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186-158
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,899 feet N/A feet true vertical 10,672 feet N/A feet Effective Depth measured 10,660 feet feet true vertical 10,441 feet 9,288, 9,316 and 10,021 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 4-1/2" 12.6#/L-80 9,465' MD 9,298' TVD 3-1/2" 9.3#/L-80 10,230' MD 10,026' TVD Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5#/L-80 10,254' MD 10,049' TVD Packers and SSSV (type, measured and true vertical depth) 4-1/2" Otis SSSV See Above 1589' MD/1589' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Same 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Operations Manager Contact Phone: 9-5/8" TIW SBR, 9-5/8" BKR, 7" TIW HB-BP Burst 1,490psi Collapse 470psi 2,670psi 7,020psi 5,380psi 6,870psi 8,160psi 4,760psi TVD 10,672'10,899' 9,738' 9,554' Intermediate 30" 9-5/8" 111' 2,493' 9,738' Conductor 2,493'Surface 9,455, 9,485, and 10,224' NA 13-3/8" ENDICOTT / ENDICOTT OIL DUCK IS UNIT MPI 2-62 Plugs Junk measured measured 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0034633 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 186-158 50-029-21648-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 72 Gas-Mcf 2050 4739 70024460 18 15801245 1841 3275 N/A measured true vertical Packer MD 111' Size 111' 2,493' Length Liner 1,414'7" Casing Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Brenden Swensen brenden.swensen@hilcorp.com 907-748-8581 324-043 PL G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 2:11 pm, Dec 10, 2024 Digitally signed by Justus Hinks (3691) DN: cn=Justus Hinks (3691) Reason: I attest to the accuracy and integrity of this document Date: 2024.12.10 12:04:52 -09'00' Justus Hinks (3691) DSR-12/16/24WCB 2-12-2025 RBDMS JSB 122624 Well Name Rig API Number Well Permit Number Start Date End Date END 2-62 E-Line 50-029-21648-00-00 186-158 2/11/2024 12/5/2024 2/14/2024 Hilcorp Alaska, LLC Weekly Operations Summary *** WELL S/I *** OBJECTIVE: PERFORATE INTERVAL W/ 2" GEO RAZOR GUN 6 spf 60 DEG PHASE MIRU YELLOW JACKET E-LINE. PT PCE 300 PSI LOW/ 3000 PSI HIGH RIH W/CH/ 1.69" GUN GAMMA / 20' OF 2'' GEO RAZOR GUN 6 spf 60 DEG PHASE TO PERFORTATE INTERVAL 10120'-10140' CORRELATED TO SLB RST SIGMA & NEUTRON POROSITY LOG DATED 24 DECEMBER 2004 RUN IN HOLE AND PERFORATE INTERVAL 10120'-10140' CCL TO TOP SHOT = 7.6' CCL STOP DEPTH = 10112.4' JOB COMPLETE *** WELL S/I ON DEPARTURE*** 12/5/2024 The primary perforation interval shot has continued to be prolific throughout 2024 and there is little to no additional capacity for adding additional fluids / perforations. Final decision was made 12/5/2024 to not pursue the contingent perforation intervals. 2/12/2024 ***CONT WSR FROM 02/11/2024*** DRIFT TO TD @ 10,618' SLM W/ 21' x 2.25" BAILER (HARD BTM AND NO SAMPLE) ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED ON WELL STATUS*** 2/11/2024 ***WELL FLOWING ON ARRIVAL*** FUNCTION TEST WLV RIH W/ 3.83" G.RING TO 1,589' MD PULL 4-1/2" QOS(ser#QOS-41) FROM SSSV NIPPLE @ 1,589' MD PULL 4-1/2" DB-CHOKE(.375" bean) FROM CAMCO SLD SLV @ 9,381' MD ***CONT WSR ON 02/12/2024*** 2/26/2024 ***WELL FLOWING UPON ARRIVAL*** (perforating) BRUSHED TBG TO SVLN @ 1589' MD W/ 4-1/2" BRUSH & 3.805" GAUGE RING. TROUBLESHOOT FROZEN BALANCE & CONTROL LINES. SET 4-1/2" BALANCE OPERATED QOS-SSSV(Ser# HQOS-18) IN SVLN @ 1589' MD. PERFORM PASSING DRAW DOWN TEST ON QOS SSSV ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** PERFORATE INTERVAL 10120'-10140 _____________________________________________________________________________________ Revised By: DH 12/6/2024 SCHEMATIC Duck Island Unit Well: END 2-62 Last Completed: 7/15/1987 PTD: 186-158 TD =10,899’ (MD) / TD =10,671’(TVD) 30” KB Elev.: 55.1’ / BF Elev.: 15.7’ By Doyon 15 7” Estimated top of cement @ 9,200’ 2 3 4 12 6 13 18 9-5/8” 1 Min ID=2.313” @ 10,240’ 20/40 Carbolite tagged @ 10,660’ (4/1/05) PBTD =10,816’(MD) / PBTD = 10,591’(TVD) 5 7” Marker Joint @ 10,322’ 13-3/8” 14 10 15 7 17 16 9 8 11 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 30" Conductor N/A / N/A / N/A N/A Surface 111’ N/A 13-3/8” Surface 72 / L-80 / Btrs 12.347 Surface 2,493’ 0.1481 9-5/8" Production 47/ NT95HS/ NSCC 8.681 Surface 9,738’ 0.0732 7" Liner 29/ L-80/ Btrs 6.184 9,485’ 10,899’ 0.0371 TUBING DETAIL 4-1/2" Tubing 12.6/ L-80/ BTC 3.958 Surface 9,465’ 0.0152 3-1/2” Tubing 9.3/ L-80/ TDS 2.992 9,465 10,224’ 0.0087 2-7/8" Tubing 6.5/ L-80/ EUE 8rd 2.441 10,224’ 10,254’ 0.0058 JEWELRY DETAIL No Depth Item 1 1,589’ 4-1/2”x 1-1/2” Otis HXO SSSV Nip, ID= 3.813” GLM DETAIL: Camco KBM G 4-1/2” x 1-1/2” w/RK Latch 2 4,185’ Sta 6: TVD: 4,185, DEV: 0, VLV: Dome, Port: 16, Date: 7/12/2024 3 6,382’ Sta 5: TVD: 6,382, DEV: 1, VLV: SO, Port: 24, Date: 7/12/2024 4 7,862’ Sta 4: TVD: 7,810, DEV: 18, VLV: Dmy, Port: 0, Date: 7/13/1987 5 8,867’ Sta 3: TVD: 8,755, DEV: 26, VLV: Dmy, Port: 0, Date: 7/13/1987 6 9,128’ Sta 2: TVD: 8,989, DEV: 26, VLV: Dmy, Port: 0, Date: 8/13/2003 7 9,274’ Sta 1: TVD: 9,121, DEV: 24, VLV: Dmy, Port: 0, Date: 7/13/1987 8 9,381’ 4-1/2” Camco SLD SLV, ID = 3.75” 9 9,440’ 9-5/8” x 4-1/2” TIW HB-BPR w/Tubing Seal Assembly, ID = 3.958” 10 9,455’ 9-5/8” x 4-1/2” TIW Packer, ID = 4.00” 11 9,465 4-1/2” x 3-1/2” XO 12 9,485’ 9-5/8” x 7” Baker Model A Liner Top Packer 13 10,139’ 3-1/2” Otis Ported Nipple w/o Blanking Slv, Milled to 2.8” (6/7/2009) 14 10,224’ 7” x 3-1/2” TIW HB-BP Packer w/Tubing Anchor 15 10,230’ 3-1/2” x 2-7/8” XO 16 10,240’ 2-7/8” OTIS “X” Nipple,ID = 2.313” 17 10,246 2-7/8” OTIS “X” Nipple,ID = 2.313” 18 10,254’ 2-7/8” WLEG (bottom at 10,254’) PERFORATION DETAIL END Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status Size SPF 10,120’ 10,140’ 9,920’ 9,939’ 20 2/14/2024 Open 2” 6 10,164’ 10,187’ 9,962’ 9,985’ 23 6/24/08 Open 2” 6 10,192’ 10,196’ 9,989’ 9,993’ 4 6/24/08 Open 2” 6 10,204’ 10,212’ 10,001’ 10,009’ 8 6/24/08 Open 2” 6 10,218’ 10,222’ 10,014’ 10,018’ 4 6/24/08 Open 2” 6 10,302’ 10,312’ 10,095’ 10,105’ 10 7/13/87 Open 5” 5 10,336’ 10,344 10,128’ 10,136’ 8 7/13/87 Open 5” 5 END Sands 10,352’ 10,406’ 10,143’ 10,195’ 54 7/13/87 Open 5” 5 10,352’ 10,406’ 10,143’ 10,195’ 54 7/13/87 Open 5” 5 10,352’ 10,406’ 10,143’ 10,195’ 54 7/13/87 Open 5” 5 10,352’ 10,406’ 10,143’ 10,195’ 54 7/13/87 Open 5” 5 See well history for cement squeeze and reperf dates WELL INCLINATION DETAIL Max Hole Angle = 26 Deg. @ 8,916’ Angle at Top Perf = 16 Deg. @10164’ TREE & WELLHEAD Tree 4-1/16” CIW Wellhead FMC GENERAL WELL INFO API: 50-029-21648-00-00 Initial Drill & Completion by Doyon 15 - 10/16/1986 SAFETY NOTES H2S reading average 230 – 260 PPM on A/L & gas injectors. Well requires a SSSV. OPEN HOLE / CEMENT DETAIL 13-3/8” 3,720 cu/ft Permafrost in 17-1/2” Hole 9-5/8"575 cu/ft Class ‘G’ plus 345 sks Permafrost C downsqueeze in 12-1/4” Hole 7” 465 cu/ft Class “G” in 8-1/2” Hole Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 4/4/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240404 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 19RD 50133205790100 219188 2/23/2024 YELLOW JACKET GPT-PERF BRU 241-23 50283201910000 223061 11/25/2023 AK E-LINE Perf HV B-13 50231200320000 207151 3/11/2024 YELLOW JACKET GPT KALOTSA 6 50133206850000 219114 3/2/2024 YELLOW JACKET PERF KU 13-06A 50133207160000 223112 3/13/2024 YELLOW JACKET GPT-PERF KU 21-06RD 50133100900100 201097 3/19/2024 YELLOW JACKET GPT-PERF END MPI 2-62 50029216480000 186158 2/14/2024 YELLOW JACKET PERF MPU G-18 50029231940000 204020 3/21/2024 READ Caliper Survey MPU G-18 50029231940000 204020 3/9/2024 AK E-LINE HoistCutter MPU I-24 50029237780000 224001 3/11/2024 AK E-LINE CBL NCIU A-18 50883201890000 223033 12/20/2023 AK E-LINE Perf NCIU A-18 50883201890000 223033 12/18/2024 AK E-LINE GPT/Plug/Perf PAXTON 3 50133205880000 209168 3/6/2024 YELLOW JACKET GPT PAXTON 3 50133205880000 209168 3/8/2024 YELLOW JACKET PERF PAXTON 3 50133205880000 209168 3/12/2024 AK E-LINE PPROF PAXTON 7 50133206430000 214130 2/26/2024 YELLOW JACKET PERF PBU 09-52 50029236180000 218168 3/24/2024 HALLIBURTON PPROF SD-06 50133205820000 208160 2/20/2024 YELLOW JACKET PERF SRU 222-33 50133207150000 223100 12/19/2023 AK E-LINE Perf Please include current contact information if different from above T38683 T38684 T38685 T38686 T38689 T38687 T38690 T38691 T38691T38692 T38963 T38963 T38694 T38694 T38694 T38695 T38696 T38697 T38698 END MPI 2-62 50029216480000 186158 2/14/2024 YELLOW JACKET PERF Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.09 13:48:29 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: ENDICOTT 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10,899 NA Casing Collapse Structural NA Conductor NA Surface 2,670psi Intermediate NA Production 5,090psi Liner 7,020psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Brenden Swensen Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: 4-1/2", PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 8,160psi Tubing Grade: 12.6" L-80, Tubing MD (ft): 9,465',Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0034633 186-158 C.O. 462.007 DUCK IS UNIT MPI 2-62 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-21648-00-00 Hilcorp Alaska, LLC Length Size Proposed Pools: 10,672 10,246 10,041 3,069 ENDICOTT OIL ENDICOTT OIL NA NA 9.3" L-80, 6.5# L-80 TVD Burst 10,224', 10,254' 8,150psi MD NA NA NA 5,380psi 111 2,493 NA 111 2,491 9,5549-5/8" NA NA 20" 13-3/8" 111 NANA 2,493 907-748-8581 brenden.swensen@hilcorp.com Operations Manager February 15, 2024 10,8991,414 3-1/2", 2-7/8" 10,671 Perforation Depth MD (ft): See Schematic 9-5/8" x 4-1/2" TIW HBBP, 9-5/8" x 7" Model A LTP, 7" x 3-1/2" TIW HBBP 9,440' MD (9,274' TVD), 9,485' MD (9,316' TVD), 10,224' MD 10,020' TVD) 10,246 9,738 NA 9,738 7" See Schematic No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Carlisle at 10:48 am, Jan 31, 2024 324-043 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2024.01.31 07:25:19 - 09'00' Sara Hannegan (2519) Perforate DSR-1/31/24SFD 2/5/2024 SFD MGR04FEB24 10-404 JLC 2/5/2024 2/5/24Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.05 14:38:51 -09'00' RBDMS JSB 020624 Page 1 of 5 Add Perforations Well: END 2-62 PTD: 186-158 Well Name:END 2-62 API Number:50-029-21648-00 Current Status:Operable Producer PTD #186-158 Estimated Start Date:02/15/2024 Rig:EL / SL Reg.Approval Req’std?Yes Estimated Duration:6 days Regulatory Contact:Darci Horner 907-777-8406 (O) First Call Engineer:Sara Hannegan 907-309-1196 (M) Second Call Engineer:Ryan Thompson 907-301-1240 (M) Current Bottom Hole Pressure:4069 psi @ 10,000’ TVD (6/19/22) 7.8 PPGE Max. Anticipated Surface Pressure:3069 psi (Based on 0.1 psi/ft. gas gradient) Min ID:2.313” @ 10,240’ & 10,246’, X nipple Max Angle:26 Deg. @ 8,916’ Reference Log: SLB RST Sigma & Neutron Porosity Log 12/24/04 History The END 2-62 is currently perforated in the F3, F1 and S3A4 sands. The F3 has additional targets which are open in offset well 2-68 and is one of the better wells in the field. This procedure is to shoot up to 71' of perforations in 3 targets. Each of these targets would add reserves based on sand intervals that currently are not being drained by other wells leaving behind residual oil volumes unless produced by these add perforations. Objective x Perforate the primary target in the F3 from 10,120’-10,140’ x If results are poor, add contingent perforations in secondary targets at 10,065’-10,080’ and 10,004’- 10,040’. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Tie In Log Page 2 of 5 Add Perforations Well: END 2-62 PTD: 186-158 Procedure (Page 1 of 1) All perforations to reference log SLB RST Sigma & Neutron Porosity Log 12/24/04 Contact Geo Brock Rust or OE Brenden Swensen for final tie in. a. Brock Rust, brust@hilcorp.com, 615-306-9509 b. Sara Hannegan, shannegan@hilcorp.com, 907-309-1196 c. Brenden Swensen, Brenden.swensen@hilcorp.com, 907-748-8581 Operations will do flow periods between perf intervals with SSSV out to optimize slickline rig ups. Slickline 2. Pull SSSV from 1,589’. 3. Drift to TD with 2” spent guns. Tubing tail is 2-7/8”, 2.313” Min ID. Eline 4. MU perforating tool string. a. Perf guns should 2” be 6spf, 60 deg phasing guns with deep penetrating charges. 5. Perforate the F3 at 10,120 – 10,140’ MD (20’). 6. Operations to flow and test well. 7. Perforate the F3 at 10,065’ – 10,080’ MD (15’).(CONTINGENT) a. Perf guns should 2” be 6spf, 60 deg phasing guns with deep penetrating charges. 8. Perforate the F3 at 10,004’ – 10,040’ MD (36’).(CONTINGENT) a. Perf guns should 2” be 6spf, 60 deg phasing guns with deep penetrating charges. Slickline 9. Slickline set SSSV at 1,589’. 10. Operations to flow and test well. Page 3 of 5 Add Perforations Well: END 2-62 PTD: 186-158 FIGURE 1: Current Wellbore Schematic Page 4 of 5 Add Perforations Well: END 2-62 PTD: 186-158 FIGURE 2:PROPOSED WELLBORE SCHEMATIC Page 5 of 5 Add Perforations Well: END 2-62 PTD: 186-158 FIGURE 3: Tie In log - SLB RST Sigma & Neutron Porosity Log 12/24/04 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Producer END 2-62 (PTD #186-158) Anomalous IA Pressure Date:Friday, December 9, 2022 9:01:30 AM Attachments:image001.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Thursday, December 8, 2022 2:35 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: Producer END 2-62 (PTD #186-158) Anomalous IA Pressure Mr. Regg, Producer END 2-62 (PTD# 186-158) was shut in on 12/6/2022. The IA pressure began to increase steadily after being shut in. The IA pressure was bled by operations and again rose steadily afterwards. The well is now classified as UNDER EVALUATION and placed on a 28 day clock for evaluation and repair. Plan Forward: 1. Slickline: C/O OGLV 2. Operations: Monitor for repressurization Please respond if there are any questions or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, July 21, 2014 11:45 AM To: AK, OPS END OIM <AKOPSENDOIM@bp.com>; AK, OPS END Facility & FieldO&M TL <AKOPSENDFacilityFieldOMTL@bp.com>; AK, OPS END Board Operator <AKOPSENDBoardOperator@bp.com>; AK, OPS END AES Drillsite Lead <AKOPSENDAESDrillsiteLead@bp.com>; AK, OPS END Operations Lead Tech <AKOPSENDOperationsLeadTech@bp.com>; AK, RES END Production Optimization Engineer <AKRESENDProductionOptimizationEngineer@bp.com>; AK, D&C Wireline Operations Team Lead <AKDCWirelineOperationsTeamLead@BP.com>; AK, D&C Well Services Operations Team Lead <AKDCWellServicesOperationsTeamLead@BP.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; Igwe, Josiah <Josiah.Igwe@BP.com> Cc: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com>; AK, D&C DHD Well Integrity Engineer <AKD&CDHDWellIntegri@bp.com>; AK, D&C Projects Well Integrity Engineer <AKDCProjectsWellIntegrityEngineer@bp.com>; 'jim.regg@alaska.gov' <jim.regg@alaska.gov>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com> Subject: OPERABLE: Producer END2-62/Q-17 (PTD #1861580) Outer Annulus Repressurization Test Passed All, Producer END2-62/Q-17 (PTD #1861580) underwent a successful Seal Tite treatment on the inner casing packoff seals. An outer annulus repressurization test was completed on 07/20/2014. There was no build up rate observed during the test. The well is reclassified as Operable. A copy of the TIO plot is included for reference. Thank you, Jack Disbrow (Alternate: Laurie Climer) BP Alaska - Well Integrity Coordinator Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@bp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Regg, James B (DOA) From: Larry McBride <Imcbride@hilcorp.com> Sent: Monday, November 16, 2015 4:00 PM i(a � To: Regg,James B (DOA) j Cc: Wyatt Rivard; Paul Boots; Tom Weglin;Taylor Wellman Subject: Endicott deficiency reports Attachments: Dean Norris Deficiency Reports.pdf; 1-17A View Port.JPG; 2-04 Lockdown Screw.JPG; 2-04 Starting Head.JPG; 2-04 View Port.JPG Mr. Regg, Enclosed are the corrected deficiency reports for Endicott. Dean Norris, Hilcorp Wellhead Specialist, completed the work. More pictures to follow. Larry McBride Hilcorp Endicott Pad Operator Office: 907-659-6530 Control Room: 907-659-6700 SCANNED 2 4 1 • • State of Alaska 1 flip grub Gas C(?nSnry t'/)rt A.;nmrnicc kri f i it 1 1III 37� Lc.;caLiurs: 7riclil.ot , Date: ,` 1 vl::, i+'•1•1-1. I l�13i 54e.j / Inspection:Op..✓..a.. Hilcorp LLC Type ISUS v}:ciowr. .. p Operator Rep: Larry McBride inspector: Guy Cook 1) oncitnn. Dad v. _.,y.. i on7-659-i7nn Correct( Y• tu 4 •l.. '- - by(date): 1'Ill 7101 :J p.E-maii: Lmcbride(Cv'higcorp.ccm roiiow Up Required: yes 1 Detailed Description of Deficiencies Date Corrected 2-62 wing valve needs to have the torque checked )o�r the seal ring replacedfon the f 1 -d?- 1 5' .- I f tcnnet¢7_nge Thera appears to t.'e a Les,_k. 1<<CA bon,, 4-3311-5 4.4ct. pt JJ fJ '-j tf� �` 1 ( { 1 E C(P4k AcC 118.6..41)9 Qo d CbT �4I�i" 1f/-�'~ 1 .... ,- (t2ftnef Cis i f 1 1 11 ! ito c i 1% 1 11 ___, 1- f 11 11.________ 11 _ ; a 1i i 1 Signatures: L ' / ii /41 --,Cy Operator Rep 7 , _"dpi _ A 4 ,AOGCC Inspector *After signing, . co•y of this form is to be left with the operator. Follow-up Instructions ' Return a copy of this Deficiency Report to AOGCC(Attention:inspection Supervisor)within 7 days of receipt. Include the "Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective factions taking,longer than the"correct by"date must requested and accompanied by justification(Attention:inspection f 1C_uner cri, I 1 aiiure to provide therequired documentation or corrective actions constitutes a vocation of 20 AA(25.300 aro is suoject i Ito en orcerr en_action under 20 Aa..25 525 1 111 Reviser.3./.9..t2015 • • Attachment to Deficiency Report - DIU 2-62 (PTD 1861580) Photo provided by Hilcorp 11/13/2015 i .'( %0 J 91p . 4t,i, '\ ..- ..4 p . >, \\,ss:s, INg et r A F ' 4 1 7 esma Wing valve bonnet flange 2015-1113 Deficiency_Report_DIU_2-62_closeout photo.docx Page 1 of 1 �� � �� 1�u� �� State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: Endicott MPI - Date: 4 / 15 PTD: 1881580 Operator: Hi|corpLLC Type Inspection: SVS Guy Larry McBride Inspector: C mok Position: Pad Operator Op. Phone: 907-658'6700 Correct by(date): 11/17/2015 Op. Email: |mobhde@hi|coqp.00m Follow Up Required: yes Detailed Description of Deficiencies Date Corrected 2-62 wing valve needs to have the torque checked or the seal ring replaced on the bonnet flange. There appears to be a leak. ^ ' l Operator Rep Signatures: ~--' ' ��° ~~ 9� AOGCC Inspector 40 °�=- - '- *After signing,a co of this form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention: Inspection Supervisor)within 7 days of receipt. Include the "Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must requested and accompanied by justification(Attention:Inspection svpervismr) Fai|ueonpmvidczheneqv.,cddocumenu,nonofcorreoivcact|cnsconm*ute,ovmiztionof2o4�L 25,Junanoasubject fu �t�ct�ox:nder2O»�C25.525 cn ccrn� ! P712 /56 15 Loepp, Victoria T (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Friday, October 02, 2015 4:36 PM To: Alaska NS - Endicott - Operations Leads;Alaska NS - Endicott - Field Foreman Cc: Loepp, Victoria T (DOA); Regg, James B (DOA); Taylor Wellman Subject: RE: END 2-62 (PTD # 1861580) Return to Production Attachments: MPI 2-62 TIO.xlsx Follow Up Flag: Follow up Flag Status: Flagged SCANNED AUG 0 4 2016 All, Endicott producer MPI 2-62 (PTD#1861580 ) was returned to production on 9-7-15 after a successful sealant treatment of the production casing packoff seals.There has been no further outer annulus pressurization since treatment. A TIO plot has been attached for reference. The well remains on production. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 llikulvI a. . T I t From: Wyatt Rivard Sent: Thursday, September 10, 2015 4:45 PM To: Alaska NS - Endicott- Operations Leads; Alaska NS - Endicott - Field Foreman Cc: 'Loepp, Victoria T(DOA)'; 'Regg, James B (DOA)'; Taylor Wellman; Mike Dunn; Chris Kanyer Subject: RE: END 2-62 (PTD # 1861580) Return to Production All, Wellhead diagnostic work was completed on Endicott producer MPI 2-62 (PTD# 1861580 )on 9-6-15.The production casing packoff seals were treated with GX Sealant and the pack off test void was tested successfully to 3000 psi.There has been no further outer annulus pressurization. Plan Forward—Operations 1) Return well to production 2) Monitor OA for signs of pressurization for 28 days. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 1 • • ttisr,wp t64 a..LU From: Wyatt Rivard Sent: Wednesday, September 02, 2015 6:11 PM To: Alaska NS - Endicott - Operations Leads; Alaska NS - Endicott- Field Foreman Cc: 'Loepp, Victoria T(DOA)'; 'Regg, James B (DOA)'; Taylor Wellman; Mike Dunn; Vanessa Hughes Subject: END 2-62 (PTD # 1861580) Sustained Casing Pressure All, Endicott Producer MPI 2-62's (PTD#1861580)outer annulus exceeded the 1000 psi sustained casing pressure limit on 8/31/15 with T/1/O= 1780/2200/1200.The production casing packoff seals were previously treated with Seal-Tite in July, 2014.The well was shut-in 9/2/15 and will remain shut-in until integrity is restored. Plan Forward—Operations 1) Bleed IA to maintain OA below 1000 psi. 2) Evaluate wellhead for sealant treatment. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 11il..,�I. til:w•h»a_ 1I.0 2 • • PTD /176 -/S Loepp, Victoria T (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Wednesday, September 02, 2015 6:11 PM To: Alaska NS - Endicott - Operations Leads;Alaska NS - Endicott- Field Foreman Cc: Loepp, Victoria T(DOA); Regg, James B (DOA);Taylor Wellman; Mike Dunn; Vanessa Hughes Subject: END 2-62 (PTD# 1861580) Sustained Casing Pressure Attachments: MPI 2-62 TIO.xlsx Follow Up Flag: Follow up Flag Status: Flagged All, Endicott Producer MPI 2-62's(PTD# 1861580 ) outer annulus exceeded the 1000 psi sustained casing pressure limit on 8/31/15 with T/I/O= 1780/2200/1200.The production casing packoff seals were previously treated with Seal-Tite in July, 2014.The well was shut-in 9/2/15 and will remain shut-in until integrity is restored. Plan Forward—Operations 1) Bleed IA to maintain OA below 1000 psi. 2) Evaluate wellhead for sealant treatment. MAR o 9 24\b. Thank You, SCROD Wyatt Rivard `:Veil Integrity Engineer 0: (907) 777-83471C: (509)670-8001 I wrivardPhilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 Hikurp . holm.i,u; 1 C> O I... C> C> 0 NJ CZ> C:Zo 01 1 i ...,,. N..1 C=P 0* 1 .N........st.............4%......L.: IIIIIPP. 1111r141410 I II, C Cr -- = c) --- I0, %AI 5: c) X> 0 .-4 C I Z 0 -10 F.. 0 PL> CL dis 0 PP N., F-1 Ln 0 I O co GI 4. 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Ul O O O O O O O O O O O O O O O O O O O O O O O O O O • • REGE,v6,,, Post Office Box 244027 0 9 Anchorage,AK 99524-4027 HilcarpAlaska,LLC JUL 201ua 3800 Centerpoint Drive Suite 100 CCAnchorage,AK 99503 1d�� Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 Commissioner Cathy Foerster SCANNED AUG 2 3 2016 Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 �� O 4Z6C- Re: Duck Island Unit Well Renaming Request 0' Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "I" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp I • Orig • New API WeliNo PermitNumber WeilName WellNumber I WeIlNumber 50029224180000 1931730 DUCK IS UNIT MPI 2-24/M12 2-24 50029218150000 1880550 DUCK IS UNIT MPI 2-26/N14 2-26 50029218470000 1880860 DUCK IS UNIT MPI 2-28/P19 2-28 50029218470100 2010180 DUCK IS UNIT MPI 2-28A/O19 2-28A 50029218470200 2030060 DUCK IS UNIT MPI 2-286/019 2-28B 50029222280000 1911400 DUCK IS UNIT MPI 2-30/009 2-30 50029222280100 1981880 ;DUCK IS UNIT MPI 2-30A/EI-02 2-30A 50029222280200 2081870 DUCK IS UNIT MPI 2-30B/ME-01 2-30B 50029220840000 1901190 DUCK IS UNIT MPI 2-32/SN3 2-32 50029216620000 1861720 DUCK IS UNIT MPI 2-34/P14 2-34 50029220140000 1900240 DUCK IS UNIT MPI 2-36/014 2-36 50029220900000 1901290 DUCK IS UNIT MPI 2-38/SN1 2-38 50029225270000 1941520 DUCK IS UNIT MPI 2-40/522 2-40 50029218920000 1881450 DUCK IS UNIT MPI 2-42/P13 2-42 50029217670000 1871190 DUCK IS UNIT MPI 2-44/R12 2-44 50029217670100 1970710 DUCK IS UNIT MPI 2-44A/Q11 2-44A 50029219210000 1890230 DUCK IS UNIT MPI 2-46/Q15 2-46 50029219210100 1961810 DUCK IS UNIT MPI 2-46A/R10 2-46A 50029219210200 1971370 DUCK IS UNIT MPI 2-468/513 2-46B 50029226120000 1951660 DUCK IS UNIT MPI 2-48/013 2-48 50029223670000 1930670 DUCK IS UNIT MPI 2-50/U08 2-50 50029217500000 1870920 DUCK IS UNIT MPI 2-52/514 2-52 50029222180000 1911220 DUCK IS UNIT MPI 2-54/Q12 2-54 50029228630000 1980240 DUCK IS UNIT MPI 2-56/EID 2-56 50029228630100 1980580 DUCK IS UNIT MPI 2-56A/EIDO1 2-56A 50029220410000 1900520 DUCK IS UNIT MPI 2-58/S09 2-58 50029223750000 1930830 DUCK IS UNIT MPI 2-60/U13 2-60 50029216480000 1861580 DUCK IS UNIT MPI 2-62/Q17 2-62 50029220550000 1900770 DUCK IS UNIT MPI 2-64/U10 2-64 50029220819500 1901130 DUCK IS UNIT MPI 2-66/U12XX 2-66XX 50029223740000 1930790 DUCK IS UNIT MPI 2-66SD12 2-66 50029218580000 1880970 DUCK IS UNIT MPI 2-68/S17 2-68 50029218990000 1881530 DUCK IS UNIT MPI 2-70/U15 2-70 50029205180000 1801200 DUCK IS UNIT MPI 5-01/SD7 5-01 50029206400000 1811180 DUCK IS UNIT MPI 5-02/SD10 5-02 50029206390000 1811170 DUCK IS UNIT MPI 5-03/SD9 5-03 50029216780000 1861900 DUCK IS UNIT SDI 3-01/N29 3-01 50029223060000 1921210 DUCK IS UNIT SDI 3-03/J33 3-03 50029216240000 1861300 DUCK IS UNIT SDI 3-05/029 3-05 50029219110000 1890120 DUCK IS UNIT SDI 3-07/N28 3-07 50029219110100 1981470 DUCK IS UNIT SDI 3-07A/L29 3-07A 50029217800000 1880020 DUCK IS UNIT SDI 3-09/L28 3-09 50029217800100 1950190 DUCK IS UNIT SDI 3-09A/L28 3-09A 50029218480000 1880870 DUCK IS UNIT SDI 3-11/M30 3-11 50029217510000 1870940 DUCK IS UNIT SDI 3-15/K33 3-15 50029219460000 1890530 DUCK IS UNIT SDI 3-17/J30 3-17 50029219460100 1940460 DUCK IS UNIT SDI 3-17A/J30 3-17A 50029219460200 1971080 DUCK IS UNIT SDI 3-17B/M31 3-178 50029219460300 1980210 DUCK IS UNIT SDI 3-17C/M31 3-17C 150029219460400 1982080 DUCK IS UNIT SDI 3-17D/M31 3-17D 150029219460500 2022470 DUCK IS UNIT SDI 3-17E/K30 3-17E ) ) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. l~b-J5g Well History File Identifier Organization (done) ~ Two-Sided RESCAN DIGITAL DATA Color items: Diskettes, No. o o Grayscale items: o Other, No/Type o Poor Quality Originals: >f Other:PøVud) ~ißJlJj¡fJi' TOTAL PAGES: '3Ç NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL Project Proofing PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL Scanned (done) PAGES: 1.3 ~ (at the time of scanning) SCANNED BY: BEVERLY BREN VINCE~¡SHER~ARIA LOWELL ReScanned (done) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL General Notes or Comments about this file: PAGES: Rescan Needed OVERSIZED (Scannable) o Maps: o Other items scannable by large scanner OVERSIZED (Non-Scannable) o Logs of various kinds X' Other DATE: /S/ o Staff Proof By: Date: DATE: /s/ DATE! oJl ); 2- 1& ~ DATE: 1st Quality Checked (done) Rev1 NOTScanned.wpd UNSCANNED, OVERSIZED MATERIALS AVAILABLE: 1 ~~, ~,~` FILE # To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission # 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 Fax (907) 276-7542 P 'rb 186 (560 Regg,, Jame's B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Sunday, April 21, 2013 9:47 PM To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS END OIM; AK, OPS END Facility & FieldO &M TL; AK, OPS END Board Operator; AK, OPS END AES Drillsite Lead; AK, OPS END Operations Lead Tech; AK, RES END Production Optimization Engineer; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; Igwe, Josiah Cc: Sayers, Jessica; AK, D &C DHD Well Integrity Engineer; Clingingsmith, Mike J; Grey, Leighton (CH2M Hill) Subject: NOT OPERABLE: Producer END2- 62/Q -17 (PTD #1861580) OA broke MOASP Attachments: END2 -62 wellsketch.pdf; END 2 -62 PTD 1861580 TIO Plot 04- 21- 13.docx All, SCANNED JUL 0 8 2013 Producer END 2- 62/Q -17 (PTD #1861580) broke MOASP on 04/20/2013 with TBG /IA /OA pressures of 388/1900/1050 psi. Initial OART attempted indicated a BUR of - 86 psi /hr. At this time the well has been shut in and reclassified as Not Operable. Plan forward: 1. APE to evaluate for Seal -Tite retreatment A TIO plot and well schematic have been included as reference. Regards, Laurie Climer ©sA—SC P M CP = ! aFs; (A1i rnrii :.fuck t.)isi,rmi') BP Alaska — Well Integrity Coordinator ` 3tg5 WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator @BP.com 1 DIU 2- 62/Q -17 PTD #1861580 4/2 1 /2013 TIO Pressures Plot Well: 2-62 4.000 • —II— IA I 7 - . 000A 031412 0515112 071612 09/ "16/12 11/17/12 01/18113 0121/13 , ___________] 1110 TREE= 4 -1/16" CCIW • TES: MS DINGS AV GE 230 - 260 PPM Lip= E N 2 �� SA ON AR. & GAS INJECTORS. WELL REQUIRES ASSSV, ACTUATOR= BAKER C "'CHROM E WFO ER PACK R 10139' - 10229' KB. ELEV= 55.1' � � ' BE ELEV = 15.T KO_P 20" CONDUCTOR H 111' I • i 1589 . — 4-112' OTiS SSSV NP, [) = 3.813' I ✓ Max Angle = 26° Q ; '3 16' - Datum MD= 10260' . tu 0 GAS LFT MANDRELS ()alum TV [) = 10000 SS STI AC) TVD DEV TYFE' VLV LATCH FORT DATE 13 -3/8' CSTG, 72#, L -80 BTRS, 0 12.347" H 2493' 6 4185 4185 0 Ru�M DOME 16 FE 01/f15/13 5 6382 6382 1 AAc M SO 20 RK 01/05113 Ak--3 , (P- &) Ps, 4 7862 7810 18 PAM OMY 0 RK 07/13/87 3 8867 8755 26 At M DMY 0 FE 07/13/87 Minimum ID = 1.74" @ 10139' ' 2 9128 9 26 R&M CMY 0 RK 08/13/03 3 -1/2" WRD ER PACKER 1 9274 9121 24 McM [NY 0 FE 07/13/87 7"• 4 r•-•71 9200' 1- -[ESTNAATEl) TOP OF CEM 'IT ∎•�• • • �.�:� 9381' H4 -1/2" CAMCO SLD SLV, D = 3.750" •�•�• ►••••• ■• 4-1/2" TBG, 12.6#, L -80 BTC, H • 9434' • ' • - •" ►�•�• •• ,r � ♦ 9440 I-- I'J- 5/8" -1 /2' TAN SBR, D = 3.958' , 0152 bpf, D = 3;958 •• • • ►���i • • •• ∎ H " 6' 9-5/8 X 4 -1/2 ' TNV PKR, D = 4.00' 0..•J A ►/ ONrir . � I 5' I — {4 - 1/2" X 3-1/2" XO,00 = 2.982" •.•�•.. 4 •••�• • • � • • •••• • ∎ J485' — 9-5/8' X 7' BKR MODE. A LTP, D = 7 I [T OP OF 7' LNR 9485' •• ► 4• ► •• 4 I • S 9716' - 10194' 3-1/2' CEMENT Si -EATH, MILLED TO 2.60" 9-5/8" CSG, 47 #, NT95HS NSCC, D 8.681' H 9738' .% 1 % VII i ► �. ! 10139' 1 3-1/2" OTiS FORTE) NP w to BLANKNG sly ••• ••••' MILLED TO 2.80' (06/07/09) 3-1/2' WFD ER C7 - ROtwE RCR D = 1.75' — 10139' - 10229' t 4' • I '` ' • 10161' - 10220' 4 -1R" X 3 -1/2" BLAST JOINTS, D = 2.992" (06/30/09) •' 1 . ■. *4 • I 13-1/2' TBG, 9.3#, L -80 TDS, .0087 bpf, ID = 2.992' I 10224' _ 10224' — 17" X 3-1/2" 11W 1- BP FKR D = 2.992" 1 ' T 10230' — 3 -1/2" X 2 -7/8" XO, D= 2.441" I I 10240' 2 -7/8 0115 X NP, D = 2.313" 1 10247' , --I2-7/8 OTIS X NP, D = 2.313" H J--- - 1 1 H 2 -7 /0 VVLEG, D= 2 -7/8" TBG, 6.5#, L -80 2.468' !� .0058 bpi, D' 2.441 10254' 1 10263' 1 — BAD LOGGED ON 12/24104 PERFORATION SIIVMARY , 9 LOG: DUJ GR ON 10/13/86 & JEA/ IE.RY LOG ON 03/26/05 FPS 1 10322' 1--1 T MARKE32 Jowl ANGLE AT TOP PST: 16 ° 10164' Note: Refer to Production DB for historical pert data SIZE I SPF - INTERVAL I OpnISgz I DATE SEE PAGE 2 FOR PERFORATION INFORMATION I 1 20/40 CA'; OUTE (TAGGED 04/01/05) 11A3TD 10816' 1 ,.�,.*IFve � OOi 17' LNR 29#, L -80 BTRS, .0371 bpf, D = 6.184" H 10899' 1.4.1 .4.1 - - DATE REV BY COMENTS DATE REV BY OOMA 31TS EC'DIOOTT 07/15/87 015 OR M COMPLETION 08/15/11 DW /M) ADDED FC2S SAFETY NOTE WELL: 2-62 /0-17 07/17/87 7/ PJC NIA L PERFORATIONS 11/19/12 DAS/JMO GLV C/O (11/12/12) PERMT tb: 1861580 04/07/05 KSBTTLH TT ELMD (12/24/05) 11/19/12 JIL JM) SET EVO TRIEVE PLUG (11/16/12) AR No: 50- 029 - 21648 -00 11/19/08 ' KC F /PJC CART SI-EA1H CORRECTIONS 01/17/13 TJWJA+U GLV C/O & PULLS) PLUG (01/05/13) SEA 36, T12N, R16E, 2112' FNL & 2350' FE. 07/28/09 RDB/PJC - MILL NP@ 10139 (06/07/09) 07/28/09 DTR/PJC SET VVFD PKR (06/30/09) t Exploration (Alaska) • • END2 -62 • 1 • • � • • � ► i•�•�• •►••••∎ iii ` ► iii iii ► i ii i •►•••• * 414 ��� ►•�w��., •■•�w� • •► "S'.' •► ❖ fa ♦. ►•. - •• ■•, Pu • •.I i • •• • i ►••• •� I , 4 * • l..• PBRFORATION %M ARY LOG, DLIJ GR ON 10/13/86 & JEWaRY LOG ON 03/26/05 PPS ANGLE AT TOP PERE: 16° 0 10164 ' Note: Refer to Production CB for historical perf data SIZE SPF INTERVAL Cpn/Sgz DATE 5' 5 10164 - 10184 S 04/01/05 2' 6 10164 - 10187 0 06/24/08 r 6 10192 - 10196 0 06/24/08 2' 6 10204 - 10212 0 06/24'" 5' 5 10204 - 10212 S 04/01/05 5' 5 10218 - 10222 S 04/01/05 2' 6 10218 - 10222 0 06/24/08 5' 5 10302 - 10312 0 07/17/87 5' 5 10336 - 10344 0 07/17/87 5' 5 10352 - 10406 0 07/17/87 DATE REV BY COMMENTS TS DATE REV BY COMMITS B1JICOTT UNIT 07/15187 D15 ORlG COM PLETFON 08/15/11 TAMJM) ADDS) H2S SAFETY NOTE WELL 2- 6210 -17 07/17/87 ?/ PJC NT1AL FE-RFORATI©NS 11/19/12 DAS/JAU,GLV C/O (11/12/12) PERMIT No: 1861580 04/07/05 KSEVTLH TTF3M)(12/24/05) 11/19/12 MACAO SET EVO- TPEVEPLUG(11 /16/12) AR No: 50- 029 - 21648 -00 11/19/08 KC. /PJC CMT SHEATH CORRECTIONS 01/17/13 TJI GLV C/O & RILED RUG (01/05/13) SEC 36, T12N, R16E, 2112' FTC & 2350' Fa. 07/28/09 RDB/PJC MU NP © 10139 (06/07/09) 07/28/09 DTR/PJC SET WED RCA (06/30/09) BP Bcploration (Alaska) • • , L� a t z49 s7 Regg, James B (DOA) 1605b0 From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator @bp.com] "VI "1 Sent: Wednesday, January 16, 2013 7:31 PM I To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS END OIM; AK, OPS END Facility & FieldO &M TL; AK, OPS END Board Operator; AK, OPS END AES Drillsite Lead; AK, OPS END Operations Lead Tech; AK, RES END Production Optimization Engineer; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; Igwe, Josiah Cc: Sayers, Jessica; AK, D &C DHD Well Integrity Engineer; AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Holt, Ryan P Subject: OPERABLE: Producer END2- 62/Q -17 (PTD #1861580) Passing OART Post Seal -Tite Treatment All, Y Producer END 2- 62/Q -17 (PTD #1861580) passed a hot outer annulus repressurization test (OART), During the test, which was ran from 01/08 - 15/2013, the buildup rate was "'10 psi /day. The well is reclassified as Operable. Please call if you have any questions. Thank you, Gerald Murphy BP Alaska - Well Integrity Coordinator APR r �(j� GW GI W ill SCANNED D }rclan obai zalioen WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com From: AK, D &C Well Integrity Coordinator Sent: Sunday, December 23, 2012 5:00 AM To: 'Schwartz, Guy L (DOA)' (quv.schwartz(&alaska.gov); 'jim.regg @alaska.gov'; AK, OPS END OIM; AK, OPS END Facility & FieldO &M TL; AK, OPS END Board Operator; AK, OPS END AES Drillsite Lead; AK, OPS EN ' • perations Lead Tech; AK, RES END Production Optimization Engineer; AK, D &C Wireline Operations Team Lead; AK ' &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; McLeod, Jennifer D Cc: Sayers, Jessica; AK, D &C DHD Well Integrity Engineer; AK, D &C Well Integrity •ordinator; Walker, Greg (D &C); Holt, Ryan P; Climer, Laurie A Subject: UNDER EVALUATION: Producer END2- 62/Q -17 (PTD #1861580) S:.I -Tite Treatment Completed on Inner Casing Hangar All, Producer END2- 62/Q -17 (PTD # 1861580) has had a Seal -Tit- reatment performed on 12/5 - 6/2012 to repair IAxOA communication through the wellhead. The well has passed a cold OART after the treatment. The well is reclassified as Under Evaluation to monitor the well while on produc '•n. Plan forward: 1. Slickline: Pull TTP 2. Operations: Return well to production 1 STATE OF ALASKA RECEIVED . AA OIL AND GAS CONSERVATION COMM�N REPORT OF SUNDRY WELL OPERATIONS JAN 0 3 2013 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U AOGCC Performed: Alter Casing ]] Pull Tubing]] Stimulate - Frac ]] Waiver ]] Time Extension]] Change Approved Program ]] Operat. Shutdown]] Stimulate - Other ]] Re -enter Suspended Well]] 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development Q Exploratory ❑ " 186 -158 -0 3. Address: P.O. Box 196612 Stratigraphic]] Service El 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21648 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0034633 EPA 2- 62/Q -17 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted ENDICOTT, ENDICOTT OIL 11. Present Well Condition Summary: Total Depth measured 10899 feet Plugs measured None feet true vertical 10671.27 feet Junk measured None feet Effective Depth measured 9341 feet Packer measured See Attachment feet true vertical 9182.63 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H -40 39 - 119 39 - 118.99 1490 470 Surface 2450 13 -3/8" 72# L -80 41 - 2491 41 - 2490.96 4930 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 1414 T 29# L -80 9485 - 10899 9315.68 - 10671.27 8160 7020 Perforation depth Measured depth 10164 - 10184 feet 10184 - 10187 feet 10192 - 10196 feet 10204 - 10212 feet 10218 - 10222 feet 10302 - 10303 feet 10303 - 10312 feet 10336 - 10344 feet 10352 - 10406 feet True Vertical depth 9962.47 - 9981.7 feet 9981.7 - 9984.58 feet 9989.39 - 9993.23 feet 10000.92 - 10008.6 feet 10014.38 - 10018.Z feet 10095.21 - 10096.1 feet 10096.17 - 10104.8 feet 10127.97 - 10135.68 feet 10143.39 - 10195.3 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured). SCANNED JAN 1 2013 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: 251 2367 1062 R _. ,� _ ., 2159 471 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development Service ]] Stratigraphic ]] Daily Report of Well Operations X 16. Well Status after work: Oil , 0 Gas ]] WDSPI.]] GSTOR ]] WINJ ]] WAG ]] GINJ ]] SUSP ]] SPLUG]] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: / N/A Contact Garry Catron Email Garry.Catroll(c�BP.Com Printed Name Garry Catron Title PDC PE Signature Phone 564 -4424 Date 1/3/2013 R8 DM S JAN 0 4 2013 /t..3-/3 Form 10 -404 Revised 10/2012 ' ,//', Submit Original Only • • Packers and SSV's Attachment ADL0034633 SW Name Type MD TVD Depscription 2- 62/Q -17 PACKER 9440 9218.82 4 -1/2" TIW HBBP Packer 2- 62/Q -17 PACKER 9485 9260.58 7" Liner Top Packer 2- 62/Q -17 PACKER 10224 9965.05 3 -1/2" TIW HBBP Packer Casing / Tubing Attachment ADL0034633 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H -40 39 - 119 39 - 118.99 1490 470 LINER 1414 7" 29# L -80 9485 - 10899 9315.68 - 10671.3 8160 7020 PRODUCTION 5375 9 -5/8" 47# NT8OS 39 - 5414 39 - 5413.83 6870 4760 PRODUCTION 4324 9 -5/8" 47# NT95HS 5414 - 9738 5413.83 - 9553.98 8150 5080 SURFACE 2450 13 -3/8" 72# L -80 41 - 2491 41 - 2490.96 4930 2670 TUBING 9429 4 -1/2" 12.6# L -80 36 - 9465 36 - 9297.1 8430 7500 TUBING 765 3 -1/2" 9.2# L -80 9465 - 10230 9297.1 - 10025.9 10160 10530 • TUBING 24 2 -7/8" 6.5# L -80 10230 - 10254 10025.92 - 10049 10570 11160 • • • Daily Report of Well Operations ADL0034633 ACTIVITYDATE 1 SUMMARY T /I /O = 0/140/10. Temp = SI. Assist Seal -Tite, IC PO LLRT (IAxOA comm). AL SI @ casing valve. ALP = 2200 psi. IA & OA FLs near surface. Bled IAP & OAP to 0 psi in 15 min and held open bleed during LLRT. Flushed IC void w /diesel until clean returns. IC LLR of 12.5 mL /min @ 1000 psi, 25 mL /min @ 2000 psi, 50 mL /min © 3500 psi. Bled IC to 2000 psi and left heater installed in WH. Tree cap bled to 0 psi. Final WHPs = 0/0/0. 12/2/2012 SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 15:30 hrs. 'TWO = 0/25/10. Temp = SI. Assist Seal- rite, Seal IC PO (IAxOA comm). AL SI @ casing valve. ALP = 2200 psi. IA & OA FLs near surface. Bled IAP & OAP to 0 psi in 15 min and held open bleed during Seal -Tite operation. Pumped 1 liter Gly -Flo & established initial seal on IC PO @ 1000 psi. Increased IC pressure after 30 consecutive min w/o pressure loss in 500 psi increments to 3000 psi. After 1 hr @ 3000 psi pressure dropped to 0 psi and could not maintain pressure to establish LLR. Discuss further actions with WIC. Final WHPs = 0/0/0. 12/3/2012 SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 16:00 hrs. T/I/0 = 0/0 +10 +. Temp = SI. Assist Seal -Tite, Seal IC PO (IAxOA comm)._ AL SI @ casing valve. ALP = 2200 psi. IA & OA FLs near surface. Bled IAP & OAP to 0 psi in 5 min and held open bleed during Seal -Tite operation. Pumped 1 liter flex plug & established initial seal on IC PO @ 1000 psi. Increased IC pressure after 30 consecutive min w/o pressure loss in 500 psi increments to 2000 psi. Left SI for overnight setup. Final WHPs = 0/0/0. 12/4/2012 SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 1330 171 /0 = 0/0 +10 +. Temp = SI. Bleed IA & OA to 0 psi. (Post Seal - Tite). AL SI © casing valve. ALP = 2200 psi. IA &OA FLs near surface. Bled IAP & OAP to 0 psi in 1 min and held open bleed during Seal -Tite operation. Started PT for flex -plug seal using gly -flo, pressured up to 1100 psi no leak detected, increased psi to 1500 no leak detected for 30 min, increased pressure to 2000 psi, lost pressure to 0 psi, seal let go. Rigged up for 2nd flex -plug pill 1L pumped into IC hanger rigged down for overnight pill set up. 12/5/2012 SV, WV = C. SSV, MV = O. IA, OA = OTG. 1400 T /1 /0 = 0/0 +10 +. Temp = SI. Bleed IA & OA to 0 psi. (Post Seal - Tite). AL SI @ casing valve. ALP = 2200 psi. IA &OA FLs near surface. Bled IAP & OAP to 0 psi in 1 min and held open bleed during Seal -Tite operation. Started PT for flex -plug seal using gly -flo, pressured up to 1100 psi no leak detected, increased psi to 1500 no leak detected for 30 min, increased pressure to 2000 psi, lost pressure to 500 psi, seal let go. Pumped 2L gly -flo lost pressure, pumped 1L tur -flo could not get pressure. Rigged up for 3rd flex -plug pill, 1L pumped into IC hanger rigged down for overnight pill set up. 12/6/2012 SV, WV = C. SSV, MV = O. IA, OA = OTG. 1900 I /I /O = 0/0 +10 +. Temp = SI. Bleed IA & OA to 0 psi. (Seal - Tite). AL SI © casing valve. ALP = 2200 psi. Held open bleed on IA & OA for seal -tite operation. 12/7/2012 SV, WV = C. SSV, MV = O. IA, OA = OTG. 1800 • • Daily Report of Well Operations ADL0034633 T /I /O = SSV /0 +/3. Temp = SI. OART (Eval IAxOA comm). AL SI @ casing valve. ALP = 2150 psi. IA, OA FLs near surface. Used ALP to pressure IA from 0+ psi to 1000 psi in 5 min. Monitored 2 hrs. per (WIE). IAP increased to 1100 psi, OAP unchanged, FLs unchanged. Called grease crew to service AL casing valve. Final WHPs SSV /1100/3. 12/8/2012 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 1600 T /I /0 = SSV /1100/3. Temp = SI. OART Day 2 (Eval IAxOA comm). AL SI @ casing valve. ALP = 2150 psi. WHPs unchanged overnight. 12/9/2012 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 1600 ? /1 /0= SSV /1030/5/ Temp= SI. OART (Eval IAxOA comm) day 2. AL SI © casing valve. ALP= 2150 psi. IAP decreased 70 psi & OAP increased 2 psi overnight. 12/10/2012 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 1120 hrs. 171/0= SSV /. Temp = SI. OART day 3. (eval IA x OA communication). ALP @ 2180 psi & SI @ IA casing valve. IAP decreased 60 psi & OAP increased 15 psi overnight. 12/11/2012 SV, WV & SSV = C. MV = O. IA & OA = OTG. NOVP. 0945 1 /I /0 =SSV /890/10. Temp = SI. OART day 5. (eval IA x OA communication). ALP = 2100 psi, SI @ casing valve. IAP decreased 140 psi, OAP increased 5 psi since 12- 11 -12. OART tags pulled. 12/13/2012 SV WV & SSV = C. MV = 0. IA & OA = OTG. 1400 hrs. TWO = SSV/890/18. Temp =SI. OART w/ Max AL Pressure(Post Seal - Tite). AL is connected, SI © casing and inline block valve. ALP =2180 psi. IA FL © 100', OA FL near surface. Increased IAP, using AL, from 890 psi to 2080 psi in 20 min. Bled OAP to 0 psi in 20 min. Held open bleed fo 30 min. Monitor for 30 min. IAP decreased 40 psi. OAP unchanged. Job complete. Final WHPs =SSV /2040/0. 12/17/2012 SV,WV,SSV= Closed. MV =Open. IA,OA =OTG. NOVP. (0300 hrs) T /I /O = SSV /1970/7. Temp = SI. OART (day 1). AL SI @ casing valve, ALP = 2220 psi. IAP decreased 70 psi, OAP increased 7 psi overnight. 12/18/2012 SV, WV, SSV = C. MV = 0. IA, OA = OTG. NOVP. 1000. ?/I/O = SSV/1970/10. Temp = SI. WHPs (OART Day 3). AL SI © casing valve, ALP = 2220 psi. OAP increased 3 psi since 12/18/12. 12/20/2012 SV, WV, SSV = C. MV = 0. IA, OA = OTG. NOVP. 03:00 hrs. AL SI © casing valve. IAP increased 50 psi & OAP increased 3 psi overnight. 12/21/2012 SV, WV, SSV = C. MV = O. IA & OA = OTG. NOVP. 09:15 T /I /0 = SSV/2020/13 Temp = SI. WHP's (OART day 5). ALP = 2040 psi, SI © casing valve. Pressures remain unchanged overnight. OART tags removed. 12/22/2012 SV, WV & SSV = C. MV = 0. IA & OA = OTG. NOVP. 0900 hrs. TREE = 4-1/16" C C E ND 2 -6 2 O I SI A iNJ6CT EAD WELL REQ GE 23 A SSSV. M WEi Lt�AD - FMC ACTU TOR = BAKER C "`"CHROM E WFD ER PACKER @ 10139' - 10229' "`" KB. ELEV = 55.1' I BF. ELEV = 15.7' KOP= 20" COPDl1CTOR 111' I 1589' H4 -12" OTIS SSSV NP, D = 3.813° I Max Angie= 26° @ 8916 Datum AD= 10260' Datum TV D = 10000 SS GAS LFT MANDRELS ST MD TVD DEV TYFE VLV LATCH PORT DATE 6 4185 4185 0 WM DMY 0 RK 11/12/12 I13 -3/8" CSTG, 72#, L -80 BTRS, D = 12.347" H 2493' 5 6382 6382 1 WM DMY 0 RK 09102/12 4 7862 7810 18 PutM DMY 0 RK 07/13/87 3 8867 8755 26 WM DMY 0 RK 07/13/87 Minimum ID = 1.74" @ 10139' 2 9128 8989 26 WM DMY 0 RK 08/13/03 3 -1/2" WRD ER PACKER 1 9274 9121 24 WM DMY 0 RK 07/13/87 141/2" EVO -TRIEV E R_UG (11/16/12) I 9349' SLM ':':;; i• • • • 9200' . 1--I �TMaT ®TOP OF CEMENT ∎ ► ' • � i 4 ■ iii I 91' — 14 -1/2" CAMCO SLD SLVD = 3.750" • 4112" TBG, 12.6 #, L -80 ETC, —{ 9434' • %i� •�• • • ∎ • 1-19-5/8 X 4-1/2" ?IVY SBR, D = 3.958" • 0152 bpf, ID= 3.958" � �., 0 0 • • • • � �- 9455' J—I9 -5/8" X 4 -1/2" T1W PKR; D = 4.00" I •*. 0 i -- • 5' 4- 1/2 "X3- 1/2 "X0,D= 2.992" i 4 • ∎ • • • �0 • TOP OF 7" MR 0486' •••4 • i � i � �� � 9485' H 9-5/8" X 7" BKR MODEL A LTP, D = ? ( 1 o. •••' ''�' 9716' - 10194' — e�I I3 -1/2" CT SHEATH, MILLED TO 2.60" I Di 1 i ► i i i I9 -5/8" CSG, 47 #, NT95HS NSCC, 0 = 8.881' H 9738' •• • • 1 1 • • • • • ; ►�•! 10139'1-13-1/2" OTIS PORTED w /o BLANKING SLV �i�i i..i E) NP MLLE) TO 2.80" 0/07/09) 3- 112" WFD ER CHROI E PKR, D = 1.75" —I 10139' - 10229 . Z., r 4 .y (06/3W09) ice I ' : :�: 10161' - 10220' 4 -1/2" X 3 -12" BLAST JONTS, D = 2.992" I i! 3-1/2`113G. 9.3#, L -80 TDS, .0087 bpf, 0 = 2.992" 10224' 10224' I--17" X 3-1/2" TIW HB-BP PKR, D = 2.992" I ■ 10230' IH3 -1/2" X 2 -7/6° XO, V= 2.441" I ' 10240' H2-7/8 OTIS X NP, 0= 2.313" I I 10247' H2 - 7/8 OTIS X NP, D = 2.313" I I2 - 7/8" TBG, 6.5#, L -80 EUE, .0058 bpf, D = 2.441 IH 10264' I— ( 10264' H2-7/8" VVLEG, D = 2.468" I 10263' H ELK/ LOGGED ON 1224/04 PERFORATION SUMMARY REF LOG: DLL/ GR ON 10/13/86 & J B N B . R Y LOG ON 03/26/05 P P S 10322' H 7" MARKER JONT I ANGLE AT TOP FERF: 16° ft 10164 ' Note: Refer to Production DB for tistorical perf data SIZE I SPF I MFRVAL I Opn/Sgz 1 DATE SEE PAGE 2 FOR PERFORAT1CNJ PFFOfiMATK)N I I I I I 10660' H20/40 CARBOLITE (TAGGED 04/01/05) I PBTD 10816' I r e• • . • • RA 1 LNR, 29#, L-80 BTRS, .0371 bpf, D = 6.184" H 10899' ► 4 4 4 4 ■ DATE REV BY COMMS DATE REV BY COMMENTS EN3IOOTT UNIT 07/15/87 D15 ORIG COMPLETION 02/17/10 NB/JMD ADDED SSSV SAFETY NOTE WELL 2 -62 /0-17 07/17/87 ?/ PJC IN11AL PERFORATIONS 08/15/11 DW/JMD ADDED H2S SAFETY NOTE FERMI No: 1861580 04/07/05 KSB/ILH TT E-ND (12/24/05) 09/05/12 CJWJMD REMOVED SSSV NOTE & GLV C/C API No: 50- 029 - 21648 -00 11/19/08 KCF/PJC CUT SHEATH CORRECTIONS 11/19/12 DAS/JM) GLV C/O (11/12/12) I SEC 36, T12N, R16E, 2112' FR & 2350' FEL 07/28/09 RDB/PJC MLL NP CO 10139 (06/07/09) 11/19/12 JMM!JMD SET EVO -TREVE PLUG (11 /16112) 07/28/09 _ DTR/PJC SET WED PKR (06/30/09) I BP Exploration (Alaska) END2 -62 • • [ -. -. -� ••4 ••• ••1 ••■ • 4•4 I •i ►i • ••. ■•••. • i i i i i i �i i I ► i i i •.• 1 1 •• •• 1■ • . I i • i• i •• •• ■• • •• i�• ► I ,• i• • : . ■ I � • i At. PERFORATION Sl4MMRY REF LOG: DLL/ GR ON 10/13/86 & JEWRY LOG ON 03/26/05 PPS ANGLE AT TOP PEiF: 16° Q. 10164' Note: Refer to PYoduction OB for historical perf data SIZE SFF INTERVAL Opn/Sqz DATE 5" 5 10164 - 10184 S 04/01/05 2" 6 10164 - 10187 0 06/24/08 2" 6 10192 - 10196 0 06/24/08 2" 6 10204 - 10212 0 06/24/08 5" 5 10204 - 10212 S 04/01/05 5" 5 10218 - 10222 S 04/01/05 2" 6 10218 - 10222 0 06/24/08 5" 5 10302 - 10312 0 07/17/87 5" 5 10336 - 10344 0 07/17/87 5" 5 10352 -10406 0 07/17/87 1 •�•�1�1�•�1 DATE REV BY CONSENTS NNTS DATE REV BY COMMENTS Et■DICOTT UNIT 07/15/87 D15 MG CAM PLETION 02/17/10 M3/J/) ADDED SSSV SAFETY NOTE VVELL• 2 -62 /0-17 07/17/87 ?/ PJC INITIAL PERFORATIONS 08115/11 OW/M) ADDED H2S SAFETY NOTE PERMIT No: 1861580 04/07/0.5 KSB/ ILH IT BIMD (12/24/05) 09/05/12 CJNIJM) REMOVED SSSV NOTE& GLV C/C AR No: 50 -029- 21648 -00 11/19/08 KCF/PJC C MT SHEATH CORRECTIONS TIONS 11/19/12 DAS/JM) GLV C/0 (11/12/12) I SEC 36, T12N, R16E, 2112' FNL & 2350' Fa 07/28/09 ROB/PJC MLL NP @ 10139 (06/07/09) 11/19/12 JMMYJM) SET EVO- 78511E PLUG (11/16/12) 07 /28/09 DTR/PJC SET WFD RCR (06/30/09) BP Exploration (Alaska) • Ytr1 2 -6 z- Prb Ic« -f, Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] �01 I zi24.1 Z Sent: Sunday, December 23, 2012 5:00 AM To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS END OIM; AK, OPS END Facility & FieldO &M TL; AK, OPS END Board Operator; AK, OPS END AES Drillsite Lead; AK, OPS END Operations Lead Tech; AK, RES END Production Optimization Engineer; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; McLeod, Jennifer D Cc: Sayers, Jessica; AK, D &C DHD Well Integrity Engineer; AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Holt, Ryan P; Climer, Laurie A Subject: UNDER EVALUATION: Producer END2- 62/Q -17 (PTD #1861580) Seal -Tite Treatment Completed on Inner Casing Hangar All, Producer END2- 62/Q -17 (PTD # 1861580) has had a Seal -Tite treatment performed on 12/5- 6/2012 to repair IAxOA communication through the wellhea,The well has passed a cold OAR the treatment. The well is reclassified as Under Evaluation to monitor the well while on production. Plan forward: 1. Slickline: Pull TTP 2. Operations: Return well to production 3. DHD: OART while on production Please call if you have any questions. SCANNED APR 1 1 2013 Thank you, Gerald Murphy BP Alaska - Well Integrity Coordinator Global Wells Organization WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Monday, December 03, 2012 8:34 PM To: 'Schwartz, Guy (DOA)'; 'Regg, James B (DOA)'; AK, OPS END OIM; AK, OP D Facility & FieldO &M TL; AK, OPS END Board Operator; AK, OPS END AES Drillsite Lead; AK, OPS END Opera s Lead Tech; AK, RES END Production Optimization Engineer; AK, D &C Wireline Operations Team Lead; AK, D:. Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; McLeod, Jennifer D Cc: Sayers, Jessica; AK, D &C DHD Well Integrity Engineer; Cline' gsmith, Mike J Subject: NOT OPERABLE: Producer END2- 62/Q -17 (PTD # ;61580) Sustained Casing Pressure on the OA above MOASP All, 1 • Dr. • � 17 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com], 1 p Z`iI� v Sent: Monday, October 29, 2012 10:33 AM ( I To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS END OIM; AK, OPS END Facility & FieldO &M TL; AK, OPS END Board Operator; AK, OPS END AES Drillsite Lead; AK, OPS END Operations Lead Tech; AK, RES END Production Optimization Engineer; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; McLeod, Jennifer D Cc: Sayers, Jessica; AK, D &C DHD Well Integrity Engineer; AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Clingingsmith, Mike J Subject: UNDER EVALUATION: Producer END2- 62/Q -17 (PTD #1861580) Sustained Casing Pressure on the OA above MOASP Attachments: Producer END2 -62 (PTD #1861580) TIO Plot.docx; Producer END2 -62 (PTD #1861580) welibore schematic.pdf All, Producer END2- 62/Q -17 (PTD #1861580) was found to have sustained OA casing pressure on 10/26/2012. The wellhead pressures were tubing /IA /OA equal to 626/1900/2000 on 10/26/2012. The well is reclassified as Underkaluation. The well has had a Seal -Tite treatment on the inner casing hangar in 2006 that is thought to require1 trey rrtent. Proposed plan forward: 1. Wellhead — Eval inner casing void pressure — Completed 2. Slickline: Set downhole plug and dummy gas lift valves 3. Fullbore: MIT -IA . SCANNED APR 0 9 2013. 4. WIE: Evaluate for Seal -Tite retreatment - A copy of the TIO plot and welibore schematic are included for reference. Please call if you have any questions or concerns. CAA 5CP Thank you, C`� = 2660 F5 Gerald Murphy _ 6360 ,, BP Alaska - Well Integrity Coordinator ? - Z GlAt Global Wens Organ z t3on WIC Office: 907.659.5102 WIC Email: AKDCWellInte Coordinator a BP.com 1 Endicott 2- 62/Q17 PTD #1861580 10/29/2012 TIO Pressures Plot weu 4.000 3.9:74 - 1 Tby yi..tt - r —F O IA •••• —a.— OA ••• ••-• -•••- _•••- •••• OOA on • 99r941 4&1 41318/12 082502 99!41'12 09412 09/15/12 • 09/22/12 09/2912 10/06/12 1013/12 10/29.12 1027/12 1 TREE= 4-1/16" CNV • V 3..LFEAD FMC SAFETY NOTES; MS pNGS AV £GE 230 - 260 PPM E ©� �� ON A/L & GAS INJECTORS. WELL REQUIRES A SSSV. ACTUATOR 4 BAKER C " CHROME WED 132 PACKER 1, 10139' - 10229' "' KS. FIB/ - 55,1' BF. ELEV = 15.7' KC>P 20" CONDUCTOR M i n . ' 1 1589' I— 4-1 /2" OTIS SSSV NP, D = 3.813" Max Angle = 26° QQ 8916 - Cbtum MD = 10260' Dam TV turn = 10000 SS GAS LEFT MANDRILL ` ST NU TVD CEV TYPE VLV LATCH FORT' DATE 13 -3/8' CSTG, 72#, L -80 BTRS, D = 12.347 — 1 2493" 6 4185 4185 0 A1rrM 50 24 RK 09/02/12 5 6382 6382 1 McM CAN 0 RK 09/02/12 1‘.4s4P= 73tOf'S, 4 7862 7810 18 McM MY 0 RK 07/13/87 3 • • 7 8755 26 Mc M CMY 0 RK 07/13/87 Minimum ID = 1.74" @ 10139' 2 9128 ,» 9 26 A,kM CMY 0 RK 08/13/03 3 -1/2" WRD ER PACKER 1 9274 9121 24 Mc M CMY 0 RK 07/13/87 r•'•'4 r4 , IM 9200' --{ESTATED TOP OF CEMINT ••• ... _ • • • " [ 9381' - {4 112' CAMC' 5LD SLV, D = 3.750' i• :••4' 11••1 i 0 • 4 -1/2" TBG, 12.6#, L -80 BTC, — 9434' '.'.'� :•�•�• ■�•�i f i 9440 I-- I9 -5/8" X 41/2" 11W SBR, D= 3.958' 0152 bpf, D = 3.958' •• • / � . �� • 0.. 0 .. -. 9455' 9-5/8" X 4 -1/2' TM/ PKR, D = 4.00" •-•;•;. t;;':.: I 9485' I--.i4 -1/2" X 3-1/2" X0,13= 2.992" •■• • ► ••• •• 9485' 9 -5/8" X 7" BKR MODEL A LTP, D = 7 I TOP OF 7" LNR — 9485' �.�. • 0 . 0 ., !••�•. �■• 9716' - 10194' —13 -1/2" CEME34TSF MILLB) TO 2.60" P . •■ . 9-5/8" CSG, 47 #, NT95HS NSCC, D = 8.681" H 9738' '. - 1 1 j ►•.4 .4 j • • . ∎i•� 10139' — 3-1/2" OTIS FORTED NIP w /o BLANKING SLV i �i KILLED TO 2.80" (06/07/09) 3 WFD ETR CH ROMEFKR l) =1.75' — 1 0139' - 10229' I • ! :V V. I �'4 10151' - 10220' 4 -1/2" X 3 -1/2" BLAST JOINTS, I0 =2.992" (06/30/09) i►�� I i 3-1/2" TBG, 9.3#, L -80 TDS, .0087 bpf, ID = 2.992" H 10224' L 10224 T X 3-1/2 TNV FB-BP FKR D = 2.992" l 10230' 1H3 - 1/2' X 2 -7/8" XO, D = 2.441" I 10240' 2-7/8 OTIS X NP, D = 2.313" I I 10247 ' — I2-7/8 OT1S X NP, ID = 2.313" I2 -7/8" TBG, 6.5#, L -80 WE, .0058 bpf, D = 2.441 I—I 10254' — I 10254' — 2 -7/8' WLEG, 0 = 2.468" 10263' I — E LMD LOGGED ON 12/24/04 PERFORATION SUMMARY ' REF LOG: DLL/ GR ON 10/13/ =. & JEWB-Rl' LOG ON 03/26/05 FPS 1 10322' j_[7" M■RKER JOtNT I ANGLE AT TOP FERE: 16 °Q 10164' I tbte: Refer to R oduction CO for historical perf data I SIZE I SPF I INTERVAL Opn/Sqz I DATE SEE PAGE 2 FOR PERFORATION NFORl1A4TION I I I I 1 — 20/40 CA - .OLITE (TAGGED 04/01/05) . PBTD I—{ 10816* r� ����Tt•� � ■ 7" LNR 29#, L -80 BTRS, .0371 bpf, D = 6.184' — 10899' 1.. ..... [DATE REV BY COPt4E NTS )ATE REV BY - CONAVaITS EN ICOTT UNIT 07/15/87 015 GREG COMPLETION 07/28/09 RCB/ IC MLL NIP@ 10139 (06/07 /09) WELL: 2-62 /0-17 07/17/87 7/ PJC (I'(TlAL PERFORATIONS 07/28/09 DTR/PJC SET WFD PKR (06/30/09) FERMI No: 1861580 04/07/05 KSB/TLH TT ELM) (12/24/05) 02/17/10 MB/JA+D ADDED SSSV SAFETY NOTE AR No: 50- 029-21648 -00 04/01/05 KCF /PJC CEMENT/ CA' : OLITE 08115/11 t7W/JMD ADDS FES SAFETY NOTE SEC 36, T12N, R16E, 2112 FILL & 2350' FEI 11/16/08 PJC CONVERT TO CANVAS 09/05/12 CJWJMD REMOVED SSSV NOTE& GLV GO (09/02/12) 11/19108 KCF/PJC aurr SFEATH CORRECTIONS 1 I BP Exploration (Alaska) w E N D2 -62 ii • ••• ••• ∎ • • '••••. ■••••• ■ !O• ■•• ❖, !••••. ► ❖•• ■ !. ❖. ■ 4 •0.0 1 • • • • • • 1 ►••••∎ •-•-•-., %.•.•.; 0. ••••• ► •∎�•�• • •�•�• ►�•�.�• eo ►. ••• ►Di .• • . ►•• • •• ►••• •., i I ►••• • •,� , . ∎. , • •• •• •.4' • : V, • il 111 CI 1,32 AO PEfFFORATO©N SUMMARY LOG: DLU GR ON 10/13/.+ & JEWELRY LOG ON 03/26/05 PPS I ANGLE AT TOP Fes: 16° © 10164 ' Note: Refer to Production ICE for historical perf data SFZE SFF NIERVAL OPn /Sqz DATE 5 5 10164 - 10184 S 04/01/05 2' 6 10164 - 10187 0 06/24/08 I 7 6 10192 - 10196 0 06/24 2' 6 10204 - 10212 0 0624/08 5' 5 10204 - 10212 S 04/01/05 I 5" 5 10218 - 10222 , S 04/01/05 7 6 10218 - 10222 0 06/24/08 ' ' 5" 5 10302 - 10312 0 07/17/87 5' 5 10336 - 10344 0 07/17/87 5' 5 10352 - 10406 0 07/17/87 1''1'''''' 1 - IIjIj , DATE REV BY C3AM3JTS DATE REV BY COMMENTS EM)ICOTT L.NT 07/15/87 015 ORIG COMPLETION 07/28/09 RDB/PJC MI L !NIP r_, 10139 (06/07 /09) WELL: 2 -62 /0-17 07/17/87 7/ PJC IWT1AL PERFORATIONS 07/28/09 DTR/PJC SET 1AFDIA4R (06/30 /09) PERMIT No: 1861580 04/07/05 KSBTTIJ1 TT ELM) (12/24/05) 02/17/10 M3/110 ACM) SSSV SAFETY NOTE API No: 50- 029-21648 -00 04/01/05 KCF /PJC CEMENT/ CARBOLETE 08/15 /11 [Mf/JM© ADDED H2S SAFETY NOTE SEC 36, T12N, R16E, 2117 FNL & 2350' FE. 11/16/08 PJC CONVERT TO CANVAS 09/05/12 CJWJM) REMOVED SSSV NOTE & GLV C/O (09/02112) _11119/08 KCF/PJC CMT SI-EATH CORRECTIONS I I • +* Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 22, 2012 NNEt) SU 2 1 a14 Mr. Jim Regg Alaska Oil and Gas Conservation Commission ` 1 q 333 West 7 Avenue N1) �.. Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Endicott Row 2 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 2 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing extemal corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my altemate, Gerald Murphy, at 659 -5102. Sincerely, I;_y Mehreen Vazir BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Endicott Row 2 Date: 03/28/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal END2 -02 / P -18 1860630 50029215680000 15.0 3.0 0.5 8/28/2010 1.70 9/29/2010 END2 -04 / M -19 1860820 50029215850000 4.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2 -06 / J -22 1870180 50029216990000 2.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2 -08 / K -16 1880040 50029217710000 1.5 0.1 0.5 9/2/2010 3.40 9/29/2010 END2 -12 / Q -16 1921170 50029223020000 0.5 1.0 0.0 9/2/2010 NA 3/28/2012 END2 -14 / 0.16 1861490 50029216390000 2.5 3.0 0.5 9/2/2010 1.70 9/28/2010 END2 -16 / M -16 1881340 50029218850000 2.0 0.5 0.5 9/2/2010 1.70 9/28/2010 END2 -18 / L -16 1900430 50029220320000 2.0 0.3 0.5 9/2/2010 2.60 9/28/2010 END2 -20 / L -15 1900600 50029220480000 5.0 3.0 0.5 8/28/2010 3.40 9/28/2010 END2 -22 / L -14 1890340 50029219310000 5.0 5.0 0.5 8/28/2010 6.80 9/28/2010 END2 -24 / M -12 1931730 50029224180000 0.5 NA 0.5 NA 1.70 9/28/2010 END2 -26 / N -14 1880550 50029218150000 2.0 1.8 0.5 9/2/2010 1.70 9/28/2010 END2 -28B / 0 -19 2030060 50029218470200 0.5 NA 0.5 NA 1.70 9/28/2010 END2 -30B / ME -01 2081870 50029222280200 3.0 3.0 0.5 8/28/2010 2.60 9/28/2010 END2 -32 / SN-03 1901190 50029220840000 3.0 2.0 0.5 8/28/2010 2.60 9/28/2010 END2 -34 / P -14 1861720 50029216620000 1.0 NA 1.0 NA 12.80 9/25/2010 END2 -36 / 0 -14 1900240 50029220140000 5.0 3.0 0.5 8/28/2010 2.55 9/25/2010 END2 -38 / SN -01 1901290 50029220900000 3.0 4.0 0.5 8/28/2010 1.70 9/25/2010 END2 -40 / S -22 1941520 50029225270000 15.0 13.0 0.5 9/2/2010 4.00 9/25/2010 END2 -42 / P -13 1881450 50029218920000 5.0 4.0 0.5 8/28/2010 2.55 9/25/2010 END2 -44A / 0-11 1970710 50029217670100 0.5 NA 0.5 NA 22.10 10/5/2010 END2 -46B / S -13 1971370 50029219210200 4.0 1.0 0.5 9/2/2010 3.40 9/25/2010 END2 -48 / 0-13 1951660 50029226120000 2.0 2.0 0.5 8/28/2010 1.70 9/25/2010 END2 -50 / U-08 1930670 50029223670000 2.0 1.0 0.5 8/28/2010 1.70 9/25/2010 END2 -52 / S-14 1870920 50029217500000 1.0 0.3 0.5 9/2/2010 0.85 9/25/2010 END2 -54 / Q-12 1911220 50029222180000 4.0 3.0 0.5 8/28/2010 1.70 9/25/2010 END2 -56A / E101 1980580 50029228630100 0.5 NA 0.5 NA 25.50 9/25/2010 END2 -58 / S-09 1900520 50029220410000 7.0 5.0 0.5 8/28/2010 3.40 9/25/2010 7END2 -62 / Q-17 , 1861580 50029216480000 10.0 7.0 0.5 8/28/2010 8.50 9/25/2010 END2 -64 / U -10 1900770 50029220550000 2.0 1.0 0.5 8/28/2010 2.55 9/25/2010 END2 -66 / SD -12 1930790 50029223740000 0.3 NA 0.3 NA 1.70 9/24/2010 END2 -68 / S -17 1880970 50029218580000 2.0 3.0 0.5 8/28/2010 1.70 9/24/2010 END2 -70 / U -15 1881530 50029218990000 0.7 NA 0.7 NA 3.40 9/24/2010 ,:<. , - ~8 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM ION /(/~ REPORT OF SUNDRY WELL OPERATIONS~~~°~~a~~ ~ ~ ~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other ~;:A ,,-; Performed: Alter Casing ~ Pull Tubing Perforate New Pool ~ Waiver Time Extensio ~., ~'`~ .,, ~, rw~,. ,, Change Approved Program ~ Operat Shutdown Perforate ~ Re-enter Suspended Well '~;~ 0 C~t' , . ~ f . 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development '' Exploratory 186-15so - 3. Address: P.O. Box 196612 Stratigraphic ~ Service 6. API Number: Anchorage, AK 99519-6612 50-029-21648-00-00 " 7. KB Elevation (ft): 9. Well Name and Number: 55.1 KB ' 2-62/0-17' 8. Property Designation: 10. Field/Pool(s): ADLO-034633' ENDICOTT Field/ ENDICOTT OIL Pool 11. Present Well Condition Summary: Total Depth measured 10899' feet Plugs (measured) None true vertical 10671.27 - feet Junk (measured) None Effective Depth measured 10660 feet true vertical 10441 feet Casing Length Size MD TVD Burst Collapse Conductor 72 20" 91.5# H-40 39 - 111 39 - 111 1490 470 Surface 2453 13-3/8" 72# L-80 39 - 2492 39 - 2492 4930 2670 Production 9700 9-5/8" 47# N-80 38 - 9738 38 - 9554 6870 4760 Liner 1412 7" 29# L-80 9485 - 10897 9316 - 10669 8160 7020 ~a~NN JUL ~ ~ 2008 Perforation depth: Measured depth: See Attached True Vertical depth: Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 36 - 9465 3-1/2" 9.3# L-80 9465 - 10230 2-7/8" 6.5# L-80 10230 - 10254 Packers and SSSV (type and measured depth) 4-1/2" TIW HBBP-R Packer 9440 7" Liner Top Packer 9485 3-1/2" TIW HBBP Packer 10224 0 0 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: 260 418 8679 438 Subsequent to operation: 1076 24103 659 2420 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~' Development ~ Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil I Gas ~' WAG ~ GINJ ' WINJ j~ WDSPL ~ 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: N/A Contact Gary Preble ,; ~', ~~ ~~j_ ~ c~ ~QO~ Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 7/9/2008 E ~ j ~~ ~ ~ P ~ •. ~ r ~ - . ~~ ~`~ 2-62/Q-17 186-1580 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base I Tvd Depth Top Tvd Depth Base 2-62/Q-17 7/13/87 PER 10,164. 10,184. 9,962.47 9,981.7 2-62/Q-17 7/13/87 PER 10,204. 10,212. 10,000.92 10,008.61 2-62/Q-17 7/13/87 PER 10,218. 10,222. 10,014.38 10,018.22 2-62/Q-17 7/13/87 PER 10,302. 10,312. 10,095.21 10,104.84 2-62/Q-17 7/13/87 PER 10,336. 10,344. 10,127.97 10,135.68 2-62/Q-17 7/13/87 PER 10,352. 10,406. 10,143.39 10,195.38 2-62/Q-17 2/1/88 STC _ 10,164. 10,184. 9,962.47 9,981.7 2-62/Q-17 2/1/88 STC 10,204. 10,212. 10,000.92 _ 10,008.61 2-62/Q-17 2/1/88 STC 10,218. 10,222. 10,014.38 10,018.22 2-62/Q-17 2/16/98 MIS 10,302. 10,303. 10,095.21 10,096.17 2-62/Q-17 5/3/00 MIR 10,302. 10,303. 10,095.21 10,096.17 2-62/Q-17 5/3/00 STO 10,164. 10,184. 9,962.47 9,981.7 2-62/Q-17 5/3/00 STO 10,204. 10,212. 10,000.92 10,008.61 2-62/Q-17 4/1/05 SQZ 10,164. 10,184. 9,962.47 9,981.7 2-62/Q-17 4/1/05 SQZ 10,204. 10,212. 10,000.92 10,008.61 2-62/Q-17 4/1/05 SQZ 10,218. 10,222. ~ 10,014.38 10,018.22 2-62/Q-17 6/24/08 APF 10,164. 10,187. 9,962.47 _ 9,984.58 2-62/Q-17 6/24/08 APF 10,192. 10,196. 9,989.39 9,993.23 2-62/Q-17 6/24/08 APF 10,204. 10,212. 4 10,000.92 10,008.61 2-62/Q-17 6/24/08 APF 10,218. 10,222. 10,014.38 10,018.22 ~ AB ABANDONED _ PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED _ SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMO VED FC_O FILL CLEAN OUT SPS SAND PLUG SET FIL _ FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE _ MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED _MLK___ MECHANICAL LEAK STO STRADDLE PACK, OPEN OH ( OPEN HOLE __ 2-62/Q-17 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE ~ SUMMARY ~ 6/24/2008 '**WELL SHUT IN UPON ARRIVAL. SSSV PULLED, SSV CLOSED'~~ !'INITIAL T/I/0=800/1700/375. 2" PJ OMEGA 2006, HMX, 6 SPF, 60 DEG '':;PERFORATING GUNS RUN TO PERFORATE 4 INTERVALS: 10164'-10187, ;10192'-10196', 10204'-10212', 10218'-10222'. NO PARAFFIN OR HEAVY '::SLUDGE PRESENT ON TOOLS. OIL WAS CLEANED FROM TOOLS UPON RETRIEVAL. "*'`WELL LEFT SHUT IN ON DEPARTURE. SSV CLOSED, GAS LIFT SI, ~"~ FINAL T/I/0=1900/2000/375. *~*JOB COMPLETED"** FLUIDS PUMPED BBLS 1 diesel 1 Total Schlumbergel' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth RECEiVED DEC 2 1 2005 AJaska Oil & Gas Cons. Ccffirr~kn Anchorage Well Job# Log Description Date BL C-04A 10687728 SBHP SURVEY 01/07/05 1 L 1-15A 10715359 PROD PROFILE W/DEFT 11/04/03 1 S-29A 11087187 INJECTION PROFILE 10/04/05 1 09-33 N/A PROD PROFILE W/DEFT 07/16/05 1 D.S 18-03B 11057071 SBHP SURVEY 12/02/05 1 M-10 11072878 LDL 08/05/05 1 D.S 18-25A 11057072 SBHP SURVEY 12/03/05 1 A-31A 11072881 LDL 08/07/05 1 K-06A 11075903 MEM PROD & INJ PROFILE 07/30/05 1 L 1-27 11058255 PROD PROFILE WIDEFT 10/25/05 1 AGI-10 11087429 LDL 09/05/05 1 S-36 11152365 LDL 11/08/05 1 K-20B 11057076 SBHP SURVEY 12/06/05 1 M-18B 11072876 INJECTION PROFILE 08/02/05 1 2-18/L-16 11087185 LDL 10/01/05 1 2-62/Q-17 /B(o-/58 11084325 INJECTION PROFILE 11/21/05 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ,..../,-. [t. io.íh.H'-~O··· \ Î lid 2· - v- f'- ')"t..,;~ð"s'1Þ,...! "lAp;" 5 ZJUB Date Delivered: 12121105 NO. 3630 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne Pt. Color CD Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received bY~n RECEIVED ALASKA Oil AND GAS CONSERVATION COMMISSION MAY 1 0 Z005 REPORT OF SUNDRY WELL OPERATIONSOiI&Gas Cons. Commissi( Anchoraae Stimulate 0 OtherLJ WaiverD Time ExtensionD Re-enter Suspended WellD 1 . Operations Performed: Abandon 0 Alter Casing D Change Approved Program D 2. Operator Name: 3. Address: ) ) STATE OF ALASKA Repair Well 00 Pluç PerforationsD Pull Tubing 0 Perforate New PoolD Operation Shutdown 0 Perforate 0 4. Current Well Class: Development [!] 5. Permit to Drill Number: 186-1580 6. API Numbe 50-029-21648-00-00 BP Exploration (Alaska), Inc. ExploratoryD Total Depth measured 10899 feet true vertical 10671.3 feet Effective Depth measured 10660 feet true vertical 10440.6 feet P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 55.10 8. Property Designation: ADL-034633 11. Present Well Condition Summary: Casing Conductor Liner Production Surface Perforation depth: Length 72 1412 9700 2453 Stratigraphic 0 Service D 9. Well Name and Number: 2-62/0-17 10. Field/Pool(s): Endicott Field 1 Endicott Oil Pool Plugs (measured) None Junk (measured) None Size 20" 91.5# H-40 7" 29# L-80 9-5/8" 47# N-80 13-3/8" 72# L-80 MD TVD Burst Collapse 39 111 39.0 111.0 1490 470 9485 - 10897 9315.7 - 10669.3 8160 7020 38 - 9738 38.0 - 9554.0 6870 4760 39 - 2492 39.0 - 2492.0 4930 2670 Measured depth: 10164 -10184, 10204 -10212,10302 -10303,10303 -10312, 10336 -10344, 10352 -10406 True vertical depth: 9962.47 - 9981.7,10000.92 -10008.61,10095.21 -10096.17,10096.17 -10104.84,10127.97 -10135.68 10143.39 - 10195.38 Tubing ( size, grade, and measured depth): 4-112" 12.6# L-80 3-1/2" 9.3# L-80 2-7/8" 6.5# L-80 @ 36 @ 9465 @ 10230 ~6~~(fÜ'H~E[) MAY 11 ?005 10254 "'- Packers & SSSV (type & measured depth): 7" Liner Top Packer 4-1/2" TIW HBBP-R Packer 3-1/2" TIW HBBP Packer @ 9485 @ 9440 @ 10224 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9200' - 10224' Treatment descriptions including volumes used and final pressure: 50 Bbls Class G Cement @ 900 psig Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 16.1 800 2250 0.08 7798 1000 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations_ RBDMS tn·l MAY 1 ï 2005 Oil-Bbl 586 73 Tubing Pressure 242 361 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ! 15. Well Class after proposed work: Exploratory D 16. Well Status after proposed work: Oil[!] GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: NIA Garry Catron Garry Catron ß~C~ Contact Printed Name Signature Form 10-404 Revised 4/2004 Development ŒJ Service D Title Production Technical Assistant Phone 564-4657 5/9/05 Date OR'Gjl~AL I~ . ) ) 2-62/Q-17 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 03/26/05 CTU # 9. *** CONTINUE FROM 3/25/05 *** RIH WI WFRD 1 - 11/16" MHA & PDS GR/CCL. TAG TO AT 108001 UP AND PERFORM TIE IN LOG TO 9000'. POOH WHILE PUMPING DOWN TUBING AND BLEEDING IA. CHECK DATA, MAKE + 1.0' CORRECTION TO TIE INTO 13-0CT-86 DLL-GR. MU 1.75" BDJSN AND RIH WHILE PUMPING DOWN TUBING W/1% FILTERED KCL AND VENTING GAS TO FACILITY. AT 8000' START BULLHEADING IA AT 6.0 BPM TO FLUID PACK IA AND CONTINUE RIH. BEGAN TO LOOSE INJECTIVITY AT -250 BBLS AWAY. STOPPED BULHEADING IA AT 603 BBLS AWAY AND MONITORED WELL. IA AND TUBING APPEAR TO HAVE VERY LITTLE GAS BASED ON HYDROSTATICS. LAY IN SAND DUMP # 1.10.7 BBLS CARBOLlTE & 30.3 BBLS GEL FOR 41 BBLS SLURRY. HOLD 650 PSI BACK PRESSURE.. . *** CONTINUE ON 03/27/05 WSR *** 03/30/05 CTU # 9 W/1.75" CT. *** CONTINUE FROM 03/29/05 WSR *** RIH WITH WEATHERTFORD 3.70 " OD 5 BLADE CEMENT MILL. ABLE TO RIH TO TO XO WITHOUT PROBLEMS OR MILLING. CORRECT TO DEPTH AND PAINT FLAG AT 9400'. POOH. RIH WITH 2.60" 00 MILL. RIH TO FLAG, CHECK DEPTH CORRELATION AND RIH AND TAG CEMENT TOP AT 9728' ELMD. START MILLING CEMENT AT APPROXIMATELY 30 FPH BY TAKING 30' BITES, PUMPING 5 TO 8 BBL FLO PRO SWEEPS WITH SHORT TRIPS BETWEEN EACH BITE, MILL TO 9960' AT MIDNIGHT. ***CONTINUED ON WSR 31-MAR-05 *** 03/31/05 CTU #9 W/1.75" CT. ***CONTINUED FROM 03-30-05*** MILL, FCO, MILLING CEMENT W/2.600" JUNK, MILL FROM 9960' TO 10206' ELMO AND ENCOUNTER HARD SPOT. WORK MILL AND SET DOWN 4500# WOB AND BROKE THROUGH. CONTINUE TURNING THROUGH SAND AND TAG 2-7/8" XO AT 10241' ELMO (10229' DRILLERS DEPTH). PUMP FINAL 17 BBL FLO PRO SWEEP AND CHASE OOH AT 80%. LEAVE 60/40 CAP ON TUBING. LAY DOWN TOOLS, INSPECT AND CALIPER MILL - 2.582" OD. MIT-IA TO 3000 PSI - PASSED. MU 1.75" JSN, RIH TO BEGIN FCO. *** CONTINUED ON WSR 01-APR-05 *** 04/01/05 CTU #9 W/1.75" CT. ***CONTINUED FROM 03-31-05*** FCO, CLEAN OUT SAND, CARBOLlTE WI 1.75" JSN FROM 10230' TO 10660' ELMO LEAVING 2541 OF RAT HOLE. FCO COMPLETED WITH 1.5# BIOZAN, AND A FINAL 32 BBL FLO-PRO SWEEP OFF BOTTOM. WHILE RIH TAGGED 4.5" X 3.5" XO AT 9480'. RETURNS WERE CONSISTANTLY 1:1 DURING FCO, SOME GAS IN RETURNS TOWARDS END OF CLEAN OUT. PLUGGED CHOKE OFF NUMEROUS TIMES. TRAPPED 350 PSI ON WELL, FREEZE PROTECTED TUBING WITH 60/40 FROM 2500'. JOB COMPLETE, FLUIDS PUMPED BBLS 419 60/40 Methonal 1 Water 1482 1 % KCL 139 Fresh Water 50 Class G 15.8 ppg Cement 22 8 ppa Carbolite Slurry 11 8 ppa Carbolite Slurry w/2565# 36 Gel 3673 1 % Slk KCL 235 1 .5# Biozan Page 1 192 Flo Pro 6259 TOTAL ) 2-62/Q-17 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS Page 2 ) RT ELEV. = 56.1' BFELEV =15.7' MAX. DEV. = 26:10 8900' MD TREE: 4 -1/16' 15000 PSI 1 CIW DEPTH WELLHEAD: 11" 1 5000 PSI 1 FMC MDBRT NOTE: COMPLETION EQUIPMENT DEPTHS ARE DRILLER'S DEPTHS. PERFORATING DEPTHS ARE WIRELlNE MEASUREMENTS. e L ~: ~ ] i/.."t!' .~~~ ~ .J", ~ I 10816' HPBID I ] ~ END2-62 1589' H 4-1/2" SSSV, 10 = 3.813" (w /SSSV IN = 2") H4-1/2", 12.6#, L-80 BTRS TBG, 10 = ,0152" GAS LIFT MANDRELS (CAMCO-KBMG) ST MO TVO VLV LATCH PORT DATE 6 4185 4130 DOME RK 16 04/05/05 5 6382 6327 SO RK 20 04/05/05 4 7862 7756 OMY RK 0 3 8866 8699 OMY RK 0 2 9128 8934 OMY RK 0 1 9274 9066 OMY RK 0 9200' H CEMTENT TOP IN IA ESTIMA TL 9381' H4-1/2" CAMCO SLIDING SLEEVE, 10 = 3.750 9440' H9-5/8" TIW HB-BPR W/TBG SEAL ASSY 9465' H3-1/2", 9,2#, L-80, IDS TBG,.0087, 10 = 2.992" 9485" HTOP7" LNR 9176" H3-1/2" TOP OF CEMENT SHEATH 9738" H9-5/8 CSG SHOE, 47#, N-80,.0732, 10 = 8.681 10136' OTIS PORTED NIPPLE, 10 = 2.666 WfTH BLANIKNG SLEEVE/2.350" W/O BLANKING SLEEVE 10151' H4,5" BLASTS JOINT 1 0194' H BOTTOM OF CEMENT SHEA TH 10219' H4.5" BLASTS JOINT 1 0224' H 7" TIW HB-BP PKR WfTH TBG ANCHOR 10230" H2-7/8" TUBING ??? H 10'-2-7/8" PUP JOINT 10240' H2-7/8" X NIPPLE, 10= 2.313 ??? H 5'-2-7/8" PUP JOINT 10247' H2-7/8" X NIPPLE, 10= 2.313 ??? H5'-2-7/8" PUP JOINT 10254' H WIRE LINE ENTRY GUIDE 10263' HTT ELMO (12/24/04) PERFORA TION SUMMARY REF LOG: ANGLE AT TOP ÆRF: Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE 10164 - 10184 10204 - 10212 10218 - 10222 10302 - 10312 10336 - 10344 10352 - 10406 10660' HTOPOF 20/40 CARBOLITE ???? H7"·29#.,0371,10=6,184 1 0801' H BOTTOM OF 20/40 CARBOLfTE SCHLUMBERGER DPC - 5' @ 5 SPF REF: DLL-GR (10/13/86) OA TE REV BY COMMENTS OA TE REV BY 09/09/88 JLH ?????? 04/07/05 KSB/TU- TT ELMO (12/24/05) 12/24/04 KSB/PJC TT ELMO 04/01/05 KCF/PJC CEMENT/CARBOLfTE COMMENTS I I I " I I I I I I I I ENDICOTT UNfT WELL: 2-621 Q-17 ÆRMfT No: ?? API No: 50-029-21648 SEC T N R E BP Exploration (AlasKa) Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well /1'~l 0.5. 07 -03A JOJ -f t.{:f K-1 OB ''1f;-CJ!7 0.5. 02-15A i'17~12:3- 0.5. 18-13A '7 ~.l'/I-G-12B ~_ þ2 ( -D.S. 05-26A ,7 v:,3- \\. Lf-15-04A ['15"-ð3ð 18-02A ~/_09ð.,¿18-04B I'7.5-()1!f L 1-01 e?'3-l'j1-L5-17 I'.', ,..?IH-18 ..'ð - --lD 2-62/Q-17 ¡8L-I?/1. L5-15 ~~L5-15 ,~q; L5-15 \ L5-15 ¡r¡O-t.¡g- E-17 '(6- ¡-y.t- G-15A Job # 10715406 10715402 10715404 10715395 10715391 10715420 10715374 10621764 10708056 10913000 10900124 10703975 10900129 10708050 10563129 10672368 10913848 10703983 10679055 MCNL MCNL MCNL MCNL MCNL MCNL MCNL RST RST USIT USIT RST RST RST RST RST RST RST RST SCANNED JUN <1 6 2005 Log Description Date 06/03/04 05/16/04 05/18/04 04/16/04 03/21/04 08/19/04 01/14/04 02/23/04 03/05/04 12/25/04 11/30/04 02/17/04 12/24/04 02/07/04 11/15/03 04/16/04 09/26/04 04/09/04 02/02/04 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ·~~t5 Blueline /9r;, - /5<g 02/28/05 NO. 3354 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Prints .--- CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 / -- 1 Ý 1 1 1 1 1 1 1 1 1 1 1 1 1 1 / Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 AnCh~rage. AK 992;03-238 , itL ATTN. B~ /J 1 Receive~lJ~Q.v-· ·'Z!A4,r,.a.....-r Ó Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 08/27103 NO. 2952 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD D.S. $-28A ~.(~)\ -- ~ ~ iLDL 08/17/03 L1-15 ~,-~5;~_c~ -' ~ ~'-~ ~ :RST-GRAVEL PACK 08120103 GNI-03 i(~ ':~ -_ ~ ~-~__c.~ ISHUT-IN TEMP SURVEY 08/18/03 1 NK-62 ~.~ -(~-~, PROD PROFILE/DEFT 05/30/03 1 4-081P-27~-~ '~ -~;~3<:~ INJECTION PROFILE 08/20/03 1 2-62/Q-17 ~;~[O'~ ~c:~ LDL 08/17/03 1 2-32/SN-03 I~ (~ --~ ~ C~ LDL 08/18/03 1 D-13A ~).(~(~ ~'~'~ -i 23402 MCNL 06123103 1-$7/R-23 !_~ "!! )~ ' 23281 RST-SlGMA 05107/03 I I~_,_ )~.~ fi! PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. aenson Blvd. Anchorage, Alaska 99508 Date Delivered: · , Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth STATE OF ALASK, A ALASK~A OIL AND GAS CONSERVATION coMMIsSION REPORT ( :SUNDRY WELL OPt IATIONS 1. Operations performed: Operation shutdown m Stimulate__ Plugging__ Pull tubing m Alter casing __ Repair well __ Perforate__ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora_~le, Alaska 99519-6612 4. Location of well at surface 2112' SNL, 2350' WEL, Sec. 36, T12N, R16E At top of productive interval 2852' SNL, 3270' WEL, Sec. 36, T12N, R16E At effective depth 2860' SNL, 3423' WEL, Sec. 36, T12N, R16E At total depth 2865' SNL, 3444' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development .. Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) KBE = 55.10 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-62/Q- 17 MPI 9. Permit number/approval number 86-158/Not Rec~uired 10. APl number 50- 029-21648 11. Field/Pool Endicott Off Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 10899 feet Plugs (measured) 10671 BKB feet 10227' 10816 feet 10591 BKB feet Junk (measured) ORIGINAL Size Cemented MeasUred depth True vertical depth BKB BKB 71' 30" Driven 111' 111' 2453' 13 3/8" 3720 c.f. Permafrost 2493' 2493' 9698' 9 5/8" 575 c.f. Class G 9738' 9554' 1412' 7" 465c. f. Class G 9485'- 10897' 9316'- 10668' measured 10164'- 10184', 10204'- 10212', 10218'- 10222', (all shut in), 10302'- 10312', 10336'- 10344', 10352'- 10406' true vertical (Subsea) 9908' - 9927', 9946' - 9954', 9959' - 9963', (afl shut in), 10040' - 10050', 10073' - 10081', 10089'- 10141' Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing to 9440', 3 1/2" 9.2# L-80 tubing with 2 7/8" tailpipe to 10254' Packers and SSSV (type and measured depth) 9 5/8" HB-BPR Packer at 9440', 7" HB-BP Packer at 10224', SSSV at 1589' 13. Stimulation or cement squeeze summary PuflXXplug, pufl ported sleeve. Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure 718 20892 252 0 659 24055 404 0 Tubing Pressure 3310 3283 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas__ Suspended.__ Service Date 5/30/00 SUBMIT IN DUPLICATE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S,gned ~¢-CL(-~,._c.C-~'~ ~-~ 1~t~c~,.,(\L_(o,.~'b_~! Title ~_ninr Te~hnin~l ~s.~i.et~nt IV Form 10-404 Rev 06/1 BPX Endicott Production Engineering Department Static Survey & Plug Pull DATE: 05~03~00 WELL N-°: 2-62 / Q-17 BP EXPLORATION REP: SERVICE COMPANY: MARK SAUVE HES / NYQUIST SIWHP (PSIG) lAP (PSIG) I OAP (PSIG) 3,700# 400# I 100# TIME/DATE OF SHUT-IN DATE/TIME OPERATIONS SUMMARY 1000 SAFETY MEETING,RIG UP 1141 RIH WI4 ~/~" GS & PRONG TO SVLN @ 1,556' WLM,OOH W/BBE # NBB-23 1240 RIH W/2.25 CENTRALIZER,BUMPER SUB & DUEL SPARTEK GAUGES,TAG TOP OF PLUG @ 10,230' WLM = 10' CORRECTION, IsT STOP @ 10,042',2"D STOP @ 10,146',3RD STOP @ 10,198',4TM STOP @ 10,146',POOH 1610 OOH W/GAUGES 1636 RIH W/SHEARD GS & EQULIZlNG PRONG TO "XX" PLLUG @ 10,230',TAP DOWN,OOH,MARKS ON PRONG INDICATE EQ VALVE OFF SEAT 1750 RIH WI 3 ~/2" GS TO PORTED NIPPLE @ 10,120' WLM,OOH WI PORTED SLEEVE 1845 LDFN,ALLOW PLUG TO EQULIZE OVER NITE 05/04/00 SITP:3,800# lAP:400# OAP:100# 0745 SAFETY MEETING,RIG UP 0830 RH W/2 Y2" GS TO "XX" PLUG @ 10,230' WLM,LATCH PLUG,STILL HAD SOME CROSS-FLO,ABLE TO PULL PLUG 1000 RIH W! 3 ~,~" GS & PORTED SLEEVE TO 10,120'SET 1205 RIH W/1.90 CENTRALIZER,T.E.L. & 1.77 SAMPLE BAILER,UNABLE TO PASS PORTED NIPPLE,POOH,DROP SAMPLE BAILER 1300 RIH W/T.E.L. & 1.90 CENTRALIZER,TAG TBG TAIL @ 10,250' WLM = 4' CORRECTION,TAG HARD BOTTOM @ 10,794' CORRECTED 1435 BEGIN PURGEING BALANCE & CONTROL LINES 1515 PUT HEAT ON SWAB VALVE 1655 RIH WI4 ~" BBE # NBB-34 TO SVLN @ 1,556' WLM, SET, BLEED LOTS OF GAS FROM LINES, RE PURGE, CLOSURE TEST BBE 3,700# > 3,400#, GOOD TEST, ROTATE BALL 3 TIMES 1755 RIG DOWN,SPOT EQUIP ON 2-56 SPARTEK DEPTH I DEPTH DEPTH BHSIP BHSIT Delta P TIME TVDSS MDBKB WLM PSIA deg F PSI/HR 15 MIN 9800 10052 10042 5132.87 207.97 0 15 MIN 9900 10156 10146 5144.56 208.18 0 15 MIN 9950 10208 10198 5151.12 208.43 0 30 MIN 9900 10156 I 10146 5145.04 208.37 0 SUMMARY: PULLED BBE # NBB-23 PERFORMED STATIC BHP SURVEY ON STRADDLE ZONE W/SPARTEK GAUGES EQULIZE PLUG,PULLED PORTED SLLEEVE,PULLED PLUG TAG TD / CORRECTED DEPTH OF 10,794' SET & TESTED 4 Y2" BBE # NBB-34 NOTIFIED PAD OP. & PCC OF WELL STATUS, LEFT WELL SHUT IN SSSV: IN (BBE#NBB-34) STATE OF ALASKA ALASi"-'- qlL AND GAS CONSERVATION COMMIS?' REPORT C," SUNDRY WELL OPL ATIONS Operations performed: Operation shutdown__ Stimulate X Plugging Pull tubing__ Alter casing __ Repair well __ Perforate__ Other__ 2. Name of Operator 5. Type of Well: 6, Datum elevation (DF or KB) BP Exl~loration (Alaska) Inc. Development X KBE = 55.10 feet Exploratory __ 3. Address Stratigraphic .__ 7. Unit or Property name P. 0. Box 196612, Anchora.cle, Alaska 99519-6612 Service__ Duck Island Unit/Endicott 4. Location of well at surface 8. Well number 2112' SNL, 2350' WEL, Sec. 36, T12N, R16E At top of productive interval 2852' SNL, 3270' WEL, Sec. 36, T12N, R16E At effective depth 2860' SNL, 3423' WEL, Sec. 36, T12N, R16E At total depth 2865' SNL, 3444' WEL, Sec. 36, T12N, R16E 2-62/Q- 17 MPI 9. Permit number/approval number 86-158/Not Reauired 10. APl number 50- 029-21648 11. Field/Pool Endicott Off Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 10899 feet Plugs (measured) true vertical 10671 BKB feet 10227' measured 10816 feet Junk (measured) true vertical 10591 BKB feet Length Size Cemented 2 7/8" XX Plug w/Sand Ext. set 2/16/98 Measured depth True vertical depth BKB BKB 71' 30" Driven 111' 111' 2453' 13 3/8" 3720 c.f. Permafrost 2493' 2493' 9698' 9 5/8" 575 c.f. Class G 9738' 9554' 1412' 7" 465 c.f. Class G 9485'- 10897' 9316'- 10668' measured 10164'- 10184', 10204'- 10212', 10218'- 10222', (all shutin), 10302'- 10312', 10336'- 10344', 10352'- 10406' true vertical (Subsea) 9908' - 9927', 9946' - 9954', 9959' - 9963', (all shut in), 10040' - 10050', 10073' - 10081', 10089'- 10141' Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing to 9440', 3 1/2" 9.2# L-80 tubing with 2 7/8" tailpipe to 10254' packers and SSSV (type and measured depth) 9 5/8" HB-BPR Packer at 9440', 7" HB-BP Packer at 10224', SSSV at 1589' 13. Stimulation or cement squeeze summary Pull blanking sleeve, set 2 7/8" XX plug w/sand extension,' Set ported sleeve. ...... i .,iAL Intervals treated (measured) '~ i ~-'-~ i~ ~:~?i ~J , . Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 553 3843 9523 0 605 1417 12263 186 0 3156 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas__ Suspended Service 17. I hereby certify that t.~foregoin~ is true and correct to the best of my knowledge. Signed~~,/~/;./L-~~ ~ Title~eninrTechnic~/4.~.~i.~t~ntlV Form 10-40~"'-I~v-0(~/~'~/88 - - Date 3/10/98 SUBMIT IN DUPLICATE~ BPX Endicott Production Engineering Department OPERATIONS REPORT DATE: 2-16-98 WELL N°: 2-62 / Q-17 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: SET PLUG ECKSTEIN HES / LAWSON DATE/TIME OPERATIONS SUMMARY 1100 1430 1530 1630 MIRU. RIH wi 2 7/8" X-LINE, PRONG, 2 7~8" XX PLUG w/SAND EXT. IN CONT. POSITION. PLUG SET @ 10227' WLM. POOH. RIH wi 3 ¥2 GS, 3 ¥2 PORTED SLEEVE. SLEEVE SET (~ 10130' WLM. POOH. RIH w/4 1/2 X-LINE, PRONG, 4 1/2 BBE (NBB-23). SSSV SET (~ 1569' WLM. POOH. GOOD CLOSURE TEST. RD. SIP: 1900 IA: 0OA: 0 SUMMARY: SET 2 7/8 XX PLUG. SET PORTED SLEEVE. SET 4 1/2 BBE. GOOD CLOSURE TEST. RD. SSSV: IN BPX Endicott Production Engineering Department DATE: 2/15~98 WELL N°: 2-62/Q-17 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: OPERATIONS REPORT PULL BLNK SLV-ATTEMPT PLUG SET J. ECKSTEIN HES/TILBURY DATE/TIME OPERATIONS SUMMARY 1500 1600 1730 22OO 0200 0500 MIRU. RIH wl31/2 GS TO PORTED NIPPLE (~ 10120' WLM. PULL 3¥2 BLANKING SLV. POOH. RIH wi2 7/8 XX PLUG w/SAND EXT, (TOTAL LENGTH=33"). RAN THROUGH LOWER XLN @ 10230' WLM. UNABLE TO COME BACK UP DUE TO UPPER ZONE FLOWING DOWN HOLE. OPEN CHOKE & FLOW TOOLS OOH. FROZEOFF IN TREE. APPLY HEAT & MEOH. 2116~98 RIG UP HB&R TO PUMP ?? BBLS HOT DIESEL. OOH w/PLUG. 0600 RDMO. S1=1750 IA=0 OA=0 SUMMARY: UNABLE TO SSSV: PULLED BLANKING SLEEVE FROM PORTED NIPPLE. RAN 2 718 XX PLUG. TO COME UP THROUGH XLN DUE TO DOWN FLOW FROM UPPER ZONE. FLOW WELL TO ALLOW PLUG TO COME UP HOLE. FROZEN UP IN TREE. CALL HB&R PUMP 55 BBLS. OF HOT DIESEL. RECOVERED PLUG. OUT RECEIVED 17 1994 AJasJ{a Oil & Gas Cons. Commission Anchorage ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. RE: ANCHORAGE AK, 99501. USA Date: 3 May 1994 Transmittal of Data Sent by: U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 2-62/Q-17 (MPI) 3-1t/M-30 SDI 1 PLS FINAL BL //% PLS FINAL RF SEPIA Run # 1 Run # 1 1PLS FINAL BL · PLS FINAL RF SEPIA Run # 1 Run # 1 /~1SPINR/TEMP FINAL BL SPINR/TEMP RF SEPIA Run ~ 1 Run ~ 1 1 PLS FINAL BL 1 PLS FINAL RF SEPIA Run # 1 Run # 1 1 PLS/SPNR FINAL BL 1 PLS/SPNR RF SEPIA Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Run # 1 Run # 1 ECC No. 4297.04 6191.00 5723.03 6175.01 5764.03 Received by: Date: Please sign and return to: Sonya Wallace (MB 3-3) Petrotechnical Data Center BP Exploration (Alaska) Inc. 900 East Benson Boulevard Anchorage, Alaska 99508 Received by: Date: STATE OF ALASKA AI~oKA OIL AND GAS CONSERVATION COMMIS,.. ~N REPORT OF SUNDRY WELL OPERATION 1. Operations performed: Operation shutdown Pull tubing Stimulate . Plugging Alter casing Repair well Perforate (~~,~ ~ Other X 6. Datum elevation (DF or KBE = 55.14 feet 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2112' SNI_, 2350' WEL, Sec. 36, T12N, R16E At top of productive interval 5. Type of Well: Development X Exploratory Stratigraphic Sen/ice 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-62/Q- 17 MPI 9. Permit number/approval number 86-158/Not Required 10o APl number 50- 029-21648 2852' SNL, 3270' WEL, Sec. 36, T12N, R16E At effective depth 2860' SNL, 3423' WEL, Sec. 36, T12N, R16E At total depth 2865' SNL, 3444' WEL, Sec. 36, T12N, R16E 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical 10899 feet 10671 BKB feet Plugs (measured) Blanking sleeve set at 10117' WLM Effective depth: measured true vertical 10816 feet 10591 BKB feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vejti.c..~l depth BKB 71' 30" Driven 111' 111' 2453' 13 3/8" 3720 c.f. Permafrost 2493' 2493' 9698' 9 5/8" 575 c.f. Class G 9738' 9554' 1412' 7" 465c. f. C/ass G 9485'- 10897' 9316'- 10668' measured 10164'- 10184', 10204'- 10212', 10218'- 10222', (all shut in), 10302'- 10312', 10336'- 10344', 10352' - 10406' true vertical (Subsea) 9908' - 9927', 9946' - 9954', 9959' - 9963', (all shut in), 10040' - 10050', 10073' - 10081; 10089'- 10141' Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing to 9440', 3 1/2" 9.2# L-80 tubing with 2 7/8" tailpipe to 10254' Packers and SSSV (type and measured depth) 9 5/8" HB-BPR Packer at 9440', 7" HB-BP Packer at 10224', SSSV at 1589' 13. Stimulation or cement squeeze summary Scale Inhibitor Treatment Intervals treated (measured) 10302'- 10312', 10336'- 10344', 10352'- 10406' Treatment description including volumes used and final pressure SBbls seawater spacer, 60 Bbls diesel/mutual solvent mix, 40 Bbls scale inhibitor/seawater overflush, 160 Bbls seawater/2% surfactant, 204 Bbls. seawater and $ Bbls methanol. FSlWHP=2000 PSlG 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1533 / 7739 2521 0 1943 2121 ~/ 9789 3230 0 1850 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing isle the best of my knowledge. Signed ~'~ C:~', Title Senior Technical Assistant II SUBMIT IN DUPLI(~ATE ~ Form 10~ Rev 06/15/88 STATE OF ALASKA 0 ~- ALA,-,.~A OIL AND GAS CONSERVATION COMMISS.,.-.,I REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing ~ Alter casing Repair well Perforate~ Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2112' SNL, 2350' WEL, Sec. 36, T12N, R16E At top of productive interval 2552' SNL, 3270' WEL, Sec. 36, T12N, R16E At effective depth 2860' SNL, 3423' WEL, Sec. 36, T12N, R16E At total depth 2865' SNL, 3444' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 55.10 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-62/Q- 17 MPI 9. Permit number/approval number 86-158/92-044 10. APl number 50- 029-21648 11. Field/Pool Endicott Off Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 10899feet 10671 BKBfeet 10816feet 10591 BKBfeet Plugs (measured) Junk (measured) Length Size Cemented 71' 30" Driven 2453' 13 3/8" 3720 c.f. Permafrost 9698' 9 5/8" 575 c.f. Class G Blanking sleeve set at 10117' Measured depth _ 111' 111' 2493' 2492' 9738' 9554' 1412' 7" 465~£ C~ss G 9485'-10897' 9316'-10668' 10164'- 10184; 10204'- 10212; 10218'- 10222; ¢flshutM), 10302'- 10312; 10336'- 10344; 10352'-10406' true vertical (Subse¢ 9908'-9927; 9946'-9954; 9959'-9963~ ¢flshutin), 10040'-10050; 10073'- 10081; 10089'-10141' Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing to 9440', 3 1/2" 9.2# L-80 tubing with 2 7/8" tailpipe to 10254' Packers and SSSV (type and measured depth) 9 5/8" HB-BPR Packer at 9440', 7" HB-BP Packer at 10224', SSSV at 1589' 13. Stimulation or cement squeeze summary Scale Inhibitor Treatment Intervals treated (measured) 10302'- 10312', 10336'- 10344', 10352'- 10406' Treatment description including volumes used and final pressure 5Bbls seawater pad, 47 Bbls diesel/mutual solvent mix, 88 Bbls scale inhibitor/seawater overflush. FSIWHP=6OOPSIG 14. Prior to well operation Subsequent to operation Representative Daily Average Produ~ion orlnjection Data OiI-Bbl Gas-Mcf W~er-Bbl Casing Pressure Tubing Pressure 1426 4608 357 0 2492 1383 5244 486 0 2509 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned.~(~'¢¢'~&--' ,~'. ~' Title Seniot Technical Assistant II Form 10-44~ Rev 08/15/88 Date ,/¢///~-' SUBMIT IN DI~P(_.ICATE STATE OF ALASKA~_ ~ ALA,.,,-,A OIL AND GAS CONSERVATION COMMISS~uN APPLICATION FOR SUNDRY APPROVALS' 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate X Change approved program __ Pull tubing __ Variance__ Perforate __ Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2112' SNL, 2350' WEL, Sec. 36, T12N, R16E At top of productive interval 2852' SNL, 3270' WEL, Sec. 36, T12N, R16E At effective depth 2860' SNL, 3423' WEL, Sec. 36, T12N, R 16E At total depth 2865' SNL, 3444' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development Exploratory Stratigraphic Service RECEIVED MAR 1 1 t992 Alaska .0il & Gas Cons. C0mmissl0~ ~chorage 12. Present well condition summary Total depth: measured true vertical 10899 feet 10671 BKB feet Plugs (measured) 6. Datum elevation (DF or KB) KBE = 55.10 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-62/Q- 17 MPI 9. Permit number 86-158 10. APl number 50- 029-21648 11. Field/Pool Endicott Oil Pool feet Effective depth: measured 10816 feet true vertical 10591BKB feet Junk (measured) Casing Length Size Cemented Measured de~ TrueBv/~ical depth Structural Conductor 71' 30" Driven 111' 111' Surface 2453' 13 3/8" 3720 c.f. Permafrost 2493' 2493' Intermediate 9698' 9 5/8" 575 c.f. Class G 9738' 9554' Production Liner 1412' 7" 465c. f. Class G 9485'- 10897' 9316'- 10668' Perforation depth: measured 10164'- 10184', 10218'- 10222', 10336'- 10344', 10204'- 10212', 10302'- 10312', 10352'- 10406' true vertical (Subsea) 9908'- 9927', 9959'- 9963', 10073'- 10081', 9946'- 9954', 10040'- 10050', 10089'- 10141' Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing to 9440', 3 1/2" 9.2# L-80 tubing with 2 7/8" tailpipe to 10254' Packers and SSSV (type and measured depth) 9 5/8" HB-BPR Packer at 9440', 7" HB-BP Packer at 10224', SSSV at 1589' 13. Attachments Description summary of proposal__ Detailed operations program X BOP sketch__ 14. Estimated date for commencing operation March/April, 1992 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S~gned ~_~-~_~/~/~-~ ~~.~ . ~,~ ~ Title Senior TechnicaiAssistant II FOR COMMISSION USE ONLY Cond~ ~ri~ns of approval: Notify Commission so representative may witness Plug integrity_ BOP Test__ Location clearance__ Mechanical Integrity Test__ Subsequent form required 10- ORIGINAL SIGNED BY Approved by order of the Commission LONNIE'.;.r' ,.:.ctr:,~ ITH~,., Form 10-403 Rev 06/15/88 :~::~ ''f:.'i i !';~'i ~mmissioner Date 3//* i ~ SUBMIT IN TRIPLICATE BPCI Scale Inhibitor Squeeze Procedure Well 2-62/Q-17 PRE-TREATMENT OPERATIONS 1. Please contact Benton Dibrell in Anchorage at 563-3655 to allow for BPCI personnel to come to Endicott for the treatment a,qd flowback analysis. 2. Obtain well test at normal recommended rate pdor to treatment. Ensure WC sample is taken. SCALE INHIBITOR TREATMENT 1. Mix or obtain fluids as detailed on attached treatment fluids sheet. . MIRU for bullhead treatment. Pressure test lines to 3000 psi. Pump the following at 1-2 BPM. Avoid shutting down during the treatment. Evidence indicates that even brief shut-downs of 5-10 min have an adverse affect on the treatment. a. 5 bbl seawater (establish injection) b. 47 bbl Arctic Diesel w/~5% mutual soivent c. 71 bbl S-289 inhibitor as 11% mixture in seawater d. I 07 bbl seawaterovedlush e. 1 2 3 bbl seawater to displace tubing f. 30 bbl arctic diesel to freeze protect (tubing displaced to top pedoration) Note: Filter all fluids that are to enter the perfs to 3 p, preferably on the fly while pumping the job. 3. RDMO. Leave the well shut in for 24 hours. . POP well to test separator at 500 BPD for 12 hrs. and arrange with BPCI to monitor returns. Pull single brine samples, for inhibitor flowback evaluation, per the following schedule. Also obtain a watercut sample with each inhibitor flowback sample pulled. · Every 4 hours for first 12 hours · Daily for the following seven days · Weekly thereafter After 12 hours, return the well to target production rate. The bdne samples will be used by BPCI for inhibitor analysis. Watercut samples should be analyzed at the Endicott production lab. Mark each sample with date and time pulled. Please note on telex when the well is actually POP'd. . . After the last 24 hr sample has been obtained (,,,8th day), set a DH corrosion coupon in the tubing tailpipe or sliding sleeve to monitor scale inhibitor effectiveness. Ensure that a watercut sample is pulled during the test. Sample for inhibitor returns weekly thereafter. Pull the downhole coupon monthly, as operations permit, and inspect for scale deposition. RECEIVED DVT/2406 MAR 11 992 ~Aiaska Oil & Gas Cons. Commission Anchorage BPCI SCALE INHIBITION PROGRAM TREATMENT FLUID SUMMARY Well 2-62/Q-17 ARCTIC DIESEL w/MUTUAL SOLVENT Add 110 gallons SS-8603 to 44 bbls arctic diesel. Volume: 47 bbls BPCI INHII~ITOR. S-289 Volume: 71 bbls Dilute 330 gal of BPCI's inhibitor with 63 bbls of seawater in a clean stainless steel vac truck equipped with mixing paddles. Mix thoroughly. SEAWATER: ESTABLISH INJECTION / OVERFLUSH / DISPLACEMENT Pump 5 bbls seawater to establish injection initially. Pump 107 bbls as overflush. Pump 123 bbls to displace tubing. Add non-ionic sudactant to seawater (not required on tubing displacement volume). Volume: 235 bbls Ser vice Company Product Name Concentration BJ NE-18 O.2% Halliburton Losurf 300 0.2% Dowell/Schlumberger F-75N 0.2% ARCTIC DIESEL FREEZE PROTECTION For tubing displacement only; mutual solvent not required. Volume: 30 bbls DVT/2406 41aska Oil 8, Gas Cons. Commission Anchorage June 13, 1991 Alaska Oil and Gas Conservation Commission Page 3 WELL 2-58/S-09 TEMPERATURE COLLAR LOG v/ 13000'-14335' TEMPERATURE LOG 9900'-10806' . WELL 2-68/S-~17 PRODUCTION PROFILE V/ 10500'-11100' W~L ~-~0~U-~S~/.'~ "I 5 3 TEMPERATURE LOG 11308'-12175' WELL 3-01/N-29 -v/ PERFORATING RECORD 11650'-12750' SCHLUMBERGER WELL 3-05/0-29/ X - Y CAUPER SURVEY V 11440'-12550' TEMPERATURE SURVEY 11600'-12565' 12100'-12430' ATLAS WIREUNE 5/25/91 RUN ONE 6/4/91 RUNONE 5/1 9/91 RUN ONE 5/19/91 RUNONE 5/13/91 RUNONE 5/7/91 RUNONE 5/24/91 RUN ONE 6/6/91 RUNONE 2Ol 3/JLH/clt WELL 2-46/Q-15 STATIC TEMPERATURE SURVEY 10539'- 11 000' CAMCO 8/13/90 RUN ONE WELL 2-52/S-14 STATIC TEMPERATURE SURVEY 11500'-12182' CAMCO 8/13/90 RUN ONE WELL 2-62/Q-17 TEMPERATURE SURVEY SURF-1500' CAMCO 9/2/90 RUN ONE WELL 2-64/U- 10 4~tD-DUAL PROP RGD 1:240 TVD SURF-13885' TELECO ~r,~I~/PCCD-DUAL PROP RGB 1:240 MD SURF-13885' TELECO DUAL PROP RGD 1:600 TVD TELECO MW~ DUAL PROP RGD 1:600 MD TELECO SPECTRAL DENSITY DSN 13780'-14465' HALLIBURTON LOGGING SERVICES DLL/MSFL 13818'-14487' HALLIBURTON LOGGING SERVICES CET 2961'-14615' SCHLUMBERGER 8/18/90 RUN ONE 8/18/9O RUN ONE RUN ONE RUN ONE 8/24/90 RUN ONE 8/24/9O RUN ONE 8/28/90 RUN ONE WELL 2-36/O- 14 *DUAL LATEROLOG MICRO LATEROLOG (GAMMA RAY) 10504' - 11643' Run No. 1 ATLAS WlRELINE SERVICES *Z- DENSILOG COMPENSATED NEUTRON GAMMA RAY 10504' - 11634' Run No. 1 ATLAS WlRELINE SERVICES *FORMATION MULTI- TESTER 10572' - 11364' Run No. 1 ATLAS WlRELINE SERVICES *DUAL GAMMA RAY COMPENSATED NEUTRON POROSITY SIMULTANEOUS FORMATION DENSITY 10,520' - 11036' Run No. 1 11,036' - 11650' Run No. 1 SPERRY-SUN *ELECTROMAGNETIC WAVE RESISTIVITY DUAL GAMMA RAY 10,520' - 11036' Run No. 1 11,036' - 11650' Run No. 2 SPERRY-SUN *CEMENT BOND LOG (CBT) 10228' - 11552' Run No. 1 SCHLUMBERGER *CEMENT EVALUATION LOG (CET) 10228' - 11552' Run' No. 1 SCHLUMBERGER WELL .2-44/R- 12~ *INJECTION PROFILE SURVEY 11300' - 12708' Run No. 1 CAMCO WELL 2-62/Q-17 *TEMP LOG 9900' - 10800' HRS Run No. 1 *PRODUCTION PROFILE SURVEY 10290' - 10798' Run No. 1 CAMCO BP EXPLORATION October 12, 1989 BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Boyle' Enclosed please find one sepia and one blue. line print for the cased hole well logs run in the following Endicott wells' WELL 3-15/K-33 *STATIC TEMPERATURE SURVEY Logged 9/28/89 Run 1 WELL 2-62/Q-17 *STATIC TEMPERATURE SURVEY Logged 9/27/89 Run 1 WELL 1-35/O-25 *TEMPERATURE SURVEY Logged 9/26/89 Run 1 Logged by Camco. Sincerely, GND/Ims cc: File ORIGINAL I~ELL COMPLETION REPORT l±-±/-~b REVISED WELL ~MPLETION REPORT 11-23-88 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION .,=LL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Standard Alaska Production Company 86-158 3. Address B. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-21648 4. Location of well at surface 9. Unit or Lease Name 2112' SNL, 2350' WEL, SEC. 36, T12N, R16E Duck Island Unit/Endicott At Top Producing Interval 10. Well Number 2852' SNL, 3270' WEL, SEC. 36, T12N, R16E 2-62/Q-17 MPI f 1. Field and Pool At Total Depth Endicott Field/Endicott Pool 2865' SNL, 3444' WEL, SEC. 36, T12N, R16E 5. Elevation in feet (indicate KB, DF, etc.) [6. Lease Designation and Serial No. 55.10'= KBE I ADL 34633 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 09-20-86 10-13-86 07-15-87I N/A feet MSL I One 1'3. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)19. Directional Survey 120. Depth where $SSV set 121. Thickness of Permafrost I 10899'MD 10671'TVD 10816'MD 10591'TVD YeS [] NO [] 1589 feet MD I 1466 ~'2. Type Electric or Othe~ Logs Run DLL/MSFL, FMS MONITOR, NGT, Array Sonic, CNL-LDT 23. CASING, LINER AND CEMENTING RECORD SE'FI'lNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" Structural Drive Pipe Surface 131' Drive 13-3/8" 72# L-80 Surface 2493' 17-1/2" 3270 cuft Permafrost 9-5/8" 47# NT80S Surface 5413' 12-1/4" 9-5/8" 47# NT95HS 5413' 9738' 12-1/4" 575cu ft Class G .75% CFR-2 +O. 12%HR-7 7" 29# L-80 9485' 10897' 8-1/2" 465 cu ft Class G 0.5% Halad 344 + 0.3% LWL .,. 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MDI PACKER SET IMDI Schlumberger 5" @ 5 spt 4-1/2" 12.6# 9440' 9-5/8" ~ 9455' MD TVDss L-80 7" ~ 10224' 10164'- 10184' 9907'-9926' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10204'-10212' 9945'-9953' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10218'-10222' 9959'-9963' i3-3/8"X 9-5/8" Annulus Down Squeeze with 345 SKS 10302'-10312' 10040'-10049' 10336'- 10344' 10072'- 10082' Permafrost C followed by 115 bbls 10352'- 10406' 10088'- 10140' Crude Oil. 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) J. uly 13, 1987 I Flowing :Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ]GAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED..~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE air 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate/~ 29. -" 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP HRZ 9482' 9258' ITKIL YARIAK 9765' 9525' TOP KEKIKTUK 10003' 9753' 31. LIST OF ATI'ACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Q Drilling Engineering .-~ ..; , Signed~/¢/'''' ~- Title Endicottsuoorvisor Date //~'-~ ~/" ,.~2 _/ '~ 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 1-41/0-23 January 29, 1988 SPINNER 1-35/0-25 Run 1 February 8, 1988 * PRODUCTION PROFILE 2-34/P-14 Run 1 February 9, 1988 ~ * FLOWMETER/TEMPERATURE 1-27/P-20 Run 1 February 3, 1988 '~ * PRODUCTION PROFILE 2-62/Q-17 Run 1 January 31, 1988 ~* CONTINUOUS FLOW SURVEY ,~..* DIFFERENTIAL TEMPERATURE * PRODUCTION PROFILE (2-5-88) 2-52/S-14 Run 1 February 4, 1988 * PRODUCTION PROFILE Received by S~rely, Laura FujikawJJ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ¢ Stimulate ~ Plugging ~ Perforate [~ Pull tubing Alter Casing ~ Other ~J 2. Name of Operator 3. Address P. O. Box 196612. Anchoraq~. Ala.~]ca 4. Location of well at surface 2112' SNL, 2350' WEL, Sec. 36, T12N, R16E At top of productive interval 2852' SNr., 3270' WEL, Sec. 36, T12N, R].6E At effective depth At total 8dcbg~h 2 SNL, 3444' WEL, Sec. 36, T12N, R16E 5. Datum elevation (DF or KB) Feet 6. Unii';7" P~-op~e~t~"n~ame 7. Well number 2-62/~-17 8. Approval number ?-36? 9. APl number 50--029-21648 10. Pool Endicott Pool 11. Present well condition summary Total depth: measured true vertical 10899' feet 10671' BKB feet Plugs (measured) Effective depth: measured 10816 ' feet true vertical 10591' BKB feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size 111' 30" 2493' 13-3/8" 9738' 9-5/8" 1412' 7" Perforation depth: measured true vertical Tubing (size, grade and measured depth) 10164'-10184' 10204'-10212' (Subsea) 9907'-9926' 9946'-9953' Cemented Measured depth Driven 111' 3720 cu.ft. Permafrost 2493' 575 c.f. Class G 9738' w/.75% CFR-2+0.12% HR-7 465 c.f. Class G 9485'-10897' w/0.5% Halad 344 + 0.3% LWL 10218'-10222' 10336'-10344' 10302'-10312' 10352'-10406' 9959'-9963' 10040'-10050' 10073'-10080' 10088'-10140' ~ue Verticaldepth BKB 111' 2493' 9554' 9316'-1066 4-1/2" 12.6#/ft L-80 BTRS Non-IPC at 9440' Packers and SSSV (type and measured depth) . Q-~/~" p~er. _at 9~55! ?" p=_cker =_t !0224'; SSSV zt !5~9' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation Not on Production 14. Attachments Initial Perfarating SummarYc~ies of Logs and Surveys Run Daily Report of Wel/Operat~ons ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge //,~/~'- 'F~rm 10-404 J. --8~ JLH/ls, v/1951D Title Division Drilling Engineer Date ~'/'~/~-'~ Submit in Duplicate Endicott Well ~-62/0-17 ~PI Initial Perforation Proposal The following intervals for initial oil production were perforated July 13, 1987 using Schlumberger 5" tubing conveyed perforating guns at 5 s.p.f. 10164' - 10184' MD 10204' - 10212' MD 10218' - 10222' MD 10302' - 10312' MD 10336' - 10344' MD 10352' - 10406 MD (Refo DIL/SFL, 10/13/86) (Ref. DIL/SFL, 10/13/86) (Ref. DIL/$FL, 10/13/86) (Ref. DIL/SFL, 10/13/86) (Ref. DIL/SFL, 10/13/86) (Ref. DIL/SFL, 10/13/86) A tubing and packer completion followed immediately thereafter. A lubricator was installed and tested to 3500 psi and a SSSV was set and tested in the ball valve nipple at 1589' on July 16, 1987 after the well was completed. /lsv/1951D " STATE OF ALASKA ALA ..... OIL AND GAS CONSERVATION CON... ,SION 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,,~r Other,J~, 2. Name of Operator 5. Datum elevation (DF or KB) feet Standard Alaska Pr~d11~.~_~ C~m~ally T(lqF. = 55 l f1' 3. Address 6. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Duck Island Unit/Endicott 4. Location of well at surface 7. Well number 2112' SNL, 2350' WEL, Sec. 36, T12N, R16E 2-62/Q-17 At top of productive interval 8. Permit number 2852' SNL, 3270' WEL, Sec. 36, T12N, R16E 86-158 At effective depth 9. APl number 2860' SNL, 3423' WEL, Sec. 36, T12N, R16E 50_029-21648 At total depth 10. Pool 2865' SNL, 3444' WEL, Sec. 36, T12N, R16E E~idicott Pool 11. Present well condition summary 10899' Total depth: measured feet Plugs (measured) true vertical 10671' B[B feet Effective depth: measured 10816' feet Junk (measured) true vertical 10591' BKB feet Casing Length Size Cemented Measured depth True Vertical depth Structural BKB Conductor 111' 30" Driven 111' 111' Surface 2493' 13-3/8" 3720 cu. ft. Permafrost 2493' 2493' 9738' 9-5/8" 575 c.f. Class G 9738' 9554' Intermediate w/.75% CFR-2+0.12% HR-7 Production Liner 1412' 7" 465 c.f. Class G 9485' -10897' 9316'-10668' Perforation depth: measured w/0.5% Halad 344 + 0.3% LWL None true vertical :, '. .: Tubing (size, grade and measured depth) ' None .-i;_~:._~. Packers and SSSV (type and measured depth) ' ;;':" :':~ None 12.Attachments Description summary of proposal [] Detailed operations program ~ BOP sketch [] 13. Estimated date for commencing operation June/July 1987 14. If proposal was verbally approved ii Name of approver Date approved ~11t .~~reby certify that the foregoing is true and correct to the best of my knowledge ~'?¥&i~hed~ ~ ~ ~ ~ Title Division Drilling Engineer Date Commission Use Only Conditions of approval Notify commission so representative may witness Approval No..~ .~/ [] Plug integrity [] BOP Test [] Location clearanceI /'- J(~' 7 , ~- by order of ~ ..... ~ Commissioner the commission Date Approved by, ~?~' !:i'i:!~::ii * ~"~' Form 10-403 Rev 12-1-85 Submit in triplicate Endicott Well 2-62/Q-17 MPI Initial Perforation Proposal .... ~~~e~.to_ p_ei~__._flo~- t~e~f-~wing--inte~v~ls:--fo-~=:ihitfal-'-~il~rdduC{i0n -? ....... -~ing-dr~llpipe conveyed perforating guns at 4 s.p.f, in June/July, 1987. 10164' - 10184' MD 10204' - 10212' MD 10218' - 10222' MD 10302' - 10312' MD 10336' - 10344' MD 10352' - 10406 MD (Ref. DIL/SFL, 10/13/86) (Ref. DIL/SFL, 10/13/86) (Ref. DIL/SFL, 10/13/86) (Ref. DIL/SFL, 10/13/86) (Ref. DIL/SFL, 10/13/86) (Ref. DIL/SFL, 10/13/86) After perforating, the guns will be removed and the well will be shut-in. We will then run a tubing and packer completion. A lubricator will be installed and tested to 3500 psi and a SSSV will be set and tested in the ball valve nipple after the well is put on production. Standard Alaska Production Company 900 Eost Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANUAItU ALASKA PRODUCTI,,G~,I , ..... .... April 3, 1987 Mr. Lonnie Smith 'l~'~"~ ~': 3001 Porcupine Drive l~_~.r-'~ I ~eZZ~ o~ ~o~ ZO-~OZ ~ Z~e~ ~e~ B, We also ask that wells drilled to date be referenced by this dual designation. For your use is a list of wells drilled to date. WELL NAME PERMIT NUMBER API NUMBER 1-5/0-20 (MPI) 1-27/P-20 (MPI) 1-29/M-25 (MPI) 1-35/0-25 (MPI) 1-41/0-23 (MPI) 1-47/Q-21 (MPI) 2-2/P-18 (MPI) 2-4/M-19 (MPI) 2-6/J-22 (MPI) 2-14/0-16 (MPI) 2-34/P-14 (MPI) 2-62/Q-17 (MPI) 3-1/N-29 (SDI) 3-5/0-29 (SDI) 3-21/5-34 (SDI) 3-23/N-32 (SDI) 3-27/M-33 (SDI) 3-33/K-37 (SDI) 3-35/5-36 (SDI) 3-47/Q-35 (SDI) 4-8/P-27 (SDI) 4-20/M-35 (SDI) (T-34 Redrill) 4-20/T-34 (SDI) (Abandoned) ~ ~nit of the original Standard Oil Company ~ ~,f '.~iounded in Cleveland, Ohio, i,, 1870 86-106 50-029-21605 87-9 50-029-21693 86-181 50-029-21669 86-184 50-029-21672 87-32 50-029-21713 86-131 50-029-21625 86-63 50-029-21568 86-82 50-029-21585 87-18 50-029-21699 86-149 50-029-21639 86-172 50-029-21662 86-158 50-029-21648 86-190 50-029-21678 86-130 50-029-21624 87-33 50-029-21714 86-155 50-029-21645 86-83 50-029-21586 86-180 50-029-21668 87-20 50-029-21701 86-64 50-029-21569 87-8 50-029-21692 86-173 50-029-21640-01 86-150 50-029-21640 We thank you for your assistance and should you have any questions, give me a call at 564-5007. Yours very truly, R. S. Allan Division Drilling Engineer RSA/MAW/pm/1664D cc: R. H. Reiley_ B L J. G. Vidrine I. R. Robertson D. Huxley B. Ross File 16.4 Endicott Development SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited HOUSTON. TEXAS 7'700! ocr~o]3~'~,l:~. 2 7 I ] 9 8 6 PLEAS£ REPLY TO ! TT~./~' T , Court AK ~~'~[]q~,'.:,., -NGI:,~:~~TH SAP~~Y ~ Additional prints.ore being sent to?'-,, l_BL. prin_ts & 1 RF01ded,-SePia Alaska Oil & Gas ' Conservation Commission . i~ ~001 Porcupine Drive ' x,~nchorage, AK 99501 / "ATTN: William Van Alep . / l RRolled Sepia . ..~ 1 B1 p ints UNOCAL . 909 w. 9th ~.nchoraRe, aK ~ 5~v=~0247 Standard Alaska Production Co. 900 E. Benson Blvd. MB ~2-2 Anchorage, AK 99519-66~2 Attention: Laura Fu]ikawa Gentlemen: %~ RUN 1 Enclosed are 2 BIzprints ofthe]Z, BT (10/22/86) Company Standard AK Prod Co ,Well 2-62/~-17 MPI Field Endicott North Slope S. SCHLUMBERGER OFFSHORE SERVICES 500 W. International Airport Rd. Anchorage, Ak 995~8 ATTN- Print Room on: , State A 1 a s ka 1RRolled Sepia I BL prints ARCO ANO-879E Anchorage, AK 99510 ATTN' Lucille Johnston prints l RRolled Sepia 1. BL prints Amoco Production Co. Amoco Building 1670 Broadway Denver, CO 80202 ATTN: Tom Harting 1 RRolled Sepia 1BL prints Exxon Company, USA 800 Bell St. (Room 2917-J) Houston, TX 77002-7426 ATTN: Steve Wilson The film is returned tO SAPC prints prints Date' We appreciate the privilege of serving you. Very truly yours, SCHLUMBERGER OFFSHORE SERVICES Charles Merriman DISTRICT MANAGER SO~--1565.A SOHIO, Standard Alaska x~-h Preduction Cempany P.O. Box 196612 Anchorage. Alaska 9951 ~,-o~12 PANY TO 1,13i'l [ io_m ALASF%. PRODUCTION Oil in/ I ATTENTION ~ RE: WE ARE SENDING YOU [] Attached [] Under separate cover via the following items: [] Shop drawings [] Copy of letter [] Plans £~- , [~],Saml~ljes [] Specifications .;' ,;"! ¢,~ f re¢{ ? COPIES DATE NO. DESCRIPTION / THESE ARE TRANSMITFED as checked below: [] For approval ~For your use [] As requested I-], [] Approved as submitted [] Approved as noted [] Returned for corrections [] Resubmit__,copies for approval [] Submit copies for distribution [] Return corrected prints [] Your proposal due REMARKS: COPY TO SIGNED: not n( nntprj bjndjv nntjfv u( ot once. SOHIO A Standard Alaska Praduction Companl P.O. Box 196612 Anchorage. Alaska 99519-6612 ANY TO STANDARD ALASKA PRODUCTION IJOB NO. RE: WE ARE SENDING YOU [] Attached [] Under separate cover via the following items: [] Shop drawings [] Copy of letter [] Plans [] Samples [] Specifications COPI ES DATE NO. DESCRIPTION THESE ARE TRANSMITTED as checked below: [] F o,~"'P roval ~F/For your use [] As requested [] Approved as submitted [] Approved as noted [] Returned for corrections [] Resubmit__copies for approval [] Submit copies for distribution [] Return corrected prints REMARKS: [] Your proposal due COPY TO 0 R IN A t ALAL '" .IL AND GAS CONSERVATIOI . ' ' /1MISSION WELL COMPLETIOH OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] Classification of Service Well 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchoraqe, Alaska 4. Location of well at surface 2112' SNL, 2350' WEL, Sec. 36, T12N, R16E At Top Producing Interval 2852' SNL, 3270' WEL, Sec. 36, T12N, R16E At Total Depth 2865' SNL, 3444' WEL, Sec. 36, T12N, R16E 99519-6612 7. Permit Number 86,158 8. APl Number 50-029-21648 9. Unit or Lease Name Duck Island Unit/Endicott 10. Well Number Q-17 MPI 11. Field and Pool Endicott Field 5. Elevation in feet {indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. 55.10' = KBE I ADL 34633 Endicott Oil Pool 12. Date Spudded 13. Date T.D. Reached I 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions Sept. 20, 1986 Oct. 13, 1986 I Oct. 16, 1986 I N/A feet MSL I None 1 7. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) /19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost ]_0899'MD Z0671'TVD 10816 'ND, Z0591~V'jDYEs I~ NO [] None feet MD 1466 22. Type Electric or Other Logs Run CBT )LL/MSFL, FMS MONITOR, NGT, Array Sonic, CNL-LDT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE 20" Stru(~tural Dr Surface 111' 13-3/8" 9-5/8" 72~ 47# .ye Pipe L-80 NTBOS Surface Surface 2493' 5413' 17-1/2" 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 12-1/4" 9-5/8" 47# NT95HS 5413' 9738' 12-1/4" 7" 29ff L-80 9485' 10897' 8-1/2" 25. CEMENTING RECORD AMOUNTPULLED Drive 3720 cu. ft. PermafrOst · o + 575 cu. ft Class G.[5~CFR-2 0.12% HR- 465 cu. ft. Class G 0~5% Halad 344 + TUBING RECORD O. 3% LWL SIZE DEPTH SET (MD) PACKER SET (MD) None None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED Annulus downsqueeze with 345 sks Permafrost C followed by 13-3/8" x 9-5/8" 27. PRODUCTION TEST Date First Production Date of Test Hours Tested Casing Pressure IMethod of Operation (Flowing, gas lift, etc.) PRODUCTION FOR TEST PERIOD I~ CALCULATED 24-HOUR RATE OIL-BBL OIL-BBL GAS-MCF GAS-MCF Flow Tubing Press. WATER-BBL WATER-BBL CHOKE SIZE GAS-OIL RATIO 28. CORE DATA OIL GRAVITY-APl (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. k "' ! 8 i986 Als*k3 Oil & r3~$ Cons. (;omm!ssion Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submil in duplicate 29. NAME Top HRZ Itkilyariak Top Kekiktuk 31. LIST OF ATTACHMENTS GEOLOGIC MARKERS 30. FORMATION TESTS MEAS. DEPTH 9482' j Include interval tested, pressure data, all flui(Js recovered and (r~lvity, ~LLJ-E ~-.~,~E,--'7~-,-~ GOR, and time of each phase. 9258' ii 9765' i! i ', 9525 ' ii 9753' 10003 ' ~d 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Divis±on Drilling Signed2 ~ C~ · ~--'~k'~L~-' Title Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". F:nrm 1Q 407 Rig' Doyon #15 Well' Q-17 SAPC Daily Drilling Report -- ENDIC(1TT September 20, 1986 at 0600 hours AFE # 71 751 5 0600 Depth: ' Day: -1 2a-Hour Ftg' ' Current Operation: Rig up to spud. Move rig to Q-17. Prepare for spud. MUD TYPE-Spud Mud WT'8.6 VIS'300 PV' YP- FL' SOLIDS'48 TEMP' °F SURVEY MD ANGLE DIRECTION TVD SECT ION COORD I NATES DLS 1249H' SAPC Daily Drilling Report -- ENDICOTT September 21, 1986 at 0600 hours Rig: Doyon #15 Well: Q-17 AFE # 717515 0600 Depth: 51 5' Day: 1 24-Hour Ftg: 51 5' Current Operation: Clean pits. Accept rig at 0600 hrs. on 9/20/86. Spud well at 1230 hrs. on 9/20/86. Drill 17-1/2" hole. Plug bit. Trip bit. Drill 17-1/2" hole to 515 ft. POH. Clean pits of gravel. MUD TYPE-Spud Mud WT:8.9 VIS:280 PV: YP: FL: SOLIDS:48 TEMP: °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1249H: SAPC Daily Drilling Report -- ENDICOTT September 22, 1986 at 0600 hours Rig: Doyon #15 Well: Q-17 AFE # 717515 Current Operation: Drilling. Clean pits. 0600 Depth: 1485' Day: 2 24-Hour Ftg: 970' RIH and drill 17-1/2" hole with Sperry-Sun gyro-surveys to 1485 ft. MUD TYPE-Spud Mud WT:9.2 VIS:240 PV: YP: FL: SOLIDS: TEMP:46 °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1249H: SAPC Daily Drilling Report -- ENDICOTT September 23, 1986 at 0600 hours Rig' Wel 1 ' Doyon O-17 #15 AFE # 717515 0600 Depth' 251 5' Day' 3 24-Hour Ftg' 1030' Current Operation' Circulating. Drill 17-1/2" wi th stab-in. to ~515 ft. MUD TYPE-Mud WT'9.8 VIS'lBO PV' yp. FL- POH. SOLIDS' Run 13-3/8" casing. RIH TEMP' 50 °F SURVEY MD ANGL____~E DIRECTION TVD __ SECTION -- COORD I NATES DLS 1249H' Rig: Doyon #15 Well: Q-17 SAPC Daily Drilling Report -- ENDICO1-F September 24, 1986 at 0600 hours AFE # 717515 0600 Depth: 2515' Day: 4 24-Hour Ftg: ' Current Operation: Service top-drive. RIH wi th stinger. Mix and pump cement. Bump plug. POH. 13-3/8" shoe at 2491 ft. Float collar at 2449 ft. Nipple up BOPE. Test BOPE to 3000 psi. Service top drive. MUD TYPE- WT:9.1 VIS:39 PV:8 YP:9 FL:28.0 SOLIDS:3 TEMP: °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1249H: SAPC Daily Drilling Report -- EIJDICOTT September 25, 1986 at 0600 hours R i 9' Doyon Well' Q-17 #15 AFE # 717515 0600 Depth' 4157' Day' 5 24-Hour Ft§' 1642' Current Operation' RIH. RIH. Drill float equipment and shoe plus l0 ft. new hole. Conduct FIT to 11.5 ppg. Drill 12-1/4" hole to 4157 ft. Trip bit. MUD TYPE-S.W.Lig WT'9.2 VIS'36 PV'IO YP-8 FL'19 SOLIDS'4 TEMP:85 °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS = 1249H' Ri§: Doyon #15 Well: 0-17 SAPC Daily Drilling Report -- ENDICOTT September 26, 1986 at 0600 hours AFF. # 717515 0600 Depth: 4990' Day: 6 24-Hour Ftg.' 833' Current Operation: Drilling. RIH. Drill 12-1/4" hole to 4963 ft. Trip bit. Drill to 4990 ft. MUD TYPE-Sea/Ligno WT:9.5 VIS:36 PV:16 YP:8 FL:12 SOLIDS:6 TEMP: °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1249H: SAPC Daily Drilling Report -- ENDICOTT September 27, 1986 at 0600 hours Ri g' Ooyon Well · O-17 #15 AFE # 717515 0600 Depth' 6477' Day' 7 24-Hour Ftg' 1487' Current Operation' Drilling. Drill 12-1/4" hole to 6477 ft. POH for kick-off. MUD TYPE-Sea-Ligno WT-9.6 VIS'37 PV'8 YP'9 FL'8 SOLIDS'7 TEMP'90 °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1249H' Ri g: Doyon Well: Q-17 #15 SAPC Daily Drilling Report -- ENDICOTT September 28, 1986 at 0600 hours AFE # 717515 Current Operation: MUD TYPE-Sea-Ligno 0600 Depth: 6885' Day: 8 24-Hour Ftg: ~.08' Dyna-drill 12-1/4" hole. POH for Dyna-drill. RIH taking MWD surveys every 500 ft. 13-3/8" casing shoe. Dyna-drill 12-1/4" hole to 6885 ft. WT:9o6 VIS:36 PV:7 YP:6 FL:8 SOLIDS:7 TEMP:89 °F below SURVEY MD 14 6496 15 6591 1 6 6686 17 6781 ANGLE DIRECTION TVD SECTION COORDINATES 2.0 S41W 6496 19 ~ 38 ~ 8 4.1 S33W 6590 24 ~ 42 ~ 5 6.7 S41W 6685 33 % 49 ~ 1 8.9 S39W 6779 46 S 59 v~9 1249H: DLS · 1.2 2.4 2.7 2.4 SAPC Daily Drilling Report -- ENDICOTT September 29, 1986 at 0600 hours Rig' Doyon #15 Well' Q-17 AFE # 71 751 5 Current Operation' Dynadrill. Dyna-dril 1 721 5 ft. 0600 Depth' 7215' Day' 9 24-Hour Ftg' 330' 12-1/4" hole to 6985 ft. Trip bit. Dyna-dril 1 to M[JD TYPE-Sea-Ligno WT-9.6 VIS'35 PV'7 YP'6 FL'7 SOLIDS'8 TEMP' °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1 8 6876 11.4 S39W 19 6975 13.6 S41W 20 7070 15.5 S39W 6873 6969 7061 62 83 107 S' 72 S 89 S: 107 ~20 2.6 ~ 33 2.3 vd 49 2.1 1249H' Ri g: Doyon Well: Q-17 #15 SAPC Daily Drilling Report -- ENDICOTT September 30, 1986 at 0600 hours AFE # 71 751 5 0600 Depth: 7375' Day: l0 24-Hour Ftg: 160' Current Operation: Drilling. Dynadrill 12-1/4" hole to 7320 ft. Trip for BHA change. RIH. Wash and ream throug~ tight spot. Stuck pipe. Work stuck pipe free. Drill to 7375 ft. MUD TYPE-Sea Ligno WT:9.6 VIS:36 PV:8 YP:6 FL:7 SOLIDS:8 TEMP: °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 21 7165 1 7.8 S38W 7152 1 34 ~ 1 28 v~66 22 7261 1 9.5 S40W 7243 163 % 1 52 ~ 85 1249H: DLS 2.5 159 SAPC Daily Drilling Report -- ENDICOTT October l, 1986 at 0600 hours Ri g: Doyon Well: Q-17 #15 AFE # 717515 Current Operation: 0600 Depth: 7912' Day: ll 24-Hour Ftg: 537' Drilling. Drill and survey 12-1/4" hole to 7912 ft. MUD TYPE-Sea Water WT:9.7 VIS:37 PV:9 YP:7 FL:6 SOLIDS:8 TEMP:92 °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 23 7370 20 S41 W 7346 200 S' 1 80 ~J 1 09 0: 6 24 7467 20.1 S42W 7437 233 $ 205 ~ 1 31 O. 4 25 7652 19.1 S44W 7611 293 $ 250 ~J173 0.6 1249H: SAPC Daily Drilling Report -- ENDICOTT October 2, 1986 at 0600 hours Ri g: Doyon Wel 1: O-1 7 #15 AFE # 717515 Current Operation: Tripping. Dril 1 and RIH. 0600 Depth: 8128' Day: 12 24-Hour Ftg' 216' survey 12-1/4" hole to 8128 ft. POH. Test BOP's. MUD TYPE-SW-Ligno WT:9.8 VIS'3~ PV'll YP'8 FL'6 SOLIDS'8 TEMP'88 oF SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 26 7844 18.1 S44W 7793 356 ~ 295 w216 0.5 27 8034 16.4 S46W 7975 412 ~ 334 1~/255 0.9 1249H: Ri g' Doyon Well-0-17 #15 SAPC Daily Prilling Report -- ENDICOTT October 3, 1986 at 0600 hours AFE # 71 7515 Current Operation' Drilling. RIH. Dril 0600 Depth' 8464' Day' 13 24-Hour Ftg' 336' and survey 12-1/4" hole to 8464 ft. MUD TYPE-SW-Li gno WT'9.8 VIS'40 PV'13 YP'IO FL'5.4 SOLIDS'8 TEMP' 96 oF SURVEY MD ANGLE DIRECTION TVD SECTION 28 8229 1 7.2 S49W 8161 469 $ 371 COORDINATES ~J298 1249H- DLS 0.6 SAPC Daily Drilling Report -- ENDICOTT October 4, 1986 at 0600 hours Ri g: Doyon Well: 0-17 #15 AFE # 717515 Current Operation: 0600 Depth: 8852' Day: 14 24-Hour Ftg: 388' Drilling. Drill and survey 12-1/4" hole to 8852 ft. MUD TYPE-S.W. Li gno WT'9.9 VIS'38 PV-15 YP:IO FL'5 SOLIDS'9 TEMP' SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 29 8423 1 9.7 S54W 8345 530 ~'410 ~ 3z~6 1 . 5 30 8608 22.6 S56W 8518 5~t6 £ 448 ~400 1.6 1249H: Rig: Doyon #15 Well: Q-17 SAPC Daily Drilling Report -- ENDICOTT October 5, 1986 at 0600 hours AFE # 717515 0600 Depth: 9179' Day: 15 24-Hour Ftg' 327' Current Operation: Tripping. Drill and survey 12-1/4" hole to 9179 ft. Trip bit. MUD TYPE-SW-Ligno WT:IO VIS:38 PV:16 YP:ll FL.'5 SOLIDS:9 TEMP:96 °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 31 8799 25 S58W 8693 673 S 490 N465 32 8984 26 S61W 8860 751 $ 530 ~534 33 9092 25.6 S60W 8957 797 $ 553 k, 575 1249H: DLS 1.3 0.9 0.4 Rig: Doyon #15 Well: O-17 SAPC Daily Drilling Report -- ENDICOTT October 6, 1986 at 0600 hours AFE # 717515 0600 Depth: 9618' Day: 16 24-Hour Ftg: 439' Current Operation: Drilling. Drill and survey 12-1/4" hole to 9618 ft. MUD TYPE-S. W.-Li gno WT:IO.O VIS.'40 PV:16 YP:12 FL:5 SOLIDS:9 TEMP:98 °F SURVEY MD ANGLE DIRECTION TVD SECTION 34 9270 24.1 S61W 9118 870 35 9451 21.8 S63W 9285 939 COORDINATES 590 623 ~640 ~702 1249H: DLS 0.8 1.4 SAPC Daily Drilling Report -- ENDICOTT October 7, 1986 at 0600 hours Rig: Doyon Well: Q-17 #15 AFE # 717515 0600 Depth: 9755' Day: 17 24-Hour Ftg' 137' Current Operation' Run 9-5/8" casing. Drill and survey 12-1/4" hole to 9755 ft. POH. Run 9-5/8" casing. IiUD TYPE-S.W.Ligno WT'IO VIS'40 PV-16 YP-IO FL'5.2 SOLIDS'lO TEMP'96 OF SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 36 9641 20.35 S65W 9463 1003 ~ 652 ~761 1.6 37 9750 18.45 S66W 9567 1036 ~ 667 ~783 1249H: Ri g' Doyon #1 5 Well- 0-17 AFE ~ 71 7~ F 0600 Depth' 9755' Day' 1 8 24-Hour Ftg' ' Current Operation' L/D BHA. Run 9-5/8" casing. Shoe at 9738 ft. Mix and pump cement. Bump plug. N/D BOP's. Install pack-off and test to 5000 psi. Install tubing spool and double stud adaptor flange. N/U BOP's. Test BOP's. L/D 8" D/c's. MUD TYPE- WT'9.8 VIS'42 PV'15 YP-IO FL'6.4 SOLIDS'9 TEMP' OF SURVEY MD ANGLE DIRECTION TVD SECTION COORD I NATES DLS 1249H. SAPC Daily Drilling Report -- ENDICOTT October 9, 1~°86 at 0600 hours Ri g' Doyon #1 5 Wel 1 · O-1 7 AFE # 717515 0600 Depth' g845' Day' 1 9 24-Hour Ftg' 90' Current Operation' Drilling. RIH. Test casing to 3000 psi. Drill FC and cement. Test casing to 3000 psi. Drill cement and shoe plus 10 ft. new hole. Conduct FIT to 13.5 ppg. Drill ahead 8-1/2" hole to 9845 ft. MUD TYPE-SW-Ligno WT'9.8 VIS'38 PV-IO YP'8 FL'6.5 SOLIDS'9 TEMP' OF SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1249H' Rig: Doyon #15 Well: 0-17 SAPC Daily Drilling Report -- ENDICOTT October 10, 1986 at 0600 hours AFE # 717515 0600 Depth: 10,085' Day: 20 24-Hour Ftg' 240' Current Operation: Drilling. Drill 8-1/2" hole to 9880 ft. Trip bit. Drill 8-1/2" hole to 10,085 ft. ~UD TYPE-Sea Ligno WT'9.8 VIS'36 PV'IO YP'7 FL-6.5 SOLIDS'9 TEMP' °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1249H: Rig' Doyon fl5 Well' Q-17 SAPC Daily Drilling Report -- Ek~DICOTT October l l, 1986 at 0600 hours AFE ~ 717515 0600 Depth' 10,468' Day' 21 24-Hour Ftg' 383' Current Operation- Drilling. Drill 8-1/2" hole to 10,463 ft. Trip bit. Drill to 10,468 ft. MUD TYPE-Sea Ligno WT-9.8 VIS:34 PV'IO YP'7 FL'7 SflLIDS'9 TEMP'96 °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1249H' Rig: Doyon Well: Q-17 #15 SAPC Daily Drilling Report -- ENDICOTT October 12, 1986 at 0600 hours AFE # 717515 0600 Depth: 10,899' Day: 22 24-Heur Ftg' 431' Current Operation: Circulating. Drill 8-1/2" hole to 10,899 ft. CBU. MUD TYPE-Sea Ligno WT:9.8 VIS:37 PV:12 YP:7 FL:7 SOLIDS:9 TEMP:95 °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1249H: SAPC Daily Drilling Report -- EIJDICOTT October 13, 1986 at 0600 hours Rig' Wel 1 · Doyon Q-17 #15 AFE # 717515 0600 Depth' 10,899' Day' 23 24-Hour Ftg' ' Current Operation' Cut drilling line. POH. Pun open hole logs. RIH w/bit and BHA. MUD TYPE-Sea Ligno WT:9.8 VIS'37 PV-IO YP'7 FL'6.5 SOLIDS'9 TEMP' °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1249H' SAPC Daily Drilling Report -- ENDICOTT F~ctober 14, 1986 at 0600 hours Rig- Doyon #15 Wel 1 · 0-17 AFE # 71 7515 0600 Depth' 10,899' Day' 24 24-Hour Ftg' ' Current Operation' Change rams. RIH. CBU. POH. Run liner. Mix and pump cement - bump plug. POH. P/U scraper. Change rams. 7" shoe at 10,899 ft. MUD TYPE-Sea Ligno WT'9.8 VIS'38 PV-lO YP-6 FL'6.5 SOLIDS'9 TEMP' °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1249H' SAPC Daily Drilling Report -- E~.~DICOTT October 15, 1986 at 0600 hours Rig: Doyon #15 Wel 1: O-17 AFF_ # 717515 0600 Depth: 10,899' Day: ~5 24-Hour Ftg: ' Current Operation: Clean pits. RIH and tag cement at 8951 ft. Drilled cement from 8951 to 9485 ft. CBU. POH. RIH to top of liner at 9485 ft. Test lap to 3000 psi. RIH and tag cement at 10,682 ft. Drilled to float collar at 10,816 ft. CBU. Test liner to 3000 psi. Clean pits. MUD TYPE-SW-Ligno WT:9.8 VIS:37 PV: YP: FL: SOLIDS: TEMP: °F SURVEY MD ANGLE DIRECTION TVD SECTION COORD I NATES DIS _ 1249H: SAPC Daily Drillin9 Repnrt -- F. IJDIC, DTT Octeber 16, 1986 at 0600 hours Rig' Poyon #1~ Well' Q-17 (2-62) AFE # 71 751F 0600 Depth' 10,899' · Day 24-Hour Ftg' ' Current Operation' Prepare to move rig. Displace well to 9.6 ppg brine. POH. Run 1 ,it. tubing below hanger· N/D BOPE. Install tubing hea~ adaptor and master valve. Test to 5000 psi - OK. Prepare tn move rig. Rig released at 0600 hrs. 10-16-86. MUD TYPE-NaC1 WT'9.6 VIS' PV- YP' FL' SOLIDS' TEMP' °F SURVEY MD ANGLE DIRECTION TVD' SECTIOn! COORD I ~ATES DLS 1249H- GREAT [.AND OIRECTIONAL ORILLING INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY STANDARD ALASKA PRODUCTION COMPANY ~,.;-..! ,~, J-.: .:~. }. ....... PAD MI WELL NO Q-17123-36-12-16] ./ ...... ..................................................................................... '...t..;:'../. .... £...:,',..,.,~,~_~.Q~} ....................... .......... , ...... ENDICOTT L *,.]) C A T T 0 i*;~ AL98&035 MWD & SINGLE SHOT 10-1S-86 N A fii E "!' ]: '¥' I... !ii: S :1: i; ~,! ~:~ T I..~ I:;; ii:: 485 FT 9750FT i')Ei::"f'H iNTERVAL. !::'I:~0~I 'f'O 9-2,S-86 10....6-86 r, A 'l"':" i ii:;: V E ,. c. S Y "t" A t'::.' IE i"i {':' 1:;: f'i f'"'l 'i" {*) THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALL. COPIES OF THE SURVEY REPORT WIt. L. BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. GREAT LAND DIRECTIONAL~ DRIL. LING,INC I0--].~ Client .............. : Well ................ : Closure Direction...: aa~netic Declination: Data file name ...... : SI'ANDARD ALASKA F'RODUCTION I30MPANY PAD MI WELL. Q-17223-36--12-16] S 49.00 W 31. deg 1S mln E B:QIT.DAT RECORD OF: SURVEY IWell assumed vertical to ColY, pUtat}on: Survey dote: Hethod ..... : RKB Height.: 486.0 ) RADIUS OF CURVATURE 10-13-86 GYRO SURVEYS & MWD READIN( S6.0 ft MEAS DEPTH 48S 962 ]. S 04 ~032 2510 3476 4 0 OS 4496 4988 S496 S998 6496 6S91 6686 6876 6976 7070 7 ;1.65 ! ,_.,_ I 7:7-.)7 0 7467 7652 DR I Fl' TRUVERT SUBSEA SECT I ON DG MN DEPTH EIEPI'H DIST 0 20 486. O0 429. O0 I. 1.1 0 10 96'1.99' 9 OS. 99 2.78 0 25 1.503.99 1.447.99 2.43 0 I.S ~ q' ~.0~. 1. 98 ~.,"~ c"~S, .98 0 . 98 0 3S 2S09.96 2453.96 3.S6 6 1. 3 0 42 1. 6 0 30 0 30 0 30 48 0 .'1.8 0 6 42 S4 24 36 30 pog'-:. 93 2939.93 4. '.I. 6 .... 7-a . 3475.87 34'1.9.87 -.2. lB 4004.8~. 3948 ~:82 -.6.1.1 4495 80 44'-29'i:,80 -S. 12 4987.78 4931. Ji~8 -. 1.. 67 [~_ . -- i"-'" ,~o_-._- s494.73 , 43U,.;7s <,. 'm_t 67 . _ 'o' 70 S997 68 S94~2'.i~8 6406.60 63S0i.';!~50 <;o 1~~. S7 6S9 0 .42 6534- ':~'~ ~i.$ ~" -- 668S. 00 6629 .~,~ 0 32.7S 6779. i ~ 6723 .~ l 45.49 6872.62 6816.62 6]. 97 6969.26 ~9:1.3.26 83.13 7061_22 7005.22 106.70 71.7 .'1.9 20 20 51.9 D I RECI' I ON ANGLE S 87.20 W S 83.70 W N 32.80 E S 9.60 E S 2S.30 W N 88.00 E N 76.00 E S 46.00 E S 9.00 E S 39.00 W S .'1.7.00 W c: '1. O0 W S 33.00 W S 41.. O0 W S 33.00 W S 41.00 W S 39.00 W S 39.00 W S 41.00 W o 39.00 W 48 71S2.22 7096.22 1.33.47 S 38.00 W 30 7243. :1.8 7187.1.8 .'1.63.70 S 40. O0 W 0 734S.9'5' 9'289.77 200.!,2 S 41.00 W 6 7436.89 7380.89 233.09 S 42.00 W 6 76:1.1..'1.7 7SSS. 17 294.8:1. S 44.00 W REL..AT IVE COORDINATES FROM WELL-HEAD 0.0'7 S 1..41 W 0.23 S 3.48 W 1..6S N 4.66 W 1.17 N 2.3:'1. W 2.22 S 2.78 W O I STANCE .1...41. 3.49 2. S9 3. S6 CLOSURE! DOC t,_.EG DG MN Fi.'; de i_O · S 87 ;1.2 0 W 0.069 S 86 9 25 W 0.03S N 70 29 30 W 0.046 N 63 1.2 33 W 0.032 S Si 1.9 40 W 0.070 6.02 o¢' 0.28 W 6.02 4.97 S 7.17 E 8.72 6.80 S 1.4.00 E 1. S.S7 10.S4 S :1. S.9S E 1.9.;1.1 1.4.66 S 1.4.87 E 20.81. ;t9.61 S 1.2. 519 E 23.09' 27.39 S 10.9S E 29.S0 36.14 S 8.68 E 36..1.7 37..'18 S 7.04 E 37.84 41.21 S 4.00 E 41.41 48 ~S ~' I 37 W 48 . _ o . ,. 37 S8.22 S 9.66 W S9.02 71.23 S 20.19 W 74.04 87.66 S 33.96 W 94.00 10S.93 S 49.30 W i16.84 127.23 S 66.25 W 143.44 1.51.08 o~ 85 .... 57 W 173 6~ '1.79 0° S 1.09 49 W 20~ 91 204.00 S '1.311.52 W 242.72 24~ 38 ~ 1.73 84 W 303 99 S 241. 2W S SS 16 37 E S 64 E.; SE; E S S6 33 6 E S 4S 3S S2 E S 31. S]. 27 E S 21. 47 Sd E S 13 43 48 E S 1.0 43 38 E S _ 32 ~ ~8 E S 1. 37 28 W S 925 SW S 1.'-.._, 4-9 36 W S 2'I 10 S6 W S 24 57 3S W 0.024 0.083 0.1.1.3 0.001. 0.001. 0.0S9 O. 040 C 73 O., 87 o 211. o 739 f..... o 632 ¢._ . 2.006 S 27 .~0 oo W S 29 31 30 W ,o 3:1. o' 22 S 32 48 39 W S 34 S2 49 W 1. 786 0.471 O. :1.60 0.5S3 PAID MI WELL, Q-. ].7E23-3d- ].2- ].6:] .'1.0-.'1.3--.8¢5 RECORD OF SURVEY MEAS DRIFT TRUVERI' SUBSEA SECT ION DIRECT ION RELAI' I VE COORDINATES CLOSURE DEPTH DG MN DEF~TH DEPTH DIST ANGLE FROM WEL[..-FIEAD DISTANCE DG MN S 7844 :1.86 '7793.:l. 4 773'7. ].4 333.82 S 44.00 W 2~3.~3 S 21~.38 W 364.39 S 3~ 2~ 21 W 8034 ...... 16 24 7974 58 7¢1.8 58 4.1.,:. 02 c~ 46.00 W 333.27 S 256.22 W 420.38 S 37 33 1.2 W 8229 :l.? ~.2 8:1~:1..26 8108.2~ ~8.3S S 4~.00 W 371..3~ S 2~7.77 W ~7S.98 S 38 43 31 W 8423 :1.~ 42 834.5.27 8289.27 E2~.67 S S~.O0 W 40~.35 S 345.80 W S36.01 S 40 10 33 W 8608 22 36 85~.?.?~ 8461.?~ 5~6.04 S 56.00 W 44?.83 S ~00.47 W 600.?? S ~:t 48 :l.?W 8799 23 0 8692.34 8636.34 8984 26 0 8839.51 8803.S]. 9092 25 36 8956.7~ 8900.75 9270 24 6 9~.~.8.26 9062.26 9431 2]. 48 9284.92 9228.92 672.36 S S8.00 W 7S0.66 S 6]..00 W 796.72 S 60.00 W 870.02 S ~1.00 W 938.78 S 63.00 W 489.80 S S30.22 S SS3.37 S S90.20 S 623.33 S #6S.10 W S33.72 W S7#.63 W 639.73 W 702.04 W ~73.43 S 43 31 4 W 732.32 S 43 ].]. 18 W 797.7S S 46 4 48 W 870.40 S 47 18 22 W ~38.83 S 48 23 SS W 9641 20 33 9462.07 9406.07 lOOS.].l S 6S.00 W 9760 ].8 #S 9S64.7~, 9S08.71 1040.29 S 66.00 W 663.44 S 668.~S S 763.77 797.~.S iOOS.1S S 49 27 6 W 1040.45 S SO 0 36 W DOG LEG deg/].O0 r ~99 ~32 ]..322 1.S76 1. 270 0. 624 0.409 0. 848 1..=80 0.663 1.686 PAD MI WEi_L Q--17[23-36-.I. 2-16] !0- 13-86 DATA INTERPOL. ATED FOR EVEN I00 F:'EEZI' OF SUBSEA DEPTH MEAS. DEPTH :15;,6 256 356 456 'f'RL! VEiRT '"1 I'-' . c~ _ c, SEA MID--. I'VD DEP'F H DEPTH D I FF. 56 0 0 156 100 0 256 200 0 2156 300 0 456 400 0 VER'I' I CAL CORRECT 0 0 0 0 0 556 556 500 0 0 656 656 600 0 0 756 756 700 0 0 856 856 800 0 0 956 95¢-5 900 0 0 1.056 11.56 1256 :[ 35,6 1456 1556 :1.65,6 :I. 756 :1.856 1956 2056 °156 2256 2356 2456 105,6 1000 0 1.1.5d 11.00 0 1.25d 1.200 0 1356 :1.300 0 1.456 1400 0 1556 1.500 0 1.656 1600 0 .1,..~o 1.700 0 1.85;6 1.800 0 1956 1900 0 "°056 2000 0 ~:I. 56 ~1.00 0 °°Rz =~00 0 2356 2300 0 2456 2400 0 2556 2500 0 2656 2'600 0 2756 2700 0 Oor' .-' =ooo 2!800 0 25'56 2900 0 255,6 2756 2856 2956 RELAI' I VE COORD I NATES FROM WEL. t..-.HEAD 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.09 S 1.81 W 0.12 S 2.31. W O. 16 S 2.76 W 0 °O S 3 14 W 0.23 S 3.47 W 0.33 S 3.78 W 0.58 S 4.09 W 0.98 S 4.33 W I..S0 S 4.43 W 2.06 S 4.33 W 1.98 N 4.48 W o 64 N 4 42 W L . . 3.21. N 4.65 W 3.58 1'4 5.10 W 3.68 Ixl S.65 W 1.06 N 2.29 W 0 SS N .o 16 W O.OS S '1.92 W 0 7.'-4'-' I 5'7 W 1.47 S 1..08 W 67 o¢' ~.°.94 W 72! S .o 98 W 77-I S .o 59 W S.53 S 1.80 W 97 '-' 0 74 W ,_'_'_'_'_'_'_'_'_'~ . PAID MI WELL. Q-..].TE2!3-36- 12-1.6D !0- 13-B6 DATA INTERPOLATED FOR EVEN 100 FEEl' OF SUBSEA DEPTF1 355~ 3656 3756 3856 395~ 4056 4156 4256 4456 4556 4656 47~ ' 4856 4956 S056 S156 5256 S356 S456 c': ~: S 6 5656 59S6 TRU VERT SUB SEA MD-TVD DE P T H DE P T I,-I D IFF:. 30S'6 3000 0 3.].56 3.'1.00 0 :',c.:.~o 3200 0 :'3. 3 F] 6 33 00 0 3456 3400 0 3558 3500 0 3656 3600 0 3756 3700 0 3856 3800 0 3956 3900 0 4056 4000 0 4 .].56 4100 0 4256 4200 0 4356 4300 0 4456 44OO 0 4556 4500 0 4656 4600 0 4756 4700 0 4856 4800 0 4956 4900 0 S056 SO00 0 SIS6 S100 0 S256 S200 0 S356 5300 0 S456 S400 0 5556 SS 00 0 S6R6 ~-;~ _ .... :~o00 O S ~ ,~,._ 5700 0 I:::;,c-lt:, < t-_:O 0 0 0 =- ~.- ....I '.-.~ t..tt.J S956 5900 0 VE!RT I CAt_. CORRECT 0 0 0 0 0 RELATIVE COORDINATES FROM WEI..L.-HEAD S.98 S 0.48 E S.87 S 1..85 E S.68 S 3.37 E S.41 S S.02 E S. OS S 6.80 E 4.50 S 8.S7 Ei 3.71. S .].0.02 E o 74 S 11. 13 E 1.69 S 11.88 E 0.64 S 1.2.27 E 7.10 S 14.34 E 7.62 S 15.04. E 8.04 S 15.80 E 8.35 S 1.6.61. E 8.56 S 1.7.46 E Il. OS S 16.06 E 11.87 S 16.3S E 12.83 S 1.6.78 E 13.30 S 17.33 E 13.87 S :1.7.99 E :I.S.OS S 1.4.49 E 1S.88 S 13.94 E 16.83 S 1.3.39 E 17.91 S 1.2.86 E 19.11 S 12.37 E °0 44 S 11 9.q E °1 88 S :1.1 60 E 23.39 cS .I.:I.32 E 24.99 :q 1 1.1 I. E 26.67 S 10.98 E PAD MI i:)ATA .I:.NTERPO!_A'fED FOR EVEN ~!1 :].00 FEE-f' 01:: ::_BoEA IDEPTH MEAS. DE P T H 6056 6256 6aS6 64 56 6657 6758 6859 ¢596'.1 7065 7169 7275 7381 7487 7593 7699 780 [5 79 :i 0 o fl :1 8:1 :[9 p:'q2o 8542 8650 8759 8869 8980 'TRU VE:-RI' SUB SEA MD--.TVD DEE P T I.'-I IDF P T I--I D I F F:. 6056 6000 0 6 :l [-3 6 6 :l 00 0 625¢5 6200 0 63r:56 6300 0 64 [56 6400 0 65[5¢5 ¢5[500 :l 6656 6600 :I. 6756 6700 2 6856 6800 3 6956 6900 5 70S6 7000 9 7:1r ,; ," =,~o 7200 :19 7356 7300 25 7456 7400 31 7[3[56 7[300 37 76[56 7600 43 77[5¢5 7700 49 7856 7800 [54 7956 7900 [59 8056 8000 63 8156 8:100 68 8256 8200 73 8356 8300 79 84S6 8400 86 85[:56 8500 94 8656 8600 :I 03 8756 8700 :1:13 88[5¢......5 8800 :!24 8956 8900 :I. 3S VERT I CAI_ CORRECI' 0 0 0 0 0 RELAT I VE C, OOR[] I NATEES FROM WEI..L.-}-IEAD 28.43 S :.1.0.98 E 30.29 S :1:1.22 E 32.2"+ S :1_1..73 E 74. 4.2 :I ...3 :l 2. S 3 E 36.24 S 7.93 F 8 9 :[ 0 :1:1 .13. I 39.39 S [-_i. 29 E-- 0 46.:17 S 1.:11 E .I SS.S2 S '7.4.~+ W I 68.69 S :18.13 W ? 85.60 S 3:1.47 W 4 .'t04.81 S 48.40 W 4 128.19 S 67.00 W 6 .1.54.S7 S 88.49 W 6 :18.'1.9:1 S 1:1:],.93 W 6 209.17 S :136. :16 W 236.:10 S :159.74 W ,_o0.45 S 184_53 W 284.63 S 207.88 W 308.00 S 230.28 W 330.54 S 251.:1.:1 W 3S0.32 S 273.48 W 372.28 S 294.42 W 39~.93 S 320.4~ W 4:1~.84 S 348.9[5 W 434.52 S 379.37 W 456.95 S 423.89 W 482.26 S 450.03 W SOS.9:i S 490.32 W S32.78 S 530.:12 W [553.:!9 S 574.32 W PAD MI WEL. L (~1-;1.7[]23-36--.I. 2-.I.~D .'].0--:13-8¢~ DATA INTERPOLA'FIED FOR EVEN 100 FEET OF SUBSEA DEPTH MEAS. DE P T H 920 :t 93;1. 1 9527 TRU \/EF]'I' SUB SEA MD--TVD VERTI(.'..At_ DEPTH DEPTFt D I FF. E:ORRECT 9056 9000 :1.4S :I0 9 :I SF..; .9:100 :lBS :lO 9256 9200 ].6~ 9 93 5 ¢5 9300 :l 7:1 7 9~.~ 56 9~ 00 .'178 7 RELAT I VE ('.'.OORD I NATES FROM WELl..- HEAD 576.8:1 S S98.29 S 6i9..~S S 636.22 S 6Sl~. ~e5 S 6:1~. 75 W 6.Si+..'].9 W 690.7S W '726.9:1 W 760.68 W 97~:1. 9556 9S00 :18S 7 667.92 S 791+. :19 W PAD MI WEL. L Q..-17E23--36-12--:I6:] 10-:[3-.86 DATA INTERPOLATED FOR EVEN 1000 FE'ET OF: MEASURED DFP'FH MEAS. TRU VERT SUB SEA I3 F P 'F H D E P T H D E P T H :[ 000 :1000 944 2000 2000 :1944 3000 3000 294~+ 4000 4000 3944 '5000 5000 494q, 8000 6000 5944 7000 8994 6938 8000 7942 7886 9000 8874 8828 RELATIVE COORDINATES FROM WEL..L-HEAD 0.2,'5 S 3.60 W 3.64 N 5.88 W 6.0.'1 S 0.23 W O_ 19 S .'12_34 E :l.'+. 6,'+ S iq.. 80 E 27.42 S 10.95 E 92.:18 S 37.87 W 327..'+5 S 248_31W 533.62 S ~39.84 W I~,ker, Iden~:lf lcal:tort 1413 ~J'rD 975O HORIZONTAL VIEW STANDARD ALASKA PRODUCTION CDMPA PAD MI WELL Q-i7123-36-i2-16] CLOSURE: 1040 ft S 50,0 ~ ~DECLINATION: 3i.25 deg E ; !SCALE · ~ inch = 200 feet IDRAN' i0-13-86 ~00 300 4OO 500 600 700 BOO 900 tO00 iiO0 I I i300 iiO0 lO00 900 800 700 600 ~00 400 300 200 lO0 0 lO0 'l ilO0 38.5O T 4400 7t50 BBO0 i VERTICAL SECTION STANDARD ALASKA PRODUCTION COMPA PAD MI NELL ~-I7123-36-i2-i6] SECTION AT S 49.00 N TVD SCALE: 1 inch = ltO0 feet DEP SCALE: 1 inch = ii00 feet DRANN : 10-i3-86 ~r~ I~enttf ication 9750 9~6~ i040 550 tiO0 2'~0 33OO Departure 4400 4950 ~ 60~0 $ UB.S URFA CE DIRECTIONAL SURVEY ~UIDANCE ~ONTINUOUS [-~ OOL Company Well Name Field/Location STANDARD ALASKA PRODUCTION COMPANY 2-62/~-17 MPI (2112'SNL & ~iL34g'WEL~ SEC. ENDICOIT~ NORTH SLOPE~ ALASKA 36~T12N~R16E) Jol3 Reference No. 72008 Logaed B~ WEET Date 10/22/86 Computed 8¥: SINES GCT DZ'RECT~']NAL SURVEY CUSTOMER LISTING ST~NOARD ALASKA PRODUCTZON CO. · ::,~-17 MPZ ENDICOTT NJRT~ SLOPE ,.ALASKA SURVF-Y DAT~: £2-0CT-85 ENGiNE:R: T. W~.ST ,METHODS OF CC,lPUTATZC:N TOOL LOCATION: TA>~JENT!AL- AVERAGES ZNTERP3LATIJN: LZNEAR V;RTICAL SECTION: HORZZ, DIST. PROJECTED OEVIATION AND &ZIHUTrt ONTO A TARGET AZIMUTH OF SOUTH MZN W~ST C~MPUTATIDN C~ATE: ~T-OCT-~6 PA'SE STANOARD ALASKA PRODUCTION CO. Q-17 MPI ENDICOTT NORTH SLOPE,ALASK.4 ZN'TERPOLATED VALUES FOR ".:V:SN 100 FEET OF ME AS DE TRUE SUB-SEA URED VERTICAL VERTICAL PTH DEPTH DEPTH COURSE VERTICAL DOGLEG DEVIATION AZZM!JTH SECTION SEV$'RITY DEG MiN DEG MIN FEET DEG/IO0 0.00 0,00 -55.10 100.00 99,94 44,84 200,00 19'9,94 144,84 300.00 299,94 244.84 400,00 399,94 344,84 300,00 499,94 444,84 600,00 599,'34 544,B4 700,00 699,94 644,84 800.00 799,93 744,83 900,00 899,93 544,83 0 0 N 0 0 E 0.00 0.00 0 16 N 87 8 E -1.10 2.09 0 10 S 11 a3 E -1.21 0.30 0 9 S 82 29 W -0,93 0,29 0 9 N 3 40 W -0.94 0.04 0 3 S 36 25 E -!.03 0.43 0 18 S 35 15 W -0,72 0.02 0 19 S 36 31 W -0,18 0,09 0 1T S 41 32 W 0.35 O,Zl 0 14 N 5~ 51 W 0,61 0.03 lOOO,O0 999,93 944,83 1100,00 1099,93 1044,83 1200,00 1199,93 1144,83 1300,00 1299.93 1244,83 1400,00 1399.93 1344,83 1500,00 1499,93 1444,83 1600,00 1599.93 1544.63 1700,00 1699,93 1644,83 1800,00 1799,93 .1744,83 1900.00 1899.93 1~44.83 0 14 N 55 3 W 0.72 0.04 O 14 N 51 58 W O.:B1 0.03 0 15 N 48 33 W 0.39 0.03 0 13 N 35 6 ~ '3.91 0.21 0 I0 N 45 43 E 0,74 0,52 0 9 N 76 48 E 0,4~, ~..,26 0 10 N 85 43 E 0,21 0,12 '3 9 S 76 ~,~:5 =.. -0.08 0.33 0 15 S 25 0 N 0,15 0,11 0 15 N 25 7 J 0.45 1.63 ZO00.O0 19'99.92 1944,82 2100,00 2099.92 2044,82 2200,00 2199,92 2144.32 2300,00 2299,92 2244,82 2400,00 2399.92 2344,52 2500,00 2499,91 2444,81 2600,00 2599,91 2~4~.81 2700,00 2699,91 2644.31 2800,00 2799,90 274~.$0 2900.00 2899,90 2844,~0 0 12 N 5 ~1 W 0.16 0.13 0 6 N 7~ 45 E 0.05 1.38 0 22 S 5 21 E 0.43 O.21 0 ;7 ~ 7 °l : 0.77 '~ ~3 0 31 S 29 0 W 1,48 0,11 O 29 S ~6 30 W 2,31 0,24 0 31 S 37 i2 w 3,19 0,22 0 14 $ 59 6 ~ 3.66 0,42 0 17 S 20 28 W 4.OB 0.74 O 35 S 54 al [ 4.1.~ 0.08 3000.00 2999,90 2944.83 3100,00 3099.88 3044,75 3200,00 3199,87 3144,77 3300,00 3299,86 3244,76 3400.00 3399,85 3344,75 3500.00 3499.84 34~4,74 3600.00 3599.~3 35~4,73 3700.00 3699.83 3~44.73 3800.00 3799.82 3744.72 3900.00 3899.82 3844,72 0 44 S 79 40 : 3.73 !,17 0 51 N $3 15 ~ 2.48 0.44 0 51 N ~Z 46 ~ 1.18 0,22 0 51 N ;3 ., =6 ~ 0,04 0.13 0 51 N 52 47 ~ -1.29 3.0'9 0 45 N ~4 Z E -2,55 0,32 0 35 S 38 53 : -3,46 0.11 0 26 S ~0 37 E -4,07 0,18 0 24 5~ 57 56 5 -4.51 0,64 0 26 N 50 41 E -:.25 0,08 DATE OF SU.qVEY: 22-:3CT-86 KELLY BUSHING ELEVATION: 55.10 FT ENGINEER: T. WEST MEASURED DEPTh 1.33 N 1,37 W 1,91 N 45 50 ~ 1,58 N 1,45 W 2,15 N 42 26 W 1.03 N 1.47 W 1.80 iq 54 57 W 0.34 N 1.31 W 1.35 N 73 33 W 0.42 S 1.60 W 1.65 S 75 11 W 1.13 S 2.05 W ~.' 37 S 51 28 ~, 1,36 S 2,61 W 3,21 S 54 36 W 2.16 S 2.98 W 3.68 S 54 7 ~ 2.44 S 3.28 W 4.0'9 S 53 22 W 3,11 S 2.80 W 4,1'3 S 42 0 W 3.62 S 1.79 W 4.04 S 26 19 W 3.41 S 0.32 W 3.42 S 5 ZOW 3.19 S 1.2O E 3.41 S 20 42 E 3.32 S Z.65 E 4,03 S ~1 35 E 2.83 S 4,17 E 5.03 S 55 50 :._ ~ ,5q S 5 66 E 6 24 S 65 5 E 2.58 S 6,3? E 7,30 S 69 16 E 2,66 5 7,70 ~ 8,15 S 70 58 ~ ~,° 7~ S 8,36 = 8, 80 S 71 52 ~ 2,32 S B,97 E 9,27 S 73 31 ~ 0.42 S 0.59 W 0.73 S 54 40 W 0.17 S 0.93 W 0.94 S 79 31 W 0.11 N 1,27 W 1,28 N 34 54 W 0.41 N 1,57 W 1,63 N 75 14 W 0,73 N 1,51 W 1,76 N 65 ~1 W 0.80 N 1.33 W 1.56 N 58 53 W 0,87 N 1,04 ~ 1,35 N 49 57 ~.~ 0,94 N 0.71 W 1,18 N 37 10 W 0.87 N 0,96 W 1.30 N 47 50 W 0,93 N 1,41 W 1,69 N 56 34 W 0,00 N 0,00 E 0,00 N 0 0 E 0.51 N 1,C1 E 1.13 N 63 8 i ~.44 N 1.22 E 1.30 N TO 2 E 0.20 N 1.06 ~ 1.08 N 79 23 ; 0.37 N 0.93 E 1.00 N 68 17 0.52 N 0.93 E 1.07 N 50 43 ~. 0,20 N 0.78 E 0,80 N 75 45 ~ 0,24 S 0,46 E 0,52 S 61 47 F- 0,6'9 S 0,14 E 0.70 S 11 11 E 0.66 $ 0,24 W 0,70 S 19 57 W RECTANGULA~ COOP, DINATES HORIZ. DEPARTURE NORTrt/SOUTH EAST/WEST DIST. AZIMUTH FE~T FEET FEET DEG , C 3M PUT A T i ON STANDARD ALASKA PRODUCTION CO. Q-17 MPI ENDICOTT NORTH SLOPE,.ALASKA INTERPOLATEO VALUES TRUE MEASURED VERTICAL DEPTH DEPTH SUB-SEA CgURSE VERTICAL DEVIATION AZIMdTH DEPTH DEG MIN 9:G MIN 4000.00 3999.82 4100.00 4099.82 4200.00 4199.62 4300,00 4299,81 4400,00 4399,~1 4500,00 4499,81 4600,00 4599,81 4700,00 4699,80 %800,00 4799,80 4900,00 4899,80 3944,72 0 25 N 63 9 4044,72 0 22 N 69 27 4144,72 0 16 S 26 36 4244,71 0 18 S 53 59 4344,71 0 18 S 42 1~ 4444,71 0 19 S 39 4 4544,71 0 21 $ 36 12 4644,?0 0 22 S 34 59 4744,70 0 21 S 39 12 4844,70 0 24 S 37 56 5000,00 4999,80 5100,00 5099,79 5200,00 5199,79 5300,00 5299,78 5400,00 5399,78 5500.00 5499,77 5600,00 5599,76 5700,00 5699,75 5800,00 5799,75 5900,00 5099.74 6000,00 5999.73 6100,00 6099.72 6200,00 6199,70 6300.00 6299.6~ 6400,00 6399,68 6500,00 6499,65 6600.00 6599.53 6700,00 6699,07 6800,00 6798,!5 6900,00 6896,56 7000,00 6994.10 7100,00 7090.77 7200,00 7186,2~ 7300.00 7280.62 7400,00 7374,68 7500,00 746~,50 7600,00 7562.76 7700,00 7657.20 7800,00 7751.91 7900.00 7~46,95 4944,70 0 27 S 36 5044,6'9 0 25 S 35 5144,69 0 31 S 37 5244.6'~ 0 34 S 31 5344,65 0 31 S 30 ~444,67 0 .41 S 26 5544,66 0 45 q 24 5544,66 0 42 ~ 22 5744,65 0 47 S 20 5844.64 0 48 S 21 5944.63 0 4~ S IS 604~,62 0 52 S 15 6144.50 0 55 S !9 ~244.59 0 ~9 S 27 ~344,5~ i 0 S 36 6544.43 3 56 S ~4 6643,97 6 31 S 35 6743.05 m Se S 37 5841.46 !1 13 S 39 6939.00 13 a9 S 29 7035.67 15 54 S 38 7131,1.9 i6 14 S 3'9 7225,72 19 41 S 41 7319.5.5 lO 1~ S ~! 7413,4~ 19 54 S 41 7507.66 1'~ 23 S 42 7602.10 18 5~ S 43 7696.81 1~ 23 $ 43 7791.85 17 47 S ~ DATE: 27-9CT-86 FOR EVEN 100 V.=.~T!CAL S~_CTIDN FEET = -= 97 -6,6v W -6,70 W -6,22 W -5.70 -5,12 W -4,53 W - 3.90 W -3.24 W -2.55 ~3 W -1 80 45 W -0.98 S W 0.13 33 W O. 80 30 W !,75 ,~ W 2.83 55 W 3,97 49 W 5,12 34 W 6,26 0 W 7,38 ~ W $ .61 10 ',,~ 9. ~ 9 2 ~ 11.26 :2~i W 12.72 14 W 14.16 15 W 16.34 AB W 21.0~ 42 W 30,20 6 'W *3 · 36 iOw 60,81 15 w 82.48 27 W 107.62 5 W 135.70 25 w 158.94 47 W 203,16 40 W 237,27 .S W 27~.61 4 W 303.2'9 51 w 335.23 53 W 366.24 FE~T DF M'~ASURE DOGLEG RECTAN SEVERITY NgRTH/ D£G/IO0 FEE ,3.21 1. O.!B , 1. 0,20 1, 0.09 2. 0.11 2. 0,04 3. 0.03 3. 0,07 4, 0.06 4, 0,11 5, 0,30 5 · 0 · 3'~ 6. 0.1~ 7. 0,13 7, 0.26 0 · 13 9 · $ · 11 10, 0,09 12, 0 · 22 13 · 1,15 14. 0.30 15. S,~9 17, 0.49 10. 0.46 20. 0,67 21. 2,48 23. 3.24 27. 2..5 35. 2.44 46, 4,20 60, 2.14 77. 2.47 96. I .85 120. 1.10 144. 0.76 170. 0.55 196 0.53 221. 0.52 245. 0.72 268. 1.02 291. P AG~ 2 ATE DF SURVEY: 22-0CT-86 ELLY BUSHING ELEVATION: 55.10 F'T ENGINEER: T. WEST D DEPTH GULAR COORDINATES HDRIZ. DEPARTURE SDUTh E~ST/WEST DIST. AZIMUTH T FEET FEET DEG MIN 96 S 9.62 E 9,81 S 78 29 ~ 56 S 10,21 E 10,34 S 80 47 E 76 S 10,40 E 10,55 S $0 24 E 20 S 10,15 E 10,38 S 77 4.5 : 61 S 9.82 E 10,16 S 75 5 08 S 9,45 ~ 9,94 S 71 58 .. 55 S 9.0~ ~ 9.75 S 65 39 ~z 07 ,S 8,71 E 9,62 S 64 57 ~ 53 S 5.32 E ~.52 S 50 54 ~ ZO S 7,90 E '9,45 S 56 3~ E 80 S 7,43 E 9,42 S 5.2 0 E 50 S 6,94 E 9,51 S 46 53 E 18 S 6,42 ~ 9,63 S 41 47 E 98 S 5.88 E 9.91 S 36 23 i 85 S 5.37 E 10.35 S 31 15 E $7 S 4,83 ~ 10,98 S 26 5 d 97 S 4.28 E 11.78 $ Z1 19 E 13 S 3,76 E 12,70 S 17 13 f 32 S 3.29 E 13.72 S 13 51 E 49 S 2.62 E 14,76 S 11 1 E 91 S 2.42 i 1.5,09 31 S 1.95 E 17,42 84 S 1.46 E 1~.89 38 S 0.~5 5 20.39 62 S 0.02 E 21,62 44 S 1,27 W 23,4e. 55 S 3.98 W 27,.~3 34 S 9.30 W 35.54 09 S 17.39 W 49.26 0c., S 28.38 W 65.41 S 8 39 E S 6 ~5 ; S 4 25 E S ~ ~3 f S 0 2 ~ S 3 6 S .~ 13 ,,~ S 14 ~ W S 25 17 W 06 S 42.29 W 87.91 S ~3 45 W 94 S 53.34 w 113.14 S 31 2 W 08 S 76,75 W 142,51 S 32 35 W 95 S 97,34 W 174,5~ S 34 1 W 64 S 120.85 W 209,10 S 35 1.3 W 32 S 1~3,72 W 243,31 S 36 12 W 3~ S 166,12 W 276,78 S 36 52 w 57 S 185,40 W 309,51 S 37 29 W 88 $ 210,~ W 341,44 S 38 3 14 S 232,19 W 372,39 S 38 34 W COMPUTATION DATE: 27-8CT-86 PAGE 3 STANDARD ALASKA PRODUCTION CC. ~-17 MPZ ENDICOTT NORTH SLOPE~ALASKA INTERPOLATED VALUES FOR TRUE MEASURED VERTICAL DEPTH DEPTH SUB-SEA COURSE VERTICAL DEVIATION AZIMUTH DEPTd DEG MIN g=G MIN 8000,00 7942,37 8100,00 8038.25 8200,00 8134,25 8300,00 8229,57 8400,00 8324,11 3500.00 8~18.03 8600,00 8511,03 8700.00 8603.06 8800.00 8694.25 8'900.00 8784.42 ~7887.27 16 59 S 46 5 7983.15 16 7 S 47 12 8079.15 16 48 S 43 30 8174.47 18 22 $ 50 9 8269.01 19 31 S ~2 35 ~362.93 20 46 S 55 ~ 8455.93 22 18 S 56 10 8547.96 23 38 S ~7 4 3639,15 24 54 S 57 29 8729,32 26 10 S 58 13 9000.00 8874.09 9100.00 8963,97 9200.00 9054,.05 9300,00 9144.88 9400.00 9236,78 9500.00 9329.48 9600.00 9423.15 9700.00 9~17.69 9800.00 9613.01 9900.00 9708.69 8818.9~ 26 6 S 59 ~ N 8908.87 25 54 S 59 39 W 8998.95 25 26 S 59 53 W 9039.79 23 52 S 61 17 W 9181.68 22 40 S 62 ~ W ~274.38 21 23 S 63 15 W 9368,05 19 39 S 65 9 W 9462.59 I~ 20 S 66 30 N 9557.91 17 7 S 67 38 W 9653.59 16 36 S 69 13 W 10000.00 9804.68 10100,00 '9900,~0 10200.00 9996.95 10300,00 10093.14 10400.00 10189.43 10500.00 10285.80 10600.00 10382.43 10700.00 10479.13 10500.00 10575.66 10899.00 10671.17 'W7~9.53 16 5 S 70 37 W 9845.70 15 54 S 70 41 W 9941.85 16 0 S 70 36 W 10038.04 15 34 S 71 4 W 10134.38 15 46 $ '71 I1 W 10230.70 15 8 S 73 19 W 10327.33 14 45 S 74 39 W 10424.04 14 55 S 75 25 W 10520.~,=5 ~,~ ~ 15 S 75 ~ w 10616.07 15 15 $ 75 j w DATE OF SURVEY: II-OCT-86 KELLY BUSHING ELEVATION: 55.10 FI ENGINEER: T. WEST EVEN 100 F~ET OF MEASURED DEPTH V~RTICAL DOGLEG RECTANGULAR SOCTION SEVERITY NORTH/SOGTH FEET SEG/IO0 FEET COORDINATES MORIZ. DEPARTURE EAST/WEST 915T. AZIMUTH FEET FEET OEG MIN 39~,11 0,99 312,'10 424.43 .2,55 331,57 452.48 1.51 350,38 482,70 1,47 370,09 ~15,23 1,42 390,44 5~9.42 1.76 410.53 5d5.92 1.57 431,30 624.69 i.ll ~52.52 565.29 1.44 474.94 70~.01 0.97 498.02 S 25 S 27 S 29 S 31 S 34 S 37 S 40 S 43 S 46 S bO 3.55 W 402,11 S 39 5 W 4,21 W 430,27 S 39 35 W 4.96 W 458,01 S 40 5 w 7.88 W 487.86 S 40 3~ " 3,28 'W 519.89 S 41 19 1.03 W 553.43 S 42 5 ~ 1.43 W 589.21 S 42 56 W 4.09 W 627,28 S 43 47 W 5.65 W 667.24 S 44 37 W 5.20 W 709.40 S 45 24 W 75!.63 0.42 521.02 794.7~ 0.29 543.30 ~,37.43 1.09 565.19 8'78.40 !,61 5.~5.76 ~16.84 1.24 604,45 953.32 1,67 621.74 987,04 1,4'7 635.92 1019.23 1.5'3 650.25 1047.03 0.72 552.07 1074.40 0.87 672.76 S 54 S 58 S 61. S 65 S 58 S 72 S 75 S 78 S ~1 S 83 3.00 W 752.54 S ~6 11 W 0.76 W 795.27 S 46 54 W '3.29 W 837,69 S 47 34 W 4.69 W 878.49 S 4:5 10 W 9.38 W 916.35 S 48 45 W 2.70 ~ 953.34 $ 4'9 17 W 4.18 W 987.14 S 49 49 W 3.91 N 1018.50 5 50 19 N 1.;50 W 1047.5, S 50 48 W 8.78 W 1075.25 S 51 16 W 1100.5~ 0.10 ,582.31 S 1126.21 0.14 691.45 S 1151.7~ 0.29 700.58 S 1177.12 ' 0,63 709.56 S 1201,93 0.DB 713.17 S 1225.73 1.00 726.53 S 1250.03 0.61 733.55 S 1272.$8 0.76 740.14 S 12%6.33 0.00 746.76 S 1319,74 0.00 753.47 .S 89 91 94 96 99 101 104 106 109 5.15 W 1101.8~ S 51 44 W 1.1a W 1127.96 S 52 11 W 7.09 W 1154.06 S 52 37 W 2.89 W 1180.04 S 53 Z N 8.28 W 1205.34 S 53 ~6'~ 3.~6 W t231.10 S 53 49 8.6a W 1255.28 S 54 14 i~ 3.20 W 1279.09 S 5~ 38 W 8.51 W 1303.59 $ 55 3 W 3.b9 W 132~.i1 '$ 55 26 ,~ COHPUTATZDN DATE: 27-0CT-86 PAG~ 4 .STANDARD ALASKA PRODUCTION CS. r4-17 MPI ENDICOTT NORTH SLOPE,ALASKA INTERPOLATED VALUES F3R =YEN 1003 FEET DF TRUE SUB-SEA MEASURE9 VERTICAL VERTICAL DEPTH DEPTH DEPTH CJURSE VERTICAL DJGLEG DEVIATIDN AZIMUTH SECT'ON SEVERITY DEG MiN 2:G MZN ~EET DEG/IO0 0.00 0.00 -55.10 1000.00 999.93 944.83 2000.00 1999.92 194~.82 3000.00 29'99.90 2944.~0 4000.00 3999.8£ 3944.72 5000°00 49'99.80 4946.70 6000.00 5999.73 5944.63 7000.00 6994.10 6939.00 6000.00 7'942.37 78~7.27 9000.00 8874.09 8816.99 0 0 N 0 0 b 0.00 0.30 0 14 N 55 3 W 0.72 0.04 0 12 N 8 41 W 0.16 O.I'B 0 44 S 79 40 E 3.73 1.17 0 25 N 63 9 E -5.97 0.21 0 27 S 35 22 ~ -!.80 0.30 0 48 S 1~, ~ W :3.61 0.30 13 49 S 39 16 W 82.48 2.14 16 59 S 46 5 W 396.11 0.99 26 6 S 59 8 W 751.63 13.42 10000.00 9804.68 9'749.58 16 5 10899.00 10671.17 10615.07 15 15 S 70 37 ;4 1100.58 0.10 S 75 5 '~ 1319.74 0.00 DATE ~F SURVEY: 22-0CT-86 KELLY BUSHING ELEVATION: 55.10 FT ENGINEER: T. WEST t. IEASUR2D CEPT RECT.&NGULaR COORDINATES HORIZ. DEOARTUR~ NORTH/SOUTH EAST/WEST GIST. AZIMUTH FEET F-ET FEET DEG MIN 0.00 N 0.00 E 0.00 N 0 O E 0.42 S 0.59 W 0.73 S 54 40 W 1.33 N 1.37 W 1.91 N 45 50 W 3.62 S 1.79 W 4.04 S 26 19 '" 1.96 S 9.62 E 9.81 S 78 2',9 5.80 S 7.43 E 9.42 S 52 0 · 15.91 S 2.42 ~ 1,5.09 S ,3 39 : 77.06 S 42.29 W 87.91 S 2~ 45 W 312.10 S 253.55 W 40~.11 S 39 5 W 521.02 S 543.00 W 752.54 S 46 11 W 682.31 S 855.15 W 1101.84 S 51 44 W 753.47 S 1093.69 w 1323.11 S 55 25 W CO~PUTATiON OAT'--: 27-DCT-86 STANDARD ALASKA PRODUCTIDN CD. Q-IT MPI ENDICOTT NORTH SLOPE,ALASKA iNTERPOLATED VALUES POR EVEN 100 :EET OF TRU- MEASURED VERTICAL DEPTH DEPTH SUB-SEA CCUmSE~ V~RTICAL,_, .... DOGLEG VERTICAL DEVIATION AZIMUTH SECTION SEVERITY D~PTH DEG MIN DEG MIN F~ET OEG/iO0 0.00 0.00 55.16 55.10 155.16 155.10 255.15 255.10 355.16 355.10 455.16 455.10 555.15 555.10 655.16 655.10 755.16 755.10 855.17 855.10 -55.10 0 0 N 0 0 ~ 0.00 0.00 0.00 0 50 N 47 52 E -3.52 0.92 100.00 0 6 S ,55 55 E -1.23 0.50 200.00 0 i1 S 33 0 W -!.07 0.33 300.00 0 8 N 25 20 W -O.B8 0.39 400.00 0 5 N ~: 44 E -1.0~ O.ZO 500.00 0 14 S 25 30 W -0.93 0.37 600.00 0 18 S 36 31 w -0.43 700.00 O 19 S 35 54 W 0.11 0.10 800.00 0 14 N 5'9 30 W 0.55 0.07 955.17 955.10 1055.17 1055.10 1155.17 1155.10 1255.17 1255.10 1355.17 1355.10 1455.17 1455.10 1555.1'7 1555.10 1655.17 1655.10 1755.17 1755.10 1855.17 1855.10 900.00 0 15 N 57 13 W 0.68 0.15 1000.00 0 14 N 52 42 W 0.77 0.0.5 I100.00 0 15 N 4~ 52 W 0.85 0.06 1200.00 0 14 N 44 53 W 0.91 0.06 1300.00 0 11 N ,5 50 w 0.8~ 0.16 1400.00 0 10 N 72 23 E 0.58 0.1'3 1500.00 0 'i0 N 77 26 ~ 0.32 0.07 1600.00 0 12 N 73 39 ~ 0.04 0.05 1700.00 0 15 S ~8 0 ~ -0.01 0.24 1800.00 0 15 N S5 11 W 0.35 0.02 1955.18 1955.10 2055.18 2055.10 2155.18 2155.10 2255.18 2255.10 2355.18 2355.10 2455.19 2455.10 2555.19 2555.10 2655.19 2655.10 2755.1~ 2755.10 2855.20 2855.10 2955.20 2955.10 3055.21 3055.10 3155.22 3155.10 3255.24 3255.11 3355.25 3355.10 3455.25 3455.10 3555.27 3555.10 3655.27 3555.10 3755.27 3755.10 3855.28 3855.10 1900.00 0 14 N 7 39 ~ 0.27 0.13 ;000 O0 0 8 N 17 ~o W 0 O~ 0 13 2100.00 0 21 S O 6 ~ 0.26 0.11 2200.00 0 24 S 14 6 ~ 0.61 0.2~ P~00 O0 0 PS q 79 i !.I I 1> 0 2400.30 0 2~ S 35 3% 'N 1.95 0.19 2500.00 0 30 S 36 29 W 2.50 0.09 2600.00 J 9 S &3 55 W 3.52 0.56 2700.05 C 1~ S 47 11 W 3.89 0.15 2,~00.00 0 33 S 41 50 ~ 4.22 0.33 2900.00 0 40 S 53 58 ~ 3.93 0.25 3000.00 0 54 N 76 23 2 $.06 0.42 ~100 O0 0 5' ~ N DO 5 ~ ~ ! 74 0.2 ~P200.O1 0 49 ~,, ~.~ 32 =: v.~ 50 0.13 3300.00 O 52 N 52 13 : -3.73 3400.00 0 53 N 81 55 ~ -£.00 0.15 3500.00 0 33 N 87 47 ~ -3.09 0.22 3600.00 0 29 S 54 12 ( -3.83 0.16 3700.00 0 23 S 7e, 3 ~ -4.32 0.32 3800.00 0 25 N .,:5 32 =- -4.92 0.17 PAGE DATE DF SURVEY: 22-0CT-86 KELLY BUSHING ELEVATION: 5 55.10 fNGINEER: T. WEST SUE-S~& D~PTH R~CTANGOLAR NGR'TH/SOdTH FEeT 0.00 N 0.25 N 0.53 N 0 · 2 '7 N 0.25 N 0.50 N 0.35 N 0.0~- S 0.50 S 0.76 S O.F3 S 0.29 S 0.02 S 0.23 N 0.59 N 0.78 N 0.56 N 0.91 N 0.$9 N 0,~S7 W CO'ORDiNATES HORIZ. DEPARTURE EAST/WEST DIST. AZIMUTH FEET FEET DEG MIN 0.00 2 0.00 0.60 E 0.65 1.17 E 1.29 1.18 E 1.21 0.94 E 0.98 0.91 E 1.04 0.90 'E 0.98 0.50 E 0.61 0.28 E 0.57 0.08 W 0.7~ 0.44 W 0.59 0.75 W 0.83 1.12 W 1.12 1.45 W 1.48 1.63 w 1.74 1.45 w 1.65 1.17 W 1.45 0.~5 W 1.25 0.76 W 1.17 1.22 W 1.50 N 0 0 E N 67 10 E N 65 26 E N 77 12 N 75 2 ' N 61 19 -- N 67 S ~5 49 E S 29 28 5 S 6 14 W S 39 47 w S 69 42 ~ S 89 6 W N 79 8 W N 70 5 W N 61 41 W N 53 51 W N 43 2 ~ N 40 23 W N 54 23 W 1.16 N 1.50 N 1.32 N 0.6,5 N 0.09 S 0.~4 S 1.53 S 2.10 S 2.29 S 2.:i2 S 3.43 S 3.51 S 3.27 S 3.09 S 2.91 S Z.71 S 2.5~ S 2.61 S 2.75 S 2.49 S 1.37 W 1.79 1.41 W 2.06 1.49 W 2.00 1.39 W 1.54 1.41 w 1.41 1.d~ w 2.0~ 2.38 W 2.83 2.84 W 3.53 3.17 W 3.91 3.15 W 4.22 2.29 W 4.12 1.00 W 3.65 0.54 E 3.32 2.03 E 3.70 3.50 ~- 4.55 5.01 ~ 5.70 5.34 E 6.85 7.35 E 7.80 8.11 E 8.57 8.68 E 9.03 N 49 44 W 43 12 W 48 23 W 64 27 W 3,5 29 55 43 57 13 W 53 27 W 54 3 W 43 9 ',.~ S 33 4a w 15 5,5 w 924i S 33 16 E 50 i2 ~- Ol 34 E 57 50 5 70 26 ~2 71 17 E 74 0 i COMPUTATION STANDARD ALASKA PROOUCTION CO. Q-17 MPi ENDICOTT NORTH SLOPE,ALASKA D'~TE: 27-007-86 TRU~ MEASURED VERTICAL D~PTH DEPTH 'INTERPOLATED VALUES F"2R EV=N 100 FEET OF 3955.23 3955.10 4055.28 4055.10 4155.29 4155.11 4255.29 4255.11 4355.29 4355.10 4455.2'9 4455.10 4555.29 4555.10 4655.29 4655.10 4755.30 4755.10 4855.30 4855.10 SUB-SEA COURSE VERTICAL DOGLEG VERTICAL DEVIATION AZIMUTH SECTION SEV=RITY DEPTH DEG MIN D~G MIN FEET OEG/IO0 4955.30 4955.10 5055.31 5055.10 5155.31 5155.10 5255.31 5255.10 5355.32 5355.10 5455.33 5455.10 5555..33 5555.10 5655.34 5655.10 5755.35 5755.10 5855.36 5855.10 3900.00 0 24 N 59 ! E -5.65 0.30 4000.00 '0 22 N 51 ~ 5 -5.35 ,3.23 4100.01 0 ~ S !.2 27 W -5.84 1.30 4200.01 0 17 S 30 47 w -6.44 0.03 4300.00 0 18 S 38 19 N -5.93 0.15 4400.00 0 21 S 36 1~ ~ -5.38 0.10 4500.00 0 21 S 3'7 9 W -4.80 0.05 4600.00 0 22 S 35 2 ,4 -4.1'9 0.i0 4700.00 0 24 S 33 35 W -3.53 0.09 4800.00 0 .~5 ~ 35 17 W -~.87 0.04 5955.37 5955.10 6055.3B 6055.10 6155.39 6155.10 6255.40 6255.10 6355.42 6355.10 6~55.43 6455.10 6555.50 6555.10 6655.7~ 5,555.10 6756.47 6755.10 6S57.78 $855.10 ~900.00 0 25 S 3~ 45 ~ -2.1~ 0.17 ~.O00.O0 0 32 S B4 ~'~1 W -1._~4 0.1~_. 5100.00 0 30 S 37 15 N -0.53 0.27 5200.00 0 34 S 33 17 W 0.37 0.10 5300.00 ,$ 3,5 S 20 2 W 1.35 0.33 5400.00 0 42 S 27 14 w 2.3'2. 0.38 5500.00 0 41 S 26 34 W 3.45 0.06 5600.00 0 45 $ 24 50 W 4.62 0.20 5700. O0 0 43 S 22 ~°1 W ~.= 73 0 · 33 5800.00 0 ~0 S ~? >5 W 6.90 0.67 6959.91 6955.10 7062.9'9 7055.10 7167.2,S 7155.10 7272.71 7255.i0 7379.09 7355.10 7485.56 7~55.10 7591.$~ 7555.10 7697.78 7655.10 7~03.36 7755.10 7908.56 7~55.10 5900.00 C 51 S 14 1,5 ~ '~.06 0.36 600,D.00 0 5'0 .S 1~ 30 W 9.31 0.2~+ 6100.00 0 5~ S 19 5 W !0.64 0.32 .5200.00 0 57 S 20 53 W 12.10 0.4! 6300.00 0 51 S 3~ 30 '~ 13.4~ 3.35 6400.00 i 17 S 35 i0 ',,l 15.25 6300.00 2 57 S ?,3 16 W i8.51 2.50 o~00.00 5 42 S 33 55 W 25.63 2.96 6700.C, 0 7 50 S 3,~_. 55 W 37.1~_ _.T~ 6.5 aclO0.O0 10 29 ~ 3d 21 ~4 52.95 2.58 6900.00 12 55 S 39 14 W 73.31 2.34 7000.00 15 4 S 3~ 49 W ')7.94 2.11 7100.00 17 36 ~ Ed 35 W 126.73 2.20 7200.00 19 22 S 40 5i W 159.~9 1.51 7300.00 20 20 S 41 52 W 155.91 0.59 7400.00 1 ~ PT S 41 J9 W 232.43 0.55 7500.00 19 25 S 42 4 w 267.94 0.55 7500.0,3 I~ 59 S ~3 3 ,~ 302.57 0.51 7700.00 16 22 S 43 53 W 336.28 0.70 7800.00 17 42 S 45 0 W 36~.~5 0.96 PAGE 5 DATE ~F SURVEY: 22-007-B5 KELLY 3USHiNG ELEVATION: 55.10 FT ENGINEER: T. WEST SUE-SEA DEPTH RECTANGULAR NORTH/SOUTH FEEl COORDINATES HORIZ. DEPARTURE EAST/WEST DIST. AZIMUTH FE~T FEET DEG MIN 2.11 S 1 · 78 S 1.64 S 2.00 S 2.44 S 2.B7 S 3.33 S 3.83 S 4.39 S 4.94 S 9.32 E 9.56 S 77 15 "~ 9.95 E 10.11 S 79 5,2 E 10.45 E 10.61 S 81 6 ~2 10.27 E 1J.46 S 7~ 5:9 c 9.97 E 10.27 S 76 1~ 9.62 E 10.04 S 73 23 '9.25 E 9.83 S 70 13 ~ ~.~8 E 9.67 S 66 39_ E ~.50 E 9.57 S 62 40 ~ 8.09 E 9.48 S 55 35 ~ 5.52 S 5.18 S 6.86 S 7.60 S 8.48 S 9.38 S 10.46 S 11.63 S 12.76 S 1~ .01 S 7.54 E 9.~3 S 54 '~ E 7.15 E 9.45 S 49 10 E 6.66 E 9.56 S 44 9 E 5.12 E 9.76 S 38 50 E 5.59 ~ 10.16 S 33 23 E 5.08 E 10.66 S 28 25 E 4.53 E 11.40 S 23 24 E 3.9'9 5 12.29 S 18 56 ~ 3.50 f 13.23 5 15 gO ~ 3.03 E la.34 S 12 12 5 15.27 16.67 18.17 19.74 21.04 22.51 25.37 31.46 41.0~ 53.~3 2.59 E 15.4~9 S 9 37 Z · 15 1.6'9 1.13 E 1:~.77 S 3 17 E 0.43 E 21.05 S 1 10 0.64 'd 22.52 S 1 37 2.4~ W 25.49 S 5 34 6.02 W 32.15 S 11 52 W 13.54 23.37 W 5:3.6'5 S 23 27 W 59.67 89.2q I12.15 138.08 165.20 192..58 245.04 2,59.~4 292.99 35.39 W 75.78 S 27 30 W 52.20 W 103.35 S 30 19 w 70.40 w 132.44 S 32 5 w 91.d3 W 163.83 S 33 37 ~q 115.97 W 201.64 S 35 4 W 140.4o W 235.45 S 36 5 W 154.32 w 274.0~ $ 35 50 W 157.90 W 30~.79 S 37 28 ;~ 211.18 W 342.50 S 3~ 4 W 234.03 W 374.99 S 3B 37 W CCMPUT~TiON D&TE: 27-0CT-56 PA'S~ 7 STANDARD ALASKA PRODUC'TZON Q-17 MPI ENDICOTT NORTH SLOPE,ALASKA TRUE MEASURED VERTICAL DEPTH DEPTH 8013,31 7955,10 8117,54 8055,10 $221,79 5155,10 8326,94 8255,10 8432,91 8355,10 8539.73 8455.10 8547.75 $555.10 8756.94 B655.10 8867.37 8755.10 8978.84 8855.10 9090,13 8955,10 9201,17 9055,10 9311.16 9155,10 9419,84 9255,10 9527.47 9355.09 9633,87 9455,09 9739,34 9555,10 9844.03 9655.10 9948.39 9755.10 10052.47 9855.10 10156,46 9955.10 10260,48 10055,10 10364,25 10155,10 10468,1.3 10255.10 10571,73 10355.10 10675.14 10455.10 10778.69 10555.10 10882.34 10655.10 10899.00 10671.17 iNTERPOLATED Sus-S A VERTICAL DEPTH 7900,00 16 51 8000,00 16 4 8100,00 17 8 8200.00 18 43 8300.00 19 53 6400.00 21 23 8500.00 23 1 8500.00 24 19 8700,00 25 49 8800.00 26 10 8900 O0 9000.00 25 25 9100,00 23 41 9200.00 22 26 9300.00 ZO 54 9399,99 19 12 9500.00 17 45 9600,00 15 54 9700,00 16 17 ~800,00 16 0 9900.00 !5 57 10000.00 15 47 lOlOO.O0 15 35 10200.00 15 28 13300.00 14 52 10400.00 14 47 10500.00 15 15 10600.00 15 15 10616.07 15 15 VALU~S FOR COURSE DEVIATION AZIMUTH DEG MIN OEG S 46 15 W .S 47 22 w S 48 50 w S 50 43 W S 53 31 W S 55 42 w S 55 34 W S 57 25 w S 57 52 W S 5S 57 W 59 59 61 63 65 66 68 7O 7O 37 W 53 N 23 W 49 W 39 W 55 w $ w S 70 33 w S 70 50 w S 71 i5 W S 72 21 w S 75 i! w S 75 5 W S 75 5 ~ S 7=., 5 W YVEN 100 FEET OF V~RTiC&L DOGLEG SECTION SEV=RITY =EET DEG/IO0 399,96 1.04 429.33 0.42 45~.82 1,70 491,30 1.40 ~26.29 1.47 563.54 1.4~ 604,16 1,46 547.57 1,30 693.86 1,43 742,45 0,57 7~0,50 0.27 537,92 1,12 ~82.78 1.60 ~24,25 1,27 962,91 2,31 9'97.85 1.3~ 102q.83 1,47 1059,21 0,57 !087,22 0,75 1114,08 0,24 1140,59 0.28 1167.20 0.55 1192.9~ 0,61 1219.06 1.53 124'3.50 O.ld 1267,17 0.55 1291.29 0.00 1315.80 O.O0 131'5.74 O.OO DATE 'OF SURVEY: 22-0CT-36 KELLY BUSHING ELeVATiON: ~NGZN~ER: T, WEST 55,10 FT SUB-SEA DEPTH RECTAN N$RTH/ 314. 334. 354. 375. 397, 418. 441. 465, 490, 516, 541. 5~5. 587. 608. 626. 641, 555. 665. 677, 687, 696, 706. 715. 724, 731, 738, 745. 752. 753. GULAR C03ROINATES HORIZ. SOUTH =AST/WEST DIST. 'T FEET FEET 76 S 256,33 W 405,93 87 S 277,'77 W 435,08 57 S 299,72 W 464,28 56 S 324.51 W 496.34 11 S 352,14 W 530,75 7~ S 382.82 W 567,36 49 S 416.74 W 607.11 32 S 453.54 W 649.79 44 S 493,03 W 695,43 22 S 535,01 W 743,45 11 S 577,04 ~ 791.06 44 S 618,72 W 838,18 91 S 658,63 W 882,85 O1 S 696,11 W 924,25 15 S 731.57 W 962,94 61 S 754,42 w 99~,00 05 S 795,10 W 1030.19 91 S 523,73 W 1059,56 52 S 951.62 W 1088.25 13 S 873.85 W 1115,58 57 S 905,78 W 1142,65 05 S 932,79 W 11~9,87 05 S 959,14 w 1195.35 06 S 985..35 W 1223.16 61 S 1011.67 ~ 124~.49 52 S 1037,04 w 1273.13 32 $ 1063.09 W 129~.32 34 5 !0~9.~5 ~ 1323.9~ 47 S 109~.69 W 1328,11 DEPARTUR~ AZIMUTH DES MIN S 39 S 39 40 W S 40 12 W S 40 4'.~ S 41 33 , S 42 26 s 43 zo S 44 15 W S 45 9 W S 46 1 W S 46 50 W S 47 34 W S 48 14 N S 48 51 W S 4'9 26 W S 4'9 59 W S 50 30 W $ 51 0 W $ 51 29 W S 51 55 W S 52 25 W S 52 52 w S 53 17 W S 53 42 ~q S 54 7 S 54 32 S 54 57 w S 55 22 W S 55 26 w STANOARD ALASKA PROOUCTION CO. Q-i7 MPI ENOICOTT NORTH SLOPE,ALASKA INTERPOLATED COMPUTATi3N VaLUeS MARKER DAT~: £7-CCT-86 CHOSEN ffJRIZONS ORIGIN: 2112 TVO KB SUa-SEA PAGE 8 DAT5 OF SURVEY: 22-0CT-86 KELLY BUSHING ELEVATION: 55.10 ENGINEER: T. WEST ~T SNL, SURFACE LOCATION ~T 2350 WSL, S~C. 36, T12N, R16~, RECTANGULAR CGORDIN.~TES NORTH/SOUTH EAST/WEST TOTAL DEPTH 10899.00 10671.17 10616.07 753.47 S 1093.69 W CD.MFUTATION DAT;-_:: :9 STANDARD .ALASKA PRODUCTION CO. ~-17 MPZ ENDICOTT NORTH SLOPE,ALASKA STR~TiGR~PMi, C MARKER TOTAL DEPTH MEASURED DEPTH 10899.00 ZT-'DCT-85 SUMMARY 10671.17 PAGE DATE CF: SURVEY: 22-'JCT-86 KELLY ...BUSHING ELEVATION: ENGINEER: T. WEST 55.10 FT SURFACE LOCATION AT ORIGIN: 2112 SNL, 2350 WEL, SEC. 36, T12N, R16E, TVD R~CTANGULAR COORDINATES SUB-SEA NORTH/SOUTH EAST/WEST 10616.07 753.47 S 1093.69 W FINAL MEASURED DEPTH WELL LOCATION AT TD: TRUE SUB-SEA VERTICAL VERTICAL DEPTH DEPTH H 3 R I :..= N T ~ L ~; ~ P A R T U k L= DI STANC~ AZ I MUTH ~£~T DES MIN 10899.00 10571.17 10816.07 132r3.11 S 55 26 W SCHLUMBEROER O I REC T I ONAL SURV E Y COMPANY STANDARD AiASKA PRODUCTION COMPANY WELL 2-62/Q-17 MPf FIELD COUNTRY USA RUN DATE LOGGED ocz. 22, 1986 REFERENCE FSIA. WELL' 2-62/Q-17 MPI (2112,'SNL & 2349'W~ SEC.36,T12N,R16E) ~RIZONTAL PROJECTION NORTH 60O 400 2OO _zOo -400 -600 -800 SOUTH -1000 -IZOD WEST REF FSIA. SCALE = ]/200 IN/FT ..4-.;.-..:....:...,..4-.-~....:-~..~.A-4..4..4:..i...L.L4_.~ ...... L.1...1..4...;...L.L4...L. -4-4-.~...;-.-~...~...~..--;-.; ....... -:.-L.~...i-.,'-.L4...1..4 ...... L4-4.-4...:..4...1...L.~ ....... L.:,...L.L,[...~ ....... 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' ;.- 4-4.-44- -; 4 ~ ~ ~ ~ 4. ; ~ ~ 4.-: ,t 4. ~ 4 ; - : ;...~.. 4.~...:...~ -t.-..;i i i i'4' -.; ....I i~: :::::::::::::::::::::::::::: q:::q:: ::::::: ::::::::::::::::::: :::::::::::::::::::::::::: :::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: -1000 -800 -600 -400 -200 0 ZOO 400 ERST WELL: 2-62/Q-17-MPI (2112-'SNL & 2349'WF~' SEC.36,T12N,R16E) ~ ~ICAL PROJECTION 49 -]SO0 -]000 -SO0 0 0 SO0 PROJECTION ON VERTICAL PLANE 299. - 49. SCALED IN VERTICAL OEPTH$ HORIZ SCALE = I/SO0 IN/FT ?SOO ,v EMORAN 'UM ALASKA Oi~AND GAS CONSERVATION CO~R~IS~_~DIq C. ~V. C~~~9~ DAI~: October 1, ChJi~a~ ~ ~t~ No.. D .BDF. 74 Lonnie C. Smith ;~ .~> TELEPHONE NO.' Co~issioner SUBJECT: TH RU: FROM- Bobby-Foster Petroleum Inspector State of Alaska 1986 BOP Test SAPC DIU YdPI Q- 17 Permit No. 86-158 Endicott Oil Pool w.]~dnesda)b Sept.ember 24, 1986: The test began at 12:15 a.m. and was completed at 2'~45 a.m. As the attached BOP test report shows, there were two items to be repaired and the AOGCC office notified. In sum~nary, I witnessed the BOP test on Standard Alaska Production Company Endicott well Q-17. Attachment Bob Mize, Doyon toolpusher, contacted me on 10/1/86 and informed me that the repairs on the air pump and HCR valve were completed and were in good working order. I02-001 A(Rev 1¢84) STATE OF ALASKA ALASKA OIL & CAS CONSERVATION COPiMISSION B.O.P.E. Inspection Report Dat~ Location, General_~~_~Well Sign~ ACCUMULATOR SYSTEM - . Mud Systems / Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H. C.R. Valve Kill Line Valves Check Valve Test Pressure Pressure After Closure /~-~'-~ psig Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: Controls: Master Remote (~ Blinds switch cover~~ Kelly and Floor Safety Valves Upper Kelly / Test Pressure Lower Kelly / Test Pressure Ball Type / Test Pressure inside BOP / Test Pressure Choke Manifoid~_~_Test Pressure ~o. Valves / ~ No. flanges 3 g Adjustable Chokes Hvdrauica!!¥ ooerated choke mind'sec. min~.2 sec, Repair or Replacement of failed equipment to be made within ~ day~ and Inspector/ Commission office notified. F 't ~7 '' ,, ' , l ~ ' Distribution orig. - AO&GCC cc - Operator cc - Supervisor September 3, 1986 Mr. R. S. Allan Division Drilling Engineer Standard Alaska Production Company P.O. Box 196612 Anchorage, Alaska 99519-6612 Telecopy-. (907) 276-7542 Re.. Duck Island Unit Q-17 MPI Standard Alaska Production Company Permit No. 86-158 Sur. Loc. 2!12'SNL, 2350'~.IEL, Sec. 36, T12N, R16E, Btm~hole Loc. 2940'S~tL, 3373'~?EL, Sec. 36, T12N, R16E, UM. Dear Mr. Allan: Enclosed is the approved application for permit to drill the above referenced well. The permit ~to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Vea~truiy~rs, ~ ~ Chairman of Alaska Oil and Gas Conservation Commission BY OP~ER OF TH_E COP~iSSION d!f Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA Row 2 Slot 62 ALASK,_ 3IL AND GAS CONSERVATION ,_ .,'MMISSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill ~r Redrill Re-Entry [] Deepen[]1 Service _~ Developement Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Standard Alaska Production Company BKB = 56' feet 3. Address 6. Property Designation Endicott Field P.O. Box 196612, Anchorage, AK 99519-6612 ADL 34633 Endicott Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 2112' SNL, 2350' WEL, Sec. 36, T12N, R16E Duck Island gnit/Endicot:t At top of productive interval 8. Well nu ,mber Number 2852' SNL, 3270' WEL, Sec. 36, T12N, R16E Q-17 MPI K00683449-G-14 At total depth 9. Approximate spud date Amount 2940' SNL, 3373' WEL, Sec. 36, T12N, R16E Sept. 10, 1986 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 10,720' HD ADT, 312828 2880feet Q-21 184.6 feet 2560 10,494' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 lel(2)l 4900 psi Kickoff depth 647? -'. feet Maximum hole angle 20 0 Maximum surface 3900 psig At total depth (TVD) 10 , O00TVD~g 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" Structural )rive Pipe 75' Surfac; 131' 131' Drive 17-1/2" 13-3/8" 72~ L-80 Butt. 2444' Surfac; 2500' 2500' 2700 cu. ft. Permafros 12-1/4" 9-5/8" 47~ NT80S NSCC 5444' Surfac ; 5500' 5500' 320 cu. ft. Permafrost 12-1/4" 9-5/8" 47~ NT95H: NSCC 4142' 5500' 9642' 9484' 425 cu. ft. Class G 8-1/2" 7" 29# L-80 Butt. 1328' 9392' 9249'10,720' 10496' 375 cu. ft. Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth StrLJctural Conductor Surface i'k .. '- i:'~; ~_, Intermediate Production Liner Alaska u~l a Gas Cons. O0mmissi0~ Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee ~ Property plat ,~, BOP Sketch ~: Diverter Sketch [] Drilling program ,~. Drilling fluid program ~ Time vs depth plot D Refraction analysis [] Seabed report [] 20AAC25.050 requirements ?, 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~.~, Commission Use Only Permit Number .... I APl number -. "~ I -' .. , 09/03~86 . ,Lfor other requirements I Conditions of approval Samples required [] Yes ",~No Mud Icg required ~ Yes .,~No Hydrogen sulfide measures ~ Yes ,~ No Directidnal survey required ~Yes ?, No' - Requiredwork~s~~~~; © 10M; ~ 15M t,i~../~.~.~.~,. Other: by order of Approved by 'k.. ~ ./. ~,.__//./~/~.~f/,vv Commissioner the commission D~a Form 10-401 Rev. 12d-85 Su in triplicate PROPOSED DRILLING AND COMPLETION PROGRAM NELL 0-17 (MPI) Drill 17-1/2" hole to 2500', run, and cement 13-3/8", 72#/ft., L-80 Buttress casing to surface. Install BOPE. Maximum BHP is 4900 psi at 10000' TVDss. Maximum possible surface pressure is 3900 psi based on a full gas column. Directionally drill 12-1/4" hole to the intermediate casing point above the KekiKtuK formation. Run and cement 9-5/8", 47#/ft., NT80S and NT95HS, NSCC casing. No fresh water sands are anticipated below the surface casing shoe. No abnormal pressure intervals are expected in the 12-1/4" hole section. The programmed 9-5/8" casing cement will provide over 500 ft. of annular fill-up above all significant hydrocarbon zones. Downsqueeze the 13-3/8" x 9-5/8" annulus with Permafrost cement followed by a nonfr_e~zin fluid Pre res ~~togt~c~ . ssure t the 9-5/8" casing to 3000 psi. ~~_ r . be given to the AOGCC so that a representative of the commission may witness the test. Drill 8-1/2" hole to TD. Log and run and cement 7", 29#/ft., L-80 Buttress line, to TD with approximately 250' of lap in the 9-5/8" casing. ~~to float equipment. Test casing and lap to 3000 psi. Prior ~--~ be given to the AOGCC so that a representative of the commission may witness the test. Change over to NaCl packer fluid. Move off ri g. Move rig on in 1987. Perforate well utilizing drill pipe conveyed guns. Kill well. Run and set 7" and 9-5/8" packers. Run 4-1/2", 12.6#/ft., L-80, TDS tubing with a sliding sleeve and GLM's. A subsurface safety valve will be placed 50' below base of permafrost. Install and test tree. Shut in well. Rig up to flow well. Flow tubing volume to tanks. Shut in well. JGV/pm/O736D OR£L L £1VG PtqOGR~Id PROPOSEO 14EL L BORE tqELL 0-~7 FMP£? RIG: DQ~QN 15 ~Q BKB BK~' S~' A~St 13t ' m t0. 4~° 13I ' $466 ' 1~I6 ' 939~' 730' 30' Structural Baoo ~rma~oat ~SSV Top of Do~noquoozo Comont t3-3/0" 7~ &/ft t-O~ BTC 9-~/8" T~V~ Pact~or ~/ SBA ~o}octo# P~rforatlona 7 · TIN Packer Pr~Joctod P~rforattono 7" ~2 ~/f t £ -OQ B.O.P. STACK CONFIGURATION 13-S/8 IN. TRIPLE RAM STACK SO00 PS! WP DRILLING ANNULAR PREVENTER 2 IN. KILL LINE CHECK HAND GATE GATE I ] ! I PIPE RAMS 1 1 BLIND RAMS 1 DRILLING SPOOL I PIPE RAMS I 4 IN. CHOKE LINE ! GATE GATE . ,.. ~ -.:.~ ~ .. ~,..:,, J~:..~, ~..~ II I I II II Ill Itl ~t ll l l~' II d ~ , [ [ d; ':, 'i PLAT OF PROPOSED WELL LOCATIONS MPi 11~11! Ll4:eled IA Si¢.&~,T. IZI~,R. 16[.,Umi~t M. SDI ~1~ill Le4:Med IA :1~t:. D,T.IIN.,R.I?E.,Um'~et M. ! PREPARED FOR SOHIO ALASKA PETROLEUM CO. DRW NO. IIG' 15 SHEET I of I0 REV. O F.R. BELL & &SSOC. PRUDHOE BAY OFFICE PRUDHOE B~Y, AL&~4~A I~T['. NOV. 13, 14115 ICALE: I"l I MILE :{}iAIII# 1t': R~.I'. CXEC. K t D BY' i 75o 42400 0 44 0 36 43 0 53 0 §75~3 0 S~_ 0 6 liT_ u CERTIFICATE OF SURVEYOR I llearby certify thatl em properly registered and licensed to practice land surveying in the State a~ Alaska end that l#il plat represents an propoled I~ation for the Well num~r8 shown above. All surveying was done by me or under my ~upervismn, end t~t ell dimflslons end details ire correct. DRW. 116,-85 SHEET Z o! I0 REV. 0 Indicates well Indicates Celcbleted Section Cer~er Indicates Perpendicular Offset Distance Indicetq8 ~ndiculer Off~t Disteace ~erpend,cular alstgnc~ v~ries fgr ~a~ will PLAT ~Pi PROPOSED WELL LOCATIONS L~CATED IN IE~,II~ T.I~ N.,R. ~EPARED FOR SOHIO ALASKA PETROLEU CO. PR E PAR E D BY F.R. BELL · ASSOC. PRUDHOE BAY OFFICE PRU~OE BAY, ~ASKA I I DATE' NOV. I$, SCALE' I "" _ DRAWN iY: RI.T. CHECKED BY' B.t. BILL ~ ZNI I .,T 0il 6 LdlTITIIII L~ TUll I! r IT 22 Y- 8912497,'97 lli 7105521.27 7FZl'10,1Sll' 147°B7'26.224Z· i9i9.1! Z223.6S Xm 2SI914.14 [- 464077.31 23 Y- 5982392.27 N- 780:5296.74 70°2!'09.1613' 147o57'22.2244· 2020.49 2086.13 X-. 259t17.65 E- 46411B.59 24 'fY' 5982489.77 , N- 7805325.75 ' 70c21'10.0757' 147c57'26.3842' 1927.53 ' 2229.13 X- 2589?8,40. E- 4~4075.~8 25 Y- 598-2~4.08 N- 7805294 . 22 ~ 7-0~ 21' 09. 0790' ~147 ~7'2~.~84~' 20~.~ 20~2.:0 'X- 259111.92 E= 4~4116.88 ~ 2& Y= 5982481.58 N= 7805525.25 70~ 21'09.9954' ~ 147~57'26.5440' ~ 1955.90 2254.&0 :X- 258~72.67 ~ E= 464075.~7 ~ ~ ! 29 Y- ~982367.70 N- 7B0~2~9.17 ~70021'0B.~143' 147d57'22.7040· 204~.I1 2103.24 X- 2~9100.4~ E- 4641I~.47i 30 Y- ~98246~ 20 N- 710~31i Ii ~70~21'09 12B7' 147°~7'2~.81~7· 1~2.~4, 224~ ~4 x- 2~e~61.20 E- 464070,~6~ 31 Y. ~9~2359.50 N- 710~2~.I~ ~70~21'0~,1320" 147c~7'22.1~3~· 2053,~ i210B.72 ~- 259094.71 ,,E= 4a4111.7a ~ ._ 32 Y- 59~2457.01 N- 7~05315.~5 j70c21 09.74~4" 147°57 27.023~" 1~1.01 ~ 22~1 01 I X= 258955.46 E= 464068.85 ~ / 3~ Y= 5982351 31 N' 7805284 12~ ' ' =] ' ....]70~21 08 749b" 147~7 23 0237 , 2062.35~i 2114.19 X- 259088,98 E' 4641~0,06 ~ ~ 34 Y= 5982448.82 N= 780531~ 13 ~70c21'09.&641= 147e57'27'1834" ~1 Zgkg.38 ~ 2256.49 X- 2~8949,7~ E- 46406751~ , , 36 Y- ~982416.0~ N- 780~303' ~ 03 . 70°21'09 3347" 147c~7'27.B229" 2002.87 2278.37 X- 2~8926.78 E- 464060.32 *, 37 Y- 5982310.36 N- 780527J.50 ~70°21'08.3379" 147°57'23.8230" 2104.21 2141.5~ x- 2 9060.30 E- 464 0 '5 ' , 38 Y- ~982407.86 N- 7805300.~1 ~70°21'09.2524" 147°57'27.9127" 2011.24 2283.84 X- 258921.0~ E- 4640~8.61 39 Y- 59B2302.17 N- 7B0~268.98 7~21'08.2556" 147c~7'23.~129" 2112.58 2147.02 X- 2~90~4.~6 E- 464099.82 ~ 40 Y- ~982399.67 N- 780~297.98 ~ 70°21'09, 1700" 147057'28. ~426" 2019.~2 2289.3~ X- 2~891~.31 E- 4640~6.91 ~ 41 Y- :98229~.97 N- 780~266.4~ ~70°2i'08.1733" 147~7'24.1427" 2~20.95 21~2.49 , X- 2~9048.83' E- 464098.11 42 Y- 39B2591,48~ N- 7B0~29~.46 70o21'09,0577" 147°57'28.3024" 2027,99 2294.79 X- 2~8909.~8 ~ E- 4640~.20 . ~?~~ .... .h MPI PR~SED WEL~ L~ATION LIST r't. ' ...... . .. SOHIO ALASKA PETROLEUMCO. '~~~~~L' DEW. NO. IlS-mS PREPARED BY DATE'HOV.I), '~ ~s~~ F.R BELL ~ ~SSOC ~~~~ SHEET 4 of IO ' ' SCALE; " PRUDHOE BAY O~CE -'. REV. O PRUDHOE BAY, ~A$KA DRAWN IY: R.G.~ ' CHECKED IY: B.[. i i i i i I _1111 II I _I I I I I I I rI I__ I _. '' '"-- ~---- -- -- ~ I II_l Z UTi, ,/1~ & LITITU~E Lit ~LL i Y- St12412. Z7 N- 710~324.S1 7~2i'i0.0~70' 14~17'Zl.~'~' g' 2~1110,7~ E' 4&4~37,3& ., 2 Y- 5982~79.88 N- 780~353.~2 70~21'20.98~4· 147°57'24.&257· X- 259041.4q E- 464094.4~ ~ .Y- ~2474,1~ ~N- 7g0~2.9~ 70~21'09.~4~' 247'"~7'~0,&~' 19~6.77~ ~0~2,11 ~x= 25~175 ol EI 464155 65~ ~ . 4 'Y- 5~2571.~ ~= 7805~50.~ 70°21'10.8~91" 147' 57'24.785&' ~ 1845.80 2174.41 5 iY= 5~824~5.~ 'N= 780551~.46 70~21'09.~02~" 147~ 57 ' 20. 7857 , iX= 25~1&~,27 EI 4&~155.~5 ~ ' ., . a Y= ~82565,50 N= 7805548,47 70021'10,81~8" 147°57'24,~454' 1852,17:217~,88 ~' 25~030,02 E' 4~40~1,04 / 7 yI ~82457,80 N= ~80551&,~4 70c21'09.8200' 147°57'20,~455' 1~55,52~ 2045,0& I Z= 25~1&5,54 E= 4&~152,24 , 8 yI ~82555,50 N- 7805545,~4 70°21'10,7544' 147°57'25,1055' X- 259024 29~ E- 464089:33 9 Y- ~982449~61 N- 7805314 41 70°21'09.7~76' 147°57'21.19~4' Ifil.It. 204B.53 X- 2~9157.B0 E- 464130.53 10 Y- 5982547.11 N- 7B0~343,42 70~21'10.6521' 147~7'25.2651' IB&B.9I 2190.B3 X- 2~9018.~ E- 464.087.62 11 Y- ~982441.42 N- 7805311.B9 70~21'09.6553' 147°57'21.2653' 1970.26 2054.00 X- 259152.07 E- 464128.83 . 12 Y- ~9~2~38.92 N- 7805340.90 70~21'10.~697' 147°57'2~.4250' 1877.21' 2196,30 X- 259012,82 E- 464085.92 13 Y- ~982433.23 N- 780~309.36 70c21'09.~7~0' 147°57'21.4251' 1978.63' 2059:' .47 X- 2~9146.33 E- 464127.12 14 Y- ~982530.73 N- 780~358.37 70~21'10.4874' 147°~7'25.5B49' IB85.66r 2201.77 X- ~9007,08 ~- 464~84,21 1~ Y- 598242~.03 N- 780~306.84 70c21'09.4906' 1470~7'21.5850' 1987.00 2064.94 X- 259140.60 E- 464125,42 16 Y- ~982522.54 N- 780~335.85 70t21'10.40~1' 147°~7'25,7447' 1194.03 2207.24 X- 2~9001,3~ E- 4640B2.~0 17 Y- 5982416.i4 N- 7805304.31 70021'09.4083' 147°57'21.7449' 1995.3B 2070.41 X- 2~9134.16 E- 464123.71 lB Y- ~982514.35 N- 7B0~333.32 700~1'10.3227' 147°57'25.904&' 1~02.40 2212.71 X, 2~899~.61 E- 464080.80 19 Y- $982408,65 N- 780~01.79 70c21'09.$260' 147o$7'21.~0~7· 200~.75 207~.19 , ~- 2~9129.13 E- 464122.00 20 Y' ~9B2506.16 N- 7g05330.B0 70c21'10.240~' J 147~57'26.0644' 1910.77 221B. IB ~- 258989.B7 E- 464079,09 21 Y- ~9g2400.46 N- 7805299.27 70~21'09.24~6' ~ 147~57'22.0~4~' 2012.12~ 2091.36 ~ X' 2~9123.39: E~ 464120.30 ~ i ~.~~~ ~ ~:~ ~,~ ~:../~; .;:. MPI PRO~SED WELL L~ATION LIST a'~ ~~~..' ,~ ~,i 0~ ~ ~'~'*?: (;;~-~'~ ~:~ ........ SOHIO ALASKA PETROLEUM CO. ~,~.% ~]9~ '/,F~ DRW. NO. 116-~5 PREPARED IY DATE'NOV. I~. ~i*°~'~'~~ F.R BELL & ASSOC ~_~ESS~~ ~ SHE ET 5 of IO · · SCALE · N/A ~~~ " P RU DHOE BAY OFFICE DRAW B y- RG.T ,Er. O PRUOHOE BAY, ALASKA CHECKED BY~ B.E. i i _ ..... I II I ~- Il .I ..... ~lll I~LL ~lP ZO~ I UTh ..0N~ & L&TITtLDE L0~, ,rUN IIIV~ lilt 43' Y- S9122fl.71 N- 710S2&$.'95 70¢21'01.'0t09b 14~k7~Z4.~2&' ~i~.11 X- '2~9043.09 E- 46409&.41 .... 44 Y- ~982383.29 N- 780~292.93 70~21'09.00~4' 147°~7'2i,4&23' 203&.3& 2300.26 x- 2~e~os.e~:E. 464o~.~o. , ...... X- 258898.11 I E' 464051.79 : 47 Y- 5~B22~.40 ~ N~ 7805258.88 70~21'07.~2~5" 147c57'24.6225" 214~.07 21~8,91 X- 259031.62 E' 464092.99 : 4B Y' 5982366,91 N- 7B05287,89 ~70°21'08.B407" 147°57'28.782O" 205~.10 I 2311.20 X- 258892,37 E-. 464050.08 49 Y' 5982261.21 N- 7805256,35 70o21'07,8439" 147°~7'24.7B22' 2154.44 ~ 2174.38 X- 259025,89 E- 464091.29 ~0 Y' ~9823~B,71 N' 780~28~.3~ 70°21'08.75B4' 147~7'2~.941B' 2061.47 ] 2316.&7 I X- 2~8BB6.63 E- 464048.3~ 51 Y- 598225~.02 N- 780~2~3.83 70~21'07.7616" 147°57'24,9420" 2162,11 1 2179.86 / X- 259020,15 E- 46~089.~8 52 Y- ~982350,52 N- 7BO5282',B4 70c21'08.6760' 147°57'2~,1017' 2069,B5 2322,14 X- 258880,90 E- 464046.67 53 Y- 5982244.B3 N- 7~0~251.~1 70021'07.6793. 147°57'2~.1019' 2171.19 2185.33 X- 259014.41 E- 464087,8B 54 Y- 5982342,33 N- 7BO~2BO.31 70021'08.5937' 147°'57'29.2&15" 207B,22 2327,&2 X- 258875.16 E- 4640q4.96 55 Y- 5982236,64 N- 780~24B,78 70c21'07,5969' 147dS7'25.2&17' 2179,~6 2190,B0 X- 259008,68 E- 464086.17 ~6 Y- ~982334,14 N- 780~277,79 70~21'08,5113" 147°57'29,4214' 20B6,~9~ 2333.09 1 .... X- 258869.4~ E- 464043,26 57 Y- 598222B,44 N- 780~246,26 70o2i'07,5146· 147o~7'25.421&" 21B7,93) 2196,"27 I X- 2~9002,94 E- 464084,46 58 Y- ~982325.95 N- 7805275,27 70°21'08,4290" 147°57'29,~112' 2094.96 233B,~6 X- 258863,~9 E- 464041,55 59 Y' ~982220,25 N- 7B0~243,73 70o21'07,4323~ 147°57'2~,~114' 219&,30 ~201,7~ ~" 25B997,21 E' 4~40B2,T& 60 Y- 5982317,76 N- 780~272.74 70021'0B,3467' 147°57'29,7lll' 2103,33 2344.03 [- 2588~7,96 E- 464039.B5 61~ Y- ~982212,06 N- 7B05241.21 700 21' 07. 3499" 147°57'25,7413" 220'4,&7 2207.21 X- 2~8991,47 E- 464081.05 62 Y- ~9'82309.57 N- 7805270.22 '70c21'08.2643' 147°~7'29,~009' 211'1.71 2349.50 X" 2~8852.22 E' 464038,t4 63 Y- 598220~,B7 N- 78052~8.b9 70°21'07.267b" 147o~7"25,90t1" 2213.05 2212.b9 X- 258985.74 ~ E' 464079,34 _. I i .~t ~ 4~:~1 ~': L:; :~) MPI PRO~SED WELL L~TION LIST 4lqk~'°~5~~:~a SHEET sol lo KR. BELL & ASSOC, SCALE' --~~~ PRUDHOE BAY OFFICE DRAWN BY : _ REV. O PRUDHOE ~Y, ALAS~ CHEC~EO~Y* ii i i i il m B i l! I~LL ~ ZONE $ I1i', ONE & LITITUIE LO. TLI~E IXlT(~) lilT ! .. X- 2SII4&,41 E- 4&403&.43 &~ Y- ~982~9~.&8 N- 7S052~,26 70~22'07.~8~2· ~47~7'26,0&20· 2221.4~ X" 258980,00 E" 464077.&4 , 66 'Y' 59822'93,18' N' 78~}65.17 ~ 70-21'08.09q7" ''147'57'30.22'0~" 2129.45 X' 25~e40.75 E' ~7 Y' 59B21~7.47-- N= 780525~.64- 70:2~'-~7.1027" 147-57'2b,2208" ; '~27-.80 , 2225.~$ X' 25~974.26 E' 464075,95 ~J 68 Y- 5982284,99 N- 7805262,&4~ 70t21'08,0173" 147'57'30.3805" ] 2136.82 2~b5,~2 X- 2588~5,01 E- 4640~,02 ~ . &9 Y- ~t82~9,]0 ~ H- 7B0~2~1,11 70c21'07,0206' ~ 141c~7'2~,]807' 22~8,17' 2229,10 X- 258968,53 ~ E. 464074,23 70 Y- 5982276,10' N- 7B05260,~2 70~22'07,9~50· ~ 247~57'~0.540~· 2~45.29 2~7~.~9 X= 258829,28 E- 46403t,3t~ ~ /.. .~ '.~ i MPI PRO~S[O WE~ L~ATI~ LIST 4~ ~' LOCATED IN SEC. 56,T. 12 N.,R. I6 e. UMIAT M. ~'~~'~-'~ SOHIO ALASKA PETROLEUM CO. · JbD~,.N~L~ ~-- SHEET e of lo F.R. BELL S ASSOC. SC~E: qk~"~ss~~~ PR U DHOE BAY OF FICE -~~~ DRAWN BY · R.G.T. e~. o PRUDHOE BAY~ALASKA cHEc~Eo~x' a.E. i OZt~EC TZONA L ££ZL L £NG 14£L L ~- _I 7 (~1t~£) i~L A 7- 0 Target $5~1 (TN)~ D,e=p~tu~e ddO~' / Y ~ 9~t, 670 ~ dO, 3B6 ND (dO, ~26 TVD) /~ Sec. 3~ T~ Rd6~/ ~ ~parture d440' X=R~ 733 Y~ 9Bd, 404 40, XRO ~ (~0, 496 TVD] Bec. 3~ r~R~ Rd6E Su~ face £ oca tJon Y=~, 9a~, 3~0 Sec. 36, Td2N, Rd6E ENDICOTT MUD PROGRAM MAIN PRODUCTION ISLAND HELL 0-17 (MPI) Interval Mud Neight Viscosity Fluid Loss (ppg) (sec/qt) (ml/3Omin) 0-2500 8.8-9.4 100-200 20-15 9.0-9.5 Mud Type/ Components Generic Mud #5 Seawater Fresh Hater Soda Ash Set 13-3/8" Casing 2,500 - 9,642 8.8-9.4 40-45 lO-12 10.0-10.5 Generic Mud #7 Seawater Fresh Hater Gel Caustic Soda Soda Ash Barite Lignosulfonate Drispac Lignite Set 9-5/8" Casing 9,642 - 10,720 9.4-9.6 40-45 6-8 10.0-10.5 Generic Mud #7 Seawater Gel Caustic Soda Soda Ash Barite Lignosul fonate Drispac Lignite Hang 7" Liner JGV/pm/O736D OUhSE L I NE Searci~ Radiu?:;= 30590 C' "' .... For p~opos~d bJe.l~' C ' '" ._c~.HOK I . LIS 3 2(.:,--AU~; ': '-" .....)¢" 3E Lt].:.:__AP '~' ~-" ~ ,., '"~ c, c::~ ..... ........ Closest App'~oach Anal. gsi. s ......... Date' ~6-AUg..--86 / 'Time' 09' '37' 34 Note' A!i (~ei:~ths in .~eet Below K. eilg ]?ushing (BF,:B) C 1 c,s~est Appv. oach v_rticai WELL !DENT /PROFOSED\ /NEARBY\ CLOSEST /PR{]POSED'x 'f'V D DEF AR T TVD DEP ART D I STANCE TVD D EP A'R T MI-SD3 !010!, 6 ] 172, 1 9249. 0 79. 0 6788. 9 ': ~ 2985. 1 M I -SD4 ! 010 '~.... 6 I i ~ ~... '~ I 10884. 2 56o3. =: A029-20280C) 0 SI-DI1 9446 1 933, 6 11229, 5 4924. 1 14676. 1 SI-DI2 6419. 7 O. 0 6392, 0 3275. 7 170'78, 3 A029-2051000 SI-DI3 426. 0 O. 0 400. 0 I . 6 23214. 0 ~j~i/ ~".~,~, ~:~.,,, '~-~:._ A029-2051800 ~.,2 ....... , MI-SD7 2807 2 0 0 2799 9 14 6 1723. ' ~ ' ' ' A 029-2063900 MI-SD9 1'707. 5 O 0 1700 0 3 3 1775. 3 g02~-2064000 MIS~O 4867 = O. 0 4860 q 1081 1 1383 6 .~ A029-..-2156800 M l - P I El 3'? ':~,.: ,.:,,: ..... P, O. 0 37 .q 6 0 O. 0 328. A029-21 56900 SI-Q35 .3100 i O. 0 3099. 5 2D. 4 16172. A029-2158500 MI-MI9 i?601. ! O. 0 2600. 0 7. 4 320. A029-21 5~600 SI-M33 718S. i 113. i 9043. 4 4434. 8 14084. A029-2160500 N I-OZO ~ 700. 6 O. 0 1699. 9 18. ! 338, A029-21 ' ~: . MI-G21 O. 9 O. 0 O. 0 O. 0 SUMMARY The well which comes closest to the p~'oposed Closest appT'-C:.ach dist..ar:,c..e = / ~,~ meet KICK OFF ~of t.i~is run = 6477.0 f:ee't well is' If tN DOUBT - - - ASKII ~c~ . C O: ' J i i · IG-O' ~z '0" i1' O' J il :S 11:5 ' J i,~ '0' /2 :o ' i '! ' I ,.-~LA~J V/£ w - Z £ v£ L ~ ~2't:,DUAB~' I'Z Dht A!',I..7)1 5. [}DMS ]p,l~ (7t]. 7 CLO'dAP.__o. HOtx"' ~ T . L I ~'~,.-~ 3 Z' /'' ''- A ij '3 ''- ,- ! "-',"~:~"":':: }~d::. Closest A~pwo,~zh Analysis ....... Dste' 26-AUG--86 Time' 09' 37' 3,~ ~e=rch Rodius= 30590 COURSE LINE For propoqed_ ~el~' MI-(21~[23-'36-1~-16]., Note' All ~epti~s iT'~ P-eet Belo~ Kelly Bushin§ (BKB) WELL IDENT MI-SD3 ,~010~ 6 ]1~,~.. 1 A029-~024500 MI-SD4 10101. 6 1172. I A02~-2028000 SI-DI1 ~446. i ~33,6 A02~-202800I SI-DI2 64i~.7 0.0 A029-200i000 SI-DI3 426. 0 0.0 A02~-205i800 MI-SD7 2807. 2 0.0 A02~-2063~00 MI-SD~ i707.~ 0.0 A02~-2064000 MISPtO 4~67.7 0.0 A0~--~156~00 MI-PlO A0~-~156~00 AO~-~ 158500 MI -Mi ~ AO~-~I 50600 SI--M33 A0~-~I60500 MI-020 A02~-~I6~500 MI-Q21 ,, SUMMARY Cl.osest Approach /PROPOSEDX. /NEARBY\ CLOSEST /PROP TV D DER AR T TVD DEP AR T D I STANCE 7'VD D_ EPA R T 9249. 0 79. 0 6788. 3756>. 0 O. 0 310(3. I O. 0 L~601. I O. C) 7188. 1 113. 1 1700. 6 O. 0 0.9 0.0 10884.2 5653.2 2985.1 11~29. D 4924. 1 14676. 1 .,~. ...... ~, 63~2,0 3275.7 17078.3 "':":: 40'0.0 i. 6 ~3~14. 0 ~7~.9 14.6 1723. ~ ,4 ....... ..:' 1700.0 3. 3 1775. 3 ,~.,' 'i~ ..j .,:~ 4~60.2 1081. 1 1383. 6 .~-,.'<C7. :;7 '. ..,. ', 3756.0 O. 0 328. ~ 30~. 5 ~5. 4 I6172. 8 ~600.0 7. 4 3~0. 0 ~043. 4 4434. 8 14084. 9 1699.9 18. I 338, ~ 0.0 0.0 ~ The well Closest KICK OFF which comes closest to the proposed well is' A'6fq"':' it -I o ...... _I ......... mpp~osch distance = / ~,& ~eet ~of this ~'un = 6477. 0 fee't ENDICOTT MUD PROGRAM MAIN PRODUCTION ISLAND WELL 0-17 (MPI) Interval Mud INeight Viscosity Fluid Loss (ppg) (sec/qt) (ml/3Omin) 0-2500 8.8-9.4 100-200 20-15 9.0-9.5 Mud Type/ Components Generic Mud #5 Seawater Fresh Water Soda Ash Set 13-3/8" Casing 2,500 - 9,642 8.8-9 4 40-45 lO-12 10.0-10.5 Generic Mud #7 Seawater Fresh INater Gel Caustic Soda Soda Ash Barite Li gnosul fonate Drispac Lignite Set 9-5/8" Casing 9,642 - 10,720 9.4-9.6 40-45 6-8 10.0-10.5 Generic Mud #7 Seawater Gel Caustic Soda Soda Ash Barite Lignosulfonate Drispac Lignite -Hang 7" Liner JGV/pm/O736D IF IN DOUBT . - - ASK:II ~9 :o PLAAI VIEW-/.E VEL Z ~4.0oo OA~ . I- TESTING THE B.O.P. STACK WITH THE 13-1/8" x 4½" IF BOX X BOX, (THRU-BORE), TEST PLUG (FIG. 7) 1.) Make up the 13-1/8" x 4½" IF test plug to a stand of drill pipe. (Illustration 9) NOTE: Sometimes it is helpful to make a stand of heavy wall up to the bottom of the test plug in order to help energize the compression packing. 2.) Lower the ~est plug through the B.O.P. stack until it lands on the lowe:r load shoulder of the split unihead unit. 3.) Run in at least two of the lower set of lockdown screws 180° opposed to hold the test plug in place. This is so the drill pipe can be backed out in order to test the blind rams. NOTE: All lockdown screws can be run in if need to energize the compression packing on the test plug. 4.) Test the B.O.P. stack. 5.) Back out all lockdown screws which have been run in. 6.) Remove the test plug. 13-1/8" X 4-1/2" IF BOX X BOX (THRU-BORE) TEST PLUG THIS E/VD UP L FMC P.N. 48-261-082 REQ'D PART NO. DESCRIPTION 1 48-261-268 Test Plug 1 48-261-083 Body 1 48-261-673 Compression Ring 4 79-040-074 Set Screws 1 48-081-529 Packing ~ 1 51-092-001 2" Ball Check Figure ~7 (Part number 48-261-082 continued on next page) FMC P.N. 48-261-082 continued REQ'D. PART NO. DESCRIPTION 1 19-505-663 Coil Spring 1 25-411-356 Retaining Plate 1 25-411-357 Circ.-O-Lox Ring 2 48-180-027 Pipe Plug ~ 52-304-013 Drlg. Pipe Sub. ,z ., ILLUSTRATION 9 B.O.P. STACK 3-5/8" 5000 3-5/8" 3000 WP TESTING THE B.O.P. STACK WITH THE 13½" X 4½" IF BOX X BOX, (UPPER) , TEST PLUG (FIG. 19) 1.) Make up the 13½" x 4½" IF test plug (upper) to a stand of drill pipe. (Illustration 13) NOTE: Sometimes it is helpful to make a stand of heavy wall 6p to the bottom of the test plug in order to help energize the compression packing. 2.) Lower the test plug through the B.O.P. stack until it lands on the upper load shoulder of the split unihead unit. . 3.) Run in at least two of the upper set of lockdown screws .. 180° opposed to hold the test plug in place. This is so the drill pipe can be backed out in order to test the blind rams. NOTE: All lockdown screws can be run in if you need to · energize the compression packing on the test plug. 4.) Test the B.O.P. stack. 5.) Back out all lockdown screws which have been run in. 6.) Remove the test plug. 13-1/2" X 4-1/2" IF BOX X BOX (UPPER) TEST PLUG L HIS END UP FMC P.N. 48-261-068 REQ'D PART NO. DESCRIPTION 1 48-261-067 Body 1 48-261-671 Compression Ring 4 79-040-074 Set Screw 1 82-741-117 Packing 1 51-092-001 2" Ball Check 1 19-505-663 Coil Spring 1 25-411-356 Retaining Plate 1 25-411-357 Circ.-O-Lox Ring 2 48-180-027 Pipe Plug · Figure #19 ILLUSTRATION # 13 STACK [~]'13-5/8" 5000 WP 13-5/8" 3000 WP TESTING THE B.O.P. STACK WITH THE 10" X 4-1/2" IF BOX X BOX (COMBINATION) , TEST PLUG (FIG. 22A) 1.) Make up the 10" x 4%" IF test plug (combination) to a stand of drill pipe. , 2.) Lower the test plug through the B.O.P. stack until it lands on the upper load shoulder of the tubing/casing head. 3.) Rin in at least two of the upper set of lockdown screws 180° opposed to hold the test plug in place. This is so the drill pipe can be backed out in order to test the blind rams. 4.) Test the B.O.P. stack. 5.) Back out all the lockdown acres which have been run in. 6.) Remove the test plug. 10" CO.qBINATION TEST PLUG AND BOWL PROTECTOR RUNNING/RETRIEVING TOOL THIS END UP F~IC PART NO. 48-261-503 ~REQ'D. PART NO. DESCRIPTION 1 48-261-504 BODY ,,, 1 48-085-833 BELT PACKING 1 48-180-025 PLUG, 1¼ L.P. 1 48-180-025 PLUG, 1¼ L'P. , , , 4 I 48-180-015 PLUG, ½ L.P. 1 48-010-009 WRENCH (Figure #22A) "~ B.O.P. STACK 1" 5000 w? 13-5/8" 3000 STACK .... _ ........... 11" 5000 WP 11" 5000 WP -- ~ CHECK LIST FOR Nk~W Wl<i ITEM APPROVE (1) Fee ~/'t_. ~-~z~ 1. Is (2) toe' 2. zs (2 thru 8) · 3. Is 4. Is 5, Is 6. Is 7. 8. (3) Admin Qg thru 13) 10. _//:-'// ii. (10-and 13) / 12. 13. (4) Casg ~z~.~.~. ~_~-~ '" (i4 thru '22) (5) BOPE (23 thru'28) ' Lease & Well No. NO the permit fee attached .................................. ...... .. well to be located in a defined pool ...... well located proper distance from property well located proper distance, from other wells .................... ~--~ sufficient undedicated acreage available in this pool ............ ~7~ -- well to be deviated and is wellbore plat included ................ ~-~ -- Is operator the only affected party ................................. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ' Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27 28. Is conductor string provided ........................................ Will surface casing protect freshwater zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schen~qtic and list of equipment adequate~..~,, Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~ooo/O-~o~psig .. Does the choke manifold comply w/AP1 RP-53 (May 84) ..... % .......... Is the presence of H2S gas probable ................................. (29 thru 31) (6) Add: Geolog~r_; Engi~_ ee~ing: ~Wt', ~ LCS rev: 07/18/86 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ........ AdditionffI~ Remarlcs: INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 8 Well History File APPENDIX Information of detailed nature that is not padiculady germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX.' No special'effort has been made to chronologically organize this category of information. LIS TAPE V'ERIFICATIBN LISTING MICROFILMED :VP OIO.HO2 VERIFI~ATIO~ LISTING :~ REEL HEADER ~ ;ERVICE NAME :EDIT )ATE :86/10/17 ]RIGIN : ~EEL NAME :71754 ~ONTINUATION # :01 )REVIOUS REEL : :OMMENTS.:LIS TAPE, STANDARD ENOICOTT g-17, API 50-029-21648 ~, TAPE HEADER ~.'~'~. ~ERVICE NAME :EDIT ATE :86/10/17 RIGIN :FS1A rAPE NAME : :ONTINUATION # :01 ~'REVIOUS TAPE : ~OMMENTS :LIS TAPE~ STANOARO ENDICOTT Q-17, API 50-029-21648 PAGE .001 1024 ='L ~.~i~ E TYPE ~-.~REVIDUS FILE : INFORMATION RECORDS · E.NDt TT ~ NG. 1 aE ~'0 W N: 12 N '~ T: S E C 36 CO,UN. NORTH SLOPE STAT: ALASKA PROCUCTION CO. M:NEM CONTENTS UNIT TYPE CATE:~.~. St, ZE',..C. DDE.. 000 000' 030 000 000 01-4 000 000 008 000 000 004 000 000 004 000 000 OO2 0,0'0 000 012 000 000 006 O65 065 O65 O65 065 065 065 UNIT TYPE CATE SIZE CODE PRES: E 000 000 001 065 ** COMMENTS ,'-,~,-'--' .... -'- -'. -',.-'- ,'- -'. -',' -'- -' ,VP OlO.H02 VERIFICATION LISTING PAGE 2 SCHLUMBERGER ALASKA COMPUTING CENTER ~OMPANY : STANDARD ALASKA PRODUCTION CO JELL : 2-62/Q-1? MPI :IELD = ENDICOTT ~OUNTY = NORTH SLOPE 80ROUGH ;TATE = ALASKA JOB NUMBER AT ACC: 71754 ~UN ~ONE, DATE LOGGED: 13-0CT-1986 .DP: T HALSTEAD ;ASING : 9.625" @ 9738' - BIT SIZE : 8.5" TO 10899' [YPE FLUID : SEAWATER LIGNO ]ENSITY = 9.8 LB/G RM = 0.571 @ ?8 OF tISCOSITY = 37.0 S RMF = 0.4~1 @ 78 DF ~H : 10.5 RMC = 0.757 @ 78 DF :LUID LOSS : 7.0 C3 RM AT BHT = 0.251 @ I86 DF MATRIX SANDSTONE ~*~ THIS DATA HAS BEEN DEPTH SHIFTED - DOES NOT OVERLAYS FIELD PRINTS ,- ~ .~- -,- -,- ALL DATA WAS DEPTH SHIFTED T'O THE DUAL LATERLOG ~ '" '" ~ '" ~ '~' "' "' ": '~" "' "' "' ~ "' "" ~'~ ""~ "' "' ~HERE IS A VERY LARGE PULL IN THE M~IN PA,SS OF DATA. IN ACCORDANCE OF ~VP OlO.H02 VERIFICATIO~ LISTING PAGE [NSTRUCTIONS FROM STANDARD ALASKA PRODUCTION COMPAN¥~ WE SPLICED GOOD DATA :ROM THE REPEAT FILE ONTO THE MAIN PASS WHERE THE DATA IS QUESTIONABLE. tHE REPEAT INTERVALS THAT WERE USED ARE: DUAL LATERLOG (DLL) 4SFL,CALS .LS ~LLD~DV1 ~DVO~DIO~ SVO ~SV1 ~P SG R ~ENS 10120' - 10082' 10100' - lOOTO' TOTAL MAIN PASS USED 10044' - 10020' 10110' - 10085' COMPENSATED NEUTRON - LITHO DENSITY (LOT) i~LI ~ RHOB, DRHO~ DPHI !cF~QSS ~ QLS ~LSHV~ SSHV ~ ~ ~ LL LS ~ LITH~SS1 ~ S. S2 ~,:~AT ~ NPHI ~ RNRA,NCNL~FCN:L SGR, CGR ~ 10074° - 10050' 10056' - 10034' 10044' - 10020' VP OIO.HOZ VERIFICATION LISTING ! 'ENS lOIlO' - i0085' NATURAL GAMMA RAY SPECTROMETRY (NGT) ;GR,CGR,THOR~URAN~POTA ilNG,W2NG~W3NG~W4NG,WSNG PAGE 10044' - 10020' ;S TOTAL MAIN PASS USED FENS 10110~ - 10085' rHE HTEN CURVE WAS DETERMINED AS COMPLETELY INVALID - IT IS NOT INCLUDED ON FHIS LIS TAPE. SCHLUMBERGER LOGS INCLUDED WITH THIS MAGNETIC TAPE: DUAL LATERLOG (DLL) DATA AVAILABLE: 10888' TO 9734' .ARRAY SONIC LOG (SOT) DATA AVAILABLE: 10872' TO 9734' LITHO DENSITY COMPENSATED LOG (LOT) .VP OlO.HO2 VERIFICATIO~ LISTING PAGE 5 * COMPENSATED NEUTRON LOG (LOT) * DATA AVAILABLE: 10857' TO 9734' ~-' NATURAL GAMMA TOO.L (~4GT) * DATA AVAILABLE: 10826' TO 9734' -'-.- GAMMA RAY IN CASING (GR.CNL) ~- DATA A~AILABLE: 973~ TO 9290 ~-'- ~, DATA FORMAT RECORD ~NTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 1 66 0 4 1 66 8 4 73 60 9 4 65 .liN 16 I 66 1 0 1 66 0 )ATUM ,SPECIFICATION BLOCKS 4NEM SERVICE SERVICE UNIT AP1 API AP1 API FILE SIZE SPL REPR ID ORDER ~ LOG TYPE CLASS MOD NO. CODE FT O0 000 O0 0 0 4 LOT GAPI O0 310 01 0 0 4 ~GR LOT GAPI O0 310 01 0 0 ,~ SALI LOT IN O0 280 O1 0 0 4 LOT G/C3 O0 350 02 0 0 4 LOT G/C3 O0 356 O1 0 0 4 ~,RAT LOT O0 420 O1 0 0 4 LOT O0 000 O0 0 0 4 LOT PU O0 890 O0 0 0 4 LOT PU O0 89,0 O0 0 0 4 PEF LOT O0 358 01 0 0 4 LOT CPS O0 330 31 0 0 4 LOT CPS' O0 330 30 0 0 4 LDT O0 000 O0 0 0 4 LOT O0 000 O0 0 0 4 LOT V O0 000 O0 0 0 4 LOT V O0 000 O0 0 0 4 LOT CPS O0 354 O1 0 0 4 LiS LOT CPS O0 354 O1 0 0 4 LU LOT CPS O0 354 O1 0 0 4 PROCESS (OCTAL) .I 68 00000000000000 I 68 000000000'00'000 1 68 00000000000000 ! :68 00000000000000 1 68 00000000000000 1 68 O00000OO000000 1 68 0,0000000000000 1 68 00000000000000 1 68 00000000000000 t 68 1 68 '0000000,0000000 1 68 0000 1 68 000'0 1 68 00'000 ~000'0 1 6'B 00000'00:000'0000 1 68 O0, OOOO00000000 1 68 000000000'00000 i 6B 00000000000000 ! 68 0000000000000'0 1 68 00000000000000' .VP 010.H02 VERIFIC4, TION.LISTING PAGE .ITH ;S1 ;52 FENS ~'OTA )OTA HOR :RAN :S ~iNG ~2NG ~3NG ~4NG ~,SNG lENS SGR LLS 0 tENS CO SM 'ST LDT CPS O0 354 OI 0 0 LDT CPS O0 000 O0 0 0 LDT CPS O0 000 O0 0 0 LDT L8 O0 635 21 0 0 NGT GAPI O0 310 01 0 0 NGT GAPi O0 310 01 0 0 NGT PU O0 719 50 0 0 VOL PU O0 719 50 0 0 NGT PPM O0 790 50 0 0 NGT PPM O0 792 50 0 0 NGT F/HR O0 636 Z! 0 0 NGT CPS O0 310 O1 0 0 NGT CPS O0 310 01 0 0 NGT CPS O0 310 01 0 0 NGT CPS O0 310 O1 0 0 NGT CPS O0 310 O1 0 0 NGT LB O0 635 21 0 0 DLL GAPI O0 310 O1 0 0 DLL OHMM O0 Z20 10 0 0 DLL OHMM O0 220 09 0 0 DLL IN O0 000 00' 0 0 DLL MV O0 OlO O1 '0 0 OLL MV O0 000 O0 0 0 DLL MV O0 000 O0 0 0 DLL ~ O0 000 O0 0 0 OLL NV O0 000 O0 0 0 DLL UA O0 00'0 O0 0 0 DLL LB O0 635 Z1 0 0 SOT GAPI 80 310 01 0 0 .SDT US/F 80 000 .00 0 0 SOT US/F 80 000 O0 0 '0 SOT US 80 000 O0 0 0 SDT DS/F 80 520 80 0 0 SOT US/F 80 520 80 0 0 SOT US/F 8:0 520 80: 0 0 SDT US/F 80 520 80 0 0 SDT LB 80 635 21 0 0 CNL GAPI O0 310 01 0 0 CNL LB O0 635 21 0 0 DATA DEPT RMOB NP H I FCNL SSHV ITH G R 10896.0000 SGR 2.5547 DRHO 26.5137 DPHI 1135.0000 QSS 1082.0000 LL 62.7188 SS1 0.0000 CGR 0-0000 URAN 82.8125 W3NG 5124.0000 SGR 19.2656 SP 0.0000 0.011.2 5.6641 0.0269 131.3750 223.0000 0.0000 0.00'00 22.6875 0.0000 -25,6563 CGR NRAT PEF QLS LS SSZ POTA CS W4NG LLD D. V1 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4~ 4 4 4 4 0.0000 2.50,39 2,2070 0.0000 254.6250 296.7500 0.0000 899.5000 12.4844 60.5200 0,1660 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 '68 68 68 68 68, 68 68 68 68 68 68 68 6'8' 68 CALI RNRA NCNL LSHV LU 'TENS POTA W'ING WSNG LLS DV'O 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000,~ 000000 0000.0 ~§000000 00000000000000 00000000000000 00000000000.000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 0,00000000000~00 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 000000,00000000 00000000000~000 00000000000000 8.4453 2.6387 2996.0000 1083.0000 246.5000 5124.0000 0.0000 131.6250 2,26 '95 150. 1892 -1208.0000 .Vp ;R FENS DEPT :~HO B ~,PH I ~IT H SGR H 0 R LS :0 r s )B R ING S S IS OlO,H02 VERIFICATION.LISTING 0.3066 SVO -999.2500 DTCO -999.2500 DTL -999.2500 GR 0.3623 -999.2500 -999.2500 -999.2500 i0800.0000 SGR 2.2695 DRHO 22.1191 DPHI 1550.0000 QSS 1081.0000 LL 155.0000 SSi 21.3750 CGR 2,1094 URAN 33,0625 W3NG 6332.0000 SGR 8.4219 SP 615,5000 SVO 18.3906 DTCD 81.1250 DTL 6032.0000 GR 21.3750 0,0000 22.9004 234,5000 18.3281 0'¢087 13,6172 21.3750 -25,6250 1,2842 78.0000 80-3,750 --999.25'0.0 10700'~0.0.0 SGR 2. 656 DRHO 25.4395 DPHI 1125~0'0:0:0" QSS i082,,,0000 154.3750 21.9219 CGR 2.i0 URAN 34.87 6~08B.00 8-46 5'64'00 SVO DTCO 243.5'0'00 14.4375 1.0010 58"80.0000 GR -999.25:00 10'600~0000 2 3~27 1288.0000 1083.0000 143.7500 28.2500 2.8516 42.6875 6048.0000 8.4297 QSS 28- 2500 0.0156 20.9473 0.0430 213..0000 243.2500 23.. 8125 O. 59.38. 16. 500,0 28. 2500 -33.i562 URAN W3NG SGR SP SVO DTCO DTL GR SIO DTSM LSDT TENS CGR NRAT PEF QL S LS SS2 POTA CS W4NG LLD 0¥'1 SIO DTSM LSDT TEN S SS2 POTA S CS N4NG SI DTIM 0.5620 TENS -999.2500 DTST -999.2500 LDTL -999.2500 18.3281 CALl 2,22,46 RNRA 1.8232 NCNL -0,0063 LSHV 41~;75'00 LU 331,5000 TENS 0.6348 POTA 1760'0000 WING 6.8086 W5NG LLS D¥O 947.0000 TENS 132'0000 DTST 79-50'00 LDTL -999,'2500 426,~? .0 337.2500 0.3906 P) 1758.0000 'WING 3.87'50 WSNG 4'99~$'9: .LLS '076 -0.0...098 40'1:-50',00 LU 333' 2'500 TENS 0.7813 Pi 175:9 01 2 ~. LL$ DVO 8t, 6250 LDTL 5960"0'000 PAGE 5124.0000 -999.2500 -999.2500 8.6016 2,3594 3658.0000 1080,0,00,0 388.0000 633Z,.0000 0'0063 65.1250 0.0000 1.9661 2.6621 6332.0000 232.0000 80.2500 392.50'00 6088.0000 0.0039 69.7500 244 -62 50 84 ,,,ST 50 325: 108 37 6048.0000 0.0078 .8828 7.5162 4.6875 6048.00'00 222'2'500 80.0000 DE:PT 10500.0000 SGR 79.0625 CGR 56-7500 CALI 9.3828 .VP ~HO B IPHI :CNL ;SHV .ITH ;GR 'HOR 12NG i,ENS ~LS ~IO ;R }T ~ENS EPT /HO B dPHI L HV .S ~NS )E P T NL HV TH N G ~LS 0 tENS DE PT ~HOB qPHI :C.N L SSH V GITH OlO.H02 VERIFICATION.LISTING 2.6230 DRHO 17.3340 DPHI 1565.0000 QSS 1083.0000 LL 61.0313 SS1 79.06'25 CGR 10.0391 URAN 105.6875 W3NG 6428.0000 SGR 8.7813 SP 381.7500 SVO 83.0000 DTCO 67.0625 DTL 5980.0000 GR 1040'0.0000 SGR 2.3262 DRHO 24.5117 DPHI 1102.0000 QSS 1084.0000 LL 130'6250 SS1 23.7969 CGR 2.5684 URAN 37.7500 W3NG 5904,0000 SGR 0.0239 NRAT 1.5137 PEF 0.0498 QLS 119.4375 LS 223.5000 SS2 56.7500 POTA 2.9922 CS 39.7500 W4NG 79.0625 ,LLD -12.7344 DV1 5.7852 SIO 68.00,00 DTSM 67.0000 LSDT -999.2500 TENS 23.7969 CGR 0.0537 NRAT 19.5313 PEF 0.0615 QLS 215.8750 ES 255.3750 SS2 20.3594 POTA 0.4609 CS 14.5156 W4NG 23.7969 L'LD 22.4688 DTCO 84.562.5 DTL 5700.0000 GR 84. 0000 DTSM 82.6875 LSDT -999.2500 TENS 10300.0000 SGR 2.5957 DRHO 20.2637 OPMI QSS 10t LL 6 5 88. 6432.0000 URAN SGR 88.3750 0.0049 3.17'38 4 8 CGR NR AT PEF QL S LS SS2 POTA CS W'~N6 52.6563 DTCO 71.9375 OTL 5820.0000 GR 71.0'000 71.6875 -999.2500 DTSM LSDT TENS lOZO0.O000 SGR 2.6699 DRHO 20'9961 DPHI 1386.0000 QSS 1083.0000 LL 53.6875 SS1 96.6875 CGR 96.6875 0.0132 -1.'3184 0.0059 109.3750 215.8750 69.0000 CGR NRAT PEF QLS LS SS2 POTA 1.9687 2.7500 -0.0054 234.0000 284.7500 1.1230 1751.0000 14.5469 19.5868 8.6484 460.2500 118.0000 67.3750 -999.2500 20.3594 2.3828 2.3887 -0.0190 409.0000 340.7500 0.6348 1781.0000 2.9023 130.29'04 141.0000 83.2'500 -999.2500 61.5-625 2.1367 2.7'1,29 237. 289- 394. i ! 5.000 0 70.1,250 -999. 2500 69.0000 2.1875 3.1328 0. O186 213.7500 2,88.5000 0., '9277 RNRA NCNL LSHV LU TENS POTA WING WSNG LLS OVO TENS DTST LDTL CALI RNRA NCNL LSHV LO TENS POTA WING WSNG LLS DTST LOTL CALI RNRA NCNL LU WING TENS DTST LDTL CALI RNRA NC N :L LSHV LU TENS PDTA PAGE 1.9355 3030.0000 1084.0000 229.3750 6428.0000 0.0112 265.7500 6.7891 18. 2291 8.39 84 5428.0000 201.0000 65.6250 8.6016 2.5273 2786.0000 1083.0000 386.2500 5904.0000 0.0063 77.4375 2.9023 65-8869 59~ 2'0156 4'"0000 235.0000 83.3750 9.0781 2.373,0 4026.0000 1053.0000 226.3750 6432.0000 8 6432 20,4.0000 69.5000 9.0781 2.3672 3'2'8,2.0000 1083-000'0 Z08.7~00 5888.0'000 0.0093 ;VP OiO.HOZ VERIFICATION.LISTING :HOR 14.0625 /2NG 146.0000 'ENS 5888.0000 ;ALS 8.7813 )IO 416.0000 ;R 123.7500 )T 69.2500 KENS 5604.0000 )EPT 10100.0000 ~HOB 2.6641 ~PHI 23.5352 :CNL 1199.0000 ;.SHV 1082,0000 .t.TH 55,2500 ~GR 85.3750 FHDR 9.7969 ~2NG 132.3750 FENS 5392.0000 ;ALS 8.6953 )IO 427.2500 ;R 92.1250 )T 69.2500 FENS 5644°0000 URAN W3NG SGR SP SVO DTCO DTL GR SGR DRHO DPHI QSS LL SS1 CGR URAN W3NG SGR SP SV'O DTCO DTL GR 3.7070 CSr 42.5313 W4NG 96.68?5 LLD -23.7031 DV1 5.7383 SIO 71.0000 DTSM 70.2500 LSDT -999.2500 TENS 85.3750 CGR 0.,0181 NRAT -0.9277 PEF 0.0298 QLS 112.6875 LS 218.6250 552 61.0000 POTA 3.2637 CS 44.4688 W4NG 85.3750 LED -19.6563 OVl 3.9414 SI,O DTSM LSDT -999.25-00 TENS qPHI 22.3145 DPHI :CNL 1230.0000 QSS 1083.000.0 ~1 .55,625'0 SGR 87.50'00 CGR FMOR 11,8359 URAN W'3NG SGR )59 SP 87 · 50:00 0,0':i9':5 -3.7109 PEF 0.0049 QLS 104 LS 215 SS'2 68.4 POTA 2. 5547 CS 36.7500 N:4 NG 8,,.7'i~,, ,50'O,Q.~ LLD - DY,1 -99 r'HDR ¢2N G )I0 9900:,0Q0::0 $,G,R. 2'6"719 DR'HO 15.8203 DPHI 198:9,0000 QSS 1083.00'00 ll 45.5625 SS1 62'.0000 CGR 4.9805 URAN 103.3750 W3NG 6224.0000 SGR 8.6719 SP 306.5000 S¥'O 57.5313 DT:CO 6Z.. 0000 o' 04 3'5 - 1.4160 P E F 0.0435 QLS 112.4375 LS 226,.5000 SS2 33.I562 POTA 3. 8613 CS 28,984~ W4NG 62..0000 L'LO -17.53.I3 DV1 9.i328 SIO 68,'0000 DTSM 1786.00,00 WiNG 13.5391 W5NG 19.6755 LLS 9.4063 DVO 522.0000 TENS 121'.0000 DTST 7t.0000 LDTL -999.2500 61.0000 CALl 2.3828 RNRA 2.9785 NCNL 0.0361 LSHV 217.6250 LU 283.5000 TENS 1.4160 POTA 1773.0000 WI,NG 8.7031 W5NG 13.9271 LLS 6.8633 DVO 564.0000 TENS 121.000'0 D'TST 68.5000 LDTL -999.2.500 3,'6680 NCNL 0°0234 LSHV 1.4160 POTA 178:5-0'000 WING 5'~80'08 NS'NG 6.8086 DVO 71.2500 LO.T,L -999.2500 220, 0 288.50,00 0'8789 1783,0000 4,8281 36.4956 13.2266 384.7500 120.,0000 NC'NL LSHV LU TENS POTA WING W5NG LLS DVO TENS D'TST PAGE 318.0000 19.3281 15.9374 9.1953 5888.0000 204.0000 70.1250 9.3906 2.3652 2838.0000 1082.0000 210.0000 6832.0000 0.0142 276.5000 1.9336 10.1287 6.6875 6392,0000 201-0000 68.8750 _2932.0000 1083.0000 200.2500 6084-00'0'0 .0'014.2 292.0000 10.6328 8~:0~96,5 6'2656 3986.0000 1082.0000 216.7500 6224.0000 0.0088 2.12,5000 5'7969 34.4236 12.5781 6224.0000 203.000.0' .VP )T FENS )EPT ~HOB ~PHI :CNL ~SHV ,ITH ~GR ~2NG tENS ;ALS )IO ~R )T tENS )EPT RHOB ~I,PH I ~:C NL V 'TH R NG t'ENS TENS R NG TEN S CALS DI 0 ~R DT TEN S DE PT RHOB N:P H I OlO.H02 VERIFICATION.LISTING 69.7500 DTL 5588.0000 GR 69.5000 LSOT -999.2500 TENS 85.3?50 CGR 0,18T5 NRAT 4.9805 PEF 0,0586 QLS 172.8750 LS 288.2500 SS2 60.0625 POTA 3.3945 CS 44.5313 W4NG 85.3750 LLO -13.9922 DVl 2.6035 SIO 77.0000 DTSM 76.6875 LSDT 38.9687 TENS 124.9375 CGR -0.4019 NRAT -4.10'16 PEF -0.1030 QLS 50.5625 LS 65-125,0 SS2 55. 1562 W4NG 124.9375 LLD -5-5938 DV:i 0.0566 SIO 55.0000 DTSM 61.5000 LSDT 116.8750 TENS 9800.0000 SGR 2.5664 DRHO 25.0977 DPHI 874.0000 QSS 1083.0000 LL 84.8125 SSi 85.3750 CGR 8.6172 URAN 124.3125 W3NG 5872.0000 SGR 9.0625 SP 573.0000 SVO 84.5625 DTCO 76.4375 DTL 5524.0000 GR 9700.0000 SGR 2.7168 DRHO 52.0996 OPHI 397.7500 QSS 1086.0000 LL 11,3281 SS1 124.:9375 CGR 7 8567 URAN' 195.5000 W3NG 5648.0000 SGR 8.9297' SP 887.5000 SVO 111.2500 DTCO 58.2500 DTL 5348.0000 GR 9600.0000 SGR -999.2500 DRHO 999.2500 D'PHI -999!.2500 QSS -99'9.2500 ~L -999,25,00 SS1 -999.2500 CGR 99'9.2500 URAN -999.2500 W3NG -999.2500 SGR -999.2500 SP -9.99,2500 SVO -999.2500 DTCO 999.2500 DTL -999.2500 GR -999. 2500 CGR -999. 2500 NRAT -999.25,00 PE,F -999.2500 QLS -999.2500 LS -999 · 2,5'00 -999.2500 W4NG -999.2500 LLD -999.2500 DVI -999,2500 SIO -999. 2500 DTSM -99'9. 2500 LSDT 151.2500 TENS 9500.0000 SGR -999.2500 DRHO -999.2500 DPHI -99'9.2500 CGR -999.2500 NRAT -999.2500 PEF 68. 5000 -999.2500 60.0625 2.6094 3.1543 -0.0361 335.0000 370 O0 6O2 1778.20000 7. 500 6.9900 5.1328 702.5000 15'1.0000 94.2500 5060.0000 62.7188 4.0195 8,750 -- 112.5000 91.187'5 15.4844 O. 67'72 1.4541 2376.0000 94.0000 7.2. 5000 5 328 · 0000 -999.2500 -999.2500 -9 -9 -999, -999.2500 -999.2500 -999.2500 -999.250'0 -999.2500 -999.2500 5324.0000 -999.2500 -999.2500 -999.2500 LDTL CALi RNRA NCNL LSHV LD TENS POTA WING WSNG LLS DVO TENS DTST LDTL CALI RNRA NCNL LSHV LU TENS WSNG LLS D¥O TEN S DTST LDTL CALI RNRA NCNL LSHV LU' TEN S POTA WING WENG LLS DVO TENS DTST LDTL CALI RNRA NCNL PAGE 10 65.6250 11.2969 2.8047 2452.0000 1082.0000 324.5000 5872.0000 0.0166 281.7500 4.1445 5.3723 4.5000 5872.0000 229.0000 75.3750 8.9375 4.3516 173Z.0000 1083.0000 123.8750 5648.0000 12.5781 0.1452 0.6753 5648.0000 228.0000 198.0000 -999.2500 -999'2500 9:99'.2500 -999.2500 -999'2500 -999'2500 '-999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 '-999.2500 .¥P ;CNL ;SHV .IT H [GR 'HOR 12NG 'ENS ;ALS 'ENS )EPT :CNL ;SHV .ITH ~HO R ALS 0 NS HV OR !NS )T CENS )E PT ~"HO B ~PHI =CNL SSHV -I T H tHOR ~2NG OlO.H02 VERIFICATIDN,LISTING -'999.2500 QSS -999.2500 LL -999.2500 SS1 -999.2500 CGR -999.2500 URAN -999.2500 W3NG -999.2500 SGR -999.2500 SP -999 2500 SVO 999~25oo DTCO -999.2500 OTL -999,2500 GR -999.2500 QLS -999.2500 LS -999.2500 SS2 -999.2500 POTA -999.2500 CS -999.2500 W4NG -999.2500 LLO -999.2500 0V1 -999.2500 SIO -999.2500 DTSM -999,2500 LSDT 93.4375 TENS 9400.0000 SGR -999.2500 D'RHD -999.2500 DPHI -999.2500 QSS -999.2500 LL -999.2500 SS1 -999.2500 CGR -999. 2500 URAN -99:9.2500 W3NG -999.2500 SGR -999.2500 SP -999'2500 SVO -999-2500 DTCO ':999'"250'0 DTL -999.2500 GR -999,2500 CGR -999.2500 NRAT -999,2500 PEF -999.2500 QLS -999.2500 LS -999 2500 S$2 999:2500 POTA -999.2500 CS -999'2500 W'4.NG -999.2500 ELD -999.2500 DY! SIO -999.2500 75,2500 TENS 9300.0000 SGR -999-2500 DRHO -999.250'0 DPHI -999.2500 QSS LL O0 -9~ '. 50'0 - 9'99" SG R -" SP - SVO - 0 DTCO -9'99' :500 DTL' -999,2500 GR -999.2500 CGR -999,2500 NRAT -999,2500 PEF -999.2500 QLS -999-2500 LS -9 O0 POTA CS O0 LLO -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 5244.0000 9288.0000 SGR' -999,2500 DRHO -999.2500 DPHI -999.2500 QSS -999..2500 LL -999.2500 SS1 -999.2500 CGR -999.2500 URAN -999.2500 W3NG -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 '-999.2500 -999.2500 -99'9.2500 -999'2500 -999-2500 -999.2500 5180.0000 -999..25'00 -9'99'2500 -999-2500 -999-2500 -9'99,,25'00 -9~9-25':00 -999,2500 -999. __999..,~5'00 0 -9' DTSM -994 0 -99 LSDT -'999 82.6875 TENS 5120.0000 -999.2500 CGR -9.99.2500 NRAT -999.2500 PEF -999.250:0 Q'LS -999'2500 LS -999.2500 SS2 -999.2500 POTA -999.2500 CS '999.2500 W~NG -999.2500 -999.2500 '9'99.2500 -999.25'00 -999,~2500 -999-2500 -999-2500 -999.2500 -999.2500 LSHV LU TENS POTA WiNG W5NG LLS DVO TENS DTST LDTL CALI RNRA NCNL LSHV LU TENS POTA WING 'WENG LLS DVO TENS OTST LDTL CALl RNRA NCNL LSHV LU TENS POTA WING WSNG LLS DYO T;ENS DTS'T LDTL CALI RNRA NCNL LSHV' LU TENS POTA WING WENG PAGE 11 -999.2500 -9'99.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2~00 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ~999~'2500 -999.2500 -999.250'0' -9'99.2500 -999-2500 -999.2500 -999.2500 --999.2500 -999.2500 -999'2500 -999'2500 -99~ -99~ -999.2500 -999.2500 -999.2500 -999.2500 -999.2'500 -999.2500 -999.2500 -999.2500 -999.2500 .VP OlO.HO2 YERIFICA~TION.LISTING :ENS -999.2500 SGR ~ALS -999.2500 SP ~IO -999.2500 SVO ;R -999.2500 DTCD ~T -999.2500 DTL 'ENS -999.2500 GR -999.2500 LLD -999.2500 DV1 -999.2500 SIO -999.2500 DTSM -999.2500 LSDT 90.6250 TENS -999.25 oo -999.2500 -999.2500 -999.2500 -999.2500 5100.0000 LLS DVO TENS DTST LDTL P/~GE -999.2500 -999.2500 .-999.2500 -999.2500 -999.2500 12 ,~ FILE TRAILER ..4. .:.I L E NAME :EDIT .001 ;ERVICE NAME : IERSION # : )ATE : ~AXIMUM LENGTH : I024 :ILE TYPE : tEXT FILE NAME : FILE HEADER ~ LE NAME :EDIT RV'ICE NAME : ;ION # : XIMUM,LEN?TH : LE TYPE ~ EVIOUS FILE : .002 1024 DATA FORMAT ~N"TRY BLOCKS RECORD TYPE SIZE REPR CODE 2 1 66 4 ! 66 8 4 73 9 4 6.5 16 1 66 0 1 66 )~TUM SPECIFICATION BLOCKS ~NEM SERVICE SERVICE UN'IT ID ORDER # )EPT FT ~SFL DLL OHMM AP1 AP1 API API FILE LOG TYPE CLASS MOD NO. 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