorp requests that the 3/20/23 MIT-IA be accepted for satisfying the initial MIT-IA criteria for DIO 46 rule #4. After injection is commenced on the well, Hilcorp will notify AOGCC to witness a subsequent MIT-IA once injection conditions have stabilized. Please reach out to me with any questions or concerns about this request. I appreciate your help working through this with me. Thank you, Casey Morse Well Integrity Engineer Hilcorp Alaska, LLC (907) 777-8322 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,222 N/A Casing Collapse Structural Conductor 630psi Surface 2,090psi Intermediate Production 4,320psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Casey Morse Contact Email:Casey.Morse@hilcorp.com Contact Phone:(907) 777-8322 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: Chg Well Status to WDSPL DIO 46 2/1/2024 4-1/2" See schematic See schematic 9,222' Perforation Depth MD (ft): 4,103 - 4,180 9,222' 3,326 - 3,371 6,499'7" 386' 30" 16" 10-3/4" 623' 2,985' MD 1,640psi 3,580psi 623' 2,620' 623' 2,985' Length Size Proposed Pools: 386' 386' J-55 TVD Burst 5,892 4,980psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017589 / ADL0037831 169-063 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-883-20028-00-00 Hilcorp Alaska, LLC N Cook Inlet Unit A-08 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY North Cook Inlet Tertiary System Gas Same 6,499 4,181 3,371 N/A See schematic No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:08 am, Jan 18, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.01.18 05:17:52 - 09'00' Dan Marlowe (1267) 324-019 SFD 1/29/2024 Class II, DIO 46, CDW 01/29/2024 Sterling Undefined Waste Disposal SFD None required.x CDW 01/29/2024 Operation of well to be in accordance with DIO 46. Rule 6 post injection Temperature Survey and Rule 4 post injection witnessed MIT are required. BJM 1/30/24 DSR=1/26/24*&:JLC 1/31/2024 1/31/24Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2024.01.31 15:22:05 -09'00' RBDMS JSB 020124 1 Juanita Lovett From:Casey Morse Sent:Wednesday, January 17, 2024 3:20 PM To:Wallace, Chris D (OGC) Cc:Juanita Lovett Subject:RE: [EXTERNAL] RE: Tyonek NCIU A-08 / DIO 46 (PTD 1690630) Thank you, Chris. I will get a 10-403 sent in shortly to request changing the well to WDSPL. While pulling together the backup material for the 10-403 request, I realized that I mixed up some of the dates referenced below in my email.:ƵƐƚĨŽƌĐůĂƌŝĮĐĂƟŽŶ͕ǁĞ ƉĞƌĨŽƌŵĞĚƚŚĞƚĞŵƉĞƌĂƚƵƌĞƐƵƌǀĞǇŽŶƚŚĞŵŽƌŶŝŶŐŽĨϯͬϮϵͬϮϯ͕ƚŚĞŶďĞŐĂŶƚŚĞŝŶũĞĐƟŽŶƚest later that day and completed it on 3/30/23. Regards, Casey Morse Well Integrity Engineer Hilcorp Alaska, LLC (907) 777-8322 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Wednesday, January 17, 2024 8:46 AM To: Casey Morse <Casey.Morse@hilcorp.com> Cc: Juanita Lovett <jlovett@hilcorp.com> Subject: [EXTERNAL] RE: Tyonek NCIU A-08 / DIO 46 (PTD 1690630) Casey, This all looks good. tŚĞŶ/ĐŚĞĐŬŽƵƌĚĂƚĂďĂƐĞ/ƐĞĞƚŚĞǁĞůůŝƐƐƟůůĚĞƐŝŐŶĂƚĞĚĂƐϭ-GAS. I see Sundry 323-110 was amended (by AOGCC) to ďĞĂŶŝŶũĞĐƟǀŝƚǇƚĞƐƚĂŶĚŶŽƚƚŽĂĐƚƵĂůůǇĐŽŶǀĞƌƚƚŚĞǁĞůůĂƐƚŚŝƐǁĂƐƉƌĞ/KϰϲďĞŝŶŐŝƐƐƵĞĚ͘ ƐĞƉĂƌĂƚĞƐƵŶĚƌǇĂƉƉůŝĐĂƟŽŶϭϬ-403 should be made to change the well to a WDSPL well./ƚĐĂŶŵĂŬĞŵĞŶƟŽŶŽĨƚŚĞƐĞ steps performed previously as required by DIO 46. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7 th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax),chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. CAUTION:External sender. DO NOT open links or attachments from UNKNOWN senders. 2 From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Tuesday, January 16, 2024 8:51 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com> Subject: Tyonek NCIU A-08 / DIO 46 Chris, dŚĂŶŬƐĨŽƌƚĂŬŝŶŐƚŚĞƟŵĞƚŽĚŝƐĐƵƐƐǁŝƚŚŵĞƚŚĞƌĞƋƵŝƌĞŵĞŶƚƐĨŽƌƐƚĂƌƟŶŐŝŶũĞĐƟŽŶŽŶdǇŽŶĞŬE/h-08 as described in DIO 46 a couple weeks ago. Below are some follow-up items that came out of that discussion. As it pertains to DIO 46, Rule 6 states: x The operator shall run a baseline temperature log and perform a baseline step-ƌĂƚĞƚĞƐƚƉƌŝŽƌƚŽŝŶŝƟĂůŝŶũĞĐƟŽŶ͘ ƐƵďƐĞƋƵĞŶƚƚĞŵƉĞƌĂƚƵƌĞůŽŐŵƵƐƚďĞƌƵŶŽŶĞŵŽŶƚŚĂŌĞƌŝŶũĞĐƟŽŶďĞŐŝŶƐƚŽĚĞůŝŶĞĂƚĞƚŚĞƌĞĐĞŝǀŝŶŐǌŽŶĞŽĨ the injected Ňuids. Hilcorp performed a temperature survey on 3/29/23, and we believe this survey accurately reŇects the baseline temperature proĮle in the wellbore.WĞƌZƵůĞϲ͕,ŝůĐŽƌƉǁŝůůƉĞƌĨŽƌŵĂƐƵďƐĞƋƵĞŶƚƚĞŵƉĞƌĂƚƵƌĞƐƵƌǀĞǇĂŌĞƌŽŶĞŵŽŶƚŚ ŽĨŝŶũĞĐƟŽŶƚŽĚĞůŝŶĞĂƚĞƚŚĞƌĞĐĞŝǀŝŶŐǌŽŶĞŽĨƚŚĞŝŶũĞĐƚĞĚŇƵŝĚƐ͘ Hilcorp proposes to submit the results of the subsequent temperature survey overlayed with the temperature proĮle obtained on 3/29/23 for comparison. ,ŝůĐŽƌƉƉĞƌĨŽƌŵĞĚĂŶŝŶũĞĐƟǀŝƚǇƚĞƐƚŽŶϯͬϮϭͬϮϯ͘ dŚŝƐƚĞƐƚǁĂƐƉĞƌĨŽƌŵĞĚƵƐŝŶŐƚŚĞŝŶƐƚĂůůĞĚŝŶũĞĐƟŽŶĞƋƵŝƉŵĞŶƚŽŶƚŚĞ ƉůĂƞŽƌŵĂŶĚƌĞŇĞĐƚĞĚŶŽƌŵĂůŽƉĞƌĂƟŶŐĐŽŶĚŝƟŽŶƐĨŽƌƚŚĞƐǇƐƚĞŵĨŽƌďŽƚŚƌĂƚĞĂŶĚƉƌĞƐƐƵƌĞ͘ ƵƌŝŶŐƚŚŝƐŝŶũĞĐƟŽŶ cycle, pressures started at approximately 1700 psi and stabilized at approximately 1450 psi with a steady rate around 1 bpm.dŚĞŝŶũĞĐƟŽŶƚĞƐƚůĂƐƚĞĚĨŽƌϮϴŚŽƵƌƐĂŶĚƉƌŽǀŝĚĞƐĐŽŵƉĞůůŝŶŐĞǀŝĚĞŶĐĞƚŚĂƚǁĞŝŵŵĞĚŝĂƚĞůǇĂƉƉƌŽĂĐŚĞĚƌĂĚŝĂů ŇŽǁ͕ĂŶĚƚŚĞĨŽƌŵĂƟŽŶǁĂƐŶŽƚĨƌĂĐƚured during this period.dŚĞŝŶũĞĐƟŽŶƉƵŵƉŽŶƚŚĞdǇŽŶĞŬŝƐůŝŵŝƚĞĚƚŽĂƉƌĞƐƐƵƌĞ ŽĨϮϮϬϬƉƐŝďǇƚŚĞŝŶƐƚĂůůĞĚW^s͕ĂŶĚƚŚĞƉƵŵƉǁĂƐŽƉĞƌĂƟŶŐĨƵůůǇŽƉĞŶĚƵƌŝŶŐƚŚĞŝŶũĞĐƟŽŶƚĞƐƚ͘The pressure response ŽďƐĞƌǀĞĚƚŚƌŽƵŐŚŽƵƚƚŚĞŝŶũĞĐƟŽŶƚĞƐƚƐƵŐŐĞƐƚƐƚŚat we did not induce fractures.As such, Hilcorp requests that the ϯͬϮϭͬϮϯŝŶũĞĐƟŽŶƚĞƐƚďĞĂĐĐĞƉƚĞĚŝŶůŝĞƵŽĨĂŶĂĚĚŝƟŽŶĂůƐƚĞƉ-ƌĂƚĞƚĞƐƚƚŽƐĂƟƐĨǇ/KϰϲƌƵůĞηϲ͘ DIO 46, Rule 4 states: x The mechanical integrity of NCIU A-ϬϴŵƵƐƚďĞĚĞŵŽŶƐƚƌĂƚĞĚďĞĨŽƌĞŝŶũĞĐƟŽŶďĞŐŝŶƐĂŶĚďĞĨŽƌĞƌĞƚƵƌŶŝŶŐƚŚĞ ǁĞůůƚŽƐĞƌǀŝĐĞĨŽůůŽǁŝŶŐĂǁŽƌŬŽǀĞƌĂīĞĐƟŶŐŵĞĐŚĂŶŝĐĂůŝŶƚĞŐƌŝƚǇ͘ŶK'-witnessed mechanical integrity ƚĞƐƚŵƵƐƚďĞƉĞƌĨŽƌŵĞĚĂŌĞƌŝŶũĞĐƟŽŶŝƐĐŽŵŵĞŶĐĞĚĨŽƌƚŚĞĮƌƐƚƟŵĞŝŶƚŚĞǁĞůů͕ƚŽďĞƐĐŚĞĚƵůĞĚǁŚĞŶŝŶũĞĐƟŽŶ ĐŽŶĚŝƟŽŶƐ;ƚĞŵƉĞƌĂƚƵƌĞ͕ƉƌĞƐƐƵƌĞ͕ƌĂƚĞ͕ĞƚĐ͘ͿŚĂǀĞƐƚĂďŝůŝǌĞĚ͘ Hilcorp performed MIT-/ŽŶϯͬϮϬͬϮϯĂƐƉĂƌƚŽĨƚŚĞǁŽƌŬŽǀĞƌĂĐƟǀŝƟĞƐĚĞƐĐƌŝďĞĚŝŶ^ƵŶĚƌǇϯϮϯ-110. Hilcorp requests that the 3/20/23 MIT-/ďĞĂĐĐĞƉƚĞĚĨŽƌƐĂƟƐĨǇŝŶŐƚŚĞŝŶŝƟĂůD/d-IA criteria for DIO 46 rule #4.ŌĞƌŝŶũĞĐƟŽŶŝƐ ĐŽŵŵĞŶĐĞĚŽŶƚŚĞǁĞůů͕,ŝůĐŽƌƉǁŝůůŶŽƟĨǇK'ƚŽǁŝƚŶĞƐƐĂƐƵďƐĞƋƵĞŶƚD/d-/ŽŶĐĞŝŶũĞĐƟŽŶĐŽŶĚŝƟŽŶƐŚĂǀĞ stabilized. WůĞĂƐĞƌĞĂĐŚŽƵƚƚŽŵĞǁŝƚŚĂŶǇƋƵĞƐƟŽŶƐŽƌĐŽŶĐĞƌŶƐĂďŽƵƚƚŚŝƐƌĞƋƵĞƐƚ͘ I appreciate your help working through this with me. Thank you, Casey Morse Well Integrity Engineer You don't often get email from casey.morse@hilcorp.com.Learn why this is important 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. 3 Hilcorp Alaska, LLC (907) 777-8322 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. 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No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. _____________________________________________________________________________________ Updated By: JLL 04/21/23 SCHEMATIC North Cook Inlet Unit Well: NCIU A-08 PTD: 169-063 API: 50-883-20028-00 No Depth (MD) Depth (TVD)ID Item 38.9' 39' 4.500 FMC Tubing Hanger 1 291' 291' 3.813 Otis SCSSV Landing Nipple (No valve installed as of 3/9/23) 2 4,232’ 3,401’ CIBP w/25’ cement – Calc TOC 4,181’ (3/20/23) 3 4,400’ 3,265’ CIBP w/5’ of cmt TOC 4,395’ (7/8/20) 4 4,487’ 3,547’ Cement Retainer (7/3/20) 5 4,512’ 3,561’ 3.375 Permanent patch from 4512’ – 4534’ MD 6 4,545' 3,580' 3.880 Halliburton VSR Packer (Retrievable w/tubing adapter) 7 4,560 3,588’ CIBP w/5’ of cmt TOC 4,554’ (6/29/20) 8 4,613' 3,619' 3.813 Halliburton X Nipple 9 4,850’ 3,758’ - 4-1/2” CIBP w/5’ cmt. TOC at 4,840’ 10 4,891' 3,783' 3.970 Halliburton MHR Packer (Permanent) 11 5,361' 4,072' 3.970 Halliburton MHR Packer (Permanent) 12 5,496' 4,158' 3.970 Halliburton MHR Packer (Permanent) 13 5,699' 4,287' 3.970 Halliburton MHR Packer (Permanent) 14 5,892’ 4,412’ 3.958” WLEG 15 6,031’ 4,503’ >6.276 7” cement stage collar OPEN HOLE / CEMENT DETAIL 16”22” Hole: Pumped 462sxs (220bbls) 11.5ppg type G lead followed by 125sxs (24bbls) 15.6ppg class G tail. Volumetric ToC suggests at surface (no notes) 10-3/4" 15” hole: 700sxs (330bbls) of 11.5ppg class G lead followed by 125sxs (24bbls) of 15.0ppg class G tail. Found cement inside casing at 2800’ MD.Volumetric annular ToC assuming 30% washout = 525’ MD 7" 9-5/8" hole: Pumped 545sxs (132bbls) of 13.3ppg Class G primary cement job. Volumetrics using OH caliper put ToC at ~7700’ MD. 2nd stage through DV collar at 6031' pumped 860sxs (168 bbls) of 15.6ppg class G. 7/23/69 CBL showed ToC at 3,012’ 4-1/2” x 7” annulus 7/3/20: CT pumped 12bbls of 15.3ppg cement through cement retainer at 4500’ MD. Worst case ToC volumetrically should be 3950’ MD.7/4/2020 RCBL shows great cement below 4010’ MD, and patchy cement up to 3895’PBTD: 4,148’ TD: 9,222’ 2 30” RKB: MSL = 96’ 7” 8 9 14 15 Tubing Punch through patch 4,516’ – 4,518’ (6/30/20) 10-3/4” 16” 1 Parted Casing below EZSV @ 7,182’ Tubing Punch 4,635’ Sterling Y Sterling X 4 6 7 10 11 12 13 5 Sterling X X 3 2 CASING DETAIL Size Wt Grade Conn ID Top Btm 30” H-40 STC 28.000 Surf 386’ 16” 65 H-40 STC 15.250 Surf 623’ 10-3/4” 45.5 J-55 BTC 9.794 Surf 2,985’ 7” 26 J-55 BTC 6.276 Surf 9,222’ TUBING DETAIL 4-1/2” 12.75 J-55 EUE 8rd 3.958 Surf 5,892’ Updated By: JLL 04/21/23 SCHEMATIC North Cook Inlet Unit Well: NCI A-08 Last Completed: 06/17/1994 PTD: 169-063 API: 50-883-20028-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Sterling 4,103’ 4,121’ 3326 3336 18’ 03/19/23 Open Sterling 4,126’ 4,144’ 3339 3350 18’ 03/20/23 Open Sterling 4,144’ 4,162’ 3350 3360 18’ 03/19/23 Open Sterling 4,162’ 4,180’ 3359 3371 18’ 03/18/23 Open Sterling X 4,344 4,362 3,465 3,476 18' 07/10/20 Isolated (3/9/23) Sterling Y 4,425 4,439 3,511 3,519 14’ 07/05/20 Isolated (7/8/20) B 4,635’ 4,650’ 3,631’ 3,640’ 15’ 06/29/20 Isolated B 4,635' 4,735' 3,631' 3,690' 100' 6/2/1994 CMT SQZD CI-1 4,979' 5,036' 3,836' 3,870' 57' 05/05/20 Isolated CI-2 5,061' 5,161' 3,885' 3,947' 100' 05/05/20 Isolated CI-3 5,191' 5,211' 3,965' 3,977' 20' 05/05/20 Isolated CI-3.1 5,240' 5,250' 3,996' 4,002' 10' 05/05/20 Isolated CI-4 5,266' 5,283' 4,012' 4,023' 17' 05/05/20 Isolated CI-4 5,288' 5,325' 4,026' 4,049' 37' 05/05/20 Isolated CI-5 5,388' 5,438' 4,089' 4,121' 50' 05/05/20 Isolated CI-6.2 5,563' 5,570' 4,200' 4,204' 7' 05/05/20 Isolated CI-7 5,580' 5,596' 4,211' 4,221' 16' 05/05/20 Isolated CI-7 5,600' 5,624' 4,227' 4,242' 24' 05/05/20 Isolated CI-8.2 5,743' 5,753' 4,315' 4,322' 10' 05/05/20 Isolated CI-9.1 5,837' 5,845' 4,376' 4,381' 8' 05/05/20 Isolated CI-10 5,855' 5,885' 4,387' 4,407' 30' 05/05/20 Isolated A-3 6,014' 6,015' 4,492' 4,493' 1'8/3/1969 CMT SQZD B-6 6,302' 6,310' 4,679' 4,684' 8'8/3/1969 CMT SQZD E-8, E-9 7,030' 7,067' 5,113' 5,135' 37'8/4/1969 ISOLATED F-4, F-5 7,197' 7,214' 5,211' 5,221' 17'8/4/1969 ISOLATED F-6 7,218' 7,238' 5,224' 5,235' 20'8/4/1969 ISOLATED G-1 7,309' 7,326' 5,280' 5,290' 17'8/4/1969 ISOLATED G-4 7,388' 7,398' 5,330' 5,336' 10'7/30/1969 ISOLATED H-1 7,478' 7,488' 5,386' 5,392' 10'8/4/1969 ISOLATED H-3 7,513' 7,538' 5,408' 5,424' 25'8/4/1969 ISOLATED H-6 7,583' 7,598' 5,452' 5,461' 15'8/4/1969 ISOLATED I-7 7,822' 7,828' 5,601' 5,605' 6'7/27/1969 ISOLATED K-2 8,008' 8,018' 5,719' 5,725' 10'8/4/1969 ISOLATED M-2 8,180' 8,185' 5,826' 5,829' 5'8/4/1969 ISOLATED M-10 8,307' 8,314' 5,906' 5,910' 7'8/4/1969 ISOLATED N-2 8,375' 8,425' 5,949' 5,982' 50'7/24/1969 ISOLATED Rig Start Date End Date Eline 3/5/23 3/29/23 03/05/2023 - Sunday MIT-IA 4-1/2" x 7" Annulus to 1,500psi charted for 30min - Test good 0 / 15 / 30 min pressures: 1712 / 1673 / 1654 for losses of 39 followed by 19psi Overall loss <4% Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-08 50-883-20028-00-00 169-063 PJSM and PTW SITP 10psi Production filled the tubing overnight, took 13BBL. M/U and RIH with 1.6875" OD CCL and weight bars, tag CIBP at 4231.6ft' no issues . POOH M/U and RIH with 2.75" OD Junk Basket, CCL and weight bars, tag CIBP at 4231.6ft' no issues . POOH Fly 2.5" OD cement bailer out to the platform. M/U and RIH with 20Ft x 2.5" OD Cement dump bailer, set down at 4,063' (168ft high). Work tools with no luck. POOH. M/U and RIH with 10Ft x 2.5" OD empty dump bailer, set down at 4,063' (168ft high). POOH. Secure well and RD AK E-line. 03/09/2023 - Thursday PJSM and PTW SITP 40psi. R/U AK E-line. M/U CCL and 4.5" 10k-psi CIBP (3.5"OD) CCL to plug 7.6ft. Pressure test lubricator to 250psi/1500psi - Test good. RIH w/ CIBP. Work plug down as deep as we could get it and set CIBP at 4231.6'. RIH and tag plug, verify good set. POOH. M/U and RIH with 3.5"OD x 20ft cement dump bailer. Sat down at 890' and couldn't work through. POOH. M/U and RIH with 1.6875" OD CCL and weight bars to 1,100' no issues. POOH. M/U and RIH with 3.5"OD x 20ft empty dump bailer to 1,100' no issues. POOH. M/U and RIH with 3.5"OD x 20ft cement dump bailer. Sat down at 4057' (149' high) worked tools with no luck. POOH. Lay down the lubricator. Secure well and SDFN. 03/10/2023 - Friday Rig Start Date End Date Eline 3/5/23 3/29/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-08 50-883-20028-00-00 169-063 03/12/2023 - Sunday Rig up on well. PT 250/1500 PSI- pass. Rih w/ 4 1/2 BLB to 4020' kb, w/t 4051' kb, pooh. Rih w/ 3.5" X 8' DD Bailer to 4020' kb, w/t 4061' kb, pooh, ooh w/ 1 gal of mud. Rih w/ same to 4063' kb, w/t fall to 4128' kb, dont work tools, pooh. Rih w/ Brush to 4100' kb, w/t 4236' kb, brush between 4000-4238' kb 20 X, fall very slow every time, does not seem to improve. Rih w/ 3.5 LIB to 4236' kb, w/t pooh, inconclusive marks. (did not have good spang action). Rih w/ 3.5 X14' DD Bailer to 4236' kb, w/t pooh. Ooh full thin mud. Rih w/ 2.87 X 20' dummy guns to 4236' kb, w/t pooh. Ooh w/ tools, rig down. 03/13/2023 - Monday PJSM and PTW Spot equipment and R/U on well M/U 5' weight bar, and 3.5"OD x 20' dump bailer Pressure test lubricator to 250psi/1500psi - Test Good. RIH with weight bar, and 3.5"OD x 20' EMPTY dump bailer, set down at 4,005ft (226ft high). Work tools. POOH Bailer has 2ft of packed sand in the bottom. Secure well RD AK E-line Set-up Slickline to come out and bail. Rig Start Date End Date Eline 3/5/23 3/29/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-08 50-883-20028-00-00 169-063 03/14/2023 - Tuesday MIT-T 4-1/2" to 1,500psi charted for 30min - Test good 0 / 15 / 30 min pressures: 1760 / 1749 / 1745 for losses of 11 followed by 4psi Overall loss <1% Test against CIBP at 4,231' w/o cement. PJSM and PTW RU Pollard SL SITP zero psi Pressure test lubricator to 250psi/1500psi - Test good. Rih w/ 3 1/2''x10' dd bailer w/ flapper bottom to 4033'kb w/ tool to 4054'kb pooh fluid only Rih w/ same w/ castle bottom to 4056'kb w/ tool to 4068'kb pooh full thick fluid Rih w/ same w/ ball bottom to 4066'kb w/ tool 4078'kb pooh full same Rih w/ 4 1/2'' braided line brush 4052'kb w/ tool to 4085'kb pooh Rih w/ 3''x6' dd bailer to 4088'kb w/ tool 4096'kb pull up 15' rih to 4089'kb w/ tool to 4106'kb pooh full fluid. Rih w/ 3 1/2''x14' pump bailer to 4050'kb sit falling slow to 4068'kb w/ tool 4076'kb pooh full thin mud Secure well SDFN 03/15/2023 - Wednesday PJSM and PTW Build lubricator. Stab on riser p/t to 1500psi good test Rih w/ 3 1/2''x14' pump bailer to 4053'kb falling slow to 4080'kb would not fall w/ tool pooh full thick mud Rih w/ same to 4083'kb w/ tool to 4089'kb pooh full same Rih w/ same to 4083'kb w/ tool to 4097'kb pooh full same Rih w/ same to 4085'kb w/ tool to 4115'kb pooh full same;Rih w/ same to 4108'kb w/ tool to 4125'kb pooh full same Rih w/ same to 4104'kb w/ tool to 4120'kb pooh full same Rih w/ same to 4119'kb w/ tool to 4123'kb pooh full same Rih w/ 4 1/2'' braided line brush to 4127'kb w/ tool to would not fall make several passes from 4000' to 4127'kb pooh Lay down lub. Cut wire rehead check toolstring Secure well and SDFN MIT-T 4-1/2" to 1,500psi charted for 30min - Test good Test against CIBP at 4,231' w/o cement. Rig Start Date End Date Eline 3/5/23 3/29/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-08 50-883-20028-00-00 169-063 03/16/2023 - Thursday PJSM and PTW P/U lub. build 3 1/2'' bailer Stab on riser Rih w/ 3 1/2''x14' pump bailer to 4121'kb w/ tool to 4127'kb pooh full thick mud Rih w/ same to 4125'kb w/ tool to 4127'kb pooh full same Rih w/ same to 4130'kb w/ tool 4131'kb pooh full same Rih w/ same to 4135'kb w/ tool pooh full same Rih w/ same to 4140'kb w/ tool pooh full same;Rih w/ same to 4147'kb w/ tool pooh full same Rih w/ same to 4152'kb w/ tool pooh full same Rih w/ same to 4160'kb w/ tool pooh full same Rih w/ same to 4182'kb w/ tool pooh full same Rih w/ 4 1/2'' braided line brush to 4196'kb tag fill w/ tool from 4000' to 4195' make several passes Lay down lub Secure well and SDFN 03/17/2023- Friday Morning meeting JSA permit p/u lub. Build bailer Rih w/ 3 1/2''x14' pump bailer falling slow from 4160' to 4189'kb w/ tool pooh full thick mud Rih w/ same to 4206'kb w/ tool pooh full same Rih w/ same to 4214'kb w/ tool pooh full same Rih w/ same falling slow from 4175' to 4235'kb w/ tool pooh full same Rih w/ same falling slow from 4179' to 4237'kb w/ tool pooh full same;Rih w/ same falling slow from 4180' to 4234'kb w/ tool pooh full same Rih w/ same falling slow from 4195' to 4235'kb w/ tool pooh full mud getting thinner Rih w/ same to 4236'kb sit w/ tool pooh full thinner fluid Rih w/ same to 4236'kb w/ tool pooh full thick fluid Remove knuckle joint Rih w/ 2 7/8''x20' spent dummy guns 250fpm to 3900' slow to 100fpm to 4234'kb;Break off dummy guns, lay down lub. Secure well for night Rig Start Date End Date Eline 3/5/23 3/29/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-08 50-883-20028-00-00 169-063 03/18/2023 - Saturday Morning meeting JSA and PTW p/u lub. Build bailer RIH w/ 3 1/2''x14' pump bailer to 4232'kb. POOH full of mud with a 1ft sand plug on bottom (CIBP is at 4,232') RIH w/ 3 1/2''x14' pump bailer to 4232'kb. POOH full of thinner mud, no course sand. RIH w/ 2 7/8''x20' spent dummy guns to 4232'kb RD Slickline;RU AK E-line M/U 3.125"OD gun gamma, 2-3/4" x 18ft Geodynamics gun 6spf, 15gm. (CCL to top shot 9.0') Pressure test lubricator to 250psi/2500psi - Test good Pressure up tubing to 300psi, bleed off IA to 25psi. Tag CIBP at 4,232ft. Pull the correlation logs and send to town. On depth;Pull on depth and perforate the Sterling injection sands from 4,162 - 4,180'. POOH, All shots fired T/IA 0min - 538psi/33psi 5min - 33psi/5psi Turn on the injection charge pump to keep the tubing at 100psi. Well taking ~1BPH;M/U and RIH w/ 3.5"x20' empty dump bailer with glass bottom. Tag at 4,225' (6.5ft high). POOH;M/U and RIH w/ 3.5"x20' cement dump bailer. Tag at 4,203' (28ft high). POOH without dumping cement;Lay down lubricator Secure well and SDFN Production will run injectivity test overnight perforate the Sterling injection sands from 4,162 - 4,180'. Turn on the injection charge pump to keep the tubing at 100psi. Well taking ~1BPH; Tag CIBP at 4,232ft. Rig Start Date End Date Eline 3/5/23 3/29/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-08 50-883-20028-00-00 169-063 03/19/2023 - Sunday Injection test overnight. 3X attempts @ 0.9BPM, the well pressured up to 1,500psi in 2-4min. PJSM and PTW. Re-head E-line and M/U CCL 2.75"OD CCL, 2-3/4" x 18ft Geodynamics gun 6spf, 15gm. (CCL to top shot 5.5')Pressure up tubing to 100psi, IA @ 0psi Tag at 4212ft. Pull the correlation logs and send to town. On depth;Pull on depth and perforate the Sterling injection sands from 4,144 - 4,162'. POOH, All shots fired T/IA 0min - 126psi/0psi 5min - 97psi/6psi Once out of the hole perform an injection test. Pressured up to 1,500psi in 90seconds @ 0.9BPM. Pressure up IA to 1000psi holds steady;M/U CCL 2.75"OD CCL, 2-3/4" x 18ft Geodynamics gun 6spf, 15gm. (CCL to top shot 5.7') Pressure up tubing to 100psi, IA @ 1000psi Tag at 4220'. Pull the correlation logs and send them to town. On depth;Pull on depth and perforate the Sterling injection sands from 4,103 - 4,121'. POOH, All shots fired T/IA 0min - 97psi/930psi 5min - 97psi/930psi RIH with spent gun and tag at 4,217';Once out of the hole perform an injection test. Cycle injection pressure 7 times working up 50psi per cycle. Well started taking 0.9BPM at 1862psi, tubing pressure slowly dropped to 1685psi after 1hr of injecting at 0.9BPM IA pressure bled down to 150psi and is holding steady. Lay down AK E-line, secure well, SDFN Production to inject and monitor overnight;Injected produced water at 1325bwpd rate (0.92bpm) from 16:00 - 23:59 (8hrs). Final injection pressure at midnight had fallen to 1520psi. Injected 440 total bbls on 3/19/23 with an average WHIP = 1635psi;Cum daily injection: 440bbls Cum injection for project: 440bbls perforate the Sterling injection sands from 4,144 - 4,162' tubing pressure slowly dropped to 1685psi after 1hr of injecting at 0.9BPM Production to inject and monitor overnight;Injected produced water at 1325bwpd rate (0.92bpm) e perform an injection test. Well started taking 0.9BPM at 1862psi, Final injection pressure at midnight had fallen to 1520psi. Injected 440 total bbls on 3/19/23 with an average WHIP = 1635psi; Pressured up to 1,500psi in 90seconds @ 0.9BPM. Pressure up IA to 1000psi holds steady; RIH with spent gun and tag at 4,217'; perforate the Sterling injection sands from 4,103 - 4,121'. Rig Start Date End Date Eline 3/5/23 3/29/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-08 50-883-20028-00-00 169-063 03/20/2023 - Monday Continued injecting produced water after midnight at 1325bwpd (0.92bpm). Injected from 00:00 - 2:00 (2 hrs). 110 total bbls injected since midnight at an average WHIP = 1520psi.;MIT-IA 4-1/2" x 7" Annulus to 1,500psi charted for 30min - Test good 0 / 15 / 30 min pressures: 1619 / 1614 / 1616 for losses of 10 followed by +2psi Overall loss <1% MIT-IA done while injecting warm fluids;PJSM and PTW MIT-IA 4-1/2" x 7" Annulus to 1,500psi for 30min - Test good Gauge was not recording MIT-IA done with injection offline R/U AK E-line;M/U CCL 3.125"OD CCL, 2-3/4" x 18ft Geodynamics gun 6spf, 15gm. (CCL to top shot 5.5') Pressure up tubing to 100psi, IA @ 17psi Tag at 4,220'. Pull the correlation logs and send them to town. On depth;Pull on depth and perforate the Sterling injection sands from 4,126' - 4,144'. POOH, All shots fired T/IA 0min - 100psi/17psi 5min - 100psi/17psi RIH with spent gun and tag at 4,220' Perform injection test at 0.9BPM for 1hr, maximum pressure seen 1722psi final injection pressure 1649psi;Resume injection of produced water at 1325bwpd (0.92bpm). Injected from 10:00 - 11:00 (1 hr). 60 bbls injected at an average WHIP = 1670psi.;Re-test MIT with chart recording MIT-IA 4-1/2" x 7" Annulus to 1,500psi charted for 30min - Test good 0 / 15 / 30 min pressures: 1619 / 1567 / 1549 for losses of 52 followed by 18psi Overall loss <5% MIT-IA done with injection offline;M/U 2.5"ODx20ft cement dump bailer. RIH, tag at 4,207'. Pick-up and dump 6.5' of cement. POOH. RIH w/ 2.5"ODx20ft cement dump bailer. Dump 6.5' of cement. POOH RIH w/ 2.5"ODx20ft cement dump bailer. Dump 6.5' of cement. POOH RIH w/ 2.5"ODx20ft cement dump bailer. Dump 6.5' of cement. POOH Calc TOC 4,181';RD AK-Eline;Cum daily injection: 170bbls Cum injection for project: 610bbls Pick-up and dump 6.5' of cement. POOH. MIT-IA 4-1/2" x 7" Annulus to 1,500psi charted for 30min - Test good MIT-IA 4-1/2" x 7" Annulus to 1,500psi for 30min - Test good perforate the Sterling injection sands from 4,126' - 4,144' Calc TOC 4,181'; Rig Start Date End Date Eline 3/5/23 3/29/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-08 50-883-20028-00-00 169-063 Continued produced water injection from midnight to 16:30. WHIP continued to fall from 1585 at midnight and stabilized out at 1460psi. Rates stayed around 0.9bpm IAP stabilized at ~400psi. Cum daily injection: 915bbls Cum injection for project: 1885bbls 03/28/2023 - Tuesday Rig up slickline p/t lub. To 1500psi good test. Rih w/ 1 3/4''x4' dd bailer to 4175'kb tag w/ tool pooh w/ thick cement. Rih w/ tri-gauge to 4140' @ 100fpm see stop sheet for stops. Ooh down load data-good. Rig down slickline secure well for production. Brought well on, produced water injection at 1710psi. Injected for 6hrs till midnight. Injection pressure slowly fell to 1585psi by midnight. IA pressure climbs form 91p si to 370psi by midnight (thermal). 340bbls injected today at an average rate of ~0.9bpm. Cum daily injection: 360bbls Cum injection for project: 970bbls 03/29/2023 - Wednesday David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: David.Douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 6/21/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: NCIU A-08 PTD: 169-063 API: 50-883-20028-00-00 CEMENT BOND LOG 23-JULY-1969 Scanned Log Print - (PDF and TIF Format) Please include current contact information if different from above. PTD: 169-063 T37776 Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.21 13:44:26 -08'00' Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 04/14/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230414 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPF-81 50029229590000 200066 3/29/2023 READ CaliperSurvey MPI-04A 50029220680100 201092 4/2/2023 READ CaliperSurvey MPI-27 50029236920000 221013 4/2/2023 READ CaliperSurvey MPI-27 50029236920000 221013 3/20/2023 READ CaliperSurvey MPL-12 50029223340000 193011 4/2/2023 READ CaliperSurvey MPU I-27 50029236920000 221013 3/23/2023 READ LeakPointSurvey PBU 09-23A 50029210660100 198044 3/28/2023 READ MultipleArrayProductionProfile PBU L-112A 50029231290100 222138 3/27/2023 READ MemoryRadialCementBondLog END 1-11 50029221070000 190157 3/19/2023 AK E-LINE Perf END 1-29 50029216690000 186181 2/9/2023 AK E-LINE Perf NCI A-08 50883200280000 169063 3/20/2023 AK E-LINE Perf BCU 19RD 50133205790100 219188 4/4/2023 AK E-LINE PPROF SRU 224-10 50133101380100 222124 3/31/2023 AK E-LINE CIBP_GPT_Perf SRU 224-10 50133101380100 222124 4/3/2023 AK E-LINE GPT_Perf SRU 231-33 50133101630100 223008 3/29/2023 AK E-LINE GPT Please include current contact information if different from above. T37595 T37596 T37599 T37599 T37597 T37599 T37598 T37601 T37603 T37600 T37602 T37594 T37604 T37604 T37605 NCI A-08 50883200280000 169063 3/20/2023 AK E-LINE Perf Kayla Junke Digitally signed by Kayla Junke Date: 2023.04.17 14:10:44 -08'00' From:McLellan, Bryan J (OGC) To:Ryan Rupert Cc:Karson Kozub - (C); Dan Marlowe; Juanita Lovett Subject:RE: [EXTERNAL] RE: NCIU A-08 Injectivity test (PTD# 169-063) Date:Wednesday, March 15, 2023 3:16:00 PM Ryan, My mistake. I meant to say. Confirm TOC with wireline tag before adding additional perfs below 4180’ md, before step 7. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Wednesday, March 15, 2023 3:13 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Karson Kozub - (C) <kkozub@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com> Subject: RE: [EXTERNAL] RE: NCIU A-08 Injectivity test (PTD# 169-063) Tag ToC before step #7 below? There is currently no cement on top of the plug Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, March 15, 2023 3:11 PM To: Ryan Rupert <Ryan.Rupert@hilcorp.com> Cc: Karson Kozub - (C) <kkozub@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com> Subject: [EXTERNAL] RE: NCIU A-08 Injectivity test (PTD# 169-063) 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Injectivity Test Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9,222 feet See schematic feet true vertical 6,499 feet N/A feet Effective Depth measured 4,181 feet See schematic feet true vertical 3,371 feet See schematic feet Perforation depth Measured depth 4,103 - 4,180 feet True Vertical depth 3,326 - 3,371 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.75# / J-55 5,892 (MD) 4,412 (TVD) Packers and SSSV (type, measured and true vertical depth) See schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Tertiary System Gas 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 100 323-110 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ryan Rupert Ryan.Rupert@hilcorp.com 907 777-8503Operations Manager N/A 386 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 386 N/A 0 Size 386 623 0 10 0 2440 10-3/4" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 169-063 50-883-20028-00-00 3. Address: Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0017589 / ADL0037831 North Cook Inlet / Tertiary System Gas N Cook Inlet Unit A-08 Plugs Junk measured Length measured TVD Production Liner 9,222 Casing Structural 6,4999,222 623 2,985 623Conductor Surface Intermediate 30" 16" 4,320psi 1,640psi 3,580psi 4,980psi 2,985 2,620 Burst Collapse 630psi 2,090psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Kayla Junke at 10:58 am, Apr 24, 2023 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.04.21 14:56:06 - 08'00' Dan Marlowe (1267) _____________________________________________________________________________________ Updated By: JLL 04/21/23 SCHEMATIC North Cook Inlet Unit Well: NCIU A-08 PTD: 169-063 API: 50-883-20028-00 No Depth (MD) Depth (TVD)ID Item 38.9' 39' 4.500 FMC Tubing Hanger 1 291' 291' 3.813 Otis SCSSV Landing Nipple (No valve installed as of 3/9/23) 2 4,232 3,401 CIBP w/25 cement Calc TOC 4,181 (3/20/23) 3 4,400 3,265 CIBP w/5 of cmt TOC 4,395 (7/8/20) 4 4,487 3,547 Cement Retainer (7/3/20) 5 4,512 3,561 3.375 Permanent patch from 4512 4534 MD 6 4,545' 3,580' 3.880 Halliburton VSR Packer (Retrievable w/tubing adapter) 7 4,560 3,588 CIBP w/5 of cmt TOC 4,554 (6/29/20) 8 4,613' 3,619' 3.813 Halliburton X Nipple 9 4,850 3,758 - 4-1/2 CIBP w/5 cmt. TOC at 4,840 10 4,891' 3,783' 3.970 Halliburton MHR Packer (Permanent) 11 5,361' 4,072' 3.970 Halliburton MHR Packer (Permanent) 12 5,496' 4,158' 3.970 Halliburton MHR Packer (Permanent) 13 5,699' 4,287' 3.970 Halliburton MHR Packer (Permanent) 14 5,892 4,412 3.958 WLEG 15 6,031 4,503 >6.276 7 cement stage collar OPEN HOLE / CEMENT DETAIL 1622 Hole: Pumped 462sxs (220bbls) 11.5ppg type G lead followed by 125sxs (24bbls) 15.6ppg class G tail. Volumetric ToC suggests at surface (no notes) 10-3/4" 15 hole: 700sxs (330bbls) of 11.5ppg class G lead followed by 125sxs (24bbls) of 15.0ppg class G tail. Found cement inside casing at 2800 MD.Volumetric annular ToC assuming 30% washout = 525 MD 7" 9-5/8" hole: Pumped 545sxs (132bbls) of 13.3ppg Class G primary cement job. Volumetrics using OH caliper put ToC at ~7700 MD. 2nd stage through DV collar at 6031' pumped 860sxs (168 bbls) of 15.6ppg class G. 7/23/69 CBL showed ToC at 3,012 4-1/2 x 7 annulus 7/3/20: CT pumped 12bbls of 15.3ppg cement through cement retainer at 4500 MD. Worst case ToC volumetrically should be 3950 MD.7/4/2020 RCBL shows great cement below 4010 MD, and patchy cement up to 3895PBTD:4,148 TD:9,222 2 30 RKB: MSL = 96 7 8 9 14 15 Tubing Punch through patch 4,516 4,518 (6/30/20) 10-3/4 16 1 Parted Casing below EZSV @ 7,182 Tubing Punch 4,635 Sterling Y Sterling X 4 6 7 10 11 12 13 5 Sterling X X 3 2 CASING DETAIL Size Wt Grade Conn ID Top Btm 30 H-40 STC 28.000 Surf 386 16 65 H-40 STC 15.250 Surf 623 10-3/4 45.5 J-55 BTC 9.794 Surf 2,985 7 26 J-55 BTC 6.276 Surf 9,222 TUBING DETAIL 4-1/2 12.75 J-55 EUE 8rd 3.958 Surf 5,892 Updated By: JLL 04/21/23 SCHEMATIC North Cook Inlet Unit Well: NCI A-08 Last Completed: 06/17/1994 PTD: 169-063 API: 50-883-20028-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Sterling 4,103 4,121 3326 3336 18 03/19/23 Open Sterling 4,126 4,144 3339 3350 18 03/20/23 Open Sterling 4,144 4,162 3350 3360 18 03/19/23 Open Sterling 4,162 4,180 3359 3371 18 03/18/23 Open Sterling X 4,344 4,362 3,465 3,476 18' 07/10/20 Isolated (3/9/23) Sterling Y 4,425 4,439 3,511 3,519 14 07/05/20 Isolated (7/8/20) B 4,635 4,650 3,631 3,640 15 06/29/20 Isolated B 4,635' 4,735' 3,631' 3,690' 100' 6/2/1994 CMT SQZD CI-1 4,979' 5,036' 3,836' 3,870' 57' 05/05/20 Isolated CI-2 5,061' 5,161' 3,885' 3,947' 100' 05/05/20 Isolated CI-3 5,191' 5,211' 3,965' 3,977' 20' 05/05/20 Isolated CI-3.1 5,240' 5,250' 3,996' 4,002' 10' 05/05/20 Isolated CI-4 5,266' 5,283' 4,012' 4,023' 17' 05/05/20 Isolated CI-4 5,288' 5,325' 4,026' 4,049' 37' 05/05/20 Isolated CI-5 5,388' 5,438' 4,089' 4,121' 50' 05/05/20 Isolated CI-6.2 5,563' 5,570' 4,200' 4,204' 7' 05/05/20 Isolated CI-7 5,580' 5,596' 4,211' 4,221' 16' 05/05/20 Isolated CI-7 5,600' 5,624' 4,227' 4,242' 24' 05/05/20 Isolated CI-8.2 5,743' 5,753' 4,315' 4,322' 10' 05/05/20 Isolated CI-9.1 5,837' 5,845' 4,376' 4,381' 8' 05/05/20 Isolated CI-10 5,855' 5,885' 4,387' 4,407' 30' 05/05/20 Isolated A-3 6,014' 6,015' 4,492' 4,493' 1'8/3/1969 CMT SQZD B-6 6,302' 6,310' 4,679' 4,684' 8'8/3/1969 CMT SQZD E-8, E-9 7,030' 7,067' 5,113' 5,135' 37'8/4/1969 ISOLATED F-4, F-5 7,197' 7,214' 5,211' 5,221' 17'8/4/1969 ISOLATED F-6 7,218' 7,238' 5,224' 5,235' 20'8/4/1969 ISOLATED G-1 7,309' 7,326' 5,280' 5,290' 17'8/4/1969 ISOLATED G-4 7,388' 7,398' 5,330' 5,336' 10'7/30/1969 ISOLATED H-1 7,478' 7,488' 5,386' 5,392' 10'8/4/1969 ISOLATED H-3 7,513' 7,538' 5,408' 5,424' 25'8/4/1969 ISOLATED H-6 7,583' 7,598' 5,452' 5,461' 15'8/4/1969 ISOLATED I-7 7,822' 7,828' 5,601' 5,605' 6'7/27/1969 ISOLATED K-2 8,008' 8,018' 5,719' 5,725' 10'8/4/1969 ISOLATED M-2 8,180' 8,185' 5,826' 5,829' 5'8/4/1969 ISOLATED M-10 8,307' 8,314' 5,906' 5,910' 7'8/4/1969 ISOLATED N-2 8,375' 8,425' 5,949' 5,982' 50'7/24/1969 ISOLATED Rig Start Date End Date Eline 3/5/23 3/29/23 03/05/2023 - Sunday MIT-IA 4-1/2" x 7" Annulus to 1,500psi charted for 30min - Test good 0 / 15 / 30 min pressures: 1712 / 1673 / 1654 for losses of 39 followed by 19psi Overall loss <4% Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-08 50-883-20028-00-00 169-063 PJSM and PTW SITP 10psi Production filled the tubing overnight, took 13BBL. M/U and RIH with 1.6875" OD CCL and weight bars, tag CIBP at 4231.6ft' no issues . POOH M/U and RIH with 2.75" OD Junk Basket, CCL and weight bars, tag CIBP at 4231.6ft' no issues . POOH Fly 2.5" OD cement bailer out to the platform. M/U and RIH with 20Ft x 2.5" OD Cement dump bailer, set down at 4,063' (168ft high). Work tools with no luck. POOH. M/U and RIH with 10Ft x 2.5" OD empty dump bailer, set down at 4,063' (168ft high). POOH. Secure well and RD AK E-line. 03/09/2023 - Thursday PJSM and PTW SITP 40psi. R/U AK E-line. M/U CCL and 4.5" 10k-psi CIBP (3.5"OD) CCL to plug 7.6ft. Pressure test lubricator to 250psi/1500psi - Test good. RIH w/ CIBP. Work plug down as deep as we could get it and set CIBP at 4231.6'. RIH and tag plug, verify good set. POOH. M/U and RIH with 3.5"OD x 20ft cement dump bailer. Sat down at 890' and couldn't work through. POOH. M/U and RIH with 1.6875" OD CCL and weight bars to 1,100' no issues. POOH. M/U and RIH with 3.5"OD x 20ft empty dump bailer to 1,100' no issues. POOH. M/U and RIH with 3.5"OD x 20ft cement dump bailer. Sat down at 4057' (149' high) worked tools with no luck. POOH. Lay down the lubricator. Secure well and SDFN. 03/10/2023 - Friday Rig Start Date End Date Eline 3/5/23 3/29/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-08 50-883-20028-00-00 169-063 03/12/2023 - Sunday Rig up on well. PT 250/1500 PSI- pass. Rih w/ 4 1/2 BLB to 4020' kb, w/t 4051' kb, pooh. Rih w/ 3.5" X 8' DD Bailer to 4020' kb, w/t 4061' kb, pooh, ooh w/ 1 gal of mud. Rih w/ same to 4063' kb, w/t fall to 4128' kb, dont work tools, pooh. Rih w/ Brush to 4100' kb, w/t 4236' kb, brush between 4000-4238' kb 20 X, fall very slow every time, does not seem to improve. Rih w/ 3.5 LIB to 4236' kb, w/t pooh, inconclusive marks. (did not have good spang action). Rih w/ 3.5 X14' DD Bailer to 4236' kb, w/t pooh. Ooh full thin mud. Rih w/ 2.87 X 20' dummy guns to 4236' kb, w/t pooh. Ooh w/ tools, rig down. 03/13/2023 - Monday PJSM and PTW Spot equipment and R/U on well M/U 5' weight bar, and 3.5"OD x 20' dump bailer Pressure test lubricator to 250psi/1500psi - Test Good. RIH with weight bar, and 3.5"OD x 20' EMPTY dump bailer, set down at 4,005ft (226ft high). Work tools. POOH Bailer has 2ft of packed sand in the bottom. Secure well RD AK E-line Set-up Slickline to come out and bail. Rig Start Date End Date Eline 3/5/23 3/29/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-08 50-883-20028-00-00 169-063 03/14/2023 - Tuesday MIT-T 4-1/2" to 1,500psi charted for 30min - Test good 0 / 15 / 30 min pressures: 1760 / 1749 / 1745 for losses of 11 followed by 4psi Overall loss <1% Test against CIBP at 4,231' w/o cement. PJSM and PTW RU Pollard SL SITP zero psi Pressure test lubricator to 250psi/1500psi - Test good. Rih w/ 3 1/2''x10' dd bailer w/ flapper bottom to 4033'kb w/ tool to 4054'kb pooh fluid only Rih w/ same w/ castle bottom to 4056'kb w/ tool to 4068'kb pooh full thick fluid Rih w/ same w/ ball bottom to 4066'kb w/ tool 4078'kb pooh full same Rih w/ 4 1/2'' braided line brush 4052'kb w/ tool to 4085'kb pooh Rih w/ 3''x6' dd bailer to 4088'kb w/ tool 4096'kb pull up 15' rih to 4089'kb w/ tool to 4106'kb pooh full fluid. Rih w/ 3 1/2''x14' pump bailer to 4050'kb sit falling slow to 4068'kb w/ tool 4076'kb pooh full thin mud Secure well SDFN 03/15/2023 - Wednesday PJSM and PTW Build lubricator. Stab on riser p/t to 1500psi good test Rih w/ 3 1/2''x14' pump bailer to 4053'kb falling slow to 4080'kb would not fall w/ tool pooh full thick mud Rih w/ same to 4083'kb w/ tool to 4089'kb pooh full same Rih w/ same to 4083'kb w/ tool to 4097'kb pooh full same Rih w/ same to 4085'kb w/ tool to 4115'kb pooh full same;Rih w/ same to 4108'kb w/ tool to 4125'kb pooh full same Rih w/ same to 4104'kb w/ tool to 4120'kb pooh full same Rih w/ same to 4119'kb w/ tool to 4123'kb pooh full same Rih w/ 4 1/2'' braided line brush to 4127'kb w/ tool to would not fall make several passes from 4000' to 4127'kb pooh Lay down lub. Cut wire rehead check toolstring Secure well and SDFN Rig Start Date End Date Eline 3/5/23 3/29/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-08 50-883-20028-00-00 169-063 03/16/2023 - Thursday PJSM and PTW P/U lub. build 3 1/2'' bailer Stab on riser Rih w/ 3 1/2''x14' pump bailer to 4121'kb w/ tool to 4127'kb pooh full thick mud Rih w/ same to 4125'kb w/ tool to 4127'kb pooh full same Rih w/ same to 4130'kb w/ tool 4131'kb pooh full same Rih w/ same to 4135'kb w/ tool pooh full same Rih w/ same to 4140'kb w/ tool pooh full same;Rih w/ same to 4147'kb w/ tool pooh full same Rih w/ same to 4152'kb w/ tool pooh full same Rih w/ same to 4160'kb w/ tool pooh full same Rih w/ same to 4182'kb w/ tool pooh full same Rih w/ 4 1/2'' braided line brush to 4196'kb tag fill w/ tool from 4000' to 4195' make several passes Lay down lub Secure well and SDFN 03/17/2023- Friday Morning meeting JSA permit p/u lub. Build bailer Rih w/ 3 1/2''x14' pump bailer falling slow from 4160' to 4189'kb w/ tool pooh full thick mud Rih w/ same to 4206'kb w/ tool pooh full same Rih w/ same to 4214'kb w/ tool pooh full same Rih w/ same falling slow from 4175' to 4235'kb w/ tool pooh full same Rih w/ same falling slow from 4179' to 4237'kb w/ tool pooh full same;Rih w/ same falling slow from 4180' to 4234'kb w/ tool pooh full same Rih w/ same falling slow from 4195' to 4235'kb w/ tool pooh full mud getting thinner Rih w/ same to 4236'kb sit w/ tool pooh full thinner fluid Rih w/ same to 4236'kb w/ tool pooh full thick fluid Remove knuckle joint Rih w/ 2 7/8''x20' spent dummy guns 250fpm to 3900' slow to 100fpm to 4234'kb;Break off dummy guns, lay down lub. Secure well for night Rig Start Date End Date Eline 3/5/23 3/29/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-08 50-883-20028-00-00 169-063 03/18/2023 - Saturday Morning meeting JSA and PTW p/u lub. Build bailer RIH w/ 3 1/2''x14' pump bailer to 4232'kb. POOH full of mud with a 1ft sand plug on bottom (CIBP is at 4,232') RIH w/ 3 1/2''x14' pump bailer to 4232'kb. POOH full of thinner mud, no course sand. RIH w/ 2 7/8''x20' spent dummy guns to 4232'kb RD Slickline;RU AK E-line M/U 3.125"OD gun gamma, 2-3/4" x 18ft Geodynamics gun 6spf, 15gm. (CCL to top shot 9.0') Pressure test lubricator to 250psi/2500psi - Test good Pressure up tubing to 300psi, bleed off IA to 25psi. Tag CIBP at 4,232ft. Pull the correlation logs and send to town. On depth;Pull on depth and perforate the Sterling injection sands from 4,162 - 4,180'. POOH, All shots fired T/IA 0min - 538psi/33psi 5min - 33psi/5psi Turn on the injection charge pump to keep the tubing at 100psi. Well taking ~1BPH;M/U and RIH w/ 3.5"x20' empty dump bailer with glass bottom. Tag at 4,225' (6.5ft high). POOH;M/U and RIH w/ 3.5"x20' cement dump bailer. Tag at 4,203' (28ft high). POOH without dumping cement;Lay down lubricator Secure well and SDFN Production will run injectivity test overnight Rig Start Date End Date Eline 3/5/23 3/29/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-08 50-883-20028-00-00 169-063 03/19/2023 - Sunday Injection test overnight. 3X attempts @ 0.9BPM, the well pressured up to 1,500psi in 2-4min. PJSM and PTW. Re-head E-line and M/U CCL 2.75"OD CCL, 2-3/4" x 18ft Geodynamics gun 6spf, 15gm. (CCL to top shot 5.5')Pressure up tubing to 100psi, IA @ 0psi Tag at 4212ft. Pull the correlation logs and send to town. On depth;Pull on depth and perforate the Sterling injection sands from 4,144 - 4,162'. POOH, All shots fired T/IA 0min - 126psi/0psi 5min - 97psi/6psi Once out of the hole perform an injection test. Pressured up to 1,500psi in 90seconds @ 0.9BPM. Pressure up IA to 1000psi holds steady;M/U CCL 2.75"OD CCL, 2-3/4" x 18ft Geodynamics gun 6spf, 15gm. (CCL to top shot 5.7') Pressure up tubing to 100psi, IA @ 1000psi Tag at 4220'. Pull the correlation logs and send them to town. On depth;Pull on depth and perforate the Sterling injection sands from 4,103 - 4,121'. POOH, All shots fired T/IA 0min - 97psi/930psi 5min - 97psi/930psi RIH with spent gun and tag at 4,217';Once out of the hole perform an injection test. Cycle injection pressure 7 times working up 50psi per cycle. Well started taking 0.9BPM at 1862psi, tubing pressure slowly dropped to 1685psi after 1hr of injecting at 0.9BPM IA pressure bled down to 150psi and is holding steady. Lay down AK E-line, secure well, SDFN Production to inject and monitor overnight;Injected produced water at 1325bwpd rate (0.92bpm) from 16:00 - 23:59 (8hrs). Final injection pressure at midnight had fallen to 1520psi. Injected 440 total bbls on 3/19/23 with an average WHIP = 1635psi;Cum daily injection: 440bbls Cum injection for project: 440bbls Rig Start Date End Date Eline 3/5/23 3/29/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-08 50-883-20028-00-00 169-063 03/20/2023 - Monday Continued injecting produced water after midnight at 1325bwpd (0.92bpm). Injected from 00:00 - 2:00 (2 hrs). 110 total bbls injected since midnight at an average WHIP = 1520psi.;MIT-IA 4-1/2" x 7" Annulus to 1,500psi charted for 30min - Test good 0 / 15 / 30 min pressures: 1619 / 1614 / 1616 for losses of 10 followed by +2psi Overall loss <1% MIT-IA done while injecting warm fluids;PJSM and PTW MIT-IA 4-1/2" x 7" Annulus to 1,500psi for 30min - Test good Gauge was not recording MIT-IA done with injection offline R/U AK E-line;M/U CCL 3.125"OD CCL, 2-3/4" x 18ft Geodynamics gun 6spf, 15gm. (CCL to top shot 5.5') Pressure up tubing to 100psi, IA @ 17psi Tag at 4,220'. Pull the correlation logs and send them to town. On depth;Pull on depth and perforate the Sterling injection sands from 4,126' - 4,144'. POOH, All shots fired T/IA 0min - 100psi/17psi 5min - 100psi/17psi RIH with spent gun and tag at 4,220' Perform injection test at 0.9BPM for 1hr, maximum pressure seen 1722psi final injection pressure 1649psi;Resume injection of produced water at 1325bwpd (0.92bpm). Injected from 10:00 - 11:00 (1 hr). 60 bbls injected at an average WHIP = 1670psi.;Re-test MIT with chart recording MIT-IA 4-1/2" x 7" Annulus to 1,500psi charted for 30min - Test good 0 / 15 / 30 min pressures: 1619 / 1567 / 1549 for losses of 52 followed by 18psi Overall loss <5% MIT-IA done with injection offline;M/U 2.5"ODx20ft cement dump bailer. RIH, tag at 4,207'. Pick-up and dump 6.5' of cement. POOH. RIH w/ 2.5"ODx20ft cement dump bailer. Dump 6.5' of cement. POOH RIH w/ 2.5"ODx20ft cement dump bailer. Dump 6.5' of cement. POOH RIH w/ 2.5"ODx20ft cement dump bailer. Dump 6.5' of cement. POOH Calc TOC 4,181';RD AK-Eline;Cum daily injection: 170bbls Cum injection for project: 610bbls Rig Start Date End Date Eline 3/5/23 3/29/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-08 50-883-20028-00-00 169-063 Continued produced water injection from midnight to 16:30. WHIP continued to fall from 1585 at midnight and stabilized out at 1460psi. Rates stayed around 0.9bpm IAP stabilized at ~400psi. Cum daily injection: 915bbls Cum injection for project: 1885bbls 03/28/2023 - Tuesday Rig up slickline p/t lub. To 1500psi good test. Rih w/ 1 3/4''x4' dd bailer to 4175'kb tag w/ tool pooh w/ thick cement. Rih w/ tri-gauge to 4140' @ 100fpm see stop sheet for stops. Ooh down load data-good. Rig down slickline secure well for production. Brought well on, produced water injection at 1710psi. Injected for 6hrs till midnight. Injection pressure slowly fell to 1585psi by midnight. IA pressure climbs form 91psi to 370psi by midnight (thermal). 340bbls injected today at an average rate of ~0.9bpm. Cum daily injection: 360bbls Cum injection for project: 970bbls 03/29/2023 - Wednesday 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: External sender. DO NOT open links or attachments from UNKNOWN senders. Ryan, Hilcorp has approval to proceed with the plan below, with the additional step of tagging TOC with wireline before adding perfs. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Wednesday, March 15, 2023 12:49 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Karson Kozub - (C) <kkozub@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: NCIU A-08 Injectivity test (PTD# 169-063) Bryan- Per our discussion, please see below for Hilcorp’s proposed path forward on NCIU A-08 (PTD #169- 063) regarding approved sundry #323-110. Attached is the current schematic, and recent events. Modified steps: 1. Set CIBP: DONE set at 4232’ MD on 3/9/23 2. Perforate per approved sundry. Bottom perf to be NO deeper than 4180’ MD 3. MIT-IA to 1500psi 4. Establish injectivity per approved sundry parameters 5. Clean up sump with SL bailers / brushes / etc… 6. As long as we can get the sump cleaned, Dump bail 25’ cement on top of CIBP at 4,232’ MD 7. If required, and after cement has been dump bailed, add perfs down to 4,207’ per original sundry Hilcorp accepts that getting 25’ of cement dump bailed on top of CIBP at 4,232’ MD will be required before an approved DIO will be issued (Hilcorp yet to apply). Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. lbb �11\\\\o �100 1 Or on Ix 10 MC MP-5000-1HR 2 NO - 0: L> -JA OC I C�b N V .. e. .500\\ \. i L� •.qac f I \ O CHART N0. MC MP-5000-tHR�\\� \ I k_ oa 4�p ✓EIEC _ _._ • I I '. I. rF r - 'etEN Ofr i. f.. .•_,. O4tf _MITf =d.$CD �1;Tef+ 0£ 6 r,2 oti 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: North Cook Inlet 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,222 N/A Casing Collapse Structural Conductor 630psi Surface 2,090psi Intermediate Production 4,320psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Ryan Rupert Contact Email:Ryan.Rupert@hilcorp.com Contact Phone:(907) 777-8503 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 4,3956,499 3,494 1182 16"623 MD 623 4,980psi6,4999,222 623 2,620 Perforation Depth MD (ft): 9,222 7" 10-3/4"2,985 2,985 Length Size Proposed Pools: 386 386 TVD Burst PRESENT WELL CONDITION SUMMARY 386 30" See schematic 1,640psi 3,580psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017589 / ADL0037831 169-063 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-883-20028-00-00 Hilcorp Alaska, LLC N Cook Inlet Unit A-08 Tertiary System Gas Same Other: Convert to Injector N/A Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 12.75 / J-55 5,892 3/10/2023 See schematic See schematic 4,344 - 4,362 3,465 - 3,476 4-1/2" 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Operations Manager Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Meredith Guhl at 7:36 am, Feb 21, 2023 323-110 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2023.02.20 13:36:54 -09'00' Dan Marlowe (1267) Injectivity test A DIO is required before converting this well to a Class II disposal well. X -bjm DSR-2/27/23 bjm 10-404 BJM 3/1/23 SFD 2/24/2023 For setting plug only 2/24/23 Bryan McLellan JLC 3/1/2023 3/1/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.03.01 15:21:00 -09'00' RBDMS JSB 031824 Disposal Injector Screening Well: NCIU A-08 Well Name:NCIU A-08 API Number:50-883-20028-00-00 Current Status:SI Gas Producer Permit to Drill Number:169-063 First Call Engineer:Ryan Rupert (907) 301-1736 (c)Leg 3 (SE corner) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Maximum Expected BHP:1530 psi @ 3,476’ TVD 0.44psi/ft to deepest open perfs Max. Potential Surface Pressure: 1182 psi Using 0.1 psi/ft Brief Well Summary NCIU A-08 on the Tyonek platform is a long-term shut-in Gas producer. It has exhausted its gas sand opportunities. The well is under consideration for conversion to a disposal injector. Hilcorp would like to plugback the existing well, perforate the disposal zone, and perform an injectivity test to confirm the well’s viability to take disposal water. We would concurrently subject the well to disposal operating conditions and be able to confirm the well’s integrity performance under these conditions. The proposed perf interval in A-08 correlates with the currently authorized disposal interval in NCIU B-01A (PTD#198-002) per DIO #033. Attached is an area of review of offset wells within ¼” mile of A-08’s intersection of the disposal zone. All cementing information is contained in that AOR table. If this proposed scope if approved by the AOGCC, and the final results are promising, Hilcorp would likely at that point apply to permanently convert A-08 to a Class II disposal injector. The goal of this project is to evaluate the injectivity and integrity of the well while operating at disposal conditions. Pertinent wellbore information: - SSSV: WL retrievable - Inclination all <55 degrees above PBTD -7/10/20 o EL perf’d Sterling X formation down to 4362’ with 20’ x 2-7/8” guns (no issues) o EL tag at 4,382’ MD (2 days after cement in place) o EL set CIBP at 4400’ MD and dump bailed 5’ cement on top - 7/4/20: o CBL shows ToC at 3,895’ MD o MIT-IA to 1500psi: PASS o MIT-T to 2500psi: PASS - 7/3/20: o CT circ’d cement into IA to allow for uphole recompletes Agree. SFD 2/24/2023 DIO needed. SFD 2/24/2023 viability to take disposal water. plugback the existing well, perforate the disposal zone, and perform an injectivity test to confirm the well’s Disposal Injector Screening Well: NCIU A-08 Pre-work 1. MIT-IA of 4-1/2” x 7” annulus to 1500psi 2. Confirm SL has removed WL-SSSV and bailed sand to depth necessary E-Line Perf procedure 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 1500psi high 3. RIH and set 4-1/2” CIBP a. Target depth = 4300’ MD b. Current fill in the well will likely make this depth unachievable c. Hilcorp would like to set the CIBP as deep as practical depending on sand bailing (no shallower than 4,050’ MD) 4. Cap CIBP with 5’ cement 5. RIH and perforate from ±4,015’ – ±4,207’ MD (±3,274’ – ±3,382’ TVD) per RE/Geo 6. RDMO EL Post-work 1. MIT-IA to 1500psi 2. Perform injectivity test a. Rates not to exceed 2.4bpm b. WHIP’s not to exceed 2500psi c. Cumulative volume injected not to exceed 10,000bbls d. Inlet water or produced water may be used Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Area of Review table 4. AOR maps (x2) Cap CIBP with 25' of cement. -bjm ±4,015’ – ±4,207’ NOTE: RCBL shows "great" cement in annulus below 4,010' MD, and patchy cement from that depth upward to 3,895' MD. SFD 2/24/2023 _____________________________________________________________________________________ Updated By: JLL 02/14/2023 SCHEMATIC North Cook Inlet Unit Well: NCIU A-08 PTD: 169-063 API: 50-883-20028-00 No Depth (MD) Depth (TVD)ID Item 38.9' 39' 4.500 FMC Tubing Hanger 1 291' 291' 3.813 Otis SCSSV Landing Nipple:WL-SSSV installed 7/5/20 2 4,400’ 3,265’ CIBP w/5’ of cmt TOC 4,395’ (7/8/20) 3 4,487’ 3,547’ Cement Retainer (7/3/20) 4 4,512’ 3,561’ 3.375 Permeant patch from 4512’ – 4534’ MD 5 4,545' 3,580' 3.880 Halliburton VSR Packer (Retrievable w/tubing adapter) 6 4,560 3,588’ CIBP w/5’ of cmt TOC 4,554’ (6/29/20) 7 4,613' 3,619' 3.813 Halliburton X Nipple 8 4,850’ 3,758’ - 4-1/2” CIBP w/5’ cmt. TOC at 4,840’ 9 4,891' 3,783' 3.970 Halliburton MHR Packer (Permanent) 10 5,361' 4,072' 3.970 Halliburton MHR Packer (Permanent) 11 5,496' 4,158' 3.970 Halliburton MHR Packer (Permanent) 12 5,699' 4,287' 3.970 Halliburton MHR Packer (Permanent) 13 5,892’ 4,412’ 3.958” WLEG 14 6,031’ 4,503’ >6.276 7” cement stage collar OPEN HOLE / CEMENT DETAIL 16”22” Hole: Pumped 462sxs (220bbls) 11.5ppg type G lead followed by 125sxs (24bbls) 15.6ppg class G tail. Volumetric ToC suggests at surface (no notes) 10-3/4" 15” hole: 700sxs (330bbls) of 11.5ppg class G lead followed by 125sxs (24bbls) of 15.0ppg class G tail. Found cement inside casing at 2800’ MD.Volumetric annular ToC assuming 30% washout = 525’ MD 7" 9-5/8" hole: Pumped 545sxs (132bbls) of 13.3ppg Class G primary cement job. Volumetrics using OH caliper put ToC at ~7700’ MD. 2nd stage through DV collar at 6031' pumped 860sxs (168 bbls) of 15.6ppg class G. 7/23/69 CBL showed ToC at 3,012’ 4-1/2” x 7” annulus 7/3/20: CT pumped 12bbls of 15.3ppg cement through cement retainer at 4500’ MD. Worst case ToC volumetrically should be 3950’ MD.7/4/2020 RCBL shows great cement below 4010’ MD, and patchy cement up to 3895’PBTD: 4,395’ TD: 9,222’ 2 30” RKB: MSL = 96’ 7” 7 8 13 14 Tubing Punch through patch 4,516’ – 4,518’ (6/30/20) 10-3/4” 16” 1 Parted Casing below EZSV @ 7,182’ Tubing Punch 4,635’ Sterling Y Sterling X 3 5 6 9 10 11 12 4 X X 2 CASING DETAIL Size Wt Grade Conn ID Top Btm 30” H-40 STC 28.000 Surf 386’ 16” 65 H-40 STC 15.250 Surf 623’ 10-3/4” 45.5 J-55 BTC 9.794 Surf 2,985’ 7” 26 J-55 BTC 6.276 Surf 9,222’ TUBING DETAIL 4-1/2” 12.75 J-55 EUE 8rd 3.958 Surf 5,892’ SFD DV Collar at 6031' MD 10-3/4" at 2,985' MD TOC ~7,700' MD TOC 3,012' MD Updated By: JLL 02/14/2023 SCHEMATIC North Cook Inlet Unit Well: NCI A-08 Last Completed: 06/17/1994 PTD: 169-063 API: 50-883-20028-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Sterling X 4,344 4,362 3,465 3,476 18' 07/10/20 Open Sterling Y 4,425 4,439 3,511 3,519 14’ 07/05/20 Isolated (7/8/20) B 4,635’ 4,650’ 3,631’ 3,640’ 15’ 06/29/20 Isolated B 4,635' 4,735' 3,631' 3,690' 100' 6/2/1994 CMT SQZD CI-1 4,979' 5,036' 3,836' 3,870' 57' 05/05/20 Isolated CI-2 5,061' 5,161' 3,885' 3,947' 100' 05/05/20 Isolated CI-3 5,191' 5,211' 3,965' 3,977' 20' 05/05/20 Isolated CI-3.1 5,240' 5,250' 3,996' 4,002' 10' 05/05/20 Isolated CI-4 5,266' 5,283' 4,012' 4,023' 17' 05/05/20 Isolated CI-4 5,288' 5,325' 4,026' 4,049' 37' 05/05/20 Isolated CI-5 5,388' 5,438' 4,089' 4,121' 50' 05/05/20 Isolated CI-6.2 5,563' 5,570' 4,200' 4,204' 7' 05/05/20 Isolated CI-7 5,580' 5,596' 4,211' 4,221' 16' 05/05/20 Isolated CI-7 5,600' 5,624' 4,227' 4,242' 24' 05/05/20 Isolated CI-8.2 5,743' 5,753' 4,315' 4,322' 10' 05/05/20 Isolated CI-9.1 5,837' 5,845' 4,376' 4,381' 8' 05/05/20 Isolated CI-10 5,855' 5,885' 4,387' 4,407' 30' 05/05/20 Isolated A-3 6,014' 6,015' 4,492' 4,493' 1'8/3/1969 CMT SQZD B-6 6,302' 6,310' 4,679' 4,684' 8'8/3/1969 CMT SQZD E-8, E-9 7,030' 7,067' 5,113' 5,135' 37'8/4/1969 ISOLATED F-4, F-5 7,197' 7,214' 5,211' 5,221' 17'8/4/1969 ISOLATED F-6 7,218' 7,238' 5,224' 5,235' 20'8/4/1969 ISOLATED G-1 7,309' 7,326' 5,280' 5,290' 17'8/4/1969 ISOLATED G-4 7,388' 7,398' 5,330' 5,336' 10'7/30/1969 ISOLATED H-1 7,478' 7,488' 5,386' 5,392' 10'8/4/1969 ISOLATED H-3 7,513' 7,538' 5,408' 5,424' 25'8/4/1969 ISOLATED H-6 7,583' 7,598' 5,452' 5,461' 15'8/4/1969 ISOLATED I-7 7,822' 7,828' 5,601' 5,605' 6'7/27/1969 ISOLATED K-2 8,008' 8,018' 5,719' 5,725' 10'8/4/1969 ISOLATED M-2 8,180' 8,185' 5,826' 5,829' 5'8/4/1969 ISOLATED M-10 8,307' 8,314' 5,906' 5,910' 7'8/4/1969 ISOLATED N-2 8,375' 8,425' 5,949' 5,982' 50'7/24/1969 ISOLATED _____________________________________________________________________________________ Updated By: JLL 02/20/2023 PROPOSED North Cook Inlet Unit Well: NCIU A-08 PTD: 169-063 API: 50-883-20028-00 No Depth (MD) Depth (TVD)ID Item 38.9' 39' 4.500 FMC Tubing Hanger 1 291' 291' 3.813 Otis SCSSV Landing Nipple:WL-SSSV installed 7/5/20 2 ±4,300’ ±3,430’ CIBP w/5’ of cmt (ToC ±4,295’) 3 4,400’ 3,265’ CIBP w/5’ of cmt TOC 4,395’ (7/8/20) 4 4,487’ 3,547’ Cement Retainer (7/3/20) 5 4,512’ 3,561’ 3.375 Permanent patch from 4512’ – 4534’ MD 6 4,545' 3,580' 3.880 Halliburton VSR Packer (Retrievable w/tubing adapter) 7 4,560 3,588’ CIBP w/5’ of cmt TOC 4,554’ (6/29/20) 8 4,613' 3,619' 3.813 Halliburton X Nipple 9 4,850’ 3,758’ - 4-1/2” CIBP w/5’ cmt. TOC at 4,840’ 10 4,891' 3,783' 3.970 Halliburton MHR Packer (Permanent) 11 5,361' 4,072' 3.970 Halliburton MHR Packer (Permanent) 12 5,496' 4,158' 3.970 Halliburton MHR Packer (Permanent) 13 5,699' 4,287' 3.970 Halliburton MHR Packer (Permanent) 14 5,892’ 4,412’ 3.958” WLEG 15 6,031’ 4,503’ >6.276 7” cement stage collar OPEN HOLE / CEMENT DETAIL 16”22” Hole: Pumped 462sxs (220bbls) 11.5ppg type G lead followed by 125sxs (24bbls) 15.6ppg class G tail. Volumetric ToC suggests at surface (no notes) 10-3/4" 15” hole: 700sxs (330bbls) of 11.5ppg class G lead followed by 125sxs (24bbls) of 15.0ppg class G tail. Found cement inside casing at 2800’ MD.Volumetric annular ToC assuming 30% washout = 525’ MD 7" 9-5/8" hole: Pumped 545sxs (132bbls) of 13.3ppg Class G primary cement job. Volumetrics using OH caliper put ToC at ~7700’ MD. 2nd stage through DV collar at 6031' pumped 860sxs (168 bbls) of 15.6ppg class G. 7/23/69 CBL showed ToC at 3,012’ 4-1/2” x 7” annulus 7/3/20: CT pumped 12bbls of 15.3ppg cement through cement retainer at 4500’ MD. Worst case ToC volumetrically should be 3950’ MD.7/4/2020 RCBL shows great cement below 4010’ MD, and patchy cement up to 3895’PBTD: 4,395’ TD: 9,222’ 2 30” RKB: MSL = 96’ 7” 8 9 14 15 Tubing Punch through patch 4,516’ – 4,518’ (6/30/20) 10-3/4” 16” 1 Parted Casing below EZSV @ 7,182’ Tubing Punch 4,635’ Sterling Y Sterling X 4 6 7 10 11 12 13 5 Sterling X X 3 2 CASING DETAIL Size Wt Grade Conn ID Top Btm 30” H-40 STC 28.000 Surf 386’ 16” 65 H-40 STC 15.250 Surf 623’ 10-3/4” 45.5 J-55 BTC 9.794 Surf 2,985’ 7” 26 J-55 BTC 6.276 Surf 9,222’ TUBING DETAIL 4-1/2” 12.75 J-55 EUE 8rd 3.958 Surf 5,892’ SFD SFD DV Collar at 6031' MD 10-3/4" at 2,985' MD TOC ~7,700' MD TOC 3,012' MD Updated By: JLL 02/20/2023 PROPOSED North Cook Inlet Unit Well: NCI A-08 Last Completed: 06/17/1994 PTD: 169-063 API: 50-883-20028-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Sterling ±4,015’ ±4,207’ ±3,274’ ±3,382’ ±192’ FUTURE PROPOSED Sterling X 4,344 4,362 3,465 3,476 18' 07/10/20 Isolated Sterling Y 4,425 4,439 3,511 3,519 14’ 07/05/20 Isolated (7/8/20) B 4,635’ 4,650’ 3,631’ 3,640’ 15’ 06/29/20 Isolated B 4,635' 4,735' 3,631' 3,690' 100' 6/2/1994 CMT SQZD CI-1 4,979' 5,036' 3,836' 3,870' 57' 05/05/20 Isolated CI-2 5,061' 5,161' 3,885' 3,947' 100' 05/05/20 Isolated CI-3 5,191' 5,211' 3,965' 3,977' 20' 05/05/20 Isolated CI-3.1 5,240' 5,250' 3,996' 4,002' 10' 05/05/20 Isolated CI-4 5,266' 5,283' 4,012' 4,023' 17' 05/05/20 Isolated CI-4 5,288' 5,325' 4,026' 4,049' 37' 05/05/20 Isolated CI-5 5,388' 5,438' 4,089' 4,121' 50' 05/05/20 Isolated CI-6.2 5,563' 5,570' 4,200' 4,204' 7' 05/05/20 Isolated CI-7 5,580' 5,596' 4,211' 4,221' 16' 05/05/20 Isolated CI-7 5,600' 5,624' 4,227' 4,242' 24' 05/05/20 Isolated CI-8.2 5,743' 5,753' 4,315' 4,322' 10' 05/05/20 Isolated CI-9.1 5,837' 5,845' 4,376' 4,381' 8' 05/05/20 Isolated CI-10 5,855' 5,885' 4,387' 4,407' 30' 05/05/20 Isolated A-3 6,014' 6,015' 4,492' 4,493' 1'8/3/1969 CMT SQZD B-6 6,302' 6,310' 4,679' 4,684' 8'8/3/1969 CMT SQZD E-8, E-9 7,030' 7,067' 5,113' 5,135' 37'8/4/1969 ISOLATED F-4, F-5 7,197' 7,214' 5,211' 5,221' 17'8/4/1969 ISOLATED F-6 7,218' 7,238' 5,224' 5,235' 20'8/4/1969 ISOLATED G-1 7,309' 7,326' 5,280' 5,290' 17'8/4/1969 ISOLATED G-4 7,388' 7,398' 5,330' 5,336' 10'7/30/1969 ISOLATED H-1 7,478' 7,488' 5,386' 5,392' 10'8/4/1969 ISOLATED H-3 7,513' 7,538' 5,408' 5,424' 25'8/4/1969 ISOLATED H-6 7,583' 7,598' 5,452' 5,461' 15'8/4/1969 ISOLATED I-7 7,822' 7,828' 5,601' 5,605' 6'7/27/1969 ISOLATED K-2 8,008' 8,018' 5,719' 5,725' 10'8/4/1969 ISOLATED M-2 8,180' 8,185' 5,826' 5,829' 5'8/4/1969 ISOLATED M-10 8,307' 8,314' 5,906' 5,910' 7'8/4/1969 ISOLATED N-2 8,375' 8,425' 5,949' 5,982' 50'7/24/1969 ISOLATED We l l Na m e P T D A P I S t a t u s To p o f di s p o s a l zo n e ( M D ) To p o f di s p o s a l zo n e (T V D ) To p o f Cm t (M D ) To p o f Cm t (T V D ) C o m m e n t s A- 1 6 20 8 0 9 8 5 0 8 8 3 2 0 1 2 7 0 0 Ga s Pr o d u c e r 42 6 3 3 2 8 9 S u r f a c e S u r f a c e 9- 5 / 8 ” C a s i n g i n 1 2 - 1 / 4 " h o l e : P u m p e d 5 2 4 b b l s o f 1 2 . 0 p p g C e m e n t f r o m c a s i n g sh o e a t 4 , 5 3 6 ' . O b s e r v e d 7 0 b b l s c e m e n t r e t u r n s . T o C a t s u r f a c e . A- 1 3 19 2 1 0 6 5 0 8 8 3 2 0 0 8 7 0 0 Di s p o s a l in j e c t o r 37 3 5 3 2 7 7 3 4 5 0 3 0 5 7 13 - 3 / 8 " C a s i n g i n 1 7 - 1 / 2 ” h o l e ( 3 s t a g e j o b ) : 1s t s t a g e : P u m p e d 1 0 0 0 s x s . C e m e n t r e t u r n s o b s e r v e d a t s u r f a c e a f t e r ci r c u l a t i n g t h r o u g h l o w e r D V . 2n d s t a g e ( D V c o l l a r a t 7 5 2 4 ' ) : P u m p e d 4 4 0 0 s x s C l a s s G c e m e n t a t 1 5 . 8 p p g a n d 1. 1 7 f t 3 / s x . L o s t r e t u r n s a f t e r 5 6 1 b b l s p u m p e d a n d p u m p e d r e m a i n d e r o f j o b wi t h o u t r e t u r n s . E s t T O C w i t h 4 0 % w a s h o u t i s 5 3 1 8 ' . 3r d s t a g e ( D V c o l l a r a t 4 3 0 8 ' ) : P u m p e d 1 0 0 0 s x s o f C l a s s G c e m e n t a t 1 5 . 8 p p g an d 1 . 1 7 f t 3 / s x . R e t u r n s d e c r e a s e d t h r o u g h o u t t h e j o b w i t h n o r e t u r n s a t t h e en d . 1/ 2 3 / 9 3 C B L s h o w s p a t c h y c e m e n t f r o m s h o e u p p a s t l o w e r D V w i t h f r e e p i p e fr o m 4 9 5 0 ’ u p t o u p p e r D V a t 4 3 0 8 ’ . L o g s h o w s p a t c h y c e m e n t a b o v e u p p e r D V wi t h f r e e p i p e a b o v e 3 4 5 0 ’ . A- 0 3 16 8 0 9 9 5 0 8 8 3 2 0 0 2 0 0 0 A b a n d o n e d 3 5 8 5 3 2 4 8 2 5 1 8 2 3 2 9 7" c a s i n g i n 9 - 5 / 8 ” h o l e : I n A - 0 3 p a r e n t b o r e ( 1 9 6 9 ) P u m p e d 5 1 5 s x s ( 1 9 1 b b l s ) 12 . 9 p p g c l a s s G c e m e n t . S t a g e c o l l a r a t 5 1 1 4 ’ f a i l e d t o o p e n . M u l t i p l e s q u e e z e s we r e p e r f o r m e d a t 3 , 9 3 0 ’ , 4 , 1 0 0 ’ , 4 , 1 7 8 , a n d 4 , 7 9 3 ’ . 9 1 t o t a l b b l s p l a c e d be h i n d p i p e w i t h s q u e e z e s . 1 1 / 1 3 / 1 9 R C B L s h o w e d g o o d c e m e n t f r o m a t l e a s t to 3 , 9 8 8 ’ ( P B T D a t t h e t i m e ) u p t o 3 , 2 6 0 ’ . F r e e p i p e a b o v e 2 , 5 1 8 ’ . A- 0 3 A 22 1 0 5 1 5 0 8 8 3 2 0 0 2 0 0 1 Ga s Pr o d u c e r 36 4 7 3 2 6 5 4 1 8 4 3 5 9 7 7" c a s i n g i n 9 - 5 / 8 ” h o l e : S e e A - 0 3 p a r e n t b o r e a b o v e 4- 1 / 2 " l i n e r i n 6 - 1 / 8 ” h o l e : P u m p e d 9 0 b b l s o f 1 5 . 3 p p g c e m e n t . 5 4 b b l s l o s s e s du r i n g c e m e n t j o b . 1 0 / 2 2 / 2 1 C B L l o g g e d T o C a t 4 , 1 8 4 ’ . ( K O P f r o m 7 " c a s i n g a t 3, 2 0 9 ' . ) TOC is deeper than injection zone in A-03A. This well is at the edge of the 1/4 mile area of review. -bjm 7" c a s i n g i n 9 - 5 / 8 ” h o l e : S e e A - 0 3 p a r e n t bor e a bov e Gas 4- 1 /2" l i n e r i n 6 - 1 /8” h o l e : P u m p e d 9 0 b b l s o f 1 5 . 3 p p g c e m e n t . 5 4 b b l s l o s s e s A-03 A 22 1 0 5 1 5 0 8 8 3 2 0 0 2 0 0 1 36 4 7 32 6 5 41 8 4 35 9 7 Prod u c e r dur i n g c e m e n t job . 1 0 / 2 2 / 2 1 C B L l o gg ed T o C a t 4 , 1 8 4 ’ . ( K O P f r o m 7 " c a s i n g a t We l l Na m e P T D A P I S t a t u s To p o f di s p o s a l zo n e ( M D ) To p o f di s p o s a l zo n e (T V D ) To p o f Cm t (M D ) To p o f Cm t (T V D ) C o m m e n t s A- 0 1 16 8 0 7 2 5 0 8 8 3 2 0 0 1 6 0 0 A b a n d o n e d 3 6 6 5 3 2 8 6 2 5 5 2 2 3 9 9 7" c a s i n g i n 9 - 5 / 8 ” h o l e : Fi r s t s t a g e : C a s i n g l a n d e d a t 7 4 4 9 ’ a n d p u m p e d 5 4 6 s x s ( 1 3 1 b b l s ) 1 3 . 2 p p g c l a s s G c e m e n t . C e m e n t s e e n b a c k t o s u r f a c e w h e n c i r c u l a t i n g t h r o u g h D V c o l l a r be f o r e 2 n d s t a g e p u m p e d . 2n d s t a g e t h r o u g h D V c o l l a r a t 5 , 0 9 4 ’ . P u m p e d 5 5 2 s x s ( 1 2 2 b b l s ) 1 5 . 4 p p g c l a s s G. F u l l c i r c u l a t i o n t h r o u g h o u t . 9 / 2 2 / 9 2 U S I T s h o w s f r e e p i p e a b o v e 2 5 5 2 ’ . A- 0 1 A 22 1 0 7 1 5 0 8 8 3 2 0 0 1 6 0 1 Ga s Pr o d u c e r 38 3 1 3 2 9 3 2 5 5 2 2 3 9 9 7" c a s i n g i n 9 - 5 / 8 ” h o l e : Se e A - 0 1 p a r e n t b o r e a b o v e 4- 1 / 2 " c a s i n g i n 6 - 1 / 8 ” h o l e : P u m p e d 1 2 3 b b l s 1 5 . 3 p p g c e m e n t . S a w 1 b b l ce m e n t c i r c u l a t e d o f f t h e l i n e r t o p . 1 0 / 2 6 / 2 1 C B L s h o w s c e m e n t u p t o L i n e r T o p pa c k e r a t 2 9 5 0 ’ . A- 0 8 16 9 0 6 3 5 0 8 8 3 2 0 0 2 8 0 0 Ga s Pr o d u c e r 40 1 5 3 2 7 4 3 0 1 2 2 6 3 8 7" c a s i n g i n 9 - 5 / 8 " h o l e : 2 n d s t a g e t h r o u g h D V c o l l a r a t 6 0 3 1 ' p u m p e d 8 6 0 s x s (1 6 8 b b l s ) o f 1 5 . 6 p p g c l a s s G . 7 / 2 3 / 6 9 C B L s h o w e d T o C a t 3 , 0 1 2 ' . NNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCC TTTTTTTTTTTTTTTTooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooopppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppp__DDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDiiiiiiissssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppoooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooosssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaa NNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCIIIIII 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MMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDTTTTTTTTTTTToooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooopppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppp_______DDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDiiiiiiisssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooosssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaalllllllll NNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA-00000000000000000000000000000000000000000008888888888888888888888888888888888888888888888888888888888888888888888888 44444444444444444444444444444444444444444444444444444000000000000000000000000000000000000000000000000000000000000000000000000000000011111111111111111111111111111111116666666666666666666666666666666666666666666666666666666666666666666666666666666666666666666666666 MMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDTTTTTTTTTTTTTTTTToooooooooooooooooooooooooooooooooooooooooooooooooooooooooppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppp_DDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDiiiiiiisssssssssssssssssssssssssssssssssssssssssssssssssssssssssspppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppooooooooooooooooooooooooooooooooooooooooooooooooooooooossssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaalllll NNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA-11111111111111111333333333333333333333333333333333333 333333333333333333333333333333333333333333333333333777777777777777777777777777777777333333333333333333333333333333333333333333333333333355555555555555555555555555555555555555555555555555555 MMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDTTTTTTTTTTTooooooooooooooooooooooooooooooooooooooooooooooooopppppppppppppppppppppppppppppppppppppppppppppppppppp_DDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDiiiiisssssssssssssssssssssssssssssssssssssssssssssppppppppppppppppppppppppppppppppppppppppppppppppppppooooooooooooooooooooooooooooooooooooooooooooooooooossssssssssssssssssssssssssssssssssssssssssssssssssssssaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaalll NNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA-11111111111111111111111166666666666666666666666666666666666666 444444444444444444444444444444444444222222222222222222222222222222222222222222222222226666666666666666666666666666666666666666666666666633333333333333333333333333333333333333333333 MMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDTTTTTTTTTTTTTTTTTTTTooooooooooooooooooooooooooooooooooooooooooooooooooppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppp__DDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDiiiiisssssssssssssssssssssssssssssssssssssssspppppppppppppppppppppppppppppppppppppppppppppppppppppppppooooooooooooooooooooooooooooooooooooooooossssssssssssssssssssssssssssssssssssssssssssssssssaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaalll NNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCIIIIII 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MMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDTTTTTTTTTTTTTTTTooooooooooooooooooooooooooooooooooooooooooooppppppppppppppppppppppppppppppppppppppppppppppppppp__DDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDiiiiissssssssssssssssssssssssssssssssssssssssspppppppppppppppppppppppppppppppppppppppppppppppppppppppooooooooooooooooooooooooooooooooooooooooooosssssssssssssssssssssssssssssssssssssssssssssaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaalll NNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA- TTTTTTTTTTTTTTTToooooooooooooooooooooooooooooooooooooooooooooooppppppppppppppppppppppppppppppppppppppppppppppp_____DDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDiiiiisssssssssssssssssssssssssssssssssssssspppppppppppppppppppppppppppppppppppppppppppppppppppppoooooooooooooooooooooooooooooooooooooosssssssssssssssssssssssssssssssssssssssssssssaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaalll NNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCC BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaassssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssseeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee____DDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDiiiiisssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooossssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaalll NNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA-000000000000000000000000000000000000000000000000000000000000000000000000000000000000000000000000033333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333 33333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333377777777777777777777777777777777777777777777777777777777111111111111111111111111111111111111111111133333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333333 MMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaasssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssseeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee________DDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDiiiiiiiissssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssspppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooooosssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaalllll NNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA--000000000000000000000000000000000000000000000000888888888888888888888888888888888888888888888888888888888888888888888 444444444444444444444444444444444444444442222222222222222222222222222222222222222222222222222222222222222222222222222222000000000000000000000000000000000000000000000000000000000077777777777777777777777777777777777777777777777 MMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaassssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssseeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee__DDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDiiiiissssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssspppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppooooooooooooooooooooooooooooooooooooooooooooooooooooooooosssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssssaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaalllllll NNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA--1111111111111111113333333333333333333333333333333333333 3333333333333333333333333333333333333333333333333333333888888888888888888888888888888888888888888888888888777777777777777777777777777777777777777888888888888888888888888888888888888888888888888 MMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaassssssssssssssssssssssssssssssssssssssssssssssssssseeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee___DDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDiiiiisssssssssssssssssssssssssssssssssssssssssssppppppppppppppppppppppppppppppppppppppppppppppppppppppooooooooooooooooooooooooooooooooooooooooooooooooooooossssssssssssssssssssssssssssssssssssssssssssssssssssaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaalllll NNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA---111111111111111111111111166666666666666666666666666666666666666666 444444444444444444444444444444444444444444444444444444444444444444444444444444444444444444444444444444444444444443333333333333333333333333333333333333333333333 MMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMMDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaasssssssssssssssssssssssssssssssssssssssssseeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee___DDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDiiiiissssssssssssssssssssssssssssssssssssssssppppppppppppppppppppppppppppppppppppppppppppppppppooooooooooooooooooooooooooooooooooooooooooosssssssssssssssssssssssssssssssssssssssssssaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaall NNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA-00000000000000000000000000000000000000000000033333333333333333333333333333333333333333333333333333333333333AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAABBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaasssssssssssssssssssssssssssssssssssssssssssssssssssssssseeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee___DDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDiiiiiisssssssssssssssssssssssssssssssssssssssssssssssssssppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppppoooooooooooooooooooooooooooooooooooooooooooooooooossssssssssssssssssssssssssssssssssssssssssssssssssssssssssaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaall NNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNNCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA-00000000000000000000000000000000000000111111111111111111111111111AAAAAAANNNNNNNNNNNNNNNCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCIIII AAAAAAAAAA 00000000000000000000001111111AAAAA 4444444444444444444444444444444440000000000000000000000000000000000000000088888BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaasssssssssssssssssssssssssssssssssssssssssssseeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee_____DDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDiiiiiissssssssssssssssssssssssssssssssssssssssppppppppppppppppppppppppppppppppppppppppppppoooooooooooooooooooooooooooooooooooooooooossssssssssssssssssssssssssssssssssssssssssssaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaaallllllllll Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 10/01/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL NCI A-08 (169-063) Raidial/Sector Cement Bond Gamma Ray/CCl Log 4 ½” Pipe 07/04/2020 Please include current contact information if different from above. Received by the AOGCC 10/01/2020 PTD: 1690630 E-Set: 34014 Abby Bell 10/01/2020 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Cement Pkr & N2 Operations Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9,222 feet 5,446; 4,850; 4,560; 4,487; 4,400 feet true vertical 6,494 feet N/A feet Effective Depth measured 4,395 feet See schematic feet true vertical 3,494 feet See schematic feet Perforation depth Measured depth 4,344 - 4,362 feet True Vertical depth 3,465 - 3,476 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.75 / J-55 5,892 MD 4,412 TVD Packers and SSSV (type, measured and true vertical depth)See Schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: Hilcorp Alaska, LLC 2. Operator Name N Senior Engineer: Senior Res. Engineer: Burst 1,640psi 3,580psi (907) 777-8384 Collapse 630psi623 2,620 4,773 2,090psiSurface 4,320psi 30" 16" 10-3/4" 6,455 4,980psi Production Casing Structural Liner Length 386 623 2,985 Conductor Karson Kozub kkozub@hilcorp.com 5. Permit to Drill Number: 0 North Cook Inlet Field / Tertiary Gas PoolN/A measured 6,455 Size 16 N Cook Inlet Unit A-08 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 N/A Intermediate N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-216 20 Authorized Signature with date: Authorized Name:Daniel E. Marlowe Operations Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 169-063 50-883-20028-00-00 Plugs ADL0017589 / ADL0037831 Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 1220 Casing Pressure Tubing Pressure 0 Oil-Bbl measured true vertical Packer 7" WINJ WAG 0 Water-Bbl MD 386 623 2,985 TVD 386 Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Jody Colombie at 4:58 pm, Aug 07, 2020 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.08.07 13:37:32 -08'00' Dan Marlowe (1267) SFD 8/10/2020gls8/28/20 DSR-8/7/2020 Perforate RBDMS HEW 8/10/2020 Cement Pkr & N2 Operations _____________________________________________________________________________________ Updated By: JLL 08/06/20 SCHEMATIC North Cook Inlet Unit Well: NCI A-08 Last Completed: 06/17/1994 PTD: 169-063 API: 50-883-20028-00 PBTD: 5,978’ TD:9,222’ 2 30” RKB: MSL = 96’ 7” B 5 6 8 9 10 11 12 13 14 15 16 17 Tubing Punch 4,518’ – 4,519’ 10-3/4” ’ E-8, E-9 F-4, F-5 F-6 G-1 G-4 H-1 H-3 H-6 I-7 K-2 M-2 M-10 N-2 16” 1 4 TOC @ 4,020’ 18 19 21 20 Parted Casing below EZSV @ 7,182’ 22 CI-1 CI-3 CI -3.1 CI -4 CI-2 CI-5 CI -6.2 CI -7 CI-8.2 CI -9.1 CI -10 A-3 B-6 Tubing Punch 4,528’ – 4,530’ Tagged Fill @ 5,335’ – 04/15/20 Tubing Patch 4,512’ – 4,534 ID 3.375” Tubing Punch 4,635’ CIBP w/ 10’ Cmt TOC @ 4,840’7 Tubing Punch 4,516’ Sterling Y Sterling X 3 2 X X CASING DETAIL Size Wt Grade Conn ID Top Btm 30” H-40 STC 28.000 Surf 386’ 16” 65 H-40 STC 15.250 Surf 623’ 10-3/4” 45.5 J-55 BTC 9.794 Surf 2,985’ 7” 26 J-55 BTC 6.276 Surf 6,455’ TUBING DETAIL 4-1/2” 12.75 J-55 EUE 8rd 3.958 Surf 5,892’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 38.9' 39' 4.500 FMC Tubing Hanger 1 291' 291' 3.813 Otis SCSSV Landing Nipple 2 4,400’ 3,265’ CIBP w/5’ of cmt TOC 4,395’ 3 4,487’ 3,547’ Cement Retainer 4 4,536' 3,575' 3.937 Upper Seal Bore 4,541' 3,578' 3.937 Ratch Latch 4,545' 3,580' 3.880 Halliburton VSR Packer (Retrievable w/tubing adapter) 5 4,560 3,588’ CIBP w/5’ of cmt TOC 4,554’ 6 4,613' 3,619' 3.813 Halliburton X Nipple 7 4,850’ 3,758’ - 3.958” 4-1/2” CIBP w/5’ cmt. TOC at 4,840’ 8 4,890' 3,782' 3.813 Locator No-Go 4,891' 3,783' 3.970 Halliburton MHR Packer (Permanent) 9 5,183' 3,961' 3.958 Otis XD Sliding Sleeve (Closed 11/12/12) 10 5,313' 4,042' 3.958 Otis XD Sliding Sleeve (Open 02/17/10) 11 5,349' 4,065' 3.937 Upper Seal Bore 5,360' 4,071' 3.937 Ratch Latch 5,361' 4,072' 3.970 Halliburton MHR Packer (Permanent) 12 5,446' 4,126' 3.813 Otis XA Sliding Sleeve (Closed)PX Plug set in sleeve 13 5,495' 4,157' 3.937 Ratch Latch 5,496' 4,158' 3.970 Halliburton MHR Packer (Permanent) 14 5,648' 4,254' 3.813 Otis XD Sliding Sleeve (Closed) 15 5,698' 4,286' 3.937 Ratch Latch 5,699' 4,287' 3.970 Halliburton MHR Packer (Permanent) 16 5,859' 4,390' 3.725 Halliburton X Nipple 17 5,892' 4,412' 3.958 Wireline Re-Entry Guide w/Pump Out Plug 18 5,978’ 4,468’ - Cement Retainer 19 6,150’ 4,582’ - Cement Plug 20 6,850’ 5,007’ - CIBP 21 7,030’ 5,113’ - Cement Plug 22 7,150’ 5,183’ - Cement Retainer Updated By: JLL 08/06/20 SCHEMATIC North Cook Inlet Unit Well: NCI A-08 Last Completed: 06/17/1994 PTD: 169-063 API: 50-883-20028-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Sterling X 4,344 4,362 3,465 3,476 18' 07/10/20 Open Sterling Y 4,425 4,439 3,511 3,519 14’ 07/08/20 Isolated B 4,635’ 4,650’ 3,631’ 3,640’ 15’ 06/29/20 Isolated B 4,635' 4,735' 3,631' 3,690' 100' 6/2/1994 CMT SQZD CI-1 4,979' 5,036' 3,836' 3,870' 57' 05/05/20 Isolated CI-2 5,061' 5,161' 3,885' 3,947' 100' 05/05/20 Isolated CI-3 5,191' 5,211' 3,965' 3,977' 20' 05/05/20 Isolated CI-3.1 5,240' 5,250' 3,996' 4,002' 10' 05/05/20 Isolated CI-4 5,266' 5,283' 4,012' 4,023' 17' 05/05/20 Isolated CI-4 5,288' 5,325' 4,026' 4,049' 37' 05/05/20 Isolated CI-5 5,388' 5,438' 4,089' 4,121' 50' 05/05/20 Isolated CI-6.2 5,563' 5,570' 4,200' 4,204' 7' 05/05/20 Isolated CI-7 5,580' 5,596' 4,211' 4,221' 16' 05/05/20 Isolated CI-7 5,600' 5,624' 4,227' 4,242' 24' 05/05/20 Isolated CI-8.2 5,743' 5,753' 4,315' 4,322' 10' 05/05/20 Isolated CI-9.1 5,837' 5,845' 4,376' 4,381' 8' 05/05/20 Isolated CI-10 5,855' 5,885' 4,387' 4,407' 30' 05/05/20 Isolated A-3 6,014' 6,015' 4,492' 4,493' 1'8/3/1969 CMT SQZD B-6 6,302' 6,310' 4,679' 4,684' 8'8/3/1969 CMT SQZD E-8, E-9 7,030' 7,067' 5,113' 5,135' 37'8/4/1969 ISOLATED F-4, F-5 7,197' 7,214' 5,211' 5,221' 17'8/4/1969 ISOLATED F-6 7,218' 7,238' 5,224' 5,235' 20'8/4/1969 ISOLATED G-1 7,309' 7,326' 5,280' 5,290' 17'8/4/1969 ISOLATED G-4 7,388' 7,398' 5,330' 5,336' 10'7/30/1969 ISOLATED H-1 7,478' 7,488' 5,386' 5,392' 10'8/4/1969 ISOLATED H-3 7,513' 7,538' 5,408' 5,424' 25'8/4/1969 ISOLATED H-6 7,583' 7,598' 5,452' 5,461' 15'8/4/1969 ISOLATED I-7 7,822' 7,828' 5,601' 5,605' 6'7/27/1969 ISOLATED K-2 8,008' 8,018' 5,719' 5,725' 10'8/4/1969 ISOLATED M-2 8,180' 8,185' 5,826' 5,829' 5'8/4/1969 ISOLATED M-10 8,307' 8,314' 5,906' 5,910' 7'8/4/1969 ISOLATED N-2 8,375' 8,425' 5,949' 5,982' 50'7/24/1969 ISOLATED perfed 3,465 3,476 18' 07/10/20 OpenSterling X 4,344 4,362 Rig Start Date End Date CTU/Eline 6/29/20 7/10/20 07/02/2020- Thursday MIRU CTU. Crane pick & turn reel 180*. Pick ops cab & set behind reel. Run power pack hydraulic lines to ops cab, injector & BOP. MU X-over flanges & riser to WH & BOP & P-sub to riser. Tighten all connections. Run DW supply line to fluid pump. Run pumping iron from fluid & N2 pump to reverse out skid & reel. Run return line from 7" IA casing valve to reverse out skid. Continue CTU RU. Test BOPE as per Hilcorp & AOGCC requirements, witness waived 6/30/2020 by AOGCC Inspections Supervisor Jim Regg, 250/3500. BOPE Test complete, pick up tools and slings for the night. SDFN 07/01/2020 - Wednesday PJSM & permit. T/IA = 100/100. RU fluid pump to tubing, PT 250/2500. RU IA 7" casing valve to choke manifold & FB tank, PT = 250/2500. Open swab and casing valve. Pump drill water to tubing, taking returns from IA 7" casing valve, to perform circulation step rate test as follows: 0.35 BPM @ 40 psi for 5 bbl, 0.60 BPM @ 50 psi for 7 bbl, 1.00 BPM @ 55 psi for 5 bbl, 1.50 BPM @ 90 psi for 5 bbl & 2.00 BPM @ 125 psi. Continue pumping DW @ 2.00 BPM to circulate 83 bbl BU. returns to FB tank are clean. Stop pump. SI IA 7" casing valve. Perform CMIT = 1500 psi for 30 minutes. Chart & Pass CMIT. Save chart & MIT form to O drive Projects file. Bleed off all Pressures. RD pump & FB lines. Ready for CTU & Eline. Job in Progress. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-08 50-883-20028-00-00 169-063 Start testing the IA for the MIT-IA - PASS. Wake up slb coil guys to pressure up tubing for MITT to 2600psi -PASS. Make up ELU and 2' tubing punch. Head to well, stabbed on well. WHP 0, IA 115. Open well, RIH,TAG CMT TOP AT 4553.8' KB. Log up to get on depth. CF +3 Pull up to 4507' CCL Depth, Magnet top 4513' KB, Top shot 4515.7' KB, BS 4517.8' KB. Pressure up TBG to 800 psi, IA had 115 psi. Shoot tubing punch, WHP dropped to 500, IA came up to 525. Good indication we have communication. POOH, OOH tools look good, stack back eline for the night. Get well set up to do injection test down tbg up the IA. SDFN PJSM with Eline, Crane and ops personnel. RU ELU, re head wire, make up 3" MRBP. PT WLV & Lubricator = 250/1500 psi. RIH, WHP 20psi. WT CK 4400' 510lbs. log down to 4600' CCL depth, log up to 4530' CCL depth. Drop back down to 4600', start logging up , CF +.5'. Park wire at 4549.9' CCL +13.1' Puts top of MRBP @ 4560' RKB. Line wt 510 lbs, set plug line wt dropped to 410lbs. POOH, OOH MRBP was gone. All tools looked good. Batch up 5 gal cmt. make up 2" X 30' Bailer. Dump 3.89 gal 15.8 ppg cmt into bailer. Stab on well, Open up, rih. Lightly sit down on PLUG 4560' KB. Dump 5' cmt on plug at 4560' KB, TOC @ 4555' KB POOH. OOH all cement left in hole. RDELU, SDFD. 06/30/2020 - Tuesday 06/29/2020 - Monday Puts top of MRBP @ 4560' RKB. Wake up slb coil guys to pressure up tubing for MITT to 2600psi - Perform CMIT = 1500 psi for 30 minutes. Start testing the IA for the MIT-IA - Shoot tubing punch, WHP dropped to 500, IA came up to Rig Start Date End Date CTU/Eline 6/29/20 7/10/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-08 50-883-20028-00-00 169-063 MIRU ELU on A-08. ELU stab on well. Pressure test WLV & lubricator, 250/2000. Start in hole to caliper CBL tools. Stop at 450' caliper tool. Eline operator had to make a phone call and some adjustments to CBL logging tool. Start logging down with CBL, Tag at 4487.75' RKB. Log ooh at 50 fpm to 700'. OOH download data. Send Data to engineers. RDMO ELU. Round up chart recorder and hoses for MITT's. Hook up to IA for a MIT-IA. Pressure up to 1750 psi, bleed off below 1500, bleed down to zero swap out hoses. Bring up to 1750 psi, bleed down below 1500. Move hoses and bring up to 1625 psi again, holding good this time. Watch for 30 min. IA PASS. Rearrange lines so we can MITT. Bring pressure up to 2700 psi. Hold for 30 min. Tubing Pass. Rig down chart recorder and hoses. Pick up Injector head, 10' lubricator. Make up CC, checks, stinger and DJN, Stab on well, Pt low 250, high 4000. Open well, swab 20, RIH. Job in progress 07/03/2020 - Friday PJSM, Get work permit signed. PU injector head make up cc, pull test, 30k, Press test CTC = 4200( External Slip CTC 2.88" X 1.60') ( C&J DICONNECT 2.88" X 1.29') ( XO 3.12" X .25'0 ( 3.50" ALPHA FH SETTING TOOL 3.69" X 8.67') ( 4.5" CEMENT RETAINER 3.58" X 1.95') TOL= 11.81'. Disco Ball = 7/8", Setting Tool Ball = 5/8" Move to Well. PT Lubricator & WHA = 250/3500 psi. HES cement crew fly to Beluga to offload cement equipment. Wait on cement crew to return. Pre-job safety & operations meeting w/ Schlumberger & Halliburton crews. T/IA/OA = 0/0/0. Open swab & RIH w/4-1/2" cement retainer BHA. 2500' WT CHK = 8.5K. 4330' WT CCHK = 12K. Tag top of Tubing Patch @ 4510' RKB. PUH 10'. Drop 5/8" ball & circulate w/ 20 bbl DW @ 1.25 bpm @ 2545 psi. Drop PR = 0.50 bpm @ 624 psi & land ball w/ 29 bbl total DW pumped. Pressure up to 2259 psi & set 4-1/2" cement retainer @ 4500' RKB. Stop pump. WT = 8K, slack off to 5K & hold. T/IA = 0/125 Pump to 4-1/2" tbg pressuring up Tubing = 1008 psi. IA = 152. Bleed Tbg down = 500 psi. Bleed IA = 0 psi. Pump 70 bbl 1.5% corrosion inhibited DW (7 gal CRW-9152A/10 bbl DW) circulating to 4-1/2" tbg X 7"csg inner annulus taking returns to surface from 7" casing valve @ 1.50 bpm/3160 psi. Tbg = 535 psi. HES blend 12 bbl 15.8 ppg cement. WSM verifies 15.8 ppg @ mudscale. Pump 2 bbl DW. SI & PT HES 250/4500. Come on line w/ HES pump w/ 15.8 ppg cement @ 1.0 bpm/1386 psi. 8.1 bbl cement away: 1.0 bpm/1658 psi. 10.3 bbl cement away: 0.7 bpm/1813 psi. 12 bbl cement away: 0.7 bpm/1965 psi. Swap to DW & displace to end of coil w/ 29.6 bbl holding 500 psi @ choke w/ 1:1 returns. Close choke. Bleed off Tbg = 0. Unsting from 4-1/2" cement retainer, cycle 10' above retainer. PUH to 4457', Circulate 110 bbl DW (BU X 2). POOH. OOH 5/8" ball recovered, setting tool was stroked and looked good. WHP 0, IA 300. SDFN. WOC. Job in Progress. 07/04/2020 - Saturday Pressure up to 2259 psi & set 4-1/2" cement retainer @ 4500' RKB. Eline operator had to make a phone call and some adjustments to CBL logging tool. Start logging down with CBL, Tag at 4487.75' RKB. Log ooh at 50 fpm to 700'. OOH download data. Rig Start Date End Date CTU/Eline 6/29/20 7/10/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-08 50-883-20028-00-00 169-063 EL crew went to morning meeting, got permit started. Standby for cement to set up on CIBP. Stack up Lubricator. Make up 3 1/8" x 10' bailer. Head to well, stab on well, PT WLV and lubricator 250/2500 psi. Open well, swab 20, WHP 900, IA 13, OA 0. RIH to try and find fluid level. Did not get good indication of fluid level due to wt swings with Eline. Tried multiple speeds and depths to get the weight to level off. No luck. CRIH to tag cement. Tag @ 4379' CCL depth. +16' to bottom of tools = 4395' RKB. POOH. OOH Sample bailer came back with very small amount of cement and some fine sand. Stack down so slickline can get rigged up. Called slickline crew out, chopper will depart shore at 0001. Slickline arrives on Tyonek platform. Get checked in, lay down for the night. 07/08/2020 - Wednesday R/U AK E-line. Pressure test lubricator to 250psi/1500psi - Test Good. R/U and RIH with 4.5" CIBP. Tagged fill at 4,404.6Ft. Pull correlation log and send to town. Log on depth. Pull on depth and set 4.5" CIBP at 4,400'. POOH - plug set. R/U and RIH with cement and dump bailer. Dump 5ft of cement on top of CIBP at 4,395' - POOH. Secure well and SDFN. 07/09/2020- Thursday 07/05/2020 - Sunday Continuing from night before. Come online with N2 @ 850 scfm tripping in hole. Tag Cement retainer @ 4487' RKB. PU 10' park here for 20 min. Start chasing ooh to surface. OOH Swab shut well secure. Pumped a total of 121,000 SCF N2. Well blown dry. Recovered 84 bbl water. Start rigging down CTU. RD BOP & riser. Normal up tree w/ bowen companion flange & tree cap. Turn over well to Prod. Operator. Pressure up Tubing = 800 psi w/ lift gas. RU ELU. Surface test GR/CCL & FH. MU Perf Gun: 2-7/8" X 14' GeoDynamics carrier, 6spf, 60*, 15 gm Razor charges. CCL-to-Top Shot = 6.9', CCL-to-Bottom Shot = 20.8', CCL-to Bottom of Gun = 21.6'. PT WLV & Lubricator = 250/1500, changeout o-ring, re-test for PASS. RIH w/ 2-7/8" X 14' Perf Gun to 4456' CCL Tag @ TOP OF CEMENT (TOC = 4456' + 21.6' = 4476.6' KB),T/IA = 780/0. 4456' CCL, log up to 4206' CCL. Correction = 2'. Send log for review & approval. Log & correction verified and approved. RBIH to 4456' CCL. Log up to 4418.1' CCL to place shots on depth (4418.1' + 6.9' =4425' Top Shot). Fire gun to perforate Zone Sterling Y 4425' - 4439'. T/IA = 790/0. Log up 200' & POOH. OOH w/ all shots fired. Perf Gun bull plug filled w/ damp, grey sand. RD ELU. Turn over well to Prod Op. to BOL. Stack out ELU, toolbox, grease skid & lubricator on pipe deck. Prep gun rack for backload to boat. Finish CTU RD. Stack out CT package. Prep fluid pump for boat backload. Clean & secure drill deck & Wellroom# 3. Suspend Job, Job In Progress. Pull on depth and set 4.5" CIBP at 4,400' Rig Start Date End Date CTU/Eline 6/29/20 7/10/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-08 50-883-20028-00-00 169-063 07/10/2020 - Friday Morning ops meeting with S/L and Eline. MIRU S/L. Make up tools with 3.5" blind box, head to well, stabbed on well, PT WLV and lubricator 250/2500 psi. Open well, WHP 900, IA 13, OA 0. RIH, Find fluid level at 3620' RKB, CRIH Tag CMT @ 4395' RKB, OOH Bleed 100 psi off well. RBIH Same fluid level 3620' RKB. Bleed 100 psi three more times, 700, 600, 500 psi got same fluid level. Bleed whp down to header pressure 53 psi. RIH to check fluid level one last time. Fluid level 3620' RKB. OOH, RDSL. MIRU EL. Make up 20' 2 7/8" 6 spf, 60* phase, Razor charge for an 18' perf interval. Head to well, stabbed on. Open up. Put 900 psi back on WHP. Rih tag cement at 4382' rkb, log up to 4000', send log to Engineers. Log was not good, trip back in the hole tag cement 4382' RKB. Log up to 3800', download and send off to Engineers. Depth shift -30'. Got confirmation from Engineers we are on depth. PU to 4333.9 CCL Depth. CCL-TO-TOP shot 10.1', CCL- To- Bottom shot 28.1'. Perf Sterling X formation from 4344'-4362'. WHP 899 PSI, IA 0, OA 0,POOH. OOH break down gun, all shots fired. Very small amount of debris in bullnose. Rig down ELU. MIRU SLU. Make up 4.5" x-lock SSSV. Head to well, stabbed on well. Open well, WHP 899, IA 0, OA 0. RIH Set down at 307' RKB. Spang down to set in place. Pressure up on control line to 3600 psi. Holding pressure. Shear off, pooh, ooh rig down SLU. Turn over to operations to BOL. 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): North Cook Inlet Field / Tertiary Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 9,222'N/A Casing Collapse Structural Conductor 630 psi Surface 2,090 psi Intermediate Production 4,320 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:mmckinley@hilcorp.com Contact Phone: (907) 777-8387 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: N2 Operations 4,773'7" 6,455' 386' 30" Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 6/14/2020 4-1/2" Daniel E. Marlowe Packers (x5) See schematic & Otis SCSSV Landing Nipple Perforation Depth MD (ft): 4,635 - 4,650 6,455' See schematic & 291 (MD) 291 (TVD) Tubing Grade:Tubing MD (ft): 3,631 - 3,640 Perforation Depth TVD (ft): 12.75 / J-55 386' TVD 16" 10-3/4" 623' 2,985' 1,640 psi 3,580 psi 623' 2,620' 623' 2,985' 169-063 50-883-20028-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC N Cook Inlet Unit A-08 MD COMMISSION USE ONLY Authorized Name: Burst 4,412 4,980 psi Tubing Size: Authorized Signature: Operations Manager Mark McKinley CO 68A PRESENT WELL CONDITION SUMMARY 5446' & 4,850'6,494' 4,840' 3,752' 1,209 psi Length Size 386' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017589 / ADL0037831 Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 1:50 pm, May 28, 2020 320-216 Daniel Marlowe I am approving this document 2020.05.28 12:16:16 -08'00' Daniel Marlowe gls 6/1/20 XCT X DSR-5/28/2020 *3500 psi BOPE test (CT) (cement packer) 10-404 DLB 05/28/2020 * CBL required to verify cement placement Comm Required? Yes 6/2/2020 dts 6/1/2020 JLC 6/1/2020 RBDMS HEW 6/4/2020 Well Work Prognosis Well Name:NCIU A-08 API Number:50-883-20028-00 Current Status:SI Gas Well Leg:Leg 2 Estimated Start Date:6/14/2020 Rig:Slickline/E-line/Coil Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett Permit to Drill Number:169-063 First Call Engineer:Mark McKinley Office: 907-777-8387 Cell: 907-953-2685 Second Call Engineer:Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Current Bottom Hole Pressure:1,572 psi @ 3,631 ’ TVD 0.433 psi/ft water gradient to surface Maximum Expected BHP:1,572 psi @ 3,631’ TVD 0.433 psi/ft water gradient to surface Maximum Potential Surface Pressure:1,209 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)( 4) Well History: The NCIU A-08 producer was drilled and completed in 1969. The original completion produced the Middle and Lower Beluga sands from 1969 until 1974 when annular communication through a leaking packer was identified. NCIU A-08 was shut in, and remained shut in until 1983 when a rig workover was performed. During this rig workover parted casing was found at 7182’ MD and a cast iron bridge plug and cement were used to isolate the lower completion. The 1983 rig workover brought online the Upper Beluga and Sterling Sands. In 1994 a second rig workover was performed during which the Sterling B sand was squeezed with cement along with an upper Beluga sand due to water production. A completion was run that consisted of multiple stacked packers and sliding sleeves, providing the ability to open and isolate sands based upon their productivity and water/sand production. In 2020 the Sterling B sand (CI-B) was tested. CI-B was watered out and didn’t produce, A-08 was shut in. The primary objective of this work is to isolate the Sterling B sand (CI-B) and complete the well to produce the Sterling X and Y sands. Safety Concerns: x Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. x Consider tank placement based on wind direction and current weather forecast (venting methane and Nitrogen during this job) x Ensure all crews are aware of stop job authority (Review Standard Well Procedure – Nitrogen Operations) Wellbore Notes: x Tubing punch at ~4,518’ – 4,519’ and ~4,528’ – 4,530’. x Tubing patch from 4,512’ to 4,534’ ID 3.375” x Slickline will remove SSSV Procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. RU CIBP. RIH with CIBP and set at ±4,550’. POOH. 3. RU bailer. RIH and dump bail 5’ of cement on CIBP. TOC @ ±4,545’. POOH. a. Wait on cement to cure 4. Pressure test tubing to 2,500psi for 30mins. Record on chart p h CIBP and set at ±4,550’ (suggest MIT-IA 1500 psi pre-tubing punch also) (Cement Packer completion is proposed) CIBP #1 The primary objective of this work is to isolate the Sterling B sand (CI-B) and complete the well to produce the Sterling X and Y sands. NOTE: CBL and MIT-IA to verify cement placement is required.gls Well Work Prognosis 5. RU tubing punch. RIH with tubing punch. Punch holes at ±4,515’. Consult Engineer prior to tubing punch. POOH. a. R/U and RIH with cement retainer to ±4,500’. Set cement retainer b. Contingent to set cement retainer on Coil Tubing 6. Establish circulation rates down tubing and up IA. a. Contingent second tubing punch to establish acceptable circulation rates b. Circulate well until clean returns are established 7. Pressure test tubing and IA to 1,500psi for 30mins. Record on chart 8. R/U Coil tubing unit a. Perform BOPE pressure test 250psi/3,500psi (Note: Notify AOGCC 48hrs in advance to allow them to witness) b. R/U and RIH with cement retainer at ±4,500’. If not ran on E-line. c. Establish circulating rates Contingency (if unable to establish circulation through retainer) i. Punch tubing near retainer ±4,490’ ii. Establish circulation rates down TBG & up IA iii. Set cement retainer at ±4,475’ iv. Establish circulation rates 9. R/U Cement unit a. Pressure test cement lines 10. Pump cement down coil with a TOC ±4,000’ in the IA. a. Displace cement to retainer with water b. Unsting from cement retainer c. Circulate bottoms up 2X or until clean d. POOH with Coil 11. R/U Slickline a. RIH and tag b. Run pressure temperature log to establish TOC (~6hrs after cement is pumped) 12. Pressure test tubing to 2,500psi for 30mins. Record on chart 13. Pressure test IA to 1,500psi for 30mins. Record on chart 14. Unload well to open top tank. POOH 15. RD Coil tubing 16. MIRU E-line, PT lubricator 250psi/1,500psi 17. RIH w/ E-line guns and perforate per program. RD E-line. 18. RIH set SSSV. RD Slickline. 19. Turn well over to production. Test SVS per regulations. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Coil Tubing BOP Drawing 4. Standard Well Procedure – Nitrogen Operations 5. Flow Diagrams 6. Sundry Revision Change Form (CBL required for Cement packer completion) cement vol approx 500' x .0186 bbl/ft = 10 bbl Pressure test IA to 1,500psi for 30mins. Record on chart (Top perf at 435' MD) MIT-T MIT-IA (Post cement) . Pressure test tubing to 2,500psi for 30mins. Record on chart (Rig up CT and unload well with N2) NOTE: forward CBL log to AOGCC for review before perforating well. gls punch tubing Pressure test tubing and IA to 1,500psi for 30mins. Record on chart Coil tubing cementing (pre cement)CMIT _____________________________________________________________________________________ Updated By: JLL 05/21/20 SCHEMATIC North Cook Inlet Unit Well: NCI A-08 Last Completed: 06/17/1994 PTD: 169-063 API: 50-883-20028-00 PBTD: 5,978’ TD: 9,222’ 30” RKB: MSL = 96’ 7” B 3 4 5 6 7 8 9 10 11 12 13 Tubing Punch 4,518’ – 4,519’ 10-3/4” ’ E-8, E-9 F-4, F-5 F-6 G-1 G-4 H-1 H-3 H-6 I-7 K-2 M-2 M-10 N-2 16” 1 2 14 15 17 16 Parted Casing below EZSV @ 7,182’ 18 CI-1 CI-3 CI-3.1 CI-4 CI-2 CI-5 CI-6.2 CI-7 CI-8.2 CI-9.1 CI-10 A-3 B-6 Tubing Punch 4,528’ – 4,530’ Tagged Fill @ 5,335’ – 04/15/20 Tubing Patch 4,512’ – 4,534 ID 3.375” Tubing Punch 4,635’ CIBP w/ 10’ Cmt TOC @ 4,840’3A X X CASING DETAIL Size Wt Grade Conn ID Top Btm 30” H-40 STC 28.000 Surf 386’ 16” 65 H-40 STC 15.250 Surf 623’ 10-3/4” 45.5 J-55 BTC 9.794 Surf 2,985’ 7” 26 J-55 BTC 6.276 Surf 6,455’ TUBING DETAIL 4-1/2” 12.75 J-55 EUE 8rd 3.958 Surf 5,892’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 38.9' 39' 4.500 FMC Tubing Hanger 1 291' 291' 3.813 Otis SCSSV Landing Nipple 2 4,536' 3,575' 3.937 Upper Seal Bore 4,541' 3,578' 3.937 Ratch Latch 4,545' 3,580' 3.880 Halliburton VSR Packer (Retrievable w/tubing adapter) 3 4,613' 3,619' 3.813 Halliburton X Nipple 3A 4,850’ 3,758’ - 3.958” 4-1/2” CIBP w/5’ cmt. TOC at 4,840’ 4 4,890' 3,782' 3.813 Locator No-Go 4,891' 3,783' 3.970 Halliburton MHR Packer (Permanent) 5 5,183' 3,961' 3.958 Otis XD Sliding Sleeve (Closed 11/12/12) 6 5,313' 4,042' 3.958 Otis XD Sliding Sleeve (Open 02/17/10) 7 5,349' 4,065' 3.937 Upper Seal Bore 5,360' 4,071' 3.937 Ratch Latch 5,361' 4,072' 3.970 Halliburton MHR Packer (Permanent) 8 5,446' 4,126' 3.813 Otis XA Sliding Sleeve (Closed)PX Plug set in sleeve 9 5,495' 4,157' 3.937 Ratch Latch 5,496' 4,158' 3.970 Halliburton MHR Packer (Permanent) 10 5,648' 4,254' 3.813 Otis XD Sliding Sleeve (Closed) 11 5,698' 4,286' 3.937 Ratch Latch 5,699' 4,287' 3.970 Halliburton MHR Packer (Permanent) 12 5,859' 4,390' 3.725 Halliburton X Nipple 13 5,892' 4,412' 3.958 Wireline Re-Entry Guide w/Pump Out Plug 14 5,978’ 4,468’ - Cement Retainer 15 6,150’ 4,582’ - Cement Plug 16 6,850’ 5,007’ - CIBP 17 7,030’ 5,113’ - Cement Plug 18 7,150’ 5,183’ - Cement Retainer Updated By: JLL 05/21/20 SCHEMATIC North Cook Inlet Unit Well: NCI A-08 Last Completed: 06/17/1994 PTD: 169-063 API: 50-883-20028-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status B 4,635’ 4,650’ 3,631’ 3,640’ 15’ 05/07/20 Open B 4,635' 4,735' 3,631' 3,690' 100' 6/2/1994 CMT SQZD CI-1 4,979' 5,036' 3,836' 3,870' 57' 05/05/20 Isolated CI-2 5,061' 5,161' 3,885' 3,947' 100' 05/05/20 Isolated CI-3 5,191' 5,211' 3,965' 3,977' 20' 05/05/20 Isolated CI-3.1 5,240' 5,250' 3,996' 4,002' 10' 05/05/20 Isolated CI-4 5,266' 5,283' 4,012' 4,023' 17' 05/05/20 Isolated CI-4 5,288' 5,325' 4,026' 4,049' 37' 05/05/20 Isolated CI-5 5,388' 5,438' 4,089' 4,121' 50' 05/05/20 Isolated CI-6.2 5,563' 5,570' 4,200' 4,204' 7' 05/05/20 Isolated CI-7 5,580' 5,596' 4,211' 4,221' 16' 05/05/20 Isolated CI-7 5,600' 5,624' 4,227' 4,242' 24' 05/05/20 Isolated CI-8.2 5,743' 5,753' 4,315' 4,322' 10' 05/05/20 Isolated CI-9.1 5,837' 5,845' 4,376' 4,381' 8' 05/05/20 Isolated CI-10 5,855' 5,885' 4,387' 4,407' 30' 05/05/20 Isolated A-3 6,014' 6,015' 4,492' 4,493' 1'8/3/1969 CMT SQZD B-6 6,302' 6,310' 4,679' 4,684' 8'8/3/1969 CMT SQZD E-8, E-9 7,030' 7,067' 5,113' 5,135' 37'8/4/1969 ISOLATED F-4, F-5 7,197' 7,214' 5,211' 5,221' 17'8/4/1969 ISOLATED F-6 7,218' 7,238' 5,224' 5,235' 20'8/4/1969 ISOLATED G-1 7,309' 7,326' 5,280' 5,290' 17'8/4/1969 ISOLATED G-4 7,388' 7,398' 5,330' 5,336' 10'7/30/1969 ISOLATED H-1 7,478' 7,488' 5,386' 5,392' 10'8/4/1969 ISOLATED H-3 7,513' 7,538' 5,408' 5,424' 25'8/4/1969 ISOLATED H-6 7,583' 7,598' 5,452' 5,461' 15'8/4/1969 ISOLATED I-7 7,822' 7,828' 5,601' 5,605' 6'7/27/1969 ISOLATED K-2 8,008' 8,018' 5,719' 5,725' 10'8/4/1969 ISOLATED M-2 8,180' 8,185' 5,826' 5,829' 5'8/4/1969 ISOLATED M-10 8,307' 8,314' 5,906' 5,910' 7'8/4/1969 ISOLATED N-2 8,375' 8,425' 5,949' 5,982' 50'7/24/1969 ISOLATED _____________________________________________________________________________________ Updated By: JLL 05/27/20 PROPOSED North Cook Inlet Unit Well: NCI A-08 Last Completed: 06/17/1994 PTD: 169-063 API: 50-883-20028-00 PBTD:5,978’ TD:9,222’ 2 30” RKB: MSL =96’ 7” B 4 5 6 7 8 9 10 11 12 13 14 15 Tubing Punch 4,518’ – 4,519’ 10-3/4” ’ E-8, E-9 F-4, F-5 F-6 G-1 G-4 H-1 H-3 H-6 I-7 K-2 M-2 M-10 N-2 16” 1 3 TOC @ ± 4,000’ 16 17 19 18 Parted Casing below EZSV @ 7,182’ 20 CI-1 CI-3 CI-3.1 CI-4 CI-2 CI-5 CI-6.2 CI-7 CI-8.2 CI-9.1 CI-10 A-3 B-6 ,, Tubing Punch 4,528’–4,530’ Tagged Fill @ 5,335’ – 04/15/20 Tubing Patch 4,512’ – 4,534 ID 3.375” Tubing Punch 4,635’ CIBP w / 10’ Cmt TOC @ 4,840’5A Tubing Punch ±4,515’ Sterling Y Sterling X 2 X X CASING DETAIL Size Wt Grade Conn ID Top Btm 30” H-40 STC 28.000 Surf 386’ 16” 65 H-40 STC 15.250 Surf 623’ 10-3/4” 45.5 J-55 BTC 9.794 Surf 2,985’ 7” 26 J-55 BTC 6.276 Surf 6,455’ TUBING DETAIL 4-1/2” 12.75 J-55 EUE 8rd 3.958 Surf 5,892’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 38.9' 39' 4.500 FMC Tubing Hanger 1 291' 291' 3.813 Otis SCSSV Landing Nipple 2 ±4,500’ ±3,554’ Cement Retainer 3 4,536' 3,575' 3.937 Upper Seal Bore 4,541' 3,578' 3.937 Ratch Latch 4,545' 3,580' 3.880 Halliburton VSR Packer (Retrievable w/tubing adapter) 4 ±4,550 ±3,583’ CIBP w/5’ of cmt TOC ~4,545’ 5 4,613' 3,619' 3.813 Halliburton X Nipple 5A 4,850’ 3,758’ - 3.958” 4-1/2” CIBP w/5’ cmt. TOC at 4,840’ 6 4,890' 3,782' 3.813 Locator No-Go 4,891' 3,783' 3.970 Halliburton MHR Packer (Permanent) 7 5,183' 3,961' 3.958 Otis XD Sliding Sleeve (Closed 11/12/12) 8 5,313' 4,042' 3.958 Otis XD Sliding Sleeve (Open 02/17/10) 9 5,349' 4,065' 3.937 Upper Seal Bore 5,360' 4,071' 3.937 Ratch Latch 5,361' 4,072' 3.970 Halliburton MHR Packer (Permanent) 10 5,446' 4,126' 3.813 Otis XA Sliding Sleeve (Closed)PX Plug set in sleeve 11 5,495' 4,157' 3.937 Ratch Latch 5,496' 4,158' 3.970 Halliburton MHR Packer (Permanent) 12 5,648' 4,254' 3.813 Otis XD Sliding Sleeve (Closed) 13 5,698' 4,286' 3.937 Ratch Latch 5,699' 4,287' 3.970 Halliburton MHR Packer (Permanent) 14 5,859' 4,390' 3.725 Halliburton X Nipple 15 5,892' 4,412' 3.958 Wireline Re-Entry Guide w/Pump Out Plug 16 5,978’ 4,468’ - Cement Retainer 17 6,150’ 4,582’ - Cement Plug 18 6,850’ 5,007’ - CIBP 19 7,030’ 5,113’ - Cement Plug 20 7,150’ 5,183’ - Cement Retainer cement packer 4 1/2 x 7" = .0186 bbl/ft CBL---------------> Updated By: JLL 05/27/20 PROPOSED North Cook Inlet Unit Well: NCI A-08 Last Completed: 06/17/1994 PTD: 169-063 API: 50-883-20028-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Sterling X ±4,335 ±4,362 ±3,460 ±3,476 ±27' Future Proposed Sterling Y ±4,425 ±4,439 ±3,511 ±3,519 ±14’ Future Proposed B 4,635’ 4,650’ 3,631’ 3,640’ 15’ 05/07/20 Isolated B 4,635' 4,735' 3,631' 3,690' 100' 6/2/1994 CMT SQZD CI-1 4,979' 5,036' 3,836' 3,870' 57' 05/05/20 Isolated CI-2 5,061' 5,161' 3,885' 3,947' 100' 05/05/20 Isolated CI-3 5,191' 5,211' 3,965' 3,977' 20' 05/05/20 Isolated CI-3.1 5,240' 5,250' 3,996' 4,002' 10' 05/05/20 Isolated CI-4 5,266' 5,283' 4,012' 4,023' 17' 05/05/20 Isolated CI-4 5,288' 5,325' 4,026' 4,049' 37' 05/05/20 Isolated CI-5 5,388' 5,438' 4,089' 4,121' 50' 05/05/20 Isolated CI-6.2 5,563' 5,570' 4,200' 4,204' 7' 05/05/20 Isolated CI-7 5,580' 5,596' 4,211' 4,221' 16' 05/05/20 Isolated CI-7 5,600' 5,624' 4,227' 4,242' 24' 05/05/20 Isolated CI-8.2 5,743' 5,753' 4,315' 4,322' 10' 05/05/20 Isolated CI-9.1 5,837' 5,845' 4,376' 4,381' 8' 05/05/20 Isolated CI-10 5,855' 5,885' 4,387' 4,407' 30' 05/05/20 Isolated A-3 6,014' 6,015' 4,492' 4,493' 1'8/3/1969 CMT SQZD B-6 6,302' 6,310' 4,679' 4,684' 8'8/3/1969 CMT SQZD E-8, E-9 7,030' 7,067' 5,113' 5,135' 37'8/4/1969 ISOLATED F-4, F-5 7,197' 7,214' 5,211' 5,221' 17'8/4/1969 ISOLATED F-6 7,218' 7,238' 5,224' 5,235' 20'8/4/1969 ISOLATED G-1 7,309' 7,326' 5,280' 5,290' 17'8/4/1969 ISOLATED G-4 7,388' 7,398' 5,330' 5,336' 10'7/30/1969 ISOLATED H-1 7,478' 7,488' 5,386' 5,392' 10'8/4/1969 ISOLATED H-3 7,513' 7,538' 5,408' 5,424' 25'8/4/1969 ISOLATED H-6 7,583' 7,598' 5,452' 5,461' 15'8/4/1969 ISOLATED I-7 7,822' 7,828' 5,601' 5,605' 6'7/27/1969 ISOLATED K-2 8,008' 8,018' 5,719' 5,725' 10'8/4/1969 ISOLATED M-2 8,180' 8,185' 5,826' 5,829' 5'8/4/1969 ISOLATED M-10 8,307' 8,314' 5,906' 5,910' 7'8/4/1969 ISOLATED N-2 8,375' 8,425' 5,949' 5,982' 50'7/24/1969 ISOLATED Sterling X ±4,335 ±4,362 ±3,460 ±3,476 ±27'Future Proposed Sterling Y ±4,425 ±4,439 ±3,511 ±3,519 ±14’Future Proposed STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. 1110K PSI Fluid PumpNitrogen PumpCirc PSIInjector HeadHR-580GooseneckCT StringSuction Hose To Source Tank Coiled Tubing Treating Equipment Layout Dart CVNitrogen Tank2,000 Gallons ea.N2 Bleed StackChoke ManifoldReturn Line To TankSLB Flow Cross4.06"10K Quad BOPTreating Line Bleed Stack Dart CVCustomer ValveWH PSI4.06" 10K Riser From WH To DeckCO62 5K LubricatorTop Load StripperBackside CVPump CV1502 Treating Iron 2"1502 Flowback Iron 2" 1502 Nitrogen Iron 1.5" LP Suction Hoses 3"Plug Valve 2"x2"Check ValveLP ValvePressure SensorNote: Exact stack drawing and equipment layout with equipment dimensions will be provided following a site visitPump PSI<-----N2 Hilcorp Monopod Rig 56 Flow Diagram Fluids Pumped Fluids Returned Valve Open Valve Closed Gate Valve Ball Valve Butterfly Valve Lo Torq Valve Automatic Choke Manual Choke Pressure Gauge Knife Valve Choke Line P PIT SYSTEM SucƟon SHAKER SHAKER CHOKE MANIFOLD GAS BUSTER Panic Line C12 C13 C15 C14 C16 A B C4 C5 C6 C7 C2 C10 C9 C11 C8 C3 P C1 C Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well N Cook Inlet Unit A-08 (PTD 169-063)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Tubing Punch & Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9,222 feet 5,446; 4,850 feet true vertical 6,494 feet N/A feet Effective Depth measured 4,840 feet See schematic feet true vertical 3,752 feet See schematic feet Perforation depth Measured depth 4,635 - 4,650 feet True Vertical depth 3,631 - 3,640 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.75 / J-55 4,412 MD 3,504 TVD Packers and SSSV (type, measured and true vertical depth)See Schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: WINJ WAG 0 Water-Bbl MD 386 623 2,985 TVD 386 Casing Pressure Tubing Pressure 0 Oil-Bbl measured true vertical Packer 7" Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 200 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 169-063 50-883-20028-00-00 Plugs ADL0017589 / ADL0037831 N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-170 160 Size 156 N Cook Inlet Unit A-08 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 14 Authorized Signature with date: Authorized Name:Daniel E. Marlowe Operations Manager Mark McKinley mmckinley@hilcorp.com 5. Permit to Drill Number: 0 North Cook Inlet Field / Tertiary Gas PoolN/A measured 6,455 N/A Intermediate Production Casing Structural Liner Length 386 623 2,985 Conductor Surface 4,320psi 30" 16" 10-3/4" 6,455 4,980psi 623 2,620 4,773 2,090psi Burst 1,640psi 3,580psi (907) 777-8387 Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse 630psi Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:53 am, May 22, 2020 Daniel Marlowe I am approving this document 2020.05.22 07:26:28 -08'00' Daniel Marlowe DSR-5/26/2020gls 5/26/20 Tubing Punch & Tubing Patch Perforat Plug Perforations RBDMS HEW 5/22/2020 _____________________________________________________________________________________ Updated By: JLL 05/21/20 SCHEMATIC North Cook Inlet Unit Well: NCI A-08 Last Completed: 06/17/1994 PTD: 169-063 API: 50-883-20028-00 PBTD: 5,978’ TD: 9,222’ 30” RKB: MSL = 96’ 7” B 3 4 5 6 7 8 9 10 11 12 13 Tubing Punch 4,518’ – 4,519’ 10-3/4” ’ E-8, E-9 F-4, F-5 F-6 G-1 G-4 H-1 H-3 H-6 I-7 K-2 M-2 M-10 N-2 16” 1 2 14 15 17 16 Parted Casing below EZSV @ 7,182’ 18 CI-1 CI-3 CI-3.1 CI-4 CI-2 CI-5 CI-6.2 CI-7 CI-8.2 CI-9.1 CI-10 A-3 B-6 Tubing Punch 4,528’ – 4,530’ Tagged Fill @ 5,335’ – 04/15/20 Tubing Patch 4,512’ – 4,534 ID 3.375” Tubing Punch 4,635’ CIBP w/ 10’ Cmt TOC @ 4,840’3A X X CASING DETAIL Size Wt Grade Conn ID Top Btm 30” H-40 STC 28.000 Surf 386’ 16” 65 H-40 STC 15.250 Surf 623’ 10-3/4” 45.5 J-55 BTC 9.794 Surf 2,985’ 7” 26 J-55 BTC 6.276 Surf 6,455’ TUBING DETAIL 4-1/2” 12.75 J-55 EUE 8rd 3.958 Surf 5,892’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 38.9' 39' 4.500 FMC Tubing Hanger 1 291' 291' 3.813 Otis SCSSV Landing Nipple 2 4,536' 3,575' 3.937 Upper Seal Bore 4,541' 3,578' 3.937 Ratch Latch 4,545' 3,580' 3.880 Halliburton VSR Packer (Retrievable w/tubing adapter) 3 4,613' 3,619' 3.813 Halliburton X Nipple 3A 4,850’ 3,758’ - 3.958” 4-1/2” CIBP w/5’ cmt. TOC at 4,840’ 4 4,890' 3,782' 3.813 Locator No-Go 4,891' 3,783' 3.970 Halliburton MHR Packer (Permanent) 5 5,183' 3,961' 3.958 Otis XD Sliding Sleeve (Closed 11/12/12) 6 5,313' 4,042' 3.958 Otis XD Sliding Sleeve (Open 02/17/10) 7 5,349' 4,065' 3.937 Upper Seal Bore 5,360' 4,071' 3.937 Ratch Latch 5,361' 4,072' 3.970 Halliburton MHR Packer (Permanent) 8 5,446' 4,126' 3.813 Otis XA Sliding Sleeve (Closed)PX Plug set in sleeve 9 5,495' 4,157' 3.937 Ratch Latch 5,496' 4,158' 3.970 Halliburton MHR Packer (Permanent) 10 5,648' 4,254' 3.813 Otis XD Sliding Sleeve (Closed) 11 5,698' 4,286' 3.937 Ratch Latch 5,699' 4,287' 3.970 Halliburton MHR Packer (Permanent) 12 5,859' 4,390' 3.725 Halliburton X Nipple 13 5,892' 4,412' 3.958 Wireline Re-Entry Guide w/Pump Out Plug 14 5,978’ 4,468’ - Cement Retainer 15 6,150’ 4,582’ - Cement Plug 16 6,850’ 5,007’ - CIBP 17 7,030’ 5,113’ - Cement Plug 18 7,150’ 5,183’ - Cement Retainer Tubing Punchg 4,635’ CIBP w/ 10’ Cmt TOC @ 4,840’ 3A 4,850’3,758’-3.958” 4-1/2” CIBP w/5’ cmt. TOC at 4,840’ CIBP w/ cmt Updated By: JLL 05/21/20 SCHEMATIC North Cook Inlet Unit Well: NCI A-08 Last Completed: 06/17/1994 PTD: 169-063 API: 50-883-20028-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status B 4,635’ 4,650’ 3,631’ 3,640’ 15’ 05/07/20 Open B 4,635' 4,735' 3,631' 3,690' 100' 6/2/1994 CMT SQZD CI-1 4,979' 5,036' 3,836' 3,870' 57' 05/05/20 Isolated CI-2 5,061' 5,161' 3,885' 3,947' 100' 05/05/20 Isolated CI-3 5,191' 5,211' 3,965' 3,977' 20' 05/05/20 Isolated CI-3.1 5,240' 5,250' 3,996' 4,002' 10' 05/05/20 Isolated CI-4 5,266' 5,283' 4,012' 4,023' 17' 05/05/20 Isolated CI-4 5,288' 5,325' 4,026' 4,049' 37' 05/05/20 Isolated CI-5 5,388' 5,438' 4,089' 4,121' 50' 05/05/20 Isolated CI-6.2 5,563' 5,570' 4,200' 4,204' 7' 05/05/20 Isolated CI-7 5,580' 5,596' 4,211' 4,221' 16' 05/05/20 Isolated CI-7 5,600' 5,624' 4,227' 4,242' 24' 05/05/20 Isolated CI-8.2 5,743' 5,753' 4,315' 4,322' 10' 05/05/20 Isolated CI-9.1 5,837' 5,845' 4,376' 4,381' 8' 05/05/20 Isolated CI-10 5,855' 5,885' 4,387' 4,407' 30' 05/05/20 Isolated A-3 6,014' 6,015' 4,492' 4,493' 1'8/3/1969 CMT SQZD B-6 6,302' 6,310' 4,679' 4,684' 8'8/3/1969 CMT SQZD E-8, E-9 7,030' 7,067' 5,113' 5,135' 37'8/4/1969 ISOLATED F-4, F-5 7,197' 7,214' 5,211' 5,221' 17'8/4/1969 ISOLATED F-6 7,218' 7,238' 5,224' 5,235' 20'8/4/1969 ISOLATED G-1 7,309' 7,326' 5,280' 5,290' 17'8/4/1969 ISOLATED G-4 7,388' 7,398' 5,330' 5,336' 10'7/30/1969 ISOLATED H-1 7,478' 7,488' 5,386' 5,392' 10'8/4/1969 ISOLATED H-3 7,513' 7,538' 5,408' 5,424' 25'8/4/1969 ISOLATED H-6 7,583' 7,598' 5,452' 5,461' 15'8/4/1969 ISOLATED I-7 7,822' 7,828' 5,601' 5,605' 6'7/27/1969 ISOLATED K-2 8,008' 8,018' 5,719' 5,725' 10'8/4/1969 ISOLATED M-2 8,180' 8,185' 5,826' 5,829' 5'8/4/1969 ISOLATED M-10 8,307' 8,314' 5,906' 5,910' 7'8/4/1969 ISOLATED N-2 8,375' 8,425' 5,949' 5,982' 50'7/24/1969 ISOLATED Open05/07/20B 4,635’ 4,650’ 3,631’ 3,640’ 15’ Rig Start Date End Date E-Line 5/5/20 5/7/20 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-08 50-883-20028-00-00 169-063 No activity. M/U 4 1/2" x 20' Owen X-span tubing patch. Wait on boat delivery of lubricator. Obtain PTW and hold PJSM. Wait on crane. R/U sheaves. P/U tools and lubricator. Pressure test 250 L/1500 H. Open swab valve. RIH with patch and tagged at 4580'. Logged CCL up pass. Correlated to packer at 4536'. Consult with engineer. Positioned patch at 4512.5' to 4534'. Set patch. Good indication of set. POOH. R/D patch setting tools. Install night cap. Production test tubing at 970 psi. Production filling annulus with water and bleeding gas for MIT when annulus is full. 05/07/2020- Thursday No activity. Perform MIT on annulus at 1500 psi for 30 minutes on chart recorder. Good test. RIH with 1 9/16" x 1' tubing punch loaded with 4 shots. Set down on cement plug at 4840'. Perform depth correlation. Confirm depth with engineer. Pull into position at 4636'. Fire shots. 970 psi on tubing. POOH. Pick up 15' x 2 7/8" 6 spf, / 60 degree perf gun. RIH and correlate on depth. Confirm with engineer. Adjust uphole 1'. Fire guns perforating 4635' to 4650'. POOH. tubing pressure increased to 1120 psi. Rig down e-line unit. Secure well. Release crew. No further activity on this day. Attempt to flow well, A-08 will not produce and is dead. A-08 Shut-in. 05/06/2020 - Wednesday Daily Operations: Obtain PTW and hot work permit. Rig up and make up lubricator and tools. P/U 1.68 Gamma/CCL with Baker #10 setting tool and 3.5 OD CIBP. Pressure test at 250 L/1500 H. Open swab valve. RIH and make correlation pass from 4930' to 4400'. Send log to engineer and confirm set depth. Set CIBP at 4850'. Confirm set. POOH. Muster for high gas alarm. Mix 5 gallons cement. Fill bailer and RIH. Set on plug at 4850'. P/U 10' and dump cement. POOH. Rig down and secure well. Crew rest. No activity. 05/05/2020 - Tuesday Perform MIT on annulus at 1500 psi for 30 minutes on chart recorder. G Positioned patch at 4512.5' to 4534'. Set patch. Set CIBP at 4850'. M/U 4 1/2" x 20' Owen X-span tubing patch. W Pick up 15' x 2 7/8" 6 spf, / 60 degree perf gun. Fire guns perforating 4635' to 4650' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): North Cook Inlet Field / Tertiary Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,222'5,373' Casing Collapse Structural Conductor 630 psi Surface 2,090 psi Intermediate Production 4,320 psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:jkaiser@hilcorp.com Contact Phone: (907) 777-8393 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: Tubing Patch & Tubing Punch 4,773'7" Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 5/1/2020 4-1/2" Daniel E. Marlowe Packers (x5) See schematic & Otis SCSSV Landing Nipple 6,455' Perforation Depth MD (ft): 4,979 - 5,885 6,455' See schematic & 291 (MD) 291 (TVD) Tubing Grade: Tubing MD (ft): 3,836 - 4,407 Perforation Depth TVD (ft): 386' 30" 16" 10-3/4" 623' 2,985' MD 1,640 psi 3,580 psi 623' 2,620' 623' 2,985' 386' 12.75 / J-55 TVD Burst 4,412 4,980 psi Tubing Size: 169-063 50-883-20028-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC N Cook Inlet Unit A-08 5,446'6,494' 5,335' 4,056' 1,209 psi COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017589 / ADL0037831 Authorized Signature: Operations Manager Joe Kaiser CO 68 PRESENT WELL CONDITION SUMMARY Length Size 386' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Daniel Marlowe I am approving this document 2020.04.17 11:21:52 -08'00' Daniel Marlowe By Jody Colombie at 2:21 pm, Apr 17, 2020 320-170 DSR-4/17/2020DLB 04/17/2020 X 10-404 + Alternate SSV placement approved per 20 AAC 25.265(o)(1) gls 4/20/20 Comm. q 4/20/2020 dts 4/20/2020 JLC 4/20/2020 Well Work Prognosis Well Name:NCIU A-08 API Number:50-883-20028-00 Current Status:Gas Well Leg:Leg 2 Estimated Start Date:5/1/2020 Rig:E-Line Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett Permit to Drill Number:169-063 First Call Engineer:Joe Kaiser Office: 907-777-8393 Cell: 907-952-8897 Second Call Engineer:Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Current Bottom Hole Pressure:1,572 psi @ 3,631 ’ TVD 0.433 psi/ft water gradient to surface Maximum Expected BHP:1,572 psi @ 3,631’ TVD 0.433 psi/ft water gradient to surface Maximum Potential Surface Pressure:1,209 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)( 4) Well History: The NCIU A-08 producer was drilled and completed in 1969. The original completion produced the Middle and Lower Beluga sands from 1969 until 1974 when annular communication through a leaking packer was identified. NCIU A-08 was shut in, and remained shut in until 1983 when a rig workover was performed. During this rig workover parted casing was found at 7182’ MD and a cast iron bridge plug and cement were used to isolate the lower completion. The 1983 rig workover brought online the Upper Beluga and Sterling Sands. In 1994 a second rig workover was performed during which the Sterling B sand was squeezed with cement along with an upper Beluga sand due to water production. A completion was run that consisted of multiple stacked packers and sliding sleeves, providing the ability to open and isolate sands based upon their productivity and water/sand production. The primary objective of this work is to test the Sterling B Sand (CI-B). Analysis of the NCIU’s history, coupled with current log analysis, indicates that water coning due to excessive drawdown was the culprit for the increased water production seen historically. Significant gas reserves appear to remain in the Sterling B Sand, therefore, the top 15’ of the sand will be perforated and drawdown will be controlled to optimize the gas rate from the Sterling B Sand. Waiver Request: Hilcorp requests waiver to 20AAC25.265(c)(1). We request locating the SSV on the tree wing allowing the SSV to remain in the production stream while providing concurrent well bore access. Additionally, a SSSV will be installed. Wellbore Notes: x Tubing punch at ~4,518’ – 4,519’ and ~4,528’ – 4,530’. x Slickline removed SSSV and tagged at 5,335’ WLM. E-line Procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. RU CIBP. RIH with CIBP and set at ~4,850’. POOH. 3. RU bailer. RIH and dump bail 5’ of cement on CIBP. TOC @ ~4,845’. POOH. 4. RU tubing punch. RIH with tubing punch. Punch hole at ~4,635’. Consult Engineer prior to tubing punch. POOH. Note: Tubing punch is to determine the integrity of the squeezed B-sands. If well flows it will be returned to production. variance The primary objective of this work is to test the Sterling B Sand (CI-B). Analysis of the NCIU’s history, coupled with current log analysis, indicates that water coning due to excessive drawdown was the culprit for the increased water production seen historically. Significant gas reserves appear to remain in the Sterling B Sand, therefore, the top 15’ of the sand will be perforated and drawdown will be controlled to optimize the gas rate from the Sterling B Sand. Variance approved ... SSSV is also at 291 ft MD Punch hole at ~4,635’plug perfs Well Work Prognosis 5. RU e-line guns and perforate per program. RD E-line. 6. RU Slickline. PT lubricator to 1,500 psi Hi and 250 psi low. 7. RIH with tubing patch. Set patch from ±4,515’ – ±4,535’. 8. Pressure test casing to 1,500 psig for 30mins. Record on chart. 9. RIH set SSSV. RD Slickline. 10. Turn well over to production. Test SVS per regulations. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic tubing patch and MIT-IA _____________________________________________________________________________________ Updated By: JLL 04/14/20 SCHEMATIC North Cook Inlet Unit Well: NCI A-08 Last Completed: 06/17/1994 PTD: 169-063 API: 50-883-20028-00 PBTD: 5,978’ TD:9,222’ 30” RKB: MSL = 96’ 7” B3 4 5 6 7 8 9 10 11 12 13 Tubing Punch 4,518’ – 4,519’ 10-3/4” ’ E-8, E-9 F-4, F-5 F-6 G-1 G-4 H-1 H-3 H-6 I-7 K-2 M-2 M-10 N-2 16” 1 2 14 15 17 16 Parted Casing below EZSV @ 7,182’ 18 CI -1 CI -3 CI -3.1 CI -4 CI -2 CI -5 CI -6.2 CI -7 CI -8.2 CI -9.1 CI -10 A-3 B-6 Tubing Punch 4,528’ – 4,530’ Tagged fill @ 5,335’ – 04/15/20 X X CASING DETAIL Size Wt Grade Conn ID Top Btm 30” H-40 STC 28.000 Surf 386’ 16” 65 H-40 STC 15.250 Surf 623’ 10-3/4” 45.5 J-55 BTC 9.794 Surf 2,985’ 7” 26 J-55 BTC 6.276 Surf 6,455’ TUBING DETAIL 4-1/2” 12.75 J-55 EUE 8rd 3.958 Surf 4,412’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 38.9' 39' 4.500 FMC Tubing Hanger 1 291' 291' 3.813 Otis SCSSV Landing Nipple 2 4,536' 3,575' 3.937 Upper Seal Bore 4,541' 3,578' 3.937 Ratch Latch 4,545' 3,580' 3.880 Halliburton VSR Packer (Retrievable w/tubing adapter) 3 4,613' 3,619' 3.813 Halliburton X Nipple 4 4,890' 3,782' 3.813 Locator No-Go 4,891' 3,783' 3.970 Halliburton MHR Packer (Permanent) 5 5,183' 3,961' 3.958 Otis XD Sliding Sleeve (Closed 11/12/12) 6 5,313' 4,042' 3.958 Otis XD Sliding Sleeve (Open 02/17/10) 7 5,349' 4,065' 3.937 Upper Seal Bore 5,360' 4,071' 3.937 Ratch Latch 5,361' 4,072' 3.970 Halliburton MHR Packer (Permanent) 8 5,446' 4,126' 3.813 Otis XA Sliding Sleeve (Closed)PX Plug set in sleeve 9 5,495' 4,157' 3.937 Ratch Latch 5,496' 4,158' 3.970 Halliburton MHR Packer (Permanent) 10 5,648' 4,254' 3.813 Otis XD Sliding Sleeve (Closed) 11 5,698' 4,286' 3.937 Ratch Latch 5,699' 4,287' 3.970 Halliburton MHR Packer (Permanent) 12 5,859' 4,390' 3.725 Halliburton X Nipple 13 5,892' 4,412' 3.958 Wireline Re-Entry Guide w/Pump Out Plug 14 5,978’ 4,468’ - Cement Retainer 15 6,150’ 4,582’ - Cement Plug 16 6,850’ 5,007’ - CIBP 17 7,030’ 5,113’ - Cement Plug 18 7,150’ 5,183’ - Cement Retainer Updated By: JLL 04/14/20 SCHEMATIC North Cook Inlet Unit Well: NCI A-08 Last Completed: 06/17/1994 PTD: 169-063 API: 50-883-20028-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status B 4,635' 4,735' 3,631' 3,690' 100' 6/2/1994 CMT SQZD CI-1 4,979' 5,036' 3,836' 3,870' 57' 7/30/1983 OPEN CI-2 5,061' 5,161' 3,885' 3,947' 100' 7/30/1983 OPEN CI-3 5,191' 5,211' 3,965' 3,977' 20' 7/30/1983 OPEN CI-3.1 5,240' 5,250' 3,996' 4,002' 10' 7/30/1983 OPEN CI-4 5,266' 5,283' 4,012' 4,023' 17' 7/30/1983 OPEN CI-4 5,288' 5,325' 4,026' 4,049' 37' 7/30/1983 OPEN CI-5 5,388' 5,438' 4,089' 4,121' 50' 7/30/1983 OPEN CI-6.2 5,563' 5,570' 4,200' 4,204' 7' 7/30/1983 OPEN CI-7 5,580' 5,596' 4,211' 4,221' 16' 7/30/1983 OPEN CI-7 5,600' 5,624' 4,227' 4,242' 24' 7/30/1983 OPEN CI-8.2 5,743' 5,753' 4,315' 4,322' 10' 7/30/1983 OPEN CI-9.1 5,837' 5,845' 4,376' 4,381' 8' 7/30/1983 OPEN CI-10 5,855' 5,885' 4,387' 4,407' 30' 7/30/1983 OPEN A-3 6,014' 6,015' 4,492' 4,493' 1'8/3/1969 CMT SQZD B-6 6,302' 6,310' 4,679' 4,684' 8'8/3/1969 CMT SQZD E-8, E-9 7,030' 7,067' 5,113' 5,135' 37'8/4/1969 ISOLATED F-4, F-5 7,197' 7,214' 5,211' 5,221' 17'8/4/1969 ISOLATED F-6 7,218' 7,238' 5,224' 5,235' 20'8/4/1969 ISOLATED G-1 7,309' 7,326' 5,280' 5,290' 17'8/4/1969 ISOLATED G-4 7,388' 7,398' 5,330' 5,336' 10'7/30/1969 ISOLATED H-1 7,478' 7,488' 5,386' 5,392' 10'8/4/1969 ISOLATED H-3 7,513' 7,538' 5,408' 5,424' 25'8/4/1969 ISOLATED H-6 7,583' 7,598' 5,452' 5,461' 15'8/4/1969 ISOLATED I-7 7,822' 7,828' 5,601' 5,605' 6'7/27/1969 ISOLATED K-2 8,008' 8,018' 5,719' 5,725' 10'8/4/1969 ISOLATED M-2 8,180' 8,185' 5,826' 5,829' 5'8/4/1969 ISOLATED M-10 8,307' 8,314' 5,906' 5,910' 7'8/4/1969 ISOLATED N-2 8,375' 8,425' 5,949' 5,982' 50'7/24/1969 ISOLATED _____________________________________________________________________________________ Updated By: JEK 04/16/20 PROPOSED North Cook Inlet Unit Well: NCI A-08 Last Completed: 06/17/1994 PTD: 169-063 API: 50-883-20028-00 PBTD: 5,978’ TD: 9,222’ 30” RKB: MSL = 96’ 7” B 3 4 5 6 7 8 9 10 11 12 13 Tubing Punch 4,518’ – 4,519’ 10-3/4” ’ E-8, E-9 F-4, F-5 F-6 G-1 G-4 H-1 H-3 H-6 I-7 K-2 M-2 M-10 N-2 16” 1 2 14 15 17 16 Parted Casing below EZSV @ 7,182’ 18 CI-1 CI-3 CI-3.1 CI-4 CI-2 CI-5 CI-6.2 CI-7 CI-8.2 CI-9.1 CI-10 A-3 B-6 Tubing Punch 4,528’ – 4,530’ Tagged Fill @ 5,335’ – 04/15/20 Tubing Patch ±4,515’ – ±4,535 ATubing Punch 4,635’ CIBP w/ 5’ Cmt TOC @ 4,845’3A X X CASING DETAIL Size Wt Grade Conn ID Top Btm 30” H-40 STC 28.000 Surf 386’ 16” 65 H-40 STC 15.250 Surf 623’ 10-3/4” 45.5 J-55 BTC 9.794 Surf 2,985’ 7” 26 J-55 BTC 6.276 Surf 6,455’ TUBING DETAIL 4-1/2” 12.75 J-55 EUE 8rd 3.958 Surf 4,412’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 38.9' 39' 4.500 FMC Tubing Hanger 1 291' 291' 3.813 Otis SCSSV Landing Nipple 2 4,536' 3,575' 3.937 Upper Seal Bore 4,541' 3,578' 3.937 Ratch Latch 4,545' 3,580' 3.880 Halliburton VSR Packer (Retrievable w/tubing adapter) 3 4,613' 3,619' 3.813 Halliburton X Nipple 3A ±4,850’ ±3,758’ - 3.958” 4-1/2” CIBP w/5’ cmt. TOC at 4,845’ 4 4,890' 3,782' 3.813 Locator No-Go 4,891' 3,783' 3.970 Halliburton MHR Packer (Permanent) 5 5,183' 3,961' 3.958 Otis XD Sliding Sleeve (Closed 11/12/12) 6 5,313' 4,042' 3.958 Otis XD Sliding Sleeve (Open 02/17/10) 7 5,349' 4,065' 3.937 Upper Seal Bore 5,360' 4,071' 3.937 Ratch Latch 5,361' 4,072' 3.970 Halliburton MHR Packer (Permanent) 8 5,446' 4,126' 3.813 Otis XA Sliding Sleeve (Closed)PX Plug set in sleeve 9 5,495' 4,157' 3.937 Ratch Latch 5,496' 4,158' 3.970 Halliburton MHR Packer (Permanent) 10 5,648' 4,254' 3.813 Otis XD Sliding Sleeve (Closed) 11 5,698' 4,286' 3.937 Ratch Latch 5,699' 4,287' 3.970 Halliburton MHR Packer (Permanent) 12 5,859' 4,390' 3.725 Halliburton X Nipple 13 5,892' 4,412' 3.958 Wireline Re-Entry Guide w/Pump Out Plug 14 5,978’ 4,468’ - Cement Retainer 15 6,150’ 4,582’ - Cement Plug 16 6,850’ 5,007’ - CIBP 17 7,030’ 5,113’ - Cement Plug 18 7,150’ 5,183’ - Cement Retainer MIT-IA to 1500 psi Updated By: JEK 04/16/20 PROPOSED North Cook Inlet Unit Well: NCI A-08 Last Completed: 06/17/1994 PTD: 169-063 API: 50-883-20028-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status A ±4,573’ ±4,578’ ±3,596’ ±3,599’ ±5’ Future Proposed B ±4,635’ ±4,650’ ±3,631’ ±3,640’ ±15’ Future Proposed B 4,635' 4,735' 3,631' 3,690' 100' 6/2/1994 CMT SQZD CI-1 4,979' 5,036' 3,836' 3,870' 57' 7/30/1983 Isolated CI-2 5,061' 5,161' 3,885' 3,947' 100' 7/30/1983 Isolated CI-3 5,191' 5,211' 3,965' 3,977' 20' 7/30/1983 Isolated CI-3.1 5,240' 5,250' 3,996' 4,002' 10' 7/30/1983 Isolated CI-4 5,266' 5,283' 4,012' 4,023' 17' 7/30/1983 Isolated CI-4 5,288' 5,325' 4,026' 4,049' 37' 7/30/1983 Isolated CI-5 5,388' 5,438' 4,089' 4,121' 50' 7/30/1983 Isolated CI-6.2 5,563' 5,570' 4,200' 4,204' 7' 7/30/1983 Isolated CI-7 5,580' 5,596' 4,211' 4,221' 16' 7/30/1983 Isolated CI-7 5,600' 5,624' 4,227' 4,242' 24' 7/30/1983 Isolated CI-8.2 5,743' 5,753' 4,315' 4,322' 10' 7/30/1983 Isolated CI-9.1 5,837' 5,845' 4,376' 4,381' 8' 7/30/1983 Isolated CI-10 5,855' 5,885' 4,387' 4,407' 30' 7/30/1983 Isolated A-3 6,014' 6,015' 4,492' 4,493' 1'8/3/1969 CMT SQZD B-6 6,302' 6,310' 4,679' 4,684' 8'8/3/1969 CMT SQZD E-8, E-9 7,030' 7,067' 5,113' 5,135' 37'8/4/1969 ISOLATED F-4, F-5 7,197' 7,214' 5,211' 5,221' 17'8/4/1969 ISOLATED F-6 7,218' 7,238' 5,224' 5,235' 20'8/4/1969 ISOLATED G-1 7,309' 7,326' 5,280' 5,290' 17'8/4/1969 ISOLATED G-4 7,388' 7,398' 5,330' 5,336' 10'7/30/1969 ISOLATED H-1 7,478' 7,488' 5,386' 5,392' 10'8/4/1969 ISOLATED H-3 7,513' 7,538' 5,408' 5,424' 25'8/4/1969 ISOLATED H-6 7,583' 7,598' 5,452' 5,461' 15'8/4/1969 ISOLATED I-7 7,822' 7,828' 5,601' 5,605' 6'7/27/1969 ISOLATED K-2 8,008' 8,018' 5,719' 5,725' 10'8/4/1969 ISOLATED M-2 8,180' 8,185' 5,826' 5,829' 5'8/4/1969 ISOLATED M-10 8,307' 8,314' 5,906' 5,910' 7'8/4/1969 ISOLATED N-2 8,375' 8,425' 5,949' 5,982' 50'7/24/1969 ISOLATED ii ii .ww . , ' -- _.r- • STATE OF ALASKA MAR 2 0 ZU 13 ALA OIL AND GAS CONSERVATION COMA ION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well ❑ Plug Perforations U Tubing Punch U Other U DGL installation Performed: Alter Casing ❑ Pull Tubing Stimulate - Frac ❑ Waiver ❑ Time Extension Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 169 -063 3. Address: P.O. Box 100360 Stratigraphic El Service ❑ 6. API Number: Anchorage, Alaska 99510 - 0360 50- 883 - 20028 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL37831 / ADL17589 — NCIU A - 08 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A North Cook Inlet / Tertiary System Gas Pool 11. Present Well Condition Summary: Total Depth measured 9156 feet Plugs measured 5446 feet true vertical 6494 feet Junk measured 5373 fill feet Effective Depth measured 5978 feet Packer measured 4545 feet true vertical 4484 feet true vertical 3558 feet Casing Length Size MD TVD Burst Collapse Structural 347' 30" 386' 386' Conductor 584' 16" 623' 623' SCANNED MAR 2 7 2013 Surface 2946' 10 -3/4" 2985' 2616' Intermediate n/a Production 9117' 7" 9156' 6453' Liner n/a Tubing Punch depth Measured depth 4518' - 4519' feet attempted tubing punch holes 4528', 4529', 4530' and True Vertical depth 3575' - 3578' feet attempted tubing punch holes 3585', 3586', 3587' tvd Tubing (size, grade, measured and true vertical depth) 1.900" L -80 4547' - 5325' 3560' - 4042' Packers and SSSV (type, measured and true vertical depth) WFT Wide Pak LE 4536' - 4513' and 3591' - 3568' tvd WRDP 291' and 291' tvd 12. Stimulation or cement squeeze summary: n/a Intervals treated (measured): n/a Treatment descriptions including volumes used and final pressure: Ran 778' of 1.900" dip tube placing its shoe below the bottom open perforation effectively straddling tubing punch holes above the production packer allowing lift gas to be placed below bottom pert to de -water the well. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 3 Subsequent to operation: 0 0 40 -60 822 69 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations x 16. Well Status after work: Oil ❑ 0) Gas s WDSPL ❑ WBD Post install x GSTOR LI WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 313 -036 Contact Marcus Barbee Email barbem g(a�conocoph illir s.com Printed Name Marcus Barbee Title Wells Engineer Cook Inlet Operations Signature �^ Phone 265 -6932 Date 2 Form 10 -404 Revised 10/2012 Ra L+ ,/`b g A t '� e)� ) �, � � j Submit Original Only �1Y Ph�HF / ��, • • i 02/09/13 3 DAY WEATHER HOLD, TRAVEL TO PLATFORM, REPLACE VALVES ON IA FOR DGL PREP ATTEND SUNDAY SAFETY MEETING, PJSM, SHUT DOWN FOR HIGH WINDS, 02/10/13 WINDS SLOWED, SPOT EQUIPMENT, BEGIN RU, MIX 6 %KCL, SHUTDOWN FOR NIGHT, IN PROGRESS 02/11/13 CONTINUE W /RU, ELINE, SLICK LINE, BOP STACK AND PUMP, RU SL, DRIFT /TAG FILL @ 5367' RKB, IN PROGRESS TEST BOP, KILL WELL, RUN 24 JTS 1.900" TUBING / LOWER DGL PACKER, SET 02/12/13 @ 4541' RKB MID - ELEMENT, SHUT DOWN FOR NIGHT, IN PROGRESS RU SL, SET CAT STANDING VALVE @ 4546' RKB, LOAD TUBING, TEST LOWER 02/13/13 PACKER TO 1000 PSI, RU ELINE, TUBING PUNCH @ 4530' RKB, SHUT DOWN FOR NIGHT, IN PROGRESS 02/14/13 VERIFY NO T /IA COMMUNICATION, BEGIN RU ELINE, SHUTDOWN FOR HIGH WIND, IN PROGRESS RU ELINE, ELINE DOWN WITH COMPUTER PROBLEMS, FIXED COMPUTER, PUNCH TUBING FROM 4528' - 4529', GOOD INDICATION OF SHOT, NO T /IA 02/15/13 COMUNICATION, DISCUSS W/WELLS ENG, RIH TO PUNCH TUBING FROM 4518' - 4519', GOOD INDICATION OF SHOT, CONFIRMED T /IA COMMUNICATION, RU SL, PULL CAT STANDING VALVE, PULL R PLUG, MU UPPER DGL PACKER, 02/16/13 SET @ 4511 WLM, RUN CAT STANDING VALVE, LOAD TUBING, PT UPPER DGL PACKER TO 1000 PSI, PULL CAT STANDING VALVE, INSTALL SSSV, SHUTDOWN FOR NIGHT, JOB COMPLETE 02/19/13 FLY TO PLATFORM; OFFLOAD N2 PUMP FROM BOAT; WELL A -08 IS NOW PRODUCING AND DOES NOT REQUIRE N2 PUMP; STANDBY Customer Conoco Phillips Contact Marcus Barbee, Johnson Or Contact Details Jake Bramwell / J Moseley W /ford Location Alaska - Cook Inlet Weatherford Field/ Well No. NCI A -08 Toolstring Desc. RGL System Left In Hole BHA Seq Description Asset OD ID (Inches) Weight Length Setting Number (Inches) (Lbs) (Feet) Depth 1 Top Of Upper WidePak Packer 4508 2 374 Widepak Packer WFT 3.740" 2.375" 95.2 Lbs 6.21 8 x Setting pins (96001bs) CP 450022 5 x Release Pins (6000Ibs) 3.5" VAM FJL Pin 2.875" Sealbore ID : a 3 Center Packing Element 4513 ? 1 c/w Seal Stack ■ 4 Tubing Punch 4518 -4519 5 2 -Each 9.2# Pup Joints WFT 3.530" 2.930" 179.6 Lbs 19.52 4514.21 3.5" VAM FJL Box x Pin 6 Centralift AVE Sub PCS 3.515" N/A 14.5 Lbs 0.44 4533.73 lir„: ji, 3.5" Vam FJL Box X Pin 7 WP Anchor Seal Latch WFT 3.700" 2.240" 39.8 Lbs 1.50 4534.17 3.5" VAM FJL Box c/w Seal Stack CPS i 3.67 OAL 5 x Release Pins (6000Ibs) Dual Flapper Check Valve WFT 1.688" 0.790" 3.1 Lbs 0.00 1.0" CS pin X Stub Acme Box 4535.67 a' 8 Top Of Lower WidePak Packer 4536 F 9 374 Widepak Packer WFT 3.740" 2.375" 95.2 Lbs 6.21 4541.88 "I 8 x Setting pins (9600 lbs) CP 450023 .1 5 x Release Pins (60001bs) 2.875" WTS -8 Pin I' 2.875" Sealbore ID Stinger Rod w/ DFCV WFT 1.750" 0.875" 41.6 Lbs 6.56 1" CS Pin X Guide Nose c/w Seal Stack 4541.88 I 10 Center Packing Element 4541 a 11 Slotted Sub WFT 3.215" 2.375" 10.3 Lbs 1.34 4543.22 ° 2.875" WTS -8 Box x Stub Acme Box ° 12 PBR - Seal Bore WFT 2.875" 1.750" 26.3 Lbs 0.96 4544.18 Stub Acme Pin x 2.375" WTS -8 Pin 13 Profile Nipple CoP 3.125" 1.710" 10.0 Lbs 0.96 4545.14 2 3/8 WTS -8 Box X Pin 14 Torq -Thru Quick Connect WFT 2.875" 1.375" 25.0 Lbs 1.66 4546.80 Irl 2.375" WTS -8 Box x 1.900 NU 1 Ord Pin 15 24 -JTS" Of Jointed Pipe CoP 2.115" 1.560" 2139 777.98 5324.78 1.90" NU 1ORD, 2.751b/ft WNW t t 16 2.375" Dual Flapper Assembly WFT 2.375" 0.75" 10.0 Lbs 0.78 5325.56 1.900" NU 10RD Box x Bullnose III PREPARED BY: Gary Gilliam, Aaron McDonough Weight : 2690 Lbs Length: 817.6 Ft TRADE SECRET AND CONFIDENTIAL Copyright © Weatherford Inc. 2012 116' rkb • 0 North Cook Inlet Unit WeII: Tyonek A -08 j, 'j'P PTD: 169 -063 4 API: 50- 283 - 20028 -00 30 "386' 4 � ' ADL: 37831 16" 65# ; . Leg 3 Slot 2 H -40 @ 623 1 I � ► , v 7 " � i 0 06- 18- 94 10 -3/4" 45.5 & 51# = CBL TOC 3010' � DGL W B D J -55 2985' ' 1 1 �'" :•no:: . . : '.Td�.- . . . . . t3 . .... . .. vY.F . _ _ .... . ,f� :' ;: �::c -: ,d� .. . .. .. . . .: ,sttst :: :... .. ro,t ...,:. T•eiu€i::;: ,- 4 54 5 .: _ 30' 41' 366' `� t 16 ' 41 623 65# H -40 ST &C 1540 600 293 10 3/4 " 41' 2985' 45.58 & 51# J -55 BT &C 3350 1970 531 ,, �� 9156' 23# & 26# J -55 BT &C 4080 3080 288 a;. "- p c ,, 41/2" 39' 325' 12.60# J -55 Mod BT &C 4730 4980 135 4, 407 -' _ 4 1/2 " 325 5893' 12.75# J -55 Mod 8rd 4730 4980 134 "' 1�. :koa :- .....ri+ath..- _..,.- ,.,..,...biaddoait :: 1i: iti 1 0.00 #1 0.00 38.90 Elevation 1 . _ 38.90 0.67 FMC / OCT 6" 3M 4 1/2" 8rd x 4 1/2" Mod BT &C Tubing Hanger y" yi 39.57 251.21 4 1/2 " 12.60 lb/ft L -80 Mod BT &C Tubing 3.958 5.563 -- 290.78 2.51 Otis 4 1/2" SCSSV Landing Nipple - reset SCSSV 9/10/02 3.813 5.566 _ 293.29 31.56 4 1/2 " 12.60 lb/ft L -80 Mod BT &C Tubing 3.958 5.562 Fill 5373' - 324.85 0.74 X -Over 41/2" BT &C x 4 1/2" EUE 8rd Mod 3.958 4.910 ; ,# * . it 325.59 4210.63 4 1/2 " 12.75 lb/ft J -55 EUE Mod 8rd Tubing 3.958 5.563 Px Plug 5455' 4508.006.21' Upper DGL Packer (WFT wide Pack) 2.375 3.740 `; #, 4518 4519.00 1 tubing punch holes .33 hole x 4 (see attachment for more detail) 0.330 times 4 5485 4535.67' 27.67' pup joints and internal kit 3.500 „� . - `, 4535.67 6.21 lower DGL Packer (WFT Wide pack) 2.375 3.740 NMI p 4541.88 1.34 slotted sub 2.375 3.215" 1 A 4543.22 0.96 PBR 1.750 3.215 < - 111 �: 4544.18 096R Nipple' 1.710 3.125 " kit* 4545.14 1.66 quick connect 1.330 2.875 t„",4s, 5697 4546.80 777.981.900" dip tube 2.76#/ft L -80 10 rd IJ BxP 1.560 2.200 a = i° a 4536.22 8.91 Upper Seal Bore 3.937 5.960 le MESE 3 4116. 4545.13 0.35 Ratch -Latch Locator 3.937 5.051 -! -+ 4545.48 7.28 Halliburton "VSR" retr. packer with tbg. adapter. 3.880 5.91 4552.76 60.07 4 1/2 " 12.75 lb/ft J -55 EUE Mod 8rd Tubing 3.958 5.563 �p . :" > a r . ,,. 4612.83 1.55 Halliburton "X" Profile 3.813 4.75C �w 4614.38 275.72 4 1/2 " 12.75 lb/ft J -55 EUE Mod 8rd Tubing 3.958 5.563 t G= S ' 4890.10 1.15 N o -Go Locator 3.813 4.50C � a 4891.25 1223 Halliburton "MHR" permanent packer 3.97 5.875 , .=� _ - 4903.48 279.88 4 1/2 " 12.75 lb/ft Tubing and Blast Joints 3.958 5.57C j ' . „ ' "• a -# 5183.36 4.70 Otis 4 1/2" "XD" Sliding Sleeve CLOSED 3.813 5.57C 5188.06 125.26 4 1/2 " 12.75 lb/ft Tubing and Blast Joints 3.958 5170 _ -_ 5313.32 4.71 Otis 4 1/2" "XD" Sliding Sleeve CLOSED 3.813 5.57C p '+ < S 5318.03 31.31 4 1/2 " 1275 lb/ft J -55 EUE Mod 8rd Tubing 3.958 5.563 " E161 1 11 5325.00 0.78 dip tube dual flapper check shoe 78 / 0 2.375 " 5349.34 10.84 UpperSeal Bore 3.937 5.96£ 5360.18 0.55 Ratch -Latch Locator 3.937 5.051 [ v i 7 ,i ' ' 536073 12.31 Halliburton "MHR" permanent packer 3.97 5.870 G 4 1 ^ 5373.04 72.65 4 1/2 " 12.75 lb /ft Tubing and Blast Joints 3.958 5.57C "' - 5445.69 4.17 Otis 4 1/2" "XA" Sliding Sleeve CLOSED 3.813 5.57C 1 r a„ 5449.86 31.24 4 1/2 " 12.75 lb/ft J -55 EUE Mod 8rd Tubing 3.958 5.563 Parted Casing 5481.10 14.18 Tubing Seal Divider 3.958 5.960 @ 7182' , - `"' °, 5495.28 1.15 Ratch -Latch Locator 3.937 5.051 " C �y .. 5496.43 12.34 Halliburton "MHR" permanent packer 3.97 5.875 iF • " ' J O S :cmt 550877 13911 4 1/2" 12.75 lb/ft J -55 EUE Mod 8rd Tubing 3.958 5.563 �`ii 5648.28 4.22 Otis 4 1/2" "XD" Sliding Sleeve CLOSED 3.813 5.57C 4; r'' ,' 5652.50 31.26 4 1/2 " 12.75 lb/ft J -55 EUE Mod 8rd Tubing 3.958 5.563 1' 5683.76 14.18 Tubing Seal Divider 3.958 5.966 * 5697.94 1.15 Ratch -Latch Locator 3.937 5.051 0C 0 .' 5699.09 12.34 Halliburton "MHR" permanent packer 3.97 5.875 e� .1 5711.43 148.03 4 1/2 " 12.75 lb/ft J -55 EUE Mod 8rd Tubing 3.958 5.563 a 4 5859.46 1.61 Halliburton 4 1/2" "XN" Nipple 3.725 4.50C tie` C ` 5861.07 31.3 4 1/2 " 12.75 lb/ft J -55 EUE Mod 8rd Tubing 3.958 5.563 qtr +\ _ , i f 9103' PBTD 5892.37 0.61 Re -Entry Guide with Pump Out Plug 3.958 5.57C 4 p""'< �� • '� 5892.98 End of Tubing 4 4 , , - t ` f 7" 9156' 6494'tvd 116' rkb • 0 I Ai fl 1. a ' 2 I I': 3. ►. 1 1. Upper DGL Packer (Wft Wide Pack LE) 8 2. 3 -1/2" spacer pipe 5. 6. 3. AVE Sub 697....1.,':1,:—.'' 4 . 10. = 11. - 45 - 4. Anchor Latch Seal Assembly 12 5. 1" spacer pipe 6. PBR Seal Assembly - - 7. Lower DGL Packer (Wft Wide Pack LE) 8. Ported Sub i; 9. PBR x 1.75" 10. 'R' Nipple Profile 1.71" 11. Wft Quick connect 12. 1.900" IJ 10rd 2.76 # /' jointed Pipe 13. ' 13. Dual Float Shoe 5361' Fi115373' Px Plug 5455' I ! - 1 .11 M IF lif I a • SAK NCI A -08 COnOcoPhillips Well Attributes • Max Angle & MD TD AkaSka, Inc . Wellbore APIIUWI Field Name Well Status Incl ( °) MD (ftKB) Act Btm (ftKB) ps 508832002800 ,COOK INLET PROD 55.75 4168.01 9,222.0 ° Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date ..° we9conrw: - NCI A - 0s, 3/14/2013 iri.15 t., SSSV: NIPPLE Last WO: 6/17/1994 _ _ 8/12/1969 :.Schematic - Act.[ 'Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date - _ .1 Last Tag: RKB 5,342.0 7/14/2011 Rev Reason: Add Attachment, Set Packer Assy. haggea 3/11/2013 HANGER, 39 - -° - NIPPLE, 291 \ Casing Strings WRDP, 291 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR, - CONDUCTOR 30 28.000 39.0 386.0 386.0 H - 40 STC 39 I Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR, CONDUCTOR 16 15.250 39.0 623.0 623.0 65.00 H STC 39-623 --- -, SURFACE, E. String Casing Description Strin 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 39 - 2,985 SURFACE 103/4 9.794 39.0 2,985.0 2,620.5 45.50 J - 55 BTC PACKER, 4,508 - Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd .m PUNCHES, IPI PROD UCTION Tubing Strings 7 6.276 39.0 9,156.0 6,455.8 26.00 J -55 BTC 4,518 SEAL, 4,534 Tubing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SEAL BORE, \ 4,536 lIl. TUBING 41/2 1958 38.9 5,893.0 4,412.4 12.75 J -55 EUE -8rd PACKER,4,538 Completion Details ffii: ■1 Top Depth STIN 4,544 - 0 2 (TVD) Topincl Nomi... PACKER, 4,545 I ' Top (ftKB) (RKB) (°) Item Description Comment ID (in) (1 '• 4 38.9 38.9 0.00 HANGER FMC TUBING HANGER 4.500 PBR, 4,552- �:, NIPPLE, 4,553- j CONNECT, 290.8 290.8 0.00 NIPPLE OTIS SCSSV LANDING NIPPLE 3.813 4,554 4,536.2 3,575.2 55.25 SEAL BORE UPPER SEAL BORE 3.937 NIPPLE, 4,613 4,545.1 3,580.2 55.19 RATCH LATCH 3.937 CMT 502, 4,835.4,735 - - r' 'I 4,545.5 3,580.4 55.19 PACKER HALLIBURTON VSR PACKER (retrievable w /tubing adapter) 3.880 LOCATOR, 890 4,612.8 3,618.6 54.74 NIPPLE HALLIBURTON X NIPPLE 3.813 PACKER, 4,891 4,890.1 3,783.5 53.64 LOCATOR LOCATOR no go 3.813 4,9795036 - + ` 4,891.3 3,784.2 53.63 PACKER IHALLIBURTON MHR PACKER (permanent) 3.970 APERF, 7 ! - 5,0815,161 4,903.5 3,791.3 53.55 BLAST JTS 3.958 SLEEVE - C, 1 5,183.4 3,960.7 51.63 SLEEVE -C OTIS XD SLIDING SLEEVE (CLOSED 11/12/2012) 3.958 5,183 APERF, e 5,188.1 3,963.6 51.60 BLAST JTS 3.958 5.191 APER F, (OPEN 2/17/2010) 5 4,041.8 50.83 SLEEVE OTIS XD SLIDING SLEEVE OPEN 2/17 /2010 3.958 APERF, 5,240 5,349.3 4,064.6 50.79 SEAL BORE (UPPER SEAL BORE 3.937 APERF, 5.266 5,360.2 4,071.4 50.78 RATCH LATCH 3.937 APERF, LEEV SLEEVE - O, .O, il� rmanent - -- 5 4,071.7 50.77 PACKER HALLIBURTON MHR PACKER 3.970 S ) 5,313 1 5,373.0 4,079.5 50.76 BLAST JTS 3.958 FLAPPER, I 5,445.7 4,125.6 50.68 SLEEVE -C OTIS XA SLIDING SLEEVE (Closed) 1813 5,334 SEAL BORE, ] - +I 5,495.3 4,157.1 50.62 RATCH LATCH 3.937 5,349 5,496.4 4,157.8 50.62 PACKER HALLIBURTON MHR PACKER (permanent) 3.970 PACKER, 5,361 - APERF, 5,648.3 4,256.6 51.07 SLEEVE -C OTIS XD SLIDING SLEEVE (Closed) 3.813 IF 5,3885,438 I 1 - SLEEVE - C, 5,697.9 4,287.1 50.67 RATCH LATCH 3.937 PLUG, 5,446 5,699.1 4,287.9 50.66 PACKER HALLIBURTON MHR PACKER (permanent) 3.970 I I 5,859.5 4,390.3 49.38 NIPPLE HALLIBURTON XN NIPPLE 3.725 PACKER, 5,496 5,892.4 4,412.0 49.11 WLEG WIRELINE RE -ENTRY GUIDE w/Pump Out Plug 3.958 APERF, � Tubing Description String 0... String ID ...Top (RKB) Set Depth (f Set Depth (TVD) .. String Wt . St g String Top Thrd 5,563 - 5,570 t RGL Packer Assy 2.115 I 1.560 I 4,508.0 I 5,334.3 4,055.1 2,139.40 � 5,58006 5 6-f Completion Details °`Gr v ; ,$',:, , n, APERF, Top Depth 5,6005,624 (TVD) Top Inc] Noml... SLEEVE -C, Top (ftKB) (RKB) ( °) Rem Descr Comment ID (In) 5,648 _ - - - -- _ 4,508.0 3,559.5 55.44 PACKER 374 WIDEPAK PACKER 2.375 RATCH _ MI 4,534.2 3,574.1 55.26 SEAL WP ANCHOR SEAL LATCH 2.340 LATCH, 5,698 '_< ∎' 1 PACKER, 5,699 r 4,537.9 3,576.1 55.24 PACKER 274 WIDEPAK PACKER 2.375 APERF, - _. 4,544.1 3,579.6 55.19 STINGER STINGER ROD W /DFCV 0.875 5,7435,753 5,83 - ERF, 4,552.0 3,584.0 55.14 PBR PBR SEAL BORE 1.750 5,845 - 4,552.9 3,584.6 55.14 NIPPLE PROFILE NIPPLE - NIPPLE, 5,859 4,553.9 3,585.1 55.13 CONNECT TORQ -THRU QUICK CONNECT 1.375 APERF, 5,8555,885 1 V . :T.; 5,333.5 4,054.6 50.81 FLAPPER 2.375 DUAL FLAPPER ASSY WLEG, 5,892 ' Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) RETAINER, Top Depth 5.978 (TVD) Top Inc1 Cement Beluga Top (RKB) (ftKB) (°) Description Comment Run Date ID (in) Zone. 5,948 I 290.8 290.8 0.00 WRDP HES FX WRDP 3/28/2010 2.250 CMT SO2, 6,0145,015 4,518.0 3,565.0 55.37 PUNCHES TUBING PUNCH 2/16/2013 CMT SO2, _ 5,445.7 4,125.6 50.68 PLUG PX PLUG SET IN SLEEVE 2/6/2010 0.000 6 CMTau9 5,978.0 4,468.3 48.43 RETAINER CEMENT RETAINER 6/7 /1994 6,150 MI PLUG, 8,850 6,850.0 5,007.0 54.00 PLUG CAST IRON BRIDGE PLUG SET, BLOCKS OFF BELUGA 8/2/1983 0.000 IPERF, IM PERFS 6902-8425' 7,030 - 7,0671 RETAINER, 7,150.0 5,1815 54.23 RETAINER CEMENT RETAINER SET AFTER INDICATIONS OF 7" 6/16/1983 7,150 CSG PARTING BELOW 7182 IPERF, r 7,197 - 7,214 Cement Plug, 7,030 IPERF, 7,218 -7,238 IPERF, 7,309 -7,326 IPERF, 7,388 -7,398 IPERF, 7,478 -7,488 IPERF, 7,513 -7,538 IPERF, - 7,583 -7,598 IPERF, 7,822 -7,828 IPERF, - 8,008 -8,018 IPERF, 8,180 -8,185 IPERF, 8,307-8,314 N IPERF, \ 8,375$425 \ PRODUCTION, _ 39 -9,156 TD, 9,222 i 17 MAR, ,D, - 2.013 WELL LOG TRANSMITTAL �"°� A %j' y0 To: Alaska Oil and Gas Conservation Comm. February 26, 2013 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 �Zi2 Anchorage, Alaska 99501 RE: Deep Gas Lift Hoist/ Packer Setting Record/ Perforation Record: NCIA-08 Run Date: 2/12/2013 - 2/15/2013 The technical data listed below is being submitted herewith. Please address any problems or concerts to the attention of. Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 NCIA-08 Digital Dat AS), Digital Log file 5 -$ 3-20028-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: NNS Signed: • OF T • 4 ,4) . 1//7 11 , m THE STATE• Aiaska 011 and as F'� P � , f CG£�FtservationL t1 I�issL 1 Witt Th GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Marcus Barbee Wells Engineer 167- b ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 Re: North Cook Inlet Field, Tertiary System Gas Pool, NCIU A -08 Sundry Number: 313 -036 Dear Mr. Barbee: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this S day of February, 2013. Encl. SCANNED l4AR 14 2013 • * RECEIVED STATE OF ALASKA � JAN 2 5 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Deep Gas Lift Installatio 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number ConocoPhillips Alaska, Inc. Exploratory ❑ Development MI - 169 -063 • 3. Address: P.O. Box 100360 Stratigraphic ❑ Service ❑ 6. API Number. ?fib Anchorage, Alaska 99510 -0360 50 -283- 20028 -00-00 I P - 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No NCIU A -08 9. Property Designation (Lease Number): ?I0 Lu13 10. Field /Pool(s): _ ?V- at•b 1/, / S North /(tI7 A s G- Al � - � � 8y c ADL 37831 ort Beluga. r � �'t 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9156' 6494' • 5978' retainer 4484' • 5446' Px plug • 5373' fill Casing Length Size MD TVD Burst Collapse Structural 347' 30" 386' 386' Conductor 584' 16" 623' 623' Surface 2946' 10 -3/4" 2985' 2616' Intermediate n/a Production 9117' 7" 9156' 6453' Liner n/a Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): . 4979' - 8425' - 3828' - 5852' 4-1/2" L -80 5893' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program • 0 BOP Sketch El , Exploratory ❑ Stratigraphic ❑ Development 0 • Service Q 14. Estimated Date for 2/12/2013 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas 1151 • WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Marcus Barbee Email barbemg@conocoohillios.com Printed Name Marcus Barbee Title Wells Engineer Signature / ' Ph ne — �� z Date 1/22/2013 4 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBI v6, FEB 06 2013 ek Spacing Exception Required? Yes ❑ No Subsequent Form Required: ! c, ,., y01.1 APPROVED BY / Approved by: / � `� ' COMMISSIONER THE COMMISSION Date: _ S te- [3 r 6 Submit Form and o oRte iNo /A2L Approved application is valid for 12 months from he date of approval. / I - 6 cln, , p N + I • • Tyonek Well A -08 Deep Gas Lift Installation Pre - Installation well work 1 Close in the well at the wing valve 2 Pull the SCSSSV 3 Tag bottom 4 Clean out the production tubing below Sliding sleeve © 5313' and leave +- 75' of ratt hole 5 Drift the production tubing with a Deep Gas Lift Packer Drift below the production packer © 4575' 6 Pressure test the Inner Annulus to 1000 psi Leave the well shut in until Deep Gas Lift can be installed Deep Gas Lift Installation Procedure 1 Mobilize Slick -Line E -Line Mud hands, Roustabouts, Crane aerator, Banksman, Down hole •um• and crew to the Tyonek Platform. Perform platform orientation upon arrival, hold SIMOPS meeting with operations when checked in 2 Mix 780 Bbls of 6% KCL in the pits while laying pump side hard line 3 Flange up the 7" wireline valves with 1.900" inserts to the well head of A -08 4 Pick up the shoe tract and lower it into the Wireline valve and close same on the 1.900" tubing. 5 Fluid pack and pressure test the pump side hard line 250 psi low and 4000 psi high. 6 Test the wire line valve 250 psi low and 3000 psi high 7 Bleed test pressure to zero, lay down test joint and cap the Wire -Line valve 8 Line up the down hole pump to bull head and come on line pumping 1 -1/2 wellbore volumes prior to shut down 9 Lay out the 1.900" tubing and strap same with a steel tape measure, generate a pipe talley and give to the company man 10 Isolate pump and monitor well for 30 minutes to establish a leak off rate 11 Come online and catch fluid, measure the volume required to catch fluid and record same in job log. SD pump and secure same 12 Repeat step 11 and verify the leak rate after an additional 30 minutes have passed 13 Rig up the handling equipment for the 1.900" tubing, bowls, slips, elevators, TIW valve, crummies etc. 14 Pick up the shoe tract and lower it into the well and set the hand slips on same 15 Continue picking up 1.900" tubing until all 24 joints have been picked up and run in the hole 16 Install the lower portion of the Weatherford quick connect to the box end of the 1.900" tubing looking 38 " 17 Pick up the Wire -Line lubricator with standard 1- 11/16" tool string with Gamma Ray & CCL N eg-At - �=��" `� p 9 Y —! 18 MU the DPU and setting tool to the Wire -Line tool string, MU the Wide pack packer to the setting adaptor 2.00 les 1- 19 MU the ported sub, PBR, 1.71" 'R' Nipple profile with 'Rx' plug installed and upper portion of the Weatherford quick connect �� 20 MU the upper quick connect to the lower quick connect and tighten with pipe wrenches 21 Pick up the entire BHA with the wire -line hoist / drum, remove the slips and bowl and stab lubricator & wire line valve on the well head 22 Close the rams on the 1.900" tubing and pressure test the lubricator 250 psi low 1000 psi high 23 Bleed test pressure to zero, open the tubing rams and run in the hole logging the packer on depth 24 Set the packer with the center of the element exactly 5' above the bottom of the first full joint above the PBR 25 POOH & BO & LD the DPU and packer setting adaptor / Rig back Wire - line 26 Rig up Slick - Line with a standard 1 -3/4" tool string 27 PU &MU Weatherford packer test tool, RIH & stop + -5' above the lower wide pack packer 28 Line up the down hole pump to bull head and come on line until fluid is caught / shut down the pump 29 Set the packer test tool inside the lower wide pack packer and pressure test the assembly to 250 psi low & 1000 psi high 30 Bleed test pressure to zero, shear off the test tool and pull it out of the hole. BO &LD the test tool when complete " 31 Rig back slick line and rig up E - Line 32 PU &MU a tubing punch qun for 4 -1/2" tubing with (2) two 1/2" jet holes to the Wire -Line tool string 33 Ensure the inner annulus has a minimum of 100 psi on the surface prior to firing the tubing punch gun • 34 RIH & tubing punch the production tubing exactly 5' above the top of the Wide Pack packer / POOH when complete 35 Rig back E - Line and rig up slick - line 36 PU & MU standard 1 -3/4" tool string with GS and watermellon prong to equalize and pull a 1.71 " 'Rx' Plug 37 RIH and recover the 1.71" 'Rx' Plug inside the lower DGL dip tube, POOH when complete 38 BO &LD the 'Rx' plug, PU & MU the upper DGL packer assembly consisting of HES DPU, setting tool, setting adaptor, Wft wide pack packer LE, 3 -1/2" spacer pipe, AVE sub, Anchor Latch Seal Assembly, spacer pipe, PBR seal assembly. Zero the counter with the PBR @ the tubing hanger 39 RIH with the upper DGL assembly, set the same in the top of the lower DGL assembly previously set in the hole Verify the upper assembly is latched to the lower with a 1500# straight pull bind on the anchor latch seal assembly 40 Set the full weight of the upper assmbly on the lower and allow the DPU to fire. POOH when complete 41 BO & LD the HES DPU. PU & MU the Wft packer test tool. RIH to +- 5' above the upper DGL packer assembly. 42 Line up the down hole pump and come on line at maximum rate until fluid is caught. Shut down the pump. 43 Set the packer test tool inside the upper DGL packer and pressure test the production tubing to 250 psi low & 1000 psi high 44 Bleed test pressure to zero, pull the test tool OOH 45 BO & LD the packer test tool. PU & MU SCSSSV 46 RIH & set the SCSSSV as per SOP. POOH when complete. Perform function test on SSSV, continue procedure when valve passes test. 47 Rig down from A -08 and return the well to production 48 Walk through the well bay room with the production operators and ensure they are happy with the way we are returning the well to them. Production to bring the well on line as per instructions from Matt Ortwein • • la IICOM: - NCIA-03, V220131'1114 P13 9ClematlC- Actual 11.114.157', tit41s 1 I141LL! LLL}1LLLd,911 4 E y ititt _t_1..,ti 1 r i e "J1't11 tlrW111 nl NIPPLE,Z31 WROP,Z11 BERET CONOUCTOR,39•335 CONDUCTOR, 33F23 SURFACE, 2936 SEAL PORE, 4536 PAC NEE, 4545 c� NIPPLE, 4513 CIJTSOZ,4,635-4,735 `' LOCATOR ,4E I PACKER, 4591 APERF, 197961336 P j APERF,5p615,161 SLEEVE-C,5,133 APERF,5,1915211 APERF,524662a13 AP ER F,50355763 AP ERF,52 -5325 SLEEVE-0,5313 SEAL tO RE,5549 PAC KEN ,5,351 I ..:...a. - APERF,S,X-5,133 SLEEVE-C,5,116 PLUG,5,446 C S[ PAC 4E11.5.496 -. AP ERF,55635570 APERF,5 -5,935 AP ER F, SEEC5A24 SLEEVE-0,5518 RATCH IATCH,5598 PACNER,5 xe - AP ERF,5,7136,753 AP ERF,5E13155E5 • NIP P LE, 5,899 '*�® APERF,6 5-5,8 E REFAINER,5878 Ceme It Es NgaCo Ie,59N1 CNT SIDE, 65145p15 Vlf J✓A CLITScZ,6X12 -6,310 EDI 4V GRIT P115,6,150 eP .W. IPERF,7 -7p61 REFAIN ER, 7, 1511 IP ERF,7,197- 7 211, Ceme It 115, 1555 IP ERF,7218 -1233 IP ERF,7 -7,'26 IP ERF,1 IP ERF,7,418 -7,88 IP ER F ,1 A137 pa IP ER F,7 ,91}7558 IP ERF,7 X22 -7,8L IP ERF,811738p18 IP ERF,8,1EC5,156 IP ER F,E,III5 IP ERF,8,3158A PRO UCTC N, 39-9,156 TD, 9222 -~� • • 116' rkb North Cook Inlet Unit :; Well: Tyonek A -08 �� PT�:169 -063 API 50-283-20028-00 le 30"386' ADL: t 8 16 "65# Leg 3 Slot 2 R R H-40 @ 623 � . 06 -18 -94 10J4 ' 45,5 & 51# CBL TOC 3010' J- 55298S' current WBa tie Gas Producer FMC OCT RKB -Dri8 Deck. , , 14,,,, Single 6" 3M 4 112 " 9rd X 4112 RKB-THF. Comm. FMC OTC 40.77 39,4 nt RKB-SL Annulus Fluid 70/30 Methanol / 2% KCI Completion Fluid X100 115 ;P. TOC 301 0 S am CBL dated 07123169 WATERDEPTH 120 .y RKB L ; ,3 :z . -0ii s1: f '... � iai k. ...r.;; Grit% ..: }.::.< 8� $ #:.... ,r a M $1;,,irt4 "1 se e .it G & tN ' ".i t f.,, 7 Ii B IN s 0 30" 41' 386' " 16 " ST &C 1540 600 29 10 314 a1' 41` 9 623 85 45.5# &511 J5 BT &C 3350 197 III 7" 3Y 9156 23# &65# 264 Hd0 J -55 BT &C 4080 3080 288 fill 5373' 41/2 39 25 12 604 J 65 MO4 BT &G 4730 44369500888000 980 135 4112 325 5893 12 754 J 55 Mod 8rd 4730 4980 134 Px Plug 5455' ' i X 180:.;: ;,..:..: =1i '- �?w -. 911..: ies .ter 0 0.00 38.90 Elevation ; 4 FMCtOCT anger 6" 3M4 1t2 "8rd x41!2 MddBT &G Tubing 38.90 0.67 t 290.78 251.2" 88M&tting 3.591, .56 ' 3 3957 !M L' 3 24.8_ 0 51 1 0ti6 12 SCSSVL Ib/ft 1- 88 and 'snQNip(be resetSGSSV9110f02 3.8 5 293.25 31.56 d 1t2 " 12.601tdR L -80 Mad BT &C Tutting 1 3.958 5 563' 74XOer 4112 BT &Cxd112 EUE 8rd Mod 3.958 4.915 i " tl " 325.65 4210.63 4 1/2 ' .75 ft J-55 EUE Mod 8rd Tubing 3.9 5.3 4536.22 8.91 Upper Seat 12 Bore lb/ ng 3.837 55 5.86 t 4545.13 0.35 Ratch -Latch Locator 3.937 5.051 4545.40 7.28 Ha0iburton VSR "retr, packer ovfhtbg. 3.880 5.91 � = adapter. 4552.7E 60.07 4 .75 0rdt EUE Mod Ord Tubing 3. 5 4612.8_ 1.55 Hal liburton 12 X Profile J-65 3.6 13 4:756 563 8 am" 4614,38 275.72 4112" 12.76) ft J-55 EUE Mad 8rd Tubing 3.958 5.563 4890.10 1.15 No -Go Locator 3.813 4500 � 4891.25 12.23 Hai66udon MHR permanent packet 3.97 5.875 �- 4903.48 279.88 d 112 " 12.751ts4k Tubrnq snd Bla Joints 3.958 5.570 "'"` 618 4 Oti 41/2" "XD' Sliding Sleeve CLOSED ' 5188.06 125.26 b 112" 12.75 tTubi 3.958 3.813 5.570 65 ?C 5313.32 4.71 Otis 41/2"Z Sling Sl CLOSED 3.813 958 5.5573 0 5318.03 31.31 d 112 " 12.76 lbtft J -56 EUE Mod 8rd Tutting 3..56 5349.34 1484 Upper Ratch Seat atch BoreLocaor 3.937 5.966 + ui' 5360.18 055 Lt 3.937 5.051 5 360.73 12.31 Halliburton "MHR "`permanent packer 3.97 5.876 5373.04 72 . 65 4112 "' 1275 #WRTu�ngarnl BlastJOints 3 3958 5.670 Parted Casing . ., ao t 544 42.17 Otis 412" "XA" Sliding Sleeve CLOSED 3.813 5. 7182' 544486 31.24 4112" 12.76 Mt J 55 EUE Mod 8 d Tubing 3.958 5.56 , ''', e , t ' ` ° �., ` , 5481.10 14.18 Tubing Seal Divider 3 958 5.966 a 5495.28 1 Ralph-Latch an locator N 3.937 5 051' $ 5496.43 12.34 tirt 7vtR pe rmanent packer 3.97 S87 E' ` 5508 77 139.51 d 1/2 " 12 Wit -55 EUE Mod 8rd ng 3.958, 5 563. w 564828 422 Otis 4172" "XD " Shd ma Sleeve CLOSED 3.813 5 570 o 5652.50 31.26 b 112 ° 1275lb/ft J•55 EUMad 8 d Tub Tubing 3. 958 958 5 5.964 563 �� 5683.769 14.18 Tubing Seal Divider 3. 6697.94 1.15 Ratch Latch Locator 3.937 5.051 K 5699.09 12.34 Ha litw ton' MHR" permanent packer 3.97 5.87E �P 9103" PBTD 5711.43 148 4 .75 itrlft J -55 EUE Mod 8rd Tubing 3.966 5.563' r '),...,,N 5859,46 1.61 rtan4112 " ° ! "Nipple 3.725 4.500 + �`� b r �r 5861,07 31.34112" 12.76 J -55 EUE ModBrdTutrinq 3.958 5.56'_ � 5892.37 0.61 Ra -Entry Guide 1b1ft with h Pump Out Plug 3.958 5,570 t � ' 6892.98 End olTubing ' 7" 9156' 6494'tvd • 116' rkb L. 46' +OF r.re . 11r1 '14 tc4 1. t-c4.5.! 4- 2 p 4,1 3. 6. . 4 - 4 ' 7 1. Upper DGL Packer (Wft Wide Pack LE) - 5. 8. - 2. 3-1/2" spacer pipe 9. i I 6. 3. AVE Sub 10 .1. 11 4545, 4. Anchor Latch Seal Assembly 5. 1" spacer pipe 12. 6. PBR Seal Assembly 4891' 7. Lower DGL Packer (Wft Wide Pack LE) 8. Ported Sub !-N 9. PBR x 1.75" 10. 'R' Nipple Profile 1.71" 11. Wft Quick connect 12. 1.900" Ii lOrd 2.76#/' jointed Pipe P-44 13. Dual Float Shoe 13. . . 5361 Fill 5373' Px Plug 5455' = - .- 509 NW*1 f • • SPECIFICATIONS AND REPLACEMENT PARTS BOWEN SNUBBING BLOWOUT PREVENTERS 1 RAM TYPE BLOWOUT PREVENTERS - CLOSING /OPENING VOLUMES 6 PRESSURES GALLONS GALLONS ASSEMBLY B.O.P. WORKING VERTICAL HYD. PRESS. I TO TO CLOSE NO. SIZE PRESSURE BORE FOR OPERATION CLOSE OPEN RATIO INCHES INCHES PSI I (PER SET OF RAMS) (PER SET OF RAMS) 79289 2y,. Single 20,000 2y,, 1,200 I' .65 .78 j 22.7:1 79926 3'%, Single 20,000 3y,. 1,250 .69 .74 16.2:1 78684 4'4. Single 15,000 4'4. 1,250 .69 .74 16.2:1 I i • f f 81296 4y,. Single 20,000 4%, 1,250 69 .74 16.2:1 Keyless 79288 4%, Twin 15,000 4'J. 1,250 .69 .74 16 2 63642 74 „ Single 10,000 7y,. 900 1.02 1.10 16.2:1 79466 7' /,, Twin 10,000 7y,. 900 1.02 i 1.10 16.2:1 • i RAM ASSEMBLY Size Me” 3%," 4 ' /n" 4%," Keyless 7 %e " COMPLETE RAM ASSEMBLY Part No. 74542 77692 77692 146469 63643 1, Weight 14 34 110 3 Consists of BODY Part No. 74202 80875 80875 146312 63644 Weight 13 30 30 1 OUTER SEAL Part No. � 81073 43603 43603 43603 66409 Weight F INNER SEAL Part No. 74182 77729 77729 77729 66408 Weight I r INNER SEAL RETAINING SCREW Part No. 74184 77691 77691 77691 64227 Weight % 4 % 1 Oz Part No 50476 61654 79550 61654 RAM KEY Weight 'L '4 '4 RAM KEY SCREW Part No ... 64219 22830 22830 62887 Weight 1 Oz. 1 Oz. 1 Oz. .... 1 Oz i ,.. 4 ,.; ,, -23- A I. B p C • I 0 • 1.7 dli M 4 4 ir r :. : „. `�� _. : I_) Z : 1 1 r 4,-,, 11 . r II % r . y 9197 Y i NIMIIIN 41 .I. 1 iiipw., 50.12 4 iv 50.31 4-W- -5000 PSI A.■V X -MAS TREE 3 �� 3 1 12 fill Hai I _ 15000 PSI � � -- .1 ..1.50 NN FLANGE i E ui o u1 IIII 2 -1r -5000 PSI 15100 2218 i GATE VALVE MI r 1 1� i 3502 immo`i i '' I 1 q -11 -5000 PS API FLO Nei 4 e 1.. '� 2- i}��-5000 PSI 2598 - 1. 1 : ' Q i GATE VALVE 1 1' -5000 PSI MODIFIED FLANGE 2 2 Li '� fin V G -SEAL � I�11• ASING NCR, 18.19'09 -5/8' 1512 ,II IL 4- 4'- 12PPF- L80 28.93 OY- 28PPF -L80 '.. )1111 riuu 11.81 -L800 SURFACE CASING WICK DISCONNECT 23 -5/8 X 20.00 28 BUTT WELD A:I>LIi I ' 4' LP OUTLETS 11.00 I I/ WELL FLOOR I — 028.00 - 0.50 WALL CONDUCTOR _ ■ — I_•2i100 I M00095 vetcogray s �' ASSEMBLY /SWE SPLIT MULTIBOWL SYSTEM, FOR CONOCO PHILIPS, TYONEK PLATFORM w B. w M li 4G FAGH 28` X 9 -5/8 X 7 X 4 -1/2 1 THIS IS A GENERIC Hp HE RIC MBEWING. HE CM 4 - 1/16 - 5M, X -MASS TREE REFER TO DASH SH NUMBERED PARTS - SHOWING MULTIBOWL & X -MASS TREE NOTES: UST FOR ADDITIONAL INFORMATION. R 08 APWL 2008 pp a D I2a7 CEN08 -075 INC P oo NOT ewt ortAW I9 212000 -0741 '*.G. Os) NA I s. 1. 7 PRINT SCALE: 1 =8 A I B n C I D A A I• B v C Si 0 4 4 DRILLING ADAPTER 21 -1/4 -2000 QD BOTTOM 1 d :\\1 , 18.41 21.35 �__ _ QUICK DISCONNECT - -; 23 -5/8 X 20.00 81 / I TS mm � �� 28 BUTT WELD 3 3 < �- -BUTT WELD +, 4 4 1 \ 1 / \ ish\ , - 017.62 ID 11.00 / 4" LP OUTLETS C WELL FLOOR ---- 028.00 -0.50 WALL CONDUCTOR 028.00 2 2 1 1 voas vetcogray° ASSEMBLY /SWE SPLIT MULTIBOWL SYSTEM, FOR CONOCO PHILIPS, TYONEK PLATFORM V. 1OVAFFA08 ARRANGEMENT SHOWING C. WO''' Q.D. DRILLING ADAPTER 1 THIS IS A GENERIC DRAWING. M °He Y NOTES: REFER TO DASH NUMBERED PARTS UST FOR ADDITIONAL INFORMATION. P O8 APWL 2008 �+ O a D I &�uaFA CEN08 -075 I P oo NOT SCALE auto. U42008 -0741 .c' (Les) NA I 'PEE. 7a 2 PR/NT SCALE: 1 =4 A I B n C I N • • CONOCO PHILLIPS TYONEK PLAFORM 4- 1/16" 15M TUBING BOP STACK 4" 10M WIRELINE CAP UNKNOWN HEIGHT DSA 4" 15M X 4" 10M - 3" TALL 4" 15M BOWEN SGL GATE �i� DRESSED 1.900" 28" TALL 4" 15M BOWEN SGL GATE DRESSED CSO 28" TALL DSA 4" 15M X 4" 5M - 3" TALL V.•, 4" 5M CROSS W /2" 5M OTL _ ® = �n � = W/2 EACH 2" 5M MGV'S IRl efiN IS1'1 `" 18" TALL DSA 4" 5M X 4" 3M - 3" TALL 4" 3M WELLHEAD IC 83" TOTAL HEIGHT FOR COMPONENTS ADD 1 " -2" FOR RING GASKETS = "'84 " -85" TALL STACKUP • • �Pd OF /T � ,t THE STATE � Alaska Oil and Gas °ALASKA Conservation Commission GOVERNOR SEAN PARNELL OA, � Anchorage, 333 West Seventh Avenue Alaska 99501 -3572 ALAS Main: 907.279.1433 �+ d Fax: 907.276.7542 et 1t1 Marcus Barbee +' ! Wells Engineer 6.3 ConocoPhillips Alaska, Inc. 167.- P.O. Box 100360 Anchorage, AK 99510 Re: North Cook Inlet Field, Beluga Oil Pool, NCI A -08 Sundry Number: 312 -440 Dear Mr. Barbee: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / - ) teA d e„L___ Cathy '' . Foerster Chair DATED this ?/ day of November, 2012. Encl. STATE OF ALASKA .i , ♦`V •SKA OIL AND GAS CONSERVATION COMAION II iy � • APPLICATION FOR SUNDRY APPROVALS e� 20 AAC 25.280 1. Type of Request: Abandon f Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Rill Tubing r lime Extension r 1 Operational Shutdown E Re -enter Susp. Well r Stimulate r Alter casing r Other:Fill Clean Out • )✓ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. • Development p . Exploratory r" 169 - 063 3. Address: Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 883 - 20028 - 00 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require spacing exception? Yes r No r NCI A - • 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 37831 North Cook Inlet / Beluga 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9222 6499 4635' 3608' 5446' Casing Length Size MD TVD Burst Collapse CONDUCTOR 584 16" 623' 623' SURFACE 2946 10.75 2985' 2621' R E I V irr • '' PRODUCTION 9117 7 9156' 6456' NOV 20Z012 07) t,(2_7(1 i ACGCC Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13 sets from 4979' - 5885' 3836' - 4407' 4.5 J - 5893 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - HALLIBURTON VSR PACKER (RETRIEVABLE W/TUBIN MD= 4545 TVD= 3580 PACKER - HALLIBURTON MHR PACKER (PERMANENT) MD= 4891 TVD= 3783 PACKER - HALLIBURTON MHR PACKER (PERMANENT) MD= 5361 TVD= 4072 PACKER - HALLIBURTON MHR PACKER (PERMANENT) MD= 5496 TVD= 4158 PACKER - HALLIBURTON MHR PACKER (PERMANENT) MD= 5699 TVD= 4287 SSSV - OTIS SCSSV LANDING NIPPLE MD =291 TVD =291 12. Attachments: Description Summary of Proposal J 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development p-- • Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/23/2012 • Oil r Gas j- - WDSPL r- Suspended r 16. Verbal Approval: Date: (►• z L WIND r GINJ r WAG r Abandoned r Commission Representative: 6 � Aic.,,.(1. GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Marcus Barbee @ 265 -6932 Email: barbema iconocoohillios.com Printed Name Marcus Barbee," Title: Wells Engineer JJ Signature Phone: 265 -6932 Date /�- j :)- Z a/ � Commission Use Only Sundry Number:3) Z o g/ Conditions of approval: Notify Commission so that a representative may witness y (� Plug Integrity r BOP Test Mechanical Integrity Test r" Location Clearance r Other: 3SD) / O$ - gOf f ti Spacing Exception Required? Yes 11 No No \� \ Subsequent Form Required: /U _ Y O 1 �' '/ v THERO MMI BY f/ / Approved by: COMMISSIONER THE COMMISSION Date: Approved application is valid for 12 months from the date of a•pr.val. 0 Rrf 2 / �` NOV 2 8 2012 iI y t Form n uicate `' • • 6 Clean out fill with 2" x 1" concentric coil tubing b Recover catcher and plug body with Slick line Recover IBP with coil tubing Run patch tubing with platform crane & deploy with Coil Tubing • Clean out fill to top of catcher sub • Recover catcher sub • Clean out fill to top of PX Plug • Recover PX prong and plug body • Clean out fill to top of IBP • Recover IBP • Drift and tag lower completion and find PBTD • - : : " - 1 - .' • - - • e - well- paekers • RTP • i SAK • NCI A -08 Conoco Phillips $ Well Attributes Max Angle & MD TD A tSha, hlr; s o Welibom API /UWI Field Name Well Status Ind ( MO (ftKB) Act Btm (RKB) W en,it7aps 508832002800 COOK INLET PROD 55.75 4,368.01 9,222.0 Comment H25 (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date ••• W81100889 . cIA -08,010i20111L2501AM SSSV: NIPPLE Last WO: 5/1/1994 8/12/1969 ,., - -- Schematic - Actual Annotation Depth (RKB) End Date Annotation Last Mod ... End Date • Last Tag: RKB 5,342. 7/14/2011 Rev Reason: TAG ninam 8/10/2011 HANGER,39 Casing Strings ■ Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd NIPPLE.291 CONDUCTOR 30 28.000 39.0 386.0 386.0 H -40 STC WRDP, 291 I Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd ■ CONDUCTOR 16 15250 39.0 623.0 623.0 65.00 H-40 STC Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 103/4 9.794 39.0 2,985.0 2,620.5 45.50 J-55 BTC MI Casing Description String 0... String ID ... Top (RKB) Set Depth (1... Set Depth (TVD( ... String Wt... String ... String Top Thrd cor4DU 7oR,^ PRODUCTION 7 6. 276 39.0 9,156.0 6,455.8 26.00 J -55 BTC CONDUCTOR. Tubing Strings SURFACE, Tubing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 39 - 2,985 TUBING 41/2 I 3.958 I 38.9 5,893.0 4,412.4 12.75 I J - 55 EUE - 8rd SEAL BORE, 4,538 / 1 Completion Details Tom .:. ; Top Depth Tom{ (TVD) Top Ind Nomi... PACKER, 4,545 _ Top (RKB) (RKB) (°) Item Description Comment ID (In) 38.9 38.9 0.00 HANGER FMC TUBING HANGER 4.500 NIPPLE. 4,613 ��< 290.8 290.8 0.00 NIPPLE OTIS SCSSV LANDING NIPPLE 3.813 4,536.2 3,5752 55.25 SEAL BORE UPPER SEAL BORE 3.937 APERF, - 4,545.1 3,580.2 55.19 RATCH LATCH 3.937 4,635 -4,735 -_ Sot, 4.835 4,545.5 3,580.4 55.19 PACKER HALLIBURTON VSR PACKER (retrievable w /tubing adapter) 3.880 LOCATOR, ' l 4,612.8 3,618.6 54.74 NIPPLE HALLIBURTON X NIPPLE 3.813 4.890 i �a = 4,890.1 3,783.5 53.64 LOCATOR LOCATOR no go 3.813 PACKER, 4,891 - 4,891.3 3,784.2 53.63 PACKER HALLIBURTON MHR PACKER (permanent) 3.970 APERF. 7.7-.! = 4,903.5 3,791.3 53.55 BLAST JTS 3.958 4,979 -5,036 5,183.4 3,960.7 51.63 SLEEVE -0 OTIS XD SLIDING SLEEVE (OPEN 3/28/2010) 3.958 APERF, 5,188.1 3,963.6 51.60 BLAST JTS 3.958 5,0615,161 t . 5,313.3 4,041.8 50.83 SLEEVE -O OTIS XD SLIDING SLEEVE (OPEN 2/17/2010) 3.958 SLEEVE -0, 5,349.3 4,064.6 50.79 SEAL BORE UPPER SEAL BORE 3.937 5,163 5,3602 4,071.4 50.78 RATCH LATCH 3.937 APERF, 5,360.7 4,071.7 50.77 PACKER HALLIBURTON MHR PACKER (permanent) 3.970 5.1915,211 __ . .. . 5,373.0 4,079.5 50.76 BLAST JTS 3.958 APERF, -- 5,445.7 4,125.6 50.68 SLEEVE -C OTIS XA SLIDING SLEEVE (Closed) 3.813 5,240 -5,250 5,495.3 4,157.1 50.62 RATCH LATCH 3.937 APERF, 5,496.4 4,157.8 50.62 PACKER HALLIBURTON MHR PACKER (permanent) 3.970 5,2885,283 5,648.3 4,256.6 51.07 SLEEVE -C OTIS XD SLIDING SLEEVE (Closed) 3.813 APERF, 5,697.9 4,287.1 50.67 RATCH LATCH IIN 5,2885,325 SLEEVE -0, 5,699.1 4,287.9 50.66 PACKER HALLIBURTON MHR PACKER (permanent) 3.970 5,313 5,859.5 4,390.3 49.38 NIPPLE HALLIBURTON XN NIPPLE 3.725 5,892.4 4,412.0 49.11 WLEG WI RELINE RE -ENTRY GUIDE w /Pump Out Plug 3.958 SEAL BORE, i 5,349 LE I Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Intl PACKER, 5,381 a• Top (RKB) (RKB) ( °) Description Comment Run Date ID (in) 1 1 . " 291 290.8 0.00 WRDP HES FX -4-4 WRDP 3/28/2010 2.250 APERF. i t 1 5,446 4,125.6 50.68 PLUG PX PLUG SET IN SLEEVE 2/6/2010 0.000 5,388-5,438 SLEEVE -C, 5,446 Perforations & Slots PLUG. 5,446 - Shot ` Top (TVD) Btm (TVD) 0908 '. Top (RKB( Btm (RKB) (ftK8) (RKB) Zone Date (h -• Type Comment t. 4,635 4,735 3,631.4 3,690.2 B, NCI A -08 7/1/1983 12.0 APERF CEMENT SQZ'd • "Mt 4,979 5,036 3,835.8 3,870.2 CI -1, NCI A-08 7/1/1983 ' 12.0 APERF PACKER. 5,496 .....' 5,061 5,161 3,885.5 3,946.9 CI -2, NCI A-08 7/1/1983 12.0 APERF 1 e..' 5,191 5,211 3,965.4 3,977.5 CI -3, NCI A-08 7/1/1983 12.0 APERF APERF, 5,240 5,250 3,995.7 4,002.0 CI -3.1, NCI A -08 7/1/1983 12.0 APERF 5,5635,570 5,266 5,283 4,012.0 4,022.7 CI-4, NCI A -08 7/1/1983 12.0 APERF APERF, - -- 5288 5,325 4,0269 4,0492 CI-4, NCI A-08 7/1/1983 12.0 APERF 5580 -5,596 - 5,388 5,438 4,089.0 4,120.7 CI -5, NCI A -08 7/1/1983 12.0 APERF APERF, 5,6005,624 5,563 5,570 4,200.0 4,204.4 CI -6.2, NCI A -08 7/1/1983 12.0 APERF I p. 5,580 5,596 4,210.8 4,221.0 CI -7, NCI A -08 7/1/1983 12.0 APERF SLEEVE -C, 5,600 5,624 4,227.4 4,241.8 CI -7, NCI A -08 7/1/1983 12.0 APERF 5,648 I 1., 5,743 5,753 4,315.4 4,321.7 CI -8.2, NCI A -08 7/1/1983 12.0 APERF 5,837 5,845 4,375.6 4,380.9 CI -9.1, NCI A-08 7/1/1983 12.0 APERF RATCH ,M , 5,855 5,885 4,387.4 4,407.1 CI -10, NCI A-08 7/1/1983 12.0 APERF LATCH, 5.696 ..... PACKER. 5,699 I , ' APERF. 5,743-5.753 APERF, 5,837 -5.845 NIPPLE, 5,859 fly APERF, 5,855 -5,885 - WLEG. 5,892 Cement Beluga Zone, 5,948 Cement Plug, 7,030 PRODUCTION, 39 -9,156 TD, 9,222 SAK • NCI A -08 . ConocoPhillips ) AwsK,,,111 KB -Grd (ft) Rig Release Date "' 8/12/1969 Well Confp: - NCI A-08, 8/10/201111:25:01 AM - - Schematic -Actual - - HANGER,39 Notes: General & Safety 11 End Date Annotation NIPPLE, 291 7 /1/1983 NOTE: WORKOVER WRDP, 291 9/1/1988 NOTE: WORKOVER 1/25/2011 NOTE: VIEW SCHEMATIC w /Kaska Schematic9.OREV 4/2/2011 NOTE: PLUG SET @ WLM DEPTH IN WSRs; COMPONENTS @ RKB DEPTHS CONDUCTOR, 39 -386 CONDUCTOR, 39523 SURFACE, 39 -2,985 SEAL BORE, 111 4,536 PACKER, 4,545 .�. IR NIPPLE, 4,613 1! APERF, 4,635 -0,735 SO2, 4,635 - - LOCATOR, 4,890 Mg PACKER, 4,891 APERF, II 4,979 -5,036 APERF, III 5.061 -5,161 SLEEVE -O, 5,183 ARF, 5,1915 APERF, 5,240 -5,250 - II IN 1 APERF, 5,26fiPERF APERF, 1 5,288 -5,325 1 SLEEVE -O, 5,313 SEAL BORE, 5,349 PACKER, 5,361 5,388-5,438 I! I SLEEVE -C, If 5,446 PLUG, 5,446 IF PACKER. 5.496 APERF, 5,563 -5,570 APERF, 5,5805,596 APERF, 5,600 -5,624 SLEEVE.C, 5,63 46 II RATCH .ice.. LATCH, 5,698 ' PACKER, 5,699 APERF, 5,743 -5,753 APERF, 5,8375,845 NIPPLE, 5,859 11 APERF, 5,855 -5,885 WLEG, 5,892 LL Cement ,948 Zone, 5,948 Cement Plug, 7,030 PRODUCTION, 39 -9,156 N TD, 9,222 • Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, November 21, 2012 11:08 AM To: 'Barbee, Marcus G (Swift Technical Services LLC)' Subject: RE: Tyonek CCT work (A -08 PTD 169 -063) Markus, You have verbal approval (Commissioner Foerster) to rig up CTU and begin your wellwork on A- 08. This is the first well in your program of FCO's using Concentric Coil tubing. Make sure you get a 24 hour notice in to the inspectors for BOP test. Sundry requires a 3500 psi BOP test. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Schwartz, Guy L (DOA) Sent: Tuesday, November 20, 2012 9:03 AM To: 'Barbee, Marcus G (Swift Technical Services LLC)' Subject: RE: Tyonek CCT work Marcus, Typically we require a witnessed BOP test for the first CTU job on a CI platform. What we would like is a cover letter listing all the wells planned with a job scope along with a 10-403 for the very first well only. (you will also need one for well 16 as you mention below).... We will then send out an Inspector for the first BOP test on the CTU unit. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Barbee, Marcus G (Swift Technical Services LLC) [mailto:Marcus.G. Barbee @contractor.conocoph illips.com] Sent: Tuesday, November 20, 2012 8:55 AM To: Schwartz, Guy L (DOA) Subject: Tyonek CCT work Mr. Schwartz, ConocoPhillips Alaska Inc. is preparing to mobilize 2" x 1" concentric coil tubing to the Tyonek platform to begin a clean out and fishing campaign and should remain on the platform through the end of the year. I am reviewing the AOGCC regulations and do not believe our scope of work will require an approved 10- 403 sundry application but want to contact you prior to going out to make sure. My plans are to perform fill clean out operations on wells A 1, 7, 8, 10a, 16 and push a fish to bottom in well 15. I do plan to patch the 7" casing in well 16 which will require an approved 10-403 application when we are ready for that portion of the well; which wont be for several weeks if things progress well. Thank you for your advice. Regards, 11/21/2012 Page 2 of 2 • Ha# c '8a/rbe& -Wells Engineer ConocoPhillips Alaska, Inc. 1- 907 - 265 -6932 0. 1- 907 - 250 -1163 C. This transmission may contain information that is privileged, confidential and / or exempt from disclosure under applicable law. If you are not the intended recipient, you are hereby notified that any disclosure, copying, distribution, or use of the information contained herein (including any reliance therein) is STRICTLY PROHIBITED. If you received this transmission in error, please immediately contact the sender and destroy the material in its entirety, whether in electronic or hard copy format. Thank You. 11/21/2012 Well Name Pre 2008 Survey Location NAD27 ASP 4 Northing Easting Post 2008 Survey Location NAD27 ASP4 Northing Easting Distance Moved NCI A-01 2,586,726.69 332,100.19 2,586,726.40 332,102.26 2.09 - -- ---- NCI A-02 2,586,722.85 332,108.29 2,586,721.16 332,111.27 __ 3.43 _ __ NCI A-03 _ 2,586,728.60 332,106.22 2,586,728.31 332,109.43 _ __ 3.22 _ _ NCI A-04 2,586,719.62 __ 332,105.09 _ 2,586,718.58 332,108.09 3.18 NCI A-05 2,586,725.55 332,110.17 2,586,725.14 332,111.79 1.67 NCI A-06 2,586,719.66 332,102.09 2,586,719.22 332,104.19 2.15 NCI A-07 2,586,727.79 332,103.73 2,586,728.78 332,105.40 1.94 NCI A-08 2,586,720.56 332,098.31 2,586,722.44 332,101.65 3.83 NCI A-09 2,586,666.58 332,039.08 2,586,667.35 332,040.44 1.56 NCI A-10 2,586,670.21 332,040.91 2,586,673.71 332,044.17 _ 4.78 _ NCI A-10A 2,586,670.21 __ 332,040.91 2,586,673.71 332,044.17 _ 4.78 NCI A-11 ___ 2,586,670.23 __ 332,039.14 2,586,677.01 332,041.75 .: __ 7.27 NCI A-12 2,586,722.73 331,947.80 2,586,723.59 331,994.15 46.36 NCI A-13 2,586,734.88 331,993.50 2,586,733.15 331,995.48 2.63 NCI B-01 _ 2,586,730.03 331,999.80 2,586,723.04 331,998.16 7.18 NCI B-01A 2,586,730.03 331,999.80 2,586,723.04 331,998.16 7.18 NCI B-02 2,586,731.14 331,999.29 2,586,729.60 332,001.86 3.00 NCI B-03 2,586,731.69 331,986.37 2,586,726.81 331,991.70 7.23 NCI B-03PB1 2,586,731.69 331,986.37 2,586,726.81 331,991.70 __ 7.23 ~~9!!!~ NrK ~ ~ LUU~ ~~~ -U~ • t ... _ _. __. _- _. I~\ REV DATE BY CK APP DESCRIPTION REV DATE BY C P DESCRIPTION I 2/29/08 S.QS KVVA MODIFY WELL HOUSE SCHEMATIC, SHT.2 ADD MUD LINE ELEV., SHT.3 go ~ ~ 36 31 T 12 N 31 32 qn,~ a ~~ h i~ 1 6 ~ ~'s T 1 ~ N 6 5 TIW R0 (1 , ~ ~ 5. IYYS' SEC. 6 1206' SCALE: I"-1320' -6 ---- ~ ~ ~ o ~ ~ I 6 I 6 5 12 7 ~ 8 GENERAL NOTES: ~~~~ OF ~ \\~, I. SEE SHEET 3 FOR COORDINATE TABLE . i '`P'''~~~~~~~.~~~~''~s~-~1~ 2. SEE SHEET 3 FOR NOTES ON HORIZONTAL AND ~ ~ "~ VERTICAL SURVEY DATA : ~~ ' 49th ~ M ~ ..... 3. SECTION LINES AND TIES ARE BASED ON PROTRACTED ~""""""""""""""""""""'' VALUES j . ~. ................................ ..... ~• ~, KENNETH W. AYERS ;' ~~ J' ~',~ LS-8535 ~,' ~~~i SURVEYOR'S CERTIFICATE ~~~, .....„ A ~ ~~ 1 HEREBY CERTIFY THAT ! AM PROPERLY REGISTERED , ROFE P`~P .~ AND \\\~,~ ~:~~~~ LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DONE BY LOUNSBURY DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF & ASSOCIATES, INC. FEBRUARY 28, 20DB. SURVEYORS ENGINEERS PWNNERS v~ PHONE: (907) 272-5451 ~.~ AREA: MODULE: UNIT: ConocoPhilli s NORTH COOK INLET p TYONEK PLATFORM Alaska, Inc. WELL CONDUCTOR AS BUIET CADD FILE N0. DRAWING N0: PART: REV: 08-005 AS BUILT 02/27/08 ~g-~05 AS BU~L_T 1 of 3 1 i REV DATE BY CK APP DESCRIPTION REV DATE BY PP DESCRIPTION I 2/29/08 SAS KWA MODIFY WELL HOUSE SCHEMATIC, SHT.2 ADD MUO LINE ELEV., SHT.3 o ~ Ar s ~ o9~ Q ~ 9 y°s ~ AAg ~ i1w na ~0 s. rov' e siS scc ~~ ~j ~ ~~ ~~ SCALE: 1"=30' 9a kA O ESD 600 50 - ESD 600-51 •10 I p •B2 B3• AB A•A• p5 • • • A3• A6 Al BI . •AS • A4 A2 WELL HOUSE 2 Op• 2p A1Oo LEGEND: 5 p • 3 A • WELL p WELL CONDUCTOR 0 ESD (EMERGENCY SHUT OFF VALVEI GENERAL NOTES: I. SEE SHEET 3 FOR COORDINATE TABLE 2. SEE SHEET 3 FOR NOTES ON HORIZONTAL AND VERTICAL SURVEY DATA LOUNSBURY 3. NO WELLS EXIST IN WELL HOUSE N0. 4, AND IT WAS NOT & ASSOCIATES, INC. A S BUILT SURVEYORS ENGINEERS PLANNERS ~ ~ PHONE: 19071 272-5451 AREA: MODULE: UNIT: ConocoPhilli S NORTH COOK INLET TYONEK PLATFORM Alaska, Inc. WELL CONDUCTOR AS BUILT CADD FILE N0. DRAWING N0: PART: REV: 08-005 AS BUILT 02/27/08 08-005 AS BUILT 2 of 3 1 I 2/29/08 SA$ KWA MODIFY WELL HOUSE SCHEMATIC, SHT.2 ADD MUD LINE ELEV., SHT.3 ASP ZONE 4, NAD83, FEES NAD83 GEOGRAPHIC MLLW DESCRIPTION (POINT NO.) NORTHING FASTING LATITUDE LONGITUDE ELEVATION NqU W ELL TAG NO. WELL HOUSE NO.1 1001 2586492 1472018 61 04 34.38 150 57 03.71 72.0 Conductor 1 1002 2586489 1472017 61 04 34.34 150 57 03.72 73.9 B3 1003 2586485 1472019 61 04 34.31 150 57 03.67 74.1 A12 1004 2586485 1472023 61 04 34.31 150 57 03.59 73.8 B1 1005 2586487 1472027 61 04 34.33 150 57 03.52 72.0 Conductor 5 1006 2586491 1472027 61 04 34.37 150 57 03.52 73.7 B2 1007 2586495 1472025 61 04 34.41 150 57 03.57 72.1 Conductor 7 1008 2586495 1472021 61 04 34.41 150 57 03.65 73.7 A13 WELL HOUSE N0.2 2001 2586437 1472060 61 04 33.84 150.57 02.83 71.9 Conductor 1 2002 2586433 1472059 61 04 03.38 150 57 02.84 71.9 Conductor 2 2003 2586430 1472062 61 04 33.77 150 57 02.79 71.8 Conductor 3 2004 2586429 1472066 61 04 33.77 150 57 02.71 73.4 A9 2005 2586431 1472069 61 04 33.79 150 57 02.65 71.9 Conductor 5 2006 2586435 1472069 61 04 33.83 150 57 02.64 73.3 A10 2007 2586439 1472067 61 04 33.86 150 57 02.69 73.3 A11 2008 2586439 1472063 61 04 33.87 150 57 02.77 71.9 Conductor 8 WELL HOUSE N0.3 3001 2586488 1472128 61 04 34.36 150 57 01.47 73.0 Al 3002 2586484 1472127 61 04 34.32 150 57 01.48 73.1 A8 3003 2586481 1472130 61 04 34.29 150 57 01.43 73.1 A6 3004 2586480 1472133 61 04 34.28 150 57 01.35 73.0 A4 3005 2586483 1472137 61 04 34.31 150 57 01.29 73.0 A2 3006 2586487 1472137 61 04 34.34 150 57 01.28 73.0 A5 3007 2586490 1472135 61 04 34.38 150 57 01.33 73.0 A3 3008 2586490 1472131 61 04 34.38 150 57 01.41 73.3 A7 50 2586540 1472069 61 04 34.86 150 57 02.69 72.7 ESD Valve 600-50 51 2586501 1472011 61 04 34.46 150 57 03.86 72.6 ESD Valve 600-51 100 2586572 1472123 61 04 35.18 150 57 01.58 115.3 Top center helipad -101' MUD LINE SURVEY NOTES: 1. ALL COORDINATES ARE ASP ZONE 4, NAD83, US SURVEY FEET. GEOGRAPHIC COORDINATES ARE NAD83. 2. ELEVATIONS ARE IN FEET, BASED ON MLLW, REFERENCED TO DRAWING NO. MPD- TY04-2021, SHEET 1 OF I, REV. 2 3. ALL AS BUILTS ARE TO THE CENTER OF EXISTING STRUCTURE. 4. WELL CONDUCTOR ARE VERTICALLY AS BUILT TO THE TOP OF A l/4" STEEL LID, TACK WELDED TO THE TOP OF THE CONDUCTOR. 5. WELLS ARE VERTICALLY AS BUILT TO THE TOP OF THE LOUNSBURY LOWEST HORIZONTAL FLANGE ON THE WELL. & assoclaTES, lrrc. SURVEYORS ENGINEERS PLANNERS ~ Y'~ PHONE: f907) 272-5451 `,,.~ AREA: MODULE: UNIT: ConocoPhillips NORTH COOK INLET TYONEK PLATFORM Alaska, Inc. WELL CONDUCTOR AS BUILT CADD FILE N0. DRAWING N0: PART: REV: 08-005 AS BUILT 02/27/08 ~8-0~5 AS BUILT 3 of 3 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other_X Variance 2. Name of Operator Conoco Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchora~le, AK 99510-0360 4. Location of well at surface 1256' FNL, 1080' FWL, Sec. 6, T11N, R9W At top of productive interval 107' FNL, 1055' FEL, Sec. 1, T11 N, R10W At effective depth At total depth 400' FSL, 1929' FEL, Sec. 36, T12N, R10W 5. Type of Well: Development __X Exploratory _ Stratigraphic __ Service_ 6. Datum elevation (DF or KB feet) RKB 116' feet 7. Unit or Property name North Cook Inlet 8. Well number A-8 9. Permit number / approval number 69-63 / 302-225 10. APl number 50-883-20028 11. Field / Pool Cook Inlet / Beluga 12. Present well condition summary Total depth: measured true vertical 9222 feet 6487 feet Effective depth: measured 4635 feet true vertical 3608 feet Length Casing Structural Conductor Surface Production Plugs (measured) Junk (measured) PBTD 5948' 1. Cmt retainer @ 6200', 50 sx below, 10 sx above 2. Cmt retainer @ 5978', 45 sx below, 5 sx above. Size Cemented Measured Depth True vertical Depth 30" Driven 386' 386' 16" 587 sx 623' 623' 10-3/4" S25 sx 2985' 2603' 7" 1405 sx 9156' 6443' Perforation depth: measured 4979-5885' true vertical 3815-4399' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) RECEIVED SEP I .... 2002 4-1/2" 12.60#, J-55, surface-325' 4-1/2" 12.75#, J-55, 325-5893' Hallibu~on MHR permanent packers ~ 4891, 5361, ~96, and 5699' Hallibu~on VSR retrievable packer ~ 4545' Hallibudon Series 10 FXE WLRSV ~ 291' 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl N/A N/A Representative Daily Avera.qe Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure . Tubing Pressure 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X Oil __ Gas __XX Suspended _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed T, itl~ Prcb!~m ~r~.~!O!', Sup¢,'vlsor Service Date Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Date Comment NCIUA-8 Event History 05/13~02 06/05/02 09/08/02 09/09/02 09/10/02 STATIC BHP MONITOR SSSV CONTROL LINE INITIATED WELLHEAD REPAIR. GAUGED TUBING TO 4500' WLM. DRIFTED WITH 5' X 3.805' DUMMY PLUG TO 4230' WLM. ATTEMPTED TO SET 4.5" PES TUBING PLUG, PLUG PARTIALLY SET IN LUBRICATOR, RIGGING UP BACK-UP PLUG FOR SECOND ATTEMPT AT REPORT TIME. SET PES PLUG AT 4250' WLM. DRAWDOWN TEST 600 PSI --> 0 PSI GOOD. SET DUMMY SSSV W/PX PLUG & PRONG AT 291' RKB. LOAD TBG ABOVE 291' WITH 4.5 BBL TEG/WATER, PT 1500 PSI GOOD. SET BPV. PULL WELLHEAD & REPLACE NECK SEALS (TOP SEAL CUT) & APl RING GASKET. REPLACE WELLHEAD, PT HANGER VOIDS TO 3000 PSI, GOOD TEST. PRELIMINARY TEST OF SSSV CONTROL LINE GOOD. PULL BPV, PULL PX PLUG FROM SSSV PROFILE. IN PROGRESS. PULLED PES TUBING PLUG, FLUSHED CONTROL LINE, SET SSSV AND FUNCTION TESTED SAME. GOOD TEST OF SSSV. JOB COMPLETE. Page 1 of I 9/16/2002 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 September 17, 2002 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations NCIUA-8 (69-63 / 302-225) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent operations on the Tyonek well NCIUA-08. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad Jul 1S 02 02:04p WELLS GROUP 90~,~59 7314 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS p.3 1. Type of request: Abandon_ Suspend_ Alter casing_ Repair well _ Change approved program _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1256' FNL, 1080' FWL, Sec. 6, T11N, R9W At top of productive interval 107' FNL, 1055' FEL, Sec. 1, T11N, R10W At effective depth At total depth 400' FSL, 1929' FEL, Sec. 36, T12N, R10W Operational shutdown _ Plugging _ Pull tubing _ 5. Type of Well: Develepment_X F. xplorato~y _ Stratigraphic __ Service_ (asp's O, O) (asp's O, O) Re-enter suspended well _ Time extension _ Stimulate _ Variance _X Perforate _ 6. Datum elevation (DF or KB feet) RKB 116' feet 7. Unit or Property name North Cook Inlet 8. Well number A-8 9. Permit number / approval number 69-63 10. APl number 50-883-20028 11. Field / Pool Cook Inlet / Beluga Other _ 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Structural 30" Conductor 16" Surface 10-3/4" Production 7" Perforation depth: measured 4979-5885' true vertical 3815-4399' Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 9222 6487 4635 3608 feet Plugs (measured) feet feet Junk (measured) feet Cemented Driven 587 sx 825 sx 1405 sx 4-1/2" 12.60#, J-55, surface-325' 4-1/2' 12.75#, J-55, 325-5893' PBTD 5948' 1. Crnt retainer @ 6200', 50 sx below, 10 sx above 2. Cmt retainer @ 5978', 45 sx below, 5 sx above. Measured Depth True vertical Depth 386' 386' 623' 623' 2985' 2603' 9156' 6443' RECEIVED Halliburton MHR permanent packers @ 4861, 5361, 5496, and 5699' Halliburton VSR retrievable packer @ 4545' Halliburton Series 10 FXE WLRSV @ 291' 13. Attachments Description summary of proposal _X Detailed operations program _ 14. Estimated date for commencing operation I 15, Status of well classification as: Immediately Name of approver Date' appr0,v, ed Service 17. I hereby certify th_at the foregoing is true and ~p.[rect to the best of my knowledge. Signed ~;;/~~ C·((-~'~Title: Problem Well Supervisor Date Jern/~retnlels ~ FOR COMMISSION USE ~'NLY BOP sketch m Suspended _ Conditions of approval: Notify Commission so representative may witness II Approval Plug integrity_ BOP Test_ Location clearance ~ .~echanical Integ. rity Test ~, e t Subsequent form required . (.~g,nal ._S~. n~..,~ commissioner Approved by order of the Commission ~'~.~mm. ~ .... : .......... Form 10-403 Rev 06/15/88 ORIGINAL SUBMIT IN TRIPLICATE TOC {~ 5948 sx cem't TOC @ 6150 : 50 sx cern1 PBTD 9103' TD = 9,222' Be 386 623 2985 TOC @ 3010 Halliburton VSR packer @ 4545' "B" Sands (4635 - 4735 Squeezed Off) Permanent Packer @ 4891' Cook Inlet Sands 4979 - 5036 C1-1.0 5061-5161 CI-2.0 5191 - 5211 CI-3.0 5240 - 5250 CI-3.1 5266-5283 CI-4.0 5288-5325 CI-4.0 Permanent Packer @5361' 5388 -5438 CI-5.0 Permanent Packer @5498 5563- 5570 Cl-6.2 5580-5596 Cl-7.0 5600-5624 CI-7.0 Permanent Packer @ 569~ 5743-5753 CI-8.2 '5837-5845 CI-9.1 -5885 C1-10.0 ga Sands cem't ret @ 5978' 6008 - 6022 a-3 cem't ret @ 6200' 6302 - 6310 b-6 CIBP 6850' 6904-6914 e-3 ?NRofperf? 7030 - 7067 e-8 & e-9 EZSV @ 7150' 7197-7214 f-4&~5 7218-7238 f-6 7309-7326 g-1 7388-7398 g-4 7478-7488 h-1 7513-7538 h-3 7583-7598 h-6 7822-7828 i-7 8008- 8018 k-2 8180-8185 m-2 8307-8314 m-10 8375-8425 n-2 7" @ 9156' NCIU A-8 WELL COMPLETION DIAGRAM BPV(Make~Type,OD) FMC OCT [RKB-Drill Deck: Tbg. Hgr.(Make,Type) FMC 6" 3M 4 1/2" 8rd X 4 1/2" BT&C ]RKB-THF: . 39.40 [AnnUlus Fluid: 70 / 30 Methanol / 2 % KCI Completion Fluid ]RKB-SL: 3 116.00 [TOC: 3010' from CBL dated 07/23/69 WATER DEPTH: 120' ]RKB-ML: Production 65 lb/f[ ST&C 1540 45.5 & 51 lb/f[ BT&C 3350 23 & 26 lb/f[ BT&C 4080 12.60 lb/f[ Mod BT&C 4730 12.75 lb/f[ Mod 8rd 4730 PRODUCTION TUBING STRING 38.90 Elevation 0.67 FMC / OCT 6" 3M 4 1/2" 8rd x 4 1/2" Mod BT&C 251.21 4 112" 12.60 lb/f[ L-80 Mod BT&C Tubin8 2.51 Otis 4 t/2" SCSSV Landin8 Nipple - reset SCSSV 12/2001 31.56 4 1/2" 12.60 lb/f[ L-80 Mod BT&C Tubing 0.74 X-Over 4 1/2" BT&C x 4 1/2" EUE 8rd Mod 4210.63 4 1/2" 12.75 lb/f[ J-55 EUE Mod 8rd Tubin$ 8.91 Seal Bore 0.35 Ratch-Latch Locator 7.28 Halliburton "VSR" retr. 60.07 4 1/2" 12.75 lb/f[ J-55 EUE Mod 8rd Tubin8 1.55 Halliburton "X" Profile 275.72 4 1/2" 12.75 lb/f[ J-55 EUE Mod 8rd Tubing[ 1.15 No-Go Locator 12.23 279.88 4.70 Halliburton "MHR" permanent packer 4 1/2" 12.75 lb/f[ Tubing and Blast Joints Otis 4 1/2" "XD" Sliding Sleeve 125.26 4 1/2" 12.75 lb/fi Tubing and Blast Joints 4.71 Offs 4 1/2" "2KD" Sliding Sleeve 31.31 4 1/2" 12.75 lb/f[ J-55 EUE Mod 8rd Tubin8 10.84 0.55 Ratch-Latch Locator 12.31 72.65 4.17 31.24 14.18 1.15 12.34 139.51 4.22 Halliburton "IVff-IR" permanent packer 4 1/2" 12.75 lb/f[ Tubing and Blast Joints Otis 4 1/2" "XA" Sliding Sleeve 4 1/2" 12.75 lb/f[ J-55 EUE Mod 8rd Tubin~ Ratch-Latch Locator 31.26 Halliburton "MI-IR" permanent packer 4 1/2" 12.75 lb/f[ J-55 EUE Mod 8rd Tubin~ Otis 4 1/2" "XD" Sleeve 4 1/2" 12.75 lb/f[ J-55 EUE Mod 8rd Tubin[g 14.18 S cai Divider 1.15 Ratch-Latch Locator 12.34 Halliburton "MHR" 148.03 4 I/2" 12.75 lb/f[ J-55 EUE Mod 8rd Tubin8 1.61 Halliburton 4 1/2" "XN" Nipple 31.30 4 1/2" 12.75 lb/f[ J-55 EUE Mod 8rd Tubin[g 0.61 WELL HISTORY August 1969 - Well Originally completed in Beluga e-8 thru n-2 from 7030'-8425' July 1983 Workover - Abandon Beluga 7030'-8425' due to casing collapse. Perforate Beluga a-3, b-6, Cook Inlet B, 1.0 - 10.0 from 4635'-6310' All zones commingled CI B thru 10.0, Beluga a-3 & b-6. July 1986: CI B SS shut after testing high nitrogen. Aug/Sep 1988 WO: Producing from CI 1.0 - 10.0 & Beluga a-3 to b-6 commingled. May 1994 WO: Pull tubing, tubing plugged from 6001' to EOT at 6385' 6302'-6310' tubing had holes cut due to produced sand. Set EZSV ~ 6200 and Squeezed Beluga b-6 from 6302'-10' DST Beluga a-3, 6008'-22', zone would not flow, abandon with EZSV and squeeze with cement. DST CI 1.0 thru 10.0, test 9.9 IvIMCFD, 240 BWPD, C16000, FTP 195 psi CI 8.2, 9.1, 10.0 tested no water, CI 6.2 & 7.0 tested 200 BWPD, CI 3.0 thru 5.0 tested 320 BWPD CI 3.0, 3.1, & 4.0 tested no water, Run tubing and packers, Well completed in CI 8.2, 9.1, & 10.0 September 1999 TD - 5493' (1.72" gauge) April 4, 2001 Pull SCSSV. Attempt 3 times to set PX plug in SC sleeve ~ 5183'; unsuccessful Attempting to seal tubing to change out failed neck seals in wellhead June 3, 2001 Tag fill @ 5915' WLM Dec. 2001 Find neck seals okay. Set SCSSV Updated by: ImO 2/17/02 PBTD: 5,948' [Supv: ITbgWt: 4 1/2" - 12.60 & 12.75 lb/f[ Well: North Cook Inlet Unit No. A-08 [ August 08, ]994 Location: Lower Cook Inlet, Alaska Field: Cook Inlet Unit PKD A~ STATE OF ALASKA ~ , AL A OIL AND GAS CONSERVATION COMMI .)N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator: Phillips Petroleum Co. 3. Address: P.O. Box 1967 Houston, Texas 77251-1967 4. Location of well at surface: Operation Shutdown Stimulate__ Pull Tubing .,.X Alter Casing Plugging Repair Well 5. Type of Well Development X Exploratory Stratigraphic ~ Service Leg 3, Slot 2 PPCo. Tyonek Platform Perforate X Other 6. Datum elevation (DF or RKB) RKB 116 7. Unit or Property Name North Cook I~let U~Jt 8. Well Number Feet 1,256' FNL & 1,080' FWL At top of productive interval: 107' FNL & 1,055' FEL At effective depth: 107' FNL & 1,055' FEL At total depth: 5,948' MD; 400' FSL & 1,929' FEL Sec 6-T11N-R9W 4,635' MD; 3,608' TVD Sec 01-T11 N-R1 OW 4,635' MD; 3,608' TVD Sec 01-T11N-RIOW 4,434' TVD Sec 36 -T12N-R1 OW A-08 9. Permit Number / Approval Number 69-63 10. APl Number 50-883-20028 11. Field /.Pool Cook Inlet / Beluga 12. Present well condition summary: Total Depth: measured true vertical 9,222 feet 6,487 feet Effective Depth: measured true vertical 4,635 feet 3,608 feet Casing: Structural Conductor Surface Intermediate Production Liner Length Size Cemented 30" Driven 16" 587 sx 10 3/4" 825 sx 7" Perforation Depth: measured 4,979' - 5,885' true vertical 3,815' - 4,399' Tubing (size, grade and measured depth) Packers and SSSV ( type and measured depth) Plugs (measured) PBTD 5,948' 1) Cem't retainer @ 6,200'. Sqz'd. 50 sx below, 10 sx above. 2) Cem't retainer @ 5,978'. Sqz'd. 45 sx below, 5 sx above. Junk (measured) ORIGINAL Measured Depth True Vertical Depth 386 386 623 623 2,985' 2,603' 1,405 sx 9,156' RECEIVEr, s, jAN 2 7 1995 Ataska Oil & Gas Cons. Commission ' Anch0r~ ,: 4 1/2" 12.60 Ib/ft J-55 Mod BT&C Tubing ' Surface to 325'. 4 1/2" 12.75 Ib/ft J-55 Mod EUESrd Tubing 325' to 5,893'. Halliburton "VSR" Retrievable Packer @ 4,545'; Hallibu~on MHR permanent packers ~ 4,891 ', 5,361', 5,496', and 5,699'. Hallibu~on Series "10" Type "FXE" WLRSV ~ 290.78'. 13. Stimulation or cement squeeze summary: 1) Sqz 50 sx below retainer @ 6,200', spot 10 sx above. 2) Sqz 45 sx below retainer @ 5,978', spot 5 sx above. 3) Squeeze perfs 4,635' - 4,735'. Intervals treated (measured): 1) Beluga Sands below 6,200'. 2) Beluga Sands below 5,978' 3) Cook Inlet Stray perfs 4,635' - 4,735'. Treatment description including volumes used and final pressure: 1) 60 sx D/S Class "G". 2) 50 sx D/S Class "G". 3) 125 sx D/S Class "G". Max psi 1,950 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 8500 69.48 75 895 02~05~94 Subsequent to operation 0 13800 3.56 555 921 08/06/94 15. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations 16. Status of Well Classification as: X Oil Gas X Suspended Service 15. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed ~~----~-~- ~" 2'~~, Title Principle Engineer Form 10-404 Rev, 06/15/88 Date 19-Jan-95 SUBMIT IN DUPLICATE , PHILLIPS PETROLEUM PAGE:I ' DAILY REPORT S~ ..... WBLLsNorth Cook Xnlet Unit No. &-8 RIG:/ FIELD:COOK INLET NORTH AFE$: CNTY/STATE:TYONEK OFFSHORE/ALASKA AUTH COST:$1,238,000 DATE DEPTH RPT NO NW OPERATIONS SLI4NARY ~)~,-- -0 ..... 1 - --' ~¥~- ~rb- h~:~b- ~bU-~ ......... ~5/z?/gd~ 0 2' 8.5 SKID RIG OVER A-8, SKID PIPE RACK, RIG UP RIG AND PiPE RACK. ACCSPTED RIG AT 0000 hfs 5/27/94 RIG UP TO KILL ~ELL, KILL WELL, CANOT SET BPV. 05128194 0 3 '8.'~ ATTEHPT TO PULL BPV WITH FHC LU8RICATON WITH NO SUCCESS. RIG UP WIRE LINE, NO SUCCESS, HADE UP TOOL WiTH BIGGER SHEAR PINS, PULLED BI)V. RIG UP WIRE LINE TO PULL SCSSV. DALLY COST CUN COST $34,68~ S66", 1~ O5/29/94 0 4 8.5 tj5/30194 9,156 5 8.5 ~/~i/94 9,156 6 8.5 ~6/01/94 9,156 ?' ' 8.5 PULL SCSSV,CLOSE SS, SET PLUG, SET SCSSV, NIPPLE DCM TREE NIPPLE UP AND TEST BOPS AND BOPE.PULL SCSSV, PULL PLUG, RIG UP TO PULL TBG.PULL GUT OF OTIS RH PKR WITH 110,000 CIRC WEL POOH & LAY DM $.5- TBG ASSEHBLY.TBG PLUGGED FROM 6001' TO 638SO.HOLES IN BLAST JT. FRC]4 iS302-6310.R/D TBG TOOLS.P/U T/S PKR HILLING ASS.TIH.TAG AT &931.CBU.HILL ON PACKER. HILL UP AND RECOVER 3 PACKERS FROM 4931,5525 & 5978.TIH W/ 6N BIT TO CLEAN GUT.TAG FILL ~ 63IS,CLEAN GUT SOFT FILL TO 6~00~ .CBU AND PUI4P HI-VIS SleEP. $40,925 s138,451 S52,150 ' $190,600 s5o, 170' $2~o,770 ' CIRC & SVEEP.TOH.L/D BHA.TIH.SET EZSV ~ 6200 . SQUEEZE 10 BBL S3T,503 06/0Z/94 ' 9,156 GO/O3/94 9' i"S6 OqT BELGU.ABANDON PERFS 6302 TO 6310.SPOT SO' CHT ON TOP. TOH.TIH.SET EZSV a 4800.TOH.TIH.SOUEEZE PERFS O ~635-&735. 8 8.6 SQUEEZE PERFS 4635-4735.TOH.TIH TO 4500.SLIP & CUT.TIH.CHT i 537,o55 &585.TEST CSG TO 2000.OK.DRILL CHT TO EZSV g 4~SO0.TEST PERFS TO IOO0.OK.DRILL EZSV.CBU.TOH.PAJ CSG SCRAPER AND TIH. 9 8.6 TIH TO 6150.CBU & DISPLACE FLUID.TOH.PAJ 4 5/8# TCP GUNS & $78,383 5315',3a? $393,710 06/04/94 9,156 CASED HOLE TEST TOOLS.CORRELATE GUNS & SPACE OUT.SAFETY HTG. PERF &OO'.FLOW kN~LL FOR CLEANUP. 10 8.5 FLOW WELL FOR CLEANUP.KILL WELL.TOH W/PERF GUNS & TEST TOOLS S19&,683 $58~,393 ~/05/94 9,156 11 8.6 06/06/94 9,156 i2 8:'5 06107/94 9,156 13 8.5 P/U BIT & SCRAPER & TIH TO 6100.PLUGGED STRING.TOH.SAND & PERF DEBRIS IN BOTTOM 60.TIH STAGING TO BOTTOM.NOW AT 6069. TIH 6150.CIRC & SWEEP.TOH.TIH W/DST TOC)LS.SET PKR ~ 4933,END AT 6022.OPEN TO TEST.DEAD.R/D TREE.RAJ COILED TBG.JET WELL IN.KICKED OFF WITH SO BBLS H20 OUT.FLOWING bELL.CLEANUP/TEST FLCM TEST/KILL bIELL/POOH LD TEST TOOLS/P/U BIT & SCRAPER.TIH TO &9OO.CBU.TIH TO 6150.SUEEP & CBU.TOH.UEEKLY BOP TEST. DST ZONE O 6013-6027.GAS 8 SURFACE TSTH.WELL DIED.FILL TBG & $36,37'9 $624,T72 $72;686 $40,628 $738,086 06/o8/94 9;'156 TOH.L/D TEST TCX:)LS.TIH.FILL aBC)24.CLEAN TO O075.CBU.TOH.P/LI EZSV.TIH.SET 05999.SQUEEZE 9 BBLS CHT BELOW.TOH.PRTD=S948~. 14 8.5 POOH W/EZSV SETTING TOOL/TIH W/BIT TO PRTDOS94,9/CBU/POOH S57,827 $795,913 06/09/94 9,156 15 TIH W/DST TOOLS/OPEN WELL FAIL TO FLCYd/RU COIL TBG/ JET WELL IN WITH NITROGEN & FLC~/ FOR CLEAN UP 8.6 FLOW TEST/KILL WELL/RD COIL T~JG/RELEASE PACKER/CIRC OUT GAS POOH/RIH WITH BIT & SCRAPER/CIRC/POOH/RIH WITH DST TOOLS/ S100,640 S896,553 b6/10/94 9,1"56 06/11/94 9,156 06/lz/94 9,156 06/13/94 9,156 b6/14/9~ 9,156 06115194 '9,156 16 8.6 17 8.6 18" 8.7 19 8.6 20 8.6 21 8.6 SET PACKER & FLOW TEST COOK INLET SANDS 8, 10, & 11. FLOW TESTED Cl 8 THROUGH Cl 11/HOVED PACKER/FLOW TESTED Cl 6 & ?/NC)VED PACKER/FLGId TESTED CZ 3, 4, & S/KILLED blELL/CIRC OUT GAS/PGOH W/TEST T(X)LS/RIG REPAIR/RIH WITH BIT & SCRAPER FINISH BIT & SCRAPER RUN/CIRC/PC)OH/RUN EZSV & ISOLATE Cl # 5 RIN WITH DST TGOLS/OPENED WELL/WELL DIED/RU COIL TBG & JET WITH NITROGEN ON CI # 5 WATER ONLY/LOAD TBG/CIRCULATE CLEAN ~9,553 $93~,1C)5 $37;559 $973,66~ POOH WITH DST TOOLS/BIT-SCRAPER RUN/SET EZSV ABOVE Cl 5/RIH WITH DST TOOLS/ATTEHPT TO TEST Cl ~/NOVE PACKER DUE TO CCH4JNICATION AROUND PACKER/JET IN Cl 3 & & & CLEAN UP FINISH FLCX,/ TESTING Cl 3"& Cl ~/KILL b/ELLAJNSET PACKER/ClRC HOLE CLEAN/PGOH WITH DST TCX)LS/CLEAN GUT EZSVtS WITH BIT/ ClRC HOLE CLEAN/POOH/TEST BOPtS/BIT & SCRAPER RUN/CIRCULATE 563,941 Sl ,037,605 S91',943 $1,129,548 FINISH CIRCULATING/POOH/RUN & SET 1ST PACKER ASSEHBLY/CIRC/ POOH/14U 2ND PACKER ASSEHBLY & RIH WITH SANE CONTINUED WITH COI4PLETION OF WELL BY RIH ~ SETTING PACKER $41,562 $1,171'11'0 $41,572 Sl,212,682 b6?16/94 9,156 i)6/'17/94 9,156 06/18/94 9,156 22 8.6 23" 8.6 24 8.6 ASSENBLIES # 2, 3, & 4. PRESENTLY NAKING UP ASSEHBLY # 5. RUN TBG TO PACKER t~/PULL X PLUG/PC)OH/RUN ASSEHBLY # 5/ POOH/RUN PRODUCTIOM TUBING/ FINISHED RUNNING PRGOUCTION TUBING/ND 8C)P'S/NU TREE/JET IN WELL WITH COIL TUBING & NITROGEN & FLOW TILL CLEANED UP FINISHED FLQW CLEAN UP OF t~LL & RELEASED WELL TO PROOUCTIC)N FINAL REPORTllI S3~,~89 Sl,247,171 S303,500 Sl,550,6~1 S72,857 Sl,6Z3,528 623 2985 TOe ~ 3010 'B' 8~d ~ P~m~t ~k~ ~ok In~ ~m~t P~ P~m~t P~k~ ~7~ - 5~ 1~ ~m't r~ ~ ~78' ~m't r~ ~ ~' - ~10 TOC@ 5940 6150 FINAL WELL COMPL~ ~'ON DIAGRAM -T ilpV(M&Ite,T~,OD). FMC OCT ~ [~,H~r. fMake,T~) FMC 6' 3M 4 1~.,8~ X 4,1~' BTAC R~.-~ 39.~ Annulus Fluid: 70 [ ~ Methanol [ 2 ~ KCI Core,etlon Fluid R~-SL :., 116.~ 'T~: ~10'~ron CB~ dated 07~/69 ' WA~R DH~:' 1~ R~-ML: : . Pr~uction C~hA: ..... .... ~' 41 , ~ 16' 41 6~ 65 I~rt H~ ,, STSC ..... l0 ~4 ' . 41 ~98S. 4S~S & Sl I~t J-SS BT&C 33~. 1~0 531 ?' ~ %1~ ~ & ~ i~tt J-SS ST&C , ,,, .... . , 4 1~". 39 3~ 12.~ ~ft J-55 Mod BT&C 47~ 4~ 135 4 1~" 3~ 5,8~ IZ75 l~ft J-55 Mod 8~ 47~ 4~ :::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: PRODUCTION ~BING STRING .......... ~ ....... ...... " ~ o.~ ' 39 0.~ .... ~.~ ~evatim ...... ., ~ ~.~ 0.67 FMC / ~T 6" 3M 4 1~" 8~ x 4 1~ Mod BT&C TuMng HanKer 37 ~.57 ~1.21 41~" l~l~ft L-~M~dBT~CTuMn~ ,3.9~ 5.~3 ~ 2~.78 ~51 ~b,~ !~" S~SV ~ndi~ Nipp~ 3.813 5.~ 35 2~.~ 31.~ 41~" 12.~l~ft L-~M~BT&CTuMng 3.~ 5.~3 ~ 3~.85 0.74 X-~er 4 1~BT~Cx4 l~"EUB8rd Mod ,, ,3.9~ 4.~19 33 , 3~ 4210.63 4 1~" 12.75 l~ft J-55 EUB Mod 8~ TuMng ' 3.9~ ' 5.~3 32 45~.22 8.91 Up~r Seal Bo~ 3.~ 31 4545.13 0.35 Ratch-~tch ~t~ 3.~37 5.051 ......... ~ 4545.~ " ' 7.~ Haili~n~'"~SR~ ~tr. ~cke~th t~. ad~P~r. 3.~ 5.91 29 [ 455~76 ~.~ 4 1~" 1Z75 l~ft J-55 EUB Mod 8~ Tubing 3.9~ 5.~3 ~ ~12.83 1.55 Hallibun~ "X" ~ofile 3.813 4.7~ .... 27 ~14.~ 275,72 4 1~" 12.75 l~ft J-55 EUB Mod 8~ TuMnR 3.958 ,5.~3 ,,, ~ ~.,!0 1.15 No-Go ~t~ 3.813 4.5~ ......... ~ ~91.~ ,, 12.~ Halli~n~"~"~a~ent~cker . ~,~ ,~.~ ~ 4~3.~ 279.~ 4 1~" 1~75 l~ft TuMng and Blast Jo~ , 3.9~, 5.570~ ~ 5183.~ 4.70 ~ 4 1~ 'XD" Slidi~,Sl~, 3.813 5.570 ~ 51~.~ 1~.~ 4,1~' l~751~ftTuMn~andBlastJoin= 3.9~ 5.570 21 5313.32 4.71 ~ 4 1~ "~" Slid~ Siee~ ......... 3~13 5,570 ~ 5318.~ 31.31 4,1~" 1~75 l~ft J-55 BUB M~ 8~ TuMn~, ,3.9~ ,,, 5.~3 ~9 5~9.~ 10.~ Up~r ~al Bo~ ,. 3.~ 5.~ !8 5~.18 0.55 Ra~h-~tch ~t~ .... 3.~7 5.051 16 5373.~ 72.65 4 1~ ' 1~75 lb/ft TuMn~ and Bias~ Join~ 3.9~ 5~570 ,,, 15 5~5.6~ 4.17 ~ 4 1~" '~" Slid~g Slee~ 3.813 5.570 14 ~9.~ 31.~ 4 1~" 1~75 I~ft J-55 B~ M~ 8~ Tuber 3.9~ 5.~3 13 ~1.!0 14.18 Tpbing ~1Di~r ,, 3.~ 5.~ 12 5495.~ 1.15 Ratch-~tch Lo~t~ 3.937 5.051 11 ~.43 ' l~ Halli~n~ "MH~" ~anent packer , 3.~ 5.~ 10 55~.77 139.51 4 1~" !2,751~ft J-55B~Mod8~TUbi'p~'' '3.9~ 5.~3 9 ~.~ 4~22 ~b 4 1~""~" Slidi~ Slee~ 3.813 ,5~570 8 ~52.~ 31.~ 4 1~' 1~751~ft J-55BUB ModS~TUMnK 3.9~, 5.~3 7 ~3.76 14.18 TuMnR Seal DiH~r 3.~ 5.~ 6 ~.~ L15 Ratch-~tch Lo~t~ 3,~7 5.051 ,,. 5 ~.~ 12.~ Hnll,~bun~ "M~" ~anent ~cker ,. 3.~ 5.~ 4 571L43 1~.03 41~" 12,751b/ft J-55B~ModS~TuMnK '319~ 5.~3 .... 3 ~59.~ 1.61 Halli~ 4 1~ "XN" Nippb 3.7~ 4.~ 2 5~1,~ 31.~ 4 1~" 12.75 I~ft J-55 BU~ Mod 8~ Tub~n~ 3:~ 5~3 1 ~7 0,61 Re-~t~ Guide ~th ~mp ~t Plug 3.9~ 5~70 ~.~ End of Tu~ng ,,. , ~ ,, ' - ~t - ,, PROD~ION PERORATION INTERV~ COOK INL~ SA~S BELUGA S~DS 'O' ~ - 47~ (~UE~ OF~ NOT~: ~1 ~ ~w ~m ~ut off w~, ~6P. ~-2 ~1 - 5161 ~ - ~10 ~-3 5191 - ~11 ~ - ~ 'Mi~ ~ - ~14 Q-4 ~ - ~ 7~ - ~ - ~ 7197 - ~14 ~-5 ~ - ~ 7218 - ~-6 ~ - ~70 7~ - 7~ Q-7 ~ - ~ 7~ - 7~ ~ - ~4 7478 - ~-8 57~ - 57~ 7513 - 7~ 7~ - 7~ . Q- 10 ~7 - ~ ~- 11 ~ - ~ '~w~ 7~ - 7~ 81~ - 81M ~7 - ~14 Well: No~h Cook Inlet Unit No. A-08 J A~sust ~f~n: ~Wer Cook Inlet. Alaska FinN;, ~ook Inlet UQi,~ CIBP 6850' EZSV ~ 7150' 7197 - 7214 '-~ 7216 - 7238 -'~ 7300 - 73~ --~ 7388 - 7~tJ -~ 7478 - 7~ ~ 7513 - 7~ ~ - ~18 81~ - 81~ ~7 - ~14 ~75 - ~ 7" ¢~ 0156' TD = 9.222' ,, PHILLIPS PETROLEUM COMPANY P. O. Box 1967 Houston, Texas 77251-1967 6330 West Loop South Bellaire, Texas 77401 May 05, 1994 North Cook Inlet Unit "A"-8 Phillips Tyonek Platform "A" North Cook Inlet, Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: North Cook Inlet Unit A-8 Workover Program Attached are three copies of the Application for Sundry Approvals, form 10-403, and three copies of the tentative workover program for the workover of the A-08 well on the North Cook Inlet Unit. Included in the program are the BOP schematic and the well control policy for the workover. If you have any questions concerning this workover or need any additional information please contact Paul R. Dean at (713) 669-3502. g Manager A, R. Lyons ~ M. L. Jones (r) F'.'I~. Dean J.F. Mitchell Central files cc: RECEIVED MAY -9 1994 Oil & Gas Cons. Commission /mchorage STATE OF ALASKA '~'~S(ION ALASKA OIL AND GAS CONSERVATION COMMI 'APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well Change approved program __ Operation shutdown __ Re-enter suspended well ~ Plugging __ Time extens,on __ Stimulate ~ Pull tulmng ~ Variance ~ Perforate ~ Other 2. Name of Operator Phillips Petroleum Company 3. Address 6330 W. Loop South, Bellaire, TX 77401 5. Type of Well: Development x__ Exploratory __ Stratigraphic ~ Service ~ 6. Datum elevation (DF or K__B__) 116 ' R_KB feet 4. Location of well at sudace PPCO Tyonek Platform, Leg 3 Slot 2 1256' FNL 1080' FWL Sec. 6 TllN-R9W At top of productive interval "B" Sands 4635' MD 3608' TVD 107' FNL 1055' FEL Sec 1-TllN-R10W At effective depth Same At total depth (PBTD: 6,850' MD; 4,985' TYD) 936' FSL 2,544' FEL Sec 36-T12N-R10W 12. Preser~i well condition summary 7. Unit or Property name North Cook Inlet Unit 8. Well number A-8 9; Por~,~,~~ 10. APl number 50--283-20028 11. Field/Pool Cook Inlet/Beluga Total depth: measured 9,222 feet Plugs(measured) true vertical 6,487 feet Effective depth: measured 4,635 feet Junk (measured) true vertical 3,608 feet Casing Length Size Cemented Structural 345 ' 30" Driven Conductor 16" 587 sx "G" Sudace 10-3/4" 825 sx "G" Intermediate .... Production 7" 1405 sx "G" Liner Perforation depth: measured 4,635' - 6,310' PBTD 6,850 (CIBP) 7,150 (cement retainer w/ 50 sx of cement) Measureddepth ~ueverticaldepth 386' 386' 623' 623' 2,985' 2,603' 9'156' 6,443' truevertica, 3,608' - 4,670' MAY -9 1994 Tubing (size, grade, and measured depth) 3~" . ~ 9 3 lb/ft N-80; J-55 @ 6,385' AJaska Od & Gas Cons. ComlalSs[OI1 Anchorage Packers and SSSV (type and measured depth) Otis "RH" @ 4595; Baker F-1 @ 4,913; Baker F-1 @ 5,509'; Baker F-1 @ 5~962'; Otis AO SSSV (WLR) @ 267'. 131 AttachmentJ Description summary of proposal .._x Detailed operations program __ BOP sketch ._x. 14. Estimated date for commencing operation ~ 15. June 1, 1994 16. If proposal was verbally approved Oil __ Gas ._X .-Name of approver__ ~ Date approved Service 17. ~'hereby~ert~e for~'goir]g is/tr.u~'and correct to the best of my knowledge. k /~/~/~)/ [ ~._ Drilling & ProdUction Sig~f ~// ~ Title En ]_neer3.n' ' Manager Co~tions of approval: No~11~Comrnission so re.~13resentative may witness //Plug integrity __ BOP Test ~ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10- ~ 7 Status of well classification as: Suspended __ Date May 3, 1994 I Approva' Approved by order of the Commission Form 10-403 Rev 06/15/88 Original Signed By David W. Johnston nnrnvmd ~n~{~mmissi°ner Returned SUBMIT IN TRIPLICATE May 5, 1994 Houston, Texas North Cook Inlet Unit "A"-8 North Cook Inlet Unit Tyonek County, Alaska Tentative Procedure le · · · Se ® · · · 10. Skid rig over No. 8 slot in Leg 3. Kill well with 9.0 lb/gal KCl water / XanVis polymer. Fill tubing and annulus with 2 % kcl water. Bleed off pressures and monitor same. Close SSSV. Install BPV, remove XMAS tree, NU and test 13 5/8" 10M BOP equipment. Utilize a 16 3/4" 5M x 13 5/8" 10M DSA (FMC Unihead with 16 3/4" 5M BX Clamp Hub). Test the BOP equipment as per the attached "Well Control" program. Rig up to pull tubing. Release Otis "RH" packer (4,595') along with Baker seal assembly from the Baker Model "F-i" packer at 4,913'. Pull 4 1/2" tubing, SSSV and retrievable packer with tailpipe. All tubing should come in one piece unless sanded in place. TIH with Baker packer milling assembly (Baker Model CJ or equivalent) on 3 1/2" drillpipe and drilling BHA. Mill over packer slips and recover Baker "F-i" permanent packer. POOH. Repeat Step No. 4 for the additional two Model "F-i" packers remaining in the well. TIH with 6 1/8" bit and casing scraper for 7 "23 and 26 lb/ft casing. Clean out casing to PBTD of 6850'. Circulate hole clean and POOH. TIH with retrievable bridge plug and packer. Set RBP at 4,800' and test to 2,000 psi. Pull packer uphole to 4,500', set same and test annulus to 2,000 psi. POOH with packer. TIH with open ended drill pipe and spot 150 sx cement from 4,750 - 4,100'. Pull drill string above cement and squeeze Cook Inlet "B" perfs (4,635 - 4,735'). POOH with drill string. WOC 8 hours minimum. TIH with bit and drill out cement. Test perforated interval to 2000 psi. Resqueeze as necessarY. When squeeze is obtained, TIH to PBTD and circulate hole clean. POOH. Make up and TIH with tubing conveyed perforating assembly to reperforate the existing Beluga and Cook Inlet Sands as follows: 4979' - 5036' 5061' - 5161' 5191' - 5211' 5240' - 5250' 5266' - 5283' 5288' - 5325' 5388' - 5438' 5563' - 5570' 5580' - 5596' - RECEIVED 5743' - 5753' 5837' - 5845' 5855' - 5885' MAY,-9 1994 6008' - 6022' Ma$~Oil&GasOon$.~mmi~ion 6302' - 6310' ~nehora~e 11. Use Ga~ima Ray log to correlate guns on depth. Set packer and pressure up on tubing with nitrogen to fire guns. 12. Unload well and flow for initial clean-up. 13. Kill well and POOH with perforating assembly. 14. TIH with bit and scraper and clean out well to PBTD. Circulate out gas until well is stable. 15. TIH with Halliburton 7" permanent packer with 4 1/2" tailpipe equipped as per the proposed wellbore schematic. Set packer at 4,900' with sliding sleeves at 5,200' and 5,900'. 16. Make up and TIH with 4 1/2" tubing and isolation packer. Set "VSR" isolation packer at 4,550' as per the attached schematic. 17. Make up Halliburton packer seal assembly onto the 4 1/2" tubing. TIH with 7" tubing and SCSSV landing nipple. Land seal assembly into isolation packer. Test annulus, then pull out of seal assembly and circulate 70/30 methanol / KCl packer fluid into annulus. Space out tubing. 18. Close SCSSV, install BPV, ND BOP equipment and NU and test 7 1/16" x 4 1/2" Xmas Tree. Remove BPV's. 19. Use coiled tubing (if necessary) and nitrogen to lower fluid level and get well kicked off. Unload well and allow clean up through the production testing equipment. Release workover rig to next well. NOTE: BHP at 3608 TVD is approx 1400 psi (7.8 lb/gal equivalent), somewhat less than the 9.0 lb/gal equivalent which will be used to kill the well during the recompletion phase. RECEIVED MAY - 9 1994 Alaska Oil & Gas Cons. Commission Anchorage SECTION A WELL CONTROL PROCEDURES This well is a category 3 well, as defined in Phillips Completion Workover and Well Control Policy. As such two barriers must be in place during nipple up and nipple down operations. For all other operations two barriers, e.g. the BOP's, fluid column, etc. must be in place in order to conduct simultaneous operations. The BOP equipment is 10000 psi WP Class 4 as per Phillips Well Control manual. The bottom set of rams should be 5" pipe rams, the middle set will be blind rams and the top set should be variable rams. Although the BOP is rated to 10000 psi, the riser and the wellhead are rated to 5000 psi. The BOP and choke manifold should be stump tested to 3000 psi. The BOP should be tested to 3000 psi upon nipple up and to 1500 psi on a weekly basis. The Alaska Oil and Gas Conservation Commission (AOGCC) should be notified prior to conducting BOP tests. The notification to AOGCC should be made early enough for them to witness the test if they desire. The maximum surface pressure for the well is 1071 psi. This pressure was obtained during the welltest of February 10, 1994. The well can be killed and stability maintained with 9.0 lb/gal fluid. Well control drills are to be conducted with each. crew as per Phillips well control manual. Drills should be reported on the IADC daily drilling report and on Phillips Daily Drilling Report. This well produces from a series of very permeable sands. A small decrease in pressure at the perforations can result in very large flowrates. It is vital that good well control practices be followed during the course of this workover. Trip speed while POOH should be kept relatively slow to avoid any tendency to swab. Before any trip is made swab and surge calculations should be made based on the properties of the fluid in the hole. DO NOT exceed the running speed determined by the calculations. A detailed trip book comparing measured fill up requirements to the calculated requirements should be maintained for each trip. The cause for any discrepency between the actual and required fill up volume must be determined before continuing with the trip. MAINTAINING CONTROL OF THE WELL IS OF THE UPMOST IMPORTANCE, TRIP SPEED IS SECONDARY. Ail of the zones presently perforated in this well can be killed with water. As a precautionary measure, a line should be ran from the annulus valves on the tubing head to supply workover fluid, drillwater, or seawater. This line can be used to supply workover fluid as discussed above or as a last resort can be used to kill the well with drillwater or seawater. Pumping drillwater or seawater through the annulus valves should be considered only in an emergency situation as these fluids could result in formation damage. RECEIVED MAY -9 1994 A~;~ska Oil & Gas Cons. Commission Anchorage NCIU A-~ RISER AND BOP ARRANGEMENT ANNULAR PREVENTER '1 I ~ 1OM VARIABLE BORE PIPE RAMS 1OM BLIND RAMS DRILLING SPOOL 3 1/2' 1OM PIPE RAMS RISER 13 5/8' 1OM X 13 5/8' 6M ADAPTER 13 6/8' 6M X 16 3/4' 6M CLAMP RISER 16 3/4' 6M X 16 3/4' 6M UNIHEAD 16' 8RD X 16 3/4' eM CLAMP HUB RECEIVED MAY - 9 1994 A~ska Oil & Gas Cons. Commission Anchorage ~ . EXISTING WELL COMPLETION DI/r~-RAM RKB-Dnll Deck: ~ /(Make,'r~pe,OD) FMC OCT 8rd X 4 1/2" BT~ RKB-THF 39.40 26 'll~Hgr.(Make,~) FMC 6" 3M 4 l 25 Annulus Fluid: 9.0 lb/gal fresh water mud (gel + barite) RKB-SL: 116.00 381 TOC: 3010' fa'om CBL dated ..~.../~23/..69. WATER DEFTH: 120 RKB-ML: 1990 30" 41 386 TOC @ 1945 16" 41 623 65 lb/ft H-40 EF&C 1540 600 293 10 3/4" 41 2~985 455 & 51 lb/fl J-55 BT&C 3350 1970 531 7" 39 9~156 23 & 26 lb/ft J-55 BT&C 4080 3080 288 labial[ St~b 3 1/2" 39 975 9_3 lb/ft N-80 BT&C 7950 9160 3 1/2" 975 6r385 9_3 lb/ft J-55 BT&C 5700 6440 PRODUCTION TUBING STRING 29 0.00 38.66 Elevation "xo" 28 38.66 0.33 FMC ! OCT 6" 3M 4 1/2" 8rd x 4" BT&C Tubing l-lan 3.958 6.000 27 38.99 030 X-Over 4"BT&Cx3 I/2"BT&C 26 39.49 227.94 3 1/2" 9.3 lb/fi N-80 BT&C Tubing 2.992 4.500 25 267.43 4-52 Otis 3 1/2" SCSSV {Type DKS) 2.992 4-520 24 271.95 703.32 3 1/2" 9.3 lb/ft N-80 BT&C Tubing 2.992 4-500 ot~ nH packer 23 97527 358630 3 1/'2" 9.3 lb/ft J-55 BT&C Tubing 2.992 4-500 ll @ 4s~s, 22 4561.77 3.08 otis 31/2""x0" Sliding Sleeve ~"'/,A" a~ 20 4594.78 4.54 Otis "RI-I" Hydraulic Set Retrievable Packer ~*~ 21 4564.85 29.93 3 1/2" 9-3 lb/ft J-55 BT&C Tubing 2.992 4.500 i _~ ~ ,mas - 4735 19 4599.32 186.56 3 1/2" 93 lb/ft J-55 BT&C Tubing + Blast Joints 2.992 4.500 "~________ 18 4785.88 3.08 Otis4l/2""XA"Sliding Sleeve /' ll__l i Baker F-I packer 17 4788.96 123.67 3 1/2" 9.3 Ib/ft J-55 BT&C Tubing 2.992 4.500 ~ @ 4913' 16 4912.63 0.00 Baker Seal Assembly : i 15 4912.63 8.51 Baker "F-l" packer assembly ~ ¢ookln~t Sand, 14 4921.14 563.87 3 lf2" 93 lb/ft J-55 BT&C Tubing + Blast Joints 2.992 4-500 i__ -~ 4879 - 5038 13 5485.01 2.67 Otis 3 1/2""XA" Sliding Sleeve · xA' ~ 8381-8181 12 5487.68 20.98 31/2" 9.31b/ft J-55BT&CTubing 2.992 4.500 -~ 5191 - 5211 11 5508.66 923 Baker "F-l" packer assembly ~ s~4o- 825o 10 5517.89 410.90 3 1/2" 9.3 lb/ft J-55 BT&C Tubing 2.992 4.500 ~ ~- 52aa 9 5928.79 2.67 Otis 3 1/2""XA" Sliding Sleeve ~ 52a~- 5328 8 5931.46 30.77 3 1/2" 9.3 lb/ft J.55 BT&C Tubing 2.992 4.500 ~ mans- 5438 7 5962.23 10.06 Baker "F-l"packer assembly - [ 6 597229 28.71 31/2" 9.3,1b/ft J-55BT&CTubing 2.992 4.500 ll lli @ 8539' 4 6003.67 348.97 3 1/2" 93 lb/ft J-55 BT&C Tubing + Blast Joints 2.992 4.500 I 3 6352.64 0.81 Otis 3 1/2""XN" Nipple' 2.992 3:500 I ~ 8583 - 5570 2 6353.45 30.67 3 1/2" 9.3 lb/ft J-55 BT&C Tubing 2.992 4.500 I ~ sss@- ss~ 1 6384.12 0.98 Mule Shoe Guide ~ -~. ~- 8524 6385.10 End of Tubing ~ 5743- 5753 ~ 5837 - 5845 ~l~[ Baker F-1 packer · -@ 8962' ~ ~o;- 531o ,~aQlen (iii R, Rna ~nne Rnmmleelnn ,~<N,, -~[ ................................... ;i Anchorage ,:,:.::,:...,:,:.~..,.:._:,>_>.= ! PRODUCTION PERFORATION INTERVALS ~~[~[;:i~'%~;;~'~i ClBP ~50' COOK INLET SAND BELUGA SAND ~ 7030- 7067 'n' 4~6- 4735 'Ur~ar' 6005- 50~ ~ ] 5302- 5310 ,l ! C1-1 4979 - 5038' NOTE: All perfa below are shut off with ClBP. ~i!f!:":.~!~;~ .:,~,~' i CI-2 5061 - 5101' 'Middle' 7030- 7067 lillll~ i CIBP 7150' Cl-3 5191 - 52tl 7197- 7214 I i 5240- 5250 7218- 7238 I [ Cl-4 5266- 5283 7309- 7326 ~ 7197- 7214 5288- 5325 7388- 7398 ~ 7218 - 7238 Cl-5 5388- 5438 7478 - 7488 ~ 7388 - 7398 Cl-7 5580-55~~'~ 7583 - 7598 ~ 7478- 7488 5600- 5624 ~ 7513 - 7538 Cl-8 5743- 5753 'Lower' 7822 - 7528 ~.. 7583 - 7598 8008 - 8018 C1-10 5837- 584~ 8180 - 8185 7822 - 7828 C1-11 5855- 5885 8307 - 8314 ~ 8008 - 8018 8375 - 8425 ~ 8180 - 8185 ~ 8307 - 8314 ~ 8375 - 8425 ~ 7" @ ~15~' PBTD: 6,850' ISup~ ITbgWt: 31/2" - 9.31b/ft Well: North ~oolr I~l~t IJ~it No. A-08 I April 29, 1994 TD = Location: Alaska Field: Cook Inlet Unit ' ~ .... [' PROPOSED WELL COMPLETIO~r DIAGRAM 1 $ Tbg. Hgr.(Make. T~pe) FMC 6" 3M 4 1/2" 8rd X 4 1/2" BT&C RKB-THF 39.40 14 Annulus Fluid: 70 / 30 Methanol / 2 96 KCI Completion Fluid RKB-SL: 116.00 381 TOC: 3010' from CBL dated 07/23/69 WATER DEPTH: 120 RKB-ML: Prodnction Casing: I ~ ~9o 30- 41 TOC @ 1 945 16" 41 623 65 lb/ft H-40 ST&C 1540 600 293 10 3/4" 41 2,985 45.5 & 51 lb/fl J-55 BT&C 3350 1970 531 7" 39 9,156 23 & 26 Ib/ft J-55 BT&C 4080 3080 288 Fubing Strfi ig: 4 1/2" 39 400 12.60 lb/ft L-80 Mod BT&C 6600 6530 135 3 1/2" 400 6,320 12.75 Ib/ft J-55 Mod 8rd 4730 4980 134 PRODUCTION TUBING STRING 'X' i Hallibu~n 17 0.00 38.66 Elevation 2.992 4.500 ~ i '~' sands 16 38.66 0.34 FMC / OCT 6" 3M 4 1/2" 8rd x 4 1/2" Mod BT&C Tu bing Hanger I (4~5 -- 4735 15 39.00 361.00 4 1/2" 12.60 Ib/ft L-80 Mod BT&C Tubing 2.992 4.500 ~ ~ [ Squ~zedO~0 14 400.00 3.00 Otis4 1/2" SCSSV Landing Nipple I i Permanent Pa~ker 13 403.00 3.00 X-Over 4 1/2" BT&C x 4 1/2" EUE 8rd Mod 2.992 4.500 ; @4900~ 12 406.00 4113.00 41/2" 12.751b/ft J-55EUEMod8rdTubing _ i 11 4519.00 1.00 Otis "X" Profile ~.~ Cook lnle~ Sands 10 4520.00 30.00 4 1/2" 12.75 lb/ft J-55 EUE Mod 8rd Tubing 2.992 4.500 ~ 4979 - s035 9 4550.00 10.00 Halliburton VSR packer with seal bore extension ~ 50~1 - 51el 8 4560.00 340.00 4 1/2" 12.75 lb/ft J-55 EUE Mod 8rd Tubing 2.992 4.500 I~ ~ 5191 - 5211 7 4900.00 10.00 Halliburton permanent packer with seal bore extensio~ 'XD' ~ ~ - ~ 6 ! 4910.00 290.00 4 1/2" 12.75 lb/ft J-55 EUE Mod 8rd Tubing 2.992 4.500 ~ ~ - ~ 5 5200.00 3.00 Otis 4 1/2" "XD" Sliding. Sleeve ~ ~ - ~ 4 5203.00 697;00 4 1/2" 12.75 lb/ft J-55 EUE Mod Srd Tubing 2.992 4.500 ~ ~ - ~ 3 5900.00 3.00 Otis 4 1/2" "XA" Sliding Sleeve ~ ~a - 5570 2 5903.00 416.00 4 1/2" 12.75 lb/ft J-55 EUE Mod 8rd Tubing 2.992 4.500 ~ ~ - ~ 1 6319.00 1.00 Otis 4 1/2" "XN" Nipple --~ 5500 - 55n4 6320~00 End of Tubing ~ 5837 - 5845~- __ __ ' - '~x ~ 'XA" Sliding Sleeve Beluga Sands ; coos - s022 At~gka flil ,R, Rn~ r,,,.. ,., ..... ....... w.o. OUllll/ll$$10 I ~ ~ - ~310 i PRODUCTION PERFORATION INTERVALS ~ ¢1~ 0550' COOK INLET SANDS BELUGA SAND ~ 7030 -- 7067 'B" 4635 - 4735 (SQUEEZED OFF) "Upper' 600~ - j 630~ - 6;310 ~ el- 1 4979 - 5036 NOTE: All perf~ below are shut off with ClBP, ~~:~~ Cl-2 5061 - 5161 "Middle' 70~0 - 7067 ~.~~§ EZSV(~ 7150' Cl-3 5191 - 5211 7197 - 7214 5240 - 7218 - 7238 ,+:+~+:,~.~,,.~..,~,~w~,~.~_.~.;~ ~ 7197 -- 7214 5288 - 5,.'.'.'.'.'.'.'.'.~ 7388 - 7398 ~.:~:.:.:.:<,:;:~<+:~ ~ 7218- 7238 CI-5 5.388 - 5438 7478 - 7488 ~ ~ - 7326 Cl-6 5563 - 5570 7513 - 7,5.38 ~ 7388 - 7396 CI-7 5580 - 5596 7583 - 7596 ~ 7478- 7488 5600- 5624 ~ 7513 - 75.38 CI-8 5743 - 5753 "Lower' 7822 - 7828 ~ 7583 - 759~ 8006 - 5018 C1-10 5837 - 5845 8180 - 8155 7822 - ~ C1-11 5855 - 5885 8307 - 8,314 ~ 8180 - 8185 ~ 8307 - 8314 ~'rD 9103, ~ 7" @ 9~ 56' PBTD: 6~850' ] Supv: [ Tbg Wt: 4 1/2" - 12.60 & 12.75 lb/ft Well: North Cook Inlet Unit No. A-08 I May 02, 1994 TD = 222' Location: Lower Cook Inlet Field: Cook Inlet Unit PRD PHILLIPS PETROLEUM COMPANY ANCHORAGE, ALASKA 99503 2525 C ST., CIRI BLDG., SUITE 508 PHONE: 907 279-0606 TELEX: 090 26555 EXPLORATION AND PRODUCTION GROUP Anchorage Area August 8, 1983 File: A-JFS-252-83 CERTIFIED #P200 299 268 RETURN RECEIPT REQUESTED Mr. C. V. Chatterton, Director Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: NORTH COOK INLET UNIT WELL #A-8 Attached in duplicate are the following final reports for the subject well workover of which was completed 8/4/83: 1. Sundry Notice Form 10-403. 2. Monthly~ort of ... Workover Operations Form 10'404. ,, · Settle .~--~ Area Manager JFS/NEP:kd Attachments cc: W/attach NICU A-8 well file Gas Cons. Asc,horag9 j STATE OF ALASKA ~ ALASK~( Il AND GAS CONSERVATION ,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator Phillips Petroleum Company 3. Address 2525 C Street, Suite 508, Anchorage, Alaska 99503 4. Location of Well THL - Platform 'A', Leg 3, Slot 2 - 1256' FNL & 1080 FWL Sec 6-11N-9W, SM 5. Elevation in feet (indicate KB, DF, etc.) RKB is +100' MSL 6. Lease Designation and Serial No. ADL 37831 7. Permit No. 8. APl Number 50-- 883--20028--00 9. Unit or Lease Name North Cook Inlet 10. Well Number A-8 11. Field and Pool North Cook Inlet 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). From 7/06-13/83, rigged.up. From 7/13/83 to 8/4/83, worked over well. PBTD 6850 MD RKB. During clean out, discovered parted casing below 7182' RKB. Set cement retainer at 7150' RKB and pumped 50 sacks of neat cement below. ~_~...~.~.~p.S,T,,.~i.~.~Bel~gaforma~,%on. P~ring DS%.. #!.,.we!,lfl0wed lp~s. of,.,p~d. ~e~...~.~d_g~_p~_B&,,.,~.,~.~.~. Perf'd Cook Inlet pay sands. Ran 3½ completion string with accessories using 3 permanent packers and one retrievable packer to separate the pay intervals so wireline techniques can be used to- isolate water entry when it occurs. 'Tubing was set at 6375' RKB. PaCkers were set at 5960', 5505,, 4904' & 4585' RKB. SS are at 5919', 5475' & 4776' RKB. SSSV at 267' RKB. Workover complete at 1600 hrs 8/4/83. Final report. ~ uu- a 1983 Ar!r;h0rage 14. i here lng is true and correct to the best of my knowledge. i Sign J.F. Settle Title Area Manager o~ for Commissio~use Date 8/8/83 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate '"' STATE OF ALASKA ~ 0 "' ALASKA~ L AND GAS CONSERVATION C( .MISSION ~. ?~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONSi 1. Drilling well [] Workover operation ~ 2. Name of operator 7. Permit No. Phillips Petroleum Company 3. Address 8. APl Number 2525 C Street, Suite 508, Anchorage, Alaska 99503 50- 883-20028-00 9. Unit or Lease Name North Cook Inlet 4. Location of Well at surface Platform A, Leg 3, Slot 2, - 1256' FNL & 1080 FWL Sec 6-11N-9W, SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB is +100" MSL I ADL 37831 10. Well No. A-8 11. Field and Pool North Cook Inlet For the Month of August ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks PBTD 6850'. On 8/1/83, set permanent BP at 6850' RKB. From 8/1-4/83, set Baker Model F-1 permanent packers at 5960, 5505 & 4904' using electric line. Ran 3½ completion string, set at 6375'. SSSV set at 267' RKB. Nipple down BOPE/riser. Nipple up tree. Test same to 3000 psi. Workover complete 1600 hours, 8/4/83. Final report. 13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description 15. Logs run and depth where run 16. DST data, perforating data, shows of H2S, miscellaneous data 17. I hot ro~oin~ is true and correct to tho best of mg knowledge. SlG~~~~/J. F. Settle TITLE Area Manage[ i . DATE 8/8/83 TE--Reporton this for~is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Rev. 7-1-80 Submit in duplicate PHILLIPS PETi~OL~:UM COiV'iP/~N'¥' ANCHORAGE, ALASKA 99503 2525 C ST., CIRI BLDG., SUITE 508 PHONE: 907 279-0606 TELEX: 090 26555 EXPLORATION AND PRODUCTION GROUP Anchorage Area August 5, 1983 File: A-JFS-250-83 CERTIFIED #P 200 299 266 RETURN RECEIPT REQUESTED Mr. C. V. Chatterton, Director Alaska Oil & Gas .Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: NORTH COOK INLET UNITS WELLS~8~''& A-il Attached in duplicate is Form 10-404 (Monthly Report .. o of Workover Operations") for each of the subject wells for the month of JulY, 1983. Area Manager JFS/NEP: kd Attach cc: Well files W/attach NCIU A-8 NCIU A-ii :5~ A~b OF ALASKA '~ ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY REPOR1 DRILLING AND WO( XOVER OPERATIONS · Drilling well [] Workover operation 2. Name of operator Phillips Petroleum Company Address 2525 C Street, Suite 508, Anchorage, Alaska 99503 Location of Well at surface Platform 'A' Leg 3, Plot 2 - 1256' FNL & 1080 FWR Sec 6-11N-9W, SM. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. ADL 37831 RKB is +100' MSt 7. Permit No. 8. APl Number so- 883-20028-00 9. Unit or Lease Name North Cook Inlet 10. Well No. A-8 11. Field and Pool North Cook Inlet For the Month of_ July ,19 83 Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks PTD 7150' RKB. From 7/6-13/83, rig up. From 7/13-16/83, kill well, Nipple down tree, nipple uP BOPE and pull tubing. From 7/16-20/83, clean out to 7350' RKB. Ran logs .(see below). Indications were 7" casing parted below 7182' RKB. Set cement retainer at 7150' RKB and pumped 50 sacks of cement below. From 7/21-30/83, ran 4 DSTs. 7/30-3f/83, Perf Cook Inlet pay 5889 back to 4642' overall (14 intervals - listed on back)~ 13. Casing or liner run and quantities of cement~ results of pressure tests ~ 14. Coring resume and brief description 15. Logs run and depth where run DIL From 7302 back to 6500' PAL From 7186 back to 6650' CNL-FDC from 7000 back to 4000' AUG - 8 !983 Anchorage. 16. DST data, perforating data, shows of H2S, miscellaneous data DST # PERFS DURATION GAS RATE FTP LIQUID RATE 1 7030-7067 11 hours 10.8 mmcfd 450 ps--~g 0 BPD 2 6902-6912 3 hours 0 0 0 3 6302-6010 18 hours 8.1 mmcfd 500 psig 15 BPD 4 6008-6022 11 hours 9.3 mmcfd 600 psig l0 'BPD LIQUID PRODUCED Filled lines & sep.w/s~ Nothing Mud, filtrate, SW? Mud, filtrate, SW? 17. I hereby~ the foregoing is true and correct to the best of my knowledge: .,'~"~,.~" / J. F. Settle TITLE__~ DATE_ 8/5/83 SIOlk[f~3 '"'--- ' TE-- eport on this f rm is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the/~,laska /~~ervatil;~ Commission by the 15th of the succeeding month unless otherwise directed. Form 10-404 Rev. 7-1-80 Submit in duplicate DIL DEPTH FROM RKB COOK INLET PERFO~'~"~-~Nc 4642-4742 4984-5041~ 5066-5166~ 5196-5216 5245-5255 5271-5288~ 5293-5330 5392-5442~ 5567-5574~ 5584-5600 5604-5628~ 5747-5757~ 5841-5849 5859-5889~ STATE OF ALASKA ALASK.~II ~ll AND GAS CONSERVATION ~'.... MMISSION SUNDRY NOTICES AND REPORi ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Phillips Petroleum Company 3. Address 8. APl Number 2525 C Street, Suite 508, Anchorage, Alaska 99503 50- 883-20028-00 4. Location of Well THL - Platform 'A', Leg 3, Slot 2 - 1256 FNL & 1080 FWL Sec 6-11N-9W, SM BHL - 1223 FWL & 1711 FSL, Sec 36-12N-10W, SM 5. Elevation in feet (indicate KB, DF, etc.) RKB is +100 MSL 12. I 6 . Lease Designation and Serial No. · AD 37831 9. Unit or Lease Name North Cook Inlet 10. Well Number A-8 11. Field and Pool North Cook Inlet Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Set Baker Model 'N' cast iron bridge plug on electric line at 6850' RKB at 0300 hours 8/2/83. This blanks off Beluga perfs 7030'-7067' and 6902'-6912' RKB 14. I hereb that the oing is true and correct to the best of my knowledge. I Sign/n~.. ~:~~~.v~, j._ J.F. Settle Title Area Manager sp e be,ow for use h~nsof Approvaq, if any: Approved by. Date 8/5/83 By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1430 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASK IL AND GAS CONSERVATION MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Phillips Petroleum Company 3. Address 8. APl Number 2525 C Street, Suite 508, Anchorage, Alaska 99503 50- 883-20028-00 4. Location of Well THL - Platform 'A', Leg 3, Slot 2 - 1256 FNL & 1080 FWL Sec 6-11N-9W, SM BHL - 1223 FWL & 1711 FSL, Sec 36-12N-10W, SM 5. Elevation in feet (indicate KB, DF, etc.) RKB is +100' MSL 12. I 6. Lease Designation and Serial No. AD 37831 9. Unit or Lease Name North Cook Inlet 10. Well Number A-8 11. Field and Pool North Cook Inlet Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We propose setting a bridge plug in the 7" casing at 6850' RKB to abandon old Beluga perfs 7030-7067 and~new~Beluga..per~.,6902-6912. DST of 7030'-7067'RKB (DIL Log) indicate well producing lots of sand. DST of 6902'-6912' indicate not productive. Also clean out following testing indicate casing collapse or parting below 7033' RKB. Verbal approval to blank off casing was given by Mr. Jim Trimble to Neal Porter on 8/1/83. Subsequent ~Vork Reported Alaska 0il & Gas Cons, Co~nmiSSior~ o~ Form lqo. ~,,. ':~- Dated ~ ---/~ Anchorage ~ 14. [ hereby ~t~that the foregoing is true and correct to the best of my knowledge. ~ Sig,~~ ~~ ~. F. Settle Title Area Manager Date 8/5/83 /~Gonditions of Approval~if Approved Copy Returned Approved by ill LQNNIE C. SIITll By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate PHILLIPS PETROLEUM COMPANY ANCHORAGE, ALASKA 99503 2525 C ST,, CIRI BLDG,, SUITE 508 PHONE: 907 279-0606 TELEX: 090 26555 EXPLORATION AND PRODUCTION GROUP Anchorage Area July 26, 1983 File: A-JFS-240-83 Mr. C. V. Chatterton, Director Alaska Oil & 'Gas Conservation CommisSion, 3001~Porcupine Drive Anchorage, Alaska 99501 RE: NORTH COOK INLET UNIT WELL' #A-8. Attached:is 'subsequentSundryNotice (Form 10-403)Outlining the work'Performed on the subject well. ettle ~Area Manager JFS/NEP:kd Attachment induplicate cc: NCIU A-8 well file w/attach JUL 2 7 1983 Alaska Oil & Gas Cons. Commissfon Anchorage ('- STATE OF ALASKA ALASK/~ iL AND GAS CONSERVATION ~ .AMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE L L :1~:: OTHER [] 2. Name of Operator Phillips Petroleum Company 3. Address 2525 C Street, Suite 508, Anchorage, Alaska 99503 4. Location of Well THL - Platform A, Leg 3, Slot 2, 1256' FNL & 10B0 FWL Sec 6 - liN - 9W, SM BHL - 1223' FWL & 1711' FSL, Sec 36 - 12N - i0W, SM 5. Elevation in feet (indicate KB, DF, etc.) RKB is +100' MSL 6. Lease Designation and Serial No. ADL 37831 12. 7. Permit No. 8. APl Number 50-- 883--20028--00 9. Unit or Lease Name North Cook Inlet 10. Well Number A-8 11. Field and Pool North Cook Inlet Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Set Baker Model K cement retainer on wireline at 7150' RKB. GIH with 3½ DP and stung into retainer. Pump in test at 2.5 bpm at 1700 psi. Unstung from retainer. Mixed 50 sx of 15.8. ppg neat 'G' cement in fresh water and spot at bottom of DP. Stung back into retainer. Displace cement at 1.75 bpm at 1900 psi. Unstung from retainer. Reverse out. Recover cement contaminated mud but no cement. Job complete 0600 hours 7/23/83. This action ~laBks off ~e__lu~a 'B_~perfs from 7197-8425' RKB overall following discovery ox parted casing at 7182 RKB. RECEIVED JUL 2 Signe,~'~ ~ ,~' ,4,~,, · . Settle Title Area Manager T,h,~sp~e below for Commission use I Cbj3d'itions of Approval, if any: Alaska Oil & Gas Cons, Commission ,Anchorage Date 7/26/83 By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate PHILLIPS PETROLEUM COMPANY ANCHORAGE, ALASKA 99503 2525 C ST., CIRI BLDG., SUITE 508 PHONE: 907 279-0606 TELEX: 090 26555 EXPLORATION AND PRODUCTION GROUP Anchorage Area July 22, 1983 File: A-JFS-234-83 CERTIFIED #P13 1753595 RETURN RECEIPT REQUESTED Mr. C. V. Chatterton, Director Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: SUNDRY NOTICE FOR NCIU WELL A-8 Attached is Form 10-403. confirming our verbal request to change workoVer plans on the subject well. Verbal approval to proceed ~as outlined~ was received' from Mr. Blair wondzell on 7/21/83. JFS/NEP: kd Attachment in triplicate cc: NCIU A-8 well file with attach STATE OF ALASKA ALASK~:"'IL AND GAS CONSERVATION/.G~'MMISSION SUNDRY?OTICES AND REPORI,., ON WELLS DRILLING WELL[] COMPLETED WELL~ ; ~/TH~ 7. Permit No. 50 - 883-20028-00 9. Unit or Lease Name 2. Name of Operator Phillips Petroleum Company 3. Address 2525 C. Street, Suite 508, Anchorage, Alaska 99503 4. Location of Well THL - Platform 'A', Leg 3, Slot 2, 1256' FNL & 1080' FWL North Cook Inlet Sec 6 - liN - 9W, SM 10. WellNumber BHL - 1223' FWL & 1711' FSL, Sec 36 - 12N - IOW, SM A.-8 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB is + 100' MSL I ADL 37831 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data _ NOTICE OF INTENTION TO: - SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 11. Field and Pool North Cook Inlet' [] [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We propose to alter the workover plans previously approved by AO/GCC as follows: Instead of cleaning out to the original PBTD of 9103' RKB, we would like approval to set a cement retainer about 7160' RKB and pump 50-100 sx of neat cement, through it and abandon the 12 Beluga 'B' perforated intervals below (7197'-8425' overall). The current Beluga B perfs at 7030-7067~ RKB would be retained. We also will select Beluga A and Cook Inlet sands and complete as a commingled producer as dictated by log analyses and DST.results as stated in our original workover plans. Verbal approval to blank off was given by Mr. Blair W0ndzel% to Neal Porter on 7/21/83. Following is brief well history required by Mr. Wondzell at that time. The reason for blanking off below 7160' RKB is it appears 'the~7" casing is parted below 7182' RKB. During the clean out to 7350, we noted the presence of iron and clay in the mud. When bit was pulled, it was worn out and drill Collars were scratched their entire length. A junk basket was r.'un and small pieces of what we believe to be casing were recovered. The upper limit of the D.C. scratches indicated the casing part would be at 7182' RKB. This depth tends to correlate to the 7185' depth where the original drilled hole was side tracked back in 1969 (A fish was left in original hole from 8421 back to 7329' RKB following unsuccessful fishing attempt.)' The side track hole was drilled to 9222' RKB, 7" set at 9156' and cemented in two stages with stage collar at 6032' RKB. SubSequent Work Reported CONTINUED ON BACK OF SHEET on Form No./::'>" 4//1 ~'> ¢~' / r.~'/>" > ..... '-D~ted . ~' / "'L--I r~ ....... 14. I her d cor[ect to the best of my knowledge. :: , > ,~ Signed ~ ~'~/ ~ J. F. Settle Title Area Manager Date 7/22/83 The sj;~'below for Commission use J ~i~ons of Approval, if any: Approved Copy ]~eturned By Order of Approved by BY LtlHNIE C.SiVIITil COMMISSIONER the Commission Date __ 7-- A 7--o°3 Form 10-403 Rev. 7-1430 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate After perforating the Beluga B sands, mentioned earlier, 4" tubing and retrievable packer were set at 4307' RKB. This setting was selected because at that time it was planned to perf additional Cook Inlet and Beluga pay with thru-tubing guns following production evaluation of the Beluga B sand perfs. This was never done. In July, 1974, pressure was noted in the tubing/casing annulus. The AO/GCC gave approval to leave the well SI pending a workover because the pressure conditions were safely below the burst strength of the casing. The well was shut-in at that time and has not produced since. PHILLIPS PETROLEUM COMPANY ANCHORAGE, ALASKA 99503 2525 C ST., CIRI BLDG., SUITE 508 PHONE: 907 279-0606 TELEX: 090 26555 EXPLORATION AND PRODUCTION GROUP Anchorage Area April 12, 1983 File: A-JFS-138-83 CERTIFIED P13 1753584 RETURN RECEIPT REQUESTED Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Form 10-403 for NCIU Wells No. A-8 & 'A-11 Attached. in triplicate are "Sundry'Notices" indicating our proposed plans to workoVer the subject wells to improve their deliverability. If you have any questions, please call Neal Porter or myself at ~279-0606. JFS/NEP:mm Attachments RE£EIVED APR 1 4 1983 Alaska Oil & Gas Cons. C~n.missMn Anchorage ALASK ' IL AND GAS CONSERVATION MISSION SUNDRY NO ICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL APR i 2. Name of Operator Phillips Petroleum Co~t~0it & Gas C0,fis, 3. Address Anchorage 2525 'C' Street, Suite 508, Anchorage, AK 99503 4. Location of Well THL - Platform 'A', Leg 3, Slot 2, 1256' FNL 7 1080' FWL Sec 6-TllN-R9W, SM BHL - 1223' FWL & 1711' FSL, Sec 36-T12N-R10W, SM I 6 . Lease Designation and Serial No. ADL 37831 5. Elevation in feet (indicate KB, DF, etc.) RKB is + 100' MSL 7. Permit No. 8. APl Number 50- 883-20028-00 9. Unit or Lease Name OTHER [] 12. North Cook Inlet 10. Well Number A-8 11. Field and Pool North Cook Inlet Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate i-~ Alter Casing [] ~ Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well r'~ Change Plans [] Repairs Made [] Other Pull Tubing i-~ Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Propose to perform the following operations starting 9bout July 1, 1983: _ ! /'~ ' 1. Rig up. hi±± we±± with 8.8-9.0 ppg fluid.~ Remove tree. ' ~talfrise~ and BOP ~r stack (Hydril, 1 doublegate & 1 s~nglegate). Ail components 2M WP or better and arranged per AP1 RP53. Test BOP, choke & kill lines, and riser to 2M psi. 2. Pull 4" tubing and retrievable packer. 3. GIH w/DP and condition mud and clean out to 9103' RKB PBTD. 4. Run GR-CNL log from 7000' back to 4500' RKB. 5. GIH w/Ret. BP &RTTS tool and test existing perforated intervals from 7030' - 8425' RKB for ~ entry. 6. Squeeze cement perforations found to be wet. Following squeeze work, PU bit and clean out to PBTD. 7. Perforate sands per logs from 6309' - 49_~RKB. 8. Run permanent packers on WL and set according to results of leg analyses and testing. Then run 3~" 2 tubing string with sliding sleeves, retrievable hydraulic top packer and SSSV. Set tubing at lowermost set o.B perfs open to wellbore. Set top packer about 4900' RWB. Set SSSV about 300' RKB. Clean up well and conduct 4 point BPT. Return to production as a co~mminAled._producer in Cook Inlet and Beluga formations. Date 4/12/83 . 14. I hereby ce~y that the foregoing i~.ta~e and correct to ~J~'best of my knowledge. Co~iti~of Approval, if any: _Approve-. I~¥ [9~,"it£ C. SMITH By Order of Approved bv. COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 REV. 1-10-73 ,, Submit "intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1, OIL r-'] GAS ~ WELLL=J WELL I-~J OTHER 2. NAME OF OPERATOR Phillips Petroleum Company 3. ADDRESS OF OPERATOR P. 0. Drawer 66 - Kenai AK 99611 4. LOCATION OF WELL At surface Leg 3 Slot 2, 1256' FNL & 1080' FWL of Sec 6 - TllN- R9W, SM BHL: 1711' FSL & 1223' FWL, Sec 36 - T12N - R10W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 14. Check Appropriate.Box To Indicate Nature of Notice, Re 50-283-20028 6. LEASE DESIGNATION AND NC U " z0. F~ELD a~D ~00~, OR W~OC~ NO~h Cook Inlet 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) See Item 4 BHL 12. PERMIT NO. 69-63 ~ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANs (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF : REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) C~ange in Plans (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. 1. Postpone the weil workover program set forth on the Form 10-403 submitted 7/7/75. . Continue to leave the well shut down and monitor the pressures on the tubing and annulus for any indication of a change in condition as outlined in our letter to you on July 24, 1974. Currently the SIWHTP is 1635 psig and the SIWHCP is 1239 psig. These pressures are only 57 and 66 psi greater respectively than those reported on 7/24/74 indicating their magnitude and relationship has not changed significantly. 3. Perform monthly test o£ tubing safety valve. 4. Take appropriate action if pressure relationship and/or tubing safety valve operational status changes. This confirms'verbal agreement between your Mr. Lonnie Smith and our ...... . ,,;>' f (This space for State offi~use) ~ TITLE ,, ' , DATE' September 19, 1975 DATE See Instructions On Reverse Side Form 10403 REV. Submit "1 ntention$" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill o; to deepen Use "APPLICATION FOR PERMIT-J' for such proposals.) 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. ADL-37831 ~' O,L I--1 GAs [~ WELLL.-i WELL OTHER 2. NAME OF OPERATOR 8. UN!T, FARM OR LEASE NAME P:~'ps Petroleum Company NCIU 3. ADDRESS OF OPERATOR 9. WELL NO. P. O. Drawer 66, lanai, Alaska 99611 A-8 4. LOCATION OF WELL At su.ace Leg 3, Slot 2, 1255.6' FNL~ 1080.~' ~ Sec. T lIN, R 9 W, SeM. BHL 1711' FSI~ 1223' F~L, Sec. 36, T12N, RIOW~. S.M. 13. ELEVATIONS (Show-whether DF, RT, GR, err_) ~ 32L6 Fz'om NZZ~ Check Appropriate Box To Indicate Nature of Notice, Re: 14. 10. FIELD AND POOL, OR WILDCAT North Cook Lulet 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) See Item ~ BHL 12. PERMIT NO. 6%63 Bott, or Other' Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIOiZE REPAIR WELL ' (Other) Cteanout/Perf PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLAN5 SUBSEQUENT REPORT OF: WATER SHUT~:)FF : REPAIRING WELL : FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) __ (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Rig up. Kill well with 10.5 ppg mud. Remove tree. Install !2"-3000~ W~~ riser ~ 12" 3000~ WP double gate preventor and Hydril. Test BOP crud riser. 2. .T~l g" tbg and retrievable packer. 3. Perforate Cook Inlet & Beluga Pay ~634- 6309 MD RRB overall.. Run combination ~[-" X 3~~'' tubing string with Otis subsurface safety w~!ve set about 292' RKB and Obis retrievable packer set about 4600' ~2 RKBt and tubing set 8/+35 ~E) i~B. Install tree and displace mud with water. Set. hy~anlic pac.ker. Test packof£. Utilize as a producer commingled in Cook Inlet and Beluga ps~s. - ~timated start of OperatiOns is 7/z /7 JUL 8 I975 16..! hereby certify that the fore.rue and correct SIGNED F '~.'~ ',.~im ~ ..... TITLE DATE (This space for State office use) APPROVED BY ~~ CONDITIONS OF APPR~AL, IF~ANY: TITLE See Instructions On Reverse Side PHILLIPS PETROLEUM COMPANY P. O. Drawer 66 Kenai, Alaska 99611 RE: North Cook Inlet Unit Well No. Unit ~011450 API Well No. 283-20028-00 Pool Code- 564570 Mr. Homer Burrell, Director Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchoraget Alaska 99501 CONFER: -- Dear Sir: This is to inform you that a leak has developed between the 4" tubing - 7" casing annulus of the subject well and to request approval to leave this well shut-in without being killed until the well can be worked over. We are in the process of planning workovers on all the NCIU wells for the summer of 1975. We would prefer to leave the well shut-in in its present status until that time. Administrative approval of a temporary waiver to General Regulation 2164 (automatic shut-in equipment) until the well can be worked over in the summer of 1975 is hereby requested. Leaving the well shut-in in its present status will not constitute a hazard in our opinion bec ause :' 1. The leak is below the tubing safety valve which is closed and sealing effectively, 2. The pressur~ in the tubi~casing annulus is 1700 psi below the 7" 23f~J casing burst rating and llO0 psi b~low the 4" lO.9~J tubing collapse rating. (See attached wellbore'-schematic for completion der ails. ) 3. The leak is small because the tubing and annulus pressures have not equalized. When we noticed abnormal pressure on the casin~tubing annulus, the ball valve seal and the tubing and wellhead above the ball valve were checked and found to be o.k. The Camco type KBM gas lift dummy valve at 1535' RKB MD (1525' TVD) was pulled, dressed and reset following inspection. The inspection did not indicate a leak at this point. The fluid in the annulus is at this point as the result of pulling the dumn~ valve. An attempt was made to set a plu~ in the Obis "Q" nipple at 4306' RKB MD (3419'TVD) so the packer could be checked, but sand (?) in the tubing above the packer at 4261 REB'MD (3394' TVD) prevented making this check. This also prevents us from setting this plug to completely seal off the tubing. JtlI_ 6 I974 Page 2- The static wellhead shut-in pressure on the tubing is 1578 psig. The static wellhead shut-in pressure on the annulus is 1173 psig. Consider- ation of this pressure difference and the annulus fluid level indicates the leak is in the tubing and not at the packer. The burst rating for 7" 23~J casing der. at~e,d,,2~ is 3270'psi. The maximum burst pressure to which the casing is subj_e_ct~is the wellhead shut-in pressure of the well. The WHSIP is static at 15~psiJ~Therefore, the casing has a burst strength 1700 psi .above the WHSIP~~. onsequently, there .is no _ danger of casing burst. The burst rating for ]+" 10.9J tubing der~ed' 2~% is,~_~_~ ;~. This is about 2300 psi above the WHSIP. Note- this-dOes n~t-Consi cd. the opposing pressure in the annulus which would increase the .margin of burst safety. The collapse rating for this tubing .derated 25~ is;~.~_.~i. Even under the most severe condition that could p°Ss~b~-~xis6"~-~lus full of salt water with 1578 psi pressure applied to this head and O psi inside the tubing)~ a llOO psi collapse safety margin would exist. The collapse safety margin is 3700 psi based on current practical conditions. leak waano~ sma~±~ the liquid mu' the'~amuulus would run out and the annulus pressure at the wellhead would build up rapidly until it was equal to the tubing pressure. This has not been the case. Therefore, we believe the leak of such a small size that it does not present any hazard. As mentioned earlier, we are in the process of making a workover study for all the NCIU wells. Well performance studies have indicated that work should be done in the summer of 1975 to enable us to meet contract demand. Our intent is to finalize these plans and begin making preparations for their implementation. However~ we estimate it will take until next summer to assemble the rig and tubular goods to perform these workovers. We prefer not to leave kill fluid on the producing formation for this period of time because it could permanently damage the reservoir. Con- servation of the resource can be effected better with very little hazard to life and property by simply shutting in the well mechanically at the sub-surface safety valve and at the wellhead. Very truly yours, H. J, b~einer ~ Production Superintendent I-~S/N2P/eh attachment I.O.-Inche~ '":."" :'::~?:::)~:.~,~;: ITEM="~,?}:~/.'/~:~; RKB- Top.= ~-. '. ::~.',-:~:'. :",:'-~,..'-::~':' .,,..... ,~,~,:/..,',~.?'"'~-'.~'?'~4:'~'~':':,~?~:" ': ' :'. ~ ~' ,, SO ~:: ~ 'Pi~':~. 586 ',. :.'./":..;~L/',. ' . ' ":' :. (7 :~, ?~?";~.: '.:: ?'," .'.'.: :':'. ~ "?/'.::;f, :".?: ?.'-..:. ," .." .'.' .. ., I/ ' ~E ]' ' · ';-: ,.:: . -.. '. ''.~: ...'.-' t .~ '~:./ ~ ,;, ~ ,',' ~, . ~ ,'- "~::": ':, % (';_.' ' .".., '~',:.'.~ '~' ~.~ ~...':'-' -. ?'":":, .7 ',, "'.~':/~.,"-='~" :'f . -,~... .. -~ ~" . -'~',: , , · . '. :.,:.,. f'? . (',. .: -" ' (: "<,:".'.:.,") : .; ...... . ~'....; :...':":~:,..~.'.~"(,'.~..,~;.'~-','U':.'.,~"/::,..:'.' ""/:)' '~'" :.' '"/::'( )~'.:...:~' 'Cemented to Surt~co' ' . ~ :'.. '... :' .,. "....' E'~, ,'.~','~ ~,-' ,,,'~ 1/ ,,'"~;; .'.~' ~,'" -', .~.',.~. T , .' ./ , . - ~ ' " ~ ,. (.. ~... 9.,,;. ~' /%.~;'4:,, ':: ~' ..:'~ :'~ '. :., ".'~"4'. 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",'..- '/,' :/?","~,..J~,,".;C ':'~)~ .'~' 5 ', '. ,:.. .: '* :'. · .-. ..~ '~' · . :.'::~.'. ,, . . : ". ,:' -~ ~. ,.,L. /. ~ - ~ ~:., . ~ . '. ,, ' .. ,f ..~ 'j':v~ ;,,. :..:.,~f'. 'L .'~,,'.', . :;;u .,C~,'. .r..',: '. ,'.' ,' ~ '.- -, ' ~, '/' ,::: ~' ~ .' ~ .., .:~. /-: .'/ ..... .- , ,..:.: . ........ /.,.~&, <.:..',:~ ..,:~.,~;:;;,~..,'>:;, ?.., ,.....: -:. ...... : . :'~',,:, . .:, . ~:~':.~:'-,'. ~'/:?7 ,'~' "..:'.: ?.:.'~'~?..',-?:~ ~'.-:: '" '.'.." .':' ..~ ?":~ '~.[:: ~/,~...,::'.')v:-.'~.~ ':.: ' .... SUBMIT IN DUPLIC',b. -~'~ STATE OF ALASKA ',see other in- structions on OIL AND GAS CONSERVA11Q~N~-COMMITTEE reveYse side) WELL COMPLETION OR RECOMPLEIION REPORT AND LOG* la. TYPE OF WELL: b. TYPE OF COMPLETION: Nzw F~ wolu¢ FI WELL OVER OILwELL E~ GAgwELL [] DRY E] Other EN BACK - nESVR/.L_~ ) Other 2. NAME OF 0PERAT01% Phillips Petroleum Company 3. ADDRE88 OF OPERATOR 13. ATE SPUDDED 114. DATE T.D. REACHED 115. DATE CO,MP, SUSP, OR ABAND. ] 16. ELEVATIONS (DF, RKB, *-~A,.¢,9 i 7-].9-49 . [ a-'!~---69 ! Jla, RT{'B IS. TO~2ALA~PT.}I.~MD & 'TVDp9. "PLUG B~CK~. ~., .MD~&_ 'l~;O~0. ~F 1VrULT ;I~LE COMPL., I 'ix. yZZ~' MD / DE~H ~£U~' ~ I ~ow m~mw. ! ROTAR~ TO0':S A~,~,~ ~m I '' AA16~ ~rD ,! Sinale [ 22. PR~D~fC~HG 'L~'r~a~VAL(S), OF THIS COMPi~ETIO~--TO~, BOTTOM, NAME (MD'~D T~rD)* Beluga ~m. - 7030' ~ (5077' TTD) to 8L25' ~D (5952' ~) UNIT,FAi{M OR LEASE NAME Noz~ch Cook Inlet Unit WELL NO. 515 "D" Street, Anchorage, Alaska 995014 lo. ~nm~ a, su~ace~g 3, ~lOt 2, ' F~, 10~.'~' ~, Sec. 6, TI~, ~LSmC.,T.,R.,~.,(~M~O~ R~5, S.M., No~h Cook I~et P~tfo~ ~ne~ At ~o, ,,o~. ,.t,,.., ,.,o,t., ~.,o~ 7030' 1~, 5077':~, Si?' FSL, 2610' ~ Sec. 36, T~N, ~0W, S.M. At total dep~ 17~ FSL & ~3' ~, Sec. 36, T~N,t~0W, S.M. RT, GR, ~)'~17. ~. ~SINGED · ~, 73' :_Sec. 36, T12N, EIOW, S.M. 12, .PEBblIT NO. INTERVALS DRILLED BY /),11 I CABLE ~OOLS 23. 'WAS DIREC~I~IO,NAL SURVEY 1VIADE Yes DILL~ FDC, SNP & CBL CASING RECORD (Report all strings set in well) _ c~,sm~ Size. 1 WEIGHT, LB/FT. I GI:~DI~, I DEPTH SET (iII.D) I ~=~. I 16" OD [ 65~ . / H-LO [ 623'~' ' I 22" l:' 587 sx C~-ss "G" Cemen% .lO-q/&', OI~ ['23~-& 2~'] J-55[ 9155' 19-5/8. p0~ sx Class "G" Cement , T','oo, ~'~ & q_~l J-ss I 2985, ! z~,, l a2~ ,× 26. LINER ~CO~ [ 27, TUB~G [ ~' !CEMENT* 28. PERFORATIONS OPeN TO PRODUC-~iON (Interval, size and number) SEE PERF0~~G & S~~ EECORD ATTAGHED 30. PI%ODUCTION'~ A/VIOUNT PULLED DATE FIRST~PI~ODUCTION I PI~ODUCTION METHOD (FlowE-~g, gas litt, pumping--size and type of pump) IWELL STATUS (Producing or ' ' ,, I shut-in) ' · Not Produced Y~$ [ ' , '" ~ -,:{ I Shut-In -, _ . ) ,, ')' .... ," I ~A,. o, TEAT, I~O~ ~ l~O:~ ~,Z~ I~'~ ~ O~.'~ ~C~. ~W*~~. '~-O~ ~O ' ~ ~ ~S~ ~S~ l~~~ .0I~. GA~'~ W*~B~. [OIL G~VITY-~"'(C~.> : · DISPOSITIQN OF oas (~otd, used flor ]uel, vented, etc.) ...¢~ :'~/ ~',, ,;,.,,:' ,?-"k~ ' ITEST WITNESSED BY 1 Shut-In. _ . ' . :';~ ~ .: .~,~. 32. ~xsx oF ATTACH~iENTS ' . ':,~: ?'. .''~:,'1 ' . , . .. _ . .1._9~?log~c~l ~)~ ~s~. 2. S~le Description. 3. Perforat~ & the ~egoln~ nd attached lnformStton 1~ eom~l~n~ eo~re~t determined from alUavaflable records SIGNED d ' TITLE ~strict Office ~ager DATE ..Sept. ~, .19~9 i *(See I.,tmctio,, ~ag S~ce, [or AJ8ifio.,al B~t~ o, ReVerse SiJe) t I' $CREIEN (MD) SIZE DEPTI-I SET (MD) PACIiER SET (MD) 29. ACID, SHOT, F2~.C-'TU'R.E,&<.~NT SQUEEZE, ~C. · :~INSTRUCTIONS ~'~ ~ General: This form is-d'e~gned for submitting a complete and correct well Comple~ion report andl log ~ 811r types of lands and leases in Alaska: :o -;~ " ' ~C. ~ ~': ' ~ ~: :"C ' I:"~ " i' [.~ Ite~. 16: Indicate which elevation is 'used as reference ~ : :- I '.' " .- (wh~e not oth~r~iseshown) for d h n~easu~e~ - '.'~ " ~ ment~ given' in other spaces on this-for~ and in any attachme:n'~s ' ~: ~c ~ :.k~ :: ~' ~? Items 20, nnd 22:: If this well is completed for separate production from more th one i~erV;al zon~ . . ~ · r, r, r. :.j~ }-1 , (multiple completion), so state, in item 20,: ahd'.- in item 22 show the prcdo~ing Mterval, ~. interval~ r ) top(s), bottOm(s) and name (s) (if any)for RQ~y r~he interval .reported in item 30. Su~it a .sepa. rat~ re~.rt ..: '. (page) on this form, adequately identified;-¢dr ~ach a;d~itiOnal intei[~l,;~o ~ seper~}ely pro~Oc~?~Sho~: a. lng the a~itional data pertinent' to such .,inter~v_al. , o o ~- · o ~'; .... ~:'" ~ .. . . ::. " 1~'26: "~cks Cemeni":'~Attached suppl~nt~l records for this well should show the details of any mul-: ~ ~'~:~ tiple stage cementing and the location of ~;,; .~ ~menting~..~ tool. ~ _ ~;.., ~ :ltem 28: Submit a separate completion re~} ~n this form: fGf" each int~val to ~ separately produ~. '~ :', 's' instruction for ffems 20 and 22 abe ~: :, ~.~ , , . .. "~f~' ' WATER'AND MUD. ' -'; ' ' ' ~ ' ~ ' . ' , V ~..; . 'J ] ;-, ~.) '. , :.' .....) - .. . .. o-z..~~ '"'~ Upper : " " . - 0 ._ :~.). : ~ ,. ·'[;.].j~?:: ,..~, .) . . ' ':~t~ c,_ :; ", ~ ~ . ..~: I ~,~ ' -..: .... ~ ~ ~: "' ~: ! ~ '~ ..... . ' i' ~ " ' ''~ : ' c ....... ~ ' ' ~ ..... "~) ' ;.) "· ' ,.~ ' .. ' ":_':~ , ~ , · ... ~. ,.. ,.:-, ,.~ ., ~ , ~ - 38. qOfiE DATA. A~ACI[ B {E~ 'D~CRIPI~O~S O~ LITHOLOGY..PO~OSiTY;'.'FHAC~; PP~T DIPS ' .. I ~r- AND .D~PEC~'EI) SIIOWS OF O1~, ' '' 'r~ '.~ _ ' C.2 ..~ ' -. '" '" .. .... ,-.. . ,., : . : . · _. ._.:J- '. - ' ' .'" C".. · c..~ ~) .... ~ .. ... ... C :.' . . ,..I .... :'.,;":. .. , · . .. ,,.~ f,:l, .,.. ,~ 'o " ~ ':>' '" ~" ~: ~ · "'~ '~ ....... - :~..'l . . "S~:.ATTA0~D ~~ ~S0~I0N --'~' .... ' ": :-~ :'::' '''''~ ' :. ] Im' '- -' .. r -. : , ',.~ :':.'.:. :~t ,.n: ,.] ,, , .- -- : · ... ~ ~. ,. . .... ~, " [ i i " "' , , , CHRONOLOGICAL ~,~LL HISTORY WELL #A-8 6-26-69 6-27-69 6-28/30-69 7-3/15-69 7-16/22-69 7-23-69 7-27/29-69 7-30-69 3005 ' 8425' 9222' Spudded 15" hole & drilled to 635' & rind to 22". Ran 16" csg, set 623', emtd w/462 sx Type "G" cmt mxd in 220 bbls pre-hydrated 4% Gel wtr. Cmt circ. Tailed in w/125 sx Type "G" cmt mxd in 15 bbls 2% cc wtr. Drld 15" hole to 2626'. Drld 15" hole. Ran 10-3/4" csg. Set ~ 2985'. Cmtd w/700 sx Type "G" cmt mxd in 330 bbls prehydrated 4% Gel inlet wtr. Tailed in w/125 sx ~Type "G" cmt mxd in 15 bbls 2% inlet wtr. Drld 9-5/8" hole. Pipe stuck. Spotted Scot-Free mxd w/diesel while jarring on fish. Spotted Pipe-Lax while jarring on fish. Could not jar loose. Backed off DP. Left bit, rmr, 4 stabilizers, 2 monel cols, 6 steel cols, 2 x-over subs, 25 jts H.W. DP and 1 set jars. Top of fish 7329'. PLxd & set 87 sx Type "G" cmt plug. Dressed cmt to 7171'. Sidetracked hole @ 7185'. Drld 9-5/8" hole from 7185'. Ran 7" csg. Set @ 9154'. Cmtd w/545 sx Type "G" cmt mxd w/132 bbls prehydrated 10% Diacel 'D' & 2% cc wtr. Cmtd 2nd stage w/860 sx Type "G" cmt in 103 bbls 2% cc wtr. Drld out stage col & tested csg to 2000#, O.K. Ran CBL & GR Logs. Perforated 8375' - 8425' IESMeas. for DST #1. Well had fair blow. Rec 1202'.mud & 40' muddy sand. DST #1 - 24 hr clock: IHP 3272 PSI, FSIP 2085 PSI, IFP 37 PSI, FHP 3247 PSI, 15 min FP 74 PSI, I hr SIP 2399 PSI, IFP 99 PSI, FFP k~3 PSI, FSIP 2085 PSI, FHP 3247. 48 hr clock: IHP 3295 PSI, IFP 49 PSI, 15 min FP 86 PSI, I hr SIP 2404 PSI, IFP 124 PSI, FFP 457 PSI, FSiP 2099 PSI, FHP 3283 PSI. Perforated 7822'- 7828' IES Meas. for DST #2. Had good blow. Rec 546' of drlg mud, 364' of contaminated mud w/some sand & 373' of heavy mud & sand mxd. DST #2 - 24 hr clock: IHP 3078 PSI, IFP 25 PSI, 15 min FP 29 PSI, i hr SIP 2363 PSI, IFP 62 PSI, FFP 256 PSI, FSIP 2206 PSI, FHP 3078 PSI. 48 hr clock: IHP 3112 PSI, IFP 29 PSI, 15 min FP 74 PSI, I hr SIP 2380 PSI, IFP 86 PSI, FFP 703 PSI, FSIP 2221 PSI, FHP 3112 PSI. Perforated 7388' - 7398' IES Meas. for DST #3. Had fair blow. Rec 312' of drlg mud & 12' of sandy mud. DST #3 - 24 hr clock: IHP 2933 PSI, IFP 993 PSI, 15 rain FP 1175 PSI, i hr SIP 2399 PSI, IFP 1236 PSI, 18 hr FP 1273 PSI. Clock ran out. 48 hr clock: IHP 2954 PSI, IHP 936 PSI, 15 min FP 1230 PSI, i hr SIP 2417 PSI, IFP 1267 PSI on 1/8" choke, reached high of 1683#, changed to 3/8" choke, pressure dropped to 862#, changed to ¼" choke, pressure went to 1586#, FFP 1230 PSI. 24 hr flow, FSIP 2160 PSI w/12 hr SI pressure still bldg. FH~P 2954 PSI. '.' 7-31-69 9103' PBTD Ran DST #3. Perf's 7388' - 7398' IES Meas. CHRONOLOGICAL WELL HISTORY #A_8 8-1-69 8-4-69 8-5-69 8-6/ll-69 8-12-69 Ran DST #3. Perf's 8375' - 8425' IES Meas. Flwd on 1/8" chk 5 hrs. Press. decreased to 44#. Bled press, off. 30 rains later had good bubbles thru ¼" hose submerged in 5 gal bucket of water. IHP 3368 PSI, IFP 1255 PSI, 15 rain FP 1267 PSI, ISIP 2710 PSI for 2 hfs, IFP 1279 PSI, 9 hr FP 690 PSI, FSIP 2013 PSI, FHP 3368 PSI. Rec 1200' mud, LO' muddy sand. Perf'd 60lA' - 6015' and 6024' - 6025'; 4-½" holes/ft. Squeezed perf's w/135 sx Type "G" cement. WOC 24 hrs. Drld out cement. Perf'd as follows w/Schlumberger 4" No Plug Carrier Gun, 4-.47" holes/ft: 8307' -83]2.', 8180' -8185', 8008'- 8018', 7309'- 7326~ 7583' - 7598', 7513' - 7538', 7478' - 7481', 7197' - 7214', 7067' - 7060', 7030' - 7060', IES Measurements. Ran combination 3½" & 4" tubing string. Ran 4-pt test~ as follows: #1 - Flwd 2 hfs on 3/4" chk,. FTP 1597 PSI, Temp 68v, FA_RO 24,562 MCFD. #2 - Flwd 2 hrs on 5/8" chk, FTP 1781 PSI, Temp 69°, FARO 17,920 MCFD. #3 - Flwd l½ hrs on ½" chk, FTP 1880 PSI, Temp 66°, FARO 12,007 MCFD. #4 - Flwd 3/4 hr on ¼" chk, FTP 1979 PSI, Temp 66°, FARO 2,943 MCFD. SI for BHP. CAOF 45 MMCFD. Completed gas well in Beluga Sands. Perf' s 7030' - 8425' , North Cook Inlet Field. Phillips Petroleum Company N.C.~. Unit #A-8 North Cook Inlet Field Cook ~nlet, Alaska SAMPLE DESCRIPTION 3ooo- MOO ~400- L650 A650- A870 ~870- 4980 ~980- 5960 5980- 7020 7020- 7560 7560- 7985 7985 - 8215 8215 - 9120 9].20- 9222 Sand- mod- dk ~v, f-rog, mod srtd, subang- subrnd, abnt multi-colored grains; w/se clyst - gy, slty, soft. Clyst - ay, sli slty, soft, carb, m~c; w/ se sand and coal. Sand - Mod ~v, rog, mod srtd, subang- subrnd, abnt gr and blk grains. Clyst - Lt ~v, med hd, bent?; w/thin~:, sand and coal beds. Sand- Mod ~, m-c~,., r~od srtd, abnt multi-colored grains; w/inter- bedded sltst, clyst, and coal. Sltst, clyst, coal and sand - Interbe~ded. Sand - Mod ~, rog, poorly srtd, subang - subrnd, pred. qtz; w/ interbedded clyst - ~? and bm, slty, carb, soft to mod hd. Clyst - C~y, slty, soft, carb; w/sctd thin sand beds. Sltst- Gy to brn, soft to mod hd, clayey, sdy, pt carb; w/clyst and sctd thin sand beds. Mud st and clys~ - Qv, soft to firm; w/sctd thin ss and coal beds. Sltst - Lt ~y, calc. Mr. C. R. Seewald August 28, 1969 Forn~ .No. G-1 RE¥t$[D : ,lAN. I , i965 · STAi'E OF ALASKA su~rr ~-~ OIL AND GAS CONSERVAT!ON CONU~AITTEE GAS WELL OPEN FLOW POTENTIAL ZEST REPORT 4-POINT TEST Initial D// Test Annual r-I Special ,. v/::'A:L . ' ':'~ ..' /-,-'),Z.. :, -'~ .,A.->.' ,.: ,::?...::-: ~ .~-.' .... ,~..:.,.,~ ,/" ./ ...... / /,-×-.-~c-,. (/ - / "~ ~---" ...... ' / .':" ". ....... : ' .,"/ z." , ; · .,"%,". (__. fi:. > ,'" ~ ,:t ,:' ,'oLin l~,' } Loc:.ttion ,-<'. " t -f ... , '. 'K ~,., .~..-:-:~,:_; - / D ~? - /..::?,.,(,,,./' d.~ ,. .... ,: '? ~ . · ..... ,- ....... ., ........ . ......... ,.., z .:.: '/ ¥ ,. . Produc,n~ ThrUTBG. [ CSG. Tempe:alur,R¢'etv°!r ] Wdlhead [ CSG. SlZeT~pera:ure ~,x.'t/Ft.- t I.D. '~: /.--~?~ '~ ~-.,~, 'F'~ '~ ~:-: ,' ' CZ.' ~-,,-'E~ /":'-:) ~-.'>'(: -/-, ~.......-:, t.: ....... ¢',',;', .... '~ ~., -' -~ ., kf...' .... ' -o ] Pigeiind Connection Type Taps ./,t ' .. . . '"'"" /: A::z //::.,_: ,o ::>: ~ .::,...::. ~:-,: ;.:> .<' ~.:. : >/..::., ,. ,.,._. ....,:/... .... ,:; .......... , ..... ,Mult, I~]e Comp]etio~ (D~! or Tripl~) t Type ~rod~¢tion from e~¢~ ~-one 1 Test Date Well Xo. T/Pay ~.] Producina Interval~ .,/ Gr~¥iI~ of Liquid (Api) SI. I. I ,,.:,">,. :'> .%~ c:, 2. Time [ (t~ro'ver) of Flow (Line) Hours I Size OBSERVED DATA Flow Data -(-Orifice)- Size psig' ......... ~'"" ' .'-~"'"'?"Z' ,.'?": :: t ' "? >' Diff. h FLOX'V CALCULATIONS Tubing Press. psia' /:(z.,>' -/ , K?:? / Casing Press. psig ]Flowing Temp. , , i C0effi- . .... Flow Temp. Gravity' i Compress. (24 Hr.)Vw m psia F t~ F Q MCF/D t g pv .... .>:::) ..?>-/ /, _~../,.:/-/ ., . .,...; ,..,, :.....,:ir~ ~..~, / ~ , ,.. . ,1~//->'7 ?':: - ' ....... ~' '"'""~ ~. ~ ' .: <&: / ' , . , ~ ,, ,.- , f__ ~]_ · ~ ~ I ,, , r '-~ ,,, ~ PR1E. SSI:.RE CALCULATIO]NS '" '"~:"'" .'%~CF/D ' - :'/,.. ~R~FZC~T:E: I. the undersized, sta~ that I am the ~t).""7.:, .~ ..... ~ ,'./.- ~ / (company), .nd ~at, am au~or.ed by said comp=y to make mis report; and that ~,is report pared under my supervision and direc~on ~d ~at ~e fac~ stated ~.re~ are %r~e. correct and ',' :::~.?:" ::7 ,' -"/ ~IViSi~0~01[~~ Da t e Tested STATE OF ALASKA ' OIL AND GAS CONSERVATION COM[MITTEE 'Sce Instructio~zs on Reverse Side Initial Completion* [ Special* [ t;omb Test Data Test P,.H. Observed Depth Temp. Pressure . -- Shut-In Tubing Pressure -. type of report by "X". ' ...... ~'?~:,9 7~ ......... ~ ...~--: .., - c~:..~ / j ClClt'rlFICATI,:: I, the undersigned, state that I am the 2 ........... 7 of the .},~::::(.:,A~....~-.~,:-:, k..' 0 (company), and that I am authorized 1)3' said company, to make:this report; and that this report was prepared under my supervision and direction and that !h; fae'f~*'~'~kk~g therein are true, correct and complete to thc best of lily knowledge. ~ ,// ,/ / j // / ( ¢'":;:-.- 7fi~ ~.--r'" ,.., / 6"..~%? 2. '" :'h. "...-"'-~ ?,' ' ._ ~.~ "' Signature Prod. Test ('Bbls. pe, r l),q.y) I l_,!quid ' , ' ........ Level Gradient Oil -Wate'_ ',.'5 ~'O- d:, ::2 ~Vt. of Wt of ~.' ~ Casing ~,t lMquid Gas ,. ~ Cot~mn Cohtrfin II resyiure Datum .~ 9-5 . MINER 0.4 ¢ 7 < ~ TRM OKG KLV HW~ /C_ FILE . . ~.---- ...... : ........ i---: .'-e-k-~ ~~- .......... ~, .'_z__z..__~:_, :, .... ~ ..... _..:__. ~_..~__~ i ............ !' .... f ::'~ ~-" 'i '-~:i ...... :': .......... i_._~._L.: .--' .-i .~ ',. ' ......... i.. :I-.:~..'.-~-! ..i:¢ : ..... ; ._:. ..~ ...; i ........ J ..: : '. , ~:,:-:: .,_~:_:__:~__ ........... :~-i-: 1.':-:..i-- :_!:z,L :i-:-'<:-.! . i:~: ~::::: ~:."::.!:".~'!.:::{::!': l,t- .:'i":i' !:':' ~ ' 'i I :L ~':: .:t::...~:'::4 .... ~-:!.t [ZZL': ; i'..::jil. ·. ~'? .....: -:i'l::::::;:>':~':':; ::!'! "-'"-:::' , , -- 7 6 i ' 2 3 4 5 6 7 8 910 o 4 5 6 7 c; 9 '; C: ,_~ 2 3 4 6 6 7 5 9 10 SYMBOL OF SERVICE REPORT of SUB-SURFACE DIRECTIONAL SURVEY PHILLIPS PETROLEUM COMPANY COMPANY PLATFORM "A" A-8 WELL NAME NORTH COOK INLET, ALASKA LOCATION JOB NUMBER AM6- 1869 TYPE OF SURVEY SINGLE SHOT DATE d UN E - dULY 1969 SURVEY BY ANCHORAGE UTI'tO ~Y EJI~TCO IN U.S.A. W E L L C (] M P L E T I ON R E P O R T PHILLIPS PETROLEUM COMPANY A-8 PREPARED BY SCS 07/30/69 FOR EASTMAN PAGE 1 TANGENTIAL METHOD HEASURED COURSE - - D E V I A T I 0 N .... C 0 U R S E - - - DEPTH LENGTH ANGLE DIRECTION AMOUNT V.DEPTH LATITUDE DEPARTURE - - - T 0 T A L .... V.DEPTH LATITUDE DEPARTURE ORIGIN LOCATED AT MD = 432. 527. 635. 700. 748. 825. 885. 981. 1076. 1169. 1258. 1355. 1450. 1543. 1637. 1730. 1830. 1923. 2015. 2105. 2199. 2294. 2396. 2483. 2576. 2650. 2742, 2835, 2929. 3005. 3077. 71. 95. 108- 65. 48. 77. 60. 96. 361.00, TVD = 360.99, LATITUDE 0 Om N OW 0 O' N 0 W 0 30' N 80 W 0 O' N OW 1 45' N 60 W 4 45' N 71 W 5 30m N 62 W 7 45' N 59 W 0.00 71.00 0.00 95.00 0.94 107.99 0.00 65.00 1.46 47.97 6.37 76.73 5.75 59.72 12.94 95.12 17.71 93.33 20.92 90.61 22.65 86.06 29.16 92.51 32.49 89.27 34.83 86.22 37.48 86.20 40.40 83.76 46.94 88.29 47.89 79.71 52.10 75.81 54.78 71.40 61.35 71.21 63.87 70.32 71.17 73.06 63.36 59.61 71,24 59.77 56.47 47.81 69.69 60.05 70.18 61.01 70.94 61.66 57.13 50.11 54.!3 47.~7 95. 10 45' N 63 W 93. 13 O' N 65 W 89. 14 45' N 65 W 97. 17 30' N 67 W 95. 20 O' N 70 W 93. 22 O" N 67 W 94. 23 30' N 65 W 93. 25 45' N 65 W 100, 28 0m N 64 W 93. 31 O' N 64 W 92. 34 30' N 64 W 90. 37 30' N 64 W 94. 40 45' N 63 W 95. 42 15' N 64 W 102o 44 15' N 64 W 87. 46 45' N 64 W 93. 50 O' N 62 W 74. 49 45m N 63 W 92. 49 15' N 62 W 93. 49 O' N 62 W 94. 49 b' N 61W 76. 48 45' N 61 W 72. 48 45' N 61 W \ 0.00 N 0.00 N O. 16 N 0.00 N 0.73 N 2.07 N 2.69 N 6.66 N 8.04 N 8.84 N 9.57 N 11.39 N 11.11N 13.61N 15.84 N 17.07 N 20.58 N 20.99 N 22.84 N 24.01N 27.85 N 28,00 N 31.20 N 27.77 N 33.44 N 25.64 N 32.72 N 32.95 N 34.39 N 27.70 N 26.24 N -1.43, DEPARTURE = 0.00 W 431.99 0.00 W 526.99 0.92 W 634.98 0.00 W 699.98 1.26 W 747.96 6.02 W 824.69 5.07 W 884.42 11.09 W 979,54 15.78 W 1072.87 18.96 W 1163.49 20.53 W 1249.56 26.84 W 1342.07 30.53 W 1431.34 32.06 W 1517,57 33.97 W 1603.77 36.61 W 1687.54 42.19 W 1775.83 43.05 W 1855.55 46.83 W 1931.37 49.24 W 2002.77 54.67 W 2073.98 57.41 W 2144.30 63.97 W 2217.36 56.95 W 2276.97 62.90 W 2336.75 50.32 W 2384.57 61.53 W 2444.62 61.97 W 2505.63 62.04 W 2567.30 49.97 W 2617.41 47.34 W 2664.89 -4.71 1.43 S 4.71 W 1.43 S 4.71 W 1.26 S 5.63 W 1.26 S 5.63 W 0.53 S 6.90 W 1.54 N 12.93 W 10.90 N 29. 18.95 N 44.89 W 27.79 N 63.85 W 37.3'/ N 84.39 W 48.76 N 111.24 Id 59.88 N 141.77~Id 73.49 N 173.84 W 89.33 N 207.81 Id 106.41 N 244.43~Id 126.99 N ~286.63 W 147.98 N 329.68 W 170.83 N 376.51 W 194,8~ N 425.76 W 222.70 N 480.~3 Id 250,70 N 537,84 W 281.90 N 601.8~ 309,68 N ~658.7 343.13 N 721.67 W 368.77 N 771.99 W 401.49 N 833.53 W 434.44 N 895.50 W 468.83 N 957.55 W 496°54 N 1007.53 W 522.,78 NX1054o87, W N E L L C 0 M P L E T I O N R E P OR T PHILLIPS PETROLEUM COMPANY A-8 PREPARED BY SCS 07/30/69 FOR EASTMAN MEASURED COURSE - - D E V ! A T ! 0 N .... C 0 U R S E - - - DEPTH LENGTH ANGLE DIRECTION AMOUNT V.DEPTH LATITUDE DEPARTURE 3170, 93, 49 O' N 61W 70,18 61,01 34,02 N 61.38 3329, 159, 50 O' N 61W 121,80 102,20 5.9,05 N 106,52 3512, 183, 50 45' N 60 W 141,71 115,78 70,85 N 122.72 3700, 188. 50 45' N 60 W 145,58 118.94 72.79 N 126.08 3888. {88. 52 45' N 59 W 149.64 113.79 77.07 N 128.27 4075. 187. 53 45' N 59 W 150.80 110.57 77.67 N 129.26 4262. 187. 54 45' N 60 W 152.71 107,92 76.35 N 132.25 4368. 106. 55 45' N 60 N 87.61 59.65 43.80 N 75.87 4461. 93. 55 30' N 60 N 76.64 52.67 38.32 N 66.37 4648, {87, 54 30' N 60 W 152,23 108,59 76,ll N 131,84 4835, 187, 53 15' N 60 W 149,83 111-88 74,91N 129.76 5020, 185. 52 45' N 59 W 147.26 111.97 75.84 N 126.22 5203. 183. 51 30' N 60 W 143.21 113.92 71.60 N 124.02 5382. 179. 50 45' N 60 W 138.61 113.25 69.30 N 120.04 5598. 216. 50 30' N 60 W 166.67 137.39 83.33 N 144.34 5813, 215, 49 45' N 60 W 164,09 138,91 82,04 N 142,11 6031. 218. 48 O' N 60 W 162.00 145.87 81,00 N 140.30 6208, 177. 49 45' N 59 W 135.09 114.36 69.57 N 115.79 6395. 187. 52 30' N 60 W 148.35 113.83 74.17 N 128.48 6563. 168. 53 45' N 59 W 135.48 99.34 69.77 N 116.13 6750, 187, 54 O' N 60 W 151,28 109,91 75,64 N 131,01 6935, 185. 54 O' N 59 W 149.66 108,74 77,08 N 128.29 7122. 187. 54 0e N 60 W 151.28 lOg.gl 75.64 N 131,01 7171. 49. 54 O' N 59 W 39.64 28.80 20.41N 33.97 7217. 46. 53 30' N 60 W 36.97 27.36 18.48 N 32.02 7248. 31. 53 O' N 60 W 24.75 18,65 12.37 N 21,44 7341. 93. 50 30' N 59 W 71.76 59.15 36.95 N 61.51 7600, 259. 51 15' N 57 W 201.99 162.11 110.01N 169.40 7973. 373. 51 15' N 59 W 290.89 233.46 149.82 N 249.34 8221. 248. 51 O' N 58 W 192.73 156.07 102.13 N 163.44 8760. 539. 49 30' N 58 W 409.85 350.05 217.19 N 347.57 PAGE 2 TANGENTIAL METHOD:* - - - T 0 T A L .... V.DEPTH LATITUDE DEPARTURE 2725.90 2828.10 2943.89 3062.84 3176.63 3287.21 556,81 N 1116,26 615.86 N 1222.79 686.7l N 1345.52 759.51 N ~4471.60 836.58 N 1599.87 914.25 N 1729.14 3395.13 990.61 N 1861.39 3454,79 1034.42 N 1937.27 3507.47 1072.74 N 2003.64 3616.06 1148.86 N 2135.49 3727.94 1223.78 N 2265,25 3839.9~ 1299.62 N 2391.47 3953.84 1371.23 N 2515.50 4067.10 1440.54'N 2635,55 4204,49 1523.87 N 2779.89 4343.41 1605.92 N 2922.00 4489.28 1686.92 N 3062.30 4603.64 1756,50 N 3178.10 4717.48 1830,68 N 3306.58 4816.82 1900,46 N 3422.71 4926,74 1976,10 N 3553.73 5035.48 2053.19 N 3682.02 5145.39 2128.83 N 3813.04 5174,19 2149.25 N 3847.02 5201.56 2167.74 N 3879.04 5220,21 2180,11 N 3900,48 5279.37 2217.07 N 3961.99 5441,48 2327.09 N 4131.39 5674,95 2476.91 N 4380.74 5831.02 2579.04 N 4544.19 6181,07 2796.23 N 489[.77 W E L L C 0 M P L E T [ 0 N R E P OR T PHILLIPS PETROLEUM COMPANY A-8 PREPARED BY SCS 07/30/69 FOR EASTMAN NEASURED COURSE - - D E V [ A T ! 0 N .... C 0 U R S E - - - DEPTH LENGTH ANGLE DIRECT!ON AMOUNT Vo DEPTH LAT!TUDE DEPARTURE 9222. 462° 68 30e N 57 14 346.01 306o13 188.45 N 290o19 N PAGE 3 TANGENT[AL METHOD - - - T 0 T A L .... VoDEPTH LAT!TUDE DEPARTURE 6487.21 2984.69 N 5181o96 W CLOSURE 5980.06 N 60- 6~ N Form No. H.E'V. 9-~..67 STATE OF ALASKA SUB~rr IN DWLmA~ OIL AND GAS CONSERVATION COMMI]WEE MONTHLY REPO'RT OF DRILLING AND WORKOVER OPERATIONS 2. NAME OF OP]~m,~TOR Phillips Petroleum_ Company 3. ADDRESS OF OPERATOR 515 "D" Street: Anchora~ge 4. LOCATION OF WELL Surface: Leg 3, Slot 2, 1255.6' FNL, 1080.~' FWL, Sec. 6 TliN,--RgW, S.M., North C~ek Inlet Platform "Tyonek". Top~.e..f p_ay: 500o' MD, 3900' TVD, 250' FSL, 1500' FEL, Sec. 36, T12N, RIOW, S.M. HLB , AP1 NU~iERICA-L CODE '~[ ' f,[?'~ ~I ~0-283-20028 S~? ,~ '- L~SE DESiGNA~ON AN-D S~~O. ,, - HWK ~37831 REt ~-/g ~ 7. IF INDIA]~, ALOTTEE OR TRIBE .~;ANIE ~ 8. L~.'IT,FA/:~{ OR LEASE N.~E i'iLIE , North Cook Inlet Unit 9. WELL NO. #t-8 10. FIELD A2qD POOL, OR WILDCAT North Cook Inlet 11. SEC., T., R., M.. (BO~FOM HOLE OB.~crrvE) Sec. 36, T12N, R1OW, S.M. 12. PERMIT NO. 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA~NGES IN HOLE SIZE, CASING ANT) CE1VIENTING JOBS INCLUDING DEPTH SET ~ VOLUArfF~ USED, PERFORATIONS, TESTS ~ RESULTS. FISHING JOBS, JLrNK IN HOLE AND SIDE-TRACKED HOLE A~D A_NY OTI-IER SIGNIFICANT CI4_AN~ES IN HOL~ CONDITIONS. 8-12-69 8-1-69 8-5-69 8-6/ -69 9103' PBTD Ce_mpleted gas well in Beluga Sands. Perf' s 7030'-8425' . North Cook Inlet Fiela. ' Ran DST #3. Perf:'s 8375' - 8425' IES Moas. Flwd on 1/8" chk 5 hrs. Press. decreased to h4~. Bled press, off. 30 m~_ns later had good bubbles th~ ~" hose submerged in ~ gal bucket of water. IHP 3368 PSI, IFP 1255 PSI, 15 rain FP 3~67 PSI, ISIP 2710 PSI for 2 hrs, IFP 1279 PSI, 9 hr FP 690 PSI, FSIP 2013 PSI, FHP 3368 PSI. Rec. 120-0' mud, ~0' muddy sand. Perf'd 6014' 6015' and 602~' -6025'; &~" holes/ft. Squeezed perf's w/135 sx Type "G" cement. WOO 2k hrs. Drld cut cement. Perf'd as follows w/Schlumberger $" Ne Plug Carrier Gun, &-.&7" heles/ft: 8307'-8314', 8180'-8185', 8OO8'~18", 7309'-7326', 7583 '-7598' , 7513'-7538', 7~78'-7~81', 7197'-7214', 7067'-7060' 7030~-7060', IES Measurements. Ram combination 3½" & ;+" tubing string. Ran ~-pt test as fellows: #1- Flwd 2 hrs on 3/&" chk, FTP 1597 PSI, Temp 68©, FARO '~,562 ~OFD. #2- Flwd 2 hrs on 5/8" chk, FTP 1781 PSI, Temp 69°, FARO 17,920 MCFD. #3 - Flwd 1½ hrs ..on ½" chk, FTP 1880 PSI, Temp 66°, FARO 12,007 MCFD. #~ - Flwd 3/& hr on ~" ch_k, FTP 1979 PSI, Temp 66°, FARO 2,9~3 MOFD. SI for BHP. CAOF k5 MMCFD. V ¥m'ONOFO tA G S 14. I hereby ~er~ tJ;Jltt the ~rego~ ~ SIG~~~;~ ~T~District 0fo, ~r. DA~. Au~st 28~ 1969 NOTE~Report on this form is for each calendar month, regardless of the status of operations, an~ must ~ file~ in duplicat~ required with the Division of Mines & Minerals by the 15th of the succeeding month, unless othe~ise directed. · Porto No. P---4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ~"~LL ~'ELL 0THgR SUBMIT IN DUPLICATE i HI.B TRM - ~ ' _ OKG ~ ~. AP! NU~IER/CAL bODE KLV.......... AP1 ~83..a0~8 HW~_ /£ 6. LF.,ASE DESiGN'Az'i~ON AXD SEI~.L lqO. ~ o ~ - ADL-37831 ?. IF I~DIA~, ALOTTE"~ OR TRI~J~,~ME Nerth 0eek Inlet 11. SEC., T., R., 1%{., CBOTTOM HOL~ OmmCT~) See' 36, T12N, RI~, S '1~$ ~. PEI~!VIIT NO. 13. REPORT TOTAL DEPTH AT F2qD OF MONTH, CHA~qGES IN HOLE SIZE, CASING AND CE~VIENTING JOBSINCLUDING DEPTH SET AN-D VOLLrNrEs USED, PERFOR-ATIONS, TESTS ANT) RESULTS. FISHING JOBS, JUNK IN HOLE AND SIDE-/-R~CKED HOLE AND ANY OTHER SIGNIFICANT CHAN,~E~ IN HOL~ CONDITIONS. 7-31 911)3' P~T~ 7-1/2-69 7-16/22-69 7-2-3-69 7-2A./Z6-69 Ram D~r #3. Perf's 7388' - 7398t ~ Ncaa. Drl4 15" hele. Ran 1D-3/~," esg' Set e 2985t. ~4 w/7~ ~ ~ "G" ea~t,.~ i~ 330 bbis prehy4rate4 &% ~ ~ w~r. Tailed w/l~5 ax Tn-- "~" em% ~ i. ~5 bb~s ~% t,lst ,mr. Drld 9-5/8" be~; Pipe stu~. ~t, ted ,~~e ~ w/diesel while J~ on.. fish..,Spe~%e~ Pipe-l~.x ~~ Jarrd_ng en ~sh. Ceul~ net Jar leese. ~aeked off ~.. Lef%. bits rmr, ~ ~eabi~zers, 2 menel ~, 6 steel oo~, ~ x~r ~bs, ~ its H.W. DP ~d 1 ~ j~:. Tep of ~sh 73~:t. ~ & set ~ ax ~ aG" ~ pl~. ~es~d ~ lm14 9-5/~" hele frem 71~'". aaa 7,, esg. Se~ e 915&,. ~4 w/565 sx ~ "G" 'emt ~ w/132 bbl~ pre~%ed ]9% Biaeel 'D' & 2% ee w~r. card 2nd stage w/8~ ax Type "C-" eat in ~ bbLs ~ ee wr, r. Drl4 eut stage eel & tested esg te ~, O*K. Pan CBL & GR Legs. Perferated 8375t - 8~5' /ES Neas. for BST ~1. Well had fair blew. Ree 1~$2t mm4 & ~0~" mmddy sand. '~T #1 - 2~ hr cleek: ~ 3272 PSt, FSIP 2~85 PSI, IF~ 37 PSI, FHP 3~J+7 PSI, 15 mi~ F~ 7~ PSI, 1 hr SIT ~399 PSI, ~ 99 ..PSI, FFP &A3 PSt, FSIP ~85 PSI, ~ 32A7. iS hr clock: ~ ~295 PSI, I/~ ~9 ~, 15 ~ ~ ~ ~, 1 ~ ~ ~ 14. I hereb~"c~i~i'~~oing is true and correct. ..,. SIGNED TITLE DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, aha must be filect in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed, Form No. REV. 9-30-67 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT O:F DRILLING AND WORKOVER OPERATIONS OIL [--~ GAS ~ WELL '-.~ WELL~ OTHER SUBMIT 13~ DEPLICATE AP1 NUAIERICAL CODE 6. LEASE DESIGNATION AND SEI~IAL iNTO. ?. IF Ii~DIA.N, ALOTTEE OR TRIBE NA~E 2. NA/~E OF OPEi%ATOR 3. ADDRESS OF OPER. A. TOR 515 "D" ~ree~ A~era~e; Alaska 4. LOCATION O'F WEI~ 8. LYNIT,FA3:MM OR L.EASE NAAIE Ner~h Oeek Inlet Unit 9. %VELL NO. 10. FIEJ.,D A_ND POOL, OR WILDCAT 11. SEC., T.. R.. 5i.. ~BOT'I'OM HOLE OBJECTIVE~ ~eo. 36, 1~. PE1R/~IT NO. REPORT TOTAL DEPTH AT END OF MONTH, CHA-NGES IN HOLE SIZE. CASING A_ND CEMENTING JOBS INCLUDING DEPTH SET A/WI) VOL~ USED, PEB.FORATIONS, TESTS A_ND RESULTS. FISHING JOBS. JIYNK IN HOLE AND SIDE-TI:LACKED HOLE AND A/~Y OTI-I~R SIGNIFICANT CItAblES IN HOI_~ CONDITIONS. 7-~-69 mira FP 7& PSI, 1 hr ~IP 2380 PSI, IFP 86 P~I, FFP 703 PSI, ~SIP 22~1 ~, F~P 3132 PSI. Perforate4 ?388" - 7398:' IES Meas. for ~T ~3. "~m~ f~r 3~' of ~ ~d & ~ of ~~. ~ ~3.- ~ ~ ~I, ~ ~ ~ ~3 PSI. ~ek ~ eut. ~ ~ o~: ~ 29~ P~, 6 ~, I5 ~ ~ ~3~ ~, 1 ~ ~ ~7 ~I, I~ ~7 ~ en 8" eheke, ~eh~ h~h ef ~, ~e4 te 3/8" =heke, . ~ ~ iow, ~ ~60 ~I W/~ hr [ p~ssm a~ b~g. 14. I hereby certify t~t,,th~ Ioregoin~ t rrect Dist. Oft ~r,DA',A',g' ' ~ ' Awxast /A. 1969 / N~rE--Report on this form is r~uJred for each calend~r month, regardless of the status of operations, anO must be filed in duplicate the Division of Mines & Minerals by the 15th of the succeeding month, unless othe~ise directed. Form 88;' 12-57 ^ 6012.S l~or..h Cook Inlet Unit PERFORATING AND SQUEEZE RECORD Well_ Slze of Cas!lng 11 11 I! 11 Il tt fl It I! t! t! Pefforafb9 IES MEASU!U 83!4' 8185' 8018' 7828' ?598' ' 739g' 7326' 705? ~ TEE FOLLOR~~. 004 5 ' From S375' / · 8.307 ~v' 818,0 '/ 8008 ' '/ 7¢22,/ 7583' ?~13'~ ?&?~' ~ 7388'/ 7309' ¢ 7218' / 7197 ' ~ 7030' / 'g PERFORATi( 602&' 603A ' Fee! Per!ora fed 6 15 2~ 10 10 17 2O 17 37 Holes 200 28 20 l~,0 21~. 60 !00 l~0 /4.,.0 80 ~L~EZ~D Size of Holes 1! It tl 1! l! 11 II GUll Olamefer J4,It II t! tt fl I! ft II ft It II II t! Gun Type No Plug Jt ii I! I! It Perfor~fing Company cn!umbe rge r-" Il !! Fo~m No. P--4 STATE OF ALASKA REV. 9-30-67 OIL AND GA5 CONSEEVATION CON~IITEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SUBMIT IN DEPLICATE WELL -- WELL 2. NANIE OF OPElq. ATOR Pb~l'14pm l~trele-m Ce ~mpany 3, ADDllESS OF OPEI~ATOR 515 "D" Street, L~che._~age, A~eka 4. LOCATION O.F WFJ~L $~rfae~e: Leg 3, Slet 2, 1255.6' FNL, 10~.k' ~, See. 6, TllN, RgW, S.H., North Oeek Inlet Pla%form "Tyomek" T?~ ef ~Y: ~' ~, 3~' T~, 25e' FSL, 1See' FEL, See. 36, ?12N, RI~W, ABL-37831 REL _. 7. IF INDIAN, ALOTTEE OR TRIBE NAAIE ~ - FiLE _ 8. U'NIT,FA.I:~M OR LEASE Nerth C,~k Inlet Unit 9. w~:LL NO. 10. 1'~ A_N'D POOL, OR WILDCAT 11. SEC., T., R., M.. (BOTTOM HOI~E O~IVE) 36: T12N: RiOW: PI~G~iIT NO. 69~_3 REPORT TOTAL DEPTH AT END OF MONTH, CI-IAArGES IN HOLE SI~E, CASING AN-D CE2VIEiNrlNG JOBS INCLUDING DEPTH SET A.ND VOLU1VIES USED, PERFORATIONS, TESTS A/XrD RESULTS, FISHING JOBS, JUlXTK I_N HOLE AND SIDE-WRACKED HOLE AND ANY OTHER SIGNIFICAi~T CHA3~GES IN HOL~ CONDITIONS. 6-30 6-26 6-27 6-28/30 2626 ' 2626' Drlg 15" hole. :8p~l 1y' hole amd drl~ te 635' & r~i %e ~". ~ 16" esg, 220 bbls pre-h~rate4 Drl4 15" 'hele te 2626'. ' '~'~' ' ' '- / -- ; h ,edit month re-;rdless of the status of operations /l~OTE~Report on this ~orm ~s required fe eac ca n , ~ , and must be filed in duplicate w~the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. AHCHO~AG~ ~502 TRM Ou]~ ]0, ]969 RE~, M~. John B. G~pson Ph~ 1 ] ~ ps Pe~o] eu~ Compan~ FILE 5]5 "D" Anchorage, Alaska 9950] Re' North Cook Inlet Unit #A-8 Phillips Petroleum Company, Operator Dear Mr. Gipson- In reference to the subject offshore drill-site the following stipulations are required to protect fish and game resources' 1. No material foreign to the environment will be discharged from this platform. This includes garbage, trash, refuse, petroleum and/or its products, drilling mud, and debris. 2. Drilling operations are not to interfere with commercial fishing. 3. The Habitat Biologist's Office, lOl8 West International Airport Road~ Anchorage, Alaska 99502 will be notified prior to the abandonment of this location. Statement- The foregoing provisions do not relieve the lessee and/or his contractors or assignees of any responsibilities or provisons required by law or regulation of the State of Alaska or the Federal Government. Sincerely yours, Robert J. Wienhold Habitat Biologist RJW:bb cc' B. Hilliker H. B~.r, el 1 P. Dei~ ~on OKG KI.V HWK ~ REL ~ jur~ ::26, 1969 DIVI$IO~ OF OIL ~ ~ 23, :].96~ Phtlltps Pet~oleuu Company 5~ '"l)~ St~ Anchorage, Alaska 99501 ~ion 6, To~htp liN, ~ell ,samples and, co~ chips are not required; however, a dt~Rt~ survey .is req~lrel. Other reqairema~s ,are n~t:ed on ~ pe~t. Very 't~u,ly yours, D~rec~or Labor v/o a~ach. FORM SA- I B MEMORANDUM FROM: State of Alaska DATE : SUBJECT= / / STATE O.F ALASKA SUBMIT IN TRIP ,rE (Other instructions on' reverse side) OIL AND GAS CONSERVATION ,COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLL~ BACK APl 50-283-20028 5. 6. LECkiE DIESIGNATION AXeD SEttIAL NO. ADL-37831 L IF 1T~DIAN, A~J~OT~1EE OR TI~JJ~E NA~E 8. UNIT~FARM OR LEASE NAME North Cook Inlet Unit 9. WELL NO. 10. FIELD AND POOL, OR WILDCAT North Cook Inlet 11. SEC.-, T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 36, T12N, R10W, W.M. 12. IR. TYPE OF WORK DRILL ]~ DEEPEN [--1 PLUG BACK [--] SINGLE[] MULTIPLE ~_~ 0IL ~-~WELL WELL 0AS ~ OTHER ZONE ZONE 2. NAME OF OPERATOR Phillips Petroleum Company 3. ADDRESS O'F OPERATE 515 "D" Street; Anchora_~e: Alaska 9950] 4. LOCATION OF Atsurface W~ 3, Slot 2, 1255.61 FNL, 1080.4! FWL, Sec. 6, T]lN, Rgb/, S.M. North Cook Inlet Platform "Tyonek" Atpro~sedpro'd. zone 5000' MD 3900' TVD 250! FSL, 1500 FEL, Sec. 36, T12N, RiOW. 13. DISTANCE IN iViI~ES .~NI~ DIRECTION FXOM NEAREST TOWN OR.POST OFFICE* 10.5 miles east of Tyonek, Alaska i4. BOND INFOP~AUUON: M-MI~IV State Wide Bend Rl-1 TYPE Surety and/or No. A~noun~ 15. DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT~ (Also to nearest drAg, unit, if any) ~18. DISTANCE FROM PROPOSED LOCATION* 1500 ' TO NEAREST WELL DRILLING, C.OMPLETED. OR APPLIED FOR, FT. 21. ELEVATIONS (Show whether DF, RT, C-R, etc.) RKB ll6~ from ~ 16. NO. OF ACRE~ IN LEASE I' 5002 ! 19. PROPOSED' DEPTH ' I 6/+00,, ~ :~17. NO. ACI~ES ASSIGNED TO THiS WELL 20. ROTARY OR CABLE TOOLS R~tary 22. APPROX. DANTE WORK WILL START* 6-2;+-69 23. P20,POSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING} ' WEIGHT pER FOOT GRADE ~ SmZNG D~ I ~ ~ A NTIT' OF C ~ ~ ~ N~ 22" ~ 16" ' 65~ H-40 600~ olc Circulate to sUrface 15" 10-3/~." ;.5.5~ &, 5~ J-55 ql~', ,~ ~ , ' ~rCu]at$ %0 Surface 1. Deviation required 'to reach BHL from permanent platform. 2. There are no effected operators. 3. BOP Specification attached. Intervals of interest will be perforated and may be stimulated. JUN o I9 9 INVL~)N OF OILANDGA~ * Refer to State of Alaska, AlaSka Oil & Gas Conservation Committee, Conservation Order #~0, dated 6-8-67 and #68, dated 12-7-68. NOTE: BHL: 1700' FSL, 1350' ~, Sec. 36, T~N, RiOW., S.M. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAdVI: If In'~posal is to deepen or plug hack, give data on present productive zone and proposed ne~t~ductive zo~e. If Proposal is to drill or deepen direct ~onally, give pertinent data on st~bsurface locations and measured and true vertfl d?ths. Give blowouypreventer program. 24. I hereby ceNti£y tl~ai, th~ Foregoing is ~ and Correct ._~ oD;~;RJO~2 i~Fg;Ny~.969' ' ' / ~ RE~UmaW~TS: &ff~6 $ .,..~ APPROVAL DATE June 20, 1969 PERMIT NO_ / _ APPROVEDBY .... 'TITLE.~'..~I' Of Oil & G~__~ DATE *See InstructiOns On Reverse Side , (" i ii i , iii ........ ii , ~,1 , i i u · 31 OPOSED B.H.L. A'8 ~ sec. ~S-mN-~OW ~.a. , 1700 FSL ~ 1350 FWL ~ I ~ ~-s TOP,of PAY ~ 250 FSL& 1500' FE~ ' ~A-I . ......... PHILLIPS ~ ',. . 8 DIVISION OF 0;[ AND AD/. 18741 ,iii[ [ N GRID ........ ..,~,.'S"~'~'"o~u~ ........... co~.~ - 515 "D" STREET ANCHORAGE ~ALASKA PLAT OF NORTH COOK INLET UNIT TYONEK PLATFORM ISCAL .E.'"i-i';', tO00' DRWN. N, d._~owell .... [DATE: ~-Z0-89 4~ Leg I Leg 4 Leg '2 North Cook Inlet. Unit N.C.h Un. A~ ~.~.,.u~-,~~j~ Leg 3 N.C.I. Un. A-~(~ N C (Un A'6,...~ N. C.I. Un. A-, N.C.h Un.A-2 JUN DNISION OF 0;[ AND GAS A~ICHOI~GE · ~ [i iiii ii iii - PHII~LIPS PETROLEUM COMPANY 515 "D' STREET ANCHORAGEIALASKA NORTH COOK INLET. TYONEK PLATFORM COOK INLET~ ALASKA, NOTEs Using PLATFORM NORTH, Slot No.! will be th~ furthest platform North slot in platform North- west quadrant of any legl Slots ore numbered I thru 8 in o counter-clock-wise direction. PLATFORI~ I~O~'~l~)~i; Sec.6-11N-gW t D~TIr:' ~-Z0'69 ..... "~""RWN. N.a. Pow~,ll .... " J NOT TO .SCALE: f. 36:31 31 3~ I 6 I LEG Ng. LAT. 6 97'5' o 04' 36.38" LEG N°-. 4 LAT. 61° 04' 36.89" LONG. 150° 56' 54.25" Y= 2~586,78 I X=. 3 $2,063 FROM N.W. COR. 1,198' SOUTH ...I,043' EAST· LONG.150° 56' 55.63" Y= 2,586,7;31 X= $31,995 FROM N.W. COR. ~25d SOUTH ~ 975' EAST. TIIN 6 5 LEG N-~. 2 -. LEG NO- .3 " LAT. 61° 04"35.83'!,:'.. LAT. 61u .04' 36.34" I 11 LONG; 150° 56 54,77 ~ :',LONG. 1500 56' 53.39" Y= 2,586,674 :i... :.'.:' '" ""~'. Y=2,586,724 X= 332,036...':.:'~' '-. :.:'X= 332,105 FROM N.W. COR,' ?'''~::' "': ·FROM N ,W. COR. 1,305' SOUTH ~ ..'.-.. .I,254' SOUTH ~ · 1,018' EAST....~: .!,085"EAST.: NOTE: Plat amended 7AUG.68' t'o show revised leg numbering. NOTE The location of the platform legs was accomplished by using trio ngu lotion stations BELUGA,TERRACE,and TYONEK which ore all U.S.C.& G.S. stations. AIl coordinates are Alaska State Plane, Zone 4. , NORTH COOK I NLETUNIT · PLATFORM"A" ' ' FOR pHILLIPS PETROLEUM CO DA, TE!'~21' SCALE: I"= 1000'_'_ ~ 'L~nd ~ Hydrographic FB. II374 Pp.' 11-15 Surveyors ORWN. tC,~(~ JC.C. "- 2502 W. NORTHERNL IG ,1~ BLVD. ..~JHG... I I I' .i1:574 S~N^,O, eox4:oa~ ALASKA CERTIFICATE OF SURVEYOR .. I hereby certify thor I om properly registered ond 'Ii [ iq to practice land surveying in ~e State of Alaska and that this plat represents o IocOtion suwey mode by m'e ...~ or under my supervts~on and that oil d~mens~ons and .'-:~;~:~ other details are correct ' _ ': ," HOOZUP FOR DOUBLE PREVENTERS / --;-_ j , -- ". :..... '5_-"-~~~-~'''~°'-°. ® ~" ~,o ~,.,~s~.~ ~^~,~ o,,, ~".~ ~ (eUNO RAMS). ~ '-' : "' :- -~?'':':"~- ~ "~' -' STE~L CROSS ,' - ' ' ' ' .... e ¢ {= ,,, ,,~. Ii, ,,, ,,, 4) I ~ ' ' " " ' ' 15oo .... . - I ) - - - · · ' ':" :~':'. " -'- ' "' . ' ' ' ' , · ' ' ' ;.:- -.'-~:-'.'-::": ~-.' ': ' ~ "'-' :-~.:--".-'~_/" ;:;.."' ':.: ':7.':.;'::'::'-~-..~. ~-~~0~ s~...-.,...-,.:..-'': ' ~-' .. -.-.-~_:---..-.,....-_ ..:-. - ~ . ~ ~,,~ ,,,,,s, ~ ."-.~" '","'--' ' ~ ~. ": .'-.' "--'-: ' _-.'.~ --.~."-:'. :... '~ _. . - . ':~ ,- '~ '.'.' '-"'- ;-.-..'; '.' ~--.' ~..m ~ ' '""-":"'~'~--'" ' '. . ...... __, ...................... _.__ ' ' - ' -' ' '-: '- ~ :.' -, I ~ ,~ r--- ~ h' ' ~ ~ ':.'.:.---:;.~.-:'_.}:'.;.....,.: ;:~.... ...... . . · -' ' ' ' * ' : ;~"' ' -' ; -; :- '-: ' :. i... ~ "-.. .- ' . NOTE: Double Preventers are used ~rlth flanged side -outlets for choke manifold · and fillup line connec~tions... .'.. ::.., ?~._ . 5000 PSI WORKING PR''-'ee',_.-,¢,,,.,n,... r" / BLO\VOUT PR.-\ ENTE,, HOOK-UP I "' '"' ~.~ (SERIES 1500 FL AN(,,.-_ o OR BETTER} Company Phillips Petroleum Company ADL 37831 Lease & Well No. North COok Inlet A-8 LIST FOR NE~'~I WELL PERMITS Yes No Remarks 1. Is well to be located in a defined pool ................. /q~4~, 2. Do statewide rules apply ......................... Is a registered s~vey plat Is well located proper distance from ............ ,' . . prot. x:-:.,~y 1 i ne ......... ~:,~ well 1 ..... · ocat,.:,.:~ proper di¢~"a ,.~,~-nce from other wells ............ ~_~_~. .~' ~'-~ ndedi ':.:i 6. Is st.'~:fic'i,,:~ u (:a,~,-~, acreaqe available in this pool ........ 7. Is well to be deviated ......................... ~¢' ........................................ =,~ ,.~ af~ ect~=c party ................... ~.~ 8. Is operator the only '~'~ ',,~ : . 9. Can permit be approved before ten-day wait ............... ~ ~ lO. Doe?, c,i::~::~':tor haw~ a bond in force .................. .~___~,/_~-, ll. Is conductor string provided ..................... ,i 12. )~; enough cement used to circulate on conductor and surface ...... l~' Will cement tie in surface and intermediate or production strings, . . ~, 14. Will cement cover all possible productive horizons ........... 15, Will sL~rface casing cover all fresh water zones ............ 16. Will surface csg. internal burst equal .5 psi/ft, to next string . . . .~. .... 17. Will all casing give adequate safety in collapse and tension ..... 18..Does BOPE have sufficient pressure rating . . ."..".'"~':~'.:'"- - - ..... Additional Requirements' ~~ ~ ~~ ApproVal Re~o~ended- TRd~, , 1 ;_ !