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Home My WebLink About174-003Nolan 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: 7/23/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250723 Well API # PTD # Log Date Log Company AOGCC ESet # END 1-25A 50029217220100 197075 6/19/2025 HALLIBURTON T40691 KU 41-08 50133207170000 224005 6/30/2025 AK E-LINE T40692 MPU F-05 50029227620000 197074 7/1/2025 READ T40693 MPU J-02 50029220710000 190096 5/21/2025 YELLOWJACKET T40694 MPU R-106 50029238160000 225033 6/8/2025 HALLIBURTON T40695 MPU R-107 50029238190000 225049 7/11/2025 YELLOWJACKET T40696 ODSK-41 50703205850000 208147 6/13/2025 HALLIBURTON T40697 ODSN-02 50703206710000 213046 6/13/2025 HALLIBURTON T40698 ODSN-16 50703206200000 210053 6/14/2025 HALLIBURTON T40699 ODSN-17 50703206220000 210093 6/14/2025 HALLIBURTON T40700 ODSN-24 50703206620000 212178 6/15/2025 HALLIBURTON T40701 ODSN-28 50703206760000 213148 6/17/2025 HALLIBURTON T40702 ODSN-36 50703205610000 207182 6/12/2025 HALLIBURTON T40703 PBU 07-23C 50029216350300 225043 7/4/2025 HALLIBURTON T40704 PBU 14-18C 50029205510300 225040 6/25/2025 HALLIBURTON T40705 PBU 15-33C 50029224480300 216075 7/3/2025 HALLIBURTON T40706 PBU C-30A 50029217770100 208169 7/1/2025 HALLIBURTON T40707 PBU E-09C 50029204660300 209095 6/30/2025 HALLIBURTON T40708 PBU F-38B 50029220930300 225029 6/12/2025 HALLIBURTON T40709 PBU GNI-02A 50029228510100 206119 7/4/2025 HALLIBURTON T40710 PBU GNI-02A 50029228510100 206119 7/3/2025 HALLIBURTON T40710 PBU GNI-04 50029233670000 207117 6/27/2025 HALLIBURTON T40711 PBU GNI-04 50029233670000 207117 6/27/2025 HALLIBURTON T40711 PBU J-07C 50029202410300 225026 5/30/2025 HALLIBURTON T40712 PBU L-105 50029230750000 202058 6/24/2025 YELLOWJACKET T40713 PBU L-108 50029230900000 202109 6/23/2025 YELLOWJACKET T40714 PBU NK-25 50029227600000 197068 6/5/2025 YELLOWJACKET T40715 PBU P2-06 50029223880000 193103 6/19/2025 HALLIBURTON T40716 PBU S-104 50029229880000 200196 6/21/2025 YELLOWJACKET T40717 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.28 09:54:00 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PCU-05 50283202030000 225037 7/3/2025 YELLOWJACKET T40718 TBU D-08RD 50733201070100 174003 6/4/2025 READ T40719 Please include current contact information if different from above. T40719TBU D-08RD 50733201070100 174003 6/4/2025 READ Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.28 09:53:40 -08'00' From:Rixse, Melvin G (OGC) To:Casey Morse Cc:Juanita Lovett Subject:20250715 1642 APPROVAL D-08RD PTD 174-003 Questions Date:Tuesday, July 15, 2025 4:43:27 PM Casey, Revised changes described in correspondence (July 11, 2025 15:20) immediately below is approved. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Friday, July 11, 2025 3:20 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com> Subject: RE: [EXTERNAL] D-08RD PTD 174-003 Questions Mel, In the sundry procedure under the section “Wireline Procedure” we would replace that section with the following steps: 1. RU and PT lubricator to 250psi low / 2500psi high 2. Set plug in 3-1/2” tubing below the deepest gas lift mandrel (~11,000’) 3. RU test pump and pressure test lines to 1500 psi 4. Fill well with FIW and perform CMIT to 1500 psi 5. Retrieve plug with wireline 6. Set tubing patch across identified hole in the 4-1/2” tubing (approximately 420 – 430’ per previous diagnostics) 7. RD wireline and turn well over to production for flow test CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 8. Once fluid level in the annulus is drawn down below the patch depth, utilize gas lift pressures and fluid level analysis to diagnose patch integrity Thank you, Casey Morse Operations Engineer Cook Inlet Offshore Hilcorp Alaska, LLC (907) 777-8322 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, July 11, 2025 1:43 PM To: Casey Morse <Casey.Morse@hilcorp.com> Subject: RE: [EXTERNAL] D-08RD PTD 174-003 Questions Casey, Send me a revised procedure and I will append it to the submitted sundry then I should be able to approve. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Thursday, July 10, 2025 1:26 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com> CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Subject: RE: [EXTERNAL] D-08RD PTD 174-003 Questions Mel, The most recent pressure test record I can find is from April of 2000 when the scab liner was run. Since we have live gas lift valves in the well, we could set a plug in the tubing and perform a combo MIT to check the casing and packer integrity before setting the tubing patch. Casey From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Thursday, July 10, 2025 12:19 PM To: Casey Morse <Casey.Morse@hilcorp.com> Cc: Juanita Lovett <jlovett@hilcorp.com> Subject: RE: [EXTERNAL] D-08RD PTD 174-003 Questions Casey, When was the last test of the IC to MASP or maximum gas lift header pressure? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Thursday, July 10, 2025 10:26 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com> Subject: RE: [EXTERNAL] D-08RD PTD 174-003 Questions 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. Good morning, Mel. I have a change to propose to the tubing patch procedure for this well. My initial plan was to run a permanent patch on eline that would give 2.992” ID and allow us to set and pull a plug from the 3-1/2” tubing. That would enable the pressure test that I included in the procedure. I realize now that the 2.992” ID of the permanent eline patch would prevent us from running a 4- 1/2” kick-over tool and swapping any of the 4-1/2” gas lift valves down the road. Alternatively, we could set a retrievable patch on slickline with a smaller ID (2.25” minimum ID). This would prevent us from setting and pulling a plug from the 3-1/2” tubing, so we would not be able to pressure test the tubing as I described in the sundry. Our best option is to perform a drawdown test on the IA to confirm the patch integrity. Could we change the procedure to proceed with this alternative patch option? Thank you, Casey Morse Operations Engineer Cook Inlet Offshore Hilcorp Alaska, LLC (907) 777-8322 From: Casey Morse <casey.morse@hilcorp.com> Sent: Friday, May 16, 2025 11:57 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] D-08RD PTD 174-003 Questions Mel, We were getting steady leak rates down tubing until setting the holefinder tool at 430’. The operators said the flow reduced when they set the plug at 430’. Then the tubing held pressure with the plug at 420’. Likely, the damage is between ~420-430’. The leak rate was substantial (~1 bpm). With that high of a leak rate up near surface, we probably wouldn’t see any small leaks deeper in the tubing. We are planning to run a caliper before any patch operations to pinpoint the damage spot and hopefully confirm the tubing integrity down deep before we run the patch. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. The plan is to set the plug right around 11,040’ (packer depth) in the 3-1/2”. Then, we will pull that plug before turning the well over to test production. Thanks, Casey Morse Operations Engineer Cook Inlet Offshore Hilcorp Alaska, LLC (907) 777-8322 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, May 16, 2025 10:52 AM To: Casey Morse <casey.morse@hilcorp.com> Subject: [EXTERNAL] D-08RD PTD 174-003 Questions Casey, A couple questions: 1. Is the hole in the 4-1/2” at ~420’ MD? 2. Where will you set the plug in the 3-1/2”? 3. Will you pull the plug for the flow test? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 12,398 N/A Casing Collapse Structural Conductor Surface 1,540psi Production 3,090psi Liner 7,020psi Liner 7,250psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Casey Morse Contact Email:Casey.Morse@hilcorp.com Contact Phone:(907) 777-8322 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng McArthur River Hemlock Oil & Middle Kenai G Oil Same 10,149 12,008 9,792 1,785psi N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 8,290psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018729 174-003 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20107-01-00 Hilcorp Alaska, LLC Trading Bay Unit D-08RD Length Size Proposed Pools: L-80 & N-80 TVD Burst 7,787 & 11,110 8,160psi MD 5,750psi 3,090psi2,371' 6,760' 2,532' 10,137'7" 13-3/8" 9-5/8"8,733' 2,532' Perforation Depth MD (ft): 8,733' 11,193 - 12,060 3,817' 5" 9,003 - 9,841 CO 228A Other: CTCO, N2, Patch 5/26/2025 12,041'499' 4-1/2" & 3-1/2" 9,823' See schematic See schematic 12,385' No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:57 pm, May 12, 2025 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.05.12 14:15:13 - 08'00' Dan Marlowe (1267) 325-296 * Service coil BOPE test to 2500 psi. 48 hour notice. * Assure review of Hilcorp Nitrogen Operations - Standard Well Procedure prior to N2 clean out 10-404 MGR16MAY25 Perforate 17 SFD 5/16/2025 DSR-6/3/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.04 08:53:34 -08'00' 06/04/25 RBDMS JSB 060525 Coil Cleanout Well: Dolly Varden D-08RD Well Name:D-08RD API Number:50-733-20107-01-00 Current Status:Shut in Oil Producer Leg:B-1 (SE) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:174-003 First Call Engineer:Casey Morse (603) 205-3780 (c) Second Call Engineer:Eric Dickerman (907) 564-4061 (o) Maximum Expected BHP: 3,046 psi @ 9,250’ TVD Max from offset D-12 shut-in Max. Potential Surface Pressure: 1,785 psi Using 0.1 psi/ft Brief Well Summary Dolly Varden D-08RD is a commingled Hemlock and Middle Kenai G oil producer. It was sidetracked from the D-08 in 1974 and originally completed in the Hemlock benches 1-5. Middle Kenai G perfs in benches 2-4 were added in 2000. The well has been shut in since 2018 with only short intermittent flow events since then. Slickline tags show debris accumulated into the G zone perfs. The goal of this project is to clean out scale and debris and return the well to production. Pertinent wellbore information: - Inclination: o ~45 degree sail angle from ~2400 – 8900’ with a max inclination of 49 degrees - Pertinent History o Slickline May-2025: RIH w/ 3-1/2 D&D holefinder to 11,035’. Set, test – fail. Set 10 more times moving up to 7,800’ – all fails. RIH w/ 4-1/2 D&D holefinder to 7700’ – fail. Set 13 more times up to 430’ – all fail. Set @ 230’ – good test. Set @ 420’ – good test. Suspected hole in tubing between 420-430’. Mar-2025: 2.79” GR tag 11,305’ o Apr-2000: Workover to isolate Hemlock Run test packer to 11,100’ and fail. ID bad casing up to 8,827’ Run 500’ of 5” liner from 12,008’ and cement liner to isolate Hemlock Set 7” packer at 11,040’ for gas lift completion Run 5-1/2” x 7” scab liner with packers at 7832’ and 9,182’ to straddle across leaking liner top Run 3-1/2” x 4-1/2” gas lift completion Pressure test casing to 1500 psi on 4/26/00 – good Perf G2, G3, and G4 (11,193 – 11,342’) o May-2000: CT cleanout and Perf add RIH w/ 2.75” mill and dry tag @ 11,835’. Wash down to 12,033’. Perf the H1, H3, and H4 (11,655 – 12,003’) - Pool Depths: o Top of Middle Kenai G Oil Pool:11081’ MD / 8894’ TVD Coil Cleanout Well: Dolly Varden D-08RD o Base of Middle Kenai “G” Oil Pool & Top Hemlock Oil Pool:11650’ MD / 9448’ TVD o Base of Hemlock Oil Pool:12296’ MD / 10057’ Wireline Procedure 1. RU and PT lubricator to 250psi low / 2500psi high 2. Set plug in 3-1/2” tubing 3. Set tubing patch across identified hole in the 4-1/2” tubing 4. Pressure test tubing to 2250 psi 5. RD wireline and turn well over to production for flow test Coiled Tubing FCO Procedure 1. MIRU Coiled Tubing and pressure control equipment 2. PT lubricator to 250psi low / 2500psi high 3. MU FCO BHA 4. RIH and cleanout to PBTD ±12,000’ or as deep as practical a. Working fluid will be filtered inlet water b. Take returns to surface up the CT x tubing / CT x casing annulus c. Add gas lift to assist with hole cleaning, taking returns to production d. May also utilize foam and nitrogen as necessary to carry solids to surface 5. Stand back CT and flow test well Contingent EL Re-Perf Procedure 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 3500psi high a. 0.45psi/ft * deepest potential perf add at 9841’ TVD = 4,428psi b. 4428 – (9841’ TVD * 0.1psi/ft gas gradient) = 3445psi 3. RIH and perforate Middle Kenai “G” Pool and Hemlock Pool sands from ±11,081 - ±12,060’ MD (±8,894’ - ±9,841’ TVD) per Engineer’s perf table. 4. RDMO EL Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. CT BOP Drawing (Fox Energy) 4. Nitrogen Procedure , pull plug set at ~11,040' MD. - per Casey Morse email. - mgr Per Casey Morse email 5/16/2025 11:57 : ~11,040' MD (packer depth) - mgr Tubing hole ~ 420' - 430' MD - mgr Casey Morse email 5-16-2025 11:57 am Mel, We were getting steady leak rates down tubing until setting the holefinder tool at 430’. The operators said the flow reduced when they set the plug at 430’. Then the tubing held pressure with the plug at 420’. Likely, the damage is between ~420-430’. The leak rate was substantial (~1 bpm). With that high of a leak rate up near surface, we probably wouldn’t see any small leaks deeper in the tubing. We are planning to run a caliper before any patch operations to pinpoint the damage spot and hopefully confirm the tubing integrity down deep before we run the patch. The plan is to set the plug right around 11,040’ (packer depth) in the 3-1/2”. Then, we will pull that plug before turning the well over to test production. Thanks, Casey Morse Operations Engineer Cook Inlet Offshore Hilcorp Alaska, LLC (907) 777-8322 Updated: 12/03/15 by JLL Schematic McArthur River Field, TBU Dolly Varden Platform Well: D-08RD Completed: 6/2000 PBTD = 12008’ TD = 12398’ MAX HOLE ANGLE = 49q Tree connection: 4 -1/16” 5,000# H-1 H-2 H-3 H-4 H-5 1 3 4 5 6 7 2 12-16 9 8 A B C F DE G10 11 G-2 G-3 G-4 17 A-1 A-2 18 19 X 03/28/25: 2.79” G R tagged up at 11305’. CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8” 61.0 J-55 Butt. LT&C 12.515 Surf 2,532’ 9-5/8” 40,43.5,47 N-80 Butt DV collar 8.681 Surf 5517’ 8,733’ 5519’ 7” 29 N-80 LT&C 6.184 8568’ 12385’ 5” 15 L-80 Buttress 4.408 11542’ 12041’ Tubing: 4-1/2” 12.6 L-80 Butt 3.958 Surf 7,787’ 3-1/2” 9.20 N-80 Butt 2.992 7,787’ 11,110’ JEWELRY DETAIL NO.Depth ID OD Item 41.00’ 4-1/2” Cameron Type DCB Sealock x Sealock Tbg Hngr 1 337’ 3.813 6.125 SSSV, Baker (3.813” I.D.) 2 2,456’ 3.883 7.063 GLM, 4-1/2”, Camco MMG, 1-1/2” R-2 Valve RK Latch 3 3,983’ 3.883 7.063 GLM, 4-1/2” Camco MMG, 1-1/2” R-2 Valve RK Latch 4 5,258’ 3.883 7.063 GLM, 4-1/2” Camco MMG, 1-1/2” R-2 Valve RK Latch 5 6,195’ 3.883 7.063 GLM, 4-1/2” Camco MMG, 1-1/2” R-2 Valve RK Latch 6 6,969’ 3.883 7.063 GLM, 4-1/2” Camco MMG, 1-1/2” R-2 Valve RK Latch 7 7,783’ 3.883 7.063 GLM, 4-1/2” Camco MMG, 1-1/2” R-2 Valve RK Latch 8 7,830’ 3.000 7.625 Fluted Locator, 7.5” O.D. 9 8,528’ 2.867 5.968 GLM, 3-1/2” McMurry Macco, SFO-2, R-2, RK Latch Above 7” x 5-1/2” xover 10 9,197’ 3.000 4.000 Locator, Seal Assy, 6.89’ Long (top seal 1.95’ from top) Upper Scab Liner Assembly A 7,832’ 6.000 8.218 Packer, 9-5/8” Baker Mod. F (DP set) RA tag @ 7833.83 B 8,555’ 8,556’ 4.950 4.550 5.500 6.070 Xover, 5-1/2” Buttress box x 7” buttress box and 5-1/2” buttress pin by 5-1/2” 15.5# Hydril 511 Pin C 9,172’ 4.360 5.600 Seal assembly, 5” Located in 7’ Upper PBR D 9,182’ 4.000 5.540 Anchor, Baker Mod. E-22 E 9,182’ 4.000 5.813 Packer, 7” x 4”, Baker Mod. “FA” , 4” x 4.75” step down RA tag at 9184.92’ F 9,186’ 4.375 5.000 Millout Extension, 10.1’ Long w/ 8 ea. 1” Holes @ top G 9,196’ 4.000 5.000 Lower Seal Bore Extension, 13.84’ Long 11 9,210’ 2.992 5.570 Xover, 5” LTC Box x x 3-12” 8rd x 3-1/2” Buttress Pin 12 9,260’ 2.867 5.968 GLM, 3-1/2” McMurry Macco, SFO-2, R-2, RK Latch 13 9,748’ 2.867 5.968 GLM, 3-1/2” McMurry Macco, SFO-2, R-2, RK Latch 14 10,174’ 2.867 5.968 GLM, 3-1/2” McMurry Macco, SFO-2, R-2, RK Latch 15 10,571’ 2.867 5.968 GLM, 3-1/2” McMurry Macco, SFO-2, R-2, RK Latch 16 11,000’ 2.867 5.968 GLM, 3-1/2” McMurry Macco, SFO-2, R-2, RK Latch One joint above packer 17 11,039’ 3.000 4.000 Locator, Seal Assembly, 6.5’ long 18 11,078’2.813 3.880 Otis, ‘X’ Nipple, 2.813 19 11,110’ 3.000 3.875 Wireline Entry Guide A-1 11,040’ 4.000 5.870 Packer, 7”, Baker Mod.”F-1” (DP set) A-2 11,043’ 4.000 5.870 Seal Bore Extension, 3.75’ long, bottom @ 11047’ Hole in casing 8827’- 8857’ Perforation Data Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Comments G-2 11,193' 11,199' 9,003' 9,009' 5/7/00 @ 6 spf G-3 11,251' 11,283' 9,060' 9,091' 4/28/00 @ 6 spf, 5/7/00 @ 6 spf G-4 11,317' 11,323' 9,124' 9,130' 5/5/00 @ 6 spf G-4 11,329' 11,342' 9,136' 9,149' 5/3/00 @ 6 spf HB-1 11,655' 11,665' 9,453' 9,463' 6/11/00 @ 6 spf HB-2 11,688' 11,775' 9,485' 9,570' Covered with 5” liner and cemented, 4/22/00 HB-3 11,785' 11,802' 9,580' 9,596' 6/5/00, 6 spf HB-3,4 11,835' 11,842' 9,628' 9,634' 6/5/00, 6spf HB-4 11,920' 11,940' 9,709' 9,728' 6/4/00, 6 spf HB-4 11,993' 12,003' 9,778' 9,788' 6/4/00, 6spf HB-5 12,030' 12,060' 9,813' 9,841' Covered by fill TOL @ 11533’ elm = 11542’ dpm = 11565’ wlm on 5/1/00 Updated: 5/10/25 by CDM Proposed Schematic McArthur River Field, TBU Dolly Varden Platform Well: D-08RD Completed: 6/2000 PBTD = 12008’ TD = 12398’ MAX HOLE ANGLE = 49q Tree connection: 4-1/16” 5,000# H-1 H-2 H-3 H-4 H-5 1 3 4 5 6 7 2 12-16 9 8 A B C F DE G10 11 G-2 G-3 G-4 1-A 17 A-1 A-2 18 19 X CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8” 61.0 J-55 Butt. LT&C 12.515 Surf 2,532’ 9-5/8” 40,43.5,47 N-80 Butt DV collar 8.681 Surf 5517’ 8,733’ 5519’ 7” 29 N-80 LT&C 6.184 8568’ 12385’ 5” 15 L-80 Buttress 4.408 11542’ 12041’ Tubing: 4-1/2” 12.6 L-80 Butt 3.958 Surf 7,787’ 3-1/2” 9.20 N-80 Butt 2.992 7,787’ 11,110’ JEWELRY DETAIL NO.Depth ID OD Item 41.00’ 4-1/2” Cameron Type DCB Sealock x Sealock Tbg Hngr 1 337’ 3.813 6.125 SSSV, Baker (3.813” I.D.) 1-A ±420 Tubing Patch 2 2,456’ 3.883 7.063 GLM, 4-1/2”, Camco MMG, 1-1/2” R-2 Valve RK Latch 3 3,983’ 3.883 7.063 GLM, 4-1/2” Camco MMG, 1-1/2” R-2 Valve RK Latch 4 5,258’ 3.883 7.063 GLM, 4-1/2” Camco MMG, 1-1/2” R-2 Valve RK Latch 5 6,195’ 3.883 7.063 GLM, 4-1/2” Camco MMG, 1-1/2” R-2 Valve RK Latch 6 6,969’ 3.883 7.063 GLM, 4-1/2” Camco MMG, 1-1/2” R-2 Valve RK Latch 7 7,783’ 3.883 7.063 GLM, 4-1/2” Camco MMG, 1-1/2” R-2 Valve RK Latch 8 7,830’ 3.000 7.625 Fluted Locator, 7.5” O.D. 9 8,528’ 2.867 5.968 GLM, 3-1/2” McMurry Macco, SFO-2, R-2, RK Latch Above 7” x 5-1/2” xover 10 9,197’ 3.000 4.000 Locator, Seal Assy, 6.89’ Long (top seal 1.95’ from top) Upper Scab Liner Assembly A 7,832’ 6.000 8.218 Packer, 9-5/8” Baker Mod. F (DP set) RA tag @ 7833.83 B 8,555’ 8,556’ 4.950 4.550 5.500 6.070 Xover, 5-1/2” Buttress box x 7” buttress box and 5-1/2” buttress pin by 5-1/2” 15.5# Hydril 511 Pin C 9,172’ 4.360 5.600 Seal assembly, 5” Located in 7’ Upper PBR D 9,182’ 4.000 5.540 Anchor, Baker Mod. E-22 E 9,182’ 4.000 5.813 Packer, 7” x 4”, Baker Mod. “FA” , 4” x 4.75” step down RA tag at 9184.92’ F 9,186’ 4.375 5.000 Millout Extension, 10.1’ Long w/ 8 ea. 1” Holes @ top G 9,196’ 4.000 5.000 Lower Seal Bore Extension, 13.84’ Long 11 9,210’ 2.992 5.570 Xover, 5” LTC Box x x 3-12” 8rd x 3-1/2” Buttress Pin 12 9,260’ 2.867 5.968 GLM, 3-1/2” McMurry Macco, SFO-2, R-2, RK Latch 13 9,748’ 2.867 5.968 GLM, 3-1/2” McMurry Macco, SFO-2, R-2, RK Latch 14 10,174’ 2.867 5.968 GLM, 3-1/2” McMurry Macco, SFO-2, R-2, RK Latch 15 10,571’ 2.867 5.968 GLM, 3-1/2” McMurry Macco, SFO-2, R-2, RK Latch 16 11,000’ 2.867 5.968 GLM, 3-1/2” McMurry Macco, SFO-2, R-2, RK Latch One joint above packer 17 11,039’ 3.000 4.000 Locator, Seal Assembly, 6.5’ long 18 11,078’2.813 3.880 Otis, ‘X’ Nipple, 2.813 19 11,110’ 3.000 3.875 Wireline Entry Guide A-1 11,040’ 4.000 5.870 Packer, 7”, Baker Mod.”F-1” (DP set) A-2 11,043’ 4.000 5.870 Seal Bore Extension, 3.75’ long, bottom @ 11047’ Hole in casing 8827’- 8857’ Perforation Data Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Comments G-2 11,193' 11,199' 9,003' 9,009' 5/7/00 @ 6 spf G-3 11,251' 11,283' 9,060' 9,091' 4/28/00 @ 6 spf, 5/7/00 @ 6 spf G-4 11,317' 11,323' 9,124' 9,130' 5/5/00 @ 6 spf G-4 11,329' 11,342' 9,136' 9,149' 5/3/00 @ 6 spf HB-1 11,655' 11,665' 9,453' 9,463' 6/11/00 @ 6 spf HB-2 11,688' 11,775' 9,485' 9,570' Covered with 5” liner and cemented, 4/22/00 HB-3 11,785' 11,802' 9,580' 9,596' 6/5/00, 6 spf HB-3,4 11,835' 11,842' 9,628' 9,634' 6/5/00, 6spf HB-4 11,920' 11,940' 9,709' 9,728' 6/4/00, 6 spf HB-4 11,993' 12,003' 9,778' 9,788' 6/4/00, 6spf HB-5 12,030' 12,060' 9,813' 9,841' Covered by fill TOL @ 11533’ elm = 11542’ dpm = 11565’ wlm on 5/1/00 KLU A-1 Well Head Rig Up 1 1 1 1 4 1/16" 15K Lubricator - 10 ft 100" Gooseneck HR680 Injector Head 4 1/16" 10K Flow Cross, 2" 1502 10k Flanged Valves 4 1/16" 15K Lubricator - 10 ft API Flange Adapter 10K to 5K for riser/wellhead Hydraulic Stripper 4 1/6" 15K API Bowen CB56 15K 4 1/16" 10K Combi BOPs Blind/Shear Ram Pipe/Slip Ram 4 1/16" 10K bottom flange 4 1/16" 5K flanged Riser - 10 ft if necessary STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20250516 1157 Response to current well conditions Date:Friday, May 16, 2025 4:14:29 PM From: Casey Morse <casey.morse@hilcorp.com> Sent: Friday, May 16, 2025 11:57 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] D-08RD PTD 174-003 Questions Mel, We were getting steady leak rates down tubing until setting the holefinder tool at 430’. The operators said the flow reduced when they set the plug at 430’. Then the tubing held pressure with the plug at 420’. Likely, the damage is between ~420-430’. The leak rate was substantial (~1 bpm). With that high of a leak rate up near surface, we probably wouldn’t see any small leaks deeper in the tubing. We are planning to run a caliper before any patch operations to pinpoint the damage spot and hopefully confirm the tubing integrity down deep before we run the patch. The plan is to set the plug right around 11,040’ (packer depth) in the 3-1/2”. Then, we will pull that plug before turning the well over to test production. Thanks, Casey Morse Operations Engineer Cook Inlet Offshore Hilcorp Alaska, LLC (907) 777-8322 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, May 16, 2025 10:52 AM To: Casey Morse <casey.morse@hilcorp.com> Subject: [EXTERNAL] D-08RD PTD 174-003 Questions CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Casey, A couple questions: 1. Is the hole in the 4-1/2” at ~420’ MD? 2. Where will you set the plug in the 3-1/2”? 3. Will you pull the plug for the flow test? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward 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. STATE OF ALASKA AIL OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp WeIG Other: Unable to Perforate❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 174-003 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20107-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018729 Trading Bay Unit D-08RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools 11.Present Well Condition Summary: Total Depth measured 12,398 feet Plugs measured N/A RECEIVED true vertical 10,149 feet Junk measured N/A feet DEC 0 8 2015 Effective Depth measured 12,032 feet Packer measured 7,832;9,182;11,040 feet �y true vertical 9,814 feet true vertical 6,138;7,103;8,854 feet G yy_C Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,532' 13-3/8" 2,532' 2,371' 3,090 psi 1,540 psi Production 8,733' 9-5/8" 8,733' 6,760' 5,750 psi 3,090 psi Liner 3,817' 7" 12,385' 10,137' 8,160 psi 7,020 psi Liner 499' 5" 12,041' 9,823' 8,290 psi 7,250 psi Perforation depth Measured depth 11,193-12,060 feet True Vertical depth 9,003-9,841 feetANO ] F 7 4-1/2" 12.6#/L-80 7,787'(MD) 6,108'(TVD) Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/N-80 11,110'(MD) 8,922'(TVD) Baker Model F Pkr 7,832'(MD)6,138'(TVD) Packers and SSSV(type,measured and true vertical depth) Baker Model FA Pkr 9,182'(MD)7,103'(ND) Baker Model F-1 Pkr 11,040'(MD)8,854'(ND) Baker SSV 337'(MD)337'(ND) 12.Stimulation or cement squeeze summary: 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: 5 30 21 1156 130 Subsequent to operation: 1 71 23 1234 132 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development Cl Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-614 Contact Dan Marlowe(907)283-1329 Email dmarloweOhilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature L_Jc-+ cL t,t Phone (907)777-8356 Date 1 8 ( Its iz-l5 -15 t' a5 Form 10-404 Revised 5/2015 "l„ / ,c RBDM 4`-� 1 1 2 15 Submit Original Only • • McArthur River Field,TBU Schematic Dolly Varden Platform Well: D-08RD Hilcorp Alaska,LLC Completed: 6/2000 CASING AND TUBING DETAIL Tree connection:4-1/16"5,000# SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61.0 1-55 Butt.LT&C 12.515 Surf 2,532' 1 1] 9-5/8" 40,43.5,47 N-80 Butt 8.681 Surf 8,733' 1 DV collar 5517' 5519' 7" 29 N-80 LT&C 6.184 8568' 12385' 2 5" 15 L-80 Buttress 4.408 11542' 12041' _./Illi Tubing: 3 4-1/2" 12.6 L-80 Butt 3.958 Surf 7,787' 3-1/2" 9.20 N-80 Butt 2.992 7,787' 11,110' 4 JEWELRY DETAIL 1 5 NO. Depth ID OD Item 6 41.00' 4-1/2"Cameron Type DCB Sealock x Sealock Tbg Hngr 4 7 1337' 3.813 6.125 SSSV,Baker(3.813"I.D.) 8 2 2,456' 3.883 7.063 GLM,4-1/2",Camco MMG,1-1/2"R-2 Valve RK Latch A 3 3,983' 3.883 7.063 GLM,4-1/2"Camco MMG,1-1/2"R-2 Valve RK Latch 4 5,258' 3.883 7.063 GLM,4-1/2"Camco MMG,1-1/2"R-2 Valve RK Latch 9 5 6,195' 3.883 7.063 GLM,4-1/2"Camco MMG,1-1/2"R-2 Valve RK Latch B 6 6,969' 3.883 7.063 GLM,4-1/2"Camco MMG,1-1/2"R-2 Valve RK Latch ><I 7 7,783' 3.883 7.063 GLM,4-1/2"Camco MMG,1-1/2"R-2 Valve RK Latch L , 8 7,830' 3.000 7.625 Fluted Locator,7.5"O.D. C 9 8,528' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch IL ..; D Above 7"x 5-1/2"xover E c o -. F 10 9,197' 3.000 4.000 Locator,Seal Assy,6.89'Long(top seal 1.95'from top) 10 = G Hole in Upper Scab Liner Assembly 1 1 casing A 7,832' 6.000 8.218 Packer,9-5/8"Baker Mod.F(DP set) mor 8827'- RA tag @ 7833.83 12-16 s, 8857' B 8,555' 4.950 5.500 Xover,5-1/2"Buttress box x 7"buttress box and 8,556' 4.550 6.070 5-1/2"buttress pin by 5-1/2"15.5#Hydril 511 Pin IIMIMI 17 >t). C 9,172' 4.360 5.600 Seal assembly,5" Located in 7'Upper PBR �X q_1 D 9,182' 4.000 5.540 Anchor,Baker Mod.E-22 1111 < \ A-2 E 9,182' 4.000 5.813 Packer,7" x 4",Baker Mod."FA", 4"x 4.75"step down 18 RA tag at 9184.92' x F 9,186' 4.375 5.000 Millout Extension,10.1'Long w/8 ea.1"Holes @ top 19 G 9,196' 4.000 5.000 Lower Seal Bore Extension,13.84'Long 11 9,210' 2.992 5.570 Xover,5"LTC Box x x 3-12"8rd x 3-1/2"Buttress Pin 12/10/09-2 75" 12 9,260' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch GR tagged up _ at 11253'. -= G-2 13 9,748' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch ••••1 _ 14 10,174' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch • = G-3 15 10,571' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch 16 11,000' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch One joint above packer G-4 17 11,039' 3.000 4.000 Locator,Seal Assembly,6.5'long 18 11,078' 2.813 3.880 Otis,'X'Nipple,2.813 19 11,110' 3.000 3.875 Wireline Entry Guide =, „ A-1 11,040' 4.000 5.870 Packer, 7",Baker Mod."F-1" (DP set) A-2 11,043' 4.000 5.870 Seal Bore Extension,3.75'long,bottom @ 11047' TOL @ H-1 11533'elm= Perforation Data H-2 11542'dpm= lls6s'Wlm Top Btm Top Btm Zone Comments H-3 on 5/1/00 (MD) _ (MD) (TVD) (TVD) G-2 11,193' 11,199' 9,003' 9,009' 5/7/00 @ 6 spf +'" H-4 G-3 11,251' 11,283' _ 9,060' _ 9,091' 4/28/00 @ 6 spf,5/7/00 @ 6 spf G-4 11,317' 11,323' 9,124' 9,130' 5/5/00 @ 6 spf Cleaned 5"liner G-4 11,329' 11,342' 9,136' 9,149' 5/3/00 @ 6 spf H-5 to 12032'dpm HB-1 11,655' 11,665' 9,453' 9,463' 6/11/00 @ 6 spf ----r7'.--''--'=. c.-�. on 4/22/00, L�:::::: - Coil cleanout to HB-2 11,688' 11,775' 9,485' 9,570' Covered with 5"liner and cemented, = 11990' 4/22/00 ctm/12033'elm HB-3 11,785' 11,802' 9,580' 9,596' 6/5/00,6 spf on 5/29/00 PBTD= 12008' TD= 12398' HB-3,4 11,835' 11,842' 9,628' 9,634' 6/5/00,6spf MAX HOLE ANGLE=49° HB-4 11,920' 11,940' 9,709' 9,728' 6/4/00,6 spf HB-4 11,993' _ 12,003' 9,778' 9,788' 6/4/00,6spf HB-5 12,030' 12,060' 9,813' 9,841' Covered by fill Updated:12/03/15 by JLL • • Hilcorp Alaska LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-08RD E-Line 50-733-20107-01 174-003 10/18/15 12/2/15 Daily Operations: 10/18/15-Sunday Safety meeting&Job permits.Spot equipment. Rig up lub and gun. Pickup lub connect to wellhead. Pressure test lub 250 psi low& 1500 psi high. RIH with 15'of 2 1/2" RTG 6spf,sat down @ 181' POOH. OOH,wait while water was pumped in well to clear ice plug. RIH with gun sat down @ 181'. OOH, put methanol in lub,then opened well back up. RIH with gun sat down @ 181'. OOH, broke off gun, rigged up 2-5' 1 11/16"weight bars, 2" CCL, 1 1/2"spang jars&2.70"gauge. RIH sat down @ 181'worked it and made no hole, POOH. OOH removed 2.70"gauge added 2.50"gauge. Lunch, RIH sat down @ 181' beat through worked back&forth through tight spot. Ran in to 750' POOH. Removed 2.50"gauge added 2.70"gauge. RIH sat down @ 181' beat through worked back&forth through tight spot. Ran to 1,000' POOH. Put gun string back on. RIH with gun sat down @ 8,745'tried working it and was losing hole and getting sticky. POOH,found paraffin on guns. Rigged up 2-5 1 11/16" weight bars, 2" CCL, 1 1/2"Spang,8'of 2.50" bailers and 2.70"gauge ring. RIH sat down @ 8,545'worked it and made no hole. POOH. OOH, rigged down. Equipment secured.Area cleaned up. 12/01/15-Tuesday Safety meeting. Pressure Test 500 L 2000H.Started FIW injection, T-42, IA—156,OA—84 4.2 BPM. 9 BBL away well on vacuum. Pumped 330 gallons Xylene. Pumped 95BL of Diesel T- 10, IA—186,OA—84 BPM 2.4. Displaced with 120 BBL FIW, soak well. Waiting on wireline. ARRIVE ON DOLLY.ATTEND EVENING MEETING. FILL OUT PERMIT,JSA.SPOT UNIT AND LUBRICATOR ON DECK.SLICKLINE. PT LUB TO 1900 PSI, GOOD. RIH W/2.70 G-RING TO 11,271KB(SOME BOBBLES @ 2400KB). WT CANNOT FALL. POOH. GOT HUNG UP @ 100KB. CANNOT PULL UP OR FALL. NO SPANGS.TALK W/PRODUCTION, PUT WATERFLOOD DOWN WELL. DO NOT BUILD PRESSURE. PUMP FOR APPROX. 1 HR,TOOLS DO NOT FALL, DECIDE TO PULL ON WIRE UP TO 1000#, COME FREE @ 1200#LINE. PULL DRAGGING HARD THE WHOLE WAY TO SURFACE. BREAK OFF LUB AND DISCOVER ICE PLUG IN STUFFING. CUT-WIRE, REMOVE STUFFING BOX, CLEAN AND THAW. REHEAD. 12/02/15-Wednesday MORNING MEETING. PERMIT,JSA,TIE NEW ROPE SOCKET. PICK UP TOP SHEAVE AND WIRE.STAND UP LUB. DUMP—1 GAL METHANOL DOWN LUB. RIH W/2.5"X7' DD BAILER TO 11,271KB,WT TO 11,273KB, POOH. OOH W/APPROX 2 CUPS OF SAND AND SCALE. TALK W/PROD, DECISION MADE TO CEASE OPERATIONS. RD SLICKLINE. • P„' OFTfJ� • �w\��j��sv THE STATE Alaska Oil and Gas ,-- � o f Conservation Commission ALA _ 333 West Seventh Avenue mp*- Anchorage, Alaska 99501-3572 � GOVERNOR BILL WALKER g Main: 907.279.1433 ®FALAS Fax: 907.276.7542 www.aogcc.alaska.gov Dan Marlowe CIO DEL: 015 Operations Engineer 14- O Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil and Middle Kenai G Oil Pools, TBU D-08RD Sundry Number: 315-614 Dear Mr. Marlowe: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this Ay of October, 2015 Encl. '.` icT 152015 RB©MS 1\ II IIIt ` STATE OF ALASKA '3E_P 2 9 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION /0/13//-E' APPLICATION FOR SUNDRY APPROVALS A.OGCG 20 AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown 0 Suspend❑ Perforate 0 ` Other Stimulate El Alter Casing 0 Change Approved Program❑ Plug for Redrill❑ Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well 0 Other. 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC " Exploratory 0 Development [J ' 174-003 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic 0 Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20107-01 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 228A f Will planned perforations require a spacing exception? Yes 0 No 0 / Trading Bay Unit D-O8RD ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018729 • McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 12,398 .10,149 12,032 9,814 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,532' 13-3/8" 2,532' 2,371' 3,090 psi 1,540 psi Production 8,733' 9-5/8" 8,733' 6,760' 5,750 psi 3,090 psi Liner 3,817' 7" 12,385' 10,137' 8,160 psi 7,020 psi Liner 499' 5" 12,041' 9,823' 8,290 psi 7,250 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11,193'-12,060' , 9,003'-9,841' 4-1/2"&3-1/2" 12.6#/L-80&9.2#/N-80 7,787&11,110 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): , Baker Mod.F,Baker Mod.FA,Baker Mod.F-1 &Baker SSV ' 7,832'(MD)6,138'(ND)9,182'(MD)7,103'(ND)11,040'(MD)8,854'(TVD)/337'(MD) 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic❑ Development 0- Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 10/15/2015 OIL 0 • WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR ❑ SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown 0 Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe@hilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signatuf or/L. ,Z f._ J.� Phone (907)283-1329 Date 9/29/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3154401 q Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ❑ Location Clearance ❑ Other: sit, - RBDN►s Spacing Exception Required? Yes 0 No I Subsequent Form Required: /b C/OL-1 APPROVED BY Approved by: ,' i)44e4,.../4"..._ COMMISSIONER THE COMMISSION Date:/ —(3--/S ,' /4-7—/S- 1l& 10 lis- ,r. 1 - 1 , 1 4 / L Submit Form and Form 10-403 Revised 5/2015 proved a plicatio Valhi for``1 `2 months from the date of approval. Attachments in Duplicate 14 • • Well Prognosis Well: D-08rd Hi!carp Alaska,LLC Date: 09/28/15 Well Name: D-08rd API Number: 50-733-20107-01 Current Status: Gas-Lifted producer Leg: Leg#B-1 SE corner Estimated Start Date: October 15, 2015 Rig: N/A (E-Line) Reg. Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 174-003 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Current Bottom Hole Pressure: 3,275 psi @ 9,077' TVD 0.428 psi/ft mid perf 2009 SIBHP Maximum Expected BHP: 3,275 psi @ 9,077' TVD 0.428 psi/ft mid perf 2009 SIBHP Max.Allowable Surface Pressure (Perf Job): -1,200 psi gas-lift pressure Brief Well Summary Well D-08rd is a gas-lifted oil well completed in the G and Hemlock zones. This project will re-perf the G-3 sand. E-line Procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. RU e-line guns and perforate per program. Record tubing pressures before and after perforating run. 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 4) McArthurRiver Field, TBU • Schematic DollyVarden Platform Well: D-08RD Hilcorp Alaska,LLC Completed: 6/2000 CASING AND TUBING DETAIL Tree connection:4-1/16" 5,000# SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61.0 1-55 Butt.LT&C 12.515 Surf 2,532' 9-5/8" 40,43.5,47 N-80 Butt 8.681 Surf 8,733' r- 1 DV collar 5517' 5519' 7" 29 N-80 LT&C 6.184 8568' 12385' 2 5" 15 L-80 Buttress 4.408 11542' 12041' Tubing: �. 3 4-1/2" 12.6 L-80 Butt 3.958 Surf 7,787' iL3-1/2" 9.20 N-80 Butt 2.992 7,787' 11,110' 4 JEWELRY DETAIL 5 NO. Depth ID OD Item 7> 6 41.00' 4-1/2"Cameron Type DCB Sealock x Sealock Tbg Hngr -. 7 1 337' 3.813 6.125 SSSV,Baker(3.813"I.D.) Ir 2 2,456' 3.883 7.063 GLM,4-1/2",Camco MMG,1-1/2"R-2 Valve RK Latch A 3 3,983' 3.883 7.063 GLM,4-1/2"Camco MMG,1-1/2"R-2 Valve RK Latch 4 5,258' 3.883 7.063 GLM,4-1/2"Camco MMG,1-1/2"R-2 Valve RK Latch 9 5 6,195' 3.883 7.063 GLM,4-1/2"Camco MMG,1-1/2"R-2 Valve RK Latch - B �/ 6 6,969' 3.883 7.063 GLM,4-1/2"Camco MMG,1-1/2"R-2 Valve RK Latch /� 7 7,783' 3.883 7.063 GLM,4-1/2"Camco MMG,1-1/2"R-2 Valve RK Latch L C 9 8,528' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch D Above 7"x 5-1/2"xover E �florG F 10 9,197' 3.000 4.000 Locator,Seal Assy,6.89'Long(top seal 1.95'from top) 10 hole in Upper Scab Liner Assembly 11 " °- A casing A 7,832' 6.000 8.218 Packer,9-5/8"Baker Mod.F(DP set) L_ _1 8827'- RA tag @ 7833.83 12-16 t_ -1 8857' B 8,555' 4.950 5.500 Xover,5-1/2"Buttress box x 7"buttress box and a 8,556' 4.550 6.070 5-1/2"buttress pin by 5-1/2"15.5#Hydril 511 Pin 17 > - C 9,172' 4.360 5.600 Seal assembly,5" Located in 7'Upper PBR Ag _' A-1 D 9,182' 4.000 5.540 Anchor,Baker Mod.E-22 - _I A-2 E . 9,182' 4.000 5.813 Packer,7" x 4",Baker Mod."FA", 4"x 4.75"step down 18 RA tag at 9184.92' x F 9,186' 4.375 5.000 Millout Extension,10.1'Long w/8 ea.1"Holes @ top 19 G 9,196' 4.000 5.000 Lower Seal Bore Extension,13.84'Long 11 9,210' 2.992 5.570 Xover,5"LTC Box x x 3-12"8rd x 3-1/2"Buttress Pin 12/10/09.2.u' 12 9,260' 2.867 5.968 GLM,3-1/2"McMurry Macco,510-2,R-2,RK Latch GR tagged up at 11253'. = G-2 13 9,748' 2.867 5.968 GLM,3-1/2"McMurry Macco,510-2,R-2,RK Latch 14 10,174' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch -- G-3 15 10,571' 2.867 5.968 GLM,3-1/2"McMurry Macco,S10-2,R-2,RK Latch 16 11,000' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch One joint above packer = G-4 17 11,039' 3.000 4.000 Locator,Seal Assembly,6.5'long 18 11,078' 2.813 3.880 Otis,'X'Nipple,2.813 19 11,110' 3.000 3.875 Wireline Entry Guide IX A-1 11,040' 4.000 5.870 Packer, 7",Baker Mod."F-1" (DP set) A-2 11,043' 4.000 5.870 Seal Bore Extension,3.75'long,bottom @ 11047' TOL @ H-1 11533'elm= Perforation Data H-2 11542'dpm= 11565'wlm Zone Top Btm Top Btm Comments ' H-3 on 5/1/00 (MD) (MD) (TVD) (TVD) G-2 11,193' 11,199' 9,003' 9,009' 5/7/00 @ 6 spf H-4 G-3 11,251' 11,283' 9,060' 9,091' 4/28/00 @ 6 spf,5/7/00 @ 6 spf G-4 11,317' 11,323' 9,124' 9,130' 5/5/00 @ 6 spf Cleaned 5"liner G 4 11,329' 11,342' 9,136' 9,149' 5/3/00 @ 6 spf u H-5 to 12032'dpm on 4/22/00, HB-1 11,655' 11,665' 9,453' 9,463' 6/11/00 @ 6 spf Coil cleanout to HB-2 11,688' 11,775' 9,485' 9,570' Covered with 5"liner and cemented, 11990' 4/22/00 ctm 12033'elm HB-3 11,785' 11,802' 9,580' 9,596' 6/5/00,6spf on 5/29/00 HB-3,4 11,835' 11,842' 9,628' 9,634' 6/5/00,6spf PBTD= 12008' TD= 12398' MAX HOLE ANGLE=49° HB-4 11,920' 11,940' 9,709' 9,728' 6/4/00,6 spf HB-4 11,993' 12,003' 9,778' 9,788' 6/4/00,6spf HB-5 . 12,030' 12,060' 9,813' 9,841' Covered by fill Updated:9/29/15 by.ILL • McArthur River Field, TBU Proposed Dolly Varden Platform Well: D-08RD 1Gleorp Alaska,11.1, Completed: 6/2000 CASING AND TUBING DETAIL Tree connection:4-1/16"5,000# SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61.0 J-55 Butt.LT&C 12.515 Surf 2,532' 1,11I 9-5/8" 40,43.5,47 N-80 Butt 8.681 Surf 8,733' 1 DV collar 5517' 5519' 7" 29 N-80 LT&C 6.184 8568' 12385' 2 5" 15 L-80 Buttress 4.408 11542' 12041' Tubing: L . 3 4-1/2" 12.6 1-80 Butt 3.958 Surf 7,787' 3-1/2" 9.20 N-80 Butt 2.992 7,787' 11,110' - 4 JEWELRY DETAIL 5 NO. Depth ID OD Item L---'.- 6 41.00' 4-1/2"Cameron Type DCB Sealock x Sealock Tbg Hngr 7 1 337' 3.813 6.125 SSSV,Baker(3.813"I.D.) MEM -IIIII8 2 2,456' 3.883 7.063 GLM,4-1/2",Camco MMG,1-1/2"R-2 Valve RK Latch A 3 3,983' 3.883 7.063 GLM,4-1/2"Camco MMG,1-1/2"R-2 Valve RK Latch 4 5,258' 3.883 7.063 GLM,4-1/2"Camco MMG,1-1/2"R-2 Valve RK Latch 5 6,195' 3.883 7.063 GLM,4-1/2"Camco MMG,1-1/2"R-2 Valve RK Latch 6 6,969' 3.883 7.063 GLM,4-1/2"Camco MMG,1-1/2"R-2 Valve RK Latch �� 7 7,783' 3.883 7.063 GLM,4-1/2"Camco MMG,1-1/2"R-2 Valve RK Latch A \ 8 7,830' 3.000 7.625 Fluted Locator,7.5"O.D. C 9 8,528' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch MIL:.' D E CB MI Above 7"x 5-1/2"xover �---: F 10 9,197' 3.000 4.000 Locator,Seal Assy,6.89'Long(top seal 1.95'from top) _ G Upper Scab Liner Assembly 10 -� 'foie in 11 casing A 7,832' 6.000 8.218 Packer,9-5/8"Baker Mod.F(DP set) I I 8827'- RA tag @ 7833.83 12-16 I I 8857' B 8,555' 4.950 5.500 Xover,5-1/2"Buttress box x 7"buttress box and 8,556' 4.550 6.070 5-1/2"buttress pin by 5-1/2"15.5#Hydril 511 Pin i t 17 iii C 9,172' 4.360 5.600 Seal assembly,5" Located in 7'Upper PBR M._ _" A-1 D 9,182' 4.000 5.540 Anchor,Baker Mod.E-22 I_ Elm A-2 E 9,182' 4.000 5.813 Packer,7" x1 4",Baker' Mod."FA", 4"x 4.75"step down 18 RA tag at 9184.92 = F 9,186' 4.375 5.000 Millout Extension,10.1'Long w/8 ea.1"Holes @ top 19 G 9,196' 4.000 5.000 Lower Seal Bore Extension,13.84'Long 11 9,210' 2.992 5.570 Xover,5"LTC Box x x 3-12"8rd x 3-1/2"Buttress Pin 12/10/09:2 i5 12 9,260' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch GR tagged up at 11253'. L''-2 13 9,748' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch 14 10,174' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch Ma G-3 ,,,.. 15 10,571' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch 16 11,000' 2.867 5.968 GLM,3-1/2"McMurry Macco,SFO-2,R-2,RK Latch One joint above packer G-4 17 11,039' 3.000 4.000 Locator,Seal Assembly,6.5'long 18 11,078' 3.880 Otis,'X'Nipple,2.813 19 11,110' 3.000 3.875 Wireline Entry Guide , n A-1 11,040' 4.000 5.870 Packer, 7",Baker Mod."F-1" (DP set) A-2 11,043' 4.000 5.870 Seal Bore Extension,3.75'long,bottom @ 11047' TOL@ H-1 11533'elm= Perforation Data H-2 11542'dpm= Top Btm Top Btm 11565'wlm Zone Comments H-3 on 5/1/00 (MD) (MD) (TVD) (TVD) G-2 11,193' 11,199' 9,003' 9,009' 5/7/00 @ 6 spf H-4 G-3 11,251' 11,283' 9,060' 9,091' 4/28/00 @ 6 spf, /7/00 @ 6 spf G-3 ±11,253 ±11,283 ±9,062 ±9,091 Future Cleaned 5"liner G-4 11,317' 11,323' 9,124' 9,130' 5/5/00 @ 6 WiNietion/WiltiffillE H-5 to 12032'dpm G-4 11,329' 11,342' 9,136' 9,149' 5/3/00 @ 6 spf Dig - on 4/22/00, HB-1 11,655' 11,665' 9,453' 9,463' 6/11/00 @ 6 spf � Coil cleanout to 11990' HB-2 11,688' 11,775' 9,485' 9,570'.41111 Covered with 5"liner and cemented, ctm/12033'elm 4/22/00 on 5/29/00 HB-3 11,785' 11,802' 9,580' 9,596' 6/5/00,6 spf PBTD=12008' TD=12398' HB-3,4 11,835' 11,842' 9,628' 9,634' 6/5/00,6spf MAX HOLE ANGLE=49° HB-4 11,920' 11,940' 9,709' 9,728' 6/4/00,6 spf HB-4 11,993' 12,003' 9,778' 9,788' 6/4/00,6spf HB-5 12,030' 12,060' 9,813' 9,841' Covered by fill Updated:9/29/15 by JLL • OF T7./ • 1/ T HE STATE gw . I - , s s Alaska Oil and Gas 9 °f AL AS� Conservation Commission ontt GOVERNOR SEAN PARNELL 333 West Seventh Avenue Oj , Anchorage, Alaska 99501 -3572 ALAS w" Main: 907.279.1433 Fax: 907.276.7542 October 12, 2012 Mr. Chris Myers Field Superintendent Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524 -4027 SCANNED Pf 2013 RE: No -Flow Verification Trading Bay Unit D -08RD PTD 1740030 Dear Mr. Myers: On October 4, 2012 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no -flow test of Trading Bay Unit well D -08RD located on the Dolly Varden Platform in Cook Inlet. The well is operated by Hilcorp Alaska, LLC (Hilcorp). A subsurface safety valve is not required to be installed in this well based on the no -flow test result. A fail -safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10 -004 — was rigged up to Trading Bay Unit D -08RD. The no -flow test consisted of a series of shut in periods each followed by opening the well to monitor for flow to surface. During the flow monitoring periods, there was no liquid production to surface and gas was measured at rates less than 180 standard cubic feet per hour. The subsurface safety valve must be returned to service if Trading Bay Unit D -08RD demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the Dolly Varden Platform. Sincerely, jt* b e ri James B. Regg Petroleum Inspection S cc: P. Brooks AOGCC Inspectors • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg R141 (Z . DATE: October 4, 2012 P.I. Supervisor FROM: Jeff Jones SUBJECT: No -Flow Test Petroleum Inspector Hilcorp / Dolly Varden PLT D -08RD PTD 1740030 - Trading Bay Unit October 4, 2012: I traveled to Hilcorp's Dolly Varden Platform in Cook Inlet to witness a No -Flow Test on well TBU D -08RD. On my arrival on the platform I met with Hilcorp Lead Operator Mike Loomis and we discussed the operational details of the test. Mr. Loomis indicated that the well pressure had been bled down and the welibore perfs were open to the tree cap with no plugs or restrictions. Well D -08RD was lined up from the tree top swab valve through an Armor -Flow model # 3461 -03T0 flow meter (180 SCFH to 1800 SCFH span) to a 1" hose which terminated in an open top drum. The flow from the well was monitored for 3 hours with readings recorded every 30 minutes. Unassisted gas and liquid flow from the well did not exceed 900 SCFH or 6.3 gals. hourly flow _ rate during the test. Well D -08RD meets the AOGCC requirements for a No -Flow status determination. Summary: I witnessed a successful No -Flow Test on Hilcorp's Trading Bay Unit well D -08RD on the Dolly Varden Platform. Well No -Flow Test Data Operator: Hilcorp Operator Rep: Mike Loomis AOGCC Rep: Jeff Jones Field /Unit /Pad TBU / Dolly Varden PLT Well: D -08RD Time Well Flow Comments Gas Liquid 11:30 < 180 scfh • none Start Test 12:00 < 180 scfh none 12:30 < 180 scfh none 13:00 < 180 scfh none . 13:30 < 180 scfh none 14:00 < 180 scfh none 14:30 < 180 scfh none End Test Produced to open top container through Armor -Flow meter model #3461- 03T0 -13 ser. # 991632 Total liquid produced: none. Attachments: none SCANNED APR 1 7 2013 RJF 09/19/02 Page 1 of 1 2012- 1004_No- Flow_TBU_D- 08RDJj MEMORANDUM TO: THRU: Randy Ruedrich, Commissioner Jim Regg, ~"~¢,/,z: P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission .j'~d~ ~/Z~/c'~7 DATE: August 23, 2003 FROM: Lou Grimaldi, SUBJECT: Petroleum Inspector No-Flow Test Unocal, Dolly Varden D-8RD Trading Bay Unit PTD 174-0030 NON-CONFIDENTIAL Saturday, Au.qust 23, 2003: I witnessed an attempted No-Flow verification on the Dolly Varden platform well #D-8RD in the McArthur River field. Following is a timeline and well status during test. 0800 D-8RD flowing @ < 1 psi to well clean tank, IA @ 2 psi and blowing down also. Line up well to flow meter, Shut-in casing. Initially flowing 400 scf @ <1 psi. Flow increased approximately 10 scf/min. 0850 Flowing @ 850 scf, 3 psi and both increasing. Blow well down to production. 0955 Line up well through flow meter, shut-in casing. Initial flow 300 scf and risin¢l. Time Psi ~c~h Time Psi Sc~ Time Psi Sc~h Time Psi ScEh h 1000 1 500 1020 >2.5 675 1040 4 790 1130 6. 1010 5 1005 1.5 550 1025 3 700 1045 4 805 1145 7. 1060 5 1010 2 600 1030 3.5 740 1100 5 815 1015 2.5 650 1035 4 770 1115 6 950 1200 Shut down test, well still building. Ended test, turned well back over to production. Note: The gauge used to check flow was incapable of measuring below 180 scf or above 2000 scf. 100-psi test gauge used to check tubing pressure. Zero flow indicated by hose in bucket. This well failed to exhibit inability to flow to surface unassisted due to gas flow above the maximum of 900 SCFH.. SUMMARY: I witnessed the failed attempt at No-Flow verification on UNOCAL's Dolly Varden platform well #D-SRD in the McArthur River field. NON-CONFIDENTIAL No-Flow TBU D-8 08-23-03 LG.doc ALAS~ OIL AND GAS CONSERVATION COM~SSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 August23,2003 Dwight Johnson UNOCAL Field Superintendent PO Box 196247 Anchorage, Alaska 99519 RE: No-Flow Verification TBU Well D-8RD PTD 174-003 Dear Mr. Johnson: On August 22, 2003 AOGCC Petroleum Inspector Lou Grimaldi witnessed an attempted "no-flow" test on Well D-8RD at UNOCAL's Dolly Varden Platform, Trading Bay Unit, McArthur River Field. Mr. Grimaldi arrived on Dolly Varden Platform and observed the well flowing to the clean-up tank at 450 scf/hr and 1 psi. The inner annulus (IA) was also being blown down to the clean-up tank at 2 psi. Flow was directed through the gas meter and the well was observed for 1 hour. The gas rate increased at about 10 scf/minute to 850 scf/hr at 3 psi. The well was blown down to the production system and the well was observed for 2 hours. The initial gas rate of 300 scf/hr and pressure of 1 psi increased through the monitoring period to 950 scf/hr and 7.5 psi. At the end of the observation period, the well rate and pressure were still increasing Although no liquid flow was observed, the observed performance of TBU well D-8RD (174-003) exceeds the maximum gas rate of 900 scf/hr. It has been concluded that TBU well D-8RD (174-003) did not meet the criteria of a "no- flow" performance test. The well's performance meets the criteria at 20 AAC 25.265 (b). Therefore, Unocal must maintain the fail-safe automatic SSSV in service. A copy of this letter should be maintained in the respective well file on board Dolly Yarden. Sincerely, Thomas E. Maunder, PE Sr. Petroleum Engineer TEM:\jjc SC NNtED SEP 0 2003 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan Seamount, Commissioner Blair Wondzell, P. I. Supervisor FROM: John Crisp? ~ ~. SUBJECT: Petroleum Inst~iector DATE: June 22, 2000 Safety Valve Tests Dolly Varden Platform McArthur Rv. Field June 22, 2000: I traveled to Unocal's Dolly Varden Platform in the McArthur River Field to witness the Semi Annual Safety Valve System tests. Wells number 05, 17 & 31 Subsurface Safety valves were POOH for repair. Surface Safety valve on well 01 will be changed out during next Platform shut down due to header valve leaks. The AOGCC test report is attached for failure reference. SUMMARY: I witnessed the Semi Annual SVS tests on the Dolly Varden Platform in the McArthur River Field. 24 wells, 57 components tested, 3 failures witnessed. 5.2% failure rate. Attachments: SVS Dolly Pit. 6-22-00jc cc; NON'CONFIDENTIAL SVS Dolly Pit. 6-22-00jc Alaska Oil and Gas Conservation CommisSion Safety Valve System Test Report Operator: Unocal Operator Rep: Mark Murietta AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: McArthur Rv./Dolly Varde Separator psi: LPS 110 HPS 6/22/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code GAS or CYCLE D-01 1670800 110 80 85 P 4 OIL iD-02ARD 1750380 110 80 65 P 5 OIL D-03RD2 1830810 110 80 80 P P OIL D-04RD 1820410 110 80 80 P P OIL D-05RD 1800650 110 80 100 P P 43 OIL 1921550 110 80 80 P P P OIL 1740030 110 80 75 P P P OIL D-II 1680730 110 80 80 P P P OIL D-12RD 1800820 110 80 75 P P 43 OIL D-17RD 1810230 110 80 80 P P 43 OIL D-18 1690040 800 700 700 P P P GAS D-20 1690950 1101 80 90 P P OIL D-25RD 1780870 110 80 100 P P OIL D-26RD 1981290 110 80 75 P ~ P OIL D-27 1750240 110 80 60 P P OIL D-28 1760360 110 80 100 P P OIL D-30RD2 1880980 D-31RD 1760740 110 80 70 P P 43 OIL D-32 1700370 110 80 75 P P P OIL D-40RD 1820830 110 80 80 P P OIL D-42 1830530 110 80 70 P P OIL D-43RD 1853110 110 80 70 P P P OIL D-46 1890610 110 80! 60 P P P OIL D-47 1910110 110 80 70 P P 9 OIL D-48 1921540 110 80 80 P P P OIL Wells: 24 Components: 57 Failures: 3 Failure Rate: 5.2% [] 90 Day Remarks: Wells that have SSSVs out for repair are designated 43 & not counted as failures or components tested. 6/27/00 page 1 of 1 SVS Dolly Pit. 6-22-00jcl STATE OF ALASKA ALASKA OiE AND GAS CONSERVATION C' MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: X Alter casing: Repair w~il:' X Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) UNOCAL Development: X 106' KB above MSL feet 3. Address Exploratory: 7. Unit or Property name P.O. Box 196247 Anchorage, Alaska 99519-6247 S tratigraphic: Trading Bay Unit Service: 4. Location of well at surface 8. Well number 677' FSL, 1,221' FWL, Sec. 6, T8N, R13W, SM ~'~ ~,i~~ i ~,~i Dolly Varden D-8RD At top of productive interval 9. Permit number/approval number 1776' FSL, 631' FWL, Sec. 8, T8N, R13W, SM '74-3/300-056 At effective depth ~... ~._~!~'~ 2 2 ~000 10. APl number 1698' FSL, 792' FWL, Sec. 8, T8N, R13W, SM 50- 733-20107-01 At total depth AJP~i.~ ~z ~ ..... ~.~ £. £~ Flr~i~ CO~ili~ili~iOil 11. Fiel~P~l 1642' FSL, 851' ~L, Sec. 8, T8N, R13W, SM Gzone/Heml~k 12. Present well condition summa~ ~ ~ i~ ~J~ Total depth: measured 12,398 feet Plugs (measured) ,ruew.,c , ORIGINAL Effective depth: measured 12,032 feet Junk (measured) true veAical 9,814 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2~3' 1~3/8" 2~3' 2371' Intermediate Production 8733' 9-5/8" 2,350 sx 8733' 6760' Liner 3817' 7" 1 ~0 sx 12385' 10137' Perforation dep~: measured 11193'-11199', 11251 '-11283', 11317'-11323', 11329'-11342', 11655'-11665', 11785'-11802', 11835'-11842', 11920'-11940', 11993'-12003' true veAical 9003'-9009', 9060'-9091', 9124'-9130', 9136'-9149' 9452'-9462', 9579'-9596', 9627'-9634', 9709'-9728', 9778'-9787' Tubing (size, grade, and measured depth) 4-1/2", 12.6~ L-80 Tubing to 7787', 3-1/2" 9.3~, L-80 from 7787' to 11,110' Packers and SSSV (~pe and measured depth) Baker F-1 Packer ~ 11040', Baker FA Packer ~ 9182, Baker F Packer ~ 7832' 13. Stimulation or cement squeeze summa~ On 4/20/00, squeezed all of open Hemlock perfs, 11,6~'-12,010' (clean out depth), with 23 bbls cmt. Inte~als Eeated (measured) NA Trea~ent description including volumes used and final pressure NA 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well o~ration 3/00 2~ 120 5575 1140 1 ~ Subsequent to operation 6/11/00 400 175 200 860 120 15. A~chments: 16. Status of well classification as: Copies of Logs and Suweys run: Daily Report of Well Operations: X Oih X Gas: Suspended: Se~ice: 17. I hereby certi~ that the foregoing is true and correct to the ~st of my knowledge: Sig~ed: Dan Williamso~ ~ ~ ~i~e: Drilling Manager Date: ~~~ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE UNOCAL Alaska Drilling Drilling Summary Report D-8RD 4/10/00 to 6/5/00 4/10/00 Move rig from D-6RD to D-8RD. ND tree, NU BOPE. Test BOPE. Engage tubing hanger, pull 240k, hanger did not come free. RU APRS and cut 3-1/2" tubing at 11453'. 4/11/00 Attempt to PU hanger with no success. Engage 4-1/2" tubing below hanger with spear. Jar and pull 310k, hanger came free from "F" tubing spool. Tubing not free, RU APRS. Re-cut tbg at 11455' with tbg in tension. Tbg still not free. Estimated stuck point at 8200' from tbg stretch. Cut 3-1/2" tbg at 8701'. RD APRS. 4/12/00 Pull tbg free at 230K. Lay down 8452' of 4-1/2" tbg/GLMs and 249' of 3- 1/2" tbg. RIH with 3-1/2" overshot, engage fish at 8701'. Jar pipe free at 275k. Circ BU. 4/13/00 POOH with 3-1/2" tubing fish down to cut at 11453'. RIH with washpipe and packer mill. High torque near bottom due to hole angles, wash over tubing stub and attempt to mill packer at 11465'. Unable to mill packer due to torque limit of 15k fi-lbs on 3-1/2" drill pipe. POOH with washpipe assy. 4/14/00 RIH with overshot while waiting for 5" drill pipe. Engage tubing stub above packer at 11465'. Jar and pull 300k, tubing stub came free. POOH, recovered seals and tailpipe from packer. Test BOPE. 4/15/00 PU 5" drill pipe. RIH with packer mill and PRT. Tag packer at 11470', mill packer free in 10 minutes. RIH to 11538', POOH. 4/16/00 Finished POOH, recovered packer. RIH with 6.0" mill cleanout assy. High torque at 11668'-11684' and 11910'-11920'. ROP slowed at 12006'-12008'. PUMP Hi-vis sweep and POOH. Mill was 5.70". 4/17/00 RIH with second 6.0" mill cleanout assy. Tag fill at 12,000' and clean out to 12,010'. No further progress. Pump sweep and POH to 11420', pulled tight. Work tight spot and POH to liner top at 8508'. RIH to 11127' with no drag. POOH with no drag. RIH with 7" Retrievamatic test packer. 4/18/00 Set test packer at 11,100'. Test annulus, 1500 psi leaked off to 1000 psi in 7 min. Establish injection rate below packer of 1/2 BPM at 1400 psi. Move and set packer up hole and determine highest leak point at 8827' to 8857'. POOH with test packer. RU Schlumberger, run USlT casing inspection log. 4/19/00 4/20100 4/21/00 4/22/00 4/23/00 4/24/00 4/25/OO 4/26/00 ,~.~a ~4i &. Gas Cons. Log from 11870' to 7" liner top at 8568' and log 9-5/8" casing 7500'. POOH and RD Schlumberger. RIH with 915' of 2-7/8" cement stinger and test packer on drill pipe. Tag TD at 12008'. Set packer at 11062' and establish injection rate of % BPM at 2500 psi. Release packer, mix 23 bbls of 15.8 ppg cement. Lay in 23 bbls of 15.8 ppg cement on bottom. POH 10 stands. Reverse circ 1-1/2 drill pipe volumes. Set test packer, hesitate squeeze 1.5 bbls net cement into formation at 2500 psi max. Release packer, drop drill pipe wiper dart and displace to tubing tail. POOH with test packer and 2-7/8" tubing stinger. RIH with 6" bit and 7" casing scraper. Drill out firm cement from 11460' to 12008' in 7 hrs. Circ hi-vis sweep. POOH with cleanout assembly. Test BOPE. RIH with 500' of 5" liner. Tag bottom at 12,008'. Drop ball and set HMC liner hanger with 2350 psi. Shear ball. Release C-2 running tool with right hand rotation. Cemented 5" liner with 10 bbls of 15.8 ppg cement. Bump plug, PU and set ZXP liner top packer. Reverse out cement on top of liner, observed 2 bbl cement to surface. RIH with 4-1/4" mill and 7" casing scraper. Tag cement stringer at 11,982', wash and ream to 11,999'. Circ hi-vis sweep and displace well to clean 3% KCL. POOH with cleanout assy. RIH with 9-5/8" scraper, tag top of 7"liner at 8561', 3-1/2" tail at 11,421'. Circ hole clean and POOH. RIH with lowest packer on drill pipe strapping drill pipe. Drill pipe tally correction, 33'. (Mistake was in 3-1/2" DP tally). POOH and restrap. Same correction. RIH with 7" packer on drill pipe and "J" running tool. Set packer at 11040'. POOH with drill pipe. RIH with 3-1/2" tubing tail including 5 gas lift mandrels and middle FA packer on B-2 running tool. Stab seals into lower packer at 11040'. Drop ball and set middle packer at 9182'. Pressure up annulus with no returns observed in drill pipe. Blow ball at 3200 psi and release from packer with right hand rotation. POOH with B-2 running tool. RIH with 5-1/2" x 7" scab liner. Tight spot at 8821' with bottom of 5-1/2" and 9- 5/8" packer at 7472'. Circ and work through tight spot from 8821' to 8840'. RIH with no further problem and latch up K anchor at 9182'. Shear out and PU 1'. Drop ball and set 9-5/8" packer at 7831'. Test annulus to 1500 psi. Blow ball seat at 3200 psi. Release B-2 running tool with right hand rotation. POOH with running tool. RIH with 3-1/2" x 4-1/2" completion tubing and GLMs. Pressure test casing and lower liner to 1500 psi. Stab seals into middle packer seal bore at 9196' and pressure up to 800 psi. Space out and land tbg hanger. ND BOPE. 4/27/OO NU and test tree. Clean up rig. RU slickline and pull SSSV. RIH with 2.5" dummy gun to 12010' wlm, no problem. Rig down. NU flowline and gas lift line. 4/28/OO RU Schlumberger. RIH with 2-1/2" gun and tag bottom at 11980'. Perforate G-3 zone at 11251'-11283' @ 6 spf. Flow test well. 5/1/00 RIH with bailer on slickline. Bail sand from 12016' to 12037' wlm. Correlate liner top at 11565' wlm which is 32' deep to 11533' elm and 23' deep to 11542' dpm. 5/2/00 Ran slickline temperature/pressure survey. 5/3/00 Continue slickline bailing from 12033' to 12041' wlm. RD slickline. RU Schlumberger. RIH with 2-1/2" gun and tag fill at 12019' elm. Perforate G-4 from 11329' to 11342' at 6 spf. Flow test well. 5/5/00 Perforate G-4 from 11317' to 11323' at 6 spf. Flow test well. 5/7/00 Tag fill with gun at 11908' elm (111' of fill since tag at 12019' on 5/3/00). Reperforate G-3 from 11251 '-11282' at 6 spf. Perforate G-2 from 11193' to 11199' at 6 spf. RD Schlumberger. 5/14/00 Ran slickline gas lift survey to 11150'. 5/21 to 5/24/00 Twenty-seven slickline bailer runs recovered sand/clay from 11847' wlm to 11853' wlm/11821' elm. Quit bailing due to lack of progress, only able to recover partial bailer of fill each time. 5/28/00 RU coil tubing. 5/29/00 RIH with 2.75" mill and motor, did not see liner top at 11533' elm. Dry tag at 11835' ctm. Wash down to 11,990' ctm with no resistance. Saw liner top at 11,490' CTM (11,533' ELM). Motor stall at 11,990' ctm~12,033 ELM indicating PBTD. (PBTD was 12,032' dpm~12,023' elm on 4/22/00). POOH with coil. RU slickline. RIH with 2-1/2" dummy gun and tag PBTD at 12,007' work down to 12,011' WLM. POOH and saw tubing tail at 11,102' wlm~l 1,110' dpm~l 1,101' ELM. RIH with 2.25" drive down bailer and tag at 12,010', recover 1.5 gal of sand, saw tubing tail at 12,102' wlm and top of liner at 11,527'. RIH with 2nd bailer and recover .5 gal sand down to 12,011' wlm~12,010' ELM. Bottom desired HB-4 perf at 12,003' ELM. 6~4~OO RU Schlumberger. RIH with 2-1/2" gun and tag bottom at 12,014' ELM. Perforate 11,993'-12,003'. POOH with gun #1. RIH with gun #2 and perforate 11,920'-11,940'. 6/5/00 6/11100 RIH with Gun #3 and perforate 11,835'-11,842'. POOH with Gun #2. RIH with Gun #3 and perforate 11,785'-11,802'. POOH with Gun #3 and RD Schlumberger. RU Schlumberger. Perf HB-1 zone at 11,655'-11,665'. POOH and RD Schlumberger. UNOCALe Tree connection: 4-1/16" 5,000# E 10 11 12-16 17 18 19 A-1 -- A-2 G2-4 -- 11193' ------ to 11342 H-1 H-2 H- H-4 H- PBTD = 12008' TD = 12398' MAX HOLE ANGLE = 49° Hole in casing 8827'- TOL @ 11533' elm = 11542' dpm = 11565' wlm on 5/1/00 Cleaned 5" liner to 12032' dpm on 4/22/00, Coil cleanout to 11990' ethyl2033' elm on 5/29/00 SIZE WT Dolly V~, in Well No."'ff28RD Completed 4/26/00, As of 6/11/00 CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 13-3/8" 9-5/8" 7" Tubing: 4-1/2" 3-1/2" NO. 61.0 40,43.5,47 29 15 12.6 9.20 K-55 Butt. LT&C 12.515 Surf 2,518' N-80 Butt 8.681 Surf 8,733' DV collar 5517' 5519' N-80 LT&C 6.184 8568' 12385' L-80 Buttress 4.408 11542' 12041' Depth ID L-80 Butt 3.958 Surf 7,787' L-80 Butt 2.992 7.787' 11.110' JEWELRY DETAIL OD Item 41.00' 337' 3.813 4-1/2" Cameron Type DCB Sealock x Sealock Tbg Hngr 6.125 SSSV, Baker (3.813" I.D.) 2 2,456' 3.883 7.063 3 3,983' 3.883 7.063 4 5,258' 3.883 7.063 5 6,195' 3.883 7.063 6 6,969' 3.883 7.063 7 7,783' 3.883 7.063 8 7,830' 3.000 7.625 9 8,528' 2.867 5.968 10 9,197' 3.000 4.000 A 7,832' 6.000 8.218 B 8,555' 4.950 5.500 8,556' 4.550 6.070 C 9,172' 4.360 5.600 D 9,182' 4.000 5.540 E 9,182' 4.000 5.813 F 9,186' 4.375 5.000 G 9,196' 4.000 5.000 11 9,210' 2.992 5.570 12 9,260' 2.867 5.968 13 9,748' 2.867 5.968 14 10,174' 2.867 5.968 15 10,571' 2.867 5.968 16 11,000' 2.867 5.968 17 11,039' 3.000 4.000 18 11,078' 2.813 3.880 19 11,110' 3.000 3.875 A-1 11,040' 4.000 5.870 A-2 11,043' 4.000 5.870 GLM, 4-1/2", Camco MMG, 1-1/2" R-2 Valve RK Latch GLM, 4-1/2" Camco MMG, 1-1/2" R-2 Valve RK Latch GLM, 4-1/2" Camco MMG, 1-1/2" R-2 Valve RK Latch GLM, 4-1/2" Camco MMG, 1-1/2" R-2 Valve RK Latch GLM, 4-1/2" Camco MMG, 1-1/2" R-2 Valve RK Latch GLM, 4-1/2" Camco MMG, 1-1/2" R-2 Valve RK Latch Fluted Locator, 7.5" O.D. GLM, 3-1/2" McMurry Macco, SFO-2, R-2, RK Latch Above 7" x 5-1/2" xover Locator, Seal Assy, 6.89' Long (top seal 1.95' from top) Upper Scab Liner Assembly Packer, 9-5/8" Baker Mod. F (DP set) RA tag @ 7833.83 Xover, 5-1/2" Buttress box x 7" buttress box and 5-1/2" buttress pin by 5-1/2" 15.5# Hydri1511 Pin Seal assembly, 5" Located in 7' Upper PBR Anchor, Baker Mod. E-22 Packer, 7" x 4", Baker Mod. "FA", 4" x 4.75" step down RA tag at 9184.92' Millout Extension, 10.1' Long w/8 ea. 1" Holes @ top Lower Seal Bore Extension, 13.84' Long Xover, 5" LTC Box x x 3-12" 8rd x 3-1/2" Buttress Pin GLM, 3-1/2" McMurry Macco, SFO-2, R-2, RK Latch GLM, 3-1/2" McMurry Macco, SFO-2, R-2, RK Latch GLM, 3-1/2" McMurry Macco, SFO-2, R-2, RK Latch GLM, 3-1/2" McMurry Macco, SFO-2, R-2, RK Latch GLM, 3-1/2" McMurry Macco, SFO-2, R-2, RK Latch One joint above packer Locator, Seal Assembly, 6.5' long Otis, 'X' Nipple, 2.813 Wireline Entry Guide Packer, 7", Baker MOd."F-I" (DP set) Seal Bore Extension, 3.75' lon~, bottom @ 11047' Perforation Data Zone Top Bottom G-2 11193 11199 5/7/00 @ 6 spf G-3 11251 11283 4/28/00 @ 6 spf, 5/7/00 @ 6 spf G-4 11317 11323 5/5/00 @ 6 spf G-4 11329 11342 5/3/00 @ 6 spf HB-1 11655 11665 6/11/00 @ 6 spf HB-2 11688 11775 Covered with 5" liner and cemented, 4/22/00 HB-3 11785 11802 6/5/00, 6 spf HB-3,4 11835 11842 6/5/00, 6spf HB-4 11920 11940 6/4/00, 6 spf HB-4 11993 12003 6/4/00, 6spf HB-5 12030 12060 Covered by fill STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation Shutdown: Re-enter suspended well: Alter casing: Repair well: X Plugging: Time extension: Stimulate: Change approved program: Pull tubing: X Variance: 'Perforate: X Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 106' RT above MSL feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: Trading Bay Unit 4. Location of well at surface ~ ~ v" 8. Well number 677' FSL & 1221' FWL of Sec. 6, T8N, R13W, SM Dolly Varden D-8RD At top of productive interval 9. Permit nu, j'nber 1776' FSL & 631' FWL of Sec 8, T8N, R13W, SM 74-3 ~ At effective depth 10. APl number ""%~'~ -o~(~\~ '- 1698' FSL & 792' FWL of Sec 8, T8N, R13W, SM ,50~ At total depth 11. Field/Pool 1642' FSL & 851' FWL of Sec 8, T8N, R13W, SM McArthur River/Hemlock Pool 12. Present well condition summary . Total depth: measured 12398 ~' feet Plugs(measured) ORiGiNAL true vertical 10149 '/' feet ~'" ~'~ ~ I V Effective depth: measured 12105 feet Junk (measured) None i:': i!i;.i ~s~¢') ,.~.~ 2000 true vertical 9882 feet Casing Length Size Cemented Measu red depth True vertic~~g.3 Structural Conductor Surface 2533' 13-3/8" 2350 sx 2533' 2371' Intermediate Production 8733' 9-5/8" 2350 sx 8733' 6760' Liner 3817' 7" 1400 sx 12385' 10137' Perforation depth: measu red 11655'-11665', 11688'-11775', 11784'-11804', 11870'-11910', 11920'-11976', 12030'-12060' true vertical 9452'-9462', 9486'-9570' , 9578'-9598', 9661'-9700', 9709'-9762', 9813'-9841', Tubing (size, grade, and measured depth) 4-1/2" 12.6#, N-80 @ 8452, 3-1/2", 9.3#, N-80 @ 11531' Packers and SSSV (type and measured depth) Giberson AL perm packer @11470' 4-1/2" Otis DC tubing retrievable SSSV @ 300' 13. Attachments Description summary of proposal: x Detailed operations program: BOP sketch: x 14. Estimated date for commencing operation 15. Status of well classification as: 3/20/00 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver Date approved Service: 17. I hereby_.c.certif~ that the foregoing is true and correct to the best of my knowledge. Signed: ~ ~ Dan Williamson Title: Drilling Manager Date: FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IA""r N Plug integrity~ BOP Test'"~ Location clearance Mechanical Integrity Test Subsequent form required 10- ORIGINAL SIGNEDBY Robert N. Christenson Approved by order of the Commissioner Commissioner Date ----- "' Form 10-403 Rev 06/15/88 ^FE #140086 SUBMIT IN TRIPLICATE UNOCAL Dolly Varden Well #D-8RD Rig Workover Proposed Workover Procedure Objective: The objective of the workover on D-8RD is to add G zone production and isolate part of the current Hemlock Bench 2 productive interval: The well is currently a producer in the Hemlock Benches 1 through 5. The lower part of the HB-2 perforations produce large amounts of water. The upper portion of the HB-2 perforations produce a large quantity of oil and unfortunately, there is no blank interval of casing between the upper and lower HB-2 perforations. The proposed workover will remove the tubing and packer and clean out fill below the lowest HB-5 perforations. A cement squeeze will be pumped to isolate current HB-2 perfs. After the cement is drilled out, a scab isolation packer assembly will be installed to enhance the chances of achieving isolation of the lower part of HB-2. The upper scab packer will have to be set in perforations. New 4-1/2" by 3-1/2" tubing with gas lift mandrels will be run. After the rig workover, the G-2 through G-4 intervals will be perforated and the well will be placed on production. Eventually, the upper HB-2 will be reperforated. Proposed Workover Procedure: 1. Shut-in production. 2. Cut tubing above packer at 11465'. 3. Load tubing and annulus with 3% KCL water. 4. Pressure test wellhead. 5. Install back pressure valve. ND tree. Move in rig. 6. NU BOPE, pull BPV and install 2-way check. Test BOPE to 3000 psi/250 psi with 24 hr notice given to AOGCC for witness. 7. Pull 2-way check valve. Engage tubing hanger with landing joint. 8. Pull tubing 10' and monitor well, circulate 3% KCL down tubing and up annulus (1-1/2 well volumes) to ensure well is clear of gas. 9. POOH laying down tubing. 10. RIH with mill on washpipe extension and drill up packer at 11470'. POOH with mill. 11. RIH with tubing stub overshot and retrieve packer. A].~s,~ 12. RIH with mill and watermelon mill. Clean out fill below lowest perf at 12060'. 13. If necessary, set storm packer and replace wellhead. POOH with storm packer and clean out assy. 14. RIH with drillable bridge on E-line. Set bridge plug at 11780' between HB-2 and HB-3 perfs. 15. RIH with EZSV cement retainer on drill pipe. Set retainer at 11600'. Pump cement squeeze into HB-2 and HB-1 perfs. AOGCCprocD-8rd.doc 2/25/00 Dolly Varden Well #D-8RD Rig Workover 16. Unsting from retainer and PooH with drill pipe. WOC if necessary. 17. RIH with mill and drill up retainer at 11600' and cement down to bridge plug at 11780'. 18. Pressure test cement squeeze to 1000 psi. 19. Repeat squeeze and drill out if necessary. 20. Drill up bridge plug at 11780' after satisfactory squeeze is obtained. 21. POOH with mill. 22. RU E-line. MU lower isolation packer. Set lower packer at 11780' in blank 7" liner between HB2 and HB-3 perforations. 23. RIH with upper isolation and 3-1/2" scab liner. Stab into lower packer and set upper packer at 10720' (in middle of HB-2 perforated interval) 24. RU E-line and set production packer at 11050'. 25. Run 4-1/2" x 3-1/2" completion with GLMs and 4-1/2" SSSV. Stab into production packer, space out and land hanger. Pressure test SSSV control line. .' 26. ND BOPE, install and test tree. Release rig. 27. RU E-line unit. Perforate G zone as follows with through tubing guns: G-2 11193'-11207' G-3 11251'-11283' G-4 11317'-11342' G-5 11434'-11454' 28. Evaluate production results. Reperforate and add new perforations to Hemlock as follows: HB-1 11652'-11675' HB-2 11695'-11700' HB-3 11785'-11802' HB-4 11920'-11940' HB-4 11993'-12003' (11652'-11655' is new) (11993'-12003 is new) RECEIVED 0il & G~s Cons. C0t~,~ssi0n Anchorage AOGCCprocD-8rd.doc 2/25/00 UNit:ALe RKB to TBG Head = 41.00' Tree connection: .000# DVT @ 5517' I. 7 8 18 20 B-1 B-2 B-3 B-4 B-5 PBTD [] 12,105'TD = 12,398' HOLE ANGLE = 49°, KOP @ 600' D-SrdSchm 10-8-80.doc SIZE ,, ,)Trading Bay Unit '"~/Well # D-8RD Last Workover 10/80 CASING AND TUBING DETAIL WT GRADE CONN ID TOP BTM. 13-3/8" 9-5/8" 7" Tubing: 4-I/2" 3-1/2" 61.0 K-55 Butt. LT&C 12.515 Surf 2,518' 40 N-80 Buttress 8.835 Surf 5,851' DV collar 5,517' 5,519' 43.5 N-80 Buttress 8.755 5,851' 7,998' 47 N-80 Buttress 8.681 7,998' 8,733' 29 N-80 8rd LT&C 6.184 8,568' 12,385' 12.6 N-80 ASL 3.958 Surf 8452' 9.20 N-go ASL · 2.992 8452' 11,531 ' NO. Depth 0 1 30o 2 2,260' 3 3,864' 4 5,275' 5 6,454' 6 7,541' 7 8,406' 8 8,452' 9 9,129' 10 9,641' 11 10,070' 12 10,410' 13 10,777' 14 11,081' 15 11,360' 16 11,433' 17 11,470' 18 11,473' 19 11,497' 20 11,531' ZONE B-1 B-2 B-3 B-4 B-5 ~.11 Tagged on 12/93 @ FISH: 22" x 1.95" Brass Prong, 12/93 GL Valve, 8/87 19' of Wireline tools, 7/84 JEWELRY DETAIL ID Item 2.122 Tubing hanger, 4-1/2 ASL x 4-1/2 ASL, Type F 4-1/2" Otis DC TRBV w/3.813" "X" profile Loked out Baker XVE WLR SCSS 3.89 4-1/2" MMG GLM #1 w/AT H-CF Valve w/RK Latch 3,89 4-1/2" MMG GLM #2 w/AT H-CF Valve w/RK Latch 3.89 4-1/2" MMG GLM #3 w/AT H-CF Valve w/RK Latch 3.89 4-112" MMG GLM g4 w/AT H-CF Valve wi RK Latch 3.89 4-1/2" MMG GI.M #5 w/AT H-CF Valve w/RK Latch 3.89 4-I/2" MMG GLM g6 w/AT II-CF Valve w/RK Latch 2.87 Crossover, 4-1/2"ASL X 3.1/2" ASL 2.87 3-1/2" KBUG GLM #7 w/CM1-BK valve w/BK Latch 2.87 3-1/2" KBUG GLM #8 w/CMI-BK-PB vlv w/BK Latch 2.87 3-1/2" KBUG GLM g9 w/CMI-BK-PB vlv w/BK Latch 2.87 3-I/2" KBUG GLM #10 w/CMI-BK-PB vlv w/BK Lteh 2.87 3-1/2" KBUG GLM #11 w/CMI-BK-PB vlv w/BK Lteh 2.87 3-1/2" KBUG GLM #12 w/CMI-BK-PB vlv w/BK Ltch 2.87 3-1/2" Camco K. BUG GLM #13 w/Macco CMI-24/64" orifice wi BK Latch 2.75 3-1/2" Otis "XA" Sldg Sleeve Guiberson AL Perm. Pkr. w/5' Seal bore ext. (DIL) Guiberson Locator & Seal Assy. Otis "X" Nipple 1/2 Cut Mule Shoe 2.75 PERFORATION DATA TOP BTM SPF DATE 11,655 l 1665 4 8/2/74 11,688 11,695 4 8/26/88 11695 11738 12 8/74,3/76,12/87,8/88 11738 11758 ' 8 8/74, 12/87 11758 11775 12 8/74, 12/87, 8/88 11784 11804 16 8/74,12/87,8/88 11870 11910 8 11/80, 8/81 11920 11936 12 8/74, 11/80, 8/81 11936 11976 8 11/80, 8/81 12030 12045 12 8/74, 11180, 8/81 12045 12055 4 7/74 12055 12060 6 7/23/74, 7/31/74 12120 12125 2 7/21/74 (squeezed) 11,926' WLM 11,926' WLM 11,960' WLM 12,060' CTM REC.F. IV.K:D REVISED: 2/25100 DRAWN BY: SLTfrAB UNKAL RKB to TBG Head = 41.00' Tree connection: 000~ 5 6 7 8 9 16 18 Prop G-2 ~ thru G-5 / B-1 19 / B-2 21 ~ B-3 ~ ~ B-4 ~ B-5 PBTD = 12,105'TD = 12,398' MAX HOLE ANGLE = 49°, KOP @ 600' ~rading Bay Unit x~/Well # D-8RD SIZE .WT Proposed March 2000 Workover CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 13-3/8" 9-5/8" 7" 4-1/2" 3-1/2,, 61.0 4O 43.5 47 29 12.6 9.20 K-55 Butt. LT&C 12.515 Surf 2,518' N-80 Butt~ss 8.835 Surf 5,851' DV collar 5,517' 5,519' N-80 ButWess 8.755 5,851' 7,998' N-80 Buttress 8.681 7,998' 8,733' N-80 8rd LT&C 6.184 8,568' 12,385' N-80 ASL 3.958 Surf 8452' N-80 ASL · 2.992 8452' 11,531' NO. 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 · 18 19 20 21 22 23 JEWELRY DETAIL Depth 0 3oo 2,260' 3,864' 5,275' 6,454' 7,541' 8,406' 8,452' 9,129' '9,641' 10,070' 10,410' 10,777' 11,0oo' 11 ,o50' 11,o5o' .11,090' 11,120' 11,720' 11,780' 11,820' 11,850' ZONE m 2.122 3.89 3.89 3.89 3.89 3.89 3.89 2.87 2.87 2.87 2.87 2.87 2.87 2.87 2.813 Item Tubing hanger, 4-1/2 8rd x 4-112 buttress 4-1/2" Otis DC TRBV w/3.813" "X" profile Loked out Baker XVE WLR SCSS 4-1/2" MM(} (}LM #1 w/AT II-CF Valve w/RK Latch 4-1/2" MM(} GLM #2 w/AT II-CF Valve w/RK Latch 4-1/2" MMG (}LM #3 w/AT II-CF Valve w/RK Latch 4-1/2" MM(} GLM g4 w/AT II-CF Valve w/RK Latch 4-1/2" MM(} (}LM #5 w/AT II-CF Valve w/RK Latch 4-1/2" MM(} (}LM 06 w/AT Il-CF Valve w/RK Latch Crossover, 4-1/2"butt X 3.1/2" butt 3-1/2" KBU(} (}LM #7 w/CM1-BK valve w/BK Latch 3-1/2" KBU(} (}LM #8 w/CMI-BK-PB vlv w/BK Latch 3-1/2" KBU(} (}LM 09 w/CMI-BK-PB vlv w/BK Latch 3-1/2" KBUG GLM #10 w/CMI-BK-PB vlv w/BK Itch 3-1/2" KBU(} (}LM #11 w/CMI-BK-PB vlv w/BK Ltch 3-1/2" Camco KBU(} GLM #12 w/Macco CMI-24/64" orifice wi BK Latch Baker Locator & Seal Assy. Baker F-I 7" Perm Packer (wireline set) 3-1/2" "X' Nipple, 2.813" ID WLF_~, tubing tail Baker FB-1 packer, top isolation packer 3-1/2" scab liner, 11720'-I 1780' Baker F-1 packer, bottom isolation packer 3-1/2" X nipple, 2.813" ID 3-1/2" tubing tail, WLE(} PERFORATION DATA TOP BTM SPF D~TE B-I 11,655 11665 4 B-2 11,688 I 1,695 4 11695 11738 12 11738 11758 8 11758 11775 12 B-3 11784 11804 16 B-4 11870 11910 8 11920 11936 12 11936 11976 8 B-5 12030 12045 12 12045 12055 4 12055 12060 6 12120 12125 2 8/2/74 8/26/88 8/74,3/76,12/87,8/88 8/74, 12/87 8/74, 12/87, 8/88 8/74,12/87,8/88 11/80, 8/81 8/74, 11/80, 8/81 11/80, 8/81 8/74, 11/80, 8/81 7/74 7/23/74, 7/31/74 7/21/74 (squeezed) Fill Tagged on 12/93 ~ FISH: 22" X 1.95" Brass Prong, 12/93 GL Valve, 8/87 19' of Wireline tools, 7/84 II,926'WLM ll,926'WLM ll,960'WLM 12,060'CTM RECEIVED REVISED: 2/25/00 D-Srd proposed WO.doc DRAWN BY: TAB 20' 18'-7" 18' RIG FLOOR BTM RT BEAM BOTTOM ROTARY TABLE PITCHER NIPPLE BOTTOM TROLLEY BEAM TO TRIP TANK~ ~ TO FLOW LINE RISER I 17' HYDRIL 13-5/¢ GK ,N ANNULUR PREVENTEF CHOKE CELLAR FLOOR DRILL DECK iI II 13-5/8" SM DOUBLE GATE BOP ()TOP PIPE RAM BLIND FLOOR ~9 13- "x 11" ~ 5M CROSSOVER SPOOL ~ i ..= DOLLY VARDEN PLATFORM COOK INLET, ALASKA CONTRACTOR I CONTIR. dOB NO. SDL DOLLY VARDEN PLATFORM BLOW OUT PREVENTER D-8RD I~AWINO NO. .,s UNOCALe D-DV-01 5 /30/98 ~ 1 OF 1 Unocal North Americ; Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: I have attached surface survey locations of the "LegS" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, Gar~ S. (~ush Regi%nal Drilling Manager GSB/lew DOLLY DISTANCE & DIRE. C. TI.ONS FROM SE cORNER SEC. 6, TSN, R13W CONDUCTOR LEG ~/A- 1: LAT: 60048, 28.272" LONG =151°37' 57.620" "Y" COORD. "X" COORD. WELL # FSL 2,490,836.22 208,461.20 757.5 1 2 3 4 5 6 7 8 9 10 ll 12 2,490,836.95 208,454.55 D-27 758.1 2,490,840.99 208,456.66 D-28 762.1 2,490,842.79 208,460.79 D-29 764.0 2,490,841.51 208,465.11' .D-32 762.9 .2,490,837.76 208,467.60 D-40 759.2 2,490,833.28. 208,467.10 D-41 754.7 2,490,830.18 208,463.83 D-26 751.5 2,490,829.90 208,459.34 D-25 & RD 751'.1 2,490,832.58 208,455.72 753.7 2,490,835.56 208,458.66 D-24 & 34A 756.8 2,490,838.66 208,462.17 D-31 & RD 760.0 2,490,834.00 208,462.61 D-24A 755.3 LEG ~A-2' 1 2 3 4 5 6 7 8 9 10 11 12 LEG" ,~B-I' LAT = 60°48' 27.485" LONG =151°37' 57.564" 2,490,835.42 208,381.20 754.7 2,490,836.16 208,374.66 D-1 755.3 2,490,840.19 208,376.67 ' D-17 759.4 2,490,842.00 208,380.80 D-11 761.3 2,490,840.72 208,385.11 D-7 & RD 760.1 2,490,836.97 208,387.60 D-9 756.4 2,490,832.49 208,387.10 D-19 751.9 2,490,829.39 208,383.84 D-23 748.8 2,490,829.11 208,379.34 D-21 748.4 2,490,831.78 208,375.72 ' D-5 & RD 750.9 2,490,834.77 208,378.66 D-15 & RD ~& 2 754.0 2,490,837.86 208,382.17 D-3 & RD 757.2 2,490,833.21 208,382.61 D-13 752.5 2,490,756.22 208,462.00 " 677.5 1 2 3 4' 5 6 7 8 9 l0 11 12 LEG #B-2: 2,490,755.48 208,468.53 D-8 & RD 677.0 2,490,751.45 208,466.53 D-6 672.9 2,490,749.65 208,462.40 D-14 & RD 671.0 2,490,750.92 208,458.08 D-20 672.1 2,490,754.67 208,455.59 D-16 675.8 2,490,759.15 208,456.10 D-22 680.3 2,490,762.25 208,459.36 D-2 & A & RD 683.5 2,490,762.53 208,463.85 D-4 683.9 2,490,759.86 208,467.48 D-10 681.3 2,490,756.87 208,464.53 D-12 & RD 678.3 2,490,753.78 208,461.02 D-18 675.1 2,490,758.43 208,460.58 D-30 & RD 679.7 2,490,755.43 208,382.00 (Reserved for Compressors) 674.8 FWL 1212 '0 1205.5 1207.4 1211.5 1215.8 1218.4 1218.0 1'214.8 1210.3 1206.7 1209.5 1213.0 1213.5 1132.1 1125.5 1127.4 1131.5 1135.9 1138.5 1138.1 1134.9 1130.4 1126.7 1129.6 1133.0 1133.6 1214.8 1221.4 1219.5 1215.4 1211.1 1208.5 1 208.9 1212.1 1216.5 1220.2 1217.4 1213.9 1213.4 1134.9 STATE OF ALASKA AL~A OIL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging Perforate x_._ Pull tubing ~ Alter casing __ Repair well ~ Pull tubing __ Other ~ 2. Name of Operator ' ! 5. Type of Well: 6. Datum elevation (DF or KB) UNOCAL (Marathon Oil Co - Sub Operator) Development Ix 106' KB above MSL / Exploratory __ 3. Address Stratigraphic__ 7. Unit or Property name P.O. Box 190247 Anchorage, AK 99~19 Service__ Tradin~ Bay Unit / 4. Location of well at surface Leg B-1 Cond. #1 Dolly 677' FSL, 1,221' FW%, Sec. 6-SN-13W-SM At top of productive interval 1,776' FSL, 631' FWL, Sec. 8-8N-13W-SM At effective depth 1,698' FSL, 792' FWL, Sec. 8-8N-13W-SM At total depth 1,642' FSL, 851' FWL, Sec. 8-8N-13W-SM Varden Platform 8. Well number D-8RD feet 9. Permit number/approval number 8-647 10..APl number 50-- 733-20187-01 11. Field/Pool Hemlock 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 2,533' Intermediate Production 8,733 ' Liner 3,817' Perforation depth: measured true vertical 12,398' feet 10,149 bet 12,105' ~ 9,882' feet Plugs (measured) Junk (measured) Size Cemen~d 13 3/8" 2,350 sx 9 5/8" 2,350 sx 7" 1,400 sx See Attachment #1 GL Mandrel "Fish" @ 11,96 WLM- 10' slickline tools Fish at 12,074' CTM Measured depth True vertical depth 2,533' 2,371' 8,733' 6,760' 12,385' 10,137' ~bing(size. grad~and measumddepth) 4 1/2", N-80 @ 8,452" PackersandSSSV(typeand measumddepth) AL Packer @ 11,470' DC 3 1/2", N-80 TRBV @ 300' @ 11,531' RECEIVI D JAN ! 7 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or I niection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 8/24/88 124 32 Subsequent to operation 9/27/88 681 316 935 1030 5191 1280 Tubing Pressure 180 28O 15. Attachment~ ¢f2 Copies of Logs and Surveys run __ Daily Report of Well Operations x_.. 16. Status of well classification as: Oil x_._ Gas_ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date 1/9/89 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Bench 1 Bench 2 Bench 3 Bench 4 Bench 5 ATTACHMENT #1 Well D-8RD Perforations 11,655' - 11,665' MD 11,688' - 11,775' MD 11,784' - 11,804' MD 11,870' - 11,910' MD 11,920' - 11,976' MD 12,030' - 12,060' MD 9,452' - 9,462' TVD 9,486' - 9,570' TVD 9,578' - 9,598' TVD 9,661' - 9,700' TVD 9,709' - 9,762' TVD 9,813' - 9,841' TVD NEF/em/33A/DVP Attachment #2 TBU Well D-8RD Daily Summary of Operations 8/26/88 RU wireline and PT to 2500 psi, OK. RIH w/ 2.70" gauge ring and tag fill @ 11,929' WLM. POH, RD. 8/27/88 RU E-line and PT to 2500 psi, OK. Made two perforating runs using 2-1/8" Enerjet II, 4 SPF, 0° phasing, 13.5 gm charge perforating guns. Correlated and perforated Bench 3 from 11,784' to 11,804' DIL and Bench 2 from 11,758' to 11,775' DIL. Flowed well after each perforating run. SI well and POH. 8/28/88 Made two perforating runs using same guns as before. Correlated and perforated Bench 2 from 11,708' to 11,738' and 11,688' to 11,708' DIL . Flowed well after each perforating run. POH, RD, and put well back on production. The proposed scale inhibition treatment was not performed at this time. 33A/DVP STATE OF ALASKA ALAS~' OIL AND GAS CONSERVATION COM~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend . ' Operation Shutdown , ~ Re-enter suspended well ~ Alter camng r-~ Ttme extension Change approved program Plugging '~. Stimulate ' Pull tubing Amend order .r Perforate Gl Other 2 Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3 Address P.O. Box 190247 Anchorage, AK 99519 4. Location of well at surfaceLeg B-1 Cond. #1 Dolly Varden Platform 677' FSL, 1,221' FWL, Sec. 6-8N-13W-SM At top of productive Interval 1,776' FSL, 631' FWL, Sec. 8-8N-13W-SM At effective depth 1,698' FSL, 792' FWL, Sec. 8-8N-13W-SM At total depth 1,642' FSI,, 851' FWL, Sec. 8-SN-13W-$M 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trading Bay Unit 7. Well number D-SRD 8. P~_i~ number 9. APl nu~5~§r20187_O1 50-- 10..P~elmlock feet 11. Present well condition summary Total depth: measured true vertical 12,398' feet Plugs (measured) 10,149 feet Effective depth: measured 12,105' feet true vertical 9,882' feet Casing Length Size Structural Junk(measured) GL Mandrel "Fish" @ 11,96 WLM - 10' slickline tools Fish at 12,074' CTM Cemented Measured depth ~ueVerticaldepth Conductor Surface 2,533' 13 3/8" Intermediate 2,350 sx 2,533' 2,371' Production 8,733' 9 5/8" Liner 3,817' 7" Perforation depth: measured true vertical 2,350 sx 8,733' 6,760' 1,400 sx 12,385' 10,137' ,~',u~ 2 , ]988 Alaska Oil & Cas Cons. ~chorage See Attachment #1 Tubing (size, grade and measured depth) 4 1/2", N-80 @ 8,452' 3 1/2", N-80 @ 11,531' Packers and SSSV (type and measured depth) AL Packer @ 11,470' DC TRBV @ 300' 12.Attachments 2 & 3 Description summary of proposal ~ Detailed operations program [~ BOP sketch 13. Estimated date for commencing operation August 1988 14. If proposal was verbally approved Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Env~ ronmenta! Engin~r Ro~. Ro~_rts Commission Use Only Conditions of approval Approved by Form 10-403 Rev 12.1-85 Date Notify commission so representative may witness ~ Plug integrity [] BOP TestAp~roVeC~t~)(~pC~earance LONNIE C. SMITH ~ Commissioner Approval No. g?,~ ~ ¢'~ by order of ~ ~;~,~) the commission Date -' Submit in triplicate Bench 1 Bench 2 Bench 3 Bench 4 Bench 5 ATTACHMENT #1 Well D-8RD Perforations 11,655' - 11,665' MD 11,695' - 11,775' MD 11,784' - 11,804' MD 11,870' - 11,910' MD 11,920' - 11,976' MD 12,030' - 12,060' MD 9,452' - 9,462' TVD 9,491' - 9,570' TVD 9,578' - 9,598' TVD 9,661' - 9,700' TVD 9,709' - 9,762' TVD 9,813' - 9,841' TVD MDC/em/33A/Sundry Attachment # 2 Well D-8RD Reperforation Procedure A. Perforate 1. RU WL. PT to 2500 psi. 2. RIH and pull 4-1/2" DKX ball valve. POH. 3. RIH w/3.47 gauge ring to 8452'. POH. 4. RIH w/ 2.70 gauge ring and tag fill. POH. 6. RU E-line. PT to 2500 psi. 7. Perforate the following intervals w/2-1/8" strip guns, 4 SPF, 20° phase angle, and 500 psi drawdown: Run Interval (DIL) Feet Zone 1 11,784' - 11,804' 20 2 11,758' - 11,775' 17 3 11,708' - 11,738' 30 4 11,688' - 11,708' 20 Bench 3 Bench 2 Bench 2 Bench 2 Test well for 12 hours after stabilized, continue perforating if total oil rate is less than 500 BOPD. 5 11,870' - 11,900' 30 6 11,655' - 11,665' 10 Bench 4 Bench 1 8. RD E-line. Note: Bring well on slowly and obtain a stable production test. Flow well for 3 days prior to placing D-8RD on a scale inhibition program. R C El B. Scale Inhibition Treatment ~-' '"' ...... 1. RU pumping equipment to D-8RD tree. PT to 5000 psi. A~z..s~;~a 0il & Oas C0n~. C0mm]ss]0fl An0h0rags 2. Mix and pump scale inhibitor as follows: Stage 1. Stage 2. Stage 3. Stage 4. Stage 5. 50 bbl FIW (established injection rate) 52 bbl FIW w/2.5% phosphonate preflush (55 gal Scaletreat 194/4) 25 bbl FIW spacer 225 bbl FIW containing 2750 lbs of sodium chloride w/ 10% inhibitor (1155 gal Scaletreat ESL 19P) 850 bbl FIW overflush Attachment # 2 Well D-8RD Reperforation Procedure (Continued) Treatment to be pumped at 2 BPM max, if possible. Surface pressure to be kept below 3000 psi to avoid fracturing the reservoir. 3. RD pumping equipment and shut in D-8RD for 24 hours. 4. Bring well on slowly to test. Start lift gas at lowest rate necessary to lift well. Work up to a full lift gas rate of 3.1MMSCFD over a 24 hour period. 5. A Western Wellchem engineer will take fluid samples hourly for the first 24 hours to monitor residuals. Two to four samples will be taken for the remainder of the week. After one week, samples will be taken once a week for the remainder of the month. After one month, a fluid sample should be taken monthly and sent to Wayne Cissell. 6. A gauge ring will be run every three to four months to monitor inhibitor effectiveness. 7. RU wireline. Presure test to 2500 psi. 8. RIH w/ 4-1/2" DKX ball valve. 9. POH. RD. Note: Maximum anticipated bottomhole pressure is 2000 psi. em/836/OE33 ~E~acnmen~ ~ ~LLY VARDEN PLA~J=ORM Wireline Lubricator w/Associated BOPE ------- GREASE HEAD (Hydraulically Activated) , , LUBRICATOR MANUALLY OPERATED BOP 4 1/16', 5000 psi CHISTMAS TREE "'~ '"'--~I~-----~(~'~T~---- 2' 5000 psi POSITIVE CHOKE 13 3/8' CASING _.-- 2' 3000 psi STATE OF ALASKA ALASE,,-.OIL AND GAS CONSERVATION COMM'--~ION REPORT OF SUNDRY WELL OPERATIONS 1. OCerations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Location ofwellatsurface Leg B-1Cond. #1 Dolly Varden Platfor 677' FSL, 1,221' F-W~, Sec. 6-SN-13W-SM Attop of productiveinterval 1,776' FSL, 631' ~'Ar[,, Sec. 8-8N-13W-SM Ateffective depth 1,698' FSL, 792' ~-~L, Sec. 8-8N-13W-SM Attotaldepth 1,642' FSL, 851' FWL, Sec. 8-8N-13W-SM 5. Datum elevation (DF or KB) 106' KB above MSL Feet 6. Unit or Property name 7. Well number D-SRD 8. Approval number 7-903 9. APl number ~7 50-- 733-201~7-01 10. Pool Hemlock 11. Present well condition summary Total depth: measured true vertical 12,398' feet Plugs (measured) 10,149 feet Effective depth: measured 12,105 ' feet true vertical 9,882 ' feet Casing Length Size Structural Junk(measured) GL Mandrel "Fish" @ 11,9( WLM- 10' slickline tool~ 07'C Cemented Measured de~p:~h at 12T.?Je ~rtica~depth Conductor Surface 2,533' 13 3/8" 2,350 sx 2,533' 2,371' Intermediate Production 8,733' 9 5/8" Liner 3,817' 7" Perforation depth: measured true vertical 2,350 sx 1,400 sx See Attachment #1 ~bing(size, grade and measured depth) 4 1/2", N-80 @ 8,452' 3 1/2", N-80 @ 11,531' Packers and SSSV(type and measured depth) AL Packer @ 11,470' DC TRBV @ 300' 8,733' 6,760' 12,385' 10,137' ' ~,.~¢ ~ ~ ~ 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 11/16/87 267 3 1514 1125 psi Subsequent to operation 12/26/87 470 323 3963 1240 psi Tubing Pressure 205 psi 180 psi 14. Attachment~ ~'/2 Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signe~ KO,,V D. Roberts Title Environmental Enaineer Form 10-404 Rev. 12-1-85 ,-AC. Date 1/B/88 Submit in Duplicate Z' Bench 1 Bench 2 Bench 3 Bench 4 Bench 5 ATTACHMENT #1 Well D-8RD Perforations 11,655' - 11,665' MD 11,695' - 11,775' MD 11,784' - 11,804' MD 11,870' - 11,910' MD 11,920' - 11,976' MD 12,030' - 12,060' MD 9,452' - 9,462' TVD 9,491' - 9,570' TVD 9,578' - 9,598' TVD 9,661' - 9,700' TVD 9,709' - 9,762' TVD 9,813' - 9,841' TVD MDC/em/33A/Sundry Attachment #2 TBU Well D-8RD Daily Summary of Operations 12/4/87 RU wireline, PT lubricator to 2500 psi. MU 30' of dummy guns. RIH, tag bottom @ 11,960', POOH. MU 20' of 2-5/8" hollow carrier guns, 4 SPF, O* phasing. RIH, tag bottom @ 11,960'. Flow well, PU and set CCL and perf Bench 3 from 11,784' to 11,804' DIL. SI, POOH, and put well on test. 12/5/87 RU wireline, PT lubricator. RIH w/2-5/8" hollow carrier guns, 4 SPF, 0© phasing. Correlate and perf Bench 3 from 11,784' to 11,804' DIL.' SI, POOH. RD and put well on test. 12/8/87 RU wireline, PT lubricator. RIH w/2-5/8" hollow carrier guns, 4 SPF, 0~ phasing. Correlate and perf Bench 2 from 11,745' to 11,775' DIL. SI, POOH. 12/9/87 RU and RIH w/2-1/8" strip guns, 4 SPF, 0° phasing. Correlate and perf Bench 2 from 11,715' to 11,745' DIL. POOH. MU guns as above, RIH, guns stuck. Pull out of rope socket, POOH. RD wireline and RU 2-5/16" x 1-3/8" overshot. RIH, latch fish, pull free, POOH. Disarm guns, RD, put well on test. WO further wireline work. 12117187 RU wireline, PT lubricator. RIH w/3.47 gauge ring. Tagged XO @ 8,443' WLM. POOH. RIH w/2.72 gauge ring. Tagged fill @ 11,941'. POOH. RU. BHP inst. RIH. 12/18/87 Stabilize well and take FBHP survey. POOH. RIH w/4-1/2" DK ball valve to 300' WLM. Set BV, POOH. RD. NEF/em/33A/Sundr2 STATE OF ALASKA AL~A OIL AND GAS CONSERVATION cO-~ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator UNOCAL (Marathon 0il Company, Sub-operator) 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Locationofwellatsurface Leg B-l, Cond. #1 Dolly Varden Platfoz 677' FSL, 1,221' FWL, Sec. 6-8N-13W-SM Attop of productiveinterval 1,776' FSL, 631' ~, Sec. 8-8N-13W-SM Ateffective depth - 1,698' FSL, 792' FWL, Sec. 8-8N-13W-SM Attotaldepth 1,642' FSL, 851' FWL, Sec. 8-8N-13W-SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Tr~d~ R~v II~t m 7. Well number D-8RD 8. Permit number 74-3 9. APl number 50-- 733-20187-0,Z! feet 10. Pool Hemlock 11. Present well condition summary Total depth: measured true vertical 12,398' feet Plugs (measured) 10,149 ' feet 12,105' Cl~ Effective depth: measured 12,105' true vertical 9,882' feet Junk (measured) feet 11,962' GL Valve 12,079' Slickline Fish Casing Length Structural Size Cemented Measured depth True Vertical depth Conductor Surface 2,533 ' Intermediate 13 3/8" 2,350 sx 2,533' 2,371' Production 8,733' Liner 3,817' Perforation depth: measured 9 5/8" 2,350 sx 7" 1,400 sx 12 See Attachment #1 ~~~ true vertical Tubing (size, grade and measured depth) 4 1/2" 12.6# N-80 ASL Tbg. @ 8,452', 3 1/2" 9.2# N-80 ASL Packers and SSSV (type and measured depth) Guiberson A1 Packer @ 11,470' 8,733' 6,760' ¢~ 5, G~,s Cons. CommiSslo~ Anchof~Oue Tbg. from 8,452' to 11,53 ' w/5" SBE, 4-1/2" WLR-SSSV - DFC( (2.00" ID) @ 300' 12.Attachments~ #2 Description summary of proposal ~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation November 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby~certify that the_foreg,ping is true and correct to the best of my knowledge Signed ~~1/',~¢..~.,¢,._~ Title Environmental Specialist Date 11/17/87 Candace ~¢'-. Loctkwood~r~ · --[' Comm~§Sion Use Only Conditions of approval NEtify'" commission so representative may witness I Approval No...~ [] Plug integrity [] BOP TestAp~r~,~t~§l:~earance Returned by order of ',/ Approved by ~,,.,-- Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplica/~ Bench Bench 2 Bench 3 Bench 4 Bench 5 ATTACHMENT #1 Well D-SRD Perforations 11,655' - 11,665' MD 11,695' - 11,775' MD 11,784' - 11,804' MD 11,870' - 11,910' MD 11,920' - 11,976' MD 12,030' - 12,060' MD 9,452' - 9,462' TVD 9,491' - 9,570' TVD 9,578' - 9,598' TVD 9,661' - 9,700' TVD 9,709' - 9,762' TVD 9,813' - 9,841' TVD NEF/em/33/Sundr2 Attachment #2 Well D-8RD Procedure 1. RU Otis wireline, PT lub. to 2,500 psi. 2. RIH and pull 4-1/2" WLR SSSV at 300'. 3. Make up 2.72' GR. PT to 2,500 psi. 4. RIH and cut scale as necessary. Tag bottom, POH. 5. Make up dual Amerada bombs. PT to 2,500 psi (3,500 psi Element, 6 or 12 hour clock). 6. RIH, stabilize well production. 7. Measure FBHP at 11,652' (9,450' TVD). 8. POH, RD Otis. 9. RU E-line, PT to 2,500 psi. 10. Perforate underbalanced or flowing and test the following zones as indicated using either 2-5/8" hollow carrier guns or 2-1/8" strip guns, 4 SPf, 0° phasing. Choice of guns will be based on earlier gauge ring runs. Run Interval (DIL) Feet Zone 1 11,784' - 11,804' 20 B3 Test well for 12 hours after stabilized, continue perforating if total oil rate is less than 500 BOPD. 2 11,745' - 11,775' 30 B2 3 11,715' - 11,745' 30 B2 4 11,695' - 11,715' 20 B2 Test well for 12 hours after stabilized, continue perforating if total oil rate is less than 500 BOPD. 5 11,870' - 11,900' 30 6 11,920' - 11,950' 30 7 11,950' - 11,976' 26 8 11,655' - 11,665' 10 11. RD E-line. 12. RU Otis WL, PT lub. to 2,500 psi. 13. Make up dual Amerada bombs (3,500 psi Element 6- or 12-hour clock). 14. RIH and stabilize well. Attachment #2 Well D-SRD (continued) 15. Measure FBHP at 11,652' (9,450' TVD). 16. POH. 17. Rerun 4-1/2" WLR SSSV at 300'. 18. RD Otis. 19. Otis will read both before and after flowing BHP. Data and chart will be sent to Rose Hamlin in Anchorage. A copy of the date will be sent to W. L. Browne in Nikiski. NEF/em/33/Sundr2 STATE OF ALASKA ~ ALAS,,,~. OIL AND GAS CONSERVATION COMk_,,/SION D~'C~ 8 REPORT OF SUNDRY WELL OPERATIO 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing ~"'~", Alter Casing [] Other [] 2. Name of Opera~tor UNOCAL 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Location of well at surface Leg B-i, Cond. ~1 Dolly Varden Platfo]: 677' FSL, 1,221' ~3~'L, Sec. 6-SN-13W-SM At top of productive interval 1,776' FSL, 631' FWL, Sec. 8-8N-13W-SM At effective depth 1,698' FSL, 792' 1~'~, Sec. 8-8N-13W-SM At total depth 1,642' FSL, 851' ~-~, Sec. 8-8N-13W-SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trading Bay Unit ~t 7. Well number D-SRD 8. Approval number 74-3 9. APl number 50-- 733-20187-01 10. Pool ' Hemlock Feet 11. Present well condition summary Total depth: measured true vertical 12,398' feet Plugs (measured) 10,149 feet Effective depth: measured 12,105' feet Junk (measured) true vertical 9,882 ' feet Casing Length Size Cemented Structural Conductor Surface 2,533' 13 3/8" 2,350 sx Intermediate Production 8,733' 9 5/8" 2,350 sx Liner 3,817' 7" 1,400 sx Perforation depth: measured See Attachment ~1 true vertical Tubing (size, grade and measured depth) 4 1/2", N-80 @ 8,452' 3 1/2", N-80 @ 11,531' Packers and SSSV (type and measured depth) AL Packer @ i1,470' DC TRBV @ 300' Measured depth True Vertical depth 2,533' 8,733' 12,385' 2,371' 6,760' 10,137' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 10/08/86 268 86 Subsequent to operation 11/13/86 337 108 Tubing Pressure 2411 1110 psig 230 psig 2474 1100 psig 170 psig 14. Attachments ~'/2 Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ra~h~il j;ompany - Sub Operator Signed 'Rb~ D. Roberts Title Environmental Engineer Date/.Z//~/~ Form 10-404 Rev. 12-1-85 Submit in Duplicate Bench 1 Bench 2 Bench 3 Bench 4 Bench 5 ATTACHMENT #1 Well D-8RD Perforations 11,655' - 11,665' MD 11,695' - 11,775' MD 11,784' - 11,804' MD 11,870' - 11,910' MD 11,920' - 11,976' MD 12,030' - 12,060' MD 9,452' - 9,462' TVD 9,491' - 9,570' TVD 9,578' - 9,598' TVD 9,661" - 9,700' TVD 9,709' - 9,762' TVD 9,813' - 9,841' TVD MDC/em/33/Sundry Attachment ~2 Daily Report of Well Operations Dolly Varden Well D-8RD ~o/25/86 1. RU coiled tbg unit and pressure test to 2,500 psi. 2. RIH w/Jetting tool to 8,450' and circulate hole w/FIW. 10/26/86 1. Mixed and pumped polymer while RIH. 2. Washed through tubing tail. Heaviest scale from 9,903' - 10,023'. 3. RIH to 11,600' and circulate. 4. POH w/ coiled tbg. 5. Returned well to production. 1112186 1. RU wireline w/2.65" gauge ring. 2. Pressure test lubricator to 2,500 psi. 3. RIH to 12,070' and POH. 4. Return well to production. MOC/em/33A/Sundry STATE OF ALASKA ALASi,_,'OIL AND GAS CONSERVATION COMN,,~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator 5. Datum.elevation(DF or KB) UNOCAL * 106' KB 3. Address 6. Uniter Property name P.O. Box 190247 Anchorage, AK 99519 Trading Bay Unit 4. Location of wellatsurface 677' FSL, 1,221' FWL, Sec. 6 - 8N - 13W - SM 7. Well number At top of productive interval 1,776' FSL, 631' F~, Sec. At effective depth 1,698' FSL, 792' FWL, Sec. At total depth 1,642' FSL, 851' FWL, Sec. 8 - 8N - 13W - SM 8 - 8N - 13W - SM 8 - 8N - 13W - SM 8. Permit number 74-3 9. APl number 50-- 733-20187-01 10. Pool Hemlock 11. Present well condition summary Total depth: measured true vertical 12,3 98 ' feet Plugs (measured) 10,149' feet Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation .depth: measured 12,105 ' feet Junk (measured) true vertical 9,882 ' feet Length Size Cemented Measured depth True Vertical depth 2,533' 13 3/8" 2,350 sx 2,533' 2,371' 8,733' 9 5/8" 2,350 sx 8,733' 6,760' 3,817' 7" 1,400 sx 12,385' 10,137' measured true verticalSee Attachment #1 RECEIVED Tubing (size, grade and measured depth) 4 1/2", N-80 @ 8,452' 3 1/2", N-80 @ 11,531' Packers and $$$V (type and measured depth) AL Packer @ 11,470' DC TR~V @ .300' 12.Attachments 1986 Description summary of proposal [] Detailed operations program [] BOP sketch [] See Attachment #2 13. Estimated date for commencing operation September 15, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 4~_.~' ~/~ ~ Title Date ( ~.~,~ Commission Use Only Conditions of approval Notify com"-~ission so representative may witness [] Plug integrity [] BOP Test [] Location clearance R~turn~d * Marathon Oil Company, Sub-Operator ORI~IH'~[ ~l~.qED Approved by BY [~f{~l[ C.. ~IlT[ Commissioner Approval N o.,~' ~)~.~, by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate Bench 1 Bench 2 Bench 3 Bench 4 Bench 5 ATTACHMENT #1 Well D-8RD Perforations 11,655' - 11,665' MD 11,695' - 11,775' MD 11,784' - 11,804' MD 11,870' - 11,910' MD 11,920' - 11,976' MD 12,030' - 12,060' MD 9,452' - 9,462' TVD 9,491' - 9,570' TVD 9,578' - 9,598' TVD 9,661' - 9,700' TVD 9,709' - 9,762' TVD 9,813' - 9,841' TVD MDC/em/089/OE 10 o Ar~e.l~orage Co~iSelo~ TBU WEll D-8RD Scale Cleanout ATTACHMENT #2 PROCEDURE It is Marathon's intention to remove tubing scale restrictions using coiled tubing on Well D-8RD during September 1986 by the .following procedure: 1) Rig up and pressure test coiled tubing and connections. 2) Run in hole with jet drilling tool using 1 1/4" coiled tubing. 3) Jet clean through tubing tail at 11,531', circulate clean. 4) Pull out of hole with coiled tubing and rig down. 5) Return Well D-8RD to production. MDC/em/089/OE10 RECEIVED $£P 1 0 1986 'Alaska 011 & Gas Cons. Commission Anchorage Union Oil and Gas ~' 'sion: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unl, n ~ebruary 14, 1985 Mr. C.V. Chatterton Ak. Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99502 Dear Mr. Chatterton: SUNDRY NOTICES D-17RD_,_ D_-il ,D'8RD Attached please find Sundry Notice Intentions for the following wells. D-17RD, D-Il, & D-8RD all Trading Bay Unit, McArthur River Field. Please return the approved Sundry Notice's to the undersigned. Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST. LOC/ti Attachments RECEIVED FEB 2 1 1985 Alaska Oil & Gas Cons. Commission Anchorage Union Oil and Gas Division' Western Region Union Oil Company ~alifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone' (907) 276-7600 union April 18, 1985 Hr. Chat Chatterton AK. Oil & Gas ConserVation Commission ~OO1Rorcupine Drive Anchorage, AK 99504 SUNDRY NOTICE - D-8RD Dear Hr. Chatterton: Attached is a Sundry Notice Subsequent for D-8RD, Trading Bay Unit f°r your information and file. LOC/tj Attachments Very truly yours, Lawrence O. Cutting ENVIRONHENTAL SPECIALIST RECEIVED APR 2 3 t985 ~.Sk,30i~ & Gas Gores. ~o~n~sslon ...... Anchorage STATE OF ALASKA ALASKA"~IL AND GAS CONSERVATION C~o'M MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER 2. Name of Operator Union Oil Company of California* 3. Address P.O. Box 6247 Anchorage, AK 99502 4. Location of Well Surface: Leg B-1, Cond. #1, Dolly Varden Platform 677' FSL, 1221' FWL, Sec. 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106' KB above MSL 12. I 6 . Lease Designation and Serial No. ADL-18729 7. Permit No. 74-3 8. APl NUmber 50-, 733-20187-O1 9. Unit or Lease Name Trading Bay. U~it 10. Well Number D-8RD 11. Field and Pool McArthur. River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] perforati.ons I-] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations {Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). TBU WELL D-8RD Scale Cleanout and Inhibition Treatment Coiled tubing scale cleanout, and scale inhibitor treatment operations began on Harch 15, 1985, and were completed on March 19, 1985 as follows' 1. Rig up and pressure test CTU to 5000 psi. . . RIH w/ 2.70" mill - clean out scale through tubing tail at 11,070' MD. Tagged fill at 12,079'. ~umped 41 bbls of 7.5% HCl, displaced into formation w/ 1 7 bbls 3% KCl FIW. Produced 200 bbls of fluid to separator. 4. Pumped 80 bbls SOC slug, displaced into formation w/ 400 bbls 3~ KC1 FIW. 5. POH. Leave well SI 24 hours. RECEIVED 6. Return well to production. APR 2 3 1985 *Marathon Oil Company, Sub Operator '_~aska 0ii & Gas Cons. Commission 14. I hereby c~t th~reg~~orrect to the best of my knowledge. La~~Cu~~ Env i'ronmenta I Spec ia I i st e ,04~,] 7~,85 The space below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date __ · Submit "Intentions" in Triplicate Form 10-403 'and ,Subsequent Reports" in Duplicate Rev. 7-1-80 STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION C~ISSlON SU#DRY NOTICES &ND RE ORI'$ ON WELLS t. DRILLING WELL [] COMPLETED WELL 2. Name of Operator Union Oil Company of California* 3. Address P.O. Box 6247 Anchorage, AK 99502 4. Location of Well Sur fac e: Leg B-l, Cond. #1, Dolly Varden Platform 677 ' FSL, 1221 ' FWL, Sec. 6-8N- 13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106 ' KB above MSL 6. Lease Designation and Serial No. APL- 1872 9 OTHER [] 7. Permit No. 74-3 8. APl Number 50- 733-20187-01 9. Unit or Lease Name Tpading Bay Unit 10. Well Number D-8RD 11. Field and Pool McArthur River Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~]: Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). TBU D-8RD COILED TUBING SCALE CLEANOTYr AND INHIBITION TREATMENT It is Marathon's intention to begin coiled tubing scale removal and inhibition treatment in February, 1985, by the attached procedure. *Marathon Oil Company, Sub Operator RECEIVED Alaska Oil & Bas Cons. C0r~rnJssj0ri Anchorage 14. I herebL~h~t~e f~_ ~rue and correct to the best of my knowledge. Signed I, awrence Oi Cutting tie Environmen+~! Spec!al!st The space below for Commission use Date 02-!4-85 Conditions of Approval, if any: Approved by Approved Co~y Returned By Order of COMMISSIONER the Commission Date Fc;rm 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicatb and "Subsequent Reports" in Duplicate TBU D-8RD COILED TUBING SCALE REMOVAL AND INHIBITION TREATMENT PROCEDURE 1. Rig up coiled tubing unit, lines and BOPE. Pressure test to 5000 psi. 2. RIH w/ 2.70" mill on coiled tubing to 10,900' and circulate clean wi th FIW. 3. Mill scale through tubing tail at 11,531' ._ , work through several times. 4. Clean out fill to 12,080'. 5. Spot 600 gal. of 7.5 percent HC1 with 1 percent corrosion inhibitor, .2 percent surfactant, .5 percent anti-sludge agent and 14#/1000 ~al. of iron sequestering agent across perforations. 6. Displace into formation w/ 3 percent KC1 FIW. 7. Produce well to test separator for 200 bbls. 8. Spot 93 bbls. of SOCTM slug across perforations. SOCTM slug - 80 bbls. of 3 percent KC1 FIW, 330 gal. ARCO S-256, 220 gal. inhibited 15 percent HC1, 800# CaC12. 9. Overdisplace SOCTM slug with 400 bbls. of 3 percent KC1 FIW. 10. SI well for 24 hours. 11. Return the well to production. WJL:cas 02-07-85 RECEIVED Alaska Oil & (]as Cons. Corrlmissio,~ Anchoraoe STATE OF ALASKA ALASKA"~i L AND GAS CONSERVATION ~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELLX~ OTHER [] 2. Name of Operator Union 0il Company of California* 3. Address P. O. Box 6247, Anchoraqe AK 99502 4. Location of Well Leg B-l, Cond #1, Dolly Varden Platform 677'FSL, 1221'FWL, Sec 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) _ KB 106.2' nhnv~. M.C;L 12. I 6 . Lease Designation and Serial No. APL- ! 8729 7. Permit No. 74 -3 8. APl Number 50- 733-20187-01 9. Unit or Lease Name · Trnding R~y IJn!t 10. Well Number F)-RRD 11. Field and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ]~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). , On 8-14-81 0° phasing, 4 HPF: perforated following Hemlock intervals under drawdown with a 2-1/8" perf gun, Bench 4: 11,870'-11,910' 11,920'-11,946' Bench 5: 12,030 ' -12,045 ' Production Test: Before Perfs 568 BFPD, After Perfs 2110 BFPD, *Marathon Oil Company - Sub-Operator wc, BOPD RECEiYEI) AUG 2 4 ]981 Alaska Oil & Gas Cons. Comrnissio Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The sp~e ~"eiow ~or C~omm,ss,o~n use-- - ! - Date 8/21/81 Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASK~IL AND GAS CONSERVATION (~'~MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LL~/V~3 OTHER [] 2. Name of Operator 7. Permit No. Union 0il Company of California* 74-3 3. Address 8. APl Number P. 0. Box 6247, Anchorage AK 99502 50-733-20187-01 4. Location of Well Leg B-l, Cond #1, Dolly Varden Platform 677'FSL, 1221'FWL, Sec 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 12. 6. Lease Designation and Serial No. ADL- 18729 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-SRD 11. Field and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed to reperforate Hemlock Benches 4 and 5 Bench 4: 11,870'-11,910' (40') 11,920'-11,976' (56') Bench 5: 12,030'-12,060' (30') Verbal permission received from Russ Douglass to T. L. A written subsequent notice will be submitted to the State. *Marathon Oil Company - Sub-Operator in D-8RD. Swan on August 5, 1981. RECEIVED AUG 1 9 1981 Alaska 0ii & G~s Cons. Commission Ancttorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title DTST DRI G glIPT The spac'~e ~elow fo; Commis~°-'n use ' Conditions of Approval, if any: 0lllI]IltAI' Approved by BY £01t,~1£ C. SMITlt COMMISSIONER Date 8/1 7/81 Approved .rOpy Returned By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA~./IL AND GAS CONSERVATION ~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LL~)I~] OTHER 2. Name of Operator 7. Permit No. Union 0il Company of California* 74-3 3. Address 8, APl Number P, 0, Box 6247, Anchorage AK 99502 50_733-20187-01 4. Location of Well Leg B-l, Cond #1, Dolly Varden Platform 677'FSL, 1221'FWL, Sec 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. ADL- 18729 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-SRD 11. Field and Pool McArthur River Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate J~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including'estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed to reperforate Hemlock Benches 4 and 5 Bench 4: 11,870'-11,910' (40') 11,920'-11,976' (56') Bench 5: 12,030'-12,060' (30') in D-8RD. Verbal permission received from Russ Douglass to T. L. Swan on August 5, 1981. A written subsequent notice will be submitted to the State. *Marathon Oil Company - Sub-Operator RECEIVED AUG 1 9 198I Subsequent WorI~ Ileported on Form No.~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title _I]!%T DR! G %UPT · The space below for COmmission use Date 8/1 7/81 Conditions of Approval, if any: Ol~lO~rt~L SIGXEII' BY LOH~IE C. SalTll Approved by COMMISSIONER Approved Copy Returned By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA. rilL AND GAS CONSERVATION c~M M ISS.ION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL r~ OTHER [] 2. Name of Operator Union 0il Company of California* 3. Address P.O. Box 6247; Anchorage, Alaska 99502 4. Location of Well Dolly Varden Platform, Leg B-l, Cond #l 677' FSL, 1221' FWL, Sec 6, T8N, R13W, SM 7. Permit No. 74-3 8. APl Number 50- 733-20187-01 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-8RD 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KB 106.2' above MSL I ADL 18729 12. Check Appropriate Box To Indicate Nature of Notice, Repor~6~ Other Data McArthur River Field NOTICE OF INTENTION TO' ~_ SUBSEQUENT REP~OR~.G~F'.~ (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations ~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well I--I Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations'(Clearly state all pertinent details and give pertinent dates, including estimated date of starting an~, proposed work, for Abandonment see 20 AAC 25.105-170). Verbal approval received 10-24-80 from Russ Douglas to Tony Swan. perforated following Hemlock intervals under drawdown'. 11870 - ll910 4 HPF 2-5/8" DA 0° Phasing 11920- 11976 " " " 12030 - 12047 " " " Production Test' Before Perfs After Perfs 408 BFPD 75% WC '102 BOPD 1826 BFPD 40% WC 1096 BOPD On 10-20-80, *Marathon Oil Company - Sub-Operator RECEIVED JAN 1 5 1981 Naska 0il & Gas Cons. C0mmissi0~ Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. S ,g n ed~//~~//~.z/~ ~.,¢ j ~ _T~tle misto Drlg. Th~a~e bel°W~ f~r c~m;ssi°-''~-use- ~'~.,~. ,~,,~Z~ Conditions of Approval, if any: ~ ~ ..... ~ Supt. Date 1/12/81 By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA - ALASKA~IL AND GAS CONSERVATION ~MISSION ---'~RE~ E~G-- SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL ~ COMPLETED WELL ~ OTHi Union Oil Company of California* 7~-] 3GEO' 3. Address 8. APl Number ' P. 0. Box 62~7, Anchorage AK 99502 50- 733-20187-01 , , ........ 4. Location of Well 9. Unit or Lease Name Leg B-l, Cond ~1, Dolly Varden P]aLform Trading Bay Uni~ON'FER:' ~, ...... ,. 677'FSL, 1221 ~FNL, Sec 6-8N-13W-SH 10. WellNumber FILF: 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) J 6. Lease Designation and Serial No. ~ HcArLhu r R i ver F i e ] d KR ldO.?' abpve HSLJ APL 18729 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submi~ in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing ~ ~ Perforations ~ Altering Casing Stimulate ~ Abandon ~ Stimulation ~ Abandonment Repair Well ~ Change Plans ~ Repairs Made ~ Other, Pull Tubing ~ Other ~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10~O7 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Work commended 10-05-80; completed 10-1~-80. 1. Pumped ~5 bb]s 5ale-Seal slug and displaced .across per5s w/ 160 bb]s KC] W0 fluid. 2. RIH w/ DA S perfd Lbg ~ 11,185', LD ~-1/2" tbg. ~' RIH w/ ~' biL S scraper Lo 12,005'. ~. RIH w/ fishing tools Lo 12,008~, POH w/ ~' - 3-1/2" fish. 5. RIH w/ 5-3.~~' NO shoe, OS dressed w/ 2" baskeL grapple. Washed over fish L 12,037' ~ POH. Rec'15' of 3/~" bar s~uck w/ ~ chain links. . ~. RIH w/ 6~' bi~, Lagged .junk ~ 12,063'. Washed junk Lo 12,097'. 7. Ran carbon-oxygen and NLL log across Hemlock. 8. RIH w/ Guiberson "AL" perm pkr. Set ~ 11,470'DIL. 9. RIH w/ 3-1/2" & 4-I/2" tSg w/ GL eqpmt. BFPD BOPD Form Gas TP CP Production before Repairs: 1308 643 193 160 126~~-~ .~ ~ .~" Production after Repairs: 1490 1192 365 130 108~'~:'~ ' '' ~' '~'-' ~ - Attachment: Tubi n g Deta i 1 S~q~ent "Wm'k ~eported *Marathon 0il Company - Sub-Operator , , i 14. I hereby ~tify that the foregoing i~rue and correct to the best of my knowledge. // si,n., Su, t. O ,e s~e ~ ~ The Iow for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date__ Form 10~,03 Rev. 7-1 ~O Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 REV. 1-10~73 Submit "lntenUml~' In Triplicate & "Sul. equent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not u,e this form for propo~l$ to drill or to demon U;e "APPLICATION FOR PERMIT--" for such propo~ls.) OIL I:1 GAS I--'! WELLI,~I~I WELLLI OTHER 2. NAME OF OPERATOR Union Oil Company of California* 3. ADDRESS OF OPERATOR P. O. Box 6247, Anchora. ge AK 99502 4~' LOCATION OF WELL At surface Leg B-l, Cond #1, Dolly Varden Platform, 677'FSL, 1221'FWL, Sec 6-8N-13W-SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 106.2'KB Check Appropriat. Box To Indicate Nalum of Notim, Re 5. APl NUMERICAL CODE 50-133-20167-01 ~,, L~E DESIGNATION AND SERIAL NO. ADL- 18729 7. IF INDIAN. ALLOTTEE OR TRIBE NAME ~1. UNIT. FARM OR LEASE NAME Tradinq Bay Unit 9. WEU. NO. D-8RD IO. FIELD AND POOL. OR WILDCAT McArthur River Field 11. SEC.. T.. R.. M.. (BOTTOM HOLE OBJECTIVE) Sec. 8, T8N, R13W, SM 12. PERMIT NO. ~ 74-3 tort, or-Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF L-~ FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL. PULL OR ALTER CASING MULTIPLE COMIN. ETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT'OFF N REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) , , (NOTE= Re~°rt results of multiple completion on Well ' ' ' Completion or Reeompletlon Report em] Log form.) 15. DESCRIBE.PROPOSED oR COMPLETED OPERATIONS (Clearly state ell I~rtlnent detall~, am] give I~rtlnent dates, including estimated date of starting any propose(I work. Objective: Replace defective GLV's & scale-restricted tbg, recover WL tools, & wash fill from well. Run a Carbon/Oxygen log across Hemlock. Procedure: 1. Skid rig 76 to Well D-8RD, Leg B-l, Cond. ~1. 2. RU to tree & open circ slv. Pump 170 bbl 8.6 ppg KCI WO fluid dwn tbg. Blow dwn lift gas in annls & fill w/ approx 550 bbls WO fluid. Open circ slv@ 11,468'MD & C&C WO fluid. 3. Set BPV, ND tree, & NU & test BOPE. Tst 13-3/8", 5000# BOPE each. week. 4. Pull Baker FH hyd pkr. LD tbg, break out BV, GLMr'S, circ slv,& pkr. 5. RIH w/ 6" bit & scraper to WL fish @ approx 11,997'DIL. C&C WO.fluid. 6. Rec WL fish. 7. Wash out fill to PBTD @ 12,105!DPM; 12,092'WLM. 8. Run Carbon/Oxygen log across Hemlock. 9. Set perm pkr above Hemlock. Run compl eqpmt w/ mule shoe, X nipple, seal assy, 3-1/2" XA circ slv, 3-1/2" & 4-1/2" USI mandrels w/ Macco vlvs, 3-1/2" & 4-1/2" ASL tbg & 4-1/2" Otis DC TRBV. 10. Land tbg, install BP¥, ND stack, & NU & test tree. Return well to production. Proposed starting date: September 30, 1980. *Marathon Oil Company - Sub-Operator Subsequent Work 16. I hereby/ZMr/~ thlt lng is true end cowect 'r,'r,., , -,',- / (T,,is&~,orS~,t. c,,~,,..) .. f/ ' ' APPROVED BY, /~W~ (!~ TrTLE ' CONDITIONS OF AI~ROVAL, IF A~I%~';BY ORDER OF TH~ COuMISs10N . '- See Imtru~om On Reverie 8ids C~TE~ Retur;~ed Union Oil and Gas ~_~ion' Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 union .July 26, 1976 Mr. Hoyle Hamilton Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 ~..'~' TBUS D-S Rd i""'~.~y~' .... TBUS D-28 Dear Mr. Hamilton: Enclosed for your files are two (2) copies of the Well History for TBUS D-8 Rd., two (2) copies of the Sundry Notice & Reports on Wells for TBUS D-24 A and two (2) copies each of the Well History, Surveys and Well Comple- tion Report for TBUS D-28, Dolly Varden Platform, Cook Inlet, Alaska. Very truly yours, , Callender District Drlg. Supt. sk gncl. (6) cc: Marathon Oil Co. Atlantic Richfield Co. Amoco Production Co. Skelly Oil Co. Phillips Petroleum Co. Standard Oil Co. USGS-Rodney Smith Pedro Denton (Completion Report D-28) JUL 8 1976 DMSION OF OIL AND GAS ANC:HO~AG,~ DATE MARATHON OI~OMPANY HISTORY OF OIL OR GAS WELL FIELD McArthur River BLOCK Surface WELL NO. D-SRD LEASE Dolly Varden Platform, TradinM SEC. 6 .... TIA'P. 8N PARISH Bay Unit ~I'ATE Alaska COUNTYKenai Peninsula BoroughS'. ~,~., lo6,..~. JIJL ~ ~ 19'76 I TOP OF OIL STRING , ELEV., HISTORY PREPARED BY D~an W. olstenholm MF. ASUREM£NT$ LTOP OF ROtArY TAeLZ__ EL£¥ .... TITLE Clerk TAK£N FROM ! [GRD. OR MAT. EL£¥.. ~i ~, of the greotest importance to have a complete history of the well. Use this form in report;ng the history of all importont operations ct the well, together with the dates thereof, incJuding size of hole, size and number of bits, complete description of casing, cementing, f'm~himg or drilling difficulties, surveys, aU tests, all completion operations ond procedure, etc. R. 13W SM JUL 3 B 9T6 DMsION.OF OIL AND GAS 6-8,9 6-10,11 6-15 6-~.9 Reports as of 7:00AM for previous 24 hrs activity. Loaded tubing with Inlet water followed with 700BBLS mud. Circ. mud. Moved pipe racks and mud tanks and skidded rig from Leg A-1 to Leg B-1. Rigging up over D-8. Flanging up BOPE.. Flanged up 12"-900 Double Shaffer & Hydril. Connected up flow lines, choke lines, and kill lines - modified drilling nipple. Tested pipe rams to 3000 psi-held OK, H$2dril to 2000 psi-held OK, choke & kill lines to 3000 psi-OK. Screwed into sgl "Sealock hanger and backed off tie-down screws. Pulled 180,000// net-would not come loose. Had slight movement in 13-3/8" (3"). Welded 3 4" Sch 80 pipe brackets from deck to flange on 13-3/8" head. PU BOP stack to check tie down bolts. Picked up X-O sub & ~ars w/1 jt DP & Kelly. Jarred tbg hanger loose w/160,00C~. Pulled pkr loose w/210,000~. Circ. hole .~ built mud weight to 9.8///gal. Began pulling & laying down tubing. Finished laying down 4½" & 3½" tbg string. Numbered gas lift valves & ms~udrels for inspection. Circulating sleeve was washed out below circ. ports-apparently has been leaking. Sleeve had not been opened with wireline tool when well was killed. PU DP & RIH to 13:346'. Circ & cond mud in preps.ration to lay cement plugs. TD 13,932', PBTD 12,680' - Circulated hole clean @ 13,4H6'. L~yed a cement plug to plug Hemlock perfs from 13,O45' to 13,4~6' with 5~ sxs of Class 'G' cmt with 1~ D-Bi (friction reducer) & O.5~ R-~ (retarder). Cement in place at 9:45 ~..M, 6/14/74. Pulled 9 stands of DP ~nd reversed out. WOC 8 hfs - holdin~ 1~OOO psi down pressure on DP w/rams closed. T~gged cmt top @ 1B,O~'. Mixed & pumped 65 Sxs of C1 'G' cmt (additives as above). Pulled 9 stands & reversed out. Held 1OOO psi down press on DP for 8 hrs while WOC. Job by BJ. T~gged cmt top @ 12,680'. POH. TD 13,932', PBTD 12,680' - Finished laying down 3½" DP. RIH w/8?' bit on 9 6-1/4" DCs, & 5" DP. Strapped DP to liner top. Found top at 10,24~' - recorded at 10,241'. Made 8' correction. Circ. bottoms up. POH. Rigged Dresser-Atlas & ran Variable Denq.-CBL/GR-CCL from 8-,000' to 10,249'. (D-.A showed top of. 7" liner @ 10,221',, . WLM, 28' diff. w/DP). CBL showed excellent- bonding across entire 9-5/8 mnterval. Started in hole installing rubbers on DP. TD 13,932', PBTD 12,680' - RIH installing rubbers on DP. Circ& cond mud - raised VIS to 200. POH - PU Tri-State section mill, BS, & jars. RIH to 8,733' --started milling. Milled 6' in 6 hrs. At 8,739' at 7:O0 AM. TD 13,932', PBTD 12,680' - Milled 9-5/8" w/Tri-State mill to 8,788'. Circ & work mill into shoe joint. Cut a collar at about 8751'. TD 13,932', /~BTD 12,680' - POH from 8788'. Blades worn out on mill ~/1. Slip- lmed drlg line. RIH w/mill ~2. Reamed from 8,778' to 8,788'. Milled 9-5/8" csg from 8,788' to 8,795'. POH. Blades worn out on mill //2. RIH w/Tri-State sec- tion mill ~/3. Reamed 8,789' to 8,795'. Milling at 8,796' at 7:00 AM. 'TD 13,932', PBTD 8,627' - Finished cutting section in 9-5/8" Csg to kickoff. Milled csg from 8,796 - 8,824'. Circ hole clean. POH w/Tri-State mill~ RIH w/ open-ended DP to 8,940'. Mixed .& pumped 120 sxs C1 "G" cmt w/10~ sand. P0H to 8,627' & reversed out approx. 2 BBLS. Cmt in place @ 4:30 AM. Presently WOC. History of Tradin~ Bay Unit Well D-8 Redrill Continued ~-21 PBTD 8~700' - Laid down 5" DP while POH. PU 27 its of HW Dp & started in hole. WOC 22~ hrs. Finished in hole & tagged hard cement at 8,685'. Drld cmt to 8700'. 6-22 TD 8,800' - Drld cmt to 8,782'. Circ & cond mud. POH. PU B}D~ w/Dyna-drill. RU ~perry-Sun. RIH. RU Dresser-Atlas. RIH w/wireline & steering tool (Sperry-Sun) to orient Dyna-drill. Drld in side-tracked hole from 8,782' to 8,800'. 6-23 TD 8,865' - Drld w/Dyna-drill to 8847', survey, POH w/wireline & rig down ~perry Sun. POH. Laid do~m Dyna-drill. PU BHA. RIH. Reamed 8782 to 8847'. Drld 87' hole to 8,865'. 6-24 TD 9,191' - Drld to 8938'. Surveyed. Drld to 9,064'. Surveyed. Pulled into csg. Ran sand line in hole So spliced s~me. Retrieved survey. Ran DP to bottom - drilling ahead. 6-25 TD 9,426' - Drld to 9,222'. Dropped survey - POH, for bit #4. Picked up two stabilizers. RIH, drld to 9,B90'. Ran survey. Drld to 9,426'. 6-26 TD 9,644' - Drld to 9,499'. Dropped survey & POH. Changed B}~A & RIH w/bit #5. Drld to 9,644' w/survey @ 9,606'. TD 9,885' - Drld to 9,660', dropped survey, and POH. S~ out of hole-no cor- rection. RIH & drld to 9,853'. Dropped s~rvey. Drld to 9,885'. POH for bit ~7. 6-28 TD lO,lB5' - Finished POH w/bit ~6. Pulled ~ear bushing and tested BOP stack & choke manifold to 3,000 psi-OK. Ran wear bushing back. RIH w/bit #7. Reamed 9,400' to 9,472'. Drld to 10,042' & dropped 'survey. Drlg ahead. 6-27 6-29 TD lO,BB7' - Drld to 10,200' & circ. hole. Pulled 10 stds for short trip. Drop- ped survey. Drld to 10,3B7', surveyed &P OH for bit change. 6-So TD 10,670'. &drilling 7-1 TD 10,956' 7-2 TD Ll,134' BHA& RIH. -- RIH w/bit #8. Drld to 10,608'. M~de short trip. Ran back to bottom ahead. - Drld to 10,956'. Circ & surveyed. POH for bit #g& changed BHA. RIH. - RIH w/bit ~9. Drld to 11,134'. Circ & dropped survey - POH. Changed 7-3 7-4 '7-6 7-7 TD 11,329' - RIH w/bit #10. Stopped @ 8,733' (csg shoe) & cut drlg line. Drld 11,134 to 11,298'. Ran dir. survey - no good. Drld to ll,329'-dropped survey. Showed 12~° drift angle, but unsure of direction - one instrument showed S59~E & the other showed N15°E. Resurveying. TD 11,489' - Drld & surveyed @ 11,393'. Short trip 15 stands. Drld to 11,470'. POH. RIH. Drld to 11,489'. TDll,739' - Drld to 11',582", surveyed.'Drld to 11,739' &made wiper trip. TD 11,909' - Drld to 11,771', surveyed. POH for bit. Check BOPE. Hole in good condition. RIH. Drlg ahead. TD12,118' - Drld to 12,087'. Made short wiper trip. ~ld to 12,118" surveyed &P OH for new bit. 7-8 7-10 TD 12,243' ~ Finished trip out - no correction to pipe tally. TeSted BOPE--OK. ~t & slipped drlg line. RIH w/bit #13. Reamed from.12,O50' to 12,118'. Drlg. TD 12,398' - Drld to 12,398' & circ. Made wiper trip to cSg shOe. RIH &2irc. to condition mud. POH to log w/open-hole tools. TD 12,398' - POH to run el. logs. RU Schlumberger and ran BHC-Sonic, Gam~a Ray Caliper, DIL/SP, and Density/Gamma Ray. Logged from 12,398' to 8,73~'. Rigged down Schlumberger. RIH to 12,398'. Circulating to condition hole & mud to run TD 12,B98' -Circ & cond mud .and h°le at 12,B98'. POH with wiper trip. Circ 1½ hrs, dropped survey at 12,B98'. POH. RU to run 7" liner. Ran 3,817' of 7" 29~XLine N-80 liner on 5" DP' Top at8568,. Landing COllar '12,3h3, shoe at ~,~ History of Trading B. ay Unit Well #8 Redrill Continued: 7-15 7-18 ~7~20 7-21 TD 12,398' - After running 7" liner to 12,385', circ., dropped ball, and pres- sured to 2,700 psi- shearing out to set h~nger slips. Circ &cond mud. l~ped 25 BBLS of water. Mixed & pumped 850 sxs of C1 'G' cmt w/l% D-B1 (frict. red.) & 0.~% R-5 (retarder), with 15.8# to 16.O# slurry wt. Dropped wiper plug & pumped 5 BBLS of water ahead of 290 BB~S of mud. Lacked 2 BBLS of total dis- placement to bump plug when lost returns. Shut down pump, bled off press., hole stayed full, flapper floats held. Set screw-set pkr. Picked up & rever- sed out. CIP @ lO;:15 2~, 7/11/74. Reversed out about 120 BBLS of cmt., cmt- contaminated mud, & water. Pulled B stds & circ hole. Pulled out & laid down 85 its 5" DP & all HW DP. Cut & slipped drlg line. TD 12,~98' - RIH w/8~" bit & 9-5/8" csg scraper to liner lap--SLM in hole-OK. POH. PU 6" bit &llB jts ~½" DP. RIH to 8,560'. Circ & WOC. TD 12,B98' - WOC until 8:00 AM, 7/1B/74. Ran in 7" liner & tagged cat @ 12,185'. Drld hard cmt to 12,226'--leaving ll7' cmt on top collar. Circ hole cle~n & POH. PU HOWCO test tools & RIH filling 24 stds w/filtered inlet water cushion. Set RTTS pkr @ 8,545'. Opened tool at l:~O PM & received strong blow to surface. Died in i hr. SI tool & POH. Pulled 6 stds & pipe came wet~ Reversed out 7,860' of water, including approx. 5,460' of salt water recovery from liner lap test. Took sample of recovery. TD 12,B98' - POH w/HOWCO test tools. RIH w/6" bit to 8,600'. Circ. hole & POH. PU & RIH w/HOWCO RTTS pkr. Set @ 8,400' & broke dorm @ 2,200 psi & 6 BPM. Pul- led pkr loose & pumped 20 BBLS water ahead of 150 sxs of C1 'G' cat w/l% D-B1 & 0.4% R-5 - 16.~ slurry ~b. Displaced w/5 BBLS water ahead of 94 BBLS mud & closed tool. Cement was squeezed away at 1000 psi initial press & 2,000 psi final press. Held press 5 min. - bleeding back, not staying in place. Pumped 10 BBLS & held 15 min. Bled back 5 BBLS. Pumped 6 BBLS & held. 25 min. Pulled pkr loose & reversed out 50 sxs cmt & water. CIP @ ll:OO PM, 7/14/7~. TD 12,B98' - WOC. PU bit & csg scraper. RIH to liner top @ 8,568'. No cement. Circ. bottoms up. Spotted 25 BBLS water on liner top, closed rams & press, up --broke down @ 2100 psi. Pumped away @ h.5 BPM. Press. @ 1900 psi while p,~mp- lng. Reversed out water. POH. Picked up RTTS & RIH. TD 12,~98' - RIH w/RTTS pkr to 8,369'. Set pkr & closed rams. Tested annulus to 2,000 psi for 45 rain-held OK. Bled annulus press to 1,O00 psi, then pumped into liner lap @ 2,200 psi & 5 BPM. Pumped 20 BBLS water ahead of 150 sxs C1 'G' cat w/l% D-B1, 0.~% R-5 16.~ slurry. Displaced w/5 BBLS water ahead of 94 BBLS mud. Closed pkr-squeezing w/50 BBLS of mud. Cleared pkr. Held 2150 psi on squeeze by pumping total of 31 BBLS in 6 jobs over 2 hr period, but cat wanted to bleed back. Pulled pkr loose w/ press on DP & annulus, reversed out w/2,000 psi--no cement returns. Started mixing 2nd lap squeeze @ !l:O5 ~! & job complete @ S:OO PM. While SI & WOC, annulus press, increased 400 psi. Circ & cond mud from 4:00 PM, 7-16 to l:OO ~J~, 7-17. Brd liner lad scueeze - Set pkr @ 8,BBT' & pmmped into lap @ 2,400 psi & 5 BPM (~¢d in lO BBI~G & bled back 6 BBLS). Pumped 20 BBLS water ~ead of 150 sxs C1 'G' (~s above). Displaced w/5 BBLS water & 93 BBLS mud. Closed tool-squeezed w/50 BB~.S mud. Displaced to within BO ft. of liner @ ~/4 BPM. SI @ 2,250 psi. Cement wouldn't bleed back'-held 2100 psi on squeeze. Started mixing @ l:lO AM & job complete @ 2:00 AM, 7/17/74. WOC. TD 12,398' - Held 1900 psi on squeeze #3 w/leO0 psi on annulus for 6 hrs. Bled off @ 8:00 AM, 7/17 & got 2 BBLS back. Pulled' pkr loose & circ. 1~ hrs. POH & layed down RTTS pkr. PU 87' bit & RIH to 8,O00'-circ. & WOC. Tagged top of hard cmt @ 8,417'. Drld 15!'of hard cmt (8,417'-8,568' liner top) from 1:O0 AM to 6:00 AM, ?/18. Spotted water & press, tested liner lap w/2,500 psi-held OK. TD 12,398' - POH w/bit. RIH w/Halliburton RTTS DST tools with 2150' of water cushion. Set tool @ 8,545'. Open @ 2:45 PM for 1 hr. Slight blow for 20 min. Shut in @ 3:45 for 1 hr. POH. Had 2150' of fluid (water cushion) in drill pipe. IHP-3518, FHP-B494, IFP-701, FFP-725, SIP-942. RIH w/6" bit & tagged lap @ 8,567'. Drld cat from 8567' to 8569' & pushing plug ahead of bit. TD 12,398' - Ran into cat @ 12,185' in 7" liner. 'Drld hard cmt to 12,~13'· POH, measured out--OK. RU & ran Schlumberger cat bond log from 12,~OO' to 8,BOO'. Ran gyro from 700' to 12,250'. Rigged down. T~ 12,B98', PBTD 12,313' -Made. bit & scraper run to 12,313'. RU & perforated Hemlock bench 5 from 12,120 to 12,125' 2 hpf, 4" casing gun. Started in hole w/Nalliburton RTTS DST tools with ~,000' water cushion. _~istor~,.of ,Tr.~.d_ing Bay Unit Well D-8 Redrill Continued: 7-22 TD 12~398', PBTD 12,313' - Finished in Hole with DST tools. Set pkr @ 12~077' to test Hemlock bench #5 perfs 12,120' to 12,125'. Opened tool @ 9:10 AM, 7-21-74. IHP- 5277 psi., IFP--1326-1669 (10 rain), ISI 3877 (30 rain), FFP-- 1620-3582 (4 hrs), FSI-4049 psi (8 hfs), FHP-5179. Temp. 143°. Had medium steady blow during initial & final flow. Gas to surface 1 hr 55 min on final flow (medium steady blow). Opened circ sub, reversed out net rise of 5765' 2865' of oil-wtr-mud emulsion (51 bbls), 2900'. of formation water (46 bblsi. Sample 17,500 ppm CHL. Pulled pkr loose @ 9:50 PM, 7-21-74. Waited 30 min., reverse circ. POH. Started in hole with 7" cmt retainer. 7-23 TD 12,398', PBTD 12,105' - Finished in hole with cmt retainer & set @ 12,105'. Pumped into Hemlock bench pcrfs @ 12,120-12,125' @ 1 BBL/min with 5000 psi with water. Squeezed with 100 sxs C1 'G' 1% D-B1 0.4% R-5, 16///gal slurry. Initial pressure 3500 psi & final pressure 5000 psi. Pulled out of retainer & reversed out 8 sxs cmt. Circ & cond mud. POH. RU & perforated Hemlock bench #5 from 12,055'-12,060'] 2 SPF w/4" csg gun. (Wireline plug back @ 12,092' ). Started in hole with Hallibua-ton DST tools with 3000' fresh water cushion. ?-24 7-25 7-27 7-28 7-29 TD 12,398', PBTD 12,105' - Finished in hole with DST tools. Set pkr@ 12,011'. Opened tool @ 9:45 AM. Had very weak blow during 10 min initial flow. ISI for 4~ min. Open tool for final flow of 4 hfs @ 10:40 AM. Had weak blow~ increas- ing during flow period. Gas to surface in 3 hrs 25 min. Shut in @ 2:45 for 8 hr final shut in. Reversed out 1 BBL oil on top of cushion, 22 BBLS fresh water cushion, 41 BBLS oil with trace of mud. Net rise in DP of 2722'. Pulled pkr loose @ 10:45 PM, waited 30 min & reversed out. POH. IHP-5179 psi(12,O23'), IFP--1326-17~7 psi (1Om in), ISI-did not get, FFP--1498-1988 psi (4 hrs),. FSI 3705 (8 hrs), FHP 5179 psi. TD 12,398', PBTD 12,105' - Finished in hole & circ bottoms up. POH, layed down drill pipe. Changed rams in BOPE. RU & started in hole with tubing string. TD 12,398', PBT~ 12,105' - Finished in hole with tubing string, testing joints to 4,000 psi. Installed tbg hanger & landed in head. Set pkr @ 11,503'. Tested pkr to 2500 psi - OK.'Installed BP valve. TD 12,398', PBTD 12,105' - Removed BOPE & installed tree. Tested tree to 5000 psi - OK. Tested BV line to 5000 psi - OK. RU & opened circ valve @ 11,468'. TD 12,398', PBTD 12,105' - Displaced mud with water & displaced water with diesel. RU & closed circ sleeve & opened gas lift mandrels - except #1. Un- loaded 211 BBLS diesel & well stopped t~,ing lift gas. Rigged up to run BHP. TD 12,398', PBTD 12,105' - Ran BHP survey - pressure @ 11,4OO' was approx 3500psi. Attempted to gas lift well - well would not take gas. RU & ran gas lift mandrel shifting tool & jarred on all 4½" mandrels. Started unloading well to separator. 7-30 7-31 8-1 TD 12,398', PBTD 12,105' - Unloaded valve down to approx, valve #7. RU & ?~,. Jarred on all ~2 gas lift mandrel sleeves. Unloaded well to bottom valve & well U-tubed gas. Recovered lO0~crude oil at end of unloading. TD~12,398', PBTD 12,105' - Ran BHP survey. Well lifting from bottom valve with BHP of approx, ll61 psi @ 9210' TVD. RU Dresser-Atlas & perforated bench #5 from 12,040' to 12,060'(CBL) with 750 psi gas pressure on tbg to give total hyd. pressure on formation of approx. 2000 psi. Perforated with Jumbo Jet bar gun, 4 HPF under draw-doE conditions. Tubing pressure increased from 750 to 850psi. Bled pressure to 750 psi & started in hole with gun No. 2. TD 12,398', PBTD 12,105' - Perforated remainder of bench #5 under draw-down conditions from 12,030' to 12,040' with Jumbo Jet bar gun, 4 SPF. Placed well on test & well intermitted - recovering lO~ mud, 90% oil, no water, at rate of approx. 300 BPD. RU & perf'd bench #4 under draw-doE condtions from 11,920' to 11,936' (CBL) with same-gun. Placed well on test @ rate of 30 BPH or 720 BPD, 2~ mud, 98~oil, no water. RU & perf'd'bench #3 from ll,7~' to 11,804' with same gun. Prepsa-ing to test benches 3, ~, & 5. Total fluid recov- ered 585 BBLS diesel, 352 BBLS crude oil & 15 BBLS mud. ~.~ ~istory of Trading Bay Unit Well D-8 Redrill Continued: TD 12~398', PBTD 12,105' - Tested benches 3,4,&5 - unable to obtain stable rate-producing 0.2¢ mud & 99.8¢ oil. RU & perforated bench 2 from 11,695' to 11~775' & bench i from 11,655' to 11,665', 4 SPF with Jumbo Jet under draw-down conditions. Placed well on test - unable to obtain stable rate- producing lO0~ oil with trace of mud. Released rig to D-24 @ 12:O1 AM, 8...2-74. 8-3 TD 12,398', PBTD 12,105' - Well produced @ rate of 4,824 BPD with O.5¢ BS&W, TP 140, CP 1260, lift volume 247 MCF, Gravity- 35°API, formation ~OR 2~6. FINAL REPORT. AFE 4362 Estimated cost Final cost - estimated $490,000 Production prior to redrill: 752 BOPD 828 Bw?o 52.5~ wtr 1,685 MCF lift gas Dear ~r. Burrell: Union Oil and Gas Di',ision: Western Region Union Oil CompanY'~I/California 909 W. 9th Avenue, Anchorage, Alaska 99501 Telephone: (907) 279-7681 union August 30, 1974 Hr. Homer Burrell Division of Oil ~ Gas State of Alaska 3001 Porcupine Dr. Anchorage, Alaska 99504 ! ~nclosed for your files are the Well Completion Report (Form P-7)and the Survey for Trading Bay Unit State Well D-8 (13-8), Dolly Varden Platform. t4 ~',~o1 ~.]- ~ ~NoI .... -'i-~?ou 't ~ .... t~v .I CONFER: FILE: Very truly yours, David A. Johnson Drlg. ~ngineer sk Eric1. (4) CC: ]~OCO Skelly Phillips Amoco Rodney Smith/USGS SiP 4 1~74 DIVISION CF OIL AND ANCHORAGE . SUBMIT IN DU~ !~TE* STATE OF ALASKA y'~see other ln- -~ structions on OiL AND GAS CONSERVATION ¢OM/61TTEE rev~,'~ s~e~ i WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la, TYPE OF ~'ELL: on, [~ 6AS W ELI. W ELL DR ¥ Other b. TYPE OF COMPLETION: W E L L OV ER E N B AC K EESV R. Other ~. NAME OF 0P£RATOR *Union Oil Company of California 3. ADDRES~ OF OPERATOR 909 ~est Ninth Avenue, Anchora~e,,,~ Alaska 99501 4, L0Ca'r~0N OF WELL (Re~ort location clearly and in accordance with any State requirem~ttts)* At surface 677' FSL & 1221' FWL, Sec 6, T8N, R13W, SM, Conductor #1, SE Legle~pwOlly Varden Platform At top prod. interval reporte/t Hemlock Top: 1776' FSL & 631' FWL, Sec 8, T8N, R13W, SM At total depth TD: 1642' FSL & 851' FWL, Sec 8, T8N, R13W, SM 5. API NU1VI. EZ~fODE 50-133-20 ,~7-01 6. LEA~E Dg~klGNJk~[iO~ A-ND SER~L NO. ~L-18729 7. IF INDIA_N, AJ-J-,OTTEE OR TRIBE NAME 8. UNIT,FAtlRVI OR LEASE NAME Trading Bay Unit 9. WELL NO. D-8, RD (13-8) 10. FIELD A~D POOL, OR WILDCAT McArthur River Field 11, SEC.. T., R., M., (BOTTOM HOLE OBJECTIVE ) Sec 8, T8N, R13W, SM 12. PER1ViIT NO. 74-3 , 6/11/74{ 7/9/74', ' [ MI~8/2/74D [+106..2' KB (MSL) ~ +65' (HSL) it;. '~'O~TAf~TF~.S~LD & TVD~9. P~L~G,.~'~I .~. & ~ ~. ~ ~LT~LE CO~L., [ 21. 'INTERVALS DRILLED BY . ~o_~ao, %m~ / o_aag' TVD ,/ -- I ALL { -- ~. PRObUCING .N~RVAL(S), OF ~I~ ~OM~TION~P, BOSOM, N~E (~ AND ~)* 23.WAS DIRE~IO.NAL [ SURVEY ~ADE Hemlock: 11,655'-12,060' ~ or 9,453'-9,841' T~ ~ Yes I 24. TYPE ELECTiliC AND OTHER LOGS I~UN S. onic/GR/Calip., _DI.L/S~ Densit~,/GR/Calip., & CBL ,,, CASING RECORD (Report all strings set in well) CA. SIZqG SIZE WEIGHT, DEPTH SET (~ID) HOLE SIZE Redrill - 20. LINER 1REC OI~D SIZI~ TOP (MD) [ EOTTONI (MD) ]SA. CKS CEMENT*,, ., 7" O.D. 8..568~ 1 2; qaq' g~ A~enpb- ..... clrz ,,, ~ant I 28. PERFORATIONS OPF2Xl TO PRODU ON' (interval, size and number) See Attachment II 30. PRODUCTION CF, MLNTING RECORI) TUBING RECOP~D i 2~/fOUNT PULLED $Ci%EEN (~[D; SIZE -- 4-1/2"0D 8;394' -4- (x-nvar) 3-1/2"0D 11.513' ,l 11.503' 29. ACID, SHOT, Ff~.ACTURE, C~IENT SQUEXZE ETC. D~i INT~.~ (MD) ] AAiOUNF z'~D }2!ND OF MA~PJ)L US~ See Attachmdng ~ ~ ~ ~ n ,,, ] Ug SE , .~ . DEPTH SET (MD) ] PACIfiER SET (_,'VID) DATE FIRST PIIODUCTI. ON [ PIIODUCT1ON MEI[iOD (Flowii*g, gas lif~, pumping--size and type of pump~ 8/2/74[ Gas Lift I '[PEOD'N FOR ,,,,~ o~ ~s~, I~ou~s ~'~ST~ ',c~-~o:<~ s~z~ o~. ~CF. ._ ~/9-,12/74 l! 96 ~ Il Open {~zs"~? { 20.096 I 6.112 140 usia I 1300 psig.! ~ ~ 5,024 [ 1~528 31. ~IS?OSiTIO~ O~ 0~8 (8old, u{ed Jot Jue{, v¢at¢d, etc.) Delivered to Marathon-Union Gas Gather.i. ng System .. I-Liner & Cementing Record, II-Perforating Record, & III-Directional Survey '" 33. I 'h~.reb~' certify that the'foregoing an(l~attac]ll~d information is complete and correct as determined from all-available recdrds t ii ill i i _ *(See Instructions and Spaces for Additional Data on Reverse Side) *Marathon Oil Company --- Sub-Operator INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lan:ts and leases in Alaska. item: 16: Indicate which elevation is used as reference (where not otherwise showrfl for depth measure- ments given in ether spaces on this form and in any attachments. Items 20, snci 22:: If this well is completed for separate, prcduction from more than one ir~terval zone (multiple completion), so state ~n item 20, and in item 22 show the prcJucir~g interval, or i~ter'vals, top(s), bottom(s) and name (s) (if any) for only the interva! rek~orted ir~ item 30. Submit a separate report (page) on this form, adequately identified, for each additior~al interval to be seperatety produce, J, show- ing the ackiitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of anY mul- tiple stage cementing end the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produc~l. (See instruction for items 20 ~nd 22 above). 114. SUMMAR~ ()ii` F'(.)iZNIA'I'ION TF2S'I'S IN(TLUI)IN(~ 'INTEaVkL TESTED, t>HESSURIg DATA AND ~C'~VE'RI~ OF OIL', GAS, WAT~ AND MUD , , ,, , Hemlo. ck, Bench .t~5, !2,120'-12,125'. ~: IHP - 5277 psi Used 3000' fresh water cushion IFP - 1326 psi (10 min) Recovered 51 BBLS oil-water-mud emulsion & ISIP - 3877 psi (30 min) 'G' Zone Hemlock 10,830' 8,645' 46 BBLS of formation water (17,500 ppm- FFP - 1620-3582 psi (4 hrs) 11,620' 9,417' cholorides) FSIP - 4049 psi (8 hrs) FHP - 5179 psi . Squeezed perfs with 100 sacks cement thru ret. ~ 12,105' Hemlock.~ Bench ~5~ 12,055'-12~0.60'. ~: I~ - 5179 psi (See Attached Sheet) ~. CORE DATA, Aq'I'ACI{ A~-D~: I)~.P~C~'E,D SHOWS O~' O1~, G~ OR ~VAq~{-. .. Attachment I ~'~' ~"~ August 23, 1974 TBUS WELL D-8 (REDRILL) K.A. Thoma LINER & CEMENTING RECORD 1. On 7/11/74, ran 3,817' (97 jts) of 7" OD, 29#/ft., N-80, X-line casing. Top of liner at 8,568~, screw-set packer at 8,574~, liner hanger at 8,576', collar at 12,343', and shoe at 12,385'. Cemented with 850 sacks of Class 'G' cement with 1% friction reducer & 0.4% retarder - 16.0#/gal. slurry. 2. A "Dry Test" (DST) of the 7" - 9-5/8" liner lap recovered 5,460' of salt water on 7/14/74. The liner lap was cement squeezed with a total of 450 sacks of Class 'G' cement (additives as above) in three (3) separate squeeze jobs. The lap was pressure tested with 2,500 Psi and held O.K. A subsequent dry test (DST) of the lap recovered no fluids - test O.K. 3. On 7/21/74, Hemlock Bench #5 was perforated from 12,120' to 12,125' (2 HPF). A DST was run with the packer at 12,077' (results of test on back of Form P-7). These perfs tested wet, so a cement retainer was set at 12,105' and squeezed with 100 sacks of Class 'G' cement with 1% friction reducer and 0.4% retarder. PBTD is at top of the retainer, 12,105~. AND GAS AI'-~CHORA©~ TBUS WELL D-8 (REDRILL) PERFORATING RECORD Attachment II August 23, 1974 K. A. Thoma HEMLOCK DATE BENCH , , INTERVAL, MEASURED DEPTH HPF 7/23/74* 5 7/31/74 5 8/1/74 5 8/1/74 4 8/1/74 3 8/2/74 2 8/2/74 1 12,055'-12,060'(-) 2 12,040'-12,060'(20') 4 12,030'-12,040'(10') 4 11,920'-11,936'(16') 4 11,784'-11,804'(20') 4 11,695'-11,775'(80') 4 11,655'-11,665'(10') 4 Total of 156' shot with 634 holes. TYPE GUN & HOLE SIZE 4" Casing- 0.44" 2-1/2" Ret. Strip-0.33" ,, ,, I, ,, ,, ,, ,, !I 11 I1 !1 11 Il II !I I1 !1 II I! *DST #2 - See back of Form P-7 for test results. Used 3000' fresh water cushion Recovered 22 BBLS water cushion & 42 BBLS oil with trace of mud IFP - 1727 psi (10 min) ISIP - No good recording FFP - 1498-1988 psi (4 hrs) FSIP - 3705 psi (8 hrs) FHP - 5179 psi These perfs (12,055'-12,060') left open on completion. ,, FLU I D SA M P L E D ,-A -' Ticket ~_~ ' Date 7/14/74 u_./ Number 598841 Sampler Pressure P.S,I.G. at Surface Kind Halliburton· Recovery: Cu. Ft. Gas of Job . WATER 'S}[UT O~F District ANcHO~ . . cc. Oil cc. Water Tester C, H. BOATMAN Witness __~-~._t_...~_O~'~r'l~ .... cc. Mud Drilling Tot. Liquid cc. Contractor Gravity °APl @ °F. EQUIPMENT & HOLE DATA [l(~ ' ' ' ' ' - sk ~ ~ .- - Gas/Oil Ratio ..... cu. ft./bbl. Formation Tested -' . RESISTIVITY CHLORIDE[ Elevation -- Ft. CONTENT · Net Productive Interval -- Ft. Recovery Water @ . °F. ppm All Depths Measured From. Kelly BushY. rig ' Recovery Mud __ @ °F. ppm Total Depth PPD 12,226 . Ft. Recovery Mud Filtrate ~ @ °F. ppm Main Hole/Casing Size 9 5/8" /-i. 7~/: .. . Mud Pit Sample @- °F. ppm Drill Collar Length . .. I.D. -- Mud Pit Sample Filtrate __ @ °F. .ppm Drill Pipe Length. 8513" I.D~ 4.276" Packer Depth(s) 8~38 ! · Ft. Mud We.!ght -- vis -- cp Depth Tester Valve 8520~ .. Ft. . TYPE AMOUNT Depth Back Surface Bottom ' Cushion WATER 2270 Ft. Pres. Valve .... 'Choke bubble hose Choke 3/4" .. Recovered 2270 Feetof water cushion ,, ~ p . Recovered. 5710 ' Feetof' muddy water ~" Recovered 10 Feet oi sand Recovered Feet of o Recovered Feet of " Remarks Op~]:t_tO~l for 65 minute f~_rgk flow w~th' gtron~ blow decreasing to dead · DIVISION OF OIL AND 6A$ j Gauge No. 3382 Gauge No. 338-1 Gauge No. ' ~'~'~' ......... TE[MPE[RATUR~ 8525 8551 T~ME Depth: F.t, Depth: Ft. Depth: Ft. 12 Hour Clock 12Hour Clock Hour Clock Tool 12 Est. °F. Blanked Off-~O Blanked Off Yes Blanked Off . Opened .. 8554' (~ .... · Opened 2:42 A.M. Actual 1_29 °F. Pressures Pressures Pressure's Bypass . xl~.~: Field Office Field Office Field Office Reported Computed Initial Hydrostatic 3470 '3458 3474 34.,~_~_ . Minutes Minutes Initial '1~95 .... --~148 2282 2.2._9_2 ' ] '. · '~o Flow I~'c Final 2900 2898 29],9 2~1 65 ~.~. . ..... Closed in 2900 2905 29_19 2953 .... 63 initial - ~o_ ~,~ Ftow FineI . ' . Closed in . :' _ Initial ' . '" . . . ;~] mow, ' ........... . ..... . ~.~.. Final ___ , . , · . . ,,. · , Closed in . . Fi. ual Hydrosta.tic- ~-0 3404 3460 341~ ..... ,. ' · , , , , FORMATION TEST DATA :i Drill Pipe or Tubing ...... ~ ....... Reversing Sub ...................... Water Cushion Valve ................ Drill Pipe ........................ 5" Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual CIP Valve .................. ~" Dual CIP Sampler ................. Hydro-Spring Tester ................... 5" Multiple CIP Sampler ............... Extension Joint .................... AP Running Case .................... Hydraulic Jar .................... VR Safety Joint ......... Pressure Equalizing Crossover ......... Packer Assembly ................... O, D. 6.12" 511 511 5" 8.25" I. D. 3I! 4.276" .87", .75" 3.75" 1.75" 2.44" 2 .'44" 3" {R~q~q~ .... ?e.r f.s'.·. ............ 2.87" Packer Assembly ................... Flush Joint Anchor ............ - ..... Pressure Equalizing Tube ......... Blanked-Off B.T. Running Case ....... ~~~ Temp.. Record.er ..... Anchor Pipe Safety Joint ............ 3.-87" 3.87" Packer Assembly Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...' ................... Flush Joint Anchor Blanked-Off B.T. Running Case ........ Total Depth ....................... LENGTH DEPTH 8513' 5.8g" 5.01' 4.02' 5.84' 3" 4.64' 8.77' 4.08~ .8515' 8520' 8525' 8538' 8551' 1.02' 8~54' OIL AND GAS PPD 12,226' E©L/IPMENT DATA FLUID SAMPLE D'%~,~ A .~ l~,,,, 7-18- 74 "'~ Ticket .... . Nu,~ber 59884'2 , Sampler Pressure .... P.S.I.G. at Surface Kh~it Halliburton · O Recovery: Cu. Ft. Gas !!t.J,l~, .. LAP TEST District ANCHORAGE cc. Oil cc. Water ..'!."'I"~ MR. BOATMAN Witness MR. POTTER cc. Mud Drllltnq r-- Tot. Liquidcc. C,mt,,,cl,~r PARKER DRILLING COMpA~¥ ..... DR,. S -< Gravity o APl @ _°F. _ EQ U.I P M E N T & HO L£ D A T A '~:, Gas/Oil Ratio .... cu. ft./bbl. 't'io~n,~lJon Tested - RESISTIVITY CHLORIDE [h,v~l ion_ - CONTENT Ft. Recovery Water _ @ °F._ ppm N~'t ih~,ductive Interval - Ft. All I~rplhs Measured From_~_el 1 v B~s-h ing r- Recovery Mud @ __ °F. ppm Tot~l Depth _._~1_2- 226' Ft. Recovery Mud Filtrate ~ °F. ppm Main ~tole/Cosing Size_ g ~/~, -fl Mud Pit Sample _____ @- °F. .ppm Drill Collar Length - . I.D - Mud Pit Sample Filtrate @_ °F. ppm Drill Pipe Length... 85_13i I.D. 4.276" Pock,,r Depth(s) ~537 ,' ...... · Ft. Mud Weight vis cp Deplh Tester Valve RS18 ~ Ft. , TYPE AMOUNT Depth Bock Surface Bottom Cush~on . 2270' Water Ft. Pres. Valve .~_ Choke Bubble Choke 3/4" hose Recovered 2270 Feetof ~a_._ter cushion .............. ~ ~. Recovered 30 .Feet of dril 1 lng f]_uid ............ Recovered Feet of < Recovered Feet of Recovered Feet of Re~arks Opened tool for 62 m~nute flo~. Closed tool for 62 m~nute f~nal closed i n. p. ressu re. , CH^RI$ INDICAIE poSSIBLE ,LEAKAGE.,.DURI~-CLOSED IN PRESSURE . ._ , ~ouge.~o. 33~ ~ouge No. 33~1 ~au~e'So. TEMPERATURE TIME Depth: 8523 Ft. D~pth: 8549 Ft. Depth: Ft. 1 2 Hour Clock 1 2 I'tour Clock Hour Clock Tool · A.M. ::~ Est.~__.. °F. Blanked Off NO Blanked OftYes Blank'ed ~)ff .... Opened 2' ~1 P.M. cz ~bbZ~' Opened A.M. -r' Actual. 85.97F. Pressures Pressures Pressures Bypass 4; 55 P.M. Field Office Field ..... Office Field Office Reported Computed InitialHydr0static 3518 ...... . 3513 3607 352~-',. " Him,to, M~,ute, ...~ ~n~t~a~ 701 686 713 715 ~'c Flow ' i -- '"' ~.~. Final 725 ,713-- 737 _74.~. 64 62 .. C~osed in 942 932 958 __985 .... ' 60 62 ~.~ Initial Flow Closed in , ~a,-, Initial ' , . >_.o_ r,ow ' . Final Closed in F,na, Hydro,ratio 3494 ._ ]35_13 _35_82_, ]-']..-;~528 .... "' FORMATION TES" DATA LITTLI['$ 1'S974 ~M t/?J First , First Second Second Third Third Flow Period Closed In PressureII, Flow Period ~ Closed In Pressure,. Flow Period ~' Closed In'Pres_sure Temp. Temp. Temp. Log I Temp. ] .0839 i 700* 0559 i 853** , _2 1538 t708 .0978 t 862 i 877 3 .2237 713 '1397 t 4 2936 713 .1816 i : 889 51 .3635 '713 .t ,,.235 ! I 913 !l 6 .4330 I713 654 'i 1.928 .7, ' .3073.i , 928. ! ~' ; ..... J ' I-[ k( -- s I. ~ ,3492t I 930. ...9 ..... ! .3911 ] 932J ' j to ;J.4330 I 932 t t I ]2 13 1,4 , Cauge No. 3381 .... DePth ,, 8549' Clock ot.000 715 ..000 742 "' 11.0807 732* .0539 885** .... . "' , 2 .1480 742 .0944 897 '" 3 .2153 744 .1349 909 4.2826 .. 744 !.1754"' ~ 921 ..... , s .3499 742 .2159 I 946 .i a .4170 .. ~742 .2564 958 ..... 7 ........ · ~ .2969 958 ...... .... 8 . . .3374 961 ........... J ............. ~ . .3779 971 ...... , · ,o . .4180 ['985 11 ...... ,, , ...... '13 ,, , ................ ~ ...... 14 ' ....' ' " I " Reading I.nte~al 10 6 ....... Minutes ,~E~RKS: * First 'intervAl equal to 12 minutes **-8 minutes. ..... , .......... , ...... ~ , ,, ~ ,, , ~ ~ ,, , FORM IIB3~PRI~TI~D IN U.S.A. SPECIAL PRESSURE DATA Drill Pipe or Tubing ....... :%~.,,, ...... Reversing Sub ...................... Water Cushion Valve ................ Drill Pipe ........................ Drill Collars ..................... Handling Sub & Choke Assembly ..... Dual CIP Valve ...... ............. Dual ClP Sampler .......... i. .. Hydro-Spring Tester ................ O0 D. 6.12" 5" 5I' 51, · 5" Multiple CIP Sampler ............... Extension Joint ................... AP Running Case ................ Hydraulic Jar ............ 5" VR Safety Joint ..... Pressure Equoliz'ing Crossover ......... Packer Assembly ................... 11 8.25" Distributor ........................ 2.87" Packer Assembly ................... Flush Joint Anchor ............... Pressure Equalizing Tube ....... Blanked-Off B,T, Running Case ....... Drill Collars .Tamp:. Recorder. .... Anchor Pipe Safety Joint ............ 3~87" 3.87" Packer Assembly ................... Distributor . . . - ................... Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor ................. Drill Collars ...................... Flush Joint Anchor . . .' ............... Blanked-Off B,T, Running Case ........ Total Depth ....................... Jo Do 11 4.276" .75" .,I 1.75" 11 · 2.44" 2.44" LENGTH 8513' 5.89' 5.03' 4.02' 5,84, 3' 4,64' 8.77' Perfs. 4:08' DEPTH 8513' 8518' 8523' ,~ 8537' 8554 ,°,-,.,-'"'-"°'-".'.*. EQUIPMENT DATA Ticket F L U I D S A M P L E D%,,,' A Dote 7-22-74 ',--~ Number 598844 Sampler Pressure ........... P.S.I.G. ~t Surface Kind HalliburtonR Recovc',y: Cu. Ft. Gas ........... of Job HOOK WALL District ANCH0 AGE cc. Oil cc. Wo~ T~ MR. BOAT~N wim~, MR. THOHAS . cc. Mud Drilling Tot. Liquid cc. Contr~ctor~K~R 'BRJLL[NG CQNPANY DR S Gravity. * Apl ~ *F. E Gas/Oil Ratio .....~ cu. ft./bbl. Formation Tested - ..... RESISTIVITY CHLORIDE Elevation . , CONTENT ~et Productive Interval~5' Holes 12120-12125' Ft. Recovery Water ......... (~ .... *F. __ ppm All Depths M~sured' From_~e~~B~s hi' ng ...... Recovery Mud ...... ~-----°F. ppm Total Depth. 12~13' PBD .Ft. Recovery Mud Filtrate ....... ~ __~ OF. ppm Main Hole/Casiag Size 9 5~] 7" Mud Pit Sample ..... (& _~ OF. ppm Drill Collar Length. ' ~ I.D - Drill Pipe Le.gth~531 '-8514' I.D.2~4" Mud Pit Sample Filtrate ~~.~OF ............ ppm Packer Depth(s)~ "1 2080' __.Ft. Mud Weight vis cp Depth T~ter Valve ]_~51 '~ . Ft. ...... TYPE AMOUNT Depth Back 2" 2~ C,,h~o, 300.0" Water Ft. Pres. Vo~,~ 12047' Surface Bottom Choke 1/ Choke 1/ ....Reversed : R~cov~r~d 51 ~of bbls. of 0il . Recovered 22 ~X bbls. of water cushion . Re~o,o~d 46 ~X bbls. of water < Recovered Feet of Recovered Feet of Remarks ..Q.pened tool for 10 min~t~ firs_t flow. Cl_osed tool for 31 mi~.~ first closed in pressure. Reop~d.].o_~~~~~a.s to surface in 115 minutes,-headinq blow remainder of..test. Closed tool 'for 480 minute second closed in pressure. Gauge N0. 3382 G~-g~ No. 3381 T~ATU~ . ,, g~,h: 12065 ., r.t. Depth: 1 20~2 Ft. Depth: Ft. 24. Hour Clock 24 Hour Clock Hour Cl~k Tool A.M. Est. OF, Blanked Off No ~l-~nked Off Yes, Blanked Off ,,, Opened 9-1 12097', . Actual 143 *F. Pressures Pressures PresSures .. Bypass g .... ,, Reported Computed Field Office Field. Office Field Office 'J .~inutes Minu}es Initial Hydrostatic ...~.~ ~.~ ...... ~_247 5277 ~5~.~ ', _ - _ ~,]L~]_. 1 302 14g.9_q ] 3_26 _]2990 ~ r~o- ~.~,"~-6'6"0---'~ .... .],6~.5 ............ !66_9 J~l~' 10 ,10 ~ C~o,~d i, 3874 3872 __3_8Z7 ]B~ . .. 3fl 3! ~ Initial 1636 ]_5]..~_ ]620_ _]52Z. c o Flow ........... 8c Final 3565 355~ _35~.~ ._].~8 C~o,,d ~, 4040 ...... &0g5_ .A049=:~ 4059 ~.o Flow' ~ ~ ............ Closed in ..... Q-Q~estionabl~ ' ~., · .... · ,, . ~'ORM IIII--PnlNTI~r) I1~1 U,S,A, FORMATION TEST DATA Gauge No. First Flow Period Time Deft. .000" o!.ooo ~t.035 J t 3 ~luggi-n~ Depth 1,_'~,~,.,' Clock No. 8739 ; 24 hour ! No. 598844 3382 · . First Second ii Second ~J Third Closed In Pressure Flow Period Closed In Pressure ,~ Flow Period · Temp.PSlG Time Deft. Log-~ I PSIG Corr. .000" Corr. 1409Q .000 ·11655 1655 .010 , !3698 Q20 '3760 · 030 3798 .040 !3822 ,050 ]3838 _,_060 I ,i3850 070 ~ 13860 ~ 080 J ' j3867 .090 13a72 t si I 6j i Corr. Time Deft. t PSIG jj Time Deft. .000" .000" .000 .0034 .0067 i!.0101 ' ilo134 .0168 0202 .0269 .0336 _352g .6721 (99! 3 ! _3!06 L' t -J- I~ j Time Deft. ogT'J Temp.PSIG Corr· :. .000" 3556 3876 3903 3917 3926 3931 3936 ,3938 3941 3943 3q4_~ 4N05 ao24 4o33 4o4o !. 61 3 4045 Tlq. ird Closed !n Pressure PSIG Jj Time Deft. Temp. Corr. :!J .0C0" Temp. !!.000 j.1413 !2088** 2758 ,2510 .4103 i2845 · 5448 3109 · 6793 J3354 .8140 J3556 Log t ~- ~ PS:G Temp. Corr. Gauge No. j o .000 7, 035 3381 " Depth 1 2092' Clock No. 8420 hour 24 1299Q 000 1672 .000 1527 000 3568 1672 .0101 3722 .1404 2096** 0033 38'/2 J'2j .0202 3781 .2741 2520 0066 3904 Pluggi~g .0303 3816 .4078 2855 0100 3921 J 4J .0404 3838 .5415 3125 0134 '3'931 .0505 ' 3850 .6752 3364 ·0167 3939 ..... .0606 i 3862 .8090 3568 ·0200 3943 · 0707 i 3872 0234 3946 ~ .091 0 3877 .0301 . 3953 · ,...0334. ... 3958 .3506 J4'ol / i'2t · . .6679 4034 J t~3 .9851 4047 1.3024 4057 -. , ~ ~ ,, t,,,603 405'9 I Intervol 3 * 40 *** ..... Minute.s tREMARKs: q-qUestionable *-0nly .27 minutes seqmented **-42 minutes ***- First 10-intervals equal to 1 minute Iach'; .hex'it'4 intervals equal to 95 minutes each~ last interval equal to 90 minutes, fo .......... -=.,,,,,,,.,.,,. SPECIAL PRESSURE DATA '- O, D. h D. LENGTH DEPTH Drill Pipe or Tubing ...... ~ ....... Reversing Sub ...................... Water Cushion Valve ................ Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly Dual CIP Valve ................. Dual CIP Sampler ............ Hydro-Spring Tester ............ 3.87" 3~,, 11 3.87" 3.87" 3.87" 4.25" Multiple CIP Sampler .............. Extension Joint AP Running Case .. Hydraulic Jar VR Safety Joint Pressure Equolizi.ng Crossover ....... Packer Assembly .................... 5_, 75" Distributor ..................... 2.87" Packer Assembly ................... Flush Joint Anchor .............. Pressure Equalizing Tube ......... Blanked-Off B.T. Running Case ....... Drill Collars Temp,..recorder. ..... - Anchor Pipe Safety Joint ............ 3.87" 3.87" Packer Assembly .................. Distributor ....................... Packer Assembly ............... Anchor Pipe Safety Joint .......... Side Wall Anchor ............... Drill Collars ...................... Flush Joint Anchor ................. Blanked-Off B.T. Running Case ........ Total Depth .................... 2.764-4,276" .87"' · 50" · 88" 3" 1 . 37" 2,44" 2.44" 3.60' 3531 '-8514' -4-T88' - '8 :'99' ' ' 6.72' 4.58' 10.26' 3.99' 8.77' Perfs. 4.07' .g7' 12047' '12051' 12065' 12080' 1 2092' 12097' f~Ol~M 117--1IIIIINTI~I:) IN EQUIPMENT DATA F L U I D S A M P L E D'~'F ^ Date 7-24-74 "-,.~' Ticket Number 598845 Sampler Pressure P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ftl Gas of Job HOOK WALL District ANCHORAGE cc. Oil CC. Water .............................................. Tester C.H. BOATMAN Witness KEN THOMAS cc. Mud ...................... Drilling Tot. Liquid cc. Controcto~PARKER DRILLING COMPANY SM S ............... :,, ,, _ : , ~, ,~,,,, ~ ....... , Gravity. ° APl @ °F. E ~ U tP M E N T & H O ~ E D A T A Gas/Oil Ratio .... cu. ft./bbl. Formation Tested, - ,, RESISTIVITY CHLORIDE Elevation 106' Kelly_ bushing Ft. ' CONTENT ' - Net Productive Interval. 12055-12060' Ft Recovery Water ......... @ ..... °F. ppm All Depths Measured FromKe.] l_.y' bushing Recovery Mud .... ~ ~__ °F., ppm Total Depth 12! Cl.5' Ft. Recovery Mud Filtrate ~,_ ~ ...... °F. ppm Main i~lole./Casing Size 7" L,~ Mud Pit Sample ..... @ ~ °F. ppm Drill Collar Length 35'9_4' .... I.D .... ~_,_7_~_4" ___~].p_e · Mud Pit Sample Filtrate C_~ °F. _ppm Drill Pipe Length Z__8_3_SJ~3~ I.D._ 4.276" Packer Depth(s) 129_]..]_~_ Ft Mud Weight . .................. vis cp- Depth- TeSter Valve 11982 ~ Ft. ....... TYPE AMOUNT Depth Back Surface 2 n ' Bottom C,sh~on water 3000 Ft. Pres. Va~:~. 11978' Choke 1/ Choke 1/2" Reversed. out Recovered 1 bbl. FZ~t of oi 1 ...... Recovered 22 bblFx~of water cushion ........ ., , Recovered ..4] bb 1 J:x~t of oi 1 ....... < Recovered Feet of ......... Recovered Feet of ...Remarks Tool opened for 10 minute first flow period. Closed tool for 46 minute first closed in pressure period.....Too!, reope.n..e.d for 246 minute .second flow .with a medium blow throughout test_Lgas to the surface in 207 minutes of Second flow. Closed tool for 478 minute second closed in.pressure period CHARTS. INDI_CATE .. INITIAL CLOSED IN PRESSURE MISSED · GaugeNo.' 3382 Gauge No. 3381 'Gaud~ No. ' ' TEMPERATURE TIME · Depth:119.96 Ft. D,p..t,.h.: ,,12023 "t, Depth: Ft. ,, 24' HourCIock 24 HourCIock HourClock Tom 23rd A.M. . ,, Est. °F. Blanked Off no Blanked Off Yes Blanked Off' ..Opened 9'47 P.M. Opened ' A.M. ...Actual 137 °F. Pressures Pressures ....... Pressures . .. Bypass 1 fl' 47.M. Field Office Field Office Field Office Reported Compu~e~d _1 n i__t_i_o I_]-I__Y_d_r.o_s_tat!.c_ 5174 .... .5] 9.3 ......5]_7_9 520~L:.......... _~,,te, ~,itia~ 1349 1347 ]326-- ]355_ - ~ Flow .............................................................. ~2-- F~na, ,. 1_~17 ........ ]_490 .... 15~tZ__ ,1493_ ,lQ. . 10 Oosed ~, - .:His s. ed .... - __[4i:ss ed_ 46 46 ~: ~ni,ia~.__1_~9_3__'.:__J50.0__'_~_: ']_49.8_· 15._05_ ' c o Flow ......... ' ' ' o~.~ F~na~ .1995, _]99.0 ..... ]]9.8~_ ]998_ 244 ' 24~ Oosed ~,~~] 37.08 ..... 37_0.1.] - 3705 .... 3]_Q5_' . .. , ~SO · 47R I,o'o Initial ,- . ; _~.o_ Flow .................... · .......... !~ ~, ~ Final ...... ' _' ~" -~losed in ~ Final Hydrostatic ..... 1_51.4 ....... :_516Z ........... 5_lZg_ ..... 5].82__ ._ , · . . FORMATION TEST DATA .. Gauge No. 3382 Depth 11996' Clock No. 8739 t 24 hour ! No. 598845 First First il Second j, Second Third Third Flow Period , Closed In Pressure ., Flow Period j! Closed In Pressure ,. Ftow Period il CLosed !n Pressure Time Deft. .OOO" Time Deft. .000" ~.0000 1.0068 }.0136 i.0204 }.0272 1.0340 6i 14 151 PStG Temp. Corr. 1347 1388 1421 1455 1481 1490 Time Deft. Lo g ..L~ .000" MISSED i PSIG '; Temp. ;] Time Deft. Corr. !! .000" .0000 546* .289l .4236 It o 5581 .6925 .8270 PSIG Temp. Corr. 1500 1622 1699 1751 1811 1897 1990 .0000 .1009'* .2085 .31.61 .4237 .5313 .6389 , .7465 .8541 .9617 1.0693 !.1769 .1.2845 1.3921 1.4997 1_ 6070 Log t,+/9 PSIG Temp. Corr. Time Defl. 1990 , 3639 3663 3675 3679 3682 3686 3689 2691 3691 3694 3696 3698 3698 3698 37fll PSIG Temp. Corr. i,i Time Deft. i Log t + ~ J t .ooo" i' Tcmo. Cerr Gauge No. I oj .0000 I ~ _o066 [ 3 .0198 J 4 n?t~4 IsJ-- n330 3381 Depth 12023' I1 355 1400 1.426 ~1458 1483 · 1493 l t MISSED .0000 .1546 .2891 _4236 .~SR1 ,8270 1505 1703 !76fi !821 !900 !998 Clock No. .0000 t. .1007'~ 20~ t 6377 .7451 .8525 ....... 9599 842( 24 hour 1998 .3646 3666 3678 3686 " 3688' 3690 369'3 3695 3698 1.0673 1.1747 llo) 370O 3703 JReadinCJ Interval l, 2821 1. 3895 1_49~9 4~ *F~rst Jnterval Js..equal to 46 mjnutes. ** J 3703 , I 3705: I 370fi J 3705 = 30 mJnu~es. Minutes SPECIAL PRESSURE DATA O, D, Drill Pipe or Tubing ............. · ~'" __3~ 87" Reversing Sub ......... Water Cushion Valve ................ Drill Pipe ......................... -----5II Drill Collars ..................... .3½" Handling Sub & Choke Assembly .... Dual CIP Valve ................... Dual CIP Sampler ........ Hydro-Spring Tester .. HOd 3.87" Multiple ClP Sampler ............... Extension Joint .................. ' 3.87" AP Running Case ............... Hydraulic Jar ............... 4.2.5" VR Safety Joint .... Pressure Equalizing Crossover ......... Packer Assembly ................... 5.75" m~m~mx Pet'fs .............. _ 2: R7" Packer Assembly .................. Flush Joint Anchor ............. Pressure Equalizing Tube ..... Blanked-Off B.T. Running Case ....... Drill Collars ................... Anchor Pipe Safety Joint ............ 3.87" 3'. 87" Packer Assembly ........... : ....... Distributor ........................ Packer Assembly ................. Anchor Pipe Safety Joint .......... Side Wall Anchor .............. Drill Collars ...................... Flush Joint Anchor .................. .Blanked-Off B.T. Running Case ........ Total'Depth ' LENGTH ~ 4._2Z6Z' 2.764" 1, ., 1.37" , . 2.44" 2_ 44" DEP 388_ 3594' i 8.99' 119_82 ' 6.72' 4_,_58' 10.26' 11996' 3.gg' _ 8.77' 12011' 4.07' .97' 12023' 12028' EQUIPMENT DATA MARATHGN OIL COMPANY T B U STATE 0-8 (REORILL) MCARTHUR RIVER ALASKA ...... SPERRY-SUN 'WELL-SURVEYING ANCHORAGE, ALASKA COMPUTATION--DATE MEASURED DEPTH O .......... PAGE '-1 f~D~,TE OF SURVEY JULY 19. 1'}74 '-'--]3k~RWEL GYROSCGPIC MULTISHOT SURVEY .Cw~ NU B,.R SU-3-168go %' ~'J~-'ELLY BUSHING ELEV. = 106.90 FT. .... ""~ERO POINT* INCLIh, C,'"ETER AT KBE ,"7' "'-.. · TRUE VERTICAL VERTICAL DEPTH DEPTH SUB-SEA COURSE· COURSE OaG~_ v~. TOTAL --INCLINATION- DIRECT ION"7"SEV~ RECTANGULAR" COOROINATES ....... VERTICAl2 ..... DEG MIN DEGREES OEG/IO0 NOFRTH/SOUTH EAST/I,,E ST SECTION · . 600 700 BO0 900 lO00 IlO0 1200 1300 1400 1500 1600 .......... :- 1700 1800 lgO0 2000 2100 2200 2300 2400 2500 2600 .... 27.00 2800 2900 - 3000 3100 3200 3300 3400 3500 3600 599.73 699.31 798.57 897.52 996.00 1094.05 1191.78 1289.07 1385.26 492.83 ......... 4 ..... 0 ....... S 21J-0'--~ ........ 6'.00 ............. 6.19 592.41 6 .34 S 8. 5 E 3.63 691.67 7 30 S 30.60 E 2.89 790.62 ........... g ....5 S 26'75"E ......... 1,67 889.10 to 50 S 23.4i E 1.84 987.15 Il 50 S 21.89 E 1.04 1084.88 12 35 S 22.88 E 0.78 1182.17 14 32 S 47.89 E 6.12 1278.36 17 .12 $ 47.90 E 2.66 S- 2.23 15.11 S 1.7H 26.39 S 5.90 39.05 S ............... 12.77 54.73 S 20.06 72.86 S 27.62 92.41 S 35.68 110.88 S 49.23 129.21 S 69.51 1480.18 ....... i373,28 ........ 19---25 ...... '$'-'~48.7~- E 1573.93 1467.03 1666.53 1559.63 1757.89 1650.99 1847.93 1741.03 1936.45 1829.55 ...... 2023.27 ...... 1916,,37 2106.65 1999.75 2186.44 2079.54 2266.24 2159.34 2346.03 2239.13 2423.38 2316.48 2497.19 2390.29 2567.98 2461.08 2637.69 2530.79 . - 2707.60 2600,70 2777.67 2670.77 2847.51 2740.61 ........ 29t ?,45 ......... 28 i'0 J 55 2987.75 2880.85 2.23 21 15 S 48.25 E 1.84 23 5 S 47.76 E 1.84 24 ..... 52 ......... S 47.26 E ......... 1.79 ............ 26 41 S 47.21 E 1.81 28 44 S 47.17 E 2.05 30 44 S 46.72 E 2. Ol 36 13 S 46.61E 5.48 37 54 S 46.64 E 1.68 36 .... 13 $'--'46-' ...... 2 E ..... 1.72 37 54 S 45.28 E 1.74 40 45 S 44.74 E 2.87 44 5 S 44.39 E 45 48 S 47.60 E 45 49 S 47.54 E 45 .... 28 ...... S'-47,44-E 45. 34 S 47. 4 E 45 50 S 46.89 E 45 25 S 46.84 E 45 15 S 47. g 399.98 S 363. 441.58 -S ........... 406. 483.71 S 449. 528.51' S 494. 3.34 576157 S ............. 541. 2.84 625.60 S 592. 0.07 673.98 $ 645. O: 36 .......... 722 ~'29 --'S .............. 698 . 0.30 770.73 S 750. 0.29 819.57 S 803. 0.42 ...... 868 ~-44-"S ..... 855. 3128"31 ........ 3021.41 45 32 $ 46.65 150.07 ....$ .............. 92.99 173.09 S 119.01 198.34 S 147.05 225.78 S ....... 177.00 255.31 S 208.92 286.90 S 2%3.03 320~'76" $ 279.26 358.60 S 319.36 16 74 83 63 77 69 40 O9 25 E 0.25 916.98 $ 907.23 0.31 965.54 S 959.09 O. 24 ......... 1'0i41-43"S .... lO'iO'. 89 E - 5.a6 E 11.64 E 22.38 E 36.06 E 52.10 E 70.03 E 89.30 E 111.82 E 139.16 E' i70.55 E 205.~.~g E 242.99 E 283.62 E 327.09 E 373.58 E 42'3.17 E 478.3! E 538.56 E .......... 598' 82 E 659.06 E 722.39 E 789.79 E 860.40 E 932.09 E ........... i003,5{3 E 1074.93 £ 1146.49 ~ .... 12172'97 E 1289.09 E 1360.14 HARATHON OIL COHPANY - . T B' U'STATE 0'-8- ( REDR[ LL) MCARTHUR RIVER Sp~-RRyLS'UN--~Ei~L-SURvEY Mp/~y ................................................... PAGE .... 2 ' ANCHORAGE, ALA~_. ~ ............... ~ :.c ~-[~, DATE OF 5~RVEY JULY 19, 197~ COMPUTAYI'ON Ol~ -~ O-SURWEL GYROSCOPIC-NULTISHOT-S'ORVE'~ ALASKA TRUE -MEASURED--- VERTICAL DEPTH DEPTH ':2 JOB NUMB ~ ~' ~. ~ KELLY B 09 ",- '% SUB-SEA COURSE COURSE ~G-LEG~ TOTAL ~---VERTi-CAL INCLINATION D[RECTI'ON ~-T?'~ RECTAN-~0CAR COOROIN~-TES VERTICAl- DEPTH DEG MIN DEGREES u~bTIOO~NORTH/SOUTH EAST/WEST SECTION ER SU-3-16890 USHING ELEV. = 106 90 FT. INT~,-INCLiNOMETER'~T-'KB6 ...... 3700 .... 3198~8 -~69[~-~8 --45 20 S 46.65 E 3800 3268.79 3161.89 45 t9 S 46.53 E 3900 3339.17 3232.27 45 13 S 46.44 E -~" --~000 .... 3~09.54 3302,-64 45 20 S 46,36 E. 4100 3479.86 3372.96 '45 18 S 46.26 E ....... 4200_. 3550.44 3443.54 44 55 S 46.13 E 4]00 362[.~7 ....3514;47 ............ 44-'4'$ .... s' ~6:"t-'E · 4400 ~692.67 3585o77 44 20 S 45.93 E 4500 3764.42 3657.52 43 58 S 45.53 E 6;'-2o--1o6~,3~' S-- 10~2='7o 0.10 1112.20 S 1114.36 E 1573.72 o.13 il61.11 S 1165.~8 E 1~4.75 6=i'4-- i2iO,'it s-- 12i7.33 E O. ZO [259.22 S 1268.7~ E 1786.90 0.40 [308.26 S 1319.87 E [857.7~ 0.~2 1357. t6'"S ....... 1370.63 E 1928.2~" 0.39 tAos.9o s i,zl.o, E 1998.33 0.~6 l~5~.~z s i~70.gz E 2067.97 z, 600 ........ ]S36~61 ...... 3729~71 43 36 S 45~-77- E-- 4700 3909.19 3802.29 43 20 S 45.29 E 0.42 1551.08 S 1569.49 4800 .... 3982.~2 ..... 3875.52 42 30 S AS.I~ E 0.8~ ~59g.04 S i617.82 4900 ~055.95 3949': 05 ......... 42 -'~0 ..... S - 45'.'i i'-E ..... 0:~33 .... 1'646.8~-' ~ .........1665-,-85 5000 ,129.58 4022.68 42 20 S 4~.63 E 0.59 1694.81 S 1713.58 5100 ~203.56 ~096.66 ~2 15 S 44.53 E 0.22 17~2.83 S 1760.73 ................................ __ 5200 4277.95 4171.05 ~1 37 $ 43;8~ E 0.7~ 1790782 S 1807%22 5300 4352.87 ~2~5.97 41 20 S 43.5~ E 0.35 1838.71 S 1852.97 5400 ...... 4~27.96 4321.06 4~ 20 S 42.12 E 0.93 1887.1~ S 1897.87 5500 ~502.32 ~395.W2 42 35 S 45;-2~ E 2.~1 1935.47 S 1944;03 5600 457~.8~ ~67.9~ ~ Z5 S 45.9~ E ~.89 1983.66 S ~993.~7 5700 ~6~6.17 4539.27 5800 .... ~7~7,3~ ........ ~6~0';~ 44 .... 40- ......S '45.~ E 0.29 2081,6i"S'- 2093.67 5900 ~789.~7 ~682.57 ~2 60 S ~5.63 E 1.67 2~30.13 S 21~3.07 6000 ~863.26 4756.36 41 53 S ~5.83 E 1.12 2177.2~ S 219[..39 6[00 4938.32 463[.~2 40 50 S 47.93 E 1.7~ 2222.40 S 2239.51 6200 50[~.5~ 4907.64 39 50 S ~8.9~ E 1.19 2265.34 S 2288.C2 6300 5089.91 ~983.01 ~2 20 S 49.93 E 2.58 2308.06 S 2337.95 6400 5163.09 5056.[9 .... ~3 35 S 49.72 E 1.25 2352.0Z S 2390.01 6500 523~.~6 5127.56 W5 20 S ~9.92 E 1.75 2397.21 S 2443.52 6600 5303.87 5196.97 46 45 S 50.4I E 1.46 24~3.31 S 2498.79 6700 5371.85 5264.95 17 o. 4o '1'~02'; 89 s 152o ;~;o .... E ....... 213'7;·'15- E 2205.93 E 2274.00 -E E 2409.37 E 2476.61 - E-- 25~3-, 36 E 2609.49 E 2675.37 E ........... 2742,11 E 2810.92 E 2881.00 E 2951,23 E 3020.46 E 3087.93 E 3153.99 E 3218.68 E 3284.32 E-- 3352;37- E 3422.30 E 3~94.15 '~ 3567.31 MARATHGN OIL COMPANY T B U STATE D-8 MCARTHUR RIVER ALASKA TRUE .. MEASL'RED VERTICAL - DEPTH DEPTH SPERRY-SUN WELL SURVEYI~o~AN¥© PAGE 3 ANCHORAGE, ALASK=~:=, ~ -,~ ............................. ,- ..~.,_.."'-' _~DATE OF SURVEY JULY 19, 1974 (REOR[LL! -COMPUTATION DAT~"-r~. s'i~'SURWEL"GYROSCaPIC MULTISHOT SURVE~ ~ . ~JOB NUMBER SU-3-16890 ~ '= ~ KELLY BUSHING ELEV = ~06 gO FT. ........................................ ~ ...... ~ ..... - F~ ZERO POINT~ INCLINO~ETER AT KBE -- SUB-SEA COURSE COURSE OOG-L EG ~ TOTAL VERTICAL INC[ItATION-'DIRECTION .... SEVERITY ..... R~CTANGULAR COORDiNaTES ...... VERTICA['- OEPTH DEG M[N DEGREES DEG/IO0 NORTH/SOUTH E~ST/WEST SECTION 6800 6900 7000 7100 7200 7300 7400 7500 7600 7700 7800 7900 8000 8100 8200 8300 8400 8500 8600 8700 8800 8900 9000 gIO0 9200 9300 9400 5438.60 5505.08 5572.37 5639.98 5707.64 5775.42 5843.08 5911.49 5331.70 48 40 S 53.62 E 5398.18 48 0 S 53.56 E 5465.46 47 25 S 53.t0 E 5533.08 47 30 S 52.89 E 5600.74 47 20 S 52. 5 E 5668.52 47 20 S 51.82 E 5736.i8 47 30 5804.59 46 lO. 2.28 0.67 0.67 0.19 2 0.64 2 0. I8 2 S 51.56'E ............. 0.'26'--: .... 2 S 51. 9 E 1.37 2 ..... 5980.80 5873.90 46 5 S 49.84 6049.15 ......... ~942.25 ............~7---40 S 48.83 6116.87 6009.97 47 5 S 47.85 6184.16 6077.25 48 20 S 47.18 6255.38 6148.48 40 ..... 45 S 46.57 6326.18 6219.28 49 0 S 46.48 6391.79 6284.88 49 0 S 43.67 E 6458.37 6351.47 47 30 S "~3~ 27'-'~ 6527.27 6596.73 .. _ 6665.93 6420.37 45 25 S 47.26 E 6489.83 46 35 $ 47.18 E 6559.03 ........ 45 ..... 50 ............ S"' 47.60 E O.gO E 1.74 E 0.92 E 1.34 E 7.59 E 8.25 2.12 '--1-,-53 3,56 1.17 E ........-0.8 [ 6736.38 6629.48 44 35 S 47.87 E 6808.16 6701-26 43 40 S 47.76 E 6881.89 ......... 6774.99 41 20 S 51.90 E 6958.20 6851.30 39 I0 S 50.86 E 7036.55 6929.65 37 40 S 50.42 E .__ 7117.90 7011.00 ............. 33 .... 25 ...... S'47o8! '"E 7202.34 7095.44 31 20 S 46.13 E S 42-76 E S 41.80 E S 42.37 E $ 41. 8---E 1.26 0.92 3,~4 2.26 1.52 4.51 2.26 7288.17 7181.27 30 -25 S 44.20 E 9500 7374.80 -'7267~90 29 30 9600 7463.55 7356.65 25 20 9700 7555.01 7448.11 22 20 9800 ......... 7648.54 .......... ~541=64 ................ i9 ..... 5 1.35 1.16 4.19 3.00 .~-28- - '2535,33 S ......2614.39 E ...... 3641.q0' 2579.67 S 2674.51 E 3715.57 2623.84 S 2733.84 E 3789.06 668.L9 S 2792.68 E 3862.30 713.04 S 2851.07 E 3935.56 758.37 S 2908.96 E ............... ~008.79 804.02 S ........ 2966.74 E 4082.15 849.59 $ 3023.68 E 4154.85 2895-4,7.__5 ............ 3079..27 E 4226.78 2943.03 S 3134.62 E ...... 4299.68- 2991.94 S 3189.59 E 43 73.23 __ _3041.9o s E 3089.79 S 3295.3I E 4517.28 3138.30 S 33~6.46 E 4587.78 319L.58 S 3399.88 E 4663 3245.7i 'S ......... 345[.20 E ......... 4737.67- 3296.74 S 3502.64 E 4EIO.Og 3345.60 S 3555.4~ E 4882 02 3394,47-'-S ......... 3608.56 E ........... 495~'20"' 34~2.I9 S 3661.08 E 5025.L5 ...... 3488.9~ S 3712.66 E 5094.76 3 532.54--S ......... 3764.22 E .... 5['62. I9 3572..85 S 3814.70 E 5226.58 36[2.25 S 3862.74 E 5288.57 3650~23 S .... 3906.72 E ............... 5346162-- 3686.7~ S 39~5.86 E 5400.15 3722.9I S 3982.26 E 5451.~4 3759-:"~ 3'-'~ 40 i'6 ~-62 E ....... 550L~9"' 3793.I7 S 4047.6I E 5547.[8 3823. I7 S 4074.68 E 5587.45 3849~'53---S 4098~-23"--~ .... 5622'~67 MARATHON OIL COMPANY T B U STATE D-8 MCARTHUR RIVER ALASKA MEASURED DEPTH ............. SPERRY-SUN -WELl] SURVEY[N~MPA-N~ ~,~ PAGE--4 ANCHORAGE, ALASKA~-~'" --'-' ._~ E OF SURVEY JULY lg, 1974 WEL GYROSCOPIC MULTISHOT'-SURVEY (REDR[LE) ................................COMPUTATION "DATE ~ ~i ~B NUMBER SU-3-I6890 ~ L~-~ ~ELLY BUSHING ELEV. = 106.g0 FT. __ ~ _~ _ ~ ..-.]"ZERO POINT~ INCLINOMETER AT-KBE SUB-SEA _.. COURSE CCURSE . DO ~ TOTAL [ NC'L I NAT ION--O [ RECT iON SEVERITY .... RECTANGULAR COORDinATES ...... VERTICAL DEG MIN DEGREES DEG/IO0 NORTH/SOUTH EAST/WEST SECTI ON TRUE VERTICAL VERTICAL DEPTH DEPTH 9900 (- 10000 10100 · 10200 10300 10400 10500 10600 10700 10800 lOgO0 lIO00 lllO0 11200 11300 ll400 11500 11600 '( 11700 11800 11900 12000 12100 12200 12250 7743.69 7636.79 7839.49 7732.59 7935.45 7828.55 8031.87 7924.97 8128.79 8225.87 8323.16 8420.93 8518.9B .... 86t7.25 8715.70 16 40 .......S 42*85 E ......... 2.-47 ..... 31~72'37 S .... 16 40 S 43.15 E O. lO 3893.34 S 15 60 S 44.38 E 0.75 3913.66 S l~, 45 ........ S '45.25 'E ............. 1"27 ..... 3'932.47 $ .......4176.41 8021.89 13 45 S 44.89 E 1.00 3949.85 S 4193.84 8118.97 ......... 14 ...... 0 ...... S 47.16 E 0.60 3966.49 S 4211.09 8216.26 12 40 S 48. 2'E ............... 1.34 ......... -3982.05-'S .... 4228.11 8314.03 11 35 S 50.40 E 1.19 3995.79 S 4244.00 8412.08 ll 5 S 50.32 E 0.50. 4008.32 S 4259.13 8510.35 lO 12 S 50.76 E 0'i'88 --4020.06"S ...... 4273.39 8608.80 to o $ 51.68 E 0.26 4031.04 S 4287.06 ~118.73 E ...... 5653'24 4138.29 E 5681.86 4157.73 E 5709.9~ E ....... 5736,44 E 5761.04 E ........5785.01 E 5808.07 E 5829.05 E 5848.66 E 58~7.09 E 58~4.57 8814.17 8707.27 10 5 S 49.65 E 0.36 4042.10 S 8912.36 8805~46 ............... I1.'--~0 ....... S"-~9~'35 E 1.58 4054.35 S 9010.19 8gO3.2g Ia 15 S 46.75 E O.?g 4C68.20 S 9107.74 9000.84 13 lO S 46. 5 E 0.93 4083.38 S 9204.92 9098.02 14 5 S -/~7"~31 E 0.96 4,099.53 S 9302.03 9195.13 13 30 S 46.52 E 0.61 4115.81 S 9399.40 9292.,50 12 50 S 44.77 E 0.77 4131.73 S 9593.92 9487.02 9689.79 9582,,89 ..... 9784 ,'5~ ..... 9677.'64 9877.92 9771.02 9c~69.7c~ 9862.8,:J 10015.18 ........ 9908'.28 9496~92 ......... 9390.02 ......... i2 ..... 45 ....... S- ~'3,-4'" E ............... 0'39 .... 4147~'68 S 15 22 S 45. 8 E 2.66 4165.10 S 17 35 S 46.90 E 2.27 4184.78 S i9 ~0 s 46.83 E 2.08 22 lO S 46.23 E 2.50 24 20 S 48. 5 E 2.28 ......... 25 ..... i3 ........ S-~'8J50 E 1.80 4206.61 S 4231.17 S 4258.00 S 4271,'94-S 4300.54 E 5901.96 ...... 4314.88 E ......... 5920.81 ..... 4330.28 E 5941.52 4346.20 E 5963.51 4363.35 E 5987.07 A380.76 E 6010.90 4397.05 E 6033.67 ............ &4'12.40 E 6055,78 4429.32 E 6080.0~ 4449.73 E 6108.39 4473.03 E 4498.92 E 6176.01 4527.87 E 6215.47 45~3.51E HORIZONTAL DISPLACEMENT = 6236.42 FEET AT SOUTH, 46 DEG. 45 MIN. EAST THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE OIMENSIONAL RADIUS OF CURVATURE METHOD. MARATHON OIL COHPANY T B U STATE 0-8 (REDR[LL)- HCARTHUR RIVER ALASKA ALASKA [NTERPOLATEO VALUES FOR EVEN 1000 SPERRY-SUN WELL-SURVEY[~'CO~P~Y ................................ PAGE o ANCHORAGE· ALAS~ '~- u.? COMPUTATION D ~ KELLY BIJSH[NG ELEVo FEET OF HEASURED DEPTH "- -'-._-,L gATE OF .SURVEY JULY ].9, 1974 ; ~ SURWEL GYROSCOPIC-HULTISHOT'suRvE'~ n.. ~ ~. JOB NUMBER SU-3-16890 [,-~ "' 57 KELLY BUSHING ELEV. = !06.90 FT. ~ .....-.--~ ......... '"i <"' ZERO POINT* [NCLINCMETER AT KBE = 106o90 FT. ......... TRUE ......... SUB-SEA ..................... TOTAL- ..................... , (' '~ASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVO VERTICAL ",,~EPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECT ION } 6(]0 599.73 492.83 6.19 S 2.23 E 0.27 1600 1573.93 1467.0'3 173.09 S 119.01 E 26.06 2600 2423°38 23[6.4.8 52e.s1 S 494.63 E 176o61 ~ 3600 3128.3]. 3021.41 L014.43 $ 10].0.89 E 471.68 4600 3836.61 3729.71 1502.89 S 1520.40 E 763.38 ....... 5600 ....... ~574.84 4467.94 1983"6'6'"~ ..... 1993','17 'E ;~ 6600 5303.87 5196.97 2443.31 S 24.98.79 E 1296.12 7600 5980.80 5873.90 2895.47 S 3079.27 E 1619.19 ......... 8600 ......6665.93 -i ......... 6559.03 ............ 3394~'~7 S 3608,56-E .... 1934,06 7356.65 3793.17 S 40~.7.61 E 2136.'r,i 8314°03 3995.79 S 4214°00 E 2179.06 9908.28 4.271°94 S 45z~3.5! E 2234.81 9600 7463.55 ].0600 e42o.c 3 [16co ...... lzzso zooi5, ta 25.79 150.55 295.06 291.69 261.77 270.97 323.06 '314 202 °37 42.62 2']~";-52 34.22 ( THE-~ALC~LAT~N~`PR~E~j~§-~Ak~-~--~D-~-~i-1`HE-~E-dF-.~E~-~jME~N-$.t~-NA~L-R-~$-~F --CO-~VAYURE -METHOD. DoCument: Transmittp,~ union 0i- Company ~)f Cai~ u-n,en,: .DA'TE' SUB.M TTED ' ACCOUNTING MONTH . -~ .. 8//13/74 *TO ' iFR(~ka. ' ' . . ....... · :_ ~a~t'w. '~l~ :, ~; c, wa~ ' ;' :T~L~.~.~,~:~ *--~ ~'~ . ,. 'TELEPHONE N'O; .... .:':~:':-~': ',.*. ~,~. ~"~ ~ ~-8. ('~3,~8 ~,.~u_' '' F~rm No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICA. TE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 2. NA/~E OF OP~ATOR *Union 0il Company of California- Anff~SS OF OP~TOR 909 West Ninth Avenue, Anchorage, Alaska 99501 4. LOCA~ON ~F WELL Surface: 677' FSL & 1221' FWL, Sec 6, T8N, R13W, SM, Conductor #1, SE Leg, Dolly Varden Platform Al:'! NIS{ERICAL CODE 50--133--20187--01 6. LF~$E DESiGNA~'ION AND SEIRIAL NO. ADL-18729 '7. IF INDIA~T, ALRD'I IJ~.. OR TRIBE NAME 8. UNIT,F.~LM OR LEASE NAME Hemlock Top: 3330' FNL & 930' FWL, sec 8, T8N, ~d~3W,mSj!~ ~od~' ~NI~-& 10%0' FWT,; (Estimated) J~ ~ ~ ~~oJ~ 13. REPORT TOTAL D~ AT ~D OF MON~, C~NGES IN HOLE SIZE, CASI~~. C~TING JOBS IN~iNG DEP~ SET ~ V OL~ USED, P~O~TIONS, ~TS ~ ~SULTS. FIS~NG ~ J~B ~ ~O~ ~IDE~CKD HOLE ~ ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS. Trading Bay Unit 9, %VELL NO. z)-8, m) (]_3-8) 10. l,U~nff~ AND POOL. OR WILDCA.T cArt = 11. SEC., T., R., M., (BO~I'OM HOI~ Om.mCT~W_0 Sec 8, T8N, R13W, SM, Approx. .q~c g @ TD TRADING BAY UNIT WELL D'8, REDRILL - JULY, 1,,974 B VISIO, 4 0f Ol AND GAS 7/1-9 Drilled directional hole from 10,956' MD to 12,398' MD in a sidetraCked hole following course 549°E with a 12° drift angle. 7/10 Ran open-hole logs; DIL, Sonic & Density from 8,733' (9-5/8" casing shoe at window) to 12,398' TD. 7/11-12 Ran 97 joints of 7" OD, 29#, N-80, x-line casing as liner with the shoe at 12,385' and liner top at 8,568'. Cemented liner with 850 sacks of Class "G" cement. WOC. 7/13-19 Cleaned out 9-5/8" casing to liner top. Cleaned out 7" liner to 12,226'. Ran test tools and tested liner lap. Had strong blow to surface and re- covered 5,460' of salt water. Squeezed liner lap with 450 sacks of cement in three (3) separate squeeze jobs. Cleaned out to liner top and tested with 2,500 psi - held O.K. Dry tested liner lap with DST tools - no recovery - test O.K. Cleaned out 7" liner to 12,313' PBTD. 7/20-21 Ran CBL/GR Log across liner. Ran Gyro survey from 700' to 12,250'. Per- forated Hemlock Bench 5 from 12,120' to 12,125' with 2 HPF using 4" casing gun. 7/22-23 Ran DST on Bench 5 perfs (12,120'-12,125') and r_ecpv~red 51 B___BI.g ~[ n~- water-mud emulsion and 46 BBLS of formation water, testing 17,500 ppm chlorides. Set cement retainer at 12,105' and squeezed above perfs with 100 sacks of cement. (See Attached Sheet) *Marathon Oil Company --- Sub-Operator ~OTE--Report on this form is required for each calendar month, the status of operations, and taus( ~ filed in duplicate with the Division of Mines & Minerals by the [Sth of the succeeding month, unless othe~ise directed. 7/24 7/25-31 Perforated higher in Hemlock Bench 5 from 12,055'-12,060' with 2 HPF using 4" casing gun. Ran DST of these perfs and recovered 42 BBLS of oil and trace of mud with sample cut of 95.5% oil- Ran 4-1/2" - 3-1/2" tapered tubing string for production and set packer at 11,503'. Removed BOPE, installed and tested x-mas tree to 5,000 psi. Displaced mud with water then diesel through circu- lating sleeve. Unloaded diesel down to approximately 6,500' and be- gan perforating Hemlock for production as follows: Bench No. Footage Shot .(MD) Holes/Ft. 5 12,040'-12,060' 4 On 7/31/74 perforating for production was under way. Union Oil and Gas Division: Western Region Union Oil Company'bF'California 909 w. 9th Avenue, Anchorage, Alaska 99501 Telephone: (907) 279-7681 unl, n · July 12, 1974 Mr. Homer Burrell Division of Oil & Gas State of Alaska 3001 Porcupine Dr. Anchorage, Alaska 99504 J ,SEC J CONFER: FtLE~ -- ~£ ' Ii i RE: STATE 'REPORTS Dear Mr. Burrell: Enclosed please find the required State Reports for work done and/or completed in the month of June as listed below. TBUS D-8 RD (lS-8) P-4 TBUS G-4 (WO) (12-28) P-4 TBUS G-16 CWO) (14-27) P-4 TBUS G- 14 (WO) P- 4 TBUS K-19 (Drlg.) (32-19) P-4 TBUS K-19 (Drlg.) (32-19) P-7 ~ Survey. TBUS K-4 (Drlg.) (14-21) P-4 Cohoe Unit #1 P-4 KU #21-6 (WO) P-4 Lessee's Monthly Report of Operations sk ~c1. (18) David A. Johnson Drlg. Pmgineer JUL ~ 0 1974 DiVISiON OF 011, AND l~otm ~o, P--4 ll.~'V. ~- I- 7 0 STATE ~'~ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUIOLICA.'r~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WgLL W~LL 'e. i~A.~ 0~ *Union Oil Company of California 3. ADD~S OF OP~TOI~ ..... 909 West Ninth Avenue, Anchorage, Alaska 99501 '4. 'LOCATION OF W~-T-T- Surface' 677' FSL & 1221' FWL, Sec. 6, T8N, R13W, SM, Conductor #1, Southeast Leg, Dolly Varden Platform. Hemlock Top' 3330' FNL & 930' FWL, Sec. 8, T8N, R1SW, SM. ADL.-18729 I~ INDIA~, ~LOT~E OR TRIBE 8. L~IT F.~ OR LEASE Trading Bay Unit 9 WE~ NO · = .... ~YD ~L, OR WILDCAT _NcArthur River ~ield o~ Sec. 8, TSN, R13W, S.N. %Drx. 3430 ~ FNL ~ 1050 ,~.-~,T~O. Sec. 8 O T.D FWL, · ' 74-3 '13. REPORT TOTAL DEPTH AT END OF MONTH, CHA~NGES IN HOLE SIZE. CASING AND Ck.WIENT/NG JOBS INCLUDING DEP~H SET AND VOLU'M'I~ USED, PEP. FOHATIONS, TESTS AND I~-ESULTS FISHING JOB~ JUI~K I!%T HOLE AND SIDE-TlR.ACE[ED HOLE A~TD ANY OTHJCR SIGNIFICANT CHANGI~; IN HOLE CONDITIONS 6/11-13 6/14-16 6/17-22 6/23-30 TRADING BAY UNIT WELL D-8, REDRILL - JUNE, 1974 Commenced work on well D-8 on 6/11/74. Installed and tested BOPE. Pulled tubing string. Plugged Hemlock perforations with 120 sacks of cement from 12,680' to 13,446' MD in two jobs. Ran cement bond log from 8,000' to top of 7" liner @ 10,249'. Cut window in 9-5/8" casing from 8,733' section mill. Set cement plug from 8,6 120 sacks. Left 9.7#/gal mud from 8,94 cement plugs. Polished off cement plug drilling sidetracked hole at 8,782' MD. to 8,824' (91') with 85' to 8,940' using 0' to 12,680' between to 8,782'. Began Drilled 8½~ directional hole from 8,7.82' to 10,956' MD following course S49°E with 12° drift angle. Well will be redrilled to approximately 12,400' MD to penetrate the Hemlock. 3UL 1 6 974 DI¥1SION OF OIL AND GAS * Marathon Oi~ Company -2- Sub-Operator . , ....... .,-~ ,' -./-~ /~ =~ Dist ~1~ Smt~ .a~ 7!!2/74 ._ 7/ ,r]mt ~. t.a ! .I ~no~[ , ' - ' N~~ Rlporf on thle fG~ i~ reQut~od for ~ch colindor ~fhT regQrdless of the lfotus of oporofions, oil Qnd gol eonBorvof{on commiffie by the Ifi~ of ~he &uoQ~dio9 ~n~. ~le~ ofherwile directed. January 15~ 1974 Re: Trading Bay Unit State D-8 Union 0tt (:~apa~y of California, Operator Permit No. 74--~ Mr. Robert T. Ander.son Union Ot I C.z~ny of Cai t forflla 909 W. C)~h Avenue Anchorage., Alaska 99501 Dear Si r: Enclosed ts the approved apptlcatlon for permit to drill the above re:feren~ed well on or abou~ Narch 15, Ig74, at a l.m=atlo~ fro~ the-Dolly Verd~ platform. Welt samples and core chips are not required. A d~re~ione.l s~f is required.. Poi lution of any waters of the State Is prohibited by AS 46, ~ter 03, Article 7 and the regulations promulgated theretmder (Title. {8, A{aska ~lnlstratlve Code, Chapter 70) and 'by the Federal ~tate? Potlutl-on ~tro.t Rc~, as ~d. Prior to commencing ope'rs?Ions you may be c3~tacted by a represe~tatlve of the Department of Envl ronmenl~l Conse~tton. In the event of suspension or abandeement please glve thls of'flee adequate advance notlflcaflon eo that we may have a witness present. Very t Pa t y yours, Homer L, Burr'ell Alaska 011 and ~ HL{~:Jm Enclosure cc= l:)epa~t of Ftsh and l~l~~t of E. vlronae~l'al ~v~flon ~/o ecl. For~ P--1 RE~. 9-30-67 STATE 'OI04'FI~A,L ' ~,M~LTTd~ OIL AND GAS CONSEI:g~[i~[~.J~ ,.,~u ~.~jli ~%~ APPLICATION FOR PERMIT TO DRILL, A PL~ BACK DRILL~ RD DEEPEN ~ PLUG BA~ OIL ~ O,~ ~ ~IN~LE ~ MULTIPLE ~ W~LL WELL OTH~R ZONE ZONE 2. NAME OF OP~TOR Union 0ii Company of C~]lfornie (~er~thon 5ub-0peretor) 3.ADDR~S ~ 909 W. 9th Avenue, Anchorage, Alaska ~01 LOCAT~O~ OF WELL ~tsu,~,e Conductor 1, Leg B-l, 677'N s 1221'E of the SW corner. Section 6: T8N, R13W. S.H. ,t,~opo.ed~,oa.~.,~ Top Hemlock, approx. 3970'S ~ ~520'E'of Sur. Loc. or 790'E S 3350'S of the NW corner.-S'ec'.8:'T8N, RI~W, S.H. ~3. DI~T~CE ]M ~ AN~ g~ECT~ON F.~O~ NEAREST TOWN O~-POST OFFiCe* 21 miles NW of Kenai, Alaska t~ Statewides~,~t~,~,~,. United Pacific Insurance Co. B-55502 ~: $100 ~ 000. 00 15. DISTANCE ~OM PROPOSED' ' jl~. NO. OF AC~ IN LE~E- . ~17.' NO. ACR~ ASSIGND ~CA~O~ ~o .s..~ ~ ~o ~s w~ ~~ o~ ~SAS~ ~IN~, ~. 850 ' 3 ' 085. 00 160 .~_ (A~ to nearest drip, unit, if any) ~,. ~S~A.CS ~o~ ~o~osso ~A:O~' ~'~..~O.OS~ ~ ~O. ~O~A~ O~ C*~S ~OO~S · O S~S~ WS~ OSZ~, CO~~. ! TMD 12,308 OR APPLID FOR, FT. 1,500' I TVD 10,106 . :~Rotary 21. ELEVATIONS (Show whether DF, RT. QR, etc.) ~. APPROX..DATE WORK WILL ST~T* RB 106.2 HSL . Hatch 15, 197~ FROPOS~'CASING ~D CEM~NG PROG~- " 6. ~E D~tGNA~ON ~ S~ NO. ADL~]8729 ~. IF ~I~, ~~ OR 8. ~IT~F~ OR LEASE Tradinq Bay Uni't 9. ~L State ~-8 R0 ('~-8) 10. ~D AND POOL, OR WIL~AT NcAvthuv River Fie]d 11. SEC.-, T., R., M., (BO~O~ ~OLE O~EC~IVE) Sect[on 8: TSN, R]3W, S.N. Btm. Hole: ~0'S ~ 890'E of N~ coFnev. SIZE OF HOLE SIZE OF CASING I WEIGHT PER F°OT L~--GRADrE i - SETTING DEPTH "' ~ ' : QUANTITY OF CF. MEN~ 8½" 7" Liner 29# N-80 8500 - 12,30C' 750Lsx 'ret. G-neat , ' . , · ' L PLAN OF PROCEDURE: requi red." . · . TOTAL TIME'43·days. 1. Abandon present wellbore & sidetrack hole 2. Drill 8-1/2" directional hole to 12,308'. Run required logs. 4. Run 7" liner from 8500' tO 12,'308' & cement 'as 5. Recomplete well as Hemlock producer. Redrill-30 days Completion-13 days EST. TOTAL TtME: · IN ABOVE SPACE DESCRIBE I~RO~I~OSED PROGRAM: If proposal is to deepen or plug back, give data on present productive zone and proposed new. productive zofte. If P~6~osal is to drill or deepen direct Lonslly, give pertinent data on subsurface h)ca.tions and measured and true vertic.al depths. Give blowout preventer program. 24. I hereby certify th,~,e Foregoing is True a~d Correct (This space for State office use) ,,/CONDITIONS OF APPROVAL, IF AN-Y: *See InstrucfiOns On Reverse side District Land Manager SEE' TRAN~M!TTAL LETTER A.p.I. NUMEHICAL CODE Jnauary 15, 1974 January 15, 1974 ,3 2 '8 -;54 ' ' i (1~.-;53) -12Rd I 0-52 ~ T 11,281' ~e ' // //u-o~ (12X-5) ~. D /D-gO/ / t . ~ .... D 2/ -~ -~ -~ ~ ~ D-19 ~~ / ~(g~xT~)¢ .~'DL5 ~ 2-5) ; .. - - D-24~ (43x-5)~ UNION-MARATHON (44 - 6)"~ (24-5) D -33 · 4e-7) 2- (22-7) ~ ( 13 - 8) TM~ 11~6~0 PBHL D 9466 TMD Ig,~8 ¢-6 TVD I0~ 106 D-14' (44-7) x U-M ADL 18729 -- ~x PPSS ADL 17579 ~ b-8 x (24-8) ~ D-14RD , (,,-,7) U N I0 N J~ .._..._. ~ D-22 ~ . )2-4.~I 17) · · WELL LOCATION MAP MA R.¢. THON 'SUB -OPE R ATO R TRADING BAY STATE UNIT. D'"'SR(: (i3- 8) 0 2000 SCALE:I": 2000' J ~ 26 DEC 7;5_ CHECK LIST FOR NEW WELL PERMITS. Lease & Well No. ~,~,L~. Yes No Remarks Is well to be located in a defined pool ................. //~ Do statewide rules apply ' Is a registered survey plat attached ............... Is well located proper distance from property line ........... Is well located proper distance from other wells ............ Is sufficient undediEated acreage available in this pool ........ Is well to be deviated ......................... Is operator the only affected party .................. Can pem~it be approved before ten-day wait ............... fo ' · Does operator have a bond i"n rce ................... · Is 'conductor string provided ............. ~ .... is enough ceme~t used .to circulate on conductor and surface ..... · Will cement tie in surface and intermediate or production strings · Will cement cover ail possible productive horizons ........... · Will surface casing c'over all fresh water'zones . . , ......... · Will surface csg. internal burst equal .5 psi/ft, to next string · .Will all casing give adequate safety in collapse and tension ...... · Does BOPE have sufficient pressure rating ...... - ......... ditional Requirements: