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Home My WebLink About163-002Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/16/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240116 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 09A 50133204450100 224113 10/26/2024 YELLOWJACKET SCBL BCU 12A 50133205300100 214070 8/21/2024 YELLOWJACKET GPT-PLUG-PERF BRU 233-23T 50283202000000 224088 12/28/2024 AK E-LINE PPROF BRU 233-27 50283100260000 163002 12/31/2024 AK E-LINE PPROF BRU 243-34 50283201240000 208079 12/27/2024 AK E-LINE PPROF GP 03-87 50733204370000 166052 12/25/2024 AK E-LINE CBL GP AN-17A 50733203110100 213049 12/16/2024 AK E-LINE CBL GP AN-17A 50733203110100 213049 12/21/2024 AK E-LINE Perf GP BR-03-87 50733204370000 166052 1/3/2025 AK E-LINE CBL IRU 44-36 50283200890000 193022 1/3/2024 AK E-LINE Depth Determination/Plug IRU 44-36 50283200890000 193022 12/26/2024 AK E-LINE DepthDetermination KU 31-07X 50133204950000 200148 12/3/2024 AK E-LINE Perf MPU B-21 50029215350000 186023 1/4/2025 AK E-LINE PlugSettingRecord MPU H-08B 50029228080200 201047 12/28/2024 AK E-LINE Welltech MRU G-01RD 50733200370100 191139 12/12/2024 AK E-LINE IPROF MRU G-01RD 50733200370100 191139 12/18/2024 AK E-LINE Perf MRU M-25 50733203910000 187086 12/3/2024 AK E-LINE Perf MRU M-25 50733203910000 187086 12/19/2024 AK E-LINE Perf PBU 01-37 50029236330000 219073 11/23/2024 HALLIBURTON PPROF PBU 06-05 50029202980000 178020 12/21/2024 HALLIBURTON RBT PBU 06-19B 50029207910200 224095 12/11/2024 HALLIBURTON RBT PBU 11-38A 50029227230100 198216 11/27/2024 HALLIBURTON TEMP PBU 14-31A 50029209890100 224090 11/11/2024 HALLIBURTON RBT PBU L-103 50029231010000 202139 11/25/2024 HALLIBURTON IPROF PBU M-207 50029238070000 224141 12/25/2024 HALLIBURTON RBT PBU P2-55 50029222830000 192082 12/5/2024 HALLIBURTON PPROF PBU S-15 50029211130000 184071 11/18/2024 HALLIBURTON RBT TBU M-25 50733203910000 187086 12/13/2024 AK E-LINE Perf T39958 T39959 T39960 T39961 T39962 T39963 T39964 T39964 T39965 T39966 T39966 T39967 T39968 T39969 T39970 T39970 T39971 T39971 T39972 T39973 T39974 T39975 T39976 T39977 T39978 T39979 T39980 T39981 BRU 233-27 50283100260000 163002 12/31/2024 AK E-LINE PPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.16 13:56:40 -09'00' GCW 04/14/23 JLC 4/14/2023 04/17/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.04.17 18:06:57 -08'00' RBDMS JSB 041823 By Anne Prysunka at 2:51 pm, Jul 27, 2022 Kaitlyn Barcelona Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Date: 07/18/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL Well API # PTD # Log Date Log Company Log Type Notes AOGCC Eset # BRU 212-24 50283200370000 172015 7/27/2022 AK E-Line CIBP BRU 233-27 50283100260000 163002 7/2/2022 AK E-Line PERF HVA B-16 50231200400000 212133 6/23/2022 AK E-Line PLUG/CEMENT KBU 11-08Z 50133206290000 214044 6/22/2022 AK E-Line PERF KBU 33-06X 50133205290000 203183 6/18/2022 AK E-Line PLUG/CEMENT/PUNCH MPU I-17 50029232120000 204098 7/9/2022 Read CALIPER SRU 32A-33 50133101640100 191014 6/20/2022 Halliburton TMD3D-WFL + Report Please include current contact information if different from above. T36794 T36795 T36796 T36797 T36798 T36799 T36800 Kayla Junke Digitally signed by Kayla Junke Date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ll BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:1 DATE: 6/17/22 Rig Rep.: Rig Phone: 907-659-2434 Operator: Op. Phone:907-777-8300 Rep.: E-Mail Well Name: PTD #11630020 Sundry #322-248 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/2800 Annular:NA Valves:250/2800 MASP:1694 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig NA Lower Kelly 0NA PTD On Location P Hazard Sec.NA Ball Type 0NA Standing Order Posted NA Misc.NA Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 1.75" top load P Trip Tank NA NA Annular Preventer 0 NA NA Pit Level Indicators NA NA #1 Rams 1 1.75 B/S P Flow Indicator NA NA #2 Rams 1 1.75 B/S P Meth Gas Detector NA NA #3 Rams 1 1.75 Slips P H2S Gas Detector NA NA #4 Rams 1 1.75 Pipes P MS Misc 0NA #5 Rams 0 NA NA #6 Rams 0 NA NA Quantity Test Result Choke Ln. Valves 1 2x2 FMC P Inside Reel valves 1P HCR Valves 0 NA NA Kill Line Valves 2 2x2 FMC P Check Valve 1 2" 1502 P ACCUMULATOR SYSTEM: BOP Misc 3 EQ PORTS P Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)1600 P Quantity Test Result 200 psi Attained (sec)15 P No. Valves 5P Full Pressure Attained (sec)62 P Manual Chokes 2P Blind Switch Covers: All stations Yes Hydraulic Chokes 0NA Nitgn. Bottles # & psi (Avg.): NA NA CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:3.0 Hours Repair or replacement of equipment will be made within NA days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 6/14/22 09:23 Waived By Test Start Date/Time:6/17/2022 17:00 (date) (time)Witness Test Finish Date/Time:6/17/2022 20:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Schlumberger A push/pull test was conducted on the slip rams. Bryan Mclellan with AOGCC approved testing BOPs to 2800 psi instead of 3500 psi as written on Sundry 322-248. Bryson Lowe Hilcorp Brad Gathman BRU 233-27 Test Pressure (psi): brad.gathman@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0617_BOP_Schlumberger1_BRU_233-27 9 9 9 9 9 9 9 99 9 9 9 MEU -5HJJ approved testing BOPs to 2800 psi instead of 3500 psi CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:AOGCC Records (CED sponsored) Subject:Fwd: 10-403 BRU 233-27 PTD 163-002_Sundry_322-196_Approved_042122 (need to add coil cleanout) Date:Sunday, May 1, 2022 10:32:27 PM Attachments:image001.png From: "McLellan, Bryan J (OGC)" <bryan.mclellan@alaska.gov> Date: May 1, 2022 at 10:31:13 PM AKDT To: Jacob Flora <Jake.Flora@hilcorp.com>, "McLellan, Bryan J (OGC)" <bryan.mclellan@alaska.gov> Subject: Re: 10-403 BRU 233-27 PTD 163-002_Sundry_322-196_Approved_042122 (need to add coil cleanout) Jake, approval is granted to do the FCO with CT as you outline below. I’ll ad these steps to the sundry. Bryan Sent from my iPhone On Apr 29, 2022, at 9:45 AM, Jacob Flora <Jake.Flora@hilcorp.com> wrote: Bryan, Would you like a new sundry for adding the coil cleanout on this well? It’s no issue on our side and I wanted to ask your preference, Thanks, Jake From: Jacob Flora Sent: Thursday, April 28, 2022 10:45 AM To: bryan.mclellan@alaska.gov Subject: 10-403 BRU 233-27 PTD 163-002_Sundry_322-196_Approved_042122 (need to add coil cleanout) Hi Bryan, The below well, BRU 233-27, we recently were approved to add perfs in the beluga per the subject line sundry. On this sundry I permitted all the desired sands, even with some of them below top of fill. We recently obtained a new slickline tag and now want to clean the well out with coil to access those deeper perf intervals. Can we attach the below coil steps to the approved sundry to add the fill cleanout? I’ve attached the coil BOP diagram and N2 SOP. Thanks, Jake Coiled Tubing Procedure: 1. MIRU Coiled Tubing, PT BOPE to 3500 psi Hi 250 Low. 2. SI well. 3. Route well production to open top diffuser 400 bbl tank. 4. RIH w/ 1.75” coil w/ jet nozzle BHA. a. Top of fill was recorded to be @ 4008’. Engage fill and clean out to 5,230’ (below bottom perf) using nitrogen if necessary to lift. b. Blow well dry while holding back pressure to prevent more solids from entering well bore. 5. Leave 1,000 psi on well. RDMO CTU. Jake Flora | Kenai Ops Engineer | Hilcorp Alaska | 720-988-5375 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. 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цϰ͕ϬϱϲΖ цϰ͕ϬϱϵΖ ĞůƵŐĂϱ цϰ͕ϬϴϲΖ цϰ͕ϬϵϱΖ ϵΖ цϰ͕ϬϴϲΖ цϰ͕ϬϵϱΖ ĞůƵŐĂϱ цϰ͕ϭϮϮΖ цϰ͕ϭϯϮΖ ϭϬΖ цϰ͕ϭϮϮΖ цϰ͕ϭϯϮΖ ĞůƵŐĂϲ цϰ͕ϭϵϲΖ цϰ͕ϮϬϭΖ ϱΖ цϰ͕ϭϵϲΖ цϰ͕ϮϬϭΖ ĞůƵŐĂϲ цϰ͕ϮϬϴΖ цϰ͕ϮϭϱΖ ϳΖ цϰ͕ϮϬϴΖ цϰ͕ϮϭϱΖ ĞůƵŐĂϲ цϰ͕ϮϭϵΖ цϰ͕ϮϮϲΖ ϳΖ цϰ͕ϮϭϵΖ цϰ͕ϮϮϲΖ ĞůƵŐĂ&ϰ цϰ͕ϯϮϴΖ цϰ͕ϯϯϴΖ ϭϬΖ цϰ͕ϯϮϴΖ цϰ͕ϯϯϴΖ ĞůƵŐĂ&ϰ цϰ͕ϯϳϯΖ цϰ͕ϯϳϴΖ ϱΖ цϰ͕ϯϳϯΖ цϰ͕ϯϳϴΖ ĞůƵŐĂ&ϰ цϰ͕ϯϴϲΖ цϰ͕ϯϵϭΖ ϱΖ цϰ͕ϯϴϲΖ цϰ͕ϯϵϭΖ ĞůƵŐĂ&ϱ цϰ͕ϰϮϯΖ цϰ͕ϰϮϴΖ ϱΖ цϰ͕ϰϮϯΖ цϰ͕ϰϮϴΖ ĞůƵŐĂ&ϲ цϰ͕ϰϴϬΖ цϰ͕ϰϴϴΖ ϴΖ цϰ͕ϰϴϬΖ цϰ͕ϰϴϴΖ ĞůƵŐĂ' цϰ͕ϴϬϳΖ цϰ͕ϴϭϯΖ ϲΖ цϰ͕ϴϬϳΖ цϰ͕ϴϭϯΖ ϭϬ͘ ZĞƚƵƌŶƚŽƉƌŽĚƵĐƚŝŽŶ ͲůŝŶĞWƌŽĐĞĚƵƌĞ;ŽŶƚŝŶŐĞŶĐǇŝĨǁĂƚĞƌŝƐĞŶĐŽƵŶƚĞƌĞĚĂĨƚĞƌƉĞƌĨŽƌĂƚŝŶŐͿ ϭ͘ /ĨĂŶǇǌŽŶĞƉƌŽĚƵĐĞƐǁĂƚĞƌŽƌŶĞĞĚƐŝƐŽůĂƚĞĚ͗ Ϯ͘ D/ZhͲ>ŝŶĞĂŶĚƉƌĞƐƐƵƌĞĐŽŶƚƌŽůĞƋƵŝƉŵĞŶƚ͘WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬϬƉƐŝ͘ ϯ͘ Z/,ĂŶĚƐĞƚƉůƵŐǁŝƚŚϯϱ͛ĐŵƚƚŽƉĂďŽǀĞƚŚĞƉĞƌĨŽƌĂƚŝŽŶƐKZƐĞƚƉĂƚĐŚŽǀĞƌƚŚĞǁĞƚƉĞƌĨŽƌĂƚŝŽŶƐ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ĐƚƵĂů^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ ŽŝůdƵďŝŶŐKWŝĂŐƌĂŵ ϰ͘ EŝƚƌŽŐĞŶ^KW ϱ͘ K'ZtKŚĂŶŐĞ&Žƌŵ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚǇ͗:D&ϬϰͬϮϳͬϮϮ ^,Dd/ ĞůƵŐĂZŝǀĞƌhŶŝƚ tĞůů͗ZhϮϯϯͲϮϳ >ĂƐƚŽŵƉůĞƚĞĚ͗ϴͬϭϭͬϭϵϵϯ Wd͗ϭϲϯͲϬϬϮ W/͗ϱϬͲϮϴϯͲϭϬϬϮϲͲϬϬ ϯϲ͟ ϭϬͲϯͬϰ͟ ϳ͟ Z<ƚŽD^>сϭϬϰ͛Z<ƚŽ'>сϭϱ͛ dсϱ͕ϲϴϬ͛dsсϱ͕ϲϴϬ͛ Wdсϱ͕ϲϮϬ͛dsсϱ͕ϲϮϬ͛ DĂǆŶŐůĞсϭ ĚĞŐΛϴϬϬ͛ dƵďŝŶŐDŝŶ /сϮ͘ϳϱ͟ dKΛϮ͕ϵϲϬ͟ ϰ ϱ ϲ ϳ ϴ ϵ ϭϬ ϭϭ ϭϮ ϭϯ ϭϰ ϭϱͬϭϲ ϭϳ ϭϴ ϭϵ ϮϬͬϮϭ Wϭ ^ƚĞƌůŝŶŐ^ĂŶĚƐ & & & ' , ϭϲ͟ Ϯ ϯ ϭ dĂŐŐĞĚ ϱ͕ϮϮϴ͛dD ϭϭͬϮϭͬϮϭ ^/E'd/> ^ŝǌĞ dǇƉĞ td 'ƌĂĚĞ ŽŶŶ / ƚŵ ϯϲΖΖ ŽŶĚƵĐƚŽƌ tĞůĚ ϮϴΖΖ ϮϵΖ ϭϲΖΖ ^ƵƌĨĂĐĞ ϳϱη :Ͳϱϱ ϴƌĚ ϭϱ͘ϭϮϰΖΖ ϯϬϯΖ ϭϬͲϯͬϰΗ /ŶƚĞƌŵĞĚŝĂƚĞ ϱϭη WͲϭϭϬ ϴƌĚ ϵ͘ϴϱΖΖ Ϯ͕ϰϬϬΖ ϳΖΖ WƌŽĚƵĐƚŝŽŶ ĂƐŝŶŐ Ϯϲη WͲϭϭϬ ϴƌĚ ϲ͘ϮϳϲΖΖ Ϯ͕ϮϲϱΖ ϳΖΖ WƌŽĚƵĐƚŝŽŶĂƐŝŶŐ Ϯϲη EͲϴϬ Ƶƚƚ ϲ͘ϮϳϲΖΖ ϱ͕ϮϮϱΖ ϳΖΖ WƌŽĚƵĐƚŝŽŶĂƐŝŶŐ Ϯϲη WͲϭϭϬ Ƶƚƚ ϲ͘ϮϳϲΖΖ ϱ͕ϯϬϱΖ dh/E'd/>^ ϯ͘ϱΗ WƌŽĚƵĐƚŝŽŶ^ƚƌŝŶŐ ϵ͘Ϯη EͲϴϬ dͲŵŽĚ^ƉĞĐŝĂů Ϯ͘ϵϵϮΖΖ ϱ͕ϮϰϲΖ :t>Zzd/> >ŽŶŐ^ƚƌŝŶŐ /͘ĞƉƚŚ D ĞƉƚŚ ds/;ŝŶ͘Ϳ ĞƐĐƌŝƉƚŝŽŶ ϭ ϭϱ ϭϱ ϯ͘ϱ ĂŵĞƌŽŶ dƵďŝŶŐ,ĂŶŐĞƌ Ϯ Ϯ͕ϴϵϵ Ϯ͕ϴϵϵ Ϯ͘ϴϭϮ ĂŵĐŽΖtͲϭΖ^ĞůĞĐƚŶŝƉƉůĞ ϯ Ϯ͕ϵϰϬ Ϯ͕ϵϰϬ Ϯ͘ϴϲϳ ĂŵĐŽDD''ĂƐ>ŝĨƚDĂŶĚƌĞů͕ϯ͘ϱΗǆϭ͘ϱΗ͕ϭ͘ϱΗsǁͬZ<>ĂƚĐŚ͕ůŽƐĞĚϴͬϭϭͬϵϯ ϰ Ϯ͕ϵϴϵ Ϯ͕ϵϴϵ ϯ ĂŬĞƌΖ&,>ΖZĞƚƌŝĞǀĂďůĞWĂĐŬĞƌ͕ϱϬŬη^ŚĞĂƌZĞůĞĂƐĞ ϱ ϯ͕Ϭϲϳ ϯ͕Ϭϲϳ ϯ ĂŬĞƌΖ&,>ΖZĞƚƌŝĞǀĂďůĞWĂĐŬĞƌ͕ϱϬŬη^ŚĞĂƌZĞůĞĂƐĞ ϲ ϯ͕Ϭϳϴ ϯ͕Ϭϳϴ Ϯ͘ϴϲϳ ĂŵĐŽDD''ĂƐ>ŝĨƚDĂŶĚƌĞů͕ϯ͘ϱΗǆϭ͘ϱΗ͕'>sƐĞƚϰͬϮϭͬϮϮ ϳ ϯ͕ϬϵϮ ϯ͕ϬϵϮ Ϯ͘ϵϵϮ ůĂƐƚũŽŝŶƚƐ͕ϯ͘ϱΗEͲϴϬd;ϯϱϵĨƚ͘Ϳ ϴ ϯ͕ϰϱϭ ϯ͕ϰϱϭ Ϯ͘ϵϵϮ ůĂƐƚũŽŝŶƚƐ͕ϯ͘ϱΗEͲϴϬdͲDŽĚ;ϭϳϳĨƚ͘Ϳ ϵ ϯ͕ϲϯϰ ϯ͕ϲϯϰ Ϯ͘ϴϭϮ ĂŵĐŽΖtͲϭΖ^ůŝĚŝŶŐ^ůĞĞǀĞ͕^ĞůĞĐƚEŝƉƉůĞ͕ůŽƐĞĚ ϭϬ ϯ͕ϲϰϵ ϯ͕ϲϰϵ ϯ ĂŬĞƌΖ&,>ΖZĞƚƌŝĞǀĂďůĞWĂĐŬĞƌ͕ϱϬŬη^ŚĞĂƌZĞůĞĂƐĞ ϭϭ ϯ͕ϲϲϭ ϯ͕ϲϲϭ Ϯ͘ϴϲϳ ĂŵĐŽDD''ĂƐ>ŝĨƚDĂŶĚƌĞů͕ϯ͘ϱΗǆϭ͘ϱΗ͕ϭ͘ϱΗsǁͬZ<>ĂƚĐŚ͕KƉĞŶϱͬϭϳͬϵϳ ϭϮ ϯ͕ϳϬϲ ϯ͕ϳϬϲ ϰ͘ϳϳ ůĂƐƚ :ŽŝŶƚƐ͕ϯ͘ϱΗEͲϴϬdŵŝǆĞĚǁͬƚďŐ;ϰϴϬĨƚ͘Ϳ ϭϯ ϰ͕ϭϴϲ ϰ͕ϭϴϲ Ϯ͘ϴϭϮ ĂŵĐŽΖtͲϭΖ^ůŝĚŝŶŐ^ůĞĞǀĞ͕ůŽƐĞĚϭϬͬϵϯ ϭϰ ϰ͕ϮϮϱ ϰ͕ϮϮϱ Ϯ͘ϳϱ ĂŵĐŽΖΖEŝƉƉůĞǁͬEŽͲŐŽ ϭϱ ϰ͕Ϯϵϰ ϰ͕Ϯϵϰ ϯ ĂŬĞƌϱͲϮϮ>ŽĐĂƚŽƌ^ĞĂůƐƐĞŵďůǇ ϭϲ ϰ͕Ϯϵϰ ϰ͕Ϯϵϰ ϰ ĂŬĞƌ'ƌĂǀĞůͲWĂĐŬWĂĐŬĞƌ͕^Ͳϭ>ϭϬͲϰϬ ϭϳ ϰ͕ϯϬϯ ϰ͕ϯϬϯ ϰ͘Ϯϱ 'ƌĂǀĞůWĂĐŬ^ůŝĚŝŶŐ ^ůĞĞǀĞ ϭϴ ϰ͕ϯϮϲ ϰ͕ϯϮϲ ϯ yK͕ϱΗϴƌĚŽǆǆϯ͘ϱΗϭϬƌĚƉŝŶ ϭϵ ϰ͕ϯϮϳ ϰ͕ϯϮϳ Ϯ͘ϵϵ EͲϴϬWŝƉĞϵ͘ϮηϭϬƌĚ͕ǁͬĐĞŶƚƌĂůŝǌĞƌƐсKϱ͘ϴϳϱ͟ ϮϬ ϰ͕ϰϭϳ ϰ͕ϰϭϳ Ϯ͘ϵϵ ĂŬĞƌ^ůŝŵWĂŬ^ĐƌĞĞŶ͕ϯ͘ϱΗǆ͘ϬϭϮ'ĂƵŐĞ͕ϭϬƌĚ;ϴϮϱĨƚ͘Ϳ Ϯϭ ϱ͕ϮϰϮ ϱ͕ϮϰϮ ϯ ĂŬĞƌϱͲϮϮ^ŶĂƉ>ĂƚĐŚƐƐĞŵďůǇ ϮϮ ϱ͕Ϯϰϯ ϱ͕Ϯϰϯ ϰ ĂŬĞƌ'ƌĂǀĞůͲWĂĐŬWĂĐŬĞƌ͕^Ͳϭ>ϭϬͲϰϬ WůƵŐƐͬKƚŚĞƌ /͘ ĞƉƚŚD;Ĩƚ͘Ϳ / ĞƐĐƌŝƉƚŝŽŶ Wϭ ϱ͕ϮϲϬ Ͳ 'ĂƐůŝĨƚŝƌĐ͘sĂůǀĞ;ϱͬϮͬϭϵϵϳͿ ϱ͕ϮϮϴ;dDͿ &ŝůůůĞĂŶKƵƚ;ϭϭͬϮϭͬϮϭͿ WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ ŵƚ ^W& WŚĂƐĞ ĂƚĞ^ƚĂƚƵƐ t^K ϯ͕ϬϮϲΖ ϯ͕ϬϮϴΖ ϯ͕ϬϮϲΖ Ϯ͕ϬϮϴΖ ϮΖ ϱ Ϭ ϯͬϭϲͬϭϵϲϯ ZĞƐƋǌ ϯ͕ϬϵϬΖ ϯ͕ϮϰϴΖ ϯ͕ϬϵϬΖ ϯ͕ϮϰϴΖ ϲϬΖΎ ϭϮ ϯϬ ϴͬϴͬϭϵϵϯ WĞƌĨdW ϯ͕ϯϯϮΖ ϯ͕ϰϯϰΖ ϯ͕ϯϯϮΖ ϯ͕ϰϯϰΖ ϱϰΖΎ ϭϮ ϯϬ ϴͬϴͬϭϵϵϯ WĞƌĨdW ϯ͕ϰϱϲΖ ϯ͕ϲϬϮΖ ϯ͕ϰϱϲΖ ϯ͕ϲϬϮΖ ϵϭΖΎ ϭϮ ϯϬ ϴͬϴͬϭϵϵϯ WĞƌĨdW t^K ϯ͕ϲϭϮΖ ϯ͕ϲϭϰΖ ϯ͕ϲϭϮΖ ϯ͕ϲϭϰΖ ϮΖ ϰ ϯϬ ϳͬϯϬͬϭϵϵϯ ^Ƌǌ ϯ͕ϳϭϳΖ ϯ͕ϳϲϬΖ ϯ͕ϳϭϳΖ ϯ͕ϳϲϬΖ ϮϯΖΎ ϭϮ ϯϬ ϴͬϴͬϭϵϵϯ WĞƌĨdW ϯ͕ϴϴϵΖ ϯ͕ϴϵϰΖ ϯ͕ϴϴϵΖ ϯ͕ϴϵϰΖ ϱΖ ϭϮ ϯϬ ϴͬϴͬϭϵϵϯ WĞƌĨdW ϰ͕ϭϬϱΖ ϰ͕ϭϳϱΖ ϰ͕ϭϬϱΖ ϰ͕ϭϳϱΖ ϭϴΖΎ ϭϮ ϯϬ ϴͬϴͬϭϵϵϯ WĞƌĨdW & ϰ͕ϰϰϮΖ ϰ͕ϱϭϴΖ ϰ͕ϰϰϮΖ ϰ͕ϱϭϴΖ ϮϭΖΎ ϭϲͬϱ ϯϬ ϴͬϯͬϭϵϵϯ ZĞƉƌĨdW Θ 'ƌǀůWĐŬ & ϰ͕ϲϮϰΖ ϰ͕ϳϰϯΖ ϰ͕ϲϮϰΖ ϰ͕ϳϰϯΖ ϮϬΖΎ ϭϮͬϭϲ ϯϬ ϴͬϯͬϭϵϵϯ ^dηϯͲt^K͗ KƉĞŶ ' ϰ͕ϴϮϴΖ ϰ͕ϵϭϳΖ ϰ͕ϴϮϴΖ ϰ͕ϵϭϳΖ ϭϴ͛Ύ ϭϮͬϭϲ ϯϬ ϴͬϯͬϭϵϵϯ WĞƌĨdWΘ'ƌǀů WĂĐŬ , ϱ͕ϮϭϭΖ ϱ͕ϮϮϱΖ ϱ͕ϮϭϭΖ ϱ͕ϮϮϱΖ ϭϮ͛Ύ ϭϲͬϱ ϯϬ ϴͬϯͬϭϵϵϯ WĞƌĨͬZĞƉĞƌĨ dWΘ'ƌǀůWĂĐŬ ΎWĂƌƚŝĂůůǇWĞƌĨŽƌĂƚĞĚ/ŶƚĞƌǀĂů )LOODW ¶ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚǇ͗:>>ϬϰͬϬϲͬϮϮ WZKWK^ ĞůƵŐĂZŝǀĞƌhŶŝƚ tĞůů͗ZhϮϯϯͲϮϳ >ĂƐƚŽŵƉůĞƚĞĚ͗ϴͬϭϭͬϭϵϵϯ Wd͗ϭϲϯͲϬϬϮ W/͗ϱϬͲϮϴϯͲϭϬϬϮϲͲϬϬ ϯϲ͟ ϭϬͲϯͬϰ͟ ϳ͟ Z<ƚŽD^>сϭϬϰ͛Z<ƚŽ'>сϭϱ͛ dсϱ͕ϲϴϬ͛dsсϱ͕ϲϴϬ͛ Wdсϱ͕ϲϮϬ͛dsсϱ͕ϲϮϬ͛ DĂǆŶŐůĞсϭĚĞŐΛϴϬϬ͛ dƵďŝŶŐDŝŶ /сϮ͘ϳϱ͟ dKΛϮ͕ϵϲϬ͟ϰ ϱ ϲ ϳ ϴ ϵ ϭϬ ϭϭ ϭϮ ϭϯ ϭϰ ϭϱͬϭϲ ϭϳ ϭϴ ϭϵ ϮϬͬϮϭ Wϭ ^ƚĞƌůŝŶŐ^ĂŶĚƐ & & & ' , ϭϲ͟ Ϯ ϯ ϭ dĂŐŐĞĚ ϱ͕ϮϮϴ͛dD ϭϭͬϮϭͬϮϭ >ϱʹ >' ^/E'd/> ^ŝǌĞ dǇƉĞ td 'ƌĂĚĞ ŽŶŶ / ƚŵ ϯϲΖΖ ŽŶĚƵĐƚŽƌ tĞůĚ ϮϴΖΖ ϮϵΖ ϭϲΖΖ ^ƵƌĨĂĐĞ ϳϱη :Ͳϱϱ ϴƌĚ ϭϱ͘ϭϮϰΖΖ ϯϬϯΖ ϭϬͲϯͬϰΗ /ŶƚĞƌŵĞĚŝĂƚĞ ϱϭη WͲϭϭϬ ϴƌĚ ϵ͘ϴϱΖΖ Ϯ͕ϰϬϬΖ ϳΖΖ WƌŽĚƵĐƚŝŽŶĂƐŝŶŐ Ϯϲη WͲϭϭϬ ϴƌĚ ϲ͘ϮϳϲΖΖ Ϯ͕ϮϲϱΖ ϳΖΖ WƌŽĚƵĐƚŝŽŶĂƐŝŶŐ Ϯϲη EͲϴϬ Ƶƚƚ ϲ͘ϮϳϲΖΖ ϱ͕ϮϮϱΖ ϳΖΖ WƌŽĚƵĐƚŝŽŶĂƐŝŶŐ Ϯϲη WͲϭϭϬ Ƶƚƚ ϲ͘ϮϳϲΖΖ ϱ͕ϯϬϱΖ dh/E'd/>^ ϯ͘ϱΗ WƌŽĚƵĐƚŝŽŶ^ƚƌŝŶŐ ϵ͘Ϯη EͲϴϬ dͲŵŽĚ^ƉĞĐŝĂů Ϯ͘ϵϵϮΖΖ ϱ͕ϮϰϲΖ :t>Zzd/> >ŽŶŐ^ƚƌŝŶŐ /͘ĞƉƚŚ D ĞƉƚŚ ds/;ŝŶ͘Ϳ ĞƐĐƌŝƉƚŝŽŶ ϭ ϭϱ ϭϱ ϯ͘ϱ ĂŵĞƌŽŶdƵďŝŶŐ,ĂŶŐĞƌ Ϯ Ϯ͕ϴϵϵ Ϯ͕ϴϵϵ Ϯ͘ϴϭϮ ĂŵĐŽΖtͲϭΖ^ĞůĞĐƚŶŝƉƉůĞ ϯ Ϯ͕ϵϰϬ Ϯ͕ϵϰϬ Ϯ͘ϴϲϳ ĂŵĐŽDD''ĂƐ>ŝĨƚDĂŶĚƌĞů͕ϯ͘ϱΗǆϭ͘ϱΗ͕ϭ͘ϱΗsǁͬZ<>ĂƚĐŚ͕ůŽƐĞĚϴͬϭϭͬϵϯ ϰ Ϯ͕ϵϴϵ Ϯ͕ϵϴϵ ϯ ĂŬĞƌΖ&,>ΖZĞƚƌŝĞǀĂďůĞWĂĐŬĞƌ͕ϱϬŬη^ŚĞĂƌZĞůĞĂƐĞ ϱ ϯ͕Ϭϲϳ ϯ͕Ϭϲϳ ϯ ĂŬĞƌΖ&,>ΖZĞƚƌŝĞǀĂďůĞWĂĐŬĞƌ͕ϱϬŬη^ŚĞĂƌZĞůĞĂƐĞ 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WĞƌĨdW ϯϯϯϮΖ ϯ͕ϰϯϰΖ ϯϯϯϮΖ ϯ͕ϰϯϰΖ ϱϰΖΎ ϭϮ ϯϬ ϴͬϴͬϭϵϵϯ WĞƌĨdW ϯϰϱϲΖ ϯ͕ϲϬϮΖ ϯϰϱϲΖ ϯ͕ϲϬϮΖ ϵϭΖΎ ϭϮ ϯϬ ϴͬϴͬϭϵϵϯ WĞƌĨdW t^K ϯϲϭϮΖ ϯ͕ϲϭϰΖ ϯϲϭϮΖ ϯ͕ϲϭϰΖ ϮΖ ϰ ϯϬ ϳͬϯϬͬϭϵϵϯ ^Ƌǌ ϯϳϭϳΖ ϯ͕ϳϲϬΖ ϯϳϭϳΖ ϯ͕ϳϲϬΖ ϮϯΖΎ ϭϮ ϯϬ ϴͬϴͬϭϵϵϯ WĞƌĨdW ϯϴϴϵΖ ϯ͕ϴϵϰΖ ϯϴϴϵΖ ϯ͕ϴϵϰΖ ϱΖ ϭϮ ϯϬ ϴͬϴͬϭϵϵϯ WĞƌĨdW ϰϭϬϱΖ ϰ͕ϭϳϱΖ ϰϭϬϱΖ ϰ͕ϭϳϱΖ ϭϴΖΎ ϭϮ ϯϬ ϴͬϴͬϭϵϵϯ WĞƌĨdW & ϰϰϰϮΖ ϰ͕ϱϭϴΖ ϰϰϰϮΖ ϰ͕ϱϭϴΖ ϮϭΖΎ ϭϲͬϱ ϯϬ ϴͬϯͬϭϵϵϯ ZĞƉƌĨdWΘ 'ƌǀůWĐŬ & ϰϲϮϰΖ ϰ͕ϳϰϯΖ ϰϲϮϰΖ ϰ͕ϳϰϯΖ ϮϬΖΎ ϭϮͬϭϲ ϯϬ ϴͬϯͬϭϵϵϯ ^dηϯͲt^K͗ KƉĞŶ ' ϰϴϮϴΖ ϰ͕ϵϭϳΖ ϰϴϮϴΖ ϰ͕ϵϭϳΖ ϭϴ͛Ύ ϭϮͬϭϲ ϯϬ ϴͬϯͬϭϵϵϯ WĞƌĨdWΘ'ƌǀů WĂĐŬ , ϱϮϭϭΖ ϱ͕ϮϮϱΖ ϱϮϭϭΖ ϱ͕ϮϮϱΖ ϭϮ͛Ύ ϭϲͬϱ ϯϬ ϴͬϯͬϭϵϵϯ WĞƌĨͬZĞƉĞƌĨ dWΘ'ƌǀůWĂĐŬ ΎWĂƌƚŝĂůůǇWĞƌĨŽƌĂƚĞĚ/ŶƚĞƌǀĂů ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ dh ϭϭͬϭϵͬϮϭ ϭϭͬϮϭͬϮϭ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ ZhϮϯϯͲϮϳ ϱϬͲϮϴϯͲϭϬϬϮϲͲϬϬͲϬϬ ϭϲϯͲϬϬϮ ϭϭͬϮϭͬϮϭͲ^ƵŶĚĂǇ ŽŶĚƵĐƚ:^ĂŶĚĂƉƉƌŽǀĞWdt͘^ƚĂƌƚĂŶĚtĂƌŵƵƉĞƋƵŝƉŵĞŶƚ͘,ĂƵůƉƌŽĚƵĐĞĚǁĂƚĞƌĂŶĚĨŝůůƐƵƉƉůǇƚĂŶŬ͘ KĨĨůŽĂĚƚŽƚĞŽĨDĞK,ŝŶƚŽƉƵŵƉƚĂŶŬƐ͘hŶĂďůĞƚŽŐĞƚŵĂŶůŝĨƚǁŽƌŬŝŶŐ͘dƌŽƵďůĞƐŚŽŽƚĂŶĚĚĞƚĞƌŵŝŶĞƐƚĂƌƚĞƌŚĂƐĨĂŝůĞĚ͘ hŶĂďůĞƚŽŐĞƚĂŶŽƚŚĞƌƐƚĂƌƚĞƌ͘'ƌŽƵŶĚƚŚĂǁƵŶŝƚŶŽƚĐŝƌĐƵůĂƚŝŶŐŐůǇĐŽů͘>ŽǁĨůƵŝĚůĞǀĞůĂůĂƌŵĂŶĚǁŝůůŶŽƚƌĞƐĞƚ͘,ĂǀĞŚĞĂƚĞƌ ƐŶŽƌŬĞůŝŶƐƚĂůůĞĚŝŶƚŽŐƌŽƵŶĚƚŚĂǁĐŽǀĞƌŝŶŐ͘'ĞƚƐĞŶƐŽƌƚŽƌĞƐĞƚ͘ƉƉĞĂƌƐƚƵďĞƐŝŶƚĂŶŬŚĂǀĞĂŚŽůĞ͕ƐŚƵƚĚŽǁŶŐƌŽƵŶĚƚŚĂǁ ƵŶŝƚ͘dĂŬĞŚŽƐĞƐĨƌŽŵŐƌŽƵŶĚƚŚĂǁƵŶŝƚĂŶĚŝŶƐĞƌƚŝŶƚŽƚĂŶŬĂŶĚďĞŐŝŶĐŝƌĐƵůĂƚŝŶŐĂŐĂŝŶ͘EhƌŝƐĞƌĂŶĚKWƐŽŶƚŽƉŽĨƐǁĂď ĨůĂŶŐĞ͘WĂƌĂĐŚƵƚĞĐŽŝůƌĞĞůǁŝƚŚŚĞĂƚǁŚŝůĞƚƌŽƵďůĞƐŚŽŽƚŝŶŐĞƋƵŝƉŵĞŶƚ͘ >ŽĐĂƚĞďĂƚƚĞƌǇŽƉĞƌĂƚĞĚŵĂŶůŝĨƚĨƌŽŵϯŵŝůĞĐƌĞĞŬƐĞƌǀŝĐĞƐĂŶĚŵŽďŝůŝǌĞƚŽůŽĐĂƚŝŽŶ͘hŶĂďůĞƚŽŐĞƚŵĂŶůŝĨƚƚŽŽƉĞƌĂƚĞ͕ ďĂƚƚĞƌǇƵŶĂďůĞƚŽŚŽůĚĂĐŚĂƌŐĞ͘ĞͲŵŽďŵĂŶůŝĨƚĨƌŽŵůŽĐĂƚŝŽŶĂŶĚϯŵŝůĞƚŽƐĞƌǀŝĐĞĂŶĚƚƌŽƵďůĞƐŚŽŽƚĂƚŶŝŐŚƚďĂĐŬŝŶƐŚŽƉ͘ ^&E ^>ŽŝůĂŶĚƌƵǌŽďƚĂŝŶĐŽŶĚƵĐƚ:^ĂŶĚŽďƚĂŝŶWdt͘^ƚĂƌƚĂŶĚǁĂƌŵƵƉĞƋƵŝƉŵĞŶƚ͘DhϮ͘ϭϬΗd͕ϭ͘ϳϱΗĚƵĂůĐŚĞĐŬƐ͕ϭ͘ϳϱΗ ƐƚŝŶŐĞƌ͕ϭ͘ϳϱΗƐƚŝŶŐĞƌ͕ϭ͘ϳϱΗĚŽǁŶũĞƚŶŽǌǌůĞ͘^ƚĂďŽŶƚŽKWƐǁŝƚŚůƵďƌŝĐĂƚŽƌ͘dƌŽƵďůĞƐŚŽŽƚĂŶĚĨŝǆƐƚĂƌƚĞƌŽŶ^>EϮƉƵŵƉ͘ ^>ƉƵŵƉƚƌƵĐŬŚĂƐĨƌŽǌĞŶďƵƚƚĞƌĨůǇǀĂůǀĞ͕ͲƉƵŵƉĂŶĚŝĐĞŝŶƚƌŝƉůĞǆƉƵŵƉ͘tƌĂƉŝŶƉĂƌĂĐŚƵƚĞĂŶĚŚĞĂƚĞƌ͘WdŽƵƚƚŽĐŚŽŬĞ ƚŽϮϱϬƉƐŝůŽǁͬϮϵϬϬƉƐŝŚŝŐŚ͘ĞƌŽĐŽƵŶƚĞƌƐĂŶĚŽƉĞŶǁĞůůĂŶĚZ/,͘ 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ďůŝŶĚͬƐŚĞĂƌƌĂŵǁŚŝůĞƉƌĞƐƐƵƌŝŶŐƵƉ͘^ĞŶĚŽǀĞƌKͲƌŝŶŐƐĨŽƌďŽŶŶĞƚƐĞĂůƐĨƌŽŵ<ĞŶĂŝĂŶĚƌĞƉůĂĐĞ͘KͲƌŝŶŐƐƌĞƉůĂĐĞĚĂŶĚďĞŐŝŶ KWƚĞƐƚĂŐĂŝŶ͘dĞƐƚKWƚŽϮϱϬƉƐŝůŽǁͬϰϬϬϬƉƐŝŚŝŐŚ͘tƌĂƉĐŽŝůƌĞĞůĂŶĚƉƵŵƉǁŝƚŚƉĂƌĂĐŚƵƚĞĂŶĚůĞĂǀĞŚĞĂƚĞƌƚƌƵŶŬ ĨŽƌƚŚĞŶŝŐŚƚ͘^ƉŽƚůŝŐŚƚƉůĂŶƚ͘^&E͘ ϭϭͬϮϬͬϮϭͲ^ĂƚƵƌĚĂǇ dĞƐƚKWƚŽϮϱϬƉƐŝůŽǁͬϰϬϬϬƉƐŝŚŝŐŚ͘t 1 Guhl, Meredith D (CED) From:McLellan, Bryan J (CED) Sent:Tuesday, October 5, 2021 4:28 PM To:Jacob Flora Cc:Donna Ambruz; Trudi Hallett; Benjamin Siks; Roby, David S (CED); Boyer, David L (CED); Regg, James B (CED) Subject:RE: BRU 233-27 AOGCC 10-403 320-400 PTD163-002 Approved 10-06-20 Jake, The validity of Sundry 320‐400 is extended for 6 months beyond the original 10/6/21 expiration date. New expiration date is 4/6/22. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Friday, October 1, 2021 12:16 PM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com>; Trudi Hallett <thallett@hilcorp.com>; Benjamin Siks <bsiks@hilcorp.com> Subject: BRU 233‐27 AOGCC 10‐403 320‐400 PTD163‐002 Approved 10‐06‐20 Hi Bryan, This fill cleanout sundry was approved 10/6/2020 and is coming up on it’s expiration date. The well is still offline with no changes to status and we have been waiting for the right opportunity to add it to the coil schedule. I see opportunity to fit it in while we are over there supporting the new wells this winter. We would like to request a 6 month extension on the attached Sundry. Please let me know if you need more supporting information. Thanks, Jake Jake Flora | Kenai Ops Engineer | Hilcorp Alaska | 720‐988‐5375 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 2 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. 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 w N2 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? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 5,680'N/A Casing Collapse Structural Conductor Surface 1,020psi Intermediate 3,670psi Production 5,410psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 3 - Bkr FHL Ret. Pkrs, MD=4294,5243 TVD=4294,5243 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 Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Ted Kramer Operations Manager Contact Email: Contact Phone: 777-8420 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng tkramer@hilcorp.com 5,680'5,492'5,492'2,800 psi N/A Perforation Depth TVD (ft):Tubing Size: COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA029657 163-002 50-283-10026-00-00 Beluga River Unit (BRU) 233-27 Beluga River Field / Undefined Gas Pool Length Size State Wide Pool Rules Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 9.2# / N-80 TVD Burst 5,245' 7,240psi MD 8,060psi 2,630psi 29' 303' 2400' 29' 303' 5,305'7" 36" 16" 14 10.75"2385' 288' 5,305' Perforation Depth MD (ft): 2400' See Attached Schematic 5288' MD=2989,3067,3649 TVD=2989,3067, 3649 Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: October 11, 2020 3-1/2" 2- BKR SC 1L GP Packers, No SSSV m n P 66 t Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:24 am, Sep 28, 2020 320-400 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.09.25 15:51:50 -08'00' Taylor Wellman 10-404 DLB 09/28/2020 DSR-9/28/2020 camera/patch X 2,800 psi CTU X *4000 psi BOPE test (CTU) gls 10/5/20 CO w N2CTC Comm 10/6/2020 dts 10/06/2020 JLC 10/6/2020 RBDMS HEW 11/2/2020 Well Prognosis Well: BRU 233-27 Date: 9/25/2020 Well Name: BRU 233-27 API Number: 50-283-10026-00 Current Status: SI Gas Producer Leg: N/A Estimated Start Date: 10/11/20 Rig: CTU Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 163-002 First Call Engineer: Ted Kramer (907) 777-8420 (O) (987) 867-0665 (M) Second Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (M) AFE Number: Current Surface Pressure: ~ 55 psi Maximum Expected BHP: ~ 1,803 psi @ 4,125’ TVD (Calc’d W/ .437 psi/ft gradient) Max. Predicted Surface Pressure: ~ 2,800 psi (While Pumping Nitrogen) Brief Well Summary Originally drilled in early 1963 to define the field's west flank. BRU 233-27 was completed in the Beluga F, G and H with a single string and a heater string. A workover in 1993 added the Sterling and the Beluga D-E and gravel packed the original sands. BRU 233-27 is a single 3-1/2” production string to 5,246’ w/ gravel pack screen from 4327’ to 5246’. The well flowed intermittent for the first 20 years. After the recomplete, the well flowed 5-8 MMscfd. The well has declined to 1.5-2 MMscfd and most recently would not come back on after a shutdown in late November of 2018. The well was cleaned out with coil tubing in 2019 and restored to 1 MMscfd. The well produced with this rate until September 2020 when the well again died. Slickline was put on the well and tagged fill @ 2,855’. The purpose of this work is to clean out the solids with coil tubing, blow the well dry with nitrogen and then Run a camera to see if the well has screen damage. If it does, run a straddle patch over the damaged area. Return the well to the production system. Notes Regarding Wellbore Condition x Well is currently off line. x Fill was bailed with slickline F/ 2,855’ to 2,987’. (9/17/20) Coiled Tubing Procedure: 1. MIRU Coiled Tubing, PT BOPE to 4,000 psi Hi 250 Low. 2. SI well. 3. Route well production to open top diffuser 400 bbl tank. 4. RIH w/ 1.75” coil w/ jet nozzle BHA. a. Top of fill was recorded to be @ 2,855’. Engage fill and clean out to 5,230’ (below bottom perf) using nitrogen if necessary to lift. b. Blow well dry while holding back pressure to prevent more solids from entering well bore. 5. Leave 1,000 psi on well. RDMO CTU. E-line Procedure 6. MIRU E-line. Pressure test Lubricator to 250 psi low / 2,000 psi. high. 7. PU RIH With Camera looking for a hole in the screens that would allow sand entry. POOH. 8. If hole is found, PU RIH with Straddle Patch assembly and Isolate hole. POOH. 9. RDMO E-line. 10. Bleed off Nitrogen and place well back into the system. Review N2 SOP guidelines before starting work.(note PETROTech CT unit) The purpose of this work is to clean out the solids with coil tubing, blow the well dry with nitrogen and then Run a camera to see if the well has screen damage. If it does, run a straddle patch over the damaged area. f Return the well to the production system. Well Prognosis Well: BRU 233-27 Date: 9/25/2020 Attachments: 1. Current Schematic 2. Coil BOPE Schematic 3. Standard Well Procedure- Nitrogen _____________________________________________________________________________________ Created By: JJ 6/27/2016 SCHEMATIC Beluga River Unit Well: BRU 233-27 Last Completed: 8/11/1993 PTD: 163-002 API: 50-283-10026-00 36” 10-3/4” 7” RKB to MSL = 104’ RKB to GL = 15’ TD = 5,680’ TVD = 5,680’ PBTD = 5,620’ ED = 5,492’ ETVD = 5,492’ Max Angle = 1 deg @ 800’ Tubing Min ID = 2.75” TOC @2,960” 4 5 6 7 8 9 10 11 12 13 14 15/16 17 18 19 20/21 P1 Sterling Sands A A A B C C D D E E E F F F G H 16” 2 3 1 CASING DETAIL Size Type WT Grade Conn ID Btm 36'' Conductor Weld 28'' 29' 16'' Surface 75# J-55 8rd 15.124'' 303' 10-3/4" Intermediate 51# P-110 8rd 9.85'' 2,400' 7'' Production Casing 26# P-110 8rd 6.276'' 2,265' 7'' Production Casing 26# N-80 Butt 6.276'' 5,225' 7'' Production Casing 26# P-110 Butt 6.276'' 5,305' TUBING DETAILS 3.5" Production String 9.2# N-80 BTC-mod Special 2.992'' 5,246' JEWELRY DETAIL Long String ID. Depth MD (ft.) ID (in.) Description 1 15 3.5 Cameron Tubing Hanger 2 2,899 2.812 Camco 'W-1' Select nipple 3 2,940 2.867 Camco MMG Gas Lift Mandrel, 3.5"x1.5" , 1.5"DV w/RK Latch, Closed 8/11/93 4 2,989 3 Baker 'FHL' Retrievable Packer, 50k# Shear Release 5 3,067 3 Baker 'FHL' Retrievable Packer, 50k# Shear Release 6 3,078 2.867 Camco MMG Gas Lift Mandrel, 3.5"x1.5" , No Valve in Pocket, Open 1/25/98 7 3,092 2.992 Blast joints, 3.5" N-80 BTC (359 ft.) 8 3,451 2.992 Blast joints, 3.5" N-80 BTC-Mod (177 ft.) 9 3,634 2.812 Camco 'W-1' Sliding Sleeve, Select Nipple, Closed 10 3,649 3 Baker 'FHL' Retrievable Packer, 50k# Shear Release 11 3,661 2.867 Camco MMG Gas Lift Mandrel, 3.5"x1.5" , 1.5"DV w/RK Latch, Open 5/17/97 12 3,706 4.77 Blast Joints, 3.5" N-80 BTC mixed w/ tbg (480 ft.) 13 4,186 2.812 Camco 'W-1' Sliding Sleeve, Closed 10/93 14 4,225 2.75 Camco 'D' Nipple w/ No-go 15 4,294 3 Baker 5-22 Locator Seal Assembly 16 4,294 4 Baker Gravel-Pack Packer, SC-1L 10B-40 17 4303 4.25 Gravel Pack Sliding Sleeve 18 4326 3 XO, 5" 8rd Box x 3.5" 10rd pin 19 4327 2.99 N-80 Pipe 9.2# 10rd, w/ centralizers = OD 5.875” 20 4417 2.99 Baker SlimPak Screen, 3.5"x.012 Gauge, 10rd (825 ft.) 21 5242 3 Baker 5-22 Snap Latch Assembly 22 5243 4 Baker Gravel-Pack Packer, SC-1L 10B-40 Plugs/Other ID. Depth MD (ft.) ID Description P1 5,260 - Gas lift Circ. Valve (5/2/1997) PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Phase Date Status WSO 3026' 3,028' 3026' 2,028' 2' 5 0 3/16/1963 Resqz A 3090' 3,248' 3090' 3,248' 60'* 12 30 8/8/1993 Perf TCP B 3332' 3,434' 3332' 3,434' 54'* 12 30 8/8/1993 Perf TCP C 3456' 3,602' 3456' 3,602' 91'* 12 30 8/8/1993 Perf TCP WSO 3612' 3,614' 3612' 3,614' 2' 4 30 7/30/1993 Sqz D 3717' 3,760' 3717' 3,760' 23'* 12 30 8/8/1993 Perf TCP E 3889' 3,894' 3889' 3,894' 5' 12 30 8/8/1993 Perf TCP E 4105' 4,175' 4105' 4,175' 18'* 12 30 8/8/1993 Perf TCP F 4442' 4,518' 4442' 4,518' 21'* 16/5 30 8/3/1993 Reprf TCP & Grvl Pck F 4624' 4,743' 4624' 4,743' 20'* 12/16 30 8/3/1993 DST#3-WSO: Open G 4828' 4,917' 4828' 4,917' 18’* 12/16 30 8/3/1993 Perf TCP & Grvl Pack H 5211' 5,225' 5211' 5,225' 12’* 16/5 30 8/3/1993 Perf/Reperf TCP & Grvl Pack *Partially Perforated Interval Fill in tubing to 2900 ft. STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS J CENE JUL 16 9019 1. Operations Abandon Ll Plug Perforations LJ Fracture Stimulate LJ Pull Tubing Li Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: CTCO w N20 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development Q Exploratory ❑ Stratigraphic❑ Service ❑ 163-002 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-283-10026-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL029657 Beluga River Unit (BRU) 233-27 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Beluga River Field / Undefined Gas Pool 11. Present Well Condition Summary: Total Depth measured 5,680 feet Plugs measured N/A feet true vertical 5,680 feet Junk measured N/A feet 2989,3067,3649 Effective Depth measured 5,492 feel Packer measured 4294,5243 feet true vertical 5,492 feel true vertical 2989,3067, 3649 feet 4294,5243 Casing Length Size MD TVD Burst Collapse Structural Conductor 14' 36" 29' 29' Surface 288' 16" 303' 303' 2,630psi 1,020psi Intermediate 2,385' 10-3/4" 2,400' 2,400' 8,060psi 3,670psi Production 5,288' 7" 5,305' 5,305' 7,240psi 5,410psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2# / N-80 5,245'MD 5,2451TVD 2- BKR SC 1 L GP Pkrs MD=4294,5243 TVD=4294,5243 Packers and SSSV (type, measured and true vertical depth) 3 - Bkr FHL Ret. Pkrs, N/A MD=2989,3067,3649 TVD=2989,3067, 3649 N/A; N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 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 20 0 Subsequent to operation: 0 964 11 110 67 14. Attachments (required per 20 AAC 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations Q Exploratory[] Development 21 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-580 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer@hilcoro.com (—_ -7� f '^ 2�) 9 777-8420 Authorized Signature: Date: J Contact Phone: Form 10-404 Revsl ed 4/2017 / iml, ;li-e k• f 17 RBDMS UL 1 0 2019 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BRU 233-27 CTU 50-283-10026-00-00 1 163-002 1 6/11/19 1 6/21/19 Daily Operations: 06/11/2019-Tuesday Crews arrive at Hilcorp hanger. Travel to Beluga. Fire equipment. Mobilize coil equipment to BRU 233-27. 06/12/2019- Wednesday PJSM. Continue to rig up CTU. Crane op and vac truck on location. Fill supply tank with 300 bbls of produced water. Spot crane. Pull 1.5" reel and install 1.75" CT reel. Make up riser, x over to wellhead and BOPE stack. Stab 1.75" CT through injector head. Start BOPE test. 24 hr BOPE test witness notification sent 6/11/19 @ 2:53 PM. Witness waived by Jim Regg 6/11/19 @ 3:44 PM via email. Function test BOPE combi's dressed for 1.75" CT. Test all rams and valves 250/2,800 psi. Location secure. SDFN. 06/13/2019 - Thursday PJSM. PTW. Fire equipment. Pick injector head. Make up BHA. 1.75" BHA Coil connector, DFCV, 42" stinger, 48" stinger, 7" Jet swirl nozzle. Stab on well. Chain down injector head. Pressure test stack 250/2,800 psi. Bleed down. Open master and swab 16.5 turns. Online down CT at 1 bbl/min trying to catch fluid level. 17 bbls pumped to catch fluid. Fluid level at 1,955'. RIH for try tag at 2,520' CTMD. Pick up and start circulating 1:1. Wash through sand bridges. Circulating pressure at 1.5 bbls/min 3,750 psi. Sand bridges at 2,520', 2,690', 2,850', 2,932', 2,939' and 3,110'. After washing through last known sand bridge at 3,110' Lost all returns. Circ pressure dropped from 3,750 psi to 1,786 psi. Well is on a vac. POOH to above first sand bridge. Park CT at 2,358'. Having issues getting deck engine on N2 pump fired up. Once fired up started cooling down. Shut down again for leak on triplex suction line. Total down time 2 hrs. Cooling down N2. Online N2 @ 800 scf/min. Returns to surface. N2 and fluid with sand. Increase N2 rate to 1000 scf/min and fluid rate to .5 bbls/min. Start washing and RIH. Cleanout sand from 2,350' to max depth tag of 5,268'. Continue cleanout working up and down through perfs until returns cleaned up. Shut down fluid pump and continue pumping N2 at 1,000 scf/min. Slowly working in the choke to 480-530 psi. All N2 at surface. Start POOH. Close in choke to build N2 pressure. N2 pressure broke over at 820 psi. Start injecting into formation. Shut down N2. At surface. Close in master and swab valve. Pop off injector head. and rack back. Start rigging down hard line. Location secure. SDFN. 189 bbls of fluid pumped. 2,330 gallons of N2 pumped. 216 bbls returned. gain of 27 bblsfor job. 06/21/2019 - Friday PTW and PJSM, Rig up on well. PT lub 2,000 PSI- GOOD. Rih w/ 1.75 DD Bailer to 5,240' kb, pooh, ooh 1/4 full mud/sand. Rih w/ 2.5 Blind box to 1,810' kb, tag fluid, pooh. Stand by for Swab tank. Rig up hard line to swab tank. Rih w/ 3-1/2" Swab Mandrel w/ 2 V-Cups. See Swab report. Well flows small amount of water and gas on own for 1 hr before dying off. Wells continues to flow gas at aprox 10 PSI during swabbing. Let Gas flow (still at aprox 10 PSI) to tank for half an hr. No Change. Rig down for the night. Location secure. TO 5,680' TVD=5,680' PBTD = 5,620' ED 5,492' END=5,492' Max Angle = 1 deg @ 800' SCHEMATIC DETAIL Beluga River Unit Well: BRU 233-27 Last Completed: 8/11/1993 PTD: 163-002 API: 50-283-10026-00 Size Type WT Grade Conn ID Btm 36" Conductor 2,899 2.812 Weld 28" 29' 16" Surface 75# J-55 8rd 15.124" 303' 10-3/4" Intermediate 51# P-110 god 9.85" 2,400' 7" Production Casing 26# P-110 8rd 6.276" 2,265' T' Production Casing 26# N-80 Butt 6.276" 5,225' 7" Production Casing 26# P-110 Butt 6.276" 5,305' TUBING DETAILS 3.5" 1 Production String 1 9.2# 1 N-80 I BTC -mod Special 2.992" 5,246' JEWELRY DETAIL Long String ID. Depth MD (ft.) ID (in.) Description 1 15 3.5 Cameron Tubing Hanger 2 2,899 2.812 1 Camco'W-1'Select nipple 32,940 3026' 2.867 Cameo MMG Gas Lift Mandrel, 3.5"x1.5" , 1.5"DV w/RK Latch, Closed 8/11/93 4 2,989 3 Baker'FHL' Retrievable Packer, 50k# Shear Release 5 3,067 3 Baker'FHL' Retrievable Packer, 50k# Shear Release 6 3,078 2.867 Cameo MMG Gas Lift Mandrel, 3.5"x1.5" , No Valve in Pocket, Open 1/25/98 7 3,092 2.992 Blast joints, 3.5" N-80 BTC (359 ft.) 8 3,451 2.992 Blastjoints, 3.5" N-80 BTC -Mod (177 ft.) 9 3,634 2.812 Camco'W-1'Sliding Sleeve, Select Nipple, Closed 10 3,649 3 Baker'FHL' Retrievable Packer, 50k# Shear Release 31 3,661 2.867 Cameo MMG Gas Lift Mandrel, 3.5"x1.5", 1.5"DV w/RK Latch, Open 5/17/97 12 3,706 4.77 1 Blast Joints, 3.5" N-80 BTC mixed w/ tbg (480 ft.) 13 4,186 2.812 1 CamooWl'Slicing Sleeve, Closed 10/93 14 4,225 2.75 Cameo'D' Nipple w/ No-go 15 4,294 3 Baker S-22 Locator Seal Assembly 16 4,294 4 1 Baker Gravel -Pack Packer, SC -11. 108-40 17 4303 4.25 Gravel Pack Sliding Sleeve 18 4326 3 XO, 5" 8rd Box x 3.5" 10rd pin 19 4327 2.99 N-80 Pipe 9.2# lord, w/ centralizers = OD 5.875" 20 4417 2.99 Baker SlimPak Screen, 3.5"x.012 Gauge, lord (825 ft.) 21 5242 3 Baker 5-22 Snap Latch Assembly 22 5243 4 Baker Gravel -Pack Packer, SC -IL 108-40 Plugs/Other ID. Depth MD(ft.) ID 1 Description P3 5,260 1—U. Circ. Valve (5/2/1997) PERFORATION DETAIL Sands To (MD) Btm (MD) To (TVD) Btm (TVD) Amt SPF Phase Date Status WSO 3026' 3,028' 3026' 2,028' 2' 1 5 0 3/16/1963 Resgz A 3090' 3,248' 3090' 3,248' 60'* 12 30 8/8/1993 Perf TCP B 3332' 3,434' 3332' 3,434' 54" 12 30 8/8/1993 Perf TCP C 3456' 3,602' 3456' 3,602' 911* 12 30 8/8/1993 Perf TCP W50 3612' 3,614' 3612' 3,614' 2' 4 30 7/30/1993 Sqz D 3717' 3,760' 3717' 3,760' 23'* 12 30 8/8/1993 Perf TCP 3889' , , S'E 12 30 8/8/1993 Perf TCP E 4105' 4,175' 4105' 4,175' 187* 12 30 8/8/1993 Perf TCP F 4442' 4,518' 4442' 4,518' 211* 16/5 30 8/3/1993 Reprf TCP& Grvl Pck F 4624' 4,743' 4624' 4,743' 20'* 12/16 30 8/3/1993 DST#3-W50: Open G 4828' 4,917' 4828' 4,917' 18'* 12/16 308/3/1993 Perf TCP & GNIPack H 5211' 5,225' 5211' 5,225' 12'" 16/5 30 8/3/1993 Pert/Reperf TCP & Grvl Pack *Partially Perforated Interval Created By: A 6/27/2016 n� n\is • Al k O'1 d G THE STA "'ALASKA--- GOVERNOR MIKE DUNLEAVY as a 1 an as Conservation Commission Chad Helgeson Operations Manager Hilcorp Alaska, LLC UEC 2 6 4 u i r, 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beluga River Field, Undefined Gas Pool, BRU 233-27 Permit to Drill Number: 163-002 Sundry Number: 318-580 Dear Mr. Helgeson: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair k� DATED this day of December, 2018. RBDMS t DEC 2 8 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ;.t 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 w N2 ❑Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development ❑✓ ' Stratigraphic ❑ Service ❑ 163-002 - 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-283-10026-00—�c� 7. If perforating: 8. Well Name and Number: 71 F /--.2 -- What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No ❑Q BRU 233-27 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL029657 ' I Beluga River Field / Undefined Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 5,680' 5,680' 5,492' 5,492'-2,800psi none none Casing Length Size MD TVD Burst Collapse Structural Conductor 14 30" 29' 29' Surface 288' 16" 303' 303' Intermediate 2385' 10.75" 2400' 2400' Production 5288' 7" 5,305' 5,305' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): From 3,026-4,835' 3026-4835 3-1/2" N-80 5,245' Packers and SSSV Type: 2- BKR SC 1 L GP Packers, No SSSV Packers and SSSV MD (ft) and TVD (ft): MD=2989,3067,3649 TVD=2989,3067, 3649 3 - Bkr FHL Ret. Pkrs, MD=4294,5243 TVD=4294,5243 12. Attachments: Proposal Summary Q Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch Exploratory ❑ Stratigraphic ❑ Development ❑Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: CommencingOperations: January 3, 2019 P OIL WINJ WDSPL ❑ ❑ ❑ Suspended ❑ GAS ❑✓ WAG ElGSTOR [ISPLUG ElCommission 16. Verbal Approval: Date: Representative: GINJ ElOp Shutdown ❑ Abandoned El 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerCcDhilcorp.com / Contact Phone: 777-8420 Authorized Signature:/ r — Date: U is e r COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: —V W U V Plug Integrity ❑ BOP Test [( Mechanical Integrity Test ❑ Location Clearance ❑ Other: 5 0 ' 11 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY t 1 I t e Date: 1 Approved by: COMMISSIONER THE COMMISSION L Form 10-403 Revised 4/2017 2---a2c(- I��S'' JBDN�S�a./o�C Approved applicatO-Rii'G tr-r 1-ArL the date o approve . 2. nit Form and Angh in Duplicate CIs Hilcurp Alaska, LLI Well Prognosis Well: BRU 233-27 Date: 12/20/2018 Well Name: BRU 233-27 API Number: 50-283-10026-00 Current Status: Gas Producer Leg: N/A Estimated Start Date: 01/03/2019 Rig: CTU Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 163-002 First Call Engineer: Ted Kramer (907) 777-8420 (0) (987) 867-0665 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Surface Pressure: — 165 psi Maximum Expected BHP: — 1,803 psi @ 4,125' TVD (Calc'd W/.437 psi/ft gradient) Max. Predicted Surface Pressure: — 2,800 psi (While Pumping Nitrogen) Brief Well Summary Originally drilled in early 1963 to define the field's west flank. BRU 233-27 was completed in the Beluga F, G and H with a single string and a heater string. A workover in 1993 added the Sterling and the Beluga D -E and gravel packed the original sands. BRU 233-27 is a single 3-1/2" production string to 5,246' w/ gravel pack screen from 4327' to 5246'. The well flowed intermittent for the first 20 years. After the recomplete, the well flowed 5-8 MMscfd. The well has declined to 1.5-2 MMscfd and most recently would not comeback on after a r shutdown in late November of 2018. The purpose of this work is to clean out the solids with coil tubing, blow the well dry with nitrogen and then return the well to the production system to see if it will flow. Notes Regarding Wellbore Condition • Well is currently off line. • Fill was bailed with slickline to 2,518'. i � ry il Coiled Tubing Procedure: 1. MIRU Coiled Tubing, PT BOPE to 4,000 psi Hi 250 Low. Vze- 2. SI well. 3. Route well production to open top diffuser 400 bbl tank. 4. RI w/ 1.75" coil w/ jet nozzle BHA. a. Top of fill was recorded to be @ 2,518'. Engage fill and clean out to 5,230' (below bottom perf) using nitrogen if necessary to lift. b. Blow well dry while holding back pressure to prevent more solids from entering well bore. 5. Leave 1,200 psi on well. RDMO CTU. 6. Return well to Production to Bleed off Nitrogen and place back into system. Hilcorp Alaska, LLI Attachments: 1. Current Schematic 2. Coil BOPE Schematic 3. Standard Well Procedure- Nitrogen 4. CT Flow Schematic (Forward) Well Prognosis Well: BRU 233-27 Date: 12/20/2018 . . � Beluga River Unit Well: BRU 233-27 SCHEMATIC Last 11 PTD: 163 Completed:ee8/11/1993 02 Hill corp Alaska, LLC API: 50-283-10026-00 CASING DETAIL RKB to MSL = 104' RKBtoGL=15' TD = 5,680' TVD = 5,680' PBTD = 5,620' ED = 5,492' END = 5,492' Max Angle = 1 deg @ 800' Size Type WT Grade Conn 15 3.5 36" Conductor 2,899 2.812 Weld 3 2,940 16" Surface 75# J-55 8rd 110-3/4" W218..29' 3,067 Intermediate 51# P-110 8rd 2.867 Camco MMG Gas Lift Mandrel, 3.5"x1.5", No Valve in Pocket, Open 1/25/98 7" Production Casing 26# P-110 8rd 67" 2.992 Blast joints, 3.5" N-80 BTC -Mod (177 ft.) Production Casing 26# N-80 Butt 6., 3,649 7" Production Casing 26# P-110 Butt 6.276" 5,305- I TUBING DETAILS 3.5" 1 Production String i 9.2# 1 N-80 I BTC -mod Special 1 2.992" 5,246' ds JEWELRY DETAIL Long String ID. Depth MD (ft.) ID (in.) Description 1 15 3.5 Cameron Tubing Hanger 2 2,899 2.812 Camco'W-1' Select nipple 3 2,940 2.867 Camco MMG Gas Lift Mandrel, 3.5"x1.5", 1.5"DV w/RK Latch, Closed 8/11/93 4 2,989 3 Baker'FHL' Retrievable Packer, 50k# Shear Release 5 3,067 3 Baker'FHL' Retrievable Packer, 50k# Shear Release 6 3,078 2.867 Camco MMG Gas Lift Mandrel, 3.5"x1.5", No Valve in Pocket, Open 1/25/98 7 3,092 2.992 Blast joints, 3.5" N-80 BTC (359 ft.) 8 3,451 2.992 Blast joints, 3.5" N-80 BTC -Mod (177 ft.) 9 3,634 2.812 Camco'W-1' Sliding Sleeve, Select Nipple, Closed 10 3,649 3 Baker'FHL' Retrievable Packer, 50k# Shear Release 11 3,661 2.867 Camco MMG Gas Lift Mandrel, 3.5"x1.5" , 1.5"DV w/RK Latch, Open 5/17/97 12 3,706 4.77 Blast Joints, 3.5" N-80 BTC mixed w/ tbg (480 ft.) 13 4,186 2.812 Camco'W-1' Sliding Sleeve, Closed 10/93 14 4,225 2.75 Camco 'D' Nipple w/ No-go 15 4,294 3 Baker 5-22 Locator Seal Assembly 16 4,294 4 Baker Gravel -Pack Packer, SC -11- 30B-40 17 4303 4.25 Gravel Pack Sliding Sleeve 18 4326 3 XO, 5" 8rd Box x 3.5" 10rd pin 19 4327 2.99 N-80 Pipe 9.2# lord, w/ centralizers = OD 5.875" 20 4417 2.99 Baker SlimPak Screen, 3.5"x.012 Gauge, 10rd (825 ft.) 21 5242 3 Baker 5-22 Snap Latch Assembly 22 5243 4 Baker Gravel -Pack Packer, SC -11- 10B-40 Plugs/Other ID. Depth MD (ft.) ID I Description P1 1 5,260 Gas lift Circ. Valve (5/2/1997) PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Phase Date Status WSO 3026' 3,028' 3026' 2,028' 2' 5 0 3/16/1963 Resqz A 3090' 3,248' 3090' 3,248' 60'* 12 30 8/8/1993 PerfTCP B 3332' 3,434' 3332' 3,434' 54'* 12 30 8/8/1993 PerfTCP C 3456' 3,602' 3456' 3,602' 911* 12 30 8/8/1993 PerfTCP WSO 3612' 3,614' 1 3612' 3,614' 2' 4 30 7/30/1993 Sqz D 3717' 3,760' 3717' 3,760' 23'* 12 30 8/8/1993 Perf TCP — E 3889' 3,894' 3889' 3,894' 5' 12 30 8/8/1993 Perf TCP E 4105' 4,175' 4105' 4,175' 18'* 12 30 8/8/1993 PerfTCP F 4442' 4,518' 4442' 4,518' 21'* 16/5 30 8/3/1993 ReprfTCP & Grvl Pck F 4624' 4,743' 4624' 4,743' 20'* 12/16 30 8/3/1993 DST#3-WSO: Open G 4828' 4,917' 4828' 4,917' 18'* 12/16 30 8/3/1993 PerfTCP & Grvl Pack H 5211' 5,225' 5211' 5,225' 12'* j 16/5 30 8/3/1993 Perf/Reperf TCP & GrvlPack *Partially Perforated Interval Created By:A 6/27/2016 Kill P, WH PSI II 2" 1502 x 2-1/16 1 OK Flanged Valve ll' (Manual) 2-1/16 1 OK x 2-1/16 10K Ranged Valve (Manual) Coil Tubing BOP Coiled Tubing HR580 Injector Head & Gooseneck Weight= 12,850 lbs 4-1/16" 10K Conventional Stripper 5K C062 Lubricator 5K C062 x 4-1/16" 1 OK Flange 4-1/16" 10K Combi BOP Top Set: Blind/Shear Secan d Set: Pipe/Slip 4-1/16" 10K Flow Cross Manual 2x2 Valve 1: 2" 1502 x 2-1/16" 10K Flange Manual 2x2 Valve 2: 2-1/16 10K x 2-1/16" 10K Flange Manual 2x2 Valve 3: 2-1/16" 10K x 2-1/16" 10K Flange Manual 2x2 Valve 4: 2" 1502 x 2-1/16" 10K Flange 4-1/16" 1 OK x Wellhead Adapter Flange Wellhead 14 STANDARD WELL PROCEDURE I I ih orp Alaska. LLC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINALv1 Page 1 of 1 rl 0 Open—Tap Tank w/ Diffuser up Annulus) COILED TUBING UNIT A�ma"is - N2 JETTING FLOW SCHEMATIC 10,000,000 1,000,000 HILCORP ALASKA LLC, BELUGA RIV UNIT 233-27 (163-002) BELUGA RIVER, UNDEFINED GAS Monthly Production Rates LL V O N 10,000 � O O a� C7 Li 0 1,000 U 3 U to 100 3 O s H 10 10,000,000 W 1,000,000 N O O 100,000 O 3 r+ S 10,000 O W 1,000 LA O C� G rr m 100 m I ig O 3 10 3- 1 � 1 Jan -1965 Jan -1970 Jan -1975 Jan -1980 Jan -1985 Jan -1990 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 Jan -2020 SP READSH EET_Prod-1 nject_Cu rves_WeII—V117_1630020_BRU_233-27_20181221.xlsx 12/21/2018 • ,r u rrOF 1// Tye s THE STATE Alaska Oil and Gas \\•s� -' f I A s J��l 1 Conservation Commission ► �� O 333 West Seventh Avenue '14111-7441\*�' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF Main 907.279 1433 ALAS 101 Fax 907.276 7542 scowE� \UN 5iy L www.aogcc alaska gov Mike Hazen Gly Staff Wells Engineer V 3,. ©a - ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Beluga River Field, Undefined Gas Pool, BRU 233-27 Sundry Number: 315-342 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, '7' r Danie . Seamount, Jr. ,J Commissioner DATED this / day of June, 2015 Encl. STATE OF ALASKA 1. ,KA OIL AND GAS CONSERVATION COM. 310N 4614 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well rRe-enter Susp Well r Other: Install velocity string Fi 2.Operator Name: 4.Current Well Class. 5 Permit to Drill Number: ConocoPhillips Alaska, Inc. _ Exploratory r Development p. - %LA3- 001-r 3.Address. Stratigraphic r Service r 6.API Number. P.0. Box 100360,Anchorage,Alaska 99510 50-283-10026-00 • 7.If perforating, 8 Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No p BRU 233-27 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 029657 ' Beluga River Field/Belage•6a -Pool 0„,(1,41."..41GAS pczi 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): 5680 • 5680 ' none none Casing Length Size MD TVD Burst Collapse Conductor 14' 30" 29' 29' Surface 288' 16" 303' 303' RECEIVED Intermediate 2385' 10.75" 2400' 2400' `w " D Production 5288' Ti 5305' 5305' JUN 1) 3 2015 AOGGC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): from 3026-4835'• 3026-4835' 3.5 N-80 5245 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) 3 BAKER FHL RETRIEVABLE PACKERS • MD=2989,3067,3649 TVD=2989,3067,3649 2 BAKER SC-IL GRAVEL PACK PACKERS MD=4294,5243 TVD=4294,5243 NO SSSV 12.Attachments: Description Surrrrrary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development F. Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/8/2015 OIL r VVINJ r WDSPL r Suspended E 16.Verbal Approval: Date: GAS r• WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact' Mike Hazen @ 265-1032 Email. hazenmc@conocophillips.com Printed Name Mike Haze Title: Staff Wells Engineer Signature J Phone:265-1032 Date 2 TVN IS Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ' S —3'4 2. Plug Integrity r BOP Test Mechanical Integrity Test r Location Clearance r Other , op t f51 / 3 50 0 / p 5 i l A/1 12 S P 15 /! °P55• i (, Spacing Exception Required? Yes ❑ No Z Subsequent Form Required' /o— 4 G 4- I APPROVED BY /'q/t/ � Approved by:< COMMISSIONER THE COMMISSION Date: APProv VI IZ months tro the date of approval. Submit Form and Form 10-403 Revised 5/2015 ?1i8 b lS _ s Attachments' Duplicate - ,,� W3 RBDM� JUN 10 2015 ConocoPhillips RECEIVED Alaska JUN 0 3 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC June 2, 2015 State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to install a coiled tubing (CT)velocity string Beluga River Unit Producer 233-27 (PTD#163-002). Beluga River Unit (BRU) 233-27 was originally drilled and completed in March 1963 as a producer in the Beluga F-, G-, and H-sands. The well was worked over in July 1993 when the Beluga A- through E-sands were added and the existing F- through H-sands gravel packed. The tubing was also swapped at that time from 2-3/8" 4.7# to 3-1/2" 9.2# N-80. The well is constructed with 7" 26# N80 and 29# P110 production casing to 5680'. The well is on line and currently producing approximately 3.9-MMSCFD, however is beginning to show signs of water loading. The well has potential to produce 4.5-MMSCFD. The objective of this non-rig workover is to utilize CT to hang off a velocity string on a packer from 3900' RKB to 5200' RKB to help initiate flow from the original gravel-packed perforations at 4442'-5225'. If you have any questions or require any further information, please contact me at 265-1032 or hazenmc@conocophillips.com or Jay Maguire at 263-4551 and Jav.C.Maguire@conocophillips.com. Sincerely, Michael C. Hazen Wells Engineer CPAI Drilling and Wells BRU 233-27 Coiled Tubing Velocity Deployment (PTD# 163-002) Current Status: The well is on line and currently produces approximately 3.8-MMSCFD.The well has potential of 4.4-MMSCFD. Scope of Work: The objective of this procedure is to utilize coiled tubing to hang off a velocity string on a packer from 3900' RKB to 5200' RKB.The well has shown signs of liquid loading throughout the gravel packed interval and the 2" coil velocity string will help the well unload these lower zones. General Well info: MASP: 110 psi (using 0.1 psi/ft gas gradient and Beluga F @ 5,240'MD) Max. Reservoir pressures/TVD: From 7/26/2014 SBHPS Sterling E/F @ 5,240'MD/5,240'TVD= 634 psi Max Inclination: 0.9° @ 740' KB. Min ID Within Set Depth: 2.75" D-Nipple @ 4,225' KB Wellhead type/rating: Shaffer Wellhead and WKM Tree/5,000 psig SLB BOP Configuration: Dual Stack: 1.) Blind-Shear/Blind-Shear/Pipe/Slip; and 2.) Blind-Shear/Slip- Pipe Well Type: Gas Producer Estimated Start Date: June 10, 2015 Wells Engineer: Jay Maguire (263-4551,Jay.C.MaguireWconocophillips.com) Wells Engineer Production Engineer: Tyler Hall (263-4012,Tyler.A.Hall@conocophillips.com) Cook Inlet Production Engineer Proposed Procedure: Slickline: 1. Conduct pre-job safety meeting(PJSM). 2. Drift well with 2.72" OD tool 5,200' RKB. 3. Set a two-way check in the tubing hanger to be used to pressure test tree connections/valves. 4. Pressure test tree valve and connections. 5. Pull two-way check. Coiled Tubing: 6. Conduct pre-job safety meeting (PJSM). 7. Rig up the CTU with Combi-BOP's with redundant rams (pipe/slips) on wellhead and 30ft of lubricator. C/ p 8. Mix and fill the pits with 500 bbl of 6% KCI water with 1%corrosion inhibitor. Rig up the pump to (y) the BOPE with 2" 1502 15M iron and rig the suction lines to the tanks,test system to 250-psi low, 4f 3500-psi high. Bleed pressure to zero when finished. Ensuring BOPE's are capped, line up pump v to the well at the flowcross/pump-in-sub. 9. Rig up surface lines to pump into BOPE or flow cross.Test the lines and connections. 10. Notify the AOGCC 48-hours in advance of testing BOPE. Rig up the BOPE to well head.Test and chart BOPE. 11. Pump a sufficient volume of fluid through the CT reel to sweep debris from the tubing. 12. Pump 5/8" drift ball through the CT once string is loaded with fluid. 13. Pick up lubricator and run coiled tubing out the end of the stack. 14. Prep the end of the coiled tubing with reamer and install coil connector. 15. MU pull-plate to connector and pull test to 10,000 lbs. 16. Pressure test CT to 500 psi for 5 minutes and 5000 psi for 10 minutes. 17. Break off the pull plate and make blow out plug w/seating nipple (See attached drawing). 18. Make up stack to well and PT lubricator to 1000-psi through flow cross. 19. Bleed down stack. 20. Pressure-test the pump out plug to 1000 psi by pumping down coil. (The pump out plug is set to release at 1800 psi.) 21. Zero depth counter. 22. RIH slowly until BHA passes thru wellhead. Continue run in hole at 50 ft/min and reduce the running speed to 10 ft/min passing through restrictions. 23. Perform weight check at 1000 ft and record weights. ,,�D 24. At 1300 ft, prepare to cut coil and rig up packer. .0• 23lde- SZc� 25. Close in BOP pipe rams and confirm the slip rams are holding the coil in place; perform pull test and flow test.Test both pipe rams from below against the swab valve. 26. Upon successful (negative) inflow test, bleed off riser pressure to 0 psi. 27. Open coiled tubing at the reel and inflow test the velocity string blow plug-this will ensure barriers from the well on the inside of the coiled tubing. Pressure-test the pump-out plug from above to 1,000 psi differential (down CT). Monitor for 30 minutes to see if any pressures change in the coil string. 28. Open the injector head skates 29. Break the riser and lift injector head-during this process, a coiled tubing operator will monitor the weight indicator to ensure free movement of the injector head over the stationary coiled tubing. Cut Coiled Tubing & Make-Up Packer Assembly 30. Hot tap the coil tubing to ensure there is no gas pressure at surface. 31. Close Injector Head Skates onto coiled tubing. 32. Cut coiled tubing 33. Once cut, pick coiled tubing up out of the way. MU the packer BHA consisting of 2.00" coiled tubing connector with 2-3/8" CS Pin, 3.063"Sealed tubing swivel,and 2.875" cross over 34. Dress coiled tubing in injector head and install coil connector; pull test to 20,000 lbs. 35. MU connector(upper string) to (lower string) and pull test to 10,000 lbs. 36. Pressure test the coil connector and packer connections to 1,000 psi by applying pressure through the pump through sub between the upper pipe rams and riser of the coil unit. 37. Open pipe and slip rams and RIH to set the packer at^'3900' RKB. 38. Check reel for valve alignment to drop setting ball. 39. PU coiled tubing as required to line up for inserting setting ball into coiled tubing and record all parameters such as WHP, CT hanging weight, run-in-hole weight and pick up. 40. Insert 5/8" setting ball into reel and pump 2 bbl. Shut down pumps. 41. Start pumping and pump ball over the gooseneck. 42. Stop pump and let ball fall to seat in packer setting tool (see attached). 43. Start pump at .5 bpm and monitor pressure. Stop pumps after coil tubing is full and pressured up to 1,000 psi. 44. Pressure up on CT to 2,000 PSI and stack 2,000 lbs weight down on packer. Continue to pressure up to 4,500 psi in 500 psi increments to set and release from packer. Note: 4,000 lbs. of downward force is required to properly set the packer. 45. Pressure up on annulus of CT to 500 psi to test packer sealing integrity. 46. Bleed pressure off CT annulus and pick up and POOH with setting tool assembly. 47. POOH Slick line: 48. Conduct pre-job safety meeting (PJSM). 49. RIH with cat standing valve and set in the top of the packer assembly. With the down hole pump, bull head produced water in the hole until it is full. Set the test tool inside the top of the lower packer assembly. Pressure test the production tubing to 1000 psi for 30 minutes,chart record test for future reference and place a copy in the well file. Pull the test tool and POOH. 50. With slickline OOH, pressure up on the well with nitrogen in order to open the pump-out plug at the end of the CT velocity string.The pump-out plug it set to release at 1800-psi 51. RDMO and put well back on production. Packer Setting Tools OD ID LENGTH A C.T. Connector w/11/4" CS Pin 2.060 1.250 1.00 B Dual Flapper Valve w/11/4" CS Box x Pin 2.130 1.050 1.00 C Sealed Tubing Swivel w/11/4" CS Box x Pin 2.130 1.100 1.00 D Hydraulic Disconnect w/11/4" CS Box x Pin 2.190 0.690 1.00 E Handling Pup w/11/4" CS Box x Pin 2.000 1.218 1.00 F 3-1/2" Hydraulic setting tool w/11/4" CS Box 2.650 0.560 4.00 BHA To Be Set in Hole G 3-1/2" 9.2# Paragon II Packer 2.70" O.D. x 1.625" I.D. 2.700 1.625 3.80 Seal Bore H Sealed Tubing Swivel 2-3/8" Reg 2.375 1.985 1.0 2" coil tubing connector with 2-3/8" CS Pin 2.375 1.985 1.0 J 2"Coil Tubing(SLB,See Above) 2.000 1.750 1300 K Special Blow out plug, Seating Nipple and CT 2.300 1.510 2.1 Connector(1,800 psi) w/ Pump out plug I Contingencies: .a. A pump system with 6% KCL KWF will be rigged up to pump down well and IA if necessary. I I Blind/Shear I Blind/Shear 4-1/16"BOP I I Slip I I Pipe I II II I I Blind/Shear 4-1/16"BOP PIpe/slip II II f i M.® _ Flow cross II I I F. 1 r f I ♦ LNV E I I LL KN CHOKE LINE/KILL ONE TO RETURN TANK ® 1 i ® .dehpted ©�►m --.--� �- ® KILL LINE(Secondary) 1 I o H l CCbg head KILL LINE I I Casingheatlapterad ) II /,vA\_ I 'IL -1111:1 • b. TIW valve will be on location to stab into coil connector if necessary. c. The blow out plug will be pressure tested with 1000 psi differential pressure before including it as a barrier in the installation process. d. **If gas is seen to surface when cutting coil, contingencies include shearing coil at the BOP, isolating the well and allowing the string to go downhole.** • OIgoonik Company: ConocoPhillips Alaska Well No: BRU 233-27 Well Type: Ni Co.Man: Jay Maguire Rig: Temp: Ofi^field Services Contact#: Field: Date: L44 4 Services VG-i0 Location: Prepared By: Contact: OD ID Length Equip BHA Description Connection Fish Neck (in) (in) (ft) Supplier -A: 3-1/2"9.2#Paragon II Packer 2.700" 1.625" 2-3/8"Reg Pin 3.795' 2.700"OD x 1.625"ID Seal Bore Sealed Tubing Swivel 2.375" 1.985" 2-3/8"Reg 1.00' f,' I`�I ill 2.00"Coiled Tubing Connector 2.375" 1.985" 2-3/8"Reg 1.31' F _ ) 1 U I _) 2"Coiled Tubing 2.00" 1.75" N/A 1300.00 It i 1 i Special Blow out Plug,Seating Nipple, 2.375" 1.985" N/A 2.10 il and CT Connector(1,800 psi)w/ Pump Out Plug Max 0. & Min.I . = 2.7 1.625 Total BHA Length: 1309,17 Please note that all OD's&ID's are approximate,and are given as guidance only BHA w/o Coil 9.17 TRADE SECRET AND CONFIDENTIAL All Shear Screw values are+/-15% lanaris Shipping WELD LOCATION RECORD Shipping Spool SPOOL TYPE Metal SPOOL SIZE 150-95-80 SPOOL ID NO 7485 �� STRING NUMBER 35994 Weight Meters Feet Gauge Strip Number GRADE HS-90-C BHISG 6,424 780.29 2560 .125 / P324446-1 7,001 850.39 2790 .125 / P324446-2 SIZE 2.00 6,863 833.63 2735 .125 / P324446-7 SALES ORDER NO 36008464 6,863 833.63 2735 .125 P324446-8 3,011 365.76 1200 .125 / P324450 IA DATE COMPLETED 12-18-2014 SHIPPED TO Baker Hughes, Alaska P.O. NUMBER 4507555359 TOTAL FOOTAGE 12,020 TOTAL METERS 3,663.70 EST TUBING WT 30,162 EST SPOOL WT 6,700 EST CWR WT EST TOTAL WT 36,862 FITTING LOCATION Outside Wrap FITTING TYPE 21502 Wing Half FITTING I.D. NO. 50508,50220,50536 COMMENTS: I Indicates CM(Continuously Milled)type weld Prepared By KW FOR0646711 Effective Date;3.22.2012 • N 4, N eQo 0 0v Q :4 ti " wp if � Ua -771 a)O N° � Q 4O 0 cn.? r 'RU 233-27 Final Com,_ ation . ; 7" 26 and 29#, N80 and P110 casing / 3-1/2" 9.2# N-80 BTC-AB Mod Special Clearance NPC tubing i 1.9" 2.9# N-80 CS-Hydril Heat String To 1830' / //, X. 3-1/2" Cameron tubing hanger w/double pin pup. W. 3-1/2", 9.2#, N-80, BTC-Mod, Special Clearance Tubing to hanger ,,..,,/ f V. Camco 3-1/2" Selective Nipple w/2.813" W-1 internal nipple profile U. 1 joint 3-1/2", 9.2#, N-80, BTC-Mod, Special Clearance Tubing T. Camco 3-1/2" X 1.5" MMG GLM w/4' handling pups (loaded w/DV) S. 1 joint 3-1/2", 9.2#, N-80, BTC-Mod, Special Clearance Tubing i, — E R. Baker 3-1/2" x 7" FHL packer(2989' / / Q. Two joints 3-1/2", 9.2#, N-80, BTC-Mod, Special Clearance Tubing Old Squeeze j - ,t Perfs. P. Baker 3-1/2" X 7" FHL packer (3067') 3026-3027' O. Camco 3-1/2" X 1.5" MMG GLM w/4' handling pups (loaded w/DV) N. 1 joint 3-1/2", 9.2#, N-80, BTC-Mod, Special Clearance Tubing M. Steel blast joints: 3-1/2", N80, BTC-Mod (5' overlap on all perfs) / Sterling Perfs: 3090' - 3602' r L. Pup joint: 3-1/2" X 10', 9.2#, N-80, BTC-Mod, Special Clearance Tubing • 6 i / K. Camco 3-1/2" Sliding Sleeve w/2.813" W-1 internal nipple profile (selective nipple) J. Pup joint: 3-1/2" X 10', 9.2#, N-80, BTC-Mod, Special Clearance Tubing 3' E I. Baker 3-1/2" X 7" FHL packer @ 3649' • i H. Camco 3-1/2" X 1.5" MMG GLM w/4' handling pups (loaded w/DV) , G. 1 joint 3-1/2", 9.2#, N-80, BTC-Mod, Special Clearance Tubing F. Steel blast joints: 3-1/2", N80, BTC-Mod (5' overlap on all perfs) Upper Beluga Perfs: 3717' - 4175' E. Camco 3-1/2" Sliding Sleeve w/2.813" W-1 internal nipple profile (selective nipple) i D. 1 joint 3-1/2", 9.2#, N-80, BTC-Mod, Special Clearance Tubing C. Camco 'D' nipple 2.75" NOGO / B. 2 joints 3-1/2", 9.2#, N-80, BTC-Mod, Special Clearance Tubing / ::,' A. Baker GBH-22 Seal Assy. (5' seals) Baker Gravel Pack Packer (Model SC-1L, 4" Seal Bore) @ 4294' i Gravel pack screens and assembly liLower Beluga Perfs: 4442' - 5222' r J RECEIVED Baker Model F-1 Sump Packer @ 5243'(5238' WLM) 7 SEP - 91993 410-::::.1%:'.::':::,:'-:":••:'•:':::':::-::•:::411b,. 3-1/2" 9.2# N-80 Long String @ 5246' Alaska Oil & Gas Cons. (ornmiSSlOi1 PBTD @ 5260' Anchorage �. • SAK BRU 233-27 P a Well Attribl 'Max ) TD ConocoPhilli s -- Alaska Inc Wellbore API/lift Field Name Wellbore Status Incl(') MD Act Bt (MB) ,..,,,,,I,,,, 502831002600 I BELUGA RIVER UNIT PROD 1.00 5,430.00 5,680.0 • Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ••• Well Config.-BRU 23327 2/7/2013 W.18-.27 AM SSSV:NIPPLE Last WO: 8/11/1993 49.21 12/25/1963 Sch233-FT AtWal Annotation Depth(MB) End Date Annotation 'Last Mod By End Date Last Tag:RKB 5,231.0 1/23/2013 Rev Reason:TAG haggea 2/7/2013 MANGER,15 CasingStrings CONDUCTOR I l _ Insulated W.-. Casing Description String 0... String ID...Top(ftKB) Set Depth(f---Set Depth(ND)...String Wt.-String... String Top Thrd SURFACE. CONDUCTOR 30 28.000 15.0 29.0 29.0 WELDED 15-303 Insulated 36" Casing Description String 0... String ID...Top(RKB) Set Depth(f--.Set Depth(ND)...String Wt..String...String Top Thrd SURFACE 16 15.124 15.0 303.0 303.0 75.00 J-55 8RD Casing Description String 0... String ID...Top(18KB) Set Depth(f-..Set Depth(ND)...String Wt..String... String Top Thrd NTERMEDIATE,_ __ INTERMEDIATE 103/4 9.850 15.0 2,400.0 2,399.9 51.00 P-110 8R 762,400 Casing Description String 0... String ID...Top(HKB) Set Depth(f.-.Set Depth(TVD)...String WL..String... String Top Thrd NIPPLE,2,898- - PRODUCTION J 7 6.276 16.9 I 5,305.0 5,304.8 26.00 N-80 BUTT GAS LIFT, Tubing Strings 2,940 Tubing Description String 0... String ID...Top(WB) Set Depth(f...Set Depth(TVD)...'String Wt..String... String Top Thrd PACKER,2,989 ---- - TUBING WO 3 1/2 2.992 15.0 5,245.3 5,245.1 9.20 N-80 BTC-MOD 4�- Completion Details CMT SO2,_ - Top Depth -- 3,026-3,026 (NDI Top Ind Nomi... PACKER,3,087 -- � Top(RKB) (RKB) (") Item Description Comment ID(In) 15.0 15.0 0.42 HANGER CAMERON TUBING HANGER 3.500 GAS LIFT, f 3,078 .. 2,899.2 2,899.1 0.41 NIPPLE CAMCO W-1 SELECTIVE NIPPLE 2.812 2,989.2 2,989.1 0.25 PACKER BAKER FHL RETRIEVABLE PACKER,50K SHEAR RELEASE 3.000 APERF, • __. 3,090-3,116 M. 3,067.2 3,067.1 0.28 PACKER BAKER FHL RETRIEVABLE PACKER,50K SHEAR RELEASE 3.000 3,12A37,72% - - - 3,092.2 3,092.1 0.29 BLAST JTS BLAST JOINTS 2.992 APERF, 3,451.2 3,451.1 0.44 BLAST JTS BLAST JOINTS 2.992 3,1663,178 = fs 3,634.2 3,634.1 0.11 SLEEVE-C CAMCO W-1 SLIDING SLEEVE w/NIPPLE(CLOSED) 2.812 APERF, 3,232-3,248 SAK BRU 233-27 ConocoPhillips 14 Alaska,Inc. Co 3UOPh-llps • KB-Gtd(ft) Rip Release Date Wel Conk] -BRU 233-27,2/7201310:18:27 AM _ 49.21 12/25/1963 Schematic-Actual HANGER,15 - CONDUCTOR Perforations&Slots _ Insulated 36' ------ - Shot SURFACE, Top(TVD) Btm(TVD) Dens 15303 Top(ftKB) Ben(ftKB) (ftKB) (MB) Zone Dab (eh... Type Comment 4,906.0 4,910.0 4,905.8 4,909.8 G,BRU 233-27 8/3/1993 12.0 RPERF PerfTCP 4,906.0 4,910.0 4,905.8 4,909.8 G,BRU 233-27 8/3/1993 16.0 SLOTS Gravel Pack NTERMEDIATE, 4,912.0 4,917.0 4,911.8 4,916.8 G,BRU 233-27 8/3/1993 16.0 SLOTS Gravel Pack 152,400 a 4,912.0 4,917.0 4,911.8 4,916.8 G,BRU 233-27 8/3/1993 12.0 RPERF Perf TCP NIPPLE,2,899119 9 5,211.0 5,222.0 5,210.8 5,221.8 H,BRU 233-27 8/3/1993 -16.0 RPERF OPEN,original 4 spf,Gravel Pack GASLIFT,940 5,224.0 5,225.0 5,223.8 5,224.8 H,BRU 233-27 3/13/1963 4.01 IPERF Pert TCP PACKER,2,989 Notes:Genet*&Safe I End Date Annotation CMT Sot, 1� 1/26/2011 NOTE:View Schematic w/Alaska Schematic9.0 - - 3,026-3,028 PACKER,3,067 GAS UFT, .. 3,078 APERF, a� 3,090.3,116 APERF, 3,123-3,126 APERF, 3,1653,178 APERF, 3,232-3,240 APERF, 3,332-3,338 APERF, 3,3453,360 APERF, 3,400.3,406 APERF, 3,426-3,434 • APERF, 3,456-3,490 APERF, 3,303 APERF, a 3,540-3,548 APERF, 3,556-3,572 APERF, 3,584-3,602ERF 02, 8 CMT T 3C OZ, ,614 SLEEVE-C, 3,634 PACKER,3,649 _____ GAS LIFT, 19, 3,661 APERF, 3,717-3,734 - APERF, _ 3,754-3,760 APERF, m 3,889-3,894ERF, APERF, 4,105-4,110APERF, APERF, 4,162-4,176 -- SLEEVE-C, 4,186 NIPPLE,4,225 PACKER,4,294\ SLEEVE,4,303\ ,l RPERF, 4,442-4,456 SLOTS, 4,442-4,456 RPERF, 4,502-4,509 RPERF, 4,502-4,509 IPERF, 4,517-4,518 (' SLOTS, 4,624-4,828 I''. /WERE, 4,624-4,62RPERF8 , 4,4,664-4,674um 4,664SLTS O , - SLOTS, 4,737-4,743 APERF, 4,737-4,743 SCREEN,4,417 APERF,11 -- • 4,828.4,835 SL0T8, 1,82&4,835 SLOTS, 4,906-4,910 RPERF, - 4,906-4,9i0 RPERF,l\ ' 4,912-4,917 \ SLOTS, 4,912-4,917 RPERF,_ 5,211-5,222 IPERF, III 5,224-5,225ERF, SEAL ASSY, 5,242 PACKER,5,243 PRODUCTION, 17-5,305 TO,5,680 U m I ; : rQ O. OBI° 11 cti i n. of. o D / ' Uj W za a 8 177— III' =I � . �.�ik zw fElial rl WF \ w8 7 ry. 1 illlxlllG 11 q ° i 1!Ili � Sc li;;;I �'Pv ry a hil Q=1U' X(7 a 0.8R L-5- ii O a .44111iil, a 1,0 r I V G fl!Ir icy 1 i IN kl 04 jo I)Iliiiiilllf •k ki 14 s i IA 1= 1 S — m 1 a Th-D /6 3_ oo _ STATE OF ALASKA /�D ALASKA OIL AND GAS CONSERVATION COMMISSION NOTICE OF APPLICATION DEFICIENCY The attached application is being returned due to the deficiency or deficiencies listed below. Please submit a new application and all required supporting information. _insufficient information to confirm that the casing and cementing program will protect freshwater aquifers _insufficient information to demonstrate that the proposed perforations will be in compliance with applicable spacing provisions _insufficient information to demonstrate that adequate barriers to flow will be maintained _failure to calculate(or to calculate accurately)anticipated pressures insufficient information to confirm quality of cement and TOC, relative to proposed perforations _insufficient or contradictory well location information or coordinates _insufficient ,or/contradictory geologic prognosis information Xother a c Q C- 1E'; �T T a a P _other Z� 14)d-t a€ vS ? C r p other other SCANNED MA,',' 2 9 2015 ,� 24�4s • STATE OF ALASKA AL ...)KA OIL AND GAS CONSERVATION COMI .ION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Suspend r Perforate r Other Stimulate r After Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: Install velocity string p•. 2.Operator Name: 4.Current Well Class. 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r , ‘k.,3- pO2 • 3.Address: Stratigraphic r Service r 6. I Number: P.O. Box 100360,Anchorage,Alaska 99510 50-283-10026-00 , 7.If perforating, 8.Well Name and N ber: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No F BRU 233-27, '‘ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 029657 Beluga River Field/Beluga Gas Pool ` i .64i (Ic•• 11. PRESENT WELL CONDITION SU Y Total depth MD(ft). Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft): Plugs, 'me ured): Junk(measured). 5680 • 5680 • . le none Casing Length Size MD ( D Burst Collapse Conductor 14' 30" 29' b 29' Surface _ 288' 16" 303' 303' RECEIVED Intermediate2400' 2385' 10.75" 240e' Production 5288' Ti 4 5305' MAY 'L 1 21115 AOGGG Perforation Depth MD(ft). Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): from 3026-4835' 3026'-4835' ,' k 3.5 N-80 5245 Packers and SSSV Type' P. a :V MD(ft)and TVD(ft) 3 BAKER FHL RETRIEVABLE PACKERS . 111 : 298 06',3649 TVD=2989,3067,3649 2 BAKER SC-IL GRAVEL PACK PACKERS • I =`294 243 TVD=4294,5243 NO SSSV • 1 12.Attachments: Description Summary of Proposal 1; A-I Class after proposed work. Detailed Operations Program r BOP Sket ' .loratory r Stratigraphic r Development r`. Service r 14.Estimated Date for Commencing Operations: \ ' 15 Well Status after proposed work. 6/3/2015 • OIL r WINJ r WDSPL r Suspended r 16 Verbal Approval: Date: GAS r"- WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correc o the best of my knowledge Contact: Mike Hazen @ 265-1032 Email: Jay.C.Maquireaconocophillips.com Printed Name ///111...��)Jay Maguire Title: Wells Engineer / ,_ Signature � Phone:263-4551 Date 512 //5 Commission Use Only Sundry Nunter: Conditions of approval. Notify Commissi• so that a representative may witness '' I - '611 G'r Plug Integrity r BOP Test, • Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No IZ Subsequent Form Required. APPROVED BY Approved b : COMMISSIONER THE COMMISSION Date: PP Y Approved application Is valid tor 12 months{� trom the date of approval. Submit Form and ORIGINAL ',a -� ' u Form 10-403 Revised 5/2015 �ro J/ , Attachments in Duplicate '��,.5- RBDMS *k MAY 2 9 2015 e Iv' ! SAK BRU 233-27 ConocoPhillips 0g 61 Well Attributes Max Angle&MD TD Alaska 111C Wellbore APIIUWI Field Name Wellbore Status Inci(•) MD(ftKB) Act Btrn(ftKB) Cr�aaitlllMs 502831002600 BELUGA RIVER UNIT PROD 1.00 5,450.00 5,680.0 •- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Well Conec:-BRU 233-27,2/742013 10 1824 AM SSSV:NIPPLE I Last WO: 8/11/1993 49.21 12/25/1963 Scnemalic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:RKB 5,231.0 1/23/2013 Rev Reason:TAG haggea 2/7/2013 "ANGER,15 CasingStrings CONDUCTOR g I ted J, Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd SURFACE. CONDUCTOR 30 28.000 15.0 29.0 29.0 WELDED 1s3o3Insulated 36•' Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String-.String Top Thrd SURFACE 16 15.124 15.0 303.0 303.0 75.00 J-55 8R' Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String T •Thrd NTERMEDIATE. INTERMEDIATE 103/4 9.850 15.0 2,400.0 2,399.9 51,00 P-110 8R 15-2.400 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...S g Top Thrd NIPPLE,2,899 II PRODUCTION 7 6.276 16.9 5,305.0 5,304.8 26.00 N-80 BUTT GAS LIFT. _ -4 Tubing Strings 2.940 Tubing Description String 0... String ID...Top(ftKB) Set Depth If...Set Depth(ND)...String Wt...St(g...String Top Thrd PACKER,2,989 'r TUBING WO 31/2 2.992 15.0 5,245.3 5,245.1 9.20 -80 BTC-MOD CMTSOz. _ Completion Details 3,0263,028all___ Top Depth _ (ND) Top Incl Nomi... PACKER.3,067 - Top(ftKB) (RKB) C) Item Description Comment ID(in) GAS LIFT, f 15.0 15.0 0.42 HANGER CAMERON TUBING HANGER 3.500 3078 2,899.2 2,899.1 0.41 NIPPLE CAMCO W-1 SELECTIVE NIPPLE 2.812 APERF, 2,989.2 2,989.1 0.25 PACKER BAKER FHL RETRIEVABLE PACK.•,50K SHEAR RELEASE 3.000 3.090.3,116 3,067.2 3,067.1 0.28 PACKER BAKER FHL RETRIEVABLE PAPER,50K SHEAR RELEASE 3.000 APERF, 3,092.2 3,092.1 0.29 BLAST JTS BLAST JOINTS 2.992 3,1233,128 APERF, -', 3,451.2 3,451.1 0.44 BLAST JTS BLAST JOINTS 2.992 3.165-3.178 3,634.2 3,634.1 0.11 SLEEVE-C CAMCO W-1 SLIDING• EEVE w/NIPPLE(CLOSED) 2.812 3,232-3,248 -kql3,649.2 3,649.1 0.11 PACKER BAKER FHL RETRI •ABLE PACKER(50K SHEAR RELEASE) 3.000 APERF, 3,706.2 3,706.1 0.10 BLAST JTS BLAST JOINTS 4.770 3,332-3338 - APERF, "' 4,186.2 4,186.1 0.56 SLEEVE-C CAMCO W-1 S DING SLEEVE(CLOSED 10/93) 2.812 3,346-3,380 �i1, 4,225.2 4,225.1 0.55 NIPPLE CAMCO D 'PLC 2.75"NO GO(SET 5/16"DHC 5/97) 2.750 APERF. -- 3,400.3,406 -- 4294.2 4,294.1 0.54 PACKER BAKER S•IL GP PACKER w/SEAL ASSEMBLY 4.000 APERF, 4,303.2 4,303.1 0.53 SLEEVE GRA - PACK SLIDING SLEEVE 4.250 3,4263,434 4,326.2 4,326.1 0.53 XO Reducing CR• SOVER 3.5 x 2.375,ID 1.995,#4.7,N-80,EUE8RD 2.375 APERF, 4,417.1 4,417.0 0.51 SCREEN B• ER SLIM-PACK SCREEN(.012ga) 2.990 34563,490 APERF, 5,242.1 5,241.9 1.00 SEAL ASSY .AKER 5-11 SNAP LATCH ASSEMBLY 3.000 36063518 5,243.0 5,242.8 1.00 PACKER BAKER SC-1L GRAVEL-PACK PACKER 4.000 APERF, 3,540-3,548 APERF,RF, Perforations&Slots - 3.5563.572 --` Shot APERF, ,:, Top(ND) Btm'VD) Dens 3,584.3602Top(ftKB)Btm OMB) (ftKB) ( B) Zone Date 00- Type Comment _ 3,026.0 3,028.0 3,025.9 ,027.9 A,BRU 233-27 7/30/1963 5.0 CMT CMT SQZ FOR TESTING CMT SOZ,--- -- SQZ 3,612-3,614 - - 3,090.0 3,116.0 3,089- 3,115.9 A,BRU 233-27 8/8/1993 12.0 APERF Perf TCP 30 deg phasing SLEEVE-C, 3,634 - 3,123.0 3,128.0 3,1 .9 3,127.9 A,BRU 233-27 8/8/1993 12.0 APERF PerfTCP 30 deg phasing PACKER,3,649 _.. - 3,165.0 3,178.0 3 64.9 3,177.9 A,BRU 233-27 8/8/1993 12.0 APERF Perf TCP 30 deg phasing GAS LIFT,_ __ 3,232.0 3,248.0 4,231.9 3,247.9 B,BRU 23327 8/8/1993 12.0 APERF PerfTCP 30 deg phasing 3.661 3,332.0 3,338.0 3,331.9 3,337.9 B,BRU 233-27 8/8/1993 12.0 APERF Perf TCP 30 deg phasing APERF, I 3,346.0 3,380 1 3,345.9 3,379.9 B,BRU 233-27 8/8/1993 12.0 APERF Perf TCP 30 deg phasing 3,7173.734 - 3,400.0 3,41•.0 3,399.9 3,405.9 B,BRU 233-27 8/8/1993 12.0 APERF Perf TCP 30 deg phasing APERF, 3,426.0 3'34.0 3,425.9 3,433.9 B,BRU 233-27erf 8/8/1993 12.0 APERF PTCP 30 deg� � P hasin 9 3,456.0 4,490.0 3,455.9 3,489.9 C,BRU 233-27 8/8/1993 12.0 APERF PerfTCP 30 deg phasing APERF, 3,505.0 3,518.0 3,504.9 3,517.9 C,BRU 233-27 8/8/1993 12.0 APERF PerfTCP 30 deg phasing 3,889-3.894 - 3,540 r 3,548.0 3,539.9 3,547.9'C,BRU 233-27 8/8/1993 12.0 APERF PerfTCP 30 deg phasing APERF, 3,5 ..0 3,572.0 3,555.9 3,571.9 C,BRU 233-27 8/8/1993 12.0 APERF Pert TCP 30 degphasing 4,105-4,110 P 9 APERF, 3.84.0 3,602.0 3,583.9 3,601.9 C,BRU 233-27 8/8/1993 12.0 APERF Ped TCP 30 deg phasing 4,162-4,175 SLEEVE-C. •,612.0 3,614.0 3,611.9 3,613.9 C,BRU 233-27 7/30/1993 4.0 CMT CMT SQZ FOR TESTING 4,186 NIPPLE,4,225 SQZ SLEEVE,4,303 3,717.0 3,734.0 3,716.9 3,733.9 D,BRU 233-27 8/8/1993 12.0 APERF Perf TCP 30 deg phasing RPERF, 4,442-4,456 if 3,754.0 3,760.0 3,753.9 3,759.9 D,BRU 233-27 8/8/1993 12.0 APERF PerfTCP 30 deg phasing 4.442`4.456 - r 3,889.0 3,894.0 3,888.9 3,893.9 E,BRU 233-27 8/8/1993 12.0 APERF Perf TCP 30 deg phasing 4.502-4,509/ 4,105.0 4,110.0 4,104.9 4,109.9 E,BRU 233-27 8/8/1993 12.0 APERF Pert TCP 30 deg phasing RPERF, 4.502-4,5099 4,162.0 4,175.0 4,161.9 4,174.9 E,BRU 233-27 8/8/1993 12.0 APERF Perf TCP 30 deg phasing IPERF. iir 4.517J,518 ■ 4,442.0 4,456.0 4,441.9 4,455.9 F,BRU 233-27 8/3/1993 5.0 RPERF OPEN,original 4 spf,Perf TCP SLOTS, 4.624-4,628 'I 4,442.0- 4,456.0 4,441.9 4,455.9 F,BRU 233-27 8/3/1993 16.0 SLOTS Gravel Pack 46244,628 3sai 4,502.0 4,509.0 4,501.9 4,508.9 F,BRU 233-27 8/3/1993 5.0 RPERF OPEN,original 4 spf,Perf TCP RPERF, E/£' 4,664-4674 4,502.0 4,509.0 4,501.9 4,508.9 F,BRU 233-27 8/3/1993 16.0 RPERF Gravel Pack SLOTS, 4,6644,674 ins)4 4,517.0 4,518.0 4,516.9 4,517.9 F,BRU 233-27 3/15/1963 4.0 IPERF OPEN,origspf,Gravel Pack SLOTS, - ill 4737APERF-4•743 - 4,624.0 4,628.0 4,623.9 4,627.9 F,BRU 233-27 8/8/1993 5.0 APERF Perf TCP 4.7374.743 4,624.0 4,628.0 4,623.9 4,627.9 F,BRU 233-27 8/8/1993 16.0 SLOTS Gravel Pack SCREEN,4,417 APERF, 4,664.0 4,674.0 4,663.9 4,673.9 F,BRU 233-27 8/3/1993 16.0 SLOTS Gravel Pack 4829 4.835 I`. SLOTS, .4,664.0 4,674.0 .4,663.9 4,673.9 F,BRU 233-27 8/3/1993 5.0 RPERF PerfTCP 4828-4,835 SLOTS, 14,737.0 4,743.0 4,736.8 4,742.8 F,BRU 233-27 8/8/1993 16.0 SLOTS Gravel Pack 4,9064,910 -. RPERF, i 4,737.0 4,743.0 4,736.8 4,742.8 F,BRU233-27 8/8/1993 12.0 APERF PerfTCP 4,9084,910 4 RPERF, 4,828.0 4,835.0 4,827.8 4,834.8 G,BRU 233-27 8/8/1993 12.0 APERF Perf TCP 4,912-4,9171 SLOTS, •- 4,828.0 4,835.0 4,827.8 4,834.8 G,BRU 233-27 8/8/1993 16.0 SLOTS Gravel Pack 4,912.4,917 I La RPE �'�" x211-,RF,222 IS Mandrel Details (PERF, Top Depth Top • Port 5.2245,225 it S.•• (TVD) Incl OD Valve Latch Size TRO Run N-•Top(RKB) (ftKB) C) Make Model lin) Sery TYPe TYPe (In) (p I( Run Date Com_. SEAL ASSY, 1 2,940.2 2,940.1 0.24 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/11/1993 Closed 6242 PACKER,5243 _ 2 3,078.2 3,078.1 0.28 CAMCO MMG 11/2 GAS LIFT OPEN 0 0.000 0.0 1/25/1998 Open PRODUCTION, - , 3 3,661.2 3,661.1 0.11 CAMCO MMG 1 1/2 GAS LIFT CV RK 0.000 0.0 5/17/1997 Open TD,D,5 5,680680 • SAK BRU 233-27 • ConocoPhillips 044 • Naska.lnc coomn,ia KB-Grd(ft) Rig Release Date ••• 49.21 12/25/1963 Well Conic,. BRU 233-27.2n12013 m:18:27 AM Schematic-Actual HANGER, COONDUUCTORCTOR Perforations&Slots -- - InsulatedShit36•.� 4� Dens SURFACE, Top(TVD) 868(TVD) 15-303 Top(ftKB) Btm(ftKB) (BOB) (ftKB) Zone Date (sh Type Comment 4,906.0 4,910.0 4,905.8 4,909.8 G,BRU 233-27 8/3/1993 12.0 RPERF Perf TCP 4,906.0 4,910.0 4,905.8 4,909.8 G,BRU 233-27 8/3/1993 16.0 SLOTS Gravel Pack NTERMEDIATE, 4,912.0 4,917.0 4,911.8 4,916.8 G,BRU 233-27 8/3/1993 16.0 SLOTS Gravel Pack 15-2.400 4,912.0 4,917.0 4,911.8 4,916.8 G,BRU 233-27 8/3/1993 12.0 RPERF Perf TCP NIPPLE,2,899 5,211.0 5,222.0 5,210.8 5,221.8 H,BRU 233-27 8/3/1993 16.0 RPERF OPEN,original ..2f,Gravel Pack GAS LIFT, 2,940 5,224.0 5,225.0 5,223.8 5,224.8 H,BRU 233.27 3/13/1963 4.0 IPERF Pert TCP PACKER,2.989 Notes:General&Safety End Date Annotation 30263028 1/26/2011 NOTE:View Schematic w/Alaska Schematic9.0 PACKER.3,067 1` GAS LIFT. L 3,078 F APERF, 3,090.3,116 APERF._.. _. ■ 3,123-3,128 e APERF,_ ■ 3,1653,178 APERF, ,. ■ 3,2323El`. ,248 6 APERF, 3,3323,338 • APERF. ■ 3,3W3,366 RF,_ 3,40A0PE-3,406 i. ■ 3,426.3, APERF. 434 ... • APERF, 3,4563,490 -. APERF, 3,505.3,518 ' APERF, MI ■ 3,5403,548 APERF, 3,556-3,572 2 al • 3.5843. APERF, • 6027 - 3,612 CMT-3,614 SOZ, !• SLEEVE-C, 3,634 PACKER,3,649 -- GAS LIFT, _ T•1 3,661 3,7173, APERF, 734 d 3,754-AP3ERF,,760 -: APERF, g ' 3,8893,894 Fc _ APERF, m-'.: 4,105.4,110 l - APERF, -- 4,162-4,175 SLEEVE-C. I 4.186 1 NIPPLE,4,225 PACKER,4,294 SLEEVE 4,303 RPERF, IL * 6S,6F,9F.9F,78S, 0,624-4528ERF, 4,624-A629 RPERF, �:" — 4,6644,674 ' SLOTS, 4,664-4.674 — —_ SLOTS. — 4,7374,743 APERF, 4,7374,743 SCREEN,4,417 - APERF, . 4,8284,835 SLOTS. 4.828-4,835 SLOTS, SLOTS, 6 OTS, 4,90 ;;;IT 4,910 RPERF, 4,9064,970 ' RPERF. '.04 4,9124,917 SLOTS, 2OTS, es'r 4,97 RPERF, 5,211-5,222 IPERF, 5,2245,225 SEAL ASSY. 5.242 PACKER.5,243- PRODUCTION, 175.305 TO,5,680 232-23 The objective of this procedure is to utilize coiled tubing to hang off a velocity string o a packer from 50' RKB to 5900' RKB. Hanging the plug will the plug will give us production increas: rom .5 MMscfd to an expected rate of 1MMscfd.An outline of the work is listed below: 232-23 1. Rig up slickline 2. Pull WRDP insert fr•• @ 497' KB. 3. RU SL,drift well with . " OD swedge deep to 6,000' ' 1. 4. Drift to 100' RKB with 3.7 4 D swedge. 5. Set a plug in the CAMCO •..ple 0 197' KB to be lsed to pressure test all the tree connections/valves. 6. Pressure test tree valve and co' ections. 7. Pull plug @ 497' KB. 8. Rig up CTU 9. Run coil strinf.dbwn to 5900' (right above our lowe /perfs in •- upper completion) 10. Cut coif set up packer for CTU hangoff at 50' ' B. 11. RIH ith coil and set packer at 50' RKB. 12. ring well online producing up the coil string. The objective of this procedure is to utilize c• ed tubing to hang off a velocity string on a packer from 3900' RKB to 5200' RKB. Hanging the plug ill the plug will give us production increase from 3.9 MMscfd to an expected rate of 4.4 MMsc i.An outline of the work is listed below: 233-27 1. Rig up slickline 2. RU SL, drift well with 2.7" 0 swedge deep to 5,200' RKB. 3. Rig up CTU !ems !'.k P crre 4. Run coil string down to 5 00' 5. Cut coil and set up pack-r for CTU hangoff @ 3900' KB. 6. RIH with coil and set p.cker @ 3900' KB. 7. Bring well back onlin: producing through the coil string. !mag~roject Well History File Coverage XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. RES~AN DIGITAL DATA "OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: Quality Originals: Poor [] Other: NOTES: [] Other, No/Type BY: BEVERLY ROBIN VINCE~ARIA WINDY Project Proofing [] Other items scannable by large scanner OVERSIZED (Non-ScannabJe) [] Logs of various kinds //D Other BY: BEVERLY ROBIN VINCEN~ARIA WINDY DATE Scanning Preparation / x 30= ~.~+ /~/= TOTALPAGES Production Scanning ~ Stage I PAGE COUNT FROM SCANNED FILE: P^~ cou.~^~c.~s.u~.~.,, sc.~P.~.^.^~o.: ,,~ ~s NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: Is~ Quality Checked 12/10102Rev3NOTScanned,wpd ~1f&uŒ ~~ £~~~L\\£ ALASIiA OIL AND GAS CONSEllVATION COltlltlISSION July 26, 1994 Mark H Wittow Preston Gates & Ellis 420 L St Ste 400 Anchorage, AK 99501-1937 Dear Mr Wittow: Re: Z-Energy Spacing Exception Request / WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501.3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 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 Beluga River Unit Beluga River Unit Beluga River Unit Beluga River Unit Beluga River Unit Beluga River Unit Beluga River Unit Beluga River Unit Beluga River Unit Beluga River Unit 212-35 212-25 232-04 233-27 c.-- ~ -0 D () 9-/ 14-19 244-04 212-24 241-34 224-13 212-18 221-23 Beluga River Unit Beluga River Unit Beluga River Unit Beluga River Unit Beluga River Unit Beluga River Unit Beluga River Unit Beluga River Unit Burglin Pretty Creek Unit 214-35 232-09 224-23 232-26 BRWD-1 211-03 224-34 214-26 X33-12 #1 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. ,.')/:"(> "i-::nuC)" 0,) - '. -. ..¿>,) prlr1t,:d on tr'r:yC""d p,1P,H h " '",' J 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 RiverUnit 14-19 Beluga RiverUnit 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 headng and, if the latter, the reasons you believe a written submission would be insufficient. David W JohnSton Chairman jo/rpc~z-energy ALASKA OIL AND GAS · CONSERVATION COMMISSION WALTER J, HIGKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 2767542 July 26, 1994 Rosanne M Jacobsen, Atty 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 matedal 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. Chairman ~ jo/rpc~z-energy printed on recycled paper b y C. ~. ALASKA OIL AND GAS · CONSERVATION CO~IMISSION 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 h01e 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 headng and, if the latter, the reasons you believe a written submission David W Johnston \ -" ~ Chairman ~ jo/rpc~z-energy ARCO Alaska, I~~'''~ post Offi~:~. ~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 17, 1993 Mr. L. S. Mathis Chevron U.S.A. Production Company P. O. Box 1635 Houston, TX 77251 Mr. Doug Burbank Shell Western E&P, Inc. Box 576 Houston, TX 77079 Mr. Joe Dygas Bureau of Land Management Branch of Mineral Operations 222 West Seventh Avenue P. O. Box 13 Anchorage, AK 99513-7599 ...-E/ir. Larry Grant Alaska Oil & Gas Conservation Commission 301 Porcupine Drive Anchorage, AK 99501 Gentlemen' Under separate cover we are shipping the cased hole logging data obtained during this summer's two workovers (BRU 224-23 and BRU 233-27) at the Beluga River Field. Distribution is according to our .curr'ent requirement listings by Co-owner and regulatory' agency. See attached packing list for logs and format (tape, sepia, and/or blueline print) being sent. If you have any questions, contact me at 263-4879. Sincerely,' Brian Noel Engineer Attachment cc: D.A. Grove, ATO-1276 ARCO Alaska, Inc. is a Subsidiary of AtlanticRi~:htielclCompany ..... "' One box contains BOTH wells' Thermal Neutron Decay Log (TDT-P) ~p-'~ ~.. , Blueline Print " " Cement Bond Log (CBT) ¢q ~z:z2--e~¢--.5~ s ~fl (~ ,, ,, Cement Evaluation Log (CET) BRtJ 233-27 Thermal Neutron Decay Log (TDT-P) Cement Bond Log (CBT) ¢,.~ 2~o- 5~5H ¢,'(~_,_~.__..(~ " Cement Evaluation Log (CET) ~ z¢r,;o~ 5~6~--~L~z''~'' ,, Gravel Pack Log r../[ Cement Bong Log of Squeeze Cement Evaluation Log of Squeeze ~, ~ Blueline Print One copy of blueline prints. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown__ Pull tubing x Alter casing Stimulate x Plugging __ Perforate Repair well __ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1816' FSL, 2018' FEL, SEC 27, T13N , R10W, SM At top of productive interval VERTICAL WELL At effective depth VERTICAL WELL At total depth 1816' FSL, 2018' FEL, SEC 27, T13N , R10W, SM 12. Present well condition summary Total Depth: measured true vertical 5680' 5680' 5. Type of Well: Development_~X Exploratory _ Stratigraphic _ Service -- 6. Datum elevation (DF or KB) 104' KB, 7. Unit or Property name Beluga River Unit 8. Well number BRU 233-27 Plugs (measured) feet feet 9. Permit number/approval number 13-002 & 93-088(SA ADprv 10. APl number 50-283-10026-00 11. Field/Pool Beluga River/Beluga Sterling No) Effective depth: measured 5260' true vertical 5260' feet feet Junk (measured) Casing Length Size Cemented Structural Conductor 1 6' 3 6" Yes Surface 2 9 0' 1 6" Yes Intermediate 2387' 1 0- 3/4 Yes Production 5292' 7" Yes Liner Perforation depth: measured See Attached Schematic for Perforation true vertical See Attached Schematic for Perforation Tubing (size, grade, and measured depth) Intervals Intervals Measured depth True vertical depth 29' 29' 303' 303' 24O0' 2400' 5305' 5305' t ECEIVED S E P - 9 1993 Alaska 0il & Gas Co~ls. 3-1/2" 9.2# N-80 @ 5246'-Long String, 1.9" 2.9# N-80 Heater String @ 1830' Anchorage Packers and SSSV (type and measured depth) Baker FHL Retr Pkr @ 2989',3067', 3649', Baker Mod SC-IL Pkr @ 4294', Baker F-1 Retr Prod Pkr @ 5243' 13. Stimulation or cement squeeze summary Intervals treated (measured) *See Attached Report of Operations Treatment description including volumes used and final pressure ¸14. Prior to well operation Subsequent to operation Representative Daily Average Production or Inie(;tion Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector__ Oil _ Gas X Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-~'0~t Rev 05/17/8~ Title Area Drilling En~lineer SUBMIT IN~UP'LICATE 233-27 Final Com,. ation 7" 26 and 29#, N80 and Pl10 casing 3-1/2" 9.2# N-80 BTC-AB Mod Special Clearance NPC tubing 1.9" 2.9# N-80 CS-Hydril Heat String To 1830' Old Squeeze Perfs. 3026-3027 PBTD @ 5260' X. 3-1/2" Cameron tubing hanger w/double pin pup. W. 3-1/2", 9.2#, N-80, BTC-Mod, Special Clearance Tubing to hanger V. Camco 3-1/2" Selective Nipple w/2.813" W-1 internal nipple profile U. 1 joint 3-1/2", 9.2#, N-80, BTC-Mod, Special Clearance Tubing T. Camco 3-1/2" X 1.5" MMG GLM w/4' handling pups (loaded w/DV) S. 1 joint 3-1/2", 9.2#, N-80, BTC-Mod, Special Clearance Tubing R. Baker 3-1/2" x 7" FHL packer(2989~ Q. Two joints 3-1/2", 9.2#, N-80, BTC-Mod, Special Clearance Tubing P. Baker 3-1/2" X 7" FHL packer (3067') O. Camco 3-1/2" X 1.5" MMG GLM w/4' handling pups (loaded w/DV) N. 1 joint 3-1/2", 9.2#, N-80, BTC-Mod, Special Clearance Tubing M. Steel blast joints: 3-1/2", N80, BTC-Mod (5' overlap on all perfs) Sterling Perfs: 3090' - 3602' L. Pup joint: 3-1/2" X 10', 9.2#, N-80, BTC-Mod, Special Clearance Tubing K. Camco 3-1/2" Sliding Sleeve w/2.813" W-1 internal nipple profile (selective nipple) J. Pup joint: 3-1/2" X 10', 9.2#, N-80, BTC-Mod, Special Clearance Tubing I. Baker 3-1/2" X 7" FHL packer @ 3649' H. Camco 3-1/2" X 1.5" MMG GLM w/4' handling pups (loaded w/DV) G. I joint 3-1/2", 9.2#, N-80, BTC-Mod, Special Clearance Tubing F. Steel blast joints: 3-1/2", N80, BTC-Mod (5' overlap on all perfs) Upper Beluga Perfs: 3717' - 4175' E. Camco 3-1/2" Sliding Sleeve w/2.813" W-1 internal nipple profile (selective nipple) D. 1 joint 3-1/2", 9.2#, N-80, BTC-Mod, Special Clearance Tubing C. Camco 'D' nipple 2.75" NOGO B. 2 joints 3-1/2", 9.2#, N-80, BTC-Mod, Special Clearance Tubing A. Baker GBH-22 Seal Assy. (5' seals) Baker Gravel Pack Packer (Model SC-1L, 4" Seal Bore) @ 4294' Gravel pack screens and assembly Lower Beluga Perfs: 4442' - 5222' Baker Model F-1 Sump Packer @ 5243'(5238' WLM) 3-1/2" 9.2# N-80 Long String @ 5246' S E P - 9 1993 Alaska Oil & Gas Cons. (;oa~rnissio~ Anchorage ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: BRU 233-27 NORTH SLOPE BELUGA RIVER BELUGA RIVER 50- 283-10026-00 ACCEPT: 07/22/93 06:00 SPUD: RELEASE: 08/11/93-17:30 OPERATION: Workov~r DRLG RIG: WO/C RIG: ROLLN RIG 5 07/22/93 ( 1) TD: 5680 PB: 5260 07/23/93 ( 2) TD: 5680 PB: 5260 07/24/93 ( 3) TD: 5680 PB: 5260 MOVING RIG MW: 0.0 SCOPE DOWN & LOWER DERRICK. RD PMP LINES & INTERCONNECTS. MOVE RIG CARRIER TO BRU# 233-27 LOC. LAY OUT PIT LINER UNDER RIG AREA. START LAYING DOUBLE LAYER OF MATTING BOARDS ON LINER FOR RIG CARRIER. MOVING OTHER MODULES TO LOC ~ REPORT TIME. DRESS LIB F/SL RUN MW: 8.5 KC1 CONT TO MOVE RIG & RU. ACCEPT RIG ~ 1800 HRS 07/22/93. MIX 385 BBLS 3% KCL WATER IN PITS. PULL BPV'S. TEST ANN TO 1500 PSI. BLEED OFF TEST & SWITCH LINES TO LONG STRING. INJECT 55 BBLS 3% KCL WATER DN LONG STRING & INTO PERF. SHUT DN & MONITOR WELL-TBG ON VACUUM. MIX 70 BBLS XANVIS PILL. INJECT 58 BBLS VISC PILL INTO LONG STRING & PERFS. PRESS FELL TO ZERO, BUT MORE SLOWLY. CHASE VISC PILL W/17 BBLS, 3% KCL WATER. MONITOR WELL-LIGHT VACUUM. RU PRECISION WL SL UNIT. TEST LUB TO 1500 PSI. RIH & SET STANDING VALVE IN D-NIPPLE ~ 4420' TEST TO 1500 PSI-OK. RIH TO PULL 1-1/2" DUMMY VALVE F/CAMCO 'MM' GLM ~ 2917' COULD NOT LATCH ONTO DUMMY. OOH-JDC PULLING TOOL LOOKED LIKE IT WAS HITTING FISHING NECK ON DUMMY. DRESS LEAD IMPRESSION BLOCK FOR RIH. NU BOPE & RU FLOOR MW: 8.5 KC1 FIN DRESSING LIB. RIH & LOC IN GLM ~ 2917' UNSUCCESSFUL IN CATCH. WO SWS CREW FROM KENAI. SPOT SWS UNIT. RU WL, MU 1-11/16" TBG PUNCHER. TEST LUB TO 1400 PSI. RIH-TIE INTO GLM ~ 2917' & SAFTEY JT ~ 2961' PERF TBG F/2955'-2956.5', 7 SHOTS. POH. RD SWS. DISPLACE DIESEL FROM ANN & F/2-3/8" HEATER STRING WITH VISC 3% KCL WATER. RU SL. RIH & RETRIEVE STANDING VALVE F/D NIPPLE ~ 4420' RD SL. MONITOR WELL. WELL DEAD. SET CASASCO TYPE BPV'S IN BOTH 2-3/8" HGRS. ND DUAL 2-1/16" 5 KSI TREES. NU 11" X 7-1/16" 5 KSI DSA. C/O THREADS ON LONG STRING. NU DSA. NU 11" 5 KSI BOPE. RAISE FLOOR, LEVEL RIG. CHANGE PIPE RAMS TO 2-3/8" RU FLOOR & CORD. NU BOPE. RECEIVE S E P - 9 199,3 Anchorage WELL: BRU 233- API: 50- PERMIT: PAGE: 2 07/25/93 ( 4) TD: 5680 PB: 5260 07/26/93 ( 5) TD: 5680 PB: 5260 RACK & TALLY PIPE & TOOLS MW: 8.5 KC1 CHANGE PIPE RAMS TO 2-3/8" LEVEL RIG. RU FLOOR & NU BOPE. TEST BOPE(1 FAILURE-GATE VALVE IN CHOKE MANIFOLD, WAIT ON PARTS, UALVE CAN BE ISOLATED). TEST WITNESSED BY JOE RUSSELL, BLM. WITNESS BY AOGCC WAIVED BY BLAIR WONDZELL. ATTEMPT TO BACK TEST/LANDING JT OUT OF SHORT STRING HGR NO GO, HGR SPINNING IN FALSE BOWL. PULL 2 WAY CHECK FROM 2-3/8" LONG STRING HANGER. BREAK CIRC & CIRC ONCE AROUND THE PERF ~ 2955', NO GAS, NO FLUID LOSS. SET BPV IN LONG STRING HGR. BOLDS ON DUAL UPPER BOWL/SEALS. PULL 2-3/8" HEAT STRING HGR TO FLOOR. LD LJ. PULL 2 WAY CHECK FROM HGR & LD HGR. RECOVERED UPPER BOWL/PACKOFF SSY. POH. LD ALL 64 JTS SHORT STRING. PULL BPV F/2-3/8" LONG STRING. MU LANDING JT. WORK & ROTATE PIPE, PU TO 80K# OVERPULL SLACKED OFF TO NEAR NEUTRAL WT & HGR JUST OUT OF BOWL -1" & ROTATE W/FOSTER TONGS-BROKE CC SAFTEY JT. ROTATE & PU CLEAR OF SAFETY JT. LD LJ. CIRC 1 TBG VOL + ANN VOL THRU PERF ~ 2955', OK. POH. LD 2-3/8" PROD TBG-SLOWLY TO ALLOW PIPE TO DRAIN. RECOVERED ALL PIPE + GLM + TOP HALF OF SAFETY JT. CLEAR PIPE RACKS. LOAD RACKS W/170' JTS-3-1/2" DP + 9-4-3/4" DC & TRI STATE FISHING TOOLS-RACK & TALLY SAME. START RIH W/SAFETY RETR TOOL MW: 8.5 KC1 RACK & TALLY DC & FISHING TOOLS. MU FTA MI-GUIDE W/ CC SAFETY JT RETR TOOL & JARS & DC. STAND BACK. CHANGE PIPE RAM TO 3-1/2" FUNCTION TEST-OK. RIH W/FTA 01. PU DP. TAG TOP OF FISH ~ 2966' PU KELLY. ROTATE TO RELEASE UPPER PKR & RELEASE FROM NEXT CC SAFETY JT. RELEASED PKR & PU -4K# EXTRA WT. BREAK CIRC & CIRC OUT GAS & DIESEL F/BETWEEN PKRS. HELD 100 PSI ON.CHOKE FOR 1ST CIRC-THEN SHUT DOWN & MONITORED WELL-NO FLOW. CONT CIRC & HAD LOTS OF GAS THRU 2ND CIRC. GAS ~ SURF, CLEARED UP WELL AT START OF 3RD CIRC. MONITORED WELL AFTER 3RD CIRC-WELL STABLE, NO FLOW, NO LOSS. VACUUM-50 BBLS DIESEL OUT OF PITS & BUILD 80 BBL 3% KCL. MONITOR WELL-STABLE, VERY SLIGHT GAS BUBBLING ACTION-NO FLOW, NO LOSS.' POH-SLOW. PULL FREELY FOR 12 STDS, THEN STARTED SWABBING. WORKED DP UNTIL PULLING FREELY. BREAK CIRC & CIRC OUT GAS-MONITOR WELL-OK. CONT POH. SLIGHT FLOW OUT OF DC"S-CIRC OUT DC'S & TBG FISH. MONITOR WELL-OK. CONT POH. LD FISHING TOOLS & FISH. RECOVERED ALL FISH BETWEEN CC SAFETY JTS: TOP PKR + 44 JTS 2-3/8" JEWELRY. PREPARE TO RBIH W/FTA#1 TO FISH LOWER PKR & TAIL. RECEIVED $ E P - 9 t995 Alaska Oil & Gas Cons. Anchorage WELL: BRU 233- API: 50- PERMIT: PAGE: 3 07/27/93 ( 6) TD: 5680 PB: 5260 07/28/93 ( 7) TD: 5680 PB: 5260 07/29/93 ( 8) TD: 5680 PB: 5260 TEST STORM CHOKE TO 1500 PSI MW: 8.5 KC1 RIH W/FTA#1-PU 43 JTS DP. TAG CC SAFETY JT ON LOWER PKR & TAIL ASSY ~ 4346' PU-2' ABOVE FISH. BREAK CIRC & CBU TO CLEAR GAS OUT OF HOLE. ENGAGE FISH & ROTATE PKR FREE. PU -14' & WORK PKR A FEW TIMES TO BE SURE ITS FREE. CIRC TWICE AROUND ~ 3 BPM, VERY LITTLE GAS TO SURF. MONITOR WELL-STABLE. POH SLOWLY TO AVOID SWABBING. LD FTA#1 & FISH-RECOVERED ALL REMAINING FISH/LOWER PKR & TAIL ASSY. RD FOSTER TONGS. RU TO RUN DP. STRAP BHA #1. MU 6-1/8" BIT #1 & BHA #1. RIH-TAG BRIDGE ~ 5230' WORK & WASH THRU BRIDGE. TAG BTM @ 5260' CIRC HOLE CLEAN $ 5260'-SOME GRITTY FINE SAND OFF BTM, LITTLE TO'NO GAS. POH 5 STDS. MU BAKER STORM VALVE & PKR. RIH & SET STORM VALVE/PACKER ~ 90' POH W/SINGLE + 1 STD DP. PRESS UP TO 1500 PSI TO TEST STORM PKR. TESTING FLANGES ON BOP STACK MW: 8.5 KC1 TEST STORM PKR TO 1500 PSI-OK. ND 11" 5 KSI BOP STACK. ND 7-1/16" 5 SKI TBG HEAD. CHANGE OUT 7' CSG PACKOFFS-INSTALL NEW RUBBERS. INSTALL SECONDARY SEAL & NEW 11" X 9" 3 KSI TBG HEAD. TEST PACKOFFS TO 3000 PSI-OK. START TO NU BOP STACK-WRONG SIZE, NEED 9" 3KSI. COULD NOT LOCATE A DSA OR SPOOL. DS & R IN ANCHORAGE HAVING MACHINE SHOP BUILD XO RING GASKET & STUDS TO MAKE UP 9" 3 KSI & 5 KSI FLANGES. XO STUDS & RING ARRIVED & AIR STRIP. INSTALL STUDS IN DSA. NU 11" 5 KSI BOP STACK. SET TEST PLUG & TEST FLANGES TO 3000 PSI. RIH TO SET BP MW: 8.5 KC1 CONT TESTING BOPE & FLANGES-ALL OK. RIH TO RETRIEVE STORM PKR & POOH W/SAME. RIH W/DP TO 5260' CIRC HOLE CLEAN ~ 5260' FOR LOGGING RUN. POOH. RU SWS & PU LOGGING TOOLS. RIH W/SWS & LOGGING RUN #1, INCLUDING CCL/GR/CET/CBT. TAG PBTD ~ 5261' LOG F/PBTD TO 2400' CHANGE OUT LOGGING TOOLS. RIH W/LOGGING RUN #2, INCLUDING CCL/GR/TDT-P. MAKE TWO LOGGING PASSES F/5261'-2700' RD LOGGING TOOLS & CHANGE OUT SWS E-LINE TO RUN BAKER CAST IRON BP. MU BAKER BP & RIH. S E P - '3 199, Anchorage WELL: BRU 233- API: 50- PERMIT: PAGE: 4 07/30/93 ( 9) TD: 5680 PB: 5260 07/31/93 (10) TD: 5680 PB: 5260 08/01/93 (11) TD: 5680 PB: 5260 MONITOR WELL F/FLOW & RD SWS MW: 8.5 KC1 CONT RIH W/SWS & BP. SET TOP OF BP ~ 3628' WLM. ATTEMPT TO PULL OFF BP W/O SUCCESS. PU 75% OF WEAK PT & PULL WIRE LINE F/ROPE SOCKET. POOH W/WL, LEAVING SETTING TOOL & CCL IN HOLE. RD SWS. ND SHOOTING FLANGE. NU FLOWLINE. WAIT ON TRI-STATE TO ARRIVE ON LOC. MU TRI-STATE O/S, BUMPER SUB, JARS, & DC'S. RIH TO TOP OF FISH ~ 3618' RU CIRC HEAD & CIRC. WASH OVER FISH & LATCH ONTO SAME. POU TO ll0K, SET PACKOFF IN OVERSHOT, & PULL FISH FREE. DROP BAR TO PMP OUT SBU. PRESS TO 3000 PSI & SHEAR OUT SUB. SLIP & CUT DRILL LINE. TEST CSG. POOH W/DP & DC'S. LD FISH & FISHING TOOLS. TEST 7" CSG TO 1500 PSI W/PRESS STAB AROUND 1375 PSI. RIH W/BAKER TEST PKR. SET PKR ~ 3045', 13' BELOW OLD SQUEEZE PERFS. TEST CSG BELOW PKR TO 2000 PSI W/NO PRESS LOSS. RESET PKR ~ 3015', 17' ABOVE PERFS. TEST CSG BELOW PKR TO 1500 PSI W/PRESS BLEEDING TO 1380 PSI IN 15 MIN. TEST CSG ABOVE PKR TO 2000 PSI W/40 PSI LOSS IN 20 MIN. POOH W/TEST PKR. ND FLOW LINE. NU SHOOTING FLANGE. RU SWS & TEST LUB TO 1500 'PSI. RIH W/PERF GUNS & SHOOT SQUEEZE PERF F/3612'-3614' WLM. MONITOR WELL FOR FLOW AFTER SHOOTING PERFS. WELL IS DEAD. LD STD TO MAKE SINGLES F/DRLG MW: 8.5 KC1 POOH W/SWS & RD SAME. ND SHOOTING FLANGE, NU FLOW LINE. RIH W/BAKER CMT RET ON DP TO 3560' SET RET ~ 3560' & ESTAB INJ RATE INTO SQUEEZE PERFS. RU DOWELL TO SQUEEZE CMT. TEST LINES TO 3500 PSI, UNSTING F/RET, & PMP 10 BBLS FW, STING INTO RET, & PMP 19 BBLS CLASS G CMT. DISPLACE CMT TO PERFS BULLHEADING DP VOL INTO PERFS. SQUEEZE 9 BBLS AWAY & HESITATION SQUEEZE 6 BBLS, LEAVING FINAL SQUEEZE PRESS ~ 1375 PSI. LEAVE 2 BBLS CMT IN CSG BELOW RETAINER, UNSTING & PLACE 2 BBLS ON TOP OF RET. POOH W/5 STDS DP & REVERSE CIRC DP CLEAN. POOH W/DP. LD SETTING TOOL. WOC. RIH & TAG CMT ~ 3516' LD DP TO HAVE SINGLES F/DRILLING CMT. TEST PERF TO 1500 PSI MW: 8.5 KC1 DRILL 44' OF CMT & TAG RET ~ 3560' DRILL RET TO 3563' W/SOME JUNK STILL IN HOLE. DRILL HARD CMT & JUNK PAST SQUEEZE PERFS ~ 3612'-3614' WLM TO 3628' CIRC HOLE CLEAN. TEST CSG TO 1500 PSI W/RESULTS SIMILAR TO TEST BEFORE SQUEEZE. LOST 70 PSI IN 5 MIN. POOH STANDING BACK DP & DC'S. LD JARS & BIT. PULL WEAR RING & SET TEST PLUG. TEST BOPE TO 3000 PSI. FLANGE BETWEEN PIPE RAMS & BAG HAD SMALL LEAK. REPAIR & RETEST-OK. PU BAKER TEST PKR & RIH TO 3120' TO TEST SQUEEZE PERFS ~ 3612'-3614' WLM. SET PKR @ 3120'. RECEIVED S E P - 9 199,3 Alaska Oil & Gas Cons. Anchorage WELL: BRU 233- API: 50- PERMIT: PAGE: 5 08/02/93 (12) TD: 5680 PB: 5260 08/03/93 (13) TD: 5680 PB: 5260 08/04/93 (14) TD: 5680 PB: 5260 CIRC HOLE CLEAN MW: 8.5 KC1 SET TEST PKR ~ 3121' & TEST SQUEEZE ~ 3612'-3614' TO 1600 PSI W/NO PRESS LOSS IN 15 MIN. POOH W/BAKER TEST PKR. LD SAME. MU DRILLING ASSY & RIH TO 3628' PU & SERVICE RIG & KELLY_ DRILL CMT F/3628'-3632'. TAG BP ~ 3632'. DRILL OUT BP TO 363A' CBU. RIH PUSHING BP TO PBTD ~ 5262' CIRC HOLE CLEAN ~ 4 BPM & 500 PSI. POOH. LD BIT & C/0 JB. BIT HAS ALL 3 CONES JAMMED W/LARGE PIECE OF RUBBER F/PKR. JB FULL OF SMALL METAL FRAGMENTS. PU BIT # RR1, 2 JB, & 7" CSG SCRAPER & RIH TO PBTD ~ 5262' CIRC WHILE MIXING 30 BBLS SCOUR SWEEP PILL. GETTING CMT~RETURNS ON BTMS UP. PMP PILL AROUND ~ 5 BPM, SLOW RATE WHEN PILL HITS SURF. CIRC HOLE CLEAN. CIRC & KILL WELL AFTER PERF MW: 8.5 KC1 CONT TO CIRC HOLE CLEAN AFTER SCOUR SWEEP. POOH. LD BIT & SCRAPER. ND FLOW LINE & NU SHOOTING FLANGE. RU SWS E-LINE. LOG SQUEEZE INTERVAL F/3400'-3850' W/CBT/CET/GR/CCL. POOH & RD SWS. ND SHOOTING FLANGE & NU FLOW LINE. LOAD PERF GUNS & STRAP SAME. PU PERF GUNS & STRAP SAME. PU PERF GUNS & BHA F/PERF. RIH W/PERF GUNS ON 3-1/2" DP LEAVING MFE VALVE ON BTM OF DP IN CLOSED POSITION. FILL DP EVERY 6 STDS. LEAVE LAST 500' OF DP DRY. RU SWS. RU DROP BAR ASSY W/2 MASTER VALVES, FLOOR MANIFOLD, & HARD LINE TO RIG CHOKE. RIH W/SWS GR/CCL TO SET GUNS ON DEPTH, POOH. SET PKR & OPEN MFE VALVE. DROP BAR & FIRE GUNS W/WELL SHUT IN. LET PRESS STAB. STAB ~ 200 PSI. OPEN PKR BY-PASS & CLOSE ANN TO CIRC. PERF INTERVALS: 4442'-4456', 4502'-4508', 4624'-4628', 4664'-4674',4737'-4743', 4828'-4835', 4906'-4917', 5212'-5220' CIRC THROUGH PKR BY-PASS TO KILL WELL. RIH W/3-1/2: DP MW: 9.7 NaC1 CONT TO CIRC THROUGH BY PASS ON PKR IN ATTEMPT TO KILL WELL, 5 CIRC TOTAL, HOLE TAKING FLUID. MONITORED WELL WHILE MIXING HI-VIS POLYMER PILL. DISPLACED DP W/HI-VIS PILL, SHUT IN ANN & BULLHEADED REMAINING 100 BBLS OF PILL, FOLLOWED BY 27 BBLS OF 9.7 PPG NACL W/3% KCL BRINE. SHUT IN WELL, CLEAN PIT & SERVICE RIG. CIRC AROUND W/9.7 PPG BRINE WHILE HOLDING 200 PSI BACK. PRESS. MONITORED WELL WHILE BRINGING ON 300 BBLS OF 9.7 PPG BRINE. UNSET PKR ON PERF GUNS & CBU. RD FLOW HEAD. POOH W/3-1/2" DP. CONT TO POOH, LD BHA, & PERF GUNS. MU 6.125" BIT, DC'S, JARS & BUMPER SUB. RIH W/3-1/2" DP ~ REPORT TIME. RECEIV .D S EP - 9 1993 Alaska Oil & Gas Co~s. uu~.~miss~v" Anchorage WELL: BRU 233- API: 50- PERMIT: PAGE: 6 08/05/93 (15) TD: 5680 PB: 5260 08/06/93 (16) TD: 5680 PB: 5260 08/07/93 (17) TD: 5680 PB: 5260 MAKING PASS W/CCL MW: 9.7 NaC1 CONT RIH, TAGGED ~ 5259', WASHED DOWN TO 5260'_ CBU. TRANSFER BRINE F/PITS TO STORAGE TAKDS & CLEANED PITS. FILLED PITS W/FW FOR BUILDING NEW BRINE. MIXED & FILTERED 389 BBLS OF NEW 9.7 PPG NACL W/3% KCL BRINE. DISPLACED HOLE & CIRC W/NEW BRINE WHILE FILTERING SAME TO 2 MICRONS & TOTAL SOLIDS WERE LESS THAN 10 MG/LITER. POOH. ND FLOWLINE, NU SHOOTING FLANGE. RU SWS W/CCL, JB & GAUGE RING. RAN 6.063" GAUGE RING TO 5214' WHERE GAUGE RING STOPPED, WORKED THROUGH, CONT RIH TO 5258', MAKING PASS W/CCL TO 4600' ~ REPORT TIME. RIH W/GRAVEL PACK TOOLS MW: 9.7 NaC1 MU 7" MODEL F-1 PKR & RIH ON WL. SET PKR ~ 5233' WLM. ND SHOOTING FLANGE, NU FLOWLINE. PU 825.49' OF 3-1/2", BAKER SLIM PAK SCREEN, 3-1/2", NU 10RD, .012 GAUGE & 60 X 60 MESH. PU & RIH W/2-3/8" FLUSH JT WASH PIPE, CROSSOVER TOOL, & PKR. RIH W/GRAVEL PACK ASSY. TAGGED PKR ~ 5238' RU SURF EQUIP & TEST SURF LINE TO 4000 PSI, DROPPED BALL, WAITED 15 MIN. PRESS UP ON TBG IN INCREMENTS OF 500 PSI TO 2900 PSI TO SET PKR, PULLED TO 100K TO TEST PKR-OK. PRESS TEST ANN TO 1500 PSI & RELEASED F/PKR, PRESS DROPPED TO 1250 PSI FOR ANN TEST DUE TO SQUEEZE PERFS. PU & MARKED POSITIONS, ATTEMPTED TO BLOW BALL SEAT W/3400 PSI, NO GOOD. ATTEMPTED TO BLOW BALL SEAT W/4000 PSI A TOTAL OF EIGHT TIMES, NO GOOD, PRESS TESTED SURF EQUIP TO 5000 PSI-OK. ATTEMPTED TO BLOW BALL SEAT W/4600 PSI WITH THE ANN OPEN, NO GOOD. PULLED SEAL ASSY F/SCREEN, POOH W/DP TO SLIDING SLEEVE, SLEEVE WAS CLOSED. BROKE OUT SLIDING SLEEVE & BALL SEAT, FOUND RUST & SCALE PACKED ON TOP OF BALL, CLEANED OUT & DRESSED SLEEVE. MU INTO GRAVEL PACK STRING. RIH W/GRAVEL PACK TOOLS ON 3-1/2" DP, STUNG SEALS BACK INTO GRAVEL PACK ASSY. MU SCOURING SLURRY OF POLYMER & SAND @ REPORT TIME. RIH W/GRAVEL PACK TOOLS MW: 9.7 NaC1 CONT MU OF SCOUR SLURRY W/VISC 9.7 PPG BRINE & 10 PPG SAND. PMP 8 BBLS OF SCOUR SLURRY DN DP FOLLWED BY 18 BBLS OF 9.7 PPG BRINE. CONT PMP UNTIL 4500 LBS OF 20 X 40 SAND TO GRAVEL PACK SCREEN ~ 3 PPG & 3-1/2 BPM SCREENED OUT W/2000 PSI, REVERSED OUT 500 LBS OF SAND & NO GAS GRAVEL PACK IN PLACE @ 1900 HRS, TOTAL SAND PUMPED: 20,500 POUNDS. CIRC AROUND THROUGH SLIDING SLEEVE, MONITORED WELL, WELL DEAD, PULLED SEALS FROM GRAVEL PACK SCREEN & CBU, MONITOR WELL, WELL DEAD. POH. LD GRAVEL PACK TOOLS, RU TO LD 2-3/8" WASH PIPE. LD 2-3/8" GRAVEL PACK WASH PIPE. ND FLOWLINE, NU SHOOTING FLANGE. RU SWS, RUNNING TDT/GR/CCL ~ REPORT TIME. RECEIVED SE P - 9 1993 Alaska Oil & Gas Cons. Anchorage WELL: BRU 233- API: 50- PERMIT: PAGE: 7 08/08/93 (18) TD: 5680 PB: 5260 08/09/93 (19) TD: 5680 PB: 5260 08/10/93 (20) TD: 5680 PB: 5260 CIRC OUT GAS MW: 9.7 NaC1 CONT RUNNING TDT/GR/CCL. POH & PU BAKER RBP & RIH. RBP ~ 4250' WLM. ND SHOOTING FLANGE & NU FLOW NIPPLE. RIH W/1 STD OF DP PAST BOP'S & DUMP 7 SACKS OF SAND DOWN CASG ON TOP OF BP(30"). PULL WEAR BUSHING, SET TEST PLUG, & ATTEMPT TO TEST BOPE, NO GOOD, PULLED TEST PLUG & CHANGED OUT SEALS, RESET & TESTED BOPE. JOE RUSSEL W/BLM WAS NOTIFIED & WAIVERED THE TEST. RU TO PU TCP GUNS(1092'), PU SAME, 1 JT OF 2-7/8" TBG, DEBRIS SUB, 2-7/8" PUP JT, PKR, DC, SLIP JT, 2 DC'S, MFE VALVE, RA MAKER & REVERSING VALVE. RIH W/DP WHILE FILLING PIPE W/BRINE, LEFT LAST 500' DRY. RU SWS & RIH THROUGH DP W/GR/CCL TO CORRELATE & PLACE GUNS ON DEPTH. MU SWS SURF EQUIP & TEST TO 3000 PSI. SET PKR ~ 3032' WLM, CYCLED MFE VALVE, DROPPED BAR & FIRED GUNS ~ 0300 HRS, LIQUID TO SURF @ 0310 HRS. SHUT IN WELL & OPENED BY-PASS VALVE, CIRC WELL THROUGH CHOKE, GAS TO SURF ON BU. CIRC WELL ~ REPORT TIME. CBU MW: 9.7 NaC1 CONT TO CIRC THROUGH CHOKE TO KILL WELL, CHECKED FOR FLOW, NO FLOW. RD HARD LINE & SWS TEST HEAD. POOH W/DP. PULL TO TOP OF TCP ASSY, WELL BEGAN FLOWING, SHUT IN WELL. SIDP=100 PSI, SICP=280 PSI, CIRC THROUGH CHOKE, CHECKED F/FLOW, WELL CONT TO FLOW GAS BUT AT A LOW RATE, PREP TO RUN BACK IN HOLE. RIH W/DP, BTM OF GUNS ~ 4210' CIRC AROUND THROUGH CHOKE TO KILL WELL, CHECKED FOR FLOW, SHUT WELL IN. SIDP=35 PSI, SICP=25 PSI, CIRC AROUND THROUGH CHOKE. CONT TO CIRC & MONITOR WELL WHILE FLOWING THROUGH FLOW NIPPLE, GAS DECREASED & STOPPED (GUN GAS). POOH W/STCP ASSY. LD GUNS(ALL GUNS HAD FIRED), WELL DEAD. PU BAKER RETRIEV TOOL FOR BP, RIH ON DP. WASHED DOWN THROUGH SAND & PERF DEBRIS, TAGGED RBP ~ 4250', RELEASED . IMMED HAD FLUID LOSSES OF 8-10 BBLS/HR. RIH TO 4275' & CIRC WELL AROUND FOR ANY GAS, SMALL AMT OF GAS TO SURF. CIRC WELL & PREPARE TO PMP 70 BBLS VISC PILL ~ REPORT TIME. RUNNING PROD STRING MW: 9.7 NaC1 SPOTTED 70 BBL HI-VIS PILL 0 4275' PULLED 21 STDS & WELL BEGAN TO FLOW, BULLHEADED 50 BBLS BRINE. RIH TO 4275' CIRC WELL AROUND & MONITORED FOR FLOW, NO FLOW. POOH W/BP SLOWLY. LD SAME. RIH W/OEDP TO 4275'. CIRC WELL, WELL LOSING FLUID, 1-2 BBLS/HR. PU KELLY & SWIVEL, LD SAME. LD DP. RIH W/ll STDS DP & 4 STDS DC'S IN DERRICK. LD SAME. PULLED WEAR BUSHING. RU TO RUN PROD STRING. RIH W/3-1/2" TBG & COMP ASSY ~ RPT TIME. RECEIVf. D S E P - 9 1993 Alaska 0ii & {~as Cons. Anchorage WELL: BRU 233- API: 50- PERMIT: PAGE: 8 08/11/93 (21) TD: 5680 PB: 5260 ND BOPE & RILDS MW: 9.7 NaC1 CONT RIH W/3-1/2" COMP ASSY. SPACE OUT TBG & LAND HGR. RU SL & RIH W/PLUG TO SET IN "D" NIPPLE. HANG UP IN LANDING NIPPLE ~ 2895' & SET PLUG. POOH. RIH TO RETRIEVE PLUG. POOH W/PLUG. RIH W/STANDING VALVE & SET IN #D" NIPPLE ~ 4220' POOH &'RD SL. PRESS TBG TO 1500 PSI F/10 MIN TO SET FHL RET PKR. TEST ANN TO 1500 PSI. SET BPV IN 3-1/2" TBG. RU TBG RUNNING CREW & RIH W/57 JTS 1.9"__2.9#, N-80 HEATER STRING TO 1824'. LAND STRING IN TBG HEAD. ND FLOWLINE & LIFT BOPE TO ASSURE TBG HGR IS ORIENTED CORRECTLY. ND BOPE. C/O LOCKDOWN THREADS W/CHASER. RILDS. 08/12/93 (22) TD: 5680 PB: 5260 RIG RELEASED ~ 1730 08/11/93 MW: 9.7 NaCl CONT NU X-MAS TREE, TEST SAME TO 3000 PSI HI & 250 PSI LOW FOR 15 MIN-OK. PULLED BPV. RU SL. RIH TO PULL STANDING VALVE IN CAMCO 'D' NIPPLE ~ 4235' SLM, COULD NOT RETRIEVE, POOH W/SL. RIH W/MODIFIED RETRIEVING TOOL, & PULLED STANDING VALVE FROM 'D' NIPPLE. RD SL UNIT. SET BACK PRESS VALVE WHILE DUMPING & CLEANING PITS. CONT TO DUMP & CLEAN PITS, RELEASED RIG ~ 1730 HRS 08/11/93. SIGNATURE: DATE: RECEIVED S E P - 9 199;5 Alaska Oil & Gas Cons. L, umrnis~~' Anchorage · - : STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: Abandon Suspend _ Operation Shutdown Re-enter suspended well "~,/,~'~,°- - Repair well 2. Name of Operator Service Alter ca~ing _ Change approved program _ Pull tubing 5. Type of Well: Development ARCO Alaska, Inc. Exploratory 3. Address Stratigraphic P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1816' FSL, 2018' FEL, Sec 27, T13N, R10W, S. M. At top of productive interval Vertical Well--Same as above At effective depth Vertical Well--Same as above At total depth Vertical Well--Same as above Plugging_ Time extension_ Stimulate X Variance Perforate X. Other 6. Datum elevation (DF or KB) 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 5680' feet Plugs (measured) 5680' feet 5260' feet Junk (measured) 5260' feet Casing Length Size Cemented Structural Conductor 1 6' 36" Yes Surface 290' 1 6" Yes Intermediate 2387' 1 0- 3/4 Yes Production 5292' 7" Yes Liner Perforation depth: 104' KB 7. Unit or Property name Beluga River Unit feet 8. Well number BRU 233-27 9. Permit number 63-002 10. APl number 50-283-10026-00 11. Field/Pool Beluga River Unit Beluga/Sterling Measured depth True vertical depth 29' 29' 3O3' 3O3' 2400' 2400' 5305' 5305' RE£EIVED measured See Attached Schematic for perforation intervals. true vertical Vertical Well (See attached schematic) APR1 9 199 Tubing (size, grade, and measured depth) Production: 2-3/8", N80, to 5225'; Heater String: 2-3/8", N80, to 1999'Alaska 0ii & Gas Cons. C0mmiss[0~ Packers and SSSV (type and measured depth) Anchorage Brown HS-16-1, 2-3/8" X 7" @ 2972'; Brown HS-16-1 2-3/8" X 7" @ 4354' 13. Attachments Description summary of proposal ~ Wellbore Schematics, Operations summary of propasal 14. Estimated date for commencing operation I15. May 17, 1993 I 16.If proposal was verbally approved Detailed operation program _ BOP sketch Status of well classification as: Oil __ Gas X Suspended _ Service Date Name of a~pp~er~/ Date approved 17. I hereby//dej~ JJ~'[ the foregoing is true and correct to the best of my knowledge. Signed ~//~~ Cr/,~.~,/~-/¢~,~4.Title AreaDrillin~lEn~lineer - ~/' FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IIAppr°val Plug integrity __ BOP Test Mechanical Integrity Test_ Approved by the order of the Commission Location clearance Subsequent form require Origina~ S!gned By David W. Johnston 10- ~O/q Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE BRU 233-27 GENERAL WORKOVER PROCEDURE 4/14/93 Beluga River Unit Well 233-27 will be worked over in late May. The objective of the workover is to add perforations and gravel pack the Lower Beluga Formation, squeeze above and below the Sterling Formation to obtain zonal isolation, and perforate the Sterling Formation. The well will be re-completed with a 3-1/2" single selective completion with a 1.9" heater string. Pre-Rig Procedure: 1. Contact AOGCC and advise of upcoming of workover so that they can be present to witness BOPE tests. 2. Prep. location (remove wellhead shelter, level location, spot dikes and tanks, MU hardline, etc). 3. RIH with wireline and pull dummy valve from gas lift mandrel above top packer. 4. Set back pressure valves (BPV's) in production string and heat string. General Workover Procedure: (23 days) 1. Lay hardline to tree. Mix Brine (+9 ppg). Pull BPV's from both strings. 2. Kill well. 3. Install BPV's, remove tree. Nipple up and test BOPE. (notify AOGCC of test R E C E iV E D 4.Pull heat string. APR 1 9 199,~ 5. Rig up E-line. RIH and cut tubing below both safety joints. Alaska Oil & Gas Cons. CommiSSiOn 6. Pull tubing above top packer. Anchorage 7. RIH with drill pipe. Release packer by rotating to right and POOH w/same. 8. RIH with drill pipe and pull bottom packer and tail pipe. BRU 233-27 PROCEDURE (CONT.) 9. RIH and cleanout to PBTD at 5260' with bit and scraper. Filter brine. 10. Rig up E-line. Run bond logs and formation evaluation logs. Evaluate same to determine perf depths, squeeze requirements. 11. RIH with drill pipe conveyed perf guns and perf lower Beluga zone at 12 spf. Perf underbalanced. Kill well. POOH. 12. Gravel pack lower Beluga. 13. RIH and set retrievable bridge plug below Sterling. Spot sand on same. 14. Pressure test 7" casing to 2000 psi. If pressure test fails, pick up packer (RTTS) and set above squeeze perfs. Retest casing. If squeeze perfs leak, will isolate with stradle packers. 15. Squeeze Sterling Formation as required to obtain zonal isolation. 16. Cleanout top set of squeeze perfs and test same (if old squeeze perfs held). If test, continue cleaning out to below the bottom set of squeeze perfs and test same. Filter brine. 17. RIH with drill pipe conveyed perf guns and perf Sterling and Upper Beluga underbalanced. Kill well. POOH. 18. RIH with drill pipe and retrieve bridge plug. 19. Set storm packer. Nipple down BOP's. Change out tubing spool. Nipple up BOP's. Pull storm packer. POOH and lay down drill pipe. 20. Run 3-1/2" selective completion. Run 1.9" heat string. 21. Nipple down BOPE, nipple up and test tree. RECEIVED APR 1 9 Alaska Oil & Gas Cons. Oommission Anchorage ~.~CC~-.Alask a. Inc. I'I~RU 233-27- ~ucl Date: 2/63 Last Compl: 3/63 Chematic Rev: 10/28/91 lw 1/4 Si:: 1/4 ,Sec.27,T13N,R10,$M Beluaa River Unff ,~-'-~- ~ 283-10026-~ Original RKB (Depth Ret): Ground Level: Maximum Hole Angle: Angle at Perforations: 'J ,~"% / Well Type: Gas Proclucerl ..4' Annulus Ruid: Diesel I 89" Top of ~terling: 3088' 1' A~._ 2627002~15941 3/4* Single w/heater string i mm mine m mm m mm 1 3 -=-- $ 6 X X 12 4 10 TD-5680' 1 14' 2 291T 13.2' 3 2961' 1.1:7 4 2972 6' 5 3039 1.52' 6 4267' 3.79 7 4299 13.10" 8 4341' 1.0" 9 ~ 1.10' 10 43.~' 6.00' 11 4360' 1.10" 13 5224' .58' Tubing Hanger Camco MM Mandrel B~wn CC Safety Jt. Brown Pocket HS-16-1 2 3/8"x 7' 2 3/8' Otis ~" Nipple Pos. 1 Camco MM Mandrel 2 3/8 "x 2 7/8" X-over & collar 2 7/8" x 7" Brown HS-16-1 Packer 2 7/8' x 2 3/8" X-over & collar 2 3/8" Camco "D" Nipple Venturi Shoe Cmk~ and Tubtng Surface 16" Intermediate 10 3/4" P~:Sucflon Csg 7' Production C..sg Production Csg Production Tl:)g 2 3/8" Production Tbg 2 3/8' Heater 2 3/8' 75~ J-55 8R 13.2" 51~ P-110 8R 13.2" 261~ P-110 8R 13.2' 26~ N-80 8R 2265' 26~ P- 110 8R 5225' 4.7~bevel N-80 8R 13.2" 4.7~ N-80 8R 2058' 4.7fbevel N-80 8R 13.2" F 4442'-4456' 4 14' 4502'-45[~ 4 7' 4664'~74' 4 10" 4~;K]6'-4917' 4 11' 5211'-5222" 4 11' 5224'-5225' 5 1' 6/14/77 10/3/87 5/4/91 1.70" Gauge ting 1.80" Guage ting ffi at 5230" RKB? f,I at 5231'RKB bottom at 5282' WLM? APR 1 Alaska Oil & Gas Cons. Anchorage Open Open Open Open Open JIB 10/28/91 BRU 233-27 Propose Completion 7" 26# J-55 casing 3-1/2" 9.2# N-80 BTC-AB Mod Special Clearance NPC tubing 1.9" 2.9# N-80 CS-Hydril Heat String TO 2000' Camco 3-1/2" Selective Nipple w/2.813" W-1 internal nipple profile 3-1/2" X 1-1/2" Camco MMG mandrel with circ valve and RK latch Baker 'FHL' 3-1/2" X 7" retrievable packer. Old Squeeze Perfs Baker 'FHL' 3-1/2" X 7" retrievable packer. Sterling Perfs Camco 3-1/2" Sliding Sleeve w/2.813" W-1 internal nipple profile (selective nipple) Baker 'FHL' 3-1/2" X 7" retrievable packer. Upper Beluga Perfs Camco 3-1/2" Sliding Sleeve w/2.813" W-1 internal nippl~,) profile (seleCtive nipple) Baker Seal Assy. (5' seals) Baker Gravel Pack Packer APR '~ 9 1~93 Alaska 0il & Gas Cons. Camco 'D' nipple 2.75" NOGO Anchorage Lower Beluga Perfs: Gravel Packed PBTD @ 5260' SDB 4/14/93 ~1 B STATE DEPARTMENT OF NATURAL RESOURCES Division of Oil and Gas Conservation TO: [-- FROM: MEMO TO FILES Harry. W. Kugler Petroleum Geologist DATE : June 13, 1977 ' SUBJECT: Beluga River Field Dave Courtis, Union Oil Company of California, called this date to report that there were no mud logs in the State files of the fOllowing wells: Socal BRU #232,4 Completed in 1963 Socal BRU 212-25 Completed in 1962 :~ Socal ~--- :-'-:_-' -~ ompleted in 1963 '~S'~E~'[~-BRO- 212-24 Completed in 1973 Socal BRU 224-13 Completed in 1974 He stated that'he believed our regulations are such that'we should request Socal (Chevron) submit these logs if they were run. I reported, after consultation wi th the Director and Staff members', that our interpretation of the regulations were not the same and'we would not require .the mud logs. Upon hearing this, he stated he would turn the matter over to Union's land department for their interpretation and the land department would be in touch with us. , / ST.A.~~..O!L COMPANY OF CALIFORNIA - WESTERN OPERATIONS,. INC. - OPERA~R _ '- -~ .............. ~.~ ', ~ ',L ' ......... '~ ' AREA: Cook Inlet, Alaska PROP~: Belu~ River Unit IAND OFFICE: .Anchorage Lease No.: A-029657 NO.: BRU 233-27 Section 27, Township 13 North, Range l0 West, Seward B & M LOCATION:' Surface: 1816' North and 2018' West from Southeast Corner of Section 27 (Projected). ELEVATION: 104' K.B. DATE: May 31, 1963 K.B. is. 15' above ground. C.. I~.-Ctt~T~R.TON, District up r~ (~: - · .DRILLED BY: Coastal Drilling Company, Rig ~3. DATE' COMMENCED DRILLING: February 23, 1963. DATE COMPLETED DRILLING: March .25, 1963. DATE' OF' INITIAL PRODUCTION:. None. Shut-in Gas Well. PLUGS :' 526o - 3o5' CASING:.. 36" cemented at 29'. · 16" Cemented at. BoB' · lO'3/4" cemented at. 24001' 7" cemented at 5305'J PERFORATING RECO~: 5- 4- ~" holes at ' ~" holes at "holes per foot ?' holes per foot ,[" holes at ~" holes per foot ?' holes per foot ~" holes per foot "holes at 3026 ' 3027 ' 4442 ' -~56 ' 4502' -45o9' 4518' 4664'-4674' 4906' -4917 ' 5211'-5222' 5224' ~age 2. (S~ueez~d) (Squeezed) (wso) (wso) 1. Schlumberger 2. Schlumberge~ 3- Schlumberger Schlumberger 5. Schlumberger 6. Schlumberger ~7. Schlumbergem 8. Schlumberger 9- Baroid Daily Induction - Electrical log Sonic log Microlog~Oallper Foxlzation - Density~ log Continuoms Dipmeter C~ment Bond log Neutron Collar log ~05 - 5680' 3o5 - 5677' 2402 - 568o' ~.4o2 - 568o' 2402 - 5680' 52 - 5252' 1500 - 5262' Casing Collar log and Perforating Record Mudlog , 300 - 5680' DRILL S~~S~: 5~' (wso) 491o'-~91~' 4518' (wso) 3026 ' (WNSO Squeezed) 3027 ' (WNSO Squeezed) co~P~o~ "~O~T BELUC~ RIVER UNIT ~e33-27 Section 27, T. 13 N., R. lO W.j=~e~ B.aM Spudded at 7: 30 AM. ~i~d l~ 3/4" hole to 305'. Opened hole to 20" tO LQ8', 70 pcf mud Opened hole to 20" to 30~'. ~an and cemented 16", 75~, J-55, 8R easing at ~O~' with 350 sacks cement around shoe. Casing detail: Above K.B. Cut and Recovered K.B. to top of Casing l0 Joints 16" 75~ J-55 8R Casing cemented at 4.50 21.50 17,O0' 286. oo 303'00' Installed BOPE and tested ,with 1500~ - OK. Located top of cement at Drilled out cement to 303' and drilled lB 3/4" hole to 317'. Baroid mudlo$~' unit commenced logging. February 26 ~ ~7.~11,~],.963 Drilled 14 3/4" hole to 2.137'. 76 - 79 pcf mud Drilled 14 3/4" hole to 2400'. Ran Schlumberger ,~nduetion - Electrical leg 305, - 2400' and Sonic log 305 - 2397'. R,~.n l0 3/4" casing. l~arch !,: 1.96B Ran and cemented 1~ 3/4" 51~, P-110 8R at 2400' with 1OOO sacks emme~ around shoe. Casing de~ail: Above K.B. 7.O1' 61 Joints 10 B/4" 51~ P-110 8R including shoe and float collar 2407.O1' Casing cemented at 2400.00' Removed BOPE ;.and lande~ casing. Tested Becon~ry packoff with ~ psi - O~. Reinstalled BOPE am~ l~ested with ~500 psi - 0~. ¢f~ulated and con~lomed mu~ Nareh 3 -_ 6,: 196_ 3 Drilled out cement an~ Shee an~ dried 9 5/8# hele o~o 5OOO'. , 76 - 78 pcf mu~ COMPLETION REPORT BELUGA ~VER U~T Section 27, T. 13 ~TANDA~ 0iL 'CoMPA~Y o~~~R~, ~STEPdl oPEmTI0~ '-iNc.~- ' OPEm~ March 7~ 1963 Circulated. Ran Induction - Electrical log 2402 - 4998' and Formation Demsity log 2402 - 4999'. Drilled 9 5/8" hole to 5056'. 77 pcf mud ~rch.8, 1963 Drilled 9 5/8" hole to 5608'. 77 - 79 pcf mud ~rgh~.9, 1963 Drilled 9 5/8" hole to 5680' T.D. Circulated and conditioned mud. Ran Forma., tion Density log 4900 ' 5682', Sonic log 2402 - 5677' and Microlog-Caliper 2402 - 5680'. Ran bit and conditioned hole to 5680'. Nm ~rc~ %0, 196~ Ban Continuous Dipmeter 2402 - 5676' and Induetiom - Electrical lo~ 2~Y~ - 5677'. Conditioned hole and ran 7" casing. .Narc.ch 11, 1963 Cemented 7" casing at 5305' with a total of 825 sacks cement. around shoe at 5305', 440 sacks through DV at 1500' through DV at 3785' (top). Casing detail: Above K.B. Cut and recovered K.B. to landing head 37 joints 7" 2~ P-110 LSR DV collar 19 Joints ?" 26~ P-110 LSR X - Over 37 joints 7" 26~ N-80 BT DV collar 3~ joints ?" 26~ ~o BT 2 ~oints 7" 26~ P-110 LSR Casing cemented at Used 285 sacks (top) and 100 sacks -2.71' 16.87 ' 16.87 ' 1483.~5' 1500.32' 2. O0 ' 1502. S2 ' 75~. 82 ' 2257.1~' 8.10 ' 2265.24' 1520.15' 3785.39' 2.00' 3787.39' 1437.94' 5225.33 ' . ,.79.67' 5305.00' '5305.0o' Removed BOPE and landed casing. Installed tubing head and tested Mith ]000 ~si - OK. ~rch 12,....1963 Reinstalled BOPE a~d tested with 2800 psi - OK. tested with 2900 psi - OK. March 13, 1963 Drilled out DV at 15C~' Drilled out DV at 3785' and teste~ with 290~ psi - OK. Drilled out cement 5223 - 5260'. Circulated and conditioned mud. Ran 'Cement Bond log ~2~- 52~2' and Neutron collar log 1500 - 5262'. Ran Schlumberger carrier gun and Jet perforated 5 -½'~ holes at 5224'. COMPLETION REPORT BELUGA RIVER UNIT ~233-27 Section 27, T. 13~N...~ R.. 10 W.~ Seward B & M STANDARD 'OIL cOMPANY OF CALIFORNIA, WESTERN OPERA~iON8,' Page 5'. '_ (ji~'F. RATOR March 14~ 196B Testing. HCT ~1, WSO - test at 5224'. Tool assembly: 2 outside BT recorders 8' of 2 7/8" perf'd tail pipe (3/16" perfs), 7" type"C" hookwall packer, VR safety joint, hydraulic jars, 2 inside BT recorders, hydrospring tester with ~ bean and dual closed in valve. Ran on 5168' of 3~" drill pipe. Used no water cushion. Set packer at 5192' with 21' of tail to 5213'. Opened tester at 3:44 AM for 4 mins. pressure release. Immediate moderate blow increasing to strong when shut-in. Shut - in tester at 3:48 AM for 36 mins. ISI pressure period. Opened tool to surface at $:24 AM for 3 hrs. ll mins. flow test. Shut in tool at 7:35 AM for 90 mins. FSI pressure. Pulled packer loose at 9:05 AM. Flared gas while bleeding down pressure during initial shut-in. Turned to flare immediately upon opening for flow test. Gas to surface immediately. Rat hole mud to surface at 4:30, put out flare. Mud continued for 4 minutes, then flares re-ignited. Turned to prover and obtained rates. Time 5:00 - 5:12, rate increased from 1577 to 2203 MCF/D; 5:15 AM stabilized rate of 3330 MCF/D; 5: 34 - 5: 50 stablilized rate of 3428 MCF/D; 6: 30 - 6:40 increasing rate 2291 to 2607 MCF/D; 6:50 - 7:15 increasing rate 3040 to 3298 MCF/D. Obtained gas sample at 7:25 AM at 250~. During flow period, after mud cleaned up, gas appeared clean. Burned with bright orange yellow flame, blue at the base. Recovered O' net rise. Pressure Data: De~th. ,C~. uge IH ISI IF ~ FSI,. FH Top inside 5174' 2853 2466 260 1236 2371 2789 Bottom inside 5178' 2857 2468 269 1245 2375 2793 Top outside 5205 ' 2871 2470 345 1816 2378 2812 Bottom outside 5209' 2876 2476 347 1778 2387 2817 Conclusion: WSO - OK. Set DM bridge plug at 5150' and tested with 2700 psi - OK. Ran Schlumberger carrier gun and jet perforated 4 - ½" holes per foot 4910 - 4912'. Marc,h. 15 & 16, 1963 Testing. HCT ~2, interval 4910 - 4912'. Tool assembly: as before. Ran on 4855' of 3~" IF drill pipe. Used no water cushion. Set packer at 4880' with 21' of tail to $901'. Opened tester at 2:38 AM for 4 rains, pressure release. Immediate strong blow of air, increasing, ..& turned to flare. Flare ignited 2:43 AM. Shut in tester at 2:42 AM for 38 rains. ISI pressure period. Opened tool to surface at 3:20 AM for 3 hrs. 35 rains, flow test. Shut in tool at 6:55 AM for 120 rains. FSI pressure. Pulled packer loose at 8:,55 AM. When opened, turned to flare and ignited same. Flowed to flare for i hr. to clean up. Turned to prover to obtain rates. COMP~TION RF~ORT BELUGA RIVER UNIT ~233-27 iSeCtion 27, T. 1~ N.~ ~R. 10 W,~ Seward B & M .STANDARD OiL d'OMi~ OF CALIFORNIA, WESTERN OPERATIONS, INC Time Plat___~e Coefficient Ternp . Pres s. 4: 25 3/4" .2'19.9 46° 700~ 4:40 Page 6. · - OPERATOR PROVER Tubing Surface Pressure Bean Flow Rate ~" 8984 MCF/D 700~ ~ 4:45 3/4" 219.9 23° 540~ 1350~ 3/8" 7179 MCF/D 5:00 5:05 1" 397.6 8° 320~ 1350~ 3/8" 7835 MCF/D 5:25 5:45 t~" 642.2 -1° 190~ 1350~ 3/8" 7931 MCF/D Flare burned with bright yellow flame with blue at base. No indication of water. Recovered O' net rise. Final Pressure Data: Depth Gauge IH ISI IF FF FSI FE Top inside 4862' 2684 2326 1238 1939 2307 2649 Bottom Inside 4866' 2678 2321 1273 1945 2300 2645 Top outside 4892' 2702 2326 1456 2043 2304 2668 Bottom outside 4896' 2704 2333 1462 2048 2314 2644 Conclusion: Test clean, no indication of moisture except for drilling fluid at start of flow test. Test conclusive. Set .a' Halliburton DM brige plug at 4800'. Shot 5 -½" holes at 4518'. HCT ~$, WSO.~%est at 4518-'. Tool assembly: as before. Ran on 4449' of 3½" IF drill pipe. Used no water cushion. Set packer at 4473' with 21' of tail to 4494'. Opened tester at ll:07 PM fer 6 mins. pressure release. Immediate faint blow of air and dead in 4 mins. Shut in tester at ll:13 PM for 31 mins. ISI pressure Period· Opened tool to surface at 11:44 PM for 60 mins. flow test· Shut in tool at 12:44 AM (3-16-63) for 33 rains. FSI pressure. Pulled packer loose at l:17 AM. Dead when opened for flow test. Dead throughout flow test. Recovered 30' net rise, all 77~ drilling fluid. Final Pressure Data: Depth Gauge IH ISI . IF FF FSI FH Top inside 4455' 2467 100 24 24 42 2467 Bottom inside 4459' 24?3 103 26 32 46 2473 Top outside 4486' 2488 ll3 40 40 58 2484 Bo~ttom outside 4490' 2487 ll8 40 44 60 2487 Conclusion: WSO - OK. COMPLETION REPORT BELUGA RIVER UNIT ~233-27 Page 7. Section 27, T. 13 N., R. lO~W., Seward B & M STANDARD OiL CC~PA~'~0F' C~L~IA, WES~ OPE~ATI~S,' INC. -'OPEPATOR Shot 5 ' ½" holes at 3026'. ECT ~4,.. WSO.test at 3026'. Tool assembly: as before. Ran on 2956' of 3½" IF drill pipe. Used no water cushion. Set packer at 2981' with 21' of tail to 3002. Opened tester at 2:17 PM for 3 rains. pressure release. Immediate moderate blow of air increasing to strong when shut-in. Indication of mud to surface through hose to bucket. Shut in tester at 2:20 PM for 33 rains. ISI pressure period. Opened tool to surface at 2:53 PM for 22 mins. flow test. Shut in tool at 3:15 PM for 25 rains. FSI pressure. Pulled packer loose at 3:~0 PM. Immediately turned to flare and burned. Muddy water to surface in 2 - 3 minutes and put out flare. Shut in to change surface bean from l" to ½" and strengthen line holddowns. When opened, gas and water to the surface and the flare burned intermittently being put out by the water. Closed in for final. Recovered 593' (6 1/3 stands) net rise, all gassy dirty fresh water with a small amount of fine sand. Small amount of fine - medium grained sand. 79~ mud hydrostatic at packer 1584~. Final Pressure Data: Depth Gauge I~.. ISI_ IF FF FSI... Top inside 2963' 1582 15lO 813 1351 1360 1570 Bottom inside 2967' 1582 1508 830 13~6 1361 1561 Top outside 2994' 1600 1513 926 1356 1364 1582 Bottom outside 2998' 1599 1512 914 1354 1363 1584 Conclusion: Charts indicate tool functioned properly. WNSO. Set a DM bridge plug at 3150'. _.March. 17, 1963 Set DM retainer 2834'. Broke down formation with 1400 psi and squeezed holes at 3026' with 300 sacks cement. Working pressure 800 psi. final pressure 3000 psi. Cement in place at 5:05 AM. Standing cemented. 77 pcf mud March .18, 1963 Circulated and conditioned mud. Drilled out retainer and cleaned out cement to 3069'. Pressure tested holes at 3026' with 2400 psi for 15 mins. OK. Shot 5 - ½" holes at 3027'. HCT ~5, WSO - test at 3027'. Tool assembly: as before. Ran on 2956' of 3½" IF drill pipe. Used no water cushion. Set packer at 2980' with 21' of tail to 300' at 8:01 PM. Opened tester at 8:09 PM for 3 mins. pressure release. Immediate moderate blow of air increasing to strong. Shut in tester at 8:12 PM for 37 rains. ISI pressure period. Gas to surface at 8:13 PM. Opened tool to surface at 8:49 PM for 53 rains, flow test. Shut in tool at 9:42 PM for 48 mins. FSI pressure. Pulled packer loose at ½,, 10:30 PM. Turned to flare, burned immediatel~60~ surface pressure, sur- face bean. Rat hole mud to surface 8:58 PM. Did not put out flare. Estimated gas rate .5 MMCF. Turned to prover at 9:18 PM. Large percentage of muddy gray colored fresh water. Obtained rate from 9:18 - 9:30 of 380 MCF/D. CORSPLETION REPORT Section 27~ T. l~. N.~ ,R. lO W.~ Seward B & M _ STANDARD 'OIL '~OMPANY ~F C~'LIFORNIA, WESS~RN OPERATIONS, INC. Page 8. . "dPERATO~ PROVER Tubing Surface Plate Coefficient Temp... Pr~S~. Pressure Bean Rat__~e !,', 25.28 38© 245 '230 3/8" 380 M/D Water kept putting flame out. Shut in at surface at 9:30 PM. Turned to flare at 9:37 PM. Large percentage of water kept putting flare out. Shut in. Recovered 1030' net~rise, top 1000'. Muddy fresh water with very fine grained to silty sand. Bottom 30' sand - very fine grained - silty. Tested 54 G/G salinity. Pressure Data: Depth Gauge I___~_H IS1,. , IF,, FF_ FSI .... FH. Top inside 2962' 1632 1302 197 891 1276 1635 Bottom inside 2966' 1643 1303 202 894 1276 1595 Top outside 2993' 1654 lB01 223 903 1273 1586 Bottom outside 2997' 1654 1303 212 908 1278 1608 Conclusion: Charts indicate tool open and functioned properly. WNSO. March 19,_ 1963_ Circulated. Set a DM retainer at 2836' and broke down formation with 1600 psi and squeezed holes at 3027' with 300 sacks cement. Working pressure 1000 psi, final pressure, 2500 psi. Cement in place at 11:55 AM. Standing cemented.. March 20~,, !96B Circulated and conditioned mud. Drilled out retainer and cleaned out cement to 3080'. pressure tested holes at BO26' and 3027' with 2500 psi. Pressure dropped to 1400 psi. Set D~ retainer at 2865' ~nd broke down formation with 2200 psi at a rate of 2 bbls./min. Resqueezed holes at 3026' and SO27' with 100 sack cement. Final pressure SO00 psi. Cement in place at 8:45 PM. Stand- ing cemented. March 21, 1963_ Standing cemented. Drilled out retainer and cleaned out cement to 2889'. March 22, 196~ Clemued out cement to 3075' and pressure tested holes at 3026' and 3027' with 2000 psi. Pressure dropped to 1600 psi. Pressure held at 1600 psi for 20 minutes. Cleaned out cement to 3150' · Drilled out bridge plug at 3150' ~ 4800' and 5150'. Ran 5260 and circulated. Ran Schlumberger carrier gun and shot 4 - ½" holes per foot using no-plug and crack jets 5222 - 5211'~ 4917 - 4912', 4910 - 4906', 4674 - 4664', 4509 - 4502' and 4~56 - 4442'. Ran bit and casing scraper to 5260'. and circulated. COMPLETION REPORT BELUC~ RIVER UNTT ~233-27 Section ~7, T. 13 N.~.. R. lO W.~ Seward B & ~ S~ O~ C~~ OF CALIFO~, ~S~ OP~TIONS~ Page 9. INC. - OPERATOR _March 23, 1963 Ran open ended drill pipe to 5260' and circulated. ran 2 3/8" tubing. TUBING DETAIL , , K.B. to landing head Landing head 67 joints 2 3/8". 4.7~, N-80~' 8R Rg2 with beveled collars 28 joints 2 3/8" 4.7~, N-80, 8R Rg2 Camco MM mandrel with CEV i joint 2 3/8", 4.7~, N-80 8R Rg2 Brown CC safety joint 2 3/8" pup joint Brown 2 3/8" X 7" HS-16-1 packer 2 joints 2 3/8", 4.7~ N-80 8R Rg2 2 3/8" Otis S nipple in pos. ~l 40 joints 2 3/8"~ 4.7~, N-80 8R Rg2 Brown expansion joint i joint 2 3/8", 4.7~, N-80 8R Rg2 Camco ~$~ mandrel with CEV in place I joint 2 3/8", 4.7~, N-80 8R Rg2 Brown CC safety joint 2 3/.8" pup Joint 2 3/8" X 2 crossover and collar Brown 2 7/8 X 7" HS-16-1 packer 2 7/8" X 2 3/8" crossover and collar 2 joints 2 3/8", 4.7~, N-80, 8R, Rg2 2 3/8" Camco D nipple 26 joints 2 3/8", 4.7~, N-80, 8R, Rg2 Venturi shoe Tubing landed at Laid down drill pipe and' K.,B. Depth,. 13.20 ' · 35' 13.55' 2057.63 ' 2071.18 ' 845.49' 2916.67' 13.20' 2929.87' 31.38' 2961.25 ' · 95' 2962.20' 10.10 ' 2972.30 ' 6.00' 2978.30' 60.87' 3039.17 ' 1.52 ' 3040.69 ' 1PR6.19' 4266.88' 3.79' 4270.67 ' 28.22 4298.89' 13.10' 4311.99' 29.38 ' 4341.37 ' · 94 ' 4342.31 ' 10.15' 4352.'46 ' 1.10 ' 4353.56' 6.00' 4359.56' 1.10' 4360.60 ' 59.00' 4419.66' · 92 ' 4420.58' 804.07' 5224.65' .58' 5225.23' 5225.23' HEATER STRING K.B. to landing head Landing head 64 joints 2 3/8", 4.7~, N-80 8R Rg2 with beveled collars Collar on bottom Tubing landed at 13.20 ' °35' 1984.63 ' .40' 9 8.58, March 24, 1963~ Landed tubing ~trings and removed BOPE. Installed x-mas tree and tested with 5000 psi - OK. Displaced mud with diesel oil and attempted to set packers. Setting plug stuck in tubing. Pumped setting tool loose with Ealliburton and retrieved setting plug and CEV valve. Reran CEV valve and seated same. C0~PLETION REPORT ~E~UGA RlVE~ U~ZT ~33-ZW Section ~7, T. l~ N., ,R. 10 W.~ Se~rd B & M ~mA~ O~ C0~~ OF C~0~, ~S~N O~~ONS, Page 10. INC, - OPERATOR Narch .25~ 1963 Set pakcers at 4353' and 2972' with 4500 psi. Flowed well two hours at estimated 7000 MCF/D rate through64/64" bean with 350 psi tubing pressure. Well not wet, but making some sand. Shut in tubing pressure 1980 psi. Open flow potential based on results from Formation Test on March 15, 1963 - 16,300 MCF/D. Rig released at 4:00 PM, 3-25-63 S. R. NANSEN SRE:pb COMPLETION REPORT BELUGA RIVER UNIT ~33-~7 SectiOn, ,27~ T' 1.,~. N-~ .R., lO w.~ Se.ward B & M STANDARD OIL COMP~ OF CALIFORNIA. WESTERN OPERATIONS. Page 11. "'~c. - oP~.~A~ Depth 300 ' 1140 ' 2395 ' 3000 ' 3590 ' 4205 ' 4-730' 5000 ' 5450' DEVIATION DATA Degrees_ 0%5 ' 0° 30 ' 0°30' 0° 30 ' lO00, 0° 30 ' 0o15 ' 0°15, 0045, 0°45' · lOo0, R~.lease Date ~ ~_.-25-65 _ State of Alaska Department of Natural Resources DIVISION OF MINES AND MINERALS Petroleum Branch Sec..J 27 :~ INDIVIDUAL WELL RECORD Issued 1-16-63 OperatorStan_dard Oil Go of Calif Location (Surface} 1816' FSL & 2018' FEL, Sec. 27 Lease No. A-029657 or Owner Bel.u~a River Unit: Loc. (Bottom) , : , ..... T. 13 N R. 10 W ~ Meridian Permit No. 63-2 Well No. 233_-27 ._ ......... Area Spud Date 2-23-63 Drilling ceased Suspended Abandoned Completed (F-~~ 3-25-63 ...... IP 3-25-63 B/D, Gray Total Depth 5680' 104' K..B. Elevation 89' .r-rd. API Cut_____% Gas.. 7 ~ 000 MCF/D, Bean 64 Casing: Size Depth Sx Cmt /64 CP .... psi, Perf: 4442 ' -4456,' TP ..... 35,0: psi Plugs ~ 5305 ' -.5260' 36" 29' 16" 303' 10 3/4" .2400' 7" 5305 ' 350 1000 285 @ shoe 440 DY @ 1500' i00' 'DV'@ 31~.,'.b; 4502'-4509' " '4664'-4674' 4906'-4917' 5211'-5224' Surface Lowest, Tested, , t .,__ 1, ~ . - -- -. - Name PRODUCTIVE HORIZONS Depth Contents ,, ~ ~.,... .~ ~ · Year Jan Feb Mar . .A~r WELL STATUS May~ June July Aug Sept Oct Nov Dec .' .~, .,T ~ : ~ ; 1963 1964 Shut in Remarks flow po_t~a~ial from March 15:1963 _t:es~, of 4910'-4)_~12 ' - 16.,30.0. MCF/D.- U N ['K Budget Bm~'6u ]qo. 4z--:~.~§;& -~' ApprOval expir~ 12-3~'4~0. , - ' OPERATIONS myer u~ UNITED STATES DE?ARTMENT OF THE INTERIOR GEOLOGICAL SuRvEy Budget ApDro¥1~[. ~.o omc~" :._Anoh. o?a.ge. .. LESSEE'$ MONTHLY REPORT OF OPERATIONS Stat c .....Alaska .... Co;tnty _. C°.ok. Inlet ......... ~ etd .._Beluga .RiYev Tile "~' ' ' , i'o,,~o~.c~,~,~ is a correct report of operafio~,s a,.d produ, c,~io-t~ (~'ncludl~g drilli,.~ and prodt~ct:~g ~i~c~,t's addrc:~.¥_ _ Po_Oo Box 7¢839 ............... Cot~pa~u; STA~O OIL G0....0F CALF, WOI .................................. ~ohgrage, .Alaska ...... Si2ncd , ' ' ~gC, 27 I)iYj~ion-~ 13N · '~¥ ELL P ........ , ]']"gRI~L"3 O' OIL I C} RAVITY' (In thottsr, nd~) (,A.OLIN. - ~g('OV Eli r: D ' BmUGA RI ~ UNiT 233-27 (h) ~Spudded F~bru~ 23, 1"632 ;Cemented ~6" ca~ng a~ 30~~ ~h 3 I BOPE and ~rSlle~ lh 3/h~ hole ~o 2 Cem,~nged 10 3~ i Sonic log j !sacks. } I Uo Ri~hfie;d -Co W. Ro R. Skell -! O.L. Odal, Files-Pr oduc i ~g Ex plora ;ion s.o.sL - .. H. ate -! T. R. Mar~' hall Perry Ri%ret - Attn p~ened ho~e to 16". ~O sacks [ Installed bOO'. Rsn I-ES and g at 240~' with 11OO :) Re Re R,,binson No~w,.--Therc were ....................................... runs or sales of oil; ............................................. M cu. ft. of gas sold; ............................................. runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--Report on this form is requ~ed for each calendar month, regardless of the status of operations, and must bo filed in duplicate with the supervisor by ~he 6th of the succeeding month, unlo~ otherwise directed by the supervisor. Form Form ~- ! D I 0SM ! 1/62 MEMORANDUM -...State of Alaska TO: F Jiae~ a,, ~1i~li~s DATE : 5U6J ECT: February 14, 1963 C~~ in Permit No. 63-2 7~nclosed is Application for ?ermi~ to D~_ill Well BRII 233-27. lhlmlkS ff.. MlrshsZ{., (Feb. (SUBMIT IN TRIPLICATE) UN i'TED STATES DEPARTMENT OF THE INTERIOR G£OLOG ICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS NOTICE OF INTENTION TO CJIAN6E PLANs..: .................... I ...... ~00ENT R~SORT OF ~40OTII~ ON ~CIDIZIN~ ..................... Il ~,cE OF ,.~,~ .o ~ .^~. ~~ .............. I ...... ~~ ~ ~ ~'~ ~ ....................... i I I ~TICE ~ I~~. TO ~1~ on R~AIR-~ ......... [ ......~QUENT n~ OF ~lm~ On ~AIR ............... [ ..... I ~ ~ mN~TS~ ~ ~T On ACSm~__.. ................ t ......~~ ~ ~ ~N~NT .......................... I ..... .................................................... ............... .__ _ ......................... g_,_~r~_.~ .......................... . ~ ~..~ BRU ~ ~ ~. ~4 ~. No.) ~.) (~e) (M~d~) ......... ~_~__~r~ ................................................................................ ~~. ................. (~!~) (~y or 8u~lv~) (8~ ~ ~) ~e elevation ~ the derric~'fl~r a~ve ~ level is _~.. E. DETAI~ OF WO~ IM ~nt,, ~ nil ot~ im~t ~ M) Dr~]_I te 300~ eeeaent 16" conductor and :[Git. all Cla~s III BOPE. 2. Dr~ll to ~m ~ oe~nt 10 3/4" ~i~ at ~24~~. 3. ~~ ~a ~ ~O~ ~d Test. 4. Dr~ ~e ~'. 5. ~nt 7" ~s~ at ~5~0' 6. I~t~ Ci~s ~ ~. 7. ~b~ ~O'a ~ perfora~ attract~ ~te~a. 8. Co. leto as a ~as ~. FEB Petroleum Branch Division of Mines and Minerals Aladccl Dept. of Haturai Resouroee I uncl4aq4and tlnat thl. plan o/wo.~ must reodve apptevsd in vrltin~ by ~ Caeolo~leai .eurvey before opaiqitions ma~ be eemmmauaed. Comply ..... .s_~____~__._..o_ ~___c__o_~L.o_?.=_.c_~_~.o_ ~_~,_._...~_..T._..~.__.o.~...~_..~.[..o. ~_s. L[.~.c.... ............. By 4~. V. CHATTERTON Title .D_.i.~.t__r__i..c_.t._..S_..uperintemdent - Alaak& GPO 914~74 (IPeb. l~i) B~md~et B~,,eim No. 42.,.R$Sl.4. Im Q.'m .4~q)rc~ed. (SUBMIT IN TRIPLICATE) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY U~t NOTICES AND REPORTS ON WELI~ NOTICE OF INTENTION TO NOTICE OF i~TION TO NOTICE OF INTENTION TO NOTICE OF INTENTION TO NOTICE OF INTENTION TO ~,KX)T NOTICE OF INTENTION TO PULL O~ (INDIC~TE Pi. AMS SHUT-OFF OR REPAIR WB.L ......... ;IDIZE~ .................. SUBSEQU~IT REPORT OF WATER SHUT-OFF ...... SUB~..QUENT REPORT OF SHOOTING OR SUBSEQUENT REPORT OF AJ.'TTLRING SUB~,EGUENT REPORT OF SI, IFII'U~MENTARY WElL HISTORY .... CH~CK MARK NATURE O4m' REI~:)~T, NOTICE. OR DATA) Well No. :2k~_:~ ..... is located ---~ Bee.-l~3 tk, o. No.) .......... ~~._~_v._e_.z.__ ............................ .____~._Y:. .......... ~:.~.-_K.. ......... llallle) (M,m. tdiM,) (Oounty or ! (St~t~ m' Te~itor~) The elevation of the derrick floor above sea level · . p,r ~ {kmt, tee 4~t,44 2-: ~lu 2~2-a7 Mt44 ].X BilO 233-~7 in It, FEB 11 1963 PetroJeum Branch 13~oo of N~ines and N~inerc~is Dept. of Natural ResourCe~ .... .................. ...................... !_ .... ; ..... .,~am.,~+ _ _ ~ .................. ~. _~_ _ . . S. .,~_ . . r.~. . .=. ~ . ..~ ,,. -/au ,,, ~-=~--~ ...... . ................................... : Title ~.,~ . PRODUCING DEPARTMENT TELEPHONE BR, 7--6201 C. V. CHATTERTON DISTRICT SUPERINTENDENT P. O. BOX 7-839 · ANCHORAGE · ALASKA February 6, 1963 Mr. T. R. Marshall Department of Natural Resources Division of Mines & Minerals (Petroleum Branch) P. O. Box 148 Anchorage~ Alaska BRU 24-2-27 11 lgSIt Petroleum Branch ~ of N~te~ and Mi~lqd~ AJq~a' Dept. of hlatu;'a~ k~ercal Dear Sir: On January 12, 1963, we made Application for Permit to Drill BRU 242,27. This Permit was granted January 16, 1963. We now plan to drill BRU 233-27 in lieu of BRU 242-27 as per our Application dated February l~ 1963 and request that our $50.00 Permit money be transferred to BRU 233-27. Very truly yours, -'"7 C. V. CHATTERTON ~APPLICATION' FO~' 'PERMIT' TO' DRILL, DEEPEN OR PLUG BACK JAN 16 1963 · ._~ APPI~IC.ATION .TO DRtLt~ ,~'-~. -DEI~PE,N [] PLUG BACK [] Petroleum Branch _ ~:.-;'~ ~.... ~_g..~_.- ,. ~' ...,. :~.. .: . NAME OF COMPANY OR OPERATOR DAT~ Division of Mines, and Minerah :~' " : ......... -' --:~ .............. ~ ...... ~ka De~. o~aturai Resourc Name .of le~se . ~' . [' J ~veli~ nUmb;~ ' ' ' J Elev~on (ground) ~ ell loc~tion · (~ive foot~e ~rom section lines) .Sectfon~townslfip~r~ or block ~ survey Noarest distanc01rom pr6p6sed location D!stanee from proBoso~oeatton to noaro~t ~rllllng, to property or lease line: completed or applied~r well on the s~me lease: . ' ' p x. date work wtli start ' ' complete8 i~ ~~o ~bls r~e~ot~: If le~se, pureh~se~ with on~ wells drille~, ~rom whom' Status of bond / Remarks: (If this is an application to producing zone and expected new work to be done, giving present CERTIFICATE: I, the d, state that I am (company), and that i a~ authorized by said company r~ision pared under my supe and direction and that the the best of my kno.~edge. Permit Number: Approval Date: Notice: Before n all information requested. Much unnecessary correspond- ence will thus be avoided. / /' / / / make th~ re~ort; ~d ~at this ~e~o~ was pre- the~e~ are true, correct and complete to ~0 '"-~ Alask~ and Gas Conservation Commission to Drill, Deepen or Plug Back Form No. P-1 Authorized by Order No. 1 Effective October 1, 1958 See Instruction on Reverse Side .of Form APPLICATION FOR PERMIT TO DRILL, DEEPEN OR PLUG BACK :,-~ ~.~ . :~ . ' APPLICATION T~O DRILL [~/i :. DEEPEN [] PLUG BACK [] DATE NAME OF State : '-;.;' ~" : --:-~:'/~, : --- D]~SCRIPTION' OF' W~I.~--AND LEASE Elevation (ground} Name of lease _. ......... ~ ~ (give footage_frm~_~lines) _ __ Seqtign--to~shi~.ra~, oi block & sur~ Field & reser~.oic~(!~_wildcat,; so, st~e:)-.-: . -. ~ ~ 7:.~ ~ · ;~.e~ty : -:' Distance in miles and direction from nearest town _or post office Nearest distance from proposed Iocation to property or lease line: feet Proposed depth'. Rotary or cable tOols Distance from proposed location to nearest drilling, completed or applied--for well on the same lease: Approx. date work will star~ feet Number of acres in lease: Number of weTls on lease, including this well. completed in or drilling to this reservoir:. If lease, purchased with one or more wells drilled, from whom purchased: Name' ~ Address Status of bond Remarks: (If'this is an application to deepen or p!ug back, briefly describe work to be done. givin~o~l~~"'*~--~,~*,** .... producing zone and expected new producing.~zone) FEB 11 CERTIFICATE: I, the undersigned, state that I am th~ ~'' o' the ~, ~'ii (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated therein are true, correct and complete to the best of my knowledge. Permit Number: Approval Date: Approved By: Notice: Before sending in this fei'm be sure thatydu"~iave give all information requested. Much unneeessar7 correspond- ence will thus be avoided. See l. nstruetion on Reverse Side of Form C. V. CHAI-]'£'R'~ ON Signature (~.. ~4~ ~~~ Alaska Oil and Gas Conservation Commission Application to Drill, Deepen or Plug Back Form No. P-1 Authorized by Order No. I Effective October 1, 1958 ($U~MIT IN TitlPLICATg) UNITED STATICS DEPARTMENT OF THE INTERIOR (~LrOLO~ ICAL SURVLry JAN 161968 Petroleum Branch SUNDRY NOTICES AND REPORTS ON WELL~ ~,~,.~o. o~ Mines Aiaska Dept. of N~.: .m- o,,,,,,-- ~o ~,,-,~,.,~r~--: ............. I ...... il'~"[~u'"' ~ o~ ~,,~,.. ~.. ...................... I ..... NOTICE OF 11~7.NTII~ TO PULL OR ALII3t CASII~ .............. l .....-II SUPlq. F. MENTARY WELL HISTORy .................................. -] ..... m-nc~ o~ ,.TmnO. To w..o. ~u, · I _11 ........................................................ -/-- ......... :1 ..... (INDh~.AT~ AIOVl[ BY ClM~CK WK NATURE OIr RI:I~O~T, NOTICe. O1~ OTHI~ D~TA) // 19.~I. located !~_?.__~.._ ft. from_. ],~ line and __~._. No..~t.~__-_!_T O~ cee. ma ~ No.) ~n.) ....................................... (County The elevation of the 1. Drill to ~M~ts eemamt 2. Drill to J2kO~' J. Iastall ~lams IV BOF~ and t k. Drill to t%eO0'. &o ?. gst. abltsk tigOns and I. Cemplete u a ga. .. E~ line of sec....IT. ]]&~ / / Alaska / ......... -(5~-~') ............ 7 / / floor above ~ level i~ _._ ft. / / / DI=.TAILS ~VORK imlN~tant NWO~NNNmd M) / and iz~tall Olu. III BO~. casing at ~;2J~O0'. / -/ Imm ~meeelmW IW dm ~y .... ./ / / / Title Dt )rintendent GPO 914974