Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
180-110
2025-0505_No-Flow_TBU_D-16RD_ksj Page 1 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 05/05/2025 P. I. Supervisor FROM: Kam StJohn SUBJECT: No Flow Test Petroleum Inspector Trading Bay Unit D-16RD Hilcorp Alaska LLC PTD 1801100 05/05/25: I arrived on the Dolly Varden Platform and met with Hilcorp Operator JD Hall. We discussed the options for testing and visually inspected the rig up. They used a one- inch hose and piping for flow and pressure bleeds and have an appropriate digital pressure gauge and low-flow meter installed for testing. I verified the calibrations and received the supporting documents. TBU D-16RD was shut in at 09:35 to start the test. The following table shows test details: Time Pressures1 Flow Rate2 Remarks (psi) Gas – scf/hr Liquid – gal/hr 09:33 0.10/0/128 Record Initial Pressures 09:35 0.10/0/128 Well shut In 09:50 0.10/0/128 10:05 0.30/0.01/128 10:20 0.30/0.03/128 10:35 0.30/0.04/128 10:35 0.3/0.04/128 700 0 Open well to flow. Dropped to 0 scf/hr in about 10 seconds 10:40 0.18/0.02/128 Shut in well 10:55 0.31/0.06/128 11:10 0.34/0.06/128 11:25 0.34/0.06/128 11:40 0.34/0.06/128 11:40 0.34/0.06/128 800 0 Open well to flow. Dropped to 0 scf/hr in about 10 seconds. 11:45 .0/.0/128 End No-Flow Test 1 Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr This test shows that this well will not flow to the surface without assistance. Attachments: Photos; Test Instrument Certifications 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.05.14 16:14:52 -08'00' 2025-0505_No-Flow_TBU_D-16RD_ksj Page 2 of 3 No-Flow Test – TBU D-16RD (PTD 1801100) Photos by AOGCC Inspector K. StJohn 5/5/2025 Low Flow Meter 2025-0505_No-Flow_TBU_D-16RD_ksj Page 3 of 3 Digital Pressure Gauges Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/15/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250515 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 241-23 50283201910000 223061 4/24/2025 AK E-LINE Plug/Perf T40412 END 2-72 50029237810000 224016 4/4/2025 READ CoilFlag T40413 IRU 241-01 50283201840000 221076 4/30/2025 AK E-LINE Perf T40414 IRU 241-01 50283201840000 221076 4/23/2025 AK E-LINE Plug/Perf T40414 KU 33-08 50133207180000 224008 4/22/2025 AK E-LINE PPROF T40415 MRU D-16RD 50733201830100 180110 4/21/2025 AK E-LINE Cement/Perf T40416 NSU NS-06 50029230880000 202101 4/21/2025 AK E-LINE PPROF T40417 NSU NS-19 50029231220000 202207 4/27/2025 AK E-LINE Perf T40418 NSU NS-20 50029231180000 202188 4/24/2025 AK E-LINE Perf T40419 NSU NS-23 50029231460000 203050 4/23/2024 AK E-LINE Packer T40420 PBU 02-10B 50029201630200 200064 3/21/2025 BAKER SPN T40421 PBU 06-19B 50029207910200 224095 3/1/2025 BAKER MRPM Borax T40422 PBU S-100A 50029229620100 224083 2/28/2025 BAKER MRPM Borax T40423 PBU Z-235 (Revised)50029237600000 223055 4/1/2025 READ InectionProfile T40424 SRU 231-33 50133101630100 223008 5/1/2025 AK E-LINE Plug/Perf T40425 Revision Explanation: Processing report added Please include current contact information if different from above. T40416MRU D-16RD 50733201830100 180110 4/21/2025 AK E-LINE Cement/Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.16 08:15:21 -08'00' Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov May 15, 2025 Mr. Dan Marlowe Operations Manager – CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification Trading Bay Unit D-16RD PTD 1801100 Dear Mr. Marlowe: OnMay 5, 2025, an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit D-16RD located on the Dolly Varden Platform in Cook Inlet. The AOGCC Inspector confirmed that the proper test equipment was rigged up prior to the test as outlined in AOGCC Industry Guidance Bulletin 21-001. The test procedure employed was a 1 hour shut in period to monitor pressure build up followed by a short flow period through the test equipment to an open top tank – repeated 1 additional time. Initial gas rates were below the allowed limit and fell to zero within about 10 seconds. There was no oil flow rate observed during the no-flow test. Trading Bay Unit D-16RD may be produced without a subsurface safety valve as confirmed by the AOGCC Inspector at the conclusion the test. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Trading Bay Unit D-16RD demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no-flow test. Please retain a copy of this letter on the Dolly Varden Platform. Sincerely, James B. Regg Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors James B. Regg Digitally signed by James B. Regg Date: 2025.05.15 10:43:23 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20250317 1600 APPROVAL DUMB BAIL CEMENT Trading Bay Unit D-16RD PTD 180-110_Sundry_324-703 Date:Monday, March 17, 2025 4:04:32 PM From: Rixse, Melvin G (OGC) Sent: Monday, March 17, 2025 3:58 PM To: Casey Morse <Casey.Morse@hilcorp.com> Cc: Juanita Lovett <jlovett@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com> Subject: RE: Trading Bay Unit D-16RD PTD 180-110_Sundry_324-703 Casey, Approved to dump bail cement as described below. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Monday, March 17, 2025 3:27 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com> Subject: Trading Bay Unit D-16RD PTD 180-110_Sundry_324-703 Mel, We completed the rig workover portion of Sundry 324-703 on the Dolly 16RD in January. During the workover, we cleaned the well down to the base of the Hemlock 1 zone (13,648’). We then completed the well with gas lift and returned to production. Our intent was to utilize gas lift to produce primarily from the Middle Kenai G Pool (generally lower water rates / higher oil cut than the Hemlock). Since returning the well to production, we’ve seen essentially all water in the produced fluids. Unfortunately, we’ve also dropped a fish in the well, and we identified additional fill on top of the fish since returning the well to production. The sundry includes procedures for adding perfs within the Middle Kenai G Pool. Before shooting the perfs envisioned in the sundry, we would like to attempt a water shut-off. Based on the flowing survey we obtained on 2/19 and the fluid composition we see at surface, it suggests that we are producing from the Hemlock, and this is likely limiting the drawdown we need for getting G zone contribution. In mid-February, slickline made numerous bailer runs with repeated tags between ~13,360 – 13,370’ and returned with sand each time. If our interpretations are correct, the produced fluids are coming from below this sand fill (top of Hemlock Pool is 13,622’ MD). We are seeking your approval to dump bail ~10’ of cement on top of the fill / debris at ~13,360’ to restrict / shut off from the Hemlock formation before proceeding with perforations within the Middle Kenai G Pool (~12,875 – 13,350’). Thank you, Casey Morse Operations Engineer Cook Inlet Offshore Hilcorp Alaska, LLC (907) 777-8322 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. 2025-0205_No-Flow_TBU_D-16RD_am Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 02/06/2025 P. I. Supervisor FROM: Austin McLeod SUBJECT: No Flow Test Petroleum Inspector Trading Bay Unit D-16RD Hilcorp Alaska, LLC PTD 1801100; Sundry 324-703 02/05/2025: I traveled to location to witness a No-Flow Test on the well after a recent workover had been completed (above Sundry). JD Hall represented Hilcorp. The new gas lift completion well had been depressuring since 14:30 on 02/03/2025 prepping for the test. Operations had the inner annulus and tubing in communication at surface even though the packer was not vented. Test gauges and flow meter in use had proper calibrations. No offset injectors were online as the platform has no waterflood injection. They shut in the well and started the test. We took pressures every fifteen minutes and opened to the meter on the hour twice. When opened to the meter no liquid and no measurable gas was observed. The well was left open to flow through the meter for approximately two minutes each time. I found no issues with this inspection – the well is not capable of unassisted flow. The following table shows test details: Time Pressures1 Flow Rate2 Remarks (psi) Gas – scf/hr Liquid – gal/hr 08:00 0 / 0 / 178 Shut in for pressure build 08:15 0 /0 / 178 08:30 0 / 0 / 178 08:45 0 / 0 / 178 09:00 0.01 / 0 / 178 0 0 Open to meter. Needle barely moved. Slight feel. 09:02 0 / 0 / 178 0 0 Shut in for pressure build 09:17 0.01 / 0.03 / 178 09:32 0.01 / 0.02 / 178 09:47 0.02 / 0.02 / 178 10:02 0.02 / 0.02 / 178 0 0 Open to meter. Needle barely moved. Slight feel. 10:02 0.02 / 0.02 / 178 0 0 End Test 1 Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr Attachments: Photo 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.02.11 13:41:55 -09'00' 2025-0205_No-Flow_TBU_D-16RD_am Page 2 of 2 No-Flow Test – TBU D-16RD (PTD 1801100) Photo by AOGCC Inspector A. McLeod 2/5/2025 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.govFebruary 11, 2025 Mr. Dan Marlowe Operations Manager – CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification Trading Bay Unit D-16RD PTD 1801100 Dear Mr. Marlowe: On February 5, 2025, an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit D-16RD located on the Dolly Varden Platform in Cook Inlet. The AOGCC Inspector confirmed that the proper test equipment was rigged up prior to the test as outlined in AOGCC Industry Guidance Bulletin 21-001. The test procedure employed was a 1 hour shut in period to monitor pressure build up followed by a short flow period through the test equipment to an open top tank – repeated 1 additional time. There was neither gas nor oil flow rates observed during the no-flow test. Trading Bay Unit D- 16RD may be produced without a subsurface safety valve as confirmed by the AOGCC Inspector at the conclusion the test. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Trading Bay Unit D-16RD demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no-flow test. Please retain a copy of this letter on the Dolly Varden Platform. Sincerely, James B. Regg Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors James B. Regg Digitally signed by James B. Regg Date: 2025.02.11 17:15:16 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/07/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240107 Well API #PTD #Log Date Log Company Log Type AOGCC Eset # END 2-72 50029237810000 224016 11/16/2024 HALLIBURTON TEMP END 2-74 50029237850000 224024 12/5/2024 HALLIBURTON MFC24 END 2-74 50029237850000 224024 8/13/2024 DarkVision HADES (Down hole camera) KGSF 1A 50133101600100 220063 12/5/2024 HALLIBURTON EPX-MFC40 MPU F-13 50029225490000 195027 12/22/2024 HALLIBURTON WFL-TMD3D PU F-40 50029222150000 191117 11/9/2024 READ CaliperSurvey MPU I-04A 50029220680100 201092 11/22/2024 HALLIBURTON COILFLAG MPU J-02 50029220710000 190096 12/22/2024 READ CaliperSurvey PBU L-04 50029233190000 206120 11/23/2024 HALLIBURTON WFL-TMD3D PBU L-221 50029233850000 208031 12/11/2024 HALLIBURTON WFL-RMT3D PBU Z-ϯϰ 50029234690000 212061 12/15/2024 HALLIBURTON WFL-RMT3D PBU Z-2ϯϱ 50029237600000 223055 9/24/2024 READ InjectionProfile PBU Z-ϮϮϯ 50029237200000 222080 11/24/2024 HALLIBURTON WFL-TMD3D SCU 42-05Y 50133205700000 207082 12/7/2024 HALLIBURTON EPX-MFC24 TBU D-16RD 50733201830100 180110 12/19/2024 READ CaliperSurvey TBU D-17RD 50733201680100 181023 12/21/2024 READ CaliperSurvey Please include current contact information if different from above. T39915 T39916 T39916 T39917 T39918 T39919 T39920 T39921 T39922 T39923 T39924 T39925 T39926 T39927 T39928 T39929 TBU D-16RD 50733201830100 180110 12/19/2024 READ CaliperSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.07 15:26:55 -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: Convert to Gas Lift 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?C.O. 228A Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 14,645 N/A Casing Collapse Structural Conductor Surface 1,540psi Intermediate 3,090psi Production 4,790psi Liner 7,020psi 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 Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 12/28/2024 14,644'4,955' 3-1/2" & 2-7/8" 10,265' N/A & N/A N/A & N/A 9,692' Perforation Depth MD (ft): 9,955' 13,091 - 14,066 9,692' 7" 9,157 - 9,832 6,923'7-5/8" 13-3/8" 9-5/8"9,955' 2,554' MD 5,750psi 3,090psi2,347' 7,096' 2,554' Length Size Proposed Pools: L-80 TVD Burst 8,979 & 12,615 6,890psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017579 180-110 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20183-01-00 Hilcorp Alaska, LLC Trading Bay Unit D-16RD AOGCC USE ONLY 8,160psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY McArthur River Hemlock Oil / Middle Kenai G Oil Same 10,267 14,198 9,923 2,383psi 14,510 No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:16 pm, Dec 17, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.12.17 13:58:11 - 09'00' Dan Marlowe (1267) 324-703 10-404 SFD 12/17/2024BJM 12/23/24 Perforate X , ADL0018716 SFD BOP test to 2500 psi DSR-12/20/24MEUIRUMOF Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2024.12.24 12:02:46 -09'00' 12/24/24 RBDMS JSB 123024 ESP to GL recomplete RWO Well: Dolly Varden D-16RD Well Name:D-16RD API Number:50-733-20183-01-00 Current Status:Offline ESP Oil Producer Leg:B-1 (SE) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:180-110 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Maximum Expected BHP:3,277 psi @ 8,948’ TVD 36 day shut in 9/22/24 Max. Potential Surface Pressure: 2383 psi Using 0.1 psi/ft Brief Well Summary Dolly Varden D-16RD is a G-zone / Hemlock oil producer. Although the ESP has not yet failed, the well is experiencing an inflow issue that we have not been able to remedy non-rig. Given the lower total fluid rates in recent years, D-16RD is a good gas lift candidate. This workover aims to restore productivity and recomplete as a gas lift producer. The goal of this project is to cleanout the liner to restore productivity and then convert the well to Gas Lift Pertinent wellbore information: -Last casing test: 5/8/2023 at 12,833’ to 2,300 psi -Last no-flow test: PASS 11/4/24 - Max inclination: ~55-degree sail angle from 2700 – 14,100’ MD - Pertinent History o 11/26/24: Fluid and oil both go to 0. No inflow (bridged off in liner?) o 11/4/24: Latest NFT (pass) Well comes back at 1000 fluid and 150bopd (bridge dislodged?) o 10/23/24: Squeezed away 54bbls 15% HCL: No change in gross fluid nor oil o 9/22/24: Squeezed away 48bbls of 15% HCL: Gross fluid rebounds from 150 to 300, but no oil o 8/14/24: Squeezed away 39bbls Safe acid: No restoration of gross fluid nor oil - May-2023 RWO for cleanout and new ESP o 5-7/8” bit milled from 11,210’ – 13,671’ MD (heavy scale) o At 13,671’ MD (top HK-2 perfs) well went form 1:1 returns to 50bph losses o Attempted to mill deeper, but string kept plugging up, and couldn’t get deeper o BHA had metal marks on outside indicating possible liner damage at 13,671’ MD o MIT of production casing / liner PASSED to 2300psi with test packer at 12,833’ MD - December-2020: ESP dies, live GLV’s installed and well produced on GL - 2017 RWO to remove GL completion and install ESP o Milled from 13,126’ to base G-sands at 13,510’ MD with a 6” junk mill o Milled from 13,510’ – 14,198’ with 6” junk mill pushing old packer and tailpipe into rathole - 2015 RWO to convert from long term SI injector to producer o Found hole in 9-5/8” casing o Installed and cemented 7-5/8” scab liner back to surface o MIT on of 7-5/8” casing, and 7” casing against an RTTS set at 13,015’ MD passed to 2500psi o MIT-IA to 1500psi passed against production packer set at 12,877’ MD o Caliper log ran, and shows 7” to be in good condition ESP to GL recomplete RWO Well: Dolly Varden D-16RD RWO Procedure: 1. MIRU HAK 404 2. Circulate well: a. Work over fluid will be filtered inlet water (8.4ppg) b. Ensure any wellbore fluids are fully displaced with KWF either via circulation or bullheading c. Total WBV = 824bbls i. Tubing volume = 78bbls ii. IA to ESP = 706bbls iii. Liner below ESP to base HK-2 perf = 40bbl 3. Set BPV/TWC, ND tree, NU Hilcorp BOP stack (see attached) a. Notify AOGCC 48 hours in advance for witness b. Test to 250psi Low /2,500psi High / 2,500psi Annular c. BOPE will be used as needed to circulate the well 4. Pull BPV/TWC 5. BOLDS and unseat hanger 6. POOH laying down 3-1/2” ESP/GL completion 7. PU work string 8. MU 7” liner cleanout assembly 9. RIH and mill/cleanout casing to target depth = ±13,671’ MD (or deeper if practical) 10. POOH and lay down cleanout BHA and work string 11. Pickup GL completion a. Target packer at ±12,825’ MD (8,977’ TVD) b. SSSV landing nipple planned at 400’ MD c. Plan to run completion with live GLV’s 12. Land GL completion and set packer 13. MIT-T to 2300psi (charted) 14. CMIT-TxIA to 2300psi Charted 15. Set BPV/TWC, ND BOP 16. NU tree and test, pull BPV/TWC 17. RDMO RWO crew and equipment ESP to GL recomplete RWO Well: Dolly Varden D-16RD E-Line Perf procedure 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 2500psi high 3. RIH and perforate infill oil Sands from ±12,875’ - ±14,200’ MD (±9,010’ - ±9,925’ TVD) a. Top Middle Kenai G Oil Pool: 12,785’ MD / 8950’ TVD b. Base Hemlock Oil Pool: 14,556’ MD / 10,197’ TVD (below PBTD) 4. RDMO EL Another No Flow Test will be required after on-rig cleanout and/or post-rig perforating. Conduct NFT after ~10 days of stable production Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Current Wellhead Diagram 4. Proposed Wellhead Diagram 5. BOP Drawing 6. 404 Fluid flow diagram 7. RWO Sundry Change Form ±12,875’ - ±14,200’ MD (±9,010’ - ±9,925’ TVD) Updated by JLL: 05/22/23 SCHEMATIC McArthur River Field, TBU Well: D-16RD PTD: 180-110 API: 50-733-20183-01 As Completed: 05/15/23 CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8" 61 K-55 Seal Lock 12.515 Surf 2,554' 9-5/8" 40 N-80 Butt 8.835 Surf 5,514' 43.5 N-80 Butt 8.775 5,514' 8,060' 47 N-80 Butt 8.681 8,060' 9,955' 7-5/8” 29.7 L-80 SLIJ-II 6.875 Surf 9,692’ 7" 29 N-80 Butt 6.184 9,689' 14,644' Tubing Detail 3-1/2” 9.2 L-80 Supermax 2.992” Surf 8,979’ 2-7/8” 6.5 L-80 IBT 2.441 8,979’ 12,615’ PERFORATION DETAIL Zone Top (MD)Btm (MD) Top (TVD) Btm (TVD) Feet SPF Date G-3 13,091' 13,120' 9,157' 9,177' 29' 5 5/10/2015 G-4 13,190' 13,207' 9,225' 9,237' 17' 5 5/10/2015 G-5 13,354' 13,364' 9,338' 9,345' 10' 5 5/10/2015 G-5 13,440' 13,450' 9,398' 9,405' 10' 5 5/10/2015 HK-1 13,622' 13,664' 9,525’ 9,555’ 42’ 5 06/30/17 HK-1 13,632' 13,688' 9,532' 9,572' 56 8 10/13/1984 HK-2 13,696' 13,848' 9,577' 9,683' 152' 5 06/30/17 HK-3 13,885' 13,995' 9,708' 9,784' 110' 5 06/30/17 HK-3 13,985' 14,000' 9,777' 9810 15 8 4/27/1981 HK-3 14,006' 14,033' 9,792' 9,810' 27' 5 06/30/17 HK-3 14,015' 14,036' 9,798' 9,812' 21 8 4/27/1981 HK-4 14,052' 14,066' 9,823' 9,832' 14 8 4/27/1981 PBTD: 14,510’ TD: 14,645’ 9-5/8” Window @ 9,955’ MD HOWCOEZSV permanent BP @ 14,510’ Clean-out to 14,198’ on 7/27/17 1 DV Collar @ 6,822’ HK-1 Top of Liner 9,689’ HK-4 G-3 G-5 G-4 HK-3 HK-2 Casing leak 2,473 – 2,514 MD Jewelry Details No Depth (MD)Depth (TVD)ID OD Item 44’ 44’ Hanger 1 12,615’ 8,838’ -- 4.000 Bolt-on Discharge 12,616’ 8,839’ -- 4.000 Pump (4) 400 Series, 110 Stage SF2700, 7/8" Inconel Shaft, N015 Housing, 1:3 AR, TS3, HTEM 12,703’ 8,896’ 4.000 Gas Separator/Intake, 400 Series, H2X, SS, Inconel Shaft, Durahard 12,709’ 8,900’ 4.000 Upper/Lower Tandem Seals - 400 Series, BPBSL 12,725’ 8,910’ 4.560 Motor (2) 456 Series, FMS2LT & FMS2UT 12,782’ 8,948’ 4.560 Centerlizer / Anode OPEN HOLE / CEMENT DETAIL 13-3/8"17-1/2" hole: Pumped 2000sxs class G 15.3ppg lead followed by 400sxs class G tail cement.Saw cement to surface. 9-5/8" 12-1/4" hole TD'd at 11,608' MD, but left fish with top at 10,579’ in D-16 parentbore (1969). Ran 9-5/8” casing to 10,295’ MD Primary job pumped 700 + 300sxs of Class G. Assuming 30% washout, and 1.1 cu ft. / sxs, ToC = 7600’ MD Stage 2 through DV collar at 6822' MD: Pumped 1000 + 300sxs class G . Assuming 30% washout, and 1.1 cu ft. / sxs, ToC = 3,300’ MD 7-5/8” scab Scab liner run 4/22/15 to remediate casing leak at ~2500’. Pumped 155bbls 12.5ppg lead cement, followed by 20bbls 15.8ppg tail cement.Saw cement back to surface. 7" 8-1/2" hole: Liner hanger issues, so didn’t pump traditional job. Perf’d just above landing collar at 14,553’ MD. Set cement retainer at 9758’ MD. Pumped 1235sxs class G 15.6ppg cement. Circ’d cement off top liner afterwards. Cement mill out run found ToC at 9020’ MD inside 9-5/8”. 5/9/15 CBL show's ToC at ToL (9,689’ MD) Updated by JLL: 05/22/23 SCHEMATIC McArthur River Field, TBU Well: D-16RD PTD: 180-110 API: 50-733-20183-01 As Completed: 05/15/23 GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 2,241’ 2,125’ 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 2 4,705’ 3,656’ 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 3 5,917’ 4,458’ 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 4 6,730’ 4,971’ 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 5 7,478’ 5,457’ 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 6 8,224’ 5,946’ 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 7 8,968’ 6,447’ 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 FISH Depth (MD) Depth (TVD) Item 14,198’ 9,923’ Milled / pushed Baker FB-1 7” x 4” injection packer with tail pipe and X- nipple (~50’ length) Updated by TDF: 12/17/2024 PROPOSED McArthur River Field, TBU Well: D-16RD PTD: 180-110 API: 50-733-20183-01 As Completed: FUTURE GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1GLM #1 2GLM #2 3GLM #3 4GLM #4 5GLM #5 6GLM #6 7GLM #7 8GLM #8 9GLM #9 10 GLM #10 CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8" 61 K-55 Seal Lock 12.515 Surface 2,554' 9-5/8" 40 N-80 Butt 8.835 Surface 5,514' 43.5 N-80 Butt 8.775 5,514' 8,060' 47 N-80 Butt 8.681 8,060' 9,955' 7-5/8” 29.7 L-80 SLIJ-II 6.875 Surface 9,692’ 7" 29 N-80 Butt 6.184 9,689' 14,644' Tubing Detail 3-1/2” Surface ±12,925’ PBTD: 14,510’ TD: 14,645’ 9-5/8” Window @ 9,955’ MD HOWCO EZSV permanent BP @ 14,510’ Clean-out to 14,198’ on 7/27/17 1 2 DV Collar @ 6,822’ HK-1 Top of Liner 9,689’ HK-4 G-3 G-5 G-4 4 3 HK-3 HK-2 Casing leak 2,473 – 2,514 MD PERFORATION DETAIL Zone Top (MD)Btm (MD) Top (TVD) Btm (TVD) Feet SPF Date G-3 13,091' 13,120' 9,157' 9,177' 29' 5 5/10/2015 G-4 13,190' 13,207' 9,225' 9,237' 17' 5 5/10/2015 G-5 13,354' 13,364' 9,338' 9,345' 10' 5 5/10/2015 G-5 13,440' 13,450' 9,398' 9,405' 10' 5 5/10/2015 HK-1 13,622' 13,664' 9,525’ 9,555’ 42’ 5 06/30/17 HK-1 13,632' 13,688' 9,532' 9,572' 56 8 10/13/1984 HK-2 13,696' 13,848' 9,577' 9,683' 152' 5 06/30/17 HK-3 13,885' 13,995' 9,708' 9,784' 110' 5 06/30/17 HK-3 13,985' 14,000' 9,777' 9810 15 8 4/27/1981 HK-3 14,006' 14,033' 9,792' 9,810' 27' 5 06/30/17 HK-3 14,015' 14,036' 9,798' 9,812' 21 8 4/27/1981 HK-4 14,052' 14,066' 9,823' 9,832' 14 8 4/27/1981 - ±12,875’ ±14,200’ ±9,010’ ±9,925’ - - Future Jewelry Details No Depth (MD)Depth (TVD)ID OD Item 1 44’ 44’ Hanger 2 ±400’ ±400’ SSSV 3 ±12,825’ ±8,977’ -- Packer 4 ±12,925’ ±9,044’ Mule Shoe Updated by TDF: 12/17/2024 PROPOSED McArthur River Field, TBU Well: D-16RD PTD: 180-110 API: 50-733-20183-01 As Completed: FUTURE FISH Depth (MD) Depth (TVD) Item 14,198’ 9,923’ Milled / pushed Baker FB-1 7” x 4” injection packer with tail pipe and X- nipple (~50’ length) OPEN HOLE / CEMENT DETAIL 13-3/8"17-1/2" hole: Pumped 2000sxs class G 15.3ppg lead followed by 400sxs class G tail cement.Saw cement to surface. 9-5/8" 12-1/4" hole TD'd at 11,608' MD, but left fish with top at 10,579’ in D-16 parentbore (1969). Ran 9-5/8” casing to 10,295’ MD Primary job pumped 700 + 300sxs of Class G. Assuming 30% washout, and 1.1 cu ft. / sxs, ToC = 7600’ MD Stage 2 through DV collar at 6822' MD: Pumped 1000 + 300sxs class G . Assuming 30% washout, and 1.1 cu ft. / sxs, ToC = 3,300’ MD 7-5/8” scab Scab liner run 4/22/15 to remediate casing leak at ~2500’. Pumped 155bbls 12.5ppg lead cement, followed by 20bbls 15.8ppg tail cement.Saw cement back to surface. 7" 8-1/2" hole: Liner hanger issues, so didn’t pump traditional job. Perf’d just above landing collar at 14,553’ MD. Set cement retainer at 9758’ MD. Pumped 1235sxs class G 15.6ppg cement. Circ’d cement off top liner afterwards. Cement mill out run found ToC at 9020’ MD inside 9-5/8”. 5/9/15 CBL show's ToC at ToL (9,689’ MD) Dolly Varden Platform D-16RD Current 12/16/2024 Valve, Wing, SSV, WKM-M, 3 1/8 5M FE, w/ air operator, EE trim 13 3/8'’ 9 5/8'’ 3 ½’’ 7 5/8'’ Dolly Varden D-16 13 3/8 X 9 5/8 X 7 5/8 X 3 1/2 Tubing hanger, FMC-TC-ESP, 11 X 3 ½ NS-CT lift and susp, 300-4 seal pocket, w/ 3'’ Type H BPV profile, 4- 3/8 CCL, Alloy material Valve, lower master, WKM-M, 3 1/8 5M FE, HWO, T-24 Valve, wing, WKM-M, 2 1/16 5M FE, HWO, T-24 Valve, swab, WKM-M, 3 1/8 5M FE, HWO, T-24 BHTA, Bowen, 3 1/8 5M FE X 3'’ Bowen Quick Union Casing head, CIW-WF, 13 5/8 3M X 13 3/8 casing thread bottom, w/ 2- 2 1/16 5M EFO Multibowl wellhead assy, Cactus MBS-2 13 5/8 3M x 11 5M, w/ 4- 2 1/16 5M SSO, prepped for 7 5/8 mandrel hanger, and tubing hanger, 9 5/8 HPS bottom Dolly Varden Platform D-16RD Proposed 12/16/2024 Valve, Wing, SSV, WKM-M, 3 1/8 5M FE, w/ air operator, EE trim Valve, Master, WKM-M, 4 1/16 5M FE, HWO, EE trim Valve, Upper master, WKM-M, 4 1/16 5M FE, HWO, EE trim Valve, Swab, WKM-M 4 1/16 5M FE, HWO, EE trim Tubing hanger, Cactus-EN- CCL, 13 x 4 ½ EUE 8rd lift and susp x w 6 ¼ od ext neck, 4'’ type H BPV profile, DD-NL material 13 3/8'’ 9 5/8'’ 3 ½’’ 7 5/8'’ Dolly Varden D-16 13 3/8 X 9 5/8 X 7 5/8 X 3 1/2 Casing head, CIW-WF, 13 5/8 3M X 13 3/8 casing thread bottom, w/ 2- 2 1/16 5M EFO Multibowl wellhead assy, Cactus MBS-2 13 5/8 3M x 11 5M, w/ 4- 2 1/16 5M SSO, prepped for 7 5/8 mandrel hanger, and tubing hanger, 9 5/8 HPS bottom BHTA, Bowen, 4 1/16 5M FE x 7' quick union top Dolly Varden Platform BOP Stack Shaffer SL 13 5/8 5M 2 7/8-5.5 variables Blinds 2.00' Riser 13 5/8 5M FE X 13 5/8 5M FE Spacer spool 13 5/8 5M FE X 11 5M 4.54' 2.83' Choke and Kill valves 2 1/16 5M Mud Cross 3 1/8 5M EFO 4.30'Hydril GK 13 5/8-5000 DSA 3 X 2DSA 3 X 220.40' 1.33' HILCORP ALASKA, LLC Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well: Trading Bay Unit D-16RD (PTD 180-110)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date 2024-1104_No-Flow_TBU_D-16RD_gc Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 11/04/2024 P. I. Supervisor FROM: Guy Cook SUBJECT: No Flow Test Petroleum Inspector TBU D-16RD Hilcorp Alaska LLC. PTD 1801100; Sundry 324-447 11/04/2024: I arrived on site and met with Jon Loomis with Hilcorp. We discussed the well and I looked at the rig-up for the No-Flow test. The rig-up was acceptable and all gauges were found with current calibrations. The well was shut in to start the three- hour test. The well was bled off every hour and the pressures were documented every 15 minutes. The test only lasted two hours due to the well showing no signs of flowing to surface unassisted and immediately dropped to 0 psi when opened to bleed. The following table shows test details: Time Pressures1 Flow Rate2 Remarks (psi) Gas – scf/hr Liquid – gal/hr 09:35 0 / 0.02 / 10 / 173 The well was shut in. 09:50 0 / 0.03 / 10 / 173 10:05 0.01 / 0.03 / 10 / 173 10:20 0.01 / 0.04 / 10 / 173 10:35 0.01 / 0.04 / 10 / 173 0 0 Immediate bleed off. 10:36 0 / 0.02 / 10 / 173 The well was shut in. 10:51 0 / 0.03 / 10 / 173 11:06 0 / 0.03 / 10 / 173 11:21 0.01 / 0.03 / 10 / 173 11:36 0.01 / 0.03 / 10 / 173 0 0 Immediate bleed off. End test 1 Pressures are T/IA/OA/OOA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr I believe this well cannot flow to surface unassisted and meets the requirements to be flowed without the need for a subsurface safety valve. I gave Jon Loomis permission to start flowing the well. Attachments: None 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.11.21 15:20:18 -09'00' 2024-1003_No-Flow_TBU_D-16RD_ae Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 10-4-2024 P. I. Supervisor FROM: Adam Earl SUBJECT: No Flow Test Petroleum Inspector TBU D-16RD Hilcorp Alaska LLC PTD 1801100 10-03-2024: I traveled to Dolly Varden Platform to witness a No-Flow Test after an acid job (stimulation) was performed. The well had been opened to bleed for 48 hours before shutting in for the test. The following table shows test details: Time Pressures1 Flow Rate2 Remarks (psi) Gas – scf/hr Liquid – gal/hr 10:35 0.01 / 0 / 8 Shut in to start 10:50 0.03/ 0.03 / 8 11:05 0.08 / 0.07 / 8 11:20 0.12 / 0.11 / 8 11:35 0.19 / 0.20 / 8 180 none Open to bleed through meter; 180 to 0 scf/h in 10 seconds 11:40 0.01 / 0.03 / 8 11:55 0.06 / 0.06 / 8 12:10 0.14 / 0.13 / 8 12:25 0.19 / 0.20 / 8 12:40 0.27 / 0.26 / 8 500 none Open to bleed through meter; 500 to 0 scf/h in 90 seconds 12:45 0.01 / 0.02 / 8 1:00 0.07 / 0.07 / 8 1:15 0.14 / 0.14 / 8 1:30 0.18 / 0.19 / 8 1:45 0.22 / 0.23 / 8 450 none Open to bleed through meter; 450 to 0 scf/h in 80 seconds 1 Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr It appeared to me to pass as per State guidelines. Attachments: Test Equipment Certifications 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.11.15 10:26:39 -09'00' 2024-1003_No-Flow_TBU_D-16RD_ae Page 2 of 2 No-Flow Test – TBU D-16RD (PTD 1801100) Photos by AOGCC Inspector A. Earl 10/3/2024 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov November 15, 2024 Mr. Dan Marlowe Operations Manager – CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification Trading Bay Unit D-16RD PTD 1801100 Dear Mr. Marlowe: On October 3, 2024, an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit D-16RD located on the Dolly Varden Platform in Cook Inlet. The AOGCC Inspector confirmed that the proper test equipment was rigged up prior to the test as outlined in AOGCC Industry Guidance Bulletin 21-001. The test procedure employed was a 1 hour shut in period to monitor pressure build up followed by a short flow period through the test equipment to an open top tank – repeated two additional times. There was no oil observed during the no-flow test. Gas rates measured at the surface were below the allowed 900 scf per hour during all flow rate checks. Trading Bay Unit D-16RD may be produced without a subsurface safety valve as confirmed by the AOGCC Inspector at the conclusion the test. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Trading Bay Unit D-16RD demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no-flow test. Please retain a copy of this letter on the Dolly Varden Platform. Sincerely, James B. Regg Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors James B. Regg Digitally signed by James B. Regg Date: 2024.11.15 12:29:54 -09'00' 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 14,645 feet 14,510 feet true vertical 10,267 feet N/A feet Effective Depth measured 14,198 feet N/A feet true vertical 9,923 feet N/A feet Perforation depth Measured depth 13,091 - 14,066 feet True Vertical depth 9,157 - 9,832 feet 3-1/2" 9.2 / L-80 8,979 (MD) 6,455 (TVD) Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5 / L-80 12,615 (MD) 8,838 (TVD) Packers and SSSV (type, measured and true vertical depth) N/A & N/A 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: Hemlock Oil, Middle Kenai G Oil 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: 86 324-447 Sr Pet Eng: 7,020psi Sr Pet Geo: Sr Res Eng: WINJ WAG 12 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 39 BBLS Safe Acid, Final Pressure 2,000psi / 48 BBLS 15% HCl, Final Pressure 1200psi / 46 BBLS 15% HCl, Final pressure1400 psi 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 13,091 - 14,066 100 Size 215 7623 32 155106 13-3/8" 9-5/8" 8,160psi 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 180-110 50-733-20183-01-00 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: ADL0017579 McArthur River Field / Hemlock Oil, Middle Kenai G Oil Trading Bay Unit D-16RD Plugs Junk measured Length measured TVD Production Liner 9,955 9,692 4,955 Casing Structural 7,096 6,923 7" 9,955 9,692 14,644 10,265 2,554 Conductor Surface Intermediate 3,090psi 4,790psi 3,090psi 5,750psi 6,890psi 2,554 2,347 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 8:59 am, Nov 12, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.11.08 16:09:48 - 09'00' Dan Marlowe (1267) Updated by JLL: 05/22/23 SCHEMATIC McArthur River Field, TBU Well: D-16RD PTD: 180-110 API: 50-733-20183-01 As Completed: 05/15/23 CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8" 61 K-55 Seal Lock 12.515 Surf 2,554' 9-5/8" 40 N-80 Butt 8.835 Surf 5,514' 43.5 N-80 Butt 8.775 5,514' 8,060' 47 N-80 Butt 8.681 8,060' 9,955' 7-5/8 29.7 L-80 SLIJ-II 6.875 Surf 9,692 7" 29 N-80 Butt 6.184 9,689' 14,644' Tubing Detail 3-1/2 9.2 L-80 Supermax 2.992 Surf 8,979 2-7/8 6.5 L-80 IBT 2.441 8,979 12,615 PERFORATION DETAIL Zone Top (MD)Btm (MD) Top (TVD) Btm (TVD) Feet SPF Date G-3 13,091' 13,120' 9,157' 9,177' 29' 5 5/10/2015 G-4 13,190' 13,207' 9,225' 9,237' 17' 5 5/10/2015 G-5 13,354' 13,364' 9,338' 9,345' 10' 5 5/10/2015 G-5 13,440' 13,450' 9,398' 9,405' 10' 5 5/10/2015 HK-1 13,622' 13,664' 9,525 9,555 42 5 06/30/17 HK-1 13,632' 13,688' 9,532' 9,572' 56 8 10/13/1984 HK-2 13,696' 13,848' 9,577' 9,683' 152' 5 06/30/17 HK-3 13,885' 13,995' 9,708' 9,784' 110' 5 06/30/17 HK-3 13,985' 14,000' 9,777' 9810 15 8 4/27/1981 HK-3 14,006' 14,033' 9,792' 9,810' 27' 5 06/30/17 HK-3 14,015' 14,036' 9,798' 9,812' 21 8 4/27/1981 HK-4 14,052' 14,066' 9,823' 9,832' 14 8 4/27/1981 PBTD: 14,510 TD: 14,645 9-5/8 Window @ 9,955 MD HOWCOEZSV permanent BP @ 14,510 Clean-out to 14,198 on 7/27/17 1 DV Collar @ 6,822 HK-1 Top of Liner 9,689 HK-4 G-3 G-5 G-4 HK-3 HK-2 Casing leak 2,473 2,514 MD Jewelry Details No Depth (MD)Depth (TVD)ID OD Item 44 44 Hanger 1 12,615 8,838 -- 4.000 Bolt-on Discharge 12,616 8,839 -- 4.000 Pump (4) 400 Series, 110 Stage SF2700, 7/8" Inconel Shaft, N015 Housing, 1:3 AR, TS3, HTEM 12,703 8,896 4.000 Gas Separator/Intake, 400 Series, H2X, SS, Inconel Shaft, Durahard 12,709 8,900 4.000 Upper/Lower Tandem Seals - 400 Series, BPBSL 12,725 8,910 4.560 Motor (2) 456 Series, FMS2LT & FMS2UT 12,782 8,948 4.560 Centerlizer / Anode OPEN HOLE / CEMENT DETAIL 13-3/8"17-1/2" hole: Pumped 2000sxs class G 15.3ppg lead followed by 400sxs class G tail cement.Saw cement to surface. 9-5/8" 12-1/4" hole TD'd at 11,608' MD, but left fish with top at 10,579 in D-16 parentbore (1969). Ran 9-5/8 casing to 10,295 MD Primary job pumped 700 + 300sxs of Class G. Assuming 30% washout, and 1.1 cu ft. / sxs, ToC = 7600 MD Stage 2 through DV collar at 6822' MD: Pumped 1000 + 300sxs class G . Assuming 30% washout, and 1.1 cu ft. / sxs, ToC = 3,300 MD 7-5/8 scab Scab liner run 4/22/15 to remediate casing leak at ~2500. Pumped 155bbls 12.5ppg lead cement, followed by 20bbls 15.8ppg tail cement.Saw cement back to surface. 7" 8-1/2" hole: Liner hanger issues, so didnt pump traditional job. Perfd just above landing collar at 14,553 MD. Set cement retainer at 9758 MD. Pumped 1235sxs class G 15.6ppg cement. Circd cement off top liner afterwards. Cement mill out run found ToC at 9020 MD inside 9-5/8. 5/9/15 CBL show's ToC at ToL (9,689 MD) Updated by JLL: 05/22/23 SCHEMATIC McArthur River Field, TBU Well: D-16RD PTD: 180-110 API: 50-733-20183-01 As Completed: 05/15/23 GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 2,241 2,125 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 2 4,705 3,656 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 3 5,917 4,458 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 4 6,730 4,971 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 5 7,478 5,457 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 6 8,224 5,946 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 7 8,968 6,447 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 FISH Depth (MD) Depth (TVD) Item 14,198 9,923 Milled / pushed Baker FB-1 7 x 4 injection packer with tail pipe and X- nipple (~50 length) Well Name:MRF D-16RD API #:50733201830100 Field:McArthur River Field Start Date:8/14/2024 Permit #:180110 Sundry #:324-447 End Date:11/4/2024 8/14/2024 9/22/2024 10/3/2024 10/23/2024 11/4/2024 Well Operations Summary State inspector Adam Earl witnessed No Flow test. Verval approval PASS. PTW and PJSM. PT lines 250/2000psi. Pump 290 BBLS FIW to fluid pack the well via IA. Swap to 15% HCL, and pumped 46 BBLs. Swap to FIW and pumped 54 BBLs. Close in IA. Start squeezing 60 BBls @ .5 BPM, Keeping intake pressure under 5,000 and discharge pressure under 5,200. Close in well. Blow down pump and R/D. Turnover to production. PJSM. RU lines for triplex pump. P-test to 250/2,000 psi - good. Fill well with 133 bbl FIW (tubing on vacuum). Bullhead FIW down tubing for injection test - pump 9 bbl, SD at 2,000 psi. Spot 39 bbl Safe Acid down tubing and bullhead out the end of tubing into Pressure tested surface line to 250/3000 psi. Fluid pack well with 62 bbl of FIW taking returns via IA. Close IA, inject 6 bbl of FIW, keeping ESP discharge pressure under 5000psi. Surface treating pressure at 1000psi Open IA, circ in 48 bbl of 15% HCl, pump 52 bbl of FIW. Close IA, bullhead 48bbl of FIW to displace acid below ESP. Pump in cycles to keep ESP intake pressure below 5000psi. 0.5bpm with max treating pressures at surface of 1200psi. Soak / monitor well for 4 hrs. Production start up ESP. Guy Cook witnessed no-flow test. Verbal PASS. Daily Operations: Page 1 of 1 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: ___________________ 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 14,645 N/A Casing Collapse Structural Conductor Surface 1,540psi Intermediate 3,090psi Production 4,790psi Liner 7,020psi 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 Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 8/15/2024 14,644'4,955' 3-1/2" & 2-7/8" 10,265' N/A & N/A N/A & N/A 9,692' Perforation Depth MD (ft): 9,955' 13,091 - 14,066 9,692' 7" 9,157 - 9,832 6,923'7-5/8" 13-3/8" 9-5/8"9,955' 2,554' MD 5,750psi 3,090psi2,347' 7,096' 2,554' Length Size Proposed Pools: L-80 TVD Burst 8,979 & 12,615 6,890psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017579 180-110 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20183-01-00 Hilcorp Alaska, LLC Trading Bay Unit D-16RD AOGCC USE ONLY 8,160psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY McArthur River Hemlock Oil / Middle Kenai G Oil Same 10,267 14,198 9,923 2,305psi 14,510 No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 12:56 pm, Aug 01, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.08.01 12:04:23 - 08'00' Dan Marlowe (1267) CDW 08/01/2024 DSR-8/12/24A.Dewhurst 05AUG24 BJM 8/12/24 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.08.12 16:41:49 -08'00'08/12/24 RBDMS JSB 081324 Acid Well: Dolly Varden D-16RD Well Name:D-16RD API Number:50-733-20183-01-00 Current Status:ESP Oil Producer Leg:B-1 (SE) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:180-110 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Maximum Expected BHP:3,287 psi @ 9,823’ TVD 7/11/24 Static BHP Max. Potential Surface Pressure: 2305 psi Using 0.1 psi/ft Brief Well Summary Dolly Varden D-16RD is a G-zone / Hemlock oil producer. It has been a steady producer at ~500bfpd since it’s current ESP was installed in August of 2020. After a recent production outage at Dolly, the well showed signs of poor inflow (<150bfpd). It is possible that packed in scale is to blame. The goal of this project is to remediate downhole damage and return the well to full production Pertinent wellbore information: - May-2023 RWO o Cleanout to 13,671’ MD (middle HK-2) o Ran current ESP - 6/7/23: No Flow Test (PASS) - December-2020: ESP dies, live GLV’s installed and well produced on GL - 2017 RWO o Removed GL completion and install ESP o Milled 1050’ pushing old packer into rathole - 5/5/15: RWO to convert from long term SI injector to producer o Found hole in 9-5/8” casing, Installed and cemented 7-5/8” scab liner back to surface o MIT-IA to 1500psi passed against production packer set at 12,877’ MD o Caliper log ran, and shows 7” to be in good condition Acid Stimulation Procedure 1. RU pump and treating lines 2. Pressure test all to 250psi low and 2000psi high (pump limitation = 2000psi) 3. Pump Mutual solvent/Xylene pre flush if required 4. Pump acid pill (5-15% concentration HCL, or Oilsafe AR-Synthetic acid) to stimulate perforations 5. Displace pill and spot across perfs with FIW keeping treating pressure <2000psi during displacement 6. RD pumping equipment 7. Let acid soak (duration per OE) 8. Return well to production 9. Conduct NFT within 10 days of stable production Attachments: 1. Current Wellbore Schematic (no changes) Updated by JLL: 05/22/23 SCHEMATIC McArthur River Field, TBU Well: D-16RD PTD: 180-110 API: 50-733-20183-01 As Completed: 05/15/23 CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8" 61 K-55 Seal Lock 12.515 Surf 2,554' 9-5/8" 40 N-80 Butt 8.835 Surf 5,514' 43.5 N-80 Butt 8.775 5,514' 8,060' 47 N-80 Butt 8.681 8,060' 9,955' 7-5/8” 29.7 L-80 SLIJ-II 6.875 Surf 9,692’ 7" 29 N-80 Butt 6.184 9,689' 14,644' Tubing Detail 3-1/2” 9.2 L-80 Supermax 2.992” Surf 8,979’ 2-7/8” 6.5 L-80 IBT 2.441 8,979’ 12,615’ PERFORATION DETAIL Zone Top (MD)Btm (MD) Top (TVD) Btm (TVD) Feet SPF Date G-3 13,091' 13,120' 9,157' 9,177' 29' 5 5/10/2015 G-4 13,190' 13,207' 9,225' 9,237' 17' 5 5/10/2015 G-5 13,354' 13,364' 9,338' 9,345' 10' 5 5/10/2015 G-5 13,440' 13,450' 9,398' 9,405' 10' 5 5/10/2015 HK-1 13,622' 13,664' 9,525’ 9,555’ 42’ 5 06/30/17 HK-1 13,632' 13,688' 9,532' 9,572' 56 8 10/13/1984 HK-2 13,696' 13,848' 9,577' 9,683' 152' 5 06/30/17 HK-3 13,885' 13,995' 9,708' 9,784' 110' 5 06/30/17 HK-3 13,985' 14,000' 9,777' 9810 15 8 4/27/1981 HK-3 14,006' 14,033' 9,792' 9,810' 27' 5 06/30/17 HK-3 14,015' 14,036' 9,798' 9,812' 21 8 4/27/1981 HK-4 14,052' 14,066' 9,823' 9,832' 14 8 4/27/1981 PBTD: 14,510’ TD: 14,645’ 9-5/8” Window @ 9,955’ MD HOWCOEZSV permanent BP @ 14,510’ Clean-out to 14,198’ on 7/27/17 1 DV Collar @ 6,822’ HK-1 Top of Liner 9,689’ HK-4 G-3 G-5 G-4 HK-3 HK-2 Casing leak 2,473 – 2,514 MD Jewelry Details No Depth (MD)Depth (TVD)ID OD Item 44’ 44’ Hanger 1 12,615’ 8,838’ -- 4.000 Bolt-on Discharge 12,616’ 8,839’ -- 4.000 Pump (4) 400 Series, 110 Stage SF2700, 7/8" Inconel Shaft, N015 Housing, 1:3 AR, TS3, HTEM 12,703’ 8,896’ 4.000 Gas Separator/Intake, 400 Series, H2X, SS, Inconel Shaft, Durahard 12,709’ 8,900’ 4.000 Upper/Lower Tandem Seals - 400 Series, BPBSL 12,725’ 8,910’ 4.560 Motor (2) 456 Series, FMS2LT & FMS2UT 12,782’ 8,948’ 4.560 Centerlizer / Anode OPEN HOLE / CEMENT DETAIL 13-3/8"17-1/2" hole: Pumped 2000sxs class G 15.3ppg lead followed by 400sxs class G tail cement.Saw cement to surface. 9-5/8" 12-1/4" hole TD'd at 11,608' MD, but left fish with top at 10,579’ in D-16 parentbore (1969). Ran 9-5/8” casing to 10,295’ MD Primary job pumped 700 + 300sxs of Class G. Assuming 30% washout, and 1.1 cu ft. / sxs, ToC = 7600’ MD Stage 2 through DV collar at 6822' MD: Pumped 1000 + 300sxs class G . Assuming 30% washout, and 1.1 cu ft. / sxs, ToC = 3,300’ MD 7-5/8” scab Scab liner run 4/22/15 to remediate casing leak at ~2500’. Pumped 155bbls 12.5ppg lead cement, followed by 20bbls 15.8ppg tail cement.Saw cement back to surface. 7" 8-1/2" hole: Liner hanger issues, so didn’t pump traditional job. Perf’d just above landing collar at 14,553’ MD. Set cement retainer at 9758’ MD. Pumped 1235sxs class G 15.6ppg cement. Circ’d cement off top liner afterwards. Cement mill out run found ToC at 9020’ MD inside 9-5/8”. 5/9/15 CBL show's ToC at ToL (9,689’ MD) Updated by JLL: 05/22/23 SCHEMATIC McArthur River Field, TBU Well: D-16RD PTD: 180-110 API: 50-733-20183-01 As Completed: 05/15/23 GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 2,241’ 2,125’ 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 2 4,705’ 3,656’ 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 3 5,917’ 4,458’ 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 4 6,730’ 4,971’ 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 5 7,478’ 5,457’ 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 6 8,224’ 5,946’ 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 7 8,968’ 6,447’ 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 FISH Depth (MD) Depth (TVD) Item 14,198’ 9,923’ Milled / pushed Baker FB-1 7” x 4” injection packer with tail pipe and X- nipple (~50’ length) 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov November 14, 2023 Mr. Dan Marlowe Operations Manager – CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification Trading Bay Unit D-16RD PTD 1801100 Dear Mr. Marlowe: On June 7, 2023, an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit D-16RD located on the Dolly Varden Platform in Cook Inlet. The AOGCC Inspector confirmed that the proper test equipment was rigged up prior to the test as outlined in AOGCC Industry Guidance Bulletin 10-004. The test procedure employed was a 1 hour shut in period to monitor pressure build up followed by a short flow period through the test equipment to an open top tank – repeated one time. The maximum observed gas flow rate was 1200 scf/hr that declined to 0 scf/hr within 1.5 minutes during both flow monitoring periods. There was no liquid flow to surface during the no-flow test. Trading Bay Unit D-16RD may be produced without a subsurface safety valve as confirmed by the AOGCC Inspector at the conclusion the test. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Trading Bay Unit D-16RD demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no-flow test. Please retain a copy of this letter on the Steelhead Platform. Sincerely, James B. Regg Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors James B. Regg Digitally signed by James B. Regg Date: 2023.11.14 14:28:00 -09'00' 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: Install ESP/GL 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 14,645 feet 14,510 feet true vertical 10,267 feet N/A feet Effective Depth measured 14,198 feet N/A feet true vertical 9,923 feet N/A feet Perforation depth Measured depth 13,091 - 14,066 feet True Vertical depth 9,157 - 9,832 feet 3-1/2" 9.2 / L-80 8,979 (MD) 6,455 (TVD) Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5 / L-80 12,615 (MD) 8,838 (TVD) Packers and SSSV (type, measured and true vertical depth) N/A & N/A 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: Hemlock Oil, Middle kenai G Oil 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: 3,090psi 4,790psi 3,090psi 5,750psi 6,890psi 2,554 2,347 Burst Collapse 1,540psi measured TVD Production Liner 9,955 9,692 4,955 Casing Structural 7,096 6,923 7" 9,955 9,692 14,644 10,265 2,554 Conductor Surface Intermediate 13-3/8" 9-5/8" 8,160psi 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 180-110 50-733-20183-01-00 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: ADL0017579 McArthur River Field / Hemlock Oil, Middle Kenai G Oil Trading Bay Unit D-16RD Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 28 Gas-Mcf MD N/A 555 Size 233 15217 0 10742 107 323-195 Sr Pet Eng: 7,020psi Sr Pet Geo: Sr Res Eng: WINJ WAG 7 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 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 11:32 am, Jun 29, 2023 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.06.29 10:05:39 - 08'00' Dan Marlowe (1267) Updated by JLL: 05/22/23 SCHEMATIC McArthur River Field, TBU Well: D-16RD PTD: 180-110 API: 50-733-20183-01 As Completed: 05/15/23 CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8" 61 K-55 Seal Lock 12.515 Surf 2,554' 9-5/8" 40 N-80 Butt 8.835 Surf 5,514' 43.5 N-80 Butt 8.775 5,514' 8,060' 47 N-80 Butt 8.681 8,060' 9,955' 7-5/8 29.7 L-80 SLIJ-II 6.875 Surf 9,692 7" 29 N-80 Butt 6.184 9,689' 14,644' Tubing Detail 3-1/2 9.2 L-80 Supermax 2.992 Surf 8,979 2-7/8 6.5 L-80 IBT 2.441 8,979 12,615 PERFORATION DETAIL Zone Top (MD)Btm (MD) Top (TVD) Btm (TVD) Feet SPF Date G-3 13,091' 13,120' 9,157' 9,177' 29' 5 5/10/2015 G-4 13,190' 13,207' 9,225' 9,237' 17' 5 5/10/2015 G-5 13,354' 13,364' 9,338' 9,345' 10' 5 5/10/2015 G-5 13,440' 13,450' 9,398' 9,405' 10' 5 5/10/2015 HK-1 13,622' 13,664' 9,525 9,555 42 5 06/30/17 HK-1 13,632' 13,688' 9,532' 9,572' 56 8 10/13/1984 HK-2 13,696' 13,848' 9,577' 9,683' 152' 5 06/30/17 HK-3 13,885' 13,995' 9,708' 9,784' 110' 5 06/30/17 HK-3 13,985' 14,000' 9,777' 9810 15 8 4/27/1981 HK-3 14,006' 14,033' 9,792' 9,810' 27' 5 06/30/17 HK-3 14,015' 14,036' 9,798' 9,812' 21 8 4/27/1981 HK-4 14,052' 14,066' 9,823' 9,832' 14 8 4/27/1981 PBTD: 14,510 TD: 14,645 9-5/8 Window @ 9,955 MD HOWCOEZSV permanent BP @ 14,510 Clean-out to 14,198 on 7/27/17 1 DV Collar @ 6,822 HK-1 Top of Liner 9,689 HK-4 G-3 G-5 G-4 HK-3 HK-2 Casing leak 2,473 2,514 MD Jewelry Details No Depth (MD)Depth (TVD)ID OD Item 44 44 Hanger 1 12,615 8,838 -- 4.000 Bolt-on Discharge 12,616 8,839 -- 4.000 Pump (4) 400 Series, 110 Stage SF2700, 7/8" Inconel Shaft, N015 Housing, 1:3 AR, TS3, HTEM 12,703 8,896 4.000 Gas Separator/Intake, 400 Series, H2X, SS, Inconel Shaft, Durahard 12,709 8,900 4.000 Upper/Lower Tandem Seals - 400 Series, BPBSL 12,725 8,910 4.560 Motor (2) 456 Series, FMS2LT & FMS2UT 12,782 8,948 4.560 Centerlizer / Anode OPEN HOLE / CEMENT DETAIL 13-3/8"17-1/2" hole: Pumped 2000sxs class G 15.3ppg lead followed by 400sxs class G tail cement.Saw cement to surface. 9-5/8" 12-1/4" hole TD'd at 11,608' MD, but left fish with top at 10,579 in D-16 parentbore (1969). Ran 9-5/8 casing to 10,295 MD Primary job pumped 700 + 300sxs of Class G. Assuming 30% washout, and 1.1 cu ft. / sxs, ToC = 7600 MD Stage 2 through DV collar at 6822' MD: Pumped 1000 + 300sxs class G . Assuming 30% washout, and 1.1 cu ft. / sxs, ToC = 3,300 MD 7-5/8 scab Scab liner run 4/22/15 to remediate casing leak at ~2500. Pumped 155bbls 12.5ppg lead cement, followed by 20bbls 15.8ppg tail cement.Saw cement back to surface. 7" 8-1/2" hole: Liner hanger issues, so didnt pump traditional job. Perfd just above landing collar at 14,553 MD. Set cement retainer at 9758 MD. Pumped 1235sxs class G 15.6ppg cement. Circd cement off top liner afterwards. Cement mill out run found ToC at 9020 MD inside 9-5/8. 5/9/15 CBL show's ToC at ToL (9,689 MD) Updated by JLL: 05/22/23 SCHEMATIC McArthur River Field, TBU Well: D-16RD PTD: 180-110 API: 50-733-20183-01 As Completed: 05/15/23 GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 2,241 2,125 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 2 4,705 3,656 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 3 5,917 4,458 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 4 6,730 4,971 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 5 7,478 5,457 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 6 8,224 5,946 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 7 8,968 6,447 2.867 3-1/2" Weatherford SFO-1, DK-2 Latch, 1" Dummy Valve (OD 4.125"x5.313")DUMMY 05/15/23 FISH Depth (MD) Depth (TVD) Item 14,198 9,923 Milled / pushed Baker FB-1 7 x 4 injection packer with tail pipe and X- nipple (~50 length) Rig Start Date End Date HAK 404 4/26/23 6/7/23 04/26/2023 - Wednesday PTSM, layout well center for spotting rig. Arrange decks, swap stairs up t/ crane pedestal. Prep for hand rail modification to accommodate beam package. R/U circulating lines to wellhead taking returns to production. Circulate well to well clean tank, took 62 bbls to fill well. Continue circulate to production till clean FIW returns. Unload boat from Tyonek, set beam package, carriage DW, "A" leg, pin mast. Unload rest of misc. rig eq. Send boat back to Tyonek for load #2. Install walkways, stage doghouse, stage equipment on deck, pin lift cylinders, prep derrick to stand. Lay out fast line, deadline & lower load line. Install shaft from motor to draw works. Second boat from Tyonek arrived at Dolly, work tide, offloading storage Conex boxes and spot same. Prep to move Conex boxes on East Deck. 04/27/2023 - Thursday Continue rig up & stand mast, string up drill line & tuggers unload boat & spot Eq. Check well, on vac. Fill well w/ FIW, took 21bbls to fill. Cont . circulate 60 bbls all clean. Shut in well 1 hour, check on vac. Install BPV, N/D tree, prep wellhead, cap control lines, lock open vent valve & SSSV, install Blanking sub. N/U BOPE, stack up riser, mud cross, double gate, annular & circulating head. Start torquing flange bolts. Finish torquing BOP bolts, prep to raise derrick, raise derrick and scope up same. Install rig floor and pin same, put on Guy wires, slide drillers shack in place, install 1" control lines and choke and kill lines, moving equipment on deck. Change top rams to 2-7/8 x 5' VBR'S, check koomey bottle prechrage, moving equipment on deck, center BOPE with floor, clear west pipe rack, install stair on off driller side, continue to rig up. 04/28/2023 - Friday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name D-16RD 50-733-20183-01 180-110 04/29/2023 - Saturday Continue R/U Re-route accumulator lines, spot Eq. M/U 3 1/2" TJ. Work on shell test w/3 1/2" TJ using variable pipe rams, good. Attempt to test w/ annular unable to get stable High test. AOGCC inspector Brian Bixby arrive to witness test. Start BOPE Test, test w/ 3 1/2" test joint 250/2500, all good except Failure on annular. R/U n/d circulating head & annular to C/O element in Annular & N/U same. Make up 3.5 test joint, fluid pack BOPE. Test 13-5/8 5m Annular to 250 low and 2500 psi high test made with water (good test). Lay out test joint, nipple up circulating head, hang beaver slide and secure same, hang Summit sheeve and Elephant trunk in derrick. Install stairs at beaver slide, rig up floor handling tools, make up landing joint. Cont. R/U slide & access. Pull BPV, m/u landing joint find obstruction on xo upset for hanger, source out options, & mobe out. R/U pull LD pins. Pull hanger free @ 105k, cont. pulling staging up t/ 182k working every 10k increase, w/no movement. R/U circulating lines. Pump staging up t/3.5BPM, 1840psi, work string up t/ 182k with no movement. Pump Lube pill around while cont. working pipe with no luck. Work pipe parking & let set with 185 on string. Offload E-line unit and rig up E-Line. Make up 1-11/16 tool string, head, swivel, 10 ft wt. bar, CCL with 5ft rod with 1 strand 80 grain shot. RIH with same to packer, log shot on depth f/ 407 ft. to 412 ft. Across packer, Pick up to 180 k on string, fired shot, no movement on pipe. Pooh with E-line. Rig Start Date End Date HAK 404 4/26/23 6/7/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name D-16RD 50-733-20183-01 180-110 05/01/2023 - Monday C/o handing eq. RIH p/u 6 joints of 3-1/2" wk string. PUW=21k. Tag @ 371'. Began rotating pipe w/tongs, dressed off TOF and latched fish. Pickup on fish to 180k no movement. Began jar hits @ 100k with P/u to 160k. After jarring for 3.5hrs fish came free, string weight @ 114k. Pulled 10' with drag up to 50k over string weight then weight fell off to neutral wt. S/d to inspected derrick-all good. POOH, Standing back wk. string and drill collars. L/d Jars, overshot and vent packer. All cable, control line and clamps was recovered Note: packer sheared off the upper and lower slip lugs and not at the shear pins. Will send packer to Tripoint for teardown inspection. Pumped 20bbls of FIW down Csg. C/o handling eq. Pulled cable and dual encapsulated control line to spoolers and began POOH. L/d 3-1/2" ESP completion f/9180' t/ 4950'. Change out motor lead spool, repair motor lead spooler. Continue pooh laying down 3.-1/2 supermax 9.2#, L-80 tbg and gas lift, spooling up motor lead and flat Pac. F/ 4,950' T/ 3,641'. 04/30/2023 - Sunday M/U 5ft rod with 2 strand 80 grain shot. RIH with same to packer, log shot on depth f/ 407 ft. to 412 ft. Across packer, Pick up to 180 k on string, fired shot, no movement on pipe. Pooh with E-line. C/O e-line tools. M/U tool string for 2" RCT cutter, surface test anchor good. M/U cutter. Rig lay out 3 1/2" PH-6 wk string & BHSA, prep handling tools. RIH w/ 2" RCT, correlate to place cutter @382', set anchors good cycle to fire cutter, no indication on surface cutter fired. Attempt to POOH unable to retract anchors, troubleshoot unable to retract, pick up fire jars, string was free to go down unable to pick up. Move down hole trying pickups with no luck, t/~850' cycle tool again gained ability to pickup but had a little drag. POOH to surface string, hung up dropped down picked up lost string. Mobe out tool string, continue prep handling tools for fishing string. Re-head/ M/U tool string. RIH t/ 513' clean for drift run w/2 1/8' max od, but not reading CCL, POOH. Diagnose & repair communication issue, mobe out new double pin sub for tool string. Dry check fire good, p/u 2" RCT tool string, correlate to place cutter @382' Fire cutter, POOH cutter had fired. R/D out of way. P/U on string pull up t/ 80k wk pipe not free. P/U 2.5" Jet cutter, RIH spot cutter at 383 ft ELM, fired cutter, had good indication of cut. Pooh, cutter had fired. Rig down E-line. Pick up hanger to floor. P/up 18k, terminate lines at hanger, L/d hanger, pull first joint, unable to feed cable through sheeve in derrick, cut and lay out flat pack cable one control line did not part, slipping thru clamps. Found bad spot in cable at 324 ft. Laid out total of (9) joints of 3-1/2, 9.2#, L-80 supermax tbg, FMC hanger with hanger up, (1) Halliburton TRSV- model NE with X-lock profile, with (2) pups and (1) cut piece 24.05, recovered 11 cannon clamps and 12 SS bands. Change out handling tools and make up fishing tools (Cut lip guide, 5-3/4 series overshot bowl, Overshot extension, top sub, oil jar, (6) 4-3/4 drill collars, acc jar, x/o sub. total BHA 222.19) Rig Start Date End Date HAK 404 4/26/23 6/7/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name D-16RD 50-733-20183-01 180-110 05/02/2023 - Tuesday Continued POOH w3-1/2" ESP/GL completion f/3641' t/discharge head. Filling hole @ 5bph w/8.5ppg FIW. Note Tubing is in good condition, cable had several rub marks with the armor opened. R/u summit tools, B/o discharge head and recovered lost WL toolstring. L/d ESP assembly, found first pump frozen, 2nd and 3rd pump turned free, motor oil was clean. No solids recovered from assembly. All clamps accounted for. Filled hole @ 5bph w/FIW. R/d Summit eq. Cleaned & clear rig floor & cleaning pipe rack, prep to pick up cleanout assembly, work boat, lay out 3-1/2 12.95 ph6 pipe on deck. Wait on crane operator to come from Steelhead. Rig up handling tools, load beaver slide with pipe RIH picking up 3- 1/2 PH 6 P-110 work string to 744 ft. work boat arrived at 0300 hrs. Pooh racking back in derrick. Rig up floor to pick up BHA, offloading boat with work string and Misc equipment. Making up BHA, 5-7/8" Bit, boot basket, boot basket, Bit sub, string magnet, Bumper jar, Oil jar, 6 each, 4-3/4 drill collars, X/over sub = 221.80 ft. 05/03/2023 - Wednesday RIH with cleanout assembly. P/u 3-1/2" wk string t/ 945'. Finished offloaded workboat, 3-1/2" wk string and misc rig eq. Continued RIH w/c/o assembly. P/u 3-1/2 wk string and tally as ran f/945' t/3100' filling hole @ 5bph w/FIW. Continued RIH w/c/o assembly. P/u 3-1/2 wk string and tally as ran f/3100', pipe displacing well @ 3200'. Passed thru liner top without any problems. Continue in hole picking up 3-1/2 PH 6 12.95 P110 work string tagging bridge at 11,210 dpm. Broke thru bridge, pick up to work pipe, pick up at 120k, able to work pipe down to 11,232 working back up to 11,200 ft. Pick up wt. at 90k. Rig up power swivel, make up TIW and X/over sub. Test TIW to 250 low & 2500 psi high. Make connection, install circ head and secure canister in same. Attempt to circulate long way, pipe plug off pressure up to 3500 max pressure, surge pipe several times attempting to get circulation, attempt to reverse circulate. Able to reverse circulate at 3.4 bpm at 700 psi. Rig Start Date End Date HAK 404 4/26/23 6/7/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name D-16RD 50-733-20183-01 180-110 05/04/2023 - Thursday Reversed circulated 2x BU @ 3.4bpm/700psi, returns @ 1st BU heavy scale. 2nd BU returns light scale. Est parameters, (no pump) PUW=98k, SOW=60k. Pump on @ 3.5bpm/700psi PUW=88k, SOW=56k. Rot Wt=68K @ 80rpm's, free tq 6,000ft/lbs. Ream/Wash thru bridge @ 11,200'. Full returns light to med scale across the shakers. Sent lube pill to help with high torque. Continued rev circ 3.5bpm/650psi. Ream/Washing down f/11,210' t/11,711' with no issues. Torque decreased to 4,500ft/lbs when lube pill hit bit. Full returns light to med scale across the shakers. Continued rev circ 3.5bpm/650psi. Ream/Washing down f/11,711' t/ 12,536' tagging up at 12,536 ft. SO, wt. 61k P/up wt. 84k ROT wt., 72k, 2-4 WOB, pumping at 3.4 bpm at 700 psi 4 to 5k torque. Made connection at 12,536 ft put pump online, pipe plugged, work pump pressure back and forth, unplug pipe reamed down from 12,536 to 12,599' pumping at 3.4 bpm at 700 psi, 5-6k torque, 6-8 WOB, 90 P/U wt., 61k S/O wt. 75k ROT WT. Wash and ream from ,12599 ft. 12,630 with 8-10 wob, continue to wash and ream f/ 12,630 t/ 12,754 ft. running 5/6 wob at 80 / 100 rpm 4-5k torque pumping at 3.4 bpm at 700 psi circulate at each connection due to getting heavy amount scale back at shaker. Wash and ream from 12,751 to 12,845 ft. pumping at 3.4 bpm at 630 psi, 80/100 rpm with 4/5 WOB p/up wt. 90 k rot wt. 75k, s/o wt. 61k. Circulate after each connection due to heavy scale back shakers. Had GAS Alarm muster for same, check out area on rig floor, got all clear. Attempt to break circ, circulating head leaking. Changed out rubber in same. Wash and ream f/ 12,784 ft. to 12,904 ft pumping 3.5 bpm at 650 psi 80/100 rpm 4/5k torque pu wt. 90k rot wt. 75k s/o wt. 61k. 05/05/2023 - Friday PUW=90k, SOW=61k, Rt Wt=75k. Wash/ream f/12,904' t/13,091' rev circ @ 3.5bpm/650psi 2-5k WOB, Tq 4-5000 ft/lbs. ROP slowed down f/13,053' t/13,091'. Returns 1/1 with light to med scale across the shaker Parked @ 13,091 (above G perfs) and circulated 2x BU and returns remain 1/1 with light scale across shaker. Work boat arrived, off load cutting boxes Continue washing f/13,091 t/13,405', rev circ @ 3.5bpm/650psi 2-5k WOB, Tq 4-5000 ft/lbs. 80-100RPM's, returns 1/1 with scale and sand across shakers. Note hard drilling f/13,292' t/13,374. Wash, reaming F/ 13,405' to 13,623 ft/ (from 13,405 to 13,539 running 0/4 weight on bit, (from 13,539 ft. to 13,623 ft. running 5/10k WOB, pumping at 3.5 bpm at 650 psi, 80 rpm 5/6k TQ 98k p/up wt., 64k s/o wt., 79k ROT wt. Wash and ream f/ 13,623 ft. to 13,654 ft/ with 5 /7 k WOB, at 80 rpm, torque at 6k pumping at 3.5 bpm at 650 psi. P/up wt. at 98k ROT wt. at 79k S/O wt. at 64k. Wash and ream from 13,654' to 13,671 ft. with 5/7 k wob, at 80 rpm, 6 to 7500 torque, pumping at 3. 5 bpm in reverse pump, pressure decreased f/ 650 to 450, psi loses increased to 50 bph, pump pressure increased to 1100 psi. Shut down pump unplug tubing. Attempt to wash and ream pumping in reverse after tagging bottom, tubing pressure increased f/ 450psi to 900 psi. Shut down unplug tubing, attempt to wash and ream pumping in reverse at 2.5 bpm pump pressure increased from 360 to 600 psi, unplug tubing, loses still at 50 bph torque at 7000 to 7500k. Finish Reverse circulating two tbg volumes while mixing salt pill. Mixing 50 bbl. salt pill, pooh 2 stds above perfs @ 13,091' to pump salt pill and let heal while testing BOPS. Rig Start Date End Date HAK 404 4/26/23 6/7/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name D-16RD 50-733-20183-01 180-110 05/06/2023 - Saturday Continue mixing size salt pill. R/d and hung power swivel back in derrick. R/u handling tools and POOH racking back wk. string f/13,671' t/12,847', 244' above top perf. R/u circulating eq. attempt to circ down tbg, pumped 2bbls and tbg plugged off. Lined up and rev circulated 4bpm/500psi with no issues. Circ 1.5x tbg volume until returns were clean. S/d pump. Lined up to circ down tbg and pumped 50bbl salt pill and spot at perfs. M/u landing jt with test plug, M/u double pin xo to test plug and wk string. Land test plug. B/o and L/d landing jt. M/u BOP Testing eq. Shell test Bop's 250- 2500psi good test. Test BOPE per sundry as following: Annular 250-2500psi, Rams 250-2500psi, Valves 250-2500psi. Performed Koomey Drawdown test. All good. No test on Gas Detection (Bi-Wkly). Tested with 2-7/8". N/d 3-1/2" test joint. Witness waived by Jim Regg on Thu 5/4/2023 11:01 AM. L/d BOPE Test eq. M/u 3-1/2" Handling tools and prep to RIH w/ wk. string t/13,658'. M/u circ eq. rev circ @ 3bpm and and catch returns after 55bbls away. R/d circ eq. R/u power swivel and circulating head. Reverse circulates at 3.5 bpm at 550 psi, with 1/2 BPH loss rate. Rotating at 80 rpm at 6k torque. Attempt to wash and ream @ 13,671' with 4k wob torque at 7500k, pump pressure increased to 1000 psi. Shut down pump, pressure bleed off same, pump down tbg and unplug same. Reverse 2-1/2 tbg volumes. Break out single from power swivel and lay out same. Rig down power swivel. Rig up tongs, pull rubber from circulating head. Pooh, racking back work string depth from 13,671 ft. Depth at rpt time 7,248 ft. 05/07/2023 - Sunday Continue POOH standing back 3 1/2" wk string f/5900' pumping double displacement w/FIW every 15jts out. R/u handling eq for BHA, L/d drill collars, jars, string magnet, boot baskets and bit. No metal cuttings on magnet, baskets packed full with scale. Cones were intact on Bit but were metal markings on the side indicating possible casing damage @ 13,671' in the Hk-1 lower perf. Cleaned and cleared rig floor. Serviced rig, slip and cut dill Line. Assist crane arranging deck. R/u handling tools. Tally and M/u JS3 7" Test Packer and XO to wk. string. RIH w/7" test packer on 3 1/2" wk. string from derrick to 12,838'. Set the JS3 test packer for 23 to 29# csg at 12,838 ft. with 18k dn on same. S/O WT AT 82k, PICK UP WT 122 K. Fill hole with 31 bbl, fluid pack surface lines, pressure up to 2300 psi on 7" x 7-5/8 csg with 4-1/2 bbl. 8.3 drill water, found leak on standpipe, bleed off pressure and tighten union. Pressure up to 2350 on 7" x 7-5/8 csg pressure, bleed off 21 psi every 5 minutes. Open well unseat packer, pick up 5 ft and reset packer and began retest at report time. Rig Start Date End Date HAK 404 4/26/23 6/7/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name D-16RD 50-733-20183-01 180-110 05/08/2023 - Monday Set Test Pkr @ 12,833'. Pumped 4.5bbls and pressured up on IA to 2424psi and held for 30mins. Initial =2424psi, 15mins=2411psi, 30mins=2405psi. Good MIT-IA. Bled off pressure and released packer. Let elements relax. POOH standing back wk. string f/12,833' t/11,800', PUW=132 and started increasing with packer dragging 20-30k over. Set slips, R/u circ eq. rev circ 1.5x BU @ 3.5bpm/500psi. Returned was scale and 2 big chucks of rubber. S/d pump and R/d circ eq. Continued POOH standing wk. string f/11,800' t/10,307', PUW=110k with no drag. Pumped dbl displacement w/FIW every 7 stands out. Received orders from town not to pursue additional cleanout trip. Continued POOH L/d wk string f/10,307' to 7" test packer (Note no rubbers on test packer ( 3) Elements OD 5. 75, width 2 x 2. 50" 1 x 2. 30 Thickness, . 825"). Clean packer and Break X/over on packer and lay out same. Make up mule shoe and RIH with 34 std work string to 2112 ft. Fill hole with 38 bbl. 8.3 water circulate surface to surface volume 88 bbls. Pooh laying down 3- 1/2 work string. Rig down circulating head and rig up shooting flange and rig up E-line. 05/09/2023 - Tuesday Continue R/u AK E-line, M/u tools, stab on Lubricator and PT to 250-2500psi. M/u 5.43" GR/JB. RIH to 5000' made p/u to season new line could not go down, p/u t/3000' then able to go down, cont RIH 200fpm set down 20' inside 7" liner @ 9,689'. P/u 100' could not go down, p/u 1000' still no go down. Attempted to pump down @ 1.5bpm/1500psi no luck going down. S/d pump. P/u to 3000' started free falling and came on with the rig pump @ 1.5bpm/1500. WL set down @ 3600'. Worked line but no luck going down. S/d pump, POOH Junk basket full of pipe dope and lube. Did recover 2 pieces of packer element. Wire damaged at rope socket when L/d toolstring. Wt bars arrived from beach, Re head WL tie 7:3. M/u 2x wt bar and rollers and 5.43" GR/JB. RIH with 5.43 gauge ring and junk basket setting down at 10,050 ft. ELM, pump tools down at .85 bpm at 1300 psi finial pressure to 10,450 ft ELM pooh with Junk basket recovered, scale and lube. Received orders to Rig down E-line and lubricator. Nipple up circulating head. Change out tongs, dress out handling equipment for 2-7/8. Make up a 5-5/8 over shot, x/over, x/over. = 5.84 ft. & TIH picking up 2-7/8, 6.4# L-80 IBT production tbg, depth at rpt time 1,732 ft. 05/10/2023 - Wednesday Continue RIH w/5-5/8" OS w/cut lip guide (as muleshoe), p/u 2-7/8" IBT completion Tbg f/1732' t/3623'. Total of 115jts. Fill hole 5bph w/FIW. C/o handling eq to 3-1/2", M/u XO sub 2-7/8" IBT x 3-1/2" Supermax. Continue RIH p/u 3-1/2" Supermax completion Tbg f/3623' t/ 12,741'. Fill hole with 18 bbls FIW, reverse circ at 3.9 bpm at 560 psi, got back small amount of scale. Started to get foam back at shaker, continue to circulate until clear fluid back at shaker, shut down pump well static. Rig down circulating hose and subs. Pooh laying out 4 jts of 3-1/2 super max tbg. 11,247 depth at rpt time. Rig Start Date End Date HAK 404 4/26/23 6/7/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name D-16RD 50-733-20183-01 180-110 05/11/2023 - Thursday POOH standing back 3-1/2 completion tbg in derrick f/ 11,247 ft. to 3623 ft, P/up wt. 76k s/o wt. 50k. Change out 3-1/2 handling equipment to 2-7/8 handling equipment, continue POOH racking back 2-7/8 tbg f/ 3623 to 352 ft. Lay down 11 joints of 2-7/8 IBT tbg lay out over shot. Clean and clear rig floor. Held PJSM & JSA. Rig up Summit equipment. Pick up and make up a 4.560" centralized Anode, Gauge (2) 456 series motors, 400 series lower tandem seal, 400 series upper tandem seal, 400 series gas Separator/ intake, (4) 400 series 110 stage pumps, and x/overs, total assembly 170.40. Held PJSM with Summit and rig crew, held cable cutting drill. RIH with ESP assembly on 2-7/8 IBT 6.5# L- 80 TBG installing clamps each joint & installing GLM's as per design. Depth at rpt Time 2300 ft. 05/12/2023 - Friday Continued RIH f/2300' w/ESP/GL completion, p/u 2-7/8" IBT tbg stands t/3508'. Clamping every joint and testing cable every 1000'. Filling hole 5bph w/FIW. C/o handling eq. to 3-1/2". RIH w/ESP/GL f/3508', p/u 3-1/2" stands f/derrick, clamping every other joint and testing cable every 1000'. Filling hole 5bph w/FIW. Stopped @ 6492', swap spool, Summit performed cable splice. Check reading showing imbalanced phase, began troubleshooting, cut splice check and still showing imbalance. Discuss with town and decision made to POOH. Prep to POOH. Changed reel, hang drip tube on summit sheave, connection motor cable to spooler. PJSM with summit and rig crew pooh with ESP completion f/ 6,462 ft to 3,508 ft. Change out handling equipment f/ 3-1/2" to 2-7/8" clear off floor. Pooh with 2-7/8 6.5 IBT tbg laying out GLM removing clamps f/ 3,508 ft. to pumps. Pooh lay down ESP assembly. 05/13/2023 - Saturday L/d ESP assembly, troubleshot cable, checking good, no issues with pothead and motor seal. Could possibly be a bad wire connection in the Motor. Filled hole with FIW, calculated static fluid losses @ 11bph.Cleaned and clear floor. R/u BOP Testing eq. performed good shell test. Tested BOPE as per sundry. Annular 250-2500psi, Rams 250-2500psi, Valves 250- 2500psi. Tested gas detection and performed Koomey drawdown. Tested w/2 7/8" and 3 1/2" TJ. Test all good. R/d testing eq. R/u summit eq. held PJSM for p/u ESP assembly. P/u and service New Summit ESP assembly. Make up a 4.560" centralized Anode, Gauge, (2) 456 series motors, 400 series lower tandem seal, 400 series upper tandem seal, 400 series gas Separator/ intake, (4) 400 series 110 stage pumps, and x/overs, total assembly 170.40. + single & x/o 201.84. Clear rig floor. Tip in hole with 2-7/8 6.5 IBT L-80 production tbg installing clamps each joint on 2-7/8 tbg testing cable every 1000 ft. to 3,535 ft dpm. Change 2-7/8 handling tools to 3-1/2". Continue in hole with ESP assembly running 3-1/2 9.3 L-80, super max tbg out of derrick depth at rpt time 3800' ft. Rig Start Date End Date HAK 404 4/26/23 6/7/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name D-16RD 50-733-20183-01 180-110 R/d Summit eq. R/d tongs, elevators and bails. Cleared rig floor of tools and xo's. Removed beaver slide. R/d pits and circulating hoses and put away. Dive boat arrived, suspended crane ops with divers in the water. Loosen guy wires and prep to scope down derrick. Soft broke BOP stack. Disconnect and rolled up choke/kill and koomey lines. Dive boat sailed, disco work boat arrived. Began crane ops. Load summit eq and extra GLM and tubing on boat and hauled to beach. R/d stairs, rig floor and drillers shack. Take down guy lines. Scope down derrick to half mast. N/d BOP's and riser. Service hanger N/u production tree. Raise mast to 1/2 mast unstring drillers side and off drillers side tuggers, Man rider, & drill line, cut off 72 ft of drilling line, lower mast onto headache rack, install, choke and SSV & flow line on tree. Pull BPV install two way check, test neck seals and void to 5000 psi for 15 minutes (good test). Test tree to 250 low and 3500 psi hi, pull two way check. Turn well over to production, tie up lines in derrick. Rigging down misc. rig equipment and circ equipment. Finish securing lines on derrick disconnect drive line, raising cylinder, draw works from carrier, secure racking mat to beam. Boat arrived at rig, off load totes. Tide changed, waiting on tide to work boat, roll up koomey hoses, cleaning out pits. Loading boat with derrick and draw works, and carrier. 06/07/2023 - Wednesday No Flow Test witnessed by AOGCC inspector Kam St. John. PASS. D-16 returned to production. 05/14/2023 - Sunday Continue RIH per Tally f/3800 w/ESP-GL completion f/Derrick, Testing cable every 1000' and clamping 3-1/2" every other joint. Filling hole @ 5bph w/FIW. Swapped reels, Summit made cable splice, cable check good. PJSM with crews, walked thru bare pipe shut in drill. Continue RIH w/ESP-GL completion, p/u 3-1/2" supermax tbg f/derrick, cable splice @ 6,570' (15' in on joint 197). Test cable every 1000' and clamping every other joint. Fill 5bph w/FIW to 12,733 ft. Make up landing joint to hanger w/BPV installed, make up hanger to completion string, make up motor lead to penetrator and test same, make up injection lines. Land hanger with 62k down wt. with end of ESP assembly at 12,780 ft. Total clamp count on completion, Motor clamps (32), 2-7/8 CC (106), 3-1/2 CCs (146) splice clamps (2). Make final check on motor lead (good). Run in lock downs, back out landing joint and lay out same. 05/15/2023 - Monday 2023-0607_No-Flow_TBU_D-16RD_ksj Page 1 of 4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 6/8/2023 P. I. Supervisor FROM: Kam StJohn SUBJECT: No Flow Test Petroleum Inspector Trading Bay Unit D-16RD Hilcorp Alaska LLC PTD 1801100 6/07/2023: Arrived on the Trading Bay Unit Dolly Varden Platform at 7:30 am for witness of no-flow test on Well D-16RD. I met with Garret Mclean (Hilcorp operator) to discuss the options for testing and visually inspected the rig up. They used 1-inch hose and piping for the flow path, a digital gauge, and low-flow meter for the test and meter for test. I verified the gauge and meter calibrations from the certification documents – copies attached. Well D-16RD was shut in to initiate the test. The following table shows test details: Time Pressures1 Flow Rate2 Remarks (psi) Gas – scf/hr Liquid – gal/hr 08:06 0.02/0.01/15 - - Shut in well 08:21 0.13/0.03/15 - - 08:36 0.19/0.22/15 - - 08:51 0.26/0.3/15 - - 09:06 0.33/0.38/15 1200 0 Open well to flow meter 09:08 0/0.05/15 0 0 0 SCFH in 1.5 minutes 09:22 0/0.06/15 0 0 Shut in well 09:37 0.12/0.16/15 - - 09:52 0.21/0.24/15 - - 10:07 0.29/0.33/15 - - 10:22 0.35/0.41/15 1200 0 Open well to flow meter 10:24 0/0.07/15 0 0 0 SCFH in 1.5 minutes 10:30 0/0.05/15 0 0 End test 1 Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr No liquid flow to surface occurred. The test was ended early based on the clear indication that the well cannot sustain unassisted flow to surface. Attachments: 2 Pictures; Test Equipment Calibration Records Inspector allowed well to be placed back online without a SSSV based on passing no-flow test after confirming with Inspection Supervisor -- J. Regg 2023-0607_No-Flow_TBU_D-16RD_ksj Page 2 of 4 No-Flow Test – TBU D-16RD (PTD 1801100) Photos by AOGCC Inspector K. StJohn 6/7/2023 2023-0607_No-Flow_TBU_D-16RD_ksj Page 3 of 4 Digital Pressure Gauge Calibration 2023-0607_No-Flow_TBU_D-16RD_ksj Page 4 of 4 Lo-Flow Meter Calibration 1 Regg, James B (OGC) From:Regg, James B (OGC) Sent:Wednesday, May 24, 2023 1:17 PM To:Ryan Rupert Cc:Dallas Grube; Juanita Lovett; Dan Marlowe; Zach Rolph; McLellan, Bryan J (OGC) Subject:RE: D-16RD No Flow Test (PTD#180-110) Thank you for the discussion this afternoon. The no ‐flow test can be delayed until late next week. We will reconnect next week to see how the draw down is progressing. TBU D‐16RD can continue to flow until the no‐flow test is scheduled. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907‐793‐1236 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Wednesday, May 24, 2023 8:47 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Dallas Grube <dgrube@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com>; Zach Rolph <zrolph@hilcorp.com> Subject: RE: D‐16RD No Flow Test (PTD#180‐110) Just wondered if yall had a chance to look at this? We still have 500psi to go before reaching our target FBHP. We will stick with a Friday 5/26 no‐flow test date unless we hear otherwise. Please advise. Thanks, Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Monday, May 22, 2023 12:13 PM To: 'bryan.mclellan@alaska.gov' <bryan.mclellan@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: D‐16RD No Flow Test (PTD#180‐110) Bryan‐ 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. 2 We successfully completed our liner cleanout and ESP swap on D‐16RD last week. We were unable to shoot any proposed adperfs, but did encounter heavy scale/fill deposits on our liner cleanout. Given all that, I believe the well still needs a no flow test conducted. In the sundry I specified after 10 days of production. We brought the well online 5/16/23, so 10 days would be this Friday 5/26/23. However, in the last 6 days, the well ended up being shut in for 3 days due to what looks like a pump plugging event. It was successfully brought back online 5/20/23. The FBHP still has an additional ~700psi to go before we reach our target FBHP. We are currently ~65% drawn‐down towards our target FBHP. All workover fluids have been recovered at this point. Would the agency prefer to hold the F 5/26 target date? Or target not more than 7 days after target FBHP has been reached? (not to go past 6/15/23 regardless of drawdown). We can accommodate ither, just let us know. Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) 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. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________TRADING BAY UNIT D-16RD JBR 06/01/2023 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 Tested all gas alarms and PVT's, tested with 3 1/2" test joint. Annular failed and was changed out. I did not witness the retest. Precharge bottles = 7 @ 1000psi, 8 @ 1025psi, 3 @ 1050psi. Test Results TEST DATA Rig Rep:Chris Hannevold / Ed COperator:Hilcorp Alaska, LLC Operator Rep:Harold Soule / Ed Hooter Rig Owner/Rig No.:Hilcorp 404 PTD#:1801100 DATE:4/29/2023 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopBDB230430182622 Inspector Brian Bixby Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 10 MASP: 1916 Sundry No: 323-195 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P 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"F #1 Rams 1 2 7/8x5 1/2 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 P HCR Valves 2 2 1/16 P Kill Line Valves 2 2 1/16 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3025 Pressure After Closure P1925 200 PSI Attained P22 Full Pressure Attained P84 Blind Switch Covers:PYES Bottle precharge P Nitgn Btls# &psi (avg)P4@2050 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P25 #1 Rams P6 #2 Rams P6 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2 9 9 9 9 9999 9 9 F Annular failed and was changed out. I did not witness the retest. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 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): 14,645 N/A Casing Collapse Structural Conductor Surface 1,540psi Intermediate 3,090psi Production 4,790psi Liner 7,020psi 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 10,267 9,923 1916 MDLength Size 6,890psi6,9239,692 8,160psi14,644 10,265 2,347 7,096 Perforation Depth MD (ft): 9,692 7"4,955 7-5/8" 9-5/8"9,955 13-3/8"2,554 2,554 9,955 Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 14,51014,198 5,750psi 3,090psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017579 180-110 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20183-01-00 Hilcorp Alaska, LLC Trading Bay Unit D-16RD Hemlock Oil, Middle Kenai G Oil Same CO 228A 4/14/2023 Dual ESP Pkr & TRSV - Model NE 408 (MD) 408 (TVD) & 350 (MD) 350 (TVD) 13,091 - 14,066 9,157 - 9,832 3-1/2" Other: Replace ESP/GL w/ Clean out 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior writt en approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Operations Manager Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 9.2# / L-80 9,436 Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov BJM 4/6/23 Provide 48 hrs notice for AOGCC opportunity to witness 7-5/8" casing pressure test to 2300 psi X BOP test to 2500 psi. DSR-3/31/23SFD 4/6/2023 10-404 GCW 04/07/23 04/07/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.04.07 09:34:35 -08'00' RBDMS JSB 040723 ESP Swap RWO Well: D-16RD Well Name:D-16RD API Number:50-733-20183-01-00 Current Status:ESP/Gas Lift Producer Leg:Leg B-1 (SE corner) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:180-110 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Karson Kozub (907) 570-1801 (c) Maximum Expected BHP:2,851 psi @ 9,350’ TVD Offset BHP in D-09RD (1/16/23) Max. Potential Surface Pressure: 1916 psi Using 0.1 psi/ft Brief Well Summary D-16RD is a Hemlock/G-zone Producer that was converted to an ESP from a gas-lift completion in 2017. Perfs were added, and a large ESP was run in anticipation of high fluid rates. The large ESP could only fit in the 7- 5/8” liner (not the 7”). The ESP ran for 3.5years. Towards the end, a noticeable decline in PI was observed. Given this a fill clean out of the perfs is planned. The well has had poor performance on gas lift since the ESP died given the decreased drawdown. The goal of this project is to pull and replace the ESP, while cleaning out any 7” liner obstructions. Select perfs will also be added while the completion is out of the hole. Pertinent wellbore information: - December-2020: ESP dies, live GLV’s installed and well produced on GL - 2017 RWO to remove GL completion and install ESP o Milled 375’ to base G-sands o Milled 675’ across H-sands pushing old packer into rathole - 5/5/15: RWO to convert from long term SI injector to producer o Found hole in 9-5/8” casing o Installed and cemented 7-5/8” scab liner back to surface o MIT on of 7-5/8” casing, and 7” casing against an RTTS set at 13,015’ MD passed to 2500psi o MIT-IA to 1500psi passed against production packer set at 12,877’ MD o Caliper log ran, and shows 7” to be in good condition ESP Swap RWO Well: D-16RD Procedure: 1. MIRU HAK 404. 2. Circulate well to production: a. Work over fluid will be filtered inlet water (8.4ppg) b. Ensure KWF initially fills IA and tubing, and flushes all hydrocarbons to surface, or back into formation 3. Set BPV/TWC, ND tree, NU BOP a. Notify AOGCC 48 hours in advance for witness b. Test to 250psi Low /2,500psi High / 2,500psi Annular c. BOP’s will be closed as needed to circulate the well 4. Pull BPV/TWC 5. Monitor well to ensure it is static 6. Unseat hanger and packer and POOH with 3-1/2” tubing string and ESP/GL completion 7. PU 3-1/2” workstring 8. MU 7” liner cleanout assembly 9. RIH and mill/cleanout 7” liner a. Target depth = 14,200’ MD b. Historic wear from 12,875 – 12,925 and 13,450 – 13,600’ MD c. Use caution in these areas 10. POOH and lay down cleanout BHA 11. PU 7” test packer 12. RIH on work string, and set test packer at ±12,840’ MD (±8990’ TVD) 13. MIT 7-5/8” x 7” casing to 2300psi (charted) 14. POOH and lay down test packer 15. RU EL and perforate infill G/H zone sands from 12,875’ – 14,200’ MD (9,010’ - 9,925’ TVD) 16. RD EL 17. PU, RIH with GL/ESP completion 18. Land ESP with the bottom of the assembly at ±12,900’ 19. Set BPV/TWC, ND BOP, NU tree and test, pull BPV/TWC 20. Turn well over to production 21. Conduct No flow Test per AOGCC regulations a. Produce well for ~10 days b. Shut down ESP and leave well lined up to production and monitor until fluid level is stable. c. Notify AOGCC to witness test (48hr notice to AOGCC) d. Bleed well (TBG and IA) to 0 psi e. Rig up test equipment (low pressure gauge, flowmeter, etc.) f. Let well bleed through flow meter until inspector arrives but do not exceed 48 hrs. of total bleed time g. Begin No Flow Test per AOGCC regs / guidance document ESP Swap RWO Well: D-16RD Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Current Wellhead Diagram 4. Proposed Wellhead Diagram (Same) 5. BOP Drawing 6. Fluid/Flow Diagrams 7. RWO Sundry Change Form Updated by JLL: 03/28/23 SCHEMATIC McArthur River Field, TBU Well: D-16RD PTD: 180-110 API: 50-733-20183-01 As Completed:07/04/2017 CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8" 61 K-55 Seal Lock 12.515 Surf 2,554' 9-5/8" 40 N-80 Butt 8.835 Surf 5,514' 43.5 N-80 Butt 8.775 5,514' 8,060' 47 N-80 Butt 8.681 8,060' 9,955' 7-5/8” 29.7 L-80 SLIJ-II 6.875 Surf 9,692’ 7" 29 N-80 Butt 6.184 9,689' 14,644' Tubing Detail 3-1/2” 9.2 L-80 Supermax 2.992” Surf 9,436’ PBTD: 14,510’ TD: 14,645’ 9-5/8” Window @ 9,955’ MD HOWCO EZSV permanent BP @ 14,510’ Clean-out to 14,198’ on 7/27/17 1 DV Collar @ 6,822’ HK-1 Top of Liner 9,689’ HK-4 G-3 G-5 G-4 X 4 3 2 HK-3 HK-2 Casing leak 2,473 – 2,514 MD Jewelry Details No Depth (MD)Depth (TVD)ID OD Item 44’ 44’ Hanger 1 350' 350’ 2.813 5.200 Halliburton TRSV – Model NE w/X-lock profile 2 408’ 408’ 2.992 6.670 D&L Oil Tool Dual ESP Hydraulic Set Packer w/ Weatherford WFT vent valve 3 9,398’ 6,732’ 2.810 3.750 X Nipple 4 9,436’ 6,757’ N/A 5.130 Bolt on Discharge Head 9,437’ 6,757’ N/A 5.380” Pump - 66 Stg Summit SJ10000 (x3) 9,509’ 6,804’ N/A 5.130” Seals (x2) – Summit BPBSL 9,527’ 6,816’ N/A 5.620” 500HP Motors (x2) – Summit KMS2 (1000HP/3600V/165.5A) 9,594’ 6,859’ N/A 5.620” Gauge (Zenith) / Centralizer / Anode PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Feet SPF Date G-3 13,091' 13,120' 9,157' 9,177' 29' 5 5/10/2015 G-4 13,190' 13,207' 9,225' 9,237' 17' 5 5/10/2015 G-5 13,354' 13,364' 9,338' 9,345' 10' 5 5/10/2015 G-5 13,440' 13,450' 9,398' 9,405' 10' 5 5/10/2015 HK-1 13,622' 13,664' 9,525’ 9,555’ 42’ 5 06/30/17 HK-1 13,632' 13,688' 9,532' 9,572' 56 8 10/13/1984 HK-2 13,696' 13,848' 9,577' 9,683' 152' 5 06/30/17 HK-3 13,885' 13,995' 9,708' 9,784' 110' 5 06/30/17 HK-3 13,985' 14,000' 9,777' 9810 15 8 4/27/1981 HK-3 14,006' 14,033' 9,792' 9,810' 27' 5 06/30/17 HK-3 14,015' 14,036' 9,798' 9,812' 21 8 4/27/1981 HK-4 14,052' 14,066' 9,823' 9,832' 14 8 4/27/1981 OPEN HOLE / CEMENT DETAIL 13-3/8"17-1/2" hole: Pumped 2000sxs class G 15.3ppg lead followed by 400sxs class G tail cement.Saw cement to surface. 9-5/8" 12-1/4" hole TD'd at 11,608' MD, but left fish with top at 10,579’ in D-16 parentbore (1969). Ran 9-5/8” casing to 10,295’ MD Primary job pumped 700 + 300sxs of Class G. Assuming 30% washout, and 1.1 cu ft. / sxs, ToC = 7600’ MD Stage 2 through DV collar at 6822' MD: Pumped 1000 + 300sxs class G . Assuming 30% washout, and 1.1 cu ft. / sxs, ToC = 3,300’ MD 7-5/8” scab Scab liner run 4/22/15 to remediate casing leak at ~2500’. Pumped 155bbls 12.5ppg lead cement, followed by 20bbls 15.8ppg tail cement.Saw cement back to surface. 7" 8-1/2" hole: Liner hanger issues, so didn’t pump traditional job. Perf’d just above landing collar at 14,553’ MD. Set cement retainer at 9758’ MD. Pumped 1235sxs class G 15.6ppg cement. Circ’d cement off top liner afterwards. Cement mill out run found ToC at 9020’ MD inside 9-5/8”. 5/9/15 CBL show's ToC at ToL (9,689’ MD) Updated by JLL: 03/28/23 SCHEMATIC McArthur River Field, TBU Well: D-16RD PTD: 180-110 API: 50-733-20183-01 As Completed:07/04/2017 GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 2,332’ 2,194’ 2.992 SFO-2 w/ RD-2 DG’s and RK latches 20 DOME 1233 1/6/2021 2 3,615’ 3,014’ 2.992 SFO-2 w/ RD-2 DG’s and RK latches DUMMY 3 4,630’ 3,610’ 2.992 SFO-2 w/ RD-2 DG’s and RK latches 20 DOME 1195 1/6/2021 4 5,577’ 4,231’ 2.992 SFO-2 w/ RD-2 DG’s and RK latches DUMMY 5 6,390’ 4,752’ 2.992 SFO-2 w/ RD-2 DG’s and RK latches 20 DOME 1154 1/6/2021 6 7,137’ 5,238’ 2.992 SFO-2 w/ RD-2 DG’s and RK latches DUMMY 7 7,952’ 5,760’ 2.992 SFO-2 w/ RD-2 DG’s and RK latches 20 DOME 1114 1/6/2021 8 8,635’ 6,225’ 2.992 SFO-2 w/ RD-2 DG’s and RK latches 20 DOME 1072 1/6/2021 9 9,351' 6,701’ 2.992 SFO-2 w/ RD-2 DG’s and RK latches 20 ORIFICE 1/6/2021 FISH Depth (MD) Depth (TVD) Item 14,198’ 9,923’ Milled / pushed Baker FB-1 7” x 4” injection packer with tail pipe and X- nipple (~50’ length) Updated by JLL: 04/03/23 PROPOSED McArthur River Field, TBU Well: D-16RD PTD: 180-110 API: 50-733-20183-01 As Completed: FUTURE CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8" 61 K-55 Seal Lock 12.515 Surf 2,554' 9-5/8" 40 N-80 Butt 8.835 Surf 5,514' 43.5 N-80 Butt 8.775 5,514' 8,060' 47 N-80 Butt 8.681 8,060' 9,955' 7-5/8” 29.7 L-80 SLIJ-II 6.875 Surf 9,692’ 7" 29 N-80 Butt 6.184 9,689' 14,644' Tubing Detail 3-1/2” 9.2 L-80 Supermax 2.992” Surf ±9,500’ 2-7/8” ±9,500’ ±12,900 PERFORATION DETAIL Zone Top (MD)Btm (MD) Top (TVD) Btm (TVD) Feet SPF Date G/H Zone ±12,875’ ±14,200’ ±9,010’ ±9,925’ ±1,325’ Future G-3 13,091' 13,120' 9,157' 9,177' 29' 5 5/10/2015 G-4 13,190' 13,207' 9,225' 9,237' 17' 5 5/10/2015 G-5 13,354' 13,364' 9,338' 9,345' 10' 5 5/10/2015 G-5 13,440' 13,450' 9,398' 9,405' 10' 5 5/10/2015 HK-1 13,622' 13,664' 9,525’ 9,555’ 42’ 5 06/30/17 HK-1 13,632' 13,688' 9,532' 9,572' 56 8 10/13/1984 HK-2 13,696' 13,848' 9,577' 9,683' 152' 5 06/30/17 HK-3 13,885' 13,995' 9,708' 9,784' 110' 5 06/30/17 HK-3 13,985' 14,000' 9,777' 9810 15 8 4/27/1981 HK-3 14,006' 14,033' 9,792' 9,810' 27' 5 06/30/17 HK-3 14,015' 14,036' 9,798' 9,812' 21 8 4/27/1981 HK-4 14,052' 14,066' 9,823' 9,832' 14 8 4/27/1981 Jewelry Details No Depth (MD)Depth (TVD)ID OD Item 44’ 44’ Hanger 1 ±12,900 ±9,027’ Btm ESP Assembly PBTD: 14,510’ TD: 14,645’ 9-5/8” Window @ 9,955’ MD HOWCO EZSV permanent BP @ 14,510’ Clean-out to 14,198’ on 7/27/17 1 DV Collar @ 6,822’ HK-1 Top of Liner 9,689’ HK-4 G-3 G-5 G-4 HK-3 HK-2 Casing leak 2,473 – 2,514 MD OPEN HOLE / CEMENT DETAIL 13-3/8"17-1/2" hole: Pumped 2000sxs class G 15.3ppg lead followed by 400sxs class G tail cement.Saw cement to surface. 9-5/8" 12-1/4" hole TD'd at 11,608' MD, but left fish with top at 10,579’ in D-16 parentbore (1969). Ran 9-5/8” casing to 10,295’ MD Primary job pumped 700 + 300sxs of Class G. Assuming 30% washout, and 1.1 cu ft. / sxs, ToC = 7600’ MD Stage 2 through DV collar at 6822' MD: Pumped 1000 + 300sxs class G . Assuming 30% washout, and 1.1 cu ft. / sxs, ToC = 3,300’ MD 7-5/8” scab Scab liner run 4/22/15 to remediate casing leak at ~2500’. Pumped 155bbls 12.5ppg lead cement, followed by 20bbls 15.8ppg tail cement.Saw cement back to surface. 7" 8-1/2" hole: Liner hanger issues, so didn’t pump traditional job. Perf’d just above landing collar at 14,553’ MD. Set cement retainer at 9758’ MD. Pumped 1235sxs class G 15.6ppg cement. Circ’d cement off top liner afterwards. Cement mill out run found ToC at 9020’ MD inside 9-5/8”. 5/9/15 CBL show's ToC at ToL (9,689’ MD) Updated by JLL: 04/03/23 PROPOSED McArthur River Field, TBU Well: D-16RD PTD: 180-110 API: 50-733-20183-01 As Completed: FUTURE GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date TBD TBD GLM’s Future FISH Depth (MD) Depth (TVD) Item 14,198’ 9,923’ Milled / pushed Baker FB-1 7” x 4” injection packer with tail pipe and X- nipple (~50’ length) Updated by JLL: 03/28/23 PROPOSED McArthur River Field, TBU Well: D-16RD PTD: 180-110 API: 50-733-20183-01 As Completed:FUTURE CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8" 61 K-55 Seal Lock 12.515 Surf 2,554' 9-5/8" 40 N-80 Butt 8.835 Surf 5,514' 43.5 N-80 Butt 8.775 5,514' 8,060' 47 N-80 Butt 8.681 8,060' 9,955' 7-5/8” 29.7 L-80 SLIJ-II 6.875 Surf 9,692’ 7" 29 N-80 Butt 6.184 9,689' 14,644' Tubing Detail 3-1/2” 9.2 L-80 Supermax 2.992” Surf ±12,900’ PERFORATION DETAIL Zone Top (MD)Btm (MD) Top (TVD) Btm (TVD) Feet SPF Date G/H Zone ±12,875’ ±14,200’ ±9,010’ ±9,925’ ±1,325’ Future G-3 13,091' 13,120' 9,157' 9,177' 29' 5 5/10/2015 G-4 13,190' 13,207' 9,225' 9,237' 17' 5 5/10/2015 G-5 13,354' 13,364' 9,338' 9,345' 10' 5 5/10/2015 G-5 13,440' 13,450' 9,398' 9,405' 10' 5 5/10/2015 HK-1 13,622' 13,664' 9,525’ 9,555’ 42’ 5 06/30/17 HK-1 13,632' 13,688' 9,532' 9,572' 56 8 10/13/1984 HK-2 13,696' 13,848' 9,577' 9,683' 152' 5 06/30/17 HK-3 13,885' 13,995' 9,708' 9,784' 110' 5 06/30/17 HK-3 13,985' 14,000' 9,777' 9810 15 8 4/27/1981 HK-3 14,006' 14,033' 9,792' 9,810' 27' 5 06/30/17 HK-3 14,015' 14,036' 9,798' 9,812' 21 8 4/27/1981 HK-4 14,052' 14,066' 9,823' 9,832' 14 8 4/27/1981 PBTD: 14,510’ TD: 14,645’ 9-5/8” Window @ 9,955’ MD HOWCO EZSV permanent BP @ 14,510’ Clean-out to 14,198’ on 7/27/17 1 DV Collar @ 6,822’ HK-1 Top of Liner 9,689’ HK-4 G-3 G-5 G-4 HK-3 HK-2 Casing leak 2,473 – 2,514 MD Jewelry Details No Depth (MD)Depth (TVD)ID OD Item 44’ 44’ Hanger 1 ±12,900 ±9,027’ Btm ESP Assembly OPEN HOLE / CEMENT DETAIL 13-3/8"17-1/2" hole: Pumped 2000sxs class G 15.3ppg lead followed by 400sxs class G tail cement.Saw cement to surface. 9-5/8" 12-1/4" hole TD'd at 11,608' MD, but left fish with top at 10,579’ in D-16 parentbore (1969). Ran 9-5/8” casing to 10,295’ MD Primary job pumped 700 + 300sxs of Class G. Assuming 30% washout, and 1.1 cu ft. / sxs, ToC = 7600’ MD Stage 2 through DV collar at 6822' MD: Pumped 1000 + 300sxs class G . Assuming 30% washout, and 1.1 cu ft. / sxs, ToC = 3,300’ MD 7-5/8” scab Scab liner run 4/22/15 to remediate casing leak at ~2500’. Pumped 155bbls 12.5ppg lead cement, followed by 20bbls 15.8ppg tail cement.Saw cement back to surface. 7" 8-1/2" hole: Liner hanger issues, so didn’t pump traditional job. Perf’d just above landing collar at 14,553’ MD. Set cement retainer at 9758’ MD. Pumped 1235sxs class G 15.6ppg cement. Circ’d cement off top liner afterwards. Cement mill out run found ToC at 9020’ MD inside 9-5/8”. 5/9/15 CBL show's ToC at ToL (9,689’ MD) Superseded Updated by JLL: 03/28/23 PROPOSED McArthur River Field, TBU Well: D-16RD PTD: 180-110 API: 50-733-20183-01 As Completed:FUTURE GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date TBD TBD GLM’s Future FISH Depth (MD) Depth (TVD) Item 14,198’ 9,923’ Milled / pushed Baker FB-1 7” x 4” injection packer with tail pipe and X- nipple (~50’ length) Superseded Dolly Varden Platform D-16 Current 08/08/2017 Dolly Varden D-16 13 3/8 X 9 5/8 X 7 5/8 X 3 1/2 Tubing hanger, FMC-TC-ESP, 11 X 3 ½ NS-CT lift and susp, 300-4 seal pocket, w/ 3'’ Type H BPV profile, 4- 3/8 CCL, Alloy material Casing head, CIW-WF, 13 5/8 3M X 13 3/8 casing thread bottom, w/2- 2 1/16 5M EFO Valve, lower master, WKM-M, 3 1/8 5M FE, HWO, T-24 Valve, wing, WKM-M, 2 1/16 5M FE, HWO, T-24 Valve, swab, WKM-M, 3 1/8 5M FE, HWO, T-24 BHTA, Bowen, 3 1/8 5M FE X 3'’ Bowen Quick Union Valve, WKM-M, 3 1/8 5M FE, w/ 15'’ OMNI operator Multibowl wellhead assy, Cactus MBS-2 13 5/8 3M x 11 5M, w/4- 2 1/16 5M SSO, prepped for 7 5/8 mandrel hanger, and tubing hanger, 9 5/8 HPS bottom Valve, WKM-M, 2 1/16 5M FE, HWO, DD Valve, WKM-M, 2 1/16 5M FE, HWO, DD Valve, CIW-F, 2 1/16 3M FE, HWO, AA trim Adapter, FMC-A-5-EC, 11 5M rotating flange x 3 1/8 5M rotating top, 300-4 pocket prep, 2- CCL ports, 3.266 centers Dolly Varden Platform 2020 BOP Stack 01/24/2020 Shaffer SL 13 5/8 5M 2 7/8-5.5 variables Blinds 2.00' Riser 13 5/8 5M FE X 13 5/8 5M FE Spacer spool 13 5/8 5M FE X 11 5M 4.54' 2.83' Choke and Kill valves 2 1/16 5M Mud Cross 3 1/8 5M EFO 4.30'Hydril GK 13 5/8-5000 20.40' 1.33' Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well D-16RD (PTD 180-011)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date • • MEMORANDUM scow = ate of Alaska Alaska Oil and Gas Conservation Commission G> TO: Jim Regg � (�l 6 1z-t1e DATE: 5/2/2018 P. I. Supervisor FROM: Austin McLeod SUBJECT: No Flow Test Bob Noble TBU D-16RD Petroleum Inspector Hilcorp Alaska LLC PTD 180-110 - 4/30/18: Bob Noble and I traveled to the Dolly Varden platform to witness a no flow test on well D-16RD (ESP completion). We met up Lead Op Christy Anderson to discuss the procedure. The well had been shut in and bleeding since Thursday 6 a.m. 4/26/18, while flare work was being done. The tubing and IA were in communication the entirety of the test with a "C" section plumbed to the wing on the tree. Calibrations were current on both the gauge and meter off the tree cap with documentation of the same provided by the operator. I asked the operator of any water flooding or any other means of injecting, and was told the platform has not been flooding or injecting for over a years' time. Verification that the packer vent line and SSSV were open was done prior to ✓ starting the test. The following table shows test details: Time Pressures' Flow Rate2 Remarks (psi) Gas—scf/hr Liquid —gal/hr 11:15 0/0/15 11:30 0.39/0.39/15 - 11:45 0.75/0.75/15 12:00 1.07/1.07/15 12:15 1.42/1.42/15 - 1600 0 - Open to flow meter; 2 min to <900 scf/hr; 41/2 min to zero 12:30 0.38/0.38/15 12:45 0.91/0.91/15 13:00 1.28/1.28/15 - 13:15 1.61/1.61/15 1750 0 Open to flow meter; 2 min to <900 scf/hr; 41/2 min to zero 13:30 .58/.58/15 13:45 1.13/1.13/15 - 14:00 1.39/1.39/15 - 14:15 1.72/1.72/15 - 1800 - 0 Open to flow meter; 2 min to v,, <900 scf/hr; 41/2 min to zero 1 Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr Attachments: Pictures (2); Test Equipment Calibration Certificates ✓ 2018-0430_No-Flow_TBUD-16RD_am.docx Page 1 of 3 • • No Flow Test - TBU D-16RD (PTD 1801100) Photos by AOGCC Inspector A. McLeod 4/20/2018 Armor-Flo' '�.. MODEL SEEDAI !AG ax r x7532 PEU!SSUPE ( wscosm OP '' MAx .. +F TEMPERATURE 5C of OP 4� YAx Y ERDCO, EvAMBTON. 60202 VS.* • yb 15 SCFHx100 , • SCFH Meter(top photo);Digital Pressure Gauge (bottom photo) PSI BAR MPA MediaGaugeTM el ON/UNITY . Erart OFF Backlic n' P-H 2018-0430 No-Flow_TBU D-16RD am.docx Page 2 of 3 .., • • r O N N - v O M co Li Z N• m ., N z V) M TL' ~ F-se c 0 O N n n o d m k S z c Q o in rn v o E s ',J.' W Z a U o tNv M n U •V 3: 0 C O '.e Z N Z O N N N CDP .), N N r7 l0 N Ql rbA m • .1. �o w I N mIno N rzt `� jOi M 0 N U' 0 0 "4V O Y W O N O Oip :4 c C d O h �- (Ni M r U iC ;s, F- N o y u o OO U J r ci40 E U ° y fl. E m OA �O ° 01) AI M U I. = AO aj M r 3 g oa w °qo Q z0I 0 oo U o LI-1 N N U ti o a ria— d d w '0 0 v « m tEiW E md3r� `.O_ U._tl) 10 O c.Q n'c Z h O 11'' mUtit N G NCN._....L.. IOCOi O of N CA Ls•�\7 Y o g N m Z y M y Ii; 1222 , rn Faoo2Eu,wm • 1 2 ti OF 77. ",, I%-'s, THE STAG • Alaska Oil and Gas 4 „ALASKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 F ALASFax: 907.276.7542 www.aogcc.alaska.gov May 2, 2018 Mr. Stan Golis Operations Manager—CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification scow Trading Bay Unit D-16RD PTD 1801100 Dear Mr. Golis: On April 30,2018 Alaska Oil and Gas Conservation Commission(AOGCC)Petroleum Inspectors witnessed a no-flow test of Trading Bay Unit D-16RD located on the Dolly Varden Platform in Cook Inlet. The well is operated by Hilcorp Alaska, LLC (Hilcorp). The AOGCC Inspector confirmed that the proper test equipment—as outlined in AOGCC Industry Guidance Bulletin 10- 004 — was rigged up on Trading Bay Unit D-16RD prior to the test. The well performance was monitored for four hours. Gas flow rates at the end of three separate flow checks preceded by 1- hour pressure build up periods were within the allowable rate limits. There was also no liquid flow to surface during the no-flow test. Trading Bay Unit D-16RD may be produced without a subsurface safety valve. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Trading Bay Unit D-16RD demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the Dolly Varden Platform. Sincerely, ' ' '?1 „� James B. Regg ( I Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors STATE OF ALAKA OIL AND GAS CONSERVATION COMSSION REPORT OF SUNDRY WELL OPERATIONS JUL 2 8 2017 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 A $ clown 0 Performed: Suspend ❑ Perforate 0 Other Stimulate 0 Alter Casing❑ Changprove.Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well❑ Other: GUESP Completion 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development El Exploratory 0 180-110 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service El 6.API Number: Anchorage,AK 99503 50-733-20183-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0017579 Trading Bay Unit D-16RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Hemlock Oil and Middle Kenai G Oil Pools 11.Present Well Condition Summary: Total Depth measured 14,645 feet Plugs measured 14,510&14,600 feet true vertical 10,306 feet Junk measured N/A feet Effective Depth measured 14,198 feet Packer measured 408 feet true vertical 9,923 feet true vertical 408 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,544' 13-3/8" 2,554' 2,347' 3,090 psi 1,540 psi Intermediate 9,955' 9-5/8" 9,955' 7,096' 5,750 psi 3,090 psi Production 9,692' 7-5/8" 9,692' 6,923' 6,890 psi 4,790 psi Liner 4,955' 7" 14,644' 10,265' 8,160 psi 7,020 psi Perforation depth Measured depth 13,091 -14,066 feet 'll1 6 2 i1/ � SCA True Vertical depth 9,157-9,832 feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 9,436(MD) 6,757(TVD) 408(MD) 350(MD) Packers and SSSV(type,measured and true vertical depth) Dual ESP Hyd Pkr 408(TVD) TRSV-Model NE 350(TVD) 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 49 29 577 1116 372 Subsequent to operation: 296 35 3334 111 120 14.Attachments(required per 20 AAc 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas El WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUGD 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: 317-124 Authorized Name: Stan W.GolisContact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowe@hilcorp.com Authorized Signature: 6LL3 Date: 7/ze)/1, Contact Phone: (907)283-1329 '-7 /7 Form 10-404 Revised 4/2017 �� � RBDMS V,A0 - 1 201 r7 Submit Original Only McArthur River Field, TBU n 0 SCHEMATIC Well: D-16RD PTD: 180-110 I{ilcorp Alaska,i.J,r. API: 50-733-20183-01 As Completed: 07/04/2017 CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8" 61 K-55 Seal Lock 12.515 Surf 2,554' 40 N-80 Butt 8.835 Surf 5,514' s 9-5/8" 43.5 N-80 Butt 8.775 5,514' 8,060' 2 - 47 N-80 Butt 8.681 8,060' 9,955' 7-5/8" 29.7 L-80 SLID-II 6.875 Surf 9,692' 7" 29 N-80 Butt 6.184 9,689' 14,644' DV Tubing Detail to 1 collar 3-1/2" 9.2 L-80 Supermax 2.992" Surf 9,436' 6,822' Jewelry Details 3-11 No Depth(MD) Depth ID OD Item i; (ND) 44' 44' Hanger 1 350' 350' 2.813 5.200 Halliburton TRSV-Model NE w/X-lock profile 2 408' 408' 2.992 6.670 D&L Oil Tool Dual ESP Hydraulic Set Packer w/Weatherford WFT vent valve 3 2,332' 2,194' 2.992 5.625 GLM#1 ,� 4 3,615' 3,014' 2.992 5.625 GLM#2 <12 r 5 4,630' 3,610' 2.992 5.625 GLM#3 6 5,577' 4,231' 2.992 5.625 GLM#4 ' 13 7 6,390' 4,752' 2.992 5.625 GLM#5 8 7,137' 5,238' 2.992 5.625 GLM#6 Top of < 9 7,952' 5,760' 2.992 5.625 GLM#7 Liner 10 8,635' 6,225' 2.992 5.625 GLM#8 9689' 11 9,351' 6,701' 2.992 5.625 GLM#9 12 9,398' 6,732' 2.810 3.750 X Nipple 9,436' 6,757' N/A 5.130 Bolt on Discharge Head 9,437' 6,757' N/A 5.380" Pump- 66 Stg Summit SJ10000(x3) 13 9,509' 6,804' N/A 5.130" Seals(x2)-Summit BPBSL 9,527' 6,816' N/A 5.620" 500HP Motors(x2)-Summit KMS2 (1000HP/3600V/165.5A) 9,594' 6,859' N/A 5.620" Gauge(Zenith)/Centralizer/Anode 6-3 6-4 6-5 PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Feet SPF Date G-3 13,091' 13,120' 9,157' 9,177' 29' 5 5/10/2015 8K-1 G-4 13,190' 13,207' 9,225' 9,237' 17' 5 5/10/2015 - HK-2 6-5 13,354' 13,364' 9,338' 9,345' 10' 5 5/10/2015 G-5 13,440' 13,450' 9,398' 9,405' 10' 5 5/10/2015 Z- HK-3 HK-1 13,622' 13,664' 9,525' 9,555' 42' 5 06/30/17 HK-1 13,632' 13,688' 9,532' 9,572' 56 8 10/13/1984 HK-4 HK-2 13,696' 13,848' 9,577' 9,683' 152' 5 06/30/17 Clean-out to - HK-3 13,885' 13,995' 9,708' 9,784' 110' 5 06/30/17 14,198'on HK-3 13,985' 14,000' 9,777' 9810 15 8 4/27/1981 7i27/17 HK-3 14,006' 14,033' 9,792' 9,810' 27' 5 06/30/17 Howcoersv HK-3 14,015' 14,036' 9,798' 9,812' 4/27/1981 permanent BP 21 8 @14,510 HK-4 14,052' 14,066' 9,823' 9,832' 14 8 4/27/1981 PBTD: 14,510' TD: 14,645' Updated byJLL: 07/27/17 • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-16RD Moncla 404 50-733-20183-01 180-110 4/14/17 7/4/17 DailyOperations: .,„L, . ....: ... , '. , < .... ,. .:;.r... 04/14/2017- Friday Workover personnel enroute to Dolly Varden platform. Borrowed crane op from Monopod to backload Moncla tank, mud pump and hyd jacking unit from Grayling to skid rig over D-16RD. Held safety briefing with Moncla day crew prior to commencing operations (oriented + platform walk around with 2- Moncla new hires). Worked M/V Champion receiving hyd jacking unit, Moncla mud pump and tank, Pollard slickline equipment, coflex hoses, Quadco mud box. Quadco &Total Safety set up and tested their systems. Set pancake jacks in position and cleared skid path. Skid rig carrier north to uncover access to well hatch. Set racking mat beam in place.Spot SLU on drill deck and R/U SLU. Production operator shuts in well. M/U SL BHA. PT SLU LUB and WLV= 2000 psi-Good Test. RIH with 2.73" GR to 11,358', weight slacked off. Worked 2.73" GR to 11,750', with 600-800#over pulls on pickups. POOH. Run hose from rig tank to platform water supply. Rigged mud pump to tank. Ran pump and return lines. Install panic line to gas buster. Load rig tank with FIW. L/D 2.73" GR, P/U Braided Line brush for 3 1/2" tb. RIH w/ BLB, fall to 9,100'. Work tools to 10,120' slack off, unable to pass. POOH. Broke off BLB and M/U 2 1/2" gauge ring on tool string (rope socket, 2.65" roller boogie, 10' of 1 3/4" stem, 2.65" roller boogie, 1-3/4" oil & spang jars, 2.65" roller boogie, 2 1/2" gauge). Could not get deeper than 10,450'. SOOH. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-16RD Moncla 404 50-733-20183-01 180-110 4/14/17 7/4/17 Daily Operations: ' x» 1 04/15/2017-Saturday Finished POOH w/S/L Run#3 (2 1/2" gauge ring, 2.65" roller, 1 3/4" spang &oil jars, knuckle jt, 2.65" roller, 10' of 1 3/4" stem, 2.65" roller, rope socket). Broke off rollers. Rig crew continued moving/positioning workover equipment. TIH w/ Run#4 (same as#3 w/o rollers)to 12,140' and set down-worked tool trying to get deeper and hung up (1000 PSI on well). While bleeding well tool string pulled free- POOH. B/0 2 1/2" Gauge. M/U 3 1/2" Daniels kick-over tool w/ 1 1/4"JDS running tool, 1 3/4" spang& oil jars, knuckle jt, 10' of 1 3/4" stem & rope socket-TIH w/ Run #5 to 11,872-set down- unable to get deeper. Located valve at 11,303' and latched same-equalized tb & casing pressure at 720 PSI. Pulled valve from seat and POOH. B/O lub- recovered valve. R/D slickline. Bled down pressures (to minimize affect on well clean tank) while R/D slickline and R/U lines to flush well w/ FIW. Finished skidding rig (West) over well. Began flushing well w/ FIW at 2.3 BPM 0 PSI. Worked M/V Champion receiving Knight fishing tools, KOT power tongs and (1) Moncla coflex hose along with production items. Started catching pressure at— 3000 stks (111 bbls)- returns shortly after, pressure stabilizing at 120 PSI. Reduced pump rate to 1.94 BPM (72 PSI) in order to not overrun well clean tank. 9960 stks (369 bbls) away, reduced rig pump rate to 0.9 BPM (0 psi) in order to not overrun well clean ,. tank. Continue R/U W/O package. Set heater and fuel tank in place. R/D all jacks. R/U carrier stairs and landings. Ran return line from choke to gas buster. 14000 stks (519 bbls) away, increase rig pump rate to 1.30 BPM (12 psi). Quadco calibrates koomey gauges, chart recorder and super choke gauges. Run air lines. 17600 stks (652 bbls) away, increase rig pump rate to 1.60 BPM (54 psi). 21604 stks (800 bbls) away, clean returns, shutdown pump. Monitor well, well on vacuum. NOS rep installs BPV. Laid derrick back enough to allow crane clearance for N/U-N/D. N/D tree with assistance from production. NOS rep worked spool cleaning hanger threads and ring groove-worked hold-down pins to verify all free and will back out- M/U blank test sub into hanger threads- installed check valve on SSSV control line and pressured up control line to cycle open SSSV. Started N/U BOPE stack. M/U 13-5/8" 5M riser with 11" adapter spool to tubing head. M/U 13-5/8" 5M mud cross, 13-5/8" 5M dual ram BOP and 13-5/8" 5M annular to riser.Torque all flange bolts to spec starting at 11" adapter spool and working up the BOPE stack. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-16RD Moncla 404 50-733-20183-01 180-110 4/14/17 7/4/17 Daily Operations: 1ei . �,..,; . 04/16/2017 -Sunday Finished torqueing BOP bolts- connected lines, energized koomey and function tested BOPE-scoped out derrick and secured all guy lines- mounted rig floor, wind walls and stairway on off-driller side- ran heat to BOP components. Held abandon platform drill at 0730 hrs. Setup rig floor w/power tongs and handling tools- M/U 3 1/2" test jt w/ blanking sub on btm- pumpin, safety valve & IBOP on top. Screwed into hanger and filled system w/ FIW. Shell tested BOPE to 3500 psi. Leaked at hold-down pins and 13-5/8" 5M X 11" 5M flange.Tighten same. Pressured back up for a good 3500#test.Tested all BOPE 250 PSI low 3500 PSI high as per Hilcorp andAOGCC requirements. Performed successful Koomey draw down test. Witness by Brian Bixby/AOGCC. Pulled 3-1/2" test joint and test sub. B/O hold-down pins, left 4 engaged. Pull BPV. M/U 3-1/2" landing joint w/safety valve. Backed out remaining hold-down pins and pulled on production string unseating hanger at 70K. Pulled hanger into 13 5/8" riser at 120K string weight and set on slips. Pump 12 BBL FIW to fill hole. RU Pollard SLU. Pressure tested lubricator to 2000 psi. RIH with 1-3/4 TS (0.5' RS, 10' Stem, 0.75' KJ, 3' OJ, 7' LSSJ) and 2-1/4" DD Bailer. Set down at 12,220', work tools to 12,224'. 3 jar licks to PUH. RIH to 12,224, 300 lb. over pull on pickup. POOH. Bailer full of scale. L/D 2-1/4" DD bailer, P/U 2-1/2" DD bailer and RIH w/ Run #2. Tagged at 12,221' & bailed to 12,223'- POOH and recovered same (scale) except looser. B/O 2 1/2" bailer and M/U 2 1/4" drive down bailer. TIH w/ Run #3. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-16RD Moncla 404 50-733-20183-01 180-110 4/14/17 7/4/17 Daily Operations: 04/17/2017 - Monday Continued in hole w/2 1/4" drive down bailer w/ 1 3/4" spang&oil jars, knuckle, 10' of stem, rope socket to 12,224'- worked bailer to 12,226- had to hit spang jars on P/U to free tool. POOH- no recovery, possible washout. B/O 2 1/4" DD bailer. M/U 2.27" Starbit and changed out to 2" stem w/ knuckle, oil & spang jars. TIH w/ Run#4 to 12,226' and worked tool to 12,228'-tool hung for 45 mins before jarring free-drug uphole for 10'. POOH-tool string intact- no marks on tool. Rigged to side. Rigged up Kelly hose to pumpin sub and installed night cap on Pollard lubricator- pumped 2 bbls FIW down tb and pressured up to 1000 PSI- 987 PSI on 7 5/8" gauge- lost 52#s in 30 mins. Bled off pressure. 2nd Pollard S/L crew arrived w/ 1 1/4" tool string- M/U 1 1/2" bailer w/ 1 1/4" spang& oil jars, knuckle, 10' of stem & rope socket. TIH w/ Run #5 to 12,226'-worked for 30 mins trying to get deeper, had to hit spang to jar free. POOH with 2 cups scale. M/U 2 1/4" drive down bailer w/ 1 3/4" tool string. TIH w/ Run #6 to 12,223', work tools, sticky and gained no new hole. POOH with empty bailer M/U 2 1/4" lead impression block on same tool string. TIH w/ Run #7 to 12,223', work tool. POOH with no impression. M/U 2 1/4" pump bailer w/same tool string. TIH w/ Run#8 to 12,223', work tool, not sticky. POOH with 1 cup scale. Pump 4 BBL OILSAFE ACID and displace to 10,230' with 85 BBL FIW. Stop pump, SI choke and allow acid to fall and soak for 1 hour M/U 2.60" star bit.TIH with Run#9 to 12,223', work tools, sticky pickups, no new hole made. M/U 2-1/2" DD bailer with ball bottom. TIH with Run# 10 to 12,224', work tools to 12,227'. POOH w/4 cups scale. M/U 2-1/2" DD bailer with flapper bottom.TIH with Run# 11 to 12,227', work tools to 12,230'. POOH w/4 cups scale and 1 quart muddy fluid. Call HAK Ops Eng to inform of progress made with post-acid soak runs, decision to continue on with SLU runs. M/U 2" DD bailer with chisel bottom.TIH with Run# 12 to 12,227', work tools to 12,230'. POOH with 5 cups scale M/U 2-1/4" centralizer above 1-1/2" DD bailer.TIH with Run# 13 to 12,232', work tools. Sticky pickups. POOH with empty bailer and broke flapper. M/U 2-1/4" centralizer and 3' X 1-1/2" Stem above 1-1/2" DD bailer.TIH with Run# 14 to 12,233', work tools. POOH with full bailer, 5 cups scale. M/U 2.52" star bit. TIH with Run# 15 to 12,233', work tools, no new hole. POOH M/U 2-1/2" DD bailer with flapper bottom.TIH with Run# 16 to 12,230', work tools to 12,234'. POOH with — 1 cup of scale. M/U 2.52" star bit. TIH with Run# 17. • i Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-16RD Moncla 404 50-733-20183-01 180-110 4/14/17 7/4/17 Daily Operations: 04/18/2017-Tuesday Continued in hole w/2.52" Star bit to 12,234'-worked tool in attempts to make hole- no new hole made- POOH. Cut 120' of wireline, tightened tool string and repacked wireline packoff. M/U 2" drive down bailer w/chisel point on same tool string and TIH to 12,229' attempted to make hole but failed. POOH- B/O bailer- 1/2 cup recovery of scale. Decision was made to move off D-16RD and move on D-43RD. S/L M/U 3 1/2" OK5 kickover tool w/ 1.75" spang &oil jars, knuckle, 10' of stem & RS-TIH and installed dummy valve at 11,303'. POOH & R/D S/L. Drained stack and set BPV- ran in hold down pins. Cleared and dismounted floor-de-energized koomey and disconnected lines- disconnected choke house- broke down mud pump &tank-scoped down, laid over derrick-secured all cabling to derrick. Started N/D BOPE at 1500 hrs. N/U tree. Plumb SSSV control line thru tree adapter. M/U 11" flange bolts to spec. NOS tested pack-off void, 500 psi/5 mins, 5000 psi/15 mins-good test. NOS pulled BPV and set 2-way check. Shell tested tree, --- 4500 `4500 psi/10 mins-good test. NOS pulled 2-way check. R/D casing valve-to-well clean tank return line.Turned well over to production at 21:00 hrs. Continue R/D of W/O package prepping all for move to D-43RD. Suspended Operations for D-16RD AFE# 1721533. notifed Mr Guy Schwartz with AOGCC of plans to suspend operations. 05/12/2017- Friday Pre-job safety meeting,JSA& permits. MIRU SLU. M/U 1.75" Toolstring (0.5' RS, 10'TUNGSTEN STEM, 0.75' KJ, 3' OJ, 7' LSSJ, 5'TUNGSTEN STEM). PT LUB &WLV= 500 PSI LO/2500 PSI HI. RIH with 2.40" SL Scratcher(SLS) w/well flowing —700 BPD flow rate. W/T down hole, slow progress, periodic set downs. PUH and allow well to flow off debris after set downs. Work to 12, 238' KB, set down, PUH w/heavy drag due to suspected scale ball. Continue POOH allowing well flow to clean up tool.Tool drag falls off as POOH.Trip to surface to check toolstring. L/D 2.40" SL Scratcher. M/U 2.14" Star Bit. RIH w/well shut in to 12,238' KB hard tag, break through and fall to 13,300' KB (tubing tail + 306'). PUH to 12,200'.TIH to 13,000' with no set downs. POOH. L/D 2.14" Star Bit. P/U 2.80" SLS. RIH to 13,000' KB w/o set downs. PUH to 12,200, repeat TIH to 13,000'. POOH. L/D 2.14" Star Bit, M/U 2.80" SLS. RIH with 2.80" SLS working tool from 12,200' KB to 13,000', no hard set downs. PUH to 12,200' and repeat TIH to 13,000' POOH. R/D and S/B SLU. Secure drill deck, well and well room. Turn over well to production. SDFN Job ongoing. 05/13/2017-Saturday Pre-job safety meeting,JSA and permits. RU SLU. M/U 1.75" toolstring (0.5' RS, 10' Stem, 0.75' KJ, 3' OJ, 7' LSSJ, 5' Stem). PT= 500 psi Lo/2500 psi Hi. RIH with 2.81" Helix SL Scratcher to 12,250' KB. PUH to 11,500' with heavy drag/scale. TIH to 12,286'. W/T losing hole, scale bridging off, last depth 12,100'. POOH. SI swab. Production flows well for 2 hours to clear scale and debris from well bore. L/D 2.81" Helix SL Scratcher, helixed wire bent and deformed. P/U 2.80 Gauge Ring. RIH with 2.80" Gauge Ring. Start working scale at 12,300' KB. Work tools to 12,720', unable to pass, PU very heavy. Continue working tools, losing hole and unable to PUH. Production flows well, debris flows off tools. POOH. Production flows well for 1.50 hours to clean up scale debris.T/IA/OA= 720/1030/200. RIH w/2.72" Gauge Ring. Work tools from 12,700' to 12,853' KB, then progress slows. POOH. RIH with 2.81" SLS, work tool to 12,864' KB. Work tool, Unable to pass and losing hole. POOH.JOB ONGOING. 1141 � Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-16RD Moncla 404 50-733-20183-01 180-110 4/14/17 7/4/17 Daily Operations: r, .... ��„ �,�_..� � :, ,_: � .�. . .. ..�.. tom,. 05/14/2017-Sunday Continue OOH w/2.81" SLS. R/D and stand back SLU.Turn well over to production. Production flows well. PJSM,JSA and permits. Shut in well. RU SLU, M/U 1.75" toolstring (0.5' RS, 10'Tungsten Stem, 0.75' KJ, 3' OJ, 7' LSSJ, 5'Tungsten Stem). PT= 500 psi lo/2500 psi hi. RIH with 2.14" start bit to hard tag @ 12, 878', work tools unable to pass. POOH. R/D &stand back SLU. Turn well over to production. Production flows well —850 BPD. PJSM,JSA and permits. Shut in well. RU SLU, M/U 1.75" toolstring (0.5' RS, 10'Tungsten Stem, 0.75' KJ, 3' OJ, 7' LSSJ, 5'Tungsten Stem). PT= 500 psi lo/2500 psi hi. RIH with 2.40" SL scratcher, exit tubing tail at 12, 954' and continue to tag at 13,371'. PUH to 12,200' 20 passes with 2.40" scratcher from 12,200' out tubing tail. POOH. L/D 2.40" SL scratcher, P/U 2.80" SL Scratcher. RIH w/2.80" SLS to 12,200'. 20 passes with 2.40" scratcher from 12,200' out tubing tail. POOH, L/D 2.80" SLS, P/U 2.72" Gauge Ring. RIH w/2.72" GR to 13,152' tag depth. No set downs or obstructions encountered in tubing. POOH, R/D SLU. Secure drill deck, well room and well.Turn well over to production. Fly crews to beach. SLU job completed. 06/13/2017-Tuesday Well shut-in upon arrival. Initial WHP = 750 psi. Spot Pollard ELine equipment and R/U- M/U Run #1 (1 3/8" RS, 2- 1 11/16" WBs, 1 11/16"jars, 2 1/8" CCL, XO & 2.64" gauge = 17.13'). Pulled inside lub and M/U to well. PT to 250/2500 psi.TIH to 12,988'- no tag,tb clear. Pulled correlation strip. 900#over pull at 12,988' with heavy pull up to 8,500'. POOH. B/O gauge &XO. M/U Run #2 (2 5/8" chem cutter on same tool string = 27'). RIH to 12,920' -tied into downhole hardware - PUH logging into position. Fired cutter at 12,872' (middle of 10' pup on top of pkr). Slight change in tb &casing pressure after the cut. Worked tool for 10 mins before pulling free. POOH. R/D ELine unit. 06/16/2017 Friday Night crew arrived platform (by 0715 hrs) while day crew loads 1st load of W/O equipment at GPP. Loaded derrick, A- frame, draw-works, 2-walkways, carrier, single & double strong back beams, spreader bars, driller's shack,tool connex, stairs, landings and other walkways. M/V Titon departed f/ Dolly. Day crew onboard Dolly at 1430 hrs. Offloaded tool connex-cleared deck and moved crane stairway. 1500 hrs began bleeding down well pressure (from 1150#s). Set up single and double strong back beams- bolted up spreader bars. Set and secured carrier,A-frame, draw- works, and walk ways on carrier. Positioned driller's shack- hooked up console-spotted choke house and Koomey unit. 7 Released M/V Resolution for second load at 2200 hrs. Offloaded M/V Titon receiving racking mat, Moncla mud pump, 13 5/8" x 5M BOPE equipment, rig tank w/gas buster, rig floor, Swaco tank, Quadco &Total Safety equipment. At 0330 hrs, well had 120 PSI on tubing and casing. Presently positioning and hooking up W/O equipment. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-16RD Moncla 404 50-733-20183-01 180-110 4/14/17 7/4/17 Daily Operations: N 06/17/2017-Saturday Continued positioning and hooking up W/O equipment. Primary task at hand is getting lined up to kill well with FIW sending returns to production header line. Worked M/V Resolution receiving KOTs tongs and power pack, power swivel, Moncla heater and fuel tank, Hilcorp McCoy&Gill tongs w/power pack, sized salt pill material, KOTs YTs & HYT elevators, basket w/ ram & pancake jacks, koomey lines, test jts, pressure washer, stairs, Porta Potty, thread protectors, light plant. Raised derrick and spooled on drill line and air hoist lines. Sent/received NPFT and began pumping FIW (LW) @ 3 BPM 420 psi- returns at 60 bbls pumped. Pumped a total of 600 bbls FIW. Shut down and monitored well f/ 15 mins- pressure 0, no flow. R/D hoses and set BPV- N/D Tree. NOS rep pressured open SSSV and plugged off line. Installed test sub in hanger. Leaned half-mast derrick over to N/U. N/U 11" x 13 3/8" 5M adapter flange on riser, mud cross, dbl gate rams, Hydril- hooked up all hydraulic hoses to BOP Rams and valves,tightened all BOP bolts w/torque wrench. Hooked up support cables to carrier and raised and scoped derrick up securing all guy lines- mounted rig floor. Hooked up high pres hoses to standpipe manifold and choke house. Energized and functioned Koomey unit. Setup wind walls around rig floor. 06/18/2017-Sunday Loaded rig floor with tongs and handling tools (elec rewired plugin on hyd power pack). Set up test pump and manifold- built 3 1/2" 8rd test jt w/ pumpin, SV & IBOP on top, XO to LH sub on btm. Screwed into blanked & ported sub-filled stack, closed annular and shell tested to 3500 psi- released pressure. Worked M/V receiving 3- pipe racks, test plug &wear bushing, Gill tongs, KOT fishing tools, and production items.Tested all BOPE to 250 psi low 3500 psi_ high as per Sundry in accordance to AOGCC & Hilcorp requirements. Performed successful koomey draw-down test. AOGCC witness waived by Jim Regg 10:39 pm 6/16/17 by email. Backed out blanked & ported sub- B/D test equipment. Screwed into hanger w/8rd landing jt- backed out hold-down pins and started pulling on string. Hanger moved off seat at 63k and pulled up hole at 120k- pulled hanger to surface and filled hole w/ FIW-took 20 bbls to fill hole. B/0 hanger and SSSV control line. Began POH laying down recovered 3 1/2" 9.2# L-80 Supermax production tubing and hardware (from chemical cut at 12,872'). 2000 hrs worked M/V receiving 301-jts PH-6 workstring and 6-4 3/4" DCs. 201 of 381 jts (+4- mandrels & 1-SSSV) OOH at report time = 6,177'. 06/19/2017- Monday Stopped at 6,081' (204 of 381 jts OOH) and circulated oil out to production header at 3 BPM 300 psi. Pumped a total of 400 bbls FIW. Continued POH laying down production string from 6,081' to 0 .Total jts L/D 381 +3.85' Cut Jt and 13 GLM Plus SSSV w/ pups and xo Tot 15.08'. Clean up floor and power wash walkways handrails and cellar around bop stack. Load boat w/381 Jts supermax tubing, hanger and tree. Lay out 3 1/2" workstring PH 6. Strap and Make up BHA#1 W/ KOT hand /Milling shoe w/5 3/4" KHT, 5 3/4" Ext, dbl pin sub, mud motor w/2 boot basket, bit sub, bumper jars, oil jar, 6-4 3/4"D.C, XO w/3 1/2" PH 6 work-string . MEW • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-16RD Moncla 404 50-733-20183-01 180-110 4/14/17 7/4/17 Daily Operations: 06/20/2017-Tuesday Continue pick up 3 1/2" PH 6 Workstring 90' Test Mud motor @ 3.5 bbls. Continue tally and rabbit tubing joints,fill tubing with FIW every 20 joints. 205 joints in hole (6,639'). Continue TIH with KOT BHA#1 picking up 3-1/2"" PH-6 workstring. Continue tally and rabbit tubing joints, fill tubing with FIW every 20 joints. 305 joints in hole (9,733'). Continue TIH with KOT BHA#1 picking up 3-1/2" PH-6 workstring. Continue tally and rabbit tubing joints,fill tubing with FIW every 20 joints.403 joints in hole (12,779'). R/U stripper head. RIH T/ 12870'. 06/21/2017 -Wednesday Continue rig up power swivel and hook up power pack. Due to power swivel motor.Troubleshoot motor W/ production mechanic. Start Wash/ Mill Forward at 12, 891' UPWT 178K DNWT 76K. Pump at 3.5BBLS min W/ 1000 PSI and 6500 FPT free spin.Add friction reducer to FIW. UPWT 156K DNWT 90K. Mill to 12,892', lost circulation for 15 seconds then gain returns (milled out rubber element). Continue to mill to 12,892' motor stall. PUH, establish motor free spin.TIH and set down at 12,887'. Unable to return to 12,892', continue milling. Milling at 12,887' 5/0 WT= 108K, milling at 102K, 3.4 BPM 1250- 1340 psi. Unable to mill ahead past 12,887'. PUH and prep for POOH. R/D power swivel, stripper rubber. L/D 2 joints 3-1/2" PH-6 tubing and beaver slide. POOH standing back 3-1/2" PH-6 tubing in derrick. Pump 4 bbls FIW every 20 stands. Work M/V Titan offloading 2 joints KOT wash over pipe at 02:00. KOT BHA#1 at floor. 202 stands 3-1/2" PH-6 in the derrick. Stand back drill collars. 06/22/2017 -Thursday Continue L/D BHA#1/shoe and motor. M/U BHA#2 W/ Milling Shoe 5 3/4"KOT 5.02', 1 jt 5 3/4" wash pipe 30.50, Top Bushing 31/2"X 5 3/4" 2.070, Double pin sub 3 1/1"X3 1/2" 1.410, NOV Motor 4 3/4' 24.920', Double pin sub 3 1/2'x 31/2" 1.350', 2 Boot Basket 4 1/4x1 1/2' 10.42', Bit sub 2.590', Bumper Jar7.840', oil jar 12.600', 6-4 3/4" D.0 184.400', XO PH6 X IF, 1.810'.Tot BHA#2 284.93'. Test Mud Motor 3.5 @ 250 PSI. Continue RIH with KOT BHA#2 on 3- 1/2" PH6 work string and Fill pipe every 1250'. 203 stands TIH. UpWT= 148K. DownWT= 84K. R/U stripper head and power swivel.Tag packer and milling at 12,887'. Milling with FIW at 4 BPM 1500 psi, Power swivel 60 RPM @ 6000 FPT, RotWT= 110K. Packer falls downhole, stop pump. RIH with 2 joints 3-1/2" PH-6 to 12,960'. R/D power swivel and stripper head. POOH standing back 3-1/2" PH-6 work string in derrick. String pulling wet. R/U mud bucket. Work M/V Resolution offloading and backloading. 10 stands in derrick. Continue POOH standing back 3-1/2" PH-6 work string in derrick. 13th stand to derrick string pulling dry. R/D mud bucket. Pump 4 BBL FIW every 20 stands. 155 stands in derrick. Changing out tong dies. Continue POOH standing back 3-1/2" PH-6 work string in derrick. Pump 4 BBL FIW every 20 stands. Starting to Rack back BHA#2 in Derrick. ! • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-16RD Moncla 404 50-733-20183-01 180-110 4/14/17 7/4/17 Daily Operations: `c...._, ..,. ." ... 06/23/2017 - Friday Continue L/D BHA# 2 and make up BHA#3 W/ 5 3/4"over shot, bumper jar, oil jar, 6-4 3/4" D.0, accel jar,xo, RIH W/ PH-6 work-string T 5700'. Slip 120' and Cut 120' Drilling line and service rig. Continue RIH W/ PH6 work-string T/ 12,899', Up WT 154K. Single in F/ 12,899' T/13,085'. Cont push PKR T/ 13,126'. Latch up Fish @ 13,126' Up WT 175- 190 K. Continue POOH W/fish Slow UP WT 158-180K. 8 stands 3-1/2" PH-6 in derrick. Draw work brakes spongy. Working on draw work brakes. Testing draw work brake after repair. Stand back 1 stand 3-1/2" PH-6. Continue POOH W/fish Slow UP WT 158-180K standing back 3-1/2" PH-6 work string. Hanging up at casing collars, work pipe to pass collars. Pulling free past casing collars with 20 stands in derrick. Load hole with 3.3 BBL FIW. Pump 4 BBL every 20 stands.139 stands in derrick. Continue POOH standing back 3-1/2" PH-6 workstring. Pump 4 BBL every 20 stands. 06/24/2017-Saturday Continue POH and stand back w/3 1/2" PH6 work string. Stand Back BHA#3. L/D PKR,Tail pipe Assy and over shot. R/U Test Plug and test Equip.Tested all BOPE to 250 psi low 3500 psi high as per Sundry in accordance to AOGCC & Hilcorp requirements. Performed successful koomey draw-down test. AOGCC witness waived by Jim Regg 10:30 pm 6/23/17 by email. R/D Test Equip clean up Floor. PSJM M/U BHA#4 w/KOT/junk mill 6", double pin sub, mud motor, double pin sub, 2 boot basket, bit sub, bumper jar, oil jar, 6-4 3/4" dc,xo, ph6work-string. RIH W/ KOT BHA#4 on 3- 1/2" PH6 Work-string. 56 stands 3-1/2" PH-6 RIH. Continue RIH W/ KOT BHA#4 on 3-1/2" PH6 Work-string. Choo-choo pump stops working at 19:30 hours, hole fluids flow over top of BOPE stack. Stop RIH, repair choo-choo pump, trash found in pump diaphragms. Remove trash from choo-choo pump diaphragms. 93 stands 3-1/2" PH-6 RIH. Continue RIH W/ KOT BHA#4 on 3-1/2" PH6 work string. Set down at 13,126' (414 joints+ 15' in the hole). Stand back Stand# 208 (Joints#415 &416). R/U power swivel and stripper head with new rubber installed. Load hole with 5.50 BBL FIW. TIH milling/washing F/ 13126' and picking up single joints of 3-1/2" PH-6 tubing pumping FIW at 4 BPM 1360 psi. UP wt 160K DN wt 80K. Rot wt 108K RPM @ 30. 06/25/2017-Sunday TIH milling/washing F/ 13126' and picking up single joints of 3-1/2" PH-6 tubing, pumping FIW at 4 BPM 1360 psi. UP wt 160K DN wt 80K T/ 13510'. Rot wt 108K RPM @ 30. Continue milling on lower joints WD 7" PKR @ 13510' @ 4 bbls min w/ 1325 PSI, UP wt 160K, DN wt 70K, Rot wt 110K @ 15-30 RPM, 6-7K FPT. Mill and push 7" packer to 13,534',427 joints+ 15' in the hole. Unable to mill ahead from 13,534'. P/U off packer to 13,520'. Circulate bottoms up, 426 BBL FIW (12,000 stks) @ 4 BPM, 1200psi. L/D 4 joints 3-1/2" PH-6 tubing and R/D stripper head. L/D beaver slide. POOH standing back 3-1/2" PH-6 workstring in derrick. PUWT 180-200K on Stands# 1-4, working 3-1/2" PH-6 tubing. Stand#5 PUWT= 160K, pulling free, continue POOH. Pull 20 stands total (12,178'). Load hole w/6.50 BBL FIW. Continue POOH standing back 3-1/2" PH-6 workstring in derrick PUWT 150- 160K. Pump 4 BBL FIW every 20 stands. 213 stands in derrick. Continue Standing Back BHA#4. ! • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-16RD Moncla 404 50-733-20183-01 180-110 4/14/17 7/4/17 DailyOperations ..,.. .,. .. 06/26/2017-Monday PSJM M/U BHA#5 w/KOT/junk mill 6", double pin sub, mud motor, double pin sub, 2 boot basket, bit sub, bumper jar, oil jar, 2-4 3/4" dc, xo,Tot BHA#5 127,63' ph 6work-string. Continue RIH w/ ph 6 work-string fill pipe every 20 stands T/ 13520'. Make up power swivel @ 13520' and stripper head. UPWT= 154K DNWT- 80K. Return to milling at 13,534'. ROT WT= 108K, 4 BPM 1300 psi, 6-7K FPT @ 60 RPM. Mill to 13,539', rig pump swab fails and pump starts jacking. P/U off bottom and stop pump. Replacing rig pump swabs. Test rig pump -failed. Rig pump fluid end failure beyond repair with available parts currently on platform. Call for boat delivery of replacement pump. Rig down pump and prep for backload to boat. M/V Resolution arrives with replacement rig pump. Off load replacement rig pump, back load failed pump for return to beach. R/U replacement rig pump. Return to milling at 13,539'. ROT WT= 108K, 4.25 BPM 1450 psi, 6-7K FPT @ 60 RPM. Milled to 13,571'. Rig pump pony rod loose, S/D pump.Tighten clamp and re- service pump. Return to milling at 13,571'T/ 13628'. ROT WT= 108K, 4.25 BPM 1450 psi, 6-7K FPT @ 60 RPM. 06/27/2017-Tuesday Continue cleaning out F/13628'. Add 2 drums CFS-520 and Mix 50 BBL High visc sweep w/3 sacks barazan D plus. UPWT= 170K, DNWT= 80K. ROTWT= 112K, Power Swivel 5 - 7.5K FPT turning 60 RPMs 4.25 BPM 1250 psi with mud motor turning 95 RPMs. Milling at 13,866', stripper head leaking. Stop and change out stripper head rubber element. Return to milling/cleaning at 13,866'. Mill to 13,900', rig pump oilers stop working. Stop milling, repair pump oilers. Repairing pump oilers. Return to milling/cleaning at 13,900'. UPWT= 170K, DNWT= 80K ROTWT= 112K, Power Swivel 5 -7.5K FPT turning 60 RPMs 4.50 BPM at 1450 psi. Mix 50 BBL High visc sweep w/3 sacks Barazan D Plus. Milling rate slows at top of open Hemlock perfs at 13,985', 14,015' and 14,052'. Cleanout to 14,198' (JT. 453). Pump 50 BBL(1400 stks) High visc sweep (Barazan D Plus) and chase with 150 gallons bleach in FIW at 3.90 BPM, 1180 psi. Continue to chase sweep with 546 BBL FIW (15,300 stks) circulating sweep to surface across shakers at 3.70 BPM, 1300 psi. M/V Titan arrives at platform 01:30 hrs. Work boat offloading production tubing and TCP guns. Stop pumping and complete rig tank cleanup. Pump rig tank bottoms to Trading Bay thru platform production header (NPFT submitted to Trading Bay and then confirmed by phone). 06/28/2017-Wednesday Continue cleaning pits and all lines in the circulating system. Fill pits with clean FIW 8.5 PPG. Displace well w/clean FIW 8.5# pumping down tubing taking returns to Trading Bay @ 3.25 BBLS w/980 psi, tot pump 767 BBLS. Set swivel back in derrick and rig up to L/D ph6 work-string off botton ( up wt 165k) @ 14190'. L/D 20 joints (13,578'). Continue POOH laying down 3-1/2" PH-6 tubing UPWT= 150K. Pump 4 BBL FIW every 40 joints. M/V Resolution arrives 19:00 hrs. Work boat until 20:30 hrs. OOH with 188 joints (8,399'). Continue POOH laying down 3-1/2" PH-6 tubing UPWT= 98K. Pump 4 BBL FIW every 40 joints. L/D Tot 321 Jts. • S Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-16RD Moncla 404 50-733-20183-01 180-110 4/14/17 7/4/17 Daily Operations: ,,. .. `. $feoz. '61;7,4N,,,,, ,. .. ; 06/29/2017-Thursday Continue L/D 3 1/2" 321 jts PH-6 Work string and stand back in derrick 66 stds. L/D BHA#5 and make up KOT BHA#6 w/ 7 5/8" scraper. RIH w/7 5/8" casing scraper on 3 1/2" PH-6 work string to 600'. POOH and L/D BHA#6. Clean up tools, floor and moved handling tools to rig floor. Rig up to run Halliburton TCP guns. PJSM w/workover crew and Halliburton reps. M/U 411' of 4 5/8" 5 SPF 60* phase EHC Idd w/39 grm Millennium charges+ needed hardware-total length = 506.33'.TCP assembly diagram in '0' drive.TIH w/TCP assy picking up 3 1/2" 9.2# L-80 SuperMax tubing- strapping, drifting and torqueing to specs. Ran in a total of 195 jts of 3 1/2" SuperMax at report time = 6988'. 06/30/2017- Friday TIH w/TCP assy picking up 3 1/2" 9.2# L-80 SuperMax tubing-strapping, drifting and torqueing to specs. xo T/3 1/2" PH6 work string. RIH 66 Stds and single W/ 10' pup T/ 14059'. PJSM w/Workover crew and E-line crew. Rig up Pollard ELU with pump-in sub and safety valve. RIH with 1.68" OD GR/CCL tool suite to 13,590'. Pull correlation log and send LAS & pdf files to HAK Geologist for depth verification. Depth correct log 20' per HAK Geologist with RA at 13,550'. POOH with ELU, R/D ELU. AOGCC WAIVES 7/1/17 BOPE TEST ALLOWING COMPLETION RUN POST TCP RUN (15:37 hours, email saved to "0" drive). Pull into position at 13,530' end of tubing corrected depth (RA @ 13,550'). Pump to tubing to pressure up to 1900 psi and fire guns per perf schedule. L/D 1 pup and 1 joint 3-1/2" PH-6, pump 114 BBL FIW tubing volume (10 BBL to fill hole). POOH L/D 20 joints 3-1/2" PH-6 to get above perfs. Reverse circulate 429 BBL hole volume at 3 BPM, 387 psi (losing 12 BPH while circulating). POOH L/D 3-1/2" PH-6. Pump 4 BBL FIW every 40 joints. 133 joints+ 1 pup total OOH. POOH standing back 3-1/2" 9.2# L-80 SuperMax 137 in derrick. L/D 10 its SuperMax. Pump 4 BBL FIW every 20 stands. 07/01/2017-Saturday PJSM W/ HALLIBURTON HANDS AND RIG CREW . L/D ALL PERF GUNS . ALL GUNS FIRED. CONTINUE CLEAN UP FLOOR AND HALT EQUIPMENT. R/D GILL TONGS, POWER PACK AND HOSES. PJSM W/SUMMIT AND RIG CREW. RIG UP SUMMIT ESP EQUIP AND McCOY TONGS, POWER PACK AND HOSES. R/U ESP CABLES AND HANG SHEAVE IN DERRICK. P/U SUMMIT ESP MOTOR ASSEMBLY. 25 BBL FIW pumped to keep hole filled 06:00- 18:00 hrs. (2.10 BPH loss rate) Continue P/U Summit ESP assembly M/U 1st joint of 3-1/2" 9.2# L-80 SuperMax tubing to ESP/SPM assembly with McCoy tongs to specs. M/U 2nd connection w/ McCoy tongs, 3-1/2" X-nipple sub, McCoy tong torque gauge fails. Replace McCoy tong torque gauge with new gauge, M/U 2nd connection to specs. 17 BBL FIW pumped to keep hole filled 18:00-0:00 hrs. (2.80 BPH loss rate) Continue RIH with Summit ESP/SPM assembly on 3-1/2" 9.2 L-80 SuperMax tubing (re-used) and GLMS clamping power cable and flatpack as needed.Test Insulation every 1000'. TESTED 2000' ALL GOOD CONTINUE RIH. Fill hole as needed with FIW. S Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-16RD Moncla 404 50-733-20183-01 180-110 4/14/17 7/4/17 Daily Operations: ... ; -1„ 6 . 07/02/2017-Sunday Continue RIH with Summit ESP/SPM assembly on 3-1/2" 9.2 L-80 SuperMax tubing (re-used) and GLMs clamping power cable and flatpack as needed.Test Insulation every 1000'.TESTED 2000' ALL GOOD CONTINUE RIH T/3203' Due t/GLM well head smash cable P/U 120' and made a splice. Fill hole as needed with FIW.T/3203' Due t/GLM#5 well head smash cable P/U 120' and made a splice retested all good. Relocate gas lift position w/well head clearence. Continue RIH with Summit ESP/SPM assembly on 3-1/2" 9.2 L-80 SuperMax tubing (re-used) and GLMs clamping power cable and flatpack as needed.TIH to 4,007', GLM#6, well head damages power cable. PUH 120', L/D GLM#6, to repair damaged power cable. Splice repair power cable. Reposition clamp, power cable and flatpack across GLM# 6. RIH w/3-1/2" 9.2# L-80 SuperMax tubing (re-used) and GLM#6.Test insulation - GOOD. Continue RIH with Summit ESP/SPM assembly on 3-1/2" 9.2# L-80 SuperMax tubing (re-used) and GLMs clamping power cable and flatpack as needed. Fill hole with FIW as needed.TIH to 4,884' (Std. 69), stop to change out Summit power cable spools Summit reps splicing power cable. RIH with Summit ESP/SPM assembly on 3-1/2" 9.2# L-80 SuperMax tubing (re-used), GLM#7, spliced section of power cable and flatpack to 5,102' (Std# 72).Test Insulation -GOOD. Continue RIH with Summit ESP/SPM assembly on 3-1/2" 9.2# L-80 SuperMax tubing (re- used) and GLMs#8-9 clamping power cable and flatpack as needed. @ 7200 ' Continue RIH. Fill hole with FIW as needed.Test Insulation every 1000'. 07/03/2017- Monday Continue RIH with Summit ESP/SPM assembly on 3-1/2" 9.2# L-80 SuperMax tubing (re-used)T/9179' P/U Tripoint 7 5/8" dual ESP hyrdaulic packer. Summit splice cable through packer, tie in new ESP cable and reel. Cycle Vent Valve -Good Test.Test Insulation - Good Test. RIH with 7-5/8" dual ESP hydraulic packer and ESP/SPM on 1 jt from 9,201' to 9,234'. P/U SSSV, M/U control lines. Cycle SSSV-Good Test. Continue RIH with ESP/SPM production completion on 3-1/2" 9.2# L-80 SuperMax tubing (re-used). NOS rep M/U hanger head. M/U 3-/12" landing joint. Summit built penetrator splice and plumb same through tubing hanger. NOS rep plumbed control lines through hanger. Load hole with FIW. Slacked off, landing hanger with 58K down, est. P/U 120K, end of pump at 9,593'. Ran in hold down pins and packed off void. Clear rig floor of all Summit equipment and L/D Summit sheaves Pump FIW to fill tubing, drop bar and pump FIW to pressure up tubing to 3,800 psi to set 7-5/8" dual ESP hydraulic packer. Hold for 30 minutes, charting, bleed to 0 psi. Pump FIW to test 7-5/8" casing to top of ESP packer at 1600 psi for 30 minutes, charting, bleed to 0 psi. Good Test. R/U SLU. RIH with 1-1/2 JD overshot to bar at 9,380', latch and pull bar, POOH and L/D bar. RIH with 3-1/2" GS Spear to plug at 9,384', latch and pull plug, POOH and L/D plug. R/D SLU NOS rep set BPV. Clean up rig floor, remove wind walls,V- door and rig floor. Scope down derrick. Bleed down accumulator, R/D and clean rig pump and tank. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-16RD Moncla 404 50-733-20183-01 180-110 4/14/17 7/4/17 Daily Operations: 07/04/2017-Tuesday R/D and clean rig pump and tank. N/D BOPE and clean BOPE as go . W/O crew and NOS rep install adapter flange and WH tree. NOS and Summit reps plumb control lines and power cable through tree adapter. Summit tests power cable- Good Test. NOS rep tests pack-off void, 500 psi (5 min.), 5000 psi (15 min.) -Good Test. NOS rep pull BPV, set 2-way check. NOS pressure tests WH tree, 5000 psi (5 min.) - Good Test. NOS rep pulls 2-way check.Turn over well to Production at 14:00 hours Continue cleaning and organizing W/O equipment, platform decks and well bay. Last wellez report for D-16RD AFE# 1722221. W/O crews departing platform at 0600 hrs. • • OF 7.4 THE STATE Alaska Oil and Gas OfLASIcoA Conservation Commission of 11!-' 1-1151-* _ _ 333 West Seventh Avenue h GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 (4'ALAY'P' Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis Operations Manager2017, Hilcorp Alaska, LLC scow �� 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: McArthur River Field,Hemlock and Middle Kenai G Oil Pools, TBU D-16RD Permit to Drill Number: 180-110 Sundry Number: 317-124 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / 1°241 -254— Cathy '. Foerster ,, Chair DATED this Z`1'day of March, 2017. RBD161MS UL-Ar - 3 2017 • • RECEIVED • STATE OF ALASI{A MSR 2 4 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ,0 ; 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing LI Other. GL/ESP Completion 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 0. 180-110 ' 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ElService o 6.API Number. Anchorage,AK 99503 50-733-20183-01 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 228A • / Will planned perforations require a spacing exception? Yes ❑ No 0 ° Trading Bay Unit/D-16RD ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017579 ' McArthur River Field/Hemlock Oil and Middle Kenai G Oil Pools a 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi):1 L-' ' fs4-7 Plugs(MD): Junk(MD): 14,645 ' 10,306 • 14,510 > 10,160 • Ufpsi 14,510&14,600 13,504 Casing Length Size MD TVD t-- Burst Collapse Structural YY Conductor Surface 2,544' 13-3/8" 2,554' 2,347' 3,090 psi 1,540 psi Intermediate 9,955' 9-5/8" 9,955' 7,095' 5,750 psi 3,090 psi Production 9,692' 7-5/8" 9,692' 6,923' 6,890 psi 4,790 psi Liner 4,955' 7" 14,644' 10,265' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 13,091 -14,066 ` 9,157-9,832 3-1/2" 9.3#/L-80 12,954 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Hyd.Set Liner Top Pkr&SSSV b 12,877'(MD)9,011'(TVD)&349'(MD)349'(TVD) 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program LI BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0 - Service ❑ 14.Estimated Date for 15.Well Status after proposed work Commencing Operations: 4/10/2017 OIL 0 ` WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmarlowe@hilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature 54fte /1..Ot1 Phone (907)777-8356 Date 3114 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: _// 3 1- 12-1f Plug Integrity ❑ BOP Test L/ Mechanical Integrity Test ❑ Location Clearance ❑ LA-s` 7, 12..q 1`A =16 0c%' Other: �J iter. S(S/ e r— Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Ed Subsequent Form Required: /0 ---Li0({ RBDMS LO""1 _ 3 2017 APPROVED BY Approved by: 40 COMMISSIONER THE COMMISSION Date: 3 -29_ /7 'MS 3/ 8 �� Q ® ��11f��1 j i7 3 z Submit Form and Form 10-403 Revised 11/2015 r alid for 12 months from the date of appro al. Attachments in Duplicate • • Well Work Prognosis Well: D-16rd Hilcorp Alaska,LLC Date: 03/22/17 Well Name: D-16rd API Number: 50-733-20183-01 Current Status: Oil producer(gas-lift) Leg: Leg#: B-1 (SE) Estimated Start Date: April 10, 2017 Rig: Moncla 404 Reg.Approval Required? 10-403 Date Reg.Approval Received: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 180-110 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Stan Golis (907) 777-8356 (0) Current Bottom Hole Pressure: 4,100 psi @ 9,157'TVD 0.430 lbs/ft(8.27 ppg) Maximum Expected BHP: 4,100 psi @ 9,157'TVD 0.430 lbs/ft(8.27 ppg) Maximum Potential Surface Pressure: 3 i Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) tAA5P12 Lv F s ,sten-d� ( 3 r-P d� 53 -4'a-t- �-) Brief Well Summary: /`''`' The D-16rd well is currently completed with a Gas lift string installed May 2015.This work over will replace the Gas-Lift completion with a combination gas-lift ESP and add perforations in the Hemlock to increase ✓ productivity. Last Casing Test: 05-13-15 tested IA at 12,877' MD to 1,500 psig for 30 minutes on chart Procedure: 1. MIRU Moncla Rig#404. 2. Pull lowest GLV and circulate hydrocarbon off of well.Work over fluid will be FIW. BOP's will be closed as needed to circulate the well. 3. ND WellheadNU BOP and test to 250psi low/3.500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. Monitor well to ensure it is static. 5. RU E-line and cut tubing above packer at±12,877'. 6. Unseat hanger and POOH with gas-lift completion. 7. RIH, Mill over and recover production packer. 8. RIH, and recover junk packer. 9. Cleanout to±14,200',circulate clean, POOH. 10. PU TCP guns and RIH and perforate Hemlock zones per the Perf Recommendation. 11. After detonation,circulate perf gas, confirm well is static, POOH. +'-, / 12. PU and RIH with new combo gas-lift/ESP assembly. (� 6 L '' a. A high set packer, packer vent valve, and SSSV will be ran if well indicates ability to flow to �✓� f surface. 13. Set BPV, ND BOP, NU wellhead and test. i) I ion 14. Turn well over to production. 15. Conduct SVS testing per AOGCC regulations. 16. If applicable (packer and SSSV not installed) -Schedule no-flow with AOGCC as per regulations. • Well Work Prognosis Well: D-16rd Hilcorp Alaska,LLC Date: 03/22/17 Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current 4. Wellhead Schematic Proposed 5. BOP Drawing 6. Fluid Flow Diagrams 7. RWO Sundry Revision Change Form 0McArthur River Field, TBU la SCHEMATIC Well: D-16RD As Completed: 05/17/2015 nileori Alaska,LLC CASING DETAIL 1 Size Wt Grade Conn ID Top Btm 13-3/8" 61 K-55 Seal Lock 12.515 Surf 2,554' A- r-=- 40 N-80 Butt 8.835 Surf 5,514' ' 9-5/8" 43.5 N-80 Butt 8.775 5,514' 8,060' 47 N-80 Butt 8.681 8,060' 9,955' 7-5/8" 29.7 L-80 SLIJ-II 6.875 Surf 9,692' A DV 4 Collar 7" 29 N-80 Butt 6.184 9,689' 14,644' I sr @ 6,822 Tubing Detail 3-1/2" 9.2 L-80 Supermax 2.992 Surf 12,954' 131) Jewelry Details to No Depth Depth OD ID Item Top of 'a 2-14 (MD) (TVD) Liner j Hanger 9,e89' 1 1 349' 349' 5.380 2.810 SSSV 4 . 2 2,356' 2,211' 4.800 2.991 SF0-1 GLM w/BK-2 latches 3 4,125' 3,307' 4.800 2.991 SFO-1 GLM w/BK-2 latches InI 4 5,228' 3,991' 4.800 2.991 SFO-1 GLM w/BK-2 latches 1 5 6,003' 4,512' 4.800 2.991 SF0-1 GLM w/BK-2 latches 6 6,778' 5,003' 4.800 2.991 SFO-1 GLM w/BK-2 latches 1 7 7,556' 5,505' 4.800 2.991 SFO-1 GLM w/BK-2 latches 8 8,302' 6,000' 4.800 2.991 SFO-1 GLM w/BK-2 latches 9 9,046' 6,499' 4.800 2.991 SFO-1 GLM w/BK-2 latches 10 9,824' 7,009' 4.800 2.991 SFO-1 GLM w/BK-2 latches 11 10,565' 7,505' 4.800 2.991 SFO-1 GLM w/BK-2 latches )V 12 11,303' 7,998' 4.800 2.991 SF0-1 GLM w/BK-2 latches 13 12,112' 8,510' 4.800 2.991 SFO-1 GLM w/BK-2 latches 14 12,790' 8,953' 4.800 2.991 SFO-1 GLM w/BK-2 latches 15 15 12,877' 9,011' 5.870 4.000 7"Hydraulic Set Liner Top Packer X Imo 16 16 12,919' 9,040' 4.500 2.813 X Nipple(EUE 8rd) 7 17 12,954' 9,063' 4.230 3.500 Supermax WLEG 18 13,504' 9,443' 6.184 4.000 (Junk)Otis WD 7"x4"packer w/5'seal bore ext. 8-3 3-4 8-5 18s`.."- __ HK-1 PERFORATION DETAIL Zone Top(MD) Btm (MD) Top(ND) Btm(ND) Amt SPF Date G-3 13,091' 13,120' 9,157' 9,177' 29' 4.5"TCP 05/10/15 HK-4 G-4 13,190' 13,207' 9,225' 9,237' 17' 4.5"TCP 05/10/15 G-5 13,354' 13,364' 9,338' 9,345' 10' 4.5"TCP 05/10/15 G-5 13,440' 13,450' 9,398' 9,405' 10' 4.5"TCP 05/10/15 HK-1 13,632' 13,688' 9,532' 9,572' 56 8 10/13/1984 HK-4 13,985' 14,000' 9,777' 9,788' 15 8 4/27/1981 14,510'HOWCO . 112sv permanent _ HK-4 14,015' 14,036' 9,798' 9,812' 21 8 4/27/1981 BP HK-4 14,052' 14,066' 9,823' 9,832' 14 8 4/27/1981 9' PBTD:14,510' TD:14,645' Updated: 08-11-15 by 1LL • ()McArthur River Field, TBU HPROPOSED Well: D-16RD PTD: 180-110 Hilcorp Alaska,L1.€ API: 50-733-20183-01 As Completed: FUTURE CASING DETAIL Size Wt Grade Conn ID Top Btm -rt 13-3/8" 61 K-55 Seal Lock 12.515 Surf 2,554' SA p4r 40 N-80 Butt 8.835 Surf 5,514' 1 15 9-5/8" 43.5 N-80 Butt 8.775 5,514' 8,060' 9' !2 47 N-80 Butt 8.681 8,060' 9,955' 7-5/8" 29.7 L-80 SLID-II 6.875 Surf 9,692' 4 y , 7" 29 N-80 Butt 6.184 9,689' 14,644' 1 Tubing Detail r DV ' Collar 3-1/2" 9.2 L-80 Supermax 2.992" Surf ±9,425' F1 @ If i 6,822' P 3 Jewelry Details ,e, lit11- ' No Depth(MD) Depth(TVD) ID OD Item I. 6; 44' 44' Hanger '' 111 1 1 ±350' ±350' 2.813" Contingent-SSSV 2 ±400' ±400' Contingent-Packer w/Vent valve b' 3 ±2,341' ±2,200' GLM#1 %t $ 4 ±3,591' ±3,000' GLM#2 rF 5 ±4,614' ±3,600' GLM#3 i'q ;, 6 ±5,605' ±4,250' GLM#4 43 12 Ipi 7 ±6,387' ±4,750' GLM#5 " IIII % 8 ±7,156' ±5,250' GLM#6 I 13 > 9 ±7,937' ±5,750' GLM#7 1 - 10 ±8,672' ±6,250' GLM#8 Top of "� 11 ±9,350' ±6,700' GLM#9 Liner ja 12 ±9,400' ±6,733' Contingent-X Nipple 9,689' ni Bolt on Discharge Head L 5.380" Pump 13 5.130" Seals 5.620" Motors ±9,600' ±6,863' 5.620" Centralizer Anode PERFORATION DETAIL _ G-3 Zone Top(MD) Btm(MD) Top(TVD) Btm (ND) Feet SPF Date G-4 G-3 13,091' 13,120' 9,157' 9,177' 29' 5 5/10/2015 G-5 ,I G-4 13,190' 13,207' 9,225' 9,237' 17' 5 5/10/2015 G-5 13,354' 13,364' 9,338' 9,345' 10' 5 5/10/2015 G-5 13,440' 13,450' 9,398' 9,405' 10' 5 5/10/2015 HK-1 HK-1 ±13,622' ±13,664' ±9,525' ±9,555' ±42' Future = HK-2 HK-1 13,632' 13,688' 9,532' 9,572' 56 8 10/13/1984 HK-2 ±13,696' ±13,848' ±9,577' ±9,683' ±152' Future - HK-3 ±13,885' ±13,995' ±9,708' ±9,784' ±110' Future HK-3 HK-3 13,985' 14,000' 9,777' 9810 15 8 4/27/1981 HK-4ml- HK-3 ±14,006' ±14,033' ±9,792' ±9,810' ±27' Future HK-3 14,015' 14,036' 9,798' 9,812' 21 8 4/27/1981 HK-4 14,052' 14,066' 9,823' 9,832' 14 8 4/27/1981 14,510'HOWCO QSV permanent BP I L.. PBTD: 14,510' TD: 14,645' Updated byJLL: 03/22/17 • • II Dolly Varden Platform D-16 ru1r•nrp ani+aua.I.1.1.. Dolly Varden Tubing hanger,Cactus-TC- D-16 EN-CCL,11 X 3 Y:EUE lift and 13 3/8 X 9 5/8 X 7 5/8 X susp,6''/.extended neck,w/ 31/2 3"Type H BPV profile,2-3/8 CCL,Alloy material BHTA,Bowen,3 1/8 5M FE X 3" Bowen Quick Union 1 11111V Valve,swab,WKM-M, '" a■' 31/85MFE,HWO, 0®r T-24 0'(C;\y 0®® Valve,WKM-M,3 1/8 5M FE,w/ k" 15"OMNI operator / N. O/ Valve,lower master,WKM-M, ®® ' 31/8 5M FE,HWO,T-24 ' 0 0®®P' las P. Illa" _■11� .'' I6a �II. Valve,WKM-M,2 1/16 5M FE, ' Ili., T' HWO,DD . i ' l[OO(O ® _I 1"- Multibowl wellhead assy, _ _, o.Joh Cactus MBS-2 '''— --���r: ' - 135/83Mx115M,w/4- 21/16 5M SSO,prepped for i®/ i ' 1I•I Valve,WKM-M,21/16 5M FE, 7 5/8 mandrel hanger,and 1 HWO,DD tubing hanger,9 5/8 HPSO 9 'in bottom I lea(° 11 Ii'- ji o f - ,'a.," I DPSO,13 5/8 3M x 13 5/8 3M w/3-9 5/8 P seals Casing head,CIW-WF, • 13 5/8 3M X 13 3/8 casing iI thread bottom,w/2-21/16 Valve,CIW-F,2 1/16 3M FE, 5M EFO a r4 " ? HWO,AA trim 010 i NZ —p 11 r L_ • • II Dolly Varden Platform D-16 Proposed Hik rp,tlnwku,1.1.i: 01/19/2015 Dolly Varden Tubing hanger,FMC-TC-ESP, D-16 11 X 314 NS-CT lift and susp, 13 3/8 X 9 5/8 X 7 5/8 X 300-4 seal pocket,w/3" 3 1/2 Type H BPV profile,4-3/8 CCL,Alloy material - BHTA,Bowen,3 1/8 5M FE X 3" Bowen Quick Union A u, Valve,swab,WKM-M, ' 'plik" 31/85MFE,HWO, ®Q T-24 4 G, 4 $O©> Valve,WKM-M,3 1/8 SM FE,w/ ",'�"' 15"OMNI operator Valve,wing,WKM-M, 21/165M FE,HWO, ($I ® 0�"I 0 I T-24 _ .2 o_ nY�i.Valve,lower master,WKM-M, '�- ,_ 3 1/8 5M FE,HWO,T-24 Co O u Adapter,FMC-A-S-EC,11 5M rotating flange x 3 1/8 5M rotating top,300-4 pocket prep,2-CCL ports,3.266 centers • Multibowl wellhead assy, : 1 —e ■s_ Cactus MBS-2111Valve,WKM-M,2 1/16 5M FE, 13 5/8 3M x 115M,w/4- HWO,DD 2 1/16 5M SSO,prepped for - tr el ' - 9 7 5/8 mandrel hanger,and llI 111 tubing hanger,9 5/8 HPS �,�� 1i_ I � "�""�bottom .' j_ —litt:12�I HPve,WKM-M216 5M FE, o \N 1 r I f . - i 6t ,. Casing head,CIW-WF, " It MI 111 Valve,CIW-F,2 1/16 3M FE, 13 5/8 3M X 13 3/8 casing HWO,AA trim thread bottom,w/2-2 1/16 '2 A .113%1k4' 5M EF0 11'I lit I Ilk.* I1 I-j.:. 111 _p II_ 1' _ 0 0 Dolly Varden Platform Moncla BOP 12/19/2016 4.54' s Hydril o K 13 5/8-5000 lii iii di III 1i1*1!I I11 111 1t1 CIW-uI Fr— I ( 4.67' I H Variable 2 7/8-5rams in r+ I • 13 5/8-5000 H Blind Rams III IU III III ii Choke and Kill valves -a 2 1/16 5M 2.26' I % ! D�^1Mud Cross a:LB D ii • �•' !Jf xI-, 4 1/16 5M EF0 I• x l ji 4U I[JIElT LLU Riser 135/85M FE X 13 5/8 5M FE lit til lil`1 i I Ili III Mill IIIltl Spacer spool 135/85M FE X 115M Iil IIIItIIIIIli • 0 0 0 u o U 00 : 0 : : : : : : : : : r 0 a• a d a a ar ,, ,, „, ,,, . ,-.. . .., 2 - U U U V U U U U U O N N !'/1 Cr l!1 0 rl N K1 N l0 r CO 01 N a a a a a p a a a a a a a a a a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 w u N wiiwii - _ w a, w w � y �c �c 'c 'c 'c 'c c c �c �c Yo t c c c c c ar , , al , n c C j a1 a1 a1 a1 al a) Y al 0 al CU EE E E E o 0 0 o L o s s s r t a m 0- d d d d = = U L L L L L 0. Y Y = U U U U U U U U U u u ,n 2 O. o w U 1 s- o `a ` u O n N O) n 0 L, (0 , o0 U Z Z a LCw Qw a0 F4 , -1- ,, ZO COCD O C O LLw a Q OLL d uJ K L N 0 => 0-11 : CEPID Y mem m CL 0 OQ CO F- CO W H CI. a 0 z r u) z U, O_ Z ~ w C.) z H CO D j me d CO H Ela . C CL 0 Z Z orYOCDH CD F— Z Q It Q Q U) ❑ C W Q oU � _ ZOQOCf) _ O ❑ ❑ 1 • ❑ O W CC H J O Z 1 j M LI) a 16 Y LL Z Q ry CO Z CO Q H J 0 D � _ y U- U • • OO U O U O O O U O O U O U O U O DU O D U 0 s � � � � � 222222222 22222 uuuUUUUUU 0 e-I IN maw a, m � � � � � � � a a a a a p a a a a a a U a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Y U N 4 w _ _ _ _ _ _ 4 w al .0 C C ,-.° C C t O C C C C W C h 2 2 2 2 C C j Cl al a) al al a) al Cl a) o a) EEEEE - - L L L L L L L L L L n 2_ C 2 2 2 2 Y a U S U U L U U U U U U U U U of g Ll.w a ._ O 11 11 N Q) N , CO k U ZZ ��•� ,-...-1a J Q a0 M, 't ZO II H w CC =J O CC ao rJ U- d a w (7 Cr = U ET i— co -. I I I IIli.II�III31!IIW. nim O• Q CO H wHa I a z a H- u) Q J Q z O Z ~ w Z aDz CD — H2 44 a Z — 2 U) Q o rt O U Z. Q Q O—_, Qwzc7 < 0 ° C13 ° tOmZ C J p O O Mill p 0 Z = r • _BOO rn in a� Y LI- ZQ a CD= z 0 a C3 H Z 0 Q u J D U fY 0 i • Moncla Rig 404 BOP Test Procedure Hileorp Alaska, Attachment#1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing(EOT)is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off.Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful,shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV.As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve,or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing(test)joint to lift-threads d) For ESP wells-Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(AOGCC)and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path,test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection, etc.) • ti • • Moncla Rig 404 BOP Test Procedure Hileorp Attachment#1 f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug)in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same-RIH with test plug on joint of tubing. Install a pump-in sub w/test line plus an open TIW or lower Kelly valve in top of test joint w/open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump-install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure,close valve on pump manifold to trap pressure and read same with chart recorder(test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close 1st valve on standpipe manifold,close valves 1, 2, 10 on choke manifold and close the annular preventer, open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and 2,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer,close safety valve and open IBOP on test joint, close outside valve on kill side of mud cross, open 1st valve of standpipe, close valves 3,4&9 on choke manifold,open valves 1&2 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing,and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close inside valve/open outside valve on kill side of mud cross,close valves 5&6/open valves 3&4 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. e) Close manual and super choke/open valves 5&6 on choke manifold. Pressure up to—1200 psi and bleed off 200—300#s recording change and stabilization. If passes after 5 minutes, bleed of pressure back to tank. f) Close HCR(outside valve on choke side of mud cross), open manual&super choke. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. • fi • • Moncla Rig 404 BOP Test Procedure ftileorp A�aska,Lt�G Attachment#1 g) Close inside valve/open outside valve(HCR) on choke side of mud cross. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Ensure all pressure is bled off-open pipe rams and pull test joint leaving test plug/2-way check in place. Close blind rams and attach test line to valve 10 on choke manifold, close valve 7&8/open valve 10 on choke manifold. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves(TIW or Lower Kelly Valve)and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure(+/-3,000 psi). Note: Make sure the electric pump is turned to "Auto", not"Manual"so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. . 0 le _ _ p / 0 / > r2 Q _ e 2a & § 2E 0o ■ \ / 2k ° = < � E ® • 2 Sf ) U) \ { 1 0- / f TD- O. = 0 \ JD RI > = fa� k /ƒ a & _ § .\ n C) ■ 5 \ 7L. 2 k k S COsy>- 77 J ° o G£ % -0 a \ > Q I- ..o k / \ E LL CL E C) $ \• \ C o = e CO \ as 0 S C) CO k / � k L. E ) ° _ 2 0 k \ / 0 . � / 6. S0 a. \ ƒ / § �• � 2 c c � # Cl) ca \ / c I � CD > $ C § > ± a 2 g * 0 a. \� co Ci rNL < / \ o 0. � E % / cip� Q q 2 � & ■ / \ 0 C) 0 g o U) 7 i. � w Co Vi 0 X / � CO it C.) r .. = a E E0 \ / •_ .a c »o u a_ 0 • / CO<< a. • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, March 29, 2017 11:24 AM To: Dan Marlowe Subject: RE: D-16RD(PTD 180-110) RWO Dan, Alternate calculation using SITP of 1220psi seems reasonable as you just had a 3 week shut-in on the well and is approved under 20 AAC 25.280(b)(4). The use of Moncla 404 BOPE system (3 preventer BOPE) is approved. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Dan Marlowe [mailto:dmarlowe@hilcorp.com] Sent:Wednesday, March 29,2017 10:46 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Subject: RE: D-16RD(PTD 180-110) RWO Sir Hilcorp requests an alternate pressure calculation per 20 AAC 25.280(b)(4) Unfortunately,We just had a extended shutdown on the dolly for compression and heat exchanger work. Maximum SITP during this 21 day shut-in was 1220 psig Well: D-16RD G Desc:Gas Lift Permit to drill: 1801100 Admin Approval: N/A API:50-733-20183-01-00 Date Range:01/01/2017-03/29/2017 Date Tubing IA OA OOA Oil Production Gas Production 3/29/2017 0 0 3/28/2017 180 1080 25 0 43.8 48.31 3/27/2017 175 1100 20 0 55.4 15.37 3/26/2017 160 1100 20 0 73.74 1.65 3/25/2017 1200 1200 15 0 5.33 0.27 1 • II 3/24/2017 1220 1200 15 0 0 0 V23/2017 1220 1200 15 0 0 0 3/22/2017 1220 1200 15 0 0 0 3/21/2017 1220 1200 15 0 0 0 3/20/2017 1220 1200 15 0 0 0 3/19/2017 1220 1200 15 0 0 0 3/18/2017 1220 1200 15 0 0 0 3/17/2017 1210 1210 15 0 0 0 3/16/2017 1200 1200 15 0 0 0 3/15/2017 1200 1200 10 0 0 0 3/14/2017 1200 1200 10 0 0 0 3/13/2017 1200 1200 10 0 0 0 3/12/2017 1200 1200 10 0 0 0 3/11/2017 1200 1200 10 0 0 0 3/10/2017 1200 1200 10 0 0 0 3/9/2017 1200 1200 10 0 0 0 3/8/2017 1200 1200 10 0 0 0 3/7/2017 1200 1200 10 0 0 0 3/6/2017 1200 1220 10 0 26.22 0 3/5/2017 1100 1080 10 2 56.09 29.07 3/4/2017 220 1100 10 2 79.78 59.71 From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Wednesday, March 29, 2017 9:57 AM To: Dan Marlowe<dmarlowe@hilcorp.com> Subject: D-16RD(PTD 180-110) RWO Dan, Per 20 AAC 25.035 (e)you are required to have 4 preventers on BOPE stack if MASP is 3000 psi or higher. You calculated MASP of 3023 psi for the well on the sundry application to pull tubing and run GL/ESP combo. The Moncla rig has only 3 preventers(annular, 2 rams). Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 1 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). 2 STATE OF ALASKA _ • AL ,CA OIL AND GAS CONSERVATION COM,...JSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown LI Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Other. Install ESP/Convert to Producer Plug for Redd! ❑ Perforate New Pool 0 Repair Well IIIRe-enterSusp Well El 12_1'7-5/8"Liner 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development❑ Exploratory❑ 180-110 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service 0 6.API Number: Anchorage,AK 99503 50-733-20183-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0017579 Trading Bay Unit/D-16RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Hemlock Oil and Middle Kenai G Oil Pools 11.Present Well Condition Summary: RECEIVED Total Depth measured 14,645 feet Plugs measured 14,510&14,600 fee true vertical 10,306 feet Junk measured 13,504 feet !!.1N 0 9 7015 Effective Depth measured 14,510 feet Packer measured 12,877 feet ri+rtC true vertical 10,160 feet true vertical 9,011 feet - !l, �t11 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,554' 13-3/8" 2,554' 2,347' 3,090 psi 1,540 psi Intermediate 9,955' 9-5/8" 9,955' 7,095' 5,750 psi 3,090 psi Liner 9,692' 7-5/8" 9,692' 6,923' 6,890 psi 4,790 psi Liner 4,955' 7" 14,644' 10,265' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet SCANNED JUL U 9 .0 True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80 12,954'(MD) 9,063'(ND) 12,877'(MD) 349'(MD) Packers and SSSV(type,measured and true vertical depth) r Hyd Set Liner Top Pkr 9,011'(ND) SSSV 349'(ND) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 2,473'-2,500' Treatment descriptions including volumes used and final pressure: Pumped 10 bbls suspending agent and 66 bbls Class"G"(340 sxs)down 13-3/8"casing taking returns up 9-5/8"casing to repair a 9-5/8"x 13-3/8"casing leak. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 148 300 Subsequent to operation: 31 136 1501 980 140 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Developments Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil El Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-031 Contact Ted Kramer Email tkramer(a�hilcorp.com Printed Name d Kramer Title Sr.Operations Engineer Signature ''Cr‘-, Phone (907)777-8420 Date 6/9/2015 Form 10-404 Revised 5/2015 d, 6 '.''S Submit Original Only McArthur River Field, TBU - - n SCHEMATIC Well: D-16RD As Completed: 05/17/2015 Hilcorp Alaska,LLC CASING DETAIL 1 ;, Size Wt Grade Conn ID Top Btm 13-3/8" 61 K-55 Seal Lock 12.515 Surf 2,553.63' f 40 N-80 Butt 8.835 Surf 5,514.04' P INIP A 9-5/8" 43.5 N-80 Butt 8.775 5,514.04' 8,059.53' 47 N-80 Butt 8.681 8,059.53' 9,955' wis 7-5/8" 29.7 L-80 SLIJ-II 6.875 Surf 9,692' DV - - „1 Collar 7" 29 N-80 Butt 6.184 9,689' 14,644' !l 6,822' Tubing Detail 3-1/2" 9.3 L-80 Supermax Surf 12,954' i 3 Jewelry Details aga,' No (MD) OD ID Item Top of ata , 2-14 Hanger Liner - 9,689' 1 349' 5.380 2.810 SSSV NA 2 2,356' 4.800 2.991 SFO-1 GLM w/BK-2 latches 3 4,125' 4.800 2.991 SF0-1 GLM w/BK-2 latches 4 5,228' 4.800 2.991 SFO-1 GLM w/BK-2 latches ND S 6,003' 4.800 - 2.991 SF0-1 GLM w/BK-2 latches 6 6,778' 4.800 2.991 SF0-1 GLM w/BK-2 latches 1lor 7 _ 7,556' 4.800 2.991 SF0-1 GLM w/BK-2 latches 8 8,302' 4.800 2.991 SF0-1 GLM w/BK-2 latches 9 9,046' 4.800 2.991 SF0-1 GLM w/BK-2 latches a 10 9,824' 4.800 2.991 SF0-1 GLM w/BK-2 latches 11 10,565' 4.800 2.991 SF0-1 GLM w/BK-2 latches 12 11,303' 4.800 2.991 SF0-1 GLM w/BK-2 latches imit 13 12,112' 4.800 2.991 SFO-1 GLM w/BK-2 latches 14 12,790 4.800 2.991 SFO-1 GLM w/BK-2 latches 15 15 12,877' 5.870 4.000 7"Hydraulic Set Liner Top Packer 16 12,919' 4.500 2.813 X Nipple(EUE 8rd) its16 17 12,954' 4.230 3.500 Supermax WLEG 17 18 13,504' (Junk)Otis WD 7"x4"packer w/5'seal bore ext. G-3 G-4 G-5 18 OP HK-1 PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(ND) Btm(ND) Amt SPF Date G-3 13,091' 13,120' 9,157' 9,177' 29' 4.5"TCP 05/10/15 HK-4 G-4 13,190' 13,207' 9,225' 9,237' 17' 4.5"TCP 05/10/15 G-5 13,354' 13,364' _ 9,338' _ 9,345' 10' 4.5"TCP 05/10/15 G-5 13,440' 13,450' 9,398' 9,405' 10' 4.5"TCP 05/10/15 HK-1 13,632' 13,688' 9,532' 9,572' 56 8 _ 10/13/1984 HK-4 13,985' 14,000' 9,777' 9,788' 15 8 4/27/1981 14,510'HOWCOi..,„;,,y ;' '6%5_„;''. HK-4 14,015' 14,036' 9,798' 9,812' 21 8 4/27/1981 HK-4 14,052' 14,066' 9,823' 9,832' 14 8 4/27/1981 Updated: 06/08/15 by JLL Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-16RD 50-733-20183-01 180-110 3/25/2015 5/17/2015 Daily Operations: 03/25/15-Wednesday INSTALL BPV,NO SUCCESS.ATTEMPT TO CLEAN AND TAP PROFILE, NO SUCCESS. REVISED PLAN TO UTILIZE WIRELINE PLUG TO SECURE WELL FOR NIPPLE DOWN OF THE TREE AND NIPPLE UP OF BOP AND TESTING SAME.DISCUSSED SAME WITH MR.SCHWARTZ WITH AOGCC 3/25/15 AND FOLLOWED UP WITH EMAIL ON 3/26/15.MONITOR WELL AND ASSIST WELDER REPAIR BEAVER SLIDE WHILE ASSISTING CRANE OP MOVE MISC EQUIP.SPOT SLICK LINE EQUIP AND INSTALL BEAVER SLIDE. PJSM AND JSA WITH ALL ESSENTIAL PERSONEL ON SLICK LINE OPERATIONS. RIG UP SLICK LINE,TEST LUBICATOR TO 2500 PSI,TEST GOOD. RIH WITH 2.75" GAUGE TAG @ 2,027'SLM.POOH WITH SAME. RIH WITH 3.5"AD-2 STOP.SET SAME @ 100'SLM.POOH. RIH WITH 3.5"D&D PACK OFF PLUG,SET SAME @ 98'SLM.POOH. RIH WITH A-A STOP,SET SAME @ 97'SLM. PRESSURE TEST PLUG TO 2500 PSI,NO SUCCESS. PLUG LEAKING(LOST 125 PSI IN 5 MINS). RIH WITH SLICK LINE,TAP DOWN ON PLUG AND POOH. PRESSURE TEST PLUG TO 2500 PSI. TEST GOOD. RIG DOWN SLICK LINE. NIPPLE DOWN DRY HOLE(BOLTS FROZE UP IN FLANGE HAD TROUBLE REMOVING SAME). PREPARE WELL HEAD(ALL THREADS GONE FROM HANGER). INSTALL RISER TO WELL BAY.STACK BOP'S&HCRS VALVES.TIGHTEN ALL BREAKS.INSTALL ACCUM LINES.FUNCTION TEST ALL RAMS.R/U FLOW LINE&CENTER STACK. 03/26/15-Thursday RIG UP TEST EQUIPMENT AND FILL UP BOP STACK.WITNESS WAIVED BY MR.JIM REGG,AOGCC ON MARCH 23,2015 @ 5:39 PM. TEST BLIND RAMS AS PER AOGCC AND HILCORP SPECS/250 PSI LOW AND 2500 PSI HIGH. MADE UP SPEAR ASSY ON 3.5 PH6.TEST JT DRESSED WITH 2.93"GRAPPLE. ATTEMPT TO SPEAR HANGER NO SUCCESS. MAKE UP BUMPER JAR TO SPEAR ASSY. SPEAR HANGER. HAD TO WORK PIPE DOWN,TOOK SEVERAL ATTEMPTS. TEST 11"5M BOPS AND SURFACE EQUIPMENT TO 250 PSI LOW AND 2500 PSI HIGH.PERFORMED KOOMEY DRILL. RIG DOWN TEST EQUIPMENT.BACK OUT HANGER PINS. UNSEAT HANGER AT 75K.PULL UP TO 86K.TBG STRING APPEARED TO STILL BE INTACT.SET HANGER BACK IN WELL HEAD AND SHUCK SPEAR. INSTALL POLLUTION PAN ON BOP STACK. R/U SLICKLINE,TEST LUBRICATOR TO 2500 PSI(OK).RIG WI EQUALIZING PRONG TO 100'WLM.POOH.RIH W/3"GS TO 100'WLM.POOH W/AA STOP.RIH W/3"GS TO 100'WLM.POOH.WI PACK OFF PLUG.RIH WI 3"GS TO 100'WLM.POOH WI AD-2 STOP. RIH W/PARRAFIN SCRAPPER FOUND PARRAFIN @ 620'WLM.WORK DOWN TO 4,000'WLM.POOH. RIH WI 2.75"GAUGE RING WORK DOWN TO 4,460'WLM.POOH. START PUMPING 1 BPM AND RIH W/2.75"GAUGE RING WORKD DOWN TO 5,080'WLM. POOH. R/U E-LINE,TEST LUBRICATOR TO 2500 PSI(OK).RIH WI 2.5"JET CUTTER SET DOWN AT 5,077'WLM._, 03/27/15-Friday CO_NT POOH.E-LINE CUTTER FIRED.RIG DOWN E-LINE. PICK UP AND MAKE UP 3.5 SPEAR ASSY DRESSED WITH 2.983"GRAPPLE. SPEAR HANGER.BLEED OFF JAR.UNSEAT HANGER @ 50K.CONT PULL HANGER TO FLOOR.FILL HOLE 4 BBLS.MONTIOR WELL (STATIC). SHUCK SPEAR FROM HANGER AND LAY OUT SAME.LAY DOWN HANGER. PICK UP SINGLE JT OF 3.5 PH6.MAKEUP CROSS OVERS.RIG UP STRIPPER HEAD.RUN BACK IN HOLE.MAKE UP TIW AND CIRC HOSE. BREAK CIRC PUMP 10 BBLS TO WELL CLEAN TANK @ 1BPM 60 PSI. CIRC TAKING RETURNS OVER SHAKERS @ 2 BPM 100 PSI INCREASING RATE TO 2.5 BPM MAX GAS 600 UNITS.CONT CIRC THRU GAS BUSTER @ 3 BPM W/170 PSI MAX GAS 950 UNITS WI 219 BBLS PUMPED.SHUT DOWN PUMP. LINE UP ON WELL. CLEAN TANK.CLEAN TANK PUMP MAKING NOISE,SWAP OVER SENDING RETURNS TO PRODUCTION HEADER @ 1 BPM.9 5/8 CSG PRESSURE=110 PSI,13 3/8 CSG PRESSURE=250 PSI.TOTAL PUMPED 326 BBLS. CIRC THRU GAS BUSTER @ 3 BPM 160 PSI.MONITOR RETURNS.PUMPED 102 BBLS(NO GAS). LINE UP CIRC TAKING RETURNS THRU BELL NIPPLE OVER SHAKERS @ 5 BPM 270 PSI. CONT CIRC 7 BPM 460 PSI GAS UNITS 55,91 SPM, 13 3/8"CSG=165 PSI,9 5/8"CSG=15 PSI. CONT CIRC 9 BPM 744 PSI GAS UNITS 79, 117 SPM,13 3/8"CSG=160 PSI,9 5/8"CSG=15 PSI. CONT CIRC 9 BPM 760 PSI GAS UNITS 196, 117 SPM,13 3/8"CSG=160 PSI,9 5/8" CSG=15 PSI. PUMPED 736 BBLS. RIG DOWN STRIPPER HEAD. POOH WI 3.5"9.3#N-80 ASL PROD TBG LAYING OUT ON PIPE RACK AND STRAPPING SAME.ESTIMATED TOTAL 150 JTS/4,200'LAID OUT AT REPORT TIME. Hilcorp Alaska, LLC ►►i►corp Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-16RD 50-733-20183-01 180-110 3/25/2015 5/17/2015 Daily Operations: 03/28/15-Saturday Service rig and perform safety and compliance check. Continue pooh w/3.5"ASL N-80,9.2#Production Tbg.Recovered 174 jts and one cut piece total 5,049 ft. CLEAR AND CLEAN RIG FLOOR AND PIPE RACK AND CHANGE OUT PHE.BREAK DOWN SPEAR ASSY. MAKE UP WEAR BUSHING ASSY AND INSTALL WEAR BUSHING IN WELL HEAD. GATHER TOOLS AND EQUIP TO RIG FLOOR. MAKE UP 8.125" OVER SHOT DRESSED 3.5",PUMP OUT SUB(3000 PSI),BUMPER&OIL JAR,(4)4-3/4" DRILL COLLARS&ACCL. RIH 8.125 OVER SHOT ASSY ON 3.5 PH6 WORKSTRING 100 FPM TO 1,415'DPM . TOTAL(20 STDS). RIG UP STRIPPER HEAD AND CIRC EQUIP. CIRC BOTTOMS UP @ 5 BPM 296 PSI. NO GAS,SMALL AMOUNT OF OIL ACROSS SHAKER,NO SOLIDS.PUMPED TOTAL 113 BBL FLUID WT 9.0 PPG. 13-3/8"CSG PRESS=155 PSI. RIG DOWN CIRC EQUIP AND STRIPPER HEAD. CONT TIH @ 80 FPM TO 3,283'DPM.TOTAL(50 SIDS). R/U STRIPPER HEAD. CIRC BOTTOMS UP @ 3,283'DPM.5 BPM 350 PSI 13 3/8"CSG 155 PSI 9 5/8"CSG 15 PSI.CHANGE OVER TO PZ9.CONT CIRC @ 9 BPM 980 PSI 13 3/8" 160 PSI 9 5/8" 15 PSI. R/D STRIPPER HEAD. CONT TIH TO 5,085' DPM.P/UP TO CHECK UP WT.WE HAD OVER PULL UPTO 140K W/S WT.W/BHA 56 K(FISH IN HOLE 67K).W/S&FISH=123K+BLK=131K WT. DROPPED OFF TO 100K.RACK BACK.P/U SINGLE,SLACK OFF SINGLE TO 36K DOWN P/UP TI 115K LET JARS HIT P/UP TO 150K.WT DROPPED BACK OFF TO 110K P/U 115K HIT JARS PULLED UP TO 165K W DROPPED TO 100K. SLACK 1 JT HOOKED UP CIRC HOSE PICKED UP TO PICK UP WT OF 92K ATTEMPT TO CIRC.PUMPED DOWN TBG 1/2 BPM GOT RETURNS.SHUT DOWN.LINE UP TO PUMP THRU GASBUSTER. ATTEMPT TO CIRC.PRESSURED UP TO 100 PSI.SHUT DOWN.PRESSURE HELD.BLEED OFF AT PUMP.CHECK SURFACE LINE UP,ALL GOOD.OPEN ANNULAR PUMP DOWN TBG WITH 1 BPM. ATTEMPT TO BLOW RUTURE DISC.PRESSURED UP TO 415 PSI.PIPE JUMPED WHILE PRESSURING UP.TBG WT DROPPED FROM 92K TO 37K&PRESSURE ON 13 3/8"INCREASED FROM 150 PSI TO 250 PSI& ROCKED BACK&FORTH FROM 250 TO 180 PSI&HELD 180 PSI. WITH PUMP OFF,BLEED OFF TBG FROM 415 PSI TO 0 PSI.PRESSURE ON 13 3/8" BLED FROM 180 PSI TO 150 PSI.POOH W/1 SINGLE 100K TO 80K.HOLE SWABING WHILE PICKING UP.LAY DOWN SINGLE. MONTOR WELL. R/U EXPRO SLICKLINE,TEST LUB 2500 PSI(OK).RIH WITH 2" LEAD IMPRESSION BLOCK TAGGED AT 4,820'WLM. POOH. RIH WITH 2.25"IMPRESSION BLOCK TAGGED AT 4,820'WLM. POOH.R/D SAME. R/U EXPRO ELECTRIC LINE,TEST LUB 2500 PSI (OK). FOUND THAT THE THREADS ON THE TBG PUNCH WAS THE WRONG THREAD.WAITING ON NEW TBG PUNCH TO ARRIVE AT LOCATION. 03/29/15-Sunday WAITING ON BLAST SLEEVE.R/U LUBRICATOR TEST TO 2500 PSI (OK). M/U AND RIH W/1 11/16"TBG PUNCH W/WT BAR CCL.TOTAL LENGTH 17.3'. 12 SHOT 1/2" PENETRATION,DID NOT SEE ANY OBSTRUCTION @ PREVIOUS SLICK LINE TAG @ 4,820'.CONT RIH TAGGED @ 4,987'(IN OVERSHOT).ATTEMPT TO P/U TOOL,STUCK.WORK SAME TO 2000#LINE,PULL AND HELD TOOLS CAME FREE PULL BACK UP TO 4,792'WLM. PRESS W/S TO 100 PSI PUNCH HOLES IN WORK STRING F/4,792'TO 4,796'PRESSURE BLEED F/100 PSI TO 0 PSI AND GOT RETURNS.R/D E-LINE. BREAK CIRC W/RETURNS OVER SHAKER @ 5 BPM 575 PSI W/13 3/8"CSG PRESSURE @ 150 PSI MAX GAS 1149 UNITS. CIRC THROUGH GAS BUSTER @ 2 BPM W/115 PSI MAX GAS 250 UNITS 13 3/8"CSG PRESSURE 190 PSI,9 5/8"CSG PRESSURE 55 PSI MAX GAS ON BTM UP 600 UNITS.CONT CIRC UNTIL GAS @ 75 UNITS. LINE UP AND CIRC @ 5 BPM 475 PSI, 13 3/8"CSG @ 160 PSI GA @ 110 UNITS.SMALL AMOUNTS OF SILT PUMPED.TOTAL 355 BBLS. RIG DOWN CIRC EQUIPMENT AND STRIPPER HEAD. L/D SINGLE AND POOH 8 STDS SLOW DUE TO SWABBING.CONT POOH @ MODERATE SPEED. P/U 60K S/0 40K NO DRAG. FINISH POOH W/3.5" PH6 WORKSTRING. POOH W/OVERSHOT BHA(NO MARKING ON OVERSHOT AND NO RECOVERY). M/U 3.5" MILL GUIDE, LOWER EXT,8.125" 0/5 BOWL,XO,PUMP OUT SUB,OIL AND BUMPER JARS,4 DRILL COLLARS,ACC JARS,X0,W/ 3.5"GRAPPLE BHA. RIH W/74 STDS OF 3.5" PH6 WORKSTRING. LAY DOWN 10 JTS OF 3.5"PH6 FOR WASHING.CONT RIH W/5 STDS FROM DERRICK TO 4,776'DPM(DRIFTING PIPE FROM DERRICK). RIG UP STRIPPER HEAD AND POWER SWIVEL. CIRC BOTTOMS UP STAGING PUMP UP TO 8 BPM,1050 PSI, 13 3/8"CSG PRESSURE 155 PSI,9 5/8"CSG PRESSURE 15 PSI,GAS UNITS 226. START WASHING DOWN F/4,776'DPM.CURRENT DEPTH AT REPORT TIME 4,806'DPM. Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-16RD 50-733-20183-01 180-110 3/25/2015 5/17/2015 Daily Operations: 03/30/15-Monday WASH AND CIRC AS NEEDED F/4,806'TO 5,103'TAGGING FISH @ 5,103'WASHING @ 8 BPM 1100 PSI MAX GAS UNITS(MAX PRESSURE 160 PSI ON 13 3/8). SPACE OUT W/PUPS TO DRESS OFF FISH. DRESS OFF FISH @ 5,103'AND LATCH SAME AND VERIFY LATCHED @ 105K,53K OVER UP WT. RIG DOWN POWER SWIVEL AND SPACE OUT. JARRING @ 105K STAGING UP TO 190K NO MOVEMENT ON FISH. RIG UP SLICKLINE,TEST LUB 2500 PSI (OK).RIH W/2.25" PARAFFIN SCRATCHER TAG AT 5,245'.UNABLE TO CONT IN HOLE.START PUMPING 1 BPM AND WORK DOWN TO 5,249'WOM. RIG W/2 1/8" PUMP BAILER AND 2 1/8"DRIVE DOWN BAILER SEVERAL TRIPS AND BAIL FROM 5,249'TO 5,663'RETRIEVING 1/2 TO 1 GALLON OF FINE SCALE AND SMALL PIECES OF METAL EVERY TRIP.POOH TO INSPECT BAILER. 03/31/15-Tuesday BAILING ON 3.5"INJECTION TBG F/5,662'TO 6,633'SWAPPING BAILERS FROM 2 1/8 PUMP BAILER TO A 2 1/8 DRIVE DOWN BAILER AND A 2" PUMP BAILER. RECOVERED 22 1/2 GALLONS OF SOLIDS.TOTAL FOOTAGE MADE 1,530'. CONT BAILING ON 3.5"INJECTION TBG F/6,633'TO 7,264'SWAPPING BAILERS FROM 2 1/8 PUMP BAILER TO A 2 1/8 DRIVE DOWN BAILER AND A 2" PUMP BAILER. RECOVERED 3 GALLONS OF SOLIDS AND ONE PIECE OF METAL.TOTAL RECOVERY 25 1/2 GALLONS.TOTAL FOOTAGE MADE 2,161'.RIG DOWN EXPRO. RIG UP EXPRO E-LINE,TEST LUB TO 2500 PSI(OK).RIH W/WT BAR,CCL,1 11/16 TBG PUNCH, 12 SHOT, 1/2" PENETRATION,MADE PUNCH FROM 7,212'TO 7,215'. 04/01/15-Wednesday CONT RIH W/CCL,1-11/16"TBG PUNCH 12 SHOT 1/2"PENETRATION. LOG ON DEPTH PERF TBG F/7,212'ELM POOH. RIH WI CCL,2" RTC ON E-LINE. RIH LOG ON DEPTH PICK UP TO 25K OVER STRING WT FIRE CUTTER AT 7,208' ELM. NO WT LOSS.POOH,CUTTER FIRED. SLACK OFF TO 25K JAR ON FISH @ 105K(25K OVER)PIPE FREE. RIG DOWN E-LINE. BREAK CIRC,PUMP DOWN TBG @ 7.5 BPM 1030 PSI TAKING RETURNS ACROSS SHAKER.MAX GAS 800 UNITS.SHUT DOWN PUMP.LINE UP TO GAS BUSTER.TOTAL PUMPED 450 BBLS. CONT CIRC THROUGH GAS BUSTER @ 2 BPM 115 PSI.MAX GAS 1250 UNITS.TOTAL PUMPED 60 BBLS. LINE UP TAKE RETURNS ACROSS SHAKER @ 5 BPM 500 PSI.MAX GAS 1500 UNITS.TOTAL PUMPED 150 BBLS. CIRC TO WELL CLEAN TANK @ 2.5 BPM 150 PSI. TOTAL PUMPED 187 BBLS. CONT CIRC ACROSS SHAKERS @ 7.5 BPM 1030 PSI.MAX GAS 1600 UNITS.TOTAL PUMPED 450 BBLS. CIRC THROUGH GAS BUSTER @ 2.5 BPM 165 PSI TOTAL PUMPED 130 BBLS.MAX GAS 800 UNITS. CIRC ACROSS SHAKERS @ 5 BPM 520 PSI. PUMPED TOTAL 320 BBLS.MAX GAS 600 UNITS. CIRC BOTTOMS UP @ 8 BPM 1150 PSI TAKING RETURNS ACROSS SHAKERS.TOTAL PUMPED 400 BBLS.MAX PRESSURE PUT ON 13-3/8"CSG FROM 0600 TO 1800 HRS=200PSI. RIG DOWN STRIPPER HEAD WHILE MONITOR WELL(STATIC). BLOW DOWN LINES AND POOH W/44 STDS OF 3.5"PH6 WORKSTRING. LAYDOWN 70 JTS OF 3.5"PH6 WORKSTRING TO WASH WITH. POOH WITH OVERSHOT BHA(RECOVERED FISH). POOH WITH 3.5"ASL N-80 9.3#PROD TBG LAYING ON PIPE RACK AND STRAPPING SAME.NORM=0(RECOVERED 75 JTS AND 2 CUT PIECES TOTAL LENGTH 2,167.59). CLEAN RIG FLOOR AND PIPE RACK.ESTIMATED TOP OF FISH IS @ 7,220'DPM.NO LOSSES IN FLUID,13-3/8"CSG PRESSURE 150 PSI. • Hilcorp Alaska, LLC Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-16RD 50-733-20183-01 180-110 3/25/2015 5/17/2015 Daily Operations: 04/02/15-Thursday CONT CLEANING RIG AND PIPE RACK WHILE SERVICING RIG AND PERFORM SAFETY AND COMPLIANCE CHECK. MAKE UP LANDING JT. PULL WEAR BUSHING L/O SAME. MAKE UP TEST JT LAND OUT TEST PLUG.RIG UP TEST MANIFOLD. ATTEMPT TO FILL BOP STACK WI FIW.NO SUCCESS.FLUID LEAKING OUT CSG VALVE.PULL TEST PLUG AND INSPECT SAME(OK). LINE UP ON KILL LINE AND WASH OUT BOP STACK AND LAND TEST PLUG. ATTEMPT TO FILL BOP STACK.STILL LEAKING OUT CSG VALVE.CLOSE CSG VALVE FILL BOP STACK W/FIW.CLOSE HYDRIL.OPEN CSG VALVE AND PRESSURE UP TO 800 PSI AND SEATED TEST PLUG. TEST 11"5M BOPS AND SURFACE EQUIPMENT 250 PSI LOW AND 2500 PSI HIGH.PERFORMED KOOMEY DRILL.BOP TEST WITNESS WAIVED BY JIM REGG 3.31.15 10:13AM BY EMAIL.CHECKED GAS DETECTION AND ALARMS. PULL TEST PLUG.MADE UP WEAR BUSHING ASSY AND INSTALL WEAR BUSHING IN WELL HEAD.LAY OUT LANDING JT. SHUCK TBG FROM OVERSHOT ASSY ON PIPE RACK. REDRESS OVERSHOT WI 3.5" GRAPPLE. CLEAN AND SERVICE RIG WHILE WAITING ON DRILLING JARS TO ARRIVE BY BOAT. MAKE UP 8.125"MILL GUIDE,LOWER EXT,OVERSHOT BOWL,XOVER,PUMP OUT SUB,4 DRILL COLLARS,DRILING JARS AND XOVER BHA. START TIH W/3.5"PH6 WORKSTING SET DOWN @ 2,491'DPM.ROTATE PIPE AND FELL THROUGH.CONT TIH TO 5,079'DPM. RIG UP STRIPPER HEAD AND POWER SWIVEL. CIRC BOTTOMS UP @ 8 BPM 1158 PSI,13 3/8"CSG PRESSURE 155 PSI,9 5/8"CSG PRESSURE 15 PSI,130 UNITS OF GAS. START WASHING DOWN F/5,079'TO 5,174'DPM @ 8 BPM,1158 PSI,13 3/8 CSG PRESSURE 155 PSI,9 5/8 CSG PRESSURE 15 PSI, MAX GAS 100 UNITS. 04/03/15-Friday CONT WASHING F/5,172'TO 6,289'PUMPING @ 9 BPM 1420 PSI,1-2K WOB,9.0 PPG FLUID IN AND OUT CIRC AS NEEDED.13 3/8" CSG PRESSURE 160 PSI. CHANGE OUT CROSSOVER ON POWER SWIVEL.FOUND THREADS GAULED ON XOVER BACK TO WORK STRING.CHANGED OUT SAME AND FOUND THREADS IN JT GAULDED.MAKE UP PUP JT IN SAME AND POOH AND LAYDOWN BAD JT. CONT WASHING DOWN F/6,289'TO 6,507'PUMPING 9 BPM 1683 PSI,WOB 0, 7.3 FPM,13 3/8 CSG PRESSURE 160 PSI,9 5/8 CSG PRESSURE 15 PSI. CONT WASHING DOWN F/6,507'TO 7,163'DPM 9 BPM,1788 PSI,WOB 0,7.3 FPM,13 3/8"CSG PRESSURE 160 PSI, 9 5/8"CSG PRESSURE 15 PSI. 04/04/15-Saturday CONT WASHING DOWN FROM 7,163'DPM @ 9 BPM 1800 PSI,1-2K WOB,7FPM. TAG TOP OF FISH @ 7,265'DPM.P/U OFF FISH,CIRC OUT GAS 220 UNITS @ 9 BPM 1800 PSI. SPACE OUT S/0 SET 10K DOWN ON FISH.P/U 10K OVER TO VERIFY GRAPPLE LATCHED. RIG DOWN STRIPPER HEAD. S/O TO 454K.COCK JARS,P/U JARS @ 140-150K,PULL UP TO 215K JARRED 34 TIMES.WORKED FISH UP HOLE 110'.INITIAL WT=215K P/U WT=133K. RIG UP STRIPPER HEAD AND CIRC EQUIP. CIRC BOTTOMS UP @ 9 BPM 1990 PSI MAX GAS 361 UNITS. RIG DOWN CIRC EQUIPMENT AND STRIPPER HEAD. POOH WI 3.5"PH6 WORKSTRING BHA AND FISH.MAX 13 3/8"CSG PRESSURE 160 PSI. FINISH POOH W/3.5"PH6 WORKSTRING AND OVERSHOT BHA. LAYDOWN 3.5"N-80 9.3#ASL PROD TBG,FINDING HOLES IN TBG AND TBG PLUGGED UP WITH SCALE.HAVING TO BREAK OUT SLOW,CHECKING FOR TRAPPED PRESSURE AND DRAINING JT INTO DRUM. MCCOY TONGS BROKE.CHANGE OUT WITH FOSTER TONGS,FOSTER TONGS UNABLE TO BREAK CONNECTIONS. RIG DOWN FOSTER TONGS AND RIG UP BACK UP SET OF MCCOY TONGS. . • Hilcorp Alaska, LLC IIiIeoip Alaska.LU: Well Operations Summary Well Name API Number Well Permit Number •Start Date End Date D-16RD 50-733-20183-01 180-110 3/25/2015 5/17/2015 Daily Operations: 04/05/15-Sunday CONT POOH LAYING DOWN 3.5"ASL TBG USING 131 TONGS TO BREAK DUE TO TORQUE AND BACK OUT WITH MCCOY POWER TONGS. RIG UP CIRC EQUIPMENT DUE TO OIL AND GAS IN TBG.CIRC DOWN TBG TAKING RETURNS THROUGH FLOWLINE ACROSS SHAKER ICP 1.5 BPM,110 PSI, FCP 2.5 BPM 300 PSI.TOTAL PUMPED 75BBLS. CONT POOH LAYING DOWN 3.5"ASL TBG. ATTEMPT TO CIRC DOWN TBG ON JT 137 DUE TO OIL,NO SUCCESS. PUMPED.25 BBLS 390 PSI. CONT POOH LAYING DOWN 3.5"ASL TBG RUNNING 1 INCH WATER HOSE DOWN EACH JT 30'AND WASH OUT OIL BEFORE PULLING. ATTEMPT TO BREAK OUT JT 144 HAD TRAPPED PRESSURE. SHUT DOWN MONITOR WELL.CLEAN RIG WHILE WAITING ON HOT TAP TO ARRIVE. HOT TAP 1T 144 BLEED OFF PRESSURE CONT POOH. ATTEMPT TO BACK OUT JT 145 PRESSURE ON TBG.TAP TBG AND BLEED OFF GAS.PRESSURE ON TBG=275 PSI,MAX PRESSURE ON 13 3/8"CSG=160 PSI. CONT BLEEDING DOWN TBG GETTING BACK OIL AND GAS.PRESSURE BLED TO 2 PSI THEN INCREASED TO 65 PSI GETTING GAS BACK WITH VERY LITTLE FLUID.CONT BLEEDING PRESSURE OFF TBG.PRESSURE WENT TO 30 PSI GETTING OIL BACK ON TBG. 04/06/15-Monday CONT BLEED OFF 3.5"ASL TBG. 13-3/8"CSG PRESSURE 130 PSI,TBG PRESSURE 40 PSI.RIG UP WATER FLOOD TO HOT TAP BLEED LINE. PRESSURE UP TO 200 PSI,RECORD TBG AND CSG PRESSURE HOURLY/10AM CSG=130 PSI&TBG=60 P51/11AM CSG=140 PSI& TBG=60 PSI/12PM CSG=140 PSI&TBG=70 PSI/1PM CSG=145 PSI&TBG=70 P51/2PM CSG=135 PSI&TBG=60 PSI/3PM CSG=110 PSI &TBG=40 PSI.CONT BLEED DOWN CSG TBG. 13-3/8"CSG=50 PSI&TBG=5-10 PSI.REMOVE HOT TAP INSTALL PATCH OVER TAP HOLE AND RUN JT IN HOLE. RIH W/8 JTS 3.5" PH6 WORKSTING PICKING UP FROM PIPE RACK 13-3/8"CSG=50 PSI. RIG UP SLICKLINE,TEST LUBRICATOR 2500 PSI (OK).RIH W/2"PUMP BAILER SWAPPING OUT W/2-1/8" DRIVE DOWN BAILER AND BAIL FROM 252'WLM TO 272'WLM(HOLDING 100 PSI BACK PRESSURE). RIH W/1.80"GAUGE RING CHISEL,TAG @ 270'WLM(UNABLE TO MAKE ANY HOLE). RIH W/2" PUMP BAILER BAIL FROM 270'TO 271'WLM. RIH W/1.75" PUMP BAILER TO 271'WLM (UNABLE TO MAKE ANY HOLE). RIH W/2-1/4" PARAFFIN SCRATCHER TO 271"WLM(UNABLE TO MAKE HOLE). RIH W/1.62"IMPRESSION BLOCK TO 271'WLM. 04/07/15-Tuesday RIH W/1.75"BROACH.TAG @ 271',TAG SOLID.JAR DOWN ON OBSTRUCTION,POOH. RIH W/1.77" BROACH CHISEL.TAG @ 271' SLM,TAG SOLID.JAR ON OBSTRUCITON,POOH. ADD 5'WT BAR TO TOOL STRING AND SCRATCH BAR.RIH TAG @ 271'SLM TAG SOLID.POOH. MAKE UP 5'PARAFIN SCRATCHER.RIH TAG @ 271'SLM,PRESSURE UP ON TBG TO 125 PSI. MAKE UP 2"X 8'BAILER. RIH TAG SEVERAL TIMES @ 271'SLM.POOH.BAILER EMPTY. RIH W/2"X 8'BAILER.TAG @ 271'SLM.WORK BAILER. POOH.BAILER EMPTY. MAKE UP DUMP BAILER.FILL WITH ACID.RIH TAG @ 271'SLM DUMP ACID.PRESSURE UP TO 100 PSI ON TBG.POOH. MAKE 5'CHISEL.RIH TAG @ 271'SLM.WORK CHISEL.INCREASE TBG PRESSURE TO 150 PSI.POOH. RIG DOWN SLICKLINE. BLEED TBG TO 0 PSI. TIH W/2.5"ASL INJECTION TBG ON 3.5" PH6 WORKSTRING FILLING PIPE EVERY 25 STANDS. FINISH TIH W/3.5"ASL INJECTION TBG ON 3.5" PH6 WORKSTRING FILLING PIPE EVERY 25 STANDS(PIPE STARTED FILLING UP ON ITS OWN @ 10,042'DPM). PICK UP 3.5" PH6 WORKSTRING FROM PIPE RACK DRIFTING AND STRAPPING SAME.P/U 150K S/0 87K,TAG @ 13,482'DPM. SPOT WIRELINE EQUIPMENT. Hilcorp Alaska, LLC Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-16RD 50-733-20183-01 180-110 3/25/2015 5/17/2015 Daily Operations: 04/08/15-Wednesday RIG UP E-LINE,TEST LUBRICATOR 2500 PSI (OK). RIG WI 1-9/16"TBG PUNCH 12 SHOT 1/2"PENETRATION TAG @ 11,488'ELM. PERFORATED TBG F/11,478'-11,481'ELM,POOH. MAKE UP 2"RTC.RIH TAG @ 11,488'ELM.PULL UP TO 11,477'ELM,POOH. LAY DOWN LUBRICATOR. LATCH ON TO PIPE PICK UP,UNABLE TO VERIFY PIPE CUT DUE TO HOLE DRAG. PULL UP TO 160K,10K OVER. SET SLIPS.PICK UP LUBRICATOR,TEST TO 2500 PSI (TEST GOOD). RIH WI WT BAR AND 1-11/16"CCL TAG @ 11,485'ELM.LOG UP TO VERIFY TBG CUT. RIG DOWN E-LINE. RIG UP STRIPPER HEAD AND CIRC EQUIP. BREAK CIRC,PUMP DOWN TBG TANKING RETURNS THROUGH FLOWLINE WITH PUMPING 3 BPM 435 PSI.PUMPED 10 BBLS.MAX GAS 1200 PSI.SHUT DOWN PUMP.LINE UP TO GAS BUSTER. CONT CIRC TAKING REUTRNS THROUGH GAS BUSTER ICP=1.5 BPM @ 140 PSI,FCP=3 BPM 13-3/8 CSG PRESSURE 200 PSI GAS @ 165 UNITS. CONT CIRC THROUGH GAS BUSTER 2.9 BPM @ 430 PSI 13-3/8"CSG PRESSURE 195 PSI. SHUTDOWN PUMP.SWAP TO TBAY DUE TO HELICOPTER LANDING.PUMP 3 BPM @ 467 PSI 13-3/8 CSG PRESSURE 155 PSI. SWAP BACK TO RIG TANK.CONT PUMP THROUGH GAS BUSTER @ 2.9 BPM 515 PSI,13-3/8 PRESSURE 225 PSI,GAS WENT FROM 866 UNITS TO 1910 UNITS. START PUMPING TO WELL CLEAN TANK.GOT OIL BACK @ 603 BBLS STOPPED GETTING OIL BACK @ 656 BBLS(TOTAL OF 53 BBLS)PUMPING 3 BPM @ 503 PSI 13-3/8 PRESSURE 165 PSI. SWAP BACK TO GAS BUSTER 2.9 BPM @ 480 PSI GAS 1104 UNITS 13-3/8 PRESSURE 195 PSI. SWAP TO FLOWLINE 5 BPM @ 1156 PSI GAS @ 165 UNITS 13-3/8 PRESSURE 140 PSI. SWAP TO PZ9 PUMP 8.8 BM 2753 PSI GAS @ 48 UNITS 13-3/8 PRESSURE 150 PSI.CIRC BOTTOMS UP.GAS WENT TO 0 UNITS AND 13-3/8 DROPPED TO 130 PSI. RIG DOWN CIRC HOSE.WELL U-TUBING.PUMP 8 BBLS 9.8#SLUG. BLOW DOWN LINES AND RIG DOWN STRIPPER HEAD.MONITOR WELL.WELL STATIC. PICK UP OFF BOTTOM 174K PICKED UP 30'FELL BCK TO 150K.CONT POOH TO LINER TOP. MONITOR WELL.STATIC.CONT POOH W/3.5" PH6 WORKSTRING. 04/09/15-Thursday CONT POOH W/3.5" PH6 WORKSTRING AND 3.5"ASL INJ TBG. LAY DOWN PLUGGED JT.1 CLAMP MISSING.NO PRESSURE TRAPPED IN PIPE.RIG UP CIRC EQUIPMENT BREAK CIRC.CIRC SURFACE TO SURFACE @ 2 BPM 130 PSI DOWN TBG TAKING RETURNS THROUGH FLOWLINE ACROSS SHAKERS MAX GAS=420 UNITS, 13-3/8"CSG PRESSURE=130 PSI.TOTAL PUMPED 142 BBLS. MONITOR WELL WHILE RIG DOWN CIRC EQUIPMENT.WELL STATIC.FLUID WT=9 PPG (HEAVY). POOH W/3.5"ASL INJ TBG BREAKING WITH BJ TONGS DUE TO TORQUE.BACK OUT W/MCCOY TONGS. RECOVERED TOTAL OF 13,444'OF PIPE,PLUS SEAL ASSY,TAIL PIPE AND MULE SHOE. PULL WEAR BUSHING. RUN 2 STANDS 4-3/4"DRILL COLLARS IN HOLE MAKE UP TEST PLUG AND TEST JT. LAND TEST PLUG.SEAT TEST PLUG WITH MUD PUMP.RIG UP TEST MANIFOLD TO WATER FLOOD. TEST BOP STACK.CIRC MANIFOLD,FLOOR SAFETY VALVE FOR 3.5"PIPE TO 250 PSI LOW 2500 PSI HIGH.TEST FROM MAIN STATION AND FUNCTION TEST REMOTE. PERFORM ACCUM DRILL.TEST WITNESS WAIVED BY JIM REGG 4/7/2015 @ 15:17 BY EMAIL. RIG DOWN WATER FLOOD AND TEST EQUIPMENT.PULL TEST PLUG. RIG DOWN SAME. POOH W/4-3/4" DRILL COLLARS. INSTALL WEAR BUSHING. SLIP AND CUT 86FT OF DRILL LINE.RETEST CROWN 0 MATIC(OK). MAKE UP 6"TAPERED MILL, BUMPER AND OIL JARS,4 DRILL COLLARS,XOVER,BHA AND START RIH W/109 JTS OF 3.5" PH6 WORKSTRING. 04/10/15-Friday CONT TIH W/6"TAPERED MILL ASSY ON 3.5"PH6 WORKSTRING TO 3,560' DPM. MAKE UP 8.5"STRING MILL ASSY. CONT TIH W/6" TAPERED MILL ASSY ON 3.5" PH6 WORKSTRING FROM 3,650'DPM TO 11,675'DPM. CONT TIH F/11,675' DPM.P/U 3.5" PH6 FROM PIPE RACK DRIFT AND TALLY SAME.TAG @ 12,951'DPM.SET 8K DOWN. RIG UP STRIPPER HEAD AND POWER SWIVEL. WASH DOWN F/12,951'TO 12,982'DPM.AT 8 BPM 2753 PSI GAS 50 UNITS,13-3/8"CSG PRESSURE 135 PSI,9-5/8"CSG PRESSURE 15 PSI START CIRC BOTTOMS UP. SHUT DOWN CIRC DUE TO OIL.START PUMPING TO WELL CLEAN TANK.HAD TO SHUT DOWN DUE TO WELL CLEAN PLUGGING OFF.SWAP OVER TO TBAY PUMPING 1/2 BPM 135 PSI,13-3/8" PRESSURE 240 PSI,9-5/8" PRESSURE 115 PSI, (TOTAL PUMPED 150 BBLS TO TBAY MAX GAS 1015 UNITS). SWAP TO RIG TANKS CONT CIRC 4 BPM 1085 PSI, 13-3/8"PRESSURE 135 PSI,9-5/8" PRESSURE 15 PSI. WASH DOWN F/12,982'TO 13,200' DPM.STOPPING EVERY 1T AND CIRC 10 MIN,8 BPM 2853 PSI,13- 3/8"PRESSURE 135 PSI,9-5/8"PRESSURE 15 PSI. CIRC BOTTOMS UP 8 BPM 2853 PSI,13-3/8" PRESSURE 135 PSI,9-5/8" PRESSURE 15 PSI.RIG DOWN POWER SWIVEL AND STRIPPER HEAD AND PUMP 8 BBL SLUG DUE TO PIPE U-TUBING. START POOH W/3.5" PH6 WORKSTRING,MAX DRAG 230K,WORK JT DOWN TO 50-60K DRAG,DRAG WENT BACK UP TO 209K,WORK JT BACK DOWN TO FREE UP DRAG.CONT POOH SLOW DRAG AT 176K. • Hilcorp Alaska, LLC ►,�►.,,,N:,►:� ,:.�.►.►.�: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-16RD 50-733-20183-01 180-110 3/25/2015 5/17/2015 Daily Operations: 04/11/15-Saturday RIG DOWN FOSTER TONGS.RIG UP MCCOY POWER TONGS. CONT POOH W/3.5"PH6 WORKSTRING AND 6"TAPERED MILL AND 8.5" STRING MIL ASSY. LAY OUT 8.5"STRING MILL ASSY. CONT POOH W/3.5" PH6 WORKSTRING AND 6"TAPERED MILL ASSY. SECURE WELL DUE TO PLATFORM FIRE DRILL.MUSTER FOR ROLL CALL. CONT POOH W/3.5" PH6 WORKSTRING AND 6"TAPERED MILL ASSY. LAY OUT 6"TAPERED MILL ASSY. CLEAR AND CLEAN RIG FLOOR AND PREP TO RIG UP E-LINE. REMOVE FLOW LINE AND INSTALL SHOOT NIPPLE FLANGE AND HELD PRE JOB SAFETY MEETING.RIG UP E-LINE.TEST SHOOT NIPPLE TO 500 PSI(OK). RIH WI 2 1/4" CENTRALIZER,2 3/4"CALIPER,2 1/4"CENTRALIZER,1-11/16"GAMMA RAY,1-11/16"XTU,1-11/16"W/B,1-7/16" ROPE SOCKET TO 13,100'WLM. POOH LOGGING OUT TO INSPECT CSG TO 2,469'WLM 50 FPM(TOOL GOT HUNG UP). ATTEMPT TO WORK TOOL FREE. LINE UP AND PRESSURE UP ON 9 5/8"CSG TO 47 PSI, 13 3/8"CSG PRESSURE 190 PSI UNABLE TO WORK TOOL FREE.BLEED PRESSURE OFF AND CONT WORKING TOOL ATTEMPTING TO WORK FREE. 04/12/15-Sunday CONT TRYING TO WORK FREE CALIPER ASSY @ 2,469'WLM.CLEAN RIG AND PERFORM GENERAL RIG MAINTENANCE WHILE WAITING ON E-LINE TOOLS TO ARRIVE FROM OSK. HELD PRE JOB SAFETY MEETING AND JSA WITH ALL ESSENTIAL PERSONNEL ON RIGGING UP AND RIH STRIPPING OVER WIRE LINE. RIG DOWN SHOOT NIPPLE,LAY OUT LUBRICATOR.INSTALL T-BAR ON E-LINE AND SPLICE E- LINE.HANG WIRE LINE SHEAVE IN CROWN. MAKE UP 4.75"OD OVERSHOT ASSY DRESSED WITH 1-7/16"GRAPPLE.MAKE UP 2-1/8" WIRE LINE STRIPPING ASSY(MODEL CM42-500). RIH W/4.75"OVERSHOT ASSY ON 3.5" PH6 WORKSTRING,STRIPPING OVER WIRE LINE. CONT STRIPPING OVER E-LINE WIRE TO 1,640' DPM.STARTED TAKING WT ON WIRE.WORK FREE.POOH WI 40'CUT WIRE AND REHEAD WIRE.CONT RIH W/SAME TO 2,168'DPM STARTED TAKING WT ON WIRE WORKED FREE CONT TO 2,194'DPM.STARTED TAKING WT HAD TO WORK FREE.CONT TIH TO 2,353'DPM.TOOK WT HAD TO WORK FREE.TAG @ 2,469' DPM.WORKED UP AND DOWN SEVERAL TIMES TO ATTEMPT TO LATCH FISH (FISH TOO LIGHT TO TELL IF LATCHED). RIG UP T-BAR ON BAILS.PICK UP 2-3K AND PULL WIRE FROM ROPE SOCKET.RIG DOWN SHEAVE FROM CROWN AND PULL E-LINE WIRE FROM 3.5"PH6 WORKSTRING. POOH W/3.5"PH6 WORKSTRING AND 4.75"OVERSHOT BHA(NO RECOVERY). REMOVE 2.5'SPOOL AND INSTALL SPOOL FOR FLOW LINE AND HOOK UP FLOW LINE. MAKE UP 4.75"OVERSHOT W/1-7/16"GRAPPLE AND 8"GUIDE BHA AND START TIH W/3.5"PH6 WORKSTRING. 04/13/15-Monday CONT TIH W/SERIES 150 OVERSHOT DRESSED WI 1-7/16"GRAPPLE AND 8"GUIDE ON 3.5 PH6 WORKSTRING.TAG @ 2,491'DPM.SET 12K DOWN P/U TO 40K,6K OVER P/U WT DROPPED BACK TO 34K. POOH W/3.5" PH6 WORKSTRING OVERSHOT BHA(NO FISH). WORK BHA AND LAY OUT SAME. MAKE UP 8"OVERSHOT ASSY DRESSED W/1-7/16"GRAPPLE 3' EXTENSION AND CUT LIP GUIDE. TIH W/ASSY ON 3.5" PH6 WORKSTRING TAG @ 2,491'DPM.SET 10K DOWN P/U WITH NO OVER PULL. RIG UP POWER SWIVEL. SET DOWN ON FISH W/2K WOB.ATTEMPT TO WORK OVER FISH BY ROTATING TORQUE=4500 FOR 6'STALLING OUT @ 7K.ATTEMPT TO PULL FISH FREE WI 20K OVER STRING WT AND SLIPPING OFF.CONT ATTEMPTING TO WORK OVER FISH 4 MORE TIMES WITH SAME RESULTS.SET DOWN ON FISH WI 1-2K ROTATE WT FELL OFF CONT SLACKING OFF AFTER 2'.CONT RIH TO 2,511' DPM W/NO WOB. RIG DOWN POWER SWIVEL. POOH W/3.5"PH6 WORKSTRING OVERSHOT BHA(NO FISH).WORK BHA L/0 SAME INSPECT GRAPPLE. MAKE UP 8"OVERSHOT ASSY DRESSED W/1-7/16"GRAPPLE 3'EXT AND CUT LIP GUIDE. TIH W/8"OVERSHOT ASSY. CONT TIH W/ 3.5"PH6 WORKSTRING SET DOWN @ 2,491' DPM.ROTATE PIPE AND FELL OFF.CONT TIH 70 FPM.P/U 113K,S/0 59K TAG @ 9,695' DPM SET 5K DOWN. RIG UP POWER SWIVEL. P/U 114K,S/O 61K,SET DOWN 2K ROTATE AND WORK DOWN TO 5K PICK UP 116K. RIG DOWN POWER SWIVEL. POOH W/3.5" PH6 WORKSTRING 100 FPM EASY ON AND OFF SLIPS. Hilcorp Alaska, LLC 1Iilcorp Well Operations Summary Well Name API Number Well Permit Number Start Date _End Date D-16RD 50-733-20183-01 180-110 3/25/2015 5/17/2015 Daily Operations: 04/14/15-Tuesday CONT POOH WI 3.5" PH6 WORKSTRING AND 8"OVERSHOT ASSY AND POSSIBLE FISH. WORK BHA LAY DOWN JARS AND OVERSHOT (NO FISH RECOVERED). CLEAR RIG FLOOR.REMOVE BELL NIPPLE.INSTALL SPACER SPOOL AND SHOOT NIPPLE. ASSIST CRANE CREW MOVE MISC EQUIPMENT AND SPOT EQUIP IN PLACE. HELD PRE JOB SAFETY MEETING AND JSA AND MAKE UP TOOL STRING. TEST SHOOT NIPPLE TO 500 PSI.TEST GOOD.RIH WI 4.5"BELL GUIDE DRESSED W/1-3/8"JDC TAG @ 13,115'SLM. POOH WI SLICK LINE WITH 125LBS OF OVER PULL(NO FISH). RIG DOWN AND SHOOT NIPPLE.NIPPLE UP BELL NIPPLE AND HOOK UP FLOW LINE. MAKE UP RUNNING TOOL AND 7"RETREIVABLE BRIDGE PLUG AND TIH. CONT RIH W/3.5" PH6 WORKSTRING AND 7" RETREIVABLE BRIDGE PLUG TURNING 2 ROUNDS TO THE RIGHT EVERY 10 STDS. RIG UP STRIPPER HEAD AND POWER SWIVEL. P/U 116K,S/O 60K,SET 7" RETREIVABLE BRIDGE PLUG @ 9,812'DPM.PUT 4 TURNS TO THE LEFT,PIPE SLIPPED AND TORQUE FELL OFF. SLACK OFF RBP,SET 40K DOWN.P/U PLUG DRAGGING UP HOLE.TOP SLIPS NOT SETTING.ATTEMPT TO WORK UP AND DOWN SETTING 30K DOWN.ATTEMPT TO TURN TO THE LEFT,NOTICE THAT WORK STRING WAS BACKING OUT SOME WHERE IN WORK STRING.TURN TO THE RIGHT AND RELEASE 7"RBP. RIG DOWN STRIPPER HEAD AND POWER SWIVEL. POOH W/3.5" PH6 WORKSTRING CHECKING EACH CONNECTION FOR PROPER TORQUE. 04/15/15-Wednesday SERVICE RIG AND SAFETY COMPLIANCE CHECK. POOH WI 3.5" PH6 WORKSTRING AND RETRIEVABLE BRIDGE PLUG. INSPECT RETRIEVABLE BRIDGE PLUG AND CLEAN RIG FLOOR. TIH W/7"RBP AND 3.5" PH6 WORKSTRING,1 MIN PER STAND CHECKING EACH BREAK FOR CORRECT TORQUE. PICK UP POWER SWIVEL @ 9,648'DPM. TIH W/SINGLES FROM V-DOOR MAKING CONNECTION WI POWER SWIVEL TO 9,813'DPM. SET PLUG AS PER PROCEDURE @ 9,813' DPM,RELEASED FROM SAME. LAY DOWN 10'PUP JT AND R/U STRIPPER HEAD. BROKE CIRC LONG WAY AND CIRC 735 BBLS TOTAL @ 10 BBLS 2850 PSI. P/U 31'AND DUMPED 9 SACKS OF 30/50 SAND DOWN TBG. PUMPED 72 BBLS @ 1/2-1 BPM LONG WAY TO SPOT SAND ON TOP OF PLUG. R/D POWER SWIVEL AND STRIPPER RUBBER. WELL STARTED TO U-TUBE. R/U CIRC EQUIP AND PUMPED 10 BBLS LONG WAY(WELL STATIC). POOH W/3.5" PH6 WORKSTRING AND BP SETTING TOOL. 04/16/15-Thursday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT POOH W/3-1/2"PH6 AND SETTING TOOL. M/U 8.433"RTTS AND TIH W/3-1/2" PH6 TO 3,620'DPM. SET RTTS.R/U TEST EQUIPMENT AND PRESSURE DOWN TBG TO 1500 PSI IN 500# INCREMENTS AND HOLD FOR 30 MINS ON CHART."OK". R/D TESTING EQUIPMENT. POOH TO 2,618' DPM. SET RTTS. R/U TEST EQUIPMENT AND PRESSURE DOWN TBG TO 1500 PSI IN 500# INCREMENTS AND HOLD FOR 30 MINS ON CHART."NO SUCCESS"BLED OFF 250 PSI IN 20 MINS. TIH TO 3,000'DPM AND SET RTTS. PRESSURE UP DOWN TBG TO 1500 PSI FOR 15 MINS ON CHART."OK". POOH TO 2,691'DPM. SET RTTS. R/U TEST EQUIP&PRESSURE UP DWN TBG T/1500 PSI &HELD FOR 15 MINS ON CHART"OK". POOH TO 2,567'DPM. SET RTTS.R/U TEST EQUIP&PRESSURE UP DWN TBG T/1500 PSI &HELD FOR 15 MINS ON CHART"OK". ATTEMPT TO PULL(2)STNDS W/NO SUCCESS.AT 2,501' DPM. HAD 20K OVER PULL.R/B(1)STND&P/U 10' PUP JNT. SET RTTS @ 2,514'DPM.R/U TEST EQUIP& PRESSURE UP DWN TBG T/500 PSI&HELD FOR 15 MINS ON CHART"OK". ATTEMPT TO PRESSURE UP ON CSG W/NO SUCCESS.AT 75 PSI PRESSURE ON 13-3/8" INCREASED 75 PSI.R/D TEST EQUIPMENT.POOH TO 2,473' DPM WI 30K OVER PULL @ 2,500'DPM. PRESSURE UP ON CSG T/775 PSI &HELD FOR 5 MINS"OK".INDICATION OF HOLE IN 9-5/8" BETWEEN 2,473'-2,500'DPM. POOH T/ 1,260'DPM. P/U STORM VALVE&M/U SAME ON JS PKR.L/D SAME. P/U 3-1/2" MULE SHOE&TIH W/SAME.(55 STNDS=30K). BLED/MONITORED 13-3/8"CSG. F/125 PSI-T/90 PSI.BLED BACK OIL/GAS. SET RTTS.R/U TEST EQUIP&PRESSURE UP ON CSG T/500 PSI&HELD FOR 15 MINS ON CHART"OK". POOH W/3-1/2"PH6. Hilcorp Alaska, LLC HicorpAlaska.LH.0 Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-16RD 50-733-20183-01 180-110 3/25/2015 5/17/2015 Daily Operations: 04/17/15-Friday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT BLEEDING OFF 13 3/8"CSG.RECEIVING 8.5#FLUID. SHUT IN 13-3/8"CSG AND MONITOR SAME WHILE BUILDING SURFACE VOLUME OF 9.0#F.I.W SICP=30 PSI. DISPLACE WELL DOWN 9-5/8"CSG TAKING RETURNS THRU 13-3/8"TO RIG CHOKE TO GAS BUSTER @3 BPM 150 PSI UNTIL RETURNS CLEAN AND 9.0 AT SURFACE.TOTAL PUMPED=210 BBLS.MAX GAS=1600 UNITS. SHUT IN WELL AND MONITOR PRESSURE SICP=0. PERFORM BUBBLE TEST ON 13-3/8"CSG "OK". M/U STORM PKR AND TIH.SET STORM PKR AT 300'.PUSH/PULL TEST SAME.TEST PACKER TO 500 PSI."OK".POOH W/3-1/2 PH6. M/U WEAR BUSHING PULLING TOOL.TIH AND PULL WEARBUSHING.LAY DOWN SAME. R/D FLOOR PLATES AND BEAMS.R/D FLOW LINE AND POLLUTION PANS. REMOVE FLOW CROSS FOR FLOW LINE.BLEED DOWN ACCUMULATOR AND PREP TO N/D BOPS. N/D 11"X 5M BOPS,WING VALVES, FLOW CROSS AND RISERS. N/D TBG HEAD. N/U DBL STUDDED ADAPTER&NEW TBG HEADASSIST CAMERON REP TEST TBG HEAD VOID TO 3000 PSI,AND TBG HEAD TO 3000 PSI."OK". N/U 11"X 5M BOP'S,RISER,FLOW CROSS,AND . WING VALVES. 04/18/15-Saturday FINISH N/U 11"X 5M BOPS AND SECURE SAME. INSTALL POLLUTION PANS UNDER RIG FLOOR.HOOK UP FLOW LINE AND INSTALL FLOOR PLATES ON RIG FLOOR. M/U TEST PLUG AND SET SAME,"NO SUCCESS". POOH W/TEST PLUG AND INSPECT SAME.REPLACE TEST RUBBERS AND LAND TEST PLUG,"NO SUCCESS".PULL TEST PLUG AND REPLACE TEST RUBBERS.LAND TEST PLUG AND SEAT WITH RIG MUD PUMP. TEST 11"X 5M BOPS AND SURFACE EQUIPMENT AS PER HILCORP AND AOGCC SPECS.250 LOW/2500 HIGH ON CHART DATED 4-18-2015.PERFORM KOOMEY TEST.TESTED FROM REMOTE AND FUNCTION MAIN.AOGCC WITNESS WAIVED BY JIM REGG ON APRIL 16,2015 @ 12:19 PM. R/D TEST EQUIPMENT AND TIH TO 300'. ENGAGE STORM PACKER AND RELEASE SAME. POOH W/3-1/2"PH6 AND STORM PACKER. SERVICE RIG&PERFORM SAFETY COMPLIANCE CHECKS. CONT'TO POOH W/3-1/2"PH6 &L/D MULE SHOE. P/U STORM PACKER ASSY&B/D SAME. P/U WEAR BUSHING R/R TOOL&LANDING JNT.RIH&SET WEAR BUSHING.L/D R/R TOOL&LANDING JNT.SWAPPED P.H.E.&PREP TO P/U BHA. P/U&M/U 7.38"POLISH MILL,8.25"TOP DRESS MILL,8.5"STRING MILL,BUMPER/OIL JARS,(4)4-3/4"DC'S.TOTAL LENGTH=160.43'. TIH W/3-1/2" PH6&MILL ASSY.P/U=37K, S/O=34 TAGGED @ 2,491'DPM.SET 6K DOWN. P/U POWER SWIVEL&R/U SAME. ROT/WORK THRU TIGHT SPOT TO 2,525'DPM SLOWLY.TORQUE 1500 FT/LBS W/NO WOB OR OVERPULL. R/D POWER&L/D SAME. CONT'TO TIH W/3-1/2"PH6&MILL ASSY. P/U=45K,S/0=36K. TAGGED @ 3,606'DPM SET 8K DOWN&TOOK 5K OVER TO POOH.P/U POWER SWIVEL&R/U SAME. ROT/WORK THRU TIGHT SPOT F/3,606'-T/3,649'DPM.TORQUE=5000-7000 FT/LBS W/5K DRAG UP/DWN.WORKED UP/DOWN UNTIL TORQUE DOWN TO 3K,W/2K DRAG. R/D POWER&L/D SAME. CONT'TO TIH W/3-1/2" PH6&MILL ASSY. 04/19/15-Sunday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT TIH W/3-1/2"PH6 AND MILLING ASS'Y.TO 9,684' DPM. P/U AND R/U POWER SWIVEL.MAKE CONNECTION. EST DRILLING PARAMETERS,PUMPING 3 BPM 300 PSI,RPM=75,TORQ=6-7K.CONT TIH AND TAG TOP OF LINER AT 9,695'DPM.DRESS OFF SAME. WEIGHT UP SURFACE VOLUME TO 9.5#F.I.W. DISPLACE WELL W/9.5#F.I.W.@ 2 BPM 250 PSI,UNTIL 9.5#AT SURFACE.TOTAL PUMPED=750 BBLS. MIX AND DISPLACE WELL(1)HOLE VOLUME W/9.5#F.I.W.WITH 1%CFS- 520 @ 3PM 350 PSI. CONT'TO DISPLACE WELL W/9.5 PPG F.I.W.W/1%CFS-520 ADDITIVE @ 3 BPM 300 PSI. PUMPED 720 BBLS. BUILD&PUMP 8 BBLS OF 10 PPG FIW SLUG DUE TO U-TUBING.CHASED W/3 BBLS OF 9.5 PPG FIW. R/D POWER SWIVEL&L/D SAME. POOH W/3-1/2"PH6&MILL ASSY.WORKED UP/DOWN THRU TIGHT SPOT @ 3,606'DPM W/5K OVER&4K WOB.WORKED UP/DOWN THRU SPOT @ 2,491'DPM W/NO OVERPULL&NO WOB. B/D MILL ASSY&L/D SAME. SPOT HALIBURTON CEMENT UNIT/EQUIPMENT&R/U SAME. HELD JSA W/CREW&ESSENTIAL PERSONNEL ON CEMENT JOB. HALIBURTON TEST LINES TO 2000 PSI AND START MIXING CEMENT JOB. , • Hilcorp Alaska, LLC Ilileorp Alaska.LL(. Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-16RD 50-733-20183-01 180-110 3/25/2015 5/17/2015 Daily Operations: 04/20/15-Monday HALIBURTON MIX&PUMP 10 BBLS OF SUSPENDING AGENT,66 BBLS OF 15.8#CLASS"G"CEMENT(340 SX)DOWN 13-3/8"CSG THRU CSG VALVE TAKING RETURNS UP 9-5/8"CSG BACK TO RIG TANKS.DISPLACED SURFACE LINES&SHUT CSG VALVE.PRESSURED UP ON 9-5/8"CSG TO 500 PSI AND SHUT-IN. SERVICE RIG AND PERFORM SAFEY COMPLIANCE CHECKS. BLED-OFF 9-5/8"&13-3/8"CSG. FLOW CHECK WELL"STATIC". P/U OIL JARS,&(4)4-3/4" DC'S.TOTAL BHA LENGTH =160.57. TIH W/3-1/2" PH6&TANDEM MILL ASSY T/2,650'DPM.WORKED THRU TIGHT SPOT @ 2,491'DPM (WOB=2K,AND NO OVER PULL). R/U CIRC EQUIPMENT&REV/OUT 48 BBLS @ 3 BPM 200 PSI (NO PRESSURE ON 13-3/8")RECOVERED A TRACE OF GREEN CMT @ BTMS UP. CONT'TO TIH W/3-1/2" PH6&TANDEM MILL ASSY T/4,517'DPM.WORKED THRU TIGHT SPOT @ 3,606'DPM(WOB=5K,AND OVERPULL=8K). R/U CIRC EQUIPMENT&REV/OUT 122 BBLS @ 3 BPM W/280 PSI.RECOVERED A TRACE OF CEMENT&SUSPENDING AGENT. CONT'TO TIH W/ 3-1/2" PH6&TANDEM MILL ASSY T/9,695'DPM(T.O.L.)P/U=115K,S/0=55K. R/U CIRC EQUIPMENT&REV/OUT 170 BBLS @ 3 BPM 385 PSI UNTIL RETURNS CLEAN.RECOVERED OIL,GUNK AND SCALE. MIX/PUMP 5 BBL 10#FIW SLUG&CHASE W/9.5#FIW.R/D CIRC EQUIPMENT. POOH W/3-1/2"PH6&TANDEM MILL ASSY.(P/U=115K OFF BTM). SERVICE RIG AND SAFEY COMPLIANCE CHECK. PERFORM GENERAL RIG MAINTENANCE AND HOUSEKEEPING.SLIP AND CUT 96'DRILL LINE.RESET C-O-M AND CHECK W/DRILL LINE "OK". P/U AND M/U TANDEM MILL ASSY WHILE WAITING ON CEMENT. 04/21/15-Tuesday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT POOH W/3-1/2"PH6 AND TANDEM MILL ASS'Y. BREAKDOWN AND LAYDOWN MILL ASS'Y. M/U PULLING TOOL AND PULL WEAR BUSHING. C/O PIPE RAMS TO CSG RAMS.SET TEST PLUG.R/U TEST JT AND EQUIPMENT AND TEST 7-518'CSG,RAMS,250 LOW/,2500 HIGH AS PERaHILCORP AND AOGCC SPECS ON CHART DATED 4-21-2015. R/D TEST EQUIPMENT AND PULL TEST PLUG. SPOT WEATHERFORD CASING EQUIPMENT IN PLACE AND R/U SAME. HELD PRE JOB � SAFETY MEETING AND REVIEW JSA WITH ALL ESSENTIAL PERSONNEL ON P/U CSG. M/U MULE SHOE AND FLOAT COLLAR ASSY TO 7- 5/8"CSG AND TIH W/SAME PICKING UP CSG OUT OF V-DOOR.STRAP AND RABBIT SAME.FILLING 7-5/8"CSG EVERY(5)JOINTS. TAGGED @ 2,482'DPM(P/U=61K,S/0=55K).MADE SEVERAL ATTEMPTS TO WORK THRU TIGHT SPOT BY SETTING 5K-30K DWN W/ NO OVER PULL.TURNED PIPE 180 DEGREES&ATTEMPT TO WORK THRU W/NO SUCCESS. SET 35K DOWN.P/U&TURNED PIPE A 1/4 TURN.SET 38K DOWN WORKED UP TO P/U WEIGHT&WORKED DWN THRU SPOT. CONT'TO P/U 7-5/8"CSG OUT OF V-DOOR&TIH W/SAME.STRAP&DRIFT EACH JNT.P/U 7-5/8"CSG EVERY(5)JNTS OR AS NEEDED DUE TO WEIGHT/DRAG. WORK THRU TIGHT SPOT @ 3,606' DPM (P/U=84K,S/0=65K).TOOK 7K TO PUSH THRU TIGHT SPOT W/5K OVERPULL. CONT'TO P/U 7-5/8"CSG OUT OF V-DOOR&TIH W/SAME.STRAP&DRIFT EACH JNT.P/U 7-5/8"CSG EVERY(5)JNTS OR AS NEEDED DUE TO WEIGHT/DRAG.113 JTS RAN.DEPTH=4,843'. 04/22/15-Wednesday ASSIST CRANE CREW OFF-LOAD 7-5/8"CSG FROM M/V DISCOVERY.UN-BUNDLE AND LAY OUT SAME. CONT P/U 7-5/8"CSG OUT OF V-DOOR AND TIH.RABBIT AND STRAP SAME.TAG AT 9,692'DPM W/20K DOWN. LAYDOWN(2) ITS 7-5/8"CSG AND FIGURE SPACE OUT. P/U SPACE OUT PUP JNTS.(14.62',7.65',5.62'),HANGER,&LANDING JNT.S/O&LAND HGR.BTMOF CSG @ 9_,692,90'DPM. R/U CIRC EQUIP. PUMPED 230 BBLS(8.5#)@ 2 BPM TO FILL CSG.L/U&PUMPED DWN CSG TAKING RETURNS OVER SHAKERS. PUMPED 25 BBLS(8.5#)@ 2 BPM W/350 PSI UNTIL RETURNS CLEAR OF SOLIDS. L/U TO TAKE RETURNS TO WELL CLEAN TANK.CONT' TO DISPLACE WELL W/8.5#FIW.PUMPED 290 BBLS @ 3 BPM 400 PSI. SPOT HALIBURTON CEMENT EQUIPMENT&R/U SAME. LOAD BTM&TOP PLUGS IN CEMENT HEAD.M/U CEMENT HEAD&R/U MANIFOLD ON SAME. GATHERED CREW&ESSENTIAL PERSONNEL FOR JSA ON CEMENT JOB. CONT'TO R/U MISC HOSES FOR CEMENT JOB. HALIBURTON MIX/PUMP 20 BBLS F.I.W.DROP LEAD PLUG @ 05:20. BEGIN PUMPING 155 BBLS 12.5#"G"GRADE CEMENT(LEAD),20 BBLS 15.8#CEMENT(TAIL).DROPPED PLUG&DISPLACE W/444 BBLS OF F.I.W.SENDING ALL RETURNS THRU PRODUCTION HEADER. Hilcorp Alaska, LLC Llilcorp.Al.,.ka,,L,_(: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-16RD 50-733-20183-01 180-110 3/25/2015 5/17/2015 Daily Operations: 04/23/15-Thursday HALIBURTON CONTINUE DISPLACING CEMENT W/444 BBLS OF 8.5#F.I.W.SENDING ALL RETURNS THRU PRODUCTION HEADER. CEMENT AT SURFACE AFTER DISPLACING 436 BBLS.FAILED TO BUMP PLUG.FINAL CIRCULATING PRESSURE=1820 PSI,BLEED OFF PUMP PRESSURE TO CHECK FLOAT.FLOAT,NOT,HOLDING._PRESSURE UP TO 1820 PSI AND.SHUT IN_SAME. PUMP ACROSS HANGER W/RIG PUMP&WASH OFF SAME.PUMP THRU PROD.HEADER TO CLEAN OUT SAME TOTAL=100 BBLS. ASSIST HALIBURTON FINISH RIGGING DOWN EQUIPMENT. PERFORM GENERAL RIG MAINTENANCE AND HOUSEKEEPING WHILE WAITING ON CEMENT. BLED-OFF 7-5/8"CSG.SICP=52 PSI.BLED TO ZERO. R/D CEMENT HEAD&MANIFOLDS.B/O LANDING JNT&L/D SAME.SWAPPED TO 3-1/2" P.H.E.R/U&BLEW DOWN TOP OF HANGER W/AIR THRU 9-5/8"CSG VALVE TO ENSURE NO CEMENT IN HANGER FLUTES. P/U 3-1/2" TEST JNT&M/U PACK-OFF R/R TOOL ON SAME.ATTEMPT TO SET&TEST PACK-OFF W/NO SUCCESS.ASSIST CAMERON REP TROUBLESHOOT SAME.PACK-OFF HANGING IN DSA. ASSIST CAMERON REP WORK PACK-OFF THRU DSA&SET SAME.CAMERON REP TESTED FLANGE&DOVE TAIL TO 5000 PSI"OK". L/D PACK-OFF R/R TOOL&P/U TEST PLUG.SET TEST PLUG IN WELL HEAD.R/U 3- 1/2"TEST ASSY&TEST EQUIPMENT. TEST 11"X 5M BOPS AS PER AOGCC&HILCORP SPECS 250 LOW/2500 HIGH FOR 5 MINS EACH ON CHART.STATE WITNESS WAS WAIVED BY JIM REGG,AOGCC ON 4/22/2015 @ 14:22 HRS.TESTED FROM MAIN&FUNCTIONED REMOTE. 04/24/15-Friday R/D TEST EQUIPMENT.PULL TEST PLUG AND INSTALL WEAR BUSHING. R/U FOSTER TONGS. M/U 6.750 BIT,(4)4-3/4" DC'S AND TIH W/3-1/2"PH6 TAG @ 9,141' DPM.TOTAL BHA LENGTH=125.06'. P/U AND R/U POWER SWIVEL. MAKE CONNECTION AND ESTABLISH DRILLING PARAMETERS,PUMPING 9 BPM 2200 PSI,RPM=75,TORQUE=5-6K.TIH AND TAG TOC @ 9,141'DPM.DRILL OUT CMT FROM 9,141'-9,684'DPM,PUMPING 9 BPM 2200 PSI,RPM=75,TORQUE=5-6K WOB 2-5.SOFT TO MEDIUM HARD CEMENT FROM 9,141'TO 9,600'AND HARD CEMENT FROM 9,600'TO 9.6.80,PUMPED 10 BBL N-VIS SWEEP.CHASED WITH 552 BBLS OF 8.5#F.I.W.@ 9 BPM 2400 PSI UNTIL RETURNS CLEAN.RECOVERED CEMENT&RUBBER FROM PLUGS. L/D(2)JNTS OF PH6.R/D POWER SWIVEL&L/0 SAME. R/U TEST EQUIPMENT.TEST 7-5/8"CSG TO 2500 PSI ON CHART. D TEST EQUIPMENT.ATTEMPT TO POOH W/NO SUCCESS DUE TO PIPE U-TUBING.R/U CIRC EQUIPMENT&BROKE CIRC LONGWAY WITH 15 BBLS @ 3 BPM WITH 365 PSI.CHECK WELL FOR FLOW AND WELL STATIC. POOH WITH 3-1/2 PH-6 WORK STRING. 04/25/15-Saturday CONT'TO POOH W/3-1/2"PH6&BIT. L/D 6.75"BIT.P/U 6"BIT. TIH WI 3-1/2" PH6&BIT TO 9,680'DPM.P/U=118K,S/0=60K. N/U STRIPPING HEAD.P/U POWER SWIVEL&R/U SAME.MAKE CONNECTION&INSTALL STRIPPING RUBBER.ESTABLISH PARAMETERS, P/U=108K,5/0=82K,TORQUE=6K @ 75 RPM. WEIGHT UP PITS TO 9#F.I.W.CHANGED SHAKER SCREENS&PREP TO DISPLACE WELL. DISPLACE WELL F/8.5#-T/9#F.I.W.@ 3 BPM IN REVERSE W/600 PSI. CONT'TO REV/OUT&DISPLACE WELL W/9#F.I.W.PUMPED 500 BBLS @ 4 BPM 450 PSI. ESTABLISH NEW PARAMETERS.NON ROT P/U=108K,S/0=72K,ROTW=84K,P/U=85K,S/0=82K, TORQUE=6K @ 65 RPM.TAGGED CEMENT @ 9,684'DPM. DRILL OUT CEMENT F/9,684'-T/9,700'DPM.RUNNING 1-3K WOB& CIRCULATING LONG WAY @ 9 BPM 2400 PSI.TORQUE=6500 FT/LBS. BROKE THRU CEMENT @ 9,700'DPM.ROT/WASH F/9,700'-T/ 9,812'DPM (TOP OF PLUG).CONT'CIRCULATING LONG WAY @ 9 BPM 2400 PSI. TAGGED PLUG @ 9,812'DPM.PUMPED 10 BBL N-VIS SWEEP AROUND THE LONG WAY @ 9 BPM WI 2500 PSI.TOTAL PUMPED=1110 BBLS. L/D(2)JNTS OF PH6&PULLED STRIPPING RUBBER.N/D STRIPPING HEAD.R/D POWER SWIVEL&L/D SAME.R/U TEST EQUIPMENT. TEST 7-5/8"CSG TO 2500 PSI ON CHART DATED 4-26-2015&HELD FOR 30 MINS."GOOD TEST". MIX/PUMP 8 BBL 10#SLUG&CHASED W/2 BBLS OF 9#F.I.W.R/D CIRC/TEST EQUIPMENT. POOH W/3-1/2"PH6&BIT. • Hilcorp Alaska, LLC Alkuka.,.1A: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-16RD 50-733-20183-01 180-110 3/25/2015 5/17/2015 Daily Operations: 04/26/15-Sunday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT POOH W/3-1/2"PH6 AND BIT ASSY.L/D BIT ASSY. M/U HALIB.RETRIEVABLE BRIDGE PLUG PULLING TOOL AND TIH W/3-1/2"PH6 TO 9,809'DPM. P/U AND R/U POWER SWIVEL.MAKE UP 10'PUP JT ON POWER SWIVEL.PICK UP=114K SLACK OFF=60K. CONT TIH W/RETRIEVING TOOL TO 9,812'DPM AND TAG BRIDGE PLUG.ENGAGE BRIDGE PLUG.SET 20K DOWN,P/U TO 144K(30 OVER)BRIDGE PLUG CAME FREE. REV/OUT(1)TBG VOL @ 3 BPM 800 PSI UNTIL RETURNS CLEAN.TOTAL PUMPED=90 BBLS. R/D AND LAY DOWN POWER SWIVEL. POOH W/3-1/2"PH6 AND BRIDGE PLUG SLOWLY AS PER HALIBURTON REP. L/D BRIDGE PLUG&RETRIEVING TOOL. CLEAN/CLEAR RIG FLOOR.SWAP TO 6" P.H.E.&PREP TO P/U BHA. P/U (1)JNT OF 5.75"W/P,6"N.R.C.SHOE,OIL/BUMPER JARS,&(4)4-3/4" DC'S. M/U&RIH W/SAME.TOTAL BHA#13 LENGTH=179.17'. TIH W/3-1/2" PH6&SHOE ASSY TO 12,932'AND REVERSE OUT 1 BOTTOMS UP. REVERSE OUT UNTIL RETURNS ARE CLEAN GETTING SAND,SCALE AND GUNK BACK AT BOTTOMS UP). 04/27/15-Monday SERVICE RIG AND SAFETY COMPLIANCE CHECK. N/U STRIPPER HEAD.P/U AND R/U POWER SWIVEL. MAKE CONNECTION.INSTALL STRIPPER RUBBER AND ESTABLISH DRILLING PARAMETERS.P/U=172K,SLACK OFF=64K, PUMPING 3 BPM 600 PSI,ALL PUMPING DONE IN REVERSE. WASH DOWN FROM 12,932'-12,995'DPM @ 3BPM 600 PSI.REV/OUT(1)TBG VOL EVERY 30'.GETTING TAR, SCALE AND SAND BACK IN RETURNS. LINE UP ON PZ9 TO PUMP THE LONGWAY DUE TO PAH MAKING NOISE.CONT WASH DOWN FROM 12,995'-13,150'DPM. PUMPING 8.5 BPM 3000 PSI.SWAB LEAKING ON PZ9.PAH PUMP HAD WEAK VALVE SPRING. LINE UP ON PAH PUMP.WASH DOWN F/13,150'-13,181'DPM.PUMPING 4 BPM 985 PSI,ALL PUMPING DONE IN REVERSE. REVERSE OUT @ 4 BPM 985 PSI UNTIL RETURNS CLEAN DUE TO MANIFOLDS TRYING TO PLUG. CONT'TO WASH DOWN IN REVERSE F/13,305'-13,454' AND TAGGED PACKER W/5K DOWN.P/U&REV/OUT 170 BBLS @ 4 BPM 980 PSI UNTIL RETURNS CLEAN.GETTING SCALE TAR AND SAND BACK IN RETURNS. MIX/PUMP 8 BBLS OF 10#SLUG AND CHASED W/2 BBLS OF 9#F.I.W.POOH &L/D(2)JNTS W/POWER SWIVEL. R/D POWER SWIVEL&L/D SAME.N/D STRIPPING HEAD. POOH W/3-1/2"PH6&SHOE ASSY.PULLED SLOW DUE TO DRAG& POSSIBILITY OF FISH.(P/U=189K,S/0=79K OFF-BTM).AT 06:00 DEPTH=1,200'. 04/28/15-Tuesday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT POOH W/3-1/2" PH6 AND CABLE SHOE ASSY. B/D CABLE SHOE ASSY.AND LAYDOWN SAME. WASH/CLEAN RIG AND PREP TO TIH. M/U 6" BURNING SHOE,MUD MTR,(4)5"BOOT BASKETS,(2)4.75 INLINE MAGNETS,OIL/BUMPER JARS,&(4)4-3/4 DCS.TOTAL BHA=231.19'.RIH TO 300'DPM.R/U KELLY HOSE AND TEST MUD MTR, PUMPING 3 BPM "OK"AS PER REP. TIH SLOW W/BURNING SHOE BHA AND 3-1/2"PH6, DUE TO FLUID RUNNING OVER TOP OF PIPE. P/U POWER SWIVEL @ 13,431'DPM &R/U SAME.(P/U=175K,S/0=63K). BROKE CIRC LONG WAY.CIRCULATE @ 5 BPM 1750 PSI. TAG PACKER @ 13,454'DPM.CUT/BURN OVER PKR T/13,456.50'DPM.RAN 1K-4K WOB.PUMPING 5 BPM THRU MUD MOTOR W/ 1800 PSI. LAY DOW A SINGLE&R/D POWER SWIVEL. 04/29/15-Wednesday R/D AND LAYDOWN POWER SWIVEL.C/O PHE,SERVICE RIG AND SAFETY COMPLIANCE CHECK. POOH W/3-1/2" PH6 AND MUD MOTOR BHA. B/D MUD MTR BHA,CLEAN MAGNETS AND BOOT BASKETS. RECOVERED 47#METAL,TOP SUB OF PACKER,TBG CLAMP AND RING GUAGE.SHOE 50%WORN. SLIP/CUT 108'DRILL LINE.RE-CALIBRATE HMI,RE-SET C-O-M AND CHECK WITH DRILL LINE, "OK". M/U 6.00" ROTARY SHOE,4.75"MUD MTR,(2)4.75"INLINE MAGNETS,(4)5" BOOT BASKETS,(4)4-3/4"DCS AND OIL/BUMPER JARS.TOTAL LENGTH OF BHA#15=207.17'. RIH 300'TBG.R/U CIRC EQUIPMENT&TEST MUD MOTOR"OK". TIH W/3-1/2"PH6& SHOE ASSY TO 13,430'DPM. DRIFTED EACH STAND OUT OF DERRICK.(P/U=174K,S/0=68K). P/U POWER SWIVEL&R/U SAME. BROKE CIRC LONG WAY @ 5 BPM 1585 PSI T/ENGAGE MUD MOTOR.EST PERIMETERS.P/U=173K,S/0=72K.TAGGED PACKER @ 13,456'DPM. CUT/BURN OVER PACKER F/13,456'T/13,458"DPM WITH 2K-3K WOB&PUMP PRESSURE @ 1650 PSI. P/U SINGLE AND CHASE PACKER MANDREL FROM 13,458'TO 13,476'AND TAGGED SAME WITH 3K. PUMPED 10 BBL 9.9 SLUG FOLLOWED BY 3 BBL OF 9..0 FIW.PULL AND L/O 1 SINGLE,R/D AND L/O POWER SWIVEL. Hilcorp Alaska, LLC Alaska, Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-16RD 50-733-20183-01 180-110 3/25/2015 5/17/2015 Daily Operations: 04/30/15-Thursday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT POOH W/3-1/2"PH6 AND BURING SHOE BHA ASSY. REPAIR HYD HOSE ON FOSTER TONGS,"NO SUCCESS".CHANGE OUT SAME. CONT POOH W/3-1/2"PH6 AND BURING SHOE BHA ASSY. B/D BURNING SHOE. L/D BURNING SHOE AND MUD MOTOR SHOE 50%WORN. M/U 5.75"OVERSHOT DRESSED W/4.50"GRAPPLE,(4)4-3/4"DC'S AND OIL/BUMPER JARS.TOTAL BHA#16 LENGTH =161.43'. TIH W/3-12"PH6 AND OVERSHOT BHA. TAGGED T.O.F. @ 13,474'DPM.SET 5K DOWN&ATTEMPT TO LATCH FISH.CHASED DOWN T/13,493'AND SET 20K DOWN.P/U WITH12K-15K OVERPULL(FISH PULLED FREE).S/O AND SET 15K DOWN.(INDICATIONS SHOW WE LATCHED ONTO FISH). POOH W/3-1/2" PH6,OVERSHOT ASSY,&POSSIBLE FISH.(P/U=182K OFF-BTM).DEPTH @ 06:00=6,122'. 05/01/15-Friday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT POOH W/3-1/2" PH6,0/S BHA AND POSSIBLE FISH. B/D OVERSHOT BHA,NO FISH. PULL WEAR BUSHING,SET TEST PLUG AND R/U TEST EQUIPMENT. TEST 11" X 5M BOPS AND SURFACE AS PER HILCORP AND AOGCC SPECS.250 LOW/2500 HIGH ON CHART DATED 5-01-2015.TEST FROM REMOTE AND FUNCTION MAIN.PERFORM KOOMEY TEST"OK".TEST WITNESSED BY JOHNNY HILL(AOGCC). R/D TEST EQUIPMENT.PULL TEST PLUG AND SET WEAR BUSHING. CONT'TO R/D TEST ASSY.P/U WEAR BUSHING &SET SAME.L/D TEST JNT.SWAP P.H.E.&PREP TO P/U BHA. P/U 5-3/4"OVERSHOT DRESSED W/4-7/16"GRAPPLE,OIL/BUMPER JARS,(4)4-3/4" DC'S,&ACCELERATOR JARS.M/U&RIH W/SAME.BHA#16 TOTLA LENGTH= 161.43'. TIH WI 3-1/2"PH6&FISHING ASSY TO 13,447'DPM(P/U=174K,S/0=68K). R/U CIRC EQUIPMENT&BROKE CIRC LONG WAY. EST.PERIMETERS PUMPING 3 BPM 500 PSI.WORK DOWN TO 13,478'DPM. TAGGED T.O.F.@ 13,493'DPM PRESSURE INCREASED TO 570 PSI.S/D PUMP&WORKED DOWN OVER FISH.SET 20K DOWN&HAD 12K OVERPULL.JAR DOWN ON FISH WORKING UP TO 30K DOWN.MAX OVERPULL 30K.POOH,L/D SINGLE JNT,&R/D CIRC EQUIPMENT. POOH W/3-1/2"PH6&OVERSHOT SLOW DUE TO POSSIBLE FISH.NEW P/U OFF-BTM=182K.AT 06:00=9,450'. 05/02/15-Saturday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT POOH SLOW W/3-1/2"PH6,OVERSHOT BHA AND POSSIBLE FISH. B/D OVERSHOT BHA,NO FISH.INSPECT 4-7/16"GRAPPLE,"GRAPPLE BROKEN",WASH/CLEAN RIG FLOOR AND PREP TO TIH. SLIP/CUT 66' DRILL LINE.RE-CALIBRATE HMI. RE-SET C-O-M AND CHECK WITH DRILL LINE,"OK". PERFORM GENERAL RIG MAINTENANCE AND HOUSEKEEPING WHILE WAITING ON S-LINE PERSONNEL TO ARRIVE. SPOT EQUIPMENT IN PLACE.N/U WIRELINE FLANGE AND RIG UP S-LINE.M/U 4.175"GAUGE RING,TEST LUBRICATOR TO 1500 PSI AND RIH W-S-LINE,TAG @13,492'SLM.POOH W/S-LINE.M/U 2.250" LEAD IMPRESSION BLOCK,CENTRALIZER AND 5'WEIGHT BAR.RIH W/S-LINE,TAG @13481'SLM. POOH W/S-LINE LIB SHOWED MARKS OF WICKER SIDE OF BROKE OFF GRAPPLE.P/U 3" MAGNET&RIH W/S-LINE.TAGGED @ 13,472'SLM &POOH. P/U 4" IMPRESSION BLOCK&RIH.TAGGED @ 13,472'SLM&POOH W/S-LINE.LIB SHOWS POSSIBLE E-LINE TOOLS STICKING OUT OF PACKER.P/U 3.75"OVERSHOT(BAITED)&RIH W/SAME.LATCHED ONTO E-LINE TOOLS @13,472'SLM&ATTEMPT TO PULL FREE W/ NO SUCCESS.SHEAR OFF&POOH W/S-LINE.P/U 4.1"CENTRALIZER, 1.75"SB TOOL&RIH W/SAME.LATCHED ONTO FISH @13,472' SLM.MADE SEVERAL ATTEMPTS TO JAR FREE W/NO SUCCESS.SHEAR OFF. &POOH W/S-LINE.R/D EXPRO TOOLS&EQUIPMENT. P/U 5-3/4"OVERSHOT DRESSED W/3-3/4" BASKET GRAPPLE,OIL/BUMPER JARS,(4)4-3/4"DC'S,&ACCELERATOR JARS.M/U&RIH W/SAME.DEPTH @ 06:00 13,001'. Hilcorp Alaska, LLC I!ileorp. Ia.ka.Ll.c Well Operations Summary Well Name API Number Well Permit Number Start Date _End Date D-16RD 50-733-20183-01 180-110 3/25/2015 5/17/2015 Daily Operations: 05/03/15-Sunday CONT TIH W/3-1/2" PH6 AND OVER SHOT BHA TO 13,448'DPM. M/U KELLY JT AND CONT TIH.P/U=170K,5/0=68K,TAG T.O.F. @13,479'DPM.WORK DOWN TO 13,482' DPM,W/6K DOWN,WORK UP/DOWN SEVERAL TIMES,W/6K DOWN.R/D KELLY JT. POOH SLOW W/3-1/2"PH6,OVER SHOT BHA AND POSSIBLE FISH.RECOVERE 5'7"OF WIRE LINE TOOL STRING. BREAK DOWN OVER SHOT AND ASSIST K.O.T.REP.SHUCK FISH. WAITING ON EXPRO BRAIDED WIRE ROPE UNIT TO ARRIVE FROM DOCK.PERFORM GENERAL MAINTENANCE AND HOUSEKEEPING WHILE WAITING. SERVICE RIG&PERFOMED SAFETY COMPLIANCE CHECKS. ASSIST CRANE CREW OFF-LOAD WIRE-LINE EQUIPMENT&SPOT IN PLACE.R/U LUBRICATOR&EQUIPMENT. P/U 5.5" BELL GUIDE,1-11/16" OVERSHOT(BAITED)W/3.5"GS TOOL.RIH W/BRAIDED WIRE-LINE.TAGGED @ 13,438'WLM.MADE SEVERAL ATTEMPTS TO LATCH FISH W/NO SUCCESS.POOH WI WIRE-LINE AT 6,700',LOST ALL WEIGHT.CONT'TO POOH W/LINE.LOST ENTIRE TOOL STRING UNDER 1ST X/O. P/U 3.75"BELL GUIDE,2"JDC PULLING TOOL&RIH W/SAME.TAGGED TOOLS @ 13,435'WLM.LATCHED ONTO SAME&POOH.B/D TOOL STRINGS. P/U 4"L.I.B.&RIH W/SAME.TAGGED @ 13,471'WLM.POOH W/WL. P/U 4.5"BELL GUIDE,1- 11/16"OVERSHOT,4"CENTRALIZER,(BAITED)W/3"GS TOOL&RIH W/SAME.TAGGED @ 14,431'WLM.MADE SEVERAL ATTEMPTS TO LATCH ONTO FISH W/NO SUCCESS.TOOLS GETTING STUCK AND TAKING 4K OVERPULL TO FREE.POOH W/WL. INSPECT TOOLS. JARS,CENTRALIZER,AND OVERSHOT PACKED FULL OF THICK PARAFFIN.CONSULT W/HILCORP REPS.R/D EQUIPMENT.PREP TO P/U BHA. 05/04/15-Monday SERVICE RIG AND SAFETY COMPLIANCE CHECK. TIH W/3-1/2" PH6 AND WASHPIPE CLEAN OUT ASSY.TO 13,434' DPM. N/U STRIPPER HEAD.PICK AND RIG UP POWER SWIVEL. MAKE CONNECTION AND EST DRILLING PARAMETERS.PUMPING 3 BPM 350 PSI P/U=175K, S/0=68K. WASH DOWN FROM 13,434'-13,505'DPM,PUMPING 3 BPM 350 PSI.ALL PUMPING DONE IN REVERSE.REV/OUT(1)TBG VOL EVERY JT. UNABLE TO WORK DEEPER.SET DOWN 30K. REV/OUT 120 BBLS @ 2-1/2 BPM 440 PSI. L/D(3)JNTS OF PH6. MIX/PUMP 10 BBLS OF 10#SLUG&CHASE W/2 BBLS OF 9#F.I.W. N/D STRIPPING HEAD. R/D POWER SWIVEL&L/D SAME.PREP TO POOH. POOH W/3-1/2" PH6&W/P ASSY.SLOW DUE TO DRAG. R/B(2)STNDS OF 4-3/4"DC'S.B/D JARS,WASHPIPE,SHOE&L/D SAME. RECOVERED 2 PIECES OF JUNK BACK IN CABLE SHOE. CHANGE OUT MAIN HYDRAULIC HOSE FROM BANK VALVE TO 600 GALLON RETURN TANK. 05/05/15-Tuesday CONT REPLACING HYDRALIC HOSE FROM VALVE BANK TO HYD UNIT.PERFORMED GENERAL MAINT ON RIG EQUIPMENT AND SERVICE RIG. M/U TRI-POINT 7"TEST PACKER AND TIH SLOW W/3-1/2"PH6 AS PER TRI-POINT REP TO 13,015'DPM. R/U POWER SWIVEL AND SET TRI-POINT TEST PKR @ 13,015'DPM AS PER TRI-POINT REP.PRESSURE UP ON CSG TO 2500 PSI AND TEST 7"&7- 5/8"CSG FOR 30 MINS ON CHART DATED 5-5-2015."OK".LINE UP ON TBG AND ESTABLISH INJECTION RATES,PUMPING @1/2 BPM, "NO SUCCESS",PRESSURED UP TO 2500 PSI.(LOST 80 PSI IN 30 MIN). RELEASE TEST PKR.RIG DOWN AND LAYDOWN POWER SWIVEL. POOH W/3-1/2" PH6&PKR ASSY. L/D PACKER ASSY.SWAP P.H.E. P/U(1)JNT OF 5.88"WASHPIPE,SCOS DRESSED W/4-7/16" BASKET GRAPPLE,OIL/BUMPER JARS,(4)4-3/4"DC'S,&ACCELERATOR JARS.TOTAL LENGTH OF BHA#20=194.54'. TIH WI 3-1/2" PH6&FISHING ASSY.DEPTH AT 06:00 12,028'. 05/06/15-Wednesday SERVICE RIG AND SAFETY COMPLIANCE CHECK. R/U STRIPPER HEAD.M/U KELLY JT.INSTALL STRIPPER RUBBER AND ESTABLISH DRILLING PARAMETERS.P/U 168K,S/0 67K,PUMPING 2 BPM 275 PSI.ALL PUMPING DONE IN REVERSE.CONT TIH AND WASH DOWN TO 13,507'DPM.MAKE SEVERAL ATTEMPTS TO LATCH FISH,SETTING DOWN TO 40K,NO INDICATION FISH LATCHED. R/D KELLY JT AND STRIPPER HEAD. POOH SLOW W/3-1/2"PH6,OVER SHOT BHA AND POSSIBLE FISH. BREAK DOWN OVER SHOT ASSY BHA,"NO FISH". M/U MUD MOTOR W/5 3/4"RTY SHOE,1 JT OF 5-3/4"WASH PIPE,5"MUD MOTOR,4 JUNK BASKETS,BUMPER AND OIL JARS, 4 4-4/3"DRILL COLLARS.TOTAL LENGTH BHA=226.84.(RAN HOLE TO 300'ANDTEST MUD MOTOR OK). TIH W/3.5"PH-6 WORKSTRING. R/U POWER SWIVEL. P/U WT 167K S/O 72K TAG @ 13,499'DPM.MILL ON FISH F/13,499'DPM TO 13,501'DPM PUMPING 5 BPM 1800 PSI. . • • Hilcorp Alaska, LLC llileorp Alaska,LL(: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-16RD 50-733-20183-01 180-110 3/25/2015 5/17/2015 Daily Operations: 05/07/15-Thursday Continue burning over fish f/13,501'to 13,504'DPM,pumping at 5 bpm with 1800 psi.Motor appears to be locking up. Slug pipe and rig down power swivel. Pooh w/3.5 ph-6 work string at 13,464 ft dpm.Pipe stuck,work same free,max over pull up to 228k(48k over pick up).Continue to pooh w/ no more problems.Lay down BHA(shoe worn out and no recovery of fish.Had half of packer ring in boot basket).Clear and clean floor. Slip and cut drill line 109 ft.Check crown a matic with drill line. Pull wear bushing. Rig up test plug and test BOP's to 250 psi and 2500 psi.Test witness waived by Mr.Jim Regg with AOGCC on 5-06-15 at 11:17 AM. 05/08/15-Friday CONT TEST 11"X 5M BOP'S AND SURFACE EQUIPMENT AS PER HILCORP&AOGCC SPECS,250 LOW/2500 HIGH ON CHART DATED 5- 8-2015.SEE CHART AND DETAIL SHEET FOR INDIVIDUAL TEST.TEST FROM MAIN AND FUNCTION REMOTE.PERFORM ACCUMULATOR TEST. WITNESS WAIVED BY MR.JIM REGG(AOGCC). R/D TEST EQUIPMENT.PULL TEST PLUG AND INSTALL WEAR BUSHING. M/U 6" BIT,(4)4-3/4"DCS&OIL BUMPER JAR,4)4-3/4 D.C's X/O=145.28. TIH W/3-1/2"PH6 AND BIT ASS'Y.TAG @13,486'DPM. R/U KELLY JT TIW&CIRC HOSE TAG @ 13,486'DPM.P/U TO 13,485'DPM. DISPLACE THE 9.0 FIW WITH 8.5 LB FILTERED INLET WATER, CIRCULATING AROUND UNTIL FLUID CLEAN PUMPING @ 3 BPM 525 PSI SENDING RETURNS TO TRADING BAY.PUMP TOTAL 872 BBLS. MONITOR WELL,STATIC.LAYDOWN KELLY JNT&R/D CIRC HOSE&TIW. POOH WITH 3.5"PH6 WORKSTRING. 05/09/15-Saturday Continue Pooh w/3.5"work string and 6"Bit. Lay down BHA and clear floor. Spot logging equipment.Rig up same,test shoot nipple to 1500 psi.RIH w/2.75"CBL Gamma Ray to 13,400 ft ELM.Pooh logging f/13,400 ft ELM to surface.Rig down E-line. Pick up 4.5" TCP Gun Assembly(66 ft loaded&293 ft Blank total ft of guns 359 ft). TIH With guns at 1 minute per stand. 05/10/15-Sunday Continue TIH w/gun assembly at 1 minute per stand,drifting pipe out of derrick to 13,410 ft dpm. Spaced out guns and Rig up E-line test lubricator to 1500 psi(ok).Make up and RIH w/1-11/16 Gamma ray/CCL,correlate guns on depth, guns 2 ft high. Reposition guns on depth.Rig up E-line and RIH W/Gamma Ray/CCL and verify gun position. Held PJSM dropped bar,had good indication of guns firing perforating G-3 @ 13,091'to 13,120'.G-4 @ 13,190'-13,207'.G-5 13,354'-13,364'.G-5 13,440'to 13,450',pipe went on vacuum.Fill hole 1/2 bbl of 8.5 ppg FIW.Monitor well,well static.Reverse circ out 2 tbg volume max gas 430 units.Monitor well (well static).Rig down circ hoses. Pooh to 6,937'. Reverse out gas at 6,937'. 05/11/15-Monday Continue pooh w/TCP assembly. Lay down spent TCP guns(All guns fired). Pull wear bushing. Held prejob safety meeting.Pick up and run 7"Tri-point HYD set packer w/gas lift valves loaded with dummies,on 3.5"9.2#,L-80 super max tubing,torqueing same to 2750 ft lbs,checking pups on glm.At rpt time,196 jts run.Total length 6,644.72 ft. 05/12/15-Tuesday RIH picking up 3.5,9.2#L-80,Super max tbg,drifting same,torque connections to 2750 ft lbs.Ran total of 383 fts+13 glv's loaded with dummies,+7"tripoint Hyd set packer,making up the Baker SCSSV&test control line to 5k for 5 minutes,placing the WLEG at 12,954 ft.&packer at 12,877.15.P/up wt 106k&slack off wt at 53k minus block wt of 8k.Land hanger w/44k wt.Verify hanger in place,run in lock down pin. Rig up slick line testing lubricator to 4000 k,make 2.70 gauge ring run tagging at 12,910 ft WLM.Rih w/ 1.75 RB W/PRONG at 12,910 wlm.Attempt to shear up,no success.Pressure up to 500 psi on prong,still unable to shear up.Pooh and change tool out to 1.75 SD W/PRONG.Rih tagging at 12,910 ft.Attempt to shear off prong.Pooh,still had prong.Run back in hole w/same. Hilcorp Alaska, LLC ►,��,,,,,�_��:, ,.�.,.L�: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-16RD 50-733-20183-01 180-110 3/25/2015 5/17/2015 Daily Operations: 05/13/15-Wednesday RIH WI 1.75"SB WITH PRONG TO 12,910'WLM.SET DOWN AND SHEARED OFF PRONG.PRESSURE UP TO 600 PSI TO ENSURE PRONG SET. PRESSURE UP TO 3500 PSI ON TBG FOR 30 MINS AND SET 7"TRI-POINT HYD SET LINER PACKER AT 12,877'MD.BLEED TO ZERO AND PRESSURE BACK UP TO 3500 PSI ON TBG TO ENSURE PKR SET,OK. LINE UP ON CSG AND PRESSURE UP TO 1500 PSI FOR 30 MINS ON CHART DATED 5-13-2015,OK. BLEED OFF SAME. POOH WI SLICK LINE AND RIG DOWN SAME.RIG DOWN LANDING JT. INSTALL BPV. NIPPLE DOWN 11"X 5M BOPS AND RISER.PREP WELLHEAD. INSTALL PROD TREE AND NIPPLE UP SAME.M/U SCSSV CTRL LINE, FUNCTION TEST AND LOCK OPEN SAME.TEST VOID TO 5000 PSI,OK.BPV AND INSTALL TWO WAY CHECK.BODY TEST TREE TO 2500 PSI,OK.PULL 2 WAY CHECK. R/U SLICK LINE UNIT AND EQUIPMENT,TEST LUB TEST TO 1500 PSI,OK,WHILE WATING ON WIRE LINE JUNK BASKET. RIH W/3"GS AND 5'JUNK BSKT TO 12,903'WLM.SET SAME,POOH.RIH W/3" KO1 AND ML PULLING TOOL TO 3,000' WLM. POOH DUE TO FLUID ON VAC.RIH W/3"GS PULLING TOOL TO 12,903'WLM TO RETRIEVE JUNK BSKT,SHEARED OFF. POOH REDRESS TOOL W/STEEL SHEAR PIN RIH W/SAME TO 12,903'WLM.POOH W/JUNK BSKT.RIH WI 1.75"PRONG TO 12,910'WLM SET SAME,POOH.RIH W/JUNK BSKT TO 12,903'WLM SET SAME, POOH. 05/14/15-Thursday M/U W/3"OK1&ML PULLING TOOL.PRESSURE UP TO 500 PSI AND RIH W/S-LINE TO 12,102'SLM(GLM#2). LATCH AND MAKE SEVERAL ATTEMPTS TO PULL SAME. POOH W/S-LINE,"NO RECOVERY".RIH W/3"OK1&ML PULLING TOOL TO 12,102'SLM(GLM#2). LATCH DUMMY&MAKE SEVERAL ATTEMPTS TO PULL SAME.POOH W/S-LINE,"NO RECOVERY".RIH W/3"OK1&PULLING TOOL TO 10,564'SLM (GLM#4).LATCH DUMMY AND MAKE SEVERAL ATTEMPTS PULL. POOH W/SLICKLINE,NO RECOVERY.RIH W/3"OK1& PULLING TOOL TO 9,824'SLM (GLM#5).LATCH DUMMY AND MAKE SEVERAL ATTEMPTS TO PULL SAME.POOH W/S-LINE,"NO RECOVERY". RIH W/2.75" MERLA KICK OVER TO 9,046'SLM (GLM#6).LATCH DUMMY AND MAKE SEVERAL ATTEMPTS TO PULL SAME. POOH W/S-LINE,"NO RECOVERY".RIH W/3"OK1&ML PULLING TOOL WITH KNUCKLE TO 8,295'SLM(GLM#7). LATCH DUMMY AND MAKE SEVERAL ATTEMPTS TO PULL SAME. POOH W/SLICKLINE. RECOVER DUMMY VALVE. RIH W/2.68" KOT 1.375"JDC TO 9,038' SLM (GLM#6). LATCHED DUMMY,POOH WITH DUMMY.RIH W/SAME TO 2,102'SLM (GLM#2).LATCHED DUMMY,POOH W/DUMMY.RIH W/SAME TO 11,293'SLM(GLM#3).LATCHED DUMMY, POOH.RIH W/SAME TO 10,552'SLM(GLM#4).ATTEMPT TO LATCH DUMMY. POOH,NO RECOVERY.REDRESS ROPE SOCKET.RIH W/SAME TO 6,774'SLM (GLM#9). LATCHED DUMMY POOH. RIH W/SAME TO 6,004'SLM(GLM#10). LATCHED DUMMY,POOH. RIH W/SAME TO 5,230'SLM(GLM#11).LATCHED DUMMY,POOH.RIH W/SAME TO 4,123'SLM(GLM#12). LATCHED DUMMY,POOH.RIH W/SAME TO 2,355'SLM.ATTEMPT TO LATCH,UNABLE TO GET IN POCKET.CONT RIH TO 7,556'SLM. UNABLE TO LATCH DUMMY.POOH TO REDRESS TOOL. • Hilcorp Alaska, LLC ►,�,,,,,_,I:,.�:,. Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-16RD 50-733-20183-01 180-110 3/25/2015 5/17/2015 Daily Operations: 05/15/15-Friday RIH W/2.68"KOT&1.375"JDC TO 10,552'(GLM#4).MAKE SEVERAL ATTEMPTS TO LATCH DUMMY,"NO SUCCESS".POOH TO 9,824' (GLM#5).MAKE SEVERAL ATTEMPTS TO LATCH DUMMY,"NO SUCCESS".POOH TO 7,556'(GLM#8).MAKE SEVERAL ATTEMPTS TO LATCH DUMMY,"NO SUCCESS".POOH W/S-LINE."NO RECOVERY".LEFT TOOL STRING IN HOLE.M/U 1.50" RJ PULLING TOOL W/KNUCKLE AND RIH,W/S-LINE TO 12,885'.LATCH FISH AND POOH W/S-LINE."FULL RECOVERY".M/U 2.68"MERLA KOT W/KNUCKLE &1.375"JDC.RIH W/S-LINE TO 2,348'(GLM#13). LATCH DUMMY AND POOH."RECOVERED DUMMY".RIH W/S-LINE TO 10,552'(GLM #4). MAKE SEVERAL ATTEMPTS TO LATCH DUMMY. POOH W/S-LINE(NO RECOVERY).M/U 1.250"4K SPRING KOT AND RIH W/SAME TO 2,348'(GLM#13).SET 1"LIVE VALVE. POOH. W/S-LINE VALVE NOT SET. M/U 2.68" MERLA KOT&1.250"JK RUNNING TOOL TO 2,348'(GLM#13).SET VALVE AND POOH."VALVE SET".RIH W/S-LINE TO 4,125'(GLM#12).SET 1" LIVE VALVE, POOH.VALVE SET.RIH W/S-LINE TO 5,230'(GLM#11).SET 1"LIVE VALVE,POOH W/S-LINE.RIH W/S-LINE TO 6,004'(GLM#10).SET 1" LIVE VALVE,POOH W/S-LINE.RIH W/S-LINE TO 6,774'(GLM#9).SET 1" LIVE VALVE POOH,RIH,W/2.68" MERLA KOT 1 1/4"JDC PULLING TOOL W/KNUCKLE TO 7,554'S-LINE. POOH DUMMY. RIH W/2.68"MERLA KOT 1.25"JDC TO 8,295'SLM.SET(GLM#7)1"LIVE VALVE POOH. RIH W/SAME TO 9,038'SLM.SET(GLM#6)1"LIVE VALVE POOH.RIH W/SAME TO 9,812'(GLM#5).LATCH DUMMY&POOH W/SAME. RIH W/SAME TO 9,812'(GLM#5)W/1"LIVE VALVE.WORK TO CORRELATE W/NO SUCCESS,POOH W/SAME.REPAIRED SHEARED TRIGGER.RIH W/SAME TO 9,812'SLM.ATTEMPT TO SET,VALVE,UNABLE POOH,VALVE BENT.RIH W/1 1/2"IMPRESSION BLOCK TO 10,552'SLM,POOH.REDRESS TOOL W/1 1/4"JDC PULLING TOOL.RIH W/SAME TO 10,522'SLM,UNABLE GET IN THE POCKET,POOH. REDRESS TOOL OK 1 WITH A SHORTER CATCH.RIH W/SAME. 05/16/15-Saturday TAG @ 10,552'SLM ATTEMPT TO PULL#4 DUMMY VALVE. POOH W/S-LINE AND POSSIBLE DUMMY VALVE.WIRE PARTED @ 1,973' SLM.CONT POOH.SECURE WELL.REHEAD&M/U TOOL STRING. TEST LUBICATOR TO 1500 PSI TEST GOOD. RIH W/2.5"BAITED 3" WIRE FINDER W/14"SKIRT,3"WT BAR,2.5"2 LEG WIRE GRAB TO 8,579'SLM. POOH W/S-LINE.LAY DOWN TOOL STRING. STRIP OUT OF HOLE W/RECOVERED SLICK LINE AND L/D TOOL STRING. M/U 2.68" MERLA EMPTY BK RUNNING TOOL ASSY. RIH W/2.68"BK RUNNING TOOL ASSY TO 10,552"SLM.ATTEMPT TO PULL DUMMY VALVE. POOH W/S-LINE NOTHING RECOVERED. RIH W/2.68" MERLA EMPTY BK RUNNING TOOL ATTEMPT TO SET#4 GLV @10,552"SLM. NO SUCCESS. POOH W/S-LINE AND GLV. RIH W/2.68" OK1 7FT LONG W/BK RUNNING TOOL ASSY TO 10,552"SLM. POOH W/S-LINE GLV#4 SET. RIH W/2.68"OK1 7FT LONG W/BK RUNNING TOOL TO SET#5 GLV @ 9,812"SLM.POOH. FINISH POOH W/2.68"OK1 7FT LONG W/BK RUNNING TOOL.VALVE SET. RIH W/SAME TO 11,293'SLM TO SET(GLM#3)POOH.VALVE SET. RIH W/SAME TO SET DOWM @ 11,400'SLM.UNABLE TO CONT IN HOLE.POOH W/SAME. "RIH W/2.25"MAGNET&2.70"WIRE SKIRT.SET DOWN @ 7,551'SLM.UNABLE TO CONT IN HOLE.POOH (FOUND BENT FINGER ON THE SKIRT)". REMOVE SKIRT.RIH W/2.25"MAGNET TO 12,901'SLM.POOH(RECOVERED 2 PIECES OF FISHING NECK). RIH W/2.68"OK1 7FT LONG W/BK RUNNING TOOL TO 12,102'SLM(GLM#2)POOH.VALVE SET. RIH W/GU PULLING 2.70"TO 12,901'SLM. POOH W/JUNK BSK(RECOVERED VALVE DUMMY). TEST TBG 200 PSI FOR 20 MIN (OK). RIH W/2"JDC W/1.86" OD TO 12,908'SLM TO RETREIVE 1.75" PRONG POOH. 05/17/15-Sunday POOH WITH 2"JDC F/12,908'SLM(RETRIEVED PRONG). RIH W/3"GS PULLING TOOL RETRIEVE X LOCK @ 12,910'SLM POOH W/SAME. RIG DOWN EXPRO SLICK LINE. Rig released to D-48. Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, May 08, 2015 9:47 AM To: 'Dan Marlowe' Cc: Juanita Lovett;Ted Kramer Subject: RE: D-16rd PTD 180-110, Sundry 315-031 Dan, Thanks for the update. Change to the completion is approved. I will file this email as documentation. Be sure to test and chart the IA after packer is set. Guy Schwartz VANED MAY 1 12D15 Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). From: Dan Marlowe [mailto:dmarlowe@hilcorp.com] Sent: Friday, May 08, 2015 9:28 AM To: Schwartz, Guy L(DOA) Cc: Juanita Lovett; Ted Kramer Subject: RE: D-16rd PTD 180-110, Sundry 315-031 Guy Latest update on D-16rd The packer proved to be stubborn so we have elected to complete the upper zones and as a gas-lift instead of ESP Thanks Dan From: Schwartz, Guy L(DOA) [mailto:cwv.schwartz@)alaska.gov] Sent: April 22, 2015 11:13 AM To: Dan Marlowe Cc: Juanita Lovett; Ted Kramer Subject: RE: D-16rd PTD 180-110, Sundry 315-031 Dan, Makes sense..thank you for the update. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 1 907-793-1226 office 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 Guy Schwartz at (907-793-1226) or(Guy.schwartz@alaska.gov). From: Dan Marlowe [mailto:dmarlowe@hilcorp.com] Sent: Wednesday, April 22, 2015 11:07 AM To: Schwartz, Guy L(DOA) Cc: Juanita Lovett; Ted Kramer Subject: RE: D-16rd PTD 180-110, Sundry 315-031 Guy Just to keep you in the loop We located the communication issue between the 9-5/8" and the 13-3/8" to be a breach between 2473' & 2500' DPM. The suspected casing hanger issue was not an issue. While we had cement lined up we elected to pump a 10 bbls suspending agent and a 66 bbl 15.8#class G cement(340 sx) plug down the 13-3/8 x 9-5/8 void. Prior to running the 7- 5/8" liner to help ensure annular integrity and set up for better control while cementing in the liner. Thanks Dan From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, March 26, 2015 12:33 PM To: Dan Marlowe Cc: Juanita Lovett; Ted Kramer Subject: RE: D-16rd PTD 180-110, Sundry 315-031 Dan, You have approval to modify sundry 315-031 (D-16RD) as proposed below. I will update our well file with the modified procedure. A follow-up sundry is not required. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Dan Marlowe [mailto:dmarlowe@hilcorp.com] Sent: Thursday, March 26, 2015 9:48 AM To: Schwartz, Guy L(DOA) Cc: Juanita Lovett; Ted Kramer Subject: D-16rd PTD 180-110, Sundry 315-031 Guy 2 • I have a few changes on D-16rd 1. Hanger threads completely gone so we used an slick line plug 2. The 9-5/8&13-3/8" is in direct communication due to suspected hanger seal leak.We should be able to repair it but it will complicate nipple down of the tubing spoolPotential isolation of hemlock bench 4—contingent on CBL evaluation 3. Well pressure was slightly higher than anticipated so I will add in a high set packer w/vent valve and pressure test it to 1500 psi. Revised schematic attached These changes are reflected in the procedure below Procedure: 1. RU HAK Rig 1 over D-16rd. • Hanger threads bad—set a wireline plug at 98' SLM 2. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines to 250 psi LOW and 2,500 psi HIGH. 3. RU E-line. Cut tubing in middle of first full joint above seals or as deep as possible. POOH and RD E-line. 4. PU landing joint and make-up to tubing hanger. Pull hanger up to floor height by pulling free from tubing cut. Circulate Hydrocarbons from well. 5. POOH, LD tubing. 6. RIH latch onto tubing stub,release and POOH with seals and tail-pipe. 7. PU tandem string mills and clean casing walls to top of production packer.Circulate hole clean. 8. Inspect casing to+/-13,000'and determine if liner needs installed. • Based on casing inspection, pick a location as deep as possible to set a retrievable plug. Ideally at +/- 9,750' and at a minimum +/- 2,500' • PU RTTS packer and rih to depth pressure testing between RTTS and Retrievable plug working way back out of the hole to determine casing integrity • Final test depth ideally above 2500' to be held for 30 minutes and charted at 1500 psi 9. PU storm packer, RIH and set same at 200' and hang off string. Pressure test to 1,500 500 psi and chart. (Pressure reduced as it will be on 13-3/8" at this time) 10. Release from storm packer, POOH. Remove tubing head, work with wellhead specialist to repair 9-5/8" x 13- 3/8" hanger leak, Test 9-5/8" hanger and chart, install Multi-Bowl Tubing/Casing spool. (If casing inspection passed in step#8, install tubing spool only and skip steps#13-19) 11. Test all flange breaks to 2,500 psi and chart. 12. RIH,engage storm packer, release same, POOH, LD storm packer. 13. RIH and set plug at+/-9,750'spotting 20'sand on top. 14. RIH with liner,space out and land. 15. Rig up and cement liner. 16. Pressure test liner to^'2,500 psi and chart for 30 minutes. 17. RIH cleaning out liner to top of plug at+/-9,700'. 18. Run a CBL log from 9,690'to surface. 19. RIH and retrieve plug. 20. PU retrievable test packer and RIH to+/-13,000'.Set packer,test casing to "2,500 psi and chart for 30 minutes. 21. Mill and retrieve injection packer at 13,440'. 22. Cleanout to+/-14,000'. • Based on CBL log, work with reservoir and potentially set plug above Hemlock bench 4 (+/-13,975'). 23. PU TCP guns and RIH and re-perforate the G and Hemlock zones per the Perf Recommendation. 24. After detonation, circulate perf gas,confirm well is static, POOH. 25. Run ESP completion with high set packer and packer vent valve. • Land completion, set packer, pressure test inner annulus to 1500 psig and chart for 30 minutes. 26. Set BPV. NU tree,test same. 3 Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowehilcorp.com Hilcorp A Company Built on Energy 4 McArthur River Field, TBU : H PROPOSED Well: D-16RD As Completed: Future Hilcorp Alaska,LLC P 1\ v CASING DETAIL 1 Size Wt Grade Conn ID Top Btm 13-3/8" 61 K-55 Seal Lock 12.515 43.80' 2,553.63' 4 40 N-80 Butt 8.835 44.80' 5,514.04' tUk 4(. � /4. 1;.X 1- , 9-5/8" 43.5 N-80 Butt 8.775 5,514.04' 8,059.53' t'� 47 N-80 Butt 8.681 8,059.53' 9,955' bl SLID-II 6.875 Surf DV Collar 7" 29 N-80 Butt 6.184 9,689' 14,644' alill ap...:6 822' Tubing Detail s 4 -1 rd 3-1/2" L-80 Supermax 4-12,950' it- w k ), 1 low (f.,.., JEWELRY DETAIL WNo Depth(MD) ID Item Hanger Top of , 2-14 ±350' SSSV finer ...-i , 9,689' ' ±2,345' GLM 3 ±4,106' GLM 4 ±5,239' GLM 5 ±5,987' GLM Li, 6 ±6,773' GLM 7 ±7,550' GLM 8 ±8,303' GLM 4 9 ±9,048' GLM 10 ±9,810' GLM e 11 ±10,561 GLM 12 ±11,310' GLM 13 ±12,098' GLM "1 14 ±12,785' GLM 1 ±12,950' Hydroset Pack, ±12,930' X Nipple 15 ±12,950' WLEG Ilia 16 18 13,504' (Junk)Otis WD 7"x4"packer w/5'seal bore ext. 17 - G-3 G-4 4 = 6-5 PERFORATION DETAIL 18 e'er Zone Top(MD) Btm(MD) Top(TVD) Btm(ND) Amt SPE Date HK-1 ±13,091' ±13,120' ±9,157' ±9,177' , ±29' Future G-4 ±13,190 ±13,207' ±9,225' ±9,237' ±17' Future G-5 -13,354 ±13,364' ±9,338' ±9,'^ +10' Future HK-4 G-5 3,44r +13,450' ±9,398' ±' 10' Future HK-1 13,632' 13,688' 9,532' 9,572' 56 8 10/13/1984 HK-4 13,985' 14,000' 9,777' 9,788' 15 8 4/27/1981 HK-4 14,015' 14,036' 9,798' 9,812' 21 8 4/27/1981 HK-4 14,052' 14,066' 9,823' 9,832' 14 8 4/27/1981 14,510"HOWCO - Lily per manen, BP`N Updated: 05/05/15 byJLL • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, March 26, 2015 12:33 PM To: 'Dan Marlowe' Cc: Juanita Lovett;Ted Kramer Subject: RE: D-16rd PTD 180-110, Sundry 315-031 Dan, You have approval to modify sundry 315-031 (D-16RD) as proposed below. I will update our well file with the modified procedure. A follow-up sundry is not required. Guy Schwartz Senior Petroleum Engineer SCANNED t ,,` AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALIIYNOTICE: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 Guy Schwartz at (907-793-1226) or(Guv.schwartz@alaska.gov). From: Dan Marlowe [mailto:dmarlowe@hilcorp.com] Sent:Thursday, March 26, 2015 9:48 AM To: Schwartz, Guy L(DOA) Cc: Juanita Lovett; Ted Kramer Subject: D-16rd PTD 180-110, Sundry 315-031 Guy I have a few changes on D-16rd 1. Hanger threads completely gone so we used an slick line plug 2. The 9-5/8& 13-3/8" is in direct communication due to suspected hanger seal leak. We should be able to repair it but it will complicate nipple down of the tubing spoolPotential isolation of hemlock bench 4—contingent on CBL evaluation 3. Well pressure was slightly higher than anticipated so I will add in a high set packer w/vent valve and pressure test it to 1500 psi. Revised schematic attached These changes are reflected in the procedure below Procedure: 1. RU HAK Rig 1 over D-16rd. • Hanger threads bad—set a wireline plug at 98' SLM 2. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines to 250 psi LOW and 2,500 psi HIGH. 3. RU E-line. Cut tubing in middle of first full joint above seals or as deep as possible. POOH and RD E-line. 4. PU landing joint and make-up to tubing hanger. Pull hanger up to floor height by pulling free from tubing cut. Circulate Hydrocarbons from well. 5. POOH, LD tubing. 1 6. RIH latch onto tubing stub, release and POOH with seals and tail-pipe. 7. PU tandem string mills and clean casing walls to top of production packer.Circulate hole clean. 8. Inspect casing to+/-13,000' and determine if liner needs installed. • Based on casing inspection, pick a location as deep as possible to set a retrievable plug. Ideally at +/- 9,750' and at a minimum +/-2,500' • PU RTTS packer and rih to depth pressure testing between RTTS and Retrievable plug working way back out of the hole to determine casing integrity • Final test depth ideally above 2500' to be held for 30 minutes and charted at 1500 psi 9. PU storm packer, RIH and set same at 200' and hang off string. Pressure test to 47-509 500 psi and chart. (Pressure reduced as it will be on 13-3/8" at this time) 10. Release from storm packer, POOH. Remove tubing head, work with wellhead specialist to repair 9-5/8" x 13- 3/8" hanger leak, Test 9-5/8" hanger and chart, install Multi-Bowl Tubing/Casing spool. (If casing inspection passed in step#8, install tubing spool only and skip steps#13-19) 11. Test all flange breaks to 2,500 psi and chart. 12. RIH,engage storm packer, release same, POOH, LD storm packer. 13. RIH and set plug at+/-9,750'spotting 20'sand on top. 14. RIH with liner, space out and land. 15. Rig up and cement liner. 16. Pressure test liner to^'2,500 psi and chart for 30 minutes. 17. RIH cleaning out liner to top of plug at+/-9,700'. 18. Run a CBL log from 9,690'to surface. 19. RIH and retrieve plug. 20. PU retrievable test packer and RIH to+/-13,000'.Set packer,test casing to 2,500 psi and chart for 30 minutes. 21. Mill and retrieve injection packer at 13,440'. 22. Cleanout to+1-14,000'. • Based on CBL log, work with reservoir and potentially set plug above Hemlock bench 4 (+1-13,975'). 23. PU TCP guns and RIH and re-perforate the G and Hemlock zones per the Perf Recommendation. 24. After detonation,circulate perf gas,confirm well is static, POOH. 25. Run ESP completion with high set packer and packer vent valve. • Land completion, set packer, pressure test inner annulus to 1500 psig and chart for 30 minutes. 26. Set BPV. NU tree,test same. 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 OF Titt ,s?, THE STATE Alaska Oil and Gas 4' o Conservation Commission fALAsJ(j\ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *�. Main: 907 279.1433 OF-ALAS '� Fax: 907.276 7542 www.aogcc.alaska.gov Dan Marlowe atakED -"- 2P3 s_ Operations Engineer Hilcorp Alaska, LLC gd 110 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil Pool, Trading Bay D-16RD Sundry Number: 315-031 Dear Mr. Marlowe: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, fr Cathy P. oerster Chair DATED this 23day of January, 2015 Encl. RECEIVED STATE OF ALASKA JAN0 ?.015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod 0 Repair Well❑ Change Approved Program❑ Suspend El Plug Perforations❑ Perforate 0 Pull Tubing 0 lime Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Install ESP /--N✓ci) I O WeU 2.Operator Name: '4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development ❑ 180-110 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service 0 6.API Number. Anchorage,AK 99503 50-733-20183-01 • 7.If perforating: 8.WeN Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 228A/ Will planned perforations require a spacing exception? Yes ❑ No 0 / Trading Bay Unit/D-16RD 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017579 4 McArthur River Field/Hemlock Oil Pool 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): 14,645 - 10,306 - 14,510 - 10,160 - 14,510&14,600 11,507 Casing Length Size MD ND Burst Collapse • Structural Conductor Surface 2,555' 13-3/8" 2,555' 2,347' 3,090 psi 1,540 psi Intermediate 9,955' 9-5/8" 9,955' 7,095' 5,750 psi 3,090 psi • Production Liner 4,955' 7" 14,644' 10,265' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 13,632-14,066 - 9,532-9,832 3-1/2" 9.3#/N-80 13,543 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Otis WD Packer • 13,440'(MD) 9,398'(TVD) 12.Attachments: Description Summary of Proposal 0 , 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 . Exploratory LI Stratigraphic❑ Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 2/15/2015 Commencing Operations: Oil 0• Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe@hilcorp.com Printed Name Dan Marlow �hr j �l '�.�hone (907)Title Operations Engineer Signature arlow /f 283-1329 Date 1/19/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\ 5 — 03` Plug Integrity 0 BOP Test Mechanical Integrity Test 0 Location Clearance ❑ Other: 'it 2 SC/ f 5� t3(' i % f- C /I.1.4 S-►r� Zs c F ; Spacing Exception Required? Yes No IB Subsequent Form Required: )a --`i C"I APPROVED BY Approved by: AI 147 f_._ i. t Z- I:', COMMISSIONER THE COMMISSION Date: / 23-(3 19� r v�GN 73 4-- Submd Form and Form 10-403(Revised 10/2012) I r or 12 months from the date of approval Attachments in Duplicate RBDMS-N.V JAN 2 6 2015 A Well Work Prognosis Well: D-16rd Hiloarp Alaska,►Lc Date: 01/15/2015 Well Name: D-16rd API Number: 50-733-20183-01 Current Status: Shut-in Injector Leg: Leg#B-1 (SE corner) Estimated Start Date: February 15, 2015 Rig: HAK#1 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett _ Permit to Drill Number: 180-110 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 Current BHP: —3,970 psi @ 9,450'TVD 0.42 psi/ft,(8.10 ppg)based on 250psi SIWHP on 1/9/15 and 20%oil in wellbore Max.Expected BHP:--4101 psi @ 9,450'TVD 0.434 psi/ft,(8.10 ppg)based on 250psi SIWHP on 1/9/15 and 100%water in wellbore Max.Possible SP: 0 psi Well will not flow based on an expected oil and water gradient of 0.437 psi/ft Brief Well Summary D-16rd is an injector that was shut-in in October 1985 when the tubing became plugged.This work over will remove the existing completion,clean out the well, and re-complete as an ESP producer. Z Procedure: S Erl u- --i i f. _.icr»��, 1. RU HAK Rig 1 over D-16rd. 2. Notify AOGCC 48 hours before pending ROPE test. Set BPV, ND tree, NU ROPE. Test all BOP equipment per AOGCC guidelines to 250 psi LOW and 2,500 psi HIGH., 3. RU E-line. Cut tubing in middle of first full joint above seals or as deep as possible. POOH and RD E-line. 4. PU landing joint and make-up to tubing hanger. Pull hanger up to floor height by pulling free from tubing cut. Circulate Hydrocarbons from well. 5. POOH, LD tubing. 6. RIH latch onto tubing stub, release and POOH with seals and tail-pipe. 7. PU tandem string mills and clean casing walls to top of production packer.Circulate hole clean. 8. Inspect casing to+/- 13,000'and determine if liner needs installed. 9. PU storm packer, RIH and set same at 200' and hang off string. Pressure test to 1,500 psi and chart. 10. Release from storm packer, POOH. Remove tubing head and install Multi-Bowl Tubing/Casing spool. (If casing inspection passed in step#8, install tubing spool only and skip steps#13-19) 11. Test all flange breaks to 2,500 psi and chart. 12. RIH, engage storm packer, release same, POOH, LD storm packer. /`13. RIH and set plug at+/-9,750' spotting 20' sand on top. ( 14. RIH with liner,space out and land. vY' 15. Rig up and cement liner. ,-• 16. Pressure test liner to^'2,500 psi and chart for 30 minutes. II� , 17 . RIH cleaning out liner to top of plug at+/-9,700'. 18. Run a CBL log from 9,690'to surface. 9. RIH and retrieve plug. 20. PU retrievable test packer and RIH to +/-13,000'. Set packer, test casing to ^'2,500 psi and chart for 30 minutes. 21. Mill and retrieve injection packer 13,440. 22. Cleanout to+/-14,000'. 23. PU TCP guns and RIH and re-perforate the G and Hemlock zones per the Perf Recommendation. r s ., Well Work Prognosis Well: D-16rd Hilt»rp Alaska,LLC Date: 01/15/2015 24. After detonation,circulate perf gas, confirm well is static, POOH. 25. Run ESP completion. 26. Set BPV. NU tree,test same. 27. Schedule the no flow with AOGCC within 2 weeks of stable production as per regulations. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Current Wellhead Diagram 4. Proposed Wellhead Diagram 5. BOP Stack McArthur River Field, TBU 11 SCHEMATIC Well: D-16RD Ililrorp Alaska.1.1.(: As Completed: 5/8/1981 CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8" 61 1-55 LTC Surf 2,555' i [ 40 N-80 Butt Surf 5,514' 9-5/8" 43.5 N-80 Butt 5,514' 8,059' 47 N-80 Butt 8,059' 9,955' 7" 29 N 80 Butt 9,689' 14,644' Tubing Detail 34/2" 9.3 N-80 ASL Surf 13,543' DV Collar • @ 6,822.74 • JEWELRY DETAIL Depth No (MD) ID Item 1 13,438' Locator Sub 2 13,440' Otis WD 7"x4"packer 3 5'seal bore extension 4 13,483' 3.00" Seal assembly AJ_______ : 5 13,512' 2.75" Otis X-nipple 6 13,543' Mule shoe PERFORATION DETAIL Zone Top Btm Amt SPF Date Status Bench 1 13632 13688 56 8 10/13/1984 F Tubing blocked @ 13985 14000 15 8 4/27/1981 11,507'(10-6-87) 1 Bench 4 14015 14036 21 8 4/27/1981 2 O - 14052 14066 14 8 4/27/1981 3 = 4 5 UM 6 _ p B-1 B-4 14,510'HOW -.EZSV permaneCOnt BP PBTD: 14,600' TD: 14,644' 1cArthur River Field, TBU in : - PROPOSED Well: D-16RD As Completed: Future Hilcorp Alaska,LLC CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8" 61 1-55 LTC Surf 2,555' 40 N-80 Butt Surf 5,514' A \ 9-5/8" 43.5 N-80 Butt 5,514' 8,059' 47 N-80 Butt 8,059' 9,955' 7-5/8" 29.7 L-80 SLIJ-II Surf ±9,689' DV I collar 7" 29 N-80 Butt 9,689' 14,644' 6822 Tubing Detail 3-1/2" 9.2 L-80 Supermax Surf ±9,555' JEWELRY DETAIL I I To, No Depth(MD) ID Item 9,�syL A ±9,680' HangerBottom of ESP PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(ND) Amt SPF Date G-3 ±13,091' ±13,120' ±9,157' ±9,177' ±29' Future G-4 ±13,190' _ ±13,207' ±9,225' ±9,237' ±17' Future G-5 ±13,354' ±13,364' ±9,338' ±9,345' ±10' Future G-5 ±13,440' ±13,450' ±9,398' ±9,405' ±10' Future HK-1 13,632' 13,688' 9,532' 9,572' 56 8 10/13/1984 HK-2 ±13,734' _ ±13,781' ±9,604' ±9,636' ±47' Future G-3 HK-2 ±13,826' _ ±13,843' ±9,668' ±9,679' ±17' Future 0-4 HK-3 ±13,905' ±13,960' ±9,722' ±9,760' ±55' Future HK-4 13,985' _ 14,000' 9,777' 9,788' 15 8 4/27/1981 G-5 HK-4 14,015' 14,036' 9,798' 9,812' 21 8 4/27/1981 HK-4 14,052' 14,066' 9,823' 9,832' 14 8 4/27/1981 HK-1 HK-2 HK-3 HK-4 11 IHOW. - Fisvv,meot Updated: 01/13/15 by JLL i Dolly Varden Platform D-16RD Current 01/17/2015 IGirurp tl.a.k.i.I.I.(. Dolly Varden Tubing hanger,CIW-DCB- D-16RD FBB,11 X 3'/EUE lift X 13 3/8 X 9 5/8 X 3 1/2 3%IBT susp,w/3"type H BPV,6'/."extended neck prep BHTA,CIW,w/internal knockup cap,4 1/16 5M FE ill,.::. .III DSA4/165MX31/85M Valve,Swab,CIW-FL .^` 3 1/8 5M FE,HWO, EE trim E. -'° i jp0 ilib ratit Cross,stdd-5 way, 31/85MX �. 3 1/8 5M X 2 1/16 5M -I lir/ yds. • —1 Valve,Upper Master,WKM- 00 J\ M,31/85MFE,HWO,EE =. 0\ trim -0Y0 1•6 IMO 6•11 11.1^. Valve,Master,WKM-M 3 1/8 5M FE,HWO, 00 d 010\ FF trim '10—(5)0 Void test good NMI„ • 2/23/2012 inn in, 250/S000psi ak- o s • Tubing head,CIW-DCB,13 5/ -'=° 111 , Valve,CIW-F,2 1/16 SM FE, 83MX115M,w/ iii iii HWO,AAtrim 2-2 1/16 5M SSO, X bottom ( off_ a, .i..1 RI 11■, 1 7, )1Void Test Failed Attempted to Packoff will not ��v/ pressure up and stay $1 ,! I I I Packing leaking thru. Believe III1 ' _ that the 9 5/8 casing stub is Casing head,CIW-WF, to breached in void,allowing 13 5/8 3M X 13 3/8 casing mi. am. .1. packing to go into 9 5/8 thread bottom,w/2-2 1/16 III V 111 casing. SM EFO E. j , - 2 Valve,CIW-F,2 1/16 3M FE, III. 1.10-__ItejIlN_ HWO,AAtrim 1 •—.3 r II Dolly Varden Platform D-16 Proposed n,i, wP �1:,.I,,.1.1A01/19/2015 Dolly Varden Tubing hanger,FMC-TC-ESP, D-16 11 X 3'A NS-CT lift and susp, 13 3/8 X 9 5/8 X 3 1/2 300-4 seal pocket,w/3" Type H BPV profile,4-3/8 CCL,Alloy material BHTA,Bowen,3 1/8 5M FE X 3" Bowen Quick Union 1 ,,. i tip MEM Valve,swab,WKM-M, "'^'•' 3 1/8 5M FE,HWO, 0 0 r T-24 r,n - a o0 Valve,WKM-M,3 1/8 5M FE,w/ All i•i 15"OMNI operator Valve,wing,WKM-M, ' o ;(--- 7! 2 1/16 SM FE,HWO, It® ' O�I Q T-24 o �� Valve,lower master,WKM-M, els 0 '� 31/8 SM FE,HWO,T-24 0(O\_ w Me Adapter,FMC-A-5-EC,11 5M rotating flange x 3 1/8 5M rotating top,300-4 pocket prep,2-CCL ports,3.266 centers 1 Pg.. .p11—...i=. --Pills IM. Tubing head,CW-C29L, lel I lu ■ pm Valve,WKM-M,2 1/16 5M FE, 12 1/116 5M SSO,FS ea? i O - , __ HWO,DD bottom prepped f/9 5/8 �i-- —mit 'm ) O `i -I- casing stub - 1lf1 I7 l�! Casing head,CIW-WF, :I• "� , 11111� Valve,CIW-F,2 1/16 3M FE, ��� 13 5/8 3M X 13 3/8 casing f HWO,AAtrim thread bottom,w/2-2 1/16 - _ ��� • , ,li Dolly Varden Platform D-16 Proposed 01/19/2015 Ililrnrp 1.1.34a.Ill, Dolly Varden Tubing hanger,FMC-TC-ESP, D-16 11 X 3 Y.NS-CT lift and susp, 13 3/8 X 9 5/8 X 7 5/8 X 300-4 seal pocket,w/3" 3 1/2 Type H BPV profile,4-3/8 CCL Alloy material BHTA,Bowen,3 1/8 5M FE X 3" Bowen Quick Union 1 an ti, Valve,swab,WKM-M, ' 3 1/8 5M FE,HWO, I„ T-24 45 Valve,WKM-M,3 1/8 5M FE,w/ ii_ OMNI operator Valve,wing,WKM-M, ° �� �I' 21/165M FE,HWO, 10.2 ']�i 0 ,. T-24 - - . - / 1 - ui nY Valve,lower master,WKM-M, 0 r 3 1/8 5M FE,HWO,T-24 P Q zc ®c u WWI I. IMP Adapter,FMC-A-S-EC,11 SM rotating flange x 3 1/8 SM rotating top,300-4 pocket prep,2-CCL ports,3.266 centers Multibowl wellhead assy, .. a,i,IL'_•—J1 ..■•_ Cactus MBS-2 Valve,WKM-M,2 1/16 SM FE, 13 5/8 3M x 115M,w/4- ,'.I�� S HWO,DD 2 1/16 5M SSO,prepped for ��� 7 5/8 mandrel hanger,and Ell d tubing hanger,9 5/8 HPS =NMIllio I_ I ii[0.41��1111.1-bottom ISI Ii1ISI Valve,WKM-M,2 1/16 5M FE, i _', p _ _ 0 HWO,DD i • ; P - E • 1 f r1 ISI i l 1S1 in {Il r Casing head,CIW-WF, a (� les 13 5/8 3M X 13 3/8 casing Valve,CIW-F,21/16 3M FE, thread bottom,w/2-2 1/16 II A HWO,AAtrim 5M EFO IirP 1 1.I.MI't III--'. 11 III Dolly Varden Platform 2015 BOP Drawing (HAK#1) Hdrurp %I:IA.1.I,t.(. Dolly Varden Platform BOP Drawing(HAK#1) Quail Tool Rental Stack 3.42' Shaffer Iil ill I11 I!! 4.54' CD � lM i 2 7/8-5 variables =-t.•mr.l�� Er Blinds ill mill iii In 2.00' i ,• } cr ii I11 Iil I11:it lit - Shaffer LWS 7 5/8 casing rams 1.44' n. 5M ilf Iii I!I I!I III Riser 11 5M FE X 16.00' 11 5M FE iii IJI iii Ii! In 111 3.00' Spacer spool III 11 5M FE X 11 5M FE Ii Iii IIi ',I II Hilcorp HAK#1 BOP Test Procedure Hilcorp Alaska,LLCAttachment#1 Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: Hilcorp HAK #1, Dolly Varden WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing (test)joint to lift-threads d) For ESP wells- Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path,test choke manifold per standard procedure or Hilcorp HAK#1 BOP Test Procedure Hilcorp,uaska,i.I.c Attachment#1 c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection,etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile /penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt.of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same,and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure,close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C-2 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. Hilcorp HAK#1 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 d) Open C-2. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves, to 250 psi low and 3,000 psi high,for 5 minutes each, as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test, open same. ii) Valves, 3, 4, 9. After test, open valves 3 &4. Leave 9 closed. iii) Valves 5, 6, 9. After test, open valves 5 & 6, leave 9 closed. iv) Valves, 7, 8, 9. After test, open all valves. e) Close C-3. This is the HCR(the hydraulic controlled remote)valve just outside C-1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test, open HCR, close C-1. f) Blind Rams. Make sure test joint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test C-1, C-2, and C-4 on the kill (pump-in) side by pressuring up on tubing. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW (or Lower Kelly Valve) and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/- 3,000 psi. 3) Close Annular Preventer,the Pipe Rams, and HCR. Close 2"d set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre-charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/- 30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/-3,000 psi). Note: Make sure the electric pump is turned to "Auto", not "Manual" so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. .i� 4, Hilcorp HAK#1 BOP Test Procedure HileorpAlaska,LLC Attachment#1 Diagram A: Dolly Varden BOP stack and Riser Arrangement—Typical for Single Completion Dolly Varden Platform 2014 BOP Stack MAK #1) v 01/10/2014 II,,....,. I l i Dolly Varden Platform 2014 Workovers BOP Drawing)114K 01) Quail Tool Rental Stack II I, II it I, II I 3.42' 11,h,i, 1,111 111 111 111 111 11; 4.54' 11 I;l ,i11111 III I. 2.00' ' POI*Ill Kill Side Choke side 1.00'to 2.00' 2 1/16 5M w/HCR and Unibolt line 2 1/16 5M w/HCR and Unibolt line connection �!,���I. 1 connection Drill deck Riser 11 SM FE S 16.00' 11 SM FE 1If I 115 f 3 00' Spacer spool 11 SM FE X11 5M FE Itidtuti t1 • i ♦0 Hilcorp HAK#1 BOP Test Procedure Hilcorp Alaska,L�c Attachment#1 Diagram B: Dolly Varden Choke Manifold To Gas Buster All National type To Panic line 2 1/16 5M 1502 Union ball valves IIIII • ■III N / u iiiiiin _a� pe " Chokes are 90 degrees off �.!' { in drawing in order to show / 1 detail _ilTJ :1i= M It SON �II�11 u - ) Swaco 1111 \L__ - ,, . From Bop Choke Line 2 1/16 5M Unibolt Flange S Hilcorp HAK#1 BOP Test Procedure Attachment#1 Hilcorp Alaska,LLC 3� w U J . rr'j1 7 I 6 .( 0.0 1. Q n 0. 1 t?— 0 OC9F- xc) fU 0 o n zi KC o CK U w C A o oz O O — o lL O (w v ui O Z W g a U_ Z1- � D cc a, Hilcorp HAK#1 BOP Test Procedure Attachment#1 Hi!carp Alaska,LLC <u f i X a X s) It I s.)--(vi t wi gr e i 10 1.11 ii i[ _l fYl� w L7 47 Ft • z U (9 05 O OU : ) �u QIP 0 A O O U U] zd _f tL W — - — (.1 w psi = od 5 a 4 _i00 ga u_ Z o S ce Schwartz, Guy L (DOA) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Thursday,January 22, 2015 2:20 PM To: Schwartz, Guy L(DOA) Cc: Juanita Lovett Subject: D-16r TD 180-1101Sundry request follow up Attachments: 10-403`Dolly Varden D-16RD - 2015-01-20 Submitted.pdf Guy In response to your request, here is some additional D-16rd information. D-16rd tested the Hemlock bench 4(HK-4) in April 1981 and then the well was converted to an injector in May 1981.The Hemlock bench 1 was added October 1984 resulting in a +25% rate change.It was shut-in in the late 1980's after 1.28 mmbwi upon determining that it had a channel from the HK4 down to higher permeability HK-5 &6 zones that had already been swept with water This work over will ensure casing integrity and convert the well back to production.The HK2 was never tested or injected into despite having good oil saturations so with the offset well D-14rd on injection it has excellent potential as a producer. Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowehilcorp.com Hilcorp A Company Built on Energy 1 Im~' Project Well History File Covff" '~age XHVZE This page identifies those items that were not scanned during the .initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. L~D_- 1../_~)_. Well History File Identifier Organizing : %.,.,. RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: Poor Quality Originals: [] Other: NOTES: [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERYL(~~V~/INDY Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Project Proofing BY; BEVERLY ROBIN VINCENT SHERYL~WINDY Scanning Preparation '~ x 30 = ¢~ BY: BEVERLY ROBIN VINCENT SHERYL~WINDY + ~ = TOTAL PAGES Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES /~ NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: .... YES _.~_. NO (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION I$ REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) RESCANNEDBY~ BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Is/ General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd ) Unocal Alaska Resourc ) Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCALe .r....~ .?"""'. C"'" fi.'IWOIO ¡.,~ ¡: r¡"""'" ~~.~., ,~.\,:,,,. t"",·' þ;.. " ('"""'" N ~ I~'\. b' L..... . .:tJ [...... ~..."t;' :SEP CJ September 6, 2005 ~'_"G! & GiB Q;,r~. (~fti£'~(fj ft;:~\~~~ V~b-+J.,() Hal Martin Reservoir Engineer ~."'" \}~ ~.,.'G) ~..~.~ '" .., .~. ___ " ~~'() \\ '-.. ." Y $.t> ,\: C l-\~~ --o~(~ <" .-'<-- 7 \: S X- Ú" ~~' ..' ~,-~""'-' 't)~ XÐ \<ofCj ~h~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 ~ ASSESSMENT OF WELL UTILITY TRADING SAY UNIT WELL NO. D-16RD PERMIT NO. 180-110 SUNDRY APPROVAL NO. 302-267 DOLLY VARDEN PLATFORM McARTHUR RIVER FIELD " v 2" 0 f\l; ~)C¡~\!\~~~~:;D J ¿j) . I ("J Dear Tom: I n response to a request by the AOGCC on a Sundry Approval (No. 302-267) for Dolly Varden Well No. D-16RD (Permit No. 180-110), McArthur River Field, Chevron submits the following information concerning an assessment of the future utility of this well. Well No. D-16RD, an injector which was shut-in in October 1985 when the tubing became plugged, will continue to be considered as a future workover candidate. " '"I Please note that this information has been reported to the AOGCC (Mr. Jack Hartz) yearly on an annual shut-in well report. However, in the event that this report is not sufficient as a response to the sundry or has not been reaching you, we are additionally notifying you through this submittal. Attached for informational purposes are copies of the annual shut-in reports for 2002, 2003, and 2004 mentioned above, a copy of the sundry, and a schematic. Chevron will monitor and record daily injection rates and tubing and casing pressures on the well and provide a report to the AOGCC on a monthly basis. A Shut-in MIT will be run every two years to insure integrity of the tubing and casing. Please call me at (907)263-7675 if you have any questions. Sincerely, k/h~L ) Hal Martin JHM:jll Attachments O:\OOE\OOEFields\TBU\Dolly\Wells\D-16RD\State_Forms\Correspondence\D-16RD Sundry Response Sep05.doc UNION OIL COMPANY OPERATED PROPERTIES WELL DATA FIELD 11W)INGBAYtUNR;;'¿;DOUiY.fV1\:RDEN~lI~ff SUMMARY Trt(jj1NGB'Ä¥:'tiNìtf.<GItÃYìifl(~.M.Jftm SUMMARY TRADING1í*~~G"S'Å.W~_~-n SUMMARY WELL D-6RD 0-16RD 0-22 0-30RD2 0-11 D-40RD NO WELLS ~~ 0-9 NO WELLS '''1, _,~ K-2RD K-6RD K-5 K-9 K-20 K-21RD K-23 NO WELLS "':1::.11;;:.:1 Information for AOGCC on Shut-In WeDs Reg 20 ACC 25.115 DATE SHUT-IN MechanJc:a1 Condition Dec-OO Tubing and casing in good condition Oct-85 Casing damage Dec-82 Leaky tree - couldn't repair Nov-91 Perforations covered Nov-Ol No known damage Sep-Ol Shallow hole in tubing near #2 OLM JUI-98 NO known damage Mar-99 Plug stuck in tubing Sep-98 Tubing and casing full of sand Apr-96 Can't get down to perforate Oct-96 Full of sand, Holes in casing. Dec-95 Tubing sanded up Jun- 79 Tubing integrity in question Sep-97 Tubing full of sand Page 1 Why well was Shut-In /k i!l!i03 ÞIf- Future Utility of Well 100010 Water Cut Tubing blocked Leak in tree Will not flow Stopped producing Stopped producing Will begin injection shortly . Possible WO candidate Possible WO candidate for O-Zone inj. PtanDed WO to fuel gas groducer Possible WO to water injector Possible WO to ESP -' OffOfStructure- No help Planned redrill candidate Will not flow No Flow No Flow Gas Well No Flow No Flow High water cut High water cut Planned WO to injector. Potential redrill candidate in Hemlock Potential WO for platfonn fuel gas. Potential redriIl candidate for G-Zone or Jurassic Planned WO candidate for platfonn fuel gas. Potential redrill candidate in Jurassic Potential redrill candidate. -1, Download_SteveMcMaines.xLSSbuUn_ Wen_status UNION OIL COMPANY OPERA TED PROPERTIES WELL DATA FIELD WELL ~_JlliaVARDEN D-6RD D-16RD D-22 D-30RD2 D-11 D-40RD SUMMARY NO WELLS , i , T!fti~T1I UL1lli ~f~"~G 0-8RD 0-9 0-23RD 0-30 0-34 SUMMARY NO WELLS III . :.-,':'.). .:;~., §'":,', .~.;nll"~.·'·_ ~~~1BJiII~)i: ~~~"'! ,'. _.' '_ ,.:_1 .AD M-l SUMMARY NO WELLS iJli'il& Information for AOGCC on Shut-In Wells Reg 20 ACC 25.115 DATE Mechanical Condition SHUT-IN Dec-OO Tubing-to-casing communication Oct-85 Casing damage Dec-82 Leaky tree -- couldn't repair Nov-91 Perforations covered Nov-Ol No known damage Sep-O 1 Shallow hole in tubing near #2 OLM Sep-02 E-Line wire in LS. Jul-98 No known damage Oct-02 Tubing-to-Casing Communication Jun-02 Slickline fish in SS. Sep-02 No known damage Aug-02 repaired casing patch in 2003 Why well was Shut-In Failed MIT Tubing blocked Leak in tree Will not flow Stopped producing Stopped producing Low oil production from LS. Off of structure- No help Failed MIT Low oil production from LS. Low oil production from LS. sand production Page 1 Future Utility of Well fl4 rl //1/051 A IT AcíÎrnr6' 1 . '~ Possible restore injection Possible WO candidate Possible WO candidate for O-Zone inj. Possible WO to fuel gas groducer Possible WO to water injector Possible WO to ESP Potential redrill candidate. Potential redrill candidate. Possible restore injection Potential redrill candidate. Possible WO to water injector return to production I move uphole ~ -- W eICCouncShuCIn_Status_2004_Complete.XLSShucIn_ WelCStatus UNION OIL COMPANY OPERA TED PROPERTIES WELL DATA FIELD WELL _ARDEN D-6RD D-16RD 0-22 0-30RD2 D-40RD 0-18 0-28 0-42 SUMMARY NO WELLS ~.~X~ '~_NG 0-8RO 0-23RO 0-30 0-34 0-19 0-24 SUMMARY NO WELLS c~· Information for AOGCC on Shut-In Wells Reg 20 ACC 25.115 DATE SHUT-IN Mechanical Condition Dec-OO Tubing-to-casing communication Oct -85 Casing damage Oec-82 Leaky tree -- couldn't repair Nov-91 Perforations covered Sep-Ol Shallow hole in tubing near #2 OLM Oec-03 No known damage Nov-03 Tubing leak just above packer Jun-03 Failed ESP Sep-02 E-Line wire in LS. Oct-02 Tubing-to-Casing Communication Jun-02 Slickline fish in SS. Sep-02 No known damage Oct-03 Tubing-to-Casing Communication Mar-03 No known damage Why well was Shut-In Failed MIT Tubing blocked Leak in tree Will not flow Stopped producing Made too much sand and water Mechanical integrity problem High Water Cut Low oil production from LS. Failed MIT Low oil production from LS. Low oil production from LS. Limited Injection Water High Water Cut Page 1 Future Utility of Well , JJ--6ý/ /I/~'-- ,77:;> / 05 (, ( . E;ilv . / / I Possible restore injection Possible WO candidate Possible WO candidate for G-Zone inj. Possible WO to fuel gas groducer Possible WO to ESP Possible uphole recompletion Possible W orkover Possible Redrill ~ V -' Potential redrill candidate. Possible restore injection Potential redrill candidate. Possible WO to water injector Possibly restore injection at a later date. Possible W orkover / Redrill WelCCounCShut_In_Status_Jan05 Rev.XLSShucIn_ WelCStatus 1 3 - 3/8", 6 J#, J - 5 .... 2555' 3-%", 9.3', N-80 7" Liner Top 9689'_ Casing Window 9-5/811, 40, 43.5, .4719SS5~ W-80 Mule Shoe 13,54311 711, 291, N-80 14,644' ) TBU WELL D-16RD COMPLETION SCHEMATIC ) . Co.~l.ted 5-81 / Completed on 5-8-81 Injecting II~O BWPD at 3800 pai into Bench 4 of the B..lock formation. .. ;, .....-. . I .... - ~ ~(. =:( Tubing blocked @ 11,507', .10-6-87 Locat~r 8ub 2' above packer Ot~s WD 7" x 4'" packer @ 13~440' 5' seal bore extension .Seal assembly' 13,483' - 503' 3.00" ID Otis X-nipple @ 1 3 , 51 2 " 2. 7 5 " I D ~ . ) Avg. Dev. - 47.3° Bench 13,632' - 13,688' DIL . - Bench 4 13,985) - 14,000' DIL 14,015' 14,036' 14,052' - 14,066' >< Howco EZSV permanent BP ~. 14,510' Float collar @ 14,600' ¿ '. WEC 2/89 • • 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) rr^^ Subject: II Inspections ' ect: Do s J Y p 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. 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 ED APR ti 6 `[)11 1 (' STATE OF ALASKA ', ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: X Perforate: Other: X (convert to inj.) 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: 106' KB above MSL feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: X Trading Bay Unit 4. Location of well at surface Leg B-1 Conductor 5 8. Well number 675' FSL & 1228' FWL of Sec.6. TSN. R~V, SM Dolly Varden D-16RD At top of productive interval v/, .,/r__ 9. Permit number/,.~ 2,087' FNL & 406' FEL of Sec.17, TSN, R13W, SM 180110{/' ~..x At effective depth 10. APl number 2,630 FNL & 754' FWL of Sec. 17, TSN, R13W, SM 50-733-20183-01 At total depth 11. Field/Pool 2,707' FNL & 796' FWL of Sec.17, TSN, R13W, SM McArthur River/Hemlock Pool 12. Present well condition summary ./' V Total depth: measured 14,645' feet Plugs (measured) 14,510' BP true vertical 10,265' feet 14,600' - 14,644' CMT Effective depth: measured 14,510' feet Junk (measured) 11,507' Tubing blocked true vertical 10,160' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor S u rface 2,555' 13-3/8" 2,555' 2,347' Intermediate 9,955' 9-5/8" 9,955' 7,095' Production Liner 4,955' 7" 1,235 sx 14,644' 10,265' Perforation depth: measured Bench I 13,632' - 13,668' MD 9,532' - 9,558' TVD Bench 4 13,985'-14,000'MD 9,777'- 9,787'TVD .;.~ ~""' ~..,,, ~ ,~ !~ ~'~ true vertical Bench 4 14,015'-14,036' MD 9,797'-9,812' TVD ~,ii~ ~', i~'"'~ ~..,~,i ..... Bench 4 14,052' - 14,066' MD 9,823' - 9,832' TVD ;.'. · ' ''''''~''''' ~ ...... ~ ..... Tubing (size, grade, and measured depth) 3-1/2", 9.3#,N-80 @ 13,543' .~ Packers and SSSV (type and measured depth) Otis WD Pkr. @ 13,440' '~""~"" ' 13. Attachments Description summary of proposal: Detailed operations program: BOP sketch: Well schematic X Pressure test X 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: X 17. I hereby certify that th.J.b.e~egoing is true and correct to the best of my knowledge. · Jeffery J~Oolan /' · ,/~'~ ~ Signed: ~;~ ~-//~ FoRTitle:cOMMISSIoNWaterfl°°d technicianusE ONLY Date: 8/20/2002 Conditions of approval: Notify Commission so representative may witness ~Approval No " Plug integrity. BOP TestI ~)°'~° ~ ~0 ''~ ~ Location clearance. ~','~ Mechanical Integrity Test ~ Subsequent form required 10- ~O'~--~"~'~'%~Cr~.~,Ik ~ ! Approved by order of the Commissioner ~ ~ Comm,ss,oner Form 10-403 Rev 06/15/88 k BDP,4S BFL ORIGINAL 8 ~0~UBMIT IN TRIPLICATE 9. L:~2 8: 50AM. . { (,- P.~'3 ,Pmcedu _re_for M~_on D:18RD Shut.in lniectar 1. Record daily tubing, casing, and outer casing pressures for a consecutive three day period. Change casing pressure by increasing'the 9 518' casing annuli by 200 I~.i. Continue recording daily tubing, casing, and outer ~asing pressures for an additional, consecutive, four-day period. D-16RD 8301 I1,| ! · iii ,I I I /Ed , , ,fl" ,,~ 16RD II " '" - I . ! I· 100 1:2<3 ,' __ _ ii _ . ii i I · i | BAY UNIT i .i i %d[~- i I'It. II 9-S/aa, 40, ·13.5, 4711 9955", LI-LtO ' .-.,. · 14u.Le Shoe 13,5,13' CoepJ. eeecT on 5-9-6.1. _ Znjecr-Lng ~5o ~-mo at 3800' psi.. into ~enc~ 4 og .- Avg.:. 0ev.-47.3° · · ., 7", 201, ti-80 ~.4~6.!.4' Bench 1 ~ench 4 . · · . ... 13,632' - ~3,668' m~ 13,985' - 14,~00' P~ 14,015' - ~4,036~ 14,~$2' - I4,066' /o~o.gZb'Vl:~_.t~nent ~' 9 14,510' , . F]oabcollar @ 14,600' ' 9-2-87 !'IEC ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: X Perforate: Other: X (convert to inj.) 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: 106' KB above MSL feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: ~ Trading Bay Unit 4. Location of well at surface Leg B-1 Conductor 5 8. Well number 675' FSL & 1228' FWL of Sec.6, TSN, R13W, SM Dolly Varden D-16RD At top of productive interval 9. Permit number 2,087' FNL & 406' FEL of Sec. 17, TSN, R13W, SM 1801100 At effective depth 10. APl number 2,630 FNL & 754' FWL of Sec. 17, T8N, R13W, SM 50-733-20183-01 At total depth 11. Field/Pool 2,707' FNL & 796' FWL of Sec. 17, T8N, R13W, SM McArthur River/Hemlock Pool 12. Present well condition summary Total depth: measured 14,645' feet Plugs (measured) 14,510' BP true vertical 10,265' feet 14,600' - 14,644' CMT Effective depth: measured 14,510' feet Junk (measured) 11,507' Tubing blocked true vertical 10,160' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor S u rface 2,555' 13-3/8" 2,555' 2,347' Intermediate 9,955' 9-5/8" 9,955' 7,095' Production Liner 4,955' 7" 1,235 sx 14,644' 10,265' Perforation depth: measured Bench 1 13,632' - 13,668' M D 9,532' - 9,558' TVD Bench 4 13,985' - 14,000' M D 9,777' - 9,787' 'I'VD true vertical Bench 4 14,015'-14,036' MD 9,797'-'9,812' TVD !'% ii!!:. ...... ...~ ..~.. ~,...,/ ...... ~ ..... ii ..;' i~ Bench 4 14,052' 14,066' M D 9,823' - 9,832' TVD ";';; "~ ii'"" ii ',~, ? Ii"" !:J ,,i' Tubing (size, grade, and measured depth) 3-1/2", 9.3#,N-80 @ 13,543' Packers and SSSV (type and measured depth) Otis WD Pkr. @ 13,440' ..,.-.,~,J t'? ............ 1~. Attachments Description summary of proposal: Detailed operations program: BOP sketch: Well schematic X Pressure test X 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: X 17. I hereby certify that~J3~oregoing is true and correct to the best of my knowledge. Jeffery .yl'3nl~p_~ '/.,,..,~.,,"~, ! ~(~ Signed: ..._- _._~ ,._,, Title: Waterflood technician Date: 8/20/2002 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witnessIIAppr°val No__o~:~ ~,~ Plug integrity~ BOP Test Location clearance "~ ~'~"~ Mechanical Integrity Test ~1~ Subsequent form required 10- Approved by order of the Commissioner Commissioner Date =, Form 10-403 Rev 06/15/88 DUPLICATE SUBMIT IN TRIPLICATE NOTE TO FILE Trading Bay Unit (TBU) D-16RD PTD 180-110 302-267 Unocal has submitted a "shut-in MIT" to demonstrate that this shut-in injection well does not present any risk to resources or fresh water. This note evaluates Unocal's request and recommends approval of it. According to the RBDMS database, this well has not been in service since late 1985. The file does not have much information since the original completion in early 1981. A workover was proposed in early 1987, however that was cancelled. The file does have a letter requesting Unocal to submit the bond logs for several wells, including D-16RD. There is a record in the MIT binder that Blair examined the bond log on 9/14/88 and determined that isolation was acceptable. It is unclear why the well has not been in service for so long. The monitoring information provided is similar to that submitted in 1998. In the submitted information, the initially observed pressures are 0/95/0 (tubing, IA, OA). 200 psi is applied to the IA with the resultant observed pressures of 0/295/240. The IA and OA pressures decline through the remaining 4 days of observation. The IA and OA pressures do not equalize, although the final differential is small. It is possible there is communication between the IA and OA. Area Injection Order 5 allows injection into Trading Bay Unit, McArthur River Field. The BHL of well K-2RD is located in the covered area. The portion of aquifers beneath Cook Inlet described by a 1/4 mile area beyond and lying directly below the Trading Bay Unit are exempted for Class II injection activities by 40 CFR 147.102(b)(2)(B) and 20 AAC 25.440(c). Granting Unocal's request will not endanger any fresh water. I recommend acceptance of the submitted observation information. Unocal should add this well to the monthly monitoring report and plan to perform another "shut-in MIT" in August 2004. Unocal should be reporting this well as required by 20 AAC 25.115 (a) [Shut-In Wells]. In addition to those requirements, Unocal should provide an assessment of the future utility of this well prior to the end of 3rd quarter 2003. Tom Maunder, PE Sr. Petroleum Engineer April 8, 2003 M:kUIC File Reviews\030408-TBU D-16RD.doc MECHANICAL INTEGRITY REPORT WELL DATA Cas lng: Shoe: MD TVD; DV: MD TVD Liner: 7¢~, ~J Shoe: [~~MD Tubing: F~ ,. Packer Hole Size 7~:'~ 8~'"'~. and TVD; TOP: 9&~ MD TVD .TVD; Set ~ Perfs tE,98~- to MECHANICAL INTEGEIT~ - PART Annulus Press Test: IP 1.5 rain . . .; 30 rain Co~w. ents.~ ' MECHANICAL INTEGRITY - PART ~2 ~ ~'t~' ~ :' · ~r&B Cement Volumes'.: Amt. Liner 1 2 E $"Z~.; Csg, ; DV . ~" '~,,. ~ '(os3 Cmt vol to cover perfs ~mr~~te r,~~+ /e.~,~ ~e ~.~ , Theoretical ToC ~,, ~g~c';~' 6 ~,,~ ~ ~,$ ~ &e ~. Cement Bond .Log (Yes or No) ~/~ ; In AOGCC.File CBL Evaluation, zone above perf.. Produc.tion LoE: T~e ; Evaluation ,, CONCLUSIONS: .. Part ~1: rev. 05/20/87 C.028 JUN-29-98 MON 13:41 UNOO~L ..~SET (~S C-RP NO. 9072637874 t' P. 01/01 Unocal Corporation 909 West 9* Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 UNOCAL June 29,1998 Wendy Mahan Alaska Oil and Oas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 DearWendy, Re: Status of Unocal's Cook Inlet Injector Work This letter is to provide you with an update of the work conducted since our March 27, 1998 letter which you signed granting time extensions for various wells. Testing or work was comoleted on the followitlg Anna 4642 'l-z King 4RD -g~-a'5'l King 15RD ~olly D- ! 6RD ~l-lO~ Dolly D-22 Grayling 22 Grayling 36DPN Monopod A- 12RD2 Monopod A-29 Baker 9 King 22RD wells and the results of. this work is listed: : SI MIT approved on 4/17/98. : SI MIT approved on 4/17/98, workover soheduled. : SI MIT approved on 4/17/98. Jug test proved communication, workover scheduled. : SI MIT approved on 4117198. : SI MIT approved on 4/17198. : Workover completed on 4/19/98. : Workover completed on 4128/98. : SI MIT approved on 6/03/98. : SI MIT approved on 6/03/98. : SI MIT approved on 6103/98, planning acid treatment to clean tubing for testing, : Variance granted on 6/09/98, Jug test proved casing integrity. Anna 27-42 :Coil Tubing clean out completed on 6125/98, further testing scheduled to prove casing integrity. Anna 19-42 :Coil Tubing cleanout completed on 6/27/98, further testing scheduled to prove casing integrity. Granite Point 33-14RD: Wireline fishing continuing to remove wire and wireline fish from well. Grayling 5 : Redrili in progress. Testing or work was attempted on the following shut..-in wells an..d a time extension until September 30, 1998 requested to complete further work and testing SS -o~, Anna 19-42: Coil Tubing clean out completed on 6/27/98, further testing scheduled to prove casing integrity. ",Fi' .o1~, Anna 2742: Coil Tubing clean out completed on 6/25198, further testing scheduled to prove casing integrity. · an - 0-4 Grayling 28: Coil Tubing eleanout planned to follow currently active rig program. ~o- o~, Grayling 40: Workover schedule in current rig schedule. n~-o4z. King 4RD : SI MIT granted on 4117198, workovor scheduled. ':l"t - ~%4King 15RD: SI MIT granted on 4117/98. Jug test proved communication, workover scheduled. As you can see we are making excellent progress. Unocal respectfully requests a time-extension until September 30, 1998 to complete the work on the above listed Anna wells. The Grayling and King work will be executed per our current drilling schedule. Please call me if you have any questions or clarification on these issues. Cook Inlet Waterflood Management Please acknowledge the approval of the time extension and your r~ccipt of this letter by faxint/back a si~.lled~arw of this letter to Christopher Ruff at 263-7874 (fax). "' " Wendy-'~ahan Date ' JUN 2 9 1998 AOGCC ' " AP~:±15-98 lIED 13:28 UNOOAL A~qET GAS GRP ( FAX NO. 9072637871.. P. 01703 Unocal Corporation Agricultural Products 909 West 9'~ Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone {907) 263-7830 UNOCAL ) Bo,. Ii o Re: Trading Bay Field 1~--~.% DOLLY VARDEN~ D-22 Dear Wendy: April 9, 1998 Wcndy Mahan State of Alaska Alaska Oil and Gas Conse~ation Commission 3001 Porcupine Drive Anchorage, AK 99501 RECEIVED /-',PR 15 1998 Alaska Oil & Gas Cons. Commission Anchorage This letter is to document your approval of Dolly Varden D-16RD and D-22 Shut-In MIT's. Attached is a copy of the pressure readings completed in April 1998. Please review this data. If these wells pass their Shut-In MIT, please sign and send a copy of this letter to my fax at 263-7874 otherwise call mc at 263-7830. Senior Reservoir Engineer Cook Inlet Waterflood Management Please return a signed and dated copy of this lcttcr to document notification for our records. Wend~an Date AOGCC Aogcc Dolly D-16 & D-22 SI MIT. doc 04/15/98 5-98 WED 13:29 UNOOP, L PI~qSET G~qS GRP Ft~X NO. 907263787~ P, 03/03 Procedure for MIT on Shut-in Doily Varden Injector D.16RD 1. Record daily tubing, casing, and outer casing pressures for a consecutive three day period. 2. Change current casing pressure by 100 psi.. Continue recording daily tubing, casing, and outer casing pressures for a consecutive four day period. 3. Fax completed form to Steve Tyler, fax # (907) 263-7874, Phone # (907)263-7649 R E C E IV E D Alaska Oil & Gas Cons. Commission Anchorage Outer. Ca.,,sing. Pressure Date Tubing Pressure Casing Pressure,, L13'318" 20" 4/2/98 0 122 0 0 4/3/98 0 ' 'i'~2 ..... 0 0 4/4/98 0 "' 122 ' 0 ............. O' , , ......... 4/5/98 0 122 0 0 4~6~98 0 38 0 ...... 0 .... , 4/7/98 0 46 0 0 , . . 4/8/98 0 53 0 . 0 ............... 4/9/98 0 57 0 0 , , ,, 4-2-~8 pulled & tested gauges 4-5-98 bled casing ~ 08:30 to 13:30 Teleeopy (907) 276-7542 October 27, 1988 D K Corle=t Hegion Opera:ions Eng Marathon Oil Company P 0 Box 190168 Anchorage, AK 99519 Dear Hr Corle::: . :..: .... . . On Sep:ember 26, 1988 we received :he cemen: bond logs On wells . . , . D-6RD, D-15 RD2, D-16RD, D-24A, and D-29RD. · . . -. Thank 7ou for 7o'ur promp~ help. '""" '""' SincerelT, Blair E Wondze11 Sr Pe:r Engineer Jo/A.BEW. 122 Alaska Region Domestic Production Marathon Oil Company RO. Box 190168 Anchorage, Alaska 99519 Telephone 9071561-5311 September 23, 1988 Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Sir: Enclosed are sepia copies of the cement bond logs you requested for Dolly Varden water injection wells D-6RD, D-15RD2, D-16RD, D-24A, and D-29RD. Should you have any questions or require further assistance please contact Mr. Norm Fahnholz at (907) 561-5311. Sincerely, D. K. Corlett Region Operations Engineer NEF/em/878/OE34 A subsidiary of USX Corporation STATE OF ALASKA I~ ALA'~ , OIL AND GAS CONSERVATION CO $SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] Notice of Cancellation for Proposed Workover 2. Name of Opera.[or UNOCAL 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Location of well at surface Leg B-l, Cond. 5 Dolly Varden Platform 675' FSL, 1,208' ~3/~L, Sec. 6-8N-13W-SM At top of productive interval 2,087' FNL, 406' FWL, Sec. 17-8N-13W-SM At effective depth 2,630' FNL, 754' FWL, Sec. 17-8N-13W-SM At total depth 2,707' FNL, 796' FWL, Sec. 17-8N-13W-SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Tradin_~ Bay Unit 7. Well number D-16RD 8. Approval number 7-282 9. APl number 50-- 733-20183-01 10. Pool Hemlock Feet 11. Present well condition summary Total depth: measured true vertical 14,645 ' feet Plugs (measured) 10,265' feet 14,510' BP 14,600' - 14,644' CMT Effective depth: measured true vertical · Casing Length Structural Conductor Surface 2,555' Intermediate 9,955 ' Production Liner 4,955' Perforation depth: measured 14,510' feet Junk (measured) 10,160' feet Size Cemented 13 3/8" 9 5/8" None true vertical ~bing(size, grade and measured depth) 3 1/2". 9.3#, N-80 @ 13,'543' Packers and SSSV(type and measured depth) Otis WD Pkr. @ 13,440' Measured depth 2,555' 9,955' 7" 1,235 sx 14,644' Bench 1 Bench 4 Bench 4 Bench 4 13,632' - 13,668' MD 13,985' - 14,000' MD 14,015' - 14,036' MD 14,052' - 14,066' MD True Vertical depth 2,347' 7,095' 10,265' 9,532' - 9,558' TVD 9,777' - 9,787' TVD 9,797' - 9,812' TVD 9,823' - 9,832' TVD RECEIVE , 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure SEP o 2 1987 Alaska 0ii & Gas Oons. Cem~llRI Anchorage 13. Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation 14. Attachments .. Daily Report of Well Operations [] Copies of Logs and Surveys Run E~ .. 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~-'"'~'~O -o°7 * Marathon 0il Company - Sub Operator Signed j~% /~Zz~/'~,~-c. /~~ Title Form 10-404 Rev. 12-1~85 ~.oy O. ~~~ Environmental Engineer Submit in Duplicate e' · STATE OF ALASKA AL~'. , OIL AND GAS CONSERVATION CO~,. 3SION APR2 0 19 APPLICATION FOR SUNDRY APPROVALS C: W. LocKWOOD 1. Type of Request: Abandon 1-'1 Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension ~ Change approved program [] Plugging [] Stimulate [] Pull tubing ~ Amend order [] Perforate ~ Other 2. Name of Oper~or UNOCAL 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Location of well at surfaceLeg B-l, Cond. 5 Dolly Varden Platform 675' FSL, 1,208' FWL, Sec. 6-SN-13W-SM At top of productive interval 2,087' FNL, 406' FWL, Sec. 17-8N-13W-SM At effective depth 2,630' FNL, 754' FWL, Sec. 17-8N-13W-SM At total depth 2,707' FNL, 796' FWL, Sec. 17-8N-13W-SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name TradinK Bay Unit 7. Well number D-16RD 8. Permit number 80-110 9. APl number 50-- 733-20183-01 10. Pool Hemlock feet 11. Present well condition summary Total depth: measured true vertical 14,645' feet Plugs (measured) 10,265' feet 14,510' BP 14,600' - 14,644' CMT Effective depth: measured 14,510' true vertical 10,160' feet Junk (measured) None feet Casing Structural Conductor Surface 2,555' Intermediate 9,955 ' Production Liner 4,955 ' Perforation depth: measured Length Size 13 3/8" 9 5/8" Cemented Measured depth True Vertical depth true vertical ~bing(size, grade and measured depth) 3 1/2", 9.3#, N-80 @ 13,543' Packers and SSSV(type and measured depth) Otis WD Pkr. @ 13,440' 12.Attachments 1 & 2 2,555' 9,955' 7" 1,235 sx 14,644' Bench 1 Bench 4 Bench 4 Bench 4 13,632' - 13,668' MD 13,985' - 14,000' MD 14,015' - 14,036' MD 14,052' - 14,066' MD 2,347' 7,095' 10,265' 9,532' - 9,558' TVD 9,777' - 9,787' TVD 9,797' - 9,812' TVD 9,823' - 9,832' TVD of proposal ~ Detailed oper~'~l~,.,..-. ~.---- "-'"-'~. UBOP sketch Description summary Atta-dhment 13. Estimated date for commencing operation April, 1987 APR 2 2 1987 14. If proposal was verbally approved Name of approver 0ii & Gas Cons. Commission Anchcmn, e , Date alSproveo 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ ~~..~..~ Ti t I e ]~rv-ironme~tal ]~3.gineer Date 4/20/87 '~3 ~ O' ~~ Commission Use Only Conditions of approval Notify commission so representative may witness J Approval No. ~ Plug integrity ~ .BOP Test ~ ~cation clearanceJ ~' ~~ Approved by ~ _~ -/~ ~'~~ commis;i°ne;'- the commission Date yZ~/~ J Form 10-403 Rev 12-1-85 ' ' / / S~mit in'triplicAte Attachment #1 Well D-16RD Workover Procedure 1. Skid Rig #76 over Well D-16RD. 2. Fill tubing and casing with FIW. Perforate circulation holes in tubing @ 13,300'. Kill well by circulating FIW. 3. Set BPV. ND X-mas tree. NU and test BOPE. 4. POH and LD tubing. 5. PU DP and rotary mill. Mill packer at 13,440'. Cleanout to PBTD. 6. RU electric line. Run casing inspection log. 7. Pressure test casing with retrievable packer and bridge plug to locate casing leaks indicated by casing inspection log. 8. Squeeze casing leak(s) as directed by Anchorage Drilling Department. Note: If it is determined that a 7" tieback liner is required, a change of procedure will be forwarded at that time. 9. Drill out cement squeeze(s) and test each squeeze. Pressure test 7" liner and 9-5/8" casing as required by AOGCC regulations. 10. Perforate Hemlock as follows: Bench 1 Bench 2 Bench 3 Bench 4 Bench 4 Bench 4 Bench 4 13,632' - 13,668"DIL 13,730' - 13,780' DIL 13,825' - 13,850, DIL 13,925' - 13,960' DIL 13,970' - 14,000' DIL 14,015' - 14,036' DIL 14,050' -.14,102' DIL 11. Run packer and 'completion assembly. 12. ND BOPE. NU and test X-mas tree. NOTE: BHP is 3,750 psi @ 9,450' TVD. Workover fluid will be seawater and/or KCI brine weighted.to keep the well overbalance. Sized salt pills will be used as necessary to prevent excessive fluid loss. JMG/em/34/Sundr2 APR 2 2 A~,ska Oi; & G~s Cons. Commissio,~ ATTACHMENT #2 Well D-16RD (Current)'. 2,55.5' 13-3/8" csg. 9,689' 7" liner top 9,955' 9-5/8" csg 3-1/2" 9.3# N-80 [ [] '< 13,440' Otis WD pkr 13'512' Otis "X" nipple 13,543' Hule Shoe ., Perforations DIL 13,632' - 13,668' 13,985' 14,015' 1&,~52' 11,510' 14,600' 14,644' '- i4,000' - 14,036' - 14,066' APR 2 2 · . ~.~; Ataska, Oil & Gas Cons. Commis~ Bench 4 . · . Bench 4 Bench Howco EZSV BP Float collar 7~' 29~ csg (P~oposed) 2,555' 13-3/8" csg .. 9,689' 7" liner top 9,955' 13-3/8" esr 3-1/2" 9.3~ N-80 w/Premium cplgs ± 13,400' pkr -+ 13~ 460' Tbg tail -. Perforations (DIL) Bench 1 13,632' - 13,668' Bench 2 13,730' - 13,780' DIL Bench 3 13,825' - 13,850' DIL Bench 4 13,925' - 13,960' DIL Bench 4 13,970' - 14,000' DIL Bench 4 14,015' - 14,036' DIL Bench 4 1&,050' - 14,102' 14,510' Howco EZSV BP (._._._14,600' Float Collar ~.14,644' 7' 29# csg ATTACHMENT ~3 - MARATHON OIL GO.- Pon ~ Fiowli~¢ __ Driilino~ blippl* -- DOLLY VARDEN PLATFORM -- U I 0 0 0 0 .~"~ 5,000~-.Ki;l D~ill Deck Floor -- Diac. tr~rn~ P_- l=J~/8'!x 5,000~ Riser ~-BOP £,cxck For Drillin~' From UhdCr IB3/s" ,,Sur~(~c,e G~sin8 To -F.D.-- Well I-I l_o APR221.987 ' o _m~~ Oil & Gas Cons. Commi~s[~~ An~hcmge ' ' Room Floor o o IJ~ok¢ L;n~. S'~ S, ooo CIW £win~-Boit Clamp" Conneotor$ Ff. Bpool 1-1 Collect 3:3' C. onduc~or Union Oil and Gas Division: Western Region Union Oil Compaq'- California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unlen October 30, 1984 Mr. Chat Chatterton AK. Oil & Gas Conservation Commission ~OOi Porcupine Drive Anchorage, AK 99504 Dear Mr. Chatterton: Attached are Sundry Notice Subsequents on D-2A, D-6RD, D-I6RD and D-4ORD for your information and fiie. LOC:ti Attachment Very truly yours, Lawrence O. Cutting Environmental Technician RECEIVED Nov o 2 ]9~4 Alaska Oil & Gas Cons. Commission Anchorage STATE Of ALASKAi" ALA' .A OIL AND GAS CONSERMATIC,,. 3OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL I-I COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. Union Oil Companv of C~lifornia* 80-110 3. Address 8.'APl Number P.O. BOX 6247 An~horaqe, AK 99502 50- 733-20183-01 4. Location of Well Surface: Leq B-1, C~nd .~5, Dollv Varden Platform 675' FSL, 1208' FWL, Sec. 6-SN-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106' KB above 12. 9. Unit or Lease Name .~radina Bay Unit 10. Well Number 11. Field and Pool. I6. Lease Designation and Serial No. ADL- 17579 Check App[opriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) .. Perforate [] ~lte'r Casing [] Perforations Stimulate [] Abandon [] Stimulation ,. . Repair Well [] 'change Plan'~ ' [] " Repairs Made Pull Tubing [] Other [] Pulling Tubing (NOte: Report multiple completions on Form 10-407 with a submitted Form 10-40'7 for each completion.) Nc.Arthur ~iver 'mield (Submit in Duplicate) [] : Altering Casing ,.. [] Abandodt'nent ' [] 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 Abando'nment se? 20 AAC 25.105-170). .1 ,. D-1fRr) OPEN BENCH ~1 ~OR IBIIECT. ION On Oc. tober 13, 1984, the ~.11 was perforated with 2-1/R" quns at the fol].owinq interval: Bench ~1 '13,632" - 13,668' DIL, 4 HPP, O° ohasinq Bench ~1 13,632' - 13,668' DIL, 4 HPF, 0° ohasinq, 90° offset Injection rate before opening Bench ~1: 1600 ..M~IPD @ 4010 psi. Injection rate after opening Bench ~1: 2100 M4IPD @ 4050 Dsi. *Marathon Oil Company - Sub Operator E D OCT 0 1984 NOV 0 2 Ak Environmen~ GrA~ka Oil & Gas Cons. Commissl hchorag~, 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ...~~ ~ T,tle The space below for Commission use Conditions of Approval, if any: Date 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 {i Division: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union September 21, 1984 Mr. Chat Chatterton Alaska Oil & Gas Conservation Commission ~OO1 Porcupine Drive Anchorage, Ak. 99502 Dear Mr. Chatterton: ~. SUNDRY NOTICES - DOLLY VARDEN PLATFORM Attached, for your apse Sundry Notices on Marathon operated wells D-2A, D-6RD, D-TRD an~~ Please return the approved Sundry Notices to the undersigned. Very truly yours, Lawrence O. Cutting Environmental Technician LOC :cwl Attachment RECEIVED S ER 2 5 1.98,{ Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA AL~......,~OIL AND GAS CONSERVATIO'r~(~OMMISSlON SUNDRY NOTICES AND REPORTS. ON WELLS 1, DRILLING WELL I-I COMPLETED WELL [3[ OTHER [] 2. Name of Operator Union Oil Company of California 3. Address P.O. Box 6247 Anchoraqe, AK 99502 4. Location of Well Surface: Leg B-l, 675; FSL, Cond. #5, Dolly Varden Platform 1208' FWL, Sec. 6-18N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106' KB above MSL I 6. Lease Designation and Serial No. ADL 175 79 12. 7. Permit No. 80-110 8. APl Number so- 733-20183-01 9. Unit or Lease Name Tradina Bay' Un-~ 10. Well Number D-1RRD 11. Field and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation []' Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is Marathon's intention to perforate the well with 2.6" guns at 4 HPF, 0° phasing, and 4 HPF, 180° phasing, at the following interval:.. B-1 13,632' - 13,668' DIL SubSequent ~Vork Reported on Form [No. ~~Datecl ~_~./~.~:~y -'RECEJVED SEP 2 5 1984 AlaSka 0il & Gas Cons. CorrlrnissJon Am,,ora~e *Marathon Oil Company - S~]b Operator 14. , hereby certify that the foregoing is true and correct t~i~ of myknowledge~ Signed ~ O~ '~,,~NTitle ENVIRONMENTAL TECH. The spac~ below for C~mmission i~e Conditions of Approval, if any: IRIGiliAL SIGHED BT LGIIHIE C. SMITH B¥Orderof Approved by, COMMISSIONER the Commission Date 9/21/84 Approved Returned Date Form 10-403 Rev. 7-1 60 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate · ._ . Document Transmitt-' : ' .:,'~,' .... ~ :' ' ~ '"~'" .' ,; ':1,' :"',.a~.' '!'~ Union Oil Company of Ca ,~ia DATE SUBMITTED ACCOUNTING MOI~TH ~i ~n rt -~. ,-..~,'.,~ ..ELI,~EP.~ .... ,~ ~siu~ .4-26-82 'TO FROM .. ~,~.., ,~,~ p r SSa~'.~ C ,., ~.S Cons. Co~, P~j' e~: "~2~.7 3Q:'.';~ ,Porcu~':,ine [;rive , Anc~,:ora::te, ~i( 99592 Anchorage, A1 aska ~'~..o.~ .o. TRANSMITTING THE FOLLOWING: , , , ,. . , YI'i,~, ~,~ ~'~....:J~ ,, ..- ,,,: .. . i R~i -~ Curv. 'DJ ..... ~ ............ Tangential DiPec~ional su~ve~ T~nyunCi~i, Avu. mtglu u,r'u~,u,m ~urvt~ TBU D-17' 2" and 5" DIL 2" a.d 5" BHC 5" FDC .......... UNL-rU~ ~" Rad. of Curv. D~. S a~vey ~ang. D~r. Survey Tang. Ave. Anlge DJr. Survey , , , .... , ]uu A-9 Rad, of Cu~v, Olr. S arv~ Diatttzed. Elec. loa :aoe ~616~1 FORM 1-2M02 (REV. 11-72) PRINTED IN U.S.A. HARATHON I)OLLY VARDIN PLTFM, WELL NO: D-16RD GMS TBU, COOE INLET, ALASEA GMS, 0-14459 M[!,.SURVEYOR; T BREEN/M LUND,.DATE-RUN; 21-AF'R-81 CAMERA NO; 1580, GYRO NOI 566, 90 DEG A/U NO~ 1170 SIGHTING TO; GRAYLING iN 18 10 55E) VERTICAL SECTION CALCULATED ij~'.IN PLANE?OF PROPOSAL, -~j.~!!~?~-IIRECTION; S-26 DEG;: 14 MINo E" ....... RECORD OF SURVEY TANGENTIAL METHOD . o i"iARATHON COHPU T A T I ON PAGE . _ DO, U_¥ ~ARDIN F'LTFM, WELL NO; D-16RD. GMS ..-. . TIME [mATE TBU, COOK INLET, ALASKA , '-,. 14149:08 23-APR-81 -.- -, TRUE ..... · '~IE'ASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S.U R E DOGLE( DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERI' .~, FEET - D M. .- D .... FEET .... FEET FEET ....... FEET ... FEET FEET D M DG/lOOf O. 0 0 0 100. I 0 S 84 W 200. 0 15 S 68 W 300. '0 45 N 12 W 400. i 15 N 46 W O. 0·00 0·00 -106.20 0.00 0.00 0.00 0 0 0.00 100. ......99.98 -0.60 -6·22 0.18 S. 1.74 W 1.75 S 84 0 W 1.00- 100. 199·98 -0.64 93·78 0.35 S 2.14 W 2·17 S 80 49 W 0,76 100. 299.98 -1.90 193.78 0.93 N 2.41W 2.59 N 68 50 W 0·83 100. 399.95 -3·96 293.75 2.45 N 3.98 W 4·67 N 58 24 W 0.76 ] ... 0 45 N 47.W 700· I 15- N 54 W 800· - I 0 N 84 W 900· 6 30. S 18 E 100. 499,93 -4.57 393·73 2.07 N 6o13 W 6.47 N 71 20 W ' !3 100, 599.92. -5.79 493.72 2.96 N 7·09 W 7,68 N 67 18 W 1,00 100· 699.90 -7.72 593.70 4.25 N 8.85 W 9.82 N 64 23 W 0.51 100· 799,88 -8,65 693,68 4,43 N 10.59 W 11,48 N 67 18 W 0,63 ...100, ...899,24 2·55 793.04 6.34 S 7,09 W 9,51 S 48 12 W 6,97 1000. 8 30 S 22 E 1100. 10 30 S 24 E 1200. 12 30 S 24 E 1300. 15 0 S 25 E 1400· 17 30 S 26 E 1500. 20 0 S 26 E 1600.. 22 3'0 S 27 E 1700· 25 15 S 28 E 1800. .28 0 S 30 E 2000. 33 0 S 32 E '2100. 34 30 S 28 E 2200. 36 15 S 27 E 2300. 41 30 S 30 E 2400, 47 45 S 31 E . .. 2500. 46 30_ S 27 E 2&O0o 47 45 S 25 E 2700. 49 0 S 26 E 2800. .49 0 S 27 E 2?00, 50 0 S 27 E -. ..~'.~l~. .'?--:.':~:. 100..::',:=:: 998o14'"" 17.29 .... 891.94 100,.:: i!1096.46:""-35.50.- 990.26- 36.69 s 100.::i~:1194.09-:-':':'':I' 57.13-'"1087.89:.: 56.46'S 100~'::'::::1290,69 83.00,.-1184.49 79.92 S 100.'(:~;::1386o06.:.--. 113.08:-'~ 1279.86 : 106.95 S ->":~ _....: :.- ..... ::~:.t:-: .- : .. -:'. .::.. - 100. 1480.03 147.28 1373.83 137.69 S 100. 1572.42.. 185.54 1466.22 171.79 S 100. 1662.86 228.18 1556.66 209.45 S 100. 1751,16 275.02 1644.96 250.11S 100. ...1836.42 .... 327.09 1730.22 294.89 S 100, 1920.29 381.28 1814.09 100·, ,,20'02.70.._ 437.90 1896.50 100. 2083.34 497.02 1977.14 100· 2158.24 563.14 2052.04 100. 2225,48._ 636.91 2119.28 100. 2294.31 709.44 2188.11 100. 2361.55 783.44 2255.35 ... 100. 2427.15 858.91 2320.95 100. 2492.76 934.38 2386.56 100. 2557.04 1010.97 2450.84 ... 341.08 S 391.09 S 443.78 S 501.18 S 564.61S 629.24 S 696.33 S 764.16 S 831.41 8 899.66 S 1.55 W 5.86 E 14.66 E ::25.60 E 38.78 E 20.10 S 4 26 W '2.07 37.16 S 9 4 E 2.03 58.34 S 14 33 E 2.00 83.92 S 17 46 E 2.51 113.76 S 19 56 E 2.52 53.78 E 147.82. S 21 20 E 2.50 71.15 E 185.94 S 22 30 E 2.53 91.18 E 228.43 S 23 31E 2.78 114.65 E 275.13 S 24 38 E 2.89 141.56 E 327.11 S 25 39 E ,.~.53 170.42 E ..J._381.,2~_ S 26 33 E 1.59 197.01 E J 437,91 S 26 44 E 2.68 223.86 E , 497.04 S 26 46 E ":.1.84 256.99 E i 563.21 S 27 9 E 5.58 295.11 E 637.09 S 27 36 E 6.29 328.04 E 709,62 S 27 32 E 3.19 359.33 E 783.58 S 27 18 E 1.93 392.41 E 859.03 S 27 11 E 1.46 426.67 E : 934.50 S 27 10 E 0.75 461,45 E ;1011.10 S 27 ? E 1,00 ! AR A T HO[~ . COMF'U TAT I ON DO.LLY VARDIN F'LTFH, WELL NO; [m-16R~_m GMS. ~ · . TIME DATE TBU, COOK INLET, ALASKA '. .... 14;49;08 23-AF'R-81 ,. ... TRUE iiEASURED DRIFT DRIFT COURSE" VERTIC'AL' VERTICAL SUBSEA R E C T A N G U L A R DEF'TH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD FEET D M.~... D FEET FEET FEET .... FEET PAGE NO, C L 0 S U R E DOGLE( C 0 0 R r_m I N A T E S DISTANCE DIRECTION SEVERI1 FEET FEET D M DG/IOOF 3000, 50 15 S 27 E 3100~ .... 51"i0 ...... S 27 E 3200, 52 0 S 25 E 3300, 52 0 S 26 E 3400, 53 0 S 26 E . . i~__~O. 54 0 S 26 E 100, 2620,98 1087,85 2514,78 100, 2'683.92 1i65.'56 2577,72 100, 2745,48 1244.34 2639.28 100, 2807,05 1323.14 2700,85 100, 2867,23 1403.00 2761,03 100, 2926.01 1483,91 2819,81 3600.. 54 45 S 27 E ..... 100, . 2983.72 _..1565.56 2877.52 · 3700, 55 0 S 28 E 100, 3041,08 1647,44 2934,88 968.17--S · . 1037.41S 1108,83 S 1179.66 S 1251,44 S I 1324,15 S 1396.91S 1469,24 S 3800. 55 0 S 28 E .3900o .55 30 S 28 E . . 4000, 55 0 S 28 E 4100; ........ 54-' 0 S 27 E 4200, 54 0 S 28 E 4300. 54 0 S 28 E 4400, 52 45 S 28 E ~ ~ 24 1541.57 S 100. 3098,44 1729,32 ~99~. .. 100, 3155,08 ...1811,69 3048,88 1614.~3-'S 100."....3212 · 44 ?-'-1893.56 3106.24 100,_i~:,~'3271.21.~'~'' 1974.-4& ..... 3165.01' 1 O0 .:~73329.99'-':Y-~-'-2055.32 '" 3223 · 79 . _:.: . 100,' ~;~ ~88.77 2138, i~ 3282,57 100,?~-..1447, JO. 2215,75-? 4500. 52 30 S 27 E 100, 3510,18 2295.08 3403.98 4600, 52 0 S 27 E .... 100, 3571,74... 2373,87... 3465,54 14700, 52 0 S 27 E 100, 3633,31 2452.66 3527.11 4800,"51 0 S 26 E 100, 3696,24 2530,38.. 3590,04 C)O', 51 0 S 25 E 100o 3759,17 2608,08 3652,97 100. 3823.45 2684.66 3717.25 100.- 3889.06 2760.13 3782.86 100, 3954,66 2835,60 3848.46 100, 4022,86 2908,73 3916,66 100,._.40~1,70.. _2981,26 3985,50 5000, 50 0 S 25 E -5100';' ...... 49 ...... 0 ...... s 26'E ............ ..... 5200. 49 0 S 27 E 5300, 47 0 S 27 E 5400, 46 30 S 27 E I 5500. 46 0 S 27 E 5600, 45 30 S 26 E 5700, 47 0 S 26 E 5800, 49 0 S 26 E 5900,' 51 0 S 27 E .. -~_.. - ~;: - ' '~.'~i.' ' · ~,~ . .:. 100. 4161,17 3053.18 4054.97 100, 4231.26 3124,51 4125,06 .. 100, 4299,46 3197,64 4193,26 100, 4365.06 3273,11 4258,86 100,. 4427,??.'~50o82 4~21,77 I 1686.66.:.S 1758,74'S 1830,1~'S 1901.61S 1971,89 S 2042.58 S 2112,~S 2183,00 .S 2252.85--S 2323.29 S 496,36 E 531o64 E 564,94 E 599,49 E 634,50 E 669,96 E 707.04 E 745.49 E 1087,99 S 27 9 E 1165,70 S 27 8 E 1244,45 S 27 0 E 1323,24 S 26 56 E 1403,10 S 26 53 E 1483,99 S 26 50 E 1565,65 S 26 51 E 1647,55 S 26 54 E 783.95 E "1729,45 S 26 57 E 822,64 E ~ 1811,85 S 27 0 E 0,25 0,75 1,86 0.79 1,00 ' '.'0 1,11 0.86 0,00 0,50 861.10 E i 1893.76 S 27 3 E '0,50 897,83 E T 1974,66 S 27 3 E 1,29 935,81E 2055.55 S 27 5 E 0,81 973,79 E 2136,44 S 27 7 E 0,00 1011,16 E 2216,03 S 27 9 E 1,25 1047,17 E 2295,37 . S 27 9 E 1082,95 E 1118,72 E 1152,79 E 1185,64 E 2374,17 S 27 8 E 2452,97 S 27 8 E 2530,67 S 27 6 E 2608,33 S 27 2 E 2392,71 S 1218.01 E ......... 2460,55 S 1251,10 E 2527.79 S 1285,56 E 2592,96 S 1318,56 E 2908.96 S 26 57 E 2657,59 S 1351,49 E. 2981,49 S 26 57 E · ~7~1,~ o 68 S. 1384,15 E ~ 3053,43~ S 26 57 E ~ 3124 74 S 26 56 E 2785,79 S.{1415,42 E ~ 2851,52 S 11447,48 E 1 3197o87. S 26 55 E 2919,35 S 11480,56 E ; 3273,33 S 26 54 E 2988.60 S ~1515084 E !3351.04 $ 26 54 E 0,83 0,50 0,00 1,27 0~-~,8 _ 2684,89 S 26 59 E 1,00 2760,35 S 26 57 E 1,26 2835,82 S.i.26 57 E -'.0,75 2.00 0.50 0.50 0.87 1.50 2.00 2,14 -'iARATHON COflF'UTATION F'ADE NO, ~ . .]O. LLY (J~RDIN F'LTFH, WELL NO.' D-16RD GMS TIME [mATE I'BO, CO'OK INLET, ALASKA .... 14:49:08 23-AF'R-81 ...~ .... TRUE -.. . · 'iEASURED DRIFT I]RIFT COURSE' VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEE [mEF'TH ANGLE DIRECTION LENGTH -DEPTH FEET . D M D FEET . FEET SECTION TVD FEET- FEET 6000. 51 30 S 26 E 100.. 4490.25 3429.08 4384.05 6100. 52 0 S 26 E 100.. 4551.81 3507.88 4445.61 6200, 52 30 S 27 E 100o 4612.69 3587,21 4506,49 6300. 50 30 S 27 E 100, 4676,30 3664.37 '4570,10 6400, 51 0 S 26 E lO0. 4739,23 3742.08 4633,03 ~---'-~ .~'~'-~'0 50 0 S 26 E o. o 6800. 48 30 S 26 E 6900. 49. O. S 25 E 100, 4803.51 3818.68 4697,31 100,.. 4867,79 3895,29. 4761,58 100, 4933,39 3970,76 4827.19 100. 4999,65 4045,65 4893,45 100. 5065,26 4121.10 4959,06 7000. 49 0 S 24 E 100.- 5130.87 4196,52 5024.67 "710'0-J ......... 50'~ ...... 0 ....... S"-22 'E ............. 100, ........ '.~195,= 14 .......... 4272,91 5088~94 . . 7200. 49 0 S 23 E 100,-~'":i5260,75' 4348,27 5154,55 .... 7300. 49 0 S 22 E 100,-' 5326,36 4423,53 . 5220,16 7400, 51 30 S 19 E 100,-:_:.i;:'.5388,61 .4501,17 :" 5282,41 7500, 51 30 S 19 E 100, 5450.86 4578.81 5344,66 7600, 51 0 S 18 E 100,. 5513,79 4655,72 5407.5? .7700, 51 30 S 17 E 100, 55-76.04 4732,97 546?,84 7800,'-"49 30 S 18 E 100. 5640,99 '4808.22.. 5534,79 ,'?~!?O; 48 30 S 17. E . _. 100,.. 5707,25 .... 4882,15 5601,05 8000. 46 30 S 18 E 8100. 47 O- S 18 E 8200. 46 0 S 18 E 8300. 47 0 S 18 E 8400, 47 0 S 17 E- , 8500, 47 30 S 17 E 8600, 48 0 S 16 E 8700. 48 0 S 16 E · 8800. 48 0 $ 16 E 8900. 48 30 S 16 E I ,. 100, 5776.08 49.53.94 5669.88 100.~ 584'4.28 ....... 5026.32 ...... 5738.08 100. 5913.75 5097.51 5807.55 100. 5981.95 5169.89 5875.75 100. 6050.15 5242.08 5943.95 100. 6117.71 5314.85 6011.51 100. 6184.62 5387.99 6078.42 100. 6251.54 5461.12 6145.33 100. 6318.45 5534.25 6212.25 100, 6384,71 5607,96 6278,51 D I N A T E S DISTANCE DIRECTION SEVERII FEET FEET D M DG/IOOF 3058 94_~S._..J_.1550,15 E [3429,30 3129!76 S IZs84;'69'E'"I-350~;'~¢- 3200 45 S J1620,71 E J3587,42 3269 20 S J1655.74 E )3664.58 3339 05 S J1689,81 E 5407.91S 3476.76 S 3544.59 S 3611,91S 3680,30--'S 3749.25.-.S S 26 52 E S 26 51 E S 26 51E S 26 52 E 1723.39 E 1756.97 E 1790.06 E 1822.89 E 1854.78 E 3742,2? S 26 51 E 3818.89 S 26 50 E 3895.48 S 26 49 E 3970.95 S 26 48 E 4045.84 S 26 47 E 4121.27 S 26 45 E '3820.28'S 1914.18 E 4273.01 S 26 37 E 3889.75r'S 1943.67 E 4348.33 S 26 33 E 3959.72 S 1971.94 E' 4423.57 S 26 28 E 4033.72 S 1997.42 E. 4501.18 S 26 21E 4107.72 S 2022.90 E. 4578.81 .S 26 13 E 4181.6=3"dS 2046.91 E 4655.74 S 26 5 E 4256.47 $ 2069.79 E 4733.03 S 25 56 E 4328.79-S 2093.29 E 4808.36 S 25 48 E 4.400.41S 2115.19 E 4882.38 S 25 40 E 4469.40 S 2137.60 E 4954.28 S 25 34 E -"4538',96'"S ....F'2'i60,2C-E ..... 5026-~- S 25 27 E 4607.37 S 2182.43 E 4676.92 S 2205.03 E 4746.86 S :2226.42 E 0,93 0,50 0,94 2,00 0,92 :~,o 0.00 1.00 0,50 5316.05 S 25 1E 5389.46 S 24 54 E 5462.90 S 24 46 E 0,75 3,40 1885.48 E 4196.66 S 26 42 E '0.75 1.82 1.26 4817.37 S 2247.97 E 4888.81S :2268.46 E 4960.24 S i2288.94 E 5031.68 S ~2309.42 E; 5536.35 S 24 39 E 5103,67 S ~2330,07 E) 5610.41 S 24 32 E 0.00 0.93 0.93 2.14 2,13 0,50 5098,12 S 25 21E -.1,00 5170,67 S 25 15 E 1,00. 5243,06 S 25 8 E 0,73 0.50 0.89 0.00 0.00 0,50 0.90 .'tARAI'HO~ DObLY ~'ARDIN F'LTFM, WELL NO; D-16RD GMS TBU, COOK INLET, ALASKA COMPUTATION TIME DATE 14;49;08 23-AF'R-81 PAGE NO, TRUE i'qEASURED DRIFT [;RIFT COURSE VERTICAL VERTICAL- SUBSEA R E C T A N G U L A R C L 0 S.U R E DOGLEI DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R...[; I N A T E S DISTANCE DIRECTION SEVERI] FEET D..H D FEET FEET .. FEET FEET FEET FEET D M DG/IOOf 9000. 48 30 S 15 E '9100, 48 0 S 16 E 9200, 49 0 S 15 E 9300, 48 30 S 15 E 9400, 49 0 S 16 E .. ~_~-0o 50 0 S 16 E 9600, 49 0 S 16 E 9700. 49 30 S 17 E 9800, 49 0 S 17 E 9900, 49 0 S 17 E 100, 6450,97 5681,42 6344,77 100, 6517.89 5754.55 6411.69 100o 6583,49 5828,57 6477,29 100. 6649,75 5902°03 6543,55 100, 6715,36 5976,31 6609,16 5176,02 S :2349,45 E 5247'o45"S-i"2369,94 E 5320,35 S 12389,47 E 5392,69 S '2408,85 E 5465,24 S 2429,66 E 100. 6779.64 6051.69 6673.44 5538,88 S 2450.77 E 100. 6845,24 6125,96 6739,04 5611.43 S 2471,57 E 100, 6910,19 6201,02 6803,99 5684,14 S 2493.81 E 5684,28 S 24 25 E 5757,81 S 24 18 E 5832,30 S 24 11E 5906,24 S 24 4 E 5980,98 S 23 58 E 6056,85 S 23 52 E 6131,62 S 23 46 E 6207,14 S 23 41E 100. 6975.80 6275,51 6869.60 5756,32 S 2515,87 E 6282,10 S 23 37 E .. 100, 7041,40. 6350,00 6935,20 5828,49 S 2537,94 E 6357,08 S 23 32 E 0,75 0,90. 1,25 0,50 0,90 1,00 0.91 0.50 0,00 10000, 48 0 S 21E 10100, 47 O-'S 26 E 10200. 47 15 S 27 E 10300. 48 15 S 27 E 10400, 48 0 S 27 E 10500, 48 15 8 31E 10600, 48 45 S 31 E 10700, 48 30 S 31E 10800, 47 30 S 31E 1~0,..47 45 S 35 E .............. !00.~ ...... 7108o31.::~.6424_,.0! .... 7002.,11 ..5897,8~';iS...2564,57 E .... 6431,32 S 23 30 E 100o'-..?.7176,51"'-6497,14-'7070,31 !5963,60 S 2596,63 E. 6504,39 S 23 32 E 100o.-:i!~7244,39:--'6570.57· 7138,19 .16029,03'S 2629,97 E 6577,68 S 23 34 E 100o;.~!.7310o98 6645,17--7204,78 16095,50 S 2663,84 E 6652,16 S 23 36 E 100,.;¥~i..7377,90. 6719o47->'7271,70 (6161o72 S 2697,58 E 6726,34 S 23 39 E '~'~""-';';' '"' '' ~ ';~ :" '- .... _ ! 100, 7444,48 6793,82 7338,28 16225,67 S 2736,00 E 6800,34 S 23 43 E 100, 7510,42 6868,75 7404,22 6290,11 S 2774,72 E 6874,93 S 23 48 E 100, 7576,68 6943,38 7470,48 6354,31 S 2813,30 E 6949,24 S 23 53 E 100o 7644,24 7016,86 7538,04 6417,51 S 2851,27 E 7022.40 S 23 57 E 100, .....7711.48. 7090,01 7605.28 6478,14 S 2893,73 E 7095,07 S 24 4 E 11000, 47 15_..8 35.E ............ lOOt ....... 7779,36 .... 7162,59 ..... 7673.,16 ..... 6538,30 S 2935,85 E_. 7167,18 S 24 11 E 11'100, 47 0 S 35 E 100,....:7847,56 7234,87 7741,36 .6598,21 S 2977,80 E 7239,03 S 24 17 E 11200, 48 45 S 38 E 100, 7913.49 7308,47 7807,29 16657,45 S 3024.08 E 7312,10 S 24 26 E 11300, 50 0 S 39 E 100, 7977,77 7383,18 7871,57 i6716,98 S 3072,29 E 7386,26 S 24 35 E 11400, 50 30 S 38 E 100, 8041,38 7458,72 7935,18 !6777,79 S 3119o80 E 7461.34 S 24 43 E 11500, 51 15 S 39 E 1].600, 51 30 S 39 E 11700, 51 15 S 39 E 11800, 51 0 S 40 E 11900, 51 15 S 40 E 100, 8103,97 7534,78 7997,77 100,. 8166,22 7611.11 8060,02 100, 8228,81 7687,17 8122,61 100. 8291.75 7762,65 8185,55 100,. 8554,54 7858o40 8248,14 6838,40 S 3168,88 E~ 7536,94 S 24 52 E 6899,22 S 3218,13 E' 7612,85 S 25 0 E ! 6959,83 S 3267,21E. 7688,55 S 25 9 E 7019,36 S 3317,16 E' 7763,70 S 25 18 E 7079,10 S 3367,29 E 7839,15 S 25 26 E 3,16 3,82 0,77 1,00 0,25 2,99 0,50 0,25 1,00 2-~.7 0,50 0,25 2,83 1,46 0,92 1,08 0,25 0,25 0,82 0,25 "iARA.THO~ DOLLY ~ARDIN F'LTFM, WELL NO; D-I&RD' GMS TBU, COOE INLET, ALASEA COMF'UI'AI'ION TIME [mATE 14;49;08 23-AF'R-81 PAGE NO. TRUE i4EASURED DRIFT DRIFT COURSE" VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S.U R E DOGLE[ DEF'TH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERI1 ,.~ FEET I:l M l:l FEET -. FEET FEET FEET -- FEET FEET D M DG/IOOF 12000. 49 45 S 39 E 12100[ ..... 50 0 S 39 E :[2200. 49 30 S 37 E 12300. 48 0 S 41E 12400. 50 15 S 40 E .. -':i~T,. 1~;0. 49 0 S 42 E 12600. 49 0 S 42 E 12700. 49 0 S 41 E 12800. 48 0 S 41E 12900. 48 15 S 41 E 13000. 47 0 S 40 E 13100. 46 50 S 40 E 13200. 46 15 S 40 E 13300. 46 15 S 58 E .. 13400. 46- 0 S 57 E 15500. 45 45 S 56 E 13600. 45 15 S 35 E 13700. 45 30 S J5 E 13800. 46 30 S 35 E 100, 8418,95 7912,84 8512,75 7158.42 S i 5415,33 E ~ 7913,37 S 25 54 E 100. 8483,23 7987.55 8377.05 7197,95 S-'i 3463.55'E 7987,90 S 25 42 E 100, 8548,17 8062.25 8441.97 7258,68 S i 3509,50 E 8062,48 S 25 48 E 100, 8615,09 8154oll 8508.89 !7514°76 S 3558°05 E 8134,22 S 25 56 E 100, 8679,03 8208,79 8572,85 !7375,66 S 3607,47 E 8208,82 S 26 4 E 100o 8744.64 8281.42 8638.44 7429.75 S 3657.97 E 8281.42 S 26 13 E 100. 8810.24 8354.05 8704.04 7485.83 S 5708.47 E 8554.07 S 26 21E 100. 8875.85 8427.05 8769.65 7542.79 S 3757.98 E 8427.11 S 26 29 E 100, 8942.76 8498.89 8836.56 . 100, .9009.55 8571,03 8905.15 100.':..--9077.55-- 8642.06 8971,55 100,' -" 9146,58'7''!:8712.52 . 9040,18 100...'.i:/9215.54 8782.68 9109.35 · .. 100."'79284,69 8853,40 . 9178,49 . . . : . igC_4 . 100..,,-?~.95~ .1,5 8924.06" 9247.95 --- :~.....-... . ~: ~ 100. 9423.93 8994.66 9317.73 7598,88 S 3806,74 E 8499,07 S 26 37 E 7655,18 S 3855,69 E 8571,35 S 26 44 E 7711,2~-"~ 3902,70 E 8642,55 S 26 51 E 7766,77 S 5949,52 E !8713,20 S 26 57 E 7822.11 S 3995.75 E !8785.59 S 27 4 E 7879.05 S 4040.25 E ' 8854.52 S 27 9 E 7956,48 S 4085,52 E 8925,41 S 27 14 E 7994,43 S 4125,62 E i 8996.20 S 27 18 E 100. 9494.33 9064.84 9388.13 8052~61 S- 4166.36 E i 9066o59 S 27 21 E 100, 9564,42 9155,34 9458o,~ 8111 03 S 4207,27 E ~ 9137,28 S 27 25 E 100.. 9633.26 9207.03 9527.06 8170,45 S. 4248,87 E j 9209.19 S 27 29 E 1~':?~"~0. 46 0 S 55 E ....... 100. ..... 9702.73. 9278.12 9596.53 i8229.38 S 4290.13 E i 9280.51 S 27 32 E 14000. 47 0 S 35 E 14100, 47 30 S 34 E 14200, 45 0 S 51 E 14300, 41 30 S 50 E 14400, 38 30 S 29 E 14450, 38 0 S 27 E FINAL CLOSURE - iqlRECTION DISTANCE: : I 100, 9770,95 9350,40 9664.73 8289,29 S 4332.08 E ; 9353,03 S 27 36 E -~"i'i ..... 100,.-~ 9838,48 9423,45 9732,28 8350,41S 4373,31E i9426,50 S 27 39 E 100. 9909.20 9493.92 9803.00 8411.02 S 4409.73 E ~ 9496.89 S 27 40 E 100. 9984.09 9560.04 9877.89 8468.41S 4442.86 E 9563.10 S 27 41E 100,. 10062,55 9622,22 9956,15 8522,85 S 4473,04 E 9625,33 S 27 42 E 50. 1010~.75 9655,00 9~95,55 8550.28 s 4487.01E 9656.12 S 27 41E S 27 r_IEGS 41 MINS 23 SECS E .9~5~o12 FEET 1,69 0,25' 1,61 3,36 2,37 ~ '~7 0.00 0,75 1,00 0,25 1.45 0.50 0.25 1.44 0.76 0.76 0.87 0.25 1.00 0~'~0 1.00 0.89 3.31 3.57 3.07 2,67 14;'49;08 23-AF'R-81 FILE NUMBER; '47 MARATHON DOLLY VARDIN PLTFM, WELL NO; [I-16RD GMS TBU, COOK INLET, ALASKA COIV?~RSATIONAL SURVEY PROGRAM V02oll . Eastman/" " Whipstock 'i .. ' A PETROLANE OOMPANY · . , · ,. . .,. ,..,...: ,., ~ ..... ..,,. ., . .., SURVEY ..' .... RADIUS" OF CURVATIj ·/'" "' "" ' . ' :' ','.i:.,', ,'.,, .:.,i,, ', '.: ,"' "'. '? ' ' "',."" ':', ""TYPE 'VEY "' F"SU' ' .-. ".. . '. '. :.. '.. .',..'..':.,: .... ..:.. '...'" .:,,::...~,i, . :..'...; ..~ . .." . . .... ' "' . . . .... ,......'...:,. ..... ,........,...!' ...'....' ;.... ,.,r,].., F,..//, ".~."~ 11 . . ,., .., ~....,,i,~ ,.,:..:~ .,.,~;, ,i,.,,,;?...~, ,;,..., ..,, , .~'~,,~ , .,,;,~,,.~,,~...~,.~¥,,,.. ."..'"' .COOK INLET, ALASKA .." ??.i.:!'?!i.i:.:i..:. .:,. ..,.,, .',:!:,, :', ~'.','hFt;,:A~."',:,~'..'.~.~,~/i'..,:.::..:!:::.~,,:. ~:r~;i]!ii".i":iF.~ai~i!ii;~? ..:,,i', . . ..,...~:~ ' ".':. '..... hi. ~" '~ ~;' ..... '" ~" "; '"? ' ?:'. ...... ': "~>:"~;~'~.... -....,.. II't~';:~"~': """' :. ': .j('~ .- ..,' . ',, v, , ' ' ' ' .' ..... '" .... ,'"::.~ .... ."." '!" :: ','. ": "..' , ' .'..'~'..' , ' ' ',~'~:~'~ ...... 't"'":".:"." ' ,' . ' '.' ",'; ,! :..":'.' ' '..". " ' .' ".. '..' :'.'::"".'.'.' ." .... :.,""./':'..-'". ,' .',,'. ,' ,,.'i i:.:i..:.'...';.',' ".'.. :,:'":',;.....'..:'(.. 'i...::.:;"'~"..,:,..' ': :." . '.v::,'~., .... "?7:?". ' .... :".',. ' ' .::/.'.i .... .......... ..?,....... ....... . .... DEVEL0 NE IT · ........ ' "!.. ' /'.'.'.:". , :'.'."..". .... ',.i'.'..i":' ..v....' ".... : :.'..,..,, :.'.'. .... '...'.ir...'..~:.' ..:,...'.'. ',~,~-'.~;~':i~: ..... . ....:.,::..,..:..::..':,..' ..'.. ,...,.~ ":." ' :.: .... .."; ." ~. '. " r:.,.. .',?.: .:.'.:'.i':.,:i.:'~i' :?.!~:~...:: %. :;i- !. '.' '?';:.: ':',','.?F"':'" ' '-.. '~,!',...:.',:?,.:',-~'::*:~:![~,F~::!f.t.'~i~:'.:!:,...,,,.~ .,.a ' '"" ' . ..... ' '.". '. '::/7 ".',.. · ' 6.:':.:..:: ..... "' ...... ' ' .' :,. '.....:. ,'..' ~':;,'~ . ,': ~. .'.....:..,:..'.;.X"..r ~!;',?"-%'i.,'.'.:'i::.t' ...... ".,:, "...'":.'i'.':;{,;?:'.-'~i!~:~.',~!~.'..~'~::'.'~.' ".'.' ' .'. '."...: ". ' '...:.:.."':....' .'.<.,:'".'.-..:~'-... :',: ....-..":.".'..'::.:?,:','~:.?,:." · :'~ ':i?"'~:'~:i~:::'.;~:!....;: ~...,..,.?~. :... "'..'... - ..... "' .~.:....`..~........`..........:;::.:..~.....~:..`~..:.:.:.:~``.....::.....`:`:........``:`~..~..?~.:"`..."~`.... FIlE .:'.:.~:...',.:,:',,:'!:~',,,.':~?.~:;,:',~,'.? .... ,,.?,~,....:.~:.:. .. ".':...: . :.' .'. ' .'SURVEY BY . .:' i:'" ..'..:':".: ...... . .... ' ' ".,"~ :: ". ..... ."' "' '" .' ' ... .' ..', .... .'. '. .... ' '. '".! ~'.' . ..' .... ...'. f?.' ".' ......... '~.." :,:..'....'..~'...... ~.. ".' .'L~,'.. '::,'~.:,..'..~.~,;"~,~ ....... . .~ · '..' ;.C.~'.,:~'~"[L. v TOM BREEN '~ ..... ',' ,~:.'. :: ......... ;~:: ;:8 ""'~i' ~''''''~':'' '?"::":'~f' '?":'""'"':"?"":~'~::"."' :'".,~"';~!,."~ii:~.:':""'" ":"',';:.'"":if'~:'"",~ ,',: ,".. · , LUND ":' :'~:':: '"':"~: '"""~;~'~"""~"" :"<i'"':' ':,,f',~:'.~>-::~:"~..i ~.~:.~:,::'-,',,', ,.~':.,,s'::,~'~ :" ,<~.' ~,~ .' ;.,', :.:":~?~ ~'.',:{~ ,.--" . ' ..... ' . :.'., ". '.'..'. '..' ...... ."...' ..... ..... :.,; .':' ..... . .... :~.:.-.,',,,.....:....'.,....,....,.',.......,.,.,,.:,.-..:,',,,::..............~.........?...:..~..:.....~...::.:.;:`.:`~.~¥~`....~,`::¥?~`~`..~..:..~........?.`:..`~:~.~.~:`.:`.`~..::..:.`...`..:.~`~?:~'~S:KA :..',.,,,~,~.~ " ' ........ ' ..... : ......... ".'":'".'-' ~',' .',,"-" : '.'".'""::':"~!>,.',~'"".': ~""" .... :.. ?.,~i+,:::'.?::f;~,:~. _,., ,._,.~:¢~:~::..,.'.,: MARATHON ............. '[,OLLY VAR[~IN F'LTFM, WELL NOI ~i-16RD GMS TBU, COOK INLET, ALASKA i~~I-AF'R-el ~) GMS, 0-14450 M[~, SURVEYOR: T BREEN/M LUND, [lATE RU CAMERA NO: 1580, GYRO NO: 566, 90 DEB A/U NO: 1170 SIGHTING TO: GRAYLING (N 18 10 55E) ............ VERTICAL.. SECTION CALCULATEI~.'.'.'IN PLANE OF PROPOSAL :~:~: .:~':~~ '~' m'~ -?' IR£CTION: S 26 r,[G. :i4 MIN. --:.??- --.... . .- ':'-'i-..-.--,. "-.: . ~ · -- .'- '-- :." '"' '~' .. ~:::~-.... ...... :.: --: ~:- :... .. .... .:. : .... ~;.- ; . RECOR[I OF SURVEY ANGLE AVERAGING METHOD JARA]'HON. COMPUTATION PAGE NO, ..~1 )O[.LY ~ARDIN PLTFH, WELL NO1D-16RD GMS TIME DATE ~; FBU~ COOK INLET, ALASKA 14153149 23-AF'R-81 ' TRUE ~EASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C'T A N G U L A R C L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERIT FEET . D M D FEET FEET FEET FEET FEET FEET D M DG/1OOF O, 0 0 0 O, 0,00 0.00 -106.20 0,00 0,00 100, 1 0 S 84 W 100, 100,00 .... -0.30 '-6,20 0,09 S 0,87 W 200, 0 15' S 68 W 100. 199.99 -0.53 93.79 0,36 S 1,93 W 300. 0 45 N 12 W 100. 299,99 -1.24 193.79 0,05 N 2,70 W 400, 1 15 N 46 W 100, 399,97 -2,98 2-93,77 1,58 N 3.,54 W 500. 1 15 S 80 W 100. 600, 0 45 N 47 W 100. 700, I 15 N 54 W 100, 800, I 0 N 84 W 100. 900, 6 30 S 18 E 100, 499,95 -4,48 393,75 2.22 N 5,63 W 599,93 . --5,66 ..493,73 2,71N 7,30 W 699,92 -7,25 593,72 3,82 N 8,65 W 799,90 -8,70 693,70 4,53 N 10,48 W 899,68 -5,96 793,48 0,55 S 14,60 W 0,00 0 0 0,87 S 84 0 W 1,96 S 79 33 W 2.70 N 88 50 W 3,88 N 65 57 W 6.05 N 68 29 W 7,79 N 69 37 W 9,46 N 66 9 W 11,42 N 66 38 W 14,61 S 87 49 W 0,00 1,00 0,76 0.83 0,76 0,51 0.63 6.97 1000, 8 30 S 22 E 1100, 10 30 S 24 E 1200, 12 30 S 24 E 1300, 15 0 S 25 E 1400, 17 30 S 26 E 1500, 20 0 S 26 E oo 30 S 27 E 1600. ~ 1700, 25 15 S 28 E 1800, 28 0 S 30 E ' 1900,.. 31 30 S.31E *' 2000, 33 0 S 32 E ~: 2100, 34 30 S 28 E .-. 2200, 36 15 S 27 E ~-..2300. 41 30 S 30 E .. ~:'2400, 47 45 S 31 E .... ¢{._ ;;-:2500. 46 30 S 27 E ;..~ 2600 ,:-. · '47..45 S 25 E ~1.2700, 49 0 S 26 E '2800. 49 0 S 27 E 2900, 50 0 S 27 E * :..,, 100, 998,83'- 7,02 892,63 12.82 S 10,13 W 100,';..1097,46-" 23,50 991,26 28,01 S 3,68 W 100,-'"1195,45' '43,42'!' 1089,25 46,23 S 4,42 E . ~ ~ - . .. 100, :"!i!1~9~.58 67,18 1186,38 67 85 S 14,28 E -- .. 100,i.¢.?.1388,59' 95,16-.!/ 1282,39 -' 93,11S 26,33 E ..... ~- ,; i..'-_ .;~ .... ;~ ' .. 100, 1483,28.' .... 127,30 1377,08 '122,00 S 100o 1576.48 163,55 1470.28 154,44 S 100. 1667,93 204,01 1561,73 190,34 S 100, 1757,32 248,77 1651,12 229,54 S o -'r, 29S .. 100, 1844,14 .. 298,26 1737,94 ~7~, 40,42 E 56,59 E 75,28 E 97,01E 122,19 E 100, 1928,71 351,39 1822,51 100, 2011,86 .... 406,83 1905,66 . . 100, 2093,40 ' 464,71 1987,20 100, 2171,25 527,42 2065,05 100. o~ 42' 597,47 2136,22 317,79 S 365,90 S 417,25 S 472,41S 532,94 S 150,07 E 177,85 E 204,58 E 234,53 E 270,18 E 100. 2310,46 670,67 2204,26- 597,03 S 100, 2378,50 ...... 743,96 2272,30' 662,90 S 100, 2444,93 ....... 818,70 2338,73 730,37 S 100, 2510,53 894,17 2404,33 797,91 S 100, 2575,48 970,20 2469,28 865.66 S 305,71E 337,84 E .... 370,02 E 403,69 E 438,22 E 16,34 S 38 20 W 28,25 S 7.30 W 46,44 S 5 28 E 69,34 S 11 53 E 96,76 S 15 47 E 128,52 S 18 20 E 164,48 S 20 7 E 204,69 S 21 35 E 249,19 S 22 55 E 298,45 S 24 10 E 351,44 S 25 17 E 406,84 S 25 55 E 464,71 S 26 7 E 527,42 S 26 24 E 597,51 S 26 53 E 670.75 S 27 7 E 744,02 S 27 0 E 818,75 S 26 52 E 894.22 S 26 50 E 970,26 S 26 51 E 2,07 2,03 2,00 2,51 2,52 2,50 2,53 2.78 2,89 2,68 1,84 5,58 6.29 3,19 1,93 .1,46 0.75 1,00 MARATHON COMPUTATION PAGE DOLLY VARDIN F'LTFM, WELL NOI D-16RD GMS. TIME DATE TB~I, COOK INLET, ALASKA 14153:49 23-AF'R-81 TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLE DEPTH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERI FEET D M D FEET FEET FEET FEET FEET FEET D M DG/IO0 3000. 50 15 S 27 E 3100. 51 0 S 27 E 3200. 52 0 S 25 E 3300. 52 0 S 26 E 3400, 53 0 S 26 E 3500, 54 0 S 26 E 3600, 54 45 S 27 E 3700, 55 0 S 28 E 3800, 55 0 S 28 E 3900, 55 30 S 28 E 100, 2639,59 1046,94 2533.39 934.04 S 473.06 E 1047,00 S 26 52 E 100, .2703,03 1124,24 2596,83 1002,92 S' 508,15 E 1124.31 S 26 52 E 100. 2765.28 1202,50 2659,08 1073,26 S 542,46 E 1202,56 S 26 49 E 100. 2826.85 1281.29 2720.65 1144.38 $ 576.38 E 1281.34 S 26 44 E 100. 2887.72 1360.63 2781.52 1215.69 S 611.16 E 1360.67 S 26 41 E 100. 2947.21 1441.01 2841.01 1287.94 S 100. 3005.45 1522.29 2899.25 1360.68 S 100, 3062,99 1604,06 2956,79 1433,23 S 100, 3120,35 1685,94 3014,15 1505,56 100. 3177,35 1768,07 3071,15 1578,11 S 0.25 0.75 1.86 0,79 1,00 646,40 E 1441.05 S 26 39 E ..Y--~ 0 682,67 E 1g~...33 S 26 39 E . il 720.44 E 1604.11 S 26 41 E 0.86 758.89 E 1686.01 S 26 45 E 0.00 7?7.47 E 1768.16 S 26 49 E 0.50 4000. 55 0 S 28 E 4100. 54 0 S 27 E 4200. 54 0 S 28 E 4300. 54 0 S 28 E 4400. 52 45 S 28 E 4500. 52 30 S 27 E 4600. 52 0 S 27 E 4700. 52 :0 S 27 E ~800. 51 0 S 26 E 4900, 51 0 S 25 E 5000. 50 0 S 25 E 5100. 49 0 S 26 E ~- 5200. 49 0 S 27 E ". 5300. 47 0 S 27 E .- ~.-.5400, 46 30 S 27 E ... ?.- 5500, 46 0 S 27 E ~'. !..-... 5~00, 45 30 S 26 E ~': 5700, 47 0 S 26 E 5800. 49 0 .S 26 E · . i::.,,5900. 51 0 S 27 E . . 100. 3234.35 1850.19 3128.15 1650.65 S 100,..:';.';-3292,42 1931,58 3186,~.-. 1722,87 S ..- -L 100, i;-3351.20 2012,47 3245.00 1794,63 S 100,-':-'~3409,97 2093.33 3303,77 1866,06 S · ....... -. 100,.'~-}!ii3469,63 2173,55.:~ 3363043 1936,92 S ~i.. · . . ='.. .. 836,04 E 1850,30 S 26 52 E 873,63 E 1931,71 S 26 53 E 910.99 E 2012.61 S 26 55 E 948,97 E 2093,49 S 26 57 E 986,65 E 2173,74 S 27 0 E 1000 3530,3.~'~ 2252,99 3424,13 2007,41S 1023,34 E 2253,20 S 27 I E 100. 3591,56 2332.06 3485.36 2077,86 S 1059,24 E 2332.27 S 27 I E . 100. 3653.12 2410.85 3546.92 2148.07 S 1095.01E 2411.07 S 27 i E 100. 3715.37 2489.11 3609.17 2218.11S 1129.93 E 2489.33 S 27 0 E 1000 3778,31._. 2566,82 3672,11 2288.26 S 1163,39 E 2567,02 S 26 57 E 0.50 1.29 0.81 0,00 1.25 0,83 0,50 0,00 1,27 100, 3841,91 2643,96 3735,71 2358,19 S 1196,00 E 2644,14 S 26 54 E '"::i','O0 ~ ~ O0 3800,66 2426.82 S 1228.74 E 2720.16 S 26 51 E 1.26 100, .... 3906.86 ~7~0, 100, 3972,46 2795,47 3866,26 2494,36 S 1262,41E 2795,63 S 26 51E 0,75 100. 4039,38 2869.78 3933.18 2560.58 S 1296.15 E 2869.94 S 26 51E 2.00 100, 4107,90 2942,61 4001 70 ~x~ 48 S 1329,22 E 2942,78 S 26 51E 0,50 100. 4177.05 3014.84 4070.85 2689.84 S 1362.01 E 3015.01 S 26 51 E 100, .4246,83.. 3086,47 4140,63 2753,94 S 1393.97 E 3086,64 S 26 51 E 100. 4315.98'" 3158.70 · 4209.78 2818.87 S 1425.64 E 3158.87 S 26 50 E 100. 4382,89 3233.02 4276.69 2885.66 S 1458.22 E 3233,18 S 26 49 E ~ S 1492,40 E 3309,78 S 26 48 E 100,.. 4447,17.. 3309,62 4340,97 2954,~ 0,50 0.87 1.50 2.00' 2,14 tARATHON COMF'UTATION PAOE,INO. ~ JOLLY OARDIN F'LTFM, WELL NO: D-16RD GMS TIME [mATE ~ TBU~ COOK INLET, ALASKA 14153149 23-AF'R-81 TRUE ~EASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 O R D I N A T E S DISTANCE DIRECTION SEVERIT FEEl' D M D FEET FEET FEET FEET FEET FEET D M DG/IOOF ... 6000, 51 30 S 26 E 6100, 52 0 S 26 E 6200, 52 30 S 27 E 6300. 50 30 S 27 E 6400, 51 0 S 26 E 100. 4509.76 3387,61 4403,56 3024,01 S 1527,20 E 3387,77 S 26 48 E 100, 4571.67 3466,14 4465.47 3094.60 S 1561,62 E 3466,29 S 26 47 E 100. 4632,89 3545,21 4526.69 3165,36 S 1596,90 E 3545.36 S 26 46 E 100.. 4695,14 3623.46 4588.94 3235,09 S 1632,43 E 3623,62 S 26 47 E 100, 4758,41 3700,90 4652,21 3304,39 S 1666,98 E 3701,06 S 26 46 E 0.93 0,50 0,94 2,00 0,92 6500, 50 0 S 26 E 6600. 50 0 S 26 E 6700. 49 0 S 26 E 6800, 48 30 S 26 E 6900. 49 0 S 25 E 100. 4822,02 3778.06 4715,82 3373,74 S 1700.81 E 3778,22 S 26 45 E 100. 4886,30.. 3854,66 4780,10 3442,60 S 1734,39 E 3854,81 S 26 44 E 100, 4951.25 3930,70 4845,05 3510,94 S 1767,731E 3930,85 S 26 43 E 100, 5017.18 4005.89 4910.98 3578.52 S 1800,68 E 4006,03 S 26 43 E 100. 5083.12 4081,06. 4976.92 3646,38 S 1833.05 E 4081,19 S 26 41 E 1,00 0,50 0.90 7000, 49 0 S 24 E 7100, 50 0 S 22 E 7200, 49 0 S 23 E 7300, 49 0 S~° E 7400, 51 30 S 19 E 7500, 51 30 8 19 E 7600. 51 0 8 18 E 7700. 51 30 S 17 E 7800, 49 30 S 18 E 7900, 48 30 S 17 E i 8000, 46 30 S 18 E 8100, 47 0 S 18 E 8200, 46 0 S 18 E - 8300, 47 0 8 18 E ~:; 8400, 47 0 S 17 E r~-8500, 47 30 S !7 E ~- 8600. 48 0 8 16 E -. i.- 8700, 48 0 S 16 E :.8800. 48 0 S 16 E ,..8900, 48 30 S 16 E .. 100o 5148.72 4156,50 5042,52 3715,05 S 1864,35 E 4156,61 S 26 39 E 100,-' 5213,67' 4232,42 5107,47 3785,05 S 1894,06 E 4232,50 S 26 35 E . 100o ':5278,61' 4308,30 5172.41 "3855,30 S 1923,16 E 4308,35 S 26 31 E 100,..::~i5344,22 4383,61. 5238,02 3925,03 S 1952,04 E 4383,64 S 26 27 E '~...~.~ 100,.~.=.-~408,1& ..... .4460,11 5301,96 ~3977,04 S 1978,97 E 4460,12 S 26 20 E ':~.~ .... '.-:; ..'. . -- 100. 5470.41-' .... 4537.75 5364.21' 4071.04 S 2004.45 E 4537.75 S 26 13 E ~ ~ 19 E 4615.04 S 26 5 E 100, 5533,00 4615,03 5426.80 4145.00 S 100, 5595,60 4692.11 5489,40 4219.38 S 2052,64 E 4692,17 S 25 57 E 100, 5659.20 4768.38 5553,00 4292.97 S 2075,85 E 4768,51 S 25 48 E 100. 5724.81. 4842,98 5618.61 4364,94 S 2098,54 E 4843,20 S 25 41 E 100, 5792,37 4915,85 5686,17 4435,26 S 2120,71E 4916,19 S 25 33 E 100, 5860.89 4987,93 5754,69 4504,53 S 2143.22 E 4988,41 S 25 27 E 100. 5929,72 '5059,72 5823,52 4573..52 S 2165,64 E 5060,34 S 25 20 E 100, 5998,56 5131,51 5892,36 4642.51 S 2188.05 E 5132,29 S 25 14 E 100. 6066.76 5203.80 5960.56 4712,26 S 2210,04 E 5204,77 S 25 8 E 100, 6134,64 5276,28 6028,44 4782,48 S 2231,51 E 5277,48 S 25 1 E 100, 6201,88 .5349,24 6095.67 4853,45 S 2252.54 E 5350.70 S 24 54 E lO0, 6268,79'"'"5422,37 6162,59 4924,89 8 2273,02 E 5424,13 S 24 47 E lO0. 63:35',70 5495.50 6229.50 4996.33 S 2293,50 E 5497.58 S 24 39 E 100, 6402,29 5568,92 6296,09 5068,04 S 2314,07 E 5571,35 $ 24 3;2 E 0,75 1,82 1,26 0,75 3,40 0,00 0,93 0.93 2,14 0,50 1,00 1,00 0,73 0,50 0,89 0.00 0.00 0,50 IARATH~N' COMPUTATION PAGE NO, .~ :~OLLY VARDIN PLTFM, WELL NOI D-16RD GMS TIME DATE i 'BU; COOK INLET, ALASKA 14;53;49- 23-APR-81 ' TRUE IEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEF'TH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERIT FEET D M D FEET FEET FEET FEET FEET FEET D M DG/iOOF 9000. 48 30 S 15 E 9100. 48 0 S 16 E 9200. 49 O- S 15 E 9300· 48 30 S'15 E 9400. 49 0 S 16 E ~ 50 0 S 16 E 9600· 49 0 S 16 E 9700· 49 30 S 17 E 9800· 49 0 S 17 E ~?.~)_0..,..49 0 S 17 E ~ 48 0 S 21 E lJ~ 47 0 S 26 E 10~· 48 15 S 27 E o4oo, 4m o s E 10500. 48 15 S 31 E ~ 48 45 S 31E 10700· 48 30 S 31E 10800. 47 30 S 31E 10900. 47 45 $ 35 E 47 15 s 35 E 11100, 47 0 S 35 E 11200. 48 45 s 38 E 11300· 50 0 S 39 E 11400· 50 30 S 38 E 11600. 51 30 S 39 E 11700, 51 15 $ 39 E 11800· 51 0 S 40 E 1~900. 51 15 S 40 E . , .- - .~ 100· 6468,55 5642.51 6362·35 5140·21 S 2334,08 E 5645.33 S 24 25 E 100, 6535,14 5715·81 6428·94 5;--6~;11 S 5~'~'~,;*02 E 5719,04 S 24 18 E 100, 6601o40 5789,39 6495·20 5284,28 S 2374,03 E 5793o07 S 24 12 E 100, 6667·34 5863·14 6561·14 5356.90 S 2393,49 E 5867,30 S 24 5 E 100· 6733,27 5937·01 6627·07 5429,35 S 2413,59 E 5941·65 S 23 58 E 0,75 0,90 1,25 0,50 0,90 100, 6798 ~o 6011 84 6692 02 ~.~.~44 S 2434,55 E 6016,97 S 23 52 E .~ · · .~....~ . .. 100· 6863,16 6086.67 6756,96 5575,54 S 24'55,5i E 6092.30 S 23 46 E .1:.:.' ) 100, 6928,44 6161·33 6822,24.. 5648,18 S 2477,02 E 6].67,46 S 23 41E 0,91 100, 6993,71'-"---6236,11 6887,51 5720·62 S 2499,17 E 6242,71 S 23 36 E 0·50 100. 7059.32 6310,60 6953,12: 5792·80 S ~-~1,24 E 6317.68 S 23 31E 100· . i ~_~ ~~ 7019.38 ~~ S ~E~_,_(z2_.E 6392,35 S 23 28 E 100, 7193,14. 6458,55 7086,94 ~L~$ 2.~?~5,~.02 E 6466,08 S 23 28 E 100, 7261.18 6531.83 7154,98 ~9q.~_?_~81S .26_._~i~.Z2 E 6539,26 S 23 30 E 100,.- 7328,42 .... 6605,84 7222.22 ~&~6 S ~s~ E 6613,14 S 23 32 E 100,.".-.7395,17 6680,30 ' 7288.97 6129,11 S ~13 E 6687,47 S 23 35 E .... . ....... ~ ~~~ . T,~-.' 100, 7461 ~2 6754 67 7355 72 61~4,23 S ~711,~3 E 6761,60 S 23 38 E · · e ................. · 100, 7528,18 682~,31 7421,~8 6258,43 S 2749,80 E 6835.89 S 23 43 E 100, 75~4,28';'"~04,0~ 7488.08 g322';'75'S 2788,45 E 6910,33 S 23 48 E 100, 7661.19 6~78.15 7554.~9 6386,45 S 2826.72 E &~84,0& S 23 52 E 100, 7728,59' 7051.51 7622.3~ 6448,41 S 286&,~& E 7057,01 S 23 58 E 100. 7796.15 7124.37 7689,95 6.5___0~.~.~.S 2909,25 E 7129,39 $ 24 5 E 100, 7864,19 7196,80 7757,99 6568.83 S ~'~'~';28 E 7201.36 S 24 12 E 100o 7931,27 7269,78 7825,06 6628,45 S 2995,40 E 7273,84 S 24 19 E 100, 7996.38 7343·95 .7890,18 6687.85 S 3042,65 E 7347·45 S 24 28 E · . 100 8060,32 7419·08 7954,12 6748,02 S 3090,51 E ~ 06 S 24 36 E 3.16 3.82 0.77 1.00 0,25 2,99 0.50 0.25 1,00 0.25 2,83 1·46 0,?2 _. 100, 8123,42 74?4·88 8017,22 &~StZ~.~. 3~.~z.~.(~_.E. 7497.40 S 24 45 E 100· 8185,84 7571,0m 8079,64 6869·45 S 31m7,97 E 7573,14 S 24 54 E 100, 8248,26' 7647,27 8142,06 6930,16 S 3237,13 E 7648,93 S 25 2 E 100. 8311.03 7723.04 8204·83 6990.24 S 3286.65 E 7724°34 S 25 11E 100. 8373,79, 7798.66 8267,59 7049,87 S 3336,69 E 7799.63 S 25 20 E 1.08 0.25 0.25 0·82 0,25 'iARAI'Hi~IN COMPUTATION PAGE DOLLY VARDIN F'LTFM, WELL NO: D-16RD GMS TIME DATE ~BU; COOK INLET, ALASKA 1415;]:49 23-AF'R-81 TRUE '~EASURED DRIFT ['RIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERIT FEET D H D FEET FEET FEET FEET FEET FEE][' D H DG/IOOF -~].2.~QQ~ 49 45 S 39 E 12100, 50 0 S 39 E 12200. 49 30 S 37 E 12300, 48 0 S 4i E 12400, 50 15 S 40 E l~.!..~_.5~, 49 0 S 42 E 12800, 49 0 S 42 E 12700. 49 0 S 41E 12800, 48 0 S 41E 12700. 48 15 S 41E ~ 47 0 S 40 E 13100. 46 30 S 40 E 13200. 46 15 S 40 E 13300, 46 15 S 38 E 13400, 46 0 S 37 E ~, 45 45 S 36 E 13600, 45 15 S 35 E 13700. 45 30 S 35 E 13800, 46 30 S 35 E 13900, 46 0 S 35 E 1~0-0~---47 0 S 35 E -14100. 47 30 S 34 E · .1-~, 45 0 S 31E 14300, 41 30 S 30 E .1...~.38 30 S 29 E 1445~,.--38 0 S 27'E 100, 8437.40 7873,76 8331,20 Z1.Q~..,_~.; S 3385.78 E 7874,47 S 25 28 E 100, 8501,84 7948.33 8J95.64 7168,84 S 3433,90 E 7948.83 S 25 36 E 100, 8566.46 8023,05 8460.25 7228,98 S 3480°89 E 8023,39 S 25 43 E 100. 8632,39 8096,38 8526,19 7287,41 S 3528,20 E 8096,58 S 25 50 E 100. 8697.83 8169.66 8591o63 7344.91 S 3577.~1 E 8169.75 S 25 58 E 100, 8762.61 8243,33 8656,41 7402,E0__S ~~ E 8243,35 S 26 6 E 100, 8828,21 8315,96 8722,01 7458,49 8 3677,79 E 8315o96 S 26 15 E 100, 8893.82 8388.77 8787,62 7515.01 S 3727,80 E 8388,79 S 26 23 E 100, 8960.08--'8461,19 8853.88 7571,54 S 3776,93 E 8461,29 S 26 31 E 100. 9026.83 8533,19 8920.63~. 7627,73 S 5825,78 E 8533,40 S 26 38 E 100, 8988,03 .... 8605,14 s 26 45 E 100, 9162,7 8675,53 9056,55 7739,70 S 3920,58 E 8676,06 S 26 52 E 100, 9231.74 8745,84 9125,54 7795,I6 S 3967.11E 8746.56 S 26 58 E 100, 9300,89 .... 8816,29 9194.69 7851,29 S 4012,57 E 8817o23 S 27 4 E 100, -9370,20 ...... 8886,98' 9264.00 7908.48 S 4056,45 E 8888,1J S'27 9 E .-.. . ~ 7~... 100, ~ 5.~ 9333,63 ,Z~t~i.~!~_S .409~-~..1.5 E 8958,97 S 27 14 E iO0, 950~,92 9028,01 940~,72 8024,25 S 4140,57 E ~029,56 S 27 18 E 100, 9580,16'-:'"9098,35 947~,96 8082,55 S 4181,3~ E ~100,0~ S 27 21 E 100, 9649,6~ 9169,45 ~54~,4~ 8141,48 S 4~,65 E 9171,~9 S 27 25 E 100, ~718,78 ~240,84 9612,58 8200,65 S 4264,08 E 924~,00 S 27 28 E 100, _9_Z87_~2..2~ ~.,~'i-~--2-,53 9681,42 8260,07.S ...4~05.,.~?....~. 9314,92 S 27 32 E 100, 9855,50 9~85,20 9749,30 --8320°59 S 4347,28 E 9387,81 S 27 35 E 100, 9924.65 9457,00 9818,45 8381,51 S ~J8~!.~.,E 9459,79 S 27 37 E ~ ~ S 27 J9 E 100, 9997,48 9525,33 9891,28 ~-~'~';'55-"'~ .~4~Q~.87~E 9528,~ 100, 10074,09 9589,50 9967,89 ~49.~6_6~.~.~ S 4452,52 E 9592,46 S 27 39 E ~=~ .............. . , . . . 50, 10113,35 9620,45 10007,15 8523.82 S 4467,05 E 9623,42 S 27 ;]9 E . .. 1.69 0,25 1,61 3.36 2,37 0.75 1,00 ~,25 1,45 0.50 0.25 1,44 0,76 0,76 0,87 0,25 1,00 0,89 3,31 3,57 3.07 2.67 F~INAL CLOSURE - r-ilRECTION.' DISTANCE s 27 DEGS ;]9 MINS 27 SECS E ~&2J;o42 FEE]' - ~'14~53~49 23-AF'R-81 FILE NUMBER; 47 MARATHON DOLLY VAR[lIN F'LTFM, WELL NO; D-16RD GMS TBU, COOK INLET, ALASKA . , '30NiJERSATIONAL SURVEY PROGRAM V02olI Hr. Robert C. Warthen Union 0tl Company of California P. O. Box 6247 .. Anchorage, Alaska 99502 April 22,. 1982 Re:. Hissing Information -.Completed lqells Dear Bob: We wish to brine to your attention that the below-indicated material on the following Union 0il Company wells has not yet been received by the Alaska Oil and Gas Conservation Commission: Well Granite Pt. t33-14RD Completion Date 3i6/81, Hissing Haterial -DIL/SP & CBL/VDL Elec. Logs. Trading Bay Unit tD-9RD 3/2/82 ........... '~'f'~d:Lug Bay Unit tD-16R ' 5/8/81 Trading Bay. Unit ~D-17RD 6/22/81 -Digitized E. Log Tape -Directional SUrvey -Bloc.. Logs -Directional Survey Trading Bay Unit ~K'3RD . .,, Trading Bay',St. #A-gRD .5/22/81 -well History -Directional Survey -Digitized E. Log Tape Tradin8 Bay St..tA-17RD Cannery Loop Unit ~3 ' · Kenai Unit ~34-32 7/3/81 9/13/81 1/,18/82 -Digitized E. Log Tape -Digitized E, Log Tape -Digitized E. Log Tape -Certified Survey Plat -Directional Survey -DST or Prod. Test Reports 'Trail Ridge Unit 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~urs, William Van Alen Petroleum Geolog. ist WVA:v~I ( Document TransmiU~l Union Oil Company of Ca~: lorn unlsn IDATE SUBMITTED ACCOUNTING MONTH HAND DELIVERY ] ]-5-8] TO ' ' ' I~ROM Mr. Bill Van Allen R.C. Warthen State Oil and Gas , AT Conservation Commission AT Pouch 6247. 3001 Porcupine Drive Anchorage, AK 99502 Anchroage, AK ' ' TE~' ~,.o,~ ,o. TRANSMITTING THE: FOLLOWING: -- I I I I I I I I I On-~ magn.-~tic +'"" 9-15 R! PLEASE SIGN 'AND RETURN Ol E COPY _.'i._' ...... DATE · ' NUVO5191] Alaska 0ii I Gas Cons. ( ~mmissiO~l iii ii i i i i ii iiiii i i i i i ii i i i i i i. iii i i i i I II i il ' I ii I i I iii i i ii i i i i i ii i i ii I I I I I III I FORM 1-2MO2.(REV. 11-72) PRINTED IN U.S.A. Document Transmittal Union Oil Cornpany of California unlsn ~ATE SUBMITTED ACCOUNTING MONTH 9-8-81 TO FROM Mr. Harry Kugler A!~ska Oil ~,a r.~s R_ C_ Warthen AT ^~ Conservation Commission Pouch 6247 3001 Porcupine Drive Anchorage, Alaska 99502 Anchorage, Alaska TRANSMITTING THE FOLLOWING: m D-16REDRILL: 1 ' ea. blueline and i ea. sepia of ~:he' T0~ ~owi.ng' , , . 5" Dual induction SFL 2" Dual induction SFL 5" compensated format' on density log 2" Compensated format' on densi tY log .co.mpensated neutron f~)rmation ~ensit¥ D!L/GR _ / DIL/BHC/GR ~/~PLEASE SIGN AND RETURN ONE COPY RECEIVED' D DATE' - )klas~ Oil & ( as cons. L;on mission ! nchorage m ' i FORM 1-2M02 (REV. 11-72) PRINTED IN U.S.A. STATE Of ALASKA .. ALAS,~,.~AND GAS CONSERVATION~,~ISSION WELL COMPLETION OR RECOMPLETIONREPORT AND LOG ' 1. Status of Well -'Clas$ificati'on0f Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE I~X W~ter Injection . . 2. Name of Operator 7. Permit Number --'-. ......... Union Oil Company of California* 80-110 .. 3. Address 8. APl Number P. O. Box 6247, Anchorage AK 99502 s0- 733-20183-01 4. Location of well at surface Dolly Varden Platform, Leg B-l, Cond. 5 -' 9' Un!t °r Lease Name.. 675'FSL, 1208'FWL, Sec 6-8N-13W-SM .... .: Trading Bay Unit At Tbp Producing-Interval ~- 10. Well Number 2115'FNL, 107'FWL, Sec 17-8N-13W-SM : D-16RD At Total Depth 11. Field and Pool 2700'FNL, 472'FWL, Sec 17-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 106.2'KB MSL ADL-17579 A-1222 McArthur River Fiel'd 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 03-07-81 04-13-81 05-08-81J 90 feet MSLI 1 ,7. TotaIDepth(MD+TVD, 18. Plug 1/~,~1~ ~rV Back De th ,1~ D) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafros:t 4.64~J ' MD' 10. 306 ' TI 'D 1 n I qc; I Tvn YES ]~ NO [] - - feet'MDI - - 2~. Type Electric or Other Logs Run ' - ' ' "~ Iniectivity Profile, Gyro, CBL/VDL/CCL, FDC/CNL, DIL/BHC-Sonic/GR . 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD -: CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD ' AMOUNT PULLED 7" 29# N-80 9689 1-4,644 8-~" -1235 sx . . 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD . interval, size and number) SIZE .... DEPTH SET (MD) PACKER SET (MD) Hemlock B. 4: 3-1/2" 13,5431 1'3,440' TOP BTM T~,985'MD (9777'TVD) 14,000'MD (9787"TVD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. '- 14,015'MD (9797'TVD) 14,036'MD (9812'TVD) DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED. ,. 14,052'MD (9823'TVD) 14,060'MD (9828!-"TVD): "None,- ' - Perfd w/ DA 2-1/2" gun, 4 HPF. · · . 27. PRODUCTION TE$~ "" " Date First Production I Method of Operation (Flowing, gas lift, etc.) I · . . . NA. : .- :. NA · . . .. - Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MC'F" .WA~I~R-BBL CHOKE SIZE I'GAs-OIL RATIO TEST PERIOD I Flow Tubing:. Casing Pressure CALCULATED... OI~.-BBL GAs:M'cF · WATER-BB'L OIL GRAVITY-APl (corr) Press.- 24-HOUR RAT. E ~ "~ " " " .. 28. . '.. 'CORE~"DATA ' ' ':' '"' ~ · · · . ,-- Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ' ~" ~ ~ ~ _. None -- - _. - - .--.. JUN 1..9 i9o'~ · _ . , ~,~ Cons. Commission /~l~s~a 0il & ~.-~ -. Ar.,.-ch0r~.g9 . . .- . . Form 10-407 F~v.: 7-1-80 CONTINUED ON REVERSE SIDE *Harathon 0il Company - Sub-Operator Submit in duplicate 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. None None I 31. LIST OF ATTACHMENTS ~/el] History, Liner and Tubin9 Details 32. I hereby ce~,,~dl~ that the foregoing is true and correct to the best of my knowledge Signed Title DIST DRLG SUPT Date 6/19/81 ___~Z._._'._: - __- INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng 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 ' ' F?~. -84 ~v. s-~ DATE. May 12t 1981 MARATHON OII. COMPANY HISTORY OF OIL OR GAS WELL FIELD McArthur River WELL NO D-16RD LEASE STATE A I aska Tradinq Bay Unit PARISH Kena i Pen in- COUNTY. sula Borough BLOCK SEC., 6 TWP 8N R.13W M EASUREM ENTS TAKEN FROM 106.2' ELEV. KB f ToP OF OIL STRING ELEV ~ TOP OF ROTARY TABLE ELEV. ~ GRD. OR MAT, ELEV.~ L. G. Ha ywood HISTORY PREPARED BY TITLE 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 02-13 02-14 02-15 02-16 02-17 02-18 02-19 02-20 02-21 02-22 02-23 O2-24 02-25 02-26 14,609'TD 14, 127 ' PBTD 14,609'TD 14,127'PBTD 14,609'TD 14,127'PBTD 14,609'TD 14,127'PBTD 14,609'TD 14,127-'PBTD 14,609'TD 14,127'PBTD 14,609'TD 14,127'PBTD 14,609'TD 14,127'PBTD 14,609'TD 14,127'PBTD 14,609'TD 14,127'PBTD 14,609'TD 13,465'PBTD 14,609'TD 13,465'PBTD 14,609'TD 10,071'PBTD 14,609'-TD lO,079'PBTD WELL HISTORY - WELL TBU D-16RD (Marathon AFE 4695) Parker drlg crews on rig 02-12-81. Held safety mtg & rig orientation mtg. Sk-idded rig #76 over well D-16. Began activating rig. FIRST REPORT. Cont activating rig. Unloaded drlg tools from boat. Bled off tbg & annls press from Well D-16. Cont activating rig. Pulled BV from D-16. Attempting to bleed off D-16. Began mixing mud to kill well. Cont RU drlg tools and activating rig. Cont activating rig. Perfd prod tbg'@ 13,444'-446'. Circ well w/ FIW. Circ w/ 9.5 ppg mud to kill well. Circ 9.4 ppg mud dwn tbg. Returns 8.6 ppg gas cut mud. Circ & built MW to 9.7 ppg & killed well. Set-BPV. ND Xmas tree. Began NU BOPE. Fin NU BOPE. Worked on Koomey unit & control lines. Testing BOP ' s. Fin testing. BOP. Pulled BPV. RU & RIH w/ jet tbg cutter. Could not get below 10,830' in 3-1/2" tbg. RD WL unit. Worked hyd pkr free & worked tbg up hole 12'. Backed off in 4-1/2" tbg 7 jts dwn. RIH & latched fish w/ OS. Pulled fish free w/ max 220,000//. POH & LD 304 jts 4-1/2" prod tbg. Fin POH & LD 3-1/2" prod tbg, GL mandrels, & pkr. Instld 5" pipe rams. PU & RIH w/ bit on 3-1/2" & 5" DP. Fin PU DP & RIH w/ 6" bit & 7" csg scraper. Tagged fill @ 14,045'. Washed out to 14,127 'PBTD. POH. RU & ran gyro surv. Fin running gyro_surv. RIH w/ OEDP to 14,07i~. Mixed & spotted 100 sx CIG cmt from 14,071'-13,465'. P&A old Hemlock perfs from 14,110'-13,708. POH & WOC. POH. Clabbered mud & traces of cmt in DP--washed out OK. RIH w/ 8-1/2" bit & 9-5/8" csg scraper to top of Inr @ 10,081'. Circ & POH. Fin POH w/ bit & scraper. Ran JB & gauge ring on WL. Ran CBL from 9800' to TOL @ 10,081'--bond good. Set perm BP on WL @ 10,071'. Presently RIH to wash dried mud out of DP. Fin RIH to 10,061'. Tstd 9-5/8" csg to 2500// for 30 min--OK. Rev circ to clean DP & cond mud for cutting section. Tstd BOPE (witnessed by State). Well History - Well TBU D-16RD Page 2 02-27 14,609'TD 10,079'PBTD 02-28 14,609'TD lO,079'PBTD 03-01 14,609'TD lO,079'PBTD 03-02 14,609'TD lO,079'PBTD 03-03 14,609'TD 10,079'PBTD 03-04 14,609'TD IO,709'PBTD 03-05 14,609'TD 9,850'PBTD 03-06 03-07 03-08 03-09 03-10 03-11 03-12 03-13 03-14 .. 14,609 'TD 9,800'PBTD 14,609'TD 9,960'PBTD 9,999'TD 10,132'TD 10,215'TD 10,431'TD 10,481 'TD 10,688'TD 10,861'TD Cut window in 9-5/8" csg from 9955'-9965'. Tripped for new section mill. RIH w/ section mill #2 & cut window in 9-5/8" csg from 9965'-9983'. Circ & POH. Chgd mills. RIH w/ section mill #3 & reamed 9965'-9983'. Presently milling window @ 9983'. Cut window in.9-5/8" csg from 9983'-9985'. Circ & POH. Chgd out section mills. RIH w/ mill #4. Reamed previously.cut area from 9978'-9985'. Milled window in 9-5/8" csg from 9985'-9986'. Circ & POH. Chgd out section mill. RIH w/ mill #5. RIH w/ section mill #5. Milled window in 9-5/8" csg from 9986'-9994'. Circ & POH. RIH w/ mill #6 & milled 9994'- 9999'. Circ to clean metal shavings from hole. Total window cut: 44~. Circ & pumped hi-viscous pill to clean hole. POH w/ mill //6. RIH w/ mill #7 & reamed. Mil led 9-5/8" window 9999'-10,002'. Circ & POH. RIH w/ mill //8. Total window cut: 47'. Fin RIH w/ section mill //8. Cut 9-5/8" window 10,002'-005'. Total window cut: 50' (9955'-10,005'). POH. RIH w/ bit & CO 9-5/8" stub to lO,079'DPM. Circ & thinned mud. POH. Presently RIH w/ OEDP to lay kickoff plug. Fin RIH w/ OEDP to 10,075' inside 9-5/8" csg stub. Spotted 100 sx CIG w/ 1% CFR-2 across window. PU & rev circ. POH. C&C mud while WOC. WOC. RIH & washed thru soft to med cmt to 9985'. Firm to hard cmt 9985'-10,005'. Circ & POH. RIH w/ OEDP to 10,005'. Spotted 100 sx densified cmt across window. PU & rev circ. POH & WOC. Fin POH w/ OEDP. While WOC, cut & slipped drlg line. Tstd BOPE--OK. RIH w/ bit & tagged firm cmt @ 9775'. Drld firm e to hard cmt to 9960'. C&C mud. POH. MU sidetracking BHA. RIH w/ DD. RIH w/ DD. Oriented w/ SDC on WL. Drld 9960~-9999, w/ DD. POH. RIH w/ drlg assy. RIH w/ drlg assy. Worked thru DD //1 run. Drld from 9999'- 10,072'. Surv no good--interference. POH. RIH w/ DD //2. RU SDC. Oriented & drlg 10,072'-10,132'. RD tools. POH w/ DD //2. POH w/ DD //2. RIH w/ drlg assy & drld 10,132'-10,199'. Circ & surv. POH. Chgd BHA. RIH &.reamed 9998'-10,199'. Drld 10,199'-10,215' w/ locked BHA. Drld from 10,215'-10,431'. Circ & surv. POH. MU DD //3. RIH i-o 9900'. Chgd out Iow drum chain. Instld new Iow drum chain. RIH w/ DD //3 & used SDC to orient. DD 10,431'-10,481'. POH w/ DD //3. Chgd brake bands '& block on drwks. MU BHA. Presently RIH w/ locked BHA. Fin RIH w/ bit //8. Drld to 10,680'. Surv & POH. RIH w/ bit //9. Drld 10,680'-10,688,. Drld 10,688'-10,825'. Circ & surv. POH w/ bit //9. RIH w/ DD //4. Oriented SDC for left turn. DD 10,825'-10,861'. Well History - Well TBU D-16RD Page 3 03-15 11,011'TD 03-16 11,364'TD 03-17 11,530'TD 03-18 11,846'TD 03-19 12,075'TD 03-20 12,262'TD 03-21 12,315'TD 03-22 12,510'TD 03-23 ~2,568'TD 03-24 12,671'TD 03-25 12,810'TD 03-26 12,938'TD 03-27 ~ 13,100'TD 03-28 13,274'TD 03-29 13,480'TD 03-30 13,508 'TD 03-31 ~13,508 ' TD Drld 10,861'-10,869' w/ DD #4. RD WL. POH w/ DD. MU BHA. RIH w/ locked BHA. Reamed 10,715'-10,869'. Drld 10,869'- 11,011'. Drld .11,011'-1.1,130'. Circ & surv. POH. Tstd BOPE--OK. RIH & reamed 11,045'-11,130'. Drld 11,130'-11,364' w/ bit #12. Circ & surv. Fin POH w/ bit #12. RIH w/ bit #13 & reamed 11,274'-11,364'. Drld 11,364'-11,530'. .' Drld 11,530'-11',702'. Cir¢ & surv. POH w/ bit #13. RIH w/ bit #14. Dr1~11,702'-11,846'. Drld 11,846'-11,950'. Circ & surv. POH. RIH w/ bit #15. Drld 221,950'-12,075'. Drld 12,075'-12,262'. Circ & surv. POH w/ bit #15. RIH w/ DD #5. Presently RU SDC to orient DD. Fin oriented'DD #5. DD 12,262'-12,304'. POH w/ SDC WL & tools. POH w/ DD #5. Chgd BHA & RIH. Reamed 12,184'- 12,304'. Drld 12,304'-12,315'. Drld 12,315'-12,382'. Circ & surv. POH w/ bit #17. RIH & drld 12,382'-12,510'. Surv. POH w/ 40 stds. Drwks motor out. Presently replacing brushes in motor. Fin repairing drwks motor. Repaired rig air. POH w/ bit #18. RIH. Reamed 12,442'-12,510'. Drld 12,510'-12,568'. Burned tail bearing in RT. Circ & surv. POH w/ bit #19. Tstd BOPE--OK. Began chg out RT. Fin chg out RT. RIH w/ bit #20. Drld 12,568'-12,671'. Drld 12,671'-12,677'. Circ & surv. POH w/ bit #20. RIH. Drld 12,677'-12,810'. Drld 12,810'-12,938'. Circ & surv. POH w/ bit #21. LD 6 - 6-1/4" DC's. RIH. Fin RIH. Drld 12,938'--13,051'. Circ & surv. POH to chg bits. RIH & drld 13,051'-13,100'. Drld 13,100'-13,247'. Circ & surv. POH w/ bit #23. Chgd BHA & RIH. Reamed 90' to btm. Drld 13,247'-13,274'. Drld 13,274'-13,472'.~ Circ & surv. POH. Tstd BOPE--OK. RIH & reamed 90' to btm. Drld 13,472'-13,480'. Drld 13,480'-13,508'. Power failure on EMD skid #1 @ 1100 hrs. Began cir¢ w/ HOWCO @ 1300 hrs. Chgd elec leads to EMD skid #2. Power restored @ 1630 hrs. Circ w/ rig pump. DP stuck w/ bi.t @ 13,508'. Worked stuck DP. Spotted 50 bbls Pipe Lax. Moved p_ipe e~:ery 30 min. Cont working stuck DP-- no jarring action. TOF ~ 12,558'. Worked stuck pipe w/ no jarring action. Ran FPI--showed stuck @ 12,680'; free @ 12,618' (top HWDP @ 12,646'). Backed off @ 12,558'. POH w/ 135 stds DP. RIH w/ screw-in sub, bumper jars, oil jars, & accel jars. Screwed into fish ~ 12,558'. Could not get jarring action from fishing tools. Presently removing gooseneck from swivel to run backoff. Well History - Well TBU D-16RD Page 4 04-01 13,508 ' TD 04-02 13,508'TD 04-03 13,508'TD 04-04 13,508 ' TD 04-05 13,622 ' TD 04-06 13,790'TD 04-07 13,884'TD 04-08 14,048'TD 04-09 14,153'TD .. 04-10 14,170'TD 04-11 14,462'TD 04-12 14,565 'TD 04-13 14,645'TD 04-14 14,645'TD 04-15 14,645'TD 04-16 14,645' TD 04-17 14,645'TD · 04-18 14,645'TD TOF ~ 12,588'. RIH w/ string shot'& backed off ~ 12,588'. CBU. POH. Replaced jars. RIH & screwed into fish @ 12,588'. Jarring on fish (jarring action OK). TOF @ 12,588'. Jarred on fish w/ no movement. Ran FPI-- showed still stuck @ top of HWDP ~ 12,646'. Spotted SFT/ Black Magic around BHA. Left 10 bbls inside. Let BHA soak in SFT. Worked pipe to keep fishing string free. Worked pipe while soaking fish in SFT. Jarred on stuck DP 2-1/2 hrs. 'Jars on fish began working indicating HWDP was free. Ran FPI--pipe free to top stab on DC's. Backed off 1 jt above DC's. POH w/ 3 jts DP & 20 jts HWDP. LD fish (3 jts DP, 20 jts HWDP). RIH & CBU. Engaged remaining fish & POH. Rec all 288' of fish. RU Dialog WL & RIH. Circ & washed 13,340'-13,508'. Mixing & cond mud. PU bit #26 & RIH. Washed to btm. Drld 13,508'-13,622'. Drld 13,622'-13,626' & surv. POH for new bit. RIH & drld 13,626'-13,790'. Drld 13,790'-13,883' & surv. POH to chg bits. Tstd BOPE-- OK. RIH w/ new I~it. Fin RIH. Drld 13,883'-14,048' w/ bit #28. Drld 14,048'-14,153' w/ bit #28. Pin on kelly saver sub parted. Dropped drlg string. Fished drlg string. POH to shoe. Replaced seals in air line to high clutch. Cont POH sorting & LD crooked DP & BHA. Strung on new drlg line. Off loaded drlg eqpmt from boat. MU new BHA & RIH. Washed fill to 14,153'. Resumed drlg to 14,170'. Drld 14,170'-14,462' w/ bit #29. Drld 14,462'-14,503'. POH taking multi-shot magnetic survs every 90'. Chgd bits & RIH. Reamed 51' to btm. Drld 14,503'-14,565' w/ bit #30. Drld 14,565'-14,645'. C&C mud. Made wiper trip. C&C Mud. Strapped out of hole. RU SOS & ran DIL/BHC Sonic/GR. Fin running logs w/ Schl BHA (FDC/CNL). RIH. C&C hole. POH. Began running 7" Inr. Ran 120 jts 7", 29# Inr w/ shoe ~ 14,644'; TOL ~ 9689'. Dropped ball after circ, set Inr hgr, but could not shear out sub w/ 5600 psi. Finally circ at restricted rate. Appears partially sheared. Released setting tool. POH. Setting too I OK. RU WL. Perfd 4 HPF @ 14,553'. (Landing clr@ 14,556'.) Excessive drag w/ WL. RIH w/ 6" bit & tagged clr ~ 14,556'. . POH. Fin POH w/ bit. Set 7" cmt rtnr @ 9771'DPM (TOL ~ 9689'). Circ thru perfs 14,553'-14,554' &cond mud behind Inr. Cmtd Inr w/ 1235 sx. CIP @ 1010 hrs, 04-16-81. Pulled 10 stds & rev out contaminated mud. POH & WOC. WOC. Tstd BOPE--OK. RIH & tagged cmt @ 9020' in 9-5/8" csg. Drld firm cmt to 9500'. Well History - Well TBU D-16RD Page 5 04-19 14,645 'TD 04-20 14,645 ' TD 04-21 14,645 'TD 14,515 'PBTD 04-22 14,645'TD 14,515'PBTD 04-23 14,645'TD' 14,51-O'PBTD 04-24 14,645'TD 14,510'PBTD 04-25 14,645'TD 14,510'PBTD 04-26 14,645'TD 14,510'PBTD 04-27 14,645 'TD 14,510'PBTD 04-28 14,645 ' TD 14,510 'PBTD 04-29 14,645 'TD 14,510'PBTD 04-30 14,645 'TD 14,510'PBTD 05-01 14,645'TD 14,510'PBTD 05-02 14,645'TD 14,510'PBTD 05-03 14,645'TD 14,510'PBTD 05-04 14,645'TD 14,510'PBTD Drld firm cmt to TOL @ 9689'. Press tstd 7" x 9-5/8" lap to 2500# for 30 min--OK. POH. MU test tools & RIH. Set pkr @ 9600' & ran WSO test--dry. POH. RIH w/ bit & scraper. Circ & POH. RIH w/ 6" bit @ 0700 hrs. Fin RIH & drld cmt in top of. 7" Inr. Drld cmt rtnr @ 9771'. RIH & drld cmt inside 7" Inr from 14,264'-14,515'. Circ. POH w/ 6" bit. Fin POH. RU DA & ran CBL/VDL/CCL.. Poor correlation on CBL & VDL. Repeated 'log w/ 1000 psi surf press--correlation much better. ~:..~ Fin running CBL holding 1000// surf press. Ran gyro surv from surf to PBTD. Ran gauge ring & JB. Ran gauge ring & JB on WL. Set perm BP @ 14,510'DPM. RIH w/ DP. Displ mud w/ FIW. Set prod pkr @ 13,440'WLM. Presently POH w/ WL setting tool. Fin POH w/ WL setting tool & RD WL. R IH. POH & LD DP & DC's. MU prod pkr seal assy & ran on 3-1/2" x 4-1/2" prod tbg w/ GLM's. Tstg to 4000#. Fin running 3-1/2" x 4-1/2" prod tbg, GLM's, & SSSV. Spaced out & landed tbg in pkr @ 13,440'. Tstd tbg, pkr, & seals to 2200#--0K. Set BPV. Began NU BOP' s. Fin ND BOP's. NU Xmas tree & tstd. Flanged up flowline, etc. Lifted 160 bbls out of well. RIH w/ thru-tbg perf gun--had trouble getting thru BV @ 318'. Lifted well & functioned BV. Got gun thru OK. RIH & perfd 14,052'- -14~066'DI L. Compl perfg Hemlock Bench 4. Intervals shot w/ 8 HPF: 14,052'-14,066'; 14,015'-14,036'; & 13,985'-14,000' (all -- DIL). ' GL & prod well to test. Present rate of 2040 BPD @ 98% WC. TP=250#; CP=1100//; Lift Gas=2035 MCFPD. Tstd Well @ 1013 BPD @ 98% WC. TP=120//; CP 1080//; Lift Gas= 1565 MCFPD. Prod Bench 4 perfs until 0900 hrs, 04-29-81. Final rate: 1013 BPD @ 98% WC. SI well. Bled off annls & filled w/ FIW. Hooked up wtr inj li~e. Began inj @ 2200 hrs, 04-29-81. Well took 380 bbls & press up to 3900 psi--not taking wtr at this time. Checked turbine meter--chgd out meter. Returned wel I to injection @ 2100 BPD (aver last 8 hrs) @ 3800 psi TP. Will stabilize rate before running inj surv. Stabilized wtr inj rate into Bench 4 perfs @ 1750 BPD @ 3800// TP. RU Schl & ran inj surv (tracer & temp). Fin running inj surv. Wtr distribution across Bench 4 perfs OK. Pumped drlg mud from tanl~s into D-17 to kill well. Cleaned mud pits. Perfs holes in D-16RD tbg @ 13,420'. Began mixing 9.5 ppg salt brine to kill D-16RD. Fin mixing 9.5 ppg salt brine & displ D-16RD to kill well. l nstld BPV & removed prod tree. NU & tstd BOPE. Pul led & LD 4-1/2" prod tbg. Well History - Well TBU D-16RD Page 6 05-05 14,645 'TD 14,510'PBTD 05-06 14,645 ' TD 14,510'PBTD 05-07 14,645'TD 14,510'PBTD 05-08 14,645 ' TD 14,510'PBTD Fin POH w/ prod tbg. Redressed pkr seal assy. RIH w/ 3-1/2" inj tbg string internally testing to 5000 psi. Test tool string backed off @ connection dropping hydro-test tools into tbg. POH w/ 7650' of tbg to retrieve tools. Could not stand back short 3-1/2" tbg. Closed BOP & rev circ to recover hydro-test tool. Fin RIH w/ 3-1/2" inj tbg string, located & tstd seals in pkr. Spaced out. PU &circ inhibited pkr fluid into annls. Fin displ annls w/ inhibited brine. Stabbed seals into pkr & tstd seals to 1200#. Landed tbg, ND BOPE, NU tree. Tstd tree to 5000# & RU for inj. Began inj wtr. CO mud pits & flushed lines w/ wtr. Observed wtr inj rate into D-16RD while deactivating rig 76. Final rate 1150 BPD into Bench 4 perfs w/ 3800 psi TP & 0 psi CP. Rig released @ 1800 hrst 05-07-81. FINAL REPORT TUBI,NG/CASI. N~ DETAIL . .WELL NO.: O- iA lei] DATE: ~ / z ~/ / 8 , BY: 7~/q 3~C0 ]rO.R Item Description Set ts Size Wt Thread Grade Range Condition Length From To ._ r~4-0, r-~ -I-_~bl~, ~o ,t I~ ,,~ k~¢r ~1 oo o 'N~. o o .... C~mero~ ~-/~e :DCB F B5 ~u~n~ h~n~er 1.0o ~to0 ~2.00 ' qVz" IZ.~ ~3L ~-80 o~ ,r,n~ GOO · ,, , ~ q '/z "__.~z.~ RsL ~-8o 19~q. zO ZZ73.3 ~ , ,, q'/z" %-putt huff ~ ~ RSL o 3, Iff ZZ ~0. 78 C ~Vz IZ.~ ~SL N -80 I~fl.qH ~'~z X-oveF Rst ~ $ ~ffp z1,¢7 Z .... ~"~ ~z,~ A~b ~ -~o ~-.~.~ 7 ~'~8~. o~ - ' I ....... '~'~- 0~,.~ ~ ~.~ I,~ ,~4~1 ~,~ ~, I~ o .., ....... ~Vz" ~.o?er flSL b ~ ,~'~ 6-,OG 7073. k..,5, " bo f/ '., TUBI,N6./CA$ I, NG,. DETAIL · . · . WELL NO.: O-16f~/3 DATE: ,//zN,/[g/ BY:.T~ j Rco Item Description Set ts Size Wt Thread Grade Range Condition Le, ngth From To · _ ~1 '/z Y-nver ~:,Y k )f R,SL F 3.Z3 70~Z.,S7 7o I ~ N'/z IZ.~ ASL /J-gO .. ilO~,~g qYZ2,~ ., N'lz Y-ot, e.~ buft b ~ ~.~ p 3~ l~ geiCO. I ~ - q'~ 17. ~ ~SL ~-~0 I g&-. 3~ ~ .~o.~ fib /~-,.~' ~ ~ 3 '~z ~. ~ AsL ~-Bo 7~/, 9~ ~oq~ ,z~ 3'/z ~..over g,,~t b ~ ~qLo 'C 3, !~ 10933.03 ~ b'/z ~. cuer h.SL. b ~ ~fl p .~-,o.3 I t~qH, 97 3"z ~-,.~der bv4t~ ¢ f.~&p 3.~ " II 3 ¢%7¢ 5 3'~2. fl, ~ ~$L N-80 6~%~j~ IZ oOq, Z 3 .zma rks: (jAT F. · '7_0 ~3 ]_. 'I/.£".. //,2. / .............. I PIPF 'rALLY SHI.'E'r L.'),,..,/// .V~,rlt'. .... ~'")/.,'3...! ?.3._,~z;., . DESTI,";/'-,TI'O'N Oo ,tI t/Z. ;;'EIGHT _. ,~.,__~_ .._ % · __Z~...,_ .. ~__. O R A g ~ . ,L4,,Z.-._,~_; ..... COU F"I_ I N~ ..... -t?:fl .... _ ._ 33[} 30.. 0 1 '2 3 4 5 6 7 8 9 ~0 - I I 9 tq ~,.f q/ .... TUBI,FtG./C.AS. I, NG, DETAIL WELL NO · (~-I~,,.., DATE- fi/z,/ I,~/ Item Descri)tion Set Jts Size Wt Thread Grade Range Condition Length From _To -- ZO 3 'lz ~ ~.5 ~SL .. I _.IH ~'/2 q.3 ASk A.J -~o z/26, 77 I 3 o7o. 6- L I -., V ,. , ,. . . 3'5 0~,,' X-n.o, Is O, ,.'~ I 3 ~ 80. Z.8 .... , ~ ~ J J . I do,,,n ,.1 ~ 79,~e , 6 ? 3 9 I0 11 ~2 :3 14 15 PIPE TALLY S?tEET .-, D EST i ;,' AT !'O'N" .- · _z..z.-.'._c..~_r._4.;L'__ ' "~ .... z.-. .... /...!. /~._: ~.. __ I~; ~ GRADE .?.'~-"" C'OUPL!NG..>:-"~ ...... 16 11 18 i9 _,. 2O 1 (~/ "1 4 5 6 7 8 9 ~0 lNG DETAIL WELL NO.: /') '- "~"" A:"'/"~ . . /. '-,, \ ,._~ DATE: .:.~/L~ ,/':/' ! · ' ~'?.-~'t. ," BY: /x i.'L"', 'r- . ...... Item Description Set ;_~_s S i zeWt Thread GradeRange Cond i t ion Length From To ~ .. .,.~ _~ /J~; -/ i ~ ' I I . .. . ..... , , , I ~Y- ~.'.~ J..~'2~ ~ q,L~ A~,x.x x/~s: .>:o" i4-,,~,. ~Pc_ /, '7o .... j ~ .R'/- ,~ .. . - .~ ., -7.0 /~sL /F~o ~ .~PC ~ 3o x/3, I .... L -.~ X~ ~ ~ ~ ' /'c ~/~0 . ~5'~ ~ "' .'~ .-3~ 9.3,.,...~/ ~ o'7/3..S [ ~'Tg;S, ,/.~ , . .... ~ " ' , ,~ ~,.'~... /%x. _ ;x' ~/~,~ '~c' ,~c../_. :..~-xY.. ,~.. . ,-'."/ .. /L~7~..'7~ '- 7 ',. ":~ q' /3"5%Y. 7'4 ;"~ '" ...... ~.-' ~,',q, ~,,,~.~ ~,~ -b'u~:~, ,g g~L) . /, c .u, . / ,..,..~, . , F"-. - r, ' ,,i~. ,..... g.....2 i~,z..,', ....~...,_.. ' '.~ .... ..~_~ .~D~ /~.x /.~~7~//~.~c~...~%'~ ........... I ' U, ........... '~ ....... ,,.. ~ ,, ..; . ,." /".'~ /...>.~" 1} ( ~', : .. c' , .q,..,.~ <-..7 ~ ~ ,.~r ,..,. . ~ . .. -,.. ', 4,-..,_,_' .. .... ,%'-~?'5 .~,. ,.V,...~....;./~- ~-,~ ,~, c). q-/LB' ....... ~.-. , , _ .. /A..b~ ~, .7 ...... ' ' I ~..,7, ~ / .... ~m .............. ~ '..~. ~= /~-i.~r t ~ ~) L) ) , ,, ~... "".UN' ~,. -[HI . : '. . ...'ff&~,,,.~"~-~~'~ L..~'T~ ~c~'~r~ ,.~ ~,4z~o~,-~r ~.c,~,~x ' / ,.'A ," .~'F "TM ''~'~ Y>O i ......... . ... ,, :-.,~'/t.L~V [ ~qspc*~) /,-:, ., ' · r-,a rks: WELL NO.: DATE: Item Description Set J__ts Size Wt Thread Grade Range' Condition Length From To [ 7'5:~9~ *.t-~0 ~urr ~.. .~ RD ~0. -3/, ~¢t //9¢9,0¢//97~.,~ ' ,, &t // ' ., ' ; ( , ...... ~ c~ ~ -~ . , ... ' ,. . ./~o /,/¢:e,~ / WA o o !~/~Ol, o~ ~ o,' , % · i i i ' , Hr;RAI'HON . ;" D~L. LY VARDIN F'LTFPI, WELL NO; D-16RD GMS I'BLJ, COOK INLET, ALASKA GPIS, 0-144~;0 MD, SURVEYOR; T BREEN/M LUND, [lATE RUN; 21-APR-81 CAMERA NO; 1580, GYRO NO; .566, 90 DEG A/U NO; 1170 c~].GHTING l'O; GRAYLING (N 18 10 55E) VERTICAL SECTION CALCULATED IN F'LANE OF F'ROF'OSAL DIRECTION; S 26 DEG,' 14 MING E .. .. ... ... RECORD OF SURVEY RADIUS OF CURVATURE METHOD :i¢-iRA'i- H~.N COMPUTATION PAGE NO OOLI.'~_..OARDIN F'LTFM, WELL NO: D-16R[; GMS . TIME DATE . l'E~d, CO'OK INI. ET, ALASKA '.- 14143;58 23-AF'R-81 TRUE ~ '~EASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S-U R E DOGLE~ DEF'TH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERI1 FEEl' D M D FEET FEET FEET FEET -FEEl' FEET D M DG/IOOF O, 0 0 0 O, 0,00 0,00 -106,20. 0,00 0,00 0,00 0 0 0,00 100. I 0 S 84 W 100, 99,99 -0,30 --6,21 0,09 S 0,87 W 0,87 S 84 0 W 1,00 200, 0 15 S 68 W 100, 199,99 -0,53 93,79 0,35 S 1,92 W 1,95 S 79 34 W 0,76 300, 0 45 N 12 W 100, 299,98 -1,15 193,78 0,01 N 2,60 W 2,60 N 89 53 W 0,83 400, I 15 N 46 W 100, 399,97 -2,87 293,77 1.51 N 3,43 W 3,75 N 66 16 W 0,76 .0 i 15 S 80 W 100, 499,94 -4,31 393,74 2.12 N 5,44 W 5,84 N 68 41W ~'~-'~00' 0 45 N 47 W 100, 599,93 -5,45 493.73 2,60 N 7,06 W 7,52 N 69 45 W 1,00 700, I 15 N 54 W 100, 699,91 -7,04 593,71 3,71 N 8,40 W 9,19 N 66 10 W 0,51 ~o W 11,13 N 66 40 W 0,63 800, I 0 N 84 W 100, 799,89 -8,47 693,69 4,41N 900, 6 30 S 18 E 100, 899,64 -6,16 793,44 0,12 N 13,68 W 13,68 N 89 29 W 6,97 1000, 8 30 S 22 E 1100, 10 30 S 24 E 1200, 12 30 $ 24 E 1300, 15 0 S 25 E 1400, 17 30 S 26 E 1500, 20 0 S 26 E 1600, ~° 30 S 27 E 1700, 25 15 S 28 E JGO0, 28 0 S 30 E ~0, 31 30 S 31E 2000, 33 0 S 32 E 2100, 34 30 S 28 E 2200, 36 15 S 27 E 2300, 41 30 S 30 E 2400. 47 45 S 31 E 100, 998,78 100. 1097.41 100, 1195,39 100, 1292.52 100,...1388o52 . 100, 1483,20 100, 1576.40 100. 16.67.83 100, 1757,22 100, 1844,02 100. 1928,59 100,- 2011.74 100, 2093,27 100, 2171,10 100, 2242.23 6,81 892,58 23,29 991,21 43,21 1089,19 66,97 1186,32 12,1~'"'~ 9,~ ~ W 27,33 S 2.77 W . 45,54 S 5,34 E 67.17 S 15.19 E '27o24 E 94.94 1282.32 - 92,42 S ..- : 127,08 1377,00 163,32 1470.20 203,78 1561,63 248,54 1651,02 298,02 1737,82 121,31S 41,33 E 153,74 S 57,50 E 189,64 S 76.19 E 228,83 S 97.91E 271,58 S 123,09 E 351.15 1822.39 406.57 1905.54 464,45 1987,07 527,13 2064.90 597,15 2136.03 317,08 S 150,97 E 765,18 S 178,74 E 416,5~ S 205,47 E 471,66 S 235,41E 532,15 S 271,04 E 15.24 S 37 13 W '2,07 27.47 S 5 48 W 2.03 45.85 S 6 41E 2,00 68,86 S 12 45 E 2,51 96.35 S 16 25 E 2.52 128,16 . S 18 49 E 164,14 S 20 30 E 204,37 S 21 53 E 248,90 S 23 10 E 298,17 S 24 23 E 2,50 2,53 2.78 2.89 351.18 S 25 28 E 1.59 406.58 S 26 5 E 2.68 464.45 S 26 15 E -"-'1,84 527,14 S 26 31E 5,58 597.20 S 26 59 E 6.29 2500, 46 30 S 27 E 2600. 47 45 S 25 E 2700, 49 0 S 26 E 2800. 49 0 S 27 E 2900. 50 0 S 27 E 100, 2310.27 100, 2378.31 100, 2444,74 100. 2510.34 100, 2575,29 670,33 2204,07 743,61 2272,11 818.35 2338,54 893,82 2404.14 969.85 2469,09 596,24 S 306.56 E 662.10 S 338.68 E 729.56 S 370,87 E 797,10 S 404,54 E 864.86 S 439.06 E 670,43 S 27 13 E 743,69 S 27 5 E 818,42 S 26 57 E 893,88 S 26 55 E 969,92 S 26 55 E 3.19 1.93 1,46 0,75 1,00 H A R A ~' H ON DqLi..Y VARDIN F'LTFM, WELL NO; D-16RD GMS TBU, COOK INLET, ALASKA COriF'UTATION TIME [~ATE i4;43:58 23-AF'R-81 PAGE NO. TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R DEF'TFI ANGLE DIRECTION LENGTH DEPTH FEET D M D FEET FEEl' C L 0 S U R E DOGLE( SECTION TVD C 0 0 R D I N A T E S DISTANCE [mlRECTION SEVERI' FEET FEET FEET FEET D M DG/IO01 3000. 50 15 S 27 E 3100. 51 0 S 27 E 3200. 52 0 S 25 E ;]300. 52 0 S 26 E 3400. 53 0 S 26 E '-~'--'.~0. 54 0 S 26 E 54 45 S 27 E 3700. 55 0 S 28 E ;5800. 55 0 S 28 E 39'00. 55 :30 S 28 E 100. 2639.40 1046.59 2533+20 933°24-S 100, 2702.84 1123,89 2596,64 1002,11S 100. 2765.09 1202.14 2658+89 1072.45 S 100. 2826.65 1280.94 2720.45 1143.57 S 100, 2887,53 1360.27 2781,33 1214.88 S 100, 2947.01 1440,65 2840,81 1287,13 S 100, 3005.26 1521.94 2899,06 1359.87 S 100. 3062,79 1603,70 2956.59 1432.42 S 100. 3120.15 1685.58 3013.95 1504.74 S .. 100. 3177.15 1767.71 3070.95 1577.2~-S 473.90 E 1046.67 S 26 55 E 509.00 E 1123.97 S 26 56 E 543.30 E 1202.22 S 26 52 E 577.23 E 1280+99 S 26 47 E 612.01E 1360.32 S 26 44 E 647.24 E 1440.70 S 26 42 E 683.51E 1521.98 S 26 41E 721.28 E 1603.76 S 26 44 E 759.73 E 1685.66 S 26 47 E 798.31 E 1767.81 S 26 51 E 0.25 0.75 1.86 0.79 1.00 1.11 0.86 0.00 0,50 4000, 55 0 S 28 E 4100. 54 0 S 27 E 4200. 54 0 S 28 E 4300. 54 0 S 28 E 4400. 52 45 S 28 E 100. 3234.15 1849.83 3127.95 1649.84.:-S 100. 3292.22 1931.22 3186.02 1722.05 S 100. 3351.00 2012.10 3244.80 1793.~-'S 100. 3409.78 2092.97. 3303.58 1865.24 S 100. 3469.43 2173.18 3363.23 1936,10 S 836.88 E 1849.96 S 26 54 E 874.47 E 1931.36 S 26 55 E 911.83 E 2012.26 S 26 57 E 949.81 E 2093,15 S 26 59 E 987.49 E 2173+39 S 27 I E 0.50 0.81 0o00 1.25 4500. 52 30 S 27 E 4600. 52 0 S 27 E 4700. 52 0 S 27 E ~800. 51 0 S 26 E OO. 51 0 S 25 E 5000. 50 0 S 25 E 5100. 49 0 S 26 E 5200. 49 0 S 27 E 5300. 47 0 S 27 E 5400. 46 30 S 27 E 100. 3530.14 2252.63 3423.94 2006.59 S 1024.18 E 2252.86. S 27 2 E 0.83 100. 3591.36 2331.69~ 3485.16 2077.0W--:S 1060.08 E 2331.92 S 27 2 E 0.50 100. 3652.93 2410.49 3546.73 2147.25 S. 1095.85 E 2410.72 S 27 2 E 0.00 100o 3715.18 2488.74.. 3608.98 2217.2~"S 1130.77 E 2488.98 S 27 I E - 1.27 100. 3778.11 2566.45 3671.91 2287.43 S 1164.23 E 2566.67 S 26 58 E 0'--~8 100. 3841.71 2643.60 3755.51 2357.37 S 1196.84 E 2643.78 S 26 55 E 1o00 100.- 3906.66 2719.63 3800.46 2426.00 S 1229.57 E 2719.80 S 26 53 E 1.26 100. 3972.26 2795.10 3866.06 2493.54 S 1263.25 E 2795.27 S 26 52 E ...0.75 100. 4P39.17 2869.40 3932.97 2559.75 S 1296.99 E 2869.58 S 26 52 E 2.00 100. 4107.69 2942.23 4001.49 2624.65 S 1330.05 E 2942.42 S 26 52 E 0.50 5500. 46 0 S 27 E 5600. 45 30 S 26 E 5700. 47 0 S 26 E 5800. 49 0 S 26 E 5900. 5.1. 0 S 27 E 100. 4176.84 3014.46 4070.64 2689.01 S 1362.85 E 3014.65 S 26 53 E 100. 4246.62 3086.09 4140.42 2753.11S 1394.81E 3086.28 S 26 52 E 100. 4315.77 3158.32 4209.57 2818.04 S 1426.47 E 3158.51 S 26 51 E 100. 4382.68 3232.63 4276.48 2884.83 S 1459.05 E 3232.81 S 26 50 E 100. 4446.96 3309.23 4340.76 2953.38 S 1493.23 E 3309.41 S 26 49 E 0.50 0.87 1.50 2.00 2.14 .001..L.Y gARDIN F'LTFM, WELL NO; D-16RD GMS YEi'U, cdoK INLET, ALASKA COMF'UI'AI' I ON TIME IiATE 14;43;58 23-AF'R-81 PAGE NO. TRUE 9EASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C l' A N 8 U L A R C L 0 S U R E DOGLEO DEF'TH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERI1 FEET D M D FEET FEET FEET FEET FEET FEET D M DG/100F 6000. 51 30 S 26 E 6100, 52 0 S 26 E 6200. 52 30 S 27 E 6300. 50 30 S 27 E 6400. 51 0 S 26 E 'i~--., ,..d) 50 0 S 26 E o 100. 4509.55 3387.22 4403.35 3023.17-S 1528.03 E 3387.39 S 26 49 E 100. 4571.46 3465.75 4465.2.6 3093.75 S 1562.45 E 3465.91 S 26 48 E 100. 4632.68 3544.81 4526.48 3164.51 S 1597.73 E 3544.98 S 26 47 E 100. 4694,93 3623.06 4588.73 3234.24 S 1633.26 E 3623.24 S 26 48 E 100. 4758.20 3700.50 4652.00 3303.54 S 1667.81 E 3700.67 S 26 47 E 100. 4821.80 3777.66 4715.60 3372.90 S 1701,64 E 3777.83 S 26 46 E 100. 4886.08 3854.27 4779.88 3441.75 S 1735.22 E 3854.43 S 26 45 E 100. 4951.03 3930.31 4844.83 3510.09 S 1768.55 E 3930.46 S 26 44 E 100. 5016.96 4005.49 4910.76 3577.67 S 1801.51 E 4005.64 S 26 44 E ,. 100. 5082.90 4080.66 4976.70 3645.52'-"8 1833.88 E 4080.80 S 26 42 E 0,93 0,50 0,94 2,00 0.92 ?/-~\0 0.00 1.00 0.50 0,90 7000. 49 0 S 24 E 7100. 50 0 S 22 E 7200. 49 0 S 23 E 7300. 49 0 S 22 E 7400. 51 30 S 19 E 100. 5148.50 4156.10 5042.30 3714.2.0.=-S 1865.17 E 4156.22 S 26 40 E 100. 5213.45 4232.01 5107.25 3784.19'S 1894.88 E 4232.10 S 26 36 E 100. 5278.39 4307.89 5172.19 3854.4~7"S 1923.98 E 4307.94 S 26 32 E 100. 5344.00 4383.20 5237.80 3924.16 S 1952.86 E 4383.23 S 26 27 E 100o 5407.94 ~459.68 5301.74 3996.16 S 1979.78 E 4459.69 S 26 21 E 0.75 1.82 1,26 0.75 3,40 7500. 51 30 S 19 E 7600. 51 0 S 18 E 7700. 51 30 S 17 E 7800. 49 30 S 18 E )0. 48 30 S 17 E ~_~.' 8000. 46 30 S 18 E 8100. 47 0 S 18 E 8200, 46 0 S 18 E 8300. 47 0 S 18 E 8400. 47 0 S 17 E 100, 5470,19 4537,32 5363,99 4070,16 S 2005,26 E 4537,32 . S 26 14 E 100, 5532,78 4614,60.. 5426,58 4144,1~-S 2030,01 E 4614,61 S 26 6 E 100, 5595,37 4691,68 5489,17 4218,49 .S. 2053,46 E 4691,74 S 25 57 E 100, 5658,98 4767.94 5552,78 4292,0'8-'S 2076,66 E 4768.07 S 25 49 E 100, 5724,58 4842,54 5618,38 4364,06 S 2099,35 E 4842,76 S 25 41 E 0,00 0,93 0,93 2.14 100. 5792.14 4915.41 5685.94 4434+37 S 2121.52 E 4915.74 S 25 34 E 2,13 100.- 5860.66 4987.49 5754.46 4503.64 S 2144.03 E 4987.95 S 25 27 E 0.50 100. 5929.49 5059.28 5823.29 4572.63 S 2166.44 E 5059.88 S 25 21 E ..:.1o00 100. 5998.32 5131.07 5892.12 4641.61 S 2188.86 E 5131.83 S 25 15 E 1.00 100. 6066.52 5203.36 5960,32 4711.36 S 2210.85 E 5204.31 S 25 8 E 0.73 8500. 47 30 S 17 E 8600. 48 0 S 16 E 8700. 48 0 S 16 E 8800. 48 0 S 16 E 8900. 48 30 S 16 E 100. 6134.40 5275.84 6028.20 4781.59 S 2232.32 E 5277.01 S 25 2 E 100. 6201.64 5348.79 6095.44 4852,56 S 2253.34 E 5350.22 S 24 55 E 100, 6268,55 5421,93 6162,35 4924.00 S 2273,83 E 5423,65 S 24 47 E 100, 6335,47 5495.06 6229.27 4995.43 S 2294,31 E 5497,11 S 24 40 E 100, 6402.05 5568.48 6295.85 5067.15 S 2314.88 E 5570.87 S 24 33 E 0,50 0,89 0,00 0.00 0,50 )'i ,~' R A T H ~N DOLLY 'VARDIN F'LTFM, WELL NO: D-16RD GMS l'~'U, COOK INt. ET, ALASKA COMPUTATION TIME DATE 14;43;58 23-AF'R-81 F'AGE NO. .4 TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N ~ U L A R C L 0 S U R E DOGLE( DEF'I'H ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERI' FEEl' D M D FEET FEET FEET FEET FEEl' FEET D M DG/IO0; 9000. 48 30 S 15 E 9100. 48 0 S 16 E 9200. 49 0 S 15 E 9300. 48 30 S 15 E 9400. 49 0 S 16 E 100. 6468.32 5642.06 6362.12 5139.32- S 2334.89 E 5644.85 S 24 26 E 100. 6534.90 5715.36 6428.70 5211.21 S 2354.83 E 5718.56 S 24 19 E 100. 6601.16 5788.94 6494.96 5283.38 S 2374.84 E 5792.58 S 24 12 E 100. 6667.10 5862,69 6560.90 5356.00 S 2394.30 E 5866.81 S 24 5 E 100. 6733.03 5936.55 6626.83 5428.45 S 2414.39 E 5941.16 S 23 59 E 100. 6797.98 6011.38 6691.78 5501.54 S 2435.35 E 6016,47 S 23 53 E 100. 6862.92 6086.21 6756.72 5574.63 S 2456.31 E 6091.80 $ 23 47 E 100. 6928.20 6160.88 6822.00 5647.27 S 2477.83 E 6166.95 S 23 41 E 100. 6993.47 6235.65 6887.27 5719,72 S 2499.98 E 6242.20 S 23 37 E .. 100. 7059.08 6310.15 6952.88 5791.89-'S 2522.04 E 6317.17 S 23 32 E 0.75 0..90 1.25 0.50 0.90 1'.OO 0.91 0.50 0.00 J. O000. 48 0 S 21 E lpJ. O0. 47 0 S 26 E 10200. 47 15 S 27 E 10300. 48 15 S 27 E 10400. 48 0 S 27 E 10500. 48 15 S 31E 10600. 48 45 S 31E 10700. 48 30 S 31E lnGO0. 47 30 S 31E :,~'00. 47 45 S 35 E 1:[000. 47 15 S 35 E 11100. 47 0 S 35 E 11200. 48 45 S 38 E 11300. 50 0 S 39 E 11400. 50 30 S 38 E 100. 7125.34 6384.43 7019.14 5862.69.:.8 2546.42 E 6391.82 S 23 29 E 100, 7192.90 6458.05 7086.70 5930.28 S 2575.81 E 6465.53 S 27 29 E 100. 7260.94 6531.33 7154.74 5995.88~'S 2608.51 E 6538.71 S 23 31 E 100. 7328.17 6605.35 7221.97 6061.82 S 2642.11 E 6612.59 S 23 33 E 100. 7394.92 ~679.80 7288.72 6128.16 8 2675.92 E 6686.92 S 23 35 E :. .... 3.16 3.82 0.77 1.00 0.25 100. 7461.67 6754.15 7355.47 6193.27 S 2712.01E 6761.03. S 23 39 E 100. 7527,93 6828.79 7421.73 6257.49~S 2750.58 E 6835.32 S 23 44 E 100. 7594.03 6903.57 7487.83 6321.79 S_ 2789.23 E 6909.76 S 23 48 E 100. 7660.94 6977.63 7554.74 6385.4'~-"S 2827.50 E 6983.50 S 23 53 E 100. 7728.34 7050.97 7622.14 6447.43 S 2867.73 E 7056.43 S 23 59 E 2.99 0.50 0.25 1.00 7 100. 7795.90 7123.84 7689.70 6507.82 S 2910.02 E 7128.81 S 24 6 E 0.50 100.- 7863.94 7196.26 7757.74 6567.85 S 2952.05 E 7200.79 S 24 12 E 0.25 100. 7931.02 7269.23 7824.81 6627.47 S 2996.16 E 7273.26 S 24 20 E ,~.2.83 100. 7996.12 7343.40 7889.92 6686.86 S 3043.41E 7346.87 S 24 28 E 1.46 100. 8060.07 7418.53 7953.87 6747.03 S 3091.27 E 7421.48 S 24 37 E 0.92 11500. 51 15 S 39 E 11600. 51 30 S 39 E 11700. 51 15 S 39 E 11800. 51 0 S 40 E 11900. 51 15 S 40 E 100. 8123.17 7494.33 8016.97 6807.74 S 3139.56 E 7496.81 S 24 45 E 100. 8185.59 7570.52 8079.39 6868.46 S 3188.73 E 7572.56 S 24 54 E 100. 8248.01 7646.72 8141.81 6929.17 S 3237.90 E 7648.36 S 25 3 E 100. 8310.78 7722.49 8204.58 6989.24 S 3287.41 E 7723.77 S 25 11 E 100. 8373.54 7798.10 8267.34 7048.88 S 3337.45 E 7799.06 S 25 20 E 1.08 0.25 0.25 0.82 0.25 -'i Ai'~ A ';'H!!JN COMPUTATION PAGE NO. -.5 [IOLLY gARDIN F'LTFM, WELL NO; D-16RD GMS . TIME [mATE - I*B'O, COOK INLET, ALASKA .... 1"4;43,'58 23-AF'R-81 . ~ · TRUE · '~IEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E r~OGLEG DI--F'TH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERIT FEET r~ M D FEET FEET FEET FEET FEET FEET D M DG/100F 12000. 49 45 S 39 E 12100, 50 0 S 39 E 12200. 49 30 S 37 E 12300, 48 0 S 41E 12400. 50 15 S 40 E 1'~ ,0 49 0 S 42 E zoo' o 13000. 47 0 S 40 E 15100. 46 50 S 40 E 13200. 46 15 S 40 E ].3300. 46 15 S 38 E 13400. 46 0 S 57 E 100, 8437.15 7873,20 8330,95 7108,42--S 3386,53 E 7873.89 S 25 28 E 100, 8501,59 7947,77 8395,39 7167.84 S 3434.65 E 7948.25 S 25 36 E 100, 8566,21 8022.49 8460.00 7227.98 S 3481.64 E 8022,81 S 25 43 E 100, 8632.14 8095,79 8525,94 7286.39 S 3528,94 E 8095,98 S '25 51 E 100, 8697,57 8169,07 '8591.37 7343.89 S 3578.04 E 8169.15 S 25 59 E ~ ~ 73 8656,15 7401.38 S 3628,02 E 8242,75 S 26 7 E 100, 8762.35 8~4~, 100, 8827,96 8315,36 8721,76 7457,46 S 3678,52 E 8315,36 S 26 15 E 100, 8893.56 8588,17 8787.56 7513.99 S 3728.53 E 8388,20 S 26 23 E 100, 8959.82. 8460.59 8853.62 7570,51S 3777,66 E 8460,69 S 26 31E .. 100, 9026,57 .8532.59 8920,37 7626.70--S 3826.51 E 8532.81 S 26 39 E · 100, 9093.97 8604.18 8987,77 7682,88.:S 3874.49 E 8604,55 S 26 46 E 100, 9162.49 8674,93 9056.29 7738.67'S 3921,31E 8675.46 S 26 52 E 100, 9231.48 8745,2~ 9125,28 7794,1~:"S 3967.83 E 8745.97 S 26 59 E 100, 9~00.63 8815,68 9194.43 7850.26 S 4013,29 E 8816.64 S 27 5 E 100, 9369,94 8886,38 9263,74 7907.45 S 4057,17 E 8887,54 S 27 10 E 1.69 0,25 1.61 3,36 2,37 .~7 0,00 '0,75 1,00 0.25 1,45 0,50 0,25 1.44 0,76 15500. 45..45 S 36 E 13600. 45 15 S 55 E 15700. 45 50 S 35 E 13800. 46 30 S 35 E 1~ .~0., 46 0 S 35 E 14000. 47 0 S 55 E 14100, 47 30 S 34 E 14200, 45 0 S 31E ].4300. 4]. 50 S 30 E 14400, 38 30 S 2? E 100, 9439,56 8957.01 9333.36 7965,15 S 4099,87 E 8958.38 .S 27 14 E 100, 9509.65 9027,40.. 9405.45 8023.2~'-S 4141,29 E 9028.97 S 27 18 E 100, 9579,90 9097.74 9473,70 8081,52 S- 4182.11 E 9099,51 S 27 22 E 100, 9649,37 9168.84 · 9543,17 8140.4~r'-S 4223,37 E 9170.81 S 27 25 E 100, 9718,52 9240,23 9612,32 8199.61S 4264.81E 9242,42 S 27 29 E 0,76 0,87 0,25 1,00 100, 9787.35 9511.92 9681.15 8259.03 S 4306,41 E 9314,33 S 27 32 E 1,00 100, 9855,23 9384.59 9749.03 8319.55 S 4348,00 E 9587,23 S 27 36 E 0,89 100, 9924,38 9456,38 9818.18 8380,46 S 4386,81 E 9459,19 S 27 38 E -'.3,31 100, 9997.20 9524.69 9891.00 8439,49 S 4421,58 E 9527,61 S 27 39 E 3.57 100o 10073,80 9588,86 9967,60 8495,43 S 4453.23 E 9591,85 S 27 40 E 3,07 14450, 38 0 S 27 E 10113.07 9619,80 10006,87 8522.76 S 4467,76 E 9622.80 S 27 40 E 2,67 FINAL CLOSURE -DIRECTION; DISTANCE: S 27 DEGS 39 HINS 51SECS E 9622.80 FEET 14:43;58 23-AF'R-81 FII. E NUMBER; 47 MARATHON DOI. LY VARDIN F'LTFM, WELL NO; D-16RD GMS TBU, COOK INI. ET, CO' "ERSATIONAL SURVEY PROGRAM V02oll Check Form for timely compliance wit2~ our regulations. Operator, Wel 1 Name and Number Reports and Materials to be received by: ~- ~- Date Completion Report Well History Samples Mud Log Required Yes ' Yes Date Received Remarks Core Chips Core Description Registered Survey Plat Inclination Survey ~,' (' ....'. ......... ..,"Dlrectl°nal Survey / Drill Stem Test Reports Production Test Reports ........ , .,.J" .' ".,,. ........ --~ ~ i" ...... ~.., ;~'-' ..... t.~ ........... ~'... - ,, ......... ~.'~'"' Digitized Log Data ~r.~;'.' '? , ~ ....... --'~. . ~ ._ . ..... Yes /-.n-ko STATE OF ALASKA ~ ;' ALASKA(. .L AND GAS CONSERVATION C~ .MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drillingwell~ Redri 1 I Workover operation [-I 2. Name of operator Union 0il Company of California* 3. Address P. 0. Box 6247, Anchoraqe AK 99502 Location of Well at surface Dolly Varden Platform, Leg. B-l, Cond #5, 675'FSL, 1208'FWL, Sec 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106.2' KB MSL 6. Lease Designation and Serial No. ADL-17579 A-1222 For the Month of. MAY ,19 81 7. Permit No. 80-110 8. APl Number so-733-2o183-Ol 9. Unit or Lease Name Trading Bay Unit 10. Well No. 11. Field and Pool McArthur-River Field '12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks DEPTH AT END OF MONTH: 14,645'MD 14,510'PBTD 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 Ran injectivity profile across perfOrated intervals (13,985' - 14,066'). 1 6. DST d~ta, perforating data, shows of H2S, miscellaneous data Final injection rate: 1150 BPD into Bench 4 perfs w/ 3800 psi TP, 0 psi CP. 17. I hereb~,~if¥ that the foregoing is true and correct to the best of my knowledge. SIS E D!ST DRLG SUPT. Ni~eport on this form is required f~. 1ch calendar month, regardless of the status of oper?"ons, OP~al~d Gas Conservation Commission by ~,._ 5th of the succeeding month, unless otherwise direc{~ DATE 6/12/81 ~ChOr~ge Form 10-404 *Marathon Oil Company - Sub-Operator and must be filed in duplicate with the Alaska Submit in duplicate (I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~ OTHER [] 2. Name of Operator Union 0il Company of California* 3. Address P. 0. Box 6247~ ^nchoraqe AK 99507 4. Location of Well Dolly Varden Platform, Leg B-l, Cond //5, 675'FSL, 1208'FWL, Sec 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) !06-2'KB 12. 6. Lease Designation and Serial No. ADL- 1_ 7579 A- 1222 7. Permit No. 80-110 8. APl Number 50- 733-20183-01 9. Unit or Lease Name Trad lng Bay Un it 10. Well Number D- 16RD 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 ,lq 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). Received verbal approval to complete well as an injector from Hoyle Hamilton to Tony Swan on May 5, 1981. Completed well as an injector on May 8, 1981. Perforated zones as follows:. Bench 4: 13,985'-14,000'DIL 14,015'-14,036'DIL 14,052'-14,060'DIL Injection Rate: 1150 BPD TP 3850 psi CP 0// * Marathon Oil Company - Sub-Operator 14. I her~rtify that the~re~l~ is true and correct to the best of my knowledge. ...... tie DIST DRLG SUPT- Co~tions of Approval, if any: JUN - 9198I ~[laska 0il & Gas Cons. Commissio~ Anchorage Date 6/8/8'i Approved by . [ COMM ISS ION ER Form 10-403 ~,.. Rev. 7-1-80 By Order of the C!]-mission Date Submit "Intentions" in Triplicate and ".Subsequent Reports" in Duplicate STATE OF ALASKA " ALASKA,..~L AND.GAS CONSERVATION C~,_~MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS , 1. Drilling well ~[]( Redr i 11 Workover operation [] 2. Name of operator 7. Permit No. Union Oil Company of California* 80-110 3. Address 8. APl Number Post Office Box 6247, Anchorage AK-99502 50-733-20183-01 4. Location of Well at surface Dolly Varden Platform, Leg B-l, Cond 5 675' FSL, 1208' FWL,.. Sec 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc. I 6. Lease Designation and Serial No. 106.2' KB ADL-17579 A-1222 9. Unit or Lease Name Trading Bay Unit .. 10. Well No. D- 16RD 11. Field and Pool For the Month of APR ! L ,19 81 McArthur River Field '12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks DEPTH AT END OF HONTH: 14,645'HD FOOTAGE DP, LD: 1137' Two fishing jobs: Lost rig power and stuck pipe--recovered OK.' Dropped dr]g stri ng--recovered OK. No directional drlg problems. 13. Casing or liner run and quantities of cement, results of pressure tests Ran 120 jts, 7", 29#, liner. Top of lnr @ 9689'; shoe @ 14,644' Cmtd w/ 1235 sx Class G cmt. Press tstd OK. 14. Coring resume and brief description 15. Logs run and depth where run Ran DIL/BHC-Sonic/GR; FDC/CNL logs from 9955'-"to'~..Zi;645' Ran CBL/VDL/CCL/GR from surface to 3000' and 9955' to 1.4,645' ,16. DST data, perforating data, shows of H2S, miscellaneous data Perfd Hemlock Bench 4: 14,052'-14,066'DIL w/ 8 HPF 14,015'-14,036'DIL w/ 8 HPF 13,985'-14,000'DIL w/ 8 HPF After stabilizing, 24-hr test: 1013 BFPD, 98% WC, 20 BOPD. MAY - 5 1981 Alaska Oil & Gas Cons. C0mmissi0~ Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ,~ ~'~, ("~~ ~ _ TITLE [~ist. [~']O. ~UDt. DATE 5/4/8i ~Re~ ~'hi[ ~-oorm i; required for each calendar month, regardless o'~'~-~:~t-at~s ~f -~l~eration-s, ~n~-~ust b; ~ ~n duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 *Harathon Oil Company - Sub,Operator Submit in duplicate STATE OF ALASKA ALASK.-~,,-OIL AND GAS CONSERVATION-~--<)MMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator Union 0il Company of California* 3. Address P. 0. Box 5247, Anchorage AK 99507 4. Location of Well Dolly Varden Platform, Leg B-l, Cond #5, 675'FSL, 1208'FWL, Sec 6-8N-13W-SM 5. Elevation in feet {indicate KB, DF, etc.) !06~?'KR 12. I6. Lease Designation and Serial No.. ADL-17579 A-1222 7. Permit No. 80-I 10 8. APl Number 50- 733-20183-01 9. Unit or Lease Name Trading Bay Unit 10. Well Number D- 16RD 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 Well [] ' Change Plans [] Repairs Made [] Other Repair Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for eacl~ 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 March 30, 1981, verbal approval to suspend drilling operations was given by Russ- Douglass to T. L. Swan. This action was to be taken if.an agreement was not reached settling the Inlandboatmen's Union strike which affected operations in the Cook Inlet. An agreement was reached; therefore, the request can be voided. * Marathon Oil Company - Sub-Operator RECEIYEO .APR 2 198! Alaska 0ii & Gas Cons. Comr~ission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my-knowledge. Signed e~'-(~-C~,-~J~U~D~-'/a'~(7 -- Tit,e Dist. Drlq. Supt. The space b for Commission use / Date 4/21/81 Conditions of Approval, if anv: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate . STATE OF ALASKA . ALASKA/," ;L AND GAS CONSERVATION O[ ~IMISSION ' MONTHLY REPORT UF DRILLING AND WORKOVER OPERATION 1. Drilling well r~ Redr i ] 1 Workover operation [] 2, Name of operator 7, Permit No. Union Oil Company of California* 80-110 3. Address 8. APl Number P. 0. Box 6247, Anchorage AK 99502 s0- 733-20183-01 4. Location of Well at surface Doily Yarden Platform, Leg B-I, Cond 5, 675'FSL, 1208'FWL, Sec 6-8N-13W-'SM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 106.2' KB ADL- 17579 A- 1222 9. Unit or Lease Name Tradin,q Bay Unit 10. Well No. D-16RD 11. Field and Pool McArthur River Field For the Month of, MARC H ,19 81 '12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 13,508'TD; Footage dr]d: 3548' Kicked off D-16RD at 9960'. Dr]d new hole to i3,508'. Stuck dr]g string in hole 03-30-81. As of 03-31-S1, T0F @ 12,558'. Working stuck pipe. 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 NA 16. DST data, perforating data, shows of H2S, miscellaneous data NA APR -- 9 1981 .Alaska Oil & Gas Con Anchora;~ Commission *Marathon 0il Company - Sub-Operator 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ---- ' 'NOTE':Re~ on this form is required for e~h~alendar month, regardless of the status of operations, and mus~ be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Submit in duplicate Form 10-404 R~.v 7.1-R{3 . ALASK JIL AND GAS CONSERVATION MISSION SUNDRY NOTICES AND REPORTS ON WELLS I 1. DRILLING WELL IiX COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ' Union Oil Company of California* ~O-~l 0 3. Address 8. APl Number P. O. Box 6247, Anchorage AK 99507 50-733-20183-01 4. Location of Well 9. Unit or Lease Name Tradin§ Bay Unit Do I I y Varden PI atform, Leg B-l, Cond #5, 10. Well Number 675'FSL, 1208'FWL, Sec 6-8N-13W-SM D-16 RD 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. McArthur R i ver Fie I d 106.2'KBI ADL-17579 A-1222 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 r-] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~1~ 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 ail pertinent details and give pertinent dates, inCluding estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is our intention to temporarily suspend all drilling operations, on this well. Due to the Inlandboatmen's Union strike and associated picket lines, Marathon Oil Company's operations in the Cook Inlet have been disrupted. If an agreement is not reached, our supply vessel will be unable to supply our operations, and it will be necessary to suspend drilling until the strike is settled and normal supply operations resume.. Suspension procedures as follows: , 1. Cease all drilling operations at a maximum depth of 12,700'MD. (The G-Zone will not be encountered unti I 12,812'MD.) 2. Set a 100' Class G cement plug in 9-5/8" casing from shoe up (9955'MD,)._ '- 3. Set a drillable bridge plug on top of cement. ' 4. Test plug to 2000 psi. 'MAR 2 0 ]98] 5. POH and c lose b I i nd rams. Alaska.O,i,I & Gas Cons. CommiSsio~ Anchorage .. Verbal approval was obtained from Russ Douglass to T. L. Swan on 03-20-81. * Marathon Oil Company - Sub-Operator · 14, I hereJ~ certify that the foregoing is true and corlect to the best of my knowledge. Signed/ ~' .- tle~ Dist.Dr]g. Supt.Date3/20/81 The ~l~ace, below ~or Commission use ns of Approval, ~f any: . ~'pprov~d Cop), Re~med Approved by t~"/-1~ ~//]~/] ]-' !' COMMISSIONER By Order Of .::~__ the Commission Date --' ' .' Rev. 7-1-80 Submit "Intentions" in Triplicate . and "Subsequent Reports" in Duplicate' ' -. STATE OF ALASKA . ALASK/~ ~LAND GAS CONSERVATION C(' '4MISSION /?/~ MONTHLY REPORT' DRILLING AND WOI KOVER OPERATIONS 1. Drilling well [] XX Redr i I ~ Workover operation [] Name of operator Union 0il Company of California* 7. Permit No. 80-110 3. Address 8. APl Number Post Office Box 6247, Anchorage AK 99507 50-733-20183-01 4. Location of Well at surface Dolly Varden Platform, Leg B-l, Cond 5, 675'FSL, 1208'FWL, Sec 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 106.2'KB ADL-17579 A-1222 9. Unit or Lease Name Trading Bay Unit 10. Well No. D- 16RD 11. Field and Pool McArthur River Field For the Month of. February ,1981 '12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 14,609'TD as of February 28, 1981~ Redrilling had not yet begun. Hilling window id 9-5/8" casing. 13. Casing or liner run and quantities of cement, results of pressur~. tests NA 14. ~ring resume and brief description 15. ~gs run and depth where run 16. ~[T data, perforating data, shows of H2S, miscellaneous data *Marathon Oil Company - Sub-Operator SIGNE r)-~ ~; ~_ _ r)Y,1 ~ _~lJn~' DATE ~/1~/R1 _~, ,, ! v _ _ v ,-- ~r~. .... ~ - --r - ' -, - -, - - NOT,~Z'Report on thins form is required for each c ,~.n. dar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil~nd Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. 10-404 Submit in duplicate 7.1.F~0 Thru: ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilton/~ chairman Lonnie C. Smith Commissioner · Ben LeNorman Petroleum Inspector March 2, 1981 B.O.P.E. Test on MARATHONS D-16RD Sec. 17, TSN, R13W, SM DO.!.ly VaNden_ Platform - Cook_. inl.et. _Wednesday..F_eb_ruary 25, !98!: I departed my home at 1:00 pm for a -_1':"30 pm ShOWup and 2:00 pm departure via A.A.I. twin otter for Kenai arriving at 2:30 pm. I rented a car and drove to Nikiski Heliport at 3:30 pm and arrived on Platform Dolly Varden at 3:50 pm. ..Thur.sday February 26,_ 19~8~: BOPE tests began at 1:15 am and were completed.' at 4:00 am. BOPE inspection report is attached. I departed the Dolly Varden via crew change Helicopter at 6:00 am arriving at Nikiski heliport at 6:10 am and back in Kenai at 6:30 am. I departed Kenai via A.A.I. twin otter at 6:45 am arriving in Anchorage at 7:15 am and at my home at 7:45 am. Friday February 27, 1981: Ray Olds, Marathon Drilling Foreman, '~v'kSed '~{he 'plUg-valve-in the choke manifold was repaired and tested to 3000 psig. In summary, I witnessed successful BOPE test on Marathon's D-16RD. STATE OF ALASKA'~ ~' ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Operator z~.~.~'~ '~--~.~ ~ Well D-/~ ~L Location: Sec / 7 T,~A/R/~ ~M ~ Drilling Contractor ~~-~-_ Rig # Date. /--~-/__w.. 2 ~/ Representative Permit # ~ d) /~~i%ing Set @ ,~.%-~'~' f.t. Representat ivy- Location, General Well Sign General Housekeeping Reserve pit Rig BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Results: Failures Test Pressure ACCUMULATOR SYSTEM Full Charge Pressure ~-'6D~ psig Pressure After Closure/~'~2) . psig 200 psig Above Precharge Attained: min ~Dse Full Charge Pressure Attained: ~ minc~ se N2 ~.~ ~_ ~~ ~ ~,.~.~. ~,~ ~ps ig Controls: Master ~/'~ Remote O/<~._Blinds switch cover~ Kelly and Floor Safety Valves Upper Kelly. Tes°t Pressure Lower Kelly. Bal 1 Type Ins ide BOP Choke Manifold No. Valves No. flanges Adjustable Chokes / Hydrauically operated choke. / Test Time ~ ~/~hrs.. days and Test Pressure Test Pressure West Pressure Test Pressure Repair or Replacement of failed equipment to be made within Inspector/Commission office notified. Remarks: 7~'~ ~.~,~.,:.~ ~..'~'.....~ ~ ' ~ ~'~ -.~'~ ~ "'~..'~ Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector ~/ October 1, 1980 A D M I N I S T R A T I V E A P P R O V A L NO. 80.36 Re: Application of Union Oil Company of California., operator of the Trading Bay Unit, to drill, complete and produce the Tradi_ rig_Bay Uni_~t D-16RD well as a part of the pressure main- tenance project approved by Conservation Order No. 80. Mr. Robert T. Anderson District Land Manager Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99502 Dear Mr. Anderson: The referenced application was received on October 2, 1980 and stated that the drilling, 'completion and production of the Trading Bay Unit D-16RD well will provide a crestal final with- drawal point in the Hemlock Pool. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling, completion and' production o~ the referenced well pursuant to Rule 5 of Conservation Order No. 80. Yours very truly, Harry W. Kug.le~ Commi s s loner BY THE ORDER OF THE CO~IMISSION October 1~ 1980 Mr. Robert T. Anderson District Land Manager Union Oil Company of California P. O. Box 6247 Anchorage., Alaska 99502 Trading Bay Unit D-16RD Union Oil Company of California Permit No. 80-110 Sur. Loc.': 6?5~FSL, 1208tFWL, Sec 6, TSN, RI3W, SM. .Bottomhole Loc.= 2150~FNL, 250~FWL, Sec 17, TSN,.R13W, .Dear Mr. Anderson= Enclosed is the approved application for. permit to drill the above referenced well. We1! samples, core chips and a mud'10g are not requirea. A directional survey is required. If available, a tape contain- ing the digitized log 'information sh.all be. submitted on all 1.ogs for copying except experimental, logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems, have been classified as important for the 'spaWning or migration of 'anadromous fish. Operations in .these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5., Alaska Administrative Code). Prior to commencing operations you may be. contacte~ by the ~abitat Coordinator~s office, .Department of Fish and Game. ,. Pollution of any'waters o.f the State is prohibited by AS 46, Chapter 3, Ar~icl.e 7 an~ the regulations promulgated thereunder ('Title 18, Alaska Administrative Code, Chapter 70} and by the. Federal Water PollutiOn Control Act, as amended. Prior to Mr. Robert T. Anderson Trading Bay Unit D-16RD -2- October 1, 1980 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us.in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this .office adequate 'advance notification so that we may have a 'witness present. Very truly yours,~' ~oy~e. ~. ~amilton Chairman of BY ORDER OF T;,iU. CO,~IlSS;QN . Alaska 0il & Gas Conservation Comm~sslOn Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl.. Department of Labor; Supervisor, Labor Law Compliance Division w/o encl. Robert T. Anderson District Land Manager September 30, 1980 Union Oil and Ct Divison:WesternRe~ Union Oil ComPany of California ~__ P.O. BOX 6247, Anchorage, Alaska 9950 Telephone: (907) 276-7600 ~ .... R~~ ~ 1 EN'-, .. -' ~ 3 7~.:'.~ .. · . .... ' -I a[O .... .... !'3 GEOL _L s _sf ..~ ..... FILF: ~ ~_.,- 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-16RD 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-16 location on the Dolly Varden Platform by Marathon Oil Company, suboperator~ Very truly yours, '..~ '\ '"~ x, ) '"x,,_:..... i..~ ..... , .... %... ' '>~ "~"~ %~%" '~' Richard J. Boyle Landman Anchorage" 'ision Production' ,.,perations, U.S. & Canada Marathon Oil Company P.O. Box 2380 Anchorage, Alaska 99510 Telephone 907/274-1511 September 30, 1980 Mr. Russ Douglass State of Alaska Oil and. Gas Conservation Commission 3001 Porcupine Drive Anchorage AK 99501 WELL TBU D-16RD PERMIT TO DRILL , As requested, the following information 'is submitted for inclusion to the Permit to Drill application for D-16RD. An Amerada bottom hole pressure survey run on March 19, 1980, indicated 4557 psi at 9450'TVD or 9.3%/gal. This represents a pressure gradient of .4822 pounds per foot. When compared to a salt water .gradient, a maximum surface pressure'of approximately 300 psi is indicated. CAD:i CURTIS A. DOWDEN Operations Superintendent Union Oil and Gas D~i.-';son: Western Region Union Oil Company o, California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unlen Robert T. Anderson District Land Manager September 26, 1980 Mr. Hoyle Hamilton State of Alaska Oil & Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of Alaska ' Permit to Drill or Deepen TBUS D-16 Rd., Dolly' Varden Platform, McArthur River Field. State Lease No. ADL-17579 Dear Mr. Hamilton: Enclomed for your further handling are three (3) copies of the above captioned Permit to Drill. Also enclosed is our check #19053 in the amount of $100.00 to cover the filing fees. Very truly yours, C.,~. "'"' ':....-'~,.~t" "" ...... -~ '~'''' ............. ~..(~'} '-~.,~ ~"." ~;~:~." -~' ... Richard J. Boyle Landman sk Enclosures (4) Por~ I0'-- 401 . 1~. I-I--71 STATE OF ALASKA .. SUI~MIT IN TRIP~ (Other ms,ructions o,. reverse, side1 OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN 1tr. ?YPB Or WORK RE DRILL [~ DEEPEN [-1 b. TYPZ Or WBLL O,L I~x o,. !-I .,.,,eL. ~ "'"'"'""" F'] WELL WELL OTHBI ZONU ZONE 2 NAME OF OPERATOR Union Oil Company of California* 3] ADDRESS OF OPERATOI~ P. 0, Box 6247, Anchorage AK 99502 4. LOCATION OF WELL At surface Del ly Varden Platform 675'FSL, 1208'FWL, Sec. 6, T8N, R13W, SM, Leg B-l, Cond 5 At proposed prod. zone 2150'FNL, 250'.FWL, Sec. 17-8N-1;3W-$M 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE' Approximately 21 mi les NW of Kenai,. Alask.a ]4. BOND INFORMATION: ' TYPE Statewidesuretyand/orNo, United Pacific Insurance Co. B-55502 API ~50-733-20183-01 S. 15. DISTANCE FROM PROPOSED' LOCATION TO NEAREST PROPERTY OR LEASE LINE, lI~''. 250' (Also to nearest drig, unit, if any) 18. DISTANCE FROM PROPOSED "LOCATION, TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 200' north of D-16 21. ELEVATIONS (Show whether DF, RT, C.R, etc.; . i 18. NO. OF ACRES IN LEASE 3085 iN. PROPOSED 14,609 'MD 10~250'TVD 6. LEASE DW~IGNATION A.ND SE~q/AL NO. ADL-17579 A-1222 ?. IF h~DIAN. ,,a~-r.-~.~,.~ OR ~E NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit ~. wELL NO. D- 16RD 10. FIELD AND POOL, OR WILDCAT McArthur River Field SEC.. T., R.. M.. CBO'FTO.VI HOLE OBJECTIVE) Sec. 17, T8N, R13W, SM ,-~o,mt $100. 000 17. NO: ACREs ASSIGNED TO THiS WELL. 80 20, ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK. WILL START* KB 106.2' above MSI October 1, 1'980 23. PROPO-~ED CASING AND C~-W[ENTII~G PROGRAM .., SIZE OF HOLE SIZE OF CASING ..WEIGHT PER FOo~ .GRAIYE SETTING DEPTH quantity of cement R-l~2" 7" ?g//, N-RO 14;609'MD Approx 850 Sx ,, , , , · . , , ,. · , , SEE ATTACHED SHEET ........ ~,.,. !? .~ ~..:: '..!-. ,, ,;, ,'.',, ..~..~ ..,,.~ "".., ,.;.,. . .~' ..,:'% ..::;. .......... C'/,; ,..'~ ~',.. ,,.:.=,.: ('.'q,;.~ i',,~F' ., *Narathon 0il Company - Sub-Operator ..... ~ ABO~ S~A~ D~B~ ~OS~ ~R~: Zt ~I Is to aee~n 'jive ~ on ~w p~du~ive ~ne. J~_~.~.~l ~ ~.atuL mt ~n u~o~n~, jive p~nt, ~' on's~bsu~a~ ~m ~d .me~ ~d ~ue .,, (This space for State office use) SAMPLES AND CORE CHIPS R,F.~U~ J M,U~) LO'O ~ R.E~UIREMENTS: ' DIRECTIONAL SURVEY RE~ t.TM C) NO PE,,,~ N )70- lie . ,,.,',,,,ov,,.,., oAtE aP~aOV~~m. Cha±rmrl, BY ORDER ' SSION *See Inmwtion, Oa Revere Side fL-~c~r 1, 1980 _ DATE CONDITIONS OF APPROVAL, IF ANY: A.P.L .N!~,~tlCAL CODE 3"'0- 753- Z°J~'°l zo/z/8o . TBU WELL D-16RD Ob] ect i ve: Plug the existing wellbore, sidetrack at 9988' MD in 9-5/8" casing, and drill 4621' of 8-1/2" hole to a new location with the Hemlock top approximately 2150' FNL, 250' FWL, Sec 17, T8N, R13W, SM. Run and cement 7" liner with gas lift equipment and complete as a Hemlock producer. Procedure: 1. Skid Rig #76 over Well D-16, conductor ~5, Leg B-1. 2. RU Otis. Pull BV @ 330'. 3. Bleed csg & tbg to 0 psi. Bullhead well dwn tbg w/ FIW. Fill ann w/ FIW. Open circ slv@ 13,565'. Circ well w/ FIW. Chg over to drlg mud. 4. Install BPV. ND tree. NU & test 13-5/8" 5000# BOPE. BOPE will be tstd weekly & reported. 5. PU tbg. Pull Otis RH pkr loose w/ 40,000~. POH LD tbg. 6. RIH w/ OEDP to plug back across existing perfs w/ CIG cmt from 14,050' - 13, 500' (approx 100 sx). Perfs from 13,708' - 14,110'. Fill @ 14,050'. 7. Set perm BP in 9-5/8" csg @ 10,070'. 8. Run CBL/GR across KO area from 9800' - 10,050'. If necessary, RIH w/ WL & perf 2' w/ 2 HPF (10,000' - 10,002'). Set cmt rtnr & sqz these perfs. Drill out rtnr & CO to 10,070'. 9. Mill section in 9-5/8" csg (approx 9980'-10,030'). 10. Lay KO plug (10,070'-9850', approx 100 sx). WOC 24 hrs. 11. CO to 9985'. Run DD assy w/ diamond bit & KO. 12. Drill 8-1/2" directional hole to TD (approx 14,609'MD; 10,250'TVD) according to directional pffogram. 13. Run 7", 29~, 8RD & Butt Inr fro~ TD to 9750'. Cmt w/ approx 850 sx CIG. 14. RIH w/ tbg ~tring w/.GL eqpmt & complete as Hemlock producer. There are no wel Ibores within 200 feet of the proposed well other tha~.~ ~h~. ~ .... ~.-~ exi'sting D-16. ' i'~i] ~i~'.i' ~:i',,,. !!]]' ~' ~i./ ~ !i .. - MARATHCt', q OZL GO.- · -- DOLLY VARDE PLATFORM U Mu4 Driilin9 Hippie.. Rc~ Fi do-r'.. jo ~G-P_.6 G ? / 0.~;~ .,,o'. o-~o D'i! /"'oD? · ~ L.'~..,["~ ~ D'29 ,~15rd D-lO D'2A e0-25 D-14 -i- t FC IA - 12. rd~ G-12 ~ r, o 35 I 1 PAN AM R. ST. LEGEND -L '- l[~ COMP. PROD. B-I INJ.-B-I' .~ ABAND. PR6~. B' r · 15 ABAND. INJ. B-I t O BENCH-i WELL PTS. ..! O 2OOO' 4000' 6OOO' - ' ' i i ,, · i . m i · I FEET I ii i ii i ii i MARATHON OIL COMPANY 8000' · m ] ANCHORAGE DIVISION ScoJe' I" · 2000' Dote' FEB. 1979 TRADING BAY UNIT'. MCARTHUR RIVER .FIELD TOP HE MLOCK BENCti - I CONTOUR INTERVAL -- IO0 FT. · Aufhor: D. ATCHISO~// L.N..._ . File no: i m i I ,.' · . ; ' ,. .... , ,.: , . ..., .... ,...,.' . - .. , , . . , . - ,, .. , . .. , . .-.., . .-:, ....... ""'"'' """' ':"""'BESSE'EPPS~POTT~- ~"' ' ' ' ' ' -:' ! i" ', :" ' ; ...... 'FOR " , . ....... '-; ............ · .... ' ' .: I.' ' : - ' "' ~ ; ; : '" ' ' l..; ...... · .. :.:.~.-:.,.. ....... ...! ......... ._,.. :. ... . ~_: :-. \- .; :- .... . ..., ..... .;. ...... · _: :..'... ..:..... '_'.-....... ;. '_, ~ .... .~ . · -... ....~..-:-.:'".' . ....... ~ · . , :.-":":- : ' · · I ..... ~ ' ' i' ' · ; · 'l · · . . - . , . . \- I , , - . ; · . .-. · :' :' ; ''i '';": .... ITM ' ' · " ,' .... · ,"- :"'."-- ' ~"~ ..... ." : : '' : : : '"; ' · ~'"' ..... : .... ! : · : .... , '" '"' ' : ' I ' : ...'--. . .... ..---;- . . f .-:-.'-:- :.-:.-':.'- -::4-, , ~ .... ~ ' " J ' ' ..... J.. : ..' .' .: .... : . - .. . . : ..... :. _; - · . TVD'= 7129' - · ..... i . ' · ' - ' ' I ' ' ; ' " - t ; ~ · DEP= '0 ' ' ' . ;' :'' : ': . : ' - · . '' '- · : - ' . ' ::' · TMOIO~O00 -: x~' . . , ;'. ..... . . - , - -: -- _ '- -.. .---.- · :..---.. ·· . .; , , ] : · ..: :...,. !.,., ..: ;.-.~ , :---.. : .-'- - :.~ . . :_. :..: ~ :. ...... '. , . : · : · ' · ' '' '' i-: ' '%: '" i'!," ;. '". ..... ': - '-:- --"'. :- .-'..-'. . ~ - . : ;' ; , :. iL . .~.:-~-"-!.": ' -:-:--;-' .-J '- . ''' :..-:-- -: ', '-: .-'_' - . ;.-.-: :.. : : , -. .. ' . ' . '"- : x. : --: - · -: ' · : · , · · = · . . TARGET .. . ; ' .... ~ .~ ' . "": :' ' : '~; \' ! ·" ~ : ' : ' ', : ·. i . · '_ DEP.-.2645--,-~ ~ ' -.).:..'. . i.. : ..:... : . ' .. .... ~.. ,,, I .~'. ' · · , : · '--: .'-.=--'. · . ,.;-'.'-" · ~ . ' . ' ' ' · : .' ' . "' . ' ' 250'- Item (1) Fee CHECK LIST FOR ~ WELL PERMITS Company : ~.' Approve Date Yes No ~/'~,. 9-%~ ~7 1. Is the permit fee attached ................. . ~ -- 2. Is ~11 to he located in a def&ned pool ............................. ! 3. Is a registered survey pla~ a~¢hed ................................ '~/ ~,- (2) Loc )-Lg-~o, 4. Is well located proper distance frcm property line ................. 5. Is ~11 located proper distance frcm other w~lls ................... 6. Is sufficient undedicated acreage available in this pool ............ _ 7 Is ~11 to ke deviated ..................................... 8. Is operator the only affected party ................................. / 9. Can permit be approved before ten-day wait .......................... (~ 10. Does operator have a bond in force ................................. 11. Is a conservation order needed ...................................... (4) Cas9. ~ ,9-%9- ~0~ %, 12. Is administrative approval needed ............... 13. Is conductor string provided ........................................ 14. Is enough cement used to circulate on conductor and surface ......... 15. Will c~ment tie in surface and intermediate or production strings 16. Will cement cover all known productive horizons ..................... 17. Will surface casing protect fresh water zones ....................... Remarks 18. Will all casing give adequate safety in collapse, tension and burst. (5)BOPE ~ ,~-.2~--$~<, 19. Does BOPE have sufficient pressure rating - Test to .~oo0 psig .. Approval ~c~ded: · . · . ~ ~, - . ~ ~, o . ~ ~ ~ Additional Requirements: . ~.'~,~.~ ~9"",¥ './¢ ~"I/~'~'~ ~ ~ ~'<. ~' ~ ~ -/~ ]~ ~..,. ,~.~.:~?~ ~ ,..',~'" ,. ,~.'~.~..... ~.'J l~-& Geology: Engin .~_. ring: JAL,~. rev: 03/05/80 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 simpl, ify finding information, informati;3n of this'. nature is accumulated at the end .of the file under APPENDIX... No special effort has been made to chronologically , organize this category of information. . um~Stum~.suo~ s'~''~'~0~'~'~ LIS TA~E '""' .. .. LVF OOS.H02 VER];~iCAT1UN L. IST1NG PAGE ~ RkE6 ~EaDEB SERVICE NAME :SERV1C DATE :81104121 ORIGIN : ~EEL NAS~ :REEL ID CONTINUATION # :£! PREVIOUS COMMENTS :REEL COMMENTS *~ IAPE HEADER ~ SERVICE NAME :SERVIC DATE :81104/21 TAPE NAME : CONTINU~TIUN # :0~ PREVIOUS TAB~ : COMMENT6 :T%PE 2D~MENTS ##' FILE HEADEB ~ FILE NAME :SERVIC.O~I SER'V I ~E N AM ~.J' : VERSIUN # : DATE : MAXIMUM LENGTH : ]024 FILE TYPE : PREVIOUS F~ID~ : ** INFORM'ATION RECORD5' ** CN ~: W'N :' FN. : RANG.: ~'O~N: SEC'~: COUN: STAT: CTR'¥:. MNEM CONTENTS ~ARATHON .OiL DI6. RD.'" ~CAR~UR RI'VE.R 13~ .. 8N KENAI ALASKA USA CONTENTS · PRES: DIbFDNF .. *~ RB{ORD TYPE 047 *~ ~ RECORD 'TYPE 047 ~ . . · . U'NIT TY'PE.'"CATE :SIZE '.CODE Ooo o'o0 ,,"0'0.0 '.'000 000 000 '.000 ".0.00 000 000 0'.00' 0'00 000 000 0.00 "000 000 000 , , 0.15 065 ',0'0.5':.'.06.5 ,015 065 003 0.6.5 002 065 0'01. 065. 005 065 .'010 '0'65 0.05 065 UNIT TYPE CATE 'SIZ2' CODE ... ... 0'0'0 '.000 007 065' LVP' 009.H02 YERI~ICA310{w LI$11NG PAGE 2 *~ RECDRD TYPE 047 ~* CSG 9.b25" @ 9953' / BIT B.5" / DENS 9.5 / VISC 43 / PH 10.6 R~ 2.13 @ 72 DF RH .88 / ~MF 2.21 @ 68 DF GH .~6 R~C ~.9~ ~ 68 DF MM .75 BHT ']7,4 DF RUN NU.ONE RON DaTE 4-~2-E~ .~ DATA ~"OR~A~ RECORD ** ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 4 1 66 1 8 4 73 bO 9 4 65 .lin 0 1 66 0 DATUM SPECIFICATI,ON BLOCBS MNEM SERVICE SERVICE UNi~ APl API AP1 AP1 PILE SIZE PROCESS SAMPLE REP~ ID DEPT SP SFLU ISN .ILD ISN ILS ISN GR RMOB, ISN NPHI GR CALl DRHO NR~T NCNL ISN FCNL ISN DEPT IbM GR NCNb DEPT GR NCNL ORDER LOG TYPE CLASS MOD NO. 0 0 0 0 0 0 0 0 0 46 0 0 0 0 0 32. 0 0 1 0 0 2 0 0 32 0 "0 3 0 0 0.' 0 '0 ! 0 0 92 0 0 Ic. 3 0 0 4 4 4 4' 4. 4 4 4 '4 4 4 , . .. LEVEL 0 0 0 0 0 0 0' ' 0 0 0 0 0 0 0 CODE 1 68 1 68 1 68 I 68 1' 68 1 68 1 68' 1 68 1 $8 1 68 1 $8 1 68 1 6'8' 1 68 14651.000 6.250 GR -999.250 ,CALl -999.250 .FCNL. .1 6(o.oo'o "6.25'0 G.R' ~5.9.625 CALk le 2.o.o,o, CN.L . . . . '21,0.00 SFbU 4.7.719 RHOB -999.250' :[R~O -999.250. .24 o'oo SFbU '.4'7:'7'1.9' BH'OB' 9.8S'5 ~CB~O 3'84.'750 '5.426 ...I~E -999.250 NPHI -9S9,250.. N.R~T.. 6.6.37 -999.250 -999.250. 6,~37 .59'.668... 4.496 LYP 009.~02 VERIF1CATIOI~ DEPT 14500.000 SP IbM 11.883 GR GR 83.063 CALl NCNL 3268.000 FCNL DEPT SP IbM GR GR CALl NCNb FCNL D~PT SP IbM GR GP CALl NCNL FCNL DEPT SP ILM GR GR CALl NCNb FCNL DEPT IbM GR CALl NCNb FCNL DEPT SP ILM GR GR: CALl NCNb FCN'L DEPT IbN GR GR CALl' NCNb FCNL DEPT ILM' GR NCNb DEPT, NCNb DEPT GR NCNb DEPT GR NCNb 1440 1 10 367 1430 1 8 1420 ,1 6 ~zJ 3z. 1~10 6 435 1~00 1 10 254 1390 6 298 5 458 137'0 3. 10 28.0 1360 2 4 ~74 1350 241 0.300 1,.945 1.875 4.0C0 0.000 2.320 8.000 4.000 0.000 9,3c. 1 5.688 8.000 0.000 5.4z, 5 0.781 2.060 0.000 5,820 4.375 8.060 0,000 9.695 1.406 4,OO0 O,OO0 3.7,~ 0 2.813 O..OC 0...' 0.. 00'0' 6.938 2,938 2.000 . 0,000 7.922 6.188 0..000 0'. 00'0 9.61.7 9,563 6.000 ,. SP GR: CALl $.p GR. CA.LI .FCNL Se. GR CALl, FCNL GR CALiI FCNL LISTING -47.500 53.815 10,573 1195.0C0 -30.000 68.750 10.047 1480.000 -23.000 67.355 10.242 1409.060 -35,500 ,52.656 12.813 2668.0C0 -168.000 ,49,219 9,273 2288,000 -133.500 68.625 9.758 1163.000 '-'99.500 51.2~1 .12.398 1135,060 -99.500 ~42..625' I 0.094 25 6,0.0'0· .-72,00.0 8~ 0~3 1.500 '. -169. 3.8..~5'0 ' 25' 1~.906 ..3042'.0C, 0 -'124.'250. 102.5~3 1'4,'688 6.89.5C0 SFLU RHOB D~BO SFLU RBOB DRHO SFLU RHOB DPHO SFLU RHOB DRhO $FLU RHOB SFLU RHOB DRHO SFLU'. BHOB D~HO sFLu I~HOB DRHO RHOB D R H '3..' . , . · . . .SFLU .RHO'B DRBO .. RHOB DRHO' 15.023 2.3~, B 3.058 {0.250 2.488 0.021 10.820 2.5:33 3.042 23.266 2.520 0.049 24,156 2.434 0.005 12,906 2.447. 0,020 1,0.28.9 2,516 3,02.3 '2,'6 $ 9 -0,000 ,, 16.125 2.436 0',0'38 3, i65 ,. 12.398 2,552 '3,1'55' ILP, NRA~I ILD NPhI NRAI 1LD NBkI NRA~ ILD NPHI ILD NPHI NRA~ ILD NBhI' NRA~ ILD NRF, I NRAT ILD NPB'.I NRAT I'LD NRE ! ..NRA T . N.R'~: I NI~A'I I'LD NRM I 'NRAT PAGE 13.125 25.146 2.585 13.336 23.145 2.410 13.234 20.459 2.246 20.484 9.033 1.578 16.594 1,5,479 1.834 17.734 18.652 2.086 9.992 22.998 2.496 32,625 '12.012. 1.670 .. 29,109 30,0~9 · 2..8 g 62',144 .7.. 22. !.445 ':'1'0.'750' .28.076 ..2,.'895 LYP 009.M02 VER1FICATICi~ blSTING DEFT 13400.000 ILN 13.430 GR 8 GR 106.0e3 CALl 1 NCNb i739.000 FCNL 44 i)EPT 13300.000 SP IbM 13.109 GR GR 96.312 CALl NCNL 3128.000 FCNL DEPT 13200.000 SP IbM 12.641 GR GR 67.875 CALl NCNb 3900.000 FCNL DEPT L~I(O.O00 SP ILM 11.773 GR GR 60.656 ·CALf NCNb 3896.000 FCNL DEPT 13000,0(0 IbM 9.148 GR 95.438 NCNb 3192.000 DEPT 12900.000 IbM 11,813 GR 52.094 NCNL 4472.000 DEPT 1.28C0.0(0 ibN 15.047 GR' ~7.875 NCNb 5344.000 DEPT 1~7(0,000 IbM 10,047 GR 123,438 NCNb 2302..000 DEPT "i2600.000 IbM 10.430 GR 112.563 NCNb 2064.000 DEPT I~SC0,00'0 IbM 6.348 GR 68.000 NCNb 3854.000. DEPT 124¢0.0(0 ILW{ 9.133 GR, 79,688 NCNb 2822.000 SP GR CALI FCNL SP GR CALl FCNL SP GR CALIi .FCNL SP 'GR CALl 'FCNL 'SP GR ,CALl FCNL Sp GR CALI FCNL SP GR CALI FCNL -8 8 1 129 -16 b 4 184 -,9 7 1 122 ,.'13 4 362 4 286 10 1 63 -12 10 ! 46 5 168 6 '1 1,01 8.250 0.125 1.820 4.750 5,250 2.50O 1.8~1 6.000 2.0O0 1.531 9.234 4.000 7.000 9.344 9.234 4.000 1.500 1.625 1.000 2.000 8.000 2,0'31 9.555 4,000 0.5OO 4,938 9.72.7 0,00,0 4.938 4.31~ 1.711 4~.500 8,25'0 6.500 3.2.19 1.250 i,".750 1.469 9.8.59 1.000 4,.375 5,625 3.836 2.500 t2FLU DRHO SFLU RHOB SFLU I~HOB :£REO SFLU RHOB £BhO SFLU RHOB DRHO S~LU RHOB E I~1-{ CJ SFLU RBOB DR. HO SFLD RROB' DRHO SFLU' RHOB SFLU RHOB, SFLU RHOB DRHO 39.969 2.287 0.039 13,953 2.525 0.051 13.492 2.367 0.033 14.0~3 2.350 0.017 11.453 2.395 0.015 63,719 2,543 0..034 .38.594 2 5!2 0:0,2 8.969 · ' 2.4.28 0,021 9..'375 2.262 0 ..058 9.~11 2 381 0:0'42 7.312 2.453 0,.018 ILD NPHI NRA~ ,1BI NPHI NR~T 'I~[ NPHI NR~T ILD NPHI ILD NPHI NRAT ',III[ NPHI NB.~ 'I' ILD NPHI NRA'T'. ,, ILD :'NPHI NR~T .. ILD NPHI NB~.T , , 'ILD N.PHI NR~T .. 'ILD NPHI NRAT PAGE 26.063 49.268 4.031 15.688 19.482 2.248 14.992 20.410 2.162 11..7(3 18.848 2.057 9.570 24.268 2.547 8.969 5.273 1.178 .12.820' 14.111 ~".7~0 9 531 '39~941 3.510 ~13.2~4' 48.291 4.'0'12 5.387 .19.'775 2.168 9.602' 24.316 2.625 LVP DEPT 1bM hC NL DRPT G~ NCNb DEPT ibm NCNL DEPT GB NCNL DEPT IbM GR NCNL DEPT IbM GR NCNb DEPT GR NCNb DEPT IbM NCNL DEPT ,ILN NCNb DEP~! IbM' GR NCNb DEPT GS ~CNb 009.H02 VERIFICATIOi~ LISTING 12300.000 16.281 115.625 1658.000 12200.000 .i3.358 58.188 4788.000 12{O0.DO0 ,12.0( 8 97.750 2572.0C0 12000.000 40.344 67.563 1536,000 1i900.000 :39,4(6 54.656 1473,0(0 11800.0O0 20.234 43.156 3906,000 11700..000 9,9(1 61.563 4132,0¢0 11600.000 28,328 107.312 .2278.000 l1500..DO.O ~1~.016 1.10.500 30.52.0¢ 0 .. 11400'000 4'. 344'. 75.375 .1941.0C'0 11300.000 10 711 15oo' 3990.000 SP G~ CALl FCNL SP GR CALl FCNL SP GR CALl FCNL SP CALl FCNL SP GR CALl FCNL SP GR CALl FCNL SP CALl FCNL SP . GR. CALl .' F.CNL.. GR ' 'CALl . FC.NL .. SP. CALl 'FC N'L ' GR. CALl ' .FCNL -50.253 SI~LU 99. I'~R RHOB 13.D09 322.0CO -186.250 SFLU {49.781. RHOB 9.219 2420.0(0 -79,75O SFLU :73.438 RHOB 12.047 DBHO 972,500 -129.250 SFLU 61.125 RHOB 13.759 DRHO 331,. OCO -124.750 SFLU ;44.188 RHOB 17.281 DRHO 256.250. -138.000 SFLU 36.0S4 · RHOB 9,938 DRHO 1989.0(0 -180,250' 'SFLU ;48,281 RHOB 9.211. DRHO 1792.000 -140 5'00 SFLLI 97."5e3 RHOB 15,781 DRHO 44.4. ]50. -7'2.438 SFLU 91.438 RHOB '13'883 DR. HO .1092.00o .. . . -8 ~ 2.5'0 SFLU sl.:. 938." B 12.930 DRHO 550.0'00 " .-.10'3 ~ 75'0.. 'SFLU 45,3~5 RIt. OB ".9,21'.1'. D'RB :D,- ,1. 7.37.00.0. 21.750 :).072 30.031 2.439 3.030 18.375 2,678 -0,023 84.563 1.818 3.007 256.250 1.438 -0.043 '~ ', 234 22,2! 1 .9,039 14.344 2.373 0.012. 4~',063 '2.514' -~.O01 9.398' 2 576 ... ... 6.996 .2.,.'375' 0,089 .. 12. 992" 2.379 0,027' 1LD NRF. 1 NRA~ ILD NPHI ILD NPHI NRA]. ILD NRSI NRAI ILD NPH/ NRAT ILD NRAT ILD NPH1 NRAT ILO · NB5 I NRA~ ILD. NPHI N'RAT NP'H I NRAT , , NP, I~ I N RA.T PAGE 20.031 59.277 ~.617 20.672 15.479 1.833 14.781 23.926 2.551 17,359 55.225 4.410 47.063 64.4C4 5.016 35.719 14.893 1.852 8.742 20.068 2.137 28.844 51.123 4.238 12.523 25,049 .2..674 ,. ., , .3.~:477 · 71'7 3.252 9.547 21.094 2.203 bVP DEPT GR NCNb DEPT ibm GR NCNb OEPT IbM GR NCNb DEPT GR NCNb OEPT NCNb DEPT ibm OR NCNb DEPT IbM GR NCNb OEPT GR NCNb OEPT IbM GR NCNb DEPT IbM GR NCNb DEFT IbM GR NCNb 009.h02 VERIFICATION LiSTING 11200.0£0 SP 10.977 GR 1¢0.250 CALl 2812.000 FCNL 11100.000 &P 11.930 GR 54.531 CALl 4014.000 FCNL 110C0.0(0 SP 19.563 GR 55.781 CALl 5108.000 FCNL 10900.000 5.020 GR 73.938 CALl 2162.000 FCNL 1¢8(0.000 SP 11.367 GR 65.188 .CALl 4188.000 FCNL 10700.0(0 9.422 GR 70.6~5 CALl 3876.000 FCNL 10600,000 9,266 72.750 3920.000 10500.000 7,422 69 250 2608:00o 104.'00'.~ 0¢:0 7.582 ~ 1.~ 0 2192,000 103C0.0C0 12,031 120.5£0 2748.000 i0200,'000 8.016 4.000 SP GR. '..CALl FCNL SP GR CALl f'CNL SP GR .CALl .' f'CNL . SP GR. CALl FCNL GR CAbl FCNL -110.250 81.563 9.672 1066.000 -130.750 46.563 9.125 1689.000 -140.500 50.625 9.406 2792.000 -88.250 59.969 12.1'E8 583.500 -12~.250 46.094 9.344 1801.000 -lC7.500 58.125 9.141 1489.000 -135.250 67.438 9,672 1556.000 -6~.188 58.'..155' 13.766 .759.,.5.0.0' ~7'7'.250 102.750, 56 500 -89 500 loo:. 75. .17 ~91 833.[' '00. -55,375 96.750 ',14..883 826.500 SFLU RHOB DRHO SFLL, RHOB '1' RF.O SFLU DRBO SFLU RHOB SFLU RHOB SFLU RHOB DRHO SFLU HOB SFLU RHOB · . · . .. ..S.FL.U RHOB D.RH'O RHOB DRHO. FLU RHOB DRHO 11.563 2.424 0.035 {3.086 2.342 0.013 24.15b 2.439 0.005 4.789 2.309 0.066 15.9C6 2.406 0.017 {0.555 2.355' 0.016 10.695 2.334 0.020 6,0.{2 .... 2,477 '0.004 6.07,0 053 ., 9.070 '2..578 0.024 5 ..984 ' 2.438 -0.003 ILD NFHI NRA.% In[ NPHI NR~% 1LD NPHI NRA~ :lB[ NPHI ILD NPHI ILD .NP.H I NRAT NPH1 N.R~ T ILD NPHI NR~T ILD. NPHI N'RA~'.. ILD N. PH'.I. NRA2 I, LD' NPH1 NRAT. PAGE 11.492 25.391 2.529 11.289 21.045 2.193 17.563 13.770 1.733 5.762 40.527 3.555 10.188 20.703 2.188 8.094 2'4.561 2.430 8.3'91 21.826 '.'2'.291 3.1.34.8 3.090 8.'211 38.770 3.537 13.594. 31.641. 3.205 8.383 26.855 2.822 LVP 009.H02 YERIF'ICAI1ON LISTING DEPT 1OlO0.000 8P IbM i2.312 GR GR 61.563 CALl NCNb 4~20.000 FCNL DEPT 10200.300 SP lbM 5.331 GR GR 109.063 CALl NCNb 2692.0C0 FCNL DEPT 9900.000 8P IbM 2000.000 GR G~ 63.719 CALl NCNb 1494.000 FCNL DEPT 9843.300 SP IbM I999,250 GR GR I999.~50 CALl NCNb 1379.0(0 FCNL -48.438 SFLU 55.031 RHOB 12.81.~ DRHO 2700,0£0 -29.438 96.813 RHOB 16.563 DRHO 804.000 -93.250 SFLU 49.906 RhOB 9.406 DRHO 358.5(0 -999.250 SFLU -999.250 RHOB 9.39~ DRBO 287.750 ,~. Elbe TRAILER ['ILE NAME :SERViC.O01 VERSION # : DATE :' MAXIMUM LENGT~ NEXT FIb£ NAME 1024 : ~.~#~.#.~ EOF. #~~~. .~ TAPE TRA1LER ~* SERVI.~E N~M~' ..~ :SERV.IC DA~E :81/04/21 TAP'g NAME' : CONTINUA.TI~N # :01 NEXT TAP. E N~ME.,.: ...'" COMMENTS :TAPE ~EMMENTS "~,~ RE~L TRAILER ~'~" . SERV 1C'~ NA~,E .::~,ERV lC .. DATE' :81/04/21 .. ORIGIN : REEL NAME ' :REEL ID .' CONTINUATION # .:'(1 ... . .. NEXT REEL NAME ':'.' "" COMMENTS ~R~L. ~[MMENT8 .. .,. .. 52.031 2.b29 3.099 4.051 2.463 -0.002 2000.000 2.059 -3.520 -999.250 1.959 -0.610 ILD Ng~I NRAT ILD NPHI NRA~ ILD NRSI NRAI ILD NPHI PAGE 15.227 8.496 1.543 5.730 31..250 3.158 5.852 48.633 3.B61 -999.250 59.570 4.469
