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Home My WebLink About181-080CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Trading Bay Unit D-09RD (PTD: 181-080) Change of Status Date:Tuesday, September 30, 2025 8:27:08 AM Attachments:MRF D-09RD (PTD 181080) EPA Quarterly Disposal Reports 2012 to 2020.pdf From: Daniel Taylor <dtaylor@hilcorp.com> Sent: Monday, September 29, 2025 3:02 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Wyatt Rivard <wrivard@hilcorp.com>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: Trading Bay Unit D-09RD (PTD: 181-080) Change of Status Mr. Wallace, I apologize for the delay in my response. The well does meet the AIO 5, 20 AAC 25.460, 20 AAC 25.402, and 20 AAC 25.412 requirements. Hilcorp does recognize the top of packer depth in well D-09RD is >200ft over the perforated interval. We will be submitting a request for Administrative Approval to AIO 5 in connection with this being outside the regulations outlined in 20 AAC 25.412(b). The last witnessed MIT was July 8, 2024. Hilcorp anticipates a follow up MIT on or before July 8, 2026. Please see the attached Quarterly Injection reports provided to the EPA from 2012 to 2020. Each outlines the fact that no wastes were brought to the Dolly Varden Platform from other facilities for the purpose of injection in Well D-9RD. D-9RD has been utilized for injection of produced water and filtered inlet water accumulated on the Dolly Varden Platform. Regards, Daniel Taylor, P.E. Well Integrity O: 907-777-8319 C: 907-947-8051 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Monday, September 15, 2025 9:19 AM To: Daniel Taylor <dtaylor@hilcorp.com> Cc: Wyatt Rivard <wrivard@hilcorp.com>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: [EXTERNAL] RE: Trading Bay Unit D-09RD (PTD: 181-080) Change of Status Daniel, When I do a quick check of this well I see a recent Sundry 323-045 and 10-404 showing a schematic 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. with an “estimated TOC @ 9450 ft” and shallowest open perf of G-1 at 9869 ft. So, as I see it, the IA “packer” set > 200 ft above perforations is not compliant with 20 AAC 25.412(b). 10-404 shows 07/12/2023 passing EPA witnessed MITIA, with a copy of the MITIA in the well file. Well file has the passing MITIA 07/08/2024 EPA witnessed. I do not see any outstanding administrative approval requests from Hilcorp for this well. I see AIO 5 has identified the EPA codified Trading Bay Unit aquifer exemption. 20 AAC 25.450. Underground injection control variances. (a) If injection does not occur into, through, or above freshwater, the commission will, authorize requirements for a well or project that are less stringent than the requirements in this chapter for the radius of investigation established under 20 AAC 25.252(h) or 20 AAC 25.402(b), casing and cementing, the tubing and packer mechanical integrity, operation, monitoring, and reporting, to the extent that the commission determines that the reduction in requirements will not result in an increased risk of movement of fluids into freshwater. 20 AAC 25.556. Orders. (d) Upon proper application, or its own motion, and unless notice and public hearing are otherwise required, the commission may administratively waive or amend the requirements of any order issued by the commission if the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in an increased risk of fluid movement into freshwater aquifers. Does the well meet the AIO 5 and 20 AAC 25.460 requirements? Does the well meet the 20 AAC 25.402 and 20 AAC 25.412 requirements? Is Hilcorp requesting a waiver or variance from either a commission issued order or the regulations? Once back on regular injection, after no injection since 2020, and multiple well workovers, when is the next AOGCC witnessed MITIA planned? Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Daniel Taylor <dtaylor@hilcorp.com> Sent: Monday, September 15, 2025 7:40 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Wyatt Rivard <wrivard@hilcorp.com> Subject: Trading Bay Unit D-09RD (PTD: 181-080) Change of Status Mr. Wallace, Hilcorp is requesting that Trading Bay Unit well, D-09RD (PTD: 181-080) on the Dolly Varden platform be reinstated as a Class 2 injector under AIO 5. D-09RD is currently a Class 1 injector (Permit: AK-1I006-B) that has not been utilized for disposal of any fluids since April 2020. From the year 1987 thru 2005, D-09RD’s status was a Class 2 injector under AIO 5. It was converted to Class 1 status in 2005. D-09RD no longer has utility for injection of Class 1 fluids. D-09RD’s tubing was changed out in July, 2023. Upon completion of the workover D-09RD passed a MIT-IA. Another MIT-IA was performed and passed in July, 2024. However, the well has remained shut in. Hilcorp has notified the EPA of our intention NOT to submit a Class 1 permit renewal application for D-9RD. Hilcorp respectfully requests the AOGCC reinstate Trading Bay Unit D- 09RD as a Class 2 injector under AIO 5. Regards, Daniel Taylor, P.E. Well Integrity O: 907-777-8319 C: 907-947-8051 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 responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that 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. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Trading Bay Unit D-09RD (PTD: 181-080) Change of Status Date:Monday, September 15, 2025 10:14:15 AM From: Wallace, Chris D (OGC) Sent: Monday, September 15, 2025 9:19 AM To: 'Daniel Taylor' <dtaylor@hilcorp.com> Cc: Wyatt Rivard <wrivard@hilcorp.com>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: RE: Trading Bay Unit D-09RD (PTD: 181-080) Change of Status Daniel, When I do a quick check of this well I see a recent Sundry 323-045 and 10-404 showing a schematic with an “estimated TOC @ 9450 ft” and shallowest open perf of G-1 at 9869 ft. So, as I see it, the IA “packer” set > 200 ft above perforations is not compliant with 20 AAC 25.412(b). 10-404 shows 07/12/2023 passing EPA witnessed MITIA, with a copy of the MITIA in the well file. Well file has the passing MITIA 07/08/2024 EPA witnessed. I do not see any outstanding administrative approval requests from Hilcorp for this well. I see AIO 5 has identified the EPA codified Trading Bay Unit aquifer exemption. 20 AAC 25.450. Underground injection control variances. (a) If injection does not occur into, through, or above freshwater, the commission will, authorize requirements for a well or project that are less stringent than the requirements in this chapter for the radius of investigation established under 20 AAC 25.252(h) or 20 AAC 25.402(b), casing and cementing, the tubing and packer mechanical integrity, operation, monitoring, and reporting, to the extent that the commission determines that the reduction in requirements will not result in an increased risk of movement of fluids into freshwater. 20 AAC 25.556. Orders. (d) Upon proper application, or its own motion, and unless notice and public hearing are otherwise required, the commission may administratively waive or amend the requirements of any order issued by the commission if the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in an increased risk of fluid movement into freshwater aquifers. Does the well meet the AIO 5 and 20 AAC 25.460 requirements? Does the well meet the 20 AAC 25.402 and 20 AAC 25.412 requirements? Is Hilcorp requesting a waiver or variance from either a commission issued order or the regulations? Once back on regular injection, after no injection since 2020, and multiple well workovers, when is the next AOGCC witnessed MITIA planned? Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Daniel Taylor <dtaylor@hilcorp.com> Sent: Monday, September 15, 2025 7:40 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> 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. Cc: Wyatt Rivard <wrivard@hilcorp.com> Subject: Trading Bay Unit D-09RD (PTD: 181-080) Change of Status Mr. Wallace, Hilcorp is requesting that Trading Bay Unit well, D-09RD (PTD: 181-080) on the Dolly Varden platform be reinstated as a Class 2 injector under AIO 5. D-09RD is currently a Class 1 injector (Permit: AK-1I006-B) that has not been utilized for disposal of any fluids since April 2020. From the year 1987 thru 2005, D-09RD’s status was a Class 2 injector under AIO 5. It was converted to Class 1 status in 2005. D-09RD no longer has utility for injection of Class 1 fluids. D-09RD’s tubing was changed out in July, 2023. Upon completion of the workover D-09RD passed a MIT-IA. Another MIT-IA was performed and passed in July, 2024. However, the well has remained shut in. Hilcorp has notified the EPA of our intention NOT to submit a Class 1 permit renewal application for D-9RD. Hilcorp respectfully requests the AOGCC reinstate Trading Bay Unit D- 09RD as a Class 2 injector under AIO 5. Regards, Daniel Taylor, P.E. Well Integrity O: 907-777-8319 C: 907-947-8051 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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:Conrad Cobb To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Cc:Zach Rolph; Casey Morse; Jason Hobart; Omar Ramirez; Dan Marlowe Subject:Dolly Varden Platform D-09RD MIT AOGCC Form Date:Tuesday, July 9, 2024 6:39:26 AM Attachments:D-9 MIT 7-8-24 AOGCC.pdf.xlsx You don't often get email from ccobb@hilcorp.com. Learn why this is important Please See Attached D-9 MIT Results. Thank you Conrad C. Cobb Dolly Varden Platform 55525 Rig Tenders Dock Road Nikiski AK, 99635 Phone: 907.776.6840, Fax: 907.776.6842 ccobb@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 7UDGLQJ%D\8QLW'5' 37' Submit to: OOPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 181-080 Type Inj N Tubing 0 0 0 0 Type Test P Packer TVD 9009 BBL Pump 1.5 IA 338 2500 2486 2477 Interval O Test psi 2252 BBL Return 1.3 OA 320 460 460 460 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: Hilcorp Alaska MRF / TBU / DollyVarden Platform Conrad Cobb 07/08/24 Notes:Class I Disposal Well - Annual MIT with EPA witnessing. Test result: PASS. Notes: Notes: Notes: D-09RD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Form 10-426 (Revised 01/2017)2024-0708_MIT_TBU_D-9RD -5HJJ 9 9 9 9 9 9 9 9 9 9 9 9 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: __________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,060 feet N/A feet true vertical 10,190 feet N/A feet Effective Depth measured 10,094 feet See schematic feet true vertical 9,252 feet See schematic feet Perforation depth Measured depth 9,869 - 10,850 feet True Vertical depth 9,036 - 9,985 feet Tubing (size, grade, measured and true vertical depth) 5" & 4-1/2" L-80 / L-80 Polycore 9,863 (MD) 9,032 (TVD) Packers and SSSV (type, measured and true vertical depth) See schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 0 323-045 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ryan Rupert Ryan.Rupert@hilcorp.com 907 777-8503Operations Manager N/A Hemlock Oil & Middle Kenai G Oil measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD N/A 605 Size 633 0 8080 0 5750 13-3/8" 9-5/8" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 181-080 50-733-20131-01-00 3. Address: Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0018729 McArthur River / Hemlock Oil & Middle Kenai G Oil Trading Bay Unit D-09RD Plugs Junk measured Length measured TVD Production Liner 5,721 11,044 Casing Structural 5,186 10,174 5,721 11,044 633 2,531 633Conductor Surface Intermediate 20" 3,090psi 7,020psi 3,090psi 5,750psi 8,160psi 2,531 3,419 Burst Collapse 1,540psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 10:33 am, Aug 01, 2023 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.08.01 06:45:29 - 08'00' Dan Marlowe (1267) _____________________________________________________________________________________ Updated By: JLL 07/21/23 SCHEMATIC Well: D-09RD Last Completed: 09/07/22 PTD: 181-080 API: 50-733-20131-01-00 PBTD =10,094 TD = 11,060 MAX. HOLE ANGLE = 31° D-09 Motherbore 9- 5/8 Window @ 5,750 MD 4 RKB to TBG Head = 39.52 6 B-3 HK-3 B-2 3 1 B-4 B-1 B-0 2 5 B-5 G-2 G-3 G-4 G-1 HK-1 HK-2 HK-4 HK-5 X 7 DV collars at 3,486 and 2,604 in 7 Unable to close top DV. Sqz w/ 35 sx. Passed PT X Estimated ToC @ ~9,450 MD CASING DETAIL Size Wt Grade Conn ID Top Btm 20"Surf 633 13-3/8 61 J-55 Butt 12.515 44.80' 2,531' 9-5/8 40 N-80 Butt 8.835 42.88' 4,754 9-5/8 43.5 N-80 Butt 8.755 4,754 5,721 7 29 N-80 Butt 6.184 41.47' 11,044' TUBING DETAIL 5" 18# P-110 Hydril 513 4.276" Surf 9,779' 4.5" 12.6# L-80 LTC 9,779 9,835' 4-1/2" 12.75 / 13.70 L-80 / Polycore 8 rnd EUE 3.40" 9,835' 9,863' No.Depth (MD) Depth (TVD)ID Item 1 39.52' 39.52' 4.00" Hanger 2 9,785' 8,958' 3.99" 7" 23-32# LTC BxP Hydraulic Isolation Packer Permanent 3 9,810' 8,981' 3.813" 4 1/2" LTC BxP 3.813 X Profile Nipple 4 9,835' 9,005' Non-sealing Overshot 5 9,839' 9,009' 4.00" Nickel Coated Hyd set Permanent Packer 6 9,853 9,023' 2.81" X Nipple - 3-1/2" EUE Box x Pin w/2.81" X-Profile 7 9,864' 9,033' 3.995" Wireline Entry Guide Perforation Detail Zone Top(MD) Btm(MD) Top(TVD) Btm (TVD) Amt SPF Date Status G-1 9,869' 9,883' 9,036' 9,146 16 5 12/7/2013 Open G-2 9,912' 9,926' 9,079' 9,092 14 5 12/7/2013 Open G-2 9,912' 9,926' 9,079' 9,092 14 6 5/31/2000 Open G-2 9,932' 9,946' 9,098' 9,111 14 5 12/7/2013 Open G-2 9,932' 9,946' 9,098' 9,111 14 6 5/31/2000 Open G-3 9,982' 10,004' 9,146' 9,166 22 5 12/7/2013 Open G-3 9,982' 10,004' 9,146' 9,166 22 6 5/31/2000 Open G-4 10,018' 10,056' 9,180' 9,216 38 5 12/7/2013 Open G-4 10,018' 10,056' 9,180' 9,216 38 6 5/31/2000 Open G-5 10,157' 10,174' 9,313' 9,329 17 5 12/7/2013 Open G-5 10,190' 10,207' 9,345' 9,361 17 5 12/7/2013 Open G-7 10,302' 10,320' 9,453' 9,470 18 5 12/7/2013 Open B-0 10,300' 10,320' 9,451' 9,470 20 22 5/31/2000 Open HK-1 10,370' 10,410' 9,519' 9,557 40 5 12/7/2013 Open B-1 10,370' 10,410' 9,519' 9,557 40 10 5/31/2000 Open HK-2 10,428' 10,520' 9,575' 9,664 92 5 12/7/2013 Open B-2 10,435' 10,470' 9,582' 9,615 35 4 & 8 4/16/1987 Open B-3 10,500' 10,520' 9,645' 9,664 20 9 1/9/1985 Open HK-3 10,550' 10,565' 9,693' 9,707 15 5 12/7/2013 Open B-3 10,550' 10,565' 9,693' 9,707 15 4 1/9/1985 Open HK-3 10,580' 10,630' 9,722' 9,770 50 5 12/7/2013 Open B-3 10,585' 10,630' 9,727' 9,770 45 4 1/9/1985 Open HK-4 10,642' 10,690' 9,783' 9,829 48 5 12/7/2013 Open B-4 10,642' 10,690' 9,783' 9,829 48 4 1/9/1985 Open B-5 10,725' 10,800' 9,863' 9,936 75 4 4/16/1987 Open HK-5 10,725' 10,851' 9,863' 9,986 125 5 12/7/2013 Open B-5 10,810' 10,850' 9,946' 9,985 40 4 4/16/1987 Open SLICKLINE / FISH / FILL INFORMATION: A. 2/27/00: Baker F-1 Pkr milled/pushed to bottom at 10,957 . B. 12/12/13: Well cleaned out to PBTD at 10904. OPEN HOLE / CEMENT DETAIL 13-3/8"17-1/2" hole: Pumped 2000sxs (392bbls) class G 14ppg lead followed by 400sxs (78bbls) class G 15.7ppg tail cement.Saw cement to surface. 9-5/8" 12-1/4" hole TD'd at 11,341' MD in D-09 perentbore (1968). Primary job pumped 720+600sxs of Class G. Saw trace cement when circulating through DV collar at 6966' MD. Stage 2 through DV collar at 6966' MD: Pumped 1148sxs (225bbls) class G lead followed by 100sxs (20bbls) class G neat tail cement.12/31/81 CBL shows ToC at 2070 MD 7" 8-1/2" hole: Primary job pumped 1150sxs (225bbls). Cement not pumped through either DV collar initially. Top DV at 2604' MD wouldn't close. 1/25/82 CMIT-7"x9-5/8" PASS to 2800psi through open DV collar at 2604' MD. (proves cement made it up above the 9-5/8" window) Cement retainer circ'd 35sxs (7bbls) through DV at 2604' MD. 5.2bbls made it behind pipe. 1/28/82 CBL show's ToC at 1075' MD Rig Start Date End Date CTU / Cmt Pump 2/25/23 7/12/23 02/25/2023 - Saturday Rig up on well. PT 2500 PSI- Pass. Rih w/ 4 1/2 GR w/ 4 1/2 Bait sub (1.9 ID) w/ y pulling tool to 9825' kb, beat down, well drop from 315 PSI to zero, jar up 2X, pooh slowly, well is on vaccum. Ooh w/ WRP. (fluid @ 700' pulling out of hole) Rih w/ 4 1/2 X-line w/ 4 1/2 PX-plug to 9804' kb set plug pooh. Ooh No plug. Rih w/ 3" SB w/ 4' prong (3.26 Cent on top) to 9804' kb, set prong, pooh, ooh sheared no prong. Ooh w/ tools, lay down put night cap on well. MIT-T tubing. 79bbls FIW pumped down tubing for fill-up. T/IA/OA pressures Initial: 4319 / 0 / 259 15mins: 4319 / 0 / 260 30 mins: 4322 / 0 / 259 MIT-T to 4300psi PASS. Held pressure on tubing for 4 hrs in an attempt to reset upper production packer 02/26/2023 - Sunday Stand by for production to finish PT tubing. Rig up. Rih w/ 3" JDC to 9802' kb, latch prong, well goes on vaccum, pooh. Ooh w/ prong. Rih w/ 4 1/2 GS to 9804' kb, w/t pooh.Ooh w/ plug. Rih w/ 2.25 X 3' DD Bailer to 10,300' kb, w/t pooh. Ooh 1/3 full mud. Ooh w/ tools, rig down SL. SL rigged down and out of way. MIT-IA on 5" x 7" IA with ~40bbls of FIW. No plugs in well. T/I/O Initial: Vac / 2804 / 336 15-mins: Vac / 2777 / 335 30-min: Vac / 2703 / 333 MIT-IA FAIL 28 minutes into test IAP dropped 50psi instantaneously. Loss rate went from ~10psi every 5 minutes prior to 20+psi in the next 5 minutes. Then pressure fell from 2682 to vacuum in 1 minute. Spot Eline unit, toolbox & grease unit on lower deck. Begin rig up. Make up CBP BHA. Pick up lubricator & WLV's. Stab onto to well. PT to 250/2000, pass. Tubing on a vac. RIH w/ 7' x 1.69' WB, 1.5' x 3.125" CCL, 5.5' x 2.75" setting tool, 2' x 2.75" quick change,1.9' x 3.66" HAL Obsidian CBP. CCL to top of plug = 8.4', CCL to mid element = 9', CCL to bottom = 10.3'. Tie in and send to OE. On depth. Set CBP @ 9835' mid element (9826' CCL stop depth). Pick up and tag plug on depth. POOH. Bump up and shut in. Lay down toolstring and lubricator. Secure well for the night. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name D-09RD 50-733-20131-01 181-080 Rig Start Date End Date CTU / Cmt Pump 2/25/23 7/12/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name D-09RD 50-733-20131-01 181-080 Open PTW & PJSM w/ ops. Begin rig up. Ops finished loading IA & T w/ FIW, 77 bbls. Pick up tubing punch BHA & lubricator, stab onto the well. RIH w/ 2' x 3 1/8" CCL, 12' x 1.69' WB, magnet, 2" x 3' tubing punch (6 spf, 3/8 charges), magnet. (OAL = 23'). CCL to top shot = 16.2', CCL to bottom of tool = 21.1'. Tag top of CBP @ 9834'. Send correlation to OE, on depth. Tubing punch 9826'-9829' (CCL stop depth = 9809.8'). Initial T/I/O = 7/6/232 psi, 5 min = 4/8/232 psi. POOH. Stab off and night cap well. Lay down BHA, all shots fired. PT production riser to 3200 psi, pass. Begin pumping down IA, taking returns to the tubing, establish circulation pumping 1/4 bbl/min @ 2200 psi on triplex (WHP was much lower than this due to small hoses, etc.) Returns after tubing punch were qualitatively stronger (larger flow) than from before. Pump 3 bbls taking water returns from tubing. Line up to CMIT pumping down IA with jumper hose between IA & T. Starting pressures on PT T/I/O = 2817/2821/344 psi. PT for 10 minutes, final pressures, T/I/O = 2745/2750/342. Total 10 min loss T/I = 72/71. PT pass. Pick up Cement Retainer BHA. Stab on lub. RIH w/ 7' x 1.69" WB, 2' x 3 1/8" CCL, 6.5' x 2.75" Baker 10 setting tool, 3' x 3.66" HAL FAS DRILL SVB Cement Retainer. CCL to mid element = 8.5', CCL to bottom of plug = 10.5'. Tag CBP @ 9834'. Send correlation to OE, on depth. Set Retainer @ 9820' mid element (9819' top of retainer). Tag retainer, on depth. POOH. Stab off and lay down toolstring, install night cap. Perform PT on the tubing/retainer. Starting T/I/O = 3005/346/252 psi, 10 minute T/I/O = 2985/349/254 psi. PT pass. Begin rig down, lay down lubricator and secure equipment for barge. Fly back to Kenai. PTW, JSA with crew. Fuel and fire up equipment. Load batch mixer to stir up and clean any rust or scale accumulated over time. Noticed batch mixer had communication between the two 50 bbl tanks. Discussed ways to be able to pull off cement job safetly with current condition of batch mixer. No good options. Called out a welder. Batch mixer cleaned and prepped for welder. Welder on location fixing hole. Pick injector head and stab lubricator. RIH to make up coil connector. Coiled tubing electronic counter is reading backwards and double footage. Stack down lubricator to investigate coil counter issue. Found coil counter assembled incorrectly. To late to proceed with well work. SDFN. 02/27/2023 - Monday 03/15/2023 - Wednesday Found IA on a vac. Filled up. Only took 9 gallons and pressure dup to 105psi. leveled off at 90psi. Looks like IA is still full 05/24/2023 - Wednesday 05/23/2023 - Tuesday Arrive at OSK. Travel to Dolly Varden Platform. New crew members perform site specific orientation. PTW, JSA with crew members. (Crew flew out and spotted equipment on 5/18). Rig up CTU 1 with 1.75" coil. 48 hr BOPE test witness notification received and waived by Mr. Jim Regg. Test 4.06" Combi BOPE stack and choke valves 250/2500 psi. Good BOPE test. Send in state report. SDFN. Location walk around completed. Rig Start Date End Date CTU / Cmt Pump 2/25/23 7/12/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name D-09RD 50-733-20131-01 181-080 05/25/2023 - Thursday PTW, JSA with crew. Fire up equipment. PIck injector head and make up cement stinger BHA. Cc, x over , centralizer sub, x over , tj hydaulic disco, hyd circ sub, x over, Halliburton cement stinger. BHA length 12.10'. Stab on well. PT stack 250/2500 psi. RIH. 9700' Free up weight 13.5K CIrculate top of retainer clean for 10 bbls. Stack down shut down pump. Pick up clean at 9813' CTMD . Attempt to engage cement retainer with 5k down. Pressure up 1576 psi in CT. Look to be engaged as WHP isn't climbing. Not getting returns up IA either. Continue different engagement techniques. Call town to discuss. RIg up reverse manifold. Perform reverse FCO on top of cement retainer. Pressure up IA to 3000 psi. Re engage cement retainer. Seeing 1:1 returns up IA while pumping multiple rates. Circulate IA clean with 67 bbls. Rate was .2 bbls/min at 4500 psi. After 20 bbls pumped rate increased to 1.2 bbls/min 1250 psi. Wellhead pressure is tracking CT pressure while circulating through retainer. Stinger seals are compromised. Shut down for night. 05/26/2023- Friday 05/27/2023 - Saturday PTW, JSA. Start prepping for cement. Cement wet. Mix up super sacks in batch mixer until a consistent weight of 15.8 ppg reached. Used FIW as mix water per SLB.;Coil stabbed into retainer at 9813' CTMD. 128 bbls of FIW circulated from CT cement stinger up IA to surface. Online with cement down CT string(no spacer in front). Zero micro motion once 15.8 ppg seen. Squeeze 5.5 bbls of cement below retainer. When cement hit stinger CT pressure increased to 2500 psi. After 2.0-2.3 bbls pumped, the pump rate slowed to 0. Pressure slowly dropped off continued with remaining cement. Estimated ToC in IA = 9,450' MD Displaced with gel pill followed by FIW. Pull out of stinger at 35K weight. Lay 10' of cement above retainer. Pick up 150' above and circulate bottoms up to clean CT and down hole tools. Keeping positive pressure on retainer. POOH while rolling pump with choke pinched in. 150-250 psi on choke skid during trip OOH. Tagged up at surface. Trap 150 psi on tubing. IA closed after cement circulated. Stinger had damaged seals. PTW, JSA with crew. Cement sample in office appears set-up/hard. Wait on cement. Make up YJOS milling assembly. 2.88" OD EXT Coilcon, 2.88" OD DFCV, 2.88" OD Bi-Di-Jar, 2.88" OD hyd disco 3/4" ball, 2.88" OD Dual acting circ sub, 2.88" OD mudd motor, 3.13" OD x over, 3.75" HAK owned tricone bit 26.54' BHA. WHP 0 psi. IA 400 psi. RIH with motor and mill for a dry tag at 9813' CTMD. Pick up clean. Park CT at 9700' and wait on IA MIT results. 23-24 hrs since cement was in place. Bleed 400 psi off of IA. Pressure up IA and start MIT at 2575 psi for 45 minutes. Losses of 102 / 67 / 55psi across 45minutes. FAIL. Bleed down to zero and watch flow for 30 minutes. No flow. 1.5 bbls in for pressure test and 1.5 bbls out from bleed off. Discuss plan forward with town. Have production rig up there test pump to perform 2nd MIT. Pressured up to 500psi over 1 hr. Pressured up from 500 to 1000psi over another hour. Shut down and monitor. Pressure loss was still 1 psi every minute when monitored for 5 minutes. Estimate 2.5bls pumped into IA. Bled IAP to 0psi. Talk with town decision made to let cement continue to setup for a few days. POOH with CT. Rig down YJOS motor BHA. Rack back injector head. SDFN. Rig Start Date End Date CTU / Cmt Pump 2/25/23 7/12/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name D-09RD 50-733-20131-01 181-080 05/31/2023 - Wednesday Cement has been in place for 5 days now. MIT-IA to 2400psi PASS. Pressured up IA with ops pump. Took 2.5bbls. Initial: 2 / 2500 / 388(T/I/O) 15 mins: 2 / 2478 / 386 30 mins: 2 / 2464 / 385 45 mins: 2 / 2452 / 382 60 mins: 2 / 2439 / 381. IA pressure losses were, 22, 14, 12, and 13psi in order. Across initial 30 minutes total losses were 36psi which is less than 2% overall loss. PASS 06/02/2023- Friday Mobe Crews to Dolly platform, orientate same, PJSM & permit to work. R/U for BOPE testing eq., fill surface eq. attempt shell test, with no luck, troubleshoot to swab valve, service valve & shell test 250/2500, good. Test BOPE stack and choke valves 250/2500 psi. as per Hilcorp & AOGCC requirements. Witness was waived by AOGCC inspector Jim Regg. Service Eq. M/u BHA into sections to be ready to pick up. S.D f/night, rest crews. 06/03/2023 - Saturday PTSM. P/U injector, stack up lubricator, m/u pull plate, PT t/3500 good. Pull test t/30k good. M/U BHA- connector, ck valve, Jars, Disconnect, Circ sub, 2 7/8 MTR, bit sub, 3 .75 rock bit = 26.54'. Crane unload boat, then Stab injector onto well, secure same. PT lubricator 250/2500 good. Surface test mud motor good. Open Swab valve. RIH t/9715' up wt 33k, dn wt 13k, RIH dry tag 9811' CTM. P/U 9780' Circ @ 1.3BPM 2700psi, wk down t/ 9805 stall out, cont. work area, & down t/ 9806' stall & overpulls, jar as needed to free. Cont. working down making headway back to bottom w/o hanging up t/9810' started stalling & over pulling, cycled out on coil, POOH t/surface. Shut in well. Break off, inspect BHA, Bit & Bit sub had deep scarring. L/D BHA cut 100' of coil. SDFN. Rig Start Date End Date CTU / Cmt Pump 2/25/23 7/12/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name D-09RD 50-733-20131-01 181-080 PTSM, P/U injector, C/O packoff. M/U connector, P/T 3500psi good. Pull test 30k Good. M/U BHA, connector, ck valve, Jars, Disconnect, Circ sub, 2 7/8 MTR, 5 blade 3.69" junk mill = 25.51'. Stab injector, P/T break 250/2500 good, surface test Mud MTR good. RIH @ 80FPM, t/tag @9811' up wt 34k, dn wt 13.5k. P/U t/9780, circ @ 1.4bpm, 2900psi, RIH t/9811, stall out, p/u w/overpull, restart make several attempts changing parameters with same results, last attempt hung up worked free. RIH no pumps tag 9811' p/u clean, circ 20 bbls. POOH t/surface, break off from well, found deep markings on mill. C/O BHA, connector, ck valve, Jars, Disconnect, Circ sub, Venturi = 18.81, stab onto well, test break 250/2500 good. RIH, t/ 9800' up wt 33k, dn wt 13k. Pump @ 1.3BPM, RIH slow t/ tag @ 9813', P/U 10' re-tag, P/U shut down pump, POOH. Shut in & break off well, break down Venturi & clean out, recover about 2 cups non metalic swarf, rubber pieces. Rack back lubricator & injector for night. SDFN. 06/05/2023 - Monday Clear deck, Spot WL unit. Mobe out PWL crew, PJSM. Rig up Lubricator & xo to fit on coil BOPE stack, PT t/2500psi good. RIH w/4 1/2" x-line w/ 4 1/2" x-lock t/9790' slm, POOH. RIH w/2.5" earth magnet t/9801'slm, POOH recover fine magnetic swarf. RIH w/ 2.5" LIB, tag @ 9801'slm, POOH, no identifying markings. RIH w/ 3.5" LIB, tag @ 9801'slm, POOH, no identifying markings. RIH w/ 2.5" Hydrostatic Bailer, tag @ 9801'slm, POOH, recovered shmoo w/composite pieces & slip button inserts. re-pin bailer. RIH w/ 2.5" Hydrostatic Bailer tag @ 9801'slm, POOH, recovered about 1/2 cup of composite pieces. RIH w/3.7" GR, tag @ 9801'SLM, POOH. R/D S/L,Mobe crews out. 06/06/2023 - Tuesday PTSM, Organize deck, clear WL unit from leg deck. P/U injector & lubricator, M/U pull plate & PT t/4600psi good. Work on Mix tank while waiting on crane changeout. /U BHA- Coil Connector, ck valve, Jars, Disconnect, Circ sub, Mud Motor, xo, 3.70 4 blade concave mill = 26.94. Stab onto well, PT 250/2500 good. RIH to tag @ 9816'ctm up wt 33k, dn wt 13k. P/U off bottom, pump @ 1.4BPM 2900psi, wk down stalling out 2x then start milling @ 9815'ctm, down t/ 9819'ctm, stalled out a few times before getting it moving again. Pumped 4bbl sweep. Continue Milling down t/9827'ctm, ROP stopped, rode it for awhile before breaking through, & chased it down t/ 9840'ctm, up wt 33k dn wt 13k, circ @ 1.4bpm. Continue attempting to mill, stalling out w/2-3k overpull, not making any headway. P/U t/ 9820', line up to try & inject down CT x Tubing annulus. Start pressures: 1.75 x 5" =0, 5"x7" 260psi Pressure up 1.75x 5" t/ 2000psi no injection, 5x7" 385psi Bleed off pressure, 5x7 =260, 1.75x5=0. Continue attempting to mill w/no luck. POOH, secure well L/D BHA, found outer leading edge of mill rounded off. Suggests we were on the 3-1/2" x 4-1/2" crossover. Break off lubricator & rack back injector. 06/04/2023 - Sunday Rig Start Date End Date CTU / Cmt Pump 2/25/23 7/12/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name D-09RD 50-733-20131-01 181-080 06/09/2023 - Friday Post job in-house MIT-IA to 2400psi: PASS Pressured up with 2.5bbls Initial T/I/O: Vac / 2511 / 365 15 mins: Vac / 2494 / 363 30 mins: Vac / 2478 / 362 45 mins: Vac / 2466 / 360 Pressure loss < 2%. PASS PTSM. P/U injector, cut 50' coil, p/u lubricator, m/u coil connector, PT t/4600 good, pull test t/25k. Pressure up on 5x7 IA to 2500psi to ensure no communication to tubing. Good test, appears cement / punch holes are holding. P/U BHA- connector, ck valve, Jars, Disconnect, circ sub, 2.13 mud motor, 2 7/8" bladed concave mill = 21.08', stab on well, PT t/250/2500 good. RIH t/tag @ 9830'ctm, up wt 33k, dn wt 13k. P/U break circ @ 1.2BPM, 2900psi. RIH tagging @ 9830ctm, stalling out, work spot with stalling, until breaking through. Continue wash & ream @1.4BPM, 3200psi WOB 1k, diff 50-60psi, saw weight drop @ tubing tail 9860'ctm. POOH f/9870' @ 50fpm up to 9800', RIH t/10000'ctm clean, POOH t/9860'. Perform injectivity test, pump down 5 x1.75" annulus, @ 1.5bpm 1400psi, @2bpm 1600psi, @2.5bpm, 1750psi, @2.7bpm, 1800psi. pump 24 bbls total. POOH f/9860'ctm, t/surface, pumping 1.1bpm, 2400psi. Secure well, pull injector, l/d BHA, stab onto BOPE, r/u blow down coil. Start r/d pump lines. Unstab pipe from injector & secure on reel. 06/07/2023 - Wednesday 07/06/2023 - Thursday AOGCC Witnessed waived per Jim Regg for upcoming MIT-IA. EPA will be out Wed 7/12 to witness. Rig Start Date End Date CTU / Cmt Pump 2/25/23 7/12/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name D-09RD 50-733-20131-01 181-080 EPA witnessed MIT-IA of 7"x5". Remote witness by EPA rep James Robinson. Pressured up to 2510psi with ~1bbl. Lost 13psi followed by 10psi (<2%) MIT-A PASSED to 2475psi. Bled back ~1bbl. T/I/O Pre-Test: 0 / 625 / 296 Initial: 0 / 2510 / 390 15 mins: 0 / 2497 / 388 30 mins: 0 / 2487 / 388 07/12/2023 - Wednesday 1 Regg, James B (OGC) From:Josh Allely - (C) <Josh.Allely@hilcorp.com> Sent:Thursday, July 13, 2023 10:48 AM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Cc:Ryan Rupert Subject:MIT - TBU D-09RD (EPA Class I Disposal Well) - 7/12/2023 Attachments:MIT - TBU D-09RD 2022_07_12.xlsx Attached is the official report of the successful EPA witnessed MIT performed on TBU D-09RD (PTD 181-080) on 7/12/23. Test was conducted per EPA Underground Injection Control Permit No. AK-1I006-A and followed EPA test procedures. Josh Allely Well Integrity Engineer Kenai – Hilcorp Alaska 907-777-8505 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. TBU D-09RDPTD 1810800 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1810800 Type Inj N Tubing 0 0 0 0 Type Test P Packer TVD 9009 BBL Pump 1.0 IA 625 2510 2497 2487 Interval O Test psi 2252 BBL Return 1.0 OA 296 390 388 388 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Hilcorp Alaska, LLC McArthur River / Trading Bay Unit / Dolly Varden Platform Waived - EPA Witnessed Mike Loomis 07/12/23 Notes:Class I Disposal Well - Annual MIT with EPA witnessing. Test result: PASS. Notes: Notes: Notes: TBU D-09RD Form 10-426 (Revised 01/2017)2023-0712_MIT_TBU_D-09RD          JBR; 10/30/2023 Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 03/28/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230328 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 12A 50133205300100 214070 2/18/2023 YELLOW JACKET PLUG BCU 18RD 50133205840100 222033 3/9/2023 YELLOW JACKET PERF CLU 10RD 50133205530100 222113 3/2/2023 YELLOW JACKET PERF-GPT-PLUG KBU 11-07 50133205560000 205165 3/3/2023 YELLOW JACKET PERF KBU 11-07 50133205560000 205165 3/1/2023 YELLOW JACKET PLUG KU 14X-6 50133203420000 181092 3/3/2023 YELLOW JACKET CALIPER-SCBL NCI B-02 50883200900100 197210 3/9/2023 AK E-LINE GPT Perf SRU 224-10 50133101380100 222124 2/15/2023 YELLOW JACKET PLUG TBU D-09RD 50733201310100 181080 2/27/2023 AK E-LINE Plug Punch Please include current contact information if different from above. TBU D-09RD 50733201310100 181080 2/27/2023 AK E-LINE Plug Punch Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 02/21/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230221 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 12A 50133205300100 214070 1/29/2023 HALLIBURTON PPROF END 1-69 50029220200000 190029 2/4/2023 HALLIBURTON COILFLAG END 1-69 50029220200000 190029 2/11/2023 HALLIBURTON PERF KU 14X-06 50133203420000 181092 1/27/2023 HALLIBURTON TEMP SRU 224-10 50133101380100 222124 2/3/2023 HALLIBURTON PPROF TBU D-09RD 50733201310100 181080 2/8/2023 READ LeakPointSurvey Please include current contact information if different from above. TBU D-09RD 50733201310100 181080 2/8/2023 READ LeakPointSurvey Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 02/06/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230206 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU C-07 50029212660000 185002 1/20/2023 AK E-LINE Perf Paxton 6 50133207070000 222054 1/24/2023 AK E-LINE Perf TBF A-07 50733200360000 167046 1/13/2023 AK E-LINE CBL TBF A-18 50733201430000 168076 1/22/2023 AK E-LINE Tubing Punch TBU D-09RD 50733201310100 181080 1/18/2023 AK E-LINE LDL Please include current contact information if different from above. By Meredith Guhl at 11:24 am, Feb 06, 2023 T37486 T37487 T37488 T37489 T37490TBU D-09RD 50733201310100 181080 1/18/2023 AK E-LINE LDL Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.02.06 11:33:21 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: CT Operations 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: McArthur River 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11,060 N/A Casing Collapse Structural Conductor Surface 1,540psi Intermediate 3,090psi Production 7,020psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Ryan Rupert Contact Email:Ryan.Rupert@hilcorp.com Contact Phone:(907) 777-8503 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: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 10,90410,190 10,038 1916 20"633 MD 633 8,160psi10,17411,044 633 3,419 5,186 Perforation Depth MD (ft): 11,044 7" 9-5/8"5,721 13-3/8"2,531 2,531 5,721 Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY N/A 5,750psi 3,090psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018729 181-080 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20131-01-00 Hilcorp Alaska, LLC Trading Bay Unit D-09RD Hemlock Oil & Middle Kenai G Oil Same N/A Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 18#/P-110 & 12.6#/12.75 & 13.70 9,863 2/10/2023 Hyd Packer & N/A 9,785 (MD) 8,958 (TVD) & 9,839 (MD) 9,009 (TVD) & N/A 9,869 - 10,850 9,036 - 9,111 5" & 4-1/2" 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: AOGCC USE ONLY Operations Manager Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Carlisle at 3:24 pm, Jan 26, 2023 323-045 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2023.01.26 12:17:00 -09'00' Dan Marlowe (1267) BJM 2/1/23 X CT BOP test to 2500 psi. 10-404 DSR-1/26/23SFD 2/1/2023GCW 02/02/23JLC 2/2/2023 2/2/23Brett W. Huber. Sr. Digitally signed by Brett W. Huber. Sr. Date: 2023.02.02 12:25:13 -09'00' RBDMS JSB 020323 Packer repair Well: D-09RD Well Name:D-09RD API Number:50-733-20131-01-00 Current Status:SI Class I Water Injector Leg:Leg #A-1 (NE corner) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:181-080 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Maximum Expected BHP:2,851 psi @ 9,350’ TVD SBHP on 1/16/23 after >1year SI Max. Potential Surface Pressure: 1916 psi Using 0.1 psi/ft from 9350’ TVD Brief Well Summary D-09RD is a shut-in Class-I water injector completed in the Hemlock and G-zone sands. It was SI April-2020 for suspected annular communication. In September-2022 the tubing was replaced and a stacker-packer completion run. The well passed an MIT-IA to 2500psi. Upon retesting the 7” x 5” IA, the pressure rapidly fell off indicating a downhole failure. Subsequent leak diagnostics revealed that the packer at 9785’ is leaking. It’s unclear if the packer has failed due to mechanical failure, or fluid bypass from being set in ratty 7” casing. The goal of this project is to repair the failed packer, pass an MIT-IA, and return the well to injection. Pertinent wellbore information: - 1/18/23: Spinner / temperature / Pressure (STP) leak logging o While pumping down the IA at 0.4bpm at <200psi, temperature shifts indicated no casing leak o Temperature data suggested TxIA communication o Stop counts indicated no TxIA communication across the tubing above the packer at 9785’ MD o Data suggests that the packer at 9785’ MD is leaking - 10/11/22 o Operations performs MIT-IA as a pre-test before witnessed tests o While pressuring up, the pressure stopped building, and rapidly fell off. o MIT-IA FAIL - 9/8/22 tubing swap o Old tubing pulled from cut at 9835’ MD o New tubing ran with stacker packer (swallowed old tubing stub with non-sealing overshot) o MIT-T passed to 3750psi against a plug at 9810’ MD o MIT-IA passed to 2500psi against new packer at 9785’ MD - 4/30/20: o Hilcorp reported to agencies about possible annular communication. o Injection stopped o MIT-IA failed - 6/14/14: MIT-IA to 2400psi passed against a packer set at 9839’ MD - 12/6/13 RWO to replace tubing: o Prior packer had to be milled from 9681 – 9819’ MD o 7” casing caliper was run from 9883’ to surface o Caliper showed casing wear and increased wall loss from 9760’ – 9883’ (bottom logged interval) o New tubing / packer installed Class II Class II SFD Packer repair Well: D-09RD E-Line (some/all steps may be moved to CT, as needed) 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 2000psi high 3. Set 4-1/2” composite plug at ±9,838’ MD 4. Punch tubing at ±9,830’ MD 5. Set 4-1/2” composite cement retainer at ±9,820’ MD 6. RDMO EL Coiled Tubing Part #1 1. MIRU Coiled Tubing and pressure control equipment 2. PT lubricator to 250psi low / 3500psi high 3. Sting into cement retainer at ±9,820’ MD and establish circulation up the 5” x 7” Inner Annulus 4. Pump cement job to remediate failed packer a. Take returns up IA b. Target ToC will be 9450’ MD c. Cement volume below retainer will be ±5.3bbls i. 0.2bbls between retainer and composite ii. 0.8bbls in 4-1/2” x 7” annulus iii. 4.3bbls in 5” x 7” annulus 5. Once target cement volume is pumped, unstring and lay in 10’ cement on top of retainer 6. POOH and WoC Coiled Tubing Part #2 1. After WoC, MIT-IA to 2300psi per EPA standards (9023’ TVD * 0.25 = 2256psi) 2. After passing MIT-IA, return to well with CT, and pickup motor and mill 3. Mill out cement retainer/cement/composite 4. Repeat MIT-IA to 2300psi per EPA standards 5. RDMO CT Post-work 1. Notify EPA and AOGCC for upcoming MIT-IA witness timing 2. Perform witnessed MIT-IA to EPA standards to 2300psi Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. CT BOP Drawing 4. CT flow diagram Perform CT BOP test to 2500 psi. -bjm _____________________________________________________________________________________ Updated By: JLL 01/09/23 SCHEMATIC Well: D-09RD Last Completed: 09/07/22 PTD: 181-080 API: 50-733-20131-01-00 PBTD =10,094’ TD = 11,060’ MAX. HOLE ANGLE = 31° 6 D-09 Motherbor e 9- 5/8” Window @ 5,750 MD RKB to TBG Head = 39.52’ 7 B-3 HK-3 B-2 3 1 B-4 B-1 B-0 4 2 5 B-5 G-2 G-3 G-4 G-1 HK-1 HK-2 HK-4 HK-5 X 8 DV collars at 3,486’ and 2,604’ in 7” Unable to close top DV. Sqz w/ 35 sx. Passed PT X CASING DETAIL Size Wt Grade Conn ID Top Btm 20"Surf 633’ 13-3/8” 61 J-55 Butt 12.515 44.80' 2,531' 9-5/8” 40 N-80 Butt 8.835 42.88' 4,754’ 9-5/8” 43.5 N-80 Butt 8.755 4,754’ 5,721’ 7” 29 N-80 Butt 6.184 41.47' 11,044' TUBING DETAIL 5" 18# P-110 Hydril 513 4.276" Surf 9,779' 4.5" 12.6# L-80 LTC 9,779 9,835' 4-1/2" 12.75 / 13.70 L-80 / Polycore 8 rnd EUE 3.40" 9,835' 9,863' No.Depth (MD) Depth (TVD)ID Item 1 39.52' 39.52' 4.00" Hanger 2 9,785' 8,958' 3.99" 7" 23-32# LTC BxP Hydraulic Isolation Packer Permanent 3 9,810' 8,981' 3.813" 4 1/2" LTC BxP 3.813 X Profile Nipple 4 9,835' 9,005' Non-sealing Overshot 5 9,839' 9,009' 4.00" Nickel Coated Hyd set Permanent Packer 6 9,850’ 4-1/2” WRP (set 1/17/23) 7 9,853 9,023' 2.81" X Nipple - 3-1/2" EUE Box x Pin w/2.81" X-Profile 8 9,864' 9,033' 3.995"Wireline Entry Guide Perforation Detail Zone Top(MD) Btm(MD) Top(TVD) Btm (TVD) Amt SPF Date Status G-1 9,869' 9,883' 9,036' 9,146’ 16 5 12/7/2013 Open G-2 9,912' 9,926' 9,079' 9,092’ 14 5 12/7/2013 Open G-2 9,912' 9,926' 9,079' 9,092’ 14 6 5/31/2000 Open G-2 9,932' 9,946' 9,098' 9,111’ 14 5 12/7/2013 Open G-2 9,932' 9,946' 9,098' 9,111’ 14 6 5/31/2000 Open G-3 9,982' 10,004' 9,146' 9,166’ 22 5 12/7/2013 Open G-3 9,982' 10,004' 9,146' 9,166’ 22 6 5/31/2000 Open G-4 10,018' 10,056' 9,180' 9,216’ 38 5 12/7/2013 Open G-4 10,018' 10,056' 9,180' 9,216’ 38 6 5/31/2000 Open G-5 10,157' 10,174' 9,313' 9,329’ 17 5 12/7/2013 Open G-5 10,190' 10,207' 9,345' 9,361’ 17 5 12/7/2013 Open G-7 10,302' 10,320' 9,453' 9,470’ 18 5 12/7/2013 Open B-0 10,300' 10,320' 9,451' 9,470’ 20 22 5/31/2000 Open HK-1 10,370' 10,410' 9,519' 9,557’ 40 5 12/7/2013 Open B-1 10,370' 10,410' 9,519' 9,557’ 40 10 5/31/2000 Open HK-2 10,428' 10,520' 9,575' 9,664’ 92 5 12/7/2013 Open B-2 10,435' 10,470' 9,582' 9,615’ 35 4 & 8 4/16/1987 Open B-3 10,500' 10,520' 9,645' 9,664’ 20 9 1/9/1985 Open HK-3 10,550' 10,565' 9,693' 9,707’ 15 5 12/7/2013 Open B-3 10,550' 10,565' 9,693' 9,707’ 15 4 1/9/1985 Open HK-3 10,580' 10,630' 9,722' 9,770’ 50 5 12/7/2013 Open B-3 10,585' 10,630' 9,727' 9,770’ 45 4 1/9/1985 Open HK-4 10,642' 10,690' 9,783' 9,829’ 48 5 12/7/2013 Open B-4 10,642' 10,690' 9,783' 9,829’ 48 4 1/9/1985 Open B-5 10,725' 10,800' 9,863' 9,936’ 75 4 4/16/1987 Open HK-5 10,725' 10,851' 9,863' 9,986’ 125 5 12/7/2013 Open B-5 10,810' 10,850' 9,946' 9,985’ 40 4 4/16/1987 Open SLICKLINE / FISH / FILL INFORMATION: A. 2/27/00: Baker F-1 Pkr milled/pushed to bottom at 10,957 ’. B. 12/12/13: Well cleaned out to PBTD at 10904’. OPEN HOLE / CEMENT DETAIL 13-3/8"17-1/2" hole: Pumped 2000sxs (392bbls) class G 14ppg lead followed by 400sxs (78bbls) class G 15.7ppg tail cement.Saw cement to surface. 9-5/8" 12-1/4" hole TD'd at 11,341' MD in D-09 perentbore (1968). Primary job pumped 720+600sxs of Class G. Saw trace cement when circulating through DV collar at 6966' MD. Stage 2 through DV collar at 6966' MD: Pumped 1148sxs (225bbls) class G lead followed by 100sxs (20bbls) class G neat tail cement.12/31/81 CBL shows ToC at 2070’ MD 7" 8-1/2" hole: Primary job pumped 1150sxs (225bbls). Cement not pumped through either DV collar initially. Top DV at 2604' MD wouldn't close. 1/25/82 CMIT-7"x9-5/8" PASS to 2800psi through open DV collar at 2604' MD. (proves cement made it up above the 9-5/8" window) Cement retainer circ'd 35sxs (7bbls) through DV at 2604' MD. 5.2bbls made it behind pipe. 1/28/82 CBL show's ToC at 1075' MD _____________________________________________________________________________________ Updated By: CRR 01/26/23 PROPOSED SCHEMATIC Well: D-09RD PTD: 181-080 API: 50-733-20131-01-00 OPEN HOLE / CEMENT DETAIL 13-3/8"17-1/2" hole: Pumped 2000sxs (392bbls) class G 14ppg lead followed by 400sxs (78bbls) class G 15.7ppg tail cement.Saw cement to surface. 9-5/8" 12-1/4" hole TD'd at 11,341' MD in D-09 perentbore (1968). Primary job pumped 720+600sxs of Class G. Saw trace cement when circulating through DV collar at 6966' MD. Stage 2 through DV collar at 6966' MD: Pumped 1148sxs (225bbls) class G lead followed by 100sxs (20bbls) class G neat tail cement.12/31/81 CBL shows ToC at 2070’ MD 7" 8-1/2" hole: Primary job pumped 1150sxs (225bbls). Cement not pumped through either DV collar initially. Top DV at 2604' MD wouldn't close. 1/25/82 CMIT-7"x9-5/8" PASS to 2800psi through open DV collar at 2604' MD. (proves cement made it up above the 9-5/8" window) Cement retainer circ'd 35sxs (7bbls) through DV at 2604' MD. 5.2bbls made it behind pipe. 1/28/82 CBL show's ToC at 1075' MDPBTD =10,094’ TD =11,060’ MAX. HOLE ANGLE = 31° D-09 Motherbore 9- 5/8” Window @ 5,750 MD RKB to TBG Head = 39.52’ 6 B-3 HK-3 B-2 3 1 B-4 B-1 B-0 4 2 5 B-5 G-2 G-3 G-4 G-1 HK-1 HK-2 HK-4 HK-5 X 7 DV collars at 3,486’ and 2,604’ in 7” Unable to close top DV. Sqz w/ 35 sx. Passed PT X ToC @ ±9,450’ MD CASING DETAIL Size Wt Grade Conn ID Top Btm 20"Surf 633’ 13-3/8” 61 J-55 Butt 12.515 44.80' 2,531' 9-5/8” 40 N-80 Butt 8.835 42.88' 4,754’ 9-5/8” 43.5 N-80 Butt 8.755 4,754’ 5,721’ 7” 29 N-80 Butt 6.184 41.47' 11,044' TUBING DETAIL 5" 18# P-110 Hydril 513 4.276" Surf 9,779' 4.5" 12.6# L-80 LTC 9,779 9,835' 4-1/2" 12.75 / 13.70 L-80 / Polycore 8 rnd EUE 3.40" 9,835' 9,863' No.Depth (MD) Depth (TVD)ID Item 1 39.52' 39.52' 4.00" Hanger 2 9,785' 8,958' 3.99" 7" 23-32# LTC BxP Hydraulic Isolation Packer Permanent 3 9,810' 8,981' 3.813" 4 1/2" LTC BxP 3.813 X Profile Nipple 4 9,835' 9,005' Non-sealing Overshot 5 9,839' 9,009' 4.00" Nickel Coated Hyd set Permanent Packer 6 9,853 9,023' 2.81" X Nipple - 3-1/2" EUE Box x Pin w/ 2.81" X-Profile 7 9,864' 9,033' 3.995"Wireline Entry Guide Perforation Detail Zone Top(MD) Btm(MD) Top(TVD) Btm (TVD) Amt SPF Date Status G-1 9,869' 9,883' 9,036' 9,146’ 16 5 12/7/2013 Open G-2 9,912' 9,926' 9,079' 9,092’ 14 5 12/7/2013 Open G-2 9,912' 9,926' 9,079' 9,092’ 14 6 5/31/2000 Open G-2 9,932' 9,946' 9,098' 9,111’ 14 5 12/7/2013 Open G-2 9,932' 9,946' 9,098' 9,111’ 14 6 5/31/2000 Open G-3 9,982' 10,004' 9,146' 9,166’ 22 5 12/7/2013 Open G-3 9,982' 10,004' 9,146' 9,166’ 22 6 5/31/2000 Open G-4 10,018' 10,056' 9,180' 9,216’ 38 5 12/7/2013 Open G-4 10,018' 10,056' 9,180' 9,216’ 38 6 5/31/2000 Open G-5 10,157' 10,174' 9,313' 9,329’ 17 5 12/7/2013 Open G-5 10,190' 10,207' 9,345' 9,361’ 17 5 12/7/2013 Open G-7 10,302' 10,320' 9,453' 9,470’ 18 5 12/7/2013 Open B-0 10,300' 10,320' 9,451' 9,470’ 20 22 5/31/2000 Open HK-1 10,370' 10,410' 9,519' 9,557’ 40 5 12/7/2013 Open B-1 10,370' 10,410' 9,519' 9,557’ 40 10 5/31/2000 Open HK-2 10,428' 10,520' 9,575' 9,664’ 92 5 12/7/2013 Open B-2 10,435' 10,470' 9,582' 9,615’ 35 4 & 8 4/16/1987 Open B-3 10,500' 10,520' 9,645' 9,664’ 20 9 1/9/1985 Open HK-3 10,550' 10,565' 9,693' 9,707’ 15 5 12/7/2013 Open B-3 10,550' 10,565' 9,693' 9,707’ 15 4 1/9/1985 Open HK-3 10,580' 10,630' 9,722' 9,770’ 50 5 12/7/2013 Open B-3 10,585' 10,630' 9,727' 9,770’ 45 4 1/9/1985 Open HK-4 10,642' 10,690' 9,783' 9,829’ 48 5 12/7/2013 Open B-4 10,642' 10,690' 9,783' 9,829’ 48 4 1/9/1985 Open B-5 10,725' 10,800' 9,863' 9,936’ 75 4 4/16/1987 Open HK-5 10,725' 10,851' 9,863' 9,986’ 125 5 12/7/2013 Open B-5 10,810' 10,850' 9,946' 9,985’ 40 4 4/16/1987 Open SLICKLINE / FISH / FILL INFORMATION: A. 2/27/00: Baker F-1 Pkr milled/pushed to bottom at 10,957 ’. B. 12/12/13: Well cleaned out to PBTD at 10904’. COIL TUBING BOP SWAB VALVE MASTER VALVE HilcorpMonopod Rig 56Flow Diagram Fluids Pumped Fluids ReturnedValve Open Valve ClosedGate Valve Ball ValveButterfly Valve Lo Torq ValveAutomatic Choke Manual ChokePressure Gauge Knife ValveChoke LineP PIT SYSTEM SucƟon SHAKER SHAKER CHOKE MANIFOLDGAS BUSTER Panic LineC12 C13 C15 C14 C16 A B C4 C5 C6 C7 C2 C10 C9 C11 C8 C3 P C1 C 1 Regg, James B (OGC) From:Brooks, Phoebe L (OGC) Sent:Thursday, October 27, 2022 1:27 PM To:Josh Allely - (C) Cc:Regg, James B (OGC) Subject:RE: [EXTERNAL] RE: MIT - TBU D-09RD - 9/8/2022 Attachments:MIT D-09RD 09-08-22 Revised.xlsx Thanks Josh. Attached is a revised report changing the packer TVD to reflect 9009as we use the packer closest to the uppermost open perfs. Please update your copy. Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907 793 1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From:Josh Allely (C) <Josh.Allely@hilcorp.com> Sent:Thursday, October 27, 2022 8:53 AM To:Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject:RE: [EXTERNAL] RE: MIT TBU D 09RD 9/8/2022 D-09RD wellbore schematic attached. Thanks Josh Josh Allely Well Integrity Engineer Kenai Hilcorp Alaska 907-777-8505 From:Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Sent:Tuesday, October 25, 2022 4:04 PM To:Josh Allely (C) <Josh.Allely@hilcorp.com> Subject:[EXTERNAL] RE: MIT TBU D 09RD 9/8/2022 Josh, Will you send me the current wellbore schematic so I can verify the packer TVD? CAUTION:External sender. DO NOT open links or attachments from UNKNOWN senders. revised report changing the packer TVD to reflect 9009as we use the packer closest to the uppermost open perfs. 2 Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907 793 1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From:Josh Allely (C) <Josh.Allely@hilcorp.com> Sent:Wednesday, October 5, 2022 10:52 AM To:Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject:MIT TBU D 09RD 9/8/2022 Attached is the official report of the successful MIT performed on TBU D-09RD on 9/8/22 (Class I Disposal Well). This is the pre-injection MIT-IA performed after setting packer per Guidance Bulletin 10-02B. The MIT will be repeated with AOGCC and EPA witness prior to injection start-up pending coordination with the EPA. Josh Allely Well Integrity Engineer Kenai Hilcorp Alaska 907-777-8505 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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. Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1810800 Type Inj N Tubing 0 0 0 0 Type Test P Packer TVD 9009 BBL Pump 2.0 IA 0 2600 2550 2550 Interval O Test psi 2252 BBL Return 2.0 OA 365 365 365 365 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Hilcorp Alaska, LLC McArthur River / Trading Bay Unit / Dolly Varden Platform Ed Hooter 09/08/22 Notes: Pre-injection MIT-IA performed after setting packer per Guidance Bulletin 10-02B. Test will be repeated with AOGCC and EPA witness prior to injection start-up. New packer set at 9785' MD / 8958' TVD Notes: Notes: Notes: TBU D-09RD Form 10-426 (Revised 01/2017)2022-0908_MIT_TBU_D-09RD By Anne Prysunka at 12:37 pm, Oct 03, 2022 David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/22/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL TBU D-09A CBL Well API # PTD # Log Date Log Company Log Type AOGCC Eset # TBU D-09A 50733201310100 180080 1/28/1982 Dresser Atlas CBL Please include current contact information if different from above. TBU D-09RD 181-080 T37028 PTD:181-080 Kayla Junke Digitally signed by Kayla Junke Date: 2022.09.22 12:56:17 -08'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________TRADING BAY UNIT D-09RD JBR 09/15/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 Rigless workover (crane & csg jacks) utilizing all the equipment from Rig 404 except the circulating manifold. 4.5" and 5" test joints used for testing. On test #3 the kill valve failed. The valve was serviced and retested for a pass. A kick/trip drill with both crews was done before leaving location. The drill was expected as it was stated to do so in the Sundry so the drill went very well. Test Results TEST DATA Rig Rep:C. Hanivold/E. CastangOperator:Hilcorp Alaska, LLC Operator Rep:H. Soule/E. Hooter Rig Owner/Rig No.:Hilcorp 404 PTD#:1810800 DATE:9/2/2022 Type Operation:WRKOV Annular: 250/3000Type Test:INIT Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopGDC220902174137 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 4.5 MASP: 2925 Sundry No: 322-390 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.NA Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 11 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8" 5000 P #1 Rams 1 2 7/8"x5.5" V P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16" 5000 P HCR Valves 2 2 1/16" 5000 P Kill Line Valves 2 2 1/16" 5000 FP Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P2000 200 PSI Attained P17 Full Pressure Attained P76 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P4@ 2180 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P20 #1 Rams P5 #2 Rams P5 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2 9 9 99 9 9 9 999 9 9 9 9 SVL%23(WHVWDOORZHGLQVWHDGRISVLUHTXLUHGE\ 6XQGU\VHHDWWDFKHGHPDLOMEU Rigless workover (crane & csg jacks) utilizing all the equipment from Rig 404 except the circulating manifold. kill valve failed.kick/trip drill with both crews FP DWWDFKHGHPDLO 5HJJ-DPHV%2*& )URP5HJJ-DPHV%2*& 6HQW7XHVGD\$XJXVW30 7R+DUROG6RXOH&.DWKHULQH2 &RQQRU &F0F/HOODQ%U\DQ-2*&+RZDUG+RRWHU&&RRN*X\'2*& 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rom:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] RE: D-09RD (PTD: 181-080) Sundry 322-390 BOP Question Date:Tuesday, August 30, 2022 2:53:33 PM TBU D-09RD (PTD 1810800) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (OGC) Sent: Tuesday, August 30, 2022 2:52 PM To: Harold Soule - (C) <hsoule@hilcorp.com>; Katherine O'Connor <Katherine.Oconnor@hilcorp.com> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Howard Hooter - (C) <Howard.Hooter@hilcorp.com>; Cook, Guy D (OGC) <guy.cook@alaska.gov> Subject: RE: [EXTERNAL] RE: D-09RD (PTD: 181-080) Sundry 322-390 BOP Question Request to test BOPE to 3000 psi is approved. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Harold Soule - (C) <hsoule@hilcorp.com> Sent: Monday, August 29, 2022 1:40 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Katherine O'Connor <Katherine.Oconnor@hilcorp.com> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Howard Hooter - (C) <Howard.Hooter@hilcorp.com> Subject: RE: [EXTERNAL] RE: D-09RD (PTD: 181-080) Sundry 322-390 BOP Question Yes Sir, everything is the same except for the standpipe/circulating manifold. Harold Soule Office 907-776-6754 Cell 907-227-9400 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Monday, August 29, 2022 1:30 PM To: Katherine O'Connor <Katherine.Oconnor@hilcorp.com> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Harold Soule - (C) <hsoule@hilcorp.com>; Howard Hooter - (C) <Howard.Hooter@hilcorp.com> Subject: [EXTERNAL] RE: D-09RD (PTD: 181-080) Sundry 322-390 BOP Question Accumulator, choke manifold, etc all from Rig 404? Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Katherine O'Connor <Katherine.Oconnor@hilcorp.com> Sent: Monday, August 29, 2022 9:59 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Harold Soule - (C) <hsoule@hilcorp.com>; Howard Hooter - (C) <Howard.Hooter@hilcorp.com> Subject: D-09RD (PTD: 181-080) Sundry 322-390 BOP Question Hi Jim On the condition of approval for D09RD it was written in to initially test the BOPs to rated working pressure and subsequent tests to 3000 psi. These are the same BOPs we have been using for all previous 404 jobs this year, and they were not disassembled before moving over to D-09RD; it is also the same supervisors who oversaw the previous workover (G-02RD) and the equipment move. May we change the initial test to 3000 psi instead of to full working pressure? Thanks Katherine O’Connor CIO Operations Engineer Katherine.oconnor@hilcorp.com W: (907) 777-8376 C: (214) 684-7400 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that 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. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. 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Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.08.04 16:56:44 -08'00' RBDMS JSB 080822 tĞůůEĂŵĞ͗ͲϬϵZW/EƵŵďĞƌ͗ϱϬͲϳϯϯͲϮϬϭϯϭͲϬϭ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗^//ŶũĞĐƚŽƌ>ĞŐ͗>ĞŐηͲϮ;Et ĐŽƌŶĞƌͿ ĂƚĞ͗ϴͬϭͬϮϮZŝŐ͗Eͬ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍ ĂƚĞZĞŐ͘ƉƉƌŽǀĂů ZĞĐ͛ǀĚ͗ Eͬ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗:ƵĂŶŝƚĂ>ŽǀĞƚƚWĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϭϴϭͲϬϴϬ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗<ĂƚŚĞƌŝŶĞK͛ŽŶŶŽƌKĨĨŝĐĞ͗ϵϬϳͲϳϳϳͲϴϯϳϲĞůů͗ϮϭϰͲϲϴϰͲϳϰϬϬ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗ŚĂĚ,ĞůŐĞƐŽŶĞůů͗ϵϬϳͲϮϮϵͲϰϴϮϰ Current Bottom Hole Pressure: ~3250 psi @ 9036’ TVD Based off of fluid level shot Maximum Expected BHP: ~3250 psi @ 9036’ TVD Max. 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ϱϱŬŽǀĞƌƚŚĞƚŽƉŽĨͲϬϵͿ ϴ͘WƵůůΘůĂǇĚŽǁŶƚƵďŝŶŐ ϵ͘WhĂŶĚZ/,ǁŝƚŚŶĞǁƚƵďŝŶŐĂŶĚƉĂĐŬĞƌĐŽŵƉůĞƚŝŽŶ;ƌĞƉĞĂƚŝŶŐƐĂŵĞƉƌŽĐĞƐƐŝŶƌĞǀĞƌƐĞĂƐ ƉƵůůŝŶŐƚƵďŝŶŐͿ Ă͘^ĞĞƉƌŽƉŽƐĞĚƐĐŚĞŵĂƚŝĐĨŽƌĚĞƚĂŝůƐ ď͘^ĞƚƉĂĐŬĞƌĂŶĚƚĞƐƚƚƵďŝŶŐƚŽϯϱϬϬƉƐŝĐŚĂƌƚŝŶŐĨŽƌϯϬŵŝŶ Đ͘dĞƐƚ/ƚŽϮϱϬϬƉƐŝĐŚĂƌƚŝŶŐĨŽƌϯϬŵŝŶƵƚĞƐ ϭϬ͘EKWƐΘEhƚƌĞĞ ϭϭ͘^ĐŚĞĚƵůĞǁŝƚŶĞƐƐĞĚD/d/ƚŽϮϱϬϬƉƐŝǁŝƚŚWĂŶĚK'ďĞĨŽƌĞƌĞƚƵƌŶŝŶŐǁĞůůƚŽŝŶũĞĐƚŝŽŶ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭͿƵƌƌĞŶƚƐĐŚĞŵĂƚŝĐ ϮͿWƌŽƉŽƐĞĚƐĐŚĞŵĂƚŝĐ ϯͿƵƌƌĞŶƚǁĞůůŚĞĂĚĚŝĂŐƌĂŵ dŚŝƐǁŝůůďĞĚŽŶĞǁŝƚŚĐĂƐŝŶŐũĂĐŬƐĂŶĚƚŚĞĐƌĂŶĞĂƐƚ '/% ϰͿWƌŽƉŽƐĞĚǁĞůůŚĞĂĚĚŝĂŐƌĂŵ ϱͿKWĚŝĂŐƌĂŵ ϲͿ&ůƵŝĚĨůŽǁĚŝĂŐƌĂŵ ϳͿK'ZtKĐŚĂŶŐĞĨŽƌŵ ^ŝǌĞ tƚ 'ƌĂĚĞ ŽŶŶ / dŽƉ ƚŵ ϮϬΗ ^ƵƌĨ ϲϯϯ͛ ϭϯͲϯͬϴ͟ ϲϭ :Ͳϱϱ Ƶƚƚ ϭϮ͘ϱϭϱ ϰϰ͘ϴϬΖ Ϯ͕ϱϯϭΖ ϵͲϱͬϴ͟ ϰϬ EͲϴϬ Ƶƚƚ ϴ͘ϴϯϱ ϰϮ͘ϴϴΖ ϰ͕ϳϱϰ͛ ϵͲϱͬϴ͟ ϰϯ͘ϱ EͲϴϬ Ƶƚƚ ϴ͘ϳϱϱ ϰ͕ϳϱϰ͛ ϱ͕ϳϮϭ͛ ϳ͟ Ϯϵ EͲϴϬ Ƶƚƚ ϲ͘ϭϴϰ ϰϭ͘ϰϳΖ ϭϭ͕ϬϰϰΖ ϰͲϭͬϮ͟ϭϮ͘ϳϱͬ ϭϯ͘ϳϬ >ͲϴϬͬ WŽůǇĐŽƌĞ ϴƌŶĚh ϯ͘ϰϬΗ ϯϵ͘ϱϮΖ ϵ͕ϴϲϯΖ :t>Zzd/> EŽ͘ĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ / K ϭ ϯϵ͘ϱϮΖ ϯϵ͘ϱϮΖ ϰ͘ϬϬΗ Ϯ ϵ͕ϴϯϵΖ ϵ͕ϬϬϵΖ ϰ͘ϬϬΗ ϱ͘ϴϵΗ ϯ ϵ͕ϴϱϯΖ ϵ͕ϬϮϯΖ Ϯ͘ϴϭΗ ϰ͘ϱϬΗ ϰ ϵ͕ϴϲϰΖ ϵ͕ϬϯϯΖ ϯ͘ϵϵϱΗ ϱ͘ϬϬΗ ŽŶĞ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ ŵƚ ^W& ĂƚĞ ^ƚĂƚƵƐ 'Ͳϭ ϵ͕ϴϲϵΖ ϵ͕ϴϴϯΖ ϵ͕ϬϯϲΖ ϴ͕ϮϰϱΖ ϭϲ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ 'ͲϮ ϵ͕ϵϭϮΖ ϵ͕ϵϮϲΖ ϵ͕ϬϳϵΖ ϴ͕ϮϴϳΖ ϭϰ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ 'ͲϮ ϵ͕ϵϭϮΖ ϵ͕ϵϮϲΖ ϵ͕ϬϳϵΖ ϴ͕ϮϴϳΖ ϭϰ ϲ ϱͬϯϭͬϮϬϬϬ KƉĞŶ 'ͲϮ ϵ͕ϵϯϮΖ ϵ͕ϵϰϲΖ ϵ͕ϬϵϴΖ ϴ͕ϯϬϱΖ ϭϰ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ 'ͲϮ ϵ͕ϵϯϮΖ ϵ͕ϵϰϲΖ ϵ͕ϬϵϴΖ ϴ͕ϯϬϱΖ ϭϰ ϲ ϱͬϯϭͬϮϬϬϬ KƉĞŶ 'Ͳϯ ϵ͕ϵϴϮΖ ϭϬ͕ϬϬϰΖ ϵ͕ϭϰϲΖ ϴ͕ϯϱϭΖ ϮϮ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ 'Ͳϯ ϵ͕ϵϴϮΖ ϭϬ͕ϬϬϰΖ ϵ͕ϭϰϲΖ ϴ͕ϯϱϭΖ ϮϮ ϲ ϱͬϯϭͬϮϬϬϬ KƉĞŶ 'Ͳϰ ϭϬ͕ϬϭϴΖ ϭϬ͕ϬϱϲΖ ϵ͕ϭϴϬΖ ϴ͕ϯϴϯΖ ϯϴ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ 'Ͳϰ ϭϬ͕ϬϭϴΖ ϭϬ͕ϬϱϲΖ ϵ͕ϭϴϬΖ ϴ͕ϯϴϯΖ ϯϴ ϲ ϱͬϯϭͬϮϬϬϬ KƉĞŶ 'Ͳϱ ϭϬ͕ϭϱϳΖ ϭϬ͕ϭϳϰΖ ϵ͕ϯϭϯΖ ϴ͕ϱϭϭΖ ϭϳ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ 'Ͳϱ ϭϬ͕ϭϵϬΖ ϭϬ͕ϮϬϳΖ ϵ͕ϯϰϱΖ ϴ͕ϱϰϭΖ ϭϳ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ 'Ͳϳ ϭϬ͕ϯϬϮΖ ϭϬ͕ϯϮϬΖ ϵ͕ϰϱϯΖ ϴ͕ϲϰϰΖ ϭϴ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ ͲϬ ϭϬ͕ϯϬϬΖ ϭϬ͕ϯϮϬΖ ϵ͕ϰϱϭΖ ϴ͕ϲϰϮΖ ϮϬ ϮϮ ϱͬϯϭͬϮϬϬϬ KƉĞŶ ,<Ͳϭ ϭϬ͕ϯϳϬΖ ϭϬ͕ϰϭϬΖ ϵ͕ϱϭϵΖ ϴ͕ϳϬϳΖ ϰϬ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ Ͳϭ ϭϬ͕ϯϳϬΖ ϭϬ͕ϰϭϬΖ ϵ͕ϱϭϵΖ ϴ͕ϳϬϳΖ ϰϬ ϭϬ ϱͬϯϭͬϮϬϬϬ KƉĞŶ ,<ͲϮ ϭϬ͕ϰϮϴΖ ϭϬ͕ϱϮϬΖ ϵ͕ϱϳϱΖ ϴ͕ϳϲϬΖ ϵϮ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ ͲϮ ϭϬ͕ϰϯϱΖ ϭϬ͕ϰϳϬΖ ϵ͕ϱϴϮΖ ϴ͕ϳϲϲΖ ϯϱ ϰΘϴ ϰͬϭϲͬϭϵϴϳ KƉĞŶ Ͳϯ ϭϬ͕ϱϬϬΖ ϭϬ͕ϱϮϬΖ ϵ͕ϲϰϱΖ ϴ͕ϴϮϲΖ ϮϬ ϵ ϭͬϵͬϭϵϴϱ KƉĞŶ ,<Ͳϯ ϭϬ͕ϱϱϬΖ ϭϬ͕ϱϲϱΖ ϵ͕ϲϵϯΖ ϴ͕ϴϳϭΖ ϭϱ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ Ͳϯ ϭϬ͕ϱϱϬΖ ϭϬ͕ϱϲϱΖ ϵ͕ϲϵϯΖ ϴ͕ϴϳϭΖ ϭϱ ϰ ϭͬϵͬϭϵϴϱ KƉĞŶ ,<Ͳϯ ϭϬ͕ϱϴϬΖ ϭϬ͕ϲϯϬΖ ϵ͕ϳϮϮΖ ϴ͕ϴϵϴΖ ϱϬ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ Ͳϯ ϭϬ͕ϱϴϱΖ ϭϬ͕ϲϯϬΖ ϵ͕ϳϮϳΖ ϴ͕ϵϬϯΖ ϰϱ ϰ ϭͬϵͬϭϵϴϱ KƉĞŶ ,<Ͳϰ ϭϬ͕ϲϰϮΖ ϭϬ͕ϲϵϬΖ ϵ͕ϳϴϯΖ ϴ͕ϵϱϲΖ ϰϴ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ Ͳϰ ϭϬ͕ϲϰϮΖ ϭϬ͕ϲϵϬΖ ϵ͕ϳϴϯΖ ϴ͕ϵϱϲΖ ϰϴ ϰ ϭͬϵͬϭϵϴϱ KƉĞŶ Ͳϱ ϭϬ͕ϳϮϱΖ ϭϬ͕ϴϬϬΖ ϵ͕ϴϲϯΖ ϵ͕ϬϯϮΖ ϳϱ ϰ ϰͬϭϲͬϭϵϴϳ KƉĞŶ ,<Ͳϱ ϭϬ͕ϳϮϱΖ ϭϬ͕ϴϱϭΖ ϵ͕ϴϲϯΖ ϵ͕ϬϯϭΖ ϭϮϱ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ Ͳϱ ϭϬ͕ϴϭϬΖ ϭϬ͕ϴϱϬΖ ϵ͕ϵϰϲΖ ϵ͕ϭϭϭΖ ϰϬ ϰ ϰͬϭϲͬϭϵϴϳ KƉĞŶ ^/E'd/> hƉĚĂƚĞĚďǇ͗:>>ϬϲͬϮϵͬϮϮ /ƚĞŵ WĞƌĨŽƌĂƚŝŽŶĞƚĂŝů ,ĂŶŐĞƌ EŝĐŬĞůŽĂƚĞĚ,ǇĚƐĞƚWĞƌŵĂŶĞŶƚWĂĐŬĞƌ ͚y͛EŝƉƉůĞ tŝƌĞůŝŶĞŶƚƌǇ'ƵŝĚĞ Note: Lined tubing, wireline speed normal unless running "sharp/aggressive tools" dƵďŝŶŐĞƚĂŝů ^,Dd/ DĐƌƚŚƵƌZŝǀĞƌ&ŝĞůĚ͕dh tĞůů͗ͲϬϵZ ŽŵƉůĞƚĞĚ͗ϬϯͬϭϱͬϮϬϭϰ 3%7' ¶ 7' ¶ 0$;+2/($1*/( q 5.%WR7%*+HDG ¶ Ͳϯ ,<Ͳϯ ͲϮ Ͳϰ Ͳϭ ͲϬ Ͳϱ 'ͲϮ 'Ͳϯ 'Ͳϰ 'Ͳϭ ,<Ͳϭ ,<ͲϮ ,<Ͳϰ ,<Ͳϱ ; ^>/<>/Eͬ&/^,ͬ&/>>/E&KZDd/KE͗ ͘ϮͬϮϳͬϬϬ͗ĂŬĞƌ&ͲϭWŬƌŵŝůůĞĚͬƉƵƐŚĞĚƚŽďŽƚƚŽŵĂƚϭϬ͕ϵϱϳ͛͘ ͘ϭϮͬϭϮͬϭϯ͗tĞůůĐůĞĂŶĞĚŽƵƚƚŽWdĂƚϭϬϵϬϰ͛͘ sĂƚϯ͕ϰϴϲ͛ ĂŶĚϮ͕ϲϬϰ͛ hŶĂďůĞƚŽ ĐůŽƐĞƚŽƉs͘ ^ŝǌĞ tƚ 'ƌĂĚĞ ŽŶŶ / dŽƉ ƚŵ ϮϬΗ ^ƵƌĨ ϲϯϯ͛ ϭϯͲϯͬϴ͟ ϲϭ :Ͳϱϱ Ƶƚƚ ϭϮ͘ϱϭϱ ϰϰ͘ϴϬΖ Ϯ͕ϱϯϭΖ ϵͲϱͬϴ͟ ϰϬ EͲϴϬ Ƶƚƚ ϴ͘ϴϯϱ ϰϮ͘ϴϴΖ ϰ͕ϳϱϰ͛ ϵͲϱͬϴ͟ ϰϯ͘ϱ EͲϴϬ Ƶƚƚ ϴ͘ϳϱϱ ϰ͕ϳϱϰ͛ ϱ͕ϳϮϭ͛ ϳ͟ Ϯϵ EͲϴϬ Ƶƚƚ ϲ͘ϭϴϰ ϰϭ͘ϰϳΖ ϭϭ͕ϬϰϰΖ ϱΗ ϭϴη >ͲϴϬ WͲϭϭϬ ϰ͘ϮϳϲΗ ϯϵ͘ϱϮΖ цϵ͕ϳϱϬΖ ϰͲϭͬϮΗ ϭϮ͘ϳϱͬ ϭϯ͘ϳϬ >ͲϴϬͬ WŽůǇĐŽƌĞ ϴƌŶĚh ϯ͘ϰϬΗ цϵ͕ϴϭϱΖ ϵ͕ϴϲϯΖ :t>Zzd/> EŽ͘ĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ / K ϭ ϯϵ͘ϱϮΖ ϯϵ͘ϱϮΖ ϰ͘ϬϬΗ Ϯ цϵ͕ϳϬϬΖ цϴ͕ϴϳϳΖ ϯ цϵ͕ϳϮϱΖ цϴ͕ϵϬϭΖ ϰ͘ϱϬΗ ϰ цϵ͕ϳϱϬΖ цϴ͕ϵϮϱΖ ϱ͘ϬϬΗ ϱ ϵ͕ϴϯϵΖ ϵ͕ϬϬϵΖ ϰ͘ϬϬΗ ϱ͘ϴϵΗ ϲ ϵ͕ϴϲϰΖ ϵ͕ϬϯϯΖ ϯ͘ϵϵϱΗ ϱ͘ϬϬΗ ŽŶĞ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ ŵƚ ^W& ĂƚĞ ^ƚĂƚƵƐ 'Ͳϭ ϵ͕ϴϲϵΖ ϵ͕ϴϴϯΖ ϵ͕ϬϯϲΖ ϴ͕ϮϰϱΖ ϭϲ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ 'ͲϮ ϵ͕ϵϭϮΖ ϵ͕ϵϮϲΖ ϵ͕ϬϳϵΖ ϴ͕ϮϴϳΖ ϭϰ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ 'ͲϮ ϵ͕ϵϭϮΖ ϵ͕ϵϮϲΖ ϵ͕ϬϳϵΖ ϴ͕ϮϴϳΖ ϭϰ ϲ ϱͬϯϭͬϮϬϬϬ KƉĞŶ 'ͲϮ ϵ͕ϵϯϮΖ ϵ͕ϵϰϲΖ ϵ͕ϬϵϴΖ ϴ͕ϯϬϱΖ ϭϰ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ 'ͲϮ ϵ͕ϵϯϮΖ ϵ͕ϵϰϲΖ ϵ͕ϬϵϴΖ ϴ͕ϯϬϱΖ ϭϰ ϲ ϱͬϯϭͬϮϬϬϬ KƉĞŶ 'Ͳϯ ϵ͕ϵϴϮΖ ϭϬ͕ϬϬϰΖ ϵ͕ϭϰϲΖ ϴ͕ϯϱϭΖ ϮϮ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ 'Ͳϯ ϵ͕ϵϴϮΖ ϭϬ͕ϬϬϰΖ ϵ͕ϭϰϲΖ ϴ͕ϯϱϭΖ ϮϮ ϲ ϱͬϯϭͬϮϬϬϬ KƉĞŶ 'Ͳϰ ϭϬ͕ϬϭϴΖ ϭϬ͕ϬϱϲΖ ϵ͕ϭϴϬΖ ϴ͕ϯϴϯΖ ϯϴ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ 'Ͳϰ ϭϬ͕ϬϭϴΖ ϭϬ͕ϬϱϲΖ ϵ͕ϭϴϬΖ ϴ͕ϯϴϯΖ ϯϴ ϲ ϱͬϯϭͬϮϬϬϬ KƉĞŶ 'Ͳϱ ϭϬ͕ϭϱϳΖ ϭϬ͕ϭϳϰΖ ϵ͕ϯϭϯΖ ϴ͕ϱϭϭΖ ϭϳ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ 'Ͳϱ ϭϬ͕ϭϵϬΖ ϭϬ͕ϮϬϳΖ ϵ͕ϯϰϱΖ ϴ͕ϱϰϭΖ ϭϳ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ 'Ͳϳ ϭϬ͕ϯϬϮΖ ϭϬ͕ϯϮϬΖ ϵ͕ϰϱϯΖ ϴ͕ϲϰϰΖ ϭϴ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ ͲϬ ϭϬ͕ϯϬϬΖ ϭϬ͕ϯϮϬΖ ϵ͕ϰϱϭΖ ϴ͕ϲϰϮΖ ϮϬ ϮϮ ϱͬϯϭͬϮϬϬϬ KƉĞŶ ,<Ͳϭ ϭϬ͕ϯϳϬΖ ϭϬ͕ϰϭϬΖ ϵ͕ϱϭϵΖ ϴ͕ϳϬϳΖ ϰϬ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ Ͳϭ ϭϬ͕ϯϳϬΖ ϭϬ͕ϰϭϬΖ ϵ͕ϱϭϵΖ ϴ͕ϳϬϳΖ ϰϬ ϭϬ ϱͬϯϭͬϮϬϬϬ KƉĞŶ ,<ͲϮ ϭϬ͕ϰϮϴΖ ϭϬ͕ϱϮϬΖ ϵ͕ϱϳϱΖ ϴ͕ϳϲϬΖ ϵϮ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ ͲϮ ϭϬ͕ϰϯϱΖ ϭϬ͕ϰϳϬΖ ϵ͕ϱϴϮΖ ϴ͕ϳϲϲΖ ϯϱ ϰΘϴ ϰͬϭϲͬϭϵϴϳ KƉĞŶ Ͳϯ ϭϬ͕ϱϬϬΖ ϭϬ͕ϱϮϬΖ ϵ͕ϲϰϱΖ ϴ͕ϴϮϲΖ ϮϬ ϵ ϭͬϵͬϭϵϴϱ KƉĞŶ ,<Ͳϯ ϭϬ͕ϱϱϬΖ ϭϬ͕ϱϲϱΖ ϵ͕ϲϵϯΖ ϴ͕ϴϳϭΖ ϭϱ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ Ͳϯ ϭϬ͕ϱϱϬΖ ϭϬ͕ϱϲϱΖ ϵ͕ϲϵϯΖ ϴ͕ϴϳϭΖ ϭϱ ϰ ϭͬϵͬϭϵϴϱ KƉĞŶ ,<Ͳϯ ϭϬ͕ϱϴϬΖ ϭϬ͕ϲϯϬΖ ϵ͕ϳϮϮΖ ϴ͕ϴϵϴΖ ϱϬ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ Ͳϯ ϭϬ͕ϱϴϱΖ ϭϬ͕ϲϯϬΖ ϵ͕ϳϮϳΖ ϴ͕ϵϬϯΖ ϰϱ ϰ ϭͬϵͬϭϵϴϱ KƉĞŶ ,<Ͳϰ ϭϬ͕ϲϰϮΖ ϭϬ͕ϲϵϬΖ ϵ͕ϳϴϯΖ ϴ͕ϵϱϲΖ ϰϴ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ Ͳϰ ϭϬ͕ϲϰϮΖ ϭϬ͕ϲϵϬΖ ϵ͕ϳϴϯΖ ϴ͕ϵϱϲΖ ϰϴ ϰ ϭͬϵͬϭϵϴϱ KƉĞŶ Ͳϱ ϭϬ͕ϳϮϱΖ ϭϬ͕ϴϬϬΖ ϵ͕ϴϲϯΖ ϵ͕ϬϯϮΖ ϳϱ ϰ ϰͬϭϲͬϭϵϴϳ KƉĞŶ ,<Ͳϱ ϭϬ͕ϳϮϱΖ ϭϬ͕ϴϱϭΖ ϵ͕ϴϲϯΖ ϵ͕ϬϯϭΖ ϭϮϱ ϱ ϭϮͬϳͬϮϬϭϯ KƉĞŶ Ͳϱ ϭϬ͕ϴϭϬΖ ϭϬ͕ϴϱϬΖ ϵ͕ϵϰϲΖ ϵ͕ϭϭϭΖ ϰϬ ϰ ϰͬϭϲͬϭϵϴϳ KƉĞŶ ^/E'd/> hƉĚĂƚĞĚďǇ͗<'KϲͬϮϵͬϮϮ /ƚĞŵ ,ĂŶŐĞƌ ϯϲͲϱϯ͘ϱηWĞƌŵĂŶĞŶƚ,ǇĚƌĂƵůŝĐ/ƐŽůĂƚŝŽŶ WĂĐŬĞƌ ͚y͛EŝƉƉůĞ tŝƌĞůŝŶĞŶƚƌǇ'ƵŝĚĞ dƵďŝŶŐĞƚĂŝů EŝĐŬĞůŽĂƚĞĚ,ǇĚƐĞƚWĞƌŵĂŶĞŶƚWĂĐŬĞƌ tŝƌĞůŝŶĞŶƚƌǇ'ƵŝĚĞ WĞƌĨŽƌĂƚŝŽŶĞƚĂŝů WZKWK^ DĐƌƚŚƵƌZŝǀĞƌ&ŝĞůĚ͕dh tĞůů͗ͲϬϵZ ŽŵƉůĞƚĞĚ͗&ƵƚƵƌĞ 3%7' ¶ 7' ¶ 0$;+2/($1*/( q 5.%WR7%*+HDG ¶ Ͳϯ ,<Ͳϯ ͲϮ Ͳϰ Ͳϭ ͲϬ Ͳϱ 'ͲϮ 'Ͳϯ 'Ͳϰ 'Ͳϭ ,<Ͳϭ ,<ͲϮ ,<Ͳϰ ,<Ͳϱ ; ^>/<>/Eͬ&/^,ͬ&/>>/E&KZDd/KE͗ ͘ϮͬϮϳͬϬϬ͗ĂŬĞƌ&ͲϭWŬƌŵŝůůĞĚͬƉƵƐŚĞĚƚŽďŽƚƚŽŵĂƚϭϬ͕ϵϱϳ͛͘ ͘ϭϮͬϭϮͬϭϯ͗tĞůůĐůĞĂŶĞĚŽƵƚƚŽWdĂƚϭϬϵϬϰ͛͘ sĂƚϯ͕ϰϴϲ͛ ĂŶĚϮ͕ϲϬϰ͛ hŶĂďůĞƚŽ ĐůŽƐĞƚŽƉs͘ 'ROO\9DUGHQ3ODWIRUP '5'&XUUHQW ͲϵZ ϭϯϯͬϴyϵϱͬϴyϳy ϰϭͬϮ ĂƐŝŶŐŚĞĂĚ͕/tͲt&͕ ϭϯϱͬϴϯDyϭϯϯͬϴΖ͛ĐƐŐ ƚŚƌĚďŽƚƚŽŵ͕ǁͬ ϮͲ Ϯϭͬϭϲ ϱD&K ĂƐŝŶŐƐƉŽŽů͕/tͲt&͕ ϭϯϱͬϴϯDyϭϯϱͬϴϯD͕ ǁͬϮͲ ϮϭͬϭϲϱD&K sĂůǀĞ͕/tͲ&͕ϮϭͬϭϲϯD&͕ ,tK͕ sĂůǀĞ͕/tͲ&͕ϮϭͬϭϲϯD&͕ ,tK͕ dƵďŝŶŐŚĞĂĚ͕^Ͳϴ͕ϭϯϱͬϴϯD ǆϭϭϱD͕ǁͬϮͲ ϮϭͬϭϲϱD ^^K͕ǁͬ'ďŽƚƚŽŵ ǁͬϭͲ ϮϭͬϭϲϱDt<DͲD ǀĂůǀĞƐ dƵďŝŶŐŚĂŶŐĞƌ͕^DͲ>͕ϭϭy ϰЪhůŝĨƚĂŶĚϰЪhϴƌĚ ƐƵƐƉ͕ǁͬϰΖ͛dǇƉĞ,Ws ƉƌŽĨŝůĞ͕ϮͲ ϯͬϴ>͕ϲЬ ĞǆƚĞŶĚĞĚŶĞĐŬ͕ϭϳͲϰW, ƐƚĂŝŶůĞƐƐƐƚĞĞů sĂůǀĞ͕tŝŶŐ͕t<DͲD͕ ϯϭͬϴϱD&͕ǁͬϭϱΖ͛^ĂĨĞĐŽ ŽƉĞƌĂƚŽƌ͕&&ƚƌŝŵ &Ƶůů^ƚĂŝŶůĞƐƐ^ƚĞĞů sĂůǀĞ͕^ǁĂď͕t<DͲD͕ ϰϭͬϭϲϱD&͕,tK͕&&ƚƌŝŵ sĂůǀĞ͕DĂƐƚĞƌ͕t<DͲD͕ ϰϭͬϭϲϱD&͕,tK͕&&ƚƌŝŵ ĚĂƉƚĞƌ͕^ĞĂďŽĂƌĚ͕ϭϭϱD& yϰϭͬϭϲϱD͕ǁͬϲЬƉŽĐŬĞƚ͕ ϮͲ Ъ>ĞǆŝƚƐ͕&Ƶůů^ƚĂŝŶůĞƐƐ ^ƚĞĞů ,d͕ŽǁĞŶ͕ϰϭͬϭϲϱDy ϳΖ͛Ͳϱ^ŽǁĞŶhŶŝŽŶ &Ƶůů^ƚĂŝŶůĞƐƐ^ƚĞĞů 'ROO\9DUGHQ3ODWIRUP '5'3URSRVHG ͲϵZ ϭϯϯͬϴyϵϱͬϴyϳy ϱ ĂƐŝŶŐŚĞĂĚ͕/tͲt&͕ ϭϯϱͬϴϯDyϭϯϯͬϴΖ͛ ĐƐŐ ƚŚƌĚďŽƚƚŽŵ͕ǁͬϮͲϮϭͬϭϲ ϱD&K ĂƐŝŶŐƐƉŽŽů͕/tͲt&͕ ϭϯϱͬϴϯDyϭϯϱͬϴϯD͕ ǁͬϮͲϮϭͬϭϲϱD&K sĂůǀĞ͕/tͲ&͕ϮϭͬϭϲϯD&͕ ,tK͕ sĂůǀĞ͕/tͲ&͕ϮϭͬϭϲϯD&͕ ,tK͕ dƵďŝŶŐŚĞĂĚ͕^Ͳϴ͕ϭϯϱͬϴϯD ǆϭϭϱD͕ǁͬϮͲϮϭͬϭϲϱD ^^K͕ǁͬ'ďŽƚƚŽŵ ǁͬϭͲϮϭͬϭϲϱDt<DͲD ǀĂůǀĞƐ dƵďŝŶŐŚĂŶŐĞƌ͕^DͲ>͕ϭϭy ϱЪ>ĞĨƚŚĂŶĚĂĐŵĞůŝĨƚĂŶĚ ϱΖ͛ ƉƌĞŵŝƵŵƚŚƌĞĂĚƐƵƐƉǁͬ ϱΖ͛ dǇƉĞ,WsƉƌŽĨŝůĞ͕ϳΖ͛ ŚĂŶŐĞƌŶĞĐŬ͕ϭϳͲϰW, ƐƚĂŝŶůĞƐƐƐƚĞĞů dƌĞĞĐĂƉ͕KƚŝƐ͕ϳϭͬϭϲϱD& ϱϭͬϴďŽƌĞyϵЪKƚŝƐYƵŝĐŬ hŶŝŽŶ dƌĞĞĂƐƐǇ͕/tͲ&>^͕^ƉĞĐŝĂů͕ ϳϭͬϭϲϱD&ǆϱϭͬϴďŽƌĞ͕ ͲE>ƚƌŝŵĐůĂƐƐ 'ROO\9DUGHQ3ODWIRUP %236WDFN ^ŚĂĨĨĞƌ^> ϭϯϱͬϴϱD ϮϳͬϴͲϱ͘ϱ ǀĂƌŝĂďůĞƐ ůŝŶĚƐ Ϯ͘ϬϬΖ ZŝƐĞƌ ϭϯϱͬϴϱD&yϭϯϱͬϴϱD& ^ƉĂĐĞƌƐƉŽŽů ϭϯϱͬϴϱD&yϭϭϱD ϰ͘ϱϰΖ Ϯ͘ϴϯΖ ŚŽŬĞĂŶĚ<ŝůůǀĂůǀĞƐ ϮϭͬϭϲϱD 0XG&URVV 0()2 ϰ͘ϯϬΖ ,ǇĚƌŝů '<ϭϯϱͬϴͲϱϬϬϬ ^ϯyϮ^ϯyϮϮϬ͘ϰϬΖ ϭ͘ϯϯΖ ĂƚĐŚŵŝǆĞƌ&ůƵŝĚ 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722/386+(5±(0(5*(1&< 127,),&$7,2165,* )/225 Wallace, Chris D (CED) From: Julie Wellman - (C) <lulie.Wellman@hilcorp.com> Sent: Thursday, February 4, 2021 8:40 AM To: Wallace, Chris D (CED) Subject: Dolly Varden D-09RD (PTD 181080) Class 1 disposal well status update Hi Chris, Just to keep you in the loop on Dolly Varden D-09RD class 1 disposal well. Below is the status update we sent recently to the EPA and wanted to share with you as well. Please let me know if you have any questions. Hilcorp conducted some trouble shooting operations to determine the source of a potential tubing leak into the inner annulus which was first reported to EPA on April 23rd, 2020. The well has been shut in since April 22"d, 2020. Below is a summary of the diagnostic actions taken on D9 -RD to determine the source of the leak. This work was completed on January 19th, 2021. • A triplex pump was used to pump down the inner annulus (IA) using filtered inlet seawater for -1 hour. o Operators were unable to get a consistent leak rate because the pump was too large for the leak, i.e., they were not able to pump at a low enough rate to keep pressure under 2500 psi. • Operators attempted a pressure test as they were not able to pump at a consistent rate. o The attempted MITIA failed. A E -line (EL) unit was rigged up to D9 -RD in order to run a leak detection log. o Upon running the baseline for the leak detection log, it was determined that the tubing inner diameter (ID) was restricted due to what is assumed to be the polycore liner that has separated. The Operators reported that the spinner tool kept getting hung up on separated pieces of this liner, and when EL pulled out of hole the spinner was wrapped up in lines of this polycore liner. Based on the trouble -shooting diagnostics discussed above, we have determined that a non -rig intervention to repair D- 09RD will not be possible. A workover rig will need to be sent to location in order to replace the damaged tubing and restore D-09RD for injection operations. The D-09RD well is located on the northwest leg of the platform. Unfortunately the current workover unit that Hilcorp is utilizing (rig 404) for its Cook Inlet operations will not safely fit onto this leg of the Dolly Varden platform. Therefore, Hilcorp will need to mobilize a rig that is currently cold stacked onshore (rig 301). The maintenance and mobilization work required to bring rig 301 on-line along with the current rig/ crew schedule for 2021 will not allow Hilcorp to execute this repair work until the Spring/ Summer of 2022. Hilcorp plans to mobilize a rig and execute a workover in 2022 in order to safely repair D-09RD and bring it back on injection. Until repairs and a subsequent MITIA can be successfully conducted and witnessed by EPA, D-09RD will remain shut in. Julie Wellman Regulatory Tech — Hilcorp Alaska, LLC 0:777-85051 c:360-265-4397 Julie. Wellman(u(7hilcorpcom The information contained in this email message is confidential and maybe legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed Wallace, Chris D (DOA) From: Holly Tipton <hotipton@hilcorp.com> Sent: Wednesday, April 3, 2019 2:59 PM To: Wallace, Chris D (DOA) Subject: Dolly Varden D-09RD MIT Re -scheduled P F _ D 8/ O go Hi Chris, Per our phone conversation, the EPA has re -scheduled the witnessed MIT on the D-09RD to April 25". This test was originally scheduled for March 2111 which would have put us within the one year MIT deadline for this Class I disposal well. We will keep you updated if any scheduling happens to change. Thank you! Holly Tipton 777-8330 e STATE OF ALASKA ALS A OIL AND GAS CONSERVATION COME ,ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon 0 Repair Well 0 Plug Perforations 0 Perforate 0 Other 0 Complete Performed: Alter Casing❑ Pull Tubing: Stimulate-Frac 0 Waiver 0 Time Extension❑ Change Approved Program 0 Operat.Shutdown❑ Stimulate-Other 0 Re-enter Suspended Weill] 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 181-080 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service Ei 6.API Number: PIECES ED Anchorage,AK 99503 50-733-20131-01• Al-)? 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018729 Trading Bay Unit/D-09RD '�°v� 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): • ASA GCC McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools 11.Present Well Condition Summary: Total Depth measured . 11,060 feet Plugs measured N/A feet true vertical 10,190 feet Junk measured N/A feet Effective Depth measured ` 10,904 feet Packer measured 9,778 feet true vertical 10,038 feet true vertical 8,952 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 633' 20" 633' 633' Surface 2,530' 13-3/8" 2,530' 2,419' 3,090 psi 1,540 psi Intermediate 5,721' 9-5/8" 5,721' 5,186' 5,750 psi 3,090 psi Production 10,995' 7" 10,995' 10,127' 8,160 psi 7,020 psi Liner Perforation depth Measured depth See Schematic feet SCANNED MAY 2 72014 True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 4-1/2" 13.7#/L-80 Polycore 9,863'(MD) 9,032'(TVD) 9,839'(MD) Packers and SSSV(type,measured and true vertical depth) PKR 9,009'(TVD) SSSV:N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): RBDM . MAY 1 5 2014 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 350 Subsequent to operation: 0 0 2282 25 3415 14.Attachments: 15.Well Class after work: ` Copies of Logs and Surveys Run Exploratory❑ Development 0 Service ❑,, Stratigraphic 0 Daily Report of Well Operations X 16.Well Status after work: . Oil ❑ Gas 0 WDSPL❑ GSTOR 0 WINJ 0 WAG 0 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: 313-642 Contact Dan Marlowe Email dmarlowe(a)hilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signature �o" VI'..0 Phone (907)283-1329 Date 4/8/2014 5=,2,2-i Form 10-404 Revised 10/2012 A- Submit Original Only McArthur River Field,TBU Well: D-09RD SCHEMATIC Completed: 03/15/2014 Hileocp Alaska,LLC RKB to TBG Head =39.52' CASING DETAIL Size Wt Grade ID Top Btm 1 20 Surf 633' 13-3/8" 61 J-55 12.515 Surf 2,530' / 9-5/8" 40 N-80 8.835 Surf 4,754' L 9-5/8" 43.5 N-80 8.755 4,754' 5,721' 7" 29 N-80 6.184 Surf 10,995' Z L Tubing Detail L-80/ 4-1/2" 13.7 3.40" Surf 9,863' Polycore i G \ JEWELRY DETAIL Depth No. (MD) ID Item 1 39.52' Hanger DV at 3,486' 2 9,839' 4.000 Nickel Coated Hyd set Permanent Packer and 2,604' Unable to 3 9,853' 2.81" 'X'Nipple close top DV. Sqz w/35 sx. 4 9,864' 3.995" Wireline Entry Guide Note: Lined tubing, wireline speed normal unless running "sharp/aggressive tools" 2 MN -.»-71 Perforation Detail 3 1. x ;J Zone Top(MD) Btm(MD) Top(TVD) Amt SPF Date Status 1=21G-1 9,869' 9,883' 9,036' 16 5 12/7/2013 Open 4 0-2 9,912' 9,926' 9,079' 14 5 12/7/2013 Open G-2 9,912' 9,926' 9,079' 14 6 5/31/2000 Open G-1 0-2 9,932' 9,946' 9,098' 14 5 12/7/2013 Open G-2 G-2 9,932' 9,946' 9,098' 14 6 5/31/2000 Open - 0-3 9,982' 10,004' 9,146' 22 5 12/7/2013 Open - G-3 6-3 9,982' 10,004' 9,146' 22 6 5/31/2000 Open - G-4 G-4 10,018' 10,056' 9,180' 38 5 12/7/2013 Open G-4 10,018' 10,056' 9,180' 38 6 5/31/2000 Open G-5 10,157' 10,174' 9,313' 17 5 12/7/2013 Open B-0 G-5 10,190' 10,207' 9,345' 17 5 12/7/2013 Open - HK-1 6-5 10,302' 10,320' 9,453' 18 5 12/7/2013 Open - B-1 B-0 10,300' 10,320' 9,451' 20 22 5/31/2000 Open HK-2 HK-1 10,370' 10,410' 9,519' 40 5 12/7/2013 Open B-2 B-1 10,370' 10,410' 9,519' 40 10 5/31/2000 Open HK-2 10,428' 10,520' 9,575' 92 5 12/7/2013 Open 8-2 10,435' 10,470' 9,582' 35 4&8 4/16/1987 Open HK-3 13-3 10,500' 10,520' 9,645' 20 9 1/9/1985 Open = HK-3 10,550' 10,565' 9,693' 15 5 12/7/2013 Open B-3 = B-3 10,550' 10,565' 9,693' 15 4 1/9/1985 Open HK-4 HK-3 10,580' 10,630' 9,722' 50 5 12/7/2013 Open - B-4 B-3 10,585' 10,630' 9,727' 45 4 1/9/1985 Open - HK-5 HK-4 10,642' 10,690' 9,783' 48 5 12/7/2013 Open - B-5 13-4 10,642' 10,690' 9,783' 48 4 1/9/1985 Open 8-5 10,725' 10,800' 9,863' 75 4 4/16/1987 Open HK-5 10,725' 10,851' 9,863' 125 5 12/7/2013 Open B-5 10,810' 10,850' 9,946' 40 4 4/16/1987 Open / SLICKLINE/ FISH/ FILL INFORMATION: A. 2/27/00:Baker F-1 Pkr milled/pushed to bottom at 10,957'. PBTD= 10,904' TD= 11,060' B. 12/12/13:Well cleaned out to PBTD at 10904'. MAX. HOLE ANGLE =31° Updated by:JLL 04/07/14 Hilcorp Alaska, LLC Hi!corpAhi ka, Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-09RD 50-733-20131-01 181-080 3/9/2014 3/15/2014 03/09/14-Sunday Rigging up. 03/10/14-Monday INSTALL BPV AND CLEAN WELL HEAD.N/D PRODUCTION TREE. PULL TREE AND SET IN WELL BAY.STACK 11"X 5M RISERS&DRILLING SPOOL.INSTALL CHOKE/KILL VALVES,DBL BOP,HYDRIL AND RISER FROM HYDRIL TO RIG FLOOR. N/U SAME AND INSTALL KOOMEY LINES.FUNCTION TEST VALVES AND BOPS"OK".R/U TEST EQUIPMENT.TEST 11"X 5M BOPS AND SURFACE EQUIPMENT AS PER AOGCC AND HILCORP SPECS.250 LOW/3500 HIGH.SEE CHART FOR 5 MIN._TEST F/MAIN AND FUNCTION REMOTE.ATTEMPT TO PULL BPV&SET 2-WAY CHECK VALVE FOR BLIND RAM TEST.WELL FLOWING OUT OF TBG&CSG. MONITORED WELL WHILE M/U CIRC ASSY.SCREWED INTO HANGER&R/U CIRC EQUIP.CIRC 123 BBLS DOWN TBG THRU BPV @ 2 BPM W/95 PSI.R/D CIRC EQUIP AND MONITORED WELL(STATIC). PULLED BPV&SET 2-WAY CHECK VALVE.TESTED BLINDS AS PER AOGCC&HILCORP SPECS 250 LOW/3500 HIGH ON CHART. WITNESS OF TEST WAIVED BY JIM REGG,AOGCC.PULLED 2-WAY CHECK VALVE&M/U TO HANGER. BACKED OUT LOCKING PINS&PULLED HANGER TO FLOOR.L/D LANDING JNT&HANGER.POOH&L/D 4-1/2"BTC POLY CORE PRODUCTION TBG. 03/11/14-Tuesday __CONT POOH SLOW 4-1/2"PROD TBG AND PKR ASSY.LAYING DOWN SAME IN V-DOOR AND PLACING ON PIPE RACK. CONT'TO POOH W/4-1/2"PROD TBG&PKR ASSY.&LAYING DOWN SAME IN V-DOOR.BREAK DOWN&LAY DOWN ALL PUPS&CROSSOVERS FROM PKR ASSY.UN-BUNDLE 4-1/2"PROD TBG ON PIPE RACK.CLEANED PIPE&REPLACED PROTECTORS ON EACH JT PRIOR TO BACKLOADING ON M.V.UN-BUNDLE 4-1/2"PROD TBG ON PIPE RACK.CLEANED PIPE&REPLACED PROTECTORS ON EACH JT. PERFORMED GENERAL HOUSEKEEPING AROUND RIG/PLATFORM. HELD SAFETY MEETING JSA AND STARTED PICKING UP TRI-POINT CONPLETION PKR ASSY. 03/12/14-Wednesday SERVICE RIG AND HELD PRE JOB JSA.RIH W/TRI-POINT PACKER AND 4-1/2"EU 8RD POLY CORE TBG. 106 JTS IN HOLE @ 18:00 HRS. PRE JOB JSA&CONTINUED IN HOLE WITH 4-1/2"TBG AND PACKER(225 jts ran) Depth=7,100'. 03/13/14-Thursday Held pre job meeting and JSA. Service rig. Continue running in hole picking up and drifting 4.5",13.7#,L-80 Polycore EUE 8rd tbg,run total of 302 jts putting EOT AT 9,864'W/packer at 9,838'. Make up and land tbg hanger. Rig up slickline. RIH w/2.80 gauge,found nipple at 9,849'slm,continue in hole to 9,898'slm. Pooh,install night cap. Mix and pump 40 bbls inhibitor down back side clear lines w/10 bbls. Slick line RIH w/2.813'PX Plug to 9,851'set same. Slick line RIH w/2.813"PX prong set same at 9,851'.Rig down slick line. Attempt to set packer. Pressured up to 1150 psi started pumping thru,pumped total of 10 bbls,bleed off tbg. Rig up Slick line RIH w/2.5"SB latch prong and pooh.RIH w/3"GS TO PULL PX plug from nipple. 03/14/14-Friday Continue POOH with slickline. Redress a 2.813 PX Plug and Prong. Run in Hole with PX Plug set same and nipple.Set Prong and Nipple. POOH with slickline.Rig down lubricator.Rig up lines and pressured up tubing to 3000 PSL Pumped total of 2.5 bbls of FIW, held for 15 minutes,setting the tripoint permanent packer at 9,838'MD,bled pressure off.Rig up waterflood to 9-5/8"casing,test 7" casing by 4.5 tubing annulus to 2500 PSI for 60 minutes,pressure bled to 2375 PSI in 1HR and held,no pressure increase while monitoring the 9-5/8"x 7"annulus and 9-5/8"x 13"annulus and 4-1/2"tubing. Pressure test witnessed by telephone-EPA,Thor Cutler,results submitted to Chris Wallace with AOGCC by Dan Marlowe of Hilcorp.Rig up on 4-1/2"tubing and test to 5000 PSI,after reaching 3300 with waterflood hooked up hydraulic test pump with no pressure increase.Pressured up on 4-1/2"tubing to 5000 PSI for 30 minutes,test was good,bled off lines and rigged down pumps. Rig up slickline. Recovered Prong and PX plug.Rig down slickline. Laid down landing joint and set back pressure valve,bleed down accumulator lines and prepping to nipple down BOPs. 03/15/14-Saturday Nipple down 11"5k BOPS'&riser and set out same.Prep well head&install tree. Nipple up same. Test tree to 5K(good test)and test hanger seals and tree void to 5k for 20 minutes on chart(good test). ,P, /or T,'s THE STATE Alaska Oil and Gas k � °fl 1L1 1VKA Conservation Commission *ti GOVERNOR SEAN PARNELL 333 West Seventh Avenue O P Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Dan Marlowe 0 Operations Engineer 1— Hilcorp Alaska. LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil & Middle Kenai G Oil Pools, Trading Bay Unit D-09RD Sundry Number: 313-642 Dear Mr. Marlowe: %AWED MAY 0 9 7_014 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, orsuch 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�',U day of December, 2013. End. c7)01/4-• i �. �, . STATE OF ALASKA \V\n"1 DEC 1 7 2 013 ALASKA OIL AND GAS CONSERVATION COMMISSION ar-S iL(1°y 1 (3 APPLICATION FOR SUNDRY APPROVALS .A0 0C 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing 0 - Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ I Other. Complete 0 • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 0 181-080 • 3.Address: Stratigraphic ❑ Service 0 • 6.API Number: 3800 Centerpoint Drive,Anchorage AK,99503 50-733-20131-01 - 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? WA Will planned perforations require a spacing exception? Yes ❑ No❑ Trading Bay Unit D-09RD• 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 TVD(ft): Plugs(measured): Junk(measured): 11,060 • 10,190 • 10,904' 10,038 N/A N/A Casing Length Size MD TVD Burst Collapse - Structural - Conductor 633' 20" 633' 633' Surface 2,530' 13-3/8" 2,530' 2,419' 3,090psi 1,540psi Intermediate 5,721' 9-5/8" 5,721' 5,186' 5,750psi 3,090psi Production 10,995' 7" 10,995' 10,127' 8,160psi 7,020psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 13.55#/L-80 9,814' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Hyd Pkr&SSSV:N/A • Pkr 9,778'(MD)8,952'(TVD) 12.Attachments: Description Summary of Proposal 0 • X13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development❑ Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 1/15/2014 Oil Cl Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A WINJ 0• GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 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 Signature�_, 2744.1-'1-f--6-e___-Phone (907)283-1329 Date 12/16/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test [✓J Mechanical Integrity Test [2 Location Clearance ❑ Other: k 3000 D S z. Ed? l:s t— RBDM MAY U 9 2014 Spacing Exception Required? Yes ❑ No gi7 Subsequent Form Required: /0-`4611 6)0/67 APPROVED BY Approved by: . .{..,/,-,./.4-.— COMMISSIONER THE COMMISSION Date: 12- 2,0 _/3 yam- /L-,7.,3 n 1 r I N A L _,,,,ka ��I!`15 c4)-1 i.Z,413 000 ap R V he ig/fa Submit Form and Form 10-403(Revised 10/2012) Approved a plication Is valid for 12 months om the date of approval. Attachments in Duplicate II Well Work Prognosis Well: D-09RD Hilcorp Alaska,LLCDate: 12/16/2013 Well Name: D-09RD _ API Number: 50-733-20131-01 Current Status: SI Injector Leg: Leg#A-2 (NW corner) Estimated Start Date: January 15, 2014 Rig: HAK#1 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 181-080 First Call Engineer: Dan Marlowe _ Office:907-283-1329 Cell: 907-398-9904 Second Call Engineer: Ted Kramer Office:907-777-8420 Cell: 985-867-0665 AFE Number: Budgeted Cost: The last injection for D-09RD consisted of 1,800bbls at 3,400psi on 10/12/12. When shut-in the pressure falls off rapidly and fluid level falls to a depth of about 300'. The estimated pressures are based on the fluid level that was tagged on 3/28/13, which is consistent with previous shut-in pressures and observations of surrounding wells. Current BHP: ^'4,000 psi @ 9,500'TVD/10,400'MD .42 psi/ft,(8.1 ppg)at mid perf of GZ&Hemlock Max.Expected BHP: —4,000 psi @ 9,500'TVD .42 psi/ft.(8.1 ppg)Recomplete in same zones Max.Anticipated SP: —0 psi Using 0.435psi/ft SW gradient to surface w/pumps off Brief Well Summary This well is a dual permitted injection well with AOGCC and EPA. D-09RD was a good G-zone and Hemlock injector until tubing integrity failed on 10/21/12. After attempts to find and patch the hole were unsuccessful, it was determined the well needs to be repaired with a rig. This injector is one of three (D-15RD2, D-45, D-09RD) injectors that support Dolly and Grayling offtake from the southern flank of the main feature. The objective of this rig workover is to pull the existing tubing and injection packer, re-perforate the G-zone and Hemlock, and run a new 4-1/2" injection completion with plastic-lined tubing. Once D-09RD tubing integrity is restored the well is expected to inject about 6,000 bwpd supporting offtake from much of the southern nose. Notes Regarding Current Wellbore Condition • Well was worked over in November/December 2013 but due to manufacturing issues with the lined 4/ pipe the project wasn't completed.Currently the production tubing is hung in the well but t_he packer has not been set. —_-- Procedure: 1. Skid rig and RU HAK Rig 1 over D-09RD well slot. 2. Plumb filtered inlet water(FIW) lines to circulate down the annulus and up the tubing, or vice versa, through the tree, make sure there is no gas in the tubing or annulus. 3. Notify EPA&AOGCC 48hrs before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines to 250psi LOW and 3,000psi HIGH. 4. PU landing joint and make-up to tubing hanger. Well Work Prognosis Well: D-09RD Hilcorp Alaska,LLC Date: 12/16/2013 5. POOH, LD tubing. 6. PU injection packer and 4-1/2" plastic lined tubing. RIH, set packer within 100' of top perf±9,667'. 7. Land the tubing hanger, and pressure up backside to confirm packer is set. Hold 2,500psi for 30 minutes and chart test. Use the EPA MIT form and 10-426 form to capture this information. 8. Set BPV. ND BOPE and NU tree,test same. �^ 9. Conduct EPA witnessed MITIA 10. Place well on injection. Well is expected to take between 5,000 and 7,000 bwpd at full header pressure of 4,500 psi?. 11. After 2 weeks of stable injection,schedule an Initial MIT with EPA&AOGCC. Attachments: • As-built Well Schematic • Proposed Well Schematic • Current Wellhead Diagram • Proposed Wellhead Diagram • BOP Drawing McArthur River Field,TBU II Well: D-09RD SCHEMATIC Completed: 12/12/13 II ilrorp Ala.ka.L1.1: RKB to TBG Head=39.52' CASING DETAIL Size Wt Grade Conn ID Top Btm 4,4 20 Surf 633' 13-3/8" 61 J-55 Butt 12.515 Surf 2,530' 9-5/8" 40 N-80 Butt 8.835 Surf 4,754' Z. '' 9-5/8" 43.5 N-80 Butt 8.755 4,754' 5,721' r 7" 29 N-80 Butt. 6.184 Surf 10,995' l L 0 Tubing Detail i tk.` toy. 4-1/2" 13.55 L-80,PL BTC 3.40" Surf 9,814' )1� 4i., �i 11 JEWELRY DETAIL 4 . // 4: :No. (DMpDt�h ID Item Z 4; 1 39.52' Hanger DV at 3,486' 2 9,778' 4 Packer(un-set) and 2,604' - , Unable to 3 9,804' 3.313 'X'Nipple close top DV. PP Sqz w/35 sx. 4 9,815' 3.937 Wireline Entry Guide Cr 'lk.) SG f Perforation Detail 2 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date Status G-1 9,869' 9,883' 9,036' 9,051' 16 5 12/7/2013 Open 0-2 9,912' 9,926' 9,079' 9,092' 14 5 12/7/2013 Open 3 0-2 9,912' 9,926' 9,079' 9,092' 14 6 5/31/2000 Open 0-2 9,932' 9,946' 9,098' 9,111' 14 5 12/7/2013 Open G-1 0-2 9,932' 9,946' 9,098' 9,111' 14 6 5/31/2000 Open G-2 G-3 9,982' 10,004' 9,146' 9,167' 22 5 12/7/2013 Open G-3 9,982' 10,004' 9,146' 9,167' 22 6 5/31/2000 Open -= G-3 G-4 10,018' 10,056' 9,180' 9,216' 38 5 12/7/2013 Open - G-4 G-4 10,018' 10,056' 9,180' 9,216' 38 6 5/31/2000 Open G-5 10,157' 10,174' 9,313' 9,330' 17 5 12/7/2013 Open G-5 10,190' 10,207' 9,345' 9,361' 17 5 12/7/2013 Open B-0 G-5 10,302' 10,320' 9,453' 9,470' 18 5 12/7/2013 Open HK-1 B-0 10,300' 10,320' 9,451' 9,470' 20 22 5/31/2000 Open B-1 HK-1 10,370' 10,410' 9,519' 9,558' 40 5 12/7/2013 Open HK-2 B-1 10,370' 10,410' 9,519' 9,558' 40 10 5/31/2000 Open HK-2 10,428' 10,520' 9,575' 9,664' 92 5 12/7/2013 Open - B-2 B-2 10,435' 10,470' 9,582' 9,616' 35 4&8 4/16/1987 Open B-3 10,500' 10,520' 9,645' 9,664' 20 9 1/9/1985 Open HK-3 HK-3 10,550' 10,565' 9,693' 9,708' 15 5 12/7/2013 Open - B-3 10,550' 10,565' 9,693' 9,708' 15 4 1/9/1985 Open B-3 HK-3 10,580' 10,630' 9,722' 9,771' 50 5 12/7/2013 Open B-3 10,585' 10,630' 9,727' 9,771' 45 4 1/9/1985 Open HK-4 HK-4 10,642' 10,690' 9,783' 9,829' 48 5 12/7/2013 Open - B-4 B-4 10,642' 10,690' 9,783' 9,829' 48 4 1/9/1985 Open 1-1K-5 B-5 10,725' 10,800' 9,863' 9,936' 75 4 4/16/1987 Open - B-5 HK-S 10,725' 10,851' 9,863' 9,985' 125 5 12/7/2013 Open B-5 10,810' 10,850' 9,946' 9,985' 40 4 4/16/1987 Open SLICKLINE/FISH/FILL INFORMATION: A. 2/27/00:Baker F-1 Pkr milled/pushed to bottom at 10,957'. B. 12/12/13:Well cleaned out to PBTD at 10904'. / PBTD= 10,904' TD=11,060' MAX. HOLE ANGLE =31° Revised By:JLL 12/16/13 1 .. M . s McArthur River Field,TBU II Well: D-09RD PROPOSED FUTURE Itileorp Alaska,1,1.1: RKB to TBG Head=39.52' CASING DETAIL Size Wt Grade Conn ID Top Btm 1 20 Surf 633' 13-3/8" 611-55 Butt 12.515 Surf 2,530' / 9-5/8" 40 N-80 Butt 8.835 Surf 4,754' L 9-5/8" 43.5 N-80 Butt 8.755 4,754' 5,721' 7" 29 N-80 Butt. 6.184 Surf 10,995' Tubing Detail r4-1/2" 13.55 L-80,PL BTC 3.40" Surf L. JEWELRY DETAIL L. No. Depth Depth ID Item (MD) (TVD) 1 39.52' 39.52' Hanger iiDV at 3,486' 2 ±9,800' 9is 4.000 Tripoint Stim-Top Production Packer and 2,604' Unable to 3 ±9,825' ±8,996' 3.313 X'Nipple close top DV. Sqz w/35 sx. 4 ±9,834' 4.000 Wireline Entry Guide X Perforation Detail 2 l VIIIIE Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date Status 3 0-1 9,869' 9,883' 9,036' 9,051' 16 5 12/7/2013 Open 4 0-2 9,912' 9,926' 9,079' 9,092' 14 5 12/7/2013 Open 0-2 9,912' 9,926' 9,079' 9,092' 14 6 5/31/2000 Open 0-2 9,932' 9,946' 9,098' 9,111' 14 5 12/7/2013 Open EE G-1 G-2 9,932' 9,946' 9,098' 9,111' 14 6 5/31/2000 Open G-2 G-3 9,982' 10,004' 9,146' 9,167' 22 5 12/7/2013 Open G-3 9,982' 10,004' 9,146' 9,167' 22 6 5/31/2000 Open - G-3 0-4 10,018' 10,056' 9,180' 9,216' 38 5 12/7/2013 Open G 4 G-4 10,018' 10,056' 9,180' 9,216' 38 6 5/31/2000 Open 0-5 10,157' 10,174' 9,313' 9,330' 17 5 12/7/2013 Open 0-5 10,190' 10,207' 9,345' 9,361' 17 5 12/7/2013 Open B-0 0-5 10,302' 10,320' 9,453' 9,470' 18 5 12/7/2013 Open - HK-1 B-0 10,300' 10,320' 9,451' 9,470' 20 22 5/31/2000 Open - B-1 HK-1 10,370' 10,410' 9,519' 9,558' 40 5 12/7/2013 Open El- HK-2 B-1 10,370' 10,410' 9,519' 9,558' 40 10 5/31/2000 Open HK-2 10,428' 10,520' 9,575' 9,664' 92 5 12/7/2013 Open B-2 B-2 10,435' 10,470' 9,582' 9,616' 35 4&8 4/16/1987 Open B-3 10,500' 10,520' 9,645' 9,664' 20 9 1/9/1985 Open HK-3 HK-3 10,550' 10,565' 9,693' 9,708' 15 5 12/7/2013 Open 8-3 10,550' 10,565' 9,693' 9,708' 15 4 1/9/1985 Open - B-3 HK-3 10,580' 10,630' 9,722' 9,771' 50 5 12/7/2013 Open B-3 10,585' 10,630' 9,727' 9,771' 45 4 1/9/1985 Open - HK-4 HK-4 10,642' 10,690' 9,783' 9,829' 48 5 12/7/2013 Open - B-4 8-4 10,642' 10,690' 9,783' 9,829' 48 4 1/9/1985 Open - HK-5 8-5 10,725' 10,800' 9,863' 9,936' 75 4 4/16/1987 Open B-5 HK-5 10,725' 10,851' 9,863' 9,985' 125 5 12/7/2013 Open 8-5 10,810' 10,850' 9,946' 9,985' 40 4 4/16/1987 Open SLICKLINE/FISH/FILL INFORMATION: A. 2/27/00:Baker F-1 Pkr milled/pushed to bottom at 10,957'. B. 12/12/13:Well cleaned out to PBTD at 10904'. 2 .1 PBTD= 10,904' TD=11,060' MAX. HOLE ANGLE =31° Revised By:1LL 12/16/13 „ •ll Dolly Varden Platform D-9RD Current 12/16/13 Flllearp Atonic LU Tubing hanger,SME-CL,11 X D-9RD 4''A EUE lift and 4''A TC-2 13 3/8 X 9 5/8 X 7 X susp,w/4' Type H BPV 41/2 profile,2-3/8 CCL,6'''A extended neck,17-4PH stainless steel BHTA,Bowen,4 1/16 5M X 7"-5 SA Bowen Union Full Stainless Steel II RI W. fr Valve,Swab,WKM-M, 41/16 5M FE,HWO,FF trim (IS ° Valve,Wing,WKM-M, ”'IMO"' 3 1/8 SM FE,w/15"Safeco / -I—---- 7. operator,FF trim ' Full Stainless Steel 0 .B 1 OO te la Valve,Master,WKM-M, 4 1/16 5M FE,HWO,FF trim 6 tea' 0 poo Ftl Adapter,Seaboard,11 5M FE X 41/16 5M,w/6'/.pocket, =p � s-'CCL exits,Full Stainless _ iP 41 ,aable r ■= r 2i Steel Tubing head,S-8,13 5/8 3Mrui II mu yip .11 5M,w/2-2 1/16 5M SSO,w/BG bottom a � w/1-2 1/16 5M WKM-M 0 In `I�O CO O�� a-1.1 valves ° t - NA ' . 1•1 ,� , 36.O/r5,. Casing spool,CIW-WF, illi I. 13 5/8 3M X 13 5/8 3M, 161 I I UI Valve,CIW-F,2 1/16 3M FE, w/2-2 1/16 SM EFO _ -f�` 0HWO,AA it Iw •IIIlI t '�„�'1II)II fru-i- 111 _ II, 11 1 t Casing head,CIW-WF, W ;i: 13 5/8 3M X 13 3/8"csg I 1 I Valve,CIW-F,2 1/16 3M FE, thrd bottom,w/2-2 1/16 I I 1 HWO,AA 2M EFO - - 1IIII, IpuIII(i! IIII1., I 111 RECEIVED ' STATE OF ALASKA AL _:A OIL AND GAS CONSERVATION COW-_SION DEC k 7 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon❑ Repair Well El Plug Perforations ❑ Perforate 0 Other I'J Complete Performed: Alter Casing❑ Pull Tubing El Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program❑ Operat.Shutdown❑ Stimulate-Other El Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development❑ Exploratory❑ 181-080 ' 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service El 6.API Number: Anchorage,AK 99503 50-733-20131-01 ' 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018729 ' Trading Bay Unit/D-09RD ' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools 11.Present Well Condition Summary: Total Depth measured 11,060 feet Plugs measured N/A feet true vertical 10,190 feet Junk measured N/A feet Effective Depth measured 10,904 feet Packer measured 9,778 feet true vertical 10,038 feet true vertical 8,952 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 633' 20" 633' 633' Surface 2,530' 13-3/8" 2,530' 2,419' 3,090 psi 1,540 psi Intermediate 5,721' 9-5/8" 5,721' 5,186' 5,750 psi 3,090 psi Production 10,995' 7" 10,995' 10,127' 8,160 psi 7,020 psi Liner Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet SCANNED Tubing(size,grade,measured and true vertical depth) 4-1/2" 13.55#/L-80 9,814'(MD) 8,986'(ND) 9,778'(MD) Packers and SSSV(type,measured and true vertical depth) PKR 8,952'(ND) SSSV:N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 350 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑ Service IE ' Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ ' GSTOR ❑ WINJ El . 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: 313-369 Contact Dan Marlowe Email dmarlowe( hilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signature G-�/.,t,� Phone (907)283-1329 Date 12/16/2013 y RBDMS DEC F: 20 Form 10-404 Revised 10/2012 oz- 3 yI l Submit Original Only McArthur River Field,TBU II Well: D-09RD SCHEMATIC Completed: 12/12/13 Ililcerp Alaska,I,LC RKB to TBG Head=39.52' CASING DETAIL Size Wt Grade Conn ID Top Btm 20 Surf 633' 13-3/8" 61 J-55 Butt 12.515 2,530'- - 9-5/8" 40 N-80 Butt 8.835 Surf 4,754' - i 9-5/8" 43.5 N-80 Butt 8.755 Surf 4,754' 5,721' C29 N-80 Butt. 6.184 Surf 10,995' r-1.-- Tubing Detail l a'5 4-1/2" I 13.55 I L-80,PL I BTC I 3.40" I Surf I 9,814' [ I1 JEWELRY DETAIL 4( t 7 t~� ri,a No. (DMpDjh ID Item Z. 1 ° 1 39.52' Hanger DV at 3,486' 2 9,778' 4 Packer(un-set) and 2,604' - Unable to 3 9,804' 3.313 'X'Nipple close top DV. Sqz w/35 sx. 4 9,815' 3.937 Wireline Entry --iGuide 1Lt f',~ r ,, / s✓ N o D1 Perforation Detail 2 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date Status G-1 9,869' 9,883' 9,036' 9,051' 16 5 12/7/2013 Open G-2 _ 9,912' 9,926' 9,079' 9,092' 14 5 12/7/2013 Open 3 G-2 9,912' 9,926' 9,079' 9,092' 14 6 5/31/2000_ Open _ G-2 9,932' 9,946' 9,098' _ 9,111' 14 5 12/7/2013 Open G-1 0-2 9,932' 9,946' 9,098' 9,111' 14 6 5/31/2000 Open G-2 G-3 9,982' 10,004' 9,146' 9,167' 22 5 12/7/2013 Open 0-3 9,982' 10,004' 9,146' 9,167' 22 6 5/31/2000 Open - G-3 0-4 10,018' 10,056' 9,180' 9,216' 38 _ 5 12/7/2013 Open - G-4 0-4 10,018' 10,056' 9,180' 9,216' 38 6 5/31/2000 Open 0-5 10,157' 10,174' 9,313' 9,330' 17 5 12/7/2013 Open 0-5 10,190' 10,207' 9,345' 9,361' 17 5 12/7/2013 Open B-0 0-5 10,302' 10,320' 9,453' 9,470' 18 5 12/7/2013 Open - HK-1 8-0 10,300' 10,320' 9,451' 9,470' 20 22 5/31/2000 Open B-1 HK-1 10,370' 10,410' 9,519' 9,558' 40 _ 5 12/7/2013 Open - HK-2 B-1 10,370' 10,410' 9,519' 9,558' 40 _ 10 5/31/2000 Open HK-2 10,428' 10,520' 9,575' 9,664' 92 _ 5 12/7/2013 Open B-2 B-2 10,435' 10,470' 9,582' 9,616' 35 _ 4&8 4/16/1987 Open 8-3 10,500' 10,520' 9,645' 9,664' 20 9 1/9/1985 Open - HK-3 HK-3 10,550' 10,565' 9,693' 9,708' 15 _ 5 12/7/2013 Open 8-3 10,550' 10,565' 9,693' 9,708' 15 4 1/9/1985 Open B-3 HK-3 10,580' 10,630' 9,722' 9,771' 50 5 12/7/2013 Open - B-3 10,585' 10,630' 9,727' 9,771' 45 4 1/9/1985 _ Open HK-4 HK-4 10,642' 10,690' 9,783' 9,829' 48 5 12/7/2013 Open - B-4 B-4 10,642' 10,690' 9,783' 9,829' 48 4 1/9/1985 Open - HK-5 B-5 10,725' 10,800' 9,863' 9,936' 75 - 4 4/16/1987 Open B-5 HK-5 10,725' 10,851' 9,863' 9,985' 125 5 12/7/2013 Open B-5 10,810' 10,850' 9,946' 9,985' 40 4 4/16/1987 - Open SLICKLINE/FISH/FILL INFORMATION: A. 2/27/00:Baker F-1 Pkr milled/pushed to bottom at 10,957'. B. 12/12/13:Well cleaned out to PBTD at 10904'. PBTD= 10,904' TD=11,060' MAX. HOLE ANGLE =31° Revised By:JLL 12/16/13 Hilcorp Alaska, LLC Ilit( I ) ,laaska.,.L4: Well Operations Summary Well Name API Number _Well Permit Number Start Date End Date D-09RD 50-733-20131-01 181-080 11./11/2013 12/12/2013 Daily Operations: 11/11/13-Monday Rigging up. 11/12/13-Tuesday Rigging up. 11/13/13-Wednesday Continue to rig up/re-configure rig.Improve/enhance winterization.Prepare to connect to well. 11/14/13-Thursday Prepare rig to tie onto well.Set back pressure valve.Begin nippling down tree.Nipple up BOP.Prepare to test BOP's. 11/15/13-Friday Prepare to test BOP. Pressure test BOP's 250 psi low/3500 psi high. Witness of test waived by Jim Regg,AOGCC.Rig down test equip.Rig up wireline. 11/16/13-Saturday Rig up/RIH with wireline and tag obstruction at 1,521'. POOH.RIH with cutter.Cut pipe at 1,510'.POOH with cutter.Rig down wireline.Rig up to pull hanger.Cut flared out.Pull hanger free with 21k overpull.Hanger at surface.Appears in good condition.Lay down hanger and 46 joints of 3-1/2"Eu 8rd tubing.Tubing in fair condition.Prep for running fishing BHA and 3-1/2"PH6 workstring. Pick up BHA and RIH on 3-1/2"PH-6 workstring picking up singles off the deck.Tag fish at 1,515'.Rig up power swivel.Dress off fish. 11/17/13-Sunday RIH w/dress mill and overshot.Dress off fish.Lay down power swivel.POOH racking back 3-1/2"PH-6 workstring.Lay down BHA.PU BHA-Outside cutter and washpipe assembly.RIH w/3-1/2"PH-6 workstring-picking up singles.Rig up power swivel.Tagged top of fish at 1,510'placing cutter at 1,648'.With 3k down and 40 rpm cut 3-1/2"tubing at 1,631'.P/U string.Positive indication tubing cut.Lay down 2 jts of 3-1/2" PH-6.Rig down power swivel.POOH racking back 3-1/2"PH-6 workstring.Racking back drill collars. 11/18/13-Monday Service rig.POOH.Lay down fish.Make up BHA w/overshot.Pick up drill pipe and RIH.Rig up power swivel.Tag fish at 1,628'.(WL cut at 1,631').Set 5k dn.Pull 10k over.Set pipe in neutral in the slips.Rig down power swivel.Release from fish.Space out string.Re- engage fish.Set string in neutral in slips.Rig up e-line.RIH w/2.50"drift.Tag at 2,376'.POOH. RIH w/2.37"OD chemical cutter. Worked tool down to 2,470'.Fired tool.Hole began to U-tube. POOH w/e-line.Hole stabilized.Rig down a-line.Attempted to POOH. Unsuccessful. Pipe not cut completely.Work pipe up and down staging the overpull up to 40k.No success.Rig up power swivel. Attempt to break off tubing.Max torque 2500 ft/lbs.unable to work pipe free.Rig down power swivel.Rig wireline back up.RIH with radial torch-2.00"OD.Cut tubing at 2,468'.POOH w/e-line.Rig down e-line.Pick up string.Pick up+/-10'.Pipe free. 11/19/13-Tuesday Rig down wireline.Pipe free.POOH.Rig up to pick up and run outside cutter and washpipe.Pick up BHA/washpipe and RIH.Rig up power swivel.RIH w/power swivel.Engage fish @ 2,458'DPM.Slack off 2k,pick up 3k to open cutter.Begin rotating 60 rpm w/900 ft lbs of torque w/5k overpull.2,836'cutting depth.No progress.Release cutter.Reposition and reset cutter.Begin rotating. Hilcorp Alaska, LLC uiIcor,,.Ua.ka.h.LC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-09RD 50-733-20131-01 181-080 13./11/2013 12/12/2013 Daily Operations: 11/20/13-Wednesday Continue rotating cutter.Tubing cut at 2,836'.Weight gain of+/-4k.Rig down power swivel. POOH with 3-1/2"PH-6 workstring and fish.Wash pipe at surface.Lay down 3-1/2"tubing fish-368'.Rack back washpipe.Prepare rig floor for next BHA.Shut down due to high winds.Service rig equipment. 11/21/13-Thursday RIH w/3-1/2"PH-6.Rig up and break circulation down workstring.Pump 5 bbls getting returns.Shut down pump.Shut in choke. Pressure up hole to 250 psi.Bled off psi.Slack off and tag top of fish at 2,839'DPM.Spaced out string.Rig up e-line.RIH w/2-1/8"OD gauge on e-line.Run down to 9,850'.POOH.RIH with 2"radial cutter.Cut tubing at 9,680'.POOH.Rig down sheves.Pick up on workstring.Pick up to 100K.Jars went off.Pick up to 110K.Pick up to 130K.Slack off to 30K.Pick up to 100K.Jars went off.Pick up to 130K.Slack off to 30K.Pick up to 110K.Jars went off.Pick up to 130K.Workstring not released.Slack off to neutral.Rig up to circulate. Pumped 5 bbls.No returns.String pressured up 10+/-450 psi pressure bled off.Pumped into formation.Opened bleed off in pump room,fluid continued to flow.Recovered 10+bbls of fluid.Monitored well to insure well was static. 11/22/13-Friday Pick up to 114K hookload.3-1/2"PH6-39k/Block-9k/3 1/2 8rd tubing-46 k/20k overpull.RIH w/wireline.Cut pipe at 9,632'.Good indication in wireline unit.POOH w/wireline.Pick up on string.Free travel at 95k hookload.Lay down single and space out pups. Circulate hole 1-1/2 times.2.5 bpm at 520 psi.POOH,Rack back drill collars/BHA.POOH w/3-1/2"tubing.210 joints out. 11/23/13-Saturday 210 joints of 3-1/2"8rd laid down.6 remain to be pulled.Pull remaining 3-1/2"8rd.JSA for slipping and cutting.Slip and cut drill line. Rig up BOP test equipment.Emergency drill.Activate ESD sytstem.All systems working.Continue to rig up for BOP test.Make up test plug to landing joint.RIH.Land plug.Begin pressure test.Testing blind rams.Test BOP 250 psi low/3,000 psi high. Witness of test waived by Jim Regg,AOGCC.Rig down all test equipment.Prepare to RIH w/BHA to retrieve anchor seal assy. 11/24/13-Sunday BOP Test-Good test. JSA for picking up fishing BHA and RIH.RIH w/overshot,jars,dill collars and 3-1/2"PH6 workstring to retrieve anchor tubing seal assembly.Perform derrick inspection in anticipation of jarring that will be done during anchor retrieval.142 stands plus BHA-9,569'.TOF 9,632'. Pick up power swivel.Continue power swivel rig up. 11/25/13-Monday Make up power swivel.116K pu wt/96K so wt.RIH and tag fish.Fish tagged at 9,628'DPM/9,632'WLM.Engage and set grapple.Pick up to 125K.Rotate power swivel w/3k torque.Anchor released.Lay out pup and single.Monitor well for 15 min.Rig down power swivel.POOH.Rack back drill collars.Lay down fish.Anchor tubing seal assy recovered.Make up Milling BHA-5-3/4"flat bottom burning shoe,drive sub,dbl pin sub,4-1/8"mud motor,dbl pin sub,4-1/4" boot baskets x 2,5"swaco string magnet x 2,4-11/16" Dailey bumper sub,4-3/4" Dailey oil jars,2 stands 4-3/4"drill collars. RIH w/BHA.Had a difficult time getting the shoe through the wellhead.Tight spot in casing at 3,368'-3,421'.Continue to RIH.Current depth-+/-4000'. Hilcorp Alaska, LLC lliIcorp.klaska.1.,.1: Well Operations Summary Well Name API Number Well Permit Number Start Date _End Date _ D-09RD 50-733-20131-01 181-080 11/11/2013 12/12/2013 Daily Operations: 11/26/13-Tuesday RIH w/packer milling assy.Pick up wt.117K/slack off wt.95K Tag fish at 9,681'DPM/9,686'WLM.Rig up to pump downhole and mill packer.Open waterflood to pump downhole.800/900psi.Slack off 6-7K on packer.After jars close doesn't appear to be making any hole.Getting 2500-3000 ft/lbs of torque at surface.Check with waterflood.Estimate based on fluid waterflood taking back we were pumping+/-3bpm.This is on the lower end of the motors operating range.Re-align manifold to pump with rig pump and waterflood. Open waterflood to well.Begin pumping with mud pump at 3 bpm.1300 psi stand pipe pressure.Estimate 5.5 bpm.Slack off and start milling on packer.2500-3000 ft/lbs of torque at surface.Shut down pumps.Rig down surface lines.Monitor well.Annulus static.Small trickle of fluid coming out of tubing.Pull 2 stands.Stands wet.Pick up wt 119K.Rig up to circulate.Break circulation.Circulate 45 barrels.Rig down manifold and lines in preparation for POOH. 11/27/13-Wednesday POOH.Pipe pulling wet.Drill collars at surface.Rack collars.Lay down BHA.Milling shoe at surface.Indicators pins show 14"milled off.Clean rig floor,service rig,repair winterization where needed.JSA for picking up BHA.Begin picking up BHA.Pick up new 5-3/4" flat bottom burning shoe,2 ea.4-1/4"boot baskets,2 ea.5"Swaco string magnets,4-11/16" Dailey bumper jar and 4-3/4"Dailey Oil jar,2 ea.stands 4-3/4 drill collars.Rig down BHA handling equip.Rig to run 3-1/2" BHA. RIH w/3-1/2"PH6 work string. 11/28/13-Thursday N/D 13-5/8"X 11"DSA and NU 13-5/8"x 7"adapter spool.Install stripping head.PU power swivel attempt to install stripping rubber in head w/o success.Center BOP's and install stripping rubber.Break circ,with 4 BPM 670 psi,rotate and wash from 9,675'to 9,681' DPM&tag top of packer. Mill Baker SAB packer from 9,681'to 9,685'DPM @4BPM 670 psi,WOB-7=K,Torque=4 to 6k,RPM=60. Continue milling and pushing packer from 9,685'to 9,819'picking singles up from pipe rack.RD power swivel.Chase packer body from 9,819'to 10,185'picking up singles from pipe rack with 3-5k wt down.Broke circulation with 20 bbls down tbg pumping at 2 bpm with 355psi. Continued pushing pkr body from 10,185'to 10,298',attempted to work pkr body deeper w/o success with 25k set down wt. Reverse circulate 85 bbls @ 3BPM w/360 psi.RD Kelly hose,blow down lines,pull stripping rubber&install wiper plate. POOH with packer milling assy depth @ 06:00 6,732'. 11/29/13-Friday Continue POOH with packer milling BHA.Stand back collars.B/O L/O burning shoe,Junk Baskets,magnets&jars,(12 lbs of metal in baskets and on magnets),L/O 3 stds of washpipe from derrick.Change out wash pipe handling tools to 3-1/2"handling tools.PU and MU Spear with 3.198 nom.catch grapple,2-3/8"IF box X 2-3/8"reg pin x-over,3-1/2"IF box x 2-3/8" IF pin x-over,bumper and oil jars,(4)4-3/4"drill collars,3-1/2"PH-6 pup jt.total length=149.82'.RIH with Spear BHA and 3-1/2"PH-6 work string to 10,258'. P/U&R/U power swivel. M/U single on same and insert stripping rubber.Continue in hole to 10,296'DPM and tagged top of pkr body,slack off to 10,300 with 3-5 k wt.down and engaged spear.PU 30K over PU wt.let jars hit,pull 15'with 5k drag. R/D power swivel. 11/30/13-Saturday Service rig.Blow down lines and manifold. R/D power swivel.Continue POOH from 10,300'to 10,285'and packer hung up,jarred on same with 35k 3 times and continued out of hole 6k to 10k drag to 10,150'. POOH with 3-1/2"PH-6 work string and spear BHA with-0. drag. B/O&L/O fishing BHA,recovered pkr body,millout ext,2 jts 3-1/2"tbg,(1) 3-1/2"pup jt,x nipple,w/I entry guide.Total length=74.70'.P/U&M/U clean out assy.6"bladed mill,5.969 string mill,(2)junk baskets,magnet,3-1/2"PH-6 pup jt,magnet,3- 1/2"PH-6 pup jt,bumper&oil jars,(4)4-3/4"D/C,15 stds 3-1/2"PH-6 tbg,csg.scraper,total BHA=1,154.83'.RIH with 3-1/2"PH-6 tbg and clean out assy.Work thru tight spots from 3,195'to 3,384'with 4 to 8 K,depth at 06:00=9,537'. Hilcorp Alaska, LLC Mewl)_Un..6a.t.1.1: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-09RD 50-733-20131-01 181-080 11/11/2013 12/12/2013 Daily Operations: 12/01/13-Sunday Held JSA. Serviced rig.Continue in hole with clean out BHA,tagged @ 10,327'DPM,unable to work thru tight spot.P/U&M/U power swivel,tag tight spot 10,327'DPM,rotate,pumping @ 4.5 BPM 920 psi. Attempted to mill and work thru tight spot,no success. Pipe torqueing up with 1-2K wt.on mill.Circulate Bottoms up @ 5 BPM 1290 psi.Blow down Kelly hose,standpipe,circulating manifold& pump lines.L/O power swivel. POOH with 3-1/2"work string and clean out BHA to 2,500'.P/U and M/U RTTS packer and Storm valve. RIH with same&set at 215'DPM,test same to 2000psi for 15 min,(OK).Remove pollution pan from around BOP's.N/D choke,kill, her valves&hoses. Remove floor plate.Break bolts at well head on riser spool.Break bolts on tbg spool with hyd torque wrench. Remove same with Ener-Pac. 12/02/13-Monday Continue breaking studs on tbg spool and removing same with Ener-Pac.P/U stack and pull tbg hgr spool,and remove same from riser.Install new tbg hgr spool,lower riser and connect same to tbg spool and test void on same to 5,000(OK).Torque up bolts on riser.Install pollution pans around riser.Install winterization around same. R/U test manifold and chart recorder. Test hanger spool to 2500 psi on chart for 30 mins(test OK).P/U and M/U test plug.R/U BOP test assy,land test plug in tbg hanger spool. R/U test manifold and work with production and increased pressure on water flood line to BOP test manifold.Test BOP's,manifolds,choke and lines to 250 psi low,3000 psi high,had 1 leak on kill line valve stem on circ manifold,repaired same and retest ok.Witness waived by Jim Regg 12-01-2013 at 13:24 hrs. 12/03/13-Tuesday Continue testing BOP's pipe&blind rams,lines manifold&choke to 250 psi low 3000 psi high&test annular to 250 psi low 1500 psi high.R/D testing equipment. Pull test plug,blow down lines&manifolds.Install stripping head. M/U packer retrieving tool.RIH to 215'and screw into storm valve,pull 4K P/U wt.release packer,monitor well,well static.POOH to surface with storm packer.B/0& L/0 same.Continue POOH with clean out assy and B/O&L/0 same(scrapper,mills and jars).Clean rig floor. Remove stripping head. P/U wear bushing and set same in well head.P/U and M/U 7"RTTS test packer.RIH with 3-1/2"PH-6 work string and test packer current depth 5,000'. 12/04/13-Wednesday Continue RIH with RTTS packer to 9,859'space out and set same with 20k wt.down.R/U test equipment&attempted to test casing to 2,500 psi w/o success.Packing leaking on hanger hold down pins,tightened packing&attempted to tested casing w/o success.Unset RTTS&pulled up to 9,828'reset same with 20k down and tested casing to 2,500 psi on chart for 30 min.R/D test equipment&POOH with RTTS packer.B/0 and L/O same. Shut well in and change out fan belt on generator.P/U and M/U casing clean out assy.=5" round nose mill,5"string mill,bit sub,4-3/4"bumper&oil jar,(4)4-3/4"drill collars,3-1/2" PH-6 box x 3-1/2"IF pin x-over total length=151.13'.RIH with clean out assy and 3-1/2" PH-6 work string.Depth=7,467'at 06:00. 12/05/13-Thursday Continue in hole to 10,656'DPM tagged w/3-4k wt down. R/U wash down joint and wash from 10,656'to 10,668'while pumping in reverse @ 3 BPM 800 psi,Reverse bottoms up @ 3 bpm 800 PSI. Continue washing in reverse from 10,668'to 10,683'@ 4 BPM 800 psi,unable to wash deeper due to pipe plugging. R/D wash jt&R/U power swivel. Rotate and wash from 10,683'to 10,904'DPM @ 3 BPM 650 psi,torque 4-5K RPM 54 WOB 2-3K and unable to wash or mill deeper. Circulated well clean @ 5-1/2 BPM 1300 psi, (total losses while cleaning well bore=12 bbls).RD power swivel. POOH slow to 9,900'.Monitor well for gains or losses. 12/06/13-Friday RIH from 9,900'to 10,904' DPM and did not find any fill.POOH with casing clean out equipment.B/0&L/0 same.R/U E-line unit and casing caliber tools. Test lubricator to 2000 psi.RIH to 9,850'and log up to surface with csg caliber tools.RD e-line.PU&MU 47--4- 1/2" 5 SPF TCP guns loaded with 4505P OMEA 38.8 gram RDX charges,total length including blank and loaded carriers=990'. Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-09RD 50-733-20131-01 181-080 11/11/2013 12/12/2013 Daily Operations: 12/07/13-Saturday Continue PU&MU TCP gun assy.RIH to 10,850'with 3-1/2"PH-6 work string and TCP guns. RU E-line and log guns on depth,found RA tag sub 1'deep at 9,748',contacted geologist to confirm logs,was informed ok to perf at this depth.POOH with e-line and RD same and prepare to fire guns. Broke circulation down work string with 5 bbls,drop bar and fired guns and perforated casing as per program.Top shot=9,869 bottom shot 10,851'.Monitored well for 10 mins.Fluid loses=10 bbls.RD circulating lines and valves, POOH to 1,100' (17 stds)and reverse out 2 tbg volume at 4 BPM 180 psi. Small amount of gun gas back in returns,blow down lines. POOH B/O&L/O 3-1/2"PH-6 work string. 12/08/13-Sunday Continue POOH w/3-1/2"work PH-6 work string laying out same. R/D TCP gun handling tools&R/U handling tools for 3-1/2"tbg. RIH with 29 stds of 3-1/2"PH-6 tbg&POOH laying out singles and back loading same to work boat.R/U&pull wear bushing.R/D 3-1/2" handling tools&RU 4-1/2" handling tools. Slipped&cut 105'of drill line.R/U 4-1/2"test assy&test BOP pipe rams to 250 psi low 3000 psi high and Hydril to 250 psi low 1500 psi high. 12/09/13-Monday Continue testing BOP's w/4-1/2"tbg(found and repaired stem packing leaks on 3 rig manifold valves).All failed 250 psi low test.R/D test equipment.M/U and RIH w/production packer on 4-1/2"BTC tbg,rabbiting same. Unable to rabbit several jts on box end due to poly-core coating being to thick.Honed out box end of jts and continued in hole with production tbg and packer depth at 06:00= 6,700'. 12/10/13-Tuesday Continue in hole with 4-1/2"Production tbg and Stem Top packer to 9,725'.MU hanger and land same,placing packer at 9,778.43'. RU circulating equipment and lines and pump corrosion inhibitor at 1-1/2 bpm @ 100 psi, pumped 175 bbls of inhibited fluid followed by 100 bbls of FIW.Blow down lines,run in hold pins. RU wireline. Tested lubricator to 2000 psi and run in hole to 37'with 3.40"gauge,unable to work deeper.POOH with same.Beveled leading edge of 3.40 gauge ring.RIH to 47',unable to work deeper. POOH and MU 3.30"&3.250"gauge ring,unable to work deeper.POOH&MU 3.00"gauge ring and went in hole to 100'.POOH.PU& MU 3.358"od swedge and RIH to 47'unable to get deeper.POOH with same. 12/11/13-Wednesday M/U 3"swedge on wireline and RIH w/same to 10,898'.POOH w/s-line. M/U 3.230"swedge&RIH to 9,480'and POOH with same. R/D wire line.M/U landing jt,pull hanger to surface,broke out same and found ends of plastic liner touching at box connection causing liner to mushroom out inside connection.B/O and L/0 top jt of 4-1/2"tbg(liner ID in box curled in to 3.188"ID)and replace same. P/U&M/U hanger.Jim Regg-AOGCC,approved pulling hgr to floor w/o retesting BOP's @ 09:00 hrs.R/U wire line.M/U 3.313" PX plug.M/U lubricator-test same to 2000 PSI.RIH to 2,987'&tagged tight spot. Attempted to work plug thru w/o success. Attempted to POOH with plug and broke wire at rope socket. POOH rehead w/I rope socket.M/U 2.50"JDC fishing tool. RIH to 2,987' latch PX plug&POOH with same. R/D wire line. M/U landing jt,land hgr&ran in hold down pins.B/0 landing jt and L/O same.Install back pressure valve in hanger.Remove floor plates&beams. Remove cat walks. Bleed off Kommey unit.Disconnect Koomy lines to BOP stack.Held JSA on N/D BOP's&N/D wing valve on flow cross&riser.Removed bolts on hydril and double&remove same from 13-5/8"riser. Pull riser spools&L/O same.Install tree. 12/12/13-Thursday Test void on tree to 5000 psi. R/U lines and body test tree to 3000 psi f/30 mins on chart.Prep rig for skid to D-11. Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday,October 16, 2013 12:21 PM To: 'Dan Marlowe' Cc: Ted Kramer;Juanita Lovett Subject: RE: Dolly Varden D-09RD PTD 181-080,Sundry 313-369 Dan, Apologize for not getting back to you earlier. The changes proposed are relatively minor and are approved. I will place this email and updated schematic in our well file as record. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell SCANNED r ? t -4 rt'J 907-793-1226 office From: Dan Marlowe [mailto_dmarlowe(dhilcorp.com] Sent: Wednesday, October 16, 2013 12:01 PM To: Schwartz, Guy L(DOA) Cc: Dan Marlowe; Ted Kramer; Juanita Lovett Subject: FW: Dolly Varden D-09RD PTD 181-080, Sundry 313-369 Guy, I don't find where you have responded to this email yet Please advise thanks Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowe@hilcorp.com Hilcorp A Company Built on Energy From: Dan Marlowe Sent: Friday, September 20, 2013 11:17 AM To: Schwartz, Guy (guyachwartz�.?alaska.gov) Cc:Ted Kramer; Juanita Lovett Subject: Dolly Varden D-09RD PTD 181-080 , Sundry 313-369 Guy I have a few changes to the following approved Sundry per requests from the EPA Step 11—scraper run to 9,900' 1 Step 11b(new step)—Caliper log casing to 9,900' Step 12—test packer to be set at 9,800' Step 19—Hydraulic Set packer to be placed at 9,800' See attached - Approved sundry - Revised schematic Thanks Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowehilcorp corn Hilcorp A Company Built on Energy 2. p I I �g� McArthur River Field,TBU VV Well: D-09RD PROPOSED FUTURE tlilcorp 4la.ka.HA' NdGa! RKB to TBG Head = 39.52' CASING DETAIL Grade Conn ID Btm 1 20 Surf 633' 13-3/8" 61 J-55 Butt 12.515 Surf 2,530' / 9-5/8" 40 N-80 Butt 8.835 Surf 4,754' Z 9-5/8" 43.5 N-80 Butt 8.755 4,754' 5,721' / 7" 29 N-80 Butt. 6.184 Surf 10,995' L N - - - rubing Detail r4-1/2" I 13.55 I L-80,PL I BTC 1 3.40" I Surf I I L JEWELRY DETAIL epth(MD) (ND) ID Item 1 39.52' 39.52' Hanger DV at 3,486' 2 0 4.000 Tripoint Stim-Top Production Packer and 2,604' Unable to 3 i' 8,996' 3.313 'X'Nipple close top DV. 4 4' ±9,005' 4.000 Wireline Entry Guide .4 Perforation Detail 2 Zone Top(MD: Btml rop(TVD) Btm(TVD) Amt SPF Date Status 3 X G-1 ±9,867 36 ±9,0' Future G-2 ±9,912 79' ±9,1 Future 4 L -_i G-2 9,912' 9.926' 9,079' 9,092' 14 6 5/31/2000 Open G-2 ±9,932 ±9,946 ±9,098' ±9,1. 14 Future G-1 G-2 9,932' 9,946' 9.098' 9.111' 14 6 5/31/2000 Open G-2 G-3 ±9,982 '10,004 i°146' °'.c'' 22 = G-3 9,982' 10,004' 9,146' 9,167' 22 6 5/31/2000 Open G-3 6-4 ±10,01f ,180' 38 . = G-4 G-4 10,018' 10,056' 9.180' 9,216' 38 6 ,5/31/2000 Open G-5 ±10,151 ' 6-5 310,191 = B-0 G-5 310 - HK-1 B-0 10,300' 10,320' 9,451' 9,470' 20 22 5/31/2000 Open = B-1 HK-1 ±10,a,. -i0.+i_ -7,u55 45 HK-2 B-1 10,370' 10.410' 9,519' 9.558' 40 10 5/31/2000 Open _ HK-2 310,42± 310,520' ±8,115' ±9,664' 92 Future = B-2 B-2 10,435' 10.470' 9,582' 9.616' 35 4&8 4/16/1987 Open B-3 10,500' 10,520' 9,645' 9,664' 20 9 1/9/1985 Open HK-3 310,558 +?0 F6= u93' ±9,708' 15 Future HK-3 B-3 10,550' 10,565' 9.693' 9.708' 15 4 1/9/1985 Open -- B-3 HK-3 , '10,58C ±9,722' ±9,771' 50 Future B-3 10,585' 10,630' 9,727' 9,771' 45 4 1/9/1985 Open - HK-4 HK-4 .0,642 ±9,783' ±9,829' Future = B-4 B-4 10,642' 10.690' 9,783' 9,829' 48 4 1/9/1985 Open = HK-5 B-5 10.725' 10.800' 9.863' 9,936' 75 4 4/16/1987 Open = B-5 HK-5 310,721 ±10,850 ±9,863' 19,985' , 13-5 - 10,810' 10,850' 9.946' _ 9,985' 40 _ 4 4/16/1987 Open SLICKLINE/FISH/FILL INFORMATION: A. 2/27/00:Baker F-1 Pkr milled/pushed to bottom at 10,957'. B. 2/26/00:Well cleaned out to PBTD at 10957'. \ C. 8/27/07:2"DD bailer tagged up at 10880'. PBTD=10,957' TD=11,060' MAX. HOLE ANGLE =31° Revised By:JLL 09/17/13 • • Regg, James B (DOA) From: Regg, James B (DOA) Sent: Tuesday, May 01, 2012 1:33 PM To: gstoddard @hilcorp.com %-C4- Subject: Re: Trading Bay, Dolly Varden D -9RD AK1I006 -A UIC Report 0/1,— 6 Appears to be a typographical error in EPA Form 7520 -8, Injection Volume (January 2012); Yearly Cumulative Volume is less than Monthly Total Volume. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 KANAr • JUN 1 1 • • I,' 4:- n 7 :I HIjkort Alaska, LLC VIE ' MED Post Office Sax 244027 ,,dd Anchorage, AK 99524 -4027 MAY 0 2012 3800 Centerpoint Drive Suite 100 AOGCC Anchorage, AK 99503 Phone: 907/777 -8300 Fax: 907/777-8301 April 30, 2012 UIC Manager, Groundwater Protection Unit Thor Cutler (mailstop OCE -127; l2t" floor) U.S. Environmental Protection Agency in 1200 Sixth Avenue, Suite 900, OCE -127 Seattle, WA 98101 Re: Underground Injection Control Permit: Class I Permit Number AK- 11006 -A- State of Alaska Permit Number 2010080001 Cook Inlet, Alaska, Trading Bay Unit, Dolly Varden Platform Well D-9RD 1st Quarter 2012 Injection Well Monitoring Report pit 18 I *o) Dear UIC Manager: Hilcorp Alaska, LLC operates the Dolly Varden Platform that injects regulated fluids under Underground Injection Control (UIC) Permit: Class 1 Permit Number AK- 11006 -A. Pursuant to condition Part 2, E.1 of the Permit, Hilcorp is hereby submitting the first quarter (January, February, and March) 2012 Injection Well Monitoring Report for the Dolly Varden Platform Well D -9RD. During the injection reporting period only filtered Cook Inlet water for Enhanced Oil Recovery from the Dolly Varden Platform oil and gas operations has been discharged to Well D -9RD. No wastes were brought to the Dolly Varden f - - ,.. - ti _ electronic copy of the daily monitoring data is included as Attachment 1 along with data comments and graph of daily injection pressure and rates. No significant maintenance or integrity tests have been performed during the reporting period starting January 1, 2011. Consistent with the approval to commence Class I injection activities by the EPA dated May 13, 2011, this letter certifies the Injection Well Monitoring Report attached to this letter. If you have any questions, please direct them to Gretchen Stoddard at (907)777 -8343 or via e-mail at ostoddard@hilcorp.com . I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining • • UIC Manager US Environmental Protection Agency April 30, 2012 Page 2 the information, 1 believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. Sincerely, HILCORP ALASKA, LLC n A. Barnes Senior Vice President Exploration & Production- Alaska gws Attachment: 1 Quarter 2012 injection Monitoring Well Report . . OMB No. 2040 -0042 Approval Expires 12131)2011 , United States Environmental Protection Agency avEPA Washington, DC 20460 Injection Well Monitoring Report Year 2012 Month Month Month Injection Pressure (PSI) January February March 1. Minimum 0 2800 1140 2. Average 1391 3019 2989 3. Maximum 3150 3140 3120 InJaction Rate (Gal /Min) January February March 1. Minimum 0 140 90 2. Average 20 186 142 3. Maximum 49 210 240 Annular Pressure (PSI) January February March 1. Minimum 70 140 90 2. Average 267 186 142 3. Maximum 420 210 240 Injection Volume (Gal) January February March 1. Monthly Total 900,900 1,790,964 1,868,538 2. Yearly Cumulative 3F 900100 r l(?O 1 el o 2,691,864 4,560,402 Temperature (F •) January February March 1. Minimum 59 62 63 2. Average 63 68 66 3. Maximum 68 73 71 pH January February March 1. Minimum 6,2 6.4 7.9 2. Average 6.4 7.3 8.5 3. Maximum 6.6 8.0 9.5 Other Name and Address of Parmittee Permit Number Hilcorp Alaska, LLC; 3800 Centerpoint Dr., Suite 100, Anchorage, AK 99503 AK31006 -A Name and Official Tine (Please type or print) SI at • 4.1% Date Signed John A. Barnes, Sr Vice President Expl. & Production AK �_� 04' 302012 EPA Form 7520.8 (Rev. 12 -08) • • D -9RD Daily Injection Values 1st Quarter 2012 7 „ Date Hours On Injection Cum. Tubing Casing Rate, BPI) Volume, bbls Press, psi Press, psi 1/1/2012 0 0 0 0 360 1/2/2012 0 0 0 0 360 1/3/2012 0 0 0 0 360 1/4/2012 0 0 0 0 400 1/5/2012 0 0 0 0 400 1/6/2012 0 0 0 0 400 1/7/2012 0 0 0 0 400 1/8/2012 0 0 0 0 420 1/9/2012 0 0 0 0 400 1/10/2012 0 0 0 0 420 1/11/2012 0 0 0 0 420 1/12/2012 0 0 0 0 420 1/13/2012 0 0 0 0 420 1/14/2012 0 0 0 0 350 1/15/2012 0 0 0 0 350 1/16/2012 0 0 0 0 355 1/17/2012 0 0 0 0 300 1/18/2012 20 1,350 1,350 3,070 150 1/19/2012 23 1,470 2,820 3,075 75 1/20/2012 24 1,481 4,301 3,050 125 1/21/2012 24 1,455 5,756 3,050 70 1/22/2012 24 1,478 7,234 3,025 160 1/23/2012 24 1,555 8,789 3,050 145 1/24/2012 24 1,622 10,411 3,150 110 1/25/2012 24 1,683 12,094 3,150 100 1/26/2012 18 1,247 13,341 2,950 150 1/27/2012 24 1,644 14,985 3,150 120 1/28/2012 24 1,652 16,637 3,100 120 1/29/2012 24 1,607 18,244 3,100 140 1/30/2012 24 1,598 19,842 3,100 140 1/31/2012 24 1,608 21,450 3,100 130 2/1/2012 24 1,533 22,983 3,050 140 2/2/2012 14.25 941 23,924 2,800 160 2/3/2012 24 1,623 25,547 3,050 170 2/4/2012 24 1,609 27,156 3,050 170 2/5/2012 24 1,502 28,658 3,050 140 2/6/2012 24 1,489 30,147 3,000 190 2/7/2012 24 1,508 31,655 3,000 185 2/8/2012 24 1,462 33,117 3,000 200 2/9/2012 24 1,451 34,568 2,900 180 2/10/2012 24 1,485 36,053 3,000 170 2/11/2012 24 1,433 37,486 3,000 180 2/12/2012 24 1,454 38,940 3,000 190 2/13/2012 24 1,489 40,429 3,025 180 2/14/2012 24 1,581 42,010 3,100 180 0 • D -9RD Daily Injection Values 1st Quarter 2012 7 " Injection Cuni. Tubing Daft !lours On Kate, BPI) Volume, bbls Press, psi Casing Press, psi 2/15/2012 24 1,500 43,510 2,990 210 2/16/2012 24 1,520 45,030 3,000 200 2/17/2012 24 1,447 46,477 3,000 200 2/18/2012 24 1,440 47,917 3,040 190 2/19/2012 24 1,507 49,424 3,140 190 2/20/2012 24 1,495 50,919 2,950 200 2/21/2012 24 1,392 52,311 3,000 200 2/22/2012 24 1,432 53,743 3,000 200 2/23/2012 24 1,428 55,171 3,000 200 2/24/2012 24 1,489 56,660 3,100 200 2/25/2012 24 1,500 58,160 3,050 200 2/26/2012 24 1,500 59,660 3,050 200 2/27/2012 24 1,447 61,107 3,050 200 2/28/2012 24 1,534 62,641 3,100 180 2/29/2012 24 1,451 64,092 3,050 200 3/1/2012 24 1,466 65,558 3,050 200 3/2/2012 21.5 1,302 66,860 3,050 150 3/3/2012 24 1,444 68,304 3,050 140 3/4/2012 24 1,525 69,829 3,100 130 3/5/2012 24 1,490 71,319 3,100 129 3/6/2012 24 1,470 72,789 3,100 140 3/7/2012 24 1,480 74,269 3,100 140 3/8/2012 24 1,450 75,719 3,100 140 3/9/2012 24 1,466 77,185 3,100 140 3/10/2012 24 1,502 78,687 3,100 140 3/11/2012 24 1,453 80,140 3,100 140 3/12/2012 24 1,491 81,631 3,100 140 3/13/2012 24 1,459 83,090 3,050 125 3/14/2012 24 1,453 84,543 3,060 125 3/15/2012 24 1,417 85,960 3,050 125 3/16/2012 24 1,409 87,369 3,050 125 3/17/2012 19 1,125 88,494 1,140 240 3/18/2012 6 468 88,962 2,700 100 3/19/2012 24 1,595 90,557 3,120 135 3/20/2012 24 1,509 92,066 3,100 140 3/21/2012 24 1,525 93,591 3,100 140 3/22/2012 24 1,542 95,133 3,050 90 3/23/2012 24 1,524 96,657 3,050 90 3/24/2012 24 1,478 98,135 3,000 95 3/25/2012 24 1,461 99,596 3,000 100 3/26/2012 24 1,495 101,091 3,050 105 3/27/2012 24 1,513 102,604 3,000 200 3/28/2012 24 1,458 104,062 3,000 190 3/29/2012 24 1,476 105,538 3,050 165 3/30/2012 24 1,557 107,095 3,075 175 3/31/2012 24 1,486 108,581 2,975 220 • • D -9RD Daily Injection Values 1st Quarter 2012 Tbg Inj. Annular Daily Rate Press. Press Temp. January (GPM Loa (El PH Minimum 0 0 70 59 6.2 Average 20 1,391 267 63 6.4 Maximum 49 3,150 420 68 6.6 Bb Gallons Monthly Cumulative Volume: 21,450 900,900 Tbg Inj. Annular Daily Rate Press. Press Temp. February (GPM) si (psi/ PH Minimum 941 2,800 140 62 6.4 Average 1,470 3,019 186 68 7.3 Maximum 1,623 3,140 210 73 8.0 Mk Gallons Monthly Cumulative Volume: 42,642 1,790,964 Tbg Inj. Annular Daily Rate Press. Press Temp. March (GPMj Loa (psi) PH Minimum 468 1,140 90 63 8.0 Average 1,435 2,989 142 66 8.5 Maximum 1,595 3,120 240 71 9.5 Bbls Gallons Monthly Cumulative Volume: 44,489 1,868,538 Gallons 1st Qtr 2012 Cumulative Injection Volume: 4,560,402 2012 Cumulative Injection Volume: 4,560,402 Comments for 1st Quarter 2012 A. 1/1/12 - 1/18/12 - Waterflood shut -in due to sand filter and deareator clean out, intemal inspection, and repairs. B. 01/26/12- Waterflood shut -in. Water wash performed on Binghams. C. 02/02/12 - Waterflood shut -in. Maintenance performed on Binghams. C. 02/02/12- Waterflood shut -in. Maintenance performed on Binghams. D -9RD Daily Injection Graph, 1st Quarter 2012 ..i 100 90 N 3,000 1 . — a a, 80 0 v a a • - 70 c 1/26/12 & 2/2/12 - 3 1/1/12 to 1/18/12 Well shut -in due to 3/17/12 - 3/18/12 I— Well shut -in due to Bingham Well shut -in due to sand filter & maintenance, mechanical work. 60 C Ti Q 2,000 deareator clean out, mechanical, and Y E internal inspection & water washing. ro H repairs. - 50 m v _ V V o a 0 3 - 40 c a = u i... a 1,000 - 30 co a c - 20 III 1 - 10 0 0 o titi o o o o o o o o o o o o � y\� ti�y ti� ti�� \h�ti ti titi ti1, '/>\‘'\'‘' 3�ti�\ ,,�ti � 7" Casing Press, psi Tubing Press, psi —Injection Rate, BPD —Hours On • Chevron John Zager Union Oil Company of California General Manager, Alaska 3800 CenterpoInt Drive, Suite 100 MidContinent/Alaska SBU Anchorage, AK 99503 Tel 907 263 7815 Mobile 907 223 0128 Fax 907 263 7897 Email jzager@chevron.com RECEIVED JAN 26 2012 I °SD January 25, 2012 Alaska Oil & Gas Cons. Commission ry Anchorage Marc Bentley Alaska Department of Environmental Conservation Division of Water Wastewater Discharge Authorization Program stmikED .1 /\N n 555 Cordova Street Anchorage, Alaska 99501UIC Re: Underground Injection Control (UIC) Permit No. 2010 DB001 /EPA Permit No. AK- 1I006 -A Union Oil Company of California ( "Union ") Dolly Varden Well D -9RD Annual Report Dear Mr. Bentley: In accordance with Permit No. 2010 DBOO, enclosed please find EPA Form 7520 -11 Annual Disposal /Injection Well Monitoring Report and EPA Form 7520 -8 Injection Well Monitoring Reports for the 2 " 3 and 4 Quarters of 2011 for Union's Doily Varden Well D -9RD. Note because D -9RD was authorized to begin Class I injection activities on May 13, 2011, a quarterly report is not being submitted for the first quarter. As we previously advised, Union Oil Company of California ( "Union ") entered into an Asset Sale and Purchase Agreement dated July 1, 2011 to sell its interests in the Cook Inlet Area to Hilcorp Alaska, LLC, ( "Hilcorp. ") The sale closed on December 31, 2011; effective January 1, 2012 Hilcorp began operating the assets, including this UIC Permit. Future reports will be submitted by Hilcorp. Regards, � t John Zager . Enclosures: US EPA Form 7520 -8 Injection Well Monitoring Report, Second, Third and Fourth Quarters 2011 US EPA Form 7520 -11 Annual Disposal /Injection Well Monitoring Report cc: John A. Barnes, Hilcorp Alaska, LLC Thor Cutler, EPA Cathy Foerster, AOGCC 1 of 1 0 • OMB No. 2040.0042 Approval Expires 1213112011 United States Environmental Protection Agency 6EPA Washington, DC 20460 ANNUAL DISPOSAL/INJECTION WELL MONITORING REPORT Name and Address of Existing Permittee Name and Address of Surface Owner Union Oil Company of California, P. O. Box 196247 State of Alaska, Department of Natural Resources Anchorage, Alaska 99519 550 West 7th Ave., Ste. 800, Anchorage, AK 99501 State County Permit Number Locate Well and Outline Unit on Alaska NA -State waters offshore AK- 11006/2010DB001 Section Plat • 640 Acres N Surface Location Description 1 i I f 1 1 Se 114 of ne 114 of Sw 114 of SW 114 of Section 6 Township 8n Range 13w _ 1 _ L _l _ 1 _ L 1 _ Locate well in two directions from nearest lines of quarter section and drilling unit I I I I I �I .- - t --1-- _ 1 — 1 _ Surface ......1._L1._ 1 _ L 1 _ Location 754 ft. frm (NIS) S Line of quarter section 1 I 1 I 11 and 113 tt. from (EIW) w Line of quarter section. w 1 I I 1 1 1 E WELL ACTIVITY TYPE OF PERMIT _ 1 _ L 1 _, 1 t _ L 1 _ 1/1 Brine DispoaaI Individual 1 _I 1 1 I 1 1 1 ❑ Enhanced Recovery I� Area — 1 — 1 — — '1 -- t — 1,.! Hydrocarbon Storage Number of Wells I _1_L1_ 1_L1_ I I I I I I Lease Name ADL 018729 Well Number D-9ID 1 1 1 S TUBING -- CASING ANNULUS PRESSURE INJECTION PRESSURE TOTAL VOLUME INJECTED (OPTIONAL MONITORING) MONTH YEAR AVERAGE PSIG MAXIMUM PSI* BBL MCF MINIMUM PSIG MAXIMUM PSIG January-2011 N/A N/A N/A N/A N'A N/A February-2011 N/A N/A NIA N/A N A NIA March -2011 N/A N/A N/A N/A N/A N/A April -2011 N/A N/A N/A N/A N/A N/A May -2011 2633 2760 33215 N/A 210 540 June -2011 628 2700 12076 N/A 420 1040 July -201I 0 0 0 N/A 500 1060 August -2011 940 3450 13293 N/A 20 590 September -2011 2045 3440 31706 N/A 120 440 October -2011 764 3060 10221 N/A 90 370 November -2011 2655 3200 36376 N/A 30 870 December -2011 0 0 0 N/A 240 420 Certification I certify under the penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals Immediately responsible for obtaining the Information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false Information, Including the possibility of fine and imprisonment. (Ref. 40 CFR 144.32) Name and Official Title (Please type or print) Signal re Date Signed John Za er, General Manager 7 � ' / / , ; EPA Form 7520.11 (Rev. 12-08) .' 0 • OMB No. 2040-0042 Approval Expires 12/3112011 United States Environmental Protection Agency PA Washington, OC 20460 L � + � Injection Well Monitoring Report Year 2011 Month Month Month injection Pressure (PSI) October November December 1. Minimum 0 0 0 2. Average 764 2655 0 3. Maximum 3060 3200 0 Injection Rate (GallMin) October November December i. Minimum 0 0 0 2. Average 10 35 0 1 3. Maximum 44 50 0 Annular Pressure (PSI) October November December 1. Minimum 90 30 240 2. Avenge 278 152 331 3. Maximum 370 870 420 Infection Volume Mai) October November December 1. Monthly Total 429282 1527792 0 2. Yearly Cumulative 4221462 5749254 5749254 Temperature (F') October November December 1. Minimum 72 63 N/A 2. Average 73 66 N/A 3. Maximum 74 69 N/A pH October November December 1. Minimum 7.9 6.6 N/A 2. Average 8.0 7.3 N/A 3, Maximum 8.2 8.1 N/A other Name and Address of Permitte* Permit Number Union Oil Company of California, 3800 Centerpoint Drive, Suite 100, Anchorage, AK 99503 AKII006 -A Name and Official Title (Please type or print) Signature i Date Signed John 'Lager, General Manager � ;` i t. .4 , l ^ r 3 /' - 4 EPA Form 75204 (Rev. 1246) • • D -9RD Daily Injection Values 4th Quarter 2011 7" ('um. Date Ilow. Oil I)ail Kate Tbg Press Csg Press ohmic BPD Bbis psi psi 10/1/2011 0 0 0 0 290 10/2/2011 0 _ 0 _ 0 _ 0 300 10/3/2011 0 _ 0 0 0 300 10/4/2011 0 _ 0 0 0 _ 310 _10/5/2011 0 0 _ 0 0 310 10/6/2011 0 0 0 0 320 10/7/2011 0 0 0 0 330 10/8/2011 0 0 0 0 330 10/9/2011 0 0 0 _ 0 330 10/10/2011 0 0 0 0 340 10/11/2011 0 0 0 0 340 10/12/2011 _ 0 0 0 0 _ 350 10/13/2011 0 0 ! 0 0 355 10/14/2011 0 0 0 0 360 10/15/2011 0 0 0 0 360 10/16/2011 0 0 0 0 360 10/17/2011 0 0 0 0 370 10/18/2011 0 0 0 0 360 10/19/2011 0 0 0 0 360 10/20/2011 0 0 0 0 360 10/21/2011 0 0 0 0 200 10/22/2011 0 0 0 0 220 10/23/2011 0 0 0 100 230 10/24/2011 16 804 804 2,700 200 10/25/2011 24 1,088 1.892 2,860 90 10/26/2011 21 1,255 3.147 3,000 200 10/27/2011 24 1,495 4,642 3,040 165 10/28/2011 23 1,336 5,978 2,960 165 10/29/2011 24 1,396 7.374 3,000 155 10/30/2011 23 1,343 8,717 2,950 140 10/31/2011 24 1,504 10,221 3,060 125 11/1/2011 24 1,536 11,757 3,050 130 11/2/2011 24 1,559 13,316 3,100 120 11/3/2011 24 1,554 14,870 3,100 110 11/4/2011 24 1,522 16,392 3,100 110 11/5/2011 24 1,545 17,937 3,100 110 11/6/2011 24 1,602 19,539 3,050 100 11/7/2011 24 1,580 21,119 3,100 100 11/8/2011 24 1 ,690 22,809 3,100 90 11/9/2011 24 1,575 24,384 3,100 90 11/10/2011 24 1,572 25,956 3,100 90 11/11/2011 24 1,544 27,500 3,100 95 11/12/2011 24 1,490 28,990 3,050 70 11/13/2011 24 1,247 30,237 2,900 80 11/14/2011 21 1,349 31,586 3,100 70 11/15/2011 0 0 31,586 0 380 11/16/2011 0 0 31,586 0 380 11/17/2011 6 414 32,000 2,950 60 • • D-9RD Daily Injection Values 4th Quarter 2011 7 „ ('um. Date flours On Dails Rate 1 olume bg Press Csg Press 11/18/2011 13 823 32.823 2.900 150 11/19/2011 6 464 33,287 2,900 30 11/20/2011 24 1,437 34,724 3.000 140 11/21/2011 24 1.521 36,245 3,000 120 11/22/2011 24 1,591 37,836 3,060 115 11/23/2011 24 1,509 39,345 3,050 100 11/24/2011 24 1,609 40,954 3,140 80 11/25/2011 24 1,731 42,685 3,200 80 11/26/2011 24 1,711 44,396 3,170 80 11/27/2011 24 1,662 46,058 3,120 80 11/28/2011 8 539 46,597 3,120 80 11/29/2011 0 0 46,597 0 870 11/30/2011 0 0 46,597 0 460 12/1/2011 0 0 46.597 0 330 12/2/2011 0 0 46,597 0 380 12/3/2011 0 0 46,597 0 420 12/4/2011 0 0 46,597 0 420 12/5/2011 0 0 46,597 0 310 12/6/2011 0 0 46,597 0 310 12/7/2011 0 0 46,597 0 310 12/8/2011 0 0 46,597 0 310 12/9/2011 0 0 46,597 0 240 12/10/2011 0 0 46,597 0 250 _ 12/11/2011 0 0 46,597 0 250 12/12/2011 0 0 __ 46,597 0 280 12/13/2011 0 0 46.597 0 287 12/14/2011 0 0 46.597 0 290 12/15/2011 0 0 46,597 0 290 12/16/2011 0 0 46,597 0 315 12/17/2011 0 0 46,597 0 315 12/18/2011 0 0 46,597 0 330 12/19/2011 0 0 46,597 0 330 12/20/2011 0 0 46,597 0 340 12/21/2011 0 0 46,597 0 345 12/22/2011 0 0 46,597 0 350 12/23/2011 0 0 46,597 0 350 12/24/2011 0 0 46.597 0 355 12/25/2011 _ 0 0 46.597 0 _ 360 12/26/2011 0 0 46,597 0 365 12/27/2011 0 0 46,597 0 365 12/28/2011 0 0 46,597 0 365 12/29/2011 0 0 46,597 0 368 12/30/2011 0 0 46,597 0 360 12/31/2011 0 0 46,597 0 360 t tag mj. Annular Daily Rate Press. Press Temp. .; .,;; _ (GPM) (psi) (psi) L. PH • D -9RD Daily Injection Values 4th Quarter 2011 7 Da Date Hours On Daily C'u m. t H urs � Iy Rate 1'hg Press C'sg Press Volume I Minimum 0 0 90 72 7.9 Average 10 764 278 73 8.0 Maximum 44 3,060 370 74 8.2 Bbls Gallons Monthly Cumulative Volume: 10,221 429,282 ►Pg inj. Annular Daily Rate Press. Press Temp. November (GPM) .(psi) jpsi) Ll PH Minimum 0 0 30 63 6.6 Average 35 2,655 152 66 7.3 Maximum 50 3,200 870 69 8.1 Bbls Gallons Monthly Cumulative Volume: 36.376 1,527,792 tog inj. Annular Daily Rate Press. Press Temp. December (GPM) ;psi) (psi) PH Minimum 0 0 240 N/A N/A Average 0 0 331 N/A N/A Maximum 0 0 420 N/A N/A Bbls Gallons Monthly Cumulative Volume: 0 0 Gallons 1st Qtr 2011 Cumulative Injection Volume: 0 2nd Qtr 2011 Cumulative Injection Volume: 1,902,222 3rd Qtr 2011 Cumulative Injection Volume: 1,889,958 4th Qtr 2011 Cumulative Injection Volume: 1,957,074 2011 Cumulative Injection Volume: 5,749,254 Comments for 4th Quarter 2011 A. 10/1/11 - 10/24/11 -- Well shut -in due to combination of source water pump failure, dive work around platform, and waterflood surface piping upgrades. B. 10/21 /11 -- Bled fluid off of 7" casing and reduced pressure from 360 psi to 200 psi. C. 11/14/11 - 11/20/11 -- Well down time due to combination of platform power issues and waterflood injection pump issues. D. 11/29/11 - 12/31/11 -- Waterflood shut -in due to sand filter and deareator clean out, internal inspection, and repairs. Bled fluid off of T' casing and reduced pressure from 870 psi to 280 psi. E. 12/5/11 -- Bled fluid off 7" casing and reduced pressure from 420 psi to 310 psi. F. 12/9/11 -- Bled fluid off 7" casing and reduced pressure from 310 psi to 240 psi. D -9RD Daily Injection Graph Last Update: 12/31/2011 _ — - 11/14 - 20/11 -- Wtrfld and well shut -in due -_ 3,500 • to combination of platfrom power issues and �. — 168 waterflood injection pump issues. sl' , i 3,000 144 10 /1 - 24/11 -- Well shut -in 11/29/11 - 12/31/11: Wtrfld $ due to combination of and well shut -in due to sand III p, source water pump failure, filter and deareator clean a 2,500 dive work around platform, out, i nternal inspection, and 120 V and waterflood surface repairs. Bled fluid off 7" - casing and reduced pressure ti piping upgrades. from 870 psi to 280 psi. a 2,000 96 O 0 L m / 'o 0 1,500 7 2 = I- F m 1 000 10/21/11: Bled fluid off 12/5/11: Bled fluid off 7" casing and . � 7" and reduced pressure reduced pressure from 420 psi to 310 psi. 48 re from 360 psi to 200 psi. ‘ t . H ------------""----- - 11/ \\\/'-' / 12/9/11: Bled fluid off 7" and reduced 500 pressure from 310 psi to 240 psi. 24 • 0 — 0 10/1/11 10/8/11 10/15/11 10/22/11 10/29/11 11/5/11 11/12/11 11/19/11 11/26/11 12/3/11 12/10/11 12/17/11 12/24/11 12/31 /11 — Injection Rate (BPD) Tubing Press (psi) 7" Csg Press (psi) Hours On C:1Users\su IlifwW ppData \Local \Tem p1D- 9RD_DailyV alues_4th_Qtr_2011. xlsx 0 • IliMS No. 20404042 Approval Expires 1241/2011 Unarm Sumo Environmaalal Protection Avow iv EPA Waohloglon, DC 20420 Injection Well Monitoring Report Veer 2011 Month Mona Month — Injection Prawn* D'SA July August September _ 1. Minimum it 0 0 , -- 2. Average 0 940 2045 3. Maximum 0 3450 1440 Injection Rate (0101311n) July Augott September 1. Minimum 0 (1 0 2, Menage 0 11 31 — — 3. Maximum 0 1 57 Annuls Premiere (PM) July Al`11 SA:111011ber 1. Iiielmunt 500 20 120 2. Average 830 ...2( , 245 3. Maximum 1060 590 440 —....__- Infringer, Volume Mal) July August Septembet 1, Monthly Total 0 558306 i3316' 2. Yearly Curnutetive 1902222 24605A A 70 ' 1140 Temperature ( P •) July .Vigtis: Sqltembcr 1, Minimum N/A 65 66 2. Average 7■7 A 70,5 741.; 3. Maalmurn N•A 7t. Ill pH July August September 1. Minimum N/A 7.5 7.3 2. Average N/A 7.7 7.6 3. Maximum NA 7.9 7.9 --.. Other — ..... Nano and Addems of Perndtble Pons* MAW Union Oil Company of California, 3800 Centerpoint Drive, Suite 100, Anchorage, AK 99503 AK 11006 ---,- Mame and Offichtl Otte (Pii•110 nye raping gig „4..., Date 114ned John lager, General Manager f '1 . fern.lti EPA Fenn 75204 {Rev. 1240) t., r r • Attachment 1: Additional Detail and Comments to From 7520-8 D -9RD Daily injection Values 3rd Quarter 2011 s 1 .u, t s , s , , f' f.1 4 0 i - *' , + BPD iibls psi I psi I 7/1/2011 0 0 0 0 1,040 7/2/2011 0 0 0 0 1,050 7/3/2011 0 0 0 0 1,040 7/4/2011 0 0 0 0 1.040 7/5/2011 0 j 0 0 0 1,050 716/2011 0 0 0 0 1.060 7/7/2011 0 0 0 0 1,060 7/8/2011 0 0 0 0 1,040 7/9/2011 0 0 0 0 1,040 7/10/2011 0 0 0 0 1 ,040 7/11/2011 0 0 0 0 1,040 7/12/2011 0 0 0 0 1,040 7/13/2011 0 0 0 0 1.040 7/14/2011 0 0 0 0 1,040 7/15/2011 0 0 0 0 1 ,040 7/16/2011 0 0 0 0 1,040 7/17/2011 0 0 0 0 1,040 7/18/2011 0 0 0 C 1,040 7/19/2011 0 0 0 0 500 7/20/2011 0 0 0 0 510 7/21/2011 0 0 0 0 520 7/22/2011 0 0 0 0 520 7/23/2011 0 0 0 0 530 7/24/2011 0 0 0 0 540 7/25/2011 0 0 0 0 540 7/26/2011 0 0 0 l 0 540 7/27/2011 0 0 0 1 0 545 7/28/2011 0 0 0 0 550 7/29/2011 0 0 0 0 550 7/30/2011 0 0 0 0 550 7/31/2011 0 0 0 0 550 8/1/2011 0 0 0 0 550 8/2/2011 0 0 0 0 560 8/3/2011 0 0 0 0 560 8/4/2011 0 0 0 0 560 8/5/2011 0 0 0 0 560 8/6/2011 0 0 0 0 560 8/7/2011 0 0 0 0 565 8/8/2011 0.... 0 0 0 565 8/9/2011 0 0 0 0 560 8/10/2011 0 0 0 0 570 8/11/2011 0 0 0 0 570 8/12/2011 0 0 0 0 580 8/13/2011 0 0 0 0 580 8/14/2011 0 0 0 0 580 8/15/2011 0 0 0 0 580 8/16/2011 0 0 0 0 585 • 0 D -9RD Daily Injection Values 3rd Quarter 2011 7 , . 1 o ►tlm . . 8/17/2011 0 0 0 �0- ` ' 590 8/18/2011 0 0 0 0 590 1 8/19/2011 0 0 0 0 590 8/20/2011 0 0 0 0 E 590 8/21 /2011 0 0 0 0 c:20 8/22/2011 6 699 699 3,350 ' 110 8/23/2011 14 1,778 2,477 550 250 8/24/2011 21 1,033 3,510 2,900 20 8/25/2011 24 1,136 4,646 2,850 20 8/26/2011 24 1,138 5,784 2,850 20 8/27/2011 20 1,152 6,936 3,300 126 8/28/2011 24 1,730 8,666 3,200 170 8/29/2011 24 1,724 10,390 3,250 160 8/30/2011 24 1,832 12,222 3,450 150 8/31/2011 14 1,071 13,293 3,450 150 9/1/2011 6 739 14,032 3,330 200 9/2/2011 24 1,962 15,994 3,440 120 9/3/2011 24 1,947 17,941 3,400 180 9/4/2011 24 1,942 19,883 3,400 150 9/5/2011 24 1,954 21,837 3,360 140 9/6/2011 24 1 ,272 23,109 2,700 i 220 9/7/2011 24 1,279 24,388 3,200 ` 160 9/8/2011 24 1,964 26,352 3,350 170 9/9/2011 24 1,968 28,320 3,375 200 9/10/2011 j 24 1,952 30,272 3,375 200 9/11/2011 I 24 1,941 32,213 3,400 230 9/12/2011 24 1,440 33,653 2,900 350 9/13/2011 24 1,147 34,800 2,900 440 9/14/2011 24 1,582 36,382 3,250 260 9/15/2011 24 1,456 37,838 2,875 280 9/16/2011 24 1,379 39,217 3,200 275 9/17/2011 24 1,792 41,009 3,300 250 9/18/2011 24 1,790 42,799 3,300 250 9/19/2011 24 1,763 44,562 3,300 250 9/20/2011 6 437 44,999 0 350 9/21/2011 0 0 44,999 0 280 9/22/2011 0 0 _ 44,999 0 280 9/23/2011 0 I 0 44,999 0 220 9/24/2011 0 0 44,999 0 238 9/25/2011 0 0 44,999 0 270 9/26/2011 0 0 44,999 0 240 9/27/2011 0 0 44,999 0 280 9/28/2011 0 0 44,999 0 290 9/29/2011 0 0 44,999 0 295 9/30/2011 0 0 44,999 0 295 • D -9RD Daily injection Values 3rd Quarter 2011 7" Date lluurs On t)ail■ Rate ( unt. f ha 1'ress s� �'ulum 1 "r g nl. • nnu ar Daily Rate Press. Press Temp. July .{GPM;: jgsi) jilt) Minimum 0 0 500 N/A N/A Average 0 0 830 N/A NIA Maximum 0 0 1,060 N/A N/A t Gallons Monthly Cumulative Volume 0 0 Tbg In;. Annular Daily Rate Press. Press Temp. Auqust jGPM1 Ias) sj) P Minimum 0 0 20 65 7.5 Average 13 940 426 70.5 7.7 Maximum 53 3.450 590 76 7.9 Sbls Gallons Monthly Cumulative Volume 13,293 558,306 • g nl, nnu ar Daily Rate Press. Press Temp. September (GPM) jpI 10 11 PH Minimum 0 0 120 66 7.3 Average 31 2 045 245 74.8 7.6 Maximum 57 3.440 440 81 7.9 13b1s Gallons Monthly Cumulative Volume 31,706 1,331,652 Gallons 1st Qtr 2011 Cumulative Injection Volume 0 2nd Qtr 2011 Cumulative Injection Volume 1,902,222 3rd Qtr 2011 Cumulative Injection Volume 1.889,958 4th Qtr 2011 Cumulative Injection Volume 2011 Cumulative injection Volume 3,792,180 Comments for 3rd Quarter 2011 A. 7/1/11 - 8121/11 -- Well remained shut -in until continuous rate and pressur rronitorirg installed. R. 7/19111 Since well shut -in, bled fluid off of 7" casing and reduced pressure from 1040 psi to 500 psi C. 8/27111 -- Intentionally added fluid to increase pressure on 7" casing to belt* monitor changes in pressure. D. 9120111 -- Weil shut -in due to combination of source water pump failure, diw work around p'atfcrm. and waterflood surface piping upgrade* • D -9RD Daily Injection Graph Last Update: 9/30/2011 3,5CC 168 3 . 0 0 0 'i 144 a. e 1. \i'—'.\/(/ . • m 2,500 __ _ 9/20 - 30/11— 120 U /71/11 8/21/11 Weil remained shut -in until continuous rate and pressure monitoring Well shut - in i� 1 installer!. due to 2 OOC t combination of i source water 96 c pump failure, 0 ! 7/19/11 Since well F div work 2 0 2 1,530 shut -in, bled fluid off of 8/27/11 -- Intentionally I platform, form, and 72 x V - 7" casing and reduced added fluid to increase waterflood [1 pressure from 1040 psi pressure on 7" casing to ! surface piping O. Eq. 1 000 """ �' to 500 psi. better monitor changes , . in pressure. 48 a 24 III � 0 711 /11 7/8/11 7/15/11 7/22/11 7/29/11 8/5/11 8/12/11 8/19111 8/26111 9/2/11 9/9/11 9116/11 9/23/11 9/30/11 — Infection Rate (BPD) Tubing Pross (psi) 7" Csg Press (psi) -Hours On 0:'NALAMCEIVAlaskaMerotskHESTrvironmentalMastellIMEPA Injection Weil Monitoring Reporls120111301attachments1D 9RD_DeilyValues_3rd 2011 (3).xlsx . • • OMB Ma 10/04042 Approval rapine t2212i48t1 UnW, Stator En*unmsn al Peotad$at Aiwel & EPA Washington, DC 20400 Injection Well Monitoring Report Yaw 2011 month Month Meath Mnieatlon Fraawe (Pot) April May June I. Mintinuar N/A 2550 9 2. Awraos N/A 2633 628 3. Maximum WA 2760 2700 iniauioa Rata teauMin) A pril May June 1. Minimum N/A 45 0 2. Average N/A 51 12 3, Maatmum N/A 77 54 Annuier Plenum (Ps0 April May June 1. Minimum N/A 210 420 2. Awtaoe N/A 432 7366 2. Maximum N/A 540 1040 Injection volume (oil) April May June 1. Monthly roar N/A 1395030 507192 2. Yeary Cumueatt.% N/A 1395030 1902222 Tetnperatunt pi ') April May June t. Minimum N/A 67 76 2. Avenge N/A 67 76 2. Maximum N/A 67 76 pm April May June t. Minimum N/A NIA 5 2. Average N/A N/A 5 3. Maximum N/A N/A S Other Note 1) May is averaged from the authorization start date of May 13, 2011 Note 2) See Attachment 1'or additional comments `Name mid Addnre of Permatee Permit Number (mien Oil Company of California, 3800Cenhnpoint Drive Suite 100, AX. 99503 AK 1 1006 -A ' Name and Otaabl Tate (Please type or ptlan at • mete Stinted John Lager, General Manager L. 7/9 t''!j EPA Fenn 75204 (RSV. 1240) . • • Attachment 1; Additional Detail and Comments to Form 7520 -8 D 9RD Daily Injection Values - 2nd Quarter 2011 Date I3ours 1 }:uly� Cumulative Tubing 7" Casing t}n Rate Volume Pressure Pressure; BPD BbIs psi psi EPA Director authorizes injection of Class I fluids on 5113111 5/13/2011 _ 24 2,105 2,105 2,760 210 5/14/2011 24 2,064 4,169 2,750 320 5/15/2011 19 1,588 5,757 2,750 320 5/16/2011 24 1,814 7,571 2,850 315 5/17/2011 24 1,898 9,469 2,700 320 5/18/2011 24 1,733 11,202 2,600 360 5/19/2011 24 1,561 12,763 2,650 420 5/20/2011 • 24 1,630 14,393 2,650 450 5/21/2011 24 1,672 16,065 2,600 - 460 5/22/2011 24 1,612 17,677 2,600 480 5/23/2011 24 1,548 19,225 2,550 540 5/24/2011 24 1,625 20,850 2,560 525 5/25//2011 24 1,685 22,535 2,600 515 5/26/2011 24 2,628 25,163 2,620 515 5/27/2011 22 1,585 26,748 2,620 540 5/28/2011 24 1,664 28,412 2,620 465 5/29/2011 24 1,639 30,051 2,600 460 5/30/2011 24 1,575 31,626 2,590 500 5/31/2011 24 1,589 33,215 2 500 6/1/2011 24 1,719 34,934 2,700 450 6/2/2011 24 1,790 36,724 2,650 450 6/3/2011 24 1,782 38,506 2,700 440 6/4/2011 24 1,850 40,356 2 700 420 6/512011 24 1,811 42,167 2,700 440 6/6/2011 17 1,786 43,953 2,700 440 6/7/2011 17 1,338 45,291 2,700 550 6/8/2011 0 0 45,291 0 800 6/9/2011 0 0 45,291 0 880 6/10/2011 0 0 45,291 0 920 6/11/2011 0 0 45,291 0 950 6/12/2011 - 0 0 45,291 0 970 6/13/2011 0 0 45,291 0 980 6/14/2011 0 0 45,291 0 980 6/15/2011 0 0 45,291 0 980 6/16/2011 - 0 0 45.291 0 1,000 6/17/2011 0 0 45,291 0 1,010 6/18/2011 - 0 0 45,291 0 1,010 6/19/2011 0 0 45,291 0 1,010 6/20/2011 0 0 45,291 0 1,010 6/21/2011 0 0 45,291 0 1,020 6/22/2011 0 0 45,291 0 1,010 6/23/2011 0 0 45,291 0 1,010 6/24/2011 0 0 45,291 0 1,020 6/25/2011 0 0 45,291 0 1,030 6/26/2011 0 0 45,291 0 1,040 6/27/2011 0 0 45,291 0 1,040 6/28/2011 0 0 45,291 0 1,040 6/29/2011 0 0 45,291 0 1,040 6/30/2011 0 0 45,291 0 , 1,040 1af 2 s • • — D -9RD Injection Data Summary - By Month Tubing Daily Injection Annular Rate Pressure Pressure Temp. April (GPM) foil (psi) (deg 9 pH Minimum Average Not applicable - EPA Director authorizes injection of Class 1 fluids on 5113/11 Maximum Mt Gallons Monthly Cumulative Volume: . Tubing Daily injection Annular Rate Pressure Pressure Temp. May (GPM' 101 1oll (deg 9 0, Minimum 45 2,550 210 67 Not measured Average 51 2,633 432 67 Not measured Maximum 77 2,760 540 67 Not measured Bbls Gallons Monthly Cumulative Volume: 33,215 1,395,030 r Tubing Daily injection Annular Rate Pressure Pressure Temp. June (GPM) (Dsij W1 (deg F) R_H Minimum 0 0 420 76 5 Average 12 628 866 78 5 Maximum 54 2,700 1,040 76 5 Gallons Monthly Cumulative Volume: 12,076 507,192 Gallons 2011 Cumulative injection Volume: 1,902,222 Comments and Notes for 2nd Quarter 2011 A. 4/13111 -- EPA witnessed MIT of well. Inner annulus pressured up to 2220 psi with well on injection and tubing pressure at 2725 psi. Passed test. B. 4/14/11 -- EPA witnessed slickline temperature survey of well to 10800 feet. C. 5/11/11 -- CVX mailed report of MIT test and temperature survey with attachments to EPA. D. 5/13/11 -- EPA Director authorizes injection of Class 1 fluids. E. 6/7/11 -- Informed that EPA authorized injection of Class I fluids. Since continuous monitoring of pressure and rate not yet installed on well, shut well in Notes: Bbis - barrels (42 gallons) BPD = barrels per day EPA - (US) Environmental Protection Agency GPD = gallons per day GPM = gallons per minute MIT = mechanical integrity testing psi = pounds per square inch 2of 2 , D -SRD Daily Injection Graph Last Update: 6/30/2011 3,000 - 30 i 4/13/11 EPA witnessed MIT of well. Inner annulus pressured up 1 6'7/11-- Informed that EPA 1 to 2220 psi with well on injection and tubing pressure at 2T25 psi. t--- - __I authorized injection of pass f - _ Passed test. 1 !fluids. Since continuous f12 4/ 14111 - EPA witnessed stickline temperature survey of well to ______ - _. --- - monitoring of pressure and - -- 25 a 10803. rate not yet installed ort • 1 511/11 - CVX mailed report of MIT test and temperature survey i 4 . __ - well, shut well in. Q. w`,h att. achrnen , 1' , u'E PA . to U 2,000 . - -. �_ _ 20 i. . V13111 EPA Director authorizes j . c as 1 500 ._ —_ t __ injection of Class I fluids. 15 e a. o m z 1 — a 1,000 10 m I 500 _. � ,_.. .. 5 • 0 — • 0 4/1/11 4/8/11 4/15/11 4/22/11 4/29/11 5/6/11 5/13/11 5/20/11 5/27/11 513/11 6/10111 6/17/11 6/24111 7/1/11 Injection Rate (BPD) Tubing Press (psi) T' Csg Press (psi) —Hours On D -9RD Graph — 2nd Qtr • '-it* 0 9 P71) )810560 Chevron John ager Union Oil Company of California General Manager 3800 Centerpoint Drive Suite 100 Anchorage, AK 99503 Tel 907 263 7815 Fax 907 263 7693 Email jzager@chevron.com January 25, 2012 UIC Manager, Groundwater Protection Unit U.S. Environmental Protection Agency 1200 Sixth Avenue, Suite 900, OCE-082 Seattle, WA 98101 tANNEVEB 8 2W- RETURN RECEIPT REQUESTED - CERTIFIED MAIL Re: Underground Injection Control Permit: Class I Permit Number AK-1I006-A State of Alaska Permit Number 2010DB0001 Cook Inlet, Alaska, Trading Bay Unit, Dolly Varden Platform Well D-9RD 4 Quarter Calendar Year 2011 Injection Well Monitoring Report On May 13, 2011 Union Oil Company of California ("Union") was authorized to begin Class 1 injection activities into Dolly Varden Platform Well D-9RD under s' Underground Injection Control (UIC) Permit: Class I Permit Number AK-11006-A. Pursuant to condition Part 2, E.1 of the Permit, enclosed please find the fourth quarter 2011 (October, November and December) Injection Well Monitoring Report for D-9RD. During the injection reporting period only filtered Cook Inlet water for Enhanced Oil Recovery from the Dolly Varden Platform oil and gas operations was discharged to Well D-9RD. No wastes were brought to the Dolly Varden Platform from other UOCC facilities for the purpose of injection in Well D-9RID. A copy of the daily monitoring data is included along with data comments and a graph of daily injection pressure and rates. No significant maintenance or integrity tests were performed during the reporting period starting October 1, 2011. Consistent with the approval to commence Class I injection activities by the EPA dated May 13, 2011, this letter certifies the Injection Well Monitoring Report attached to this letter. Union has sold its interest to Hilcorp Alaska, LLC. Hilcorp became the operator effective January 1, 2012. • UIC Manager US Environmental Protection Agency January 25, 2012 Page 2 I certify under penalty of law that I have personally examined and am familiar with the Information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the Information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. Best regards 17-7(1, John Zager : Enclosure: Form 7520-8 Additional Detail and Comments to Form 7520-8 D-9RD Daily Injection Graph cc: Marc Bentley, ADEC Cathy Foerster, AOGCC Gretchen Stoddard, Hilcorp Alaska LLC Hal Martin, UOCC Faye Sullivan, UOCC ■I■ 0 • OMB No. 2040-0042 Approval Expires 12402011 United States Environmental Protection Agency a f E P A Washington, DC 20440 Injection Well Monitoring Report Year 2011 Month Month Month Injection Pressure (PSI) October November December 1, Minimum 0 0 0 2. Average 764 2655 0 3. Maximum 3060 3200 0 Infection Rate (SeirMin) October November Decomber 1. Minimum 0 0 0 2. Average 10 35 0 3. Maximum 44 50 0 Annular Pressure (Psi) October Noe ember December 1. Minimum 90 30 7.40 2. Average 2 152 331 Z. Maximum 370 870 420 Injection Volume (Gan October November December 1. Monthly Total 429282 1.527792 0 2. Yearly Cumulative 4221462 5749254 5749254 Temperature (F *) October November December 1. Minimum 72 63 NiA 2. Average 73 66 N/A 3. maximum 74 69 N/A pH October November December 1. Minimum 7.9 6.6 N/A 2. Average 8.0 7.3 N/A 3, Maximum 8.2 8.1 N/A om or , . - - Name and Address of P•rrnIttee Permit Number Union Oil Company of California, 3800 Centerpoint Drive, Suite 100, Anchorage, AK 99503 AK11006 — Name and Official Tide (Pleas* typo or prim) Signetwir 1 Date Signed John Zager, General Manager / ' . 4 ,, : / ' , -\.----- i / 1 l ? EPA Form T620.4 (Rev. 12-04) . ,.. • • D -9RD Daily Injection Values 4th Quarter 2011 7" Date Boars }fin Daily Rat °t`bg Press O,' Press Volume tum BPI) 8bis psi psi 10/1/2011 0 0 0 0 290 10/2/2011 0 0 0 0 300 10/3/2011 0 0 0 0 300 10/4/2011 0 0 0 0 310 10/5/2011 0 0 0 0 310 10/612011 0 0 0 0 320 10/7/2011 0 0 0 0 330 10/8/2.011 0 0 0 0 330 10/9/2011 0 0 0 0 330 10/10/2011 0 0 0 0 340 10/11/2011 0 0 0 0 340 10/12/2011 0 0 0 0 350 10/13/2011 0 0 0 0 355 10/14/2011 0 0 0 0 360 10/15/2011 0 0 0 0 360 10/16/2011 0 0 0 0 360 10/17/2011 0 0 0 0 370 10/18/2011 0 0 0 0 360 10/19/2011 0 0 0 0 360 10/20/2011 0 0 0 0 360 10/21/2011 0 0 0 0 200 10/22/2011 0 0 0 0 220 10/23/2011 0 0 0 100 230 10/24/2011 16 804 804 2,700 200 10/25/2011 24 1,088 1,892 2,860 90 • 10/26/2011 21 1 ,255 3,147 3,000 200 10/27/2011 24 1,495 4,642 3,040 165 • 10/28/2011 23 1,336 5,978 2,960 165 10/29/2011 24 1,396 7,374 3,000 155 10/30/2011 23 1,343 8,717 2,950 140 _ 10/31/2011 24 1,504 10,221 3,060 125 11/1/2011 24 1,536 11,757 3,050 130 11/2/2011 24 _ 1,559 13,316 3,100 120 11/3/2011 24 1,554 14,870 3,100 110 11/412011 24 1,522 16,392 3,100 110_ 11/5/2011 24 1,545 17,937 3,100 110 11/6/2011 24 1,602 19,539 3,050 100 11/7/2011 24 1,580 21,119 3,100 100 11/8/2011 24 1,690 22,809 3,100 90 11/9/2011 24 1,575 24,384 3,100 90 11/10/2011 24 1,572 25,956 3,100 90 11/11/2011 24 1,544 27,500 3,100 95 11/12/2011 24 1,490 28,990 3,050 70 11/13/2011 y 24 _ 1,247 30,237 2,900 80 11/14/2011 21 1,349 31,586 3,100 70 11/15/2011 _ 0 0 31,586 0 380 11/16/2011 0 0 - 31,586 0 380 .. 11/17/2011 6 414 32,000 2,950 60 D -9RD Daily Injection Values 4th Quarter 2011 7 " cum Dale !lours On t)uiT Rate b f re± C stt Press Volume 11/18/2011 13 823 32,823 2,900 150 11/19/2011 6 464 33,287 2,900 30 11/20/2011 24 1,437 34,724 3,000 140 11/21/2011 24 1,521 36,245 3,000 120 11/22/2011 24 1 ,591 37,836 3,060 115 11/23/2011 24 1,509 39,345 3,050 100 11/24/2011 24 1,609 40,954 3,140 80 11/25/2011 24 1,731 , 42,685 3,200 80 11/26/2011 24 1,711 44,396 3,170 80 n f/ 11/27/2011 24 1,662 46,058 _ 3,120 80 CCU b 11/28/2011 8 539 46,597 » 3,120 80 7 11/29/2011 0 0 46,597 0 870 2 ' 11/30/2011 0 _ 0 46,597 0 460 12/1/2011 0 0 46,597 0 330 12/2/2011 0 0 46,597 0 380 12/3/2011 0 0 46,597 0 420 12/4/2011 0 0 46,597 0 420 w 12/5/2011 0 0 46,597 0 310 12/6/2011 0 0 46,597 0 310 12/7/2011 0 0 46,597 0 310 12/8/2011 0 0 46,597 0 310 12/9/2011 0 0 46,597 0 240 12/10/2011 0 0 46,597 0 250 12/11/2011 0 0 46,597 0 250 12/12/2011 0 0 46,597 0 280 12/13/2011 0 0 46,597 0 287 12/14/2011 0 0 46,597 0 290 12/15/2011 0 0 46,597 0 290 12/16/2011 0 0 46,597 0 315 12/17/2011 0 0 46,597 0 315 12/18/2011 0 0 46,597 0 330 12/19/2011 0 0 46,597 0 330 12/20/2011 0 0 46,597 0 340 12/21/2011 0 0 46,597 0 345 12/22/2011 0 0 46,597 0 350 12/23/2011 0 0 46,597 0 350 12/24/2011 0 0 46,597 0 355 12/25/2011 0 0 46,597 0 360 12/26/2011 0 0 46,597 0 365 12/27/2011 0 0 46,597 0 365 12/28/2011 0 0 46,597 0 365 12/2912011 0 0 46,597 0 368 12/30/2011 0 0 46,597 0 360 12/31 /2011 0 0 . 46,597 0 360 I Dg lflJ. Annular Daily Rate Press. Press Temp. October (GPM) juil 1141 LEI PH • • D-9RD Daily Injection Values 4th Quarter 2011 7 " Pre nu s ti a Daily , 'I 0 s Cse ties 72 Date Rite I 0. Minimum 0 0 90 7.9 Average 10 764 278 73 8.0 Maximum 44 3,060 370 74 8.2 Bp's, Gallons Monthly Cumulative Volume: 10,221 429,282 log mi. Annular Daily Rate Press. Press Temp. November fGPM) Loa LOD, fa PH Minimum 0 0 30 63 6.6 Average 35 2,655 152 66 7.3 Maximum 50 3,200 870 69 8.1 Bbls PallOris Monthly Cumulative Volume: 36,376 1,527,792 I og inj. Annular Daily Rate Press. Press Temp. December (GPM) fosi) LEI PH Minimum 0 0 240 N/A N/A Average 0 0 331 N/A N/A Maximum 0 0 420 N/A N/A Bbls Gallons Monthly Cumulative Volume: Gallons 1st Qtr 2011 Cumulative Injection Volume: 0 2nd Qtr 2011 Cumulative Injection Volume: 1,902,222 3rd Qtr 2011 Cumulative Injection Volume: 1,889,958 Volume: 4th Qtr 2011 Cumulative Injection o 1..957.074 2011 Cumulative Injection Vo l u me; ume 5,749,254 Comments for 4th Quarter 2011 A. 10/1/11 - 10/24/11 -- Well shut-in due to combination of source water pump failure, dive work around platform, and waterflood surface piping upgrades. B. 10/21/11 -- Bled fluid off of 7" casing and reduced pressure from 360 psi to 200 psi. C. 11/14/11 - 11/20/11 -- Well down time m i e due to co bination of platform power issues and waterflood injection pump issues. D. 11/29/11 - 12/31/11 Waterflood shut-in due to sand filter and deareator clean out, internal inspection, and repairs. Bled fluid off of 7" casing and reduced pressure from 870 psi to 280 psi. E. 12/5/11 -- Bled fluid off 7" casing and reduced pressure from 420 psi to 310 psi. F. 12/9/11 -- Bled fluid off 7" casing and reduced pressure from 310 psi to 240 psi. D -9RD Daily Injection Graph Last Update: 12/31/2011 r - _ 11/14 - 20/11 -- Wtrfld and well shut -in due 3,500 to combination of platfrom power issues and 168 waterflood injection pump issues. 7 s 'Q 3,000 -- 144 N 10 /1- 24/11 -- Well shut -in 11/29/11 - 12/31/11: Wtrfld due to combination of and well shut -in due to sand a.. source water pump failure, filter and deareator clean 0 2,500 dive work around platform, out, internal inspection, and 120 N O and waterflood surface repairs. Bled fluid off 7" i piping upgrades. casing and reduced pressure from 870 psi to 280 psi. I a 2,000 96 c j 0 va) co 0 ∎ _ 72 = in 1,500 Iva. , Nil 0- 00 10/21/11: Bled fluid off 1 12/5/11: Bled fluid off 7" casing and a) 1,000 7" reduced ressure from 420 psi to 310 psi. and reduced pressure 48 p R from 360 psi to 200 psi. Ce 12/9/11: Bled fluid off 7" and reduced — pressure from 310 psi to 240 psi. W 500 24 N 1 !L • I"' ‘, — ` , , _ j 10/1/11 10/8/11 10/15/11 10/22/11 10/29/11 11/5/11 11/12/11 11/19/11 11/26/11 12/3/11 12/10/11 12/17/11 12/24/11 12/31/11 - - Injection Rate (BPD) —Tubing Press (psi) •---7" Csg Press (psi) —Hours On C:\ Users \jbregg\AppData \Local \Microsoft\Windows \Temporary Internet Files\ Content. Outlook\ 2D91DKEK \D- 9RD_DailyValues_4th_Qtr_2011 0 r D -9RD Daily Injection Values 4th Quarter 2011 7 " Date Hours On Daily Rate Cum. '1'bg Press Csg Press Volume BPD Bbls psi psi 10/1/2011 0 0 0 0 290 10/2/2011 0 0 0 0 300 10/3/2011 0 0 0 0 300 10/4/2011 0 0 0 0 310 10/5/2011 0 0 0 0 310 10/6/2011 0 0 0 0 320 10/7/2011 0 0 0 0 330 10/8/2011 0 0 0 0 330 10/9/2011 0 0 0 0 330 10/10/2011 0 0 0 0 340 10/11/2011 0 0 0 0 340 10/12/2011 0 0 0 0 350 10/13/2011 0 0 0 0 355 10/14/2011 0 0 0 0 360 10/15/2011 0 0 0 0 360 10/16/2011 0 0 0 0 360 10/17/2011 0 0 0 0 370 10/18/2011 0 0 0 0 360 10/19/2011 0 0 0 0 360 10/20/2011 0 0 0 0 360 10/21/2011 0 0 0 0 200 10/22/2011 0 0 0 0 220 10/23/2011 0 0 0 100 230 10/24/2011 16 804 804 2,700 200 10/25/2011 24 1,088 1,892 2,860 90 10/26/2011 21 1,255 3,147 3,000 200 10/27/2011 24 1,495 4,642 3,040 165 10/28/2011 23 1,336 5,978 2,960 165 10/29/2011 24 1,396 7,374 3,000 155 10/30/2011 23 1,343 8,717 2,950 140 10/31/2011 24 1,504 10,221 3,060 125 11/1/2011 24 1,536 11,757 3,050 130 11/2/2011 24 1,559 13,316 3,100 120 11/3/2011 24 1,554 14,870 3,100 110 11/4/2011 24 1,522 16,392 3,100 110 11/5/2011 24 1,545 17,937 3,100 110 11/6/2011 24 1,602 19,539 3,050 100 11/7/2011 24 1,580 21,119 3,100 100 11/8/2011 24 1,690 22,809 3,100 90 11/9/2011 24 1,575 24,384 3,100 90 11/10/2011 24 1,572 25,956 3,100 90 11/11/2011 24 1,544 27,500 3,100 95 11/12/2011 24 1,490 28,990 3,050 70 11/13/2011 24 1,247 30,237 2,900 80 11/14/2011 21 1,349 31,586 3,100 70 11/15/2011 0 0 31,586 0 380 11/16/2011 0 0 31,586 0 380 11/17/2011 6 414 32,000 2,950 60 • • D -9RD Daily Injection Values 4th Quarter 2011 7" Cum. Date Hours On Daily Rate Volume Tbg Press Csg Press 11/18/2011 13 823 32,823 2,900 150 11/19/2011 6 464 33,287 2,900 30 11/20/2011 24 1,437 34,724 3,000 140 11/21/2011 24 1,521 36,245 3,000 120 11/22/2011 24 1,591 37,836 3,060 115 11/23/2011 24 1,509 39,345 3,050 100 11/24/2011 24 1,609 40,954 3,140 80 11/25/2011 24 1,731 42,685 3,200 80 11/26/2011 24 1,711 44,396 3,170 80 11/27/2011 24 1,662 46,058 3,120 80 11/28/2011 8 539 46,597 3,120 80 11/29/2011 0 0 46,597 0 870 11/30/2011 0 0 46,597 0 460 12/1/2011 0 0 46,597 0 330 12/2/2011 0 0 46,597 0 380 12/3/2011 0 0 46,597 0 420 12/4/2011 0 0 46,597 0 420 12/5/2011 0 0 46,597 0 310 12/6/2011 0 0 46,597 0 310 12/7/2011 0 0 46,597 0 310 12/8/2011 0 0 46,597 0 310 12/9/2011 0 0 46,597 0 240 12/10/2011 0 0 46,597 0 250 12/11/2011 0 0 46,597 0 250 12/12/2011 0 0 46,597 0 280 12/13/2011 0 0 46,597 0 287 12/14/2011 0 0 46,597 0 290 12/15/2011 0 0 46,597 0 290 12/16/2011 0 0 46,597 0 315 12/17/2011 0 0 46,597 0 315 12/18/2011 0 0 46,597 0 330 12/19/2011 0 0 46,597 0 330 12/20/2011 0 0 46,597 0 340 12/21/2011 0 0 46,597 0 345 12/22/2011 0 0 46,597 0 350 12/23/2011 0 0 46,597 0 350 12/24/2011 0 0 46,597 0 355 12/25/2011 0 0 46,597 0 360 12/26/2011 0 0 46,597 0 365 12/27/2011 0 0 46,597 0 365 12/28/2011 0 0 46,597 0 365 12/29/2011 0 0 46,597 0 368 12/30/2011 0 0 46,597 0 360 12/31/2011 0 0 46,597 0 360 1 in mi. Annular Daily Rate Press. Press Temp. October (GPM) (psi) (psi) LEI PH • , D -9RD Daily Injection Values 4th Quarter 2011 7" Cum. Date Hours On Daily Rate I bg Press Csg Press Volume Minimum 0 0 90 72 7.9 Average 10 764 278 73 8.0 Maximum 44 3,060 370 74 8.2 Bbls Gallons Monthly Cumulative Volume: 10,221 429,282 i ag mj. Annular Daily Rate Press. Press Temp. November (GPM) (psi) (psi) PH Minimum 0 0 30 63 6.6 Average 35 2,655 152 66 7.3 Maximum 50 3,200 870 69 8.1 Bbls Gallons Monthly Cumulative Volume: 36,376 1,527,792 I tog mj. Annular Daily Rate Press. Press Temp. December (GPM) (psi) (psi) LE1 PH Minimum 0 0 240 N/A N/A Average 0 0 331 N/A N/A Maximum 0 0 420 N/A N/A Bbls Gallons Monthly Cumulative Volume: 0 0 Gallons 1st Qtr 2011 Cumulative Injection Volume: 0 2nd Qtr 2011 Cumulative Injection Volume: 1,902,222 3rd Qtr 2011 Cumulative Injection Volume: 1,889,958 4th Qtr 2011 Cumulative Injection Volume: 1.957.074 2011 Cumulative Injection Volume: 5,749,254 Comments for 4th Quarter 2011 A. 10/1/11 - 10/24/11 -- Well shut -in due to combination of source water pump failure, dive work around platform, and waterflood surface piping upgrades. B. 10/21/11 -- Bled fluid off of 7" casing and reduced pressure from 360 psi to 200 psi. C. 11/14/11 - 11/20/11 -- Well down time due to combination of platform power issues and waterflood injection pump issues. D. 11/29/11 - 12/31/11 -- Waterflood shut -in due to sand filter and deareator clean out, internal inspection, and repairs. Bled fluid off of 7" casing and reduced pressure from 870 psi to 280 psi. E. 12/5/11 -- Bled fluid off 7" casing and reduced pressure from 420 psi to 310 psi. F. 12/9/11 -- Bled fluid off 7" casing and reduced pressure from 310 psi to 240 psi. • • Chevron John Zager Union Oil Company of California ata.. General Manager, Alaska 3800 Centerpoint Drive, Suite 100 MidContinent/Alaska SBU Anchorage, AK 99503 Tel 907 263 7815 Mobile 907 223 0128 Fax 907 263 7897 Email jzager @chevron.com Pl [I-O 20 December 15, 2011 rt 10,0 Thor Cutler, OCE -082 • U.S. Environmental Protection Agency, Region 10 1200 Sixth Ave. Suite 900 Seattle, WA 98101 Re: Update of Plugging and Abandonment Plan UIC Permit No. AK- 1I006 -A Union Oil Company of California Dear Mr. Cutler: UIC Permit No. AK- 1I006 -A authorized eight wells as candidate wells for Class I Non- hazardous operation. On May 13, 2011 Union Oil Company of California ( "Union ") received authorization to commence Class I injection activities in the Trading Bay Unit Dolly Varden Platform Well D -9RD. Enclosed is the updated Environmental Protection Agency (EPA) Form 7520 -14, Plugging and Abandonment Plan for D -9RD . This is submitted per Permit No. AK- 1I006 -A, Section F(4) and 40 CFR 144.62. Form 7520 -14 is being submitted before April of the year following authorization to commence well injection activities in compliance with Permit Section F(4)(b). Should you have any questions, please do not hesitate to contact Faye Sullivan at FayeSullivar achevron.com or 263 -7685. Regards, John Zager I Enclosure: US EPA Form 7520 -14 cc: Marc Bentley, ADEC Cathy Foerster, AOGCC John Barnes, Hilcorp Alaska, LLC 1 of 1 • • ' .. • • OMB No. 2040-0042 Approval Expires 12/31/2011 • United States Environmental Protection Agency Washington, DC 20460 PLUGGING AND ABANDONMENT PLAN Nalmanst__Address of .,_ Name and Address of Owner/Operator :Dolly Varden Platform, Union Oil Company of California; 52300 • i 'Union Oil Company of California; P.O. Box 196247; Anchorage, AK iNikiski Beach Road; Nikiski, Alaska 99635 ' ;99519-6247 State County Permit Number Locate Well and Outline Unit on Alaska i FR/A waters offshore iAK Section Plat - 640 Acres Surface Location Description N : ------ 1 En r---1 --: F'7" ' 4-1 I I I I I I se jig of,ne :1/4 of 1/4 of IS j 1/4 of Section !o J Township, n 1Range113 W1 _ — L_ 1 - - _J. - L_ 1 - Locate well in two directions from nearest lines of quarter section and drilling unit I I I I I I — — 1 - — — .1 — Surface ^- --- r — —L — Li._ __1_L._ Location frm (N/S)S i Line of quarter section r" 1 I I I I I 1 andij_us fL from (E/W)Lv.),±1 Line of quarter section. W E I I I 1 I I r---T---TYPE OF AUTHORIZATION WELL ACTIVITY __L-L1._ __l_LJ__ „..., Individual Permit 71 CLASS I I I I I 1 I D Area Permit 0 . CLASS 11 — — I — 1 . — — t - - I - 0 I - 0 Rule Brine Disposal fl Enhanced Recovery Number of Wells _ _1 --- C--- — i—Ht— in Hydrocarbon Storage 1 , i 1 ■ ------, r:1 CLASS III . S i Lease Name IADL 18729 I . I Well Number [API507332013100, D-9RD 1 ' - CASING AND TUBING RECORD AFTER PLUGGING METHOD OF EMPLACEMENT OF CEMENT PLUGS SIZE WT (LB/FT) TO BE PUT IN WELL (FT) TO BE LEFT IN WELL (FT) HOLE SIZE sr The Balance Method 'aril Ella4E—.1 r._ __ __________J ET89.L1111.17:71711 rbiEjiiiii Ei The Dump Bailer Method ! r ail= ILI .1 L________._____11221T _. i i.17.51_,...._...1 0 The Two-Plug Method . 7 E1i_7_7...7 1 11012.61_ _ j l8.5" CEMENTING TO PLUG AND ABANDON DATA: PLUG #1 PLUG #2 PLUG #3 PLUG #4 PLUG #5 PLUG #6 PLUG #7 Size of Hole or Pipe in which Plug Will Be Placed (inche 118.5" _:1 117.5": 7 1,17_ E_________:! Depth to Bottom of Tubing or Drill Pipe (ft ,c9166 ,:21 rflar 12 .7" ', 7_71 1 ------ _ r_ Sacks of Cement To Be Used (each plug) . - 113:::::1 ToTi,....._ I ,F113 fsT5157:17 E. " 1 r -- ,:_ ----- 1 Slurry Volume To Be Pumped (cu. ft) '315§ — 7 1 __, iiii 15S:= 19.67 -: i ____"7 ET 1 ----- __, -1 Calculated Top of Plug (ft) 1407. 3_621' --- "j i2436 _LI riff ____! ; 1 L _______j Measured Top of Plug (if tagged ft.) [9460:_ [5620' - 21 {271 Ll'i : r-- 2 - R ---- _ — _ - 1 E r ------ _ - _ --- i - Slurry INt. (Lb./Gal.) . Ii3-,--8------1 __ _ [ fi3T El__ I _ _] F.__ __i Type Cement or Other Material (Class III) • FG7ficat, i rG. Neat . 1 ro 1 _,g Nil j ! 1 {--__ ___ i LIST ALL OPEN HOLE AND/OR PERFORATED INTERVALS AND INTERVALS WHERE CASING WILL BE VARIED (if any) From To From To --./ ,-- ;,.._ ..j . r i -----' E --- --- -1 Estimated Cost to PlustWells 1 !$2,500,000.00 Certification I certify under the penalty of law that 1 have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false Information, including the possibility of fine and imprisonment. (Ref. 40 CFR 144.32) istarnaznd OffIctalTitta (plea se type ol:print) - __, SIgnatur Date Signed AltiLarf : ______I J ildate II 1 EPA Form 7620-1 (Rev. 12-08) • • Chevron John Zager Union Oil Company of California General Manager, Alaska 3800 Centerpoint Drive, Suite 100 idContinent/Alaska SBU Anchorage, AK 99503 Tel 907 263 7815 kv -QC50 Mobile 907 223 0128 Fax 907 263 7897 v %o—Oc Email jzager @chevron.com REC November 16, 2011 4�� a ®` _' - NOV 1 i : � f' UIC Manager 19 ss� Ci1 Thor Cutler, OCE -082 � VSk—c)co\---\ mcnorkge U.S. Environmental Protection Agency, Region 10 1200 Sixth Ave., Suite 900 Seattle, WA 98101 , ;� �k i Re: Amended Request for Permit Transfer: Underground Injection Control (UIC) Permit No. AK- 1I006 -A by Union Oil Company of California ( "Union ") to Hilcorp Alaska, LLC Dear UIC Manager: Please replace my letter dated November 15, 2011 requesting permit transfer of Underground Injection Control (UIC) Permit No. AK- 1I006 -A by Union Oil Company of California ( "Union ") to Hilcorp Alaska, LLC. Union Oil Company of California ( "Union ") has entered into an Asset Sale and Purchase Agreement dated July 1, 2011 to sell its interests in the Cook Inlet Area to Hilcorp Alaska, LLC, ( "Hilcorp ") with an anticipated closing scheduled on or about December 15, 2011, assuming certain regulatory approvals are received by December 1, and all other Closing conditions are met. The actual closing date may vary depending on how quickly certain regulatory approvals are processed. The transfer of Union's interest to Hilcorp is conditioned on the completion of the transaction ( "Closing ") pursuant to the Asset Sale and Purchase Agreement by and between Union and Hilcorp. Union and Hilcorp will advise you upon Closing that the transfer has become effective, and Hilcorp has taken over Union's interest and operations, including the above referenced UIC Permit No. AK- 1I006 -A. Should the Closing for any reason not occur, Union will advise you that it has retained its interest. Environmental Protection Agency (EPA) Form 7520 -7, Application to Transfer Permit, is enclosed. Eight wells are permitted as candidate wells for Class I operation under this permit. These eight wells are: Dolly Varden Platform wells D -9RD and D- 15RD2, Grayling Platform wells G -5RD and G -16, King Salmon wells K -11 and K- 24RD2, and Steelhead Platform wells M -27 and M -30. Currently, only D -9RD has received written authori7atinn from EPA Region 10 to commence Class I infection. An agreement memorializing the transfer of UIC Permit No. AK- 1I006 -A from Union to Hilcorp is also enclosed. 1 of 2 • • UIC Manager US Environmental Protection Agency November 16, 2011 Page 2 We appreciate your attention to this request and apologize for the inconvenience. Should you have any questions, please do not hesitate to contact Faye Sullivan at FayeSullivan th chevron.com or 263 -7685. Regards John ager Enclosures: US EPA Form 7520 -7 Agreement to Transfer UIC Permit No. AK- 1I006 -A cc: John A. Barnes, Hilcorp Alaska, LLC Marc Bentley, ADEC Cathy Foerster, AOGCC 2 of 2 • 41111 OMB No. 2040-0042 Approval Expires 12/3112011 United States Environmental Protection Agency 4 . 1 EPA Washington, DC 20460 Application To Transfer Permit Name and Address of Existing Permlttee Name and Address of Surface Owner Union Oil Company of California; P.O. 13ox 196247 State of Alaska, Department of Natural Resources Anchorage, AK 99519 -6247 550 West 7th Avenue, Ste. 800; Anchorage, AK 99501 State County Permit Number Locate Well and Outline Unit on Alaska NA -State waters offshore AK•11006 -A Section Plat • 640 Acres Surface Location Description l I I II I I j . Sc 114 of ne 114 of SW 1/4 of SW 1/4 of Section § Township $n Range 13w I — - I' 4 - - 4 - I- 4 - Locate well in two directions from nearest fines of quarter section and drilling unit I I I I I I r Surface - r 7�r I Location 754 fl;. frm IN/S) S Line of quarter section I I I I I ( 1 and 1 1181. from (E/W) w Line of quarter section. W j 1 11 I i i I i I Well Activity Well Status Type of Permit - ~t - - -4 -I- i - X Class l _ I TI I I r Tf I I I I K Operating Individual _ -_ _ _ _, r 7 _ __ Cla li Modification/Conversion _t5:_ Ares $ , Brine Disposal Number of Wells , _ " I- I Enhanced Recovery tC Proposed ( I I I I I I _ , Hydrocarbon Storage Class Ill Other Lease Number See Attached Weil Number See Attached Name(s) and Addresses) of New Owner(s) Name and Address of New Operator Hilcorp Alaska, LLC; 3800 Ccnterpoint Drive Suite 100; Hilcorp Alaska, LLC; 3800 Centerpoint Drive, Suite 100; Anchorage, AK 99503 -5826 Anchorage, AK 99503 Attach to this application a written agreement between the existing and new permittee containing a specific date for transfer of permit responsibility, coverage, and liability between them. The new permittee must show evidence of financial responsibility by the submission of a surety bond, or other adequate assurance, such as financial statements or other materials acceptable to the Director. Certification I certify under the penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals Immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. (Ref. 40 CFR 144.32) Name and Official Title (Please type or print) Signature Date Signed John "Lager, General Manager 11/15/2011 EPA Form 7520 -7 (Rev, 12-08) • • Attachment to Form 7520 -7, Application to Transfer Permit One well is fully authorized for operation as a Class I well. An additional 7 wells are proposed candidate wells, but are not fully authorized for operation as Class I wells. The location map and surface well location shown on the front page of EPA Form 7520 -7 illustrates the location of the 1 authorized and operating Class I well. Well information for each of the 8 permitted wells is included on this page. Well API No. Lease Feet from Section Seward Meridian Line (Surface location) Sec Twp Range Authorized Well D -9RD 50- 733 - 20131 -01 -00 ADL 018729 756 FSL/ 1138 FWL 6 8N 13W Permitted wells M -27 50- 733 - 20423 -00 -00 ADL 018730 974 FNL/ 531 FWL 33 9N 13W M -30 50- 733 - 20430 -00 -00 ADL 017594 967 FNL/ 520 FWL 33 9N 13W G -5RD 50- 733 - 20162 -01 -00 ADL 018730 1.838 FNL/ 1487 FEL 29 9N 13W 6-16 50- 733 - 20060 -00 -00 ADL 017594 1879 FSL/ 1381 FEL 29 9N 13W K -11 50- 733 - 20148 -00 -00 ADL 017594 617 FSL/ 131 FEL 17 9N 13W K -24 RD2 50-733-20330-01-00 ADL 018730 733 FSL/ 131 FEL 17 9N 13W D -15 RD2 50 -733- 20159 -02 -00 ADL 018729 754 FSL/ 1130 FWL 6 8N 13W FSL = Feet from south line of quarter section (feet south section line) FNL= Feet from north line of quarter section FWL= Feet from west line of quarter section FEL= Feet from east line of quarter section • • Agreement to Transfer UIC Permit No. AK- 1I006 -A This Agreement to Transfer UIC Permit No. AK- 11006 -A ( "Agreement ") is made the 15 day of November, 2011 between Union Oil Company of California, a California corporation ( "Union "), and Hilcorp Alaska, LLC., a Delaware limited liability company ( "Hilcorp "), collectively referred to as the "Parties," or individually as a "Party." RECITALS WHEREAS, Union and Hilcorp have executed an Asset Sale and Purchase Agreement dated effective as of July 1, 2011, ( "ASPA ") whereby Union agreed to sell its therein described interests in the Cook Inlet Area to Hilcorp; and WHEREAS, Union's interests in the Cook Inlet Area include UIC Permit No. AK- 1I006 -A; and WHEREAS, Union wishes to effect the transfer of that permit to Hilcorp as authorized by regulation promulgated by the Environmental Protection Agency ( "EPA ") at 40 CFR § 144.38(b); and WHEREAS, the EPA requires a written agreement between Union and Hilcorp containing the specific date for transfer of permit responsibility, coverage and liability between them. 1 Agreement to Transfer UIC Permit No. AK- 1I006 -A • • AGREEMENT NOW, THEREFORE, in consideration of each Party's intent to consummate the closing of the ASPA, and for such other consideration the receipt and sufficiency of which is hereby acknowledged, the Parties agree as follows: 1. In the absence of notification to the Parties by the Director of EPA of the Director's intent to modify or revoke and reissue the permit, then effective as of the date of closing of the transaction contemplated by the aforementioned ASPA (the "Closing "), which Closing is projected to occur on or about December 15, 2011, subject to certain regulatory approvals being received by December 1, 2011 and all other Closing conditions being met, Union transfers and assigns to Hilcorp, and Hilcorp agrees to accept and assume, all of Union's rights, responsibilities, and liabilities under UIC Permit No. AK- 1I006 -A. The specific date for transfer of permit responsibility from Union to Hilcorp for this permit will be on the actual Closing date, which is anticipated on December 15, 2011, but may be later depending on when Closing actually occurs. 2. Should the Closing u o tng not occur for whatever reason, the Parties agree that Union shall retain all of its rights, responsibilities, and liabilities under UIC Permit No. AK- 1I006 -A, and Hilcorp shall have no rights, responsibilities, or liabilities under the permit. 3. In the event that the Director of EPA notifies the Parties of the Director's intent to modify or revoke and reissue the permit, then, assuming the Closing will nevertheless occur, Union shall undertake commercially reasonable efforts to cooperate with Hilcorp should it 2 Agreement to Transfer UIC Permit No. AK -I I006 -A • choose to engage with EPA while the Director works to modify or revoke and reissue the permit. 4. Notices shall be made as follows: Union: Steve Wright Asset Development Manager 3800 Centerpoint, Dr., Suite 100 Anchorage, AK 99503 (907) 263 -7865 sswr @chevron.com Hilcorp: John Barnes Senior Vice President Exploration and Production - Alaska 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 (907) 263 -7739 5. This Agreement may only be amended by written agreement signed by a duly authorized representative of each Party. 6. Except as set forth herein, this Agreement shall be binding only upon, and inure only to the benefit of, the Parties and their respective successors and assigns. No Party shall assign its rights or benefits under this Agreement without the prior written consent of the other Party. 7. This Agreement shall be governed by the laws of the state of Texas. 3 Agreement to Transfer UIC Permit No. AK- 11006 -A • • 8. The Parties have jointly drafted this Agreement, and this Agreement shall not be interpreted against or in favor of either of the Parties on the ground that any Party participated in drafting this Agreement. 9. This Agreement constitutes the entire agreement and understanding of the Parties with respect to the matters addressed herein. 10. In the event that there is any conflict between terms and conditions of this Agreement and the ASPA, the terms and conditions of the ASPA shall prevail. 11. No Party or representative, agent, or attorney for a Party has made any representation or warranty to influence the execution of this Agreement that is not expressly contained in this Agreement. 12. This Agreement may be executed in counterparts, all of which • together shall constitute one and the same instrument. 13. By execution of this Agreement, each of the Parties hereto represents and warrants that they have the corporate power and authority to execute and deliver this Agreement and that each of the Parties has the power and authority to make and carry out its obligations hereunder. WHEREFORE, this Agreement shall become fully enforceable and effective in all respects on the latter of the two dates appearing below. 4 Agreement to Transfer U1C Permit No. AK- 1I006 -A • • Union Oil Company of California, Hilcorp Alaska, LLC, a a California corporation Delaware limited liability company By: _ ii By: .4:Lift � --�-- Name: `o 14 z^ r Name: ..la Its: — ., £iZ�1G° y r' -ir - c < Its: 1 pp Date: .r �� 4lr�'d, � � ac. Date: AVflJ IS 2 -o 1 1 i 5 Agreement to Transfer MC Permit No. AK- 11006 -A l Chevron John Zager Union 011 Company of California %SO General Manager 3800 Centerpoint Drive Suite 100 Anchorage, AK 99503 Tel 907 263 7815 Fax 907 263 7693 Email jzager@chevron.com October 28, 2011 IV D UIC Manager, Groundwater Protection Unit OCT 3 1 2011 U.S. Environmental Protection Agency � & Cie ° Ca 1200 Sixth Avenue, Suite 900, OCE -082 ,; Seattle, WA 98101 Anatomic RETURN RECEIPT REQUESTED - CERTIFIED MAIL 7006 3450 0000 0081 4459 Re: Underground Injection Control Permit: Class! Permit Number AK-1 1006-A State of Alaska Permit Number 2010DB0001 Cook Inlet, Alaska, Trading Bay Unit, Dolly Varden Platform Well D -9RD 3nd Quarter 2011 Injection Well Monitoring Report l oc6 o Dear UIC Manager: Union Oil Company of California ( "Union ") operates the Dolly Varden Platform that injects regulated fluids under Underground Injection Control (UIC) Permit: Class I Permit Number AK- 11006 -A. Pursuant to condition Part 2, E.1 of the Permit, Union is hereby submitting the third quarter (July, August, and September) 2011 Injection Well Monitoring Report for the Dolly Varden Platform Well D -9RD. During the injection reporting period only filtered Cook Inlet water for Enhanced Oil Recovery from the Dolly Varden Platform oil and gas operations has been discharged to Well D -9RD. No wastes were brought to the Dolly Varden Platform from other UOCC facilities for the purpose of injection in Well D -9RD. An electronic copy of the daily monitoring data is included as Attachment 1 along with data comments and graph of daily injection pressure and rates. No significant maintenance or integrity tests have been performed during the reporting period starting July 1, 2011. Consistent with the approval to commence Class I injection activities by the EPA dated May 13, 2011, this letter certifies the Injection Well Monitoring Report attached to this letter. If you have any questions, please direct them to Hal Martin at 907 - 263 -7675 or via e-mail at gretchen.stoddard@chevron.com • • UIC Manager US Environmental Protection Agency October 28, 2011 Page 2 I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. Best regards, Joh Zager Enclosure: Form 7520 -8 Attachment 1: Additional Detail and Comments to Form 7520 -8 D -9RD Daily Injection Graph Compact Disc with Electronic Excel Data File cc: Marc Bentley, ADEC Cathy Foerster, AOGCC / Certified Mail 7006 3450 0000 0081 4930 Gretchen Stoddard, UOCC Hal Martin, UOCC Faye Sullivan, UOCC • • OMB No. 20400042 Approval Expires 12/31/2011 United States Environmental Protection Agency &EP „ Washington, DC 20460 Injection Well Monitoring Report Year 2011 Month Month Month Injection Pressure (PSI) July August September 1. Minimum 0 0 0 2. Average 0 940 2045 3. Maximum 0 3450 3440 injection Rate (GalMMin) July August September 1. Minimum 0 0 0 2. Average 0 13 31 3. Maximum 0 53 57 Annular Pressure (PSI) July August September 1. Minimum 500 20 120 2. Average 830 426 245 3. Maximum 1060 590 440 Injection Volume (Gal) July August September 1. Monthly Total 0 558306 1331652 2. Yearly Cumulative 1902222 2460528 3792180 Temperature (F •) July August September 1. Minimum N/A 65 66 2. Average N/A 70.5 74.8 3. Maximum N/A 76 81 p11 July August September 1, Minimum N/A 7.5 7.3 2. Averee• N/A 7.7 7.6 3. Maximum N/A 7.9 7.9 Other Name and Address of Pennines Permit Number Union Oil Company of California, 3800 Centerpoint Drive, Suite 100, Anchorage, AK 99503 AK 1I006 -A Name and Official Title (Please type or prinl) Signature Date Signed John Zager, General Manager EPA Form 752041 (Rev. 12 -06) • . • Attachment 1: Additional Detail and Comments to From 7520 -8 D -9RD Daily Injection Values 3rd Quarter 2011 7 „ cnm. c sg Date Hours On Daily Rate I bg Press Volume 1 Tess BPD Bbis psi psi 7/1/2011 0 0 0 0 1,040 7/2/2011 0 0 0 0 1,050 7/3/2011 0 0 0 0 1,040 7/4/2011 0 0 0 0 1,040 7/5/2011 0 0 0 0 1,050 7/6/2011 0 0 0 0 1,060 7/7/2011 0 0 0 0 1,060 7/8/2011 0 0 0 0 1,040 7/9/2011 0 0 0 0 1,040 7/10/2011 0 0 0 0 1,040 7/11/2011 0 0 0 0 1,040 7/12/2011 0 0 0 0 1,040 7/13/2011 0 0 0 0 1,040 7/14/2011 0 0 0 0 1,040 7/15/2011 0 0 0 0 1,040 7/16/2011 0 0 0 0 1,040 7/17/2011 0 0 0 0 1,040 7/18/2011 0 0 0 0 1,040 7/19/2011 0 0 0 0 500 7/20/2011 0 0 0 0 510 7/21/2011 0 0 0 0 520 7/22/2011 0 0 0 0 520 7/23/2011 0 0 0 0 530 7/24/2011 0 0 0 0 540 7/25/2011 0 0 0 0 540 7/26/2011 0 0 0 0 540 7/27/2011 0 0 0 0 545 7/28/2011 0 0 0 0 550 7/29/2011 0 0 0 0 550 7/30/2011 0 0 0 0 550 7/31/2011 0 0 0 0 550 8/1/2011 0 0 0 0 550 8/2/2011 0 0 0 0 ' 560 8/3/2011 0 0 0 0 560 8/4/2011 0 0 0 0 560 8/5/2011 0 0 0 0 560 8/6/2011 0 0 0 0 560 8/7/2011 0 0 0 0 565 8/8/2011 0 0 0 0 565 8/9/2011 0 0 0 0 560 8/10/2011 0 0 0 0 570 8/11/2011 0 0 0 0 570 8/12/2011 0 0 0 0 580 8/13/2011 0 0 0 0 580 8/14/2011 0 0 0 0 580 8/15/2011 0 0 0 0 580 8/16/2011 0 0 0 0 585 • • D -9RD Daily Injection Values 3rd Quarter 2011 7" m. s ° Date !lours On Daily Rate I hg Press Volume Press 8/17/2011 0 0 0 0 590 8/18/2011 0 0 0 0 590 8/19/2011 0 0 0 0 590 8/20/2011 0 0 0 0 590 8/21/2011 0 0 0 0 590 8/22/2011 6 699 699 3,350 110 8/23/2011 14 1,778 2,477 550 250 8/24/2011 21 1,033 3,510 2,900 20 8/25/2011 24 1,136 4,646 2,850 20 8/26/2011 24 1,138 5,784 2,850 20 8/27/2011 20 1,152 6,936 3,300 126 8/28/2011 24 1,730 8,666 3,200 170 8/29/2011 24 1,724 10,390 3,250 160 8/30/2011 24 1,832 12,222 3,450 150 8/31/2011 14 1,071 13,293 3,450 150 9/1/2011 6 739 14,032 3,330 200 9/2/2011 24 1,962 15,994 3,440 120 9/3/2011 24 1,947 17,941 3,400 180 9/4/2011 24 1,942 19,883 3,400 150 9/5/2011 24 1,954 21,837 3,360 140 9/6/2011 24 1,272 23,109 2,700 220 9/7/2011 24 1,279 24,388 3,200 160 9/8/2011 24 1,964 26,352 3,350 170 9/9/2011 24 1,968 28,320 3,375 200 9/10/2011 24 1,952 30,272 3,375 200 9/11/2011 24 1,941 32,213 3,400 230 9/12/2011 24 1,440 33,653 2,900 350 9/13/2011 24 1,147 34,800 2,900 440 9/14/2011 24 1,582 36,382 3,250 260 9/15/2011 24 1,456 37,838 2,875 280 9/16/2011 24 1,379 39,217 3,200 275 9/17/2011 24 1,792 41,009 3,300 250 9/18/2011 24 1,790 42,799 3,300 250 9/19/2011 24 1,763 44,562 3,300 250 9/20/2011 6 437 44,999 0 350 9/21/2011 0 0 44,999 0 280 9/22/2011 0 0 44,999 0 280 9/23/2011 0 0 44,999 0 220 9/24/2011 0 0 44,999 0 238 9/25/2011 0 0 44,999 0 270 9/26/2011 0 0 44,999 0 240 9/27/2011 0 0 44,999 0 280 9/28/2011 0 0 44,999 0 290 9/29/2011 0 0 44,999 0 295 9/30/2011 0 0 44,999 0 295 • • D -9RD Daily Injection Values 3rd Quarter 2011 7" Cr Cs Date hours On Daily Rate I hg Press Volume Press • g nj. nnu ar Daily Rate Press. Press Temp. July (GPM) si si 1F2 PH Minimum 0 0 500 N/A N/A Average 0 0 830 N/A N/A Maximum 0 0 1,060 N/A N/A Bbls Gallons Monthly Cumulative Volume 0 0 l bg In). Annular Daily Rate Press. Press Temp. August (GPM) (psi) fob u PH Minimum 0 0 20 65 7.5 Average 13 940 426 70.5 7.7 Maximum 53 3,450 590 76 7.9 Bbls Gallons Monthly Cumulative Volume 13,293 558,306 Tbg Ind. Annular Daily Rate Press. Press Temp. September (GPM) (psi) fpg u PH Minimum 0 0 120 66 7.3 Average 31 2,045 245 74.8 7.6 Maximum 57 3,440 440 81 7.9 Bbls Gallons Monthly Cumulative Volume 31,706 1,331,652 Gallons 1st Qtr 2011 Cumulative Injection Volume 0 2nd Qtr 2011 Cumulative Injection Volume 1,902,222 3rd Qtr 2011 Cumulative Injection Volume 1,889,958 4th Qtr 2011 Cumulative Injection Volume 2011 Cumulative Injection Volume 3,792,180 Comments for 3rd Quarter 2011 A. 7/1/11 - 8/21/11 -- Well remained shut -in until continuous rate and pressur monitoring installed. B. 7/19/11 -- Since well shut -in, bled fluid off of 7" casing and reduced pressure from 1040 psi to 500 psi. C. 8/27/11 -- Intentionally added fluid to increase pressure on 7" casing to bettE monitor changes in pressure. D. 9/20/11 -- Well shut -in due to combination of source water pump failure, divt work around platform, and waterflood surface piping upgrade: 4 D -9RD Daily Injection Graph Last Update: 9/30/2011 3,500 —o._ -- i 168 - + -__ +- .a 3,000 - 144 H — — . ._ I .. _ —� m i — - d _ -,- 9/20 - 30/11 -- 120 • 2 500 f— ! co Well shut -in ✓ 7/1/11- 8/21/11 -- Well remained shut -in until continuous rate and pressure monitoring + due to i-- installed. i combination of • ra 2,000 —i- ' source water 96 c y I i -- ■ —. p um p a. failure, 1 — dive work e CO d 7/19/11 - -Since well l III la , ill around 72 C a) 1,500 - E-- - - - -• - shut -in, bled fluid off of — 8/27/11 -- Intentionally - platform, and 7" c and reduced added fluid to increase i ' � waterflood - - I ' ■, ' — d pressure from 1040 psi pressure on 7" casing to to 500 psi. better monitor changes I 1 surface piping m 1,000 I' { _ - 48 1. / 1----4 - in pr essure. .• ce - _ . II , 24 t - • 500 — — 1 1 1 0 T - 0 7/1/11 7/8/11 7/15/11 7/22/11 7/29/11 8/5/11 8/12/11 8/19/11 8/26/11 9/2/11 9/9/11 9/16/11 9/23/11 9/30/11 — Injection Rate (BPD) — Tubing Press (psi) —7" Csg Press (psi) —Hours On 1 • 1 O: \NAU \MCBUWIaska \Deets \HES \Environmental \Waste \UIC \EPA Injection Well Monitoring Reports\ 2011 \3Q\ attachments \D- 9RD_DailyValues_3rd_Qtr_2011 (3).xlsx • • Chevron s ��, ! � " ; v D John Zager Union Oil Company of California General Manager 3800 Centerpoint Drive 9 d r `; ° Suite 100 Anchorage, AK 99503 Tel 907 263 7815 iit iL1 Gil a %fir' Coif' . C io: €Fission Fax 907 263 7693 Email jzager @chevron.com July 28, 2011 UIC Manager, Groundwater Protection Unit U.S. Environmental Protection Agency 1200 Sixth Avenue, Suite 900, OCE -082 Seattle, WA 98101 RETURN RECEIPT REQUESTED - CERTIFIED MAIL 91 7199 9991 7030 0644 1364 Re: Underground Injection Control Permit: Class I Permit Number AK- 11006 -A State of Alaska Permit Number 2010DB0001 Cook Inlet, Alaska, Trading Bay Unit, DoIIy Varden Platform Well D -9RD `I\ , . � -0 2 " Quarter 2011 Injection Well Monitoring Report Dear UIC Manager: �'l cs ��tv��cc \- Union Oil Company of California ( "Union ") operates the Dolly Varden Platform that injects regulated fluids under Underground Injection Control (UIC) Permit: Class I Permit Number AK- 11006-A. Pursuant to condition Part 2, E.1 of the Permit, Union is hereby submitting the second quarter (April, May, and June) 2011 Injection Well Monitoring Report for the Dolly Varden Platform Well D -9RD. During the injection reporting period only filtered Cook Inlet water for Enhanced Oil Recovery from the Dolly Varden Platform oil and gas operations has been discharged to Well D -9RD. No wastes were brought to the Dolly Varden Platform from other UOCC facilities for the purpose of injection in Well D -9RD. An electronic copy of the daily monitoring data is included as Attachment 1 along with data comments and graph of daily injection pressure and rates. No significant maintenance or integrity tests have been performed during the reporting period starting May 13, 2011. Consistent with the approval to commence Class I injection activities by the EPA dated May 13, 2011, this letter certifies the Injection Well Monitoring Report attached to this letter. If you have any questions, please direct them to Hal Martin at 907 - 263 -7364 or via e-mail at chris. holden com. aiit AUG 0 3 ZU11 • • UIC Manager US Environmental Protection Agency July 28, 2011 Page 2 I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false infora.a '•n, including the possibility of fine and imprisonment. Best regards, • n Zager Enclosure: Form 7520 -8 Attachment 1: Additional Detail and Comments to Form 7520 -8 D -9RD Daily Injection Graph Compact Disc with Electronic Excel Data File cc: Marc Bentley, ADEC Cathy Foerster, AOGCC. / Certified Mail 91 7199 9991 7030 0644 1371 Chris Holden, UOCC Hal Martin, UOCC Faye Sullivan, UOCC • • OMB No. 2040-0042 Approval Expires 12/31/2611 United States Environmental Protection Agency iSEP Washington, DC 20460 G /�+� injection Well Monitoring Report Year 2011 Month Month Month Injection Pressure (P0I) April May June 1. Minimum N/A 2550 0 2. Average N/A 2633 628 3. Maximum N/A 2760 2700 Injection Rate (Gal/Min) April May June 1. Minimum N/A 45 0 2. Average N/A 51 12 3. Maximum N/A 77 54 Annular Pressure (P0» April May June 1. Minimum N/A 210 420 2. Average N/A 432 866 3. Maximum N/A 540 1040 Injection Volume (Gal) April May June 1. Monthly Total N/A 1395030 '''t S c1 - 507192 +' cjor.. sit `t"t 2. Yearly Cumulative N/A 1395030 1902222 VI-to S i3A - k-5 Temperature (F •) April May June 2t2— 1. Minimum N/A 67 76 2. Average N/A 67 76 3. Maximum N/A 67 76 pH April May June 1. Minimum N/A N/A 5 2. Average N/A N/A 5 3. Maximum N/A N/A 5 Other Note 1) May is averaged from the authorization start date of May 13, 2011 I Note 2) See Attachment 1 for I additional comments • Name and Address of Pennines Permit Number Union Oil Company of California, 3800 Centerpoint Drive Suite 100, AK 99503 AK11006 -A Name and Official Title (Please type or print) Sign , i lM Date Signed John Zager, General Manager ( 1 74 0 EPA Form 15204 (Rev. 12.06) 1 I 4 • Attachment 1: Additional Detai Comments to Form 7520 -8 • • D -9RD Daily Injection Values - 2nd Quarter 2011 Date H ours Daily Cumulative. Tubing 7" Casing On Rate Volume Pressure Pressure BPD Bbls psi psi EPA Director authorizes injection of Class I fluids on 5/13/11 5/13/2011 24 2,105 2,105 2,760 210 5/14/2011 24 2,064 4,169 2,750 320 5/15/2011 19 1,588 5,757 2,750 320 5/16/2011 24 1,814 7,571 2,650 315 5/17/2011 24 1,898 9,469 2,700 320 5/18/2011 24 1,733 11,202 2,600 360 5/19/2011 24 1,561 12,763 2,650 420 5/20/2011 24 1,630 14,393 2,650 450 5/21/2011 24 1,672 16,065 2,600 460 5/22/2011 24 1,612 17,677 2,600 480 5/23/2011 24 1,548 19,225 2,550 540 5/24/2011 24 1,625 20,850 2,560 525 5/25/2011 24 1,685 22,535 2,600 515 5/26/2011 24 2,628 25,163 2,620 515 5/27/2011 22 1,585 26,748 2,620 540 5/28/2011 24 1,664 28,412 2,620 465 5/29/2011 24 1,639 30,051 2,600 460 5/30/2011 24 1,575 31,626 2,590 500 5/31/2011 24 1,589 33,215 2,560 500 6/1/2011 24 1,719 34,934 2,700 450 6/2/2011 24 1,790 36,724 2,650 450 6/3/2011 24 1,782 38,506 2,700 440 6/4/2011 24 1,850 40,356 2,700 420 6/5/2011 24 1,811 42,167 2,700 440 6/6/2011 17 1,786 43,953 2,700 440 6/7/2011 17 1,338 45,291 2,700 550 6/8/2011 0 0 45,291 0 800 6/9/2011 0 0 45,291 0 880 6/10/2011 0 0 45,291 0 920 6/11/2011 0 0 45,291 0 950 6/12/2011 0 0 45,291 0 970 6/13/2011 0 0 45,291 0 980 6/14/2011 0 0 45,291 0 980 6/15/2011 0 0 45,291 0 980 6/16/2011 0 0 45,291 0 1,000 6/17/2011 0 0 45,291 0 1,010 6/18/2011 0 0 45,291 0 1,010 6/19/2011 0 0 45,291 0 1,010 6/20/2011 0 0 45,291 0 1,010 6/21/2011 0 0 45,291 0 1,020 6/22/2011 0 0 45,291 0 1,010 6/23/2011 0 0 45,291 0 1,010 6/24/2011 0 0 45,291 0 1,020 6/25/2011 0 0 45,291 0 1,030 6/26/2011 0 0 45,291 0 1,040 6/27/2011 0 0 45,291 0 1,040 6/28/2011 0 0 45,291 0 1,040 6/29/2011 0 0 45,291 0 1,040 6/30/2011 0 0 45,291 0 1,040 1 of 2 • D -9RD Injection Data Summary - By Month Tubing Daily Injection Annular Rate Pressure Pressure Temp. April (GPM) f psi) (psi) (deg F) Minimum Average Not applicable - EPA Director authorizes injection of Class I fluids on 5/13/11 Maximum Bbls Gallons Monthly Cumulative Volume: Tubing Daily Injection Annular Rate Pressure Pressure Temp. May (GPM) (psi) (psi) (deg F) pH Minimum 45 2,550 210 67 Not measured Average 51 2,633 432 67 Not measured Maximum , 77 2,760 540 67 Not measured Bbls Gallons Monthly Cumulative Volume: 33,215 1,395,030 . Tubing Daily Injection Annular Rate Pressure Pressure Temp. June (GPM) (psi) f psi) (deg Fl pli Minimum 0 0 420 76 5 Average 12 628 866 76 5 Maximum 54 2,700 1,040 76 5 Bbls Gallons Monthly Cumulative Volume: 12,076 507,192 , I 2011 Gall 222 I Cumulative Injection Volume: 1,, Comments and Notes for 2nd Quarter 2011 A. 4/13/11 -- EPA witnessed MIT of well. Inner annulus pressured up to 2220 psi with well on injection and tubing pressure at 2725 psi. Passed test. B. 4/14/11 -- EPA witnessed slickline temperature survey of well to 10800 feet. C. 5/11/11 -- CVX mailed report of MIT test and temperature survey with attachments to EPA. D. 5/13/11 -- EPA Director authorizes injection of Class I fluids. E. 6/7/11 -- Informed that EPA authorized injection of Class I fluids. Since continuous monitoring of pressure and rate not yet installed on well, shut well in. Notes: Bbls - barrels (42 gallons) BPD = barrels per day EPA - (US) Environmental Protection Agency GPD = gallons per day GPM = gallons per minute MIT = mechanical integrity testing psi = pounds per square inch 2of 2 D -9RD Daily Injection Graph Last Update: 6/30/2011 30 4/13/11 -- EPA witnessed MIT of well. Inner annulus pressured up 6/7/11 -- Informed that EPA — to 2220 psi with well on injection and tubing pressure at 2725 psi. authorized injection of Class Passed test. I fluids. Since continuous x2,500 — 4/14/11 -- EPA witnessed slickline temperature survey of well to monitoring of pressure and 25 10800'. rate not yet installed on L _ 5/11/11 CVX mailed report of MIT test and temperature survey well, shut well in. a • with attachments to EPA. v 2,000 20 : 5/13/11 -- EPA Director authorize O d 1500 injection of Class I fluids. 15 L a 1,000 — 10 co m ' = 500 - 5 0 4/1/11 4/8/11 4/15/11 4/22/11 4/29/11 5/6/11 5/13/11 5/20/11 5/27/11 6/3/11 6/10/11 6/17/11 6/24/11 7/1/11 —Injection Rate (BPD) —Tubing Press (psi) 7" Csg Press (psi) —Hours On D -9RD Graph -- 2nd Qtr I., F • 7 ,„.. , . ,.. ,,...\. .,,.... k ' '..,,,, ., „.,... -,,,,,-,,,,, .;? Tc... k... .. i • j Z' _.. ,,,,,,,,,,,;',.:, „, At I Ztok" . ,:::- o f ..L.N Irni t r ‘Q 61.4 V • • C� _ SEAN PARNELL, GOVERNOR 555 Cordova Street Anchorage, Alaska 99501 Phone: (907) 269 -6258 Fax: (907) 269 -3487 DEPARTMENT OF ENVIRONMENTAL CONSERVATION www.dec.state.ak.us DIVISION OF WATER WASTEWATER DISCHARGE AUTHORIZATION PROGRAM June 22, 2011 DEC File No.: 2339.48.033 Dale Haines Unocal Chevron, Inc. 3800 Centerpoint Drive Anchorage, AK 99501 Re: Authorization 2010DB0001 -0002; Trading Bay Class I UIC Dear Mr. Haines: The Alaska Department of Environmental Conservation has completed its review of the Notice of Intent for the Trading Bay UIC and is issuing authorization 2010DB0001 -0002. The department has both an informal review process and a formal administrative appeal process for final permit decisions. An informal review request must be delivered within 15 days after receiving the department's decision to the Director of the Division of Water at the following address: Director, Division of Water Alaska Department of Environmental Conservation 555 Cordova Street Anchorage, AK 99501 -2617 Interested persons can review 18 AAC 15.185 for the procedures and substantive requirements regarding a request for an informal department review. See http: / /www.dec. state. ak .us /commish/ReviewGuidance.htm for information regarding appeals of department decisions. An adjudicatory hearing request must be delivered to the Commissioner of the department within 30 days of the permit decision or a decision issued under the informal review process, whichever is later. An adjudicatory hearing will be conducted by an administrative law judge in the Office of Administrative Hearings within the Department of Administration. A written request for an adjudicatory hearing shall be delivered to the Commissioner at the following address: • • Commissioner Alaska Department of Environmental Conservation 410 Willoughby Avenue, Suite 303 Juneau, AK 99811 -1 800 Interested persons can review 18 AAC 15.200 for the procedures and substantive requirements regarding a request for an adjudicatory hearing. See http: / /www.dec. state. ak.us /commish/ReviewGuidance.htm for information regarding appeals of department decisions. This authorization became effective on May 18, 2011 and expires at midnight on April 21, 2015. You must reapply for an authorization on or before January 21, 2015, 90 days prior to the expiration date. If you have any questions concerning this authorization, please contact Marc H. Bentley at 907.269.6287, marc.bentley(2i alaska.gov or Adele Fetter at 907.269.7235, adele.fetter@alaska.gov. Sincerely, Michelle Bonnet Section Manager Enclosure: Permit No. 2010DB0001 Authorization 2010DB0001 -0002 cc: Marc Bentley, DEC, Division of Water, Anchorage 'iDi» MRv�✓�E� AOGCC, Anchorage Thor Cutler, EPA, Seattle • STATE OF ALASKA DEPARTMENT OF ENVIRONMENTAL CONSERVATION Division of Water AUTHORIZATION NUMBER 2010DB0001 -0002 UNDER CLASS I INJECTION WELL DEC File Number: 2339.48.033 General Permit Number 2010DB0001 See this General Permit for additional permit requirements The following responsible party is authorized to discharge in accordance with the terms of general permit 2010DB0001, the information provided in the Notice of Intent, and any site specific requirements listed in this authorization: RESPONSIBLE PARTY: First Name: Bill Last Name: Haines Company: Union Oil Co. of California Phone Number: 907.263.7951 Mailing Address: 3800 Centerpoint Dr. , P.O. Box 196247 City: Anchorage State: Alaska Zip: 99501 Email: daleah @unocal.com ON SITE CONTACTS: Platform: First/Last Name: Phone Number: Dolly Varden Christy Anderson 907.776.6840 Mike Loomis Grayling Dave Owens 907.776.6630 John Liebenthal King Salmon Dave Myers 907.776.6691 Mark Farnsworth Steelhead Mike Chivers 907.776.6830 Chester Holt FACILITIES: NAICS Code: 213111 (Formerly the Standard Industrial code SIC: 1311) Facility Name: Dolly Varden Phone Number: 907.776.6840 Mailing Address: P.O. Box 8129 Fax Number: 907.776.6845 City: Nikiski State: Alaska Zip: 99635 NAICS Code: 213111 (Formerly the Standard Industrial code SIC: 1311) Facility Name: Grayling Phone Number: 907.776.6630 • • Mailing Address: P.O. Box 8129 Fax Number: 907.776.6635 City: Nikiski State: Alaska Zip: 99635 NAICS Code: 213111 (Formerly the Standard Industrial code SIC: 1311) Facility Name: King Salmon Phone Number: 907.776.6691 Mailing Address: P.O. Box 8129 Fax Number: 907.776.6695 City: Nikiski State: Alaska Zip: 99635 NAICS Code: 213111 (Formerly the Standard Industrial code SIC: 1311) Facility Name: Steelhead Phone Number: 907.776.6830 Mailing Address: P.O. Box 8129 Fax Number: 907.776.6835 City: Nikiski State: Alaska Zip: 99635 Physical Location: All Facilities Approximatley 8 miles NW of Nikiski, AK in upper western reach of Cook Inlet, Alaska. GENERAL DESCRIPTION OF THE PROJECT: The injected wastewater would consist mainly of camp wastewater, Class II exempt fluids incuding well treatment and work -over fluids, and possibly some limited disposal of drill cuttings and muds. When a platform is finally shut -in, wastes from vessel clean outs and other abandonment activities will also be injected in the well. Camp wastewaters include sanitary wastewater that primarily comes from the camp toilets. The raw stream will be treated at the platform's wastewater treatment plant to meet NPDES discharge specifications. When EOP injection ceases, this stream will be sent to the Class I disposal well. AUTHORIZED DATES OF DISCHARGE Beginning Date: May 18, 2011 Ending Date: April 21, 2015 EPA CLASS I INJECTION WELL PERMIT NUMBER: AK- 1I006 -A Beginning Date: April 22, 2010 Ending Date: October 18, 2015 ESTIMATED INJECTION FLOW RATES AND VOLUME: Average: 12,000 — 48,000 Gallons per Day Maximum: 15,750 — 63,000 Gallons per Day Estimated Total Discharge Volume: 5,670,000 — 29,043,000 Gallons over 5 years AUTHORIZED LOCATION OF DISPOSAL Area(s): Approximately 8 miles NW of Nikiski, AK in upper western reach of Cook Inlet, Alaska Injection will be limited to the existing Class II injection zone intervals mostly in the G- Zone/Lower Typnek and Hemlock Formations and Name of formation; depth(s): possibly the West foreland Formation. The injection zone extends from the base of the Coal 39 geologic marker (8946 ft. TVDss) to the base of the West Foreland Formation (10810 ft TVDss) with an oeverall thickness of approximately 1700 feet. Dolly Varden Platform Name of Wells: Grayling Platform King Salmon Platform Steelhead Platform • • Latitude /Longitude of Injection Point(s) in decimal degrees NAD 83 Dolly Varden 60.80778 - 151.64944 Grayling 60.83972 - 151.61306 Well King Salmon Latitude: 60 86528 Longitude: - 151.60583 Steelhead 60.84833 - 151.60194 ADDITIONAL SITE SPECIFIC PERMIT REQUIREMENTS UNDER THIS AUTHORIZATION: No condition of this permit is waived. Injected fluid is required to be reported on the annual report specifying the volume of drilling wastes, desalination wastewater, and sanitary and domestic wastewater, deck drainage /storm water, and miscellaneous non - hazardous wastes. The DEC Class I UIC Annual Report form is located at http: / /www.dec.state.ak.us /water /Compliance /permittee.htm or by requesting the form at dec-wqreporting@alaska.gov The current annual negotiated fee for this discharge type has been determined to be $275.00 per year. This fee amount was calculated in accordance with the negotiated fee section of the regulations (18 AAC 72.959) SIGNATURE: '14cLIZ 6 - ZZ 20.1 Si Date Michelle Bonnet Section Manager Printed Name Title • 0 � � �eo st17.. UNITED STATES ENVIRONMENTAL PROTECTION AGENCY r REGION 10 z :1 1200 Sixth Avenue, Suite 900 W.< z , Seattle, Washington 98101 -3140 4. ,<, '19- PROS6C�\o JUN - 6 201I OFFICE OF COMPLIANCE AND ENFORCEMENT Reply To: OCE 127 CERTIFIED MAIL -7009 0820 0001 6410 0581 RETURN RECEIPT REQUESTED Mr. Dale A. Haines _ Oil and Gas Operations Manager MidContinent/Alaska SBU Chevron North America Exploration and Production 3 800 Centerpoint Drive, Suite 100 d., / Anchorage, Alaska 99503 e.,, JUN Re: Underground Injection Control Program Class I Grind and Inject Permit AK- 1I006 -A ugliii 1%. ftr °�. , Approval of Revised Waste Analysis Plan 4nese t: "z►orr Trading Bay Unit, Cook Inlet, Alaska Dear Mr. Haines: The U.S. Environmental Protection Agency, Region 10 (EPA), has received and reviewed the Trading Bay Unit Class I Disposal Wells: Waste Analysis Plan (WAP) permit number AK1I006 -A submitted by Union Oil Company of California (a wholly owned subsidiary of Chevron Corporation) (Unocal) dated May 23, 2011. Based on the review of the WAP, EPA has determined the revised WAP fulfills requirements set forth in the permit as described in Part I E.9 (f) of the EPA permit. Therefore, EPA approves the Unocal WAP revised May 2011. Please note that this EPA permit expires on October 18, 2015, and that Unocal has to maintain compliance with all permit requirements under permit number AK- 1I006 -A for the well to continue as an active Class I injection well. ' The continued efforts of members of your staff in Anchorage to coordinate and complete these steps for the revised WAP approval are appreciated. If you should have any questions, please do not hesitate to contact Thor Cutler of my staff at 206 - 553 -1673. SincereL � I Edw.t�.' .. Kowalski Di :- or cc: Dan Seamount, AOGCC- Anchorage Office Shawn Stokes, ADEC- Anchorage Office Electronic Code of Federal Reguuons: • Page 1 of 2 Horne Pale > Executive Branch > Code of Federal Regulations > Electronic Code of Federal Regulations Electronic, Code of Federal,gesuiations TAI e -CFR Data is current as of April 1, 2011 Title 40: Protection of Environment PART 144 — UNDERGROUND INJECTION CONTROL PROGRAM Subpart A— General Provisions Browse Previous 1 Browse Next § 144.6 Classification of wells. Injection wells are classified as follows: (a) Class 1. (1) Wells used by generators of hazardous waste or owners or operators of hazardous waste management facilities to inject hazardous waste beneath the lowermost formation containing, within one - quarter mile of the well bore, an underground source of drinking water. (2) Other industrial and municipal disposal wells which inject fluids beneath the lowermost formation containing, within one quarter mile of the well bore, an underground source of drinking water. ho uSOvJ (3) Radioactive waste disposal wells which inject fluids below the lowermost formation containing an underground source of drinking water within one quarter mile of the well bore. (b) Class II. Wells which inject fluids: (1) Which are brought to the surface in connection with natural gas storage operations, or conventional oil or natural gas production and may be commingled with waste waters from gas plants which are an intergral part of production operations, unless those waters are classified as a hazardous waste at the time of injection. (2) For enhanced recovery of oil or natural gas; and (3) For storage of hydrocarbons which are liquid at standard temperature and pressure. (c) Class 111. Wells which inject for extraction of minerals including: (1) Mining of sulfur by the Frasch process; (2) In situ production of uranium or other metals; this category includes only in -situ production from ore bodies which have not been conventionally mined. Solution mining of conventional mines such as stopes leaching is included in Class V. (3) Solution mining of salts or potash. (d) Class IV. (1) Wells used by generators of hazardous waste or of radioactive waste, by owners or operators of hazardous waste management facilities, or by owners or operators of radioactive waste disposal sites to dispose of hazardous waste or radioactive waste into a formation which within one - quarter (1/4) mile of the well contains an underground source of drinking water. (2) Wells used by generators of hazardous waste or of radioactive waste, by owners or operators of http : / /ecfr. gpoaccess. gov /cgi /t /text /text -idx? c =ecfr; sid =91 fd2613 65 c2b 8 f8 fd699412 ece2 a81... 4/5/2011 Electronic Code of Federal Regu1 ns: Page 2 of 2 • hazardous waste management facilities, or by owners or operators of radioactive waste disposal sites to dispose of hazardous waste or radioactive waste above a formation which within one - quarter (1/4) mile of the well contains an underground source of drinking water. (3) Wells used by generators of hazardous waste or owners or operators of hazardous waste management facilities to dispose of hazardous waste, which cannot be classified under paragraph (a)(1) or (d) (1) and (2) of this section (e.g., wells used to dispose of hazardous waste into or above a formation which contains an aquifer which has been exempted pursuant to §146.04). (e) Class V. Injection wells not included in Class I, II, III, IV, or VI. Specific types of Class V injection wens are described in §144.81. (f) Class VI. Wells that are not experimental in nature that are used for geologic sequestration of carbon dioxide beneath the lowermost formation containing a USDW; or, wells used for geologic sequestration of carbon dioxide that have been granted a waiver of the injection depth requirements pursuant to requirements at §146.95 of this chapter; or, wells used for geologic sequestration of carbon dioxide that have received an expansion to the areal extent of an existing Class II enhanced oil recovery or enhanced gas recovery aquifer exemption pursuant to § §146.4 of this chapter and 144.7(d). [48 FR 14189, Apr. 1, 1983, as amended at 52 FR 20676, June 2, 1987; 64 FR 68565, Dec. 7, 1999; 75 FR 77287, Dec. 10, 2010] Browse Previous I Browse Next For questions or comments regarding e -CFR editorial content, features, or design, email ecfr @nara.gov. For questions concerning e-CFR programming and delivery issues, email webteam @gpo.gov. Section 508 / Accessibility http: / /ecfr. gpoaccess. gov /cgi /t /text /text -idx ?c =ecfr; sid =91 fd2613 65 c2b 8 f8 fd699412 ece2 a81... 4/5/2011 44 Chevron 3. Hal Martin Chevron North America Optimization Engineer Exploration and Production MidContinent/Alaska P.O. Box 196247 111100 Anchorage, AK 99519-6247 Tel 907 263 7675 Fax 907 263 7847 Email Hal.Martin @chevron.com rot oil t 0 -- May 11, 2011 RECEIVED Mr, Thor Cutler Environmental Protection Agency (Mailstop: OCE -127) (12 Floor) 1200 Sixth Avenue Seattle, WA 98101 j \ja;;i a Gil & C m nisslof6 MIT and Temperature Survey Report Well D -9RD (PTD 181 -080) Dolly Varden Platform Trading Bay Unit 1� McArthur River Field � \c Cook Inlet, Alaska \, L� Dear Mr. Cutler: As part of the UIC Permit (Permit No. AK- 11006 -A) requirements toward the conversion of Dolly Varden Platform Well D -9RD (PTD 181 -080), Trading Bay Unit, McArthur River Field to a Class I disposal well, Union Oil Company of California (Union Oil) submits the attached EPA Mechanical Integrity Test (MIT) form and temperature /pressure versus depth (MD and TVD) plots of the temperature survey. Also enclosed is a CD with the full data file and graphs for the temperature survey. On April 13 -14, 2011, Mr. Thor Cutler and Mr. Talib Syed were onsite at the Dolly Varden Platform to witness the initial MIT and temperature survey on Well D -9RD as described below. For the MIT, the 7" inner annulus required test pressure for Well D -9RD is 2217 psi. The annulus was checked to be full of filtered inlet water (FIW). The well was kept on waterflood injection at normal /stable conditions of 2250 BWPD with 2725 psi tubing pressure and pressure gradually applied with FIW to the 7" casing to increase it from 80 psi to 2220 psi. As evident by the attached MIT report, the well lost just under 2% of the pressure on the 7" casing after 30 minutes and an additional 15 minutes of monitoring resulted in no further pressure loss. The 9- 5/8" outer casing increased from an initial 258 psi to 352 psi when pressure was applied to the 7" casing and then lost 11 psi over the course of the 45 minute test. Union Oil's interpretation of the MIT is that the well demonstrates good integrity of the tested area between the wellhead, tubing, packer, and 7" casing. cc �c.s-5f - MidContinent/Alaska Chevron North America Exploration and Production www.chevron.com Mr. Thor Cutler Environmental Protection Agency May 11,2011 Page 2 For the temperature survey, Well D -9RD was shut -in 12 hours prior to the start of the survey. Tandem pressure and temperature memory gauges were run on slickline to 10800' at 60 FPM. After the slickline run, the data was downloaded from the tools and a temperature /pressure versus time plot was visually checked to verify that good data was captured by the gauges. Union Oil's interpretation of the temperature survey is that the injected FIW is contained within the approved injection interval. i (t) ,,., c__ _ l l-1 _� ` There are several anomalous temperature curve characteristics on the temperature survey plot of temperature vs. depth that are worth clarifying. 1. The gradual heating increase /decrease between the surface and about 2000' is � due to the heat from produced fluids from other wellbores affecting the '`e surrounding rock as these wellbores are in close proximity at shallow depths beneath the platform. 2. The +/- 5 degree variability of the temperature curve trend line is believed to be due to the different warming rates of the various formation rock types and fluids. 3. In the approved injection interval, the cooling of the formation is as expected due J to 67 degree FIW being injected into the well. Well D -9RD has been on waterflood injection since 1987 and has a cumulative injected volume of over 33 MMBW. Thank you for your consideration and if you have any questions regarding this, please contact me at 263 -7675. Sincerely, Wa-Z Hal Martin _ Attachments cc: Jim Regg, AOGCC Tom Maunder, AOGCC MldContinent /Alaska Chevron North America Exploration and Production www.chevron.com United States Environmental Protection Agency Region 10 '' 1200 Sixth Avenue, Suite 900 Seattle, WA 98101 Thor Cutler - (206) 553 -1673 a -mail: cutler.Lhor®epa.gov MECHANICAL INTEGRITY TEST (MIT) FORM Facility Wen 1 Permit No. PTD No. Chevron Dolly Varden D9-RD AKII006 -A y 81 -80 Injector I MIT Type I Test Type Test Date Class I T X IA Std Annular Pressure T e s t (SAPT) t( _3- a0 Req'd'Fest Fluid Type(s) used to Packer Depth (R, Pest Interval / Comments Pressure (psi) test 'I'VD) 2,217 psi N Matt 8.864" TV') One Year Cycle ((' M"att - 1,10NiN WeVt4 Record all Wellhead Pressures before and during Test. Note whether well is on injection or SI during test. If on injection, note injection rate, injection pressure and injection fluid temperature Note volume of diesel pumped in annulus during test. ✓ STAR) TIME: RECORDED PRESSURES (PSI) RESULT E x:00 am/ 01 PRE MIT INITIAL IS MIN 30 MIN 45 MIN 60 MIN P/F S TUBING Nikillimitori 0 740 F 7 r b � ■ T INNER ANNULUS FA ®�� riL OUTER ANNULUS 1 COMMENTS. ! = r T START TIME: RECORDED PRESSURES (PSI) RESUI:I' E PRE MIT INITIAL 15 MIN 30 MIN 45 MIN 66 MIN 8 TUBING PASS/ T INNER ANNULI'S FAIL OUTER ANNULUS 2 COMMENTS: T START TIME: RECORDED PRESSURES (PSI) RESULT E PRE Mrf INITIAL 15 MIN 30 MIN 45 MIN 60 MIN 8 TUBING PASS/ T INNER ANNULUS FAIL OUTER ANNULUS 3 COMMFNTS: tMISC C(MM:NTI8: O:Ipinsl cemp ben as a Hemlock ell en 312102. R.•eon:pleted as Hemlock Class 1I on 4126101. Added O-saw perk on 8I30 00. Pads O-zcne 0012 -10060 and Hemlock 10300 - 100317 140 Class I paint elteceve Oct 19.2006. NOTE: Pressure must show stabilizing tendency: I) Total pressure loss must be less than 10 % at and of 30 minute test 2) Pressure loss in lad 15 minutes must be Tess than 3314 oftotel loss Start MIT over if 1) Total loss exceeds 1014 2) Loss during last 15 minute period = or > S09L of tens during first 15 minute period Extend test duration to 60 minutes, If netxtssaty, to eliminate thermal effects (on -site decision per Inspector). 1— E-mdl this MIT Test Data Peru to EPA Regime 10 - Thor Cutler EPA Rep: AOGCC Rep: TdYb 8yed, P.EJ Thor Carter \ )..)0-\\)(2.3 'Chevron Oil Co. WeII:1D -9RD Varden 14 -14 -2011 I Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 0 1 000 — Pressure- Temperature Profile 1. Going in hole 10800' RKB 2. Well Shut -In 2000 3000 4000 d 5000 -0 6000 o. 7000 8000 9000 – i -- x 10000 • � f i 11000 50 60 70 80 90 100 110 120 130 140 Temperature (Deg. F) —Pressure — Perfs —13-3/8" 9 -5/8" 7" TBG 20" x PKR —Temperature Report date: 5/11/2011 'Chevron Oil Co. I WeII: -9RD I Field: IDolly Varden I4 -14 -2011 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 : I 1000 Pressure- Temperature Profile - -- 1 Going in hole TVD 2000 3000 - -- 4000 — N c is 5000 ' O. as G 6000 7000 8000 — ' x 9000 - 10000 J 1 50 60 70 80 90 100 110 120 130 140 Temperature (Deg. F) —Pressure – Perfs 13 -3/8" 9 -5/8" —7" —TBG —20" x PKR Temperature Report date: 5/11/2011 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaaCrralaska.aov; doa .aoacc.prudhoe.bav('alaska.aov: phoebe.brooksebalaska.aov: tom.maundernalaska.aov OPERATOR: Union Oil Company of California FIELD / UNIT / PAD: McArthur River Field / Trading Bay Unit / Dolly Varden DATE: 04/13/11 OPERATOR REP: Christy Anderson AOGCC REP: Witnessing Waived (J. Regg) Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well D-9RD Type Inj. W TVD 8,865' Tubing 2,725 2,725 2,740 2,740 2720 Interval O P.T.D. 1810800 Type test P Test psi 2216 Casing 80 2,200 2,200 2,180 2,180 P/F P Notes: 1 year MIT Cycle per EPA Class I regulations OA 258 352 345 343 341 Also witnessed by Thor Cutler & Talib Syed with EPA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F_ Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring 1= initial Test G = Gas P = Standard Pressure T e s t 4 = Four Year Cycle I = Industrial Wastewater R = Intemal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 (Revised 06/2010) MIT Dolly Varden D-9RD 04 -1311 (2).xls • • AlfEE n[L,R\SEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMI►IISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 April 11, 201,E CERTIFIED MAIL RETURN RECEIPT REQUESTED 7005 1160 0001 5753 9257 Ms. Sharon T. Sullivan Environmental Advisor Chevron North America Exploration and Production dba Union Oil Company of California (UNOCAL) PO Box 196247 ,PR 1 p Anchorage, Alaska 99519 Re: Trading Bay Unit Well D -09RD (181 -080) Class I Disposal Injection Dear Ms. Sullivan: In 2005, UNOCAL received approval from the Environmental Protection Agency (EPA) to convert to Class I wells two Class II enhanced recovery injection wells on each of the four Trading Bay Unit Platforms in Cook Inlet. The Alaska Oil and Gas Conservation Commission (Commission) recently received a copy of EPA's March 23, 2011 letter confirming UNOCAL's intent to conduct a mechanical integrity test prior to "Approval to commence Class I injection activities ..." While the EPA has primacy for Class I waste disposal activities, EPA approval of Class I injection does not authorize such injection. The approval does nothing more than establish the EPA's agreement that such injection does not violate the Safe Drinking Water Act. The only fluids authorized for injection are those authorized by Area Injection Order (AIO) 5 and Commissioner Johnston's June 7, 1994 letter. Injection of fluids other than those authorized by the Commission is a violation of the Commission's regulations and may also constitute waste. The Commission has no record of UNOCAL providing information to satisfy the requirements of 20 AAC 252 (c) (7) or 20 AAC 25.402 (c) (9). If UNOCAL intends to proceed with disposal injection, it must first request and obtain the Commission's approval for such injection. Any such request should include the following: 1) Information regarding the planned schedule for commencing Class I injection into TBU D -09RD. Trading Bay Unit Well D IA (181 - 080) • April 11, 2011 Page 2 of 2 2) Identification of the fluids intended for injection and when different fluids are planned to be injected. 3) Fluid- formation compatibility information as required by 20 AAC 252 (c) (7) and 20 AAC 25.402 (c). 4) Information regarding impacts to hydrocarbon recovery by initiating the proposed waste disposal and whether different fluids have different effects; If UNOCAL fails to comply with the Commission's regulations, the Commission reserves the right to pursue enforcement action as provided by 20 AAC 25.535. Sincerely, ai P9k- 4 -9 . AA.--' ' Cathy P. Foerster Commission cc: Edward T. Kowalski, EPA Shawn Stokes, ADEC Thor Cutler, EPA RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) I43 080 Sent: Monday, April 04, 2011 2:20 PM \ To: 'Anderson, Christy D' �� 1l � �� -�� Subject: RE: Dolly Varden MIT D -9RD If epa is going to be there I am waiving Commission witness Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 APR R 0'7 2,01' From: Anderson, Christy D [mailto:andercd @chevron.com] Sent: Monday, April 04, 2011 2:15 PM To: Regg, James B (DOA); Brooks, Phoebe L (DOA) Cc: Martin, J. Hal; Loomis, Jon M; Johnson, Wayne E; Myers, Chris S; Greenstein, Larry P Subject: Dolly Varden MIT D -9RD Jim The Dolly Varden is going to conduct an MIT on Well D -9RD for the US EPA on April 13 2011. This MIT is being conducted as a requirement to qualify Well D -9RD as a Class 1 disposal well from the current Class 11 waterflood injector. If the state would like a witness onboard please let me know. There is a noon helicopter scheduled on April 13 2011 with a seat available for a state witness if needed. Thanks Christy D. Anderson Lead Operator Dolly Varden Platform Phone 776 -6840 Fax 776 -6820 4/4/2011 • • J � c cEDS7 . UNITED STATES ENVIRONMENTAL PROTECTION AGENCY " ; REGION 10 1200 Sixth Avenue, Suite 900 ICS \ — V 16 1 4 y Q Seattle, Washington 98101 -3140 MAR 2 3 2011 OFFICE OF COMPLIANCE AND ENFORCEMENT Reply To: OCE 127 RECEI CERTIFIED MAIL - 7008 0150 0000 8075 9886 R %.. g 21311 RETURN RECEIPT REQUESTED o Mosta oil & Ges ° Ms. Sharon T. Sullivan %W MIS Environmental Advisor Chevron North America Exploration and Production stdaNNED MAR R lI 2011 P. O. Box 196247 Anchorage, Alaska 99519 -6247 Re: Initial Class I Mechanical Integrity Demonstration, Dolly Varden Well #D -9RD Notice of Intent to Inspect, Class I UIC Permit AK1I006 -A Dear Ms. Sullivan: This letter is in response to your letter dated March 16,2011, and confirmation of receipt of the U. S. Environmental Protection Agency (EPA) Form #7520 -9, Completion Form for injection wells. Per the Underground Injection Control Permit AK1I006 -A Part II C.1., EPA intends to inspect the facility as partial fulfillment of the permit requirements prior to commencing Class I injection activities. Approval to commence Class I injection activities shall be granted upon fulfillment of the Class I permit requirements including successful demonstration of mechanical integrity as described in Part II, C.3. and receipt of notice that such demonstration is satisfactory. If you should have any questions, please do not hesitate to contact Thor Cutler of my staff at 206 -553 -1673. Sincerel 0 Edward J. ' owalski Director • cc: Dan Seamount Alaska Oil and Gas Conservation Commission Shawn Stokes Alaska Department of Environmental Conservation • • MEMORANDUM State, Of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '~ ~ 1 ~ ~ (Z~ JC~ DATE: Tuesday, September 23, 2008 ~ P.I. Supervisor ~ ( SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA D-09 RD FROM: Lou Grimaldi TRADING BAY UNIT D-09RD Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~.I~'~'t- NON-CONFIDENTIAL Comm Well Name• TRADING BAY UNIT D-09RD Insp Num: mitLG080912101620 Rel Insp Num: APT Well Number: 50-73 3-20 1 3 1-0 1-00 Permit Number 181-080-0 ~ Inspector Name: Lou Grimaldi Inspection Date• 9/10/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well D-09RD 'I`yp@ Inj. ~ V/ TVD 8866 ~ IA 80 ~ 2360 ~~ 2310 230s P T lalosoo TypeTest I SPT Test psi j z36o pA ~ ass j sso ! sso sso i i Interval aYRTST P/F r Tubing , zs2s z8zs zszs I zazs I NOtes• Good test. WeII pressured up with water flood, checked before hand for fluid to surface in IA. Tuesday, September 23, 2008 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg Q c,l "2J P.I. Supervisor \,~tt I 1"104- DATE: Monday, September 13,2004 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA D-O9RD TRADING BAY UNIT D-O9RD FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~ Comm NON-CONFIDENTIAL Well Name: TRADING BAY UNIT D-09RD API Well Number: 50-733-20131-01-00 Inspector Name: Chuck Scheve Insp Num: mitCSO40908 I 64825 Permit Number: 181-080-0 Inspection Date: 9/312004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well D-O9RD Type Inj. s TVD 8866 IA 810 2300 2270 2260 P.T. 1810800 TypeTest SPT Test psi 2216.5 OA 285 380 380 380 Interval 4YRTST PIF p Tubing 2850 2850 2850 2850 Notes: Pretest pressures observed for 30+ minutes and found stable. Well demonstrated good mechanical integrity. Monday, September 13, 2004 Page I of I • • Maunder, Thomas E (DOA) From: Thomas Maunder [tom_maunder @admin.state.ak.us] Sent: Wednesday, April 21, 2004 12:05 PM To: Regg, James B (DOA) Cc: Crisp, John H (DOA) k \ -cjc Subject: Dolly Inspections - Jim and John, Last week John was out to Dolly and encountered some interesting requests with regard to MITs on D -9RD, D -16RD and D -22. I have looked at the files and offer the following. D -9RD appears to be a normal Class II FOR well. Last MIT was satisfactory and there is no indication of communication. Larry Greenstein's message has a comment that the "inspector is to determine the annulus test pressure ". I am not sure why this would be there. The operator should have the completion information to make the necessary calculation for the applied pressure. pp P D -16RD and D -22 have not been in service for about 20 years. The last information in the files are analyses I did in early 2003. The sundries had a note that by the end of 3rd Q 2003 that Unocal should make some determination of the future utility of these wells. I don't think we ever got anything from them. This "SI MIT" is a 6 day pressure observation to see how a small pressure change effect the monitored casing spaces. I guess since Unocal is now putting all their pressure information into a data gathering spreadsheet that they would like to present that information as proof of integrity. If that is what they would like to do, then it is appropriate for them to make a formal application to do so. These 2 wells are a couple of nearly 90 wells that Unocal lists on the SI well list. As I remember, they list nearly all wells as having future utility for sidetrack which may be true, however is probably wishful thinking. I think we should probably look at how we want these long term idled wells handled. I think we all know that unless absolutely necessary, Unocal is not disposed to make any investments to refurbish the wells or abandon them. Lets discuss at your convenience. Tom '.r APR 0 20i 1 STATE OF ALASKA ALASKA AND GAS CONSERVATION ( uOMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: Alter casing: Repair well: X Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: 106' KB' to MSL feet "3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247, Anchorage, Alaska Service: X Trading Bay Unit 4. Loc. ation of well at surface Leg A-2 Conductor 5, Dolly Varden Platform 8. Well number 756' FSL, 1139' FWL, Sect 6, T8N, R13W, SM D-9RD At top of productive interval 9. Permit number/approval number 1117' FNL,666' FEL, Sec 7, T8N, R13W, SM 81-80 At effective depth0RI INAL 10. APl number 1152' FNL, 527' FEL, Sec 7, T8N, R13W, SM 50-733-20131-01 At total depth 11. Field/Pool 1160' FNL, 514' FEL, Sec 7, T8N, R13W, SM Hemlock/G 12. Present well condition summary Total depth: measured 11,060' feet Plugs (measured) true vertical 10,189' feet Effective depth: measured 10,957' feet Junk (measured) Milled out Baker Model F-1 packer at 10,957' true vertical 10.090' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2,531' 13-3/8" 2,531' 2,406' Intermediate 5,721' 9-5/8" 5,721' 5,186' Production 10,995' 7" 1,150 sx 10,995' 10,127' Perforation depth: measured (See Attachment) true vertical , Tubing (size, grade, and measured depth) 3-1/2" L-80 EUE Mod 9.3 Ib/ff at 9,766'~.,~,,.~',,~'~'~"'~ Packers and SSSV (type and measured depth) Baker Model 84SAB40x32 Permanent packer set at 9,686' 13. Stimulation or cement squeeze summary intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Iniection Data OiI-BBL Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3950 140 3950 Subsequent to operation 4650 150 3800 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: Gas: Suspended: Service: Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed _ i _ Title: Drilling Manager Date: ## 136277 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Workover Summary Dolly Varden, Well No. D-9rd DAY 1 (2/18/00) RU APRS E-LINE UNIT. PRESSURE TEST LUBRICATOR 2,500 PSI. SWAB LEAKING. REMOVE AND REPLACE. RIH AND PUNCH TUBING FROM 10,085' TO 10,087'. GOOD INDICATION OF PUNCH. POOH. RD APRS. CIRC. TUBING AND ANNULUS TO 9.2PPG FIW W/KCL. 120 PSI ON TUBING AND ANNULUS. PUMP AN ADDITIONAL 90BBLS OF 9.2 FLUID. DAY 2 (2/19100) CONT. CIRC 9.2PPG FLUID. SHUT DOWN. MONITOR SI PRESSURES. 45 PSI ON ON TUBING AND ANNULUS. UNABLE TO BLEED OFF. INCREASE WEIGHT TO 9.5 PPG. CIRC. KWF THROUGH CHOKE UNTIL RETURNS AT 9.5 PPG. SHUT DOWN. MONITOR WELL. TUBING AND ANNULUS 0 PSI. SET BPV. NIPPLE DOWN TREE. NIPPLE UP BOPE. TEST BOPE 250PSI LOW / 3,000 PSI HIGH. WHITNESSE WAIVED BY AOGCC. PULL HANGER TO FLOOR. HANGER FREE W/80K. PULL SEALS FREE AT 120K. CBU. MONITOR WELL. LOSING FLUID AT 5.6BPH. DAY 3 (2/20/00) POOH WITH COMPLETION STRING. POWER FAILURE TO RIG. NO. 1 EMD GENERATOR EXCITER FROZE UP AND FAILED. SWITCH TO NO. 2 EMD POWER. CONT POOH. 100% RECOVERY OF COMPLETION. TUBING IN VERY GOOD SHAPE. TEST KELLY VALVES. MU PACKER MILLING BHA NO.1. RIH. MILL PACKER FROM 10,119'-10,120' DAY 4 (2/21/00) CONT. MILL PACKER 10,120 - 10,126'. WORK AND PULL PACKER LOOSE W/40K OVER. PUMP DRY JOB. POOH W/SEVERAL TIGHT SPOTS. TIGHT AT 5,464'. WORK THROUGH WITH 100K. CONT POOH. WORK THROUGH DV AT 3,488' UP TO 75K OVER. WORK THROUGH DV AT 2,608' W/UP TO 75K. RECOVER REMNANTS OF PAKER AND 7.45' SEAL BORE EXTENSION. MU BHA. RIH. SD EMD NO. 2 AND INSPECT. CONT. RIH. DAY 4 (2/22/00) CONT RIH to 10,958' ETD. POOH AND RU SCHLUMBERGER. RIH TO 10356'. PACKER UNABLE TO GO DEEPER.POOH AND MAKE UP CLEANOUT ASSY. DAY 5 (2/23/00) RIH TO 10,330'. REAM FROM 10,330' TO 10,553'. POOH AND MU PACKER. RIH AND SET PACKER AT 10,496'. RD SCHLUMBERGER. MU ISOLATION ASSY. ,- DAY 6 (2/24/00) RIH WITH STRADDLE ASSY T AND ATTEMPT TO STING INTO ISOLATION ASSY WITHOUT SUCCESS. POOH AND NOTED MULE SHOE BADLY MARKED. MU CLEANOUT ASSY WITH SEAL SUB AND RIH. DAY 7 (2/25100) CONTINUE RIH WITH CLEANOUT ASSY WITH SEAL SUB.TAG AT 10478'. UNABLE TO ENTER PACKER BORE. POOH AND PU PACKER MILLING ASSEMBLY. RIH AND MILL PACKER. DAY 8 (2/26100) MILL UP PACKER. (PACKER BORE FILLED WITH JUNK) PUSH PACKER TO BOTTOM AT 10,957'. SPOT DIESEL PILL ON BOTTOM AND POOH. MU PACKER ONE-LINE AND RIH. DAY 9 (2/27/00) RIH WITH PACKER ON E-LINE. UNABLE TO PASS 3,240'. RETRIEVE PACKER. RIH AND POOH LAYING DOWN DRILLPIPE. RUN COMPLETION. DAY 10 (2/28/00) CONTINUE RUNNING 3-1/2" COMPLETION TO 9767'. DISPLACE ANNULUS WITH 1% CRW- 132 CORROSION INHIBITOR IN 9.5 PPG KCL. FILL TUBING WITH CLEAN 9.5 PPG KCL. DROP PACKER SETTING BALL AND SET PACKER AT 9686'. LAND TUBING HANGER AND PT ANNULUS TO 2250 PSI- OK. RU SLICKLINE AND PULL BALL DART AND RHC PLUG. SET BPV AND ND BOPS. DAY 11 (2/29/00) CONTINUE ND BOP'S. PREPARE TO SKID RIG. RELEASED FROM WELL AT 00:00 HRS 29 BEBRUARY 2000. LJNOCAL Dolly Varden Well No. 9rd As Built RKB to TBG Head: 39,52' G-3 G-4 B-0 B-1 B-2 ---= B-3 -= B-3 B-4 B*5 PBTD = 10,957' TD = 11,060' MAX, HOLE ANGLE = 31'~ D-9rd As Built (6-6-00) CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20 Surf 633' 13 3/8" 61 J-55 Butt I2.515 Surf 2,53(/' 9-5/8" 40 N 80 Butt 8.835 Surf 4.754' 9 5/8' 43.5 N-g0 Butt 8.755 4.754' 5,721' 7" 29 N 80 Butt. 6.184 Surf 10,995' Tubing: 3 1/2" 9.2 L 80/N 80 8rd Mod tbg 2.992 Surf 9~766' JEWELRY DETAIE NO. ~ ID Item 1 39.52' 2.992" CiW DCB SS Hanger 3 1/2" 8rd Top x 3-!/2" CSCB Hydril Bottom 2 9.766' 2.992" 3 I/2" L 80/N 80 8rd Mod Butt robing 3 9.685' 3.00" Baker Anchor (80DA40) 4 9,686' 3.00" Anchor Seal Assembh with l' of nitrile seals 5 9,686' 4.00" Baker 84SAB40 Hxdraulic Set Packer with 5..58' Mill ()ut Extensi,.)n 6 9,733' 2,81Y' Baker 'X' Nipple (2.813-) 7 9,766' 2.992" VVireline Entr,/Guide (3 125") Fill cleaned out to PBTD 10957' 2-26-00 Baker F~I Packer milled and pushed 2-27-00 Zone Top Btm G-2 9,912' 9,926' 14 6 3/31/00 9,932' 9,946' 14 6 3/31/00 G-3 9,982' 10,004' 22 6 3/31/00 G-4 10,018~ 10,056' 38 6 3/30/00 B-0 10,300' 10,320' 20 16 3/1/82 B-1 10,370' 10,410' 40 4 1/24/86 B-2 10,435' 10,470' 35 4& 8 4/16/87 B-3 10,500' 10,520~ 20 9 1/9/85 B-3 10,550' 10,565' 15 4 1/9/85 B-4 10,585' 10,630' 45 4 1/9/85 B-4 10,642' 10,690' 48 4 1/9/85 B-5 10,725' 10,800' 75 4 4/16/87 PERFORATION DATA Accum Last Amt SPF Perf Date Present Condition Proposed Reperf Proposed Reperf DATE: 2/29/00 NM Dolly Varden D-9RD Perforations B-0 10,300'- 10,320' MD 9,451'-9,470' TVD B-1 10,370'-10,410' MD 9,519'-9,558' TVD B-2 10,435'-10,470' MD 9,583'-9,615' TVD B-3 10,500'- 10,520' MD 9,645'-9,664' TVD B-3 10,550'- 10,565' MD 9,694'-9,708' TVD B-4 10,585'- 10,630' MD 9,727'-9,771' TVD B-4 10,642'-10,690' MD 9,783'-9,829' TVD B-5 10,725'- 10,800' MD 9,862'-9,936' TVD B-5 10,810'-10,850' MD 9,946'-9,984' TVD G-2 9,912'-9,926' MD 9,079'-9,092' TVD G-2 9,932'-9,946' MD 9,098'-9,111' TVD G-3 9,982'- 10,004' MD 9,146'-9,167' TVD G-4 10,018'- 10,056' MD 9,180'-9,216' TVD MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Robert Christenson~ Chairman Blair Wondzell, P. I. Supervisor DATE: March 7, 2000 FROM: Lou Grimaldi, ~ SUBJECT: Petroleum InslSector Mechanical Integrity Test Trading Bay Unit NON-CONFIDENTIAL Tuesday, March 7, 2000: I witnessed the initial MIT on Unocal D-9RD in the Trading Bay Unit, McArthur River field. This well had been recently worked over and Doug Nienhaus (Unocal Drilling foreman) performed a pm-injection MIT during the completion phase of this wells workover. The wells MIT went good this evening and was performed during my stand-by time awaiting a upcoming initial BOP test on D-25RD. The wells MIT passed and should be approved to continue injection. SUMMARY: I witnessed the passing initial mechanical integrity test on Unocal well #D-9RD in the McArthur River field. NON-CONFIDENTIAL CC; Dwight Johnson (Unocal Kenai) Attachment: MIT TBU D-9 3-7-00 LG.xIs 1 MIT TBU D-9 3.%00 LG -- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: Unocal FIELD I UNn' / PAD: McArthur River Fie/d, Dolly Varden platform DATE: 3/7/00 w°, #: ~.~.D I ~ I ~ /~/o~ w~ - ~ COMMENTS: Z~ initial MIT s/nce rig recompleted. PTD: GOMM[~IS: I Iol 520 2,280 4,000 2,260 4,000 2,250 I I I 2000 II PTD: Well #: COMMENTS: PTD: I I I II Well #: COMMENTS: PTD: Well #: COMMENTS: I i I I I Iol I I I I I I TBG. INJ. FLUID CODES F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Distribution: odg - Well File c - Operator c - Database c - Trip Rpl File TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST OPERATOR REP SIGNATURE: Dave Kirkvliet MIT TBU D-9 3-7-00 LG ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. O. OO O. OO O. OO O. OO O. OO WELL TEST: Initial X 4 - Year Workover Other , AOGCC REP SIGNATURE: Louis R. Grimaldi (Rev 9/23/99) OPERATOR: Unocal STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test FIELD / UNIT / PAD: McArfhur P/vet F/e/d, Dolly Vc~rden p/affor~ DATE: $/7/0~ PTD: 181-080 Well #: D-9RD COMMENTS: PTD: Well #: COMMENTS: PTD: Well #: COMMENTS: PTD: Well #: COMMENTS: PTD: Well #: COMMENTS: Filtered- 8,866 Inlet wtr 9,687 Initial MIT since #g recompleted. 4,000 4,000 4,000 4,000 7", 29# 2217 520 2,280 2,260 2,250 ,I I I I'1 I I 2000 I Iol I I II TBG. INJ. FLUID CODES F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. O, OC WELL TEST: Initial X 4 - Year Workover Other Distribution: orig- Well File c - Operator c- Database c - Trip Rpt File c- Inspector OPERATOR REP SIGNATURE: Dave I~rkvliet , AOGCC REP SIGNATURE: MIT TBU D-9 3-7-00 LG.xls Louis R. Gdmaldi (Rev 9/23/99) Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7671 UNOCAL Dan Williamson Drilling Manager January 10, 2000 Mr. Robert Christensen Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Workover of Dolly Varden D-9RD Dear Mr Christensen: Unocal plans on working over the Dolly Varden Well D-9RD well in mid February 2000. The well is currently a Hemlock water injector. The objective of the well workover is to add G zone injection in the well to support withdrawals in the Southern nose area in light of the successful testing of the G zone in D-12RD this past Fall. Unocal plans pull the existing completion clean out the well, isolate Hemlock Bench 2 (Bench 2 is taking approximately 50 % of the water injection) adding Hemlock Benches 1 through 5 and returning the well to injection. Please contact the undersigned with any questions regarding this application. Drilling Manager RECEIVED dali 18 000 Al ffi& ds(m. lOn Aflchot"dgo O(~ STATE OF ALASKA ~j ALASKA AND GAS CONSERVATION MMISSION 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: Variance: Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of Califonia (UNOCAL) Development: 106' KB above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Trading Bay Unit P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: X 4. Location of well at surface Leg A-2, Conductor 5, Dolly Varden Platform 8. Well number 756' FSL, 1139' FWL, Sec 6, 8N, R13W, SM D-9RD At top of productive interval 9. Permit number 1117' FNL, 666' FEL, SecT, 8N, R13W, SM 81-80 At effective depth 10. APl number 1152', FNL, 527' FEL, Sec 7, 8N, R13W, SM 50-733-20131-01 At total depth 11. Field/Pool 1160', FNL, 514' FEL, Sec 7, 8N, R13W, SM Hemlock/G 12. Present well condition summary Total depth: true measured vertical 1 11,060' feet 0,189' feet Plugs(measured) 0R / G//V4L Effective depth: measured 10,907' feet Junk (measured) true vertical 10,090' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2,531' 13-3/8" 2,531' 2,406' Intermediate 5,721' 9-5/8" 5,721' 5,186' Production 10,995' 7" 1,150 sx 10,995' 10,127' Liner Perforation depth: measured (See attachment) [~t ]~' ~ ~ ] ~'¢ ~ ]J~]l true vertical Tubing (size, grade, and measured depth) 3-1/2" 9.2 Ib/ft N-80 at 10,184' u ~,~ ~"~ ~,, v v Packers and SSSV (type and measured depth) Otis WU Permanent Packer at 10,104' J~;~$ka 0ii & {~S C0r~$. Anch0ra§e 13. Attachments Description summary of proposal: X Detailed operations program: X BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 2/15/2000 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: Water Injector 17. I hereby~hat the/~re~Op is~.~ an~ correct to the best of my knowledge. Signed:~~ [/dV(] vJ.~__~. Title: Drilling Manage, Date: ~ vv FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No. Plug integrity BOP Test X Location clearance ] ._~0~) Mechanical Integrity Test ~. Subsequent form required 10- I~ (~ i.~ ORIGINAL SIGNED. BY Approved by order of the Commissioner Robert N. Chdstenson Commissioner Date / Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Dolly Varden D-9RD Perforations B-0 10300'-10320'MD 9451'-9470' TVD B-1 10370'-10410'MD 9519'-9558' TVD B-2 10435'-10470'MD 9583'-9615' TVD B-3 10500'-10520'MD 9645'-9664' TVD B-3 10550'-10565'MD 9694'-9708' TVD B-4 10585'-10630'MD 9727'-9771' TVD B-4 10642'-10690'MD 9783'-9829' TVD B-5 10725'-10800' MD 9862'-9936' TVD B-5 10810'-10850' MD 9946'-9984' TVD RECEIVED JAN 18 2000 Alael~ Oil & Gas Oons. Commim~n UNOCAL RKB to TBG Head -- 39.52' ?? DV at 3,486' and 2,604' Unable to close top DV. Sqz w/ 35 sx. SIZE 20 13-3/8" 61 9-5/8" 40 9-5/8" 43.5# 7" 29 Tubing: 3-1/2" 9.3 Dolly Varden Well No. 9rd Completed 4/87 9.2 CASING AND TUBING DETAIl, GRADE CONN ID TOP NO. Depth 1 39.52' 2 6,974' 3 7,757' 4 10,114.' 5 10,127' 10,128' 6 10,157' 7 10,158' Surf 633' J-55 Butt 12.515 Surf 2,530' N-80 Butt 8.835 Surf 4,754' N-80 Butt 8.755 4,754' 5,721' N-80 Butt. 6.184 Surf 11,043'? N-80, IPC CS Hydril. 2.992 Surf 6,977' N-80, IPC DSS-HTC 2.992 6,977' 7,760 N-80, IPC Hydril 501 2.992 7,760' 10,114' N-80 Buttress 2.992 10,127' 10,184' ID JEWELRY DETAIL Item CIW DCB SS Hanger, 3-1/2" EUE 8rd Lift x CS-CB Hydril Suspension Crossover, 3-1/2" CS-CB Box x 3-1/2" DSS-HTC Pin Crossover, 3-1/2" DSS-HTC Box x 3-1/2" Hydri1501 Pin Otis Locator, Seal Assembly. 12.24" Long Crossover, Otis 10 rd x 3-1/2" Buttress Pin 1 it. 3-1/2", 9.2#, N-80 Buttress SC Otis 'X' Nipple, Special Clearance 1 it. 3-1/2", 9.2#, N-80 Buttress SC "With half Mule Shoe" 10,100'ELM 4.00 Otis "WD" Permanent Packer with 7.45 Seal Bore Extension 3 B-O B-1 B-2 B-3 B-3 B-4 B-5 PBTD = 10,957' TD = 11,045' MAX. HOLE ANGLE = 31° D-9rd Draw II.doc Fill Tagged w/2.65 GR 12/21/96 ~ 10,807' SLM Zone Top Btm PERFORATION DATA Accum Last Amt SPF Perf Date Present Condition B-0 10,300' 10,320' B-1 10,370' 10,410' B-2 10,435' , 10,470' B-3 10,500' 10,520' B-3 10,550' 10,565' B-4 10,585' 10,630' B-4 10,642' 10,690' B-5 10,725' 10,800' B-5 10,810' 10,850' 20 16 3/1/82 40 4 1/24/86 35 4 & 8 4/16/87 20 9 1/9/85 15 4 1/9/85 45 4 1/9/85 48 4 1/9/85 75 4 4/16/87 40 4 4/16/87 Log shows perf 10' Deep! Covered with fill RECEIVED 18 t000 DATE: 11/17/99 TCB UNOCALe Dolly Varden Well No. 9rd Proposed RKB to TBG Head = 39.52' DV at 3,486' and 2,604' Unable to close top DV. Sqz w/ 35 sx. PBTD = 10,957' B-0 B-1 B-2 B-3 B-3 B-4 ----= B-5 \ TD = 1 t ,045' MAX. HOLE ANGLE = 31° D-9rd Proposed Draw II.doc CASING AND TUBING DETAH, SIZE WT GRADE CONN ID TOP BTM. 20 Surf 633' 13-3/8" 61 J-55 Butt 12.515 Surf 2,530' 9-5/8" 40 N-80 Butt 8.835 Surf 4,754' 9-5/8" 43.5# N-80 Butt 8.755 4,754' 5,721' 7" 29 N-80 Butt. 6.184 Surf 11,043'? Tubing: 3-I/2" 9.2 L-80 2.992 Surf 9,840' JEWELRY DETAH. NO. Depth ID Item 1 39.52' 2 9,840' 3 9,855' 4 9,870' 5 9,840' ELM CIW DCB SS Hanger Locator, Seal Assembly Otis 'X' Nipple, Special Clearance Wireline Entry Guide Baker Permanent Packer with Seal Bore Extension A 10,420 B C 10,485' Scab Liner Assembly Baker Packer 5", 15#, L-80, Scab Liner Baker Packer Fill Cleaned out to PBTD 10957' Zone Top Btm PERFORATION DATA Accum Last Amt SPF Perf Date Present Condition G-2 9,912' 9,926' 14 6 9,932' 9,946' 14 6 G-3 9,982' 10,004' 22 6 G-4 10,018' 10,056' 38 6 B-0 10,300' 10,320' 20 16 B-1 10,370' 10,410' 40 4 B-2 10,435' 10,470' 35 4 & 8 B-3 10,500' 10,520' 20 9 B-3 10,550' 10,565' 15 4 B-4 10,585' 10,630' 45 4 B-4 10,642' 10,690' 48 4 B-5 10,725' 10,800' 75 4 3/1/82 1/24/86 4/16/87 1/9/85 1/9/85 1/9/85 1/9/85 4/16/87 Proposed Proposed Proposed Proposed Proposed Repeff Proposed Repeff Proposed Scab RECEIVED dAli 18 2.000 011 a oon . Comm lon Anohor le DATE: 11/17/99 TCB 20' 18'-7" RIG FLOOR BOTTOM ROTARY TABLE BTM RT BEAM RISER I CHOKE 'U HYDRIL 13-5/8" OK 5M ANNULUR PREVENTER 17' CELLAR FLOOR DRILL DECK 17'-7" SHAFFER DOUBLE GATE BOP IKILL () T OP PIPE RAM ~ BLIND I 5M CROSSOVER SPOOL "-I i, GRATING !---.',' i~''~.!'.::.,~ RECEIVED ,JAN 18 2000 i DOLLY VARDEN PLATFORM CDDK. INLET, ALASKA CONTRACTOR (~(~l";,J I~, ,JC.)I~ NO. SDL ' ' ' .... DOLLY VARDEN PLATFORM .... BLOW OUT PREVENTER -., ~AWNa NO. · ~"" UNOCAL~ D-DV-01 5 ~^~ 1/30/98 · ,','='"' 1 OF 1 · Dolly D-gRd Summary of Operations Proposal 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 Install BPV ND Tree. NU Riser, Single Gate, DBL Gate, Hydril and valves. Install Two Way Check, Test Joint Test BOPE to 5,000 psi Pull Test Joint, Two Way Check RU to Pull Completion. MU LD Joint., Back Out Lock Down Screws. Work seals from Packer POOH Laying down 3-1/2" Tubing Mill and Retrieve Packer Clear Rig Floor. RU to PU 3-1/2" Drill Pipe. PU BHA No 1. Packer Milling Assembly RIH PU 3-1/2" Drill Pipe. (700'/hr) Mill 7" "WD" Permanent Packer at 10,104' POOH LD Milling Assembly PU Packer Fishing Assembly RIH to Top of fish at 10,900' Catch Fish. POOH. LD Fish and Fishing BHA. Clean Out Fill MU 6" Mill and Scraper Assembly. RIH to 10,807' Clean out fill from 10,807'-10,957' Circulate sweep and POOH Run Scab Liner Assembly RU E-Line. RIH and Set Permanent Packer. POOH with E-Line RD E-Line. MU Scab Liner Assembly and RIH Stab into Lower Packer, set Top Packer. POOH and LD Drill Pipe. RECEIVED JAN 18 000 · AnCl~orage 33 34 35 36 37 38 Run Completion PU Completion RIH with 3-1/2" Completion to 9,840' and set packer. MU Tubing Hanger - Land. Pressure test annulus LD Landing Joint, Set BPV Nipple down BOPE and release well to Production. RECEIVED ,JA~ 18 t000 Anchorage Marathon Oil Company August 11, 1987 Prod,uction United States RO. Box 102380 Anchorage, Alaska 99510 Telephone 907/561-5311 Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Wondzell: Pursuant to UIC regulations administered by the state of Alaska, mechanical integrity tests were successfully performed on four water injection wells during the second quarter workover program on the Dolly Varden Platform. The wells in the workover program included D-6RD, 9RD, 14RD, and 29RD. The results of the mechanical integrity test for all wells, except D-29RD, were included with the subsequent Sundry Notice on each well. This was omitted in error for Well D-29RD. A recap of the four mechanical integrity tests is as follows: The test was performed on Well D-29RD on March~,, 1987 The 9-5/8" 47#, N-80 casing and 7", 29#, N-80 liner were tested to s~si for 30 minutes with no detectable pressure loss. The AOGCCwaived~e right to witness the test. The test was performed on Well D-6RD on April 24, 1987. The 7", 29#, N-80 casing was tested to 2,500 psi for 30 minutes with no detectable loss of pressure. The AOGCC waived the right to witness the test. The test was performed on Well D-9RD on APril 30, 1987. The 7", 29#, N-80 casing was tested to 2,300 psi for 30 minutes with no detectable loss of pressure at surface. The AOGCC witnessed this test. RECEIVED AUG 1 ~ 1987 Alaska Oil & Gas Cons. Co~]~/sslo Anchorage , Mr. Blair Wondz~ August 11, 1987 Page 2 The test was performed on Well D-14RD on May 10, 1987. The 9-5/8", 40# and 43.5#, N-80 casing and 7", 29#, N-80 liner tested to 2,400 psi for 15 minutes with no detectable pressure loss. The AOGCC waived the right to witness the test. Should you have any further questions, please contact Paul Mazzolini at 564-6433. Sincerely, D. K. Corlett District Operations Engineer PEM/DKC/em/468/0E22 RECEIVED AUG 1 4 ]987 Alaska 011 & Gas Cons. Commission Anchorage STATE OF ALASKA ALA ., OIL AND GAS CONSERVATION COM ..,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate,~ Pull tubing [] Alter Casing [] Other [] 2. Name of Opera[or UNOCAL 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Location of well at surfaceLeg A-2, Cond. #5 Dolly Varden Platfo~ 756' FSL, 1,139' FWL, Sec. 6-8N-13W-SM At top of productive interval 1,117' FNL, 666' FEL, Sec. 7-8N-13W-SM At effective depth 1,152' FNL, 527' YEL, Sec. 7-8N-13W-SM At total depth 1,160' FNL, 514' FEL, Sec. 7-8N-13W-SM 5. Datum elevation (DF or KB) 106' ~B above MSL 6. Unit or Property name Trad~ n~ ~B~y Un~ 7. Well number D-9RD 8. Approval numper / 9. APl number 50-- 733-20131-01 10. Pool Hemlock Fe 11. Present well condition summary Total depth: measured true vertical 11,060' feet Plugs (measured) 10,189 feet 10,907' - 11,060' CMT Effective depth: measured 10,907 ' true vertical 10,090' feet Junk (measured) feet None Casing Length Size Structural Conductor Surface 2,531' 13 3/8" Intermediate 5,721' 9 5/8" Production 10,995 ' 7" Liner Perforation depth: measured true vertical Tubing (size, grade and measured depth) Cemented Measured depth True Vertical depth 2,400 sx 2,531' 2,406' 2,575 sx 5,721' 5,186' 1,150 sx 10,995' 10,127' See Attachment #1 3-1/2". 9.3#, N-80 @ 10,129'. 3-1/2", 9.2#, N-80 Butt. @ 10,185' Packers and SSSV(type and measured dep[h) Otis 7" WD Permanent Pkr @ 10,118' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Prior to well operation Subsequent to operation Representative Daily Average IP, c(3~¢Re:~:exlnjection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 5/10/87 5,752 1 3,500 psi 13. 14. Attachment,~ #2 & 3 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 (~¢~' 3 _ ~--'~?1 * Marathon Oil Company - Sub Operator ,Signed Roy D. Roberts~/~,~~_ TitleEnvironmental Engineer Form 10-404 Rev. 12-1-85 Date 5/26/87 I Submit in Duplicate B-0 B-1 B-2 B-3 B-3 B-4 B-4 Attachment #1 Dolly Varden Well D-9RD Perforations 10,300' - 10,320' MD 10,370' - 10,410' MD 10,436' - 10,456' MD 10,500' - 10,520' MD 10,550' - 10,565' MD 10,585' - 10,630' MD 10,642' - 10,690' MD 9,451' - 9,470' TVD 9,519' - 9,558' TVD 9,583' - 9,602' TVD 9,645' - 9,664' TVD 9,694' - 9,708' TVD 9,727' - 9,771' TVD 9,783' - 9,829' TVD t MDC/em/36A/Sundr2 Attachment #2 ~ Daily Report of Well Operati~L~s~ Well D-9RD 4/25/87 :'~'~:~::<a ~:~ ,it: Sas ~"~.- Accepted Rig #77 for D-9RD WO @ 0230 hfs 4/25/87. RI) Rig #76 drlg tools & prepared to move them to Rig #77. 4/26~87 RU Swaco choke & choke panel. Connect power to Rig #77. RU flowlines & service lines. RU kill line to D-9RD. Reverse circ to production. Monitor well, well dead. ND Otis lubricator & install BPV. 4~27~87 ND X-mas tree & NU BOPE. Test BOPE. RU pull tbg hanger w/107,000#. Remove BPV. LD tubing hanger. RU &circ 82 bbls to production. Hole took 31 bbls fluid in 17 hrs. Circ, well dead. Monitor well. Mix & spot 25 bbl viscous polymer pill. POH. Standback tbg. 4~28~87 POH w/3-1/2" ASL tbg. Inspect cplgs & standback in derrick. Monitor hole for fluid loss. MU 6" bit & 7", 29# csg scraper. RIH on 3-1/2" tbg. Tag pkr @ 10,118' tbg measure. PU 2' & rev circ to clean hole. POH. MU test seal assembly w/ 1/2 cut mule shoe & "XN" nipple & standback. MU running tool for ret. BP. RIH & set @ 1,820'. Test to 500 psi, OK. PU BOPE & riser and hang in sub. 4/29/87 Changeout tbg spool & test to 3,000 psi. Tested BOPE. RIH. Retrieve BP. POH & LD same. RIH w/test seal assembly on 3-1/2" tbg. Break circ& stab into pkr. Press test annulus to 1,000 psi for 10 min & 2,350 psi for 30 min. POH & LD 3-1/2" ASL tbg. 4~30~87 POH. LD 3-1/2" ASL tbg & test seal assembly. RU floor to run tbg. PU tailpipe & seal assembly. Internally tested same to 5,000 psi. Ran combination string of 3-1/2", 9.3" N~80 tbg w/Hydril 501, CS-CB, CS-CB-SCC & AB DSS-HTC conn. Ail tbg w/IPC. Ail jts rabbited, corm: gatorhawked to 5,000 psi. Hydril conn. torqued to 3,400 ft-lbs & AB torqued to 2,900 ft-lbs. 5/1/87 Finished running 3-1/2" injection tbg string. Tagged pkr w/locator @ 10,118' tbg measure. Test annulus to 2,350 psi. RU & pump 80 gal corrosion inhibitor & displace dn tbg w/90 bbls FIW. Sting into pkr. Space out tbg & land hanger. Press test annulus to 2,350 psi. Install BPV. ND BOPE. NU X-mas tree & tested to 5,000 psi. Perform csg integrity test to 2,300 psi for 30 min. Witnessed by AOGCC. 5~4~87 Move drlg tools from Rig #77 to Rig #76. Painting and demobing Rigs #77 & 76. Final Report. NEF/em/36A/Sundr2 Attachment #3 Trading Bay Unit' Well D-9RD (Current) 13-3/8" @ 2,531' 9-5/8", 43.5# @5,721! 3-1/'2" 9.3, N-80 Tbg. IPC w/Premium connectors Otis Locator 10,115' (MD) Otis 7" WD Permanent Pkr @ 10,118' (MD) Otis Seal Units @ 10,128' (MD) 3-Z/2", '~'~2#, ~-80 Butt. w/half mule shoe @ 10,185' (MD) Perforations (DIL) Bench 0 10,300' - 10,.320' Bench 1 10,370' - 10,410' Bench 2 10,436' - 10,456' Bench 3 10,500' - 10,520' Bench 3 10,550' - 10,565' Bench 4 10,585' - 10,630' Bench 4 10,642' 10,907' DIL PBTD 10,995' 7" 29# 11,060' TD - 10,690' NEF 5/11/87 ., ALAS OIL AND GAS CONSERVATION COM ,,sSION FEB 2 0 1.987 APPLICATION FOR SUNDRY APPROVALS,, . 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter ca.~g'l~' --.~ -~-~' Time extension [] Change approved program [] Plugging [] Stimulate [] ~'ull tubing J~ Amend order [] Perforate ~ Other [] 2. Name of Operawtor 5. Datum elevation (DF or KB) UNOCAL 106 ' KB above MSL fee( 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Location of well at surfaceLeg A-2, Cond. #5 Dolly Varden Platform 756' FSL, 1,139' FWL, Sec. 6-8N-13W-SM At top of productive interval 1,117' FNL, 666' FEL, Sec. 7-8N-13W-SM At effective depth 1,152' FNL, 527' FEL, Sec. 7-8N-13W-SM At total depth 1,160' FNL, 514' FEL, Sec. 7-8N-13W-SM 6. Unit or Property name ~$ng Bay Unit 7. Well number D-DRD 8. Permit number 81-80 9. APl number 50-- 733-20131-01 10. Pool Hemlock 11. Present well condition summary Total depth: measured true vertical 11,060' feet Plugs (measured) 10,189 feet 10,907' - 11,060' CMT Effective depth: measured 10,907 ' feet Junk (measured) true vertical 10,090' feet None Casing Length Size Cemented Structural COnductor Surface 2,531' 13 3/8" Intermediate 5,721' 9 5/8" Production 10,995' 7" 1,150 sx Liner Perforation depth: measured true vertical See Attachment #1 ~bing(size, grade and measured depth) 3 1/2", 9.2#, N-80 @ 10,183' Packers and SSSV(type and measured depth) 3 1/2" Camco TRB-8 @ 336' Otis WD Perm. Pkr. @ 10,104' Measured depth True Vertical depth 2,531' 2,406' 5,721' 5,186' 10,995' 10,127' 12.Attachment~ 2 & 3Description summary of proposal [] Detailed operations program [] BOP sketch [] At tachm~nt #4 13. Estimated date for commencing operation March 1987 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 /~p~ ¢.. ~be~/~ Tit lo Emviro~tal Engineer Commission Use Only Date 2/23/87 Conditions of approval * Marathon Oil Company - Sub'Operator Approved by ? ~[.,;~ ~ ~;' ~ ~ ~ t:, ~ ~ss~ner Form 10-403 Rev I -8 Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance tbh%O~do % moifssion Date ~ .,.~,._.~ '~ / Submit in triplicate B-0 B-1 B-2 B-3 B-3 B-4 B-4 Attachment #1 Dolly Varden Well D-9RD Perforations 10,300' - 10,320' MD 10,370' - 10,410' MD 10,436' - 10,456' MD 10,500' - 10,520' MD 10,550' - 10,565' MD 10,585' - 10,630' MD 10,642' - 10,690' MD 9,451' - 9,470' TVD 9,519' - 9,558' TVD 9,583' - 9,602' TVD 9,645' - 9,664' TVD 9,694' - 9,708' TVD 9,727' - 9,771' TVD 9,783' - 9,829' TVD MDC/em/36/Sundr2 Attachment #2 Application for Sundry Approval Well D-9RD Recompletion Procedure 1. Activate Rig 77 over D-9RD. 2. Kill well, NU BOPE. 3. Pull and LD tubing. 4. Fish permanent packer at 10,104' and clean out to PBTD at 10,907'. 5. Perforate Hemlock in Benches 1 through 4. 6. Test injectivity and acidize, if necessary. 7. Run packer and completion assembly. 8. Rig down and place will on injection. 9. Run injection survey. Note: BHP is 3311 psi @ 9,450' TVD. Workover fluid will be seawater and/or KC1 brine weighted to keep the well overbalance. Sized salt kill pills will be used as necessary to prevent excessive fluid loss. em/36/Sundr2 (Current) · 4-1/2 ASL x ASL Tb§ hgr ( 336" 3-1/2" TR B-8 SSSV ~ · 2,531' 13-3/8" ~ · 5,721' 9-5/8", 43.5# 3-1/2" 9.2# N-80 Tbg ATTACHMENT f/3 Well D-9RD (Proposed) 2,531' 13-3/8" 5,721' 9-5/8", 43.5# 3-1/2" 9.2# N-80 Tbg w/Premium connectors & IPC 10,104' DIL Otis WD Perm. pkr. I0,183' Otis half cut mule shoe Perforations (DIL) 10,300' - 10,320' Bench 0 10,370' - 10,410' Bench 1 ' 10,436' - i0,456' Bench 2 -. 10,500' - 10,520' Bench 3 10,550' - 10,565' Bench 3 10,585' - 10,630' Bench 4 10,642' - 10,690' Bench 4 10,907' DIL PBTD 10,995' 7" 29# 11,060' TD ¢ ~10,100' 7" Permanent pkr. ~10,160' Mule shoe .. Perforations (DIL) 10,300' - 10,320' Bench 0 10,370' - 10,410' Bench 1 10,436' - 10,456' Bench 2 10,500' - 10,520' Bench 3 10,550' - 10,565' Bench 3 10,585' - 10,630' Bench 4 10,642' - 10,-690' Bench 4 10,907' DIL PBTD 10,995' 7" 29# 11,060' TD MARATHON OIL GO.- - DOLLY VARD£N PLATFORM -- ATTACHMENT #4 Well D-9RD Pon I~/ F'lowlin~ _ Drillint I"lippl¢-. ~ 13 5,aaa Annular Ctc~p C..o hncc-'t-o~ ]5"~ ~,O00~-,KilI Linc DHI! Deck Floor -- Di~lr~m~ 2- 1:bs/8"x 5,000* Riser ¢_ IbOP .qf~xck For Drillin~q~ From Uhclcr .5urf~c.e O~x~inS To T.D.-- Double_.-Gate..- C..,I~w CIW Swin.q-bolt Clamp" ' C_.on nec.~o rS x---- 2. Ft'. Spool o o o 12". 5,000~ ¢_,asin9 l-lc~cl w/Flan~e~ Outlef~ i \/aires ! Well Room., Floor Collar I~ ~/6' Surface Ocxsi~8 ~' C, onduc±or ALA . , OIL AND GAS CONSERVATION CO .. 3SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program I-I Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Opera.,.tor U~,'OCAL 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Location of well at surfaceLeg A-2, Cond. tt5 Dolly Varden Platform 756' FSL, 1,139' FWL, Sec. 6-SN-13W-SM At top of productive interval 1,117' FNL, 666' FEL, Sec. 7-8N-13W-SM At effective depth 1,152' FNL, 527' FEL, Sec. 7-8N-13W-SM At total depth 1,160' FNL, 514' FEL, Sec. 7-8N-13W-SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name TradinK Bay Unit ...... 7. Well number D-9RD 8. Permit number 81-80 9. APl number 5O-- 733-20131-01 . 10. Pool Hemlock 10,907' - 11,060, CMT 11. Present well condition summary Total depth: measured true vertical 11,060' feet Plugs (measured') 10,189 feet Effective depth: measured 10,907 ' true vertical 10,090' feet Junk (measured) feet None Casing Length Size Structural Conductor Surface 2,531' 13 3/8" Intermediate 5,721 ' 9 5/8" Production 10,995' 7" Liner Perforation depth: measured true vertical Cemented 1,150 sx See Attachment #1 Measured depth 2,531' 5,721' 10,995' Wue Ve.[ticaldepth 2,406' 5,186' 10,127' Tubing(size, grade and measured depth) 3 1/2", '9.2#, N-80 @ 10,183' Packers and SSSV(type and measured depth) 3 1/2" Camco TRB-8 @ 336' RECEIVED E,,, 1'5 1986 Alaska 0il & Gas Cons. Commission Anchorage Otis WD Perm. Pkr. @ 10,104' 12.Attachment~ t/2 & 3 Description summary of proposal [] Detailed operations program [] BOP sketch [] _ 13. Estimated date for commencing operation December 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that,the foregoing is~rue and correct to the best of my knowledge uignea Roy D. Rob~6fJ~s .~¢;~)_ ~'f~-~ Title Environmental Engineer Commission Use Only Conditions of approval Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI * Marathon Oil Company - Sub Operator Approved by i'~ ~ ~ ~;~ ~;~ ....... C~issioner Form 10-403 R~v i24-85 ~ . Date /.,~.../,,~ - ~c'~' No. by order of the commission Date feet Submit in triplicate B-0 B-1 B-2 B-3 B-3 B-4 B-4 ATTACHMENT 1 Dolly Varden Well D-9RD Perforations 10,300' - 10,320' MD 10,370' - 10,410' MD 10,436' - 10,456' MD 10,500' - 10,520' MD 10,550' - 10,565' MD 10,585' - 10,630' MD 10,642' - 10,690' MD 9,451' - 9,470' TVD 9,519' - 9,558' TVD 9,583' - 9,602' TVD 9,645' - 9,664' TVD 9,694' - 9,708' TVD 9,727' - 9,771' TVD 9,783' - 9,829' TVD MDC/em/36/Sundry RECEIVED ! 5 1986 Alaska, Oil & Gas Cons. L;omrnmsion ~ Anchor~rle ATTACHMENT #2 TBU Well D-9RD Marathon requests approval to test injection into Hemlock Benches 0, 1, 2, 3, and 4 through the existing completion in TBU Well D-9RD. Pending favorable evaluation of this well's injection capacity and profile, a separate permit will be filed for conversion of this producer to a service well as per Rule 2 of the TBU Area Injection Order No. 5. Following is the proposed procedure for initiating injection in Well D-9RD. 1. Shut in the lift gas and allow the well to die. 2. Fill the 7" casing with FIW. 3. Rig up waterflood lines. Inject FIW down tubing at 2000 psi while monitoring casing pressure. 4. Increase injection pressure to 3500 psi and inject FIW for 14 days while monitoring hrs on, bbls injected, tubing pressure, 7" and 9 5/8" casing pressures. 5. Run an injection profile to determine the disposition of injected fluid. 6. Continue injection until workover operations commence for permanent conversion to injection in January, 1987. MDC/em/36/Sundry RECEIVED ! 5 1986 ~laska Oil & ~as Cons. CommJssio~ Anchorage Attachment #3 TBU D-gRO Completion Schematic 7", 29# Liner~-~'''~ N-80 Butt to !0,995' Windo~ in old 9-5/8" - ~3.5#, N-80 5721' - $780' 3-1/2" Tubing 9.2#, N-80 ASL Otis WD Perm Pkr w/ 7.q5' Seal Bore Extension set at 10,104' OIL Perforations (DIL): ~ench 0 - 10.300'-320' Bench I - 10,370'-610' Bench 2 - 10,436'-456' Bench 3 - 10,500'-520' Bench 3 - 10,550'-565' Bench 4 - 10,585'-630' Bench 4 - 10,642'-690' TO - 11,060' CIW 4-1/2 ASL = ASL Tubing Hanger 3-1/2" TRB-8 2.812" 336' 3-1/2" Camco TRB 8 - Alpha Retrieva~ Safety Valve, ID-2.812" 2392' 3-1/2" McMurry Type MHO GLM's w/ 1.1 JR-STD valves and BK-2 Latches 3888' GLM #2 5104' GLM #3 6143' GLM #4 6989' GLM #5 7635 ' GLM #6 8195' GLH. #7 8577' GLM #8 8872' GLM #9 9168' GLM #10 9460' GLM #11 , 9667' GLM #12 9873' GLM #13 Orifice ~ . o 10,133' Otis Locator and Seal Assembly w/ 15t of seals IO,183' Otis HalfC~ Mule Shoe (Bottem) January 10, 1985 .RECEIV.ED DEC 1 5 PBTD 10,905' DIL PBTD ]0.,:,57' t.,iaska 0ii m, uas Coris. Commissir 7". 2qe t~n.r to I0,995' Unocal Oil & Gas Divisi~' Unocal Corporation ~ RO. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Environmental Group Alaska District February 3, 1986 Hr. C.V. Chatterton AK. Oil & Gas Conservation Comm. 3001Rorcupine Drive Anchorage, Alaska 99501 Dear Hr. Chatterton: SUNDRY NOTICE SUBSEQUENT D-9RD Attached please find two (2) copies of a Sundry Notice Subsequent for D-gRD, Trading Bay Unit for your information and file. Very truly yours, Roberts Environmental Specialist tj/O124n Attachment RECEIVED ~.~ 1 ~ 1986 Alaska Oil & Gas Cons. Commissi~m Anchorage STATE OF ALASKA ALASKA(" .~- AND GAS CONSERVATION C(~i'~ .MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL:E] 2. Name of Operator ~" 7. Permit No. Union Oil Company of California* 81-80 ;3. Address 8. APl Number P.O. Box 6247 Anchorage, AK 99502 5~_33-20131-01 9. Unit or Lease Name Trading Bay Unit OTHER [] 4. Location of Well Surface: Leg A-2. Cond. #5, Dolly Varden Platform 756' FSL, 1139' FWL, Sec. 6-SN-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106' KB Above MSL 6. Lease Designation and Serial No. ADL 18729 10. Well Number 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 [] [] Other [] Pulling Tubing ~: [] Pull 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-9RD On January 24 and 25, 1986, the well was perforated with 2 5/8" guns, 4SPF, 0° phasing, under drawdown at the following intervals: Bench 1 10,370' - 10,410' DIL Bench 2 10,436.' - 10,456' DIL RECEIVED F ~i~ 1 ~ 1986 Alaska 011 & Gas Cons. Commission Anchorage * Marathon Oil Company - Sub Operator ,.., ere , re,oi , co ec, to e.t o, mg.ed R~D.' Roberts T~t,e Env i ronmenta 1 Speci a 1 i st The space below for Commission use Date 02/03/86 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 :. Union Oil and Gas I. .~ion: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Februa~,y 4, 1985 · .?. Mr. Chat Chatterton AK. Oil & Gas Conservation Commission 3001Rorcupine Drive Anchorage, AK 99504 Dear Mr. Chatterton: Attached are Sundry Notice Subsequents f~r.~D~' & D-17RD,. Trading Bay Unit for your information and file. L0C/tj Attachments Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST 0il & Gas Cons. C0mmWsW, Anchorage STATE OF ALASKA {r ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator 7. Permit No. Union Oil Company of California* 81-80 OTHER [] 3. Address P.O. Box 6247 Anchorage, AK 99502 4. Location of Well Sur fac e: Leg A-2, Cond. #5, Dolly Varden Platform 7~6' FSL, 1139' FWL, Sec. 6-8N-13W-SM 5. Elevation Ln feet (indicate KB, DF, etc.) 106' KB above MSL 6, Lease Designation and Serial No. ADL-18729 $. APl Number 50- 733-20131-01 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-qRD 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 ED Perforations ~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] [] Other [] Pulling Tubing [] Pull 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 January 9 and 10, 1985, the well was reperforated with 2-1/2" guns, 4 HPF, 0° phasing, under dra~down at the following intervals: Bench 4 10,642' - 10,690' DIL (New Per£orations) 10,585' - 10,630' DIL (~ew Per£orations) Bench 3 10,550' - 10,565' DIL (~ew Perforations~) 10,500' - 10,520' DIL 1 spf Productio~n before reperforating: 154 BFPD, 901 WC, 15 ROPD, 139 BWPD. Production after reperforating: 720 BFPD, 875 WC, 94 BOPD, 626 BWPD. PBTD @ 10,905 ' DIL. RECEIVED FEB 0 5 JAN 2 91985 Alaska 0ii & Gas Cons. Commission Anchorage *~arathon 0il Company: &ih Operator, 14. t hereby ce~t th~,f~eg~n~d correct to.~of my knowledge. S~gned La~~~.' C~'~rg · Title Environmental Special 1st The space below for Commission use Ak Environmental Group ~;j)at e ,02/01/85 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 ~0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Unocal Oil & Gas Divisi~~'' Unocal Corporation ~ RO. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Environmental Group Alaska District January 17, 1986 Mr. C.V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 Dear Mr. Chatterton: SUNDRY NOTICE INTENTION D-gRD Attached for your approval are 3 copies of a Sundry Notice of Intention to perforate D-gRD, Trading Bay Unit. Work is expected to commence as early as Sanuary 22 therefore, we would appreciate verbal approval as soon as possible. Very truly yours tj/OO91n Attachments . Roberts ENVIRONMENTAL SPECIALIST RECEIVED JAN 1 7 Alaska Oil & (~a$ Cons, Commisslorl' Anchorage STATE OF ALASKA ALASKA(" L AND GAS CONSERVATION C~' MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ 2. Name of Operator 7. Permit No. Union Oil Company of California* 81-80 3. Address 8. APl Number P.O. Box 6247 Anchorage, AK 99502 5~33-20131-01 OTHER [] 4. Location of Well Surface: Leg A-2. Cond. #5, Dolly Varden Platform 756' FSL, 1139' FWL, Sec. 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106' KB Above MSL 6. Lease Designation and Serial No. ADL 18729 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-9t~ 11. Field and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate ~ 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 1'0-407 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). TBU Well D-9RD It is Marathon's intention to perforate the well with 2 1/2" guns 4 SPF, 0° phasing, under drawdown. B-1 10,370' - 10,410' DIL B-2 10,436' - 10,456' DIL Perforating operations are expected to begin January 22, 1986. Marathon Oil Company - Sub Operator R C V£D .jAN 1 7 19B6 Alasi~a Oil & Bas Cons, gommi~sioll Anchorage 14. I hereby certify that the foregoing is true ~nd correct to the best of my knowledge. Signed d~¢~/~ ~¢_~ ~,~.Z~v Title The space belCw for Commission use Date Conditions of APproval, if any: Approved by. ~¥ tO~,~l[ C. SalTli Approved Co~y ~t~urne~ COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Union Oil and G~" 3ivision: Western Region Union Oil CompaT,y of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union October 2, 1984 Mr. Chat Chatterton Alaska Oil & Gas Conservation Commission 3001Rorcupine Drive Anchorage, Ak. 99502 Dear Mr. Chatterton: SUNDRY NOTICE - DOLLY VARDEN PLATFORM Attached, for your approval are Sundry Notices to perforate Marathon operated wells D-gRD and D-17RD. Rlease return the approved Notices to the undersigned. Very truly yours, Lawrence O. Cutting Environmental lechn~cian LOC:cwl Attachment RECEIVED OCT 0 9 Alaska 0i~ & Gas Cons. Commission Anchorage STATE OF ALASKA I~ ALA~('?. ~ OIL AND GAS CONSERVATIO OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] :2. Name of Operator 7. Permit No. Union Oil Company of California* 81-80 3. Address 8. APl Number P.O. Box 6247 Anchorage, AK 99502 50- 733-20131 4. Location of Well Surface: Leg A-2, Cond. ~5, Dolly Varden Platform 756' FSL, 1139' FWL, Sec. 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106' KB above .MSL 6. Lease Designation and Serial No. ADL 18729 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-9RD 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 I-'} Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each comple~ion.) 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 Marathon's intention to reperf'orate the well with 2-1/2" guns, 4 HPF, 0* phasing, under drawdown. Bench 3 10,500' - 10,520' DIL 10,550' - 10,565' DIL Bench 4 10,585' - 10,'630' DIL 10,642' - 10,690' DIL (New Perforations) ( N'~w Perfo-~ations) The August, 1984, production test averages were: 400 BFPD, 75% WC, 100 BOPD, ~300 BWPD. Subsequent Work Reported *~ra~on Oil Co~y - Sub ~erator RECEIVED OCT 0 9191 ~,i ~ ~s Cons. Commi~ion Anchorage 14. I hereb~ that the foregoing ~ is true and correct to_the best of my knowledge. Signed .111~,,~(~C~ Envir0nmenta] Tech. The space below for Commission use .~ Date 10/4/84 Conditions of Approval, if any: Approved by COMMISSIONER Approved C. op~ · Return~:t -- IO/l/ i By Order of the Commission Form 10-403 Rev. 7.1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKAIrx, ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL !--I COMPLETED WELL E~ OTHER [] 2. Name of Operator 7. Permit No. Union Oil Company of Calif. * 81-80 3. Address 8. APl Number P.O. Box 6247 Anchorage Alaska 99502 so- 733-20131-dl 4. Location of Well Surface: Leg A-2, cond. #5, Dolly Varden platform 756' FSL, 1139' FNL, Sec. 6-SN-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106' KB above MSL 12. I 6. Lease Designation and Serial No. ADL-18729 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-9RO 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). Change of kick off point. A window was cut in the 9 5/8" csg at 5700' DPM beginning December 17, 1981. R[CElVED MAR - 198'3 Alaska 0il & Gas Co~s~ Commission Anchorage * Marathon Oil Company - Sub operator 14. ~// ' ~7 /~ //////hem cejtify that the fowgoi,g~s3rue a,d~rrect to the best ! S~ below- ---- / "'~'~for/Commission use Th~~ditions of App/oval, if any: · Date 3/1/83 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 Document Transmitt*~'~ Union Oil Company of Ca~ ,ia union "DA"TE 'SUBMITTED ACCOUNTIN'G MONTH HAND DELIVERY 5-2-82 TO FROM Mr. Wm. Van Alen R.C. Warthen ,~T AT State 0 & G CC PO Box 6247 ~/'~"~1 I~ ....... -*--A ~'~.' ..... , A... I. _ . A ~-9 RD' na~r .b'~ ~ i~' ~ ,,, Ancho~ag~ .... . , ........ ,, i i i , FORM 1-2M02 (REV. 11-72) PRINTED IN U,S.A. R. C. Warthen District Development Geologist Alaska District Union Oil and Gas ~on' Western Region Union Oil Company Of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unl,en April 27, 1982 ~ 2 GEOL '?q 3 GEOL ~_._-STAT TEC "r~ J---STAT TEC NFER: Mr. William Van Alen State Oil and Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Bill: Enclosed is the data you requested as per yoUr letter of 4-22-82. As you check the document of transmittal, you will note several items are missing. They are as follows: ~ ' TBU D-9 RD._..,.)' Library tape; this tape is currently being redone and reproduced by Schlumberger. TBU K-3 RD Well History; Union Oil as TBU Operator has no receipt of receiving this history from ARCo - suboperator. We are currently checking with ARCo on this matter. Cannery Loop Unit #3 Library tape; as a confidential well, the logs have never been composited by Schlumberger and therefore a library tape is not available. When available, the tape will be delivered to the Oil and Gas Commission. KU 34- 32 Test reports; these test reports have not been delivered to Union Oil Co. from Haliburton at this time. R. C. Warthen RCW:nd Hr. Robert C. Warthen Union 0il Company of California P. O..Box 6247 Anchorage, Alaska 99502 April 22,. 1982 Missing Information -.Completed Wells Dear Bob: We wish to bring to your attentio.n that the below-indicated material on the following Union Oil Company wells has not yet been received by the Alaska Oil and Gas Conservation Commission: Well _.C?,~plet ion Date M._is S i..n g Mater.iai Granite Pt. ~33-14KD Trading Bay Unit tD-9RD Trading Bay Unit tD-16RD 3/6/81 3/2/82 518181 -DIL/SP & CBL/VDL Elco. Logs. -Digitized E. Log Tape -Directional Survey Trading Bay Unit ~D-17RD 6/22/8l -Elec. Logs -Directional Survey Trading Bay Unit #K-3RD 5/22/81 -Well History Trading Bay St. #A-gED 5/6/81 -Directional Survey -Digitized E. Log Tape Trading Bay St. ~A-17RD Cannery Loop Unit #3 7/3/81 9/13/8l -Digitized E. Log Tape -Digitized E. Log Tape Kenai Unit #34-32 ,,/3.8/82 -Digitized E. Log Tape -Certified Survey Plat -Directional Survey -DST or Prod. Test Reports Trail Ridge Unit #1 12/13/80 -Certified Survey Plat Please submit the above material at your earliest convenience since you are now in violation of Title 20, Chapter 25 of the Alaska Admin- istrative Code. Very t~uly }puts, William Van Alen Petroleum Geologist WVA:v~I ALAS O, AND GAS CONSERVATION ,-.-, .,/I~SSION ~,/__ WELL COMPLETION OR RECOMPLETION REPORT AND LOG t-.Status of Well Classification of Service Well OIL I-~ GAS [] SUSPENDED [] ABANDONED [] ·SERVICE [] 2. Name of Operator 7. Permit Number Union Oil Company of California* 81-8D 3. Address 8. APl Number P. O. Box 6247, Anchorage, Alaska 99502 50-733-20131-01 4. Location of well at surface Dolly Varden Platform, Leg A-2, Cond ~5 9. Unit or Lease Name 756.4' FSL, 1138.5' FWL, Sec 6-8N-13W-SM [~L©£ATiONSi Trading Bay Unit At Top Producing Interval ] VERIFIED 10. Well Number 1117' FNL, 666' FEL, Sec 7-8N-13W-SM i Surf. ~- J D-9RD At Total Depth B. H .... ~-- 1 1. Field and Pool , ll60~ FNL, 4~o FEL, Sec 7-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106.2' KB MSLI APL-18729 A-926 McArthur River Field 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 12-09-81 01-31-82 03-02-82 90 feet MSL 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost ll060'MD 10192'TV:) 10957'MD iO090'T'~DES~ NO[] 336 feet MDI ------ 22. Type Electric or Other Logs Run Gyro, CBL/VDL/CCL/GR, DIL/SP/GR, Density/-Neutron/Caliper, Sonic/GR/Caliper 23. CASING, LINER AND CEMENTING RECORD . SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 7" 29(~ N-80 Surface 1l~' a-1/2" .. . 24. Perforations open. tO Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) .... SIZE ~ DEPTH SET (MD) PACKER SET (MD) ~' 3' 1 / 2" 10183 ' 10104 ' Top Bottom 10300' MD 9451' TVD 10320' MD 9470' TVD. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Perfd w/ DA 2-5/8" Slim Kone gun, 16 HPF DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ' " ' " ' "" ~' ~ "' 2605 35 sx CZ G .- 10500' MD '9645" TVD 10520' MD 9664' TVD 10300-10320 150 sx CZ G Perfd w/ DA 2-5/8" Slim Kone gun, 8 HPF ' 10478-10479 50 sx C1 G -?. ·' '., ' '~' ' 1055,0-10551 50 sx C1 G 27. · ' PRoDucTiO]N0f~sSr-:"i0699 50 sx C1 G Date F, irst Production Method of Operation (Flowing, gas lift, etc.) 02-'?.8'82 ' ' "' ' "GaL Lift`. ~ ' ' Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE IGAS-OILRATIO 03'02-82 24, TEST PERIOD I1~ · 687, · ., 2·20 13 Oo~_n Flow Tubing Casing Pressure 'CALCULATED r OIL'BBL GAS--MCF .. WATER'BBL OIL GRAVITY-APl (corr) Press. 170 ''~ .8S0 24-HOUR~RATEI~' 68) 220 13 34° ,. 28. ' '~ ' ' ' '" CORE DATA · Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. .- ' . None · · Marathon Oil Company - Sub-Operator Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE .. 29. '. '30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. lqor~e · 31. LIST OF ATTACHMENTS Well Hlstor¥, Caslr~§ arid 5'ut)±r~g Der_a±ls , arid Co~nplet.±or~ Sct~emal:lc 32. I hereby certify that the foregoing 'is true and correct to the best of my knowledge Sig Title DIST DRI_G SUPT Date 3/18/F{2 INSTRUCTIONS General' This form is designed fOr submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Irem 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in'item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (G L) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 FORM 484 REV. 3--63 DATE 03-04-82 MARATHON OIL COMPANY HISTORY OF OIL OR GAS WELL FIELD McArthur River BLOCK WELL NO. D-9RD LEASE Trading Bay Unit SEC. PARISH Alaska Kenai Peninsula Borough STATE COUNTY TWP. 8N R. 13W 106'ELEV. KB I ToP OF OIL STRING ELEV.. HISTORY PREPARED BY MEASUREMENTS !~TOPOF ROTARYTABLE~ELEV.~ TITLE TAKEN FROM / LGRD. OR MAT, ELEV. L. G. Haywood Secretary It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1981 12-01 - 12-08 12-09 12-10 12-11 12-12 12-13 12-14 12-15 12'16 12-17 12-18 12-19 12-20 WELL TBU D-9RD (Marathon AFE 4811) gECEIVEb Activating rig 77 and general rigging up. ll,341'TD Fin filling well w/ FIW. RU WL unit & perfd tbg w/ ll,281'PBTD 4 SPF 10,354'-356'. Circ well w/ FIW. SI well. Mixing mud to circ & kill well. ll,341'TD Mixed mud. Circ well w/ FIW followed by mud. Presently ll,281'PBTD circ mud to kill well. ll,341'TD Killed well w/ 9.4 ppg. Circ & set BPV. ND Xmas ll,281'PBTD tree & NU BOPE. Presently WO Koomey controls. ll,341'TD Cont NU BOPE. Repaired BOP controls. Presently ll,281'PBTD testing BOPE. ll,341'TD Fin testing BOP & RU driller's remote panel. Pulled ll,281'PBTD hyd pkr free from 10,476'. Circ. POH & LD 4-1/2" prod tbg & compl eqpmt. Ran gyro inside 9-5/8." csg. ll,341'TD ll,281'PBTD Compl running gyro to 10,700'. Ran CBL across section area & from 3000'-1200'. Chgd rams in BOPE. Began PU 5" DP. ll,341'TD 10,575'PBTD Fin PU 5" DP & RIH. Abandoned Hemlock perfs 10,596'' 11,153' w/ 188 sx cmt. Pulled up 10 stds & rev. Rec contaminated mud. Circ & POH. RIH w/ 8-1/2" bit & scrpr to 6500'.. POH. ll,341'TD Fin POH w/ bit & scrpr. RIH & set perm BP @ 6100'. 6,100'PBTD Tstd csg to 2000#. Incr mud visc while circ. POH. ND & PU BOP to ck tbg spool--OK. NU stack & tstd. MU section mill #1 & RIH. ll,341'TD Fin RIH w/ section mill. Unable to cut csg. POH. 6,100'PBTD Redressed mill. RIH & cut csg @ 5700'. Milled 5700'-5705'. ll,341'TD Milled section in 9-5/8" csg from 5705'-5722'. POH. 6,100'PBTD Redressed mill. RIH w/ mill & cut section 5722'-24. ll,341'TD Milled section in 9-5/8" csg 5724'-5754'. Circ & POH. 6,100'PBTD (Total section to date: 5700'-5754'.) ll,341'TD Fin POH. Redressed mill & RIH. Found error in pipe 5,600'PBTD tally, top of section @ 5721', not 5700'. Milled 9-5/8" csg to 5780' (total section 5721'-5780'=59'). Circ & POH w/ mill #4. RIH w/ DP stinger & reduced mud visc. Spotted cmt plug from 5884' w/ 122 sx. Rev out 4 bbls contaminated mud. POH w/ stinger. Well TBU D-9RD Well History Page 2 12-21 12-22 12-23 12-24 12-25 12-26 12-27 12-28 12-29 12-30 12-31 1982 01-01 01-02 01-03 01-04 ll,341'TD Fin POH w/ stinger. Held press on cmt plug 12 hrs. 5,600'PBTD Tstd BOPE. RIH w/ 8-1/2" bit. C&C mud @ 5584'. 5,742'TD C&C mud. Tagged cmt @ 5584'. Dressed cmt plug 5584'-5726'. Circ & POH. RIH w/ DD to 5726'. Tstd 9-5/8" shoe to 14.0 ppg equiv. Oriented DD & DD 5726'-5742'. 5,859'TD Direc drld 5742'-5766'. Ran leak-off test to 13.0 ppg equiv. POH. PU new bit & RIH Direc drld 5766'- 5859'. POH. PU new DD & RIH. 5,862'TD Attempted to work thru bridge @ 5769'. POH. PU drlg assy & RIH. Drld thru bridge 5770'-5807'. Reamed to 5859' & drld to 5862' Raised mud visc. POH. PU DD & RIH. Working thru fill. 5,947'TD Drld bridge @ 5775'-5803'. Reamed to 5862'. Oriented DD & drld 5862'-5947'. POH & PU conventional BHA--RIH. Hit bridge @ 5762'. Worked to btm. PU & tagged bridge @ 5775'. Coal sloughing. 6,036'TD Circ & worked bit to clean hole. POH & chgd BHA. RIH. Worked bit thru bridges & tight spots. Drld 5857'- 5873'. POH & chgd out BHA. RIH & washed dwn thrU bridge @ 5699'. Drld 5873'-6036'. 6,182'TD Drld 6036'-6053'. POH & PU DD. DD 6053'-6182'. POH & LD DD. angle. Hole cond improved. RIH for DD rUn #4. PU new BHA to drop 6,312' Reamed DD #4. Drld 6182'-6307'. Circ & surv. Tstd BOPE--OK. RIH w/ DD #5. RU steering tool. Drld w/ DD from 6307'-6312'. POH. 6,631'TD Drld w/ DD #5 6312'-6391'. POH. Tight @ 5813' & 6093'. RIH w/ bit #11. Reamed DD run. Drld 6391'- 6631'. Circ, surv, & POH. 6,715'TD Fin POH w/ bit #11. RIH w/ DD #6. Oriented w/ steering tool. DD 6631'-6715'. Circ, surv, & POH. MU drlg assy & RIH. Reamed DD run. Repaired leak on standpipe (blew cap on standpipe line where it comes thru drill deck floor). 6,959'TD Fin repairing leak in standpipe. Reamed DD ~6 run. Drld 6715'-6772'. Circ, surv, & POH. Chgd BHA to drop angle. RIH--hole cond good--no fill. Drld 6772'-6959'. Circ, surv, & POH w/ bit #13. 7,220'TD 7,538'TD 7,752'TD 7,981'TD Fin POH & chgd BHA to packed assy. 6959'. Drld 6959'-7216'. Surv. Hold cond good. Drld 7216'-7220'. RIH--reamed 6870'- POH w/ bit #14. RIH. Drld 7220'-7432'. Curc, surv, & POH w/ bit #15. RIH & drld 7432'-7538'--losing press. POH looking for washout. Fin POH. Found jet washed out of bit. RIH w/ bit #17. Drld 7538'-7752'. Circ, surv, & POH. RIH w/ bit #18. Fin RIH. Reamed 7715'-7752'. Drld 7752'-7935'. Circ & POH w/ bit #18. Tstd BOPE & MU BHA. RIH--washed thru bridge 7380'-7420'. Drld 7935'-7981'. Well TBU D-9RD Well History Page 3 01-05 01-06 01-07 01-08 01-09 01-10 01-11 01-12 01-13 01-14 01-15 01-16 01-17 01-18 01-19 8,315'TD 8,464'TD 8,653'TD 8,956'TD 9,132'TD 9,355'TD 9,640'TD 9,763'TD 10,045'TD 10,280'TD 10,509'TD 10,665'TD 10,741'TD 11,045'TD ll,045'TD Drld 7981'-8240'. Circ, surv, & POH w/ bit #19. Chgd BHA to slow angle drop. RIH & drld 8240'- 8315'. Drld 8315'-8388'. Circ, surv,. & POH w/ bit #20. Hole OK. Chgd BHA & RIH. Drld 8388'-8464'. Surv & POH w/ bit.#21'. RIH--tight spots in 9-5/8" csg @ 2807' & 2839'. Unable to get thru w/ locked BHA @ 0700 hrs. Worked free from tight spot @ 2839'. POH. RU & ran caliper log from 5623'-surf. Moderate pitting thru- out string w/ 16% remaining wall thickness @ 2803'. Chgd out BHA & RIH. Hole in good cond. Drld 8464'- 8653'. Drld 8653"-8770'. Circ, surv, & POH w/ bit #22. Hole in good cond. RIH. Only 10-15,000# drag @ 2802'. Drld 8770'-8956'. Drld 8956'-9132'. Circ, surv, & POH w/ bi% ~23. Had 10-15,000# drag in 9-5/8" csg @ 2802'. Chgd BHA & RIH. Tagged bridge @ 8666'--washed & reamed to 9132'. Resumed drlg @ 0700 hrs. Drld 9132'-9355' w/ short trip @ 9263'. Circ & surv. Made 15-std short trip. Drld 9355'-9640' w/ another short trip @ 9509'. Hole in good cond. Drld 9640'-9666'. Circ, surv, & POH w/ bit #24. Tstd BO?E--OK. RIH. Tight spots @ 6935' & 8635'-- otherwise hole OK. Reamed 40' to btm.- Drld 9666'- 9763'. Drld 9763'-9830'. Circ & made short trip. Hole in good cond. Drld 9830'-10,045'. Prep to make wiper trip. Made 15-std short trip--hole OK. Drld 10,045'- 10,280' w/ another 15-std short trip @ 10,191'. Drld 10,280'-10,441' Made wiper trip--hole OK. Drld 10,441'-10,509'. CBU, surv, & POH for new BHA. Fin MU BHA. RIH--had to work thru section in 9-5/8" csg. Bridge @ 8400'--worked thru OK. Drld 10,509'- 10,665'. Drld 10,665'-10,734' w/ short trip @ 10,721'. Surv & POH w/ bit #26. Tstd BOPE--OK. RIH & reamed 60' to btm. Drld 10,734'-10,741'. Drld 10,741'-11,045'. Circ. Made short trip to csg shoe @ 5721'. Tight from 8550'-8200'. RIH. C&C hole for logs. Circ, surv, & POH w/ bit #27. Hole OK. RU SOS & ran DIL, BHC-Sonic, FDC/CNL. Logger's TD @ 10,916'. RD SOS. RIH w/ RBP on DP & set @ 2470'. Tstd to 750#-- OK. POH w/ DP. ND BOPE to PU & instl 7" csg spool to allow running 7" csg to surf to cover bad spot in 9-5/8" csg @ 2802'. Well TBU D-9RD Well History Page 4 01-20 11,045'TD 01-21 11,060'TD 01-22 11,060'TD 01-23 11,060'TD 01-24 11,060'TD 01-25 11,060'TD 01-26 ll,060'TD 01-27 ll,060'TD 01-28 11,060'TD 10,957'PBTD 01-29 11,060'TD 10,957'PBTD 01-30 11,060'TD 10,957'PBTD Instld 7" csg spool. NU & tstd BOPE. Retr BP @ 2470'.. RIH to shoe, broke circ; RIH to 7500', broke circ. .RIH & reamed 60' to btm. Fill over last 40'. Fin reaming to btm. Drld 11,-045'-11,060' (rathole for shoe jt). CBU. Made wiper trip to csg shoe. Hole OK. C&C hole for csg. POH. Instld 7" rams. Started running 7" csg--100 jts in hole @ 0700 hrs. Fin running total of 270 jts 7" csg. Tagged fill @ 10,995' (65' off btm). Could not wash dwn. Cmtd 1st stage w/ 1150 sX. CIP @ 0225 hrs, 01-22-82. Dropped bomb to open stage tool @ 3395'--press up but could not open tool. Chased bomb w/ sandline-- it had landed in stage tool OK. Press csg again. Still unable to open tool. Unable to open DV clr @ 3435'. Dropped opening bomb & opened upper DV clr @ 2552' after several attempts. Circ & displ mud from 7" x 9-5/8" annls w/ FIW. Circ corrosion inhibitor in place in annls. PU BOPE & set 7" csg slip. Cut off 7" csg & instld tbg spool. Fin NU tbg spool & tstd OK. NU BOPE. LD 6-1/4" DC's, 5" HWDP, & 5" DP. Prep to test BOPE. Fin testing BOPE--OK. RIH w/ 6" bit & DC's & tagged upper DV clr @ 2605'DPM (reported @ 2553' by csg tally). Set 30,000# wt on DV closing plug, closed pipe rams & press to 2000#. Had indication DV clr closed. DO DV clr 9 3605'. Press tstd 7" csg & had communication to 7" x 9-5/8" annls. Tstd 7" x 9-5/8" annls to 2800#--OK. RIH & tagged 2nd DV clr @ 3446'DPM (reported @ 3435' by csg tally). POH. RIH w/ JB. POH w/ JB. RIH w/ PRT ext & bumper sub--opened DV clr. RIH w/ retr pkr & circ thru lower DV & out upper DV. POH. RIH & bumped dWn & closed lower DV. POH. RIH w/ pkr & set between DV tools--press tstd lower DV to 3000#--closed OK. POH. Set cmt rtnr @ 2560' & circ 35 sx cmt thru upper DV @ 2605' while holding back press on 7" x 9-5/8" annls. PU out of cmt rtnr @ 2560' & left press under rtnr & on 7" x 9-5/8" annls. WOC. RIH w/ 6" bit & had 4' cmt on top of rtnr. Drld cmt, rtnr, & hard cmt under rtnr to 2606'. Tstd DV clr @ 2605' to 2000#--OK. Pushed junk to lower DV clr. POH--emptied JB's & RIH w/ new 6" bit. RIH w/ bit #30. Drld lower DV clr @ 3492'. Tstd DV tools & csg to 2000#--OK. PU 3-1/2" DP & RIH. Tagged hard cmt @ 10,81I'. Drld cmt to FC @ 10,957'. POH. Started running CBL. (Depth corrections: Top DV Tool = 2605'DPM; Btm DV Tool = 3492'DPM; Flt Clr = 10,957'; 7" Csg Shoe = ll,033'DPM.) Ran CBL/CCL/GR logs w/ acceptable bond across zones of interest in the Hemlock. Ran gyro. RIH w/ 6" bit & 7" csg scrpr to 10,957'PBTD. Circ. Circ. Retstd entire 7" csg string to 2000#--OK. Displ mud w/ FIW. Mixed & spotted 3% KC1 across Hemlock interval. POH w/ 6" bit. RIH w/ WL gauge ring & JB to PBTD. Set 7" prod pkr w/ WL @ 10,150'DIL. RIH w/ 3-1/2" DP & 4-3/4" DC's. Well TBU D-9RD Well History Page 5 01-31 02-01 02-02 02-03 02-04 02-05 02-06 02-07 02-08 02-09 02-10 02-11 11,060'TD 10,957'PBTD 11,060'TD 10,957'PBTD 11,060'TD 10,957'PBTD 11,060'TD 10,957'PBTD 11,060'TD 10,957'PBTD ll,060'TD 10,957'PBTD 11,060'TD 10,957'PBTD 11,060'TD 10,957'OBTD 11,060'TD 10,957'PBTD ll,060'TD 10,957'PBTD 11,060'TD 10,957'PBTD 11,060'TD 10,957'PBTD Fin RIH. POH & LD 3-1/2" DP & 4-3/4" DC"s. Running 3-1/2" prod tbg w/ GL eqpmt. Fin running 3-1/2" prod tbg, ~GL eqpmt, & SSSV. Tstd string to 4000#. Spaced out & landed tbg in pkr @ 10,185' tbg meas (10,150'DTL)~. ND BOPE & instld Xmas tree. Flanged up prod eqpmt & RU to perf well. Fin NU flow line & GL line. Repaired leak in manu- matic control vlv. At 0700 hrs, attempting to open the SSSV to begin lifting well dwn. Opened SSSV. Unloaded 175 bbls FIW. RU lub & tstd. Perfd Hemlock Bench 0 from 10,300'-10,320'DIL (8 HPF). Prod to test & had rec 189 bbls gross @ 0645 hrs. Testing Bench 0 @ 455 BOPD, 948 BFPD @ 52% WC (4 hr extrapolated to 24 hrs). Cont testing Hemlock Bench 0 til 1130 hrs, 02-04-82. SI well & RU WL. Ran static & flowing Diff Temp surv which showed behind pipe communication from Bench 2 to Bench 0 perfs. Returned to prod testing @ 230 BOPD, 576 BFPD (60% WC) & ran flowing gradient surv to ck GL system. Bled annls gas to flare. Filled annls w/ FIW. Bullheaded FIW dwn tbg. Perfd circ holes in tbg @ 10,124'-129'WLM (2 HPF). Circ 1 hole volume w/ FIW. Began circ w/ mud. Fin circ w/ mud. CBU. Set BPV & ND tree. NU & tstd BOPE--OK. Pulled out of pkr & CBU. POH & stood tbg in derrick. PU pkr retr tools. MU Tri-State pkr picker on 6" shoe. PU 4-3/4" DC's & 3-1/2" DP & RIH to prod pkr @ 10,185' (tbg meas). BO pkr. POH & rec pkr. LD tools. RIH w/ 6" bit & 7" csg scrpr. RIH w/ bit & csg scrpr. Circ & cleaned hole to 10,972'DPM. RU DA & perfd 10,698'-699' (2 HPF) w/ 4" Jumbo Jet. POH. RIH w/ EZSV & set @ 10,590'DPM. Estab inj @ 3500#, 1/2 BPM. Spotted 10 bbls wtr @ ~ pkr. PI 2-1/2 bbls @ 3650# & broke dwn. Inj 1BPM @ 3600#. Pumped 10 bbls wtr, 50 sx cmt, 5 bbls wtr, & 58 bbls mud. Sqzd @ 3.4 BPM @ 3000#. At 18 bbls away, press had incr to 4100#. Held 5 min--bled to 3900#. Fin rev from sqz #1. POH. Perfd 10,550'-551'CBL for sqz #2. Set HOWCO EZSV on WL @~ 10,505'CBL. RIH w/ HOWCO stinger & broke dwn perf w/ 1 BPM wtr @ 4000#. Sqzd w/ 50 sx cmt @ 1 BPM w/ press incr from 3600# to 4500#. Final sqz press 4800#, bled to 4150#. Rev 5 bbls wtr, 1-1/2 bbls cmt, & 10-15 bbls contam mud. Fin rev circ after sqz #2. POH. Perfd between Benches 2 and 3 from 10,478'-479' w/ 4 holes. Set cmt rtnr @ 10,380'DPM. Could not break dwn perfs w/ 5000#. POH w/ DP. RIH & set cmt rtnr above Bench 0 perfs (10,300'-320') @ 10,194'DPM. Broke dwn @ 3600# & PI @ 2000# @ 2 BPM. Sqzd w/ 150 sx to FP of 4600#. Rev out 2 bbls cmt. C&C mud. Well TBU D-9RD Well History Page 6 02-12 02-13 02-14 02-15 02-16 02-17 02-18 02-19 02-20 02-21 02-22 02-23 11,060'TD 10,957'PBTD 11,060'TD 10,957'PBTD 11,060'TD 10,957'PBTD 11,060'TD 10,957'PBTD 11,060'TD 10,957'PBTD ll,060'TD 10,957'PBTD 11,060'TD 10,957'PBTD 11,060'TD 10,957'PBTD 11,060'TD 10,957'PBTD 11,060'TD 10,957'PBTD 11,060'TD 10,957'PBTD 11,060'TD 10,957'PBTD Drld cmt rtnr @ 10,194'. Drld cmt to 10~324'. Spotted wtr across Bench 0 perfs (10,300'-320') & tstd to 3000#--OK. Rev out wtr. RIH to 2nd cmt rtnr @ 10,381' & drld on rtnr 1-1/2 hrs. POH. CO JB's, Fin BHA. RIH w/ magnet & 2 JB's to 10,381' · Washed junk into baskets & POH. Rec'd pieces of cones off bit #31. RIH w/ bit #32. Drld rtnr @ 10,381'. RIH to 10,514'. Drld on cmt & junk @ 10,514'. POH. Rec'd additional junk from baskets. RIH w/ bit #33. Fin RIH & drld junk & cmt 10,517'-524'. Drld on rtnr~ @ 10,524'. POH w/ bit #33--lost 1 cone. Junk baskets full. RIH w/ bit #34. Drld on junk & rtnr @ 10,524'. POH. Baskets full of junk including pieces of cone. RIH w/ bladed mill. RIH w/ mill. Tight @ 10,341-343'. Milled thru rtnr . @ 10,524'. CO cmt to 10,532'. RIH & milled on rtnr @ 10,590'. POH w/ mill. RIH w/ 6" bit & drld rtnr @ 10,590'. Drld cmt 10,592'-651'. Fin drlg cmt & stringers. RIH to PBTD.~ .Circ & POH. RIH w/ bit & 7" csg scrpr to PBTD. Displ mud w/ FIW. Mixed & spotted 50 bbls 3% KCl across Hemlock. POH. POH w/ bit & scrpr. RIH on WL w/ gauge ring & JB. POH. RIH & set Otis WD pkr @ 10,120'CBL. POH. RIH w/ 3-1/2" DP, POH & LD same. RIH w/ 3-1/2" GL compl string. Approx 4000' in hole @ report time. Fin RIH w/ 3-1/2" prod tbg testing to 4000#. Stabbed into prod pkr @ 10,120'WLM--tstd to 2000#. Spaced out & landed tbg. ND BOPE & NU Xmas tree. RU flow & GL lines. Began unloading well in prep to perf Bench 0. Unloaded total of 175 bbls FIW. RU & tstd lub. RIH & perfd Bench 0 from 10,300'-320'DIL w/ 4 HPF. Put well to test @ 1730 hrs, 02-18-82. Last 4 hrs test aver 774 BPD, 100% WC, 600 MCFPD GL. Flowed well 752 BFPD, 100% WC. RU DA to run temp log. Log showed sqz #3 (10,478'-479'CBL) as zn of wtr prod. NOTE: These perfs could not be broken dwn 02-10-82 w/ 5000#; therefore, were not sqzd. POH & RD DA. Bled dwn csg gas, bullheaded FIW into tbg, filled csg w/ FIW. Shot circ holes in tbg from 10,090'-095'WLM. Circ FIW dwn tbg. Fin circ well to FIW. Displ FIW w/ mud. NU BOPE & tstd. POH w/ 3-1/2" prod tbg. -RIH & pick prod pkr. ND tree & MU BHA to Fin MU BHA. RIH w/ pkr picker PU 3-1/2" DP. Tagged prod pkr @ 10,138'DPM (10,120'WLM). Milled over pkr & POH. POH & rec prod pkr. RIH w/ 6" bit, 7" csg scrpr. Circ & POH. Set cmt rtnr @ 10,391'. Estab rate into perfs 10,478'-479' @ 1-1/2 BPM @ 4500#. Sqzd thru rtnr w/ 50 sx cmt. Rev out 1 bbl cmt.~ POH w/ stinger. Well TBU D-9RD Well History Page 7 02-24 11,060'TD 10,957'PBTD 02-25 11,060'TD 10.957'PBTD 02-26 11,060'TD 10,957'PBTD 02-27 11,060'TD 10,957'PBTD 02-28 ll,060'TD 10,957'PBTD 03-01 11,060,'TD 10,957'PBTD 03-02 11,060'TD 10,957'PBTD Fin POH w/ stinger. RIH & tagged cmt 2' .above rtnr. Drld rtnr @ 10,390'. Drld hard cmt to btm of sqz perfs (10,479'). RIH to 10,957'PBTD. Circ & POH. RIH w/ bit & scrpr. Fin RIH w/ bit & scrpr. Circ & POH. MU HOWCO test tools & RIH w/ 3500' fresh wtr cushion for dry test on sqz perfs. Set pkr @ 10,599'--could not open hydrospring tester. Retstd pkr 3 times--still unable to open tester. POH to check tools. Fin checking tools.. RIH w/ test string w/ 3500' fresh wtr cushion. Dry tstd sqz perfs 10,698'- 10,699'; 10,550'-10,551'; & 10,478'-10,479' w/ no flow from perfs. Rev out cushion. POH & LD tools. RIH w/ bit & scrpr. Circ mud out w/ FIW. Mixed & spotted '50 bbls KC1 across Hemlock. Fin spotting KC1 across Hemlock. POH. Ran gauge ring & JB. Set prod pkr @ 10,100'WLM. RIH w/ DP--POH & LD 3-1/2" DP & 4-3/4" DC's. Began running 3-1/2" prod tbg w/ GL eqpmt. Fin running 3-1/2" prod tbg. Stabbed pkr & tstd seals. Landed tbg' & ND BOPE. NU Xmas tree & tstd. Conn GL line & glow line. Unloaded 175 bbls FIW. & tstd lub. Perfd Bench 0 10,300'-320' w/ 4 HPF. Cont to unload to test Bench 0. RU GL well w/ Bench 0 perfs open. Circ dry gas--perfs not prod fluid. Loaded tbg w/ 65 bbls FIW. RU & tstd lub. Perfd Bench 3 form 10,500'-10,520'DIL w/ 8 HPF. Lifted well to test. At 0700 hrs, prod 480 BPD w/ 0% WC from Bench 3. Tstd Bench 3 @ 697 BFPD, 676 BOPD, 3% WC. Released rig @ 2400 hrs, 03-01-82. FINAL REPORT TUBI,NG/¢.A5 I,N~ DETAIL WELL NO.: DATE: . BY: T'~5 Item Descri tion Set Size Wt Thread Grade,.. Ran~te Condition ,Length From To · . . .. . . . . 37~ q,; "~ ~-Bo ~; o, cml?. . . . P~.x,,. - ot.z u:0 F~..~.~.t - s.~e 44. s,4 a lO, lo+ . I · · TUB I,NG../C.AS. I, NG~' DETAIL WELL NO.: DATE: ~-A~-' ¢3),' _ . BY :.. · Item Description Set ::s Size Wt Th re~_d- ...... Grade Range Condition Length From TO _~ 39~ 9.2. A:~...... /v.~ ~?, c~,c~l~... /°~.~'o ~..31 ~I~I,RI- .', . . I ' ~ '~ , , . 1~, X~ esl ::~ ~ · ~ ~ ~,L l~.q. 919S.~0 , , . . _ . . . , Remarks: .. TUB I,I,I.G/C.AS. I, NG)' DETAIL WELL NO.: ,O-q~,D DATE: D.- ~,'/- qAA.' BY: TF-S Item Description Set ,ts Size Wt Thread Grade Range Condi tion Length From To , ~ a~ ~,~ ~ ~ ~,~, c~. ".~.i~ ~,1~.~' .. , 3~ x-o~ ~,, ..... ~ ~ * ~s~. ~;~ /~,o~ . z~ ~~__.~ ~, ~ ~.'~ p;~ ~,o3 ~.7~, i . - . . 'umarks; : ' -. (~ TUB I,NG./¢,AS. I,N~' DETAIL WELL NO.: DATE:- BY: Item Descriptior Set ~ts S i ze Wt . ___T_h_,.?ad ,Grade Range Cond i t i on Leng th From To ..... w - '~ ' ~ ~'/~ . , , . ,. ..... 1 . . , ~ '1 ...... , , , , ........ i ' ....... ,, ,, . , ,, . . . , . . - ..... :~na rks: . . -. TUBI,NG .... ETAIL x /"'"i~) qC'~-.~"~" WELL NO.: -~-~ ~-~) DATE: l-Zl-8~ Item Description Set Jts S i.ze Wt Thread Grade Range Cond i t ion L,ength From To .... !<~ %~ 7'~ ~-!ps 4~.4-7, ,'<~ q!.47 6~ 7 ~ff 8~ u-so ~5~,~3 ~o[.o0 .., ,,. , t Re~arks: 7", 29// Li net - N-80 Butt to 10,995' Window in old 9-5/8" - 43.5//, N-80 5721' - 5780' 3-1/2" Tubing 9.2//, N-80 ASL Otis WD Perm Pkr w/ 7.45' Seal Bore Extension set at. 10,104' DIL Perforations (DIL): Bench 0 - 10,300'-320' 8 spf Bench 3- .10,500'-520' 8 spf (-k~.,,~3U..~ D-gRD Completion Schematic~,,/ C1W 4-1/2 ASL % ASL Tubing Hanger 336' 3-1/2" Camco TRB 8 - Alpha Retrievable Safety Valve, ID-2.812" 2 392' 3-1/2" McMurry Type MHO GLM's w/ 1.O JR-STD valves' and BK-2 Latches 3888' GLM //2 5104' GLM //3 6143' GLM //4 6989' GLM //5 7635' 8195' 8577' 8872' 9168' 9460' 9667' 9873' GLM //6 GLM //7 GLM //8 GLM //9 GLM GLM GLM //12 GLM #13 Orifice 10,133' Otis Locator and Seal Assembly w/ 15~ of seals 10,183' Otis HalfC~ Mule Shoe (Bottom) PBTD 10~)57' 7", 29// Liner to 10,995' TES:jmo 3/3/82 TD - 11,O60' TBU D-9 COMP~ION :SCHEMATIC C1W Tbg Hgr - 4-1/2 ASL x 4-1/2 ASL 299 4-1/2" Otis AO ~ ID=2.125" 4-1/2", 12.6# ASL ~5/8", 40#, 43.5# & 47# ~tt & 8 rd csg 3427 . 4811 5868 " 6654 " 7213 " 7677 " 8105 " 8427 " 8747 " 9079 " 9411 " 9742 " 10,039 " 10,299 " 4-1/2" USI C2F mandrel w/ Guiberson M77 valve ID=4.0" l, ~ ,! 10,434 10,474 4-1/2" Otis XO circulating sleeve XO- 4-1/2': 'x 3-1/2" 10,476 Guiberson RH-1 Hydraulic Pkr 1/2", 9.3#, EUE 8rd 10,484 Tubing ~ail (end of cut-off) Junk at 11,152 PBTD 11,281 9-5/8" CSG 11,329 Perforations B-0 10,596 - 10,628 B-1 10,678 - 10,712 B-2 10,728 - 10,798 B-3 10,822 - 10,846; 10,868 - 10,898 B-4 10,918 - 11,030 B-5 11,070 - 11,153 NOTE: 30' bar gun & 2-1/2" x 2" gauge tool lost 11-15-75 ''i r.:! .... SORFACE · TMD ': : . · · .. . ~ · . . , · FI' l i::: MAHAI HUN OIL. COMPANYi f':.;-,. '-i.i :DOELY VARDEN iPLATFORI¥'ii' ,;'.F.'-i'-! I ,l ' I ' .~ ' ' J ' I ' ",J'.' ':-i" WELLiNO.D:-gRD -i.t '--i- ,.. I .... t-J 'L ,._1., :.~..i., ~.,.:,.I-iq-..EGA-2:.CONDUCTOR 5 .' ,,t,I i .i ' I i J I ~ ' ~ ,, ' · ~ ..... *"--1":, ............... A ..... l .... I. .J-l..i, ~ ' I , : , , ,SC LE I r I000 , I '-.'.'~ .'.!It .... I~, -:-I-. . , ...... '.. ,_,,, L. ' ~_ ' DECEMBER B 1980 , ''i~ t I '. , , - i'll J"'~.'" t~,,~,-I .... '~'".. ............ ~ ;' , ........... , ,~-'--..-~-~-,_~..z,_~, . ...... ~ ......... : t-.-, BY.--, .............. +~-1., .......... l ii, ~1[; BESSE:; EPPS;-I~;POTTSj"-~-; t-!q-_,L I.~t_.~ ' I l'! "t ' ' , ' ' . , ~ · '- - '- --~ - I .:~ .I _~_,_1 . , ~OR ~, ~ I';:l,t''!lj · : . '':' ' ' ' ' .... ': ,'- ",':'-I'. I .... i''J''.- -- THIBODEAU~ :I~IRE,CTJONALi DRILI21NGi i I i I ' r ' : ........ .- .-;-.J-, ~- ...... .~ ~ ~. ., .....,...L .... .~., _.]_, . . , .. , ?--~' :', ..... '.' .... i;' --:-: !':':"~'-;'" I"] """"! :""l"i .: .... -....i_.,.J. ;-.'- ;.~ ,_ .... .L:__:_.~ i.J-'- EL-[_' J-';jl .4-/ L.t.',: .;/:'-i'7,.}.T':" t..;..,-I.- -i-t-J-I .~ L. i. . J..,. j I-.!. i--:- t.-i.,i-- ' i 1'38:5 ~URFA~CE ']'- ',~' -t · TMD- =-625! .... ~" -' ' -~- '. .I TMD ' O J ~ ~J , ..... , . , ~- ' ~ -.. ;- ~ /. , .. ~ J ~ : . . t ~ I ~ ~. -i- .t ' " ": ;'" ~ '.~. , . i ~ ; ~ · J ' 9000 TMD , , ~ ~ .~ ~ -. , ,' ~ , . ., J ' ~ ' -- JI ', ' ' r t 'I ' ' I . '. ~ . .; J..1 .i.L . ' ~ , J [ J : ~"'joO~o'~b~', ~ ~:TVD :='·9550'j'- ~ r ; ' ' ~ ' ~ , ' , : ' , ' ; ' I · ; - - ~ - .~ ........ t ~.- . ..,,, ,..,., .., , I , i-.: .... .: ~ .... ,-~ .... J./ : I I ,.;.J.~.~ .... ; ~ ,, ~ .-~ ,. 4 J .... 20~ "" ...... 3000 ....... 4000 Mr. Ken Thoma Marathon Oil Company P. O. Box 2380 Anchorage, Alaska 99502 January 29, 1982 Re: Our Boss Gyroscopic Survey Job No. Boss-16963 Well No. D-9 (SEC6 T8N R13E) ~D Trading Bay Unit Kenai, Alaska Date of Survey: January 28, 1982 Operator: John Coogle Reference Bearing: Sparks S.W. Leg @ N22.51E Dear Mr. Thoma: Please find enclosed the "Original" and-twelve (12)copies of our Boss Gyroscopic Multishot Directional Survey on the above well. Each folder presents the survey in Radius of Curvature., Average Angle, Tangential, and Trapezoidal Calculations. Thank you for giving us this opportunity to be of service, Sincerely, NL SPERRY-SUN, INC. Kirk Afflerbach District Supervisor KA/pr Enclosures MAR 2 3 1982 ~i~ska Oil & Gas Coi~s., CoJ~'~missioF~ i T R l D I NG B A Y UN I T ' '" ':: ': :':: :.: :)'-":]' .:' ']:.. :.: ::. :: .:'.: :: ' .::?/'!i ::];:'i!; :] ....... :!:]:./:::.:]i/]?'!iii'ii~i)VER T I C A L: S E C T I ON D I R E C T I ON $ -4. 6 ' q 8- 0 0 ~' E KENAIv ALASKA BOSS SUR WEL BOSS-16963 .... NL SPERRY-SUN · '"'. . ii:' :!: :i< .:':': ::.i' ":~.:':::.':~i:.'~.":: R E c oR'O~~~V-~'~:~:· ii:?:::i:::i::i~//,:.::.': ... : .. ' ......... :'TRUE:::i:::: ':.':'/: : i: ":c:ou:R~:'£"::/i!ii?::: ' TOTAL ' :":":. MEASURED, ::::: IN::C E i'..:N:A T I :ON D.I R E:O::T~-i 0 N' .': cooRDINATEs. VERTICAL DEPTH DEPTH TVD DEG MIN DEG MIN DEG/IO0 NORTH/SOUTH EAST/WEST SECTI-ON 0,00 iOO.oo t i 200,00 }_.. 3.0.0,00 0.00 E 0.00 · 0 7,,'..~ ' ,43 ~ · 77 : 400.00 399.99 357.84 0 43 S 48 12 W ,57 1.10 $ ,03 E °77 500.00 "600'00' 700.00 750,00 800.00 799,49 757.34 7 lq · :-. :: ' :' t: .: :' : · ' ' · .' ' S 48..::'4.:22:::"'::)E::?:::::::::::::::::'22 5,59 S '5,52 S 40 .42 E 3.91 9,56 S 9,37 1,11 1.65 ~.2~ 7.85 13,37 9 12 50.00 849.06 80.6.91 7 49 S 39 6 E 1.24 14.58 S 13,56 00, O0 q 3: ':.: . S:.4 :::::::::::::::::::::::::::::::::::::::::: ::" .20.04 ::S ... o o. o o :::.: 99'7 ========================================== : 7 ':::'::'::::: -: 23'12' 27 ~ ..::: s .. '. oo.oo · ~. 22:'"::::::.::. s:::. . ~':~ s, 00.00 1193.~7 1151.32 ll 58 S"~5 18 E .96 58,32 S 19.87 27.01 61.70 81.63 1300.00 1400,00 1500,00 1600,00 1680,00 1291.06 1248.91 13 11 S 44. 5/+ E 1.22 73.69 S 72,63 E · :.:-.'::::.:::' '{::::'c-:.-~;~-:-: ?: -:.:-T .-': ...... ~' ~'TZ_~~- ---*---~,~?.--~~. : .... ::.::... :::.:: : ...... ~ .... , , 1 3 8 8 · 1 1 'i...:., :':'i:i':':1223~5 :-:29 62':'::.: ? ::t: ..i:::::'14.:: .:/+ 1.' :i.::::):. :" :::. '.::.: S: ~ 6':.::::::.:::: g:f::::E:: ::::. ::::": ::1" 522':. : . .90.' 5 7'S ' ,: : ;8 9 · 8 0: E'. - i 57 9. ::: :::::::: :::::::::::::::::::?:'::::::: ~.o::::? :::. :::'::.:' : .::::::~:-:~o · 8 85' E' 1655.15 1615.00 20 40 S 45 30 E-- 2.56 103,39 127.,46 184.23 2-fl~-l'~ 1700.00 1800.00 1900,00 2OO0,00 21 00.00 155.23 E 211.49 E 2~2,94 E: 275.13 E 586.27 218.20 ~5-5-'.-~-----} 297.37 3~1,37 2200, 2300. 2/+00. 2500. O0 2125.80 2083.65 26 51 O0 2303.75 · 2261.60 . 27:32 O0 2392,16 2350.01 .': .'2fl 11 307.31E 431./+0 3-3-9~--E · 47"g'"-7-5 371,45 E.: : 522.62 40~,145E 559,30 ~T-RAOING BAY ,UN_~T '"' ':' S.,46.-_~.8__~_0_0_~_____~. KENAIe ALASKA BOSS SURWEL BOSS-16963 ~"E'A UM S RED -N-'L~'-'S'~'R"'Y' -"' S U "~" ' '..... ...................... ~ .... ' DEPTH DEPTH TVD DEG MIN DEG MIN DEG/IO0 NORTH/SOUTH EAST/WEST SECTION 2600,00 ~.,~79,99 ............. 2.~,.3.7._,8~ ......... 21~ S___~_.~ ..... 36_.E ..................... ..,.~9 .......... ......,.. _..~3.~~ 4~.~G ~ egoo.oo ........ ~7_~2..o~?~:':?;.L?,;::.:~::~ .:..~. _s...~L~_;~::~;?:~::??;:~-9/":...'.'' "~_'~.: s ~_ __ ~.o~_ ~ . ,, 3000.00 2828.97 2786.82 29 57 S ~3 ~8 E .~2 576.63 S 572.75 E 665,53 714,18 812,25 3300,00'. :: .:.;':-: ~o'~9'.z 8'."::?~:?~:~3o-~7, o3 .~:?~...??:..../.:??ee:.?~o :~'-' s ~ z :-::':::'z'~?.E~;?~:~?~;S~?:::'-:;.~' s86'"'~:~-'.'s'.:~: : ~7"~, 0'9 335o..oo : .. ...... s _~ j __ _...~:.'~.~;.::.~:~?;:?:~;':~:o ' ~" :~..~.'' 3400.00 3176.02 3135.87 29 53 S 41 36 E .G4 723.54 S 705.79 ~62.~2 911,70 961.17 010.53 3~50,.00 · ~5dO,OO 3550.00 3600,00 3650,00 ~,3o ~..-5~?~i:i~ii::~:2~.5.'~;~-':~,iii~:i:~i~:i;:~:~i~:~?:~:i~!::~!!,:'5:i;:~ 'i..:~:....~:: .'.s ,5.z...?:3!!~ ~i~;:9~i~i~!~!.:::i:ii:ii: .~'.;~... 77-~"~:~'..~s:~'. ~:.:.. '?:~75:~ ,.:'~.~,~.'E: . z o e2. ~ 3396.28 335q.15 28 36 S 55 1.8 E 2.89 799.90 S 79~,30 E 1128,05 3700,00 {~5o.oo 3800,00 3900.00 ~+000.00 '-'s 5,, ii"--~:;:.'~..!.i:-~i:~??:~:'?8'i~':ii:.i:i.'.-::i.' ~,~.~.8...s .-...,'..i:.~y.~,, 'E 5699.28 3657.13 30 qO S 5~ 18 E .57 901.50 S 938.97 E 1176.69 1201.4t 1301.60 ~100.00 q200oO0 ,4300.00 4500.00 1352.,_52 1~04.27 1456.38 1561.38 4,600.00 l .... ~?oo.oo { 4800,00 I 4900. O0 5000.00 '~'~51~3'6~':~E:~:~.~:;:;:.'~.;:~:.?~'18 :'' 1122.29-. S 1229,76":'~,E /.:. 1664,72 ~'~2,~e'~:-:'':'::::'' 43~o.~4 ". :'~-~'o-~'":'~8'-''' s .50~:~;:30/:~-E'"'::'~?';:~??:;::';'::64::'' 115~.~6 S 1269.56 E. 1715.75 ~68,72 ~426.57 29 59 S 50 36 E.- ..:-'~_,-65._:::-. _}~_6.5_2~ ..... 1~_0~53 E 1_~6_6.,!._1 ............... ~555.99 ~513.8~ 28 26 S ~9 6 E 1.71 1217.97 S 13n5.8~ ~ 181~.83 TRADIN$ BAY UNI:T ;i;~/L. ii., ;::i :;i::'iii;:ii:.i..~::~ili! ~iT'IC.AL 'SECT ION D IRECTI ON S':46,.~8 O0-E KENAI, ALASKA BOS-S SURWEL BOSS-16953 NL SPERRY-SUN MEASURED VE C]LzNA Tt.~;ON~'~:~:~-;~::.: D 'COORDINATES;.; :.': VER T I CAL DEPTH DEPTH TVD ' ' ....... D'~-~YN ...... ~' 'MTN "'::"DE'~B~/ib'O ..... NORTH~'/'~oUYh EAST~"~'T~- ' SECTZON 5100.00 464q.10 4601.95 28 I $ 49 18 E .43 1248.87 S 1381,64 E 1453,1.4 E 1~89:, 11:i:: E 1524.86 E 1862.0R 1909.47 1.957,A8¢'% 2005,99 2054.91 560.0.00 5700.00 5800.00 5900.00 6000.00 5425.75 5383.60 32 50 S 56 5. E 2.15 1538.77 S 1560,50 E 1596..'3.7. E 1675.21E 2104,20 215~.16 220A.40 2254.68 1719.14 E 2306.56 6100.00 6200.00 6300.00: 6400.00 6500.00 5510,01 5467.86 32 22 S 61 42 E 2.63 1566.27 S 5 5 9 5 "5 4 i;.~/'.T'::.55%:3'~:3~.i~.:~i~;:~;!/:;:?;:;:~%~'. 4.. ~:;i','~ .?!:.'.!~-'~Si"~'5~8."? E~~;i'~!!:~ili~!~;~';i?:. 15 ~ 9.2 ~.: s . 5682. ?:.?-': 1608.38 s '~-'': . 5858.8~ 5816.69 27 2G S 72 5~ E 1.22 1636.55 S 1765.45 E 2359.13 181 1.86 E 2408.69 1'857:.'1'2'E 2454,80 1902.~3 E 2~98.19__j 19~7.33 E 253-9-';-8'~" 6600.00 6700.00 6800.00 6900.00 7000.00 S 72 1'2 E 1.06 1650.13 S 1990.52 -'-. '~;?:.ili!!;':;i2?;;:::i!..'. S 80-.;¢i;:,.30:;iLE ?i!!i!;?!~i??.5?;:::i~;~:.!~;:L::i:,?;.t 660..46:.. S...;..?:,::.~?:,, :.' :: .-;: .2 0;'5'2';~:::7.:. .;'::;":'Ei'~::?, 2580.62~__ 2618.'~d' '~ i 2652- 67" 2684°47 7100.00 72OO°OO 7300.00 7~00.00 7500.00 6407.50 6365.35 20 25 S 80 36 E .67 6501 '. 33 ..:?:;-~..?'.i: :. :!:6' ~5"~~' ;'!i:8' ~:~":-:.i:~i!:Ti¥:ii'~~ / 2. O':::~;;i~... i:.:~.~ ,:i'::.?:.~?-..::.-~"~ S ~': 7-9-~:'-:~ Z 6783.73 6741.58 19 17 S 80 18 E .47 1681.98 S 2184.03 E 2743 168-8';' 01 S '2-2-i~'0-9' -E" ...... -' 2-7'72 1694.50 S 2251.62 E 2801 1700.92 S 2284.78 E 2829 .48 · 32 { 1706.81 S 2317.55 E 2857.82 7600.00 7700.00 7800.00 ,7900.00__ 8000.00 6878.26 6836.11 18 47 S 77 3,6 E 1.0~ 6973'.16..i;;' ":: 6931'.01 .17';~¢8~T .. S 77:..12..-E.::~?i~??~:i. ii;~i'i/7~3-' :.' 7068.3~ 7026.19 i 7-:'::"45 S 7163.67 7121.52 17;':-26-' S 77 "30:E "?' ..-..~6 7259.17 7217.02 17 3 S 76 12 E .5~ 1713.05 S 1719.9~' S 1726,93 S 1733.75 S 1740.49 S 2349.55 ~ 2885.41 2410.17 E 2939.10 2139.61 [ 2965,24 2468~4~--E ...... 299'0-;89 BOSS SURWEL EOSS-16963 [EA URE{M- S D"' ' ';;' ':": R'"~=O:OrR O":!i'i;iOi:~"i!i':!;S':U:'"~f:V"~:"'~""~!? i~i?:": :z ...... ,.,. '... i'i:'.":ii':, '" . :., . '. . 'TRU'E?.t'???:!-'?:'..""'::'.: !'.:SuB::."i!:;i::'.'ii:L::!~?i.:'COUR S'E :'::-i. ';:i:~':'i'::::" :cOU'R:$E':::i.. :'?i~'i:~:.0~'~::~i'~?.'.': '- T 0 T"A L ::'~:? .'.' '):': ' ' , v E z cA:'C:;~-;':;;:L, .;.~'~.:;::'S ~ A: .-:;-:.:~;~-;~'::~"" c L'..~ ~T~~C~:T:~z- 0 N':'.f' '~..:;:~::~.~::;;"~'~;~';; ~_~ __..: C 0 0.:~ n' Z~ A~ ~ s ____ ~ Z C A L ...... DEPTH DEPTH TVD DEG NIN DEG NZN DEG/~O0 NORTH/SOUTH EAST/UEST SECTION 8100.00 7;~5_~ · 92 7;312.77 8 ........ ..: ' v,- . ' "",' '.':" ';..i;':;.: .:~:"2':"i!.':. ............ ,~ - !:Y;~-~',::'":~" ...... ' 2 00 · 00 '. :. 7 ~ 50.,. 82..~ .'..t: ..:~'~..':.::;.7.'~ 08..,'67 ':r: 1;; 83 O0,00:":' .:-. :.;":-75 ~ 6,:.'4'5ff:;~:;;~.':~-:;;~775:0~'30 ';:.":~"'" .. 1 8500.00 7735.86 7695.71 18 48 S 81 48 E .~7 1770.83 S 2615.83 E 3~19.07 8600, O0 ',,?oo.Oo ...... ~aoo. oo ~ __8~oo.oo,, , 9000.00 7925,65 '-!..:).:;il-.:.:.~7883'50." .....:..:.?. ??'i;; .i1'18:!/;iii:1 :?/?"::':i/i!!i?il S' .8 075 ~+:!!i~?Eii.:i~!!: ii!l!~:::i!!i.~' ! 780,39':!"Si'~;. 'i: 2678' 161'E 31 71,06 8020, :.; :':':!://?:!??.i:i!ii!8~iil ~il;!ili.'ii:i:~ii~iiiii~i~!!ii.>:'.' S :8I";ii/ i"6 :?:E~.~iil 2.97S';.?~.~.~'.' ."~/. 2709"'09/.[; :":',.'. ' ', 3196,96 ~.~5,7..0.:~:~ ~:: ':.. 80.73 ?~]4::.. ~?~?j?.?~"?~Sj'~?~:::'~.~6-'~?~/E.~?~:~? ~.3~./?:~' :: .-1790~09'"'?::.S:"~_ '.~:~:'. ?::.~73.9.., 70.::' E: .." ' 32~2', ~ .. _ 8211.17 8169.02 16 50 S 79 ~2 E 1.0~ 1795.0~ S 2769.03 E 52~7.33 910,0,0.0 ,,, to2oo,'0o .... 9300.00 9~oo'oo.:::.:: 9500.00 3~+27.1'9 3~+55.z~2 3 ~+ 8, 2_,LO_5_______J 35O7.7O 10100,00 i10200.00 10300.00 tlO~O0.O0 10500.00 9258.36 9216.21 16 31 S 77 6 E .65 1861,15 S 95~7':62 ,',?, ~: 9505 ' ~ 7 __2_!~. ..... S._76 ~ !~--E~,' ,,:t~7~~--S ....... 96~.5~ 9602.39 1~ 9 S 7~ 30 E .~9 1885.63 S 3098.~8 E 3532.~9 3125.~1 E 3556.65 3151.15 E 3579.57 3199.66 E 3623.25 10600,00 10700.00 10800,00 10900,00 32~5,~0 E 3664.91 ,3267.71' r: '36~,88 3289,60_E': .. 3~_~_~_,1.3 WELL D-9 SEC 6 TSN R13Wi' ;':;'!;' :"::"::':. '..-':. --,.-?., i:ii'' ;i: i";~: .'!!i!." ' TRADING BAY UNIT "" KENAI,~ ALASKA BOSS SURWEL ....... NL SPERRY-SUN HORIZONTAL DISPLACEMENT = 5802.88 FEET AT SOUTH 59 DEG. 5~ M[N. EAST (TRUE) ' '~ PAGE 5 DATE :oF.SURvEY. UANUARy AL. SECTION DIRECTION; BOSS-16963 I KENAI, ALASKA BOSS SURWEL ~EASURED VERTICAL SUB SEA TRUE DEPTH DEPTH TVD ELEVAT[ ON ' ' .................................... 342. 342, 300. -300. 1. S ~- ~2. ~oo. -~oo. [. s . . ... -~: ~:. :.'...'-:..:?:.--.... : .... . ..~: ...... ...: .. ..... ~.-. ::=~~,-. . ~. ......... ,,.~ ............. ~ ~_ - _ 8~3. 8~2. 800. -8oo. ~. s ~' ~e, ~oo, -~oo.. es.s 1250. .':-;.'-::,.:.:;"~..;;t~. ':..:':' .:-..~-::...'.z :~ .. '.¥' 1200 · ;" "?~:'~':. ::::::::::::::::::::::: ':.~:;:';<'~:?~?~ 1200, "' '. ..66 ·: S ........ .:..:..:'..-....' '. ,":~ ~ ~.:. :' : .:: . ::.'.' :<:;- '-:.': ..-,'~ .... : '~ - ·. "".~:;~;;:.'.'.:':.../.;- :;".':.::~:.:j.~:':;:;.'~.~i<:~'~,~.:<~':':::,~:::~..~ · .' . .:.. · ' . .~ z .e ' o. 5 0 · ..... '- ' ............... : ........... -' · ' ........... . ..... - .......... ...--.-- ............. . .... . .... .. _ 1353. 1~56. 1666 !7.7~ 1883, 1342, 1300. 1~/+2, 1600, PAGE 6 dANUARY 28, 1982, 199/+, 19~2, I900, 21/+2.:'::': 23,42. 2671. 2786, 2900. 3015. -1900. 23B. S 2/+1. :2-2:00' ! :.:,: :;:'-::'"' <::!;.-?'?i- ?~:!'~:::2~0:!0:'-:.: 2300. -23OO. 2~00, '2qO0. 2 7/+ 2, :::":'" ':::' ::>' :<-__~.2_700..::... :: :::'5 ~ ! o 28/+2. 2800. -2800. 582. . 2713'..S ' 277. · :::: ..3 09 ,';. :s' .:'. :.~" 313. .' '~.~:5:,:!!;! s:.,....: ~:!:.... _~_~.,_.r. 382. S 386. ~21. $ ~23, RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST -1300. 82. S 81. -1~00. i01, S 100. o, ~._,__E O, O, O, 3.3, 23. 122. 1 20~, 501. 578. BOSS-16963 f WELL D-9 SEC 6 TSN RI'Sw~ ''. ' ' "~'i':'i~ BATE OF SURVEY i TRADING BAY UNIT . ' ., . · .i-,i~ii';-':.:: .: ' ' ' · : :' :' .:. ".i ': ? !: ?"?: : i~ ~: :':;':~ ::- ~':,!~':~i'i:!'~¥~!'?':i::L:-;:::/??.~:.'/i~:i:.: ,:!i~;. :' : ,, ,., KENAIv ALASKA ! BOSS SURWEL ,,, .... : · .: -., - .~, · MEASURED DEPTH P~G~ .... 7 .... dANUARY 2fly lg82 BOSS-16963 :....~i:i ::!::.: i i; .;i :' ::: ! NTE RP O'LA T E: Dii..i!i~ ~i:E::.~:R":Df.i!i~!:!:~!~!iiiii~ii~:::~i~!:~ iii'"ii: :':: :: :: ":! i'i:'~:' :':: :: ! i:':ii/.!.i' ;; :i". ;i~;::':: : :.::ii..,:i:i.i.::':: ::~' !i:.~:i~?:' ..:.':TOT'AL DEPTH TVO ELEVATION NORTH/SOUTH E~ST/WEST 55~. s~,~2. ' ........... 3-~o-o;~:: ..... ~'":"~': ~:'~""~?~':'"~??~?'?"~'"~'"'~'-o;: .'~'~." 's"" 3703. 3442. 3400. -3400. 814. S 656' .... E 1 732. E ! '? 7 3-.--E 817. E ............. .....,. · .- ,::,'-'-'~,' .... :. ,l ,~. :{~;: L:::., :;.':...::?'~:,;..,'c~.?~:.: ";;,?. ~ - .· .'.~ . . . . .,, · ~167, 38~2, 3800. -3800. 953, S 1008, E ~28~, 39~2. 3900, -3900. 989. S 1058, ~ ..... ~ ..... :':' "'":":"?'":': ":'?:': :~':":'":'"':~":~'~"~' ........ ~ .......... ~"~'~ ........................... ~ ..... ~ ........... o o, '?: '~L:~i~;:~?."f%~:...~/..~iT~3':::~' ?~:s?::.~::/?:':7:: '~ 3 ~ o, ........................... ,.,., ................ . ............. :~:~ ~ o o.': ': ..:~;::~'~ :~ ~'.~:?S?:~::::..~:~f:)''~ ~ ~ ~. 5525. ~8~2. ~800. -qSO0. 1.320. S 1~62. 54q0, 4-9~2. 4900. -qgO0. 1358. S 1503. 5555. 5670. 5786. 5902. 6OZO, :!';i:'5:2.0 O' :!:' ':: i::.':. :: ::!::.:! ?;?:::i i;: ::: ::iill .:,;52 0 0.. ' 5300. -5300. 5~+00, -5400. 15 ~,~+. E 1556. E 1629. E 1510. S 1676, E 15~+~+. S 1728. E 6138., 625~. ~__6368, 6~81, 1619. $.:?- .1888. E..~i, 16 3 ~ 2---8- 19 5842. 5800. -5800. /' ~ C~ "K _ I=. ~ t, ,~ ~. ~..~ ,.., ~ ..... WELL O-9 SEC' $ '/T8'N: 'i~' .~/':/.-'i~>::/.: ';~ '-ii?:?!'!:' '; DA TE KENA!~ ALASKA BOSS SURWEL 'i.' ;'".:ii ;:!;: :::i!: 'i;'i,i' '';: ':-';'. "':?:::i.~'-'-~i':]i: !;~i!i ;.-! NTER P OLA TED'i/;:'I~.'E!CO R'D-'.:O'F ~.. SU'R V'E'?Y.'; t ':':'"~ ;' ' ". T RU_E. ' :: - - ' :.' ::i;:' ,-. ?':' -':' ...... ' :' .':.".(77. ~ ,~,' "- ':"~' '"' '" ' SURVEY,.. 'A ' d NUARY PAGE 8 28, 1982 BOSS-16963 TOTAL .... MEASURED VERTICAL SUB SEA DEPTH DEPTH TVD 6300. 6400. TRUE ELEVATION L.;-~!?';':::~i-:::,i:?:.'.;::::i.,:i ~,"' ?-O.~'. -, :'¥?! :':" :,:'. :",' ~.' ,-! .:'. :,~,, .:i:,,.,..::.,..!-, ,,., ..,6.0, ,0.' ...; ~.,: ..:,,,..: ,-.. RECTANGULAR NORTH/SOUTH 166'1 · ,'~ .S '. . 1'66' 7. 'i:. S' '; ....... _1 6.73 *" :.; S ...'.. 1678. S i684. s COORDINATES EAST/WEST ! 7562. 6842, 6800. -6800. 7667, 6942. 6900. '6900. 2035. E --! 20 ~o. ~'~ · 2160. E 2197. E . '.176 9 1"' '... S..'/.'i .... 2233 , -'17o,',. i' /. 's ?. ;i .' :;;i" "...', .. 1711, S 2337. 1718. S 2370. 2402. E 2433. E 2.4763-. E 8087. 7342. 7300. -7300, 1746. S 2'493. E 8191. 744.2, 7~00, -7400. 1753. S 2522. E 8401 ' ,ii,.:?~?::i::!::!:~:O:O.',::.::;:i:'::::?: ::::::::::::::::::::::::::::::::::: === == ============== = == == ==== ====== i:" ::::.:: :: :.i:::':':::i;-~'~:~ ::?::S :::': :: ' 25~, E 8612. 7842. 7800. -7800. 1776. $ 2651. E 8717. 7942. 7900. -7900. 1781. S 2684. E 8823. 8928' 903.2, , 83A. 2. 8300. -8300. 1802. S 2807. 844Z, 84-00, -SqOO. 1'808, $ 2837. 9137. 9241. 9451. 9556, 9662, o7~n_ :' :": 8 7 4 2' "::::? :':::::::':::: 7'0 0. :::::::"18 7 o o. 8842, 8800. -8800. 1813. S. 2867, E } 1818':: S ' 2899. E { .1825, S 293 $3.._~_ .......... : 1832, S 2966, E -MARATHON OIL COMP:ANY WELL D-9 SEC 6 T8N R151,J TRADING BAY UNIT KENAI, ALASKA BOSS SURI,JEL DATE OF SURVEY PAGE 9 dANUARY 289 1982 BOSS-16963 ::i:~i-:'.;i'i:-.::":-~::.'~:!;::;~,:i:::.~ii~f:--:.'::~':~!'::'"i: ::.:.~:::-:'.:i;~-:: iii?ii'~i!!!i::?:;:i!' :7~::::: ;:':i '~ N.:;'t~.R:~iO:C::~::~:Oi~!iif ~:~;C'o R'~'ii. ii':~:!: ..... ,.,' , -, ,' v .- ..., - , ~;-~: .... . ,. ,., ,.. , . .. ,:....,.~....,:,. ,. :..... MEASURED VERTICAL SUB SEA TRUE DEPTH DEPTH TVD ELEVATION "' .?'..TOTAL ..... RECTANGULAR C-O-O-R D I N A'~-E-S- NORTH/SOUTH EAST/WEST 0 1 8 ? · 9 5 ~ 2 · 9 3 0 0. ;-g~-O-O~--- ' 1 8 [7-2-'-S 3-i-~-2-2--E* - ' 0291, 9z+42- 9400. -gz+o0. 1873. S 31~9, E Z 060~' ~ ~:' . r ~: . : '.97/+2.o::-.;,!.,:i!::i::!::/:,':::.. . .. :- ..... .....,: .... . _._ 97 00'. ;':'~.797 O. 0.., 10705. 9842, 9800. -9800. ! 08 06, 99q'2 · 990 O, -9900 · 1,879- $ 1885', ! 8.92° ... $ 18'98; ~-S . 190z+. $ 317z+. E F 3199. E ~22~. ~ t 32q6. 'E 3269. E DEPTH · FROM 0.00 FEET TO 9991,q9 FEET ' ' ' '~':" '.?:'~'%%):.:?~.'7'.'":, *::.:-...:.:::., .-,:.: -...: ,~,-, ~.; :.J -- .~,;':,..~.. :.:~-~-,-~-~-,.~..~,,..,.,~-. . ~,~- , ......... TRUE NORTH 5oo! oo ~0o~,. oo ~s%.oo ~o°b. oo ~so'b. od '" ~0o5. oo ' o0 .00 .00 ,2000.00 H. I ZONTF L. Job No. Boss'16963 Well No. D-9 (SEC6 T8N R13E) Trading Bay Unit Kenai, Alaska Survey Date: 1-29-82 Scale: 1" = 500' -~.0~ Minimum Radius of Curvature ~~, · Calculation Method ~,,~ o ' 0.00 2000. O0 4000. O0 6000. O0 8000. O0 10000. O0 12000. 00~, · Job No. Boss-16963 Well No. D-9 (SEC6 TSN R13E) Trading Bay Unit Kenai, Alaska Survey Date: 1-29-82 Scale: 1" = 2000' Minimum Radius of Curvature Calculation Method 0900 ! I 2000. O0 4000. O0 VER-i-'! C.flL PBOJ'E C T ~T ON WELL O-9 -SEC :i::.' · KENAI, ALASKA BOSS SURWEL PASE 1 DATE OF SURVEY JANUARY 28, 1982 ._-VERTICAL.:S::ECTION DIRECTION S-~6~.4.'8-00-E BOSS-16963 NL SPERRY-SUN ;,. ME A Su R E ~ ~,~ ~:;?~::.~'~?~i ~L~:,~:,~:~:.~;.~':~;~..:~;~SK A~.~:?~::~?': :~/IN c L [ N A T Z 0 N DIRECTION SEV R E C T'A:N~'~;~ AR ;~ ... :COORDINATES VERTICA .DEPTH DEPTH TVD D'E~-'MI'N ................. D E ~"-M~'N ...... DEG/'i-~'O ....N' O~Y'~O U T H CK~-T'T~'~T ....... SE CTI-O OR[G[N AT SURFACE 0.00 N o ..... 5 .................. S-4.'~ ....... o .... ~ .............. ."o'b ................. .03:.-N.',. 0 20 S 58 4.2 E .25 ',2'0'::S'- 0 10 S 20 2~'~..- .34. .'62.:S o'-~'S s .... ~'8-"1'2-~ .....'57 1.25 s 0.00 E 0.00 .O'?-Lr-- .............. -;o3 ~ ! · 35 E ,39 ''t .~+9 E .78 i .0~--£ .9 o 2.28'S .14 ~ 2.75 S ,18 E ~,--3.3.'::,$ .... 2 · 4. 3 E 10.25 S 9.4.5 E ........ 4,725 8,36 } ' 13.89 850.00 84.9,08 806.93 7 ~9 S 39 6 E 1.2~ 15.26 9 0 0 · 0 0 :: -:-~1 ':'-;:i":-': .8 4. $ S .1 4.8 "i -'9 6 ............. 2'0-;'7"3--SW-' lOOO,O0 - ?!:i::.':..99';7!.'2.'.~ ?~ic.)55:'06L::..::'":-... 10 7 S 4.6 ::l. fi -1.,5~ 32,4.9. S. 1200.00 1193.50 1151.35 11 58 ..........'S"-~'5"-'i'-8-"E .......... ;-96-- ~--9.0 ~ 13.65 E 20.39 18. ~Y-E ................ 29.69 E ~3.88 - ' ~2.97 E 62.23 '5-7-.-2-7-- E 8"2~"1 '6 1300,00 1400.00 1500,00 1600.00 1680.00 72.69 E 103.93 109.18 E' 15~,7q 130,9q F 18q,78 f5-O";-2"4'-E 2'1"I ~-6'8 1700.00 ;1BO0,O0 1900.00 . 2000.00 2100.00 1673.95 1631.80 20 q8 S 45 4.8 E .85 154.,18 S J,'76'6:'59;::.:::'::.:::':.?:::i:::':,:I:72~..~'~+'----- .... ~3'"26" ' S 4.~.'5~ E -' 2,'~'5 ................ l'8'O~"~q'-S. 20~6,G9 1 994.54 2'G---5-'0 ................. S'" 45 '5'~ .... E ........... ;'3'i ............. :'72.02 S 155.30 E 218.76 211.58 E 297.94. I 243.02 E 3~1,94. j 275 · 2-2~E' 3'8'G. 83 2200.00 2300.00 24.00,00 2500.00 2125.92 2083.77 "2~"i :::::::::::::::::::::::::::::::::::: 172 2303"8 7,.': :::::.:/(':" :!:::.'.: 22 61 · 72 3 2 .. 2'8::::-;/..::' :':'"' ' 2 5 o.: 3 2550.00 307.39 E 431,97 3'3~;3~--'E ......... 4.77,32 371,58 E 523,19 qOq,23 E 569.87 TR A D I N G ,'.B A Y ;.U N ilT:'ii~?i:?'i:i~i-.:;ii:/.~ii:~;'?~.:'?!?i??...:?i: ';:.-':'ii~i: i.' V E R.TI C A L S E C T I '0 N D I R E C T I 0 N KENAI, ALASKA BOSS SURWEL PAGE 2 UANUARY 28, 1982 $-46-48-00-E NL SPERRY-SUN :~ ....... :~:~.::i:~:!~:::~::!::?i~::i~:i~i;:.~::~!::~i~:~::~::i?~!:!i~;i~!i.:~i~:i:;?;::!~;?~;`~%?:~--.~ ....... ? "-.~'"~'E-C'O~D '-0F SURVEY --,. ~~'?'::' ....... :-; .......... ' ' "' .NEASUR.ED-. [_N_~_~,Z,N,A~.~. Q_N ....... D [RE, C T.!..9~ ........... SE V __RECTANGULAR COORD [NATES DEPTH DEPTH TVD DEG N[N DEG NZN DEG/~O0 NORTH/SOUTH EAST/~EST BOSS-16963 VERTICAL SECTION ,.__.2~. O2,o :::::::::::::::::::::::::::::::::~:? ~:-:~Odi:;.os '...':....2 9.,--_a_o ::--_".--:::::_s_..'~3 ...... 1..~ .... [_.., ' , 2 9: - 3000.00 2829.10 2786.95 29 57 S 43 18 E .62 ,~7o. ~o--s?": ,~Tl.~S-'r 505,87 S " 505,46 E 5~'1.35 S :' 538,95 E 577.38 S 572.84 E 617.64 666.10 714,75 763,46 R12. 83 3100.00 2915.78. 287.3,63 ..... 3 ~'° o"' o °'~:i::iii~::~ ~i/eo;:;:315.~,:':::.....:.129.52'.:-:.:::::::.:.:-:.:.', S 3~00.00 3176.'14 3133.99 29 53 S ~1 36 E .GA 72.~.29 S 706.89 912.28 961.75 986_,39 1011,11 1.73 742.57 S 723.52 E 5.06 7.59.501. S 740.66 E 5,94 7741.22'.?S.::':::.::'::.. '758,60 E 1.~2 787".'4111i:'~::i.::~i'::'i:._.: 777,20 .E 2.89 800.65 S 796.~7 E 1035.75. 1059,83 1082,99 1105,57 1128,69 81~+.53 S 8 2'8:;.: ~, 5:::': s :'"' 2 .... 8.~ 2:* 9 5..", S:..:. . ~:'7.z.13. 8:/.;,s:?:::::. 902.26 S 816.~7 E 1152.77 836,90 E 1177,32 857,41 E 1202,05 898'1.7 E 1251,93 939.1A E 1502.24 1353,17 1404,92 1~57,03 1509,A2 1562.03 4600.00 4'210.91 4!681_?_6 ~! ..7. S 51 36 E .87 ::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::: ":.~o ~ s :o ~o ~ - .~ 5000,00 ~556.13 ~S13.98 28 26 S ~9 6 E 1.71 1091.05 S 1123.05S 1155..'22.:S-' . 1187.29'"S 1189,55 E 1614,01 1229,94 E 1665,37 1269-7~ E 1716.41 1308,71 E 1766.76 121R.75 S 1346.01 E 1815.~9 DATE OF SURVEY JANUARY 28, 1982 ..¥:ER:T'!iCI~L:'- SECTION DIRECTION S-46-.4.8-00-E SPERRY-SUN MEA".$URED :Vi~i:iR!~!:~i ~:!A:i.!,!i?:;:,,,.:I;-.,NC'~L_!~.N_~.TIoN.'' DIRECTION SEV--: :~:i.:::RECT.AN'GUL'AR:: :.' :CooRDINATES .DEPTH DEPTH TVD. DEG" [ Nm DEG ,IN D?_-G/IO0 NORTH/SOUTH E A-~-T-£~-S-T BOSS-16963 VERTICAL S.~TION 1249,65 S 1381,81 E 1862o7~ 1312,-87:'..S!'''::':'_'':' 1~53,32 E 1958,14 13 ~ 5, ~3-:':~'S:.: 1~89,29 E 2006,66 1~78.83 S 1525,0~ E 205-~"58 5600.00 5081.66 5039.51' BO00.O0 5~25.89 5383.7~ 29 ~ . S..~6.12 E .41 1~i2,~8's 1560,68 E 210~,87 30 13 S ~5 36''E ....... r"'";'~7'" 1~7,65--S~:':~ 1596.56 E 2154.83 SO 14 S 51 5A E 3,17 I~oO,SA s 1634,~1E e205,1~ 30 43 -.s ~_~..~.__E ....... : 2,23 1510,62 s 1675,~6 E 2255.~5 .... 32 50 s 56 5~ E 2.~5 i539.64 S 1739.~0 E 2307,35 6100.00 5510.13 5~-67.98 32 22 S 61 ~+2 E 2.63 1567.15 S 1765.73 E ~359.95- -6 2 o o' .:o'io'?;!:'i~!!:~ii.5u195:i~:!5 ~ili~:i:~:5:3.:?:'-"B:.-O.'ii~:,i:i:~.:.~.~':~":.-. i::'.::~7~'0'"'7~.': ....... ;':"~ ;:..~ ..... s..~'' 6'5 ':~"~'e'~T'-~ ':.-T~ 6300".00:~..??':::~?~::~56::827:~7~56~0.?:~58;?::)'....:.-~'.::::....'28..50-'..":':.. ' S-6'8'.2~ E .' 1.78 .16.09.20;:::.:"S?.'.:,;':?. 1857,50 E 2~55,6~ o.o. oo 9 ,;,::.?: 6500.00 5858,95 5816,80 27 26 S 72 5~ E Z.22 1,06 i650,96 S 1990,97 E 2581,52 ~ 1.70 1667':'"'17:~:S..' . 2074,67 E 2653,62 2'01 1672,"29:::S''~' 2113.51 E 2685,~W 20 25 S 80 36 E .67 1682,78 S 19 52: '"-":: S 78 48 E .., 261i.. ";:.!-:!::::: 1'695 · 50 S 19 37 .- S 79 18 E ,'30' 1701,72 S 19 17 S 80 18 E .~7 1707.62 S 218~.61 E 27~+,46 --22-1' 8-;'~"8'-' E' ....... 2773.~ 2 2252.21 E 2802,30 2285.37 E 2830.87 2318.14 E 2g'58.80 7600.00 6878.37 6836.22 ?e o o. o o e .:3 o ' 8000.00 7259.28 7217.13 1713,87 S 2350.15 E 2886.~1 17-2'0:';'-7'~-'-S----- ...... 2380-,-9-i--i~-- ..... --2 9'i-3';' 5 ~+ :1727.75 S 2~10,77 E 2940o10 173-4,57 S 24~0.21 E 2966,23 r T R A O Z N G ': e'A Y./UlNiZ:':~ii::'..ili'.i.i~?,??.t:':;~.-i:.,:~??/i;.:i/.ii:!i..~:..:i:;::.' :.i ;:'..:.:-.'- :: · '" -' KENAIe ALASKA BOSS SURWEL PAGE , DATE OF SURVEY UA'NUARY 28, 1982 VERTICAL SECTION .DIRECTION S-,6-~8-00-E BOSS-16963 DEPTH DEPTH TVD DEG MIN DEG MIN DEG/iO0 NORTH/SOUTH EAST/WEST SECTION 8500,00 7735,99 7693,8/+ 18 8600.00 7830.80 , 778..8~..6.~ ..... _..J8...1.6_ S 81 12 E. .57 ~oo ,:o o: ?~?~:?~f8..~ :~'S~.~?~ ~:8'o7 ~, ~,._ ~ooo.oo ~.3o 8~6~.~s 1771,72 S 2616,45 K 2,97,-1j__~ 301.6,99 252~,62 ~ 30,1.67 2553,09 E 3066,95~'"~ 258.. 17 £ _..30%~.~.? .....__~ 3120.13 __ .~.!...~. 6_.2.! ......... __, 3172.12 __] 3198.02 3223.62 ......... 32q8."0 9100.00 , 8307.11 826..96 16 29 S'79 6 E .39 1801.21 S I "9'2'0.0 "0' O' :/? '",. "" ::'8:~02i;:~9115~ii;~'i8'~'/~'2-g0':'' ........... '"'i6:'",~'i ................. $" 8 0 ::'i'"O-i';' E ....... *-3 3 ............. i"~'O"gT~-~-~- S 9300,00'-~-::(~:::.:.:~'~:8::~98:~;6~f~~8~56,~9.' i7 5 ' S' 80 12 E ' ,~0 ~811,3a S 9500.00 8689.11 86~6.96 18 ~0 S 79 IRE 1.04 1822.21 S 2 797.83 E 32,.,.7_2.,,5.5.: 2825.90 E 3296.55 285/+.51 E 3320.82 2883.89 E 33"5.79 291~,53 E 3371.99 9600,00 8783,63 87,1 ./+8 97 00 ' 00'"' ''~ ..... 8877 '='85~i?i~!;ii!!~:~:88352 ~'O- lOOOO.O0 9162.80 9120,65 ..... ~.~..2.6 .................. $ .... 78 30 _F ...... .81 19 '+. S 77 .8 E .38 18 36 S 77 12 E 1.15 17....~.~, ........... :.S_ !8 ..... 1.2_.. r.'. ........ !.,.. 08 17 10 s 76 5, E ,56 1828.50 S 1835-38 S 18'.2:'.8 S 18-~9,10 S 1855.53 S 29~6,55 E 3399.6/+ 2979, 36 :' 3/.+28.26 30.11,~1 E 3"56,.9 3o7o.89 E 35o8.?~ 92q8.52 .9,2!6;_37 !~. o ~ oo. o o ..... ;~':.:~::'.~.:ss'~'+i~:i.r':zi;~!ii?i?;:i;:-:'~'~z ~ . 10200.00 io5oo.oo '~,~,.'7o ~o2.5s 16 31 S 77 6 .F .65 1862.05 S 15-35 ........... S '76 48 ...... [ ......... .'9'~" 1868.29 S 1,5 -'5 S 76 36 E .5.0.?...":.:,"~,:..~187,:.38.::.._S '1,~+ 1'2'1.' S 76 18 E '7" .::!:~:; :::: .'!:.: !')i ? 1'8 80: '3'3~:"S 14 9 S 74 30 E ,/+9 1886.53 S 3099.12 E 3533.fl2 3126.05 E 3557.73 3151.78 E 3580,65 3176o48 E 3602,73 3200.30 E 362~.34 ,1,06.00.00 97"!,79, 9699.6. 13 35 S 75 0 E .58 1892.8. 32qG.OZ+ E 3666.00 3268.36 F 3685,96 3290,2/+ E 3705-21 PAGE 5 DATE OF SURVEY' JANUARY 28~ 1982 VERTICAL~iSECT.ION:,DIRE'CTION S-q6-~.8-OO-E NL SPERRY-SUN ' :~'~':-:~: '~-" ~' ....... :" ' .~' FY v ARE BASED ON THE A VERASE,'ANSL. E':"..METHO'D BOSS-16963 HORIZONTAL DISPLACEMENT = 3803.89 FEET AT SOUTH 59 .DEGo 53 MIN. EAST (TRUE) i TRA DJ: NG__ BAY UN I:T:::.":":':,'::~i-: ::<!...';. :':i-:,;':'., .,... ' . ...... KENA!9 ALASKA BOSS SUR~EL DATE OF SURVEY JANUARY ~GE '6 289 1982 i'":,... ::,?>::~i:.i<!.?iii'?)::ii?i!i!!~ii:i::~ii~!i~:.~:£:::', ,:: "INTERPOLATED .RECORD OF,' SURVEY MEASURED VERTICAL SUB SEA TRUE DEPTH DEPTH .TVD ELEVATI Off 1 '- .., ,~2.:, ..<.'~:.?. ii,:.'!i:.?.~.ii?!?'.~:i:i:.::.!,!?!i!!:i:~i'?~?.': ::'.::.i :::::'~ 2'. ~i." .'-:::-.'-:: .' . 0 -.. · :... 0 · :'- ' '"'.:'.)' ":-...~ . T__O__T._~ I,_ RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST O, N O, W { .0· S O, E~ O, S__ 1· E 1. S O. E 1- S O, ~ · .-600," ~ ZOO . , "" -fiD0, -900, 3, S O, W ~, S 1. E 5, S 5, E 1~+, S 13· E 26, S 23, E 11 `48 ', :': :::<.:'.:::>:;;:::.t:::!:!;!~!?'~i!'?~)!i': !~i~:i.~:f+2:-:'~(::sii!::<:..':.!ii.:?.}<~.. ' 1100 · "-11':00 · -- 1353, 13`42, 1 300, -1300-, 1`456. 14,42. 140 O. -1`40 O. 52· S 50. E :67. S 65. E 83, S 82 102· S 101 · E · E 122· S 122 1`46. S 1`47 1.73. S 175 205· S 206 239. S 2~1 · E o E · E · E 221 s. :'....!<:::i:~?i;~i! :2':I,, 2.' .'~?'.:':': :' ;:.:.-' 2100. ': - 2. ~o o, .2331. 't~::: i.,:'i.'?!i::':! ,~'24'2"* .' !" :"" 2200. ' '2200. 2`4`43, 23`42, 2300. -2300. 2557, 2~2, 2~00, -2qO0, 27`4. S 27"77' 310, 3~6. 383. 313 386 · E · E · E · E 3015, 3130. 28~2. 29`42. 2500, -2500. '' '2600, :" '2600. 2700. ' -2700, 2800· -2800. 2900, -2900. 461. 5.00, 5~1, 625. 462. 501. 539. 578 · E 617, E WE L L D'9 :!i SEC.~:::/.6!::::!:'i.?.TSN KENAI~ ALASKA BOSS SURWEL DATE OF SURVEY ............... PAGE-"7 UANUARY 28~ 1982 B0~S-16963 "::? ~i::.:.::!:"-/!i~i:/:!!?:::;?::::ii::¢:!~? INTERPOLATED RECORD' OF. S'uRVEY ' "~" - t.'''!' .'.::: ~:'!-:~::i~':.:.:";i~:?ii:ii.:':~iii~:~i~ ~'::i:::i:ii,:!:.' :'./ :::::::::: :::::::::: ::: :'~.-.:'/.:.'.'.:- :.::..: · . MEASURED VERTICAL SUB SEA DEPTH DEPTH TVD ELEVATION .TOTAL R-L-~'C- T~ N G U L-A-R------C-O-O-R-OTN"A-TE:'S' NORTH/SOUTH EAST/WEST } ." 336 I':', :~::~4~:;~?;:;~:~:;~i~:~?~ii!?ii~?i~y~;~:?~:::i~!i~3~/+~2~~.:~:.-:. "'~i:' :': ::.:. '-'. . 3100.. -.- ' . "' - · ~...' . 3100-,. .... . · .' ! .:i'..::...'~.,+,r~':~?ii ~?.;~e;.~:~;2::?~:?.'~;:::.':.':'..::~::___ -~. :...~2AO:.::.::":,':". .... ":'._ ~ .... '?: ':?-/~-. ...... ._:~_~_o3~:-.. :~ .:..: 3589, 33~2, 330 O · - -3300 · 3702, 3~2, 3~00. -3qO0. 6.6 7'; S "6"57. 710, S 69/+, 752, S 732, 7~5. S-- 773, rE 815. S 817. E /~1 67, 38/+2, 3800. -380 /+~8~, 39/+2, 390 O, -390 8/+8.S 883. S 9_~ :'7. 's 953. S 990, S 865, E 912. E " 960 . E i'O-O'-8-~--E' 1058. E · 1107, E' 1156. E 120/+. E i'251. E 1297, ': 5~.~' :i;:i:.:"i::i::i~ ~!!~.;ii.~:.'~i!,'~ii~i~-':.::~' .:.,+,o.o. : ;'.--,~7oo' .~,?.-':;:?:~,:::.:.;???:::::'i~:i'....::i.. ~.s,,- s ~5. ~8~. ~oo. -~oo. ~. s 5~qO. ~9q2. 4900, -~900. 1358. S 1381,... 1422. 1%63. E .... 150/+, E 5902. 53/+2, 6019. 5/+/+2- 5'100, '5100. .1/+37..'S _ 5200, -52.00, lq79. S 5300'-. -5300. 1511. S 5~00. -5~00. 15/+6, S 1586. E 1626, E 1-'8'76. E 1728. E ~ ~ ~ 8. :.:.: :'.":"i'.:.::i..?::i!~..i~!~i;i:i~:!ii:i~:~?i.!ii:i.i?iis 2° 6/+81, 58~2. 6593, 59/+2, 5 5 o'O', ............ :-:' '-:,:~-~%'7o-,-~' :"-:.: ' Y 5-7'7-;--s .. 5600. :::-5600. 1601. S 5700. -5700. 1623, S 5"80o. - 5 80'0. 1%-,3/+ ·s 5900. .r~q~. ~n_ ~ 'f?'8'2";--E- ...... 1fl36, E 1887, E OF SURVEY UANUARY PA3E 8 28e 1982 BOSS-16963 :~/!?.;i{!?i:i~i~:?:'::;..- ' . I.NTERPOLATED RECORD OF sURVEy. TOTAL HEASURED · VERTICAL SUB SEA TRUE RECTANGULAR COOR DEPTH DEPTH TVD ELEVA T ION NOR TH/SOUTH EA DINATES ST/WEST -e~o.o-,.,~.:!.::.::~/?.i?::??i~::::'.::.'i.. :. 1~7~.; s -6300. 1679. S -6',00. ~s. s 2035, 2080, 2122 · 21 21 60, 97. 7562, 68~2, 6800. 7667. .6942. 6900. -6 - ~s':7_o:'o .....:;: -6800. -6900. 1692.' S 1699, S 1705, S 2-~"33, 2269. 2304. 1711, 1718. 1726. !733. 1740. 2338. 2371. 24.03, 2~33, 2464, -7300, -74.00. 174.7. S 175~+. S 2493. E 2522. E ' I ~.:84. 01 .':;,?:.;i;~':::i. :~::~i:;~::~!::~'~'~.'~:?~.:i~!:~i!?~:;:,':' ...'"':: :. ".' · '"7600 :-.. ': ..i?:76'0:-0' . ' - 1 8507":":~:~';~;~:~;;~ :;~:::.~:~:~,?:~2:~:~:~?;~:?~:~::?:: .;: ' ' 7700 · :'-' - ~'f'..;..?.'¥...,770 O .:. ~-':..':;:'~. :';,.' 8612, · 78~2. 7ilO0. -7800. 8717. 794.2. 7900. . ': ".88232::' 'i~'::-?:i ~18:10:i~::2~ :;!?':!i-:!~':'' :: :-::'::'-? ;":-~?d o-o"o';i .... · ' 8 9~8. ~::.':'~::::':::~ ::~;:~:::~?~'~:~;~:::;:~'8-i"4:-2:~:~:~::::.'¥:':'~.''::~'.- -' '-' 9137, 834R, 8300. ~241. 8q42. 8qOO, -7900. 1 -8300. -8~00. 762. S 2552. E 7'67. S 2584r E 772, S 2618, E 777. S 2652. E 782. 'S 2684. E 1787. 179.2. 1798, S 2717, E S 27/+8. E S 2779, E 18.03. S 2808. E 1808. S 28;58. E '95 s e. :~;i?:i!i'?:~!?~iii: ~/i::8'~ ~.2 ;.,:;?:~i. :'.' :.f...'-;::..:. :.. .... ,_ :_...~Z.o_ 9662, 8842, 8800. -86'00. ...... - 8'7 O'O. ~.i -?:.; :'''';~:: ' -8800. 1814. S 2868, E 1819. S 2899, E 1825, S 2933. E 1833. S 2967, E DATE OF SURVEY dANUARY 28~ 1982 BOS$-16963 I.: .' '.~'. '":' INTERPOLATED RECORD' OF MEASURED VERTICAL SUB SEA DEPTH DEPTH TVD SURVEY . TRUE ELEVATION RECT NORT TOTAL A-~"~-O'I..-'~' RO'-d-O-~'D'I NA-TE- S H/SOUTH EAST/WEST .1:008.3":~.i:iii':::'ii~:i:.ii~i:~i!i ii?.2.?.:2":i,."'i::.:: 920.0_, ' .- '. .-9200., o~,?. ~,,2. .~oo. -~,~oo. 0291, 9442, 9400, -9400. 1854. S 3065, E : 1861, S 3094. E''~, } 1867, S 3~'~;--£ ...... 1876. S 3149. E z'o~oo, : : .~70 o, "-' /.."~,7-0 o. 0703. 9842. 9800. -9800. 0806. 99~+2. 9900. -9900. 1880 · S "'3':1-75 · 1886. S 3200. 1893. S 3224. 1899, S 3'2:472 1904. S 3270. ~i~~ i!i~O.O'RDiNATES: FOR: EVERY 100,00 FEET. O. Fi-:!i: S'UB'.'SEA':'DEpTH; .'.-:. - ...... 3'2' 9'0 FROM 0.00 FEET TO 9991,65 FEET HON O. tWELL 0-9 SEC~:6 T'SN::i..Ri:3W _.T RA D I NS !~ A.'y.. ':.UN' I~T,{:ii:~;~i~i::ii?i::~!~:?:ii;i~:;~ii~;i:~iii~:i~!i:ii~{~:~?~i:::~ KENAI9 ALASKA BOSS SURUEL .... ~ .................. -- ~GE. 1 DATE OF SURVEY dANUARY 28, 1982 ........................... VERTICAL SECTION DIRECTION S-46-48-00-E B0.S'S-16963 NL SPERRY-SUN . ': ' .: :'~'::.:.:::~.>~<~::';~'~.}?:~?:?~:~.~~}~ ~~:~?~?.~}?~.::~::-:~<;: ::CouRSE:'~. COURSE .....: '. DOG- EEO... : : .':.~:':'"'-~'-~":::'::'TO:TAL. DEPTH DEPTH TVD DEG N~N DE$ ~[N DEG/~O0 ~ORTH/SOUTH EAST/~EST SECTION 0.00 N 0.00 E O.LO_O. · 05 S ,05 E ,07 ! ' ~.,26.'S' '~: ,35 E .43 i "" ... _~,~ s .55 .E ............. :.72_,~ 1.10 S ,03 E .77 1.65 4,24 7,85 13,37 8o6.8.8_____L7_. 4.9 ......... S 1151.29 11 58 S 39..6 [ ...........~.t_24 14.58 S 13.56 E el ~8 E 1,96 20.04 S 18.23 E 46 18 E 1.58 - .51.76 S ' 29.63 E - . ~6 2~E ' .92 4~,43 Sm 42.91 E 19,87 27,01 61.69 ~5 18 E .96I 58.32 S 57,21 63 73,69 1300,00 .12.91,._03 12~8,..B_8_~!.3.._1.i~ ......... $ ..... ~4_...~__E ....... .1..,..2_.2_ . '~'-.~'~'~ l~oo.oo '<': 'ii~'~a~',;~?o~8~<~;~;~.~'~1:3~"5-:~'??' i~ ~l - . '-'~ s. ~6' o ~ · i,.5~ -' ..- lSSO,OO 1655,12 1612,97 20 ~0 S ~5 30 E 2.56 148.~9 S 72,63 E 103. S 89.80 E 127. S.. . 109.13 E 154. S 130.88 E 18~. S 150.17 E 211. 39 19 12 1700,00 . 1673,8} 1631,68.' ..... 2.0.. ).8 .... - ..... S 45 ~8 E -iSoo.oo'.'i"~:;-i.;.iii;~'<:!ii~ii.i~i6!;~:."i 26-' '_.<:-'i'- ..... S'~"'~ .... 5'~'- E i ~ 00. 00 .~:.:~,~:.:.,:~~; ~I~i~::~:-~-.~:::~'~:~h'.:.<.::,~.:. 25 '>.~ 1 -s ~ 5 ~ 0 E 2100.00 2036.52 199~.37 26 5o s ~5 5~ E .85 153.~ S 2,65 179.,91.:!-S .i 2.~2.6 209.18"".S'..;:i~!.:.'.~ .... °85 239.'-97 S 155,25 E 182.00 E _..21:1,-49 E 242,93 E 218,20 255,.82 297.36 3~1,36 · 31 271,27 S 275,12 E 386.26 -' 2200,00 2125,75 2083'60 '_2.6 51 .............. S 2500.00' "a.~,~_i_.'~.';~..:.._.~_ .~ s .~ ..... 12..E -:~ .~8 2550.00 ~e.lo ~3~.~5 28 ~7 s ~ ~ E .87 302.95 S 367.89 S: 401.27""S 418.31 S 307.30 E 339.24 E 371"45 E q-Oq'.14 E 420,73 E 476.74 522,61 569.29 593,05 ~"~;GE · 2 --~-'-~ DATE OF SURVEY JANUARY 28, 1982 I VERTICAL SECTION DIRECTION S-46-48-00-E NL SPERRY-SUN · ' ::' :~' !o:Btlii-:i.i;'i.!ii?:?<i-'iii!'.~-J-ooURsE · ' '.' COURSE .' '.nOG-LEG ' · TOTAL' ' ' MEASURE'D??:~:~??~'~T:'~?~ ':~A~'~';~'~I:NC:LINATION''': 'DIRECTION'.. SEV: RECTANGULAR:. COORDINATES , ,.· ,, · ', ': ... · "..' '.' :.....-..:....'...~.~.,.....-.v:,:.,...,,.,..:.....,,:.~-...,..,........ -., ~...-..,:......, ,,. .... ;__~. ............ ~._~ ~ ............. ~-. ~ ........... ~. .. _ ..... ~.~- DEPTH DEPTH TVD DEG N[N DE6 ~[N DE6/[O0 NORTH/SOUTH 'E~S~~ST B0,SS-16963 VERTICAL $'E-C-T-I-O-N 2600.00 2q79.95 2437.80 28 z~9 S 4~+ 36 E 3000.00 2828.93 2786.78 29 57 S ~3 18 E · 62 576.63 S ~37.56 E 617.05 ~71-,-5-5--~ --665.52 505,36 E 71~,17 s~2.~,~ E ~2.~,+ 3100.00 2915.61 2873.~6 29 52 S 4,3 12 E .10 612.95'S '-::32 oO'"o'O::.::.~:i~:?!~!3:.~i~! ii~O~.!~'~?,':L:?i::::'!' ~'~--"~ ~'"~ ......... -TS'::~'i"~'~"E ............... ;':~d~ F~S'.~:~;~-7:.'TS~ 3~00.00 3175.97 3133.82 29 53 S ~l 36 E .64 723.SW S 606.91 E 862.01 6~0.87 E 91.'1.70 67~.09 E 961,16 690.38 E 985.80 706.79 E 1010.52 E 1.73 7~1.82 S 723.42 E 1055.16 E ............. 5.06: .'. 758.7'~-'-S- 7 ~ 0.5-3--';~" . 1'0'59.22 E 5.'9~ ':.." :.'.:' 77':$'~6":'-S.~...i'i;"-~:,'.'' 7'58..~3 E 1082.3~' E ,- ' 1.92:::;.'?-~-? ,786-65 ::S.?.,~.:~;~;:::'~ 777.0,3 E 1104.92 E 2.89 799.89 S 796.29 ~ 1128.0~-- 3700.00 3~39.89 3397.7~ 29 41 S 55 12 E 2.17 813.77 S 816.30 E 1152.12 ~oo:'oo'.:?'..>:.f~:~?~"'s~:.~ ~:~'::~:;-~.~:::S~?~::::.::.~::. ~:o 7 s '5~ ~'E .8~ .: :: ~.-l:~ s-:'/:':.:;:. ~57.~ E 12ol.~o -- - . .....· .... : ..:,................,... ~000.00 3699.22 3657.07 ~100.00 3785.06 37~2.91 Sl 4 S 53 18 E .65 931.79 S 980.36 E 1352.51 ~ 200.00 4'3 ...... . ............. S .... 53- i'~- "'E',':'"~';'~5 ............... ~6"2" ~-2--S'.'-F ' '"' Z'O'~'~g-i-2--E ...... f4'04';'2-6 .......... ~oo.oo.<.:;./~.:.':.::<?~?.0/~:0:~; ~74:::<z~:.'::~:;::: .:: ~2' ..~ .... : ..... , ..... ~ .... ~.&.~.?__E -~ z o~, o5.';~'~:s-;.'~::;:-. ~zo~. z~ E ~SO,. ~S ~500.00 ~125.~3 ~083.28 51 ~9 S S2 36 E .22 1058.20 S 11~8.17 E 1561.37 4600.00 qSO0.O0 4'900.00 5000.00 .tl 7 S 51 3~ £ .87 1090.26 S 1i89.36 E 1613.34 3'~ .... 5-6 .......... -S-51 ..... ~'~'-E ............. .'i8 1122.28 S 12}{~Y5 E 1664,70 30 58 S 50 30 E .6q 1154.45 S 1269.56 E ,,~_9,,A~ ............ S.~5o ~6 E . .~5 Zt~.sZ s zsos.5~E ZT~.zo 28 26 S ~9 6 E 1.71 1217.96 S 13¥~8~--E i'~i¥;82 ..... :,-.KENA~ ALASKA BOSS SURWEL - . ~ NL SPERRY-SUE DEPTH DEPTH TVD DEG H~N DEG H~N DEG/100 NORTH/SOUTH EAST/~EST DATE OF SURVEY dANLIARY 28e 1982 VERTICAL SECTION DIRECTION S-q6-48-OO~E BOSS-16963 ..V_E_~.,T I C A L,__ SECTION szoo.oo ;5~oo.o 5500.00 1862.07 1.~57.,~6 { 20_0 ..~, ,_t7_'~:__.i 2054,90 5600.00 ' ::5~oo"O'O".~.~;~j::~$ ~~:;~:.~::.:::::;~::~:,:::~:?~....:,::'.~o.'. ~'~:.:'~'': :'. "s. ~ 5..':~'~ :'E..- -:-:~"- .ST. :..' .': :~'~'~':.~'~ S :.- ,, z 59~. ~ :5'8'00 .'...0-0. ~ 6000,00 5~25,67 5383,52 32-50 S 56 Sa E 2,15 1538,76 S 1719,12 _ 6100,00 5509,92 .5.'~67.,77_ ~. 22 S 61 z+2 E 2,63 6200 · 00':i":j.;:i!:J!~i:i/;!:"5595!!;i~ i!i§=~'§3:1"d7::-::.': .30 ~ ......... .-": ..... S~'6 5"":~'8~'"'"'~ .......... 3.13- . ~oo.oO..~:,:'~.:.:,~?~:~./5:6~8~2i:4. ~5;~':4~0;~::~,~..~/~:~.:~:~:..-.......~.: 5o s 6~. ~. E ~. 7~ ~.OO. o°:~?~:;~'~:~::6:.:~.~-'~' :~8.~i'~:::~:??::~-.:.. ?j.'~,LT~ .... ,.:..=::'.~:::.~ ~_.d;,::~ ..... ~. o ~ ~soo.oo s~so.~ s~.s~ ~ ~ s ~ s~ ~ ~.~ 1566.25 S 1765.40 E 1589.21 S 1811.82 1608,'36'!:.S:' 1857.09 1623-.49'~i.S ' 1902,38 1636,52 S 1947,28 E 6600,00 5947,86 5905,71 26 25 S 72 12 E 1,06 1650,10 6'7 0 0' 0 0 'i. iilJ-il ~:?~!::i6ii~311~J~:~::~Ji~i':5:::;.'9 ~iiSi!i'*~ 0::. '/:ir. -':J~ .- ~ ~ 'i"~ "7 ...... ~' 8'0'="3"0"~E ~= ...... ~",~¥~ .............. I ~8oo.oo .' :.,::.',::~:.~?~;~:~:;~.~;~~?:-~O:d:~'.~5~:::.:-'~': :.:';',.;':::~ ~:..~:.....s e~ l~ E :', z.~o 7000,00 6313,76 6271,61 20 52 S 82 0 E 1.2~ 1676.62 1990,47 2032,73 207Q,.02 2112,86 21q9,12 ......... 2.1_0 ~_._1_? ......... 2154,14 220q.$fl 2254.65 . 2506.54 2 35 9.,_.o? ......... 2408.65 2454.75 2~98o13 2539,78 · 2580.56 2618.~3 2652.60 2684.40 271~.36 7100.00 , 6,,~+,0,?.33 6365.18 20 25 S 80 36 E .67 1681.9z+ S 2183,96 · 72'00.00~--i'-':???:-'ii';:!:6~0:!~ii:~ ~!5".:~;,::0~~ '~"1~ ':'.~-:-"" ............... S'79"i'8"E ............';"~7- ........ ~" 'i'~:~:?~8'.~:s'-:::--~F2'.'~'~;-~'~ 7~oo.'0'0 :::: :- :/~':~:':'.:~J~: ~::~.?~'.:.."::::'::j.:jj:.I~.,'::.~'7"' ..... s 7~ ~ E .~0-'::':J':'"I?o0~'.:88:':~S''??''' 7500,00 6783,56 67Q~,~1 19 17 S 80 18 E .~7 1706.78 S 2317.~9 2772,37 2801.25 2829.82 2fl57.7~ 7600.00 6878.09 6835.94 18 47 S 77 36 E 1.01 1713.02 S 2549.q9 E 78 00.00: .:.::::?~.i:';;~6!i'~i~iii~7 026" 03:?':~?::.::'-':-.'..'',1'7.,-'~ 5' :'-' S 76 24 E ..S S ::.'I726 '89 S 2 ~ 10 · i O ~ __7900,..00.'?;::~.-:'~:;7j1~:6~~::'~771;~i'35~'::::::?:':? 17:26' L__S ..... ~.~. 30.~E '~6 .. 1733,72 S 2~39,55 5 8000,00 7259,00 7216,85 17 3 S 76 12 E ,5~ 17~0,~6 S 2468,~1 E 2912.47 2939,03 2965,17 2990,82 KENAI9 ALASKA BOSS SURWEL DATE' oF SURVEY jANUARY .2_, 19'82 VERTICAL SECTION DIRECTION NL SPERRY-SUN i coURSE .' . coURSE '' ~iDOG ;EEG:.::i,.iiiii:: i'":i'~ i.ili{ii~:!.:':~i.i':':i..:: TOTAL' :':: i I'~ ' MEA SU R:E!Di~i!i./i~i.~Tii~ ii'N C:~_!_N_A_!T.!?~.=,... DI R;-E _c:T:~ g..~:., i~ .... $ Ev:.!i '.i~:.:-.iiii.'i~:: R ECT ANGULAR ::-i:i:.:: C 00 R O I. N AT E S DEPTH OEPTH TVD DEG MIN DES MIN DEG/IO0 ..... ~'O-R-T-R-/-~OUT-H BOSS-16963 VERTICAL E-A-S-T-7'~j'E-$-T' 'S'E-C'TiO N 3015.91 $040.60 3065,87 3092,29. 2615.76 E 3119,00~"% 2647,20 E 3145,13 267B,09 E 31i'0"-99 2709,02 E S196,89 2739,64 E 3222,48 2768.97 E 3247,25 9100.00 8306,80 8264.65 16 29 S 79 6 E ,39 1800,27 J'"e2'O'o .00 i .............. S-' 80 ....... ....... .............. 9500.00 8688.80 86~6.65 ~8 ~0 S 79 18 E 1.0~ 182~.28 2797.15 E 3271,40 2825,21 E $2'95.41 2853,82 E ' 3319,68 2883,20 E 3344.6q 2913.83 E 3'37-b-;-84 1827.56 S 2945.86 E 3398.49 183~'/+5'~"~S:'ii!'::.':'' 2978.. 66 E 3427.12 1841'55 $..~i..:;:~' '" 3010,72 E $q55.35 :... ,... .. :,,~ 1 8/+'8'.{1.:7.1 ::., $ i ,,. .3041,0~ E 3~+81.98 1854.60 S 3'070.18 E 3'507,,63~ lOlO0,O0 9258,19 9216,04 16 31 S 77 6 E ,65 1861,12 S 3098,41 'l 0-200 ' 00 .~iii~!~'i'!;!iiii?i.i::'~31~21~:~i!:iii~ii~i.';93.:i. 2. ;1-4'- .~-~.:'-:'~i'.~i~'~:~'35 ..... ' .....S "7'6 '-4'8:'":.~E-".:T"-'~:';" 9~4'i17 T.~TT:i~'~7-7~-~TS.'?i::.-. - :31.25 · 35 10500,00 96~,37 9602,22 Z~ 9 s"7'~-+"50 E ,~9 1885,59 S 3199.60 10600,00 97~i,~6 9699,31 13 35 S 75 0 E ,58 1891.90 S 3222,72 10800,007 :; ~;:~:~::;~{;~:~':~g~3~'~0~2~??;7989'3:::,8 7:.'..;~::.; ;. '.:' . 13 7 S 76. ~8 E' ' ;.~.-37 lg03' 15 S 3267,65 ' 12 ~7 S 78 2, E ,~9 1907,.97 :S 3289.53 3532 3556 3579 3601 3623 36~+4 3684 ,67 .58 ,50 .57 .18 .35 DATE.,.OF-,;. SURV, EY.-- .'UANU'ARY '~8~ VERTICAL' SEOT:[ON..:.,DTRECTION- BOSS-16963 HORIZONTAL DISPLACEMENT = 3802o81 FEET AT SOUTH 59 DES, 53 MINo EAST (TRUE) SEA LEVEL · .-. I KENAI~ ALASKA 'BOSS SURWEL DATE OF SURVEY UANUARY . . 28, 1982 ] BQSS-16963 ; 'i.-"i;!.i.i:..?:~ii"?'~??'i i INTERPOLATED. RECORD MEASURED VERTICAL SUB SEA DEPTH DEPTH TVD . ...:'":..;i~i-."~: il-.:-:i !: %' Li~ii;~~':i''''': '~''-:: :-- . . . T 0 T 'l L TRUE RECTANGUEAR C 00 R-'D-I-64-1-fE' S -- ELEVATION NOR TH/SOUTH EAST/WEST 0.* E O, E O. E O. W .0. W 1. E 5. E 13, E 2.'5, E · 135:3, 13~.2, 1300, 1~56, 1~2. 1~00- -1100, .' :: 51, S 50, E . .. - 120:0' 'S. ":.:_ '::~ ;':: '66, S 65 · E -130'0; "' 8'2-;- S '8~T-E -1AOO. 101. S 100. E ' 217:/i :i!i.i.i:: ':?.i .:'"' 1883. 18~+2. 1800. 199~', 19~2, 1900. .... -i.$0-0.' . ':: : 1~5. S l~+7..E . -~.7.00. .... . .:..-:' ...175.:::.$ 175. E ~ -1800. 20~. s 20-~-' E"' -1900. 238, S E { . 2106 ~:i.~:~!~.?~:~...~:::~t~¥:~:~:~:~:~:.:~i~?~??:~::~:.:~:~:.~:.:~?:.:~: 20 ~ 2.... :~.,~ - .... . ... .2000 . ~.: .. ..... .2218.~.':'3~?:.:~ ~;~:~:~?.::~L. tF2:I'~ 2.*:~::'~.;~t~ :.: :?~:::'?~:".::-~::: '." ::' .' · ' 2100 · ::.:. '-:;. :~:' :::' :::~.:.:.~.:'..'2.:~ 00 ..:.:..: :.~-;?.: ;:... . :: 309 · S I':, .:..23,~ ~<.'212::~:~"~":'~:~::~:~:~:"?~.:.;::"?:':':' -::;.:::':::: "'-:': ':2 2 0 0 .' :; ' : ' '""::: :" ~:' """:~'~' 0 0'-.. ';"' ~'"? '" ~ ~ 5'i ::: S 2~3, 23~2, 2300, -2300, 382, S 2557, 2~2, 2~00, -2~00, ~21, S 313. 3~9. 38.6, E 423, E 2 5bo. .......................................... ;'2'~'0-0-; .............. 26'00, -2'600. 500. S 2700, -2700, 5~1, S 2 800; -'2-8-00 · '58'2T-S 2900. -2900. 62/~. S 5'01, E 539. E --'5'7-8';--E---- 617. E T R'A D I N G~'. B.A Y:::::.:,ON:~:~iT:.:~!!i.~/.i!ii?;i!i? :.:i< r ~::i!i<i?!!!< :-i....":i'i: .'::.- :>.: : .' .. :".,. ,.:-,, :i KENAIe ALASKA BOSS SURWEL MEASURED DEPTH ,. "' DATE OF sURVEY ._ '~'~GE 7 28, 1982 BOs$-16963 INATES T/WEST 656· E VERTICAL SUB SEA DEPTH TVD ,.. . -_~.::'.:3 ~'76!' 3589. 3705, ':-il.-::':..:.. :i..-' :?'.: i::'..,...~:': -.:..",.: T TRUE RECTANGULAR ELEVAT ION NOR TH/SOUTH JANUARY COORD EAS ~f~i~:!2'~!~.:?:.:!?::':-~''~'-' ' ',.:.: .:_ ]a2.o 0:.: '- --: :..'. -::<-<:!:':::!-:!.-:;:32o~ o', 1. s 3342. 3300. -3300. 784. s 344.2. 3,,00. ' -~oo. ~5. s 694. E ! __732. 773. 817, E r 4167, 3842, 3flOQ. -3800, 955. S 4284, 3942, 3900, -3900, 989, S 86S'. E 912. E 960. E 1008, E 1058. E ..:: .::. . .. o 3'7 '~;-:~ >:'~::?i:!&:':~::::i>!~:~? ~:i;i~2!:~+"2:~.~:~'!:':::.'., <_ .- " _' .._9_20_ 06 "': 4753, 4342. ~300. ~869. ~q~2. ~00, -4000· -,-. ..........,. 1027· S -~ioo. '.":'::;':'i/: .:.i::):':~'.:':/.:::- io64. s -4200. 1102· S -4300. 1139· S -4400. 1177, S 1156 1204 · E 1251· E 1297· E ;. '.. 5 2 1 ! ' i:; :: ::::',::":~;:~....;-!;.:~;i: i7;i,~2'''' ;; .~:':'.'.' "' ,-' '_' "-- "..~_70.0... 5326, 484'2, 4800. 544'0. 4'94'2. 4900. -4RO0. -4900, 1213. S 1248. S 1284. S 1520. $ 1558. S 1340 1581 1421 1462 1503 · E · E . 5.7,~e.:i:?'? ':". 520 o. 5300. 5400. ~' 52 o o ,?':::i:<ii???!.'!:?'::?>~',". ??~:~':~?~- s -5300. 1510· S -5'400· 1544· S 5600'·:- _ -5"600· 5700. '- "-5700. 5800. -5800. 5900. -5900. 154'~. 1586. 1629, 1676. 1728. 1634, S 16~9, S 17~3. E 1836, E 1888. E 1939. E 1988, [ PAGE 8 .:"JANUARY 28, 1982 .. BOSS-16963 ' .' '. <"'i!!i.:">ii?~:.:.i~i~:ii i~T:RUE<?..::-:-'i!::!~¥"-..:ii::: :.' "- . '... ../ ' ....~ ::..:; < ??.': :i,?:.>.: :.. ?-f ? /-,:.:.::?:,:?..~<;:<. '."~ <:''T 0 T A L . REA SURED' ,.,.' DEPTH ' DEPTH TVD ELEVATION NORTH/SOUTH EAST/WEST 1661. s 20'3~. E 1 1'667. S 2080. E'''=%' 1'67,.,'3. S 2..3'.~ 1_;_ E ......... l 1678. S 21.60. E ~68,+. s 2~97. E -: ~...-?,+ 5 ~.'..'i:;:~i~ii::!:i:ii~iiii~i ii!~?.i:-6?:'+ ~.,..:i!:iii>.i:ii:.? ::~':. ........ : .... ,.:..~?..0. o ' 7562. 6842. 6800. 7668, 6942. 6900. 8087, 75~,2. 8191. 7442. _650-0,::"-'-_-::'. -6600,.:'.'..' --6700. '- -6800. 1691. S 2'2'325, E 1698. S 2268. E 17o4. s 2303. E 1710. S 2'3-3'7'; .... E'~ 7100, 7200, 7300. 7400, -6900. 1718· S . -7:.1'00,.:: 1732, S ' :':,-"...'7:-2'0 0.,.: ..:.<i;!- ' :".: '.. ' 1739 ,. $ -73o0. 17~+6. s -7400, 1753. S 1760, S 1766. S .... '-:1771. S i'776. S 1781. S 2370. E 2q33. E 2463, E__ 2~93. E 2522. E 25 fl/+.," ,E 2618, E 2651. E 2684. E 9137, .......... 8'b 0 O , ................ 8100. 8200 · ~ ~-o"o", .......................... 8~00. " -8.100, '/'""/ 8'200. - ~ :8'300. -8~00, 1 '?'8'--~';--'S: 1.791, 'S 1797. S 1-8-i:Y~';--s 1808. S 2'7 ]:'E;"7' ' E ......... 27/+8. E 2778 · E 2'8'0'7-',-"-E 2~37, E 9662. 8842. 8600. : ' :-86oo. 8700, . . -8700, 880'0'. -88'0-0 · 1818. S 1825. S 18-32-;"-S .... 28-67'-' E--~ 2899. E 2932. E 29'6 E,--'E .... WELL. D' : '. ' I ' KENAI, ALASKA BOSS SURWEL DATE OF SURVEY UANUARY 28, 1982~ 1 BOSS-16963 :iiii?ii?~ii:i:!:.'i'i:?:'.'~??-'.':'::.':'': "'-:::...INTERPOLATED RECORD OF'::'Su'RVEY ::"'!'::'::~":.. ?::':' :. ':i:: ":""-.: ":!::: :iiii?:?ii~i'~iiiii'ii~ii:ii:ill iiiii!iii!~i.'R:~:~£!".~i:.:::/.:i:?~:.:.'.!::~ "" :': '-:.'"::';:..~'__, ...... ::: ..... _:_ '-'.' ' :'-. :;:: - ' .' ::':'"' "? :.~." ::::' ', :'- T 0 T A L MEASURED VERTICAL SUB SEA TRUE RECTANGULAR COOR DEPTH 10187. 10291, H EA DINATES ST/WEST 3033, 3064, 3122. 31A9. o'~n'~.'- '/~':~4'27:J~:'!:~:::?:i?i/!:::'~i!?~.::~.':%-.'':.-':'' .,9.70.0..,, ':"/:~':"? :!::. ~:!,.~i':!.: :::.:.? --:._ .... :9__7_0_0_..' ':?i~i:~!?~??~'i:~:: 070q. 9812. 980 O. -980 O. 1898. 0806, 99q2. 9900. -990 O. 1903. 3174. E 3199. E 3223. E 3246. E 3269, E FROM 0.00 FEET TO 9991,32 FEET l_T R A D I N G. B A Y U N I i,:.',;';.,.ii. :i:: KENAI, ALASKA BOSS SURWEL NL SPERRY-SUN I : ...... .... :':"'i.:':: :..!:'::i~ili~:!~!~i~: ....... :::~k'CORD OF' :~'~R~'EY ..... 7-'-"'"" :: .::' ..::...:: .: iiiii~?:!.i?!?S':::OB?:':::.::::.:.':: :. couRsE : ' cOURSE ' DOG-LEG ' ' ;: '::: ::.::.'/': ::TOT AL . DEPTH DEPTH TVD DEG MIN DEG MIN DEG/~O0 NORTH/SOUTH EAST/WEST PAGE -1 DATE: OF SURVEY ,JANUARY 28, 1982 .VERTICAL .SECTION DIRECTION BOSS-16963 :V_~E, P.,.T_!__CA.L.. SECTION - 0.00 0.00 T'~'~ej~__ .ORIGIN AT SURFACE i lOo-:O · o'" 5-~ : ..... s 4 3' :: "0 ' E":'- ...... "68 i ' 0 20 : . S 5.8.:'~2. E .25 ~OO.O0 399.99 357.8A 0 ~3 S ~8 ~2 ~ .57 0.00 · .15 °83 ,72 500.00 '- 6°°'°'°'~:":"i:!~'i~:'5~:~';-'9'~e?i:.:::~i~!ii!i:!:i':~S57.8~ 0 10': s ,+2 4'~ E ' .'~3 2':~8~ s' 75o. o~ '.~:'. i.::::?~.~:~;ii~:iii? i~!i~!i~0_7.._.~.. _._ ......... ~5.~'.~.~.~ ....... s ..... ,+.~_..~:_~:: ...... ~.. ~..~. ?')_68: s':' 800.00 799.22 757.07 7 1~ S ~0 ~2 E 3.91 12.45 S .. 850.00 ............ 8.~8.,.7~ .....................80,-~l._~,,~[ ................ .7.~._,,~9. .................. S_,..~ ......... ~. E .............. ~.e.~:~ ......... ~ 7 · 7~ S ~oo..oo ~.56:~.o~ :::::8 ~: s ~Z..~.:'E · ~.~6 ...... ~':;~' ~... 10 00.00 ::::::::~:~'~{::~:::~::.996:~J6~3~ ;:954.48 .. :" 10 7 S ~6 '. 18 E 1 · 58 :35.51 S./.::: 1200.00 1192,61 1150.~6 11 58 S e5 18 E .gG 63.30 S ...._0.6__~_ 1...51 .... · 13 E 1,80 4.92 E 6.69 8_._5_1_E ...... _[._[_.3.6 12.62 E 17.72 16.90 E 2_/+.46 21,96 E 32,01 ~.5~ 63.25 , l__~PO,O0 1289,,97 · 1.2.47,82 13 11 S ~4 5~ E 1.22 i : ' ':" ::~:~::.~:':::;~::;~?:F:'~:' .~ ~680,00 ~652,~8 ~6~0,~3. 20 ~0 S ~5 ~0 E 2,56 1700.00 1670.97 1628.82 -18 00 · 00 'i'?i"i:i[ 7:62!~:!1:731iilii:i!-i:i?!! 17 20 · 5 8 19 o o. o o :~i 1'81o. 7 o 2.0 o o. o o -: ~:.~ ~ :2:'i::'~'2:~:i;i?~.:.~,::~ o_o_.~.7 2100,00 20~1,55 lC)89,40 79.45 S 97.06- S 116.38'S 138.50 :iS :.: · 79,35 E 97.58 E 137.58 118.02 E 165','70 141,08 F.. 197,65 158.29 S 161.22 E 225.88 166.31 E 232.98 i'9-4';'~-~-' ~- ....... '~'72' ,-7-~. ........ 225.29 E 316.05 257.26 E 360.72 289.68 E ~05.85 2200.00 2300.00 2400.00 2500.00 9~N.NN 2120.77 2078.62 229'8 '.. ~'5 i!'i?/i::: .::.: ::.:": :':"22.56 · 30 238-6,59 ::":: 23~'%. ~ 26 51 S ,5 0 E .~1 316.33 27 7 S q4 30 E .35 348.8~ 27 52 S q~ 36 E .~2 581,76 28 11. S'~4 12 E .68 ~15.62 PR ~7 R 4~ 1R F .R7 321,62 E ~50.99 ~ ~' '-5-6-"-~ ....... 4~'~'." 5 4 ....... ~ I 386.02 E 5~+2.73 { ~18,95 E 589.93. wELL D 911:SEC':.6':?T8N!~:;R. li3:W:ii?::i:.;.:.;:',i.:;:: , DATE OF SURVEY UANUARY 28, 1982 .TRAD,!N;:,BAY ]uN!I'T':?'if:ili!i'!;:!'!,,!?;;i::?.'!?i'f{:;;::i::i'::i!!:';?:::' :::,.-i,,,!,,,',,, ~--L--..--' ................ : ............. '~,[_RT [_~AL SECTIO, D IRECTI ON S-~6-~8-OO?E KENAI~ ALASKA ~ BOSS SURWEL BOSS-16963 NL SPERRY-SUN ~"' ~: ......... -:' ::::' ~'.' ~.~': ~: :/'~'~ ;::~:~:~' ~.~:/'?;~:~¥~{?f.~:.::~':/:??.',~::~?: ~'"::~ :? , .' ........ R E ~ ORD' oF '"~S UR V E'Y :.' ": coUrsE coUrSE TOTAL DEPTH '' DEPTH .............. TVD ' DEG N[N DEG R[N ....... DE'G/1-O'~O-~NORT~--/S-OU~ E-A-S'TT'~'~S'T ....... SECTION 26 30 ,~52,59 .... -48%-2'7'~j 520.21 553,7~ 5-8' 7-,-9'8 637.92 6' B-6-;- g9 735 · 21~ 784 · 1 1 ...... j 8'33'. 9 ~" 31 32 33 33 00.0 00.0 00.0 50.0 O0 .0 0 . 2909,51 2867.36 29 52 S .43 12 E .10 628./~0 'S 0 :' ':'~f.;::.i' i :..i29.96'.:i21;227i'!!:.ii;!~i:::i::ii:ii~.::2915~';?-- ..... 2'9' 5 2 ........ S ~"2 ' 4. 8 E .... : ' 20':' '7'-~ ..... --'"66%7'~-~ S 0: 97. ':~ 29 ~0 S ~Z Z2 E ,82'"" 702,18 S 0 .:: :' 29 ~1 S ~1 6 E .10 720,fl~ S 0 ' 3169,9~ ................. ~127,76 29 5~ ........... S ...... 4'1 ..... ~6 .... E"-' ...... 2~-4-"' .......¢39,~6 S 622.07 E 883.64 65'5 ;9'-0 -'E ........... .a33'.'3! 688.51 E 982,57 70~.78 E 1007.21 721.32 E 1032.02" 3~50. 3500. 3550 ! ..36oo' 3650, O0 3213,~8 3171,33 00:..;: ,..: :,:>.:.73 3iO2!:.ijO:5!:.t:?.;::~:::'.? 32 59 ' 9: O0 3390,~3 3348,28 29 22 S ~+3 0 E 1,73 757,Z+0 S. 2'8 1 ~ ........ s 4. 7' ~ 2'E ..... i ¢"b'g-" ........ 7 7'3';'3'2 S '27 5 S 53 56. E 5,9~+-:-' 786,82 S 27 10 S 55' z+2 E 1.92 : 799.69 S 28 .... 3"6 .............. S" 55 .... i'8'"E": ......... 7~" 8-9 ................. 8'13.31 S 738.05 E lO56.4~ ?~5V5-4-'~ ....... 1o'80Jf4 773.86 E 1102.74 792.72 E 1125.29 8'i'~'~-o--E ........... ii~8;9'7 .......... 3700.00 3750.00 3800.00 3900,00 ~000.00 3~+33.87 3391,72 :'": 3, 3 5.0 8. : 3 512:0::, i*,8:/:ii?~!? :::.:" .: 3 ~ 7 8 ' 3 3- '.:-3 6 0:'6" 85>:'.:!/;:L,":::::i.'356 ~. 7 0 3692.87 3650.72 832,73 E 1173,~6~ 85 3;'~.-5 E 13198,07 873,75 E ;1222.92 91~.27 E 1272.98 9'5-5-;'ge--£ 13-'2'3-.-5'~ ........ 4100 ~200 ~300 ~400 ~500 .00 .00 ,00 .00 3778.52 3736.37 38 63{;5 91.'"';-./~:; 3821 · 4 ~ ~91f8 i.i'i ~5906' 66: i:'~ 03:3 ,'5 3991 · ~+ '3 · 00 4118.56' 4076.~1 31 4 S 53 itt E. .65 946.59 S 31 .... ~'3 ...... 7~'' : .... S"53"lS"E ........ .65 .......778.Ol s 31 33 S 53 18 E .17 1009.28 ..3..2_ ..... 2 s..5_2_.,30 E .64 10~1.57 s 3 i ~ 9 s 52 36 E ........ · 2"~ ......... 1-07~'~s--- 997,06 E 137~+.82 f d~-9'7-2'f-E-- .......... 1 ~"27 ;'0'5 ......... 1081.17 E 1479.0/+ 1123.25 E 1531.82 1165.13 E 15'84,-27 q.600.00 l' ~+700,00 ~800,00 z+900.00 ~204.17 ~'162.02 31 7 q. 289'94. . ~247.7'9' ........... 30 .... 56 ..... Z+375"99 z~333,8a, .90 38 4~+62,61 ~+~+20.z~6 29 59 S 51 36 E .87 S 50 30 E S 50 36 E ,65 S'~9 6 E "1.71 1105,69 S 1205,63 E 1635,76 · i 137".-~'2-'s .......... 1'245 ,"9 F-~ ........ z' 6"86 .-9'9 ...... 1170.03 S 1285.23 E 1737-8z+ 1201,75 s 1323,85 E 1787.70 123'2,-9-3 S '1-359-.'8'~-"E ....... ffl35'28 ........ PAGE 3 DATE OF SURVEY JANUARY 28~ 1982 VERTICAL SECTION DIRECTION S-46-.qS-OO-.E 51oo,oo 53 00 ' 0 ~.7:,7.2 ~10.' '~: ::5~ o::o:' o o ~.~:'~::~:.~:~ ~:~:o:.:.~.~:5. o~:.:<~.~ ~'~:~S:~: ::. 5500.00 ~988.68 2.8.. I ............ s, .4 9 18...,E ........ ,. ~ S_ .... ...... 12_6 S. 5 6 S Z.A.9.~..._~..5_,E_ 28 36 S q8 18 E ,75 1295,40 S 1431,19 E 1930,06 28 ~8 S. ~8 12 E 1~27'51 S.,.: l~6T.lO E 1978.22~ ~.9~.~5 · . S ~7..30.. : 1503 13 E 2027 08 29 20 S ~6 2~ E .5~ 139~.31 S 1538.60 E 2076.06 30 13 S 45 ;56 E : .S? 146~.85 S ""~1'~{'~'36 E 30 1~ ' '.$ 51 5~ E 3.17 1~9~.92, S ": ; : 1649.98 E .... 59 00.' 00 ~::' ?~:~ 535'~'30';;~.~.~;~'~'5:2~:~,~-'' 30, _4 ~ ............. ~, 56 ...... 1:2.:E: ',=~2- 23 ............ ,.~..2~.~. S :;,: ~6~..2 ~__E ....... 6000.00 5~18.32 5376.17 32 50 S 56 5~ E 2.15 1552.9~ S 1737.85 E ........ 2,1.25 . 2175.97 2226.13 _.~,.2.,7_6.~.. 52 2;529,90 6100,00 5502,79 ~__E~;_6~__ .... 32 22 , S 61 42 E 2.63 1578.32 .S 178~-,98 I :'62 o o' o o:{.:i'.:i.i:::~.::::~is5'~:~!;,~is:~i:i~;:~i!.i:;.>i!!sS:~:~-.:ldi::::::. :'s o: ~ ..... :::'::::7'S :'gST'~ .:~E:==: :':"~S'1 s ......... 7 ...... ig'~'~':;"~g~ .:;~'. ~.~'~"~:; ~ ~ 28 50 '";S: 68~ 2~'E ; t'78 ~6~6,6L..~:S::/' :,: 1875.52 6500,00 5853,72 5811,57 27 26 S 72 5~ .E 1.22 16~2.68 'S 1965,31 E 2381...16~ E 2429.00 E 2473.84 E 2515.76 E 2557.14 6600:00 5943.28 5~,OJ,,,~,!_,~ ........ 26_.25, , S .72 12 E 1.06 16.,5.6.28 S 2~ 2, .': s ~s i2 E' i.70 ... ~'6~".15":'s":.... 7000.00 6511.1~ 6268.96 20 52 S 82 0 E 1.24 1878.47 S 2007.67 E 20.49,82 E 2632,88 2090'.26 E 2665.66 2.M_T._...5.0_E ........... 2 6 ~. 6...~ 8 2162.77 E 2725.59 2197.19 E 2754.58 2264.24 5 2812.5~ / 22_9_.Z_.__2_3 E 2 8_~_0.._6_5 ..... _.j 2529.78 E 2868.19 7.600.00 6876~07 6833,.98_.__ 77 o o. 00 6 29.04 7800.00 { ?,~00.00 onnn _ nn 79RT.A4 791 c~=gg 18 47 ........... S 77-36.,E ....... ~,.,;,,O.! .............. 17,1.~5,_,..8_6 S 17-58 S 77 12 E .83 1722.69 S '17 ~5 S 7~ 24 E .SS 1729.86 S 17 ~ R 76 12 E ,Sq 17flS,3q S 2361.23 E 2895,84 2391.31E 2922.45 2420.94 [ 2948.96 ) ._~.~..~_%19__E_ ........ 29].~..72 ........ .__J 2478.66 E 5000.26 WELL D-9. TRADING BAY.:UNI'T.~ KENAI, ALASKA BOSS SURWEL DEPTH DEPTH PAGE DATE OF SURVEY JANUARY 28, 1982 VERTICAL SECTION DIRECTION S-q6X.48-OOeE BOSS-16963 NL SPERRY-SUN :."CouRsE : "COURSE DOG-JL'EG.' -':'. '-'"':"'-.':..:-:';:'.':'TO TAL [~i~i:i:i~i~ci!~i:iS:E:::AL.::'!!iL:ii:ii!;~C:i;:INCLINATION !. DIRECTION 'sE.v· -:'.:'. RECTANGULAR "CO ORDINATES E [ ~ T~-~T VERTICAL S E C TI'0N-- 8100,00 7353,3:3 7311,18 16 29 S 76 30 E ,57 17~+9,96 -:'820'0 '"00:?'????i:!!: :i~i'~::.~.':~!;:9 i~i'.2 ~:.'017::i;: 1'!'0'.?::;:i. ::':;;:' ........ l' 6' "2'~ ....... ? ............ ~' '"'TS-' 56'" E ........... ;Ti 8 ~~l 75 ~ · 85 8300,00::~'~.'~.~":.':~:.~:~':~:';./75:~:~:;~5~9~:~ ~'0-2:"4';~"-"" 17 33 ' ,..S 77 5~ E 1.26' ' . 1763.17 oo ...... . ..... -L.S ..... .:':..7 8500,00 7733,66 7691,51 18 ~8 S 81 ~8 E ,~7 17-72,~8 2506.25 E 3024.91 25'3-3'769 E 2563.17 E 2595.83 E 3102.~8 2627.73 E 8600,00 7828,62 7786,~7 18 16 S 81 12 E ,57 87 0 0 ' o'O'.'::~i~??:?i~7'~i~-37~i~ 9000.00 8209.50 8~67.35 1777.27 mS 1782~--1' S. T1'78'7.07.'.S ~L'79:1,79 S 2658.70 E 315~.7~ 2 e ~'~-"~'-~ ........... X~'~ ~;~ 8 .......... -~ 2720.57 E 3206.5~ I I 2750.7~ E 3231.77 , ._~ 1796.97 S 2779.23 E 3256.08 9100,00 8305,.39 8'263,2~ 16 29 S 79 6 E ,39 1802,:34 ..{ 16 . 1..,: S 80 :' 'O"E' ...... T~'~33~''~ 1807.32 9500,00 8686,81 2807.09 E 3280.07 2864,31 E 3328,61 289q,13 E 3554,02 2~P-5'.58 E ~381'"01 96'00.00 8781.11 8738.96 19 26 S 78 30 E .81 1830.26 S 9700. :~T*I~'T~-4 .... .: .... ":~ .... 'S' 77"~8' E ...... i~' .: ,38 ~: ' 18'3:~2-~:0 S 9800.00 S 77 12 E S 10000.00 9160.89 9118.7~. 17 10 S 76 5~-E .............. ;~56- .......... 2958.18 E 3409,32,~% 2991.1~ E 3~38,2b 3'022.28 E 3~65.77 3051.83 E 3q91,53 .......... 3'0-8-0"~-'58~E .......... 3'5 I'7.07 10100.00 9256,77 921~.62 x o 2 o o. o o ' ":: 93 6'~."'~i0:91.":iF.~::.~ :i:: 9'3 FoTg'~ ' 10300.00 :: 15 5 S'76 36 t . ,. '50 1875.8/+ S 10,00.00: ;;::::':" 14 21 S 76 18 E ...'7~ Z~q81.71'S ~'05'b"O.o0 96~3.~9 9601.3~ 1~ 9 .............. S ...... 7~ 30 ..... E .... :~.L ....... 2,~ ............. i'8'~R.2~ S 10-600,00 97~0,70 9698.55 0700o00080 O, 00 ' 99 ~-5' 35:':~!:::~:i:!?:,9893 · 20 '::' r 0900.0______0 10._,_.__0321.8 72 16 31 S 77 6 E .65 186.'3.67 S .'5108.29 E 35,q, 1.62 15 35~ .................. 'S'?6 '48" E ............ ";94" ....... 1'86-9-;"~--S .......... 31"3~4-;"4'~--E ...... 356~.88 3~59.76 E 3587,A6 3183,83 E 3609,03 s'267';-3~'-~ ......... 3'630;'68 ....... is 35 s 75 0 E .58 .t89~-32.s 1'~"'~"~6 ......:"S'"'7'6 O' E .......... '.T:';28~-, .... 1899-,'9~ S 1:3 7 S 76 q8 E '-,37 1.905,12 S 12. 47 S 78 24 E ,/+9 lg09,57 S ;5230.08 E 325 2'"6'2-~!~ ......... 367 ~-. 65 327~.71 E 3691 3296.39 E 3710.15 TRAD!NG ::BAy.. i K ENAIe ALASKA BOSS SURWEL DATE OF SURVEY JANUARY 28, 1982 · VERTICAL SECTION DIRECTION S-46-,~.~..-_00---E NL SPERRY-SUN BOSS-16963 HORIZONTAL DISPLACEMENT = 3809'.54 FEET AT SOUTH 59 OEG. 55 MIN. EAST (TRUE) · .' i!.': i? :. i'!.~i:..'-':. :!:-:'::: ,i~ii::':.:i!'::::..:::~!ii-::,i:. ii!i:ii :ii~i!~ii~ii:~i!:::i,~/S:'Ti::A"'R':T "-:'0 F'T:~'R'V ~'~;"' ~' ~'A ~ ........... ~: 2 · '~-57~'F E'E T' ~A ~ ~'V ~- 'S'~E'i-~ ~-V"~'L'.:~' ................. ' ......... -'":': ' :: '""' ': '? W E L L O - 9 S E C :: 61 ;i.~:;SiN'?:i~R?i~W :i::: '.,:.::. :::.< .' T R A D ! N G. B A Y :;;:iU.N'II T; :::::i)ii~/...':??ii:;:? ";i:!!ii:?::ii!?i::'i:ii:;i:'. "' KENA!9 ALASKA i BOSS SURWEL ........... .:,::::::":?:?iii! MEASURED VERTICAL DEPTH DEPTH INTERPOLATED RECORD OF :SURVEY ~U-B-'-s E-A ................................ Y~ u E TVD ELEVATION 11/+ 8'::"::?,!<i:i!~i::i~!iii q'2--': '. ::::: :. i: '~...; .:':>,- ':' 1100 ' 1354. 13q2. 1300. 1~58. lq42. 1~+00- -100, -200. -300. -qO0. -500. -600, -700. -8o O-. -900. - . -1100. -1200, ;-1-3'00 · -1400. I" iss~',:':::.":':'i>':?i!;i~!!i;il;~ ~,5::'~2,~"::,'..;.:!:::?::i::::'~? .... : ..... i 5 0'0-, -:'::" "':T'':''~' 1778..,. ::-:'.::::ii.!i:i~::.~;!i ~?~!:;:117/+2...' ."' :" . 1700. ', 1888, 18~2. 1800. 2000. 1942, 1900. SURVEY T RECTANGULAR NORTH/SOUTH O. S O. S 1. S OF 1. S 2. S 2. S 3. S 7. S 17. S .29 · S DATE PAGE 6 28, 1982" BOSS-16963 OTAL C 00'R'D i-N~'TE S EA ST/I,/E ST O, E O. 1. E O. E O. W 42. S 56. S 72. S 89. S 108. S - 1600 .: :.." '<>::: <:. 156 · S -1700. '--'... :. 185. S -1900. 253. S UANUARY O. E 8. E 16. E ' 28. 56. E 71. E 89. E 109. E i-~ 2'~--E~''~:' '- 158, E 188, E 2-2'2 ;-'-E'-'~ 257 · E 2 ~ 50'..... ' I'm'a" ' ........................ 23/+2. 23~00'. ........................................... ;.'~3'b"O. 399';-S ...... :4'02. E 256,'5, 2~.q2. 2qO0. -2qoo. ~.37. s /+~0. E 2678. 2792. 2907. :' :: :: :>27 q 2 '' , ,' ,,.-',-,, i,. ........ 2842, ..................... 25'00; ..... 2600 ' · .... 2700. -2700. ........... ' ............................. ;2'800. ......... 2800. '4 '7' 7; '517. S 518. E 558. S 556. E 6'0 O---S-- 59 6', .... E ....... ",~ KENAI, ALASKA ' i BOSS SUR~JEL PASE 7 DATE OF SURVEY ,JANUARY 28, 1982 BOSS-16963 : . ':.:.'/,:: ...... . !O_T_&L. HEASURED VERTICAL SUB. SEA TRUE RECTANGULAR COORDINATES DEPTH DEPTH TVD ELEVATION NORTH/SOUTH EAST/WEST ;5 e 8 ;5 ,:~ ?ii~?~?'iiii:!:~ 2~2,:,?',:'!'L ....................... :.~3.20 0., ........ £ ...... '. · ......................... .-_5 2~0.0_*. 3595. 3342. 3300. -3300. 3710. 3~2. 3~00. -3~00. 685, S 673,E [~'~ 728..S 711, 768. S 7~9. E 798. S 791. E 830. S 837. E ........ 3.7 0.:.0.. .......................................... - 3 7 o o. :-~':~:':;' ::.~ 3800. -3800. 3900. -3900. 864. S '-88/+. E 898. $ 931. E 93~.S 979, E 970. S 1029. E 1007. S . 1078. E ~5~ ~oo. -~oo. ,~ ~2oo.. ............... . -~eoo. ~?~l. ~,2. ~oo. -~oo. ~7~. ~2. ~oo. -~oo. 1157, S 1194. S lo/+5, s 1127, E ] lO82. s 1176, E 1.120. S 1.~23.,_.E _ 1270. E 1315. E S 1397" 'E S 1/+38. E 51 o,+.i': :.':.:':::::i?{!:::!i!i '6;~2':: ~::::::' ::::! :i' ..: ::': :.:.: :. '~ 6 o o. : ~: ,' "'+6'o o .' ' : ~:::.;.:: .': :.:.:: :1.1'2 6 5. 533~, 48~2, 4800, -~800. 1338. 56~7. 49~2. 4900. -flgo0.. 1376. S lq79. S 1520. 55 62 5677, 5100. · 57~' :;..-,,.~i?~:~.~??~!?!~;:?i~::iiii~?'i?!~.?:?ii.....5~.~_~_. 5200. ' ................................ ,5_2_oo. · 5909. 8028. 62~5. 6260. 637~. 53/+2, 5300. · -5300. 5~+~+2. 5~+00. -5400. ' :.:. :..T:::::L56 q 2 ' 5600 · -5600 · -':": :' ::?'::" ':.: 7~ 2,. .... ~ .... 570.0 · ............................-_57.00. lq15. S 1~56. S 14'93, S 15~6. S 1560, $ 1588. S 1610. S 1626. S I r~b. 1 . ~ 1602. E 16~7. E 1697, E 1751. E 1858. E j 1909. E ~'c~'~,n. r IdELL D 9' SEC 16.' T;8N::R:13W:..' . _.TRAO I NG BAY 'UN I::T;::.',/!ii;',,~:>-i:':.;.' ..-':"::" :".': TKENAI, ALASKA BOSS SURWEL :':.:i.:.':.:ii'i~i~? ?::i:ili?:?.i.::!:>.:i':.:'.:' . _ INTERPOLATED RECORD OF SURiVEY ...................................................... -T'R-O E MEASURED VERTICAL SUB SEA DEPTH DEPTH TVD ELEVATI ON DATE OF SURVEY dANUARY 28, 1982 TO'TAL IC£'-CT-A-N-$~'R-~C:-O-O R-D'! '~i'A-T NORTH/SOUTH EAST/WEST ' ' 7033. .................................... 63~2. ........... 6'3'0'0. .................................. ;6300. 71/+0. .6/+~+2. 6z+O0. -6400. 1669, S 2097. E~.,~, 1675- S 2137. f6-80 · S ........ 217~';'-E' 1687. S 2211, E I,: 756A,. 68/+2. 6800. 7669. 69~2. 6900. -6600-'"- ' ~' -670 O' < -6800. -6900, 1700. S 2282, E ~ 1707, S 2316. E 1713. S 2350, E · 1721o S 2382, E i.............................................................. 7 o'O'O';" . . 798z+. ':/!' !:::: ii:ii:i 7200. -7200. 17/+2. S "' 8088.' .... '" ..................................................... 7342. ..................................... 7300. -i30b. 17q9. S 8193. 7~2. 7~00. -7~00. 1756, S ....... '"750'0. ............. 7600. 7700, 7800. 7900. '7600. '1768. S · ' -7700, 1773. S ..........- 7-8'oo. f7-78-~-s -7900, 1783, S 2~+13, 'E 2~7~. · E 2'5-0 3. C 2532. E 2597, E 2630. E 2"~'6'3",E 2696 · E 9138. 83/+2. 92./+:3, 8/+/+2' 8000, ................ :'~000. -- '~788, S 8100, · -8100, 1793, S 8200° -8200. 1799. S 8'30'0. ..................................... :R3'O-Oo 180~. S 8qO0. -flqO0. ltl09. S .... 2'72'8'. E 2759 · E 2789. E 2~FI8. F 28~8. E ......... 8.500. ................................ ;dsoO .-- 8600. -8600. 8700. -8700. ............................................ ;-8800. 8800. f~'15, s 1821. S 1828. S i'8'-35, s 28-79-~'- E-- 2911. E 29I~5 · E 29-60. E I K ENAIe ALASKA BOSS SURWEL DATE OF SURVEY dANUARY PAGE 9 28, 1982 · · BOSS-1696~ MEASURED VERTICAL SUB SEA DEPTH DEPTH TVD '.: ~ 0o85,:~:.,~.~':::'~i.i:ii: .......... 9~ o o.., 10189. 9342. 9300° 10292. 9442, 9400, OF SURVEY TRUE ELEVATION -9300. -9~00. T RECTANGULAR NORTH/SOUTH OT~L__ COORDINATES EAST/WEST 18~9. S 3045. E..~, 185'6. S 3075. E 1863. S ......... 3,104:,. E 1869, S 5131. E 1875· S 3158. E 1070~. 10807. · .... ' · '... 4 :::~.::.:: ::: :....:::===================== :.: I 0 9. 0 0 :~:' ..'.':.'.:::'..::.: ========================== ::::::::::::::::::::::: '?::.:: ::,' ::!:"'.'):::: · 9 ~ o o ' :':". _ 9 ~ o o,: ::::::::::::::::::::::::::::::":-': ::::::~..7:~ ========================= ' ~_.7. o.0,,_: :-,:':: _ '~ 7 o o. ::.:::,.--',' 9842° 9800, -9800. 99q2, 9900- -9900. 18'81, S 1888. S 189~.iS 1900. S 1905, S 3207. E 3230. E 3254. E 3276. 5 FROM 0.00 FEET TO 9990.72 FEET -50~.00 TRUE NORTH 00.00 500,00 2000.00 ~ob. oo ~oo1~.'o~ ~sob. oo soo6. oo JOb No. Boss-16963 Well No. D-9 (SEC6 T8N R13E) Trading Bay Unit Kenai, Alaska Survey Date: 1-29-82 Scale: 1'' = 500~' ~ Tangential Method of · . Calculation HOBIZON~.'FIL PROJF...C.}]~ON ~0900 0.00 2000. oo 4000. O0 6000. O0 8000. O0 10000. O0 2000.00, Job No. Boss-16963 Well No. D-9 (SEC6 TSN R13E) Trading Bay Unit Kenai, Alaska Survey Date: 1-29-82 Scale: 1" = 2000' Tangehtial Method of Calculation ~10900 ! i 2000. O0 4000. O0 VERTICAL PROJE C T ! ON Suggested form to be inserted in each "Active" well folder to check for timoly compliance with our ro:julations. Operator, Well Name 'and Number Reports .and Materials to be received by: ~- O/- Date Required Date Received Remarks · · .. Cc~ple. tion Report. . Yes' · , , We11: History, Yes Mud Log ,'. ~/(') '- ~ l ' ' Core Chips. ""' . ..Core Description Registered Survey Plat · , , Inclination· Survey . /,~(~ Directional Survey 7~X-~ Pt .~-" a ~'~-gl2- (~ ,,n.z'"' 0 ~'~ Drill Stem Test Reports , . . ... Production Test Reports Digitized Data ~ 7~.~ ,.~...- ~/,,~ _ ~.,> (~)/~ ' ' r' STATE OF ALASKA ALASKAt. ,L AND GAS CONSERVATION C~ ..,MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ~. Drilling well [~X Redrill Workover operation [] 2. Name of operator 7. Permit NO. Union Oil Company* 81-80 3. Address P. O. Box 6247, Anchorage AK 99502 4. Location of Well at surface 756.4'FSL, 1138.5'FWL, Dolly Varden Platform Sec 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106.2' Above MSLI ADL-18729 A-926 50- 733-20131-01 9. Unit or Lease Name Trading Bay Unit 10. Well No. D-gRD 11, Field and Pool McArthur River riel For the Month of. MARCH ,19 82 ~12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 11 , 060 'MD 13. Casing or liner run and quantities of cement, results of pressur9 tests NA 14. Coring resume and brief description NA 15. Logs run and depth where run NA ~1 6. DST data, perforating data, shows of H2S, miscellaneous data Perfd Hemlock Bench 3: 10,500'-10,520'DIL Released rig to production @ 2400 hrs, 03-01-82. FINAL REPORT , -- 17. , hereb~y~_._ th, at the foregoing is true and correct to the best of my knowledge. . ~. NOT~--~rt %~ ;l~is form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oilq~l'-d Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 *Marathon Oil Company - ~ ~ v~ ~ ~v~qu~-~e~a~ Submit in duplicate Rev. 7-1-80 · ALASKA ('_ AND GAS CONSERVATION C(~,' ,VllSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATI 1. Drilling well ~X Redrill Workover operation [] · 2. Name of operator 7. Permit No. Union Oil Company of California* 81-80 3. Address 8. APl Number P. O. Box 6247, Anchorage AK 99502 50- 733-20131-01 4. Location of Well 9. Unit or Lease Name at surface Trading Bay Unit 756.4'FSL, l138.5'FWL, Sec 6-8N-13W-SM i0. WeHNo. Dolly Varden Platform D-9RD 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. McArthur River Fiel 106.2' Above MSL ADL-18729 A-926 For the MoRth of. FEBRUARY ,19 82 '12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks ll,060'TD NO drilling activity during month of February. 13. Casing or liner run and quantities of cement, results of pressur9 tests Completed running 3-1/2" production tubing. Had high water/oil ratio., Pulled tubing, .performed four zone isolation squeezes, and~ reran tubing. 14. Coring resume and brief description NA 15. Logs run and depth where run NA J 6. DST data, perforating data, shows of H2S, miscellaneous data Perfd Hemlock Bench 0: 10,300'-10,320'DIL 17. I h 'e,r~b~i~e~t[f~ tidal'the foregoing is true a~d-corr~-ct to the best of my knowledge. SIGNED 'TITLE DIsrP DRT~ Sllprr' DATE 3/18/82 , , . NOTE-~/eport on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. .Form 10-404 *Marathon Oil Company - Sub-Operator Rev. 7-1-80 Submit in duplicate Document Transmittal Union Oil Cornoany of California unl®n DATE SUBMITTED ACCOUNTING MONTH HAND DELIVERY 3-23-82 TO FROM !,!r. '_;i ! I i am VanA!!en R. £. ~,!arthen AT AT State Oil and Gas CC PO Box 6247 Anchorage, Alaska T~'EP~l%~age, Alaska 99502 TRANSMITTING THE F, OLLOWING: ! KDU-O- . . 1 ea birec~ional survey, radius of curvature D-9RD; 1 ea. Directional survey, radius of curNature, tangential' average algle, tar genti~l 1 ea. Blueline and sep~i of the followirg' 2" and 5" DI-SFL .2" and 5" Borehole c~moensat~d sonic 10g compensated neutron Formatior density ~compensated .formatioi~ densit3 , J gamma-gan~n]a ' COPY DATE- ,:,~ :,,..~ ,., !)~!t[~ IV /"~,;\ J. ; i .~J:?:": ti.ii[ 8: (i:;~; ( {~S. C,:'~ ~lJSSl'Orl ~,, FORM 1-2M02 (REV. 1 1-72) PRINTED IN U.S A. - · . . , STATE OF ALASKA ALASKA ~"_ AND GAS CONSERVATION C(]~" VIlSSION ~ ~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Drilling well E~ Redrill Workover operation [] 2. Name of operator 3. Address Union Oil Company of California* P. O. Box 6247, Anchorage AK 99502 4. Location of Well at surface 756.4'FSL, 1138.5'FWL, Dollv Varden Platform -- 5. Elevation in feet (indicate KB, DF, etc.) 106.2' Above MSL Sec 6-8N-13W-SM 6. Lease Designation and Serial No. ADL-18729 A-926 7. Permit No. 81-80 8. APl Number 50- 733-20131-01 9. Unit or Lease Name Trading Bay Unit 10. Well No. D- 9RD 11. Field and Pool McArthur River For the Month of. JANUARY ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks ll,060'TD 4,101' Drld during month of January 13. Casing or liner run and quantities of cement, results of pressur9 tests Ran 270 jts 7" casing from surface to shoe @ 11,033'. Cmtd w/ 1150 sx C1 G. Started running 3½" production tubing with gas lift equipment as of report date. 14. Coring resume and brief description NA 15. Logs run and depth where run DIL, BHC-Sonic, FDC/CNL from Surface to 10,916' Logger's CBL/CCL/GR from surface to 10,954' CBL Logger's TD Gyro from 5700' - 10,954' TD 1 6. DST data, perforating data, shows of H2S, miscellaneous data NA Field 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--R/eport on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with th® Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 *Marathon Oil Company - Sub-Operator Submit in duplicate Rev. 7-1-80 - STATE OF ALASKA ALASKA (~_ AND GAS CONSERVATION CC~ ~IISSION MONTHLY REPORT OF DRILLING AND WORKOVER Drilling well [] Redrill Workover operation [] 2. Name of operator 7. Permit No. Union Oil Company of California * BI-S0 3. Address 8. APl Number P. O. Pouch 6247, Anchorage AK 99502 50- 733-20131-01 4. Location of Well at surface 756.4 'FSL, l138.5'FWL, Sec. 6-T8N-R13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106.2'KB MSL 6. Lease Designation and Serial No. ADL-18729 A-926 9. Unit or Lease Name Trad 10. Well No. D-9~D 11. Field and Pool McArthur River For the Month of, December ,19 81 2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 6959'TD; 5750'KOP 1209'Footage Drld Began redrill activities 12-09-81. 11,153' w/ 188 sx cmt and perm BP 5721'-5780'. Direc drld 8%" hole Abandoned Hemlock perfs 10,596'- @ 6100'. Milled section in 9-5/8" from 5750'KOP to 6959!. csg 13. Casing or liner run and quantities of cement, results of pressure tests NA 14. Coring resume and brief description NA 15. Logs run and depth where run Gyro surv from surface to 10,700' CBL/VDL/GR from 1200' - 3000' and 5500' - 6000' .1 6. DST data, perforating data, shows of H2S, miscellaneous data NA 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. E DIST DRLG SUPT 01/0~/81 I SIGNED , TIlL ........... DATE NOTE--R/eport on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Rev. 7-1-80 *Marathon Oil Company - Sub-Operator Submit in duplicate June 17, 1981 Robert T. Anderson District Land Manager Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99502 Re~ Trading Bay Unit D-gRD Union Oil Company of California Permit No. 81-80 Sur. Loc.: 756.4'FSL, 1138~5'FWL, Sec 6, TSN, R13W, SM Bottomhole ~c.z 1063'FNL, 484'FEL, Sec 7, TSN, R13W, SM Dear Mr. Anderson Enclosed is the apprOVed application for permit to drill the above referenced well. Well samples and a mud log are not required. A d. irectional survey is required. If available, a tape containing the digitized log information shall be submitted on all logs for copying ~eXcept experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have Ben classified as important for the spawning or migration of anadromous fish. OperatiOns in these areas are subject to AS t6.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to ~r. ~obert T. Anderson -2- June 17, 1981 of the Department of' Environmental Conservation. To aid us in scheduling field work, we ~ould apprec£~te your ~otifytng this office within 48 hours-after th~ well l~ drt,1 1~. present. Very truly yours, ~oyle H. ~amilton Chairm~n of BY ORDER OF Alaska Oil & Gas Conservation Commission Mn c lo sure cc: Department of Fish & ~.ame, ~abitat Section Department of Environmental Conservation w/o/~n~l. Union Oil and ~ Divison: Western Region Union Oil ComPany of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Robert T. Anderson District Land Manager June 16, 1981 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of Alaska McArthur River Field Application to Complete Trading Bay Unit D-9RD Gentlemen: Union Oil Company of California, as operator of the Trading Bay Unit, hereby requests approval to complete and produce the subject well to be completed in the Hemlock Formation at a crestal final withdrawal point, pursuant to Rule 5 of Conservation Order No. 80. The subject well will be drilled from the D-9 location on the Dolly Varden Platform by Marathon Oil Company, suboperator. Very truly yours, JUN 1 6 Union Oil and ~."-~ Divison: Western Region Union Oil Coml~"-,n'y of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Robert T. Anderson District Land Manager June 16, 1981 Mr. Hoyle Hamilton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of Alaska Permit to Drill TBUS D-9RD Dolly Varden Platform, McArthur River Field State Lease ADL-18729 (8-86-71-5575-601351) Dear Mr. Hamilton: Enclosed for your further handling are three copies of the above captioned Permit to Drill. Also enclosed is our check #19135 in the amount of $100.00 to cover the filing fee. Enclosures (4) Very truly yours, Robert T. Anderson ! RECEIVED JUN 1 1981 0ii & G~s Cons. C0mm]ssion Anchorage ~'] STATE OF ALASKA ALAS OIL AND GAS CONSERVATION%.,.)MMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL ~ DEVELOPMENT OII_X~ SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator Un ion Oil Company of California* 3. Address P. O. Box 6247, Anchorage AK 99502 4. Location of well at surface 9. Unit or lease name 756.4'FSL, 1138.5'FWL, Sec 6-8N-13W-SM, Trading Bay Unit At top of proposed producing interval Leg A-2, Cond ~5 10. Well number 1000'FNL, 700'FEL, Sec 7-8N-13W-SM D-9RD At total depth 11. Field and pool 1063'FNL, 484'FEL, Sec 7-8N-13W-SM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. 106'KB MSL ADL-18729 A-926 McArthur River Field 12. Bond information (see ~0 AAC 25.025) Type Blanket Drlg Bond Surety and/or number B-2-165-724-1 Amount $200,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 21 mi. NW of Kenai miles 4254 feet well 1250 feet ~ 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date "~" !1~045'MD; 10~230'TVD feet 3085 06-29-81 19. If deviated {see 20 AAC 25.050) 20. Anticipated pressures 2,7~o psig@ ~$urface KICK OFF POINT 5695 feet. MAXlMUM HOLE ANGLE 18 ° l (see 20 AAC 25'035 (c) (2) __~)~psig@~~TD(TV'D) · 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT. Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 8-1/2, 7', 79¢/ N-Ri3 R,rt--t- 5~"5, ¢~ARI3,.I/IQR?, 11 (3A~;I 1(~ 9-z, fh A,,,,,-,-.v lr~;r~ ~.., I I ~ I ~ I I I ~ I 22. Describe proposed program: Plug existing wellbore and sidetrack @ 5695' in 9-5/8" csg. Drill 8-1/2" hole to projected TD at 11,045'MD; 10,230'TVD. Run and cement 7" liner (top @ 5480.'). Run gas lift assembly and~'~-b-n~lS]'ete as Hemlock producer. There are no wellbores within 200 feet of the proposed well other than the existing D-9. · RECEIVED JUN 1 6 1981 *Marathon Oil Company - Sub-ODerator 23' I ~~the best of mY I}nowledge Alaska 0il & Gaso0ns. Cuiil[I'l]ssi0n i ( Anchorage SIGNED Robert 'T'. ~nderson / ITLE District Land Manager DATE 6/16/81~ The space below for Commission use // CONDITIONS OF APPROVAL , Samples required Mud log required Directional Survey required APl number []YES (~NO [[]YES [~NO ~r.Y E S []NO 50- ~'.~ Permit number Approval date ~/~ I SEE COVER LETTER FOR OTHER REQUIREMENTS BY_ ~,- ,COMMISSIONER DATE Qune 17, 1981, APPROVED by order of the Commission Form 10-401 Submit in triplicate Rev. 7-1-80 - MARATHON OIL GO.- M~I Pon __~ Flowlin¢ Drillino~ Hippie. -- DOLLY .VARDEN PLATFORM -- (Mydri~) U Y , . CHoke L~nc 5 ~ ~ooo* -- Dia~ir~rne 2- I:~S/8"~ 5,000~ Riser ~_ BOP ~f~ck For Drilling' From Uhcler Surfo~ae O~sin8 To T D.-- Drill Deck Floor F~.~i/ /-- GIW £win.q- Bolt Clamp" Connectors [o° gl-: RECEIVED JUN 1 6 1981 Alaska 0il & 8as Cons, Cammission Anchorage 2 Ff..Spool o ! 12"~:5,000~ Casing Head w/Flenaed Outlets ~, Valves Well Room Floor Collar !;5 ~/~' Surface oD-27 ,~D-26 D-15 -~¢ · · \ D-15.. D-9 D-4 Nm MRO UST. 0 7 -I I D-12rd ,?~ O.8rd Il ~D-14 ,/ 4- .~,¢D-14'rd D-22 .~.~.; IA · · · · LEGEND COMP. PROD. B-I INd. 0-1 ABAND. PkOL. B-I 15 ABAND, INJ, B-I 0 O, B ENCH-I WELL PTS. MARATHON OIL COMPANY ANCHORAGE DIVISION · ,¢2c TRADING BAY UNIT McARTHUR RIVER FIELD 198i r:,, HEMLOCK ,.,r'O~lTlf,~ ;,` B E N C t ~ - I --8,u!7 contour ~'r£rvaL --- ~CO rt. Stole" i" , ~ooo' ~ . _ J L F'L'TcN - MARATH ON OZL -- DOLLY' .VARDEN PLATFORM -- L , ~ Mu<:l Pan )/ Fiowlih¢ Drillin~ Hippie. C~mp C_o ~nec-'fow We. Il Room Floor xx .,, ol 12",,, $,O00~'Oc~sing Me. ad w/F'lgn~¢cl Outlets ~ Valves ! Collar 0 '0 .- MRO ,'ST. oD- ,,,D-26 5rd I 31 I 2 rd -20~c ~ D-5rd .o:~o~ ~ 6 D-15rd2 ¢?~-.~ ,.. D-2A · ~. ~- -~. ~/.¢~ ~ D-lO' ' %%~._ . , D-13. 7 ' 12rd -8rd . -14 , .~ , .¢¢D-14rd KU '1 22' 0 KU-IA LEGEND COMP. PROD. B-I INJ. B-I ABAND. PkOb. B-I 15 ABAND. INJ. B'I BENCH -I WELL PTS. MARATHON COMPANY ANCHORAGE DIVISION Zqh` TRADING BAY UNIT McARTHUR RIVER FIELD £~ :, ; T ". P H E t,~ LOC K . ' :~;¢i~.~, BE NCI, - I CONTOUR INTERVAL ~ ICO FT. ~ole' I" , 20Om' At~thO~' J L IrL'TCNI ' : F F,.-. no C1W Tbg Hgr - 4-2/2 ASL x 4-1/2 ASL 299 4-1/2" Otis AO WLR~ ID=2.125" 4-1/2", 12.6# ASL .5/8", 40#, 43.59 & 47# ~t & 8' rd csg 1/2", 9.3~, EUE 8rd Junk at 11,152 PBTD 11,281 9-5/8" CSG 11,329 '3427 4811 ~868 6654 7213 7677 8105 8427 8747 9079 9411 9742 10,039 10,299 10,434 10,474 10,476 10,484 4-1/2" USI C2F mandrel w/ Guiberson M77 valve ID=4.0" I! : I! II II II II If 4-1/2" Otis XO circulating .sleeve xo- 4"1/2': 'x 3-1/2" Gu~herson RH-~ Hydraulic Pkr Tubing ~ail (end of cut-off) Perforations B-0 10,596 - 10,628 B-1 10,678 - 10,712 B-2 10,728 - 10,798 B-3 ·10,822 - 10,846; B-4 10,918 - 11,030 B-5 11,070 - 11,153 10,868 = 10,898 30' bar gun & 2-1/2" x 2" gauge tool lost 11-15-75 __:.SURFACE DOELY ~ VARDEN iPLATFOR M. ~ : WELL. NO'.D~9 RD' EG..A~2i. CONDUCTO -;SCAEE -j ,? "DECEMBER ,..~. it_F ..~j. ~i AUX TARGET., 9000 TMD i TARGETi-' 1.045 i.. CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee ~-/~ /2 thru 8) 1. Is the permit fee attached ............................... 2. Is well to be located in a defined pool ................... 3. Is well located proper distance from property line . . . ~ 4. Is well located proper distance from other wells ................... 5. Is sufficient undedicated acreage available in this pool ........... 6. Is well to be deviated and is well bore plat included .............. 7. Is operator the only affected party ................................ 8. Can permit be approved before ten-day wait ......................... (3) Admin &~~,zx ~, '1 ~ '~/ 9. hru '11) 10. 11. (4) Casg ~ ~'/?-Y/ (12 thru 20) (21 thru 24) 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. YES NO , , ,: (5) BOPE Does operator have a bond in force ....... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... _~_ ..... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all ~asing give adequate safety in collapse, tension and burst..~) ,. Is this well to be kicked off from an existing wellbore ............. ~ .... Is old wellbore abandonment procedure included on 10-403 ............ ~__ Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure irating - Test to ~oo psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. REMARKS (6) Add: 25. Additional requirements Additional Remarks: Geology_: Engineering: HWK ~ LCS BEW WVA JAL ~_~ rev: 03/10/81 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically organize this category of information. Y LYP OlO,HO1 VERIFICATION LISTING PAGE ** REEL HEADER SERVICE NANE :SERVIC DATE ~82/01/22 ORIGIN ~ REEL NAME :REEL ID CONTINUATION # :01 PREVIOUS REEL COMMENTS :REEL COMMENTS ** TAPE HEADER TAPE NAME CONTINUATION # PREVIOUS TAPE COMMENTS :TAPE COMMENTS ** FILE HEADER FILE NAME :SERVIC.O0! SERVICE NAME VERSION # : DATE : MAXIMUM LENGTH : 1024 FILE TYPE PREVIOUS FILE INFORMATION RECORDS MNEM CONTENTS CN : WN : FN : RANGI TOWN~ SECT~ COUN: STAT: CTRY: MNEM MARATHON OIL COMPANY TBU D RD9 MCARTHUR RIVER 8N 7 KENAI ALASKA U.S.A, CONTENTS PRES~ DILOO1F RECORD TYPE 047 ** UNIT TYPE CATE SIZE CODE 000 000 02O 065 000 000 010 065 000 000 014 065 000 000 003 065 000 000 002 065 000 000 00! 065 000 000 006 065 000 000 006 065 000 000 006 065 UNIT TYPE CATE SIZE CODE 000 000 007 065 LVP OlO,HOi VERIFICATION LISTING RECORD TYPE 047 ~* RECORD TYPE 047 ~ ** COMMENTS ** SCHLUMBERGER PACIFIC COAST COMPUTING CENTER COMPANY : MARATHON OIL COMPANY WELL = TBU D RD9 FIELD = MCARTHUR RIVER COUNTY ~ KENAI STATE = ALASKA ::::::::::::::::::::::::::::::::::::::::::::::::::_ _ . JOB # 10707,62510 OIL RUN #1, LOGGED 18-JAN-8~ BOTTOM LOG INTERVAL TOP LOG INTERVAL CASING-LOGGER BIT SIZE TYPE HOLE FLUID DENSITY VISCOSITY PH 10910 FT. 5732 FT. 9.625 IN. ~ 5732 FT. NOS~LFONATE 9.6 LB/G 43° 0 S 10.0 PAGE LVP OlO,HOi VERIFICATION LISTING PAGE FLUID LOSS RM % MEAS, TEMP, RMF La MEAS, TEMP, RMC La MEAS, TEMP, RM La BHT = 1, 0 La 68,0 F -' 2,150 La 68 0 F =: ,80 La 17! ~' MATRIX SANDSTONE ** DATA FORMAT RECORD ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 4 8 4 73 60 9 4 65 ,liN 0 ! 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT APl APl APl AP1 FILE SIZE PROCESS SAMPLE REPR ID ORDER # LOG TYPE CLASS MOD NO. LEVEL CODE DEPT FT 0 SFLU DIL OHMM 7 IbM OIL OHMM 7 ILO DIL OHMM 7 SP DIL MV 7 GR OIL GAPI 7 NPHI FDN PU 42 RHOB FDN G/C3 42 GR FDN GAPI 42 CALl FDN IN 42 DRHO FDN G/C3 42 NRAT FDN 42 NCNb FDN 42 FCNL FDN 42 DT BHC US/F 60 GR BHC GAPI 60 CALl BHC IN 60 0 0 0 0 0 0 0 0 0 0 0 0 1~ 46 0 0 ! 0 0 0 3! 32 0 0 68 2 0 0 35 1 0 0 31 32 0 0 28 3 0 0 44 0 0 0 42 1 0 0 34 92 0 0 34 93 0 0 52 32 0 0 31 32 0 0 28 3 0 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 I 68 1 68 IL 68 1 68 ! 68 I 68 ! 68 1 68 1 68 1 68 1 68 1 68 ! 68 1 68 I 68 ! 68 I 68 DATA DEPT SP 10959,5000 SFLU -999,2500 GR -999.2500 IbM -999.2500 NPHI -999.2500 -999.2500 RHOB -999,2500 -999,2500 LVP OlO,HO1 VERfFfCA~ION LISTING GR -999 2500 CABI NCNb -999!2500 FCNL CALl 8 5000 -999.2500 DRHO -999.2500 DT DEPT lO~00 0000 SFLU SP -59:1250 GR GR 76,1250 CALI NCNb 2942,0000 FCNL CALl 8.1016 3,2207 IBM . 0 DRHO 1296,0000 DT DEPT 10~00,0000 SFLU SP 74.1250 GR GR 50,7188 CALf NCNb 2952,0000 FCNE CALI 8.3984 11.3750 IbM 52,4375 NPHI 8 4375 DRHO 1269:0000 DT DEPT 10100.0000 SFLU SP 75.3125 GR GR 76.0625 CALf NCNb 3098.0000 FCNL CALI 8,6953 14.1875 79,5000 NPHI 8.5625 DRHO 1315.0000 DT DEPT 10~00.0000 SFLU Sp 89,4375 GR GR 43.9687 CALf NCNb 3380,0000 FCNb CAbI 8.4375 36.5625 IbM 47.8750 NPHI 8.5625 DRHO 1762,0000 DT DEPT 10500.0000 SFLU SP =54.0625 GR GR 47.3750 CALf NCNB 2914.0000 FCNL CALl 8.7656 14.7109 IbM 48 5000 NPHI 8:9297 DRHO 1279,0000 DT DEPT 10400.0000 SFLU SP -71.0625 GR GR 52.5000 CALf NCNb 4160.0000 FCNL CALl 8,6953 113.8750 ILM 52,2187 NPHI 8.5781 DRHO 3016.0000 DT DEPT 10300.0000 SFLU Sp -8.0703 GR GR 86.2500 CALl NCNB 2996.0000 FCNL CALI 8.3203 17.1250 8.1250 NPHI 78.6641 DRHO 1288.0000 DT DEPT 10200.0000 SFLU SP -17,5625 GR GR 59.9687 CALl NCNb 3318.0000 FCNL CALl 8.3984 10.8594 IbM 1953 DRHO 1501.0000 DT DEPT 10100.0000 SFLU $p 3.3828 GR 72,2500 IbM 50.8750 NPHI -999,250~ NRAT 79.187 GR 3.4160 ILD 24.5605 RHOB 0.1338 NRAT 82.3750 GR 8.5781 21.1426 RHOB 0.0161 NRAT 77.7500 GR 12.047IbP 2. ~80 RHOB 0.0 81 NRAT 74.1875 OR 20.~687 ILD . 902 RHOB .0254 NRAT 69.0000 GR 9.0313 IbD . 1172 RHOB .0796 NRAT 67.3750 GR 36,7188 ILD :9,5703 RHOB 0.0503 NRAT 59,1875 GR 12.6016 ILD 2~,0957 RHOB .0571 NRAT 77,1875 GR 8.2109 ILD 20 1660 RHOB 0:0239 NRAT 83.0000 GR 23.2656 ILD 68,9453 RHOB PAGE -999.2500 252.1250 3 6152' 1,7520 2,1406 58.9375 9.0781 2. 3828 2.1445 48.9062 10 7734 26 6875 2~~5078 I 7451 48 9062 16.0000 2'5020 2,1172 51'0938 · 9687 31'6348 1:3838 50,7500 12 2422 2910 85, :3750 7 8281 1426 57.5OOO 23 2656 LVP OiO,HO1 VERIFZCATION LISTING PAGE 5 GR NCNb CAEI DEPT SP GR NCNb CALl DEPT SP GR NCNb CALl DEPT SP NCNb CALl DEPT SP GR NCNb CALI DEPT SP GR NCNb CALl DEPT NCNb CALl DEPT SP GR NCNb CAb! DEPT 8P NCNb CALl DEPT SP 46 2500 CAbI loo0 -3 4 490 0 0 2 5 8 6 4 0 8 4 000 SFbU 625 GR 875 CAb! 000 FCNL 375 9900.0000 SFbU 2.4668 GR 106.6875 CALl 2150.0000 FCNL 8.7109 9800.0000 SFbU 1,~438 GR 41, 437 CALI 5.0000 rCNL 1319.6797 00,0000 SFbU 9~58,5625 GR 59.1250 CALI 3046.0000 rCNb 8,0547 9600.0000 SFLU ,5625 CALl 2 .0000 rCNL 8,7188 9500,0000 SFLU -24.5781 GR 91.0000 CALl oooo 9400,0000 8FLU -68,0625 GR 55.1875 CALl 3090.0000 FCNL 8,0625 9~00.0000 SFLU 7~,8125 GR 5 .0313 CALl 3322.0000 FCNL 8,1172 9200.0000 SFLU -44.1250 GR 10.2656 DRHO 351.2500 DT i69.1250 IbM 40.3750 NPHI 8.7031 DRHO 3578.0000 DT 16.7969 IbM t11.9375 NPHI 9.3438 DRHO 659.5000 DT 491.7500 IbM 48.8437 NPHI 13,2031 DRHO 263,0000 DT 12.5859 IbM 58,0938 NPHI 8.4844 DRHO 1333.0000 DT 11.5078 IbM 113.6250 NPHI 10.0313 DRHO 770,0000 DT 24,0938 IbM 86.3125 NPHI 10.4766 DRHO 1145.0000 DT 28.2344 51,5313 NPHI 8.4219 DRHO 1455.0000 DT 19,6250 IbM 58.6250 NPHI 8.5313 DRHO 1456.0000 DT 21.3281 IbM 99.8125 NPHI '0,0205 119.3750 70.4375 9.2773 0.0166 56.0000 9.5625 37.2070 0,0708 83.3750 12.3281 .8 6426 50:0708 126,1875 4.3203 1,8262 20.0767 82.1875 11.8125 28.5156 0.0664 78.1875 19.7656 3.1445 20,1396 71.3750 27.1875 20. 13 80,0000 17 0469 2.7539 20.O532 80.5625 13.8750 25.7324 NRAT GR ILD RHOB NRAT GR ILD RHOB NRAT GR RHOB NRAT GR ILD RHOB NRAT GR ILD RHOB NRAT GR ILD RHOB NRAT GR IbP RHOB NRAT GR IbP RHOB NRAT GR IbP RHOB 5.0586 47'3438 53 5625 *216465 I 3770 40 5313 9 5547 2207 112 1875 14 3750 ii6338 45859 51 3125 3,5918 2.4805 2.1953 53.9375 5859 ,7656 117.4375 22.3125 2.5938 2,4434 90,1250 28 3438 2.4199 2,O723 50,5000 16 3594 2~4512 2.2598 62.2187 12.2187 2.6289 LVP OR NCNb CALl DEPT SP GR NCNb CALI DEPT GR NCNb CALI DEPT SP OR NCNL CALI DEPT SP NCNb CALI DEPT SP GR NCNb CALl DEPT SP GR NCNb CALI DEPT SP GR NCNb CALl DEPT SP GR NCNb CALl DEPT SP OlO.HO1 VERIFICATION 96.8125 CALI 2350.0000 FCNL 8.7031 9200.0000 SFLU -96,3750 OR 45.1875 CALl 3546,0000 FCN5 8.1094 ~000,0000 SFLU 105.0625 GR 54.9375 CALl 2874.0000 FCN5 8,0547 8900,0000 SFLU -76,3125 GR 72,5000 CALI 3134,0000 FCNL 8,1406 8800 -83 51 3094 8 0000 SFLU 3750 GR 1562 CALI 0000 FCN5 0547 8700 5O 2978 8 0000 SFLU 6875 GR 1562 CALI 0000 FCNL 0234 8~00,0000 SFLU 15.0703 OR 77.6875 CALI 1675.0000 FCN5 8.6484 8500 0000 SFLU 69,3750 CALI 2162,0000 FCN5 8.0547 84.00,0000 SFLU 50.3438 OR 48,9062 CALI 0000 FCNL 8300.0000 SFLU -58,6250 GR LISTING 9,6719 DRHO 896,0000 DT 24.9062 44.3750 NPHI 8.4844 DRHO 1608.0000 DT 12.1719 ILM 52.7500 NPHI 8.4375 DRHO 1219.0000 DT 13,9531 67,0000 NPHI 8.5625 DRHO 1148,0000 DT 13.5625 57,3125 NPHI 8,3594 DRHO 1178.0000 DT 12,1719 I5)4 9062 NPHI 1193,0000 DT 57,5625 15~ 78,0625 NPHI 9,8125 DRHO 367,5000 DT 12.4844 67.1250 NPHI 9.8984 DRHO 743.0000 DT 24.5000 IbM 39 750.0 NPHI 8:4141 DRHO 1621,0000 DT 11.6016 ILM 42.4688 NPHI 0.0879 70.7500 7.8594 1660 74 0000 5.2641 22,3633 0'0410 84,0000 10.0703 26,4648 -0.0024 83.3750 8,6953 24.5~17 0,0 96 85,0000 5.9727 22.6074 0,0420 86,5625 29 0781 60~4980 0.0352 114,7500 7.4766 310.7383 875 5 7422 0 0918 79:7 oo 6.5859 25,6348 NRAT GR IbP RHOB NRAT GR RHOB NRAT GR ILD RHOB NRAT GR RHOB NRAT GR ILD RHOB NRAT GR ILD RHOB NRAT GR ILD RHOB NRAT GR ILD RHOB NRAT GR RHOB PAGE 2,5488 100,0000 5,8203 2,4316 2 O5820 52:: 000 4 0234 2:4004 2,2246 52.6875 8.6953 2,3906 2.5098 73,6250 6 8398 2:3711 2.3633 53.3750 4 7656 2'3633 2'2402 49:6563 2~.2500 ,8291 4,5508 79.6875 6 2031 2,5840 2,9687 81.5000 12 4453 2:so5 2,0098 40,7813 5 3398 2:3379 LYP 010,HO1 YERIFICATION LISTING PAGE 7 GR 45.6250 CAhI NCNL 2686.0000 FCNL CALI 8.1328 8,3828 DRHO 1069'0000 DT DEPT 8200.0000 SFLU SP -66.0000 GR GR 42.9375 CALl NCNL 3280.0000 FCNL CALI 7.9531 17.1875 ILM 39.4063 NPHI 8.3281 DRHO 1446.0000 DT DEPT 8100.0000 SFLU SP -6,5742 GR GR 71.6250 CALI NCNL 2284.0000 FCNL CALI 8.7500 3.3711 80.7500 NPHI 10.9062 DRHO 745.5000 DT DEPT 8000.0000 SFLU SP 0.9521 GR GR 106.8750 CALl NCNL 2116.0000 FCNL CALI 8.6328 9.5313 111.0000 NPHI 10,0000 DRHO 713.5000 DT DEPT 7~00.0000 SFLU SP 42.7813 GR GR 40.1562 CALI NCNL 3650.0000 FCNL CALl 8.1562 18.9375 42.9375 NPHI 8'4375 DRHO 1740.0000 DT DEPT 7800.0000 SFLU SP -38.5313 GR GR 50.5313 CAL! NCNL 3478,0000 FCNL CALI 8,0703 24.0938 ILM 44.8750 NPH! 8.4766 DRHO 1869.0000 DT DEPT 7700.0000 SFLU SP 1.4541 GR GR 109.0000 CALI NCNb 2044.0000 FCNL CALl 8.7891 5.7930 ILM 106'0000 NPHI 10.5391 DRHO 579.0000 DT DEPT 7600.0000 SFLU SP 5,0078 GR GR 103,8750 CALl NCNL 2412,0000 FCNL CALl 8.7109 9.7344 ILM 90.0625 NPHI 11,1094 DRHO 638.0000 DT DEPT 7500.0000 SFLU SP 1~.4922 GR GR 7 ,6250 CALI NCNL 2304.0000 FCNL CALI 8.5938 6 7852 67:3750 NPHI 11.3828 DRHO 765,5000 DT DEPT 7400.0000 SFLU SP -25.0156 GR 11.8594 ILM 39.7500 NPHI 0 0557 92:0000 8.4141 20.4102 0.0366 82,7500 3 9707 0.1191 82.1875 7.8594 30 8105 88. 5625 12.2109 19.6289 0.0386 86.0000 12.9766 6,5039 10.0259 78.3750 5 8086 37:4023 0.0752 88,5625 8.2656 38,4766 0.0747 88,1875 7.~781 3t · 430 0,0723 88,5625 7.57O3 23,5840 NRAT GR ILD RHOB NRAT GR ILD RHOB NRAT GR RHOB NRAT GR RHOB NRAT GR RHOB NRAT GR RHOB NRAT GR RHOB NRAT GR ILD RHOB NRAT GR RHOB 2 4375 55:3438 6 2227 2 4199 2 0879 44 3438 4 4805 2!6543 2 8535 71 8125 8 0000 2.9180 110.4375 2 0449 45 2500 9 9844 2:4570 1.8379 46.7188 5,9023 2,5430 3.3281 108.1875 8,2891 ,4824 ;4121 111.5000 8.2266 2.4648 3.0410 64,0625 6.1445 2,3730 LVP GR NCNL CALl DEPT SP NCNL CALI DEPT SP NCNL CALf DEPT SP NCNb CALl DEPT SP NCNb CALl DEPT SP NCNL CALX DEPT SP NCNb CALI DEPT SP NCNb CALf DEPT SP NCNb CALl DEPT SP OIO,HO1 VERIFICATION 46,2187 CALl 3208,0000 FCNb 8.4609 730 1 10 182 0 0 2 4 0 3 3 0 9 0 000 SFLU 219 GR 750 CALI 000 FCNL 781 72.00i0000 SFLU 27 5625 GR 49 8125 CALX 3480.0000 FCNL 8.5781 7100.0000 SFLU 6 4609 OR 98:3750 CALX 2408,0000 FCNL 9,3594 7000,0000 SFLU 10.4063 GR 99.2500 CALX 0000 FCNL 6900.0000 SFLU 6.3984 GR 53.7500 CALI 3174,0000 FCNL 8.9375 6800.0 SFLU 14 4 OR 103 8 CALX 2204 0 FCNL 9 2 000 688 750 000 969 6700.0000 SFLU 5,1367 GR 38.6250 CALl 1341.0000 FCNL 11,0078 6600 0000 SFLU 94.0000 CALf 0000 FCNL 202~'4922 6500.0000 SFLU 1.9238 GR LISTING. 8.5625 DRHO 1346.0000 DT 6.8047 107,3750 NPHX 3906 DRHO 19.1250 IbM 55.5313 NPHI 8.6328 DRHO 1665,0000 DT 7.3672 IbM 97,8750 NPHI 12,4922 DRHO 682,0000 DT 7,1016 IbM 101,0000 NPHI 10.5469 DRHO 509.7500 DT 8,5156 IbM 60,4063 NPHX 9,2578 DRHO 1156,0000 DT 5 1133 IbM 10116250 NPHI 11 2500 DRHO 638.0000 DT 67.3125 IbM 31 031 NPHI 275.0000 DT 7,9414 89,0625 NPHI 10.1250 DRHO 552,5000 DT 6.9062 IbM 97.1875 NPHI 0.0386 90.7500 6 38 246 0.1245 98,3750 11,1953 19'3848 0.0103 86.1875 7.5352 32.6660 0.1050 93,3750 6,5234 35.5957 0.1436 107.3750 7,7734 26, 96.1875 0.6§47 92,1875 8.7969 O. 49 131.7500 6.0234 36.7676 0.0557 113.3750 6.2695 36.4746 NRAT GR ILD RHDB NRAT XLD RHOB NRAT GR RHOB NRAT GR IbP RHOB NRAT GR RHOB NRAT GR IbP RHOB NRAT OR XLD RHOB NRAT OR IbP RHOB NRAT XLD RHOB PAGE 2.3164 46.3438 6. 9609 '3379 ].6133 120'5000 9,2656 2,4141 2'0430 54'7188 .1406 '5195 3.1445 104.5000 7 5352 214766 3 2305 113 5625 7 2383 2 3926 2 5391 58 0000 5 4922 2i4609 3 1934 97 3125 36,8750 .4805 ,9883 33,8750 5 6289 '4395 87.8125 6.7969 2.4023 bYP OiO.HO1 VERIFICATION LISTING PAGE 9 GR 106.5000 CALI NCNb i916.0000 FCNb CAbI 9,6328 14,4766 DRHO 525.0000 DT DEPT 6400 SP -10 GR 57 NCNb 2772 CALI 8 0000 SFLU 2656 GR 6250 CALI 0000 FCNb 5313 li.7422 IbN 5~.4688 NPHI · 77]4 DRHO 2052,0000 DT DEPT 6300 SP 19 GR 88 NCNb 2500 CALI 9 .0000 SFLU .7188 GR .5625 CALl .0000 FCNb .7031 3,3262 IbN 82.0000 NPHI 25,6875 DRHO 789.0000 DT DEPT 6200 SP 14 GR lO0 NCNb 2260 CALl 9 ,0000 SFLU 5 CALl 0000 FCNL ~0256 · 7.7734 IbM 111,5625 NPHI 18,5313 DRHO 694,0000 DT DEPT 6100 $p -19 GR 63 NCNb 3064 CALI 8 0000 $FLU 7500 GR 0313 CALI 0000 FCNL 7344 10.7188 IbM 69.3125 NPHI 9.3047 DRHO 1181,0000 DT DEPT 6000 $P 4 GR 90 NCNb 2244 CALI 20 .0000 $rbU 2031 GR :3750 CALl .0000 FCNb ,2109 7.8750 IbM 83.0625 NPHI 15.1797 DRHO 691,5000 DT DEPT 5900 $P 2O GR 92 NCNb 1926 CALl 9 ,0000 SFLU .2813 OR .0000 CALl : OOOo 6.9297 IbM 96,3750 NPHI 91].6719 DRHO 4 .5000 DT DEPT 5800 $P 24 GR 71 NCNb 1550 CAbI 11 .0000 $FbU .2094 GR .8750 CALI .0000 FCNb ,5625 3,5801 IbM 74.0625 NPHI 22.3594 DRHO 391,5000 DT DEPT 5700 8P =44 GR 53 NCNb 1290 CALl 8 0000 SFLU 3750 GR 5625 CALl 0000 FCNb 5313 0.4912 IbM 5~.6563 NPHI .4941 DRHO 258.0000 DT DEPT $P 650.5000 SFLU ~999.2500 GR -999.2500 IbM -999.2500 NPHI 0,0791 NRAT 103.0000 GR 9.7813 ILD 25·5859 RHOB 0.0200 NRAT 98.7500 GR 3.7617 30,4688 RHOB 0.0806 NRAT 95.1875 GR 7.4805 29.2969 RHOB 0.0552 NRAT 98.1875 GR 9.~531 25. 977 RHOB 0.0444 NRAT 100.3750 GR 8,3125 29,2969 RHOB 0 87 NRAT 97:1~ 50 7.4805 IbP 36.5723 RHOB 0.1191 NRAT 105.0000 GR 6.7539 IbD 43.6523 RHOB 0.1294 NRAT t05.5625 GR 2000.0000 66.~)98 RHOB -6. 58 NRAT 56.1875 GR -999.2500 -999.2500 RHOB 3.3906 96.8125 9 2109 2:3184 2 4688 71:6875 3 8906 · ,4238 ,0801 93,6250 8 2422 2 4785 3 0801 113 0625 .9727 .2813 2.4805 55.1875 8,5859 2,4531 2 9902 8 4297 3.4785 112.4375 6 8750 2:0859 3,9707 76,2500 13 2891 . -1,9844 4,4492 58,3438 -999,2500 -999,2500 LVP 010,HO! VERIFICATION LISTING GR -999.2500 CALI NCNb -999.2500 FCNb CALI 8.5234 -999,2500 DRHO -999.2500 DT ** FILE TRAILER ** FILE NAME :SERVIC,001 SERVICE NAME VERSION # DATE ~ MAXIMUM LENGTH : 1024 FILE TYPE NEXT FILE NAME ********** EOF -999,2500 NRAT 63.5938 GR PAGE 10 -999 2500 20:6719 ** TAPE TRAILER SERVICE NAME ~SERVIC DATE :82/01/22 ORIGIN ~107~~ TAPE NAME CONTINUATION # :0! NEXT TAPE NAME COMMENTS :TAPE COMMENTS ** REEL TRAILER SERVICE NAME :SERVIC DATE :82/01/22 ORIGIN ~ REEL NAME :REEL ID CONTINUATION # NEXT REEL NAME COMMENTS :REEL COMMENTS EOF ********** EOF