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Home My WebLink About180-1201. 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: Water Wash 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 12,537 5.5' Spinner tool @ 12,133' ELMD Casing Collapse Conductor 5,200psi Surface 2,670psi Intermediate 4,760psi 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 C.O. 462.007 ENDICOTT 5-1/2" TIW Packer and 7" Otis RPB SSSV 10,842' MD / 8,928' TVD and 1,631' MD / 1,631' TVD NA 12,522' See Schematic 907-564-4763 aras.worthington@hilcorp.com Operations Manager March 25, 2025 5-1/2" Perforation Depth MD (ft): See Schematic 120' 20" 13-3/8" 9-5/8" 2,673' 7"1,503' 11,554' 5,380psi 6,870psi 2,673' 9,497' 10,270' 2,673' 11,554' 120' 120' 17# / L-80 TVD Burst 10,975' MD 1,530psi 8,160psi Hilcorp Alaska, LLC Length Size Proposed Pools: 10,282 12,475 10,232 2,900 ENDICOTT OIL Same STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0312828 180-120 DUCK IS UNIT MPI 5-01 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-20518-00-00 PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: 26# / L-80 Tubing MD (ft): 10,749'Perforation Depth TVD (ft): Aras Worthington 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: 7" and Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-129 By Gavin Gluyas at 9:36 am, Mar 07, 2025 Digitally signed by Justus Hinks (3691) DN: cn=Justus Hinks (3691) Reason: I attest to the accuracy and integrity of this document Date: 2025.03.06 17:03:03 -09'00' Justus Hinks (3691) A.Dewhurst 12MAR25 JJL 3/11/25 DSR-3/10/25 10-404 *&: 03/13/25 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.03.13 14:03:58 -08'00' RBDMS JSB 031825 Gas Injector Water Wash Well: 5-01 PTD: 180-120 API: 50-029-20518-00 1 Well Name:END 5-01 API Number:50-029-20518-00 Current Status:Operable Gas Injector Estimated Start Date:03/25/2025 Rig:N/A Reg. Approval Req’d?10-403 Date Reg. Approval Received: Regulatory Contact:Darci Horner Permit to Drill Number:180-120 First Call Engineer:Aras Worthington 907-440-7692 (M) Second Call Engineer:Ryan Thompson 907-301-1240 (M) Gas Injection Rate: ~100,000 Mscf/Day Injection Pressure: 4,000 psi Reservoir Pressure (Estimate): 3900 psi Program Objective: Water washes are designed to dissolve salts and asphaltenes in the tubing and formation. The objective is to perform a tubing water wash to increase injectivity and perform a general maintenance on Endicott gas injection wells. Proposed Program: Pump diesel followed by Fresh Water and Surfactant as per attached pumping template. Gas Injector Water Wash Well: 5-01 PTD: 180-120 API: 50-029-20518-00 2 Gas Injector Water Wash Well: 5-01 PTD: 180-120 API: 50-029-20518-00 3 Gas Injector Water Wash Well: 5-01 PTD: 180-120 API: 50-029-20518-00 4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 5-01 DUCK IS UNIT MPI 5-01 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 5-01 50-029-20518-00-00 180-120-0 G SPT 8941 1801200 2750 3880 3877 3877 3877 160 159 160 158 REQVAR P Bob Noble 8/19/2024 MIT-IA as per AIO 1.007 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 5-01 Inspection Date: Tubing OA Packer Depth 740 3258 3246 3243IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240820140125 BBL Pumped:5 BBL Returned:5 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 9 9 999 99 99 9 9 9 MIT-IA as per AIO 1.007 James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 12:38:13 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 29, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 5-01 DUCK IS UNIT MPI 5-01 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/29/2023 5-01 50-029-20518-00-00 180-120-0 G SPT 8941 1801200 2750 2275 2835 3174 3220 164 162 165 165 REQVAR P Bob Noble 8/5/2023 AIO 1.007, MIT-IA to a min of 2750 psi. 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 5-01 Inspection Date: Tubing OA Packer Depth 712 3004 2981 2976IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN230810135257 BBL Pumped:5.2 BBL Returned:3.9 Friday, September 29, 2023 Page 1 of 1 9 9 9 9 9 9 99 9 9 9 9 9 9 AIO 1.007, James B. Regg Digitally signed by James B. Regg Date: 2023.09.29 13:11:54 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, September 1, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Lou Laubenstein P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 5-01 DUCK IS UNIT MPI 5-01 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/01/2022 5-01 50-029-20518-00-00 180-120-0 G SPT 8941 1801200 2750 3783 3785 3786 3788 120 120 120 120 REQVAR P Lou Laubenstein 8/8/2022 Yearly MIT-IA to 2750 psi per AIO 1.007. 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 5-01 Inspection Date: Tubing OA Packer Depth 1417 3036 3036 3036IA 45 Min 60 Min Rel Insp Num: Insp Num:mitLOL220808122316 BBL Pumped:2.7 BBL Returned:2.7 Thursday, September 1, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 Yearly MIT-IA AIO 1.007. James B. Regg Digitally signed by James B. Regg Date: 2022.09.01 14:07:34 -08'00' 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Water Wash 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 12,537'feet N/A feet true vertical 10,282'feet 12,133 feet Effective Depth measured 12,475'feet 10,842 feet true vertical 10,232'feet 8,928 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 7" 26# / L-80 10,749' MD 8,854' TVD Tubing (size, grade, measured and true vertical depth)5-1/2" 17# / L-80 10,975' MD 9,033' TVD 10,842' MD 8,928' TVD Packers and SSSV (type, measured and true vertical depth)7" Otis RPB SSSV 1,631' MD 1,631' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Contact Email: Authorized Title:Operations Manager Contact Phone: 7,020psi 5,380psi 6,870psi 8,160psi Burst 1,530psi Collapse 5,200psi 2,670psi 4,760psi 2,673' 9,497' 10,270'12,522' measuredPlugs Junk measured N/A Length 120' 2,673' 11,554' Size Surface Intermediate Liner 20" 13-3/8" 9-5/8" 7"1,503' Casing STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 180-120 50-29-20518-00-00 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0312828 ENDICOTT / ENDICOTT OIL Hilcorp Alaska LLC 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: DUCK IS UNIT MPI 5-01 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 0 77798,134 0 4,450 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 120' 2,673' 11,554' 1,885 Conductor TVD 120' 322-324 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 88,335 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 3,503 Joleen Oshiro joleen.oshiro@hilcorp.com 907-777-8486 5-1/2" TIW Packer L G Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Meredith Guhl at 9:51 am, Jul 19, 2022 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2022.07.19 07:44:51 -08'00' Torin Roschinger (4662) Well Name Rig API Number Well Permit Number Start Date End Date END 5-01 Fullbore 50-029-20518-00-00 180-120 7/4/2022 7/4/2022 Water Wash. Pumped 10 bbls 60/40, 50 bbls 120*F Diesel, 422 bbls .2% surfactant water then SD and soaked for 2 hours. Over flushed with 127 bbls surf. Water and a 56 bbl diesel freeze protect. Traveled to COTU to load diesel for tomorrow's water washes. 7/4/2022 - Monday Hilcorp Alaska, LLC Weekly Operations Summary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y Samantha Carlisle at 1:18 pm, May 26, 2022 'LJLWDOO\VLJQHGE\7RULQ 5RVFKLQJHU '1FQ 7RULQ5RVFKLQJHU RX 8VHUV 'DWH 7RULQ5RVFKLQJHU ; 0*50$<'/%'65 -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.06.02 15:30:02 -08'00' RBDMS SJC 062722 'ĂƐ/ŶũĞĐƚŽƌtĂƚĞƌtĂƐŚ tĞůů͗ϱͲϬϭ Wd͗ϭϴϬͲϭϮϬϬ W/͗ϱϬͲϬϮϵͲϮϬϱϭϴͲϬϬ ϭ tĞůůEĂŵĞ͗EϱͲϬϭ W/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϬϱϭϴͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗'ĂƐ/ŶũĞĐƚŽƌ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ϲͬϮϴͬϮϮ ZŝŐ͗Eͬ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍ϭϬͲϰϬϯ ĂƚĞZĞŐ͘ƉƉƌŽǀĂů ZĞĐĞŝǀĞĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ĂƌĐŝ,ŽƌŶĞƌ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϭϴϬͲϭϮϬϬ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗:ŽůĞĞŶKƐŚŝƌŽ Ğůů͗ϲϱϬͲϰϴϯͲϰϳϳϰ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗:ĞƌŝŵŝĂŚ'ĂůůŽǁĂǇ Ğůů͗ϴϮϴͲϱϱϯͲϮϱϯϳ 'ĂƐ/ŶũĞĐƚŝŽŶZĂƚĞ͗Εϵϱ͕ϬϬϬDƐĐĨͬĂǇ /ŶũĞĐƚŝŽŶWƌĞƐƐƵƌĞ͗ϰ͕ϰϱϬƉƐŝ ZĞƐĞƌǀŽŝƌWƌĞƐƐƵƌĞ;ƐƚŝŵĂƚĞͿ͗ϯϵϬϬƉƐŝ WƌŽŐƌĂŵKďũĞĐƚŝǀĞ͗ tĂƚĞƌǁĂƐŚĞƐĂƌĞĚĞƐŝŐŶĞĚƚŽĚŝƐƐŽůǀĞƐĂůƚƐĂŶĚĂƐƉŚĂůƚĞŶĞƐŝŶƚŚĞƚƵďŝŶŐĂŶĚĨŽƌŵĂƚŝŽŶ͘dŚĞŽďũĞĐƚŝǀĞŝƐƚŽ ƉĞƌĨŽƌŵĂƚƵďŝŶŐǁĂƚĞƌǁĂƐŚƚŽŝŶĐƌĞĂƐĞŝŶũĞĐƚŝǀŝƚǇĂŶĚƉĞƌĨŽƌŵĂŐĞŶĞƌĂůŵĂŝŶƚĞŶĂŶĐĞŽŶŶĚŝĐŽƚƚŐĂƐŝŶũĞĐƚŝŽŶ ǁĞůůƐ͘ WƌŽƉŽƐĞĚWƌŽŐƌĂŵ͗ WƵŵƉĚŝĞƐĞůĨŽůůŽǁĞĚďǇ&ƌĞƐŚtĂƚĞƌĂŶĚ^ƵƌĨĂĐƚĂŶƚĂƐƉĞƌĂƚƚĂĐŚĞĚƉƵŵƉŝŶŐƚĞŵƉůĂƚĞ͘ '/% 'ĂƐ/ŶũĞĐƚŽƌtĂƚĞƌtĂƐŚ tĞůů͗ϱͲϬϭ Wd͗ϭϴϬͲϭϮϬϬ W/͗ϱϬͲϬϮϵͲϮϬϱϭϴͲϬϬ Ϯ 'ĂƐ/ŶũĞĐƚŽƌtĂƚĞƌtĂƐŚ tĞůů͗ϱͲϬϭ Wd͗ϭϴϬͲϭϮϬϬ W/͗ϱϬͲϬϮϵͲϮϬϱϭϴͲϬϬ ϯ 'ĂƐ/ŶũĞĐƚŽƌtĂƚĞƌtĂƐŚ tĞůů͗ϱͲϬϭ Wd͗ϭϴϬͲϭϮϬϬ W/͗ϱϬͲϬϮϵͲϮϬϱϭϴͲϬϬ ϰ MEMORANDUM TO: Jim Regg < t ('S I7�z( P.I. Supervisor�� FROM: Brian Bixby Petroleum Inspector I Well Name DUCK IS UNIT MPI 5-01 IInsp Num: mitBDB210820145202 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, August 23, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC 5-01 DUCK IS UNIT MPI 5-01 Src: Inspector Reviewed By P.I. Supry ��Fg_ Comm API Well Number 50-029-20518-00-00 Inspector Name: Brian Bixby Permit Number: 180-120-0 Inspection Date: 8/20/2021 ,, Packer Well 5-01 Type Inj ! c 'TVD PTD1801200 Type Test SPT Test psi BBL Pumped: 2.5 BBL Returned: _J Interval REQVAR WF Notes' Yearly MITIA as per A10 1.007 J Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 8941 Tubing 4373. 4376 - 4395 4387 - 2750 IA 1551 3045 29% — 2976 3.5 OA 150 - 150 150 150 ' P Monday, August 23, 2021 Page 1 of 1 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1801200 Type Inj G Tubing 4373 4376 4395 4387 Type Test P Packer TVD 8,928'BBL Pump 2.5 IA 1551 3045 2996 2976 Interval V Test psi 2750 BBL Return 3.5 OA 150 150 150 150 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: Hilcorp Alaska, LLC Endicott / DIU / MPI Brian Bixby Joshua Green 08/20/21 Notes:Yearly MIT-IA to 2750 psi per AIO 1.007. Notes: Notes: Notes: 5-01 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Form 10-426 (Revised 01/2017)MIT END MPI 5-01 8-20-2021 Wallace, Chris D (CED) From: David Gorm <dgorm@hilcorp.com> Sent: Friday, January 15, 2021 9:48 AM To: Wallace, Chris D (CED) Subject: END 5-01 (PTD: 180-120) Chris, We have completed our slickline work re -setting the SSSV on END 5-01. We have confirmed at this time that we have isolated the known TBGxlA communication. The well is online injecting gas. Please let me know if you have any questions. Thanks, David Gorm Operations Engineer Hilcorp Alaska Office: 907-777-8333 Cell: 505-215-2819 From: David Gorm Sent: Tuesday, January 12, 20218:26 AM To:'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Subject: END 5-01 (PTD: 180-120) Chris, Sending notice that we have observed a change in the IA pressure communication trend on END 5-01 (gas injector) requiring bleeds. This well has the existing AA with known potential for IA communication from the control line at the SSSV. We are planning to get a SL unit on the well as soon as the weather calms down this week Saturday to pull and reset the SSSV to reduce the communication to the IA. This has been the normal remediation for this well with success in isolating the communication lasting 6 -9 months. The last time we re -set the SSSV was in July 17 2020. Please let me know if you have any questions. Thanks, David Gorm Operations Engineer Hilcorp Alaska Office: 907-777-8333 Cell: 505-215-2819 The information contained in this email message is confidential and maybe 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 MEMORANDUM TO: Jim Regg _ P.I. Supervisor 1\e2sj FROM: Guy Cook Petroleum Inspector Well Name DUCK IS UNIT MPI 5-01 Insp Num: mitGDC200818110056 Rel Insp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, August 21, 2020 SUBJECT: Mechanical Integrity Tests liilco p Alaska, LLC 5-01 DUCK IS UNIT MPI 5-01 Src: Inspector Reviewed B P.I. Suprv!l ,r_ NON -CONFIDENTIAL Comm API Well Number 50-029-20518-00-00 Inspector Name: Guy Cook Permit Number: 180-120-0 Inspection Date: 8/18/2020 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min T e In G . —9- 3 Well 5 01 yp J g 4310 - 4312 4311 -, 4313 ' TVD 8941 TUbin 4319 4314 PTD 1 1801200 2750ypp[ 1225 3059 3067 3086 3093 3096 . BBL Pumped 33 BBL Ret , - urned: 3.3 OA - i - _ -- ----- � 150 150 150 � 150 � 150 150" Interval REQVAR - P/F I Notes: Pearly MITIA to 2750 psi per AIO 1.007. The test was performed with a triplex pump, a bleed trailer and calibrated gauges. The well was flowing at 206 degrees Fahrenheit and the diesel they used to test with was at 41 degrees Fahrenheit. The test went for an hour and a halftotal and the pressure never stopped rising. The IA Qressure at 75 minutes was 3101 and at 90 minutes was 3106. The OA stayed at 150 for the entire tes and t e tubing was 4313 at 75 minutes and 4315 at 90 minutes. Friday, August 21, 2020 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Guy Cook Petroleum Inspector I Well Name DUCK IS UNIT MPI 5-01 Insp Num: mitGDC200820113046 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, August 21, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC 5-01 DUCK IS UNIT MPI 5-01 Src: Inspector Reviewed By� P. I. Supry IJI Comm API Well Number 50-029-20518-00-00 Inspector Name: Guy Cook Permit Number: 180-120-0 Inspection Date: 8/20/2020 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 5-01 Type InjT G "IwD t 8941 Tubing -4260 ' 4260- 4257• 4260' PTD L 1801200 (Type Testi SPT iTest psi 2750 IA 1269 3077 - 3037 3021 - BBL Pumped: 3.5_ BBL Returned: 3.4 - OA 172 171 171 - 172 IntervalREQVAR �p/F P - -- L/ I --.. Notes: Yearly MITIA to 2750 per A10 1.007. This is the second attempt for this well to pass. The last test was inconclusive. Testing was done with a Little Red Services pump truck and calibrated gauges. The diesel was heated close to the temperature of the well to help eleminate thermal expansion of the fluid pumped. Friday, August 21, 2020 Page 1 of 1 Wallace, Chris D (CED) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Monday, October 21, 2019 3:40 PM To: Wallace, Chris D (CER) Subject: RE: END 5-01 PTD # 1801200) TIO Monitoring Attachments: END 5-01 TIO.xlsx Hello Chris, Admin Approval gas injection well END 5-01 (PTD #1801200)'s downhole injection valve was recently reset following an increase in IA pressurization. Following the reset, IA pressurization has been minimized with no additional bleeds required. A TO plot is attached for reference. Going forward, Hilcorp plans to leave the well on injection. Please let me know if you have any questions. Thank You, Wyatt Rivard I Well Integrity Engineer I Hilcorp Alaska, LLC 0: (907) 777-8547 1 C: (509)670-80011 wrivarciftilcoro com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 From: Wyatt Rivard Sent: Thursday, September 19, 2019 4:32 PM To: 'Wallace, Chris D (CED)' <chris.waIlace @alaska.gov> Subject: END 5-01 (PTD # 1801200) Injection Valve Changeout Hello Chris, Endicott gas injector END 5-01 (PTD # 1801200) operates under Admin Approval 1.007 for TxIA communication. Over the years, the TxIA communication has been demonstrated to occur through the SSSV control line which can be largely isolated with the downhole injection valve. Following a well shut-in during an ongoing plant turnaround, the well's IA pressurization recently increased suggesting the downhole injection valve may need to be reset (TIO Plot attached). While pressurization has increased, it remains within historic norms for the well while operating under the AA. With the ongoing TAR providing an opportunity to shelter downtime, Hilcorp plans to pull and reset the injection valve. Once reset, we plan to return the well to injection. If IA pressurization should increase over historic norms, or at indication of any other change in mechanical condition, Hilcorp will shut-in and notify AOGCC. Please let me know if you have any questions. Thank You, Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska, LLC 0: (907) 777-8547 1 C: (509)670-80011 wrivard(&hilcoru com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 Wallace, Chris D (CED) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Thursday, September 19, 2019 4:32 PM To: Wallace, Chris D (CED) Subject: END 5-01 (PTD # 1801200) Injection Valve Changeout Attachments: END 5-01 TIO.XLS Hello Chris, Endicott gas injector END 5-01 (PTD # 1801200) operates under Admin Approval 1.007 for TxIA communication. Over the years, the TxIA communication has been demonstrated to occur through the SSSV control line which can be largely isolated with the downhole injection valve. Following a well shut-in during an ongoing plant turnaround, the well's IA pressurization recently increased suggesting the downhole injection valve may need to be reset (TIO Plot attached). While pressurization has increased, it remains within historic norms for the well while operating under the AA. With the ongoing TAR providing an opportunity to shelter downtime, Hilcorp plans to pull and reset the injection valve. Once reset, we plan to return the well to injection. If IA pressurization should increase over historic norms, or at indication of any other change in mechanical condition, Hilcorp will shut-in and notify AOGCC. Please let me know if you have any questions. Thank You, Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska, LLC 0: (907) 777-8547 1 C: (509)670-80011 wrivarciftilcorp.com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 The information contained in this e-mail message is confidential information intended only for the use of the recipients) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. 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. MEMORANDUM TO: Jim Regg [ P.I. Supervisor �C'�jC3 FROM: Bob Noble Petroleum Inspector Well Name DUCK IS UNIT MPI 5-01 IInsp Num: mitRCN190820150756 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, August 22, 2019 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska LLC 5-01 DUCK IS UNIT MPI 5.01 Ste: Inspector Reviewed BX,.�OO P.I. Supry Comm API Well Number 50-029.20518-00-00 Inspector Name: Bob Noble Permit Number: 180-120-0 Inspection Date: 8/20/2019 — Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Type Inj c TVD 2751 -!Tubing nee i 4191, PTD 1s012oo TYPeTest SPT Testpsi 2750 IA I'll _ooi Asn - >_sn BBL Pumped: 2,5 BBL Returned: 2.6 - OA iso 181 - i2, 121 aEQvAe P/F P Interval Notes: AIO NO. 1.007, MIT -IA once a year to 2750 psi. Thursday, August 22, 2019 Page I of I Wallace, Chris D (CED) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Monday, July 29, 2019 1:57 PM To: Wallace, Chris D (CED) Subject: END 5-01 (PTD # 1801200) Postponed MIT -IA Attachments: 5-01 TIO.xlsx Hello Chris, As discussed, we will plan to postpone the MIT -IA for END 5-01 (PTD # 1801200), due in July, for up to one month for consideration of Hilcorp's request to reduce the required test pressure under the existing AA (AIO 1.007) to 2750 psi. The well has been on stable injection since change out of the downhole injection valve in March 2019 with no indication of IA pressurization or change in well integrity since the successful valve set (TIO plot attached). Thank You, Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska, LLC 0: (907) 777-8547 1 C: (509)670-80011 wrivardPhilcorn corn 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 The information contained in this e-mail message is confidential information intended only for the use of the recipients) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. 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 massage 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. Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Thursday, April 25, 2019 9:01 AM To: Roby, David 5 (DOA); Wallace, Chris D (DOA) Subject: RE: END 5-01 (PTD # 1801200) Monitoring Results Attachments: 5-01 TIO 4-25-19.xlsx Chris/Dave, Admin Approval gas injection well END 5-01 (PTD # 1801200)'s injection valve was swapped out on 3/16/18 with slickline. Since changing out the injection valve, IA pressurization has been minimized with no additional bleeds required. A TIO plot is attached for reference. Going forward, Hilcorp plans to leave the well on injection. Please let me know if you have any questions. Thank You, Wyatt Rivard I Well Integrity Engineer lHilcorp Alaska, LLC 0: (907) 777-8547 1 C: (509)670-80011 wrivard0hilcorp.com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 From: Wyatt Rivard Sent: Friday, March 22, 2019 10:50 AM To: Roby, David S (DOA) <dave.roby@alaska.gov>; Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Subject: END 5-01 (PTD # 1801200) Remain on Injection For Monitoring Dave/Chris, END 5-01 (PTD # 1801200)'s injection valve was swapped out on 3/16/18 with slickline. Since changing out the injection valve, the well has experienced no additional IA pressurization or bleeds. A TIO plot is attached for reference. It appears that the new MCX successfully isolated the subsurface control line. Going forward, Hilcorp will monitor the well on injection for a 28 day monitoring period to confirm that IA pressurization has been minimized. Thank You, Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska, LLC 0: (907) 777-8547 1 C: (509)670-80011 wrivard@hilcorp.com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 From: Roby, David S (DOA) [mailto:dave.robv@alaska.gov] Sent: Friday, March 8, 2019 2:07 PM To: Wyatt Rivard<wrivard@hilcorp.com> Cc: Wallace, Chris D (DOA) <chris.wallace@alaska.gov>; Regg, lames B (DOA) <iim.regg@alaska.gov>; Schwartz, Guy L (DOA) <guy.schwartz@alaska.¢ov>; Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Rixse, Melvin G (DOA) <melvin. rixse@a laska.gov> Subject: [EXTERNAL] RE: END 5-01 (PTD # 1801200) Request to Remain on Injection with Increased Bleed Frequency Wyatt, Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Friday, March 22, 2019 10:50 AM To: Roby, David S (DOA); Wallace, Chris D (DOA) Subject: END 5-01 (PTD # 1801200) Remain on Injection For Monitoring Attachments: 5-01 TIO.xlsx Dave/Chris, END 5-01 (PTD # 1801200)'s injection valve was swapped out on 3/16/18 with slickline. Since changing out the injection valve, the well has experienced no additional IA pressurization or bleeds. A TIO plot is attached for reference. It appears that the new MCX successfully isolated the subsurface control line. Going forward, Hilcorp will monitor the well on injection for a 28 day monitoring period to confirm that IA pressurization has been minimized. Thank You, Wyatt Rivard I Well Integrity Engineer lHilcorp Alaska, LLC 0: (907) 777-8547 1 C: (509)670-80011 wrivard(ahilcoro com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 From: Roby, David S (DOA) [mailto:dave.roby@alaska.gov] Sent: Friday, March 8, 2019 2:07 PM To: Wyatt Rivard <wrivard@hilcorp.com> Cc: Wallace, Chris D (DOA) <chris.wallace@alaska.gov>; Regg, James B (DOA) <jim.regg@alaska.gov>; Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov>; Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Rixse, Melvin G (DOA) <melvin.rixse @alaska.gov> Subject: [EXTERNAL] RE: END 5-01 (PTD # 1801200) Request to Remain on Injection with Increased Bleed Frequency Wyatt, Your request to keep operating this well as indicated below for up to two weeks, until you can repair it with a slickline unit, is hereby approved. Let us know if anything about the operating condition of the well changes. Regards, Dave Roby 907-793-1232 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 Dave Roby at 907- 793-1232 or dave.robv@alaska.eov. From: Wyatt I rd hilcor .com> Sent: Friday, March 8, 2019 11:3 To: Roby, David S (DOA) <dave.robv@alaska.¢o Cc: Wallace, Chris D (DOA) <chris.wallace@alaska.¢ov> Subject: END 5-01 (PTD # 1801200) Request to Remain on Injection with Increased Bleed Frequency Loepp, Victoria T (DOA) From: Sent: To: Cc: Subject: Follow Up Flag: Flag Status: Wyatt, /p 7'D /90 /Q O Roby, David 5 (DOA) Friday, March 8, 2019 2:07 PM Wyatt Rivard Wallace, Chris D (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Loepp, Victoria T (DOA); Rixse, Melvin G (DOA) RE: END 5-01 (PTD # 1801200) Request to Remain on Injection with Increased Bleed Frequency Follow up Flagged Your request to keep operating this well as indicated below for up to two weeks, until you can repair it with a slickline unit, is hereby approved. Let us know if anything about the operating condition of the well changes. Regards, Dave Roby 907-793-1232 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 Dave Roby at 907- 793-1232 or dave.robv@alaska.¢ov. From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Friday, March 8, 2019 11:36 AM To: Roby, David S (DOA) <dave.roby@alaska.gov> Cc: Wallace, Chris D (DOA) <chris.waIlace @alaska.gov> Subject: END 5-01 (PTD # 1801200) Request to Remain on Injection with Increased Bleed Frequency Hello Dave, Endicott gas injector END 5-01 (PTD # 1801200) operates under Admin Approval 1.007 for TxIA communication. The well recently experienced an increased IA bleed frequency that Hilcorp believes is due to diminished isolation of the downhole injection valve and not a change to the well's tubing or packer integrity. Hilcorp would like to leave the well online for up to two weeks until slickline can change out the injection valve. Background 5-01's downhole injection valve isolates the subsurface safety valve control line that is believed to be the leak path for the well's one way TxIA communication under gas. Following the last injection valve reset on 8/11/17 the well has had virtually no IA pressurization indicating a very good set of the valve. Recently, it appears that the injection valve seals have lost isolation of the control line and IA pressurization has resumed. Bleeds roughly every 1-2 days are required to maintain IA pressure below the AA specified 2500 psi. This represents a change in the well's recent integrity, however this bleed frequency is in line with what we have seen historically at times when the MCX was not well set. Mitigations: • Endicott well operators physically conduct twice daily monitoring of END 5-01 and are able to monitor the IA pressure remotely through SCADA at all times. • The well's IA pressure remains manageable under bleeds. • As per A1O1.007, an automatic alarm is triggered if IA pressure exceeds 2200 psi with an automatic shut-in occurring at below 2500 psi (last tested 5/6/17). Request: END 5-01 is the largest gas injector at Endicott and is important for maintaining gas throughput. The well injects at 70- 130 mmscfd on average and the impact when shut-in is expected to be between 400-700 BOPD. Hilcorp would like to keep the well on injection for a period of up to two weeks until Slickline can successfully reset the 7" MCX injection valve and reduce the bleed frequency. I have also attached a previous/similar email communication with Chris for reference. Thank You, Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska, LLC 0: (907) 777-8547 1 C: (509)670-80011 wrivard0hilcorl2com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 Wallace, Chris D (DOA) From: Roby, David S (DOA) Sent: Friday, March 8, 2019 2:07 PM To: Wyatt Rivard Cc: Wallace, Chris D (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Loepp, Victoria T (DOA); Rixse, Melvin G (DOA) Subject: RE: END 5-01 (PTD # 1801200) Request to Remain on Injection with Increased Bleed Frequency Wyatt, Your request to keep operating this well as indicated below for up to two weeks, until you can repair it with a slickline unit, is hereby approved. Let us know if anything about the operating condition of the well changes. Regards, Dave Roby 907-793-1232 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 Dave Roby at 907- 793-1232 or dave.robv@alaska.eov. From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Friday, March 8, 2019 11:36 AM To: Roby, David S (DOA) <dave.roby@alaska.gov> Cc: Wa ace, Chris D (DOA) <chris.wallace@alaska.gov> Subject: EE 1D 5-01 (PTD # 1801200) Request to Remain on Injection with Increased Bleed Frequency Hello Dave, Endicott gas injector END 5-191(PTD # 1801200) operates under Admin Approval 1.007 for TxIA communication. The well recently experienced an increased,lA bleed frequency that Hilcorp believes is due to diminished isolation of the downhole injection valve and not a change to the well's tubing or packer integrity. Hilcorp would like to leave the well online for up to two weeks until slickline can change out the injection valve. Background 5-01's downhole injection valve isolates the subsurface safety valve control line that is believed to be the leak path for the well's one way TxIA communication under gas. Following the last injection valve reset on 8/11/17 the well has had virtually no IA pressurization indicating a very good set of the valve. Recently, it appears that the injection valve seals have lost isolation of the control line and IA pressurization has resumed. Bleeds roughly every 1-2 days are required to maintain IA pressure below the AA specified 2500 psi. This represents a change in the well's recent integrity, however this bleed frequency is in line with what we have seen historically at times when the MCX was not well set. Mitigations: • Endicott well operators physically conduct twice daily monitoring of END 5-01 and7able monitor the IA pressure remotely through SCADA at all times. • The well's IA pressure remains manageable under bleeds. • • Wallace, Chris D (DOA) From: Taylor Wellman <twellman@hilcorp.com> Sent: Wednesday, September 13, 2017 7:55 AM To: Wallace, Chris D (DOA) Cc: Wyatt Rivard; Larry Greenstein Subject: RE: END 5-01 (PTD# 1801200) 28 day Monitoring Results Attachments: END 5-01 TIO 09-13-2017.xlsx Chris, Endicott gas injection well END 5-01 (PTD# 1801200)operates under A10 1.007 for TxIA communication.The well's downhole injection valve was reset on 8/11/17 following a period of increased bleed frequency. Since the reset of the injection valve,there have been no bleeds and no signs of increased IA pressurization. Hilcorp believes IA integrity has been restored to historic norms of operation under A10 1.007 and plans to leave the well on injection. A TIO plot is attached for reference. Thank You, Taylor(Filling in for Wyatt Rivard) Taylor Wellman Hilcorp Alaska, LLC—Ops Engineer: Endicott& Northstar Office: (907) 777-8449 Cell: (907)947-9533 Email:twellman@hilcorp.com From:Wyatt Rivard :Wednesday,August 16, 2017 11:01 AM To: 'W. . e, Chris D(DOA)'<chris.wallace@alaska.gov> Subject: RE: ' ! -01(PTD# 1801200) Injection Valve Reset and 28 day Monitoring Chris, Endicott gas injection well END 5-01 (P . = 1801200)operates under A10 1.007 for TxIA communication but had been experiencing increased bleed frequency when *mpared with historic norms.Slickline was able to successfully reset the downhole injection valve on 8/11/17 with a passing = •GCC witnessed SVS test on 8/14/17.The reset of the valve appears to have successfully reduced the rate of TxIA corn unication. A TIO plot is attached for reference. Going forward, Hilcorp would like to monitor the well on injection fo 28 day period to verify the reduced pressurization/bleed frequency. Monitoring results will be provided at 28 s with the well shut-in at any indication of a return to increased TxIA communication. Thank You, Wyatt Rivard I Well Integrity Engineer I Hilcorp Alaska,LLC 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 1 • • Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Wednesday,August 16, 2017 11:01 AM To: Wallace, Chris D (DOA) Subject: RE: END 5-01 (PTD# 1801200) Injection Valve Reset and 28 day Monitoring Attachments: 5-01 TIO.xlsx Chris, Endicott gas injection well END 5-01 (PTD# 1801200) operates under AIO 1.007 for TxIA communication but had been experiencing increased bleed frequency when compared with historic norms. Slickline was able to successfully reset the downhole injection valve on 8/11/17 with a passing AOGCC witnessed SVS test on 8/14/17.The reset of the valve appears to have successfully reduced the rate of TxIA communication.A TIO plot is attached for reference. Going forward, Hilcorp would like to monitor the well on injection for a 28 day period to verify the reduced pressurization/bleed frequency. Monitoring results will be provided at 28 days with the well shut-in at any indication of a return to increased TxIA communication. Thank You, Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska,LLC 0: (907) 777-8547 I C: (509)670-8001 I wrivardithilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 SCANNED AUG 2 1201i•, From:Wallace, Chris D(DOA) [mailto:chris.wallace@alaska.gov] Sent: Monday,August 07, 2017 9:43 PM To:Wyatt Rivard<wrivard@hilcorp.com> Subject: RE: END 5-01(PTD# 1801200) Increased Bleed Frequency-Request to Remain On Injection Wyatt, Thank you for the call today and additional information about the well. The plan below is approved including up to the requested 14 days injection. Regards, Chris Original message From: Rivard<wrivard@hilcorp.com> Date: 08/07/201 . 'M (GMT-09:00) To: "Wallace, Chris D (D• • " <chris.wallace • alaska.•ov> Subject: END 5-01 (PTD # 1801201 - eased Bleed Frequency- Request to Remain On Injection Chris, Endicott gas injection well END 5-01 (PTD# 1801200) injects under admin appro : • IO 1.007 for TxIA communication. The well has recently experienced an increased IA bleed frequency that 1 :'cates a change to 1 • • • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Monday,August 7, 2017 9:43 PM To: Wyatt Rivard Subject: RE: END 5-01 (PTD#1801200) Increased Bleed Frequency- Request to Remain On Injection Wyatt, Thank you for the call today and additional information about the well. The plan below is approved including up to the requested 14 days injection. Regards, Chris Original message SCANNED :w. 21 '4,, From:Wyatt Rivard <wrivard@hilcorp.com> Date:08/07/2017 3:53 PM (GMT-09:00) To: "Wallace,Chris D (DOA)" <chris.wallace@alaska.gov> Subject: END 5-01 (PTD#1801200) Increased Bleed Frequency-Request to Remain On Injection Chris, Endicott gas injection well END 5-01 (PTD#1801200)injects under admin approval AIO 1.007 for TxIA communication. The well has recently experienced an increased IA bleed frequency that indicates a change to the well's mechanical condition.A TIO plot is attached for reference. Hilcorp believes the increased bleed frequency began after a recent pull and reset of the well's downhole injection valve. Hilcorp would like to leave the well on injection until Slickline can change out the injection valve. Background: During the recent MIT-IA on 7/22/17,the 7" MCX injection valve was removed to allow Slickline to set a plug in the tubing.The downhole injection valve isolates the subsurface safety valve control line that is believed to be the leak path for the well's one way TxIA communication under gas. Following the passing MIT-IA,the injection valve was reset and the well was returned to injection. Since returning to injection,the well's IA has required bleeds roughly every 2-3 days which is an increase over the pre MIT-IA rate of roughly once every 5 days.Going forward, Hilcorp plans to reset the injection valve again to attempt to get a better seal in the tubing and reduce bleed frequency. Mitigations: 1 • • Endicott well operators physically conduct twice daily monitoring of END 5-01 and are able to monitor the IA pressure remotely through SCADA at all times. • The well's IA pressure remains manageable under bleeds. • As per A1O1.007, an automatic alarm is triggered if IA pressure exceeds 2200 psi with an automatic shut-in occurring at below 2500 psi (last tested 5/6/17). Request: END 5-01 is the largest gas injector at Endicott and is important for maintaining gas throughput.The well injects at 70- 130 mmscfd on average and the impact when shut-in is expected to be between 400-700 BOPD. Hilcorp would like to keep the well on injection for a period of up to two weeks until Slickline can successfully reset the 7" MCX injection valve and reduce the bleed frequency. Thank You, Wyatt Rivard I Well Integrity Engineer I Hilcorp Alaska,LLC 0: (907) 777-8547 I C: (509)670-8001 I wrivardc hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 2 • • I . I I I • I LTOZ/L0/80 - LTOZ/S0/80 -- LTOZ/£0/80 - LIOZ/10/80 - LIOZ/0£/L0 - LTOZ/8Z/LO LOZ/9ZLO - LZOZ/VZ/L0 LZOZ/ZZ/L0 a - LTOZ/OZ/L0 - LZOZ/81/LO -- LTOZ/9T/LO - LTOZ/Vt/L0 - LTOZ/Z1/LO - LTOZ/OT/L0 -- LTOZ/80/L0 - LTOZ/90/L0 _ LTOZ/170/L0 < - LTOZ/ZO/LO 0 LTOZ/0£/90 - LTOZ/8Z/90 - LTOZ/9Z/90 - LTOZ/VZ/90 _ LTOZ/ZZ/90 _ LTOZ/OZ/90 F_ LTOZ/81/90 2 LTOZ/91/90 - LTOZ/17t/90 _ LTOZ/ZT/90 I - LtOZ/01/90 - LIOZ/80/90 - LIOZ/90/90 - LTOZ/b0/90 -- L10Z/ZO/90 -- L10Z/1£/SO -- LTOZ/6Z/SO LTOZ/LZ/SO .° - L10Z/SZ/S0 _ LIOZ/£Z/SO I - L10Z/TZ/SO - L10Z/6t/SO - L10Z/Lt/SO -- L10Z/ST/SO - L10Z/£T/SO - L10Z/tt/SO -- LTOZ/60/50 o 0 0 0 0 0 0 o 0 0 0 0 0 1p Lf) M• aanssaad • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 7/17/i 7 DATE: Tuesday,July 25,2017 P.I.Supervisor SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 5-01 FROM: Bob Noble DUCK IS UNIT MPI 5-01 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 1 a"" NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 5-01 API Well Number 50-029-20518-00-00 Inspector Name: Bob Noble Permit Number: 180-120-0 Inspection Date: 7/21/2017 Insp Num: mitRCN170723063941 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 5-01 Type Inj N 'TVD 8941 " Tubing 1760 3792 ' 3792 - 3791 PTD 1801200 Type Test SPT Test psi 4836 - IA 1215 4836 4832 4830 - BBL Pumped: 5 [BBL Returned: 5 OA 136 - 131 - 131 ' I 131 ' Interval REQVAR P/F P ✓ Notes: MIT-IA to max injection pressure as per AIOO 1.007.A tubing tail plug was installed and tubing was pressured up to hold backside pressure. ✓ SCANNED `;r.P2 1 O 1 Tuesday,July 25,2017 Page 1 of 1 Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Monday, April 18, 2016 9:09 AM To: 'Wyatt Rivard' Cc: Regg, James B (DOA); Brooks, Phoebe L(DOA) Subject: RE: END 5-01 (PTD # 1801200)Increased IA pressurization - Request To Return To Injection Wyatt, Your 28 days additional monitoring request is approved. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission scale APR 1 8 2316 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.Rov. Original Message From: Wyatt Rivard [mailto:wrivard@hilcorp.com] Sent: Monday,April 18, 2016 9:05 AM To: Wallace, Chris D (DOA) Cc: Regg,James B (DOA); Brooks, Phoebe L(DOA) Subject: END 5-01 (PTD# 1801200) Increased IA pressurization - Request To Return To Injection Chris, As previously discussed, Endicott gas injector END 5-01 (PTD# 1801200) recently experienced an increase in IA pressurization to roughly 800 psi/day requiring daily bleeds. The well operates under A10 1.007 for slow TBGxIA communication.The communication is believed to be caused by a gas-only leak past the subsurface injection valve seals to a compromised control line. The well was SI on 4/16/16 and the 7" MCX injection valve with oversized packing was redressed and reinstalled. Since the valve's installation, there has been no further IA pressurization. Additionally a diagnostic MIT-IA passed to 2500 psi on 4/17/16, confirming tubing and production casing integrity. Please see attached diagnostic MIT-IA,TIO plot and most recent SVS& alarm/trip test. 1 • • Moving forward, Hilcorp requests permission to return END 5-01 to injection for a 28 day monitoring period. Please call with any questions. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com<mailto:ckanyer@hilcorp.com> 3800 Centerpoint Drive, Suite 1400 I Anchorage,AK 99503 2 • • 0 1 w W ,. �--i yZb 9t0910Z/9/8t/t/b00 9bt/b0 - I 10Z//9t0ZZt/ti0 - 9OZ/Ot/b0 - 910Z/80/170 9TOZ/90/b0 _ 9t0Z/b0/b0 E - 9tOZ/ZO/ti0 9IOZ/t£/£0 17 - 9tOZ/6Z/£0 - 9tOZ/LZ/£0 - 9tOZ/SZ/£0 -- 9tOZ/£Z/£0 - 9tOZ/tZ/£0 -- 91OZ/6t/£0 - 9t0Z/Lt/£0 - 9tOZ/St/£0 Q - 9tOZ/£t/£0 0 C5. .�.,�_. - —� 9IOZ/tt/£0 I - 9tOZ/60/£0 E. _ p _ 9tOZ/LO/£0 H 9t0Z/S0/£0 p -- 9IOZ/£0/£0 _� - 9tWZ/t0/£0 2 -- 9tOZ/8Z/ZO _- 9t0,/9Z/Z0 < - 9TOZ/bZ/Z0 ‘ : 9tOZ/ZZ/Z0 -- 9tOZ/OZ/Z0 9t0Z/8t/ZO --- 9TOZ/9t/ZO 9tOZ/fit/ZO - 9tOZ/Zt/Z0 - 9tOZ/Ot/Z0 - 91OZ/80/ZO tin - 910Z/90/Z0 - 9IOZ/ti0/Z0 F _- 9tOZ/ZO/Z0 I - 9tOZ/t£/t0 ( _ - 9tOZ/6Z/t0 -- 9tOZ/LZ/t0 -- 9tOZ/SZ/t0 -- 9tOZ/£Z/t0 - 9tOZ/tZ/t0 - 9tOZ/6t/t0 0 0 Lis 0 0 0 0 0 0 0 0 0 00 vi 0 m N .-i aanssaad • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Wednesday, September 02, 2015 1:16 PM To: 'Wyatt Rivard' Subject: RE: END 5-01 (PTD# 1801200) Request to Continue Injection Wyatt, Thank you for the call and updates on this well. Approved for continued injection. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 �`ANHEp .V 0 3 2015 (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: Wyatt Rivard [mailto:wrivard@hilcorp.com] Sent: Tuesday, September 01, 2015 3:51 PM To: Wallace, Chris D (DOA) Subject: RE: END 5-01 (PTD # 1801200) Request to Continue Injection Chris, Endicott gas injector END 5-01 (PTD# 1801200) has been on injection following a state witnessed MIT-IA and reset of the subsurface injection valve on 8/2/15. Since returning to injection, the well was bled three times.Two bleeds, on 8/3/15 and 8/4/15, were fluid only during high ambient temperatures as the well warmed up.An additional bleed on the IA occurred on 8/25/15 from 2350 psi to 1400 psi; all gas in 5 minutes. Based on this single gas bleed over the 28 day monitoring period,the 7" MCX injection valve with oversized packing appears to have greatly decreased the annular pressurization rate. Hilcorp would like to continued injection within the requirements of AIO 1.007.TIO plot included for reference. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 1 • MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �7 • / DATE: Thursday,August 06,2015 �e' gI 31 t SUBJECT: Mechanical Integrity Tests P.I.Supervisor � g Y ( HILCORP ALASKA LLC 5-01/SD7 FROM: Chuck Scheve DUCK IS UNIT MPI 5-01/SD7 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 3r- NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 5-01/SD7 API Well Number 50-029-20518-00-00 Inspector Name: Chuck Scheve Permit Number: 180-120-0 Inspection Date: 7/30/2015 Insp Num: mitCS150731060938 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 5-01/SD7 [Type Inj N'1TVD 8941 - Tubing 1569 - 3937 3927- 3918 1801200 - SPT 2235 ' 1200 4895 ' 4884 4877 - PTD Type Test Test psi IA Interval REQVAR P/F P OA 80 80 - 80 - 80 Notes: Tested per A1O 1.007 Thursday,August 06,2015 Page 1 of 1 Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Tuesday, August 04, 2015 7:38 AM To: 'Wyatt Rivard' Subject: RE: Request: Place END 5-01 (PTD # 1801200) Back On Injection For Evaluation Wyatt, Request for additional 28 days monitoring is granted. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue SCANNED AUG 0 4 201; 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: Wyatt Rivard [mailto:wrivard@hilcorp.com] Sent: Monday, August 03, 2015 4:22 PM To: Wallace, Chris D (DOA) Subject: RE: Request: Place END 5-01 (PTD # 1801200) Back On Injecton For Evaluation Chris, END5-01 (PTD#1801200) had a successful state witnessed MIT-IA on 7-30-15.The MIT-IA required the removal of the injection valve and setting of a tubing tail plug to provide back pressure and prevent tubing collapse.The injection valve was reset on 8/2/15 and the inner annulus pressure has remained steady following an internal SVS test.The well is currently warming up for a state witnessed SVS test. Provided the well passes the state witnessed test, we would like to continue to inject in the well for an additional 28 day monitoring period to verify no further TBG x IA communication with the reset injection valve. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 Niilrorp glad►.s.I.11 1 • O 0 0 0 0 O 0 0 0 0 t!1 M N �"� O 1 L----"---------D.I'. . in N O 01 O V iR CX_ O �.r f Q 3 00 ' IIIII O O of • O _ � ti., r` O O ' il., 4 .101 I _ — N It et YY + Co — N in I Co Op o o O O O CV • i RECEIVED Post Office Box 244027 Anchorage,AK 99524-4027 Hilcorp Alaska,LLC JUL 3 0 2015 3800 Centerpoint Drive Suite 100 AVAnchorage,AK 99503 AOGCC Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 SCAMMED AUG 2 9 2 01 Commissioner Cathy Foerster 0 Alaska Oil & Gas Conservation Commission 00 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 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 "I" 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 • I Orig New API_WeIINo PermitNumber( WelMName WeIlNumberI WellNumber 50029224180000 1931730 DUCK IS UNIT MPI 2-24/M12 2-24 50029218150000 1880550 DUCK IS UNIT MPI 2-26/N14 2-26 50029218470000 1880860 DUCK IS UNIT MPI 2-28/P19 2-28 50029218470100 2010180 DUCK IS UNIT MPI 2-28A/O19 2-28A 50029218470200 2030060 DUCK IS UNIT MPI 2-286/019 2-28B 50029222280000 1911400 DUCK IS UNIT MPI 2-30/009 2-30 50029222280100 1981880 DUCK IS UNIT MPI 2-30A/EI-02 2-30A 50029222280200 2081870 DUCK IS UNIT MPI 2-30B/ME-01 2-30B 50029220840000 1901190 DUCK IS UNIT MPI 2-32/SN3 2-32 50029216620000 1861720 DUCK IS UNIT MPI 2-34/P14 2-34 50029220140000 1900240 DUCK IS UNIT MPI 2-36/014 2-36 50029220900000 1901290 DUCK IS UNIT MPI 2-38/SN1 2-38 50029225270000 1941520 DUCK IS UNIT MPI 2-40/S22 2-40 50029218920000 1881450 DUCK IS UNIT MPI 2-42/P13 2-42 50029217670000 1871190 DUCK IS UNIT MPI 2-44/R12 2-44 50029217670100 1970710 DUCK IS UNIT MPI 2-44A/Q11 2-44A 50029219210000 1890230 DUCK IS UNIT MPI 2-46/Q15 2-46 50029219210100 1961810 DUCK IS UNIT MPI 2-46A/R10 2-46A 50029219210200 1971370 DUCK IS UNIT MPI 2-46B/S13 2-46B 50029226120000 1951660 DUCK IS UNIT MPI 2-48/013 2-48 50029223670000 1930670 DUCK IS UNIT MPI 2-50/U08 2-50 50029217500000 1870920 DUCK IS UNIT MPI 2-52/514 2-52 50029222180000 1911220 DUCK IS UNIT MPI 2-54/Q12 2-54 50029228630000 1980240 DUCK IS UNIT MPI 2-56/EID 2-56 50029228630100 1980580 DUCK IS UNIT MPI 2-56A/EID01 2-56A 50029220410000 1900520 DUCK IS UNIT MPI 2-58/509 2-58 50029223750000 1930830 DUCK IS UNIT MPI 2-60/U13 2-60 50029216480000 1861580 DUCK IS UNIT MPI 2-62/Q17 2-62 50029220550000 1900770 DUCK IS UNIT MPI 2-64/U10 2-64 50029220819500 1901130 DUCK IS UNIT MPI 2-66/U12XX 2-66XX 50029223740000 1930790 DUCK IS UNIT MPI 2-665D12 2-66 50029218580000 1880970 DUCK IS UNIT MPI 2-68/517 2-68 50029218990000 1881530 DUCK IS UNIT MPI 2-70/U15 2-70 50029205180000 1801200 DUCK IS UNIT MPI 5-01/SD7 5-01 50029206400000 1811180 DUCK IS UNIT MPI 5-02/SD10 5-02 50029206390000 1811170 DUCK IS UNIT MPI 5-03/SD9 5-03 50029216780000 1861900 DUCK IS UNIT SDI 3-01/N29 3-01 50029223060000 1921210 DUCK IS UNIT SDI 3-03/J33 3-03 50029216240000 1861300 DUCK IS UNIT SDI 3-05/029 3-05 50029219110000 1890120 DUCK IS UNIT SDI 3-07/N28 3-07 50029219110100 1981470 DUCK IS UNIT SDI 3-07A/L29 3-07A 50029217800000 1880020 DUCK IS UNIT SDI 3-09/L28 3-09 50029217800100 1950190 DUCK IS UNIT SDI 3-09A/L28 3-09A 50029218480000 1880870 DUCK IS UNIT SDI 3-11/M30 3-11 50029217510000 1870940 DUCK IS UNIT SDI 3-15/K33 3-15 50029219460000 1890530 DUCK IS UNIT SDI 3-17/J30 3-17 50029219460100 1940460 DUCK IS UNIT SDI 3-17A/J30 3-17A 50029219460200 1971080 DUCK IS UNIT SDI 3-17B/M31 3-17B 50029219460300 1980210 DUCK IS UNIT SDI 3-17C/M31 3-17C 50029219460400 1982080 DUCK IS UNIT SDI 3-17D/M31 3-17D 50029219460500 2022470 DUCK IS UNIT SDI 3-17E/K30 3-17E Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Monday, July 06, 2015 9:15 AM To: 'Wyatt Rivard' Subject: RE: Request: Place END 5-01 (PTD # 1801200) Back On Injecton For Evaluation Attachments: image001jpg; image002.jpg Wyatt, 28 day monitoring approved. Thanks and Regards, Chris Wallace 201 Sr. Petroleum Engineer bitcv JUL Q Alaska Oil and Gas Conservation Commission S1 L 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: Wyatt Rivard [mailto:wrivard©hilcorp.com] Sent: Monday, July 06, 2015 9:10 AM To: Wallace, Chris D (DOA) Subject: Request: Place END 5-01 (PTD # 1801200) Back On Injecto For Evaluation Chris, Remediation work was completed on END5-01 on 7/3/15.The insert sleeve and 4-1/2" Al (injection style SSSV) were pulled and a 7" MCX injection valve with oversized packing was installed. Since installation, the inner annulus pressure has remained steady with a —1000 psi differential between tubing and the IA. Currently the TBG/IA/OA pressures are 2450/1491/100 psi. Hilcorp would like to return the well to injection for a 28 day monitoring period to evaluate the effectiveness of the 7" MCX sub surface safety valve in reducing or eliminating the TBGxIA communication. Additionally, an AOGCC MIT-IA will be completed by the July 20, 2015 due date. A TIO plot is included for reference. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 1 llikvirp �Iaha. I.l.l, From: Wyatt Rivard Sent: Thursday, July 02, 2015 4:37 PM To: 'Wallace, Chris D (DOA)' Subject: RE: END 5-01 (PTD # 1801200) Request to Resume Injection Chris, END5-01 was shut-in today July 2, 2015. END1-09A(PTD# 1970290) is online and stabilizing. It appears to handling the gas from END 5-01 without issue. 5-01 will remain shut-in until remediation is complete. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 Ilikorp 11644.1.1A: From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Wednesday, June 24, 2015 10:47 AM To: Wyatt Rivard Subject: RE: END 5-01 (PTD # 1801200) Request to Resume Injection Wyatt, Request for additional days is approved. 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, 2 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: Wyatt Rivard [mailto:wrivard@hilcorp.com] Sent: Wednesday, June 24, 2015 10:22 AM To: Wallace, Chris D (DOA) Subject: RE: END 5-01 (PTD # 1801200) Request to Resume Injection Chris, Since returning Endicott 5-01 (PTD# 1801200)to injection on 5/29/15, bleed frequency has remained relatively consistent at one bleed every 1-3 days.We currently have a slickline unit available at Endicott to perform the remediation steps previously discussed to improve END5-01's TBGxIA integrity.Additionally, END 1-09A has been converted to a gas injector to assist with gas handling when END 5-01 is shut-in for wellwork. However there are a few days of surface work yet to be completed before injection in END1-09A can commence. END 5-01's 28 day temporary authorization to resume injection expires on 6/25/15. Hilcorp is requesting an additional 7 day extension to complete tie in for END 1-09A and begin injection on that well prior to taking END 5-01 offline. END 5-01's safety valve and alarm/shutdown system was successfully tested during pad testing on 6/14/15.The SVS test form, and an updated TIO plot are attached. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 Ililnrh Ua•ka. I.I.I. From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Thursday, May 28, 2015 11:44 AM To: Wyatt Rivard Subject: RE: END 5-01 (PTD # 1801200) Request to Resume Injection Wyatt, END 5-01 is approved for resumed injection for up to 28 days with the mitigations of AIO 1.007,operator twice daily monitoring, and bleeds as appropriate. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7`h 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 3 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: Wyatt Rivard [mailto:wrivard@hilcorp.com] Sent: Thursday, May 28, 2015 11:15 AM To: Wallace, Chris D (DOA) Subject: RE: END 5-01 (PTD # 1801200) Request to Resume Injection Chris, The last testing of the system was completed on 11/11/14 during the regularly scheduled six month Endicott SVS testing. Please see attached SVS and high pressure set point test sheets. The next 6 month test of the SVS systems is scheduled for May 2015. Logistical difficulties have postponed those tests but the 210 day test cycle provides for testing up until the end of June 2015.The Endicott operators have been in communication with AOGCC inspectors. If need be,we can perform an additional internal test of the END5-01 system prior to resuming injection.The procedure used for SVS testing of Endicott gas injectors is attached. It is an updated version of the same procedure BP utilized. Step 3.7 includes testing of the END 5-01 IA high pressure set point. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 Hiknrp 'd... a.1.l.t: From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Thursday, May 28, 2015 9:07 AM To: Wyatt Rivard Subject: RE: END 5-01 (PTD # 1801200) Request to Resume Injection Wyatt, When was the alarm and shut down systems last tested and their result? As required by Rule 5 of AIO 1.007 Amended, has Hilcorp provided .."the testing procedure that will be used to verify the integrity of the well shut-in equipment linked to the outer annulus pressure"? 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 4 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: Wyatt Rivard [mailto:wrivard©hilcorp.com] Sent: Thursday, May 28, 2015 8:40 AM To: Wallace, Chris D (DOA) Subject: END 5-01 (PTD # 1801200) Request to Resume Injection Chris, Following up on our conversation, I've included some additional information relating to Hilcorp's request to resume gas injection on END 5-01 (PTD# 1801200). Background END 5-01 remains shut-in for increased Inner Annulus bleed frequency.The well operates under A10 1.007 for slow TBGxIA communication that has required bleeds roughly 2-3 times per week. The bleed frequency increased to daily bleeds soon after the shutdown and restart of the Endicott Pipeline and most of the Endicott wells. Once the increased bleed frequency was identified,the well was shut-in on 5/26/15 and notification to the AOGCC was made. The TBGxIA leak is believed to be caused by a slow gas-only leak past the subsurface injection valve seals to a compromised control line. Replacing packing and re-installing and/or reconfiguring the style of subsurface injection valves have historically reduced the TBGxIA repressurization rate and bleed frequency. Current Impact END5-01 is an important Endicott gas injector that directly affects the plant's gas throughput. Endicott producers are still unloading large amounts of water after the recent shut-in so the impact of the END5-01 shutdown has not yet been felt. Under normal operating conditions,the impact is expected to be at least 350 BOPD. When the well was last SI in April 2014, it resulted in 6 producers being SI with a total impact of 650 BOPD. Remediation Plans: Hilcorp intends to complete the following remediation steps to reduce bleed frequency at the next available opportunity: Option 1) Pull insert sleeve and 4-1/2" Al (injection style SSSV) Set 7" MCX valve Option 2)—if Option 1 fails Pull 7" MCX valve Set re-dressed insert sleeve and 4-1/2" Al valve Option 3—if Option 2 fails Pull 4-1/2" Al valve and insert sleeve E-Line to set tubing patch across current SSSV profile Set 4-1/2" Al valve in a nipple profile in the patch Additionally, Hilcorp is in the process of finalizing the conversion of END1-09A as a gas injector. Once completed, END1- 09A may provide a backup for END5-01 in the event of future integrity issues. 5 Timetable: END5-01 remediation will require a Slickline and/or Eline unit. Currently there is no road access to Endicott due to the washout and significant damage resulting from the Sag River flooding. It is expected to take 2-3 weeks before road repairs are completed. Mitigations IA pressures can safely be managed through daily bleeds. Additional mitigations include: - Endicott well operators are currently conducting twice daily monitoring of END5-01 - As per AIO 1.007, an automatic alarm is triggered if IA pressure exceeds 2200 psi with an automatic shut-in of the well occurring at 2450 psi. Request: Hilcorp would like to resume injection in END5-01 for up to four weeks or until remediation is completed. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 Ililnrrp 1la.1.�, I.I.I. 6 O 0 O O O 0 0 0 0 O O 0 O 0 0 0 0 CD O O O O O O O O O cr. 00 N- LP t1) O O O CD CD L ... t _. _1. 1 , LAj `_ • O Al -mom. 1 ,......? • • f CD • LA "-r C7 AL kr) `j CJ kN, in O N LAO t7...- O_ Yl C N IO N 1 O t an 1 CO LA "" O O CL J."."- N E "T O 11 CD Q �' O N 0 -'1 4411._ _....... ..... ......._____ LA 0 _N Na fV O f to 0 N o O O O O O C_D O O O O O O O O O O LA "1 M N "-• Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Thursday, May 28, 2015 11:44 AM To: 'Wyatt Rivard' Subject: RE: END 5-01 (PTD# 1801200) Request to Resume Injection Attachments: image002 jpg; image003 jpg Wyatt, END 5-01 is approved for resumed injection for up to 28 days with the mitigations of AIO 1.007,operator twice daily monitoring, and bleeds as appropriate. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue %NM MAY 2 8 2015 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: Wyatt Rivard [mailto:wrivard@hilcorp.com] Sent: Thursday, May 28, 2015 11:15 AM To: Wallace, Chris D (DOA) Subject: RE: END 5-01 (PTD # 1801200) Request to Resume Injection Chris, The last testing of the system was completed on 11/11/14 during the regularly scheduled six month Endicott SVS testing. Please see attached SVS and high pressure set point test sheets. The next 6 month test of the SVS systems is scheduled for May 2015. Logistical difficulties have postponed those tests but the 210 day test cycle provides for testing up until the end of June 2015.The Endicott operators have been in communication with AOGCC inspectors. If need be,we can perform an additional internal test of the ENDS-01 system prior to resuming injection.The procedure used for SVS testing of Endicott gas injectors is attached. It is an updated version of the same procedure BP utilized. Step 3.7 includes testing of the END 5-01 IA high pressure set point. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard( hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 1 Mewl, %lanka. 1.1.(, From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Thursday, May 28, 2015 9:07 AM To: Wyatt Rivard Subject: RE: END 5-01 (PTD # 1801200) Request to Resume Injection Wyatt, When was the alarm and shut down systems last tested and their result? As required by Rule 5 of AIO 1.007 Amended, has Hilcorp provided .."the testing procedure that will be used to verify the integrity of the well shut-in equipment linked to the outer annulus pressure"? 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.Rov 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 mayviolate state or federal law. Ifyou are an unintended recipient of this e-mail, p please delete it,without first savingor forwardingit, 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: Wyatt Rivard [mailto:wrivard@hilcorp.com] Sent: Thursday, May 28, 2015 8:40 AM To: Wallace, Chris D (DOA) Subject: END 5-01 (PTD # 1801200) Request to Resume Injection Chris, Following up on our conversation, I've included some additional information relating to Hilcorp's request to resume gas injection on END 5-01 (PTD# 1801200). Background END 5-01 remains shut-in for increased Inner Annulus bleed frequency.The well operates under AIO 1.007 for slow TBGxIA communication that has required bleeds roughly 2-3 times per week. The bleed frequency increased to daily bleeds soon after the shutdown and restart of the Endicott Pipeline and most of the Endicott wells.Once the increased bleed frequency was identified,the well was shut-in on 5/26/15 and notification to the AOGCC was made. 2 The TBGxIA leak is believed to be caused by a slow gas-only leak past the subsurface injection valve seals to a compromised control line. Replacing packing and re-installing and/or reconfiguring the style of subsurface injection valves have historically reduced the TBGxIA repressurization rate and bleed frequency. Current Impact END5-01 is an important Endicott gas injector that directly affects the plant's gas throughput. Endicott producers are still unloading large amounts of water after the recent shut-in so the impact of the END5-01 shutdown has not yet been felt. Under normal operating conditions,the impact is expected to be at least 350 BOPD.When the well was last SI in April 2014, it resulted in 6 producers being SI with a total impact of 650 BOPD. Remediation Plans: Hilcorp intends to complete the following remediation steps to reduce bleed frequency at the next available opportunity: Option 1) Pull insert sleeve and 4-1/2" Al(injection style SSSV) Set 7" MCX valve Option 2)—if Option 1 fails Pull 7" MCX valve Set re-dressed insert sleeve and 4-1/2"Al valve Option 3—if Option 2 fails Pull 4-1/2"Al valve and insert sleeve E-Line to set tubing patch across current SSSV profile Set 4-1/2"Al valve in a nipple profile in the patch Additionally, Hilcorp is in the process of finalizing the conversion of END1-09A as a gas injector. Once completed, END1- 09A may provide a backup for END5-01 in the event of future integrity issues. Timetable: END5-01 remediation will require a Slickline and/or Eline unit. Currently there is no road access to Endicott due to the washout and significant damage resulting from the Sag River flooding. It is expected to take 2-3 weeks before road repairs are completed. Mitigations IA pressures can safely be managed through daily bleeds.Additional mitigations include: - Endicott well operators are currently conducting twice daily monitoring of END5-01 - As per AIO 1.007, an automatic alarm is triggered if IA pressure exceeds 2200 psi with an automatic shut-in of the well occurring at 2450 psi. Request: Hilcorp would like to resume injection in END5-01 for up to four weeks or until remediation is completed. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 3 VI a c a a F ¢ Zr. ISI SioZ/SZ/S STOZ/£Z/S STOZ/TZ/S _STOZ/6T/S STOZ/LT/S STOZ/ST/S STOZ/ET/S STOZ/TT/S STOZ/6/S STOZ/L/S StoZ/S/S STOZ/E/S STOZ/T/S _STOZ/6Z/b _STOZ/LZ/Y STOZ/SZ/4 _STOZ/EZ/V STOZ/iZ/b _SIOZ/6i/0 STOZ/Li/U 0 _STOZ/Si/V STOZ/EI/0 a-I _STOZ/ii/b STOZ/6/b LA 0 _STOZ/L/4 Z SiOZ/S/V W STOZ/E/4 sioz/T/4 STOZ/OE/E STOZ/8Z/E STOZ/9Z/E STOZ/OZ/E STOZ/ZZ/E STOZ/OZ/£ STOZ/8T/E STOZ/9i/E STOZ/4i/E STOZ/ZT/E STOZ/Oi/E StOZ/8/E S1OZ/9/E STOZ/b/E STOZ/Z/E STOZ/8Z/Z STOZ/9Z/Z 0 salaald Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Wednesday, May 27, 2015 8:21 AM To: Wallace, Chris D (DOA); Alaska NS - Endicott - Field Foreman; Alaska NS - Endicott - Operations Leads Cc: Loepp, Victoria T (DOA); Regg, James B (DOA); Taylor Wellman Subject: Injector END5-01 (PTD # 1801200) Increased Bleed Frequency Attachments: image002.jpg; 5-01.pdf; END5-01 TIO.xls All, Gas injector END5-01(PTD# 1801200) was identified as having increased bleed frequency following the recent shut-in and restart of the Endicott Pipeline. Please see attached TIO plot and list of bleeds. 5-01 was subsequently shut-in on 5/26/15.The well operates under AIO 1.007 for slow TBGxIA communication related to the SSSV control line. Initial repair efforts will focus on change out of the subsurface injection valve as soon as road access is reestablished to Endicott. Please call with any questions. Thank You, Wyatt Rivard j Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 Ni�.v�rp {A•La, ILLSCANNED MAY 2 8 2015 . , TREE= 6XTa ENDS 01 r� >� "°, : 1 WELLHEAD= 13-5/5 ACTUATOR= BAKER C SAFETY NOTES:H2S READINGS OKB.BEV= 48.7' 1 AVERAGE 230-260 PPM ON A/L& BF.ELEV= 10.8 GAS INJECTOR WELL KOP= , REQUIRES A SSSV. Max Angle= 50° 77.00' Datum M3= i \ Datum TVD= 10000.SS O 7"OTIS RPB SSSV NIP ID=5.962"w/7"X4-1/2" 1631' 13-3/8",72#/ft,L-80,Btrs Csg f HRQ INSERT,ID=3.813" (03/19/14) 2673' NOTE: CONTROL LINE INTEGRITY HAS FAILED. WELL HAS EXTREME IAITBG COMM. WHEN INSERT IS OUT. MIN ID =3.813"@ 1631' .< 7",26#/ft,L-80 IJ4S 7" X 4-1/2" HRQ INSERT CROSSOVER, 7"IJ4S to 5-1/2"TC4S 10749' NOTE: OTIS SLIDING SLEEVE I I SLIDING SLEEVE OTIS"XA" 10762' DAMAGED.*SEE WELL FILE FOR PHOTOS. (4.562"I.D.) (10/26/13) jTIW R 10822' (12'Long)SB gam_ 5 1/2" TIW PACKER 10842' 5-1/2", 17#/ft L-80,TAILPIPE 5-1/2"'X'NIPPLE OTIS(4.562"I.D.) 10893' TOP OF 7"LINER 5-1/2"'XN'NIPPLE OTIS(4.455"I.D.) 10934' 11019' > 0 "11E--------5-1/2"WLEG 10975' 9-5/8",47#/ft L-80 BUTT ELMD 10951 11554' > A PERFORATION SUMMARY REF LOG: CIL-GR(03/13/81) ANGLE AT TOP F : Note:Refer to Roduction DB for historical perf data SIZE SPF INTERVAL DATE 4' 8 11794-11874 0 3-3/8" 4 11907-11941 0 3-3/8" 4 11951-12083 0 TEST F$RFS 12096-121682 S ' 1987 ""K KEY: O=OPE /C=CLOSED/SOZ�QL ED - 1.7" diameter, 5.5' long toolstring left in hole at— 12,133' feet ELMD broken KJ, centralizer, spinner. PBTD 12475' —> Assume buried in NaCI salt. 7",29#/ft,SM-110, Btrs-TKC 12522' —�► DATE REV BY COMMENTS DATE REV BY COMrUJTS 1 EN DICOTT UNT 02109/89 JLH INTIAL COMPLETION 11/06/13 JTG/JMD REIMDV ED RESTRICTION WELL: 5-01/SD-07 05/14/95 GAM SEE"NOTE" 12/13/13 JTG/JMD SS DAMAGED(10/26/13 PEF MST No: '1801200 09/14/13 DU/PJC TREE C/O(09110/13) 04/17/14 VVICR PJC SSSV INSERT(3/19/14 AR No. 50-029-20518-00 09/17/13 LEDJM)DESSV,PLUGBRtSTRIC SBC 16,R12N,T16E,308'FNL 8 2271'FEL 10/04/13 RKT/JM)PX FLUG RLUREST DSSSV BP Exploration(Alaska) 'e Ire Project Well History File Co` ge XHVZE This page identifies those items that were not scanned during the initial production scanning .phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~}- ~ ~ ~ Well History File Identifier Organizing i~~l,:~, wo-Sided IIIIIIIIIIIIIIIIIII escan Needed ~~~~IIIiIIIII ~~~~~~ RESCAN DIGITAL DATA OVERSIZED (Scannable) ~lor items: ~~~~~~~~ ^ ^ Grayscale items: ^ Poor Q lity Originals: Other: ~~ ~ NOTES: Diskettes, No. ^ Maps: Other, No/Type ^ Other items scannable by large scanner OVE_R_S.I-ZE-D-(Non-Scannable} ~-~'' Logs of various kinds ^ Other BY: BEVERLY OBIN ~V NCENT SHERYL MARIA WINDY DATE: ~ Cj _~~ ~ 4- Project Proofing BY: BEVERL SHERYL MARIA WINDY DATE' - _ .~' l~'1' Scanning Preparation ~ x 30 =~~ + `~ = TOTAL. PAGES~,~~~~ BY: BEVERLY OBIN INCENT .SHERYL MARIA WINDY DATE:~j f~: y~~LSI ~\~ - Production Scanning Stage 7 PAGE COUNT FROM SCANNED FILE: ~~~~~~`''"'~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES ~ NO C B`/. BEVERL~aROBIN VINCENT SHERYL MARIA WINDY DATE:e(f Q-~/S/~~ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCI ERE FOUND: // t~ YES NO BY. BEVERLY ROBIN VINCENT SHERYL MARIA INDY DATE~-~"~ ~~ (SCANNING IS COMPLETE AT TMS POINT UNLESS SPECIAL ATTENTION IS REOVIRED ON AN INDIVIDUAL PAGE BASIS ~~~~~~JJJJJJ III II' I'I I DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ReScanned {titt~tVt(~£1i1/ ja;4 £~f-' ~ d3 E?C3iiJ ~Pt('7)i.'07Yj 5£.i#3Fflitt£j E: t3d31~3/Cf£; EZJ II I II I I II IIII III III RESCANNED BY. BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: /S/ General Notes or Comments about this file: Quality Checked r,U~nei IIIIIIIIIIIIIIIIIII 12/10/02 Rev3NOTScanned.wpd UNSCANNED, OVERSIZED MATERIALS AVAILABLE: igtJ AJ FILE # ! //Lap L () G- 'f {! ()ht(Jú!þ(( /2-eh~+ ¿d c--r . To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission 1333 \v. 7th Ave., Ste. 100 I Anchorage, Alaska 99501 Voice (907) 279-1433 tFax (907) 276-7542 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWeIIlntegrityCoordinator @bp.com] Sent: Wednesday, October 23, 2013 9:55 PM To: AK, OPS END OIM; AK, OPS END Facility& FieldO&M TL; AK, OPS END Board Operator; AK, OPS END AES Drillsite Lead; AK, OPS END Operations Lead Tech; AK, RES END Production Optimization Engineer; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; Wallace, Chris D (DOA); Igwe, Josiah; Regg, James B (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: OPERABLE: END5-01/SD-07 (PTD#1801200) Passing AOGCC witnessed MIT-IA Attachments: MIT END5-01 10-20-2013.xls All, Injector END5-01/SD-07 (PTD#1801200) passed an AOGCC witnessed MIT-IA to 4,900 psi on October 20, 2013.This confirms two competent well barriers. At this time the well is reclassified as Operable, and may be brought online at Operations convenience. A copy of the AOGCC MIT form has been included for reference. Please call with any questions. Thank you, Laurie Climer SCANNED BP Alaska - Well Integrity Coordinator r!�►A/ Gil Walls Y Organization WIC Office: 907.659.5102 WIC Email: AKDCWeIIlntegrityCoordinator @BP.com From: A', •&C Well Integrity Coordinator Sent: Friday, •- •ber 04, 2013 9:06 PM To: AK, OPS END 0 • 'K, OPS END Facility& FieldO&M TL; OPS END Board Operator; AK, OPS END AES Drillsite Lead; AK, OPS END Opera • Lead Tech; AK, RES END Production a•timization Engineer; AK, D&C Wireline Operations Team Lead; AK, D&C Well Servic- •aerations Team Lead; Cismoski, Dou• ,• Daniel, Ryan; 'chris.wallace @alaska.gov'; Igwe, Josiah Cc: AK, D&C DHD Well Integrity Engineer; A , C Well Integrity Coordinator; 'jim.r-:•@alaska.gov' Subject: NOT OPERABLE: END5-01/SD-07 (PTD # : 00)Video Log Complete All, Injector END5-01/SD-07 (PTD#1801200)video logging job is complete. There is n. .dditional need to dep - s the fluid level in the well at this time. The well is reclassified as Not Operable until AOGCC com. • nce testing can be co .leted. Plan forward: 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator©bp.com] Sent: Friday, October 04,2013 9:06 PM To: AK, OPS END OIM; AK, OPS END Facility&FieldO&M TL; AK, OPS END Board Operator; AK, OPS END AES Drillsite Lead;AK, OPS END Operations Lead Tech;AK, RES END Production Optimization Engineer; AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; Wallace, Chris D(DOA); Igwe, Josiah Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Well Integrity Coordinator; Regg, James B (DOA) Subject: NOT OPERABLE: END5-01/SD-07(PTD#1801200)Video Log Complete All, Injector END5-01/SD-07(PTD#1801200)video logging job is complete. There is no additional need to depress the fluid level in the well at this time. The well is reclassified as Not Operable until AOGCC compliance testing can be completed. Plan forward: 1. APE: Evaluate video log of obstruction and determine plan forward for AOGCC compliance testing. Please contact me with any questions. Thank you, Jack Disbrow r 1 4 . t t. BP Alaska Well Integrity Coordinatorw� lobai Wells Organization Office: 907.659.5102 .. WIC Email:AKDCWeIlIntegrityCoordinator @bp.com From: AK, D&C Well Integrity Coordinator Sent: Thursday, October 03, 2013 10:08 AM To: AK, OPS END OIM; AK, OPS END Facility&FieldO&M TL; AK, OPS END Board Operator; AK, OPS END AES Drillsite Lead; AK, OPS END Operations Lead Tech; AK, RES END Production Optimization Engineer;AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; 'chris.wallace @alaska.gov'; Igwe,Josiah Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; 'jim.regg @alaska.gov' Subject: UNDER EVALUATION: END5-01/SD-07 (PTD #1801200) Ready for Injection to Depress Tubing Fluid Level All, Injector END5-01/SD-07 (PTD#1801200) is ready to place on injection. BP has received permission from the AOGCC to inject gas into the well to displace the tubing fluid for diagnostic purposes. The well is reclassified as Under Evaluation and may be placed on injection. The well is not to remain on sustained injection for production support. Plan forward: 1. Endicott Operations: Place well on injection to depress fluid level as necessary 2. DHD: Monitor pressures at the wellhead while injecting and shoot tubing fluid levels as necessary 3. Eline: Perform video log of tubing obstruction 1 • • 4. APE: Evaluate plan forward based on video log results Please contact me with any questions. Thank you, Jack Disbrow BP Alaska-Well Integrity Coordinator Global Wells Organization Office: 907.659.5102 WIC Email:AKDCWelllntegrityCoordinator @bp.com From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Friday, September 13, 2013 10:47 AM To: AK, D&C Well Integrity Coordinator; Regg,James B(DOA) Subject: RE: Request to bring Injector END5-01/SD-07 (PTD #1801200)online briefly for diagnostics Laurie, Plan below is APPROVED. 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.Rov From: AK, D&C Well Integrity Coordinator[mailto:AKDCWelllntegrityCoordinator @)bp.com] Sent: Monday, September 09, 2013 9:20 PM To: Regg,James B(DOA) Cc: Wallace, Chris D (DOA) Subject: Request to bring Injector END5-01/SD-07 (PTD #1801200)online briefly for diagnostics Good Morning Jim and Chris, While working on Gas Injector END5-01/SD-07 (PTD#1801200),an unknown restriction was found at 10,814'SLMD.A passing MIT-IA to 2500 psi was performed on 09/07/2013 (after drift). Post tree change out, BP would like to bring the well online under evaluation to flush the fluid out of the wellbore in order to run a video log of the obstruction prior to the required AOGCC MIT-IA per AA1.007.The well will only be online for a short period of time. Plan Forward: 1. Valve Shop: Complete Tree change out 2. Slickline: Pull plug out of sliding sleeve 3. Ops: Bring well online long enough to purge the wellbore of fluid 4. E-line: Run video log 5. APE/WIC: Plan forward 2 I have included a copy of the recent injection/TIO plot,wellbore schematic for reference.Additionally, below is a copy of the email that was sent for the one month extension to be online through August prior to TAR. Please call with any questions. Thank you, Laurie Climer (Alternate:Jack Disbrow) BP Alaska - Well Integrity Coordinator GWt tganIzatort WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator @BP.com From: Regg, James B(DOA) [mailto:iim.reog@lalaska.gov] Sent: Wednesday,July 17, 2013 12:34 PM To: AK, D&C Well Integrity Coordinator Cc: Wallace, Chris D (DOA); Brooks, Phoebe L(DOA) Subject: RE: Request to delay AOGCC MIT-IA for Injector ENDS-01/SD-07 (PTD #1801200) As I stated during phone call on 7/15/13, BPXA's request to postpone the Endicott 5-01 MIT to coincide with restart after planned maintenance (described below) is approved. The well may remain online until secured for planned maintenance. Jim Regg AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: AK, D&C Well Integrity Coordinator[mailto:AKDCWelllntegrityCoordinator @lbp.com] Sent:Tuesday, July 16, 2013 2:38 PM To: Regg,James B (DOA); Wallace, Chris D (DOA) Cc: Igwe, Josiah; Daniel, Ryan; Climer, Laurie A; AK, D&C Projects Well Integrity Engineer; AK, RES END Production Optimization Engineer Subject: Request to delay AOGCC MIT-IA for Injector END5-01/SD-07 (PTD #1801200) Good afternoon Jim and Chris, Per our phone conversation yesterday, BP would like to request a temporary delay regarding the required AOGCC witnessed MIT-IA for Gas Injector END5-01/SD-07(PTD#1801200),AA 1.007. Endicott Operations will be performing planned maintenance end of August-September. During the this break in production,we will be changing out the tree wellhead for a newer design.The two year anniversary date is 07/21/2013—we would like to leave the well on injection through the end of August;once the TAR commences,the well will be secured and will be tested post wellhead swap. 3 • • Plan Forward: 1. Ops:continue to inject,well is on Monthly Injector Report due to AA 1.007 2. Slickline:Secure well for maintenance, removing SSSV 3. Valve Shop:Change out tree 4. Fullbore: Perform state witnessed MIT-IA I have included a copy of the wellbore schematic and TIO/Injection Plots for reference. Thank you, Laurie Climer (Alternate:Jack Dffbronit BP Alaska — Well Integrity Coordinator Gal Wens Dt an,zato WIC Office: 907.659.5102 WIC Email: AKDCWelllnteeritVCoordinator @BP.com 4 • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator @bp.com] Sent: Thursday, October 03, 2013 10:08 AM To: AK, OPS END OIM; AK, OPS END Facility& FieldO&M TL; AK, OPS END Board Operator; AK, OPS END AES Drillsite Lead; AK, OPS END Operations Lead Tech; AK, RES END Production Optimization Engineer; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; Wallace, Chris D (DOA); lgwe, Josiah Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; Regg, James B (DOA) Subject: UNDER EVALUATION: END5-01/SD-07 (PTD#1801200) Ready for Injection to Depress Tubing Fluid Level All, Injector END5-01/SD-07 (PTD#1801200) is ready to place on injection. BP has received permission from the AOGCC to inject gas into the well to displace the tubing fluid for diagnostic purposes. The well is reclassified as Under Evaluation and may be placed on injection. The well is not to remain on sustained injection for production support. Plan forward: 1. Endicott Operations: Place well on injection to depress fluid level as necessary 2. DHD: Monitor pressures at the wellhead while injecting and shoot tubing fluid levels as necessary 3. Eline: Perform video log of tubing obstruction 4. APE: Evaluate plan forward based on video log results Please contact me with any questions. Thank you, scANNED 'J-`r t�,� Jack Disbrow BP Alaska-Well Integrity Coordinator G VVGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIIlntegrityCoordinator @bp.com From: Wallace, Chris D (DOA) [mailto:chris.wallace @alaska.gov] Sent: Friday, September 13, 2013 10:47 AM To: AK, D&C Well Integrity Coordinator; Regg, James B (DOA) Subject: RE: Request to bring Injector END5-01/SD-07 (PTD #1801200) online briefly for diagnostics Laurie, Plan below is APPROVED. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 1 • • (907)793-1250(phone) (907) 276-7542(fax) chris.wallace @alaska.gov From: AK, D&C Well Integrity Coordinator [mailto:AKDCWelllntegrityCoordinator @bp.com] Sent: Monday, September 09, 2013 9:20 PM To: Regg, James B (DOA) Cc: Wallace, Chris D (DOA) Subject: Request to bring Injector END5-01/SD-07 (PTD #1801200) online briefly for diagnostics Good Morning Jim and Chris, While working on Gas Injector END5-01/SD-07 (PTD#1801200), an unknown restriction was found at 10,814' SLMD. A passing MIT-IA to 2500 psi was performed on 09/07/2013 (after drift). Post tree change out, BP would like to bring the well online under evaluation to flush the fluid out of the wellbore in order to run a video log of the obstruction prior to the required AOGCC MIT-IA per AA1.007.The well will only be online for a short period of time. Plan Forward: 1. Valve Shop: Complete Tree change out 2. Slickline: Pull plug out of sliding sleeve 3. Ops: Bring well online long enough to purge the wellbore of fluid 4. E-line: Run video log 5. APE/WIC: Plan forward I have included a copy of the recent injection/TIO plot, wellbore schematic for reference.Additionally, below is a copy of the email that was sent for the one month extension to be online through August prior to TAR. Please call with any questions. Thank you, Laurie Climer (; (t,'.ncr c:.Iu,cI act:, ri BP Alaska - Well Integrity Coordinator Gftel Weis Organizabon WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator @BP.com From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Wednesday, July 17, 2013 12:34 PM To: AK, D&C Well Integrity Coordinator Cc: Wallace, Chris D (DOA); Brooks, Phoebe L(DOA) Subject: RE: Request to delay AOGCC MIT-IA for Injector END5-01/SD-07 (PTD #1801200) 2 • • As I stated during phone call on 7/15/13, BPXA's request to postpone the Endicott 5-01 MIT to coincide with restart after planned maintenance (described below) is approved. The well may remain online until secured for planned maintenance. Jim Regg AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: AK, D&C Well Integrity Coordinator [mailto:AKDCWelllntegritvCoordinator @bp.com] Sent: Tuesday, July 16, 2013 2:38 PM To: Regg, James B (DOA); Wallace, Chris D (DOA) Cc: Igwe, Josiah; Daniel, Ryan; Climer, Laurie A; AK, D&C Projects Well Integrity Engineer; AK, RES END Production Optimization Engineer Subject: Request to delay AOGCC MIT-IA for Injector END5-01/SD-07 (PTD #1801200) Good afternoon Jim and Chris, Per our phone conversation yesterday, BP would like to request a temporary delay regarding the required AOGCC witnessed MIT-IA for Gas Injector END5-01/SD-07 (PTD#1801200),AA 1.007. Endicott Operations will be performing planned maintenance end of August-September. During the this break in production,we will be changing out the tree wellhead for a newer design.The two year anniversary date is 07/21/2013—we would like to leave the well on injection through the end of August;once the TAR commences,the well will be secured and will be tested post wellhead swap. Plan Forward: 1. Ops: continue to inject, well is on Monthly Injector Report due to AA 1.007 2. Slickline:Secure well for maintenance, removing SSSV 3. Valve Shop: Change out tree 4. Fullbore: Perform state witnessed MIT-IA I have included a copy of the wellbore schematic and TIO/Injection Plots for reference. Thank you, Laurie Climer (Alternate:Jta Di.shroit) BP Alaska — Well Integrity Coordinator Global Weirs Organization WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator @BP.com 3 i • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 02, 2011 TO: Jim Regg P.I. Supervisor l 6( It SUBJECT: Mechanical Integrity Tests � cl BP EXPLORATION (ALASKA) INC 5 -01 /SD7 FROM: Chuck Scheve DUCK IS UNIT MPI 5 -01 /SD7 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: DUCK IS UNIT MPI 5 - 01 /SD7 API Well Number: 50 029 - 20518 - 00 - 00 Inspector Name: Chuck Scheve Insp Num: mitCS110722I53907 Permit Number: 180 - 120 - Inspection Date: 7/21/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 5-ov SD 7' 1 Type Inj. N TVD 8941 • IA 895 ' 4900 4885 4877 P. 1801200 •TypeTest SPT Test psi 4800 • OA 85 85 85 85 Interval REQVAR p/F P Tubing 3000 3075 3070 3065 Notes: Well on 2 year test cycle due to slow T x IA comunication. Only witnessed testing up to 30 min. .pq ' - eressu, Atiatc aA.A`c z cJ In.J .:, pesswe._ - Ad-0 1.0o7 Tuesday, August 02, 2011 Page 1 of 1 • MEMORANDUM TO: l I 1 P1mSup~rgvisor ~ ~Ic~ ~ ~ ~f t FROM: JCr Petroleum Inspector . State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, August 03, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 5-O 1/SD7 DUCK IS iJNIT MPI 5-Ol/SD7 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~.~~~-- Comm Well Name: DUCK IS iJNIT MPI 5-01/SD7 API Well Number: 50-029-20518-00-00 Insp Num: miUCr090731163731 Permit Number: 180-120-0 ~ Rel Insp Num: Inspector Name: JCr Inspection Date: ~~30/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 5-01/SD7 Type Inj. N 'I'`7D 8941 ~ IA 340 4800 l 4760 4760 / P.T.D 180~20o TypeTest SPT Test psi za3s.zs ~ pA ao ~o ~o ~o Interval ~Qv~ p~ P Tubing zobo zazo zsio zsio NOtes: TTP set @ 10934 MD to pressure tubing to 2000 psi for 4800 psi IA test. {~~ ~~~7 ; ~~c~.J-{es~- ~r~ss~~ ~S t~~ an,~`c~~~i.~ ~~~c~1 ~~ssv~re~~ ~ ~~ ~r `a jE~~~. '~~,5.. s at . ._. ~J~ r ' :,, , e - ~e . ., . . .. _. Monday, August 03, 2009 Page 1 of I ! • WELL LOG ,I. TRANSMITTAL PROACTIVE DAAGNOSTIC SERVICES, INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 [907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Nita Summerhays LR2 - 1 900 Benson Blvd. Anchorage, AK 99508 AUG `',4 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 11 Leak Detection - WLD 19- Jul -11 5 -01 / SD-07 BL / CD 50 -029- 20518 -00 2) Signed :`� �J Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245.8952 E-MAIL : PDSANCHORAGE WEBSITE: WWVV.MEMORYLOG.COM D:\ Archives\ Distribution \TransmittalSheets\BP Transmitdocx /, f_o • 1~L~ ®]~t ~~ ~-~ C®liTSER~A~®1~T C®1~Il~i15~I®riT • SARAH PALIIV, GOI/ERAIOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 1.007 Mr. Steve Rossberg, Wells Manager BP Exploration (Alaska) Inc. ~;,~~ ,JAN ~' 4 2D0~ P.O. Box 196612 Anchorage, AK 99~ 19-6612 RE: Endicott ~-Ol/SD7 (PTD 1801200) Request for Administrative Approval Dear Mr. Rossberg: In accordance with Rule 9 of Area Injection Order 001.000, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby approves BP Exploration (Alaska) Inc. ('`BPXA")'s request for administrative approval to inject gas in the subject well. This administrative approval replaces the canceled sundry approval (93- 060). Endicott ~-O1/SD7 exhibits slow tubing by inner annulus ("IA") communication suspected to be related to the subsurface safety valve control line. AOGCC finds that BPXA has elected to perform no corrective action at this time on Endicott ~-O1!SD7. The Commission further finds that, based upon reported results of BPXA's diagnostic procedures, Endicott 5-01%SD7 exhibits two competent barriers -namely the tubing and innermost casing - to release of well pressure. Accordingly, the Commission believes that well operation in gas injection service will not threaten the environment or human safety. AOGCC's administrative approval to inject gas in Endicott ~-O1/SD7 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures, injection rates, and IA pressure bleeds; 3o BPXA shall perform an MIT-IA every two years to the maximum anticipated injection pressure; ~'[r. Steve [Zossberg September 17, 2007 Page 2 of 2 4. BPXA shall limit the well's IA pressure to 200 psi; ~. BPXA shall install and operate automatic well shut-in equipment on the well's IA; 6. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; and 7. after well shut-in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection. 8. The MIT anniversary date is July 20, 2007. As provided in AS 31.0.080, 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 ?3rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. ska and dated September 17, 2007. .~ 4 ,/ ~/ Daniel T. Seamount, Jr. Commissioner ~ . f!/~~ STATE OF ALASKA RECEIVED ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONSAUG 1 5 2007 . 1. Operations Performed: Abandon 0 Repair WellO Alter CasingO Change Approved ProgramO Plug PerforationsD as OI~ommiSSi AnchOther x -(;aTl~1 ora -403 Sundry Time ExtensionO Re-enter Suspended WellO 5. Permit to Drill Number: 180-1200 /" 6. API Number 50-029-20518-00-00 / Stimulate 0 Pull TubingD Perforate New PoOIO Operation ShutdownD Perforate 0 WaiverO 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (It): 48.70 I 8. Property Designation: ADL-312828 ( 11. Present Well Condition Summary: Total Depth measured 12522 feet true vertical 10283.0 feet Effective Depth measured 12475 feet true vertical 10245.4 feet Casing Length Size CONDUCTOR 104 20" Conductor SURFACE 2639 13·3/8" 72# L-80 PRODUCTION 11522 9-5/8" 47# L-80 LINER 1503 7" 29# SM-110 Perforation depth: Measured depth: 11794-11874, 11907-11941, 11951-12083 True vertical depth: 9703-9767, 9793-9820, 9828-9931 Tubing ( size, grade, and measured depth): 7" 26# L-80 5-1/2" 17# L-80 Packers & SSSV (type & measured depth): 4. Current Well Class: Development 0 ExploratOryO StratigraphicO ServiceŒ 9. Well Name and Number: 5-01 I SD-07 ( 10. Field/Pool(s): Endicott Field I Endicott Pool /" Plugs (measured) None Junk (measured) 1.7" OD, 5.5' Spinner tool @ -12133' ELMD MD TVD Burst Collapse 34 138 34.0 138.0 2400 770 34 - 2673 34.0 ." 2673.0 5380 2670 34 - 11554 34.0 - 9510.2 6870 4760 11019 - 12522 9081.5 - 10283.1 11220 8510 S'Cf~NED SE? 1 92007 RBDMS BFl SEP ] 9 2007 @ 32 @ 10749 10749 10975 10842 1631 9-5/8" TIW Packer 7" Halliburton MBR Flapper Valve @ @ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Oil-Bbl Prior to well operation: Gas Injection Well Subsequent to operation: Gas Injection Well 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations _ Signature s~\~~ ~ ~-O(, 0 ~.;;¡~,<~c..~ -t< ~.)'i Þ\~ A \ Çj \ ~ oc) ~ ~OI'hY1 41---- V ,'ill Representative Daily Averaoe Production or Iniection Data Gas-Met Water-Bbl Casing Pressure Tubing Pressure 15. Well Class alter proposed work: ExploratoryD 16. Well Status alter proposed work: OilO GasD DevelopmentD ServiceŒ: WAG 0 GINJŒ WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. Sundry Number or N/A if C.O. Exempt: 93-060 Title Well Integrity Coordinator Phone (907) 659-5102 8/15/07 Date Æ 'f1Í'/$7 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg «ttjtl 7('o~J,/o7 P.I. Supervisor (" l DATE: Monday, July 23, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 5-01/S07 DUCK IS UNIT MPI 5-01/S07 ö"" lIP \fð FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: ""=/' P.I. Suprv -:.J~!<- Comm NON-CONFIDENTIAL Well Name: DUCK IS UNIT MPI 5-0I/SD7 API Well Number: 50-029-20518-00-00 Inspector Name: John Crisp Insp Num: miúCr07072308I206 Permit Number: 180-120-0 Inspection Date: 7/20/2007 Rei Insp Num: Packer Depth / Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. =:-=-T~~-' ITVD '1 IA ~ Well : 5-01lS07 ¡Type Inj. ¡ G 8941 1560 1500 ! 2490 2500 I y~ -, I P.T.D¡ J801200 ITypeTest I SPT I Test psi '1""C''''''' /i VA 220 220 200 200 , , I I kterval REQVAR P/F P Tubing 4280 4300 4300 4300 i Notes: 1,7 tLti's pumped for test, No problems witnessed, SCANNED AUG 0 6 2007 Monday, July 23, 2007 Page 1 of 1 END5-01 (PTD# 1801200) Draft ca.lation of sundry / Request for AA Regg, James B (DOA) . ~Ot(q 1l~~òl Page 1 of2 From: NSU, ADWWelllntegrity Engineer [NSUADWWelllntegrityEngineer@BP.com] Sent: Sunday, July 22, 2007 9:03 PM To: Regg, James B (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: RE: END5-01 (PTD# 1801200) Draft cancellation of sundry I Request for AA Jim, Thank you for your recommendations on the draft AA request. We will make the changes and send it to your office. We will also keep reference that a tubing replacement will require a subsurface control device. END5-01 was not tested in January of this year. There was some confusion within Well Integrity because an email was sent by an AOGCC representative to decrease the test frequency. The new testing frequency was put into effect without editing the AA to reflect the change. Once the mistake was caught, we drafted the AA request and sent it to you for your comments. I sent you the MIT form for the passing MITIA performed on 07/20/07 in an earlier email. Thank you again for your assistance. We will send the request soon. Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~í}O- ~:;.D SCANNED AUG.~ 6 2007 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, July 18, 2007 4:20 PM To: NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA) Subject: RE: ENDS-Ol (PTD# 1801200) Draft cancellation of sundry / Request for AA I reviewed the draft Admin Approval request and info about approval of injection valve. Our files did not have a copy of the 10/12/1999 email from Blair Wondzell approving injection valve in lieu of SCSSV. Thank you for sending the copy. There is no further action needed for the SSSV; reminder that tubing replacement in Endicott 5-01 will invalidate AOGCC's approval and require either SCSSV or request for alternate type of subsurface control device. We can work with the request for cancellation of sundry and admin approval. Couple items: 1) Cover letter indicates IA pressure is maintained below the "maximum allowable pressure limit"; not sure what that is referencing since we do not have such for injection wells except as a condition of approval in an AA; (remember 2500 psi in CO 501 (all Endicott Pools) is for producing wells only); 2) We are missing the report for MIT that was due January 2007; Sundry 393-060 required 3000 psi MIT every 6 months - last MIT in our files was 7/22/2006 (AOGCC did not witness); 3) MIT test cycle will likely be adjusted to 2 years instead of suggested 4 years; 6 month cycle for current MIT is unnecessary, particularly with the monthly report of TIO pressures (we should have changed that long ago) 4) Good idea using the Prudhoe gas injectors (NGI, WGI, AGI) approvals as a guide. I've drafted an admin approval and will send it to Commissioners when we receive your application. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 7/23/2007 END5-0 1 (PTD# 1801200) Draft c.lation of sundry 1 Request for AA phone: 907-793-1236 4IIÞ fax: 907-276-7542 Page 2 of2 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWellIntegrityEngineer@BP.com] Sent: Monday, July 16, 2007 4:21 PM To: Regg, James B (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: END5-01 (PTD# 1801200) Draft cancellation of sundry / Request for AA Hi Jim, Here is a draft of the sundry cancellation 1 request for AA on END5-01. I followed what we currently have in place on the gas injectors in Prudhoe. «END5-01 Cancel Sundry AA Request 07-13-07.doc» «END5-01 TJ 07-17-07.doc» «END5-01 TIO.BMP» Please let me know if you have any comments or suggestions. Thank you, }f.nna (})u6e, œ lB. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 7/23/2007 ENDS-OI (PTD #1801200) Sundry ,APproved Inj Valve Documentation. Regg, James B (DOA) Page 1 of 1 From: NSU, ADW Well Integrity Engineer [NSUADWWelllntegrityEngineer@BP.com] Sent: Friday, July 13, 20072:28 PM To: Regg, James B (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: ENDS-01 (PTD #1801200) Sundry and Approved Inj Valve Documentation Attachments: S-01.zip Hi Jim, I found some documentation on Endicott S-01/SD-07 (PTD #1801200) that I thought you might like for your records. In this zip file is a copy of the current sundry #93-060 with the technical justification as well as a copy of the e-mail from Blair from 10/99 appoving an injeciton SSSV. I hope to send you a draft on the proposed AA request on Monday. «S-01.zip» Please let me know if you have any questions. Thank you, }lnna (})u6e, œ. P.. Well integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 ~.{,11t\stJ :!tq 3-Dbo I k .h e ~re~ e~~ qpprovtÚt ~- \..t£.e c>-J \ , íl\}c'Gh{¡~ VCLl Je (~ ((.et.( ðJ ~~sV (r)4rtL4~ 2() 2001 sCANNED JUL cs.'K~1 7/1812007 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: ~~~ S~:;~isor '~q ((2;1/00 DATE: Friday, January 20,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 5-0 l/SD7 DUCK IS UNIT MPI 5-01/SD7 \C60/1J» FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~ Comm NON-CONFIDENTIAL Well Name: DUCK IS UNIT MPI 5-01lSD7 API Well Number 50-029-205 I 8-00-00 Inspector Name: John Crisp Insp Num: mitJCr060 1 19093 135 Permit Number: 180-120-0 Inspection Date: 1117/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well! 5-0l/SD7 ¡Type Inj. I G I TVD 8941 , IA 1460 2520 2430 ! 2430 , i P.T. I 1801200 ¡TypeTest ! SPT ! Test psi 2235.25 I OA 180 180 180 I 180 i Interval OTHER P/F P Tubing 4600 4600 i 4600 ¡ 4600 Notes Semi Annual MIT-IA to 2500 psi for sundry. 45 bbl's pumped for test. "'::¡:-'~""\NEP F q.vn,t'~, (, 21\ Œè Friday, January 20, 2006 Page 1 of I MEMORANDUM State of Alaska ') Alaska Oil and Gas Conservation Commission TO: Jim Regg ~ ! P .1. Supervisor 'f',"'t1 7 zt:j 05 DATE: Wednesday, July 27, 200S SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 5-0 l/SD7 DUCK IS UNIT MPI 5-0I/SD7 ~~() --\W FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv '- Tßæ-- Comm Well Name: DUCK IS UNIT MPI S-01/SD7 Insp Num: mitCSOS07221S0125 ReI Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-20518-00-00 Permit Number: 180-120-0 Inspector Name: Chuck Scheve Inspection Date: 7/22/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 5-01lSD7 Type Inj. G TVD 8941 IA 360 2500 2500 2520 P.T. 1801200 TypeTest SPT Test psi 2235.25 OA 150 200 200 200 Interval REQVAR P/F P Tubing 4100 4100 4100 4100 Notes: Pretest pressures observed and found stable. 5CANNE[:, AlJG () 9 2005 Wednesday, July 27, 2005 Page I of I MEMORANDUM ) State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday, February 14,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORA nON (ALASKA) INC 5-01/sm DUCK IS UNIT MPI 5-0l/Sm ~~~ S~:~isor ~e1f 2{ Z4 0> FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Well Name: DUCK IS UNIT MPI 5-01/SD7 Insp Num: mitLG050212133834 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-20518-00-00 Permit Number: 180-120-0 Inspector Name: Lou Grimaldi Inspection Date: 2/10/2005 t( \?iJ \~ Reviewed By: P.I. Suprv- "TB"e.- Comm Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 5-01/SD7 Type Inj. G TVD I 8941 IA 720 2520 2520 2520 P.T. 1801200 TypeTest SPT Test psi I 2235.25 OA 200 200 200 200 Interval REQVAR P/F p Tubing 4100 4100 4100 4100 Notes: Prior to test, bled annulus from 720 to 340 to vent gas cap. Fluid present. IAxTubing communication when safety valve removed. This test showed isolation by SSSV insert. . " ç. '2.DD5 SCANi~ED MAR 1 4 .. Monday, February 14,2005 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Consen'ation Commission TO: J irn Regg PJ. Supervisor ....-¡ 1'4'1 7(7'1 Ctí DA TE: \Vednesda). July 28. 200-t SllBJECT: ~lechanlcallntegnry Tests BP EXPlORA.TION (ALASK..,o\' JNC FROM: Jeff Jones Petroleum Inspector 5-0 I :507 DUCK IS UNIT r-.Wl 5-0\ ,SO: Src: Inspector Re\'iewed By: -í~( PJ. Supn' . -...} t?1-- Comm NON-CONFIDENTIAL Well Name: DUCK IS UNIT ~IPI 5-01/S07 Insp Num: mltJJO-t0728 101305 Rellnsp Num: API Well Number: 50-029-20518-00-00 Permit Number: 180-120-0 Inspector Name: Jeff Jones Inspection Date: 7/27/200-t Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 5-01,507 Type Inj. G TVD 1029-1 IA 580 2500 2-185 2-185 P.T. 1\801200 TypeTest SPT Test psi 223525 OA 200 200 200 200 Inten'al OTHER PIF P Tubing -1210 -1200 -1200 -1200 Notes: ....4 BBLS 50/50 methanol pumped. I well house inspected: no exceptions nOled. 6 monlh imerval for sundry compliance: SSSV comolline leak. Wednesday. July 28. 2004 Page I of I State of Alaska and Gas Conservation Commission MEMORANDUM Alaska 0 R;tf<.. DATE: February 22, 2003 nteg rity Test Mechanical BPX MPI SUBJECT ~/ ~/ð ~ ~ P:; ;¡ I'd"'; 0""<-' TO: Randy Ruedrich Commissioner Tom Maunder P.I. Supervisor THRU FROM 1-23 Endicott 5-01 & DIU Chuck Scheve Petroleum Inspector NON· CONFIDENTIAL v f nterval P/F 30 Min. 3600 2400 15 Min. 3600 2400 nitial 3600 2400 Pretest 3600 900 Tubing Casing Depth 8940 2235 Packer TV.D. Test psi G P Type Inj Type test 5-01/8D7 180-120 v 950 950 950 950 9503 TV.D. Test psi N Type Inj Type test Leak Rate test .2 bbl per Type Inj Type test nterval P/F Tubing Casing TV.D. Test psi nterval P/F Tubing Casing TV.D. Test psi Type Inj Type test Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Interval = mitial Test 4= Four Year Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ N = NOT INJECTING Notes: Well P.TD. Notes: Well P.T.D. Notes: Well P.TD. Notes: Well P.T.D. Notes: Type INJ 1-23/015 194-128 Test's Details I traveled to BPXs DIU MPI and witnessed the six month MITon well 5-01 and the annual leak rate test on welll-23 as required by variance. Well 5-01 passed the standard annulus pressure test and could possibly be returned to the nOTIllal 4-year test schedule. Well 1-23 has a severe tubing by inner annulus leak. The initial pressures were equal at 2450 psi. The water injection was shut down and the tubing pressure slowly decreased to 950 psi with the annulus tracking slightly behind. The pump tnlck was rigged up on the annulus and an injection rate of .2 bbl per minute at 2800 psi was established. 4 hour «;.~, ~ f' (I¡;, ~ If,:,.:, ~ iÏ: ¡', "", ' ¡" ifllì PI n ~-;''JbI'.ft~ , Ir~11!;;. f..) C W'',\1 tests Total Time during cc: º Number of Failures M.I.T.'s performed: ~ Attachments: 2/27/2003 200] t'~ ¡ o MIT DIU 2-22-03 CS1.xls M IT report form 5/12/00 L.G n Z 0 0 0 E . MEMORANDUM . State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille Taylor uf, DATE: February 24, 2002 Chair .. ...\ ~UBJECT: Mechanical Integrity Tests THRU: Tom Maunder øtJ1W~~ BPXA P.I. SupeNisorf<tY "~ MPI & Endeavor Is. '\^-.c>S ~ 5-01/SD7,1-23/015 FROM: John H. Spaulding Duck Island Unit Petroleum Inspector Endicott Field NON- CONFIDENTIAL Well PTD. Notes: Well P.TD. Notes: Well P.TD. Notes: Well PTD. Notes: Well P.TD. Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALTWATER INJ. N = NOT INJECTING v p v p Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer SUNey A= Temperature Anomaly SUNey D= Differential Temperature Test InteNal 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details SCANNED SEP 1 32007 Type the test details in here. Expand or cotract the row height as needed. The sheet is protected so you will need to un protect first, there is no password. M.I.T.'s performed: ;;:¿ Attachments: Number of Failures: ø Total Time during tests: cc: MIT report form 5/12/00 L.G. mit diu 2-24-02 jS.xls 3/8/02 v -- ~ E 0 o · - o = 2~g 0 n c~ ~ 0 I- 0 0 ~ o ILl ~- n, 0 II II II II II ol E Z C · 0 1,1.1 IJJ 0 0 0 Z --- t :3~Illi~'N91S d:J~ 3090¥ .rzzm~d JO:j'J~l~uJ - 0 es~l~e~ - ~ elld Ua/Vt - 00'0 J ~I3N. I.O X' ' J~l:lO 00'0 , (lfli~l ~Nlll~O ! J~o~JoM O0'O [ ~:IIVM 1 ~t~ut 00'0 .~ I'~tlCl :1S:1113:~ 'pmi9 '9'd'd :all'll~l ~IV'IrlNNV 9NIIO3'rNI'!w ION = N TNt ~31¥M/l¥S = S 'PNI ~3~YM HS3~JJ = ~ $~JaO0 allq'l:d 'tNt '98£ 66/'0~8 ::JJ.¥O Idl4/RI(] / ::i::lo~pu3 :aVd t .LIND 1 a1:111=1 X~ :aOiVJJ3dO NOIS!IIVI~iO~ NOI.I. YA~I~ISNO0 S¥9 (]NY 110 (96.//.. !,I6 dba :D~JFIJ, VN DI9 dD ~J ~O..LV'd=Jd 0 00'0 X Jaq~o - 00'0 J~oN~oM 00'0 ~A - t O0'O le,~.q :191l ll~ 00'0 · peJ~ '~'d'd ~H£O 'K)OAq8 :aired ~WnNNV 9NIJ. 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E E · 9 ~ '~ = = ~ ~ ~-- _ ~ ~ ~ -- ~ o ~ : > ° .- ~ ~ > ~ > ~ > E ~ m = ~ ~ ~(~ ~ o m E~ E ~ E ~ c ~ ~ .- o .E -1- 0 - o ~ o &~<= _ Z 0 IL! ~ 0 ~g ~_ o 0 ~m_<___m I.IJ ILl Z 0 Z o LLI 0 0 0 I- O~ LLI I-- > 0 0 0 0 o.~ n o o > tS , ~ oE ~.~ o~ 0t- O4 · -- ~ ~ ~ 0 ~.- =o 0 ~E~ ~ ~ O0 ~ ~~vO ~ ~E ~ ~ ~ x~ m~ m E ~ 0 ~~ ~~ O~~ 0 ~ ~~ ~_~ Z=0 o~ ~~ o ~'-- ~~ Z ,Ltl ~ &' ~ ~ w ~ w ~ ~ 0 w ALASKA OIL AND GAS CONSERVATION COMMISSION MECHANICAL INTEGRITY TEST Date- 9/28/94 Company- BP EXPLORATION ALASKA~ INC. Field- ENDICOTT UNIT WELL *S *I TYPE OF PKR CASING TBG REQ PRETEST START 15 MIN 30 MIN START *P ANNULUS TVD SIZE/WT/GRADE SIZE TEST TBG TBG TBG TBG TIME P F *M *N FLUID MD PRESS CSG CSG CSG CSG PRESS PRESS PRESS PRESS DIESEL 9,730' 9-5/8", 47#/FT 1,700 1,640 1,680 1,720 4-48/K-43 P I & NT-80 TO 12,992' 4-1/2" 2432 1150 PASS SEAWATER 15,448' NT-95 TO 16,058' 300 2,550 2, 600 2,640 C~'-MENTS: CO-MINGLED SEAWATER AND PRODUCED WATER INJECTOR. DIESEL 8,892' 9-5/8", 47#/FT, 4,100 4,100 4,100 4,100 5-01/SAG-07 GA& I & L-80 TO 11,554' 7" 2225 1455 PASS SEAWATER 10,842' 1,425 2, 550 2,350 2,390 CO~tMENTS: SIX (6) MONTH TEST. DIESEL 9,350' 9-5/8", 47#/FT 4,000 4,000 4,000 4,000 2-06/J-22 ~GAS I & NT-80 TO 10,748' 7" 2337 1625 P~SS SEAWATER 12,288' NT-95 TO 12, 680' 600 2, 525 2,400 2,400 COMMENTS: SIX (6) MONTH TEST. ~C' 'ENTS: TUBING INJECTION FLUID: P = PRODUCED WATER INJ S = SALT WATER INJ M = MISCIBLE INJECTION I = INJECTING N = NOT INJECTING ANNULAR FLUID DIESEL GLYCOL SALT WATER DRILLING MUD OTHER OTHER GRADIENT: WELL TEST: Initial 4-Year 4-48 Workover 0.353 PSI/FT 0.45 PSI/FT Explain 2-06 & 5-01 ARE ON A 6 MONTH SCHEDULE AOGCC WITNESS SIGNATURE COMPANY REP SIGNATURE /S/ MICHAEL D. 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' : L_O__I__Q_OZ.O ' _. ~_._~Z.O ...... ~i~ 0c561 0016 °6~16 ~Z 9~61 0006 '6~06 6Z g6LT oog~ gg TOLl 00~ 0~66 ~896 gO '90I ~g OOC~ l O06L ' 6~/6A ~I'SIT 96, 99gi OOBL '698L C~tV6 ~3iYNIO~OOD HVIOI --- oooot ooo6 OOOL .:] ~g'ZO~ N 6~'g9 *~bg~ 'O~6g O00~ ,. · · c ' -' . . : :- · . . .:: . : · : . .. 'IVDI i~3A G3~nsv3N Cl:JJ. YqOd ~1 51 £N I . . .. Check Form for timely compliance with our regulations. ~p~ra~ame and Num~r ...... Reports and Materials to be received by: Date Completion Rcport Wel 1 History Required I, Date Received I Samples Core Chips. Core DeScription Registered Survey Plat Inclinatio'n Survey Directional Survey Drill Stem Test Reports Production Test ,Re~orts Logs Yes Remarks Digitized Log Data ~ ~ Z ~-0 O Z I o~ Z~ 0 I 3: I- Z 0 O 0 0 0 0 ee · 0 -H 0 0 0 0 '1--~ © H 0 0 0 Li ; -- / 7° >- z I 0 .r-I ',--~ 0 O0 ~ -r--I 0 M ~ <1-, '0 0 ~3 0 0 0 n3 © PLUG JOB ..~ ~,_~.~._--'-_ , I,AST CASING ~ ..... /Z_~~ ', DR~LL~¢D Dm'Tn /Z '>' 57 ', nO~,E SIZE _~"/~ MU1) WT. /~. '-7 I'I'G. PURPOSE OF PLUG ._.?t-'~,,--2:, zee ]/ REQUI'RED PLUG I~ENGT]I: FROM CALCULATEI) CEHENT VOLUME': EXCESS, TOTAL CEMENT USED WAS WITIt OPEN END I)RII~L PIPE AT _ //o70 ' uP TO laf~a ' ( /70 CU.FT. ( _.~?___sx.) + o CU. FT. ( 5'"o //o 70 ' CIRCULATED PUHPED ~ >'"- BBLS. OF sx. ). MIN. AIlEAD. ,). MIXED Al,U) PUbIPED I'J:~E-WASlt CU. FT. ( sx.) OF CEMENT, WITH Zff% DISPLACED CEHENT WITH PPG ADDITIVES. HRS. THICK TIME. BBLS. OF /q/~- ~- /7~, ,~,n-t.,~.~/,.~ STARTED MIXING CEmEN~ AT o ~o~ HRS AT A RATE OF ~' BPM AND OF ~, BPM AND I)t~]iLLPIPI'; WAS Wi';T/C-R''h~ AFTER DISPLACING. ANI) WAS OUT OF CAI,CULATED Ct';biENT TOP AT PSI. / oo o PSI. PiIi~LED- DISPLACED AT A tDtTE C.I.P. AT O~o~, HRS. .~ STANDS OF PIPE, PULLED DR'ILLPIPE TO . WAIT ON CEHEb;T ItRS. PLUC JOB 1-,' ] <; , LAST CASING ' I)R'[LI.,E1) DI.;PT}I /2- .~-~.Y I'IU 1) W'f. PPG. PURPOSE OF PLUC ,,@ I! RE(?U II(ED PLUG IA';NGTtt: FRObl CALCUI.,ATEI) CElql'tN'f VOLUME' EXCESS, TOTAL CEblENT USED WAS W].'J.'}t OPEN END I)RiI.,L PIPE AT ,/ ]'Ui. II'ED Lf/ BBLS. OF "'" . . AIIEAI). HIXED Alii) PUMPED t../~, .~ CU FT ( / ,~r_eT',~, .;~T1 2Z CEMENT, WITH - , ( sx.) + sx.). ff~'- H1N. PRE-WAS}t sx. ) oP ~DDITIVES. ])ISPLACED CE,MEN'[' WITIt HRS. THICK TIME. STARTED MIXING CEMENT AT 2 ~ t ~ HRS. AT A RATE OF ~ BPM AND ,.~ ~, o PSI. DISPLACED AT A P,J~TE OF /--~- BPM AND .2~,~ PSI. C.I.P. AT Oo--P. 0 }tP, S. ])R'[LLPIPE WAS WI';'f/))RY Al?TEl( DISPLACING. PULLED _,Z.-' STANDS OF PIPE, ATM) , ~,.._~ WAft OUT OF CA'I,CULATEI) C, Ei.iENT TOP AT 5 © ~" }IRS PULLED DRILl,PIPE TO ~ tlRS. WELL 12- _..6 ;z. CEHEN'£ING SUNNARY PLUG JOB ', DR1Lt.,EI) 1)EPT}I /2 DATE ~- , LAST CASING ', }tOI...E SIZE ~'~,c~. ~,u~Pos~ o~? ~,~.u~ ,.~, ~p ~,,,z, ,, @ REQUIRI';D PLUG LENGTtl: FROM /2_ 0 g ~ CAI,CUI.ATED CEbiENT VOLUNE: EXCESS, TOTAL CEMENT USED WAS WITtl OPEN END DRILL PIPE AT /2~ f~ PUMPED / o BBLS. OF ~/Z o AtlEAD. MIXED AND PUMPED /~. o PPG DISPI,ACED CEHENT WITIt ' uP TO //7/_..~_ ' ( .2. '~ 7 '). ~,::> CU.FT. ( 5--o SX.) + Z ~o CU. FT. ( ..5-'-0 SX.). ' CIRCULATE]) ~o MIN CU. FT. ( CEblENT, WITtt PRE-WASH. ~-o SX. ) OF HRS. THICK TIblE. BBLS. OF A'/~ - /~-- ,'~~ STARTED MIXING CEHENT AT ~ z ~ o AT A RATE OF ~.~-" BPM AND ? o o 0 OF .~ BPM AND /o ~ DRII.LPIPE WAS WET/D~i:Y AFTER DISPLACING. PULLEI) AND WAS OU'f OF CAI.CULAT]:;I) CF. blENT TOP AT ___~/ o o ........ /__ f o,? o __' A~ IIRS. ADDITIVES. HRS. PSI. DISPLACED AT A RATE PSI. C.I.P. AT gpo,/~,- HRS. ~/ STANDS OF PIPE, ! HRS. PULLED DRILl,PIPE TO · WAIT ON CEMENT Z 0 0 0 0 el* -H Z ~C I- Z il Z 0 · 0 ~ © H H 0 0 E'~ 0 0 0 ~3 ~J 0 0 0 0 -~ ?~ I I I 0 D U o~~ '-0 0 z 0 0 0 0 0 0 0 © · ~ 0 0 0 · ~ o 0 ~ 0 · 0 ~ o 0 o ~ o 0 0 0'% o I o z 0 -- 0 z 0 u.. -- © <r < 0 I I ~ I ~ m ~ c:, ,.~ I o o ~ 0 .< ~ o ! oo · .< r-z.l r~ 0 o o o 0 o {-.-. 0 0 ,.-I .,-i LI ' rd ....Q .,.-i cD rd 0.., ~ 0 I~ .,.4 .,-.i 0 Q Ei .,.-I 0 ~ · · · · · · 0 · · · · · · ~0 I O0 I 0 0 0 w W 0 W W W W w -r' z z o 1',-. ji II, o (30 II II II Ii ~- x Zl~J i 3ZI ~1 i 3 91 ~ o CHECK LIST FOR NEW WELL PERMITS Item Approve Date (1) Fee ~ ~~ ..5- (2) loc. · , Yes 1 Is the permit fee attached / 2. Is well to he located in a defined pool ............................. ,, 3. Is a registered survey plat attached ................................ / 4. Is well located ~oper distance frcm property line .................. ~_~ 5. Is well loca.ted proper distance frcm other wells .................... 6. Is sufficient undedicated acreage available in this pool ............ 7. Is well to he deviated ............................................. 8. Is operator the only affected party ................................. 9. Can permit he approved before ten-day wait ......................... / No 10. Does operator have a bond in force .................................. · , 11. Is a conservation order needed ...................................... Lease & Well No~~ (4) Casg .~2~ ( 5 ) BOPE 12. Is administrative aptmcoval needed ................................... 13. Is cor~uctor string provided ........................................ 14. Is enough cement used to circulate on conductor, and surface ..... , ..~ 15. Will cement tie in surface and intermediate or production strings .. ~ , horizons 17. Will surface casing protect freSh water zones ...................... ~ 18. Will all casing give adequate safety in collapse, tension and burst. 19. Does BOPE have sufficient pressure rating- Test to ~ psig .~_~. Approval Reccmmended: Additional Requirements: Geology: Engineering: , HWK LCS __ BEW ~.~~ rev: 03/05/80 '.':. · uo!leu, uo;u! jo fdo68~eo s!q~ ~lleO!6OlOUOJqo ol apeu~ uasq seq pop, a.le!o@ds ON · xiC]N3ddV japun alu aq~ .1.o pua aq~ ~,e paielnuJnooe s! ~nieu s!q~, jo .uo!letLuolu! 'uo?,eu-uotu! Bu!pulj Xl!.ld'tu!s o1 pue alu/dols!H IlaN~ aql 1o X~.l!qepeaJ aq~ a^cudtu! O_L 'alu fdols!q aq], to l~ed s! tnq ssaoo~d 6U!14!tLUacl IlaNt aq~, o~ aueu. ua6 ,~l~elnO!l~ed ~,ou s! leq~, ajm, eu pal!el, ap to UO!leLLUO~Ul XIQNqddV al!-I ~ots!H IlaM ~-~-.t-...-.-.-~¢ .~.~4-E.-..;- ~R.~.G.~.N ....... .:...--~.~-~Y.-S- : ~.E....-L......C..0..N.~..I.-...N.U.a..l:--z..O~ .... N~j.~.z~__F_.~._: ....... 0.4 ~E. V I 0 U S-R E E L --N-A4~---~---=. ......................................................................................................................................................................................... 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FN : ENDICOTT C. OUN: NORTH SLOPE STAT : ALASKA LCC : 150.00 ~* FORMAT ** BYTES . PROD UNITS 939.90'6 65.9.9,34 209.979 0.164 2~.549 121C.596 222~ .253 260.287 ~.55~ 25.755 2130.5E5 4437.777 299.181 ,~.27~ 2G.5~4 289~.236 :5817.87'9 C. 7 19.809 623 .,47C 3t6.745 257.297 7-467 32.824 9gg SS GR CSS RATO SS GR CSS RATO SS GR CSS SS GR CSS RATO SS GR CSS RATO SS GR CSS RATO 1'5238.470 27.887 10878.910 16.636 18807.110 18.951 13057.050 t5.539 24098.540 9.395 1716~.670 1 .316 25365.250 13.462 18508.640 8.819 5987.652 56.101 4439.090 10.054 '369.963 55.773 309.969 0.000 ENTRY ELOCKS DESCRIPTION m----~--~ ~m--~m----m------o DEPTHS DECREASE FRAME SPACING FRAME SPACING U~I?S MAXIMUM FRAMES/RECORD TERMINATOR -0.500 LEVEL SPACING DATUM SPECIFICATION BLOCKS ~URVE REPR lAME CODE SIZE SAMPLE UNITS ~CL 68 4 I DIM .S 68 4 I~ CPS ~1 68 4 I CPS ~2 68 4 I CPS ,ON 6.8 4 I CPS ,KS 68 4 I CPS ~SS 68 4 I CPS lSD 68 4 I SU )BOR 68 4 I DIM IICS 68 4 I DIM 'YPE ENTRY 4 1 8 60.0 9 .lIN 11 12 0 FORMAT ** CURVE NAME SPD GElS GR. BK L CSS SGN A; R~TO R IN REP~ CODE SIZE SAMPLE UNITS 68 4 1 68 4 I CPS 68 4 1 CPS 68 4 I API 6~ 4 I CPS 68 4 I API 68 4 I SU 68 4 I DIN 68 ~'4 I DIM ENTRY BLOCKS 'YPE ENTRY 4 1 8 60.0 9 .1I'M 11 12 0 -0.500 )~TU.M SPECIF ~ U'R ~,E RE PR ~A:ME CODE em--mm, ma, ;CL 68 68 6:8 ):K S DSS 68 .4SD 6'8 ~BOR: 68 ~ICS 68 DESCRIPTION OEPTMS ~ECREASE FRAME $: ICING FRAME SPACING 'UNIT~ MA'~IMUM FRAMES/REC RD TERMINiATOR LEVELi"SPACING ICAT~ON BLOC;KS S I'~Z, E 4 4 4 C URN E SAMPLE UNI~iS NAME I D'~M SPD I CPS SS I CPS GElS 4 1 CPS GR 4 1! C P S B'K L 4 I CPS CSS 4 1 C'PS SGM~ 4 ~ SU RATO 4 1 DIM RZN 4 t DIM DATA ** DEPTH .1:2216.000 FT 3723.&4.4C M m m m m m m m ~m m ~m m m m.m m mmmm m m mmm m~mm m ~mm m m m m m m .%C.L 0-000 SPD 0.000 L~S ~1 2929.?07 GElS 7'4962,:560 G2 4ON: ~351.262 'BK.L I 29.987 BKS [SS 340706.000 SG.N~ 26.702 HSD ~BO:R 1.944 RIN 8.468 RICS )EPTM 12200.000 FT 37t8.568C M mmmmmmmmmmmm'mmmmeem.meemmmm.mmmm ;CL 0.000 SPO 14.999 LS ~1 6417.391 GElS 667'82.1' 30 G2 ~ON 7523.906 B:KL t02.91:4 BKS ESS 3350g9.400 SGMA I 6,'988 HSD: ~BOR 1.768 RIN 8.798 RICS DEPTH t'2100.C0.0 'FT 3688.087~: M ~CL 0.000 SPD 14.9'99 LS ~1 10715.230 GElS 7.6219. ~00 G2 4ON 7.280.332 BKL t18.1~8 BKS ESS ~50980.100 SGMA 13.112 HSD ~BOR 1.735 RIN 8.195 .RIC. S DEPTH 12000.000 LS REPR CODE SI-:ZE SAMPLE UNITS 68 4 I F/MN 68 4 I CPS 68 4 I CPS 68 4 I APl 8 I CPS 68 4 1 S'U 68 4 I DIM 68 4 1 DIM 959.904 SS 14968.500 52g.947 GR 37.182 369.963 CSS 10788.930 0.312 RATO 16.25~ 3t .579 274.86] CSS 12700:790 0.49 RATO 15.2'93 26...384 20.38.255 SS 2~291.460 4537.543 GR 12.362 27~.550 C,:.SS 171~T.230 20.457 2527. 724 SS 24583 . 630 6N SS 372904 BOR 1 EPTH li900. eL 0 I 3705 ON: 6644 SS 360199 80R I · . $::K ~ .500 SGMA 12.444 MSD · 755 RIN 7.971 RIOS CO0 FT 3627.127C M ~. i t i..mm mm ,~ .~.mi .mm i m. ~. ~e .~ .m ~m..~ .000 SPD 15.169 "~LS · 934 GE1S 76C72.000 G2 .602 BKL 254.332 BKS .600 SGMA 23.417 MSD .950 RIN 8.559 RIOS EPTH I 1864.50 ,m~ ~l ,,mm ~m,e ,m, ,~mm, ~,, ,m mm ,,m,,,m m, ,,mi CL 0.0 i 689.9 ON ~727.3 SS 8~121.6 BOR 2.0 ?ARTING DEPTH NDING DEPTH FT 361 6. 3070 N O0 SPD 14.999 LS 31 GElS 18048. 200 G2 32 BKL 249,975 BKS 30 SGMA 26.043 MSD 49 RIN 8.043 RZCS =1:2216.000 FT 3723.4440 M =11864.500 FT 36t'6.3070 M * FILE TRAILER ** ILE NAME: P~SS 3.003 ERVICE NAME: ',ERSION # : 1 ~ATE: 85/11/ ,A,X~MUM LENGTH: 1024 :ILE :,TYPE: LO IE,XT FILE NAME: * FILE MEADER .~ 4 ** ILE NAME: PASS 4.004 ;ERVICE NAME: 'ERSION # : 1 !ATE.: 85/11/2C A,.X RECORD LENOTH: 1024 !~:LE.TYPE: LC REVIOUS FILE N~ME: BY T"E S "* IN,FORMAT;ION RECORDS ** MNEM CON:TENTS mmmm mmme. mmmmmmmmmmm APIN : 5002920518 CN, : ST:ANDARO ALAS~K:A WN : SAG, DELTA .NO· 7 FN : EN,OICOTT COUN : NORTH, SLOPE STAT : ALASKA LOC : 150.00 PRO0 UNITS '* FORMAT ** 0.1 9'6 21.022 927.633 84G .495 386.570 I .386 31.823 145.985 12 .987 279.972 0.220 33.253 CSS RATO SS GR CSS RATO SS GR CSS RATC 17738.680 9.750 15338.550 49.649 113t8.980 16.~21 3429.657 45.150 2529.747 22.867 ENTRY BLOCKS 'Y'PE ENTRY 4 1 8 60.0 9 .lIN 11 12 0 -0.50 ,ATUM SPEC DESCRIPTION DEPTHS' DECREASE F~AME SPACING FRAME 'SPACING UNITiS MAXIMUM FRAMES/RECORD TERMINATOR 0 'LEVEL SPACING IF']CATION 8LOCKS :URVE REPR AME CODE SIZE .SAMPLE UNITS ,iimll Ilmm IImI iImlml IImml :CL 68 4 I DIM S 68 4 I CPS I 68 4 I CPS ,2 68 4 1: CPS tON 68 ,4 t CPS ;'~S 68 4 I CPS iSS 68 ~ I C':PS SD 6~ 4 I SU i,BOR 6~ 4 1 ICS 68 4 1 DIM * FORMAT CURVE NAM E SPD SS GElS GR C::S S SGMA RAT0 RIN REPR CODE 68 68 68 68 68 68 68 68 SIZE ~m 4 .4 4 4 4 4 4 4 SAMPLE m~m~m 1 1 1 1 1 1 1 :~. 1 1 UNITS mmmmm F/MN CPS, CPS CPS SU DIM DIM ENTRY BLOCKS 'YPE ENTRY DESCRIPTION 4 I DEPTHS DECREASE 8 6C.0 FRAME SPACING 9 .lIN FRAME SPACING' UNITS 11 12 MAXIMUM FRAMES/REC'ORO 0 TERMINATOR -0.500 LEVEL SPACING I~TUM SPECIFICATION BLOCKS ;UR;YE REPR lAME CODE SIZE SAMPLE UNITS 'CL 68 4 1 DIM ,S 68 4 I CPS ;1' 68 4 I CPS ;~ 68 4 I CPS ION 68 4 I CPS ~S 68 4 1 CPS ~$S 68 4 I CPS lSD 68 4 I SU ~BOR 68 4 I DIM ~ICS 68 4 I DIM ,* DAT~ ** ]EPTH 12216.~00 FT 372~.444~ M ;eL 265,650 SPD 0,000 ;1 2829.717 GElS 74742.500 ~ON 6954.305 BKL 229.977 [SS 349'4~5.000 SG.M~ 28.91'0 ~BOR I .898 RIN 8.857 )EPTH 12200.000 FT 3718.5680 M 265.6,50 S P D ',; 14 · 611;:::; 6'~69.79~ GEi:S 67266. 750 40N 7009'055 BKL 136'~42 [SS ~40679.400 SG'N~ 17.486 ~BOR 1'838 RIM 9 .~58 )EPTH 12100.000 mT 3688.0870 M ;CL 0.000 SPD 1~:.963 ~1' 10517.700 :GELS 74685.560 7 ~BOR I 70~ RIN 8.945 3EPTH 12000.000 FT 365.7.6070. M mm~m mmm ~mm~m~ m m ~ m m ~mm ~ m mmm mm m,m.mm 3627.1270 M .004195 ~ .0.30 211 .895 3. 191 0,956 36,16.3070 M ~EPTH I 1900.000 FT ~;C'L O.CO0 SPD ~1 1373.164 GElS ~ON ~032..457 BKL [SS 91907.. 560 SGMA ~BOR t.876 RIN DEPTH 11~$64.5~0 FT ,m ,m ,m, ~mm -- ,m ,,m ,,m ,,m ,~m ,ma ,m, ,,m, *m ,mm,,m, -- -- mm ,em,~m, ,ama ,,m, ,,m ,Wm~ ,m, -- ~m,-- SC:'L 0.000 SPD -!'4.999 ~1 0,000 GElS 189.:981 qON 6069,'391 B~L 159.9;;84 ~SS 569.9~3 SGMA -15.009 ~B. OR I .188 RIN 0.001 STARTING DEPTH :12216.000 ENDING DEPTH =11864.500 CURVE REPR NAME CODE SIZE S~MPLE UNITS SPD ~8 4 1 F/MN SS 68 4 1 CPS GElS 68 4 I CPS GR 68 4 I ~PI BKL 68 4 I CPS CS;S 68 ~ 1 API SGMA 68 4 I SU RBTO 68 4 I DIM RIN 68 4 I DIM LS G2 BK S HSD RICS LS G2 BKS HSD RICS LS G2 B'KS HSD RICS ,BKS HSD RICS LS G2 B~K S HSD RICS LS G2 B'K'S HSD RICS FT FT ~723.4440 ~ 361 6. 3070 64~.935 47 .952 39'9.9'6~ O. 600 32 .ir84 O29 27,246 1;936.623 4295.859 ~05.066 2399.364 4493.41~ 316.1~21 O. 199 21' .671 670,223 447,524 300.81'7 5.864 28,35.2 19.998 0.000 329.967 12.99't 0.0.00 SS 14478.550 GR 41.830 CSS 1~658 940 R~TO 21 '. 801 SS 17722.730 GR 23.494 CSS 12504.030 RATO 15.834 SS 23863.640 GR 15,317 CSS 16824.510 RATO 12,341 .SS 24021.6.10 GR 17.757 CSS 17202.220 R~'TC 10,019 SS 4398.785 :GR ~4. 821 CSS 3241 ~!678 R~TO 6.976 SS 0.000 GR 31.870 CSS 0.000 R~TO O.O00 ** FILE TRAILER ** PILE NAME: PASS 4.004 SERVICE NAME: VERSION # : 1 D~TE: 85/11/ EXT FILE NAME: FILE HEADER # 5 ** :ILE NAME: PASS 5.005 ;ERVICE NAME: 'ERSION # : 1 tATE: 85/11/20 RECORD LENGTH: 1024 :ILE TYPE: LO 'REVICUS FILE NAME: INFORMATION RECORDS ** BYTES · MNEM CONTENTS APIN : 5002920518 CN : STANDARD ALASKA PROD WN : SAG DELTA NO. ? FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA LCC : 150.00 FORMAT ** UNITS ENTRY BLOCKS FYPE ENTRY DESCRI:PTION 4 I DEPTHS DECREASE 8 60.0 FRAME SPACING 9 .lIN FRAME SPACI:NG UNITS 11 12 MAXIMUM FRA:~ES/RECORD 0 TERMINATOR, -0.500 LEVEL SPACING 3ATUM SPECI~!ICAT'ION BLO. C~KS ;URV'E REPR ~'AME CODE SI~.E SAMPLE 'UNITS ; C L 6 8 4 1; D I :M .S 68 4 I CPS ~1 68 4 1: C,PS 68 4 I CPS 68 4 I CPS ~i:KS 68 4 I CPS ISS 6 8 4 I CPS ~,SD 68 4 1 SU ~BOR 68 4 1 DIM ~ICS 68 ~ I DIM ** FORMAT ** ENTRY ~LOC'KS TYPE E.NTRY 4 1 8 60.0 9 .lIN 1'1 12 0 - 0 · .5 O0 DATUM SPECIFI DE SCRt!PTION DEPTHS DECREASE FRAME SPACING FRAME SPACING UNITS MAXI'MUM FRAME"S/RECORD TER:MINATOR LEVEL SPACING CATION BLOCKS CUR¥~E REPR NAME CODE ,SIZE SAMPL:E UNITS mmmmmm eeem mmme emmemm emmeN CCL 68 4 t' DIM LS 68 4 1 CPS ~1 68 ~ 1 CPS ~2 68 4 1 CPS MON 68 4 11 CPS ~KS 68 4 t CPS iSS 68 4 I CPS HSD 68 4 I SU RBOR 68 4 I DIM RICS 68 4 I DIM DATA ** CURYE NAME SPD, SS GElS GR B'KL CSS S GM A RATO RIN CURVE NAME SPD SS GElS BKL ¢SS SGMA RATQ RIN REP'R CODE 6.8 58 ~8 68 ~8 58 REPR CODE ~8 6S 68 68 58 4 4 4 . 4 4 4 4 4 SIZE SAMPLE 1 1 t t 1 1 1 1 1 .SAMPLE 1 1 1 1 1 1 1 1 UNITS F/MN CPS CPS CPS SU DI~ DIM UNITS F/'MN::, CPS CPS C PS SU ~IM DIM EPTH 12~37.C(]0 FT 3729.845(] M Ct 0.000 SPO 0.000 LS I 3159.685 :GELS 63073.70(} G~: ON ~760.324 B,KL 259.974 BKS SS 296070.400 SGMA 2~.882 MSD BOR 1.882 R~N 9.150 RICS EPTH 12200.000 FT 3718.5680 CL 0.000 I 6493.301 ON 7278.353 SS ~33849.500 BOR 1.741 EPTH t 2100. ~00 FT 36 CL O.CO0 SPD ,1 10549.330 GE1 iON 6989.1 88 BKL SS 350374.400 SGM BOR I .662 RI'N I. EPTH 12000.(]00 FT 36 CL 0.000 ,1 1Cb41.610 ION 5314.898 SS 371487.200 ~BOR 1.772 M SPD 14.999 LS GElS 65692.560 G2 BKL 103.473 BKS SGMA 17.937 HSD RIN 8.810 RIC$ 88.0870 M 1~.999 LS S 74874.250 G2 119.556 BKS ~ 13.295 ~S.D 8.307 RICS 57.607C M SPD 14.999 LS GElS 79~03.190 G2 BKL 1 25.780 BKS SGMA ~'3.070 MSD RIN '8.185 RICS 3627.127~ M tEPTH 11900.000 FT ~mmmmmmmmmmmm~mmmmmmmmmmmmmmmm O.CO0 SPD t4.999 ,1 1886.463 ~ON 4975.926 iSS 95388.250 [BOR 1-032 LS G~IS 285075'900 G2 BK~ 149.581 BKS SGMA ?.71:6 MSD RIN 3.747..: RICS k~.P~H 11885.50'.0 FT 362:2.7080 M ;'CL 0'.000 ;,t 6669.742 I'ON 5015.145 :SS, 360397.500 ~BOR 1.844 SPD 1'4.999 LS GElS 7114,, ~4.440 G2 BKL : 4.359 ~KS SGMA ~117.298 MS.'D RI'N 8.763 R. IC$ ;TARTING DEPTH !NDING DEPTH =12237.000 FT =11885'.500 FT 3?29.8450 3622-7080 FILE ?R~ILER **' :ILE NAME: PASS 5.005 ;ERVICE ~'ERSION i" . 1 )ATE: 85/11/ IAXIMUM LENGTH: 1024 :tLE TYPE: LO iE'XT FILE NAME: ~* FILE HEADER # 6 ** :ILE NAME: P~SS 6.006 ;ERVICE NAME: ~ERSION # : 1 )~TE: 85/~t/20 ~!~. RECO~D LENGTH: ~024 BYTES :ILE TYPE: LO 'REVIOUS F~'LE NA~E: . INFORMATION RECORDS ** MNEM CONTENTS APIN : 5002920518' CN : STANDARD ALASKA ~N : S~G DELTA N:O. 7 FN : ENDICOTT COUN : rNORTH SLOPE STAT : ALASK~ LCC : 15.0.00 FORMAT ** PR O~ UNITS 6t9.938 599.940 339.9~6 0.780 3C.1~3 1133.685 I 947. 292 338.759 0.288 2~ .470 2009.771 4~7.891 61'1 2G.632 2352.327 4520.711 356.359 0.283 2t.488 904.157 700.416 374.613 I .690 26.742 1300.77'3 22!50.428 39'8.977 0.634 27.352 SS GR 'CSS RATO SS GR CSS RATO SS GR CSS R~TO SS GR CSS RATO SS GR CSS RATO SS GR CSS RATO 14338.570 72.373 9809.023 22.650 18236.890 28.033 12612.450 '16.153 24072.340 17.419 2411:6. 600 18.474 17287.890 10.186 4917.72.3 34 7 5.857 18354.240 ~'5.468 13171.340 14.292 YPE ENTRY DESCRIPTION 4 1 DEPTHS DECREASE 8 60.0 FRAME SPACING 9 .lIN FRAME SPACING UNITS 11 12 MAXIMUM FRAMES/RECORD 0 TERMINATOR -0.500 LEVEL SPACING )ATUM SPECIFICATION BLOCKS ;URVE REPR tAME CODE SIZE SAMPLE UNITS ;CL 68 4 I DIM .S 68 4 I CPS ~1 68 4 1 CPS ~2 68 4 I CPS tON 68 4 I CPS l~l~ S 68 4 I C. P S i:SS 68 4 I CPS tSD 68 4 I SU ~BOR 68 4 I ' DIM. ~;IC S 68 4 I D I M ~* FORMAT ** 'CURVE NAME ,,I, ,i, ,i .m -- .',m S:PO. SS GElS GR BKL CSS SGMA RATO RIN REPR CCDE 68 68 68 68 68 68 68 68 68 SIZE mmm~ 4 4 4 4 4 4 4 SAMPLE 1 1 1 1 1 1 1 1 1 UNITS F/MN CPS CPS API CPS SU DIM DIM ENTRY BLOCKS rYPE ENTRY DESCRIPTION 4 I DEPTHS DECREASE 8 60.0 .FRAME SPACING 9 .~IN FRAME SPACING UNI?S ~1 12 M~XIMUM FRAMES/~ORD 0 TERMINATOR -O.SO0 LE'¥EL SPAC'I~§ ~.,.A T U M SPECIFIC,AT, ION B.LOCK:$ R E P R C U R~ COD'E SIZE SAMP.LE UN'I~'S NaME mmmmmm mmmm mmmm mmmmmm mmmmm mm.mmmm 68 4 I C PS B~K L 68 4 I CPS CSS [SS 68 4 1 CPS SGMA ~SD 6'8 4 I SU EATO R B'O R 68 4 I D',~M R IN RI'CS 68 4 I DIM: ** DATA ** DEPTH 12400.000 FT 3779,528~ M CCL 0000 SP.D O. CO0': L.S G1 1819~818 GE.~'S ':~1782,810 G2 MON 5929.4~0 B;K~ 18~.981 B.KS ~S.$ 33~846.800 SGMA 38.705 MSD RBOR 1.9'57 RIN 9.776 RICS DEPTH 12300.000 FT 3749.0480 M mmmmmmmmm.mmmmmmmm~mmmmmmmmmmmm CCiL O.CO0 SPD 14.999 LS G1 2352.160 GElS 73043.560 5854.656 BKL MON 22.8~700 B~S RBoRISS 36590~ .100 SGMA 30.385 HSD . 028 RIN 9.192 RICS DEPTH 12200.~0 FT 3718.568~ M CCL 0.000 SPD I 4.999 LS G1 621t .781 GElS 63714.970 G2 MON ~271 098 BKL 1~8.~3 B:KS ISS 32 057:300 SGMA 17' ~:"2 "SD RBOR 1.763 RIN 9.382 RICS DEPTH 12100.000 FT 3688.08'70 M CCL 0..000 SPD 14.999 ..':L S Gl: 10586-780 GEIS '7618'5.380 G2 REPR CODE 68 6,8 68 58'9. 941 49.995 6C9.939 2.192 35.526 58B.695 358.1(~0 399.883 0.490 37.441 1030.23~ 2044.481 3~1.987 206-315 .897 t953,294 4331.3.t: 3 3 SIZE 4 4 4 4 4 4 4 S~PLE 1 1 1 1- 1 1 1 1 SS GR CSS RATO SS GR C'SS RATO SS GR CSS RATO SS GR C.SS UNITS F/MN C~S CPS CPS API S~ DIM DIM, I 2228. 780 19.919 9369.063 20.648 12644.59~ 56.70.9 9'772 9~5:3 .s 17545.750 28.061 12196.950 17.045 24t59.630 15.946 1.7014.450 BOR I .734 RIN 8.574 ,EPTH 12000.C00 FT 3657.607C M I I IIIlIII IatIIIIIIlI,IIIII RICS CL 0.000 SPD 15.598 L$ ,1 10340.640 GElS 77731.880 G2 ION 6520.1 45 BKL 98. 849 BKS 'SS 370288.700 SGMA 13,336 MSO ~BOR 1.736 RIM 8.381 RICS tEPTH 11900.000 FT 3627.1270 M ',CL 0.000 SPD 15.695 LS ,1' 5921.926 GElS 79307.~90 G2 ION 5637.234 BKL 225.910 B~S 'SS 383469.500 SGMA 17-884 HSD ',BOR I .902 RIM 8.867 RICS ~EPTH 11800.000 ~T 3596.647C M ;CL O.OOO SPD ~15.169 J'LS ;1' 13029.400 GElS 78719.130 G2 ION. 5678.043 BKL 125.967 BKS ['SS 380822.500 SGMA 10.825 ~MSD ,'80R 1.679 R~N 8.305 RICS IEPTH 11712.500 FT 3569.977~ M' I I III I I IIIIIII III I III IIIlIIIII ~CL 0.000 SPD 14.999 LS ~1 79.992 GElS 15718.430 .G2 ION 5399.461 BKL 189.981 BKiS :SS 78452.1 90 SGMA 57.527 MSD ~BOR 2.044 R~N 9.060 RIC'$ iTARTING DEPTH :12400.000 ~T 37'79.5280 M !NDI'N.G DEPTH :117'1:2. 500 FT 3569.9770 M 20.797 2392.5~0 SS 4313.867 GR 420.61C CSS 0.249 RATO 21 .82~ 1338.658 SS 1943.387 GR 471.7~6 CSS 0.721 RATO 28.61~ 2965.696 SS 6387.672 OR 398.846 CSS C.153 RATC 19.741 139.986 SS 49 99:5 GR css 3.00~. RATO 43. 589 23750.680 20.231 16970.250 9.882 18256.320 37.125 13400.640 13.602 26283.670 10.076 19290.680 8.846 2029.797: 76.356 1799.820 14.500 ,* FILE .TR~:ILER '** ;ILE NAME: P. ASS 6.006 ERSIO'N :'~ : )ATE: 85111,1 I:A'X ZMUM 'LENGTH: ::[LE TYPE: LO ~,* TAPE TRAILER ** rAPE NAME: ~ER.'V[CE ' NAME: PASS } A T E: ...... )RIG~N OF DAT~: FSYS rAPE ¢ONTINU'AT I'ON ~.E.XT TAPE NAME: ~OMMENTS: : 01 ~* REEL' TR~ILEE ** ~EEL ,NAME: SER:¥ICE NAME: BITLIS )ATE : ...... ~'R,~GIN OF DATA: FSYS REEL CONTINUATION~ : 01 ~EXT REEL NAME: :O.MMENTS: DRESSER ATE.AS REEL HEADER - 1 I'APE HEADER - 1 :~LE HEADER - 6 ['~PORMATTON - 6 :ORMAT - 12 ]ATA - 410 FABLE DUMP - 6 :ILE TRAILER - 6 FA:PE TRAILER - 1 ~'EEL TRAILER - l~ T,O T'A'L RECORD;S: 450 LIS CUSTOMER TAPE --- CR'E~TE~ :BY SOS PROGRAM R 2.0 :83110/ 7 O~ lg~ ~,~ ~0000 CO~TI~:'U~TION ~ ~01 PR~]VIC~ TAPE ********** EOF ********** :T.O.~ ~'.:: $.0:'H'I'O ALA.'$K.A'.' P'F..... F'RLLF-:U.,, C',P.,.t'~P'.A"6:-:.'.¥ 000 00'0 '0;t0' 0'6'5: ,S?,G DF.L A #7 000 000 012 065 w' l l:, D C ~.'?: . . .. .00'0 0'0' O. .0'0:.8 0'.6 $ :'l 000 ~0o 002 06~ '~'~ .... . '. ' ' · '..: ..... ..'::....:000:: '. .... .. '...'.... ".'. ..... .? ~ ...... : ..... . .' ...'.,:.:.' ....... .:......'.'.. :: :., ., .... :00.'0 .... ... 0,,0:2".· 06:5.' .... . ~ ~ 000 000 002 065 ************************************************************************************ ~F~u(jF OF T~REE ~UfgS (61522,~t523,61524) hr~p: ~.S~NFS (RECn~P) ******************************************************************************* THIS JOB W~S FOR~ATIED F~r}~ T~ DEC 10 D~T~ ~IT~OUT FIELD PRINTS. IT ~[>P~RR8 THE TOOLS RUN TH~ ~IGINAL DATA CONTAIMED ,27 CI.?VFS~ ~NR~ ~ER~ DROPPED AT THE ~T~5 REO~FST, THESE ~BRE ~N EXTPA DEPTH FIGE~ ,SP.BHC~ & GRjBHC. CLIE~, IT ~PPEARS THAT 7'~F DIL & ~HC WFR~ ~)..tN IN CO~BINATION AS THE SP & GR ~ERE IDENTICAL, ******************************************************************************************* *****~ ************************************************************************ FC ~ [ FD N '~Ti~V BLOCKS T.,Oe,TYPE CLASS FT 0 0 o fL!H~4~ 7 o 0 ~H~' 7 12 46 GAP[ 7 Il ]2 OH~ 7 0 0 ~'S/F 6n 52 32 PU 42 68 2 G/C3 ~2 35 1 ~/C3 42 44 0 I r,~ .42 28 3 42 42 I G.~PI 42 31 OHqM O :O DHN~ 0 25 0 2 MOD 0 F~ 0 0 o o FILe S1ZF PROCFS$ 0 4 0 0 4 0 0 4 0 ~ 0 0 4 0 0 4 0 o 4 0 0 4 0 9 4 0 0 4 0 0 4 0 0 0 .4 0 (.) 0 4 0 0 0 ~4 0 o 0 4 0 0 0- 4 0 0 4 0 0:: .4 SANPI, E REPR CODE 1 68 1 68 ! 68 I 68 ! 68 ! 68 O , 1_ 6g 0 o o 68 0 I 68 0 1 0 ~.2576 5000 -9'9.9 25.0'.0 :g~9 2.500 "9:9:g 2'50'.0 -999 2500 · '9':g'9 ~:5'0"0 SFLU -g99' DRHO -99g FC. Nii' ".999 ~INV -999 PO'TA ~ggg 12500 000'0 · .:"67.3'~ D'~'H'O 0. ...~ 0000 ~CNL 945 17.2011 P["JTA 2500 ILD -999.,2500 SP 250'0 D.? 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