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Home My WebLink About175-0527. 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-02 Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 175-052 50-029-20174-00-00 11002 Conductor Surface Intermediate Production Liner 8593 80 2658 9801 1462 10745 20" 13-3/8" 9-5/8" 7" 8380 31 - 111 30 - 2688 29 - 9830 9538 - 11000 31 - 111 30 - 2688 29 - 7657 7439 - 8592 none 520 2670 4760 7020 none 1530 5380 6870 8160 10308 - 10878 7" x 5-1/2" L-80 / N-80 28 - 9341 8027 - 8491 Structural 5-1/2" Baker FB-1 2202 / 2202 9329 7289 Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com (907) 564-4672 PRUDHOE BAY / PRUDHOE OIL 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 , 0028301 0 0 162025 162025 0 0 100 125 3383 3296 324-069 13b. Pools active after work:PRUDHOE OIL 7" MCX 9329 / 7289 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 By Grace Christianson at 8:36 am, Apr 17, 2024 Digitally signed by David Bjork (3888) DN: cn=David Bjork (3888) Reason: I am approving this document. Date: 2024.04.16 15:59:00 -08'00' David Bjork (3888) WCB 2024-07-15 RBDMS JSB 041924 DSR-4/23/24 ACTIVITYDATE SUMMARY 3/17/2024 T/I/O = 2709/99/35 LRS 46 - (TUBING WASH/PICKLE) Pumped 17 bbls 60/40, 100 bbls 120* Diesel, and 340 bbls Water w/ F103 into TBG. Let soak for 2 hours. Pumped additional 260 bbls Water w/ F103 and 15 bbls 60/40 into TBG. FP equipment w/ 2 bbls 60/40. DSO Notified upon LRS departure. Valve Positions: SV/WV = Closed, SSV/MV = Open, IA/OA = OTG Final WHPs = 454/74/34 Daily Report of Well Operations PBU NGI-02 (TUBING WASH/PICKLE) Pumped 17 bbls 60/40, 100() bbls 120* Diesel, and 340 bbls Water w/ F103 into TBG. Let soak for 2 hours. Pumped additional 260 bbls Water w/ F103 and 15 bbls 60/40 into TBG. FP equipment w/ 2 bbls 60/40. 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 this pool? Will perfs require a spacing exception due to property boundaries?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 ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU NGI-02 Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 175-052 50-029-20174-00-00 ADL 0028302 11002 Conductor Surface Intermediate Production Liner 8593 80 2658 9801 1462 10745 20" 13-3/8" 9-5/8" 7" 8380 31 - 111 30 - 2688 29 - 9830 9538 - 11000 31 - 111 30 - 2688 29 - 7657 7439 - 8592 none 520 2670 4760 7020 none 1530 5380 6870 8160 10308 - 10878 7" x 5-1/2" L-80 / N-80 28 - 93418027 - 8491 Structural 5-1/2" Baker FB-1 7" MCX 9329 / 7289 2202 / 2202 Date: Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com 907.564.4672 PRUDHOE BAY 3-1-2024 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: 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 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Coldiron at 1:56 pm, Feb 08, 2024 324-069 Digitally signed by Eric Dickerman (4002) DN: cn=Eric Dickerman (4002) Date: 2024.02.07 14:01:32 - 09'00' Eric Dickerman (4002) , ADL0034632 SFD DSR-2/13/24MGR13FEB24SFD 2/9/2024 10-404 *&:JLC 2/15/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.15 15:01:12 -06'00'02/15/24 RBDMS JSB 021524 Well Work Prognosis Well Name:NGI-02 API Number:50-029-20174-00 Current Status:Gas Injector Leg: Estimated Start Date:March 1, 2024 Rig:N/A Reg. Approval Req’d?10-403 Date Reg. Approval Received: Regulatory Contact:Carrie Janowski Permit to Drill Number:175052 First Call Engineer:Dave Bjork Office: 907-564-4672 Cell: 907-440-0331 Second Call Engineer: Gas Injection Rate: ~170,000 Mscf/Day Injection Pressure: 3,390 psi Reservoir Pressure (Estimate): 3300 psi Program Objective(s): NGI-02 is a gas cap injection well that has demonstrated a decrease in injectivity. The well has not been water washed since 2012. 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. 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 100 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-02 GI Water Wash 01/27/24 Increase well injectivity by performing a water wash. -Use 2 full uprights of fresh water mixed with 0.02% F-103 surfactant. Use 100 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 340 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 ~ 50 bbls of diesel to be pumped into perfs and a remaining 50 bbls to soak outside the perfs. b.) After the 2 hour soak time, resume pumping at max rate/pressure (whichever is hit first) for next 260 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 100 1.5 67 1.11 FW flush 340 5 68 1.13 Soak 2.00 FW flush 260 5 52 0.87 methanol cap 15 1.5 10 0.17 5.44 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 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 21, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC NGI-02 PRUDHOE BAY UNIT NGI-02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/21/2022 NGI-02 50-029-20174-00-00 175-052-0 G SPT 7289 1750520 1822 3345 3345 3343 3345 64 64 65 65 4YRTST P Bob Noble 7/4/2022 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-02 Inspection Date: Tubing OA Packer Depth 163 2216 2210 2210IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN220704091324 BBL Pumped:4.4 BBL Returned:3 Thursday, July 21, 2022 Page 1 of 1          Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:175-052 6.API Number:50-029-20174-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028302 Property Designation (Lease Number):10. 8. PBU NGI-02 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Water Wash Op Shutdown GAS GSTORWAG 5 SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 11246 Effective Depth MD: 11. 8/1/2021 Commission Representative: 15. Suspended Contact Name: David Bjork Contact Email: David.Bjork@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: 7" MCX Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8794 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 9329 / 7289 2202 / 2202 Date: Liner 1462 7"9538 - 11000 7439 - 8592 8160 7020 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 30 - 2688 30 - 2688 14. Estimated Date for Commencing Operations: BOP Sketch 31 - 111 Structural Proposal Summary 13. Well Class after proposed work: 5-1/2" Baker FB-1 10308 - 10878 8027 - 8491 7" x 5-1/2"28 - 9341 Production 10745 8380 none none 31 - 111 520 13-3/8" Contact Phone:(907) 564-4672 Date: 7/22/2021 80 153020"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2658 5380 Intermediate 9801 9-5/8" 29 - 9830 29 - 7657 6870 4760 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 3300 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. L-80 / N-80 By Meredith Guhl at 9:34 am, Jul 22, 2021 321-366 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.07.22 08:43:33 -08'00' Bo York 11002' DLB , ADL 0034632 X 8593' TVD DLB DSR-7/22/21DLB 07/22/2021 10-404 MGR23JUL21 dts 7/23/2021 JLC 7/23/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.23 12:31:51 -08'00' RBDMS HEW 7/26/2021 MEMORANDUM 0 TO: Jim Regg P.I. Supervisor 7 FROM: Guy Cook Petroleum Inspector NON -CONFIDENTIAL • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, July 13, 2018 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. NGI-02 PRUDHOE BAY UNIT NGI-02 Src: Inspector Reviewed By: P.I. SuprvZ Comm Well Name PRUDHOE BAY UNIT NGI-02 API Well Number 50-029-20174-00-00 Permit Number: 175-052-0 Insp Num: mitGDC180706144828 Rel Insp Num: Inspector Name: Guy Cook Inspection Date: 7/6/2018 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1 NGI-02Type Iql G -TVD 7289 Tubing 3260 3259 3260 3260 PTD D 1750520 Type Test SPT Test psi 1822 j IA 571 2498 - 2485 2485 BBL Pumped: 2.3 BBL Returned: 2.5 OA 30 29 29 - 29 Intervale aYRTST p/F P Notes: A triplex pump and bleed trailer were used for testing. SCANNED' AUG U 9 iu 16 Friday, July 13, 2018 Page 1 of 1 MEMORANDUM • 9 State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re 2 % ) DATE: Thursday, July 05, 2018 gg P.I. Supervisor gri lQ' �I tol i ` SUBJECT: Mechanical Integrity Tests (� �' BP EXPLORATION (ALASKA) INC. NGI-02 FROM: Matt Herrera PRUDHOE BAY UNIT NGI-02 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry 9— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-02 API Well Number 50-029-20174-00-00 Inspector Name: Matt Herrera Permit Number: 175-052-0 Inspection Date: 7/5/2018 Insp Num: mitMFH180705145008 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NGI-02 Type Inj G TVD 7289 Tubing 3253 3259 ', 3260 3254 PTD 1750520 Type Test SPT Test psi 1822 IA 64 2500 2518 2531 BBL Pumped: 3.9 BBL Returned: 3.1 OA 30 29 29 30 Interval aYRTST p/F I v _ _ Notes: IA tested at 2500 PSI per Operator. Conclusive test on IA not possible due to Unstable injection pressures SEA%t*0 AUG U 9 -/U-16 Thursday, July 05, 2018 Page 1 of 1 4111, • • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, November 21, 2016 5:41 AM To: AK, GWO SUPT Well Integrity;AK, OPS FS1 OSM;AK, OPS FS1 Facility OTL;AK, OPS FS1 Field OIL;AK, OPS FS1 DS Ops Lead;AK, OPS FS1 GAS INJ OPERATOR;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, GWO SR Slickline WSL; Stone, Christopher; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep; jim.regg@alaska.gov';AKIMS App User; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel, Troy;Worthington,Aras J;AK, GWO Well Integrity Well Information Subject: OPERABLE:Injector NGI-02 (PTD#1750520) No TxIA Communication Present Post-SSSV Reset Attachments: Injector NGI-02 (PTD#1750520)110 and Injection Plots.docx All, Injector NGI-02 (PTD#1750520)was made Under Evaluation on 11/04/16 after it begun to exhibit tubing x IA communication suspected through a control line at the SSSV profile. Slickline pulled and reset the SSSV on 11/13/16. Subsequently the well was brought back on injection to continue diagnostics. Pressures post-SSSV change- out indicate no tubing x IA communication present. This well is now reclassified as Operable. TIO and Injection plots attached. Thanks, Jack Lau (Alternate:Adrienne McVey) NOV 2 22016 BP Alaska-Well Integrity Superintendent SCBE W:907.659.5102 C: 907.943.0296 H:x2376 From: ', e PT Well Integrity Sent: Friday, November : , 016 2:50 PM To: AK, OPS FS1 OSM; AK, OPS .cility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 GAS INJ OPERATOR; Cismoski, Doug A; Danie, ° ; e AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; • WO SR Slickline WSL; Stone, Christopher; 'ch ris.wa l lace@a laska.gov' Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; ' , • A 0 Completions Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; 'jim.regg@alaska.gov'; AKIMS •= ser; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis 3; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternic'', sliver R; Tempel,Troy; 1 i • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday, November 04, 2016 2:50 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL;AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 GAS INJ OPERATOR; 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, GWO SR Slickline WSL; Stone, Christopher; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity; AK, GWO Completions Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; jim.regg@alaska.gov'; AKIMS App User; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel, Troy;Worthington, Aras J Subject: UNDER EVALUATION:Injector NGI-02 (PTD #1750520) Possible Tubing x Inner Annulus Communication Attachments: Injector NGI-02 (PTD #1750520) TIO Plot 2016-11-04.docx All, Injector NGI-02 (PTD#1750520) has begun to exhibit tubing x IA communication. It is suspected the communication is occurring through a control line at the SSSV profile. The well is reclassified as Under Evaluation for further diagnostics. Plan Forward: 1. Slickline:Troubleshoot subsurface safety valve 2. Downhole Diagnostics: Monitor wellhead pressures 3. Well Integrity Engineer: Additional diagnostics as needed TIO and Injection plots attached. Please reply if in conflict with proposed plan. Thanks, Adrienne McVey SCANNED MAY 2 G 2017, Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0: (907)659-5102 C:(907)943-0296 H: 2376 Email: AKDCWeIlIntegrityCoordinator@BP.com From: • D&C Well Integrity Coordinator Sent: Satur• September 12, 2015 9:18 PM To: AK, OPS FS1 0 'K, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AKOpsProdEOCTL; AK, GWO SUPT Special Pro]- • 'K, GWO SUPT Slickline; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt En• , 1 K, OPS EOC Specialists; AK, OPS Prod Controllers; AK, OPS FS1 GAS INJ OPERATOR; Morrison, Spencer; 'chris.wallace4atasska,49v' Cc: AK, GWO DHD Well Integrity; AK, GWO SUPT Well Iiitegrq.; AK, GWO Projects Well Integrity; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; 'jim.regg@alaska.gov'; Sayers, Jes'stPettus, Whitney Subject: OPERABLE: Injector NGI-02 (PTD #1750520) No Inner Annulus` ressurization post Safety Valve Changeout 1 • 0 • Injector NGI-02(PTD#1750520) TIO Plot 2016/11/04 Well 161@ _ ` t Tt6 -16-01 004 -+-0004 _a. I „'` �... 'rte ♦y 06A1 C6 :C1616 02-25'S 69^'96 0001€ 00011 0972'16 0'.7916 ''006'16 .a.. I Injection Plot ww.M6109 I I 3 40C 000 710E L—�� , I2m6 *Dm* 5., �, SO OM_- w1 1 —G 66c •66m _0699 I cut* 1 205 tmC 552006 t0 9q 000 10 ]6m0 6m, 6064 I fib Iamb I I Mt IC 0611:4 601316 X16 0901'16 010.16 051511 0214 032316 100114 101110 1010'16 102114 1110016 I • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, September 12, 2015 9:18 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 Superintendent;AK, D&C Wireline Operations Superintendent; 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; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; jim.regg@alaska.gov'; Sayers, Jessica; Pettus, Whitney Subject: OPERABLE:Injector NGI-02 (PTD #1750520) No Inner Annulus Repressurization post Safety Valve Changeout Attachments: Injector NGI-02 (PTD #1750520) TIO and Injection Plot.docx All, Injector NGI-02 (PTD#1750520) has stopped presenting signs of tubing by inner annulus communication after the subsurface safety valve was pulled and reset on September 3, 2015. The AOGCC declined to witness a MIT-IA post valve change out as the inner annulus pressure has demonstrated no noticeable indications of a buildup rate over the last ten day period.This well has been reclassified as Operable. An updated TIO and injection plot have been included for reference. Please call with any questions or concerns. Thank you, Whitney Pettus SCANNED MAY 0 2 2016 (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator GAN- , ..,;, Qrga+rzrat+os, WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator(ct�BP.com From: AK, D&C Well Integrity Coordinator Sent: Saturday, September..Q5, 2015 2:38 PM To: AK, OPS FS1 OSM; AK, OPS FS&Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engj r 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; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; 'jim.regg@alaska.gov'; Sayers, Jessica Subject: UNDER EVALUATION: Injector NGI-02 (PTD #1750520) Ready to be Placed on Injection All, 1 • ! Injector NGI-02 (PTD#1750520) TIO Plot September 12, 2015 Wel 11,14.11 1000 —0- -o—OA 00 —o-00 000. I a Oc0 - 01915 ....1000001....1000001....1000001 0"1215 070616 09@1'_ 000016 00115 060111 011015 VACS Injection Plot .Wm MOM 001. int MOW 1.! an F :-M nwc 6 1. tia OD wow Oi..kH PNM COMrtC%X G1P,fc..]2.15Mhfo.X4o.Xdeo m..Pl9`.MoIW+s Wb.obt':.,.....a..a.,fl 34110 WM,nt340134'r,S NtY',60W5^S MR�nIOM'N!M]W aWElf 4Ml1096ll MWI{(Y10nI ONN! • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Saturday, September 05, 2015 2:38 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 IL;AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; 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; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg, James B (DOA); Sayers, Jessica Subject: UNDER EVALUATION:Injector NGI-02 (PTD#1750520) Ready to be Placed on Injection All, Injector NGI-02 (PTD#1750520) is ready to be placed on injection to evaluate if the inner annulus repressurization has been mitigated following a change out of the subsurface safety valve. The well is reclassified as Under Evaluation to facilitate further diagnostics. Please use caution when placing the well on injection as the annuli are fluid packed. Plan Forward: 1. Slickline: Change out subsurface safety valve—COMPLETE 09/04/15 2. Operations: Place well on injection 3. Downhole Diagnostics: Perform MIT-IA to confirm integrity has been restored 4. Well Integrity Engineer: Additional diagnostics as needed Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate:Kevin Parks) SCANNED MAY 0 2 2016 BP Alaska-Well Integrity Coordinator G WIC Office: 907.659.5102 WIC Email: AKDCWelIIntegrityCoordinatorPBP.com From: AK, D&C Well Integrity Coordinator Se trMMonday,....l ly 06, 2015 10:41 AM To: AK, OPS FS1 OSM; AK;O &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 Subject: NOT OPERABLE: Injector NGI-02 (PTD #1750520) Inner Annulus Repre ss urization Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, July 06, 2015 10:41 AM 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; 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: NOT OPERABLE: Injector NGI-02 (PTD #1750520)Inner Annulus Repressurization Attachments: image001.png;Injector NGI-02 (PTD #1750520) TIO Plot 06-27-15.docx All, Gas Injector NGI-02(PTD#1750520) has begun to exhibit tubing x inner annulus communication. Slickline will not be able to trouble shoot the subsurface safety valve within our 28 day window due to Simops issues on the pad.The well is reclassified as Not Operable until tubing integrity can be restored. Please call with any questions or concerns. Thank you, Kevin Parks 6 2�� (Alternate: Whitney Pettus �� JUL BP Alaska-Well Integrity Coordinator GVVGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Se aturday, June 27, 2015 8:58 AM T : AK, 5 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 WeIIs Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; AK, OPS FS1 GAS IIVJ-QERATOR; 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 Ci p_Jep Subject: UNDER EVALUATION: Injector NGI-02 (PTD #-175,0520) Inner Annulus Repressurization All, Gas Injector NGI-02 (PTD#1750520) has begun to exhibit tubing by inner annulus communication. It is suspected the communication is occurring through a control line at the SSSV.The well has been reclassified as Under Evaluation and placed on a 28 day clock for additional diagnostics. 1 Injector NGI-02 (PTD#1750520)TIO Plot 06/27/15 r • ... a OW ovracm aems OWNS awn w!v asas an aavn ec+rn �n WW1! Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Saturday, June 27, 2015 8:58 AM 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;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: UNDER EVALUATION:Injector NGI-02 (PTD #1750520)Inner Annulus Repressurization Attachments: image001.png; Injector NGI-02 (PTD #1750520) TIO Plot 06-27-15.docx All, Gas Injector NGI-02 (PTD#1750520) has begun to exhibit tubing by inner annulus communication. It is suspected the communication is occurring through a control line at the SSSV. The well has been reclassified as Under Evaluation and placed on a 28 day clock for additional diagnostics. Plan Forward: 1. Slickline:Trouble shoot subsurface safety valve 2. WIE/APE: Additional diagnostics as needed A copy of the TIO plot have been included for reference. Please call with any questions. Thank you, SCANNED JUL 0 12015 Kevin Parks (Alternate Whitney Petti,> BP Alaska-Well Integrity Coordinator G�/r/ Global Wells �/�/ Organizatior Office: 907.659.5102 WIC Email:AKDCWelIIntegrityCoordinator@bp.com 1 • • Injector NGI-02 (PTD#1750520)TIO Plot 06/27/15 a 3 WC ten. a um +aooa ete a...+s amrn WWI anm awn MAIM aamn aa�s aax+s aam MONS awn au,ro aaan it • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday, March 13, 2015 12:40 PM To: AK, OPS FS1 OSM;AK, OPS FS1 Facility OIL; AK, OPS FS1 Field OTL;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-02 (PTD #1750520) MIT-IA Passed Post SSSV Changeout Attachments: image001.png; image002.png;Injector NGI-02 (PTD#1750520) 03-13-15 TIO Plot.docx All, Injector NGI-02 (PTD#1750520) passed a MIT-IA to 2500 psi on 03/13/2015 after resetting the subsurface safety valve. The passing test confirms two competent barriers in the wellbore. The well is reclassified as Operable. • A SSSV is required for injection • A copy of the TIO plot has been included for reference Please let me know if you have any questions or concerns. Thank you, Whitney Pettus SCANNED (Alternate:Kevin Parks) SCANNED f� '` 1 6 BP Alaska-Well Integrity Coordinator GW G;ot•.,1 Wells O'g.r izat,on WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com fromLAK, D&C Well Integrity Coordinator Sent: Tues aay—, Febrawry 17, 2015 1:14 PM To: AK, OPS FS1 OSM; AK,'OPS 1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations ad; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; AK, OPS FS1 GAS INJ OPERATOR; Morrison, Spencer, ri .wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordi�;--4K, D&C Projects Well Integrity Engineer; 'jim.regg@alaska.gov'; AK, OPS FF Well Ops Comp Rep Subject: UNDER EVALUATION: Injector NGI-02 (PTD #1750520) Inner Annulus Repressurization All, 1 Injector NGI-02 (PTD#1750520)TIO Plot Well MG. JO(S NI -111-11 flee . o< -•-000A -05 -a laa • (2t-..S ...a•S S:1l r• OVA 13 'J30'�1S Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, February 17, 2015 1:14 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;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: UNDER EVALUATION:Injector NGI-02 (PTD#1750520)Inner Annulus Repressurization Attachments: image001.png;Injector NGI-02 (PTD#1750520)TIO Plot.docx All, Gas Injector NGI-02 (PTD#1750520) has begun to exhibit tubing by inner annulus communication. It is suspected the communication is occurring through a control line at the SSSV.The well has been reclassified as Under Evaluation and placed on a 28 day clock for additional diagnostics. Plan Forward: 1. Slickline: Changout MCX 2. DHD: Perform MIT-IA to confirm annulus integrity has been restored 3. WIE/APE:Additional diagnostics as needed A copy of the TIO plot have been included for reference. Please call with any questions. Thank you, �►C.1�x+"'E� �u t4? 'ire a� r Kevin Parks ,Afire is;u 1_au t Climet BP Alaska-Well Integrity Coordinator G\IVGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com 1 • Injector NGI-02 (PTD#1750520)TIO Plot Well NU-02 TM -III-IA zax -•-a 00A +000A On OCC _... a _ - -- - -''— sa-tsar---•. 2-2'27.1 11.2'5.14 1205'14 12'1.14 12!20'!4 11177;14 01,11'5 011015 Or 1'15 0124,15 0111.15 02.9715 0214.'15 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWeIIIntegrityCoordinator@bp.com> Sent: Sunday, October 19, 2014 2:58 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility 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; Farinez, Javier; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Regg, James B (DOA); AK, OPS FF Well Ops Comp Rep Subject: OPERABLE: Injector NGI-02 (PTD #1750520) TxIA mitigated through wellwork Attachments: image001.png; image003jpg M Injector NGI-02 (PTD #1750520) has had successful wellwork performed mitigating tubing by inner annulus communication at the sub -surface safety valve (SSSV) nipple. The SSSV was reset with swell fix packing after competent barriers were demonstrated with a passing MIT -IA was performed on October 08, 2014. The well has been monitored for the past week, with stable pressure trends. At this time the well has been reclassified as Operable, and may remain online as needed. Please call with any questions. Thank you, Laurie Climer BP Alaska - Well Integrity Coordinator G 1I M G ooa Will Is Ot9ani2al:-011 WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@BP.com SCApNEp OCT 2 3 2014, i t.. From: AK, D&C Well Integrity Coordinator Sent: Friday, er 03, 2014 5:28 PM To: AK, OPS FS1 OSM; , PS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lea D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB Eas ells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; AK, OPS FS1 GAS INJ OPERATOR; Farinez, Javier; 'chris. ce@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D ell Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; jim.regg@alaska.gov'; AK, OPS FF Well Ops Comp Rep Subject: UNDER EVALUATION: Injector NGI-02 (PTD #175 0) Inner Annulus Repressurization All, Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, October 07, 2014 12:56 PM To: Wallace, Chris D (DOA) Cc: Regg, James B (DOA) Subject: FW: UNDER EVALUATION: Injector NGI-02 (PTD #1750520) Inner Annulus Repressurization Attachments: image001.png; Injector NGI-02 (PTD #1750520) TIO Plot.docx Chris, The updated TIO plot showing the inner annulus repressurization on NGI-02 is attached. The well remains shut in, a dummy subsurface safety valve has been set and the inner annulus repressurization has stopped. We are currently on the well with an eline unit for secure. Thank you, Jack Disbrow BP Alaska - Well Integrity Coordinator GWGlobal Wells Organization Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@bp.com SCANNED OCT 2 3 2014 From: AK, D&C Well Integrity Coordinator Sent: Friday, October 03, 2014 5:28 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility 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; Farinez, Javier; '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 Subject: UNDER EVALUATION: Injector NGI-02 (PTD #1750520) Inner Annulus Repressurization All, Injector NGI-02 (PTD #1750520) is exhibiting inner annulus repressurization, but did not exceeded MOASP. The repressurization began on 10/03/2014, and the rate is too great to manage within MOASP limits. The well must be shut in until the source of the communication can be determined. The well is reclassified as Under Evaluation and is placed on a 28 day clock. Do not place well on injection without Well Integrity Coordinator approval. Plan forward: 1. Operations: Shut in well 2. DHD: Obtain inner annulus fluid level and bleed to zero 3. APE: Evaluate subsurface safety valve changeout A copy of the TIO plot is included for reference. Please note that the TIO plot does not reflect the bleeds that took place today, once the TIO data is current a separate TIO plot will be sent out. Thank you, Jack Disbrow BP Alaska - Well Integrity Coordinator GWGlobal wens Organization Office: 907.659.5102 WIC Email: AKDCWelllntearityCoordinator@bp.com 4 X 3 ON, 2 O Injector NGI-02 (PTD #1750520) TIO Plot Well: MGM �- Tbq t bl �- OA OOA �- 0 O On Regg, James B (DOA) 175o,ZC, From: AK, D&C Well Integrity Coordinator <AKDCWeIIIntegrityCoordinator@bp.com>,/ - �� 9l t�f Sent: Tuesday, September 09, 2014 1:01 PM 14 I To: AK, OPS FS1 OSM; AK, OPS FS1 Facility 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; Farinez, Javier; 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-02 (PTD #1750520) MIT -IA Passed Post SSSV Reset Attachments: Injector NGI-02 (PTD #1750520) Wellbore Schematic.pdf, MIT PBU NGI-02 09-06-14.xls; Injector NGI-02 (PTD #1750520) TIO Plot.docx W Injector NGI-02 (PTD #1750520) passed a MIT -IA to 2500 psi on 09/06/2014 after resetting the subsurface safety valve. The passing test confirms two competentarriers 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, wellbore schematic, and TIO plot are included for reference. Thank you, • BP Alaska - Well Integrity Coordinator Global '4r ells Or anizalior Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@bp.com sED OCT 2 8 2Ot4, From: AK, D&C Well Integrity Coordinator Sent: Saturday, August 30, 2014 12:11 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility 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; Farinez, Javier; 'chris.wallace@alaska.gov'; 'jim.regg@alaska.gov'; Redmond, Randy Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; AK, D&C Projects Well Integrity Engineer Subject: UNDER EVALUATION: Injector NGI-02 (PTD #1750520) Exhibiting TxIA Communication 01 Gas Injector NGI-02 (PTD #1750520) has begun to exhibit tubing by inner annulus communication. It is suspected the communication is occurring through a control line at the SSSV. At this time, the well has been reclassified as Under Evaluation for additional diagnostics. The well is currently shut in for proration, and DHD will be onsite for well monitoring prior to intervention work. Plan Forward: 1. Slickline: Changout MCX 2. Fullbore: Perform MIT -IA to confirm annulus integrity has been restored 3. WIE/APE: Additional diagnostics as needed A copy of the wellbore schematic, TIO and Injection plots have been included for reference. Please call with any questions. Thank you, Laurie Climer Nlternate: luck Disbrow) BP Alaska - Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWellintegrityCoordinator@BP.com 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reggftalaska.gov AOGCC.Inspectors(cbalaska.gov; phoebe.brooksoalaska.gov chris.wallaceftalaska.gov OPERATOR: BP Exploration (Alaska), Inc. I AFIELD / UNIT / PAD: Prudhoe Bay/PBU/NGI / t DATE: 09/06/14 OPERATOR REP: Jack Disbrow AOGCC REP: TYPE INJ 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 Form 10-426 (Revised 11/2012) MIT PBU NGI-02 09-06-14.xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance 0 = Other (describe in notes) No Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NGI-02 Type Inj. I G TVD 7,289' Tubing 3,540 3,573 3,552 3,573 1 Interval O P.T.D. 1750520 I Type test I P Test psi 1822.25 Casing 2,515 ' 2,524 2,497 2,461 P/F F Notes: MIT -IA OA 95 99 98 98 Well NGI-02 I Type Inj. I G TVD 7,289' Tubing 3,539 3,539 31541 3,551 Interval p P.T.D. 1750520 I Type test I P " Test psi 1822.25 Casing 2,454 2,525 2,502 2,486 1 P/F I P Notes: MIT -IA OA 99 99 100 99 Well I Tye Inj. TVD Tubing Interval P.T.D. I Type test I Test psi Casing P/F Notes: OA Well I Type Inj. I TVD I Tubing Interval P.T.D. I I Type test Test psi Casing P/F Notes: OA Well Type In'. I I TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ 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 Form 10-426 (Revised 11/2012) MIT PBU NGI-02 09-06-14.xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance 0 = Other (describe in notes) No Injector NGI-02 (PTD #1750520) TIO Plot Well: NGWV 4.000 —0 — Tb9 —f— IA 2.000 — A OA OOA —♦— OOOA On 1.000 tet_ --- 06'14114 0671114 0629/14 07!05/14 07;12114 07119114 07'26'14 W02114 0&0914 0&1614 0&23:14 08r30t14 09!06+14 TREE = 6=3/8" CIW WELLHEAD GRAY ACTUATOR= KB. R EV BKR BF. REV= ? KOP = 3000' Max Angle = Datum MD = Datum TVD = 56 @_5300' 11328' 8800' SS 13-3/8" CSG, 72#, MN -80, ID = 12.347" I 2688' 7" TBG -NPC, 29#, L-80_0371 bpf, ID = 6.184" — TOP OF 5-1/2" TBG -NPC —9 Minimum ID = 4.455" @ 9321' 5-1/2" OTIS XN NIPPLE 1 5-1/2" TBG -NPC, 17#, L-80_0232 bpf, ID = 4.892" TOP OF 7" LNR 1—� 9538' 9-5/8" CSG, 47#, MN -80, ID = 8.681" PERFORATION SUMMARY REF LOG: BHCS ON 11/07/75 ANGLE AT TOP PERF: 37 @ 10308' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 10308- 10358 O 06/28/90 3-3/8" 4 10414 - 10512 O 05/03/87 3-3/8" 4 10527- 10690 O 05/03/87 3-3/8" 4 10715- 10732 O 03/08177 3-3/8" 4 10748 - 10785 O 03/08/77 3-3/8" 4 10839 - 10849 O 03/08/77 3-3/8" 4 10858 - 10878 O 03/08/77 PBTD 10911' 7" LNR, 29#, N-80, .0371 bpf, ID = 6.184" 11000' NGI-02 SAFETY NOTES: WELL REQUIRES A SSSV. 2202' 1--17" OTIS RPB SSSV NIP, ID = 5.963" E 9285' —�r'9305'O2 II 9321' 5-1/2" OTIS XN NIP, ID = 4.455" 9329' 9-5/8" X 5-1/2" BAKER FB -1 PKR 934V ELMD TT LOGGED 05/03/87 10710' 1--1 FILL (MD) 5/3/87 DATE REV BY COMMENTS DATE REV BY COMMENTS 11/20/75 ORIGINAL COMPLETION 11/24/78 LAST WORKOVER 01/10/02 RN/TP CORRECTIONS 01/02/05 WSH/TLP ADD SAFETY NOTE 06/23/07 JDM/PJC I SFTY NOTE CORRECTION 6/18/07 02/11/11 MB/JMD I ADDED SSSV SAFETY NOTE PRUDHOE BAY UNIT WELL: NGI-02 PERMIT No: 1750520 A PI No: 50-029-20174-00 SEC 12, T11 N, R1 4E, 3618.72' FEL & 1361.08' FNL BP Exploration (Alaska) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, August 30, 2014 12:11 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility 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; Farinez, Javier; Wallace, Chris D (DOA); Regg, James B (DOA); Redmond, Randy Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; AK, D&C Projects Well Integrity Engineer Subject: UNDER EVALUATION: Injector NGI-02 (PTD #17SOS20) Exhibiting TxIA Communication Attachments: image003.jpg; NGI-02 TIO -Injection Plotd 08-30-14.docx; NGI-02 Wellbore Schematic.pdf All, Gas Injector NGI-02 (PTD #1750520) has begun to exhibit tubing by inner annulus communication. It is suspected the communication is occurring through a control line at the SSSV. At this time, the well has been reclassified as Under Evaluation for additional diagnostics. The well is currently shut in for proration, and DHD will be onsite for well monitoring prior to intervention work. Plan Forward: 1. Slickline: Changout MCX 2. Fullbore: Perform MIT -IA to confirm annulus integrity has been restored WIE/APE: Additional diagnostics as needed A copy of the wellbore schematic, TIO and Injection plots have been included for reference. Please call with any questions. Thank you, Laurie Climer NEV (.i%;E�rrtirt�: JuckL)i�(�rurrl BP Alaska - Well Integrity Coordinator GWJ� f Gk)baI WoIIs r organizat+on WIC Office: 907.659.5102 WIC Email: AKDCWelllntesrityCoordinator@BP.com Injector NGI-02 (PTD #1750520) 2014 OW 3 000 MKII 1,000 90 Day TIO Plot W.1: MGM 3.80' 3.60 3A0 3.20 3.00 2.60 2.60 1.40 2.20 aF 2.00 S 1.80 1.60 1.40 120 1,O0 80 60 40 20 90 day Injection Plot W.a: MGM August 30, —1-- Tbg t 1A �— OA OOA �— OOOA — 0n Im 90,000 J17°OD° 160000 150000 140,000 130 000 110000 110.000 100.000 _ Y&W — A4 —pW 90.000 80.000 — GI — 01. 20.000 On 60.000 50 000 40.000 30.000 20,000 10 000 08"30'14 TREE = 6-3/8" CIW WELLHEAD = GRAY ACTUATOR= KB. ELEV = BKR 47' BF. ELFV = ---- KOP = - --- 3000' Max Angle Datum MD = 11328' Datum TV D = 8800' SS 13-3/8" CSG, 72#, MN -80, ID = 12.347" I 2688' 7" TBG -NPC, 29#, L-80_0371 bpf, ID = 6.184" —C TOP OF 5-1/2" --92 Minimum ID = 4.455" @ 9321' 5-1/2" OTIS XN NIPPLE 1 5-1/2" TBG -NPC, 17#, L-80_0232 bpf, ID = 4.892" 1 TOP OF 7" LNR 1-A 9538' 9-5/8" CSG, 47#, MN -80, ID = 8.681" I 9830' PERFORATION SUMMARY REF LOG: BHCS ON 11/07/75 ANGLE AT TOP PERF: 37 @ 10308' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 10308- 10358 O 06/28/90 3-3/8" 4 10414 - 10512 O 05/03/87 3-3/8" 4 10527 - 10690 O 05/03/87 3-3/8" 4 10715 - 10732 O 03/08/77 3-3/8" 4 10748 - 10785 O 03/08/77 3-3/8" 4 10839 - 10849 O 03/08/77 3-3/8" 4 10858 - 10878 O 03/08/77 PBTD 10911' 7" LNR, 29#, N-80, .0371 bpf, ID = 6.184" 11000' SAFETY NOTES: WELL REQUIRES A SSS V. NGI-02 2202' 1--17" OTIS RPB SSSV NIP, ID = 5.963" w — 9285' 9305' 5-1/2" OTIS XA SLD SLV, ID = II 9321' –15-1/2" OTIS XN NIP, ID =4.455" 9329'9-5/8" X 5-1/2" BAKER FB -1 PKR 9341' ELMD TT LOGGED 05/03/87 10710' 1--1 FILL (MD) 5/3/87 DATE REV BY COMMENTS DATE REV BY COMMENTS 11/20/75 ORIGINAL COMPLETION 11/24/78 LAST WORKOVER 01/10/02 RN/TP CORRECTIONS 01/02/05 WSH/TLP ADD SAFETY NOTE 06/23/07 JDM/PJC SFTY NOTE CORRECTION 6/18/07 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE PRUDHOE BAY UNIT WELL: NGI-02 PERMIT No: 1750520 API No: 50-029-20174-00 SEC 12, T11N, R14E, 3618.72' FEL & 1361.08' FNL BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, July 25, 2014 TO: Jim Regg � . . P.I. Supervisor (1G�� yz SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-02 FROM: Johnnie Hill PRUDHOE BAY UNIT NGI-02 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-02 API Well Number 50-029-20174-00-00 Inspector Name: Johnnie Hill Permit Number: 175-052-0 Inspection Date: 7/6/2014 Insp Num: mitJWH140706162545 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min NGI-02 Type Inj G- TVD 7289 IA 76 2514 2506 _ 2513 2515 17505210 . Type Test' SPT Test psi 1122 OA 124 123 125 126 126 , YRTST p/F r i Tubing 3366 3365 3366 336E 3366 I Notes: 2.75 bbls meth used SCANNED OCT 3 0 2014 Friday, July 25, 2014 Page I of 1 STATE OF ALASKA AKA OIL AND GAS CONSERVATION COMMOION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well [_f Plug Perforations [J Perforate [] Other[✓J Tubing Wash Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdowr0 Stimulate - Other ❑ Re -enter Suspended Well] 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development Exploratory ❑ 175 -052 -0 3. Address: P.O. Box 196612 Stratigraphic0 Service El 6. API Number: Anchorage, AK 99519 -6612 50- 029- 20174 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028302 PBU NGI -02 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 11002 feet Plugs measured None feet true vertical 8593.57 feet Junk measured None feet Effective Depth measured 10911 feet Packer measured 9329 feet true vertical 8518.26 feet true vertical 7288.89 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 94# H-40 31 -111 31 - 111 1530 520 Surface 2658 13 -3/8" 72# MN -80 30 - 2688 30 - 2687.99 5380 2670 Intermediate None None None None None None Production 9801 9 -5/8" 47# MN -80 29 - 9830 29 - 7656.63 6870 4760 Liner 1462 7" 29# N -80 9538 - 11000 7439.02 - 8591.92 8160 7020 Perforation depth Measured depth See Attachment feet SCANNED �� 1 RECEIVE D True Vertical depth See Attachment feet o rV 9 2012 I Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment AO f 3CQ Packers and SSSV (type, measured and true vertical depth) 5 -1/2" Baker FB -1 Packer 9329 7288.89 Packer Est �J None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions 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 75622 0 0 3493 Subsequent to operation: 0 181799 0 0 3279 14. Attachments: 15. Well Class after work: ,� Copies of Logs and Surveys Run Exploratorj❑ Development ❑ Service ISI Stratigraphic 0 Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas D WdSPLIJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ In SUSP ❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -295 Contact Nita Summerhays Email Nita.SummerhaysaBP.com . Printed Name Ni - Su merhay 1 Title Petrotechnical Data Technician Sig - . =ate fj/ rtf , - " 'i f , f _ Phone 564 -4035 Date 10/8/2012 1. F r(4(/ y REIDMS OCT 10 201 1)// Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0028302 ACTIVITYDATE SUMMARY _ 1= .11 - II .1 emp= : was '1c e soven rea men 'umpe• m o .g • •• me spear, 107 bbls 50/50 diesel /xylene mix, 721 bbls fresh water with 0.02% F -103 surfactant, followed 9/14/2012 by a 10 bbl meth cap. FWHP's= Vac/180/118. FLUIDS PUMPED BBLS 108 DIESEL/XYLENE 50/50 • 19 METH 721 FRESH WATER WITH 0.02% F -103 SURFACTANT 848 TOTAL • Perforation Attachment ADL0028302 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base NGI -02 6/28/1990 APF 10308 10358 8027.49 8067.28 NGI -02 3/8/1977 PER 10414 10439 8111.88 8131.83 NGI -02 5/3/1987 APF 10439 10458 8131.83 8147.02 NGI -02 3/8/1977 PER 10458 10478 8147.02 8163.04 NGI -02 5/3/1987 APF 10478 10492 8163.04 8174.28 NGI -02 3/8/1977 PER 10492 10512 8174.28 8190.35 NGI -02 3/8/1977 PER 10527 10547 8202.42 8218.56 • NGI -02 5/3/1987 APF 10547 10563 8218.56 8231.5 NGI -02 3/8/1977 PER 10563 10583 8231.5 8247.71 NGI -02 5/3/1987 APF 10583 10598 8247.71 8259.89 NGI -02 3/8/1977 PER 10598 10628 8259.89 8284.33 NGI -02 5/3/1987 APF 10628 10643 8284.33 8296.58 NGI -02 3/8/1977 PER 10643 10673 8296.58 8321.15 NGI -02 5/3/1987 APF 10673 10690 8321.15 8335.12 NGI -02 3/8/1977 PER 10715 10732 8355.71 8369.73 NGI -02 3/8/1977 PER 10748 10785 8382.94 8413.53 NGI -02 3/8/1977 PER 10839 10849 8458.32 8466.63 NGI -02 3/8/1977 PER 10858 10878 8474.11 8490.76 SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • Casing / Tubing Attachment ADLOO283O2 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 94# H -40 31 - 111 31 - 111 1530 520 LINER 1462 7" 29# N -80 9538 - 11000 7439.02 - 8591.92 8160 7020 PRODUCTION 9801 9 -5/8" 47# MN -80 29 - 9830 29 - 7656.63 6870 4760 SURFACE 2658 13 -3/8" 72# MN -80 30 - 2688 30 - 2687.99 5380 2670 TUBING 9257 7" 29# L -80 28 - 9285 28 - 7257.66 8160 7020 TUBING 56 5 -1/2" 17# MN -80 9285 - 9341 7257.66 - 7297.42 7740 6280 • IC I 411 TREE = 6 -3/8" CIW • WELLHEAD = GRAY NGI-02 S NOTES: WELL REQUIRES A SSSV. ACTUATOR = BKR KB. ELEV = 47' BF. ELEV = ? KOP = 3000' Max Angle = 56 @ 5300' 1 2202' H 7" OTIS RPB SSSV NIP, ID = 5.963" I Datum MD = 11328' Datum TVD = 8800' SS 13 -3/8" CSG, 72 #, MN-80, ID = 12.347" H 2688' I 17" TBG -NPC, 29 #, L -80, .0371 bpf, ID = 6.184" I 9285' I / 9 285 7" X 5 -1 /2" XO ITOPOF5- 1 /2 "TBG -NPC H 9285' 9305' H5-1/2" OTIS XA SLD SLV, ID = 1 1 Minimum ID = 4.455" @ 9321' I I 5 -1/2" OTIS XN NIPPLE 93 —1 5 -1 /2" OTIS XN NIP, ID = 4.455" I 1 5-1/2" TBG -NPC, 17 #, L -80, .0232 bpf, ID= 4.892" H 9329' I 9329' 1-19-5/8" X 5 -1/2" BAKER FB -1 PKR I 1 \ ( 9341' H ELMD TT LOGGED 05/03/87 I TOP OF 7" LNR I 9538' J 19 -5/8" CSG, 47 #, MN-80, ID = 8.681" H I 9830' I • ■ PERFORATION SUMMARY 1 REF LOG: BHCS ON 11/07/75 ANGLE AT TOP PERF: 37 @ 10308' I Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE I 3-3/8" 4 10308 - 10358 0 06/28/90 3 -3/8" 4 10414 - 10512 0 05/03/87 3 -3/8" 4 10527 - 10690 0 05/03/87 I 3 -3/8" 4 10715 - 10732 0 03/08/77 3 -3/8" 4 10748 - 10785 0 03/08/77 3 -3/8" 4 10839 - 10849 0 03/08/77 I 10710' I-I FILL (MD) 5/3/871 3 -3/8" 4 10858 - 10878 0 03/08/77 I I PBTD H 10911' I 00.4 17" LNR, 29 #, N -80, .0371 bpf, ID = 6.184" H 11000' I taco* DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/20/75 ORIGINAL COMPLETION WELL: NGI-02 11/24/78 LAST WORKOVER PERMIT No: 1750520 01/10/02 RN/TP CORRECTIONS API No: 50- 029 - 20174 -00 01/02/05 WSH/TLP ADD SAFETY NOTE SEC 12, T11 N, R14E, 3618.72' FEL & 1361.08' FNL 06/23/07 JDM/PJC SFTY NOTE CORRECTION 6/18/07 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE I BP Exploration (Alaska) • • co, SEAN PARNELL, GOVERNOR ----,-) /,:[LASEL ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATI ON COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Javier Farinez Petroleum AANNED A LI U Z l IZ BP Exploration (Alaska), Inc. P.O.Box196612 5-0 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU NGI -02 Sundry Number: 312-295 Dear Mr. Farinez: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy " . Foerster Chair DATED this !/ day of August, 2012. Encl. s ;i,p.1 RECEIVED STATE OF ALASKA AUG 0 01 ALASKA OIL AND GAS CONSERVATION COMMISSION ,�--S Z /a APPLICATION FOR SUNDRY APPROVALS AOGC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program El Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ v Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Water Wash o 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 175 -052 -0 • 3. Address: Stratigraphic ❑ Service El 6. API Number: P.O. Box 196612, Anchorage, AK 99519 -6612 50 -029- 20174 -00 -00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 1111 PBU NGI -02 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0028302' PRUDHOE BAY, PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11002 ` 8594 • 10911 8518 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 94# H -40 31 - 111 31 - 111 Surface 2658 13 -3/8" 72# MN -80 30 - 2688 30 - 2687.99 5380 2670 Intermediate None None None None None None Production 9801 9 -5/8" 47# MN -80 29 - 9830 29 - 7656.63 6870 4760 Liner 1462 7" 29# N -80 9538 - 11000 7439.02 - 8591.92 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: 5 -1/2" Baker FB -1 Packer Packers and SSSV MD (ft) and TVD (ft): 9329, 7288.89 No SSSV Installed No SSSV Installed 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch n Exploratory ❑ Development ❑ Service 0 • 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ Q — WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoin. • true and correct to the best of my knowledge. Contact Javier Farinez Prepared by Garry Catron 564 -4424 Printed Name Javier F: - Title q 41,5)/ 2 , k Z Signature /I� Phone Date 564 -5043 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: . `2 , '? V 15 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: 1 0 -14 O t/ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 8... . 2___/ - 2_ Form 10-403 Revised 1/2010 r= • ; ? in Duplicate l ic ate 1.2'4 AUG 0 3 t o Z p RIGINAI ck Casing Summary ADL0028302 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse Grade CONDUCTOR 80 20" 94# H-40 31 111 31 111 1530 520 H -40 LINER 1462 7" 29# N -80 9538 11000 7439 8592 8160 7020 N -80 PRODUCTION 9801 9 -5/8" 47# MN -80 29 9830 29 7657 6870 4760 MN -80 SURFACE 2658 13 -3/8" 72# MN -80 30 2688 30 2688 5380 2670 MN -80 TUBING 9257 7" 29# L -80 28 9285 28 7258 8160 7020 L -80 TUBING 56 5 -1/2" 17# MN -80 9285 9341 7258 7297 7740 6280 MN -80 • • • • Perforation Attachment ADL0028302 Well Date Perf Code MD Top MD Base TVD Top TVD Base NGI -02 6/28/90 APF 10308 10358 8027 8067 NGI -02 3/8/77 PER 10414 10439 8112 8132 NGI -02 5/3/87 APF 10439 10458 8132 8147 NGI -02 3/8/77 PER 10458 10478 8147 8163 NGI -02 5/3/87 APF 10478 10492 8163 8174 NGI -02 3/8/77 PER 10492 10512 8174 8190 NGI -02 3/8/77 PER 10527 10547 8202 8219 NGI -02 5/3/87 APF 10547 10563 8219 8232 NGI -02 3/8/77 PER 10563 10583 8232 8248 NGI -02 5/3/87 APF 10583 10598 8248 8260 NGI -02 3/8/77 PER 10598 10628 8260 8284 NGI -02 5/3/87 APF 10628 10643 8284 8297 NGI -02 3/8/77 PER 10643 10673 8297 8321 NGI -02 5/3/87 APF 10673 10690 8321 8335 NGI -02 3/8/77 PER 10715 10732 8356 8370 NGI -02 3/8/77 PER 10748 10785 8383 8414 NGI -02 3/8/77 PER 10839 10849 8458 8467 NGI -02 ' 3/8/77 PER 10858 10878 8474 8491 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED 1 RPF REPERF j I Fullbore Pumping Design Template Well Nam NGI -02 Job Scope Solvent Treatment No Samples Reporter H2S (ppm /date) WBL Cat IOR Max Pumping Pressure (psi). When fluids reach 500 ger Well Type GI AFE APBINJEC Main Fluid Type Date 7/30/2012 IOR 30 700 Main Fluid Volume (bbls) Engineer Javier Farinez Phone x5043 Methanol (60/40) Freeze Protect Type 10 Freeze Protect Volume (bbls) Job " Objective 1 • If Applicable Recent Tbg Fluid Level (ft) Improve injectivity by dissolving salts and possibly asphaltenes in the If Applicable Recent IA Fluid Level (ft) tubing and formation. Diesel /Xylene washes have been used If Applicable Recent OA Fluid Level (ft) successfully in the past on the NGI/WGI /AGI gas injectors to improve 393 Expected Tbg Fill Up Volume (bbls) injectivity. If Applicable Expected IA Fill Up Volume (bbls) If Applicable Expected OA Fill Up Volume (bbls) 393 Wellbore Volume to Perfs (bbls) Fullbore Pumping Schedule 3300 Anticipated Bottom Hole Pressure (psi) Select 1 Tubing /Casing within Pressure Limits? Stage Fluid Type Pump Volume Rate Max Into (bbls) (bpm) Pressure Size Pressure (psi) 80% (psi) Tubing Burst (psi) 5.5 7740 6192 I Pre -Flush I Methanol (60/40) 11 Tbg 101 I 25001 Tubing Collapse (psi) 5.5 6290 5032 Casing Burst (psi) 7 8160 6528 I Solvent 1 1 Select Fluid Type I Tbg I 100 I I 25001 Casing Collapse (psi) 7 7030 5624 1 Load 1 1 Select Fluid Type 11 Tbg 1 I 700 I I 5001 Select Input Depth Integrity Issues? TxIA SSSV nipple 1 Freeze Protect 1 1 Methanol (60/40) 1 Tbg I 10 1 I I I 5001 • No Input Depth Select Stage 11 Select Fluid Type 11 Select 1 1 1 1 1 I I No Tubing Caliper? Burst/Collapse ratings may need to be derated based on tubing condition I Yes Production Packer within Pressure Limits? Detailed Pumping Procedure Rated Packer dp Max Anticipated dp at Packer 1 10 bbls 60/40 meoh spear 2 100 bbls 50/50 diesel /xylene I Not Necessary 1 Hold Pressure on Other Strings? 3 700 bbls of fresh water with 0.02% F -103 surfactant Tubing (psi) 4 10 bbls 60/40 meoh IA (psi) 5 RDMO. Return well to gas injection OA (psi) 6 • • Well Name NGI -02 Job Scope Solvent Treatment Well Type GI AFE APBINJEC Date 7/30/2012 IOR 30 Engineer Javier Farinez Phone x5043 H2S No Samples Reported � � ; - -� v, / ,fob fJbje� � =`='� Improve injectivity by dissolving salts and possibly asphaltenes in the tubing and formation. Diesel /Xylene washes have been used successfully in the past on the NGUWGI /AGI gas injectors to improve injectivity. F ullbore P umpin ® r Stage Fluid Type Pump Into Volume (bbls) Rate (bpm) Max Pressure 1 Pre -Flush Methanol (60/40) I 1 Tbg I 10 1 1 I 2500 2 Solvent I Select Fluid Type I Tbg 100 1 I 1 2500 3 I Load I I Select Fluid Type 1 Tbg 700 I 500 4 'Freeze Protect Methanol (60/40) 1 1 Tbg I I 10 1 I 500 I 5 I Select Stage I Select Fluid Type I Select I 1 2. Detailed Pumping Pro( 1 10 bbls 60/40 meoh spear 2 100 bbls 50/50 diesel /xylene 3 700 bbls of fresh water with 0.02% F -103 surfactant 4 10 bbls 60/40 meoh 5 RDMO. Return well to gas injection 6 Add itional Deta If Applicable Recent Tbg Fluid Level (ft) Integrity Issues? TxIA SSSV nipple If Applicable Recent IA Fluid Level (ft) No Input Depth If Applicable Recent OA Fluid Level (ft) • • Freeze Protection - see PE manual for additional information Freeze Protect to 2500' TVD in GPB. Use 60/40 Meth Water for Injectors Use 5 bbl 60/40 Meth Water spear followed by dead crude for Producers Pipe Data (L -80) dimensions mechanical inner capacity outer capacity • size lb /ft od id drift id collapse burst bbls /ft ft/bbls bbis /ft ft/bbls 2.375 4.60 2.38 2.00 1.90 11780.00 11200.00 0.00387 258.6 0.00548 182.5 2.875 6.50 2.88 2.44 2.35 11160.00 10570.00 0.00579 172.8 0.00803 124.5 3.188 6.40 3.19 2.81 2.68 11111.00 11111.00 0.00769 130.1 0.00987 101.3 3.500 9.30 3.50 2.99 2.87 10530.00 10160.00 0.00870 115.0 0.01190 84.0 4.500 12.60 4.50 3.96 3.83 7500.00 8430.00 0.01522 65.7 0.01967 50.8 5.000 18.00 5.00 4.28 4.15 10490.00 9910.00 0.01776 56.3 0.02429 41.2 5.500 17.00 5.50 4.89 4.77 6280.00 7740.00 0 02325 43.0 0.02939 34.0 7.000 26.00 7.00 6.28 6.15 5410.00 7240.00 0.03826 26.1 0.04760 21.0 7 000 29.00 7.00 6.18 6.06 7020.00 8160.00 0.03715 26.9 0.04760 21.0 7.625 29.70 7.63 6.88 6.75 4790.00 6890.00 0.04592 21.8 0.05648 17.7 9.625 47.00 9.63 8.68 8.53 4760.00 6870.00 0.07321 13.7 0.08999 11.1 13.375 72.00 13.38 12.35 12.19 2670.00 _ 5380.00 0.14809 6.8 0.17378 5.8 custom 6.000 4.000 0.01561 64.1 0.03497 28.6 Bursts OD GRADE WT Burst 3 1/2" 80 9.3# 10160 4 1/2" 80 12.6# 7500 5 1/2" 80 15.5# 7000 80 17# 7740 7" 80 26# 7240 80 29# 8160 95 29# 9690 110 29# 11220 7 5/8" 80 29.7# 6890 80 33.7# 7900 95 29.7# 8180 9 5/8" 55 36# 3520 55 40# 3950 80 40# 5750 80 43.5# 6330 80 47# 6870 80 53.5# 7930 95 47# 8150 10 3/4" 55 45.5# 3580 80 45.5# 5190 80 55.5# 6450 11 3/4" 95 60# 6920 13 3/8" 55 54.5# 2730 55 61# 3090 55 68# 3450 80 68# 5020 80 72# 5380 95 72# 6390 16" 80 84# 4330 18 5/8" 55 96.5# 2510 55 109.3# 2910 20" 40 94# 1530 55 133# 3060 Brine Design Notes Revised: 5/1/00 NaCI KCI CaCI NaBr Design Notes: 8.5 29 8.4 31 8.5 30 8.5 30 8.6 27 8.5 30 9.0 22 9.0 25 Design for -50 degrees from surface to 100', 10 degrees through permafrost (approx. 2500'). 8.7 26 8.7 27 9.5 10 9.5 20 Be careful using McOH /H2H for freeze cap - McOH may mix with brine and dilute 8.8 24 8.9 23 10.0 -9 10.0 14 Don't use Ca based fluids that may come in contact with the formation. 8.9 22 9.1 19 10.5 -36 10.5 6 Be careful using CaCI in IA - may dump on formation 9.0 19 9.3 15 10.7 -51 11.0 -2 Corrosion Inhibitor: mix 25 gal of NEEC EC1124 per 100 bbls brine 9.1 17 9.5 15 10.8 -57 11.5 -11 Note: Inhibitor has a 1 day half -life 9.2 14 9.6 33 10.9 -35 11.7 -16 Be careful allowing very cold diesel to contact KCI - could form a slush • 9.3 11 11.0 -19 11.8 -19 9.4 9 11.5 36 11.9 -10 9.5 6 12.0 6 9.6 3 12.5 50 9.7 -1 12.7 63 9.8 -5 9.9 5 10.0 25 Crystallization Temperatures for Clear Brines 40 ACaCI e KCI * NaCI / 20 j ••. 'o / `� _ • o / 'NaBr F. / • \ -20 ■ N - --- - NaCI ■� -r- CaCI \ ,./ --in- KCI -60 - o NaBr 8.5 9 .5 Density, PPG 10 .5 11.5 - -- 12.5 ` TREE = ' 6 -3/8" CM/ WELLHEAD = GRAY • SC NOTES: WELL REQUIRES A SSSV. ACTUATOR = BKR IN G1-.02 KB. ELEV = 47' BF. ELEV = ? KOP = 3000' Max Angle = 56 @ 5300' I 2202' IH 7" OTIS RPB SSSV NIP, ID = 5.963" I Datum MD = 11328' Datum TVD = 8800' SS 113 -3/8" CSG, 72 #, MN -80, ID = 12.347" I—I 2688' I 17" TBG -NPC, 29 #, L -80, .0371 bpf, ID = 6.184" I-1 9285' I / I 9285' HT X 5 -112" X01 I TOP OF 5 -1/2" TBG -NPC H 9285' I 9305' 1-15-1/2" OTIS XA SLD SLV, ID =?I Minimum ID = 4.455" @ 9321' I I 5 -1/2" OTIS XN NIPPLE 9321' J 1 5 -1/2" OTIS XN NIP, ID = 4.455" I 15 -1/2" TBG -NPC, 17 #, L -80, .0232 bpf, ID = 4.892" H 9329' I X L 9329' I -19 -5/8" X 5 -1/2" BAKER FB -1 PKR I / I I 9341' I-1 ELMD TT LOGGED 05/03/87 I TOP OF 7" LNR I 9538' I 19 -5/8" CSG, 47 #, MN-80, ID = 8.681" H 9830' I A ■ PERFORATION SUMMARY I REF LOG: BHCS ON 11/07/75 ANGLE AT TOP PERF: 37 @ 10308' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 4 10308 - 10358 0 06/28/90 3 -3/8" 4 10414 - 10512 0 05/03/87 3 -3/8" 4 10527 - 10690 0 05/03/87 3 -3/8" 4 10715 - 10732 0 03/08/77 3 -3/8" 4 10748 - 10785 0 03/08/77 3 -3/8" 4 10839 - 10849 0 03/08/77 10710' I-I FILL (MD) 5/3/87 I 3 -3/8" 4 10858 - 10878 0 03/08/77 PBTD 10911' I *004 17" LNR, 29 #, N -80, .0371 bpf, ID = 6.184" H 11000' I 0.0.0' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/20/75 ORIGINAL COMPLETION WELL: NGI-02 11/24/78 LAST WORKOVER PERMIT No: 1750520 01/10/02 RN /TP CORRECTIONS API No: 50- 029 - 20174 -00 01/02/05 WSH /TLP ADD SAFETY NOTE SEC 12, T11N, R14E, 3618.72' FEL & 1361.08' FNL 06/23/07 JDM/PJC SFTY NOTE CORRECTION 6/18/07 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE 1 BP Exploration (Alaska) MEMORANDUM TO: Jim Regg P.I. Supervisor ~~~ 7'Z"?'Ip FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 27, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-02 PRUDHOE BAY UNIT NGI-02 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Sgt Comm Well Name: PRUDHOE BAY UNIT NGI-02 Insp Num: mitJCr100722052131 Rel Insp Num: API Well Number: SO-029-20174-00-00 permit Number: 1.75-052-0 Inspector Name: John Crisp Inspection Date: 7/21/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NGI-oz' Type Inj. G " TVD 7259 IA soo 2soo za9o ~ 2s2o - zs2o P.T.D I~soszo' TypeTest SPT Test psi Iazz OA Iao Iao Iao Iao Iao InterVal4YRTST p~F P ~ Tubing 3000 3000 3000 3000 3000 Notes: 6.2 bbls pumped for test. Witnessed test for 45 minutes due to increased IA pressure. - -:.~C-N ~~~1'~~ Tuesday, July 27, 2010 Page 1 of 1 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg~alaska.gov; phcebe.brooks@a.gov; tom.maur~er@1a~lca.gov; doa.aogcc.prudhce.bay~alaska.gov OPERATOR: BP Exploration (Alaska), lnc. FIELD /UNIT /PAD: Prudhoe Bay /PBU /NGI Pad DATE: 0721/10 OPERATOR REP: Torin Roschinger AOGCC REP: John Crisp s Packer Pretest Ini6a1 15 Min. 30 Min. Well NGI-02 T In'. G TVD 7,289' T 3,000 3,000 3,000 3,000 Interval 4 P.T.D. 1750520 T test P Test 1822.25 500 2,500 2,490 2,520 P/F P Notes: AOGCG MIT-IA to 2500 psi for 4 year tl1C OA 130 440 140 140 45 minute results: T~000 I-2520 0.1 ~ Pum 2 bbd MEOH to achieve test i Well NGt-09 T In"" G TVD 7,492' Tubi 3,500 3,500 3,SOD 3,500 Interval 4 P.T.D. 1760680 T test P Test 1873 340 2,500 2,520 2,520 P/F P Notes: AOGCC MIT-IA to 2500 psi for 4 year UIC OA 20 20 20 20 45 minute results: T-3500 I-2520 0.20 Well NGI-14 T In". G TVD 7,264' T 3,550 3,550 3,550 3,450 Interval 4 P.T.D. 1780920 T best P Test 1816 340 2,500 2,430 2,420 P/F P Notes: AOGCC MIT-IA to 2500 psi for 4 year UIC OA 340 1,240 1,360 1,440 Well T In'. TVD T Interval P.T.D. T test Test C P/F Notes: OA Well T In . TVD T Interval P.T.D. T test Test Casi P/F Notes: OA TYPE INJ Codes TYPE TEST Codes I! D =Drilling Waste M =Annulus FAoniEoring ¢., `~11'~I~~-- } " ~• I '~ ~° j ter? ~~ , .s a]., ....- , r"1 ~ as ~ ~ G =Gas P =Standard Pressure Test I =Industrial Wastewater R = Intemal Radioactive Tracer Survey N =Not Injecting A =Temperature Anomaly Survey W =Water D = Dilrerenfia! Temperature Test f~~~a ~-~"(~ '° g<a INTERVAL Codes I = Infial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (descrit~e in notes) MIT Report Form BFL 11/27/07 MIT PBU NGI-02, 09, 14 07-21-10.x1s NGI &LPC injector due for UIC ~ng • Page 1 of 2 Maunder, Thomas E (DOA) From: AK, RES GPB East Production Optimization Engineer [AKRESGPBEastProductionOptimizationEngineer@bp.com] Sent: Tuesday, July 13, 2010 8:32 AM To: Maunder, Thomas E (DOA) Subject: RE: NGI &LPC injector due for UIC testing Hello Tiffany, I assume these are the plants the State is referring to. I would take these dates as best estimates. GC1 is online now. LPC 7/14 startup GC1 Online as of 7/10 CGF Shut-down 7/15 - 8/6 Byron Jackson (alt. Ryan Rupert) GPB East Production Optimization Engineer .,~~~,~~ ~.f~~' ~ "] ~~~~~ 907.659.5923 office x2409 harmony AK, RES GPB East Production Optimization Engineer From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, July 13, 2010 8:25 AM To: AK, D&C Well Integrity Coordinator Cc: AK, RES GPB East Production Optimization Engineer; Brooks, Phoebe L (DOA) Subject: RE: NGI &LPC injector due for UIC testing Thanks Tiffany. What is the anticipated schedule for bringing the plants back on line? Tom Maunder, PE AOGCC From: AK, D&C Well Integrity Coordinator [mailto:AKDCWeIIIntegrityCoordinator@bp.com] Sent: Monday, July 12, 2010 7:34 PM To: Maunder, Thomas E (DOA); AK, D&C Well Integrity Coordinator Cc: AK, RES GPB East Production Optimization Engineer Subject: NGI &LPC injector due for UIC testing Thomas, Per our conversation, the following injectors are due for UIC compliance testing and shut in due to facility work. The wells will be put back on injection as the plants are brought back on line. Once thermally stable, we will proceed with AOGCC witnessed MIT-IA's. There are no known downhole integrity issues with any of these injectors. NGI Gas Injectors: ` GI-02 (PTD #1750520 ~~ NGI-09 (PTD #1760680) NGI-14 (PTD #1780920) 7/13/2010 NGI &LPC injector due for UIC ~ng ~ Page 2 of 2 LPC SWI injector: P1-21 (PTD #1930590) Please contact Well Integrity with any questions or concerns. Thank you, Tiffany Quy (for the Well Integrity Coordinator Gerald Murphy/Torin Roschinger) Projects Well Integrity Engineer phone: (907) 659-5102 cell: (253) 576-6153 tiffg0@bp.com 7/13/2010 UNDER EVALUATION: NGI-02~TD #1750520) IA Repressurization post SSSV change out Regg, James B (DOA) Page 1 of 2 From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, January 05, 2009 9:37 PM ~ '~ (2t?c7 To: Regg, James B (DOA); Maunder, Thomas E (DOA) ~ ~ 4 f Cc: NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: NGI-02 (PTD #1750520) IA Repressurization post SSSV change out Attachments: NGI-02 TIO 01-05-09.ZIP Jim and Tom, Well NGi-02 {PTD #1750520} has been monitored daily since the change out on the SSSV. During this time the IA pressure has remained under 200 psi and shown minimal to no signs of IA reoressurization. Provided below is an updated TIO plot for this timeframe. I believe that this well's IA repressurization has been mitigated and can be reclassified as Operable. If you agree I will make the proper notifications. «NGI-02 TIO 01-05-09.ZIP» Thank you, Taylor Wellman filling in for Anna DubelAndrea Hughes Office: 659-5102 Pager: 659-5104 x 1154 From: NSU, ADW Well Integrity Engineer Sent: Monday, December 29, 2008 8:21 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Subject: FW: UNDER EVALUATION: NGI-02 (PTD #1750520) IA Repressurization Jim, ~,~~~~r J~ii~i ~~ EK 20Q~ The SSSV was changed out on well NGI-02 (PTD #1750520} on 12!27/08. We will continue to monitor the pressures for approximately 7 days to determine if the repair attempt was a success. Please let me know if you have any questions. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Tuesday, December 23, 2008 9:35 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FSl OTL; GPB, FSS DS Ops Lead; Rossberg, R 1 /7/2009 UNDER EVALUATION: NGI-02~TD #1750520} IA Repressurizationpnst SSSV change out Page 2 of 2 • Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, EOC Specialists Cc: Quy, Tiffany; Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: NGI-02 (PTD #1750520) IA Repressurization All, Well NGI-02 (PTD #1750520) is exhibiting slow IA repressurization. This well has a history of a compromised control line and IA repressurization. The wellhead pressures were bled from 3450/1800/110 psi on 11/16/08. The well has been reclassified as Under Evaluation and the plan is to pull and reset the SSSV. The plan forward is: 1. S: Pull and reset SSSV 2. D: Monitor IA repressurization 3. WIC: Eval for AA A wellbore matic and TIO pl'ot~ "have been included for reference. ~ Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 1 /7/2009 PBU NGI-02 PTD 175-052 1 /5/2009 TIO Pressures 12 Month Plot '~/'~i " ~ ~~.'~~1I'~I~yi~~ ~• .r ~ I! I ~ ~ JI ~~ ~ 1 Month Plot ~~: j ~ ~ / / ~ L __.__... ~ j ,` ,...__._ --~- -~ I IYD X f _~ -f' _.~'' ~__~.~ _i__..-.. _.i.. .. _..^ ...._ _..- _..._-.- f~ -......_ ..__ -T--••----.- ~r 1:+16+^.8 ~2,v6~,iF !L'I6'l6 ..~.n~ ii, ,i..R .?.rd's 1+•NlB IJ:~Vi to^LR ~~ 3.x. 'f E N.Th.iq .. + reu ~ u -~ w ow aow ;. o, ~~ • u -~ w ow oaw ~ o~ FW: UNDER EVALUATION: NGI-02 (PTD #1750520) IA Repressurization Page 1 i ~ Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] t~l ~ I r Sent: Monday, December 29, 2008 8:21 AM I CL~ To: Regg, James B (DOA); Maunder, Thomas E (DOA) Subject: FW: UNDER EVALUATION: NGI-02 (PTD #1750520) IA Repressurization Jim, The SSSV was changed out on well NGI-02 {PTD #17505 0 on 12/27108. We will continue to monitor the pressures for approximately 7 days to determine if the repair attempt was a success. Please iet me know if you have any questions. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~- From: NSU, ADW Well Integrity Engineer Sent: Tuesday, December 23, 2008 9:35 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FSl OTL; GPB, DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, EOC Specialists Cc: Quy, Tiffany; Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: NGI-02 (PTD #1750520) IA Repressurization AI I, We(I NGI-02 (PTD #1750520) is exhibiting slow IA repressur tion. This well has a history of a compromised control line and IA repressurization. The wellhead pressures were bl from 3450/1800/110 psi on 11/16/08. The well has been reclassified as Under Evaluation and the plan is to pull nd reset the SSSV. The plan forward is: 1. S: Pull and reset SSSV 2. D: Monitor IA repressurization 3. WIC: Eval for AA A wellbore schematic and TI~DIot have been included for reference. Please call with ~(y questions or concerns. 12/29/2008 UNDER EVALUATION: NGI-02 (PTD #1750520) IA Repressurization Page 1 of 3 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Wednesday, December 24, 2008 1:20 PM ~ ~ J To: Regg, James B (DOA) ' lP~ ~ I `"I~'~ I~'~°~ Cc: Maunder, Thomas E (DOA); NSU, ADW Well Integrity Engineer Subject: RE: UNDER EVALUATION: NGI-02 (PTD #1750520) IA Repressurization Jim, We have recently re-written our internal Well Integrity Policy and are currently training the Operators. Our plan is to meet with you early next year to share this document in its entirety. Below is some of the verbiage from the document meant to address this very issue.... The Drill Site/Pad Operators and Well Tenders are responsible for immediately reporting to the Well Integrity Coordinator any well that exceeds MOASP pressure limits or has indications of tubing/annular communication to ensure timely notification to the AOGCC. The Well Integrity Coordinator is responsible for ensuring reported wells are evaluated and appropriately categorized, and an appropriate action plan is developed and implemented, including regulatory agency notification. and Injection wells that exhibit an increase in annulus pressure, tracking pressures, or sustained casing pressure (SCP) require timely notification to the AOGCC as required by AOGCC Area Injection Orders. To meet this requirement, the Drill Site/Pad Operator or Well Tender shall immediately notify the Well Integrity Coordinator of any well integrity concerns on an injector so that the proper notification can be made to the AOGCC. Injection wells with pressure communication may be required to have AOGCC Administrative Approval for continued operation as described in section 8.3.4, Wells Requiring AOGCC Approval. and For Injection Wells Regulations are more stringent for injection wells than for producers. Immediately report any injection well with the below characteristics to the Well Integrity Coordinator and document in the Field Logbook or other designated log. • Any indication of pressure communication between the tubing, packer, and annuli. • All annular bleeds performed on injection wells, other than to manage temperature changes. Document if gas, fluid, or natural gas liquids (NGL) are returned during bleed. A significant change in IA pressure and/or OA pressure. An increasing trend in IA pressure and/or OA pressure. NOTE: It is a BPXA well integrity recommended practice to keep at least a 100 psi differential between the IA and OA 12/29/2008 UNDER EVALUATION: NGI-O TD #1750520) IA Repressurization Page 2 of 3 • pressure on injectors. • Wells unable to maintain a 250 psi pressure differential between the tubing and IA pressure on injection wells. NOTE: Maintaining at least a 250 psi pressure differential is a BPXA well integrity required practice intended to assist in identifying potential pressure communication or leakage of any casing or tubing. Due to the difficulty of maintaining the pressure differential on low pressure wells, this is not required if the well injection pressure is 500 psi or less. Please let me know if you have any questions. Thank you, Andrea Hughes From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, December 24, 2008 11:19 AM To: NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA) Subject: RE: UNDER EVALUATION: NGI-02 (PTD #1750520) IA Repressurization It appears NGI-02 is being operated out of campliance with AIO 4E by not notifying the Commission of the repressurization that was evident much earlier {clearly there is repressurization in the iA in October until bled on or about November 15). This has been a point of discussian between AOGCC and BPXA in the past and appears to be a direct result of BPXA's internal policies of allowing pressure in IA up to 2000psi and OA up to 1000psi {following the pressure notification triggers set in Conservation Order 492 for all wells). That stategy is, however, in conflict with AOGCC requirements which do not establish an allowable pressure for the IA and OA in injection wei#s except when set in an administrative approval specific to the weli. Please review your annulus pressure notification triggers and make sure they are consistent with AOGCC requirements. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Tuesday, December 23, 2008 9:35 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; GPB, EOC Specialists Cc: Quy, Tiffany; Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer 12/29/2008 UNDER EVALUATION: NGI-02 (PTD #1750520) IA Repressurization Page 3 of 3 • • Subject: UNDER EVALUATION:. NGI-02 (PTD #1750520) IA Repressurization All, Well NGI-02 (PTD #1750520) is exhibiting slow IA repressurization. This well has a history of a compromised control line and IA repressurization. The wellhead pressures were bled from 3450/1800/110 psi on 11/16/08. The well has been reclassified as Under Evaluation and the plan is to pull and reset the SSSV. The plan forward is: 1. S: Pull and reset SSSV 2. D: Monitor IA repressurization 3. WIC: Eval for AA A wellbore schematic and TIO plot have been included for reference. «NGI-02 TIO and Injection Plot.doc» «NGI-02.pdf» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 12/29/2008 • NGI-02 TIO Plot 4 ~x~ a pmt a z x~ 1 A00 NGI-02 Injection Plot __ 3,OM 3,6M J,1Qi 3,200 3,M0 2,BM ?.600 4110 22M 2At10 ~ 1,FM 1,6M 1,41k1 1,2M 1,000 BM 6l>ll dM 2M ,u~a~ 1 MR~I 12~i,Mo ttn,~ 1 m.~ 9Q OM OO MO~-~ 0 ?U.MU 60 CA'ti KO,~i fl0.M0 00.E 20.OM i 0.~ -a- rn~ -f w -+- oa oon ooon -~ On -WHIP - SW - PW MI GI - ONix -~- On o~~tns 1o~aroe 1wn;os 1ona,~ t0,~.~ tt/01/OB nroetoe nnsroe t,mroe tv2v~o6 12/061118 tut;ros 12120/Od ~ I _.__-~_______ _.~___.___._m___,_._.._____.__..__J ro~2?~o6 taoarua to!n;~ t~ns~ tanuros ttro~.~ nroeroe nn5~ t1n2ro2 tine.~e ,%xp;,~s ta.-~+~ t~~u:rs TREE = 6-3l8" CM! WELLHEAD = GRAY ACTUATOR= SKR KB. ELEV = 47' BF. ELEV _ .__ ......... KOP 3000' Max Angle= Datum MD = 56 @ 5300' 11328' Datum TV D = 8800' SS 13-3l8" CSG, 72#, MN-80, ID = 12.347" ~--~ 268$ ~- 7" TBG-NPG, 29#, L-80, .0371 bpf, ID = 6.184" 92$5' TOP OF 5-1/2" TBG-NPC 92$5 Minimum ID = 4.455" @ 9321' 5-112" OTIS XN NIPPLE ~ 5-112" TBG-NPC, 17#, L-8Q .0232 bpf, ID = 4.892" 0-{ 9329' TOP OF 7" LNR I-I 953$` 9-5;8°' CSG, 47#, MN-80, ID = 8.681" ~ 9$30' PERFORATION SUMMARY REF LOG: BHCS ON 11/07175 ANGLE AT TOP PERF: 37 @ 10308' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/5qz DATE 3-3l8" 4 10308 - 10358 O 06/28190 3-318" 4 10414 - 10512 O 05/03/87 3-318" 4 10527 - 10690 O 05/03/87 3-3i8" 4 10715 - 10732 O 03/08(77 3-3/8" 4 10748 - 10785 O 03/08177 3-318" 4 10839 - 10849 O 03/08/77 3-3i8" 4 10858 - 10878 O 03;08177 PBTD 10911 7" LNR, 29#, N-80, .0371 bpf, ID = 6.184" 11000' 9321' -15-1I2" OTIS XN NIP, ID = 4.455" 9329' 9-5/8" X 5-1/2" BAKER FB-1 PKR 934 ELMD TT LOGGED 05/03(87 10710' ~--)FILL (MD) 5/3/87 DATE REV BY COMMENTS DATE REV BY COfIRMENTS 11124/75 ORIGINAL COMPLETION 1112417$ LAST WORKOV ER 01/10!02 RNlTP CORRECTIONS 01/42105 VVSHITLP ADD SAFETY NOTE 06/23107 JDM/PJC SFTY NOTE CORRECTION 6;18107 PRUDHOE BAY UNCC WELL: NGI-02 PERMTf No: 1750520 API Na: 50-029-20174-00 SEC 12, T11 N, R14E, 3618.72' FEL & 1361.08' FNL BP Explanation {Alaska) 2202' x-17" OTIS RPB SSSV NIP, !D = 5.963" -~ 92$51-17" X 5-112" XO I I 930"$' S-1/2" OTIS XA SLD SLV, ID = NGI-02 (PTD #1750520) OPERABLE - No further IA repressurization ~ Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~ ~ ~-~~~(~g Sent: Saturday, April 19, 2008 1:02 PM To: NSU, ADW Well Integrity Engineer; 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 Cc: Townsend, S. Eliot; NSU, ADW WI Tech Subject: NGI-02 (PTD #1750520) OPERABLE - No further IA repressurization Attachments: NGI-02 TIO plot.BMP AI1. ~ ~ ~~ Well NGI-02 (PTD #1750520} has had the pulled and reset. After monitoring the Weilhead pressures for a week, it appears that the IA repressurization has been mitigated with this weir intervention. The wail has been reclassified as Operable. ~~ MAY ~ 200 From: NSU, ADW Well Integrity Engineer - Sent: Monday, April 07, 2008 11:03 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FSl OTL; GPB, FSl DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor Cc: NSU, ADW Well Integrity Engineer; Winslow, Jack L.; NSU, ADW WI Tech Subject: NGI-02 (PTD #1750520) IA Repressurization -UNDER EVALUATION All, Well NGI-02 (PTD #1750520) has slow IA re ressurization. This well has a history of a compromised control line and IA repressurization. The wellhead pressures were 3510/1170/80 psi when we had DHD perform a bleed on 04/05/08. We are currently quantifying the IA repressurization with the further intention of replacina the SSSV. The plan forward is: 1. D: Monitor IAP BUR 2. S: Troubleshoot the SSSV A wellbore schematic and TIO plot have been included for reference. « File: NGI-02.pdf» « File: NGI-02 TIO PIot.BMP » The well has been reclassified as Under Evaluation. Please call with any questions or concerns. Thank you, 4/29/2008 NGI-02 (PTD #1750520) OPERABLE - No further IA repressurization Andrea Hughes • Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 • Page 2 of 2 4/29/2008 ~~~ I Zou~ J'~ a,ooa a,ooa ~,ooo 1,000 PJ~I~~ TIc7 Plot.. ix nn~~s~ rJ~t h4fi,fi~.SF ~- Tb~ 1 rrr2oos 1 r~2rzoaa 2A6~2a08 ~rz1 X1008 3fTl~oos 3t~2~0o8 ~~~2008 ~t22120as a~- ~~. -fir OA OOA 000 II ~,ooo 3,000 N~I-02 TIC Plot # Tbr.~ -~- IA 2,000 I.'a hd,4.~s, -ir OA 1,000 OA hA~.~,~F ~ n sr~oos 2r~rzoos 2!1 arzoo$ 3~4~20os 3~1 srzoos ~~3~aa8 ^ are 9008 s~~,~oo$ ~~ JBF= OOA ~00~ TREE = 6-318" CNV WELLNEAD= GRAY ACTUATOR.= BKR KB. ELEV - BF. ELEV _~ 47' ~ KOP = 3000' _ Max Angle = 56 @ 5300' Datum MD = 11328' Datum TV D = 8800' SS i 13-318" CSG, 72#, MN-80, ID = 12.347" ~~--) 2688' ~- TBG-NPC, 29#; L-80, .0371 bpf, ID = 6.184" 92$5' TOP OF 5-1(2"TBG-NPC 9285' Mlt11!'11l11'Ti I®_ ~.Q~rJJ" @ 9321' 5-102" OTIS XN NIPPLE 5-112" TBG-NPC, 17#, L-80, .0232 bpf, ID = 4.892" TOP OF 7" LNR 9-518" CSG, 47#, MN-80; ID = 8.681„ PERFORATION SUMMARY REF LOG: BNCS ON 11107/75 ANGLE AT TOP PERF: 37 ;~ 1030$' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OprZlSgr DATE 3-3r'8" 4 10308 - 10358 0 06/28/90 3-318" 4 10414 - 10512 0 05(03!87 3-318" 4 10527 - 10690 0 05?03187 3-318" 4 10715 - 10732 0 03!08/77 3-318" 4 10748 - 10785 0 03(08!77 3-318" 4 10839 - 10849 0 0310$!77 3-318" 4 10$58 - 10878 O 03108!77 PBTD 7" LNR, 29#, N-80..0371 bpf, ID = 6.184" NGI-02 ~.J 2202° ~-{ 7" OTIS RPi6 SSSV NIP, ID = 5.963" 928 5' J-~ 7" X 5-1/2" XC) 9305' 5-1f2°` OTIS XA SLD SLV, ID 9321' -~ 5-112" OTIS XN NIP, ID = 4.455" 9329' 9°518" X 5-162" BAKER FB-1 PKR 9341' ~ ELMD TT LOGGED 05103!87 10710' '--~ FILL {MD} 513187 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDNOE BAY UNtF 11!20175 ORIGINAL CC3MPLEi'ION WELL: NGI-02 11124!78 LAST WOF2KpVER PERMt1~ No:1750520 01110/02 RNlTP CORRECTIONS API Na: 50-029-20174-00 01/02/05 WSI-IITLP ADD SAFETY NOTE SEC 12, T11 N, R14E, 3618.72' FEL & 1361.08' FNL 06.23.-07 JDMIPJC SFTY NOTE CORRECTION 6118!07 SP Explaraiian (Alaska} NGI-02 (PTD #1750520) TxIA C~unication Page 1 of 2 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Tuesday, October 02, 2007 1:05 PM 1 To: Regg, James B (DOA); NSU, ADW Well Integrity Engineer ~~~ ~~lAl~7 Cc: Maunder, Thomas E (DOA); Hughes, Andrea; Engel, Harry R ~'1 Subject: RE: NGI-02 (PTD #1750520) TxIA Communication Jim - ~f We are presently working on a system to flag any injection well which has an IA that breaks 1000 psi. In this same rollout will be a flag for any bleed event on an injector. Thank you - Jack L. Winslow {for Anna Dube) Well Integrity Engineer office - 659-5102 pager - 659-5100, 1154 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, October 01, 2007 7:50 AM To: NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA); Hughes, Andrea; Engel, Harry R Subject: RE: NGI-02 (PTD #1750520) TxIA Communication You reference a "set limit" regarding IA perssures; what is it? Jim Regg Aoccc ~~~~~~~ N~V ~. 3 2007 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Friday, September 28, 2007 6:50 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); Hughes, Andrea; Engel, Harry R Subject: RE: NGI-02 (PTD #1750520) TxIA Communication i Jim. Although ,ve communicate with operations that any indication of potential integrity concerns or high annulus pressure needs to be reported to us in Well Integrity, we are aware that this does not happen consistently. To help us better identify potential integrity concerns on injectors, we are working on reports to highlight injectors with bleeds and injectors with lA pressure over a set limit. Please !et us know if you have any additional concerns. Thank you, 7`t 68' ~. ell Integrity Gcaordinator 10/4/2007 NGI-02 (PTD #1750520) TxIA C~unication Page 2 of 2 GPB ells Group • Phone: (sg73 ss-1f32 Pager: (907) 659-5100 x1154 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, September 19, 2007 1:25 PM To: NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA) Subject: RE: NGI-02 (PTD #1750520) TxIA Communication What would normally trigger bleeding annulus pressure? Using this well as an example, it appears to me that you are using the 2000psi criteria from CO 492 (remember that is for producing wells only). 1 would have expected diagnostics and notification much earlier in the pressure build up in NGI-02. Jim Regg AOGCC 333 W.7th Avenue, Suite 10fl Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Friday, September 07, 2007 4:00 PM To: GPB, Area Mgr North (Gas Plants/GPMA); 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; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA}; Senden, Leslie B; NSU, ADW WL & Completion Supervisor; Cismoski, Doug A Cc: NSU, ADW Well Integrity Engineer; Roschinger, Torin T.; Austin, Paul A Subject: NGI-02 (PTD #1750520) TxIA Communication Hi all, Well NGI-02 (PTD #1750520) has TxIA communication represented by increasing IA pressure. This well has a history of a compromised control line and IA repressurization. The wellhead pressures were 3469/1960/120 on 09/04/07 when the operator bled the IA pressure down to 800 psi. Work to pull and reset the SSSV is currently in progress. This wel! will be tracked on the Monthly Injection report until pressure trends confirm that resetting the SSSV has mitigated the IA repressurization. The plan for ward is: 1. S: Pull and reset the SSSV - In progress A wellbore schematic and plot of wellhead pressure have been included for reference. «NGI-02.pdf» «NGI-02.BMP» Please call with any questions. 10/4/2007 TREE = 6-3/8" CMl 'WELLHEAD = GRAY ACTUATOR = BKR KB. ELEV = 47' BF. ELEV = KOP = 3000' Max Angle = 56 @ 5300' Datum MD = 11328' Datum TV D = 8800' SS L13-3P8" CSG, 72#, MN-80, ID = 12.347" ~-~ 2688' i- 7" TBG-NPC, 29#, L-80, .0371 bpf. !D = 6.184" 9285' ~TdPOF 5-112" TBG-NPC~ 92$5' Minimum IQ = 4.455" @ 9321' 5-1 /2" OTIS XN NIPPLE ~ 5-1 /2" TBG-NPC, 17#, L-80; .0232 bpf, ID = 4.892" TOP OF 7" LNR ~--~ 9538' 9-518" GSG. 47#, MN-80, ID = 8,681" ~-~ 9830 PERFORATION SUMMARY REF LOG: BHCS ON 11107/75 ANGLE AT TOP PERF: 37 @ 10308' Nate: Refer to Praductian DB far historical pert data SIZE SPF INTERVAL OpniSgz DATE 3-318" 4 10308 - 10358 O 06128(90 3-318" 4 10414 - 10512 O 05(03(87 3-3i8" 4 10527 - 10690 O 05103/87 3-318" 4 10715 - 10732 O 03(08177 3-318" 4 10748 - 10785 O 03108(77 3-3/8" 4 10$38 - 10849 O 03/08!77 3-318" 4 10858 - 10878 O 03/08/77 PBTD --L ~ 7" LNR, 29#, N-80, .0371 bpf, ID = 6.184" --~'~ NGI-02 2202' ~--~ 7" OTIS RPB SSSV NIP, ID = 5.963" 9285 T` X 5-112" xOJ 9305' 5-112" OTiS XA SLD SLV, ID = g321, ~--~ 5-1/2" OTIS XN NIP, ED = 4.455" 9329' 9-518" X 5-112" BAKER FB-1 PKR 9341' ELMD TT LOGGED 05f03/87 10710' ~--{FILL (MD) 513/87 DATE REV BY COMMENTS DATE REV BY COMfUEMS 11/20/75 ORIGINAL COMPLETIOP! 11124/78 LAST 1NORKOVER 01/10/02 RN/TP CORRECTIONS 01/02/05 WSWTLP ADD SAFETY NOTE 06!23!07 JDfiNPJC SFTY NOTE CORRECTK3N 6/18107 PRUDHOE BAY UNR- WELL: NG4-42 PERMif' No: 1750520 API No: 50-029-20174-QO SEC 12, T11 N, R14E, 3618.72' FEL & 1361.08' FNL SP Exploeafion (AVaska) ~_ wci-0a r~o Piot J -~- Tby -f- IA IA MA.ASP ~ -~ OA MAASP ~ - _ _~_ OOA 0 - T ~ OOOA 9(!!2006 11 I6f2006 1 J6C1007 3182007 Sf8/2007 7l6f2007 9/7!2007 • • .r/ MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg ~,/: 7/2"; Iv P.I. Supervisor ' -1~(' I -' ¡ ,~"'" DATE: Wednesday, July 12,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-02 PRUDHOE BAY UNIT NGI-02 11S~D~~ FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: ']13' --. " J¿-- P.I. Suprv,-..i ¡ Comm NON-CONFIDENTIAL Well Name: PRUDHOE SAY UNIT NGI-02 API Well Number 50-029-20174-00-00 Inspector Name: Jeff Jones Insp Num: miùJ060711203857 Permit Number: 175-052-0 Inspection Date: 7/8/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well! NGI-02 ¡Type Inj. i G I I I I i ! I ¡TVD 7289 IA 0 2010 2015 2020 ! 2020 i P.T. ! 1750520 iTypeTest I SPT i Test psi ! 1822,25 I OA 180 ! 250 r 260 260 I 260 I ! Interval 4YRTST P/F P Tubing i 3550 I 3550 ! 3550 3550 I 3550 I j Notes 3,4 bbls diesel pumped, 1 well house inspected; no exceptions noted, tJ l.~ .:¡ ~;j I Wednesday, July 12,2006 Page I of I ~/TREE = W!:i.LHEAD: ACTUATOR: -------,--.."---~--_...- KS, ElEV '" SF, ElEV '" KOP= Max Angle: Datum MD = Datum 1VD = ? GRAY AXElSON -.---..-.-.-...---........--. 47' ? 3000' 56 @ 5300' 1132S' SSOO' SS e NGI-02 2202' . 1 13-3/S" CSG, 72#, MN-SO, ID: 12,347" I 2688' 15-1/2" TSG-NPC, 17#, L-SO, ,0232 bpf, ID = 4,S92" I 7" TBG-NPC. 29#, L-SO, ,0371 bpf, ID: 6, 1S4" I TOP OF 5-1/2" TBG-NPC , AÆTY NOTES: THIS WELL IS A AJEL SOURCE WELL THAT REQUIRES A SURFACE- CONTROLLED SSSV -17" OTIS RPB SSSV NIP. ID = 5,963" I 9285' -f 7" X 5-1/2" XO I 9305' -f 5-1/2" OTIS XA SLIDING SL V Minimum ID = 4.455" @ 9321' 5-1/2" OTIS XN NIPPLE 9321' -f 5-112" OTIS XN NIP, ID: 4 A55" I 9329' -19-5/S" X 5-112" BAKER FB-1 PKR I 9341' -1 ElMO TT LOGGED 05/03/S7 I 1 TOP OF 7" LNR I I 9-5/S" CSG, 47#, MN-SO, ID = S,6S1" I PERFORA TION SUMMARY REF LOG: BHCS ON 11/07/75 ANGLE AT TOP PERF: 37 @ 10308' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 4 1030S - 10358 0 06/2S/90 3-3/S" 4 10414 - 10512 0 05/03/S7 3-3/S" 4 1 0527 - 1 0690 0 05/03/S7 3-3/S" 4 10715 - 10732 0 03/0S/77 3-3/8" 4 1074S - 10785 0 03/0S/77 3-3/S" 4 10839 - 10S49 0 03/0S/77 3-3/S" 4 1 OS5S - 10S7S 0 03/0S/77 PBTD I 11000' 10911' I 7" LNR, 29#, N-SO, .0371 bpf, ID = 6, 1S4" I DA TE REV BY 11/20/75 11/24/78 01/10/02 RNlTP 01/02/05 WSHITL COMMENTS COMMENTS ORIGINAL COM PLETION LAST WORKOVER CORRECTIONS ADD SAFETY NOTE DATE REV BY -i FILL (MD) 5/3/S71 PRUDHOE BA Y UNIT WElL: NGI-02 PERMIT No: 1750520 API No: 50-029-20174-00 SEC 12, T11N, R14E, 361S,72' FB.. & 1361 ,OS' FNL BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: CaTTy O Taylor ~ DATE: May 25, 2002 Chairman SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder ~~ BPX P.I. Superviso~F'J/.... ~--~ NGI-02 b(-) PBU FROM: Chuck Scheve Prudhoe Bay Petroleum Inspector NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well[ NGI-02 I TyPelnj. I G [ T.V.D. I 7289 ITubing [' 3400 I 3400 I 3400 i 3400 I lntervall 4 P.T.D.I 175-052,TypeteStl P ITestpsil 1822 i casingl 50 I 2520 Notes: 4-year MIT Well] IType Ini'I IT.V.D.I ITubingI' I ' I I I'intervall P'T'D'I ITypetestlITestpsil I Casing l' I ' I "I I PIF I Notes: WoIiJ P.T.D~I Notes: WellI P.T.D..I Notes: WellI P.T.D.I Notes: I Type Inj. I I ~.v.o. I I TUbing I'1 I I "' I lnterValJ ' ' Type testI I Test psiI I CasingI I . J I I PIF J I Type Inj. I ! ¥.V.O. II Tubing I ' I I I I lntervall TYpe. testJ ITestpsil . ICasing l 'I , I . I I PIE I 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 I traveled to BPXs NGI-02 Well and witnessed the 4-year workover MIT on this well. The pretest tubing and casing pressures were observed and found to be stable. The casing was then pressured up and observed .for 30 minutes with the well demonstrating good mechanical integrity. M.I.T.'s performed: 1_ Attachments: Number of Failures: Total Time during tests: I hour cc: MIT report form 5/12/00 L.G. MIT PBU NGI-02 5-25-02 CS.xls 6/3/02 STATE OF ALASKA ALASK~~''~. AND GAS CONSERVATION REPORT'- F SUNDRY WELL OP r" ATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 802' FNL & 1114' FWL, Sec., 12, T11N, R14E, UM At top of productive interval 1075' FNL & 990' FWL, Sec. 7, T11N, R15E, UM At effective~depth 1141' FNL & 1281' FWL, Sec. 7, T11N, R15E, UM At total depth 1155' FNL & 1325' FWL, Sec. 7, T11N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 47 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number NGI-2 (11-7-11-15) 9. Permit number/approval number 75-52/90-295 10. APl number 50 - 029-20174 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11002 feet 8567 feet Plugs(measured) 10917' - Cement feet Effective depth: measured 10730 feet true vertical 8344 feet ?±.1.]. (measured) 10730 Casing Length Size Cemented Measured depth True vertical depth Conductor 54' 20" 240 sx Permafrost II 80' 80' Surface 2662' 13-3/8" 5100 sx Permafrost II 2688' 2688' Production 9804' 9-5/8" ~ooo,x c~.., G cr= 9830' 7637' 125 sx Permafrost II, 2nd Stage Liner 1462' 7" 400 sx 9538'-11000' 7422'-8566' Perforation depth: measured 10308-10358'; 10414-10439'; 10458-10478'; 10492-10512'; 10527-10547'; 10563-10583'; 10598-10628'; 10643-10673'; 10715-10732'; 10748-10785';10839-10849'; 10858-10878' true vertiCal 8003-8044'; 8090-8110'; 8125-8141'; 8152-8168'; 8180-8196'; 8209-8225'; 8238-8262'; 8274-8298'; 8332'-8346'; 8359-8389'; 8434-8442'; 8449-8465' Tubing (size, grade, and measured depth) 7", 29#, L-80, ABM 8rd to 9285' MD 5-1/2", 17#, L-80, ABM 8rd @ 9285-9329' MD Packers and SSSV (type and measured depth) 9-5/8"x7" Baker FB-1 Packer @ 9329' MD/Otis SSSV @ 2202' MD ~q, I-, ,~,'", I" I ! I !?~ i~ 13. Stimulation or cement squeeze summary ~ Intervals treated(measured) OCT 2 9 1990 Treatment description including volumes used and final pressure '-~laska 0JJ & Gas Cons, · Reoresentative Daily Averaoe Production or Injection Data Prior to well operation Subsequent to operation OiI-Bbl Gas-Md Water-Bbl Casing Pressure ~'ubin~ ?~'essu~'e - - 21 OM .... 3900 - 220M .... 3900 14. 16. Status of well classification as: ., Oil ~ Gas Suspended Service Gas Injection 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations SUBMIT IN DUPLICATE 17. I hereby certify th.a.t~he foregoing is true and correct to the best of my knowledge. Signed Title Senior Area E, ngineer Form 10~04 Re; 06/15/88 - ~ NGI-2 Work Summary On June 28, 1990 the following perforations were added in Well NGI-2. Interval, MD (BHCS 11/07/75) Interval Length Formation Name SPF 10308-10358' 50' Sag River 4 STATE OF ALASKA ALA,.~. ,A OIL AND GAS cONSERVATION COb, ~ of Welt O~L E~ G~S [~ REVISED* susPENDED [~ ABANDONED [~ SERVICE AddreSS su~ce 802' FNL, 1114' FWL, SEC 12, TllN, R14E UM At Top Producing Interval 1259' FNL, 963' FWL, SEC 7, TllN, R15E UM* At Total Depth etc.) .TVO) 10917' MD/8521' TVD 11002' MD/8591' TVD . Pun *LOCATIONS cHANGED DUE TO GYRO sURVEYS BEING RERUN. Comp., 19 Directional Survey Number 4/ Name pRUDHOE BAY FIELD PRUDHOE BAY OIL poOL Depth where sssV set 2225' feet lad offshore 1 teet ThickneSS of perm~tfrost 1900' (approX) 24 Perforatior'~ open to Production (MD+t'VD of T(~p and Bottom and interval, size and number) 10414,-10512'MD/8110"8189"rVD W/4 SPF 10527'.10690'MD/8201"8333'TVD W/4 sPF 10715,.10732,MD/8353,.8368q-VD W/4 SPF 10748,_10785'MD/8381"8412q'VD W/4 sPF 10839,.10849'MO/8456"8465'TVD W/4 sPF 0858,.10878'MD/8472"8489"TVD W/4 SPF ~te First production Tested o! Test 24 oCT. PreSSure · Tubing . of Operation (F~owing, gas tilt, etc.) ACI N/A NIA NIA RECEIVED NONE Form 10-407 Rev. 7.1.80 OCT o 9 ]990 · ::~s~ Oil& Gas Cons. C~mmissi~ PERFORA~'ED WELL 3/13/77. RECOMPLETED WELL 11127/78. ADDITIONAL PERFORATIO~~ cONtINUED ON REVERSE SIDE NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH .TRUE VERT. DEPTH GOR, and lime of each phase. TOP SADLEROCHIT 10409' 8106' BASE SADLEROCHIT 10947' 8546' N/A 31. LIST OF ATTACHMENTS REVISED GYROSCOPIC SURVEY (2 COPIES) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~.-~,flm/iL~ ~.~./, . Title DRILLINGANA, J=YST Date Signed INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item-5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such 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 ARCO ALA~'KA, INC P.O. BOX ANCHORAGE~ ALA~'KA 995~ DA TE · '7-'7--96, REFERENCE' ARCO CA3'ED HOLE F'INALi.'.' xi (;; I - i 6 - o ,::, ,:.-.:,,.-:; N G I -2 6 - '28 - 96' NC.; I--~; 6- 29- 9,:'-) N (; I - 4 6 - 13 9 -- 9 ¢ NE]; .... 6 6-5¢-9¢ NE l-'7 7- i -9(-} N (.'-;. 1-8 7--i - 9¢ N(; :r..-,:~ '"' ',..-. ',-, :3 NC;I .... iO 7-4-96' COLLAR/PERF' COLLAR/F'ERF COLLAR/PEF;,'F COLLAR/F'ERF: C'OLI. AR/PERF COLLAR/PERF COL. LAR/PERF C 0 L L A R / P E R F"' COI. LAR/F'ERF RUN i , ..,"t' F;: U N, i ...,~" ' RUN t, 5" RUN i, 15' RLJN i , .; RUN i, 5' F.'.U N i , ..,.";"" i:;,'UN i, .5" RUN i , .,.~;'" HAVE A NICE DAY! ;~ALL. Y HOFFECKER ATO- i 529 L 1 0 1990 _ , · Gas Cons. ~cho~ge iT: A N 2' :. 9 (~2";~ A 'f' I.. A.'::.' A i I._A,? A 'f' 1... A ,!i: a'f'LAZ r:-~ 'f' L. A.~;: A'f'L A A 'FLA;~¢ A'f LA;g' A 'FL.A~.~ DISTRIBUTION ~ CF'NTRAt_ F' II_ELq ,,.~" CHEVRON. . . DaM · .i'-. E X T' E N 3' i 0 N. E,.F'X'" t_ORATION_ . · $ EXXON NARATFtON :~ MOBIL F'HILLIF'~ F'B WELL F'ILE~ R & D BPX ~TATE OF AI_A~KA TEXACO ALASK''~ AND GAS CONSERVATION APPLIC riON FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend -- Operation shutdown -- Re-enter suspended well Alter camng Repair well , Plugging Time extension Stimulate Change approved program, Pull tubing Variance Perforate X, 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 802' FNL & 1114' FWL, Sec. 12, T11 N, R14E, UM At top of productive interval 1075' FNL & 990' FWL, Sec. 7, T11N, R15E, UM At effective depth 1141' FNL & 1281' FWL, Sec. 7, T11N, R15E, UM At total depth 1155' FNL & 1325' FWL, Sec. 7, T11 N, R15E, UM 6. Datum of elevation(DF or KB) 47 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number NGI-2 (11--7-11-15) 9. Permit number 75-52 10. APl number 50 - 029-20174 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11002 feet 8567 feet Plugs(measured) 10917' - Cement RECEIVEP Effective depth: measured 10917 feet ~¥ 0 ~ ]990 true vertical 8497 feet Junk(measured) None Alaska 0ii & {~as Cons. Coml~lJ~J Casing Length Size Cemented Measured depth J~l[d3~ical depth Conductor 54' 20" 240 sx Permafrost II 80' 80' Surface 2662' 13-3/8" 5100 sx Permafrost II 2688' 2688' Production 9804' 9-5/8" ~0oo sx c~ G Cn~ 9830' 7637' 125 sx Permafrost II, 2nd Stage Liner 1462' 7" 400 sx 9538'-11000' 7422'-8566' Perforation depth: measured 10414-10439'; 10458-10478'; 10492-10512'; 10527-10547'; 10563-10583'; 10598-10628'; 10643-10673'; 10715-10732'; 10748-10785'; 10839-10849'; 10858-10878' true vertical 8090-8110'; 8125-8141'; 8152-8168'; 8180-8196'; 8209-8225'; 8238-8262'; 8274-8298'; 8332'-8346'; 8359-8389'; 8434-8442'; 8449~8465 Tubing (size, grade, and measured depth) 7", 29#, L-80, ABM 8rd to 9285' MD 5-1/2", 17#, L-80 ABM 8rd @ 9285-9329' MD Packers and SSSV (type and measured depth) 9-5/8" x 7" Baker FB-1 Packer @ 9329' MD/Otis SSSV @ 2202' MD 13. Attachments Description summary of proposal x 14. Estimated date for commencing operation May, 1990 16. If proposal was verbally approved Name of approver Date approved Detailed operations program I15. Status of well classification as: Oil... Gas Suspended Service gas injection well BOP sketch x 17. I hereby.certify that the foregoing is true and correct to the best of my knowledge. Signed .~z;~'~~'~x.~~'/_~~_ ~.- Title Operations Engineering Manager FOR COMMISSION H.~I= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Original Signed By David W. Johnston Approved by order of the Commissioner Commissioner Date ¢/~' ~'/~.,~ IAppr°val N°' Form 10-403 Rev 06/15/88 Approveci Cgpy SUBMIT IN TRIPLICATE NGI-2 Proposed Additional Perforations ARCO Alaska, Inc. proposes to add perforations in Well NGI-2. The proposed perforation intervals are as follows: Interval, MD Interval, MD Interval Formation (BHCS 11/7/75) (Tie-in) Length Name 1029G 10308' 1029G1~' 18' Put River 10308-10~8' 10308-10358' 50' Sag River 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 the wellbore loaded with sea water. After perforating, gas injection will resume with the wellbore load fluid being displaced into the wellbore formation. No flaring is anticipated. ARCO RASED Hnl..F FINAl.. £01 I AP/F'FrRFRPATTON It. RI lAS' ¢ F'Ar]KFF-,,") r]131_l.AS' rt.r'l[ I.. AR/F'F. RFI'IRTTnN r't. 01 ..I.. AR'/PERFOR"AT .T ON C.f]!.. !. AR/F'FRFRR'ATT ON £FII..I AR/PERFFIRAT.T AN C. RI...I. AR'/P FRF'RR'AT T Cf]l...I... AR/PERFOR'AT T. ON F't.N[ 1~ AR'/F'ER'FNR'ATTI]NI Crl. I...I..A R / F' .F. RFI3R' AT T ON CR! .I.. AR'/PFR'FI'IRA T T OI',J COl.I A R / F' Fi F,' g l'"!R' A T .T. f'l i',,I C. OI... i .AR/PFRFRR'ATTON ~ L,J F. I - ,?.. 5-25-97 RRI..I...AR' / P ER F f!F.'A T .T F1N -'"" bJ .f., T. -4 5-25-87.: $'ECEI' ED BY/ ....... _,~,___ ' ~ ::._ '~'__L_ , t .... d · H~ ~ E A N .T CE ~~ - ~d:~rage . F' .F.'. ~ C.. Y BENNETT ATO- ~ 5'~° .. ,~:.. · APPROVED D]'~TRTRI.ITTON DIJN 'I; 5 · RIIN t; 17t IN t . 5" 171 IN 'I; 5: · RIIN ~ . ~" RIIKI i ~ S'IIN t , R'IIN 4 , R'IIN t. 5~ I-'?I.JN t ; 5" R'IIKI i · 5" RIIN i. 5" I;.'IINi: R'I!N t. F<!IN 'I . RE...ETPT OF DATA DR'F~XFR DRF~FR DRF~.~Ir.R DRF~FR DRE~IrR DRF~F~ BR'E~Ft~ CENTRAl_ FTI..E~ CHFV~ON.. D & M EXTFNXTON FYF'I..NRATTON EvyRN MARATHON MORTI._ PHI I..,I... T P..? F'R blFt..I .%AF'C .gTATF F!F TF'XAr't.n FTI.. Fr AI..ASKA STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COrv,,,,iSSION REPORT. OF SUN DRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing [] Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation(DF or KB) ARCO Alaska, Inc. 47' RKB 3. Address 6. Unit or Property name POst Office Box 100360, Anchorage, AK 99510 Prudhoe Bay Unit 4. Location of well at surface 802' FNL & 1114' FWL,. Sec. 12, T11N, R14E, UN At top of productive interval 1075' FNL & 990' FWL, Sec. 7, T11N, R15E, UM At effective depth 1113' FNL & 1165' FWL, Sec. 7, T11N, R15E, UM At total depth 1155' FNL & 1325' FNL, Sec. 7, T11N, R15E, UM 7. Well ( 11- 7-11-15 ) 8. Approval number 7-222 9. APl number 50-- 029-20174 10. Pool Sadlerochit Feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11002 feet Plugs (measured) 8567 feet 10710 feet Junk (measured) 8328 feet 10917' - Cement 10710- Fill Casing Length Conductor 54' Surface 2662' Production 9804' Liner 1462' Size Cemented Measured depth 20" 240 sx Permafrost II 80' 13-3/8" 5100 sx Permafrost II 2688' 9-5/8" 1000 sx Class G Cmt 9830' 125 sx Permafrost II, 2nd Stage 7" 400 sx 9538'-11000' True Vertical depth 80' 2688' 7637' 7422'-8566 Perforation depth: measured 10414-10512', 10527-10690', 10715-10732', 10748-10785', 10839-10849', 10858-10878' true vertical 8079-8168', 8180-8312', 8332-8346', 8359-8389', 8434-8442', 8449-8465' Tubing (size, grade and measured depth) 7", 29#, L-80, ABM 8rd to 9285 'MD 5~~'', 17#, L-80 ABM 8rd @ 9285-9329' 'MD Packers and SSSV (type and measured depth) 9-5/8" x 7" Baker FB-1 Packer @ 9329'MD/Otis SSSV @ 2202'MD j~;.~ii.2!~i~p~__~'~ ~ "~ 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. (';ommiss[on Anchorage, 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data 5/2/87 5/11/87 OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure -- 166914 .... 3908 174976 .... 3731 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 .~2~ /j..../.).~ _<~ · -~ v.. Form 10-404 Rev. 12-1-85 Title 0per. Engr. Mgr. Date ~//'~,,,/~.~ MRO (265-6R10~ Submitin Duplicate NGI-2 DAILY WELL OPERATIONS ADD PERFORATIONS 5/2/87 PT lower BOPs, upper BOPs, and lub to 4000 psi Pull SSSV PT lub to 4000 psi. OK RIH w/3-3/8" dummy gun, TTL & bailer Tagged PBTD @ 9530' 5/3/87 PT hardlines to 4000 psi. OK Pump in xylene wash w/paravam Freeze protect w/methanol SD for 1 hour soak time PT wireline equipment to 4000 psi - repaired 2 O-ring leaks Retest to 4000 psi. OK RIH w/3-3/8" x 20' dummy gun & CCL Tagged PBTD @ 10710 RIH w/gun #1, 3-3/8" x 22', 4 SPF @ 120© phasing Perf 10672'-10689' and 10637'-10642' POOH - all shots fired RIH w/gun #2, 3-3/8", 4 SPF @ 120° phasing Perf 10627'-10637' and 10582'-10597' POOH - all shots fired RIH w/gun #3, 3-3/8", 4 SPF @ 120° phasing Perf 10546'-10562' and 10481'-10491' POOH - all shots fired RIH w/gun #4, 3-3/8", 4 SPF @ 120° phasing Perf 10477'-10481' and 10438'-10457' POOH - all shots fired 5/4187 PT BOPs and lub to 4000 psi. OK RIH w/bailer & 3~ centralizers Tagged PBTD @ 10689' POOH - recovered sample RIH w/SSSV to 2181 SLM Pressured up. Good POOH Failed flow test Pulled SSSV 5/6/87 PT equip to 4000 psi. OK Set SSSV @ 2184' WLM PT to 4500 psi. OK Flow tested valve to 500 psi. OK RD. STATE OF ALASKA "' ALAS, , OIL AND GAS CONSERVATION COM~,.,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 J~ Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Office Box 100360, Anchoraqe, AK 99510 4. Location of well at surface 802' FNL & 1114' FWL, Sec. 12, T11N, R14E, UM At top of productive interval 1075' FNL & 990' At effective depth 1141' FNL & 1281' FWL, Sec. 7, T11N At total depth 1155' FNL & 1325' FWL~ Sec. 7, T11N 11. Present well condition summary Total depth: measured 11002 true vertical 8567 FWL, Sec. 7, T11N, R15E, UM , R15E, UM ~ R15E~ UM feet Plugs (measured) feet 5. Datum elevation (DF or KB) 47' RKB 6. Unit or Property name Prudhoe BaS Unit 7. Well number NGI-2 (11-7-11-15) 8. Permit number 7.~-52 9. APl number 50-- 029-20174 10. Pool Sadlerochit feet 10917' - Cement i':./ili'-~ Effective depth: measured 10917 feet Junk (measured) None . i ~'-:' , ] ::!':'::' true vertical 8497 feet Casing Length Size Cemented Measured depth True ;VettLca~l. depth Conductor 54' 20" 240 sx Permafrost II 80' 80' Surface 2662' 13-3/8" 5100 sx Permafrost II 2688' 2688' Production 9804' 9-5/8" 1000 sx Class G Cmt 9830' 7637' 125 sx Permafrost II, 2nd Stage Liner 1462' 7" 400 sx 9538'-11000' 7422'-8566 Perforation depth: measured 10414-10439', 10458-10478' , 10492-10512' , 10527-10547' , 10563- 10583' 10598-10628' 10643-10673' 10715-10732' 10748-10785' 10839-10849' 10858-108 true vertical 8090-8110', 8125-8141', 8152-8168; 8180-8196', 8209-8225', 8238-8262', 8274-8298',-8332-8346', 8359-8389', 8434-8442', 8449-8465' Tubing (size, grade and measured depth) 7", 29#, L-80, ABM 8rd to 9285'MD 5½", 17#, L-80 ABM 8rd @ 9285-9329' 'MD Packers and SSSV (type and measured depth) 9-5/8" x 7" Baker FB-1 Packer @ 9329'MD/Otis SSSV @ 2202'MD Description summary of proposal [] Detailed operations program Fi BOP sketch 12.Attachments May, 1987 13. Estimated date for commencing operation Date approved 14. If proposal was verbally approved Name of approver Date ~'/$/~t'~ 15. I hereby,certify that the_foregoing is true and correct to the best of my knowledge Commission Use Only Notify commission so representative may witness [] Plug integrity ~ BOP Test [] Location clearance Conditions of approval 0t] I Q!NAI, S t t~N=[J] Commissioner by order of the commission Date Approved by Form 10-403 Rev 12-1-85 -, ~ MR0 (265-6810) Submit in triplicate NGI-2 Proposed Additional Perforations ARCO Alaska, Inc. proposes to add perforations within the Sadlerochit interval in Well NGI-2. The proposed perforation intervals are as follows' Existing Perforations 10414-10439 (25') 10458-10478 (20') 10492-10512 (20') 10527-10547 (20') 10563-10583 (20') 10598-10628 (30') 10643-10673 (30') 10715-10732 (17') 10748-10785 (37') 10839-10849 (10') 10858-10878 (20') TOTAL = 249' Proposed Perforations 10439-10458 (19') 10478-10492 (14') 10547-10563 (16') 10628-10643 (15') 10673-10680 (7') 10684-10690 (6') 10732-10748 (16') 10914-10928 (14') 10935-10945 (10') TOTAL = 117' Reference BHCS of 11/7/75 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. .f~-~. r~-'',, .~ WELL: NGI ~2 " SPUD DATE: 10/12/75 SURFACE LOCATION: 802'S & llI4'E of NW cr. Sec. I2, TllN, R14E, UM · BOTTOM HOLE LOCATION: 1155'S & i325'E of ~IW cr. Sec. 7, TllN, R14E, UM ORIGINAL RKB': 47' RKB TO Gray HANG£R TOP OF SADLEROCHIT: 10408 , MD AVERAGE HOLE ANGLE: ALL DEPTHS ARE RKB MD Depths are to TOP of equipment ,,.----. lTop Job w/ 300 sx 80' 20",'94#, H-40 vetco 19.124 2202' Otis RPB Nipple 5.963" ID 38o ID 2395' 9-5/8" FO w/ 125 sx 2500' Bottom of 9-5/8", 47#, SOO-g5 BTC 8.681" ID 2642' 9-5/8" FO 2688' 13-3/8", 72#, MN-80 BTC 12.347" ID w/ 5100 sx 9285' Bottom of 7", 29#, L-80 ABM 8rd 6.184" ID 9305' Otis XA 5½", Sliding Sleeve 4.562" ID 9321' Otis XN Nipple 4.562" ID w/ 4.¢55 No-Go 9329' 9-5/8" x 7" Baker FB-1 Packer Bottom of 5½", 17#, L-80 ABM 8rd 4.892" ID NO TUBING TAIL 9341' Baker Seal Bore Assembly 9538' Top of Liner, BOT MC Hanger 9830' 9-5/8", 47#, MN-80 BTC 8.681" ID w/ 1000 sx 10414 10458 10492 10527 10563 10598 10643 10715 i0748 10839 10858 109~7 11000 11002 - 10439' - 10478' - 10512' - 105¢7' - 10583' - 10628' - 10673' - 10732' - 10785' - i0849' - 10878' PBTD 7", 29#, N-80 BTC 6.184" ID TD 26' MAXI~iUM ANGLE: 56.5o @ 5859' ANGLE AT TD: 34.6° 10.8 ppg CaC12 & 15 bbl Diesel Cap WORKOVER-STIMULATION 2/2~/7T'Hydril tubing removed. New string ABMOD 4/17/78 Water washed well w/ 250 bbl. 6/1/78 Water washed well w/ 325 bbl. 10/27/78 Parted 7" tubing @ 95'. ~lilled out packer @ 9293'.. Cleaned out fill 10631'-10917'. Squeezed 300 sx cement thru FO @ 2395' Washed and cleaned out to 10911' 1/84 4 2 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 Gay ~npany North Alask,. District Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer July 8, 1981 Reference:Cased~Hole Final NGI #2 6/30/81 X-Y Caliper Log Run 1 5" sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #417 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL ~ PHILLIPS S 0 H I 0 C H E V R 0 N °~a~' ~ioo ARCO Oil and Gas Company is a Division of AtlanlicRichfieldCompany I__. COM/~" ' COM _ /, R~S E:NG April 3, 1979 1 4 ENG 1 GEOL ' 2GE~ l~nclosed J.s ~he ~oliow.i~g P-l~c~su.-Fc ]~Llildul> S~v'oy '~U~3 GEOLF NGI f2, dated. 12-16-78. '[ ~ STATTE~ [ I STAT TE~- Please sign and retun~ d~e attached copy oE th.e Very truly yours, -9 · / ~, R. A. }Iamli~ North ~era. tions Engineering Transmittal #146 DISTRIB[ITI. ON North. Geology Exxon D~'i 1] ing Mobil ]2ri,q-. ~'!anager Getty R [} 1) Sohio Geology ~ia'rathon State of Alaska I'hil].:i_ps D & H Ch evro'n Posl Off;ce Ancbora.qe, ~' ~ 0.3510 Tc:lepho:J.~ 9u 2/7 5637 March 29, 1979 ~. _ Reference' - " · .. Enclosed are the following cased hole logs: '~D,~6-8 -' Diff. Temp. 10/31/78 S,.6-5 .~' CCL 1]./18/78 /~38~. 6- 8 CNL 10/30/78 S 6-1 ~ CNL 10/21/78 '/ ccu 0/ s./78 Diff. Temp. 12/ 9/78 . CCL w/'dm~y ~ 11/21/78 .... . 6-6 / Fluid Density 11/25/78 2-1{ D~ff. Temp. 12/12/78 Please sSgn ~d retu~ the copy as receipt Sincerely, V. G, Reimers North Engineering Ti%~NSMI ~I'AL #138 "' DISTRIB[WION North. Geology Drilling Frog. Manager R&D Geo logy ..... State of Alaska' }~xort MobZ1 Getty Sohio Marathon t)hillip$ Chevron Post O[ii'-'~., Anchorage, ? ..j~ 99510 Telephone 907 277 5-337 March 15, 1979 Reference: -. Enclosed are the following cased hole logs' DS 1-10 N TDT 11/18/78 DS 13-1 ~ CBL 11/27/78 DS 13-1¢ CNL 12/ 2/78 DS 7-7v CNL 12/1 7/78 EPL 1 2/ 8/78 J 4 ENG "J ~' EPL 12/16/78 Please sign and return the copy as receipt of data. Sincerely, V.G. Reimers North Engineering TRANSMITTAL #1 O0 DISTRIBUTION North Geology Drilling Eng. Manager Geology ' State o£ Alaska ]%xxon Sohio ~Iobil }.Iarathon P]~ilJ. ips Chevron Getty Posl O.qics/ Ancl,,or~',go,~laska 99510 Yelephone 907 277 January 22, 1979 Reference: - Enclsoed are the following cased hole logs: DS 5-14 Cont. Flow ' 6/14/78 DS 9-17 Cont. Flow 6/28/78 DS 6-8 Borehole Audio 10/31/78 DS 6-7 CNL 8/25/78 DS 3-7 Spinner 10/19/78 DS 9-9 Fluid Density 10/29/78 DS 6-2 CCL w/dummy gun 10/29/78 DS 1-4 GR/N 11/11/78 DS 6-4 CCL 11/13./78 ~,~_j~ CNL 11/14/78 C~ CCL w/Dummy gun 10/27/78 DS 4-6 CNL 11/12/78 DS 2-1 CNL 11/11/78 NGI #2 CCL w/ Dummy gun 11/23./78 DS 5-12 Cont. Flow 6/10/78 DS 5-2 CNL 11/09/78 Please sign and return the copy as receipt of data~/ .~ Sincerely, </ / V.G. Reimers North Engineering TRANSMITTAL #033 DISTRIBUTION North Geology Drilling Eng. Manager R&D Geology State of Alaska D&M ~xxon Sohio Mobil Marathon Phillips Chevron Getty AtlanticRiChfieldCompany North Ameri~ Producing Division Alaska Reg? Post Office'=~x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 8, 1978 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject' NGI #2 Permit No, 75-52 Dear Sir' Enclosed please find our Sundry Notice of Subsequent Report along with a Completion Report, detailing the work done on the above- mentioned wel 1. Very truly yours, P. A. VanDusen District Drilling Engineer PAV-jh Enclosures Form 10-403 REV. 1.'10~73 Submit "I ntenti~ns" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. Ow~LLLDWELL GAS O OTHER Gas Iniectinn 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360~ Anchoraqe~ Alaska 4. LOCATION OF WELL At SUrface 802'S & ll14'E of NE cr Sec. 12, 13. 5. APl NUMERICAL CODE 50-029-20174 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 14. ELEVATIONS (Show whether DF, RT, GR, etc.) 18.4' Pad Level 99510 T11N. R14E, UM 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. N6I #2 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 12. Sec. 7, T11N, R15E~ UM PERMIT NO. 75-52 Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [~ FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) )orr, or Other Data SUBSEQUENT REPORT OF: PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SNOOTING OR ACIDIZlNG ABANDONMENT* (Other) (NOTE= Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all I~rtlnent details, and give pertinent dates, Including estimated date of starting any proposed work. See Attached Sheet. TITLE District Drillina EnaineeroATE. 12/g/7R (This space for State office use) APPROVED BY. CONDITIONS OF APPROVAL, IF ANY; T IT LE DATE See Instructions On Reverse Side NGI #2 10/12/78 - Damaged thg hgr caused difficulty in initial att to tpt BOP's. Att to pull tbg landing jt. Rec inner mandrel of tbg hgr. Had to use spear to latch onto 7" tbg. Rec 3 jts 7" tbg plus collar on top of 4th jt had split. Top of fish @ 95'. Set BP @ 80' & tstd ok. Tstd BOP. Pulled BP. RIH w/spear. Caught fish. Sheared out of PBR. LD 7" tbg. RIH w/fishing tools. Top of fish @ 9270'. Latched on fish. Att to back out K Anchor. Overshot pulled off. Unable to relatch fish. PU 5-7/8" grapple. Latch fish @ 9242'. Back out K Anchor. POH w/fish. RIH & milled out pkr @ 9293'. Rec pkr assy. Set RTTS @ 2842'. Tag junk @ 10,631'. Pushed same to 10,691' Drld & CO to 10,~915'. Ran gauge ring & junk bskt Ran EZ drl BP ~ 10,350'. Tstd csg. NU flow nipple. Drld EZ drl BP. Pushed plug to 10,915'..Chgd over from Dril-S to 10.8 ppg CaCI? wtr. Ran gauge ring & junk bskt. RIH w/pkr & set @ 9400' Ran 7" tDg. Pulled dummy valve. Ran dummy gun/CCL log, Found fill. Washing & CO to 10,917'. Set BV. NU & tstd tree. Rec BV. Opened sliding sleeve @ 9398'. Displ tbg w/diesel to sliding sleeve. Pumped 10 bbls diesel into annul. Closed sliding sleeve. Press 7" x 9- 5/8" annul to 3000 psi. Press bled to 2200 psi in 30 min. Recheck sliding sleeve for closure. Repress annul w/1050 psi on tbg. Csg bled to 2615 psi tbg press held Opened sliding sleeve @ 9398'. Pumped thru 5 bbl diesel to verify sleeve open. Closed sleeve. Press csg to 3000 psi w/1225 psi on tbg. Csg press dropped to 1400 psi in 5 hrs w/tbg stabilizing @ 1100 psi. Opened sleeve. Tool hung up. WL parted. Killed well w/lO 8 CaCl2. ND tree. Pulled 7" tbg. Fished for WL. Rec WL to 9412'. .Miiled ou~ prk @ 9412' & rec. Rec remainder of WL. Set pkr @ 2642'. Set pkr below FO @ 2396'. Apparent leak thru lower FO. Att to close FO. Opened upper FO. Pumped thru upper FO. Closed & tstd upper FO. Set BP @ 935~' w/sand on top.--Tstd BP ok. Opened upper FO, rev out. ~sx Arcticset cmt thru FO. Closed FO and tstd. Press tst csg ok. Rev sand off BP. Rec BP. Washed & CO fill to 10,911'' Press tstd 5" x 9-5/8" annul .Press tstd 5" x 9-5/8" annul. R~n gauge ring & jUnk bskt. Ran dummy gun. Ran 7" compl assy @ 9341', pkr @ 9329'. Tstd control lines. Ran dummy gun/CCL. Ran & set flapper valve. NU & tstd tree. Pulled flapper valve. Displ tbg w/diesel. Set flapper valve & tstd. Released rig @ 2400 hrs 11/27/78. Vor,'u SUBMIT IN DU~ .~.. gATE* STATE OF ALASKA (See other tn- st ructions on side) reverse OIL AND (}AS CO~$fRVAYIO~ CO~l~7ff : WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* 5. API NU]W. CA~CAL CODE 50-029-20174 $, LEASE DESIGNATION A.ND SERIAL NO. _ ADL 28302 i?, IF INDIA.N, A.LLO~ OR TRIBE NAM2E la. TYPE OF WELL: b. TYPE OF COMPLETION: .NEw F-] WOnK ~;~ WELL OVER OH.WELL [~ ~ASwr. LL'[~] DRY F'-t Other Gas Injection ,E~,'-[--] ,AcKPL~ [--] ''~'" [] Other' Perforated EN EESVR, 2. NAbIE OF OPERATOR Atlantic Richfield Company 3. AbVRESS OF 6PERATOR P. O. Box._360, Anchoraqe, Alaska 99510 ~.LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 802'FNL & 1114'FWL Sec. 12, T11N-R14E, OM At top prod. interval reported below 1075'FNL a 990'FWL, Sec. 7, T11N-R15E, OM At total depth 1155'FNL & 1325'FWL, Sec. 7, T11N-R15E, UM 13. :DATE SPUDDED .~14. :DATE T.D. IR~g~Ci~EE~ :I.15. DAT~.-CO,MP SUSP O(R ABAND. 10-12-75] 11-4-75 ~ 11=20-75 18.i TOTAL DEI~H, 1VI_D & TVD[9. PLUG, ~CK MD & TV~). /~ ~ULTI~LE COM~L., 21. ': ! ~-]~OW 1ViAI~Y* ' ROTARY TOOLS 1~002'MD(8567 'TVD)i 917 !MD(8497 'TVD),I Single All 25. PRODUCING INTEHVAL(S), OF TH/S COMP3_~-"~IO/q~, BOTTOM, ArA/VIE (MT) AND 10~408'MD (8085'TYD) !Top Sad]erochit 10:,946'MD (8521'TYD),Base Sad]erochit 8. UNIT,FA~IVI OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. NGI #2 (11-7-11-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe BaS Field-Prudhoe 11. SEC..o~rc~ivE,~.. R., ~.. (so~o5 ~¥~Poo 1 12. PE'Ih%ilT NO, 75-~ Il0. ELEVATIONS (DF, RKB RT, OR, ~IN~) ]17. EL,EV'. CASINGHEAD . 18.4 ~raYel Pad,~ 47' KBI INTERVALS DRILLED BY CABLE TOOLS ~one 23. WAS DIRECTIONAL 1 SURVEY 1V~ADE .! I Yes Sec. 7, T11N-R15E, UM 10,839'-10,849' 10,563"10,583' 10,439' 10,748'-10,785' 10,527' 10,547' W/4 shots 10,715'-10,732' 10,492.':10,512' per ft. 10,643'-10,673' 10,458'-10,478' 24. TYPE ELECTRIC A~ND OTHER IX)GS RUN DIL, BHCS/GR, FDC/C.N[/GR and CBL/VDL, GR/CNL/CCL , . 25. CASING RF~COHD (Report all strips set in well) , CASLNG SIZE 1 WEIGHT; LB/FT~ ~ G~E ! D~ ~T (~) ! HO~ S~E I C~NTING RECO~ ~OUNT PU~ ' 20" [ "' 94~".[ H'40 ]80' be~.pa4 32" [240 sx Permafrost II 13-3/8~' [ 72t ~ [MN-80 [2688' ] [17-1/2" [5100 sx Permafrost II 9-5/8' [ . 47~ IMN-80 19830' . !12-1/4" l 1000 sx Class G ':-~ Js00-95J ~ J [125 sx PF II ~?q0od ~aq~ . , . . 28. PERORATIONS OP~ TO PRODU~ON (interv~, size ~d number) 29 ~ ACID Si:tOT F~CT'URE C~IEArT SQU~ZZ ~C 10,858'-10,878' 10,598',10,628' 10,414' PRODUCTION Division ol 0ii :md Ga'.~ PI{oDucTION ME'II{OD (Flowm.g, gas lifl, pump~g--size and type of pump) [ViEL~ ~$~oduc~ or Injection ] unut-in). OI~BEL. G~CF. WATt. BBL. GAS-OIL I o l o,ooo s q o GAmMa. WA~BBL. [OIL GRAVITY-~I (CO~.) 150,000 SCr/D] 0 tTE~T WITNESSED B~ Production 0petal;ion DATE FIRST PI~ODUCTION DATE OF TEST, II-iOU~S TESTED TM ']CHOI<E SiZE PROD'N FOR ~ST P~OD Oct. 1977 I ,Opsi I .: l- o . ~e i nj ec ted ' ~~ ~,,~.~. Distr. ict iDrilling Engineer ~TS J~C/Z. /~)~_ *(See Instructions and Spaces for Additi6nal Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete arid correct well completion report' end log on all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise showlfl for depth measure- meats given in ether spaces on this forn~ and in ar~y attac}~t~er-~ts Items 20, and 22:: If this well is completed for separ~tc f')rc, ctuction from more than one interval zone (mulliple completion), so state ~n item 20, and in ite,-~ 22 show the p~c:J,cJ~'~.'.·l interval, or ~ntervals, top(s), bottom(s) and name (s) (if any) for only the interv~I restarted ir~ ~tem 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produce:J, show- ing the ack~itional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementi~g and the location of the cementing tool. Item 28: Submit a separate completion report on this forrq for each inlerval to be separately produc~,cl. (See instruction for items 20 and 22 above)· 34. SUMMAHY OF FOI~.MATION TES'Ii$ IN('LUI)IN(; IN'I'E[/.VAL, TESTED. I)flE.,~'~SURE DATA AND'~'OVERI~ OF ()Il.,. GAS. 35. GEOLOGIC M AR KIgP~ WATER AND MUD __ lq'AMg MEA$. DEPTI~ '~I~U~ VII~IT. ,~ , , , Top Sadlerochit 10,408' 8,085' IBaso Sadleroch~t 10,946' 8,521' · .~t~. C'OI1E DATA. A'I'I'ACII llRIEF, DlgSEP~.~VI~IO'N$ O1~. LI,TIlOLOGY. POnO,~ITY. FHA("TIJRES, APp.'A.P,-ENT~ DI:PS~ ANL~. ~E'I~EC-I:EI) SII()WS OP" ()IL,, GAvel Oil WA'VEIl. ? , · .. AtlanticRichfieldCompany North Ame,.r~-~. roducing Division North Alas .,trict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 13, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject.~Permit No. 75-52 DS 7-6, Permit No 78-14 Dear Sir: Enclosed please find a Monthly Report of Drilling Operations for the above-mentioned wells. Very truly yours, P. A. VanDusen District Drilling Engineer PAV-jh Enclosures Form No. 10404 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-029-20174 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 1. 7. IF INDIAN'ALOTTEE OR TRIBE NAME OIL [~ GAS~-] Gas. I:njeCtion Well WELL WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL 802'S & 1114'E of NW cc Sec. 12, TllN, R14E, UM 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. NGI #2 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe Oil Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 7, T11N, R15E, UM 12. PERMIT NO. 75-52 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 October, 1978 10/12/78 - Well appears to be leaking thru tbg hgr past BPV. Att to pull tbg landing jt. Rec inner mandrel of tbg hgr. Had to use spear to latch onto 7" tbg. Rec 3 jts 7" tbg plus collar on top of 4th jt had split. Top of.fish @ 95'. Set BP @ 80' & tstd ok.. Tstd BOP. Pulled BP. RIH w/spear. Caught fish. Sheared out of PBP. LD 7" tbg. RIH w/fishing tools. Top of fish @ 9270'. Latched on fish. Att to back out K Anchor. Overshot pulled off. Unable to relatch fish. PU 5-7/8" grapple. Latch fish @ 9242'. Back out K Anchor. POH w/fish. RIH & milled out pkr @ 9293' Rec pkr assy. Set RTTS @ 2824'. Tag junk @ 10,631' Pushed same to 10,691' Drid & CO to 10,915'. Ran gauge ring & junk bskt Ran E~ drl BP @ 10,350'. Tstd'csg NU flow nipple. Drld EZ drl BP. Pushed plu~ to 10,915'. Chgd over from D ril-S ~o 10.8 ppg CaC12 wtr. Ran gauge ring & junk bskt. RIH w/pkr & set @ 9400' Ran 7" tbg. Pulled dummy valve Ran dummy gun/CCL log. Found fill. As of OctOber 31, washing & CO fill to 10,917'. SIGNED.¥. t/-" T,TLE District Driilling EngineOrTE 11/14/78 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. DEP~ OF NATUPAL RESCD~CES Di'~isic~ of Oil and Gas Ccmservaticm Hoy~ H. Hamilton~ October 24, 1978 BOPE Test - Arco's N~I-2 1978 - at 7:15 AM for 7:40AM showup and 8:40 AM departure vxa Aroo cbarher for Prndhoe Bay, arriving at 10:20 AM. ~eith Bullard, Aroo drilling fcmmmn re~f, and D. C. Murphy, Bowsn Rig #35 too~, aco~panied Temperature +4° F, light wind, high sca~ clouds at 4000'. Tests began at 8:00 PM ~ the annular ~ter but a linear leakDff contlnusd and could not be isolated. It was decided ~o back the ~ jo/nt out and the ~s to prevent any fluid buildup in the joint. ~ were s~pended at 10:00 PM. valve om the kill line, leaking 9 5/8" pmmkDff, and finally a ring At 8:00 PM it was decided to pull the tubing ~ and set a te~-t plug. ~, ~ threade~ mandrel ~ out of the tubin~ hangar cm the landim~ joint and attsmpts to scre~, back into the three 'jc~nts of 7" ~ ~ a snarl of c0~trol line was landed ab~ midnight. The test plug was set but they could not get it inside valve an~ check valve in tbe kill line testing to 5000 psig. ~, the cuts~ ~ valve on the kill line would not test and at about that time both the test plu~ and 9 5/8" packoff began leaking again. It was decided to set a hrid~e plug, r~nove the ---2-- October 24, 1978 ~ c~ of ~ ~ plmg ~o tms~ 6~e blind r~s ~ tot=ed the s~3- wms u~. Bltna ~ ~ ~ ~o 50(~ psig. electric ac~-~ula4x~ ~ of~ an~ cluse~ c~e set of pipe rams, ~~~ ~~~~~~lt~ ~ 2950 ~g I de~a~aed Dem~aorse via ~ flight %10 at 1:50 PM, arriving in ;~uboraqe at 3:30 PM and at my bo~e at 4:00 PM. At~t Drlg. Permit No. ,/~'/~,-,,~ Well/~ Sec_~___T Operator_~--'- Represented by_~_~..~_~,~,.~ Name & Number_~_~T~;~ Satisfactory Type Inspection Satisfactory Type Inspection Yes No Item (~7~l~ocation,General Yes No Item (I~)~BOPE Tests (,g,- ( ) (~..- ( ) () () (~¢'" ( ) ) () ) () ) () ) () ) () ) () ) () 1. Well Sign 2. General HousekeepinQ ~. Reserve Pit-( )open( )filled 4. Rig ( ) Safety Valve Tests 5. Surface-No. Wells 6. Subsurface-No. Wells ( ) Well Test Data 7. Well Nos. , , , 8. Hrs. obser , , ,.. 9. BS&W , , , m lO. Gr. Bbls. · ( ) Final Abandonment ll. P&A Marker 15 ~_~_~asinq set ._~__~ 16 Tes[ fluid-( )wt~( )mud (~)~oil (h-- ( ) (,q-- ( ) (,.~ ( ) (,h'- ( ) (,~() (h'() (A.~ ( ) (h~() (~.- ( ) 17. Master Hyd. Control Sys.-.~'mpSiQ 18. H2 btls£~ 19. Remote Controls ~.~'- 20..~ Drilling spool-~"outlets 21'. Kill Li~e-(~Check valve 22. Choke Flowline (~HCR valve 23. Choke Manifold No. valvs/~flms~, 24. Chokes-(~)rRemote( )Pos..(~d,! 25. Test Pluo-(~llhd( )csq( )i:'bne 26 Annular Preventer,~F~,,,~siQ 27 Blind R. ams,~.psim 28 Pipe Rams_.~-~psiq ) ( ) lZ. Water well-( )capped( )plugged (~)~'() 29 Kelly & Kelly-cock~F_~gsig ) ( ) 13. Clean-up (~ ( ) 30 Lower Kelly valve,~psio ) ( ) 14. Pad leveled (~() 31 Safety Floor valves--~-'~V Total inspection observation time ~ hrs/~ Total number eaks and/or equiP, fai!ures~. . Remarks ~~ ~ v~~ ~ ~..~ ~.~ ~_,~:~ .~.~'/~.? ~.~ ~..,.~~~.z',. cc-~=~__~Notify in ____days or when ready___ AtianticRici~;ietdCornpany North American Producing Division Alaska Reai~ Post Offic~ 360 AnchOrage, Alaska 99510 Telephone 907 277 5637 EnclosRd are copies of the following Cased Hole Logs: S. #7-2 ~D.S. #5-2 Compensated Neutron i 11/16 GR/N/CCL Engineered Productiqn Log · 6-3-'78 (~v- ~) 2" & 5" 211 2" & 5" '6/NGI #2 Engineered Production I~og 2" & 5" 5-31-78 V~NGI #3 Engineered Production Log 2" & 5" ~Piease sign and return attached copy of transmittal as receipt of data. Very truly yours, / A. A. Logue North Alaska Operations Engineering Transmittal #461 AtlanticR;chfieldCompany North Amer~Producing Division North Alask. ,strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 15, 1978 Mr. Hoyle H. Hamilton State Of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive ~Anchorag~, Alaska 99501 Subject: ~NGI #2.~ Pe,rmit No. 75-52 Permit No. 75-69 NGI?#7 Permit No. 76-38 NGI #g~ Permit No. 76-68 NGI #10 Permit No. 76-69 Dear Sir: Enclosed please find a Completion Report for the above- mentioned wells. Very truly yours, Frank M. Brown District Drilling Engineer FMB:lr Attachments . SUBMIT IN DIt ~,-LLqATE* STATE OF ALASKA st ructions on ~OIL AND GAS CONSERVATION COMMITTEE i i i iii i I iii WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* "la. TYPE OF WELL: " 01~',' ' ~ '%~S '~ D,Y ~ Other Gas In, action WELL WELL b. TYPE OF COMPLE~ON: WgLL OX'gu EX hACK ngsva. Other Perforated 2. NAME OFOPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360 Anchorage, Alaska 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 2' ~nte80:r,alFNL & 1114'FWL. Sec. 12, TllN-R14E, UM At top prod. reported beqow at total deptl1075'FN-L & 990'FI~, Sec. 7, TllN-R15E, UM 5. AP1 NU1WEP~CAL CODE 50-029-20174 6, LEASE DESIGNATION A-ND SERLa. L NO. ADL 28302 7. IF INDIA.N, ALLOTTEE OR TRIBE NAME 8. UNIT,FAff~IVi OR LF~kSE NAME Pr,lrlhna R~y Iln~t .. g. WELL NO. NC.I #2 (11-7-11-15) 10. FLELD A~ND'POOL, OR WILDCkT Pr,,dhmm Ray ¥~ald/Prudhoa 11. SEC., T., R., M.~, (BOTTOM H~ Pool OBJECTIVE) 'I~. rm~iTSeC' ~7d TllN-K15E, UM UM l155'FNL & 1325'FWL, Sec. 7, TllN-R15E, 75-52 10-12-75 11-4-75, , | 11-20-75. 18.4 Gravel Pad,47'KB.~. , I~OW 1ViANY* ROTARY TOOLS llO02'MD(8567'TVD) [ 10917'MD(8497'TVD~I... Single All 22. PRODUCING INTERVAL(S), OF THIS COMPLETION--TOP, BOTTOM, NAME (MD AND TVD)* 10,408'MD (8085'TVD) Top Sadlerochit 10_qhf'lvIT~ (2521'TVD5 Raga gmdlarmchJt 24. TYPE 'E~E~TEIC ANb eTHEl% LOG~ RUN .... DTT.: C~CK/G~, FDC/CfNI./C~R and CBL/VDL. GR/CNL/CCL ~5. CASING RECORD (Report all strings set in well) C~SIZqG SIZE PIOLE SIZE 20" 32" 1 ~_-~/g" 17~" 9-5/8" 12¼". 7" -" ' 4 ...... , [ 9538 , [ 11,000 [ 00 [ [ [ 2~. PERFORATIONS OP¢~XI TO PRODUCTION' (interval, size and number) INTERVALS DRtLI, ED BY CABI,E TOOLS None 23. WAS DIRECTIONAL SUIIV~.Y MADE i Yes CESILNTING RECOP~D ! A~IOUNT PULLED [240 sx Permafrost II , , · [5100 .~x Permafrost II li:~5 sx PF II second stage 27. TUBING RECO~ SCi~F_~N (~,D) SIZE DEPTI-I SET (MD) ~ PACI~.ER SET (MD) 7" 9470' i 9335' 29. ACID, SHOT, FiI~C~'LIRE, C~.%iENT SQU~7~-_~, ETC. D~T~i INT~m.-~VAL (MD),[ AMOUNt ;~_?_, .I'~!ND,' OF MAX~YaAL USED / 10,858'-10,878' (10,598'-10,628' 10,414'- 10,839'-10,849' )10,563'-10,583' 10,439' N/A [ ; ~ I.' ~ ( r" '' :~ ~ ~ f~ 10,748'-10,785' i10,527'~10,547' w/4 Sho :s -- [ ' ~:' /~ ~ '.:' ,. 10,715'-10,732' /10,492'-10,512' per g~. [ ~!j[? o ,, i~o.~ -~o.~vs (~o.~ss ,zo.~a ~ ~'. j,~.,. ' ' ": 30. ' ' PKoDU~ioN ...... ''~lV:~ C,3' ~.. ' ..... ............... t ih/ ~, ~ ~ . DA'rg W~ST mZODUC~O~ [ ~ODUC?ZO~ Mg'Zt~O.D (Wowh~g, ga: U~, pump~g~size and type o~ pump) [;~. ~'~"I'US ~produc~ng or ~ ! I ITEST PE~OD i . , oct ~9771 2~ I ~/& ] ~- ! 0 ~o~oo:~gc~/~ 0 I ~/& I , , [" [0 0 I ........... 31. ~SPOS[TWN OF O~S (8Old, u~e4 ]or ~eI, ve~ted, etc.) [~ZS~' ~"'~T~SS~D ~ ~einjected [ Production Operation 32. LIST OF ATTACHMENTS hereby certify that the foregoing and attached information la complete and correc{ as determined "from alUa(,ai'lable recordS/ SIGNE~~~"~'/~TITLE District Drilling Engineer DATE ~~._/~~ *(See Instructions and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well complet,on report and log or', all types of lanJs and leases ir', Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- menls given in cther spaces on this form and in any attachmenls. Items 20, and 22:: if this well is completed for separatc, production from more than one interval zone (multiple completion), so state ,n item 20, and in item 22 show the p,cJucing interval, or ,ntervals, 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 addilional interval to be seperately produced, show- ing the adlditional 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 '~8: Submit a separate` completion report on this form for each interval to be separately produc~l. (See instruction for items 20 and 22 above). ' 34. SUMMAI~Y OF I~o~MATION TES'"~ IN('I,UI)IN(; IN~:'.F, RVAL TF~STED. I'H~UR~ DATA ~'~OVERI~ OF OI~'. GAS.' 35. G~GIC MARK~ WATER AND MUD Top Sadlerochi~ 10,408 ' 8,085' Base sadlerochit 10,9~6' 8,521' ............ ~ ............~ -~-~ 36. COI%E DATA. Aq'I'ACI{ I1RIEF ~%~0~ OF LITIIOLOGY. POROSITY. ANO DE'I~ECTEI) SIIOWS OF OIL. G~ OR WA~. , i , ,1 ~ . ,~ , ,.. ~. , .~ ,., ~ , Atlanti~:Ric~fieldCompany North Ame~-"Producing Division North Alasi ~,strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 8, 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 #2 " Permit No. 75-52 Dear Si r- Enclosed please find a Sundry Notice outlining our plans for the above-mentioned wel 1. Very truly yours, Frank M. Brown District Drilling Engineer FMB: j h Enclosure Form 10~403 R~EV. 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.) o,- F-! GAS F--! WELLL-J WELL ii OTHER Gas Injection Well NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. 0, Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL Atsu,ace 802'5 & 1114'E of NW cr Sec. 12, T11N, R14E UM At TD 1155'S & 1325'E of NW cr Sec. 7, T11N, R15E, UM 13. ELEVATIONS (Show whether DF, AT, GA, etc.) · 18.4' Pad Level 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20174 6. LEASE DESIGNATION AND SERIAL NO. APL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE I~AI~'E Prudhoe Bay Unit 9. WELL NO. NGI #2 (11-7-11-15) ].0. FIELD AND POOL, OR WILDCAT 'Prudhoe Bay Field-PrUdboe 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 7, T11N, R15E, UM 12. PERMIT NO. 75-52 )ort, or Other Data NOTICE OF INTENTION TO= FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE~ Report results of multiple completion on Well Completion or .Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state ell pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. Atlantic Richfield Company proposes to repair a downhole tubing leak in this well. A 13-5/8" 5000 psi RSRRA BOP stack will be used. It will be pressure tested each week and operationally tested each trip. A packer and .string of 7" 29# N-80 tubing with provisions for subsurface safety equipment will be rerun. 'A 5000 psi't~P wireline lubricator, tested to working pressure will be utilized with all wireline work. The well will be backflowed to a burn pit to clean out workover fluid, acidized, and baCkflowed .again to clean"up. 16. I hereby certify that the foregoing is true and correct TITLE District Drilling Engineer DATE _ (This space for State office use) CONDITIONS OF APPROVAL. IF AN~ PET~DLEUM ENGINEER · See Instructions On Reverse Side DATE ~-.L,,,~nllCHlCilZlelaL;ompan¥ ~ortn ~,merican t'roauctn~l uivl~u~] North Alaska~rict Post Office Anchorage, Amska 99510 Telephone 907 277 5637 Reference: Enclosed are prints of the following wells' Gamma-Ray Neutron ]~og . D.S. #4-9 11 Compensated Neutron D.S~ #4-11 $" D.S. #4-14 5" Continuous Flow Survey D.S. #3'8 11 Bor~racer Survey- Differential Temperature Log Due to an error in reproduction, Some copies of sepias are prefolded. If thisl~of any inconvenience to you, please request another copy and it ~vill be sent as soon as possible. If all data is acceptable to you, please sign attached copy of letter and return it as receipt of data. Very .truly .yours, R. A Logue North Operations Engineering RECEIVED 9 o !9'/'8 Division of 011 & G~s Gon~erva!;c, April 19, 1978 Hoyle H. ~lton ~~ ~ ~ ~ ~ %3 ~ ~ occasions with the foll~ vol~s: 6~, 3~an~l~ ~a~of 10M~F. Theyalso soaked~ tubing with ~. ~he injectivity before ~ ~ms 30 ~2F~ @ 4100 psi. After ~s treatn~m~t it was 177 ~4CF/D at the same le~_l in cas~ amazlus ~ a drop of 500'. ~, the readin~ wasn't ~ fluid in that ~ ~ level ~o be at least 3000'. ~ ~ t~o ~estrictions ~ in ~ %2, at 5000' and 8000'. They ~ f~ ~ ~ at a ~ of 6.9 H~CF. Injectivity /reproved from 20 M~CF/D to 80 ~/D, ~ at 4100 psi. They w~ll soak the tuh~ ~ From ' J. A. Rochoii/R. A. Logue i'ran:~Hii tied herewith are the following for the subject well' No. Scale xerox Sepia 'BL Line Acid or Fracture Treatment Log - BHP Buildup ~ Flmv Profile Survey Borehole Geomet~b' Log -Carbon Oxygen Log Cement Bond Log Compensated Neutron Log - Cased Hole Core ~malysis - Interval Core No. Core Description (~XlC) - Interval ' Core Description (Cony.) - Core No. Directional Survey ~ Gyro - SLngle Shot - ~lultishot 'Engi-neering Production' Log Fluid Analysis _ Fluid Dea~sity Gamma'Ray Location Plat Monthly Well Test Data Mud Log Perforating Record State Reservoir Pressure Report Surveillance Reports __ Temperature Log Transient Pressure Surveys TFD Logs - Ik~el Induction Laterolog - Compensated Formation Density Log - Compensated Neutron-Fm~nation ~ensity Log - Borehole Compensated Sonic Log - Porosity I,og .ece.tI t. Acknowledged By' 'lease Return Receipt To: Ms. R. A. Logue ^tlantic Richfield Compr.,ny P. O. Box 360 Anchorage, Alaska 99510 RECEIVED APR 1 8 Oil ~nd (las P"OOoFY~IiQI1 / , ....... A~jtla, nticl~ichfield Company North Amer~"~,Producing Division North Alask~. ~. ?strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 7, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- NGI #2 (11-7-11-15) '" ! ;,;,c ..... ~ Permit No. 75-52 ,,'::,:; ;. ~-~ ?: Dear Sir' '---7L-- ~-~-~ Enclosed please find our Sundry Notice of Subsequent Report detai g the work done on the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /am Enclosure Forr~ 10-403 REV. 1-10~73 Submit "1 ntentlons" 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~u~]WELL''GAS I"-! OTHER Gas Injection 2. NAME OF OPERATOR Atlantic Richfield Company 5. APl NUMERICAL CODE 50-029-20174 6. LEASE DESIGNATION AND SERIAL NO. Surface' ADL 28302 B~h,'"Hol e' ADL 34632 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. Box 340; Anchorage, Alaska 99510 NGI #2 (11-7-11-15) 4. LOCATION OF WELL At su~ace 802'S & ll14'E of NW cr Sec. 12, TllN, R14E, UM At TD: 1155'S & 1325'E of NW cr Sec. 7, T11N, R15E,UM 13. ELEVATIONS (Show whether DF, RT, GR, etc) 18.4 Pad Level 14. Check Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe 0il Pool 31. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 7, T11N, R15E, UM 12. PERMIT NO. 75-52 )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING L-_..J MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ~ ALTERING CASING SHOOTING OR ACIDIZING I I ABANDONMENT* (Other) P erfo,Fa"t~e (NOTEt 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 details, and give pertinent dates, Including estimated date of starting any proposed work. Began perf operations 0600 hrs 3/6/78. Tstd tree, csg & wireline BOP's. Pulled ball valve. Perf'd intervals 10,414'-10,439', 10,458'-10,478', 10,492'-10,512' 10,527'-10,547', 10,563'-10,583'~ , 10,598'-10,628' w/4 shots per ft. All perf'd depths referenced to BHCS open hole log of 11/7/75. Ran & set ball valve. Tstd balance & control lines to 5000 psi, OK. Bled press above ball valve to 0 psi, held OK. Installed & tstd tree cap to 5000 psi OK. Flowed well to burn pit to unload diesel. Released well to Production Dept @ 1800 hrs 3/13/78. 16. I hereby certify that the true and correct SIGNED,~ T,TLEDistrict Drilling Engineer DATE, 4/7/78 (This space for State office use) APPROVED BY . CONDITIONS OF APPROVAL, IF ANY: TITLE, , DATE See Instructions On Reverse Side ' -"' ' I DENTIAL: ' . . :TP, !'BUTED TO: · ~;. OF ALASK3k ::'0' OF OIL & ,, iiTL&N~ lC RIGfFIELD North Alask~ District Engineering, TRANSM I TTAL From' J.A. Rochon/P. Hellstrom April 12, 1977 ;fell Name: NGI # 2 Transmitted herewith are the following for the subject well: Run No. Scale Xerox Sepia BL Line BHC Sonic/Caliper Log; BHC Sonic/Caliper - Gamma Ray Log . BHC Sonic/Gm Ray Log -.. _ Caliper/CCL Cement Bond Log/VDL . Compensated Formation Dens_i_ty. Log · Compensated NeutrOn-Formation Density Compensated Neutron Log . _~,,' Core Analysis - Interval .., . , · Core No. " Core Description (SWC) - InterVal "' Core Description (C°nv.) - Core No. ~rectional Survey - Gyro Sh6~ ........ '"'" Singl~e.. · . · . Multishot I~ill Stem Test - Test No. ~--:'"' ........ '- Dual 'Induction Laterolog -., , Formation Density Log FOrmation Density Log/Gamma Ray Gm.~r,a Ray/CCL ..... . Laterolog. Location Plat Microlaterolog Microlog ~adlog- Interval ..... Sample Log (A.R.Co.)-inter~ai) .... Synergetic Log 'TVD-DiL TFD-Porosity Log Receipt Acknowledged For' Date ' Please return receipt to: 207 Atlantic Richfield Company North Alaska Engineering Manager P. O. Box 560 Anchorage, Alaska 99510 A[,lanticRichfieldCompany North Ameri;-'-~.Producing Division North Alaska. .strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 23, 1978 Mr. Hoyl e Hamil ton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine 'Drive, Anchorage, AK 99501 Subject- NGI 6 (44-2-11-14) Permit No. 76-29 '----4~mm~i~' No. 75-52 Dear Sir' Enclosed please find a Sundry Notice outlining our plans for the above-mentioned wells. Very truly yours, F. M. Brown District Drilling Engineer /am Enclosure Form 10-403 REV. 1-10-73 Subrntt "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 ctrill or to deel3en Use "APPLICATION FOR PERMIT---s' for such proDos~is.) OIL r-'l GAS F-1 WELLI I WELL OTHER Gas T -~ ~--~,nj.~c~.on 2. NAME OF OPERATOR AtlantiC RiChfield Company 3. ADDRESS OF OPERATOR - P.O. 'Box 360; .Anchorage, 'AK 99510 .: .:.: .4. LOCATION OF WELL 5, APl NUMERICAL CODE 50-029-20174 6. LEASE DESIGNATION AND SERIAL NO, ^DL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. NGI #2 (11-7-11-15) 10. FIELD AND POOL, OR WILDCAT surface - 802'S & II14'E..of NW cr Sec .... 12,' T11N, R14E, UH at at'TD- 1155'S & 1325'~E of NW cr Sec'~. 7, T11N, R15E-, UM ].3._ ELEVATIONS (SHOW wheth, r. DF. RT~ GR, etc..) :-... i ..: .... . .. 18,,4' Pad.Levelm ' 14. Check Appropriate Box To Indicate Nature of Notice, Re Prudh°e-.Bay Unit - Sadlerochit ].1. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 7, TllN, R15E, UN 12. PERMIT NO. 75-52' )orr, 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 ABANDON* CHANGE PLANS Perforate SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT~ ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT.* (Other) (NOTEs Report results of multiple completion on Well COml31etlon or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all Pertinent ¢letails, end give pertinent dates, Including estimated date of starting any proposed work. Atlantic Richfield Company proposes to perforate additional selected intervals within the Sadlerochit interval. All perforated intervals will be reported on subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized with all wireline work. All perforations will be made with hollow carrier type guns at 4 shots per foot. After setting and testing the downhole safety valve, the well will be blown down and flared to the pit for cleanup only. A static bottom hole pressure will then be taken] Estimated Start Date: 3/6/78 16. i hereby certify that the foregoing Is true and correct SIGNED .~/~ ~P~ TITLE District Drilling Engineer DATE 2/23/78 (This space for State office use) CONDITIONS OF/~rp~ROV~L, IF ANY:' See Instructions On Reverse-Side DATE Approved ~.op¥ ~O01B . STATE of ALASKA TO: ~-- TO the Files DEPARTHE~ OF NATURAL RESOURCES 01vts~-on of 0t.1 and Gas Conservation .. FROM: DATE : I!I~,.,V' 10, lg77 Thomas R. Plarsha11, ~lr, Chiref Petroleum Geologist .... ~ .;~¥~ SUBJECT: Prudhoe Bay Field start-up Louis Burdon with Arco called and reported that on Play 6, 1977 NG! #2 started Injecting gas fnto gas cap for about 12 hours at 40 ~ncf rate. flad minor mechanical problem._, now beJng repaired, This completes start-up wtth all the different types of operation tn the fteld. Not all modules of equt'pment have. been shaken down, however. 024~)1B STATE" - A'iLAS A Hoyle TO:. ~--Otrector Thru: .Lennte C. Smtt~ ChJef Petroleum Engtneer DEPARTMENT OF NATURAL RESOURCES D1viston of 0tl and Gas Conservation DATE , March 29, 1977 FROM: Harold R. Hawkins Petroleum Inspector ~/'~/~ SUBJECT..~i~less Subsurface Safety Valve and Surface Control Safety Valve Tests for Arco NG! #2 ~a;~J?day, ~..r~.....1.'2,. 1977- ~ subsurface ~fety va]ye was all ready set ~fore I-~arr~ and Arco had just Completed a flow test. "The bombs were retrieved and the subsurface safety valve was closed with 3250 psi on the tubing. ~.~.SSSV was set at 2,235 feet. Arco's engineers wanted to leave 1500 psi ~ ~e tubing above the SSSV. This would be a 1.:75'0 .psi differential-below SSSV. I observed .the pressure of 1560 psi above the SSSV for I 1/2 houKs - three times the ordinary observation. Also the surface control safety valve and master valve were ~ested with no . :~'leakage. Tubing pressure below SSSV was 3250 .psi,- I~inos Hebert was operator for Arco. In s~ry: I observed the Subsurface safety valve and also the surface COntrot Safety valve and maser valve with no leakage. Tests were satisfactory. Attackmmnt ( ( ) 7. 'Wel 1'-Nos-. , , -, 8. Hrs~'-ObSer ' "~ ' - · & .~ . . ,... , ,..?-_ (;~.')¥ ( ) 24 Chokes~( )Remote( )Pos';'(~.lAdj.- 9. BS W..?';-;..'-i-,~.- '~,- "- =;;...:. ( ). ( ) 25. Test Plug-( )Wellhd(".)~sg( )none 10: G~; BblS': _'-, , , ;-I:,'i.-'I') 26,':"Annular'JPreventer, psig' : ) Final Abandonment ' ) 27. Blind Rams,_____psig 11. P&A Marker .~ .... ('-,) .(). 28. Pipe Rams __psig 12' Water well-( ')capped( )'plugged ( ) ( ) 29. "Kelly & Kelly-co,Ck _j~____psig ( ): ( ) 13. Clean'up' ('.) ( ) 30~. Lower 'Kelly valve psig' (.)- ( ) 14. Pad' leveled , ~, ' (') (.)~ 31.- Safety Floor val~,es-(' )'BV ( )Dart T;Otal.'inspectiOn observation time ~ {h~'s/days Total.-number leaks and/or eau_ip, failures .... v . . ·: - -. . . . ' . :; . . .... ~z.~z~, ...... . . . . . . cc: ~¢ ~/~ "otSfy 5n days or ~hen ready Inspected by ~ _ . ,;,-~.,~'.;.,' .... . -~., .-:-~..: · ._=. : .~.- . .-; <. STATE of ALASKA File: 3.14 500.41 TO; F Poyle Hamilton, Director Division of Oil and Gas FROM: Pedro Denton Chief, ~als Section. DATE SUBJECT: Mardi 17, 1977 We await your confirmation of the production capability of the subject wells as requested in ARCO's letters of March 15, 1977, copies of which were: ~sent to you. RECEIVED ~.tlanti~b'}~chfieldCompany North Ame~ Producing Division North Alas[ ~ ,istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 15, 1977 Mr. Hoyle Hamil ton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- NGI #2 (11-7-11-15) Permit No. 75-52 Dear Sir- Enclosed please find our Sundry Notice of Subsequent Report detailing the work done on the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /nb Enclosure RECEIVED MAR 1 Ig77 ~f Oil and .P:x$ Consewation Form 10-403 REV. 1-10-~73 Subml t "1 ntentlons" 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.) °w[~-OWELLGAS 0 OTHER Gas Injection 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL ^tsu,ace 802'S & ll14'E of NW cr Sec 12, TllN, R14E, UM At TD- 1155'S & 1325'E of NW cr Sec 7, TllN, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 18.4 Pad Level 14. Check Appropriate Box~o Indicate Nature of Notice, Rel NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) 5. APl NUMERICAL CODE 50-029-20174 6. LEASE DESIGNATION AND SERIAL NO. Surface' 28302 Btm hole: 34632 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudh0e Bay 9. WELL NO. NGI #2 (Il-7-11-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay - Sadlerochit 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 7, TllN, R15E, UM 12. PERMIT NO. 75-52 3ort, or Other Data SUBSEQUENT REPORT OF-' PULL OR ALTER CASING L_...J WATER SHUT-OFF MULTIPLE COMPLETE H FRACTURE TREATMENT ABANDON* SHOOTING OR AClDIZING CHANG E PLANS (Other) REPAIRING WELL ALTERING CASING ABANDONMENT* forate (NOTEt Report results of multiple completion on Welt 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. Installed wellhead house, 3/3/77. Installed. & tstd surf lines & conn. Press tstd manifold & tst separator. Press tstd .xmas tree to 5000 psi OK. RU & press tstd lubricator. Pulled dummy valve. RIH & perf'd w/4 shots/ft intervals 10,868' - 10,878', 10,858' - 10,868', 10,839, - 10,849', 10,755' - 10,785', 10,748' - 10,755' 10,715' - 10,732' & 10,643' - 10,673' RD perf unit. Ran & set ball valve'. ~ress tstd bal & control lines to 5000 ~si. Bled tbg press to 0 psi above ball valve. Ball valve held OK. Flowed we~l on choke sizes 16/64", 32/64" & 48/64" w/est max rate 38MM/day & max temp 88VF. Ran press & temp recorder. Flowed well to cleanup. Flow tstd well on choke 2ize 32/64" w/est 21 to 25MMCF/day, 57 bbls/MM. Flowing tbg press 3100 psi w/temp 86VF. Shut well in for 24 hr press build up tst. Operationally tstd ball valve. RD surf conn. Installed & tstd tree cap to 5000 psi. Released well to Production Department 0600 hrs 3-13- 77. RECEIVED .MAR 1 6 1977 D:vision ~f Oil snd ¢...~-;~ Ccnser/?.tion Anch0ra,~a 16. I hereby certlf_y that the foregoing is true and correct TITLE Di stri c't Dri 11 i no En§i neer DATE (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side North Alaska District Post Office'~ 360 Anchorage; ,-...aska 99510 Telephone 907 277 5637 March 15, 1977 Director, Division of~Lands Department of Natural Resources State of Alaska 323 E. 4th Avenue Anchorage, Alaska 99501 Attention: Mr. Pedro Denton, Minerals Officer Leasing Section Re: Request for Minimum Royalty Status ADL-34632 Dear Mr. Denton: A well has been completed on State of Alaska Oil and Gas Lease, ADL-34632, which is capable of producing in paying quantities. Attached for your information is a report of production test conducted on this well. The production test was witnessed by a representative of the Division of Oil and Gas Conservation. By copy of this letter, we are requesting that the Division of Oil and Gas Conservation furnish you the findings based on this test. In accordance with the lease provisions, it is now appropriate that the lease be placed on minimum royalty status. Please furnish us with a Decision Letter to that effect. Very truly yours, ATLANTIC RICHFIELD COMPANY C. R. McCiain Senior Landman CRM/gr cc: Mr. Hoyle H. Hamilton, Director ~tate of Ala~'~a Division of Oil and Gas Conservation A t t a chmen t RECEIVED Norlh Alask~Z',,, ',ric! Pos{ O~fice. 360 Anchorage, ,.~ aska 995'10 Telephone 907 277 5637 November 12, 1975 Mr. O. K. Gilbreth State of Alaska Department of Natural' ReSources Oil and Gas Division 3001 Porcupine Drive And~orage, Alaska 99504 Permit No. 75-52 Dear Sir: We are enclosing the Well Completion Report alongwith the Well History and Directional Survey for the above mentioned well. Sincerely, C. R. Knowles District Drilling Engineer CRK:alh Enclosures RECEIVED 1977 REPORT OF PRODUCTION TEST AND WELL STATUS ATLANTIC RICHFIELD COMPANY North Gas Injection #2 Well ADL- 34632 The North Gas Injection #2 well was directionally drilled from a surface location 802' S and 1114' E of the NW corner of Section 12, TllN, R14E, UM, Alaska. The bottom hole location and the location of the tested interval is in Section 7, TllN, R15£, UM, which is the SW section of ADL-34632. The top of the perforated interval at 10,643' measured depth is located 985' S and 1,102' E of the NWcorner of Section 7, TllN, RISE, UM. On March 11, 1977, a production test was conducted within the interval 10,643' MD to 10,878' MD and this test was witnessed by DiVision of Oil and Gas representative, Mr. Harold Hawkins. Copies of the Well Completion Report and test results are attached. Following the production test, the ball valve was closed and tested. The test was witnessed by the Division of Oil and Gas. The well has been shut in and will be used as a gas injection well when field production commences. NGI NO. 2 Well Test Information Division of Oil & Gas Representative' Mr. Harold Hawkins Interval Tested: 10643-10878' Test Method: Flow through test separator Date Tested: March 11, 1977 Test Results' 5/9/77 7' O0 PM to 12' O0 Midnight 3/10/77 9:00 PM to 12'00 Midnight Cleaned well up on chokes increasing from 16/64" to 48/64" Produced well to pit to warm up 3/11/77 Time Choke WHT FTP 0'45 A.M. 52/64 90° 5100 Comments Reduced choke to 52/64 1'00-3:00 32/64 88° 3100 Put flow thru line heater and separator, stabilized separator Flow Period #1, 32/64" choke, 3100#FTP, 86° Wellhead Temp., 3.250" Orifice Plate Time 3'00 3:15 3:30 3:45 4:00 4:15 Separator Fluid, Bbl Gas Measurement Rates* Pres. Temp. Cum. Delta stati'c''" Diff~ Temp. Sp. Gr.' Gas Bbl/~N Comments 1230 54 123.04 - 1260 43 56 15.0 - 1240 54 136.75 13.71 1260 73 56 21.0 62.7 1240 54 149.53 12.78 1255 74 56 21.25 57.7 1240 54 163.66 14.13 1255 75 56 21.25 63.8 1240 56 176.31 12.64 1250 75 56 .765 21.25 57.1 1220 56 189.87 13.56 1230 77 56 .760 21.50 60.5 · D'.v~bn cf Oil a~'~~ C .~ *Gas rates are uncorrected field calcula- tions, accurate data below 4:30 4:45 5:00 Time 6:15 6:30 6:45 7:00 7:15 7:30 7:45 8'00 8'15 1190 1190 1200 56 204.85 14.98 1210 77 56 21.25 67.6 56 215.55 10.70 1210 76 56 .765 21.25 48.3 56 228.50 12.95 1225 75 56 21.25 58.5 Liq. gravity 52.4° AP1 Flow Period #2, 40/64" choke, 3100# FTP, 96° Wellhead Temp., 4.000" Orifice Plate Separator Fluid, Bbl Gas Measurement Rates~ Pres. Temp. Cum. Delta st'atic'' Diff. Temp. Sp. Gr. Gas Bb%/MM 1200 50 276.46 - 1220 60 54 33.0 - 1200 52 297.55 21.14 1220 62 60 33.0 61.4 1230 53 319.23 21.68 1250 62 60 .770 33.5 62.1 1230 53 336.51 17.28 1250 62 62 33.5 49.5 1240 55 356.58 20.04 1260 62 63 .770 33.5 59.1 1240 57 375.25 18.67 1265 62 64 33.5 53.5 1220 57 391.70 16.45 1270 62 64 33.5 45.1 1220 58 409.15 17.45 1265 63 65 33.5 50.0 1230 59 427.70 18.55 1270 62 66 .754 33.5 53.1 Comments Liq. gravity 54.8° AP1 Time 8:45 9:00 9:15 9:30 9:45 10:00 10:15 10:30 10:45 Flow Period #3, 44/64" ck, 3100# FTP, 105° Wellhead Temp., 4.000" Orifice Plate Fluid,, Bbl ..Separator Gas Measurement Pres. Temp. Ctun. Delta Si~tic "Di'ff. Temp. 1350 60 470.61 - 1370 82 70 1340 66 488.30 17.69 1375 82 70 1340 76 511.40 23.00 1390 82 72 1350 76 533.50 22.10 1380 82 72 1350 77 554.25 20.75 1380 82 72 1350 77 576.21 21.96 1380 82 72 1350 77 597.30 21.09 1380 82 73 1350 78 617.10 19.80 1380 82 74 1350 79 652.92 35.82 1380 82 74 Rates~ Sp. Gr. Gas Bbl/MM 40.0 - 40.0 42.4 .757 41.0 54.0 41.0 51.7 41.0 48.5 41.0 51.4 41.0 49.3 41.0 46.3 41.D 83.8 RECEIVED Comments Gas thru liq. meter 11:00 11:15 11:30 11:45 12:00 12:15 12:30 12'45 Time 1:00 1:15 1:30 1:45 2:00 2:15 2:30 2:45 3:00 3:15 3:30 3:40 1350 79 673.80 20.88 1350 79 695.60 21.80 1350 79 715.16 19.50 1350 82 736.70 20.00 1345 84 756.70 20.00 1350 84 776.70 20.00 1350 84 798.20 21.50 1380 82 75 41.0 48.8 1380 83 75 41.0 51.0 1380 83 75 41.0 45.6 1380 83 75 41.0 50.5 1380 83 75 41.0 46.8 1380 83 75 41.0 46.8 1380 83 75 41.0 50.3 1350 84 818.87 20.67 1380 83 75 .753 41.0 48.4 Liq. gravity 54.2° AP1 Flow Period #4, 36/64" ck, 3150# FTP, 100° Wellhead Temp., 4.000" Orifice Plate ...Spparator Fluid, Bbl_ Gas Measurement Rates~ Pres. Temp. Cum. Delta $~ati¢ Di~I. Temp. Sp. Gr'. Gas Bbl/~N 1500 82 854.77 15.90 1320 44 75 29.0 52.6 1500 82 847.80 13.03 1320 44 75 29.0 45.1 1500 82 860.25 12.45 1320 44 75 29.0 41.2 1500 82 874.60 14.55 1520 44 75 29.0 47.1 1500 82 894.40 19.80 1320 44 74 29.0 65.6 1300 82 910.55 16.15 1320 44 73 28.5 54.4 1300 82 924.42 13.87 1320 42 73 28.5 46.7 1300 82 937.60 13.18 1340 42 73 29.0 43.6 1300 82 952.16 14.56 1340 43 73 29.0 48.1 1300 82 969.18 17.02 1350 43 72 29.0 56.3 1300 82 981.65 12.47 1350 43 72 29.0 41.2 Shut in well Comments Gas thru liq. meter Bottom Hole Pressure: Two Sperry Sun Pressure recorders at 10,878', one recorder ceased working. Bottom Hole Temperature 17.~°F, SIBHP 45Z0psig Flow Period Flowing BHP 1 4318 2 4312 3 4303. 4 4316 Well Capacity Calculations Rate, MMCFD Flowing BHP, PSIA 19.35 4332.6 24.48 4330.6 28.68 4326.6 34.20 4317',6 Flowing Temp. 86 100 100 105 Liquid Yield Bbl/MMCF Liquid rates were measured, however until PVT data are analyzed, actual gas li- quid ratios are unknown SIBHP 4334.6 PSIA Our calculations indicate a calculated Absolute Open Flow for NGI No. 2 of 104 FNCFD. RECEIVED 7 .,_, ..... ~,~,,. .... . ..... ._ ~ ~? h~~'~'' ~ :. .. . .~ .., ~'~ .............. ,Jq'Sh,.~ '. ~ ... ~ . ............ . .............. ~ .......... ~ ..... ~ .... , ;.~,.(: .' _.. ~n'/.~'o /o0 '¢oo ,.,, ~' ' "," ..... ,, . , '-' .~,,: ,~.~,o, o ~,~,0~.~ ~ .... · ....... . "."' ' . ' ' - _~__~. i _~ ....... ~q '*~ , 31~0 z~-~o /~ ~ ~ 1 .......... , _. ~ ............ _'.' ....... -.~.,~ ....... ,-~ ......~.'~ :~Z..[~ .'-'-. .......... i .... ~.:_ ..: ~ : . "~/:o ~-: Z~)o ~ :: ..... ~.~ :. .... ~ ....... '_. _.. ".L .............. 2.; ........... ' .... ' ._: ........ 1 ............. '- :: ;~:- -I ' ' 3~ ~..~d~.~' ~bsr~z '~"~ "~''''' ........ :" ' - ' ~ .... ~"~1 ..... i '': .' ........ · .... ', ; , . ......- _ _'.._ ~ .... ~ ...... ~ .:.~-- ',~ ' '1' ".~,~ )~'~od *h:~ .~- ~. lg~,z~ /~z~ I~O ~ · ~ t~¢ 7~ - "' ~,~: ~,8 · ~.~I ....7 z '/~' ' 'z-)oo t¢'f' z z~/¢% ~, ~,~ /¢~V~.s~ /2~0.~._ ,l.4~'¢~ ,/]~O 7.7 ') z/.~ ~o~' .:.: : ........... I.~-4~:- ~ l "_'L_L. .. .'- '" - , . . '' ' ... '~ ~'~::-:-- I . ' .. ' ,' ' '" ~ '.~" . t,. · . . ~ , ,,,?~4., ¢. ; 2..:.( . .:, , , ,... , ~:. ' " ..... '.' k . , ; / ' .-'," ~ " '' . ..., .' .... ':. '.., '..~ :...~'..-.',:~,";, . , . . ~ ~ .,,;., I~ntlcp, iCh fi,~ldCompsny r'~ . t33 ,, ' t: ....... '. '" '~' "~" ....... !" '~-~" "" ,"'~' "'""': ..... ~'° -'~':'~"~' "~ ...... ~ ~: ,~ " ~ ~'.,t° ~--"~~," "' ....... ~Zd~ ..... ; .... ~ ..... : ............................. , ........ ~-: ~,~ ...... ?~-~'~'[~'~%--"~-~ Size T~p, ~. Delta Press Temp. Sp,,GR, Temp Press Diff. 'Oil Wtr Gas BI~P ~P ~TE 'P.I;' CO2 ~2S CRAV. OIL ~ B.S. PP~ P~ ~ ::t:~,'-::: :':': :::' ~>~o ~ ~? d-.:*:~:,: ~0~1~ ~=,~:>~:~/:~t~ ~,~ .... ~"~F 6~/o ~:: ",:,-, ~'~, ~' q~:,'~ ' ..... : ...... ] .... ~ .... ~':---:-: ':, ........ :0 -~::c 2:0 .?,:-O:/z~o 5 ~ fo 0 ......... . ................... . : :~ __ ]~..:,, ............ " . .......... "'.' , ...... -::: . ................. . .... ~ .... , ,, ,, ...... ~ , , ~ ..... , , , . ~ :: -: .~, , , . ................... ·, . , ,, ' ~ ~ .~ ~-~ ..........t ~ ~ ...................... ~ ': .............................................. ~'~ :" .... ~ ,, · ~ ., .. ] ~ ..... , ...... ...... , . ,' , , . ..... , ....... ... .... ....... ~. ~..~:::_. . , ......... , ................. ' ' '" .... ' " " ....... · ........ .......... "'-~ ........... 1 .: ~ I, .- ! i _I ' "~:':" ....... .......... ~t NOON ' AtlanticRichfieldCompany North Ame~ Producing Division North Alask. ~istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 7, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject: NGI #2 (11-7-11-15) Permit No. 75-52 Dear Mr. Hamilton: Enclosed please find our Sundry Notice outlining our plans for the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /jw Enclosure Form 10-403 REV. 1-10-73 Submit "I ntentions" 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.) O,L F-! GAS i---! WELLL..J WELLL. J OTHER Gas Injection ~5. APl NUMERICAL CODE 50-029-20174 3. ADDRESS Of OPERATOR P. 0. Box 360, Anchorage, Alaska 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME NAMEOFOPERATOR 8. UNIT, FARM OR LEASENAME Atlantic Richfield Company Prudhoe Bay 99510 4. LOCATION OF WELL Atsurface 802'S & ll14'E of NW cr Sec 12, TllN, R14E, UM At TD:l155'S & 1325'E of NW cr Sec 7, TllN, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 18.4' Pad Level 14. Check Appropriate Box To Indicate Nature of Notice, Re 9. WELL NO. NOZ It2 (11-7-11-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay- Sadlerochit 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 7,, TllN~ R15E, UM 12. PERMIT NO. 75-52 )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~] PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Witness test SUBSEQUENT REPORT OF: WATER SHUT-OFF r-~ 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 ali pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Atlantic Richfield Company requests that a representative of the State Division of Oil and Gas be present to witness the production flow test and ball valve test. The production flow will be performed on 3/8/77 and the ball valve test approximately 72 hours after the production flow test. R ECEIVi!D MAR '? !977 16. I hereby certifY- that the foregoing is true and correct PPROv March 7, 1977 See Instructions On Reverse Side h;*' ~: Copy Retu~d ~tlantieRichfieldCompany North Ame,r~--'~ Producing Division North Alasl, istrict Post Office BOx 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 23, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: NGI #2 (11-7-11.-15) Permit No. 75~52 Dear Sir: :' · Enclosed please find our Sundry Notice of Subsequent Report detailing the work done on the above-mentioned well. Very truly yours, Frank M. Brown DiStrict Drilling Engineer /jw Enclosure RECEIVED Form 10-403 REV. 1-10~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY. NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) 1. O,L I'-'! GAS F--I Gas Injection WELLI I WELL 1 I OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3, ADDRESS OF OPERATOR P. 0. Box 360, .Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 802' S & 1114' of NW cr Sec ~ 12, T11 N, R14E, UM At TD- 1155'S & 1325'E of NW cr Sec 7, TllN, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 18.4' Pad Level 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20174 6. LEASE DESIGNATION AND SERIAL NO. ASL 28302 i7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. NGI #2 (11-7-11-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay - Sadlerochit 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 7, TllN, R15E, UN 12. PERMIT NO. 75-52 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSE(~UENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Comol eti on (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 elates, Including estimated date of starting any proposed work. Accepted rig @ 0600 hrs 1-29-77. NU & press tstd BOPE. Unlanded 7" tbg. Pulled out of PBR &circ CaCl~ wtr. Pulled & LD 7" Hydril tbg. Engaged top of PBR @ 9270' w/overshot & POH. Full REi~. Stabbed into top of pkr. P0H REC 3 steel bands in choke sub. RIH w/seal asbly. Sheared out of PBR.$et retrievable BP @ 1000'. ND BOPE. Rem & rep 9-5/8" csg pkoff. NU & press tstd BOPE. Retrieved BP. Press tstd 9-5/8" csg pkoff to 5000 psi. Ran 7" tbg comp. string. Unable to press tst. Pulled & LD 7" tbg strin9. PBR sea~s damaged. R[H w/shea~, engaged BPR. POH. No REC. R[H ~o PBR seve~a~ ~mes. No REC. Finally recoverd Baker anchor & PBR barrel. Milled out SAB pkr. Made bit & scraper run. Ran wireline junk bskt & gauge ring. Ran 7" 29~ N-80 8rd A-B mob tbg w/shear sub e 9470', Baker SAB pkr e 9335', sliding sleeve e 9209', ball valve nipple e 2194' Press tstd tbg head pkoff OK. Displ tbg w/diesel. Dropped ball & set pkr. N~ & press tstd xmas tree to 5000 psi. Pulled dummy valve. Ran GR/CNL/CCL log. Ran & set dummy valve. Hooked up for 48 hr press tst. Released rig e 0600 hr 2-20-77. RECeiVeD 16. I hereby certify that the foregoing is true and correct TITLE District Drilling Engineer~ATE (This space for State office use) APPROVED BY. CONDITIONS OF APPROVAL, IF ANY; TITLE DATE See Instructions On Reverse Side · AtlanticRichfieldCompany North Amed-'~ Producing Division North Alas, .4strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 8, 1977 Mr. Hoyle Hamil ton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' NGI #2 (11-7-11-15) Permit No. 75-52 Dear Sir: Enclosed please find our Sundry Notice outlining our change of plans for the above-mentioned well. Very truly yours, H. E. McIntire, Jr., for Frank M. Brown District Drilling Engineer /jw Enclosure RECEIVED FEB - g 1977 Division of 0ii ~nd (~aa Conservation Afl~hora~ia Form 10-403 REV. 1-10-73 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Submit "Intentions" in Triplicate & "Subsequent Re0orts" in Duplicate 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.) WELLO'L.[]] WELL GAS [--1 OTHER Gas Injection NAME OF OPERATOR Atlantic Richfield Company 3, ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL 5. APl NUMERICAL CODE 5.0-029-20174 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudh0e Bay 9. WELL NO. NGI #2 (11-7-11-15) 10. FIELD AND POOL, OR WILDCAT At surface 802'S' & lll4'E of NW cr Sec 12, TllN, R14E, UM At TD: l155'S & 1325'E of NW cr Sec 7, TllN, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 18.4' Pad Level Check Appropriate Box To Indicate Nature of Notice, Re Prudhoe Bay - Sadlerochit 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) .. SeC 7, . T.l.1N.,. R].SE?~ UM 12. PERMIT NO. 14. 75-52 3ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING g-_J MULTIPLE COMPLETE ABANDON* CHANGE PLANS _ - SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) · 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS ({~'learly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Atlantic Richfield Company proposes to perforate the intervals as follows' 10,414' - 10,439'; 10,458' - 10478'; 10497' - 10512'; 10527' - 10547'; 10,565' - 10,580'; 10,596' - 10,631'; 10643' - 10663'; 10858' - 10878'. A 5000 WP wireline lUbricator, tested to working pressure will be utilized with all wireline work. All perforations will be made with hollow carrier guns at four shots per foot. The downhole safety valve will be installed upon conclusion of perforating. Well will then be flowed to burn pit for clean-up only. Bottom hole static pressures will be measured wi th downhole pressure bombs run on wireline. RECEIVED This work is currently in progress. Divl~101~ e! 01t an~l ~{~ ~ni~rvati01~ 16. I hereby certify that the fore. go)nc is true and correct ... ....... ...-~-_-~,~ .,/- ~ - ,' . .- / ...... SIGNED" TITLE District Drilling Engineer DATE February 8, 1977. · (This space for State office use) ,,"~ ' etroleum Engineer 2-14'77 · ': "~,PPRC[VEI~ B~' . L _. TITLE .......... DATE CONDITIONS OF APPROVAL IF A ' ' ' ~: Ball valve test to be witnessed by State representative', See Instructions On Reverse Side ~eoved Copy Relumed .,{lan!icRichfieldCompany / North Ame~.i~'.~ Producing Division North Alas: ,strict Post Office E~6x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 31, 1977 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: NGI #2 (11-7-11-15) Permit No. 75-52 Dear Sir: CONFE2: FILE: i Enclosed please find the Monthly Report of Drilling Operations for the above mentioned well. Sincerely, Frank M. Brown District Drilling Engineer /jw R Ci:IVED Enclosures F r: r~ - ~ 1977 l)lvlli~n ~+ ui: r~aJ 6!~ Conservation REV. 3- I-?0 STATE OF ALASKA OIL AND GAS CONSERVATION CO/V~ITTEE SUBMIT I1~ DLTPLICAT~ MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS AP1 NUMERICA. L CODE 50-029-20174 6 LEASE DESIGI~ATION AND SEi~IAL NO. ADL 28302 1. T. IF INDIAN~, ALOi Ik~: OR TRIBE NAME o,L []] o~. l-'-I o,,-, Gas Injection WgLL WI~LL 2. NAME OF OPEI%ATOR Atlantic RiChfield Company 3. ADDRESS OF OPEP,,ATOR P. O. Box 360, Anchorage, Alaska LOCATION OF W 99510 802'S & lll4'E of NW cr Sec 12, TllN, R14E, UM 8. UNIT,FARM OR LEASE NAME Prudhoe Bay 9. WELL NO NGI #2 (11-7-]1-15) 10. F~ A_N'D POOL. OR WILDCAT Prudhoe Bay - Sadlerochit II. SEC.. T., R., M.. (BOTTOM HO]~E Sec 7, TllN, R15E, UM 1~-, PERMIT NO. 75-52 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOL~ USED, PERFORATIONS, TESTS ~ RESULTS. FISHING JOBS. JUNK IN HOLE AND SIDE-TI~ACKED HOLE AND A_NY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Accepted rig @ 0600.hrs 1-29-77. NU & press tstd BOPE. PU & unlanded 7" tbg. Pulled out of PBR & circ CaCle wtr. As of January 31, 1977, fin pulling & LD 7" Hydril. Chgd & press tstd 5" r~ms. PU 5" DP. 14. I hereby certify that the ioregoin~ is true and correct /~ / s,omm~~~.. ~ :~ Dist. Orillin. Enoinaaw o^~ / 72 NOTE --Roi)or! on this form Is required for tach calender months regardless of the status of operations, and must be flied in duplicate with the otl end gas coneervotlon committee by tho Itth of the succeeding month, unless otherwise directed. AtlanficRichfieldCompany ¢ North Amed~! Producing Division North Alask .strict Post Office bux 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 20, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' NGI #2 (11-7-11-15) Permit No. 75-52 Dear Sir' Enclosed please find our Sundry Notice outlining our plans for the above-mentioned well. Very.. truly yours, FILE: Frank M. Brown Di stri ct Dri 11 ing Engineer FMB/jw Enclosure / ~orm 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.) 5. APl NUMERICAL CODE · 50-029-20174 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 1. OIL F--'l GAS r--l OTHER Gas Injection WELLL--J WELL 2. NAME OF OPERATOR 8, UNIT, FARM OR LEASE NAME Atlantic Richfield Comapny Prudhoe Bay 3. ADDRESS OF OPERATOR 9. WELL NO. P. 0. Box 360, Anchorage, Alaska 99510 NGI #2 (11-7-11-15) ,, 10. FIELD AND POOL, OR WILDCAT 4. LOCATION OF WELL At surface 802 ' S & lll4'E of NW cr Sec 12, TllN, R14E, UM At TD' l155'S &-1325'E of NW cr Sec 7, TllN, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 18.4' Pad Level 14. Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SHOOT OR ACIDI'ZE REPAIR WELL (Other) Perforate Prudhoe Bay - Sadlerochit 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 7, TllN, R15E, UM 12. PERMIT NO. 75-52 )ort, or Other Data 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 Recompletlon 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 perforate the intervals as follows: 10414' - 10439'; 10458' - 19478'; 10497' - 10512'; 10527' - 10547'; 10565' - 10580'; 10596' - 10631'; 10643' - 10663'; 10716' - 10731'; 10753' - 10788'; 10858' - 10878'. A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized with all wireline work. All perforations will be made with 3-1/8" Jumbo Jet hollow carrier guns at four shots per foot. The downhole safety valve will be installed upon conclusion of perforating. Well will then be flowed to burn pit for clean-up only. Bottom hole static pressures will be measured with downhole pressure bombs run on wireline. Estimated start date, February 1, 1977. RECEIVED JAN 2 4 1977 Division of 0il and Gas C0n~erv~tt0n 16. I hereby certify that the foregol~ng is true and correct TITLE District Drilling EngineerDATE January 20, 1977 ...... (this space for State office u.se) __ CONDITIONS OF A(~P~ROVAL, IF ANY: ' See Instructions On Reverse Side Approved Copy Retumed North Alaslf,~istrict Post Office 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 14, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK-99501 Subject: NGI No. 1 (33-12-11-14) ~N~I No. 2 (11-07-11-15) NGI No. 3 (32-11-11-14) NGI No. 4 (13-06-11-15) NGI No. 5 (33-01-11-14) Dear Sir: Enclosed are our Sundry Notices outlining recompletion plans for the above-mentioned wells. .Very truly yours, C R,. Knowles District Drilling Engineer CRK/Cs Enclosures ';. 1976 - · Fo rm ~0~403 REV. 1-10-3'3 Submi t "I ntentlons" 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.) OIL !---! GAS F~ WELL! d WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Company- 3. ADDRESS OF OPERATOR P.O. 8ox 360,. ^nchora§e, Al( 99510 4. LOCATION OF WELL At surface 802'5 & lll4'E of NW cr of Sec 12, TllN' R14E, · ~ UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 47' RKB 14. CheCk Appropriate Box To Indicate Nature of Notice, Re! 5. APl NUMERICAL CODE 50-029-20174 6. LEASE DESIGNATION AND SERIAL NO. ADL 34632 (Bottom Hole) ADL 28302 (Surface) 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudh0e BaT. 9. WELL NO. NGI No. 2 (Il-7-11-15) 10, FIELD AND POOL, OR WILDCAT Prudhoe Bay-Sadlerochit Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 7~ TllN, R15E, UM 12- PERMIT NO. 75-52 3orr, or Other Data SUBSEQUENT REPORT OF-' NOTICE OF .INTENTION ~Tt:)~: FRACTURE TREAT MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING SHOOT OR AClDIZE ABANDON* SHOOTING OR ACIDIZING ABANDONMENT* REPAIR WELL CHANGE PLANS (Other) (other) COMPLETION (NOTE: Report results of multiple completion on Well · Completion or Recompletlon 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 recompletion of this well in "·Sept. 1976. A rig utilizing 13-5/8" 5000 psi Shaffer LWS BOP's (one double plus one single) and a spherical BOP will be used. The 7" Hydril tubing will be pulled. A completion string comprised of a Baker Oil Tool Model "SAB" Production Packer (set at ' 9272 ' MD) .PBR mandrel and Otic "HQ" 1.anding nipple with .dummy valve in place will be run with 7" 29# L-80 LT&C 8rd A-B Modified tubing. A 6" 5000 psi tree will be installed and the completed well left unperforated with diesel in the tubing down' to'the;PBR. Prior to setting the packer' and nippling up the xmas tree, all work will be done in a calcium chloride brine with a 300·psi overbalance. 16. ! hereby certify that the foregoing is true and correct District Drlg Engineer DATE-July 15., 1976 ., (This space for State office use) See Instructions On Reverse Side Copy ?tla,~ticR, ichfieldCom pany North Am~ ~ Producing Division North Alaslk~ uiStrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 25, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99504 Subject' NGI No. 1 (33-12-11-14) NGI No. 2 (Il-07-11-15) NGI No. 3 (32-11-11-14) Dear Sir: Enclosed are our Sundry Notices outlining recompletion plans for the above-mentioned wells. Very truly yours, C. R. KnoWles District Drilling Engineer CRK/JWS/jr Enclosures Approved ai:~y Returned ,morn;, 1 O-403 REV, 1-].(3-73 Submit "1 ntentlons" In Triplicate & "SubseQuent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SuNDRy NOTICES AND REPoRTs ON WELLS (Oo not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 5. APl NUMERICAL CODE 50-029-20174 6. LEASE DESIGIN~TION AND SERIfi. I_ NO. ADL 34632(B0tt0m H01e} ADL 28302 (Surface) 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 1. WELLr-'-jg.-a GAS W E L L~,~ OTHER 2. NAME OF OPERATOR ·Atl anti c Ri chfi el d Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, AK 99510 4. LOCATION OF WELL At surface 802'S & ll14'E of NW cr of Sec 12, TllN, R14E, UM 8. UNIT, FARM OR LEASE NAME Prudhoe Bay :9. WELLNO. NGI No. 2 (Il-7-11-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay-Sadlerochit Pool 11, SEC., T,, R,, M., (BOTTOM HOLE OBJECTIVE) ISec 7, TllN, R15E, UM 12. pERMIT NO. 75-52 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 47' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF,, TEST WATER SHUT-OFF J____J FRACTURE T REAm SHOOT ORACIDIZE REPAIR WELL (Other) COMPLETION pULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS WATER SHUT-OFF FRACTURE TREATMENT SHOOTING OR ACIDIZING (Other) REPAIRING WELL ALTERING CASING ABANDONMENT* (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 recompletion of this well in July,.1976. A rig utilizing 13-5/8" 5000 psi Shaffer LWS BOP's (one double plus one single) and a spherical BOP will be used. the 7" Hydril tubing will be pulled. A completion string comprised of a Baker Oil Tool Model "SAB" Production Packer (set at 9272'MD) PBR mandrel and Otis "RQ" landing nipple with dummy valve in place will be run with 7" 29# L-80 LT&C 8rd A-B Modified tubing. An oil fluid will be left in the 9-5/8" x 7" annulus and in the tubing. A 6" 5000 psi tree will be installed and the completed well left unperforated. o 16. I hereby certify that the foregoing is true and correct SIGNED dJ~~ TITLE District Drlg Engineer DATE .May 25~ 1976 ( rhis space for State office u~) CONDITIONS OF~.~PPROVAL, IF ANY: See Instructions On Reverse Side Approved Copy Returned State of Alaska Division of Oil & Gas Attn: Mr. John Levorsen 3001 Porcupine Dr. To: Anchorage, AK Atlantic Richfield Company North Alaska District TRANSMITTAL From: R.A. McIntosh -.North Geological Date: 12/19/75 Well Name: North Gas In~ection Well f~2 Transmitted herewith are the following for the subject well: Run No. Scale Xerox Sepia_ BI Line BHC Sonic/Caliper Log . BHC Sonic/Caliper-Gamma Ray Log BHC Sonic-Gamma Ray Neutron Cement Boad Log Continuous Dipmeter (HPD) Continuous Dipmeter Polliwog Plot Continuous Dipmeter Printout Core Analysis Interval Core No. Core-Description~ (SWC) Inter~al ....... Core Description (Conv) Core No. Directional Log Drill Stem Test - Test No. Dual Induction Laterolog Compensated Formation Density Compensated Neutron Formation Density Gamma Ray-Neutron Microlog Mudlog Interval Pr oximity-Microlo g/Caliper Log Sample Log (ARCO) Interval Sidewall Neutron Porosity Samples (SWC) Interval No. Boxes Sample's (Conv) Core No. No. Boxes x Samples (Dry) Interval 4450'-11,000' No. Boxes Samples (Wet) Interval No. Boxes Synergetic Log . Receipt acknowledged: ~ . Return receipt to:' Atlantic Richfield Company North Alaska District Attn: District Geologist P.O. Box 360 Anchorage, Alaska 99510 Date: AtlanticR [chfieldCompany North Amerr~Producing Division North Alaska _ ..strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 12, 1975 Mr. O. K. Gilbreth State of Alaska Department of .Natural Resources Oil and Gas Division 3001 Porcupine Drive Anchorage, Alaska 99504 Permit No. 75-52 Dear Sir' We are enclosing the Well Completion Report along with the Well History and Directional Survey for the above mentioned well. Sincerely, C. R. Knowles District Drilling Engineer CRK'alh Enclosures Form P - 7 _ WELL cOMPLETION OR RECOMPLETION REPOR~iA:NiD::LOG* ' l'a. TYPE OF WELLI on', ' w ELL --d ....... b. TYPE OF COMPLETION: 3. ADDRESS OF OPERATOR P. 0. Box 360, Anchorage ~ A1,,aska 99510 4. LOCATION OF WELL (Rel~ort location clearly and in accordance with any State requ~rementa)* ~t~a,e 802~FNL [ lll4~FWL, Sec 12, TllN-R14E, gM At top prod. interval reported below 1075'FNL ~ 990'FWL, Sec 7, TllN-RiSE, gM At total depth " · IDI 1':: I::, I ...... I' :i,: STATE OF ALASKA ,--~.~ ~. ~:~e;FLho~mt.:'~ ,~ OIL AND GAS CONSERVATION COMMITTEE ..... '~ ..... ~[ '~ " ! 6J'L~E D~IGNA~ON ~D SER~L NO. . ~L 28502 2. ~ o~ o~o~ Pm~oe Bay Atl~tic Richfield Co~y ~. w Pm~oe Bay, SadlerochSt u. s~c., ~.. a., ~.. <eo~o~ ao~ Pool O~E~IVE) Sec 7, TllN-~SE, ~ 12, P~IT ~O. 1155~F~ ~ 1525~, Sec 7, TllN-R15E, ~ 75-52 10-12-75 11-4-75 i 11-20-75 ~ 18.4 Gravel Pad,(~7~ TOTAL DEPTH, ~LD & TVD~9. PLUG, B~C'K MD & TVD~0. IF ~LT~LE CO~L., ~{ 21. 11002'~ (8567'~[ 10917'~ (8497'~):~~' I .oz~ ~ooi~1 PRODUCING !N~VAL(S), OF ~IS COMP~TIO~--TOP, BOSOM, NAME (~ AND 10,408'~ (8085'~) Top Sadlerochit 10,946'~ (8521'~) BaSe Sadlerochit INTERVALS DR[I,L~D BY CABLE TOOLS None ,23. WAS DIRECTIONAL ! SURVEY MADE . ~ yes 24. TI~PE ELECTRIC AND OTHEI% LOGS RUN DIL, GHCS/GR, FDC/CNL/GR and CBL/VDL CASING RECORD (Report all strings set in W~ll) 20" 94~ [ H:40 180' 32" 240 sx Pemafrost II 13-3/8" 72~ ~-80 ~2688' 17-1/2"~ 5100 sx Pemafrost II , 9-5/8" 47~ ! -80 19830, ! 12,1/4"{:1000 sx Cia, s G .... 26. LINER ~CO~ 27. TUBING RECOF~ 7 9535' ' 400 7" 9408' q272 ' 28. PE~OR. ATIONS OP~ TO PRODU~O (interval SQUEeZe, size and number) 29. ACID, SiiOT, F;~AC~'URE, C~IENT ~C. D~i 1NT~V.~ (MD) ~ AMOUNE 2~D I'2!ND OF MATEPIAL US~ i iii ii i i i ii i i i i ii ii 30, P~ODUCTION DATE FI~PfLODUCTION. [ ~ODUCTION MEI t{OD (FiowiDz, Fas lift, pdmP~lg--size and type of pump) ~ VdELL STATUS (Pr0duckn~ or i ~%-, TLTBING CAS~G PRESSURE, ~[CAL~~ OI~BBL GA~rvICF. WA~BBL. :~SS. r ' I24-HOUR RA~ OIL GRAVITY-~I (coRR.) 'oas (Sold; used tar el, Cented, etc.) TE~T ' X['ITN~SS~D Drilling HiS~ ~d Gyro surey 33. I hereby certify that the foregoing and attached information la complete and correct aa ~etermined from ~lVaYallable re~ords ' *(S~e 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 measure- mentsgiven in cther 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 completion), so state in item 20, and in item 22 show the ptc. Jucing 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 inte.~val to be seperately produce'J, show- ing the acklitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should 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 produc~J. (See instruction for items 20 and 22 above). 34. SUMMAHY OF 'IoORMATION TESTS INCLUDIN(; INTERVAL TESTED. PHE. SSURE DATA. ~ ~OV~I~ OF OIL. GAS, 35. G~GIC ~ARK~ WA~ AND MUD Top Sadlero~it 10408.' 8085' Base Sadlero~it 10946~ i 8521~ I . . ~'~~i) SIIO~S O~ OIL. G~ ~ ~. I ........................ Atlantic Richfield Company NGI No. 2 (11-7-11-15) API 50-029-20174, ADL 28302, Permit No. 75-52 Drilling History Spud @ 7 PM 10-12-75. Drilled 17-1/2" hole to 2712'. Ran 13-3/8" casing to 2688', ~cementedw/5100 sx Permafrost II cmt w/full returns to surface. Recemented 13-3/8" x 20".~annulus w/PF II thru 2-3/8" risers. Landed and cut off casing, installed and tested casing head. NU and test BOPE. Drilled float collar, cement shoe and 10' of formation; test to 0.65 psi/ft okay. Directionally drilled 12-1/4" hole to 9860'. Ran DIL. Ran 9-5/8" casing to 9830' w/float collar @ 9740', FO tools at 2396' and 2642'. Cemented w/1000 sx Class G cmt. ND BOPE, set 9-5/8" packoff, N~head. Change rams, test BOPE. RIH, cemented thru lower FO w/125 sx Permafrost II. Closed FO and reversed out. Opened upper FO, circulated out 9-5/8" x 13-3/8" annulus w/mud, washed w/water, pumped 342 bbl Arctic Pack; 0% excess water @ end of job. Closed FO, tested to 3000 psi. RIH w/8-1/2" BHA, drilled out cement, shoe and drilled 10' of formation; tested to 0.62 psi/ft. Drilled to 11,002'. POH. Ran DIL, BHCS/GR and FDC/CNL/GR logs. Ran 7" liner to 11000'. Dropped setting ball and set liner hanger. Cemented liner w/400 sx Class G cmt. Trip out w/setting tools. RIH w/8-1/2" bit and scraper, drilled cement stringer from 8900' to 9535' top of liner. POH. RIH w/RTTS, set @ 9326' Tested below RTTSw/3500 si okay. pOH RIH w/6" ; ~ . P __ · _ bit, cleaned out to 10917 , tested casing to 3000 psi, POH. RIH w/WSO tools, set @ 9500'. Opened tools w/weak blow for.3 minutes, 'then dead rest of 1 hour open. Shut in for 1 hour, POH. Ran GR/CCL, Gyro and CBL/VDL. RIHw/bit, reversed out mud w/water and water w/diesel. Checked for flow. LDDP. Ran 7" completion assembly w/shear sub @ 9408' packer @ 9272' and'R__Qni_pple @ 2198'. Set BPV, landed tubing on hanger and tested padkoff to 3000 psi. ND BOPE, NU and test tree. Dropped ball, set packer. Ran 2-7/8" dummy perf gun to 10,896'. Released Rig @ 10 PM 11-20-75. Suspended Gas Injection Well. SURVEY I~---] UIDANCE r~'IONTINUOUS [-flooL Company ARCO ALASKA~ INC. Well Name NGI-2 (802' FNL,114' FWL,SEC Field/Location PRUDHOE BAY, NORTH ~;LOPE. 12~T11N~RI~rE.UM) ALASKA Job Reference No. 73687 Lo(:j{3ed BY; PORTER Date, 1 -0CT-89 Computed By; KOHRING SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA~ INC. NGI-2 PRUDHOE BAY NORTH SLOPE~ ALASKA SURVEY DATE: 1-0CT-1989 ENGINEER: PORTER METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 87 DEG 48 MIN EAST DATA FROM SURFACE TO 10680' ACQUIRED ~ITH TANGENTIAL METHOD FROM SCHLUMBERGER GCT TOOL. OATA FROM 10900" TO 1100Zm ACQUIRED WITH RADIUS' DF CURVATURE METHOO FROM MEASURED WHILE DRILLING SURVEY. MWD DATA TIED TO GCT DATA AT DEPTH 10680.0e. COMPUTATION DATE: O2-MAR-90 PAGE ARCO ALASKA, INC. NGI-2 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 1-0CT-1989 KELLY BUSHING ELEVATION: 47.00 FT ENGINEER: PORTER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE qEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH OEPTH DEG MIN DEG MIN 0.00 0.00 -47.00 0 0 N 0 0 E 100.00 100.00 53.00 0 13 N 16 18 W 200.00 200.00 153.00 0 7 S 53 30 W 300.00 300.00 253.00 0 20 S 0 23 W 400.00 400.00 353.00 0 25 S 13 37 W 500.00 499.99 452..99 0 25 S 4 39 E 600.00 599.99 552.99 0 24 S 10 56 E 700.00 699.99 652.99 0 I S 54 9 W 800.00 799.99 752.99 0 3 S 85 53 E 900.00 899.99 852.99 0 I S 56 51 E 1000.00 999.99 952.99 1100.00 1099.99 1052.99 1200.00 1199.99 1152.99 1300.00 1299.99 1252.99 1400.00 1399.99 1352.99 1500.00 1499.99 1452.99 1600.00 1599.9'9 1552.99 1700.00 1699.99 1652.99 1800.00 1799.99 1752.99 1900.00 1899.99 1852.99 0 6 N 9 23 E 0 2 N 36 2 W 0 6 N 2 28 E 0 9 S 82 35 0 5 N 53 36 E 0 4 S 72 3 E 0 13 N 5 34 E 0 8 N 37 52 E 0 2 N 89 59 W 0 18 S 63 6 E 2000.00 1999.99 1952.99 2100.00 2099.98 2052.98 2200.00 2199.98 2152.98 2300.00 2299.98 2252.98 2400.00 2399.98 2352.98 2500.00 2499.98 2452.98 2600°00 2599.97 2552.97 2700.00 2699.97 2652.97 2800.00 2799.95 2752.95 2900°00 2899.64 2852.64 026 S 37135 0 27 S 16 40 E 0 I N 66 Z W 0 27 It 41 10 E 0 32 N 64 28 E 0 26 N 73 8 E 0 21 S 69 21 E I I S 60 85 1 43 S 79 29 E 654 N 88 18 E 3000.00 2998.31 2951.31 11 2 3100.00 3096.13 3049.13 12 25 3200.00 3193.67 3146.67 13 14 3300.00 3290.63 3243.63 15 1 3400. O0 3386.90 3339.90 16 24 3500.00 3482.34 3435.34 18 27 3600.00 3576.52 3529.52 20 42 3700.00 3669.62 3622:.62 22 6 3800.00 3761.79 3714.79 23 31 3900.00 3852.98 3805.98 25 6 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH .FEET OEG/IO0 FEET FEET FEET OEG MIN 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 N 0.00 W -0.09 0.51 0.09 N 0.09 W -0.15 0.17 0.35 S 0.17 W -0.22 0.09 0.88 S 0.2.5 W -0.20 0.35 1.64 S 0.27 W -0.17 0.36 2.29 S 0.26 W -0.03 0.18 2.62 S 0.13 W -0.02 0.00 2.70 S 0.12 W 0.00 0.00 2.68 S 0.10 W 0.07 0.12 2.63 S 0.03 W 0.06 0.35 2.54 S 0.04 W 0.12 0.00 2.33 S 0.03 E 0.19 0.03 2.24 S 0.10 E 0.42 0.09 2.16 S 0.34 E 0.54 0.00 2.14 S 0.46 E 0.65 0.18 1.83 S 0.58 E 0.71 0.71 1.61 S 0.65 E 0.75 0.00 1.39 S 0.70 E 0.97 0.50 1.55 S 0.91 E 0.00 N 0 0 E 0.00 N 16 49 W ~ 0.12 N 45 11 W 0.38 S 25 37 W ' 0.92 S 16 4 W 1.67 S 9 12 W 2.31 S 6 26 W 2.62 S 2 50 W 2.70 S 2 33 W 2.68 S 2 12 W 1.55 0.92 1.88 S 1.48 E 2.05 1.64 2.65 S 1.95 E 2.05 0.00 3.05 S 1.93 E 2.32 0.69 3.01 S 2.21 E 2.BO 0.00 2.67 S 2.70 E 3.44 0.25 2.35 S 3.35 E 4.03 0.40 2.39 S 3.94 E S.O0 0.23 2.75 S 4.90 E 6.52 4.73 3.60 S 6.39 E 13.99 '5.41 3.94 S 13.85 E 2.63 S 0 37 W 2.54 S 0 57 W 2.33 S 0 43 E 2.24 S 2 37 E 2.19 S 8 56 E 2.18 S. 12 7 E 1.92 S 17 31 E 1.74 S 21 55 E 1.56 S 26 33 E 1.80 S 30 21 E S 89 21 E 30.08 2.77 S 88 57 E 50.84 0.55 S 87 31 E 72.84 1.92 S 86 50 E 97.30 1.46 S 86 6 E 124.35 1.54 S 86 9 E 154.15 2.39 S 86 46 E 187.73 1.80 S 87 28 5 224.23 1.49 S 87 35 E 263.01 1.40 S 87 36 E 304.06 1.96 2.40 S 38 15 E 3.29 S 36 28 E 3.61 S 32 21 E 3.73 S 36 12 E 3.80 S 45 22 E 4.09 S 55 0 E 4.61 S 58 43 E 5.62 S 60 43 E 7.34 S 60 35 E 14.40 S 74 9 E 3.72 S 29.96 E 30.19 S 82 55 E 4.08 S 50.72 E 50.88 S 85 24 E 4.79 S 72.71 E 72.86 S 86 14 E 5.95 S 97.14 E 97.32 S 86 30 E 7.63 S 124.14 E 124.38 S 86 29 E 9.70 S 153.89 E 154.20 S 86 24 E 11.79 S 187.42 E 187.79 S 86 24 E 13.58 S 223.88 E 224.29 S 86 32 E 15.26 S 262.62 E 263.06 S 86 41 E 16.94 S 303.63 E 304.10 S 86 48 E COMPUTATION DATE: 02-MAR-90 PAGE 2 ARCO ALASKA, INC. NGI-2 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 1-0CT-1989 KELLY BUSHING ELEVATION: 47.00 FT ENGINEER: PORTER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000.00 3942.70 3895.70 27 25 4100.00 4030.10 3983.10 30 47 4200.00 4114.28 4067.28 34 31 4300.00 4195.03 4148.03 37 47 4400.00 4273.12 4226.12 38 4 4500.00 4353.13 4306.13 137 4 4600.00 4431.21 4384.21 40 25 4700.00 4505'.25 4458.25 43 55 4800°00 4575.13 4528.13 47 21 4900.00 4640.51 4593.51 51 7 S 85 44 E 348.19 3.17 S 84 6 E 396.67 3.7'7 S 82 37 E 450.46 3.46 S 80 48 E 509.06 3.74 S 85 20 E 571.18 8.09 S 88 56 E 631.14 2.85 S 89 22 E 693.57 4.21 S 88 35 E 760.75 3.65 S 87 49 E 832.26 3.10 S 87 20 E 907.89 3.52 19.42 S 347.70 E 348.24 S 86 48 E 23.81 S 396.04 E 396.76 S 86 34 E % 30.04 S 449.63 E 450.64 S 86 11 E 38.64 S 507.95 E 509.42 S 85 39 E 47.29 S 569.79 E 571.75 S 85 15 E 49.53 S 629.71 E 631.65 S 85 30 E 50.36 S 692.15 E 693.98 S 85 50 E 51.57 S 759.33 E 761.08 S 86 7 E 53.84 $ 830.80 E 832.54 S 86 18 E 57.09 S 906.37 E 908.17 ' S 86 24 E 5000.00 4700.76 4653.76 54 40 5100.00 4757.35 4'710.35 56 2 5200.00 4813.25 4766.25 55 58 5300.00 4869.34 4822.34 56 2 5400.00 4925.17 4878.17 55 56 5500.00 4981.13 4934.13 55 54 5600.00 5037.42 4990.42 55 36 5700.00 5093.89 5046.89 55 28 5800.00 5150.44 5103.44 55 42 5900.00 5206.83 5159.33 55 25 S 96 48 E 987.67 5 86 35 E 1070.10 S 86 27 E 1152.99 S 86 18 E 1235.76 S 86 7 E 1318.69 S 86 10 E ' 1401.53 S 86 24 E 148~.15 S 86 19 E 1566.65 S 86 8 E 1649.10 S 85 52 E 1731.63 2.89 1.84 0.43 0.89 0.57 0.96 0.20 1.26 0.46 0.78 61.21 S 986.05 E 987.95 S 86 27 E 66.00 S 1068.35 E 1070.39 S 86 28 E 71.06 S 1151.11 E 1153.30 S 86 28 E 76'.35 S 1233.74 E 1236.10 S 86 28 E 81.90 'S 1316.51 E 1319.06 S 86 26 E 87.57 S 1399.20 E 1401.93 S 86 25 E 93.02 S 1481.67 E 1484.58 S 86 24 E 98.24 S 1564.03 E 1567.11 S 86 24 E 103.66 S 1646.33 E 1649.59 S 86 24 E 109.51 S 1728.70 E 1732.17 S 86 23 E 6000.00 5263.47 5216.47 55 20 6100.00 5320.37 5273.37 55 10 6200.00 5377.37 5330.37 55 12 6300.00 5434.48 5387.~8 55 5 6400.00 5491.57 5444.57 55 Z 6500.00 5548.97 5501.97 54 54 6600.00 5606.08 5559°08 55 29 6700.00 5662.78 5615.78 55 25 6800.00 5719.60 5672.60 55 23 6900.00 5776.62 5729.62 54 54 S 85 49 E 1814.00 S 85 40 E 1896.18 S 85 40 E 1978.29 S 85 32 E 2060.31 S ~5 33 E 2142.35 $ 85 7 E 2224.16 S 85 8 E 2306.15 S 85 13 E 2388.44 S 85 15 E 2470.65 S 85 22 E 2552.71 1.07 0.72 0.77 1.82 0.94 I .28 0.85 0.79 1.18 1.32 115.54 S 1810.90 E 1814.58 S 86 21 E 121.60 S 1892 91 .i 1896.81 S 86 19 E - 127.83 S 1974:83 E 1978.97 S 86 18 E '3 134.11 S 2056.68 E 2061.05 S 86 16 E .~ 140.49 S 2138.54 E 2143.15 S 86 14 E 168o07 S 2466.01 E 2471o73 S 86 6 E 174.85 S 2547.88 E 2553.87 S 86 4 E 7000.00 5834.17 5787.17 54 41 7100.00 5891.97 5844.97 54 31 7200.00 5949.95 5902.95 54 32 7300.00 6007.91 5960.91 54 33 7400.00 6066.10 6019.10 54 29 7500.00 6124.17 6077.17 54 28 7600.00 6182.63 6135.63 54 6 7700.00 6241.56 6194.56 53 51 7800.00 6300.83 6253.83 53 12 7900.00 6360.41 6313.~1 53 37 S 85 14 E 2634.42 S 85 12 E 2715.94 S 85 13 E 2797.33 S 84 59 E 2878.73 S 84 56 E 2959.96 S 84 51 E 3041.27 S 84 49 E 3122.29 S 84 44 E 3202.97 S 84 39 E 3283.40 S 84 40 E 3363.59 0.79 0.97 0.98 0.73 0.73 0.85 1.40 0.36 0.95 0.57 181.57 $ 2629.39 E 2635.65 S 86 3 E 188.33 S 2710.71 E 2717.24 S 86 2 E 195.09 S 2791.90 E 2798.71 S 86 0 E 202.04 S 2873.09 E 2880.19 S 85 59 E 209.18 S 2954.11 E 2961.51 S 85 57 E 216.45 S 3035.19 E 3042.90 S 85 55 E 223.73 S 3115.99 E 3124.02 S 85 54 E 230.97 S 3196.46 E 320¢.80 S 85 52 E 238.30 S 3276.67 E 3285.32 S 85 50 E 245.90 S 3356.62 E 3365.62 S 85 49 E COMPUTATION DATE: O2-MAR-90 PAGE 3 ARCO ALASKA, INC. DATE OF SURVEY: 1-0CT-1989 NGI-Z KELLY BUSHING ELEVATION: 47.00 FT PRUDHOE BAY NORTH SLOPE9 ALASKA ENGINEER: PORTER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL ODGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET OEG/IO0 FEET FEET FEET OEG MIN 8000.00 6420.21 6373.21 52 48 8100.00 6480.84 6433.84 52 27 8200.00 6541.98 6494.98 52 21 8300.00 6603.73 6556.73 51 32 8400.00 6666.25 6619.25 51 4 8500.00 6729.57 6682.57 50 26 8600.00 6793.56 6746.56 49 58 8700.00 6858.43 6811.43 49 9 8800.00 6924.09 6877.09 48 41 8900.00 6990.56 6943.56 48 I 9000.00 7058.11 7011.11 47 9 9100.00 7126.52 7079.52 46 14 9200.00 7196.01 7149.01 45 27 9300.00 7266.11 7219.11 44 50 9400.00 7337.22 7290.22 44 24 9500.00 7409.08 7362.08 43 36 9600.00 7481.93 7434.93 42 50 9700.00 7556.04 7509.04 41 38 9800.00 7631.40 7584.40 40 27 9900.00 7707.90 7660.90 39 54 10000.00 7784.92 7?37.92 39 35 10100.00 7862.14 7815.14 39 24 10200.00 7939.91 7892.91 38 21 10300.00 8018.83 7971.83 37 17 10400.00 8098.58 8051.58 37 13 10500.00 8178.53 8131.53 36 34 10600.00 8259.24 8212.24 35 36 S 84 35 E 3443.61 S 84 50 E 3523.01 S 84 47 E 3602.02 S 84 49 E 3680.57 S 84 39 E 3758.50 S 84 29 E 3835.78 S 84 40 E 3912.51 S 84 28 E 3988.49 S 84 2 E 4063.76 S 83 52 E 4138.31 S 83 44 E 4211.88' S 83 32 E 4284.63 S 83 33 E 4356.32 S 82 40 E 4427.39 S 83 5 E 4497.46 S 83 3 E 4566.77 S 82 41 E 4635.02 S 82 10 E 4701.86 S 81 33 E 4767.23 $ 80 49 E 4831.19 S 79 30 E 4894.37 S 78 16 E 4957.16 S 76 25 E 5018.97 S 75 22 E 5079.03 S 75 17 E 5137.96 S 75 20 E 5196.58 S 75 14, E 5254.20 1.20 I .30 0.82 1.44 2.04 1.08 2.44 2.19 1.08 0.62 1.62 1.90 4.06 5.65 3.19 3.24 1.55 3.51 3.51 3.23 3.06 4.37 2.70 0.09 I .32 2.60 253.49 S 3436.41 E 3445.75 S 85 47 E 250.94 S 3515.58 E 3525'25 S 85 45 F 268.25 S 3594.38 E 3604.37 S 85 275.46 S 3672.70 E 3683.02 S 85 43 282.61 S 3750.42 E 3761.05 S 85 41 E 289.95 S 3827.47 E 3838.44 S 85 40 E 297.16 S 3903.98 E 3915.27 S 85 39 5 304.45 S 3979.73 E 3991.36 S 85 38 E 311.99 S 4054.77 E 4066.76 S 85 36 E 319.75 S 4129.08 E 4141.44 S 85 34 E 327.61 S 4202.40 E 4215.15 S 85 33 E 335.60 S 4274.90 E 4288.05 S 85 31 E 343.99 S 4346.32 E 4359.91 S 85 28 E 352.64 S 4417.10 E 4431.16 S 85 26 E 361.07 S 4486.91 E 4501.42. S 85 24 E 369.33 S 4555.95 E 4570.90 S 85 22 E 377.91 S 4623.93 E 4639.34 S 85 20 E 386.79 S 4690.46 E 4706.39 S 85 17 E 396.06 S 4755.53 E 4772.00 S 85 14 E 406.07 S 4819.16 E 4836.24 S 85 11 E 417.17 S 4881.96 E 4899.75 S 85 7 E 429.33 S 4944.32 E 4962.93 S 85 2 E 443.15 S 5005.64 E 5025.22 S 84 56 E 458.23 S 5065.17 E 5085.86 S 84 50 E 473.45 S 5123.56 E 5145.39 S 84 43 E 488.75 S 5181.64 E 5204.64 S 84 37 E 503.77 S 5238.73 E 5262.89 S 84 30 E 10680.0 ~:~ TIE-IN POINT GOING FROM GCT TO MWD DATA CSEE INTERPOLATED VALUES FOR CHOSEN HORIZONS). 10700.00 8341.23 8294.23 34 34 10800.00 8424.05 8377.05 34 2 10900.00 8506.87 8459.87 33 30 S 75 21 E 5310.10 S 76 11 E 5364.93 S 77 I E 5419.77 2.12 1.36 0.60 518.23 S 5294.10 E 5319.41 S 84 25 E 531.63 S 5348.47 E 5374.83 S 84 19 E 545.04 S 5402.83 E 5430.25 S 84 14 E 11000.00 8589.69 8542.69 34 39 11002.00 8591.34 8544.34 34 40 S 75 3 E 5474.62 S 75 I E 5475.72 1.57 0.00 558.62 S 5457.20 E 5485.71 S 84 9 E 558.89 S 5458.29 E 5486.82 S 84 9 E COMPUTATION DATE: 02-MAR-90 PAGE 4 ARCO ALASKAt INC. NGI-2 PRUDHOE BAY NORTH SLOPEr ALASKA DATE OF SURVEY:' 1-0CT-1989 KELLY BUSHING ELEVATION: 47.00 FT INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASUREO DEPTH ENGINEER: PORTER VERTICAL DOGLEG RECTANGULAR COORD:NATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET OEG HIN N 0 0 E 0.00 N 9 23'5 0.07 S 37 13 E 1.55 S 89 21 E 30.08 S 85 44 E 348.19 S 86 48 E 987.67 S 85 49 E 1814.00 S 85 14 E 2634.42 S 84 35 E 3443.61 S 83 44 E 4211.~8 ',TRUE SUB-SEA COURSE MEAS~UREO VERTICAL VERTICAL DEVIATION AZIMUTH OEPTH OEPTH OEPTH DEG NIN DEG 0.00 0.00 -47.00 0 0 1000.00 999.99 952.99 0 6 2000.00 1999.99 1952.99 0 26 3000.00 2998.31 2951.31 11 2 4000.00 3942.70 3895.70 27 25 5000.00 4700.76 4653.76 54 40 6000.00 5263.47 5216.47 55 20 7000.00 5834.17 5787.17 54 41 8000.00 6420.21 6373.21 52 48 9000.00 7058.11 7011.11 47 9 10000.00 7784.92 7737.92 39 35 S 79 30 E 4894.37 0.00 O.1Z 0.92 2.77 3.17 2.89 1.07 0.79 ! .20 1.62 0.00 N 0.00 E 0.00 N 0 0 E 2.63 S 0.03 W 2.63 S 0 37 ' 1.88 S 1.48 E 2.40 S 38 15 3.72 S Z9.96 E 30.19 S 82 55 E 19.42 S 347.70 E 3~8.24 S 86 48 E 61.21 S 986.05 E 987.95 S 86 27 E 115.54 S 1810.90 E 1814.58 S 86 2.1 E 181.57 S 2629.39 E 2635.65 S 86 3 E 253.49 S 3636.41 E 3445.75 S 85 47 E 327.61 S 6202.40 E 4215.15 S 85 33 E 3.06 417.17 S 4881.96 E 4899.75 S 85 7 E 10680.0 ~:)~ TIE-IN POINT GOING FROM GCT TO MWD DATA CSEE INTERPOLATED VALUES FOR CHOSEN HORIZONS). 11000.00 8589.69 854Z.69 34 39 S 75 3 E 5474.62 1.57 558.6Z S 5457.20 E 5~85.7! S 8~ 1100Z.00 8591.34 8544.34 34 40 S 75 I E 5475.72 0.00 558.89 S 5458.29 E 5486.82 S 84 COMPUTATION DATE: 02-HAR-90 PAGE 5 ARCO ALASKA, [NC. NGI-2 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 1-0CT-1989 KELLY BUSHING ELEVATION: 47.00 FT INTERPOLATED VALUES FOR EVEN tO0 FEET OF SUB-SEA DEPTH TRUE SUO-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG 0.00 0.00 -&7.00 0 0 N 0 0 E 47.00 47.00 0.00 0 6 N 7 40 W 147.00 147.00 100.00 0 3 N 44 20 W 247.00 247.00 ZO0.O0 0 16 S 10 I W 347.00 347.00 300.00 0 18 S 11 26 W 447.00 447.00 400°00 0 26 S 0 19 W 547.01 547°00 500.00 0 20 S 7 17 W 647.01 647.00 600.00 0 13 S 27 23 E 747.01 747°00 700.00 0 5 S 3 10 E 847.01 847.00 800.00 0 1 N 46 24 E 947.01 947.00 900.00 1047.01 1047o00 1000.00 1147.01 1147.00 1100.00 1247.01 1247.00 1ZO0.O0 1347.01 1347.00 1300o00 1447.01 1447.00 1400.00 1547.01 1547.00 1500o00 1647.01 1647.00 1600.00 1747.01 1747.00 1700.00 1847.01 1847.00 1800.00 0 5 N ~7 56 E 0 3 N 22 6 W 0 10 N 26 25 E 0 5 N 13 34 E 0 12 N 69 33 E 0 4 N 70 23 E 0 15 N 17 16 E 0 8 N 14 3~ E 010 N 7 15 E 0 6 S 40 2 E 1947.01 1947.00 1900.00 2047.01 2047.00 2000.00 2147.02 2147.00 2100.00 2247.02 2247.00 Z200.O0 2347.02 2347.00 2300.00 2447.02 2447.00 2400.00 1547.03 2547.00 2500.00 . 2647.03 2647.00 2600.00 2747.04 2747.00 2700.00 2847.11 2847.00 2800.00 0 25 S 65 26 E 0 34 S 32 26 E 021 S 9 9 W 0 14 S 27 22 E 0 11 N 63 41 f 0 18 N 61 24 E: 0 20 S 89 24 E 0 30 S 76 5 E 0 45 S 50 19 E 4 8 S 86 0 E 2947.85 2947.00 2900.00 9 21 3049.72 3047.00 3000.00 12 6 3152.11 3147.00 3100.00 12 39 3254.90 3247.00 3200.00 14 15 3358.47 3347.00 3300.00 15 49 3462.84 3447.00 3400.00 17 36 3568.50 3547°00 3500.00 ZO 5 3675.61 3647.00 3600.00 21 45 3783.88 3747.00 3700.00 23 17 3893.41 3847.00 3800.00 24 59 ENGINEER: PORTER VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST OIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 N 0.00 E -0.04 0.00 0.08 N 0.04 W -0.15 0.14 0.06 S 0.15 W -0.16 0.00 0.57 S 0.18 W -0.27 0.45 1.23 S 0.31 W -0.20 0.06 1.95 S 0.28 W -0.07 0.38 2.53 S 0.16 W -0.05 0.,00 2.65 S 0.1.5 W 0.00 0.00 2.68 S 0.11 W 0.04 0.00 2.68 S 0.07 W 0.06 0.00 2.56 S 0.04 W 0.07 0.14 2.46 S O,OZ W 0.11 0.24 2.28 S 0.02 E 0.35 0.6~ 2.21 S 0.26 E 0.48 0.00 2.12 S 0.40 E 0.60 0.13 2.05 S 0.52 E 0.66 0.14 1.69 S 0.59 E O.7B 0.69 1.44 S 0.72 E 0.74 0.88 1.41 S 0.69 E 1.19 O.BO 1.64 S 1.13 E 1.74 0.73 2.23 S 1.65 E 2.03 0.77 2.99 S 1.92 E 2.06 0.74 3.15 S 1.94 E 2.46 0.88 2.85 S 2.36 E 3.12 0.26 2.51 S 3.03 E 3.74 0.89 2.28 S 3.65 E 4..35 0.74 2.4.7 S 4.26 E 5.55 0.76 3.16 S 5.53 E 8.93 5.49 3.80 S 8.79 E N 88 36 E 20.77 4.94* S 88 52 E 40.13 1.42 S 88 4 E 62.13 0.92 S 87 23 E 85.87 1.95 S 86 26 E 112.83 1.47 S 86 I E 142.68 2.22 S 86 32 E 176.76 2.15 S 87 24 E 215.13 1.46 S 87 3:3 E 256.59 1.53 S 87 39 E 301.29 1.95 3.68 S 20.64 E 3.86 S 40.01 E 4..37 S 62.01 E 5.37 S 85.73 E 0.00 N 0 0 E. 0.00 N 0 0 r ~ 0.09 N 24 45 ~. 0.17 S 67 0 W' 0.60 S 17 48 W 1.27 S 14 17 W 1.97 S 8 3 W 2.53 S 3 42 W 2.66 S 3 16 W 2.68 S 2 18 W 2.68 S I 17 W 2.56 S 0 47 W 2.46 S 0 32 W 2.28 S 0 29 E 2.23 S 6 48 E 2.16 S 10 ¢4* E 2.12 S 14 18 E 1.79 S 19 23 E 1.62 S 26 34 E 1.57 S 25 55 E 1.99 S 34 29 E 2.77 S 36 35 E 3.55 S 32 42 E ) 3.70 S 31 35 E 3.70 S 39 33 E 3.93 S 50 21 E 4.31 S 57 59 E 4.92 S 59 57 E 6.37 S 60 14 E 9.57 S 66 37 E 20.97 S 79 53 E 40.20 S 84* 30 E 62.17 S 85 58 E 85.89 S 86 25 E 6.88 S 112.65 E 112.86 S 86 30 E 8.91 S 142.44 E 142.72 S 86 25 E 11.15 S 176.46 E 176.81 S 86 23 E 13.17 S 214.78 E 115.18 S 86 29 E 14.99 S 256.21 E 256.65 S 86 39 E 16.83 S 300.87 E 301.3¢ S 86 4.8 E COMPUTATION DATE: 02-MAR-90 PAGE 6 ARCO ALA'SKAt INC. NGI-2 PRUDHOE BAY NORTH SLOPEr ALASKA DATE OF SURVEY: 1-0CT-1989 KELLY BUSHING ELEVATION: 47.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MZN 4004.86 3947.00 3900.00 27 34 4119.73 4047.00 4000.00 31 32 4240.04 4147.00 4100.00 35 48 4366.57 4247.00 4200.00 39 9 4492.34 4347.00 4300.00 36 53 4620.88 4447.00 4400.00 41 14 4759.01 4547.00 4500.00 46 ! 4910.44 4647.00 4600.00 51 29 5081.48 4747.00 4700.00 55 59 5260.11 4847.00 6800.00 55 49 5439.0! 4947.00 4900.00 55 59 5616.97 5047.00 5000.00 55 39 5793.90 5147.00 5100.00 55 42 5970.97 5247.00 5200.00 55 33 6146.69 5347.00 5300.00 55 17 6321.91 5447.00 5400.00 55 11 6496.57 5547.00 5500.00 54 52 6672.21 5647.00 5600.00 55 24 6848.18 5747.00 5700.00 55 16 7022.24 5847.00 5800.00 54 48 7194.91 5947.00 5900.00 54 31 7367.19 6047.00 6000.00 54 20 7539.17 6147.00 6100.00 54 11 7709.23 6247.00 6200.00 53 53 7877.40 6347.00 6300.00 53 36 8044.30 6447.00 6400.00 52 48 8208.19 6547.00 6500.00 52 16 8369.30 6647.00 6600.00 51 14 8527.31 6747.00 6700.00 50 15 8682.47 6847.00 6800.00 49 22 ENGINEER: PORTER 8834o61 6947.00 6900.D0 48 27 8983.66 7047.00 7000.00 47 9 9129.54 7147.00 7100.00 45 55 9272.84 7247.00 7200.00 4,5 34 9413.68 7347.00 7300. O0 44 14 9552.25 7447.00 7400.00 43 8 9687.90 7547.00 7500.00 41 49 9820.49 7647.00 7600.00 40 17 9950.83 7747.00 7700.00 39 21 10080.38 78¢7.00 7800.00 39 34 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 S 85 38 E 350.44 3.13 S 83 49 E 406.83 3.85 S 81 47 E 473.41 3.37 S 92 21 E 550.37 5.78 S 88 54 E 626.55 2.49 S 89 14 E T07.23 3.66 S 88 7 E 802.45 3.54 S ~7 16 E 916.06 3.50 S 86 37 E 1054.74 2.16 S 86 20 E 1202.72 1.17 S 86 I E 1351.00 S 86 24 E 1498.15 S 86 9 E 1644.06 S 85 50 E 1790.11 S 85 39 E 1934.51 S 85 34 E 2078.28 S 85 8 E 2221.36 S 85 8 E 2365.59 S 85 15 E 2510.23 S 85 16 E 2652.57 S 95 12 E 2793.19 S 84 56 E 2933.31 S 84 54 E 3073.05 S 84 48 E 3210.42 S ~4 33 E 3345.43 S 84 35 E 3473.83 S 84 45 E 3608.48 S 84 45 E 3734.63 S ~J4 36 E 3856.77 S ~J4 29 E 3975.22 S 84 7 5 4089.65 S 83 49 E 4199.93 S 83 12 E 4305.86 S 82 57 E 4408.16 S 83 7 E 4506.99 S 82 39 E 4602.59 S ~2 13 E &693.84 S 81 1~ E 4780.43 S T9 53 E 4863.39 S 78 38 E 4944.84 0.48 0.48 0.38 0.98 1.41 1.19 1.14 0.90 1.08 0.58 1.02 0.77 1.21 0.60 0.89 1.18 1.20 1.68 0.64 1.87 1.40 1.75 1.74, 5.99 0.74 2.60 3.76 2.07 0.77 3.63 FEET FEET FEET OEG MIN 19.59 S 349.94 E 350.49 S 86 48 E 24.88 S 406-17 E 406.94 S 86 30 F 33.18 S 472.48 E 473.65 S 85 59 45.04 S 549.05 E 550.89 S 85 19 E 49.44 S 625.11 E 627.06 S 85 29 E 50.53 S 705.81 E 707.62 S 85 54 E 52.77 S 801.01 E 802.75 S 86 14 E 57.49 S 9.14.53 E 916.33 S 86 24 E 65.09 S 1053.02 E 1055.03 S 86 28 E 74.24 S 1200.75 E 1203.05 S 86 28 E 84.13 S 1348.76 E 1351.38 S 86 26 E 93.90 S 1495.65 E 1498.60 S 86 24 E 103.32 S 1641.30 E 1644.55 S 86 24 E 113.79 S 1787.06 E 1790.68 S 86 21 E 124.52 S 1931.15 E 1935.16 S 86 19 E 135.50 S 2074.61 E 2079.03 S 86 16 E 146.89 S 2217.35 E 2222.21 S 86 13 E 159.27 S 2361.22 E 2366.58 S 86 8 E 171.34 S 2505.50 E 2511.35 S 86 5 E 183.07 5 2647.49 E 2653.81 S 86 3 E 194.75 S 2787.77 E 2794.56 S 86 0 E 206.82 S 2927.53 E 2934.83 S 85 58 E 219.30 S 3066.89 E 3074.72 S 85 55 E 231 65 S 3203 88 E 3212.25 S 85 52 E 244:19 S 3338~51 E 3347.43 S 85 49 E 256.82 S 3471.53 E 3481.02 S 85 46 E 268.85 S 3600.82 E 3610.84 S 85 44 E 280.40 S 3726.61 E 3737.15 S 85 42 E 291.95 S 3848.40 E 3859.46 S 85 40 E 303.17 S 3966.50 E 3978.07 S 85 38 E 314.67 S 4080.58 E 4092.T0 S 85 35 E 326.30 S 4190.49 E 4203.18 S 85 33 E 338.05 S 4296.04 E 4309.32 S 85 30 E 350.16 S 4397.96 E 4411.88 S 85 27 E 362.21 S :,496.40 E 4510.97 S 85 24 E 373.T6 S 4591.63 E 4606.82 S 85 21 E 385.70 S 4682.49 E 4698.35 S 85 17 E 398.04 S 4768.66 E 4785.25 S 85 14 E 411.56 S 4851.17 E 4868.60 S 85 9 E 426.84 S 4932.09 E 4950.53 S 85 3 E COMPUTATION DRTE: O2-MAR-90 PAGE 7 aRCO ALASKA9 INC. NGI-2 PRUDHOE BAY NORTH SLOPEr ALASKA DATE OF SURVEY: 1-0CT-1989 KELLY BUSHING ELEVATION: 47.00 FT ENGINEER: PORTER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MEN 10209.05 7947.00 7900.00 38 7 10335.38 8067.00 8000.00 37 13 10460.67 8147.00 8100.00 37 0 10584.91 8247.00 8200.00 35 53 10706°96 8347.00 8300.00 34 32 10827.71 8447.00 8400.00 33 53 10948.46 8547.00 8500.00 34 3 11002.00 8591.34 8544.34 34 40 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/Z00 FEET FEET FEET OEG MIN S 76 1~ E 5024.48 S 75 28 E 5099.94 S 75 20 E 5173.62 S 75 lB E 5245.60 $ 75 24 E 5313.91 S 76 24 E 53B0.13 S 76 3 E 5'446.35 S 75 I ~ 5475.72 1.57 I .83 3.10 2.07 1.15 1.07 0.00 444.47 S 5011.1.1 E 5030.78 S 84 56 E 463.'62 S 5085.B9 E 5106.98 S 84 47 F ~\ 492.81 S 5158.89 E 5181.43 S 84 39 E 501.53 S 5230.20 E 5254.19 S 84 31 E 519.16 S 5297.89 E 5323.27 S 84 24 E 535.35 $ 5363.53 E 5390.,18 S 84 18 E 551.62 S 5429.18 E 5457.13 S 84 12 E 558.89 S 545B.29 E 5486.82 $ 84 9 E ARCO ALRSKA~ INC. NGI-2 PR.UDHOE BAY NORTH SLOPE~ ALASKA MARKER SAG SHUBLIK TOP SADLEROCHIT ZONE 4 ZONE 3 ZONE Z GCT LAST READING ZONE ! B MWD FIRST READING PBTD BASE SADLEROCHIT TD COMPUTATION DAT.. 02-MAR-90 PAGE 8 DATE OF SURVEY:' 1-0CT-1989 KELLY OUS'HING ELEVATION: 47.00 FT ENGINEER: PORTER INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOC~TION = 80Z' FNL & 1114' FWL, SEC1Z T11N R14E MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 19308.00 8025.20 7978.20 459.45 S 5069.86 E 10361.00 806'?.44 8020.44 467.50 S 5100.84 E 10409.00 8105.75 8058.75 474.84 S 5128.82 E 10409.00 8105.75 8058.75 474.84 S 5128.82 E 10526.00 8199.40 8152.40 492.69 S 5196.63 E 10594.00 8254.37 8207.37 502.88 S 5235°35 E 10680.00 8324.67 8Z77.67 515.54 S 5283.Z3 E 10788.00 8414.11 ,8367.11 530.03 S 5341.94 E 10900.00 8506.87 8459.87 545.04 S 5402.83 E 10917.00 8520.95 8473.95 547.35 S 5412.07 E 10947.00 8545.79 8498.79 551.42 S 5428.38 E 11002.00 8591.34 8544.34 558.89 S 5458. Z9 E ARCO ALASKA, INC. NGI-Z PRUDHOE BAY NORTH SLOPE, ALASKA MARKER SAG SHUBLIK TOP SADLEROCHIT ZONE 4 ZONE 3 ZONE Z ZONE IB PBTO BASE SAOLEROCHIT TD COMPUTATION D&TE: O2-MAR-90 PAGE 9 DATE OF SURVEY: 1-0CT-1989 KELLY BUSHING ELEVATION: 47.00 FT ENGINEER: PORTER STRATIGRAPH[C SUMMARY ~~~ SURFACE LOCAT'ION = 802e FNL & 1114e FWL, SEC12 T11N RlaE MEASURED 'DEPTH TVD BELOW KB FROM K8 SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 10308.00 80ZS.ZO 7978.20 459.45 S 5069.86 E 10361.00 8067.&4 8020.a4 467.50 S 5100.84 E 10409.00 8105.75 8058.75 474.84 S 5128.82 E 10409.00 8105.75 8058.75 474.84 S 5128.82 E 10526.00 8199.40 815Z.40 49Z.69 S 5196.63 E 10594.00 8254.37 8207.37 502.88 S 5235.35 E 10788.00 8414.11 8367.1! 530.03 S 5341.94 E 10917.00 8520.95 8473.95 547.35 S 541Z.07 E 10947.00 8545.79 8498.79 551.4Z S 5~28.38 E 11002.00 8591.34 8544.34 558.89 S 5458.29 E FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPAR'TURE DISTANCE AZIMUTH FEET DEG MIN 11002°00 8591.34 85¢4.34 5486.82 S 84 9 E SCHLUMBERGER O I REC T I ONAL SURVEY COMPANY ARCO ALASKA, INC. 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SCALED IN VERTICAL OEPT~ HORIZ SCALE = 1/1000 IN/FT i. - . . .: A PETROLANE COMPANY REPORT of SUB-SURFACE DIREC TIONA L SURVEY Atlantic Richfield Co. COMPANY ~a'r #2 WELL NAME Prudhoe Bay LOCATION JOB NUMBER A1175. G0028 TYPE OF SURVEY Gyz"o DATE 11-13-75 SURVEY BY Jay Mar~in OFFICE Alaska ¢ 0 MP UE~T-I-O-~--~-E-P -O-R T A-T~-~'N'Y Ic I~"~'C~tFIE~i~--¢O'~--~ELL N~ I NO, 2 NOVE~B-E-R 28 , 1975 KB ELEV. 47. GYROSCOPIC SURVEY JOB NO. Al175-G RADIUS OF CURVATURE METHOD OF COMPUTATIONS _COMPUTED FOR EASTMAN WHIPSTOCK', INC, BY F.M. LINDSEY AND ASSOC. RECORD OF SURVEY ALL'CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER · . TRUE ~;.!'..'~ . -fq-E-A-S';--DR~I-'F'T'-9-ERT-i'C-/~L sUB DRILY TOTAL COORDI'-NATES -::'"'---C L'O S U R E $ DEPTH -~-~GLE DEPTH SEA DIREC ~' D',I;ST'ANCE ANGLE D M DEG. , -,,_ D M S SS~OEL,F'~D- '~- ~ ~. ' 0~-0--0 I 118'0--0N 25,00 W 120,61:N '30-0- 0 15 299~9'9~~2~'"9~ $'~-O-~O--OE 117,6~ N 2~,34 W 120.16 N 11 41 16 W &0'0~0~0--3-99~99 352'J99 ~1'8;'00W~i-~.88 N 2~.39 W 119~-~0--N--1I--47 28 W ~SO0 ..... -0-35 .... 4'99',-98--~52 ~'98 "S48*'OOW--11-5'~97-"N 2'~99-'-W- 'lr18"-63-N ..... 12'--9--39 W '600'--0--1'5~'599~98- 552'98 .... S4~'~'0~i-1-5~31 N 25.00 W ii7-;}9 N 12 13 59 W DOG LEG SEVER I TY SECT ION DEG/IOOFT DISTANCE 0.000 -'30.02 0.000 -30.02 0.340 -29.72 0.090 -29.35 0.420 '29,37 0.080 -29.92 0.340 -29.90 0.104 -29,53 0.215 '29,11 9-00' 0 15 899,98--852,98 SSO.OOE ---'I-000 0 0 999,98 952,98 550.00E-- '1100'-'~-10---i~99;98 i'052,98 N12'OOE' ---1-200'--0-~0 ~i~9~? i'1'5'2~97 N'~3~O'OW ~i~00. 0 10 1299.97 1252.97 N-'~,OO'W 2~00 O. 0 2399.97 1500 0 15 1~99,97 1452e97 N88eOOE 115.09 N 23,80 W 114,95 N 23,64 W 1i~,99 N 23,52 ~ 115.61 N 23.81 W 1'-17.53 N 11 4I 12 W 0,290 --127;3~-N'--:11 37 1~ W 0.250' 117,3 7 -N -11"-'~'3'""3'9--W .... 0';'-i.i70. 118.,0~ N 11 38 26 W 0-500' -28.70 -28.53 =2 e-,-,~'! ) '28,73 116.19 N 24,20 W 116,34 N 24.21 116.~9 N ' 24,08 118.69 N 11 ~5 59 W 118.83 N 11 45 25 W 118.95 N 11 ~0 51 ~ 0.:500 __ 0:.170 -29.16 0,250 -29.04 '-i-~-00 0 25 15~9.97 1552.97 NSO-e'~OW 116.92 N ~1700---0--i0- 2'~'~-c~;'cj?' i"g52;97 .... N79,00E~ -1-1-'7;33 N 2800 0 0 ~.-7~)-'-97 1-~52-~-9~ --NT~,OOE--117.36 N i900 0 O- 18c~9'-;-97 .... 1-~52-;-97 N79.00E 117,36 N -2000 .... 0-i5'-- 1999'97 !952*97 .... S8 o'*rOoE ....... 11-7;36 N 2i00' 0 0 20-9~;~-7 2052'97---S80.OOE 117.32 N 23,68 W -28,67 23.93 W 1.!9.35_N_1.1._3~ ..... 6 W :"0~,80 -28~91.._ 23'~-$2-~ 119.72 N 11 28 48 W 0.260 -28.82 119.72 N 11 24 32 W 0.170 23.68 W 119,72 N 11 24 32 W 0.000 -28.67 23,46 W 119e68 N 11 18 25 W 0,250 -28.46 ............................... 23.25 W 11q,60 N 11 12 34 ~ 0.250 -28.2./, 2200----0 .....0 2199'97 21'52;97 ..... $80"00E 2300 ......... 0 ...... 0 ..... 2299,97 ...... 2252.97 .... S80.OOE ............ 1i'~'~32'-'N ........ 2~-e"25-9 ......... 11'9.60-N'~1 12 .... 34""W ............. 0';000 .............. ;28,'2~ ..... 2400---0--i5 '2399-;97 2352;97- S8~;-ooE ...... i'f7.26 N 22.88' W ..... ii~;~7-N--i1 .... 2'--26 W 0.~30 -27;87- · .................................................................. ----~-~-~'ORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M,ELECTRONIC COMPUTER TRUE DOG LEG .~EAS, DRIFT VERTICAL SUB DRIFT DEPTH ANGLE DEPTH SEA DIREC D M DEGe TOTAL COORDINATES C L 0 $.U_R_.E._5__ sEVE_R~!__TY ..... D ! S T AN CE ................ A N G L E .......... D.E G/..],.OOF. T .......... D_!_S.?AN.. D M $ 2500 0 :~5 2499,96 2452,96 N76,00E 117,31 N 21,99 W 119,3.5 N 10 37 ..... 13_~. ............. 0_~160 2600 0 45 2599.96 2552.96 S83,OOE 117.38 N 20.83 W 119,21 N 10 3 56 W 0.160 -25.83 2700----0--56" .-2-~-99-'95---~'6-52"*-95 ..... -S8-4,-00E - -1"i-~2-2~- - i-9"~'45--W' ..... ~'1'8-~8~"-N ....... 9-25 ..... 28-'-W ......0-"090 -2~,45 ...... 290'0 ....... '6 ..... i0 ....2899.'68 ...... 2852.68 SgO.OOE 115.7~ N l!_e_!.~W ..... !!_6~27_ N ...... ~._.30 ..... ~_..__W_ ....... i~_~_8_3_~ ..... .......................................................................... ......... i-Z ...... ......... E Z.ZS.SO__N Z Z ........ 44 ..E ........... Z.250_ ....................... 3200 13 25 31~,25 3147,25 .......... ss.g~_OOE 116,68 N ~,70 E 12~,95 ....N.__20~_5_7____~_l._E .....1.,_596_ _ 39_,._6.7 - -330d 1-~ .... 6' -~-29i'~i-9- .... ~-2'~-'"19 S88,50E ._!.!69!~ N 6_9~25_E ....... 135,22 _N ~0 48 _15_E ............. 1.,5~0 ........... 3400 i-5 ....~'-~'"33'87',-57 -3~40,57 S87,00E 115010_.._N .......... 95_~89 E ............. 149e81 N ~9 47 5~._.E .......... 0.937 ................................ 90e88_ .... 3800-'23--'25 3?63;34 ........ 37~6.3b 590,00E-~ 112.69 N 23~.88 E 257,S~ N 6~ b 52 E ~.~30 226,85 3900--25 ......0 .... ~854'5~ ...... 3807.5~ SgO;OOE ~~,-N- ..... ~_2;89 ...... E-~ .... ~'95;24,''-'N' 67 33 ~4 E .......... 1-'570 267.83 ~-4000-'27-i'0- ..... 394~;35- -3897* 35 587; OOE .... ~11,5'3-~N'"~~~,-.,.~'335'90 N"?O "3~ 22 E'_' ~.~.~_'--_ 2,25'8-"~_--~.~._--.~,,3~ ~"_~i00 30_?5 ......?03~83 ...... 3984,83 586.50E ..... ~0{.9~9.~___365~_7__._E .......... 3..81_._04...._N._73__24.56 E ..... 3,582 ................ ~200 .... 34 .10 ....~1~6.20__.~069,20 _S85,00E ........ Z04.gZ.._N ....~8,69___E ~31.61. N .75 56_42..E ....... 3,453 ........... ~300 37 50 ...... ~197.08_. ~150.08 S8~.50E ......... 99.~,N ........ ~77.22 E ........ ~87.47 N 78 13 ~6_E ......... 3.675 .............. 672.5~ .... ~00 37 50 ~276.05 ....... ~229,05 S87.50E ..........95.~6 N 538.61 E ...... 5~6,75 N ?9._58 36__E ...... 1.8~0 .............. 533,85_ 4500---37 ........ 0 ..... ~355,~7 ~308,~7 '-SgO,OOE ........ g_3,~3..,.~ 597_~15_E ....... 606.~6 .N_81___ 5. 56.E ......... !,23.5 ............. 59~,.59 .... A~00--~0---25 .... A'433;69 .....-4386'~9 NSg.50E 96.10 N 66~.69 E 668.35 N 81 5~ 19 E 3.436 657.06 ~700 ~'- 5 ..... ~507.~8 '~60,A8 $90,ooE ........ g~.40"N .......... 728.92 E ......... 735.01 N 82 37 16 E_'--~" 3-.,~68 ........ 724,22 ¢8'00 ~7 30 ...... ~577'20-- '4530.20 S89.OOE 4900 51 15 4542.29 4595.29 S8geOOE · '--~000 54 50 4702.~0 4655,40 S89,50E 5109 55 55 4759,21-' 4712.21 S89,00E 5200 55 35-~ 4815.47 4768,~7 S89,00E 5300 55 50 4871.81 482a,~! S88,50E 93~77___N_ 800..59_E ..........805.07 ...... N 83 19 .......9_E 3.453 ............... 92.a5 N 876.a7 E 881.33 N 83 58 42 E 3.750 871,72 91e40 N 956e36 E 960.72 N 84 32 25_E ....... 3.606 ..... 951e58 90-'3~'~'N'~-~E .... 1042.57 N 85 1 46 E 1.143 1033.84 88,88 N ..... ~121;31 E 1124,82 N 85 28 3 E - 0,340 1116,48 8~.08 N 1203.91 E 1207.06 N 85 51 45 E 0.~24 RECORD,OF SURVEY ALL CALCU. L~] O~.$.._?,EB,FOR__~_E~.P__B.~__~___B_ :~ ELECTRON TRUE DOG LEG NE-A-§. D-R-]:-FT--V-E-RY']-CAL ,SUB DR I FT DEPTH ANGLE DEPTH SEA D]REC D M DEG, TOTAL COORDINATES CLOSURES SEVERITY SECTION D ! $,T, AN~E .............. ANGL.,E .................... DE.G./. 3. OOF? .................. D! 5T.A.~N...C.E_ D N 5 5400 56 0 4927.8~ 4880.8.4 S89.00E 85,27 N 1286,72 E 1289,5/+ N 86_12 .... 29_.E ........ 0~.37.9_. .......... 1281.8.9 ) --56'00 56 0 5039-~-5- .... -4-992';-~5 ...... $-89~-50E 83,4~ N [452.~0 E [/+55,00._.._N__~6 /+2 ~0 E 0,090 ---570~--5-5"~-'5----5-0-~-~;'5-~ ~-~4'8 ;-5'2'__~,..$'~'~-;~60E ....... 8 Z~.38 __N,,__ Z 535,4 6_E ......... J 5 3 7,6 7...N _.8 6 ...~ 5 _?..a_..E ...... Q,3.5 q .......... 1.5.3.0 .,.. 5~ ..... 5'800-"55-55 ........ ~zs~"',"~'~ ........... 5~.04.5~ S88..50E 80.57 N ~6Z8.28 E Z620.28 N 87 8 58 E 0.~4 6200'-55'-i5 .... 53~6,96 5329,96 S88,00E 70,8~ N Z9~8,56 E ~949.85_N_8~ _5_~ 3 ...... E ....... O_,__a8~ ........ --63 0 O- 5 5 ...... 5- ~-43 4"0 e ........ -53 B 7.08 ....... S 8 8',0 0 E-~-_72.~?.~' ~ 8-:~,'N;_~2'93;0-;5 9;.;E':~2/;.~20 31'. 73 N 8 s .... 4 _57... E ................ 0.. 160 .................. 202 5.83 .... ...... ~400-""' 55 ...... 5 ...... 549 i ' 31 54 ~'4 ~'~ l_:":'::::: S_87 ~ 00.E ......... 6.~_~?_ON_ 2_1.12._,5 2_ _E .......2 ~13_, 50_:: _fi.'~_ 88 .__! 5 ....... Z 3 ..... E_ ~0.. 820 ............ 2! 07., 8_~____ ....... ~oo--~5 ........ 5 ...... 55-4'e-;5-Y-- ~o~,53 .... Se?..5. QE ........ .~_.o_,~..Z_N ...... 2z~..~__E ....... 8..~e.5~.~.~_._N.._ee .... 2~ ....... zT__.E ..... o.~jo ..... 6"600--55 ..... ~-5 ...... 5'~'05';-40--5558,~0 588,50E 57,59 N 2276,63_.E .......... 2277,36 N 88 33- 2_E .......... 0,845 .................. 2272,09 ---680-0--5-5 20--5-71S,~49 .... 567~.~9 SST. 00E 50,04 N 2~.41 E 26~1.93 N 8S ~g 32 E 0,~30 2437.0~ .... ~900--55 ...... 5 5-775;54 ..... 5-728'5~ ..... S87.00E 45e74 N 2523.~3 E 2523.85 N 88....57__..~Z E .............. 0,250 ............. 25~9.17 ...... .... ?000'55 .....0 -5832.83 .... 5785.83"-588.00E .......... ~~: ~= ..--'2605.65 N 89 ~ 21 E 0.677 .... 7300 54 55 6004,96 _ 5957.96_ S88.00E ....... ~3~Sg..N ..... 2850~87_E 2851.07_N. 89 _lg_..29_E ...... 0,070 ..........2846e83__ 7~00-5~-'50 -6062.~8 60~5.~8 587.00E 30.02 N- 2~32.59 .... E ..... 2932,75 N 89 2~ .._~7 E ......... 0,67~ ....... 2928,63 __ ...... 7500--54--50---6-~20",-07 ....... 6073.07 .... 588.00E-- 2'6~--~6--N ...... 30i~.27 E 30~4,39 N 89 29 49 E ............. oeec8 ............ ~0z0,38 -'7600 5~'"10 ....... 6178.'13 .... 6131.13 S86.50E ....... ~_2~_5.5~_.N ..... 3095~59 E_. 3095.67_N 89__.3~__57___E ........... 1,192 ........ 3091.80 -7700--'5~----0- 6236,79~- 6~89.79 587.00E 17,96 N 3176.45 E 3176.50 N 89 40 33 E 0.369 .... 7800--53'-60-'6295"80 62~8.$0-'S87.00E .... i-3;'?~'--~ ...... 3'257e-O7-E .... ~-257.~0--N~-89' 45'"~'~9 E 7900 53 55 635~.86 6307.86 SS?.OOE 9.5! N 333?.65 E 3337.67 N 89 50 ~! E 8000 53~ 5 ..... 6~/+,33 6~67.33 587.50E-. :i_.5.-~ __/+.1~:~9~_E ..3~17.96 N 89 5/+ 18 E 8~00 5~ ~5-' 6~?~.62 6~27,~2 $87.00E 1,83 N 3~97.6~ E 3/+97.65 N 8~ 58 ~ E ._ . 8200 52 20 6535.~3 6~S8.~3 587.00E 2,32 S 357~.92 E 3576.92 S 89 57 45 E ~. . 0.330 3253.50 0.260 333/+.20 0.899 3414.59 0e465 3~9~,~7 0.410 3573.75 RECORD OF SURVEY ALL CALCULATION,5 PERFORMED BY I B M ELECTRONIC COMPUTER DOG LEG MEAS· DRIFT VERTICAL SUB DEPTH ANGLE DEPTH SEA DRIFT DIREC TOTAL COORDINATES ¢ L 0 $ U R E $ SE_VER!_TY_ SECTION D I ,STANCE ANGLE ......... D M DEG· D M' $ Et 30 q_.5]. ..... 5.0.. __6 596 ._88 .... 65.~9_788 ..... _,587.0.0 E ....... 6 .*. 4. .5_ _ $_ .3655_,.7...1._..E____~6 55,, 7.1...,$__89..,...5..3__.55... E ............ 0..· ~:.0.~ ....... 8~00 51 10 6659·12 6612,12 S87,00E 10,54 S 3733.87 E 3733.88 S 89 50 17 E 0·670 3730.90 ....... ~5.07__50 _~.0... 67_2,~_, ~1.66675_,_[ 6 ~_86~_0_0.E. _.1_5.~_8_~ ~_8!~_?_3_5___E 3_8..!_.!__e_38 S._89_~6_ 12 E 0 · 780 .... .8,600__~0 25__.678.5_,__7.0_ 6738..~0 ..... 586...00E ................. 20_~_.6.7__5___3888_, 38_..E ......3888./+3_,.5..,89_./~1.,.?+3_._E .... 0,.7240 ........... 3885.71 . _8_7~0.0_/+9 .3~_ _68~9·_9_?. ...... 6...8.02.._97_ ..... _$85.,._0.0E __2_6_,..68.5 396..~..,_75E __3~_6_4.,_8~__5_~..?_._36__5 ! E ! ·02 ]. 3~62,...2_7 _ .8800.4._8 ....55_ .... 69_!5.,23 .....6868_,23. _.$86.,_00E 32.62 5 z~0~0_,2_9_[ ._/+_0_/+_0._42_._$_._8_e__.32 .!.~__E _ 0:.87! ~,03_7_._._9_9 8900_98 .....30 ..... 69e!~2.! ........ 693~.2! ........ ,586.50E ..... _~.7_~.5./+_5__~_1..15_·2.?__E ...... :~1!5,.4/+._.S._89 ..... 28_38 ..... E ....... 0.513 ...... 9P00..___/+_?_~_5 .... .7_0/+7·.8.~. ?000.,~___S86700E ~+2.42 ,5 /+189.68 E /+189..89_$__89._25 11 E _Q.633 9100 /+6 25 7115·81 7068,81 .... $85.00E ~"~"~"~'-$~~~§~ 4263_+_0.7__5_8_9__21__ 9__E ........... 1,589 ....... _/+260.96 9200--~+-$--20 -71-8~+-·79--~137,79 S85,00E 5/+,48 ,5 /+334,92 E ....... _~..3..35,26 S e 9 ~ e ~ 7 E.......... 0 ' 0 90 ............... ~333e29 ..... -- 93 O0 '-"4'6'i-"~_0."-~7.~ 541oi0:9 ~-_-':72 07,.0-~ ........... i S.8 ~ ?._0 oEi'~""ff'- '_T6'_i01:'_77--'_~:'5-"':41~06..'7 8_E .... 4_~0.7..2 0-:Slii_.8 9__.!_2 '-"_3 5~'_-E .... 0,3_/+0 4405_. 35 9400 /+5 ~+5 7323,66 7276·66 ,584,50E 67·3z~ 5 /+47_8_,2.6__E____~_4!8_,77 5 89 8 18 E 0,.358 ........ 9500--'4'~-' -30----739-/+';'2 2 .... ;-7-3'/+7', 22 '--555',--00E .......... ~3 ,.8.~2_...5__.! 5..6.8,83 ...... E ....... _4_5/+9. · ~ 3.. S .. 89 ..... ~_...!.2 .... E ............. 1,274 .......... --"9600-"43 ........ 5 ..... 7466·~,'0 ......... 7419*/+0 ......S84,00E 80.45 S _/+..61_Y,_.__72 ..... E ..... 4__618../+2._5__89 ......0 .__6_E 1.485 4616.9~ ...... 9800--41 ..... 1'-5'- 761Y+,-72 .....75'67;72 .... S84,00E 93,31 S 4751.26 E /+752.17 S 88 52 29 E 0.946 4750'·90- ...... 9900 40' 10-'-7690.52 76/+3.52 S8~..OOE ....... i'00."13'-S ..... 481-6';12--E ...... 4817.16'-'5 88 /+8"32 i ........... 1;0'80 ................ ~+816.00-- -'10000'-3~-'-~0 --??'~? ;-12 ??ao". 1~ .... se2; 50E -!O~-;-~'~)--$--T.9:i-?%"ge- E ......... /+SS~-";'i s-'S-'-~8--Z~/+- ~-'-£ ....... O',~ge /+S~O. 10 '-'10200 ~8 55 ?~1.~9 ?~74.1~ $79.00~_~ _!..25-_6_.°__S__ 50_0_6:_.17 E ..... 5007_.75_,5 a8 .... 3a.~a__a ...... 1.e23 ................ 5O06.?? -10300--3-"/ .... 55 ?999;53- ..... 7952.53-',577·00E 138·61 S 5066.96 ................ E 5068.8'6 S 88 25_ 58__E _ _1,253 .......... 5.068.26__ -10/+00-37-i5 8078;77- Eio'31-e77 ..... STg:'-'OOE-: _--1-5"f;82'-S ..... ~-12'6.52 E ......... 5128.'/6 S 88 18 .... 13...E ........ 0_~772 ............ 5128.32 -'10500 36 40-8155:67 811~,-67 577,50E 16'4,-57'-'$- .... 51aS..:2~___E__5!_8.7,.8~_.S_88__.!O ..... 55 ,E ..... 0,_~07_ .......... 5187,57"" ................................... ~ ................... -:1m .... 10600 36 10 8239,14 8192,.4 S77.OOE 17~·63 S 5243.18 E 5246.19 S 88 3 32 E .......... 0,529 ......... 521+5.98 _ 10700-'35- 50 .... 8320-~-04- -$273,0~ .... -S?6-'50E,ii:'--19T-:.-15-:S'i:::5300-:~'/+0 'E ....... 5303.8~.__,5 87 56 /~...E ...... 0.372 10800 35 0 -8401.53 8354.53 S76.00E 20~+.93 ............ S 5355,_69 E ...... 5360.61 S 87 48 32 .E .......... 0.855 ..........5360.56_ 10900 ..... 34 ..... 5~- ..... 84-$3'52- $436.52 '575.50E .... 219.02 S 5412.!7 E 5416.60 S 87 40_.57 E ........ 0.229 ......... 5416..59__ 109i7-'-34"-50 ..... 8,q. 97.~8 9~,50,z:.8 575,SOE ....... 22i-?'5-'$- -5~'21.'58--E ...........5z+26,!0 $ 87 39 39 E 0.000 5/+25,09 lOg_~6_3Z~.~5 852~,29 8/+7~, 29 _._ 575,50E - 225~5_9__S .... 543~,60 E ....... 5/+z+2,.28 5.~87_ 37_27__E .......... 0,310 RECORD OF SURVEY ALL CALCULATIONS PERFORNED BY I B N TRUE DOG LEG MEA-s-~-D-R-IFT VERTICAL SUB--DRIFT TOTAL COORDINATES C L 0 S U R E S SEVERITY SECTION DEPTH ANGLE DEPTH SEA D[RE¢ D!STANCE ANGLE 'D- M DEG, D M S DEG/_10 O.._F~_ ......... D.I $ T.A.N. CE_ 11002 3~ 40 8567.32 8520.32 S75.00E 7233.71 S BOTTOH HOLE CLOSURE 5473.43 FEET AT S 87 33 9 E _ · INTERPOLATED _VALUE`5. FOR_EVEN_. 1000-F,-EET._OFMEASURED,_DEP_T_H. TRUE '" .... MEASURED VERTICAL SUB DEPTH DEPTH SEA TOTAL COORDINATES ., 1000 999. 952. 114,.95 N 23.64 W 2000 1999. 1952. 117.36 N 23.46 W 3000 2998. 2951. 115.99 N 3.38 E ~000 3944. 3897. 111.53 N 316.84 E 5000 4702. 4,655. 91.05 N 956.35 E 6000 5263. 5216. 75.51N 1783.82 7000 5832. 5785. 42.17 N 2605.31E 8000 6414,. --~6367. 5.31N 3~17'.93 9000 70~+7. 7000. 4.2.74 '5 4,189.'65 E /,,""-- I.,0000 7767. 7720. 107.96 ,5 4879.92 E 11000 8565. 8518. 233.55 ,5 54,67.30 E :. INTERPOLATED .TRUE.-.VERT I CAL. DEPTHS t .... COORD INAIES-AND-..CLOSURES ..FOR ..-G I.VEN-.DEPTHS TRUE CODE MEASURED VERTICAL TOTAL COORDINATES C L 0 S U R E SUB NAME DEPTH DEPTH DISTANCE ANGLE SEA' D M S / --i 0908 8005,8 4 !03.61 1097'7 10994 199.72 S 5071,75 E 80~7..,78 146.82 8060_,48 ..... 148 ,.89_S 5.112,87 E 8074.00 151,06 S 5122,95 E 10408 8085,14 152,83 $__513!~5 E 10521 8175~59 16[,99 S __5197,48 E 10594 8234,30 177,19 $ 5239,66 E 10854 8445,79 212.55 S 5386,68 E 50_7_3_,67 S 88 25 19 E 7958..,84 51..05 ,.48____$_88 _21_ 7E 8000,78 5 l_ZS_..,_.l e___S_iii 8 _ 18 _~__9. E_ ..8.027_,_.0 O_ __5_1_3S.._52 S__88 1~7__38 E 8_038.. 1~+ ' 5200.17__5_88 .... 9_.19_.E__8128.53 __5242,66__5_88 .... 3__~! E 818Y__.30_ _ 5390.87 S 87.~_~ 2.5E 8_3_98_.79_ 10946 8521,29 225.73 $__5437.56E_ 5_~_~2,2.4 %._87__3_7__2! E 841~.,.29___ MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB sEA DEPTH.. TRUE MEASURED VERTICAL SUB MD-TVD __DEPTH D_E P T H SEA D_I F_~_F ER EN C E VERT I CAL CORRECTION TOT AL CO0 R DI _NA_T_E$ 1&7 147. 100 0 0 117.99 N 24.93 W 247 247. 200 0 0 117.90 N 24,46 W 3~7 347. 300__0 0 117.39 N 24.32 W 24,62 W 447 447, ~+00 0 0 116.40 N 547 547, .500 0 0 115.60 N 25,16 W 6~+7 647, 600 0 0 I15,19 N 26,86 W 747 747, 700 0 0 115,06 N 24,4~ W 8~7 8~7.. 800 0 0 115.18 N 2~,01 W 947 947. 900 !!~_~99 N 23,68 W 'i'~'4-?' 10'47, 1000 0 0 ~, 114,95 N 23,61 W 11/+7 1147. 1100 0 0 115.19 N 23.41 W 1247 12/+7, ~200 0 0 1'3'4'7 13'4-"/;-- ....... i'300 'I-4 ~ 7 14 4 7, i-~0 0 I~-~? I5-4'?~. 1500 1-547 1'6~'7'; .... i600 I74~ 1-7'~7. 1700 ~I8-4-7 18~7. 1800 1-947 --19~'7'; 1900-- 20'a ? 20~?, 2000 0 0 · i16,30. N 24,21W 0 0 116,39 N 24,20 W " 0 0 116,37 N 23,89 W o o 1 I7';'i'~-N 2 4. o 2 w 0 0 i17,35 N 23,72 W 0 0 117.36 N 23,68 W o o o o 21~+7 2147, 2i00 0 117.36 N 23.63 W 117 ;-3'3--1~ ........ 23,31 W 117,32 N 23.25 W .2247 2247-,- .... 2200 .......... 0 2'347 2347. 23'00 0 2447 2447. 2400 0 254'7 -- 25%-7.. 2500 0 2647 2647. 2600 0 2747 2747. 2700 0 2847 2~'7~ .......... 2800 ............ 0 2948 2947. 2900 0 - ~-049 3047e 3000 2 ......... 3151 3147, 3100 ............... 4 3254 3247. 3200 7 3358 3347' 3300- i0 0 1'17; 32' "N .......... 23 ' 25 0 117.31 N 23,17 0 117.24 N 22,50 W 0 117.39 N 21,49 W 0 11'7.30 N 20,20 W . __ o 117,. IO_N ............. 0 116e30 N 15,64 W 0 115.79 N 5,18 W 2 116e31 N 12e64 E 2 116.81 N 33e64 E 3 116.39 N' 57e62 E 3 115.53 N 84.46 E ........... 3~62 ................... 3447" 3400~ 4 ............................... ~ ............................... 114.28 N 113.25 E ........ 35~7 .............. 3547; ...... 3500 19 ......................... 5 .......................... ! 13;2'4 'N-- 145 ."45 M EASURED_DEP~H_ANDO..THE. R_DAT_A_£OR E.~ERmY_~EV. EN __ 00 F EEZ OE_SU B__5 EA_DEP_'[H, TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH SEA DIFFERENCE DEPTH CORRECTION TOTAL COORDINATES 3674 3647, 3600 27 8 112,71N 183,59 E 3782 3747, 3700 35 8 112,69 N 224,75 E 3892 3847. 3800 44 9 112,69 N 269,37 E 4003 3947, 3900 55 11 1.11,46 N 318,21 E ~118 4047, 4000 70 15 108,14 N 374,28 E 4238 4147. 43.00 90 20 4363 4247, 6200 116 26 02_._8.~_N.. ...... ~,4Q...3 2 E __ 96,03 N 515,71 E 448'9 4347, 4300 142 26 93.59 N 592,51E 461.8 4447, ~400 170 28 6756 4547, ~500 208 38 94,29 N 673,4~ E 96,20 N "768,56 E 4907 4647, 4500 260 52 92,35 N 881*94 E 5078 4767, 4700 331 71 5255 4847, 6800 408 77 5634 4947, ~,900 487 79 90,28 N 1020,~4 E 87,87 N 1166.70 E 84,78 N 1314,90 E 5613 5047. 5000 566 79 -.5'79 ! 51-4-7, 5 ! O0 644 78 -5-970 5267, 5200 723 79 5300 8OO 77 5400 ......875 75 6147 5347, 6322 5667, 6497 5547, 5500 950 75 83.27 N 1463.38 E 80,46 N 1610,81 E 76.38 N 1759,01.E 72.00 N 1905,00 E 67.31N 2048,62 E 60,24 N 2191.95 E 6673 5667. 5600 1026 76 6'85b 57~+7"~ ....... 5700- ....... l l'O 3 77 7024 5867e 5800 1i-77 74. 7199 5947. 5900 1252 75 --7-373 664Y'; ......... 6000--13'26 76 7546 61~7, 6100 1399 73 7717 6247, 6200 1470 71 7886 6367. 6300 153'9 69 8054 6447. 6600 1607 68 e~z9 6547. 6506---i672 65 8380 6647. 6600 1733 61 853'9 6767. 6700 1792 59 55.11 N 2336,83 E 47.89 N 2482.~8 E 41.48 N 2624,96 E _ 36_~...~8_.N,. _2768 · 22 .... E 31.13 N 2910.5/+ E 24.84 N 3051._*_7~_E 17,24 N 3190,18 E 10~_10 N 332.6m35___E__ 3.40 N 3461.02__E 3.10 $ _3591.85 E 9e~3 5 3718.29 E 11.38_S _ 3841.~2 E ............ 8695 .................... 6847_, .......... 6800 1848 ........................~56 ........................... 26,35.5 ...... 3960,95 E .............. ......... 8848 ................ 6 94_7_, ........ 6900 1901 5.3 3_5,1 ~__5 ......... 4076,32 :_E 899_8 ..... 70~_"/_, ...... 7_000 ..... 1951 50 _42.64..S ..... A188,16_E · !ASURED DEPTH AND OTHER DATA FOR EVERY EVEN lO0 FEET OF SUB SEA DEPTH, TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTLON TOTAL C QOR_D_[NA_I_E_S 9145 71/+7, 7100 1998 4,7 51.01 5 4295.26 E __9290 7247. 7200 20/+3 45 60.13 5 4,399,50 E 9433 7347, 7300 2086 4,3 9573 ', 7447, 7~00 2126 40 69,73 S 4,501.70 E 78.56 S 4599,30 E 9709 7547. 7500 2162 36 9843 7647. 7600 2196 34 9974 7747, 7700 2227 31 X03.0~. 7847, 7800 2257 ~ 30 10233 7947, 7900 2286 29 i~ 03-6'0 8047, 8000--'23 ~. 3 27 :1. 0/+85 8147, 83. 00 ~.338 25 10610 8247e 8200 2363 25 87 e_z+7 S -4' 69_1_,0 8._E 9 6.,.2.5__..$ ..... 47 79., 1.8_E 105,70 5 4863,25 E 116,08 S 4,.946,05 E !._29_,_.7_~_A__ 5_02 6_,.~ 8__E 146,69 S 5102,77 E 162,83 S 5176.47 E 178.97 S 52~8,77 E i'073-3 834,7. 8300----2-386 23 ].O-8-'~5 ex+4'7, 8400 2/+08 22 109-77' 8547, --8500 2'2~3"0 22 195.81 5 5_3.19_,_.08 E 212,70 S 5387.23 E 230,16 S 545/+,66 E HORIZONTAL VIEW SCALE I"= I000' J 60oo 6400 ATLANTIC RICHFIELD COMPANY WELL NGI No. 2 RADIUS OF CURVATURE METHOD 7200' - 7600 'i i ~ i ALL DEPTHS SHOWN i!! ARE TVD. 84O0 TVD= 8,567 TMD I 1~002 1 '~';".: ~:- ii, ,, : i I~ VERTICAL SECTION -I .... . _ . : ' !j i !.';..' .i ...... ~"';.'J'-: ~ .'~.'~ . I SCALE I"= I000' · _ : !.' !':'i eoo ATLANTIC RICHFIELD COMPANY . . i: .... '.'."!.' i"'-1 .... ...~ ....... .L..L2 .............. ..L ! .... .~'. ......................... ~. WELL NGI No. 2 ............. ; ........... ~ ......... ;~-;'"i'~';-'' ..... . - . RAOIUS OF CURVATURE METHOD ........... 1200 .... l -- -: -~ - - · : '. ........... ~ - · ' I ' ; ~ i ~ : ~ : ' ~:'I' ~._i :._L__I-_ iL_z_!j .......... L ........... i-:---~.....' ....... '---,.: .... I-~L. DEPTHS SHOWN I , · ~ .. ~ :.t ', :.,:-~--.t-; ~-- I~ ..... I ~':': .... ~ .... I .... :' ;''i .... i~ ' ' , ' ~ " ./ ........ [ .... ~,_L,,~, .~ ..... ~ ....... ~.,~ .... I ~ ~.~~ .......... ~ ...... ~..' : : '-,-~---;-~ ........... ~ ......... { ................................ . ............. ~ ........... ' ~ : . , , , .... i ~_._.:"'~, '.-_'_._...~.~ ........ , . · . .1 , . . ..... ' .............. ~ ..... ~ ...... ~ ....... ~-~' ..... ~-~ .......... ~ I ! .... J. J~...'t. L.~,. ;~1.-~.~-:_.:.I ~bF,~_.~ I...~-_4,!... :..~.!-.I. dTM,~ ;,._~_..L.[~ :_~ ..... ;._~ .... ~,1..: : ! .... : ........... '~ [ j : L_.: ~ ' ": ..... ', .......t ........... ~- I ...... ~ .......... : .......... ~ ...... i ........ : ........... ~ ...... : .... I-~.~-.~-k:-~--~----~-,--:--:'~-'-::'~:7,: .... ?" ..... :::':'-~ ....... ,'"':"~ ................ :"~'~': ....... : ........ ~ , ' J - I J . :. .': :.., .... ; : ' . I ;..' · ~ - .-:'-', :" [ : ~,. i: ., .. . ~ i ' TVD= 8,567 AtlanticRichfieldCompany North Ame!~'% Pr,oducing Division North AlasL ~,istrict Post OffiCe~Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 10, 1975 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil an8 Gas 3001 Porcupine Drive Anchorage, Alaska 99501 RE' NGI No. 2 Permit No. 75-52 Dear Sir: Enclosed please find the Monthly Report of Operations covering the month of October for the above mentioned well. Sincerely, C. R. Knowles District Drilling Engineer CRK: alh Enclosure , r,:,~ No. ~,---~ STATE OF ,,~d. ASKA ~. 3- I-?0 SUBMIT IN DUPLICA'I"E OIL AND GAS CONSERVATION COMMI'rI'EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS O,L [~ o,,. ~ o..,,,,.,, Gas Injection W~LL W~LL 2. NAME OF OPEI%ATOR Atlantic Richfield Company 3. ADDarSS OF OPeRaTOR P. 0. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL 802'S & ll14'E of NWcr ,f Sec 12, TllN-R14E, UM ~5. API NLTNIERICAL CODE 50-029-20174 $ L~&SE DESIGI~ATION AND SERIAL NO. ADL 28302 7. IF INDIA~, ALOTLE£ OR TRIBE NAME 8. L,~IT FABAI OR LEASE NAME Prudhoe Bay NGI No. 2 (11-7-11-15) 10. FiRLr) A_ND POOL. OR WILDCAT Prudhoe Bay, Sadlerochit Pool 11. SEC., T., R., M..-(Bo'CrOM HOLE OBJ-F, CrlvE) Sec 7, TllN-R15E, UM 1~. PER.MIT NO. 75-52 13. REPORT TOTAL DEi~TH AT END OF MONTH, CHA~NGES IN HOLE SIZE. CASING AND ClfdVIENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED. PERFORATIONS. TE~TS ~ RESULTS, FISHING JOB~, JUNK IN HOLE AND SIDE-TRACKED HOLE A.ND AJqY OTHER SIGNIFICANT CHANI~ES IN HOLI~ CONDITIONS. Report on operations for the month of October, 1975 Spud @ 7 PM 10-12-75. Drilled 17-1/2" hole to 2712'. Ran 13-3/8" casing to 2688', cemented w/5100 sx Permafrost II cmt w/full returns to surface. Recemented 13-3/8" x 20" annulus w/PF II thru 2-3/8" risers. Landed and cut off casing, installed and tested casing head. NU and test BOPE. Test casing to 1500 psi. Drilled float collar, cement, shoe and 10' of formation; test to 0.65 psi/ft okay. Directionally drilled 12-1/4" hole to 9860', conditioned to log. Ran DIL. POH. Ran 9-5/8"casing to 9830' w/float collar @ 9740', FO tools @ 2396' and 2642'. Cemented w/1000 sx Class G cmt. ND BOPE, set 9-5/8" packoff and tested to 5000 psi. Preparing to cement the second stage of the 9-5/8" casing on November 1, 1975. NOTE --Report on this form il required for -each calendar month% regardless of the otu$ of operations, and must be flied in duplicate with the oil and gas conlervation committee by the 15th of the succeeding moth, unle.~ otherwise directed. "MEMORAN[-' M ' DEPARTMENT ~OF NATURAL RESOURCES Division-of Oil and Gas TO: O, K. Gtlbreth, Jr,~~ Di rector ~q/~ '~Y ~ · State DATE: FILE NO: THRU: Hoyle H. Hamilton ,'~ TELEPHONE NO: Chief Petroleum Engineer FROM: Alaska. October 21, 1975 Ben LeNorman Petroleum Inspector SUBJECT: BOP Stack Test, BP GC-2A BOP Stack Test, ARCO NGI-2 Departed my home at 7:40 AM October 16, 1975 to catch 9:00 AM BP charter for Prudhoe Bay, arriving at Deadhorse at 10:30 AM. I was met at the air- strip by Mr. Neil Booth, BP representative, and we proceeded to Nabors Drilling Rig 18-E where we learned nippling up had just begun and it would be several hours before tests would begin. Mr. Brian Rose, Drilling Foreman, was asleep and Mr. Booth recommended a short tour of the field before checking me into a room at BP operations. Temperature was +12°F with light snow. On checking into BP operations, we immediately attemped to contact Mr. Tom Webster, ARCO Drilling Foreman, at ARCO's NGI-2 location but were unsuccessful in doing so. (We were to learn later that the phone to Challenger Rig No. 51 was experiencing problems which were to plague us during the next three days. }. Intermittent reports throughout the day and evening indicated many problems in nippling up at'the BP location. Nabors 18-E Rig is on it's first location with new crews and highly sophisticated equipment. At 8:05 AM October 17, 1975 Mr. Tom Webster of ARCO called advising~ the BOP stack was nippled up but changes in the choke manifold and the inability to obtain two inch schedule 160 weld ells were delaying tests. Mr. Webster suggested he contact Mr. Rose with BP to try to coordinate possible wit- -. nessing of both ARCO and BP tests. We agreed. We'were called to the BP location at 12:30 PM to begin tests. However, on arrival it was soon evident..that additional problems had_ to be overcome . ,i_ We toured the rig and location with Mr. Rose and Mr. Bob Pomeroy, Nabors Toolpusher. The reserve pit was diked and in good condition. Fuel tanks were not diked. The well sign had not been finished yet. N2 bottles were not on the floor at the accumulator site. Pipe rams, blind rams and hydril were actuated by the prin~ry controls. The pipe and blind rams opened and "closed in five seconds. The hydril opened and closed in 13 seconds. A Attemps to pressure test the 'stack failed when the test plug would not seat in the casing head. Attempts to correct this problem began. · At 12:30 ~M October 18, 1975 Mr. Elden Schultz, Toolpusher for Challenger Rig No. 51, arrived to take me to the ARCO NGI-2 location. It had been -- agreed that the ARCO gas injection we'll should take precedence over the BP. :water injection well if the two rigs tested equipment simultaneously, We arrived at the ARCO NGI-2 location at 1:05 AM to find Mr. Tom Webster had 'been relieved by Mr. John Gossett. Due to the change of personnel and phone problems the stack and kill line components had already been. tested to 5000 psig without my being on location. Another hitch developed in the choke O. K. Gtlbreth, Jr. B. LeNorman - Field Trip Report BOP Stack Tests - BP, ARCO Page 2 October 21, 1975 manifold and testing was delayed. At 6:00-AM we were advised a further delay could be expected. I~e toured the location which was neat and well orgatnzed. The reserve pit was diked but the fuel tanks were not. The well sign was correct and in place. Ne bottles at the accumulator tested 2200, 2100 and 500 psig. Five spare N~ bol:tles were on hand and we recomended the 500 psig bottle be replaced.' 'Testing of the choke manifold began at 10:30 AM and lasted, until 3:10 PM. Nineteen valves including two manual adjustable chokes and the Swaco auto- matic choke were tested successfully to 5000 pstg as well as 66 flanges. Testing was delayed tntemittently due to four leaking valves and the failure of the Sprauge pump to bleed off after pressuring up. These problems were corrected as they occurred. The kelly cock, lower kelly valve, and both ball and dart type floor valve were tested to 5000 psig. Testing was completed at 5:05 PM. A Field Inspection Report was prepared, the original given to Mr. Gossett with a copy to Mr. Richard Knowles and a copy attached to this report. At 6:05 PM we contacted Mr. Brian Rose at the BP GC-2A location to see if tests had been completed. He advised all tests were completed by mid-after- noon. The N.2 bottles would be hooked to the accumulator, the well sign completed an~ discharge lines from the choke manifold to flare pit, reserve pit and separator would be installed before drillt~ out, Mr. Rose advised. We did not complete a Field Inspection Report on this well due to the lack of. observations made. I departed Deadhorse airport at 10:55 AM October 19, 1975 .via Wten flight 10 and arrived at Anchorage International airport at l:15 PM via Fatrbanks~ In summary, we witnessed partial testing of both BP's GC-2A and ARCO's NGI-2 BOP equipment before drilling out from under surface. Alaska Oil and Gas Conservation Committee ~ Field Inspection Report ~-.,, .~,~ .,j:,~l,,~ Well/Platfm Sec//_T~y_A~_/R~,- M Drl g. Permit No.~~ :~. A,!' - Operator ~" · Represented by 0~-o~.~-.,~--~ Name & Number ~ / ~,.~:~,' ~.~.~.:,~ ...,~. - ....... Satisfactory Type Inspection Satisfactory Type Inspection Yes No Item (~.)"Location,General " Yes No Item (~,,)"'BOPE Tests (~)~- ( ) 1. Well Sign (~")~ ( ) (1~.)~- ( ) 2. General Housekeepin.Q · (~ ( ) ' ( ) ( ) ~. Reserve Pit-( )open( )filled (~')" ( ) ( ) ( ) 4. Rig (~')~ ( ) ( )Safety Valve Tests (~)" ( ) ( ) ( ) 5. Surface-No. Wells (~,')" ( ) ( ) ( ) 6 Subsurface-No. Wells (>.~ ( ) ( ) Well Test Data (~,'-)"~ ( ) ( ) ( ) 7. Well Nos.__,__,__,__ (~"~ ( ) ( ) ( ) 8. Hrs. obser__,__, ,__ (~)~ ( ) ( ) ( ) 9. BS&W__,__, , (~")" ( ) ( ) ( ) 10. Gr. Bbls. , , -~ (~" ( ) ( ) Fina~ahdo'n~n~-n~---~ (~)' () ( ) ( ) .ll. P&A Marker (~)~' ( ) ( ) ( ) 12. Water well-( )capped( )plugged (~)~ ( ) ( ) ( ) 13. Clean-up (N'>~ ( ) 30. Lower Kelly valve ( ) ( ) 14. Pad leveled (m,).~ ( ) 31 Safety Floor valves--L-(- ~--~:BV (~qgart Total inspection observatio.n,, time *~~hrs/'days' Total number leaks and/or e~;,.uiP, failures 15 t~'Casing set @~~ 16 TesL fluid-( )wtr.---~ )mud 17. Master Hyd. Control Sys.-~m~)sig'::i' 18. N2 btls.~,~,~m~,~,?~psig .... ..~ 19. Remote Controls 20. Drillin~ spool- ,~ "outlets 21. Kill Li~e-(~,')~'~Che-~-~-valve 22. Choke Flowline (w)'."HCR valve 23. Choke Manifold No. valvs/?fl.~s 24 Chokes-(~-~Remote( )Pos.(~dj 25. Test Pluo-( )Wellhd( )csg( )none 26. Annular Preventer,~psi.~ 27 .. B1 i nd Rams ~,~ps i ~ 28. Pipe Rams ~..~o~psiq · 29. Kelly & Kel~y-cock,~~s. ig . /,.,~ ,,, days or when ready Inspected by~_,.~ ~ )~+,.~.~ Date cc .~~.?~.:,~,?~.~ .,~."::~r Noti fy i n . ticaichfieldCompany North AZ' .,;an Producing Division North A,_ ~;a District Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 OCt 2 . . _..., October 7, 1975 Mr. O. K. 6ilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99S04 Sec 7, T1LN, tLI4E, UM Permit No. 7S-S2 Dear Sir: Enclosed is our Sundry Notice outlining our plans for the subject well. Very truly yours, C. R. Knowles District Drilling Engineer CRK: alh Enclosure Form REV. 9-30-69 STATE O.F ALASKA S~abrntt "Intenttons" tn Triplicate "Subsequent Reports" tn Duplicate OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (DO not use this form for proposals Ix) drill or to deepen Use "APP]~ICATION FOR ~'Elll~IT-2-'' 'for such 'p[o~osal-~.) OIL ~_{ GAS ~LL ~ELL ~ OTHER Gas Injection 2. NAME OF OPERATOR Atlantic Richfield Company 3: ADDRESS OF OPERATOR P. 0. Box 360, Anchorage Alaska 99510 ..... .. ~ .... -:- :: .... i . - ........ .--' :-'- -' -' - ' 4. LOCATION OF WELL .... .. . . At surface - "' ' 802'S & ll14'E of NW cr of Sec 12, TllN, R14E, UM 13, ELEVATIONS (Show whether DF, RT, Gl{, etc. 18 ' Gravel Pad Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: FRACTURE TREAT ' SHOOT OR ACIDIZE REPAIR %VELL PULL OR ALTER CASING 'MULTIPLE COMPI.ETE ABANDONs CHANGE PLAN8 ~Other) APl Nbg, I,EIiIC.,U~ CODE 50-029-20174 6.~E DESIGNATION ~'qD SEl{IAL NO. ADL 28302 7." IF IiN~DIA~N*, ALLO'rlE32 OR TRIBE 8. UNIT~ FAI:~%I OR LEASE NAME Prudhoe Bay 9. WELL NO. NGI No' 2 .(11-7-11-15) 10. FIELD A~ND POOL, OR WILDCAT Prudh0e Bay, Sadlerochit 11, SEC., T., R., M., (BOTTOM PIOLE OBJECTIVE) Sec 7, TllN, RkO, UM 12. PEtlAIIT NO. 75-52 ~ort, or Other Date SUBSEQUENT R~PORT OF: , [ WATER SHUT-OFF ' REPAIRING ~'ELL FRACTURE TREATMENT ALTERING CASING SHOOTING O11 ACIDIZINO'~ j ~BANDONME~'T' (Other) -~ (No,z: Report results of multiple completion on Well C.mpletion or Recompletlon Report and Log form.) !5. DESCRIBE PROPOSED OR COMPLETED OPERATION8 (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. The Atlantic Richfield Company proposes to change bottom hole location of this gas injection well from 2550' N and 1000'W of SE cr of Sec 11, TllN, R14E, UM to 1000' S and 1000'E of NW-cr of Sec 7, TllN, ~, UM. We propose to directionally drill this well to 11500' MD, 8750' TVD for use as a future gas injection well in the Sadlerochit gas cap. Because of the longer well crouse, 9-5/8" casing will be set @ +-9550'MD and cemented with -+1000 sacks of cement. A 7'"." 'liner will be set @ TD as originally proposed. Logging, completion and well control programs will. not be changed. Surface location of this well is on ADL 28302 and the bottom hole location will be in ADL 34632. , 16. I hereby certffykat the fjrregolog is~true and correct '., ' .... /J~ . ..'-.t~.~ f...J .... OCT 6 19'75 · 5ep~r. ]2, 1B75 Re: Pr~adhoe Bay ~t.G.~. No. 2. A~tant. lc Richfield Company Mr. C. R. )~nowles Otstr~ct Orilltng £ngtneer Atlanttc Richfield Company P. O. Box360 Anchorage, A1aska 99510 Bear Sir: Enclosed is the approved a'pplicatton for permit to dr111 the above referenced well at a location in Section ll, Township 11)t, RAnge 14£, UM. Well samples, core chips, and a mud log are not required. A directional survey t s requt red. Many rivers in Alaska and their drainage systems have been classified as important for the spa~ntng or migration of anadromous fish. Operations tn these areas are subject to AS 16.$0.870 and the regulations promulgated there' under (Title 5, Alaska Admlnts~tlve Code). Prtor to commencing operations you may be contacted by the Habitat Coordinator's office, Oepartment of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 03, Article 7 and the regu]attons promulgated thereunder {Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amend. Prior bo cmmmncing operations you may be contacted by a re~entative of the Oepartment of Environmental Conservation. Pursuant to AS 38.40, Locat Hire Under State Leases, the Alaska Department of Labor ts being notified of the issuance of this permit to drt11. In the event of suspensto~ or aban~nt please give this office adequate advance notification so that we 'may have a witness present. Very trul~ ~, 0. lC. Gilbreth, Jr. Chairman Alaska Oil and Gas Conservation. Ceaeittee rOb:be Enclosure cc: Oepartment .of Fish and-Game, Habitat Section w/o encl. Department of Envt~tal Conservation w/o encl. Oepartment of Labor, Supervisor, Labor Law Compliance AtlanticRichfieldCompany North A~-'~"%n Producing Division North Al;. District Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 SEP 8 975 September 5, 1975 Mr. O. K. Gilbre~th State of Alaska/ Department of Natural Resources Division of Oil a~d Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Re: N.6.I. No. 2 (43-11-11-14) Sec. 11, TllN, R14E, UM Dear Sir: Enclosed is our Application for Permit to Drill for the Subject Well, together with the $100 Application Fee and reqUired survey plat. This well will be directionally drilled. The surface location and target location are both on ADL 28302. This lease has an effective date of 10/1/65 and termination date of 3/27/84. The information in the above paragraph will be help- ful to the State Depar.tmentof._~Labor. Very truly yours, Jerry W. Schmidt for C. R. Knowles District Drilling Engineer CRK/JWS/gr Enclosure lmorm ( Other instruction. reverse side) OIL AND. GAS CONSERVATIO'N ,COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK l&. TYPB O~ WORK DRILL l~1 DEEPEN I--I PLUG BACK b. TYP~ O~ WI~LL ~IINOLm o,,.w.,.,. I-I w..,.,.°A" I-I o.... c~ Tnj,~,-~--~,-,~ ........ ,.o,, ~ .,,,,T,,',,...o.. 2, NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OIF OPEH, ATOR P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 802' FNL & 1114' FWL of Sec 12, TllN-R14E, UM At p"~'~l~rr°~,~'e~ 1000 FEL of Sec 11, TllN-R14E, ~4 13, DISTANCE IN MILES AND DIRECTION F=COM NEAREST TOWN OR POST OFFICE* Approximately 8 miles Northwest of Deadhorse 14. BOND INFORIV[ATION: TYPE .~t;:q-~-FalaT-~ (-1/:a Surety and/or No. '~/;~fl~:~-.v,,~l T 15. DISTANCE FROM--P~H-OPOSED* ........... '~.'~¢O.~F ACI~'i~-~I~ LWA-~ETM LOCATION TO NEARE-~T / PROPERTY OR LEASE LINE. . , FT. ,,~ .... (Also to nearest drig, unit, If any) ~b~)O . 2560 l~. DISTANCE FROM PROPOSED' LOCATION* ilg. PROPOSE'b TO NEAREST WELL D~ILLING, COMPLETED. / 5200' | 9700' API #50-029-20] 74 6. LEASE DESIGNATION A.ND SI~J.&L NO, ADL 2/~302, 1, IF INDIAN, A.I. JAD~ OR 'FPABE NA.M.E $. UNIT~FARM OR LEASE NA~ME Prudhoe Bay 9. WELL NO. NT_ n_ T_ #2 (4'~-11 -11-14) 10. FIELD AND POOL, bR WILDCAT Prudhoe Bay, Sadlerochit 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 11, TllN, R14E, UM 12. i~nmmt d, 1 nn nnn t7. N-O. ACRES %~'~I~E~wu TO THiS WELL 32O 20. ROTARY OR CABLE TOOLS Rotary 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 22. APPROX, DATE WORK WILL START* 18 ' Gravel Pad . October 1, 1975 23. PROPOSED CASING AND CEMENTING PROGRA~ .. SIZE OF HOLE SIZE OF CASING WEIGHT pER F°OT GRAZyE r' S~.-i~-LNG DEP~ QUANTITY OF 32" i20" 94~ H-4O l flfl' C~rC tO s,]rFace - 17-1/2" 13-3/8'~ 72~ , ~-gO 2700' ~rc tn surface - ~nnn sx _ 12-1/4" 9-5/g" ~7~ .. ~.nn ninon, Icnn,~ ~ ~,~. , ......................... , ~ · . ....... sx) sx) , Ex) The Atlantic Richfield Company proposes to directionally drill this well to 9700' MD~8876 TVD for use as a future gas injection well in the Sadlerochit gas cap. Logs will be run over selected intervals.' A 20-3/4" 2000 psi Hydril will be used on the 20" conductor. A 13-5/8" 5000 psi Hydril and 13-5/8" 5000 psi pipe and blind rams will be used on the 13-~/8" casing. The BOP equipment will be presSure tested weekly and operationally tested each trip. A non-freezing fluid ·will be left in all uncemented annuli within the permafrost interval. 7", 29# Mod N-80 Hydril SUE tubing with a BOT Arctic Husky RH-1 packer and a 7" safety valve landing nipple will be run as a completion assembly. The well will be shut in waiting on perfOrating. IN ABOVE SPACE ~D]~SCRIBE I~ROPOSED PROGRAm: If proposal is to deepen or plug back, give data on present productive zone and proposed new productive ~t~e. If proposal is to drill or deepen dh-ecS :onally,, give pertinent data on subsurface locationz and measured and true vertical depths. Give blowout preventer program. 24, I hereby certify that the F~oregoLng is True anc~ Correc~ DATE ~~ SI t(~r~g (This space for State office use) CONDITIONS OF APpROvAL, IF ANY: SAMPLES AND CORE CHIPS [] YES ~NO iDXfCTIONAL SURVEY REQUIREDYES [] NO OTHER REQUIREMEN'~: I A.P.I. N~MEI~CA.L COD~e September 12, 1975 '~ *S~ Indmctions On Reverse Side Chairman o.~=September 12, 1975 SECTION I 915' 940' sectiOn line 965' 990' 1015' 1040' 1065' ~,090' IllS' ,., 1139' LAT. PROPOSED WE _L NO. 2 LAT. 70° 19' 37.283" Y 5 971 516.79 LONG. 148028'50.744" X 687 322.66 'ELL NO. 3 70019'38.438" Y 5 971 633,~ 148°28'51.473'' X 687 29' LONG. WELL LAT. LONG. NO. 4 19'59.592" Y 5 971 '02" X 5 10.747" 2.930" Y 866.94 687 239.03 WEL LA'E LONG. NO 70° 19' Y 5 971 983,65 X 687 211.15 WELL LAT. LONG. NO. 7 7'0° 148028'5` WELL LAT. LONG. NO 70° 2 I0" 116" WELL O. 9 364" 8028, 55.845" L NO. I0, ~. 70o19' 46.519'' )NG. 148°28' 56. 573" Y 5 972 100.57 X 687 185.27 Y 9 72 217.09 X 87 15539 Y59 X 687 Y 5 972 450.i X 687 099.6, Wells to be on 120ft. centers. XPROPOSED WELL · EXISTING WELL WELL NO. I TOP PAD ELEV.= 18.4 FT. MLLW ATLANTIC RICHFIEL. D CO. , ~///~ ~ WELL NUMBER I I HEREBY Y THAT lAM PROPERLY REGISTEREd~// I~.~-:.FjNORTH INJECTION SITE AND LICENSED TO PRACTICE LAND SURVEY'"~m_ ~/ ? , ~.:~ LOCATED IN PROTRACTED AND OTHER DETAILS ARE CORRECT, ~ CHECK LIST FOR NEW WE'LL PERMITS =- . Company ' Lease & Well No. 2 Yes~ No Remarks 1. Is the permit fee attached · ...... ~/~.~ _ 2. Is well to be located in a defined pool ................ A~ 3. Is a registered survey plat attached ................ ~ 4. Is well located proper distance from property line ......... X~ 5. Is well located proper distance from other wells .......... ~a~ 6. Is sufficient undedicated 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 ............. ~K O. Does operator have a bond in force . ..... ~< 1. Is a conservation order needed ................... 2. Is administrative approval needed ................. 3. Is conductor string provided .................... 4. Is enoUgh cement used to circulate on conductor and surface .... 5. Will cement tie in surface and intermediate or productiOn strings 6. Will cement cover all known productive horizons .......... 7. Will surface casing protect fresh water zones ........... 8. Will all casing give adequate safety in collapse, tension & burst 9. Does BOPE have sufficient pressure rating ............. kdditional Requirements' .. Approval Recommended' G-eol og~v Eng i nee ri ng' TRM ~-~ HI;IK ~_ ~ OKG~TJ ^ ~m~-,HHH ~ JAL ~tS~',~' ~LCS/__~JCM~ Revised 1/15/75