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HomeMy WebLinkAbout177-081MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, April 4, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC NGI-12 PRUDHOE BAY UNIT NGI-12 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/04/2024 NGI-12 50-029-20284-00-00 177-081-0 N SPT 7423 1770810 3500 374 403 402 402 12 13 12 12 REQVAR P Bob Noble 2/9/2024 2 year MIT-IA as per AA AIO 4G.014. Max anticipated injection pressure 3500 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:PRUDHOE BAY UNIT NGI-12 Inspection Date: Tubing OA Packer Depth 647 3691 3671 3660IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240211123727 BBL Pumped:3.6 BBL Returned:3.1 Thursday, April 4, 2024 Page 1 of 1            7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU NGI-12 Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 177-081 50-029-20284-00-00 9693 Conductor Surface Intermediate Production Liner 8651 81 2754 8691 1301 9650 20" 13-3/8" 9-5/8" 7" 8612 27 - 108 27 - 2781 25 - 8716 8391 - 9692 27 - 108 27 - 2708 25 - 7757 7460 - 8650 none 520 2670 4760 7020 none 1530 4930 6870 8160 9186 - 9604 L-80 23 - 8448 8190 - 8570 Structural Baker FB-1 2207 / 2191 8353 7426 Bo York Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 PRUDHOE BAY Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028302 23 - 7512 323-044 13b. Pools active after work: 7" Camco BALO 8353 / 7426 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations 7" 26# x 5-1/2" 17# x 4-1/2" 12.6# PRUDHOE BAY By Samantha Carlisle at 8:30 am, Feb 28, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248), ou=Users Date: 2023.02.27 13:40:09 -09'00' WCB 11-24-2023 177-081 323-044 Water Wash Sundry Number PBU NGI-12 PRUDHOE BAY RBDMS JSB 030223 DSR-2/28/23 ACTIVITYDATE SUMMARY 2/21/2023 T/I/O= 2460/573/2. LRS 72 Water Wash (TUBING WASH/PICKLE). Pumped 10 bbls of 60/40 MeOH, 50 bbls of 120*F diesel and 325 bbls of 120*F fresh water with 0.02% F-103 surfactant into the TBG. Let it soak for 2 hours. Pumped 282 bbls of FW with surfactant into the TBG and freeze protected with 15 bbls of 60/40 MeOH. Final T/I/O= 0/703/15. Daily Report of Well Operations PBU NGI-12 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU NGI-12 Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 177-081 50-029-20284-00-00 ADL 0028302 9693 Conductor Surface Intermediate Production Liner 8651 81 2754 8691 1301 9650 20" 13-3/8" 9-5/8" 7" 8612 27 - 108 27 - 2781 25 - 8716 8391 - 9692 27 - 108 27 - 2708 25 - 7757 7460 - 8650 none 520 2670 4760 7020 none 1530 4930 6870 8160 9186 - 9604 L-80 23 - 84488190 - 8570 Structural 7" Camco BALO 8353 / 7426 2207 / 2191 Date: Bo York Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 PRUDHOE BAY 2-16-23 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov 7" 26# x 5-1/2" 17# x 4-1/2" 12.6# 9-5/8" Baker FB-1 By Samantha Carlisle at 3:24 pm, Jan 26, 2023 323-044 Digitally signed by Bo York (1248) DN: cn=Bo York (1248), ou=Users Date: 2023.01.26 12:16:39 -09'00' MGR08FEB23 X 10-404 DLB 02/01/2023 2420 mgr DSR-1/26/23JLC 2/9/2023 GCW 02/09/23 2/10/23Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.10 10:06:08 -09'00' RBDMS JSB 021023 Well Work Prognosis Well Name:NGI-12 API Number:50-029-20284-00 Current Status:Gas Injector Leg: Estimated Start Date:Feb 16, 2023 Rig:N/A Reg. Approval Req’d?10-403 Date Reg. Approval Received: Regulatory Contact:Carrie Janowski Permit to Drill Number: First Call Engineer:Dave Bjork Office: 907-564-4672 Cell: 907-440-0331 Second Call Engineer: Gas Injection Rate: ~190,000 Mscf/Day Injection Pressure: 3,475 psi Reservoir Pressure (Estimate): 3300 psi Program Objective(s): NGI-12 is a gas cap injection well that has demonstrated a decrease in injectivity. The well has not been water washed since 2019. 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 Gas Injection Wells. Proposed Program: Pump diesel followed by Fresh Water and Surfactant as per attached pumping template. 177-081 MPSP = 3300-880 = 2420 psi mgr Well Work Prognosis Well Work Prognosis H2S Value N/A H2S Date N/A Work Desc AFE Date Engineer Phone Job Objective Pump Schedule Stage Fluid Type Pump Into Vol (bbls) Rate (bpm)Max Pres (psi) 1 Spear Methanol / Water TBG 10 1-3 2500 2 Solvent Diesel TBG 50 1-3 2500 3 Over-Flush Fresh Water TBG 600 see below 1800 4 Spear Methanol / Water TBG 15 1-3 1800 5 6 7 Detailed Procedure David Bjork (907) 564-4672 Well NGI-12 GI Water Wash 01/16/22 Increase well injectivity by performing a water wash. -Use 2 full uprights of fresh water mixed with 0.02% F-103 surfactant. Use 50 bbls of diesel from COTU. -Heat diesel to ~120*F -Order FreshWater to be at ~160*F -Freeze Protect contingent on WSL and ambient temp/seasonal pumping 1.) 10 bbl 60/40 MeOH/water spear 2.) 50 bbls COTU diesel (heated to ~120 deg F)at ~1 to 3 bpm. 3.) Pump 600 bbls of fresh water with 0.02% F-103 surfactant per following: a.) Pump 325 bbls of fresh water with 0.02% F-103 surfactant at ~5 bpm. Max pressure during this pumping can reach 1800 psi. Once 340 bbls has been pumped, shut-down pumps and let diesel soak across perfs for 2 hours -this should allow ~ 25 bbls of diesel to be pumped into perfs and a remaining 25 bbls to soak outside the perfs. b.) After the 2 hour soak time, resume pumping at ~5 bpm for next 275 bbls of fresh water with 0.02% F-103 surfactant. 4.) 15 bbls of 60/40 MeOH/water freeze protect. 5.) RDMO. Return well to gas injection. if well isnt going to be POI then FP See ~ pumping time schedule and notesbelow COTU diesel has xylene impurities left, treat with proper safety precautions Clear Well Work Prognosis Pump Time Fluid type vol (bbls)rate (bpm)Time (min) time (hours) methanol 10 1 10 0.17 diesel 50 1.5 33 0.56 FW flush 325 5 65 1.08 Soak 2.00 FW flush 275 5 55 0.92 methanol cap 15 1.5 10 0.17 4.89 Soak Time of Diesel/Xylene 1 2 Tubing has gas in it prior to pumping, any fluids pumped first will free fall. Soak time - keep at a minimum of ~2 hours; xylene works best with longer soak times (at least on asphaltenes) SBG treatments have a 3 hour soak time as well (just an FYI) Soak time is really a time for diesel/xylene to seep through the perfs vs pushing/rushing through 1Carlisle, Samantha J (OGC)From:Wallace, Chris D (OGC)Sent:Thursday, March 3, 2022 10:53 AMTo:AOGCC Records (CED sponsored)Subject:FW: OPERABLE: Gas Injector NGI-12 (PTD #177081) AA granted for continued Gas InjectionAttachments:AIO 4G.014.pdf  From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>  Sent: Wednesday, March 2, 2022 4:26 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com>; John Conrad <John.Conrad@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: OPERABLE: Gas Injector NGI‐12 (PTD #177081) AA granted for continued Gas Injection  Mr. Wallace,  Gas Injector NGI‐12 (PTD # 1770810) now operates under AA AIO 4G.014 for continued gas injection with known TxIA communication. The well is now classified as OPERABLE.  Please respond with any questions.  Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816      CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe.   2From: PB Wells Integrity  Sent: Saturday, February 12, 2022 7:37 AM To: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: 'Regg, James B (CED)' <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Gas Injector NGI‐12 (PTD #177081) Slow TxIA communication  Mr. Wallace,  Injector NGI‐12 (PTD #177081) passed AOGCC MIT‐IA on 02/10/22 and SSSV has been re‐installed. Our current plan forward is to monitor re‐pressurization while online for an additional 14 days and decide at that point based on the results weather to apply for AA for continued injection or if the TxIA communication has been resolved.  Please call with any questions or concerns.    Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005  From: PB Wells Integrity  Sent: Thursday, January 20, 2022 1:15 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com> Subject: UNDER EVALUATION: Gas Injector NGI‐12 (PTD #177081) Slow TxIA communication  Mr. Wallace,  Injector NGI‐12 (PTD #177081) is suspected to have slow TxIA communication <5 psi / day as evidenced by daily pressure monitoring and a 40’ liquid level in the IA. The well is now classified as UNDER EVALUATION and will remain online for diagnostics / corrective action.  Plan forward: 1. Downhole diagnostics: Packoff test tubing / GX sealant control & balance lines. 2. Well Integrity: Monitoring / further action as needed.  Please call with any questions or concerns.    3Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005  From: Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>  Sent: Wednesday, July 7, 2021 3:46 PM To: Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>; chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio ‐ (C) <John.Condio@hilcorp.com>; Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: RE: UPDATE: OPERABLE: Gas Injector NGI‐12 (PTD #177081) extend monitoring period after GX pumping  Mr. Wallace,   DHD pumped a GX sealant job on 05/18/21 into the Control and Balance SSSV lines and during the subsequent extended monitoring period the IA has not demonstrated any re‐pressurization.    The well is now classified as OPERABLE.    Please respond with any questions.  Aras Worthington Hilcorp Alaska LLC Well Integrity Engineer, PE Aras.worthington@hilcorp.com 907.564.4763 907.440.7692 mobile   4From: Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>  Sent: Monday, June 14, 2021 10:34 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John  5Condio ‐ (C) <John.Condio@hilcorp.com>; Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: UPDATE: UNDER EVALUATION: Gas Injector NGI‐12 (PTD #177081) extend monitoring period after GX pumping Mr. Wallace, DHD pumped the GX sealant job on 05/18/21 and during the subsequent monitoring period, the IA has not demonstrated any re‐pressurization. However, due to the slow nature of re‐pressurization when the well was initially reported, the Under Evaluation period will be extended for continued monitoring. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816   6From: Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>  Sent: Monday, May 17, 2021 12:57 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio ‐ (C) <John.Condio@hilcorp.com>; Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Gas Injector NGI‐12 (PTD #177081) slow IA re‐pressurization Mr. Wallace,  7Gas Injector NGI‐12 (PTD # 177081) has been identified to have a slow IA re‐pressurization trend. A possible source of the re‐pressurization could be from a Wireline Retrievable SSSV that was set in November of 2020. The well is now classified as UNDER EVALUATION and is on the 28‐day clock for diagnostics. Plan Forward: 1.DHD: Pump GX sealant down control line2.DHD: Monitor for BUR post GX pumping3.Well Integrity: Additional diagnostics as neededPlease respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816   8The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UPDATE UNDER EVALUATION: Gas Injector NGI-12 (PTD #177081) Slow TxIA communication Date:Tuesday, February 15, 2022 8:13:15 AM Attachments:image001.pngimage002.pngimage003.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, February 12, 2022 7:37 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Gas Injector NGI-12 (PTD #177081) Slow TxIA communication Mr. Wallace, Injector NGI-12 (PTD #177081) passed AOGCC MIT-IA on 02/10/22 and SSSV has been re-installed. Our current plan forward is to monitor re-pressurization while online for an additional 14 days and decide at that point based on the results weather to apply for AA for continued injection or if the TxIA communication has been resolved. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Thursday, January 20, 2022 1:15 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com> Subject: UNDER EVALUATION: Gas Injector NGI-12 (PTD #177081) Slow TxIA communication Mr. Wallace, Injector NGI-12 (PTD #177081) is suspected to have slow TxIA communication <5 psi / day as evidenced by daily pressure monitoring and a 40’ liquid level in the IA. The well is now classified as UNDER EVALUATION and will remain online for diagnostics / corrective action. Plan forward: 1. Downhole diagnostics: Packoff test tubing / GX sealant control & balance lines. 2. Well Integrity: Monitoring / further action as needed. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Wednesday, July 7, 2021 3:46 PM To: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>; chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: RE: UPDATE: OPERABLE: Gas Injector NGI-12 (PTD #177081) extend monitoring period after GX pumping Mr. Wallace, DHD pumped a GX sealant job on 05/18/21 into the Control and Balance SSSV lines and during the subsequent extended monitoring period the IA has not demonstrated any re-pressurization. The well is now classified as OPERABLE. Please respond with any questions. Aras Worthington Hilcorp Alaska LLC Well Integrity Engineer, PE Aras.worthington@hilcorp.com 907.564.4763 907.440.7692 mobile From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Monday, June 14, 2021 10:34 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: UPDATE: UNDER EVALUATION: Gas Injector NGI-12 (PTD #177081) extend monitoring period after GX pumping Mr. Wallace, DHD pumped the GX sealant job on 05/18/21 and during the subsequent monitoring period, the IA has not demonstrated any re-pressurization. However, due to the slow nature of re-pressurization when the well was initially reported, the Under Evaluation period will be extended for continued monitoring. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Monday, May 17, 2021 12:57 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Gas Injector NGI-12 (PTD #177081) slow IA re-pressurization Mr. Wallace, Gas Injector NGI-12 (PTD # 177081) has been identified to have a slow IA re-pressurization trend. A possible source of the re-pressurization could be from a Wireline Retrievable SSSV that was set in November of 2020. The well is now classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD: Pump GX sealant down control line 2. DHD: Monitor for BUR post GX pumping 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that 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 considersappropriate. MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Guy Cook Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, February 24, 2022 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC NGI-12 PRUDHOE BAY UNIT NGI-12 Sre: Inspector Reviewed By: P.I. Supry Comm Well Name PRUDHOE BAY UNIT NGI-12 API Well Number 50-029-20284-00-00 Inspector Name: Guy Cook 177-081-0 2/10/2022 Permit Number: Inspection Date: Insp Num: mitGDC220210074718 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NGI-12 ' Type Inj G -TVD 7423 Tubing I78 619 607 598 PTD 177081a Type Test SPT est psi 1856 IA 680 3652 3647 _ 3645 BBL Pumped: 3.2 BBL Returned: 3.1 OA 0 0 _ 0 0 Interval OTHER P/F P Notes: AA application MIT -IA for a slow TxIA communication. Testing completed with a triplex pump and calibrated gauges. i Thursday, February 24, 2022 Page I of 1 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Gas Injector NGI-12 (PTD #177081) Slow TxIA communication Date:Friday, January 21, 2022 11:02:08 AM Attachments:image001.pngimage002.pngimage003.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, January 20, 2022 1:15 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com> Subject: UNDER EVALUATION: Gas Injector NGI-12 (PTD #177081) Slow TxIA communication Mr. Wallace, Injector NGI-12 (PTD #177081) is suspected to have slow TxIA communication <5 psi / day as evidenced by daily pressure monitoring and a 40’ liquid level in the IA. The well is now classified as UNDER EVALUATION and will remain online for diagnostics / corrective action. Plan forward: 1. Downhole diagnostics: Packoff test tubing / GX sealant control & balance lines. 2. Well Integrity: Monitoring / further action as needed. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Wednesday, July 7, 2021 3:46 PM To: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>; chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: RE: UPDATE: OPERABLE: Gas Injector NGI-12 (PTD #177081) extend monitoring period after GX pumping Mr. Wallace, DHD pumped a GX sealant job on 05/18/21 into the Control and Balance SSSV lines and during the subsequent extended monitoring period the IA has not demonstrated any re-pressurization. The well is now classified as OPERABLE. Please respond with any questions. Aras Worthington Hilcorp Alaska LLC Well Integrity Engineer, PE Aras.worthington@hilcorp.com 907.564.4763 907.440.7692 mobile From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Monday, June 14, 2021 10:34 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: UPDATE: UNDER EVALUATION: Gas Injector NGI-12 (PTD #177081) extend monitoring period after GX pumping Mr. Wallace, DHD pumped the GX sealant job on 05/18/21 and during the subsequent monitoring period, the IA has not demonstrated any re-pressurization. However, due to the slow nature of re-pressurization when the well was initially reported, the Under Evaluation period will be extended for continued monitoring. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Monday, May 17, 2021 12:57 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Gas Injector NGI-12 (PTD #177081) slow IA re-pressurization Mr. Wallace, Gas Injector NGI-12 (PTD # 177081) has been identified to have a slow IA re-pressurization trend. A possible source of the re-pressurization could be from a Wireline Retrievable SSSV that was set in November of 2020. The well is now classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD: Pump GX sealant down control line 2. DHD: Monitor for BUR post GX pumping 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that 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 considersappropriate. MEMORANDUM TO: Jim Regg f I-31 Ot Z -f P.I. Supervisor (2t, ( 1 FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, August 23, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC NGI-12 PRUDHOE BAY UNIT NGI-12 Sre: Inspector Reviewed By: P.I. Supry l I�— Comm Well Name PRUDHOE BAY UNIT NGI-l2 API Well Number 50-029-20284-00-00 Inspector Name: Lou Laubenstein Permit Number: 177-081-0 Inspection Date: 8/15/2021 Insp Num: mitLOL210815145430 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NGI-12 _......... Type Inj G TVD 7423 TubiIIg 3262 3268 3272 - 3272 - PTD 1770810 'Type Test SPT ,Test psi 1856 IA 613 2605 2594 2591 " BBL Pumped: 9.1 BBL Returned: 6 OA 28 32 31 31 Interval 4YRTST VIF P y Notes: 4 year MIT -IA Monday, August 23, 2021 Page 1 of I Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity<PBFieldWellIntegrity@hilcorp.com> Sent: Wednesday, July 7, 2021 3:46 PM To: Alaska NS - PB - Field Well Integrity; Wallace, Chris D (CED) Cc: Regg, James B (CED); Oliver Sternicki; John Condio - (C); Alaska NS - PB - Field Well Integrity Subject: RE: UPDATE: OPERABLE: Gas Injector NGI-12 (PTD #177081) extend monitoring period after GX pumping Mr. Wallace, DHD pumped a GX sealant job on 05/18/21 into the Control and Balance SSSV lines and during the subsequent extended monitoring period the IA has not demonstrated any re -pressurization. The well is now classified as OPERABLE. Please respond with any questions. Aras Worthington Hilcorp Alaska LLC Well Integrity Engineer, PE Aras.worthin2ton(@hilcoro.com 907.564.4763 907.440.7692 mobile Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Monday, June 14, 2021 10:34 AM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Aras Worthington; Oliver Sternicki; John Condio - (C); Alaska NS - PB - Field Well Integrity Subject: UPDATE: UNDER EVALUATION: Gas Injector NGI-12 (PTD #177081) extend monitoring period after GX pumping — - Mr. Wallace, DHD pumped the GX sealant job on 05/18/21 and during the subsequent monitoring period, the IA has not demonstrated any re -pressurization. However, due to the slow nature of re -pressurization when the well was initially reported, the Under Evaluation period will be extended for continued monitoring. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity/ Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 STATE OF ALASKA Vj C�1VpE) ALASKA OIL AND GAS CONSERVATION COMMISSION tl Nm, y 6.REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ {n) i^_6j Pull Tubing ❑ Operation shuldown2019 ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Chang A o PmgraLn PC ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other p 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ❑ Exploratory ❑ 5. Permit to Drill Number 177-081 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 0 6API Number: 50-029-20284-00-00 7 Property Designation (Lease Number): ADL 028302 8. Well Name and Number: PBU NGI-12 9. Logs (List logs and submit electronic and printed data per 20AAC25.071). 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 9693 feet Plugs measured None feet true vertical 8651 feet Junk measured None feet Effective Depth: measured 9650 feet Packer measured 8353 feet true vertical 8612 feet Packer true vertical 7425 feet Casing: Length: Size: MD: TVD: Burst. Collapse: Structural Conductor 81 20" 27-108 27-108 1530 520 Surface 2754 13-3/8" 27-2781 27-2708 4930 2670 Intermediate 8691 9-5/8" 25-8716 25-7757 8150/6870 5080/4760 Production Liner 1301 7" 6391 -9692 7460-8650 8160 7020 Perforation Depth: Measured depth: 9186-9604 feet True vertical depth: 8190-8570 feet Tubing (size, grade, measured and true vertical depth) T' 26# x 4-1/2" 12.6# L-80 23-8448 23-7512 Packers and SSSV (type, measured and Baker FB -1 Packer 8353 7426 true vertical depth) Carrico WRDP-2 SSV 2207 2181 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descrptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 206998 0 350 3476 Subsequent to operation: 0 231245 0 350 3476 14. Attachments: (rcgmred per2a nac 25 070.25.071. a 25.2821) 15. Well Class after work: Daily Report of Well Operations 21 Exploratory ❑ Development ❑ Service 0 Stratigrephic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WI NJ ❑ WAG ❑ GINJ m SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-525 Authorized Name: Brown, Don L. Contact Name: Brown, Don L. Authorized Title: Petroleum Engineer Contact Email: browd2@BP.com Authorized Signature: Date: ( J'LL^(,✓� !,2 Contact Phone: +1 9075644675 Form 10-404 Revised 04/2017 ��,�� G.itzF,QFzt� ABDMS DEC 17 2019 Submit Original Only Daily Report of Well Operations PBU NGI-12 ACTIVITYnATP T/1/02608/345/10 (Water Wash) Pumped 10 bbls 60/40 meth down TBG followed by 208 bbls 100* Diesel Xylene followed by 3 bbls 60/40 meth spacer followed by 250 bbls Water w/F103 surfactant down TBG, Freeze protected suface lines with 2 bbls 60/40. Let soak for 4 hours. ***Job 11/27/2019 continued on 11/28/2019*** ***Job continued from 11/27/2019*** TBG Wash (DSL Xylene, 0.02% F103 Surfactant) Pumped 200 bbis 150* freshwater (F-103) surfractant @ 0.5 bpm, followed by 120 bbls 150* freshwater (F-103) @ 3bpm followed by 10 bbls 60/40 meth cap. DSO notified of well status upon 11/28/2019 departure. FWHP=452/387/18 TREE = 6 3/8" CMU WELLHEAD= GRAY ACTUATOR= BAKER KB. ELEV = 44.0' BE ELEV = NA KOP = 1825' Max Angle = 35 @ 5188' Datum MD = 9206-9222 Datum TV D = 8800' SS =12.347" H 2781' Minimum ID = 3.725" @ 8436' 4-1/2" OTIS XN NIPPLE TBG, 26#, L-80,.0383 bpf, ID = 6.276" I—F 8344' 14-1/2" TBG, 12.6#, L-80_0152 bpf, ID = 3.958" 1 19-5/8" CSG, 47#, N-80, ID = 8.681" I PERFORATION SUMMARY REF LOG: BHCS ON 12/20/78 A NGLE AT TOP PERF: 24 @ 9186' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 04/02/10 4 9186-9206 O 01/23/80 3-3/8" 4 9206-9222 O 05/23/87 4 9222-9247 O 01/23/80 4 9264-9284 O 01/23/80 3-3/8" 4 9284-9296 0 05/23/87 4 9296-9326 O 01/23/80 3-3/8" 4 9326-9340 O 05/23/87 4 9340-9360 O 01/23/80 3-3/8" 4 9360-9374 O 05/23/87 4 9374-9394 O 01/23/80 3-3/8" 4 9394-9414 O 05/23/87 4 9414-9434 O 01/23/80 3-3/8" 4 9444-9450 O 05/23/87 4 9450-9465 O 01/23/80 3-3/8" 4 9465-9472 O 05/23/87 4 9479-9499 O 01/23/80 3-3/8" 4 9499-9517 0 05/23/87 4 9517-9542 O 01/23/80 4 9553-9573 O 01/23/80 4 9584-9604 O 01/23/80 bpf, ID = 6.184" SAFETY NOTES: WELL REQUIRES A SSSV. NG I -12 'NEEDED FOR EMERGENCY FIELD FUEL GAS DATE REV BY I COMMENTSDATE REV BY COMMENTS 12/31/78 ORIGINAL COMPLETION 12125/87 ROWAN3 RWO 04/02/10 DC/JMD SAFETY NOTE UPDATE 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE 03/01/11 MEF/PJC TREE C/O (08/21/10) I7" CAMOO BAL-O SSSV N, ID = 5.937 1 'BJ'J•1MA16I41i 19-5/8" FOC 17" X 5-1/2" XO, ID = 4.892" 1 5-1/2" BKR G-22 LOC SEAL ASSY, ID = 4.875" 9-518" BKR FB -1 PKR, ID = 6.00" BKR SBFID 7-5/8" X 4-1/2" XO, ID = 3.958" I IUF'UF BUf TIEBACK SLV, D=7.00" 9-5/8" X 7" BOT MC LNR HGR 14-1/2" OTIS XN NP. D = 3.725" 1 14-1/2" WLEG, ID=3.958" 1 PRUDHOE BAY UNIT WELL: NGI-12 PERMIT No: 177-0810 API No: 50-029-20284-00 1, T11 N, R14E 372' FSL & 865' FWL THE STATE OfALASKA GOVERNOR MIKE DUNLEAVY Ryan Thompson Petroleum Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU NGI-12 Permit to Drill Number: 177-081 Sundry Number: 319-525 Dear Mr. Thompson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.Qogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Jere M. Price Chair DATED this day of November, 2019. IBDMSL�- NOV 18 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations Shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter -Casing ❑ Other Water Wash 0 . 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number 177-081 ' 3. Address: P.O. Boz 196512 Anchorage, AK 99519-6612 Stratigraphic ❑ Service D 6. API Number: 50-029-20284-00-00 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number. Will planned perforations require a spacing exception? Yes ❑ No 21 PBU NGI-12 - 9. Property Designation (Lease Number): 10. Field/Pools: ADL 0028302 • PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft) : Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9693 8651 9650 8612 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 81 20" 27-108 27-108 1530 520 Surface 2754 13-3/8" 27-2781 27-2708 4930 2670 Intermediate 8691 9-5/8" 25-8716 25-7757 8150 / 6870 5080/4760 Production Liner 1301 7" 8391 -9692 7460-8650 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grace: Tubing MD (ft): 918E - 9604 8190 - 8570 7" 26# x 4-i/2" 12.6# L-80 23-8448 Packers and SSSV Type: Baker FB -1 Packer Packers and SSSV MD (ft) and TVD (ft): 8353/7426 Cameo WRDP-2 SSV 2207 2181 12. Attachments: Proposal Summary 0 Wellbore Schematic ® 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service R1 14. Estimated Date for Commencing Operations: 11/29/2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ 0' O ❑ P Shutdown Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Thompson, Ryan be deviated from without prior written approval. Contact Email: RYAN.THOMPSON@bp.com Authorized Name: Thompson, Ryan Contact Phone: +1 907 564 4535 Authorized Title: Petroleum, Engineer Authorized Signature:Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number:TT 1 319 a5-0-26— Plug Integrity 11 BOP Test ❑ Mechanical Integrity Test 11 Location Clearance ❑ cJa " Other: Post Initial Injection MIT Req'tl? Yes 11No ❑ 3BDMSW—/moV 1 B 119 Spacing Exception Required? Yes ❑ No Subsequent Form Required /0 —yp e APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: I 11 v U 0000V 1/'�� 61OZ 5l AON Form 10-40 Revised 04/2017 Approved applicatic 'I ! R & .A date of approval, a 3A43 'D plical 10-403 Sundry Application for Well PBU NGI-12 PTD#177-081 Expected Start Date: November 29, 2019 Current condition of well: Gas Injection Well, Operable, Online: Gas Injection Rate: 143541 Mscf/Da Injection Pressure: 3308 psi Reservoirpressure: 3380 psi Program objective(s): NGI-12 has had several successful water washes historically, the most recent being on 9/17/10. These water washes have been successful and injectivity in this well has decreased since the 2010 water wash. If this water wash goes to plan, injectivity should improve as the process is designed to dissolve salts and possibly asphaltenes in the tubing and formation. Diesel/Xylene washes have been used successfully in the past on the NGI/WGI/AGI gas injectors to improve injectivity. Proposed program: 1. Pump diesel/xylene water wash as per attached pumping template. BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Wen NGI-12 Work Dese Fluid Tire, AFE 0 Data 11/13/19 Engineer Ran Thom son Phone 907 564-4535 H2S Value N/A H2S Date N/A Job Ob'edive Increase well njectivity by performing a water wash. Use 2 full uprights of freshwater mixed with 0.02%F-103surfactant. Use200bblsofdiesel/xylene. Pum Schetlule 1.) 10 b6160/40 MeO H/water spear 2.) 200 bills 50/50 diesel/xylene heated to 80 degrees F or as hot as LRS can heat it. 3.) Pump 600 bbls of fresh water with 0.02% F-103 surfactant per following: a.) Pump 250 bbls of fresh water with 0.02% F-103 surfactant at 1-3 bpm, shut -down pumps and let diesel/xylene soak across perfs for 4 hours -this should allow ^ 100 bbls of D/%to be pumped into perfs and a remaining 100 bbls to soak. b.) Resume pumping at 0.5 bpm for next 200 bbls of fresh water with 0.02%F-103 surfactant. c.) Once 450 bbls of fresh water with 0.02% F-103 surfactant has been pumped resume pumping at 1-3 bpm for remainder of over0ush )^150 bb Is). 4.) 106615 of 60/40 McOH/waterfreeze protect 5.)ROM O. Return well to gas injection. WIT *1 Test Type Target Pressure Max Applied Pressure Test Fluid Integrity Limns Confirmed MIT#2 Test Type Target Pressure Max Applied Pressure Test Fluid Integrity Limits Confined MIT#3 ETyposure nfirmed Steps Fluid Tire, Pump Into Vol bbls) Rate b on Max: Pres s 1 Spear Methanol/Water TBG 10 1-3 3000 2 Solvent DieselM ene TBG 200 Max 3000 3 Over -Flush Fresh Water TBG 600 See Below 3000 4 Freeze Protect Methanol/Water TBG 10 1-3 3000 5 6 7 1.) 10 b6160/40 MeO H/water spear 2.) 200 bills 50/50 diesel/xylene heated to 80 degrees F or as hot as LRS can heat it. 3.) Pump 600 bbls of fresh water with 0.02% F-103 surfactant per following: a.) Pump 250 bbls of fresh water with 0.02% F-103 surfactant at 1-3 bpm, shut -down pumps and let diesel/xylene soak across perfs for 4 hours -this should allow ^ 100 bbls of D/%to be pumped into perfs and a remaining 100 bbls to soak. b.) Resume pumping at 0.5 bpm for next 200 bbls of fresh water with 0.02%F-103 surfactant. c.) Once 450 bbls of fresh water with 0.02% F-103 surfactant has been pumped resume pumping at 1-3 bpm for remainder of over0ush )^150 bb Is). 4.) 106615 of 60/40 McOH/waterfreeze protect 5.)ROM O. Return well to gas injection. WIT *1 Test Type Target Pressure Max Applied Pressure Test Fluid Integrity Limns Confirmed MIT#2 Test Type Target Pressure Max Applied Pressure Test Fluid Integrity Limits Confined MIT#3 ETyposure nfirmed TREE = 6 3/8" CNV WELLHEAD= GRAY ACTUATOR= BAKER KS. ELEV = 44.0' BF. B -EV = NA KOP= 1825' Max Angle = 35 @ 5188' Datum MD = 9206-9222 Datum TVD = 8800' SS F,3-3—/B'—CSG 72#, N -8-01—D= 12.347" Minimum ID = 3.725" @ 8436' 4-1/2" OTIS XN NIPPLE 7" TBG, 26#, L-80,.0383 bpf, ID = 6.276" —T $3" 1/2" TBG, 12.6#, L-80_0152 bpf, ID = 3.958" 9-5/8" CSG, —47#.r+80. ID = 8.681 PERFORATION SUMMARY REF LOG: BHCS ON 12/20/78 ANGLE AT TOP PERF: 24 @ 9186' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 04/02/10 4 9186-9206 O 01/23/80 3-3/8" 4 9206-9222 O 05/23/87 4 9222-9247 O 01/23/80 4 9264-9284 O 01/23/80 3-3/8" 4 9284-9296 O 05/23/87 4 9296-9326 O 01/23/80 3-3/8" 4 9326-9340 O 05/23/87 4 9340-9360 O 01/23/80 3-3/8" 4 9360-9374 O 05/23/87 4 9374-9394 O 01/23/80 3-3/8" 4 9394-9414 O 05/23/87 4 9414-9434 0 01/23/80 3-3/8" 4 9444-9450 O 05/23/87 4 9450-9465 0 01/23/80 3-3/8" 4 9465-9472 O 05/23/87 4 9479-9499 O 01/23/80 3-3/8" 4 9499-9517 O 05/23/87 4 9517-9542 O 01/23/80 4 9553-9573 0 01/23/80 4 9584-9604 O 01/23/80 M 7" LNR, 29#, SAFETY NOTES: WELL REQUIRES A SSSV. NG 1 = 12 ***NEEDED FOR EMERGENCY FIELD FUEL GAS*** DATE REV BY I COMMENTS DATE REV BY COMMENTS 12/31178 ORIGINAL COM PLETION 12/25/87OWAN 3 RTO 04/02/10 DC/JMD SA FET' NOTE UPDATE 02/11/11 MB/JMD I ADDED SSSV SAFETY NOTE 03/01/11 NEF/PJC TREEGO(08/21/10) 17" CAMCO BAL-O SSSV N, ID = 5.937 1 M111-IM141N 7" X 5-1/2" XO, ID = 4.692" 1 5-1/2" BKR G-22 LOC SEAL ASSY, 9-5/8" BKR FB -1 PKR, ID = 6.00" BKR SBE, ID=6.00" 7-5/8" X TOP OF BOT TIEBACK SLV, ID = 7.00" 9-5/8" X 7" BOT MC LNR HGR 4-1 /2" OTIS XN NIP, ID = 3.725" 4-1/2" WLEG, ID=3.958" 17" MARKER JTS (TWO) PRUDHOE BAY UNIT WELL: NGI-12 PERMIT No: 177-0810 AR No: 50-029-20284-00 SEC 1, T11 N, R14E 372' FSL & 865' FWL C Wallace. Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday, August 12, 2018 1:44 PM To: Wallace, Chris D (DOA); AK, OPS EOC Specialists; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS Pipeline Compl Specialist; AKOpsProdEOCTL; G GPB FS1 Drillsites; Oestgaard, Finn; Stone, Christopher; Vandergon, Mark A Cc: Regg, James B (DOA); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity, AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Roma, Louis A; Sternicki, Oliver R, Tempel, Joshua; Worthington, Aras J Subject: OPERABLE: Injector NGI-12 (PTD #1770810) monitors indicate no signs of IA repressurization external -email: 0 All, Gas Injector NGI-12 (PTD #1770810) was placed Under Evaluation on 07/22/18 for possible IA repressurization. Follow up monitors have indicated no IA repressurization beyond thermal effects. The well will be classified back to OPERABLE. Please respond with any questions Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Otfice: 907-659-8110 SCAH%Efl AUG 14 201b • Wallace, Chris D (DOA) • From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday, July 22, 2018 1:57 PM To: Wallace, Chris D (DOA); AK, OPS EOC Specialists; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL, G GPB FS1 Drillsites; Oestgaard, Finn; Stone, Christopher; Vandergon, Mark A Cc: Regg, James B (DOA); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: UNDER EVALUATION: Injector NGI-12 (PTD #1770810) possible slow IA repressurization All, Gas Injector NGI-12 (PTD #1770810) has been identified as having possible anomalous IA repressurization. The well will be classified as UNDER EVALUATION and is on the 28 day clock for continued monitoring and any additional diagnostics. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 �C.ANIiIEfl .11JI 2 7 a,b • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Friday,August 18,2017 Jim Regg f P.I.Supervisor 1\1y &(z j/ SUBJECT:Mechanical Integrity Tests ( BP EXPLORATION(ALASKA)INC. NGI-12 FROM: Brian Bixby PRUDHOE BAY UNIT NGI-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry. 32 NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-12 API Well Number 50-029-20284-00-00 Inspector Name: Brian Bixby Permit Number: 177-081-0 Inspection Date: 8/16/2017 - Insp Num: mitBDB170816140511 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NGI-12 "Type Inj G TVD 7423 Tubing 3357 ' 3355 3362 3386 - 3390 PTD 1770810 Type Test SPT Test psi 1856 IA 27 2304 - 2301 2334 2339 BBL Pumped: 32 BBL Returned: 2.7 - OA 2 2 " 2 2 - 3 Interval 4YRTST P/F P vl Notes: SCANNED ! Friday,August 18,2017 Page 1 of 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Wednesday, May 06, 2015 12:50 PM To: AK, OPS FS1 OSM;AK, OPS FS1 Facility OTL;AK, OPS FS1 Field OIL;AK, OPS FS1 DS Ops Lead;AK, OPS PCC EOC IL;AK, D&C Well Services Operations Team Lead;AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS Prod Controllers;AK, OPS FS1 GAS INJ OPERATOR; Morrison, Spencer;Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer; Regg,James B (DOA);AK, OPS FF Well Ops Comp Rep Subject: OPERABLE:Injector NGI-12 (PTD# 1770810) MIT-IA Passed Attachments: image001.png; image002.png;Injector NGI(PTD# 1770810)Injection and TIO plot 05-06-15.docx; MIT PBU NGI-12 05-04-15.xls All, Injector NGI-12 (PTD#1770810) passed an non witnessed MIT-IA on May 3,2015. A positive pressure pack off test on the tubing hanger passed on May 1, 2015. The passing test confirms two competent barriers in the wellbore. The well is reclassified as Operable. • Well status is Operable • A SSSV is required for injection Copies of the passing MIT-IA, injection plot, and TIO plot are included for reference. Thank you, Kevin Parks iAlie lithe 11'intney Pettus) BP Alaska-Well Integrity Coordinator GWGlobal Wells SCANpEO MAY 2015 Organization Office: 907.659.5102 WIC Email:AKDCWelllntegntyCoordmator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Saturday, April 18, 2015 8:23 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; AK, OPS FS1 GAS INJ OPERATOR; Morrison, Spencer; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; 'jim.regg@alaska.gov'; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Hidalgo, Ramon; Pettus, Whitney Subject: UNDER EVALUATION: Injector NGI-12 (PTD# 1770810) Inner Annulus Repressurization 1 All, Gas Injector NGI-12 (PTD#1770810) has begun to exhibit slow tubing by inner annulus communication.The well has been reclassified as Under Evaluation and may remain online for further diagnostics. Plan Forward: 1. Wellhead: PPPOT-T 2. Downhole Diagnostics: Perform MIT-IA then bleed down inner annulus pressure 3. Well Integrity Engineer: Monitor TIO pressures for 7 to 14 days 4. Well Integrity Engineer:Additional diagnostics as needed A copy of the TIO plot have been included for reference. Please call with any questions. Thank you, Whitney Pettus (Alternate:Kevin Parks) BP�AllasV Vska-Well Integrity Coordinator U g.r,4t.i109 on WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com 2 • • Injector NGI-12 (PTD#1770810) Injection plot 05-06-15 3550. 51 4111. 350 - - 330 ^V �•--�.�—�....� v 3.10(. 1500 2K0 2]00 22500 0 24 2 00 1200 204 21150 -;15lot 004 550 leo m0 —M no —6 1600 -90.500�' —05:5 1550. On 1550 -9n.550 1.305: :72 202 200 1 a -50.350 ,am 950 50050 ►V 'GO •600 .0 00E 50 5 -50504 x550 350 250 -,0304 100 iI Injector NGI-12 (PTD#1770810)TIO plot 05-06-15 450 1 3500 —0-14 y—M 140 —0A OOM000 —a ou 000515 0211315 022015 0202115 0305'15 031505 032305 0327,5 040315 041015 04 215 042415 M0'.15 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reag )alaska.00vi AOGCC.Insoectorsl7a alaska.aov; phoebe.brooks@alaska.gov chris.wallace@alaska.gov OPERATOR: BPXA FIELD/UNIT/PAD: Greater Prudhoe Bay/Prudhoe Bay/NGI DATE: 05/03/15 OPERATOR REP: Kevin Parks AOGCC REP: Non-Witnessed Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NGI-12 Type lnj. G ND 7,423' Tubing 3,377 3,373 3,371 3,369 Interval O P.T.D. 1770810 Type test P Test psi 1855.75 Casing 233 2,507 2,481 2,466 P/F P Notes: Under Evaluation Well-Evaluate TxIA comm OA 57 59 61 61 Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In).- ND Tubing _ Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Int. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Dulling Waste M=Annulus Monitonng I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industnal Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT PBU NGI-12 05-04-15.xls Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, April 18, 2015 8:23 PM To: AK, OPS FS1 OSM;AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OIL;AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC IL;AK, D&C Well Services Operations Team Lead;AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; AK, OPS FS1 GAS INJ OPERATOR; Morrison, Spencer;Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; Regg,James B (DOA);AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Hidalgo, Ramon; Pettus, Whitney Subject: UNDER EVALUATION:Injector NGI-12 (PID# 1770810)Inner Annulus Repressurization Attachments: image001.png; NGI-12 TIO and Injection Plot 04-18-15.docx; NGI-12 Wellbore Schematic.pdf All, Gas Injector NGI-12 (PTD# 1770810) has begun to exhibit slow tubing by inner annulus communication.The well has been reclassified as Under Evaluation and may remain online for further diagnostics. Plan Forward: 1. Wellhead: PPPOT-T 2. Downhole Diagnostics: Perform MIT-IA then bleed down inner annulus pressure 3. Well Integrity Engineer: Monitor TIO pressures for 7 to 14 days 4. Well Integrity Engineer:Additional diagnostics as needed A copy of the TIO plot have been included for reference. Please call with any questions. Thank you, SCANNED APR 3 2015 Whitney Pettus (Alternate:Kevin Parks) BP�Allaska-Well Integrity Coordinator G Y Y G*bat Wells 0,ga+i,zat on WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com 1 TREE= 6 3/8"CIW SAFETY NOTES:WELL REQUIRES A SSSV. WELLHEAD= GRAY N G 1-1 2 ***NEEDED FOR EMERGENCY FIELD FUEL GAS*** ACTUATOR= BAKER C KB.ELEV= 44.0' BF.ELEV= NA KOP= 1825' 2207' 1—J 7"CA MCO BA AL-0 SSSV N,ID=5.937 Max Angle= 35 @ 5188' 48) I 2420' h9-5/8"FOCI Datum MD= Datum TVD= 8800'SS 2548' —19-5/8"FOC 13-3/8"CSG,72#, N-80,ID=12.347" —I 2781' I] — , Minimum ID = 3.725" @ 8436' 4-1/2" OTIS XN NIPPLE I 8345' —17"X 5-1/2"XO,ID=4.892" I 7"TBG,26#,L-80, .0383 bpf,ID=6.276" —1 8344' 1-- 8351' —15-1/2"BKR G-22 LOC SEAL ASSY,ID=4.875" if 8353' —19-5/8"BKR FB-1 PKR, ID=6.00" 8356' —1 BKR SBE,ID=6.00" 8373' H 7-5/8"X 4-1/2"XO,ID=3.958" 8391' H TOP OF BOT TIEBACK SLV,ID=7.00" I 4-1/2"TBG, 12.6#,L-80, .0152 bpf,ID=3.958" l 1 8447' ® . 8397' 9-5/8"X 7"BOT MC LNR HGR 9-5/8"CSG,47#, N-80,ID=8.681' — 8716' I 8436' J-f 4-1/2"OTIS XN NIP,ID=3.725" I PERFORATION SUMMARY / 8448' —4-1/2"WLEG,ID=3.958" REF LOG:BHCS ON 12/20/78 ' ANGLE AT TOP PERF:24 @ 9186' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4 9186-9206 0 01/23/80 3-3/8" 4 9206-9222 0 05/23/87 4 9222-9247 0 01/23/80 4 9264-9284 0 01/23/80 3-3/8" 4 9284-9296 0 05/23/87 • 8906' 1-17"MARKER JTS(TWO) I 4 9296-9326 0 01/23/80 3-3/8" 4 9326-9340 0 05/23/87 4 9340-9360 0 01/23/80 3-3/8" 4 9360-9374 0 05/23/87 4 9374-9394 0 01/23/80 3-3/8" 4 9394-9414 0 05/23/87 4 9414-9434 0 01/23/80 3-3/8" 4 9444-9450 0 05/23/87 4 9450-9465 0 01/23/80 3-3/8" 4 9465-9472 0 05/23/87 4 9479-9499 0 01/23/80 3-3/8" 4 9499-9517 0 05/23/87 4 9517-9542 0 01/23/80 4 9553-9573 0 01/23/80 4 9584-9604 0 01/23/80 PBTD —1 9650' .../.1* 7"LNR,29#,N-80,.0371 bpf, ID=6.184" -J 9692' MA'AM DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/31/78 ORIGINAL COMPLETION WELL: NGI-12 12/25/87 ROWAN 35RWO PERMIT No: 177-0810 04/02/10 DC/JMD SAFETY NOTE UPDATE API No: 50-029-20284-00 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE SEC 1,T11N,R14E 372'FSL&865'FWL 03/01/11 MEF/PJC TREE C/O(08/21/10) BP Exploration(Alaska) • • Injector NGI-12 (PTD# 1770810) 90 day TIO Plot April 18, 2015 61d1:11Cf12 • - - 3 CC4 t ite -i-w 2000 -.1,-OA • 00A - 0008. —on ttn 02:'1015 022515 033405 03'115 03'815 03'2515 06.'01.15 349\8'5 06'+515 Injection Plot Wn11.DO 12 350U 1400 . '93.000 3300 3200 - 00000 3.00 1 MO 3 000 2.930210 x yp 2930 2 2600 .oa 500 2 tam. ro 2.320 20.200 2200 '20020 2 10 200C 9 MOg — 193C '.00000_ —hl 1100 € —M 1 600 %KO 1590 8 —�� 1400 00000 —On 320 ,0009 220 1 100 64200 1000 500 %MO 300 '00 0000 ae S40 30000 +m 20020 320 210 '01 0 +m 02 ._._._.... / --------400 15/0 ??115 0111:tS QYtY15 0928'15 a0+:+5 W"s3+5 W.815 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,September 04,2013 TO: Jim Regg q P.1.Supervisor ' ?ejl `( -7 3 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC NGI-12 FROM: Jeff Jones PRUDHOE BAY UNIT NGI-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry j&(1 NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-12 API Well Number 50-029-20284-00-00 Inspector Name: JeffJones Permit Number: 177-081-0 Inspection Date: 8/30/2013 Insp Num: mit.1.1130901211609 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min } 1770810 SPT 1855 11 12 12 2423 2392 2383 Well Type In TVD 7 IA 62 zslo 2479 1 423 } I — 13 PTD NGI-1z 'Type Test1 (Test psi OA 12 13 1nterVal II4YRTST P/F 1 P ,/i Tubing 3249 , 3248 i 3224 1 3219 , 3216 - 3226 - Notes: 3.7 BBLS methanol pumped. 1 well inspected,no exceptions noted. ,, SCAWED i c f,j': Wednesday,September 04,2013 Page 1 of I ~ MEMORANDUM To: Jim Regg Gt P.I. Supervisor ( ~ `~~~~~ FROM: Jeff Jones Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, September 08, 2009 SUBJECT: Mechanical Integrity Tests BPEXPLORATION(ALASKA)INC NGI-12 PRUDHOE BAY UNIT NGI-12 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~-' Comm Well Name: PRUDHOE BAY iJNIT NGI-12 Insp Num: miUJ090906172815 Rel Insp Num: API Well Number: 50-029-20284-00-00 Permit Number: 177-081-0 Inspector Name: JeffJones Inspection Date: g/23/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Wel~ NGI-12 Type Inj. ~* ~j'~ 7423 / jA 920 2200 / 2260 2320 P.T.D 1770810 TypeTest SPT Test psi 1855.75 ~ p,~ ~o ~o ~o ~o Interval 4YRTST p~F F Tubing 3450 3430 3440 3440 NOtes' 2.9 BBLS diesel pumped, well pressure did not stabilize and started ]eaking gas & fluid from wellhead alignment pin packing. . ~.- S }itdsS~ r ~ ~4'~.1~, ~i' w,'~~r:... u..~ .~ u,;.~ _. : Tuesday, September 08, 2009 Page 1 of 1 • MEMORANDUM 'ro: Jim Regg %~~~/~ Z~ P.I. Supervisor ~E'~j ~ [ FROM: Chuck Scheve Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, September O1, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-12 PRUDHOE BAY LJN1T NGI-12 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~1~--~- Comm Well Name: PRUDHOE BAY i1NIT NGI-12 Insp Num: mitCSO9o828152559 Rel Insp Num: API Well Number: 50-029-20284-00-00 Permit Number: 177-081-0 -i Inspector Name: Chuck Scheve Inspection Date: 8/28/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Wel~ ~ NGI-12 Type Inj. G 'j'~ ~ 7423 ~ jA 375 2195 ~ 2175 2175 P.T.D~ l~~os~o ~-- TypeTest SPT Test psi ~8ss pA - ~s as as -- as Interval a~TST p~ P,~ Tubing 3a2o 3azo sazo 3azo Notes: ~~~~.~ , ~t~ aL. ,`~ !-~ ~1 .. ~ ~ ~~~~~~ .n. v ~ hi H9 L - ' - Tuesday, September O1, 2009 Page 1 of 1 LTNDER EVALUATION: NGI-1~PTD# 1770810) MITIA Failed • Page 1 of 2 Regg, James B (DOA) ~ , ~~~ ~~ From: Regg, James B (DOA) Sent: Monday, August 24, 2009 11:09 AM To: 'NSU, ADW Well Integrity Engineer'; Maunder, Thomas E(DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Sinyangwe, Nathan; Schwartz, Guy L(DOA) Cc: Quy, Tiffany; Holt, Ryan P(ASRC); Wellman, Taylor T Subject: RE: UNDER EVALUATION: NGI-12 (PTD# 1770810) MITIA Failed Taylor - / As discussed this morning, Wells NGI-12 (PTD 1770810), NGI-03 (PTD 1750610), and AGI-04 (PTD 1921460) may remain on injection for diagnostics to evaluate suspected thermal effects as the cause of failed MIT due to repressuring in IA. Piease contact this office if diagnostics/subsequent MIT are not completed this week. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 , ~~~.~.~'~i i ' ;a~„ r-~~ "` ~~~~~~~~. «`: ,:: ~,> C.S~? ~.a~° From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Monday, August 24, 2009 10:51 AM To: Regg, James B(DOA); Maunder, Thomas E(DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Sinyangwe, Nathan; Schwartz, Guy L(DOA) Cc: Quy, Tiffany; Holt, Ryan P(ASRC); Wellman, Taylor T; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: NGI-12 (PTD# 1770810) MITIA Failed All, Well NGI-12 (PTD #1770810) failed a witnessed ~LQ~.when the inner annulus pressure built up 120 psi in 30 minutes. The well has een reclassified as Under Evaluation and may remain online for further eva ua i~f~on work. The plan forward is as follows pending AOGCC approval: 1. Well Integrity Coordinator: Gain approval from AOGCC regulator to continue injection for AOGCC MITIA 2. DHD: Monitor pressures, rate, temp every 12 hours for 2-3 days 3. Pumping: AOGCC MIT-IA to 2200 psi A TIO Plot, MITIA test form and wellbore schematic have been included for reference. ~ ~ ~ «NGI-12 TIO Plot.doc» «MIT PBU NGI-12 08-23-09.x1s» «NGI-12.pdf» Please call with any questions or concerns. Thank you, Taylor Wellman filling in for Anna Dube/Andrea Hughes Office: 659-5102 8/24/2009 LTNDER EVALUATION: NGI-1~TD# 1770810) MITIA Failed • Page 2 of 2 Pager: 659-5100 x 1154 8/24/2009 PBU NGI-12 PTD 1770810 8/23/2009 TIO Pressures: 12 Months a,ooo h ~.ooa 2,000 ~ ,oou f Tbg ^ IA ~- OA OOA ~- OODA ~ On • n LJ 09120J08 10/21I08 11121J08 12122I08 01122109 02/22l09 03/25/~3 04I2F~09 05126/09 06I26/09 07/27/09 r~ ~ U STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. ~~~f v ~Z~9 ~0~ FIELD / UNIT / PAD: Prudhoe Bay / PBU / NGI (~ DATE: 08/23/09 OPERATOR REP: AOGCC REP: Torin Roschinger Jeff Jones Packer Depth Pretest Initial 15 Min. 30 Min. Well NGI-12 Type Inj. G ND 7,422' Tubin 3,480 3,430 3,440 3,440 Interval 4 P.T.D. 1770810 Type test P Test psi 1855.5 Casin 920 2,200 2,260 2,320 P/F F Notes: MIT-IA for 4 year regulatory compliance OA 70 70 70 70 Well Type In'. TVD Tubin Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casin P/F Notes: OA Well Type Inj. TVD Tubin Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPEINJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R= Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU NGI-12 08-23-09.x1s C~ TREE= 7-1l16" GRAY WELLHEAD = GRAY ACTUATOR= AXELSON KB. ~EV = 44.0' B F. ELEV = NA KOP = 1825' Max Angle = 35 @ 5188' Datum MD = Datum TVD = 8800' SS PERFO RA 110N S UMM4 RY R~ LOG: BHCS ON 12/20f78 ANGLEATTOP PfftF: 24 @ 9186' Note: Refer to Production DB for historical perf data SIZE SPF~ INT9~VAL Opn/Sqz DATE 4 9186-9206 O Ot/23/80 3-3/8" 4 9206-9222 O 05/23/87 4 9222-9247 O 01/23/80 4 9264-9284 O 01/23/80 3-3/8" 4 9284-9296 O OSl23/87 4 9296-9326 O 01/23/80 3-3/8" 4 9326-9340 O 05/23/87 4 9340-9360 O 01/23/80 3-3/8" 4 9360-9374 O OS/23/87 4 9374-9394 O 01/23/80 3-3/8" 4 9394-9414 O OS/23/87 4 9414-9434 O 01/23/80 3-3/8" 4 9444-9450 O 05/23l87 4 9450-9465 O 01/23/80 3-3/8" 4 9465-9472 O 05/23/87 4 9479-9499 O 01/23/80 3-3/8" 4 9499-9517 O 05/23/87 4 9517-9542 O 01/23/80 4 9553-9573 O 01/23/80 4 9584-9604 O 01/23/80 NGI-12 i L141E REV BY COMNENTS DATE REV BY COMNENTS 12/31/78 ORIGIfyALCOMPLEf10N 12/25/87 RWO 01/12/01 SIS-CS CONVERTED TO CANVAS 01/26/01 SIS-ND FINAL 01/02/02 CH/lP CORRECTIONS PRUDHOEBAY UNIT WELL: NGF12 PfftMT IVo: 177-0810 API No: 50-029-2028400 S~ 1, T11 N, R14E 372' FSL & 865' FWL BP Exploration (Alaska) Gas Injector Volume Calculations~Flow meters replaced • Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] A~'~~ ~ Sent: Wednesday, May 27, 2009 9:46 AM ~~~ `~-~ To: Regg, James B(DOA); Maunder, Thomas E(DOA) Cc: Engel, Harry R; Rossberg, R Steven; GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; NSU, ADW Well Integrity Engineer; GPB, FS1 Fac Engr Subject: Gas Injector Volume Calculations -- Flow meters replaced Attachments: Gas Injector volume calculations.xls Jim, ~ / The flow meter on NGI-13 was blocked in on 03/29/09 and returned to surface on 05/11/09; as this transmitter developed a small gas leak and was removed from service at that time. It wasn't until later that the lower design pressure was noticed on this and other transmitters, at which time the remainders were blocked in. The flow meters on NGI-01 03. 04. 05. 08, 12 were blocked in on 04/23/09,~r,td o!a__~e_d b~ck in service on 05/12/09. The pressure-rate data for operation before and after this time was extrapolated graphicall to determine the rates for the time the transmitters were blocked in. Allowing them to operate or a short time after they were put back in service has been helpful in assuring the most accurate representation of the time they were out of service. I have attached a spreadsheet containing daily rates and pressures, as well as the graphical analysis completed to obtain the data for the time the transmitters were out of service. «Gas injector volume calculations.xls» ~ Please call with any questions or concerns. Thank you, Andrea Hughes Well integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 i~;~'~- ___--- ~ ~~~ ,~G;.Z.. o ~ I 7 ~ -Dh~ (~GL~ ~GZ~- 03 l~5-6~~r p,~u ~;CT -~ ~ r~s-o~~ s~~,~ J~~~~~ ~~ 1,' ~ ~} 20C~ ~'~~- ~~~- 0~5 r~~-~d~~ ~'g~ ~ . ~; s~ i~~ ~-~ S-~ ~- ~~au ~~'~2 - ~ Z t7~-Gx'~I ~~1~ ~y° I 3~ 2~' ~~ 1 f~ 8/6/2009 • ` SUMMARY OF INJECTED VOLUMES DURING FLOW TRANSMITTER OUTAGE Volume Tubing Injected Pressure Date (MCFPD) (psi) NGI-01 05/12/09 119,210 3,165 05/11/09 117,670 3,148 05/10/09 136,884 3,360 05/09/09 144,134 3,440 05/08/09 143 , 228 . 3, 430 05/07/09 145,131 3,451 05/06/09 143, 681 3, 435 05/05/09 140,146 3,396 05/04/09 140,509 3,400 05/03l09 142,865 3,426 05/02/09 141,868 3,415 05/01 /09 140, 871 3,404 04/30/09 135,796 3,348 04/29/09 135,977 3,350 04/28/09 134,708 3,336 04/27/09 133,530 3,323 04/26/09 140,056 3,395 04/25/09 142,503 3,422 04/24/09 140,328 3,398 04/23/09 138,515 3,378 NGI-03 05/12/09 110,330 3,450 05/11/09 110,692 3,455 05/10/09 110,836 3,457 05/09/09 111,053 3,460 05/08/09 113,151 3,489 05/07/09 113,657 3,496 05/06/09 113,006 3,487 05/05/09 112, 211 3,476 05/04/09 113,947 3,500 05/03/09 113,368 3,492 05/02/09 114,814 3,512 05/01 /09 114, 091 3, 502 04/30/09 113,874 3,499 04/29/09 112,934 3,486 04/28/09 112,138 3,475 04/27/09 111,487 3,466 04/26/09 113,802 3,498 04/25/09 113,947 3,500 04/24/09 114, 091 3, 502 04/23/09 114,742 3,511 NGI Volume Calculations ~ . ~ NGI-04 05/12/09 112,110 3,070 05/11 /09 112,143 3,050 05/10/09 111,633 3,356 05/09/09 111,437 3,474 05/08/09 114, 568 1, 595 05/07/09 113,765 2,077 05/06/09 111,428 3,479 05/05/09 111,498 3,437 05/04/09 111,488 3,443 05/03/09 111,445 3,469 05/02/09 111,460 3,460 05/01/09 111,488 3,443 04/30/09 111,587 3,384 04/29/09 111,575 3,391 04/28/09 111,603 3,374 04/27/09 111,630 3, 358 04/26/09 111,493 3,440 04/25/09 111,450 3,466 04/24/09 111,490 3,442 04/23/09 111,410 3,490 NGI-05 05/12/09 179,667 3,375 05/11/09 179,789 3,380 05/10/09 179,910 3,385 05/09/09 180,007 3,389 05/08/09 179,813 3,381 05/07/09 180,299 3,401 05/06/09 179,935 3,386 05/05/09 179,010 3,348 05/04/09 179,108 3,352 05/03/09 179,667 3,375 05/02/09 179,472 3,367 05/01/09 179,156 3,354 04/30J09 177,892 3,302 04/29/09 178,062 3,309 04/28/09 177, 721 3, 295 04/27/09 177,405 3,282 04/26/09 179,108 3,352 04/25/09 179,667 3,375 04/24/09 179,156 3,354 04/23/09 180,178 3,396 NGI-08 05/12/09 150,117 3,470 05/11/09 150,117 3,470 05/10/09 150,117 3,470 05/09/09 149, 821 3,467 05/08/09 148,833 3,457 05/07/09 151,599 3,485 05/06/09 150,117 3,470 05/05/09 145,869 3,427 05/04/09 146,067 3,429 05/03/09 148,438 3,453 NGI Volume Calculations 2 ~ ~ 05/02/09 147, 351 3, 442 05/01/09 145,573 3,424 04/30/09 139,744 3,365 04/29/09 140,535 3,373 04/28/09 138,954 3,357 04/27/09 137,275 3,340 04/26/09 145,672 3,425 04/25/09 148,142 3,450 04/24/09 145,968 3,428 04/23/09 151,006 3,479 NGI-12 05/12/09 179,508 3,400 05/11/09 179,508 3,400 05/10/09 179,508 3,400 05/09/09 181,429 3,419 05/08/09 180,216 3,407 05/07/09 179,508 3,400 05/06/09 179,508 3,400 05/05/09 177,485 3,380 05/04/09 177,587 3,381 05/03/09 180,014 3,405 05/02/09 179,002 3,395 05/01/09 177,283 3,378 04/30/09 171, 721 3, 323 04/29/09 172,429 3,330 04/28/09 170,912 3,315 04/27/09 169,294 3,299 04/26/09 177,485 3,380 04/25/09 180,014 3,405 04/24/09 178,193 3,387 04/23/09 182,946 3,434 13 05/10/09 246,658 3,350 05/09/09 246,368 3,341 05/08/09 246,078 3,332 05/07/09 246,754 3,353 05/06/09 246,497 3,345 05/05/09 243,279 3,245 05/04/09 245,306 3,308 05/03/09 245,692 3,320 05/02/09 245,660 3,319 05/01/09 243,247 3,244 04/30/09 240, 801 3,168 04/29/09 243,955 3,266 04/28/09 243,375 3,248 04/27/09 243,086 3,239 04/26/09 245, 370 3, 310 04/25/09 246,078 3,332 04/24/09 245,564 3,316 04/23/09 246,979 3,360 NGI Volume Calculations 3 • 04/22/09 247,494 3,376 04/21/09 246,979 3,360 04/20/09 247,366 3,372 04/19/09 247,333 3,371 04/18/09 247,301 3,37p 04/17/09 247,301 3,370 04/16/09 246,658 3,350 04/15/09 246,722 3,352 04/14/09 245,821 3,324 04/13/09 244,244 3,275 04/12/09 243,536 3,253 04/11 /09 239,160 3,117 04/10/09 243,729 3,259 04/09/09 244,051 3,269 04/08/09 244,823 3,293 04/07/09 246,304 3,339 04/06/09 247,816 3,386 04/05/09 247,591 3,379 04/04/09 247,816 3,386 04/03/09 248,234 3,399 04/02/09 248,363 3,403 04/01/09 245,692 3,320 03/31/09 243,987 3,267 03/30/09 246,175 3,335 03/29/09 247,237 3,368 03/28/09 249,103 3,426 03/27/09 248,588 3,410 03/26/09 245,757 3,322 03/25/09 245,049 3,300 03/24/09 245,049 3,300 NGI Volume Calculations ~ NGI-01 155,000 150,000 y = 90.632x - 167640 • 145, 000 0 140,000 ~ 135,000 130,000 125,000 3,300 3,350 3,400 3,450 3,500 pressure 3,550 ~ NGI-03 140,000 120,000 ~ 100, 000 80, 000 w f- ~ 60,000 40,000 20,000 0 3, 350 3,400 3,450 3,500 3, 550 3,600 • PRESSURE y = -1.6665x + 197226 160, 000 140,000 120,000 100,000 w ~ 80,000 ~ 60,000 40,000 NGI-04 u 20,000 0 3,300 3,350 3,400 3,450 3,500 PRESSURE 3, 550 3,600 NGI-05 9 82, 000 181, 500 181, 000 180, 500 180,000 d r ~ ~ 179, 500 179, 000 178, 500 178, 000 177,500 y = 24.302x + 97587 • • 3,300 3,320 3,340 3,360 3,380 3,400 3,420 3,440 3,460 3,480 Pressure NGI-08 160,000 155,000 y = 98.79x - 192684 • 150,000 m ~ 145,000 140,000 135, 000 130,000 3,300 3,350 3,400 3,450 3,500 3,550 Pressure 3,600 ~ NGI-12 rate = 101.13(pressure) - 164334 200,000 195, 000 190, 000 185,000 m ~ 180,000 175, 000 170,000 165,000 160,000 ~--- 3,300 3,350 3,400 3,450 3,500 i Pressure NGI-13A 260,000 255,000 ~J 250,000 245,000 w ~ ~ 240,000 235,000 230,000 225,000 ~ 2,500 2,600 2,700 2,800 2,900 3,000 3,100 PRESSURE 3,200 3,300 3,400 3,500 ~ UPDATE: NGI Flow Transmitter~ • Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, May 04, 2009 2:11 PM ~~>~~ ~r~/~ To: Regg, James B (DOA) ~` ~ ~ ~ Cc: GPB, FS1 OTL; GPB, Area Mgr North (Gas Plants/GPMA); GPB, FS1 Fac Engr; Rossberg, R Steven; NSU, ADW Well Integrity Engineer; Daniel, Ryan; Bill, Michael L(Natchiq); Cahalane, Ted W; Dahlem, Jason E; Seymour, Len I; NSU, ADW Well Operations Supervisor; Cismoski, Doug A; Engel, Harry R Subject: UPDATE: NGI Fiow Transmitters Jim, After further evaluation, it has been decided to leave the underrated flow transmitters on the seven NGI weiis isolated until the fuliv rated transmitters are available for replacement. The fully rated transmitters are expected to arrive on the slope on May 13th and work to install them is planned to begin on May 15th. After the transmitters are replaced, calculations will be made to determine injection volumes and rates for the time the meters were out of service. We will also provide our calculation and the exact number of days the flow meters ~ were out of service. We will continue to update you on the status of the replacements. If you have any questions in the interim, please don't hesitate to contact me or Anna Dube. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 From: Engel, Harry R Sent: Thursday, April 23, 2009 4:57 PM To: James Regg Cc: GPB, FSl OTL; GPB, Area Mgr North (Gas Plants/GPMA); GPB, FSl Fac Engr; Rossberg, R Steven; NSU, ADW Well Integrity Engineer; Daniel, Ryan; Bill, Michael L(Natchiq); Cahalane, Ted W; Dahlem, Jason E; Seymour, Len I; NSU, ADW Well Operations Supervisor; Cismoski, Doug A; Engel, Harry R Subject: NGI Flow Transmitters Jim- This is a follow up to our telephone conversation this afternoon regarding flow transmitters at ~ NGI pad. The NGI 13 flow transmitter failed on March 29th. There was a minor gas release associated with the failure, far below 1 MMSCF. The flow transmitter was found to be underrated, yet the 8/6/2009 UPDATE: NGI Flow Transmitter~ ~ Page 2 of 2 body is fully rated. We discovered six additional underrated flow transmitters at NGI 1 3. 4, 5, 8, 12. All seven flow transmitters have been temporarily taken out of service. The wells remain on injection. No other gas injection well flow meters are affected. We have taken the following actions; a. Contacted the manufacturer and ordered metal backed Viton O rings which will increase transmitter operating pressure rating. These O rings will be installed in all seven wells within 1'~ week. This is a temporary modification until new transmitters are installed. b. New fully rated transmitters have been identified and will be installed in all wells in ~ approximately 2-6 weeks. Flow rates will be calculated during the periods when the transmitters are out of service. / As you requested, we will send you the flow rate calculation method and the total number of ~ days the transmitters were out of service. I will be out of the office for a few days next week. If you have any questions, please contact Andrea Hughes at 659-5102. Regards, Harold R. Engel (Harry) Engineering Team Leader Integrity Management, Alaska Drilling & Wells 907-564-4194 office 907-564-5510 fax 8/6/2009 ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~!0' C¡'/ (3)òS' P.I. Supervisor ( ( DATE: Tuesday, August 30, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-12 PRUDHOE BAY UNIT NGI-12 \ 1---- ~ o~ I FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~JB.e- Comm NON-CONFIDENTIAL Well Name: PRUDHOE SAY UNIT NGI-12 Insp Num: mitJCr050825124852 Rellnsp Num API Well Number 50-029-20284-00-00 Permit Number: 177-081-0 Inspector Name: John Crisp Inspection Date: 8/23/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. :'i~11I:~;;~::;:~~1s~1 i:~RSi L;:j, ~ )f¡ ~~: +~ 211:00J~I~:--I~;J~1_~_ -1m~!:Yª!.~~!_~_ __~f_______P _ __________ Tubi_~____~~~J.__~_t_~~___ I 3450____-.L_______l____ Notes 3 bbls pumped for test. , ", .;-, ! ,\~' ~ ~.;:; C' ~,~¡¡(!tiN~,.(:.",j ~~)'t'r.l C' "'. ') Dì1t.;, {~, ti ,.. v" Tuesday, August 30, 2005 Page 1 of 1 ) 1REE = 7 -1/16" GRAY WELLHEA. D = GRAY .. .~. ._. ~, ~ ..... ..... ....... , ,,~.. ....J ACl1JA TOR = AX8..S0N ..... ..... ....... ~... KB. 8..BI = 44.0' f3F'-8..EV = . .. NA 'KOpu;;,u ...u 1825' 'M:ixÄngïe';;"" "'3'i5(~'-5 faaï 'ti,itÚïn MY;' èiatüiïï 1ŸÖ = ... asöä'sS 113-3/8" CSG, 72#, N-80, ID = 12.347" l-j 2781' Minimum ID = 3.725" @ 8436' 4·1/2" OTIS XN NIPPLE 17" 1BG, 26#, L-80, .0383 bpf, 10 = 6.276" 1-1 8344' NGI-12 . ~ ---I ---I ~ .... / ~ ~ I J J II ~ 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" 1-1 8447' 1 " 19-5/8" CSG, 47#, N-80, 10 = 8.681" l-i 8716' r----a .. PffiFORA TION SUMVlARY REF LOG: BHCS ON 12/20/78 ANGLE AT TOP PERF: 24 @ 9186' Note: Refer to Production DB for historcal perf data SIZE I SPF I INTERV AL 1 Opn/Sqz I DATE SEE PAGE 2 FOR ÆRFORA 1l0N DATA I AHO l-f IT' LNR. 29#, N-80, .0371 bpf, 10= 6.184" 1---1 9650' 9692' ~ DATE REV BY COMI'vENTS OA. TE RBI BY CO rvTv18'JTS 12/31/78 ORIGINAL COI\iPLErION 12/25/87 RlVO 01/12/01 SIS-CS CONVERTED TO CANVAS 01/26/01 SIS-MO ANAL 01/02/02 CI-VTP CORRECTIONS ) I SAFETY NOTES: 2207' 1-17" CAIVCO BAL-O SSSVN, 10 = 5.937 1 2420' li9-5/8" FOC 1 2548' 1---19-5/8" FOC 1 8345' I-1T' X 5-1/2" XO, ID = 4.892" 8351' 1-i5-1/2" BKR G-22 LOC SEA.L ASSY, ID = 4.875" 8353' 1-i9-5/8" BKR FB-1 A<R, 10 = 6.00" 1 8356' I-iBKR SBE, 10 = 6.00" 1 8373' 1---17-5/8" X 4-1/2" XO, 10 = 3.958" 1 8391' I-iTOPOFBOTllEBACKSLV, 10=7.00" 1 8397' 1-19-5/8" X 7" BOT rvc LNR HGR I 8436' 1-{4-1/2" OTIS XN NP, ID = 3.725" 1 8448' 1-f4-1/2" WLEG, 10 = 3.958" 1 8906' I-iT' M\RKERJTS (TWO) 1 FRUDHOE BA Y UNIT W8..L: NGI-12 ÆRrv1!TNo: 177-0810 APII\b: 50-029-20284-00 SEC 1, T11 N, R14E 372' FSL & 865' FWL BP Exploration (Alaska) TREE = 7-1/16" GRA Y WELLHEAD = GRA Y 'AëriJA TõFf~ .. . AXELSON N G 1-12 KB. 8..13i ~ ... -44.0" BF. ELEV = NA KOP = 1825' ..........................,.,..... ................. Max Angle = 35 @ 5188' 'i5äíÛiïï MD ~ .... '--" 'ÓatÚm NO''; . ....... ····ssòä sS- ÆRFORA 1l0N SUMMA.RY RB= LOG: BHCS ON 12/20/78 ANGLEATTOPPffiF: 24 @ 9186' Note: Refer to Production œ for historical perf data SIZE SFf INTffiVAL Opn/Sqz DATE 4 9186-9206 0 01/23/80 3-3/8" 4 9206-9222 0 05/23/87 4 9222-9247 0 01/23/80 4 9264-9284 0 01/23/80 3-3/8" 4 9284-9296 0 05/23/87 4 9296-9326 0 01/23/80 3-3/8" 4 9326-9340 0 05/23/87 4 9340-9360 0 01/23/80 3-3/8" 4 9360-9374 0 05/23/87 4 9374-9394 0 01/23/80 3-3/8" 4 9394-9414 0 05/23/87 4 9414-9434 0 01/23/80 3-3/8" 4 9444-9450 0 05/23/87 4 9450-9465 0 01/23/80 3-3/8" 4 9465-9472 0 05/23/87 4 9479-9499 0 01/23/80 3-3/8" 4 9499-9517 0 05/23/87 4 9517-9542 0 01/23/80 4 9553-9573 0 01/23/80 4 9584-9604 0 01/23/80 ~ .. \ I ZÐ ~ \ I l J ~ I! ! , ~ .. BIItIÁ QA. TE REV BY COMI'vENTS DATE REV BY COMI'vENTS 12/31/78 ORIGINAL COMA-EllON 12/25/87 RWO 01/12/01 SIS-CS CONVERTED TO CANV AS 01/26/01 SIS- M) FINAL 01/02/02 ŒiI1P CORRECllONS PRUDHOE SAY UNIT WELL: NGt-12 PffiMT I'b: 177-0810 APII'b: 50-029-20284-00 SEC 1, T11N, R14E 372' FSL &865' FWL 8P Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser Commissioner THRU: Tom Maunder P.I. Supervisor FROM: Jeff Jones DATE: August 20, 2001 SUBJECT: Mechanical Integrity Tests BPX NGI Pad NGI-06, 07, 08, 10, 12 PBU Petroleum Inspector PBF NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Wall NGI-O8 I Type~nj.I (~' !T-v-D- I 7426 ]Tubirml 3~01 3~01 3~1 3~'l~.te-all 4" p.T.D.I 1760290 I'Ty~testl P ITe~tpsil 1~,7 I CasingI r~O I 2010'1 2OOO I 2OOO I PA: I -" Notes: Pre-test pressures monitored 30 minutes & stable. wa~I ,~-o? I Type~nj.! ~ I T.V.D. I 7398 ITuk~ngl 33o01 3300""i 33oo 1'3300 I~.te,v~l41~ p.T.D.I 1760380 Iwpet~! P. ITestpsil ,~ I c~;~.o,I 8o I 2010 I 201,0 I 2010 I PA: I __P Notes: pre-test pressures monitored 30 minutes & stable. 'w.~'l "~'-~ l'~e'nJ'l ~ '1 ..v.o. I ~.~'~ I .u~,n0 I~01~'1 ~ I'' ~°° I'~v~'l ~ P.T.D.i 1760520 ITypetestI P, ITestpsil 1855 I Casingl ,110 I 2o15 I 2020 ! 2o15 I PA: I P__" Notes: Pre-test pressures monitored 30 minutes & stable. "w~,! .~,~o I,,,e,nj.! ~ '1 ':v.o. I~ I.u~n~l ~°° I ~,~o i~oo i~o0 },.te..a,I '~ .... P.T.D.I 176o69o ITYpetestl, P, ITestpsil 1832 l Casingl ,28O '1 2O2O, I '2O2O I 2O2O I PA:, I ---P' Notes: Pre-test pressures monitored 30 minutes & stable. w~'l "~"~ I""e'nJ'l ~ I,'v'°' I ~ I'u~'nol ~01 ~ I ~?~01 ~0 I,~e-a,I ~ ~-I 177o81o ITypet, estI P ITestpsil 185~ I CaangI 54O'I 2010 1'2000 I, 2..OOO I PA: I E Pre-test pressures monitored 30 minutes & stable. Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Monday, Aul~ust 20, 2001: I traveled to BPX's NGI Pad to witness 4 year MIT's on wells NGI-06, NGI-07, NGI-08, NGI-10 and NGI~12. Scott Lyon (BPX representative) performed the tests today. The pre-test pressures were monitored for 30 minutes and observed to be stable. AIl five wells passed the MIT's and are suitable for continued injection. Summary,: I witnessed 5 successful MIT's at BPX's NGI Pad in the Prudhoe Bay Field. M.I.T.'s performed: 5_. Number of Failures: _0 Total Time during tests: 3.5 hrs. Attachments: .cc:. MIT report form 5/12/00 L.G. MIT PBU NGI-06,07,08,10,12 8-20-01 JJ.xls 8/27/01 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE J~ GA,~...INJECTOR 2. Nam~ of Operator 7. Permit Number ARCO Alaska, Inc. 77-81 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-20284 4. Location of well at surface 9. Unit or Lease Name 372' FSL, 865' FWL, Sec. 1, T11N, R14E, UN Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1574' FNL, 1304' FEL, Sec.12, TllN, R14E, UM NGI-12 At Total Depth 11. Field and Pool 1719' FNL, 1152' FEL, Sec.12, TllN, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Oi 1 Pool RKB 44' ADL 28302 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ] 15. Water Depth, if offshore 116. No. of Completions 12/02/78 12/21/78 12/31/78'I N/A feet MSLI 1 17. Total Depth (MD+TVD} 18.PlugBackDepth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 9693'MD, 8651 'TVD 9650'MD, 8612'TVD YESx] NO [] 2207' feet MDI 1900' (approx) 22. Type Electric or Other Logs Run D IL/BHCS/GR, FDC/CNL/GR, GR/CNL/CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surf 100' 30" 325 sx AS cmt 13-3/8" 72# N-80 Surf 2781' 17-1/2" 4300 sx PF cmt 9-5/8" 47# N-80/ Surf 8716' 12-1/4" 800 sx Class G & 300 s PFC Soo-95 7" 29# L-80 8391' 9692' 8-1/2" 425 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/4 spf 7"/4-1/2" 8448' 8353 ' 9186'-9247'MD 8190'-8246'TVD 9264'-9326'MD 8261 '-8318'TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 9336 '-9434 'MD 8327'-8416'TVD DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 9444 ' -9465 'MD 8425 ' -8444 'TVD N/A 9479'-9542'MD 8457'-8514'TVD 9553 ' -9573 'MD 8524 ' -8542 'TVD 9584 ' -9604 'MD 8552 ' -8570 'TVD 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. -' *Note: Perforated well 1/31/80. Perforations added 5/23/87. STATE OF ALASKA .... ~ ALASKA OIL AND GAS CONSERVATION CuMMISSION WELL COMPLETION OR RECOMPLETION REPORT Al,ID LOG WC5/I5 :DAN I Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE /'/j/ 29. 30~' GEOLOGIC MARKERS ~ F~RMATION TESTS .,. · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE rEFIT. DEPTH GOR, and time of each phase. Top Sadlerochit 9177' 8182' N/A Base Sadl erochi t 9646' 8608' I 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed //~~ ~~c/.~_ w/ Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL)or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the loCation of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 DATE' REFERENCE' ARCO P. A2ED HnI.IF FINAl.. COl .I AF,'/F'Ii.'FcFFIRRA'IFTON ~01 I. AF-~: ~' PACK FF-,' ) COl. !. AR/F'I=RFFIRTTON P. OI ..l.. AR/F:'ER FORAT I ON CJI!. il. AR/PFRFFIRRATTON ~fll..I AR/PEI:RFFIRAT l F!N C. F1 L. I AR'/F'FRFnRAT T F1N COI..LAR/F'ERFORATION P. Fll. I. AI;:/F'ERFFIRATTON COI..I.. AK'/F'ERFORA T T ON COl .I. AR./F'EI::;.,FQRAT T FIN COI.I AR/F'ERFORATI!]N COl... I.. AR/F'b-RF'F1R A T T ON Ri]I..I. AR/F'ERFI]RAT I ON F'EF~GY BENNETT AT[]-t ~'~o AF'F'ROVEI) __ __ O ]' ?, TF;: T RlllT T ON RI':.;CETPT OF DATA,. D~F~Irl:~ DRFS2F'R D~F~FR T)PF~FP BRF~FR DRF~IrF~ DRF~IZR T)RF~FR I)RF~FI7 DRE~tzR DRF~FR CENTRAl_ CHFVRON D & M EXTENYTON FWF'I.I. ORAT l ON Ex×nM MARATHON MF]RTI.__ " F'HII I TF'.:C F'R NFI.I FTI. F',? · -,,-'"' STATF. F1F. ~ TFWAF:.n STATE OF ALASKA ALAS, OIL AND GAS CONSERVATION COMk..,~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~., Alter Casing [] Other 2. Name of Operator ARCO A]aska~ inc, 3. Address Po0. Box 100360, Anchorage, AK 4. Location of well at surface 99510-0360 372' FSL, 865' FWL, Sec. 1, TllN, R14E, UM At top of productive interval 1574' FNL, 1304' FEL, Sec.12, TllN, R14E, UM At effective depth 1685' FNL, 1214' FEL, Sec.12, T11N, R14E, UM At total depth 1719' FNL~ 1152' FEL~ Sec.12~ TllN~ R14E~ UM 11. Present well condition summary Total depth: measured 9693 'MD true vertical 8651 'TVD Stimulate ~ Plugging [] Perforate [] Pull tubing WORKOVER 5. Datum elevation (DF or KB) RKB bt4 ' 6. Unit or Property name Prudhoe Bay Unit 7. Well number NGI -12 8. Approval number 7-921 9. APl number 50-- 029-20284 10. Pool Prudhoe Bay 0il Pool feet Plugs (measured) None feet Effective depth: measured 9650 'MD true vertical 8612 'TVD feet Junk (measured) Fill ~ 9638' feet Casing Length Size Conductor 73' 20" Surface 2754 ' 1 3-3/8" P roducti on 8689' 9-5/8" Liner 1301 ' 7" Feet Perforation depth: measured 9186'-9247 ' 9479 ' -9542 ' true vertical 8190 ' -8246 ' 8457'-8514' Tubing (size, grade and measured depth) 7"/4-1/2", L-80, tbg w/tail ~ 8448' Packers and SSSV (type and measured depth) FB-1 pkr @ 8353' & Bal-O SSSV @ 2207' Cemented Measured depth ~ue Vertical depth 325 sx Arcticset IO0'MD IO0'TVD 4300 sx Permafrost 2781'MD 2708'TVD 800 sx Class G & 8716'MD 7757'TVD 300 sx PFC 425 sx Class G 8391'-9692'MD 7460'-8650'TVD , 9336'-9434', 9444'-9465', , 9584'-9604' , 8327'-8416', 8425'-8444', , 8552'-8570' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) , 9264'-9326' , 9553'-9573' , 8261'-8318' , 8524'-8542' 13. Treatment description including volumes used and final pressure N/A Representative Daily Average Production or Inj. ection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation Copies of Logs and Surveys Run [] 14. Attachments (Workover Well Hi stor~_) Daily Report of Well Operations 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Associate Engineer Date /-/~-,~ (Dani) SW03/33 Submit in Duplicate Form 10-404 Rev. 12-1-85 (¢ ARCO Oil and Gas Company ," Well History - Initial Report - Dally Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work: prior to spudding should be summarized on the form giving inclusive dates only, District ARCO Alaska, Inc. Field PRUDHOE BAY Auth. or W.O. no. Operator .'~,C O ICounty. parish or borough NORTH SLOPE Lease or Unit ADL: 28302 Title WORKO~v'~R IState NGI-12 IWell no. API: 50-029-20284 Spudded or W.O. begun ACCEPT I ARCO w.i. IPrior status if a w.o, [Date12/11/87 IH°ur 1930 HRS 1122'0000 Date and depth as of 8:00 a.m~ I Complete record for each day reported WESTWARD RIG I PUMP BRINE DOWN TBG MW: 9.4 Na~i MOV~ RIG F/ LGI-6 TO NGI-12. ACCEPTED RIG AT 1930 HRS, 1.2t10:/87. RU ON TRBE TO KILL TBG. BLEED ANNULUS TO 500' ' PSI~. PUMP-36 BBL~ SEAWATER. PULL BPV. PUMP 400 BB~ ' DOWN TBG FOLLOWED BY 9.4 BRINE. DAXLY:$39,467 CUM:$39,467 ETD:$39~467 EFC:$6a3,000';' · '-' .. . · SETTING BPV MW: 9 · 2 NaiL- KILLED WELL. SET BPV. DAILY: $105,299 CUM: $144,766 ETD: $144,766 EFC: $683,000 12/13/87 ( TD: PB: 9650 SUPV:DL/BB 12/14/87 ( TD: PB: 9650 SUPV:DL/BB 12/15/87 ( TD: PB: 9650 SUPV:DL/BB 12/16/87 ( TD: PB: 9650 SUPV:DL/BB 12/17/87 ( TD: PB: 9650 SUPV:HP/CD 12/18/87 ( TD: PB: 9650 SUPV:HP/CD The above la correct Signature TESTING BOPES MW: 9.2 NaCl SET BPV .ND TREE. NU BOPE AND TEST TO 5000 PSI. TEST ANNULAR TO 3500 PSI. TESTING LINES . DAILY:S65,025 CUM:$209,791 ETD:S209,791 EFC:$683,000 FISHING MW: 9.2 NaCl TEST 13 3/8" X 9 5/8" PACKOFF TO 5000 PSI. BLED OFF 110 PSI IN 10 MIN. PU ON 7" TUBING 5.6'. WOULD NOT FREE UP. RELAND TUBING. RIH WITH OVERSHOT. DAILY:S38,313 CUM:$248,104 ETD:S248,104 EFC:$683,000 FISHING MW: 9.4 NaCl FISH OUT 34' OF WL FISHING TOOLS AND PACKER SETTING TOOL. MILL ON PACKER. PACKER FELL FREE TO 2239'. TIH WITH SPEAR. ATTEMPT TO WORK INTO FISH'. DAILY:S46,853 CUM:$294,957 ETD:S294,957 EFC:$683,000 CHANGING BOP RAMS TO 7" MW: 9.4 NaCl FISH OUT PACKER. MILL JUNK IN HOLE. RIH WITH GR/JB. SET BP @ 8212'. ND LUBRICATOR. CHANGE TOP RAMS TO 7'% i , DAILY:S28,457 CUM:$323,414 ETD:S323,414 EFC:$683,000 RIH WITH TBG CUTTER MW: 9.4 NaCl CHANGE TOP RAMS TO 7" AND TEST TO 5000 PSI. PUNCH CIRC HOLES IN TUBING @ 8185.5',8182.5'. CIRC AND SPOT TREATED BRINE IN ANNULUS. ATTEMPT TO CUT TUBING @ 6560'. RIH WITH CUTTER #3. DAILY:S35,089 CUM:$358,503 ETD:S358,503 EFC:$683,000 POOH LD TUBING MW: 9.4 NaCl RIH WITH MECHANICAL CUTTER AND CUT TUBING @ 6591'. POOH LD TUBING. DAIL~: $$3, ,~..~. - ................ ~'" ,.... ..~." ..... ;$441,745 ..... I Date [ Title /-[/.~ Associ.ate Engineer For form preparatlq~'/and distribution, see Procedures M~(r)bal, Section 10, Drilling, Pages 86 ~rnd 87, ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describi~,g work performed, Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin~ until completion. District ICounty or Parish I stateAK ARCO Alaska, Inc. ~ NORTH SLOPE Field ILease or Unit JWoll no. PRUDHOE BAY NGI-12 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. WESTWARD RIG 1 12/19/87 ( TD: PB: 9650 SUPV:HP/CD 12/20/87 ( TD: PB: 9650 SUPV:HP/CD 12/21/87 ( TD: PB 9650 SUPV:HP/CD 12/22/87 ( TD: PB: 9650 SUPV:HP/CD 12/23/87 ( TD: PB: 9650 SUPV:HP/CD 12/24/87 ( TD: PB: 9650 SUPV:DL/BB o) 1) 3) POH WITH DP MW: 9.4 NaCl LD TUBING. RIH WITH FISHING TOOLS. SPEARED TUBING FISH & PULLED FREE. CIRC. POH & LD FISHING TOOLS. POH & LD TUBING. IMPROPER HOLE FILL-GAS MIGRATING UP ANNULUS. RU & RIH W/7" TUBING ON 3-1/2" DP TO 8044'. CIRC. GAS OUT OF HOLE. MONITOR WELL. POH WITH DP, SLOWLY. DAILY:S29,766 CUM:$471,511 ETD:S471,511 EFC:$683,000 POH FOR NEW MILLING SHOE MW: 9.4 NaCl CUT DRILLING LINE. POH WITH DP. FINISHED LD TUBING. CIRC. OUT GAS BUBBLE BELOW BRIDGE PLUG IN THE TUBING. MU FISHING BHA %2 & RIH W/DP. TAGGED PKR @ 8246'. MILLED ON PKR. POH FOR NEW MILLING SHOE. DAILY:S28,505 CUM:$500,016 ETD:S500,016 EFC:$683,000 PREPARE TO CHANGE PACKOFF MW: 9.4 NaC1 FINISHED ?OH. CHANGED OUT MILLING SHOE & TIH. MILLED ON & RECOVERED PKR. POH. RIH W/RETRIEVABLE BRIDGE PLUG. TESTED CASING TO 2500-PSI-OK. POH. HANG OFF DP. PREPARED TO CHANGE OUT 9-5/8" CASING PACKOFFS. DAILY:S46,786 CUM:$546,802 ETD:S546,802 EFC:$683,000 RIH TO PBTD MW: 9.4 NaCl INSTALLED NEW 9-5/8" PACKOFF & TESTED TO 3000 PSI. RIH. . ~ET. STORM VALVE & RTTS @ 31'. RET. BRIDGE PLUG SET @ 8351'. CIRC. BOTTOMS UP. POH. MU CLEANOUT BHA & TIH. DRILLED FILL F/9569'-9638'. CIRC. BOTTOMS UP. RIH TO ?BTD. DAILY:S40,016 CUM:$586,818 ETD:S586,802 EFC:$683,016 POH LDDP MW: 9.4 NaCl WASHED F/9578'-9638'. REV. OUT FILL. POH. RU WIRELINE. RAN GR/JB. RD WIRELINE. MU PACKER & TAILPIPE. RIH & SET PKR @ 8345' POH. TESTED CASING & PKR TO 2500 PSI - OK. RIH W/COLLARS & DRILL PIPE. POH & LD SAME. DAILY:S42,882 .CUM:$629,700 ETD:S629,700 EFC:$683,000 SPACE OUT MW: 9.4 NaCl LD DP & DC'S. PULLED WEAR BUSHING. CHANGED RAMS TO 7". RIH WITH BAKER SEAL ASSY ON 7" COMPLETION EQUIPMENT. DAILY:S25,390 CUM:$655,090 ETD:S655,090 EFC:$683,000 The above is correct Signature ~.. ~ IDate For form preparation an~c~istribution -- see Procedures Manua~'~ection 10, Drilling, Pages 86 and Associate Engineer ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final RePort'' on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District County or Parish NORTH S'r,OPE Lease or Unit ITitle AD'r, -- 28302 WORKOVER Accounting stat~K cost center code Field ARCO Alaska, Inc. PRUDHOE BAY NGI-12 Well no, Auth. or W.O. no, 50-029-20284 Operator I A.R.Co. W.I. ARCO I 22. 0000 Spudded or W.O. begun IDate ACCEPT I 12/10/87 Date and depth aa of 8:00 a.m. Complete record for each day reported WESTWARD RIG i I otal number of wells (active or inactive) on this Dst center prior to plugging and ~ bandonment of this well I our I Prlor status If a W.O. I 1930 HRS 12/25/87 ( 1 TD: PB: 9638' WL SUPV:DL/BB Old TD New TD Released rig RELEASED RIG MW: 8.5 SEAWATER/DIESEL SPACED WELL OUT. DISPLACES WELL WITH TREATED SEAWATER & DIESEL CAP. LANDED TUBING. TESTED ANNULUS TO 2500 PSI & TUBING TO 3000 PSI. SET BPV. ND BOPE. NU TREE & TESTED TO 5000 PSI. SECURED WELL & RELEASED RIG @ 0430 HRS, 12/25/87. SSSV @ 2207', FB-1 PKR @ 8353', & TAIL @ 8448'. DAILY:S265,587 CUM:$920,677 ETD:S920,661 EFC:$683,016 PB Depth Type completion (single, dual, etc.) Classifications (oil, gas, etc.) Date Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing interval Oil or gas Test time Production Oil on test Gas per day · PUrnl~ size, SPMX length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above Is correct For form preparation ~l~ld distribution, see Procedures ManuM, Section 10, Drilling, Pages 86 and 87. Associate Engineer , COMM I COMM iCOMM i Fi'I~S ENG IS-R"E'I~G XEROX TELECOPIER 295 ; F R 0 r'l 12-24-87; 9072767542 · ~-": ¢-,'.%",. }; ~ t - -z ~.' "--. ,' '% '%.. ....... STATE OF ALASKA -'- ALA,..,-,.. OIL AND GAS CONSERVATION COk .... ,oSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown [] Re-enter suspended well ~ Alter casing Time extension ~ Change approved program ~. Plugging ~ Stimulate ~ Pull tubing,~ Amend order ~ Perforate C~ Other 2. Name of Operator ARCO Alaska~ Inc. 3. Address P. 0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 372' FSL, 865' FWL, 5ec. 1, T11N, R14E, UM At top of productive interval 1574' FNL, 1304' FEL, 5ec.12, T11N, R14E, UN At effective depth 1685' FNL, 1214' FEL, Sec.12, T11N, R14E, UN At total depth 1719' FNL, 1152' FEL, 5ec.12, T11N, R14E~ UH 11. Present well condition summary Total depth: measured 5. Datum elevation (DF or KB) RKB 44 ' 9693 'MD feet Plugs (measured) true vertical 8651 ' TVD feet measured 9650 ' HD feet true vertical feet 8612 ' TVD Effective depth: 6. Unit or Property name Prudhoe Bay Unit 7. Well number NGI-12 feet 8. Permit number 9. APl number 50-- 029-20284 10. Pool P;udhoe Ba~y.--~l Pool None / Junk (measured) Casing Length Size Cemented 'ffb-e'-¥ert ical depth.. Measured depth Conductor 73 ' 20" Surface 2754 ' 1 3-3/8" Producti on 8689 ' 9-5/8" Liner 1301 ' 7" 325 sx Arcticset IO0'MD 4300 sx Permafrost 2781'MD 800 sx Class G 8716'MD 425 sx Class G 8391'-9692'MD IO0'TVD 2708'TVD 7757'TVD 7460'-8650'TVD Perforation depth: measured 9186 ' -9247 ' 9479 '-9542 ' true vertical 8190 ' - 8246 ' 8457 ' -8514 ' Tubing (size, grade and measured depth) , 9264'-9326', 9336'-9434', 9444'-9465', , 9553'-9573', 9584'-9604' , 8261'-8318', 8327'-8416', 8425'-8444', , 8524'-8542', 8552'-8570' 7", 26//, L-80 to 2233'; 7", 29//, L-80 f/2233'-8218'; 5-1/2", 17//, L-80 f/8218'-8271' Packers and SSSV (type and measured depth) Baker FB-1 pkr (~ ~2";~'MD... Otis .c;$~v ,~ 22~9'M_n 12.Attachments Description summary of proposal [] Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation December 2, 1987 14. If proposal was verbally approved Date Name~of approver Alaska 0il &. G~.:'.. Cons. Coli'im~;si0i~ Date approved 15. I certify,~,hat the fore.q,oing is true and correct to the best bf my knowledge Sign ~_-._ ,. itle Associate Engineer ""' - Commission Use Only (Dani) SA3/25 Conditions of approval '" Notify commission so representative may witness I [] Plug integrity [] BOP Test [] Location clea. ra, nce| , Approved uopy Approved by Form 10-403 Rev 12-1-85 ORIGINAL SIGNED BY LON_NlP d- Commissioner Approval No. 7- by order of the commission Date Submit in triplicate NGI-12 WORKOVER PROCEDURE SUMMARY 1) MIRU WW1. 2) Kill the well with NaC1 and viscous pill. 3) ND tree. NU BOPE and test. 4) Pull and lay down 7" x 5-1/2" completion string and fish. 5) Mill and retrieve FB-1 permanent packer. 6) TIH w/test packer and test the casing and FOs. 7) TOH. Lay down test packer, PU bis. 8) TIH. Clean out fill to PBTD. TOH. 9) RIH w/new FB-1 packer on drillpipe and set at ±8350'. 10) TOH and LD drillpipe. 11) RIH with new completion of 7", 26#, L-80 IJ4S tubing and seal assembly with a new 7" SSSV nipple at ±2200'. 12) Space out tubing. Displace well. 13) Set BPV. ND BOPE. NU tree and test. 14) Test tubing and annulus. Shear out sub. 15) Set BPV. Release rig and move off well. Anticipated bottomhole pressure: 3750 psi Workover fluid: 9.2 ppg NaC1 SA3/25a 11/24/87 _000 BOP ,. TACK ANNULAR PREVENTER § PIPE RAHS 5 BLIND RAHS TUBIN6 HEAD 3' . , . 1. 13-3/8" CASING HEAD 2. 9-5/8" CASING HEAD 3. 5000 PSI TUBING HEAD 4. 13-5/8" - 5000 PSI BLIND RAMS 5. 13-5/8" - 5000 PSI PIPE I~AM$ 6. 13-5/8" - 5000 PSI ANNULAR 10. 11, !2, 13. !4. ACCUMULATOR CAPACITY TEST I. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS :3000 PS1 WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. $. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAININ~ AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT I$ 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. STACK TEST FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL, CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED, PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD, RUN IN LOCK-DOWN SCREWS IN HEAD, CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 2500 PSI AND HOLD FOR 10 MINUTES, BLEED TO ZERO PSI OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 10 MINUTES, CLOSE VALVES DIRECTLY uPSTREAM OF CHOKES. BLEED DOWNST!qEAr"; PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY. WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNST~EAr'I, BLEED SYSTEM TO ZERO PSI, OPEN PIPE RAMS. BAC~OFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000. PSI FOR 10 MINUTES. BLEED TO ZERO PSt. OPEN BLIND RAMS AND RECOVEP, TEST PLUG, MAKE SURE MANIFOLD AhO LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLII',I(~ POSITION. TEST STANDPIPE VALVES TO 5000 PSI. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. '~!S AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. JG NOVEMBER'21 , 1986 ARCO ALa~km, Inc I='. O, Box Anchormge, A 9951 0 DATE' 9-25-87 REF"ERENCE: ARCO Cm.sed HoLe F'ilnaL 4-t 8-t6-87 Product ion Profi Le Run t , 5" Camco t -" 8 8-" 2'2 -- 8'7 ]: n j e c ~ i o n F:' r o f i L e R u. ~'~ t , 5 ' C a m c o t-5 8-28-87 F'r od ur: 'f i on F'rofi Le Run t, 5" Camc:'o 4.-..5 8-.-2e-..8'7 Procluction F'rofi te Run t, 5" Camco 4-2 8-.-24-87 F'roduc'tion F'rofil. e/F'l, uid Den.s~ Run t, 5" C,:~mc':o t4-..t'? 8-.28-8'? F'rodu. ction F'rofi Le Rt~¥~ t, 5" Camco t~-.6 ~-~8---87 Inj~c'l'ion Proft Le Run t, 5" Camco t~-.-28 9-t 6-87 Pump-In Temperature Ru.n t, 5" Camco 5-.'5 9....9-..87 F'roduc'~ion F:'rofi Le Run t, 5" Camco 5-'-t6 8--.2S-87 CCL. Run t, 5' Camco fS.-1 9 .... t0...-87 Pump-In Temperafl~re Run t , t~" Camco :~..D8 8-2:3-87 L. eak Dekect'ion Rt~n t, 5" Camc. o NGI---~2 9-t5-87 40 Arm In~pecfion CaLiper Run ~, 2" Camco tt-..25 9 .... t2--87 F:'roduc'tion Profi l.e Run t , 5" Camco S---. 9 8 ..- 29 -.-87 F' ~ T 5' R u n t , 5" C a m c o .: I::'l. ea~e .sign and re'l'urr, the at'Lachecl copy as' rec:eip~ of data, Received .-~y ................. , ....................................... ~ ! I-lAVE A NICE DAY~ ""l ~.., l [.- ~ 29 ka 0ii ~ Gas Oons. Commission / / Anchorage AI:,~ roved ............................................................... D 1,7 T R I B U T I 0 N ---- STATE OF ALASKA AL. ;A OIL AND GAS CONSERVATION CC...,VlISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 372' FSL & 865' FWL, Sec. 1, T11N, R14E, UM At top of productive interval 1574' FNL & 1304' FEL, Sec. 12, T11N, R14E, UN At effective depth 1685' FNL & 1214' FEL, Sec. 12, T11N, R14E, UM At total depth 1719' FNL & 1152' FEL, Sec. 12, T11N, R14E, UM 5. Datum elevation (DF or KB) 44' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well ~u~l:)_~r2 8. Approval number 7-226 9. APl number 50-- 029-20284 10. Pool Sadlerochit Feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 73' Surface 2754' Production 8689' Liner 1301' 9693 feet Plugs (measured) 8651 feet None 9574' - Fill 9574 feet Junk (measured) 8543 feet '~. Size Cemented Measured depth True Vertical depth 20" 325 SX Arcticset Cmt 100' 100' 13-3/8" 4300 sx Permafrost Cmt 2781' 2708' 9-5/8" 800 sx Class G Cmt 8716' 7757' 7" 425 sx 8391' -9692' 7460' -8650 Perforation depth: measured 9186-9247' 9264-9326' 9336-9434' 9444-9465' 9479-9542' 9553-9573', 9584-9604' true vertical 8190-8246', 8261-8318', 8327-8416', 8425-8444', 8457-8514', 8524-8542', 8552-8570' Tubing (size, grade and measured depth) 7", 29#, L-80, ABMOD 8rd to 5949'MD 5½", 17#, L-80 ABM 8rd La 5949'-8271'MD Packers and SSSV (type and measured depth) Baker FB-1 Packer La 8258'MD/0tis SSSV La 2249'MD 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 5/20/87 -- 148312 .... Subsequent to operation 5/26/87 -- 162373 .... Tubing Pressure 3740 375O 14. Attachments Daily Report of Well Operations ~ Copies of Logs and Surveys Run ~_ 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge ~- Z-~', .... '~..~ "-~ Form 10-404 Rev. 12-1-85 Title Operations Engineering Manager Date MRO ( 265-6810~ Submit in Dupli.cate NGI-12 ADD PERFS Daily Report of Well Operations 5/22/87 PT BOP, & lub to 4500 PSI. OK. Pull SSSV. PT lub to 4000 PSI. OK. RIH w/Dummy Gun. TTL, & Bailer. Tag bottom @ 9338 SLMD. POH. 5/23/87 PT hardline to 4000 PSI. OK. Pump in diesel/xylene wash - spot across perfs. PT lub/rams. OK. RIH w/20' & 6' select fire gun, 3-3/8", 4 SPF, 120° phasing. Shoot 9394-9414' (20'). Shoot 9290-9296' (6'). POH - All shots fired. PT lub/rams. OK. RIH w/ 6' & 18' select fire gun, 3-3/8", 4 SPF, 120° phasing. Shoot 9499'-9517' (18'). Shoot 9444'-9450' (6'). POH - all shots fired. PT lub/rams. OK. RIH w/14' & 7' select fire gun, 3-3/8", 4 SPF, 120° phasing. Shoot 9565'-9572' (7'). Shoot 9336' -9340' (4'). POH - all shots fired. PT lub/rams. OK. RIH w/16' & 6' select fire gun, 3-3/8", 4 SPF, 120° phasing. Shoot 9284 '-9290' (6'). Shoot 9206 '-9222' (16'). POH - all shots fi red. PT lub/rams. OK. RIH w/14' gun, 3-3/8", 4 SPF, 120° phasing. Shoot 9360' -9374'. POH - all shots fired. PT lub/rams to 4500 PSI. OK. RIH w/SSSV and set @ 2220. Pressure up hydraulic lines. POH. Test SSSV w/240 PSI differential. OK. STATE OF ALASKA ~-'-' ALASr.., OIL AND GAS CONSERVATION COMN....,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown E~ Re-enter suspended well [] Alter casing Time extension ~ Change approved program [] Plugging [] Stimulate ~ Pull tubing [] Amend order E] Perforate ~ Other 2. Name of Operator ARCO Ala_~ka: Tnn. 3. Address Post Office Box 100360, Anchoraqe, AK 99510 4. Location of well at surface 372' FSL & 865' FWL, Sec. 1 T11N R14E UM At top of productive interval ' ' ' 1574' FNL & 1304' FEL, Sec. 12, T11N, R14E, UM At effective depth 1707' FNL & 1165' FEL, Sec. 12, T11N, R14E, UM At total depth 1719' FNL & 1152' FEL~ Sec. 12.~ T11N, R14E, UM 5. Datum elevation (DF or KB) 44' RKB 6. Unit or Property name Prudhoe Bay Unit 7, Well number NGI-12 8. Permit number 77-R1 9. APl number 50-- 029-2(1284 10. Pool Sad]erochi t feet 11. Present well condition summary Total depth: measured true vertical 9693 feet Plugs (measured) 8651 feet 9650' - Cement Effective depth: measured 9650 feet Junk (measured) None true vertical 8612 feet Casing Length Size Cemented Measured depth ~ue Vertical depth Conductor 73' 20" 325 sx Arcticset Cmt 100' 100' Surfac~ 2754' 13-3/8" 4300 sx Permafrost Cmt 2781' 2708' Production 8689' 9-5/8" 800 sx Class G Cmt 8716' 7757' Linem -~ ' 1301' 7" 425 sx 8391'-9692' 7460'-8650 Perforation depth: measured 9186-9206', 9222-9247', 9264-9289', 9296-9326', 9340-9360', 9374-9394', 9414-9434', 9450-9465', 9479-9499', 95].7-9542', 9553-9573', 9584-9604' true vertical 8190-8208', 8223-8246', 8261-8280', 8291-8318', 8331-8349', 8362-8380' , 8398-8416' , 8431-8444' , 8457-8475' , 8492-8514' , 8524-8542' , 8552-8570' Tubing (size, grade and measured depth) 7", 29#, L-80, ABMOD 8rd to 5949'MD 5½" 17# L-80 ABM 8rd @ 5949'-8271'MD Packers and SSSV (type and measured depth) Baker FB-1 Packer fa R?SF~'Mfl/Oti~ .c;SSV fa ??4c)'Mfl 12,Attachments Description summary of proposal [] Detailed operations program E] BOP sketch ~1 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver MaS, 1987 Date approved 15. I hereb~ertify that,~/~fo/~goi,~is true and correct to the best of my knowledge Signed ~¢~_ ~.~'/_ .~ ~- Title Operations Enqineerinq Manager Commission Use Only Conditions of approval Date Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI No. ,, Commissioner Approved by Form 10-403 Rev 12-1-85 by order of the commission Date MR0 (265-6810) Submit in triplicate NGI-12 Proposed Additional Perforations ARCO Alaska, Inc. proposes to add perforations within the Sadlerochit interval in Well NGI-12. The proposed perforation intervals are as follows: Existing Perforations 9186-9206 (20') 9222-9247 (25') 9264-9284 (20') 9296-9326 (30') 9340-9360 (20) 9374-9394 (20) 9414-9434 (20) 9450-9465 (15) 9479-9499 (20) 9517-9542 (25) 9553-9573 (20') 9584-9604 (20') Proposed Perforations 9206-9222 (16') 9284-9296 (12') 9360-9374 (14') 9394-9414 (20') 9444-9450 (6') 9465-9472 (7') 9499-9517 (18') 9620-9628 (8') Reference BHCS of 12/20/78 TOTAL = 255' TOTAL = 101' A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized for this work. All perforations will be made with hollow carrier type guns at 4 shots per foot. All perforations will be made with an appropriate fluid, the perforating performed, and gas injection resumed with the wellbore load fluid being displaced into the formation. No flaring is anticipated. WELL: SURFACE LOCATION: BOTTOM HOLE LOCATION: ORIGINAL RKB': TOP OF SADLEROCHIT: ALL DEPTHS ARE RKB MD Depths are to TOP of equipment NGI #12 '-' SPUD DATE: 12/2/78 372'N &,865'E of SW cr. Sec. 1, TllN, R14E, UM 1719'S &~liSl"J of NE cr. Sec. 12,' 711N, R14E, UM 44' RKB TO Gray HANGER 27' 9177' , MD l~lO0' AVERAGE HOLE ANGLE: 290 MAXIMUM ANGLE: 34.50 @ 5188' ANGLE AT TD: 25o ANNULUS FLUID: 10.8 ppg CaLl2 & Diesel 20", 94#, H-40 Vetco (19.124" ID) w/ 325 sx 2196' 2249' 2364' 2420' 2548' 2781 5949 Bottom of 7", 26#, L-80 ABIJ4S (6.276" ID) Otis RPB Landing Nipple (5.963" ID) Bottom of 9-5/8", 47#, S00-95 BTC (8.681" ID) 9-5/8" FO w/ 300 sx Permafrost C Cmt. 9-5/8" FO ' 13-3/8", 72#, N-80 BTC (12.347" ID) w/ 4300 sx ' 7", 29#, L-80 AB[IOD 8rd (6.184" ID) 8238' Otis XA Sliding Sleeve (4.562" ID) 8257' Otis XN Nipple (4.562" ID w/ 4.455" No-Go) 8258' Baker FB-1 Packer Baker G-22 Locater (4.875"'ID) 8271' Bottom of 5½", 17#, L-80 ABM 8rd (4.892" ID) 8391' Top of Liner, BOT MC Nanger 8716' 9-5/8", 47#, N-80 8TC (8.681" ID) w/ 800 sx 9186' - 9206' 9222' - 9247' 9264' - 9284' 9296' - 9326' 9340' - 9360' 9374' - 9394' 9414' - 9434' 9450' - 9465' 9479' - 9499' 9517' - 9542' 9553' - 9573' 9584' - 9604' 9650' PBTD 9692' 7", 29#, N-80 BTC (6.184" ID) w/ 425 sx 9693' TD 1/84 iii i iiii i iii il 3 i,lI 2 I , I iI 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF W I REL I NE BOP EQU I PMENT ARCO Oil and Gas mpany North Slope ~,strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 25, 1980 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil & Gas Conservati on Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 Subject' NGI #12 (Permit # 77-81) WGI #2 (Permit # 79-43) Dear Si r' Enclosed please find corrected copies of the Well Completion Reports for the subject wells, as requested by your staff. The individual drilling histories and gyroscopic surveys remain unchanged as originally submitted. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'sp Enclosures Alaska 0il & Gas Cons. Anchorage ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form SUBMI-r' IN DUP[. ~ATE* STATE OF ALASKA (see ct,er in- structions on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* WELLL_J DRY[]]] Other Gas In.iection_ b. TYPE OF COMPLETION: NEW ~ WORKF--1 DEEP-F---I PLUG [---I DIFF. [-'-] WELLF~ I OVER I I EN I I BACKI I RESER.I I Other 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* 5. APl NUMERICAL CODE 50-029-20284 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. NGI-12 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field, Prudhoe At surface 372'N & 865'E of SW cr Sec 1, TllN, R14E, UM At top prod. interval reported below 1571'S & 1307'W of NE cr Sec 12, T11N, R14E, UM At total depth 1719'S & 1151'W of NE cr Sec 12, T11N, R14E, UM t. SEC., T., R., M., (BOTTOM HOLE 0i 1 OBJECTIVE) Sec 12, T11N, R14E, UM 12. PERMIT NO, 77-81 I DEPTH HOW MANY* 21. ROTARY TOOLS CABLE TOOLS 9693'HD 8651'TVD 9650 MD 8612'TVD Single All 22. PRODUCING INTERVAL(S), OF THIS COMPLETION -- TOP, BOTTOM, NAME (MD & TVD)* 23. WAS DIRECTIONAL Top Sadlerochit 9177'MD 8182'TVD SURVEYMADE Base Sadlerochit 9646'MD 8608'TVD Yes Bay Pool 24. TYPE ELECTRIC AND OTHER LOGS RUN FDC/CNL/GR, GR/CNL/CCL DIL/BHCS/GR, 2'5. CASING SIZE WEIGHT, LB/FT. 20" 94# 13-3/8" 9-5/8" 72# 47# CASING RECORD (Report all strings set in well) GRADE DEPTH SET (MD) I HOLE SIZE I H-40 88'Be10w Gq 30 325 iN-80 2781 .I 17~ I 4300 N-80 & 8716 I 12~ 1800 sou I I LINER RECORD SCREEN (MD) SIZE TOP (MD) BOTTOM (MD) SACKS CEMENT* 7" 8391 9692 425 ~. PERFORATIONS OPEN TO PRODUCTION (Interval, size and number) 9584-9604 9414-9434 9222-9247 9553-9573 9374-9494 9186-9206 9517-9542 9340-9360 All intervals shot .~'~.~9479-949_9_9_. 9296-9329 ~. ~ w/4 SPF 9450-9465 9264-9284 30. CEMENTING RECORD AMOUNT PULLED sx ArcticSet Cmt SX Permafrost Cmt To surface sx Class G Cmt 27. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 11 ~271 fi2~fi 29. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED PRODUCTION DATE FIRST PRODUCTION JPRODUCTION METHOD (Flowing, gas lift, pumping--size and type of pump) N/A DATE OF TEST. JHOURS TESTED CHOKE SIZE J PROD'N FOR I TEST PERIOD PRESS. 24-HOUR RATE ~ 31. DISPOSITION OF GAS (Sold, used for fuel, vented, etc.) 32. LIST OF ATTACHMENTS C, OI1111'ItSSIO[ 33. l hereby certifv~2Z;TZatyZd information is co~ plete and corre~,~r~j~,' ~~ble recoras. SIGNED~~~' ~~~] TITLE Dist. Dril'l~ng"Eng. I WELL STATUS (Producing or shut-In) Gl L--BBL. GAS--MCF. WATER--BBL. I GAS-Gl L RATIO I GAS--MCF. ~W J J ~:~ "[: [~q: ~ :~: ~ ~i~ E ATER--BBL. OIL GRAVITY-APl (CORR.) I TEST WITNESSED BY 'i '3 (~ ('i J I *(See instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26: "Sacks Cement"' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, WATER AND MUD 35. GEOLOGIC MARKERS NAME MEAS. DEPTH TRUE VERT. DEPT None Top Sadlerochit 9:~77 8:~82 Base Sadlerochi't 9646 8608 , ,, 36. CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER. , , None October 24, i980 Atlantic Richfield Company Attn: Pete Van Dusen 711 West Eight Street P.O. Box 360 Anchorage, Alaska 99510 Dear Hr. Van Dusen: In looking over the perforation intervals for this well I am wondering if there is a typo-error on the enclosed form. Should the intervals actually be 9477-9484 and 9484-9499? If there is an error, could you please submit a corrected copy. Thank you for your attention to this matter. Sincerely, Barbara Morgan Statistical Technician 1980. P. O. Box 360 Anchorage, Alaska 99510 We appreciate your letter of [~3rch 1...3_.~.~exp .~g subsurface safety valve testing in Prudhoe Bay gas inj.~.cn .~alls. Our understanding is that · NGI we!]~q 2, 12, 13, and 14 ar9 _ .equi~ with Otis flapper type valves. During non, al operatic~s these...type, valves are not surface ccntrolled. The remaining, gas' :injebti~n ~]~.s~ .are . .equi..~ with ball type valves. We have been witnessing initial "tests of these valves prior to the wells being used for injection, i iAl.th0ugh'these tests are /nloortant, we are anxious to see how these v~. :ves. .pe~f.~ _unde__r cpera~ ccnditic~s. Due to the problems involved with .bleeding off the gas during the testing., we agree that operational testir.~....of .these .valves should be d~layed until the gas bl~ system is installed. ~herefo~, we propose ccntinued 're..sting. ~ of new valves when first in- stalled, and witnessing operati ~' .~..test/ng of all .c/as injectic~ valves upc~ cc[~pletion of the gas blc~~ syste~ in August. We ~c~tld also appreciate a ~11 invent, lis.'~ng the 'type 'of subsurface safety valve C.~th, ~ssic~.r ARCO Oil and Gas Company - ~. April 3, 1980 Reference- ARCO Cased Hole Logs D.S. 2-2 2/29/80 Spectralog Run ] 5" D.S. g-10 2/12/80 Spectralog Run ] 5" ' D. S ,~_1~4:_8 1/27/80 ACBL/VDL Run 1. 5" #12 .... 1/25/80 Differential Temp. ~n 1 ~Please si~ ~d return the attached copy as receipt of data. K. J. Sahlstrom North Engineering TRKNSMITI'AL # 251 DISTRIBLrFION North Geology Drilling Eng .Manager D & ~I Geology State of Alaska ~Iobil Gett:y ?hi].l~ps Sohio ~.Iarathon Che~,Ton ARCO Oil and Ga.~;-~"~mpany Norih Aiask., ~J[strJct ~,~.~ 00× 360 ,Anchorage, Alaska 99510 Telephone 907 277 5637 February 12, 1980 Hoyl e Hami 1 ton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' NGI #12, Permit No. 77-81 Dear Sir: Enclosed please find a Completion Report and Perforating Hisory for the above-mentioned well. Very truly yours, P, ^. YanDusen District Drilling Engineer PAY/ms Enclosures RECEIVED ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form P--7 SUBMIT IN DU~.~.,,. ~TE* STATE OF ALASKA (see other In- structions on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: VV:L ' ' 9,1~L, Lr--'] GASwELLF--l DRYF-'] Other Gas Injection b. TYPE OF COMPLETION: NEW ~ WORK[~l DEEP-[~I PLUG r'-I DIFF. I'--] WELLI ~ OVER L__I EN I I BACKI I RESER.I I Other 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360, Anchoraqe, AK APl NUMERICAL CODE 50-.029-20284 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. NGI #12 99510 10. FIELD AND POOL, OR WILDCAT 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* A~f~N & 865'E of SW cr Sec 1, TllN, R14E, UM At top prod, interval reported below I I ltBto7t]ldeSpth& 1307W of NE'cr Sec 12, lllN, R14E, DM 1719'S & 1151'W of NE cr Sec 12, TllN, R14E, UM 13. DATE SPUDDED 12/2/78 18. TOTAL DEPTH, MD & TVD1119' DEPTHPLUG BACK MD & TVDI20. IFHowMULTIPLEMANY. COMPL., Si ngl e 9693 'MD 8651'TVD I 9650'MD 8612'TVD I 22. PRODUCING INTERVAL(S), OF THIS COMPLETION -- TOP, BOTTOM, NAME (MD & TVD)* Top Sadlerochit 9177 'MD 8182'TVD Base Sadlerochit 9646'MD 8608'TVD Prudhoe Bay Fi eld-Prudhoe Ol~ 11. SEC., T., R., M., (BOTTOM HOLE Pool OBJECTIVE) Sec 12, TllN, R14E, UM 12. PERMIT NO. 77-81 21. ROTARY TOOLS INTERVALS DRILLED BY CABLE TOOLS All 23. WAS DIRECTIONAL SURVEY MADE Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL/BHC/GR, BHCS/GR, FDC/CNL/GR, GR/CNL/CCL 25. CASING RECORD (Report all strings set in well) 20" 94#Welde~! H-40 I 88'below (~L 30,,,r, 13-3/8" 72#Butt ! N-80I 2781" ! 17-1/2"J 9-5/8" 47#Butt / N-80&I 871 6' / 12-1/4!"/ - I soo-9 I I s,~ I TOP (MD) I BOTTOM (MD) I SACKS CEMENT* SCREEN (MD) 7" I 8391' I 9692'I 425 sx I I CEMENTING RECORD ~ AMOUNT PULLED 325 sx Arcticset cmt 4300 sx Permafrost cmt Class "G" cmt 800 sx 27. SIZE 7" TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 8271" 8258" 28. PERFORATIONS OPEN T~]~RODUCTION ~, (Interval, size and number) ..':'~584'-9604'. i.94.~'-9484'-'~,',.79306''9326' ~ DE.TH INTERVAL (MD) 9553 -~573 ~450 -9465 ~296 -9306 9186 9206 ,::..,9522-9542 ~9414 -9434-'~, C9286 -9296 N/A 9517 -9522 ~9374 -9394: .9264 -9284 .~ , ........~_~. ?~:9484'-9,499~' ~9340'-9360'.' ~9222'-9247! w/¢ s,,u.~ v:, ,-~. 30. PRODIJCTION DATE FIRST PRODUCTION IPRODUCTION METHOD (Flowing, gas lift, pumplng--slze and type of pump) N/A I FLOW TUBING ]CASING PRESSURE PRESS. 29. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. AMOUNT AND KIND OF MATERIAL USED WELL STATUS (Producing or shut- n) [WATER--BBL. IGAS--OIL RATIO CALCULATED OIL--BBL. GAS--MCF. WATER-BBL. ICIL GRAVITY-APl (CORR.) 24-HOUR~ RATE~ I I ITEST WITNESSED BY 31. DISPOSITION OF GAS (Sold, used for fuel, vented, etc.) 32. LIST OF ATTACHMENTS Perforating Hi story hereby certify that the foregoing ~d attac~hed Information is co/nplete and correct as determined from all available records. TITLE District Drilling Engineer *(See instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item' 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26: "Sacks Cement"' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28' Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, WATER AND MUD 35. GEOLOGIC MARKERS NAME MEAS. DEPTH TRUE vERT. DEP*r ,,, NONE Top Sad]erochi 9] 77' 8] 82' Base Sad] erochi 9646' 8608' 36. CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER. NONE ' Perforating Hi story NGI #1 2 API No. 50-029-20284, ADL 28302, Permit No. 77-81 Began perf operations 0600 hrs 1/23/80. Bled press off well. Set tree plug. Tstd tree to 5000 psi. Pulled tree plug. RU wireline. Pull SSSV. RD wireline. Tstd 9-5/8" x 7" ann & 7" tbg. Tstd all valves & choke man. RU perf mast unit. Ran diff temp log. Perf'd intervals from 9584'-9604', 9553'-9573', 9522'-9542', 9517'- 9522', 9484' -9499', 9497'-9484', 9450' -9465', 9414' -9434', 9374' -9394', 9340' -9360', 9306'-9326', 9296'-9306', 9286'-9296', 9264'-9284', 9222'-9247', & 9186'-9206' w/4 shots/ft. Ran HP press tool. Took static reservoir press f/1 hr. Instl & tstd BOP to 5000 psi. Attempt to set SSSV. Could not get below 658' 'Ran wire- brush then gauge ring. Flowed well to flare pit. Filled hole w/diesel. Ran & tstd SSSV. RD perf equip. Instl & tstd tree cap to 5000 psi. Released well to Production Department @ 2330 hrs 1/31/80. ADDENDUM WELL' 12/26/87 NGI-12 Instal led tree cap adapter w/6-3/8" bore. Tested to 5000 psi. RU lubricator. Pull BPV. Pressure annulus to 1500 psi. Pressure tubing to 3800 psi to shear shear out sub. ISTP - 200 psi. SI tubing. Bled annulus to O. Drilling Supervisor \ Dat~e ARCO Oil and Ga'""ompany Alaska Post Office Bo× 360 Anchore~ge, Alaska 99510 Teiephone 907 277 5637 July 18, 1979 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: NGI #12 Permit No. 77-81 Dear Mr. Hamilton' Enclosed please find a Sundry Notice outlining our plans for the above-mentioned well. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'cs Enclosures ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Forn~ ! 0-403 '~ Submit "1 ntentions" in Triplicate REV. 1-10~73 & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) WELL LJ OTHER Gas Injection NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360 Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 372'N & 865'E of SW cr Sec 1, TllN, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 51'RKB, 18' Pad Elevation (Gravel) 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20284 6. LEASE DESIGNATION ANO SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. NGI 12 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe 0il Pool 11. SEC., T., R., M., {BOTTOM HOLE OBJECTIVE) Sec 12, TllN, R14E 12. PERMIT NO. 77-81 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS {Other) SUBSEQUENT REPORT OF-. WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all I~ertlnent {letalls, and give pertinent dates, Including estimated date of starting any proposed work. Atlantic Richfield Company proposes to perforate selected intervals in the Sadlerochit between 9186' and 9604'MD. A 5000 psi WP wireline lubricator, tested to working pressure, will be used on all wire!ine work. The well will beflowed to the flare pit for clean up and liquids will be burned in accordance with. the Department of Environmental Conserva- tion Burn Permit. The downhole safety valve will be installed and tested upon conclusion of the job. Estimated start is August 1, 1979. SIGNED-~J * I~, _ _ __ . TITLE District Dril 1 inq Enqine~r DATE -. APPROVED BY TITLE DATE CONDITIONS OF APPROVAL, IF ~(~N~.' IBY ORDER OF THE See Instructions On Reverse Side 7/18/79 Jtme ]..q, 1979 Enclosed are the :12~]_lo~,/J.ng logs' 4/~1/79 4/9/7g 4/~:~/79 4./~_/7~ (s'.ff,~ Picasc s.t-'~,~j~ and ~-eturn the cop); as_ ~'c(:o:Lpt o[ d~fa. SJ ncerc].y, Tib%XS!~II"ITA[, /! 1$ 8 Post Office 8,~k350 Anchorage, ska g9510 Tel~-:phone 9,07 277 51537 Reference: Enclosed are the following Directional Surveys: DS 13-4 Singleshot ~/23/79 -DS 7-9 Singleshot 4/3/79 DS 7-10 Singleshot 4/3/79 DS 7-11 Singleshot 4/3/79 DS 14-7~ Singleshot 4/25/79 ~NGI #1~ Singleshot 4/23/79 DS 7-12 Singleshot- 4/23/79 c:op~, receipt of data. Please sign_ and ret~a~nfthe as Sincerely~ ~ V.G. Reimers North Engineering TRANSMITTAL #163 DISTRIBUTION North Geology,., '~' Drilling Eng. Manager Geology State of Alaska D&M ~xxon- .... Mobil Getty Sohio '~" ~rathon ~illips Chevron ~,iorti-~ Americ.2n ProS~:cing Post Of,"ice ~ "277 March 27, 1979 Reference: Enclosed is the following cased hole log' NGI #12 CNL '12/20/78 Please sign and return the copy as receipt of data.~//~1~9'- 7/~,;~ V.G. Reimers North Engineering TRANSMITTAL #127 DISTRIBUTION North Geology Drilling Eng. Manager R&D Geology State of Alaska D&M blobil Getty Sohio Marathon Phillips Chevron A::ia;~.',ic~ich5 North American Produci~:9 Division North Alas!¢ ~'~istrict Post Offics ~, 3,60 Anchorage, Alaska 99510 Telephone 907 277 5537 March 16, 1979 Reference' Enclosed are the following open ~'ole logs' NGI #12 g.,~L' 12/20/78 5" NGI #12 ~'~'iCS 12/20/78 S"'~ NGI #12 '~L/FDC 12/20/78 5" NGI #12 ~JF/DC 12/20/78 .5" NGI #12 z~BHCS 12/20/78 2" Please sign and return the copy as receipt of data. Sincerely, V.G. Reimers North Engineering TRANSMITTAL #104 DISTRIBUTION NOrth Geology Drilling Eng. Manager R&D Geology State of Alaska D&M Exxon Sohio Mobil Marathon ;Phillips Chevron Getty Atlan[icP, ichfie:d Company North American Producing Division North Aiask~'~-;strict Post Office ~ .380 Anchorage, Alaska 99510 Telephone 907 277 5S37 March 16, 1979 Reference' / ~~- 3 F;NG 4 L:NG 5 ' ENG & D~AFT I -- SEC CONFER: FILE: Enclosed is the following cased hole log' NGI #12 CNL Please sign and return the data. Sincerely, 12/25/78 copy as receipt V.G. Reimers North Engineering TRANSMITTAL #105 North Geology Drilling l Eng. Manager R & D Geology State of Ataska DISTRIBUTION Exxon Sohio ,Mobil }.'brathon Phillips Chevron Getty fiorU1 Alaska Dislr~c! Pos~ Ofiice Box 380 Anchorag~ ~aska 99510 Telephone ua7 277 563~ March 12, 1979 Reference' '-. Enclosed are the following Magnetic Tapes' · · DS 7-9 CNL/CCL/GR 2/25/79 .12/25/78 7700-10770' 6630-9680 ' #54316 Please sign and retuz~ the copy as receipt of d~ta. Sincerely, V.G. Reimers North Engineering TP4tY~'IlTTAL fi'89 North Geology Drilling Eng. Manager R&D Geology State of Alaska DISTRIBUTION }L~xon Sohio ~bbJ. 1 Marat]~on Phillips C]~evron Getty Q' t North Alaska Dislrict Poat O/lice '~ ,' 380 Ar'~(;t'~o~age,, aska 9:)510 Telephor~e 007 2775~37 February 20, 1979 Reference' .Enclosed are the following ~'blGNETIC TAPES' I)S 15-1 12/2/7~ #54607  1/1/79 #54576 OI-I 12/20/78 #54.571 OI-I * 1/2/79 #54575 OH . ease sign and return the copy as receipt of data. Sincerely, V.G. Reimers North Engineering TRANSMITTAL # 78 DISTRIBUTION North Geology Drilling Eng. Manager R& D Geology State of Alaska D &M Exxon Sohio Mobil Marathon Phillips Chevron Getty Plltq~orh!io Atla.~ficRich!ieldComp~ny North Ameri~an Producing Division North Aiasl< ~strict Post Office Box 360 Anchorage, Alaska 995'~0 Telephone 907 277 5637 January 31, 1979 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 .. Subject: NGI #12, Permit No. 77-81 Dear Mr. Hamilton' Enclosed find a Completion Report along with the Drilling History and Magnetic Multishot Survey for the above-mentioned well. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'cs Attachments Form P---7 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE i i WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: On,,,.ELL [--] ~ASWELL CJI DRY []]] otberGaS Injection b. TYPE OF COMPLETION: NEW[] W0nK [] DEEP-[] PLUG ~-~ DIFF.[] WELL OVER EN BACK P.E SV R. Other ____ SUBMIT IN DL...CATE* (Se~ :ther reverse 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.0. Box 360 Anchorage, ^laska 99510 4~'. LOCATION OF WELL (Report location clearly and in accordance with any State requiremeuts)* At surface 372'N & 865'E of SW cc Sec 1, TllN, R14E, UM At top prod. interval reported,below 1571'S & 1307'W of NE cr Sec 12, TllN, R14E, UM At total depth 1719'S & 1151'W of NE cr Sec 12, TllN, RI4E, UM 18. TOrF~L DEPTH, MD & TVD ~19. PLUG, ]EK~LCK MD & TVD~20. LF IVEULT~LE COM. PL., ! 21. / / I-IOW i~2kNY* I ROTARY TOOLS 9693'MD 8651'TVD |9650'MD 8612'TVD ~ Sinqle 22. PRODUCING INTeRVAL(S), OF THIS COMPLETIOENT--TOIP, BOTTOM, NAME (NIT) AND TVD)' ~Top Sadlerochit 9177'MD 8182'TVD Base Sadlerochit 9646'MD 8608'TVD 5. API NU-M_F_ATICAL CODE 50-029-20284 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7.IF INDIAN, A-LLOTTEE OR TRIBE NAME 8. UNIT,FA.ILM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. NGI #1 2 Sec 12, TllN, R14E, .UM 12. PER]VIIT INTO. 77-81 44' RKB INTERYAI.S DRILLED BY A11 23. 'vVAS DIRECTIONAL SURVEY MADE Yes 24. TYPE ELECTRIC AND OTHEi% LOGS RUN DIL/BHC/GR, BHCS/GR, FDC/GNL/GR, GR/CNL/CCL ii ! -- Ill 25. CASING RECORD (Report all strings set in wi'{i) . 20" 9z~# We i ded[ H-40 ] 88' bei bW G[~ 30" 1 13-3/8" 72# Butt [ N-80 ~ 2781" [ 17-1/2"i -' 9-5/8" 47# Butt /N-80&! 87161' I 12-.1/4"/ _ I · I s00-951 / 26. LIN'~,~ I:LE C O lq.D : N/^ C 'EAiLNTING RECOILI) AMOUNT PULLED 325 sx ^rcticset cmt 4300 sx Permafrost cmt 800 sx Class G cmt i lit 27. TUBING RECOIkD SCREEN (~[D) SIZE DEPTH SET (I~D) 7" , 8271', [ 29. ACID, Si!CT, FiiACX~CrtXE, CEa~IENT SQUr'm77'2 ETC. D]~iFIi iNTERVAL (MD) [PACKER SET (MD) 8258' L USED , 3O. PRODUCTION DATE FIRST Pt%ODUCTZON [ PRODUCTION N/A DATle O1~' TruST, It{OURS TESTED ' [CI-IOZ(E SiZE [PROD'N FOiq, ~'W;"k~_miN~ ~ FASING PRESSU'm~ ICALCUr~am~ 81. rnsPos~T~o~ or ~AS (,gOld, u~ed.for ~uel, vented, etc.) ME'iHOD (Flowh*g, gas lifL pumping--size and type of pump) OIL--t~EL. 1 GAS---M~C'F. 1 I TEST WITNESSED BY · ,, sz. ~lsT o~' ~{kCHnES~S Drilling History, Magnetic Multishot (Gyroscopic not available at this time) ,, 33. I hereby certify that the ,~oregot'ng and attached information is complete and eorreCf as determined from all-available records SIGNED ....... TITLE District Drilling Engineer ~TE *(See Instructions and Spaces [or Additional Data on Reverse Side) / :) ,>,/-~ ,,; : ' r ~I~US (Producing or ~nut-in) GAS--IVLCF. W£JI'ER~--BBL. ] GAS-OIL R.%TIO I i WA~BBL. [ OIL GRAVITY-~I (CO~,) ___1-_31 - 79 INSTRUCTIONS General: This form is designed for submittincj a complete arid correct welt completion reDort all types of lanJs and leases In Alaska. Item: 16: Indicate which elevation is used as reference (whe~'e not otherwise showl~) for depth measure- merits given in c, ther spaces on this forr'~ ar~c:l in ar~y attac!~menls Items 20, and 22:: If this well is completed for separate~ prcd:~cti.~n from more than one interval zone (mulliple completion), so state ~n item 20, 0nd iI'~ ite.~ '?? show thc: F~c.J~c~:Ct intcrvol, o: top(s), bottom(s) and name (s) (if any) for only the interv~l ret~orted in item 30 Submit a separate report (page) on this form, adequately identified, for each additior~al interval to be seperately produce:'t, show- ing the acktitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). , ,, , 34. SUMM'AR¥ OF I,~ORM'ATION TESTS IN('LUD~N(; INTEI~{VAL TE,STE~'.'t-:~HE.'e~SURE i)Aq'A ~'~C()V~RIF~ OF OIL GAS. 35 G~GIC MARK~ WAT~ AND MUD NAME lop Sad]eroch~t 9177' 8182' Base Sadl eroch~ t 9646' 8608' .. , ,, ~ , ,, , , ~ ~ ~ , 'an. col[E DATA. A'I'I'ACl[ ~RIEV ~'~RIPI~O~S O? LITIiOLOGY, POnOSITY. FRAC~R~, APP~T DIPS AND I)~l'gLn'gl) SlIOWS OF OIL, G~ Oll WA~I. i ii m i i .-i~ ii i [ i iii ~one ,, , , , NGI #12 Drilling History API 50-029-20284, ADL 28302, Permit No. 77-81 Spudded @ 1700 hrs 12-2-78. Drld 17-1/2" hole to 2800'. RU & ran 13-3/8" csg w/shoe @ 2781'. Cmtd w/4300 sx Permafrost cmt. Drld shoe & 10' new form. Did leak off tst. Drld 12-1/4" hole to 8730'. RU & ran 9-5/8" csg w/shoe @ 8716'. Cmtd w/800 sx Class G cmt. Sqz 300 sx Permafrost "C" cmt thru lower FO. Did Arctic Pack job thru upper FO. Drld shoe & tstd to 12.5 EMW. Drld 8-1/2" hole to 9683'. Ran DIL/BHC/GR, BHCS/GR, FDC/CNL/GR logs. Drld to 9693'. RU & ran 7" lnr w/shoe @ 9692', top @ 8391'. Cmtd l nr w/425 sx Class G cmt. Tstd l nr to 3000 psi, OK. Ran WSO tst. Displ mud w/CaC12. Ran GR/CNL/CCL logs. Ran gauge ring & junk bskt. Ran 7" compl assy set @ 8271'. Tstd balance & control lines. Pulled dummy valve. Ran CCL/dummy gun. Ran SSSV. NU & tstd tree. Pulled SSSV. Displ tbg w/diesel. Reran SSSV. RU for long term tbg tst. Released rig @ 0600 hrs 12/31/78. -- ~ iiii i i ~ ~ ~_ _ I ii ~ · ii ii ii DATE REPORT and PLAN of SUB-SURFACE SURVEY i i i i nl i ! i ~ n ii III I II II I III IIIiiiii I ii i1111 III II ! I COMPLETION REPORT 23 APR 79 ATLANTIC RICHFIFLD CO N G I - 12 MAGNETIC SINGLE SHOT SURVEY DECLINATION 31 DEG RADIUS OF C[JRVATURE METHOD OF COMPUTATIONS K B ELEV ~+4 FT COMPUTED FOR ADDCO BY F M LINDSEY AND'AsSOCIATES EA S.T RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY. I..B M.E!.ECT!~ONI¢ COMPU TI::. R TRUE ............................................................... DQF~..... L E G M~As, DRIFT VERTICAL .... SUB . DRIFT .TOTA..L..C_O0~DINATE5 .C L 0 ~ U R ..D~PTH , ANGLE .... DEPTH SEA. DIREC DISTANCE D M ........ DEG. D M S 0 0 0 o,oo -46~00 N.O~OOE .............. E~gO S 0,00 W . 0.00 ......... ~96 ...... 0..0 .... 696~90 ........ 652.~00 1340 0 30 1339.99 1295,99 .50.OOW .... Q,O0 N 1,TR w 1.78 ............ ~446 !.~0 ........ !~45~97 ...... ~4~1,_97 ..... !~44~00E ...............g,.~_~ ..... Q,44 w 0,70 _ 1537 3 0 !53~90 1492.90 _N86,00E ....... 0~93 N .... 2,7! E 2.87 ...... %627 ...... 4...~0 .... 1626..70 ..... ~2~70 .... !72~ .... 7.3~. !7%9,18 ~675~!8 1811 9 30 1996 14 30 2273 21 30 2522 28 0 2615 29 30 2706 3O 0 3016 29 30 3298 31 30 3577 32 0 __ ~ 3888 33 30 4351 34 0 4679 34 0 51R8 34 30 5997 33 0 6497 32 0 6991 32 0 7463 31 0 8016 29 O !809,18 1765,18 572.00E 1990.08 1946,08 S64,00E 20.21 S 66,45 E 2253.36 2209,36 S49,00E 67,29 S 137,58 E 2479.36 2435.36 S54.00E !32,13 S 219.09 E 2550.90 2516,90 556.00E _!57~78 _ 2639.90 2595.90 564.00E 180.34 S 294.8! E 2909,04 __286~04...~65,0Q~ '.. _~4~_~_~ .__ 3152.01 3108,01 S63.00E 309,30 S 582.27 E _ _ 3389,26 3345,26 S62,00E 377.09 S 692.50 E _ . 3650.81 3606,81 S60.OOE 458,65 S 839.63 4035.78 3991.78 S61,OOE ...585,3!S 1063,51 E 4307.71 4263.71 S61.OOE 674,23 S 1223.93 E 4728,44 4684,44 S60,OOE ~5.30 $ _1473,25 E ._ 5401,08 5357.08 S61.OOE 1036.61 S 1864.42 E 5822.77 57.78.77 S60,ooE !168.90 S 2098.24 E 6241.70 6197,70 S55~00E !309,50 S 2318.95 E 6644,%5 6600.15 557.00E !447,40 7123.03 7079.03 S55.00E 1602~00 $ 2752,60 E 8.59 18.08 3!,37 69,45 153.15 S 6_3.. 56 .l~.g .... ]._2_,630 255.85 S 300,49 345.59 $ 58 32 498_~8~ $ 60_.22 641.73 ,5 61 11 788.5! S 61 2_5 956.7zf 1213.94. $ 61 lQ 1397,35 S 61 9 1~83,80 S 61_ 2 2135.J2 S 60 55 ~401o86 2663.15 S 60 ~2 2909,04 S 60 9 31b4,85 S 59 48 ARCO NGI-12 MAGNETIC SINGLE SHOT SURVEY 23 APR 79 REcoRD OF SURVEY ALL cALCULATiONS PERFORHED-BY-I ~--.a.ELECTf~ONIC cOMPUTER TRUE FJ(D~. LEG ............................. '.HEA.S ~ii DR!.F.T 'VERT ! CAL ...... sUB ...... L' DR ! FT iT E'DQ.R.D ! ~AT E5 C L 0 S._ .... ~.. ~ &EWE.~.I_ ~_Y_ ................. _5~C_T_I_ON. DEPTH ANGLE DEPTH SEA DIREC DISTANCE ..ii. ii' 'i' '~_.iii _._ D_"i .. .... ~ .... 'DEG' .__ii.._i ..... i.._i~i_-i .......... 90.3.5 ~3 0 .. 8043.73 7999.73 ~45,~OE ..... !870,8~ 5 ..... ~094,76 E :56!6.31 $ ~8 ~0 45..~ ........... ~4~7 ................. ~.~ ).~ ......... 9683 .25 O ... 86.34.87 .... 8590,~T 548.00E ~0~4.~ S ...... 3286~20 E .. 3875~61 S 57.59 9 E .......... 0.,~6Q ~..~..7_.~..~.6~ .......... 969~ ~.~ ....... O ...... 864.3...9~ ..... 8~99.~.9~ ..... ~8.~QQ~ ..........~g.~_7. t~.~ ..... ~_ ......... ~9...,~ ~ ~79,77 ~ ~7 .... ~ 30 .... E O.000 3~79.77 ARCO NGI=12 MAGNETIC SINGLE SHOT SURVEY 23 APR 79 MEASURED.DEPTH AND OTHER DATA FOR EVERY EVEN. 1_0o FEET OF SUP. SEA DEPTH, ................ TRUE MEASURFD VERT_ICAL SUB MD-TVD VERTICAL ._DEPTH DEPT_H SEA .DIFFEREN_C.E ......... CQRRECTIQN TOTAL COORDINATE5 144 144. 100 0 0 0,00 244 244, 200 0 0 0.00 344 344. 300 0 0 0.00 .............. 444 ........ 444. ..... 400 ..... 0 ............................ 0 .... Q.OO 544 544. 500 0 0 0.00 .......... 644 644, ......... 600 0 ............... 0 0.00 744 744, 700 0 0 0,01 844 844. 800 0 0 0,!3 .................. 944 944, ...... 900 ...... 0 ............. 0 0.32 ................... %044 ............ 1044, .... 1000 ............. 0 ................................. P 0,47 .... ~!44 1144. .... 1100 0 ............. 0 .......... 0,50 ...... -]' .............. ~.244 .......i ....... %24~. ...... 1200 ..... 0 ....................................... 0 0,34 _ .. 1344 1344, !300 0 ...... O 0.03 ...........................................................................................................................1444 1444, 1400 0 0 .56 ....... 1544 1544. ..... !500 .................. !.6~4 ~._ 1644. .........1600 1745 1744. _1700 ...... 1846 ..... 18~4, ....... 1800 1949 1944, 1900 .__ ~052 2044, 2000 2157 . 2!44,. 2100 ~263 ........ 2244. 2200 2371 2344. 2300 _ . _ .......... 2402 I 2444,. 2400 2596 254a. _2500 .... 2711 2644. .g6OQ . 2R26 2744. 2700 ....... 2941 2844, __ 2800 3058 2944. 2900 _ ~72 3044, 3000 328'9 314~. 3100 _ 3406 3244. 3200 3524 3344. 3300 .......... 3642 3444. 3400 3760 3544. 3500 0 ............. O .... 0,95 0 .......................... 0 0,29 1 1 2.77 7,77 15.51 . . 27,00. 4 2 7 ....................... 3 18 27 9 38 ............. 11 _ 51 13 67 .... 16 82 . 15 97 ........ 15 112 15 127 _ 15 144 17 161 _. 17 179 18 197 ....... 18 216 19 S S ...... 0 _,. ao W ............................................................ S O,~O W ........................................................ 5.' 0..00 ~' . ................................................ $ . U,O0 .vi ...............................F-- 5.'. ......... O.O0 N O.QO E ............................... N .............. 0,0 5 _ E ....................................................... N O,2g E N .... 0,~4 g ' . _ _ N ..... 0,98 E N ........_!:~. g ...................................................... . 1,78 W ....................................... .............. _0,48 N _ _3.08 E ................................................................ N .. 9,96 E .................................. S 21,23 E .......................... S 3.6,5 7 E 43,37 64,98 91,78 121,16 152.44 181,38 206.40 230.86 254.97 280,27 307.08 335.16 363.88 393.44 424.07 56,11 E ............. 79,48 E ......................................... 105,95 E 134.78 E ............... 166,77 E ................................. 204,~7 E ............... 247,8~ E 296.93 E ..................................... 348.70 E ............ ~00,!~ E 451.56 E 504,13 E ...... 557.90 E 612.60 E ....................... ~67,55 E 722,98 E ............. 778,7~ E ........................... ARCO NGI-12 MAGNETIC SINGLE SHOT SURVEY 23 APR 79 ' MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA .......................... TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE C°RREcT I QN T~TAL _ 3880 4000 3744,. 3700 . 255 .... 20 ..................... ~!gO .............. 3844~ ..... 3.8Q0. .276 ...... 4240 3944, 3900.. 296 ..................... ~36~ 4.044~ .........4000 ........ 3~7 ........ ~48! ......... 4!44~. ~100 337 .................... 4602 ....... 4244~ ..... ~200 ...... ~8 .................................. g! ......... .......... 4723 . 4344~ ..4300 378 4964 ..... 4544. 4500 ~20 .......... DEPTH, 3644: .... 3.600 2_35 ........................ !9 ............... 456,60 S 835_, 73 ............. 5085 ........ 4644~ ......... 46~0 ..... 441 ................................. g 5207 4744~., ~700 46~ .......................... 2 53~8 .................. ~8~4, ........... ~.800 ~84 ............................... 2 ........................... 5569 ........ 56_89 ................ _5 BO_ 9 . .. ........ 5929 ................. 6048 6167 ........... 6286 __ 64.04 .......... 6522 664O 675a 6876 6994 7111 72_29 ........... 7346 7463 7579 7695 7811 _ 514~. 5100 5244, 5200 5344, 5300 5444, _ .DfiO0 5544, 5500 56.5 .............................. 2 585 .. 2 6Q~ ............... 1 623 1 7925 l ......................... 719.~0._1_ ~ 1~0.~,18 E COORDINATE E 489.49 S 893.,32 E .......................................... 555,!5 S 1009,~7 E 588,00 $ 1068,~6 620,56 $ 1127,09 686,13 S 1245,35 732 ..... !8 750 ............... 767 17 785 18 802 17 819 17 835 16 851 16 867 16 _ .7044o _.'7000 . 88 % ............ !4 6144. 6100 6244. 6200 . _ 6344. 6300 6444. 6400 6544. 6500 6644. 6600 6744. 6700 6844. 6800 6944. 6900 5644. ..5600 6~2 ................. 19 . 574~. 5700 660 _ _16 5844, _. 5UO0 678 5944. 5900 696 6044. __ .6000.. 7~4 26 $ 1~22,7~ E ............. 64 S 1482,51 E .................................... 71 5 .... 15~1,76 E 35 $ 1600,61 E 32 S 1717,0~ E 66 $ 177~.71 E 58 S 1831,9~ E 10~0,1~ S 1888.74 E 1081.55 S 19~4.94 E ............................ 1112,93 $ 2000.50 E ........ 1144,26 S 2055,4Z E 1172,54 $ 2109,70 E 1207,59 ~ 2163,36 E 1240.75 $ 2216,32 E 1310,33 5 2320,1~ E ........ 13q5.75 S 237!.g! E 1380.40 $ 2~22,~ E 1414.26 S 2472~82 1447.35 S 2523,32 E ............... 1479~99 S 2~73~18 15!2.4b S 2621~98 E 15~4~72 S 2669,72 !575.79 S 2716,42 E 0 1018, 9 1 ............ 786, 1 888. 0 .................. 921. O ............ 954, 0 ....... 986. ARCO NGI-12 HAGNET IC SINGLE SHOT SURVEY 23 APR 79 MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, TRUE .. MEASURED VERTICA~ SUB MD-TVD VERTICAL .................. DEPTH ..... DEPTH .... SEA DIFFERENCE ....... ~©RRECTI.ON TOTAL COORDINATES 8040 7144. .......~1'00 896 .. 15 1608,63 ..................... ~53 7244. .......7200 ~ 909 ................................. !3 ........ 1639,~2 ........ ~.g65 7344. 7300 92! ................ !2 1668,32 .................... 8.~77 ............ ?444. ......... ~GO0 9~3 ......................... ~g ............ ~696,58 ..... 8487 7544, ........ ?5DO.. 943 ......... ~O ...... 1724.99 ....... 8598 .......... 7644, .......7600 ........ 954 .................... !~ !75~7! 8708 7744. 7700 964 10 1782.70 ......... ................. 8817 ............ 7844. ........... ZSO0 .... 973 ....................................... ~ ..................... ~8!!.93 6926. ~ 7944. 7900 .... 9~2 ~ ................. 1841.3~ ........ 9.03~ ........... 8044.. ........... 80QO.. 79! ? ................... !8~0.86 2762,07 2805,89 28~7.31 Z~7~17. E .~925.,36 2962~ 2997,4~ 30~7~.E 9144 8144. 8100 1000 ....................... 9 1900o90 S 3125,~8 E -9~53 '- 8244. 8200 1009 9 1.85 9363 8344. 8300 1018 9 1963.~2 S 3188.8~ E . ..... ....................... Pg73 .................. 8444, ...... 8~.0~ ~0~.8 ........................... 10 !99~.~8.& ..3221,61 E 95~3 .... 8544. .... 8500 !.038 ....................... %0 Z026,2l s 3955.11 .................................................................................... ARCO NGI-12 MAGi'iETIC SINGLE SHOT SURVEY 23 APR 79 !~!TEF,~pQL_A_TED. VA._L. UES. FQR EVEN !000 FEET OF HgS.SWRED DEPTH, TRUE MEASURED VERTICAL SUB ........................ ..... .]DEPTH ' DEPTU ...... ] ........... SEA .......... T.O_T__A~ ....C_ 0(..) R D_' I ~:IA T E S ........... !O00 ..... 999? ......... ~5~. ........... 0~4~. ~ ........ 0.38 E _.. 2000 1993~ 1949. 20~65 S 67,35 E 3000 2895, ..........2851~ ....... ~~.~ .... 426,50 E 4000 3744. 3700. 489.49 S 893.32 E ~000 4573? .............. 45~9. ............ 76~.4~ S __ 138!.08 E. 6000 5403. 5359. ],037,40 S 1865.8,5 E 8000 7109, ..........7065, ....... I_597,5~ S 2746.24 E - '. ...... _ ~ VERTICAL SECTION 400 ...... ATLANTIC RICHFIELD CO .......................................................................................... NGI -12 - -- - ..... -':-- -'- ..... ' MAGNETIC SINGLE SHOT 6oo ...................... RADIUS OF CURVATURE ............................................................................................................ SCALE I" = I000 - '-~200 ............ APRIL 26, 1979 1600 - 3200 ............ 4400 4800 5200 5600 ................ 64d 6800- ............................ 7200 ....... 7600 eO00 .................. 8400 TVD: 8644' TM0=9695a .... ' -- ~....- ............... HORIZONTAL VIEW ........ .._ . ATLANTIC RICHFIELD CO. ..... NGt -12 .................. ' ........ MAGNETIC SINGLE SHOT ............... RADIUS OF CURVATURE ....... SCALE I" = i000' ..... . .... . ..... ARE. TVD_ _ . ....... 2000 Eastman/ Whipstock A PETROLANE COM~ REPORT of SUB-SURFACE DIREC TIONA L SURVEY ATLANTIC RICHFIELD COMPANY COMPANY NGI 12, WELL NAME JOB NUMBER A1278 S0097 PRUDHOE BAY, ALASKA .... LOCATION ~ECEIVED TYPE OF SURVEY DATE SURVEY BY Jeremy Beattie OFFICE Alaska COf,~,PLFT ION REPORT DECLi,,!i:;i-:ii::~ 25, !97~.~ ATLANTIC RICHFiE, Li,) CO,~ N G I 12 tMAC:~NFT ! C !qtll T l FHOT SURVEY reAI~_]'U$ OF C[]R\/ATtJRE ?IF:THOD OF C(}f4PUTE..P, FOR EAST~qAN WHIPSTOCK DECLIi",}ATiOr,~ ..... ':~I, DiLG, EAST C()~'.4PUTATIOf,~iS K ff :'Lf:.':V. 4,':f f'T. , i3Y F. ivi. LIND,SLY AND ASSOCIATk;~, RECORD OF 5UP, VEY ALL CALC, UI,-ATION$ PEF~FORt4E, D BY I [~ ::4 ELECT(~Ot,!IC CO[,,tPUTE" TRUE , DOG LEG HEA5, DRIFT VERTICAL SUB _DEPTt,t ANGLE DEPTH SEA D H DRIFT TOTAl.. Ck:Ot,,~,,IK. AT:5 C L 0 D I RE~ L.)I STANCE DEG. ,5 U R ~,,S SEVERITY Ah,iGLE' DEG/]OOFT [)I.STANCt .... 0 0 0 0 145 0 15 144 236 0 0 235 32~{ 0 ]5, 327 420 0 0 419 511 0 15 510 ~03 0 45 602 695 0 30 .CO -fl4.00 SSR.O(,3E ,99 100,99 .99 ~91,99 S8~.()0[( · 99 28.3,99 ,99 : 375.99 5 i.OOE · 99 466,9c) S ~.ODE ~99 55~,,99,.,. Sll,00w · 98 65C,98 S 0 · 00 S 0 · '~ W .... ,¢0 0.00 S 0 0 0 ,',~' O.~GO O.OQ 0.16 $ 0.26 F. 0.31 5 ~7 59 ~9 E 0.172 0-31 0.23 S 0.~5 E 0,50 S 63 10 8 E 0.275 0.50 0,24 5 o . ,, ,. .~5 E. o.7~ S 69 17 24 E ,:) 27,~ 0.68 0.3,B S 0.77 E 0.58 S 0.78 E 0.97 S 53 28 31 E 0.275 0.97 1.37 5 .0.71 F' 1.-55 S 27 21 b4 E 0.543 1.34 2.36.5 0.53 E Z.42 S 12 50 4 E 0.272 1.73 78,..5 0 0 ,,, 87~ 0 15 877 970 0 45 o--,~o9 1051 1 0 1060.97 1157 ._. O 30 1152,96 1245 O 15 1244.96 · 98 74] · 9[! Ai7nv, OOE '2.57 S (-:.7c~. E 2.69 S 17 7 ,-'- ,_ =' 0.549 ,98 8373,98 ?':70.OOF 2.50 S '3.98 E. 2.69 S 21 23, i2 E 0,279 .96 925.98 S57.00E 2,59 S 1.75 E 5.13 S '34 0 57 E 0.544 1016.97 $51..00E 3.41 S ,':::.,37 E z'.--.~-6 S 40 '1 24 E 0.275 4-2,__0_ t-.~ . 11u,,,96 ,5,69 OOE 4.01 ~ '~.91 [! ~- _ · ~ .,.50 S 44 i'7 44 ~: 0.5~,3 ~..,..4~_ 1200.96 S54.00E 4.29 52 4.44 i:-: ,5.1~ S 45 56 31 i 0.272 . 6.05 ],29]..96 ,54. z?r.,:O0/ 4.63 ,b 4.''-~c;:,. [.: 6.77 S 40 12 3(! r,.; ().27~ 1383.94 ,'--:~,2.oog 5.12 S 6.17 [-] b;O~?: S 50 15 09 E O.b16 7,,~_ 1475.B9 S~3.0()E 5.1:'; S 9.17 L 10.49 S bO ~4 39 g 1.359 lO.Z;'/_ 1336 0 30 1335.96 1~2~ ~ 15 1~27~4 152.) 2 30 1519.89 1611 4 30 ]~10.72 15o6.72 ST3.OOE C.25 5 14.59 F'Z 1D.S8 S 06 48 10 E 2.19~ lP.66 1703 7 0 17'02.25 165p '- c. 7 ;'~ ....... ,_-,;-:.;, ,,, 3.,,,,at, ~.95, s ';z.4i ~-' ,. ~. z2.()6 S 69 4 ~9 g 1795 g ~0 ]793.29 1749.2~ S74.0C:[:: 12.69 S 36.0E, ~' 38.23 S 7U 36 10 F g..717 g4-5~__ 2.718 37.22 1U$6 11 45 1882.72 183~.72 S69.O()E~ 18.02 Fo 51.g7 L 55.01 S 70 52 3b H 2.4e, 3 53.q8 197,5 14 0 1972.40 1928.40 S61.GO2 2C,.t7 .q 7;:;.53 F_ 75.41 S 69 !6 5b E 2.498 73.7b 2070 1-1 0 2061.05 2017.L'5 S60.OUE , 3g,7E S 91.93 g 99.77 S 67 7 37 E 3.202 93-33 2151 18 45 2147.65 2103.65 S54.0[)E 53.9~ S 115.34 E 127.35 S 6~ 5~ 5 E 2.040 i26.2~ 0253 21 o 02=4.17 219(.~.17 S54,OGC 72.37 S I~+', ¢.,% E 15~ i7 S 62 46 i~: E 2.446 1.bY 47 · - ' -'~ - '~ ' ':-.' . ' . .r . . .... ~. ~- ?.'iAG,'.IET IC i,.:!lJl T ISF!C)T i.'~FC'E?~if2, F!~ 26: 1978 ALL CALCULATIONS P '"~: '~ E,"~ ~ 0 R M E D u Y I 8 M E L E C T R 0 :,! I C C 0 i',,! P 0 T ~ il TRUE DOG LEG MEAS, DRIFT VERTICAL SUB DRIFT TOTAL COORDINATES C L 0 S U R E S ~EVFRITY DEPTH ANGLE DEPTH SEA DIREC .. DISTANCE . A;'~GL E' DFG/]OOFT D M C, F G, 2 }/; S SEC T I ON £) ! S TANCJ: 2345 2B 15 2319.39 22'15.39 S54.00E 92.73 S 1(~R.67 2436 25 15 2402,35 2358,35 S57,00E 113,90 S iq'9.47 _ 2528 27 15 2484,86 24~0,86 S5?,UOE ]36,06 S 233,60 [:. 270.33 S 59 46 51 E 2.174 2620 2H 45 2566,09 2522,09 S61,OOE 158,30 S 270,61 E ~3,51 S 59 40., 2q ~, 1,916 2711 28 15 2646,06 2602,06 S67.00E 177,32 S 309,62 E 356,80 S 60 it 56 E 1.576 2750 28 0 26~0.46 2636,46 S68,00~] 184,B6 S 326.50 F: 372.,.U5 S ~0 3B 21 E 2an oo 27 S66~00E 203.54 S 371.'1a c 423.~6 S 61 1~ ~ E 0.477 ..... ~5g7 45 2773,27 g7~.,, 2949 29 15 2855,oa 2811,88 863.(.0~ a22,85 S 412,<7 .............. ~ .... , .......... 708 3042 30 15 2936.62 2892,62 S64,O(.)E 2a3.gq. S 453.57 g 5i4.77 S 61 46 55 ~ 1.109 31~5 31 30 3016.~.~ 2972,44 $O0,OOg 265.84 S 495,70 E 562.4d S 61 41 322~ 32 0 3095.52 3051,52 S61~00E . 289.94 S 538.29 E 61i,4i S __~321 32 0 3174t39. 3%30,39 S60.O(~E 314,20 S 5b~l.l[i 6 660.68 SOi 30 i0 E 0,570 3415 32 15 3254,00 3210,00 S62.00E 338.44 S '624.90 E 710.a6 S °l 33 37 E 0.062 192,06 2529-41 2?o. 313._26 '355.37 374,..47 422 · &9. 407,~e, 5i3,25 (~o9.67 708.70 350~ 32 $5 3332,65 ~258,65., S62,00E 361.73 S o6~,7Z~ E 760,29 S 61 35 £0 E 0.00() '756,23 ' 000 . . . . . . ~ , ' 3~ 0 3410,57 3366 57 S61 OOE 385 O.:! S 711 71 3692 ~3 0 3488,10 3444.10 .562.002 406.66 S 759.i5 E 3786 33 0 3566,99 ~.u522,99 S62.0'.)2. 4;~2.7i.).. S ~{U(),35 E 909,8~ S 61 36 9 2 0.000 907,35 3880 32 45 3645,94 3601,94' S62.O0E 456.65 S !~4.5.40 6 960,;d6 S 3975 33 15 3725.61 3681.61 S62,OOE ' 480,94 S 89i.0~ E- 131a.59 S 6i 38 34 E 0.526 1009,7~ 4069 3q 15 3804.22 ;760.22 S5~ OOE 5'~ ~ ..... ' " ,~5.14 a .,:,o.5c: .... ,_. , ~ 106q.13 S 61 >5' 36 E 0.000 10o1.15 4161 ')3 15 3681.16 3837.16 S62.06E 528.b2 S ~Ji..i3 E 1114.58 S 61 40 32 4252 33 45 '3957,(55 3913,05 S62.00E 552.40 S 1025.46 F/ ii64,[i0 Sol 41 22 E 0.549 11~1,49 4345 34 0 4034.26 3990.26 S6i.COE 577.14 S 1071.o3 C i210.64 S 6i ~43S }q 15 4111.25 4(~67,25 SOg.OOi 60~q3 S lil6.~J{: "' $2(..Fi SCi ~o 20 i 0.434 i265,21. 4532 ~4 45 4188.71 4144.71 SO].0OE 627.43 5 1i63.67 i i322.05 5 O1 43 i E 0.634 1318,33 4624 34 45 4264.30 4220,30 S60.00F 653,20 S 12~,%,'Jl E i'~.74,48 S ~1 37 Zl E 0.020 1~70.69 4717 34 30 4340.:':,3 4296,83 Se, i.OOF. 579.Jg 5 1255.31 ti 1:+Z¥.31 $ 6~, 34 01.6 0.437 4;507 35 0 4414.78 437{.).78 S61.OOE 704.i5 S lbc,:.:}.17 L i478.61 S O1 33 3U E 0.556 aD01 3q 45 4491.9U 4447,90 S60:Og'k] 730,61 S 1346,9~. i 1532,b~ S 61 ~1 25 i 0.430 ?<!AGf, tE 1' I C t;tUL T I SH()]' TRUE ,DOG L,E g MEAS, [;'RIFT DEPTH ANGLE D M VERTICAL SUB DRIFT. TOTAL CO. U.~,PDI"A:.,,~ Ti:~b DEPTH SEA D~RE(: C L 0 S U R E 5 D ! ST^, ,.., ,~,, r F: ,,., ,_ ANGLE SEVER [ TY SECT DEG/iOOFT OISTANC 5178 33 4,5 5271 5366 5459 5553 5645 5737 5830 5924 601.7 6110 8202 5295 6390 64~4 8578 667] 6765 6858 6950 7043 . 7117 72~I 7325 741~ 7511 4568,43 4524.43 S59.OOE 757 ~644.47 4600,47 S61,OOE 783 4720,86 4676,86 S6].OL)L 80~ 3 45 4798,18 4754,18 S60.Q()~ 833.62 3 0 487.7,52 4833.52 559.00~2 860,15 3 45 4955.18 4911,18 559,0QE 886,50 2 15 5034.01 4990.01 &59.0()E 912.87 2 15 5111,32 5067,82 558,OQE 938,52 2 15 5],89.63 5145,63 S58,00E 964°53 2 30 5268,17 5224,17 558.00E 990.92 2 45 5347,34 5303,34 ~57.0Q~ !018.15 ? 30 5425,66 5381,66 S57,OOE 1045,46 3 0 5503.38 5459,88 S57~00E i072.b6 ~ 0 5581,04 5537,04 S56.OOE 1100.51 3 0 5659.0~ 5615,03 556.00E .1128,84 3 30 5738,48 5694~48 S5O.OOE 1157.96 3 15 5~16.98 5772,9~ 656,00i 1186,25 ~ 15 5~95,59 5~51.59. S55.00[ 121o,07 2 45 5973,59 5929,59 5~5~Q0% t245.13 2 45 6052,64 6008,64 555~OOE 1~74,29 3 0 6130,75 6086.75 S55.,00E 1303 ~ 45 6208.02 o164~02 ~',5.00F2 1331 2 30 6256,34 0242,34 $59.00E ~360 2 15 6365.73 0~21,73 555,0r3~ 13~9 1 45 6445.45 6401.45 555.00: i418 1 30 6525,49 64~1,49 S55~Q(.)E 1446,36 1 15 6604,53 656:3,89 $55,00E 1474,13 1 O ~.654.50 664C.50 S55.00E 1501.71 .43 S 1392.48 · 32 S ]437.52 ,18 S 14'~ 2 . ]. 7 1527,14 1572,17 1616.02 1659.90 1701.76 ] 743. qO 1785,63 1 ~ 7'3 · 42 19!2.61 19~6.39 :,,fi7 ~OS~ ,44 ~124,91 · 25 S 2247.41 · 89 S g2:50.52 · 09 $ 2'4i~.43 E E E E E' E E 1585.16 S 61 27 22 E 10~5.92 S 61 24 i6 E 168~'~.19 S 6i 23 51. E 17~.9,b5 S 61 22 15 · 1792._09 $ 61 i8 59 E i843.21 S 81 15 7 E 1894,36 S 61 11 2b E . 1943,40 1992,42 S 61 2 47 g042,i5 2092.74 S 60 53 17 E 2 ! ~ 2.77 219~,97 ~24.~.94 S 60 gZ93,43 S 60 >345.36 Z599.68 5 59 54 ~7 b Z6,:).~4 S 59 49 i~ - 2°94.40 $ 59 43 b2 E d7f15.~7 S 59 3b 40 E 275'9.22 S 59 33 43 d 'll;C 24n5,4~.. ~ 25'~c.53 S 59 24 30 ,_~ S 253.-~,~'~4 i-i d944.56 S 59 20 il bf.. 0.437 1581 · 13. O. 870 1632.85 0.272 ...... 16H4.02 0,597 1735,6~ 0.849 17~7 0,806 1.596 1~~ 0,000 1988, 0 · 269 203 ~ 0.409 ~088.., O, 538 2 i89.2~ O. 592 g2~'9,3Z 0.Z65 23'Jb.7~ 0 · 000 ~ ;46 0,269 o · ~ 7~ 2047 0.2~ 2~97~ 0.5~2 2797 · 0,2~ g694,7~ 0.z69 2942.~2 760.°_ .._ ) I~'-lr' 45 8762" 61 6718'61. S56'00E 1528'1& S 2571,33l. g .--'>':;91' i5.' S >':~.. 16 36 E 0.3a7.. 29C~"" ' RAGNETIC t,4~l 1'I-__,.: ,T, EY R'%C'ji:~D OF ~Ui<VF"Y ALL CALCULATIONS PERFOi:;ahIED fSY I E~ '.',~ ELECTRONIC /'4 EAS. DRIFT DEPTH ANGLE D M TRUE VERTICAL SUt3 DR,,I FT TOTAL DEPTH SEA DIREC DFG~ D I STANCE D 0 G L !! G ..R F V F' R f T Y DF G / ! O0 F T 7788 29 !5 fl923.68 6879.68 555.00E 1580.49 S 764b,20 E 7882 28 45 7005.90 6961.90 SS~.0UE 1606.,~6 S 2685.30 F' 7975 28 0 7087,72 7043,72 354,00E 1&32,93 S 2'721,06 F 8069 27 15 7171,01 7127,01 354~00E 1658,55 3' 2756.32 E 8152 2~ 45 7253,97 7209,87 £fiS,00g 1683,07 S 2790,69 E []254 26 0 7336,29 7292,29 353o00b _!70,7°09 S 282~,7D i ~348 ~5 30 7490,96 7376.96 ,%DS.00E 17B1,~7 3 2856.37 i ~441 2~5 0 7505,07 746~,07 ~,OOE 17~5.~2 3 85~4 24 0 758~,70 7~4fi.70 o · ' ~. '~200E 1779,50 3 291~.93 8627 2~ 15 7674.90 7630,90 $52,00E 1802,51 $ 2947.60 3¢)~8.10 3 59 ~3 35 E 0-806 3175.4~ S 59 I 53 tl .... f),~36 3216.85 3 58 57 48,,E O.793 ,b25~,94 S 56 54 20 E . 0.590 3299,06 $ 58 50 42 ~ 0,916 ~340.Z9 S 58 46 25 E 0.532 3036:51- 3!27.97 3 ! 72,09 ~2!5.A0 5267.77 3298,57 5417,21 ,.,:=664 23 0 7708.93 7564.93 S51,00E 8730 23 0 7769.68 7725.68 SSI.OOE ~933 2.2 30 7956,59 7912.89 S48,00E 1811,55 S 295&.97 E 3469.4.7 S 5°6 31 26 E 0.792 1827.78 3 2970.01 E 3495.04 S 58 '28 7 E V.OOO 18':7'8.'16 3 3039.'10 E 35'/2.60 ,b 58 16 20 E 0.328 34~S..77 3494 · 40 3572.15 9024 22 45 ~040.89 7996.89 $.47,00E 1902.41 -5 3004.5i E 30(3,0.99 $ 5¢ ..... 10 o E 0.320 ~090.95 E ,0642.47 S 58 3 29 i 0,269 9117 23 0 8126.57 8082,57 S47.00E 1927.06 S ,~ '" ,, 9211 ,~.3 45 8212.86 8165.86 346.00% 1952.7':+ S 3116:.00 if 3679.2:1 S 57 bO 3! E 0:016 9305 24 15 ~2~9B.73 8254.73 S46.00E~ 1979.30 S 3145.50 E 3116,42 S 57 49 1.% g~' 0,532 9399 24 15 8384,44 6340.44 346.Coi 200o.ll S 3175.27 g :5'794.22 S 57 41 57 g 0.000 .... 3u05,64, 304 }P~O_ 3o7t.,53 3716.31 9492 25 0 B468.9.8 &424,.95 S46.00~' 2033,03 3 32()1.15 E .~792.18 $ 57 34 ~0 L 0.606 379Z~1~ 9596. :: 2~ 15 8554.08 8510.0~. ._,~47.0UE 2066,5~ c ....... ~, , ,, 325a.lc) ~ z,~l.3~ s ~7 27 ~? 6 0.529 °617 25 0 3532.15 b538.15 348.00L 2069.40 S 32~~: "-0 - . ..... .c~ ff ~044.31 3 57 25 ;4 E 0 991 3ob1,~4 ~44.31 T~9683 25 0 ~541.a7 ~597.~7 S4g. OOF 20"h.06 S 3260.53 E :' ......... ~,,,71.83 S 57 21 ;1E 0.000 [5OTTO!,! HOLE CLOSURE 3~.!71.83 F'FET AT S 57 21 5i E a o. F F'i N ~q I,..-.. 12 MEASURED DEPTH AND OTHER DATA. Fg, i:,:, i.iVLRY EVEN l"",O,.., FEET OF 5U,~.~, &t:-,, F)LmTH._.. TRUE ~,.- r.~ T ! CA, L, ¢,.!EA,S(,,,4EI) VERTICAL FtJP, ND-TVD DEPTH DEPTH S~. DIF_E.ERt::NE~!] . EOi:;;:REETI©i"-~ TCTAt E()ORi)!:',,tATES 100, 0 f). i & 200 0 :)-,_23 300 , 0 ...... ("i,. ? ,':: 400 0 , c!.39 500 0 _, __ 0.77 S 600 0 i. 86 ~,3 700 0 2. ~ 3 S ~00 0 -; 900 () 2.49 S 1000 0 3,23 11oo , 0 0 3.~)6 5 . 1200 , , ,~ ................ 0 ............. ~.2,9 S 4.43 1400 0 0 ~.08 5 6.54 1500 0 O 5.2'? 5 ~0.~] ~600 0 0 7,08 ~ 17~ ~700 1 , ~ 10.5~ 5 28.71 1800 ,,, Z ~ 15,,(~ 5 , ~.71 1900 4 . g 23,49 -20QO 8 4 36,20 2100 13 ~ ~3,2~ , ~ ~. ~.u~, 19 6 74.6G 5 143.7~ 0.45 E O- 7 ! F 0.76 iZ 3.77 E 0,6.2 E' ,,, 0.65 E ()~fi6 E 5 2.64 E' 144 , 144, 244 244, %q,4, , 344, ~44 , 444, G4~ 544, 644 , (¢ 414...,..l 744 V44: 844 .... 844, ' 44 9,,44. 1044~ I 1044, 1144 1144, 1244 1244, 1B44 1344, 1444 %444, 15Z+4 1544, 1_~44 1644 · 1745 ] 744. 1847 1844, 1949 1944, 2052 2044 ..1 2157 2144, 2,2,.54 2244. . 2372 2344, ~300 27 8 9.J.97 ¢ .~ 17'7.40 ~482 ~.444, g400 38 11 %94,7¢ 5 216,23 2595 2544, 2500 50 12 152.37 3 260,16 2709 2644, 2600 65 15 176.39 5 30S.60 2e22 2..7q4, 2-[Q9 78 13 1')7,b4 ~ l ~.J 57 i. ~? ¢.; ~ 2935 2844, 2800 91 13 21:~,79 o 4Ob.lb i 3(.)50 2944, 2900 %96 15 24~,22 S 457,i9 E 3167 3044, 3000 123 17 27'+.17 S ~I0,24 ¢ 3285 3144. 3100 14! 15 3(:.~+.72 S 504,63 E 3403 3244. 3200 159 18 'J35.42 $ 619,25 E 3521 .33~1.4. 3300 177 18 ~i:5.,')0 < 67~ i]:,~ t~ 3639 3444.. 3400 195 18 395.09 S 729.93 El 3758 3544. 35C)0 214 19 425.54 S 786.89 E !-12 i'.'~AGNETIC t,.'~ttLTl~.h!C,l' SUP,\/.~-Y DFCF'MRFR 2a;197E~ MEASURED DEPTH AND OTHER DATA FQR EVLRY EVEN i00 FELT OF SUt~ SEA .PCP.TH, TRUE ;'..tFA_%tJ,r.~F'F~ VERTICAL SUB MD-TVD VERT I CAL DEPTH DEPTH SEA P[FFERENCE CORRECT ~ Ot, i T,CTAL C©ORD INATES 3R78 3644, 3600 234 3~P97 . 3744, 3700 223 4] ] 6 '~ 8 g4.,.. BRQO 272 4236 3944, ~900 292 4357 4044, 4000 ~47R 4144, 4100. 333 ~599 4244, 4200 355 472] 4344, 4300 376 4~43 4444, ~40.O ....... 39.9 49~4 4544, 4500 420 5085 4644e 4600 441 .. 5206 4744, 47C0 462 5~26 4844, 4800 482 5~45 4944. 490Q 501 5R65 504.4, 5000 521 ._. 5683 5144, 5100 539 5.B0] 5244, 5200_ 60~9 5444. 5400 594 l 19 19 20 20 21 23 21 2!.. 2~ 19 517.24 S 959.~5 548.23 S 1017,64 ~: ~0.32 S 1076.79 6i2.61 S 1136.61 646.16 $ 1196~96 6°0.33,_., S 1257.21 74b,71 ~ 1377,88 , ~i5,71 S 1495,67 b?;2.50 S 1609,37 ~.0 19 <';'~,6;~,F S 160,5;30 E 947.26 S 171~,96 if 1015,97 3 1(~26.55 ](;51.83 S la20,23 E 6;15a 5544, 5500 614 0277 5644, 5600 633 6397 5744, 5700 i 653 6516 5!~44, 5800 672 063.6 57~4, 5900 6~.~2 6755 604q~ 6000 71] o674 6144~ 6100 730 6993 6244, 5200 749 711] 634~, ~)00 767 7229 6444, 64C0 7~5 7347 6544. 65C0 203 19 l'..'~..;: 7,~5 $ t934,40 E ti2~.36 S 198f.,26 E 2O 19 1.~ i9 127i.10 S 2203.50 i'3'::.:, i 8 S 2256.45 14i7,49 S 2412.50 E 18 145i.56 3 24~3.0~ U 7464 6644. 6600 (~20 7580 6744, ,6700 836 ~696 6844, 6~OO 7311 6944. 6900 8{.,7 ~7 14::7,71 S 2512.83 : ]6 152i.34 S 2562,01 E 1~ 15:;~.95 S 2657,37 E 7.:~.5 7044.. 700:) 681 t4 i::::::.04 o ;:7:~1.1~4 : ARCr~ N1EA$1JRE[,'I, DEPT~-~ AND OTHER DATA FQt':.: E. VLi<Y EVEN lO0 FEET OF &UP J:; i..:i /:,, L;EPTH. TRUE _ ~",IEAAtJR~.:;F) VERTICAL ~LJM ND-TV.r;, VFRT!CAI DEPTH DEPTH SEA D IFFERLFiCE CORRECT 107,~ T c, T A 1 ......' .... Lt.,,,,)R, ,, INATL 5, 8039 7144, 7100 895 8151 7244, 7200 .907 ~26~ . 7344.. 7309 919,,, , 8,BTB , '74~+4, 7400 929 8484 7544, 7500 940 , 859~ 70~'4, 7600 949 , , ,, ~ n.¢ %. , , 870g 7744, -1700 958 8811 7844, 7800 967 8919 7944, 7900 , 9,7,5 ........ 9027 8044, 8000 983 9%36 8144, 8100 991 14 12 10 I1 9 1650.33 S 2745.00 17S%.15 S 2~64,9~ 1766.~'3 S 290i.99 t794.20 S 2930,96 1 ~4'7,79 S 1903,20 S 3065,~6. ].932,14 S 3096,37 20 9245 , ~ ~ ...... ~ _ 9355 9464 844~, 8400 1020 9 2C24.85 S 5192,67 9575 854.4, 8500 1030 10 A~CC) NGI~'I? F'~AGNETIC ,v:ULTISHOT SURVEY,, tV~TERPOLATE[) VALUES FOR EV~j 1000 ,,FbET QE ?,"iE&,~;UF-'..ED DEPTi4 .......... TRUE NEASURED VEP. T [ ~AI,. ,SU13, DEPTH DEPTH SEA TOTAL COORD I f,!ATE lOOO 2000 199~. .... 7~ 3OO0 ...... 4.000 . ~7~6, 37.02, 5000 ~P73. 6000 5411. 5367. 2.82 S , ,~,,09 ,, 29.33 S 75,60 23~, 15 ,~, 43,~,,,,,77 759.1~ S ~, 1395.40 7 0~,,0 . 6250. 6206. 800'...9 7109,. 70.65. 90C)0 8018.. 797z~, , 13a7.38 S / 2312.~4 E ~' ~639,~1 SV' 2730~5~ E ~' 1896.10 $ ~"3057,72 g ~ ....................................................... ATLANTIC RICHFIELD COMPANY ......................... ' .................... . ............. NG I 12 - ~ ............" ' SCALE I"= gOO' ....... · RADIUS OF OURVATURE'~ ...... . '-7 ". ............... . ......... ........................... : - '-:'~-}--~-~" '-- ~'}-",-~-,~ ..... ~- -.---~:-~'?-- ~----.' :-'- ...... '-- MAGNETIC MULTI- SHOT .............................................................. : ................................................. : ..................... ; ..... ....................................... . ................. _ ...................... .............................. - .... ~ ............................ . ................... ................................................... ......... , 2800 ............... 3200 ............. 5200 5600 ...... 6000 . 6400 6800 _ ............ - ................................ AT.LANTIC RICHFIELD COMPANY ....... ............................. ' ................... NGI t2 ........... ~ . 4oo SCALE I"= I000 ......... .................................................... MAGNETIC MULTI- SHOT ............... 800 ....................................... ......... ~ ............................. . .............................. 1200 ............................................. -: .................................... _ . l',lo~'th Alask~ Dis[rict Post Office ~ -" 3,S0 Anchorage .... ~ska °.0,3510 Telephone 907 277 5637 January 24, 1979 Reference: Enclosed are the following logs' PS .5-11 . O~/N ~/~2/7S ~~ Spinner 6/6/78 CCL 12/27/78 Please sign and return 'the Copy as receipt of data. SSncerely, V.G. Reimers North Engineering TRANSMITTAL #043 DISTRIBUTION North Geology Drilling Eng. Manager R&D Geology State of Alaska 'D & M Exxon Sohio Mob:il Marathon Phillips Chevron Getty North Alaska District Post Offi=e Anchorage, A, 4ka 99510 Telephone 907 277 5637 January 8, 1979 RECEIVED Reference: Enclosed are the following Directional Surveys:  12 / 15/78 Mult isho t 12/5/78 Multishot ~S 7-7 12/10/78 Multishot ~DS 7-6. . 11/15/78 Multishot __E~_~_ , ¢~ Please sign and return the coPy as receipt of data.'~~. ~~ . Sincerely, V.G. Reimers North Engineering TRANSMITTAL #016 DISTRIBUTION North Geology Exxon Drilling Soh:i.o Eng. Manager Mob:i 1 R & D Marathon Geology Phill.~ps State of Alaska Chevron D & M Getty AtlanticRichlieldCompany North American Producing Division North Alas~istrict Post Office. ,x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 3, 1979 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 13-2, Permit No. 78-61 DS 7-8, Permit No. 78-16  Permit No. 78-53 Permit No 77-81 Dear Sir: Enclosed ~lease find a Monthly Report of Drilling Operations for the above-mentioned wells. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'mln Enclosures Form No. 10404 REV. 3-1-70 SUBMIT 1N DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-029-20284 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. 1F INDIAN.ALOTTEE OR TRIBE NAME 1. OIL [--] GAS ~-] Gas Injection WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME ATLANTIC RICHFIELD COMPANY Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. Box 360, Anchorage, AK 99510 NGI #12 4. LOCATION OF WELL 372'N & 865'E of SW cr Sec 1TllN, R14E, UM 10. FIELD AND POOL, OR WILI~AT Prudhoe Bay Field-Prudhoe Oil Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec l, Tl lN, R14E, UM 12. PERMIT NO. 77 -81 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Report of Operations for the Month of December 1978. Spudded @ 1700 hrs. 12-2-78. Drld 17-1/2" hole to 2800'. RU & ran 13-3/8" csg w/shoe @ 2781'. Cmtd w/4300 sx Permafrost cmt. Drld shoe & 10' new form. Did leak off tst. Drld 12-1/4" hole to 8730'. RU & ran 9-5/8" csg w/shoe @ 8716'. Cmtd w/800 sx Class G cmt. Sqz 300 sx Permafrost "C" cmt thru lOwer FO. Did Arctic Pack job thru upper FO. Drld shoe & tstd to 12.5 EMW. Drld 8-1/2" hole to 9683'. Ran DIL/BHC/GR, BHCS/GR, FDC/CNL/GR logs. Drld to 9693'. RU & ran 7" lnr w/shoe @ 9692', top @ 8391'. Cmtd lnr w/425 sx Class G cmt. Tstd lnr to 3000 psi, OK. Ran WSO tst. Displ mud w/CaC12. Ran GR/CNL/CCL logs. Ran gauge ring & junk bskt. Ran 7" compl assy set @ 8271'. Tstd balance & control lines. Pulled dummy valve. Ran CCL/dummy gun. Ran SSSV. NU & tstd tree. Pulled SSSV. Displ tbg w/diesel. Reran SSSV. As of Dec. 31, RU for long term tbg tst. 14. I hereby~,t~, ~]e fj~..regoing~ true and correct / / $IGNED~TITEED] stri ct Dri 11 i n~oA~ NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. /~. tlantici~ichfiela ~.o:'n~ a ny No. ~n A~as~,~',fstrict Post Office ~_ Anchorage, ~l~skz 99510 Y~lephone 907 277 5337 December 29, 1978 Anchorage, Alaska 99501 Subject: Permit Permit Mr. Hoyle Ha,;ilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 ?orcupine Drive Dear Si r: Encl'osed please find a Sundry Notice outlining our plans for the above-mentioned wells. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'cs Enclosure Form 10-403 ' REV. 1-10~73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) V~L[-~WELLGAS [--'] OTHER Gas Injection 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 372'N & 865'E of SW cr Sec. O1, TllN, R14E, UM (@ 8300'ss) 1320'S & 1320'W of NE cr Sec. 12, TllN R14E UM 13. ELEVATION5 (Show whether DF, RT, GR, etc.) 51'RKB, 18' Pad Elevation (Gravel) 14. 5. APl NUMERICAL CODE 50-029-20284 6. LEASE DESIGNATION ANO SERIAL NO. APL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. NGI 12 10. FIELD AND POOL, OR WILDCAT Prudh0e Bay Field-Prudh0e 0il P001 '11. SEC.,T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 12, TllN, R14E 12. PERMIT NO. 77-81 Check Appropriate Box To Indicate Nature of Notice, Re )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE AE~ANDON* CHANGE PLANS SUBSEC~UENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE,' Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent ¢letells, and give pertinent dates, including estimated date of starting'any proposed work. The drilling permit specified a 7" 29# N-80 LT&C tubing string would be used to complete this well. It is proposed that 7" 29# N-80 LT&'C tubing continue to be used below the safety valve nipple at +2200~, and that 7" 26# L-80 IJ4S tubing be used above the safety valve nipple. Verbal approval was received from R. A. Douglass on December 21, 1978. ' · 16. I hereby certify that the foregoing is true and correct (This Space for State office use) APPROVED BY. CONDITIONS OF APPROVAL, IF ANY.' T IT LE DATE See Instructions On Reverse Side ALA~ OIL AND ¢~S ~S~R~VATION O~.~SSI~ 3001 Porcupine Drive Anchorage, Alas}~ 99501 Hoyle H. Hamil~~ Director Chief Petroleum En~ Ben Lelgorman l:~troleum Deoembe_r 15, 1978 B.O.P.E. Tests on Arco' s NGI-12 ~ursday,_ De~_7_- I departed my ~ at 5:30 ~4 for a 6:00 AM s'~ and s~heduled 7:00 AM d~ via Wien Flt. ~23 for ~se, howev~_r deicJ~ng of the %~ing and tail surfaces of the aircraft delas~=d our departure until 7:30 ~4 and we arrived in Deadhorse via Fairbanks at 9:50 AM. I p~ to NGI-12 pad and introduced Bobby Foster to Arco Drilling Foreman Kelly Goff and ~c~an Rig #35 Toolpusher, D.C. ~lrp~, P~g crews were nippling up the stack. ~ather: +2 degrees Fahrenheit, 2000' Broken, Fog, Wind 10 mph frcm the north. R%sts began at 6:20 PM with the shoe on the 13 3/8" at 2780'. The annular preventer te~ to 3000 psig. The test hose froze and while thawing took place, I toured the location which ~s ~11 organized, rig was in good repair. ~serve pit well built, and the ~11 sign was up. Tests restmmd at 7:40 t~4 with the upper pipe rams, HCR valve in the. choke line, and d~ck valve in the kill line testing to 5000 psig. Then tbs inside -~alve on the choke line and both wing valves c~ the kill line tested to 5000 psig, and lower pipe r~ns and wing valves c~ the ~ spool tested to 5000 psig. Thirteen valves and twentyssix flanges in the choke manifold tested to 5000 psig. The s~aco superchoke was actoated fully ~ ~nd fully closed and tbs. manual adjustable choke was free movingo Before backing out of the test plug. to test ~ blind rams, we perforn~d the accumula~ test. Accumulator pressure ~as 2950 psig. With the aomzm/lator l~amps turned off, we closed one set of pipe rams, the annular preventer, and HCR valve s~taneously. Accunulator pressure dropped to 1200 psig and remained steady. We then turned the accumnlator pumps ~n and pressure built to 2950 psi9 in four minutes, ~rty secongs. N2 backup bottles tes~ at 2250, 2300, 2300, 2300, 2150 and 2300 psig. Blind r~$, kelly cock, and lc~_r kelly valve then tested to 5000 psig and ~ dart and ball type floor valves %~_re. in place before the drawworks. Tests were c~ncl~ at 10:30 PM and a field inspection report was prepared witt~ a copy given to Kelly C~ff, a copy mailed, to Bob tlin~s ar~cl the original attauhed to this report. December 8 S go~V' s tested on w~lls 1.tRQ, 1½f6, and. 1-17, the S~a~ar~ day, ~cember__9- S~7's tested c~ wells 6-2 and 6-3, ~e subject of ,- Tes*.~d low pilot and S~q~V cm 1-1, low pilots ~n SSSV' s and lc~ pilots ~n 4-12 and 4-13, and SSV's and SSSV's om 6-7v ~ject of a separate re~.  .- Annulas pres~ check, ed and SSV's and SSSV's v 66~, ar~ 6~8, the subject of a _separate ateB.B.~.M.E. ~ oc~pleted cm Aroo' s DS 13~2, y~_~~.~3 ~.O.p.E. Tests ocmpleted c~ Az~o's D~ 14-4, ec~ of 'a ~~ repo~.  o~~I departed ~ ~rf via Arco ~ a tl:O0 at 2:30 PM and at my ~ at 3:00 PM. m~m~Ff,~~ ~~~ B.O.P.E. t~ m ar~'s ~-12. I BL~ t~~ .. '. ' -" .~ ' .:i!~!~-'i'?''.' ..i '.' ' ' p ' p ' ' Drlg' .perm~t~ N.~i.~_~ ........ -, ......· .... r--- Well/P~m~F:n Sec ! T/._/~_R/~-,_~]_M 6'p~t,~ ~~ ~"~ ~prese~ted by ~/~ ~~a~ & <~ < } ~. ~eneral ?vs~k~epin~ , ...... ~_ ~ } ~. ~frl~,~-kC~lkS~'~~~}~ '-' ' · · . .y · . . s ,, ( ) ( ) 5. Surface-No. Wells (~() 20. Drilling s~o~lz~o~tlets ( ) ( ) 6. Subsurface-No. We]~ (~ ( ) 21. Kill Line-~bnecK valve ( ) Well Test Data. (~ ( ) 22. Choke.Flowline (~CR valve ( ) ( ) 7. Well No s.~, . , ( ) ( ) 8. Hrs. obser__,__, ( ) ( ) 9. BS&W ~,_ , ( ) ( ) 10. Gr. Bbls. , , ( ) Fina~--~-.~andonment (~/~ ( ) 23. Choke Manifold No. val.v$/~ fl~s~ (~ ( ) 24 Chokes-(~/~emote( )Pos.(~:;~dj ..... (,~/'" ( ) 25. Test Pluo-(,-~Wellhd( )csg( )none (~r' ( ) 26. Annular Preventer~m~_e~osip (~() 27. Blind Rams ( ) ( ) 11. P&A Marker (~7' ( ) 28. Pipe Rams,.~psiq {~-~) ( ) ( ) 1Z. Water well-( )capped( )plugged (~ ( ) 29 Kelly & Ke~ly-cock~psig ( ) ( ) 13. Clean-up (~ ( ) 30. Lower Kelly valve,,~~si~ ( ) ( ) 14. Pad leveled (~ ( ) 31 Safety Floor valves-(~,~BV (~/Dart Total inspection observation time ~ hrs/~l,~es Total number leaks and/or equiP, failures 0 Remarks cc:..~,~,~; .~_~',~s- Notify in days or when ready Inspected by ~ ~ ~_.___Date/~-~~_ AflanficRichfieldCompany North American Producing Division Alaska Re~~ ~ Post Office =,ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 October 31, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject: NGI #12 Permit No. 77-81 Dear Si r- Enclosed please find a Sundry Notice outlining our plans for the above-mentioned wel 1. Very truly yours, P. A. VanDusen District Drilling Engineer PAV:jh Enclosure Form 10-403 REV j1-10-73 Submit "Intentions" In Triplicate & "SubseQuent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drlll or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) OIL !--I ~As i--i WELL! I WELL L-J OTHER Gas Injection NAME OF OPERATOR · Atlantic Richfield Company 3~ ADDRESS OF OPERATOR 'P. 0 Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 372'N & 865'E of SW cr Sec. 01, TllN, R14E, UM (@ 8300'ss) 1320'S & 1320'W of NE cr Sec. 12, T11N R14E UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 51'RKB, 18' Pad Elevation (Gravel) 14. Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: 5. APl NUMERICAL CODE 50-029-20284 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit :9. WELL NO. NGI 12 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Fi el d-Prudhoe 0il P0ol 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 12, T11N, R14E 12. PERMIT NO. 77 -81 3orr, or Other Data SUBSEQUENT REPORT OF-' TEsT WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MU LTI PLE cOMPLETE ABANDON* CHANGE PLANS WATER SHUT-OFF REPAIRING WELL ALTERING CASING ABANDONMENT* FRACTURE TREATMENT SHOOTING OR ACIDIZING {Other) (NOTE= Report results of multiple completion on Well COml31etlon or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent ¢letalls, and give pertinent dates, Including estimated date of starting any proposed' work. Due to changes in the directional plan of this well, the proposed measured depths are revised. There is no change in ~b~e bottom hole location. The setting depth of the 13-3/8" casing will be 2776'+MD~'"{~he setting depth of the 9-5/8" casing will be 8575'+MD, and the setting depth of the 7" liner will be 9558'_+MD. 16. I hereby certify that the foregoing is true and correct TITLE District Drillipq Enoineer DATE-. 10/30/78 . (Thls space for State office use) APPROVEDBY ~. d. ~TITLE CONDITIONS OF APPROVAL, IF ANY~ Petroleum. Encineer See Instructions On Reverse Side DATE 11/8/78 AtlanticRLchfieldCompany , North Ameri~qan Producing Division -. Alaska Re(. Post Office ~ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 October 20, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject' NGI #12 Permit No. 77-81 Dear Si r' Enclosed please find a Sundry Notice outlining our plans for the above-mentioned wel 1. Very truly yours, P. A. VanDusen District Drilling Engineer PAV-jh Enclosure Form 1'0-403 ~ .- Submit "intentions" inTrlpllcate ,REV.'I-10-73 & "Subsequent Reports" in Duplicate STATE oF' ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) WELLI I OTHER Gas Injection ?_ NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At Surface 372'N & 865'E of SW cr Sec. 01, T11N, R14E, UM .- (@ 8300'Ss) 1320'S & 1320'W of NE cr Sec. 12 T11N R14E U~. 13, ELEVATIONS (Show whether DF, RT, GR, etc.) 51'RKB, i8' Pad ElevatiOn (Gravel) 14. 5. APl NUMERICAL CODE 50-029-20284 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. NGI 12 10, FIELD AND POOL, OR WILDCAT _Prudhoe Bav FiP_ld-Prudhoe Oil Pool 11. SEC., T., R.,~M., (BOTTOM HOle OBJECTIVE) Sec. 12, T11N, R14E 12. PERMIT NO. 77-81 Check Appropriate Box To Indicate Nature of Notice, Re )ort, or Other Data NOTICE OF INTENTION TO: T EST WAT E R SH UT-O F F [~ FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. Atlantic Richfield Company proposes to change the planned bottom hole location at 8300'ss from 1000'S & 1250'W of NE cr Sec° 01, T11N, R14E, UM to 1320'S & 1320'W of NE cr Sec. 12, T11N, R14E, UM. Setting depth of the 9-5/8" casing will be changed from 9531'+MD to 8970'+MD, and the setting depth of the 7" liner will be changed from 10,614'-+MD to 9986'_+HD. The 7" liner will be cemented its full length requiring _+200 sx. When perforated, the well will be backflowed to the flare pit for clean-up and burned in accordance with Department of Environmental Conservation Burn Permit. 16. I hereby certify that the foregoing is true and correct T,TLE District Drillin.q En.qineer.. DATE- See Instructions On Reverse Side · T,TLE Chief Petroleum Enginee~ATE Approved Copy ~anti, cRichfieldCompany North Ame;-:-;an Producing Division North Ala,. District Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 30~ 1977 Mr. Hoyle H.. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: NGI #11 (XX-02-11-14) Permit No. 77-80 NGZ #12 (XX-01-11-14) Permit No. 77-81 Dear Sir: Enclosed please find three (3) copies of a certified location plat for the subject wells. Sincerely, F. M. Brown District Drilling Engineer FMB/mln ? S E C TJ~ON $ - BUILT WELL NO. I LA T, 70°19'36.129'' LONG, 148o28'50016" Y 5 :~71 400.07 X ~-387 350.54 865 890 section .... .. 965' 989' · 1014 _ ~ SECTIONio39' 12 1064' 1089' o o LEGEND · EXISTING WELL OR CONDUCTOR PIPE NOTE: WELL NO.I TOP PAD ELEV..= 18.4. FT. ABOVE M L.LW . CERTIFICATE OF SURVEYOR I HEREBY~ER.TIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE [.AND SURVEYING IN THE STATE OF ALASKA AND THAT THISmRLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION, AND ALL DIMEN'S[ONS AND OTHER DETAILS ARE _CORRECT. DEC 18, 1977 ~-~*~/'//~ELL II +12 ADDED OCT 4, ~75 , E'.. :,!"~ ' · WEL_L NO. 2 LAT 70° 17'37.284" Y 5 971 516 90 LONG, 148°28'f;0.762'' X ~87 322 06 LA-[ 70° 19'38.441" Y 5 971 6,33 76 LONG. 148°28'51493'' X ~,87 :'94,09 WELL NO. 4 LAT 70° /9'39.596" Y 5 971 750.62 LONG 148° 28'52 223" X 687 266. I8 WELL t'~O. 5 LAT 70°19'40.749'' Y 5 971 ,967.11 LONG. 148°28'52 947'' X (;87 238.47 WELL NO. 6 LAT 70°;9'41 908" Y 5 ~971 ~84 28 LONG 1480,78'55.682'' X ~87 210.34 WELL N,. 7 L. AT 70° 19',43.052" F 5 '..)72 U99.94 LONG. 14~°2854.412 X 687 ,'82.47 WELL NO. 8 LAT. 70a,'9'44 2t0'' Y !; ~72 ?,'7.07 LONG. .'48'~;78'55./26" X 687 .35.06 WELL NO. 9 LAT. :0° I.-)' 45.370" 'r 5 -372! .*,754.31 LONG. ,48°28'55.850'' X WELL NO. II LAT. 70° 19'47,675" Y 5 972 567.37 LONG. /48°'28~57.319'' X 687 071.18 WELL NO. 12 t30" ¥ 5 972 684.11 LONG. 148028'58.044'' X 687 04~. 43 --: REVISION NO. - 1 ARCOf¢ AFE 292265 HVL #..,~0-,t~15-7..~" ATLANTIC RICHFIELD CO. AS -BUILT WEL~ I THUR 12 NORTH~A INJECTION SITE LOCATED IN PROTRACTED SECTIONS I &I21T, IIN~ RI4Ei,.,,U.M. _ PREPARED HEWITT V. LOUNSBURY I~ ASSOC. W 6TH.AVE., ANCHORAGE, ALASKA DATE OCr a, 1975 CHKD. BY__~.._.D. SCALE /": 300' LOOSE FIELD BK. LEAF December 22, 1977 ~ Bay Unit ~-12 (~x-0!-ii-14) Atlantic ~cbz~ield ~y Pena~t ~. 77-81 District Drilling Fr~lineer Atlantic Richfield C(x~y P. O. ~ 360 ~nc~~, ~/[askka 99510 ~nclos~] is ~ ~approved ~lication for ~t to drill the above referemm~ ~ at a location in Section 0i, Tcwnship llN, Range 14~..~., U.M. ~ sm~, ~ore chips ~ a r.~d log are not required. su~y is req~. A directi~ml 5~u~y ri,m=_rs ~n ~~ ~ ~ drainage ~rystsm~ b~ve been classified as i~~t for ~ spa~/ng or migration of anadrc~cus fish. .Operations in ~ areas are subject ~ AS 16.50.870 and the r~tions promulga~ ~hereunder (Title 5, Alaska Administrati~ Co~e). Prior to cc~e~cing operations ~ ma}, ~ cc~~~ by ~ne Habitat Coo~*~r's office, Depart~t of Fish ~u-%d C~. Pollut/mn of any w~ters ~ ~h~ State is prohibited by AS 46, Chap~ 03, -~aicie 7 ar~! ~ re~alations pzumulgated thereu~lar (Title 18, Ala~,a Administrati~ ~, C~r 70) ~ by the Federal ~at~r Pollution O~ntrol Act, as ~. ~ior to ~ing operations you may be cc~~ by a repres~n~tive of the De~t of Env~tal ~rvation. I%lrs~nt ~ ~ 38.40, ~ ~ L-~der State ~s, the Alaska Department of ~ is ~ir~3 notified of ~ is~ of tb/s permit to drill. F. M. Brown -2- P.B. U~zit NGI-I2 Dec~rber 22, 1977 In the ~t of suspe~micm or aban~t pleurae give this office a~]equa~ te advance no~icaticn so t~mt w~ may P~ve a wit~ess present. Very truly~ours, O. K. Gilbreth, Jr. Chaixm~n Alaska Oil ~nd Gas Ccmser~a~on Committee Enclosure Department of Fish a~ Gang, Habitat Section w/o e~cl. De~t of En~_ntal Conservation w/o encl. De~t of !~bor, Super, ~_~_bor Imw ~liance Division w/o encl. No~h Alask~ ~rict Post Office 8ox 360 Anchorage, A)~ska 995~0 December 14, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: NGI #12 (xx-01-11-14) Dear Sir: Enclosed herewith is our Application for Permit to Drill NGI #12 and $100.00 filing fee. The required survey plat will be sent as soon as it is available. Very truly yours, F. M. Brown District Drilling Engineer / am Enclosures Form 10-401 SUBMIT IN TRIi .ICATE RE¥. I-l-?l (Other instructions on STATE OF ALASKA reverse side) OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN MULTI PLE ZONE [--'] la. TYPE OF WORK .... DRILL [~ DEEPEN r"-] b. TYPE OF WELL OIL GAS WELL~ ,~, OTHER Gas In~ection SINGLE WELL r ,- ..... ZONE F-~ 2. NAME OF OPERATOR ATL/~TIC RICHFIELD COMt)g2qY 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, _&laska 99510 4. LOCATION OF WELL Atsufface 371'N & 865'E of SW er Sec. 01, TllN, R14E, UM . kPI No. 50-029-20284 6. LEASE DESIGNATION AND SERIALNO. ADL-28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. NGI-12 (IX-01-11-14) 10.~FIELD,~kND POQ.,L, OR Yruonoe ~ay ~l~d Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM At pro~d prod. zone I~ ZO I ~ O I ~ (@.8300'.SS) -t~'S & i-2-50'W of NE cc.. Sec~.~ TllN, R14E,UM 13. DISTANCE IN MILES AND DI~ION FROM NEA~ST TOWN OR ~ST OFFI~* Approximately 8 miles NE of Deadhorse 14. BOND INFORMATION: xvPEStatewide Surety and/or No. Federal Insurance Company #8011-38-40 15. DISTANCE FROM PROPOSED * [ 16.No. OF ACRES IN LEASE LOCATION TO NEAREST PROPERTY OR LEASE LINE. FT. 2560 (Also to nearest drig, unit, if any) 19. PROPOSED DEPTH 4~d~&' + TVD 18. 12. 1000' 2750' DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. ~o,nt. $100,000 17. NO,ACRES ASSIGNED TO TIllS WELL 160 20. ROTARY OR CABLE TOOLS Rotary · 21. ELEVATIONS (Show whether DF, RT, CR, etc.) , 22. APPROX. DATE WORK WILL START ~4~'. RKB, 18' Pad Elevation (Gravel) 2-7-78 23. PROPOSED CASING AND CEMENTING PROGRAM 'SIZE OF HOLE SIZE OF CASING %%I~IGHT PER FOOT GRADE ,SETTING DEPTtl Quantity of cement 32"' 20". 94 lb. H-40 101' + MD 300 sx Permafrost. II to Surface '~7-1/2" 132-3/8'' 72 lb. Mlq-80 2700' + MD Circ. to surface-approx. 5500 sx 12-1/4" 9-5/8" /,7 lb. 80&95 99-3-t'+- MD 700' ± cat column on 1st stage (a ' ~-q~o 700 si) plus 300' '+--column on 2n .... '" q ~/ sta~e (approx. 3~0 si) 8'1/2" 7" liner 29 lb. MN-80 ~q)6i-&' + MO i383-+ cmt column-approx.' 500 sx pprox, ~tla~chfield Company proposes to directionally drill this well to 10614' + MD, 8444.' _+. ~VD~to produce the Sadlerochit zone. Logs will be run across selected ~ntervals. A 13-578"$~00 psi Hydril and 13-5/8" 5000 psi pipe and blind rams will be used on the 13-3/8" casing. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 7" 29# N-80 LT&C tubing, packer, and necessary provisions for subsurface safety equipment will be run. The packer will be set above the Sadlerochit. A non-freezing liquid will be left in all uncemented annuli within the permafrost interval. Selected intervals within the Sadlerochit interval will be perforated,(cont.) IN ~O~ SPACE DESC~BE PROPOSED PROGRAM: If propoml is to deepen gNe ~ta on present productive zone and pressed new produ~ve zone. If pro~ ~ to drill or dee~n d~ection~y, ~ve pertinent data on sub~ce locations and measured and true verti~ dep~ Give blowout preventer pro~. / / (This space for State office use) CONDITIONS OF APPROVAL. IF ANY: OTHER REQUIREMENTS: SAMPLES AND CORE CHIPS REQUIRED MUD LOG [] YES [] NO [] YES [~ NO DIRECTIONAL SURVEY REQUIRED [~ YES [] NO A.P.I. NU.MERICAL CODE 50-029-20284 PERMIT NO. 77-81 _ APPROVAL DATE ~/~~' ·TITLE Chairman APPOVED BY . ~' ' *See Instruction On Reverse Side December 22, 1977 DATE December 22, 1977 :.~;, Lib~ FU~ ',~,', ',';LLL raF, i']~ib Is the permit fee attached . Yes No Remarks Is ;,,'ell to be located in a defined pool .......... Is a registered survey plat attached Is well loco~d proper distance from property line Is .,.,'ell located pFoper distance from other wells ......... ;>,~,: 6 Is sufticien,~ undedqcated acreage available in this pool 7. Is well to be deviated ....... 8. Is operator the only affected party ....... 9. Can permit be approved before ten-day wait ........ ii!' Does operator have a bond in force Is a cor, servation order needed '~ io ~:~, .~'i~is~ra,_~ve approval needed , ~3. Is conductor string provided . lJ. Is enoush cement used to circulate on conductor and surface . Will cement tie in surface and interF,~ediate or production strings 16. ',/ill cement cover all known productive horizons l?. !.!~lt surface casing protect fresh water zones . , 18. Will all casing give adequate safety in collapse, tension & burst 19. ~oes BOPE have sufficient pressure rating - Test to _~o___ psig 20. Has DT. EI',, approved Plan of Operation Additional .P. eaui foments' Revised 11/17/76 Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX.' No special'effort has been made to chronologically organize this category of information. !llll. 1 IllIII I I II II II I1 I I I 1 I I I1 Il lIIllI IIIIII ¥¥ ~Y Y¥ Y¥ YY Y¥ YY Y¥ ¥¥ 000000 000000 5555555555 000000 000000 5555555555 O0 O0 O0 O0 55 O0 O0 O0 O0 55 O0 0000 O0 0000 555555 O0 0000 O0 0000 555555 O0 O0 O0 O0 O0 O0 55 O0 O0 O0 O0 O0 O0 55 0000 O0 0000 O0 55 0000 O0 0000 O0 55 O0 O0 O0 O0 55 55 O0 O0 O0 O0 55 55 000000 000000 555555 000000 000000 555555 *START* USER PCCC [10706.54]15],,,,. dOB sH1e t4(.]NITOR SWS KI, IOB31 21 NOV 78 *SI,ART* FILE' DSKH.VE IFY- . -iR . .005<057>[~0706.54316] CREATED: PRINTED: 29 JAN-79' '18:48:48 - /SPACING: ~ 3298 DATE 29-JAN-79 29-OAN-79 18:23:06 18:42:u4 PACIFIC COAST COMPg!I'ISG CENTER 10706,54316 REEL HEADER LENGTH: 132 BYTES REEL NAME: P.C.D.C. SERVICE NAME: EDIT REEL CgNTINUATIUN NUMBER: O! PREVIOUS REEL NAME: COMMENTS: LIS FORMAT CllSTO~ER TAPE DATE: 79/ 1129 TAPE HEADER LENGTH: 132 BYTES TAPE NAME: 54316 SERVICE NAME: EDIT TAPE CgNTINUATION NUMBER: 01 PREVIOUS TAPE NA~E: COMMENTS: E 0 F * , * * , * * FILE HEADER LENGTH: 02 BYTES ' ' T FILE NA~E: EDI .00~ ~AXIMUM PBYSICAL [~ECgRD LENGTH: PREVIOUS FILE MA~E: FILE COMME~'rs USER W~RDS 4' 15 M~IN LOG CNL USER WORDS 16-20 REPEAT FIbE CML DATE: 791 1/29 1024 BYTES WELL SITE 'tNFORMATI[)N RECgRD LENGTH: 135 BYTES CO,PAN Y: W EI.,L: FIELD. COUNTY: STATE: ATI,,~Ak. TIC RICHFIELD NGI ~!2 B PR[iDHOE i AY Nf]RTH SLOPE AbASKA ~)ATA F(3Rt~;AT SPECIFIChTI{~N [,Ei~iGTf~i: ~50 [-i~.4TRY BI,,~CKS: TYPE 0 SIZE R T DA, TUN SPECIFICATION BLOCKS: ENTRY IC TOOL SV~I~D# I}NITS AP1 API AP1 AP1 FIL, E# SIZE EXP PROC SA~ ~EP {)EPT S~IFT DEPT GR C NPHI CNL, {qRAT CHh ~CNL, CNL FC~IL, GR NPHI CNL NRAT CNL NCNb CNL FC N I., CNL F T 0 0 0 0 0 4 O 0 I 68 0 0 (;APl 4~ 31 {2 0 0 4 0 0 1 65 o 0 PO 42 b8 3 0 0 4 0 0 I 68 0 0 C /C 4 2 412 I 0 0 4 0 0 I 6 8 0 0 CPS 42 34 92 0 0 4 0 0 I 68 ,0 0 CPS ~2 34 93 0 0 4 0 0 I 68 C~ 0 GAPI 42 31 32 0 0 4 0 0 I 68 0 0 P U 42 68 3 0 0 4 0 0 1 68 0 o C/C 42 42 1 0 0 4 0 0 1 68 0 0 CPS ~2 34 92 0 0 4 0 0 ! 68 0 0 CPS 42 34 93 0 0 4 0 0 1 b8 0 0 DEPTH 9680. 000 9600.000 9500.000 9400.00O 9300.000 920o. 000 9100.000 9000.000 8900. 000 8800.000 8700.000 8600. ()00 8500.000 8400.000 MN EtqUNIC ¥ AI,,i,IE !,4, N E~ON IC VALItE GR -999.000 NPH1 -999 000 FCNL -999. 000 aR 0 :()00 NCNb 0.00o FCNI, O. 000 GI~ 39. 900 NPHI O. 180 ~RAT FCNL 149.292 GR 37.900 NPHI NCNb 271..128 f'CNL 141,141 GR 22.900 NPHI (7) .094 i~RAT FCNL 228.228 GI~ 24.200 aPBI 5iCNb 352.6,38 FCNL 257.400 · · ,p r' GR 1940() NPHI 0083 N,.A[ FCNL 292.149 GR 18.300 apal NCNb 350,064 FCN!a 276.705 GR 22.600 NPHI 00a9 NRAT FCNL 252.681 GR 24:100 NPH[ NCNb 36~].792 FCNb 287.859 GR 26.100 NPH I, 0.117 NRAT FCNL 202,917 GR 2],800 NPHI NCNb 295,152 FCNL 215.78'7 Glq 49.70o NPHI O 185 NRAT FCNL 127.842 GR 47:800 NPHI NCNb 225,654 FCNL I]1.274 G~: 161.20o aPHI 0.407 NRAT FCNL 63.063 GR 154.600 ~PaI NC'Nh 172.029 FCNL 57.057 GR 48.100 NPH I O. 186 NRAT FCNL 130.416 Gla 52.600 ~Pl41 NCNb 186.186 FCNL 65.208 GR 105 · 800 NPH I 0,429 ~,~ Ra'r FCNL 57.486 GR 52.600 NPHI NCNL 186.186 FCNb 65.208 GR 46.900 NPDI O, 458 NRAT FC:Nb 48.906 GR 52.600 NP[qI NCNb 1. 86.186 FC~.!L 65,208 GR 53,600 ,,,.F HI O, 426 NRAT FCNL 49. 764 GR 52.600 NPHI NCNb 186.186 FCNL 65. 208 GR 53,700 ~PHI 0.497 FCNh 50,622 GR 52 600 NPHI NCNb 186.186 P"CNL 65~ .082 2.490 ~CNL, 208.554 O. 190 mRAT 2.6'14 2.030 aC i"~b ,335.049 0.094 NRAT I .91 4 1.7t~o NCNb 341. t) 55 O. 095 NRAT I. 880 2. o I o NC~;L 342.342 0.082 NP, AT 1 .~34 2.12 t) !~ C ~:~ L 283.5 o 9 O.10~ NRAT 2.018 2."108 NCNB 228.657 0.191 NRAT 2.624 3.950 NCaL 165.165 0.450 ~RAT 4.376 2,644 SCNb 229.944 O,287,~ NRA:T 4,096 4.2q~ ¢~Cf~tb lb0.875 0.287 :NR, AT 4.096 4.jUu aCN[j 1,35.991~ 0,281 , NRAT 4,096 .11o i~C i',i L I37.280 .287 N~AT ~'O96 4 ~5 2 0 ' "i" 866 NC '~b 151 , 4.7 10 F:iCr<~h 134.2 17 0,2$ t NRAT 4'0:96 DEPTH 8300,000 8200,000 8100,000 8000,0O0 7900,0OO 7800.000 7700,000 7600.000 7500.000 740O. 000 7300.000 EMON1C GR FCNL NCNL GR FCNL NCNL GR FCNL NCNL FCNL NCNL GP FCNL NC N b GR FCNL NCNL GR FCNb NC Nlm GR FCNL GR FCNL NCNb GR FCNL NC N L GR FCNL NC NL 7200.000 GR FCNL NCNL 7100.000 GR FC N b NCNL 7000.000 GR FCNL NC N I, (.' V h L U E 47,200 62,205 186,186 47.900 78.507 186.186 53.30O 66.495 186.186 51.000 60.060 186.186 59.000 69.498 1R6.186 49.800 62.634 186.186 54 400 69:498 186.186 4 ! · 600 69.498 1.86.186 50.100 60.060 186.186 42.700 55.770 i86.186 186.186 26.100 58.344 !86.186 4i.000 44.187 186.186 45.6C)() 52,767 186.186 M N E ~ O N 1 C aPD I GR FC N L NPH I G~ FCNI, NPH I GR FC N L NPH I GR FC N L Np{.{ 1 GR F'CNL NPH1 G~ FCNL NPHI GR FCNL NPH I GR FC N [j N P H .[ GR FCNL GR FC N b N P }q I G~ FCNL 0. 344 52.600 65.208 V aL, tiE 1 4~. 0o5 0.289 N t{ A T 3.312 i>i C rq L, t 62.. 591 52. 600 NPM [ 0. 287 NRAT 4. 090 65.208 0,321 i~RAt 3,450 NCNb l.~5.86~) 52,600 ~qPH I 0,281 NRa'IT 4,096 65. 208 NRAT 3.850 NC~L I 39.q25 NPHI O, 2~ t NRAT ~4. ugo 0.374 52.600 05.208 0,311 52,600 NPHI 0,2~ ? N. RAT 4, 65.208 o. 333 52.600 65,208 0 .309 52:600 65.208 0.3~o 52,600 65.20~ ~RAT 3.'l~u NCNL 137,2~() NPHI 0,2~'1 NRAT 4,096 NR AT 3.412 NCN[, 147.. 85'1 NPHI 0.28'1 N RAT q. 096 iq R A T 3.5 i u N C N i., I. ~, q~. 5 '1 ~ NPH l o, 28'7 NRA'[' 4,0'96 NRAT 3.81u NCNL, lt2.132 NPH [ O. 2i~7 NRAT 4. ()96 0,365 5~.600 65.208  383 NRAT ~,9~0 NC!'qL 5:600 NPHI ,287 NR.AT 65. 208 0.379 52'600 65.208 0,326 52,600 65,208 0 521600 85.2 () 8 0 379 52: 600 ~5. 208 RAT NPHI 0.2e t NRAI' I '28.7 ~} 0 ~'09$ NRAT NC~gL,, 1 i7. {" ' ' ' .096 N P ~t I ~{ R A F 4 N F', A T 4, ~ o b ~'~ C a L I 07.679 NPji... I 0.28'/ t"qRA'~ 4.096 NRAT 3,758 NCN!5 108.537 N'PH I O' 28i NRAT q. 096 DEPTH 6900,000 6800,000 6700.000 0630.000 MNENOMIC GR FCNL, NC Nb GR FCNL NCNb GR FC NL NCNb FCNL NCNb VALUE MNEMONIC VALUE ~ N E;.,'40 a I C VALUE 35. BO0 NPHI O. ~97 NRAT 3.7 60. 489 GR 52.600 NPH [ 0.2 186, ~ 80 FCNI 65,208 24.900 NPHI 0.362 NRAT 3,8~2 i~CNL 11) 250 56.199 GR 52.000 NPHI 0,2~1 NRAT ~096 186.186 F'CNL 65.208 36,000 NPH[ 0.391 NRAT 3.9ug NCNL 107.679 51.051 G~ 52.600 NPHI 0.281 NRAT 4.096 186.186 FCNL 65.208 30.000 NPHI 0..~42 ~RAT ~.b~2 N (7 D~.~ L, 12t .a07 58,773 GR 52.600 N P{"t I 0,2u 1 NRAT ,~. Ogo 186.1 ~6 FCNL 65. 208 SU~NARY {IF DATA RECORD,5 NUMBER OF RECORDS: 266 LENGTH OF RECORDS: 1018 BYTES DENGTit ('IF 'LAST RECORD: 270 BYTES FILE TRAILER LENGTH: 62 BYTES FILE NAME: ED1T .001 MAXIMUM PHYSICAL RECORD LENGTH: NEXT FII,E NAME: 1024 BYTES TAPE TRAILER LENGTH: 132 BYTES TAPE NAME: 54316 SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: Ol NEXT TAPE NAME: COMMENTS: DATE: 79/ 1/29 V'v vv EEEEEEE~EE ~RRNRRRH VV VV EEEEEEEEEE R~RRR~ VV VV EE R~ ~ VV VV EE RR ~R VV VV EE R~ ~R VV VV EE RR RR VV VV EEEEEEEE RRRRRRRR V¥ VV EEEEEEEE R~RRRRRR VV VV EE RR R~ VV VV EE RR RR VV VV EE RR RR VV VV EE RP RR VV EEEEEEEEEE RR RR VV EEEEEEEEEE RR RR !I. II IIII 1I II .1I II II II II II II ii IIII !I!I I1 11 II II Y Y 'y¥ ¥¥ YY YY ~Y YY Y¥ ¥¥ Y¥ Y¥ 000000 000000 222222 000000 000000 222222 O0 O0 O0 OO 22 22 O0 O0 O0 O0 22 22 Ou 0000 O0 0000 22 O0 0000 O0 0000 22 O0 O0 O0 O0 O0 O0 22 O0 O0 O0 O0 O0 O0 22 OOO0 O0 0000 O0 22 0000 O0 0000 O0 22 O0 O0 O0 O0 22 O0 O0 O0 O0 22 000000 000000 2222222222 000000 000000 2222222222 *START* USER ,CCC .[10706,54571] JOB SHIP MONITOR SWS KLIOB3! 2t-NOV-78 FILE: DSKH:VER[FY.O02<057>[10706.54571] CREATED: PRINTED: 06-FEB-79 06:19122 OUEUE $~ITCHE$: /FILE:FORT /COPIE$:I /SPACING:! /LIMIT:552 /FORMS:NORMAL 815 DATE 06-FEB-79 06-f'EB-79 05:47:39 06:11:10 PACIFIC COAST CF~PUT'!NG CENTER 10706, .54571 ~EEL HEADER LENGTH: 132 BYTES REEL NAME: P.C.D.C. SERVICE NAME: EDIT REEL CONTINUATION NUMBER: 01 PREVIOUS REEL NAME: COMMENTS: LIS FORMAT CUSTOHER TAPE [)ATE: 79/ 21 6 TAPE HEADER LENGTH: 13R BYTES TAPE NAME: 54571 SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: PREVIOUS TAPE NAME: COMMENTS: DATE: 79/ 2/ 6 EOF FIbE HEADER LENGTH: 62 BYTES FILE NAME: EDIT .00~ ~AXIMUM PHYSICAL RECO~D I,ENGTH: 1024 BYTES PREVIOUS FILE NAME: FILE COMMENTS JOB CONTAINS DIL/BHC COMBINATION AS WELL AS A BHC BY ITSELF. WORDS 19 - 22 ARE FROM A CASED HOLE CML. ~EL6 SITE INFORMATION RECORD LENGTH: COMPANY: WELL: FIELD: COUNTY: STATE: 138 BYTES ATLANTIC RICHFIELD CO. NGI 12 PRUDHOE BAY NO}~TH SLOPE ALAS~ A DAT~ Y_t31:II~'tAT SPEC II" ICgTIUfq !,EI~iGTH: 850 [{¥Tff;S ENTRY CLOCKS: T ¥171:.~ 0 i {>b 0 DATU" ~PECIFICATI[)N BLOCKS: lC TOOL SVORD# 1 OEPT 2 SP OIL CIbD 4 CILM DIL 5 CLI, 8 DIL ? DT BHC 8 GR BHC 9 DT BHC 10 GR CNL 11 CALl CNL 12 DRHO FDC 13 NPHI CNL 14 RHOB FDC 15 NRAT CNL 16 NCNG CNL 17 FCNL-CNL 18 GR CNL 19 NPHI CNL 20 NRAT CNL 21 FCNL CNL UNITS API APl API AP[ FILE# SIZE EXP Pt~.OC SAM kE;P DEPT SHIFT PT ~P~HO GAPI (;AP1 US/F GAPI iN G/C3 p U G/C3 C/C CPS CPS GAPI C/C CPS 0 0 0 0 0 4 0 0 1 b B 0 0 7 I 0 0 0 4 0 0 1 68 o 7 11 46 0 0 4 0 0 1 u8 0 0 7 11 44 0 0 4 0 0 I 68 0 () 7 21 8 0 0 4 0 0 1 68 0 7 31 ~2 0 0 4 0 0 i 68 0 7 52 32 0 0 4 0 0 I 68 0 0 60 31 32 0 0 4 0 0 I 68 0 0 60 52 32 0 0 4 0 0 1 68 0 0 42 31 32 0 0 4 0 0 1 68 0 0 42 28 1 0 0 4 0 0 I 68 0 0 42 44 0 0 0 4 0 0 I 68 0 0 42 68 3 0 0 4 0 0 I 68 0 0 42 35 ! 0 0 4 0 0 i 68 0 0 42 42 1 0 0 4 0 0 1 68 0 0 42 34 92 0 0 4 0 0 1 68 0 O 42 34 93 0 0 4 0 0 1 68 0 0 42 31 32 0 0 q 0 0 I 68 0 0 42 68 3 0 0 4 0 0 1 68 0 o q2 42 1 0 0 4 0 0 1 68 0 42 ]4 9] O 0 4 0 0 I 68 O 0 DEPTH 9715.000 9700.000 9600.000 9500.000 9400.000 9300.000 9200.000 9100.000 9000.000 MNEMONIC VAI,[J~; MNEMONIC VALUE MNEMONIC VA[.,UE MNKbiONIC V ALII~: SP 999.250 CILD -999 250 CILM -999.2bu CLIJa -999.259 GR -999,250 OT -999~250 GR -999.250 D!I' -1010.424 GE -1206..969 CALl -999°250 DRHO -999,250 NP}il *******~** RHOB -999,250 NRAT -999,250 NCNL -999.2b0 f'CNL -999.250 GR -1208.125 NPHI ***'8'**** NRAT -999.25o FCNL -999.250 SP 29.367 CILD 275.423 CI. LM 263.021 el,L8 226.986 GR 0.000 DT 77.750 GR -999.000 DT -999.000 GR 0,458 CALl 0.000 DR}iii O.OOU NPHI -0.525 RHOB 2,500 NRAT -999,000 NCNL -999,000 FCNL -999.000 GR -999.000 NPHI -999.000 NRAT -999.26(i) FCaL -999.000 SP -49,620 CILD 18,197 CIL~ 25,351 Cbb8 1'!.539 GR 56.100 DT 92,850 GR 65.900 DT 87.080 GR 62.083 CALl 8,400 DRHO 0,021 NPHI 19.548 RHOB 2.336 N~AT 2.182 NCNL 495.9~q FCNL 214.bO0 GR -999.000 NpR] -999.000 NRAT -999,000 FCNL -999.000 SP -76.962 CILD 11 066 ClL~M 21.086 CLL8 29.64~ GR 41.400 DT 85~800 GR 46.700 DT ~5.~64 GR 36,950 CALl 8.400 DRHO 0.036 NPHI 14.006 RHUB 2.365 NRAT 1.892 NCNb 557 700 FCNL 293.436 GR -999.000 NPHI -999.000 NRAT -999~000 FCNL -999.000 SP -31.392 CILD 55.976 Clba 102.802 CLL8 97.275 GR 33,700 DT 83,150 GR 34.30u DT 81,225 GR 29,458 CALl 8.400 DRHO -0.0i2 NPHI 10.457 R~B 2,345 MR'AT I 592 :NCNb 623.75~ FCNI., 3'16 662 GR -999.000 NPHI -999~000 N~a'r -999.000 FCNb '999~(')00 SP -42.785 CILD 32.509 CIL~ IU,144 C[,I,8 3.020 GR 35.800 OT 79,050 GR 44,800 DT '19,35'! GR 36.104 CALl 8.400 DRHO 0.010 NPHI 10.803 RHOB 2,390 NRAT 1'556 NCNb 628,4~5 FC'NL '34B 348 GR -999.000 NPHI -g99.000 NNAT -999.000 FCNL 999~000 SP -32. 152 CILD 9.~3U C~L8 7.58u GR 38,200 OT ~7'100 D'I 1:02'37:4 GR, 38.279 8 300 DRHO .005 NPHI 1.5.969 :ooo .ooo .ooo - 99.ooo SP -42.785 CiLD 2£ .512 CILM 33. i 13 C'L_I.,8 29.107 D GR 8,5 . 2,00, :DT 100. (iR 91 . 808 CALI. 8.450 DRH(') NPHI 22. 090 RHOB 2.25:7 NRAT ~:CNL 151. 437 ' 0 f [ NL -Q99, ()00 GR -999. 000 NPHI'. NRAT SP -16,962 CILD 1i69,499 CI ~a 847.227 CLL8 328.095 GR 243,600 DT 103.150 GR 271 , 600 DT . 95() DR}i[) -00..~Z i~}iI' 103 131 GR 300. 85O CALl 9 . . 46.353 RHO~ 2.554 NRAT , 244 5 77~ GR -999,000 biPH I. 999.000 {:~RAT -999, -999'000 I.) E P T t4 8900,o00 8B00,000 8700.000 8600,00O 8500,000 8400.000 8300.OO0 @200.000 8100.000 SP G~ G~ RHOB GR SP RHOB SP GR GR RHOB GR SP GR RHOB GR SP GR GR RHOB GR SP GR GR RHOB GR SP GR RHOB GR -28.101 CII.,D 133.900 OT 141.954 CALl 2.375 NRAT -999,000 NPHI -47,848 CILD 158,400 DT 183,762 CALl 2,409 NRAT -999,000 NPHI 47.089 CILD 78,400 DT 78,758 CALI 2,588 NRAT -999,000 NPHI -0,759 CILD 0.000 DT 199,350 CALI 1,999 NRAT 86,774 NPHI -0.759 CILD 0,000 DT 199,471 CALI 1,999 NRAT 100,323 NPHI -0.759 CILD 0,000 DT 199.471, CALl 1.999 NRAT 117,500 NPHI -0,759 CII, D 0.000 DT 999 NRAT 54,234. NPHI SP '0,759 CILD GR 0,.000 OT GR 199.471 CAI..,I RHOB 1,999 NRAI GR 59,556 NPH SP GR GR RHOB GR -0,759 CILD 0,000 PT 199.471 CALl 1,999 NRAT 65,726 NPHi VAL 7 93 9 2 -999 218 111 10 3 -999 104 60 4 -999 9999 0 0 2 9999 0 0 2 9999 0 0 47 9999 0 0 9999, 8' . 3 ' . 9999. 0, 0. .920 . .150 .914 .000 .776 .900 .250 .722 .000 .713 .300 .900 .078 .000 ,q98 .000 .0 O0 292 :618 998 iO00 000 ,306 .053 ,998 000 000 306 6]8 998 ". 000 ,000 ,306 .2:34 998 000 000 306 467 998 000 000 376 C ILa GR I) F~ H 13 NCNb N RAT CILM I) R H t') NCNb NRAT C1L,~ GR ORHO NCNb m RAT CIL~% GR O R H O NCNb NRAT Clba GR D R ii 0 NCNI, NRA T C!L~ GR DRHO NCNb NRAT CILM GR DRHO NCNL NRAT GR ID R H 0 CN C I I:,, H GR 0 R H 0 C N b NNRAT 64. 209 Ci..,[.,a 05. 464 170,10o bT 92.685 -0. 002 NPtJl 29,392 325.1uZ ~CNL 117.117 -999. OOO FCmL -999, 208,930 CLLH 154.17o 183. 300 lOT 110. 198 O. 004 NPHI 39. 072 252.681 FCNI, 68.6<40 -999.000 FCNL -999.000 U 00o CLL8 H55.uo7 91~000 DT 55.179 -0.279 NPHI 47.370 202.917 FCNL 49.7~ -999.0~0 FCNU -999,oou 9999.99U CLLH 9999.99~ -0.2OO DT 59.772 -().5OO i~PMI 19.2o4 1016.035 F'CNL 994.422 1.902 FCNL 47.190 9999.998 CLI, 8 9999.998 -0.2uo DT 139. 727 -0. 500 NPHt 19. 874 I: 04 ~ FCNI, 1001,286 ,99~ CLL8 9999,998 .727 O, 0(.) NPHI 1'!~,874 104~2754 FCNL 1001,286 9999.998 C.L[~8 9999 0,20 D~ -0'500 NPHi :['9 1040,754 i F'C:IqL 100i 3.634 F:CNI~ 66 .99~ ,721 1874 ,286 .495 9999 99~ Cb,La 9999 O :, u,r · 139 -0, O0 i'~,ipHI 19 104(), ~/5~ FCNL .1 O0 1 .~.670 F C :~ L 59 2874 28e~ :20'2 I'IlIllIl DEPTH B000.000 7900,000 7800.000 7700.000 7600,000 7500,000 7400.000 7300,000 7200. 000 MNEMU~\$IC VALUe]: bNE~ONiC VALOE SP -0.75q CIbD 9999.998 GR 0.000 DT 0.000 (;R 199.471 CALl 0.000 RHOB 1.999 NRAT 2.306 GR 61.976 NPHI 35.517 SP -0.759 CILO 9999.998 GR 0.000 OT 0.000 GR 199.471 CAbI 0.000 RHOB 1.999 NRAT 2.306 GR 67.298 NPHI 37.073 SP -0.759 CILD 9999.998 GR 0.000 DT 0.000 GR 199.471 CALI 0.000 RHOB 1.999 NRAT 2.306 GR 57.258 NPHI 39.174 SP -0.759 Ci, LD 9999.998 GR 0.000 DT 0.000 GR 199.471 CAbI 0.000 RHOB 1.999 NRAT 2.306 GR 64.637 NPHI 33.315 SP -0.759 C II_,D 9999.998 GR O. 000 DT O. 000 GR 199.471 CAhI 0.000 RHOB 1.999 NRAT 2: 306 GR 48.427 NPHI .]~ 851 SP -0.759 CILD 9999.998 GR 0.000 07' 0 000 GR 199.471 CALI 0:000 RHOB 1,999 NRAT 2,30~ (';R 59.798 NPHI 34.4~7 CIL~ 9999.998 GR -o,200 DkHO -0.500 NCNb 1040.764 NRAT 3.6~O CIl,a 9999,99~ GR -0.2UO DRHO -0,500 NCNb 1040.Tbq NRAT CII~ 9999.99~ GR -0.200 DRt40 -0.500 NCNb 1040.7bq NRAT 3.932 CILM 9999.9~ GR -0.200 DRHO -0.500 NCNb !040,754 NRAT 3.500 C I l.~t~ 9999,998 GR -0,200 NCNL 1040~764 NRAT 3.6 '12 Clb~ 9999.9~8 GR -0,~00 DRHO -0. Ou NCNb NRAT SP -0.759 CILD 9999,998 CILM G~ o. ooo OT o. ooo Ga GR 199.471 ~LI 0.000 DRHO RHOB I '999 ,,~AT 2' 306 NCNb GR 50. 847 NP,[!l 32' 790 NRAT 9999.998 SP -0.759 CILD 9999.998 Clha 9999.998 GR 0.000 DT ~ 000 GR -0,200 GR 199.471 CALl :000 DRHO -0,500 GR 37.661 NPNI 36. 952 NRAT . [ 02 SP -0.759 CibD 9999.998 C II, i¢ 9999.998 G}~ O. 000 DT GR -0~2~00 GR CALl DRHO -0~~00 RI.lOB NRAT NC~iL 1040.754 G}~ 35 · 363 NPH I N RAT 4 . 014 CI.,LS' 9999.998 DT I 39.727 ~PHI 19.874 I;'C N b 1()01.286 Cbb8 9999.998 OT 139,72'! ~PHI 19.~74 ~CNb 1001.286 F'Ci~L 57.915 CLI, 8 ~999.998 DT 139.727 NPHI 19,874 F'CNL 1001.286 FCNb ~2.205 CLL8 9999.99S DT I ]9.727 aP[il 19 8'14 FCNI., 1001.'286 FC~'~b 57.9 15 CLLg 9999.998 DT 1 39.727 NPHI 19.874 FCNL !001.286 FCNL 45.474, CLL8 9999.998 DT 139 7 27 ~pHI 19: 87 4 FC:ML 10()! ,286 FCNL 60. 489 CLL8 9999 998 727 874 341 Cbl, 8 9999. 998 T'. 1:3:9' 727 PHI 19.87.1 [~CNL l()ul .2.~b · , B" .,' Cribs 9999.998 DT 139 ~27 FCNL I001 286 FCNL 54 ~ 054 · ( D E P T H -.,..,71 oo, 000 7000°000 ~900.o00 6800,000 6700.000 6600.000 6500,000 6400.000 6300.00() SP -0.759 CILD 9999.998 CIDM GR 0.000 DT 0.000 GR GR 199.471 CALl 0.000 D~H(3 RHOS 1.999 NRAT 2,306 NCNL GR 46.129 NP))I 39,194 NRAT SP -0.759 CILD 9999.998 CILM GR 0.000 DT 0 O00 GR GR 199.471 CALl 0:000 DRHO RHOB 1.999 NRAT 2,306 NCNb GR 54.718 NPHI 36.749 N~AT SP -0.759 CILD 9999.998 Clh~ GR 0.000 DT 0.000 GR GR 199.471 CALl 0.000 DRHO RHOB 1.999 N~AT 2,306 NCNB GR 37.903 NPHI 35.578 NRAT SP -0.759 CILD 9999,998 Clba GR 0.000 DT O.OUO GR GR 199.471 CALl 0.000 DRHD RHOB 1.999 NRAT 2.306 NCNb GR 30.403 NPHI :37,275 NRAT SP -0.759 CILD 9999.998 CIL~ G R 0,000 D T 0,000 G R GR 199.471 CAb I 0. 000 DRHO RHOB 1.999 NRAT 2 306 NC.Nb GR 43 · 589 NPH I 40: 648 NRAT SP -0.759 CILD 9999.998 CIL~{ GR 0,000 DT 0,000 GR GR 19g. 471 CALI 0. 000 DRHO RHOB I ,999 NRAT 2,306 NCNB GR 32,218 NPHI 38. 749 NRAT SP -0.759 CILD 9999.998 CILM GR O. 000 DT 0.000 GR (;f4 199.471 CALl O.OO0 DRHO RHOB 1. 999 NRAT 2,306 NCNL GR 35.605 NPHI 38' 891 NRAT SP -0.759 C1LD 9999.99~ CILia  0.000 OT O0 000 G~ R 199.471 Cll,I : 000 DRHt} .R~OB 1. 999 NP, AT 2 3~ ~CaD GR 2~.105 NPH.I 37:840 RAT SP CILD 9999,998 GR DT ~0,000 ] GR GR 199 . 471 C A L I 0 . 0 (} 0 0 RHOB 1,999 NR,AT 2 306 NCNB GR 44 . 919 NPH 1 42: 325 NRAT V A 1., [.{ E 9999.998 -O.5UO 1040 75t Cb, La 9999.998 DT 139.727 {~PHI 19.R74 FCNL 1001.28o FC~L 46,332 9999.998 -O.2OO -0.50o 1040.75~ 3.758 Ct, L8 9999.990 OT 139.727 NPlqI 19.~74 F'CNL 1001.286 FC~L 51.909 9999.99~ -0.200 1040.75~ 3.7o~ Chh8 9999,998 DT 139.727 NPHI t9.874 FCNB I001.286 FCNL 61.776 9999.998 -0,200 -0,5O0 ~040.764 3.~8 CL!,t.t 9999.9961 DT 1 39.721 NPHI 19.874 FCNL 1 00! .286 FChb ~'1. I 90 9999.99S -0 -0:52'0OO0 1040,7 b~ 4 .022 9999.99~ -0, OO 1'04~:91z CLL8 9999.99a DT I 39,,727 !x} P ),i I I 9 r4 FC:NL 1'001 [;'CML 5 3 9999.998 C,BL8 9999,99~ -0,200 OT 1:39i727 -0.500 NPHI 19,87~ 1040.754 FC~L:l:OOl,286 3.96~ F'CNL 54.054 9999,998 C!.,L8 9999.998 ,2 0 ' ~' -,0 P ... D.I 1 39. -0 ·~00 ~P~"lI 1.9. 874 ' 10~0.764 I~CNL 1001.2 .~' g' 3,83b FCivB 49. 764 9999.998 CBL8 9999,9~8 -0,~00 DT 139,727 -0. O0 NPHI. 19,87~ 104~,754 FCNL 1001,286 .024 FCNL 38.18I DEPTH 6200.000 0100.000 6000.000 5900.000 5800,000 5700.000 5600,000 5500,OO0 5400,000 SP -0.759 CII,D GR 0.000 DT GR 199.471 CALl RHOB 1,999 NRAT GR 43,831 NPHI SP -0,759 CII:D GR 0.000 DT GR 199.471 CALl RHOB 1.999 NRAT GR 42.742 NPHi SP -0.759 ClbO GR 0.000 DT GR 199.471 CALl RHOB 1.999 NRAT G~ 30.645 NPHI SP -0.759 CII, I) GR 0.000 DT GR 199.471 CALl RHOB 1.999 NRAT GR 40.202 HPHI SP -0.759 CILD GR 0.000 DT GR 199.471 CAI, I RHOB 1.999 NRAT GR 57.500 NPHI SP -0.759 CILD o:ooo GR lO 4'71 CAI.~I SP -0,759 CILD GR 0,000 OT GR. 199,471 CALl RHOB 1.999 NRAT GR 25.081 NPHI 8P -0,759 CILD GR 0,000 OT GR 199,471 CAbI RHOB 1,999 NRAT GR 30.524 NPHI 1 C V A L U E; MNEMON lC VALUE 9999.998 Cil..,i~ 9999.99~ 0.000 GR ,0.200 0.000 OR)l[J 2.306 NCNb 1040.75~ 41,558 NRAT 4,090 9999.998 CILM 9999,99~ 0.000 GR -0,200 0.000 DRHO -o,500 2.306 NCNb 1040,754 46,911 NRA~ 4.322 9999.998 CILM 9999.998 0.000 GR -0,200 0.000 ORHO -0.500 2.306 NCNb 1040.7b~ 43,113 NRAT 4.040 9999.998 CIL~ 9999.99~ o ooo ¢;R -o.2oo o:ooo OaHO -0.500 2.306 NCNL 1040.754 40.244 NRAT 3.930 9999.998 CILM 9999.998 0.000 GR -O.2UO 0.000 DRaO -0.500 2 306 NCNb 1040,754 44:851 NRAT 4 9999.998 CIL~ 9999.998 0.000 GR -0.200 0.000 DRHO -0.500 2,~06 NCNL 4b.265 NRAT 9999.998 CIbN 9999.99~ o .00o Ga -0.200 OiO00 OR,I! -0.500 CI,L,~ 9999.998 D T I 39.727 i'~ P~,t I i9.874 KCNL I00! ,28b FCt,-~L 41,61 3 C[,L8 9999.998 [)T !39.727 aPHl FCNL 1001.28b FC~L 41.184 C[.,L8 9999.998 DT 139.72'1 mPHI 19,87~ F'CbL lo01.286 FCNI., 44.6i6 CLL8 9999.998 DT 1,39 727 NPHI 19:~7q FCNL 1001.28~ FC~L 38.181 CLL8 9999.998 DT 1,39.727 NPHi 19.874 FCNL 1001,286 FOaL 40.755 Cbb8 9999.998 DT 13:9.72'7 FCNL I00I ,286 FC~IL 51 . 909 CLL8 9999. 998 DT i: 39.727 N P }.11 1 9.8 '74 ~C:~..L lOUl 2 FCNL 54,9i2 9. 9.9'9a ChL8 9999 998 ~ -0.759 ClbO 9999 998 GR I 99,471 CALl 0,000 DRH[') -0,,500 NPHI 19.~74 RHOB 1'999 N'RAT 306 NC'N FCNLIOOl 2.6 GE 26.411 NPHI 4 .053 NRA FCNL ~7:752 I:) E P'[' H 5300,000 5200. 000 5100.000 5000. 000 4900.000 4800.000 4700.000 4600.000 4500. 000 SP G~ RHO~ SP GR GR RHO8 GR SP (;Iq GU SP (;R GR SP GR GR RHOB GR SP GR RHOB GR SP GR G~ GR SP GR GR -0,759 CILD 9999,998 CILg 9999.99~ Cbb8 9999.998 0.000 OT 0.000 G~ -0.200 DT 139.72'1 199.471 CAi, I 0.000 ORHi) -0.500 ~PHI 1.999 N~AT 2.306 NCNL 1040,75~ FCN[, 1001.286 27.258 MP~I 44.689 N~AT 4.1Zo FCNL 42.900 -0.759 CIL[) 9999.998 C 1 b~"~ 9999.998 C i.,L, 8 9999.998 0.000 DT 0.000 GI~ -0.200 DT 1 39.72i 99.471 CALI O. 000 ORHO -0. 500 NP~f ] ! 9. [474 1.999 NRAT 2 306 NCNb 1()40.7b~ f.'CNI,, 1001.28b 62.581. NPH! 571154 NEAT 4.964 F'CNL 40.326 -0,759 C1LD 9999,998 CIL~ 9999,99~ CLLB 9999.998 0.000 DT 0.000 GR -0,200 D'r 159.72'7 199,471 CALl 0.000 DRHO -0.500 ~PHI 19,874 1.999 NRAT 2.306 NCNb 1040.754 FCNL I001.2~6 32.218 NPHI 50.770 NRAT 4.~9~ FCNL ~%2.900 -0.759 CILD 9999.998 C1Ls 9999.998 Chi.,8 9999 99~ 0.000 OT 0.000 GR -0.200 DT I~9~727 1.99.471 CAI, I ('} 000 DRHO -0.500 NPHI 19.87~ 1.999 NRAT 2~306 NCNL 1040.7b~ FCNL 1001.286 51.452 NP}4l 43.800 N~AT 4.184 FCNL 38.181 -0.759 CILD 9999.998 CiL~ 9999.998 CLL8 9999.998 0.000 DT 0.000 GE -0. 200 DY 1 ~9. 727 99.471 CALl O. 000 ORHO -0. 500 NP['{ I 19.874 47. 823 ~4PBI NRAT .36t~ FCNL 4~i ~ 326 -0.759 CILD 9999.998 ClbS 9999.998 Cl.,b8 9999.998 1.99.471 CALI 0.000 DRHO 0.500 NPHI ~ 4 I .999 NRAT 30~ NCNb 1040.754 FC~L 1001,28 29.t94 NPHI 4 ~7f)9 NRAT 4.4~6 FCtVL 42.471 -0.759 CiLO 9999,998 .C., I bM 9999.99i~ CbL8 9999 998 0.000 [)T 0.000 GR -0.200 DT 39~ 727 199,471 CALl 0.000 DRHO -0,500 t,~ P}.l I 19.87q 1.999 MR'AT .306' NCNb 1014 .75~ !001,286 58.952 NPBI 5 .598 {~RAT .632 FC~L 36'894 .998 CLL, 8 9999.998 '0.759 CILD 9999.998 CiL!~ 9999 I,t9 39,,727 o.ooo o:ooo 199.471 CALI 0.000 DRHO -0.50'0 NPHI 19.87,i 1,999 NRAT 2,306 NCNb 1040'7b~ FCNL ' 1.001,286 42 742 r~PHI 48.64~ ~ "'* ' ". ~a~ 4. 24 FCML ~6,465 5 GR 199.471 C~LI O. 000 RHO . 506 PaI 19. 874 RHO.B I · 999 NRAT 42 306 NC~L I04 ~CNL ! 301 . 286 ~ ~ ' . ~ ~'< GR 42 137 NPHt 194 aRAT ~ C..~b 39'468 DEPTH ,i400,000 4300 4200.000 4100.000 4000.000 3900,000 3800,000 3700.000 3600.000 MN SP GR RHOB SP GR GR GR GR RHUB G~ GR RHOB GR. SP GR GR SP G~ GR EH 0 B SP GR GR GR SP GR (;R RHOB G~ SP GR RHOB GR VALUE -0.759 0.000 199.471 1.999 33.185 -0.759 0.000 199.471 1.999 39.960 -0.759 0.000 lq9.471 1.999 41.774 -0.759 0.000 199.471 1.999 39.839 -0.759 0.000 199.471 1.999 48.548 -0.759 0.000 199.471 1-999 50.484 -0.759 0.000 199.471 1,999 45.040 -0.759 0.0OO 1,99.471 1.999 41.169 -0. 759 0 ' 000 199.471 ! .999 24.597 CILD OT CALl NRAT NPHI CIL[.) UT CALk NRAT NPH I CILD DT CALl NRAT NPH1 CILD DT CALl NRAT NPHi C I L D DT CALI NRAT NPHI CILD DT CALl NRAT NPHI C I L D DT CAbI NRAT NPH I CII, D DT CALI NRAT NPHI CILD DT CALl NRAT NPHI VALUE 9999.998 0.000 o.000 2.306 45.~59 9999.998 0.000 0.000 2.306 47.477 9999.998 0.000 o.000 2.306 43.~9q 9999.998 0.000 0.00O 2.306 45.032 9999.998 0.000 o.000 2 30~ 48:467 9999.998 0.000 0.00o 2.306 47.8o0 9999.998 0,000 0,000 2,306 47.618 9999.998 ,000 .000 2.306 50.325 9999.998 0.0 O0 o, ooo 2.306 41 .356 tq Ngiq[)I'~ I C V ALL.lIS ClI, a 9999,99d GR -0.200 o~aO -0.Sou aCS[, 1040.7~q NRA? 4.2i~ CLL8 9999 . 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