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Home My WebLink About192-1171. 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: Wellhead repair treatment 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 10,410 feet 10,327 feet true vertical 10,020 feet N/A feet Effective Depth measured 10,327 feet 9,606 & 9,670 feet true vertical 9,943 feet 9,286 & 9,344 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 7" 26# / NT80S 9,674' 9,347' 7" SABL-3 1,503' MD Packers and SSSV (type, measured and true vertical depth)7" TIW LTP See Above RPB SSSV 1,500' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Same 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:Operations Manager Contact Phone: Burst NA Collapse NA 2,260psi 5,090psi 7,020psi 5,020psi 6,870psi 8,150psi 8,160psi 4,760psi TVD 9-5/8"9,587' Production Production 30" 9-5/8" 120' 2,738' Casing 13-3/8" Conductor 2,777'Surface 10,020' 9,940' 10,410' 8,357' 8,395' 8,208' ENDICOTT / ENDICOTT OIL DUCK IS UNIT MPI 2-12 Plugs Junk measured measured NA 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0034633 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 192-117 50-029-22302-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC 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 1839 0 186633,837 0 37090 4231 22,304 N/A measured true vertical Packer MD 120' Size 120' 2,771' Length Liner 1,545' 740'7" Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ryan Thompson ryan.thompson@hilcorp.com 907-564-5005 325-034 PL G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 12:26 pm, Sep 09, 2025 Digitally signed by Justus Hinks (3691) DN: cn=Justus Hinks (3691) Reason: I attest to the accuracy and integrity of this document Date: 2025.09.09 10:36:08 -08'00' Justus Hinks (3691) J.Lau 11/4/25 RBDMS JSB 091225 DSR-9/11/25 Well Name Rig API Number Well Permit Number Start Date End Date END 2-12 Well Diagnostics 50-029-22302-00-00 192-117 2/28/2025 8/13/2025 7/20/2025 - Sunday Slickline: ***WELL INJECTING ON ARRIVAL*** PULLED MBR SSSV FROM LANDING NIPPLE @ 1503' MD BRUSHED R NIPPLE @ 9668' MD MADE UNSUCCESSFUL ATTEMPT AT SETTING 5.96 PR PLUG BODY *** WSR CONT ON 7/21 *** Fullbore: (Assist S-Line) TFS U4, Initial WHP T/ I/ O = 3100/550/0, pumped 10 bbls spear 60/40 followed by 497 bbls 2% KCL to load and secure well, Pumped 10 bbls pill followed by 60 bbls DSL to FP TBG, SL led in with plug body, ***WSR cont for new day*** 2/28/2025 - Friday T/I/O = BPV/1500/0. Temp = SI. Greenstick re-treat tubing test void. Bled IAP to 0 psi in 20 min (gas). R/U packing gun to Hoke valve, pump up to 5000 psi, wait for pressure to stablize. Bump pressure up to 5000 psi in attempt to get returns (no returns). Bump pressure up multiple times until stablized @ 5000 psi, Repeat from opposing test port with same results. Held 5000 psi for 30 min on both side. Pumped less then 1/4 of gun total. SV = C. WV, SSV, MV = O. IA, OA = OTG. 18:00 Hilcorp Alaska, LLC Weekly Operations Summary T/I/O = BPV/0/0. Pulled 6" J BPV w/ QTS and 1' extension. RDMO. FWP = 2680/0/0. GREEN STICK TBG HGR VOID T/I/O= BPV/0/0 Green stick had previously been pumped into TBG HGR void through test port. Pulled front LDS on TBG head, installed packing gun with modified LDS. Pumped green stick and pressured up to 5000, pulled Mod. LDS. Re install LDS and move to back side. Pumped up to 5000 psi and move to left and right sides. RU to TBG HGR test void with packing gun and pressure up to 5000, monitored for 30 min. RD packing gun. 3/1/2025 - Saturday 3/4/2025 - Tuesday Well Name Rig API Number Well Permit Number Start Date End Date END 2-12 Well Diagnostics 50-029-22302-00-00 192-117 2/28/2025 8/13/2025 Hilcorp Alaska, LLC Weekly Operations Summary Slickline: ***POLLARD 63 RIG DOWN*** 7/31/2025 - Thursday ***WELL S/I ON ARRIVAL*** FUNCTION TEST WLV=PASS BRUSH 7" OTIS SVLN @ 1,503' MD M/U 7" PLUG ***CONT WSR ON 8/1/25*** 8/1/2025 - Friday ***CONT WSR FROM 7/31/25*** SET 7" RBP PLUG BODY(6.05") IN RPB SVLN @ 1,503' MD (lih: 54") SET CENTRALIZED P-PRONG IN 7" PLUG BODY @ 1,503' MD (lih: 114") ***WELL S/I ON DEPARTURE, PAD-OP NOTIFIED ON WELL STATUS*** 7/21/2025 - Monday Slickline: ** WSR CONT FROM 7/20 *** SET 5.962'' PR-PLUG BODY IN R-NIP @ 9668'MD SET P-PRONG IN PLUG BODY @ 9668'MD CONDUCT PASSING CMIT-TxIA *** WSR CONT ON 7/22 *** Fullbore: (Assist S-Line) TFS U4 Initial WHP T/ I/ O= 434/ 429/ 0, Pumped 74 bbls DSL down TBG to lube and bleed, pressured TBG up to 2020psi let TBG stabilize for 1 hour and bled back only energized fluid, bled IA from 532 psi down to 50 psi, opened jumper hose to both TBG/IA to equilize pressure between strings, ***Pumped 6 bbls DSL down TBG/IA to reach MAP @ 2762/2734/0 for CMIT-TxIA, First 15 minutes TBG lost 83 psi and IA lost 16 psi, Second 15 minutes TBG lost 39 and IA lost 6, resulting in a ***PASSING*** CMIT-T/IA, Bled back 8 bbls DSL, Final WHP T/I/O= 707/702/0 ***Well left in pollard SL control*** **** Called off well to assit another S-Line Unit on well 2-56 **** Job will continue on 7-21-2025 **** 7/22/2025 - Tuesday Well Name Rig API Number Well Permit Number Start Date End Date END 2-12 Well Diagnostics 50-029-22302-00-00 192-117 2/28/2025 8/13/2025 Hilcorp Alaska, LLC Weekly Operations Summary ***CONTINUED FROM 8/12/25 WSR*** PULLED PLUG BODY FROM 9,668' MD SET 7" MBR(sn=HNF001) IN SVLN @ 1,503' MD ***WELL LEFT S/I ON DEPARTURE, WELL TENDER NOTIFIED OF STATUS*** 8/5/2025 - Tuesday T/I/O=0/0/0 Set "J" TWC #408 with dry rod, WS nipple down tree & THA. Clean & inspect SBMS & "S" seal profile. Remove enough green stick to access ¼" control lines. Splice the control lines to add length to exit new THA. Pressure control lines at 5k to test splice. (good test) Install new SBMS in tubing hanger neck & "S" seals in new THA. Install new BX-159 ring gasket, Nipple up new THA feeding1/4" control line though termination ports. Terminate the1/4" control line outside the THA & leave 2' +/- of control line exiting the ports. Sting monitor port. Rig up to test port & pump hydraulic fluid across the void, pressure up to 8000 psi with consistent pressure loss by the body of the tubing hanger & no fluid loss by the "S" seals. Bleed pressure from tubing hanger void. Pressure up SBMS monitor port at 500 psi with no pressure loss after 30 min, bleed pressure from monitor port. WS nipple up tree & test at 6500 psi with SBMS monitor port open (good test). No pressure loss by the SBMS seal. Cap1/4" control line, check out with WS RDMO. Both the SBMS & "S" seasl are holding pressure as they should. The tubing hanger body seal is leaking. The tubing hanger void is still packed with green stick from the tubing head flange down to the tubing hanger body seal. Final WHP's T/I/O=0/0/0 8/12/2025 - Tuesday Slickline: ***WELL S/I ON ARRIVAL*** PULLED 7" RBP PLUG AT 1,503' MD PULLED P-PRONG FROM 7" PR PLUG AT 9,668' MD PULLED 7" PR PLUG BODY AT 9,668' MD & LEFT IT IN SVLN AT 1,503' MD (GS sheared) ***CONTINUE ON 8/13/25 WSR*** 8/13/2025 - Wednesday 13326 HILCORP ALASKA, LLC 10326 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Operable - GI END 2-12 (PTD:1921170) - Post neck seal replacement Date:Tuesday, September 9, 2025 3:27:43 PM Attachments:END2-12 Sundry #325-034.pdf From: Stephen Soroka <Steve.Soroka@hilcorp.com> Sent: Tuesday, September 9, 2025 3:22 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: RE: Operable - GI END 2-12 (PTD:1921170) - Post neck seal replacement Mr. Wallace, Gas Injector END 2-12 (PTD: 1921170) had the tubing head adaptor removed and neck seals replaced on 8/5/25, per sundry #325-034. The well was placed on injection on 8/15/25 and had an IA thermal bleed on 8/22/25. There has been no indication of Tubing by IA communication since the bleed. See attached 30-day TIO plot. The Well has been re-classified as operable. Please respond with any questions or concerns. Thank you, Steve Soroka Hilcorp Alaska LLC Field Well Integrity Steve.Soroka@hilcorp.com P: (907) 830-8976 Alt: Chris Casey From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Friday, April 11, 2025 10:07 AM To: Ryan Thompson <Ryan.Thompson@hilcorp.com>; jim.regg <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: [EXTERNAL] Re: UNDER EVALUATION: Gas Injector END 2-12 (PTD #192117) TxIA communication Ryan, Thank you for the email, and call of yesterday. This plan and continued injection under evaluation is approved. Monthly reporting of TIO and bleeds flagged. Fixed or shut in by September 30, 2025. Regards, Chris From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, April 11, 2025 9:54:46 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Gas Injector END 2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas Injector END 2-12 had a wellhead greenstick treatment performed on 3/1/25. IA pressures remained low until starting to build on 3/28/25 as shown in the attached 30 day TIO plot. As we discussed, the next step in attempting to repair the TxIA communication is to secure the well, remove the tubing head adapter (THA) and replace the neck seals. Replacement seals/parts are on order but are currently expected to arrive on the slope in July 2025. These steps are included in approved sundry #325-034. In May 2025 the well is due for its 4 year MIT-IA, if the well fails its 4 year MIT-IA the well will be shut in and made not operable. Approval is requested to leave this well online under evaluation until the wellhead seal replacement parts are received in Prudhoe Bay in July 2025 and replacement can be executed per approved sundry #325-034. Monthly TIO plots will be provided to AOGCC. Please respond with any questions or comments. Thank you, Ryan Thompson 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 steve.soroka@hilcorp.com. Learn why this is important CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Thursday, March 13, 2025 2:29 PM To: Stephen Soroka <Steve.Soroka@hilcorp.com>; jim.regg <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com>; Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: [EXTERNAL] RE: Request to extend: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Steve, Approved for additional 28 days monitoring and diagnostics. 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: Stephen Soroka <Steve.Soroka@hilcorp.com> Sent: Thursday, March 13, 2025 2:05 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com>; Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: Request to extend: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas Injection Well END2-12 received a sealant treatment on the tubing hanger test void on 3/4/25. With your approval, we would like to keep the well under eval for an additional 28 days to evaluate the treatment. Attached TIO plot since the treatment. Please respond at your earliest convenience. Thank You Steve Soroka Steve Soroka Hilcorp Alaska LLC Field Well Integrity Steve.Soroka@hilcorp.com P: (907) 830-8976 From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, February 14, 2025 2:33 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; jim.regg <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace – On 2/6/25 sundry #325-034 was approved for END 2-12 to attempt an additional sealant treatment on the tubing hanger test void. We plan to execute the work in the coming days. Following the sealant treatment, we will monitor for IA re-pressurization. Included in sundry #325-034 is work scope to pull the THA and replace neck seals pending success of the upcoming sealant treatment. The well will remain under evaluation for an additional 28 days to perform the sealant treatment, monitor for success & determine plan forward on the pending neck seal replacement job. Attached is a 90 day TIO plot. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, January 17, 2025 11:57 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace – Following the completion of the second greenstick treatment on the tubing hanger void on 12/16/24, TxI build up rate has improved but has not been eliminated on END 2-12, as shown in the attached 90 day TIO plot. Our plan forward is to submit a second 10-403 to attempt a tubing hanger void sealant treatment with an alternative product to greenstick, if this is unsuccessful the 10-403 will include steps to pull the tubing head adapter (THA) and replace the neck seals. The well will remain under evaluation while the 10-403 is submitted. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, December 20, 2024 10:11 AM To: 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov>; 'Regg, James B (OGC)' <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace – On 12/16/24 a second greenstick treatment was completed on the tubing hanger void on END 2-12. In order to continue to monitor the effectiveness of this treatment on IA re- pressurization, we will leave the well under evaluation for an additional 28 day monitoring period. Attached is a 30 day TIO plot. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, November 22, 2024 3:39 PM To: 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov>; 'Regg, James B (OGC)' <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace – On 10/27 the greenstick treatment on the tubing hanger void on END 2-12 (PTD #192117) was completed and the well was placed back online, the IA pressure remained <100 psi until 11/15 when the IA pressure began to build. This weekend we plan to again set the J plug and perform a re-treat of the tubing hanger void with greenstick under the approved 10-403. The well will remain under evaluation for an additional 28 days to monitor the re-treatment results. Attached is a 30 day TIO plot. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, October 25, 2024 3:01 PM To: 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov>; 'Regg, James B (OGC)' <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Following the 10-403 approval for END 2-12 (PTD# 192117) on 10/2/24 to perform the tubing hanger wellhead treatment, a J-plug has been set and the treatment has been ongoing since 10/19/24. We expect the wellhead treatment to conclude in the coming days and the J-plug will be removed from the well. We will then place the well back on injection and monitor for the duration of an additional 28 day under evaluation period to verify effectiveness of the treatment. If you have any questions or concerns with the plan forward please reach out. Attached is a 30 day TIO plot. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, September 27, 2024 1:52 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas Injector END 2-12 (PTD# 1921170) had the following troubleshooting operations performed following identification of TxI communition: 9/1/24: PPPOT-T – established communication across the primary wellhead seal. 9/12/24: A J-Plug was set and a leak path evaluation (LPE) established communication across the neck seal. 9/15/24: The SSSV was pulled and replaced. The well is online with an IA build up rate of ~300-400 psi / day. A sundry was submitted on 9/25/24 to perform a wellhead treatment on the tubing hanger test void. Per our communication the well will remain online Under Evaluation for an additional 28 day period. Once the sundry submittal is approved, the wellhead treatment will be performed and the well monitored for TxI communication. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, September 1, 2024 4:47 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Ryan Thompson <Ryan.Thompson@hilcorp.com>; Alaska NS - Endicott - Field Foreman <AlaskaNS- Endicott-Field-Foreman@hilcorp.com> Subject: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas injector END2-12 (PTD 192117) was reported by operations with increasing IA pressure while shut in on 09/01. The IA pressure was bled from ~900 psi to 300 psi, a re-pressurization rate of 20 psi / hr was observed post bleed. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Slickline: Troubleshoot / repair SSSV. 2. Well Integrity: Further action as required. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 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 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 delete this 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 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, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this 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. 6= Wdl: z-lz aoo • 280 5500 260 5,000 21 TIO Plot a5W 220 200 tTubing 4.000 On 1&1 Bleed log * Operable E 3,000 1aa m } Not Oper ♦ Under Eval n 2b00 120 m f— Man. IA 100 —� Man. OA 2.000 Man. OOA l,ypp +- Man. OOOA 60 ) Man. WNT 1,000 � 500 20 0EiV925 M1125 Wl W5 wl1 0&1725 08l1 0 W5 002325 Ofl?5?5 082]f15 OB24R5 063125 09N21G5 09NY15 039625 09(0&25 J MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 23, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 2-12 DUCK IS UNIT MPI 2-12 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/23/2025 2-12 50-029-22302-00-00 192-117-0 G SPT 9286 1921170 2322 3511 3512 3509 3510 8 17 15 15 4YRTST P Bob Noble 5/16/2025 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:DUCK IS UNIT MPI 2-12 Inspection Date: Tubing OA Packer Depth 637 2600 2584 2577IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250516161339 BBL Pumped:4.3 BBL Returned:3.5 Wednesday, July 23, 2025 Page 1 of 1            From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Gas Injector END 2-12 (PTD #192117) TxIA communication Date:Monday, April 14, 2025 9:30:00 AM Attachments:END 2-12 - 30 day TIO.docx From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, April 11, 2025 9:54 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Gas Injector END 2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas Injector END 2-12 had a wellhead greenstick treatment performed on 3/1/25. IA pressures remained low until starting to build on 3/28/25 as shown in the attached 30 day TIO plot. As we discussed, the next step in attempting to repair the TxIA communication is to secure the well, remove the tubing head adapter (THA) and replace the neck seals. Replacement seals/parts are on order but are currently expected to arrive on the slope in July 2025. These steps are included in approved sundry #325-034. In May 2025 the well is due for its 4 year MIT-IA, if the well fails its 4 year MIT-IA the well will be shut in and made not operable. Approval is requested to leave this well online under evaluation until the wellhead seal replacement parts are received in Prudhoe Bay in July 2025 and replacement can be executed per approved sundry #325-034. Monthly TIO plots will be provided to AOGCC. Please respond with any questions or comments. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Thursday, March 13, 2025 2:29 PM To: Stephen Soroka <Steve.Soroka@hilcorp.com>; jim.regg <jim.regg@alaska.gov> 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 steve.soroka@hilcorp.com. Learn why this is important CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Cc: Justus Hinks <jhinks@hilcorp.com>; Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: [EXTERNAL] RE: Request to extend: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Steve, Approved for additional 28 days monitoring and diagnostics. 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: Stephen Soroka <Steve.Soroka@hilcorp.com> Sent: Thursday, March 13, 2025 2:05 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com>; Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: Request to extend: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas Injection Well END2-12 received a sealant treatment on the tubing hanger test void on 3/4/25. With your approval, we would like to keep the well under eval for an additional 28 days to evaluate the treatment. Attached TIO plot since the treatment. Please respond at your earliest convenience. Thank You Steve Soroka Steve Soroka Hilcorp Alaska LLC Field Well Integrity Steve.Soroka@hilcorp.com P: (907) 830-8976 From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, February 14, 2025 2:33 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; jim.regg <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace – On 2/6/25 sundry #325-034 was approved for END 2-12 to attempt an additional sealant treatment on the tubing hanger test void. We plan to execute the work in the coming days. Following the sealant treatment, we will monitor for IA re-pressurization. Included in sundry #325-034 is work scope to pull the THA and replace neck seals pending success of the upcoming sealant treatment. The well will remain under evaluation for an additional 28 days to perform the sealant treatment, monitor for success & determine plan forward on the pending neck seal replacement job. Attached is a 90 day TIO plot. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, January 17, 2025 11:57 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace – Following the completion of the second greenstick treatment on the tubing hanger void on 12/16/24, TxI build up rate has improved but has not been eliminated on END 2-12, as shown in the attached 90 day TIO plot. Our plan forward is to submit a second 10-403 to attempt a tubing hanger void sealant treatment with an alternative product to greenstick, if this is unsuccessful the 10-403 will include steps to pull the tubing head adapter (THA) and replace the neck seals. The well will remain under evaluation while the 10-403 is submitted. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, December 20, 2024 10:11 AM To: 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov>; 'Regg, James B (OGC)' <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace – On 12/16/24 a second greenstick treatment was completed on the tubing hanger void on END 2-12. In order to continue to monitor the effectiveness of this treatment on IA re- pressurization, we will leave the well under evaluation for an additional 28 day monitoring period. Attached is a 30 day TIO plot. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, November 22, 2024 3:39 PM To: 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov>; 'Regg, James B (OGC)' <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace – On 10/27 the greenstick treatment on the tubing hanger void on END 2-12 (PTD #192117) was completed and the well was placed back online, the IA pressure remained <100 psi until 11/15 when the IA pressure began to build. This weekend we plan to again set the J plug and perform a re-treat of the tubing hanger void with greenstick under the approved 10-403. The well will remain under evaluation for an additional 28 days to monitor the re-treatment results. Attached is a 30 day TIO plot. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, October 25, 2024 3:01 PM To: 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov>; 'Regg, James B (OGC)' <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Following the 10-403 approval for END 2-12 (PTD# 192117) on 10/2/24 to perform the tubing hanger wellhead treatment, a J-plug has been set and the treatment has been ongoing since 10/19/24. We expect the wellhead treatment to conclude in the coming days and the J-plug will be removed from the well. We will then place the well back on injection and monitor for the duration of an additional 28 day under evaluation period to verify effectiveness of the treatment. If you have any questions or concerns with the plan forward please reach out. Attached is a 30 day TIO plot. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, September 27, 2024 1:52 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas Injector END 2-12 (PTD# 1921170) had the following troubleshooting operations performed following identification of TxI communition: 9/1/24: PPPOT-T – established communication across the primary wellhead seal. 9/12/24: A J-Plug was set and a leak path evaluation (LPE) established communication across the neck seal. 9/15/24: The SSSV was pulled and replaced. The well is online with an IA build up rate of ~300-400 psi / day. A sundry was submitted on 9/25/24 to perform a wellhead treatment on the tubing hanger test void. Per our communication the well will remain online Under Evaluation for an additional 28 day period. Once the sundry submittal is approved, the wellhead treatment will be performed and the well monitored for TxI communication. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, September 1, 2024 4:47 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Ryan Thompson <Ryan.Thompson@hilcorp.com>; Alaska NS - Endicott - Field Foreman <AlaskaNS- Endicott-Field-Foreman@hilcorp.com> Subject: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas injector END2-12 (PTD 192117) was reported by operations with increasing IA pressure while shut in on 09/01. The IA pressure was bled from ~900 psi to 300 psi, a re-pressurization rate of 20 psi / hr was observed post bleed. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Slickline: Troubleshoot / repair SSSV. 2. Well Integrity: Further action as required. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 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 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. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Gas Injector END 2-12 (PTD #192117) TxIA communication Date:Monday, April 14, 2025 9:29:36 AM From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Friday, April 11, 2025 10:07 AM To: Ryan Thompson <Ryan.Thompson@hilcorp.com>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: Re: UNDER EVALUATION: Gas Injector END 2-12 (PTD #192117) TxIA communication Ryan, Thank you for the email, and call of yesterday. This plan and continued injection under evaluation is approved. Monthly reporting of TIO and bleeds flagged. Fixed or shut in by September 30, 2025. Regards, Chris From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, April 11, 2025 9:54:46 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Gas Injector END 2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas Injector END 2-12 had a wellhead greenstick treatment performed on 3/1/25. IA pressures remained low until starting to build on 3/28/25 as shown in the attached 30 day TIO plot. As we discussed, the next step in attempting to repair the TxIA communication is to secure the well, remove the tubing head adapter (THA) and replace the neck seals. Replacement seals/parts are on order but are currently expected to arrive on the slope in July 2025. These steps are included in approved sundry #325-034. In May 2025 the well is due for its 4 year MIT-IA, if the well fails its 4 year MIT-IA the well will be shut in and made not operable. 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 You don't often get email from steve.soroka@hilcorp.com. Learn why this is important CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Approval is requested to leave this well online under evaluation until the wellhead seal replacement parts are received in Prudhoe Bay in July 2025 and replacement can be executed per approved sundry #325-034. Monthly TIO plots will be provided to AOGCC. Please respond with any questions or comments. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Thursday, March 13, 2025 2:29 PM To: Stephen Soroka <Steve.Soroka@hilcorp.com>; jim.regg <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com>; Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: [EXTERNAL] RE: Request to extend: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Steve, Approved for additional 28 days monitoring and diagnostics. 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: Stephen Soroka <Steve.Soroka@hilcorp.com> Sent: Thursday, March 13, 2025 2:05 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com>; Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: Request to extend: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication is safe. Mr. Wallace, Gas Injection Well END2-12 received a sealant treatment on the tubing hanger test void on 3/4/25. With your approval, we would like to keep the well under eval for an additional 28 days to evaluate the treatment. Attached TIO plot since the treatment. Please respond at your earliest convenience. Thank You Steve Soroka Steve Soroka Hilcorp Alaska LLC Field Well Integrity Steve.Soroka@hilcorp.com P: (907) 830-8976 From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, February 14, 2025 2:33 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; jim.regg <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace – On 2/6/25 sundry #325-034 was approved for END 2-12 to attempt an additional sealant treatment on the tubing hanger test void. We plan to execute the work in the coming days. Following the sealant treatment, we will monitor for IA re-pressurization. Included in sundry #325-034 is work scope to pull the THA and replace neck seals pending success of the upcoming sealant treatment. The well will remain under evaluation for an additional 28 days to perform the sealant treatment, monitor for success & determine plan forward on the pending neck seal replacement job. Attached is a 90 day TIO plot. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, January 17, 2025 11:57 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace – Following the completion of the second greenstick treatment on the tubing hanger void on 12/16/24, TxI build up rate has improved but has not been eliminated on END 2-12, as shown in the attached 90 day TIO plot. Our plan forward is to submit a second 10-403 to attempt a tubing hanger void sealant treatment with an alternative product to greenstick, if this is unsuccessful the 10-403 will include steps to pull the tubing head adapter (THA) and replace the neck seals. The well will remain under evaluation while the 10-403 is submitted. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, December 20, 2024 10:11 AM To: 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov>; 'Regg, James B (OGC)' <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace – On 12/16/24 a second greenstick treatment was completed on the tubing hanger void on END 2-12. In order to continue to monitor the effectiveness of this treatment on IA re- pressurization, we will leave the well under evaluation for an additional 28 day monitoring period. Attached is a 30 day TIO plot. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, November 22, 2024 3:39 PM To: 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov>; 'Regg, James B (OGC)' <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace – On 10/27 the greenstick treatment on the tubing hanger void on END 2-12 (PTD #192117) was completed and the well was placed back online, the IA pressure remained <100 psi until 11/15 when the IA pressure began to build. This weekend we plan to again set the J plug and perform a re-treat of the tubing hanger void with greenstick under the approved 10-403. The well will remain under evaluation for an additional 28 days to monitor the re-treatment results. Attached is a 30 day TIO plot. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, October 25, 2024 3:01 PM To: 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov>; 'Regg, James B (OGC)' <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Following the 10-403 approval for END 2-12 (PTD# 192117) on 10/2/24 to perform the tubing hanger wellhead treatment, a J-plug has been set and the treatment has been ongoing since 10/19/24. We expect the wellhead treatment to conclude in the coming days and the J-plug will be removed from the well. We will then place the well back on injection and monitor for the duration of an additional 28 day under evaluation period to verify effectiveness of the treatment. If you have any questions or concerns with the plan forward please reach out. Attached is a 30 day TIO plot. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, September 27, 2024 1:52 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas Injector END 2-12 (PTD# 1921170) had the following troubleshooting operations performed following identification of TxI communition: 9/1/24: PPPOT-T – established communication across the primary wellhead seal. 9/12/24: A J-Plug was set and a leak path evaluation (LPE) established communication across the neck seal. 9/15/24: The SSSV was pulled and replaced. The well is online with an IA build up rate of ~300-400 psi / day. A sundry was submitted on 9/25/24 to perform a wellhead treatment on the tubing hanger test void. Per our communication the well will remain online Under Evaluation for an additional 28 day period. Once the sundry submittal is approved, the wellhead treatment will be performed and the well monitored for TxI communication. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, September 1, 2024 4:47 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Ryan Thompson <Ryan.Thompson@hilcorp.com>; Alaska NS - Endicott - Field Foreman <AlaskaNS- Endicott-Field-Foreman@hilcorp.com> Subject: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas injector END2-12 (PTD 192117) was reported by operations with increasing IA pressure while shut in on 09/01. The IA pressure was bled from ~900 psi to 300 psi, a re-pressurization rate of 20 psi / hr was observed post bleed. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Slickline: Troubleshoot / repair SSSV. 2. Well Integrity: Further action as required. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 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 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. 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 steve.soroka@hilcorp.com. Learn why this is important From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Request to extend: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Date:Thursday, March 13, 2025 2:30:31 PM From: Wallace, Chris D (OGC) Sent: Thursday, March 13, 2025 2:29 PM To: Stephen Soroka <Steve.Soroka@hilcorp.com>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com>; Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: RE: Request to extend: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Steve, Approved for additional 28 days monitoring and diagnostics. 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: Stephen Soroka <Steve.Soroka@hilcorp.com> Sent: Thursday, March 13, 2025 2:05 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com>; Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: Request to extend: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas Injection Well END2-12 received a sealant treatment on the tubing hanger test void on 3/4/25. With your approval, we would like to keep the well under eval for an additional 28 days to evaluate the treatment. Attached TIO plot since the treatment. Please respond at your earliest convenience. Thank You Steve Soroka Steve Soroka Hilcorp Alaska LLC Field Well Integrity Steve.Soroka@hilcorp.com P: (907) 830-8976 From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, February 14, 2025 2:33 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; jim.regg <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace – On 2/6/25 sundry #325-034 was approved for END 2-12 to attempt an additional sealant treatment on the tubing hanger test void. We plan to execute the work in the coming days. Following the sealant treatment, we will monitor for IA re-pressurization. Included in sundry #325-034 is work scope to pull the THA and replace neck seals pending success of the upcoming sealant treatment. The well will remain under evaluation for an additional 28 days to perform the sealant treatment, monitor for success & determine plan forward on the pending neck seal replacement job. Attached is a 90 day TIO plot. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, January 17, 2025 11:57 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace – Following the completion of the second greenstick treatment on the tubing hanger void on 12/16/24, TxI build up rate has improved but has not been eliminated on END 2-12, as shown in the attached 90 day TIO plot. Our plan forward is to submit a second 10-403 to attempt a tubing hanger void sealant treatment with an alternative product to greenstick, if this is unsuccessful the 10-403 will include steps to pull the tubing head adapter (THA) and replace the neck seals. The well will remain under evaluation while the 10-403 is submitted. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, December 20, 2024 10:11 AM To: 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov>; 'Regg, James B (OGC)' <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace – On 12/16/24 a second greenstick treatment was completed on the tubing hanger void on END 2-12. In order to continue to monitor the effectiveness of this treatment on IA re- pressurization, we will leave the well under evaluation for an additional 28 day monitoring period. Attached is a 30 day TIO plot. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, November 22, 2024 3:39 PM To: 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov>; 'Regg, James B (OGC)' <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace – On 10/27 the greenstick treatment on the tubing hanger void on END 2-12 (PTD #192117) was completed and the well was placed back online, the IA pressure remained <100 psi until 11/15 when the IA pressure began to build. This weekend we plan to again set the J plug and perform a re-treat of the tubing hanger void with greenstick under the approved 10-403. The well will remain under evaluation for an additional 28 days to monitor the re-treatment results. Attached is a 30 day TIO plot. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, October 25, 2024 3:01 PM To: 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov>; 'Regg, James B (OGC)' <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Following the 10-403 approval for END 2-12 (PTD# 192117) on 10/2/24 to perform the tubing hanger wellhead treatment, a J-plug has been set and the treatment has been ongoing since 10/19/24. We expect the wellhead treatment to conclude in the coming days and the J-plug will be removed from the well. We will then place the well back on injection and monitor for the duration of an additional 28 day under evaluation period to verify effectiveness of the treatment. If you have any questions or concerns with the plan forward please reach out. Attached is a 30 day TIO plot. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, September 27, 2024 1:52 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas Injector END 2-12 (PTD# 1921170) had the following troubleshooting operations performed following identification of TxI communition: 9/1/24: PPPOT-T – established communication across the primary wellhead seal. 9/12/24: A J-Plug was set and a leak path evaluation (LPE) established communication across the neck seal. 9/15/24: The SSSV was pulled and replaced. The well is online with an IA build up rate of ~300-400 psi / day. A sundry was submitted on 9/25/24 to perform a wellhead treatment on the tubing hanger test void. Per our communication the well will remain online Under Evaluation for an additional 28 day period. Once the sundry submittal is approved, the wellhead treatment will be performed and the well monitored for TxI communication. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, September 1, 2024 4:47 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Ryan Thompson <Ryan.Thompson@hilcorp.com>; Alaska NS - Endicott - Field Foreman <AlaskaNS- Endicott-Field-Foreman@hilcorp.com> Subject: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas injector END2-12 (PTD 192117) was reported by operations with increasing IA pressure while shut in on 09/01. The IA pressure was bled from ~900 psi to 300 psi, a re-pressurization rate of 20 psi / hr was observed post bleed. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Slickline: Troubleshoot / repair SSSV. 2. Well Integrity: Further action as required. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 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. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Date:Tuesday, February 18, 2025 8:42:49 AM Attachments:END 2-12 TIO.docx From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, February 14, 2025 2:33 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace – On 2/6/25 sundry #325-034 was approved for END 2-12 to attempt an additional sealant treatment on the tubing hanger test void. We plan to execute the work in the coming days. Following the sealant treatment, we will monitor for IA re-pressurization. Included in sundry #325-034 is work scope to pull the THA and replace neck seals pending success of the upcoming sealant treatment. The well will remain under evaluation for an additional 28 days to perform the sealant treatment, monitor for success & determine plan forward on the pending neck seal replacement job. Attached is a 90 day TIO plot. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, January 17, 2025 11:57 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace – Following the completion of the second greenstick treatment on the tubing hanger void on 12/16/24, TxI build up rate has improved but has not been eliminated on END 2-12, as shown in the attached 90 day TIO plot. Our plan forward is to submit a second 10-403 to attempt a tubing hanger void sealant treatment with an alternative product to greenstick, if this is unsuccessful the 10-403 will include steps to pull the tubing head adapter (THA) and replace the neck seals. The well will remain under evaluation while the 10-403 is submitted. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, December 20, 2024 10:11 AM To: 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov>; 'Regg, James B (OGC)' <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace – On 12/16/24 a second greenstick treatment was completed on the tubing hanger void on END 2-12. In order to continue to monitor the effectiveness of this treatment on IA re- pressurization, we will leave the well under evaluation for an additional 28 day monitoring period. Attached is a 30 day TIO plot. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, November 22, 2024 3:39 PM To: 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov>; 'Regg, James B (OGC)' <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace – On 10/27 the greenstick treatment on the tubing hanger void on END 2-12 (PTD #192117) was completed and the well was placed back online, the IA pressure remained <100 psi until 11/15 when the IA pressure began to build. This weekend we plan to again set the J plug and perform a re-treat of the tubing hanger void with greenstick under the approved 10-403. The well will remain under evaluation for an additional 28 days to monitor the re-treatment results. Attached is a 30 day TIO plot. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, October 25, 2024 3:01 PM To: 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov>; 'Regg, James B (OGC)' <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Following the 10-403 approval for END 2-12 (PTD# 192117) on 10/2/24 to perform the tubing hanger wellhead treatment, a J-plug has been set and the treatment has been ongoing since 10/19/24. We expect the wellhead treatment to conclude in the coming days and the J-plug will be removed from the well. We will then place the well back on injection and monitor for the duration of an additional 28 day under evaluation period to verify effectiveness of the treatment. If you have any questions or concerns with the plan forward please reach out. Attached is a 30 day TIO plot. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, September 27, 2024 1:52 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas Injector END 2-12 (PTD# 1921170) had the following troubleshooting operations performed following identification of TxI communition: 9/1/24: PPPOT-T – established communication across the primary wellhead seal. 9/12/24: A J-Plug was set and a leak path evaluation (LPE) established communication across the neck seal. 9/15/24: The SSSV was pulled and replaced. The well is online with an IA build up rate of ~300-400 psi / day. A sundry was submitted on 9/25/24 to perform a wellhead treatment on the tubing hanger test void. Per our communication the well will remain online Under Evaluation for an additional 28 day period. Once the sundry submittal is approved, the wellhead treatment will be performed and the well monitored for TxI communication. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, September 1, 2024 4:47 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Ryan Thompson <Ryan.Thompson@hilcorp.com>; Alaska NS - Endicott - Field Foreman <AlaskaNS- Endicott-Field-Foreman@hilcorp.com> Subject: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas injector END2-12 (PTD 192117) was reported by operations with increasing IA pressure while shut in on 09/01. The IA pressure was bled from ~900 psi to 300 psi, a re-pressurization rate of 20 psi / hr was observed post bleed. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Slickline: Troubleshoot / repair SSSV. 2. Well Integrity: Further action as required. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 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. 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: 02/03/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: DIU MPI 2-12 PTD: 192-117 API: 50-029-22302-00-00 FINAL OPEN HOLE WIRELINE LOGS (03/16/1993) x DLL, MSFL, LDT, CNL & GR/CNL IN CASING (LIS Tape File + Verification Listing) SFTP Transfer - Data Folders: Please include current contact information if different from above. 192-117 T40046 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.03 14:14:14 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Wellhead repair treatment 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: ENDICOTT 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10,410 NA Casing Collapse Conductor N/A Surface 2,260psi Production 4,760psi Production 5,090psi Liner 7,020psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 8,357 2,738 9-5/8"x7" Baker S3 Pkr, 9-5/8"x7" TIW LTP, and 7" Otis RPB SSSV NA 9,940 8,395 1,545 7" See Schematic 120 9-5/8" 8,208 26# / NT80S Aras Worthington Operations Manager February 12, 2025 10,410740 7" 10,020 Perforation Depth MD (ft): 2,777 9,5879-5/8" 30" 13-3/8" 907-564-4763 aras.worthington@hilcorp.com 9,606 MD/ 9,286 TVD & 9,670 MD/ 9,344 TVD and 1,503 MD/ 1,500 TVD 2,770 TVD Burst 9,674 8,150psi MD 6,870psi NA 5,020psi 120120 Hilcorp Alaska, LLC Length Size Proposed Pools: 10,020 10,328 9,944 2,742 ENDICOTT OIL Same STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0034633 192-117 C.O. 462.007 DUCK IS UNIT MPI 2-12 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22302-00-00 AOGCC USE ONLY 8,160psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): See Schematic 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 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 8:31 am, Jan 27, 2025 325-034 Digitally signed by Justus Hinks (3691) DN: cn=Justus Hinks (3691) Reason: I attest to the accuracy and integrity of this document Date: 2025.01.24 17:20:39 -09'00' Justus Hinks (3691) 10-404 DSR-1/31/25JJL 2/6/25 A.Dewhurst 31JAN25*&: 2/6/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.06 16:04:16 -09'00' RBDMS JSB 021025 END 2-12 PTD: 1921170 Well Name:END 2-12 API Number:50-029-22302-00-00 Current Status:Gas Injector Rig:NA Estimated Start Date:02/12/25 Estimated Duration:1 Day Regulatory Contact:Darci Horner Permit to Drill Number:19211700 First Call Engineer:Aras Worthington 907-564-4763 907-440-7692 (M) Second Call Engineer:Ryan Thompson 907-564-5005 907-301-1240 (M) AFE Number:TBD Current Bottom Hole Pressure:3742 psi @ 10000’ TVD END 4-26 SBHPS – 3/17/17; (7.2 ppg) Max. Anticipated Surface Pressure:2742 psi Gas Column Gradient (0.1 psi/ft) Recent SI WHP:3000 psi 9/15/24 Brief Well Summary END 2-12 was drilled as a Gas Injection well in March 1993. In December 2006 the well was secured and the THA was removed allowing the replacement of multiple wellhead seals and repairing the SSSV lines. On 9/1/24 the well experienced an increase in IA pressure after being shut in and was placed Under Evaluation. Wellhead testing has established that both the primary and neck seals are leaking by creating TxIA communication. Greenstick treatments of the THA were executed twice per approved Sundry #324-555 but the TxIA communication was not remedied. Notes Regarding Wellbore Condition x Under Evaluation well for IA repressurization. x 4 year AOGCC MIT-IA passed to 2608 psi on 5/27/21 x Internal MIT-IA passed to 2476 psi on 9/6/23 post SSSV changeout x PPPOT-T failed 9/1/24 (leaking primary seal), LPE on 9/12/24 established leaking neck seal. x SSSV changeout 9/15/24 Objective: x Perform wellhead treatment of the tubing hanger test void to help mitigate pressure communication across the wellhead. x If sealant does not fix the leak, secure the well, remove the tree and replace the neck seals. Procedure Wellhead 1. Pump sealant into the tubing hanger test void – intent is to trial a couple different sealants that we have not tried before in this well. 2. Put well back on gas injection. Well Integrity 3. Monitor for IA re-pressurization while under evaluation. If IA re-pressurization continues, proceed with neck seal replacement as per below. END 2-12 PTD: 1921170 Fullbore/Slickline 4. Pull SSSV 5. Pump down tubing to kill well for secure as follows; Max tubing pressure 3600 psi. a. 10 bbls neat methanol b. 460 bbls 2% KCL (1.2x WBV) c. 10 bbls neat methanol 6. Set plug in nipple @ 9668’ MD. 7. CMIT-TxIA to 2500 psi target pressure, 2750 psi max pressure. 8. Bleed tubing, IA, and C&B line pressures to 0 psi and monitor for 24 hours. 9. If tubing, IA, and C&B lines stay at 0+ psi per above, proceed with step 12. 10. If tubing, IA, and C&B lines do not stay at 0+ psi, set 7” Baker RBP or HEX plug @ 9647’ MD. 11. Bleed tubing, IA, and C&B pressures to 0 psi and monitor for 24 hours. Valve Shop 12. Set TWC 13. ND Tree and tubing head adapter. 14. Replace neck seals and C&B line fittings. 15. NU tubing head adapter and test void to 5000 psi. 16. NU tree and PT to 6000 psi. 17. Pull TWC. Slickline 18. Pull Baker RBP and tubing tail plug. 19. Set SSSV – recommend three sets of over-sized sandwich packing per last install on 9/15/24. 20. Put well back on gas injection. Well Integrity 21. Monitor for IA re-pressurization while under evaluation. Attachments: 1. As-built Schematic 2. Wellhead Schematic END 2-12 PTD: 1921170 END 2-12 PTD: 1921170 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Date:Friday, January 17, 2025 12:25:16 PM Attachments:END 2-12 90 day TIO.docx From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, January 17, 2025 11:57 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace – Following the completion of the second greenstick treatment on the tubing hanger void on 12/16/24, TxI build up rate has improved but has not been eliminated on END 2-12, as shown in the attached 90 day TIO plot. Our plan forward is to submit a second 10-403 to attempt a tubing hanger void sealant treatment with an alternative product to greenstick, if this is unsuccessful the 10-403 will include steps to pull the tubing head adapter (THA) and replace the neck seals. The well will remain under evaluation while the 10-403 is submitted. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, December 20, 2024 10:11 AM To: 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov>; 'Regg, James B (OGC)' <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace – On 12/16/24 a second greenstick treatment was completed on the tubing hanger void on END 2-12. In order to continue to monitor the effectiveness of this treatment on IA re- pressurization, we will leave the well under evaluation for an additional 28 day monitoring period. Attached is a 30 day TIO plot. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, November 22, 2024 3:39 PM To: 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov>; 'Regg, James B (OGC)' <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace – On 10/27 the greenstick treatment on the tubing hanger void on END 2-12 (PTD #192117) was completed and the well was placed back online, the IA pressure remained <100 psi until 11/15 when the IA pressure began to build. This weekend we plan to again set the J plug and perform a re-treat of the tubing hanger void with greenstick under the approved 10-403. The well will remain under evaluation for an additional 28 days to monitor the re-treatment results. Attached is a 30 day TIO plot. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, October 25, 2024 3:01 PM To: 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov>; 'Regg, James B (OGC)' <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Following the 10-403 approval for END 2-12 (PTD# 192117) on 10/2/24 to perform the tubing hanger wellhead treatment, a J-plug has been set and the treatment has been ongoing since 10/19/24. We expect the wellhead treatment to conclude in the coming days and the J-plug will be removed from the well. We will then place the well back on injection and monitor for the duration of an additional 28 day under evaluation period to verify effectiveness of the treatment. If you have any questions or concerns with the plan forward please reach out. Attached is a 30 day TIO plot. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, September 27, 2024 1:52 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas Injector END 2-12 (PTD# 1921170) had the following troubleshooting operations performed following identification of TxI communition: 9/1/24: PPPOT-T – established communication across the primary wellhead seal. 9/12/24: A J-Plug was set and a leak path evaluation (LPE) established communication across the neck seal. 9/15/24: The SSSV was pulled and replaced. The well is online with an IA build up rate of ~300-400 psi / day. A sundry was submitted on 9/25/24 to perform a wellhead treatment on the tubing hanger test void. Per our communication the well will remain online Under Evaluation for an additional 28 day period. Once the sundry submittal is approved, the wellhead treatment will be performed and the well monitored for TxI communication. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, September 1, 2024 4:47 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Ryan Thompson <Ryan.Thompson@hilcorp.com>; Alaska NS - Endicott - Field Foreman <AlaskaNS- Endicott-Field-Foreman@hilcorp.com> Subject: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas injector END2-12 (PTD 192117) was reported by operations with increasing IA pressure while shut in on 09/01. The IA pressure was bled from ~900 psi to 300 psi, a re-pressurization rate of 20 psi / hr was observed post bleed. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Slickline: Troubleshoot / repair SSSV. 2. Well Integrity: Further action as required. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 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. 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: Wellhead repair treatment 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 10,410 feet 10,327 feet true vertical 10,020 feet N/A feet Effective Depth measured 10,327 feet 9,606 & 9,670 feet true vertical 9,943 feet 9,286 & 9,344 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 7" 26# / NT80S 9,674' 9,347' 7" SABL-3 1,503' MD Packers and SSSV (type, measured and true vertical depth)7" TIW LTP See Above RPB SSSV 1,500' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Same 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:Operations Manager Contact Phone: Burst NA Collapse NA 2,260psi 5,090psi 7,020psi 5,020psi 6,870psi 8,150psi 8,160psi 4,760psi TVD 9-5/8"9,587' Production Production 30" 9-5/8" 120' 2,738' Casing 13-3/8" Conductor 2,777'Surface 10,020' 9,940' 10,410' 8,357' 8,395' 8,208' ENDICOTT / ENDICOTT OIL DUCK IS UNIT MPI 2-12 Plugs Junk measured measured NA 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0034633 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 192-117 50-029-22302-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC 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 816 01080 0 35580 4118 0 N/A measured true vertical Packer MD 120' Size 120' 2,771' Length Liner 1,545' 740'7" Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ryan Thompson ryan.thompson@hilcorp.com 907-564-5005 324-555 PL G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 11:37 am, Jan 16, 2025 Digitally signed by Justus Hinks (3691) DN: cn=Justus Hinks (3691) Reason: I attest to the accuracy and integrity of this document Date: 2025.01.16 10:27:39 -09'00' Justus Hinks (3691) JJL 2/7/25 DSR-1/17/24 RBDMS JSB 012825 SFD 2/10/2025 13326 HILCORP ALASKA, LLC 10326 Well Name Rig API Number Well Permit Number Start Date End Date END 2-12 Well Support 50-029-22302-00-00 192-177 10/20/2024 12/16/2024 T/I/O = 0/0+/0. Temp = SI. Greenstick tubing test void (eval TxIA). R/U packing gun to hoke valve. Pumped 8 guns of greenstick. Job not complete. SV, WV, MV = C. SSV = O. IA, OA = OTG. 17:15 No operations to report. 10/19/2024 - Saturday T/I/O = 0/0+/0. Temp = SI. Greenstick tubing test void (eval TxIA). Bled IAP to BT to 0 psi, hold open bleed on IA. Stung into T- Test void, 0+ psi. Bled void to 0. Monitored for 10 min. No change in pressure. R/U elephant gun to hoke valve. Pumped 4.5 guns of greenstick. Final WHPs = 0/0/0. SV, WV, MV = C. SSV = O. IA, OA = OTG. 17:15 10/22/2024 - Tuesday 10/20/2024 - Sunday T/I/O = 0/0/0. Temp = SI. Greenstick tubing test void (eval TxIA). Stung into T-Test void, 0+ psi. Bled void to 0. Monitored for 10 min. No change in pressure. R/U hoke valve to T-Test void. Pumped 3 guns of greenstick. Final WHPs = 0/0/0. SV, WV, MV = C. SSV = O. IA, OA = OTG. 17:00 10/21/2024 - Monday 10/18/2024 - Friday No operations to report. 10/16/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 10/17/2024 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date END 2-12 Well Support 50-029-22302-00-00 192-177 10/20/2024 12/16/2024 10/25/2024 - Friday T/I/O = 0/0+/0. Temp = SI. Greenstick tubing test void (eval TxIA). R/U packing gun to hoke valve. Pumped 4 1/2 guns of greenstick until packed off, held for 1 hour to ensure good pack. Job complete. SV, WV, MV = C. SSV = O. IA, OA = OTG. 16:45 10/23/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary T/I/O = 0/0+/0. Temp = SI. Greenstick tubing test void (eval TxIA). R/U packing gun to hoke valve. Pumped 7 1/2 guns of greenstick. Job not complete. SV, WV, MV = C. SSV = O. IA, OA = OTG. 17:15 10/24/2024 - Thursday T/I/O = 0/0+/0. Temp = SI. Greenstick tubing test void (eval TxIA). R/U packing gun to hoke valve. Pumped 6 guns of greenstick. Job not complete. SV, WV, MV = C. SSV = O. IA, OA = OTG. 17:15 No operations to report. No operations to report. 10/26/2024 - Saturday No operations to report. 10/29/2024 - Tuesday 10/27/2024 - Sunday T/I/O=BPV/0/0. RU Lubricator 68-840 w/ Test SUB. Tested to 5000 psi. Pass. Pulled 6" BPV #421 @170". ***Job Complete*** Final WHP's 2690/0/0. 10/28/2024 - Monday Well Name Rig API Number Well Permit Number Start Date End Date END 2-12 Well Support 50-029-22302-00-00 192-177 10/20/2024 12/16/2024 12/13/2024 - Friday No operations to report. 12/11/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 12/12/2024 - Thursday No operations to report. No operations to report. No operations to report. 12/14/2024 - Saturday T/I/O = 300/0/0. Temp = SI. Greenstick Tubing Test Void. R/U packing gun to hoke valve. Pumped <1/2 gun of greenstick, very slow, appears to be packed off. Held pressure for 1 hr to ensure packed off. Job complete. SV, WV = C. SSV, MV = O. IA, OA = OTG. 17:00 12/17/2024 - Tuesday 12/15/2024 - Sunday T/I/O = 300/0/0. Temp = SI. Greenstick Tubing Test Void. R/U packing gun to hoke valve. Pumped 2-1/2 guns of greenstick, rate slowed down but still pushing greenstick into void. Job not complete. SV, WV = C. SSV, MV = O. IA, OA = OTG. 17:00 12/16/2024 - Monday CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Date:Tuesday, January 7, 2025 4:08:18 PM Attachments:END 2-12 - 30 day TIO.docx From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, December 20, 2024 10:11 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace – On 12/16/24 a second greenstick treatment was completed on the tubing hanger void on END 2-12. In order to continue to monitor the effectiveness of this treatment on IA re- pressurization, we will leave the well under evaluation for an additional 28 day monitoring period. Attached is a 30 day TIO plot. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, November 22, 2024 3:39 PM To: 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov>; 'Regg, James B (OGC)' <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace – On 10/27 the greenstick treatment on the tubing hanger void on END 2-12 (PTD #192117) was completed and the well was placed back online, the IA pressure remained <100 psi until 11/15 when the IA pressure began to build. This weekend we plan to again set the J plug and perform a re-treat of the tubing hanger void with greenstick under the approved 10-403. The well will remain under evaluation for an additional 28 days to monitor the re-treatment results. Attached is a 30 day TIO plot. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, October 25, 2024 3:01 PM To: 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov>; 'Regg, James B (OGC)' <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Following the 10-403 approval for END 2-12 (PTD# 192117) on 10/2/24 to perform the tubing hanger wellhead treatment, a J-plug has been set and the treatment has been ongoing since 10/19/24. We expect the wellhead treatment to conclude in the coming days and the J-plug will be removed from the well. We will then place the well back on injection and monitor for the duration of an additional 28 day under evaluation period to verify effectiveness of the treatment. If you have any questions or concerns with the plan forward please reach out. Attached is a 30 day TIO plot. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, September 27, 2024 1:52 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas Injector END 2-12 (PTD# 1921170) had the following troubleshooting operations performed following identification of TxI communition: 9/1/24: PPPOT-T – established communication across the primary wellhead seal. 9/12/24: A J-Plug was set and a leak path evaluation (LPE) established communication across the neck seal. 9/15/24: The SSSV was pulled and replaced. The well is online with an IA build up rate of ~300-400 psi / day. A sundry was submitted on 9/25/24 to perform a wellhead treatment on the tubing hanger test void. Per our communication the well will remain online Under Evaluation for an additional 28 day period. Once the sundry submittal is approved, the wellhead treatment will be performed and the well monitored for TxI communication. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, September 1, 2024 4:47 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Ryan Thompson <Ryan.Thompson@hilcorp.com>; Alaska NS - Endicott - Field Foreman <AlaskaNS- Endicott-Field-Foreman@hilcorp.com> Subject: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas injector END2-12 (PTD 192117) was reported by operations with increasing IA pressure while shut in on 09/01. The IA pressure was bled from ~900 psi to 300 psi, a re-pressurization rate of 20 psi / hr was observed post bleed. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Slickline: Troubleshoot / repair SSSV. 2. Well Integrity: Further action as required. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 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. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Date:Sunday, November 24, 2024 4:23:43 PM Attachments:END 2-12 30 day TIO.docx From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, November 22, 2024 3:39 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END 2-12 (PTD #192117) TxIA communication Mr. Wallace – On 10/27 the greenstick treatment on the tubing hanger void on END 2-12 (PTD #192117) was completed and the well was placed back online, the IA pressure remained <100 psi until 11/15 when the IA pressure began to build. This weekend we plan to again set the J plug and perform a re-treat of the tubing hanger void with greenstick under the approved 10-403. The well will remain under evaluation for an additional 28 days to monitor the re-treatment results. Attached is a 30 day TIO plot. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, October 25, 2024 3:01 PM To: 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov>; 'Regg, James B (OGC)' <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Following the 10-403 approval for END 2-12 (PTD# 192117) on 10/2/24 to perform the tubing hanger wellhead treatment, a J-plug has been set and the treatment has been ongoing since 10/19/24. We expect the wellhead treatment to conclude in the coming days and the J-plug will be removed from the well. We will then place the well back on injection and monitor for the duration of an additional 28 day under evaluation period to verify effectiveness of the treatment. If you have any questions or concerns with the plan forward please reach out. Attached is a 30 day TIO plot. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, September 27, 2024 1:52 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas Injector END 2-12 (PTD# 1921170) had the following troubleshooting operations performed following identification of TxI communition: 9/1/24: PPPOT-T – established communication across the primary wellhead seal. 9/12/24: A J-Plug was set and a leak path evaluation (LPE) established communication across the neck seal. 9/15/24: The SSSV was pulled and replaced. The well is online with an IA build up rate of ~300-400 psi / day. A sundry was submitted on 9/25/24 to perform a wellhead treatment on the tubing hanger test void. Per our communication the well will remain online Under Evaluation for an additional 28 day period. Once the sundry submittal is approved, the wellhead treatment will be performed and the well monitored for TxI communication. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, September 1, 2024 4:47 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Ryan Thompson <Ryan.Thompson@hilcorp.com>; Alaska NS - Endicott - Field Foreman <AlaskaNS- Endicott-Field-Foreman@hilcorp.com> Subject: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas injector END2-12 (PTD 192117) was reported by operations with increasing IA pressure while shut in on 09/01. The IA pressure was bled from ~900 psi to 300 psi, a re-pressurization rate of 20 psi / hr was observed post bleed. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Slickline: Troubleshoot / repair SSSV. 2. Well Integrity: Further action as required. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 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 responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Date:Friday, October 25, 2024 3:35:37 PM Attachments:END 2-12 - TIO.docx From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, October 25, 2024 3:01 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Following the 10-403 approval for END 2-12 (PTD# 192117) on 10/2/24 to perform the tubing hanger wellhead treatment, a J-plug has been set and the treatment has been ongoing since 10/19/24. We expect the wellhead treatment to conclude in the coming days and the J-plug will be removed from the well. We will then place the well back on injection and monitor for the duration of an additional 28 day under evaluation period to verify effectiveness of the treatment. If you have any questions or concerns with the plan forward please reach out. Attached is a 30 day TIO plot. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, September 27, 2024 1:52 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas Injector END 2-12 (PTD# 1921170) had the following troubleshooting operations performed following identification of TxI communition: 9/1/24: PPPOT-T – established communication across the primary wellhead seal. 9/12/24: A J-Plug was set and a leak path evaluation (LPE) established communication across the neck seal. 9/15/24: The SSSV was pulled and replaced. The well is online with an IA build up rate of ~300-400 psi / day. A sundry was submitted on 9/25/24 to perform a wellhead treatment on the tubing hanger test void. Per our communication the well will remain online Under Evaluation for an additional 28 day period. Once the sundry submittal is approved, the wellhead treatment will be performed and the well monitored for TxI communication. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, September 1, 2024 4:47 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Ryan Thompson <Ryan.Thompson@hilcorp.com>; Alaska NS - Endicott - Field Foreman <AlaskaNS- Endicott-Field-Foreman@hilcorp.com> Subject: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas injector END2-12 (PTD 192117) was reported by operations with increasing IA pressure while shut in on 09/01. The IA pressure was bled from ~900 psi to 300 psi, a re-pressurization rate of 20 psi / hr was observed post bleed. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Slickline: Troubleshoot / repair SSSV. 2. Well Integrity: Further action as required. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 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. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Date:Monday, September 30, 2024 9:34:38 AM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, September 27, 2024 1:52 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com> Subject: RE: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas Injector END 2-12 (PTD# 1921170) had the following troubleshooting operations performed following identification of TxI communition: 9/1/24: PPPOT-T – established communication across the primary wellhead seal. 9/12/24: A J-Plug was set and a leak path evaluation (LPE) established communication across the neck seal. 9/15/24: The SSSV was pulled and replaced. The well is online with an IA build up rate of ~300-400 psi / day. A sundry was submitted on 9/25/24 to perform a wellhead treatment on the tubing hanger test void. Per our communication the well will remain online Under Evaluation for an additional 28 day period. Once the sundry submittal is approved, the wellhead treatment will be performed and the well monitored for TxI communication. Please respond with any questions or concerns. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, September 1, 2024 4:47 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Ryan Thompson <Ryan.Thompson@hilcorp.com>; Alaska NS - Endicott - Field Foreman <AlaskaNS- Endicott-Field-Foreman@hilcorp.com> Subject: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas injector END2-12 (PTD 192117) was reported by operations with increasing IA pressure while shut in on 09/01. The IA pressure was bled from ~900 psi to 300 psi, a re-pressurization rate of 20 psi / hr was observed post bleed. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Slickline: Troubleshoot / repair SSSV. 2. Well Integrity: Further action as required. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 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 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 delete this 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 Other: Wellhead repair treatment 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: ENDICOTT 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10,410 NA Casing Collapse Conductor N/A Surface 2,260psi Production 4,760psi Production 5,090psi Liner 7,020psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng NA 9,940 8,395 1,545 7" See Schematic Operations Manager October 5, 2024 10,410740 7" 10,020 Perforation Depth MD (ft): See Schematic 9-5/8"x7" Baker S3 Pkr, 9-5/8"x7" TIW LTP, and 7" Otis RPB SSSV 120 9-5/8"8,208 2,738 907-564-5005 ryan.thompson@hilcorp.com 9,606 MD/ 9,286 TVD & 9,670 MD/ 9,344 TVD and 1,503 MD/ 1,500 TVD 2,770 8,208 120 2,777 9,5879-5/8" 30" 13-3/8" 26# / NT80S TVD Burst 9,674 8,150psi MD 6,870psi NA 5,020psi 120 Hilcorp Alaska, LLC Length Size Proposed Pools: 10,020 10,328 9,944 2,742 ENDICOTT OIL Same STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0034633 192-117 C.O. 462.007 DUCK IS UNIT MPI 2-12 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22302-00-00 PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 8,160psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Ryan Thompson 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: 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 12:45 pm, Sep 26, 2024 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2024.09.25 16:17:24 - 08'00' Sara Hannegan (2519) 324-555 GINJ DSR-9/27/24SFD 9/30/2024MGR01OCT2024 10-404 JLC 10/2/2024 Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.10.02 13:53:45 -08'00'10/02/24 RBDMS JSB 100324 Well: END 2-12 PTD: 1921170 Well Name:END 2-12 API Number:50-029-22302-00-00 Current Status:Gas Injector Rig:NA Estimated Start Date:10/5/24 Estimated Duration:1 Day Regulatory Contact:Darci Horner Permit to Drill Number:19211700 First Call Engineer:Ryan Thompson 907-564-5005 907-301-1240 (M) Second Call Engineer:Brenden Swensen 907-748-8581 (M) AFE Number:TBD Current Bottom Hole Pressure:3742 psi @ 10000’ TVD END 4-26 SBHPS – 3/17/17 Max. Anticipated Surface Pressure:2742 psi Gas Column Gradient (0.1 psi/ft) Recent SI WHP:3000 psi 9/15/24 Brief Well Summary END 2-12 was drilled as a Gas Injection well in March 1993. In December 2006 the well was secured and the THA was removed allowing the replacement of multiple wellhead seals and repairing the SSSV lines. On 9/1/24 the well experienced an increase in IA pressure after being shut in and was placed Under Evaluation. Wellhead testing has established that both the primary and neck seals are leaking by creating TxI communication. The plan forward is to treat the tubing hanger test void with J- stick. Notes Regarding Wellbore Condition x Under Evaluation well for IA repressurization. x 4 year AOGCC MIT-IA passed to 2608 psi on 5/27/21 x Internal MIT-IA passed to 2476 psi on 9/6/23 post SSSV changeout x PPPOT-T failed 9/1/24 (leaking primary seal), LPE on 9/12/24 established leaking neck seal. x SSSV changeout 9/15/24 Objective: x Perform wellhead treatment of the tubing hanger test void to help mitigate pressure communication across the wellhead. Procedure Wellhead 1. With the well shut in, set J-plug in tubing hanger BPV profile. 2. Bleed off tree and IA to ~0 psi. 3. Pump J-stick (if necessary greenstick) into the tubing hanger test void. 4. Pull J-plug. 5. Place well back on gas injection. Well Integrity 1. Monitor for IA re-pressurization while under evaluation. Attachments: 1. As-built Schematic 2. Wellhead Schematic 192-117 SFD Well: END 2-12 PTD: 1921170 Well: END 2-12 PTD: 1921170 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Date:Tuesday, September 3, 2024 8:33:48 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, September 1, 2024 4:47 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Ryan Thompson <Ryan.Thompson@hilcorp.com>; Alaska NS - Endicott - Field Foreman <AlaskaNS- Endicott-Field-Foreman@hilcorp.com> Subject: UNDER EVALUATION: Injection END2-12 (PTD #192117) TxIA communication Mr. Wallace, Gas injector END2-12 (PTD 192117) was reported by operations with increasing IA pressure while shut in on 09/01. The IA pressure was bled from ~900 psi to 300 psi, a re-pressurization rate of 20 psi / hr was observed post bleed. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Slickline: Troubleshoot / repair SSSV. 2. Well Integrity: Further action as required. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 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 responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Gas Injector END 2-12 (PTD# 1921170) Anomalous IA Pressure Date:Thursday, September 7, 2023 11:12:18 AM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Thursday, September 7, 2023 10:42 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com> Subject: OPERABLE: Gas Injector END 2-12 (PTD# 1921170) Anomalous IA Pressure Mr. Wallace, On 9/4/23 Gas Injector END 2-12 (PTD# 1921170) had the SSSV changed out. On 9/6/23 the well passed a non-witnessed MIT-IA to 2476 psi while on injection. The well is now classified as OPERABLE following the passing MIT-IA. Please respond with any questions. Thanks, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, August 25, 2023 10:34 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com> Subject: UNDER EVALUATION: Injector END 2-12 (PTD# 1921170) Anomalous IA Pressure Mr. Wallace, On 8/20/23 we were able to perform a LPE on the tubing hanger after fixing the swab valve restriction noted below, confirming the secondary seals are holding on the tubing hanger. Per our conversation we will role the UNDER EVALUATION clock for an additional 28 days. Plan forward is for SL to be on the well this weekend and changeout the SSSV and perform an MIT- IA. Please respond with any questions, Thanks, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, July 28, 2023 1:30 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com> Subject: RE: UNDER EVALUATION: Injector END 2-12 (PTD# 192117) Anomalous IA Pressure Mr. Wallace, On 7/14/23 we performed a failing PPPOT-T on END 2-12 (PTD# 192117). On 7/15/23 we attempted to set a BPV to perform a Leak Path Evaluation on the tubing hanger void and encountered a restriction at the swab valve concluding the swab valve would not fully open. We are currently awaiting parts to fix the swab valve issue and then will resume diagnostics on this well. Per our conversation we will now role the clock another 28 days for the UNDER EVALUATION period starting 7/30/23. Please respond with any questions, Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: Jerimiah Galloway Sent: Sunday, July 2, 2023 6:58 AM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; Regg, James B (CED) <jim.regg@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com> Subject: UNDER EVALUATION: Injector END2-12 (PTD# 192117) Anomalous IA Pressure Mr. Wallace, Gas Injector END2-12 (PTD# 192117) inner annulus was bled on 7/1/2023 from 2050 psi to 500 psi. The pressure increased back to 2050 psi during the subsequent 12-hour period indicating possible TxIA communication. The well is now classified as UNDER EVALUATION and is on a 28-day clock for diagnostics and resolution. The well will remain online during initial diagnostics. Plan Forward: 1. PPPOT-T 2. MIT-IA 3. Evaluate additional diagnostics Please respond if there are any additional questions. Jerimiah Galloway Hilcorp Alaska Email: jerimiah.galloway@hilcorp.com C: (828)553-2537 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. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injector END 2-12 (PTD# 1921170) Anomalous IA Pressure Date:Tuesday, August 29, 2023 8:53:50 AM Attachments:END 2-12 SCHEMATIC 4-25-2019.pdf END 2-12 TIO"s.docx From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, August 25, 2023 10:34 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com> Subject: UNDER EVALUATION: Injector END 2-12 (PTD# 1921170) Anomalous IA Pressure Mr. Wallace, On 8/20/23 we were able to perform a LPE on the tubing hanger after fixing the swab valve restriction noted below, confirming the secondary seals are holding on the tubing hanger. Per our conversation we will role the UNDER EVALUATION clock for an additional 28 days. Plan forward is for SL to be on the well this weekend and changeout the SSSV and perform an MIT- IA. Please respond with any questions, Thanks, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, July 28, 2023 1:30 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com> Subject: RE: UNDER EVALUATION: Injector END 2-12 (PTD# 192117) Anomalous IA Pressure Mr. Wallace, On 7/14/23 we performed a failing PPPOT-T on END 2-12 (PTD# 192117). On 7/15/23 we attempted to set a BPV to perform a Leak Path Evaluation on the tubing hanger void and encountered a restriction at the swab valve concluding the swab valve would not fully open. We are currently awaiting parts to fix the swab valve issue and then will resume diagnostics on this well. Per our conversation we will now role the clock another 28 days for the UNDER EVALUATION period starting 7/30/23. Please respond with any questions, Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: Jerimiah Galloway Sent: Sunday, July 2, 2023 6:58 AM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; Regg, James B (CED) <jim.regg@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com> Subject: UNDER EVALUATION: Injector END2-12 (PTD# 192117) Anomalous IA Pressure Mr. Wallace, Gas Injector END2-12 (PTD# 192117) inner annulus was bled on 7/1/2023 from 2050 psi to 500 psi. The pressure increased back to 2050 psi during the subsequent 12-hour period indicating possible TxIA communication. The well is now classified as UNDER EVALUATION and is on a 28-day clock for diagnostics and resolution. The well will remain online during initial diagnostics. Plan Forward: 1. PPPOT-T 2. MIT-IA 3. Evaluate additional diagnostics Please respond if there are any additional questions. Jerimiah Galloway Hilcorp Alaska Email: jerimiah.galloway@hilcorp.com C: (828)553-2537 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 responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 13326 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injector END 2-12 (PTD# 192117) Anomalous IA Pressure Date:Tuesday, August 1, 2023 11:09:55 AM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, July 28, 2023 1:30 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com> Subject: RE: UNDER EVALUATION: Injector END 2-12 (PTD# 192117) Anomalous IA Pressure Mr. Wallace, On 7/14/23 we performed a failing PPPOT-T on END 2-12 (PTD# 192117). On 7/15/23 we attempted to set a BPV to perform a Leak Path Evaluation on the tubing hanger void and encountered a restriction at the swab valve concluding the swab valve would not fully open. We are currently awaiting parts to fix the swab valve issue and then will resume diagnostics on this well. Per our conversation we will now role the clock another 28 days for the UNDER EVALUATION period starting 7/30/23. Please respond with any questions, Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: Jerimiah Galloway Sent: Sunday, July 2, 2023 6:58 AM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; Regg, James B (CED) <jim.regg@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com> Subject: UNDER EVALUATION: Injector END2-12 (PTD# 192117) Anomalous IA Pressure Mr. Wallace, Gas Injector END2-12 (PTD# 192117) inner annulus was bled on 7/1/2023 from 2050 psi to 500 psi. The pressure increased back to 2050 psi during the subsequent 12-hour period indicating possible TxIA communication. The well is now classified as UNDER EVALUATION and is on a 28-day clock for diagnostics and resolution. The well will remain online during initial diagnostics. Plan Forward: 1. PPPOT-T 2. MIT-IA 3. Evaluate additional diagnostics Please respond if there are any additional questions. Jerimiah Galloway Hilcorp Alaska Email: jerimiah.galloway@hilcorp.com C: (828)553-2537 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. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injector END2-12 (PTD# 192117) Anomalous IA Pressure Date:Monday, July 3, 2023 12:14:40 PM Attachments:END 2-12 Under Evaluation TIO_Schematic.docx From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Sunday, July 2, 2023 6:58 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com> Subject: UNDER EVALUATION: Injector END2-12 (PTD# 192117) Anomalous IA Pressure Mr. Wallace, Gas Injector END2-12 (PTD# 192117) inner annulus was bled on 7/1/2023 from 2050 psi to 500 psi. The pressure increased back to 2050 psi during the subsequent 12-hour period indicating possible TxIA communication. The well is now classified as UNDER EVALUATION and is on a 28-day clock for diagnostics and resolution. The well will remain online during initial diagnostics. Plan Forward: 1. PPPOT-T 2. MIT-IA 3. Evaluate additional diagnostics Please respond if there are any additional questions. Jerimiah Galloway Hilcorp Alaska Email: jerimiah.galloway@hilcorp.com C: (828)553-2537 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, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this 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. FORMO►1 U TO: Jim Regg r / / P.I. Suipervisor "eG1 r�q )1 2{JZ,( FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Cas Conservation Commission DATE: Tuesday, June 8, 2021 SUBJECT: Mechanical Integrity Tests Bilcorp Alaska, LLC 2-12 DUCK IS UNIT MPI 2-12 Sre: Inspector Reviewed By: P.I. Supry jFp— Comm Well Name DUCK IS UNIT MPI 2-12 API Well Number 50-029-22302-00-00 Inspector Name: Bob Noble Permit Number: 192-117-0 Inspection Date: 5/27/2021 " IDSA Num: mitRCN210527134530 Rel IDsp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well z-12 Type Inj G 'TVD 9286 Tubing 4529 - 4526. 4528 _ 4528 - PTD 9zu70 Type Test sPT Test psi zszz - IA 842 2612 2609 - 2608 - BBL Pumped: 1 2.5 - IBBL Returned: 2.4 - OA 20 20 20 20 . Interval 4YRTST P/F P Notes: Tuesday, June 8, 2021 Page 1 of Hilcorp Alaska, LLC August 26, 2019 Mr. Guy Schwartz Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: 907/777-8547 f aka., U Ln L to Ez AUG 2 9 2019 ()G(DC�' Re: Endicott Conductor Annulus Cement and Corrosion Inhibitor Treatments 8/6/19-8/18/19 Dear Mr. Schwartz, Enclosed please find multiple copies of a spreadsheet with a list of Endicott wells that were treated with cement and corrosion inhibiting casing filler in the surface casing by conductor annulus. The heavier than water "grease -like" filler displaces water to prevent external casing contusion that could result in a surface casing leak. The attached spreadsheets include the well names, field, API and PTD numbers, treatment dates and volumes. If you have any additional questions, please contact me at 777-8547 or wrivard@hilcorp.com. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC Endicott Surface Casing by Conductor Annulus Cement Top lob and Fill Coat Corrosion Inhibitor (CI) Applications well Field API PTD initial Top of Cement (ft.) Volume of Cement Pumped(bbis) Final Topof Cement (ft.) Cement Pump Date Corrosion Inhibitor Fill Volume (gal) Final Cl Top (ft.) Corrosion Inhibitor Treatment Date 1-61 DIU 50029225200000 1941420 6.5 3.86 1 8/6/2019 23 Flush w/top of cond uctor 8/18/2019 2-12 DIU 50029223020000 1921170 15 10.18 0.5 8/6/2019 18 Flush w/top of conductor 8/18/2019 3-11 DIU 50029218480000 1880870 9.2 6.11 0.5 8/9/2019 7 Flush w/top of flutes 8/18/2019 50029221250200 2030210 12.2 7.87 1 8/9/2019 3 Flush w/top of flutes 8/18/2019 50029218780000 1881260 6.4 3.79 1 8/10/2019 5 Flush w/top of flutes 8/18/2019 M 50029218110000 1880510 5.2 2.95 1 8/9/20195 Flush w/top offlutes 8/18/2019 50029215690000 1860640 2.9 1.33 1 8/9/2019 1 3 Flush w/top of flutes 8/18/2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS u -— V� a V 16. Mel APR 2 5 2010 1. Operations Abandon Plug Perforations LJ Fracture StimulatEF Pull Tubing LJ Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulat❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair We❑ Re-enter Susp Well ❑ Other: Surface Casing Repair Q 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑ Stratigraphic ❑ Exploratory ❑ Service ❑4 192-117 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-22302-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0034633 DUCK IS UNIT MPI 2-12 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A ENDICOTT / ENDICOTT OIL 11. Present Well Condition Summary: Total Depth measured 10,410 feel Plugs measured 10,327 feet true vertical 10,007 feet Junk measured N/A feet Effective Depth measured 10,327 feet Packer measured 9,606 & 9,678 feet true vertical 9,933 feet true vertical 9,284 & 9,349 feet Casing Length Size MD TVD Burst Collapse Conductor 120' 30" 120' 120' N/A WA Surface 2,738' 13-3/8" 2,777' 2,770' 5,020psi 2,260psi Production 8,357' 9-5/8" 8,208' 8,041' 6,870psi 4,760psi Production 1,545' 9-5/8" 9,587' 9,267' 8,150psi 5,090psi Liner 740' 7" 10,410' 10,007' 8,160psi 7,020psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 7" 26# / NT80S 9,674' 9,345' 7" SABL-3 1,503' MD Packers and SSSV (type, measured and true vertical depth) 7" TIW LTP See Above RPB SSSV 1,500' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 0 0 0 0 0 Subsequent to operation: 1 0 80,050 Inj 0 50 4,538 14. Attachments (required per 20 AAC 25.070, 25.071, &25.283) 15. Well Class after work: Daily Report of Well Operations ❑� Exploratory[-] Development❑ Service ❑� Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ p SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-051 l—k Authorized Name: Chad Hel eson 9 Contact Name: Wyatt Rivard Authorized Title: Operations Manager Contact Email: wriyard Whilcorp.com / Authorized Signature: Date: 4/24/2019 Contact Phone: 777-8449 17 Form 10-404 Revised 4/2017 RBDMSZ APR Z 6 2019 Submit Original Only TREE = S" X r CNV FLS VA3-LFFAD= 135/8"FMC ACTUATOR= _... BAKERC KB. B -EV = 55.3' 4" 4 KOP= Max Angle = [AtumtuD= DatumND= --2-9--@---8-42(Y 6020' 29" @ 8420' 10449' 10000'SS 13-3/8" CSG, 68#, NT -80, BTRS, D = 1 GE 230 - 260 E N D2 -12 PPM ON AIL B GAS INJECTORS. WEAFETY NOTES: H2S READINGS LL REQUIRES HI I I I SSSV. IN...n, A64.. I.I.I: 1111 110 7"OTIS RPB SSSV NP, ID=5.962" 2777' Minimum ID = 4.50" @ 1503' T' DUMMY SSSV tPOT3173Q1"; kL.7FYKge�IFi�71E1.7:_�3 4H1D:�Si7 PERFORATION SL&WRY REE LOG: CNL-GR (06/16/93) ANGLEAT TOP PERF: 23° @ 10108 Note: Refer to Production DB for historical perf data SIZE SPF INT9ZVAL Opn/Sgz DATE 4" 4 10108 - 10112 O 04/10193 4" 4 10116 - 10120 O 04/10193 4" 4 10142 - 10158 0 04/10/93 4" 4 10166-10170 O 04/10193 4" 4 10211 - 10222 O 04/10/93 4" 4 10230- 10236 O 04/12193 4" 4 10250 - 10263 O 04/12/93 4" 4 10263 -10283 O 04/12/93 4" 4 10290 - 10310 O 04/12/93 LW 29#,L-80, TKGBTC, .0371 bpf, 10= 6.184" —L-1 9606' H9-518" X 7" BKR S-3 PKR. 0=6.00" 9666' --j7- OTIS R NP, D= 5.962" DATE REV BYOOMdE�lTS DATE REV BY COMu NTS 03121193 D15 INITIAL COMPLETION 10/19/12 LEC/PJC RAL DSSSV 8 PLUG (5/16112) 01/12/07 DRF/PAG RILL RUGS (01/06/07) 03/01/07 WMPJC CONVERT TO NEW FORMAT 06101/12 LECJJM) PR PLUG & D ODRR (05130112) 06/17/12 RKT/PJC MN DCORRECTgN 07/30/12 JO/JM3 TREE 00(07/18112) 'F'..b?/e31f311tlu4Al1^JII� 2-L'LSC69A�AIIH�f'i:7i tY.'.LILi�9➢:F'�i1H:Yl:Ti ESD COTT UNIT WB -L' 2-12 / 0-16 PERIAT No: 1921170 AR No: 50-029-22302-00 Sl3336, T12N, R16E, 1877' FP18 2196' Fli HILCORP ALSKA, LLC Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-12 WSS 50-029-22302-00-00 192-117 3/5/19 4/15/19 Daily Operations. 2/27/2019 - Wednesday No activity to report. 2/28/2019 - Thursday No activity to report. 3/1/2019 - Friday No activity to report. 3/2/2019 -Saturday No activity to report. 3/3/2019 -Sunday No activity to report. 3/4/2019 - Monday No activity to report. 3/5/2019 -Tuesday Pre job meeting with Jacobs and BP DHD crew on set up of WSS on MPI 2-12. Got to location and began R/U of WSS. Set WSS over MPI 2-12 and got it centered up with top of master valve. R/U control trailer and check out electronics and function check WSS. Took measurements and adjusted WSS down comer to our well head dimensions. Bolted up cross over to adapt 2-12 to WSS knuckle spools. Bolted up knuckle spool to down comer. Torque all bolts. Lay down for the evening at 10pm. 12K weight on load cells left on wellhead for the night. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-12 WSS 50-029-22302-00-00 192-117 3/5/19 4/15/19 Daily Operations. 3/6/2019 - Wednesday Pre job meeting with Endicott crew and GBR welding. M/U to site and check on well and structure. All good. Roll our welding leads and begin to cut 30' conductor from the surface casing. Cut several foot section out below the starting head and remove from cellar. Began notching out starting head and slips. Cut out one section and tried to slide top of conductor down to the cellar floor with no success. Roll up welding leads and lay down for the night. 3/7/2019 - Thursday Pre job meeting with Endicott crew and GBR. M/U to site and roll out leads. Begin scarfing out starting head section of conductor. Remove starting head in 3 sections and lifted to surface. Noticed that the surface casing was in much worse shape than previously thought. Call town to discuss options. Decision is made to use the larger diameter patch with the wedding bands. Sent inspections out to UT pipe where it was to be welded and found to be of adequate thickness. Sent welders to fab shop with patches to dress up and put final bevel on. Welders came back to 2-12 to weld the lower wedding bands on. Welders tacked bands on and proceed to use a straight edged to check for clearances for the patch. Clearances were found to inadequate for the diameter of the patch due to shifting and buckling of the casing above the casing collar. Decision was made to send welders in for the night and call town to discuss options. Decision was made to seal weld the casing collar and attempt to scarf out high spots on collar to make the existing patch fit. Sent inspection out to do a UT study of collar and lay out the thickness of the metal. Lay down for the night. 3/8/2019 - Friday Pre job meeting with Endicott crew and GBR. M/U to sit and roll out leads. Send inspection to site to do a 360° map of entire collar every 2" for high spots. Begin to pre heat collar per welding procedure. Seal weld top and bottom of casing collar. Let weld cool for 2hrs and mag weld to test for flaws. Weld was good. Decision was made to shorten the patch from 60" to 48" to make room for an extra patch to be placed over pressure containing patch. Grind out tacks from existing welds and move wedding bands up 1'. Begin to weld out top and bottom of bands per welding procedure. R/D welder and roll up leads. Lay down for night. 3/9/2019 - Saturday Pre job meeting with Endicott crew and GBR. Roll out to site and get welding leads and welder rigged up. Begin to finish welding lower band out per welding procedure. When done wrap with wool to wait the 24hr cool down period. Summon inspections to OK moving forward with scarfing of casing collar. Begin cutting sides of collar with air arc. Cut approximately and 18' wide section of collar out. Check well support structure and weight cells out. No change. Clean up area and roll up machine for the night. Will come back in the morning and begin welding out patch. 3/10/2019-Sunday Pre job meeting with Endicott crew and GBR. Begin fit up of clamshell patch on 13-3/8" casing. Break patch as needed to complete fit-up. Once fit-up complete, tac weld in place. RD welders a roll up leads for the night. 3/11/2019 - Monday Pre Job with Endicott crew and GBR. RU welder and leads. Begin circumferential welds of patch sleeves to spacer bands. Weld patch clamshells together with vertical welds. Begin 24 cooling period for NDE inspection. RDMO welding equipment and crew. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-12 WSS 50-029-22302-00-00 192-117 3/5/19 4/15/19 Daily Operations. 3/12/2019-Tuesday Pre job. Welds cooled for NDE inspection. Perform shear wave inspection and mag test. Welds passed both tests. Rig up to outer annulus and attempt MIT-OA to 1000 psi. Pressure up OA to 1170 psi with 1.5 bbls diesl, 15 min = 1000 psi, 30 min = 975 psi - Fail. Pressure back up to 1150 psi, 15 min = 1055 psi, 30 min = 987 psi - Fail. Pressure to 500 psi, 15 min 516 psi, 30 min 514 psi - Passed. No inflow in conductor or lea;leaks at surface. Assume open OA shoe. Begin to RDMO WSS. Slack off gradually from 100K to Olbs of tension. RDMO for night. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-12 WSS 50-029-22302-00-00 192-117 3/5/19 4/15/19 Daily Operations. 3/13/2019- Wednesday Pre Job. Complete RDMO of Well Support Structure. Demob Unit. 3/14/2019 - Thursday No activity to report. 3/15/2019 - Friday No activity to report. 3/16/2019-Saturday No activity to report. 3/17/2019-Sunday No activity to report. 3/18/2019 - Monday No activity to report. 3/19/2019-Tuesday No activity to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-12 WSS 50-029-22302-00-00 192-117 1 3/5/19 4/15/19 Daily Operations. 3/20/2019- Wednesday No activity to report. 3/21/2019 - Thursday No activity to report. 3/22/2019 - Friday No activity to report. 3/23/2019 -Saturday No activity to report. 3/24/2019 -Sunday No activity to report. 3/25/2019 - Monday Pre job meeting with Endicott crew and GBR. Roll out to site and get welding leads and welder rigged up. Vac out water from cellar. Preheat casing and weld lower band out per welding procedure. When done wrap with wool to wait the 24hr cool down period. 3/26/2019 -Tuesday Pre job meeting with Endicott crew and GBR. Weld upper band out per welding procedure. Begin 24 cooling period for NDE inspection. Hilcorp Alaska, LLC nWeekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-12 Slickline 50-029-22302-00-00 1 /19 Daily Operations. 4/10/2019- Wednesday No activity to report. 4/11/2019 - Thursday No activity to report. 4/12/2019 - Friday No activity to report. 4/13/2019 -Saturday No activity to report. 4/14/2019 -Sunday No activity to report. 4/15/2019 - Monday WELL S/I UPON ARRVAL, NOTIFY PAD -OP, PT PCE 300L/3,200H. PULLED 7" TTP FROM 9,668' MD. SET 7" MBR SSSV @ 1,503'. PAD OP PERFORM CLOSURE TEST, T/IA/OA = 2,750/0/0, BLEED TBG DOWN TO 2,400psi, WATCH FOR 15min, GOOD TEST. JOB COMPLETE, PAD -OP NOTIFIED WELL LEFT SHUT-IN UPON DEPARTURE. 4/16/2019 -Tuesday No activity to report. THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Endicott Field, Endicott Oil Pool, DIU MPI 2-12 Permit to Drill Number: 192-117 Sundry Number: 319-051 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, zlx� Daniel T. Seamount, Jr. Commissioner DATED this S day of February, 2019. SCANNED F'R 0 6 2019 RECEIVED STATE OF ALASKA FEB 0 1 201-1 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGC �In AA(. 9S 98(1 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Surface Casing Repair ❑' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hill Alaska LLC Exploratory ❑ Development ❑ Stratigraphic ❑ Service 192-117 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-22302-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 462.007 Will planned perforations require a spacing exception? yes ❑ No ❑+ DUCK IS UNIT MPI 2-12 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0034633 I ENDICOTT / ENDICOTT OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): • 10,410' 10,007' 10,327' 9,933' 3,150 10,327' N/A Casing Length Size MO TVD Burst Collapse Conductor 120' 30" 120' 120' N/A N/A Surface 2,738' 13-3/8" 2,777' 2,770' 5,020psi 2,260psi Production 8,357' 9-5/8" 8,208' 8,041' 6,870psi 4,760psi Production 1,545' 9-5/8" 9,587' 9,267'8,150psi 5,090psi Liner 740' 7" 10,410' 10,007' 8,160psi 7,020psi Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 7" 26# / NT80S 9,674' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 7" SABL-3 & 7" TIW LTP and RPB SSSV 9,606MD/ 9,284TVD & 9,678MD/ 9,349ND and 1,503MD/ 1,500ND 12. Attachments: Proposal Summary [a Wellbore schematic [a 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: 2/16/2018 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ RI . Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. brL-✓L Authorized Name: Chad Hell Contact Name: Watt Rivard Authorized Title: Operations Manager Contact Email: wrivard O hilcor .Colli Contact Phone: 777-8547 Authorized Signature: Date: 2/1/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: o 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: ` — 41 y APPROVED BY I C f Approved by: COMMISSIONER THE COMMISSION Date: ` cJ ,2•'i-rq O R I G I N A L RBDMSImFEB 0 5 2019 CT �� Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments ipDuplicate ��iqz"//9 K Hilean, Alaska, LLI Surface Casing Leak Repair Well: END 2-12 PTD:1921170 API: 50-029-22302-00-00 Well Name: END 2-12 API Number: 50-029-22302-00-00 Current Status: SI Rig: SL & Well Support Structure Estimated Start Date: Feb 16, 2019 Estimated Duration: 14 Reg.Approval Req'std? Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 1921170 First Call Engineer: Wyatt Rivard (907) 777-8847 (0) (509) 670-8001 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) AFE Number: 1950250 Well EZ Inputs Required: Yes Current Bottom Hole Pressure: Max Bottom Hole Pressure: Max. Proposed Surface Pressure: Recent Sl Surface Pressure: Brief Well Summary: 4,150psi @ 10,000' TVD 4,150psi @ 10,000' TVD 3,150psi 2900psi (Based on offset 2-70 SBHPS on 2/1/18) (Based on offset 2-70 SBHPS on 2/1/18) (Based on: MPSP= Max BHP -(0.1 psi/ft x 10,000 TVD) (Taken on 1/10/19) END 2-12 was SI on 11/16/18 following a confirmed hydrocarbon leak from the conductor with WHPs of T/I/O = 4800/700/0. The leak was observed at the top of the conductor landing rine and stopped soon after shut-in. While attempting to MIT -OA, the OA showed immediate communication to the conductor at 0 psi. Further inspection showed a significant line of circumferential corrosion including two holes 2" below the top of the conductor landing ring. Damage is at surface and excavation will not be needed for repair. Objective: Remove conductor and weld an external surface casing patch to restore OA integrity. Wellhead Support Structure (WSS) will be used to support wellhead during the repair. Notes On Wellbore Condition: • The well had a passing MIT -IA on 5/31/2017 and has no history of TAA or IAxOA communication in last 10+ years • Well was secured with a 7" PR plug set in the R -Nipple at 9668' MD with passing drawdown test. • Surface casing was hung with emergency slips in the conductor. Fluted mandrel hanger is effectively only a crossover to the starting head and sits —6" above the conductor landing ring. • Ultrasonic thickness measurements of the surface casing show weldable, nominal thickness (.5") metal roughly 4" above the conductor landing ring • Due to the close proximity of the weldable metal to the surface casing holes, the surface casing patch will either be welded directly below the fluted hanger or to the hanger itself. • Well had a 6500 psi rated injection tree installed and tested in 2012. Procedure: Pre -Sundry Work Prep Work 1. Disconnect flowline and instrumentation. 2. Verify tubing, IA and OA pressures have been bled to Opsi. 3. Sniff cellar and adjacent area with multi -gas meter for LEL, CO, H2S and 02. Ensure confined space, egress and ventilation is adequate for operations 4. Vac out gravel from well cellar down to cellar liner to remove residual hydrocarbons and provide more space for conductor removal H Hilwrp ,wet,, LU Surface Casing Leak Repair Well: END 2-12 PTD:1921170 API: 50-029-22302-00-00 5. Install fire blankets around the conductor landing ring to protect surface casing holes from hot machining debris. 6. Rig up in-place machine tooling to machine surface casing hanger flutes. 7. Proceed to machine down the OD of the flutes to 14-5/8" to provide additional access for welding the patch and potentially serve as a weldable surface in the event that the patch spans a surface casing collar. (_� ��J b -W. 8. Remove wellhouse Sundry Work (Approval required to proceed) Surface Casing Repair 9. Move in and rig up Well Support Structure. Place rig mats as needed to level out support structure legs. 10. Sniff cellar and adjacent area with mutli-gas meter for LEL, CO, H2S and 02. Ensure confined space, egress and ventilation is adequate for operations 11. Install BPV and test to 3500nsi. 12. Nile down tree at master valve or tubing head adapter as needed to makeup Wellhead Support Structure adapter flange. 13. Prepare to transfer load to the Well Support Structure. Pretension load cells according to operating manual.' 14. Pull 75001bs (Wellhead Weight) gradually building up load in 500 Ib increments. `57—Vonitor the wellhead for any signs of movement and discontinue increasing tension if movement observed. 15. Once wellhead neutrally loaded, install secondary containment around lower edge of conductor. 16. Drill holes (cold cutting drill bit) in the conductor roughly 5 ft below the landing rig to ensure adequate space for surface casing patch. 17. Remove cement as needed to confirm weldable, uncorroded surface casing at hole depth before cutting conductor. 18. Flush conductor with water from the landing ring and bull plug while taking fluid returns from the lower inspection holes. Flush until clean returns are observed. 19. Install N2 purge equipment for the conductor and OA. a. Use of an N2 cap/purge will be determined on site, prior to proceeding, with accurate gas readings and fluid returns observed. b. Prior to cutting conductor, install continuous gas monitoring for LEL's from the conductor. c. Hot work permit to outline if adjacent wells will require shut in as part of safety mitigations. 20. Cut ander remove rond tus: from above the inspection holes. a. Monitor load on Well Support Structure in addition to wellhead vertical displacement during initial conductor cuts. b. Adjust load to maintain constant vertical displacement in the event that conductor was supporting some of wellhead/casing weight. c. Primary cutting option is to use an air arc torch but the Hot Work Permit for this portion of the job will dictate if an alternative cutting method will be required. d. Two horizontal cuts (below landing ring and one at bottom of conductor section) and two vertical cuts will be required to remove the conductor. Alternately, if there is not sufficient room to drop the landing ring below the patch area, the vertical cut may be carried all the way up and through the landing ring. 21. Chip away excess cement from the surface casing. Buff and prepare surface casing for inspection and welding. 22. Inspection department to UT the exposed surface casing. b. Inspect for any additional holes below landing ring. H Hilcom Alaska. LG Surface Casing Leak Repair Well: END 2-12 PTD:1921170 API: 50-029-22302-00-00 c. Areas to patch to be identified marked and inspected on a grid to ensure competency for welds 23. Determine if any 13-3/8" collard connections are present in the area of the patch d. No historic tally is available for the 13-3/8" surface casing. e. If no surface casing collars are in the area of the patch, a flush 13-3/8" ID patch will be installed directly against the surface casing. If collars are present, spacer rings will installed a 14 5/8" ID patch utilized; obtaining necessary clearance around collars. f. Once patch final length is determined, cut patch to required length. 24. Install 13-3/8" ID clamshell patch and weld circumferentially to the surface casing and vertically to the other patch half. i. Patch material: A516-70, ID=13-3/8" thickness=1/2". 25. Contingency, if surface casing collar is present, proceed to install 14-5/8" diameter patch. g. The external OD of the machined flutes will be used as spacer band for the upper patch area. h. Circumferentially weld a band/spacer ring to the surface casing for the lower patch area i. Band material: A516-70, ID=13-3/8" thickness=5/8". i. Install clamshell patch and weld circumferentially to the machined flutes/ring and vertically to the other patch half. i. Patch material: A516-70, ID=14-5/8" thickness=1/2". 26. Inspect the welds to ensure competency./,� 27. Conduct an MIT -OA to 1000psi. ^� viJ 136,-)--, v 28. Weld cut conductor halves back onto conductor 29. Gradually release wellhead load from Well Support Structure back onto patched surface casing. 30. Unbolt and remove the adapter flange 31. Reinstall injection tree. 32. Pressure test the injection tree to 6500psi against the BEH -(-W j. Monitor tubing hanger test void to ensure neck seals are holding 33. Reinstall well house and backfill gravel over cellar liner 34. Re -install flowline and instrumentation. Slickline 35. RU SL unit. 36. Pressure test PCE to at least 300psi low/3200psi high. 37. RIH to pull TTP in 7" R Profile @ 9668' MD. 38. RIH and set 7" MBR SSSV in profile at 1503' MD. 39. RD SL unit. Attachments: -Wellbore Schematic -SC Leak Photo TR�= 6'X7'CIWFLS VVELLFFAD= 13-5/8'FMC MC TOR= BAKERC KB. R = 55.3' BF. Uhf— 16:1Z MOP= 6020' Max Angie = _ 29° @ 8420' --10449' a3tummD= —_ DatumTVD - 1oo00'SS 47#, NT80S XO NT95HS 11 8395' Minimum ID = 4.50" @ 1503' T' DUMMY SSSV NT -80S, .0383 bpf, IDM -80S, .0383 bpf, ID = 6.276' 1—{ 9674' CSG, 47#, NT95HS, D =8.691- 9940' PERFORATION SIMMRY REF LOG: CPL-GR(06/16/93) ANGLE AT TOP PERF: 230 @ 10108 Note: Refer to Production DB for historical pert data SIZE SPF INTERNAL Opn/Sqz DATE 4" 4 10106- 10112 O 04/10/93 4" 4 10116 - 10120 O 04/10/93 4- 4 10142 - 10158 O 04/10/93 4- 4 10166 - 10170 O 04/10/93 4- 4 10211 - 10222 O 04/10/93 4' 4 10230-10236 O 04/12/93 4- 4 10250 - 10263 O 04112/93 4' 4 10263 - 10283 O 04/12/93 4' 4 10290 - 10310 O 04/12/93 .0371 bpf, ID=6. GE 230 - 260 END 2 — ■ 2 PPM ON AIL 8 GAS INJECFETY NOTES: H2SDTORS. WENGS AV LL REQUIRES A SSSV. ® 1503' 7.OTIS RPB SSSV NP, ID = 5.962" 9590'—I7.OTIS R NP, D = 5.962' 19-5/8' X 7' BKR S-3 PKR D = 6.00' 1 -1 9668'—7.OTIS R NP, D = 5.962OTIS R NP, D = 5.962' 7" RP plug on 1/29/19 9670' 1-i9-5(8'X7'TMJLTPw/DEBACKSLV,ID=6.123' 17' MULESHOE D = 628' 1 9996' 1-17' MARKER JOINT DATE REV BYCOAQvF7415 DATE REV BY COMMENTS 03121193 D15 INITIAL C)00 N 110119112 LEC/PJC PULL DSSSV 8 FLOG (5176/12) 01/12/07 DFS/PAG Pl1LL PLLGS (01106/07) 03/01/07 WRR/PJC CONVERT TO NEN FORMAT 06/01/12 LE7JIvD PR PLUG 8 D CORR (05130112) 06117/12 RKT/ PJC MN D CORRECTDN 07/30/12 JO/JMt TREE CIO (07118112) E DICOTT UNO WELL: 2-1210-16 PERMT No: 1921170 APINo: 50-029-22302-00 SEC 36, T12N, R16F 1877' FNL 8 2196' FEL BP Exploration (Alaska) END 2-12 SC Leak Locations "Holes y mergency lips onductor anding Ring Schwartz, Guy L (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Thursday, January 31, 2019 4:10 PM To: Schwartz, Guy L (DOA) Subject: END 2-12 (PTD #1921170) Surface Casing Repair Prep Work Follow Up Flag: Follow up Flag Status: Flagged Hello Guy, As discussed, we are getting ready to submit a sundry for a surface casing weld repair on END 2-12 (PTD #1921170). The well is a SI gas injector with a confirmed SC leak at surface and has been secured with a tubing tail plug. We have a window to perform the repair in roughly 2-3 weeks and will be submitting the Sundry tomorrow. In preparation for the repair, we need to mill down the external upsets of the fluted surface casing hanger to create room for welding the patch. This well's surface casing was actually set with emergency slips in the conductor landing ring and the fluted "hanger" floats ^'8" above the conductor. It's only purpose in this configuration is to act as a crossover from the surface casing to the wellhead. Machining the external flutes down will not affect the structural or pressure integrity of the wellhead system. We are hoping to get started on this machining prep work soon and I wanted to confirm that this work could be conducted prior to the sundried surface casing repair. Here is the rough order of operations: 1) Prep Work o Cut/Machine Flutes; IZ/U� o Remove Wellhouse & Flowlines v 2) Sundried Repair o Remove tree and support wellhead with Well Support Structure o Cut Conductor o Weld surface casing patch on 13-3/8" Surface Casing o Weld Conductor Also here is a rough photo of the portion of the flutes that will be milled down to make room for the patch: Thank You, Wyatt Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska, LLC 0: (907) 777-8547 1 C: (509)670-80011 wrivard(a)hilcorp.com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 t MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday,June 20,2017 P.I.Supervisor Fejt J"( i SUBJECT:Mechanical Integrity Tests HILCORP ALASKA LLC 2-12 FROM: Jeff Jones DUCK IS UNIT M'I 2-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 2-12 API Well Number 50-029-22302-00-00 Inspector Name: Jeff Jones Permit Number: 192-117-0 Inspection Date: 5/28/2017 Insp Num: mitJJ170618121814 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2-12 " Type Inj I G "TVD 9286 ' Tubing 4796 - 4799 4800 4806 4806 PTD 1921170 -Type Test SPT Test psi 2322 - IA 2630 2627 - 2623 - 2616 - 2607 - BBL Pumped: BBL Returned: 2.4 OA 20 20 20 - 20 20 " Interval 4YRTST P/F P ✓ Notes: This data is from an extended(1 hour 45 min.)MIT to further demonstrate integrity. - 5ee asoMets1/or;[812.tool 6,0 Pia 0-- (.14„4„.„9 SCANNED AUG 1 0 2017, Tuesday,June 20,2017 Page 1 of 1 • , . • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jing Regg 'Ref r DATE: Tuesday,June 20,2017 P.I.Supervisor ' ` 1 h(4°1 t 7 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 2-12 FROM: Jeff Jones DUCK IS UNIT MPI 2-12 Petroleum Inspector Src: Inspector Reviewed By:,— P.I.Supry ib/2— NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 2-12 API Well Number 50-029-22302-00-00 Inspector Name: Jeff Jones Permit Number: 192-117-0 Inspection Date: 5/28/2017 , - Insp Num: mitJJ170618121007 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2-12 - Type Inj G' TVD 9286 Tubing 4794 4794 4798 4793 4795 4794 PTD 1 1921170 " Type Test SPT Test psi 2322 IA 592 2605 2610- 2617 - 2624 - 2629 ' BBL Pumped: 1 3.4 ' BBL Returned: OA 20 20 20 20 20 20 Interval 4YRTST P/F 1 Notes: 1 well inspected,no exceptions noted.This test was continued for another 45 minutes to demonstrate integrity,see related inspection mitJJ 170618121814 for this data. ;/ 5 GoUrke,Qj S`lpp` t c CWA44 k 5 Tuesday,June 20,2017 Page 1 of 1 *Regg, James B (DOA) `L0 M +t 1 Zee(.('8(ztet37 tiotdi$(zt$%4 From: Regg,James B (DOA) Sent: Tuesday, May 30, 2017 3:48 PM To: 'Wyatt Rivard' 1� � (t7 Cc: Brooks, Phoebe L(DOA) (� Subject: RE: MIT-IA on Endicott Gas Injector 2-12 (PTD # 1921170) - Difficult IA Stabilization Thanks for the supporting info. We will accept the results for a passing MIT. - Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or jim.regg(a)alaska.gov. From: Wyatt Rivard [mailto:wrivard@hilcorp.com] Sent:Tuesday, May 30, 2017 12:44 PM To: Regg,James B (DOA) <jim.regg@alaska.gov> Cc:Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Subject: MIT-IA on Endicott Gas Injector 2-12 (PTD# 1921170)- Difficult IA Stabilization Jim, Endicott performed an AOGCC witnessed MIT-IA on gas injector 2-12 (PTD# 1921170) on 5-28-17. Unfortunately the IA stabilization was hampered by thermal changes over the course of testing. IA pressure rose 24 psi over the first hour test and then dropped back down 20 psi after an additional 45 minute test.The IA had been fluid packed on 5/19/17. After reviewing gas compressor discharge temps, the ''2 hr period of testing coincides with a 3-4 degF bump in gas temperature. We do not have automated wellhead temps or IA pressures on 2-12 but I've included a screenshot of the gas compressor temps for comparison. Additionally I've included an IA pressure trend from nearby waivered gas injector �A 1-0-5 which shows a similar pressure response observed over the same perl'o of time. The 4000 psi TxIA and ^'500 psi IAxOA differentials maintained before and after the test give a good indication that there are no integrity issues on this well. Additionally, there was no pressure response observed on the OA during the test. Initial and final IA pressures over the total of 2 hrs of observation were within 2 psi and we would consider the test a pass when factoring in the additional temperature data. Going forward, should Hilcorp schedule an additional AOGCC witnessed MIT-IA or will the attached MIT meet the 4-year requirement? Thank You, 1 0 i . . • Endicott 2-12(PTD 1921170) MIT dated 5/28/17 Endicott Gas Compressor Discharge Temperature ,..b I In Iwnl.sol J y$; our•0:0051511.7 - 41-O• !Perim:08x.._... I0l5S: 30,0 228.0 2220 III 215.0 / �``v" <- TEST 1-> <-TEST 2-> 210.0 - - 204.0 00.0 8:0000 AM 8'3090 AM 9:22:00 22 9:30:0022 10:2220 AM 10:3090 AM 11:00:00 AM 11:30:22 AM 12:00:00 FM 12:30:00 PM 100:00 PM 130:00 PM 2:00:00 PM 2:30:00 PM 5/2832017 - 3'.42:27 PM J MEM..,_ .4 4 : ,c, M,,. Pan ID P..MM Dowd. la. Hd, Peleece Vele. vs._ •END F1C1794 C1Wgopv MPI GAS!NJ S-I_.. Stye _... OUY 5:29/2017104800AM. END PI)94C M/Algopv MPI GAS INJ 5-01 .END_00071A wNgo.pv WELL5-11AP END FIC1794 dlelgo op MPI GAS{NJ S-1 ,IEND 041699_1 pi1699_1.w 1FTGA4MPI0SDI Endicott 1-05 (PTD 1861060) 1GINJ Thermal Pressure Response lAnd:111114I2P _j F ra0 34200520=5.40 - nj- _ MMC...r..1... u»0 112 0 11100 \\ 1100.0 i 1040 Di� TEST # 1 TEST # 2 1000.0 10700 10600 9:1528 M1 9:30:00 AM 9:45.00 AM 1070:2222 10:15:0022 10:2222 AM 10'.4520 AM 11'.002022 11:15:0822 11:3000 AM 11^4520 AM 12:22:0002 12:15.00PM 12:33COW 5728/2017- 107:'4,Pr I J ® ,., r 4 P 04515 P..MI. DP.. la MO BM..,.e vel,. Ctm v END FICI)91 C40J92W GAS SPC,4NJ 2213 5014 _ 41 00 W[19k91]191500.02 Vw. 0 00 148 0554 00 84 034.19 MSCFD 6:.'3161 MSCFG ENO1,11005B wmgPW MPI C✓SMJ WI-05 090 600022 470049 PSIG 6875.53 PSIG ' � • ! awnloA 0 0 0 0 0 0 0 0 0 0 0 o 0 0 0 0 o 0 poj 00o N in v m NO - o I i i I i I i i . . . . . . LIOZ/6Z/SO - LTOZ/LZ/SO - LIOZ/SZ/SO - LIOZ/EZ/S0 - LIOZ/IZ/S0 -LIOZ/6T/S0 -LIOZ/LI/SO _ -LIOZ/ST/S0 f Ln - LIOZ/EI/S0 3 _LIOZ/II/S0 t -LIOZ/60/S0 -LIOZ/LO/SO - LIOZ/SO/SO -LIOZ/E0/S0 LIOZ/IO/S0 -LIOZ/6Z/b0 } . LTOZ/LZ/b0 -LIOZ/SZ/b0 -LIOZ/EZ/b0 I + -LIOZ/IZ/b0 0 a --LTOZ/6T/b0 0 amm.... -LIOZ/LT/b0 I— ....mow mom. -LIOZ/SI/b0 LIOZ/ET/b0 rl _LTOZ/TI/b0 _--LLLIIIOOOZZZ///600//bb00 < am — LTOZ/SO/b0 I [ r---- £0/b0 - TO/b0 OE/E0 8Z/E0 9Z/£0 VZ/EO ZZ/E0 ®..... -LIOZ/OZ/E0 C i • C -LLTTOOZZ/8bT £0O il ~ LIOZ/9 / O ILIO / /EO _LLTOZ/OI/EO IOZ/80/£0 - LIOZ/90/E0 LIOZ/b0/E0 - LIOZ/ZO/EO 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 l0 v) V r+l N 4 aanssaJid • • II .k Post Office Box 244027 0 ttS Anchorage,AK 99524-4027 Hilcorp Alaska,LLC ,JUL. 3 2015 3800 Centerpoint Drive Suite 100 Anchorage,AK 99503 AOGCC Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission _. I + 7 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ,— I Re: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "/" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD # 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp • Orig • New API_Wel1No PermitNumber WellName WellNumber WellNumber 50029218010000 1880370 DUCK IS UNIT MPI 1-01/119 1-01 50029226010000 1951500 DUCK IS UNIT MPI 1-03/P16 1-03 50029216050000 1861060 DUCK IS UNIT MPI 1-05/020 1-05 50029217430000 1870810 ?DUCK IS UNIT MPI 1-09/118 1-09 50029217430100 1970290 DUCK IS UNIT MPI 1-09A/L21 1-09A 50029221070000 1901570 DUCK IS UNIT MPI 1-11/SN4 1-11 50029223610000 1930560 DUCK IS UNIT MPI 1-15/P25 1-15 50029221000000 1901500 DUCK IS UNIT MPI 1-17/SN2 1-17 50029221000100 1961990 DUCK IS UNIT MPI 1-17A/117 1-17A 50029225690000 1950930 DUCK IS UNIT MPI 1-19/118 1-19 50029220050000 1900020 DUCK IS UNIT MPI 1-21/K25 1-21 50029225100000 1941280 DUCK IS UNIT MPI 1-23/015 1-23 50029217220000 1870420 DUCK IS UNIT MPI 1-25/N22 1-25 50029217220100 1970750 DUCK IS UNIT MPI 1-25A/K22 1-25A 50029216930000 1870090 DUCK IS UNIT MPI 1-27/P20 1-27 50029216690000 1861810 DUCK IS UNIT MPI 1-29/M25 1-29 50029225620000 1950720 DUCK IS UNIT MPI 1-31/M21 1-31 50029225770000 1951070 DUCK IS UNIT MPI 1-33/M23 1-33 50029225770100 1980870 DUCK IS UNIT MPI 1-33A/L24 1-33A 50029225770200 1982550 DUCK IS UNIT MPI 1-33B/L24 1-33B 50029225770300 2050040 DUCK IS UNIT MPI 1-33C/M24XX 1-33CXX 50029216720000 1861840 DUCK IS UNIT MPI 1-35/025 1-35 50029217480000 1870900 DUCK IS UNIT MPI 1-37/P24 1-37 50029218270000 1880630 DUCK IS UNIT MPI 1-39/P17 1-39 50029218270100 2061870 DUCK IS UNIT MPI 1-39A/N-16 1-39A 50029217130000 1870320 DUCK IS UNIT MPI 1-41/023 1-41 50029218640000 1881050 DUCK IS UNIT MPI 1-43/P26 1-43 50029219910000 1891240 DUCK IS UNIT MPI 1-45/Q26 1-45 50029216250000 1861310 DUCK IS UNIT MPI 1-47/Q21 1-47 50029216250100 1972030 DUCK IS UNIT MPI 1-47A/M20 1-47A 50029218410000 1880780 DUCK IS UNIT MPI 1-49/P21 1-49 50029223040000 1921190 DUCK IS UNIT MPI 1-51/V20 1-51 50029225010000 1941120 DUCK IS UNIT MPI 1-53/Q20 1-53 50029217880000 1880210 DUCK IS UNIT MPI 1-55/R25 1-55 50029218730000 1881140 DUCK IS UNIT MPI 1-57/R23 1-57 50029226440000 1960220 DUCK IS UNIT MPI 1-59/024 1-59 50029225200000 1941420 DUCK IS UNIT MPI 1-61/Q20 1-61 50029219050000 1890060 DUCK IS UNIT MPI 1-63/T22 1-63 50029226270000 1951880 DUCK IS UNIT MPI 1-65/N25 1-65 50029226270100 2032120 DUCK IS UNIT MPI 1-65A/N27 1-65A 50029219850000 1891140 DUCK IS UNIT MPI 1-67/T20 1-67 50029220200000 1900290 DUCK IS UNIT MPI 1-69/V19 1-69 50029215680000 1860630 DUCK IS UNIT MPI 2-02/P18 2-02 50029215850000 1860820 DUCK IS UNIT MPI 2-04/M19 2-04 50029216990000 1870180 DUCK IS UNIT MPI 2-06/J22 2-06 50029217710000 1880040 DUCK IS UNIT MPI 2-08/K16 2-08 150029223020000 1921170 DUCK IS UNIT MPI 2-12/Q16 2-12 50029216390000 1861490 DUCK IS UNIT MPI 2-14/016 2-14 50029218850000 1881340 DUCK IS UNIT MPI 2-16/M16 2-16 50029220320000 1900430 DUCK IS UNIT MPI 2-18/L16 2-18 150029220480000 1900600 DUCK IS UNIT MPI 2-20/L15 2-20 '50029219310000 1890340 DUCK IS UNIT MPI 2-22/L14 2-22 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE- Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED -[] Logs-of vadous kinds . [] Other COMMENTS: Scanned by: ~ t Dianna Vincent Nathan LOwell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si C u�`,A� 1///%% t.,), THE STATE P .. ,.i _ a l'1_0' : Tr-----_.` t� ice _�'i_- "^ � 1'.\ /- `._. ik -_ — 333 West Sevenih Avenue 9 GOVERNOR SEAN PARNEI I, Anchorage Alaska 99501-3572 amu ¢ ✓ 907.279 1 e z3 Josiah Igwe ,, Petroleum Engineer NNED MAY 2 0 l()14 BP Exploration (Alaska), Inc. F q d� ..- 117 P.O. Box 196612 ----'. Anchorage, AK 99519-6612 Re: Endicott Field, Endicott Oil Pool, EPA 2-12/Q-16 Sundry Number: 314-124 Dear Mr. Igwe: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, G f 4_,(.) 71-------- Cathy P. Foerster Chair DATED this Jr-day of March, 2014. Encl. • RECEIVED STATE OF ALASKA MAR 0 3 2 1 • ALASKA OIL AND GAS CONSERVATION COMMISSION 075 3(5/ I APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 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 E ' Alter Casing❑ Other. _Water Wash [i 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 192-117-0 - 3.Address: Stratigraphic ❑ Service Q . 6.API Number P.O.Box 196612,Anchorage,AK 99519-6612 50-029-22302-00-00 ' 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? EPA 2-12/Q-16 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0034633 - ENDICOTT, ENDICOTT OIL - 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): 10410 • 10020 A 10327 9943 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 40-120 40-120 Surface 2738 13-3/8"68#NT8OCYHE 39-2777 39-2770.58 5020 2270 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 740 7"29#L-80 9670-10410 9343.77-10020.1 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 7"26#NT8OS NT-80S 38-9674 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths 7"MBR SSSV 1503,1500.34' 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Development ❑ Service E 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ Q WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Josiah Igwe Email Josiah.lgwe@BP.Com Printed Name Josiah Igwe Title Petroleum Engineer Signature W—~ ' . Phone 564-4753 Date Prepared by Garry Cation 564-4424 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number Vii_.— L1--( Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: RBDM MAY V 9 2014 Spacing Exception Required? Yes ❑ No D' Subsequent Form Required: /0 —zi.6 4- r/' APPROVED BY r7/� Approved by: a �Ii,Y�`' COMMISSIONER THE COMMISSION Date: ,3 —,S - / I / Form 10-403 Revised 1 /2012/ /(� r ,ray ` Ij `'o alid for 12 months from the date of approval. Submit Form and Attachments Duplicate / 0 I � � Packers and SSV's Attachment ADL0034633 Well Facility Type MD Top Description TVD Top 2-12/Q-16 SSSV 1503 7" MBR SSSV 1500 2-12/Q-16 PACKER 9606 7" Baker SABL-3 Packer 9286 2-12/Q-16 PACKER 9678 7"TIW Liner Top PKR 9351 Cl)• o o o O O O O _l Z H H Z Z • 00000 N O N. O N p r- O N 0 N oo (D ON. L0 N •- CO N- O N CCI CO CO CO O N- o N O co r- m O N O 00 r•-• _ O o N �n f� 00 N O 0 0 I- O 4- 0 0 0 00 0 Tr 0M C co co C) M a� E M o 0 o N- (Ø m N CA f�CO 2 f� (A o 0 J0 N 0 1-1HOIcornrnco Q O o co co co co 0 2 w cn = >- o L0 O U) 0 O z IT N X * * Z Z O N CO ((D O N. A L- N- 1.0 CO CD 0) O O O V co co N co N- co O N- co co N O O O O 0) H pH= w V ZwOOCCEi O Z Etr o D 0 .JCL CL Cl Perforation Attachment _ ADL0034633 Well Date Perf Code MD Top MD Base TVD Top TVD Base 2-12/Q-16 4/12/93 PER 10108 10112 9740 9743 2-12/Q-16 4/12/93 PER 10116 10120 9747 9751 2-12/Q-16 4/12/93 PER 10142 10158 9771 9786 2-12/Q-16 4/12/93 PER 10166 10170 9793 9797 2-12/Q-16 4/12/93 PER 10211 10222 9835 9845 2-12/Q-16 4/12/93 PER 10230 10236 9853 9858 2-12/Q-16 4/12/93 PER 10250 10283 9871 9902 2-12/Q-16 4/12/93 PER 10290 10326 9908 9942 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF To: Len Seymore/Tyler Norene (ADW Well Service TL) Date: February 28, 2014 Jerry Middendorf/Rob Liddelow (AD Wireline TL) GPB Well Ops Team Leaders From: Ramon Hidalgo (Well Integrity Engineer) AFE: AENCAPSU Est. Cost: Subject: END2-12:Solvent wash/MIT-IA IOR: 100 Please perform the following procedure: 1 . W PPPOT-T and PPPOT-IC to 5,100 psi 2. S Pull SSSV, Drift & Tag well, Solvent wash and Load and Kill well, Set TTP, MIT T to 2,500 psi, Load IA and MIT-IA to 5,100 psi while holding 4,100 psi on tubing, Pull TTP, Reset the SSSV 3. F Assist Slickline Current Status: Operable Gas injector Last Test: 05/31/13 AOGCC MIT-IA Passed to 4,000 psi Max Deviation: 29 degrees @ 8,420' MD Minimum ID: 4.50" @ 1,503' MD 7" Dummy SSSV Last IA FL: 02/6/14 IA FL at surface Last T/I/O: 02/6/14 4620/630/30 Program Objective END2-12 is a gas injector which is currently injecting about 52 mmscfpd at 4,700 psi but has historically injected 90 mmscfpd at about the same pressure. Solvent wash is required to improve its injectivity. At the same time, End2-12 passed an AOGCC MIT-IA to 4,000 psi in 5/31/2014, retesting is required to satisfy BP guidelines of MIT-IA above maximum injection pressure. Decision was made to retest to lx maximum injection of 5,100 psi after evaluating the loads applied to the 20 year old production casing and packer. Solvent wash is required to improve the injectivity and MIT-IA to 5,100 psi is required to satisfy BP guide lines. Well History END2-12 is a gas injector which currently injects about 52 MMSCFPD at 4,700 psi. The beginning of the program is a solvent wash to restore injectivity, the well has historically injected 90 MMSCFPD at about the same pressure. END2-12 passed an AOGCC MIT-IA to 4,000 psi on 5/31/13, retesting is required to satisfy BP guidelines of MIT IA above maximum injection pressure. The decision was made to re-test to lx Maximum injection Page 1 of 4 • pressure of 5,100 psi after evaluating the loads applied to the 20 year old production casing and packer. Wellhead 1. W: PPPOT-T and PPPOT-IC to 5100 psi. Slickline/Fullbore 1 . SL: Pull 7" OTIS RPB SSSV at 1,503' MD. 2. SL: Drift and Tag to PBTD with sample bailer • Send any sample recovered to BP lab for analysis 3. FB & SL: Solvent wash and Load and Kill well and set plug in TT • Fullbore to rig up hardline so we have the capability to pump at 8 bpm • Pump 200 bbls of 50/50 Diesel/Xylene with 1 % mutual solvent • Pump 300 bbls of 2% KCI with 0.2% F103 (Surfactant) • Finish loading well with 300 bbls 2% KCI per attached pump schedule • FP tubing • Set plug in the 7" Otis R Nipple @ 9,668' MD 4. FB: MIT-T to 2,500 psi A. If MIT-T passes, continue to step 5 B. If MIT-T Fails trouble shoot TTP good enough to hold support pressure for the MIT-IA. 5. FB: MIT IA to 5,100 psi while holding 4,100 psi on the Tubing as per attached pumping program, record LLR if fails. A. If MIT-IA passes, remove the TTP, and set SSSV, RDMO. B. If MIT-IA fails, leave TTP in hole, RDMO for secure and upcoming LDL. Contacts: Josiah lgwe END PE Desk: 564-4753 Cell: 590-0610 Ramon Hidalgo Desk: 564-5992 Cell: 406-425-2590 Page 2 of 4 Versionl.1 0412812010 Fullbore Pumping Design Template Well Name END2.12 Job Scope MITIA H2S(ppm/date) WBL Cat Reg Compl Cost 5100 Max Pumping Pressure(psi) Well Type GI AFE AENCAPSU 2%KCI Main Fluid Type Date 212812014 PE IOR 0 600 Main Fluid Volume(bbls) Engineer Ramon Hidalgo Phone 564-5992 Diesel Freeze Protect Type Job Objective 70 Freeze Protect Volume(bbls) NA Recent Tbg Fluid Level(ft) Solvent wash is required to improve the injectivity and MIT-IA to 5,100 ' At Sfc Recent IA Fluid Level(ft) psi is required to satisfy BP guide lines NA Recent OA Fluid Level(ft) 360 Expected Tbg Fill Up Volume(bbls) <5 Expected IA Fill Up Volume(bbls) NA Expected OA Fill Up Volume(bbls) 395 Wellbore Volume to Perfs(bbls) Fullbore Pumping Schedule 4000 Anticipated Bottom Hole Pressure (psi 8800') 9200 Anticipated Pressure at the Packer Pump Volume Rate Max Yes Tubing/Casing within Pressure Limits? Stage Fluid Type Into (bbls) (bpm) Pressure Size Burst/Collapse 80%Burst/Collapse Tubing Burst(psi) 7 7240 5792 Spear Methanol(60/40) Tbg 10 8 2500 Tubing Collapse(psi) 7 5410 4328 Casing Burst(psi) 9.625 6870 5496 Solvent 501.50 Diesel Xylene Tbg 200 8 2500 Casing Burst 2(psi) 9.625 8150 6520 Load 2%KCI Tbg 600 8 2500 Select Input Depth Integrity Issues? Select Input Depth MIT Diesel Tbg 70 8 2500 Select Input Depth MIT Methanol(60140) IA 5< 1 5100 No Tubing Caliper? Burst/Collapse ratings may need to be derated based on tubing Yes Production Packer within Pressure Limits? Detailed Pumping Procedure 10000 Rated Packer dp 5200 Max Anticipated dp at Packer 1 PJSM. RU&PT lines 2 Pump per schedule above Yes-Tubing Hold Pressure on Other Strings? 3 Load as per the schedule above 4100 Tubing(psi) 4.Set TTP and MITT to 2500 psi IA(psi) 5. MIT IA to 5100 psi while holding 4100 psi on the Tubing OA(psi) 6. RDMO Page 3 of 4 a • • TRFF WELLHEAD= 6" x13-518 RAC E N D2-12 ONFETY Al&GAs R:H2S .WELL'REQUIRES A ACTUATOR- BAKER C SSSV. KB.BEV= 55.3' BF ELEV= 16 12' 1503' I-1 7'OT15 FEB SSSV MP.ID-5.962' KOP= 6020' Q Mix Angle= 29"@ 8420' Dahill MD- 10449'. Wean = 10000'SS 13-318'CSG,681x.NT-80,BTRS,O=12.415'1-1 2777' /11 • ,9-t3/8"CSG,47*,NT80S X0 NT95HS 1— 8396' ■ ■ 9590' 7"OBS R D=5.962'1 Minimum ID= 4.50" 1603' 17"DUMMY SSSV $ $ asA1ssrs-xrarcRs3FKR e ■ ■ 1 9668' 1 I r-OTE R NP()-6 962 1 9670' H9-518"X 7"TM(LIP wTIEBACK SLV,U)1312""- TOP OF rTOPOF T LNR —{ 9670' I7"TBG,26M,NT-80S,.0383 bpi.U=6.276" 1 1 9674' 9674' H 7"MJLE5HCE D=$.2e' 19-5,8"CSG.4711 N195HS,13=8.691" H 9940' 1---41 9996' 1 17"MARKER JOINT] FERFORATION SLM1NRY ' REF LOG CNL-GR(06(16/93) ANGLE AT TOP PERE 23° 10108 l bte.Refer 10 Production DB for hislorical perf data. SIZE SIV NTERVAL CpnJSgz{ DATL 4" 4 10108-10112 0 04110+93 4" 4 10110-10120 0 04410+93 4' 4 10142-10158 0 x,04110193 4" 4 10166-10170 0 1048110+'93, 4" 4 10211 10222 0 04110/;3• 4' 4 10230-10236 0 104112193' 4" 4 10250-10263 0 04112863 4" 4 10263-10283 0 04112/93' 4" 4 10290.10310 0 04112(93 i 1f "n H 10328' 1- 10IN11 11111114 441 441 1111111A4,411 I7"LNR 298.--8o,TKGBTC,.3311 bpf,U=45 40-1 11/410 14 I NMI rel I 11 DATE REV BY COMBOS DATE Ofli BYt7DIALFHTS FPCICOTTtNT 11.11 1i J UID IM I WNM L 1: I'Ltl14111 11111x11[. tEOPJC RLL OSSSV 8 FiLIG(5116112) WEL 2-12 t 0-16 — 01112807 DRF/PAG PULL R_UGS (01106!07) T{RM1TNo. 1921170 03101,0! WF4Ft11 JC CUNVERI 10 NEW I-0F4,44 I AR No 50-029-22302-00 Orw01i12 .EGM) PR PLUG&d OORR(05'30112) SEE 36,T12N,R166,1877'FM&2196'FB 06,t 71 t 2 RKT1 PJC I)CORREC7UN 3r tni17 JOUteU TfLLGO(07118112) OP Exploration(Alaska Page 4 of 4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,June 04,2013 TO: Jim Regg �,, P.I.Supervisor l±r e�(1.3 t3 SUBJECT: Mechanical Integrity Tests l BP EXPLORATION(ALASKA)INC 2-121Q16 FROM: Bob Noble DUCK IS UNIT MP]2-12/Q16 Petroleum Inspector Src: Inspector Reviewed By:�/ P.I.Supry a- NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT MP12-12/Q16 API Well Number 50-029-22302-00-00 Inspector Name: Bob Noble Permit Number: 192-117-0 Inspection Date: 5/31/2013 Insp Num: mitRCN 130604073617 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min well 2-12/Q16 Type Inj c TVD 9286 IA l 400 ' 4024 - 4013 4006 f PTD - ',T e Test _- 1921170 ;Type SPT IP/Ft pst 2321 OA 34 36 39 39 T_ — Interval 4YRTST P ✓ I Tubing 1 4735 4740 4743 4737 ,, Notes: SCANNED FEB 2 0 2014. Tuesday,June 04,2013 Page 1 of 1 MEMORANDUM To: Jim Regg r''kk~ P.I. Supervisor '1 ~~ ~)~((J{ FROM: Lou Grimaldi Petroleum Inspector State of Alaska :J Alaska Oil and Gas Conservation Commission DATE: Monday, June ls, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 2-12/Q16 DUCK IS UNIT IvII'I 2-12/Q16 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~J. '~-~ Comm Well Name: DUCK IS UNIT MPI 2-12/Q16 Insp Num: mitLG090612133815 Rel Insp Num: API Well Number: s0-029-22302-00-00 Permit Number: 192-117-0 Inspector Name: Lou Grimaldi Inspection Date: 6/12/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2-tz/Q16 Type Inj. O TVD 9286 ~ IA 870 4000 - 3990 3990 , P.T.D 19u1~o TypeTest SPT Test psi aooo ~ pA o zo zo 20 Interval aYRTST p~ P i Tubing asoo asoo asoo asoo Notes' Pretest conditions observed for thirty minutes "OK". s Bb]'s pumped, 4 returned. Good test tti1~ n. -~,1. ~essw~- Z3Z~ psi Monday, June Is, 2009 Page 1 of 1 • ~/ u~~~ C~J~ IL SGJ lJ ll\~u tl AI.ASSA OIL A1~TD GAS CO1tTSERQA7`IO1~T CO1~II-IISSIOIQ Jose Solo PE BP Exploration Alaska Inc. PO Box 196612 ' Anchorage, AK 99519-6612 u SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 (; 1s~:~ ti ~ ~1 Re: Endicott Field, Endicott Oil Pool, 2-12/Q-16 ~ ~ ~-- Sundry Number: 309-018 Dear Mr. Solo: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. *~ / Chair DATED this~JdPay~of January, 2009 Encl. ~~ • I ~~ STATE OF ALASKA ~~~~® / (~ ALASKA OIL AND GAS CONSERVATION COMMISSIOryAN 2 0 2009 ~--1 APPLICATION FOR SUNDRY APPROVAL ~~ ~ 20 AAC 25.280 ~ GaS Cons. Commission 1. Type of Request: Abandon Suspend Operational shutdown Perforate Anchor"er Othe ~ After casing ^ Repair well ^ Plug Perforations^ Stimulate ^ Time Extension ^ ACID WASH' Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmeni^ Exploratory ^ 192-1170 3. Address: P.O. Box 196612 Stratigraphic^ Service ~ ~ 6. API Number: Anchorage, AK 99519-6612 50-029-22302-00-00 7. If pertoraGng, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: 2-12/Q-16 Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-034633 ~ 56 KB - Endicott Field / Endicott Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 10410 ~ 10020.1 10327 9942.78 NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 131 30" Surtace 131 Surtace Surface 2733 13-3/8" 68# nt-80s Surtace 2777 Surface 2777 5020 2270 Production 9896 9-5/8" 47# nt80s Surface 9940 Surtace 9487 6870 4760 Liner 740 7" 29# L-80 9670 10410 9244 9920 8160 7020 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - 7" 26# NT-80S SURFACE - 9674' Packers and SSSV Type: 9-5/8"X7" BKR S-3 Packers and SSSV MD (ft): 9606' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/2/2009 OIL ^ GAS ~ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ~ WINJ ^ WDSPL ^ 1 Commission Representative: Prepared by Gary Preble 564-4944 ~ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jose Soto Printed Name se t Title P.E. Signature Phone 564-5972 Date 1/19/2009 COMMISSION USE ONLY N b S d ~~~ '" ~ ~ un um er: ry - 6 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form R wired: ~~ ~ APPROVED BY ~7 Approved by: COMMISSIONER THE COMMISSION Date: ( ~ Form 10-403 Revised 06/2006 ~ ~'~, ~C~, `~ 1~0~ Submit in Duplicate 2-12/Q-16 192-1170 PERF ATTArHMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 2-12/Q-16 4/12/93 PER 10,108. 10,112. 9,739.73 9,743.41 2-12/Q-16 4/12/93 PER 10,116. 10,120. 9,747.09 9,750.77 2-12/Q-16 4/12/93 PER 10,142. 10,158. 9,771.06 9,785.83 2-12/Q-16 4/12/93 PER 10,166. 10,170. 9,793.22 9,796.92 2-12/Q-16 4/12/93 PER 10,211. 10,222. 9,834.9 9,845.11 2-12/Q-16 4/12/93 PER 10,230. 10,236. 9,852.54 9,858.11 2-12/Q-16 4/12/93 PER 10,250. 10,283. 9,871.12 9,901.81 2-12/Q-16 4/12/93 PER 10,290. 10,326. 9,908.32 9,941.85 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • by To: Clark Olsen/Jerry Bixby -Well Operations Supervisor December 15, 2006 From: Jose Soto -Endicott Production Engineer Subject: END2-12/Q-16 Acid/Water Wash Est. Cost: $60 M AFE ENR02WL12-C IOR: Est 100 BOPD Summary: • C -Acid/Solvent Bullhead with 05/50 DAD Acid Frac Gradient: 0.72 psi/ft BHT: 214 F Current Status: Operable gas injector Max Inclination: 28.52° at 7,420'md Minimum ID: 5.961" OTIS R nipples C~ 1503', 9590 and 9668" md. Last TD tag: 01/07/07: Tagged @ 10,100' SLM with 5.75" CENT and 4.5" 3 prong wire grab Last Downhole Op: 10/03/07: Set 7" MBR in SVLN at 1503' MD. Latest H2S value: END2-12 is an upper zone 85 mmscfpd steady gas injector (zones Fiii, Fiv, Fv). Recently in 12/14 the well suffered an infectivity reduction of around 25 mmscfpd after the plant lost a couple thousand gallons of seal oil (turbine 32) into the gas injection stream. Aiming to clean a broad frame of possible damages, a 12% DAD Acid wash (includes 50% xylene) is recommended. Objectives - No spills, No injuries, No harm to the environment - Clean out tubing of heavy hydrocarbon deposits. - Inject solvent in the formation to help remove heavy hydrocarbon that could be restricting flow to wellbore. Procedure 1. Mobilize/RU pumping equipment, tanks. Hold PJSM. 2. Preheat seawater 80°F. 3. PT Dowell surface lines to 5000 psi s ~~ i. ~ 4. Pump the following treatment at maximum rate or 3000 psi max pressure. a) 100 bbls 12% DAD Acid b) 900 bbls Filtered Seawater (To displace acid away from wellbore) c) 5 bbls Methanol (spacer between water and gas) 5. Slowly open injection choke. Step the injection pressure from WHSIP* to full injection pressure over a 4 hour period. 6. RD Schlumberger. *WHSIP: well head shut in pressure Fluid description: 50:50 DAD Acid (12% HCL) to contain: 50% Xylene + other componets: A261 Corrosion Inhibitor A179 Corrosion Inhibitor A153 Corrosion Inhibitor W54 Non-Emulsifier F103 Surfactant L58 Iron Control W60 Anti-sludge Note: Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on fhe WSR and have results available on location. Note: Please have Schlumberger send a digital copy of the post job report (including a digital, ASCII or EXCEL, copy of the pumping rates and pressures) to jose.soto@bp.com. TREE = 6" MCEV OY WELLHER.D = 13-5/8" FMC ACTUATOR = ~'~ KB. ELEV = 55.3' BF. ELEV = 16.12' KOP = 6020' Max Angle = 29° @ 8420' Datum MD = 10449' Datum TVD = 10000' SS ~ END2-12 u 13-3/8" CSG, 68#, NT-80, BTRS, ID = 12.415" 2777' 9-5/8" CSG, 47#, NT80S XO NT95HS I-{ 8395' 7" OTIS RPB SSSV NIP, ID = 5.962" 7" OTIS R NIP, ID = 5.962" Minimum ID = 5.82" @ 9670' 9-5/8" X 7" TIW wIT1EBACK SLEEVE 9606' 9-5/8" X 7" BKR S-3 PKR, ID = 6.00" 9668' I-17" OTIS R NIP, ID = 5.962" _ 9670' -19-5/8" X 7" TM! LTP w /TIEBACK SLV, ID = 5.82" TOP OF 7" LNR 9670' 7" TBG, 26#, NT-80S, .0383 bpf, ID = 6.276" 9674' 9674' -~7" MULESHOE, ID = 6.28" 9-5/8" CSG, 47#, NT95HS, ID = 8.691" 9940' 9996' 7" MARKER JOINT PERFORATION SUMMARY REF LOG: CNL-GR (06/16193) ANGLEATTOPPERF: 23° @ 10108 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4" 4 10108 - 10112 O 04/10/93 4" 4 10116 - 10120 O 04/10/93 4" 4 10142 - 10158 0 04/10/93 4" 4 10166 - 10170 O 04/10/93 4" 4 10211 - 10222 O 04/10/93 4" 4 10230 - 10236 O 04/12/93 4" 4 10250 - 10263 O 04/12/93 4" 4 10263 - 10283 O 04/12/93 4" 4 10290 - 10310 O 04/12/93 PBTD ~7" LNR, 29#,L-80, TKGBTC, .0371 bpf, ID = 6.184" DATE REV BY COMMENTS DATE REV BY COMMENTS 03/21/93 D15 INITIAL COMPLETION 01/12/07 DRF/PAG PULL PLUGS (3 EA) (01106/07) 08/27/94 JTP API#CORRECTION 03/01/07 WRR/PJC CONVERTTONEWFORMAT 11/19/06 ?! PAG CONVERSION EDITS 11/19/06 CJWPAG SSSV EDITS 11/23/06 TEL/PJC SET IBP @ 10080' 12/17106 TEUPAG SET BKR IBP @ 9647' / EDfT ENDICOTT UNIT WELL: 2-12 /0-16 PERMfT No: 1921170 API No: 50-029-22302-00 SEC 36, T12N, R16E, 1877' FNL & 2196' FEL BP Exploration {Alaska) RE: Well END 2-12/Q-16 (PTD #1921170) Slow IA Repressurizatio... ~ . Hi Jim, tI I have included an injection plot for END2-12 for your review. Much of the characterization on the TIO plot corresponds to the changes in injection rate. Of note on the injection plot, there was a large decrease in injection rate on 07/23/06 and the well was shut-in on 08/13/06. Annulus pressures also change due to thermal affects of injecting warmer or cooler fluids. The operator notes confirm there were no bleed events in July. The first bleed event was noted on 09/22/06. The repressurization was first suspected to be due to thermalization since the injector had been down most of August and September with the plant shut-down. The second bleed event was late on 09/26J06, the well integrity team was notified on 09/27/06, and the AOGCC was verbally notified on 09/28/06. The purpose of the MAASP lines for the IA and OA are for Well Integrity Engineers and others reviewing the TIO plot to quickly note the operational pressure limits. BP is operating under the operational practice of having the same pressure limits for producers and injectors. The exception is when pressure limits are changed due to being waivered for an integrity anomaly. Operators are required to notify the Well Integrity Engineer when they suspect possible annular communication. In addition, Well Integrity Engineers review TIO plots of injectors that have tubing and IA pressure limits within 250 psi of each other. This tool in addition to operator call-ins provide a means for BP Well Integrity Engineers to identify potential annular communication and subsequently notify the AOGCC. The MAASP are an operational limit, not a notification threshold. Please call me if you would like to discuss this further. Thank you, }lnna fDu6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 .".~t..íM~' :.",~; ¡,"!',-=:.- v~'J >/".'''..-' ? From: James Regg [mailto:jim_regg@admin.state.ak.us] Sent: Monday, October 02,20062:35 PM To: Hughes, Andrea Cc: winton_aubert@admin.state.ak.us; Engel, Harry R; NSU, ADW Well Operations Supervisor; McMullen, John C; END/BAD Area Manager; END, Board Operator; Neels, Andrew J (ASRC ENERGY SERVICES); Rockafellow, Joseph D Subject: Re: Well END 2-12/Q-16 (PTD #1921170) Slow IA Repressurization - MIT Form lof2 11/24/20063:55 PM RE: Well END 2-12/Q-16 (PTD #1921170) Slow IA Repressurizatio... . . Pressure data indicates there has been TxIA communication at least since July. There are also indications on the graph of pressure bleeds in response to possible repressurization in mid/late July. Why the delay in notifying the Commission? Rule 7 of Area Injection Order 1 requires BP to, among other things, notify the Commission the first working day after observation of pressure communication or leakage. - What is the purpose of MAASP lines for the IA and OA? [Pressures appear to match criteria in Conservation Order 501 - Sustained Casing Pressure Rules; Endicott]. - Is BP operating under the assumption that injectors have the same annulus pressure allowances that producing wells have? Jim Regg AOGCC Hughes, Andrea wrote: Hello Jim and Winton, Well END 2-12/Q-16 (PTD #1921170) has recently been exhibiting indications of pressure communication between the tubing and lA, as noted on the attached TIO plot. DHD obtained a bleed rate of approximately 180 psi per hour on 09/28/06. An MITIA on 9/29/06 passed to 4,000 psi (see the attached MIT form). Currently the well is shut-in. Our plan forward for this well is for slickline to troubleshoot the SSSV and then put the well back on injection to verify the problem has been corrected. If the SSSV work corrects the problem, we will redo the MITIA to 1.25 * Packer TVD for a witness. If the problem is not corrected by SSSV work, we will shut in the well and develop a diagnostic plan. «END2-12.BMP» «2-12.pdf» «MIT END 2-12 09-29-06.xls» Please call with any questions or concerns. Andrea Hughes (Filling in for Anna Dube) Well Integrity Engineer Office: (907) 659-5102 Pager: (907) 659-5100 x1154 Content-Description: END2-12 Inj Plot.pdf Inj Plot.pdf Content-Type: application/octet-stream Content-Encoding: base64 20f2 11/24/20063:55 PM 0~/2ö65 o o o ci N 12/4/2005 2/4/2006 4/4/2006 6/4/2006 8/4/2006 0/4/2006 C Q. ~ ŒI a u.. () ::::¡¡¡ ~ en - ~ C + ~ !!: (; ::::¡¡¡ ùi III C) o o o ci '<t o o o ci to o o o ci co » < IC :e :J: ~ 'g III cei' o o o o '<t ..- o o o ci N ..- o o o o o ..- 2-12 Daily Allocated Injection Plot . . \ Re: Well END 2-12/Q-16 (PTD #1921170). IA Repressurization... . Ké'qé¡ IOIz./o<p Pressure data indicates there has been TxIA communication at least since July. There are also indications on the graph of pressure bleeds in response to possible repressurization in mid/late July. Why the delay in notifying the Commission? Rule 7 of Area Injection Order 1 requires BP to, among other things, notify the Commission the first working day after observation of pressure communication or leakage. - What is the purpose of MAASP lines for the IA and OA? [Pressures appear to match criteria in Conservation Order 501 - Sustained Casing Pressure Rules; Endicott] - Is BP operating under the assumption that injectors have the same annulus pressure allowances that producing wells have? Jim Regg AOGCC ,cej" .,,~¡¡~\t;;~ . 0~h;:! ,~~~,""0 t- 2. r. \. r. ".r:. ..... n"1 \..' _'c Hughes, Andrea wrote: Hello Jim and Winton, Well END 2-12/Q-16 (PTD #19211?O) has recently been exhibiting indications of pressure communication between the tubing and IA, as noted on the attached TIO plot. DHD obtained a bleed rate of approximately 180 psi per hour on 09/28/06. An MITIA on 9/29/06 passed to 4,000 psi (see the attached MIT form). Currently the well is shut-in. Our plan forward for this well is for slickline to troubleshoot the SSSV and then put the well back on injection to verify the problem has been corrected. If the SSSV work corrects the problem, we will redo the MITIA to 1.25 * Packer TVD for a witness. If the problem is not corrected by SSSV work, we will shut in the well and develop a diagnostic plan. «END2-12.BMP» «2-12.pdf» «MIT END 2-12 09-29-06.xls» Please call with any questions or concerns. Andrea Hughes (Filling in for Anna Dube) Well Integrity Engineer Office: (907) 659-5102 Pager: (90?) 659-5100 x1154 1 of 1 10/2/2006 2:39 PM END2-12.BMP 830x283 . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION .. - 'lIQ& Mechanical Integrity Test :ß I Ù z,\ ø¿r1 Email to:Wintonßubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.uS;Jim_Regg@admin.stae.al.us;Tom_MaUnder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Endicott I END I Duck Island Unit 09/29/06 Andrea Hughes \o..~\\1 Packer Depth Pretest Initial 15Min. 30 Min. Well 12-12 I Type Inj. I N TVD I 9,286' Tubing 3,700 3,700 3,600 3,600 Interval I 0 p.T.D.11921170 I Type test I P Test psil 2321.5 Casing 1,900 4,000 3,880 3,860 P/FI P Notes: AOGCC MIT-IA for eval TxlA communication. OA 8 5 5 5 Weill I Type Inj. I I TVD I Tubing Interval I p.T.D.1 I Type test I I Test psi Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing Interval! P.T.D.' I Type test I I Test psi I Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing Interval! P.T.D.I I Type test I I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing Interval! P.T.D.I I Type test I I Test psi! Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 ~. TYPE TEST Codes M = Annulus Monitoring P = standard Pressure Test R = Internal Radioactive Tracer SUlvey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) 2006-0929_MIT _DIU_2-12.xls RT. ELEV = 55.3' B.F. ELEV = 16.12' MAX DEV = 28" 39' @ 8,420' M.D. . . TREE: 6" /10,000 psi / McEvoy WELLHEAD: 13-5/8" /10,000 psi / FMC . S OTI > ~ 7",26 NSC >- - 7"0 .141 ~5.96 X h ¿ 9-5/8' ~ r-- BAK 7"0 > \ 1,/ 5.96 7"W ::; lZ >- ~ ~ 93) RVAL 8' TO 10,112' 6' TO 10,120' 2' TO 10,158' , TO 10,170' l' TO 10,222' 0' TO 10,236' 0' TO 10,283' 0' TO 10326' 8' I > " " , X X X > 13-3/8", 68#1ft, L-80, Btrs Csg I 2,777' 9-5/8", 47#/ft NT80S XO to NT95HS I 8,395' TOP OF 7" LINER I 9,670' I 9-5/8", 47#/ft, NT95HS, NSCC I 9,940' I PERFORATING SUMMARY Ref. Log: CNL-GR (3/16/ CO SIZE SPF INTE ATLAS 4" 4 10,10 10,11 10,14 10,166 10,21 10,23 10,25 1029 PBTD: Driller 7", 29#/ft, NT-80 NSCC DATE 10,32 10,410 > BY COMMENTS SSV LANDING NIPPLEI 1 583' S (5.962"1.0.) , #/ft, NT-80S C Tubing TIS "R" NIPPLE Z'I.D. , X 7" PACKER ER "SABL-3" TIS "R" NIPPLE Z'I.O. LEG 9,596' 9,606' 9,668' 9,674' CB Completion & Perforations ENDICOTT WELL: 2-12/Q-16 API NO. 50-029-22302 COMPLETION DIAGRAM 3/21/93 8/27/94 JTP CHANGE API # B.P. EXPLORATION (ALASKA) INC. e e rJ . q\1lt< \ ~lf~ Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: FIELD ( UNIT ( PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / Endicott 09/05/05 Donald Reeves I ~.p- -At? Packer Depth Pretest Initial 15Min. 30 Min. WeIlIEND2-12 I Type Inj. I G TVD I 9,286' Tubing 3,940 3,940 3,940 3,940 Interval! 4 p.T.D.11921170 I Type test I P Test psi I 2500 Casing 520 2,500 2,500 2,500 P/FI P Notes: 4 Year Regulatory Compliance. OAO 0 0 0 AOGCC declined by Chuck Scheve WeIlIEND2-70 I Type Inj. I W I TVD I 9,196' Tubing 2,500 2,500 2,500 2,500 Interval! 4 P.T.D.11881530 I Type test I P I Test psil 2600 Casing 300 2,600 2,590 2,590 P/FI P Notes: 4 Year Regulatory Compliance. OA 0 0 0 0 AOGCC declined by Chuck Scheve WeIlIEND4-04 I Type Inj.1 G I TVD I 9,498' TUbingl 3,500 3,500 3,500 3,500 Interval! 4 P.T.D.11890860 I Type test I P I Test psil 2550 Casing 740 2,550 2,520 2,510 P/FI P Notes: 4 Year Regulatory Compliance. OA 170 170 170 170 AOGCC declined by Chuck Scheve Weill I Type Inj.1 \ TVD \ Tubing I I I I Interval I P.T.D.I I Type test \ Test psi I I Casing I I I I P/FI Notes: I OAI \ I I Weill I Type Inj.1 I TVD I Tubing Interval I P.T.D.I I Type test I I Test psil Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waist G = Gas I = Industrial Waistewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperatw'e'Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0,= Other (describe in notes) l....,\.O\.& (\"~ t'JûDr., 5CJ\NNEt I'~" p i Qji '- " .~ MIT END 2-12, 2-70, 4-04 09-05-05.xls ON OR BEFORE T STATE OF ALASKA ALAS':"~-OIL AND GAS CONSERVATION COMMiS.-~- 1,4 REPORT C,; SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate m Plugging__ Pull tubing__ Alter casing Repair well __ Perforate__ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.qe, Alaska 99519-6612 4. Location of well at surface 1877' SNL, 2196' WEL, SEC. 36, T12N, R16E At top of productive interval 1561' SNL, 3968' WEL, SEC. 36, T12N, R16E At effective depth 1577' SNL, 3904' WEL, SEC. 36, T12N, R16E At total depth 1544' SNL, 4046' WEL, SEC. 36, T12N, R16E 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service .. 6. Datum elevation (DF or KB) KBE=56' feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-12/Q- 16 9. Permit number/approval number 92-117 (not required) 10. APl number 50- 029-22302 11. Field/Pool Endicott Field/Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10410' feet 10008' feet 10327' feet 9933' feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 131' 30" Drive 131' 131' 2733' 15.3/$" 11996 cuft PF 'E'/464' 'C" 2777' 2777' 9896' 9-5/8" 2093 CUft Class 'G' 9940' 9487" 740' 7" 168 cuft Class 'G' 9670'-10410' 9244'-9920' measured 10108'-10112', 10116'-10120', 10142;10158', 10166'-10170', 10211'-10222', 10230'-10236', 10250; 10283', 10290; 10326' (open) true vertical 9736';9740', 9743;9747', 9767'-9781', 9788'-9792', 9829'-9839', 9846'-9851', 9864;9894', 9900'-9932' (open) Tubing (size, grade, and measured depth) 7'26#/ft NT-80S NSCC tubing to 9671' Packers and SSSV (type and measured depth)7'PackerBaker'$ABl.-~~!V~'~ 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 1997 RIGINAL 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 35981 37087 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X _- _ 16. Status of well classification as: Oil__ Gas X Suspended Service 17. I ~he'reby certify ~hat the'J:Qregomgls trueand correct to the best of my knowledge. ,, :';: :. ,,-/ j.;, . /: ', !-;-~i':'C..'t.-¥".'_'-.-f' . ( .-.-'L-'- ,' /~ 'f /' Signed- :: / '-' ..... '---"-L:- -':-:-~- ..... ? Title 5~ni~r T~chnic~1,4.e.ci.et~nt IV i-Form 10-~p~ Rev 06/15/88 " Date 4/30/97 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department OPERATIONS REPORT DATE: ~ WELL N°: 2-12/Q-16 TYPE OF OPERATION: MIT BP EXPLORATION REP: VARBLE SERVICE COMPANY: HB&R DATE/TIME OPERATIONS SUMMARY 1002 MIRU HB&R. P/T TO 3000 PSI 1008 PUMP 3 BBLS DIESEL DOWN IA & PRESSURE UP TO 2500 PSI. MONITOR FOR 30 MIN. 1038 PASSED MIT. BLEED BACK TO 500 PSI. RDMO SUMMARY: PASSED MIT. WITNESSED BY AOGCC REP. DOUG AMOS LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 17 May 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 PLS FINAL BL+RF 1 PLS/STP FINAL BL+RF 1 PLS FINAL BL+RF ECC No. Run # 1 5912.05 Run # 1 6175.02 Run # 1 6397.10 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services ' 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please sign and ~,e~urn ~! Petrotechnieal Data Center BP Exploration (Alaska) InS 900.~ast Benson Boulevard ;n~e r e, Al~ka MAY 2 q 1995 Da'8~ ......... Alaska. ~.G.~s Cons~Commissi.o.n " A~horage PERMIT 92-117 92-117 92-117 92-117 92-117 92-117 92-117 92-117 92-117 92-117 92-117 92-117 92-147. i ~.~OGCC Individual Well Geo±ogical Materials Inventory DATA DWOP ~ SURVE Y~ SURVEY CNA / LDT T DATA_PLUS -- R COMP DATE:03/16/93 R 02/27-03/21/93 R 100-9867 MWD ANADRILL R 120-10320 GYRODATA L 9940-10409 DLL/MSFL/' PDLS/GAS INJ P FC/C.,.~L~ PROD~/ PROD J L 9940-10409 L 10000-10290 L 10000-10301 L 10000-10300 L 9950-10318 RFTJ L 10116-10321 SBT/GR/CCL j L 9000-10321 SSTVD/DLL-MDFL~ L 9940-10409 Page' 1 Date: 01/10/95 RUN DATE_RECVD 05/03/93 05/03/93 05/03/93 04/23/93 1 03/25/93 1 03/25/93 1 09/08/94 1 04/30/93 1 06/11/93 1 06/11/93 1 03/25/93 1 04/30/93 1 03/25/93 Are dry ditch samples required? yes ~ And received? y~~ Was the well cored? yes ~ Analysis & description received? ye~ Are well tests required? yes no Received? Well is in compliance ~. Initial yes no COMMENTS ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 29 August 1994 RE: Transmittal of Data ECC #: 5912.04 Sent by: ANCHORAGE EXPRS Data: PL Dear Sir/Madam, Reference: BP 2-12/Q-16 MPI ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 PL/PROFILE FINAL BL Run # 1 1 PL/PROFILE RF SEPIA Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 AK 99518 Anchorage, D. Paulson ~ Receive~ / // ¢ Date~..~ ~ w~ - ~ %~ ~, d.-x~ "~ Please sign and return to: Petroteahnical Data Center BP Exploration (Alaska) Inc 900 East Benson Boulevard Anchorage, Alaska 99508 Received by BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box'196612 Anchorage, Alaska 99519-6612 (90'7) 561-5111 June 10, 1993 Alaska Oil and Gas Conservation Commission 3001 Porcupine Ddve Anchorage, Alaska 99501 Dear AOGCC Representative, Attached in duplicate is detailed information regarding the enclosed well logs for the Endicott Field. Please contact me at 564-5225 if you have any questions. Sincerely, en?ne L. Haas or Technical Assistant !1 JLH Enclosures xc: File 06.10 VED ,~l~k~ Dil & Gas Cons. Co~joti WELL NAME 3-03/J-33 DATE INTERVALS LOG NAME 5~23~93 13400'- 13670' PFC/CCL RUN NO COMPANY NAME I ATLAS I- 13-1~- 3-41/K-39 7-.30-- 3-35/L-36 0' I~,t '- 1-29/M-25 ~-, 5[ 3-45/M-39 ~- I~Oi. 2-14/O-16 5---5~, 1-15/P-25 '~'" '~ 4-08/P-27 ;L-I t'l?~ 2-12/Q-16 Cl - 0L. 1-63fr-22 ~'"1 ), q 1-51N-20 5115/93 13200'-13655' P~CTION LOC.-.-.-.-.-.~31NG 5/2 2193 11900'-12264' PRCOUCTE~ LOGGING 5/24193 13100'-14071' PDK- 100 5120193 29'-11848' PFIODUC~ LOGGING 6/1193 10350'-10578' PRODUCTE~ I..C)C_.-~ING 6~4~93 10350'- 1 oeoo' P~TION ~ING 5/14/93 11950'-12960° DUAL LATEROLOG - MSFL 5114~93 11950'-12960' . DLL-MSFL-GR SSTVD LOG 5/17/93 11700'-12897' CNL/GR 5/17/93 11700'-12897' ~I~I~G R/CCL 5/19/93 13000'- 13676' ' PI:IODUCTION I_C)C_~ING 5/27/93 10000'-10300' PRODUCTION ~ING 5127193 9950'- 10318' PFIODUCTE~ ~ING 5~26~93 12100'-12700' P~TION LOC.-.-.-.-.-.-.~IING 5/26193 11400'-12200' GR/CCL 5/1 5193 11300'-12500' PFC/CCL. 5/16~93 12350'-12600' PFC/CCL 5/18~93 12350'-12600' PFC/CCL ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS SCHLUM~ SCHUJM~ ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS STATE OF ALASKA -'~ ALASKA OIL AND GAS CONSERVATION WELL COMPLETION OR REOOMP LETION REPORT Classilicalion of Service We~l ¢' 1. Status of Well OIL [] GAS I-I ~ED [] ABANDONED Itl SERVICE [[] 2. Name of Operator BP Exploration 3. Address P. 0. Box 196612, Anchoraqe, A/aska 99519-6612 Gas Injector 7. Permit Number 92-117 8. APl Number 50- 029-22302 9. Unit or Lease Name Duck Island Unit/Endicott 10. Well Number 2-12/Q-16 1. Field and Pool 4. Location of well at surface 1877'SNL, 2196' WEL, SEC. 36, T12N, R16E At Top Produ~ng ,nte,~ N/A At mot~ D~th 1~' SN~ 40~' WEL, SEC. 36, T12N, R16E iL'CK~ATIC~ w~¢~ i 5. Elevation in feet (indicate KB, DF, etc.) 16 Lease Designation and Serial No. KBE = 56' IADL 34633 12. Date Spudded 113. Date T.D. Reached 114. Date Comp., Susp. or Aband. 2/28/93 J 3/15/93 ~ 3/16/93 118. Plug Back Depth (MD+TVD)~19. Directional Survey 120. ] 10327' MD/9933' TVD ! YES [] N3 [] I Endicott Field/Endicott Pool I 15. Water Depth. if offshore 116. No. of Completions 6'-12'MSLfeet MSL JOne I1. Thickness of Permafrost 1465' (Approx.) 17. Total Depth (MD+TVD) 10410' MD/10008' TVD 22. Type Electric or Other Logs Run Run #1 DLL/MSFL/GR Run #2 LDT/CL Run #3 RFT/GR/ANIS Depth where SSSV set 1500'feet MD 23. -- CASING, LINER AND CEMENTING R_F-CORD CASING SIZE WT. PER FT. GRADE 30" Struct. Drive 13-3/8" 68# NT-80 9-5/8" 47# NTSO/NT95 7" 29# NT-80 SETtiNG DEPTH MD TOP BOTTOM Surface 131' 44' 2777' 31' 994O' 967O' 1041 O' 24. Pedorations open to Production (MD+TVD of Top and Bottom and interval, size and number) Gun Diameter 4" 4 spf MD TVD 10108'-10112' 9736'-9740' 10116'-10120' 9743'-9747' 10142'-10158' 9767-9781' 10166'- 10170' 9788'-9792' 10211'- 10222' 9829'-9839' 10230'- 10236' 9846'-9851' 10250'- 10283' 9864'-9894' 10290'- 10326' 9900'-9932' HOLE SIZE CEMENTING RECORD AMOUNT PULLED Drive 16" 1196 cuft PF "E"/464 cuft PF: "C" 12-1/4" 2093 cuft Class "G" 8-1/2" 168 cuft Class "G" 25. TUBING RECORD SIZE 7", 26# DEPTH SET (MD) 9671' PACKER SET (MD) 9603' 26. ACID, FRACTURE, CEMENT SQUEF71=, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODt. K~TE)N TEST Date First Production Injectin9 - 4/13/93 Date o! Test Hours Tested Flow Tubing Casing Pressure Press. IMethod of Operation (Flowing, gas lift, etc.) Injector PRODUCTION FOR TEsT PER~D ~ CALCULATED 24-HOUR RATE OIL-BBL OIL-BBL GAS-MCF GAS-MCF WATER-BBL ICHOKE SIZE IGAS-OIL RATIO WATER-BBL ~DIL GRAVITY-APl (corr) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RErdE V, D MAY - ~ 199~ Aiask¢o 0il & 6as Cons. Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS I-~.'RMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. i Top HRZ 9910' 9558' Itkilyariak 9910' 9558' Top Kekiktuk 10083' 9714' ,, 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If-this well is completed-for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such intervaE Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: MPI 2-12/Q-16 BOROUGH: NORTH SLOPE UNIT: ENDICOTT FIELD: ENDICOTT LEASE: API: 50-029-22302 PERMIT: APPROVAL: ACCEPT: 02/27/93 12:00 SPUD: 02/28/93 09:30 RELEASE: OPERATION: DRLG RIG: DOYON 15 WO/C RIG: DOYON 15 02/27/93 (1) TD: 80' ( 80) R/U. MOVE RIG. MW: 8.5 VIS: 0 02/28/93 (2) TD: 80' ( 0) 03/01/93 (3) TD: 1700' (1620) 03/02/93 ( 4) TD: 2795' (1095) 03/03/93 (5) TD: 2795'( 0) 03/04/93 (6) TD: 3650' ( 855) 03/05/93 ( 7) TD: 5676' (2026) 03/06/93 (8) TD: 6580' ( 904) P/U BHA. MW: 8.5 VIS:300 MOVE RIG. RIG ACCEPTED @ 12:00 HRS, 2/27/93. N/U DIVERTER. TEST SAME. P/U BHA. DRLG. MW: 9.3 VIS:165 PREP TO DRILL. R/U ATLAS. SPUDDED WELL @ 09:30 HRS, 2/28/93. DRLG F/ 80'-1230' CIRC. SHORT TRIP TO 566'. DRLG F/ 1230'-1700' RUN 13-3/8" CSG. MW: 9.5 VIS: 85 DRLG F/ 1700'-2795' CIRC. SHORT TRIP TO BHA. CIRC. POOH. L/D BHA. RIH W/ 13-3/8" CSG. TEST BOPE. MW: 9.4 VIS: 64 RIH W/ 13-3/8" CSG. CIRC. CMT CSG. BUMP PLUG W/ 2000 PSI. L/D LAND JT. N/D DIVERTER. N/U BOPE. TOP JOB W/ 12 BBLS (80 SX) 'C' PERM CMT. N/U BOPE. TEST BOPE. DRLG. MW: 9.3 VIS: 61 TEST BOPE. REPAIR DRAWWORKS. RIH. TEST CSG. DRLG FC, CMT, FS, 10' NEW HOLE. CIRC. LOT (14.1 PPG EMW) . DRLG F/ 2905'-3500' SHORT TRIP TO SHOE. DRLG F/ 3500'-3650' POOH. MW: 9.5 VIS' 55 DRLG F/ 3650'-4519' SHORT TRIP TO 3650' DRLG F/ 4519'-5676' CIRC. POOH. DRLG. MW: 9.5 VIS: 51 POOH. CHANGE BHA. RIH. DRLG F/ 5676'-6580' 03/07/93 (9) TD: 7191' ( 611) 03/08/93 (10) TD: 7910' ( 719) RIH. SHORT TRIP TO 5880' BIT. RIH. MW: 9.5 VIS: 45 DRLG F/ 6580'-7191' POOH. CHANGE POOH. MW: 9.7 VIS: 49 DRLG F/ 7191'-7643' SHORT TRIP. DRLG F/ 7643'-7740' CIRC. DRLG F/ 7740'-7910' POOH. Aiaska 0il & Gas Cons. Anchorage WELL : MPI 2-12 OPERATION: RIG : DOYON 15 PAGE: 2 03/09/93 (11) TD: 8635' ( 725) 03/10/93 (12) TD: 9200' ( 565) 03/11/93 (13) TD: 9610' ( 410) 03/12/93 (14) TD: 9940' ( 330) 03/13/93 (15) TD: 9940' ( 0) 03/14/93 (16) TD: 9970' ( 30) 03/15/93 (17) TD:10250' ( 280) DRLG. MW: 9.8 VIS: 43 POOH. CHANGE BHA, BIT. RIH. DRLG F/ 7910'-8460' SHORT TRIP TO 7910'. DRLG F/ 8460'-8535' DRLG. DRLG TO 9077' 9200' MW:10.0 VIS: 47 CIRC. POOH. CHANGE BHA. RIH. DRLG TO SHORT TRIP. MW:10.3 VIS: 43 DRILLED TO 9384'. TRIP FOR BHA. DROPPING ANGLE TOO FAST. HOLE TIGHT 9384-8719'. WASH F/ 8684-9384'. DRLD TO 9610' SHORT TRIP. HOLE TIGHT. RAISED MW F/ 10.0 PPG TO 10.3 PPG. POOH. MW:10.5 VIS: 44 RIH. DRLG TO 9940' CBU. SHORT TRIP. REAM F/ 8788'-9940' CIRC. POOH. LAND CSG. MW:10.5 VIS: 52 POOH. L/D BHA. TEST BOPE. RIH W/ 9-5/8" CSG. R/U HOWCO. PUMP 10 BBLS PREFLUSH, 332 BBLS 11 PPG LEAD CMT, 41 BBLS 15.8 PPG TAIL CMT. DISP W/ MUD. BUMP PLUG W/ 3000 PSI. N/D BOPE. INSTALL EMERGENCY SLIPS. CUT CSG. L/D LAND JT. CUT CSG FLUSH. DRLG. MW: 9.4 VIS: 38 INSTALL PACKOFF. TEST SAME. N/U BOPE. TEST BOPE. RIH TO 9854' .TEST CSG. DRLG FC, CMT TO 9936'. CIRC. DRLG FS, 10' NEW HOLE. FIT (10 PPG EMW). DRLG TO 9970' DRLG. DRLG TO 10250' MW: 9.4 VIS: 45 03/16/93 (18) TD:10410' ( 160) 03/17/93 (19) TD:10410' ( 0) 03/18/93 (20) TD:10410 PB: 0 R/U SWS. MW: 9.4 VIS: 43 CIRC. POOH. CHANGE BIT. RIH. DRLG TO 10410' TD WELL @ 22:00 HRS, 3/15/93. CBU. SHORT TRIP TO 9900'. CIRC. POOH. R/U SWS. RIH. MW: 9.5 VIS: 41 LOG RUN %1' DILL/MSFL/GR. RIH. CIRC. POOH. LOG RUN #2: LDT/CL. LOG RUN %3: RFT/GR/ANIS. R/D SWS. RIH. POOH. MW: 9.5 WBM RIH. CIRC. POOH. L/D DP. RIH W/ 7" LNR ON DP. CIRC. R/U HOWCO. PUMP 70 BBLS PREFLUSH, 50 BBLS SPACER, 30 BBLS 'G' CMT. DISP W/ MUD. BUMP PLUG. SET PKR W/ 4000 PSI. RELEASE F/ LNR. REV CIRC. POOH. WELL · MPI 2-12 OPERATION: RIG : DOYON 15 PAGE: 3 03/19/93 (21) TD:10410 ?B:10327 03/20/93 (22) TD:10410' ( 03/21/93 (23) TD:10410 PB: 0 o) DISP WELL TO SEAWATER. MW: 8.6 Seawater POOH. L/D LNR RUNNING TOOLS. RIH W/ SCRAPERS. CBU. POOH. RIH W/ BIT. CLEAN OUT F/ 10312'-10327' CIRC. TEST CSG. CIRC. DISP WELL TO SEAWATER. RIH W/7"TBG MW: 9.8 VIS: 0 DIPLACE WELL TO SEAWATER, MONITOR WELL FOR FLOW-WELL STABLE, TRIP OUT L/D EXCESS DP, R/U ATLAS, ~UN JB/GR TO 9672', RUN SBT, GR, CL, PULL WEAR RING RIH W/7 BAKER SABL-3 PKR ON 204 JTS 7"26~ L-80 TBG, INSTALL & TEST BALL VALVE & CONTROL LINES TO 5000 PSI @ 0530 HRS RIG MOVING TO 1-51/V-20 MW: 8.6 Seawater RIH W/ SAB-3 PKR ON TBG, TESTED SSSV LINES, INSTALLED 2 WAY CK IN HGR, LND HGR IN TBG SPOOL, N/D BOPE, N/U TREE, PUMP 100 BBLS DIESEL DOWN TBG, U-TUBE TO CSG ANNULUS, PRESSURE TBG TO 4000 PSI SET PKR, PUMP 5 BBL DIESEL DOWN ANNULUS, RELEASE RIG @ 24:00 HRS .__ S I GNATURE: (drilling superintendent) DATE: MAY Oil & Gas Oons. AnChorage ~MP~%~' PBDG W~L NAME 2-12/~-16 LY]CAT!ON 1 HPi ,~NDICOTT LOCATI~ ~ ~¢SB :Al~ASKA DAII~: P_7-F~:-~ WELL NU ,~..~ 0 T "/' fi WELl, HEAI~ ,.OCA:IuN. LAT(N/-S:.'- 0,00 ~IML~H ~, ~T~Y TABLE TO TAR:ET IS TIE IN F~INT(?IP) : ~7~S[~-,'ED DFJ:'TH 1®,00 TRUE V~,'T Db-T-'?H 100,00 INCLINATI[~ 0,00 AZI~J~H 0~00 LATITL~E(~/-S) · O,(K~ D~F'ARTt~(E/-W) 0,00 D~'(E/-W) 281,51 0,00 - 199,3 0il & Gas Cons. Comrnissio~ Anchorage ~S~.::D INT~VAL t.~TI~L ft 100,00 0,0 J. O0~O0 697,00 311,0 7~,14 26.1 7~.13 81:,7~ ~2.6 81:,73 TAF~T ~ATION AZiMLFFH LATITUDE SECTiF~ IW_:LN ~ ~ ;-~ ft de9 ds: ft 0,~) 0,00 0.(>:~ 0,00 -0,73 0,[¢0 112,90 -0,29 -2,8~ 0,50 34.50 -0,71 -3,03 0,42 103,65 -0,75 -2.~5 1.30 $o3;~_:. -0,58 D~'ARTdRC DISF'LACB~NT at ~I~H E/-W ft ft deg 0,~) 0,00 0,69 0,75 i12,?0 2,79 2,86 1(~.35 3,~) 3,~ !03,97 2,31 2,36 I{~,20 DLS deg/ lt¥~ft 0,10 0~ 0,~' 856,00 978 IQ, Z,8, 1169.!0 40~3 8~,97 29,6 8B5,75 ~,6 978,21 94,5 1072,41 -1,~ 1,70 236,90 -0,21 1,33 1,~ 98.91 -0,~ 2,36 2%.~5 0,27 0.~ O,4& ~.45 4,55 ~ ~ ~" ~ _ ~,8~ ~,~ 2.3~' -4,1~ 4,79 299,92 11,8~ 5,24 2?2.23 5.~ -I1,05 12.~ ~5,64 21,50 6,49 Z~'4,77 %25 -20,N 22,(~ 2~4,75, !,32 1,61 1,46 1,33 1263,49 1~9,79 1454,81 1550,34 1644,57 94,4 126! ~ .q 1~7,~.8 95,0 !452,10 ~,5 1547,C)2 94,Z 1640,73 31,49 5,96 293,55 t3,44 -2~',40 32,33 ~4,37 41.74 6,44 235,05 17,11 -39,12 42,70 2~3,E~ 52,~ 6.45 269.41 20.54 -49,22 53.33 ~',65 &3,05 6,51 251,01 ~,35 -5~,59 64,01 291,40 72,~ 5.53 279.97 25.16 -63,30 73,73 289.95 0,58 0,79 0,16 0,99 179~,03 1837,40 2028,45 ?4.5 1734,44 98,4 1832,41 ~,8 1927,67 95,2 2022,43 96,0 2118,f~, 82,83 6,~ 276,02 26,51 93,73 6,37 26~.24 27,03 104,00 6,16 272,20 27,15 112,8~ 5,24 253~87 26,14 120,41 5,~5 2:-~,05 ~.47 -79,13 83,45 286,52 1,16 -~D,15 94,tl 2~.,69 0,79 -100,60 !04,20 285,I0 0,40 -i~',89. 1i2.~ ~.~"~. ~ ~ 2,t3 -118,10 1~.41 28i,24 0,40 2316,$5 2410,68 25C9,30 2601,56 96,1 ~13,88 96,4 ~!0,18 93,7 2403,87 98,6 2~2.¢~. 92,3 2594,69 126,~o ~ ~ .~ ,. ~.~ 25~,m'~ 20,61 123,58 1,65 255.53 18,86 131,83 1,54 24~.09 18,01 133,91 1,37 249,54 17,06 ~.~= 1.45 25()+02 16,27 -124,58 'oz ~v .~,.,,., .,~,40 1,91 '128,40 129,78 ~78,35 1,91 -133,18 134,27 277,~ 0,19 -1~:,31 1$6,29 Z76,86 0,08 2696,~ 2734.7~ 2N.7,58 2976,32 3031,16 38,2 ~?~ "~ 132,8 2860,65 106,7 2969.37 S4,8 3024,21 137,76 1,32 2¢5,6? 15,43 138,50 1,31 ~!,82 15.12 140,60 0,94 237,81 14,07 141,68 0.80 24B.67 13,32 142,52 0,91 22832 -137,44 138,~) 276,41 0,16 -1~,26 l[~',O& $=&,24 -140,62 141,~ 235,71 0,34 -142,08 142,71 L"'~,36 0.20 -142,81 143,40 275,18 0,~ 3t26,07 37-~1,14 ~16,45 3413.M 2516.01 94,9 3119.11 ~.1 3214.18 ¥~,..-, ~0.-,,48 97,2 3406.66 102,4 35~',03 143,45 0.6J 233.90 12,22 143,78 0,46 183,45 11.50 144,02 0.76 216.07 I0,61 144,58 0,76 2!5,5~ %56 144,84 0,4~ 18%46 8,59 -143,91 1'44.43 2..74,~5 0,25 -144,37 144,~°~ ~v4,56 0,55 -1~.81 145,20 ~74,19 -145,60 145,91 ~3,76 0,02 -1¢f.,06 _146,32 ~-~,~ 36 0,36 3~4~',37 3703,~ 38.X),60 38?6,33 ~,4 3602,40 93,9 2~96,34 97,3 37%:,61 95,7 38~9,33 94,2 3983.~ 144,82 0,S4 I3!,31 7,76 144,80 0.55 128.79 6,~) 144,6! 0,.~) 1~5.02 6,02 144,08 0,66 149.87 5,13 143,24 0.89 151,19 4,02 -146,21 !46,42 ~3,04 0,07 -1¢5,37 146,53 272,70 0.04 -146,~ 146,48 272,35 0,20 -145,%' 145,08 272,01 0,~- -145,36 I45,42 Z~1,58 0,24 PAG~ ~, 3 F~ MEASURe: ZN~E~,~AL 6~ICAL DEPTH D~F'TH ft ft ft 4084,44 55,? 4079,42 4~ ~ 96,0 4175,40 4278,~O ~5,9 4373.79 9~.5 4366.75 4457,~4 9~,9 44.~,62 ~. 2-12/0-16 S~Y CALr_~:A7IO~ ,~.',~X..~ ~'tC, F~n Ac. AFl[: ?AF:G~T S~ATI[~-~ AZIML!?H LATi?UbE SECTION !)tC~q, N/-S ft deg deg ft 142,69 0,77 le.5.1e. 2,73 142.52 0,69 181.72 1,51 142,25 0,~.~, 167,$0 0,47 141,74 0,73 157.% -0,_,=5 140.94 0,76 142.0t -1,5'.-? D~ARTUPJ~ PlSPL~CEHE~!T at ft ft -145,~ 145,05' -145,14 145,15 -145,07 145,(~ -144,76 144,77 -!44,16 144,17 AZIMUTH ~e~ 271,08 270,60 270,19 DES deg/ lO£fft 0,52 0,19 0.~ 0,~ 4659,63 4755,00 4944,00 5044,97 5.2,30,67 5426,~) 96,7 4557,~ 95,4 4747,95 94,0 4M!,98 95,0 49~,93 101,0 5037,8? 95,0 5132,86 95.0 5227,~ 5419~11 140,?~ 0,52 16%24 -2,53 140,02 0,51 t76.12 -3,37 139,74 0,50 165.(~ -4,20 139,15 0,78 151,71 -5,16 138,55 0,59 167.62 -6,21 1~.,09 0,4~ 1..~,57 -7,26 137,64 0,46 157.96 -8,12 137.35 0,42 179,06 -8,82 137,2~ 0,17 173.46 -9,31 137,10 0,15 141,90 -9,~ -143,68 143,70 268,~ 0,39 -143,59 143,,-~g 2,.,6~6-, 0,0~, -143,¢z.. 143,53 268,32 0,12 -143.06 143,15 267,93 0,34 -142,66 142,80 267,5i 0.~ 14~,_9 267,08 0,~ -142,41 ~ 5' -142.12 142.~ "'~ ''''~ _ ~. L.~.../,., 0.20 -141,97 142,24 266,44 0,17 -141,95 142.25 ,.--..~':', 25 ~n,v.~.. -141,&6 142,18 266,15 0.05' ~21,32 55?8,64 56?5,65 5790,20 95,1 5514,23 77,3 72,7 94,5 _.t-'/~,lI 136,8~ 0,23 126.57 -9,76 136.61 0,19 15W.19 -9,97 136,JW 0,07 47.56 -10,00 1~.,37 0,30. 126,35 -i0,~ 136,!3 0,22 I84.32 -10,41 -141,62 141,96 2~,06 0,10 -141,44 141.79 265,97 0,14 -141,41 141,77 265,96 -141,23 141,58 265,92 0,40 -141,04 141,42 265,78 O,Z7 5887,23 5967,76 5982,28 6077,43 6172,71 5'7,0 80 ~ .~ 5960.~ 14,5 5975,18 95,1 6070,24 ~.3 6165,26 135,71 0,49 12~.02 -10,8i 1~,31 1,34 266.44 -11,01 I~.,64 1,3~ 259,06 -11,02 140,44 3.33 26B.~7 -1!,10 147,45 5.24 273.49 -t0,90 -140,70 141,11 265,61 0,45 -141,~ 141,78 265,55 2,2i -141,69 t42,12 265,55 0,00 -!45,58. 1¢5,~ 265,...44 2,07 -152,69 153,08 265,92 2,04 6267,00 6961 655,3,11 6741,(~ 6837,49 6~31.79 7026,36 7121,~ 94,3 62~.,99 ?4.9 6~2,94 96,7 6448,15 9'4,6 6540,68 94,0 6~1,92 96,4 4o~ ~o ?4,3 6~)3,44 ~4,6 67~1,66 ~,2 157,55 7,14 276.75 -9,95 170,63 8,73 279,32 -8,09 187,20. 1t,07 276.28 -5,88 206,67 12,~ 27!,13 ~.03 14,86 276,03 -3,21 254,33 16,~. 2.~k6,77. 0,55. 2~3,19 16,37 280.19 5.79 314,17 20,0i 277,16 10.95' 348,~ 22,23 ~1.29 17,06 385,37 23,72 283,96 25,21 -162,81 1E.:3,12 2~-d-..,50 -175,78 175,96 267,37 1,71 -192,24 192,33 268,25 2,46 -211,87 211,'}~ 268,73 2,28 -2~.38 234,4t' 269,22 2,39 -259,44 259,44 270,12 2,18 -267,83 267,89 271,15 -318,38 318,57 271,98 1,78 -35!,?0 352,31 272,76 2,~. -[-88,14 388,96 273,72 1,91 7217,79 7313,75 7406,38 7503,17 7595.29 96,2 7!66.79 96.0 7252.76 94,6 7336,42 ?4,8 7419,~ 9.., 7501,19 425.41 25,50 283,~7 34.,% 466,03 27.25 263,55 44.59 512.17 28.45 234,44 55.28 557,02 28,05_. 2B2,61 65,78 6'00,~ 28.13 ~,..,-~ ~o 75,25 -427,09 428.4? 274,64 1,~.7 -4.~,55 470.67 275.44 1.83 -511,45 514,43 ~,~.., ,, ~' 1,3~ -555,~5 558,94 Z76,76 1,00 -597,39 602,11 2~,16 0,10 MEASL.RIiD IHT-~RVAL ~,TJ:fflCAL ft ft ~t 7787~47 ~.6 7670.% 7843,40 ~. ~, " 7~,85 ~2,4 7801.21 8n~ ~ ~ 96,3 7885, 81Z7,:., 9 827.1,82 94,8 8'""~ ~' '~':" 94,6 8411.77 95.3 8_%8.~? 96,5 8604,53 96,2 86"79,0.5 94,5 8..o,93 94,9 8~%.28 96,4 8985.72 95,4 90~,61 35.,9 9121,93 99,3 9219,47 97,5 9313,94 94,5 940.8,~ 95,0 7969,69 8053,33 8..~5,53 ~Y.:~qS~'~ CALCULATI~4S **~**~,~.***~., CI.~LA~: AF~-~0['~*~.* TAF~ET. STATION .-....&YT"!J?J4,,: LATITUDE DE~'AFPJRE DISPLAC~E~E at AZIMUTH SB3Ti~J I~LN. N/-S ~/-W ~t deg d_~ ft ft ft deg M6.02 26,29 2~3~67 85,.~ -641,84 647,53 277,60 A9t,20. 28.13 -=~,P~, ~, 96.10 717.61 28,26 282.2~ 101,89 -711.59 718,85 ~8,15 76i,47 28,41 283,87 111,79 -7M,34 762,57 278,43 807,12 ~8,~1 282.D3 122,21 -7~8,80 8C~,09 278,70 851.89 28.,~ 2~.37 13~.24 -842.44 852.76 27~,.92 8'¢6, :--:..~J.95 284,.,I 142.96 -885,64 897,11 279,17 940,80 Za,13 282,35 153,29 -928,87 941,~. 279,37 9~,19 28,73 282,79 163,18 -973,20 98.5,76 279,52 1032,18 28,D 280,49 172,47 -1018,24 1032.~ 279.61 DLS deg/ iCOft 0,32 0,79 0,86 0,70 0,45 } 1,09 0,./-4. 1,26 8390,38 1077,60 28,14 283.77. t82,01 -1062,65 1078,12 279,72 1,61 847~.~3 1121,72 27.52 2~.22 191,20 -1105,81 1122.21 279,81 1,87 85~.,14 1165,40 27,46 275,78 197,29 -1149.14 1165,95 ?.79,74 2,16 ~3.~ 1D9,89 2.7.6? 279,6~ 203.29 -1193,~2 1210,51 279,&7 1,89 8728,18 1253,98 27,39 278.56 210,28 -1~.,89 1254,M 279,65 0.63 87.~),94 1270,91 27,~ 278,47 212,79 -1253,a6 1271,59 279,63 8849,32 1316,17 26,96 278.74 219,57 -12~'8,47 1316,9i 279,60 B'.~e&.4,36 13~,!5 26,~ 279,85 226,68 -1341,90 1~),91 279.59 9021.04 1402,01 25,95 280.70 ~M,14 -13L~3.!1 1402,76 279,6! 9i(.~..64 1443,24 25,49 281,57 242,10 -1423,56 1444,(~ 279,65 9504,12 95,2 9192,42 9599:74 95.6 9278,53 9695,60 95,9 5~.4,93 9793,37 5 7 Y 94,8 94~,~ 7867,2~ 76,9 9519,55 O ro I4M,46 25,85 ....~ ~O,M -1463.87 1485,19 ~9,72 1526,04 25,6? ~,35 259,18 1526,74 ,77 1567.56 ~,65 281.86 267,53 -1545,25 1568,24 279.82 -1618,19 '~' 1~<)9,2~ 279,&5 1642,14 26.01 282,36 7~83.11 1642,77 279,92 0,17 0,59 0.67 0.62 0.52 0,4~.. 0,09 0.47 SURVEY REPORT B. P. EXPLORATION ENDICOTT WELL NO. 2-12/Q-16 MDI UNIT, ALASKA APRIL 15, 1993 Oil & {~as !;oas. Anchorage Gyrodata Incorporated P.O. Box 79389 Houston. Texas 77279 713/461-3146 Fax: 713/461-0920 April 15, 1993 Mr. Bryce Cunningham B. P. Exploration P. O. Box 196611 Anchorage, AK 99519-6611 Re: Endicott Well No. 2-12/Q-16 MDI Unit, Alaska Dear Mr. Cunningham: Enclosed please find one (1) original and six (6) copies of the completed survey of Well Number 2-12/Q-16. We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future. Sincerely, Ernest E. Surman, Jr. Operations Manager EES/cv Enclosure Gyrodata Services, Inc. Houston, TX / Lafayette, LA / New Orleans, LA / Ventura, CA / Aberdeen, U.K. / Calgary, Alberta Anchorage, AK / Kuantan, Malaysia / Buenos Aires, Argentina / Bergen, Norway / Alkmaar, The Netherlands Date Run: 05-AP[.4-93 07:30:00 Job Nur~'be. r: AKO493G348 Su~'veyo]?: TOH STODDAR[) Ca].cula. t~.on ~Iethod: H]iNi[~Ui~( CURVATURE Su~:vey Lat.:i. tude: 70deg 2'lm~.'~ 'II. see N Bea~'?J.'~,$ (;orree'ted ldeg 30m;i.n 13sec WEST to Ve~'t~_caJl. Sect.:ion C;a].cuit_,?,t. ed. :t'~"o!'a We.tlt Head Loc;a't..'.i_c.~'~"~ Closu~?e C',,'.~..l. cul,..'!.l, ted f~.-o~,:'~ 14eli. Head. l'.,ocatJ, on Y~. t:". r;' -, ("),' ,:., N O I. ( .... >IDI UNT T, Job A 6 y 1" o Cl. r~t t. a [-'age \'lEAS I NC: g AZ I MUTIq I)E',PTtt Et dca d. eg .0 .0 0 . ('} (') 520 ,. 0 . '1 '1 5.) ,%. e 7 ~q 20.0 ,3 '.:~ !!b 7. {: .5 1. 0 20 ,, ,q) 4. ~ I. :2 29 'I., 1. I. t 'I 20. f.) .%, '3F 2L.P, 7. l 2 2 0.0 ~i. 0 ,q 2,c; %. 0 7 I .3 2 [), (') Ir, . 0 2 2 ~i ':{~. ') 2 t520.0 !'~. I,"~ 281. i() 1 !:.~ 20.0 %. ,c; 2 27,c;. l.'~ ~.:; 1 $ 20.0 ~:i~. 20 270,01 }:',r)Dh' MOL, l!!, DOG-EEC.;. VE,[tT V [!iRT '" .... L\.L~ ',.' - · '~ :7 " .. l ..... lION JD]~ :5 TA.N(3E', [,I'.AR J NO S E.V'DT, RI"I'Y lT)P;'P'I'f'! S '.'~'t',.' ', ...... 'N (') 0 F?, . (')O . (') ,0 . O N 0 t';Yl.(()l)l'l'/\ l',ItJl,,'l'.l :.;lll)'l' l','l-lt)Jvl 1'.2() I,'tql,','l' 'I'{) I()3'2() I,'ILI,,'I' b'll,A,.,lll.,'Fql) ])I,["TI.I:'5 [:ll::,';I)'[hl.(l!',Nt;l'".l')"I'C) [~ I< l; %5 I~'l".ti'."l ,Sl:;f')\,"l.', :..5/\NI')I., () T-E l't O [K ]i Z () N T A g .,,'"' ('} cIR F) 7[ N A T E, S . () () 'N .0 (') F, x';,S; t!, ,Iz'; S .40 E, '3 ,'5 f,4 , <,~ ,". N' '[. ,q :~, W ,$ W 20.47 N 106.56 W 13 W ll7.813 N 115.27 W 3 W '{/t,8',.q N 122.08 W '1"' i4 1,-~ o.-) N 12{'.5 07 W 4':3 W 1. l.~b7 X 128.~54 W :~.,NOICOTT LL,1, NO. ,IDI UNIT, ALASKA l'ob Numb&~'~: AK0"q ~ o' ~ a=e 2 2520.0 1.62 244.11 S 64 7 w 2620.0 '1.37 243.95 S 6:3 57 w 2720.0 ]..25 241.57 S 61:34 W 2820.0 1.06 240.97 S 60 58 W 2920.0 .86 238.58 S 58 35 W 3020.0 .67 233.83 S 53 50 W 31.20.0 .52 221.10 S .-'i.t 6 W 3220.0 .52 208.16 S 28 10 W 3320.0 .57 205.20 S 25 712 W 3420.0 .55 21/4.02 S 34 1 W 3520.0 ·4.3 197.00 S 17 0 W 3620·0 .43 190.37 S ]0 '22 W 3720.0 .38 7185.6.6 S 5 ",27 W 3820.0 .40 182.36 S 2 22 W 3920.0 .52 152.0'?) S 27 55 4020·0 .81. 149.68 S 30 '[9 E 4120.0 .63 161.98 S 1.8 1 E 4220.0 .60 167.83 S 12 10 E 4320.0 .58 161.. 70 ,5 18 18 E 4420.0 .67 171.15 S 8 51 E 4520.0 .56 162.1.8 S 17 49 E 4620.0 .65 166.03 S 13 58 E 4720.0 .67 1.65.08 S 14. 55 g 4820.0 .72 160.67 S 19 20 E 4920.0 .66 163.89 S 1.6 7 E DC)G-LEG VERT SEVERITY I)EPI.q d e g / ] 00 ' If t .08 251.3.6 130.5 .05 261. 3.6 1. 32.4. .13 271.3.6 134.2 .18 2813.6 1.35,8 .21 2913,6 1.37,0 ,20 3013.5 138.0 .20 31 13.5 1,38.6 .1 '2 3 21,13.5 139.0 .05 35313.5 139.2 .09 3413.5 139.5 · 30 .4013,5 138.6 .24 411.3.5 137.8 .07 4213.5 137·3 .07 4313.5 136.9 .13 4 z, 1:3.5 l 36.."..~ .15 4513.5 ]136.0 · 10 4613.5 1:35.5 .02 4713.5 135.0 .08 4813.5 134,, 5 .07 4913.4 133.9 13t./4 N 85 22 W 1. 33.5 N 85 "54 W t135.4 N 86 24 W 13-.1 N 86 .5 / 1 W 1.38.5 N 87 14 W 1·,39.6 N 87 :'33 W 1.~,0.3 N 87 51. W 140,8 N 88 10 W '.1/41.2 N 88 31 W 141.7 N 88 51. W 142,] N 89 10 W 142,3 N 89 6.5 W 142.4 S 89 59 W 141.6 S 89 16 W '141.t S 88 49 W 140,8 S 88 23 W 140.6 S 87 59 W 140./4 S 87 33 W t40.2 S 87 7 W 140.0 S 86 42 W 139.8 S 86 lZ, t4 139.5 S 85 45 W 139.2 S 85 16 W H O R. I Z C) N T A L (] 00 R D I N A T E S f e e. 't' 1.0.60 N 130.93 W 9.54 N 133.1.2 W 8,49 N 135,15 W 7.53 N 1,'.36.92 W 6.69 N 138.37 W 5.95 N 139.48 W 5.2(.-',N 140.25 W 4.52 N 7140.76 W 3.67 N 1.41.19 W 2.83 N 141.67 W 2.07 N 142.04 W 1.:'14 N 142.22 W .64 N 1.42.32 W .04. S 1.42.37 W .79 S 14.2.17 W 1.80 S 141.60 W 2.93 S 141.07 W 3.97 S 140.79 W 4.96 S 1.40.52 W 6.02 S 140.27 W 7.05 S 140.04 W 8.07 S 139.75 W 9.18 S 139.46 W 10.34 S 139.10 W 11.,49 S 13,9.73 W 13.P. EXPLORATION gNDICOTT WFJ,L NO. 2-]2/Q-16 MDI I.,N[], A[,ASKA ,Tol) Number: At(()493(;342 A G y .t:" n d a t a [) 'i. t-' e c t 'J. o n a.i. S ~'1 y v e y 6020,0 1.57 2(,1.24 6].20.0 4. [I. 3 271. 211. 6220.0 6.2] 274.93 6320.0 7.85 277 64'20.0 'lO,Oa 276, $ 8] 15 W N $,..q 47 W N 82,.'~ 3 W N 2') ,31 W 6520.0 12.12 26':). 73 6620.0 '14,24 27(). 76 6720,0 '1.5,73 277.06 6 8 2 0.0 '1 7. ,.c) S 2 7 7.9 6 6920.0 .I 9 o 28 277.57 7020.0 2'I ,SS 71.20.0 2.3. fi 7 7220.0 25, ] 3 73 '~0 0 "'~- aO 7420.0 28.53 278,56 2 $ ]. 41 282,05 282.22 282,29 X S] 27 IS N 7,q. 35 W g 77 57 W ,X 77 47 W D 0 G - L g G V f.!', B,']" S EV Ell l' TY l[)'E P'N.t' (I e 2. / '1.0 0 ' i:.' t; VEf~T C [,, 0 $ U g E S [!', C T ]Z (") N ') IS ;PA N C [:!', B }?,A R'[ N G t: t:. 1! t: d e gm.: t 43,9 S 83 fl W 152.7 S 83 40 w _ 509.7 h' $5 5/~ ~ f-I O P, I Z 0 N T A L C: O 0 R D I N A T E S J:! e e t, 12,51 S 138,4.1 W .~ .... :5 lo$,.tl W 14.08 S ]37,92 W 1..!~,55 ::ii ]_37,81 W I5,()0 $ ]37,66 ~ ]6,18 S 137.12 W '16.,f;'2 $ 136.55 W ].7.2Z~ S 137,86 W 17.38 S 142,81 W 16,34 S 15].80 W 15.47 S ]63.96 W '13 , 57 S 'l 79.4 2 W 12.63 $ 198.61 W 10.69 S 247.16 W 2.60 S 307.34 W 2.32 N 34.1.90 W 8,99 N 379.62 W 17.37 N 4]19.91 W 26.60 X Z:162.86 W B.P. EXPI,ORATION %NDICOTT WELL NO. 2-12/Q-16 ~DI UNIT, ALASKA .Job Number: AKO493G348 A Gy rod a t a I) :i. r e c t i o n a. ]. Survey Page 4 MEAS ]7 N{':[, AZ DEPTH . rt 'ft deg. 7520,0 28,26 281.,90 7620,0 28,27 281,54 7720,0 28,26 281,14. 7820,0 28,09 281,60 7920,0 28,3 .~ 28 t, .54 8020.0 28.29 281.43 8120.0 28.2!5 281,]7 8220.0 28.01 281..54 8320.0 28.]3 280.82 8420.0 28.65 279.65 8520,0 28,32 280,27 8620,0 27.94 280,27 8720,0 27,76 279,56 8820,0 27,96 277,90 8920.0 27,52 277.89 9020.0 27.25 278.19 9120.0 27.08 277.62 9220.0 26.62 278.59 9320.0 25,, ,S 3 278. q 6 9420.0 25 .a0 279.3S 9520.0 25.65 279 9620.0 25.65 280.'29 9720.0 25.55 280.03 9820.0 25.81 280.75 9920.0 26.12 280.83 BORE HO[,F, DOG-LE(:; I.,['.,AR J. N[:, EVI?,RI ('i e~, mJ..n d ...... 100 N 78 6 W ,33 N 78 28 W ,17 N 78 5'2 W ,19 N 78 24, W ,28 N 7~ 28 W 2.5 (,.~ ~, N 78 34 W ,07 N 78 50 W ,]3 N 78 28 W ,29 N 79 il W ,36 N 80 21 W ,77 N ? c /-I , 'J 4 W 44 N 79 /,4 W .39 N 80 27 W N 82 6 W .80 N 82 7 W W °'l. 48 W .30 q) . · N ,5';2 23 W .:32 ~ 8] 25 W ,64 N $1 2 W ,80 N 80 37 g; ,47 I") I:{', li'"l' t-I S :, t, [ .[ ( 1N f t f 't 7437,0 553,4 7525,1. 600,7 76] 3 o 1 648,1 7701,3 695,,3 7789,4 7/-:2 ~6 7877,5 790,0 7965,5 837 ~ 3 8053,7 884,5 8141 ,9 93]. ,5 8 '229,9 979..l. 8317,8 ]026.8 8406.0 1073,9 S 494,4 '1 '1. 20.6 8582.8 I ] 67 .,3 867 J.. 3 ]. 2 '.1. 3,8 556.8 N 85 ]3 W 603,9 N 84, 40 W 65].0 N 84 14 W 698.0 N 83 51W 7'~15~1 'N 813 31 W ,"' 9 ':2 ,, .3 N 83 '13 W 839.5 N 82 58 W 88{5.6 N 82 44 W 933.5 N 82 132 W 981.0 N 82 24 W '1025,7 N 8'2 ]7 W I.()75,g N 82 1.1 W '1 '1 2 2. ,".~ N ,g 2 6 W 116 g, 2 N $ 2 4 W 1215,7 N 82 4 W t.l O I.~ .[ Z (7) N T A L C: ()0 t?, D l' N A T E S .f. ee t 46.45 N 554,88 W 56,07 N 601,24 W 6,5,38 N 647,67 W 74,69 N 693,96 W 84.'1,7 N 740,28 W 93,61. N 786,77 W 102.89 N 8533,2l W '[]2,1.8 N 879,43 W ]21.,30 N 925,60 W 1.29,74 N 972,39 W 137,99 N 1019,37 W ]46,40 N 1065,76 W 154,4.':, N 1111,77 W 1.61,53 N 1157.96 W -~,9') N 1204,07 W .174,35 N 1249,62 W 180.63 N 1294,84 W 187,00 N 1339,55 W 1.93.73 N 1383,22 W 200.62 N '[425.90 W 207,74. N 14.68,40 W 2]5.23 N 1511.03 W '222~85 N 1553,56 W 230.67 N 1596.18 W 238.87 N 1639,20 W -) 3.P. EXPI,ORATION :[,NDIC,.,OTT WE[.,[.., NO. 2-12/Q-16 ~DI UNIT, ALASKA Job Nt.~raber: AK04.93034.,'.'5 A G y r o d a t a I) i r e c t i o n a 1 S 'LIr v e y Page 5 MEAS INCL AZIMUTH BORE HOLE DOG-LEG VERT VERT DEPTH BEARING SEVERITY DEPTH SECTION ft deg deg deg min dcA/lO0' ft ft 10020.0 24.63 281.73 N' 78 16 W 1.54. 9659.1 1697.2 10120.0 22.93 283.05 N 76 57 W 11.78 9750.6 1.737.6 10220.0 21,80 282,81 N 77 1.2 W 1..13 9843,1 1775,6 10320.0 21.;33 283.44 N 7~3 33 W .53 '.i:~936.1 1812.3 C L 0 S II R E DISTANCE BEARING ft deg min 1(,99.3 N 81 38 W 1739.5 N 81 32 W '1777,5 N 81 27 W 1814.l N 8'1 2'1W tt O R I Z 0 N T A L COORDINATES feet 247.24 N 1681.22 W 255.88 N 1720.60 W 264.39 N 1757.68 W 272.74 N 1793.48 W l,' Ei n a ] S 'r. a t -i. o 1"1 C 1 o s ~11"' e: 1 ,?, 14. I f' e e t' N o ~.- t. h 81 d e g 2 ] m i n 11 ,'-.-., e, c W e,,-", -~' . 'TON INSTRUMENT AUSTIN. TEXAS CHART NO. 101515-L ~ FON INSTRUMENT AUSTIN. TEXAS CHART NO. IO1515-L B.P. EXPLORATION ENDICOTT WELL NO. 2-12/Q-16 QUALITY CONTROL COMPARISONS JOB NUMBER: Q@0493G348 INRUN / OUTRUN COMPARISON DEPTH iN INC OUT INC DELTA IN AZ 1020.0 3.92 4.12 -.21 291.45 2020.0 5.47 5.33 .15 263.31 3020.0 .82 .67 .15 241.08 4020.0 .72 .81 -.10 153.63 5020.0 .61 .56 .05 174.13 6020.0 1.46 1.57 -.11 164.41 7020.0 21.64 21.58 .05 280.05 8020.0 28.36 28.29 .07 283.00 9020.0 27.31 27.25 .05 279.40 10020.0 24.67 24.63 .04 283.20 10320.0 21.33 21.33 .00 284.77 FOR INCLINATIONS GREATER THAN O. DEGREES : AVERAGE INCLINATION DIFFERENCE = .013 AVERAGE AZIMUTH DIFFERENCE = 6.681 OUT AZ 292.61 257.29 235.33 151.18 161.88 262.75 280 .O6 282.93 279.70 283.23 284.95 DELTA 1.16 -6.02 -5.74 -2.45 -12.25 98.33 .02 -.06 .30 .03 .17 B.P. EXPLORATION ENDICOTT WELL NO. 2-12/Q-16 080493 FMT-'F8.2 IX, lO!F9.2 1X)' 1020.00 ' 3 92 ' 291.45 2020.00 5.47 263.31 3020.00 .82 241.08 4020.00 .72 153.63 5020.00 .61 174.13 6020.00 1.46 164.41 7020.00 21.64 280.05 8020.00 28.36 283.00 9020.00 27.31 279.40 10020.00 24.67 283.20 10320.00 21.33 284.77 10320.00 21.33 284.95 10020.00 24.63 283.23 9020.00 27.25 279.70 8020.00 28.29 282.93 7020.00 21.58 280.06 6020.00 1.57 262.75 5020.00 .56 161.88 4020.00 .81 151.18 3020.00 .67 235.33 2020.00 5.33 257.29 1020.00 4.12 292.61 3735.50 -2362.50 1589.50 -3891.00 -1521.00 1115.00 -5327.00 -4401.00 -4392.00 -4446.00 -4201.50 -4183.00 2359.00 2932.00 3912.00 3308.00 -851.00 -3919.50 -1814.50 -1091.50 2189.50 -3511.00 2097.50 -3326.50 3620.50 266.50 3569.50 -6964.50 -3283.50 -5761.00 -5426.00 -5119.00 -4834.00 -4841.00 -6384.50 -6355.00 -6143.00 -5331.50 3977.00 108.50 -3392.00 -3747.50 -3328.50 2621.50 53.46 43.42 20.61 28.20 19.40 10365.03 42.50 18.45 13.31 11.27 17.11 14.91 28.90 11.99 6.52 14.05 309.95 10.53 16.06 9.01 17.36 39.23 26.27 22.37 10.86 16.27 10.51 9500.33 7.16 6.75 16.00 1.45 .81 3.39 13.12 13.48 12.53 17.26 234.59 5.77 5.21 5.34 18.90 7.26 60.53 59.48 63.47 51.87 74.96 22698.47 66.86 80.65 50.63 50.94 119.41 77.89 67.29 138.08 54.99 99.49 1292.26 65.71 58.52 98.78 48.47 53.01 72.00 28.15 37.14 34.43 60.35 19848.03 97.91 143.82 80.57 21.83 37.47 36.30 35.24 99.43 31.06 49.93 2053.94 41.85 26.92 79.33 27.81 25.99 358.84 227.33 93.00 293.62 209.09 24.87 165.76 180.18 180.76 179.16 181.20 181.20 239.88 243.71 249.48 255.23 105.24 287.36 1.76 286.91 301.32 112.12 75.22 75.39 75.59 75.51 75.55 75.67 75.66 75.62 75.6O 75.6O 75.54 75.55 75.51 75.56 75.57 75.64 75.70 75.86 75.93 76.06 76.12 76.14 B.P. EXPLORATION ENDICOTT WELL NO. 080493 FMT=' (3((FlO.3),X)) ' 1020.000 3.919 5.472 .821 .716 .613 1.458 21.636 28.361 27.307 24.668 21.328 21.329 24.629 27.253 28. 294 21.584 1.571 .564 .814 .669 5.326 4.124 2020.000 3020.000 4020.000 5020.000 6020.000 7020.000 8O2O .000 9020.000 10020.000 10320.000 10320.000 10020.000 9020.000 8O2O .000 7020.000 6020.000 5020,000 4020.000 3020.000 2020.000 1020.000 2-12/Q-16 291,450 263.309 241.075 153.630 174.128 164.414 280.046 282.995 279.399 283.204 284.772 284.946 283.235 279.697 282.933 280.061 262.746 161.880 151.181 235.335 257.288 292.611 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 April 29, 1993 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear AOGCC Representative, Attached in duplicate is detailed information regarding the enclosed well logs for the Endicott Field. Please contact me at 564-5225 if you have any questions. Sincerely, fi~'L. Haas- ' r Technical Assistant II JLH Enclosures xc: File 06,10 BP EXPLORATION March 24, 1993 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear AOGCC Representative, Attached in duplicate is detailed information regarding the enclosed well logs for the Endicott Field. Please contact me at 564-5225 if you have any questions° Sincerely, eannne L. Haas ior Technical Assistant II JLH Enclosures xc: File 06.10 RECEIVED MAR 2 5 1993 Alaska 0il & Gas Cons. Commission Anchorage MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to: David Johnso~ date: Commissioner" file: thru: Blair E Wondzell ~ subject: Sr Petr Engineer _~/'~,["z? from: :J~hn Spaulding Petr Inspector March 3, 1993 JOH03031.DOC BOP Test - Doyon 15 BPX DIU Well 2-12/Q16 PTD 92-117 Wednesday, March 3, 1993: I witnessed the BOP Test on Doyon Rig 15, BPX DIU Well 2-12/Q16. Four valves leaked on the stem packing and were repaired immediately. SUMMARY: I witnessed the successful BOP Test on Doyon Rig 15 BPX DIU Well 2-12/Q16; 32 components tested with 4 failures; test time 4 1/2. Attachment STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: / Workover. DATE: J-~- Drlg Contractor:. Rig No. ~ PTD # ~,~- / / ? Rig Ph.# ~ ~9 - ~ ~-/ Operator. Rep. /~ ~- ,5,,~c~1~/'~ Well Name: ~,/~, ~//-, Rep. ~'=~/~[Y Casing Size: /,_~ ~/9 Set ~ ~,? ~ ? ~ Feet Loc~tiOn: Sec. ~ T. /~/ R. //= ~- MeM. /,~, Test Initial Weekly . ~ ;.~. ~:.-,~. -..~.,>:.'--.--~::.~.?.-o~x ...... : ..... ,..---- ...,.-.--x...:.-.:...-.x........,.:'x.:.~-..:¥.~×.x.:.x-.'.-..--...:...--x>-'-'-:-. .. .... c.:.:¥.~2;./..~:.::..:.:.:.-.-:::: :.>;.~.:..?...-~..-..-.'~.¥:?.: ..~.~ ..~ ~:::: . ~.-+:+~.' :"~.~..~:.:.:...x~:.x.:-.-.-.- ~.>-.~.:::.;,.;~?.y:,.'.~.'.,~-..~'.'_::.:.*'-'-'--? ? -~... ..*. : ,. .';': ;-.':'.:':. y:::~:'; ,.- :_ *, .:::.-.-,~ -.-: :-: ::- -~: ---. .:¥.:-:.:*. ........ . _ .+.-.-~. ~.,.~ ~. --*:-~. ~:-_~ · ......-.....-.... _ .... ..._,......,.. ..... - .............. Test MISC. INSPECTIONS: Lo~ation C~n.: Housekeeping: ~(Gen) R~e ~ Well Sign ~ Drl. Rig ~ .... Test Pressure BOP 8TACK: Attn. Preventer Pipe Rams Blind Rams Chk/I.n Valves HCR Valves Kill Une Valves Check Valve pA= FLOOR SAFETY VALVES: Upper Kelly Lower Kelly Ball Type ~ BOP Glen. I / / / Pressure MUD sysTEM: Light Alarm Trip Tank Pit Level Indic. atom ~ .,~ Flow Indicator · Gas Detectors C OKE iiNaFOU : No. Valves No. Ranges Manual Chokes Hydraulic Chokes ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 I~i Attained Alter Closure System Pressure Altain~ Blind Switch Covers: IVlastec. Nltgn. atYs: d' TI'I ~'1"]' ...... ~l':"'" '1' ' "~'1~" ' "" ':""*'"'" ..... : '~'''' I'('I I ' ' I--I ' ''1 .... ' ' ''' ' I --' '' '[ Ifil* '' '/ ''' ''l'l ....... ' '''I ' ' ............. ' .............. I Il ''ri........ II'll'"'l'l' Number of Failures ~/ Test Time ~ '/z. Hours Number of valves tested ,~_~Repair or Replacement of Failed Equipment shall be made within ~--~-? - days. Notify ~e Inspector on duty and follow with Written or Faxed varffication to he AOGCC Commission Offme at: Fax No.' 276-7M2 Inspector North Slope Pager No. If your call is not returned by the inspector within 12 hours Pleese contact ~e P. I. Supervisor at 2'/~1433 REMARKS: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector STATE WITN~ REQUIRe? YES NO 24 HOUR~.~CE GIVEN YES NO Waived By:. FI-021~T Rev. 1/93 MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to: David W Joh.~on date: Chairma~ file: thru: Blair E Wondzell ~ / ~ (;[~.~ subject: Sr Petr Engineer from: ~bby Foster Petr Inspector March 25, 1993 031393. doc BOP test - Doyon 15 BPX DIU 2-12/Q16 MPI Permit #92-117 Endicott Field Saturday, March 13, 1993: The BOP test began at 10:00am and was concluded at 12:30pm. There was one (1) failure. The upper kelly valve on the top drive unit leaked. This is to be repaired and an AOGCC representative notified. Summary: I witnessed the BOP test on Doyon 15. Test time was 2% hours with 1 failure. Attachment: Saturday, March 13, 1993, I was notified at 4:00pm by Mike Droddy, Doyon toolpusher, that top kelly valve had been repaired and tested o.k. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: ~ Workover:~ Drlg Contractor: ~~~~~__~~ Operator: Well Name: Casing Size: ~,~,: / Test: Initial Weekly DATE: Rig No. 1 ~'~ PTD #~/~. ~///7 R~ Ph.~ . ~ Rep. Rep. Feet Loca~on: Sec. ~ ' T.-/~ R. Other Test MISC. INSPECTIONS: Location Gen.: ~ Housekeeping: ~ (Gan) Reserve Pit~ BOP STACK: Ann. Preventer Pipe Rams Blind Rams Chk/Ln Valves HCR Valves : ~-. Kill Line Valves Check Valve Qua, Well Sign Dri. Rig Test Pressure P/F I P MUD SYSTEM: Light Alarm Tdp Tank ./-" ,.--' Pit Level Indicators Flow Indicator Gas Detectors -,/- FLOOR SAFETY VALVES: Upper Kelly Lower Kelly Ball Type Inside BOP Quan. Pressure P/F CHOKE MANIFOLD: Ne. Valves No. Flanges Manual Chokes Hydraulic Chokes ACCUMULATOR SYSTEM: System Pressure '~'::~-~:~ I Pressure After Closure 200 psi Attained After Closure -- minutes _2~ System Pressure Attained ,2~ minutes /~ Blind Switch Covers: Master: ~ Remote: Nitgn. Btl's: c~.~ ~/~, / _~ c~'g ,/'~,;~ ~ ~ Psig. 'humber of FailUres /.7 .... test'Ti'm~'"e~y,~ Hours Number of valves tested ~.~ Repair or Replacement of Failed Equipment shall be made within J days. Notify the Inspector on duty and follow with Wdtten or Faxed verifica~on to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 / Distribution: odg-Weil File c - Oper./Rig c- Database ~.- Tdp Rpt File · Inspector iSTATE WITNESS REQUIRED? YES NO 24 HOUR NOTICE GIVEN YES NO Waived By: W'rtnessed By: FI-021L.XLT Rev. 1/93 MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to: David W Johp~3'~ date: Chairman ~ file: thru: Blair E Wondzell ~[z~l~7 subject: Sr Petr Engineer from: ~OU Grimaldi Petr Inspector March 24, 1993 031193. doc Rig/BOPE inspection Doyon Rig ¢15 BPX ¢2-12/Q-16 Duck Island Unit PTD 92-117 Thursday, March 11, 1993: I made a rig/BOPE inspection on Doyon Rig ¢15 drilling BPX well ¢2-12/Q-16 at Endicott. I found Rig 15 to be very clean with all BOPE equipment to be in place and in apparent good working order. I did find three hammer-up type unions downstream of the choke manifold; two were used in the blowdown lines and one was in between the choke manifold and the gas buster. Mike Drody (Doyon toolpusher) will check on availability of unibolt type connections. Rig 15 is a very well maintained rig manned by experienced hands who show pride in their rig and safety record. The area surrounding the rig was exceptionally clean and orderly. Summary: I made a rig/BOPE inspection on Doyon Rig ¢15 drilling BPX well ¢2- 12/Q-16 in Endicott and found unauthorized connectors in the lines downstream of the choke manifold. Attachment DOUG AMOS STARE OF ALASKA ALASKA',.._ AND GAS CONSERVATION COMMISSION RIG / BPS INSPECTION REPORT OPERATION: Drilling ,2(' Workover ~Compl, UIC ~ DATE: Well N~tme: c~..-/~/(r3Aj¢., Ddg Contractor: ~ O ~~ Rig¢ / ~ Rep. -- Locstion: Sedion ~ T. /~ ~ R. /~¢ M. ~ ;~.:/::::.;; (A.) B.O.P. STACK YES NO N/A ~;~ (~,) MUD SYSTEM ~';~;;; Wellhead fig wkg press ~ ;~.;Pit level ~3:; Annular p~eventer ~ :~;i~;; Mud g~s separator /;;~:' Pipe r~s K ;~::; Degosser ::/6':; Ste~, and~ored ~ ~.~;~.( Gss sensors {?~:.; Chkehdll line size ~ ':~:~ 0hoke line connedions ~i;~';~ All turns targeted (chke & kill Ln.) ~ :::~;- Td tank . ;,.: ;. ..P. ~:;9 HCR k/elves (chke & kill Ln.) ~ ~::~ ~;~ ?~ ~i)I~$]BE~i~ :i;:0 Manu~ivaives (chke & kill Ln.),, ~ '~'""""(6']}"~i~"~LdbA : ~:i Connections (Flgd. Whd. Cl~mped ~ /~:?;~: Kel~ cocks (upper. lower, IBoP) .~.~ ,.~ Drilling spool ~. ;~.8~ Floor v~lves :;13; Flow Nipple ~ ~;;~:~;: K~i~ & floOr v~ive wrenches :~i:~ Flow monitor ~ ~:~;:. Drillers console (flow monitor. ; ,:~:~; -: ..... , ~:.~ 5~ Con~a'ol lines fire protected ._ ~ ............. flow r~te indicator, pit level ';~'~-~:~ ~B.) CLOSING UNIT YES NO N/A ~:~:.~:; Kill sheetup-~d~te ~:6 WerMng pressure ~ ;.~ G% detedion monitors ~!~ Fled level -- ~ ;(H~S & methane) J.;~: Operating pressure ~ ~:~;~ Hydraulic choke p~nel ~].:9: Pressure go. uges ~ ~.~:~:Choke m~ilold 2E 4-wayvalves (~u~tors) ~. ;~;:'~lo. reNent line -;~'~; Blind rsms h~ndle cover ~ ;~:~; Al' turns targeted :~;¢.~ Driller control p.nel ~ (do~stre,m choke lines) ;~g~5~ Remote conlrol panel ~ ~:~:~i: R. eserge pitt=nk~ge ".~6'~ FirewsII ~ ;:'~8;: Personnel protedive equip. ~1. ~5:5; "'"'"" ;g:?:~ N,t, ogen po=er source (b~ckup)~' ~5~;~1Drillsile Supe~isors Trained :~:8; Condition (le~ks. hoses, e~) ~ For Procedures . . :~'~ HaS probes . ~i~Ji~ Ri~ housekeepin~ REk,~ARKS: RECORDS: Dine of L~tst Rig / BPS Inspection "-- Date of Last BOP Test ~- '7-~'~ Resulling Non-Complimnce Items: ------ Non-Compliance not correcled & Reason: -'-- Date Corrections Will Be Completed: BOPTest & Results Properly' Entered On Dsily Record? ~/~¢'~5 Kill Sheet Current? ,V4~6'¢... O,'O~o,O's ¢o,..,,vb ,,,,j ,O,.<oo¢.r,z_/,.v~ ~,,vl>, Distribution: orig - Well File c- OpeL/Rig c- D~I~b~tse c - %ip Rpt File c- Inspector OPERATOR REP: FI-022.XLT (Rev. MEMORANDUM TO: THRU: David Johnstog~~ Commission~ Blair Wondzell,~,,,L P. I. Supervisor Stale of Alaska Alaska Oil and Gas Conservation Commission DATE: March 5, 1993 FILE NO: jph-rep20 Jerry Herring, ~ SUBJECT: FROM: Petroleum InslOector Diverter Test - Doyon 15 BPX, DIU, MPI 2-12 Endicott Field PTD 92-117 Saturday, February 27, 1993: I witnessed the function test on Doyon 15's diverter system. Doyon 15 is drilling well MPI 2-12 and had just moved on location from the SDI pad. See the attached Diverter Systems Inspection Report. The function test began at 6:00 PM and did not go well. I found the hands on board to be inexperienced and tired from the rig move completed the night before. The wrong supply and return lines were connected from the accumulator system, so the diverter and knife valve assembly did not function properly. After the correct plumbing of the control lines to the diverter and the knife valve was accomplished, a performance test of the accumulator system was completed and the diverter system functioned properly. The 10" vent line initially had a tee approximately 100 feet from the rig. The two manual block valves intended to direct the flow according to the prevailing winds were not piped correctly so the teed run to the North East was shut-in and isolated. The isolated teed run was not pointing in a safe direction, but in the direction of the production control center. A single straight 10" run from the diverter to the edge of the existing wellhead houses facing in a North West direction will be in use. Since there is an exemption on the Diverter System requirements for Endicott dated 4125186, ! accepted the configuration with a single line in the North West direction. The function test was finally completed at 4:00 AM the next morning. Only minor problems were left,noted on the Diverter Systems Inspection Report. These include posting the current wellhead sign, the kill sheet needed to be updated for the current effort, and the current Permit To Drill needed to be posted on the rig floor. These items were all present, but were from the previously drilled well. Summary: A successful diverter test was witnessed on Doyon 15, drilling well SDI 2-12 at Endicott for BPX. Attachment STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Operation: Drlg Contractor: DOYON Rig No. Operator: B.P. Exploration Oper. Rep.: Well Name: MPI 2-12 Rig Rep.: Location: Sec. 36 T. 12N. R. 16 E. Development 15 PTD # Date: 2/27/93 YES Exploratory: 92-117 Rig Ph. # 659-6510 Everett Potter Ronnie Gould / Al Sinclair Merdian UMIAT MISC. INSPECTIONS: ACCUMULATOR SYSTEM: Location Gen.: OK Well Sign: NO Systems Pressure: 3050 psig Housekeeping: OK (Gen.) Drlg. Rig: OK Pressure AfterCIosure: 1800 psig Reserve Pit: N~, Flare Pit: N~A 200 psi Attained After Closure: 1 min. 5 sec. Systems Pressure Attained: 3 min. 35 sec. Nitrogen Bottles: 4 Botttles DIVERTER SYSTEM INSPECTION: Diveder Size: Dived Valve(s) Full Opening: Valve(s) Auto & Simultaneous: Vent Line(s) Size: Vent Line(s) Length: Line(s) Bifurcated: Line(s) Down Wind: Line(s) Anchored: Turns Targeted / Long Radius: 20 in. 2700,2400,2400,2300 psig YES YES MUD SYSTEM INSPECTION: Light Alarm 10 in. Trip Tank: OK OK 140 ft. : Mud Pits: OK OK NO Flow Monitor: OK OK YES YES GAS DETECTORS: Light Alarm N/A ~ Methane OK OK Hydrogen Sulfide: N/A N/A NOTES: Kill sheet needs to be posted. Need to post current wellhead sign. Need to post current PTD on rig floor. N.W. ~ 10" Sch. 40 Hydraulic Actuator 10" Knife Valve-'/' Hydrill MSP 2000 20" Distribution orig. - Well File c - Oper/Rep c - Database c - Trip Rpt File c -Inspector F1-022 AOGCC REP.: OPERATOR REP.: D15-DIV1.XLS Signed: Jerry Herring Signed: Ronnie Gould ALASKA OIL AND GAS CONSERVATION COMMISSION December 10, 1992 Michael Zanghi Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 WALTER J. HICKEL, GOVERNOR ., .~. 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Re: Duck Island Unit/Endicott 2-12/Q-16 BP Exploration (Alaska) Inc. Permit No. 92-117 Sur. Loc 1877'SNL, 2196'WEL, Sec. 36, T12N, R16E, UM Btmhole Loc. 1458'SNL,4254'WEL, Sec. 36, T12N, R16E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Commissioner BY ORDER OF THE COMMISSION dlf/Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill[~llb. Type of well. Exploratory[] Stratigraphic Test[] Development Oil[] Re-Entry [] DeepenI-II Service [] Development Gas [] SingleZone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration BKB=56 feet Endicott Fie/d/Endicott Pool 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 34633 4. Location of well at surface 7. Unit or property Name 11. Type Bond(~e 20 AAC 25.025) 1877' SNL, 2196' WEL, SEC. 36, T12N, R16E Duck Island Unit/Endicott At top of productive interval 8. Well number Number 1477' SNL, 3937' WEL, SEC. 36, T12N, R16E 2-12/Q-16 2S100302630-277 At total depth 9. Approximate spud date Amount 1458' SNL, 4254' WEL, SEC. 36, T12N, R16E 12/20/92 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 34636/3820 feet 2-14/0-16-10'@ Surfacefeet 2560 10767' MD/10291' TVD[eet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.o35 (e)(2)) Kickott depth 6000 feet Maximum hole angle 28. 70 Maximum surface 3900 psig At total depth (TVD) 10000'/4890 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" Struct. Drive Pipe 131' Surfac~ 131' 131 Drive 16" 13-3/8" 68# ~r~oc~',E Butt 2763' Surfac~ 2763' 2763' 1266 cu ft PF/625 cuft "G" 12-1/4" 9-5/8" 47# NT80S NSCC 8724' Surfac~ 8724' 8500' 12' 1/4" 9-5/8" 47# NT95HS NSCC 1313 8724' 8500' 10037' 9651' 2083 cu ft Class "G" 8-1/2" 7" 29# NT-80S NSCC 980 9787 9432' 10767' 10291' 335 cu ft Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor J EEEIVED Surface Intermediate Production OCT 8 1992 Liner Alaska 0il & Gas Cons. 6ommisSioa Perforation depth: measured true vertical Anchorage 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs d~/~3th pict [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21.1 hereby~certify th~,~the~.~g~ng is true and correct to the best of my knowledge Si~ned.~-~~'~ [:" ~- 7~ ~ Title WorkoverEn~ineerSupervisor Date,..~-..~. ~)~ "-" j- Commission Use Only Permit Number IAPI number IApproval date ISee cover letter ~'2,.,-//;;' J50- d~-E-.2..2.,3o-P-_ J /,~-/0 "'~;~ Jfor other requirements Conditions of approval Samples required [] Yes ,];~'NO Mud Icg required []Yes ~No Hydrogen sulfide measures [] Yes ~ No Directional survey required ~ Yes [] No Required working pressure for BOPE CI2M; 1~]/3M; ~,5M; I-IIOM- I-I15M; / ' Other: ORIGINAL SI6NED BY/' by order of Approved by RUSSELL A. DOUGLAS'~ Commissioner me commission Date /~--"/D "~ _ Form 10-401 Rev. 12-1-85 Submit in triplicate PROPOSED DRILLING WELL AND COMPLETION 2-12/Q-16 (MPI) PROGRAM Objective Well 2-12/Q-16 will be drilled as a gas injection well. Zone 3C is the primary objective. The completion will be run at the time of drilling and will consist of a simple type assembly. Operation Execute a rig move and rig-up. Directionally drill surface hole with a 8.5 - 9.5 ppg mud system to 2763 feet. Run and cement 13-3/8" 68#/ft NT-80CYHE Buttress casing to surface. Pressure test casing. Install BOPE. Maximum BHP is 4890 psi at 10,000 ft. TVDss. Maximum possible surface pressure is 3900 psi based on a full gas column. Drill out casing and 5 ft. of new hole and conduct a formation leak-off test. Directionally drill 12-1/4" hole with a 9.0 - 10.2 ppg mud system to the intermediate casing point above the Kekiktuk formation. Run and cement 9-5/8" 47#/ft., NT80S and NT95HS, NSCC casing. No abnormal pressures are expected in the 12-1/4" hole section. Pressure test casing. Drill out casing shoe. Drill 8-1/2" hole with a 9.7 ppg mud system to TD. Run open hole logs. Run and cement 7" 29#/ft, NT-80S liner to TD with approximately 250 ft. of lap in the 9-5/8" casing. Clean out to landing collar. Test casing and lap to 3000 psi. Change over to NaCI packer flu id. Run CET/CBT/GR/CCL in 7" liner and CBT/GR/CCL from. PBTD to 1000' above 9-5/8 shoe. Complete with a simple type assembly. A subsurface safety valve will be installed below base of permafrost. Nipple down BOPE. Install tree on wellhead and release rig. Perforate well and run GCT/gyro after rig release. Fluids incidental to the drilling of the well will be pumped down the 13-3/8" by 9-5/8" annulus of the well. The 13-3/8" x 9-5/8" annulus will be freeze protected with a non-freezing fluid down to 2000 feet once the rig is released. PC 9-27-92 RE(E VED Alaska Oil & Gas Cons. Anchorage ENDICOTF PRELIMINARY WELL PLAI-. Well: 2-12/Q-16 Island: Main Production Island RT Elev. AMSL: 56 Rig: Doyon #15 BR/100': 2 Location Surface: X= 259,013 Y= 5,982,539 1877' SNL, 2196' WEL, Sec. 36, T12N, R16E Target: X= 257,172 Y= 5,982,976 1500' SNL, 4050' WEL, Sec. 36, T12N, R16E Est. Spud Date: 11/20/92 Operation Days: 25 Max. Angle: 28.73 KOP (BKB): 6000 Target Dep.: 1,891 Target Dir.: N 78.49° W Item TVDss TVD BKB MD BKB DEPARTURE 30" Drive Pipe 75 131 131 Base Permafrost 1,41 0 1,466 1,467 28 13-3/8" Casing 2,700 2,756 2,763 145 E O B 7,315 7,371 7,437 499 9-5/8" NTSOS Casing 8,444 8,500 8,724 1,118 Top Tuffs 8,860 8,916 9,199 1,346 Top HRZ 9,245 9,301 9,638 1,557 9-5/8" Packer 9,332 9,388 9,737 1,6051 7" Liner Top 9,376 9,432 9,787 1,6291 Base H RZ 9,510 9,566 9,940 1,702 Top Itkilyariak 9,510 9,566 9,940 1,702 9-5/8" NT95HS Casing 9,595 9,651 10,037 1,749 Top Kekiktuk/Zone 3C 9,645 9,701 10,094 1,776 GOC 9,855 9,911 10,334 1,891 Target 9,855 9,911 10,334 1,891 Top Zone 3B 9,855 9,911 10,334 1,891 Top Zone 3A 10,040 10,096 10,545 1,993 O W C 10,200 10,256 10,727 2,080 Total Depth 7" 29# Liner 10,235 10,291 10,767 2,100 Logging Program: Open Hole: Final: RUN 1: DLL/MSFL/GR, GR in 9-5/8" over HRZ RUN 2: LDT/CNL/GR RUN3: RFT 12points ~ ~'"~"""" "~""'" Cased Hole: 7" Liner: OCT 2 8 1992 CET/CBT/GR/CCL Gyro survey from PBTD to surfac~Iaska~ & Gas Cons. 60mrnissi0n CBT in 9-5/8" casing Anchorage ENDICOTT PROPOSED DIAGRA! WELL 2.12/Q-16 (MPI) NON-FREEZING FLUID TVD (BKB} MD (BKB) 30" DRIVE PIPE 131 FT 131 FT BASE PERMAFROST 1466 FT 1466 FI' SSSV 1550 FT 1550 FT 13-3/8" 68#/FT NT-80CYHE BTC 2756 FT 2763 FT BOTTOM OF FREEZE PROTECTION (ESTIMATED) 2000 FT TOP OF 9-5/8" CEMENT (ESTIMATED) 3500 FT KOP ( DIR: N 78.5° W; ANGLE: 28.7°) 6000FT 7", 26#/FT L-80 TUBING WITH 5-1/2" TAILPIPE ~ 9-5/8" 47#/FT NT80S NSCC 8500FT 8724FT ~9-~8"PACKER 9332 FT 9737FT 7"LINERTOP 9432FT 9787FT 9-5/8" 47#/FT NT95HS NSCC 9651 FT EEEIVED OCT 2 8 !992 Alaska 0il & Gas Cons., ~;ommission Anchorage PLUG BACK TD 7" 29#/FT NT-80~SCC LINER 10291 FT 10037 FT 10687FT 10767FT PC/9-27-92 GREAT LAND DIRECTIONAL DRILLING, INt. Corporate Office 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 349-2487 RECEIVED oct 8 399 Alas/(a .Oil .& Gas Cons. Comr~ission Anchorage DIRECTIONAL WELL PLAN for PRUDHOE BAY DRILLING Well ......... : 2-12/Q-16 (P1) Field ........ : ENDICOTT MPI Computation..: MINIMUM CURVATURE Prepared ..... : 09/25/92 Section at...: N,78.49,W KB elevation.: 56.00 PROPOSED WELL PROFILE STATION IDENTIFICATION PLEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES DL/ DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD 100 KB NUDGE BUILD 1.5/100 0 0.00 0 -56 0 N 0.00 E 0 N 0 E 0.0 1000 0.00 1000 944 0 N 78.49 W 0 N 0 E 0.0 1100 1.50 1100 1044 1 N 78.49 W 0 N 1 W 1.5 1200 3.00 1200 1144 5 N 78.49 W 1 N 5 W 1.5 1300 4.50 1300 1244 12 N 78.49 W 2 N 12 W 1.5 END 1.5/100 BUILD NUDGE DROP 1.0/100 1400 6.00 1399 1343 21 N 78.49 W 4 N 21 W 1.5 2300 6.00 2294 2238 115 N 78.49 W 23 N 113 W 0.0 2400 5.00 2394 2338 125 N 78.49 W 25 N 122 W 1.0 2500 4.00 2494 2438 132 N 78.49 W 26 N 130 W 1.0 2600 3.00 2593 2537 139 N 78.49 W 28 N 136 W 1.0 END 1.0/100 DROP KOP BUILD 2.0/100 2700 2.00 2693 2637 143 N 78.49 W 29 N 140 W 1.0 2800 1.00 2793 2737 146 N 78.49 W 29 N 143 W 1.0 2900 0.00 2893 2837 146 N 78.49 W 29 N 143 W 1.0 6000 0.00 5993 5937 146 N 78.49 W 29 N 143 W 0.0 6100 2.00 6093 6037 148 N 78.49 W 30 N 145 W 2.0 6200 4.00 6193 6137 6300 6.00 6293 6237 6400 8.00 6392 6336 6500 10.00 6491 6435 6600 12.00 6589 6533 153 N 78.49 W 31 N 162 N 78.49 W 32 N 174 N 78.49 W 35 N 190 N 78.49 W 38 N 209 N 78.49 W 42 N 150 W 2.0 159 W 2.0 171 W 2.0 186 W 2.0 205 W 2.0 6700 ~14.00 6686 6630 6800 16.00 6783 6727 6900 18.00 6879 6823 7000 20.00 6973 6917 7100 22.00 7066 7010 231 N 78.49 W 46 N 257 N 78.49 W 51 N 287 N 78.49 W 57 N 319 N 78.49 W 64 N 355 N 78.49 W 71 N 227 W 2.0 252 W 2.0 281 W 2.0 313 W 2.0 348 W 2.0 END 2.0/100 BUILD TOP HRZ 7200 24.00 7158 7102 394 N 78.49 W 7300 26.00 7249 7193 436 N 78.49 W 7400 28.00 7338 7282 482 N 78.49 W 7437 28.73 7371 7315 499 N 78.49 W 9638 28.73 9301 9245 1558 N 78.49 W 79 N 386 W 2.0 87 N 428 W 2.0 96 N 472 W 2.0 100 N 489 W 2.0 311 N 1526 W 0.0 BASE HRZ TOP ITKILYARIAK INTERMEDIAT CASING TOP ZONE 3C 9941 28.73 9566 9510 1703 N 78.49 W 9941 28.73 9566 9510 1703 N 78.49 W 9952 28.73 9576 9520 1708 N 78.49 W 10095 28.73 9701 9645 1777 N 78.49 W 340 N 1669 W 0.0 340 N 1669 W 0.0 341 N 1674 W 0.0 354 N 1741 W 0.0 (GLDD (c)92 212Q16 B1.35 7:03 AM 2) 2-12/Q-16 (P1) 09/25/92 Page 2 PROPOSED WELL PROFILE STATION IDENTIFICATION TARGET TOP ZONE 3B TOP TUFFS TOP ZONE 3A TOP S3A3C TD MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES DL/ DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD 100 10334 28.73 9911 9855 1892 N 78.49 W 10334 28.73 9911 9855 1892 N 78.49 W 10340 28.73 9916 9860 1895 N 78.49 W 10545 28.73 10096 10040 1993 N 78.49 W 10653 28.73 10191 10135 2046 N 78.49 W 377 N 1854 W 0.0 377 N 1854 W 0.0 378 N 1857 W 0.0 398 N 1953 W 0.0 408 N 2004 W 0.0 10767 28.73 10291 10235 2100 N 78.49 W 419 N 2058 W 0.0 REE. EIVEE) OCT 2 8 i992 Alaska Oil & 6as Cons, 6omrFfission Anchorage (GLDD (c)92 212Q16 B1.35 7:03 AM 2) PRUBHOE BAY DRILLING (PJ) VERTICAL SECTION VIEN Section at: N 78.49 W TVD Sca]e.: I inch = 1200 feet Dep Scale.: ~ inch = ~200 feet Drawn ..... :09/25/92 Great Land Directional Drilling Marker Identification MD BKB SECTN A) KB 0 0 0 B) NUDGE BUILD 1.5/t00 1000 1000 0 C} END 1.5/100 BUILD 1400 1399 21 D) NUDGE DROP 1.0/100 2300 2294 E) END 1.O/lO0 DROP 2900 2893 146 F) KOP BUILD 2.0/100 6000 5993 246 G) END 2.0/100 BUILD 7437 7371 499 H) INTERHEDIAT CASING 9952 9576 170B I) TARGET 20334 '991~ 1892 J) TD 10767 ~029~ 2100 INCLN 0 O0 0 O0 6 O0 6 O0 0 O0 0 O0 28 73 28 73 28 73 28 73 RECEIVED O0T 2 8 1992 & Gas Cons. (Commission Anchorage 0 600 J200 1800 Section Departure [GLDD (c)92 2J20t6 Bi.35 7:08 AN 2) 2400 3000 3600 PRUDHOE BAY DRILLING Narke¢ Identification MD N/S A) KB 0 0 N B) NUDGE BUILD 1.5/100 t000 0 N C) END t.5/J00 BUILD J400 4 N D) NUDGE DROP 1.0/100 2300 23 N E) END 1.0/~00 DROP 2900 29 N F) KOP BUILD 2.0/~00 6000 29 N G) END 2.0/100 BUILD 7437 100 N H) INTERMEDIAT CASING 9952 34~ N I) TARGET 10334 377 N J) TD 10767 4]9 N E/W 113 ~43 143 489 1674 1854 2058 2-12/ -16 (PI) PLAN VTEW CLOSURE ..... : 2100 ft at N 78.49 W DECLINATION.: 30.00 E SCALE ....... : 1 inch : 500 feet DRAWN ....... :09/25/92 8rea~ Land Directional OrJYYJng Alaska.Oil .& Gas Cons. 6omraisslor~ 3250 3000 2750 2500 2250 2000 1750 t500 t250 1000 750 500 250 0 250 <- WEST' EAST -> · (6LOD (c)92 2~20t6 BJ.35 7: JO AM 2) Existing Well 250U08 151V20 115P25 266SAGSW 101J19G 105020G 109J18G lllSN4G ll7SN2G 121K25G 125N22G 127P20G 129M25G 135025G 137P24G 139P17G 141023G 143P26G 145Q26G 147Q21G 149P21G 155R25G 157R23G 163T22G 167T20G 169V19G 202P18G 204M19G 206J22G 208K16G 214016G 216M16G 218L16G 220L15G 222L14G 226N14G 226N14G 228P19G 230009G 230009G 232SN3G 234P14G 236014G 238SN1G 242P13G 244R12G 246Q15G 252S14G 254Q12G 258S09G 262Q17G 264U10G 268S17G 270U15G Great Land uirectional · Collision Avoidance Analysis Planned Well: 212Q16 Pad: MPI Field: 09/25/92 10:11:25 Closest Approach Sep Depth min ft TVD ft MD ft Drilling, Inc. NSLOPE 100ft [MD's] Warning band Start End 25ft Serious band Start End 220 0 0 286 0 0 171 0 0 300 0 0 177 648 648 172 363 363 157 1047 1047 170 1 1 173 1 1 177 1 1 184 1002 1002 188 189 189 192 1 1 227 28 28 215 1123 1123 233 1288 1288 248 0 0 255 1 1 261 1035 1035 270 1 1 274 799 799 302 1 1 282 1507 1509 336 1 1 354 1 1 362 0 0 50 1026 1026 40 1 1 30 0 0 20 197 197 10 1 1 12 635 635 26 1256 1256 30 1248 1248 48 1355 1355 65 1489 1490 58 5408 5415 68 1485 1486 56 1831 1834 28 3683 3690 63 3138 3145 104 1645 1647 51 5593 5600 43 1633 1635 151 5041 5048 146 4420 4426 184 5619 5626 214 1924 1927 212 2486 2493 228 2593~ 2599 259 2113 2118 276 2464 2470 282 3833 3839 298 2168 2173 1 1820 1 1903 0 1439 56 1760 1 2148 1 1952 1 2210 0 2190 1 2235 56 2234 5110 5630 1 1894 0 2806 2945 4028 0 3455 5410 5781 1384 1836 56 725 1 1432 1 920 REEEIVED OOT 8 !99 AJaska Oil & Gas Cons, 6ommission Anchorage 501SG7G 502SG10G 503SN9G DI01G DI02G DI03G SAGD1G SAGD2G SAGD2AG SAGD3G SAGD4G SAGD5G SAGD8G SAGDllG SD311016 SD311116 started: 1459 1180 1516 15164 17232 23076 18549 16133 16134 6895 2960 31985 13362 28757 67286 40238 10:11:25 281± 4703 2739 6836 6086 413 6004 3055 2968 10252 10253 5994 3124 10234 3105 3291 ended: 2818 4710 2746 6854 6092 413 6011 3062 2975 10718 10720 6000 3131 10701 3112 3298 10:27:19 ECEIVED OCT 2 8 1997 .OJi .& Gas Cons, rjomm~ssm,; Anchorage TA ~,3 ~ TO STAI~P VoI.~IHE TAI, IK rANt~ 130 B~- TO Ii TRIP TAI',I K 75" BESL p~-C~ 55gR 'rANK V',~C u u /'I T Y F'E F~I. UM~ TNJ K MUD CLEAIdE~ ~1~, /HO H U O C. ZEAN ~ - Choke Manifold - Poor Boy Degasser · - Brand t Vacuum.-Type Degasser - Brand t Dual Tandem Shale Shaker - Pioneer Mud Cleaners - Pioneer MKI Centrifuge ,"MUD DISTRII~LITION DITC / ,,' / /' /' [. ,/ 1 - RecOrding drilling fluid, pit 'level indicator with both visual and audio warning devices at driller's console 1 - Trip Tank (75 BBL.) 1 - Drilling fluid flow sensor with readout at driller's console 11 - 5 Hp AgitatOrs S U F, ... ',-I, CE, .OLE DIVEF1TE,=I SYSTEM ...... Two lines venting 90 deg. apart in directions that ensure sate down wind venting, and ex- lending to a point at least 100' lrom any source al igniliono _10' Full Opening Valves ' 35, or as required Dresser Sleeve 1. All pipe conne~ons 150# ANSi Flanges or welded connectbns and secured to prevent movemenL 2_ Manual 10" full opening valves mechanically connected to ensure that one valve is fail-sate open at all limes. 10' Diverter Uno 3. All tums are 90 deg. and targeted. 10' Full opening ball valve w/Hyd~ulic Actuator Cellar 20' Diverter Spool w/10' Side Outlet ECE]VED OCT 2 8 199 Alaska OJJ .& Gas Cons. 6ommissi°r~ ~r~chorage MEM 1/'3/g0 DOYON 15 13 5/8" 5,000 psi Stack 9.00 4.65 3.00 t2.00 2.00 1 85 r," RKB ~1 I I I HYDRIL 5" PIPE RAM BLIND RAM KR TO RF RI( i FLO' 11.32 14.32 R 16.32 4" Choke MUD CROSS 4 1/2"x 7" VARIABLE PIPE RAM 20.17 39.05 13.95 4 FEET ABOVE GROUND LEVEL REEEiVED OCT 2 8 !992 .0JJ .& Gas Cons. ~ur~r~issior, ~Anchorage 2-12/Q-16 (rvlPI) Casing Design Specifications SURFACE CASING 13-3/8" 68#/FT NT-80CYHE BTC CASING BURST COLLAPSE PBYS (#) TJYS (#) NT-80CYHE 5020 2260 1556000 1585000 Burst Pressure Calculation Burst rating based on shutting in the well on a gas kick equivalent to the LOT (14.0 ppg) at the surface casing shoe. LOT (ppg) TVD (FT) SIPRESSURE 14 2700 1966 Burst S.F. 2.55 Collapse Calculation Collapse rating based on losing returns until the fluid level is below the surface casing shoe Mud weight behind the surface casing is 9.5 ppg Mud Wt. (ppg) TVD (FT) Collapse press 9.5 2700 1334 Collapse S.F. 1.69 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 68 2763 PBYS Tension S.F. 9.69 Mud Wt. 9.5 ppg TJYS 9.87 String Wt. (#) 160603 P, EEEIVED OCT 2 ~ 1992 0il & Gas Cons. ~0mrnissio~ Anchorage 2-12/Q-16 (MPI) Casing Design Specifications Production Casing 9-5/8", 47#,NT-80S and NT-95HS,NSCC Casing GRADE BURST COLLAPSE NT-80S 6870 4750 NT-95HS 81 50 5080 PBYS (#) 1086000 1289000 TJYS (#) 1161000 1273O0O Burst Pressure Calculation Burst rating based on have a tubing leak on top of full column of fluid Worst case will be at the surface, which has no back up gradient. Srl'P 3900 Burst S.F. Burst S.F. 1.76 (NT-80S) 2.09 (NT-95HS) Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) 10.2 9645 0.1 Collapse S.F. 1.1 4 (NT-80S) Collapse S.F. 1.22 (NT-95HS) Collapse press 4151 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) Mud Wt. 47 10037 10.2 PBYS TJYS Tension S.F. 2.73 2.92 Tension S.F. 3.24 3.20 String Wt. (#) 398195 (NT-80S) (NT-95HS) RECEIVED OCT 2 8 1992 .Oil .& Gas Cor~s. ~;urnrnission Anchorage 2-12/Q-16 (MPi) Casing Design Specifications PRODUCTION LINER 7% 29#,NT-80,NSCC Casing GRADE BURST NT-80 81 60 COLLAPSE PBYS (#) TJYS (#) 7020 676000 746000 Burst Pressure Calculation Burst rating based on formation pressure on top of 9.7 ppg fluid SITP Fluid wt (ppg) back up (ppg) Burst Pressure 3900 9.5 9.7 3808 Burst S.F. 2.1 4 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 9.7 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse Press 9.7 9645 0.1 3900 Collapse S.F. 1.80 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 29 980 Mud Wt. String Wt. (#) 9.7 23989 Tension S.F. PBYS TJYS 28.18 31.10 OCT AJas~ Oil .& Gas Cons. 'Anchorage ~8 0 ° °° '® ~o o 36 4, ao~~° o 4~ 0 ~5 0 '- ~'. 0 57s~ 0 6565~90 0 67 0 R ¢EIVED OCT 2 8 !992 Oil & Gas Cons. Commission Anchorage NO rES' 36 CERTIFICATE OF SURVEYOR i hearby certify thatl am properly registered and licensed to practice land surveying in the State of Aloskaand that this plQt represents Qn proposed location for the 'Well numbers shown ubove. All surveying was done by me or under my supervision~ and thot all dimensions end details are correct- DRW. 116-85 SHEET 2 of IO Indicates well Indicates Calc~Jlated Section Corner Position Indicates Perpendicular Offset Distance Indicates Perpendicular Offset Distance perpendicular distunce varies tar each well I PLAT OF MPi PROPOSED WELL LOCATIONS REV. O LOCATED IN SEC. :56, T. IZN., R. 16 E. UMIAT M. PREPARED FOR SOHIO ALASKA PETROLEUM CO. PREPARED BY *F.R. BELL '1~ ASSOC.' PRUDHOE BA_Y OFFICE DATE' NOV- IS. 1~85 SCALEs I#= 60' DRAWN BY: R.~.T. PRUDHOE BA-Y~ AI. ASKA CHECKEO BY' 8. E. 36 ~8 0 © ._ : :,...-SEC; I ~)o ?0 ~ ~0 I~ 0 15 0 ~7 0 19 0 21 0 25 0 272~© 29 0 56 3~o° 514~0 . '- 5:¢,. 0 575,~ 0 6~590 0 6 0 67 0 RECEIVED ,'~iaska Oil & 6as Cons. 6ornmission Anchorage 36 NO TES' CERTIFICATE OF SURVEYOR · I hearby certify thatl am properly registered and licensed to practice land surveying Jn the State of Alaska end that this plat represents an proposed location for the 'Well numbers shown above- All surveying was done byme or under my supervision~ and that all dimens;ons and details ore correct- DRW. il6-85 SHEET Z of I0 REV. 0 /'49za Indicates well 4~ Indicates Calcblated Section Corner Position Indicates Perpendicular Offset DeD~Scs~tance Indicates Perpendicular Offset i once [perpendicular distance varies tar well 1 PLAT OF MPI PROPOSED 'WELL LOCATIONS LOCATED IN SEC. ;56, T. IZ N., R. 16 E. UMIAT 14. PREPARED FOR SOHIO ALASKA PETROLEUM CO. PREPARED BY 'F.R. BELL '8~ ASSOC. : PRUDHOE BA_Y OFFICE PRUDHOE DA-Y, AI. ASKA DATE' NOV. I~. 1~85 SCALE; I#= 60' DRAWN BY: RJB.T. CHECKED BY' B.E. ' ' I II I _1_ I II ,*r~ I - . X' 2~91BO.TG E'~ 2 Y- 5982579.88 N-~7805353,52 70o21'10.'9814" 147057'24.6257' 1835.43 2168.94 X- 2~904~.49 3' Y- ~982'474.18 N-~80'5322~.98· 70o22'09.9846' 247°~7'20,62~8" " ~936.77 2032.22 E ~. 4641~,6~ X- 2~9~7~.QZ - ~ ~ 4 Y~ 5982~7~.69 N=~780~Oa99- 70o2~'~0,899~" ~47°57'24.7856~ ~B4~,80 2~74.4~ X~ 2~90~.76 E=-~, 464092.74 5 Y~ 5982465, 99: N=~780~9.46 70o2~'09,902~~ ~47°57'20.7857" ~945,~ 20~7,58 X~ 2~9~69,27 E= 464~.9~ 6 . Y~ 598256~,~0 N~f780~48.47 70°2~'~0,8~6B~ ~47°~7'24.94~4~ ~B~2,~7 2~79.88 X- 2~90~0.0~ E~" 46409~,04 ,I 7 Y~ ~9824~7.:B~ N~780~6.94 70°2~'09.8200e ~47°~7'20.94~' ~9~.52 204~.06 X- 2~9~6~.~4 E~ 464~2,24 _ 8 Y= 59825~5.~0 N=,., 7805~4~, 94 70°21'10.7~44" 147°~7'25,105~" 1860,~4 218~,35 x- X~ 2~9 I~7.. 80: ~E~' '464'1'30 , 53 .. 5982547.1 N- TBo 4 .42 70o2 ' 0.652 , 147o57'25.2651' e6e.9 2 90.83 X= 259018.55 E~-~ 464,087"62 11 Y= 5982441,42 N=~7805~I1.89 70°21'09.655~" 147°57'21.265~'' 1970.26 2054,00 X= 2591~2.07 E=~ 464128.83 12 Y= 5982538.92 N=,:780~340.90 70°21'10.5697" 147°57'2~,4250'' 1877.28 2196.30 X= 259012.82 E= 464085.92 1~ Y= 598243~,2~ N= 7805309.3'6 70°21'09.57~0" 147°57'21.4251" 1978.6~ 2059,47 I X= 259146.3~ E= 464127.12 14 Y= 5982530,73 N=' 7805338.37 70°21'10.4874" 147°57'2~,5849" 1885.66 2201,77 X= 259007,08 E= 464084.21 15 Y= 5982425,0~ N= 7805306.84 70021'09.4906" 147°57'21,5850" 1987,00 2064.94 ;';'s~e~:"'::}~:*-~f'~f...~ '~, - ~;..:;:';~:i '-.-~-: --;: ~. - -* ' *" ' '' '~ '-' ' "- -' ~ ' .... *.*' I-"-4 ..... X~ .... 2~9140.60 ~ 46412~'~.42'd ....... ' ..... '*:'~*"*: ............ 16 Y= ~982~22,~4 N=' 780~3~5.85 70°21'10.4051" 147057'25.7447'' 1894,03 2207,24 X~ 259001,35 E= 464082.~0 17 Y= 5982416,84 N= 7805~04.~1 70°21'09.4085" 147°57'21.7449" 1995,~8~ 2070.41 X= 259154,86 E= 464125.71 18 Y= 5982514.~5 N= 7805335.~2 70°21'10,~227'' 147057*25.9046'' 1902,40 2212.71 X= 25899~.61 E=~. 464080.80 19 Y= 5982408.65 N=)~7805501.79 70°21'09.5260" 147°57'21.9047'' 2005.75 2075.89 X= 2591'29,13 E=['~ 464122 O0 20 Y= 5982506.16 N=~7805~0.80 70°21'10,2404" 147°57'26.0644" 1910.77 2218.18 X= 258989.87 E? 464079.09 21 Y= 5982400.46 N=~'7B05299.27 70°21'09,24~6" 147057'22,0646'' 2012.12 2081,36 . X= 259123,39 E=i, 464120,~0 i ~ eec '.*e~~ = LOCATED IN SEC. 36,T. IZN., R.16E. UMIAT M. ocr 281992 ~ z ~,. e~ ~, , PREPARED FOR ~,-~~~~'~ : ' ~nchorage SOH IO ALASKA PETROLEUM CO. 'It%~%. 26919~ '"Sg~ ORW. NO-',6-85 PREPARED BY DATE: NOV. '5,1985 ~a~--..~~ ~ ~ ......... F.R. BELL & ASSOC q~F~c~,~k~~ - 5.CC/ O OT lU ' SCALE: N/A ~'- ~ ..... ~ ~ PRU DHOE BAY OFFICE ~. REV. O PRUDHOE BAY, ALASKA aRAWN a~: R~.T ~ CHECKED BY~.B.E. ..~;43~:~: :Y-::598228~.78.. N- 780~263.93:70°21-;~:08,-0909". 14~.~7,24,3~26"' X- -2~9043..09 E- 464096.41 44 Y- 59B2383.29 N- 7B05292.93 70°21'09.0054" 147°57'28.4623" 2036.36 2300,26~ :4~": Y- 5982277.~9 N- 7805261.'40 '70°21'OB.'OOB6" 147°~7'24~62~" .... 213~7-~7 X= 2~90~7.~6 E= 464094.70 46 Y= 5982375,10 N= 7805290.41- 70°21'08.92~0" 147°57'28.6221" 2044,7~ 2305,73 X= 2~8898.11 E= 4640~1,79 47 Y= 5982269,40 N= 7805258,88 70°21'07,926~" 147°57'24,622~" 2146,'07 2168,91 X= 2~90~1,62 E= 464092,99 48 Ya 5982~66.91. N" 7805287.89 70°21'08.8407" 147°57'28,7820"' 205~,10 2~1,20 X= 2~8892.~7 E= 464050,08 49 Y' 5982261.21 N= 7805256.~5 70°21'07.84~9" 147o57'24.7822" '~ 2154,44 2174,~8 X= 259025,89 E= 464091,29 50 Y= 5982358.71 N= 7805285,3~ 70°21'08,7584" 147°57'28,9~18" 2061,47 2~16,67 X= 258886,6~ E= 464048,~8 51' Y= 598225~,02 N= 7805253,8~ 70°21'07,7616" 147°57'24,9420" 2162,81 2179,86 : ...... X= 259020,15 E= 464089,58 52 Y= 5982J50,52 N= 7805282,84 70°21'08,6760" 147°57'29,1017" 2069,85 2~22,14 X= 2~8880,90 E= 464046,67 5~ Y= 5982244.8~ N= 7805251.~1 70°21'07.679~" 147°57'25. I019'' 2171.19 2185,~3 X= 259014.41 E= 464087,88 54 Y= 5982542.55 N= 7805280.51 70°21'08.5957" 147°57'29.2615'' 2078.22 2527,62 X= 258875.16 E= 464044.~6 55 Y= 5982256.64 N= 7805248.78 70°21'07,5969'' 147°57'25,2617'' 2179.56 2190.80 X= 259008.68 E= 464086.17 56 Y= 5982554.14 N= 7805277.79 70°21'08.5115'' 147°57'29.4214'' 2086.59 2555.09 X= 258869.4~ E= 4640~,26 57 Y= 5982228.44 N= 7805246.26 70°21'07,514~" 147°57'25.4216" 2187.95 2196.27 ,~ ......... X= 259002.94 E= 464084, 4~. .] ......,~:,::.:~,:/-..?::=.:'--.:'- - -.: -:::: :.~ .... ,.. ' ~-", -:~,-., .... -' :. :-.---' 58 Y= 5982525.95 N= 7805275.27 70°21'08.4290" 147°57'29.5812" 2094.96 2558.56 X= 25886~.6~ ~ E= ~6404~.~ I 59 Y= 5982220 25 J N= 7805245'75 70°21'07.4525" 147°57'25.5814'' 2196.50 2201.74 X= 258~97,21 ~ E= 464082.76 60 Y= 5982517.76 N= 7805272.74 70°21'08.5467" 147°57'29.7411" 2105.55 2544.03 X= 258857.96 E= 464059.85 61 Y= 5982212.06 N= 7805241.21 70°21'07.5499" 147°57'25.7415" 2204.67 2207.21 X= 258991.47 E= 464081.05 62 Y= 5~82509,57 N= 7805270.22 70° 21' 08. 2645'' 147°57'29.9009" 2111,71 2549.50 X= 258852,22 E= 464058.14 70°21'07.2676" 147°57'25.9011" 2215.05 2212.6~ 65 Y= 5982205 87 N= 7805258 69 X= 258985:74 [ E= 464079:54 ~ ~ ,~e,,, ~ ~ LOCATED IN SEC. 36,T. IZN.,R. IGE. UMIAT M. -~:...~ '-. ~ II ~-- ~e -.~e~ee~.~~.. · ~. ~cho~~ q~oFE~S~K~~ SHEET 5 0f I0 PREPARED FOR SOHIO ALASKA PETROLEUM CO. PREPARED BY DATE: NOV. 15, 19851 F.R. BELL 8~ ASSOC. SCALE' N/A PRUDHOE BAY OFFICE BA";ALAS."'T~ Ir~ DRAWN BY : R.G.1 . PRUDHOE cHECKED BY: B.E- REV. o in [ [1 _ . WELL ASP ZONE 3 UTN ZONE 6 LATITUDE LONGITUDE DIGT~) · , . 64 Y" 59Ei23;01,38 'N- 7805267,69 70°21'08. t820" [47°57'30,060B" 2t20.08 2~.97 , . X" 258846.48 E' 4640~6.43 65' Y" 5982195,68 N" 780523~.16 70°21'07,1852'" 147657'26,0610" 2221,43 221B, X" 258980,00 E-- -464077,64 66 Y- 5982293.18 N= 7805265.~7 70021'08.0997" 147°57'30,2206" 212B.45 2~60,45 X~ 258B40.75 E~ 4640~.7~ 67 Y= 59~2~87.49 N~ 7B052~,6~ 70°21'07.~029'' ~47°57'26.220~'' 22'29,B0 222~.63 X~ 258974,26 E= 46~07~,95 68 Y~ ~992284.99 N~ 7~05262.64 70°21'08.017~" 147o57'30.5B05" 2~56'.B2 2~65.92 X- 2~8~5,01 E= ~6403~.02 . '69 Y- 5982179,30 N~ 7B052~1,~ 70021'07.0206'' 147°57'26,~807" 2238,~7 2229.10 X- 258968.55 E~ 464074.2~ 70 Y~ 5982276.80 N- 7B05260.~2 70°21'07,9350'' ~47°57'30.540~" 2145.19 2~7~.~9 X- 2~8829.28 E- 46405~,~ ................... ~ ,. ::,- .... .... . -~...,-.. .~.., . . ~~ O~ A~ t- LOCATED IN SEC. S6,T. IZN.,R. 16 E. UMIATN. ~.. Alaska. Oil & Gas Coils, Gommiss' 3~ P R E P A R E D F 0 R so,,o f.~ ~ ........ ~ ~ DRW NO 116-85 PREPARED BY DATE: NOV. I~, 1985 F.R. BELL ASSOC. SCALE: N/A ~. ~~ ~ PRUDHOE BAY OFFICE I -- R~. 0 PRUDHOE BAY~A.bASKA DRAWN eY: R.~Z. , CHECKED BY: ~E- i i ~t 77, /~7, ? State: Alaska Borough: Well: 2-12/Q-16 Field: Endicott St. Perm; 92-117 Date 11!19!92 Engr: M. Minder DIU~i-16.EXL Casing Interval interva! Size ~ Top L~ lA 13.375 35 2A 9.625 SA 9.625 4A 7 5A 0 6A 0 7A 0 8A 0 9A 0 10A 0 Descriptk3n Descri~ion Desc¢iption Tension Lbs Grade Thread Lbs 68 NT80C BTC 0 8500 35 8724 47 NTS0-S NSCC 0 9651 8500 1313 47 NT95HS NSCC 0 10291 ~~0~ ~(~0 '~E'~' 2913CR800 ~$ 0 0 NSCC0 00 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Mud Hydraulic Wieght Gradient ppg psiftt 1B 9.5 0.494 2t9 10.2 0.530 319 10.2 0.530 4B 9.8 0.510 5B 0.0 0.000 619 0.0 0.000 7B 0.0 0.000 8B 0.0 0.000 9B 0.0 0.000 1 OB 0.0 0.000 3900 3900 3900 0 0 0 0 0 0 8160 2.1 ~YD 0 #DIVIO.I 0 #DIV/O! 0 #DIV/O! 0 #DIV/0! 0 #DIV/0! 0 #DIV/0! Tension Strength K/Lbs K/Lbs 1C 187.68 1556 2C 410.028 1086 3C 61.711 1289 4C 25.085 5C 0 6C 0 7C 0 8C 0 9C 0 10C 0 'I'DF 8.29 2.65 20.89 676 26.95 0 #DNIOI. 0 #DIViO! 0 #DIVIO! 0 #DIVlO! 0 #DR/lO! 0 #DIVKI! Collapse Collapse Pr-Bot-Psi Resist. CBF 1361 2260 1.660 4508 4750 1.054 5119 7150 1.397 5244 7020 1.339 0 0 #DlVlO! 0 0 #DIV/0! 0 0 #DIV/0! 0 0 #DIVI0! 0 0 #DIV/0! 0 0 ENDICO' r MP! 2-12/Q-16 CEMEN. PROGRAM 13 :3/8" SURFACE CASING CASING SIZE: 13 3/8", 68# CIRC. TEMP: 60°F LEAD CEMENT TYPE: TYPE 'E' PERMAFROST ADDITIVES: n/a WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx APPROX #SACKS: 585 PUMP TIME: 4:30 hrs MiX WATER: 11.63 gps FW Mix water temp: 50-65F TAIL CEMENT TYPE; CLASS G ADDITIVES: 2% Calcium Chloride WEIGHT: 15.8 ppg YIELD:1.16 ft3/sx APPROX #SACKS: 625 PUMP TIME: 4 hrs MIX WATER: 5.00 gps FW Mix water temp: 50-65 TOP JOB CEMENT TYPE: TYPE "C" PERMAFROST (if necessary) ADDITIVES: n/a WEIGHT: 15.6 ppg YIELD:0.94 ft3/sx MIX WATER: 3.5 gps FW APPROX #SACKS: 250 PUMP TIME: 2:30 hrs Mix water temp: 50-65 . SPACER.: 100 bbls fresh water ahead of lead slurry. The WATER temperature should be 50-65F CEMENT VOLUME 1. Lead'slurry to surface w/40% excess. 2. Tail slurry volume 625 sx 3. Top job volume +/- 250 sx. 9 5/8" INTERMEDIATE CASING CASING ~IZE; 9 5/8", 47# CIRC. TEMP 135°F LEAD CEMENT TYPE; Class 'G' WEIGHT: 12.0 ppg APPROX #SACKS: 575 TAIL CEMENT TYPE: CLASS'G WEIGHT: 15.8 ppg APPROX #SACKS: 200 YIELD:3.24 ft3/sx PUMP TIME: 4:30 hrs YIELD:1.15 ft3/sx PUMP TIME: 4 hrs MIX WATER: 11.63 gps FW Mix water temp: 50-65F MIX WATER: 5.00 gps FW Mix water temp: 70-80 F SPACERS: Pump 20 bbls ARCO Preflush; 50 bbls ARCO spacer @ 11 ppg. OTHER CONSIDERATIONS; Continuously mix lead and tail slurries. CEMENT VOLUME 1. Lead Slurry is designed to cover Cretaceous injection interval. 2. Tail Slurry to 500' MD above shoe w/30% excess. 7" LINER CASING SIZE: 7", 26# CIRC. TEMP: 135° F Displace at 12-15 bpm. g£C£1v£b CEMENT TYPE: CLASS G WEIGHT: 15.8 ppg yIELD'I.20 ft3/sx MIX WATER: 5.0 gps APPROX #SACKS: 280" PUMP TIME: 3:30 hrs + 1 hr mixing @sUrface Mix water temp: 70-80 F PREFLUSH: 20 bbls ARCO preflush SPACER: 50 bbls ARCO spacer weighted to 11 ppg OTHER CONSIDERATIONS: Batch mix the cement slurry. Perform fluid loss test on the batch mixed slurry. Fluid loss should be 20-30cc. Displace @ 8-10 bpm. LINER CEMENT VOLUME Calculated volume+ 100% excess. ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS APPROVE DATE ['2 ~hru (3) Admin ~.?z' ,~//~,~/~ ~_ 9. ['9 -thru' 13 ] ' 10. ~,~.~<' //-./~-.~ z--- 11. [10 & 13] 12. 13. [14 thru 22] (5) BOPE /~'~I [23 thru 28] (6) Other [2-9 thru ~i] (7) Contact (8) Addl ,-}/-~1~-~t~__. eng i nee r i ng: MTM ~ RAD~ ~' ~t -_ geology' DWJ RPC~ rev 08/18/92 jo/6.011 Company YES 1. Is permit fee attached ............................................... ~ 2 Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... L Lease $ We 1 1 ~ /~.42/-- ,~ y~ ._~ ,~ .~ /~)~. NO REMARKS . 4. Is well located proper distance from other wells ..................... ~ 5. Is sufficient undedicated acreage available in this pool ............. X 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. ~ 8. Can permit be approved before 15-day wait ............................ -~- 4 conductor st r ing prov i ded ......................................... ~ 1 surface casing protect all zones reasonably expected serve as an underground source of drinking water .................. _~ enough cement used to circulate on conductor & surface ............ ~ Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease n~nber appropriate .......................................... Does well have a unique name $ n~nber ................................ 14. Is 15. Wil to 16. Is 17. Wil 18. Wil 19. Wil 20. Is 21. Is 22. Is 23. Is 24. 25. 26. 27. 28. 1 cement tie in surface & intermediate or production strings ...... 1 cement cover all known productive horizons ..................... 1 all casing give adequate safety in collapse, tension, and burst. well to be kicked off from an existing wellbore ................... old wellbore abandonment procedure included on 10-403 ............. adequate wellbore separation proposed ............................. a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of :i~mm~t~l~ BOPE attached .... Does BOPE have sufficient pressure rating -- test to ._ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: 29. Are data presented on potential overpressure zones ................... 30. Are seismic analysis data presented on shallow gas zones ............. 31. If offshore loc, are survey results of seabed conditions presented... 32. Name and phone number of contact to supply weekly progress data ...... 33. Additional requirements INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA :~ SHORE '6 </ Additional remarks' ~ 197 C lT~o · 0 --I ITl Z