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Home My WebLink About193-062Nolan 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: 1/21/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260121 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 16RD 50133205540100 207125 12/3/2025 AK E-LINE PPROF T41253 BRU 211-35 50283201890000 223050 11/7/2025 AK E-LINE Perf T41254 BRU 213-26 50283201920000 223069 11/23/2025 AK E-LINE Perf T41255 BRU 213-26T 50283202040000 225038 11/4/2025 AK E-LINE Perf T41256 BRU 241-34S 50283201980000 224077 11/9/2025 AK E-LINE Perf T41257 BRU 241-34T 50283201810000 220052 11/6/2025 AK E-LINE Perf T41258 BRU 244-27 50283201850000 222038 12/13/2025 AK E-LINE Perf T41259 BRU 244-27 50283201850000 222038 12/19/2025 AK E-LINE StripGun T41259 GP ST 17586 9 50733204480000 193062 11/13/2025 AK E-LINE Perf T41260 IRU 241-01 50283201840000 221076 12/21/2025 AK E-LINE Perf T41261 IRU 241-01 50283201840000 221076 12/30/2025 AK E-LINE Perf T41261 IRU 241-01 50283201840000 221076 12/16/2025 AK E-LINE Plug T41261 IRU 241-01 50283201840000 221076 11/26/2025 AK E-LINE Plug/Perf T41261 KALOTSA 01 50133206570000 216132 11/19/2025 AK E-LINE Perf T41262 KBU 31-18 50133206490000 215024 11/8/2025 AK E-LINE Drift/PPROF T41263 KU 12-17 50133205770000 208089 11/14/2025 AK E-LINE StimGun T41264 LRU C-01RD 50283200610100 201168 11/27/2025 AK E-LINE RCT/Perf T41265 MPI 2-32 50029220840000 190119 12/10/2025 AK E-LINE LDL T41266 MPI 2-38 50029220900000 190129 12/5/2025 AK E-LINE LDL T41267 MPU H-16 50029232270000 204190 12/3/2025 AK E-LINE CBL T41268 MPU H-16 50029232270000 204190 11/19/2025 AK E-LINE TubingCut T41268 MPU I-14 50029232140000 204119 11/13/2025 AK E-LINE CBL T41269 NCIU A-06A 50883200260100 225071 11/28/2025 AK E-LINE Perf/Plug T41270 NCIU A-08 50883200280000 169063 12/2/2025 AK E-LINE GPT T41271 NCIU A-19 50883201940000 224026 12/16/2025 AK E-LINE GPT T41272 NCIU A-19 50883201940000 224026 12/12/2025 AK E-LINE GPT/Perf/Plug T41272 NCIU A-19 50883201940000 224026 12/17/2025 AK E-LINE Perf T41272 NCIU A-21A 50883201990100 225075 12/30/2025 AK E-LINE PPROF T41273 OP19-T1N 50029234910000 213068 11/19/2025 AK E-LINE TubingPunch T41274 GP ST 17586 9 50733204480000 193062 11/13/2025 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.21 13:56:35 -09'00' 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: PCU D-10 50283202080000 225082 12/9/2025 AK E-LINE Perf T41275 SCU 322C-04 50133101040100 215217 12/4/2025 AK E-LINE TubingPunch T41276 SRU 222-33 50133207150000 223100 12/7/2025 AK E-LINE Plug T41277 SU 43-10 50133207390000 225107 11/26/2025 AK E-LINE CBL T41278 TBU A-12RD 50733200760100 171029 11/29/2025 AK E-LINE Perf T41279 TBU D-24A 50733202240100 174064 12/2/2025 AK E-LINE TubingPunch T41280 TBU D-24A 50733202240100 174064 11/21/2025 AK E-LINE TubingPunch T41280 TBU M-10 50733205880000 209154 11/15/2025 AK E-LINE Perf T41281 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.21 13:56:51 -09'00' 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: 11/20/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251120 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 23 50133206350000 214093 10/14/2025 AK E-LINE PPROF T41129 BR 09-86 50733204480000 193062 10/28/2025 AK E-LINE Perf T41130 BRU 213-26T 50283202040000 225038 10/30/2025 AK E-LINE Perf T41131 END 1-57 50029218730000 188114 11/16/2025 READ PressTempSurvey T41132 END 2-28B 50029218470200 203006 11/15/2025 READ PressTempSurvey T41133 END 2-30B 50029222280200 208187 11/18/2025 READ PressTempSurvey T41134 END 2-52 50029217500000 187092 10/28/2025 HALLIBURTON LDL T41135 KALOTSA 10 50133207320000 224147 11/7/2025 AK E-LINE Perf T41136 MPF-92 50029229240000 198193 11/8/2025 READ CaliperSurvey T41137 MPH-01 50029220610000 190086 11/7/2025 READ CaliperSurvey T41138 MPI-14 50029232140000 204119 11/8/2025 READ CaliperSurvey T41139 MPU H-01 50029220610000 190086 11/4/2025 AK E-LINE Drift/CBL/Caliper/Packer T41138 MPU I-14 50029232140000 204119 11/8/2025 AK E-LINE RigAssist T41139 MPU J-02 50029220710000 190096 11/6/2025 AK E-LINE Caliper/Gyro T41140 NCIU A-07A 50883200270100 225094 11/1/2025 AK E-LINE CBL T41141 NCIU A-07A 50883200270100 225094 11/4/2025 AK E-LINE Perf T41141 ODSN-01A 50703206480100 216008 10/24/2025 HALLIBURTON PACKER T41142 ODSN-25 50703206560000 212030 10/23/2025 HALLIBURTON PACKER T41143 ODSN-26 50703206420000 211121 11/4/2025 HALLIBURTON PERF T41144 PBU 02-10B 50029201630200 200064 10/27/2025 HALLIBURTON RBT T41145 PBU A-24B 50029207430200 225067 10/20/2025 BAKER MRPM T41146 PBU B-05E 50029202760500 225093 10/23/2025 HALLIBURTON RBT T41147 PBU B-05E 50029202760500 225093 10/23/2025 BAKER MRPM T41147 PBU B-20A 50029208420100 212026 10/16/2025 BAKER SPN T41148 PBU F-18B 50029206360200 225099 11/5/2025 HALLIBURTON RBT-COILFLAG T41149 PCU D-10 50283202080000 225082 10/31/2025 AK E-LINE Patch T41150 PCU D-10 50283202080000 225082 10/17/2025 AK E-LINE Perf T41150 PCU D-10 50283202080000 225082 10/22/2025 AK E-LINE Perf T41150 PCU D-10 50283202080000 225082 10/29/2025 AK E-LINE Perf T41150 T41130BR 09-86 50733204480000 193062 10/28/2025 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.20 13:27:19 -09'00' 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: PCU D-11 50283202090000 225088 10/16/2025 AK E-LINE CBL T41151 PCU D-11 50283202090000 225088 10/24/2025 AK E-LINE Perf T41151 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.20 13:27:31 -09'00' 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:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:FW: PTD 193-062, Sundry 325-211, Granite Pt St 17586 9, Bruce 09-86, Re-perf Date:Thursday, October 23, 2025 4:21:09 PM Attachments:image001.png From: Rixse, Melvin G (OGC) Sent: Thursday, October 23, 2025 4:19 PM To: Eric Dickerman <eric.dickerman@hilcorp.com> Subject: RE: PTD 193-062, Sundry 325-211, Granite Pt St 17586 9, Bruce 09-86, Re-perf Eric, Hilcorp is approved to reperforate as described below. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Eric Dickerman <eric.dickerman@hilcorp.com> Sent: Thursday, October 23, 2025 3:05 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: PTD 193-062, Sundry 325-211, Granite Pt St 17586 9, Bruce 09-86, Re-perf Mr. Rixse, As discussed on the phone regarding Sundry 325-211, we have completed the coiled tubing fill clean out and N2 lift. We believe that the perforations may be damaged with a water block based on a lower production rate post wellwork in comparison to pre-wellwork rates. Hilcorp is requesting approval to re-perforate the interval from 5,541’ – 5,642’, in an attempt to perforate past any damage or water block. The perforations will be performed with Eline and all runs will be fully lubricated. Steps: 1. MIRU Eline. 2. Pressure test PCE to 250 psi / 2,000 psi high (Max. potential surface pressure is 1,003 psi). 3. Perforate target interval from 5,541’ – 5,642’. 4. RDMO. Thank you, Eric Dickerman Hilcorp – CIO Ops Engineer Cell: 307-250-4013 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual orentity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us byreturn 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 onwardtransmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted bythe company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 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?N/A Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 5,950 5,630 Casing Collapse Structural Conductor Surface 1,950psi Intermediate 4,760psi Production 7,020psi Liner 7,250psi 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: Eric Dickerman Contact Email:Eric.Dickerman@hilcorp.com Contact Phone:(907) 564-4061 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 Other: CTCO, N2 4/21/2025 5,950'644' 2-7/8" & 2-3/8" 4,203' See schematic See schematic 5,481' Perforation Depth MD (ft): 1,960' 4,500 - 5,793 5,481' 5" 3,206 - 4,087 3,860'7" 30" 13-3/8" 242' 9-5/8"1,960' 565' MD 6,870psi 3,450psi 242' 565' 1,709' 242' 565' Length Size Proposed Pools: N-80 TVD Burst 4,374 & 5,550 8,160psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017586 193-062 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20448-00-00 Hilcorp Alaska, LLC Granite Pt St 17586 9 AOGCC USE ONLY 8,290psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Granite Pt Granite Pt Gas N/A 4,203 5,625 3,963 1,003psi N/A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-211 By Gavin Gluyas at 8:01 am, Apr 10, 2025 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.04.08 07:31:47 - 08'00' Dan Marlowe (1267) A.Dewhurst 10APR25 DSR-4/11/25 10-404 MGR18APR25 * BOPE test to 3000 psi. 48 hour notice. *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.18 18:36:07 -08'00'04/18/25 RBDMS JSB 042125 Fill clean out Well: GPF Bruce 09-86 Well Name:Granite Pt. St. 17586 #9 API Number:50-733-20448-00 Current Status:Online gas well Leg:Leg #1 (NW corner) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:193-062 First Call Engineer:Eric Dickerman 307-250-4013 Second Call Engineer:Casey Morse 907-777-8322 Maximum Expected BHP:1,393 psi at 3,908’ tvd SIBHP survey Max. Potential Surface Pressure (MPSP):1,003 psi Using 0.1 psi/ft gradient to surface Brief Well Summary Bruce 09-86 is a gas producer that was completed in 1993. Both the Tyonek and the Beluga sands were tested, with only the Tyonek sands having production at commercial rates. The current production rate is 61,000 scfd. In January of 2017, a coiled tubing cleanout was performed, and subsequent production rates increased to 300,000 scfd. This project is attempting to repeat the previous success and increase production rate. Objective: Coiled tubing cleanout down to the TCP fish at 5,630’. Lift the fluid head out of the well with nitrogen. Notes on wellbore condition: - 1/8/25: slickline tagged at 5,599’. - Fluid level tagged around 3,600’. Fill clean out Well: GPF Bruce 09-86 Coiled Tubing Procedure: 1. MIRU Fox Energy offshore Coiled Tubing #9 and pressure control equipment. 2. Pressure test lubricator to 250 psi low / 3,000 psi high. a. Provide AOGCC with 48 hr BOP test witness notification. 3. MU cleanout BHA. Dry tag top of fill, then begin cleaning out as deep as possible. a. Working fluid will be 6% KCl (8.6ppg). b. Add foam and nitrogen as necessary to carry solids to surface. 4. RIH and blow well dry with nitrogen. 5. RDMO CT. Attachments: 1. Wellbore Schematic 2. CT BOP Drawing (Fox energy) 3. Nitrogen procedure _____________________________________________________________________________________ Updated By: JLL 2/20/17 SCHEMATIC Granite Point Field Well: Granite Pt St 17586 #09 Last Completed: 06/10/1993 PTD: 193-062 API: 50-733-20448-00 PBTD:5,867‘TD:5,950’ 30” RKB: MSL = 5” 3 4 5 6 7 8 9 10 11 12 13 9-5/8” 7” 1 2 13-3/8” 14 15 16 17 CASING DETAIL Size Wt Grade Conn ID Top Btm 30” Conductor 29” Surf 242’ 13-3/8” 68 K-55 BTC 12.415” Surf 565’ 9-5/8” 47 N-80 BTC 8.681” Surf 1,960’ 7” 29 N-80 BTC 6.184” Surf 5,481’ 5” 15 N-80 BTC 4.408” 5,306’ 5,950’ TUBING DETAIL 2-7/8” 6.4 N-80 BTC 2.441” Surf 4,374’ 2-3/8” 4.6 N-80 BTC 1.995” 4,374’ 5,550’ PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Beluga 4,500’ 4,558’ 3,206’ 3,243’ 58’ 06/20/1993 Beluga 4,730’ 4,734’ 3,353’ 3,356’ 4’ 06/20/1993 Beluga 4,740’ 4,763’ 3,359’ 3,374’ 23’ 06/20/1993 Beluga 5,000’ 5,016’ 3,530’ 3,541’ 16’ 06/20/1993 Beluga 5,022’ 5,042’ 3,545’ 3,558’ 20’ 06/20/1993 Tyonek 5,541’ 5,642’ 3,903’ 3,976’ 101’ 06/13/1993 Tyonek 5,707’ 5,793’ 4,023’ 4,087’ 86’ 06/13/1993 JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 42.85’ 42.8’ Vetco Grey 10.75” hanger 1 287’ 287’ 2.313” 4.750” Otis SSSV permanently locked out 12/1/2001 1.125 2.313 Macco WFII 9’ 10” long. Requires 10’ 6” prong to pull 2 4,374’ 3,128’ 1.990” 3.520” XO 2-3/8” x 2-7/8” 3 4,403’ 3,146’ 1.875” 3.050” Otis XA Sliding Sleeve 4 4,444’ 3,171’ 3.250” 6.000” Otis HVT Packer 5 4,503’ 3,208’ 1.995” 5.870” Y Block w/ 73.64’ 2.75” TCP gun hung to side of tubing 6 4,587’ 3,261’ 1.875” 3.050” Otis XA Sliding Sleeve 7 4,680’ 3,321’ 4.000” 5.875” Otis BWH Packer w/ seal bore extension 8 4,730’ 3,353’ 1.995” 5.870” Y Block w/ 51.20’ 2.75” TCP gun hung to side of tubing 9 4,790’ 3,392’ 1.875” 3.050” Otis XA Sliding Sleeve 10 4,958’ 3.502’ 4.000” 5.875” Otis BWH Packer w/ seal bore extension 11 5,007’ 3,535’ 1.995” 5.870” Y Block w/ 52.51’ 2.75” TCP gun hung to side of tubing 12 5,068’ 3,576’ 1.875” 3.050” Otis XA Sliding Sleeve 13 5,269’ 3,713’ 4.000” 5.875” BWH Packer w/ seal bore extension 14 5,292’ 3,728’ 1.995” 5.750” TIW Locator 15 5,472’ 3,854’ 1.875” 3.050” Otis XA Sliding Sleeve 16 5,514’ 3,883’ 1.995” 3.070” Ported Sub 17 5,550’ 3,909’ 3.380” Tail - Auto TCP Gun Release Sub Fish: 5,630’ (CTM) – Top of Fish, 261’ 3-3/8” 4spf Vann Guns KLU A-1 Well Head Rig Up 1 1 1 1 4 1/16" 15K Lubricator - 10 ft 100" Gooseneck HR680 Injector Head 4 1/16" 10K Flow Cross, 2" 1502 10k Flanged Valves 4 1/16" 15K Lubricator - 10 ft API Flange Adapter 10K to 5K for riser/wellhead Hydraulic Stripper 4 1/6" 15K API Bowen CB56 15K 4 1/16" 10K Combi BOPs Blind/Shear Ram Pipe/Slip Ram 4 1/16" 10K bottom flange 4 1/16" 5K flanged Riser - 10 ft if necessary STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Barney Phillips To:Regg, James B (OGC) Subject:RE: [EXTERNAL] RE: SVS GP Bruce 05-3-24 Date:Saturday, May 4, 2024 10:30:44 AM Attachments:SVS GP Bruce 05-3-24 MISC rev.xls Hello Jim, Seems my tubing pressure entry skewed the test. The 220 PSI listed was SITP as we had the well shut in & it built during SSSV installation. The actual flowing pressure of the well is 63 PSI. I revised the form in hopes this will bring us back in to range on low pilot. Many thanks, Barney From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Saturday, May 4, 2024 8:37 AM To: Barney Phillips <bphillips@hilcorp.com> Subject: [EXTERNAL] RE: SVS GP Bruce 05-3-24 The self-test result is a FAIL; the low pressure pilot tripped lower than required by regulation. Minimum trip for this test was 55 psi (based on tubing). Link to SVS regulation is 20 AAC 25.265, paragraph(h)(9) – “the system actuation pressure of the low- pressure mechanical or electrical detection device installed on a production well must be at least 50 percent of the separator inlet pressure or at least 25 percent of the flowing tubing pressure, whichever is greater” Regulation goes on to further require that the device must immediately be repaired or replaced and performance tested, or the well must be shut in (paragraph (i)(1). Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Barney Phillips <bphillips@hilcorp.com> Sent: Saturday, May 4, 2024 7:24 AM Granite Pt 17586 9 PTD 1930620 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. To: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: SVS GP Bruce 05-3-24 Good morning, Please find attached single well test report for Well # 17586 09 self-test performed 5/3/24. The wireline retrievable SV was pulled in order to perform other down hole work and same SV was re-set and self-tested on 5/3/24 at 150 PSI-DP. Request for Inspector for Witness has been submitted. Many thanks, Barney Phillips bphillips@hilcorp.com 907-394-2454 Mobile The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Date:5/3/2024 LPS 65 HPS SSV SSSV Retest/SI Date Well Type Gas Lift Waiver Well Permit Separ Set L/P Test Test Test Date Passed Retest Inner Outer Tubing Yes/No Yes/No Number Number PSI PSI Trip Code Code Code Or Date Shut In PSI PSI PSI 17586 09 1930620 65 45 48 P P P GAS 530 315 63 NO NO Wells:1 3 Failures:0 0.00% Well Pressures Operator Rep:Stuart Allison Field/Unit/Pad:GP HAK Bruce Platform Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator:Hilcorp Energy Submitted By:Barney Phillips Remarks:Well # 17586 09 wireline retrievable SSSV was pulled in order to perform wireline operatio AOGCC Rep:None Separator psi: Well Data Pilots down hole. SSSV was re-set and self tested good at 150 PSI-DP. Oil, WAG, GINJ, GAS, CYCLE, SI Components:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day PLB 01/26/11 Page 1 of 1 2024-0503_SVS_GPF_Bruce_9-86_revised REVISED REPORT   J. Regg; 5/6/2024 Date:5/3/2024 LPS 65 HPS SSV SSSV Retest/SI Date Well Type Gas Lift Waiver Well Permit Separ Set L/P Test Test Test Date Passed Retest Inner Outer Tubing Yes/No Yes/No Number Number PSI PSI Trip Code Code Code Or Date Shut In PSI PSI PSI 17586 09 1930620 65 45 48 P P P GAS 530 315 220 NO NO Wells:1 3 Failures:0 0.00% Well Pressures Operator Rep:Stuart Allison Field/Unit/Pad:GP HAK Bruce Platform Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator:Hilcorp Energy Submitted By:Barney Phillips Remarks:Well # 17586 09 wireline retrievable SSSV was pulled in order to perform wireline operatio AOGCC Rep:None Separator psi: Well Data Pilots down hole. SSSV was re-set and self tested good at 150 PSI-DP. Oil, WAG, GINJ, GAS, CYCLE, SI Components:Failure Rate:90 Day 90 Day 90 Day 90 Day 90 Day PLB 01/26/11 Page 1 of 1 2024-0503_SVS_GPF_Bruce_9-86 Required trip pressure is 55 psi or above based on reported tubing pressure; Fail Code 3. -- J. Regg; 5/3/2024 == 1 Regg, James B (OGC) From:Regg, James B (OGC) Sent:Monday, November 28, 2022 2:43 PM To:bphillips@hilcorp.com Subject:RE: AOGCC Test Witness Notification Request: SVS, GPP-Platform Bruce Thank you for sending result for test for Granite Point 17586 Bruce 9 (PTD 1930620) on 11/21/2022. AOGCC witness is waived based on that passing test. Jim Regg Supervisor, Inspections AOGCC 333 W. 7 th Ave, Suite 100 Anchorage, AK 99501 907 793 1236 From:Jotform <noreply@jotform.com> Sent:Tuesday, November 22, 2022 7:05 AM To:DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; ced svc ogcforms (CED sponsored) <ced ogc jotforms@alaska.gov> Subject:AOGCC Test Witness Notification Request: SVS, GPP Platform Bruce Question Answer Type of Test Requested:SVS Requested Time for Inspection 11 25 2022 8:00 AM Location GPP Platform Bruce Name Barney Phillips E mail bphillips@hilcorp.com Phone Number (907) 394 2454 Company Hilcorp Other Information: Well BR9 86 WLSV pulled to perform gyro work 11/20/22. Same WLSV reset and self tested 150 PSI DP 11/21/22. Requesting Inspector for witness. In lieu of holiday, suggesting Friday or later. Submission ID:5449423031316036547 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. Granite Point 17586 Bruce 9 (PTD 1930620) 1 Regg, James B (OGC) From:Barney Phillips <bphillips@hilcorp.com> Sent:Tuesday, November 22, 2022 7:12 AM To:Brooks, Phoebe L (OGC) Cc:Regg, James B (OGC) Subject:SVS GP Bruce 11-21-22 MISC Attachments:SVS GP Bruce 11-21-22 MISC.xls Good morning, Please find attached single well test report for Well # 17586 09 self test performed 11/21/22. The wireline retrievable SV was pulled in order to run a gyro survey on 11/20/22 and same SV was re set and self tested on 11/21/22. Request for Inspector for Witness has been submitted. Have a great Thanksgiving, Barney Phillips bphillips@hilcorp.com 907 394 2454 Mobile 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. 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. Date: 11/21/2022 LPS 65 HPS SSV SSSV Retest/SI Date Well Type Gas Lift Waiver Well Permit Separ Set L/P Test Test Test Date Passed Retest Inner Outer Tubing Yes/No Yes/No Number Number PSI PSI Trip Code Code Code Or Date Shut In PSI PSI PSI 17586 09 1930620 65 45 48 P P P GAS 505 310 78 NO NO Wells:1 3 Failures:0 0.00% Well Pressures Operator Rep: Stuart Allison Field/Unit/Pad: GP HAK Bruce Platform Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Hilcorp Energy Submitted By: Barney Phillips Remarks:Well # 17586 09 wireline retrievable SSSV was pulled in order to perform wireline gyro sur AOGCC Rep: Separator psi: Well Data Pilots down hole on 11/20/22. SSSV was re-set and self tested good at 150 PSI-DP on 11/21/22. Oil, WAG, GINJ, GAS, CYCLE, SI Components: Failure Rate: 90 Day 90 Day 90 Day 90 Day 90 Day PLB 01/26/11 Page 1 of 1 SVS GP Bruce 11-21-22 MISC (002) From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:SVS - Granite Pt Bruce Platform Date:Monday, November 28, 2022 2:55:23 PM Attachments:2022-1121_SVS_GranitePt_17586_Bruce-9.pdf Granite Pt State 17586 9 (PTD 1930620) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 STATE OF ALASKA • ALIRA OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing 0 Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well 0 Other: CTU Clean Out w/N20 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 193-062 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic Service 0 6.API Number: Anchorage,AK 99503 50-733-20448-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0017586 Granite Pt St 17586 9 RECEIVED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Granite Pt Field/Undefined Gas Pool FFR 21 1017 11.Present Well Condition Summary: Total Depth measured 5,950 feet Plugs measured N/A fee """C`°'� true vertical 4,203 feet Junk measured 5,630 feet Effective Depth measured 5,625 feet Packer measured See Schematic feet true vertical 3,963 feet true vertical See Schematic feet Casing Length Size MD TVD Burst Collapse Structural Conductor 242' 30" 242' 242' Surface 565' 13-3/8" 565' 565' 3,450 psi 1,950 psi Intermediate 1,960' 9-5/8" 1,960' 1,709' 6,870 psi 4,760 psi Production 5,481' 7" 5,481' 3,860' 8,160 psi 7,020 psi Liner 644' 5" 5,950' 4,203' 8,290 psi 7,250 psi Perforation depth Measured depth 4,500-5,793 feet True Vertical depth 3,206-4,087 feet 2-7/8" 6.4#/N-80 4,374'(MD) 3,128'(TVD) Tubing(size,grade,measured and true vertical depth) 2-3/8" 4.6#/N-80 5,550'(MD) 3,909'(TVD) Packers and SSSV(type,measured and true vertical depth) Packers(x4)See Schematic Otis SSSV 287'(MD)287'(TVD) 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A CASti*D L Treatment descriptions including volumes used and final pressure: lT N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing PressureTubing Pressure Prior to well operation: 0 0 0 610 860 Subsequent to operation: 0 0 0 500 1085 14.Attachments(required per 20 AAC 25.070;25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory Development Service❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ 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: 316-595 Contact Dan Marlowe(907)283-1329 Email dmarlowe@hilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature L c--:) Phone (907)777-8356 Date 2 /Zo/LL 7 2.24./7 7,,, ,::41' ,, Form 10-404 Revised 5/201507 Submit Original Only RBDMS l/'- FEB 17,2017 Last Complete • • Granite Point Field • 11Well:Granite Pt St 17586#09 SCHEMATIC PTD:193 062 d:06/10/1993 Ililcarp Alaska,LLC API: 50-733-20448-00 RKB:MSL= CASING DETAIL I 1 l Size Wt Grade Conn ID Top Btm 30" Conductor 29" Surf 242' 30" 13-3/8" 68 K-55 BTC 12.415" Surf 565' [ [ 9-5/8" 47 N-80 BTC 8.681" Surf 1,960' 7" 29 N-80 BTC 6.184" Surf 5,481' 13-3/8" 5" 15 N-80 BTC 4.408" 5,306' 5,950' TUBING DETAIL 9-5/8 2-7/8" 6.4 N-80 BTC 2.441" Surf 4,374' 2-3/8" 4.6 N-80 BTC 1.995" 4,374' 5,550' JEWELRY DETAIL No Depth Depth ID OD Item (MD) (ND) 42.85' 42.8' Vetco Grey 10.75"hanger 1 287' 287' 2.313" 4.750" Otis SSSV 2 2 4,374' 3,128' 1.990" 3.520" XO 2-3/8"x 2-7/8" 3 4,403' 3,146' 1.875" 3.050" Otis XA Sliding Sleeve 4 4,444' 3,171' 3.250" 6.000" Otis HVT Packer 3 iTf1 5 4,503' 3,208' 1.995" 5.870" Y Block w/73.64'2.75"TCP gun hung to side of tubing 4 6 4,587' 3,261' 1.875" 3.050" Otis XA Sliding Sleeve 7 4,680' 3,321' 4.000" 5.875" Otis BWH Packer w/seal bore extension •e 5 . ... 8 4,730' 3,353' 1.995" 5.870" Y Block w/51.20'2.75"TCP gun hung to side of tubing 6 9 4,790' 3,392' 1.875" 3.050" Otis XA Sliding Sleeve 7 10 4,958' 3.502' 4.000" 5.875" Otis BWH Packer w/seal bore extension Iii 5,007' 3,535' 1.995" 5.870" Y Block w/52.51'2.75"TCP gun hung to side of tubing 8� 12 5,068' 3,576' 1.875" 3.050" Otis XA Sliding Sleeve �• 8 13 5,269' 3,713' 4.000" 5.875" BWH Packer w/seal bore extension 14 5,292' 3,728' 1.995" 5.750" TIW Locator 9 "' 15 5,472' 3,854' 1.875" 3.050" Otis XA Sliding Sleeve 10 16 5,514' 3,883' 1.995" 3.070" Ported Sub • 17 5,550' 3,909' 3.380" Tail-Auto TCP Gun Release Sub •• 11 12 (T(. 13 PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status 14 Beluga 4,500' 4,558' 3,206' 3,243' 58' 06/20/1993 01 IM Beluga 4,730' 4,734' 3,353' 3,356' 4' 06/20/1993 Beluga 4,740' 4,763' 3,359' 3,374' 23' 06/20/1993 $ E Beluga 5,000' 5,016' 3,530' 3,541' 16' 06/20/1993 15 1TI. Beluga 5,022' 5,042' 3,545' 3,558' 20' 06/20/1993 a IMF ► Tyonek 5,541' 5,642' 3,903' 3,976' 101' 06/13/1993 y- 16 It; Tyonek 5,707' 5,793' 4,023' 4,087' 86' 06/13/1993 • 17 Fish: 5,630'(CTM)—Top of Fish,261'3-3/8"4spf Vann Guns A T PBTD:5,867' TD:5,950' Updated By:JLL 2/20/17 f Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Granite Pt St 17586 9 CTU 50-733-20448-00 196-062 1/21/17 , 1/24/17 Daily Operations: 01/21/17-Saturday Fire up eq. blow through lines, drain riser. Swap wellhead hatch covers. Bleed off pressure, break off tree cap from 9- 86. Pull BOPE w/riser from 3-87. M/u on 9-86. M/u coil connector, pull test t/20k,good. M/U MHA,flood surface lines & 1.5" coil w/brine.Test connector& MHA t/250/4500.good. M/U GS spear. Stab lubricator, fill stack, shell test 250 low 4500 high 5 min each. Had leak at reel 1502 connection on high test, bleed off, replace rubber& retest good. (AOGCC Jim Regg granted waiver to continue working off of BR 3-87 BOPE test from 1-15-17. Shell testing break at tree connection, choke & kill line breaks from moving BOPE f/3-87 to 9-86). RIH t/4300' CBU. Cont. in hole tag choke, p/u w no op, set back down 5k, p/u 20k op, set back down p/u came free. POOH recovering down hole choke. C/O coil connector, displace coil &surface lines t/brine for winterization. Rest crew. 01/22/17-Sunday PJSM. Start&test eq., blow through surface lines, mix brine for freeze protect.Test BOPE as per Hilcorp&AOGCC requirements. AOGCC witness waived by Jim Regg @ 1:01 pm on 1-20-17, test all to 250 low/4500 high. M/U BHA- 1.5" nozzle, stab lubricator, p/t 250 low-4500 high good. Displace brine to tank from coil. Rih t/4391 (CTM ) tag, wash down t/5625' pumping @ 1.15bpm, 2980 psi,tagged bridges at 4475,4964, 5291. CBU, while POOH t/4300'. Shut down monitor well, static. PJSM. Fire up N2 pump, start pumping taking returns to diffuser tank, icp 2100 coil, 260 ann, when good returns. Rih while pumping t/5000', with N2 on back side. POOH t/2800' returns to tank dry. Shut down pump& shut in choke. Cont. POOH secure well with 570psi on tubing. Winterize & shut down for night. 01/23/17- Monday Rest crew's, monitor well pressure at 930psi. Bleed nitrogen from well to diffuser tank,final pressure 550 psi,45% LEL. Turn well to production to test. Housekeeping, wk on prepping to rig down. R/u &drain fluids to production. R/u vac unit to clean tank. Pack up hoses. R/u pump line to production. 01/24/17-Tuesday PJSM. R/d coil unit& prep for boat. Partially clean diffuser tank, backload boat, load CTU crew on boat. OF ?It, • I v77 sA THE STATE Alaska Oil and Gas of A T ASKA Conservation Commission s _ = 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 AL AS Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis SCOW FEB 27 2Q 1?, Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Granite Point Field,Undefined Gas Pool, GPS 17586 9 Permit to Drill Number: 193-062 Sundry Number: 316-595 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, aZ4 Cathy . Foerster Chair DATED this 2iday of November, 2016. RBDMS 0-. NOV 2 8 20113 • • RECEIVED STATE OF ALASKA NOV 18 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other. CTU Clean Out w/N2 I] 2.Operator Name: 4.Current Well Class: 5.Pend to Drill Number. Hilcorp Alaska,LLC • Exploratory ❑ Development 0, 193-062 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20448-00 ` 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A / Will planned perforations require a spacing exception? Yes 0 No❑ / Granite Pt St 17586 9 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017586 " Granite Pt Field/Undefined Gas Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVDAN: Effective Depth MD: Effective Depth ND: MPSP(psi): / Plugs(MD): Junk(MD): 5,950 4170 4,05 t992 5,867 4,141 1,400 psi N/A 5,630 Casing Length Size MD TVD Burst Collapse Structural Conductor 242' 30" 242' 242' Surface 565' 13-3/8" 565' 565' 3,450 psi 1,950 psi Intermediate 1,960' 9-5/8" 1,960' 1,709' 6,870 psi 4,760 psi Production 5,481' 7" 5,481' 3,860' 8,160 psi 7,020 psi Liner 644' 5" 5,950' 4,203' 8,290 psi 7,250 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 4,500-5,793 + 3,206-4,087 2-7/8" 6.4#/N-80 4,374' 2-3/8" 4.6#/N-80 5,550' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Packers x4(see schematic)&Otis SSSV Packers x4(see schematic)&SSSV 287'(MD)287'(TVD) / 12.Attachments: Proposal Summary 3 Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic❑ Development I]` Service 0 14.Estimated Date for 15.Well Status after proposed work: 12/2/2016 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS 0 ' WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmarloweCaahilcorD.corrt Printed Name Stan W.Golis ,,� Title Operations Manager Signature ' tl 4_ Phone (907)777-8356 Date I i / lee I l C.. COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: , _ C5.6 C--r Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ LocationnClearance ❑ Other: V 4 S00 `05 C2f y t (C. .r h1 44S F- t t \-2_,--L\ 1 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: / O ^41 ©H �S <✓ NOV 8 2818 APPROVED BY R�® Approved by: 19QCOMMISSIONER THE COMMISSION Date:)/ _ 22 —/t Ka 1 ath c' ,.r aA//6 �//2/i(, sinFoo �j3f3 jIt4jIId rm 10-403 Revised 11/2015 for 2 months from the date of app vol. Attachments in Duplicate Well Work Prognosis Well: BR 09-86 Hilrnrp Ala,ka,LELDate: 11/14/16 Well Name: GRANITE PT ST 17586#9 API Number: 50-733-20448-00 (BR 9-86) Current Status: S/I Gas Well Leg: Leg#1 (North) Estimated Start Date: 12/02/2016 Rig: Coil Tubing Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 193-062 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904(M) Second Call Engineer: Stan Golis (907) 777-8356 (0) Current Bottom Hole Pressure: 1,400 psi @ 3,900'TVD 0.359 psi/ft(6.90 ppg)SIBHP survey Maximum Expected BHP: 1,400 psi @ 3,900'TVD 0.359 psi/ft(6.90 ppg)SIBHP survey Maximum Potential Surface Pressure: 1,400 psi worst case using gas only in wellbore Brief Well Summary: The BR 9-86 is a gas producer completed in 1993. It is currently plugged at the downhole choke at 4,403'.This procedure will clean out the fill blocking the tubing, remove the choke and cleanout any fill down to the TCP fish at 5,630'. Safety Concerns: • Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. • Consider tank placement based on wind direction and current weather forecast(venting methane and __Nitrogen duringtbis job)vSj . • Ensure all crews are aware of stop job authority(Review Standard Well Procedure—Nitrogen Operations)v Procedure: 1. MIRU Coil Tubing. 2. NU BOP and test to 250psi low�4,500psi High._(Note: Notify AOGCC 48 hours in advance of test) 3. RIH cleaning out fill to downhole choke at 4,403'. Circulate bottoms up. If returns are not present, see attached Standard Well Procedure—Nitrogen Operations. Fluids will be Filtered Inlet Water.All returns will be to open top rig tanks(non-enclosed) 4. POOH with coil 5. RIH and pull orifice in XA Sleeve at 4,403' 6. RIH cleaning out fill to±5,630' 7. Unload well to open top tank 8. POOH with coil 9. RD coil and turn well over to operations. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Coil Tubing BOP Drawing 4. Standard Well Procedure—Nitrogen Operations 5. Flow Diagrams 6. RWO Sundry Revision Change Form • • Granite Point Field .11 Well:Granite Pt St 17586#09 • SCHEMATIC Last PTD: 193-062 Completed:06/10/1993 Hilcora Alaska,LLC API: 50-733-20448-00 RKB:MSL= CASING DETAIL Size Wt Grade Conn ID Top Btm 1 30" Conductor 29" Surf 242' 30' 13-3/8" 68 K-55 BTC 12.415" Surf 565' [ [ 9-5/8" 47 N-80 BTC 8.681" Surf 1,960' 7" 29 N-80 BTC 6.184" Surf 5,481' 13-3/8" 5" 15 N-80 BTC 4.408" 5,306' 5,950' TUBING DETAIL 9-5/8" 2-7/8" 6.4 N-80 BTC 2.441" Surf 4,374' 2-3/8" 4.6 N-80 BTC 1.995" 4,374' 5,550' JEWELRY DETAIL No Depth Depth ID OD Item (MD) (TVD) 42.85' 42.8' Vetco Grey 10.75"hanger 1 287' 287' 2.313" 4.750" Otis SSSV 2 iM 2 4,374' 3,128' 1.990" 3.520" XO 2-3/8"x 2-7/8" ^,Lit.)--- -,/-- ✓L 3 4,403' 3,146' 1.875" 3.050" Otis XA Sliding Sleeve(with 3/16"retrievable choke) 4 4,444' 3,171' 3.250" 6.000" Otis HVT Packer 3 00Q ...---i 1 5 4,503' 3,208' 1.995" 5.870" Y Block w/73.64'2.75"TCP gun hung to side of tubing 4 I= r' 6 4,587' 3,261' 1.875" 3.050" Otis XA Sliding Sleeve e " 7 4,680' 3,321' 4.000" 5.875" Otis BWH Packer w/seal bore extension 5 8 4,730' 3,353' 1.995" 5.870" Y Block w/51.20'2.75"TCP gun hung to side of tubing 6 0 9 4,790' 3,392' 1.875" 3.050" Otis XA Sliding Sleeve 10 4,958' 3.502' 4.000" 5.875" Otis BWH Packer w/seal bore extension 7 11 5,007' 3,535' 1.995" 5.870" Y Block w/52.51'2.75"TCP gun hung to side of tubing 8 _....—.= 12 5,068' 3,576' 1.875" 3.050" Otis XA Sliding Sleeve 13 5,269' 3,713' 4.000" 5.875" BWH Packer w/seal bore extension 14 5,292' 3,728' 1.995" 5.750" TIW Locator 9 '000 15 5,472' 3,854' 1.875" 3.050" Otis XA Sliding Sleeve 10 /_ 16 5,514' 3,883' 1.995" 3.070" Ported Sub 17 5,550' 3,909' 3.380" Tail-Auto TCP Gun Release Sub i 11 12 'OOQ 13 E PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 14 Beluga 4,500' 4,558' 3,206' 3,243' 58' 06/20/1993 Beluga 4,730' 4,734' 3,353' 3,356' 4' 06/20/1993 Beluga 4,740' 4,763' 3,359' 3,374' 23' 06/20/1993 Beluga 5,000' 5,016' 3,530' 3,541' 16' 06/20/1993 Beluga 5,022' 5,042' 3,545' 3,558' 20' 06/20/1993 15 000 a IL Tyonek 5,541' 5,642' 3,903' 3,976' 101' 06/13/1993 16 11111 Tyonek 5,707' 5,793' 4,023' 4,087' 86' 06/13/1993 17~ Fish: 5,630'(CTM)–Top of Fish,261'3-3/8"4spf Vann Guns 5„ • — 1 PBTD:5,867' TD:5,950' Updated By:JLL 11/14/16 • Granite Point Field • Well:Granite Pt St 17586#09 • PROPOSED Completed:Last 06/10/1993 PTD: 193-062 Hilcorp Alaska,LLC API: 50-733-20448-00 RKB:MSL= CASING DETAIL I 1 I Size Wt Grade Conn ID Top Btm 30" Conductor 29" Surf 242' 30' 13-3/8" 68 K-55 BTC 12.415" Surf 565' L [ 9-5/8" 47 N-80 BTC 8.681" Surf 1,960' 7" 29 N-80 BTC 6.184" Surf 5,481' 13-3/8" 5" 15 N-80 BTC 4.408" 5,306' 5,950' TUBING DETAIL 9-5/g' 2-7/8" 6.4 N-80 BTC 2.441" Surf 4,374' 2-3/8" 4.6 N-80 BTC 1.995" 4,374' 5,550' JEWELRY DETAIL No Depth Depth ID OD Item (MD) (ND) 42.85' 42.8' Vetco Grey 10.75"hanger 1 287' 287' 2.313" 4.750" Otis SSSV 2 2 4,374' 3,128' 1.990" 3.520" XO 2-3/8"x 2-7/8" 3 4,444' 3,171' 3.250" 6.000" Otis HVT Packer 4 4,503' 3,208' 1.995" 5.870" Y Block w/73.64'2.75"TCP gun hung to side of tubing 5 4,587' 3,261' 1.875" 3.050" Otis XA Sliding Sleeve 3 NM = 6 4,680' 3,321' 4.000" 5.875" Otis BWH Packer w/seal bore extension 7 4,730' 3,353' 1.995" 5.870" Y Block w/51.20'2.75"TCP gun hung to side of tubing 4 — 8 4,790' 3,392' 1.875" 3.050" Otis XA Sliding Sleeve 5 9 4,958' 3.502' 4.000" 5.875" Otis BWH Packer w/seal bore extension 6M.OOQ 10 5,007' 3,535' 1.995" 5.870" Y Block w/52.51'2.75"TCP gun hung to side of tubing 11 5,068' 3,576' 1.875" 3.050" Otis XA Sliding Sleeve I — 12 5,269' 3,713' 4.000" 5.875" BWH Packer w/seal bore extension 7 13 5,292' 3,728' 1.995" 5.750" TIW Locator 14 5,472' 3,854' 1.875" 3.050" Otis XA Sliding Sleeve 8 OUB 15 5,514' 3,883' 1.995" 3.070" Ported Sub 9 r„ 16 5,550' 3,909' 3.380" Tail-Auto TCP Gun Release Sub 10= 11 00Q 12 7 PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status 13 Beluga 4,500' 4,558' 3,206' 3,243' 58' 06/20/1993 Beluga 4,730' 4,734' 3,353' 3,356' 4' 06/20/1993 Beluga 4,740' 4,763' 3,359' 3,374' 23' 06/20/1993 E Beluga 5,000' 5,016' 3,530' 3,541' 16' 06/20/1993 14 000 Beluga 5,022' 5,042' 3,545' 3,558' 20' 06/20/1993 II Tyonek 5,541' 5,642' 3,903' 3,976' 101' 06/13/1993 _ 7" 15 Mr Tyonek 5,707' 5,793' 4,023' 4,087' 86' 06/13/1993 16 Fish: 5,630'(CTM)–Top of Fish,261'3-3/8"4spf Vann Guns '.r 5„ • ' PBTD:5,867' TD:5,950' Updated By:ILL 11/14/16 • • Bruce Platform . 11 Coiled Tubing BOP Ihtvurp:itia,kn.t.1R,, 11/08/2016 Lubricator to injection head k 3 0 (421471) I 1 _ _ T1 // t_ __ Blind/Shea 1/1610 Blind/Shear _ :J --_ C -_-1 c= Blind/Shear Blind/Shear^_ -J Cr— 0 '' 000 _—CI— • _ _ €_ Slip — Slip _ .-j C –__ i __-/ c_ Pipe Pipe __ _ ! -1 o I( 0 ( �ot o ]IIIIII Manual Manual Manual Manual 2 1/16 10M 2 1/16 10M 2 1/16 10M 2 1/16 10M Valve,swab,CIW-FL, ®®�IP' 3 1/16 10M FE,HWO •�J ®° Valve,wing,CIW-FL, li- ® 3 1/16 10M FE,HWO Valve,master,CIW-FL .e 3 1/16 10M FE,HW TIP' 's1V N � co 'UI— = � — — i aa) o ° o > m , yl 0 asc x al cococo � ..7 -c oE -c. 8� • III Ill N- J a U J CL N n c a) - iPI1111114q W c- E ; O L Z a il. N N Q O 0 N O Z N Cr a) _ a� ,t,,.....,......:1., .., ..., .+.0 2 f iIi . apIII'�I: �� o J■ iG- a) a 6_, ! c \ ��I II Y or. i .:. ►f"T� 1141 W a-4,!y - ++ O 0'ill Ofd t J ®C c0 J a1 c 0 ll' Nv ,V ~ m a 11 N N ^' Z .. ,i1.111111.611111111114,- lpv ° ea," i �ii' 1) m a '�I •— c V R I�� U c Y 2 w I� i� EL' H(13.9 N Ia_,IF1•1[®]. s♦ C 0 t I ENO MI CM -1C L • a w\ .10 `� ;i : ffIii III ice,_ 1ii hi ii li 1II� is . mmm� 6 ' \\ I. . ._ . . 8 ` la �n "4 YO o eu. FY CM �v2 N co O�m LL yN S O /C in J Q lD'C O <O y o m� O.0 o mV 0 w5 m a'c SSS �U) U-I va ( 4� • „ ll •STANDARD WELL PROCEDURE llikrnp Alaska,LLC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure supplier has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. 09/23/2016 FINAL v-offshore Page 1 of 1 • • § kms :t-1ep /> W2 • & , 03 c 2E % oco \ / 2 k0_ § / « � E ® Eo E -o ot � �. = § I �� f a a < ±.- 7 / 2 CD ® e f2�k = ƒ Fq CD /B a2 cs � 2.2 §/ co -0 ■ ■ � �O ow L k 1"; a. $ CO§ �>- CO OL * = f @ CO � U B o O C _o , O k � a 14. ' \k a) Co ge C a e CD _c� U 0 \ 0 # \ \ k w 112 E G © : 2 O k ƒ •/ a o a _0 / t \ / c »% CO c § 7 / 2 . Cl) Q0 C w > 2 ¢ o 2 @ o > ± ■ 0 0 0.� a # 1■ 04 « / 0 0. ca 47. / Q 0 Et E o v) q Q $ X 2 » ■ I-as a) k ■ 46 / a- 0 / k to' 0 E U) 0 n 2 � 4 li 172 - p M .. © - % $ - & , -o E 0 > CO 0 0 ex co k 9 0 < a. · XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED -[] Logs-of various kinds . [] Other COMMENTS: Scanned by: Dianna Vincent Nathan Lowell Date: TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si MEMORANDUM TO: Julie Heusser, Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: December 8, 2000 THRU: john CriSp,, ~~~:. P. I. Supervisor FROM: John Crisp, SUBJECT: Petroleum Inspector Platform Inspection Anna & Bruce Platforms Granite Point Field December 8, 2000; I traveled to UNOCAL's Anna & Bruce Platforms in the Granite Point Field. I arrived on the Anna Platform at 9'30 am and did a walk through inspection of the facility. I inspected all the wells on the platform. The Unocal production personnel were preparing for wireline work & I conducted inspections on my own with no problems encountered. PlatfOrm is Clean & in good condition. From the Anna I made the 5-minute helicopter trip to the Bruce Platform arriving at 1200 hrs. I performed a walk through inspection of the facility. Lead operator Mike Petrov, at my request, performed a-test of the safetY system on producing ..gas well B-9. The surface and sub surface safety valves as well as the pressure switch functioned properly passing their tests. Unocal's HSE Rep. Archie Cook was on the Bruce Platform during my inspection. I stated to Mr. Cook my appreciation of UnoCal's production personnel ( in their under-manned status ) testing Safety Systems on the Platforms upon my request. SUmmary; I performed the platform inspection on UNOCAL's Anna & Bruce platforms in the Granite Point Field. Bruce Platform,1 well, 3 components tested. No failures witnessed. Attachments: sVs Bruce Pit. 12-08-00jc NON-CONFIDENTIAL Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: Unocal Operator Rep: Mike PetrOv AOGCC Rep: John Crisp Submitted By: John Crisp Date' FielWU~ad: Granite Point Bruce Pit. Separator psi: LPS HPS 12/8/00 Well Permit Separ set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Tdp Code Code Code Passed CASorC¥CLE 08 1670360 14 1790330 16 1670770 - 18 1680120' 20RD 1910200 30 1780730 3RD 1931270 42 1930730 5 1680240 6 1891030 8 1800840 9 1930620 60 30 30 P P P GAS . · Wells: Remarks: 1 Components: 3 Failures: 0 Failure Rate: 0.0% F19o var Well B-9 has 2 chokes installed on the flow line. 12/13/00 Page 1 of 1 SVS Bruce Plt. 12-08-00jc.xls 01'4 OR BEFORE 5 / 09 D i:i Y i)Z T,2 I..I .... ,fi 07 2II 511 2!l t) ii TV[.':' .... ARH 93 0 {ii 2 i,,i I.I i1:, I.. 0,3 93 062 ~ FORHA'T'ION Mi... 5I~ CAS.ti:NG [Yl .... ? ~ CA:i::;ZNG W e i J 'l' :: C OH i'.'i ti{ i'"..l "f' S Page ~ i [?, .... :.~-I; e ' 0 a. /" i i ./' 9 .. ~..,, I.J N D A i E_._R E C V :) 07/18/1993 07/i 8/i 993 07/06/i993 07/06/199~,, 07/06/! 993 07/'1o1 'i .93 07/16/'1993 07/I 6/199.:? 07/i 6/'i 993 o 't /i 6/' 19 e s 07/16/i993 07/ i 8/1993 os/og/ 07/i 6/'1993 ~ ,.199~ 0 ? / ! ~:'~ / . .... 'i i-i C <.'~ irl p J 'i ,".:.:I I"l C ::! :l: n '¥ t '¥ a '! iq O. y e ~ lq 0 Unocat North AmericaD Oil & GaS Division Unocal Corpora, ti,on '-~-~' :- p O. Box 190z~/ · e Ala~,ka 995't9-0247 A'~chorag , ,-,.7~ .~ 7600 'Te[ephone (,9,-,-, _76- Ataska RegiOn DOc T ¢$ I'rTAL August 6, 1993 TO: L~ Grant ~.OM: R~ch~td L. SteWart LOCATION: ?.o.~O× LOCATION 3~ eogC~~ P~ ~C~o~o~ ~ 995t9 · ~OC~ 1 bMe~e ~d ~ sepia mudlog- fo~a~on log Unocal North Americ' . - Oil & Gas Division ~ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 Alaska Region UNOI:AL DOCUMENT TRANSMITTAL July 16, 1993 15 2" 5" 5- 2" 5. TO: Larry Grant FROM: Richard L. Stewart LOCATION: 3OOl PORCUPINE DRIVE ANCHORAGE, AK 99501 ALASKA OIL & GAS CONSERVATION COMM. ,, LOCATION: P.O.BOX 196247 ANCHORAGE AK 99519 UNOCAL TRANSMITTING AS FOLLOWS ~uxm'r~ ~nvr ~7s86 ~ q'~ 1 blueline and 1 sepia 2"" BHC Acoustilog/Gamma Ray/Caliper "BEC Acoustilog/Gamma Ray/Caliper -" Compensated Density/Compensated Neutron/Gamma Ray -' Compensated Density/Compensated Neutron/Gamma Ray · -- 4-arm Diplog -'Dual Induction Focused Log/Gamma Ray ~ Dual Induction Focused Log/Gamma Ray ---Segmented bond Log/Gamma Ray/CCL Log 5"casing - Segmented bond Log/Gamma Ray/CCL Log 7"casing 2" - TVD/Dual Induction/Gamma Ray DIFL/AC/CDL LIS Tape and listing Dry samples Box 1 570-3600 Box 2 3600-5496 Box 3 5496-5950 PLEASE ACKNOWLEDGE RECEItrr BY SIGNING AND RETURNING ONE COPY OF THIS DO~~ TRAN~AL. THANK YOU DATED: ,/ Unocal North Americ: Oil & Gas Division '--~ .... ~ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region June 23, 1993 Mr. David Johnston Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 PLATFORM BRUCE ADL 17586 WELL # 9 Dear Mr. Johnston In the attached well completion report (form 10-407) you will find that a 5" liner was run in order to penetrate the Tyonek gas sands which were the original objective of this well. The 7" casing was set early due to a geologic correlation error and the 5" liner was required to finish the well. Verbal approval for the 5" liner was given by Mike Minder on June 1, 1993. The subsequent perforating and testing of the Tyonek gas sands (5541'-5642' and 5022'-5793') resulted in a non- commercial gas rate. The completion was then modified to perforate and test each of three Beluga gas sands between 4500' and 5042'. These also failed to flow at commercial rates. Verbal approval for the Beluga completion was given by Mike Minder on June 15, 1993. The current plan is to continue to produce the Tyonek gas sands with the Beluga gas sands shut in behind sliding sleeves and evaluate the pressure data in order to determine the size of the Tyonek reservoir. S~ncer~ely ~ ~ /! G. Russell Schmidt JUL - ~ ~9~ Drilling Manager Alaska Oil & Gas Cons. 6ommissio~ Anchorage ALASKA Al_g~5 OIL AND GAS CONSERVATION COt 3SION WELL COMPLE] )N OR RECOMPLETION , _PORT AND LOG 1. Status of Well Classification of Service Well · . 2. Name of Operator , ~ve~.~ 7. Permit Number ' -/ UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 93-62 3. Address1_~' ~ ' 8. APl Number !/ P.O. BOX 196247 ANCHORAGE, AK 99519 , ~, ~.~_' 50-733-20448-00 4. Location of well at surface LEG #1, SLOT 4, PLATFORM BRUCE-~- ~" ~'--~'~'"" 9. Unit or Lease Name 2049' FSL, 2019' FWL, SEC. 31, T11 N, SM J ~,~PI _FTI0~t ~ , - ~ GRANITE POINT 17586 i ~ .... At Top Producing Interval (4500~ 3784' FSL 30' FEL, SEC. 36, T11 N, R12W, S? ~.~~'l)/'"'rF- /_.~..~ 10. W ELLWell Number#9 ~r'~l~ ~ 11. Field and peel At Total Depth (59053 4538' FSL 802' FEL, SEC. 36, T11 N, R12W, SM i -"~-~--~ ~. ............. . '.;/: ~_ GRANITE POINT UNDESIGNATED 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. 115'KBI ADL 17586 12. Date Spudded05/18/93 13. Date T.D. Reached06/05/93 14. Date Comp., Susp. or Aband.06/23/93 115' Water Depth' if OffshOre62 Feet MSL 116' NO' Of COmpletiOns'l 5905'/4170' 5905'/4169' YES [~ NO L] N/A feet MD N/A _ 22. Type Electric or Other Logs Run RUN 1: DIFL/GR/AC/CN/DL; DIPLOG; RUN #2: DIFL/GR/AC/CN; DIPLOG; SBT, CBL 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER GRADE TOP I BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" 1/2" WALL 49' 242' - - - DRIVEN 13-3/8" 68# K-55 48' 565' 17.5" 248 BBLS 9-5/8" 47.53# S-95, N-80 47' 1960' 12.25" 153 BBLS 7" 29# N-80 44' 5481' 8.5' 135 BBLS 5" 15.5# L-80 5305' 5950' 6" 15 BBLS --- 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE I DEPTH SET (MD) I PACKER SET (MD) . . MD TVD SEE ATFACHED SCHEMATIC 4500'-4558' 3207'-3243' 4730'-4734' 3353'-3355' 26. ACID, FRACTURE, CEMENT SQUEEZE~ ETC. 4740'-4763' 3360'-3374' DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED 5000'-5016' 3530'-3541 ' N/A 5022'-5042' 3545'-3559' 5541 '- 5642' 3902'- 3975' 5707'- 5793' 4023'- 4087' 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 6-24-93 FLOWING ., Date of Test Hours Tested PRODUCTION'FOF OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OiL RATIO .2/22/93 TEST PERIOD ......... FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 1475 0 24-HOUR RATE --- 750 --- 28. CORE DATA Brief description of lift, olegy, Porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NO CORES TAKEN ..~ ~~ ~V ~, Anchor~.~ Form 10-407 Submit in duplicate rev. 7-1-80 CONTINUED ON REVERSE SIDE 29, 30. NAME INTRA BELGUA MARKER TYONEK FM. GEOLOGIC MARKERS MEAS, DEPTH 31. LIST OF A'I-rACHMENTS 4495 5385 TRUE VERT, DEPTH 3203 3793 FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 4500'-4558'; 4730'-4734'; 4740'-4763' 5000'-5016'; 5022'- 5042' 5541'- 564.2'; 5707'- 5793' DALLY REPORT OF OPERATIONS, GYRO-SURVEY, WELL BORE SCHEMATIC 32, I herej3y c~~d correct to ~he best of my knowledge Signed G, RUSSELLSCHMIDT Title DRILLING MANAGER Date 06/24/93 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'. GRANITE POINT FIELD BRUCE WELL ~ ADL 17586 CURRENT 30' @ 242' DRIVEN 13-3/8' at 565' CEMENT TO SURFACE 287' OTIS SSSV 9-5/8' at 196o' CEMENT TO SURFACE NOTE' ALL COMPLETION DEPTHS ARE DIL 7' CASING AT 5481' 5', 15,5~' LINER FROM 530~-595~ NOTE: 18~ HANGER 4500'-4558' (58') 4730'-4734' (4') 4740'-4763' (23') 5000'-5016' (16') 5022'-5042' (20') 4359' XO 2-3/8 x 2-7/8' 4388' OTIS XA SLEEVE 4430' OTIS HVT PACKER 4572' OTIS XA SLEEVE 4665' OTIS BWH PACKER 4776' OTIS XA SLEEVE 4945' OTIS BWH PACKER 5054' OTIS XA SLEEVE 5256' OTIS BWH PACKER 5278' TIW LOCATOR 5458' OTIS XA SLEEVE 5500' PORTED SUB 5541 '-5642' (101 ') 5707'-5793' (86') 5537' TUBING TAIL 5630' TOP OF FISH (CTM) ~ ~' 5950' TD jUL. - B Oil & Gas Cons. Corl~ Anchorage GRB 6/24/93 BRUCE PLATFORM WELL #9-6 BRUCE PLATFORM WELL #9-6 DAY I (05/17/93) SKID RIG TO SLOT #4, WELL #9-6. HOOK UP SERVICE LINES. DRESS 30" CONDUCTOR. INSTALL 30" 500# X 20" 2000# DSA. NU 20" RISER & FLOWLINE. RU SLICK LINE UNIT & GYRO. RU FLOOR, SHALE CHUTE OVER BOARD LINE. UNLOAD BOAT, TAKE ON CMT. STRAP BHA. PU SAME. TORQUE UP KELLY. PU HWDP. BRUCE PLATFORM WELL #9-6 DAY 2 (05/18/93) MU BHA #1. PU KELLY. HOLD PRE-SPUD MEETING. RIH. TAG FILL @ 189'. CHANGE HOLE OVER TO SPUD MUD. GYRO @ 147'. WASH OUT CONDUCTOR F/189'-240'. SPUD WELL @ 0800 HRS. DRILL & GYRO 17.5" HOLE F/240'~,00' K.O.P. POH. BRUCE PLATFORM WELL #9-6 DAY 3 (05/19/93) MU BHA #2. RIH. DIRECTIONAL DRILLED 17-1/2" HOLE TO 566'. POOH. RIGGED UP AND RAN 13-3/8" CASING TO 565'. RIH WITH STAB IN ASSEMBLY. BRUCE PLATFORM WELL #9-6 DAY 4 (05/20/93) STABBED INTO FLOAT COLLAR At 524'. PUMPED 180 BBLS 12.9 PPG LEAD, 68 BBLS 15.8 PPG TAIL. FULL RETURNS. POOH WITH STAB IN ASSEMBLY. WOC. ROUGH CUT 13-3/8" CASING. REMOVED 20" RISER. FINAL CUT 13-3/8" CASING. INSTALLED SLIP ON CASING HEAD. TESTED UPPER AND LOWER SEAL TO 1500 PSI, OK. Alaska, 0J/& Gas Cons. Commission Anchorage BRUCE PLATFORM WELL #9-6 WELL #9-6 DAY 5-7 (05/21-23/93) INSTALLED AND TESTED 13-3/@" BOPE. RIH TO 523'. PRESSURE TESTED CASING TO 1500 PSI, OK. CLEANED OUT FLOAT TRACK. DRILLED TO 571'. RAN GYRO SURVEY. PERFORMED L.O.T., OK. TRIP FOR BHA. DIRECTIONALLY DRILLED 12-1/4" HOLE FROM 571'-1303'. CIRC. TRIP FOR MWD. DRILLED TO 1584'. WELL #9-6 DAY 8 (05/24/93) CIRC. TRIP FOR BIT. DRILLED 12-1/4" HOLE FROM 1584'-1970'. WIPER TRIP TO 565'. NO FILL. POOH. CHANGED TOP RAMS TO 9-5/8". PULLED WEAR BUSHING. TESTED RAMS TO 2000 PSI, OK. WELL #9-6 DAY 9 (05/25/93) RAN 9-5/8" CASING TO 1960'. CEMENTED 9-5/8" CASING WITH 68 BBLS LEAD AND 85 BBLS TAIL, CEMENT RETURNS TO SURFACE. INSTALLED PACK OFF. REMOVED BOPE. INSTALLED MULTIBOWL TUBING HEAD. INSTALLED BOPE. TESTED BOPE TO 3000 PSI, OK. WELL #9-6 DAY 10 (05/26/93) SET WEAR BUSHING. INSTALLED PITCHER NIPPLE. LAID DOWN 12-1/4" BHA. TESTED 9-5/8" CASING TO 3000 PSI. TAGGED CEMENT AT 1916'. DRILLED TO 1975'. PERFORMED LO.T. W/16.8 PPG EMW LEAK-OFF. DRILLED 8-1/2" HOLE FROM 1975'-2284'. WELL #9-6 DAY 11 (05/27/93) DRILLED 8-1/2" HOLE FROM 2284'-2815'. SHORT TRIP TO 1960'. DRILLED FROM 2815'-3413'. JUL - Alaska Oil & Gas Corm. Commission Ai~chora~e BRUCE PLATFORM WELL #9.6 WELL #9-6 DAY 12-15 (05/28-31/93) DRILLED 8-1/2" HOLE 3413'-3789'. SHORT TRIP. DRILLED 8-1/2" 3789'-5400'. CIRCULATED BOTFOMS UP & CHECKED CUTTINGS. DRILLED 8-1/2" HOLE 5400'-5430'. SHORT TRIP. DRILLED 8-1/2" HOLE 5430'-5496' TD. (SPUD TO TD 12 DAYS + 4-1/2 HOURS). CIRCULATED AND CONDITIONED HOLE. TRIPPED FOR LOGS. LOG #1 ATLAS "GRAND SLAM" (CNL/CDL/DIFL/GR) 5472'-600' & LOG #2 DIP/GR 5480'-2000'. WIPER TRIP. INSTALLED 7" RAMS IN BOPE. RAN 7" CASING. WELL #9-6 DAY 16 (06/01/93) RAN 7" 29 PPF, N-80, BUTT CASING TO 5481'. CIRCULATED AND CEMENTED IN ONE STAGE WITH 618 SX CMT SLURRY @ 13.7 PPG. INSTALL PACK-OFF AND TEST @ 3000 PSI. L/D 5" D.P. CLEANED PITS. DECIDED TO DRILL ADDITIONAL FOOTAGE. ORDERED SLIM HOLE TOOLS. TESTED BOPE. MIXED MUD. WELL #9.6 DAY 17 (06/02/93) CONT'D MIXING MUD. GENERAL MAINTENANCE AND CLEAN UP. PRESSURE TESTED BOPE TO 3000 PSI, OK. RIH PICKING UP 3-1/2" DRILL PIPE TO 5384'. PRESSURE TESTED 7" CASING TO 2000 PSI, OK. CLEANED OUT TO 5386'. WELL #9.6 DaY 18 (06/03/93) CLEAN OUT FLOAT TRACK. DRILLED 6" HOLE F/5496'-5504'. PERFORM L.O.T., 0.94 PSI/FT. TRIP FOR BIT. DRILLED 6" HOLE F/5504'-5703'. WELL #9-6 DAY 19-21 (06/04-06/93) DRILLED 6" HOLE F/5703'-5950' WIPER TRIP. RAN DIL/GR/CNL/ACOUSTIC/TEMP LOG F/5948'-5481'. WIPER TRIP. RAN DIP LOG, GR, CAL F/5928'-5450'. RAN 5" 15.5# L-80 LINER. TAGGED FILL AT 5931'. CIRC AND CONDITION MUD, PACKING OFF. PUMPED HIGH VISC SWEEP. CEMENTED LINER WITH 15 BBLS. BUMPED PLUG TO 4000 PSI. RELEASED FROM HANGER. SET PACKER. POOH. RIH WITH 6" BIT, TAGGED LANDING COLLAR AT 5867'. CIRC. R/U WIRELINE. Alaska. Oil & Gas Cop, s. Co[l~[[~issioF~ An~horaq~ BRUCE PLATFORM WELL #9-6 WELL #9-6 DAY 22 (06/07/93) RAN GR/CCL/SBT/VDL F/5306'-1700', SBT NOT WORKING. RAN SAME IN 5" LINER FROM 5829'-5306', OK. RAN GYRO SURVEY F/5800'- SURFACE. TRIPPED WITH A 6" MILL AND A 7" CASING SCRAPER TO 5306'. RAN GR/SBT PACKAGE FROM 5300'-1500', OK. PRESSURE TESTED CASING TO 2000 PSI FOR 30 MIN, OK. WELL #9-6 DAY 23 (06/08/93) CHANGED RAMS TO 3-1/2" AND TESTED TO 3000 PSI, OK. RIH WITH 4-1/8" MILL AND CLEANED OUT TO 5905'. TESTED 7" & 5" CASING TO 2000 PSI, OK. CHANGED WELL OVER TO FILTERED 5% KCL. WELL #9-6 DAY 24 (06/09/93) PICKED UP TCP AND OTIS PERM PACKER ASSEMBLY. TAGGED LINER TOP. POSITIONED GUNS. SET AND TESTED PACKER AT 5271'. POOH L.D. DRILL PIPE. CHANGED TO 2-7/8" RAMS AND TESTED. RAN 2-3/8" X 2-7/8". PROD STRING AND HYDROTESTED TO 4500 PSI. WELL #9-6 DAY 25 (06/10/93) FINISHED RIH WITH 2-3/8" X 2-7/8" PRODUCTION STRING HYDROTESTING TO 4500 PSi. STABBED INTO PERM PACKER AT 5277'. LANDED TBG. REMOVED BOPE. INSTALLED TREE. BRUCE PLATFORM WELL #9-6 WELL #9-6 DAY 26-28 (06/11-13/93) PREP TO FLOW WELL. OPENED SLIDING SLEEVE AT 5243'. DISPLACED WITH NITROGEN TO 1500'. CLOSED SLIDING SLEEVE. DROPPED BAR. GUNS DID NOT FIRE. RETRIEVED BAR. BAILED ON PORTED SUB AT 5500'. DROPPED BAR. GUNS FIRED PERFORATED THE TYONEK FROM 5541'-5642' AND 5707'- 5793'. FLOWED WELL. RECOVERED 20 BBLS BRINE. FLOW SLOWED, FLOWING W.H. PRESSURE 60 PSI. FLUID LEVEL APPROX 4393'. RAN BAILER TO 5545, GUNS HAVE RELEASED. RAN PRESSURE GAUGES, INDICATED NO FLUID IN WELL. RIGGED UP COILED TUBING. TESTED C.T. TO 2500 PSI, OK. RIH AND TAGGED AT 5630', GUNS ON BO,-rOM. RIGGED DOWN C.T. FLOWED WELL 1.67 MMSCF/D AT 400 PSI, WAITING ON ORDERS. SHUT IN THE WELL. SET PLUG IN XA SLEEVE AT 5471' FILLED TBG WITH BRINE. WELL #9-6 DaY 29 (06/14/93) FILLED TUBING WITH 8.6 PPG BRINE. OPENED THE XA SLEEVE AT 5243'. CIRC. S.I. AND MONITORED FOR 2 HRS. SITP, 375 PSI. (:;IRC 8.8 PPG BRINE. RIGGED ATLAS RAN GR/CCL FROM 5440'-3700'. SITP BUILT TO 180 PSI IN 3 HRS. CIRC. MONITORED WELL 3 HRS SITP 400 PSI. BLED OFF IN 1-1/2" MIN. INSTALLED BPV. REMOVED TREE. INSTALLED BOPE. WELL #9-6 DAY 30 (06/15/93) COMPLETED INSTALLATION OF BOPE. TESTED BOPE TO 3000 PSI, OK. FILL TBG & REM BPV. RU WL & RIH. TAG FILL @ 5449'. POOH. RIH W/DN BAILER, BAIL SAND TO 5468'. CIRC 9.1 PPG BRINE W/RTNS ON ANNULUS. RU WL & RIH, TAG FILL AT 5448'. WELL #9-6 DAY 31, 32 (06/16,17/93) MADE 3 TRIPS WITH PUMP BAILER AND 5 TRIPS WITH HYDROSTATIC BAILER AND CLEANED OUT SAND FILL TO 5470'. RAN AND SET WIRELINE TUBING PLUG AT 5470'. WEIGHTED SYSTEM TO 9.5 PPG. PULLED COMPLETION STRING. RAN STACKED COMPLETION ASSEMBLY #2 WITH SIDE MOUNTED TCP GUNS AND SET PACKER @ 4946'. POH WITH DP RUNNING STRING. RAN STACKED COMPLETION ASSEMBLY #3 WITH SIDE ,,Y, N~,v, OU N~'~ ~'C~ ~U NS ,,N ~ S ~ ~'AOK~, ~ 4~'. ,~OWN ,~,. 0"~O ~ ~:C ~f~/'~ ~ ~ Alaska. Oil & Gas Cons, Anchorag~ BRUCE PLATFORM WELL -#9-6 WELL #9-6 DAY 33-35 (06/18-20/93) POOH LAYING DOWN D.P. INSTALLED 2-7/8" RAMS AND TESTED. RIH WITH TOP PACKER AND SIDE MOUNT GUNS AND SET PACKER AT 4665' (DIL). INSTALLED TUBING HANGER. DISPLACED TUBING WITH 30 BBLS 9.6 PPG BRINE. RIH WITH "SB" PULLING TOOL TO RECOVER "W" PLUG AT 5470'. TAGGED AT 5365'. BAILED TO 5395', VERY LI3-FLE RECOVERY, MOSTLY SAND. PRESSURED TUBING TO 3500 PSI TO SET HVT PACKER AT 4444'. OPENED SLEEVES AT 5067', 4789', 4590' & 4403'. CLOSED SLEEVE AT 4403'. PRESSURE TESTED TOP PACKER, NEG. SET PLUG IN "XA" SLEEVE AT 4590'. PRESSURE TUBING TO 4100 PSI TO COMPLETE SE-I-FING "HUT" PACKER. RETRIEVED PLUG. TESTED PACKER TO 3000 PSI, NEG. RIH AND CLOSED ALL SLIDING SLEEVES. SET "X" PLUG AT 4590'. PRESSURED TUBING TO 5000 PSi TO SET "HV-F' PACKER. RETRIEVED PLUG. OPENED SLEEVES AT 4590'. TESTED "HUT' PACKER TO 3000 PSI, OK. OPENED SLEEVES AT 5067' AND 4789'. TESTED CASING TO 3000 PSI, OK. OPENED SLEEVE AT 4403'. REMOVED BOPE. INSTALLED TREE. CALIBRATED HI-LO SSV. DISPLACED NITROGEN THROUGH SLEEVE AT 4403' WITH 1350 PSI. SHOT F.L. AT 4403'. CLOSED SLIDING SLEEVE. INSTALLED TREE SAVER. TESTED CHOKE LINES TO 5000 PSI, NITROGEN LINES TO 7000 PSI. PRESSURED TUBING TO 6600 PSI TO INITIATE TIME DELAY FIRING HEADS. BLED TUBING OFF TO 750 PSI. HAD INDICATION OF GUN DETONATION. FLOWED WELL THROUGH CHOKE, GAS TO SURFACE, NO FLUID. RATE AND PRESSURE DROPPED UNTIL WELL DIED 45 MINS AFTER DETONATION. RIGGED UP 1-1/2" COILED TUBING. WELL #9-6 DAY 36 (06/21/93) TESTED COILED TUBING BOPE TO 3000 PSI. BEGAN PUMPING NITROGEN AND RIH, APPARENT FLUID LEVEL AT 3000'. LIFTED 9.6 PPG BRINE TO 4300'. POOH WITH COILED TUBING. NO INCREASE IN RATE OF GAS FLOW. RIH WITH SLICKLINE AND TAGGED AT 5274'. FLUID LEVEL ROSE TO 3100'. CLOSED ALL SLEEVES. PRESSURE TESTED TUBING TO 3000 PSI. OPENED SLIDING SLEEVE AT 4590'. PUMPED INTO PERFS F/4500'-4558'. CLOSED SLEEVE. TESTED TBG TO 3000 PSI. OPENED SLEEVE AT 5067' PUMPED INTO PERFS F/5000'-5016', 5022'-5042'. CLOSED SLEEVE. TESTED TBG TO 3000 PSI. Gars Cons, Cornmissiorl Ancho~-ag,s BRUCE PLATFORM WELL #9-6 WELL #9-6 DAY 37 (06/22/93) OPENED SLEEVE AT 4789'. PUMPED INTO PERFS F/4730'-4734', 4740'~,763'. CLOSED SLEEVE. TESTED TBG TO 3000 PSI. OPENED SLIDING SLEEVE AT 4590'. PUMPED INTO PERFS F/4500'-4558'. RIGGED UP COILED TUBING. TESTED RISER TO 3000 PSI. LIFTED WELL WITH NITROGEN TO 4650', NO FLOW. RIH AND WASHED DOWN TO 5467' (CTM). RIGGED UP SLICK LINE. WELL #9-6 DAY 38 (06/23/93) RIH AND RECOVERED "W" PLUG. VERIFIED THAT ALL SLEEVES ARE CLOSED. RIGGED UP COILED TUBING. TESTED RISER TO 3000 PSI. WASHED TO 5470' (CTM). RIG UP SLICKLINE. A~-FEMPT TO RECOVER XX, NEG. BAILED ON PLUG. RECOVERED XX PLUG. RELEASED WELL TO PRODUCTION. RELEASED RIG @ 2400 HRS. T A G y t" o d a t. a D .i. t"e c :5 t~ 1" v e y b'll::.A S I Fi C l., AZ [ NUTI'] I)F, PT[I 130 (';-ii, Et; :4 F,V F',I', T T Y tleg/1.00 ' · () . 0() . 0() . ()0 10 (.). 0 2O0.0 300.0 400.0 700.0 800.0 '!) 00.0 1. 000.0 I 100.0 1200.0 1300.0 1400.0 1500.0 1600.0 1700.0 1800.0 1 900.0 .21 .11 .21 2' 47 5.24 7.79 3.88 7.65 I .01 S. 32 ,."t / 9.35 3.61 :5.59 I .55 I .SI 3.9 ?, 3.94 4.10 ~"~. 33 3.8l .'35 '1.74 335 . 69 296.95 321.10 .14 .09 .14 .12 VERT I') E P"['I t [ t AI,I., DI);F'TttS 100 200 3O0 4O0 VERT C [, O S U R >; I.'(;TI' {')N I) 1STANt':F, /\Z l b'[tl'l'll I7 I; [' t: d e 2000.0 2100.0 2'200.0 2300.0 2400. ~ ,..x o C) O .() .() P,L',l M.,f:NCIt;f) '1"(") 1~. 1<. [;. .0 . 1 .O .3 . O .6 .0 .9 '242.7'7 .91 500.0 1 5 13,., 57 2.98 600.0 156.50 3.04 699.7 -6,4 234.30 8.41 799.2 -8.5 277.24 9.72 897.6 3.6 5.54 3.92 7.69 7.10 4.73 4.31 4.98 2.98 .47 2.82 292.30 298.45 '304.22 309.95 311.85 312.8;) 3 '13.11 313.55 314.06 113.15 993 1088 1179 1264 1344 141.8 1488 1552 1614 1674 1732 1791 1850 1908 1967 ~'13. ,c;O ~13.1() )11.19 311.20 310. '37 H O R '[ Z O N T A I.' ~ O t, .77 .57 .55 .23 .85 .8 28.4 . '2 60.7 .0 102.0 .2 154. ) · 0 214.4 .9 280.5 .2 352.3 .4 428.7 .4 506.8 .3 5,~6.5 .7 .6 .3 .8 .5 747.9 7 · O . () . I ) 51.7 .4 '344.8 .7 3 36.2 '1.0 329.5 1.5 296.0 1.4 '210.'2 7.4 159.3 15.1 184.0 25.5 226.5 45.f; 256.'3 74.4 273.1 I 12.7 283 . 3 '161.8 290.8 '2 '19 3 296 o 283.6 299.9 354.1 302.6 429.7 304.5 507.3 305.9 586.7 306.9 667.,h ~07.7 747.9 30 S. 3 S28.7 308.7 909.7 308.9 990.7 309. I .0() N .00 E .12 N - . · 42 N I I. .03 N .28 .82 N .48 W .68 N 1.38 W 1.18 S .69 W 6.93 S 2.62 E 15.09 S 1.07 W' 17.54 S 18.51 W 10.27 S 44.4.6 W 4.03 N 7Z~.26 W 25.94 N 109.69 W 57.63 N 151.20 W 97.12 N 196.68 W 141.73 N 245.61 W 190.83 N 298.31. W 243.45 N 354.08 W 297.76 N 410.70 352.95 N 468.( 408.80 N 527.56 464.42 N 586.26 W 518.72 N 646.26 W 572.15 N 707.30 W 625.04 N 768.61 W t ICI OFILMED [1NI)CAI, I'tRtICE PISATF()I~H, WI!if,L, ~:OOK INLET, ALASKA ,Iolo Number: A1(0693(;39 A (; v F 0 (1 ;.t I. D 5 F t! C O 11 ,'1 ,<'~ il 1' V I:! y MEAS I NC[.., AZ [ HUTH DEPTH f't deg (leg 2500.0 54.78 2600.0 54.68 2700.0 54.24 2800.0 54,92 2900.0 !54.56 3()00.0 '55). 9'.5 3100.0 54.30 3200.0 54.07 3300.0 54.82 3400.0 54.22 3500.0 53.95 .3600.0 54. b9 3700.0 54.2 ) 3800.0 54.:38 .3900.0 54. '12 4000.0 53.54 4100.0 52.813 4200.0 52.&6 4300.0 51.93 4400.0 51.51 4500.0 50.99 /4600.0 50.58 4700.0 50.06 4SOO .0 49.45 4900.0 45.72 310.12 310.48 310.77 310.75 :110.53 '110.90 ) 1 (). 09 ) 10. ?3/4 30'). 83 311.00 :3 '1 ]. C)I 311.28 312.66 3 '10.84 1110.99 ,) 10.80 311.18 311.30 311 .~6 3ll .87 311.90 312.58 311.94 312.12 312.50 DO(;--[, EG S EVER I TY deg/lO0' I .OO .31. .49 .68 .40 .75 .65 1..1l 1.13 .27 .78 1.22 I. 48 .29 .60 .77 .38 .5/4 .53 .52 .67 .72 .63 .78 VERT DEPTH ft 2025.8 2083.6 21/41.7 219'3,7 2257.4 23 'l 5.8 2374.4 2432.9 2491.1 2549.1 26(') 7.8 2666.1 '2724.2 2782.6 28/41.0 2900.0 296O .0 3O2O .6 3081.9 3143.9 3206.5 3269.7 3333.5 3398.1 3463.6 VERT C L O S U R E SECTION DISTANCE AZIHUTIt ft ft deg 1071 .S 1153.4 1234.7 131 {~, '] 1397.7 147 o ,,~; 1. 55'3. S 1680.8 1, 7 '~ '''~ 1803.5 1. 8,84.4 1 '365.5 2O/46.8 2t 27.8 2208.9 2289.6 2369.5 2448.9 2527 .S 2606.2 "~6 ° 4 1 2761.4 2838. '2 291.~ .3 2989.7 1071.9 309.2 1.15:3.5 309.2 1234.8 30'3.3 1316.3 309.4 1398 o0 30':l. 5 1479.1, 309.5 1560. I 309.6 1.64.1.2 309.6 1722.6 309.7 1804.0 309.7 1.884.9 30').7 1966.1 30').8 2087.5 309.9 2'128.6 31.0.0 2209.8 .310.0 2290.5 310.0 2370.5 310.1 2/450.0 310.1 2529.0 310. l 2607.5 .310.2 2685.4 310.2 2762.9 .310.3 2839.8 310.3 2916.1 .310.a 2991.6 310.4 H O R I Z O N T A L C, O () R I) I N A T E $ · f e e t 677.50 N 830.59 7.30. ,31 N 89 '2 .,c- .... 783.29 N 954 $36.49 N 1016.'3., 889.67 N 1078.31 9fl2.61 N 1139.83 995.23 N 1201.45 1.047.86 N 1263.15 1100.51 N 1325.16 1153.30 N 1387.16 1206.64 N 1648.27 1259.8a N 1. 509.44 1314.29 N 1569.94 1368.37 N 1630.53 1421.52 N 1691.86 1674.37 N 1752.88 1526.88 N 1813.31 1579.28 N 1873.08 1631.51 N 1932.36 1683.69 N 1991.01 1735.76 N 2049.0 1787.84 N 2106.4~ 1839.60 N 2163.39 1890.70 N 2220.09 1941.57 N 2275.97 bt E A :-; I N t'; I .... ,fX Z .l blU T H D O G- [, E G I) E PTt l S EVERI T¥ f t (1 eg ct ~:[;, deg / 100 ~ SO00.0 47.'J9 3 I 2.44 .73 5100.0 47.49 3 [3.04 .67 5200. () 47.00 '1 I 2.94 .50 5300.0 g6.26 313.57 .87 540('). 0 45.58 '313.1.8 .73 VERT DEPTH ft 353 O, l 3597.3 3665.2 3733.9 3803.5 )873. S 3944.8 40 '18.0 4091., ti, RI C L f)S U I',I E [!',CT'[ ON D]S TAN(-; E AZ I MIITII f t f I: d e ~; 30 !:'~ 4, '3 3 '13,.S. 1 3211,3 3283.7 335 fi. ] ;.342 (:i. ,:': 3496.2 3564. ] 30 ('~ 6.3 :110. b 31.40,2 310,~i 3213.6 310.6 32,$6.2 310.6 3358.0 1310.7 ,3429. ;.3 3 '10.6 3499.4 310.8 3567.4 310.8 ~634.7 .1 l(). 9 t-I O R I. Z (.) N T A [, (; O () R I) '1 N A T t:", i:-e e t 199'2,0'2 N 2331 2042.25 N 2385 2092.32 N 243 2142.12 N 2492 2191.46 N 2544.3, 2240.58 N 2596.14 2"289. ()0 N 2646.88 2335.36 N 2696.75 ')380 67 N 2'I 57 . . i 46, l"Till'tl :'41,.:l iOll (:l():-;llt'('' )(il )"Il · Y l~t."e't 31.0.9180 MEMORANDUM ALASKA OIL AND GAS CONSERVATION COMMISSION STATE OF ALASKA to: David Johnsto~ Commissioner.-¥- thru: Blair E Wondzell Petr lnsp Supervisor from: ~'"~u Grimaldi Petr Inspector date: June 1,1993 file: 052193.doc subject: BOP Test Platform Bruce Pool Arctic rig UNOCAL we!! # BR-9 Granite Point Unit PTD 93-62 Friday, May 21, 1993: I traveled to UNOCAL's platform Bruce in the Granite Point unit to witness the initial BOP test on well # BR-9. I found the rig to be in fair shape with all necessary well control equipment to be in place and in good shape. I did find one-~rernot in compliance, this being the choke manifold did not provide a emergency vent (blooey) line. After conferring with Mike McAII (drilling foreman) a temporary line was installed and the rig engineers will design a permanent installation. The BOP test, once underway, went well with two failures observed, these being the lower pipe rams which required the ram elements to be replaced. These passed their subsequent retest. The second failure was the valve downstream of the hydraulic choke, this was a very slow leak which once greased, held. Doug Niehause (POOL Toolpusher) directed the test and I found him to be thorough and intent on performing a good BOP test. Summary: I witnessed the initial BOP test on platform Bruce (BR-9), test time 4.0 hours, zero failures. attachments qig Ne, ~Ril_iC~ PTD# Dri. P,i~ Upper Kr~ity '~ '~ Type reside BOP ::'mssure After Closurc ...... ' ~'"~ .... t ..... ' ..... ...................... ~ tic, Tm~K '-' P System Pressure A!tained :5 rr~htl~e::: 45 ~:ec. Flow lndioxtor ~:', .. . ,,,~:;uc~o: on duiy arid follow with WJitlo~i o~ Fax:~d ,¢~-;r .... :i :. to AND RETEST -_ .... .... L.: ,tit,.,:: r,AANIF L OUi,5':, ¢~ GRIMAL. .DI WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION May 7, 1993 G. Russell Schmidt Drilling Superintendent UNOCAL P O Box 196247 Anchorage, AK 99519 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Re: Granite Point Well 9 UNOCAL Permit No: 93-62 Sur. Loc. 2012'FSL, 1951'FWL, Sec. 31, TllN, RllW, SM Btmhole Loc. 4268'FSL, 806'FEL, Sec. 36, TllN, R12W, SM Dear Mr. Schmidt: Enclosed is the approved application for permit to drill the above referenced well. The Commission grants approval to use a 13-5/8" BOP stack in lieu of a diverter on the 13-5/8" conductor, casing string. This variance is granted under the authority of 20 AAC 25.035(c)(2). The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission at 279-1433. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. --- STATE OF ALASKA ALASKA' .LAND GAS CONSERVATION CON PERMIT TO DRILL 20 AAC 25.005 SSION la. Type of work Drill ~: Redrill [-] lb. Type of well. Re-Entry [~ Deepen [~ Service E~ Expl~)ratory E~ Stratigraphic Test E~ Development Gas ~: Single Zone Development Oil Multiple Zone 2. Name of Operator Union Oil Company of California (UNOCAL) 3. Address P.O. Box 196247, Anchoraqe, AK 99519 4. Location of well at surface Platform Bruce, 2012' FSL 1951' FWL, Sec. 31, T11N, R11W, SM At top of productive interval Top Beluga Gas, 3912' FSL 359' FEL, SEc. 36, T11N,.R--1-~, At total depth (5575') 4268' FSL, 806 FEL, Sec. 36, 12, Distance to nearest 113. Distance to nearest well property line i' 4800' feet 4' @ surface feet 16. To be completed for deviated wells Kickoff depth 720' feet Maximum hole anqle 60 5. Datum Elevation (DF or KB) 115' feet 6. Property Designation ADL 17586 7. Unit or property name Granite Point 8. Well number Well 9 9. Approximate spud date May 9, 1993 14. Number of acres in property 3O7O AC 10. Field and Pool GRANITE POINT UNDESIGNATED 11. Type Bond (SEE 20AC025.025) United Pacific Ins. Co. Number U62-9269 Amount $200,000 15. Proposed depth (MDa. dTVU) 5575'MD/3750' TVD feet 17. Anticipated Pressure(see 20 AAC 25.035 (e)(2)) Maximum surface 761 psig At total depth (TVD) 3750' psi~l 18. Casing program size Hole i Casing Weight 113-3/8" Specifications Grade. Coupling ! Length -- i WELDED 156' Setting Depth Top Bottom MD TVD MD 45 45 201 43 I 43I 600' 43 I 431 1980' 42 I 42! 5575'- TVD Quantity of cement (include stage data) 17-1/2" 12-1/4" ! 9- 5/8" 8-1/2" j 7" I 68 47 1557' K551 BU'Fr N80I BU'FI" i 1937' 29 J NS01 BUTT I 5533' , j 19. To be completed for Redrill, Re-entry, and Deepen Operations Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet 201' Driven 600' 75 bbls (surface) 1715' 110 bbls (surface) 3750' 126 bbls (surface) Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length Size Cemented Measured depth True vertical depth 20. Attachments Filing fee ~: Property plat ~ BOP Sketch[~ Diverter Sketch ~ Drilling program E~ Drilling fluid program [~ Timevs d. epth plot E~ Refraction analysis E~ Seabed report ~ 20 AAC 25.050 requirements BI 21.1 hereby ce .'.~. t.~..t.h~eo~k~ga~i~d correct tO the best of my knowledge Signed G. RUSSELL SCHMIDT Title DRILUNG SUPERINTENDENT Date Commission Use Only N~r~ J API number I Ap~.~_~, date J See cover letter Permit b,_e~ ,~ 50- 7 ~ - ~ O ~/~ ~ '7 -" ~'-2¢' for other requirements Conditions of approval Samples required ~ Yes ~ No Mud log required E~ Yes ~' No Hydrogen sulfide measures E~ Yes J~ No Directionalsurvey required ~ Yes E~ No Required working pressure for DOPE ~ 2M; ~ 3M; ~ 5M; E~ 10M;E~ 15M Other: by the order of Approved by Commissioner the commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate Unocal North America Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region April 12, 1993 Mr. David Johnston Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 PLATFORM BRUCE ADL 17586 WELL # 9 Dear Mr. Johnston: In the attached permit to drill you will find that Unocal is requesting approval to install a 13-5/8" BOP stack on the 13-3/8" conductor casing set at 600' MD, 600' TVD. Due to the slim hole nature of the well this will allow drilling of the entire well with one BOP stack. It has been the practice on the Bruce platform to drill to +/- 600' with a riser, run and cement conductor casing, install a diverter and drill to +/- 3000'. These wells have demonstrated that a fracture gradient of 0.85 psi/ft or greater can be expected at 600' TVD. The maximum anticipated pressure at the 13-3/8" casing shoe during a kick situation is 357 psi (see the MSP calculations in the permit to drill). This is significantly less than the anticipated 510 psi fracture pressure of the 13-3/8" shoe (0.85 psi/ft * 600' = 510 psi). Since the casing shoe will not break down in a kidk situation we feel that this is a prudent design. APR 1 4 Alaska Oil & Gas Cons, Anchorage Sincerely, G. Russell Schmidt Dr±ll±ng Manager GRANITE POINT 17586 #9 DRILLING PROCEDURE 1. SKID RIG OVER LEG#i, SLOT #4, PLATFORM BRUCE 2. CLEAN OUT THE 30" CONDUCTOR WITH A 17-1/2" BIT AND A 26" HOLE OPENER. DRILL THE INITIAL 5' WITH THIS ASSEMBLY. 3. INSTALL A 20" FLOW NIPPLE. 4. DIRECTIONAL DRILL 17-1/2" HOLE FROM 205' TO 600' MD 5. RUN AND CEMENT 13-3/8" CASING AT 600'. 6. INSTALL A 13-5/8" BOPE STACK AND TEST TO 2000 PSI. · DRILL 12-1/4" HOLE FROM 600' TO 1980' (1716' TVD). A BUILD OF 5© /100' WILL BE REQUIRED TO REACH AN ANGLE OF 60©. 8. LOG FROM 1980' - 600'. 9. RUN AND CEMENT 9-5/8" CASING. 10 DRILL 8-1/2" HOLE FROM 1980' TO 5575' MD (3750' TVD). THE SECTION FROM 1980' TO 4540' IS TO HOLD THE 60© ANGLE PREVIOUSLY ESTABLISHED. ONCE 4566' MD (3035' TVD) IS REACHED DROP ANGLE AT 4© /100' UNTIL TD AT 5575' MD (3750' TVD) IS REACHED. 11 DEPENDING ON HOLE CONDITIONS AN OPEN HOLE LOG WILL BE RUN TO TD. DIL/GR/ARRAY SONIC/SP DENSITY/CNL/CALIPER/GR 14 CHANGE THE WELL OVER TO COMPLETION BRINE· 15 RUN A PERMANENT PACKER AT +/- 4600'. 16 RUN A SINGLE STRING FLOWING GAS WELL COMPLETION WITH DROP OFF CASING GUNS ATTACHED AND A PERMANENT PACKER AT +/- 4600'. 17 REMOVE THE BOPE AND INSTALL A SINGLE TREE. 18 PERFORATE UNDERBALANCED AND DROP THE GUNS. 19 RELEASE THE WELL TO PRODUCTION. TIME: 25 DAYS GRANITE POINT 17586 WELL NO. 9 Anticipated Pressures for the 17-1/2" hole: Mud weight = 9.0 ppg = .468 psi/ft Total Depth of 17-1/2" hole is 600' MD, 600' TVD Pore Pressure Gradient = 0.450 psi/ft Maximum Surface Pressure cannot exceed maximum bottom hole pressure; 600' * 0.450 psi/ft = 270 psi Anticipated Pressures for the 12-1/4" hole: Mud weight = 9.3 ppg = 0.484 psi/ft 13-3/8" Shoe is proposed to be at 600' MD, 600' TVD Total Depth of the 12-1/4" hole is 1980' MD, 1715' TVD Estimated Fracture gradient (13-3/8" shoe) = 0.85 psi/ft Pore Pressure Gradient = 0.450 psi/ft Gas gradient (assume worst case) = 0.0 psi/ft Assume 1/2 of the wellbore volume is gas and 1/2 is mud during a kick situation. Maximum Surface pressure = (1715 ft * 0.450 psi/ft) - 0.5 (1715 ft * 0.4~84 psi/ft) -0.5 (1715 * 0 psi/ft) = 357 psi Anticipated Pressures for the 8-1/2" hole: Mud weight = 9.5 ppg = 0.494 psi/ft 9-5/8" Shoe is proposed to be at 1980' MD, 1715' TVD Total Depth of the 8-1/2" hole is 5575' MD, 3750' TVD Estimated Fracture gradient (9-5/8" shoe) = 0.95 psi/ft Pore Pressure Gradient = 0.450 psi/ft Gas gradient (assume worst case) = 0.0 psi/ft Assume 1/2 of the wellbore volume is gas and 1/2 is mud during a kick situation. Maximum Surface pressure = (3750 ft * 0.450 psi/ft) - 0.5 (3750 ft * 0.494 psi/ft) -0.5 (3750 * 0 psi/ft) = 761 psi Alaska Oil & G. as GRANITE POINT WELL 17586 WELL NO. 9 MUD PROGRAM MUD TYPE: Low solids/Non Dispersed/Gel DEPTH: 200' - 600' MUD PROPERTIES: Weight (Lbs/gal) = 9.0 - 9.5 Funnel Viscosity (Sec/Qt) = 80 - 250 Plastic Viscosity (cps) = 10 - 20 Yield Point (#/100 Cu ft) = 15 - 30 pH = 9.0 - 10.0 API Fluid Loss < 75 cc MUD TYPE: Low solids/Non Dispersed/Gel DEPTH: 600' - 1980' MUD PROPERTIES: Weight (Lbs/gal) = 9.3 - 9.6 Funnel Viscosity (Sec/Qt) = 42 - 80 Plastic Viscosity (cps) = 10 - 20 Yield Point (#/100 Cu ft) = 10 - 30 API Fluid Loss (cc) = 10 - 12 pH = 9.0 - 10.0 Drill Solids (Lbs/bbl) < 75 MUD TYPE: Low solids/Non Dispersed/Gel DEPTH: 1980' - 5575' MUD PROPERTIES: Weight (Lbs/gal) = 9.5 - 10.0 Funnel Viscosity (Sec/Qt) = 42 - 80 Plastic Viscosity (cps) = 10 - 20 Yield Point (#/100 Cu ft) = 10 - 30 API Fluid Loss (cc) = 10 - 12 HPHT Fluid Loss (cc) = 12 - 15 (500 psi @ 200 Degrees F) pH MBT (Lbs/bbl) Drill Solids (Lbs/bbl) = 9.0 - 10.0 < 25 < 50 + '5 25 + -I- + --I- 17586 #9 36 4- --i- 17586 17586 #5 1758( -t- 17586 ,NEK ST 1 oTM 17587 ~6 ~9 17587 #5 3O TYONEK ST 1758~ 2 (o m + 8 O~ + 17587 #5 6 7 18742 ~14 g + 5 2 ~54 18742 ~20 Jr 17587 -I- 18742 #6 +31 18742 #12~ ~742T'~g~EK ST 18742o#10 -~ i,.-r:i .- r, ,- , - . /~,~lOi~O~E~ ,5' 18742 ~$1 52 UNOCAL BRUCE Platform 9-6 slot #4-2 Granite Point Field Cook in[et, Alaska PROPOSAL LISTING by Eastman Te[eco Your ref : 9-6 Version #2 Our ref : prop751 License : Date printed : 6-Apr-93 Date created : 6-Apr-93 Last revised : 6-Apr-93 Field is centred on n60 59 36.731,w151 18 33.112 Structure is centred on n60 59 36.731,w151 18 33.112 Slot location is n60 59 56.542,w151 17 53.549 Slot Grid coordinates are N 2559380.514, E 269562.634 Slot local coordinates are 2012.00 N 1951.00 E Reference North is True North APR ! ~- 199,3 Alaska Oil & Gas Cons. [:or[~mission Anchorage UNOCAI Structure : BRUCE Platform Well : 9-6 iCreated by : jones IDote plotted ' 6-Apr-95 iPIot Reference is 9-6 Version #2. iCoordinates ore in feet reference slot #4-2.i iTrue Vertical Depths ore reference wellhead. --- Eastman Teleco --- Field : Granite Point Field Location : Cook Inlet, Alaska i WELL PROFILE DATA J---- Point .... I~D Inc Dir TVD Tie on 0 0.00 0.00 o !End of Hold 400 0.00 0.00 400 I End of Build 600 4.00 O.O0 600 iKOP 720 4.00 0.00 720 iEnd of Build 1878 60.56 `308.54 1666 !End of Hold 4566 60.36 `308.54 2995 i Targe[ 4644 57.26 .308.54 3,035 IEnd of Drop ~7~. 20.00 308.54 3750 <-- We Scale 1 : 125.00 I I I I I I I I I I I I I I I I 3400 RKB ELEVATION: 115' Begin Nudge 2.00 L 15 3/8 Csg Pt End of Build Kick off Point L2: 9.00 18.68 5 BEG / 100' OOOLEG 8.58 '518.50 ~8.47 EOC 9 5/8 Csg Pt MAXIMUM ANGLE 60.36 DEG TD ANGLE 20 DEG 50.56 DEG W 356Z'(TO TD) Begin Angle Drop DROP 4 BEG / 100' ID / 7 Csg Pt (End Angle Drop) i i i i i i i i i I i i i i i i i i i i i i i i i i i 0 200 400600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 Scale 1 : 100.00 Vertical Section on 309.44 azimuth with reference 0.00 N, 0.00 E from slot #4-2 i i i i i 2800 3000 3200 Nodh East 0 o 7 15 403 -43 1859 -2258 1900 -2310 ~56 -27~52 ; 250O _2250 _ _2000 _ _1750 - - _1250 - _ lO00 500 - _ 250 0 _ APR I 4.' ,4,1aska. Oil & Gas Cons. 60.,. issi0r A . ch0rage TARGET 52.00 44.00 56.00 i i 28.00 20.00 J i i 36oo UNOCAL BRUCE Platform,9-6 Granite Point Fie[d,Cook Inlet, Alaska PROPOSAL LISTING Page 1 Your ref : 9-6 Version #2 Last revised : 6-Apr-93 Measured Inc[in. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 400.00 0.00 0.00 400.00 0.00 N 0.00 E 0.00 500.00 2.00 0.00 499.98 1.74 N 0.00 E 2.00 600.00 4.00 0.00 599.84 6.98 N 0.00 E 2.00 600.16 4.00 0.00 600.00 6.99 N 0.00 E 0.00 0.00 0.00 Begin Nudge 1.11 4.43 4.44 13 3/8" Csg Pt 720.00 4.00 0.00 719.54 15.35 N 0.00 E 0.00 720.46 4.01 359.74 720.00 15.38 N 0.00 W 5.00 800.00 7.15 333.27 799.17 22.59 N 2.24 W 5.00 900.00 11.83 322.24 897.78 36.25 N 11.32 ~ 5.00 1000.00 16.69 317.49 994.67 54.96 N 27.31 ~ 5.00 9.75 9.77 KOP 16.08 31.77 56.00 1100.00 21.62 314.85 1089.11 78.55 N 50.09 ~ 5.00 1200.00 26.57 313.15 1180.37 106.86 N 79.48 ~ 5.00 1300.00 31.54 311.96 1267.76 139.66 N 115.27 W 5.00 1400.00 36.51 311.06 1350.61 176.71 N 157.18 ~ 5.00 1500.00 41.49 310.35 1428.30 217.72 N 204.88 ~ 5.00 88.58 129.26 177.74 233.64 296.54 1600.00 46.48 309.77 1500.23 262.39 N 258.03 g 5.00 1700.00 51.46 309.28 1565.86 310.37 N 316.20 ~ 5.00 1800.00 56.45 308.85 1624.68 361.30 N 378.97 W 5.00 1878.41 60.36 308.54 1665.75 403.04 N 431.09 ~ 5.00 1980.00 60.36 308.54 1715.99 458.06 N 500.15 g 0.00 365.96 441.37 522.20 588.97 EOC 677.26 9 5/8" Csg Pt 2000.00 60.36 308.54 1725.88 468.90 N 513.75 ~ 0.00 2500.00 60.36 308.54 1973.14 739.70 N 853.64 ~ 0.00 3000.00 60.36 308.54 2220.40 1010.50 N 1193.54 W 0.00 3500.00 60.36 308.54 2467.66 1281.30 N 1533.44 ~ 0.00 4000.00 60.36 308.54 2714.93 1552.10 N 1873.33 ~ 0.00 694.64 1129.17 1563.70 1998.23 2432.76 4500.00 60.36 308.54 2962.19 1822.90 N 2213.23 g 0.00 4566.04 60.36 308.54 2994.85 1858.67 N 2258.12 ~ 0.00 4600.00 59.00 308.54 3011.99 1876.93 N 2281.05 W 4.00 4643.59 57.26 308.54 3035.00 1900.00 N 2310.00 ~ 4.00 4675.09 56.00 308.54 3052.33 1916.39 N 2330.57 ~ 4.00 2867.29 2924.68 Begin Angle Drop 2953.99 2991.00 TARGET 3017.31 4775.09 52.00 308.54 3111.09 1966.80 N 2393.84 ~ 4.00 3098.18 4875.09 48.00 308.54 3175.36 2014.52 N 2453.74 ~ 4.00 3174.76 4975.09 44.00 308.54 3244.81 2059.34 N 2509.98 W 4.00 3246.67 5075.09 40.00 308.54 3319.11 2101.02'N 2562.31 ~ 4.00 3313.56 5175.09 36.00 308.54 3397.89 2139.38 N 2610.45 ~ 4.00 3375.11 5275.09 32.00 308.54 3480.78 2174.22 N 2654.18 ~ 4.00 3431.01 5375.09 28.00 308.54 3567.37 2205.37 N 2693.27 ~ 4.00 3480.99 5475.09 24.00 308.54 3657.23 2232.68 N 2727.55 W 4.00 3524.82 5575.09 20.00 308.54 3749.93 2256.02 N 2756.84 ~ 4.00 3562.26 5575.17 20.00 308.54 3750.00 2256.04 N 2756.86 ~ 4.00 3562.29 TD / 7" Csg Pt (End Angle Drop) RECEIVED APR 1 4 199 Alaska Oil .& Gas Cons. o0mmissio~ Ail'data is in feet un[ess otherwise stated ~nch0rage Coordinates from slot #4-2 and TVD from we[[head (115.00 Ft above mean sea [eve[) Vertical section is from we[[head on azimuth 309.44 degrees. Declination is 0.00 degrees, Convergence is -1.14 degrees. Calculation uses the minimum curvature method. Presented by Eastman Te[eco UNOCAL BRUCE Platform,9-6 Granite Point Field,Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref : 9-6 Version #2 Last revised : 6-Apr-93 Comments in we[lpath MD TVD Rectangular Coords. Comment 400.00 400.00 0.00 N 0.00 E Begin Nudge 600.16 600.00 6.99 N 0.00 E 13 3/8" Csg Pt 720.46 720.00 15.38 N 0.00 ~ KOP 1878.41 1665.75 403.04 N 431.09 g EOC 1980.00 1715.99 458.06 N 500.15 ~ 9 5/8" Csg Pt 4566.04 2994.85 1858.67 N 2258.12 ~ Begin Angle Drop 4643.59 3035.00 1900.00 N 2310.00 ~ TARGET 5575.17 3750.00 2256.04 N 2756.86 ~ TD / 7" Csg Pt (End Angle Drop) Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing · 0.00 0.00 O.OON O.OOE 600.16 600.00 6.99N O.OOE 13 3/8" Csg 0.00 0.00 O.OON O.OOE 2010.96 1731.30 474.83N 521.20~ 9 5/8" Csg 0.00 0.00 O.OON O.OOE 5575.17 3750.00 2256.04N 2756.86~ 7" Csg Targets associated with this we[[path Target name Position T.V.D. Local rectangular coords. Date revised 9-6 Version #1 not specified 3035.00 1900.00N 2310.00~ 6-Apr-93 RECEIVED APR 1 4 1993 Alaska Oil & Gas Cons. Oomrnissio~ Anchorage All data is in feet un[ess otherwise stated Coordinates from slot #4-2 and TVD from wellhead (115.00 Ft above mean sea [eve[) Bottom hole distance is 3562.30 on azimuth 309.29 degrees from wellhead. Total Dogleg for we[[path is 102.28 degrees. Vertical section is from wellhead on azimuth 309.44 degrees. Declination is 0.00 degrees, Convergence is -1.14 degrees. Calculation uses the minimum curvature method. Presented by Eastman Te[eco UNOCAL BRUCE Platform 9-6 slot #4-2 Granite Point Field Cook Inlet, Alaska CLEARANCE REPORT by Eastman Teleco Your ref : 9-6 Version #2 Our ref : prop751 License : Date printed : 6-Apr-93 Date created : 6-Apr-93 Last revised : 6-Apr-93 Field is centred on n60 59 36.731,w151 18 33.112 Structure is centred on n60 59 36.731,w151 18 33.112 Slot location is n60 59 56.542,w151 17 53.549 Slot Grid coordinates are N 2559380.514, E 269562.634 Slot local coordinates are 2012.00 N 1951.00 E Reference North is True North ( WARNING: DATA BELOW/ IS A SUMMARY, DETAIL PROXIMITIES NOT TABULATED ) Object wellpath MSS <2280-11500'>,,4,BRUCE Platform MSS <2020-11443'>,,6,BRUCE Platform GMS <7000-10550'>,,20Rd,BRUCE Platform MSS <6990-10085">,,20,BRUCE Platform GMS <O-10060'>,,12Rd,BRUCE Platform MSS <2144-10480'>,,12,BRUCE Platform PGMS <0-12434'>,,6,BRUCE Platform MSS <10203-10518'>,,8,BRUCE Platform MSS <3970-12001'>,,8,BRUCE Platform PGMS <0-9931'>,,30,BRUCE Platform MSS <1970-10370'>,,lO,BRUCE Platform GMS <0-10585'>,,14,BRUCE Platform MSS <0-9960'>,,18,BRUCE Platform GMS <0-10675'>,,31,BRUCE Platform MSS <4220-11996'>,,40-2,BRUCE Platform MSS <6386-9613'>,,5,BRUCE Platform MSS <6386-10756'>,,5,BRUCE Platform GMS <0-9550'>,,5Rd,BRUCE Platform MSS <4828-6878'>,,5,BRUCE Platform MSS <5293-12200'>,,5,BRUCE Platform MSS <2102-10087'>,,8,BRUCE Platform MSS <3225-10143'>,,16A,BRUCE Platform MSS <3225-7065'>,,16,BRUCE Platform MSS <5017-10905'>,,4,BRUCE Platform GMS <0-10013'>,,34,BRUCE Platform MSS <2040-12033'>,,3,BRUCE Platform MSS <2168-11015'>,,3,BRUCE Platform Closest approach with 3-D minimum distance method Last revised Distance M.D. Diverging from M.D. 19-Mar-93 106.9 60.0 5575.2 22-Feb-93 72.6 780.1 5575.2 4-Apr-93 70.1 760.2 5575.2 22-Feb-93 70.1 760.2 5575.2 2-Apr-93 68.4 400.0 5575.2 2-Apr-93 68.4 400.0 5575.2 2-Apr-93 28.1 925.0 925.0 3-Apr-93 61.9 620.0 5575.2 3-Apr-93 61.9 620.0 5575.2 2-Apr-93 63.8 433.3 5575.2 2-Apr-93 71.2 140.0 5575.2 2-Apr-93 74.5 760.2 5575.2 2-Apr-93 72.3 320.0 5575.2 2-Apr-93 73.2 260.0 5575.2 2-Apr-93 66.5 433.3 5575.2 5-Apr-93 7.6 300.0 5575.2 4-Apr-93 7.6 300.0 5575.2 4-Apr-93 7.6 300.0 5575.2 3-Apr-93 77.1 680.0 5575.2 3-Apr-93 77.1 680.0 5575.2 3-Apr-93 3.5 100.0 5575.2 2-Apr-93 6.2 400.0 5575.2 2-Apr-93 6.2 400.0 5575.2 5-Apr-93 6.0 200.0 5575.2 5-Apr-93 6.0 200.0 5575.2 3-Apr-93 8.8 60.0 5575.2 3-Apr-93 69.8 740.3 5575.2 <-- West 80 70 60 50 40 30 20 1300 UNO Slruetum : BRUCE Plofform Well : 9-6 F~ld : Orantte Point F'leld Lo,ration :Coek Inlet, Alaska 1200 1200 1100 10 I Scale 0 1100 10.00 2O 1000 10 lO0 9O 8O 7O 6O /x Z 40 0 3O 9O0 800 1300 700 200 600 1000 800 5OO 2O 10 0 10 2O WELL CASING STRING CASING AND TUBING DESIGN BOROUGH /~'~ o c ,' STATE DESIGN BY ~ o Q.t ¢- HUD WT. I 5~. .5- # / g . /o.0 ttYD GR. I O,'~-9~' psi/ft. Oo .,F-O 0 O..~o MUD WT. II #1g. HYD. GR. II psi/ft. M.S.P. ps~ CASING SIZE 1./.3 ~.~_~" INTERVAL Bottom Top LENGTH 6~oo 93 z-x? DESCRIPTION Wt. Grade Thread ~/7~ A/- ~o ~,~ WEIGHT W/ BF W/O BF X lbs TENSION MINIMUM COLLAPSE COLLAPSE -top of STRENGTH PRESS. ~ RESIST. section TENSION bottom tension lbs 1000 lbs TDF psi psi CDF INTERNAL BURST MINIMUM PRESSURE YIELD psi psi BDF ~'.6 8'.s- 7 .S 5rd-o & c,. ¢ /2 7.3 / ~/ ~.r 7 / ?~0 65 70 3. ._.4"-.z'3 3 9' 2 /60., 9,.,r'? .s:.,,e_ ~7~ % ~ ~5'..Fo 702. .3,6 / 5'.Y-O 2/~0 9. UNOCAL - BRUCE ':,x 3 - 5000 WP laS" 'i L .I Itei I Oty. ~escription .l l.O0 6 way block 4X4X3X]X312' 2 4.00 4' ~M oat~ valw '~.00 3' 5H ~ate valve 4 1.00 flan~ed tee 4X3 5~ 2.00 4 ~ay block 3' 5~ 6 2.00 byd-cboke ~' 7 1.00 man choke 3' ~ 1.00 drilled saacer 3' ~ ~ 5 .75' lO 1.00 ~SA ~' f,~ I I0~ X 12 1.00 DS~ 4' 5~ X 4.5' !5 5.00 target flange 3' 16 2.00 blind flange ~' I.O0 soool 3' ~ flo 20 1.00 buffer tank 15' O.~,X 96' 21 1.00 flanoed cross 2' 22 2,00 blind flanoe 2' 24 ~.00 2' 5~ X 2-2' LPT tran~aitter t.O0 0-6000 ps~ o~uoe 2.00 blind flanoe 4' 27 5.00 ~-2~ API rino 30.00 R-3S APl rino 8.00 R-3~ API rino ~.00 ~I-l~ API rirm 31 ~.00 siu~ w/ 2 nut5 7/~X6 1/2 32 72.00 stud ~/ 2 nut~ I I/SX 7 1/2 33 B.O0 stud wi 2 nuts 1 I/BX 7 3/4 40.00 stud w/2 nuts I I/4X ~ I/2 ~.00 stu~, 2/ nuts ~.00 stud w/ Z nuts 1 front view VIeW BRUCE SHAXER ?IT3 Desilter e 8I! Blanked off 52.5 bbl# · 618 bbl/in Eq. riser Nud return ; to pits ! · : Eq. windows '. 57" frm btm Eq. windows/~ ~ ~:.~" frm~q '~ b~ Btm Eq ;m 57,5 bbl# .677 bbl/in ~and Trap 156.8 bbl* 1.84 bbl/tn · · · · · Flow Line 6" rrm poorbo degasser opossum Belly 2" Reverse out ine frm rig flo gates " $ ~-- 4" Floor drain ~-- Butterfly valve *.-- With riser $ 85" Cuttings Rumba Shaker Trough Overboard .. .o #4 1.9 bbl/in 229 bbl #5 2 bbl/in 240 bbl Mud Retu~-~n-l, eg 1 Top Eq 96"Frm Btm To Top Deck #6 1.54 bbl/i 184 bbl 6~ izer Flow Line 8 Il Equa .lzer 8~ S'un Pill Pi aturn Legs 3 & 4 Su_s ti.on_~ ILl ne Walk Way Btm Equalizer 10" Frm Btm Equalizer Btm Eq 0" Frm Btm #2 2 bbl/ln 240 bbl n Line Equalizer ill b #3 1.9 bbl/in 229 bbl t 1.54 bbl/in 184 bbl Top Eq 96" Frm Btm Hopper Return AncJ~o~'a~?, un ~--Ball Valve "~G Lines) --Dump Valve --ButterflY Valve PLATFORM BRUCE _DRILLING STACK PITCHER NIPPLE- 16' ID W/10" FLOWLINE ANNULAR BOP "NL SHAFFER" 13 5/8' 5000 PSI BX-160 ASSY WT. 13,650 LBS. DBL GATE BOP "NL SHAFFER' 13 5/8' 5000 PSI BX-160 ASSY WT. 16,500 LBS. MUD CROSS- 13 5/8' BORE W/4" 5000 PSI VALVES SGL,-GATE BOP "NL SHAFFER" 13 5/8' 5000 PSI BX-160 ASSY WT. 9100 LBS. RISER 18'OD 13 5/8" 5000 FLG A!ask~ ~il & Gas Cons, CommiSsior~ A~chora§~ LOWER RISER 11" ID W/lO" 5000 PSI FLG (RX-54) State: Alaska Borough: Well: GPF #9 Field: Granite Pt. Field St. Perm ~ 9,3-62 Da~e 4/1 Engr: M. Minder t~PFtlg. DOC Casing Interval Interval Descriptionescripfionescription Tension Size Boffom Top Length 1A 13.375 600 43 577 2A 9.625 1715 43 1937 3A 7 3750 42 5533 4A 0 0 0 0 5A 0 0 0 0 6A 0 0 0 0 7A 0 0 0 0 SA 0 0 0 0 9A 0 0 0 0 10A 0 0 0 0 Lbs Grade Thread Lbs 68 K-55 BTC 0 47 N-80 BTC 0 29 N-80 BTC 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Mud Hydraulic Collapse Weight Gradient Gradient ppg psi/It psi/ft lB 9.5 0.494 0.394 2t9 9.6 0.499 0.399 SB 10.0 0.520 0.420 4B 0.0 0.000 -0.100 5B 0.0 0.000 -0.100 CoB 0.0 0.000 -0.100 7B 0.0 0.000 -0.100 819 0.0 0.000 -0.100 9B 0.0 0.000 -0.100 1 OB 0.0 0.000 -0.100 Maximum Minimum Pressure Yield psi psi BDF 1950 3450 1.8 1950 6870 1950 8160 4.2 0 0 #DIV/O! 0 0 #DIV/O! 0 0 #DIV/O! 0 0 #DIV/O! 0 0 #DIV/O! 0 0 #DIVI0! 0 0 #DIV/O! Tension Strength K/Lbs K/Lbs 1C 39.236 1069 2C 91.0G9 1086 3C 160.457 4C 0 5C 0 6C 0 7C 0 8C 0 9C 0 10C 0 TDF 27.25 11.93 676 4.21 0 #DIV/O! 0 #DIV/O! 0 #DIV/0! 0 #DIV/0.1 0 #DIV/0! 0 #DIV/O! 0 #DIV/0! Collapse Collapse Pr-Bot-Psi Resist, CDF 236 1950 8.;Z49 685 4750 6.938 1575 7020 4.457 0 0 #DIV/0! o 0 #DiV/O! 0 0 #DIV/O! 0 0 #DIV/0! 0 0 #DIV/O! 0 0 #DIV/0! 0 0 #DIV/O! Page 1 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee ~- (2) _Loc. [2 thru 8] (3) Admin~...-[ 8 9~ru 13 ] [10 & 13] [14 thru 22] (:5) [23 thru 28] (6) Other~.. ~ I~-~:1 [29 thru 31] (7) Contact · [32] (8) Addl geology' engineerinq' DWJ MTM~,./' RAD RPC~ BEW .'"" LG rev 12/92 jo/6.011 Company 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ e 10. 11. 12. 13. 14. 15. Lease & Well ~,~/3L 17~-~ YES NO Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nc~nber appropriate .......................................... Does well have a unique name & n~nber ................................ I s conductor st r i ng prov i ded ......................................... Will surface casing protect al 1 zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. adequate wel lbore separation proposed ............................. Is Is a diverter system required ........................................... Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of ~ BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... 16. 17. 18. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone n~nber of contact to supply weekly progress data ...... 33. Additional requirements ............................................. I INI'TIAL GEoL .... UNIT ON/OFF ,pooL CLASS STATUS ,,,, AREA ~ SHORE t)c oF/:- , REMARKS Additional remarks: ~T~.~: ;.~ ~,,~ $~-!,!to,.,,:. e~,c' ~' . UM / hlERIDIAN: SM~-' ~ TYPE: Exp/Dev,,,~ 'Inj ,, .... Redri l l__ Rev .... 0 ,-,0 c'bm z Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, informati;3n 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. Tape Subfile 1 ~s ~ype: LIS **** REEL HEADER **** 93/ 6/21 **** TAPE HEADER **** 93/ 6/21 Tape Subfile: 1 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subfile 2 is type: LIS **** FILE HEADER **** CN WN FN COUN STAT : UNOCAL : GRANITE POINT 17586 #9 : GRANITE POINT : KENAI : ALASKA LIS COMMENT RECORD (s): MERGED MAIN PASS, RUN ~1 & RUN ~2. GR, CN, & AC DATA WAS SPLICED AT 5430 ft. DIFL DATA WAS SPLICED AT 5463 ft. * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 23 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 2 AC AC 68 1 3 ACQ AC 68 1 4 CHT AC 68 1 5 TEN AC 68 1 6 TTEN AC 68 1 7 TEMP AC 68 1 8 SPD AC 68 1 9 CNC 2435 68 1 10 CNCF 2435 68 1 11 CN 2435 68 1 12 LSN 2435 68 1 13 SSN 2435 68 1 14 DEN CDL 68 1 15 CORR CDL 68 1 16 CAL CDL 68 1 17 RFOC DIFL 68 1 18 RILM DIFL 68 1 19 RILD DIFL 68 1 20 SP DIFL 68 1 21 CILD DIFL 68 1 GAPI US/F LB LB LB DEGF F/MN PU-S PU-S PU-L CPS CPS G/C3 G/C3 IN OHMM OHMM OHMM MMHO 4 06 969 49 6 4 48 852 89 1 4 81 285 47 0 4 95 558 30 1 4 95 558 30 1 4 95 558 30 1 4 61 008 99 5 4 61 094 30 1 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 4 59 047 24 5 4 34 168 75 6 4 87 374 67 0 4 27 515 24 6 4 06 213 78 0 4 04 903 06 0 4 53 419 67 0 4 34 704 23 6 22 VILD DIFL 68 1 MV · · 23 VILM DIFL 68 1 MV 4 04 522 10 4 04 522 10 * DATA RECORD (TYPE# 0) Total Data Records: 1982 966 BYTES * 92 Tape File Start Depth = 5954.000000 Tape File End Depth = 1000.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 475609 datums Tape Subfile: 2 1988 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 3' is {ype: LIS **** FILE HEADER **** CN WN FN COUN STAT : UNOCAL : GRANITE POINT 17586 NO.9 : GRANITE POINT : KENAI : ALASKA LIS COMMENT RECORD (s) : RUN #1 MAIN PASS. * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 19 Curves: Name Tool Code Samples Units 1 GR AC 68 1 2 AC AC 68 1 3 ACQ AC 68 1 4 CHT AC 68 1 5 TTEN AC 68 1 6 SPD AC 68 1 7 RFOC DIFL 68 1 8 RILD DIFL 68 1 9 RILM DIFL 68 1 10 SP DIFL 68 1 11 VILD DIFL 68 1 12 CNC 2435 68 1 13 CNCF 2435 68 1 14 CN 2435 68 1 15 LSN 2435 68 1 16 SSN 2435 68 1 17 DEN CDL 68 1 18 CORR CDL 68 1 19 CAL CDL 68 1 API API API API Log Crv Crv Size Length Typ Typ Cls Mod GAPI 4 US/F 4 4 LB 4 LB 4 F/MN 4 OHMM 4 OHMM 4 OHMM 4 MV 4 MV 4 PU-S 4 PU-S 4 PU-L 4 CPS 4 CPS 4 G/C3 4 G/C3 4 IN 4 4 06 969 49 6 4 48 852 89 1 4 81 285 47 0 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 4 27 515 24 6 4 04 903 06 0 4 06 213 78 0 4 53 419 67 0 4 04 522 10 6 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 4 59 047 24 5 4 34 168 75 6 4 87 374 67 0 * DATA RECORD (TYPE~ 0) 966 BYTES * Total Data Records: 1214 Tape File Start Depth = 5506.000000 Tape File End Depth = 1866.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet 76 **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 291221 datums Tape Subfile: 3 1219 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile ~ is ~ype: LIS **** FILE HEADER **** CN WN FN COUN STAT : UNOCAL : GRANITE POINT 17586 NO.9 : GRANITE POINT : KENAI : ALASKA LIS COMMENT RECORD (s): RUN #1 REPEAT PASS. * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 19 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 2 AC AC 68 1 3 ACQ AC 68 1 4 CHT AC 68 1 5 TTEN AC 68 1 6 SPD AC 68 1 7 RFOC DIFL 68 1 8 RILD DIFL 68 1 9 RILM DIFL 68 1 10 SP DIFL 68 1 11 VILD DIFL 68 1 12 CNC 2435 68 1 13 CNCF 2435 68 1 14 CN 2435 68 1 15 LSN 2435 68 1 16 SSN 2435 68 1 17 DEN CDL 68 1 18 CORR CDL 68 1 19 CAL CDL 68 1 GAPI 4 US/F 4 4 LB 4 LB 4 F/MN 4 OHMM 4 OHMM 4 OHMM 4 MV 4 MV 4 PU-S 4 PU-S 4 PU-L 4 CPS 4 CPS 4 G/C3 4 G/C3 4 IN 4 4 06 969 49 6 4 48 852 89 1 4 81 285 47 0 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 4 27 515 24 6 4 04 903 06 0 4 06 213 78 0 4 53 419 67 0 4 04 522 10 6 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 4 59 047 24 5 4 34 168 75 6 4 87 374 67 0 * DATA RECORD (TYPE# 0) 966 BYTES * Total'Data Records: 113 Tape File Start Depth = 5506.000000 Tape File End Depth = 5170.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet 76 **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 502510 datums Tape Subfile: 4 118 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 5 is {ype: LIS **** FILE HEADER **** CN WN FN COUN STAT : UNOCAL : GRANITE POINT 17586 NO.9 : GRANITE POINT : KENAI : ALASKA LIS COMMENT RECORD(s): RUN #2 MAIN PASS. * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 2 AC AC 68 3 ACQ AC 68 4 CHT AC 68 5 TTEN AC 68 6 TEN AC 68 7 SPD AC 68 8 RFOC DIFL 68 9 RILD DIFL . 68 10 RILM DIFL 68 11 SP DIFL 68 12 CILD DIFL 68 13 VILD DIFL 68 14 VILM DIFL 68 15 TEMP DIFL 68 16 CNC 2435 68 17 CNCF 2435 68 18 CN 2435 68 19 LSN 2435 68 20 SSN 2435 68 1 GAPI 1 US/F 1 1 LB 1 LB 1 LB 1 F/MN 1 OHMM 1 OH/~I 1 OHMM 1 MV 1 MM/-IO 1 MV 1 MV 1 DEGF 1 PU-S 1 PU-S 1 PU-L 1 CPS 1 CPS 4 4 06 969 49 6 4 4 48 852 89 1 4 4 81 285 47 0 4 4 95 558 30 1 4 4 95 558 30 1 4 4 95 558 30 1 4 4 61 094 30 1 4 4 27 515 24 6 4 4 04 903 06 0 4 4 06 213 78 0 4 4 53 419 67 0 4 4 34 704 23 6 4 4 04 522 10 6 4 4 04 522 10 6 4 4 40 467 34 0 4 4 98 211 23 1 4 4 98 211 23 1 4 4 52 326 75 5 4 4 84 023 70 1 4 4 83 368 34 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 270 Tape File Start Depth = 5954.000000 Tape File End Depth = 5146.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet 80 **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 359115 datums Tape Subfile: 5 276 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Tape Subfile 6 is {ype: LIS **** FILE HEADER **** CN WN FN COUN STAT : UNOCAL : GRANITE POINT 17586 NO.9 : GRANITE POINT : KENAI : ALASKA LIS COMMENT RECORD (s): RUN #2 LOWER REPEAT PASS. (TD- 5650) * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units 1 GR AC 68 1 2 AC AC 68 1 3 ACQ AC 68 1 4 CHT AC 68 1 5 TTEN AC 68 1 6 TEN AC 68 1 7 SPD AC 68 1 8 RFoc DIFL 68 1 9 RILD DIFL 68 1 10 RILM DIFL 68 1 11 SP DIFL 68 1 12 CILD DIFL 68 1 13 VILD DIFL 68 1 14 VILM DIFL 68 1 15 TEMP DIFL 68 1 16 CNC 2435 68 1 17 CNCF 2435 68 1 18 CN 2435 68 1 19 LSN 2435 68 1 20 SSN 2435 68 1 API API API API Log Crv Crv Size Length Typ Typ Cls Mod GAPI 4 US/F 4 4 LB 4 LB 4 LB 4 F/MN 4 OHMM 4 OHMM 4 OHMM 4 MV 4 MMHO 4 MV 4 MV 4 DEGF 4 PU-S 4 PU-S 4 PU-L 4 CPS 4 CPS 4 4 06 969 49 6 4 48 852 89 1 4 81 285 47 0 4 95 558 30 1 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 4 27 515 24 6 4 04 903 06 0 4 06 213 78 0 4 53 419 67 0 4 34 704 23 6 4 04 522 10 6 4 04 522 10 6 4 40 467 34 0 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 89 Tape File Start Depth = 5916.000000 Tape File End Depth = 5652.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet 80 **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 524708 datums Tape Subfile: 6 95 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Tape Subfile 7 is fype: LIS **** FILE HEADER **** CN WN FN COUN STAT : UNOCAL : GRANITE POINT 17586 NO.9 : GRANITE POINT : KENAI : ALASKA LIS COMMENT RECORD (s) : RUN #2 UPPER REPEAT PASS. (5600 - 5200) * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 2 AC AC 68 1 3 ACQ AC 68 1 4 CHT AC 68 1 5 TTEN AC 68 1 6 TEN AC 68 1 7 SPD AC 68 1 8 RFOC DIFL 68 1 9 RILD DIFL 68 1 10 RILM DIFL 68 1 11 SP 'DIFL 68 1 12 CILD DIFL 68 1 13 VILD DIFL 68 1 14 VILM DIFL 68 1 15 TEMP DIFL 68 1 16 CNC 2435 68 1 17 CNCF 2435 68 1 18 CN 2435 68 1 19 LSN 2435 68 1 20 SSN 2435 68 1 GAPI 4 US/F 4 4 LB 4 LB 4 LB 4 F/MN 4 OHMM 4 OHMM 4 OHMM 4 MV 4 MMHO 4 MV 4 MV 4 DEGF 4 PU-S 4 PU-S 4 PU-L 4 CPS 4 CPS 4 4 06 969 49 6 4 48 852 89 1 4 81 285 47 0 4 95 558 30 1 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 4 27 515 24 6 4 04 903 06 0 4 06 213 78 0 4 53 419 67 0 4 34 704 23 6 4 04 522 10 6 4 04 522 10 6 4 40 467 34 0 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 139 Tape File Start Depth = 5629.000000 Tape File End Depth = 5213.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet 80 **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 394081 datums Tape Subfile: 7 145 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Tape Subfile 8j ~s ~ype: LIS **** TAPE TRAILER **** 93/ 6/ 8 **** REEL TRAILER **** 93/ 6/ 8 Tape Subfile: 8 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes End of execution: Mon 21 JUN 93 8:59p Elapsed execution time = 1 minute , 35.2 seconds. SYSTEM RETURN CODE = 0