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Home My WebLink About186-009CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Brooks, Phoebe L (OGC) To:Brian Woolley Cc:Regg, James B (OGC) Subject:RE: [EXTERNAL] RE: Beluga River BRWD MIT results. Date:Thursday, November 20, 2025 4:33:14 PM Attachments:MIT BRU BRWD 1 10-13-25 Revised.xlsx Thanks Brian. I’ve attached a revised report correcting the PTD # to reflect 1860090 and well # to 1 (the AOGCC Rep should only include an inspector’s name if witnessed or be left blank if waived so I moved the verbiage to the remarks). Please update your copy. Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Brian Woolley <bwoolley@hilcorp.com> Sent: Thursday, November 20, 2025 4:26 PM To: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: RE: [EXTERNAL] RE: Beluga River BRWD MIT results. Phoebe, I see on our PTD 10-404 and 10-403 forms as 186-009 for BRWD-1. Does that help? Brian Woolley Beluga River/Westside Lead Operator Office 907-263-3905 Cell 907-252-3745 Alternate:Brandon Bauer Hilcorp Alaska, LLC From: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Sent: Thursday, November 20, 2025 3:11 PM To: Brian Woolley <bwoolley@hilcorp.com> Subject: [EXTERNAL] RE: Beluga River BRWD MIT results. %HOXJD5LYHU8QLW%5:' 37' 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. Brandon, The Well number was not listed (BRWD was included where the well # should be)…PTD #1841360 is for 232-09 (which was tested on 9/30/25), so I wanted to verify what well this was for. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Brian Woolley <bwoolley@hilcorp.com> Sent: Thursday, October 16, 2025 8:28 AM To: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Daniel Taylor <dtaylor@hilcorp.com>; Joe Nightingale <jnightingale@hilcorp.com>; Brandon Bauer <bbauer@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: Beluga River BRWD MIT results. Phoebe, Please find our Beluga River BRWD MIT test results. Thanks Brian Woolley Beluga River/Westside Lead Operator Office 907-263-3905 Cell 907-252-3745 Alternate:Brandon Bauer Hilcorp Alaska, LLC 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. 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. Submit to: OOPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1860090 Type Inj N Tubing 1783 1783 1782 1781 1779 1778 Type Test P Packer TVD 3125 BBL Pump 0.5 IA 247 1512 1511 1510 1510 1510 Interval O Test psi 1500 BBL Return 0.5 OA 0 00000Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Hilcorp Beluga River / BRU / BRWD Brandon Bauer / Andrew Schaafsma 10/13/25 Notes:Test result is PASS. Witness waived. Notes: Notes: Notes: 1 Form 10-426 (Revised 01/2017)2025-1013_MIT_BRU_BRWD-1 9 9 5HJJ 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: CTCO Development Exploratory 3. Address: Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 3,560 feet N/A feet true vertical 3,560 feet 3,249 3,500 feet Effective Depth measured 3,500 feet 3,125 feet true vertical 3,500 feet 3,125 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 2.875" N-80 3,147' MD/TVD Packers and SSSV (type, measured and true vertical depth) Hughes Pkr; N/A 3,125' MD/TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 2,000' 2,000' Burst Collapse Production Liner 3,536' Casing Structural 3,554'3,554' 98'Conductor Surface Intermediate 20 9-5/8" 76' 1,980' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 186-009 50-283-20078-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0058831 Beluga River / Undefined WDSP Beluga River Unit BRWD-1 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 350 Size 98' 0 3500 0 00 0 Jake Flora, Operations Engineer 323-399 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 jake.flora@hilcorp.com 907-777-8442 N/A p k ft t Fra O s 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 10:50 am, Aug 25, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.08.23 16:51:35 - 08'00' Noel Nocas (4361) Rig Start Date End Date 8/1/23 8/2/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BRWD-1 50-283-20078-00-00 186-009 08/01/2023 - Tuesday PJSM and PTW, SIMOPS with production and construction. MOBE equipment from E pad to DW2. Spot equipment, fill supply tank with produced water, R/U Fox coil tubing and Cruz crane. N/U riser and BOPEs, run choke and kill lines. Fluid pack surface lines. Test BOPE per Hilcorp and AOGCC requirements to 250psi/2500psi - TEST GOOD Witness waived by AOGCC Jim Regg via e-mail @ 0829 on 8/1/23. Secure well and SDFN 08/02/2023 - Wednesday PJSM and PTW. SIMOPS with production and construction SITP 0psi. P/U injector, M/U coil connector, check valve, stinger, and 1.70"OD nozzle Stab on well, fill reel with produced water Pressure test pump iron, lubricator, and stripper to 250psi/2,500psi -Test good. RIH and dry tag at 3,154ft Come online with the pumps at 1.6BPM and wash from 3154' to 3164' encounter hard spot, wash at 3,164' for 1hr, broke through easily wash down to 3,237' and encounter hard spot slowly wash from 3,237' to 3247'. Circulate until returns are clean POOH while circulating. Secure well Break the injector off, and secure the injector in the cradle. Open well for injection test. Pump injection test. Stage up in 500psi increments, pressure broke over at 1,300psi and injection established 1.0BPM @ 400psi 2.0BPM @ 450psi 2.5BPM @ 560psi 3.0BPM @ 650psi 3.5BPM @ 800psi 4.0BPM @ 940psi 4.5BPM @ 1030psi 5.0BPM @ 1150psi Injected 60BBLs Total losses to well 120BBL of produced water. Secure well R/D Coil, Crane, Tanks SDFN _____________________________________________________________________________________ Updated by DMA 08-23-23 SCHEMATIC Beluga River Unit Well: BRWD 1 Last Completed: 5/28/1986 PTD: 210-050 API: 50-283-20078-00-00 20 9-5/8 7 RKB to MSL = 88 RKB to GL = 70 TD = 3,560 TVD = 3,560 PBTD = 3,560 ED = 3,500 ETVD = 3,500 Beluga Sands P1 P2 P3 P4 P5 P6 P7 P8 P9 P10 2 3 4 5 A B Max Angle = 1.8 deg @ 0 Tubing Min ID = 2.323 TOC @ 2,104 TOC to Surface 1 Suspected casing collapse @ 3,283 TUBING DETAILS 2-7/8"Production String 6.5#N-80 EUE-8RD 2.441''3,134.2' CASING DETAIL Size Type WT Grade Conn ID Btm 20''Conductor 94#H-40 Weld 19.124''96' 9-5/8"Surface 43.5#AC-95 BTC 8.835''904' 9-5/8"Surface 40#N-80 BTC 8.835''1,729' 9-5/8"Surface 47 RS-95 BTC 8.835''2,000' 7''Production 29#P-110 BTC 6.059''3,554' JEWELRY DETAIL Production String ID. Depth MD (ft.) ID (in.) Description 1 15.9 2.323 WKM U-EN Tubing Hanger 2 3,120 2.375 Hughs CL Locator w/ 4 Seal Units 3 3,125 3.25 7" I-B Hughs Packer 4 3,131 3.92 Millout Extension Cut and Dropped at 3134' 5 3,134 -Coil Tubing Underreamer Cut of Millout. EOT=3134 PERFORATION DETAIL Zones Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Phase Date Status P1 3,133'3,141'3,133'3,141'8'6 60 8/23/2014 Open RPERF P1 3,133' 3,141' 3,133' 3,141' 8' 6 60 8/12/2014 Open RPERF P2 3,141' 3,155' 3,141' 3,155' 14' 6 60 8/23/2014 Open RPERF P2 3,141' 3,155' 3,141' 3,155' 14' 6 60 8/12/2014 Open RPERF P3 3,186' 3,191' 3,186' 3,191' 5' 6 60 8/23/2014 Open RPERF P3 3,186' 3,191' 3,186' 3,191' 5' 6 60 8/12/2014 Open RPERF P4 3,191' 3,197' 3,191' 3,197' 6' 6 0 5/30/2013 Open APERF P4 3,191' 3,197' 3,191' 3,197' 6' 6 60 6/3/2013 Open RPERF P5 3,205' 3,212' 3,205' 3,212' 7' 6 0 5/30/2013 Open APERF P5 3,205' 3,212' 3,205' 3,212' 7' 6 60 6/3/2013 Open RPERF P6 3,222' 3,231' 3,222' 3,231' 9' 6 0 5/30/2013 Open APERF P6 3,222' 3,231' 3,222' 3,231' 9' 6 60 6/3/2013 Open RPERF P7 3,286' 3,356' 3,286' 3,356' 70' 22 1 7/1/1992 Perf'd in '86 @ 12SPF, '87 @ 4 SPF, '92 @ 6 SPF P8 3,408' 3,422' 3,408' 3,422' 14' 22 1 7/1/1992 Perf'd in '86 @ 12SPF, '87 @ 4 SPF, '92 @ 6 SPF P9 3,448' 3,478' 3,448' 3,478' 30' 22 1 7/1/1992 Perf'd in '86 @ 12SPF, '87 @ 4 SPF, '92 @ 6 SPF P10 3,478' 3,502' 3,478' 3,502' 24' 16 1 7/1/1992 Perf'd in '86 @ 12SPF, '87 @ 4 SPF Fish ID. Depth MD (ft.) ID (in.) Description A Estimate TOF @ 3,249(7/12/23)2.205 12.8' of 4.5" Max OD millout Extension & 2.875' Tailpipe left on bottom of 7" perforation section after Coil Tubing unit Underreamer tubing cut 8/11/2014 B 3,500 - Slickline toolstring Overshot w/ fishing neck & unknown length of wire attached, left on bottom 10/05/87 1.91" OD x 1.5' 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: CTCO 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 3,560'3,232', 3,500' Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Hughes Pkr; N/A 3,125' MD/TVD; N/A, N/A 3,560'3,560'3,560' Beluga River Undefined WDSP 20" 9-5/8" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Beluga River Unit BRWD-1CO 802 Same ~1183psi N/A Length July 28, 2023 2.875" Perforation Depth MD (ft): 3,554' See Attached Schematic 98' 3,554' 98' 2,000' Size 76' 7"3,536' 1,980' MD Hilcorp Alaska, LLC Proposed Pools: N-80 TVD Burst 3,147' 2,000' Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0058831 186-009 50-283-20078-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Jake Flora, Operations Engineer AOGCC USE ONLY Tubing Grade: jake.flora@hilcorp.com 907-777-8442 Noel Nocas, Operations Manager 907-564-5278 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: m n P s 66 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:22 pm, Jul 14, 2023 323-399 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.07.14 14:35:41 - 08'00' Noel Nocas (4361) CT BOP test to 2500 psi. CDW 07/21/2023 DSR-7/19/23BJM 7/21/23 MDG 7/18/2023 10-404 GCW 07/26/2023 07/26/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.07.26 14:02:35 -08'00' RBDMS JSB 072823 Well Prognosis Well Name: BRWD 1 API Number: 50-283-20078-00-00 Regulatory Contact: Donna Ambruz Permit to Drill Number: 186-009 First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (M) Second Call Engineer: Chad Helgeson (907) 777-8420 (O) (907) 229-4824 (M) Maximum Expected BHP: ~ 1530 psi @ 3478’ TVD (0.44 psi/ft gradient to bottom perf) Max. Potential Surface Pressure: ~ 1183 psi (Max expected BHP minus gas to surface) Well Status: Injection Well; Last Injection 10/22/22 (125 bbls water at 1200 psi) Brief Well Summary BRWD 1 is a Class II disposal well drilled and placed on injection in July, 1986 with a DIO allowing disposal of fluids below 3060’. Hilcorp took over operations in 2016 and currently trucks water from the North half of the Beluga River Field for disposal and has begun construction this summer (2023) to set up a grind and inject ball mill to dispose of drilling solids. Slickline has identified fill over most of the perforations. The objective of this sundry is to increase injectivity by cleaning out the wellbore & re-perforating prior to injecting drilling solids. Last Downhole Operation 07/13/23 Bail from 3166-3169’ w 2” DDB, rec muddy sand 05/19/19 1.75” DDB to 3133’, 2” DDB to 3076’ 05/18/19 2” DDB to 3161’ 08/12/14 perforations added: 3133-55, 3186-91’ 08/11/14 coil tubing cut tubing tail at 3134’, dropping 12’ tailpipe, drifted w coil to 3232’, did not tag, fish top likely at 3249’ 2013 perforations added: 3191-97’, 3205-12’, 3222-31’ 2013 obstruction noted at 3290’, suspect casing collapse Procedure 1. Review approved COAs 2. Provide 48hrs notice to AOGCC of BOP test 3. MIRU Coiled Tubing, PT BOPE to 2500 psi Hi 250 Low 4. SI well 5. Route returns to open top diffuser tank 6. RIH w/ 1.75” coil w/ jet nozzle BHA a. Top of fill was recorded to be @ 3133’. Engage fill and clean out as deep as possible (likely to top of fish at 3249’) 7. RU E-line, PT lubricator to 2500 psi 8. Perforate sands from 3133’ – 3231’ MD within existing open perf interval. 9. Hand over to operations Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Coil Tubing BOP Diagram 10/15/2021 MITIA to 1695 psi. Passed. -bjm Perforate sands from 3133’ – 3231’ MD within existing open perf interval. re-perforating p _____________________________________________________________________________________ Updated by DMA 07-14-23 SCHEMATIC Beluga River Unit Well: BRWD 1 Last Completed: 5/28/1986 PTD: 210-050 API: 50-283-20078-00-00 20” 9-5/8” 7” RKB to MSL = 88’ RKB to GL = 70’ TD = 3,560’ TVD = 3,560’ PBTD = 3,560’ ED = 3,500’ ETVD = 3,500’ Beluga Sands P1 P2 P3 P4 P5 P6 P7 P8 P9 P10 2 3 4 5 A B Max Angle = 1.8 deg @ 0’ Tubing Min ID = 2.323” TOC @ 2,104’ TOC to Surface 1 Suspected casing collapse @ 3,283’ TOF @ ~3,161’ TUBING DETAILS 2-7/8"Production String 6.5#N-80 EUE-8RD 2.441''3,134.2' CASING DETAIL Size Type WT Grade Conn ID Btm 20''Conductor 94#H-40 Weld 19.124''96' 9-5/8"Surface 43.5#AC-95 BTC 8.835''904' 9-5/8"Surface 40#N-80 BTC 8.835''1,729' 9-5/8"Surface 47 RS-95 BTC 8.835''2,000' 7''Production 29#P-110 BTC 6.059''3,554' JEWELRY DETAIL Production String ID.Depth MD (ft.)ID (in.)Description 1 15.9 2.323 WKM U-EN Tubing Hanger 2 3,120 2.375 Hughs CL Locator w/ 4 Seal Units 3 3,125 3.25 7" I-B Hughs Packer 4 3,131 3.92 Millout Extension Cut and Dropped at 3134' 5 3,134 -Coil Tubing Underreamer Cut of Millout. EOT=3134 PERFORATION DETAIL Zones Top (MD)Btm (MD)Top (TVD)Btm (TVD)Amt SPF Phase Date Status P1 3,133'3,141'3,133'3,141'8'6 60 8/23/2014 Open RPERF P1 3,133'3,141'3,133'3,141'8'6 60 8/12/2014 Open RPERF P2 3,141'3,155'3,141'3,155'14'6 60 8/23/2014 Open RPERF P2 3,141'3,155'3,141'3,155'14'6 60 8/12/2014 Open RPERF P3 3,186'3,191'3,186'3,191'5'6 60 8/23/2014 Open RPERF P3 3,186'3,191'3,186'3,191'5'6 60 8/12/2014 Open RPERF P4 3,191'3,197'3,191'3,197'6'6 0 5/30/2013 Open APERF P4 3,191'3,197'3,191'3,197'6'6 60 6/3/2013 Open RPERF P5 3,205'3,212'3,205'3,212'7'6 0 5/30/2013 Open APERF P5 3,205'3,212'3,205'3,212'7'6 60 6/3/2013 Open RPERF P6 3,222'3,231'3,222'3,231'9'6 0 5/30/2013 Open APERF P6 3,222'3,231'3,222'3,231'9'6 60 6/3/2013 Open RPERF P7 3,286' 3,356' 3,286' 3,356'70'22 1 7/1/1992 Perf'd in '86 @ 12SPF, '87 @ 4 SPF, '92 @ 6 SPF P8 3,408' 3,422' 3,408' 3,422'14'22 1 7/1/1992 Perf'd in '86 @ 12SPF, '87 @ 4 SPF, '92 @ 6 SPF P9 3,448' 3,478' 3,448' 3,478'30'22 1 7/1/1992 Perf'd in '86 @ 12SPF, '87 @ 4 SPF, '92 @ 6 SPF P10 3,478' 3,502' 3,478' 3,502'24'16 1 7/1/1992 Perf'd in '86 @ 12SPF, '87 @ 4 SPF Fish ID.Depth MD (ft.)ID (in.)Description A Estimate TOF @ 3,249’(7/12/23)2.205 12.8' of 4.5" Max OD millout Extension & 2.875' Tailpipe left on bottom of 7" perforation section after Coil Tubing unit Underreamer tubing cut 8/11/2014 B 3,500 - Slickline toolstring Overshot w/ fishing neck & unknown length of wire attached, left on bottom 10/05/87 1.91" OD x 1.5' _____________________________________________________________________________________ Updated by DMA 07-14-23 PROPOSED Beluga River Unit Well: BRWD 1 Last Completed: 5/28/1986 PTD: 210-050 API: 50-283-20078-00-00 20” 9-5/8” 7” RKB to MSL = 88’ RKB to GL = 70’ TD = 3,560’ TVD = 3,560’ PBTD = 3,560’ ED = 3,500’ ETVD = 3,500’ Beluga Sands P1 P2 P3 P4 P5 P6 P7 P8 P9 P10 2 3 4 5 A B Max Angle = 1.8 deg @ 0’ Tubing Min ID = 2.323” TOC @ 2,104’ TOC to Surface 1 Suspected casing collapse @ 3,283’ TUBING DETAILS 2-7/8"Production String 6.5#N-80 EUE-8RD 2.441''3,134.2' CASING DETAIL Size Type WT Grade Conn ID Btm 20''Conductor 94#H-40 Weld 19.124''96' 9-5/8"Surface 43.5#AC-95 BTC 8.835''904' 9-5/8"Surface 40#N-80 BTC 8.835''1,729' 9-5/8"Surface 47 RS-95 BTC 8.835''2,000' 7''Production 29#P-110 BTC 6.059''3,554' JEWELRY DETAIL Production String ID.Depth MD (ft.)ID (in.)Description 1 15.9 2.323 WKM U-EN Tubing Hanger 2 3,120 2.375 Hughs CL Locator w/ 4 Seal Units 3 3,125 3.25 7" I-B Hughs Packer 4 3,131 3.92 Millout Extension Cut and Dropped at 3134' 5 3,134 -Coil Tubing Underreamer Cut of Millout. EOT=3134 PERFORATION DETAIL Zones Top (MD)Btm (MD)Top (TVD)Btm (TVD)Amt SPF Phase Date Status P1 3,133'3,141'3,133'3,141'8'6 60 8/23/2014 Open RPERF P1 3,133'3,141'3,133'3,141'8'6 60 8/12/2014 Open RPERF P2 3,141'3,155'3,141'3,155'14'6 60 8/23/2014 Open RPERF P2 3,141'3,155'3,141'3,155'14'6 60 8/12/2014 Open RPERF P3 3,186'3,191'3,186'3,191'5'6 60 8/23/2014 Open RPERF P3 3,186'3,191'3,186'3,191'5'6 60 8/12/2014 Open RPERF P4 3,191'3,197'3,191'3,197'6'6 0 5/30/2013 Open APERF P4 3,191'3,197'3,191'3,197'6'6 60 6/3/2013 Open RPERF P5 3,205'3,212'3,205'3,212'7'6 0 5/30/2013 Open APERF P5 3,205'3,212'3,205'3,212'7'6 60 6/3/2013 Open RPERF P6 3,222'3,231'3,222'3,231'9'6 0 5/30/2013 Open APERF P6 3,222'3,231'3,222'3,231'9'6 60 6/3/2013 Open RPERF P7 3,286' 3,356' 3,286' 3,356'70'22 1 7/1/1992 Perf'd in '86 @ 12SPF, '87 @ 4 SPF, '92 @ 6 SPF P8 3,408' 3,422' 3,408' 3,422'14'22 1 7/1/1992 Perf'd in '86 @ 12SPF, '87 @ 4 SPF, '92 @ 6 SPF P9 3,448' 3,478' 3,448' 3,478'30'22 1 7/1/1992 Perf'd in '86 @ 12SPF, '87 @ 4 SPF, '92 @ 6 SPF P10 3,478' 3,502' 3,478' 3,502'24'16 1 7/1/1992 Perf'd in '86 @ 12SPF, '87 @ 4 SPF Fish ID.Depth MD (ft.)ID (in.)Description A Estimate TOF @ 3,249’(7/12/23)2.205 12.8' of 4.5" Max OD millout Extension & 2.875' Tailpipe left on bottom of 7" perforation section after Coil Tubing unit Underreamer tubing cut 8/11/2014 B 3,500 - Slickline toolstring Overshot w/ fishing neck & unknown length of wire attached, left on bottom 10/05/87 1.91" OD x 1.5' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, November 3, 2021 To: Jim Regg P.I. Supervisor �� (� �� I�1 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC BRWD-I FROM: Adam Earl BELUGA RIV UNIT BRWD-1 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry` NON -CONFIDENTIAL Comm Well Name BELUGA RIV UNIT BRWD-1 Insp Num: mitAGE211028124902 Rel Insp Num: API Well Number 50-283-20078-00-00 Inspector Name: Adam Earl Permit Number: 186-009-0 Inspection Date: 10/15/2021 ✓ Packer Depth Well BRWD-1 Type Inj N VD 1 3125 Tubing PTD 1860090 Type Test sl`T' (Test psi 1 1500 . I IA — BBL Pumped. 0.8 BBL Returned: 0.8 OA Interval 4YRTST Notes' Well was not injecting during test and tubing psi steadily dropping,/ Pretest Initial 15 Min 30 Min 45 Min 60 Min 806 801 737 699 3191699 - 1697 1695 0 0 0 0 Wednesday, November 3, 2021 Page I of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg DATE: Thursday,November 02,2017 P.I.Supervisor 'iT46 1117/i SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC BRWD-1 FROM: Lou Laubenstein BELUGA RIV UNIT BRWD-1 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry �&IZ— NON-CONFIDENTIAL Comm Well Name BELUGA RIV UNIT BRWD-1 API Well Number 50-283-20078-00-00 Inspector Name: Lou Laubenstein Permit Number: 186-009-0 Inspection Date: 10/22/2017 - Insp Num: mitLOL171024070416 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well BRWD-1 Type Inj N TVD 3125 Tubing 3 ;— 33 , 10 3 1 PTD 1860090 Type Test SPT Test psi 1500 IA 235 1795 , 1795 1795 ----------- ------ --- BBL Pumped: 0.5 - BBL Returned: 0.5 - OA o . 0 • 0 - 0 Interval 4YRTST - ;P /F P v Notes: Good test Thursday,November 02,2017 Page 1 of 1 STATE OF ALASKA ALA.OIL AND GAS CONSERVATION COMOSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Plug Perforations r Perforate r Other r Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdow n r Stimulata�Other. P- Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 186-009 • 3.Address: 6.API Number: Stratigraphic r Service !✓ P. O. Box 100360,Anchorage,Alaska 99510 50-283-20078-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 58831 • BRWD-1 - 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Beluga River Unit Undefined WDSP • 11.Present Well Condition Summary: Total Depth measured 3560 feet Plugs(measured) none true vertical 3560 feet Junk(measured) 3286 Effective Depth measured 3500 feet Packer(measured) 3125 true vertical 3500 feet (true vertical) 3125 Casing Length Size MD TVD Burst Collapse Conductor 76' 20" 98' 98' Surface 1980' 9.625" 2000' 2000' Intermediate 3536' 7" 3554' 3554' Imp NOV : 2D,, OG 'Q.T2 1t3 Perforation depth: Measured depth: 2191'-3502' , .. True Vertical Depth: 2191'-3502' .^j Tubing(size,grade,MD,and TVD) 2.875", N-80,3147' MD, 3147'TVD Packers&SSSV(type,MD,and TVD) PACKER-7"I-B Hughs Packer @ 3125 MD and 3125 ND no SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 22 bbls 7.5% hydrochloric acid 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation not applicable Subsequent to operation not applicable 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL fit! Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 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: 313-462 Contact Mike Hazen 265-1032 Email Michael.C.Hazen aconocophillips.com Printed Name _Mike Hazen Title Staff Wells Engineer Signature S�, Phone:265-1032 Date 30 S6 P l3 RBDMS OCT 11 21 X /(5./(03 Form 10-404 Revised 10/2012 , t 46'0 Submit Original Only BRWD-1 Well Work Summary DATE SUMMARY S • PUMPED 10-BBL PRODUCED WATER LEAD, THEN 22-BBL 7.5% HYDROCHLORIC ACID, , 9/16/2013 FOLLOWED BY APPROXIMATELY 75-BBL PRODUCED WATER FLUSH. a i SAK BRWD-1 Conocorhi lips ; Well Attributes Max Angle&MD TD Wel!bore API/UWI Field Name Well Status Intl(°) MD(RKB) Act Btm(RKB) Alaska,MC. 502832007800 BELUGA RIVER UNIT DISP 3,560.0 Comment H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:NONE LAST WO: 22.00 5/26/1986 Well Canfq.-BRematic-Actual Annotation PM Schematic-Actual Annotation Depth OMB) End Date Annotation Last Mod...End Date Last Tag:SLM 3,283.0 12/7/2012 Rev Reason:ADD PERFS osborl 6/4/2013 Casing Strings Casing Description String 0... String ID...Top(SOB) Set Depth(f...Set Depth(TVD).. String Wt,..String... String Top Thrd .�� .:._, CONDUCTOR 20 19.124 22.0 96.0 94.00 H-40 WELDED HANGER,16 Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd - SURFACE 9 5/8 8.835 22.0 2,000.0 40.00 N-80 BTC Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.059 22.0 3,554.0 29.00 P-110 BTC )' Tubing Strings Tub ng Desc ption String 0... String ID...Top(5KB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR. TUBING 27/8 2.441 15.9 3,147.0 6.50 N80 EUE-BRD 22-96 I Completion Details Top Depth Noml... (ND) Top not Top(RKB) (RKB) (°) Item Description Comment ID(in) 15.9 HANGER WKM U-EN TUBING HANGER 2.323 SURFACE. 3,120.1 SEALS HUGHS CL LOCATOR w/4 SEAL UNITS 2.375 22'2.000 3,124.9 PACKER 7"1-B HUGHS PACKER 3.250 3,130.9 MILL OUT MILLOUT EXTENSION 3.920 3,137.0 NIPPLE XN NIPPLE 2205 APERF. 2.191-2.197 - = Other In Hole ireline retrievable plugs,valves,pumps,fish,etc.) Top Depth ?-: (ND) Top Intl I Top(RKB) (RKB) l°) Description Comment Run Date ID(in) 3,500.0 FISH Fishing Neck Slickline overshot with fishing neck,left on 10/5/1987 0.000 bottom 10/05/87. SEALS,3,120 i• we Perforations&Slots Shot PACKER,3,125 Top(ND) Btm(TVD) Dens IMF. Top(RKB)Btm(RKB) (RKB) (ftKB) Zone Date (eh- Type Comment 2,191.0 2,197.0 5/30/2013 6.0 APERF 2.125"Shogun,60 degree phase, 14.2 gram,.26"hole,33.4" penetration 3,191.0 3,197.0 6/3/2013 6.0 RPERF 2.125"Hero,60 degree phasing,6.5 3,,131 131 MILL gram,.24"hole,19.4"penetraction 3,205.0 3,212.0 6/3/2013 6.0 RPERF 2.125"Hero,60 degree phasing,6.5 gram,.24"hole,19.4"penetraction 3,205.0 3,212.0 5/30/2013 6.0 APERF 2.125"Shogun,60 degree phase, NIPPLE.3,137 II 14.2 gram,.26"hole,33.4" 3,222.0 3,231.0 5/30/2013 6.0 APERF 2.125"Shogun,60 degree phase, 142 gram,26"hole,33.4" penetration 3,222.0 3,231.0 6/3/2013 6.0 RPERF 2.125"Hero,60 degree phasing,6.5 gram,.24"hole,19.4"penetraction 3,286.0 3,356.0 7/1/1992 22.0 RPERF RPERF, 3,408.0 3,422.0 7/1/1992 22.0 RPERF 3,191-3,197 - 3,448.0 3,478.0 7/1/1992 22.0 RPERF 3,478.0 3,502.0 7/1/1992 22.01 RPERF RPERF, Notes:General&Safety 3,2053212 _ End Date Annotation APERF' 3,205 • • ) I%%i sv THE STATE Alaska Oil and Gas Of AL ASKA I - Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF Q. Anchorage, Alaska 99501-3572 ALAS" Main: 907.279.1433 Fax: 907.276.7542 Mike Hazen ��EQ wi 1 Staff Wells Engineer SC A444# Alaska, Inc. l Q�6 Off` P.O. Box 100360 v Anchorage, AK 99510 Re: Beluga River Field, Undefined WDSP Pool, BRU BRWD-1 Sundry Number: 313-462 Dear Mr. Hazen: 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, Cathy P Foerster Chair Ai DATED this 2 day of September, 2013. Encl. • #4,1/bi,i. RECEIVED STATE OF ALASKA AUG 2 3 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program ❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ A,cCStimulate L(' Alter Casing❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: CCN Oc_o'P4-II 4-4,iPS A-LA-s A— 1 N c , Exploratory ❑ Development ❑ 1 Se ` ot,ct • 3.Address: ' 6.API Number: Stratigraphic ❑ Service � 'Po, eoK fob 361 ,AnK-ogt,,4tC 97,5-10 50- ZS 3 - Zoo -S -De, 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? L1)44 1J UNIT- Bi2m,.0-- 1' Will planned perforations require a spacing exception? Yes ❑ No❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 5883 o ° gel")44 RAVER- ()MT - VNat-p+.+)3 w •sp • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 3560 • -560 • 3500 3506 328E'FIL..L Casing Length Size MD TVD Burst Collapse Structural Conductor 16 ' zro " 918' /a Surface IIbo' c1.6z „ .�t� ' woo o Intermediate 3r 3‘' .4 .. 35-5-47'' 3.—.5--9 Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 2f7t — 350'2- 219/ -- 3502. 2€45 " /sJ by 3i4-4` Packers and SSSV Type: tai awg- Packers and SSSV MD(ft)and TVD(ft): 1B H-tkikiES P„44,4e-2 rip 3i-2—Y' .'' o vc 31Z•i` 12.Attachments: Description Summary of Proposal RI 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service g 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Of SEP I3 Oil ❑ Gas ❑ WDSPL g, Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact M t 1tLE el,/ Email h q 2e--✓1•v c L cc/loco/4;114s.(0,11 Printed Name Mir E 14A7zeAi 7.45--103z_ Title S-014=-F- tAkz■.-S 41'vs-E-rt. Signature Phone Date 22 4tJ4 i 3 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 ei Plug Integrity❑ BOP Test❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS OCT 1 0 213 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /b—Li 0K APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 6-/'3 -(3 7. 30•!3 Submit Form and ON Form 10-403(Revised 10/2012) ApproyK a icitiD�isNalidfor�2 tit the from the date of approval. Attachments in Duplicate \13)._i U K /V• I N A L � � 4)17 ' • • Subject: BRWD-1; Acid Treatment , Overview: Injection pressures are higher than desired despite having cleaned out the well, and re- perfed/add-perfed zones. An obstruction in the tubing prevents deeper cleaning or uncovering of more existing perforations. This proposed acid treatment of the available ✓ perforations, as well as the recently re/add-perforated zones, should increase allowable injection rates at current pressure. Obiectives: Our work is never so urgent or important that we cannot take the time to do it safely and in an environmentally prudent manner. • No HSE incidents. • Perform 7.5% HCI acid stimulation in existing zones to restore some injection. • Under separate procedure, re-perforate target zones if acid treatment does not yield desired injection rates. Well Status: Minimum ID: 2.205" XN profile at 3137' MD. Fish: (-3500' MD) slickline toolstring on bottom w/unknown length of wire attached. Well has no SSSV profile Tubing last pumped full with produced water; annulus contains diesel. Well is regulated by Disposal Injection Order# 3, #3.001, #3.002 &#3.003 Well History: Attainable injection rates at desired pressures declined in this injection/disposaLwelLand it now appears that obstruction or possible collapse tubing hinder access to the well beyond 3290' MD. Master valves were changed out (2007) to 3000-psi valves. Slickline lost a 1- 3/4" tool string (2010) with attached wire of unknown length on top (3500'). Coiled tubing cleaned out the well in 2010 to 3482' and injected 2.5-bpm @ 1350 psi. Coiled tubing again cleaned out the well in 2011 to 3500' (no injection testing). Slickline tagged bottom at 3459', March 2012, and was able to inject only 0.5-bpm @ 1700-psi. Coiled tubing again cleaned out the well October 2012 to a hard tag @ 3493' and was able to inject 1.5-bpm at 1770-psi. Subsequent slickline and CT tags all occur vicinity 3290' MD with no success penetrating deeper despite washing, milling, chisel, etc. Electric line video logging was attempted to the blockage in May 2013 but clear pictures were not attained, while a slickline LIB run the same month yielded possible indications of collapsed tubing. E-line (re/add)-perforated the well above the problem area in various intervals between 3191' and 3231', and injectivity testing was again conducted. Injection improved but latest testing still shows 2.25-bpm at 1986-psi. A proposed acid treatment should improve injection at the existing perfed zones; contingent perforating procedures will follow if desired results are not obtained. • • • Procedure 1. Mobilize pump equipment, product, and personnel to Beluga. Hold a SIMOPS meeting with the production personnel and obtain work permits as necessary. 2. Mobilize to the BRWD-1 location, north of the field. Inspect wellhead and pad to identify hazards or hindrances to the job; remedy as required prior to rig up. Post the approved SIMOPS Card in the operations cab. 3. Conduct Pre-Job Safety Meeting to discuss HCI acid handling, product MSDS, proper PPE, spill precautions, eye wash stations, emergency shower, wind direction, muster points, etc. Fill out JSA as per normal injection operations. a. Acid: 7.5% HCI plus additives (0.2% NE-118 non-emulsifier; 0.3% CI-27 corrosion inhibitor; 0.2% Ferrotrol iron reducer; 0.1% Clay Master-5C clay inhibitor). 4. Spot and rig up the down-hole pump and support equipment. Pump to be placed in containment, with additional secondary containment placed at all hose and flowback iron connections. Rig up treating iron to BRWD-1 wellhead via tree cap or wing using approved 1502 2" flange adapter. Rig up HCI totes and produced water for displacement. 5. Pressure test surface lines as per SOP to 200-psi low, and 2400-psi high; bleed test pressure down to SITP and line up the equipment to pump down hole. 6. Rig up auxiliary pump (Baker or LRS)with diesel source, and line up a '/2" hose to (�,IA the inner annulus. Pressure up on the inner annulus to 1000-psi, monitor& maintain that pressure throughout the acid treatment process. 7. Come on line pumping produced water spacer at minimum rate. With well liquid packed, establish intended treating rate and pressure of approximately 2-bpm and 1900-psi. With rate and pressure leveled out, pump schedule below summarized as 22-bbl 7.5% HCI, followed by 75-bbl produced water flush. Do not exceed maximum allowable surface rate of 3-bpm or pressure of 2400-psi, whichever comes first. Please capture/document all rates and pressures throughout job. . Pump Schedule: i. 20-bbl produced water pre-flush targeting 2-bpm, if possible below 2400-psi, but any rate over 1-bpm is acceptable. ii. 2bbl 7.5% HCI down tubing to open perfs iii. 75-bbl produced water displacement/flush iv. Shut down. 8. Fill out all necessary paperwork to document the injection with the State of Alaska. 9. Bleed inner-annulus pressure to pre-injection pressure, isolate same and normal up the tree. 10. Rig down the pump equipment and return the location to pre-work status. Walk through location with the production operators and ensure they are happy with the way we are returning their well to them. SAK BRWD-1 -ConocoPhillips a. ttributes • Max Angle&MD TD Aleska,Inc. Wel!bore API/UWI Field Name Well Status Incl(1 MD(ftKB) Act Btm(ftKB) ConocoPhillips 502832007800 BELUGA RIVER UNIT DISP 3,560.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ••^ Well Confg: -BRWD-1,7125/20134:59:38 PM SSSV:NONE LAST WO: 22.00 5/26/1986 Schematic-Actual Annotation Depth(ftKB) 'End Date Annotation Last Mod By End Date Last Tag:SLM 3,283.0 12/7/2012 Rev Reason:ADD PERFS osborl 6/4/2013 Casing Strings Casing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(ND)... String Wt... String... String Top Thrd -_.. up■ CONDUCTOR 20 19.124 22.0 96.0 94.00 H-40 WELDED RANGER,16 „ Casing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(ND)... String Wt... String... String Top Thrd 1" SURFACE 9 5/8 8.835 22.0 2,000.0 40.00 N-80 BTC Casing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(ND)... String Wt... String... String Top Thrd PRODUCTION 7 6.059 22.0 3,554.0 , 29.00 P-110 BTC -" fi7 ''' Tubing Strings Tubing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(TVD)... String Wt... String... String Top Thrd TUBING 2 7/8 2.441 15.9 3,147.0 6.50 N-80 EUE-8RD CONDUCTOR, 22-96 Completion Details Top Depth (ND) Top Intl Nomi... Top(ftKB) (ftKB) (°) Item Description Comment ID(in) 15.9 HANGER WKM U-EN TUBING HANGER 2.323 SURFACE, 3,120.1 SEALS HUGHS CL LOCATOR w/4 SEAL UNITS 2.375 22-2,000 3,124.9 PACKER 7"I-B HUGHS PACKER 3.250 3,130.9 MILL OUT MILLOUT EXTENSION 3.920 3,137.0 NIPPLE XN NIPPLE 2.205 APERF, 2,191-2,197 Other In Hole Wireline retrievable plugs,valves, pumps,fish,etc.) Top Depth (ND) Top Inc! II Top(ftKB) (ftKB) (°) Description Comment Run Date ID(in) 3,500.0 FISH Fishing Neck Slickline overshot with fishing neck,left on 10/5/1987 0.000 bottom 10/05/87. SEALS,3,120 ,_ Perforations&Slots Shot PACKER,3,125 Top(ND) Btm(ND) Dens 1 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date (sh••• Type Comment 2,191.0 2,197.0 5/30/2013 6.0 APERF 2.125"Shogun, 0 degree phase,14.2 gram,.26"hole,33.4"penetration 3,191.0 3,197.0 6/3/2013 6.0 RPERF 2.125"Hero,60 degree phasing,6.5 la MILL OUT gram,.24"hole,19.4"penetraction 3,131 3,205.0 3,212.0 6/3/2013 6.0 RPERF 2.125"Hero,60 degree phasing,6.5 gram,.24"hole,19.4"penetraction 3,205.0 3,212.0 5/30/2013 6.0 APERF 2.125"Shogun, 0 degree phase,14.2 gram,.26"hole,33.4"penetration NIPPLE,3,137 11 3,222.0 3,231.0 5/30/2013 6.0 APERF 2.125"Shogun, 0 degree phase,14.2 gram,.26"hole,33.4"penetration I 3,222.0 3,231.0 6/3/2013 6.0 RPERF 2.125"Hero,60 degree phasing,6.5 gram,.24"hole,19.4"penetraction 3,286.0 3,356.0 7/1/1992 22.0 RPERF 3,408.0 3,422.0 7/1/1992 22.0 RPERF .s--_-_-. 3,448.0 3,478.0 7/1/1992 22.0 RPERF RPERF, 3,478.0 3,502.0 7/1/1992 22.0 RPERF 1 „ 3,,s,-3,,s7 Notes:General&Safety End Date Annotation 4/16/1986 NOTE:TUBING COMPONENTS ARE'WLM'MEASUREMENT NOT'RKB' RPERF, - 4/16/1986 NOTE:CASING TOPS ARE AN ESTIMATE AS NO DATA IS AVAILABLE 3,205-3,212 _ APERF, = 10/1/1989 NOTE:WELL HAD ACID TREATMENTS 1986,TWICE IN 1989 3,205-3,212 4/16/1997 NOTE:3470'RKB TTL Locator(25'correction) 10/1/1997 NOTE:WELL HAD BLEACH TREATMENTS 1993,1994&1997 RPERF, 1/28/2011 NOTE:View Schematic w/Alaska Schematic9.0 3,222-3,231 _ APERF, 3,222-3,231 = RPERF, 3,286-3,356 = RPERF, 3,408-3,422 = RPERF, 3,448-3,478 RPERF, 3,478-3,502 - FISH,3,500 --1^) = PRODUCTION, 22-3,554 TD,3,560 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, May 15, 2013 3:01 PM To: 'Herrmann, Daniel D' Subject: RE: BRWD -1 Perforation 10 -403 Sundry #313 -066 F / e E pTD 12 -Q O`I Dan, You can go ahead and perforate the approved zones as listed in sundry # 313 -066. Submit a final 10 -404 report with all wellwork to date including the attempted FCO and tagging operations. List both the sundries that are open on the 10- 404 to close them out. (313 -066 & 313 -195. ) operation cover letter with the 10 -404 should be included that captures t the overall p eration and outcome of the wellwork. 3191 -3197' 3205 -3212' 3222 -3231' Guy Schwartz Senior Petroleum Engineer SCANNED 4ViA, AOGCC 907- 444 -3433 cell 907 -793 -1226 office From: Herrmann, Daniel D [m ii m :jDAef n F:ccznoL:op?, !kps cool] Sent: Wednesday, May 15, 2013 7:46 AM To: Schwartz, Guy L (DOA) Subject: RE: BRWD -1 Perforation 10 -403 Sundry #313 -066 Guy, The Approved sundry number for the perforations we discussed earlier today is 313 -066. I have attached a copy of the sundry that was submitted, as I don't have the electronic copy of the approved sundry currently but I can get it if you would like to see it. I have also attached a wellbore diagram with a crude drawing of where our potential collapse is as well as where the new perforations will be. All of our recent tags with slickline and CT have all been right at the top of our perforations with some slight depth differences due to the CT and SL. Please let me know if you would like any other information. We will plan to perform the operations the end of this week or early next week Cheers, Pair 1i` &, mar t Beluga Production Engineer Office: 907 - 263 -4619 Cell: 713- 703 -5282 1 1 SAK w BRWD -1 ConocoPhillips 01 Well Attributes Max Angle & MD TD Alaska Inc. Welber. APINWI Field Name Well Status Incl (') (30 (BKB) Act Blm (N08) ca....iimp, 502832007800 BELUGA RIVER UNIT DISP 3,560.0 ' Comment (42S (pent) Date Annotation End Date KB-Grd (6) Rig Release Date ••• Wen Confer •BRwD -1, 1201/2012 721.56A1.1 SSSV: NONE LAST WO: 22.00 5/26/1986 -- Schematic - Actual Annotation Depth (NIB) End Date Annotation Last Mod ... End Date Last Tag:SLM 3283.0 12/7/2012 Rev Reason: TAG _ ninam 12/11/2012 Casing Strings Casing Description String 0... String ID ... Top (MB) Set Depth (L.. Set Depth (TVD) ... String Wt... Siring ... String Top Thrd -- - - - CONDUCTOR 20 19.124 22.0 96.0 94.00 1 WELDED Casing Description String 0... Strng ID ... Top (1IK8) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER. 16 ��— SURFACE 95/8 8.835 22.0 2,000.0 40.00 N BTC Casing Description String 0... String ID ... Top (InIB) Set Depth (f_. Set Depth (TVD) ... String WI... String ... String Top Thrd U PRODUCTION 7 6.059 22.0 3,554.0 29.00 P -110 BTC Tubing Strings Tubing Description String 0... String ID ... Top (1KB) Set Depth (L.. Set Depth (TVD)... String Wt... String... String Top Thrd TUBING 27/8 2.441 15.9 3,147.0 I 6.50 N-80 EUE -8RD 1 l I TV D Completion Details op Depth () Top brcl Komi... COSDVCTOR, T.1,Me) MK (1 Item Description Comment ID (In) 72.96 15.9 HANGER WKM U- EN TUBING HANGER 2.323 3120.1 SEALS I4UGHS CL LOCATOR w/ 4 SEAL UNITS 2.375 3,124.9 PACKER 7" I-B F UGHS PACKER 3.250 3,130.9 MILL OUT MILLOUT EXTENSION 3 3,137.0 NIPPLE XN NIPPLE 2.205 — SURFACE. Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) 22-2,000 - Top Depth (1V13) Top Mel Top (MB) IflN (1 Description Comment Run Date ID (In) 3,500 FISH Fishing Neck Slickline overshot with fishing neck, left on 105/1987 0.000 Z bottom 10/05/87. ill SEALS, 3,120 Perforations & Slots MN Shot Top (ND) Bhe (1VD) Dens T op ( SKB) Bbn ((KB) MKS) (hKB) Zone Date (:tins Type Comment PACKER. 3.125 _ 3286 3,356 7/1 /1992 22.0 RPERF 3.408 3,422 7/1/1992 22.0 RPERF 3,448 3,478 7/1/1992 22.0 RPERF 3,478 3,502 7/1/1992 22.0 RPERF r Notes: General & Safety End Date AmmotaBon MILL OUT. 4/16/1986 NOTE: TUBING COMPONENTS ARE lo/LM' MEASUREMENT NOT 1 3.131 4/16/1986 NOTE: CASING TOPS ARE AN ESTIMATE AS NO DATA IS AVAILABLE 10/1/1989 NOTE: WELL HAD ACID TREATMENTS 1986, TWICE IN 1989 4//6/1997 NOTE: 3470' RKB TTL Locator (25' correction) — 10/1/1997 NOTE: WELL HAD BLEACH TREATMENTS 1993 1994 8 1997 NIPPLE, 3.137 1/282011 NOTE: View Schematicwl Alaska Schernatic9.0 (- -- _ __; NeA.) (-pert 606 : 3rd - , 3 � 2 - 7 / 3LtY 7 �. - L RPERF. 27 3'2. "3 1 3.2863.356 7^ S IT RPERF. - ,OVV' / (� `' f C0 /( S c. 3.406.3,422 RPERF, . 3.4483.478 RPERF, 3.4783,502 l / FISH. 3.500 -1) PRODUCTION, 22 -3554 TD.3560 • • w w ��l %� s 9 THE STATE A a.s Oil Gas - == Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue 4Lnsv" Anchorage, Alaska 99501 -3572 Main: 907.279.1 433 Fax: 907.276.7542 Dan Hellmann SCANNED MAY 01 2013 Production Engineer � _ � o � ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Beluga River Field, Undefined WDSP Pool, BRWD -1 Sundry Number: 313 -195 Dear Mr. Herrmann: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this 3 day of April, 2013. Encl. • • RECEIVED . STATE OF ALASKA APR 2 4 Z01 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrilt ❑ Perforate New Pool ❑ Repar Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate is • Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: ✓ 4. Current Well Class: v 5. Permit to Drill Number. ✓ ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 186 -009 • 3. Address: Stratigraphic ❑ Service Q • 6. API Number r P.O. Box 100360, Anchorage, Alaska 99510 50- 283 - 20078 -00 • 7. If perforating: 8. Well Name and Number. , What Regulation or Conservation Order governs well spacing in this pool? Dt0 # 3 / EPA AK- 200001 -I Will planned perforations require a spacing exception? Yes ❑ No El BRWD -1 • 9. Property Designation (Lease Number): 10. Field /Pool(s): ✓ ADL 58831' Beluga River Unit - Undefined WDSP • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 3560 3560 3500 3500 3286' fill Casing Length Size MD TVD Burst Collapse Conductor 76' 20" 98' 98' Surface 1980' 9.625" 2000' 2000' Intermediate 3536' 7" 3554' 3554 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3286' - 3502' • 3286' - 3502 2.875" N -80 3147' Packers and SSSV Type: None Packers and SSSV MD (ft) and TVD (ft): y IB Hughes Packer • MD 3124' and TVD 3124' 12. Attachments: Description Summary of Proposal 15 , 13. Well Class after proposed work: -, Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic 0 Development ❑ Service IS 14. Estimated Date for 4/29/2013 15. Well Status after proposed work: V Commencing Operations: Oil ❑ Gas ❑ WDSPL is • Suspended ❑ 16. Verbal Approval: Date: q.--1.4 •13 WINJ 0 GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: S 1/1-(0 -- . GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is ti .je and correct to the best of my knowledge. Contact Dan Herrmann Email )d.herrmannacop.com Printed Name Dan Herrmann Title BRU Production Engineer Signature Phone 263 -4619 Date 4/23/2013 / by/ X //3 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: :1 n Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test © Location Clearance ❑ Other: Spacing Exception Required? Yes 0 No IJd Subsequent Form Required: /D-- 4/ 61 - 1 APPROVED BY 4 /.3 Approved by: COMMISSIONER THE COMMISSION SSISI ON Date: Q rV 4 /20 3 f;�r F L11 ` �z / (� t � Sa6mit Form and Form 10 -403 (Revised 10/2012) Appro i I v lid (1 months from the ate of approval. Attachmen in Duplicate \ RBDMS APR 3 0 2013 T ■ , . 9,67,..Q & �y • • Procedure Justification: Injection pressures are up on this well; D & T (drift and tag) confirms that the perforations are once again uncovered to bottom perf depth. Re- perforate existing injection zones to fix potential plugged perf tunnels in the existing perfs, & verify lower injection pressure by performing a routine injection as per DIO # 3. The Oblective: Safety First! Incident Free Operations • Safety is the first objective, do it safely or not at all • There is always time to do it right, we are not in a hurry • Zero uncontrolled environmental releases of any kind • Perforate additional zone below 3060' & lower injection pressure • RIP Job Concerns: Minimum ID: 2.205" Xn Profile Well has no SSSV profile Slick line tool string on bottom w /unknown length of wire attached @ +- 3500' Annulus is full of diesel Well is regulated by Disposal Injection Order # 3, #3.001, #3.002 & #3.003 Well History: The master valves were changed out in 2007 to 3000 psi valves. Lost 1 -3/4" slick line tool string and unknown length of wire in 2010. CT cleaned out the well in2010_to 3482' and injected 2.5BPM a 1350 psi., CT cleaned out the well in 2011 to 3500'. Slick line tagged bottom 03 -17 -2012 © 3459' and was able to inject only 0.5 BPM @ 1700 psi. Coil Tubing cleaned out the well on 10- (27 -29) -2012 to a hard tag @ 3493' and was able to inject @ 1.5 BPM @ 1770 psi Slick line: Confirm current perforations are uncovered by fill. Well is ready to perforate once an approved 10 - 403 sundry application is received from the State. Electric Line: 1. Mobilize a conventional Electric line unit with crew to the Beluga River Unit on the West Side of Cook Inlet. Hold a SIMOPS meeting with the production operators and obtain work permits as necessary. 2. Mobilize to the BRWD -1 location, north of the field. Inspect the wellhead and surrounding area to identify any pre existing conditions or hazards and remedy as required prior to rig up. Post the approved SIMOPS Card in the operations cab. • • 3. PUMU standard 1.688 inch 'safe' perforating Electric Line tool string, complete with GR/CCL. Test tool string for functionality and remedy any anomalies prior to MU of bottom hole assembly. Lubricate logging tools, stab on, PT as per SOP, open the swab valve, & RIH logging the existing production tubing and casing. Determine the number of shots that will be required and the placement of those shots while on this run in the hole. Make tie in logging runs as required to definitely identify all available perforations. POOH when complete. Secure the well as per SOP. Re- perforation depths if available post logging run: 3478' — 3500', 22', 3448' 3478', 30', 3408' — 3422', 3286' ✓ — 3356', MD RKB Tied into Gamma Ray log 4. PUMU 2 inch hollow carrier guns or strip guns sufficient to perforate existing zones believed to be potentially plugged as indicated by Daniel Herrmann above. Accomplish this in the shortest number of overall runs in the hole, ie, make the perforation runs as efficient as possible for overall number of shots fired. Test the lubricator as per SOP before each trip in the hole and bleed back same to nominal SITP prior to RIH. 5. Once all of the new perforations have been shot then RDMOL Electric Line Unit and crew. Turn the well over to down hole pump crew for injection. Production Operations: 1. Fill out JSA as per normal injection operations, mobilize a standard (non - hazardous oilfield waste fluid) field source water tank and rig up the down hole pump to the BRWD -1 Well head as per standard operations for disposal of fluids into this well. Pressure test surface lines as per SOP, bleed same to SITP and line up the pump to discharge down hole. Ensure a check valve is inline and as close to the wellhead as practical; utilize no less than 10M 1502 hardline and connections W' » 2. MIRU field tri -plex pump w/ diesel source and line up a /2 hose to the inner annulus. Pressure up on the inner annulus to 1000 psi, monitor & maintain that pressure through out the injection process. 3. Come on line at minimum rate and establish an initial injection rate and pressure. Once this rate and pressure have leveled out, begin to increase the rate and pressure (in 0.25 BPM rate increases) to a maximum allowable surface rate of 3.47 BPM and pressure of 2500 psi. De- crease the injection rate to the desired injection pressure and complete the necessary volume of injection prior to shut down. 4. Fill out all necessary paperwork to document the injection with the State of Alaska. 5. Bleed inner annulus pressure to pre - injection pressure, isolate same and normal up the tree. Secure the field tri -plex and return to its storage location. 6. Rig down the 2" hardline and return the location to pre -work status. Walk through location with the production operators and ensure they are happy with the way we are returning their well to them. 7. RTP. • • Scale ConocoPhillips BRWD-1 API# 50- 283 - 20078 -00 l a Water Disposal Annulus Fluid: 0 -200' diesel, >200' water w/ Tretolite KW 132 Single Max Hole Angle: 1.8° © 0' Spud Date 5/13/82 Sect. 13, T13N, R1OW, NE 1/4 Ground Level: 70.' • Last Completion 5/27/82 2,000 ASP: , Original RKB: 88.'. Schematic Rev. 5/11/00 3,116 CASING & TUBING Hole by TDT 3,120 Description OD Btm. Weight Grade Thread Size Cement 3,124 b,c /14 Conductor 20 96' 94. # H -40 Driven 3,128 d Surface 9 5/8" 904' 43.5 # AL -95 BTC 12 1/4" Lead 600sx "G" w/ 6% gel 3,132 e Surface 9 5/8" 1,729' 40. # N -80 BTC 12 1/4" Tail 200sx "G ". 210sx rtns. 3,136 f,g } {I Surface 9 5/8" 2,000' 47. # RS -95 BTC 12 1/4" 3,144 Prod Casing 7 3,554' 29. # P -110 BTC 8 1/2" 3,152 Tubing 2 7/8" 3,147' 6.5 # N -80 EUE -8RD 3,160 3,168 Lbl. Top TUBING JEWELRY& FISH Length ID OD 3,176 a 15.9 WKM U -EN Tubing Hanger 0.75 2.323" 3,185 b 3,124' Hughs CL locator w/4 seal units 4.80' 2.375" 3.25" 3,193 Locator's full length runs thru pkr. 3,201 c 3,124' Pkr 7" I -B Hughs Packer 5.30' 3.25" 5.75" 3,209 d 3,129' 4 x 4.5" crossover 0.78' 3.92" 5.00" 3,217 e 3,130' Millout extension 5.30' 3.92" 4.50" 3,225 f 3,136' 4.5" x 2 7/8" crossover 0.75' 2.441" 5.00" 3,233 g 3,137' "XN" 2 7/8" Nipple 1.02' 2.205" 3.00" 3,241 Note: Jewelry depths based on DIL, CET, and perf logs WLM not on RKB. 3,249 h 3,500' FISH WL Overshot with fishing neck 1.50' 1.91" 3,257 3,266 PERFORATIONS, FILL & PLUGS Net Incline 3,274 Zone To Btm. Status Date SPF Ft. Angle 3,282 Pre-A 3,286' 3,356' Perf'd in '86 @12 SPF, '87 @4 SPF, '92 ©6 SPF 07/88 22 70' 1° 3,290 Pre -A 3,408' 3,422' Perf'd in '86 ©12 SPF, '87 ©4 SPF, '92 @6 5 07/88 22 14' 1° 3,298 Pre -A 3,448' 3,478' Perf'd in '86 @12 SPF, '87 ©4 SPF, '92 ©6 5. 07/88 22 30' 1° 3,306 Pre -A 3,478' 3,502' Perf'd in '86 @12 SPF, '87 ©4 SPF 10/83 16 24' 1° 3,314 PBTD 3,525' 05/94 3,322 FC 3,552' Float Collar 05/94 3,330 TAGS 4/15/93 3470' RKB TT locator (25' correction) 1 10/3/91 3478' RKB 2" bailer 3,338 3,347 Proposed Peforations with 6 SPF thru- tubing guns 3,355 3478' - 3500' 22' total 3,363 3448' - 3478' 30' total 3,371 3408' - 3422' 14' total 3,379 3286' - 3356' 70' total 3,387 3,395 3,403 3,411 I 3,419 3,428 3,436 3,444 08/82 Acid job 3,452 09/82 Pretty Creek Unit #1 injects drilling mud w/o approval from BRU WIO's 3,460 09/82 Acid job 3,468 09/83 Reperforate with 2 -1/8" & 1- 11/16" strip guns. Lost overshot at 3500' WLM 3,476 05/85 Acid job 3,484 >. 10/85 Acid job 3,492 h T c, c r re 07/88 Repecrforate with 2 -1/8" strip guns 3,500 o 0 8/ 89 I nject wor kover fluids and treat with lithium hypochlorite s-k 3,509 -. 08/90 Bleach treatment, 3.3 ppb lithium hypochlorite in fresh water. 3,517 PBTD 3525 cn 04/93 Run scratcher to remove build -up. BHP =1432 psia © 3400' WLM (3283' SS) 3,525 FC ► F ., 04/93 Kinley caliper shows tubing in good condition w/ no pitting nor wall Toss. TD 3560' I. = 10/93 Bleach treatment, 30 bbls 1% lithium hypochlorite w/ 45 gals of sodium hypochlorite. • i Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent Friday, April 26, 2013 12:42 PM To: 'Herrmann, Daniel D' Cc: Wallace, Chris D (DOA); Bettis, Patricia K (DOA) Subject: RE: BRWD -1 Re- perforation 10 -403 Sundry (PTD 186 -009) Dan, You have verbal approval to re -perf the proposed intervals in Sundry ( #313 -195). You may want to retract existing sundry #313 -066 ( also to re -perf) since you won't be doing that well work. You can send a separate email requesting that .... Guy Schwartz Senior Petroleum Engineer AOGCC 907 - 444 -3433 cell 907 - 793 -1226 office From: Herrmann, Daniel D [ mailto_JD.Herrmannconocophii ps.com] Sent: Thursday, April 25, 2013 5:34 PM To: Schwartz, Guy L (DOA) Cc: Wallace, Chris D (DOA) Subject: RE: BRWD -1 Re- perforation 10 -403 Sundry (PTD 186 -009) Guy Sorry ancut. procedure 1 am not sure why it was cut off attache_) an easier to read version to the email. T :Ansccer s o!!' questions Can you also elaborate on the max rate and pressure limits set on the injection test you propose? Where did you get these values? Ile maximum rate is based ell the maximum rate allowed 111 the D!` ;po,al In ge; tion Order. and the llla\i nulil pressure I5 : :,!.`,111113lll \`.+ \}'hill'; l)ressii!l' Ut our \\� \' \'l't.h n01. e \pccI t1+:!1' above 111110 131'D which is our iiiiection What is going on with the perforation sundry 313 - 066... that was just approved? N:\'(; \\er� 1 +i,;m!ill,, to pcl !Orin that pertortitilio \\ rh !.\ er the ■\ inter to Ilorehili\ alim\ injection in the welt in case our injection '+ i l_3Rt_, _'? 2 -h \■ellt down. \'A e had ",+)lire logistical issues in (2,i;tt!I1 perforating equipment to i_ieluga that oci;l \ed the ■1tii'h. If we had performed ed the periOratim4 there e.a a risk drat It could complicate our I ill Clean Out on d . k+ i;l so ■\e decided to h._}Id of loll nert'orI1ui e the periOrating o1 the !oiler above otir eurrent perlbratio! s until allCt' !lit` clt;i'n -olu ai d re- peiloratiluJ, iii the c\IHti112 /oyes t scc ittllls work, would Inks care ()lour injection needs, The 3-01)6 wort. \\o .ill have been performed it \ \c had n o Issue \11!11 our primary injector: since we didn't have any 1 1 hull oft o i p+_Oe 1iiuliV C{I T1 111C11till'! +cur clean-out- Plc Ir„ lei we i�.i�� ? \�. i! 1 s' an ; i!N\ \er;l,l1 \' more dire `?1io111., !/a4 //eP `Ara4'K Beluga Production Engineer 1 , Office: 907-263-4619 • • Cell: 713- 703 -5282 From: Schwartz, Guy L (DOA) [ mailtoguy .schwartalaska.gov] Sent: Thursday, April 25, 2013 4:52 PM To: Herrmann, Daniel D Cc: Wallace, Chris D (DOA) Subject: [EXTERNAL]RE: BRWD -1 Re- perforation 10 -403 Sundry (PTD 186 -009) Dan... What is going on with the perforation sundry 313- 066... that was just approved? Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907- 793 -1226 office From: Schwartz, Guy L (DOA) Sent: Thursday, April 25, 2013 4:45 PM To: ' JD.Herrmann @conocophillips.com' Cc: Wallace, Chris D (DOA) Subject: RE: BRWD -1 Re- perforation 10-403 Sundry (PTD 186 -009) Dan, Can you also elaborate on the max rate and pressure limits set on the injection test you propose? Where did you get these values? Guv Schwartz Senior Petroleum Engineer AOGCC 907 - 444 -3433 cell 907- 793 -1226 office From: Schwartz, Guy L (DOA) Sent: Thursday, April 25, 2013 4:40 PM To: ' JD.Herrmann @conocophillips.com' Subject: RE: BRWD -1 Re- perforation 10-403 Sundry (PTD 186 -009) Dan, Can you re -send the procedure . The printer skipped several key lines in it. Email is ok. Guy Schwartz Senior Petroleum Engineer AOGCC 907 -444- 34.33 cell 907 -793 -1226 office From: Guy Schwartz [rnaii Sent: Thursday, April 25, 2013 4:25 PM To: Schwartz, Guy L (DOA) Subject: RE: BRWD -1 Re- perforation 10-403 Sundry 2 • • From: JD. f iLl1niania conocophi I lips.con) To: Li- i NotmaiLcom Date: Thu, 25 Apr 2013 13:40:49 -0800 Subject: BRWD-1 Re-perforation 10-403 Sundry Guy, I submitted the attached sundry below to the AOGCC yesterday. With the barge limitations we have for Beluga we would like to perform our re-perforations across our current sand intervals on e-line starting next Monday (4/29). Is there a possibility we could get a verbal approval for performing this work by the end of the week so that we can make sure we have everything lined up in time for performing the work? I appreciate the help on short notice, Dan Herrmann Beluga Production Engineer Office: 907-263-4619 Cell: 713-703-5282 3 / - -6 (D? Davies, Stephen F (DOA) From: Lemke, Sandra D [ Sandra. D. Lemke @conocophillips.com] Sent: Monday, April 01, 2013 4:02 PM To: Davies, Stephen F (DOA) Subject: RE: BRU surface location error to report to AOGCC Attachments: BRU BRWD -1_as built_1986_error.pdf Steve, think an 'informal' correspondence is adequate for this situation. As mentioned, while performing a geospatial QC we identified that the surface location of the BRWD -1 well (186 -009), API 502832007800, plotted in the wrong location. I pulled the as -built for the well from AOGCC's scanned web link files. The as -built supplied to AOGCC by Chevron (attached), has correctly calculated x,y coordinates to place it in the correct location in the BRU field. The legal description, however, when converted to ASP4 NAD 27 x,y's, posts the well quite a distance from the correct location. The legal description is incorrect. It appears all correspondence to AOGCC just copied previous paperwork with the erroneous legal description coordinates. Using ground based observation and aerial photography, we believe the x,y location on the as built is correct. The legal description should be changed to conform with the x,y and the corrected legal description is T13N R1OW Sect 13 FNL 1664.27 FEL 176.09 Seward Meridian. AOGCC should calculate and revise their databases with the new surface location coordinates for the 'revised' surface location or the X,Y coordinates on the as- built. Our internal 'gold' database has been revised. If you have any questions please contact me. Regards, SCANNED JUN 0 7 2013 C 4 , ( ) Cijk Sandra D. Lemke � � Alaska IT Staff Associate -Data // ` � / / 7 7, ) ConocoPhillips Alaska !(J (c 700 G Street, ATO 340 zz Anchorage, AK 99501 c:.`_. / ".� T � / 3 ( l ` /( LJ S ` /1-1: (907) 263 -6947 phone, (907) 440 -4512 (cell) / ) Sandra. D. Lemke @conocophi flips. com M b 2-7 (/' = Z6, c 1 /ci. S / L / . /. /5 From: Davies, Stephen F (DOA) [ mailto :steve.davies(aalaska.gov] Sent: Monday, April 01, 2013 3:30 PM To: Lemke, Sandra D Cc: McIver, Bren (DOA) Subject: [EXTERNAL]RE: BRU surface location error to report to AOGCC Sandra, If the correspondence is a formal letter to the AOGCC, please address it to Cathy Foerster, Chair. If the correspondence is an informal email, send it to me and I'II make sure that the change is made to AOGCC's well history file and databases. Regards, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 1 • • Phone: 907- 7934224 Fax: 907 - 276 -7542 From: Lemke, Sandra D [mailto: Sandra. D.Lemke@conocophillips.com] Sent: Monday, April 01, 2013 11:33 AM To: AOGCC Cust Svc (DOA sponsored) Subject: BRU surface location error to report to AOGCC Through geospatial QC of CPAI wells in the Beluga River Unit field, we have a surface location revision to report to AOGCC. Which person at the Commission should receive this correspondence? Sandra D. Lemke Alaska IT Staff Associate -Data ConocoPhittips Alaska 700 G Street, ATO 340 Anchorage, AK 99501 (907) 263 -6947 phone, (907) 440 -4512 (cell) Sandra. D. Lemke @conocophi!lips. com 2 9 • / --( - - :C7 I ( ( . • k -0 1 WELL SIIRVEY Pro-312 . WELL 110. E. A WO - / COUNTY OF /:/'ii CITY OF r / SECTION NO. /$ TOWNSN I P /3./4 RANGE /C W" CEG S. B.$. 1 M. 0.4. D. B. 1 M. TRACT NO. LOT NO. F I ELD Re-lye) ,A'ivq r 0 PROPOSED /9&C.reet sdoiiterki q-1-Eysiii.1 • P , -r:.., 1.• .. .• or. 0 PRELIMINARY LOCATION Of Pi j c.'../ •5i C1 If Lind 0.4.c.„ ti ic,c1/,_g. ri?A/ El FINAL J 1yh d5. "ion, ::.-,21.1. 4.0i,71.49ry. f 1 Iwo . r - - - e n 1 1 :TR/ RIQ) 5- .‘ ELEVATION: GROUND CONCRETE NAT DERRICK FLOOR ALTERNATE OR SURVEYED LOCATION LOCATION ' DESIGNATION ON.LOCATION COORDINATES MOVE REMARKS 11/ y. 2 c31 X 3.?524.14 c er d er p'r r )4. 1,7 4101 4,gli cosirry r _ . ......._L___ * , NORTH SKETCH OR REMARKS I . r....., .)e–ifroks Or Allocko :74 )4:- Pbne• Zvne if set c 1 ...._ /13 '‘i .. C. \„. t.... ,---........k.—. ..— ...-- .4._. — G2 :..ii.,.."1 ...„.. ...„.: i I ...!. ' SOUTH BENCH MARK IS: 7 ..cenlac_.2 ...(1 ...; ,..i.Loy Fiev z 4y, YY CCIAlkrr■ ilkLik)) STATION SEARING DISTANCE SINE COSINE NORTH SOUTN EAST WEST • _ .4_ . , . --... ...-- - '----- , ■ . . . C.C. DIY. ENGR. • FILE SURVEYOR Croil ,..). MAINT. FR1111. MAINT. SUPT. DATE ?I Apr, 1 X DATE. DATE PUINYtD IN u.s.a, PW..312 (25004CD.1.5d) - - . 17.111111.1.1111.11.1111111111 OF 6 ;0" I j/j s . THE STATE Alaska Oil and Gas OfALAS KA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF ¢. Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 �.f��HEM OR 0 6 2013 R. Tyler Senden` Staff Wells Engineer 0 ConocoPhillips Alaska, Inc. Q P.O. Box 100360 1 0 Anchorage, AK 99510 Re: Beluga River Field, Undefined Pool, BRWD -1 Sundry Number: 313 -066 Dear Mr. Senden: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, aiL Cathy P. oerster Chair DATED this 1 `t'' day of February, 2013. Encl. • • • RECEIVED STATE OF ALASKA FEB 0 8 20t3 ALASKA OIL AND GAS CONSERVATION COMMISSION 07S 2 / /'5t 3 APPLICATION FOR SUNDRY APPROVALS A 20 MC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate S - Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 186 -009 • 3. Address: 6. API Number: Stratigraphic ❑ Service El • P.O. Box 100360, Anchorage, Alaska 99510 50- 283 - 20078 -00- 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? DIO # 3 / EPA AK- 2D0001 -I Will planned perforations require a spacing exception? Yes ❑ No 12 BRVVD -1 • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 58831 • Beluga River Unit - Undefined WDSP - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): • 3560 3560 3500 3500 3286' fill Casing Length Size MD TVD Burst Collapse Conductor 76' 20" 98' 98' Surface 1980' 9.625" 2000' 2000' Intermediate 3536' 7" 3554' 3554 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3286' - 3502' • 3286' - 3502 2.875" N -80 3147' Packers and SSSV Type: None Packers and SSSV MD (ft) and TVD (ft): IB Hughes Packer i MD 3124' and TVD 3124' 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 12 • 14. Estimated Date for 2/17/2013 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL © Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 2L76 Contact R. Tyler Senden 2L76 - 1544 Email r. tvler .senden(cilconocophillips.com Printed Name R. Tyler Senden Title Staff Wells Engineer Signature \ N , Phone 265 -6932 l /� ate 2/7/2013 C USE ONLY Conditions of approval: No i% Commission so that a representative may witness Sundry Number: 3t3 . 0 (1)( i 61 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: I,, QQ / 4 ` - 14 0', e f J.' 6 b, 6;.,, moo. 1. L ra 5 RBDMS FEB 15 2013 Spacing Exception Required? Yes ❑ No Subsequent Form Required: ' O APPROVED BY Approved by: QA, COMMISSIONER THE COMMISSION Date: 2- �/ q.. /3 i‘ Z• (3°U ■•# 2,4- 7() O D�n A� Subm' and ��\A t- 0 1 �3 i 0 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate e • BRWD -1 • Additional Perforations DIO# 3 EPA AK- 2D0001 -I Procedure Justification: Injection pressures are up on this well; D & T (drift and tag) confirms that the perforations are once again covered up. Perforate additional zone below 3060', & verify lower injection pressure by performing a routine injection as per DIO # 3. The Objective: Safety First! Incident Free Operations • Safety is the first objective, do it safely or not at all • There is always time to do it right, we are not in a hurry • Zero uncontrolled environmental releases of any kind • Perforate additional zone below 3060' & lower injection pressure • RTP Job Concerns: Minimum ID: 2.205" Xn Profile Well has no SSSV profile • Slick line tool string on bottom w /unknown length of wire attached @ +- 3500' Annulus is full of diesel Well is regulated by Disposal Injection Order # 3, #3.001, #3.002 & #3.003 • Well History: unknown length of wire in 2010. CT cleaned out the well in 2010 to 3482' and injected 2.5BPM © 1350 psi. CT cleaned out the well in 2011 to 3500'. Slick line tagged bottom 03 -17 -2012 @ 3459' and was able to inject only 0.5 BPM @ 1700 psi. Coil Tubing cleaned out the well on 10- (27 -29) -2012 to a hard tag @ 3493' and was able to inject @ 1.5 BPM @ 1770 psi Slick line: Has already confirmed perforations are covered by fill. Well is ready to perforate once an approved 10 - 403 sundry application is received from the State. Electric Line: 1. Mobilize a conventional Electric line unit with crew to the Beluga River Unit on the West Side of Cook Inlet. Hold a SIMOPS meeting with the production operators and obtain work permits as necessary. 2. Mobilize to the BRWD -1 location, north of the field. Inspect the wellhead and surrounding area to identify any pre existing conditions or hazards and remedy as required prior to rig up. Post the approved SIMOPS Card in the operations cab. • • BRWD -1 Additional Perforations DIO# 3 string for functionality and remedy any anom�aaii gHo - iv IU of bottom hole assembly. Lubricate logging tools, stab on, PT as per SOP, open the swab valve, & RIH logging the existing production tubing and casing. Determine the number of shots that will be required and the placement of those shots while on this run in the hole. Make tie in logging runs as required to definitely identify all available perforations. POOH when complete. Secure the well as per SOP. Tied into Gamma Ray log indicated by Daniel Herrmann above. Accomplish this in the shortest number of overall runs in the hole, ie, make the perforation runs as efficient as possible for overall number of shots fired. Test the lubricator as per SOP before each trip in the hole and bleed back same to nominal SITP prior to RIH. 5. Once all of the new perforations have been shot then RDMOL Electric Line Unit and crew. Turn the well over to down hole pump crew for injection. Production Operations: field source water tank and rig up the down hole pump to the BRWD -1 Well head as per standard operations for disposal of fluids into this well. Pressure test surface lines as per SOP, bleed same to SITP and line up the pump to discharge down hole. Ensure a check valve is inline and as close to the wellhead as practical; utilize no Tess than 10M 1502 hardline and connections 2. MIRU field tri -plex pump w/ diesel source and line up a 'h" hose to the inner annulus. Pressure up on the inner annulus to 1000 psi, monitor & maintain that pressure through out the injection process. pressure have leveled out, begin to increase the rate and pressure (in 0.25 BPM rate increases) to a maximum allowable surface rate of 3.47 BPM and pressure of 2500 psi. De- crease the injection rate to the desired injection pressure and complete the necessary volume of injection prior to shut down. 4. Fill out all necessary paperwork to document the injection with the State of Alaska. 5. Bleed inner annulus pressure to pre- injection pressure, isolate same and normal up the tree. Secure the field tri -plex and return to its storage location. 6. Rig down the 2" hardline and return the location to pre -work status. Walk through location with the production operators and ensure they are happy with the way we are returning their well to them. 7. RTP. . ' ,- al Scale ConocoPhillips BRWD-1 API# 50- 283 - 20078 -00 l a ' Water Disposal Annulus Fluid: 0 -200' diesel, >200' water w/ Tretolite KW 132 S i ng l e Max Hole Angle: 1.8° © 0' Spud Date 5/13/82 Sect. 13, T13N, R1OW, NE 1/4 Ground Level: 70.' Last Completion 5/27/82 2,000 ASP: Original RKB: 88.' Schematic Rev. 5/11/00 3,116 CASING & TUBING Hole by TDT 3,120 Description OD Btm. Weight Grade Thread Size Cement 3,124 b,c Conductor 20 96' 94. # H -40 Driven 3,128 d Surface 9 5/8" 904' 43.5 # AL -95 BTC 12 1/4" Lead 600sx "G" w/ 6% gel 3,132 e Surface 9 5/8" 1,729' 40. # N -80 BTC 12 1/4" Tail 200sx "G ". 210sx rtns. 3,136 f,g Surface 9 5/8" 2,000' 47. # RS -95 BTC 12 1/4" 3,144 Prod Casing 7 3,554' 29. # P -110 BTC 8 1/2" 3,152 Tubing 2 7/8" 3,147' 6.5 # N -80 EUE -8RD 3,160 3,168 Lbl. Top TUBING JEWELRY& FISH Length ID OD 3,176 a 15.9 WKM U -EN Tubing Hanger 0.75 2.323" 3,185 b 3,124' Hughs CL locator w/4 seal units 4.80' 2.375" 3.25" 3,193 Locator's full length runs thru pkr. 3,201 c 3,124' Pkr 7" I -B Hughs Packer 5.30' 3.25" 5.75" 3,209 d 3,129' 4 x 4.5" crossover 0.78' 3.92" 5.00" 3,217 e 3,130' Millout extension 5.30' 3.92" 4.50" 3,225 f 3,136' 4.5" x 2 7/8" crossover 0.75' 2.441" 5.00" 3,233 g 3,137' "XN" 2 7/8" Nipple 1.02' 2.205" 3.00" 3,241 Note: Jewelry depths based on DIL, CET, and pert logs WLM not on RKB. 3,249 It : , 3,500' FISH WL Overshot with fishing neck 1.50' - ! : 1..1" 3,257 3,266 PERFORATIONS, FILL & PLUGS Net Incline 3,274 Zone Top Btm. Status Date SPF Ft. Angle 3,282 Pre -A 3,286' 3,356' Perf'd in '86 @12 SPF, '87 @4 SPF, '92 @6 SPF 07/88 22 70' 1° 3,290 Pre -A 3,408' 3,422' Perfd in '86 @12 SPF, '87 @4 SPF, '92 @6 E 07/88 22 14' 1° 3,298 Pre -A 3,448' 3,478' Perfd in '86 @12 SPF, '87 @4 SPF, '92 @6 5 07/88 22 30' 1° 3,306 Pre-A : ' ° 3,478' 3,502'. Perfdin'86" @12 SPE, '87 @4 SPF.. 10/83 '; 16 "24:. "; "- 1$;: 3,314 PBTD 3,525' 05/94 3,322 FC 3,552' Float Collar 05/94 3,330 TAGS 4/15/93 3470' RKB TT locator (25' correction) I 10/3/91 3478' RKB 2" bailer 3,338 3,347 - Proposed Peforations with 2" hollow carrier 6 SPF thru- tubing guns 3,355 • 3191' - 3197' 6' total 3,363 -3205' - 3212' 7 total 3,371 ' 3222' - 3231' 9' total 3,379 3,387 3,395 3,403 3,411 3,419 3,428 3,436 3,444 08/82 Acid job 3,452 09/82 Pretty Creek Unit #1 injects drilling mud w/o approval from BRU WIO's 3,460 09/82 Acid job 3,468 09/83 Reperforate with 2 -1/8" & 1- 11/16" strip guns. Lost overshot at 3500' WLM 3,476 05/85 Acid job 3,484 >. 10/85 Acid job 3,492 h '`-. k CC 07/88 Reperforate with 2 -1/8" strip guns 3,500 p 08/89 Inject workover fluids and treat with lithium hypochlorite 3,509 `c 1- 08/90 Bleach treatment, 3.3 ppb lithium hypochlorite in fresh water. 3,517 PBTD 3525 cn 04/93 Run scratcher to remove build -up. BHP =1432 psia @ 3400' WLM (3283' SS) 3,525 FC ►-- -� ,., 04/93 Kinley caliper shows tubing in good condition w/ no pitting nor wall loss. A TD 3560' h = 10/93 Bleach treatment, 30 bbls 1% lithium hypochlorite w/ 45 gals of sodium hypochlorite. • STATE OF ALASKA ALAIDOIL AND GAS CONSERVATION COMMION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Li Repair Well Lf Plug Perforations Li Perforate Li Other U step rate test Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConoconPhillips Alaska, Inc. Development p p ❑ Exploratory ❑ 186 -009 - 3. Address: P.O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 0 6. API Number: 50- 283 - 20078 -00 0 3 7. Property Designation (Lease Number): 8. Well Name and Number: ADL -58831 - BRWD -1 'S 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): n/a Undefined WDSP -- 11. Present Well Condition Summary: Total Depth measured 3560 feet Plugs measured n/a feet true vertical 3560 feet Junk measured 3500 feet Effective Depth measured 3459 feet Packer measured 3124 feet true vertical 3459 feet true vertical 3124 feet Casing Length Size MD TVD Burst Collapse Structural - - Conductor 76' 20" 98' .. 98' 2710 1100 Surface 1980' 9.625" 2000' 2000' 4990 7720 Intermediate n/a - - - Production 3536' 7" 3554' 3554' 8330 11220 Liner n/a - - f RECEIVED D JUL ( 3 ZO1L Perforation depth Measured depth 3286 -3502' e MAY 3 0 2012 True Vertical depth 3286' -3502' feet AOGCC Tubing (size, grade, measured and true vertical depth) 2.875" L -80 ! " 1 3147' 3147' Packers and SSSV (type, measured and true vertical depth) I -B- Hughes, 7" 3147'md / 3147' TVD No SSSV 12. Stimulation or cement squeeze summary: Step rate injectivity test with produced water only, no stimulation Intervals treated (measured): 3286' - 3502' Treatment descriptions including volumes used and final pressure: See attached pump rate from 0.25 BPM - 2.5 BPM (68.75 Bbls used) 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0.5 0 1700 Subsequent to operation: 0 0 2.5 0 2100 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run n/a Exploratory ❑ Development Service 151 - Stratigraphic ❑ Daily Report of Well Operations x 16. Well Status after work: Oil ❑ Gas LJ -s WDSPL U 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: 312 -187 Contact Marcus Barbee Printed Name Marcus Barbee Title Wells Engineer Signature 0i�✓�6.G��'''--' Phone 265 -6932 Date 5/30/2012 � % ,07/Z - Form 10-404 Revised 11/2011 D�1}S MAY 0 LU Submit Original Only • Page 1 of 1 Barbee, Marcus G (Swift Technical Services LLC) From: Schwartz, Guy L (DOA) [guy.schwartz @alaska.gov] Sent: Thursday, May 17, 2012 2:56 PM To: Barbee, Marcus G (Swift Technical Services LLC) Cc: Dethlefs, Jerry C; Herrmann, Daniel D; Regg, James B (DOA) Subject: [EXTERNAL]RE: Verbal approval for BRWD -1 step rate test Marcus, Regg and I discussed the situation and both agree you should move ahead with your proposed Step rate Injection test as outlined below. You have verbal approval to proceed. As you said the formal sundry will be delivered sometime today. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Barbee, Marcus G (Swift Technical Services LLC) [mailto:Marcus.G. Barbee @contractor.conocophillips.com] Sent: Thursday, May 17, 2012 2:19 PM To: Schwartz, Guy L (DOA) Cc: Dethlefs, Jerry C; Herrmann, Daniel D Subject: Verbal approval for BRWD -1 step rate test Mr. Schwartz, ConocoPhillips would like to perform a step rate injection test on well BRWD -1 over the weekend. We have submitted a 10 -403 sundry application to your office but believe it to be delivered too late for you to approve prior to the weekend. We performed a step rate test to 1700 psi earlier this year but need to qualify the well to a higher pressure (2500 psi). The procedure is written verbatim with the only change being the maximum injection pressure; it is attached for you review. Please let me know if this is acceptable to you and your office. Thank you, H ai' u ' &u' - biee' Wells Engineer ConocoPhillips Alaska, Inc. 1- 907 - 265 -6932 O. 1- 907 - 250 -1163 C. This transmission may contain information that is privileged, confidential and / or exempt from disclosure under applicable law. If you are not the intended recipient, you are hereby notified that any disclosure, copying, distribution, or use of the information contained herein (including any reliance therein) is STRICTLY PROHIBITED. If you received this transmission in error, please immediately contact the sender and destroy the material in its entirety, whether in electronic or hard copy format. Thank You. 5/29/2012 WSR Historical - QC Job: Misc. Capacity Sustainment ✓ • • Report Date: 5/19/2012 ConocoPhillips BRWD -1 Rig: LRS PUMPING 26 API / UWI Field Name 5028320078 BELUGA RIVER UNIT Well Type Original KB /RT Elevation (ft) Well Status Legal WeIlName Development 92.00 DISP BRWD - 1 JOB Actual Start Date End Date Secondary Job Type Primary Wellbore Affected 5/19/2012 12:00 5/19/2012 16:15 ZX03 Pumping / Load Well BRWD -1 NETWORK Primary Job Type Project Description Common WeIlName AFE / RFE Network/ID # Misc. Capacity Sustainment BRWD #1 Expense Wellwork BRWD -1 10336367 10336367 RIG Rig Accept Date Rig Release Date Rig Type Contractor Rig Name /No 5/19/2012 12:00 5/19/2012 16:15 PUMPING LRS 26 Rig Supervisor Title Company Phone Work Phone Mobile Pager Merritt, Cameron - CPAI, Wells Supervisor Wells Supervisor CPAI 907 - 263 -3932 907 - 252 -9243 N/A job scope, worksting information, or noted if job is performed during Drilling Operations Comment initial and final pressures General Remarks T /I /O Initial = 0/0/0 T /I /O Final = 250/0/0 this data box is reviewed daily by engineers, supervisors, and techs. Last 24hr Summary Rigged up and performed an injectivity test with LRS Pump Truck, Turned the well back over to production, Job Complete 0.25 bpm = 300 psi 1.50 bpm = 1400 psi 0.50 bpm = 450 psi 1.75 bpm = 1600 psi f ' (p /' Lti r 0.75 bpm = 650 psi 2.00 bpm = 1800 psi 1.00 bpm = 900 psi 2.25 bpm = 1950 psi 1.25 bpm = 1150 psi 2.50 bpm = 2100 psi weather related data when and if weather has affect on job Weather Wind T ( °F) DAILY OPERATIONS Report Start Date Report End Date Status at Reporting Time Time Log Total Hours (hrs) 5/19/2012 12:00 5/19/2012 16:15 05/20/2012 4.25 CONTRACTOR Supervisor Title Company Phone Work Mobile Pager JENSEN - LRS, Pump Operator Pump Operator LRS 659 -7173 N/A N/A TIMELOG Cum Dur Start Time End Time Dur (hrs) (hrs) Operation Wellbore 12:00 14:15 2.25 2.25 Spotted, Rigged in Unit, Permits, Rigged up Well Head BRWD -1 14:15 15:15 1.00 3.25 Began Pumping Step Rate Injectivity Test BRWD -1 15:15 16:15 1.00 4.25 Rigged down Unit and Associated pumping lines, hose, and equipment BRWD -1 DAILY COSTS * * amount = 0 for jobs done while drilling, show cost & customer in note section for jobs done while drilling * * AFE /RFE/Maint.# Cost Description Vendor Note / Description 10336367 / 10336367 CPAI Wellsite Superv, Engineern, Labr ConocoPhillips Company 10336367 / 10336367 Pressure Truck / Hot Oiler Little Red Services Inc FLUIDS Fluid To (bbl) Note PRODUCED WATER 35.0 TBG www.peloton.com Page 1/1 Report Printed: 5/29/2012 • • 7 [T": If AlnsEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7a, AVENUE, SUITE 100 ANCHORAGE. ALASKA 995°1453g CONSERVATION COMMISSION PHONE (907) 279 -1433 FAX (907) 276 -7542 Marcus Barbee Wells Engineer ConocoPhillips Alaska, Inc. \,,c,>00'61 P.O. Box 100360 Anchorage, AK 99510 • Re: Beluga River Field, Undefined Pool, BRWD -1 Sundry Number: 312 -187 Dear Mr. Barbee: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this Zy day of May, 2012. Encl. • • RECEIVED , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 17 2012 APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 A O GCI i 1. Type of Request: Abandon r FWg for Redr8 r Perforate New Fool r Repair wen r ange Approved Program r Suspend r Pug Perforations r Perforate r FUN Tu bkrg r The Extension r Operational Shutdown r Ra -ender Susp. Well r Stkrukde r Alter casing r O her:Step-Rate loon Test FT 2. Operator Name: 4. Current Well Class: 6. Perrnft to DrUI Number: Conoc oPhillips Alaska, Inc. Devebpmerd r Dcpbratory r 186-009 3. Address: Stratigraphb r Service W 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 283 - 20078-00 7. if perforating, closest approach b pool(s) opened by this operation to nearest property line 8. Wen Name and Number. where own efshlp or bndownership changes: Spadng Exception Required? Yes r No Fir BRWD-1 9. Property Deslgnatbn (Lease Number): 10. FIeINPoos(s): ADL 58831 Bskga River Unit - Undefhed WDSP 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): affective Depth MD Eft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 3560 3560 3500' 3500' 3525 Casing Length Size MD TVD Burst Collapse Conductor 76' 20" 98' 98' 1 Surface 1980' 9.625" • 2000' 2000' Production 3536' 7. 3554' 3554' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubkig MD (ft): 3286' - 3502' 3286' - 3502' 2.875 N 3147 Packers and SSSV Type: • Packers and SSSV MD (ft) and TVD (ft) PACKER - IB Hughes Packer MD.3124 and TVD=3124 NO SSSV 12. Attachments: Description Summary of Proposal Fi 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service J7 14. Estimated Date for Commenting Operations: 15. Well Status after proposed work: 5/2W2012 Gil r Gas r WDSPL F7 Suspended r 16. Verbal Approval: Guy Schwartz Date: 5/17/2012 WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing Is true and correct to the best of my knowledge. Contact: Marcus Barbee @ 265 -6932 Prk>ted Name iii -at .: _ 0. Title: Wens Enithuser S19nature /� �,,�j �` Phone: 285 -6932 Date /7- /. d Commission Use Only Stmdry Number/j )2 m Conditions of approval: Notify Cor aleston so that 5 represerdative may witness ccJJ PIug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Stunt Form Required: /(5 q di APPROVED BY Approved b COMMISSIONER THE COkNASSION Date: 5 24 — / 2 Form 10-403 Revi ed 1/2010 DUPUCTE St rntt in Duplicate • • SUITE [IF AILASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Marcus Barbee MAY 4 �� ; �� Wells Enginee ©19 ConocoPhillips Alaska, Inc. P.O. Box 100360 r o Anchorage, AK 99510 Re: Beluga River Field, Undefined Pool, BRWD -1 Sundry Number: 312 -187 Dear Mr. Barbee: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this 4-1 7' day of May, 2012. Encl. • , , STATE OF ALASKA RECEIVED ALA OIL AND GAS CONSERVATION COM ON b S S 1z f / APPLICATION FOR SUNDRY APPROVALS MAY 17 2012 20 MC 25.280 �� ~2 �� µ � I c 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair well r Cfiarig9"ApAiroTdFrogram r Suspend r Rug Perforations r Perforate Pu ll Tubing g ]'°`°° Time Extension r Operational Shutdown r Re - enter Susp. Well r Stimulate r Alter casing F Other:Step -Rate Injection Test 17. 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 186 - 009 3. Address: 6. API Number: Stratigraphic r Service ;r . P. O. Box 100360, Anchorage, Alaska 99510 50 - 283 - 20078 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No i✓ BRWD -1 . 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 58831 • Beluga River Unit - Undefined WDSP 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 3560 3560 3500' 3500' 3525' Casing Length Size MD TVD Burst Collapse Conductor 76' 20" 98' 98' Surface 1980' 9.625" 2000' 2000' Production 3536' 7" 3554' 3554' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3286' -3502' 3286' -3502' 2.875 N -80 3147 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER - IB Hughes Packer MD =3124 and TVD =3124 NO SSSV 12. Attachments: Description Summary of Proposal J;r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development Service i 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/20/2012 Oil r Gas r WDSPL 1V Suspended F 16. Verbal Approval: Guy Schwartz Date: 5/17/2012 WINJ r GINJ J WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Marcus Barbee © 265 -6932 Printed Name _ Barbee Title: Wells Engineer r Signature f � - C "-�' f PPhone: 265 -6932 Date 3 /iJ — Commission Use Only Sundry Number: 3i 2. .., lt .- 1 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: / 0. Lie 4 / APPROVED BY r Approved by: COMMISSIONER THE COMMISSION Date: J - Z f. - / 2 -- - ` Form 10 -403 R e v l s t e r Y l?1 2 4 2011 1 S'zz- n • Submi 'n D u p l i c a t e • • Drilling v--- ConocoPhillhps ,>9�iis Alaska Conic f'L,utps Date: May 17, 2012 File code: Well File BRWD -1 Subject: BRWD -1 Drift, Tag, and injection profile Procedure To /Location: Central Wells Group NSK -69 Network Number: Activity: Zx48 Digitally si ` d by Marcus• : Barbee, o —We p, Marcus Barbee DN o — d illin g ells, be " .s com, c =US Prepared By: Marcus Barbee ITT" 2 "05.1 -00 Telephone: 265 -6932 / 250 -1163 ■ ■ Approved By: Ty Senden ) 5/4[9_ Telephone: 265 -1544 / 982 -3996 OIL\ Procedure Justification: A new pump will be installed on th - -st side and it is prudent to ensure the well will be able to accept the w -i' er. This is a disposal well for the West side and will be on t - ritic- ath . the rig while it is in operation the summer of 2012. Perform rate i -c ion test with logging tools in the hole using produced fluid. 44 cc: Wells • ineer - Ty Senden e-mail Beluga Production Engineer — Daniel Herrmann e-mail Wells Supervisor - Thure Johnson e-mail Wells Supervisor - Cameron Merritt e-mail Beluga Production Operators e-mail Pollard Wireline Supervisor e-mail MGB 5/17/2012 • • Iv Drifting ConocoPhii[ips , _ +"tints Alaska carom.oPF∎Il ,s Job Objective: S Firs Incident Free Operations!! Obtain updated drift, tag, and injection BHP survey data Job Concerns: Minimum ID: 2.205" XN profile Well has no SSSV profile Slick line tool string on bottom w /unknown length of wire attac Annulus is full of diesel Well History: The master valves were changed out in 2007 to 3 i Ives. Lost 1 -3/4" slick line tool string and unknown length of wire in 2010. ed out the well in 2010 to 3482' and injected 2.5BPM @ 1350 psi. , ed out a well in 2011 to 3500'. Slick line tagged bottom 03 -17 -2012 @ 34 and able to inject only 0.5 BPM @ 1700 psi. Procedure: Slickline: 1. Hold SIMOPS • - ing • pro ction, slick line, and pump crews, obtain work permits as nec ° - 2. MI Slick li e 't, Co Duct S. -ty Meeting and Identify Hazards on location. • -ct wellhea• urrounding area to identify any pre existing conditions, 1 equire• ..rto rig up. r operations, MU 1 -3/4" standard slick line 3. R kline ui pme t as per standard ope at ions tool tring w /2" fluted swedge, TTL, and DD sample bailer w /flapper bottom sub. With , ubricator bottom even with the height of the tree, position the finger of the TTL -: oss from the lock down screws on the tubing hanger and zero your counter. Lubricate tools and pressure test lubricator to 2,500 psi, bleed to nominal SITP. 4. Open the swab valve (count turns and record in job log). RIH and drop out the tail with the tool string. PUH slowly until the tubing tail is located, drop back down a couple of times to ensure its location before shearing the pin, record depth in job log and correct for RKB. Once located and finger pin is sheared continue to RIH and tag bottom. On bottom, work tools to collect a sample, record corrected depth MGB 5/17/2012 • • • ConocoPhillips Alaska ConocoPfiilti{x of new PBTD. POOH. Note: if a length of perforations is covered up, bailing operations may begin... call town if there are perforations covered up. 5. MIRU pump and associated equipment and crew. Hold PJSM with all personnel on location. 6. Lay hard line to companion valve on well head. Clear area around hard line of all non - essential personnel. Flood lines with produced water and test same 250 psi low / 5,000 psi high. Bleed to zero and stand by for Slickline. 7. Once OOH BO the swedge, TTL & SB, collect the sample and send to town attn: Marcus Barbee. PUMU memory pressure temperature tools, zero at the tubing hanger and lubricate tools. 8. Close in the master valve, open the swab valve, open the companion valve and pressure test the lubricator to 4,000 psi with produced water. Bleed test pressure to nominal SITP, close in the companion valve, open the master valve and RIH with memory logging tools, making stops as per reservoir engineer Daniel Herrmann. 9. Once a SBHPS pass has been made, open the companion valve and come on line for a step rate injection profile making passes across the perforated interval @ 30' /minute with pump rates @ .25, .5, .75, 1, 1.5, 2, 2.5 BPM using (2,500 psi as Maximum Allowable Surface Pressure) (note: make up passes only while logging then run back to bottom for the next up pass while increasing to the next step rate) 10. POOH, Once OOH, down load memory data and verify good data was obtained. If so, begin the rig down process, if not, repeat the logging run until good data is achieved. 11. Prior to RD of the pump equipment, dispose of any remaining produced water by injecting it down hole. Record volume pumped for injection profile and record remaining volume that was injected. 12. RDMOL Walk throw cation with production operator, ensure location is clean and free of debris. Turn well back over to production. MGB 5/17/2012 • • Dritling n 'or" W1 Co oco s p Alaska Cc n< oPhilEips Well History: 10/26/2011 6:00 RU SL UNIT, TAG FILL @ 3495' RKB, RDMO, COMPLETE 10/25/2011 6:00 RU CTU, TEST BOP, PERFORM N2 /FCO TO 3500' RKB, SHUTDOWN FOR NIGHT, IN PROGRESS 10/24/2011 8:00 FLY TO BELUGA, LOCATE EQUIPMENT, PJSM, RU CTU, IN PROGRESS 9/30/2011 7:00 RIH W/1.75" BAILER TAG FILL @ 3316 RKB, MA/ RUNS, BAILED TO 3336' RKB, FINES AND HARD CHU K FINES IN BAILER, CALL ENG W /FINDINGS, IN PROGRESS 7/3/2011 16:00 MIRU POLLARD S/L UNIT. RIH W/ 1.75" DD BAIL:' TO B TAG FILL, POOH. WELL ON VACUUM. SECURE LLHE A RDMO. 8/17/2010 3:00 Performed N2 assisted FCO to hard tag @ ` !� ct ' . 8/16/2010 7:00 MIRU BJ COIL UNIT ON BRWD INJEC IO ELL, AIT ON SPOOL ADAPTER FROM KENAI, IN LL • D BOPE TO WELLHEAD, MAKE UP HARD LI TO LO : TANKS. 8/11/2010 6:00 MIRU POLLARD S/L UNIT. RI " D BAILER TO 3,361'WLM TAG FILL and retrieve sampl- POO . L ON VACUUM. SECURE WELLHEAD, R► 5/27/2010 6:00 Performed FCO to hard @ 34. ctmd (top of fish). Heavy sand returns, performed i ti test in well w/ 80 bbls of produced water at 2.5 bpm 50 • - ' `RDMO coil unit. 5/25/2010 6:00 TAG HARD FILL E 7" C © 3294' CTMD. JETTED ON FILL WITH BJ V*;' LE BUT MADE SLOW PROGRESS TO 3306 CTM r . u E ET PAST 3306' CTMD. ORDER UP MOTA• ' D MILL M RE N2. JOB IN PROGRESS. 5/24/2010 6:00 RIGGEI OIL IT AND TANKS FOR CLEAN OUT. PERFORM S F • TEST, TEST WAIVED BY JEFF JONES. JOB IN • OGR -. 5/12/2010 8:00 2.00" R to 3, •' WLM, ran survey to 3,259' WLM ran 2.30" GR to i • - - at 3, 4' WLM 3/13/201e Tried below Bow Spring tried w /KJ 3/12/2010 00 • fis • string w /bailer in 7" casing, tried w /KJ on top of Bow ing al -. tried w /no Bow Spring just pulling Tool cannot sit down on anything sticky off bottom 3/11/2010 6:0k,. Ran in w /8' 1.75" DD Bailer made 7 runs tag at 3,288' WL bailed to 3,292' WL last run pulled out very sticky sling shot up hole pooh parted wire at surface called for fishing tools could not latch or get picture of fish 3/10/2010 6:00 Standby for change out & removal of hard line & electrical change tree connection on well 2/2/2010 6:00 WORK STRING DETAIL: N/A DEBRIS LEFT IN HOLE: NONE SUMMARY OF WORK: Rigged down wireline 2/1/2010 6:00 WORK STRING DETAIL: (1 1/2 ") RS, KJ, 13' Stem, KJ, OJ, Spangs DEBRIS LEFT IN HOLE: NONE SUMMARY OF WORK: Bailed fill at MGB 5/17/2012 • • , Clriitliitlg ConocoPhillips &We > Alaska Co•nucc01 ila ps 3,289' WLM (7" liner) approx 570 cubic inches of material removed from liner final SITP- 320# PSI start SITP 750# PSI 1/31/2010 8:00 WORK STRING DETAIL: (1 1/2 ") RS, KJ, 13' Stem, KJ, OJ, LS Spangs DEBRIS LEFT IN HOLE: NONE SUMMARY OF WORK: Ran 1.75" Bailer to 3,282' WLM tagged fill 8/31/2007 6:00 PT TWC 1400 psi, OK. LD lubricator. Remove lower master. NU new MV's & wing valve. Close wing & PT valve bodies & breaks against TWC to 2300 psi, OK. RU lub & pull TWC. Close lower MV & PT 2380 psi, OK. Close upper MV & PT 2390 psi, . RDMO. 8/30/2007 6:00 Reviewed LOTO & EIP. Verified tbg on vac. Clos - • er MV. Removed leaking upper MV, tee & wing valve. Install ap on lower MV. RU Cameron lubricator. PT lub & tree c. • 101 i. Open lower MV & set TWC in tbg hanger. SDFN. e gibc 1 OPP MGB 5/17/2012 SAK • BRWD -1 ConocoPhillips Well Attri butes Max Angle & MD TD AIr14M:+, I�lc: ! Wellborn API /UWI ''Field Name Well Status !Inc! ( °) MD (ftKB) 'Ant Btm (ftKB) • (a,ocaetaups , 502832007800 BELUGA RIVER UNIT DISP 3,560.0 Comment `528 (ppm) !Date Annotation End Date I KB -Grd (ft) Rig Release Date ••• WellConfq: - ERwo-f,4/12011 4:5205 PM SSSV: NONE LAST WO: I 22.00 5/26/1986 End m Scheatic -Antual Annotation Depth (ftKB) [End Date Annotation Last Mod ... End Date � Last Tag: 3,482.0 5/27/2010 I Rev Reason: FORMAT UPDATE ninam 4/1/2011 Casing Strings Casing Description String 0... String ID ... Top (RKB) Set Depth (T... Set Depth (TVD)... String Wt.. String ... String Top Thrd - - - -- CONDUCTOR 20 19.124 88.0 96.0 94.00 H WELDED Casing Description String 0... String ID ....Top (568) Set Depth (f... Set Depth (TVD)... String WE.. String... String Top Thrd HANGER, 18 SURFACE 9 5/8 8.681 • 88.0 2,000.0 47.00 RS BTC Casing Description String 0... 'String ID ... Top (ftKB) Set Depth (f... 'Set Depth (TVD) ... String WE.. String ... String Top Thrd • PRODUCTION 7 6.059 88.0 3,554.0 29.00 P -110 I BTC --3 Tubing Strings Tubing Description String 0... String ID ... Top (RKB) Set Depth (1... Set Depth (TVD)... String Wt... String ... !String Top Thrd ',TUBING 27/8 2.441 15.9 3,147.0 6.50 N -80 I EUE -8RD Completion Details ' Top (MB) ( ( °) Rem Description Nomn). Top Depth (ND) Top Mel Comment ID (In) 2.323 88 CONDUCTOR, `• 1 5.9 HANGER WKM U -EN TUBING HANGER 3,124.2 SEALS HUGHS CL LOCATOR w/ 4 SEAL UNITS 2.375 3,124.2 PACKER 7"1-8 HUGHS PACKER 3.250 SURFACE, 3.130.2 MILL MILLOUT EXTENSION 3.920 8&2,000 - __ 3,137.0 _.. _._ .__._ NIPPLE XN NIPPLE 2.250 Other In Hole reline retrievable plug valves, pumps, fish, etc.) Top Depth I SEALS, 3,124 (ND) Top Intl Top (ftKB)'. (ftKB) ( ° ) 1 Deaeriplbn Comment Run Date ID (In) PACKER, 3,124 3,500 'FISH Fishing Neck Slickline overshot with fishing neck, left on 10/5/1987 0.000 L G bottom 10/05/87. Perforations ,& Slots I Shot Top (TVO) Btm )TVD) I Dens Top ([R(B) Btm (ftKB) (RKB) (R■B) : _ Zone Date (sh••• Type Comment 3,286 3,356 7/1/1992 22.0 RPERF MILL 3,130 3,4081 3.422 7/1/1992 22.0 RPERF 3,448' 3.478 7/1/1992 22.0 RPERF 3.478 3,502 7/1/1992 22.0 RPERF Notes: General & Safety End Date Annotation 4/16/1997 ,NOTE: 3470' RKB TTL Locator (25' correction) ;1/28/2011 I NOTE: View Schematic w/ Alaska Schematic9.0 NIPPLE. 3,137 - -- TUBING, 3,138 -- RPERF, 3.286-3358 - -- • RPERF, 3,408 -3,422 - RPERF, 3,4483,478 • RPERF, 3,478-3502 FISH, 3,500 - - — 4 ...._ _, PRODUCTION, 88- 3,554 TD, 3,560 - — . • • Page 1 of 2 Schwartz, Guy L (DOA) r , j / (f6, —doh From: Dethlefs, Jerry C [ Jerry.C.Dethlefs @conocophillips.com] Sent: Tuesday, May 22, 2012 11:24 AM To: Regg, James B (DOA); Barbee, Marcus G (Swift Technical Services LLC) Cc: Herrmann, Daniel D; Schwartz, Guy L (DOA); Dethlefs, Jerry C; Shultz, Steve (Orbis Engineering, Inc.) Subject: RE: Verbal approval for BRWD -1 step rate test Hello Jim; To my knowledge BRWD -1 has never accepted slurried waste. Also, to my knowledge, we are not planning to inject slurried waste in the future in BRWD -1. I think the 4 -year MIT schedule is still appropriate. I will check with the Drilling folks to verify the program this summer will not include slurry. Let me know if you have any other questions. Jerry Dethlefs Well Integrity Director ConocoPhillips Alaska Office: 907- 265 -1464 Cell: 907- 268 -9188 V From: Regg, James B (DOA) [mailto:jim.regg @alaska.govj Sent: Tuesday, May 22, 2012 8:31 AM To: Barbee, Marcus G (Swift Technical Services LLC) Cc: Dethlefs, Jerry C; Herrmann, Daniel D; Schwartz, Guy L (DOA) Subject: [EXTERNAL]RE: Verbal approval for BRWD -1 step rate test Has BRWD-1 (PTD 1860090) ever accepted slurried waste? Is the plan for the upcoming well work to inject slurried waste into BRWD -1? Appears from our injection data that BRWD -1 have been used infrequently since the Class I well BRU 232 -09 (PTD 1841360) commenced injection in early 2010. I cannot tell from AOGCC well records since everything into a disposal well is broadly labeled as water, but MIT frequency has been every 4 years indicating that no solids have been injected. Injected materials have implications for type of diagnostic testing that may be needed to confirm integrity. Slurry injection also impacts the frequency for compliance MITs; Industry Guidance Bulletin 10 -002 notes AOGCC policy that slurry injectors are tested for mechanical integrity every 2 years. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Schwartz, Guy L (DOA) Sent: Thursday, May 17, 2012 2:56 PM To: Barbee, Marcus G (Swift Technical Services LLC) Cc: Dethlefs, Jerry C; Herrmann, Daniel D; Regg, James B (DOA) Subject: RE: Verbal approval for BRWD -1 step rate test Marcus, 5/22/2012 • Page 2 of 2 Regg and I discussed the situation and both agree you should move ahead with your proposed Step rate Injection test as outlined below. You have verbal approval to proceed. As you said the formal sundry s o u pp p y ry will be delivered sometime today. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Barbee, Marcus G (Swift Technical Services LLC) [mailto:Marcus.G. Barbee@ 7contractor.conocophillips.com] Sent: Thursday, May 17, 2012 2:19 PM To: Schwartz, Guy L (DOA) Cc: Dethlefs, Jerry C; Herrmann, Daniel D Subject: Verbal approval for BRWD -1 step rate test Mr. Schwartz, ConocoPhillips would like to perform a step rate injection test on well BRWD -1 over the weekend. We have submitted a 10-403 sundry application to your office but believe it to be delivered too late for you to approve prior to the weekend. We performed a step rate test to 1700 psi earlier this year but need to qualify the well to a higher pressure (2500 psi). The procedure is written verbatim with the only change being the maximum injection pressure; it is attached for you review. Please let me know if this is acceptable to you and your office. Thank you, Ala-veto- 8G , Wells Engineer ConocoPhillips Alaska, Inc. 1- 907 - 265 -6932 O. 1- 907 -250 -1163 C. This transmission may contain information that is privileged, confidential and / or exempt from disclosure under applicable law. If you are not the intended recipient, you are hereby notified that any disclosure, copying, distribution, or use of the information contained herein (including any reliance therein) is STRICTLY PROHIBITED. If you received this transmission in error, }Tease immediately contact the sender and destroy the material in its entirety, whether in electronic or hard copy format. Thank You. 5/22/2012 • • Page 1 of Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, May 17, 2012 2:56 PM To: 'Barbee, Marcus G (Swift Technical Services LLC)' Cc: Dethlefs, Jerry C; Herrmann, Daniel D; Regg, James B (DOA) Subject: RE: Verbal approval for BRWD -1 step rate test Marcus, Regg and I discussed the situation and both agree you should move ahead with your proposed Step rate Injection test as outlined below. You have verbal approval to proceed. As you said the formal sundry will be delivered sometime today. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Barbee, Marcus G (Swift Technical Services LLC) [mailto:Marcus.G. Barbee @contractor.conocophillips.com] Sent: Thursday, May 17, 2012 2:19 PM To: Schwartz, Guy L (DOA) Cc: Dethlefs, Jerry C; Herrmann, Daniel D Subject: Verbal approval for BRWD -1 step rate test Mr. Schwartz, ConocoPhillips would like to perform a step rate injection test on well BRWD -1 over the weekend. We have submitted a 10-403 sundry application to your office but believe it to be delivered too late for you to approve prior to the weekend. We performed a step rate test to 1700 psi earlier this year but need to qualify the well to a higher pressure (2500 psi). The procedure is written verbatim with the only change being the maximum injection pressure; it is attached for you review. Please let me know if this is acceptable to you and your office. Thank you, itiarc'' &Wi Wells Engineer ConocoPhillips Alaska, Inc. 1- 907 - 265 -6932 O. 1- 907 - 250 -1163 C. This transmission may contain information that is privileged, confidential and / or exempt from disclosure under applicable law. If you are not the intended recipient, you are hereby notified that any disclosure, copying, distribution, or use of the information contained herein (including any reliance therein) is STRICTLY PROHIBITED. If you received this transmission in error, please immediately contact the sender and destroy the material in its entirety, whether in electronic or hard copy format. Thank You. 5/17/2012 • • r arc i vl ~. Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, June 03, 2010 2:40 PM To: Czarnezki, Marta P. Subject: RE: Injection Question - DIO -3 Marta, ~ ~~o~ ~~ Whether a well is producing or not is not a factor that is relevant. What matters is if the well is a development/producer (oil, gas or water supply) or service (EOR or Class II disposal) injection well. Wastes from such wells are E&P exempt. Tom Maunder, PE AOGCC From: Czarnezki, Marta P. [mailto:Marta.P.Czarnezki@conocophillips.com] Sent: Thursday, June 03, 2010 2:35 PM To: Maunder, Thomas E (DOA) Subject: RE: Injection Question - DIO -3 Hi Tom - I did consult the "red book", but could not find any specific reference/differential regarding fluid disposal generated from anon-E&P exempt (non-producing) well...which is what prompted my call to AOGCC. I will route this accordingly and hopefully your interpretation will make it into the next "red book" revision. That is (in part) why I wanted something in writing from you. THANKS again!! -Marta Cz From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, June 03, 2010 11:11 AM To: Czarnezki, Marta P. Subject: RE: Injection Question - DIO -3 Hello Marta, Waste solids and fluids from production or Class I! injection wells (EOR or disposal) are defined as Class II. Some confusion is introduced when Class I wells enter the mix and EPA's position that wastes derived from a Class I well can only be disposed of in a Class I well. Since we spoke, it has occurred to me that the °'Red Book used on the slope by your colleagues might be a source of information that you can access. You might contact Wendy Mahan or Shelly Cosgrove(?) with questions. I hope our call and this response answer your questions. Call or message anytime. Tom Maunder, PE AOGCC From: Czarnezki, Marta P. [mailto:Marta.P.Czarnezki@conocophillips.com] Sent: Wednesday, June 02, 2010 4:10 PM To: Maunder, Thomas E (DOA) Subject: Injection Question - DIO -3 Hi Tom, As discussed, I would like confirmation that it is acceptable to AOGCC to inject fluid used to workover BRWD-1 (a non-producing well) back into BRWD-1 for disposal. If you can paraphrase the logic you gave me, along with the differences in views between AOGCC & EPA that would be terrific. I will circulate this to my NS counterparts & field supervisors as well for education purposes. 6/16/2010 ra~C ~ ui ~ THANK YOU so much for your time and assistance! Marta Czarnezki Environmental Coordinator Cook Inlet Asset ConocoPhillips Company PO Box 66 48237 Kenai Spur Hwy Kenai AK 99611 Ph: 907-776-2092 Fx: 907-776-2095 Cell: 907-252-6794 email: Marta.p.czarnezki@conocophillips,com 6/16/2010 • a~~Q~[~ OG~ Q~Q~~(Q /.~.~..E..w~~ J. Ennis Wells Engineer ConocoPhillips Alaska, Inc. ~. `~~~`,' ~~ ~(~ .,, ~ ~~t~a? ;. ~~ ~ V P.O. Box 100360 , : a Anchorage, AK 99510 Re: Beluga River Field, Undefined Oil Pool, BRWD-1 Sundry Number: 310-154 Dear Mr. Ennis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for ood cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, 'f~- DATED this~~ day of May, 2010. Encl. Daniel T. Seamount, Jr. Chair ` t,'~1A~ ~ ~~ STATE OF ALASIG4 ~~ ~ ~.1~ ALAS~IL AND GAS CONSERVATION COMMISS• 5•~ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ~C~~~ ~~ MAY 1 ~s~dl~zoio .-aska ail & Gas Cons. Ccfrtmtsslu+ 1. Type of Request: Abandon "" Plug for Redrill `~" Perforate New Pool Repair w ell ~""' Change ove ogram Suspend '" Plug Fierforations ~ Perforate ~'°'" Pull Tubing ~"" Time Extension ]"" Operational Shutdow n Re-enter Susp. Well ~ Stimulate Alter casin g Other: Coiled Tubing Clean-out 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development '"" Exploratory J"'" 186-009 3. Address: Stratigraphic "' Service ~' 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-283-20078-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS ~ No `', BRWD-1 ' 9. Property Designation: 10. Field/Pool(s): ~ ~ ~[~~crc~c~ ~~~~, ADL 58831 Beluga River Unit -,~ieclir~Pre=A '~ ~ ° ~ ~ `'~' 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (n): Effective Depth ND (ft): Plugs (measured): Junk (measured): 3560 3560 3500' 3500' 3525' Casing Length Size MD ND Burst Collapse Conductor 7g~ 20~~ gg~~ 98' Surface 1980' 9.625" 2000' 2000' Production 3536' 7" 3554' 3554' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3286'-3502' 3286'-3502' 2.875" N-80 3147' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) I-B Hughs Packer 3124' MD / 3124/ ND no SSSV 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ~"`, BOP Sketch Exploratory Developmen t i Seance ' 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/24/2010 Oil J"` Gas ~" WDSPL Suspended "° 16. Verbal Approval: Date: WINJ ~ GINJ ~" WAG Abandoned Commission Representative: GSTOR SPLUG ~j 17. I hereby certify foregoing is true and correct to the best of my knowledge. Contact: J. Ennis @ 265-1544 Printed Nam . Enn1S Title: Wells Engineer Signature Phone: 265-1544 Date ~ ~ 7 / b C mmi i n Sundry Number: ~1 ~ ~1 ~~ Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ~'" BOP Test Mechanical Integrity Test °'" Location Clearance Other: "T'~S•~ `BQ ~ E 'f `O ~{'S ~ O '7S ~ . Subsequent Form Required: ~Q - (~,0 4 • APPROVED BY ~ 0 O Approved by: COMMISSIONER THE COMMISSION Date: DMS MAY 2 0 Form 10-403 Revised 1/2010 Submit in Duplicate ~'~~ ~~:l~~rt,~ BRWD #1 • CT FCO to restore Class 2 injection PTD# 186-009 Wells Network: 10281607 The procedure outlined below will remove fill tagged at the top perf from the 7" casing w' itrified fluid utilizing BJ Services 1.75" coiled tubing and jet nozzle. SBHP of 40 psi was obtained on 5-12-10 @ 3225' MD. Reminder: All personnel on location are required to have received Beluga orientation training at the CPAI Kenai LNG Plant within the past year. Procedure• l MIRU BJ 1.75" CTU. Nipple up and test BOP's 200/4500 psi as per SOP. Notify AOGCC 24 hours prior to BOP testing. 2. RIH w/ 2.125" Vortex nozzle BHA to EOT at 3150' CTMD (slickline bailer tag depth 3289' MD 2/1/10). Establish circ @ 0.75 bpm produced water containing 1 gal/1000 gal FRW-16 & 750 scfm N2. CO to PBTD @ 3525' MD using max penetration rate of 7 fpm after encountering fill. If hard fill is encountered above fish @ 3478' MD, POOH for Weatherford motor & mill & resume CO. Do not attempt to run motor & mill past fish. Continue pumping & POOH @ 10 fpm to 3100' and then increase to 95 fpm until reaching 300' and slowing as per SOP. RDMO CTU. 3. RU Pollard slickline. Roundtrip 2.25" bailer to tag fill & verify. RD Pollard. Turn well over to disposal injection. ~ 5/17/2010 BRWD #1 CT FCO procedure OS-17-10.doc Created by jjennis ScDale ConocoPhillips BRWD-1 ~ ~J API# 50-283-20078-00 Annulus Fluid: 0-200' diesel, >200' water w/ Tretolite KW 132 Max Hole Angle: 1.8° @ 0' Spud Date 5/14/86 Ground Level: 70.' Last Completion 5/28/86 Original RKB: 88.' Schematic Rev. 5/12/04 yoke by TDT Water Disposal Sing/e sect. 13, T13N, R10W, NE 1/4 2,000 4SP: , 3,116 CASING & TUBING 3,120 3,124 b 3,128 3,132 3,136 f 3,144 3,152 3,160 3,168 3,176 3,185 3,193 3,201 3,209 3,217 3,225 3,233 3,241 3,249 3,257 3,266 3,274 3,282 3,290 3,298 3,306 3,314 3, 322 3,330 3,338 3, 347 3,355 3,363 3,371 3,379 3, 387 3,395 3,403 3,411 3,419 3,428 3,436 3,444 3,452 3,460 3,468 3,476 3,484 3,492 3,500 3,509 3,517 3,525 Fc ~onductor 20 ! 96' 94. # H-40 surface 9 5/8" X04' 43.5 # AL-95 BTC surface 9 5/8" 1,729' 40. # N-80 BTC iurface 9 5/8" 2,000' 47. # RS-95 BTC prod Casing 7 3,554' 29. # P-110 BTC tubing 2 7/8" 3,147' 6.5 # N-80 EUE-8RD Driven 12 1/4" Lead 600sx "G" w/ 6% gel 12 1/4" Tail 200sx "G". 210sx rtns. 12 1/4" 8 1/2" Lbl. Top TUBINGJEWELRY& FISH Length ID OD a 15.9 WKNI U-EN Tubing Hanger 0.75 2.323" b 3,124' Hughs CL locator w/4 seal units 4.80' 2.375" 3.25" Locator's full length runs thru pkr. c 3,124' Pkr 7" I-B Hughs Packer 5.30' 3.25" 5.75" d 3,129' 4 x 4.5" crossover 0.78' 3.92" 5.00" e 3,130' Millout extension 5.30' 3.92" 4.50" f 3,136' 4.5" x 2 7/8" crossover 0.75' 2.441" 5.00" g 3,137' "XN" 2 7/8" Nipple 1.02' 2.205" 3.00" Note: Jewelry depths based on DIL, CET, and pert logs WLM not on RKB. h 3,500` FISH WL Overshot with fishing neck 1.50' ~,,,~~~ ~; 1:' 91",~ PERFORATIONS, FILL & PLUGS Net Incline gone Top Btm. Status Date SPF Ft. An41e re-A 3,286' 3,356' Perfd in '86 @12 SPF, '87 @4 SPF, '92 @6 SPF 07/92 22 70' 1° re-A 3,408' 3,422' PerF'd in '86 @12 SPF, '87 @4 SPF, '92 @6 ' 07/92 22 14' 1° re-A 3,448' 3,478' Perf'd in '86 @12 SPF, '87 @4 SPF, '92 @6 ' 07/92 22 30' 1° re-A 3,478' 3,502' Perf'd in?86 @i`SPF,'8''~i4 SPF 10/87 ~,~ ~~' .. ,.° ,~,~,,. 3TD 3,525' 05,/98 FC 3,52' Float Coll~.r o5'9s IGS 4/16/97 3470' RKB TT locator (25' correction) ~ 10/4/95 3478' RKB 2" bailer 2/ 1/ 10 3289' RKB 08/86 Acid job 09/86 Pretty Creek Unit #1 injects drilling mud w/o approval from BRU WIO's 09/86 Acid job 10/87 Reperforate with 2-1/8" & 1-11/16" strip guns. Lost overshot at 3500' WLM 05/89 Acid job 10/89 Acid job 07/92 Reperforate with 2-1/8" strip guns 08/93 Inject workover fluids and treat with lithium hypochlorite 08/94 Bleach treatment, 3.3 ppb lithium hypochlorite in fresh water. 04/97 Run scratcher to remove build-up. BHP=1432 psia @ 3400' WLM (3283' SS) 04/97 Kinley caliper shows tubing in good condition w/ no pitting nor wall loss. 10/97 Bleach treatment, 30 bbls 1% lithium hypochlorite w/ 45 gals of sodium hypochlorite. MEMORANDUM State of Alaska ') Alaska Oil and Gas Conservation Commission TO: Jim Regg ·f ( P.I. Supervisor \~ei 1. 7: Z0/ DÇ' DATE: Tuesday, June 28, 2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA mc BRWD-l BELUGA RIV UNIT BRWD-l \%(,,: 00 C FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv (fBL 7/UI0r5 Comm NON-CONFIDENTIAL Well Name: BELUGA RlV UNIT BRWD-I Insp Num: mitLG050627134805 Rei Insp Num: API Well Number: 50-283-20078-00-00 Permit Number: 186-009-0 Inspector Name: Lou Grimaldi Inspection Date: 6/27/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well BRWD-l Type Inj. N TVD 3124 IA 305 1540 1535 1535 P.T. 1860090 TypeTest SPT Test psi 781 OA 30 30 30 30 Interval OTHER P/F P Tubing 2 2 Notes: Yearly MIT. Good test, well was prepped and ready. -.'[' f\UG Ç\ 9 2D05 SCJ\NNE \1 N-\ ] ~J <.J Tuesday, June 28, 2005 Page I of 1 ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us OPERA TOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. BRU BRWD-1 06/27/05 Larry Baker Lou Grimaldi /k- "Y( 4/>-~ Well BRWD-1' Type Inj P.TD. 1860090 Type Test Notes: 4-Year MIT N P Packer TV.D. Test psi Depth 3134 1500 Tubing Casing Pretest Initial 15 Min. 30 Min. 1.0 1.5 1.5 1.5 Interval 325 1540 1535 1535 P/F 4 P Well Type Inj TV.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj TV.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj TV.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.TD. Type Test T est psi 1500 Casing P/F Notes: Test Details: SCANNED JUL 0 7' 2005 TYPE INJ codes F = Fresh Water Inj G = Gas I nj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover 0= Other (describe in notes) MIT Report Form Revised: 05/19/02 MIT BRU BRWD-1 06-27-05.xls 6/29/2005 r(î:r \~:- !Gi) 00 ,,--. Œ .I ,:-:-, ", I':I~~ r-W ,:' ¡" \ ~ " j, l~ \, t " I~" gß\I, 'lb ff ,r¡....ld ¡, : i ,W \U Wi "', I"~,, ~,¡F,......] 'Wi r:' , ¡ ! l ' I I , ¡ r , ~ t ,~ , r, ¡: ~ W" Iii '~r, I:.J ) 171 n I--~~"\ 'fl':~ i ¡ ,': ð': , I) :1 r..l,1...J," ¡ ""\ : i i .: ,\ '1.""\" , " II ~ : " '", ",', \, " , \ lr¡ \ ¡1 II. \ íl ì J: L ~.J L=::ï W \\.1 ''''-~ ) /:zCp "1)1) 1 .fM !j~j FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Bearden Cook Inlet Reservoir/Operations Engineer ConocoPhillips Alaska P.O. Box 100360 Anchorage, Alaska 99501 '8Çj\N¡~Ef"" APR 2 8 20D5 Re: Beluga River BR WD-1 Sundry Number: 305-088 Dear Mr. Bearden: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superio urt unless rehearing has been requested. ~ DATED this/! day of April, 2005 Enc!. Beluga Disposal Well--BRU BRWD-l (186-009) ) ) Subject: Beluga Disposal Well--BRU BRWD-I (186-009) :From: 'Thomas Maunder <tom _ maunder@admin.state.ak.us> "Date: Wed, 13 Apr 2005 10:12:14 -0800 To: John Braden <John.C.Braden@conocophillips.com>, Dan Bearden <beardjd@conocophillips.com> John and Dan, I was reviewing the file regarding the sundry we have received for the bleach stimulation. From what records I have, it appears this well has needed to be stimulated, at least prior to 1994. The last item I show in the file is the MIT performed 6/25/01. Based on the 4 year schedule, an MIT is due prior to the end of June. Prior to the MIT the "latest" information in the file is dated June 1994. Does your well file have additional information after June 1994?? Is there an "electronic summary" of any well work?? For Slope wells, the Problem Wells engineers have been able to provide such a summary. In the interest of having a complete file, especially on a disposal well, Ild appreciate your checking on what might be available. Thank, call or message with any questions. Tom Maunder, PE AOGCC ~t>\...~ ~~ ~~ ...... "-.,, ~ \...E. ~,,~ \>..:) ~ \\ \-',,:;\0,/ \f',.~t"-~\-\<c"" -\0 ~~~M.\~. ~l\fs-()Ç 1 of 1 4/18/2005 9: 15 AM ) , ConocóP'hillips ) J. Daniel Bearden Cook Inlet Asset Telephone: (907) 265-6214 Facsimile: (907) 265-1441 beardjd @conocophillips.com '. ' 700 G. Street P. O. Box 100360 Anchorage, Alaska 99510-360 April 11,2005,2005 Commissioner Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 RE: SUNDRY NOTICE FOR BRWD #1 RECEIVED tiP . R 1 3 200S ~"'Qfl ¡ GII . ~c-q U',-, Dear Commissioner, Attached is an Application for Sundry Approval for bleach biomass removal stimulation on the Beluga River Unit water disposal well, BRWD #1. With your approval, we would like to begin this work as soon as possible. If you have any questions, please contact Dan Bearden at 265-6214 or John Braden at 263-4536. Sincerely, Q MV1J ~bnd-el^- Dan Bearden Cook Inlet Engineering Attachments 1. Type 6f Request: Abandon U Alter casing 0 Change approved program 0 , STATE OF ALASKA ' ALA,- lOlL AND GAS CONSERVATION COMM. liON APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: RECEIVED A APR 1 3 Z005' 4¡t<6 Suspend U Repair well 0 Pull Tubing 0 AI k 0" it Ga~ons.. Commis~inl1 , Perforate U as a Imiver Other U Stimulate 0 Time Extens~" rage Re-enter Suspended Well 0 5. Permit to Drill Number: 2. Operator Name: ConocoPhillips, Alaska 3. Address: PO Box 100360, Anchorage, AK 99501 7. KB Elevation (ft): 88 ft Development 0 Stratigraphic 0 Exploratory 0 ~ \<6"b-oa" Service 0 6. API Number: 50-283-20078-00 8. Property Designation: ADL 58831 11. Total Depth MD (ft): 3560' 9. Well Name and Number: BRU BRWD-1 10. Field/Pools(s): Beluga River Unit - Sterling Pre-A PRESENT WELL CONDITION SUMMARY Casing Structu ral Conductor Surface Intermediate Production Liner Total Depth TVD (ft): 3560' Length Effective Depth MD (ft): 3500' Effective Depth TVD (ft): 3500' Plugs (measured): 35'25' Junk (measured): 351!:JO' Collapse Size MD TVD Burst 76' 20" 1980' 95/8" 3536' 7" 98' 2000' 98' 2000' 1530# 5750# 520# 3090# 3554' 3554' 11220# 8510# Perforation Depth MD (ft): 3286' - 3502' Packers and SSSV Type: Perforation Depth TVD (ft): 3286' - 3502' 7" I-B Hughs Packer Tubing Size: 27/8" Tubing Grade: N-80 Packers and SSSV MD (ft): Tubing MD (ft): 3147' 3134' 12. Attachments: Description Summary of Proposal U Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Date: 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: 5/20/2005 Oil 0 Gas 0 Plugged 0 WAG 0 GINJ 0 WINJ 0 Service 0 Commencing Operations: 16. Verbal Approval: Commission Representative: Abandoned o o WDSPL Printed Namt\ Dan Bearden Signature No.N\.liJ IS e()4 ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Bearden Title Cook Inlet Reservoir/Operations Engineer t-'hone 907 -265-6214 COMMISSION USE ONLY Date 4/7/2005 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~S - () <6"' ~ Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ~ Location Clearance 0 " ~ <:.. '-' ~~~ i'-~ ~ \ '\ "O..\\d ~""'-.) <-I:> s - 0 ç Other: I.~ ~\\'t<?~\G\~,",~~ ~/..\~\'~O\>~,ú..\\ð~ \ \=>\~c..~<c <:.i)~~~ \õ""'\\o.~~~\ l \c,.~...\";;t-SO) 0'"" ~~(. ~ <.. \<;. ~- \ ã ~I' '" \ .. \ ~ \O}""O c.."û.~(r ~\\~~<;~. Date 1/( £ APPROVED BY Approved by: , ,c, . ð~ìIGE.'1N A [E COMMISSION Form 10-403 Revised 11/2004 ~dffirr5 c¡ I :z.Z_ Submit in Duplicate · /')~ ;1" ~ss~M:FJ Co~illips Well: Date: From: Phone: BRU BRWD-1 5/20/2005 Braden/Bearden 263-4536 265-6214 ) ) BLEACH STIMULATION BRWD-1 Job Scope: Capital or Expense: Estimated Cost: Net Gas Benefit: Bleach Stimulation Expense $15M N/A JUSTIFICATION I COMMENTS I HISTORY The injectivity of BRWD-l has been decreased from January 2004 to below 0.1 bbVd/ßpsi. The trend of increasing wellhead injection pressures and declining injection rates continues to date. A stimulation treatment is recommended to restore the disposal well to an injectivity of at least 0.15 bbVd/ßpsi as the volume of disposal fluids is expected to increase. The average yearly volume of water injected has increased by 22% per year since 2000. The target disposal rate is 250 bbl/d at 1,000 psig injection pressure. This treatment is performed every few years to restore matrix rate injectivity. OBJECTIVES A target injectivity of at least .15 bbVd/ßpsi is desired. The stimulation treatment uses bleach to break up the bacteria and biomass that plug perforations and decrease injectivity. PROCEDURE 1. Hookup tank of 30 bbls LiOCl or NaOcl (Lithium or Sodium Hypochlorite) solution with water to BRWD injection pump. 2. Pump step rate test on first 25 bbls within matrix rate (1700 psi pump limit). Record injection pressure and volume every IS minutes to determine baseline injection characteristics. 3. Reduce rate, continue pumping remainder of bleach/water. Continue recording injection pressure and volume every 15 minutes. 4. Displace with 25 bbls of clean water. 5. Shut-in and let soak for at least 12 hours 6. Pump 25 bbls of water at matrix rate (1700 psi surface pumping limit), and record injection pressure and volume every 15 minutes. 7. Return well to disposal service for at least 24 hours. 8. Pump step rate post test within matrix rate (1700 psi pump limit). Record injection pressure and volume every 15 minutes to determine post treatment injection characteristics. 9. Return well to disposal service. BACKGROUND INFO Treating Volume: (30 bbls) * (42 gal/bbl): 1260 gal Squeeze Volume: (1260 gal/138'): 9.13 gal/ft of perforated interval 27/8" Tubing Volume: (.00579 bbl/ft) * (3147'): 18.2 bbl 7" Casing Volume from TBG end to top & bottom perf: (.0371 bbl/ft) * (139 & 155') : 5 to 13 bbl Max radial penetration of bleach if entire height was treated uniformly... v = !!.- h (D 2 _ d 2 ) 4 V = 30 bbl = 168 II 3 h = 138 ft d = (7 /12 )11 => D = 1.37 II .. Perf Height " +--+ d D . Þ I; ...' P.. æs .- , "E1 ~ ë ~ I ~ ~ ~. ~~ '\·d 'f ·Je~~ ~~ea¿ Services RO. BOX 190515 ANCHORAGE, ALASKA 99519-0515 TELEPHONE (907) 349-4668 .'~r ',; RO. BOX 470 KENAI, ALASKA 9961'·0470 TELEPHONE (907) 283-3822 ~tJD -rt:", W"£¿G ¡(£l1ò J)E.SZ:6-^( ~. ~ . 1/?-E:E(!-1? , \\r"r·~ I! t/lIl¡Æ Z 11(0 &( S"~Ò rJr ~ ~~~ rw/Æ ':::J . z, 'Vt~" SC::>ÒÒ -PSI: \~ ! .t~:~ _7'~ ~-\,M¿¡)$,': Z ~'4?1 5ò¿k) ?s:r ~ [!' ~~ ---1 : - " .~ /Y?é ,v.-~ I r ~:: "--7ïj/(41 ·-j~-?Z~ì 15~~ ~~ ;;:t};" C::-%:,~ill z 1/~ .. $Còò ~sr ~ ¿JYLU /1'1 .J'Oðð ?.sr II'f 3 Oð() -psr -, Tý1>£'S" r 8- C:tJ""--,r eSG-. lib. LJ tlAw~ L ~rL_,,-- / c~' .sò'-J U , ' " Z 'Ilf~ 3CJòò? sz --:::> q f8'" C.s c,.. 7 ., C.sô- '~ If _ - z, ~ T'B G- BRWD History 1 of 1 ) Subject: BRWD History From: "Braden, John C" <John.C.Braden@conocophillips.com> Date: Mon, 18 Apr 2005 09:33:59 -0800 To: t01~maunder@admin.state.ak.us Tom- Atta ched is the 13RWD-1 history since 1993. John Braden ) l '6(O-'Oa~ . Content-Description: BRWD-l CHRON from 1993.rtf, BRWD-l CHRON from 1993.rtf Content-Type: application/rtf · Content-Encoding: base64 SGANNED APR 1 8 2.005 4/18/2005 9:54 AM BRWD-1 Date 8/5/93 8/14-15/93 8/9-18194 8/19/94 9-12/94 10/4/95 4/15/97 4/16/97 4/17/97 7/14/97 CHRvlJOLOGY ) \ '6Co-oo\ Operations Dowell pumped 652 bbls of bleach treated workover brine (Max. rate 3.25 bpm at 2120 psig). Ran step rate test at start with 192 bbls and 10 min. increments: Rate (bpm) Pressure (psiq) 0.47 1400 0.73 1480 1.04 1570 1.57 1680 2.50 1780 3.19 1910 3.19 2050 Dowell injected remaining workover fluids (397 bbls), started at 3.25 bpm/1950 psig and completed at 2 bpm/2150 psig. Pumped bleach treatment (lithium hypochlorite mixed with fresh water) to improve well's injectivity: Bleach Job: Bbl Fluid Rate (bpm) Pressure(psiq) 20 water wi 3.5 ppb LiOCI 1.70 1800 23 water 1 .85 1770 SI overnight for bleach to soak - SITP 1700, decreased to 1420 in AM 10 water 2.0 20 water wi 3.5 ppb LiOCI 2.4 20 water wi 3.5 ppb LiOCI 3.5 20 water 3.0 SI well with 1730 psig. 1810 1870 1980 1910 Injection pressures increased from 1200-1650 psig while disposing of:::::1 000 bbls of CTU fluids (Xanvis, KCL water). Dowell injected 622 bbls of remaining CTU fluids and produced water at rates from 2.25 bpm/1850 psig to 3.75 bpm/2025 psig. Bleach treatment (3.3 ppb lithium hypochlorite in fresh water) to improve well's injectivity: ' Pumped 10 bbls bleach, 20 bbls water, 20 bbls bleach, 20 bbls water at 1.5-1.75 bpm/2050 psig. SITP 1500 psig, leave well shut in 2+ weeks to soak. Average injection pressure decreased from 1550 to 1350 by year end. Scratcher indicates top 100' of tubing rough. Scratch nipple at 3125' WLM vs 3137' MD. Tag btm @ 3466' WLM + 12' = 3478'MD. Water sample smells like sewage. Pressure at 1404 psi @ 3370'MD. MIT failed because plug leaking. Casing pressure was constant. Tubing pressure fell from 2025 psi to 1550 psi. Lost 50 psi in first 10 minutes. Prep well for caliper. RIH with scratcher and made passes from swab to 3050'. Prep well for caliper and obtain BHP. Continued scratching to remove buildup on tubing walls. Drifted tubing with 2.25" gauge ring. Ran memory pressure gauge. BHP=1432 psia at 3400' wlm (3283' ss). Tagged fill at 3495' wlm. Kinley caliper run. Tubing in good condition with no pitting or wall loss detected. MIT for State Regs. Passed. Pressured up annulus to 1510 psi and monitored. Dropped to 1506 psi over 30 minute period. C:\TEMP\BRWD-1 CHRON from 1993.rtf 4/18/05 BRWD-1 9/1/97 10/11/97 10/15/97 5/22/98 6/25/01 CHRlJ~OLOGY ) \<t;(o-ooq Pump shutting down on high pressure of 1750 psi after 2-3 hrs of injection. Injection pressure has been on increase since disposing of coiled tubing fluids and rainwater runoff. Disposed of 4700 bbls of fluid from July thru September. Replaced 1" plungers with %" and pump no longer shutting down but injection pressure still high. Bleach Treatment: Pumped 30 bbls of 1 % lithium hypochlorite with 45 gals of sodium hypochlorite, chased with 20 bbls of fresh water. 1450 psi injection pressure prior to treatment, 1250 psi at end of freshwater chase. Post bleach treatment: Injection pressure @ 1170 psi after 4 hrs of pumping. Injection pressure suddenly increased from 1150 to 1420 psi. No abnormal fluids injected - produced water and fluid skimmed off solid waste pit. Will continue to monitor. MIT conducted per State regulations with AOGCC inspector onsite to witness. Passed. C:\TEMP\BRWD-1 CHRON from 1993.rtf 2 4/18/05 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser '~ t~j DATE: June 25, 2001 Commissioner SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder .~tv{ I'~' .~Z?.'t" "J~.ll.~ Phillips Alaska Inc. P.I. Supervisor ~ (.~.~q )(~,; j BRWD-1 Beluga River Field/BRU FROM: Jeff Jones' Petroleum Inspector I Packer Depth Pretest Initial 15 Min. 30 Min. I' WellI BRWD-1 I Typelnj.! F I T.V.D. I 31:~4 ] Tubing I 7 I 36 I 23 I 16 I lntervall 4 "P.T.DiI :186-009~TypetesiI P I'l:estpsil, 1500 I'C'asingl 1 I 1582 I' 1575 I 1571 I P/F'I .P_. Notes: I. nj. fluid is produced water and other exempt fluids. Type INJ. Fluid Codes F = FRESH WATER IN J, G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details MM_onday, June 25~ 2001: I traveled to Phillips Alaska lnc.'s Beluga River Unit to witness a 4 year Mechanical Integrity Test on well BRWD-I. Phillips representatives Scott Fahrney and James Redfern were on hand for the testing, which was performed in a safe and proficient manner. The pretest pressures were monitored for 30 minutes and observed to be stable. The standard annulus pressure test was then performed. I observed an 11 psi. pressure decrease in the casing over the 30 minute time span and a trend toward stabilization. This well is used for disposal of produced water and other exempt fluids and the test data above indicates it is suitable for continued injection. Summary: I witnessed a successful MIT on PAl's BRWD-1 injection well in the Beluga River Field/Unit. M.I.T.'s performed: 1_ Number of Failures: 0 Total Time during tests: 1,5 hrs. Attachments: _0 C.C: MIT BRU BRWD-1 6-25-01 JJ.xls 6/27/01 MICROFILMED 9/11/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 Mark H Wittow Preston Gates & Ellis 420 L St Ste 400 Anchorage, AK 99501-1937 Re: Z-Energy Spacing Exception Request Dear Mr Wittow: In the Course of its deliberations in the above-referenced matter, the C~)mmission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga 'River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga.River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 . Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit '212-24 Beluga River Unit 224-34 BelUga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit 221-23 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission would be insufficient. Vo' . Chairman ~ ""--J jo/rpc~z-energy ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 D A Grove, BRU/Kup Staff Mgr ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Z-Energy spacing Exception Request Dear Ms Grove: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit 221-23 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the material in these files, please notify the commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission would be insufficient. David W Johnston Chairman ~x.~~ jo/rpc~z-energy ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 Rosanne M Jacobsen, Arty ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Z-Energy Spacing Exception Request Dear Ms Jacobsen: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit' 221-23 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission would be insufficient. David W Jol~nston \ ~-- ~ Chairman ~ jo/rpc~z-energy ALASKA OIL AND GAS · CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR ~.. 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 Paul Craig, President Z-Energy Inc 2900 Boniface Pkwy #610 Anchorage, AK 99504-3132 Re: Z-Energy Spacing Exception Request Dear Mr Craig: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit 221-23 Data specifically referenced in the files included open hOle well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission David VV Johnston \ -' ~ Chairman ~ jo/rpc~z-energy ARCO Alaska, Inc. ~') Post Office Bo~ 100360 Anchorage, A~aska 99510-0360 Telephone 907 276 '~2'~5 August 26, 1992 Commissioner Leigh Griffin Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for BRWD-1 Reperforation. Dear Commissioner Griffin: Attached is a Report of Sundry Well Operations for the reperforation of the Sterling zone from 3286' to 3478' on Beluga River Unit BRWD-1. Please refer to the attached well schematic and Well Service Report for details of this operation. If you require further information, please call Brian Noel at 263-4879. Sincerely, J. C. Winn Acting Regional Engineer JCW:JLB :ka: 0179 Attachment cc: Mr. M. R, Williams Shell Western E&P, Inc. Mr. Mike W. Sellers Chevron USA, Inc. ,ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfi,eldComl]any STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown ~ Stimulate Plugging Perforate X Pull tubing ~ Alter casing ~ Repair well Pull tubing ~ Other Z. Name of Operator ARCO Alaska. Inc. 3. Address P. O. 8ox 100360, Anchorage, AK 99510 4. Location of well at surface 1936' FNL, 1 59' FEL, Sec. 13, T13N, R1 OW, SM At top of productive interval S. Type of Well: Development Exploratory Stratigraphic Service At effective depth At total depth Strai~lht Hole 6. Datum elevation (DF or KB) 88' KB 7. Unit or Property name Beluga River Unit 8. Well number I~P, WD-1 9. Permit number/approval number 86-9/92-180 10. APl number 50-283-20078-00 11. Field/Pool Belu~la River-Sterling feet 17. Present well condition summary Total Depth: measured true vertical 3525' feet 3525' feet Plugs (measured) Effective depth: measured 3525' feet true vertical 3525' feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Reperf: Length Size Cemented Measured depth True vertical depth 76' 20" Driven 98' MD 98' TVD 1980' 9-5/8" 2000'-surf 2000' MD 2000' TVD Reperf: Tubing (size, grade, and measured depth) 2-7/8", N-80 6.5# @ 3147'MD Packers and SSSV (type and measured depth) Packer 3134' MD 3536' 7" 3554'-surf 3554' MD 3554' TVD (conbination casing) measured Current: 3286'-3356',3408'-3422',3448'-3502' MD 16 SPF 3Z86'-3316'r3316'-3346'r3346'-3356'r 3408'-3422'~3448'-3478' MD 6 SPF true vertical Current: 3286'-3356';3408'-3422',3448'-3502' TVD 16 SPF 3286'-3316',3316'-3346',3346'-3356', 3408'-3422',3448'-3478' TVD 6 SPF RECEIV£D 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure N/A AU G 2 B 1992 Alaska 0il & Gas Cons. Gommiss'~on Anchorage 14. Representative Daily Averaoe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation SI Subsequent to operation SI 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil __ Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-404 Rev 06/1 5/88 Title Cook Inlet Re~lional En~lineer Service Date ~/~.7/9 '~ SUBMIT IN DUPLICATE 'ARCO, Alaska,'lnc. BRWD- 1 Spud Date: 5/14/86 Last Comph 5/28/86 Schematic Rev: 3/20/89 SEI/4NEI/4 Sec. 13,T13N i}.eluga River Uni.t API : 283-20078-00 Original RK0 (Depth Ret): 88' Ground Level: 70' Maximum Hole Angle: 1 3/4° RIOW, SM Angle at Perforations: 1° Well Type: Water Disposal Annulus Fluid: Diesel Top of Sterling: N/A ASTM: Single String 4 5 6 7 PBTD= 3525' TD=3560' L Jewelry 1 15.9 0.75' 2 3134' 4.80' 3 3134' 5.30' 4 3139' ,78' 5 3140' 5.30' 6 3145' .75' 7 3146' 1.02' WKM U-EN Tubing Hanger 2.323" Hughs CL Locator W/4 Seal Units* 2.375" 3.25" 7" I-B Hughs Packer 3.250" 5.75" X-Over 4" x 4 1/2" 3.920" 5.00' Millout Extension 3.920" 4.50" X-Over 4 1/2" x 2 7/8" 2.441" 5.00" 2 7/8" "XN" Nipple 2.205" 3.00" * Locator's entire length runs through packer * Tie-in w/DIL, CET & 10/87 peff shows top of packer @ 3124' MD and tubing tail @ 3137' MD (ELM) Casing and Tubing lZe.~zilztJL{~ Size ~ Grade Thread ToD Boflom Conductor 20" 94# H-40 Plain End 96' Surface 9 5/8" 43.5~ AL-95 BTC 904' Surface 9 5/8" 4Oft N-80 BTC 1729' Surface 9 5/8" 47# RS-95 BTC 2000' Production Csg 7" 29# P- 110 BTC 3554' Tubing 2 7/8" 6.Sit N-80 EUE-8RD 3147' Perforations Upper Sterling (Pre-A) J;~ [Ze..BS[tY~ Sect. Intewal 3286'-3356' 22 SPF 70' 3408'-3422' 22 SPF 14' 3448'-3478' 22 SPF 30' 3478'-3502' 16 SPF 24' Injection Open 7/92 Open 7/92 Open 7/92 Open * Originally 12 SPF, reperforated after CTU clean out w/4 SPF 10/4&7/87. Note: Slickline overshot w/fishing neck (1.91" OD x 1.5') left on bottom 10/5/87. 10/2/89 1.5" bailer 3524' RKB 10/30/90 1.8" gauge ring 3488' RKB 5/6/91 1.5" bailer 3494' RKB 6/21/92 1.75" bailer 3493' RKB* * Fill @ 3483' MD (E-Icg) RECEIVED A U G 2 8 t992 Alaska Oil & Gas Cons. Commission Anchorage JLB 6/92 TO NEW UENTURE __ JUL.-21-1992 14:00 FROM =ELUGR.._ RI UER ~ELL -' - " ' iPBDT ' ' I FIELD - DISTRICT- STATE I DAYS o _ - CHECK THIS BLOCK IF ,SUMMARY CONTINUED ON BACK AU G 2 8 I992 Alaska Oil ~, Gas'dons. Oom~issiO,~' " Ancfiorage' jSlgned $UL-2~,c1992 14:00 FROM ~m II~A RIUER TO ~ I NEW UENTURE P. ~5 '~'~ ~n~u,,~m~, in~ ' ) WELL SERVICE REPORT F~,KS_. ri_gq"' '~2fi"n.:'"~~,-- ~ ''" ~' ' ' ; ' '"' ' " i i, _J , CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK -'i~:~?~¥ ~ ,!IUL-13-~92 MON 15:5~ ID:COOKINLET~N.U ENGR TEL ,N0:907 265 69~5 ~413 P01 Post Office tk~ 1003~ Au~~ ~a~lo Chari~e Code Xerox copies to: NOTE: Bldg. Rm ommentB Please Numberyour Pa~lS Use Only Black Ink Use Only Cleard:)eBzmd RECEIVED Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office Bok .,0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering ORIGINAL July 7, 1992 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Submittal of Application for Sundry Approval for BRWD- 1 reperforation. Dear Mr. Smith: Attached is an Application for Sundry Approval for a reperforation of the Sterling zone from 3286'-3478' on BRWD-1. Please refer to the attached perforating procedure and well schematic for details of this operation. If you require any further information in this regard, please call Brian Noel at 263-4879. Sincerely, ,J.C. Wren Acting Re~onal Engineer JCW:DRH:jlg:0158 Attachment CC: Mr. C. Kidwell Mr. D. Santi Shell Western E&P, Inc. Chevron U.S.A., Inc. ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company {' STATE i: 0 I{ 16 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend I i Alter casing _ Repair well _ Change approved program_ Operation Shutdown Re-enter suspended well Plugging _ Time extension _ Stimulate ~ Pull tubing _ Variance _ Perforate ~ Other 2. Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Strafigraphic Service 4. Location of well at surface 1936' FNL, 159° FEL, Sec. 13, T13N, R10W, SM At top of productive interval 6. Datum elevation (DF or KB) 88' KB 7. Unit or Property name Beluga River Unit 8. Well number BRWD-1 9. Permit number ~- ? feet At effective depth At total depth Straight Hole 12. Present well condition summary Total Depth: measured true vertical 3525' feet Plugs (measured) 3525' feet Effective depth: measured 3525' feet Junk (measured) 10. APl number 50-283-20078-00 11. Field/Pool Belu[la River/Sterlin[t RECEIVED JUL -' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Proposed reperf: Proposed reperf: true vertical 3525' feet Length Size Cemented 76' 20" Driven 1 980' 9-5/8" 2000'-surf Td~ ~. ~/e~tical depth 98' MD 98' TVD 2000' MD 2000' 'I'VD 3536' 7" 3554'-surf 3554' MD 3554' TVD (combination casing) measured Current: 3286-3356'; 3408-3422'; 3448-3502' MD, 16 SPF 3286-3316', 3316-3346', 3346-3356', 3408-3422', 3448-3478' MD, 6 SPF true vertical Current: 3286-3356'; 3408-3422'; 3448-3502' TVD, 16 SPF 3286-3316', 3316-3346', 3346-3356', 3408-3422', 3448-3478' MD, 6 SPF Tubing (size, grade, and measured depth 2-7/8", N-80, 6.5# @ 3147' MD Packers and SSSV (type and measured depth) Packer 3134'MD 13. Attachments · Description summary of proposal Detailed operation program _ BOP sketch X 14. Estimated date for commencing operation Julv. 1992 Oil 16. If proposal was verbally approved Name of approver Date approved 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ./(%,Jz.,J~(,%,)~/c.V~ Title Cook Inlet Rocjional En,(]r. FOR COMMISSION USE ONLY 15. Status of well classification as: Gas Suspended Service X (Water Disposal) Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test _ Subsequent form require Approved by the order of the Commission Form 10-403 Rev 5/03/89 Original Signed By D~_,:!d W_ Johpsto'n IApproval , 10- ¥05f ..¢::,r:,'oved Copy Returned ......... 7:1~' q 2 Commissioner Date SUBMIT IN/'TRIPLICATE WELL BRWD-1 Re-perforating Procedure BR 23 June 23, 1992 OBJECTIVE; Re-perforate existing intervals to increase the disposal well's injectivity. Evaluations have shown that the well is susceptible to damage by perf plugging and swelling clays in the injection zones. In the past mud acid has been used to stimulate the well, but the positive results were very short lived. Re-perforation at 4 SPF in 1987 improved injecfivity from 0.05 to 1.85 bpm. This well becomes even more critical to the field as water production rates increase. The availability of a perforating unit on the west side of the inlet, allows the work to be done today as a proactive response to the well's declining injectivity. WELL STATUS: BRWD-1 is used for injection as needed to dispose of produced water. Last Tag: Fill @ 3493' RKB - 6/21/92 with 1.5" bailer. NOTE: Fill depth @ 3483' MD by tie-in w/ DIL, CET, and 10/4/87 perf log - see schematic. PBTD at 3525' RKB Pressures: TP: 1400-1600 psi when injecting PC: 0 psi SC: 0 psi Tubing size: 2-3/8" Casing size: 7" Min. ID: 2.205" CXN" nipple @ 3146' MD) PERFORATION DATA; Tie-in Log: 5/24/86 Schlumberger CET (CET is on depth with DIL) DIL: 5/21/86 Schlumberger (5") Interval (MD-CET) Interval (MD-DIL) ~ SPF 3448-3478 3448-3478 30 6 3408-3422 3408-3422 1 4 6 3346-3356 3346-3356 1 0 6 331 6-3346 3316-3346 30 6 3286-331 6 3286-3316 30 6 114 NOTES: All intervals to be shot with 2 1/8" DynaStar strip guns. Run #1 (re-perfs top 30' of existing interval) allows 5' between bottom shot & top of fill Run #2 intervals combined using select fire. RECEIVED d U L - B 1992 Alaska Oil & Gas Cons. Commission Anchorage Re-perforating Procedure 1. Record SITP on WSR. Hold safety meeting with all personnel involved and obtain detail diagram of tools to be mn in the well. . Rig-up electric line unit and lubricator. Make-up tool string of adequate weight bars, perforating guns, decentralizer and CCL. Turn off radios, phones and electric welders before arming perforating guns. These may be returned to service at the discretion of the wireline supervisor. 4. Pressure test lubricator to 1500 psi per wireline supervisors instructions. , . , RIH with well shut-in at wing valve and tie-in with CET log (depths in bold print). Note: Prior peff tie-ins show packer & robing tail 10' shallower than schematic depths. Park gun at proper depth and fire. After shooting, log out to at least one tubing collar above the packer to document location of tubing tail & packer. POOH and turn off radios, phones and electric welders before reaching the surface. Check gun and record depths of any misfires. Repeat the gun run if necessary. 8. Make up next gun and repeat steps 5 through 7 for the runs listed. 9. Rig-down electric line unit and lubricator. ,ARCO Alaska, Inc. . I-BRWD- 1 Spua Date: 5/14/86 Last Compl: ' 5/28186 Schematic Rev: 3/20/89 SEII4NEI/4 Sec. 13,T13N L R10W, SM Beluq River Unit APi~. 283-2007~ Original RKB (Depth Ret): 88' Grouncl Level: 70" Maximum Hole Angle: 1 3/4° Angle at Perforations: 1° Well Type: Water Disposal Annulus Fiuicl: Dieset ToD of Sterling: N IA ASTM: Single String Jewelry 1 1&9 0.75' 2 3134" 4.8~ 3 3134"~' 5.30" 4 3139' .78' 5 3140' 5.30" 6 3145' .75' 7 3146'~' 1.02" WKM U-EN Tubing Hanger 2.323' Hugl~s CL Locator W/4 Seal Units* 2.375' 3,25" 7" I-B Hugt~s Packer 3.250" 5.75" X-Over 4" x 4 1/2" 3.920" 5~0' Millout Extension 3.920" 4,50" X-Over 4 1/2" x 2 7/8" 2.441" 5.00" 2 7/8" 'XN" Nipple 2.205" 3.00" · Locator~s entire length runs through packer Casing en~l TUb~g Conauctor 20' 94~ H-40 Plain Ena 96" Surface 9 5/8' 43.5t AL-95 BTC 904' Surface 9 5/8" 40~ N-80 BTC 1729' Surface 9 5/8" 47~ r~s-95 BTC 2000' Procluctton Csg 7" 29~ P-110 BTC 3554' Tubing 2 7/8' 6.5~ N-80 ELIE-SED 3147' Perforcltions Upper ~ Sterling 3286'-3356" 16SPF 70' Open (Pre-A) 3408'-3422' 16SPF 14' Open 3448'-3502' 16SPF 54' Open · Oflginally 12 SPF. reperforatea after CTU clean out w/4 SPF 10/4&7/87. Note: Slickline overshot w/fishing neck ( 1.91" OD x 1.5') left on bottom 10/5/87. 10/2/89 1.5" bailer 3524' RKB 10/30/90 1.8' gauge ring 3488' RKB 5/6/91 1.5" bailer ~494' RKB E-Line BOPE's Grease Head/ Hydraulic Packoff ~-- Lubricator Extension Manual Rams Swab Valve Double Maste:r Valves Wellhead ARCO Alaska, Inc.~[' Post Office Bo:(' ~u0360 Anchorage, Alaska 99510-0360 Telephone 9(17 276 1215 Cook Inle~ Engineering December 19, 1991 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Subsequent Report for BRWD-1 Mechanical Integrity Test. Dear Mr. Smith: On 10/16/91 ARCO Alaska Inc. completed a Mechanical Integrity Test on BRWD-1, to comply with UIC Rule No. 6, to test tubing-production casing integrity. Enclosed is the Report of Sundry Operations, MIT test results, a Well Service Report and a well schematic for BRWD-1 for reference. If you require any further information in this regard, please do not hesitate to call Rowland T. Burno at 263-4145. Sincerely, ~'"'~-~ ,<7 J. C. Winn JCW:DRH:czm:0010 Attachment R£C£1V D CC: Mr. C. Kidwell Mr. D. San ti Shell Western E&P, Inc. Chevron U.S.A., Inc. DEC 2 ? 19°A ~[ & Gas Cons. Commlssle~ ,. Anchorage ARCO Alaska, Inc. Is a Subsidiary of Atlantic Richfield Company i" STATE OF ALASKA ALASKA OIL AND 6AS CONSERVATION COMHISSION REPORT OF SUNDRY WELL OPERATIONS Type of Request: OperationShutdown~ Stimulate Plugging . Pull tubing.~ Alter casing ~ Repair well~ 2. Name of Operator ARCO Alask~l, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1936' FNL, 159' FEL, Sec. 13, T13N, R1OW, SM At top of productive interval Straight Hole At effective depth $. Type of Well: Development __ Exploratory __ Stratigraphic ~ Service X At total depth 12. Present well condition summary Total Depth: measured true vertical 3525' feet 3525' feet Plugs (measured) Perforate Pull tubing__ Other MIT 6. Datum elevation (DF or KB) 88' KB feet 7. Unit or Property name Beluga River Unit , 8. Well number BRWD- 1 9. Permi_t n.umber/approval number 10. APl number 50-283-20078-00 11. Field/Pool Beluga River-Sterl Effective depth: measured 3525' feet true vertical 3525' feet Junk (measured) 13. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Current: Current: Length Size Cemented 76' 20" Driven 1980' 9-5/8" 2000'-surf 3536' 7" 3554'-surf measured 3286-3356',3408'-3422',3448'-3502 MD true vertical 3286'-3356';3408'-3422',3448'-3502' TVD Tubing (size, grade, and measured depth) 2-7/8", N-80 6.5~ @ 3147'MD Packers and SSSV (type and measured depth) Packer 3134' MD Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Measured depth True vertical depth 98' MD 98' TVD 2000' MD 2000' TVD 3554' MD 3554' TVD N/A RECEIV i) DEC l 19 J1 Alaska Oil & Gas Cons. Anchorage 14. ReDresentative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 200-400bbls per mnth 1200-1500psi Subsequent to operation 200-400bbls per mnth 1200-1500psi 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sicjned ..... .. ~c~.~.~._~,_,.,.~ Title Cook Inlet Reqional Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE 1 OIL ~ ~P~ CDI~ERVA1rl011 CONqI'S~ION HECH~ICAL ]NI~'I~ITY 'I~T Z *III~INI:; IN,,"[L'IlON FLUID: P = PRODUCE I~AIER 5: SALT ~AT/R P, = HISCIBL[ I '- II~ECT1NG N = NOT I~NJECTIN~ (rev 05/10/901 ANNULAR FLUID: DIESEL GLYCOL SALT ~AT~ DRILLING HUD OTHER OTHER GRAD 1E.NT: ~ELL TY.~T: '-inittll'' )t-~lr X llorkov,r. Explein AOGCC IITNES5 Sl(;llfillJli[ (1)HPANY AP $ l CNATURE L4 SEP-22-'91 11:27 BELUGA ARCO Alaska, Inc. Sub~idilty of Atl~ntte Ri¢l~fl~l¢l Complm¥ TEL NO: WELL SERVICE REPORT I PBDT ~'~.'1~ - DISTRICT- STATE ]DAYS !DATE ............ CONTRACTOR ' ' IOPERATION AT REPORT;lIME ......... REMARKS ...... I-"] CHECK THIS BLOCK tF SUMMARY CONTINUED ON BACK We,th,rR,oort iTemp' ,,. } Chill Flm°r I Vlilblllty.= __,,.. Iwind vel' ,.__,. ISIgned ARCO Alaska, Inc. BelL' River Unit Well BRU BRWD#1_ Spud Date: 5/86 ~)riginal RKB: 88' Top of Sterling: N/A Annulus Fluid: Diesel APl#: 283-2C]07~ Completion Date: 5/86 Ground Level: 70' Maximum Hole Angle: 0 Last Revised: 3-20-89 All Depths are RKB MD to Top of Equipment. 4 5 Jeweler 1 15.9 0.75' 2 3129 4.80' 3 3134' 5.30' 4 3135' .78' 5 3140' 5.30' 6 3141' .75' 7 3142' 1.02' Casing and Tubing Well Type: Water Disposal New I~! Workover i-I RKB to Hanger: 15.9' Angle at Perforations: 0° Reason: WKM U-EN Tubing Hanger Hughs CL Locator W/4 Seal Units 7" I-B Hughs Packer X-Over 4' x 4 1/2" Millout Extension X-Over 4 1/2" x 2 7/8" 2 7/8" "XN" Nipple PBTD= 3525' 20" 94# H-40 ' 9 5/8" 4C~ N-80 9 5/8' 43.5~ AL-95 9 5/8" 47# RS-95 7" 29~ P- 110 BTC 2 7/8" 6.5~ N-80 8RD Perforations Sterling 2.3" 2.3" 2.441' 2.205' 96' Conductor Surface Casing Surface Casing 2C][X7 Surface Casing 3554' Production Casing 3147" Production Tubing 3286'-3356' 12 SPF 3408'-3422" 12SPF 3448'-3502' 12 SPF perforations 70' 14' 54' J. B3/89 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging_ Time extension _ Stimulate __ Pull tubing _ Variance _ Perforate __ Other X (MIT) 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1936' FNL, 159' FEL, Sec. 13, T13N, RI OW, SM At top of productive interval Straight Hole At effective depth At total depth 12. Present well condition summary Total Depth: measured true vertical 3,525 feet Plugs (measured) 3,525 feet Effective depth: measured 3,525 feet Junk (measured) true vertical 3,525 feet Casing Length Size Cemented Structural Conductor 76' 2 0" D riven Surface 1 980' 9-5/8" 2000'-surf Intermediate Production 3536' 7" 3554'-surf Liner (combination casing) Perforation depth: measured Current: 3286-3356'; 3408-3422'; 3448-3502' MD, 12 SPF true vertical Current: 3286-3356'; 3408-3422'; 3448-3502' TVD, 12 SPF Tubing (size, grade, and measured depth 2-7/8", N-80, 6.5# @ 3147' MD Packers and SSSV (type and measured depth) Packer 3134' MD 6. Datum elevation (DF or KB) 88' KB 7. Unit or Property name Beluga River Unit feet 8. Well number BRWD-1 9. Permit number 10. APl number 50-283-2007~-00 11. Field/Pool Beluga River/Sterlin[t None Measured depth True vertical depth 98' MD 98' TVD 2000' MD 2000' TVD 3554' MD 3554' TVD RECEIVED S EP 1 G 1991 Alaska 0ii & Gas Cons. C0mm~ss~et~ Anchorage 13. A~achments · Description summary of proposal Detailed operation program X BOP sketch 14. Estimated date for commencing operation September, 1991 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Suspended Service ..X (Water Disposal) 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned '~~~ Title Cook Inlet Re~lional En~]r. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance m Mechanical Integrity Test x~' Subsequent form require Approved by the order of the Commission Form 10-403 Rev 5/03/89 ORIGINAL SIGNED By LONNIE C. SMITH 10- ~"/.~, ~t. -~pproved Copy Returned Commissioner Date c/_ j ~. ~ [ SUBMIT IN TRIPLICATE JApproval No. Alaska, Inc.~'{[' ARCO Post Office Box ~00360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering September 9, 1991 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Submittal of Application for Sundry Approval for BRWD- 1 Mechanical Integrity Test Dear Mr. Smith: Attached is an Application for Sundry Approval for a Mechanical Integrity Test on BRWD-1, to comply with UIC Rule No. 6, to test tubing-production casing integrity. Also, a proposed operations plan and well schematic for BRWD-1 are included for reference. If you require any further information in this regard, please do not hesitate to call Rowland T. Burno at 263-4145. Sincerely, T. Wellman TW:DRH:czm:0129 Attachment CC: Mr. C. Kidwell Mr. D. San ti Shell Western E&P, Inc. Chevron U.S.A., Inc. RECEIVED S EP 1 6 1991 Alaska Oil & Gas Cons. CommiSsion Anchorage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company 27 O T, O. S&M) T.D. T.O, U.S. SURVEY 3sg6 35 U.S. SURVEY 3ge3 SURVEY 3902 12 ALASKA ENEIqG~ T.D, 3MO' UkltON T,D. IMO' 0 Z?Z-ZS T,D, SIOO 224-I3 o T.D, t&~O' - ,' _ "~"'~BELUGA RIVER UNIT T13N R10W T13N Rgw - - TI2N RIOW-T12W Rg-W RECEIVED - S E P 1 6 Alaska Oil .& Gas Cons.' Oommiss[e~ Anchorage 11 _J OVERLAY ARCO Alaska, Inc. UPPER COOK INLET BELUGA RIVER UNIT Well BRWD- 1 Procedure #BR 13 Mechanical Integrity Test [MIT) Objective Complete mechanical integrity test of the well. Current Status BRWD-1 is on water injection. Minimum Restriction: 2.205" "XN' Nipple in 2-7/8" tubing. LastTag: 3494' MD (5/91) Annulus Fluid: Diesel Packer depth: 3134' MD Procedure Prior to Testinq 1. Contact Anchorage Office to Verify Sundry Approval and notify the State 24 hours prior to MIT. 2. Assure that 20 bbls of diesel is on location. Mechanical Inteqrit~ Test (MIT} . Conduct safety meeting with the field foreman, # 1 operator, AAI wireline supervisor, AOGCC witness and service company personnel. The service company personnel will review the MIT procedure prior to commencing the test. 2. MIRU pump unit and vac truck to production casing annulus. 3. Pressure test lines to 2000 psi. ~z~ 4. Pump diesel into PC to slowly pressure annulus up to 1500 psi. Record PC initial pressure and SITP. It is estimated that approximately 1-2 bbls of diesel will be needed. 5. Monitor PC and SITp for 30 minutes while recording pressures in 5 minute intervals. . If PC drops below 1350 psi (10% loss) within the 30 minute interval, go back to step #3 and repeat. If test continues to fail, please notify the Anchorage office and production supervisor in Kenai. 7. RD. Return well to service. RECEIVED SEP 1 6 19'91 oo 6/ m Alaska Oil & Gas Cons. Cornmissi°~ugust 29, 1991 Anchorage ARCO Alaska, Inc. BelL' 1 River Unit Well BRU BRWD#1 Spud Date: 5/86 ~)riginal RKB: 88' Top of Sterling: N/A Annulus Fluid: Diesel All Depths are RKB MD to Top of Equipment, 2 3 4 5 6 7 E APl#: 283-2007~ Completion Date: 5/86 Ground Level: 70' Maximum Hole Angle: 0 Last Revised: 3-2[]-89 Jewel~ 1 15.9 0.75' 2 3129' 4.80' 3 3134' 5.3(]' 4 3135' .78* 5 314~ 5.30" 6 3141' .75' 7 3142" 1.02' Casing and Tubing PBTD= 3525' Well Type: Water Disposal New I~ Workover I-1 RKB to Hanger: 15.9' Angle at Perforations: 0° Reason: WKM U-EN Tubing Hanger Hughs CL Locator W/4 Seal Units 7" I-B Hughs Packer X-Over4" x 4 1/2" Millout Extension X-Over 4 1/2" x 2 7/8" 2 7/8" "XN" Nipple 20" 94# H-40 9 5/8" 40~ N-80 9 5/8" 4,3.5~ AL-95 9 5/8' 47# RS-95 7" 29.~ P- 110 BTC 2 7/8" 6.5~ N..80 81~D Perforations Sterling 2.3" 2.3" 2.441" 2.205" 96' Conductor Surface Casing Surface Casing 20[~ Surface Casing 3554' Production Casing 3147' Production Tubing 3286'-3356' 12 SPF 3408'-3422' 12 SPF ~4s3'-~ 12 SPF: 70' 14" 54' RECEIVED S E P t 6 '~,:~r~, J~la's.[a ~oil ,& Gas Corls. tomrnissio~', Anchorage ,JU~3/89 A~ STATE OF ALASKA "' ~..$KA OIL AND GAS CONSERVATION COMI~,,~.SION OPERATIONS REPORT OF SUNDRY WELL 1. Operations performed: Operation shutdown I Stimulate ~ Plugging __ Pull tubing __ Alter casing __ Repair well __ Perforate ~ Pull tubing __ Other __ 2. Name of Operator ! 5. Type of Well: Development __ ARCO A I aska, I nco Exploratory__ 3. Address Stratigraphic __ P.O. Box 100360 Anchorage, AK 99510 Bisposal Service.~_ 13, T13N, RIOW, SM 4. ~cationofwell~surface · 1936' ENL. 159.'.F~L Sec. ~p of proaucuve interval ' Same as above. ~effectivedepth Same as above. ~totaldepth Same as above. 6. D~umelevation(DForKB) GL=70', KB=88' Z UnitorPropedyname Beluga River Unit feet 8. Well number BRWD- 1 9. Permit number/approval number / ¢'- 10. APl number 50--283-20078 11. Field/Pool Beluga River- undefine~ 12. Present well condition summary Total depth: measured Dr i I led trueverticat Effective depth: measured ( PBTD ) true vertical 3560 ~et 3560 feet 3525 feet 3525 feet Plugs (measured) Junk (measured) Casing Length Conductor 76' Surface 1,980 ' Production 3,536 ' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 2-7/8", 6.5//, N-80 Packers and SSSV (type and measured depth) Packer 3134' Size 20" 9-5/8"' 7" Cemented driven 2,000'-surf 3,554'-suer TVD 3502 - 3448' 3422- 3408' 3356 - 3286' Measureddepth 98' 2,000' 3,554' ~ueve~icaldepth 98' 2,000' 3,554' Length 54 14 70 Density 16 SPF 16 SPF 16 SPF ECE YE 13. Stimulation or cement squeeze summary Mud acid stimulation to increase Intervals treated (measu red) injection capacity. Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification aS: Oil __ Gas __ Suspended __ ServiceProd. Water Dispos 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sicjned ~,/(~,~ Title Cook Inlet Engineering Manager Date /d//.../. ~)Z~.? Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE BRU BRWD-1 Mud Acid Stimulation Treatment description: STEP VOLUME 1. 30 BBLS 2. 36 BBLS 3. 48 BBLS 4. 12 BBLS 5. 30 BBLS FLUID 2% NH4CL water 10 % HCL w/additives 10 % HCL- 1.5% HF w/additives 10 % HCL w/additives 2% NH4CL water w/10% mutual solvent, 1% clay stabilizer REC'E'JV'ED OCT 2 ,~.~ 1989 Alaska Oil & Gas Cons. Commission Anchorage Alaska, Inc. River Unit YY_e BRU BRWD 'pud Date: 5/86 Original RKB: 88" Top of Sterling: N/A Annulus Fluid: Diesel APl#: 283-~7~ Completion Date: 5/86 Ground Level: 70' Maximum Hole Angle: 0° Last Revised: 3-20-89 All Depths are RKB MD to Top of Equipment. 1 15.9 0.75' 2 3129' 4.80' 3 3134' 5.30' 4 3135' .78" 5 314(7 5.30" 4~ ~, 6 3141' .75' 7 3142' 1.02" Well Type: Water Disposal New I~ Workover E] RKB to Hanger: 15.(Y Angle at Perforations: 0o Reason: WKM U-EN Tubing Hanger Hughs CL Locator W/4 Seal Units 7" I-B Hughs Packer X-Over 4" x 4 1/2" Millout Extension X-Over 4 1/2" x 2 7/8" 2 7/8" "XN" Nipple 2.3' 2.3' 2.441" 2.205" 2 3 4 5 6 7 Casing and Tubing 20" 94# H-40 9 5/8" 40~ N-80 9 5/8" 43.5~ AL-95 9 5/8" 47# RS-95 7' 29# P- 110 BTC 2 7/8" 6.5~ N-80 8r'~D Perforations Sterling PBTD= 3525' 3286'-3356' 12 SPF 3408'-3422' 12 SPI: 3448'-35[]2. 12SPF 96' Conductor Surface Casing Surface Casing 2G317 Surface Casing 3554" Production Casing 3147' Production Tubing 70' 14" 54' TD= 356O' ,.LB 3/89 E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension Manual Rams Swab Valve Double Maste~ Valves Wellhead ARCO Alaska, In( Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 T. Stewart McCorkle Engineering Manager Cook Inlet/New Ventures September 22, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: Sundry Notice for BRWD # 1 Dear Mr. Dygas: Attached is an Application for Sundry Approval for a mud acid stimulation on the Beluga River Unit Water Disposal well, BRWD #1. With your approval, we would like to begin this work by October 1, 1989. If you have any questions, please contact Scott Wilson at 263-4144. Sincerely, T. S. McCorkle TSM:SJW:ch:0020 Attachments RECEIVED SEP 2 989 Alaska Oil & ~as Cons. Cor~rnisslOr~- Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6279 STATE OF ALASKA ~ ~",,, , ._ASKA OIL AND GAS CONSERVATION CO ,$SION APPLICATION FOR SUNDRY APPROVALS OR 16 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate ..~ Pull tubing ~ Variance ~ Perforate ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510 FEL, Sec. 13, 5. Type of Well: Development __ Exploratory ~ Stratigraphic __ D i sposa I Service._~ 4. Location of well at surface 1936' FNL and 159' At top of productive interval Same as above. At effective depth Same as above. At total depth Same as above. T13N, RIOW, SM 6. Datumelevation(DForKB) GL = 70' KB = 88' Z UnitorPropertyname Beluga River Unit 8. Wellnumber BRWD-1 9. Permit number 86-9 10. APl number 50-- 283-20078 11. Field/Pool Beluga River feet 12. Present well condition summary Total depth: measured (Drilled) true vertical Effective depth: measured ( PBTD ) true vertical Casing Conductor Surface Production ~ngth 76' 1980' 3536' Perforation depth: measured 3560 3560 3525 3525 Size 20" 9'5/8" 7" true vertical ~bing(size, grade, and measureddepth) 2-7/8, 6.5#, N-80 Pac~rsandSSSV(typeandmeasureddeCh) Packer 3134' feet feet feet feet Plugs (measured) Junk (measured) Cemented Measured depth RECEIVED SEP 2 5 989 Alaska 0il & (~as Cons. C0mmiss Tr ueA~§~.~tli~ pth Driven 98' 98' 2000'-surf 2000' 2000' 3554'-surf 3554' 3554' TVD-MD Length Density 3502-3448' 54 16 SPF 3422-3408' 14 16 SPF 3356-3286' 70 16 SPF 13. Attachments Description summary of proposal ~X Detailed operations program __ BOP sketch __X 14. Estimated date for commencing oPeration October, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ SuSpended __ Service Produced Water Disposal 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~.~ Title Cook In let Engineer ing FOR COMMISSION USE ONLY Manager Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commissioner ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner lAppr°val N°' ~-, ,~ ~ Approved Copy Returned Date FOrm 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE BRWD #1 Stimulation Procedure PROCEDURE: Safety/Regulatory: 1) Ensure that an approved Sundry has been obtained prior to starting the job. 2) Hold Safety meeting and locate a f'n:e extinguisher at the well. 3) Pressure test all lines to 2500 psi prior to pumping. Mud Acid Stimulation 4) 5) 6) 7) 8) 9) Ster~ 1) 2) 3) 4) 5) Observe acid titration on location to ensure proper acid concentration. MIRU stimulation company. Install recording pressure gauge on the tubing and PC annulus. Flush clean pump skid and lines. Roll each acid compartment before pumping starts. Pressure test lines to 2,500 psi. Pump the following fluids at less than 1 BPM and 1000 psi surface pressure. Volum~ 30 Bbls 1500 gals 2000 gals 500 gals 30 Bbls Fluid 2% NH4C1 water 10% HC1 with additives 10% HC1 - 1.5 % HF with additives 10% HCL with additives 2% NH4C1 water w/10% mutual solvent, 1% clay stabilizer. 10) Immediately begin disposal of 0.5% KC1 (2#/Bbl) weighted produced water. RECE i'V'ED SEP 2 ~.-; 1989 Alask:~ Oil .& Gas Cons. Corrlmissio~ Ai',,chora..q.e. ,~, AJ~CO Alaska, Inc. I~ uga River Unit Well_ J~RU BRWD# 1 'pud Date: 5/86 Original RKB: 88" Top of Sterling: N/A Annulus Fluid: Diesel APl#: 283-~7~ Completion Date: 5/86 Ground Level: 70' Maximum Hole Angle: 0° Last Revised: 3-20-89 All Depths are RKB MD to Top of Equipment. E Jeweler 1 15.9 0.75' 2 312~ 4.80' 3 3134' 5.30' 4 3135' .78' 5 3140' 5.30' 6 3141" .75' 7 3142' 1.02' Casing and Tubing Well Type: Water Disposal New I~l Workover I-I RKB to Hanger: 15.9" Angle at Perforations: 0° Reason: WKM U-EN Tubing Hanger Hughs CL Locator W/4 Seal Units 7" I-B Hughs Packer X-Over 4" x 4 1/2" Millout Extension X-Over 4 1/2" x 2 7/8" 2 7/8" "XN" Nipple PBTD= 3525' TD= 3560' 20" 94# H-40 9 5/8" 40~ N-80 9 5/8" 43.5~ AL-95 9 5/8" 47# RS-95 7" 29# P- 110 BTC 2 7/8" 6.5-~ N-80 8RD Perforations Sterling i.D. 2.3" 2.3" 2.441" 2.205" 96' Conductor Surface Casing Surface Casing 2g~ Surface Casing 3554' Production Casing 3147' Production Tubing J~ Density 3286'-3356' 12 SPF 3408'-3422' 12 SPF 3448'-3502' 12 SPF 70' 14' 54' JI.B 3/89 E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension Manual Rams Swab Valve Double Maste~ Valves Wellhead ARCO Alaska, Inc.~, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 T. Stewart McCorkle Engineering Manager Cook Inlet/New Ventures May 19, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ~.~L~u~for BRWD #1 [~i Dear Mrr. Dygas'as:_.] ? ~ched is an Application for Sundry Approval for a tubing and perforation wash on the Beluga River Unit Water Disposal well, BRWD #1. With your approval, we would like to begin this work as soon as possible. If you have any questions, please contact Scott Wilson at 263-4144. Sincerely, T. S. McCorkle TSM: SJW: ch:0014 Attachments , ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6279 " STATE OF ALASKA I~,..,ON ALL,.,KA OIL AND GAS CONSERVATION COMM APPLICATION FOR SUNDRY APPROVALS 1: Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ 2. NameofOperator ARCO Alaska, Inc. &Address Post Office Box 100360 Anch., AK 4. ~cationofwellatsudace 1936' FNL and 159' ~topofproductiveinterval Same as above. Ateffectivedepth Same as above. ~totaldepth Same as above. FEL, Sec. 13, T13N, Operation shutdown ~ Re-enter suspended well __ Plugging ~ Time extension __ Stimulate X Pull tubing __ Variance ~ Perforate __ Other 5. Type of Well: Development Exploratory Stratigraphic D i sposa IService RIOW, SM 6. Datumelevation(DForKB) GL = 70' KB = 88' UnitorPropertyname Beluga River Unit 8. Wellnumber BRWD-1 9. Permit number 86-9 10. APl number 50-- 283-20078 11. Field/Pool Beluga River . feet 12. Present well condition summary Total depth: measured (Dr i I led) true vertical 3560 feet 3560 feet Plugs (measured) Effective depth: ( PBTD ) Casing Conductor Surface I~t~~ Production Perforation depth: measured true vertical Length 76' 1980' 3536' measured 3525 feet 3525 feet Size 20" 9-5/8" 7,1 true vertical ~bing(size, grade, and measureddepth) 2-7/8, 6.5#, N-80 PackersandSSSV(typeandmeasureddepth) Packer 3134' Junk (measured) Cemented Measured depth True vertical depth Driven 98' 98' 2000'-surf 2000' 2000' 3554'-surf 3554' 3554' 'TVD-MD Length 3502 ' -3448 ' 54 3422 ' -3408 ' 14 Density 16 SPF 16 SPF 16 SPF 13. Attachments 14. Estimated date for commencing operation May, 1989 Description summary of proPosal X 15. Status of well classification as: Date approved 16. If proposal was verbally approved Name of approver BOP sketch X Oil __ Gas_ Suspended __ Service Produced Water Disposal 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,¢~.,~, /~¢,z~ Title Cook In let Engineer lng Mgr. Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance __ Mechanical Integrity Test_ Subsequent form required 10- Approved by order of the Commissioner ,~;,',~,NAL SIGNED ~':~t CONNIE C. SMITH Date Heturne(I Commissioner Date .~"'" / ~ ~ suBMIT IN TRIPL~'ICATE FOrm 10-403 Rev 06/15/88 Attachment #1 i Description summary of proposal BRWD-1 Acid Wash Procedure 1) Confu'm that a fu:e extinguisher is on location and functional. Have 2 sacks of potash (KOH) on hand to neutralize any spilled or unused acid. 2) Titrate acid to determine concentration. If acid is not 15 % HC1 + 2 %, consult Engineering. 3) Rig up a recording pressure gauge to the injection line as close to the wellhead as is possible. 4) Pump two tubing volumes (36 bbl) produced water at ~-0.5 bpm to determine baseline injection characteristics and test pumping equipment. 5) Pump +5 bbl acid at 0.5 bpm. 6) Displace at 0.5 bpm with 18 bbl saline produced water. 7) Immediately begin disposal of produced fluids. ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company AR3B-6001-A Belu~,: River Unit Well BRU BRWD# Spud Date: 5/86 Original RKB' 88' Top of Sterling' N/A Annulus Fluid: Diesel APl#: 283-~78~ Completion Date: Ground Level: 70' 5/86 Maximum Hole Angle: 0~ Last Revised: 3-20-89 Well Type: Water Disposal New i~1 Workover i-I RKB to Hanger: 15.9' Angle at Perforations: 0° Reason: All Depths are RKB MD to Top of Equipment. 1 Ill ,4 2 3 4 5 6 7 [ r r r r L Jewelry Deoth Lenath 1 15.9 0.75' 2 3129' 4.80' 3 3134' 5.30' 4 3135' .78' 5 3140' 5.30' 6 3141' .75' 7 3142' 1.02' Casing and Tubing Size Weiaht 20" 94# 9 5/8" 40~ 9 5/8" 43.5# 9 5/8" 47# 7" 29# 2 7/8" . 6.5# Perforations Sterling PBTD= 3525' TD= 3560' WKM U-EN Tubing Hanger Hughs CL Locator W/4 Seal Units 7" I-B Hughs Packer X-Over4" x 4 1/2" Millout Extension X-Over 4 1/2" x 2 7/8" 2 7/8" "XH" Nipple I.D. Grade Thread H-40 N-80 AL-95 RS-95 P-110 BTC N-80 8RD Bottom 96' Conductor 2CO0' Surface Casing 2Q~' Surface Casing 2Q30' Surface Casing 3554' Production Casing 3147' Production Tubing 3286'-3356' 3408'-3422' 3448'-3502' Density - Perforations 70' 14' 54' JLB 3/89 E-Line BOPE's L Grease Head/ Hydraulic Packoff Lubricator Extension Manual Rams Swab Valve Double Master Valves Wellhead ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 13, 1988 Mr. Steve Planchon Cook Inlet Region Inc. P. O. Box 93330 Anchorage, AK 99509 Mr. James Eason Alaska Department of Natural Resources Division of Oil and Gas P. O. Box 107034 Anchorage, AK 99510-7034 Mr. Chat Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Anchorage, AK 99501 Re: Disposal of PCU and LRU class II produced Water in the BRWD-1 Disposal Well Gentlemen: Unocal has requested that it be allowed to dispose of not more than 700 barrels of produced water in the BRWD-1 disposal well. The fluids were generated in connection with production operations of the PCU #2 well and the LRU C-1 well. Unocal has certified that the fluids meet the qualifications for Class II disposal and the BRWD-1 well is currently approved for such disposal. The Beluga River Unit Owners are willing to accept such fluids on a one- time only basis if Unocal will make a cash payment to reimburse them for the operating and .maintenance costs associated with this disposal activity and agree to indemnify them from injury. Acceptance is also condition- ed upon receipt of written approval from.AOGCC, DOG (as the Lessor) and CIRI (as the surface owner). The BRU WIO's and Unocal will enter into an agreement in substantially the same form as the attached draft to control the operation. Unocal's need for disposal is urgent and we respectfully request that your agency/company review this request and advise of your comments and/or approval at your earliest convenience. If this operation meets with your approval, please so indicate by signing in the space provided below ARCO Alaska. Inc, is a Subsidiary of AllanticRichfieldCom~)anV CIRI/ADNR/AOGCC June 13, 1988 Page 2 and return one copy to the attention of the undersigned. Please call me at 265-6834 should you have any questions on this matter. Yours very truly, J. Patrick Foley Senior Landman JPF: 195:18 cc: Kevin Tabler, Unocal F. E. stacey, Shell Tom Pixton, Chevron The.~njection operati~on~r~posed herein is approved this /~/~_-~day of ~ ~-~ ~,~,~_~-_, 1988. Name: Agency / Company: ~~~ ~ Y ~ ~ ~.=~m~~ ~ Disposal Injection Order No. 3 March 11, 1987 Page 3 DONE at Anchorage, Alaska and dated March 11, 1987. C. V. Chatterton, /Chairman Alaska Oil and Gas Conservation Commission Lonnie C. Smi~ , Commissioner Alaska Oil and Gas Conservation Commission W. W. Barnwell, Commissioner Alaska Oil and Gas Conservation Commission' ARCO ALASKA, INC. Cook Inlet/New Ventures Engineering LOG TRANSMITTAL TO: ~,m~--Lm->~<_~ ADDRESS' _ ~/~F~~ ~m FROM: DATE: WELL: Please find the following logs enclosed: Blue *** Sepia *** Line Folded Rolled Mylar Tape Receipt Acknowledgment: Return Receipt to: ' ARCO Alaska ~(~ ~ ATTN' Judy o~ e~' ATO--_.! ~ ~,.O,,~ons Commission Pos t Of fi ce Box lOq~,~,a oit ~u~ · Anqhorage, AK 99510 Anchorage STATE OF ALASKA AL r" ~ OIL AND GAS CONSERVATION C(~ '~ISSION REPOR' ' OF SUNDRY WELL RATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other ~ Clean out and reperforate 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510 4. Location of wellatsurface 1936' FNL and 159' FEL sec. Attop of productiveinte~al Same as above Ateffective depth Same as above Attotaldepth Same as above 13, T13N, RIOW, SM 5. Datum elevation(DF orKB) GL = 70' KR = 6. Unit or Property name Beluga River Unit 7. Wellnumber BRWD-1 8. Approval number 9. APl number 50-- 283-20078 10. Pool Belu_aa River Unit Feet 11. Present well condition summary Total depth: measured true vertical (Drilled) Effective depth: measured ( PBTD ) true vertical Casing Length Structural Conductor 76 ' Surface 1980' Intermediate Production 3536' Liner Perforation depth: measured 3560 356O 3525 3525 Size 20" 9-5/8" 7I, ~bing(size, grade and measured depth) 2-7/8", 6.5#, N- 80 Packers and SSSV(type and measured depth) Packer 3134' MD feet feet feet feet Plugs (measured) N()V " Junk (measured) ~,~..~a.. ~ ~ was [;0ns. Comlllissj .-' ~lUU~mge Cemented Measured depth True Vertical depth driven 98' 98' 2000-surf 2000' 2000 3554'-surf 3554' 3554' TVD-MD 3502-3448' 3422-3408 3356-3286' Length Present Density 54 16 SPF 14 ' 16 SPF 70 16 SPF 12. Stimulation or cement squeeze summary Summary: Cleaned out to 3525' MD with coil tubing. Intervsls treated (measured) Treatment description including volumes used and final pressure Reperforated esixting intervals with 4 SPF 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf 14. Attachments Daily Report of Well Operations [] Water-Bbl Casing Pressure 48 bbls/day 0 ~bing Pressure 1160 psi 168 bbls/day 0 1160 psi Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 124-85 Title Enqineering Manaqer Date Submit ir~ 'l~uplicate~_=~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: THE REQUEST OF ARCO ) ALASKA, INC. to dispose) of non-hazardous gas ) field liquid wastes by ) underground injection ) in well BR WD-1, Beluga) River Gas Field ) Disposal Injection Order No. 3 Beluga River Gas Field March 11, 1987 IT APPEARING THAT: · · · ARCO Alaska, Inc. (ARCO) requested on February 6, 1987 the Alaska Oil and Gas Conservation Commission to authorize the continued use of BR WD-1 as a disposal well in the Beluga River Gas Field. ARCO will inject non-hazardous waste fluids generated by normal drilling and production operations. Notice of an opportunity for a public hearing on March 26, 1987 was published in the Anchorage Daily News on February 23, 1987. No protest or request for a public hearing was timely filed. Accordingly, the Commission will, in its discretion, issue an order without a public hearing. FINDINGS: · ARCO, as operator of the Beluga River Gas Field, ~ currently is authorized by EPA permit AK-2D0001-Jf, issued in conformance with the Safe Drinking Water Act as amended 42 USC 300f et seq, to utilize well BR WD-1 for injection of non-ha~-~r~-0-6s liquid wastes into the Sterling formation below the measured depth of 3060 feet. Disposal Injection Order No. 3 March 11, 1987 Page 2 · , · · . · Ail aquifers below 3030 feet within a one-mile radius around the well bore of well BR WD-1 Beluga River Gas Field, are exempted in E.P.A. Permit AK-2D0001-~ for Class II injection activities. ~ Permeable strata, that will accept injected ~fluids, are present below 3060 feet in well BR WD-1. A series of confining strata are present above 3060 feet in well BR WD-1 that will prevent upward movement of the injected waste fluids into non-exempt aquifers. The strata into which fluids are to be injected will accept fluids at injection pressures which are less than the fracture pressure of the injection strata and their confining formations. ~ To ensure that waste fluids are confined to injection strata, the mechanical integrity of BR WD-1 will be demonstrated per'iodically and monitored routinely for disclosure of possible abnormalities in operating conditions. BR WD-1 is constructed and has been tested in con- formance with the requirements of 20 AAC 25.412. 'CONCLUSIONS: The geologic sequence present at the well site and maintenance of the mechanical integrity of well BR WD-1 will prevent movement of injected waste fluids into non-exempt aquifers. NOW, THEREFORE, IT IS ORDERED THAT: Non-hazardous oil field waste fluids may be injected in conformance with Alaska Administrative Code Title 20, Chapter 25, for the purpose of disposal into the Sterling formation below the measured depth of 3060 feet in well BR WD-1, Sec. 13, T13N, R10W, S.M., Beluga River Gas Field. STATE OF ALASKA A{,. ~KA OIL AND GAS CONSERVATION C{ ~MISSlON REPORI- OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other r~ Clean out and r-eperforate 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510 4. Location of well at surface 1936' FNL and 159' FEL sec. At top of productive interval Same as above At effective depth Same as above At total depth Same as above 11. Present well condition summary Total depth: measured 3560 true vertical 3560 13, T13N, RIOW, SM (Drilled) Effective depth: ( PBTD ) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: feet feet Plugs (measured) measured 3525 true vertical 3525 Length Size 5. Datum elevation (DF or KB) GL = 7~)' KR = 6. Unit or Property name Beluqa River Unit 7. Well number BRWD- 1 8. Approval number 9. APl number 50-- 283-20078 Feet 10. Pool e.Lu_Qa River Unit ELi'I V ~lJ feet feet Junk (measured)Alaska Oil & Gas Cons. Commission Anchorage Cemented Measured depth True Vertical depth 76 ' 20" 1980' 9-5/8" driven 98' 98' 2000-surf 2000' 2000 3536' 7" 3554'-surf 3554' 3554' measured Tubing(size, grade and measured depth) 2-7/8", 6.5#, N- 80 Packers and SSSV(type and measured depth) Packer 3134' MD TVD-MD 3502-3448' 3422-3408 3356-3286' Length Present Density 54 16 SPF 14 16 SPF 70 16 SPF 12. Stimulation or cement squeeze summary Summary: Cleaned out to 3525' MD with coil tubing. Intervals treated (measured) Treatment description including volumes used and final pressure Reperforated esixting intervals with 4 SPF 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf 14. Attachments Daily Report of Well Operations [] Water-Bbl Casing Pressure 48 bbls/day 0 ~bing Pressure 1160 psi 168 bbls/day 0 1160 psi Copies of Logs and Surveys Run [] 15. I hereby .certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Title Enqineerinq Manaqer Date Submit in Duplicate C o o i.,: ! r~,; e 't / h', e w t. "e ;~ '[ u r e s En,gin~'-~r~.,~. ~.g September 30, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Commissioner Chatterton- Attached please find our Application for Sundry Approval reperforate BRWD-1. Any questions concerning this work may C. L. Crabtree at 265-6298. H. F. Blacker HFB-CLC:ch'O061 Attachment cc' BRWD-1 Wellfile to cleanout and be addressed to Oil & 8as Cons. Commiss[or~ ~nchorage ARCO Alaska, Inc. is ~ Subsidi,~r~.~ of AttanticRicl~fie]dCornp~]~y STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon F~ Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate ~ Pull tubing [] Amend order E~ Perforate ~ Other 2. Name of Operator AR. CO Alaska, Inc. 3. Address ?. O. Box 100360 Anchorage, AK 99510 4. Location of wellatsurface 1936' FNL and 159' FEL, Sec. 13, T13N, R10W, SM 5. Datum elevation(DF or KB) GL=70' KB=88' 6. Unit or Property name Beluga River Unit 7. Well number BRgrD- 1 At top of productive interval Same as above At effective depth Same a's above At total depth Same as above 8. Permit number 86-9 9. APl number 50-- 283-20078 10. Pool Beluga River - Sterling feet 11. Present well condition summary Total depth: measured (Drilled) true vertical Effective depth: measured (PBTD) true vertical 3560 feet 3560 feet 3525 feet 3525 feet Plugs (measured) Junk (measured) Casing Length Structural Conductor 76 ' Surface 1980' Intermediate Production 3536 ' 'Liner Perforation depth: measured Size Cemented Measured depth 20" 9-5/8" True Vertical depth driven 98' 98' 2000'-surf 2000' 200~' 3554' 3554' 7" 3554'-surf Length Dens. ity TVD-MD ~u~ve~a+ 3502'-3448' 3422'-3408' 3356'-3286' Tubing(size, grade and measured depth) 2-7/8, 6.5#, N-80 Packers and SSSV(type and measured depth) Packer 3134' 54 12 S~ RECEIVED 14 12 SPF 70 12 SPF OCT 0 ! 1987 Alaska 0il & Gas Cons. Commiss[o Anchorage 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation October 2, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby ce. rtify that the .foregoip:g is true and correct to the best of my knowledge Signed ,/~'~//~~ Title Regional Engineer Commission Use Only Conditions of approval Notify commission so ~epresentative may witness Approved by [] Plug integrity Date Form 10-403 Rev 12-1-85 I Approval No. [] BOP Test I-] Location clearance '"~ '~ ' ..... by order of Commissioner the commission Date~ "~/ ~.~ Submit in triplicate BRWD-1 CLEANOUT & REPERFORATE 1. Clean out fill from 3477' to PBTD with coil tubing. 2. Reperforate existing perforated intervals 4 SPF. RECEIVED OCT o 1 1967 Alaska Oil & Gas Cons. Commissio~ Anchorage CLC/O061 ARCO ALASKA, INC. Cook Inlet/New Ventures Engineering TRANSNITTAL TO: Commi s s ioner C,C'F ,Ir~ ~ F,~ v,'~,~'{: AOGCC DATE' 3/5/87 FROM: H.F. Blacker COMPANY' ARCO WELL NAME.BRU BRWD-1 Transmitted herewith are the following- PLEASE NOTE' BL = Blueline, S = Sepia, F = Film, T = Tape, PC = Photocopy The results from deviation surveys run on BRWD-1 ANGLE ' 460 1/2m 915 1/2~ i346 1/4n Iai4 1 1.Z23 2000 1~ 2662 1 3/4~ 250.5 1® Recei pt Acknowledgment' Return Receipt to- ARCO Alaska, in'c. AT. TN' Judy Boegler AT0-579 Po~ Office Box 100360 Anchorage, AK 99510 ARCO ALASKA, INC. Cook Inlet/New Ventures Engineering TRANSHITTAL TO' COMPANY' DATE: COMPANY' WELL N AI,1E: ~~;~/~/'~ Transmitted herewith are the following- PLEASE NOTE- BL = Blueline, S = Sepia, F = Film, T = Tape, PC = Photocopy RECEIVED FEB 2 0 1987 Receipt Acknowledgment' .... ,.. n.'~ ~. Ooe ~nne l'l, nmmis.qJnrl Anchorage Return Receipt to- ARCO Alaska, Inc. ATTN' Judy Boegler AT0~579 Po§{ Office Box 100360 Anchorage, AK 99510 STATE OF ALASKA ALASK,i' ;- AND GAS CONSERVATION (( '4MISSION~1~ [ WELL COMPLET; N OR RECOMPLETIOI r. EPORT AND LOG 1. Status of Well Cias$,ficat,on of Service Well OIL '~ GAS i'~ ~uSPENDED ~ ABANDONED L~ SERVICE Name of OPerator Chevron U.S.A. Inc. - ?.O. Box 107839, Anchorage, AK 99510 ~ .... 7~: ':'~ of ,.~,ed at s~rf3ce I7. Permit Number 86-9 I8 APl Number ,50- 283-20078 I 9. ',Jn,t or Lease Name 1996' S & 159' W of NE Corner Section S13, T13N, RiOW, SB&.M r .:, ='r, ducmg Interval At To:ai Depth same 5'evat,on ,n feet (,nd,cate KB. DF. etc.) G.L. = 70' K.B. -- 88' 17. 6. Lease Oesignat,on ana Serial No. ~ ADL- 58831 Da:e SpuCaea I 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 5-14-86 I 5-21-86 5-26-86 Total Depth (MD+TVD) I I$. Plug Back Depth (MD+TVD) 3560' I 3525' 19. Directional Survey YES [] NO [~ !Beluga River Unit i0. We!l Numoer , BRWD ~.-~1 i11. F~eld and Pool , Beluga River - Sterling 15. Water Depth, if offshore )16. No. of Completions N/A feet MSL 20. Depth where SSSV set 21. Thickness of Permafrost N/A feet MD N/A 22. TYI3e Electric or Other Logs Run DIL/SFL/SP/GK/CAL/CNL/LD:.'//~/VD~/CCL/BHC.,SONI..C/SWS's/TRACER 23. ' CAjS'fNG. LINER AND CEMENTING RECORD ..... S"~'T'T'iNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP I BOTTOM 20" 94 H-40 22'II 96' 9-5/~" 47 RS-95 1,729' 9.000' '...9-5/8". 40 . 'N-8.0 904' ! 1:729' 9-5/8" ! 4~.~ .. AC-.9~ . 20'I 904' 7" 29 P-Il0 18' 3 ~4' , t , 24. :e,'orat~ons open to Production (MD+TVD of Top and Bottom and 3502' - 3448' 54' .51" 648 JS 34'2'~ - 3408' 14' .51" 168 JS 3356' - 3286' 70' .51" 840 JS HOLE SIZE CErvlENTING RECORD .,,Driven 12-1/4" i 800 SK$ "G" f 12-1/4" ], , 1,2-.1/.4" i 8-1/2" !7oo s <s 25. TU'BI NG RECORD , S)ZE . 2-7/8" 26, N/A AMOUNT PULLED SET (,M,D) ; PACKER SET 3~147' i 3 !34' A~ID, :~ACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL IMD) I AMOUNT &"KIND OF MATERIAL USED 27. N/A PRODUCTION TEST .Date First Production IMeth°d °f Operatl°n (Fl°wing' gas lift' etc'). Date of Tes! Hours Tested PRODUCTION FOR OJ L-BBL GAS-MC'~ WATER'-BBL CHOKE SiZE GAS-OIL RATIO 'TEST PERIOD ~ Flow TUbing Casing'Pr. es.sure cALCULATED ej OIL-BBL GAS-MCF WATER-BBL (~'IL'GRAVITY-API (c'o"rr) ~ress. 24-HOUR RATE 28. ' CORE DAT'A ' ' ' · , , , , Brief clescript~on of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. FEB 2 o Alaska Oil & Gas Cons. Commissi,:~:: ' Anch0rarje , Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. Top Sterling GEOLOGIC ,MA IP ~, E RS liMEAS. DEPTH [! TRUE VERT. DEPTH 30. FOR M,~T IC, N TESTS IncluOe ilqterval lesteo, pressure data. all fluids recovered and gravity, GOR, and time of each phase, ?erforated with 400 ?SI underbalance N2 cushion with tub±ng conveyed guns, Open ~,,ell 5/24/86 on &/6'~" choke, and !eft ~,'ell open 2-1/4 hrs. .Maximum fluid rise to !09' and stabilize at 156' 31 L:ST OF ATTACHMENTS I he-eDy certify ~na! the forego~nc ,s true ant correct tO the oes~ of my knowledge /~~~ A~~ Area Operations ~:~ed /~ T,t~e Sumerintendent' I NS'TRUCTIONS ..:eneral' This form is designed for submitting a complete and correct well coml:)letion report and og on ::'i .:ype~ of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam ~njection, 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 Df any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 REPLY TO M/S 409 A'I-rN OF: U.S. Eri RONMENTAL PROTECTION AGEI~i ' REGION 10 1200 SIXTH AVENUE SEATTLE, WASHINGTON 98101 OCT 1 o 198~ M.K. Hauser Acting Area Operations Superintendant Chevron U.S.A Inc. P.O. Box 107839 Anchorage, Alaska 99510 RE: UIC Pemit No. AK-2DO01-I for injection well BAWD-1 at the Beluga Gas Field Dear Mr. Hauser: This is in reference to your October l, 1986, letter updating the operational status of BAWD-1. In accordance with the EPA Permit No. AK-gDO01-I, please submit the enclosed Application to Transfer Pemit (EPA Fora 7520-7) before October 20, 1986. Thank you for keeping us informed. Dick Thiel, Chief' Drinking Water Programs Branch cc: C.V. Chatterton, AOGCC, w/copy of incoming letter. RECEfVED OCT 1 6 1986 Alaska 0ii & Gas Cons, Commission. .Anchorage Chevron U.S.A. Inc. P.O. Box 107839, Anchorage, AK 99510 · Phone (907) 786-6600 RECEIVED OCT 6 1986 EPA-DWPB October 1, 1986 UIC Permit AK-2D001-1 BRWD-1 Acid Jobs Report Transfer of Permit Beluga River Field, A1A-qka RECEIVED Mr. Harold M. Scott U.S. Environmental Protection Agency Region 10 1200 Sixth Avenue Seattle, WA 98101 OCT I 6 1986 Alaska Ofl & Gas Cons, Commission Anchorage Dear Mr. Scott.' Pursuant to your telephone conversation of September 12, 1986 With Ms. Christine Creed and Mr. Jim Arlington of this office, as well as Mr. Jim Ives of ARCO, attached find copies of the acid ]ob information submitted to the AOGCC and an update on the well's status. BRWD-1 was placed on injection July 2_6_,._!.~6,..- Due to low injection rates the weU was acidized on August 7, 1986 u~iJig-2000 gals. of 15% HC1 and 2000 gals. of 12%- 3% mud acid. The well was returned to injection at a rate of 2 bbL/min, with 900 psi tubing pressure. (Prior to acidizing, BRWD-1 was injecting at 1/4 bbl./min. with 900 psi tubing pressure.) This injection rate decreased back to 1/4 bbL/min. at 900 psi tubing pressure within 24 hours. The injection fluid was analyzed and it was recommended to reduce the filtration size from ?0 microns to 3 microns. The new filtration system was put into place in September. The well was reaeidized September 11, 1986 and the well returned to injection at a rate of 1 bbl./min, at a tubing pressure of 100 psi. This injection rate decreased back to 1/4 bbl./min, at 900 psi tubing pressure again within 24 hours. Chevron had planned to run an injectivity test on the well on September 16, 1986, and had received permission from you to do so. However, the test has been delayed due to first, lack of equipment, and then lack of injection fluid volumes. Insufficient injection fluid volumes occur presently to conduct such a test and will Mr. Harold M. Scott U.S. Environmental Protection Agency October 1, 1986 Page 2 likely remain so until the spring of 1987. The test will likely be delayed until that time. ARCO, Inc. takes over operatorship of the Beluga River Field effective October 1, 1986~ Chevron U.S.A. Inc. hereby transfers the above permit to ARCO effective October 1, 1986. M. K. Hauser Acting Area Operations Superintendent CDC:fr Attachments RECEIVED OCT 1.6 1986 Alaska 0{{ & ({as Cons. Commission Anchorage REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ 'Stimulate 13[ Plugging ~ Perforate E3 Pull tubing [] Alter Casing '-.' Other [] 2. Name of Operator Chevron U.S.A. ]nc. 3. Address P.O. Box 107839, Anchorage, Alaska 99510 4. Location of well at surface 1936' S & 159' W of N.E. Corner, Section 13, TI3N, RIOW, SB~M 5. Datum elevation (DF or KB) G.L. = 70' K.B. = 88' 6. Unit or Property name Beluga River Unit 7. Well number BR-WD-1 At top of productive interval Same At effective depth Same At total depth Same 8. Approval number 9. APl number 50-- 283-20078 10. Pool Beluga River - Sterling Feet 11. Present well condition summary Total depth: measured true vertical 3560 feet Plugs (measured) - feet 3525 Effective depth: measured 3525 feet Junk (measured) true vertical - feet Casing Length Size Cemented Structurai - - - Conductor 96' 20",94# Driven Surface, 2000' 9 5/8",40#,47# 800 sks Intermediate - ' - Production 3554' 7", 29# 700 sks Liner - - - Perforation depth: measured 3502'-3448', 3422'-3408', 3356'-3286' Measured depth True Vertical depth · · Perforated 12 SPF true vertical = Tubing (size, grade and measured depth) 2 7/8", 6.5#, N-80 to 3147' Packers and SSSV (type and measured depth) Packer @ 3134 12. Stimulation or cement squeeze summary R£C£1V£D OC~ 1 6 1BBB Alaska 0il & Gas Cons. Commission Artchorn.n.e 13. Intervals treated (measured) 3502'-3448', 3422'-3408', 3356'-3286' Treatment description including volumes used and final pressure 1000 gals ]5% HCI, 2000 gals ]2-3 Mud Acid, 1000 gals 15% HCI, Final Injection pressure 500psi, rate 2} bbls./mln. Representative Dally Average Production or Injection Data Oii-Bbl. Gas-Mcf Water-Bbl Casing Pressure Prior to well operation Subsequent to operation - - 30o o Tubing Pressure IqNO o ~oo 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge ,~'~ ~. Signed ~~ Title Acting Area Operations SuperintendentDate Form 10-404 Rev. 1~-1-85 Submit in Duplicate ALASKA ~'" APPLICATIOi I STATE OF ALASKA ~ID GAS CONSERVATION COMMIS~r' FOR SUNDRY APPROVALS Type of Request: Abandon ~ Suspend ~ Operation Shutdown D Re-enter suspended well [";, Alter casing ~ me extension ?' Change approved program ~ Plugging ~ Stimulate ]~ Pull tubing ~ Amend order ~ Perforate ~.- Other Name of Operator C~hevron U.S.A. Inc. _ Address P.O. Box 107839, Anchorage, Alaska 99510 . Location-of well at surface 1936' S & 159' W of N.E. Corner, Section 13, TI3N, RI0W, SB&M 5. Datum elevation (DF or KB) G.L. = 70' K.B. = 88' 6. Unit or Property name Beluga River Unit 7. Well number BR-WD-I 8. Permit number 86-9 9. APl number 50-- 283-20078 feet At top of productive interval Same At effective depth Same At total depth Same 1. Present well condition summary Total depth: measured true vertical 3560 feet - feet Plugs (measured) 10. Pool Beluga River - Sterling 3525' Effective depth: measured trUe vertical 3525 feet feet Junk (measured) Casing Length Structural _ Conductor 96' Surface 2000' Intermediate - Production 3554 ' Liner Perforation depth: measured Size Cemented 9 5/8",40#-47# 800 sks 7", 29# 700 sks 3502'-3448', 3422'-3408', 3356'-3286' true vertical Measured depth True Vertical depth Perforated 12 SPF. RECEIVED Tubing (size, grade and measured depth) 2 7/8", 6.5#, N-80 to 3147' Packers and SSSV (type and measured depth) Packer @ 3134' OCT 1 6 1986 Alaska 0il & (~as Cons, Corr Anchorage 12.Attachments Description summary of proposal tX Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation 14. If proposal was verbally approved Name Of approver / Date approved 15. I hereby certi, fy~~reg_~oing ts true and correct to the best of my knowledge /~~/'~,'~2.,-----//~~-~'~ Title Acting Area Operations SuperlntendeDate Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test I~ Location clearance I Approved by Commissioner by order of the commission Date ;Ion :orm 10-403 Rev 124-85 Submit in triplicate ,EPA -NAME A~ID ADDRES~ OF EXISTING "E~RMITTEE LOCATE WELL AND OUTUNE UNIT ON SECTION PI.~T -- 640 ACRES W '111"111 --~.1 !. I I, 1-- III I1.1 --TII 'T~T-- --$!! ~1~-- III III I , I I I .. ~ I I I I I i _± I ~ .... L,. I1_ III III --t~~----~~~ __±~J .... L~±_ Ill Ill STATE Form A~ ~d. OMB No. 2000-0042. Approval expires 9-30.86 uNITEI~ STATES ENVIRONMENTAL pROTECTIoR .ENCY " WASHINGTON, DC 20460 APPLICATION TO TRANSFER PERMIT NAME AND ADDRESS OF SURFACE OWNER ICOUNTY I PERMIT NUMBER SURFACE LOCATION DESCRIPTION 'A OF 'A OF ~,4 SECTION TOWNSHIP RANGE LOCATE WELL IN TWO DIRECTIONS FROM NEAREST UNES OF QUARTER SECTION AND DRILLING UNIT Line of quarter section Line of quarter section WELL STATUS Surface Location ft. from (N/S) and I ~1 from (E/W) WELL ACTIVITY [] Class I [] Class II []Brine Disposal [] Enhanced Recovery [] Hydrocarbon Storage [] Class III [] Other TYPE OF PERMIT [] Operating [] Individual [] Modification/Conversion [] Area [] Proposed Number of Wells Lease Name Well Number NAME(S) AND ADDRESS(ES) OF NEW OWNER(S) NAME AND ADDRESS OF NEW OPERATOR Attach to this application a written agreement between the existing and new permittee containing a specific date for transfer of permit responsibility, coverage, and liability between them. The new permittee must show evidence of financial responsibility by the submission of surety bond, or other adequate assurance, such as financial statements or other materials acceptable to the director. RECEIVED OCT 1 6 ]986 Alaska Oil & Gas'Cons. Commission AnChorage CERTIFICATION I certify under the penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. /am aware that there are significant penalties for submitting fa/se information, including the possibility of fine and imprisonment. (Ref. 40 CFR 144.32) NAME AND OFFICIAL TITLE (Please type or print) EPA Form 7520-7 (2-{14) SIGNATURE DATE SIGNED c. STATE OF ALASKA R~. " ALASr. OIL AND GAS CONSERVATION COM ,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) Chevron U.S.A. Inc. G.L. = 70' K.B. = 88 Feet 3. Address 6. Unit or Property name P. O. Box 107839, Anchorage, AK 99510 Beluga River Unit Well number ('~'~ s ~¢'~,~-~, BRWD #1 Approval number 4. Location of well at surface 7. 1936' S & 159' W of NE Cr. S13, T13N, R10W, SB&M At top of productive interval 8. Same At effective depth Same 86-9/123 9. APl number 50-- 283-20078 10. Pool Sterling At total depth Same 11. Present well condition summary Total depth' measured true vertical Effective depth: measured true vertical 3560 feet Plugs (measured) feet 3525 feet Junk (measured) feet Length Size Cemented Measured depth 74' 20" Driven 96" 1980' 9 5/8" 2000' - sfc 2000' 3536' 7" 3554' - sfc 3554' measured 3502' - 3448' 3422' - 3408' 3356' - 3286' True Vertical depth 96' 2000' 3554' true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: RECEIVe. O' Tubing (size, grade and measured depth) 2 7/8" 6.5# N-80 8RD EUE @ 3147' Packers and SSSV (type and measured depth) 7" 1-B @ 3134' 1986 Anoii0ra~e 12. Stimulation or cement squeeze summary NA Intervals treated (measured) Treatment description including volumes used and final pressure NA Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 13. Copies of Logs and Surveys Run X] 14. Attachments Daily Report of Well Operations [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed - Title Area Operations Superintendent Date Form 10-404 Rev. 12-1-85 Submit in Duplicate 5-14-86 5-15-86 5-16-86 5-17-86 5-18-86 5-19-86 BRWD #1 HISTORY Depth = 170', 120'-1/2 Hrs, 20" Cond at 96' 8.7 PPG 111 Vis., FIRST REPORT: Located 1936' S and 159' W of NE Corner Section 13, T13N, R10W, SB&M, G.L. = 70' K.B. = 98', MI & RU BSI #58 from BRU 224- 34, NU 20" Diverter and lines, Mix spud mud, PU & TIH w/17-1/2" bit, Spud 17-1/2" hole at 9:00 PM 5-14-86, Drill 50' to 170' w/Bit #1 DS made 120'-1/2 hrs at 0-20M 90 RPM 1500 PSI T3 B3 GO, POH, PU & TIH w/12-1/4" Bit and BHA. Depth = 1814', 1644'/15 Hrs, 20" Cond at 96'. 9.0 PPG 89 Vis 15.2 WL, TIH w/12-1/4" bit & Stb's at 60' & 90', Drill to 1814' w/Bit #2 X3A Made 1644'/15 hrs at 10-40 M 100 RPM 1500 PSI - Run survey at 1814' and tool would not pass 1295', ROH to clean out rock & debris, TIH -Wash & ream 1754' - 1814', Running svy Surveys: 460' - 1/2° 915' -1/2° 1346' - 1/4° 1814' - 1-1/2° Depth = 2000', Made 186'/2 Hrs, 20" Cond at 96'. 9.0 PPG 68 Vis 15 WL, Drill to 2000' w/Bit #3 RR #2 Made 186'/2 hrs at 10-40M 100 RPM 1700 PSI T3 B3 GO, Circ, Wiper trip w/9' fill - SLM w/no corr, Circ, POH, RU Schlumberger, Run DIL/SFL/SP/GR 1998'-96' CNL/LDT/GR/CAL 1998' - 96' shot & Rcvd 21 SWS, RD Schlumberger, TIH w/12-1/4" bit #4, Circ & Cond, POH & Lay dn 8" DC's & 12-1/4" STB's, RU & Running 9-5/8" Csg Survey: 1814 - 1-1/2o 2000' - lO' Depth = 2000' 9-5/8" Csg at 2000', 9.0 PPG 68 Vis 15 WL; Run float shoe, Ijt 9-5/8" 47# RS-95 BTC, Float collar, 6 its 9-5/8" 47# RS-95 BTC = 270.63'; 20 its 9-5/8" 40# N-80 BTC = 825.86'; 24 its 9-5/8" 43.5# AC-95 BTC = 911.31'; Set at 2000'; Circ csg; RU Howco & test lines to 3000 'PSI; Cmnt w/20 Bbls FW, 600 sks C1 "G" + 6% gel 3% salt 2% CaC12 ~ 13.7 PPG, Tail in w/200 sks C1 "G" + 2% CaC/2 15.8 PPG, Displ w/138 Bbls mud - CIP at 7:00 AM 5-17-86 w/1500 PSI and circ 210 sks, Floats held; WOC - ND Diverter lines & valves; ND Diverter & cut off 20" Csg; Weld on 11" - 3000 PSI x 9-5/8' SOW head. Depth = 2000', 9-5/8" Csg at 2000', 9.0 PPG 40 Vis 19 WL, Test wellhead to 1500 PSI, NU 13-5/8" - 5000 PSI BOPE, Test to 3000 PSI, Test annular to 2500 PSI, PU & TIH w/8-1/2" bit and csg scraper, Circ, Test csg to 1500 PSI for 30 min, POH, RU Schlumberger, Run CBL/VDL/GR/CCL 1951' - 50', Depth = 2359', 359'/5 hrs, 9-5/8" Csg at 2000'. 9.2 PPG 43 Vis 10 WL, Fin running CBL, RD Schlumberger, TIH w/8-1/2" bit, Drill float collar cmnt& shoe 1958' - 2000', Drill to 2010', Circ, RU Howco, Run leak off test to 600 PSI w/9.0 PPG mud 14.7 PPG EMW, Drill to 2102' W/Bit #6 FDGH. Made 102'/1-1/2 hrs at 10-20M 80 RPM 1700 PSI, POH, PU & TIH w/8-1/2" bit & STB;~ at 60' & 90', Drill to 2141' w/Bit #7 J-3. Made 39'/1/2 hrs at 10-40M 80 RPM 1700 PSI - Lost pump pressure, POH - Lost 1 bit jet, TIH, Drill to 2265' - Parted svy line & Rcvd line and tool, Drilling w/Bit #8 RR#6 FDGH ~ 10-40M 80 RPM 1700 PSI Survey: 2265' - 1-1/4°. R~~ ~ ~ ,{ ,~. ~) 5-20-86 5-21-86 5-22-86 5-23-86 5-24-86 5-25-86 Depth = 3359', 1000'/19-1/2 hrs, 9-5/8" Csg at 2000', 9.4 PPG 52 Vis 8 WL, Drill to 2891' w/Bit #8 RR #6 Made 749'/11-1/2 hrs at 10-20M 80 RPM T5 B3 GO 1700 PSI, RTCB, Drill to 3044' - Lay dn washed out jt & saver sub, Drilling w/Bit #9 RR #7 at 10-20M 80-100 RPM 1700 PSI Survey: 2662' - 1-3/4° 3140' - 1-1/4°. Depth = 3560', 201'/3-1/2 hrs, 9-5/8" Csg at 2000', 9.4 PPG 47 Vis 8.6 WL, Drill to 3520' w/Bit #9 RR #7 Made 629'/14 hrs at 10-20M 80-100 RPM T3 B3 GO 1700 PSI, Circ, Wiper trip - 6' fill, Circ, POH -SLM w/no corr, RU Schlumberger, Run DIL/SFL/SP/GR/BHC Sonic 3520' - 1980' CNL/LDT/GR/CAL 3520' - 1980' shot 45 SWS Rcvd 45, RD Schlumberger, TIH w/8-1/2 bit, Drill to 3560' w/Bit #10 RR #7. Made 40'/1-2 hrs at 10-20M 80-100 RPM T3 B3 GO 1700 PSI, Circ, POH - Lay dn drill string Survey: 3505' - lO TD = 3560' PBTD = 3514' 7" Csg at 3554'; 9.4 PPG 47 Vis 8.6 WL; Fin laying dn drill string; Install 7" rams & function test; RU & run float shoe, Ijt 7" 29# P-110 BTC Csg, Float Collar 86 its 7" 29# P-110 BTC Csg = 3558.86' set at 3554'; Circ csg; RU HoWco and test lines to 3000 PSI; Cmnt w/20 Bbls FW, 270 sks C1 "G" + 12% Gel 1/4 #/sk Celloflake at 12.6 PPG, Tail in w/430 Sks C1 "G" + 4% Gel 3% salt .6% Halad - 344 at 14.1 PPG, Displ w/i21 Bbls mud - CIP at 12:15 PM 5-22-86 w/1500 PSI and circ cmnt to sfc; set csg slips through BOP's w/80,000# csg; WOC - ND BOPE; Cut off 7" csg; Install packoff & NU 11" - 3000 x 7- 1/.16" - 3000 PSI tubing spool; Test to 1500 PSI, NU BOPE. TD = 3560' PBTD = 3525' 7" Csg at 3554', 9.4 PPG BW, Fin NU BOPE, Install 3-1/2" rams, PU & TIH w/6"bit csg scraper and 3-1/2" drill pipe to TOC at 3493', Drill to float collar at 3505', Displace w/9.4 PPG BW, Drill float collar & cmnt 3505' - 3525', Circ, Test 7" csg to 1500 PSI f/30 min, POH, RU Schlumberger, Running CET. TD = 3560' PBTD = 3525' 7" Csg at 3554'; 8.4 PPG FW; Run CET 3522' - 1800'; RD Schlumberger; Test BOPE to 3000 PSI; Test annular to 2500 PSI; PU and TIH w/5" TCP guns, pkr, MFE on 3-1/2" drill string; RU Schlumberger; Run GR/CCL; Space out & set pkr at 3251'; Check space out; NU test head & sfc lines and test to 3000, PSI w/N2; Load 975 PSI N2 cushion estmd 400 PSI underbalance; Open tools and fire guns w/900 PSI annular pressure; Open well on 1/8" choke - tool left open - final fluid rise to 109'; Close tools; Rlsd pkr and fluid fell to 450'; Shear out reverse sub & fill hole; Displacing hole w/FW. TD = 3560' PBTD - 3525' 7" Csg at 3554', 8.4 PPG FW, POH - Lay dn test tool and guns - all shots fired, PU & TIH w/6" bit and csg scraper to 3488', Clean out fill to 3525', Circ, POH, RU Schlumberger, Run GR & RA tracer svy, TIH w/OE DP to 3244', RU Howco, Run injection test at 200-1000 PSI 1.0 BPM - 4.6 BPM at 700 & 800 PSI 3.75 BPM at 1000 PSI, Lay dn drill string, Run on WL "XN" nipple Millout Extn & 1-B 7" pkr set at 3124', RD Schlumberger. 5-26-86 TD = 3560' PBTD = 3525' 7" Csg at 3554', 8.4 PPG FW, Install 2-7/8" rams & function test, RU & Ran CL Locator seal assembly & 100 its 2- 7/8" 6.5# N-80- 8 RD EUE Tbg tested to 5000 PSI, stab into pkr and space out, Displace dn annulus w/wtr inhibited w/tretolite KW-132, tail in w/200' diesel, stab into pkr and land hanger, test to 1500 PSI, ND BOPE - Install two way check, NU tree and test to 3000 PSI, Test pkr/annulus to 1500 PSI f/30 ~nin, Clean pits & Rlsd Rig at 12:01 AM 5- 27-86, FINAL REPORT. Attention: Mr. Harold Scott Gentlemen: Chevron previously submitted to your agency the results of the mechanical integrity test on the BRWD-1 Disposal Well (J.L. Weaver letter, June 4, 1986). The report erroneously stated that the test was held for 30 minutes. The test was ac__t_ua~~~ as reported in the injectivity test analysis report (J.L. Weaver letter, June 4, 1986). The mechanical integrity test was witnessed and approved, however, by the AOGCC representative. The AOGCC was granted primacy' for th~ Class II UIC program as of June 19, 1986. Please call Mr. Greg Molesworth of this office if you have any questions. ~ ~ ~ ~ V Very truly yours, C 2 9 1986 A~')Ct~ y:~.,~ Acting Area Operations Superintendent CDC:fr ce: ~:Alaska ~::300 ~"I'or eupine'-Driv e Anehorat~ e; :.A K.,-. 9 9 5 0 o~ ~l /¢ g ~ Alaska 0il & ,as Cons. Commission "~~' D, ~ Anchora~le STATE OF ALASKA ALAS~~ 'IL AND GAS CONSERVATION COMM{ ION APPLICA'I,ON FOR SUNDRY APi-,ROVALS 1. Type of Request: Abandon ~. Suspend ~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing Time extension ~ Change approved program ~ Plugging ~ Stimulate]~ Pull tubing D Amend order ~ Perforate r-.,. Other 2. Name of Operator 3. Address P.O. Box 107839, Anchorage, Alaska 99510 4. Location of well at surface 1936' S & 159' W of N.E. Corner, Section 13, TI3N, RI0W, SB&M At top of productive interval Same At effective depth Same At total depth Same 11. Present well condition summary Total depth: measured true vertical 3560 feet Plugs (measured) - feet 5. Datum elevation (DF or KB) G.L. = 70' K.B. = 88' feet 6. Unit or Property name Beluga River Unit 7. Well number BR-WD-1 8. Permit number 86-9 9. APl number 50-- 283-20078 10. Pool Beluga River - Sterling 3525' Effective depth: measured true vertical 3525 feet Junk (measured) feet Casing Length Structural _ Conductor 96' Surface 2000' Intermediate - Production 3554' Liner Perforation depth: measured Size Cemented 20", 94# Driven 9 5/8",40#-47# 800 sks -- -- 7", 29# 700 sks -- m -- 3502'-3448', 3422'-3408', 3356'-3286' true vertical Measured depth True Vertical depth -- -- -- -- -- -- .. Perforated 12 SPF. Tubing (size, grade and measured depth) 2 7/8", 6.5#, N-80 to 3147' Packers and SSSV (type and measured depth) Packer @ 3134' 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation 14. If proposal was verbally approved Name Of approver _,,/ Date approved 15. I hereby c e~ h..~_~/f~ng is true and correct to the best of m yknowledge Signed / ,~ ~~./~,~-2..------ Title Acting Area Operations SuperintendeDl~te Conditions of approval Commission Use Only Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI Approved by Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate BR-WD-1 Beluga River Unit Aeidizing Due to miscommunication within the Chevron U.S.A. Inc. Anchorage Production Department, the Alaska Oil and Gas Conservation Commission was not asked for permission to stimulate Beluga River Disposal Well BR-WD-I. We apologize for the discrepency and would like to bring the AOGCC up to date with current activities of the subject well BR-WD-! was placed on injection 7-26-86. Due to low injection rates the well was acidized on 8-7-86 using 2000 gals. of 15% HC1 and 2000 gals. of 12%-3% mud acid. The well was returned to injection at a rate of 2 bbL/min, with 900 psi tubing pressure. (Prior to acidizing BR-WD-1 was injecting at 1/4 bbl./min, with 900 psi tubing pressure.) This injection rate decreased back to 1/4 bbL/min, at 900 psi tubing pressure within 24 hours. The injection fluid was analyzed and it was recommended to reduce the filtration size from 70 microns to 3 microns. The new filtration system was put into place in September and the well was reacidized on 9-11-86, using the same volumes of acid. The well was returned to injection at a rate of I bbl./min, at a tubing pressure of 100 psi. Chevron is planning to run an injectivity test on the well on 9-16-86. The results of the injeetivity test willbe sent to both EPA and AOGCC. Again, Chevron U.S.A. Inc. apologizes for the error in not asking permission from AOGCC. If there are any further questions please contact Mr. G r. Molesworth at 786-6638. M. K. Hauser Acting Area Operations Superintendent GRM:fr ,. STATE OF ALASKA ALASKi )IL AND GAS CONSERVATION COMIV~, ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~, Stimulate ~ Plugging S Perforate ~ Pull tubing Alter Casing ~ Other ~ 2. Name of Operator 5. Datum elevation (DF or KB) Chevron U.S.A. Inc. G.L. = 70' K.B. = 88' Feet 3. Address 6. Unit or Property name P.O. Box 107839, Anchorage, Alaska 99510 Beluga River Unit 4. Location of well at surface 1936' S & 159' W of N.E. Corner, Section 13, T13N, RIOW, SB&M At top of productive interval 8. 7. Well number BR-WD-1 Approval number Same At effective depth Same At total depth Same 9. APl number 50-- 283-200?8 10. Pool Beluga River - Sterling 11. Present well condition summary Total depth: measured true vertical 3560 feet Plugs (measured) - feet Effective depth: measured 3525 feet Junk (measured) true vertical - feet Casing Length Size Cemented Structural _ _ _ Conductor 96' 20",94# Driven Surface 2000' 9 5/8",40#,47# 800 sks Intermediate - - - Production 3554' 7", 29# 700 sks Liner _ _ _ Perforation depth: measured 3502'-3448', 3422'-3408', 3356'-3286' 3525 Measured depth Perforated 12 SPF True Vertical depth -- ,. true vertical Tubing (size, grade and measured depth) 2 7/8", 6.5#, N-80 to 3147' Packers and SSSV (type and measured depth) Packer @ 3134 12. Stimulation or cement squeeze summary Intervals treated (measured) 3502,'-3448', 3422'-3408', 3356'-3286' Treatment description including volumes used and final pressure 1000 gals 15% HC], 2000 gals 12-3 Mud Acid, 1000 gals 15% HCI, Final injection pressure 500psi, rate 2½ bbls./min. 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas. Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed e,~~~~~~~ Title Acting Area Operations SuperintendentDate Form 10-404 R Submit in Duplicate "~hevron Chevron U.S.A. Inc. P.O. Box 107839, Anchorage, AK 99510 · Phon~ (907) 786-6600 CERTIFIED MAIL Return Receipt Requested No. P 175 864 228 August 11, 1986 UIC Permit (AK-2D001-1) Class II Injection Well BRWD-1, Beluga River Field Mr. Harold M. Scott U.S. Environmental Protection Agency Region 10 1200 Sixth Avenue Seattle, WA 98101 Dear Mr. Scott: As required by Section I.D.l.a.(i) & (ii) of the above permit, Chevron U.S.A. Inc. hereby submits a comprehensive water analysis performed on the BRWD-1 injection fluid. As all of the reserve pits (the source of injection fluids) being dewatered this summer were drilled with basically the same drilling mud, no separate water analysis will be performed for each reserve pit's fluids. The attached analysis also satisfies the quarterly requirement for the 3rd quarter of 1986 (the first quarter injection occurred). Please call Ms. Christine Creed of this office (786-6711) if you have any questions. CDC:fr Attachment M.K. Hauser Acting Ares Operations Superintendent cc: Certified M~'~I No. P 460 104 310 Mr. Bill H. Lamoreaux Alaska Department of Environmental Conservation 437 E Street, Suite 200 Anchorage, AK 99501 Satisfies Appendix A, Part C. 3 requirement of Permit No. 8523-DB017 Mr. Chat Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. P.O. BOX 4-1276 Anchorage, Alaska 99509 TELEPHONE (907) 562-2343 ANCHORAGE INDUSTRIAL CENTER 5633 B Street WATER ANALYSIS REPORT OPERATOR Chevron USA, Inc. DATE 8/4/86 WELL NO. BRWD-1 LOCATION FIELD Beluga FORMATION COUNTY INTERVAL STATE Alc~ska LAB NO. 3766 SAMPLE FROM Injec ,tion Fluid REMARKS & CONCLUSIONS: Iron, n~/t : 16 Barium, m~/1 : 5.6 Si'iica, mg/1 : 121 Specific Conductance mmhos/cm : Specific Gravity @ 68°F : 15,000 1.0090 Cations mgll Sodium ............. Potassium ........... Calcium ............. 46 Magnesium .......... 4.2 Iron ................ 2,376 1,800 Total Cations ......... megll 103.87 46.08 2.30 0.35 152.10 Anions Sulfate .............. Chloride ............. Carbonate..: ........ Bicarbonate ......... Hydroxide ........... ~ng/1 23-0-- 4,600 24 1,025 Total Anions .......... megll 0.79 16.81 152.10 Total dissolved solids, mg/1 .......... 9,593 NaCl equivalent, mg/1 ....... ,~:..-'"";(*~,... 9,291 Observed pH ............. .,:,, 8. 8 ~' ?.."::"~'r"'WATER ANALYSIS PATTERN ,~.,., ~,-~ .'~, .. ,,, - ' ""': Scsle Sample:a~6v~ de?S;ribed MEQ per Unit Na Ca Mg Specific resistance @ 68° F.: Observed Calculated ......... 0.67 ohm-meters 0.73 ohm-meters Fe Cl 50 Na HCO3 1 Ca SO' 1 Mg CO~ 1 Fe INVOICE #39150 i 11 ilJllf i1~11 Illl JllllJl[IJll[lllllllllllllllIIII IIIIIl Ill[ IIllllllJJlllllillllllllllllflrl 11 lllll[lllltllll ii1~ ii ftll [llllLlI]l[llllll I[llllril!Il C1 HCO3 SO4 CO= (Na value in above graphs includes Na, K, and L1) NOTE: Mg/1 = Milligrams per liter Meq/l = Milligram equivalent per liter ' ,, .., ..i-,, r,,,~,.~ ~ ,~ .... ~h~.~ ~1~- ,f*,~- , ....... ~ .... MEMORANr) UM Stat,,, of Alaska ALASKA_ OIL ~' .~D GAS CONSERVATION CO~IJ~ .~ON TO: THRU: FROM: C. V. ~t Chairm~ozv on Lonnie C Smith .--,v ~?'~ · .., ,..,'/' ,~ Commis s ioner " .... '-' Bobby D. Foster Petroleum inspector DATE: August 11, 1986 FI LE NO.: D. BDF. 58 TELEPHONE NO.' SUBJECT: Observe Injection Operations Chevron BRU BRW!D ~1 Permit 86-9 Beluga River Field Wednesday, August 6, 1986: I arrived at the disposal well BRWD #1 location at 1:15 p.m. and talked with the injection pump operator. He informed me that he was not injecting at the time due to overheating of the transmission, on the pump unit; and the fluid level in the suction tank was low. A vacuum truck was being used to transport the water from storage pits to the well site. I asked at what rate he was injecting the fluid in the well, and he said between 200-275 bbls/day at.a pressure not exceeding 800-843 psig. A two-pen pressure recorder had been tied into the Xtree on the tubing and annulus, and I checked all the control valves, and then looked at the chart. Since no injection was taking place at the time, both pens were on 0 psi, so I asked the operator if they had ever bled the annulus off or if any pressure had ever been observed. He answered no to both questions. The injection unit is very well made and rigged up in a very orderly manner. There was no spillage around the area. I departed the location at 3:30 p.m., but returned at 11:45 p.m. and talked to the night operator. Again, the transmission was overheated, so I observed the chart. The operator had been pumping. for approximately 2 hours, and had been shut down for 15 minutes before I arrived. The operator explained that the pump rate was so low the clutch had to be engaged and disengaged so often it caused the transmission to overheat. I departed the location at 12:30 a.m. 8/7/86. At 7:00 a.m. I met with Jim Gossett, Production/Construction Foreman, and we discussed the disposal well. Jim informed me that an acid job was to be performed on the well this date to try to improve the injection rate. I departed Beluga River at 8:00 a.m. and returned to Anchorage via a Troy Airline plane. )2-001 A ( Rev 10~84) .,~ REPLY TO M/S 409 ATTN OF: M.K. Hauser Acting Area Operations Superintendent Production Department Chevron U.S.A. Inc. P.O. Box 107839 Anchorage, Alaska 99510 1200 SIXTH AVENUE SEARLE, WASHINGTON 98101 RE;' Completion Report for Injection Well BRWD-1 (Permit' No. AK-2DO001-I), Beluga Gas Field Dear Mr. Weaver: The Completion Report (EPA Form 7520-10) and attachments dated June 4, 24, 1986, and July 18, 21, 1986, is equivalent to permit condition C.1. Therefore, injection may. commence at this well. Si ncerely, Director, Water Division cc' ~C.V. Chatterton Alaska Oil and Gas Conservation Commission Bill Lamoreaux A1 aska Department of Environmental Conservation RECEIVED AUG- 4 1986 Naska 011 & Gas Cons. Commission Anchorage TRANSMITTAL AND ACKNOWLEDGEMENT OF RECEIPT OF CLASSIFIED MATERIALS Alaska Oil & Gas Conservation Com mission Attn: Mr. W.M. Van Alen 3001 Porcupine Dr. Anchorage, AK 99501-3192 DATE- ~ELL NANE' .'~?,~A,/D - :L... We are sending the material tabulated below. Please acknowledge receipt and return one copy to: Mr. J. L. Weaver Chevron U.S.A. Inc. 3001 C Street Anchorage, ~ 99~llD3 ,, ,, ,, s. i I~ If If '~ '~,5" CF.: RECIPIENT PLEASE ACKNOWLi COMPANY' BY: DATE: st Senders~ Instructions:- These transmittal sheets are made on NCR (No Carbon Required) paper with three sheets per set. Retain one copy for originator's file. Include one copy with transmitted material. Send original under sepa- rate cover to addressee. {If sending by air freight, put air bill number on backside of envelope.) Please use ball-point pen when filling out this form. EXP- 180-8 (CD- 3-82 ) Printed in U,S,A. TRANSMITTAL AND' ACKNOWLEDGEMENT OF RECEIPT OF CLASSIFIED MATERIALS Alaska Oil & Gas Conservation Com mission Attn: Mr. W.M. Van Alen 3001 Porcupine Dr. Anchorage, AK 99501-.3192 DATE: ~,- ~- 8(~ WELL NAME: We are sending the material tabulated below. Please acknowledge receipt and return one copy to: Mr. j. L. Weaver Chevron U.S.A. Inc. 3001 C Street Anchorage, AK 99503 E IX/F .. DATE. ~',a~ ~,, ~ ~:s~ .... ~-- '- ' Anchorage Senders~ Instructions:- These transmittal sheets are made on NCR (No Carbon Required} paper with three sheets per set. Retain one copy for originator's file. Include one copy with transmitted material. Send original under sepa- rate cover to addressee. (If sending by air freight, put air bill number on backside of envelope.) Please use ball-point pen when filling out this fora. EXP-180-8 (CD-3-82) Printed in U.S.A. TRANSMITTAL AND ACKNOWLEDGEMENT OF RECEIPT OF CLASSIFIED MATERIALS Alaska Oil & Gas Conservation Com mission Attm Mr. W.M. Van Alen 3001 Porcupine Dr. Anchorage, AK 99501-3192 WELL NAME We are sending the material tabulated below. Please acknowledge receipt and return one copy to: Mr. j. L. Weaver Chevron U.S.A. Inc. 3001 C Street Anchorage, AK 9950~~ ~?~,-.. .. RECIPIENT PLEASE ACKNOWLEDGE BY: Developme~ Geolog-ist COMPANY: DATE Senders~ Instructions:- lhese transmittal sheets are made on ~CR (~o Carbon Required) p~per with three sheets per set. Retain one copy for originator's file. Include one copy with transmitted material. Send original under sepa- rate cover to addressee. (If sending by air freight, put air bill number on backside of envelope.) Please use ball-point pen when filling out this form. EXP-180-8 (CD-3-82) Printed in U.S.A. ALAS;i STATE OF ALASKA ' OIL AND GAS CONSERVATION COM,~, ,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [~ Plugging [] Stimulate [] Pull tubing ~ Amend order [] Perforate ~ Other [] 2. Name of Operator Chevron U.S.A. Thc. 3. Address P.O. Box 107839, Anchorage, AK 99510 4. Location of well at surface 1936' S & 159' W of NE Corner S13, T13N, R10W, SB&M 5. Datum elevation (DF or KB) G.L. = 70' K.B. = 88 6. Unit or Property name BeluRa River Unit 7. Well number BRWD #1 At top of productive interval Same as above At effective depth Same as above At total depth Same as Above 8. Permit number 86-9 9. APl number 50-- 283-20078 10. Pool St'erling 11. Present well condition summary Total depth: measured true vertical 3560 feet 3560 feet Plugs (measured) Effective depth: measured true vertical 3525 feet 3525 feet Junk (measured) Casing Length Structural Conductor 76 ' Surface 1980' Intermediate Production 3536 ' Liner Perforation depth: measured feet Size Cemented Measured depth ~ue Verticaldepth 20" Driven 98' 98'- 9-5/8" 2000' - Sfc 2000' 2000' 7" 3554' - Sfc 3554' 3554' true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 12.Attachments Description summary of proposal R E C l::lV E D MAY 2 7 1986 ,Alaska Oil & G~s Cons. 6ommissio~ Detailed opera[~ons program BOP sketch [] 13. Estimated date for commencing operation Immediately 14. If proposal was verbally approved Name of a. pprover Date approved 15. I herebyj~erti'f)~that ~he foregoing is true and correct to the best of my knowledge Signed ~~.~//~ Title Area Operations Superintendent Condit~ approval Date Commission Use Only Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance I Approved by !~ ,~. Form 10-403 Rev 12.1-85 7' 006 ...... .. .......... by order of Commissioner' the commission Date~---~.-~ Submit in triplicate WELL' ORIGINAL SUMMARY CHEVRON U.S.A. INC. WESTERN REGION ALASKA AREA WELLWCRK PROCEDURE SUMMARY TYPE JOB' SUPPLEMENTAL SUMMARY ~ NO. // _ K.8. CASING' PROGRAM / T.D. ,~,~ (~ PBTO LINER' 3~'- N~TES: ~~. ~~ ~ 6G A~chor~ae DETAILS ATTACHED Distribution: Origiflel to Well. File Orig. Superintefldent Engr. (3) Filial Office Preporlr (I) Engr. Techfliciofl (I) CHEVRON U.S.A. INC. WESTERN RE GiON ALASKA AREA WELL,WORK ~DURE SUMMARY PROGRAM (C0NTINUED _ ce.. O~ DETAILs ATTACHED original to Will. File Prepared by Date o,,~. s,,.,,,,,.,,,,.,t ~,,v. (~) MAY 2 7 i~ Field Office {I) ·.~..~proved by Preparer {I) AJaska Oil & Gas Cons, gom.m,.a4.:;~:,~ I[ngr. Techfli¢ion {I) ~,,r'~ .... In CHEVRON U.S.A. INC. WESTERN RE GION WELL_WORK PROa[BURE~ ~t,JMM~RY WELL: - PAGE OF ,~ -- ~ iCONTINUED): A . DETAILS ATTACHED [3 DIstribution: Date CHEVRON U.S.A. INC. WESTERN REGION ALASKA AREA WELLWORK PROCEDURE SUMMARY PAGE -- CONTINUED - r · DETAILS ATTACHED Dlstrlbutlon: Original to Well. File Orig. Superintendent Field Office Preparer [ngr. Technician (I) MAY 2 ? la~ Prepared by Alaska Date Dote CHEVRON U.S.A. INC. · WESTERN REGION AI.A,SKA ARF. A WELl,WORK PROCEI~RE ~IJMMARY WELL: '--"'~~ "J~/ - PAGE ~ OF ,,~ _ ~ (CONTINUED): ii i u · i DETAILS ATTACHED DIstribution: Original to Well. File Orig. Sugerintendent Engr. (3} Field Office Prel)Orer Eng¢. Technician Apl~'oved bye,) i i i Date THRU: FROM: _,vIORANPUM Stat o ALAS}~A OIL A.,O GAS CONSERVATION COI,'~IISS-~b~ C.V. '(~e ton Chai .~~,~ DATE' FI LE NO.: Lonnie C. Smith/-:-~C~ TELEPHONE NO.' Commissioner SUBJECT: Harold R. Hawkins Petroleum Inspector~/f)~ f Alaska May 20, 1986 D.HRH. 27 BOP Test Chevron BRWD 1 Permit No. 86-9 Beluga River Gas Field Supday_, May 18,. 1986: I left Anchorage at 3:00 p.m. by Troy air to Beluga RiVer to witness a BOP for Chevron on BRWD 1. There were four failures. Three valves failed on the choke manifold, and well sign was not on location. I filled out an AOGCC report which is attached. In s~_~_mmary, the BOP tests were satisfactorily performed and tested, with the exception of the four' failures. Chevron is to call AOGCC when failures are repaired or changed out and tested, and well sign is installed.. Attachment Tuesday, May 22, 1986: Hank Graham of Chevron called to say the ~'h'r'e'e' valves (:;~-~z~e manifold were changed out and tested satisfactorily. .001 A (Rev 10-84) Inspector STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date Well Operator ~~~ ~,/~o /~ ~, Wen _f f D / Location: Sec /3. ,T~/b~ ~_~_~ Drilling Contractor ;~/~/~f~f/ Ri Location, General ~ Well Sign~aF&~' General Housekeeping Oil Rig 4~ Reserve Pit ~/( Mud Systems Visual Audio. Trip Tank Pit.GaUge '~ Flow Monitor ~ ~ Gag Detectors ~., BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves Valve Kill Line Valves Check Valve 'Of1' ' Test Pressure Representative ,.~.~ Casing set Representative~ ACC~LATOR SYST~ Full Charge Pressure '~bP ~ psi~ Pressure After Closure / ~,~-~ psig Pump incr. clos. pres. 200 psig .~- min~J'~sec. Full Charge Pressure'Attained' ~ min/~~- · sec. Controls: Master ~/~ . . Remote ~{G Blinds switch cover , Kelly and Floor Safety Valves Upper Kelly, Lower Kelly Ball Type Inside BOP Choke Manifold No. Valves.,,f~ Test Pressure ~B Test Pressure. ....... ~Od Test Pressure, ~d Test Pressure ~ Test Pressure Test Results: Failures No. flanges .~ ~ Adjustable Chokes ~.~ O~ Test Time / hrs. ~*] f" ,'~ ?~"~ '~ Repair or Replacement equipment to :'~, days and Inspector/ of failed be made within Commission office notified. Remarks:_ ...... . Distribution orig. - AO&GCC cc - Operator cc - Supervisor DEPT. OF ENVIRONMENTAL CONSERVATION / SOUTHCENTRAL REGIONAL OFFICE 437 E STREET, SUITE 200 ANCHORAGE, AK 99501 May 9, 1986 J.L. Weaver Chevron U.S.A., Inc. P.O. Box 107839 Anchorage, AK 99510 Dear Mr. Weaver: RE: Waste Disposal Permit 8523-DB017 RECEIVED Alaska 011 & ~as Oor~$, Oornmissio~ Anchorage The Department has reviewed your request for a permit modification dated October 29, 1985. Based on our evaluation, the following modifications are hereby granted: - Appendix A. Part B.1. shall be changed to read: The injection shall be limited to the Sterling Formation in the subsurface interval between 3,060 ft. and 3,521 ft. unless authorized by a permit modification issued by the Regional Supervisor of ADEC. - Appendix A. Part B.4. shall be changed to read' The injection pressure shall not exceed the fracture pressure. - Appendix A. Part B.5. shall be changed to read: The discharge shall be limited to those wastes directly related to drilling activities. This includes pr,oduced water, drilling and completion fluids, dilution water, and equipment washwater. - Appendix A. part C.3. shall change the first sentence to read as fol 1 ows: The Permittee shall conduct a composite, representative chemi- cal analysis of the drilling fluids to be injected from each new well and workover that utilized a mud system which has not previously been sampled. Department of Environmental Conservation regulations provide that any person Who disagrees with any portion of this decision, may request an ad- judicatory hearing in accordance with 18 AAC 15.200-310. The request J.L. Weaver -2- May 9, 1986 should be mailed to the Commissioner of the Alaska Department of Environ- mental Conservation, P.O. Box O, Juneau, Alaska 99811-1800, or delivered to his office at 3220 Hospital Drive, Juneau. Failure to submit a hearing request within thirty (30) days of receipt of this letter shall constitute a waiver of that person's right to judicial review of this decision. Si ncerel y, BHL'JH:ep CC- KDO Valerie Payne, EPA-Anchorage Jerry Opatz, EPA-Seattle b/Chat Chatterton, AOGCC v Alaska Center for the Environment RECEIVED MAY 1 198G · Alaska Oil & Gas Cons, C Chevron U.S.A. Inc. P.O. Box 107839, Anchorage, AK 99510 · Phone (907) 786-6600 J.L Weaver Area Operations Superintendent Production Department May 7, 1986 BRWD 1 Chevron U.S.A. Inc. APD ~, . ;- Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-319;? Dear Mr. Chatterton: Please make the following additions to our program for the APD for the BRWD 1: Step 15. Notify the AOGCC 2q hours in advance of pressure testing the 9-5/$" casing so that a representative of the Commission may witness the testing. Step 15A Step ;?5. Circulate the well clean. Pull out of the hole. Rig up Schlumberger, and run a CBL/VDL/CCL/GR from the float collar of the 9-5/8" casing to the shoe of the';?0" conductor. Rig down Schlumberger. Notify the AOGCC 2q hours in advance of pressure testing the 9-5/8" casing so that a representative of the Commission may witness the testing. Also, see the attached list of equipment that the drilling fluid system contains. If you have additional questions, please contact V. W. Angell of this office at 786- 6600. VWA:cbw Attachments cc: 3. D. Arlington . L. Weaver . RECEIVED MAY 1 4 1986 Alaska Oil & Gas Cons. Commission Anchorage DRILLING FLUIDS SYSTEM EQUIPMENT LIST 1. Drilco type degasser and mud/gas separator with lines for mud from choke manifold to separator. 2. Tandem double deck shaker (BrandO. De-sander (Swaco). Mud cleaner with single shaker screen (Brandt). Centrifuge (Brandt). 3. Sufficient supply of different size screens for shakers and mud cleaner to provide optimum removal of solids. Pit level indicator with high/low audio (horn) and visual (lights) alarms. 24 hour record chart. 5. Flowline sensor with high/low audio and visual alarms. 6. Pump stroke counter to determine fill on trips. 7. Stirring paddles in each pit (except sand trap). Low pressure submarine guns. 8 Drilling fluids test kit to conduct tests per API RP 13B. 24 hour mud engineer coverage. RECEIVED MAY 1 19tl, A!aska Oil & Gas Co~s., Commission Anchorage, May 5, 1986 Mr. J. L. Weaver Area Operations Superintendent Chevron U.S.A. Inc. P. O. Box 107839 Anchorage, Alaska 99510-7065 Telecopy: (907) 276-7542 Re: Beluga River Unit BRF~rD-1 Chevron U. S~A. Inc. Permit No. 86-9 Sur. Loc. 1936'S & 159' W of NE cr Sec.13, T13N, R10W, . SBM. Btmhole Loc. 1936'S & 159' W of NE cr Sec.13, T13N, R10W, SBM. Dear Mr. Weaver: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention .equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. ~~~r~. z~t r u.~. y~-y~o u_r s, z ~ C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Bill H. Lamoreaux Chevron LancJ lgepar~men! Chevron U.S.A. Inc. 3007 C Street, Anchorage, AK 99570 Mail Address: P.O. Box 107839, Anchorage, AK gg510 Phone 1907t 2866600 .~1ay 2, ~986 APPlieation for Permit to Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Sirs: Enclosed Please find an ApPlieation for Permit to Drill from Chevron U.S.A. /ne. for the above refereneed Well and ebeek number 13705 in the amount of $100. Chevron respeetfully requests an expedited review of this approximate spud date is on or about May 5, 1986. application since The Commission has Previously reviewed an ApPlieation for Permit to Drill this well but suspended review pending approval by the EPA for modification of its UIC Permit. This APD takes into aeeount the modifications that have recently been approved by EPA. Should you have any questions or eoneerns with this applieation' please do not hesitate to eall me at 786-6665. Upon approval of this apPlieation, please return it to the Undersigned. JDA:mw Enelosure Very truly yours, ames D. Arlington ee: j.L. Weaver RECEIVED MAY 0 2 t986 ,Alaska Oil & "'" '"',-s Co~:*~mission A~c~or~,ge STATE OF ALASKA i MAY U 2 1986 ALASKA G!.._ AND GAS CONSERVATION CO ,, . .,t l SS l O N 20 AAC 25.005 ~ch~rage L la. Type of work Drill ~ Redrill ~1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development O,1 [] Re-Entry [] DeepenI-qI Service ~ Developement Gas [] Single Zone [] Multiple Zone ~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Chevron U.S.A. Inc. G.L. TM 70' K.B = 88set Beluga River - 3. Address 6. Property Designation Sterling P.O. Box 107839, Anchorage, AK 99510 ADL - 58831 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see20 AAC 25.025) 1936' S & 159' W of NE Corner Section 13 Beluga River Unit Blanket T/~t3~'P ~'f'lCTt4ot:lu~VIinterval 8. Well nurpber Number same as above BRWD 1 U80-61-55-2 At total depth 9. Approximate spud date Amount May 5~ 1986 $500~000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in pr°perty1 15. Proposed depth (MD and TVD) property line Lease Line 159 feet BRU 212-18 29.~ feet 788.57 3600' & 3600~ feet 16. To be completed for deviated wells NA 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth feet Maximum hole angle 0 Maximum surface 1620 psig At total depth (TVD) 1695 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" 94 H-40 PE 76' 22' 22' 98' 98' Driven 12-1/4" 9-5/8" 40 K-55 BTC 1980' 20' 20' 1000' 2000' 990 SKS 8-1/2" 7" 23 K-55 BTC 3512' 18' 18' 3530' 3530' 600 SKS 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee ~3 Property plat [~ BOP Sketch [~ Diverter Sketch E~ Drilling program [~ Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] 21. I hereby certify' ~~rue and'~ ~~,.,~~ correct to the best of my knowledge ¢ Area Operations ~ Signed Title Superintendent Date Permit Numb ,~,.._c/ APl number Approval date. See cover letter 50-- 2..~5- ~'~ 37 ~ 05/05/86 for other requ rements Conditions of approval Samples required [] Yes ~ No Mud Icg required L-J Yes [] No Hydrogen sulfide measures [] Yes [] No Directional survey required [] Yes ~ No R equiredwor~/fo/~~; I-q 5M; E~ l OM; I-q 15M ~~.'~ Other: by order of Approved by~ ,../', ( .~'~~ Commissioner the commission Date . / Form 10-401 Rev. 12-1-85 Sub/n n triplicate WELL NO. ~.~ ,, L,~,"~- / SECTION NO. /.~' TRACT NO. ~ PROPOSED ~ PREL Ildl NARY F~ FI NAL WELL ~RVEY Pro-312 COUNTY OF /~-/;J/ CITY OF ,TOWlI~NIP /.,~'~J RANGE /~ ~/' I~;~ S. 8.~. A N. ~ N.D.B. & N. LOT RO. FI ELD ~'/u,;O I~'~C r ELEVATION: GROUND CONCRETE NAT DERRICK FLOOR " A LTEIIAT£ OI SUffYEYED LOCATI O# '' LOCAT I O~ . DES I GII AT 1011 LOCAT 1011 COORD I BATES NOV E It ......... /-;r',,.~ //: Z ~ ~/~2. ~- . .......... ... .......... ........ , ...... ................ .... ~ ................. ................. , . .... NORTH 1 SKETCH OR RENARK$ SOUTH '$TATIO# BEAII#e DIST)JICE ~1#£ ..... ~O$1#E #ORTN ~OUTN F..A~T " VEST · C.C. DIV. ENGR. FI LE f IIIIT(O III SURVEYOR 14AINT. FIINN. MAINT.' SUPT. DATE DATE P!~':,. 312 (2500.0D. 1. b~) , PROPOSAl. FOR WELL OPERATIONS PRO 316-1 Field: Property and Well: Surface Location: Bottom Hole Locations: Elevation: Beluga River BRWD 1 1936' S and 159' W of NE Corner Section 13, TI3N~ RIOW, SB&M. Same as above (vertical well). G.L. = 70' K.B. = TENTATIVE CASING PROGRAM: 20" 9q# H-q0 PLAIN END CSG DRIVEN TO g0' +/- BGL 9-5/8" ~0# K-55 BTC CSG CEMENTED TO SFC AT 2000' +/- 7" 23# K-55 BTC CSG CEMENTED TO SFC AT TD = 3530' +/- BLOWOUT PREVENTION CONSIDERATIONS: I. Potential Problems A. Water flows: No water flows are anticipated. Gas Entries: No high volume gas flows are expected above 3536'. Coal seams can be encountered anywhere from the surface to TD. A controlled penetration rate~ al,gasser and possibly a rotating head should eliminate any gas encountered while drilling through coal seams or through the injection intervals. C', Lost Circulation: Lost circulation is not anticipated with the programmed mud weight. However, LCM should be readily available. D. Stuck Pipe: Coal seams should be drilled and reamed with care. Do not stop moving the pipe in coal seams. E. Precautions: All kicks should be handled by the normal procedure. Drilling crews should be made aware of these methOds prior to spudding. Kick and BOP drills should be practiced tourly or more often and noted on the tour sheets. An adequate supply of weight materials should be kept at the well at all times. 2. Maximum Anticipated Formation Pressure: (From surrounding well data.) Pressure (PSI) Mud Wei~iht (PPG) Gradient (PSI/FT) Depth (FT) 169§ 9.2 .~g 3539 . Maximum Anticipated Surface Pressure: 1620 PSI = (.052 * Maximum Anticipated Mud Weight * TVD) - (.03 (Gas Gradient) * TVD) = (.052 * 9.~ * 3530)- (.03 * 3530) Blowout Prevention Equipment: Brinkerhoff Signal Inc. Rig t?58 is equipped with a 5000 PSI BOP Stack. A. 20" Conductor: 21-l/4" - 2000 PSI Diverter with two (2) 10" lines for down wind venting at any time. B. 9-5/8" Surface Casing: Class III 5000 PSI BOPE. C. 7" Production Casing: Class III 5000 PSI BOPE. D. Testing: 1. At Nipple Up. 2. Weekly. DIRECTIONAL CONSIDERATIONS: This is to be a straight hole. Maintain angle at less than three (3) degrees and survey every 500! or less. BRWD 1 PROGRAM ~ .. NOTE: Become familiar with new AOGCC regulations prior to spudding· this well. 1. Drive 20" conductor to refusal. '~'-~ ~. 2. Move in and rig up the drilling rig. . Nipple up the 20" diverter system and 10" lines for down wind diverting. Earthern berms should be constructed at the outlet of each line to contain diverted fluids. Function test the diverter and valves. The AOGCC may witness the testing and will need 2~ hours prior notice. Clean out the conductor casing to the shoe with a 17'1/2" bit. Drill enough new hole to bury the BHA. 6. Drill a 12-1/~" hole to 2000' +/- or below the fresh water sands as follows: A. Run a pendulum BHA with stabilizers.at 60' and 90'. Be Plan the hydraulics with drill pipe annular velocity of 70+ FPM (370+ GPM) and 1700 PSI. C. Maintain optimum bit weight and rotary speed by running frequent drill- off tests. . Circulate and condition the mud and hole for logs. Make a wiper trip to the shoe of the conductor, and condition as required. Prior to pulling out of the hole, obtain a 1/2 gallon mud sample. Pull out of the hole, and SLM. . Rig ,up Schlumberger, and run the following logs as directed by the well site geologist. A. DIL/SFL/SP/GR 2000' - SFC B. CNL/LDT/GR/CAL 2000' - SFC G. Sidewall cores as directed (anticipate 20). . Trip in the hole with a 12-I/~" bit, and condition the hole for casing. Circulate at least two hole volumes. Pull out of the hole. 10. Rig up and run the 9-§/g" OD q0#/FT K-55 BTC casing as follows: A. Float shoe on the bottom. B. Float collar one joint up. C. Thread lock the float equipment. D. 2000' 9-2/8" casing. E. Centralizers 2' above the shoe, 2' above the float collar, and then every other joint back to the surface. 11. Cement the 9-5/8" casing as follow= 12. 13. lq. A. Circulate a minimum of one circulation. B. Pump 20 BBLS of fresh water. C. Pump sufficient Class "G" · 6% Gel, 3% Salt, and 2% CaCI2 at 13.6 PPG to circulate cement to the surface. D. Tail in with 200 sks of Class "G" + 2% CaCI2 at 15.8 PPG. E® Displace the top plug, with drilling fluid, and bump the plug to 1500 PSI over displacing pressure. Check that the floats hold. F. Perform a top job with 1" tubing if cement does not circulate or if the cement falls. Cut off the 20" OD conductor and 9-5/8" OD casing. NOTE: Do not slack of! of the 9-5/8" casing for six (6) hours after cement is in place. Weld on the 9- 5/8" SOW x 11" 3000 PSI well head. Test to 1200 PSI. Nipple up the 13-5/8" 5000 PSI BOPE. Test the rams, manifold, surface valves, and annular preventer to 3000 PSI. The AOGCC may witness the testing and will need 2q hours prior notice. 15. Trip in the hole with an 8-1/2" bit, and clean out to the float collar. Prior to drilling the float e~uipment,~test the casing to 1500 PSI loc 30 minutes. . d .x..' 16. Drill the float collar, cement, and Sho~. Drill I0' off'new formation, and run a leak off test. Record the results on the Chevron and IADC tour sheets. Drill sufficient hole to bury the BHA. Pull out of the hole. 17. 18. 19. Drill an 8-1/2" hole to 3530' or TD as directed by the field geologist as follows: A. Run a pendulum assembly with stabilizers at 60' and 90'. Be Plan hydraulics so that the drill pipe annular velocity is 90+/- FPM (190 GPM) at 1700 PSI, C. Maintain optimum bit weight and rotary speed by running frequent drill- off tests. Condition the mud and hole for logs. Make a wiper trip to the shoe of the 9- 5/8" casing, and condition as required. Prior to pulling out of the hole, obtain a 1/2 gallon mud sample. Pull out of the hole, and SLM. Rig up Schlumberger, and run the following logs as directed by the well site geologist. A. DIL/SFL/SP/GR 3330'- 1500' 20. 21. B. BHC SONIC/SP/GR/CAL 3530'- 1500' C. CNL/LDT/GR 3530'- 1500' D. Sidewall cores as directed (Anticipate 50). Trip in the hole with an 8-1/2" bit, and condition the mud and hole for casing. Circulate at least two (2) hole volumes. Pull out of the hole, and lay down the drill string. Rig up and run the ?" OD 23#/PT K-55 BTC Casing as follows: A. Float shoe on the bottom. B. Float collar two joints up. C. Thread lock the float equipment. D. 3530' of 7" casing. i. Centralizers 5' above the shoe, 5' above the float collar, and every other joint back to the surface. 22. Cement the 7" OD casing as follows: 23. 2q. A. Circulate a minimum of one hole volume. B. Pump 20 BBLS of fresh water. Ce 250 sks of Class "G" + 12% Gel, I/0 LB/SK cellophane flakes, and retarders at 12.8 PPG as a preflush (this cement should circulate to the surface). De Sufficient Class "G" + retarders, friction reducers, and water loss additives for 100 cc or less fluid loss, 0% free water, pumping time, and temperature at 15.3 PPG. Circulate the top of this cement 500' into the 9-5/8" casing. E. Reciprocate the pipe in 10' strokes while cementing until just before the plug bumps. F® Displace the top plug with drilling fluid, and bump the plug to 2000 PSI over displacing pressure. G. Check that the floats hold. He Set the casing slips through the BOP stack. Set the full weight of the casing on the slips. Nipple down the BOP stack; cut off the 7" casing; nipple up the 11" 3000 PSI x 7-1/16" 3000 PSI tubing spool; and test to 1500 PSI. Nipple up the Class III 5000 PSI BOPE. Test the BOPE to 3000 PSI. The AOGCC may witness and will need 20 hdours prior notice. 25. 26. 27. 28. 29. 30. 31. 32. 33. 36. 37. 38. 39. Pick up, and trip in the hole with a 6-1/8" bit, tandem casing scrapers, 0-3/0" drill collars, and 3-1/2" drill pipe. Clean out to PBTD as directed. Circulate the well clean,}and test the casing to 1500 PSI for 30 minutes. ~.lean the mud pits, and disptace the well with lease water completion fluid. Pull out of the hole. Rig up Schlumberger, and run a GR/CCL/CET log from PBTD to the shoe of the 9-5/8" casing. If squeezes are required, a supplementary program will follow the CET. Rig up Schlumberger, and perforate the interval 3521' - 3060' (the exact net intervals will be determined after logging) using ~" casing guns with density and shot size to be determined later. Trip in the hole with a 6-1/8" bit, casing scraper, and drill string. Clean out to PBTD, and circulate the well clean. Perform injection test as required by Anchorage engineering. Lay down the drill string. Rig up Schlumberger, and run a permanent packer on wireline set as directed. Pick up and internally test in the hole to 5000 PSI the 2-7/8" 6.§I! N-80 8RD EUE tubing and seal assembly. Space out; sting into the packer; and land the tubing with sufficient weight as determined from tubing movement calculations. Test the annulus to 1500 PSI for 30 minutes. Nipple. down the BOPE. Nipple up the tree, and test to 3000 PSI. Clean the mud pits, and release the rig. V. lit. Angell SHEET,,, / OF / SHEETS PROPOSAL FOR WELL OPERATIONS DRILLING WELL PROGRESS CURVE Pro- 316-2 TIME-DAYS PRO-316-2 (CD-8-82) Printed in U.S.A. ~L/,~'O R,q~I_C Z I ! l<'lL [ C HZ-V~OH ~ 5. R. I~IC, ANNtJLAR PREVENTE I 3 5/8"-500C psi __ 13 5/8"- 500C psi DOUBLE GATE - 13 5/8"_ 5000 psi 2"- 5000 psi KILL LINE 2"- 5000 psi BULL PLUG TUBING HEAD '1 I I I ! I *'-13 5/8"-5000 ps~ ~ 7,J/6~3000 psi II "-3000 psi 3000 psi BLIND FLANGE SOW 3"-5000 psi TO MANIFOLD · · · · · I~ m . d~mm~ m ,mm~II~ m l, ',, CEMENT I ,I ~ · - .; o CLASS TTT BOP.,' ChevrQfl CHEVRON U.S.A. DIVERTER REQUIREMENTS SCHEMATIC: See the attached. /. EQUIPMENT LIST: 1 21=1/4" 2000 PSI APl flanged spool with two (2) 10" ANSI 150 PSI outlet flanges. I 10" 1 10" I 10" I 10" 2 10" 1 21- 1 ANSI 150 PSI blind flange ANSI 150 PSI x 10" 300 PSI API adapter spool 300 PSI full opening hydraulic actuated ball valve 150 PSI targeted TEE 150 PSI full opening hydraulic actuated ball valves. 114" 2000 PSI annular preventer 21-1/4" 2000 PSI x 20" SOW wellhead with two outlets with one outlet blanked off with a blind flange and one outlet with one (1) 3" 2000 PSI or higher rated gate valve. Sufficient 10" pipe to extend diverter line from the diverter spool to the targeted TEE beyond the edge of the substructure and sufficient 10" pipe to extend two (2) diverter lines a minimum of 100' in opposite directions from any ignition source. 1 10" 300 PSI weld end flange 3 10" 150 PSI weld end flanges Assorted flanges as required. OPERATIONAL PROCEDURE: I® The diverter system will be nippled up such that the line that extends from the diverter spool will be in a straight line to the targeted TEE. The down wind diverting lines from the targeted TEE will be in a straight line to the earthern berms located a minimum of 100' from any ignition source. . All lines will be securely tied down to prevent movement during diverting operations. All line connections will either be flanged or welded. 0 The annular diverter and hydraulic operated outlet valve will be nippled up to a remotely operated closing unit in a fail safe manner such that when the annular diverter is actuated to close, the valve automatically and ' simultaneously opens. The hydraulic operated valves for down wind diverting will be nippled up to a remotely operated closing unit in a fail safe manner such that when one valve is in the closed position the other valve will be open. The valves will also operate in a manner such that when the open valve is closed, the closed valve will simultaneously and automatically open. . All valves and lines will be constructed such that there will be no possibility of freezing. . . 10. In the event that there is flow while drilling~ close the diverter (automatically opening the diverter valve) and divert down wind. Circulate at the maximum pump rate while raising the mud weight. If the active system is depleted~ start pumping fresh water at the maximum rate in an attempt to initiate hole bridging. If a weighted mud does not kill the flow or if fresh water does not cause the hole to bridge~ then prepare to spot a cement plug. V/hen the flow is controlled~ it will be determined whether additional casing strings need to be set and at what setting depths. · V, qZVk- ,. · BRWD 1 DRILLING FLUIDS PROGRAM 12-1/~" Hole 8-1/2" Hole Mud Type Spud & Gel/Gelex Gel/Gelex LoW Solids Density (PPG) 8.8-9.2 9.0-9.# Funnel Viscosity (SEC/QT) 100+ bO - 50 Plastic Viscosity (CPS) 12- 18 Yield Point (LBS/100 FT2) 20 - 30 Gel Strength, Initial 6+/- Gel Strength, i0 Minute 15+/- pH 9.0 9.0 Chlorides Fresh Fresh Water Loss (APl) NC I0 - 5 PROGRAM . ® . It will be very important to maintain the drilled solids as low as possible with this system. All solids control equipment and agitation equipment must be working at all times. Spud the 12-1/4" hole with a fresh water-gel spud mud with low weight and solids. Drill to 2000' with viscosity as required for gravel and sand. Condition the mud to logging conditions prior to reaching 2000'. Condition the hole for logging operations, and make a wiper trip into the 20" conductor. After logging, condition the hole for the 9-5/8" casing. Pretreat for cement contamination. Drill out below the 9-5/8" casing with the same mud and drill 10' of new formation. Perform the leak off test. Drill to 3530' or TD as directed Condition the mud to logging conditions prior to reaching TD. Adjust the YP depending on the fill on connections and trips; tight hole on connections and trips; etc. Condition the hole for logging operations. Make a wiper trip into the 9-5/8" casing. 10. After logging, condition the hole for the 7" casing. STIR STIR STIR ADJUSTABLE OVERFLOW UNDERF LOW UNDERFLDW UNDERFLOW STIR STIR ~ ~ STIR STIR ~ SUCTION SUCTION SUCTION PILL PIT i00 BBLS DESA NDER ) UNDERFLOW ~ TO PUMP DESI L TE R ~.~ENTREFUGE TTO PUMP UNDERFLOW TO OVERFLOW pOUaLEI pet'<I TO RESERVE PIT FLOW LINE FROM BELL NIPPLE CHEVRON U.S.A. INC. GENERALI'ZED DRILLING FLUIDS PIT SCHEMATIC FOR BELUGA RIVER AND PRETTY CREEK U~IITS · .-... I'e~"J-i I ..,_.~.,_.~.. I A P -A-2 78 - 0 FORMATION EVALUATION PROGRAM BRWD-1 BELUGA RIVER FIELD, COOK INLET, ALASKA Instructions to Electric Loggers WELL SECURITY CLASSIFICATION "CONFIDENTIAL" No information will be released except by production or exploration depart- ment in conformance with existing policy. WELLSITE DEVELOPMENT GEOLOGIST N. D. Stone 3001 "C" Street, Room 164 Anchorage, AK 99503 (907) 786-6664 work (907) 694-5534 home GENERAL INSTRUCTIONS · . All logs are to be digitally recorded· A 1/2 gallon sample of circulated drilling fluid is to be obtained by logging engineer immediately prior to pulling drill pipe for logging operations. Sample is to be measured for R m, R mr, and R mc by logging engineer· · Two maximum recording thermometers are to be used on all logging sondes run in hole. Record both thermometer readings in "remarks" section of log heading. 4. All log calibrations are to be recorded and printed on 5''= 100' scale logs. 5. 2" = 100' and 5" = 100' logs are to be printed with separate headings· . A quality control check list is to be completed for each log run and attached to the 2" DIL-SFL, or 2" DLL-MSFL film. See wellsite geologist for check list. 7. Record all fil ms with heavy weight lines· . Repeat sections are to be presented on tail of 5" logs only. If hole conditions are severe, discuss with Chevron geologist before repeating. If hole conditions are favorable, repeat sections should be run over zone of interest. , 10. 11. Tie-in successive logs to previous runs by overlapping gam ma ray curves for a distance sufficient to establish high confidence in correlation. Log Dual Induction Log (or DLL) going down hole and record on tape and on 2'~100'film. Do not reduce speed below normal to improve quality of down log. All logging tools are required by Chevron policy to have been shop calibrated within 30 days of their use. Do not bring a tool to wellsite which cannot meet this requirement. INTERMEDIATE LOG RUN (+/-400ft. to intermediate TD, +/- 2OOO ft.). 1. DIL-SFL-G R 2" = 100' Log: 5" = 1 00' Log: Resistivity, linear 0-50 ohms conductivity, linear 0- 1000 mmho; SP, 10 millivolt divisions GR, 0-100 APl units. Resistivity 0.2 - 2,000 oh ms, logrith mic Display SP as solid line. 2. LDT-CNL-GR. Use 0-60 porosity unit scale. 3. SWS. Anticipate 20 SWS. TD LOG RUN (TD (+/-3540 ft.) to shoe of 9 5/8"csg). 1. DIL-SFL-G R-SP 2,,= 100' Log: 5"= 100' Log: Resistivity linear 0-50 ohms conductivity linear 0-1 000 m m ho; Resistivity logarithmic 0.2-2,000 ohms; GR 0-100 APl units; SP 1 0 m illivolt divisions. Display SP and'GR in track #1 for 2" and 5" logs. Show SP as a solid line curve. Eliminate amplified curve. Display shallow (SFL) and deep (IL D) curves on 2". Display ILS, ILD, and SFL on 5". 2. B H C Sonic - SP-G R: Display SP, G R, caliper, and bit size in track #1. Tension curve in track #3. Use 50-150 microsecond time scale. Transit time to be integrated & recorded. Run in combination with DIL. 3. LDT- CNL- GR: Use 0-60 porosity unit scale. Playback SP from prior log and display in track #1 0 Sidewall Coring (SWS): a) Anticipate +/- 50 SWS (one trip in hole with tandem guns). b) Bullets are to be designed for most efficient recovery? The formation is soft and the sands are often unconsolidated. c) SWS are to be sent for routine analysis to: PTS 4450 W. 50th Avenue Anchorage, AK 99502 (907) 243-2822 Bi Final 1 Data~ Composite Wireline Logs: Schlumberger to send the following for each log: original blue line prints rolled reverse sepias folded reverse sepia magnetic LIS tapes tO: Mike Gaetzman Chevron U.S.A. Inc. P.O. Box 1 07839 Anchorage, AK 99510 Mike Gaetzman will distribute final data sets as follows: 1 blue line print, 1 rolled reverse sepia,and 1 magnetic tape to: Jane Oetting Chevron U.S.A. Inc. 6001 Bollinger Dr., Room G-1344 Anchorage AK 99510 2 blue line prints, 1 rolled reverse sepia and 1 magnetic tape to: Mr. J. C. Havard ARCO Alaska P.O. Box 100360 Anchorage, AK 99510 2 blue line prints, 1 rolled reverse sepia and 1 magnetic tape to: Mr. R. G. Hollis Shell Western E&P Inc. P.O. Box 527 Houston, TX 77079 1 blue line print and 1 rolled reverse sepia to: J. L. Weaver Chevron USA Inc. Anchorage, AK 99510 1 blue line print, 1 folded reverse sepia and 1 magnetic tape to: AOGCC Attn: William Van Alen 3001 Porcupine Dr. Anchorage, AK 2 blue line prints to: Bureau of Land Management Attn: Joseph A. Dygas Anchorage District Office Assistant' District Manager Division of Mineral Resources 6881 Abbot Loop Toad Anchorage, Alaska 99507 *Chevron U.S.A., Anchorage, Alaska, will retain all original films CHEVRON U.S.A., INCORPORATED Underground Injection Control Permit No. AK-2DO001-I and Aquifer Exemption Response to Comments Received During the Public Notice and Public Hearings o A statement was made that the proposed project does not appear to affect the area of TyoneK. EPA concurs. 2~ Request was made to delete continuous recording requirements under Part I.A. of the permit because of the intermittent injection schedule and 40 CFR 146.23 does not require. The Agency has reviewed this request and agrees to delete the requirement for continuous recording devices. Instruments will be required, however, to monitor the injection pressure, flow rate, cumulative volumes and annular pressure. These measurements are required to be recorded monthly. 3, Concern was expressed that the Statement of Basis regarding the future use of. ground waters .in the area was not based on good judgement considering the proximity to Anchorage and that the Mat-Su Borough may, in the long-term future, sell 1,700 acres in the area for development. EPA agrees that it is difficult to predict the future growth and ground water needs. However, considering the depth of the injection zone and availability of surface and shallow ground water there should be adequate drinking water sources for future users. A correction to the Statement of Basis seems warranted since the community of Tyonek uses a lake (not ground water) for their drinking water. The Agency is unaware of any demographic data demonstrating the use of the exempted aquifer during the foreseeable future. . Concern that the area of review was limited.to 1/4 of mile radius around the well instead of one mile. Under 40 CFR 146.6(b) the EPA accepts the 1/4 mile area of review. Therefore, the corrective action data Chevron provided for wells within 1/4 mile of the injection well in the application are still valid. 5. Concern was expressed that more information regarding the toxicity of drilling muds and the accidental contamination of the injection fluid needs to be determined. The permit is written to allow only Class II fluids to be injected. The operator is responsible for maintaining the integrity of the fluids being injected and injection of other than Class II fluids would be non-compliance and subject to enforcement actions. Under 40 CFR 261.4 drilling muds, produced waters and other wastes associated with the exploration, development, or production of crude oil or natural gas are not hazardous wastes. . Concern was expressed whether the application was critically reviewed by a hydrogeologist, seismologist, and oil and gas expert. A hydrogeologist and civil engineer reviewed the application. , Concern was expressed for the verification of where the wastes actually go since expert predictions are often wrong. The calculations which show the injection fluids will remain in the injection zone are based on current technical knowledge regarding the flow of fluids in porous media. Monitoring wells would provide limited verification at the expense of breaching the integrity of confining zones protecting underground sources of drinking water. EPA Chanqes to Permit The tubing and packer will be required to a depth of 3540 feet since the confining zone exists from 3510 and 3540 feet. The modifications to Part I.A.1. and 2. are commensurate with good engineering design and operation and standard industry practice. For mechanical integrity under 40 CFR 146.8 the following is required: · Pressure test the casing-tubing annulus to 1,O00 psia for thirty minutes with a pressure .'loss not to exceed lO0 psia to demonstrate there is no significant leak in the casing, tubing or packer; and . Submittal of adequate cementing records to demons'trate there is no significant fluid movement through vertical channels adjacent to the well bore. PUBLIC NOTICE and STATEMENT OF BASIS CHEVRON U.S.A., INCORPORATED Produced Water Disposal Well and Aquifer Exemption UIC PERMIT NUMBER: AK-2DO001-I CONTACTS: Harold Scott U. S. Environmental Protection Agency Region lC, M/S 409 1200 Sixth Avenue Seattle, Washington 98101 Telephone: (206) 442-1846 or (FTS) 399-1846 DESCRIPTION OF FACILITY AND BACKGROUND INFORMATION: On February 1, 1985, Chevron U.S.A., Incorporated, Anchorage, Alaska, made application for an underground injection control permit for injection of produced waste brines into the Lower Sterling Formation. The BRWD-1 well is located adjacent to the Cook Inlet in the NE quarter of Section 13, Township 13N, Range lOW in Alaska. A maximum of 5,000 barrels of waste brines (produced waters, drilling muds, and completion fluids) will be injected each day through the BRWD--1 well to a depth of 3,540 feet below ground level. The aquifers deeper than 3,400 feet for a one mile radius around the well bore have been exempted. Chevron has submitted all required information and data necessary for permit issuance in accordance with 40 CFR Parts 124, 144, 146 and 147, and a final permit and aquifer exemption were issued on September 16, 1985, and effective October 21, 1985, unless review is granted under 40 CFR 124.19. The permit was issued for the operating life of the injection well, therefore, no reapplication will be necessary unless the permit is terminated for reasonable cause (40 CFR 144.39, 144.40, and 144.41). However, the permit will be reviewed every five years. This Statement of Basis gives the derivation of the site specific permit conditions and reasons for them. The general permit conditions for' which the content is mandatory and not subject to site specific differences (based on 40 CFR Parts 144, 146, and 147), are not included in the following discussion. SECTION A. CONSTRUCTION REQUIREMENTS Casing and cementinq: The well will be cased and cemented throughout the depth of the well according to Attachment L/M-2 except that the packer shall be placed at 3,540 feet. The construction features will prevent movement of fluids into or between underground sources of drinking water. Proposed changes and workovers: In order to provide EPA the opportunity to review any proposed changes and keep the permit file up to date, the permittee will be required to submit notice of planned changes. Copies of workover reports, etc. are needed to ensure compliance with the permit. SECTION B. CORRECTIVE ACTION The applicant submitted the required area of review information with the permit application. The applicant submitted detailed information on the~only two wells within this quarter mile: 1. A gas production well drilled to a total depth of 70,~(~/ has been properly cemented but shut-in since October 1975. 2. A water supply well drilled to 145 feet does not pass through the injection zone. All information was reviewed and it is EPA's determination that all USDNs are adequately protected. Therefore, no corrective action is being required. SECTION C. NELL OPERATION Prior to commencing injection: The permittee is required to submit a well completion report after the well is constructed. The report will be used to ensure that the well has been cemented adequately through the overlying confining zone and according to the construction plan. A demonstration of mechanical integrity is being required to ensure that the casing, tubing, and packer can maintain integrity and that fluid is not leaking from the casing. Mechanical integrity: A mechanical integrity test is required every five years to ensure the well continues to maintain integrity during the operational life of the well. Injection interval: The applicant requested an injection interval of 3540 to 4009 feet within the Lower Sterling Formation, therefore, the permit limits injection w~thin th~s interval. Injection will be ~nto the same formation from which the gas is produced. Injection pressure: The applicant requested a maximum operating in~ection pressure of 700 pounds per square ~nch absolute (ps,a), measured at the surface. EPA established a conservative maximum operating pressure formula ~n 40 CFR 147.103(b) which ~s designed to assure against fracturing of the in~ect~on zone. This formula, if applied to the proposed injection well, would allow injection at approximately 955 ps~a. By l~mit~ng the injection, pressure to 700 ps,a, however, as requested by the applicant, further safeguards against fracturing the ~njection zone and therefore the confining zone are built into the permit. Maintaining the integrity of the confining zone w~ll prevent fluid migration ~nto underground sources of drinking water. Annular fluid~ ~n~ection rate & flu}d lim~tations: All proposed operating characteristics that the applicant requested were accepted. In~ect~on rate is l~mited to 5,000 barrels of fluid per day. The fluid which ~s ~njected ~s 1}mired to produced water, drilling muds and completion fluids from both ex~st}ng sources and proposed future sources. The annular fluid ~s l~m~ted to a corrosion ~nh~b~ted, sodium chlor}de solution or diesel fluid. SECTION D. MONITORING, RECORDKEEPING, AND REPORTING OF RESULTS Injection well mon}tor~ng program: The permittee ~s required to monitor water qual}ty of the ~njected fluids at reasonable ~ntervals..Due to the high concentration of TDS ~n the water being injected, quarterly samples are required. These samples of ~njected fluids shall be analyzed for TDS, pH, Specif}c Conductivity, and Specific Gravity. The applicant projected that additional sources of water will be ~njected at some t~me in the future. Therefore, a comprehensive water quality analys~s ~s required when the source of ~njection fluids change. The permittee ~s required to observe the in~ect~on pressure, annular pressure, flow rate and cumulative volume weekly to ensure compliance w~th the permit. Monitoring information, recordkeeping, & reporting of results: The minimum requirements according to 40 CFR 146 have' been established. SECTION E. PLUGGING AND ABANDONMENT The plugging and abandonment plan submitted by the applicant with the permit application is incorporated into the permit and shall be binding on the permittee. The minimum requirements for pre-plugging notice (45 days) and post-plugging reporting (60 days) have been incorporated. In addition, if injection activities are halted for a period of more than two years, the permittee is required to plug the well or demonstrate that it will be used in the future and will not endanger the environment during temporary abandonment. SECTION F. FINANCIAL RESPONSIBILITY The applicant submitted a copy of the 1983 Standard Oil Company of California Annual Stockholders' Report. This demonstration meets all financial responsibility requirements. The permit includes provisions for an annual update of the financial data so that EPA can ensure continuous compliance with the financial responsibility demonstration. SECTION G. EXEMPTED AQUIFERS The formations into which Chevron proposes to inject are considered to be "underground sources of drinking water" or "USDWs" by EPA's UIC definitions. EPA considers all waters of less than lO,O00 mg/1 total dissolved solids (TDS) to be a USDW; the proposed injection formation contains waters of approximately 2,600 mg/1TDS. By EPA rules, injection into a USDW is illegal, therefore, the injection activity will only be allowed in the aquifers exempted as a USDW. EPA has established in 40 CFR 146.4 the exemption criteria. An aquifer or a portion thereof which meets the criteria for a USDW may be determined to be an exempted aquifer if: It does not currently serve as a source of drinking water; and It cannot now and will not in the future serve as a source of drinking water because: a. It is mineral, hydrocarbon or geothermal energy producing, or can be demonstrated by a permit applicant as part of a permit application for a Class II or III operation to contain minerals or hydrocarbons that considering their quantity and location are expected to be commercially producible. b. It is situated at a depth or location which makes recovery of water for drinking water purposes economically or technologically impractical. c. It is so contaminated that it would be economically or technologically impractical to render that water fit for human consumption; or d. It is located over a Class III well mining area subject to subsidence or catastrophic collapse; or Alaska Oil & Gas Cons,, Commission . The total dissolved solids content of the ground water is more than 3,000 and less than 10,000 mg/1 and it is not reasonably expected to supply a public water system. EPA exempted the aquifers deeper than 3,400 feet, for a one mile radius from the well bore, for the following reasons: They are not currently being used sources of drinking water. They cannot now and will not in the future serve as sources of drinking water because: a. The aquifers are hydrocarbon producing (the field was discovered in 1962 and had produced some 161 billion cubic feet of gas as of January l, 1984); and, b. They are situated at depths which makes recovery of water for drinking purposes economically and technologically impractical. The aquifer exemption will only allow for the operation of the Class II (oil and gas) injection well. The injection of hazardous waste will not be allowed by this exemption. Over the estimated life of the well (25 years), it is estimated that the extent of migration, from the well bore, will be approximately 700 feet. This determination is based on the following relationship: V ] '/2 radius : 3.14 Oh V = volume (cubic feet) of injected fluid. In 25 years the volume is estimated to be 122.9 million cubic feet. 0 : formation porosity of 0.30 h = average reservoir thicKneSs of 250 feet radius : 122.9 x lO6 ft.3 (3.14)(.30)(250 ft.) radius = 722 feet In order to assure that the fluids remain within an exempted aquifer zone, a one mile radius was authorized. The one mile radius will also compensate for several assumptions in the above formula which tend to underestimate the extent of migration. Above the injection zone, 30 feet of shale and coal serves as a confining zone which effectively prevents the upward migration of injection fluids. The integrity of this confining zone is established by its ability to contain the gas. Construction features of the injection well will assure that no upward fluid migration along the well bore can occur. Presently there are 15 water wells in the shallow aquifers of the Beluga River Field of which three are used for drinking water. Most wells are drilled to an average depth of 100-200 feet of which three are deeper, with the deepest being 515 feet. According to the 1974 Alaska Regional Profiles, Volume I, these shallow aquifers consist of abundant good quality water. Formed by unconsolidated deposits of sand and gravel, silt and clay, the aquifers are capable of supporting wells yielding lO-lO0 gallons per minute. The nearest community, Tyonek (pop. 325), is about 12 miles southwest from the in~ection well. Tyonek uses a lake as their source of drinking water. The in~ection well will not affect the Tyonek water supply. Future domestic uses of the shallow aquifers in the Beluga area are expected to be very limited as no permanent population is expected in the immediate area in the foreseeable future. It is doubtful that the proposed exempted aquifers would ever be needed for domestic supply due to the limited demand on the shallow aquifers and the abundant water they could supply. The March 1983 U.S. Department of Agriculture Susitna River Basin Study (Cultural Resource Assessment of Willow-Talkeetna-Beluga Areas) states that much of the area is boggy. This may further discourage any permanent population in the area. Alternatives to the proposed in~ection well are discharge to Cook Inlet, surface impoundments, or in~ection into deeper formations. Discharge to Cook Inlet is prohibited by 40 CFR 435.30-.32 requirements. Surface impoundments would significantly disrupt the land surface, may potentially contaminate the important shallower aquifers, and may not be practical due to the volume of wastes to be contained. It does not appear to be justified to require injection into deeper formations since this would increase the cost of construction of the in~ection well and the proposed injection zone fully qualifies for an aquifer exemption for the reasons cited above. Operation of the proposed injection well will result in produced fluids being returned to the same formation from which they were initially removed during gas production. The proposed in~ection well is on land owned by the Cook Inlet Region, Incorporated. SECTION H. PERMIT APPEAL PROCEDURES Under 40 CFR 124.19 any person who filed comments on the draft permit and aquifer exemption, or particiPated in the public hearing may petition the Administrator to review any condition of the permit decision. Any person who failed to file comments or failed to participate in the public hearing may petition for administrative review only to the extent of the changes from the draft to the final permit decision. Petitions must be received by Harold Scott at the above address before October 17, 1985. Petitions shall include a statement of the reasons supporting the'review, including a demonstration that issues being raised were raised during the public comment period (including public hearings), and, to the extent required by the regulations, a showing that the condition in question is based on: 1. A finding of fact or conclusion of law which is clearly erroneous, or o An exercise of discretion or an important policy consideration which the Administrator should in h~s discretion, review. A decision by the Administrator to grant the review shall be conducted in accordance with 40 CFR 124.10. Notice of denial of review shall be sent only to the person(s) requesting review. Persons making an appeal are advised to review 40 CFR 124.19. ('9. ,thru 13) ~(10 and (14 thru 22) .. (5) BOPE (23 thru 28) (29 thru 31) Geology: JAn En$ine~ering: ncs /' rev: 04/03/86 ". 011 the permit fee: attached " · ,. Is well to be located in a defined p0ol ...................... .ili~3, Is well located proper distance from property line ........... ~::4,'Is well located proper distance from other wells., ........... 5. Is sufficient undedicated acreage avail~le in this pool .~ .l~,., · ,~.:6. Is well to be deviated and is wel~ore at included ................ ,'"7. Is operator the o affected party ................................. , ,~i~:!,8. Can permit be approved before ten'day wait ........................... ,, 9, Does operator have a bond in force ................................... :i0. Is a conservation order needed .' ................ ' ..... 11.. Is adatinistrative a proval needed .................. '~12o Is the lease nuatber ~propr±ate 13, Doe~ the ~ell have a unique name and , 'LeaSe & Well No. YES : NO ,, , 14. Is cOnductor string provided ........................................ 15. Will surface casin~ protect fresh water zones ....................... 16. Is enough cementused to circulate on conductor and surface'. ........ 17. Will cement tie in surface and tntermediate or production strings ... 18. Will cement cover all known productive horizons ..................... 19. Will all casing gt~ze adequate safety in collapse, tension and burst.. 20. Is this well to be'kicked off from an existing wellbore ............. .21. Is old wellbore abandomment procedure included on 10-403 ............ 22. Is adequate wellbore separation proposed ............................ 2'3. 24. 25. 26. 27. 28. Is a diverter system required ....................................... ~ Is 'the drilling fluid program, schematic and list of equipment adequate~f~/ Are necessary diagrams and descriptions of diverter and BOPE attached.~ Does BOPE have sufficient pressure rating - Test to ~OOC) psig .. Does the Choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones ............ 31. If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE 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, information, of this nature is accumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically organize this category of information. LVP O[O.HOZ VERIFICATIO~.LISTINS PAGE: HELL SITE DATA A~D TABLES ARE NOT:' INCLffDED IFl~'TtlI$ LISTI~G ~' wAvEFORMS' AND F~ST C~NN=L D~T'A A'RE ~OT [Nc:LU'DED~.IN' THIS~LZSTZ~ ~'~' . LVP.O'IDoHO2 VERIFIC~TIO~ LISTINS 2 PAGE ~-~: REEL. HEADER ~.~ SERVICE-: NA~E :EDIT' DATE :85/0.5/29 ORIGIN : REEL~ NAqE : CoN'r[NU~,TZ,.DN ~1 ~01 PREVIOUS REEL COMMENTS' :LIBRARY TAPE ~ TAPE HE~DER SERVICE NAME :EDIT DATEi :85/05/29 ORI2IN; :FS1A TAPE -NA.~IE CO~TINU~TZON. ~ :01 PREVIOUS' T~PE COMMENTS' :LIBRARY TAPE EOF ~***~**~*~:: e*.FIL'E:HE~DER FZLE. N6RE: :EDIT .001 SERVZCE NA~E : ~ERSIO~.I : DATE : MAXIMUM:LEnGTH :. 1024 FILE. TYPE PREfIDU$ FILE ************************************************************************************ ~' SC~LUMBERGER~ -' ,.- ALASKA'CO. NPUTINGiCE~TER. COMPANY =, &HEV. RON'.USA' INC' ' WELL~ = BRWD'I FIELD, m BELUGA RIVER COUNTY = KEN~I STATE' = ALAS~-A LVP 010oHOZ ¥-ERIF[CATIO~'ILISTZN$ PAGE S JOB NUMBER AT ACC:. 71&91' RUN' #2, DATE L'gGGEO= -Z1. MAY LDpr: RI~,K KRUWELL L~ CASING = g°625 TYPE FLUID = FRESH .GEL.' )EN'SZTY =: 9,& LB/3 VZS:OSZT? = ~7 S' PH- FLUID LOSS = 198,5 BZT $iIZE =: 8°5" R:~F R~:: AT:: BFIT: 3520"- = 3-&50 a: SZ: DF =' 3°ZSO. ~) SS OF = 3.650 .~ 5~': DF: = 1-976:~ 9& OF MATR,~X-r SANDSTONE SCHLUqBERSE'R LOGS ZNCLUDED!WJ:TH: t~I$ .R:AGNETIC:!TAPE: D~AL. INDJCTIO~S'P~'ERICALLY F3CUSE~-~ DAT~ A~[LABLE= 351~ TO 1980' BgREHOLE COMPENSATED LOG 3Ata AVaiLABLE: LJTHO OE~SZTY CDMPENSATEO LOG:CLOT) . LYP 010.HOZ. VERIFICATIO~ LIST~N~ PAGE: · CDHPENSATED ~EUTR~N LOG (LDT) DATA AVaiLABLE:. 3517, TD 1870', ALASKA CDHPUT[NG CENTER CO:,qPANY = :HEVRON USA ldE LL:. =' BRklO-1 · F:]:ELD = BEL U.GA COdNITY = KEN',I: . . S T.e,T E = AL A S ,"<,A S JOi~ NUqBER. AT. ACC= 71485 RUNr #D~IEt DATE LOGGED: 16 ~t0,¥ 85 LDP:..T HIALSTEAO .. . L C;AS:]:NG = zO.O" a 96"'- - TYPE FLL/]:D = ,'=RES"I RES" : DEhlS:]:TY =. ~..2 LB/$ . V]:SCDS]:TY = lr~.O S RR ~,T $~T PH := 10. ~. 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REEL NAME : CO~RENTS-:LIBRAR¥ TAPE **~**~e** -999.2-500 p 1Z ....... SCH~ LJMBE~GER .... $. L iS TA'~E CE,~IFICATION LIS.TING LVm OlO.M02 VEP. IFiCATI]'~ LISTIN$ pA~$F- 1 SERVICE NA~E :EOiT 3RI~IN : R55L N~M~ :1~041 ZOqTIN~TION # :01 PR~ViOJS REEL : ~rOMM~NT5 .'LIBRARY, TAP; ~ ....TAPr' HE&DER :',:* S~RVICE NAME :EDIT -DATE :35/05/Z0 DRISIN :FS1A TA~E N~ME : CO~TINU~TIDN e :01 PREVIO'JS TAPE : COM'qENTS :LIBRARY TAPE ~ :ILE HEADER ~q: mILE NAME :EDIT S~RVICE NAME : VERSION ~ : DATE : MAXIMUM LENGTH ~iL5 TYPE : PREVIOUS FILE ......INFORMATION .001 : 1024 : RECORDS MNEtq CONTENTS JNiT TYPE C~TE SIZE CODE Im--~ ~---- --mi-- CN : CHEVRgN USA 000 WN : BR~D-1 000 ~N : BELUGA ~IVER 000 RANS: 10 ~ 000 TONN: 1~ N 000 SECT: 13 OOO ~OJN: K.ENAI 000 ST~T: ALASKA 000 ~ANEM CONTENTS UNIT TYPE PRES: E 000 012 065 300 005 085 000 012 065 000 00~ O65 000 004 O65 000 002 000 005 065 000 005 065 ~TE STZE r-~: 000 000 001 065 LVP 010.H02 VERIFICATI3~ LISTIN; RAGE 2 ::: S CH LU M ":: ALASKA CDMPUTING Cr-NTER · , ..... ,- .,- -,- -,- -,- -,- -,- ::~ ;',.: "' ~,- )',-' :~ :X,,- :;~ ~: ¥ ...... ""' "'" ............. " .... 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SERVICE NA~E :EDIT D~TE :8~05/20 ~RISIN :FSiA TAPE NA~E : SS~TINdATI]N ~ :O1 N~XT TA~E ~AME : CgMMENTS :LIBRARY TAPE q:.,-~' REEL TRAILER ',-~'~",' SERVICE NAME :EDIT DATE :~5/05/20 ]RISIN : REEL NAIE :144041 CONTINUATI3N ~ :01 NEXT REEL AAME : COMmeNTS :LIBRARY TAPE ~:~:~ ........ 31.2705 -999.2500 -999.2500 -999.2500 -999.2500 CALZ NPdt TNR~ TNP~ -999.2500 -999.2500 -9~9.2500 -999.2500 -999.2500 LIS - v ~ 'r ~, l"l -'4 :.T,- ~-zqVlC.-2 N,'A',IE :-- .DATE :8610-.5121 ~i3!N : ~R~v'i~JS, ~ REEL : .JO1 I074 '4N: '4 C3qT :N TS SN : Cm~-VR3'~ 4N : 3R4D-1 RA"~3: lO^! TC,4~:,.' 13~I SEST: 13 3.3 J ~,,i: KE'4~i 5 l',~T: ALASKA ST?Y: OSg USA, '4N: '4 ' DXiT z,,,!T S TY~ 03 0 00 0 TYP~ 000 S~TE 3OO 3OO 3OO 300 OO5 0~ SiZc 001 O55 065 O65 O55 365 055 L"~ I"I I I I i-i 1 ii:-] ~[~ [:-] ~ ~ VD ~i~ ~D~ V~FZ~TT~q LI~TiN~ RUX~ L3P gAS TYP ;!l S .=LJ ',!AT :~: :I: :','- h. 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