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Home My WebLink About192-155Nolan 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: 08/07/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250807 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 23 50133206350000 214093 6/26/2025 AK E-LINE PPROF T40741 BCU 25 50133206440000 214132 7/16/2025 AK E-LINE Plug/Cement T40742 BRU 211-35 50283201890000 223050 6/11/2025 AK E-LINE Perf T40743 BRU 211-35 50283201890000 223050 6/20/2025 AK E-LINE PPROF T40743 BRU 213-26 50283201920000 223069 7/7/2025 AK E-LINE Perf T40744 BRU 213-26T 50283202040000 225038 7/2/2025 AK E-LINE Perf T40745 BRU 213-26T 50283202040000 225038 7/4/2025 AK E-LINE Perf T40745 BRU 213-26T 50283202040000 225038 6/28/2025 AK E-LINE Perf T40745 BRU 241-23 50283201910000 223061 7/18/2025 AK E-LINE Perf T40746 GP 11-13RD 50733200260100 191133 6/2/2025 AK E-LINE PPFROF T40747 KBU 32-06 50133206580000 216137 7/1/2025 AK E-LINE PPROF T40748 MPU E-28 50029232590000 202055 5/8/2025 AK E-LINE Caliper T40749 MPU F-21 50029226940000 196135 7/10/2025 AK E-LINE Caliper T40750 MPU G-02 50029219260000 189028 7/6/2025 AK E-LINE Puncher T40751 MPU I-01 50029220650000 190090 7/7/2025 AK E-LINE TubingPunch T40752 NS-19 50029231220000 202207 6/27/2025 AK E-LINE Perf T40753 PBU J-07C 50029202410300 225026 5/29/2025 BAKER MRPM T40754 PBU N-07B 50029201370200 223122 6/7/2025 BAKER MRPM T40755 PCU-05 50283202030000 225037 7/10/2024 AK E-LINE Perf T40756 TBU D-07RD2 50733201170200 192155 7/19/2025 AK E-LINE Perf T40757 TBU M-09 50733204760000 196127 7/18/2025 AK E-LINE Perf T40758 Please include current contact information if different from above. T40757TBU D-07RD2 50733201170200 192155 7/19/2025 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.08 11:16:55 -08'00' 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 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: Hemlock Oil 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 12,438 11,958 Casing Collapse Conductor Surface 2,670psi Intermediate Production 3,090psi Liner 5,410psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Casey Morse Contact Email:Casey.Morse@hilcorp.com Contact Phone:(907) 777-8322 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Trading Bay Unit D-07RD2 McArthur River 9,306 12,438 9,306 2,279psi N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017594 / ADL0018729 192-155 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20117-02-00 Hilcorp Alaska, LLC CO 228A Length Size Proposed Pools: 398' 304' N-80 TVD Burst 11,407 MD 5,750psi 6,380psi1,069' 7,375' 2,869' 7" 1,401' 398' 33" 13-3/8"1,401' See schematic See schematic 9-5/8"9,665' Perforation Depth MD (ft): 9,665' 12,095 - 12,436 3-1/2" 9,218 - 9,213 Other: CTCO, N2 Middle Kenai G & Hemlock Oil 12,095' 9,218' 7,240psi 4/10/2025 12,436'492' 2-7/8" 9,213' 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 3:43 pm, Mar 27, 2025 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.03.27 14:41:14 - 08'00' Dan Marlowe (1267) 325-179 DSR-4/2/25 MGR09APR2025 * Service coil BOPE test to 2500 psi. - 48 hour notice. 10-404 SFD 5/13/2025*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.05.13 14:00:33 -08'00'05/13/25 RBDMS JSB 051425 Coil Cleanout / Addperf Well: Dolly Varden D-07RD2 Well Name:D-07RD2 API Number:50-733-20117-02-00 Current Status:Gas Lift Oil Producer Leg:A-2 (NW) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:192-155 First Call Engineer:Casey Morse (603) 205-3780 (c) Second Call Engineer:Eric Dickerman (907) 564-4061 (o) Maximum Expected BHP: 3,200 psi @ 9,215’ TVD (mid-horizontal) Max from offsets Max. Potential Surface Pressure: 2279 psi Using 0.1 psi/ft Brief Well Summary Dolly Varden D-07RD2 is a Hemlock Bench 1 producer. It was sidetracked to its current bottomhole location in 1993 when a ~400’ horizontal was drilled. In 2024 the well was converted from ESP to gas lift to align with declining production. Since that workover, sand / debris has entered the wellbore and restricted production rates. The goal of this project is to clean out the well down to the top of the slotted liner and add perforations to the Middle Kenai G for increased production. Pertinent wellbore information: - Inclination: o Max inc above slotted liner = 58 degrees at 4420’ MD o Goes > 70 degrees at 12,080’ MD - Pertinent History o March-2024: Workover to convert from ESP to gas lift Most recent acid job pumped 3/9/24 Most recent casing pressure test 3/19/24 at 2260 psi for 30 mins o June-2017: Tubing perforated, and well produced on single point injection GL o March-2017 ESP dies after 3-year runtime o Nov- 2015: Acid job pumped o April-2014: RWO to convert to ESP After pulling GL completion, EL punches holes from 11,935 – 11,941’ MD to allow for flow around fish. 8.5” bit/casing scraper run to top of 7” 6.151” mill would not pass 7” liner top 5.8125” mill + 5.969” string mill in 7” liner down to 11,875’ MD MIT to 1500psi PASSED against a test packer set at 11,875’ MD ESP completion run (no Packer nor SSSV due to passing NFT) o April/May 2012: Multiple CT and SL fishing attempts for catcher sub EL ultimately cuts catcher sub at mid-point, and CT successfully fishes the top half Unable to fish lower half EL shoots downward facing charge to blow through remaining catcher sub Coil Cleanout / Addperf Well: Dolly Varden D-07RD2 1.5” blind box appears to indicate bottom of catcher sub blown out (but still can’t passthrough) o March-1994: SL set catcher sub in X-nipple at 11,958’ MD. Unable to retrieve. o 7/30/93: SL drifts to 12,010’ MD with a 2.74” gauge ring (likely broke knock out isolation valve at 11,942’ MD on this intervention) o 1993: D-07RD sidetracked to D-07RD2 Pre-sidetrack abandoned all open perfs Cemented back to 11,500’ in 7” liner D-07RD had Hemlock only perfs, all below D-07RD2 kickoff point Sidetrack drilled a ~350’ lateral in Hemlock Bench 1 and lined with 3-1/2” slotted liner GL completion installed Coiled Tubing FCO Procedure 1. MIRU Coiled Tubing and pressure control equipment 2. PT lubricator to 250psi low / 2500psi high 3. MU FCO BHA 4. RIH and cleanout to fish top ±11,958’ or as deep as practical a. Working fluid will be filtered inlet water b. Take returns to surface up the CT x tubing / CT x casing annulus c. Add foam and nitrogen as necessary to carry solids to surface d. May also utilize gas lift to assist with hole cleaning 5. Stand back CT and flow test well Contingent EL Perf Add Procedure (would only be completed after flow testing well) 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 3500psi high a. 0.45psi/ft * deepest potential perf add at 9100’ TVD = 4095psi b. 4095 – (9100’ TVD * 0.1psi/ft gas gradient) = 3185psi 3. RIH with tubing punch and re-punch liner below the liner top packer ±11,925 – 11,940’. 4. RIH and perforate Middle Kenai “G” Pool sands from ±11,450 - ±11,920’ MD (±8,710’ - ±9,100’ TVD) per Engineer’s perf table. 5. RDMO EL Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Current Wellhead Diagram (no change) 4. CT BOP Drawing (Fox Energy) 5. Nitrogen Procedure 48 hour notice for AOGCC to witness. - mgr Revised By: JLL 07/22/24 Well: D-07RD2 Completed: 03/19/2024 PTD: 192-155 API: 50-733-20117-02-00 SCHEMATIC CASING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM (MD)TYPE 13-3/8”61 J-55 BTC 12.515 Surface 1,401’ 9-5/8” 40 N-80 BTC 8.835 Surface 5,761' 43.5 N-80 BTC 8.755 5,763'7,919' 47 N-80 BTC 8.681 7,919'9,665' 7”29 N-80 LTC 6.184 9,226’12,095’ 3-1/2”9.3 L-80 Hydril 2.992 11,944'12,436’Slotted TUBING DETAIL 2-7/8”6.5 N-80 8rd EUE 2.441 Surface 11,407' DV Collar from 5,761' to 5,763' in 9-5/8" Casing Tubing Punch @ 11,935’-11,941’ 4/11/14 JEWELRY DETAIL No Depth (MD) Depth TVD ID Item CIW Tbg Hanger 10" Nom. "DCB" 1 387'387'2.313 Giant Oil Tools - TR-SSSV 2 11,302'8,585'2.313 Halliburton - Sliding Sleeve: close up, open down. CLOSED as of 3/19/24 3 11,353'8,628'2.990 7" 26-32# DLH Hydraulic Set Retrievable Packer 4 11,402'8,670'2.313 X-Nipple 2.313 Profile 5 11,407'8,674'2.441 Mule shoe 2 7/8" A 11,921'9,101'4.00”Baker"SC-1R" Packer B 11,942'9,118'3.50”Baker Knock-out Isolation Valve (likely knocked out 4/6/93) C 11,945'9,121'2.968”Baker Rotationally Locked Safety Joint (pinned to 57k#) D 11,958'9,132'2.81” Otis "X" Nipple: FISH. Bottom half of catcher sub (24”) stuck in X-nip since 1994. 1.75” hole blown down through assembly on 5/5/12 Hemlock Bench 1 Horizontal – 1993 (no prior D-07RD perfs above sidetrack window). GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 3,269'2,863'2.340"SFO2-1.5" Valve (Top drifted w/ 2.34"12 Dome 1255 3/19/2024 2 5,277'4,190'2.441"SFO2-1.5" Valve 12 Dome 1230 3/19/2024 3 7,088'5,288'2.441"SFO2-1.5" Valve 12 Dome 1205 3/19/2024 4 7,911'5,888'2.340"SFO2-1.5" Valve (Btm drifted w/ 2.34"12 Dome 1180 3/19/2024 5 8,732'6,481'2.441"SFO2-1.5" Valve 12 Dome 1155 3/19/2024 6 9,427'6,999'2.441"SFO2-1.5" Valve 12 Dome 1130 3/19/2024 7 9,928'7,395'2.441"SFO1-1" Valve 20 Dome 1105 7/11/2024 8 10,418'7,810'2.441"SFO1-1" Valve 20 Dome 1080 7/11/2024 9 10,853'8,193'2.441"SFO1-1" Valve 20 Dome 1055 7/11/2024 10 11,220'8,515'2.441"SFO1-1" Valve 22 Orifice 7/11/2024 13-3/8"17-1/2” Hole in parentbore D-07: Pumped 2400sxs of 14.0ppg Class G. ToC seen back to surface. 9-5/8" 12-1/4” Hole in parentbore D-07: Pumped 1250sxs class G cement in stage #1 from 10,169’. Slight cement back to surface when circulated through DV at 5,761’ MD.ToC at base DV collar 2nd Stage: Pumped 1065sxs of class G through DV collar at 5,761’ MD. Assuming 10% washout and 1.54 ft^3 / sxs, volumetric ToC = 1000’ MD. 7”8-1/2” hole in parentbore D-07RD: Pumped 1000sxs class G. Saw 250sxs circulated off liner top when POOH.2/25/78 CBL confirms ToC at ToL. Revised By: CDM 03/26/25 Well: D-07RD2 Completed: 03/19/2024 PTD: 192-155 API: 50-733-20117-02-00 PROPOSED TD = 12,438’ TVD = 9,306’ All Measurements are RKB to Top of E q uip ment.RKB: 43.80’ 1 33” 13-3/8” 9-5/8” 7” 6” Open Hole A B C D 2 4 3 5 7” Window 12,052 – 12,095 Tubing punch 11,935’-11,941’ Hemlock Perf’s Bench 1-6 12,035 – 12,625 Abandonded X CASING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM (MD)TYPE 13-3/8” 61 J-55 BTC 12.515 Surface 1,401’ 9-5/8” 40 N-80 BTC 8.835 Surface 5,761' 43.5 N-80 BTC 8.755 5,763' 7,919' 47 N-80 BTC 8.681 7,919' 9,665' 7” 29 N-80 LTC 6.184 9,226’ 12,095’ 3-1/2” 9.3 L-80 Hydril 2.992 11,944' 12,436’ Slotted TUBING DETAIL 2-7/8” 6.5 N-80 8rd EUE 2.441 Surface 11,407' DV Collar from 5,761' to 5,763' in 9-5/8" Casing Tubing Punch @ 11,935’-11,941’ 4/11/14 JEWELRY DETAIL No Depth (MD) Depth TVD ID Item CIW Tbg Hanger 10" Nom. "DCB" 1 387' 387' 2.313 Giant Oil Tools - TR-SSSV 2 11,302' 8,585'2.313 Halliburton - Sliding Sleeve: close up, open down. CLOSED as of 3/19/24 3 11,353' 8,628' 2.990 7" 26-32# DLH Hydraulic Set Retrievable Packer 4 11,402' 8,670' 2.313 X-Nipple 2.313 Profile 5 11,407' 8,674' 2.441 Mule shoe 2 7/8" A 11,921' 9,101' 4.00” Baker"SC-1R" Packer B 11,942' 9,118' 3.50” Baker Knock-out Isolation Valve (likely knocked out 4/6/93) C 11,945' 9,121' 2.968” Baker Rotationally Locked Safety Joint (pinned to 57k#) D 11,958' 9,132' 2.81” Otis "X" Nipple:FISH. Bottom half of catcher sub (24”) stuck in X-nip since 1994. 1.75” hole blown down through assembly on 5/5/12 Hemlock Bench 1 Horizontal GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 3,269' 2,863'2.340"SFO2-1.5" Valve (Top drifted w/ 2.34" 12 Dome 1255 3/19/2024 2 5,277' 4,190' 2.441" SFO2-1.5" Valve 12 Dome 1230 3/19/2024 3 7,088' 5,288' 2.441" SFO2-1.5" Valve 12 Dome 1205 3/19/2024 4 7,911' 5,888'2.340"SFO2-1.5" Valve (Btm drifted w/ 2.34" 12 Dome 1180 3/19/2024 5 8,732' 6,481' 2.441" SFO2-1.5" Valve 12 Dome 1155 3/19/2024 6 9,427' 6,999' 2.441" SFO2-1.5" Valve 12 Dome 1130 3/19/2024 7 9,928' 7,395' 2.441" SFO1-1" Valve 20 Dome 1105 7/11/2024 8 10,418' 7,810' 2.441" SFO1-1" Valve 20 Dome 1080 7/11/2024 9 10,853' 8,193' 2.441" SFO1-1" Valve 20 Dome 1055 7/11/2024 10 11,220' 8,515' 2.441" SFO1-1" Valve 22 Orifice 7/11/2024 13-3/8"17-1/2” Hole in parentbore D-07: Pumped 2400sxs of 14.0ppg Class G.ToC seen back to surface. 9-5/8" 12-1/4” Hole in parentbore D-07: Pumped 1250sxs class G cement in stage #1 from 10,169’. Slight cement back to surface when circulated through DV at 5,761’ MD.ToC at base DV collar 2nd Stage: Pumped 1065sxs of class G through DV collar at 5,761’ MD.Assuming 10% washout and 1.54 ft^3 / sxs, volumetric ToC = 1000’ MD. 7”8-1/2” hole in parentbore D-07RD: Pumped 1000sxs class G. Saw 250sxs circulated off liner top when POOH.2/25/78 CBL confirms ToC at ToL. PERFORATIONS Zone Top (MD) Bottom (MD) Top (TVD) Bottom (TVD)Length Date Status G ±11,450 ±11,920 ±8,710 ±9,100 Proposed Dolly Varden Platform D-07RD2 01/22/2024 Tubing head, CIW-DCB-S, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SSO, X-bottom prep Valve, WKM-M, 2 1/16 5M FE, HWO, AA Qty 2 Casing head, CIW-WF, 13 5/8 3M X 13 3/8'’ threaded bottom, w/ 2- 2 1/16 5M EFO Valve, CIW-F, 2 1/16 5M FE, HWO, AA Valve, Upper Master, CIW-FC, 3 1/8 5M FE, HWO, EE trim Valve, Swab, CIW-FC, 3 1/8 5M FE, HWO, EE trim Valve, Master, CIW-FC, 3 1/8 5M FE, HWO, EE trim Valve, SSV, FC, 3 1/8 5M FE, w/ 15'’ Safeco oper-air operated Tubing hanger, CIW-DCB- FBB-CCL, 11 X 3 1/2 EUE lift and susp, w/ 3'’ type H BPV profile, 6 ¼ EN, 2- ½ npt CCL ports Adapter, CIW-EN-CCL, 11 5M Stdd x 3 1/8 5M, prepped for 6 ¼ EN and 2- ½ npt CCL ports, EE material Dolly Varden Platform D-07RD2 13 3/8 X 9 5/8 X 2 7/8 BHTA, Bowen, 3 1/8 5M FE X 3'’ Bowen Quick Union KLU A-1 Well Head Rig Up 1 1 1 1 4 1/16" 15K Lubricator - 10 ft 100" Gooseneck HR680 Injector Head 4 1/16" 10K Flow Cross, 2" 1502 10k Flanged Valves 4 1/16" 15K Lubricator - 10 ft API Flange Adapter 10K to 5K for riser/wellhead Hydraulic Stripper 4 1/6" 15K API Bowen CB56 15K 4 1/16" 10K Combi BOPs Blind/Shear Ram Pipe/Slip Ram 4 1/16" 10K bottom flange 4 1/16" 5K flanged Riser - 10 ft if necessary STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. 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 12,438 feet N/A feet true vertical 9,306 feet 11,958 feet Effective Depth measured 12,438 feet See schematic feet true vertical 9,306 feet See schematic feet Perforation depth Measured depth 12,095 - 12,436 feet True Vertical depth 9,218 - 9,213 feet Tubing (size, grade, measured and true vertical depth) 2-7/8" N-80 11,407 (MD) 8,674 (TVD) Packers and SSSV (type, measured and true vertical depth) See schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Hemlock 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 5,410psi 6,380psi 5,750psi 7,240psi Burst Collapse 2,670psi measured TVD Liner Liner 9,665 2,869 492 Casing Conductor 7,375 9,218 3-1/2" 9,665 12,095 12,436 9,213 1,401 1,401Surface Intermediate Production 33" 13-3/8" 9-5/8" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 192-155 50-733-20117-02-00 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: ADL0017594 McArthur River / Hemlock Oil Trading Bay Unit D-07RD2 Plugs Junk measured Length 398 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) 62 Gas-Mcf MD 398 N/A 586 Size 304 1,069 546 113715 0 125116 113 324-034 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 17 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 1:29 pm, Apr 16, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.04.16 11:06:54 - 08'00' Dan Marlowe (1267) RBDMS JSB 041924 DSR-4/23/24 Revised By: JLL 04/12/24 Well: D-07RD2 Completed: 03/19/2024 PTD: 192-155 API: 50-733-20117-02-00 SCHEMATIC TD = 12,438’ TVD = 9,306’ All Measurements are RKB to Top of E q uip ment.RKB: 43.80’ 1 33” 13-3/8” 9-5/8” 7” 6” Open Hole A B C D 2 4 3 5 7” Window 12,052 – 12,095 Tubing punch 11,935’-11,941’ Hemlock Perf’s Bench 1-6 12,035 – 12,625 Abandonded X CASING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM (MD)TYPE 13-3/8” 61 J-55 BTC 12.515 Surface 1,401’ 9-5/8” 40 N-80 BTC 8.835 Surface 5,761' 43.5 N-80 BTC 8.755 5,763' 7,919' 47 N-80 BTC 8.681 7,919' 9,665' 7” 29 N-80 LTC 6.184 9,226’ 12,095’ 3-1/2” 9.3 L-80 Hydril 2.992 11,944' 12,436’ Slotted TUBING DETAIL 2-7/8” 6.5 N-80 8rd EUE 2.441 Surface 11,407' DV Collar from 5,761' to 5,763' in 9-5/8" Casing Tubing Punch @ 11,935’-11,941’ 4/11/14 JEWELRY DETAIL No Depth (MD) Depth TVD ID Item CIW Tbg Hanger 10" Nom. "DCB" 1 387' 387' 2.313 Giant Oil Tools - TR-SSSV 2 11,302' 8,585'2.313 Halliburton - Sliding Sleeve: close up, open down. CLOSED as of 3/19/24 3 11,353' 8,628' 2.990 7" 26-32# DLH Hydraulic Set Retrievable Packer 4 11,402' 8,670' 2.313 X-Nipple 2.313 Profile 5 11,407' 8,674' 2.441 Mule shoe 2 7/8" A 11,921' 9,101' 4.00” Baker"SC-1R" Packer B 11,942' 9,118' 3.50” Baker Knock-out Isolation Valve (likely knocked out 4/6/93) C 11,945' 9,121' 2.968” Baker Rotationally Locked Safety Joint (pinned to 57k#) D 11,958' 9,132' 2.81” Otis "X" Nipple:FISH. Bottom half of catcher sub (24”) stuck in X-nip since 1994. 1.75” hole blown down through assembly on 5/5/12 Hemlock Bench 1 Horizontal –1993 (no prior D-07RD perfs above sidetrack window). GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 3,269' 2,863'2.340"SFO2-1.5" Valve (Top drifted w/ 2.34" 12 Dome 1255 3/19/2024 2 5,277' 4,190' 2.441" SFO2-1.5" Valve 12 Dome 1230 3/19/2024 3 7,088' 5,288' 2.441" SFO2-1.5" Valve 12 Dome 1205 3/19/2024 4 7,911' 5,888'2.340"SFO2-1.5" Valve (Btm drifted w/ 2.34" 12 Dome 1180 3/19/2024 5 8,732' 6,481' 2.441" SFO2-1.5" Valve 12 Dome 1155 3/19/2024 6 9,427' 6,999' 2.441" SFO2-1.5" Valve 12 Dome 1130 3/19/2024 7 9,928' 7,395' 2.441" SFO1-1" Valve 12 Dome 1105 3/19/2024 8 10,418' 7,810' 2.441" SFO1-1" Valve 22 Orifice 3/19/2024 9 10,853' 8,193' 2.441" SFO1-1" Valve Dummy 3/19/2024 10 11,220' 8,515' 2.441" SFO1-1" Valve Dummy 3/19/2024 13-3/8"17-1/2” Hole in parentbore D-07: Pumped 2400sxs of 14.0ppg Class G.ToC seen back to surface. 9-5/8" 12-1/4” Hole in parentbore D-07: Pumped 1250sxs class G cement in stage #1 from 10,169’. Slight cement back to surface when circulated through DV at 5,761’ MD.ToC at base DV collar 2nd Stage: Pumped 1065sxs of class G through DV collar at 5,761’ MD.Assuming 10% washout and 1.54 ft^3 / sxs, volumetric ToC = 1000’ MD. 7”8-1/2” hole in parentbore D-07RD: Pumped 1000sxs class G. Saw 250sxs circulated off liner top when POOH.2/25/78 CBL confirms ToC at ToL. Well Name:MRF D-07RD2 API #:50733201170200 Field:McArthur River Start Date:3/8/2024 Permit #:192155 Sundry #:324-034 End Date:3/19/2024 3/8/2024 3/9/2024 3/12/2024 3/13/2024 3/14/2024 3/15/2024 3/16/2024 Continue R/U w/o unit, spot and plume test pump, hook up electric cable to heater, trouble shoot same, function test bop's, hootch choke manifold. Rig up test joint, attempt to shell test Bop's, trouble shoot test equipment, change out bad conections on test joint. Well Operations Summary R/u eq. PT lines 250L-2000H. Pumped away 15bbl of diesel and 26bbls safe acid pill displacing with FIW per pump schedule. Recored pressure fluctuation up to 314psi while injecting pill to formation. R/d pump and circulating lines. Well SI. Mobe crews out to Dolly platform. orientate crews, off loading equipment from workboat, rig up pump and kill well with 807 BBls FIW, max pump pressure at 400 psi at 2.5 bpm, shut down pump TBG on vacuum, IA on slght vacuum, set BPV,Nipple down TREE Held PJSM, R/u 404 pump and circulating hoses. Stage safe acid totes. Prep to pump job in the AM. N/D tree, prep wellhead, install blanking sub, N/U BOPE, install work window, and snubbing unit to BOP stack and secure same to deck, Running & hooking up koomey lines, place choke manifold. Replace bad xo fitting from Test joint, & reconfigure. perform shell test on BOPE, TEST Bops to Hilcorp and AOGCC specs, to 250 lo & 2500 psi hi. , test Witness By AOGCC Josh Hunt, no failures, tested Gas Alarms, ALL good, pull blanking sub, and BPV , tbg on vacuum, Circulate well with FIW, pump total of 256 bbls getting water back, shut down pump, Rig up summit spoolers,and power up same, perp to pull hanger, Continue R/U ESP pulling eq. M/U landing joint. pull and lay out hanger,weld down spoolers, pooh with ESP assembly, laying down 2- 7/8 6.5#, N-80 11,819 ft. to 7935 ft. Daily Operations: Page 1 of 2 Well Name:MRF D-07RD2 API #:50733201170200 Field:McArthur River Start Date:3/8/2024 Permit #:192155 Sundry #:324-034 End Date:3/19/2024 3/17/2024 3/18/2024 3/19/2024 Well Operations Summary Daily Operations: R/U set packer, pressure up t/3700psi, set packer @ 11359', hold chart f/30min testing tubing good, R/U to IA testing packer/casing t/2260psi hold f/ 30 min good. pull landing joint, set BPV, rig down aux eq. Rig down TSI HWO unit, prep to ship to dock, nipple down BOPE, install vertical run of 3-1/16 tree, nipple up same test void to 5k good test, install SSV and test tree to 250 low and 5000 high, pull two way check, Back loading boat,, cleaning decks Prep, Completion, finish Tally PJSM with hands. P/U & RIH w/2 7/8" 6.5# L-80 Gas lift completion,m/u hanger & land place tubing tail @ 11440' Continue to POOH with ESP pump assembly laying down 2-7/8 6.5#, EUE 8rd N-80 tbg, laid down total of 360 joints, Held PJSM with crew on laying down pumps, pooh laying down pump assembly, Had full recovery of pump assembly . Rig down summit and clean decks. Page 2 of 2 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________TRADING BAY UNIT D-07RD2 JBR 04/12/2024 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:0 2-7/8" Test joint. Nitrogen precharge 20 @1025 psi. Good test. Test Results TEST DATA Rig Rep:Tom Mathews/ Don MiOperator:Hilcorp Alaska, LLC Operator Rep:Harold Soule/ Ed Hooter Rig Owner/Rig No.:Team Snubbing TSI 102 PTD#:1921550 DATE:3/15/2024 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopJDH240317104741 Inspector Josh Hunt Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 3.5 MASP: 2279 Sundry No: 324-034 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" 5K P #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" 5K P HCR Valves 2 2-1/16" 5K P Kill Line Valves 2 2-1/16" 5K P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P1800 200 PSI Attained P30 Full Pressure Attained P122 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P6@ 1800 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 P10 #1 Rams P8 #2 Rams P7 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1        1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10.Field: Hemlock Oil 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 12,438 N/A Casing Collapse Conductor Surface 2,670psi Intermediate Production 3,090psi Liner 5,410psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Ryan Rupert Contact Email:Ryan.Rupert@hilcorp.com Contact Phone:(907) 777-8503 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other 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 Trading Bay Unit D-07RD2 McArthur River 9,306 12,438 9,306 2,279psi N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017594 192-155 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20117-02-00 Hilcorp Alaska, LLC CO 228A Length Size Proposed Pools: 398' 304' N-80 TVD Burst 11,721 MD 5,750psi 6,380psi1,069' 7,375' 2,869' 7" 1,401' 398' 33" 13-3/8"1,401' SC-1R Prk & N/A 11,921 (MD) 9,096 (TVD) & N/A 9-5/8"9,665' Perforation Depth MD (ft): 9,665' 12,095 - 12,436 3-1/2" 9,218 - 9,213 Other: ESP to GL HWO Hemlock Oil & Middle Kenai G Oil 12,095' 9,218' 7,240psi 2/6/2024 12,436'492' 2-7/8" 9,213' 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 2:22 pm, Jan 24, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.01.24 13:59:50 - 09'00' Dan Marlowe (1267) 324-034 If Middle Kenai "G" Oil Pool perfs are added commingled production must be done in accordance w/ CO 234A Perform MITIA or MIT-tbg to 2200 psi verify integrity of new tubing. SFD 1/31/2024 Perforate New Pool X BOPtestto2500psi BJM 2/5/24 DSR-1/26/24 10-404 JLC 2/5/2024 2/5/24Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.05 14:41:07 -09'00' RBDMS JSB 020624 ESP to GL HWO Well: Dolly Varden D-07RD2 Well Name:D-07RD2 API Number:50-733-20117-02-00 Current Status:Failed ESP Oil Producer Leg:A-2 (NW) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:192-155 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Maximum Expected BHP: 3,200 psi @ 9,215’ TVD (mid-horizontal) Max from offsets Max. Potential Surface Pressure: 2279 psi Using 0.1 psi/ft Brief Well Summary Dolly Varden D-07RD2 is a Hemlock bench-1 producer. It was sidetracked to its current bottomhole location in 1993 when a ~400’ horizontal was drilled. In 1994 a catcher sub was left downhole from a GL intervention. Production stayed fairly steady around 500 bfpd producing around the fish until total fluid rates fell to <100bfpd in 2005. The well was SI. Multiple fishing attempts were made without success, and the well remained SI until Hilcorp purchased the field in 2012. Hilcorp performed a CT intervention in 2012 and successfully recovered the top half of the catcher sub (see history below). A hole was also blasted through the remaining lower half of the catcher sub. Production was restored, but only to ~150bfpd. In 2013 several acid jobs were performed, and production jumped up to the 500bfpd range. With the productivity restored, a RWO was performed in 2014 to install an ESP. Punches were shot in the tubing tail above the fish to further connect to the slotted liner completion below. The ESP ran for ~3 years and then died in March of 2017. Throughout this recent history, it is well documented that acid has been successful in restoring productivity. Well D-07RD2 sits on the NW leg of the Dolly Varden Platform.This leg’s configuration and deck layout precludes our Hilcorp owned RWO rig (#404) from rigging up on this leg’s wells. Given that we plan to utilize Team Snubbing’s Hydraulic Workover unit with a smaller footprint to workover well D-07RD2. The goal of this project is to pull the failed ESP and replace with a gas lift completion to restore full production ESP to GL HWO Well: Dolly Varden D-07RD2 Pertinent wellbore information: - Inclination: o Max inc above fish = 58 degrees at 4420’ MD o Goes > 70 degrees at 12,080’ MD - Pertinent History o June-2017: Tubing perforated, and well produced on single point injection GL o March-2017 ESP dies after 3 year runtime o 12/15/15: Most recent NFT PASSED o Nov- 2015: Most recent acid jobs pumped o April-2014: RWO to convert to ESP After pulling GL completion, EL punches holes from 11,935 – 11,941’ MD to allow for flow around fish. 8.5” bit/casing scraper run to top of 7” 6.151” mill would not pass 7” liner top 5.8125” mill + 5.969” string mill in 7” liner down to 11,875’ MD MIT to 1500psi PASSED against a test packer set at 11,875’ MD ESP completion run (no Packer nor SSSV due to passing NFT) o April/May 2012: Multiple CT and SL fishing attempts for catcher sub EL ultimately cuts catcher sub at mid-point, and CT successfully fishes the top half Unable to fish lower half EL shoots downward facing charge to blow through remaining catcher sub 1.5” blind box appears to indicate bottom of catcher sub blown out (but still can’t passthrough) o March-1994: SL set catcher sub in X-nipple at 11,958’ MD. Unable to retrieve. o 7/30/93: SL drifts to 12,010’ MD with a 2.74” gauge ring (likely broke knock out isolation valve at 11,942’ MD on this intervention) o 1993: D-07RD sidetracked to D-07RD2 Pre-sidetrack abandoned all open perfs Cemented back to 11,500’ in 7” liner D-07RD had Hemlock only perfs, all below D-07RD2 kickoff point Sidetrack drilled a ~350’ lateral in Hemlock Bench-1 and lined with 3-1/2” slotted liner GL completion installed HWO Conditions x Operations shall be 24hrs continuous x Traditional well control approach will be implemented x Filtered Inlet water (FIW) will be used as kill weight fluid (8.4ppg or greater) x KWF will be a barrier at all times x No snubbing operations will be conducted x The same 13-5/8” BOP stack that has been in continuous service with rigs 401, 404, and Monopod #56 will be used for BOPE ESP to GL HWO Well: Dolly Varden D-07RD2 HWO Procedure: 1. MIRU PESI Hydraulic Workover (HWO) Unit (Snubbing International, Alberta, Canada: DBA PESI) 2. Circulate well to production: 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. Tubing volume = 68bbls d. IA + Liner + Openhole volume ~720bbls 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. BOP’s will be closed as needed to circulate the well 4. Pull BPV/TWC through BOP stack 5. BOLDS and unseat hanger 6. POOH laying down ESP completion 7. Pickup same 2-7/8” pipe and RIH with gas lift + packer completion a. Top pool is ±11,450’ MD b. Set packer at ±11,425’ MD (±8,718’ TVD) to enable future G-zone perfs c. Run completion with live GLV’s Contingency if can’t get completion / packer to set depth 8. PU 3-1/2” workstring 9. MU 7” liner cleanout assembly 10. RIH and mill/cleanout 7” liner to target depth = 11,500’ MD 11. POOH and lay down cleanout BHA and workstring Note: No change to perfs/reservoir section, so no new NFT should be required if cleanout is performed 12. Set packer and perform charted CMIT-TxIA to 2200psi 13. Set BPV/TWC, ND BOP, NU tree and test, pull BPV/TWC, and RDMO HWO crew and equipment Perform MITIA or MIT-T to 2200 psi to verify tubing integrity. - bjm ESP to GL HWO Well: Dolly Varden D-07RD2 Contingent Acid Stimulation Procedure 1. RU pump and treating lines 2. Pressure test all to 250psi low and 2000psi high 3. Pump Mutual solvent/Xylene pre flush followed by acid pill (5-15% concentration HCL, or Oilsafe AR- Synthetic acid) to stimulate slotted liner and openhole 4. Displace pill and spot across openhole with FIW keeping treating pressure <2000psi during displacement 5. RD pumping equipment 6. Let acid soak (duration per OE) 7. Return well to production Contingent EL Perf Add Procedure (would only be completed after HWO complete) 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 3500psi high a. 0.45psi/ft * deepest potential perf add at 9125’ TVD = 4107psi b. 9125’ TVD * 0.1psi/ft gas gradient = 3194psi 3. RIH and perforate Middle Kenai “G” Pool sands from ±11,450 - ±11,958’ MD (±8,737’ - ±9,125’ TVD) per RE/Geo 4. RDMO EL Well will need another witnessed no flow test if perfs are added, or acid is pumped Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Current Wellhead Diagram 4. Proposed Wellhead Diagram 5. Hilcorp BOP Drawing 6. Modified fluid flow diagram to include Snubbing equipment 7. RWO Sundry Change Form Downhole commingling of production from the Hemlock and Middle Kenai G Oil Pools in the McArthur River Field is authorized by CO 234A. - DSR 1/26/24 *Proposed perfs will lie in Middle Kenai G Oil Pool. In D-07RD: Top Middle “G” Oil Pool: 11,420' MD / 8,665' TVD Top Hemlock Oil Pool: 12,035' MD / 9,176' TVD Per M. Petrowsky, 1/31/2024 SFD Revised By: JLL 01/16/24 Well: D-07RD2 Completed: 04/22/14 PTD: 192-155 API: 50-733-20117-02-00 SCHEMATIC TD = 12,438’ TVD = 9,306’ All Measurements are RKB to Top of E q uip ment.RKB: 43.80’ 1 33” 13-3/8” 9-5/8” 7” 6” Open Hole 2 3 4 5 6 7” Window 12,052 – 12,095 Tubing punch 11,935’-11,941’ Hemlock Perf’s Bench 1-6 12,035 – 12,625 Abandonded CASING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM (MD)TYPE 13-3/8” 61 J-55 BTC 12.515 Surface 1,401’ 9-5/8” 40 N-80 BTC 8.835 Surface 5,761' 43.5 N-80 BTC 8.755 5,763' 7,919' 47 N-80 BTC 8.681 7,919' 9,665' 7” 29 N-80 LTC 6.184 9,226’ 12,095’ 3-1/2” 9.3 L-80 Hydril 2.992 11,944' 12,436’ Slotted TUBING DETAIL 2-7/8” 6.5 N-80 8rd EUE 2.441 Surface 11,721‘ DV Collar from 5,761' to 5,763' in 9-5/8" Casing Tubing Punch @ 4,725’ (Single shot) 6/14/17 Tubing Punch @ 11,675’-11,677’ (10 shots) 6/14/17 Tubing Punch @ 11,935’-11,941’ 4/11/14 JEWELRY DETAIL No Depth (MD) Depth TVD ID Item 1 CIW Tbg Hanger 10" Nom. "DCB" 2 11,721’ 8,944’ Bolt-On Discharge 11,723’ 8,945’ Pump (x2) 400 Series, 144 Stage, SF1000 11,766’ 8,978’ Intake 11,785’ 8,993’ Motor – 456 Series (Max OD = 4.56”) 11,820’ 9,019’ Bottom of ESP 3 11,921' 9,096’ 4.00” Baker"SC-1R" Packer 4 11,942' 9,112’ 3.50” Baker Knock-out Isolation Valve (likely knocked out 4/6/93) 5 11,945' 9,115’ 2.968” Baker Rotationally Locked Safety Joint (pinned to 57k#) 6 11,958' 9,125’ 2.81” Otis "X" Nipple:FISH. Bottom half of catcher sub (24”) stuck in X-nip since 1994. 1.75” hole blown down through assembly on 5/5/12 Hemlock Bench 1 Horizontal – 1993 (no prior D-07RD perfs above sidetrack window). CEMENT DETAILS 13-3/8"17-1/2” Hole in parentbore D-07: Pumped 2400sxs of 14.0ppg Class G. ToC seen back to surface. 9-5/8" 12-1/4” Hole in parentbore D-07: Pumped 1250sxs class G cement in stage #1 from 10,169’. Slight cement back to surface when circulated through DV at 5,761’ MD.ToC at base DV collar 2nd Stage: Pumped 1065sxs of class G through DV collar at 5,761’ MD.Assuming 10% washout and 1.54 ft^3 / sxs, volumetric ToC = 1000’ MD. 7”8-1/2” hole in parentbore D-07RD: Pumped 1000sxs class G. Saw 250sxs circulated off liner top when POOH.2/25/78 CBL confirms ToC at ToL. Assuming 10% washout Revised By: JLL 01/22/24 Well: D-07RD2 Completed: Future PTD: 192-155 API: 50-733-20117-02-00 PROPOSED TD = 12,438’ TVD = 9,306’ All Measurements are RKB to Top of E q uip ment.RKB: 43.80’ 1 33” 13-3/8” 9-5/8” 7” 6” Open Hole 2 A B C D 3 5 4 6 7” Window 12,052 – 12,095 Tubing punch 11,935’-11,941’ Hemlock Perf’s Bench 1-6 12,035 – 12,625 Abandonded X G-Zone G-Zone CASING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM (MD)TYPE 13-3/8” 61 J-55 BTC 12.515 Surface 1,401’ 9-5/8” 40 N-80 BTC 8.835 Surface 5,761' 43.5 N-80 BTC 8.755 5,763' 7,919' 47 N-80 BTC 8.681 7,919' 9,665' 7” 29 N-80 LTC 6.184 9,226’ 12,095’ 3-1/2” 9.3 L-80 Hydril 2.992 11,944' 12,436’ Slotted TUBING DETAIL 2-7/8” 6.5 N-80 8rd EUE 2.441 Surface ±11,450‘ DV Collar from 5,761' to 5,763' in 9-5/8" Casing Tubing Punch @ 11,935’-11,941’ 4/11/14 JEWELRY DETAIL No Depth (MD) Depth TVD ID Item CIW Tbg Hanger 10" Nom. "DCB" 1 ±400’ 305’ TRSSSV w/ctrl line to surface 2 ±11,275’ 8,603’ GLV’s – Live (# TBD) 3 ±11,375’ 8,680’ Sliding Sleeve 4 ±11,425’ 8,718’ Packer 5 ±11,440’ 8,729’ X Nipple 6 ±11,450’ 8,737’ WLEG A 11,921' 9,096’ 4.00” Baker"SC-1R" Packer B 11,942' 9,112’ 3.50” Baker Knock-out Isolation Valve (likely knocked out 4/6/93) C 11,945' 9,115’ 2.968” Baker Rotationally Locked Safety Joint (pinned to 57k#) D 11,958' 9,125’ 2.81” Otis "X" Nipple:FISH. Bottom half of catcher sub (24”) stuck in X-nip since 1994. 1.75” hole blown down through assembly on 5/5/12 Hemlock Bench 1 Horizontal – 1993 (no prior D-07RD perfs above sidetrack window). CEMENT DETAILS 13-3/8"17-1/2” Hole in parentbore D-07: Pumped 2400sxs of 14.0ppg Class G. ToC seen back to surface. 9-5/8" 12-1/4” Hole in parentbore D-07: Pumped 1250sxs class G cement in stage #1 from 10,169’. Slight cement back to surface when circulated through DV at 5,761’ MD.ToC at base DV collar 2nd Stage: Pumped 1065sxs of class G through DV collar at 5,761’ MD.Assuming 10% washout and 1.54 ft^3 / sxs, volumetric ToC = 1000’ MD. 7”8-1/2” hole in parentbore D-07RD: Pumped 1000sxs class G. Saw 250sxs circulated off liner top when POOH.2/25/78 CBL confirms ToC at ToL. PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status G-Zone ±11,450' ±11,958' ±8,737' ±9,125' 508' Future Proposed *Proposed perfs will lie in Middle Kenai G Oil Pool. In D-07RD: Top Middle “G” Oil Pool: 11,420' MD / 8,665' TVD Top Hemlock Oil Pool: 12,035' MD / 9,176' TVD Per M. Petrowsky, 1/31/2024 SFD * Dolly Varden Platform D-07RD2 Current 04/21/2014 Dolly Varden Platform D-07RD2 Proposed 01/22/2024 Tubing head, CIW-DCB-S, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SSO, X-bottom prep Valve, WKM-M, 2 1/16 5M FE, HWO, AA Qty 2 Casing head, CIW-WF, 13 5/8 3M X 13 3/8'’ threaded bottom, w/ 2- 2 1/16 5M EFO Valve, CIW-F, 2 1/16 5M FE, HWO, AA Valve, Upper Master, CIW-FC, 3 1/8 5M FE, HWO, EE trim Valve, Swab, CIW-FC, 3 1/8 5M FE, HWO, EE trim Valve, Master, CIW-FC, 3 1/8 5M FE, HWO, EE trim Valve, SSV, FC, 3 1/8 5M FE, w/ 15'’ Safeco oper-air operated Tubing hanger, CIW-DCB- FBB-CCL, 11 X 3 1/2 EUE lift and susp, w/ 3'’ type H BPV profile, 6 ¼ EN, 2- ½ npt CCL ports Adapter, CIW-EN-CCL, 11 5M Stdd x 3 1/8 5M, prepped for 6 ¼ EN and 2- ½ npt CCL ports, EE material Dolly Varden Platform D-07RD2 13 3/8 X 9 5/8 X 2 7/8 BHTA, Bowen, 3 1/8 5M FE X 3'’ Bowen Quick Union 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 DS A 3 X 2 DS A 3 X 2 20.40' 1.33' H i l c o r p A l a s k a , L L C Hi l c o r p A l a s k a , L L C Ch a n g e s t o A p p r o v e d R i g W o r k O v e r S u n d r y P r o c e d u r e Su b j e c t : C h a n g e s t o A p p r o v e d S u n d r y P r o c e d u r e f o r W e l l D - 0 7 R D 2 ( P T D 1 9 2 - 1 5 5 ) Su n d r y # : X X X - X X X An y m o d i f i c a t i o n s t o a n a p p r o v e d s u n d r y w i l l b e d o c u m e n t e d a n d a p p r o v e d b e l o w . C h a n g e s t o a n a p p r o v e d s u n d r y w i l l b e c o m m u n i c a te d t o t h e AO G C C b y t h e r i g w o r k o v e r ( R W O ) “ f i r s t c a l l ” e n g i n e e r . A O G C C w r i t t e n a p p r o v a l o f t h e c h a n g e i s r e q u i r e d b e f o r e i m p l e m e n t i n g t h e c h a n g e . Se c P a g e D a t e P r o c e d u r e C h a n g e N e w 4 0 3 Re q u i r e d ? Y / N HA K Pr e p a r e d By (I n i t i a l s ) HA K Ap p r o v e d By (I n i t i a l s ) AO G C C W r i t t e n Ap p r o v a l R e c e i v e d (P e r s o n a n d D a t e ) Ap p r o v a l : As s e t T e a m O p e r a t i o n s M a n a g e r D a t e Pr e p a r e d : Fi r s t C a l l O p e r a t i o n s E n g i n e e r D a t e 1 Davies, Stephen F (OGC) From:Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent:Wednesday, January 31, 2024 9:41 AM To:Davies, Stephen F (OGC) Cc:Juanita Lovett; Dewhurst, Andrew D (OGC); Matthew Petrowsky Subject:RE: [EXTERNAL] FW: TBU D-07RD2 (Permit 192-155, Sundry 324-034) - Question From our Geologist, MaƩ: TheDͲ07RD2wellboreisaHemlockBench1(HK1)lateralthatexitedfromtheDͲ07RDparentwellbore.Wedonothave anylogdatapertainingtothelateralitself.SinceitiswithintheHK1sandtherewouldn’tbetrueHK1toppick.Therefore, IamprovidingyouwiththeTopHemlockandTopMiddleKenai“G”OilPoolpicksintheparentwell(DͲ07RD)to supplementyourrequest.Pleasedon’thesitatetoreachoutifyouhaveanyquesƟons. Thanks. DͲ07RD TopMiddle“G”OilPool:11,420’MD/8,665’TVD TopHemlockOilPool:12,035’MD/9,176’TVD Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Wednesday, January 31, 2024 9:13 AM To: Ryan Rupert <Ryan.Rupert@hilcorp.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL] FW: TBU DͲ07RD2 (Permit 192Ͳ155, Sundry 324Ͳ034) Ͳ Question Hi Ryan, I’m reviewing the Sundry ApplicaƟon for TBU DͲ07RDs, and I’d like to keep the applicaƟon moving through AOGCC’s review process. I just want to remind you all that I need the items listed in my email, aƩached below, to conƟnue my porƟon of the review. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2 Thanks, Steve Davies AOGCC CONFIDENTIALITYNOTICE: This eͲmail message, including any aƩachments, contains informaƟon from the Alaska Oil and Gas ConservaƟon Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain conĮdenƟal and/or privileged informaƟon. The unauthorized review, use or disclosure of such informaƟon may violate state or federal law. If you are an unintended recipient of this eͲmail, please delete it, without Įrst saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907Ͳ793Ͳ1224 or steve.davies@alaska.gov From: Davies, Stephen F (OGC) Sent: Monday, January 29, 2024 1:40 PM To: Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: TBU DͲ07RD2 (Permit 192Ͳ155, Sundry 324Ͳ034) Ͳ Question Ryan, Could you please ask the project geologist to provide picks (in MD and TVD) for the top of the Hemlock and Middle Kenai G Oil Pools in TBU BͲ07RD2? Cheers and Be Well, Steve Davies AOGCC CONFIDENTIALITYNOTICE: This eͲmail message, including any aƩachments, contains informaƟon from the Alaska Oil and Gas ConservaƟon Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain conĮdenƟal and/or privileged informaƟon. The unauthorized review, use or disclosure of such informaƟon may violate state or federal law. If you are an unintended recipient of this eͲmail, please delete it, without Įrst saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907Ͳ793Ͳ1224 or steve.davies@alaska.gov 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. 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: 11/15/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231115 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PBU D-01A 50029200540100 197078 10/31/2023 HALLIBURTON RBT TBU D-07RD2 50733201170200 192155 11/5/2023 READ Caliper Survey TBU D-17RD 50733201680100 181023 11/5/2023 READ Caliper Survey TBU D-47 50733201950200 191011 11/4/2023 READ Caliper Survey Please include current contact information if different from above. T38136 T38137 T38138 T38139 11/21/2023 TBU D-07RD2 50733201170200 192155 11/5/2023 READ Caliper Survey Kayla Junke Digitally signed by Kayla Junke Date: 2023.11.21 10:31:56 -09'00' MEMORANDUM State• f Alaska Alaska Oil and Gas Conservation Commission TO: Jim Reggi171 DATE: December 15, 2015 P. I. Supervisor II FROM: Guy Cook SUBJECT: No Flow Test Petroleum Inspector Trading Bay Unit D-07RD2 Hilcorp Alaska LLC PTD 1921550 Tuesday, December 15, 2015: I witnessed the verification test for No Flow status on Hilcorp Alaska LLC's well TBU D-07RD2 onboard the Dolly Varden platform in the Cook Inlet. Jon Loomis had the proper test equipment rigged up correctly. The test equipment consisted of; • Erdco "Armor Flo" Gas meter, Serial #031189, range 180scf-1800scf. • SSI Digital Test Gage, Serial # 1506248074, Range 0-30 psi. Calibration certificates were on hand and copies are attached to this report. The well was open to atmosphere when I arrived and there was no discernable flow. I started the test at 12:00 pm. I observed the well during three shut-in/flow cycles each of. equal time periods. While the well pressured up to approximately the same pressure during throughout the test, the well exhibited quicker discharge of said build-up pressure in subsequent test periods. It should be noted the Inner Annulus and Tubing were tied in together during the test today. The following table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 12:00 0/0/20 0 0 Flowing to atmosphere 12:30 0.12/0/20 0 0 Shut-in 1:00 0/0/20 450 0 Open to Flow 1:30 0.11/0/20 0 0 Shut-in 2:00 0/0/20 450 - 0 Open to Flow 2:30 0.11/0/20 - 0 0 Shut-in 3:00 0/0/20 450 0 End Test - 1 Pressures are T/IA/OA Summary: This well exhibited inability to flow to surface unassisted. v Attachments: Test gauge calibration certifications (2) SCANNED 1)G ,/.2?6I5 2015-1215_2015-1215_No-Flow_TBU_D-07RD2_gc.docx Page 1 of 1 • u„oc_43 )-A. I Certificate This is to certify that this instrument has been calibrated for the fluid conditions specified on the purchase order and embossed on the nameplate. Measuring devices that are traceable to the United States National Institute for • Standards and Technology (NIST- formerly National Bureau of Standards) were used for this calibration. T chnicia D to Instrument Serial Number ERDCO Engineering Corporation 721 Custer Av ♦ Post Office Box 6318 Evanston, IL 60204-6318 USA 0 • • • 1 � v, uc_D CERTIFICATE bF CALIBRATION 41'4' d Part Name: Armor-Flo Meter Model Number: 3461=03T0-13 Serial Number: 031189 ERDCO Order#: 7216 Calibration Date: This is to certify that this instrument has been calibrated for the fluid conditions specified on the purchase order and embossed on the nameplate:: A/L /19/IS r echnician Date ERDCO® ERDCO Engineering Corporation 721 Custer Avenue,Evanston,IL 60202-2200 • tel 847.328.0550 • fax 847.328.3535 mail PO Box 6318,Evanston,IL 60204-6318 • email info@erdco.com , • 11 ' rr- P CALIBRATION C=RT11-71C1\7-- 12 L.,L.)r . Test Equipment Traceable. to NIST \,-;auce type: , Pressure range: C j - ratJei . ) , Date: e -AL\ - TEST PRESSURE INDICATION 1-7 I ) ..1 -7) '';-7.; . ; • ) C; C;) , Cbrated - f _ Test equipment SIN: - — T This cerffcate expires in 90-days on . For recertification, contact Gina Bogart or Cathy Marshal! at KGF 776-6825. i i OF 'Tic \\ 11/7:' THE STATE Alaska Oil and Gas of T a sConservation Commission 6. 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 -�7TV pF nir .6, Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov December 21, 2015 Mr. Stan Golis Operations Manager—CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification Trading Bay Unit D-07RD2 PTD 1921550 SCANNED Dear Mr. Golis: On December 15, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit D-07RD2 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-07RD2 prior to the test. The well performance was monitored for three hours with alternating shut in and open flow periods. The resulting gas flow rate at the end of each flow monitoring period was below the regulatory limit; no liquids were produced during the test. The passing no-flow test means TBU D-07RD2 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-07RD2 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 cc: P. Brooks AOGCC Inspectors STATE OF ALASKA AlKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon 0 Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casin30 Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ Re-enter Susp WdI❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 192-155 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphi:❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20117-02 7.Property Designation(Lease Number): 8.Well Name and Number: RECEIVED ADL0017594 Trading Bay Unit/D-07RD2 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): DEC 14 ZUib N/A McArthur River Field/Hemlock Oil Pool 11.Present Well Condition Summary: AOGCC Total Depth measured 12,438 feet Plugs measured N/A feet true vertical 9,227 feet Junk measured N/A feet Effective Depth measured 12,438 feet Packer measured 11,921 feet true vertical 9,227 feet true vertical 9,101 feet Casing Length Size MD TVD Burst Collapse Conductor 398' 33" 398' 398' Surface 1,401' 13-3/8" 1,401' 1,378' 6,380 psi 2,670 psi Intermediate 9,665' 9-5/8" 9,665' 7,182' 5,750 psi 3,090 psi Liner 3,679' 7" 12,912' 9,159' ' 7,240 psi 5,410 psi Liner 39' 3-1/2" 11,959' 9,132' Liner 27' 3-1/2" 11,986' 9,155' Liner 408' 3-1/2" 12,394' 9,229' Perforation depth Measured depth 11,959-12,394 feet (perforated/slotted liner) C Wt :t 0 .�: True Vertical depth 9,132-9,229 feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/N-80 11,721'(MD) 8,935'(TVD) Packers and SSSV(type,measured and true vertical depth) SC-1R Packer 11,921'(MD)9,101'(ND) SSSV:N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): 11,959-12,394 Treatment descriptions including volumes used and final pressure: First Batch-330 gallons WAW-5206/660 gallon Xylene Preflush. 1500 gallons 10%Hydrochloric Acid.583 bbls FIW displacement.Final Pressure 1315 psi @ 0.85 bpm. Second Batch-825 gallons of 15%Hydrochloric Acid,75 BBL of FIW.Final pressure 900 psi @ 0.48 bpm. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 52 16 339 120 120 Subsequent to operation 32 11 256 120 120 14.Attachments(required per 20 MC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ID Exploratory❑ Development] Service❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDGPL❑ 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: 315-608 - Contact Dan Marlowe Email dmarloweCa hilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature ` LU 4 Phone (907)777-8356 Date 1 Z /114 I I S Form 10 101 Reviced0. /20�z _2c -('5 RBDMS L`�� 12015 9 Only Submit Ori rn�l �, L– , /4-'/��if— • Trading Bay Unit SCHEMATIC Well: D-07RD2 Hilcorp Alaska,LLC Completed: 04/22/14 CASING DETAIL All Measurements are RKB to Top of SIZE WT GRADE CONN MIN TOP BTD TYPE Equipment. RKB:43.80' L13-3/8" 61 J-55 BTC 12.515 Surface 1,401' 40 N-80 BTC 8.835 Surface 5,761' 9-5/8" 43.5 N-80 BTC 8.755 5,763' 7,919' 33 47 N-80 BTC 8.681 7,919' 9,665' 7" 29 N-80 LTC 6.184 9,226' 12,912' X-Line 9.3 L-80 Hydril 2.992 11,920' 11,959' 3-1/2" 9.3 L-80 Hydril 2.992 11,959' 11,986' Perforated 9.3 L-80 Hydril 2.992 11,986' 12,394' Slotted TUBING DETAIL 13-3/84 ` 2-7/8" 6.5 N-80 8rd EUE 2.441 Surface 11,721' DV Collar from 5,761'to 5,763'in 9-5/8"Casing JEWELRY DETAIL No Depth ID Item (MD) 1 CIW Tbg Hanger 10"Nom."DCB" 2 11,721' Bolt-On Discharge 3 11,723" Pump(x2)400 Series,144 Stage,SF1000 4 11,766' Intake 5 11,785' Motor-456 Series 6 11,820' Bottom of ESP 9-5/8" 7 11,920' Baker 80-40 Locator 8 11,921' Baker"SC-1R"Packer Size 70-40,Baker Seal Bore Ext. 9 11,937' Baker Mill-out Ext. 2 10 11,942' Baker Knock-out Isolation Valve 3 11 11,945' Baker Rotationally Locked Safety Joint 4 12 11,958' Otis"X"Nipple(2.81 Profile) it 5 13 12,424' Baker Pack-off Bushing 6 14 12,435' Baker"V"Float Shoe 7 8 9 Tubing punch holes 10 NOTE:X-Lock (No Packing)and perforated Catcher Sub(2.73" 11,935'-11,941' O.D., 24"TOL left in X-Nipple at 11,958'TM (11,986'WLM) 11 12 Hemlock Bench 1 Horizontal-1993 13 343'Horizontal (12,095'- Displacement 12,438'MD) 14 6" Open Hole TD = 12,438' TVD = 9,227' Revised By: 1 LL OS/22/14 • • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-07RD2 Pumping 50-733-20117-02 192-155 11/2/15 11/29/15 Daily Operations: 11/02/2015- Monday Safety Meeting. Rig up to well, pressure test to 500 Low/2000 High. Pump preflush -330 gallons WAW-5206/660 gallon Xylene mix.Tubing- 33 psi, 9-5/8-45 psi, 13-3/8 34 psi. Pump 35 bbls 10% HCL Acid. Displace with 583 bbls FIW, stopping to let pressure bleed down multiple times. Max Pressure 1600 psi. Final Pressure 1315 psi @ 0.85 bpm. Shut In well to soak overnight. Returned to production. 11/29/2015-Sunday Safety meeting. Rig up to well. Pressure tested 500 L- 2000 H. Pumped 10 barrels FIW taking returns out the IA to test v pump and well.Tubing-820, 9-5/8-309, 13-3/8 -48, BPM - .41. Pumped 18 bbl of 15%acid into the i—Pumped 40 BBL of FIW then closed 9-5/8 casing vent. Pumped 35 BBL of FIW to spot the acid. Tubing-900, 9-5/8-206, 13-3/8- 48, BPM .48. Completed job and rigged down.Acid soak. Return to production @ 20:00. OF Tk • �\I%%%s� THE STATE Alaska Oil and Gas of/� Ta Oil anConservation Commission s - 2_ _ = 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 110Z� �'M Main: 907.279.1433 ®F ALAS Fax: 907.276.7542 www.aogcc.alaska.gov fb} '22A 2A Dan Marlowes*S Operations Engineer 1 — I55- Hilcorp Alaska, LLC ., 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil Pool, TBU D-07RD2 Sundry Number: 315-608 Dear Mr. Marlowe: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster / Chair DATED this `1'"day of October, 2015 Encl. C C1 " 1° • • RECEIVED STATE OF ALASKA SEP 2 5 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION G)T5 to 4 g CS APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate 2(Acid) Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC ' Exploratory ❑ Development E 192-155- 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic E] Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20117-02 . 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 / Trading Bay Unit/D-07RD2 - 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL0017594 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): 12,438 • 9,227 12,438 • 9,227 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 398' 33" 398' 398' Surface 1,401' 13-3/8" 1,401' 1,378' 6,380 psi 2,670 psi Intermediate 9,665' 9-5/8" 9,665' 7,182' 5,750 psi 3,090 psi Liner 3,679' 7" 12,912' 9,159' 7,240 psi 5,410 psi Liner 39' 3-1/2" 11,959' 9,132' Liner 27' 3-1/2" 11,986' 9,155' Liner 408' 3-1/2" 12,394' 9,229' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A 2-7/8" 6.5#/N-80 1 1,721 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker SC-1R Pkr&N/A ' 11,921'(MD)9,101'(TVD)&N/A 12.Attachments: Description Summary of Proposal 2 13.Well Class after proposed work: Detailed Operations Program Cl BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ nvelopmenl L , Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 10/12/2015 Commencing Operations: OIL El - WINJ ❑ WDSP❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOE SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe(@hilcorp.com Printed Name Dan Marlowe Title O errations Engineer Signature ! . "t':•-•z2/"' P� r j / 2 T329 Date 9/25/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 316 - G,o Plug Integrity CIBOP Test EllMechanical Integrity Test 111Location Clearance CI Other: Spacing Exception Required? Yes Li No 4l Subsequent Form Required: fr.,t — (,.`>'/ PAPPROVED BY / Approved by: '� COMMISSIONER THE COMMISSION Date:/S— 9— / 1)K6 1 d !S �,j� l 32015 3. 0CI ORIGINAL. Ri3nM . Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • •14 • • Well Work Plan Well: D-07rd2 Hilcorp Alaska,LL Date:09/24/2015 Well Name: D-07rd2 API Number: 50-733-20117-02 Current Status: ESP Lifted Producer Leg: A-2 (NW Corner) Estimated Start Date: 10/12/15 Rig: N/A Reg. Approval Req'd? Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 192-155 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Current Bottom Hole Pressure: 2,700 psi @ 9,000' TVD ESP Intake Gauge SIBHP Maximum Expected BHP: 4,700 psi @ 9,000' TVD Well SIBP of 2,700 psi plus 2000 psi pump pressure. Max. Anticipated Surface Pressure: 2,000 psi treatment pump pressure limit Well Summary The D-07rd2 is an oil well producer which is currently on ESP artificial lift. Total fluid production from this well has declined since the April 2014 work over. This decrease is believed to have been caused by a combination of organic and inorganic deposits in the liner and near wellbore. Well Objective Hilcorp plans to pump a combo solvent acid wash down the production tubing and across the perforations to clean up any deposition. 7/Lt. o5 Procedure: a or? F ? 1. MIRU pumping equipment. 2. Shut down ESP. 3. Pressure test surface lines to 2,000 psi (treatment pump relief valve limit). 4. Mix chemicals and pump in the following sequence: a. Open back side, pump FIW down tubing taking returns up the annulus. b. Pump 990 gallons of pre-flush (330 gallons WAW-5206 mutual solvent blended with 660 gallons of Xylene. 5 c. Pump +/- 1,500 gallons of ±10% Hydrochloric Acid d. Pump >_75 barrels of FIW for displacement. closing the 9-5/8" casing return line after the first 20 bbls and bullhead the chemical pills across the perfs 5. Shut down pump and let soak for >_6 hours. 6. RD Pumping equipment. 7. Return well to production. 8. Schedule a No-Flow test within 14 days of stable production. 2U 2.3 — A-,,� 34, Attachments: 1. As-built Schematic • • Trading Bay Unit SCHEMATIC Well: D-07RD2 HiS rp-ala4a•1,11. Completed: 04/22/14 CASING DETAIL M All Measurements are RKB to Top of SIZE WT GRADE CONN MIN TOP BT TYPE Equipment. RKB: 43.80' 13-3/8" 61 J-55 BTC 12.515 Surface 1,401' 40 N-80 9 5/8" 43.5 N 80 BTC 8.835 Surface 5,761' BTC 8.755 5,763' 7,919' 3 3„ 47 N-80 BTC 8.681 7,919' 9,665' 7" 29 N-80 LTC 6.184 9,226' 12,912' X-Line 9.3 L-80 Hydril 2.992 11,920' 11,959' 3-1/2" 9.3 L-80 Hydril 2.992 11,959' 11,986' Perforated 9.3 L-80 Hydril 2.992 11,986' 12,394' Slotted TUBING DETAIL 2-7/8" 6.5 N-80 8rd EUE 2.441 Surface 11,721' 13-3/8A \ DV Collar from 5,761'to 5,763' in 9-5/8"Casing JEWELRY DETAIL No �M�) ID Item 1 CIW Tbg Hanger 10"Nom."DCB" 2 11,721' Bolt-On Discharge 3 11,723" Pump(x2)400 Series,144 Stage,SF1000 4 11,766' Intake 5 11,785' Motor-456 Series 6 11,820' Bottom of ESP 9-5/8" 7 11,920' Baker 80-40 Locator 8 11,921' Baker"SC-1R"Packer Size 70-40,Baker Seal Bore Ext. 9 11,937' Baker Mill-out Ext. 2 10 11,942' Baker Knock-out Isolation Valve 3 11 11,945' Baker Rotationally Locked Safety Joint 4 12 _ 11,958' Otis"X"Nipple(2.81 Profile) 5 13 12,424' Baker Pack-off Bushing \ 1_1 14 12,435' Baker"V"Float Shoe 6 8 79 Tubing punch holes _, o. 10 X-Lock (No Packing)and perforated Catcher Sub(2.73" 11,935'-11,941 O.D., 24"TOL left in X-Nipple at 11,958'TM (11,986' WLM) 11 12 Hemlock Bench 1 Horizontal-1993 13 343 Horizontal D lspl a,ement (12,095'-12438'MD) 14 6" Open Hole TD = 12,438' TVD = 9,227' Revised By: ..ILL 05/22/14 XHVZE Pages NOT Scanned in this. Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. PAGES TO DELETE Complete RESCAN - Color items'- Pages: Grayscale, halftones, pictures, graphs, charts- Pages: ' Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED .~ Logs 'of various kinds [] Other COMMENTS: Scanned. by: Bevedy Dian~athan I"'owell [] TO RE-SCAN Notes: Isl Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: STATE OF ALASKA ALA_ A OIL AND GAS CONSERVATION COMM ,ION REPORT OF SUNDRY WELL OPERATIONS • 1.Operations Abandon❑ Repair Well El Plug Perforations ❑ Perforate❑ Other❑s Run ESP Performed: Alter Casing❑ Pull Tubing Stimulate-Frac El Waiver❑ Time Extension❑ Change Approved Program❑ Operat.Shutdown❑ Stimulate-Other 0 Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development Q Exploratory❑ 192-155 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service 0 6.API Number: Anchorage, AK 99503 50-733-20117-02 7.Property Designation(Lease Number): 8.Well Name and 0.Number: - L ADL0017594 Trading Bay Unit/D-07RD2 ! (.� , ', D 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): McArthur River Field/Hemlock Oil Pool ‘1,i ,' 2 L' 2i-_,,,4 11.Present Well Condition Summary: AOGCC Total Depth measured 12,438 feet Plugs measured None feet true vertical 9,227 feet Junk measured None feet Effective Depth measured 12,438 feet Packer measured 11,921 feet true vertical 9,227 feet true vertical 9,101 feet Casing Length Size MD TVD Burst Collapse Conductor 398' 33" 398' 398' Surface 1,401' 13-3/8" 1,401' 1,378' 6,380 psi 2,670 psi Intermediate 9,665' 9-5/8" 9,665' 7,182' 5,750 psi 3,090 psi Liner 3,679' 7" 12,912' 9,159' 7,240 psi 5,410 psi Liner 39' 3-1/2" 11,959' 9,132' Liner 27' 3-1/2" 11,986' 9,155' Liner 408' 3-1/2" 12,394' 9,229' Perforation depth Measured depth N/A feet SCANNED J U i 3. 4 2.014 True Vertical depth N/A feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/N-80 11,721'(MD) 8,935'(ND) Packers and SSSV(type,measured and true vertical depth) Baker SC-1R Pkr 11,921'(MD) 9,101'(TVD) SSSV-N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): Slotted liner from 11,959'-12,394' Treatment descriptions including volumes used and final pressure: 55 gallons of Baker Petrolite WAW-5206(Mutual Solvent),330 gallons Xylene,and 550 gallons of 7.5%Hydrochloric Acid;Displaced with 165 bbls FIW Final Pressure Opsi at surface 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 86 65 416 1200 192 Subsequent to operation: 136 44 581 102 109 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Service ❑ Stratigraphic 0 Daily Report of Well Operations X 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ GSTOR ❑ WINJ El WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-147 Contact Dan Marlowe Email dmarlowe(c�hilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signature �� k, !//1,‘/ Mit . ` Phone (907)283-1329 Date 5/22/2014 F_. . .I: ---,. -d1O/20x7 I,.. • .11 1 • 1Y ii- c 3,`� ,,C 4./.07 'RIMS MAY 2 3 2ax Trading Bay Unit SCHEMATIC Well: D-07RD2 -HJmrp Alaska,LLC Completed: 04/22/14 CASING DETAIL All Measurements are RKB to Top of SIZE WT GRADE CONN MIN TOP (MM TYPE Equipment. RKB: 43.80' I1 13-3/8" 61 J-55 BTC 12.515 Surface 1,401' 40 N 80 BTC 8.835 Surface 5,761' 9 5/8" 43.5 N 80 BTC 8.755 5,763' 7,919' 3 s" L 47 N-80 BTC 8.681 7,919' 9,665' 7" 29 N-80 LTC 6.184 9,226' 12,912' X-Line 9.3 L-80 Hydril 2.992 11,920' 11,959' 3-1/2" 9.3 L-80 Hydril 2.992 11,959' 11,986' Perforated 9.3 L-80 Hydril 2.992 11,986' 12,394' Slotted TUBING DETAIL 13-3/8te 2-7/8" 6.5 N-80 8rd EUE 2.441 Surface 11,721' . DV Collar from 5,761'to 5,763'in 9-5/8"Casing ' JEWELRY DETAIL No Depth ID Item (MD) 1 CIW Tbg Hanger 10"Nom."DCB" 2 11,721' Bolt-On Discharge 3 11,723" Pump(x2)400 Series,144 Stage,SF1000 4 11,766' Intake 5 11,785' Motor-456 Series 6 11,820' Bottom of ESP 9-5/8" 7 11,920' _ Baker 80-40 Locator 8 11,921' Baker"SC-1R"Packer Size 70-40,Baker Seal Bore Ext. 9 11,937' Baker Mill-out Ext. - 2 10 11,942' Baker Knock-out Isolation Valve 11 11,945' Baker Rotationally Locked Safety Joint 4 12 11,958' Otis"X"Nipple(2.81 Profile) 5 13 12,424' Baker Pack-off Bushing 6 14 12,435' Baker"V"Float Shoe 7 8 9 Tubing punch holes 1 : 10 NOTE:X-Lock (No Packing)and perforated Catcher Sub(2.73" ,A1411,935'-11,941' a r *, n "�,. O.D.,24 TOL left in X-Nipple at 11,958 TM (11,986 WLM) 11 ; 12 Hemlock Bench 1 Horizontal-1993 13 343'Horizontal Displacement (12,095'-12,438'MD) 14 6" Open Hole TD = 12,438' TVD = 9,227' Revised By: JLL 05/22/14 Hilcorp Alaska, LLC Iiikcorp AIat ka,1.1,C Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-07RD2 50-733-20117-02 192-155 4/5/2014 4/22/2014 N s- 04/05/14-Saturday Pre-job safety meeting. Pressure tested portable pump 250 L/2000 H (OK).Lined to well clean tank and pumped 250 BBLS of FIW dow tubing displacing gas from annulus,caught returns @ 20:00 then pumped 25 more barrels to displace the hydrocarbon.Mixed 55 gallons of WAW-5206,1 tote of Xylene and two totes of 7.5 acid. Pumped chemical in tubing followed by 5 BBLS FIW to clear pump and lines. LINE UP Rig Pump AND PUMP DOWN TUBING WITH 140 BBLS OF FIW @ 1.6 BPM W/900 PSI displacing acid into slotted liner,acid soak for 6 hours. Line up and pump 20 BBLS OF FIW @ 1.5 BPM-0-PSI displacing acid from slotted liner into formation. 04/06/14-Sunday No operations. 04/07/14.Monday No operations. 04/08/14-Tuesday No operations. 04/09/14-Wednesday RIGGING UP. 04/10/14-Thursday R/U SLICK LINE UNIT&LUBRICATOR.M/U 2.75"GAUGE RING.TEST LUBRICATOR TO 2000 PSI.RIH W/S-LINE TO 11,941'SLM.POOH W/S-LINE AND RIG DOWN SAME. R/U 2.50"OD 6 SPF GUN ON E-LINE.RIH W SAME AND PERFORATED FROM 11,935'TO 11,941'. POOH AND RIG DOWN E-LINE. R/U SLICKLINE AND RIH WITH TBG STOP AND SET SAME AT 11,900'SLM&POOH. P/U 3"P/0 PLUG& RIH W/SAME TO 11,898'SLM.SET PLUG&POOH. R/D SLICK-LINE EQUIP.FILLED HOLE WITH 385 BBLS.RIG UP AND ATTEMPTED TO TEST TBG AND CSG TO 500 PSI W/O SUCCESS. CASING AND TBG ON VACUUM. 04/11/14-Friday INSTALLED BPV N/D PRODUCTION TREE AND L/0 SAME. N/U 11"5M RISERS,BOP'S,ANNULAR,CONNECT KOOMEY LINES,WING VALVES,PU TEST JT SCREW SAME INTO HGR. RU TESTING EQUIPMENT. TEST BOP'S,RAMS ANNULAR,LINES,MANIFOLDS AND SAFETY VALVES WITH 4-1/2" &3-1/2"TBG TO 250 PSI LOW 2500 PSI HIGH FOR 5 MIS ON CHART.WITNESS WAIVED BY JIM REGG @ 8:42 PM,4/08/2014.ATTEMPTED TO BACK 4-1/2" LANDING JT FROM HGR AND CONNECTION AT PUP JT ABOVE HGR BROKE BEFORE CROSSOVER IN HGR BROKE.MADE SEVERAL ATTEMPT TO BREAKOUT CROSSOVER AT HGR W/O SUCCESS.CONNECTION AT PUP JT KEPT BREAKING FIRST.BROKE 11" RISER ABOVE WELL HEAD BACKED OUT PUP AND X-OVER. TEST BREAK AND BLINDS TO 250 LOW 2500 PSI HIGH FOR 5 MINS ON CHART.PULL 2 WAY CHECK.PU/MU 3-1/2"LANDING JT TO HGR.BACK OUT HANGER HOLD DOWN PINS. 04/12/14--Saturday 1, CiAN PI P/U TO 182K(20K OVER AND SET SLIPS).R/U E-LINE UNIT AND EQUIPMENT.RE-HEAD E-LINE.M/U 2.125"CHEMICAL CUTTER.TEST LUBRICATOR TO 1500 PSI.RIH W/E-LINE. NO SUCCESS.E-LINE WIRE JUMPED OUT OF SHEAVE.L/D CHEMICAL CUTTER AND RE-HEAD E-LINE.M/U CHEMICAL CUTTER ON E-LINE AND RIH W/SAME. CORRELATE CUTTER ON DEPTH&FIRE CUTTER.CUT 4-1/2" PRODUCTION TBG @11,875'ELM.POOH AND R/D E-LINE.LATCH LANDING JT AND P/U ON TBG.TBG FREE.PIPE WT=148k,FINISH R/D E-LINE EQUIPMENT AND UNIT. PULL HGR TO RIG FLOOR.TERMINATE CTRL LINE FROM HGR TO SCSSV. BREAK OUT HGR AND LANDING JT,LAY DOWN SAME.FILLED HOLE WITH 100 BBLS. CONT TO POOH W/4-1/2"PROD TBG AND LAYING DOWN SAME IN V- DOOR.CONT TO POOH W/4-1/2" PROD TBG.ATTEMPTED TO B/O JNT W/TONGS BUT BACK-UPS WERE SLIPPING.SWAPPED TO BPS AND CONT TO POOH.PUMPED 45 BBLS AND WELL BEGAN TO U-TUBE.R/U CIRC EQUIP AND PUMPED 290 BBLS OF FIW DOWN TBG 1- 1/2 BPM W/50 PSI.R/D CIRC EQUIP AND CONT TO POOH W/4-1/2"PROD TBG. 04/13/14-Sunday CONT DISPL.WELL(1)HOLE VOL W/8.5#PPG FIW @ 2 BPM 60 PSI TAKING RETURNS THRU CHOKE.TOTAL PUMPED=677 BBLS. MONITORED WELL PRESSURES-0 PRESSURE OR FLOW ON CASING OR TBG. CIRCULATE 8.7 PPG FLUID AROUND HOLDING 200 PSI ON CHOKE.MONITORED WELL(STATIC).R/D CIRCULATING LINES,POOH WITH 5 JTS PRODUCTION TBG.PIPE PULLED WET.MIXED AND PUMPED 8.9 PPG SLUG. CONTINUED OUT OF HOLE L/0 TBG AND CLEANING SAME.PIPE DRAGGING 5 TO&6K OVER P/U WT.AT 9,632'HAD TO PULL 10K TO GET PIPE THRU TIGHT SPOT. Hilcorp Alaska, LLC Hilcorp Alaska,LL(: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-07RD2 50-733-20117-02 192-155 4/5/2014 4/22/2014 04/14/x.4-Monday �6 MONITOR WELL WHILE SERVICE RIG AND SAFETY CHECK. CONT POOH W/4-1/2"&3-1/2" PROD TBG&GLM's.RECOVERED 283 JTS 4- 1/2"IBT TBG.(6)4-1/2"GLM'S,89 JTS OF 3-1/2"8 RD TBG.(4)3-1/2 GLM'S, 1-CUT JT OF 3-1/2"TBG---TOTAL LENGTH=11,850'. R/D HYDRALIC TONGS.CLEAN/CLEAR RIG FLOOR.DRESSED TONGS FOR 3-1/2"DP&R/U&TESTED SAME.PREP TO P/U BHA. P/U&M/U 9.625"SCRAPER ASSY&RIH WITH SAME.BHA=8-1/2"OD JUNK MILL,CASING SCRAPER,HYD JARS 3-1/2"PH-6 BOX X 3-1/2 IF PIN X- OVER,3-1/2"PH-6 PUP JT.TOTAL BHA=30.54'.CONT TO TIH W/3-1/2"PH6&SCRAPER BHA TO 9,218'DPM,TAGGED LINER.P/U TO 9,210'. RU LINES-LINE UP PUMP AND REVERSE OUT AT 3-1/2 BPM 300 PSI. 04/15/14-Tuesday CONT.REV/OUT 1-1/2 TBG VOLUMES AT 3-1/2 BPM 600 PSI.TOTAL PUMPED=100 BBLS.R/D CIRC.EQUIPMENT.MONITOR WELL "WELL STATIC". POOH W/3-1/2"PH6 AND 9-5/8"SCRAPER ASSY.BREAK DOWN&LAY DOWN SCRAPER ASSY.WASH&CLEAN RIG FLOOR. P/U&M/U 7"MILL&7"SCRAPER BHA -6.151"OD BLADED JUNK MILL, 7"CSG SCRAPER,BIT SUB,OIL JAR,3.50"PH-6 BOX X 3.50"IF PIN X-OVER,3-1/2"PH-6 PUP.TOTAL LENGTH=30.37'.TIH W/3-1/2"PH6 AND 7"SCRAPER ASSY.TAGGED TOL @ 9,227' DPM.ATTEMPT TO GO THRU W/NO SUCCESS.SET 10K DOWN&TOOK 25K OVERPULL TO PULL FREE. R/U CIRCULATING EQUIP&L/U AND DISPLACE WELL W/CLEAN 8.7 PPG FIW.SEND RETURNS TO TRADING BAY. PUMP A TOTAL OF 732 BBLS,FLOW CHECKED WELL (STATIC).R/D CIRC EQUIP.&PREP TO POOH. POOH WITH 7"SCRAPER ASSY. 04/16114-Wednesday 1111111''' r= SERVICE RIG AND CONT POOH W/3-1/2"PH6 AND 7"MILL ASSY.BREAK DOWN AND LAYDOWN 7"MILL ASSY.WASH AND CLEAN RIG FLOOR AND PREP SAME TO TIH.STRAP AND CALIPER 6"MILL ASSY.MAKE UP SAME.BHA=5.8125 BLADED MILL,BIT SUB,5.969 OD STRING MILL,BOWEN BUMPER JAR,OIL JAR,3-1/2"PH-6 BOX X 3-1/2"IF PIN X-OVER,3-1/2"PH-6 PUP,TOTAL LENGTH=37.94'. TIH W/3-1/2"PH6,5-13/16"MILL AND 5.969" STRING MILL ASSY TO 10,160'DPM.P/U 3-1/2"PH6 OUT OF V-DOOR AND CONT TIH. STRAP AND RABBIT SAME.TAG TBG STUMP W/5K DWN @ 11,876'DPM.L/D(1)JNT&SWAPPED ELEVATORS. P/U POWER SWIVEL &R/U SAME.L/U TO REVERSE CIRCULATE.REVERSE CIRC 340 BBLS OF 8.7 PPG FIW UNTIL RETURNS CLEAN AND FREE OF SOLIDS. CIRCULATE WELL WITH 8.7 PPG FIW TREATING SAME W/CFS-520 @ 3 BPM W/500 PSI. R/D POWER SWIVEL. POOH WITH 3-1/2" WORK STRING AND 7"CLEAN OUT ASSY. 04/17/14-Thursday ,te " , Continue POOH with 7"casing scraper,B/0&L/0 same. Clean rig floor and repair tbg tongs. P/U&M/U 7"test packer&RIH with same to 11,875'and test csg.to 1500 psi on chart for 30 min on chart.Test ok. R/D test equipment and POOH with test packer. B/O &L/O 7"test packer. 04/18/14-Friday SERVICE RIG AND M/U BHA#4- 5.96"BURNING SHOE,2 JTS OF 5-3/4"OD WASHPIPE,(2)-4-3/4"DRILL COLLARS,4-3/4"HYD JAR,X- OVER 3-1/2"PH 6 BOX X 3-1/2"IF PIN,TOTAL BHA=157.50'. TIH W/3-1/2" PH6 AND WASH PIPE ASSY.TAG TOP OF FISH @ 11,876' DPM.ATTEMPTED TO WORK OVER TOP OF FISH,"NO SUCCESS".P/U AND R/U POWER SWIVEL.BREAK CIRCULATION. ROTATE OVER FISH&WASH F/11,876'TO 11,920',TAGGED TOP OF PACKER.PUMPING 3 BPM 500 PSI,REVERSE OUT 2 TBG VOLUMES PUMPING 3 BPM 500 PSI.R/D POWER SWIVEL&L/O SAME.POOH W/3-1/2"PH6&BHA#4 W/P ASSY.B/O&L/0 BHA#4&P/U BHA#5-5-3/4" OVERSHOT WITH 3-1/2"BASKET GRAPPLE,4-3/4" BUMPER AND OIL JAR,(2)4-3/4"DRILL COLLARS,3-1/2"PH-6 BOX X 3-1/2"IF PIN X- OVER.TOTAL LENGTH =96.64'. RIH WITH 3-1/2"PH-6 WORK STRING AND BHA#5. 04/19/14-Saturday SERVICE RIG AND SAFETY CHECK.CONT TIH W/3-1/2"PH6 AND OS BHA TO 11,866'DPM. M/U KELLY JT.&CONT.TIH.TAG TOP OF FISH @ 11,875'DPM.LATCH FISH,SET 10K DOWN,P/U TO 180K(50K OVER PU=130K)ATTEMPT TO PULL FISH FREE,NO SUCCESS. COCK JARS AND PICK UP TO 180K AND ATTEMPT TO JAR FISH FREE,PULLING UP TO 200K(70K)OVER AFTER JARS HITTING.PULLED UP TO 240K(IN 10K INCREMENTS),FISH CAME FREE.MONITOR WELL.WELL INITIALLY TOOK 70 BBLS.CUT BACK MUD WEIGHT IN PITS TO 8.5#FIW. POOH SLOW W/3-1/2"PH6,0/S BHA AND FISH.Recovered(1)cut jt 11.14',(1)jt 31.55'(1)pup 4.22',Locator seal assy 9.51' total=56.42'.TEST 11"X 5M BOPS,ANNULAR, SURFACE EQUIP,AND SAFETY VALVES TO 250 LOW/2500 HIGH ON CHART FOR 5 MIN EACH TEST.PERFORMED KOOMEY DRAW DOWN TEST.WITNESS OF TEST WAIVED BY LOU GRIMALDI ON 4/18/14 @ 11:14 AM. R/D TEST EQUIP,L/D TEST ASSY.TOTAL FLUID LOSS=220 BBLS. Hilcorp Alaska, LLC IliIcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-07RD2 50-733-20117-02 192-155 4/5/2014 4/22/2014 uw 04/20/14-Sunday FINISH RID BOP TESTING EQUIP AND CLEAN RIG FLOOR.SERVICE RIG AND SAFETY COMPLIANCE CHECK.HELD PJSM W/ESSENTIAL PERSONNEL ON RIGGING UP AND RUNNING ESP PUMP.RUN FLAT PACK AND ELECTRICAL CABLE THRU SHEAVES AND HANG SAME IN DERRICK.M/U 4"PUMP ASSY. MAKE SPLICE ON ELECTRICAL CABLE TO PUMP. M/U(2)CONTROL LINES,FILL PUMP W/OIL AND INSTALL TBG CROSSOVER.TIH W/2-7/8"PROD TBG&ESP.DRIFTING EACH JT IN V-DOOR.TESTING CONTROL LINES&POWER CORD EVERY 1000'.CONT'TO TIH W/2-7/8"PROD TBG&ESP.DIRFTING EACH 1T IN V-DOOR&TESTING LINES&WIRE EVERY 1000'. DEPTH @ 06:00=3,000'.FLUID LOST TO FORMATION=120 bbls.TOTAL FLUID LOST TO FORMATION=240 BBLS. 04/21/14-Monday CONT TIH W/2-7/8" PROD TBG AND ESP PUMP INSTALLING CANON CLAMPS ON EVERY OTHER JT.&CHECKING CONTINUITY EVERY 1000'. STRAP AND RABBIT SAME.(DEPTH=3,978'). MAKE SPLICE IN ELECTRICAL CABLE TO NEW SPOOL&TEST SAME(OK).CONT TIH W/2-7/8"PROD TBG AND ESP PUMP INSTALLING CANON CLAMPS ON EVERY OTHER JT.&CHECKING CONTINUITY EVERY 1000'. STRAP AND RABBIT SAME. SERVICE RIG&SAFETY COMPLIANCE CHECK. CONT TIH W/2-7/8"PROD TBG AND ESP PUMP INSTALLING CANON CLAMPS ON EVERY OTHER JT.&CHECKING CONTINUITY EVERY 1000'.STRAP AND RABBIT SAME.(DEPTH=7,664'). MAKE SPLICE IN ELECTRICAL CABLE TO NEW SPOOL&TEST SAME(OK). CONT TIH W/2-7/8"PROD TBG AND ESP PUMP INSTALLING CANON CLAMPS ON EVERY OTHER JT.&CHECKING CONTINUITY EVERY 1000'. STRAP AND RABBIT SAME. DEPTH @ 06:00=10,400'.FLUID LOST TO FORMATION=140 BBLS.TOTAL FLUID LOST=380 BBLS. 04/22/14-Tuesday SERVICE RIG&SAFETY COMPLIANCE CHECK.CONT TIH W/2-7/8"PROD TBG AND ESP PUMP.INSTALLING CANON CLAMPS ON EVERY OTHER JT.&CHECKING CONTINUITY EVERY 1000'.STRAP AND RABBIT SAME.(DEPTH 11,775')M/U HGR AND LANDING JT.INSTALL ELECTRICAL PLUG,SPLICE ELECTRICAL CABLE TO SAME AND INSTALL IN HGR.AND TEST SAME(OK).INSTALL AND M/U(2)1/4"CTRL LINES TO HGR,LAND HGR.(END OF ESP PUMP ASSY @ 11,820').RUN IN HGR PINS,TEST VOID TO 5000 PSI FOR 15 MIN(OK). BACK OUT LND JNT&L/D SAME.PULLED ESP TEST CABLE&CLEAR OFF RIG FLOOR.REMOVED HANDRAILS&POLLUTION PANS.PULLED FLOOR PLATE&BEAMS.N/D 11"X 5M BOPS,SPACER SPOOLS,RISER,&WING VALVES.N/U PROD TREE AND TEST SAME.R/D MISC EQUIP TO PREP TO SKID RIG TO D-15RD2.FLUID LOST TO FORMATION=120 BBLS.TOTAL FLUID LOST=500 BBLS. L ®g �R1 n 7 r-, f/.4r_ of 1i v� ; T7'" A. C �`` 9 = AS _� — 333 West Seventh Avenue , GOVERNOR SEAN PAR�,I;LIAnchorage, Alaska 99501-3572 :, . :;1 a4t' '' Main: 907 279 1433 (2,14 �ASS Fax: 907.276.7542 Ep �U� 222.014: S5Dan Marlowe SCA Operations Engineer I � Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil Pool, Trading Bay Unit D-07RD2 Sundry Number: 314-147 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, ll_(,)i_, / 1,27e1,1i/,___ Cathy P. Foerster Chair DATED this 1 7 day of March, 2014. Encl. ` s STATE OF ALASKA " ALASKA OIL AND GAS CONSERVATION COMMISSION i /. 1 0Zu `'' IjS APPLICATION FOR SUNDRY APPROVALS 3/' 78 i Q- 20 AAC 25.280 AOG C 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool 0 Repair Well 0 Change Approved Program 0 Suspend 0 Plug Perforations 0 Perforate❑ Pull Tubing 0 ' Time Extension 0 Operations Shutdown 0 Re-enter Susp.Well 0 Stimulate❑ Alter Casing 0 Other: Run ESP 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory 0 Development I] . 192-155 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ED Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20117-02. 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A . Will planned perforations require a spacing exception? Yes 0 No 0 Trading Bay Unit I D-07RD2 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594 „ McArtur 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): 12,438 ' 9,227. 12,438. 9,227< None None Casing Length Size MD TVD Burst Collapse Conductor 398' 33" 398' 398' Surface 1,401' 13-3/8" 1,401' 1,378' 5,380 psi 2,670 psi Intermediate 9,665' 9-5/8" 9,665' 7,182' 5,750 psi 3,090 psi Liner 3,679' 7" 12,905' 9,160' 7,240 psi 5,410 psi Liner 39' 3-1/2" 11,959' 9,132' Liner 27' 3-1/2" 11,986' 9,155' Liner 408' 3-1/2" 12,394' 9,229' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A • N/A 4-1/2" 12.6# L-80 8,932' 3-1/2" 9.3# L-80 11,920' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Packer:Baker SC-1R Packer Sz 70-40/ SSSV:Camco Retrievable Packer:11,921'(MD)9,101'(TVD)and SSSV 335'(MD) 335'(TVD) 12.Attachments: Description Summary of Proposal 0 . 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 • Exploratory 0 Stratigraphic 0 Development 0 ' Service 0 14.Estimated Date for 15.Well Status after proposed work: 4/12/2014 Commencing Operations: Oil 0 • Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG 0 Abandoned 0 Commission Representative: GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe@hilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signatur hone 907 283-1329 Date 3/10/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: —/ .3\`k vLr -1 Plug Integrity ❑ BOP Test NI Mechanical Integrity Test 0 Location Clearance 0 Other: 4i- 2576 /esz. ,2 a e `- W;414.c-55 G A ``AIo fisso ` F its r e-144-4:r'Q. RBDMS MAY 11 2014 Spacing Exception Required? Yes 0 No V Subsequent Form Required: 15—evict Approved by: . APPROVED BY COMMISSIONER THE COMMISSION Date: 3 —/7—/y it 1 '�//�� / .3/6/// Submit Form and Form 10-403 -evised 10120 prod�aRCftGi1vN fAtonths from the date of approval. Attachments in Duplicate Well Work Prognosis Well: D-07rd2 Hileorp Alaska,LLC Date: 03/10/14 Well Name: Trading Bay Unit D-07rd2 API Number: 50-733-20117-02 Current Status: Producer(Gas Lift) Leg: Leg#A-2 (NW corner) Estimated Start Date: 04/12/2014 Rig: HAK#1 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 192-155 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 Bottom Hole Pressure: —2,730 psi @ 9,266'TVD (Pressure buildup data from 1993) Maximum Expected BHP: — 3,795 psi @ 9,232' TVD Based on Offset Well buildup D-1 during the 2009 Redoubt Shut-in. Max.Allowable Surface Pressure: —0 Psi static, 2,500 psi pumping during treatment Brief Well Summary D-7RD2 was drilled as a Hemlock Bench 1 horizontal producer in April 1993. Gauges ran after completion showed 2,730 psi of reservoir pressure at that time. In 1994 during a gas lift valve change, a catcher sub was lost in the well and not recovered. In 2012,a coiled tubing work-over was executed without success to recover the catcher sub. At the end of that work-over a down charge was used to shoot down through the catcher sub. Procedure: 1. At least one day prior to rig move, stop lift gas to well and bleed down tubing and casing. 2. Skid rig and RU HAK Rig 1 over D-07rd2 well slot. ✓3. Pump Xylene/HCL pill to soak slotted liner.Displace to top of liner and soak 6 hours. 4. Rig up E-Line and perforate tubing between packer and X-nipple to add a flow path around catcher sub. and set plug inside seal assembly. 6. 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 si IGH. 7. Punch tubing above packer or pull lowest gas lift value possible. 8. Circulate FIW to ensure tubing and casing are full.✓ o� 9. RU E-line and cut tubing in the middle of the first full joint of tubing just above the packer(-11,900'). 10. RD E-line. POOH laying down tubing and GLMs. 11. Scrape 9-5/8" and 7" casing to^'11,900'. 12. RIH and wash over tubing stub to packer top.Circulate well clean and swap out fluids to clean FIW. 13. Pressure test casing to 1500 d start. POOH with same. 14. MU Overshot assembly and latch onto the tubing stub/seal assembly. 15. POOH, LD cut tubing joint and seal assembly.✓ 16. PU, RIH with ESP completion. 17. ND BOP, NU wellhead and test. 18. Turn well over to production. 19. Conduct a no-flow test within 2 weeks after stabilized flow and water cut is achieved. Well Work Prognosis Well: D-07rd2 Hilcorp Alaska,LLC Date: 03/10/14 Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. BOP Drawing 4. Current Wellhead Diagram 5. New Wellhead Diagram Trading Bay Unit SCHEMATIC Well: D-07RD2 Hr7rrgr Alaska,LLC Completed: 4/6/1993 CASING DETAIL All Measurements are RKB to Top of SIZE WT GRADE CONN MIN TOP BTM TYPE Equipment. ID (MD) 1L 33" Surface 398' 13-3/8" 72 N-80 BTC 12.347 Surface 1401' 2 40 N-80 BTC 8.835 Surface 5,761' 33 9-5/8" 43.5 N-80 BTC 8.755 5,763' 7,919' 47 N-80 BTC 8.681 7,919' 9,665' 7" 26 L-80 BTC 6.184 9,226' 12,905' 9.3 L-80 Hydril 2.992 11,920' 11,959' 3-1/2" 9.3 L-80 Hydril 2.992 11,959' 11,986' Perforated 3 9.3 L-80 Hydril 2.992 11,986' 12,394' Slotted TUBING DETAIL 13-3/8A 4-1/2" 12.6 L-80 BTC 3.958 Surface 8,932' 3-1/2" 9.3 L-80 EUE 8RD 2.992 8,932' 11,920' 4II DV Collar from 5,761'to 5,763'in 9-5/8"Casing ■ ■ 5 JEWELRY DETAIL 111 No Depth ID Item 1 CIW Tbg Hanger 10"Nom."DCB" 62 335' 3.812 SCSSV-Camco Retrievable Flapper Valve,TRDP-4A 3 2,285' 3.833 4-1/2"Camco MMG w/1.5"Valve,RK Latch 4 4,197' 3.833 4-1/2"Camco MMG w/1.5"Valve,RK Latch 7 5 5,867' 3.833 4-1/2"Camco MMG w/1.5"Valve,RK Latch 6 7,216' 3.833 4-1/2"Camco MMG w/1.5"Valve,RK Latch 87 8,104' 3.833 4-1/2"Camco MMG w/1.5"Valve,RK Latch 9 8 8,872' 3.833 4-1/2"Camco MMG w/1.5"Valve,RK Latch 9 8,932' X-Over 4-1/2"Butt AB Mod x 3-1/2"EU 8RD 10 9,675' 2.867 3-1/2"Camco MMG-II w/1.5"Valve 11 10,396' 2.867 3-1/2"Camco MMG-II w/1.5"Valve 9-5/8"p10 12 11,085' 2.867 3-1/2"Camco MMG-11w/1.5"Valve MI 13 11,835' 2.867 3-1/2"Camco MMG-II w/1.5"Valve 11IM 14 11,920' Baker 80-40 Locator and Seal Assy. 12 15 11,921' Baker"SC-1R"Packer Size 70-40,Baker Seal Bore Ext. MIL 13 16 11,937' Baker Mill-out Ext. 17 11,942' Baker Knock-out Isolation Valve 18 11,945' Baker Rotationally Locked Safety Joint 1' 19 11,958' Otis"X"Nipple(2.81 Profile) 15 20 12,424' Baker Pack-off Bushing 16 21 12,435' Baker"V"Float Shoe 17 NOTE:X-Lock (No Packing)and perforated Catcher Sub(2.73" 18 O.D.,24"TOL left in X-Nipple at 11,958'TM (11,986'WLM) 19 \NI._ 20 343'Horizontal _ Displacement (12,095'-12,438'MD) 21 6" Open Hole TD = 12,438' TVD = 9,227' Revised By: JLL 03/14/13 PROPOSED Trading Bay Unit Well: D-07RD2 , . n HilrnrpAlaska,LLC Completed: Future CASING DETAIL All Measurements are RKB to Top of SIZE WT GRADE CONN MIN TOP (MD TYPE Equipment. 33" Surface 398' 13-3/8" 72 N-80 BTC 12.347 Surface 1401' 40 N 80 BTC 8.835 Surface 5,761' 33" L 9-5/8" 43.5 N 80 BTC 8.755 5,763' 7,919' 47 N-80 BTC 8.681 7,919' 9,665' 7" 26 L-80 BTC 6.184 9,226' 12,905' 9.3 L-80 Hydril 2.992 11,920' 11,959' 3-1/2" 9.3 L-80 Hydril 2.992 11,959' 11,986' Perforated 9.3 L-80 Hydril 2.992 11,986' 12,394' Slotted J \ TUBING DETAIL 13-3/8 2-7/8" 6.5 L-80 8rd EUE Surface ±11,800' DV Collar from 5,761'to 5,763'in 9-5/8"Casing ■ ■ JEWELRY DETAIL Depth Depth No ID Item (MD) (ND) S 1 CIW Tbg Hanger 10"Nom."DCB" 4e5 2 ±11,800' Bottom of ESP 3 11,920' Baker 80-40 Locator and Seal Assy. 4 11,921' Baker"SC-1R"Packer Size 70-40,Baker Seal Bore Ext. 5 11,937' Baker Mill-out Ext. 6 11,942' Baker Knock-out Isolation Valve 7 11,945' Baker Rotationally Locked Safety Joint 8 11,958' Otis"X"Nipple(2.81 Profile) 9 12,424' Baker Pack-off Bushing 9-5/8"p 10 12,435' Baker"V"Float Shoe Z 3 4 5 Tubing punch holes � 6 11,940'-11,945' NOTE:X-Lock (No Packing)and perforated Catcher Sub(2.73" 7 O.D.,24"TOL left in X-Nipple at 11,958'TM (11,986'WLM) 8 _ (2-pZ 9 343'Horizontal Displacement (12,095'-12,438MD) 10 6"Open Hole TD = 12,438' TVD = 9,227' Revised By: JLL 03/04/14 Doily Varden Platform .. fir D-07RD2 Current 03/07/2014 Hikarp Alaska,1,IA. Dolly Varden Tubing hanger,CIW-DCB- D-07RD2 FBB,11 X 4/EUE 8rd lift X 4'/IBT susp,w/4"type H 13 3/8 X 9 5/8 X 4 1/2 BPV,1/8 non continuous control line,7"extended neck prep BHTA,CIW,w/internal knockup cap,4 1/16 5M FE swam In in 4111.11 milt 181 ris 6, • • Q,- ®p0 r .. Tree,Block,CIWF,11 5M X , 4 1/16 SM run X 3 1/8 SM iI 0 fs+ jpip'. wing,double master and - . a wing valve,EE trim prepped � wit for 7"FBB type hanger neck, .. 4,l im w/'/:control line exit .-. ,, " "' r, *, At it....,:ify i _in 9� Tubing head,CIW-DCB, - 13 5/8 3M X 11 5M,w/2- :1!i i . liar 2 1/16 5M SSO,X bottom 1 i 1 _ 111 Valve,WKM-M,2 1/16 5M FE,HWO,AA trim -' L Qty 2 •Il 0 III _ 1I1 Casing head,CIW-WF, IIII 13 5/8 3M X 13 3/8 casing ■l� Valve,CIW-F,2 1/16 SM FE, thread bottom,w/2-2 1/16 111 111 HWO,AA trim 5M EFO - i� ° ■0ICI ISI- L Dotty Varden Platform •• Eli D-07RD2 Proposed 03/07/2014 HJrnrp%la,.ka,1.11A, Dolly Varden Tubing hanger,CIW-DCB-ESP, D-07RD2 11 X 3%EUE lift and susp,w/ 13 3/8 X 9 5/8 X 3 1/2 3"type H BPV profile,5'''A EN, 2-3/8 continuous control line ports,prepped for BIW penetrator BHTA,Bowen,3 1/8 SM FE X 3" Bowen Quick Union 1,4 1.1 Valve,swab,WKM-M, 3 1/8 SM FE,HWO, T-24 IMO Valve,wing,WKM-M, 2 1/16 5M FE,HWO, Ili . yI Valve © ,WKM-M,3 1/8 5M FE,w/ 1-24 O MA-16 operator MINIM .1 Valve,lower master,WKM-M, 3 1/8 5M FE,HWO,T-24 ;Y 1>) , 1 �J 1.1 i.l Adapter,CIW-Toadstool,11 5M Stdd X 3 1/8 5M FE,prepped for 5%ESP neck,2-Y2 npt continuous control line ports ' SpaD .1.1.4te P‘‘' —' r Tubing head,CIW-DCB, . 13 5/8 3M X 11 5M,w/ 2-2 1/16 5M SSO, I I ;f Valve,WKM-M,2 1/16 5M FE, X bottom HWO,DD ° Qty 2 UI _ It p 3oco r,;, Casing head,CIW-WF, ;Ili! IivValve,CIW-F,2 1/16 5M FE, III 13 5/8 3M X 13 3/8 casingHWO,AA trim thread bottom,w/2-2 1/16 5M EFO � i I .I1Lt1)uI " Doily Varden Platform 2014 BOP Stack(HAK#1) 01/10/2014 Hilrarp Alaska,,LIC Dolly Varden Platform 2014 Workovers BOP Drawing(HAK#1) Quail Tool Rental Stack 111 to 1i i Tr 3.42' Shaffer 11"5M Ili Iti Iti!Ii iii 4.54' ,. ak� :., CI ee9 s III al I i lil lit A -111 1II III ip ill 2.00' �R ( :lii ill 111 III Ill Kill Side Choke side 1.00'to 2.00 21/16 5M w/HCR and Unibolt line 21/16 5M w/HCR and Unibolt line connection lit tll III I11 tit connection Drill deck Riser 11 5M FE X 16.00' 11 5M FE lit lil Iii lil lit 111 lit tit ill UI 3.00' Spacer spool 115M FE X 115M FE Ill lit(It 111 ill • STATE OF ALASKA E E f . v ED ALASKA OIL AND GAS CONSERVATION COMMISSION „ H 2013 • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Other ❑ =,. A" Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other p Re -enter Suspended Well❑ 2. Operator ✓ 4. Well Class Before Work: ✓ 5. Permit to Drill Number: ✓ Name: Hilcorp Alaska, LLC Development IS Exploratory ❑ 192-155 3. Address: 3800 Centerpoint Drive, Suite 100 StratigraphiC❑ Service ❑ 6. API Number: ✓ Anchorage, AK 99503 50- 733 - 20117 -02 7. Property Designation (Lease Number): ✓ 8. Well Name and Number: ✓ ADL0017594 Trading Bay Unit D -07RD2 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): ✓ McArthur River Field / Hemlock Oil Pool 11. Present Well Condition Summary: Total Depth measured 12,438 feet Plugs measured None feet true vertical 9,227 feet Junk measured None feet Effective Depth measured 12,438 feet Packer measured 11,921 feet true vertical 9,227 feet true vertical 9,101 feet Casing Length Size MD TVD Burst Collapse Conductor 398' 33" 398' 398' Surface 1,401' 13 -3/8" 1,401' 1,378' 6,380 psi 2,670 psi Intermediate 9,665' 9 -5/8" 9,665' 7,182' 5,750 psi 3,090 psi Liner 3,679' 7" 12,905' 9,160' 7,240 psi 5,410 psi Liner 39' 3 -1/2" 11,959' 9,132' Liner 27' 3 -1/2" 11,986' 9,155' Liner 408' 3 -1/2" 12,394' 9,229' Perforation depth Measured depth N/A feet SCANNED MAY 0 3 2013 True Vertical depth N/A feet 4 -1/2" 12.6# / L -80 8,932' (MD) 6,632' (TVD) Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.3 # / L -80 11,920' (MD) 9,100' (TVD) Packers and SSSV (type, measured and true vertical depth) Baker SC-1R Pkr 11,921' (MD) 9,101' (TVD) SSSV - Cameo Ret. 335' (MD) 335' (TVD) 12. Stimulation or cement squeeze summary: . Intervals treated (measured): Treated tubing to 11,920', perforations from 11,954'- 11,986' and the slotted liner from 11,986'- 12,394'. Treatment descriptions including volumes used and final pressure: Pumped 930 gal (600 gal 7.5% HC1 & 330 gal Xylene) followed by 140 bbls FIW. Ending pressure = 1500 psi. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 30 135 260 1150 265 Subsequent to operation: 30 40 415 1150 230 14. Attachments: 15. Well Class after work: •' Copies of Logs and Surveys Run Exploratory❑ Development El Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: ✓ Oil p Gas ❑ WDSPLD 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: ✓ 313 -137 Contact Ted Kramer Email tkramer @hilconD.com Printed Name Ted Kramer Title Sr. Operations Engineer Signature 4" 'd Phone (907) 777 -8420 Date 4/29/2013 Form 10-404 Revised 10/2012 RBDMS MAY -1 2013 / S / • Z. • /3 bmi Or i�� my Hilcorp Alaska, LLC Hilcorp Alaska. LLC Well Operations Summary Well Name API Number (Well Permit Number Start Date End Date D -07RD2 50- 733 - 20117 -02 192 -155 4/4/2013 4/5/2013 Daily Operations: ..; i 04/04/13 - Thursday Rig up. Fluid level at 7,500', tubing 200 psi. Begin pumping FIW down tubing at 4.75 BPM, fluid u- tubing into annulus. Fluid level at 1,800', tubing 300 psi, bleed gas from annulus and continue filling. Well full at 415 bbls FIW away. Mix chemical pill in batch tank. Started pumping chemical at 2 BPM. Pump 150 bbls FIW displacement at 10 GPM 1500 psi. 04/05/13 - Friday Rate increased when acid reached liner. Shut in for 2 hour soak. Pump 15 bbl FIW displacement and soak for 1 hour. Return well to production. Trading Bay Unit I in SCHEMATIC Well: D -07RD2 Hile rp Alaska, (.(,(: Completed: 4/6/1993 CASING DETAIL All Measurements are RKB to Top of SIZE WT GRADE CONN MIN TOP BTM Ecluipm ent. 1 33" Surface 398' III I 13 -3/8" 72 N - 80 BTC 12.347 Surface 1401' 2 40 N - 80 BTC 8.835 Surface 5,761' 33" ■ 9 - 5/8" 43.5 N -80 BTC 8.755 5,763' 7,919' 47 N -80 BTC 8.681 7,919' 9,665' 7" 26 L -80 BTC 6.184 9,226' 12,905' 9.3 L -80 Hydril 2.992 11,920' 11,959' 3 - 1/2" 9.3 L -80 Hydril 2.992 11,959' 11,986' Perforated 3 9.3 L -80 Hydril 2.992 11,986' 12,394' Slotted TUBING DETAIL 13 - 3/84 ■ 4 - 1/2" 12.6 L - 80 BTC 3.958 Surface 8,932' 3 -1/2" 9.3 L -80 EUE 8RD 2.992 8,932' 11,920' 4 DV Collar from 5,761' to 5,763' in 9 -5/8" Casing • ■ • 5 JEWELRY DETAIL ■ No Depth 1 ID Item CIW Tbg Hanger 10" Nom. "DCB" 6 ® 2 335' 3.812 SCSSV- Camco Retrievable Flapper Valve, TRDP -4A 3 2,285' 3.833 4 -1/2" Camco MMG w/ 1.5" Valve, RK Latch 4 4,197' 3.833 4 -1/2" Camco MMG w/ 1.5" Valve, RK Latch ® 5 5,867' 3.833 4 -1/2" Camco MMG w/ 1.5" Valve, RK Latch 6 7,216' 3.833 4 -1/2" Camco MMG w/ 1.5" Valve, RK Latch 8 - 1. "Valve, RKL 7 8 104' 3.833 4 1/2" Camco MMG w/ 5 Latch 9 8 8,872' 3.833 4 -1/2" Camco MMG w/ 1.5" Valve, RK Latch 9 8,932' X -Over 4 -1/2" Butt AB Mod x 3 -1/2" EU 8RD 10 9,675' 2.867 3 -1/2" Camco MMG -II w/ 1.5" Valve 11 10,396' 2.867 3 -1/2" Camco MMG -II w/ 1.5" Valve 9 -5 /8 M k 12 11,085' 2.867 3 -1/2" Camco MMG -II w/ 1.5" Valve 10 13 11,835' 2.867 3 -1/2" Camco MMG -II w/ 1.5" Valve 11 14 11,920' Baker 80 -40 Locator and Seal Assy. Alt 12 15 11,921' Baker "SC -1R" Packer Size 70 -40, Baker Seal Bore Ext. MD 13 16 11,937' Baker Mill -out Ext. 17 11,942' Baker Knock -out Isolation Valve 18 11,945' Baker Rotationally Locked Safety Joint 14 19 11,958' Otis "X" Nipple (2.81 Profile) 15 20 12,424' Baker Pack -off Bushing 16 21 12,435' Baker "V" Float Shoe 17 NOTE: X - Lock (No Packing) and perforated Catcher Sub (2.73" 18 I O.D., 24" TOL left in X- Nipple at 11,958' TM (11,986' WLM) 19 r-t. 20 343' Horizontal Displacement (12,095' - 12,438' MD) 21 6" Open Hole TD = 12,438' TVD = 9,227' Revised By: JLL 03/14/13 OF TfJ • • %%i s THE STATE A Al Oil and a ofALASK - Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF ¢. Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 SCANNED MAR 2 2 2013 Fax: 907.276.7542 Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC r-- 1 5 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil Pool, TBU D -07RD2 Sundry Number: 313 -137 Dear Mr. Kramer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, • Cathy P. ' oerster Chair DATED this day of March, 2013. Encl. p'7'S ^ +3 1,-.2z,/3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS .., ds 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ PuII Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ d it St GI' Alter Casing ❑ Other ❑ 2. Operator Name: 4. Current Well Class: 5. Pemiit to Drill Number. Hilcorp Alaska, LLC Exploratory ❑ Development p• 192 -155 • 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number. Anchorage, AK 99503 50- 733 - 20117 -02 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑ Trading Bay Unit / D-07RD2 • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0017594 • McArtur 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): • 12,438 9,227 12,438 9,227 None None Casing Length Size MD TVD Burst Collapse Conductor 398' 33" 398' 398' Surface 1,401' 13 -3/8" 1,401' 1,378' 5,380 psi 2,670 psi Intermediate 9,665' 9 -5/8" 9665' 7,182' 5,750 psi 3,090 psi Liner 3,686' 7" 12,905' 9,160' 7,240 psi 5,410 psi Liner 39' 3 -1/2" 11,959' 9,132' Liner 27' 3 -1/2" 11,986' 9,155' Liner 408' 3 -1/2" 12,394' 9,229' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 4 -1/2" 12.6# L -80 8,932' 3 -1/2" 9.3# L -80 11,920' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Packer: Baker SC -1R Packer Sz 70 -40 / SSSV: Camco Retrievable Packer: 11,921' (MD) (TVD) and SSSV 335' (MD) (TVD) 12. Attachments: Description Summary of Proposal 2 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 3/22/2013 Commencing Operations: Oil El • 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 Ted Kramer Email tkramerCa�hilcorp.com Printed Name Ted Kramer Title Sr. Operations Engineer signature G j1 Phone 907 777-8420 Date 3/15/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 -1 3 , 7 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: R QDMS MAR 2 2 416 Spacing Exception Required? Yes ❑ No El Subsequent Form Required: 1 0 L i 0 APPROVED BY Approved by: ` COMMISSIONER THE COMMISSION Date: 3 - — 3 0 o s 3 " 10.15 Submit Form and L ��'b FR tf-6ifvN1A1JL Approved application is valid for 12 months from the date of ap val. Attachments in r 3 y$� v • • Well Prognosis Well: D -07RD2 Hilcorp Alaska, LL Date: 03 /15/13 Well Name: D -07RD2 API Number: 50- 733 - 20117 -02 Current Status: SI Leg: A -2, NW Corner Estimated Start Date: 03/22/13 Rig: NA Reg. Approval Req'd? Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett 777 -8332 Permit to Drill Number: 192 -155 First Call Engineer: Ted Kramer (907) 777 -8420 (0) Second Call Engineer: Mike Dunn (907) 777 -8382 (0) Current Bottom Hole Pressure: — 2,730 psi @ 9,266'TVD (Pressure buildup data from 1993) Maximum Expected BHP: — 3,795 psi © 9,232' TVD Based on Offset Well buildup D -1 during the 2009 Redoubt Shut -in. Max. Allowable Surface Pressure: — 0 Psi static, 2,500 psi pumping during treatment Brief Well Summary D -7RD2 was drilled as a Hemlock Bench 1 horizontal producer in April 1993. Gauges ran after completion showed 2,730 psi of reservoir pressure at that time. In 1994 during a gas lift valve change, a catcher sub was lost in the well and not recovered. In 2012, a coiled tubing workover was executed without success to recover the catcher sub. At the end of that workover a down charge was used to shoot down through the catcher sub. Job Summary It is believed that Scale and Paraffin are forming on the lost catcher sub impeding the flow of fluids into the well bore. This treatment is designed to remove the deposits and return this well to full production potential. Brief Procedure: 1. Obtain a representative production test during the week prior to the squeeze treatment. 2. Contact TBPF 48 hours in advance. Complete Non - Produced Fluids Transfer and fax to TBPF prior to shipping any fluid. 3. Ensure that pump is recorded in Temporary Equipment Database — Use Engine # "185 ", Unit ID# - "Squeeze Pump Connex ", S/N — "497578" 4. Verify that MSDS sheets are onsite for all chemicals and that safe handling procedures are followed. -' 5. Shut in well to allow fluid level to build. 6. Conduct safety meeting with platform foreman, operators, and pumping personnel to ensure safe operating procedures are followed. a) Review mixing and pumping procedures prior to rigging up and complete JSA & Work Permit. b) All hot work to be shut down on drill deck during pumping operations. c) Implement Safe Practices Standard 7.16 "Well Servicing Operations" including the safety checklist. 7. Send Non - produced fluids transfer form to TBPF. 8. Rig up pump, and tanks. a) Install a check valve in the treating line as close to well head as possible. b) Monitor tubing pressure, casing pressures, pump rate. c) Ensure that all equipment is grounded and bonded prior to any pumping or chemical transfers. 9. Pressure test lines first at low and then high pressure. Use a low pressure of 500 psig and a high pressure of 2000 psig. a) Test from pump to swab valve. b) Pressure test from pump to master valve and production wing valve. c) Bleed off pump pressure to verify that check valve holds. •. • • Well Prognosis Well: D -07RD2 Hilcorp Alaska, Lr) Date: . 03/15/13 10. Mix chemicals in 2000 gallon batch tank a. 1 drum Baker Petrolite WAW -5206 (ground tote while transferring) b. 1 tote Xylene (ground tote when transferring) c. 3 totes 7.5% Hydrochloric Acid 11. Record pump rates and pressures throughout the job. Do not exceed 1500 psi annulus pressure (when annulus is shut -in). Reservoir pressure is estimated to be 3,500 psi. a. Pump FIW Pump Chemical Pill b. Pump 150 bbls FIW overflush and soak for 4 hours c. Displace with 15 bbls FIW and soak for 4 hours 12. Shutdown pumping, ensure all tanks, lines, etc. are thoroughly rinsed. 13. Rig Down, Blow -down pump, drain all lines, and turn well over to Production. Attachments: 1. As -built Schematic • • Trading Bay Unit . 14 SCHEMATIC Well: D -07RD2 Ha""rp Alaska, 1,u: Completed: 4/6/1993 CASING DETAIL All Measurements are RKB to Top of SIZE WT GRADE CONN MIN TOP BTM TYPE Equipment. ID (MD) 1 33" Surface 398' II 13 -3/8" 72 N -80 BTC 12.347 Surface 1401' 2 40 N -80 BTC 8.835 Surface 5,761' 33' ■ 9 - 5/8" 43.5 N -80 BTC 8.755 5,763' 7,919' 47 N -80 BTC 8.681 7,919' 9,665' 7" 26 L -80 BTC 6.184 9,226' 12,905' 9.3 L - 80 Hydril 2.992 11,920' 11,959' 3 -1/2" 9.3 L -80 Hydril 2.992 11,959' 11,986' Perforated 3 9.3 L -80 Hydril 2.992 11,986' 12,394' Slotted 13 -3/8A TUBING DETAIL ■ 4-1/2" 12.6 L-80 BTC 3.958 Surface 8,932' 3 - 1/2" 9.3 L - EUE 8RD 2.992 8,932' 11,920' 4 DV Collar from 5,761' to 5,763' in 9 -5/8" Casing ■ ■ 5 JEWELRY DETAIL No Depth ID Item 1 CIW Tbg Hanger 10" Nom. "DCB" 6 2 335' 3.812 SCSSV- Camco Retrievable Flapper Valve, TRDP - 3 2,285' 3.833 4 -1/2" Camco MMG w/ 1.5" Valve, RK Latch 4 4,197' 3.833 4 -1/2" Camco MMG w/ 1.5" Valve, RK Latch 7 5 5,867' 3.833 4-1/2" Camco MMG w/ 1.5" Valve, RK Latch 6 7,216' 3.833 4 -1/2" Camco MMG w/ 1.5" Valve, RK Latch 8 7 8,104' 3.833 4 -1/2" Camco MMG w/ 1.5" Valve, RK Latch 9 • 8 8,872' 3.833 4 -1/2" Camco MMG w/ 1.5" Valve, RK Latch 9 8,932' X -Over 4 -1/2" Butt AB Mod x 3 -1/2" EU 8RD 10 9,675' 2.867 3 -1/2" Camco MMG -II w/ 1.5" Valve 11 10,396' 2.867 3 -1/2" Camco MMG -II w/ 1.5" Valve 9 - 5/8" I li 10 12 11,085' 2.867 3 -1/2" Camco MMG -II w/ 1.5" Valve _ 13 11,835' 2.867 3 -1/2" Camco MMG -II w/ 1.5" Valve 11 _ 14 11,920' Baker 80 -40 Locator and Seal Assy. 12 15 11,921' Baker "SC -1R" Packer Size 70 -40, Baker Seal Bore Ext. MIMI 13 16 11,937' Baker Mill -out Ext. 17 11,942' Baker Knock -out Isolation Valve 18 11,945' Baker Rotationally Locked Safety Joint 14 19 11,958' Otis "X" Nipple (2.81 Profile) 15 12,424' Baker Pack -off Bushing 16 21 12,435' Baker "V" Float Shoe 17 NOTE: X - Lock (No Packing) and perforated Catcher Sub (2.73" 18 O.D., 24" TOL left in X- Nipple at 11,958' TM (11,986' WLM) 19 rIr ) , - 20 343' Horizontal Displace (12,095'- 1 2,438' MD) 21 6" Open Hole TD = 12,438' TVD = 9,227' Revised By: JLL 03/14/13 TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 UNOCAL Field Superintendents 260 Cavair Street Kenai, Alaska 99611 Re: No-Flow Verification TBU Well D-7RD2 PTD 192-155 TBU Well D-47 PTD 191-011 Gentlemen: • November 20, 2001 On September 5, 2001 AOGCC Petroleum Inspector Chuck Scheve witnessed "no-flow" tests on Wells D-7RD2 and D-47 at UNOCAL's Dolly Varden Platform, Trading Bay Unit, McArthur River Field. Mr. Scheve arrived on Dolly Varden Platform and observed both wells shut in with 0 tubing pressure. The wells remained SI while safety valve tests were conducted. After several hours, the tubing of each well was opened to atmosphere. No liquid flow was observed and only a slight and diminishing gas flow was noted. The observed performance of TBU wells D-7RD2 (192-155) and D-47 (191-01) demonstrated that the wells are incapable of unassisted flow of hydrocarbons to the surface. Therefore, these welts need not be equipped with a commission approved fail-safe automatic surface-controlled subsurface safety valve ("SSSV") system. However, these wells must be equipped with fail-safe automatic surface safety valve ("SSV") systems capable of preventing uncontrolled flow and maintained in proper working condition. If for any reason any of the wells become capable of unassisted flow of hydrocarbons, the SSSV must be returned to service. A copy of this letter should be maintained in the respective well files on board Dolly Varden. Sincerely, ~,~~ Thomas E. Maunder, P.E. Sr. Petroleum Engineer ALASKA OIL AND GAS CONSERVATION COMMISSION September 7, 2001 Dwight Johnson, Superintendent Chris Meyers, Superintendent UNOCAL Field Superintendents 260 Caviar Street Kenai, Alaska 99611 TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 RE: No-Flow Verifications TBU Well D-7RD2, PTD 192-155 TBU Well D-47, PTD 191-011 Gentlemen: On September 5, 2001 AOGCC Petroleum Inspector Chuck Scheve witnessed a "no flow tests" on Unocal's Trading Bay Unit Wells D-7RD2 and D-47. Mr. Scheve arrived on Dolly Varden Platform and found the wells shut in and depressurized as requested. While testing the safety valve system the wells remained shut in for several additional hours. When safety valve testing was concluded, each well was opened to atmosphere. Neither well produced any fluid with only a slight but diminishing gas flow noted. Therefore, it is determined; that TBU Well D-7RD2 (PTD 192-155) and TBU Well D-47 (PTD 191-011) need not be equipped with a commission approved fail-safe automatic surface-controlled subsurface safety valve ("SSSV") system. However, the wells must be equipped with fail-safe automatic surface safety valve ("SSV") systems capable of preventing uncontrolled flow and maintained in proper working condition. If for any reason either well becomes capable of unassisted flow of hydrocarbons, the SSSV must be retumed to service. A copy of this letter should be maintained in the respective well files on board Dolly. Sincerely Thomas E. Maunder, PE Sr. Petroleum Engineer cc: Bob Fleckenstein TEM:\jjc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O Taylor, C~;~ DATE: Chairman Tom Maunder, P. I. Supervisor"'~.:~c~. THRU: FROM: Chuck Scheve, SUBJECT: Petroleum Inspector September 5, 2001 '~. No Flow Trading Bay Unit DOlly Varden Platform D-7RD2,' PTD192-155 D-47 PTD 191-011 Wednesday, September 5, 2001' I traveled to Unocal's Dolly Varden Platform and witnessed no-flow tests on.wellsD-7RD2~ and D-47. I arrived on location and found both wells shut in with 0 psi on the tubing. Both were observed for several hours, while testing Safety Valve Systems. The tubing was then opened to atmosphere and observed, no fluid and only a very slight and diminishing gas flow (probably gas breaking out of wellbore fluids) noted. I recommend Wells D-7RD2 and D-47 on the Dolly Varden Platform be approved no flow status for the purpose of removing the Sub Surface Safety Valve. SUMMARY: Wells D-7RD2 and D-47 meet the AOGCC requirements for no flow status. A,,ttachments: x Unclassified Classified Unclassified with Document Removed MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan Seamount, Commissioner ~ Blair Wondzell, P. I. Supervisor FROM: John Crisp,~''. ~~. SUBJECT: Petroleum In~ector DATE: June 22, 2000 Safety Valve Tests Dolly Varden Platform McArthur Rv. Field June 22, 2000: I traveled to Unocal's Dolly Varden Platform in the McArthur River Field to witness the Semi Annual Safety Valve System tests. Wells number 05, 17 & 31 Subsurface Safety valves were POOH for repair. Surface Safety valve on well 01 will be changed out during next Platform shut down due to header valve leaks. The AOGCC test report is attached for failure reference. SUMMARY: I witnessed the Semi Annual SVS tests on the Dolly Varden Platform in the McArthur River Field_ _ 24 wells, 57 components tested, 3 failures witnessed. 5.2% failure rate. Attachments' SVS Dolly Pit. 6-22-00jc cc; NO.N~,CONFIDENTIAL SVS Dolly Pit. 6-22-00jc Alaska Oil and Gas Conservation CommisSion Safety Valve System Test Report Operator: Unocal Operator Rep: Mark Murietta AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit~ad: McArthur Ry./Dolly Varde Separator psi' LPS 110 HPS 6/22/00 Well Permit Separ Set' L/P Test Test Test oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code GAS or C¥¢[E D-01 1670800 110 80! 85 P 4 OIL D-02ARD 1750380! 110 80~ 65 P 5 OIL D-03RD2 1830810i 110 80 80 p p OIL D-04RD 1820410 110 80 80 p p OIL D-05RD 1800650 110 80 100 P P 43 OIL ~ 1921550 110 80 80 p p p OIL D-08RD 1740030 110 80 75 p p P OIL D-11 1680730 110 80 80 p p P OIL D-12RD 1800820 110 80 '75 P P 43 OIL D-17RD 1810230 110 80 80 P P 43 OIL D-18 1690040 800 700 700 p p P GAS D-20 1690950 110 80 90 p p OIL D-25RD 1780870 110 80 100 p p OIL D-26RD 1981290 110 80 75 p p OIL D-27 1750240 110 80 60 p p OIL D-28 1760360 110 80 100 · p p OIL D-30RD2 1880980 D-31RD 1760740 110 80 70 P P 43 OIL D-32 1700370 110 80 75 p p P OIL D-40RD 1820830 110 80 80 p p OIL D-42 1830530 110 80 70 p p OIL D-43RD 1853110 110 80 70 p p P OIL D-46 1890610 110 80 60 p p P OIL D-47 1910110 110 80 70 P P 9 OIL D-48 1921540 110 80 80 p p P OIL Wells: 24 Components: 57 Failures: 3 Failure Rate: 5.2% I--190 oar Remarks: Wells that have SSSVs out for repair are designated 43 & not counted as failures or components tested~ 6/27/00 page 1 of 1 SVS Dolly Pit. 6-22-00jc 1 ~ S BEEI',I ON OR BEFOP O1 2000 ~--'AOGCC Individual Well k._~,, Geological Materials Inventory Page: 1 Date: 01/11/95 PERMIT DATA T DATA__PLUS RUN DATE_RECVD 92-155 92-155 92-155 MUD~/ DRY' DITCH J S 12050-12438 SS# 886 06/07/93 / SURVEY R 12052-12438 E TELECO 07/08/93 L 12100-12400 1 06/07/93 Are dry ditch samples required? yes ~-And received? ~~~---~o was the well cored? yes {b.a_s. Analysis & description received?k~~ Are well tests required? yes ~ Received? ye~-o~ Well is in compliance Initial COMMENTS Z~//~ '2 ~ Unocal North Americar, .... Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL- Alaska Region DOCUMENT TRANSMITTAL July 6, 1993 TO' Larry Grant LOCATION' 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 ALASKA OIL & GAS CONSERVATION COMM. FROM. Kirk Kiloh LOCATION: P.O.BOX 196247 ANCHORAGE AK 99519 UNOCAL TRADING BAY UNIT Marathon TBU D-7RD #2 TRANSMITTING AS FOLLOWS 1 blueline and 1 sepia of the following Directional Survey PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU DATED: Unocal North American Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region DOCUMENT TRANSMITTAL June 4, 1993 TO' Larry Grant LOCATION-3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 ALASKA OIL & GAS CONSERVATION COMM. FROM' Kirk Kiloh LOCATION: P.O.BOX 196247 ANCHORAGE AK 99519 UNOCAL TRANSMITTING AS FOLLOWS TRADING BAY UNIT Marathon TBU D-7RD#2 1 blueline and 1 sepia of mudlog one set of washed and dried drill cuttings 12059 - 12438 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL THANK YOU DATED: I12. Date Spudded 113. Date T.D. Reached :3/11/93 13/28/93 17. Total Depth (MD+TVD) 118. Plug Back Depth (MEH-TVD) 12,438 9,212 ] 12,438 9,212 22. Type Electric or Other Logs Run STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COIvIM ISSIE~//~ ?,,~ WELL COMPLETION OR RECOMPLIETION REPORT 1. Status of Well Classification of Service We~l( O1'~ ~ GAS ~J SUSPENDED ~ ''~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number IR~OCAL (Marathon 0il Company - Sub-operator) 92-155 , 3. Address 8. APl Number P.O. Box 196247 Anchorage, AK 99519 50-733-20117-~2 4. Location of well at surface Leg A-2, Cond. #4 Dolly Varden Platform 9. Unit or Lease Name 760' FSL, 1,136 FWL, Sec. 6-8N-13W-SM ::~ ~:!:'i'.';~"~.i:,'~i..! ~: ~_ i~.'fi~.~ Trading Bay Unit At Top Producing Interval ~ ;¢~-~4,,F)~.{:~ 10. Well Number 970' FSL, 851 FEL, SEC 32-9N-13W-SM .,,z_,~ , D-7RD2 At Total Depth ~1t~~ !; ¥'!i!;,i:,,~i?' ~,/r_.,,/ /...~ ~';'~'S~,~/ ~1. Field and Pool ~. 1,172' FSL, 540 , Sec. 32-9N-13W-SM ~d~ ., · .......... ~ I ' 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designg~tion and Seri~l No. Hemlock ! 06 ' _KB ~bov_e MSL _ ADL 17594 14. Date Comp., Susp. or Aband. [ 15. Water Depth, if offshore'!16. No. of Completions 4/6/93 I 132 feet MSLI 1 19. Directional Survey I 20. Depth whereSSSV set 21. Thickness of Permafrost YES ~ NO [] I 325 feet MD N/A GRADE None 23. I CASING SIZE :33" CASING, LINER AND CEMENTING RECORD SETTIN( DEPTH MD TOP BOTTOM 0 398 0 2,717 0 9,665 9~226 12,0~2 13-3/8" 9-5/8" 7" WT. PER FT. 68 J-55 N-80 47 29 N-80 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) Horizontal Open Hole with 3-1/2" Slotted Tailpipe 12-052' - 12,438~ MD 9,196 ~.- 9,212 TVD HOLE SIZE ]7-1/2" 12-1/4" CEMENTING RECORD 2400 SX 201.5 S× ~ 1000 SX , AMOUNT PULLED 25. TUBING RECORD SIZE 4-t/2" 3-1/2" 26. DEPTH SET (MD) PACKER SET (MD) 0 - 8~932 g~q~2-12~436 11,971 ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 4/7/93 I Gas Lift Date of Test 4/23/93 Flow Tubing Press. 120 Hours Tested 12 Casing Pressure ~40 PRODUCTION FOR TEST PERIOD ~ CALCULATED 24-HOUR RATE OI L-BBL I GAS-MCF 470 13~ .... OIL-BBL GAS-MCF 939 278 28. CORE DATA ! WATER-BBL ICHOKESIZE GAS-OIL RATIO I 45 I. _N/A 296 WATER-BBL IOILGRAVITY-API (corr) 89 I 34 Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED MAY 1 2 199;5 Alaska 0il & Gas O0ns. 00mmiss~0~ Anchorag~ Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. NAME Hemlock Top GEOLOGIC MARK MEAS. DEPTH 12,038' TRUE VERT. DEPTH ! 9,198' [:OR,MATION TESTS inc!ode interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Production test as on reverse side. 31. LIST OF ATTACHMENTS 32. Operations Surmmar¥ Report, Directional Sur~Ley I hereby certify that the ~oregoing is true and correct tc the best of my knowledge ~-~ . _ Ti INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and tog on all types of lands and leases in Alaska. Item I: 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 welt should show the details of an,/multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form t0-407 WELL.' D-TRD2 ~!~$~..UH..~' ~'~ 00[~$o. · .... Continued from D-7RD abandonment. 03/11/93 29 12063 9.000 FINISHED L/D TUBING FROM DERRICK. P/U BIT, MUDMOTOR, MI,D AND 4 3/4" DRILL COLLARS AND RIH. ATTEMPTED TO GET MWO SURVEY. CHANGED LINERS IN MUD PUMPS. ORIENTED MOTOR. DRILLED 12,052' TO 12,063' 03/12/93 30 12074 9.100 DRILLED FRC~ 12,063' TO 12,074'. MUD MOTOR STALLING OUT, UNABLE TO MAKE HOLE. CBU, EVALUATED CUTTINGS'98~.CEMENT. POOH. P/U 3 1/2 TUBING RIH, TAGGED 12,074'. SET BALANCED PLUG FROM 12,074' TO 11,814'. POOH 6 STANDS AND REVERSED OUT TWO DP VOLUMES. PUT 1000 PSI ON ANNULUS & WAIT ON CEMENT. 03/13/93 31 11866 9.100 WAIT ON CEMENT, HOLDING 1000 PSI ON PLUG. POOH. P/U BIT AND RIH. TAGGED CEMENT AT 11,841'. DRILLED CEMENT TO 11,866'. 03/14/93 32 12055 9.150 DRILLED CEMENT FRC~ 11,866' TO 12,049'. CBU. POOH. P/U MUDMOTOR ASSEMBLY. RIH. TIMED DRILLED CEMENT PLUG TO 12,055' 03/15/93 33 12085 9.200 TIMED DRILLED W/ AKO MUD MOTOR FROM 12,055' TO 12,059'. POOH. P/U AB MUD MOTOR AND RIH. DRILLED W/AB MUD MOTOR FROM 12,059' TO 12,085'. 03/16/93 34 12095 8.900 DRILLED FROM 12,085' TO 12,095' WITH MUD MOTOR. CBU. DISPLACED HOLE WITH XANVIS MUD. CLEANED PITS. POOH. R/U TO TEST BOP'S. 03/17/93 35 12114 8.950 TESTED BOP~S. M/U BHA AND RIH. CIRCULATED AND CONDITIONED MUD. SURVEYED AND ORIENTED MOTOR. REAMED BUILD PORTION OF CURVE. DRILLED FROM 12,095' TO 12,114'. SURVEYED BUILD SECTION. 03/18/93 36 12196 9.000 DRILLED FROM 12114' TO 12186' SURVEYING WITH MWD. MADE WIPER TRIP TO 12047'. DRILLED TO 12196'. Mt&) FAILED. POOH. 03/19/93 37 12242 8.900 POOH. P/U NEW BIT AND MWO. R[H. DRILLED AND SURVEYED FROM 12196' TO 12242'. 03/20/93 38 12261 8.900 DRILLED FROM 12242' TO 12249'. WIPER TRIP TO 12016'. DRILLED FROM 12249' TO 12261'. POOH FOR MOTOR, MI~ AND BIT. SLIP AND CUT DRILL LINE. RIH. 03/21/93 39 12261 8.900 RIH. WASHED FROM 12190~ TO 12220'. MOTOR STALLED AND LOCKED UP. POOH. CHANGED OUT MOTOR AND BIT. RIH. WASHED AND REAMED FROM 12034' TO 12232~. PIPE STUCK. WORK STUCK PIPE. 03/22/93 40 12261 9.000 WORKED STUCK PIPE FREE. POOH. L/D MOTOR AND MI~I). L/D EXCESS PiPE OUT OF DERRICK. WAIT ON NEW MUD MOTORS. MOTORS ARRIVED 0330. WAIT ON WEATHER. 03/23/93 41 12291 9.000 WAITED ON WEATHER TO LIFT TO FLY OUT MUD MOTORS. M/U BHA. RIH. WASHED AND REAMED FROM 12049' TO 12261'. DRILLED FROM 12261' TO OPERATION SUMMARY REPORT WELL: D-TRD2 ~nchorag~ 12291' 03/24/93 42 12364 9.000 DRILLED FROM 12291' TO 12311'. MADE WIPER TRIP TO 12039'. DRILLED TO 12364'. CBU AND SURVEY. 03/25/93 43 12364 9.000 CBU. POOH. TIGHT 12,275' TO 12,200'. R/U AND TESTED BOP'S. P/U NEW MUD MOTOR AND TUBING, AND STARTED RIH. 03/26/93 44 12364 9.000 FINISHED RIH TO 12,030'. MUD MOTOR STALLED. POOH TO TOP OF 7" AND ATTEMPTED TO CLEAR MOTOR. POOH. BIT PARTIALLY PLUGGED. CHANGED OUT MW~). RIH, BREAKING CIRCULATION EVERY 15 STANDS. 03/27/93 45 12419 FINISHED RIH TO 12,030'. SURVEY AND ORIENTED TOOL FACE. WASHED AND REAMED TO 12,364'. DRILLED FROM 12,364' TO 12,415'. SHORT TRIPPED. DRILLED FROM 12,415' TO 12,419'. 03/28/93 46 12438 I DRILLED FROM 12,419' TO 12,438'. PIPE STUCK WHILE ORIENTEERING MOTOR AT 12,400'. W~)RKED SAME FREE, UNABLE TO REAM PAST 12,400'. CBU. SHORT TRIPPED TO CASING SHOE. CBU. POOH, RABBIT DP. 03/29/93 47 12438 L/D BHA. M/U 3 1/2" LINER WITH 2 1/16" WASH STRING. RIH WITH LINER ON DRILL PIPE. SET PACKER AT 11,921 WITH SHOE AT 12,436'. DISPLACED LINER WITH 3% KCL. POOH TO 11,916' WITH WASH STRING. 03/30/93 48 12438 DISPLACED MUD WITH FILTERED INLET WATER. DISPLACED FIW WITH 3% KCL. CIRCULATED AND FILTERED FLUID. POOH, L/D DRILL PIPE. 03/31/93 49 12438 FINISH POOH, L/D DRILLPIPE, DC'S AND WASH STRING. R/U TO RUN PROD TUBING. STARTED RUNNNING 3 1/2" AND 4 1/2" PRODUCTION TUBING. 04/01/93 50 12438 FINISHED RUNNING TUBING. SPACED OUT. MADE UP PUP JOINTS AND TUBING HANGER. LANDING JOINT PULLED OUT OF TUBING HANGER PRIOR TO LANDING. WAITED ON SPEAR. SPEARED TUBING HANGER AND PULLED TO SURFACE. POOH WITH TUBING TO SAFETY VALVE. RAN AND SET STORM PACKER. STARTED NIPPLING DOWN TO INSPECT TUBING SPOOL. 04/02/93 51 12438 NIPPLED DOWN AND INSPECTED TUBING SPOOL. NIPPLED UP. POOH WITH STORM PACKER. POOH WITH TUBING STRING. CHANGED LOWER SEALS ON SEAL ASSEMBLY. RIH WITH 3.5" TUBING. SET STORM PACKER. STARTED N/D FOR TUBING SPOOL REPLACEMENT. 04/03/93 52 12438 N/U NEW TUBING SPOOL AND TESTED. N/U BOP BREAKS AND TESTED. RETRIEVED STORM PACKER. RIH WITH 4.5" TUBING TESTING BREAKS TO 5000 PSI EXTERNALLY. TAGGED FILL AT 11900' AND WASHED TO TOP OF PACKER AT 11921'. STUNG SEALS 2' INTO PACKER. CIRCULATED TWO HIGH VIS SWEEPS WITH LARGE AMOUNT OF SAND ACROSS SHAKERS. R/U UP OTIS TO BAIL. 04/04/93 53 12438 CIRCULATED. R/U OTIS AND MADE FIVE BAILER RUNS. R/D OTIS. CIRULATED AND SWEPT HOLE WITH HI VIS PILL. STABBED INTO PACKER WITH OPERATION SUMMARY REPORT WELL: D-TRD2 04/05/93 04/06/93 54 55 12438 12438 SEAL ASSEMBLY. SPACED OUT AND M/U TUBING HANGER. CIRCULATED HOLE WITH FILTERED INLET WATER PRIOR TO DISPLACING WITH KCL. CIRCULATED WELL WITH FILTERED INLET WATER. DISPLACED WITH KCL COMPLETION FLUID. CIRCULATED AND FILTERED FLUID. STUNG SEAL ASSEMBLY INTO PACKER AND LANDED HANGER. SET BPV. N/D BOPS AND N/U TREE AND FLOWLINE. CLEAR RIG CELLAR. PREPARE RIG FLOOR TO R/U SLICKLINE. R/U SLICKLINE. TESTED LUBRICATOR AND BOPS. RIH WITH BAILER. BAILED FROM 11957' TO 11976'. RECOVERED THREE GALLONS OF SAND IN EIGHT RUNS. R/D SLICKLINE. TURNED WELL OVER TO PROOUCTION. MARATHON 0IL Company Structure : DOLLY VARDEN Platform Well: D-7 Field : McArthur River Field Location : TBU, Cook Inlet, Alaska 9~o_ - - 9260_ _ 92~0_ ~o,~ ~: ,o.oo E o s t - - > 4460 4480 4,500 4520 4540 456(} 4580 4600 4620 4~40 4660 46.804700 4720 4740 4760 4780 a,8004820 4~40 I I I i I I I I I i I I I I I I I I I I I I I I I I 1 RECEiVeD 'A~chorage _5720 _ _5700 5520 _ _5500 o _ _,5480 .. _ ] I t [ I I I [ [ I [ I I I I / I [ [ I I [ [ I I ] ] I I [ [ I I [ [ [ [ I ] [ ] I [ I [ [ 7040 7060 7080 7100 7120 7140 7160 7180 7200 72.2D 7240 7260 7280 7500 7520 7,3407560 7380 7400 7420 7440 7460 7480 75 Scote 1 : 10.00 Verficol Section on 39.57 ozimufh with reference 0.00 N. 0.00 W from slot #A2-4 ORIGINAL MARATHON Oil Company DOLLY VARDEN Platform D-7Rd#2 slot #A2-4 McArthur River Field TBU, Cook Inlet, Alaska SURVEY LISTING by Eastman Teleco Your ref : PMSS <12052 - 12438'> Our ref : svy3742 License : Date printed : 8-Jun-93 Date created : 15-Mar-93 Last revised : 29-Mar-93 Field is centred on n60 50 4.803,w151 36 18.018 Structure is centred on nCO 48 20.815,w151 38 22.052 Slot location is nCO 48 28.300,w151 37 59.155 Slot Grid coordinates are N 2490840.952, E 208385.160 Slot local coordinates are 760.10 N 1135.90 E Reference North is True North MARATHON Oil Company DOLLY VARDEN PlatformwD-7Rd#2 McArthur River Field,TBU, Cook Inlet, Alaska SURVEY LISTING Page 1 Your ref : PMSS <12052 - 12438'> Last revised : 29-Mar-93 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 12052.00 32.06 45.66 9196.38 5489.95 N 4503.03 E 0.00 7057.60 12055.00 33.30 40.50 9198.90 5491.13 N 4504.13 E 101.62 7059.21 12059.00 37.20 39.70 9202.17 5492.90 N 4505.62 E 98.18 7061.51 12063.00 42.40 45.30 9205.24 5494.78 N 4507.35 E 157.79 7064.06 12067.00 48.30 45.30 9208.05 5496.78 N 4509.38 E 147.50 7066.91 12070.00 53.30 45.30 9209.95 5498.42 N 4511.03 E 166.67 7069.23 12073.00 58.10 45.30 9211.64 5500.16 N 4512.79 E 160.00 7071.71 12076.00 60.40 45.30 9213.17 5501.97 N 4514.62 E 76.67 7074.29 12079.00 64.70 45.30 9214.56 5503.84 N 4516.51 E 143.33 7076.95 12082.00 69.40 45.30 9215.72 5505.79 N 4518.48 E 156.67 7079.71 12085.00 74.10 45.30 9216.66 5507.79 N 4520.50 E 156.67 7082.56 12088.00 78.60 45.30 9217.37 5509.84 N 4522.57 E 150.00 7085.47 12091.00 82.30 45.30 9217.87 5511.92 N 4524.67 E 123.33 7088.43 12094.00 85.60 45.30 9218.19 5514.02 N 4526.79 E 110.00 7091.41 12097.00 88.20 48.20 9218.35 5516.07 N 4528.98 E 129.72 7094.41 12100.00 90.00 50.00 9218.40 5518.03 N 4531.24 E 84.84 7097.40 12103.00 91.50 50.10 9218.36 5519.96 N 4533.54 E 50.11 7100.39 12106.00 92.20 50.90 9218.26 5521.87 N 4535.86 E 35.42 7103.38 12111.00 93.10 51.70 9218.03 5524.99 N 4539.75 E 24.07 7108.35 12116.00 93.50 52.50 9217.74 5528.06 N 4543.69 E 17.86 7113.31 12121.00 93.60 53.30 9217.43 5531.07 N 4547.67 E 16.09 7118.26 12126.00 93.40 53.30 9217.13 5534.05 N 4551.67 E 4.00 7123.21 12131.00 92.80 54.90 9216.86 5536.98 N 4555.72 E 34.13 7128.15 12136.00 92.20 55.70 9216.64 5539.82 N 4559.82 E 19.99 7133.07 12146.00 90.60 58.10 9216.39 5545.28 N 4568.20 E 28.84 7142.88 12156.00 89.40 59.70 9216.39 5550.44 N 4576.76 E 20.00 7152.61 12166.00 89.40 62.10 9216.50 5555.31 N 4585.50 E 24.00 7162.26 12176.00 89.60 63.70 9216.58 5559.86 N 4594.40 E 16.12 7171.81 12186.00 89.80 65.30 9216.64 5564.17 N 4603.42 E 16.12 7181.27 12196.00 90.40 66.90 9216.62 5568.22 N 4612.57 E 17.09 7190.64 12206.00 91.20 69.30 9216.48 5571.95 N 4621.84 E 25.30 7199.88 12216.00 92.20 69.30 9216.18 5575.48 N 4631.19 E 10.00 7209.04 12226.00 92.80 70.90 9215.75 5578.88 N 4640.59 E 17.07 7218.13 12236.00 93.20 69.30 9215.22 5582.28 N 4649.98 E 16.47 7227.22 12246.00 94.80 70.90 9214.53 5585.68 N 4659.36 E 22.60 7236.31 12256.00 98.50 70.90 9213.37 5588.92 N 4668.74 E 37.00 7245.29 12266.00 101.50 66.10 9211.63 5592.53 N 4677.90 E 55.98 7254.36 12276.00 102.80 64.50 9209.53 5596.62 N 4686.78 E 20.34 7263.57 12286.00 103.50 63.70 9207.25 5600.87 N 4695.54 E 10.47 7272.80 12296.00 104.20 62.90 9204.86 5605.23 N 4704.22 E 10.46 7282.06 12306.00 101.10 58.90 9202.67 5609.98 N 4712.74 E 49.84 7291.47 12316.00 93.70 54.00 9201.38 5615.46 N 4720.99 E 88.51 7301.20 12326.00 85.20 53.30 9201.48 5621.38 N 4729.04 E 85.29 7311.09 12336.00 77.40 52.50 9202.99 5627.33 N 4736.92 E 78.40 7320.89 12346.00 75.00 54.10 9205.37 5633.14 N 4744.70 E 28.59 7330.52 12356.00 77.00 54.10 9207.79 5638.83 N 4752.56 E 20.00 7340.11 12366.00 78.90 53.30 9209.88 5644162 N 4760.44 E 20.55 7349.80 12376.00 79.70 52.50 9211.74 5650.54 N 4768.28 E 11.22 7359.54 12386.00 80.70 50.10 9213.44 5656.70 N 4775.97 E 25.68 7369.35 12396.00 82.70 47.70 9214.88 5663.21 N 4783.42 E 31.05 7379.23 All data is in feet unless otherwise stated Coordinates from slot #A2-4 and TVD from wellhead (106.90 Ft above mean sea level Vertical section is from N 0.00 W 0.00 on azimuth 45.66 degrees. Declination is 0.00 degrees, Convergence is -1.43 degrees. Calculation uses the minimum curvature method. Presented by Eastman Teleco MARATHON Oil Company DOLLY VARDEN Platform,D-7Rd~2 McArthur River Field,TBU, Cook Inlet, Alaska SURVEY LISTING Page 2 Your ref : PMSS <12052 - 12438'> Last revised : 29-Mar-93 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 12406.00 88.90 46.90 9215.61 5669.97 N 4790.75 E 12416.00 93.50 46.90 9215.40 5676.80 N 4798.05 E 12438.00 102.89 44.55 9212.27 5691.98 N 4813.62 E 62.51 7389.19 46.00 7399.18 43.97 7420.94 Projected Data - NO SURVEY All data is in feet un[ess otherwise stated Coordinates from slot #A2-4 and TVD from wellhead (106.90 Ft above mean sea level Vertical section is from N 0.00 ~ 0.00 on azimuth 45.66 degrees. Declination is 0.00 degrees, Convergence is -1.43 degrees. Calculation uses the minimum curvature method. Presented by Eastman Teleco MARATHON Oil Company SURVEY LISTING Page 3 DOLLY VARDEN Platform,D-7Rd#2 Your ref : PMSS <12052 - 12438'> McArthur River Field,TBU, Cook Inlet, Alaska Last revised : 29-Mar-93 Comments in wellpath MD TVD Rectangular Coords. Comment 12438.00 9212.27 5691.98 N 4813.62 E Projected Data - NO SURVEY All data is in feet unless otherwise stated Coordinates from slot #A2-4 and TVD from wellhead (106.90 Ft above mean sea level Bottom hole distance is 370.52 on azimuth 56.96 degrees from wellhead. Vertical section is from N 0.00 W 0.00 on azimuth 45.66 degrees. Declination ts 0.00 degrees, Convergence is -1.43 degrees. Calculation uses the minimum curvature method. Presented by Eastman Teleco ORI IN4L HARATHON O[L Company DOLLY VARDEN Platform D-TRd82 slot #A2-4 McArthur River Field TBU, Cook Inlet, Alaska SURVEY LISTING by Eastman Teleco Your ref : PMSS <12052 - 12438'> Our ref : svy3742 License : Date printed : 13-Apr-93 Date created : 15-Mar-93 Last revised : 29-Mar-93 Field is centred on n60 50 4.803,w151 36 18.018 Structure is centred on n60 48 20.815,w151 38 22.052 Slot location is n60 48 28.300,w151 37 59.155 Slot Grid coordinates are N 2490840.952, E 208385.160 Slot local coordinates are 760.10 N 1135.90 E Reference North is True North MARATHON OIL Company DOLLY VARDEN Platform,D-TRd~2 HcArthur River Field,TBU, Cook Inlet, Alaska SURVEY LISTING Page 1 Your ref : PMSS <12052 - 12438'> Last revised : 29-Mar-93 Measured Inc[in. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 12052.00 32.06 45.66 9196.38 5489.95 N 4503.03 E 0.00 7057.60 12055.00 33.30 40.50 9198.90 5491.13 N 4504.13 E 101.62 7059.21 12059.00 37.20 39.70 9202.17 5492.90 N 4505.62 E 98.18 7061.51 12063.00 42.40 45.30 9205.24 5494.78 N 4507.35 E 157.79 7064.06 12067.00 48.30 45.30 9208.05 5496.78 N 4509.38 E 147.50 7066.91 12070.00 53.30 45.30 9209.95 5498.42 N 4511.03 E 166.67 7069.23 12073.00 58.10 45.30 9211.64 5500.16 N 4512.79 E 160.00 7071.71 12076.00 60,40 45.30 9213.17 5501.97 N 4514.62 E 76.6? 7074.29 12079.00 64.70 45.30 9214.56 5503.84 N 4516.51 E 143.33 70?6.95 12082.00 69.40 45.30 9215.72 5505.79 N 4518.48 E 156.67 7079.71 12085.00 74.10 45.30 9216.66 5507.79 N 4520.50 E 156.67 7082.56 12088.00 78.60 45.30 9217.37 5509.84 N 4522.57 E 150.00 7085.47 12091.00 82.30 45.30 9217.87 5511.92 N 4524.67 E 123.33 7088.43 12094.00 85.60 45.30 9218.19 5514.02 N 4526.79 E 110.00 7091.41 12097.00 88.20 48.20 9218.35 5516.07 N 4528.98 E 129.72 7094.41 12100.00 90.00 50.00 9218.40 5518.03 N 4531.24 E 84.84 7097.40 12103.00 91.50 50.10 9218.36 5519.96 N 4533.54 E 50.11 7100.39 12106.00 92.20 50.90 9218.26 5521.87 N 4535.86 E 35.42 7103.38 12111.00 93.10 51.70 9218.03 5524.99 N 4539.75 E 24.07 7108.35 12116.00 93.50 52.50 9217.74 5528.06 N 4543.69 E 17.86 7113.31 12121.00 93.60 53.30 9217.43 5531.07 N 4547.67 E 16.09 7118.26 12126.00 93.40 53.30 9217.13 5534.05 N 4551.67 E 4.00 7123.21 12131.00 92.80 54.90 9216.86 5536.98 N 4555.72 E 34.13 7128.15 121~.00 92.20 55.?0 9216.64 5539.82 N 4559.82 E 19.99 7133.07 12146.00 90.60 58.10 9216.39 5545.28 N 4568.20 E 28.84 7142.88 12156.00 89.40 59.70 9216.39 5550.44 N 4576.76 E 20.00 7152.61 12166.00 89.40 62.10 9216.50 5555.31 N 4585.50 E 24.00 7162.26 12176.00 89.60 63.70 9216.58 5559.86 N 4594.40 E 16.12 7171.81 12186.00 89.80 65.30 9216.64 5564.17 N 4603.42 E 16.12 7181.27 12196.00 90.40 66.90 9216.62 5568.22 N 4612.57 E 17.09 7190.64 12206.00 91.20 69.30 9216.48 5571.95 N 4621.84 E 25.30 7199.88 12216.00 92,20 69.30 9216.18 5575.48 N 4631.19 E 10.00 7209.04 12226.00 92.80 70.90 9215.75 5578.88 N 4640.59 E 17.07 7218.13 122~6.00 93.20 69.30 9215.22 5582.28 N 4649.98 E 16.47 722?.22 12246.00 94.80 70.90 9214.53 5585.68 N 4659.36 E 22.60 7236.31 12256.00 98.50 70.90 9213.37 5588.92 N 4668.74 E 37.00 7245.29 12266.00 101.50 66.10 9211.63 5592.53 N 4677.90 E 55.98 7254.36 12276.00 102.80 64.50 9209.53 5596.62 N 4686.78 E 20.34 7263.57 12286.00 103.50 63.70 9207.25 5600.87 N 4695.54 E 10.47 7272.80 12296.00 104.20 62.90 9204.86 5605.23 N 4704.22 E 10.46 7282.06 12306.00 101.10 58.90 9202.67 5609.98 N 4712.74 E 49.84 7291.47 12316.00 93.70 54.00 9201.38 5615.46 N 4?20.99 E 88.51 7301.20 12326.00 85.20 53.30 9201.48 5621.38 N 4729.04 E 85.29 7311.09 12336.00 77.40 52.50 9202.99 5627.33 N 4736.92 E 78.40 7320.89 12346.00 75.00 54.10 9205.37 5633.14 N 4744.70 E 28.59 7330.52 12356.00 77.00 54.10 9207.79 5638.83 N 4752.56 E 20.00 7340.11 12366.00 78.90 53.30 9209.88 5644.62 N 4?60.44 E 20.55 7349.80 12376.00 79.70 52.50 9211.74 5650.54 N 4768.28 E 11.22 7359.54 12386.00 80.70 50.10 9213.44 5656.70 N 4775.97 E 25.68 7369.35 12396.00 82.70 47.70 9214.88 5663.21 N 4783.42 E 31.05 7379.23 All data is in feet unless otherwise stated Coordinates from slot #A2-4 and TVD from wellhead (106.90 Ft above mean sea level Vertical section is from N 0.00 W 0.00 on azimuth 45.66 degrees. Declinatiorl is 0.00 degrees, Convergence is -1.43 degrees. Calculation uses the minimum curvature method. Presented by Eastman Teleco MARATHON OZL Company DOLLY VARDEN PLatform, D-TEc~2 McArthur River Field,TBU, Cook Inlet, Alaska SURVEY LISTING Page 2 Your ref : PMSS <12052 - 12438,> Last revised : 29-Mar-93 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 12406.00 88.90 46.90 9215.61 5669.97 N 4790.75 E 62.51 7389.19 12416.00 93.50 46.90 9215.40 5676.80 N 4798.05 E 46.00 7399.18 12438.00 102.89 44.55 9212.27 5691.98 N 4813.62 E 43.97 7420.94 Projected Data - NO SURVEY ~?~ias~a (Ill & ~s 6ons. (~o!-m~',ssio," All data is in feet unless otherwise stated Coordinates from slot #A2-4 and T~ fr~ wellhead (106.90 Ft a~ve ~an sea level ~C~O~'a{~8 Vertical section is fr~ N 0.00 ~ 0.00 ~ azi~th 45.~ degrees. D~li~ti~ is 0.00 degr~s, C~verg~e is -1.4~ degrees. Calculation uses the mini~ curvature ~th~. Present~ by East~n Te[~o MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to: David W Johpst~n Chairman~ date: April 7, 1993 file: 032493.doc , thru: Blair E Wondzell ~ subject: Sr Petr Engineer from: ~B~bby Foster Petr Inspector BOP test Dolly 76 Union Oil D-7RD2 PTD #92-155 Trading Bay Unit Wednesday, March 24, 1993: I traveled this date to the Dolly Varden platform and witnessed the BOP test on Union Oil Co. rig 76. The test began at 9:30 pm and was concluded at 2:00 am 3/25/93. The two items listed as failUres were non-compliance items. There were no covers over the blind ram controls at the accumulator and at the platform SD station. This is to be corrected and an AOGCC rep notified. The location of the accumulator unit, which.is located in a very small room on the rig floor, was a point I discussed with Lance Lamons, Union rep, and'Holly Waldon, PAA toolpusher. They both agreed with me that the room was too small and it would be hard to do any maintenance on the unit, especially the accumulator bottles. They said they would give it some thought as how to correct the problem. Summary: I witnessed the BOP test on Union Oil Co.'s rig 76. Test time was 4 1/2 hours. There were 2 non-compliance items. Attachment STATE OF ALASKA /~I~iL,/ ~.~/~.~ ~Ji~l~l~,l'~V/'~ I I~1~ ~lVIl~li~l~ll BOPE Test Repo~ Drip' ~ Workover' DATE: Well Name; x~/ .~z ~ _ : .... _ ....... , ~ ' . _- -/ . - . - ...... Operator: U~¢~ / ~ Rep.; /~~ . ~~ ...... Drig Co.tractor: ~-)--~¢% ......... ~i~No. ~¢_~ Rep.: -~o//~ ' ~,"' Sot" ¢ ..... Location' Sec Casing Size: ~ ~ 8 /~ .~ .... - ~"~ ' Test: Initial Wookly ~ Other .......... Test MISC. INSPECTIONS: Location Gen.' ~ Housekeeping: (Gan) Reserve Pit ~ / , BOP STACK: Qua, Ann. Preventer Pipe Rams ___ /__ Blind Rams / ChldLn Valves HCR Valves / Kill Line Valve~ Check Valve Well Sign Drl, Rig '['es[ Pressure PIF MUD SYSTEM: Visual Alarm Trip Tank Pit Level Indicators , Flow Indicator Gas Detectors ~'~ FLOOR SAFETY VALVES: Upper KELLY/IBOP Lower KELLY/IBOP Ball Type Inside BOP Quan Pressure P/F ./... 1_. ..... CHOKE MANIFOLD: No Flanges Manual Chokes Hydrauli6 Chokes ACCUMULATOR SYSTEM: System Pressure r2~'~ 6~ .. l~__ Pressure After Closure //-//~"0 l .'~'. _. 200 psi Attained After Closure -- minutes ~ / sec. System Pressure Attained ~ minutes~.~sec. Blind Switch Covers: Minster: '/y"D Remote:~,/~ Nitgn, Btrs: ~ ~.~ Numu~r o~"l~i~'~s- :'--:' ' '" ..................... ' ............' ........ :' ' ' Hours Number of valves tested .,~,_..~...... Repair or Replacement of Failed Equipment shall be made within days. Notify lhe Inspector on duty and follow with Written or Faxed verification to the AOGCE Commission Office at: Fax No.: 276.7542 Inspector North Slope Pager No, 659-3607 If your call is not returned by the inspector wi~Jn 12 hours, please contact t~e P. I Super~sor at 279.1433, Distribution: orig-Well File c - Oper,/RJg c - Database c. Trip Rpt File c -Inspector STATE WITNESS YES ~//' NO~ 24 HOUR NOTICE GIVEN YES p// NO ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 February 18, 1993 Gary S. Bush Drilling Mgr. UNOCAL P O Box 190247 Anchorage, AK 99510-0247 Re: Trading Bay D-7RD2 UNOCAL Permit No. 92-155 Sur. Loc. 760'FSL, l136'FWL, Sec. 6, T8N, R13W, SM Btmnhole Loc. 1343'FSL, 742'FWL, Sec. 32, T9N, R13W, SM Dear Mr. Bush: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole.' Notice may be given by contacting the Commission at 279-1433. S, Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc.- Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ prinred on recycled paper b y STATE OF ALASKA ALASKA (JIL AND GAS CONSERVATION CC.,,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill - Redrill _xI lb. Type of well. Exploratory - Stratigraphic Test '- Development Oil :X Re-Entry - Deepen--I Service -- Developement Gas '- Single Zone - Multiple Zone 2. Name of Operator UNOCAL (Marathon Oil Company-Suboperator) 3. AddressP.O. Box 190247 Anchorage, Alaska 99510-0247 4. Location of wellatsurface Leg A-2 ~ion 4 760'FSL, l136'F~CL, SEC.6, T8N, R13W, S.M. Attop of productiveintervat 994'FSL,384'FWL, SEC.32,T9N,R13W,SM@9215'TVD Attotaldepth 1343'FSL,742'FWL,SEC.32,T9N,R13W,SM @9215'TV 12. Distance to nearest property line 5500 13. Distance to nearest well 1500 feet 5. Datum Elevation (DF or KB) 106'KB Above MSL feet 6. Property Designation ADL 17594 7. Unit or property Name Trading Bay 8. Well nu ,mber D-7RZ)2 9. Approximate spud date D 2-15-91 14. Number of acres in property 10. Field and Pool McArthur River Field Hemlock Pool 11. Type Bond ,see 20 AAC 25.025~ Number 5194234 Amount $200,000 feet 16. To be completed for deviated wells 17. Anticipated pressure fsee 20 AAC 25.035 Kickoff depth 12,030 ~feet Maximum hole angle 900 Maximum surface 2743 ;~,a. At tota, oeoth,'r'./D~ 3800 9,215' TVD feet 18. Casing program Settinq Depth size Specifications Top Bottom Hole Casing Weight GradelCouplinglLength MD t TVD I MD I 33" SURF.~CE 1398I 9 5/8" 470 N-80 BTC SURF{CE 19665 19. To be completed for Redritl, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Quantity of cement TVD (include stage datal 398 2495 2400 SX 7049 2015 SX · ,]:000 · SX Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 398 33" 2717 13 3/8" 2400 SX 9665' 9 5/8" 2015 SX 3686 7" 100 SX measured true vertical Measured depth True Vertical depth 398' 398' 2717' 2495' 9665' 7049' 12,030 9192' 20. Attachments Filing fee _~ Property plat ~ BOP Sketch ~ DiverterSketch - Drilling program ~ Drilling fluid program ~ Time vs depth plot ~- Refraction analysis -- Seabed report - 20 AAC25.050 requirements _ 21. I hereby c~tify that the foregoing is true and correct to the best of my knowledge Signed , ,...,..~ ~,,, Title ,\\ Permit Numbe~ '~' APl number j App~a~ ~,~ I See cover letter ¢~ -~,~ 50--~ - ~ O//~- ~ ~ for other requirements Conditions of approval Samples required - Yes ~ No Mud Icg required - Yes Hydrogen sulfide measures % Yes ~ No Directional survey required ~Yes - No Required working prepare for ~PE %2M; X3M; - 5M; - 10M; - 15M Other: ~rlgina~ o.~gned By by order of Approved by Commissioner the commission Date.~ //~]~ b..LUNG AND COMPLETION PROGRAM MARATHON OIL COMPANY ALASKA REGION WELL: D-7RD2 LEG: A-2 SLOT: 4 FIELD: AFE No: TYPE: Trading Bay Unit, Dolly Varden Platform 8327-2 Hemlock Bench 1 Horizontal Producer REVISION NO.: 0 DATE: 11/19/92 SURFACE LOCATION: TARGET LOCATION: BO'I-I'OM HOLE LOCATION: 760 FSL, 1136' FWL, Sec.6,T8N, R 13W, S. M. 994'FSL, 384'FWL, Sec.32,T9N,R13W, S.M.@ 9215'TVD 1343'FSL, 742'FWL, Sec.32,T9N,R13W, S.M.@ 9215'TVD KB ELEVATION: 106 ft. GL ELEVATION: 0 ft. MSL ESTIMATED FORMATION TOPS FORMATION DEPTH(MD) POTENTIAL DEPTH(TVD) CONTENT Hemlock, Bench 1 12030 9192 oil/water TYPE SIZE CASING PROGRAM WT. GRADE SET SET HOLE THREAD FROM TO SIZE CONDUCTOR: 33" Surf 398' Existing SURFACE: 13 3/8" 72.00 N-80 BTC Surf 2717' Existing INTERMEDIATE: 9-5/8" 47.0 N-80 BTC Surf 9665' Existing PRODUCTION: (Liner) Production interval 7" 29.0 N-80 BTC 9226' 12912' Existing OPENHOLE 12030' 12576' 6" CASING DESIGN Note: Casing is in place SIZE SETTING FRAC GRD FORM PRSS DESIGN FACTORS WEIGHT GRADE DPTH,TVD @SHOE MASP TENS COLL BURST 9-5/8" 47# N-80 7049 N/A N/A 2743 N/A N/A 1.38 7" 29# N-80 9192 17 3800 2743 N/A N/A 1.64 Page1 F'~WOUT PREVENTERS The blowout preventer stack will consist of a 13-5/8" x 3000 psi Hydril type GK annular preventer and a 13-5/8" x 5000 psi Cameron Type U double gate ram type preventer outfitted with pipe rams in the bottom and blind rams in the top. The riser will be rated 13-5/8" x 5000 psi. The choke manifold will be rated 3-1/16" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor- boy gas buster ,and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mud pits will contain sensors to measure the volume of fluid in the surface mud system. The blowout preventers, choke manifold and associated equipment will be pressure tested to 250 psi and to 3000 psi with the exception of the annular which will be tested to 250 psi and to 2000 psi, The BOPE will be tested every seven days and whenever a flange or seal is broken on the stack. MUD PROGRAM DEPTH DEPTH WEIGHT VISC. WATER MUD TYPE FROM TO ppg sec/qt LOSS 12030' 12035' 8.6-8.9 12035' 12,576' 8.6-8.9 70-250 No control Generic #2 40-50 < 10cc's Xanvis SPECIAL CONSIDERATIONS: Mud discharges will be monitored and reported per EPA requirements. Generic mud #2 will be used while abandoning existing perforations, milling the section, laying the kickoff plug and kicking off of the plug. The Xanvis mud will be used for drilling the final build and lateral sections of the well. MUD EQUIPMENT The solids control equipment consists of an Brandt dual tandem shale shaker, a 2-cone desander and a desilter. WELLHEAD SYSTEM TUBING SPOOL: 13-5/8" 3M X 10" 5M w/x-over double studded adapter Page 2 b.r{ECTIONAL PLAN NORTH DESC MD TVD INCL AZIM COORD EAST COORD VERTICAL SECTION RKB 0 0 0 N0.0W 0 Existing Wellbore Kickoff 12030' 9192' 32.12 N45.71E 5488 Build @ 14.0 deg./100 ft, End of Build #1 12035' 9196' 32.82 N45.71E 5490 Build @ 1.4 deg./ft. End of Build #2 12075' 9215' 90.00 N45.71E 5514 0 4501 4503 4528 0 7046 7049 7084 Total Depth 12576' End of Horizontal Section 9215' 90.00 N45.71E 5863 4886 7584 POTENTIAL INTERFERENCE: WELL TVD TVD on D-7RD2 Distance D-30 R D 6215' 6215' 42 Direction from high side 99.50 Note: D-30RD has been plugged and abandoned and poses no risk from an interference standpoint. LOGGING No logging is planned for this well. CORING PROGRAM No cores are planned for this well. TESTING PROGRAM No open hole tests are planned for this well. Page3 MAXIMUM ANTICIPATED SURFACE PRESSURE MASP = FORMATION PRESSURE- (GAS GRAD.) (FORMATION DEPTH) MASP = 3800 PSI- (.115)(9192) MASP = 2743 PSI PAGE 3a DRILLING r,~OGRAM SUMMARY FOR WELL D-7RD2 LOWER HEMLOCK ABANDONMENT: Kill well with filtered inlet water (FIW). Close SSSV and set BPV. N/D xmas tree and N/U and test BOPE. Release Guiberson Mark VII packer by pulling straight up. POOH and L/D tubing following AKR NORM policy. RIH w/6" bit and 7" casing scraper and clean out fill to approximately 12,420'. POOH. RIH w/7" cmt retainer on wireline and set at 12080' MD. Squeeze lower Hemlock perfs with 75 sx of cement. POOH. SECTION MILLING M/U 7" section mill, RIH, and tag retainer set @ +- 12,080'. Mill section from 12,030'-12,055'. POO RIH with 500' of 3-1/2" tbg stinger and an R'I-rS. Lay a balanced plug from 12,080' to 11,880'. POO leaving bottom of stinger at 11,850'. Reverse out and set R'I-rS. Leave 500 psi on cement for 12 hours. WOC a total of 24 hours..- DRILL HORIZONTAL SECTION: RIH w/6" bit and dress off plug to 12,030' (this will be witnessed by the directional driller). POOH and P/U 4-3/4" kickoff assembly with an AKO motor set at maximum build up rate. RIH and drill 5+- ft. of new hole. Displace hole with Xanvis mud and POOH. M/U Angle Build BHA and RIH until its. from bottom. M/U side-entry sub and wireline to run steering tool. (Note: An MWD will be used it is available resulting in no need for a steering tool.) RIH and orient motor. Drill the curve maintaining the proper orientation. After drilling the curve, POOH and L/D Angle Building BHA. P/ Angle Hold BHA and RIH. (M/U steering tool equipment if necessary.) RIH and ream curve section of hole. Orient motor and drill ahead as necessary to remain in Hemlock Bench 1. When total departure is reached, POOH to Kick Off Point and RIH to check for fill. POOH to KOP. Circulate out drilling fluid with 3% KCI brine. POOH and L/D BHA and drillpipe. COMPLETION: M/U completion assembly including packer and GLM's. RIH and set packer @ +- 12,000'. Unload well to production. Page 4 MARATHON OIL COMPANY DOLLY V ARDEN PLATFORM (~ 3" flowco Lo Torque 5000 psi Valve All F~anges are 3" 5000 Remote Adjus!able Choke 3/4' Manual Choke Pressure Sensor Rig Floor CHOKE MANIFOLD Targeted Tee r '-'-'~ 3" Vent Line Targeted Tee , Targeted Tee Targeted Tee Be Left Open) 3' Ux/ ' 1 1/2" Manual Choke : t ~ I!~~ 3" Bull Plug II 3I~ Targeted Tee 2' Blind Flange 6" to Shaker Choke Line 3' 5000 pst MARATHON OIL COMPANY DOLLY VARDEN PLATFORM BOP STACK Kill Line 3" 5000 psi Drill Deck Floor Flowline I I "~.~ ! 13 5/8'x 5000 psi Annular Preventer Spool Pieces to Casinghead I .... Clamp Connector O '"~ Pipe Rams ! I _~13 5/8" 5000 psi Double Rams Blind~~ams ~-~J' Choke line 3' 5000 MARATHON OIL COMPANY ]~¢A.RTH'UR RJY~R ~ MARATHON OIL Company Structure : DOLLY VARDEN Platform Well : O-7Rd~2 · Field : McArfhur River Field Location : ~,.,, Cook Inlet, Alaska gATE PLOTTED : 27-AUG--92 ~LOT ~EFERENCE ISD-71~D #2($R) VERSION ltl. S30~DINATE$ ARE iNFEET REFERENCE SLOT#A2--4.. -,.qUE VERTICAL DEPTHS AI:;?E REFEP. ENCE WELLHEAD. EASTMAN TEL£CO WELL PROFILE DATA .... .... Po~Fr .... '~r ON ' 2030 32.12 45.7t )I 92 5~B ~501 END 0F 8UI~ ~ 2035 32.82 ~5.71 ~196 5~90 ~5031 ENO OF 8Ul~ '207a 90.~ 45.71 ~21~ 551& ENO OF HOLO ' 2576 90.00 45.71 )215 5863 C*LE,::O.OOEast --> .ca~- 0 z-~O ~,520 4-560 .,~600 4640 ~80 4720 ~760 NOT~S: 12030 - 12035 to be drilled w/ 4 3/4" .~KO Shor~ Radius Angle Build Motor Lo complete curve ~) 1.4 deg / [i Achieves horizontal at 9215' Tvd ,,I, 800 ~-e~O z880 ~.~20 ~.060 ',g60 -5920 ~aeo -5'000 - ~_5760 j ~720 ~6eO Z - 0 - 2600 F 560 ~480 " ~0 2O- ,,,,.. - // 6veo 7o00 70~ 7120 7leo 7200 SCALE ; : 20.00 Vertical Section on 45.8,2 azimuth with reference 4.35 N, 4.47 E from slot #A2-4 7280 73 0 7400 74.-~O 75 0 76 0 7640 7680 MARATHON OIL Company DOLLY VARDEN Platform D-7Rd#2 slot #A2-4 McArthur River Field TBU, Cook Inlet, Alaska PROPOSAL LISTING Your ref : D-7Rd #2(SR) Version #1 Our ref : prop555 Other ref : Date printed : 27-Aug-92 Date created : 23-Jul-92 Last revised : 27-Aug-92 Field is centred on n60 50 4.803,w151 36 18.018 Structure is centred on n60 50 4.803,w151 36 18.018 MARATHON OIL Company DOLLY VARDEN Platform,D-7Rd#2 McArthur River Field,TBU, Cook Inlet, Alaska PROPOSAL LISTING Page 1 Your ref : D-7Rd #2(SR) Version #1 Last revised : 27-Aug-92 {easured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100Ft Sect L2030.00 32.12 L2035.00 32.82 ~2075.84 90.00 .2500.00 90.00 .2575.84 90.00 45.71 9192.15 45.71 9196.37 45.71 9215.11 45.71 9215.11 45.71 9215.11 5488.10 N 4501.13 E 0.00 7046.48 KOP - Sidetrack Point 5489.98 N 4503.05 E 14.00 7049.16 5513.99 N 4527.67 E 140.00 7083.55 TARGET / EOC 5810.19 N 4831.27 E 0.00 7507.71 5863.16 N 4885.56 E 0.00 7583.55 End of 500' Section Ail data is in feet unless otherwise stated Coordinates are from slot #A2-4 and TVDs are from wellhead. Vertical section is from N 4.35 E 4.47 on azimuth 45.82 degrees. Calculation uses the minimum curvature method. MARATHON OIL Company DOLLY VARDEN Platform,D-7Rd#2 McArthur River Field,TBU, Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref : D-7Rd #2(SR) Version #1 Last revised : 27-Aug-92 Comments in wellpath MD TVD Rectangular Coords. Comment 12030.00 9192.15 5488.10 N 4501.13 E 12075.84 9215.11 5513.99 N 4527.67 E 12575.84 9215.11 5863.16 N 4885.56 E KOP - Sidetrack Point TARGET / EOC End of 500' Section Ail data is in feet unless otherwise stated Coordinates are from slot #A2-4 and TVDs are from wellhead. Slot coordinates are 9789.97 S 5035.08 W. Bottom hole distance is 537.08 on azimuth 45.71 degrees from wellhead. Total Dogleg for wellpath is 57.88 degrees. Vertical section is from N 4.35 E 4.47 on azimuth 45.82 degrees. Calculation uses the minimum curvature method. MARATHON OIL Company DOLLY VARDEN Platform D-7Rd#2 slot #A2-4 McArthur River Field TBU, Cook Inlet, Alaska CLEARANCE REPORT Your ref : D-7Rd #2(SR) Version #1 Our ref : prop555 Other ref : Date printed : 1-Sep-92 Date created : 23-Jul-92 Last revised : 1-Sep-92 Field is centred on n60 50 4.803,w151 36 18.018 Structure is centred on n60 50 4.803,w151 36 18.018 ( WARNING: DATA BELOW IS A SUMMARY, DETAIL PROXIMITIES NOT TABULATED ) Object wellpath GMS <0-13585'>,,D-24A,DOLLY VARDEN Platform MSS <2450-10125'>,,D-31,DOLLY VARDEN Platform GMS <0-10628'>,,D-31Rd,DOLLY VARDEN Platform MSS <2742-13908'>,,D-10,DOLLY VARDEN Platform PGMS <8000-12100'>,,D-4Rd,DOLLY VARDEN Platfor Closest approach with 3-D minimum distance method Last revised Distance M.D. Diverging from 4-Nov-91 4654.4 12030.0 12030.0 4-Nov-91 3333.5 12030.0 12030.0 4-Nov-91 2036.9 12030.0 12030.0 4-Nov-91 5513.3 12030.0 12030.0 4-Nov-91 5460.6 12030.0 12030.0 GMS <0-11100'>,,D-4,DOLLY VARDEN Platform MSS <6927-12557'>,,D-2,DOLLY VARDEN Platform MSS <9482-12425'>,,D-2Rd,DOLLY VARDEN Platform GMS <0-11356'>,,D-2ARd,DOLLY VARDEN Platform MSS <l1209-14850'>,,D-22,DOLLY VARDEN Platform GMS <0-14600'>,,D-16,DOLLY VARDEN Platform PGMS <10000-14645'>,,D-16Rd,DOLLY VARDEN Platf MSS <1205-10506'>,,D-20,DOLLY VARDEN Platform MSS <7866-12700'>,,D-14,DOLLY VARDEN Platform GMS <0-13600'>,,D-14Rd,DOLLY VARDEN Platform MSS <6662-12195'>,,D-6,DOLLY VARDEN Platform MSS <l1790-15510'>,,D-6St,DOLLY VARDEN Platfor PGMS <0-13700'>,,D-6Rd,DOLLY VARDEN Platform MSS <8722-13932'>,,D-8,DOLLY VARDEN Platform PGMS <700-12250'>,,D-8Rd,DOLLY VARDEN Platform PGMS <0-13111'>,,D-29Rd,DOLLY VARDEN Platform GMS <100-13050'>,,D-29,DOLLY VARDEN Platform MSS <10913-11930'>,,D-47,DOLLY VARDEN Platform PGMS <0-12970'>,,D-44,DOLLY VARDEN Platform MSS <3550-17010'>,,D-21,DOLLY VARDEN Platform MSS <2730-13462'>,,D-24,DOLLY VARDEN Platform GMS <0-11180'>,,D-34,DOLLY VARDEN Platform PGMS <0-11150'>,,D-43,DOLLY VARDEN Platform GMS <0-11510'>,,D-25Rd,DOLLY VARDEN Platform MSS <8330-11350'>,,D-25,DOLLY VARDEN Platform GMS <0-11905'>,,D-26,DOLLY VARDEN Platform GMS <0-11600'>,,D-41,DOLLY VARDEN Platform GMS <6100-12573'>,,D-40,DOLLY VARDEN Platform PGMS <0-12520'>,,D-40Rd,DOLLY VARDEN Platform MSS <2506-11160'>,,D-32,DOLLY VARDEN Platform GMS <0-12445'>,,D-28,DOLLY VARDEN Platform GMS <0-11000'>,,D-27,DOLLY VARDEN Platform PGMS <0-10300'>,,D-45,DOLLY VARDEN Platform MSS <2727-11000'>,,D-13,DOLLY VARDEN Platform PGMS <8700-11100'>,,D-3Rd,DOLLY VARDEN Platfor GMS <0-10881'>,,D-3,DOLLY VARDEN Platform PGMS <6600-10920'>,,D-3Rd2,DOLLY VARDEN Platfo PGMS <2100-10225'>,,D-15Rd2,DOLLY VARDEN Platf GMS <0-10935'>,,D-15Rd,DOLLY VARDEN Platform MSS <2642-10250'>,,D-5,DOLLY VARDEN Platform GMS <0-10650'>,,D-5Rd,DOLLY VARDEN Platform MSS <3550-16606'>,,D-23,DOLLY VARDEN Platform PGMS <0-10450'>,,D-42,DOLLY VARDEN Platform MSS <6059-16650'>,,D-19St,DOLLY VARDEN Platfor PGMS <0-12345'>,,D-46,DOLLY VARDEN Platform MSS <2944-7950'>,,D-19,DOLLY VARDEN Platform GMS <5600-10700'>,,D-9,DOLLY VARDEN Platform PGMS <0-10900'>,,D-9Rd,DOLLY VARDEN Platform MSS <2701-11682'>,,D-ii,DOLLY VARDEN Platform 4 -Nov- 91 4 -Nov- 91 4-Nov-91 4 -Nov- 91 4-Nov-91 4-Nov-91 4 -Nov- 91 4 -Nov- 91 4-Nov-91 4-Nov-91 4-Nov-91 4 -Nov- 91 4-Nov-91 4 -Nov- 91 4 -Nov- 91 4 -Nov- 91 4 -Nov- 91 4 -Nov- 91 4-Nov-91 4-Nov-91 4 -Nov- 91 4-Nov-91 4-Nov-91 4-Nov-91 4-Nov-91 4 -Nov- 91 4 -Nov- 91 4-Nov-91 4 -Nov- 91 4 -Nov- 91 4 -Nov- 91 4 -Nov- 91 4 -Nov- 91 4 -Nov- 91 4 -Nov- 91 4 -Nov- 91 4 -Nov- 91 4 -Nov- 91 4-Nov-91 4 -Nov- 91 4-Nov-91 4 -Nov- 91 4-Nov-91 4 -Nov- 91 4 -Nov- 91 4-Nov-91 4 -Nov- 91 4-Nov-91 4-Nov-91 5467.5 3507.9 3085.7 4331.7 10345.6 10015.8 10015.8 4586.9 8684.0 8684.0 8013.6 8013.6 8077.5 9108.8 9108.8 2277.0 1878.4 2487.6 5274.0 10006.0 4822.1 5128.2 4692.9 6718.8 6829.8 1622.1 2894.3 5254.2 4248.0 2376.8 2398.7 2961.4 5837.2 8683.1 3022.3 3335.3 2707.4 6478.8 5827.7 6908.8 4545.6 10183.6 2462.3 4107.9 7297.4 4907.0 8282.1 7483.5 4041.6 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12075.8 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12030.0 12075.8 12030.0 12030.0 12030.0 12030.0 12030.0 MSS <10665-11808'>,,D-17,DOLLY VARDEN Platform GMS <0-10800'>,,D-17Rd,DOLLY VARDEN Platform MSS <0-12071'>,,D-1,DOLLY VARDEN Platform MSS <10156-13600'>,,D-30,DOLLY VARDEN Platform GMS <0-12237'>,,D-30Rd,DOLLY VARDEN Platform MSS <2220-8175'>,,D-18,DOLLY VARDEN Platform MSS <9453-12381'>,,D-12,DOLLY VARDEN Platform GMS <0-12050'>,,D-12Rd,DOLLY VARDEN Platform GMS <0-12900'>,,D-7Rd,DOLLY VARDEN Platform GMS <100-13300'>,,D-7,DOLLY VARDEN Platform 4 -Nov- 91 4-Nov-91 4 -Nov- 91 4 -Nov- 91 4 -Nov- 91 4-Nov-91 4 -Nov- 91 4 -Nov- 91 4-Nov-91 4-Nov-91 5301.2 5297.2 1315.2 256.7 41.9 4551.1 8103.3 8103.3 0.0 474.8 12030.0 12030.0 12035.0 12130.0 12280.0 12030.0 12030.0 12030.0 12030.0 12480.0 12030.0 12030.0 12035.0 12130.0 12280.0 12030.0 12030.0 12030.0 12030.0 12480.0 MARATHON OIL Company DOLLY VARDEN Platform D-7Rd#2 slot #A2-4 McArthur River Field TBU, Cook Inlet, Alaska CLEARANCE REPORT Your ref : D-7Rd #2(SR) Version #1 Our ref : prop555 Other ref : Date printed : 1-Sep-92 Date created : 23-Jul-92 Last revised : 1-Sep-92 Field is centred on n60 50 4.803,w151 36 18.018 Structure is centred on n60 50 4.803,w151 36 18.018 Main calculation performed with 3-D minimum distance method Object wellpath Closest approach with 3-D minimum distance method Last revised Distance M.D. Diverging from MSS <10156-13600'>,,D-30,DOLLY VARDEN Platform 4-Nov-91 256.7 12130.0 12130.0 GMS <0-12237'>,,D-30Rd,DOLLY VARDEN Platform 4-Nov-91 41.9 12280.0 12280.0 MARATHON OIL Company DOLLY VARDEN Platform, D-7Rd#2 McArthur River Field,TBU, Cook Inlet, Reference wellpath Alaska CLEARANCE LISTING Page 1 Your ref : D-7Rd #2(SR) Last revised : 1-Sep-92 Version #1 Object wellpath : GMS <0-12237'>,,D-30Rd,DOLLY VARDEN Platform M.D. T.V.D. Rect Coordinates M.D. T.V.D. Angle fm Min'm TCyl Rect Coordinates HighSide Dist Dist 12030.0 9192.1 5488.1N 4501.1E 12032.2 9096.3 5621.6N 4531.0E -27.6 167.0 168.4 12035.0 9196.4 5490.0N 4503.0E 12036.0 9098.9 5622.9N 4533.3E -27.2 167.6 168.9 12130.0 9215.1 5551.8N 4566.4E 12110.0 9149.5 5649.7N 4580.3E -56.4 118.6 163.3 12180.0 9215.1 5586.7N 4602.2E 12145.5 9173.7 5662.7N 4602.8E -61.4 86.5 114.9 12230.0 9215.1 5621.6N 4638.0E 12181.0 9197.9 5675.7N 4625.3E -72.8 58.2 70.8 12280.0 9215.1 5656.6N 4673.8E 12216.5 9222.0 5688.7N 4647.8E -99.5 41.9 42.3 Ail data is in feet unless otherwise stated Coordinates are from slot #A2-4 and TVDs are from wellhead. Vertical section is from N 4.35 E 4.47 on azimuth 45.82 degrees. Calculation uses the minimum curvature method. ALASKA OIL AND GAS CONSERVATION COMMISSION December 29, 1992 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 ADMINISTRATIVE APPROVAL NO. 80.64 Re: The application of Union Oil Company of California, operator of the Trading Bay Unit (TBU), to drill, complete and produce the TBU D-7 Redrill No. 2 (RD 2) well. Mr. Gary S. Bush Regional Drilling Manager UNOCAL Corp. P. O. Box 190247 Anchorage, Ak 99502-0247 Dear Mr. Bush: Your application of December 28, ·1992 for a permit to drill the TBU D-7 RD 2 indicates that the drilling and completion of the TBU D-7 RD 2 well will provide additional oil recovery from the Hemlock Oil Pool. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling and completion of the TBU D-7 RD 2 well pursuant to Rule 5 of Conservation Order No. 80. Sincerely, Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION ,' "--, STATE OF ALASKA '--.- ALA,, , OIL AND GAS CONSERVATION COMMISS .; APPLICATION FOR SUNDRY APPROVALS .,es,,: .~oanclol? _~X SdsDend ~ Ailer casing __ Repair wed __ ~cange aporoved program __ ..f Opera[o: l' 5. Type of Well: JNOCAL (Marathon Oil Company - Sub ~perato~;~;;oe~L .foss ! Stratigraoh~c ~ P.O. Box 190247 Anchorage, AK 9951r9 Service__ ocatr-nO~wellatsudace Le§ A-2, Cond. #4, D6iiy Yarden Pla[run. ~ ~6~' [Si_i 1,136' [Wi_, Sec. 6-SN-13W-$M ,-\t tod cf productive interval 990' FSL, 514' FEL, Sec. 32-9N-13W-SM ,:., effect,ye depth 1,143' FSL, 373' FEL, Sec. 32-9N-13W-SM :..t tOtal depth 1,330' FSL, 199' FEL, Sec. 32-gN-13W-SM ©oerat~on shutdown __ Re-enter sus[)ended well __ Plugging __ Time extension __ St~mulale __ Puli tubing __ Vanance__ Pedorate m Other __ 6. Datum elevation (DF or KB) 106' KB above MSL feet 7. Unit or Properly name Trading Bay Unit 8. Well number D-7RD 9. Permc number 77-82 10, APl number ..3o-733-20117-01 11. Field!Pcql Hemlock ~2 ?~esent well condmon summary .??.ai .C. eDtn: measured (rue vertical 12 915' ' feet Plugs (measured) 9,934' feet 12,420' Guiberson A1 Pkr 12,559' UMT l"cc: '. e :opm' measured 12,420 ' feet Junk (measured) :"Je vertical 9,510 ' feet 12,326' Perf gun fish 12,094' fill ':'ds,nq Lengtn Size Cemented Structural Conductor Su,fface Intermediate 9,665' 9-5/8" 2,015 SX Production Liner 3,686' 7" 1,000 sx F'erforat~on depth: measured true verhcal See Attachment #1 Measured depth 9,665' 12,912' True verl~cal depth 7,049' 9,932' ._ .,E,~na (s~ze, qrade, and measure(] depth) 4-Z/2",-12.6#, N-80 ASL Tbg. to 9,039', 3-1/2", 9.3#, '~J'l~s~r~SS/SV,(ty~§a~i2r~e~-~m) Pkr (2.992" ID) @ 11,899', N-80 ASL 4-1/2" !3..qttacnments Description summary of proposal X Detailed operabons program Tbg from 9,039'to 11,899' K Storm Choke (2.25" BOPsketch_.,,~ II) ~,..z Estimated date for commencing operabon FebruarS 15, 1993 "16 If oroposal was verbally approved ,",lame of approver Date approved Service :7. I heret:)V"~ertify th~the fore_.CL~,OXng ~s~true,-and cor, rect to the best of my knowledge. 15. Status of well classification b L:. I V Oil ~x Gas__ Su~.p~.ded '8-'199;5 Anchorage FOR COMMISSION USE ONLY Condmons of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Co~ F.,3rm 10 403 Rev06/15/88 , - ~ .... ! Approval N~::?, ~----d:) / Commissioner SU IN TRIPLICATE ITEM (1) Fee (2) Loc , , ** CHECK LIST FOR NEW WELL PERMITS ::* APPROVE ~ ['2'~thru , / _ - [10 & 13] · 2. 3. 4. 5. 6. 7. 8. . 10. 11. 12. 13 14. 15. [14 thru 22] [23 thru 28] 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. (6) Other /~2~ /z/~7//~Z~ 29. thru 31] 30. 31. (7) Contact 32. [32] (8) Addl ~-Z~.~ ?-~?-~.g' 33. geology' ~ngineerinq: DWJ~::iL~- MTM~ RADS) 2~-tT.,.- LG rev 12/92 jo/6.011 Company YES Is permit fee attached ............................................... L ..... is well to be located in a defined pool .............................. ~, .. Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... Is sufficient undedicated acreage available in this pool ............. _L Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... t0N Is a Conservation order needed ....................................... Is administrative approval needed ..................... · .............. Is lease number appropriate .......................................... Does well have a unique name & nL~nber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface $ intermediate or production strings ...... Will cement cover all known productive horizons ..................... //~' Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wel l bore separation proposed ............................. Is a diverter System required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of ~ BOPE attached .... Does BOPE have sufficient pressuPe rating -- test to ~OOO psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... Lease & Well NO REMARKS FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone number of contact to supply weekly progress data ...... // / Additional requiremen%s ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~t SHORE " Additional MERIDIAN' remarks' UM TYPE: Exp/Dev ><' In j__ ' - Redr i 1 I _::~' Rev