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196-127
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: 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. T40758TBU M-09 50733204760000 196127 7/18/2025 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: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 4,500 N/A Casing Collapse Structural Conductor Surface 1,950psi Intermediate 4,760psi Production 7,020psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Ryan Rupert Contact Email:Ryan.Rupert@hilcorp.com Contact Phone:(907) 777-8503 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng McArthur River Middle Kenai Gas Pool Same 3,077 4,381 3,016 1,061psi 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 ADL0018730 196-127 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20476-00-00 Hilcorp Alaska, LLC Trading Bay Unit M-09 Length Size Proposed Pools: L-80 TVD Burst 2,409 8,160psi MD 6,870psi 3,450psi 488' 837' 1,450' 488' 838' 3,073'7" 28" 13-3/8" 488' 9-5/8"1,488' 838' Perforation Depth MD (ft): 1,488' 2,590 - 4,298 4,494' 2,120 - 2,976 CO 228A Other: CTCO, N2 Operations 11/27/2024 3-1/2" See schematic See schematic 4,494' No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 12:58 pm, Nov 20, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.11.20 11:59:01 - 09'00' Dan Marlowe (1267) 324-657 A.Dewhurst 21NOV24 DSR-11/21/24 X 10-404 BJM 11/26/24 CT BOP test to 2500 psi *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.11.26 14:45:02 -09'00'11/26/24 RBDMS JSB 112924 CT FCO +Perf add Well: Steelhead M-09 Well Name:M-09 API Number:50-733-20476-00-00 Current Status:Offline Gas Producer Permit to Drill Number:196-127 First Call Engineer:Ryan Rupert (907) 301-1736 (c)Leg B-2 (NE corner) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Maximum Expected BHP:1364 psi @ 3,029’ TVD 0.45psi/ft to deepest proposed perf Max. Potential Surface Pressure: 1061 psi Using 0.1 psi/ft Brief Well Summary M-09 on the Steelhead platform is a Middle Kenai Gas Pool Producer open in several sands currently. The well recently died and stopped producing, from what appears to be water loading. There are some potential bypassed sands to complete. A cleanout is needed to access all potential sands. The goal of this project is to add infill gas sand perfs. All proposed perfs remain within the Middle Kenai Gas Pool Pertinent wellbore information: - Sail angle / max inclination of 60 degrees from ~2100’ MD to TD - SSSV: Hydraulic nipple profile (requires WL-SSSV) -April-2023 o SL tagged at 2454’ MD, and worked down to ~2600’ MD o Fought at 2600’ with bailers for 2 days, and made no hole (occasionally lost some) o Bailers came back full of coarse sand - 10/9/22: o SL tagged at 3061' o Able to work down / clean all the way to 3831' SLMD o Got called off at that depth - 8/12/21 o CT motor and mill to 4381' CTMD, then N2 blowdown. o CT noted tight spots at 3574' and 3860' CTMD. - July-2021: RWO to gravel pack SZ sands, and install smaller tubing (from 7") o Several SZ sands shot, and gravel packed o Run 3-1/2” completion - 1996: Initial cement log after drilling shows corrected PBTD = 4405’ ELMD CT FCO +Perf add Well: Steelhead M-09 Coiled Tubing Procedure 1. MIRU Fox Energy offshore Coiled Tubing and pressure control equipment 2. PT lubricator to 250psi low / 1500psi high 3. MU FCO BHA 4. RIH and cleanout to PBTD or as deep as practical a. Working fluid will be water (8.33ppg or greater) b. Take returns to surface up the CT x tubing annulus c. Add foam and nitrogen as necessary to carry solids to surface d. Can use GL to assist with hole cleaning 5. Once cleanout is completed, blow well down with nitrogen 6. RDMO CT E-Line Perf procedure 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 1500psi high 3. RIH and perforate sands from ±2,420’ – ±4,405’ MD (±2,035’ – ±3,029’ TVD) per RE/Geo a. All proposed perfs within Middle Kenai Gas Pool b. Bottom pool is below PBTD c. Top pool is at 1462’ MD / 1428’ TVD (above shallowest existing production packer) d. Pressures: i. 9-5/8” at 1,450’ TVD: LOT at 16.0 ppg (8/22/96) ii. Worst case pressure could create a 12.0ppg at the top sundried perf (2035’ TVD) 4. RDMO EL CONTINGENCY plug: (if any zone makes unwanted solids or water) 1. RU nitrogen to tubing and PT lines to 1500psi (or higher if needed) 2. Pressure up on tubing and displace water back into formation 3. MIRU E-line and pressure control equipment 4. PT lubricator to 250psi low / 1500psi high 5. Set isolation plug per OE 6. RDMO Nitrogen and EL NOTE: WL-SSSV will need to be pulled, and reinstalled. It must be tested within 14 days of the well being returned to production Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. CT BOP Drawing (Fox energy) 4. Nitrogen procedure Updated By: JLL 11/19/24 SCHEMATIC McArthur River Field Well: M-09 Last Completed: 07/19/21 PTD: 196-127 API: 50-733-20476-00 PBTD: 4,405’ TD: 4,500’ MAX HOLE ANGLE = 61.1º @ 2,701’ 28” RKB: MSL =160’ RKB to Seafloor = 345’ 7” A-2 3 4 5 6 17 20 7 8 11 12 16 TOL 7” @ 1,003’ 13-3/8” 9-5/8” 1 2 TOC @ 756’ 14 15 9 13 A-2 & A-3 A-5A & A-5 TOC @ 1,484’ SZ-18A SZ-23 SZ-20 SZ-24 SZ-22 SZ-18A SZ-19A SZ-19B 10 18 17 19 F X X F CASING DETAIL Size Wt Grade Conn ID Top Btm 28” Surf 488’ 13-3/8” 68 K-55 BTC 12.415 Surf 838’ 9-5/8” 47 L-80 BTC 8.681 Surf 1,488’ 7” 29 L-80 KC Butt 6.184 Surf 1,003’ 7” 29 L-80 NSCC 6.184 1,003’ 4,494’ TUBING DETAIL 3.5” 9.2 L-80 IBT-M 2.922 Surf 2409’ JEWELRY DETAIL No Depth (MD) Depth (TVD) ID Item 72' 72' Tbg Hanger: Assembly #111692 A02, 3-1/2" EUE Lifting Threads Top&Bottom, 3" Type H Profile 1 474’ 474’ ±6” Milled out SSSV Landing Nipple 2 505’ 505’ 2.813 3.5” 2.813 XXO SVLN. Ser. No. 1404764-1 3 1,705’ 1,622’ 2.992” GLM #1 – SFO-2 (unknown GLV) 2,363’ 2,007’ 2.992” GLM #2 – SFO-2 (live GLV) 4 2,410’ 2,030’ 2.992” 7” Hydraulic Retrievable Packer 5 2,426' 2,038' 2.813" 3.5” X nipple (2.813” ID) 6 2,544' 2,097' 2.991" 3.5” 0.012 Ga Wire Wrapped Screen (31jts) (Length 949’) 3,493' 2,570' 2.990" Bottom screen 7 3,497' 2,572' 3.000" Model D Perm Packer 8 3,509' 2,578' 2.813" X-Nipple – (2.813” ID) 9 3,524' 2,586' 4.000" BOT SC-1R PACKER 5-13/16” X 4.00” 10 3,533' 2,590' 4.250" SLIDING SLEEVE 5-13/16” X 4-1/4” 11 3,645' 2,646' 3.563" 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4- 5/8” X 3-9/16” (Length 180’) 12 3,825' 2,734' 3.313" Bottom screen / BOT “F” SEATING NIPPLE 4-3/4” X 3.313” 13 3,828' 2,736' 4.00" BOT SC-1R PACKER 5-13/16” X 4.00” 14 3,837' 2,740' 4.250" SLIDING SLEEVE 5-13/16” X 4-1/4” 15 3,863' 2,753' 3.563" 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4- 5/8” X 3-9/16” (Length 121’) 16 3,984' 2,815' 3.313" Bottom screen / BOT “F” SEATING NIPPLE 4-3/4” X 3.313” 17 3,986' 2,816' 4.000" BOT SC-1R PACKER 5-13/16” X 4.00” 18 3,996' 2,821' 4.250" SLIDING SLEEVE 5-13/16” X 4-1/4” 19 4,127' 2,888' 3.563" 4” .012 GA 140 SCRN W/ 6-1/16” CENT IN MID & PIN END 4- 5/8” X 3-9/16” (Length 181’) 4,308' 2,980' 3.250" Bottom screen 20 4,308' 2,980' 3.250" BOT “DA” SUMP PACKER 5-11/16” X 4” X 3-1/4” Updated By: JLL 11/19/24 McArthur River Field Well: M-09 Last Completed: 07/19/21 PTD: 196-127 API: 50-733-20476-00 SCHEMATIC PERFORATION DETAIL (Tie-In Log Intervals - DIL Depths) Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT SPF Date COMMENTS SZ-18A 2,590’ 2,600’ 2,120 2,125’ 10’ 6 11/08/17 2-7/8” 6 SPF Razor Carrier SZ-18A 2,600’ 2,646’ 2,124’ 2,147’ 46’ 02/13/21 Open SZ-19A 2,806’ 2,818’ 2,225’ 2,231’ 12’ 12 07/16/21 Open SZ-19B 2,833’ 2,844’ 2,239’ 2,244’ 11’ 12 07/16/21 Open SZ-20 2,982’ 3,010’ 2,314’ 2,329’ 28’ 12 07/16/21 Open SZ-22 3,221’ 3,241’ 2,434’ 2,444’ 20’ 12 07/16/21 Open SZ-22 3,246’ 3,266’ 2,447’ 2,457’ 20’ 12 07/16/21 Open SZ-22 3,270’ 3,290’ 2,459’ 2,469’ 20’ 12 07/16/21 Open SZ-23 3,320’ 3,330’ 2,484’ 2,488’ 10’ 12 07/16/21 Open SZ-24 3,451’ 3,476’ 2,550’ 2,562’ 25’ 12 07/16/21 Open A2 3,677' 3,681' 2,662' 2,664' 4' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,689' 3,704' 2,668' 2,676' 15' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,710' 3,816' 2,679' 2,731' 106' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2A 3,868' 3,902' 2,757' 2,774' 34' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 3,942' 3,948' 2,794' 2,797' 6' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 3,970' 3,977' 2,808' 2,812' 7' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A5A 4,151' 4,165' 2,901' 2,909' 14' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,186' 4,248' 2,919' 2,951' 62' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,266' 4,298' 2,960' 2,976' 32' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE Updated By: JLL 11/20/24 PROPOSED McArthur River Field Well: M-09 Last Completed: 07/19/21 PTD: 196-127 API: 50-733-20476-00 PBTD: 4,405’ TD: 4,500’ MAX HOLE ANGLE = 61.1º @ 2,701’ 28” RKB: MSL =160’ RKB to Seafloor = 345’ 7” A-2 3 4 5 6 17 20 7 8 11 12 16 TOL 7” @ 1,003’ 13-3/8” 9-5/8” 1 2 TOC @ 756’ 14 15 9 13 A-2 & A-3 A-5A & A-5 TOC @ 1,484’ SZ-18A SZ-23 SZ-20 SZ-24 SZ-22 SZ-18A SZ-19A SZ-19B 10 18 17 19 F X X F CASING DETAIL Size Wt Grade Conn ID Top Btm 28” Surf 488’ 13-3/8” 68 K-55 BTC 12.415 Surf 838’ 9-5/8” 47 L-80 BTC 8.681 Surf 1,488’ 7” 29 L-80 KC Butt 6.184 Surf 1,003’ 7” 29 L-80 NSCC 6.184 1,003’ 4,494’ TUBING DETAIL 3.5” 9.2 L-80 IBT-M 2.922 Surf 2409’ JEWELRY DETAIL No Depth (MD) Depth (TVD) ID Item 72' 72' Tbg Hanger: Assembly #111692 A02, 3-1/2" EUE Lifting Threads Top&Bottom, 3" Type H Profile 1 474’ 474’ ±6” Milled out SSSV Landing Nipple 2 505’ 505’ 2.813 3.5” 2.813 XXO SVLN. Ser. No. 1404764-1 3 1,705’ 1,622’ 2.992” GLM #1 – SFO-2 (unknown GLV) 2,363’ 2,007’ 2.992” GLM #2 – SFO-2 (live GLV) 4 2,410’ 2,030’ 2.992” 7” Hydraulic Retrievable Packer 5 2,426' 2,038' 2.813" 3.5” X nipple (2.813” ID) 6 2,544' 2,097' 2.991" 3.5” 0.012 Ga Wire Wrapped Screen (31jts) (Length 949’) 3,493' 2,570' 2.990" Bottom screen 7 3,497' 2,572' 3.000" Model D Perm Packer 8 3,509' 2,578' 2.813" X-Nipple – (2.813” ID) 9 3,524' 2,586' 4.000" BOT SC-1R PACKER 5-13/16” X 4.00” 10 3,533' 2,590' 4.250" SLIDING SLEEVE 5-13/16” X 4-1/4” 11 3,645' 2,646' 3.563" 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4- 5/8” X 3-9/16” (Length 180’) 12 3,825' 2,734' 3.313" Bottom screen / BOT “F” SEATING NIPPLE 4-3/4” X 3.313” 13 3,828' 2,736' 4.00" BOT SC-1R PACKER 5-13/16” X 4.00” 14 3,837' 2,740' 4.250" SLIDING SLEEVE 5-13/16” X 4-1/4” 15 3,863' 2,753' 3.563" 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4- 5/8” X 3-9/16” (Length 121’) 16 3,984' 2,815' 3.313" Bottom screen / BOT “F” SEATING NIPPLE 4-3/4” X 3.313” 17 3,986' 2,816' 4.000" BOT SC-1R PACKER 5-13/16” X 4.00” 18 3,996' 2,821' 4.250" SLIDING SLEEVE 5-13/16” X 4-1/4” 19 4,127' 2,888' 3.563" 4” .012 GA 140 SCRN W/ 6-1/16” CENT IN MID & PIN END 4- 5/8” X 3-9/16” (Length 181’) 4,308' 2,980' 3.250" Bottom screen 20 4,308' 2,980' 3.250" BOT “DA” SUMP PACKER 5-11/16” X 4” X 3-1/4” Updated By: JLL 11/20/24 McArthur River Field Well: M-09 Last Completed: 07/19/21 PTD: 196-127 API: 50-733-20476-00 PROPOSED PERFORATION DETAIL (Tie-In Log Intervals - DIL Depths) Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT SPF Date COMMENTS Middle Kenai Gas ±2,420’ ±4,405’ ±2,035’ ±3,029’ Future Proposed SZ-18A 2,590’ 2,600’ 2,120 2,125’ 10’ 6 11/08/17 2-7/8” 6 SPF Razor Carrier SZ-18A 2,600’ 2,646’ 2,124’ 2,147’ 46’ 02/13/21 Open SZ-19A 2,806’ 2,818’ 2,225’ 2,231’ 12’ 12 07/16/21 Open SZ-19B 2,833’ 2,844’ 2,239’ 2,244’ 11’ 12 07/16/21 Open SZ-20 2,982’ 3,010’ 2,314’ 2,329’ 28’ 12 07/16/21 Open SZ-22 3,221’ 3,241’ 2,434’ 2,444’ 20’ 12 07/16/21 Open SZ-22 3,246’ 3,266’ 2,447’ 2,457’ 20’ 12 07/16/21 Open SZ-22 3,270’ 3,290’ 2,459’ 2,469’ 20’ 12 07/16/21 Open SZ-23 3,320’ 3,330’ 2,484’ 2,488’ 10’ 12 07/16/21 Open SZ-24 3,451’ 3,476’ 2,550’ 2,562’ 25’ 12 07/16/21 Open A2 3,677' 3,681' 2,662' 2,664' 4' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,689' 3,704' 2,668' 2,676' 15' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,710' 3,816' 2,679' 2,731' 106' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2A 3,868' 3,902' 2,757' 2,774' 34' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 3,942' 3,948' 2,794' 2,797' 6' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 3,970' 3,977' 2,808' 2,812' 7' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A5A 4,151' 4,165' 2,901' 2,909' 14' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,186' 4,248' 2,919' 2,951' 62' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,266' 4,298' 2,960' 2,976' 32' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE 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 Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 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 4,500 feet N/A feet true vertical 3,076 feet N/A feet Effective Depth measured 4,398 feet See schematic feet true vertical 3,026 feet See schematic feet Perforation depth Measured depth 2,590 - 4,298 feet True Vertical depth 2,120 - 2,976 feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# / L-80 2,409 MD 2,029 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: 13. Prior to well operation: Subsequent to operation: 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: Contact Name: Authorized Title: Contact Email: Contact Phone: Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: Daniel E. Marlowe Operations Manager Burst Collapse Katherine O'Connor Katherine.oconnor@hilcorp.com Tubing Pressure 1,950psi 4,760psi 3,450psi (907) 777-8376 8,160psi 488 837 1,451 3,074 488 838 Conductor Surface 7,020psi 28" 13-3/8" 9-5/8" 1,488 3,491 Size 57 Production Casing Structural Liner Length Intermediate N/A Junk 5. Permit to Drill Number: 860 McArthur River Field / Middle Kenai Gas PoolN/A measured 1,488 0 Gas-Mcf 9 N/A Oil-Bbl 475 Water-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-277 7 Authorized Signature with date: Authorized Name: 5 WINJ WAG STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 196-127 50-733-20476-00-00 Plugs ADL0018730 Trading Bay Unit M-09 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 180 Casing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 7" 4,494 MD 488 838 TVD Other: Gravel Pack measured true vertical Packer measured 6,870psi PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 4:21 pm, Sep 08, 2021 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.09.08 13:46:58 -08'00' Dan Marlowe (1267) SFD 9/9/2021DSR-9/8/21 RBDMS HEW 9/10/2021 BJM 10/26/21 Updated By: JLL 08/30/21 SCHEMATIC McArthur River Field Well: M-09 Last Completed: 07/19/21 PTD: 196-127 API: 50-733-20476-00 PBTD: 4,398’ TD: 4,500’ MAX HOLE ANGLE = 61.1º @ 2,701’ 28” RKB: MSL =160’ RKB to Seafloor = 345’ 7” A-2 3 4 7 8 TOL 7” @ 1,003’ 13-3/8” 9-5/8” 1 2 TOC @ 756’ 5 6 A-2 & A-3 A-5A & A-5 TOC @ 1,484’ SZ-18A SZ-23 SZ-20 SZ-24 SZ-22 SZ-18A SZ-19A SZ-19B X X X CASING DETAIL Size Wt Grade Conn ID Top Btm 28” Surf 488’ 13-3/8” 68 K-55 BTC 12.415 Surf 838’ 9-5/8” 47 L-80 BTC 8.681 Surf 1,488’ 7” 29 L-80 KC Butt 6.184 Surf 1,003’ 7” 29 L-80 NSCC 6.184 1,003’ 4,494’ TUBING DETAIL 3.5” 9.2 L-80 IBT-M 2.922 Surf 2409’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 72.05 72.05 Tbg Hanger: Assembly #111692 A02, 3-1/2" EUE Lifting Threads Top&Bottom, 3" Type H Profile 1 474’ 474’ ±6” Milled out SSSV Landing Nipple 2 505’ 505’ 2.813 3.5” 2.813 XXO SVLN. Ser. No. 1404764-1 3 1,705’ 1,622’ 2.992” GLM #1 –SFO-2 2,363’ 2,007’ 2.992” GLM #2 – SFO-2 SZ GRAVEL PACK 4 2,410’ 2,030’ 2.992” 7” Hydraulic Retrievable Packer 3.5” X nipple (2.812” ID) –2424’ MD Production Overshot 4.3' swallows 3.8' (Seal Area 4.80 ID) 4 1/2" Hook up Nipple W/4 1/2" LTC Pin (Polish Stem 4.75" O.D.) 3.5” L-80 NU 10rd Blank Pipe (3 jts) 3.5” 0.012 Ga Wire Wrapped Screen (31jts) XO 3.5” NU 10rd Box x 3.5” EUE Pin 4" Snap Latch Assy X-Nipple – (2.813” ID)3,509’ MD 3-1/2" L-80 EUE WLEG (3.64' ) A2 GRAVEL PACK 5 3,524' 2,586' BOT SC-1R PACKER 5-13/16” X 4.00” UPPER EXT 5-9/16” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-5/8” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 3554’ 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 3645’ BOT “F” SEATING NIPPLE 4-3/4” X 3.313”@ 3825’ S-22B SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ 1/2 MULE SHOE 4.00” X 3.25” A2 & A3 GRAVEL PACK 6 3,828' 2,737' BOT SC-1R PACKER 5-13/16” X 4.00”@ 3828’ UPPER EXT 5-9/16” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-9/16” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 3858’ 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 3863’ BOT “F” SEATING NIPPLE 4-3/4” X 3.313”@ 3984’ S-22B SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ 1/2 MULE SHOE 4.00” X 3.25” A5 GRAVEL PACK 7 3,986' 2,817' BOT SC-1R PACKER 5-13/16” X 4.00”@ 3986’ UPPER EXT 5-1/2” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-9/16” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 4017’ 4” .012 GA 140 SCRN W/ 6-1/16” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 4127’ SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ CHAM BTM4.00” X 3.25” 8 4,308' 2,981' BOT “DA” SUMP PACKER 5-11/16” X 4” X 3-1/4”@ 4308’ Updated By: JLL 08/30/21 McArthur River Field Well: M-09 Last Completed: 07/19/21 PTD: 196-127 API: 50-733-20476-00 SCHEMATIC PERFORATION DETAIL (Tie-In Log Intervals - DIL Depths) Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT SPF Date COMMENTS SZ-18A 2,590’ 2,600’ 2,120 2,125’ 10’ 6 11/08/17 2-7/8” 6 SPF Razor Carrier SZ-18A 2,600’ 2,646’ 2,124’ 2,147’ 46’ 02/13/21 Open SZ-19A 2,806’ 2,818’ 2,225’ 2,231’ 12’ 12 07/16/21 Open SZ-19B 2,833’ 2,844’ 2,239’ 2,244’ 11’ 12 07/16/21 Open SZ-20 2,982’ 3,010’ 2,314’ 2,329’ 28’ 12 07/16/21 Open SZ-22 3,221’ 3,241’ 2,434’ 2,444’ 20’ 12 07/16/21 Open SZ-22 3,246’ 3,266’ 2,447’ 2,457’ 20’ 12 07/16/21 Open SZ-22 3,270’ 3,290’ 2,459’ 2,469’ 20’ 12 07/16/21 Open SZ-23 3,320’ 3,330’ 2,484’ 2,488’ 10’ 12 07/16/21 Open SZ-24 3,451’ 3,476’ 2,550’ 2,562’ 25’ 12 07/16/21 Open A2 3,677' 3,681' 2,662' 2,664' 4' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,689' 3,704' 2,668' 2,676' 15' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,710' 3,816' 2,679' 2,731' 106' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2A 3,868' 3,902' 2,757' 2,774' 34' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 3,942' 3,948' 2,794' 2,797' 6' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 3,970' 3,977' 2,808' 2,812' 7' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A5A 4,151' 4,165' 2,901' 2,909' 14' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,186' 4,248' 2,919' 2,951' 62' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,266' 4,298' 2,960' 2,976' 32' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE SZ-19A 2,806’ 2,818’ 2,225’ 2,231’ 12’ 12 07/16/21 Open SZ-19B 2,833’ 2,844’ 2,239’ 2,244’ 11’ 12 07/16/21 Open SZ-20 2,982’ 3,010’ 2,314’ 2,329’ 28’ 12 07/16/21 Open SZ-22 3,221’ 3,241’ 2,434’ 2,444’ 20’ 12 07/16/21 Open SZ-22 3,246’ 3,266’ 2,447’ 2,457’ 20’ 12 07/16/21 Open SZ-22 3,270’ 3,290’ 2,459’ 2,469’ 20’ 12 07/16/21 Open SZ-23 3,320’ 3,330’ 2,484’ 2,488’ 10’ 12 07/16/21 Open SZ-24 3,451’ 3,476’ 2,550’ 2,562’ 25’ 12 07/16/21 Open Rig Start Date End Date HAK 404/CTU 7/1/21 8/12/21 Nipple down tree, prep wellhead. N/u 7 1/16 5m tubing spool, N/U riser, mud cross, double-gate, annular. Nipple up choke and kill valves and lines, torque BOPE flanges. Raise mast secure drwks and guy lines, scope up mast, plug in lights, install rig floor and pin to mast. Skid double beam support closer to rig in order to set rig floor supports on beam. Rig up rig floor circulating head. Adjust rig floor to circulating head level. General rig up setting landings stairs and ladders, hanging rig floor lights, rig up weight indicator, set beaver slide. Pick up and make up test plug and 3 1/2" test joints. Test BOPE to 250 psi low 2,500 psi high. 07/03/2021 - Saturday Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name M-09 50-733-20476-00 196-127 Simops meeting with Production, arrange decks. Mobe crews to platform & orientate same. PTSM, cont. arrange eq. work on rig layout, r/u jacks & skid rig south to well center. Work on cleaning pits. Move jacks, r/u and skid rig SE t/ well center. Tack skid feet to beams to move rig, continue cleaning pits. Remove drilling line spool from carrier, set base beam, prep to string up and raise mast. Install drillers console on side of mast, remove hatch covers to retrieve hotsy from below deck to clean oily pits for KCL. Replace hatch covers. Raise mast, (short stand) Hold pre tour and orientation meeting for new hands on crew and new to Steelhead platform. Continue rigging up, string blocks, spool drilling line into drwks, install dead man and guy lines, string man rider and tugger, lay down mast. unload boat, continue cleaning pits with Hotsy. 07/02/2021 - Friday Spot accumulator, choke manifold, r/u remote panel, check accumulator pre-charge good, level carrier, continue cleaning pit, finish unloading boat, spot mix tank & w/l unit, stand mast. R/U w/l, test lubricator good, rih w/5.7" gauge ring t/474' good, POOH m/u GS rih latch SSSV attempt to pull free, no go, work on spanging & jarring free. Finish cleaning rig pit, clean mix tank, r/u gas detection system, calibrate & test same good, pulled SSSV to surface & l/d same. R/d W/L, fill pit with FIW, mix 6% KCL, transfer to rig tank (trouble shoot mix tank electrical, blowing fuses, rig up and use rig pump to mix KCL) lower mast. Make up pump in sub, tie into with rig pump, pump 150 bbl into well bore (hole capacity) observe well. Well built pressure to 90 psi, observe well mix KCL. bleed well to 20 psi. Pump 50 bbl 6% KCL into well. observe well. (offload boat) Well on vac. (mixing KCL transferring to rig tank). Rig down and remove wire line riser. (mixing KCL transferring to rig tank) set TWC into well head. 07/01/2021 - Thursday Daily Operations: pulled SSSV to surface & l/d same. BOPE to 250 psi low 2,500 psi high. Rig Start Date End Date HAK 404/CTU 7/1/21 8/12/21 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name M-09 50-733-20476-00 196-127 Daily Operations: Cont. POOH l/d 3 1/2" wk string. Monitor well, unload boat. Cont. POOH l/d BHA #1, P/U BHA #2- 6" bit, scraper, boot basket, xo double box, string magnet, xo = 20.34'. C/O handling eq. & setup for 2 7/8". Tih p/u 2 7/8" wk string, wiping 50' above & below projected packer setting area @ 2,409'. Cont. RIH t/2868', tagged up, up wt 28k, dn wt 22k. R/U attempt to wash down with no luck, 3 BPM, 0 psi. R/d & rotated down through tight spot & cont. in hole rotate as needed t/2966, @ 2,966 were unable to rotate pipe, work tight pipe, pull to 2,956. Could not pull or rotate. Pump 25 bbl 6% KCL down tubing, 0 psi, no returns, pipe moving up, POH working pipe (acting like junk dragging up), to 2,650'. Pump 10 bbl 6% KCL with no returns to surface, @ 2,650', POH no excess drag. Lay down 6" bit and scraper BHA. Clean magnet and boot basket, no recovery in basket. (Pumping 10 bbl 6% KCL every 30 min.) Rig up Pollard slick line unit, RIH with 5.5" od ring junk basket, stopped at 2,900' work basket, POH very little recovery in basket. Observed fluid level by slick line weight is 1,220'. Finish R/U lubricator for pulling TWC, Test same 250/2500 good. Engage TWC w/pulling tool, equalize pressure in stack & lubricator @ 100 psi. Pull TWC & raise above profile. Pump 6% KCL, 120 bbls holding 110 psi, shut down & build more fluid while monitor well. Bleed to 70 psi with no build up, cont. pumping bleeding down to 0, pmp total 257 bbls, @ 2.25 BPM surfacing no fluid, sd monitor well 30 min, on vac. N/D lubricator & companion flange, lay it down w/TWC. N/u circulating head, Raise rig floor, install slide & stairs, r/u tongs & 3 1/2" handling equipment. M/U BHA #1, - 6" taper mill, pup jt, 6" string mill, double box xo, boot basket, Double pin xo, string magnet, xo= 32.33'. RIH p/u 3 1/2" PH6 wk string. RIH t/tag @ 482' UP dn wt 14k. L/d single P/U 10' pup, P/U power swivel. Adding 2 bbl 6% KCL every 5 minutes to annulus. Milling SSSV profile with 6" mill assembly from 482' to 486', 90 rpm, 500 to 5,000 torque, 14K rot wt. adding 2 bbl 6% KCL every 5 minutes to annulus. Rig down and lay down power swivel. Continue pumping 1 bbl 6% KCL every 5 minutes into well. Lay down 3 1/2' tubing work string. Continue pumping 1 bbl 6% KCL every 5 minutes into well. 07/06/2021 - Tuesday 07/04/2021 - Sunday Cont. Test BOPE as per Hilcorp & AOGCC requirements, witness was waived by AOGCC inspector Jim Regg, tested 250/ 2500 with 2 7/8 & 3 1/2" TJ, all good. R/D test eq. went to pull TWC pressure had built up under it, tied into control line for SSSV checked pressure @ 150 psi. R/u to pump down control lines to fill hole, was only able to get .07 BPM rate @ 3500 psi, r/d same. Bringing out lubricator to pull TWC on next boat. N/D circuating head spool from annular & lower rig floor preping to install lubricator for when it arives, ( 00:30 in time to the dock) remove beaver slide and stairs, lower rig floor to top of annular level, lay out and strap 3 1/2" tubing for 6" mill run, pick up and make up 6" milling assemble set in slide. Stand by for boat with lubricator. Perform rig maintenance and platform housekeeping while standing by for boat. Off load boat, Receive tools for TWC removal. Unload basket and install 13 5/8" adapter flange onto annular preventer, pick up and make up rod and lubricator. 07/05/2021 - Monday witness was waived by AOGCC inspector Jim Regg, t Milling SSSV profile w Rig Start Date End Date HAK 404/CTU 7/1/21 8/12/21 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name M-09 50-733-20476-00 196-127 Daily Operations: Continue clean out f/ 3,239' t/3,481', reverse 2X tubing vol and monitoring returns before ever connection break, significant sand returns 0 / 1K wob, 80 rpm, 3 bpm @ 120 psi. 0 to 2K wob, 80 rpm, average losses 20 bph. Working tight spot at 3,481'. Can not rotate or move pipe either direction but able to circulate. Reverse circluted 3x BU, heavy sand returns before cleaning up. Discussed plan foward with town engineer, continued circulating and working tight spot to free pipe. Observed fluid losses increasing to 70-80 bbls per hr but able to get some returns to surface. SIMOP: building 20bbl HI-VIS Gel Sweep. Pumped 10bbl HI-VIS Sweep, 10 bbl spacer, 10 bbl HI-Vis, Rev circulated sweep @ 3.5bpm/60psi. When sweep reached perfs fluid loss rate decreased to 40 bph. Sweep hit shaker bring back heavy sand. Once returns were clean SD pump. Continued working tight spot at 3,481'. hole clean 2.7 bpm = 77 psi. Continue to circulate and work and torque string attempting to free pipe with out success. Rig up Alaska E-line. Lay down power swivel for wire line work. Rig up Alaska Eline. RIH with 1.44" motorizes free point tools @ 3,457' POH with Eline. Discuss options with engineer. 07/07/2021 - Wednesday Run 4.45" magnet on wireline in hole unable to get enough momentum to get past 2140' area. POOH, run 4' 3" bailer t/ 2900' POOH recovered heavy grey sand, re-ran with same results, unable to break through. R/D wireline. M/U BHA #2 run 2 - 6" bit, scraper, boot basket, xo double box, string magnet, xo = 20.34'. RIH w/ 2 7/8" wk string from derrick, t/ 2909' tagged up, up wt 27k, dn wt 22k, rack back stand, & l/d 2 working joints. Service rig, R/D pull up t/ 2722', & park while mixing size salt pill. Work on rig maint. & deck organization while mixing 45 bbl size salt pill. POOH t/ 2602', pump 41 bbls size salt pill spot in place & let fall across perfs, while building more volume. Pump total 78 bbls 3% KCL on back side, fluid returns to surface @ 5.5 BPM, establish loss rate of 60 to 80 BPH. Mix up 60 bbl size salt LCM pill per recipe, Stand back 1 stand, (Bit at 2,541'). Continue mixing pill. 07/08/2021 - Thursday Continued Mixing Salt Pill. Pumped and spotted 60bbl Salt Pill down Workstring @ 2-4 bpm/0psi and chased with 3bbls of 3% KCl. Stand-by letting Salt Pill Soak. DSM Changeout, walk through with HAK HSE Rep. Filled IA with 14bbls of 3% KCL, Established loss rate of 10 bph static loses. RIH f/2541'md and tag 2,602'md. Stood back 1 stand and parked. RU Circulating Equipment. Started circulating 3bpm/280psi, catch returns after 4 bbls and started seeing salt pill at surface after 47bbls pumped away. SD montiored well on U-tube. Continued circulating STS 2.5bpm/80psi with 15bph loss rate while circulating. SD monitored tbg/IA balanced. Pick up and make up power swivel, make up Kelly valves and set torque for clean out @4,000 fp. Wash ream and clean out 7" casing from 2,632' to 2,905' clean, little solids returns. Wash down and reverse circulating every 60'. From 2,905 to 3,088 observed bit taking some weight (0 to 2K) with significant sand returns 3.5 gpm 80 rpm 0 to 2k wob 3 bpm = 150 psi , average losses to formation 20 bph. Continue clean out from 3,088' to 3,239' wash 30 and reverse 2X tubing volume, significant sand returns 0 / 1K wob, 80 rpm, 3 bpm @ 175 psi. 0 to 2K wob, 80 rpm, average losses 20 bph. 07/09/2021 - Friday Can not rotate or move pipe either direction but able to circulate. Rig Start Date End Date HAK 404/CTU 7/1/21 8/12/21 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name M-09 50-733-20476-00 196-127 Daily Operations: 07/10/2021 - Saturday POOH w/EL. L/D free point tools. Free point reading pipe is 90% free @ 3,435', 227' above BHA. Discussed with OE and decided the best option is to cut in the 1st joint 15' above the BHA. Waiting on EL jars to arrive on helicopter. Mix 6% KCL in rain4rent tank. Filling hole 5bph. M/U 1-11/16" RCT Tool-string assembly. RIH and set down @ 2,170', made several attempts to work tools down with no success. POOH to reconfigure tool-string. Shorten the lower anchor assembly 2 foot and M/U pump-in sub. RIH w/ RCT assembly, set down @ 1950', started pumping down WL tools @ 1-2bpm. Set down no-go in BHA XO. Make correlation pass. Parked WL on depth, pulled 20k over on string. Tried setting the anchor, showing direct short. Discussed with town. Made cut @ 3,427' without anchors set. POOH, RCT did fire. RD EL. Pipe not free. Worked pipe up to 140k (110k over string weight) no luck. RU power swivel, continued working and torqueing and pipe came free pulling 40k over string weight. String weight PU 28k with no drag. Lay down power swivel, POH standing back 2 7/8" work string. Cut joint = 14.54'. Test BOPE, Witness waived by Jim Regg, 7/10/21. Make up and set test plug. Test BOPE to 250 / 2,500 psi, test 3 1/2" and 2 7/8" test joints. 07/11/2021 - Sunday Continued Test BOPE per Sundry as following; Annular 250-2500psi, Rams 250-2500psi, Valves 250-2,500psi. Test alarms and Performed Koomey Drawdown. No failures recorded. Witness Waived by Jim Regg on 7/10/21 @ 17:51hrs. R/D BOPE Testing Equipment, cleaned and cleared rig floor. P/U Handling Tools, MU Fishing BHA as following: OS dressed to catch 2-7/8" OD, Bumper Jar, Oil Jar, 6 Drill Collars, XO to 3-1/2" PH6. Filling hole 5bph. TIH w/BHA picking up 3-1/2" PH6 Workstring to TOF, establish parameters PUW 43k, SOW 32k. Engaged fish @ 3,429'md. Filling hole 5bph. Work and jar on fish, work up pull to hit with 60K over string wt. no progress or movement. Rig up head pin to circulate, perform derrick inspection, check guy wires and tie downs. No issue found. Continue to work and jar on fish with up to 60K over string wt. Circulate at 3 bpm @ 150 psi. observed losses of 10 bph while circulating. Continue to work and jar on fish with 60K over with out movement. Circulate at 3 bpm @ 150 psi. observed losses of 9 bph while circulating. Perform rig, drwks and derrick inspection. No issue found. Continue to work and jar on fish with 60K over with out movement. 42K up 32K dn wt. continued working and torqueing and pipe came free pulling 40k over string weight. Test BOPE to 250 / 2,500 psi, test 3 1/2" and 2 7/8" test joints. Test BOPE, Witness waived by Jim Regg, Engaged fish @ 3,429'md. Rig Start Date End Date HAK 404/CTU 7/1/21 8/12/21 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name M-09 50-733-20476-00 196-127 Daily Operations: 07/12/2021 - Monday Continued working and jarring on fish 60k over with no movement. Circulated well 3.5bpm and inspected Derrick and Guy Lines. Continued working beating down on fish, was able to move fish downhole 8", resume jarring on fish @ 80k over (PUW 42k SOW 32k). Pipe came free. PU 30' and pipe free with no drag, string weighting 43k. Inspected Derrick and prepared rig to POOH to see if we have the fish. POOH standing back 3-1/2 workstring, pumping single displacement, no drag while TOH,Changed out handling tools, L/D Fishing BHA and the FISH. Inspected fish, no visual tattletales of why fish was stuck. Pic in O-drive for viewing. Clear floor of fishing tools, slip and cut drilling line due to jarring operation, service drwks motor (oil change), work boat and mix viscus pill. Make up 6" clean out assembly BHA #4, 2 7/8" PH6 mule shoe and joint, 6" string mill, jars and 6 each 4 3/4" drill collars. RIH with 3 1/2' PH6 work string. RIH with 6" string mill assembly to 3,132'. Pick up power swivel, break circulation, set torque make up quill and saver sub. Wash and rotate from 3,132' to 3,194'. 4 bph losses, 36K down, 40K rot, 44K up wt. 3 bph = 40 psi. 07/13/2021 - Tuesday Continued RIH, Wash and rotate from 3,194' to 3,505' 4 bph losses, 36K down, 46K rot, 50K up wt. 3 bph. No torque or WOB. Reversed circulated 2X BU @ 3bpm/50psi. Returns clean. Wash and rotate down f/3505' t/3535 did not see TOP @ 3,524' with 2-7/8" Muleshoe. Discussed with OE decided to cont RIH and tag/no-go the top of the packer with 4.75"OD XO below the string mill. Closed bag, worked pipe down while reverse circulating 2.5bpm tag bridge @ 3,550'. Rev cir 2X BU, Heavy sand returns then clean. Continued washing down to 3,560' and tag the top of the packer @ 3,525' with String Mill XO. Confirmed tag with 5k down and observed 200psi pump pressure increase. Pumped 20x10x20 HI-VIS sweep, swapped over to clean 6%KCL, reversed circulated STS at 4bpm/200psi. 1st sweep hit shakers with med to heavy sand, 2nd sweep hit with light to trace of sand, returns clean 6% KCL. SD Pump. L/D single, XO and Kelly Valve. R/D Power Swivel. POOH L/D 3-1/2" work string, lay down 6" clean out BHA, clear floor. Pick up and make up Baker anchor latch, X nipple, 10K dual glass disc sub, 7" Model D packer, LC-20 setting tool XO to 2 7/8" PH6. (BHA = 54.46). RIH with Baker 7" Sump packer assembly on 2 7/8" PH6 work string. RIH with Baker 7" Sump packer assembly on 2 7/8" PH6 work string. Pipe came free. L/D Fishing BHA and the FISH. Rig Start Date End Date HAK 404/CTU 7/1/21 8/12/21 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name M-09 50-733-20476-00 196-127 Daily Operations: Continued RIH with 7" Sump packer assembly on 2 7/8" PH6 work string f/2,800' to just above SC-1 Pkr. RIH 60fpm per Tripoint Rep. PUW 21k, SOW 18k, Slacked and tagged TOP @ 3,524'. Worked and rotate pipe 1/4" turns until locator latch assembly went into the packer roughly 4-6". Worked pipe for 3 hrs trying to latch with no success. Started losing hole while working pipe 2-3" with every pickup, discussed with OE and decided to TOH to make cleanout trip. SOOH 2- 7/8" WS and packer assembly at 60fpm, no over pull or drag encountered while tripping. L/D Packer assembly, found small trace of sand around the tool joints and the latch locator. Cleaned and cleared rig floor, filled hole with 6% KCL. MU 2-7/8" Mule shoe and RIH on 2-7/8" PH6 Workstring tagged @ 3,519' dpm. Trouble shoot power swivel would not start. RU Power Swivel. Wash and work into SC-1 packer @ 3,524' reverse hole clean @3 bpm, (minimal to trace sand returns). RIH to 3,556' reverse hole clean @ 2 bpm, 3 X drill pipe volume, (trace to med sand returns). Average 30 bph losses while reverse circulating hole clean. 34K up, 26K dn wt. Rig down power swivel. Pull mule shoe out of production liner and packer, no overpull, POH standing back 2 7/8" PH6 work string. Service rig. Pick up and make up 7" packer assembly. 3 1/2" EUE mule shoe, 3 1/2' EUE pup, 3 1/2" X nipple, 3 1/2" EUE pup, Model D packer, LC-20 set tool sleeve and setting tool, XO, 2 7/8" PH6 tubing work string, (RA sub one stand above BHA , included in BHA length), BHA = 46.73'. (RIH 1 minute slack off time per tripoint rep). 07/15/2021 - Thursday Cont. RIH w/ 7" sump packer assy t/tag no go @ 3522', up wt 30k, dn wt 23k. No sign of mule shoe entering lower packer, quarter turn assy and reset no change. Discuss options with Ops engioneer decide to verify with e-line. R/U e-line run correlation log, showing RA sub at correct depth putting packer on depth& mule shoe assy 3' in lower existing packer @ 3524'. R/D e-line, r/u circ line, Drop 1.25" ball. Pump & pressure up t/ 3800 psi & hold 10 min, setting packer @ 3499', pull 10k over verifying set, rotate to the right backing off running tool from packer. POOH standing back 2 7/8" wk string, pulling slow @ 1 min per stand. L/D Pkr setting tools. Needing to make more room for fluid storage. Discussed with OE decided to pump Kill on M-31 with stored dirty brine from M-09 cleanout. R/U circulating lines to M-31. Circulated well kill on M-31. Pumped 200bbls of FIW, 330bbls of 8.9ppg dirty brine followed by 71bbls of FIW. SIMOP: While circulating M-31 c/o handling tools and prepared rig to make TCP run. R/D circulating hoses from M-31. Held PJSM, P/U and assemble TCP Guns per Tripoint Rep. 07/14/2021 - Wednesday L/D Packer assembly, found small trace of sand around the tool joints and the latch locator. Rig Start Date End Date HAK 404/CTU 7/1/21 8/12/21 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name M-09 50-733-20476-00 196-127 Daily Operations: 07/17/2021 - Saturday Cont. POOH stand back 2 7/8" wk string & l/d cleanout BHA, with plug & retrieval tool. C/O handling tools, prep to pickup screen assembly. P/U 4" Snap Latch Seal Assembly, Glass Disc Sub, P/U 3-1/2" screen assembly, 31 screens & 3 blanks=1043.72'. P/U 4-1/2" Hook-Up Nipple, 2-7/8" Clutch Jt Release and Upper Sub, Lower Cir Sub, 7" JS-2 Retrievable Pkr, Upper Cir Sub, Seal Bore Sub, XO to 2-7/8" PH6. RIH w/GP assembly on 2-7/8" working from derrick t/3487', P/U 1 single w/TIW and pump in sub. PUW 38k SOW 22k. RIH and tagged Sump Pkr @ 3499'. Worked pipe several times before engaging the snap latch seal assembly in the packer. Picked up 5K over to verify latch. Set JS-2 Retrievable Packer @ 2415'. Filled IA with 36bbls of 6% KCL and tested 1000psi-good test. Spotted Sand Pot Injector and r/u circulating hoses. Found 2 valves leaking on the Sand Pot. Greased and cycled valves, tested good. Held PJSM, Started pumping and established circulation rate @ 1bpm/100psi 2bpm/250psi. Shut-in IA established injection rate @ 1bpm/150psi 2bpm/300psi and 3bpm/500psi. Pumped 20/40 Gravel pack Sand @ 2 BPM, maintaining returns 1 bpm. Monitoring pump pressures. Averaging 3,500lbs of sand per hr. Sanded out and pressured up to 2000psi and let bled to 0psi, Pressured up to 2000psi and let bled to 0psi. Pumped and placed a total of 15,200lbs of 20/40 GP Sand. Lined up to rev cir, Open Pkr Bypass and reversed circulated 3x Bottoms Up, with returns clean shut down pump. 07/16/2021 - Friday Cont. P/U TCP gun assy as per Tripoint rep, (4.5" 12 SPF, 60 deg Phasing ), C/O handling eq. Cont. run TCP assembly in on 2 7/8" wk string from derrick, drifting on way in t/3485', up wt 30k, dn wt 22k. P/U single, rih tag @ 3499', P/U had over pull, cont pull t/shear @ 38k, leaving isolation plug in sump packer @ 3499', pick up t/ 3482' R/U e-line. RIH pull correlation pass, send to Engineering to correlate, make 1' adjustment as per Geo Engineer. Pull guns onto depth with bottom shot @ 3476' r/u & break circulation, @ 3 BPM 105 psi, good. Shut in annular, drop firing bar, guns fired after 2 min fall, good indication at surface, tubing on vac, POOH 2 stands t/3364' up wt 30k, dn wt 22k. Shot 12 SPF, 60 deg phasing, 3476-3451, 3330-3320, 3290-3270, 3266-3246, 3241-3221, 3010-2982, 2844-2833, 2818-2806. Circulate hole volume, initial fill 40 BPH loss rate, pump 3 bpm, 167psi. POOH standing back 2-7/8" Workstring, f/3364 t/837'. Filled hole w/10bbls of 6% KCL, C/O handling tools, L/D TPC guns, all shots fired. Cleaned and cleared rig floor, c/o handling tools. M/U Overshot loaded w/2.625" Grapple, 7" Csg Scraper, RIH w/2-7/8" work string from derrick t/3490. PUW 29k SOW 21k. RU circulating equipment, RIH and tagged sump packer plug 3499'. Slacked off 8k and engaged plug, PU 10k over and sheared plug free. Lined up to rev cir, pumped 3bpm/0psi, catch returns after 42bbls away, continued rev circulating 3x Bottoms Up. After 1st BU returns trace of sand and gun resin, 2nd and 3rd BU returns clean. SD pump, R/D circulating equipment. 50bph losses to formation. POOH standing back 2-7/8" workstring. Set JS-2 Retrievable Packer @ 2415'. Shot 12 SPF, 60 deg phasing, 3476-3451, 3330-3320, 3290-3270, 3266-3246, 3241-3221, 3010-2982, 2844-2833, 2818-2806. Filled IA with 36bbls of 6% KCL and tested 1000psi-good test. S P/U 3-1/2" screen assembly, 31 screens & 3 blanks=1043.72' Rig Start Date End Date HAK 404/CTU 7/1/21 8/12/21 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name M-09 50-733-20476-00 196-127 Daily Operations: R/U wireline, RIH pull sleeve from SSSV profile @ 470', RIH & pull plug from x-nipple @ 2396' WLM. RIH w/ 2.77 drift on w/l to tag top of stump @ 2431' WLM, using tags for correlation calculated overshot had swallowed hookup nipple. P/u space out joint RIH t/tag @ 2441', R/U w/l rih w/2.77 drift t/2481', make several passes through area with no tags, good. POOH L/D w/l. Get space out measurements, POOH l/d 4 joints, P/u space out pups & one joint, rih, P/u landing joint & hanger, make up same. RIH land hanger placing overshot 3.57' over hook up nipple @ 2438', up wt 30k, dn wt 23k. R/U fill up line to annulus, RILD pins. R/U w/l RIH w/RHCP plug attempt to set but shearing pins at WRSV profile, POOH re-pin, RIH set plug in x-nipple @ 2426', RIh set isolation sleeve in WRSV profile & test control line unable to get pressure. Pull isolation sleeve, redress & re-run. PT to 5k good. Pull isolation sleeve, rih set ball & rod. R/u circ lines & fill tubing, pressured up to 3,800psi and set packer. Had to continually bump pressure for 30mins to maintain setting pressure. Tubing leak off ~150psi/min. R/U circulating hoses and filled IA, pressured up to 1800psi observed slow leak off 20psi/min, found 1/2" needle valve thread end leaking on the wellhead, bled off IA and swapped out valve. Pressured up on IA to 1800psi, leak off at 50psi/min. Bled off pressure. R/U Mud pump to IA and Test pump to the Tbg, pressured up on IA/Tbg to 1800psi, MIT-IA to 1800psi and charted for 30mins-good test. Confirmed RHCP is leaking in the X-nipple @ 2426'. (AOGCC witness waived for IA pressure test by Jim Regg on 7-17 @ 10:47 PM). Called out Pollard to bring Plugs/Tools to test the Tubing. Waiting on Helicopter to arrive with WL Tools and relief crew. Rig crew cleaning and preparing equipment for rig move. SL Tools and personnel arrived, R/U SL, RIH to 2426' pulled ball&rod from RHCP. RIH with Pack-off plug and set above RHCP @ 2426'. Hooked up circulating lines, Filled Tbg and pressure up to 2,500psi and tbg leaked off 500psi/min. Tried running into plug with pressure several time with same results. Bled off pressure. 07/18/2021 - Sunday R/D circulating lines, release packer, rotate off of hook up nipple @ 2436'. C/O handling eq. POOH l/d 2 7/8" wk string to packer assy. L/D packer & clutch assy C/O handling eq. POOH l/d washpipe 32 joints. C/O handling eq. RIH w/19 stands 2 7/8" wk string, POOH l/d same. C/O handling eq. prep completion, lay out & tally 3 1/2" completion jewelry & tubing. (Todays BOPE test was waived By AOGCC Inspector Jim Regg allowing us to run completion). P/U Production Overshot, X- Nipple, 7" Hydraulic Packer and GLM #1, RIH picking up 3-1/2" 9.2# L-80 IBT. P/U and serviced SSSV, Continued RIH w/3- 1/2 Completion spooling and banding 1/4" control line. Tag hook up nipple @ 2,634'. Could not see the Overshot swallowing the stump. Worked pipe making several attempts with no indication of the overshot swallowing the stump. MU circulating lines and pumped tbg volume with no pressure increases. Discussed with OE and decided to run in with E- line CCL to verify the Production Overshot is on depth. 07/19/2021 - Monday CMIT TxIA Not MITIA Filled Tbg and pressure up to 2,500psi and tbg leaked off 500psi/min. T (Todays BOPE test was waived By AOGCC Inspector Jim Regg allowing us to run completion) R/U circulating hoses and filled IA, pressured up to 1800psi observed slow leak off RIH picking up 3-1/2" 9.2# L-80 IBT. (AOGCC witness waived for IA pressure test by Jim Regg on 7-17 @ 10:47 PM R/U Mud pump to IA and Test pump to the Tbg, pressured up on IA/Tbg to 1800psi, MIT-IA to 1800psi and charted for 30mins-good test. Rig Start Date End Date HAK 404/CTU 7/1/21 8/12/21 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name M-09 50-733-20476-00 196-127 Daily Operations: 07/20/2021 - Tuesday R/U w/l RIH w/ D & D hole finder t/2424' & set. Fill tubing & PT t/2500 psi for 30 min good. POOH l/d D & D Plug, rih retrieve pack off tool & PX plus @ 2426'. RIH set SSSV @ 502', pressure test control line & function valve, t/5k good. POOH r/d wireline. Pull landing joint, set BPV, R/U circulate M-31, prep to r/d floor. R/D slide, stairs & floor. Clean RfR tank, prep & scope down mast, unspool drill line, tuggers & manrider, L/D mast. Arrange decks. Broke down BOP lines, ND BOP's, Pulled riser, prepared wellhead for tree, continued arranging deck. NU production Tree, Orientate tree per production, Tested void 250/5000psi held 10mins-good test. Test tree 5000psi-good test. Pulled TWC and M/U Night Cap. Well secured. Rearranged deck space for 404 to be staged. Prepared carrier and mast to be moved. Crew cleaning up work areas. Boat arrived with production change out crew, no time to backload boat with equipment, boat headed back to the dock to drop off personnel while tide allows. Assisted crane with picking Derrick, carrier and beam package and set aside on deck. 08/06/2021 - Friday Fly CT crew to platform. Platform orientation, PJSM & permit. Crane crew offloading CTU equipment from M/V Masco on platform south side. Offloaded doghouse toolbox, injector, console, C-pump, lubricator box. iron rack, choke skid, gooseneck basket & batch mixer spotting all on SW corner. M/V Masco called away for priority delivery of potable water to Spartan 151. M/V Masco to return after water delivery complete. Prep drill deck for CTU rig up. M/V Sovereign arrives @ platform. Offload M/V Sovereign off of platform south side. Offload & spot flowback tank on north side of drill deck. M/V Sovereign away from platform & waiting on tide change. Move CTU equipment from platform south side to platform north side & start spotting on north drill deck for rig up. Clear SW corner of all CTU loads. Move 404 & production loads to SW corner prepping for backload to M/V Masco. Build herculite containment to hold 4 N2 tanks on north drill deck. Continue to offload M/V Sovereign off of north side of platform. Offload & spot 4 N2 tanks generator, hose basket, ELU, perf gun wine rack, ELU tool shed & grease skid on north drill deck. 10 pallets of KCl remain onboard M/V Sovereign. M/V Sovereign released to return to dock for 16:30 Spartan 151 loadout. Waiting on M/V Masco to return. CT crew continues to prep drill deck & CTU equipment for rig up. M/V Masco arrives platform on north side. Offload & spot CT reel, fluid pump, & BOP on north drill deck. M/V Masco moves to south side of platform. Offload reverse skid & Yellowjacket toolbox. Backload 404/production loads to boat. CT crew runs hyd. lines from power pack to console & reel. Grease CT reel level wind & horses head.. Crane moves reverse skid from SW corner & spots on north drill deck. SDFN. Job in Progress. Fill tubing & PT t/2500 psi for 30 min good. RIH w/ D & D hole finder t/2424' & set. Rig Start Date End Date HAK 404/CTU 7/1/21 8/12/21 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name M-09 50-733-20476-00 196-127 Daily Operations: Simops meeting w/ Production. PJSM & permit. Wait on crane to complete picks for production. MU FIW supply line to batch mixer & take on FIW while building 50 bbl of 6% KCl water. PU injector. Pull Test CTC = 10K. Pressure test CTC = 3800 psi. MU BHA1: CTC(1.75" X 0.25'), DFCV(1.75" x 1.08'), SB(1.75" x 4'), Jet Swirl Nozzle(1.75" x 0.88') OAL = 6.21'. Move to well. Pressure Test BOP & Lubricator = 4200 psi. NPT - waiting on SLB management to provide approved MOC. Receive approved MOC. Open swab(20T). RIH w/ slim 1.75" JSN BHA. Tag restriction @ 505' RKB. Wireline retrievable SSSV was installed. POOH. RD injector & secure well. Call for SL crew. Waiting for SL crew helicopter to arrive. SL crew canceled due to covid protocols. Call for Yellowjacket GS spear & toolhand. Waiting on Yellowjacket TH & tools. SLB E. Tech arrives platform. E. Tech replaces failed injector hydraulic circuit board. Test injector hydraulics - PASS. Continue waiting on YJ TH & tools. YJ TH & tools arrive. Fly SLB E. Tech to the beach. PU injector & cut off SLB BHA1. MU YJ GS fishing BHA2: CTC, DFCV, BI-DI Jar, Disco, 3-1/2 GS spear. Pull test CTC = 15K. Press Test CTC = 3000. Move to well. PT BOP & Lub = 5000. Open swab(20T). RIH to 460'. WT CHK = 0. RIH to 505' KB & latch SSSV. PU w/ 2K overpull. POOH. OOH w/ SSSV FISH ON. Secure well & drill deck. SDFN. Job in Progress. 08/07/2021 - Saturday Simops meeting w/ Production. PJSM & permit. Continue to MIRU CTU for FCO & N2 blow down. Prep for BOP test. Run hydraulic lines from power pack to injector. Rig up pump iron from pumps to reel & kill line to choke skid. Rig up flowback line. Ran all data acquisition cables. Waiting on crane operator to complete M-11 ELU rig up to continue w/ BOP test. Run hydraulic lines to BOP. Crane operator released from M-11 ELU Add Perf job & returns to M-09 CTU rig up operations. Test BOPE per Hilcorp & AOGCC specifications & standards. Witness waived by Jim Regg, 8/4/21. Test BOPE to 250 / 3000 psi. BOPE Test Report submitted to AOGCC & copy saved to M-09 Project file on O drive. Install injector gooseneck. Crane operator released from M-09 CTU RU & returns to M-11 ELU Add perf job to RD ELU. Secure CTU & drill deck. SDFN. Job in Progress. 08/08/2021 - Sunday Simops meeting w/ Production. PJSM & permit. Continue to rig up CTU for FCO & N2 blow down. No hydraulic function to injector. Unable to stab pipe. Troubleshoot problem & identify failed electric-over-hydraulic circuit board. No replacement circuit board available in Kenai. Schlumberger sourcing replacement board. Replacement circuit board found in Prudhoe Bay. Will ship replacement board & E. tech on 1st flight out of Prudhoe Bay tomorrow (Monday, 8/8/21). Coil operator continues to test & troubleshoot issue. Coil operator wires up bypass of failed circuit board & gains hydraulic function to injector. Stab pipe & MU CT connector. Waiting on M/V Masco to arrive w/ 10 pallets of KCl. M/V Masco arrives platform. Offload 10 pallets of KCl. SDFN. Job in Progress 08/09/2021 - Monday OOH w/ SSSV FISH ON. Test BOPE per Hilcorp & AOGCC specifications & standards. Witness waived by Jim Regg, Rig Start Date End Date HAK 404/CTU 7/1/21 8/12/21 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name M-09 50-733-20476-00 196-127 Daily Operations: 08/12/2021 - Thursday PTSM, prep & start eq. PT lubricator 250/3500 good, stand by while Production attempts to gas lift well. RIH t/ 4350' CTM. Stand by while production sets up to lift well. Fire up N2 pump. Pump N2 @ 325 SCF, increasing to 500SCF, changing rates & using GL trying to optimize lifting water & get well flowing on its own. POOH f/ 4350't/ surface. Secure well, stack down lubricator & injector, organize deck, backload MT N2 tanks. 08/10/2021 - Tuesday Simops mtg w/ production. PJSM & permit. PU injector & lubricator. MU motor & mill BHA. BHA3: CTC(2.25" x 0.80'), DFCV(2.13" x 0.98'), BI-Di Jar(2.13" x 6.00'), Disco(2.13" x 1.58'), Circ Sub(2.13" x 1.08'), Motor(2.13" x 10.45'), Tapered Mill(2.58" X 0.88') OAL = 21.77'. Disco Ball = 5/8". Circ Sub Ball = 1/2". Move to well. PT BOP & Lub =250/3500. RIH w/ C/O BHA, tag & break through disk sub @ 3471' CTM, tag fill after breaking through, cleanout t/3525' pump 6% KCL @ 1.2BPM 2500psi, no returns. Pick up rih dry tag @ same depth 3525', come on line @ .8 BPM KCL & 400 SCF N2. Cont. pumping till returns to surface. Cont. c/o f/3525 t/3560, N2 400, .8 6% KCL 3050psi,180 psi WHP. POOH t/ surface, secured well, perform rig maint. dispose of return fluids, build 20 bbls 6% KCL. 08/11/2021 - Wednesday PTSM, Permits, start eq. line up & surface test mud motor with 6%KCL, good. RIH t/2500' w/c/o assy pumping 1 BPM 6%KCL, come online w/250 SCF N2. Cont rih t/ 3400' cont. pumping till surface fluid @ 47 bbls pumped. RIh cleaning out f/3560'CTM t/ 4381'CTM, hit hard spots @ 3574' & 3860', pump 1 BPM 6% kCL, 250 SCF N2, 3240psi. Drop 1/2" ball to open circ sub, observed pump pressure fluctuation indicating sub opened. CBU @ 1 BPM, N2 @ 250 SCF. Mix & pump 2 bbls inhibited water, chase & blow down @ 300SCF N2, unload fluid & surface N2. Line up returns to production & monitor, increase rate t/ 400SCF, no significant fluid increase in test separator. Shut down N2, monitor well flow dropped off from ~.785-.095 MMCF/d. Bring N2 back on line @ 400 scf, flow increase to ~.747 MMCF/d, no significant water increase in separator ( >1 bbl). Discuss options with Production & Engineering, shut down N2, POOH shut in well. Break lubricator, l/d c/o BHA, p/u jet nozzle, stab lubricator, secure well. Rest coil crews. cleanout t/3525' pump 6% KCL @ 1.2BPM 2500psi, no returns. Pick up rih dry tag @ same depth 3525', come on line @ .8 BPM KCL & 400 SCF N2. David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-5245 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 08/05/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL MRF M-09 (PTD 196-127) FTP Folder Contents: Log Print Files and LAS Data Files: Please include current contact information if different from above. Received By: 08/05/2021 37' (6HW By Abby Bell at 2:43 pm, Aug 05, 2021 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: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): McArthur River Field / Middle Kenai Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 4,500'N/A Casing Collapse Structural Conductor Surface 1,950 psi Intermediate 4,760 psi Production 7,020 psi 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 Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:Katherine.oconnor@hilcorp.com Contact Phone: (907) 777-8376 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: Gravel Pack 3,074'7" 4,494' Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 7/1/2021 7" Daniel E. Marlowe See Schematic See Schematic Tubing Grade:Tubing MD (ft): 2,120 - 2,976 Perforation Depth TVD (ft): 29# / L-80 9-5/8"1,488' 838' Perforation Depth MD (ft): 1,488' 2,590 - 4,298 3,491' TVD 28" 13-3/8" 488' 3,450 psi 488' 837' 1,451' 488' 838' Anchorage, AK 99503 Hilcorp Alaska, LLC Trading Bay Unit M-09 MDLength Size COMMISSION USE ONLY Authorized Name: Burst 1,003 8,160 psi Tubing Size: Authorized Signature: Operations Manager Katherine O'Connor CO 228A PRESENT WELL CONDITION SUMMARY N/A3,076' 4,398' 3,026' 738 psi 6,870 psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 196-127 50-733-20476-00-00 Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:40 pm, Jun 02, 2021 321-277 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.06.02 14:36:23 -08'00' Dan Marlowe (1267) BJM 6/16/21 DSR-6/3/21 XX X BOP test to 2500 psi. MITIA to 1500 psi. Install 4.5" tubing string 10-404 DLB 06/03/2021 dts 6/16/2021 JLC 6/17/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.17 11:06:20 -08'00' RBDMS HEW 6/17/2021 Well Prognosis Well Name: M-09 API Number: 50-733-20476-00-00 Current Status: Shut In Gas Well Leg: B-2 Estimated Start Date: July 1, 2021 Rig: 404 Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 196-127 First Call Engineer: Katherine O’Connor Office: 907-777-8376 Cell: 214-684-7400 Second Call Engineer: Karson Kozub Office: 907-777-8434 Cell: 907-570-1801 Current Bottom Hole Pressure: 150 psi @ 2320’ TVD Maximum Expected BHP: 960 psi @ 2215’ TVD Max. Allowable Surface Pressure: 738 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft)) Brief Well Summary The M-09 well has dropped significantly in rate in the last year. In early December 2020, the gas rate fell off dramatically and due to sand/silt production, proven by recent slickline tags/samples at 3,488’MD (12/13/2020) & most recently at 3,023’MD (1/23/2021). The latest tag is above the SZ-22 sands perforated on 7/28/2020. Additional perforations were added in early 2021 that had minimal gas added. The purpose of this work/sundry is to gravel pack the upper sands and cleanout the fill to TD. Wellbore Notes x Slickline will pull SSSV ahead of time x All perforations will be re-perforating already open zones Rig 404 Cleanout Procedure 1. MIRU HAK 404 2. Pump KWF until well is dead a. KWF will be 6% KCl 3. Set BPV, ND tree, NU BOPEs 4. Test BOPEs to 250 psi low/2500 psi high/2500 psi annular. x Notify AOGCC 48 hours in advance of test to allow witness 5. Monitor well to ensure it is static, pull BPV. 6. Bit and scraper RIH, cleaning out fill to top packer @ 3524’ MD. POOH W/ bit and scraper. x Mill safety valve landing nipple out to ±6” ID 7. Set isolation sump packer @ ±3467’ MD 8. PU TCP guns, RIH and perforate per program 9. After detonation circulate out any perf gas, confirm well is static. POOH Note: From here forward use minimal amount of pipe dope with a 2” paint brush. Remove dope brushes from rig floor. Discuss with rig crew how excessive pipe dope can damage the gravel pack and formation. Rig 404 Gravel Pack Procedure 1. Pick-up and RIH GP screen, hook-up nipple, clutch joint and JS-2 Packer/crossover tool assembly. 2. Tag top of sump packer @ 3,467’ and verify depth. Ensure Safety joint with FO safety valve and crossover to screen connection is readily available on rig floor. Well Prognosis 3. Pick up and space out work string to safe working height. 4. Slack off and land screen assembly in sump packer. 5. Set GP (JS-2) Packer and test. Test backside to 1500 PSI applied to work string x tbg annulus. 6. Rig up sand injector. 7. Establish circulation and record rates @ 1 & 2 BPM. 8. Close casing valve and establish injection rates @ 1 & 2 BPM. 9. Spot to end of tubing and pump 20/40 Gravel pack sand @ 2-3 BPM until sand out of 800 – 1000 psi over injection rate. (Approximately 25# per foot of perforations) 10. Restrict returns by 1 BPM to aid in sand injection to the formation. 11. After achieving sand out allow pressure to bleed to 0 psi. 12. Re-stress Gravel pack two more times and bleed to 0 psi each time. 13. Open packer bypass and reverse out 1-½ tubing volumes and monitor returns. 14. Release clutch joint and POOH slowly to avoid swabbing the interval. 15. Lay down service tool assembly. 10. RIH with 4-1/2” gas lift completion, SSSV, X nipple w/ plug. See proposed schematic for details and depths. 11. Set packer/pressure test completion a. Pressure up and set packer b. Test tubing against plug in X nipple to ш2,500psig and chart for 30 minutes. c. Test IA to 1,500 psi and chart for 30 minutes (This will pressure up tubing also). d. Pull prong and plug in X-Nipple. 12. Pick up, space out and make up tubing hanger. 13. ND BOP, NU wellhead, test same. 14. RDMO Rig 404 15. MIRU Coil tubing 16. Test BOP’s to 250psi low/3,000psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). a. Cleanout well to PBTD w/ KCl b. Blow the well dry with N2 c. Returns taken to the production header d. RD Coil tubing 17. Turn well over to production 18. Schedule SVS testing with AOGCC as per regulations Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Wellhead Diagram 4. BOP Stack 5. Standard Well Procedure – Nitrogen Operations 6. Flow Diagrams 7. Coil Tubing BOP stack 8. BOP Test procedure 9. RWO Sundry Revision Change Form Provide 48 hrs notice to AOGCC to witness MITIA. Test IA to 1,500 psi and chart for 30 minutes Updated By: JLL 03/02/21 SCHEMATIC McArthur River Field Well: M-09 Last Completed: 09/07/1996 PTD: 196-127 API: 50-733-20476-00 PBTD: 4,398’ TD: 4,500’ MAX HOLE ANGLE = 61.1º @ 2,701’ 28” RKB: MSL =160’ RKB to Seafloor = 345’ 7” A-2 3 4 7 TOL 7” @ 1,003’ 13-3/8” 9-5/8” 1 2 TOC @756’ 5 6 A-2 & A-3 A-5A & A-5 TOC @ 1,484’ SZ -18A SZ -23 SZ -20 SZ-24 SZ -22 SZ-18A SZ -19A SZ-19B X CASING DETAIL Size Wt Grade Conn ID Top Btm 28” Surf 488’ 13-3/8” 68 K-55 BTC 12.415 Surf 838’ 9-5/8” 47 L-80 BTC 8.681 Surf 1,488’ 7” 29 L-80 NSCC 6.184 1,003’ 4,494’ TUBING DETAIL 7” 29 L-80 KC Butt 6.184 Surf 1,003’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 1 74.05 RKB 74.05 RKB CIW 12” X 7” TWO STEP TBG HANGER W/ 7” BUTT TOP & BOTTOM W/ “J” PROFILE 2 474' 474' 3.50 HES 5.963” SVLN W/ BAL LINE W/ 5.693” SCSSSV W/ BAL LINE (3.50” ID) ON 5.963” “RB” LOCK MANDREL 3 1,003' 1,000' 6.64’ BAKER SEAL ASSEMBLY FOR TIE BACK EXTENSION A2 GRAVEL PACK 4 3,524' 2,586' BOT SC-1R PACKER 5-13/16” X 4.00” UPPER EXT 5-9/16” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-5/8” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 3554’ 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 3645’ BOT “F” SEATING NIPPLE 4-3/4” X 3.313”@ 3825’ S-22B SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ 1/2 MULE SHOE 4.00” X 3.25” A2 & A3 GRAVEL PACK 5 3,828' 2,737' BOT SC-1R PACKER 5-13/16” X 4.00”@ 3828’ UPPER EXT 5-9/16” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-9/16” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 3858’ 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 3863’ BOT “F” SEATING NIPPLE 4-3/4” X 3.313”@ 3984’ S-22B SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ 1/2 MULE SHOE 4.00” X 3.25” A5 GRAVEL PACK 6 3,986' 2,817' BOT SC-1R PACKER 5-13/16” X 4.00”@ 3986’ UPPER EXT 5-1/2” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-9/16” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 4017’ 4” .012 GA 140 SCRN W/ 6-1/16” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 4127’ SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ CHAM BTM4.00” X 3.25” 7 4,308' 2,981' BOT “DA” SUMP PACKER 5-11/16” X 4” X 3-1/4”@ 4308’ Updated By: JLL 03/02/21 McArthur River Field Well: M-09 Last Completed: 09/07/1996 PTD: 196-127 API: 50-733-20476-00 SCHEMATIC PERFORATION DETAIL (Tie-In Log Intervals - DIL Depths) Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT SPF Date COMMENTS SZ-18A 2,590’ 2,600’ 2,120 2,125’ 10’ 6 11/08/17 2-7/8” 6 SPF Razor Carrier SZ-18A 2,600’ 2,646’ 2,124’ 2,147’ 46’ 02/13/21 Open SZ-19A 2,806’ 2,818’ 2,225’ 2,231’ 12’ 02/13/21 Open SZ-19B 2,833’ 2,844’ 2,239’ 2,244’ 11’ 02/13/21 Open SZ-20 2,982’ 3,010’ 2,314’ 2,329’ 28’ 6 11/06/17 2-7/8” 6 SPF Razor Carrier SZ-22 3,221’ 3,241’ 2,434’ 2,444’ 20’ 6 07/28/20 2-7/8” 6 SPF Razor Carrier SZ-22 3,246’ 3,266’ 2,447’ 2,457’ 20’ 6 07/28/20 2-7/8” 6 SPF Razor Carrier SZ-22 3,270’ 3,290’ 2,459’ 2,469’ 20’ 6 07/28/20 2-7/8” 6 SPF Razor Carrier SZ-23 3,320’ 3,330’ 2,484’ 2,488’ 10’ 6 11/07/17 2-7/8” 6 SPF Razor Carrier SZ-24 3,451’ 3,476’ 2,550’ 2,562’ 25’ 6 05/02/20 2-7/8” 6 SPF GeoRazor Carrier A2 3,677' 3,681' 2,662' 2,664' 4' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,689' 3,704' 2,668' 2,676' 15' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,710' 3,816' 2,679' 2,731' 106' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2A 3,868' 3,902' 2,757' 2,774' 34' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 3,942' 3,948' 2,794' 2,797' 6' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 3,970' 3,977' 2,808' 2,812' 7' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A5A 4,151' 4,165' 2,901' 2,909' 14' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,186' 4,248' 2,919' 2,951' 62' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,266' 4,298' 2,960' 2,976' 32' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE Updated By: JLL 04/20/21 PROPOSED McArthur River Field Well: M-09 Last Completed: FUTURE PTD: 196-127 API: 50-733-20476-00 CASING DETAIL Size Wt Grade Conn ID Top Btm 28” Surf 488’ 13-3/8” 68 K-55 BTC 12.415 Surf 838’ 9-5/8” 47 L-80 BTC 8.681 Surf 1,488’ 7” 29 L-80 KC Butt 6.184 Surf 1,003’ 7” 29 L-80 NSCC 6.184 1,003’ 4,494’ TUBING DETAIL 3.5” 9.2 L-80 IBT-M 2.922 Surf 2409’ JEWELRY DETAIL No Depth (MD) Depth (TVD) ID Item 74.05 RKB 74.05 RKB Hanger 1 ±470’ ±470’ SSSV 2 ±474’ ±474’ ±6” Milled out SSSV Landing Nipple 3 ±1,675’ ±1,600’ 2.992” GLM #1 ±2,350’ ±2,000’ 2.992” GLM #2 SZ GRAVEL PACK 4 ±2,409’ ±2,029’ 2.992” 7” Hydraulic Retrievable Packer 3.5” X nipple (2.812” ID) – 2424’ MD 3.5” Production Overshot w/ 3.5” EUE Box 3.5” Hook Up Nipple w/ 3.5” NU 10rd Pin 3.5” L-80 NU 10rd Blank Pipe (3 jts) 3.5” 0.012 Ga Wire Wrapped Screen (30jts) XO 3.5” NU 10rd Box x 3.5” EUE Pin 4” Snap Latch Seal Ass’y 4” x 5.5” 7” Permanent packer 3.5” EUE 10k Dual Disk Sub 3.5” X nipple (2.812” ID) – 3512’ MD 4” Locator Seal Ass’y w/ 2 seal units 5.50”x4.00” A2 GRAVEL PACK 5 3,524' 2,586' BOT SC-1R PACKER 5-13/16” X 4.00” UPPER EXT 5-9/16” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-5/8” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 3554’ 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4-5/8” X 3-9/16” @ 3645’ BOT “F” SEATING NIPPLE 4-3/4” X 3.313” @ 3825’ S-22B SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ 1/2 MULE SHOE 4.00” X 3.25” A2 & A3 GRAVEL PACK 6 3,828' 2,737' BOT SC-1R PACKER 5-13/16” X 4.00” @ 3828’ UPPER EXT 5-9/16” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-9/16” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 3858’ 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4-5/8” X 3-9/16” @ 3863’ BOT “F” SEATING NIPPLE 4-3/4” X 3.313” @ 3984’ S-22B SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ 1/2 MULE SHOE 4.00” X 3.25” A5 GRAVEL PACK 7 3,986' 2,817' BOT SC-1R PACKER 5-13/16” X 4.00” @ 3986’ UPPER EXT 5-1/2” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-9/16” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 4017’ 4” .012 GA 140 SCRN W/ 6-1/16” CENT IN MID & PIN END 4-5/8” X 3-9/16” @ 4127’ SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ CHAM BTM4.00” X 3.25” 8 4,308' 2,981' BOT “DA” SUMP PACKER 5-11/16” X 4” X 3-1/4” @ 4308’ Updated By: JLL 04/20/21 McArthur River Field Well: M-09 Last Completed: FUTURE PTD: 196-127 API: 50-733-20476-00 PROPOSED PERFORATION DETAIL (Tie-In Log Intervals - DIL Depths) Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Date COMMENTS SZ-18A ±2,590’ ±2,600’ ±2,120 ±2,125’ ±10’ 6 11/08/17 2-7/8” 6 SPF Razor Carrier SZ-18A ±2,600’ ±2,646’ ±2,124’ ±2,147’ ±46’ 02/13/21 Open SZ-19A ±2,806’ ±2,818’ ±2,225’ ±2,231’ ±12’ 02/13/21 Open SZ-19B ±2,833’ ±2,844’ ±2,239’ ±2,244’ ±11’ 02/13/21 Open SZ-20 ±2,982’ ±3,010’ ±2,314’ ±2,329’ ±28’ 6 11/06/17 2-7/8” 6 SPF Razor Carrier SZ-22 ±3,221’ ±3,241’ ±2,434’ ±2,444’ ±20’ 6 07/28/20 2-7/8” 6 SPF Razor Carrier SZ-22 ±3,246’ ±3,266’ ±2,447’ ±2,457’ ±20’ 6 07/28/20 2-7/8” 6 SPF Razor Carrier SZ-22 ±3,270’ ±3,290’ ±2,459’ ±2,469’ ±20’ 6 07/28/20 2-7/8” 6 SPF Razor Carrier SZ-23 ±3,320’ ±3,330’ ±2,484’ ±2,488’ ±10’ 6 11/07/17 2-7/8” 6 SPF Razor Carrier SZ-24 ±3,451’ ±3,476’ ±2,550’ ±2,562’ ±25’ 6 05/02/20 2-7/8” 6 SPF GeoRazor Carrier A2 ±3,677' ±3,681' ±2,662' ±2,664' ±4' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 ±3,689' ±3,704' ±2,668' ±2,676' ±15' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 ±3,710' ±3,816' ±2,679' ±2,731' ±106' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2A ±3,868' ±3,902' ±2,757' ±2,774' ±34' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 ±3,942' ±3,948' ±2,794' ±2,797' ±6' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 ±3,970' ±3,977' ±2,808' ±2,812' ±7' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A5A ±4,151' ±4,165' ±2,901' ±2,909' ±14' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 ±4,186' ±4,248' ±2,919' ±2,951' ±62' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 ±4,266' ±4,298' ±2,960' ±2,976' ±32' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE Steelhead Platform M-09 Current 05/12/2021 Casing head, McEvoy SL (two-step), 13 5/8 5M x 13 3/8 SOW, w/ 2- 3 1/8 5M EFO Tubing head, McEvoy SL (two-step), 13 5/8 5M x 13 5/8 5M w/ 2- 2 1/16 5M SSO, YB type bottom Tubing hanger, McEvoy-SL- EN, 13 5/8 x 7'’ BTC lift and susp, w/ 2- non continuous control line ports, 6 3/8 J type BPV profile, 5 seal neck hanger Valve, master, CIW-FC, 7 1/16 5M w/ 6 3/8 bore, HWO, EE trim Valve, Swab, CIW-FC, 7 1/16 5M w/ 6 3/8 bore, HWO, EE trim Valve, upper master, SSV, CIW-FC, 7 1/16 5M w/ 6 3/8 bore, w/ Baker oper, EE trim Tree cap, OTIS, 7 1/16 5M x 9 ½ OTIS quick union Valve, wing, CIW-FL, 4 1/16 5M FE, HWO, EE trim Valve, wing, CIW-FL, 4 1/16 5M FE, HWO, EE trim Steelhead Platform M-09 13 3/8 x 9 5/8 x 7 13 3/8 9 5/8 7 Steelhead Platform M-09 Proposed 05/19/2021 Valve, Master, CIW-FLS, 3 1/8 5M FE, HWO, EE trim Valve, Upper master, CIW-FLS, 3 1/8 5M FE, HWO, EE trim Valve, Swab, CIW-FLS 3 1/8 5M FE, HWO, EE trim Valve, Wing, SSV, WKM-M, 3 1/8 5M FE, w/ 15'’ air operator Casing head, McEvoy SL (two-step), 13 5/8 5M x 13 3/8 SOW, w/ 2- 3 1/8 5M EFO Tubing head, McEvoy SL (two-step), 13 5/8 5M x 13 5/8 5M w/ 2- 2 1/16 5M SSO, YB type bottom Tree cap, OTIS, 3 1/8 5M x 3'’ Bowen quick union Steelhead Platform M-09 13 3/8 x 9 5/8 x 7 x 3 1/2 13 3/8 9 5/8 7 Attachment spool, Cactus- TCM, 7 1/16 5M FE top x 7 1/16 5M Studded bottom, w/2- 2 1/16 5M SSO, no bottom prep Adapter, Cactus-EN-CCL, 7 1/16 5M Stdd x 3 1/8 5M prepped for 5 ½ extended neck hanger Tubing hanger, Cactus-EN- CCL, 7 x 3 ½ EUE 8rd lift and susp, 3'’ Type H BPV, 5 ½ EN, 2- ¼ npt control line ports 3 1/2 BOP Stack Rig 404 Shaffer SL 13 5/8 5M 2 7/8-5.5 variables Blinds 2.26' Riser 13 5/8 5M FE X 13 5/8 5M FE 4.54' 2.83' Choke and Kill valves 2 1/16 5M Mud Cross 4 1/16 5M EFO 4.30' Hydril GK 13 5/8-5000 DSA 4 X 2DSA 4 X 2Spacer spool 13 5/8 5M X 13 5/8 5M ? ? HILCORP ALASKA, LLC SwacoSuperchokeBlooey LineTo Gas BusterInlet Coiled Tubing BOP 05/21/2020 SWAB VALVE MASTER VALVE Hilcorp Flow DiagramFluids Pumped Fluids ReturnedValve Open Valve ClosedGate Valve Ball ValveButterfly Valve Lo Torq ValveAutomatic Choke Manual ChokePressure Gauge Knife ValveChoke LineP PIT SYSTEM SucƟon SHAKER SHAKER CHOKE MANIFOLDGAS BUSTER Panic LineC12 C13 C15 C14 C16 A B C4 C5 C6 C7 C2 C10 C9 C11 C8 C3 P C1 C Rig 404 BOP Test Procedure Attachment #1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Rig 404, WO Program – Oil Producers, Gas Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with kill weight fluid. x Note: Fluid level will fall to a depth that balances with reservoir pressure. x Shoot fluid levels as needed. 3) Confirm that well is static. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won’t pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) Fill well with KWF if the fluid is not to surface b) ND tree with no BPV Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing (test) joint to lift-threads d) For ESP wells - Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and / or a penetrator leaks, notify Operations Engineer (Hilcorp), Mr. Bryan McLellan (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) Rig 404 BOP Test Procedure Attachment #1 f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests (i.e. Test Plug can be set in the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same- RIH with test plug on joint of tubing. Install a pump-in sub w/ test line plus an open TIW or lower Kelly valve in top of test joint w/ open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump- install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder (test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close 1 st valve on standpipe manifold (PM1), close valves 8,10 &11 on choke manifold and close the annular preventer, open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and xxx psi (see sundry) high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer, close safety valve and open IBOP on test joint, close outside valve on kill side of mud cross (K2), open PM1, close valves 5,7 & 9 on choke manifold, open valve 10 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close manual and super choke / open valves 7 & 9 on choke manifold. Bleed pressure from step b or c recording change and stabilization. If passes after 5 minutes, bleed off pressure back to tank. e) Close inside valve (K1) / open outside valve on kill side of mud cross (K2), close valves 2,4 & 6 / open valves 5,7 & 9 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. f) Close valves 1 & 3 / open valves 4 & 6 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. Rig 404 BOP Test Procedure Attachment #1 g) Close HCR (CL2) open valves 2,4 & 6 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Close inside valve (CL1) / open outside valve (HCR) on choke side of mud cross. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Ensure all pressure is bled off- open pipe rams and pull test joint leaving test plug / 2-way check in place. Close blind rams and attach test line to valve 11 on choke manifold, close valve 1,2 & 3 / open valve 11 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. j) Test additional floor valves (TIW or Lower Kelly Valve) and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record “Accumulator Pressure”. It should be +/- 3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2 nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read “10 bottles at 2,150 psi”). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the electric pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/- 30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/- 3,000 psi). Note: Make sure the electric pump is turned to “Auto”, not “Manual” so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format. Document both the rolling test and the follow up tests. Rig 404 BOP Test Procedure Attachment #1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Rig 404, WO Program – Oil Producers, Gas Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with kill weight fluid. x Note: Fluid level will fall to a depth that balances with reservoir pressure. x Shoot fluid levels as needed. 3) Confirm that well is static. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won’t pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) Fill well with KWF if the fluid is not to surface b) ND tree with no BPV Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing (test) joint to lift-threads d) For ESP wells - Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and / or a penetrator leaks, notify Operations Engineer (Hilcorp), Mr. Bryan McLellan (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) Rig 404 BOP Test Procedure Attachment #1 f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests (i.e. Test Plug can be set in the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same- RIH with test plug on joint of tubing. Install a pump-in sub w/ test line plus an open TIW or lower Kelly valve in top of test joint w/ open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump- install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder (test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close 1 st valve on standpipe manifold (PM1), close valves 8,10 &11 on choke manifold and close the annular preventer, open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and xxx psi (see sundry) high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer, close safety valve and open IBOP on test joint, close outside valve on kill side of mud cross (K2), open PM1, close valves 5,7 & 9 on choke manifold, open valve 10 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close manual and super choke / open valves 7 & 9 on choke manifold. Bleed pressure from step b or c recording change and stabilization. If passes after 5 minutes, bleed off pressure back to tank. e) Close inside valve (K1) / open outside valve on kill side of mud cross (K2), close valves 2,4 & 6 / open valves 5,7 & 9 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. f) Close valves 1 & 3 / open valves 4 & 6 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. Rig 404 BOP Test Procedure Attachment #1 g) Close HCR (CL2) open valves 2,4 & 6 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Close inside valve (CL1) / open outside valve (HCR) on choke side of mud cross. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Ensure all pressure is bled off- open pipe rams and pull test joint leaving test plug / 2-way check in place. Close blind rams and attach test line to valve 11 on choke manifold, close valve 1,2 & 3 / open valve 11 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. j) Test additional floor valves (TIW or Lower Kelly Valve) and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record “Accumulator Pressure”. It should be +/- 3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2 nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read “10 bottles at 2,150 psi”). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the electric pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/- 30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/- 3,000 psi). Note: Make sure the electric pump is turned to “Auto”, not “Manual” so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format. Document both the rolling test and the follow up tests. Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well: Trading Bay Unit M-09 (PTD 196-127)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 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 4,500 feet N/A feet true vertical 3,076 feet N/A feet Effective Depth measured 4,398 feet See schematic feet true vertical 3,026 feet See schematic feet Perforation depth Measured depth 2,590 - 4,298 feet True Vertical depth 2,120 - 2,976 feet Tubing (size, grade, measured and true vertical depth)7" 29# / L-80 1,003 MD 1,000 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: 13. Prior to well operation: Subsequent to operation: 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: Contact Name: Authorized Title: Contact Email: Contact Phone: Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: Daniel E. Marlowe Operations Manager Burst Collapse Katherine O'Connor Katherine.oconnor@hilcorp.com Tubing Pressure 1,950psi 4,760psi 3,450psi 6,870psi (907) 777-8376 8,160psi 488 837 1,451 3,074 488 838 Conductor Surface 7,020psi 28" 13-3/8" 9-5/8" 1,488 3,491 Size 9 Production Casing Structural Liner Length Intermediate N/A Junk 5. Permit to Drill Number: 551 McArthur River Field / Middle Kenai Gas PoolN/A measured 1,488 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 9 N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-062 12 Authorized Signature with date: Authorized Name: 0 WINJ WAG STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 196-127 50-733-20476-00-00 Plugs ADL0018730 Trading Bay Unit M-09 measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 30 Casing PressureOil-Bbl measured true vertical Packer 7" 4,494 402 Water-Bbl MD 488 838 TVD PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 10:20 am, Mar 04, 2021 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.03.03 15:28:37 -09'00' Dan Marlowe (1267) SFD 3/16/2021BJM 4/6/21 DSR-3/4/21 RBDMS HEW 3/5/2021 Updated By: JLL 03/02/21 SCHEMATIC McArthur River Field Well: M-09 Last Completed: 09/07/1996 PTD: 196-127 API: 50-733-20476-00 PBTD: 4,398’ TD: 4,500’ MAX HOLE ANGLE = 61.1º @ 2,701’ 28” RKB: MSL =160’ RKB to Seafloor = 345’ 7” A-2 3 4 7 TOL 7” @ 1,003’ 13-3/8” 9-5/8” 1 2 TOC @756’ 5 6 A-2 & A-3 A-5A & A-5 TOC @ 1,484’ SZ -18A SZ -23 SZ -20 SZ-24 SZ -22 SZ-18A SZ -19A SZ-19B X CASING DETAIL Size Wt Grade Conn ID Top Btm 28” Surf 488’ 13-3/8” 68 K-55 BTC 12.415 Surf 838’ 9-5/8” 47 L-80 BTC 8.681 Surf 1,488’ 7” 29 L-80 NSCC 6.184 1,003’ 4,494’ TUBING DETAIL 7” 29 L-80 KC Butt 6.184 Surf 1,003’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 1 74.05 RKB 74.05 RKB CIW 12” X 7” TWO STEP TBG HANGER W/ 7” BUTT TOP & BOTTOM W/ “J” PROFILE 2 474' 474' 3.50 HES 5.963” SVLN W/ BAL LINE W/ 5.693” SCSSSV W/ BAL LINE (3.50” ID) ON 5.963” “RB” LOCK MANDREL 3 1,003' 1,000' 6.64’ BAKER SEAL ASSEMBLY FOR TIE BACK EXTENSION A2 GRAVEL PACK 4 3,524' 2,586' BOT SC-1R PACKER 5-13/16” X 4.00” UPPER EXT 5-9/16” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-5/8” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 3554’ 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 3645’ BOT “F” SEATING NIPPLE 4-3/4” X 3.313”@ 3825’ S-22B SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ 1/2 MULE SHOE 4.00” X 3.25” A2 & A3 GRAVEL PACK 5 3,828' 2,737' BOT SC-1R PACKER 5-13/16” X 4.00”@ 3828’ UPPER EXT 5-9/16” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-9/16” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 3858’ 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 3863’ BOT “F” SEATING NIPPLE 4-3/4” X 3.313”@ 3984’ S-22B SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ 1/2 MULE SHOE 4.00” X 3.25” A5 GRAVEL PACK 6 3,986' 2,817' BOT SC-1R PACKER 5-13/16” X 4.00”@ 3986’ UPPER EXT 5-1/2” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-9/16” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 4017’ 4” .012 GA 140 SCRN W/ 6-1/16” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 4127’ SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ CHAM BTM4.00” X 3.25” 7 4,308' 2,981' BOT “DA” SUMP PACKER 5-11/16” X 4” X 3-1/4”@ 4308’ Updated By: JLL 03/02/21 McArthur River Field Well: M-09 Last Completed: 09/07/1996 PTD: 196-127 API: 50-733-20476-00 SCHEMATIC PERFORATION DETAIL (Tie-In Log Intervals - DIL Depths) Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT SPF Date COMMENTS SZ-18A 2,590’ 2,600’ 2,120 2,125’ 10’ 6 11/08/17 2-7/8” 6 SPF Razor Carrier SZ-18A 2,600’ 2,646’ 2,124’ 2,147’ 46’ 02/13/21 Open SZ-19A 2,806’ 2,818’ 2,225’ 2,231’ 12’ 02/13/21 Open SZ-19B 2,833’ 2,844’ 2,239’ 2,244’ 11’ 02/13/21 Open SZ-20 2,982’ 3,010’ 2,314’ 2,329’ 28’ 6 11/06/17 2-7/8” 6 SPF Razor Carrier SZ-22 3,221’ 3,241’ 2,434’ 2,444’ 20’ 6 07/28/20 2-7/8” 6 SPF Razor Carrier SZ-22 3,246’ 3,266’ 2,447’ 2,457’ 20’ 6 07/28/20 2-7/8” 6 SPF Razor Carrier SZ-22 3,270’ 3,290’ 2,459’ 2,469’ 20’ 6 07/28/20 2-7/8” 6 SPF Razor Carrier SZ-23 3,320’ 3,330’ 2,484’ 2,488’ 10’ 6 11/07/17 2-7/8” 6 SPF Razor Carrier SZ-24 3,451’ 3,476’ 2,550’ 2,562’ 25’ 6 05/02/20 2-7/8” 6 SPF GeoRazor Carrier A2 3,677' 3,681' 2,662' 2,664' 4' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,689' 3,704' 2,668' 2,676' 15' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,710' 3,816' 2,679' 2,731' 106' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2A 3,868' 3,902' 2,757' 2,774' 34' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 3,942' 3,948' 2,794' 2,797' 6' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 3,970' 3,977' 2,808' 2,812' 7' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A5A 4,151' 4,165' 2,901' 2,909' 14' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,186' 4,248' 2,919' 2,951' 62' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,266' 4,298' 2,960' 2,976' 32' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE SZ-18A 2,600’ 2,646’ 2,124’ 2,147’ 46’ 02/13/21 Open SZ-19A 2,806’ 2,818’ 2,225’ 2,231’ 12’ 02/13/21 Open SZ-19B 2,833’ 2,844’ 2,239’ 2,244’ 11’ 02/13/21 Open // / Rig Start Date End Date Eline 2/13/21 2/13/21 Morning meeting, PTW, PJSM. Make up Gamma/CCL & 9' X 3.12" WT bar. Stab on well, Fluid pack for low/high pt. O- ring leak on lub. break off lub and replace O-ring. Re pt WLV and lub 250/1500. Open well, swab 23, whp 10 psi, RIH. Start setting wt down at 3005.9', Log up to 2400', send log to town for evaluation. POOH, Tagged up, swab shut, bleed down, pop off well. Make up Gun #1, 11', 2.875", 6 spf, 60* phase, 15 gram razor gun. Stab on well, Open up. RIH, @ 3000', pull log up to 2600', Send to town for correlation. Approval to shoot SZ-19B 2833'-2844' (Geologist), RIH to 3000', PU getting on CCL depth 2821.9'. CCL t/top shot 11.1', CCL t/bottom shot 22.1'. Shoot SZ-19B 2833'-2844'. ITP 10, FTP 10, NO change. POOH, Tagged up, swab shut, bleed down, pop off well. All shots fired. Dry Gun. Make up Gun #2, 12', 2.875", 6 spf, 60* phase, 15 gram razor gun. Stab on well, Open up. RIH, @ 2950' log up to 2600', Send log to town engineers for approval to shoot SZ-19A 2806'-2818'. Approved (Geologist). RIH to 2900' Log up getting on CCL depth 2795.9'. CCL t/top shot10.1', CCL t/bottom shot 22.1'. Shoot SZ-19A 2806'-2818'. ITP 10, FTP 10. 300k increase. POOH, Tagged up, bleed down, pop off well, All shots fired, Dry gun. Make up Gun #3, 20', 2.875", 6 spf, 60* phase, 15 gram razor gun. Stab on well, Open up. RIH, @ 2800' log up to 2450'. Send log to town engineers for approval to shoot SZ-18A 2626'-2646'. Shift log 1', resend to town for approval. Got approval to shoot SZ-18A 2626'-2646' (Geologist). RIH to 2800', log up getting on CCL depth 2617.7'. CCL T/top shot 8.3', CCL T/bottom shot 28.3'. Shoot SZ- 18A 2626'-2646'. ITP 10psi, FTP 10psi. POOH. Tagged up, swab shut, bleed down, pop off well. All shots fired, Wet gun. Make up Gun #4, 26' 2.875", 6 spf, 60* phase, 15 gram razor gun. Stab on well, Open up, RIH, @ 2800' log up to 2400', send log to town engineers for correlation. Got approval to shoot SZ-18A 2600'-2626' (Geologist). RIH to 2800', log up getting on CCL depth 2590.9', CCL t/top shot 9.1', CCL t/bottom shot 35.1', Shoot SZ-18A 2600'-2626'. ITP 11, FTP 11, not much change. POOH, Tagged up, swab shut, bleed down, pop off well, All shots fired. Wet gun. RD move over to M-16. 02/13/21 - Saturday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name M-09 50-733-20476-00 196-127 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): McArthur River Field / Middle Kenai Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 4,500'N/A Casing Collapse Structural Conductor Surface 1,950 psi Intermediate 4,760 psi Production 7,020 psi 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 Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:Katherine.oconnor@hilcorp.com Contact Phone: (907) 777-8376 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 6,870 psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 Authorized Signature: Operations Manager Katherine O'Connor CO 228A PRESENT WELL CONDITION SUMMARY N/A3,076' 4,398' 3,026' 864 psi COMMISSION USE ONLY Authorized Name: Burst 1,003 8,160 psi Tubing Size: 196-127 50-733-20476-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC Trading Bay Unit M-09 MDLength Size 3,450 psi 488' 837' 1,451' 488' 838' TVD 28" 13-3/8" 488' 9-5/8"1,488' 838' Perforation Depth MD (ft): 1,488' 2,590 - 4,298 3,491' See Schematic See Schematic Tubing Grade:Tubing MD (ft): 2,120 - 2,976 Perforation Depth TVD (ft): 29# / L-80 3,074'7" 4,494' Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 2/20/2021 7" Daniel E. Marlowe Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 4:08 pm, Jan 29, 2021 321-062 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.01.29 14:12:01 -09'00' Dan Marlowe (1267) DSR-2/1/21DLB 02/01/2021 X gls 2/2/21 Perforate GAS 10-404 Comm. 2/2/21 dts 2/2/2021 JLC 2/2/2021 RBDMS HEW 2/3/2021 Well Work Prognosis Well Name:Trading Bay Unit M-09 API Number: 50-733-20476-00 Current Status:Gas Well Leg:B-2 (NE corner) Estimated Start Date:2/20/2021 Rig:E-Line Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett Permit to Drill Number:196-127 First Call Engineer:Katherine O’Connor Office: 907-777-8376 Cell: 214-684-7400 Second Call Engineer:Karson Kozub Office: 907-777-8434 Cell: 907-570-1801 Current Bottom Hole Pressure:150 psi @ 2,320’ TVD Maximum Expected BHP:960 psi @ 2,215’ TVD Maximum Potential Surface Pressure:864 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)( 4) **Well to be perforated well flowing Brief Well Summary: Well M-09 is a gas well currently completed in the SZ and A Sands. In 2020, 85’ of perforations in the SZ sands were added uphole. Recently the well has began sanding up and lost production due to fill in the tubing. Plan is to eventually gravel pack the well for full production. In the meantime, the objective is to add more perforations uphole. E-line Procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. RU e-line guns and perforate with well flowing per program. 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Updated By: JLL 08/21/20 SCHEMATIC McArthur River Field Well: M-09 Last Completed: 09/07/1996 PTD: 196-127 API: 50-733-20476-00 PBTD: 4,398’ TD: 4,500’ MAX HOLE ANGLE = 61.1º @ 2,701’ 28” RKB: MSL =160’ RKB to Seafloor = 345’ 7” A-2 3 4 7 TOL 7” @ 1,003’ 13-3/8” 9-5/8” 1 2 TOC @756’ 5 6 A-2 & A-3 A-5A & A-5 TOC @ 1,484’ SZ-18 SZ-23 SZ-20 SZ-24 SZ-22 X CASING DETAIL Size Wt Grade Conn ID Top Btm 28” Surf 488’ 13-3/8” 68 K-55 BTC 12.415 Surf 838’ 9-5/8” 47 L-80 BTC 8.681 Surf 1,488’ 7” 29 L-80 NSCC 6.184 1,003’ 4,494’ TUBING DETAIL 7” 29 L-80 KC Butt 6.184 Surf 1,003’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 1 74.05 RKB 74.05 RKB CIW 12” X 7” TWO STEP TBG HANGER W/ 7” BUTT TOP & BOTTOM W/ “J” PROFILE 2 474' 474' 3.50 HES 5.963” SVLN W/ BAL LINE W/ 5.693” SCSSSV W/ BAL LINE (3.50” ID) ON 5.963” “RB” LOCK MANDREL 3 1,003' 1,000' 6.64’ BAKER SEAL ASSEMBLY FOR TIE BACK EXTENSION A2 GRAVEL PACK 4 3,524' 2,586' BOT SC-1R PACKER 5-13/16” X 4.00” UPPER EXT 5-9/16” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-5/8” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 3554’ 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 3645’ BOT “F” SEATING NIPPLE 4-3/4” X 3.313”@ 3825’ S-22B SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ 1/2 MULE SHOE 4.00” X 3.25” A2 & A3 GRAVEL PACK 5 3,828' 2,737' BOT SC-1R PACKER 5-13/16” X 4.00”@ 3828’ UPPER EXT 5-9/16” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-9/16” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 3858’ 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 3863’ BOT “F” SEATING NIPPLE 4-3/4” X 3.313”@ 3984’ S-22B SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ 1/2 MULE SHOE 4.00” X 3.25” A5 GRAVEL PACK 6 3,986' 2,817' BOT SC-1R PACKER 5-13/16” X 4.00”@ 3986’ UPPER EXT 5-1/2” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-9/16” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 4017’ 4” .012 GA 140 SCRN W/ 6-1/16” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 4127’ SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ CHAM BTM4.00” X 3.25” 7 4,308' 2,981' BOT “DA” SUMP PACKER 5-11/16” X 4” X 3-1/4”@ 4308’ Updated By: JLL 08/21/20 McArthur River Field Well: M-09 Last Completed: 09/07/1996 PTD: 196-127 API: 50-733-20476-00 SCHEMATIC PERFORATION DETAIL (Tie-In Log Intervals - DIL Depths) Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT SPF Date COMMENTS SZ-18 2,590’ 2,600’ 2,120 2,125’ 10 6 11/08/17 2-7/8” 6 SPF Razor Carrier SZ-20 2,982’ 3,010’ 2,314’ 2,329’ 28’ 6 11/06/17 2-7/8” 6 SPF Razor Carrier SZ-22 3,221’ 3,241’ 2,434’ 2,444’ 20’ 6 07/28/20 2-7/8” 6 SPF Razor Carrier SZ-22 3,246’ 3,266’ 2,447’ 2,457’ 20’ 6 07/28/20 2-7/8” 6 SPF Razor Carrier SZ-22 3,270’ 3,290’ 2,459’ 2,469’ 20’ 6 07/28/20 2-7/8” 6 SPF Razor Carrier SZ-23 3,320’ 3,330’ 2,484’ 2,488’ 10’ 6 11/07/17 2-7/8” 6 SPF Razor Carrier SZ-24 3,451’ 3,476’ 2,550’ 2,562’ 25’ 6 05/02/20 2-7/8” 6 SPF GeoRazor Carrier A2 3,677' 3,681' 2,662' 2,664' 4' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,689' 3,704' 2,668' 2,676' 15' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,710' 3,816' 2,679' 2,731' 106' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2A 3,868' 3,902' 2,757' 2,774' 34' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 3,942' 3,948' 2,794' 2,797' 6' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 3,970' 3,977' 2,808' 2,812' 7' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A5A 4,151' 4,165' 2,901' 2,909' 14' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,186' 4,248' 2,919' 2,951' 62' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,266' 4,298' 2,960' 2,976' 32' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE Updated By: JLL 01/28/21 PROPOSED McArthur River Field Well: M-09 Last Completed: 09/07/1996 PTD: 196-127 API: 50-733-20476-00 PBTD: 4,398’ TD: 4,500’ MAX HOLE ANGLE = 61.1º @ 2,701’ 28” RKB: MSL =160’ RKB to Seafloor = 345’ 7” A-2 3 4 7 TOL 7” @ 1,003’ 13-3/8” 9-5/8” 1 2 TOC @756’ 5 6 A-2 & A-3 A-5A & A-5 TOC @ 1,484’ SZ-18A SZ-23 SZ-20 SZ-24 SZ-22 SZ-18A SZ-19A SZ-19B X CASING DETAIL Size Wt Grade Conn ID Top Btm 28” Surf 488’ 13-3/8” 68 K-55 BTC 12.415 Surf 838’ 9-5/8” 47 L-80 BTC 8.681 Surf 1,488’ 7” 29 L-80 NSCC 6.184 1,003’ 4,494’ TUBING DETAIL 7” 29 L-80 KC Butt 6.184 Surf 1,003’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 1 74.05 RKB 74.05 RKB CIW 12” X 7” TWO STEP TBG HANGER W/ 7” BUTT TOP & BOTTOM W/ “J” PROFILE 2 474' 474' 3.50 HES 5.963” SVLN W/ BAL LINE W/ 5.693” SCSSSV W/ BAL LINE (3.50” ID) ON 5.963” “RB” LOCK MANDREL 3 1,003' 1,000' 6.64’ BAKER SEAL ASSEMBLY FOR TIE BACK EXTENSION A2 GRAVEL PACK 4 3,524' 2,586' BOT SC-1R PACKER 5-13/16” X 4.00” UPPER EXT 5-9/16” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-5/8” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 3554’ 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 3645’ BOT “F” SEATING NIPPLE 4-3/4” X 3.313”@ 3825’ S-22B SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ 1/2 MULE SHOE 4.00” X 3.25” A2 & A3 GRAVEL PACK 5 3,828' 2,737' BOT SC-1R PACKER 5-13/16” X 4.00”@ 3828’ UPPER EXT 5-9/16” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-9/16” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 3858’ 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 3863’ BOT “F” SEATING NIPPLE 4-3/4” X 3.313”@ 3984’ S-22B SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ 1/2 MULE SHOE 4.00” X 3.25” A5 GRAVEL PACK 6 3,986' 2,817' BOT SC-1R PACKER 5-13/16” X 4.00”@ 3986’ UPPER EXT 5-1/2” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-9/16” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 4017’ 4” .012 GA 140 SCRN W/ 6-1/16” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 4127’ SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ CHAM BTM4.00” X 3.25” 7 4,308' 2,981' BOT “DA” SUMP PACKER 5-11/16” X 4” X 3-1/4”@ 4308’ Updated By: JLL 01/28/21 McArthur River Field Well: M-09 Last Completed: 09/07/1996 PTD: 196-127 API: 50-733-20476-00 PROPOSED PERFORATION DETAIL (Tie-In Log Intervals - DIL Depths) Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT SPF Date COMMENTS SZ-18A 2,590’ 2,600’ 2,120 2,125’ 10’ 6 11/08/17 2-7/8” 6 SPF Razor Carrier SZ-18A ±2,600’ ±2,646’ ±2,124’ ±2,147’ ±46’ Future Proposed SZ-19A ±2,806’ ±2,818’ ±2,225’ ±2,231’ ±12’ Future Proposed SZ-19B ±2,833’ ±2,844’ ±2,239’ ±2,244’ ±11’ Future Proposed SZ-20 2,982’ 3,010’ 2,314’ 2,329’ 28’ 6 11/06/17 2-7/8” 6 SPF Razor Carrier SZ-22 3,221’ 3,241’ 2,434’ 2,444’ 20’ 6 07/28/20 2-7/8” 6 SPF Razor Carrier SZ-22 3,246’ 3,266’ 2,447’ 2,457’ 20’ 6 07/28/20 2-7/8” 6 SPF Razor Carrier SZ-22 3,270’ 3,290’ 2,459’ 2,469’ 20’ 6 07/28/20 2-7/8” 6 SPF Razor Carrier SZ-23 3,320’ 3,330’ 2,484’ 2,488’ 10’ 6 11/07/17 2-7/8” 6 SPF Razor Carrier SZ-24 3,451’ 3,476’ 2,550’ 2,562’ 25’ 6 05/02/20 2-7/8” 6 SPF GeoRazor Carrier A2 3,677' 3,681' 2,662' 2,664' 4' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,689' 3,704' 2,668' 2,676' 15' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,710' 3,816' 2,679' 2,731' 106' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2A 3,868' 3,902' 2,757' 2,774' 34' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 3,942' 3,948' 2,794' 2,797' 6' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 3,970' 3,977' 2,808' 2,812' 7' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A5A 4,151' 4,165' 2,901' 2,909' 14' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,186' 4,248' 2,919' 2,951' 62' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,266' 4,298' 2,960' 2,976' 32' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 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 4,500 feet N/A feet true vertical 3,076 feet N/A feet Effective Depth measured 4,398 feet See schematic feet true vertical 3,026 feet See schematic feet Perforation depth Measured depth 2,590 - 4,298 feet True Vertical depth 2,120 - 2,976 feet Tubing (size, grade, measured and true vertical depth)7" 29# / L-80 1,003 MD 1,000 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: 13. Prior to well operation: Subsequent to operation: 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: Contact Name: Authorized Title: Contact Email: Contact Phone: 1,467 Water-Bbl MD 488 838 TVD Oil-Bbl measured true vertical Packer 7" measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 180 Casing Pressure STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 196-127 50-733-20476-00-00 Plugs ADL0018730 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-293 20 Authorized Signature with date: Authorized Name: 0 WINJ WAG Trading Bay Unit M-09 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 8 N/A Intermediate N/A Junk 5. Permit to Drill Number: 3,867 McArthur River Field / Middle Kenai Gas PoolN/A measured 1,488 3,491 Size 8 Production Casing Structural Liner Length 488 838 Conductor Surface 7,020psi 28" 13-3/8" 9-5/8" 1,488 4,494 8,160psi 488 837 1,451 3,074 1,950psi 4,760psi 3,450psi 6,870psi (907) 777-8376 Collapse Katherine O'Connor Katherine.oconnor@hilcorp.com Tubing Pressure Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: Daniel E. Marlowe Operations Manager Burst PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 1:37 pm, Aug 24, 2020 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.08.24 08:42:33 -08'00' Dan Marlowe (1267) DSR-8/24/2020 RBDMS HEW 8/27/2020 gls 9/9/20 SFD 8/28/2020 Updated By: JLL 08/21/20 SCHEMATIC McArthur River Field Well: M-09 Last Completed: 09/07/1996 PTD: 196-127 API: 50-733-20476-00 PBTD: 4,398’ TD: 4,500’ MAX HOLE ANGLE = 61.1º @ 2,701’ 28” RKB: MSL =160’ RKB to Seafloor = 345’ 7” A-2 3 4 7 TOL 7” @ 1,003’ 13-3/8” 9-5/8” 1 2 TOC @756’ 5 6 A-2 & A-3 A-5A & A-5 TOC @ 1,484’ SZ-18 SZ-23 SZ-20 SZ-24 SZ-22 X CASING DETAIL Size Wt Grade Conn ID Top Btm 28” Surf 488’ 13-3/8” 68 K-55 BTC 12.415 Surf 838’ 9-5/8” 47 L-80 BTC 8.681 Surf 1,488’ 7” 29 L-80 NSCC 6.184 1,003’ 4,494’ TUBING DETAIL 7” 29 L-80 KC Butt 6.184 Surf 1,003’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 1 74.05 RKB 74.05 RKB CIW 12” X 7” TWO STEP TBG HANGER W/ 7” BUTT TOP & BOTTOM W/ “J” PROFILE 2 474' 474' 3.50 HES 5.963” SVLN W/ BAL LINE W/ 5.693” SCSSSV W/ BAL LINE (3.50” ID) ON 5.963” “RB” LOCK MANDREL 3 1,003' 1,000' 6.64’ BAKER SEAL ASSEMBLY FOR TIE BACK EXTENSION A2 GRAVEL PACK 4 3,524' 2,586' BOT SC-1R PACKER 5-13/16” X 4.00” UPPER EXT 5-9/16” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-5/8” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 3554’ 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 3645’ BOT “F” SEATING NIPPLE 4-3/4” X 3.313”@ 3825’ S-22B SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ 1/2 MULE SHOE 4.00” X 3.25” A2 & A3 GRAVEL PACK 5 3,828' 2,737' BOT SC-1R PACKER 5-13/16” X 4.00”@ 3828’ UPPER EXT 5-9/16” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-9/16” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 3858’ 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 3863’ BOT “F” SEATING NIPPLE 4-3/4” X 3.313”@ 3984’ S-22B SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ 1/2 MULE SHOE 4.00” X 3.25” A5 GRAVEL PACK 6 3,986' 2,817' BOT SC-1R PACKER 5-13/16” X 4.00”@ 3986’ UPPER EXT 5-1/2” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-9/16” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 4017’ 4” .012 GA 140 SCRN W/ 6-1/16” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 4127’ SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ CHAM BTM4.00” X 3.25” 7 4,308' 2,981' BOT “DA” SUMP PACKER 5-11/16” X 4” X 3-1/4”@ 4308’ SZ-ZZ 22 Updated By: JLL 08/21/20 McArthur River Field Well: M-09 Last Completed: 09/07/1996 PTD: 196-127 API: 50-733-20476-00 SCHEMATIC PERFORATION DETAIL (Tie-In Log Intervals - DIL Depths) Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT SPF Date COMMENTS SZ-18 2,590’ 2,600’ 2,120 2,125’ 10 6 11/08/17 2-7/8” 6 SPF Razor Carrier SZ-20 2,982’ 3,010’ 2,314’ 2,329’ 28’ 6 11/06/17 2-7/8” 6 SPF Razor Carrier SZ-22 3,221’ 3,241’ 2,434’ 2,444’ 20’ 6 07/28/20 2-7/8” 6 SPF Razor Carrier SZ-22 3,246’ 3,266’ 2,447’ 2,457’ 20’ 6 07/28/20 2-7/8” 6 SPF Razor Carrier SZ-22 3,270’ 3,290’ 2,459’ 2,469’ 20’ 6 07/28/20 2-7/8” 6 SPF Razor Carrier SZ-23 3,320’ 3,330’ 2,484’ 2,488’ 10’ 6 11/07/17 2-7/8” 6 SPF Razor Carrier SZ-24 3,451’ 3,476’ 2,550’ 2,562’ 25’ 6 05/02/20 2-7/8” 6 SPF GeoRazor Carrier A2 3,677' 3,681' 2,662' 2,664' 4' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,689' 3,704' 2,668' 2,676' 15' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,710' 3,816' 2,679' 2,731' 106' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2A 3,868' 3,902' 2,757' 2,774' 34' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 3,942' 3,948' 2,794' 2,797' 6' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 3,970' 3,977' 2,808' 2,812' 7' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A5A 4,151' 4,165' 2,901' 2,909' 14' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,186' 4,248' 2,919' 2,951' 62' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,266' 4,298' 2,960' 2,976' 32' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE SZ-22 3,221’ 3,241’ 2,434’ 2,444’ 20’ 6 07/28/20 2-7/8” 6 SPF Razor Carrier SZ-22 3,246’ 3,266’ 2,447’ 2,457’ 20’ 6 07/28/20 2-7/8” 6 SPF Razor Carrier SZ-22 3,270’ 3,290’ 2,459’ 2,469’ 20’ 6 07/28/20 2-7/8” 6 SPF Razor Carrier SZ 22 3 221’ 3 241’ 2 434’ 2 444’ 20’ 6 07/28/20 2 7/8”6 SPF R C i ///,,,, Rig Start Date End Date Eline 7/28/20 7/28/20 PJSM. R/u Lubricator & m/u tool string = GR, CCL, gun #1- 20' 2 7/8" carrier with 15 gram Razor charges, 6 SPF, 60 deg Phasing. Stab on lubricator, PT 250/1500 good. RIH t/3460', log up t/ 3090', send log into town for correlation adjustment, log verified good by GEO. Pull gun #1 i nto position CCL @ 3262.1', CCL 7.9' t/top shot, CCL 27.9' t/BTM shot, placing shots @ 3270-3290' fire gun, good indication gun fired, IFTP 25, flow rate 2.0, post shot FTP 50 psi, flowing 4.0, log up 200' cont. POOH all shots fired bull plug wet & grey silt. Pull gun #2- 20' 2 7/8" carrier with 15 gram Razor charges, 6 SPF, 60 de g Phasing into position CCL @ 3262.11', CCL 7.9' t/top shot, CCL 27.9' t/BTM shot, placing shots @ 3246'-3266' f ire gun, good indication gun fired, IFTP 50, flow rate 4.0, post shot FTP 65 psi, flowing 4.8 MMCF, log up 200' cont. POOH all shots fired bull plug wet & grey silt. Rih had issues getting Gun #3 down, had production pinch flow back cont. in hole t/ 3257'. Pull gun #3- 20' 2 7/8" carrier with 15 gram Razor charges, 6 SPF, i nto position CCL @ 3213.1', CCL 7.9' t/top shot, CCL 27.9' t/BTM shot, placing shots @ 3221'-3241' fire gun, goo d indication gun fired, IFTP 88 , flow rate 4.1, post shot FTP 92 psi, flowing 4.3 MMCF, log up 200' cont. POOH all shots fired bull plug wet & grey silt. R/D move over to M-02 07/28/20 - Tuesday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name M-09 50-733-20476-00 196-127 placing shots @ 3270-3290' fire gun, placing shots @ 3246'-3266' fire gun, placing shots @ 3221'-3241' fire g 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): McArthur River Field / Middle Kenai Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 4,500'N/A Casing Collapse Structural Conductor Surface 1,950 psi Intermediate 4,760 psi Production 7,020 psi 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 Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:Katherine.oconnor@hilcorp.com Contact Phone: (907) 777-8376 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 3,074'7" Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 7/25/2020 7" Daniel E. Marlowe See Schematic 4,494' Perforation Depth MD (ft): 1,488' 2,590 - 4,298 3,491' See Schematic Tubing Grade:Tubing MD (ft): 2,120 - 2,976 Perforation Depth TVD (ft): 28" 13-3/8" 488' 9-5/8"1,488' 838' MD 3,450 psi 488' 837' 1,451' 488' 838' 29# / L-80 TVD Burst 1,003 8,160 psi Tubing Size: 196-127 50-733-20476-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC Trading Bay Unit M-09 N/A3,076' 4,398' 3,026' 838 psi COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 Authorized Signature: Operations Manager Katherine O'Connor CO 228A PRESENT WELL CONDITION SUMMARY Length Size 6,870 psi Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Jody Colombie at 3:59 pm, Jul 10, 2020 320-293 Daniel Marlowe I am approving this document 2020.07.10 15:44:04 -08'00' Daniel Marlowe DSR-7/10/2020VTL 7/13/20 10-404 DLB 07/10/2020 X X Comm. 7/13/2020 dts 7/13/2020 JLC 7/13/2020 RBDMS HEW 7/16/2020 Well Work Prognosis Well Name:Trading Bay Unit M-09 API Number: 50-733-20476-00 Current Status:Gas Well Leg:B-2 (NE corner) Estimated Start Date:7/25/2020 Rig:E-Line Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett Permit to Drill Number:196-127 First Call Engineer:Katherine O’Connor Office: 907-777-8376 Cell: 214-684-7400 Second Call Engineer:Mark McKinley Office: 907-777-8387 Cell: 907-953-2685 Current Bottom Hole Pressure:1,050 psi @ 2,120’ TVD 0.495 psi/ft SIBP Maximum Expected BHP:1,050 psi @ 2,120’ TVD 0.495 psi/ft high case for new perfs Maximum Potential Surface Pressure:838 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)( 4) **Well to be perforated well flowing Brief Well Summary: Well M-09 is a gas well currently completed in the SZ and A Sands. In early 2020 a sundry was submitted to perforate the SZ-22 & SZ-24b sands, but after perfing the SZ-24B sands, the SZ-22 perforations were put on hold due to the success of the 24B zone. It is now time to go back in and perforate SZ-22. E-line Procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. RU e-line guns and perforate with well flowing per program. 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Updated By: JLL 05/11/20 SCHEMATIC McArthur River Field Well: M-09 Last Completed: 09/07/1996 PTD: 196-127 API: 50-733-20476-00 PBTD: 4,398’ TD: 4,500’ MAX HOLE ANGLE = 61.1º @ 2,701’ 28” RKB: MSL =160’ RKB to Seafloor = 345’ 7” A-2 3 4 7 TOL 7” @ 1,003’ 13-3/8” 9-5/8” 1 2 TOC @ 756’ 5 6 A-2 & A-3 A-5A & A-5 TOC @ 1,484’ SZ-18 SZ-23 SZ-20 SZ-24 X CASING DETAIL Size Wt Grade Conn ID Top Btm 28” Surf 488’ 13-3/8” 68 K-55 BTC 12.415 Surf 838’ 9-5/8” 47 L-80 BTC 8.681 Surf 1,488’ 7” 29 L-80 NSCC 6.184 1,003’ 4,494’ TUBING DETAIL 7” 29 L-80 KC Butt 6.184 Surf 1,003’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 1 74.05 RKB 74.05 RKB CIW 12” X 7” TWO STEP TBG HANGER W/ 7” BUTT TOP & BOTTOM W/ “J” PROFILE 2 474' 474' 3.50 HES 5.963” SVLN W/ BAL LINE W/ 5.693” SCSSSV W/ BAL LINE (3.50” ID) ON 5.963” “RB” LOCK MANDREL 3 1,003' 1,000' 6.64’ BAKER SEAL ASSEMBLY FOR TIE BACK EXTENSION A2 GRAVEL PACK 4 3,524' 2,586' BOT SC-1R PACKER 5-13/16” X 4.00” UPPER EXT 5-9/16” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-5/8” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 3554’ 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 3645’ BOT “F” SEATING NIPPLE 4-3/4” X 3.313”@ 3825’ S-22B SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ 1/2 MULE SHOE 4.00” X 3.25” A2 & A3 GRAVEL PACK 5 3,828' 2,737' BOT SC-1R PACKER 5-13/16” X 4.00”@ 3828’ UPPER EXT 5-9/16” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-9/16” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 3858’ 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 3863’ BOT “F” SEATING NIPPLE 4-3/4” X 3.313”@ 3984’ S-22B SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ 1/2 MULE SHOE 4.00” X 3.25” A5 GRAVEL PACK 6 3,986' 2,817' BOT SC-1R PACKER 5-13/16” X 4.00”@ 3986’ UPPER EXT 5-1/2” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-9/16” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 4017’ 4” .012 GA 140 SCRN W/ 6-1/16” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 4127’ SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ CHAM BTM4.00” X 3.25” 7 4,308' 2,981' BOT “DA” SUMP PACKER 5-11/16” X 4” X 3-1/4”@ 4308’ Updated By: JLL 05/11/20 McArthur River Field Well: M-09 Last Completed: 09/07/1996 PTD: 196-127 API: 50-733-20476-00 SCHEMATIC PERFORATION DETAIL (Tie-In Log Intervals - DIL Depths) Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT SPF Date COMMENTS SZ-18 2,590’ 2,600’ 2,120 2,125’ 10 6 11/08/17 2-7/8” 6 SPF Razor Carrier SZ-20 2,982’ 3,010’ 2,314’ 2,329’ 28’ 6 11/06/17 2-7/8” 6 SPF Razor Carrier SZ-23 3,320’ 3,330’ 2,484’ 2,488’ 10’ 6 11/07/17 2-7/8” 6 SPF Razor Carrier SZ-24 3,451’ 3,476’ 2,550’ 2,562’ 25’ 6 05/02/20 2-7/8” 6 SPF GeoRazor Carrier A2 3,677' 3,681' 2,662' 2,664' 4' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,689' 3,704' 2,668' 2,676' 15' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,710' 3,816' 2,679' 2,731' 106' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2A 3,868' 3,902' 2,757' 2,774' 34' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 3,942' 3,948' 2,794' 2,797' 6' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 3,970' 3,977' 2,808' 2,812' 7' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A5A 4,151' 4,165' 2,901' 2,909' 14' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,186' 4,248' 2,919' 2,951' 62' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,266' 4,298' 2,960' 2,976' 32' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE Updated By: JLL 07/10/20 PROPOSED McArthur River Field Well: M-09 Last Completed: 09/07/1996 PTD: 196-127 API: 50-733-20476-00 PBTD: 4,398’ TD: 4,500’ MAX HOLE ANGLE = 61.1º @ 2,701’ 28” RKB: MSL =160’ RKB to Seafloor = 345’ 7” A-2 3 4 7 TOL 7” @ 1,003’ 13-3/8” 9-5/8” 1 2 TOC @756’ 5 6 A-2 & A-3 A-5A & A-5 TOC @ 1,484’ SZ-18 SZ-23 SZ-20 SZ-24 SZ-22 X CASING DETAIL Size Wt Grade Conn ID Top Btm 28” Surf 488’ 13-3/8” 68 K-55 BTC 12.415 Surf 838’ 9-5/8” 47 L-80 BTC 8.681 Surf 1,488’ 7” 29 L-80 NSCC 6.184 1,003’ 4,494’ TUBING DETAIL 7” 29 L-80 KC Butt 6.184 Surf 1,003’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 1 74.05 RKB 74.05 RKB CIW 12” X 7” TWO STEP TBG HANGER W/ 7” BUTT TOP & BOTTOM W/ “J” PROFILE 2 474' 474' 3.50 HES 5.963” SVLN W/ BAL LINE W/ 5.693” SCSSSV W/ BAL LINE (3.50” ID) ON 5.963” “RB” LOCK MANDREL 3 1,003' 1,000' 6.64’ BAKER SEAL ASSEMBLY FOR TIE BACK EXTENSION A2 GRAVEL PACK 4 3,524' 2,586' BOT SC-1R PACKER 5-13/16” X 4.00” UPPER EXT 5-9/16” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-5/8” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 3554’ 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 3645’ BOT “F” SEATING NIPPLE 4-3/4” X 3.313”@ 3825’ S-22B SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ 1/2 MULE SHOE 4.00” X 3.25” A2 & A3 GRAVEL PACK 5 3,828' 2,737' BOT SC-1R PACKER 5-13/16” X 4.00”@ 3828’ UPPER EXT 5-9/16” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-9/16” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 3858’ 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 3863’ BOT “F” SEATING NIPPLE 4-3/4” X 3.313”@ 3984’ S-22B SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ 1/2 MULE SHOE 4.00” X 3.25” A5 GRAVEL PACK 6 3,986' 2,817' BOT SC-1R PACKER 5-13/16” X 4.00”@ 3986’ UPPER EXT 5-1/2” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-9/16” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 4017’ 4” .012 GA 140 SCRN W/ 6-1/16” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 4127’ SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ CHAM BTM4.00” X 3.25” 7 4,308' 2,981' BOT “DA” SUMP PACKER 5-11/16” X 4” X 3-1/4”@ 4308’ Updated By: JLL 07/10/20 McArthur River Field Well: M-09 Last Completed: 09/07/1996 PTD: 196-127 API: 50-733-20476-00 PROPOSED PERFORATION DETAIL (Tie-In Log Intervals - DIL Depths) Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT SPF Date COMMENTS SZ-18 2,590’ 2,600’ 2,120 2,125’ 10 6 11/08/17 2-7/8” 6 SPF Razor Carrier SZ-20 2,982’ 3,010’ 2,314’ 2,329’ 28’ 6 11/06/17 2-7/8” 6 SPF Razor Carrier SZ-22 ±3,221’ ±3,241’ ±2,434’ ±2,444’ 20’ FUTURE PROPOSED SZ-22 ±3,246’ ±3,266’ ±2,447’ ±2,457’ 20’ FUTURE PROPOSED SZ-22 ±3,270’ ±3,290’ ±2,459’ ±2,469’ 20’ FUTURE PROPOSED SZ-23 3,320’ 3,330’ 2,484’ 2,488’ 10’ 6 11/07/17 2-7/8” 6 SPF Razor Carrier SZ-24 3,451’ 3,476’ 2,550’ 2,562’ 25’ 6 05/02/20 2-7/8” 6 SPF GeoRazor Carrier A2 3,677' 3,681' 2,662' 2,664' 4' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,689' 3,704' 2,668' 2,676' 15' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,710' 3,816' 2,679' 2,731' 106' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2A 3,868' 3,902' 2,757' 2,774' 34' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 3,942' 3,948' 2,794' 2,797' 6' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 3,970' 3,977' 2,808' 2,812' 7' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A5A 4,151' 4,165' 2,901' 2,909' 14' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,186' 4,248' 2,919' 2,951' 62' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,266' 4,298' 2,960' 2,976' 32' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. W ell 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 4,500 feet N/A feet true vertical 3,076 feet N/A feet Effective Depth measured 4,398 feet See schematic feet true vertical 3,026 feet See schematic feet Perforation depth Measured depth 2,590 - 4,298 feet True Vertical depth 2,120 - 2,976 feet Tubing (size, grade, measured and true vertical depth)7"29# / L-80 1,003 MD 1,000 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: 13. Prior to well operation: Subsequent to operation: 15.W ell Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16.W ell Status after work:Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: Hilcorp Alaska, LLC 2. Operator Name Senior Engineer:Senior Res. Engineer: Daniel E. Marlowe Operations Manager Burst 3,450psi 6,870psi (907) 777-8387 Collapse 488 837 1,451 3,074 1,950psi 4,760psi Surface 7,020psi 28" 13-3/8" 9-5/8"1,488 4,494 8,160psiProduction Casing Structural Liner Length 488 838 Conductor Mark McKinley mmckinley@hilcorp.com 5. Permit to Drill Number: 3,867 McArthur River Field / Middle Kenai Gas PoolN/A measured 1,488 3,491 Size 8 Trading Bay Unit M-09 14.Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 8 N/A Intermediate N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-171 20 Authorized Signature with date: Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 196-127 50-733-20476-00-00 Plugs ADL0018730 Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. W ell Class Before Work: 0 Representative Daily Average Production or Injection Data 180 Casing Pressure Tubing Pressure 0 Oil-Bbl measured true vertical Packer 7" WINJ WAG 1,467 Water-Bbl MD 488 838 TVD PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Daniel Marlowe I am approving this document 2020.05.18 13:19:32 -08'00' Daniel Marlowe By Samantha Carlisle at 2:56 pm, May 20, 2020 DSR-5/20/2020 SFD 5/21/2020 Perforate RBDMS HEW 5/20/2020 3,867 gls 5/26/2020 Updated By: JLL 05/11/20 SCHEMATIC McArthur River Field Well: M-09 Last Completed: 09/07/1996 PTD: 196-127 API: 50-733-20476-00 PBTD: 4,398’ TD: 4,500’ MAX HOLE ANGLE = 61.1º @ 2,701’ 28” RKB: MSL =160’ RKB to Seafloor = 345’ 7” A-2 3 4 7 TOL 7” @ 1,003’ 13-3/8” 9-5/8” 1 2 TOC @ 756’ 5 6 A-2 & A-3 A-5A & A-5 TOC @ 1,484’ SZ-18 SZ-23 SZ-20 SZ-24 X CASING DETAIL Size Wt Grade Conn ID Top Btm 28” Surf 488’ 13-3/8” 68 K-55 BTC 12.415 Surf 838’ 9-5/8” 47 L-80 BTC 8.681 Surf 1,488’ 7” 29 L-80 NSCC 6.184 1,003’ 4,494’ TUBING DETAIL 7” 29 L-80 KC Butt 6.184 Surf 1,003’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 1 74.05 RKB 74.05 RKB CIW 12” X 7” TWO STEP TBG HANGER W/ 7” BUTT TOP & BOTTOM W/ “J” PROFILE 2 474' 474' 3.50 HES 5.963” SVLN W/ BAL LINE W/ 5.693” SCSSSV W/ BAL LINE (3.50” ID) ON 5.963” “RB” LOCK MANDREL 3 1,003' 1,000' 6.64’ BAKER SEAL ASSEMBLY FOR TIE BACK EXTENSION A2 GRAVEL PACK 4 3,524' 2,586' BOT SC-1R PACKER 5-13/16” X 4.00” UPPER EXT 5-9/16” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-5/8” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 3554’ 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 3645’ BOT “F” SEATING NIPPLE 4-3/4” X 3.313”@ 3825’ S-22B SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ 1/2 MULE SHOE 4.00” X 3.25” A2 & A3 GRAVEL PACK 5 3,828' 2,737' BOT SC-1R PACKER 5-13/16” X 4.00”@ 3828’ UPPER EXT 5-9/16” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-9/16” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 3858’ 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 3863’ BOT “F” SEATING NIPPLE 4-3/4” X 3.313”@ 3984’ S-22B SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ 1/2 MULE SHOE 4.00” X 3.25” A5 GRAVEL PACK 6 3,986' 2,817' BOT SC-1R PACKER 5-13/16” X 4.00”@ 3986’ UPPER EXT 5-1/2” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-9/16” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 4017’ 4” .012 GA 140 SCRN W/ 6-1/16” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 4127’ SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ CHAM BTM4.00” X 3.25” 7 4,308' 2,981' BOT “DA” SUMP PACKER 5-11/16” X 4” X 3-1/4”@ 4308’ SZ-24 add perfs Updated By: JLL 05/11/20 McArthur River Field Well: M-09 Last Completed: 09/07/1996 PTD: 196-127 API: 50-733-20476-00 SCHEMATIC PERFORATION DETAIL (Tie-In Log Intervals - DIL Depths) Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT SPF Date COMMENTS SZ-18 2,590’ 2,600’ 2,120 2,125’ 10 6 11/08/17 2-7/8” 6 SPF Razor Carrier SZ-20 2,982’ 3,010’ 2,314’ 2,329’ 28’ 6 11/06/17 2-7/8” 6 SPF Razor Carrier SZ-23 3,320’ 3,330’ 2,484’ 2,488’ 10’ 6 11/07/17 2-7/8” 6 SPF Razor Carrier SZ-24 3,451’ 3,476’ 2,550’ 2,562’ 25’ 6 05/02/20 2-7/8” 6 SPF GeoRazor Carrier A2 3,677' 3,681' 2,662' 2,664' 4' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,689' 3,704' 2,668' 2,676' 15' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,710' 3,816' 2,679' 2,731' 106' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2A 3,868' 3,902' 2,757' 2,774' 34' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 3,942' 3,948' 2,794' 2,797' 6' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 3,970' 3,977' 2,808' 2,812' 7' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A5A 4,151' 4,165' 2,901' 2,909' 14' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,186' 4,248' 2,919' 2,951' 62' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,266' 4,298' 2,960' 2,976' 32' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE new perfs SZ-24 3,451’ 3,476’2,550’ 2,562’ 25’ 6 05/02/20 2-7/8” 6 SPF GeoRazor Carrier Rig Start Date End Date Eline 4/30/20 5/2/20 Waiting for 10:30 chopper to deliver GR tool to Platform. GR tool arrives @ Platform. MU tool suite - GR/CCL w/ 2- 7/8" X 25' perf gun. Hoist tool string and move to well. PT WLV & Lub = 250/1500, lubricator leak @ Bowen connection. Bleed off pressure and replace Bowen o-ring. Re-test same - Good Test. SSSV blocked in and locked open. Open Swab & RIH, well flowing @ 1.64 MMSCFD, w/ 2-7/8" x 25' perf gun, 6 spf, 60* phased, 15 gram HMX GeoRazor carrier. CCL-to-Bottom Shot = 32.0', CCL-to-Top Shot = 7.0'. RIH to 3820' CCL depth. T/IA = 17/8 psi. Log up w/ GR/CCL from 3820' - 2500' CCL depth. Send logging pass LAS file and pdf copy to Town for correlation. Correct log +9.0'. RBIH to 3830' CCL depth. Log up for correlation pass to 2490' CCL depth. Town confirms correlation correction and approves for shooting. RBIH to 3600' CCL depth. Log up from 3600' to 3444' CCL depth to place and park 25' perf gun on depth (3444' CCL + 32' CCL-to-Bottom shot = 3476'MD Bottom Shot). Fire gun perforating Zone SZ-24 from 3451' - 3476' MD. Log up for 200' and then continue POOH. Close Swab and bleed pressure. Break off well, all shots fired. LD gun and logging tools. RD WLV & lubricator, clean & secure drill deck & upper well bay room. Return well to production operators. Send all LAS files and pdf copies of shooting pass to Steelhead Platform Operations Engineer. Job Complete. 05/02/2020 - Saturday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name M-09 50-733-20476-00 196-127 Arrive @ Platform. Pre-job Safety Meeting with SLU crew and Platform Operators. RU SLU. MU 7" riser & WLV to WH. Boat arrives @ Platform. Crane working boat. Return to SLU RU. MU 3" DD Bailer toolstring. PT WLV & Lub = 2500 psi - good test. T/IA = 21/8 w/ well flowing. RIH w/ 3" DD Bailer. Set down @ 3000' RKB (top of SZ-20 perfs), work tools & fall thru. Continue RIH to tag @ 3890' RKB. PUH w/ multiple passes from 2980' - 3010'. Pulling thru clean. POOH. OOH w/ 2 cups mud in bailer. RIH w/ 2-7/8" x 20' Dummy Gun w/ roller bogie to 456' RKB set down. POOH. Remove roller bogie. RBIH w/ 2-7/8" x 20' Dummy Gun, minus roller bogie, to 3000' RKB set down. PU, increase RBIH speed to 180 FPM & fall thru to 3500' RKB. POOH, OOH. Secure well & shut down for night. Job in Progress. 05/01/2200 - Friday No operations to report. 04/30/2020 - Thursday Fire gun perforating Zone SZ-24 from 3451' - 3476' MD.all shots fired. Fire gun perforating Zone SZ-24 from .3451' - 3476' MD. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): McArthur River Field / Middle Kenai Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 4,500'N/A Casing Collapse Structural Conductor Surface 1,950 psi Intermediate 4,760 psi Production 7,020 psi 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 Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:mmckinley@hilcorp.com Contact Phone: (907) 777-8387 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Signature: Operations Manager Mark McKinley CO 228A PRESENT WELL CONDITION SUMMARY Length Size 6,870 psi COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 196-127 50-733-20476-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC Trading Bay Unit M-09 N/A 29# / L-80 TVD Burst 1,003 8,160 psi MD 3,450 psi 488' 837' 1,451' 488' 838' 28" 13-3/8 488' 9-5/8"1,488' 838' 4,494' Perforation Depth MD (ft): 1,488' 2,590 - 4,298 3,491' See Schematic Tubing Grade: Tubing MD (ft): 2,120 - 2,976 Perforation Depth TVD (ft): Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 5/1/2020 7" Daniel E. Marlowe See Schematic Tubing Size: 3,076' 4,398' 3,026' 838 psi 3,074'7" Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Daniel Marlowe I am approving this document 2020.04.17 13:08:49 -08'00' Daniel Marlowe By Jody Colombie at 2:32 pm, Apr 17, 2020 320-171 DSR-4/17/2020 Perforate X 10-404 gls 4/20/20 DLB 04/17/2020 Comm. 4/20/2020 dts 4/20/2020 JLC 4/20/2020 Well Work Prognosis Well Name:Trading Bay Unit M-09 API Number: 50-733-20476-00 Current Status:Gas Well Leg:B-2 (NE corner) Estimated Start Date:05/01/2020 Rig:E-Line Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett Permit to Drill Number:196-127 First Call Engineer:Mark McKinley Office: 907-777-8387 Cell: 907-953-2685 Second Call Engineer:Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Current Bottom Hole Pressure:1,050 psi @ 2,120’ TVD 0.495 psi/ft SIBP Maximum Expected BHP:1,050 psi @ 2,120’ TVD 0.495 psi/ft high case for new perfs Maximum Potential Surface Pressure:838 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)( 4) **Well to be perforated well flowing Brief Well Summary: Well M-09 is a gas well currently completed in the SZ and A Sands. This project will add perforations in the SZ-18, SZ-22 & SZ-24. E-line Procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. RU e-line guns and perforate with well flowing per program. 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Updated By: JLL 10/26/17 SCHEMATIC McArthur River Field Well: M-09 Last Completed: 09/07/1996 PTD: 196-127 API: 50-733-20476-00 PBTD: 4,398’ TD: 4,500’ MAX HOLE ANGLE = 61.1º @ 2,701’ 28” RKB: MSL =160’ RKB to Seafloor = 345’ 7” A-2 3 4 7 TOL 7” @ 1,003’ 13-3/8” 9-5/8” 1 2 TOC @756’ 5 6 A-2 & A-3 A-5A & A-5 TOC @ 1,484’ SZ-18 SZ-23 SZ-20 X CASING DETAIL Size Wt Grade Conn ID Top Btm 28” Surf 488’ 13-3/8” 68 K-55 BTC 12.415 Surf 838’ 9-5/8” 47 L-80 BTC 8.681 Surf 1,488’ 7” 29 L-80 NSCC 6.184 1,003’ 4,494’ TUBING DETAIL 7” 29 L-80 KC Butt 6.184 Surf 1,003’ PERFORATION DETAIL (Tie-In Log Intervals - DIL Depths) Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT SPF Date COMMENTS SZ-18 2,590’ 2,600’ 2,120 2,125’ 10 6 11/08/17 2-7/8” 6 SPF Razor Carrier SZ-20 2,982’ 3,010’ 2,314’ 2,329’ 28’ 6 11/06/17 2-7/8” 6 SPF Razor Carrier SZ-23 3,320’ 3,330’ 2,484’ 2,488’ 10’ 6 11/07/17 2-7/8” 6 SPF Razor Carrier A2 3,677' 3,681' 2,662' 2,664' 4' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,689' 3,704' 2,668' 2,676' 15' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,710' 3,816' 2,679' 2,731' 106' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2A 3,868' 3,902' 2,757' 2,774' 34' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 3,942' 3,948' 2,794' 2,797' 6' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 3,970' 3,977' 2,808' 2,812' 7' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A5A 4,151' 4,165' 2,901' 2,909' 14' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,186' 4,248' 2,919' 2,951' 62' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,266' 4,298' 2,960' 2,976' 32' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 1 CIW 12” X 7” TWO STEP TBG HANGER W/ 7” BUTT TOP & BOTTOM W/ “J” PROFILE 2 474' 474' 3.50 HES 5.963” SVLN W/ BAL LINE W/ 5.693” SCSSSV W/ BAL LINE (3.50” ID) ON 5.963” “RB” LOCK MANDREL 3 1,003' 1,000' 6.64’ BAKER SEAL ASSEMBLY FOR TIE BACK EXTENSION A2 GRAVEL PACK 4 3,524' 2,586' BOT SC-1R PACKER 5-13/16” X 4.00” UPPER EXT 5-9/16” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-5/8” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 3554’ 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 3645’ BOT “F” SEATING NIPPLE 4-3/4” X 3.313”@ 3825’ S-22B SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ 1/2 MULE SHOE 4.00” X 3.25” A2 & A3 GRAVEL PACK 5 3,828' 2,737' BOT SC-1R PACKER 5-13/16” X 4.00”@ 3828’ UPPER EXT 5-9/16” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-9/16” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 3858’ 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 3863’ BOT “F” SEATING NIPPLE 4-3/4” X 3.313”@ 3984’ S-22B SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ 1/2 MULE SHOE 4.00” X 3.25” A5 GRAVEL PACK 6 3,986' 2,817' BOT SC-1R PACKER 5-13/16” X 4.00”@ 3986’ UPPER EXT 5-1/2” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-9/16” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 4017’ 4” .012 GA 140 SCRN W/ 6-1/16” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 4127’ SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ CHAM BTM4.00” X 3.25” 7 4,308' 2,981' BOT “DA” SUMP PACKER 5-11/16” X 4” X 3-1/4”@ 4308’ Updated By: JLL 04/14/20 PROPOSED McArthur River Field Well: M-09 Last Completed: 09/07/1996 PTD: 196-127 API: 50-733-20476-00 PBTD: 4,398’ TD: 4,500’ MAX HOLE ANGLE = 61.1º @ 2,701’ 28” RKB: MSL =160’ RKB to Seafloor = 345’ 7” A-2 3 4 7 TOL 7” @ 1,003’ 13-3/8” 9-5/8” 1 2 TOC @ 756’ 5 6 A-2 & A-3 A-5A & A-5 TOC @ 1,484’ SZ-18 SZ-23 SZ-20 SZ-24 SZ-22 X CASING DETAIL Size Wt Grade Conn ID Top Btm 28” Surf 488’ 13-3/8” 68 K-55 BTC 12.415 Surf 838’ 9-5/8” 47 L-80 BTC 8.681 Surf 1,488’ 7” 29 L-80 NSCC 6.184 1,003’ 4,494’ TUBING DETAIL 7” 29 L-80 KC Butt 6.184 Surf 1,003’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 1 CIW 12” X 7” TWO STEP TBG HANGER W/ 7” BUTT TOP & BOTTOM W/ “J” PROFILE 2 474' 474' 3.50 HES 5.963” SVLN W/ BAL LINE W/ 5.693” SCSSSV W/ BAL LINE (3.50” ID) ON 5.963” “RB” LOCK MANDREL 3 1,003' 1,000' 6.64’ BAKER SEAL ASSEMBLY FOR TIE BACK EXTENSION A2 GRAVEL PACK 4 3,524' 2,586' BOT SC-1R PACKER 5-13/16” X 4.00” UPPER EXT 5-9/16” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-5/8” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 3554’ 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 3645’ BOT “F” SEATING NIPPLE 4-3/4” X 3.313”@ 3825’ S-22B SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ 1/2 MULE SHOE 4.00” X 3.25” A2 & A3 GRAVEL PACK 5 3,828' 2,737' BOT SC-1R PACKER 5-13/16” X 4.00”@ 3828’ UPPER EXT 5-9/16” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-9/16” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 3858’ 4” .012 GA 140 SCRN W/ 5-3/4” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 3863’ BOT “F” SEATING NIPPLE 4-3/4” X 3.313”@ 3984’ S-22B SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ 1/2 MULE SHOE 4.00” X 3.25” A5 GRAVEL PACK 6 3,986' 2,817' BOT SC-1R PACKER 5-13/16” X 4.00”@ 3986’ UPPER EXT 5-1/2” X 4-13/16” SLIDING SLEEVE 5-13/16” X 4-1/4” SEAL BORE 5-9/16” X 4.00” LOWER EXT 5.00” X 4-7/16” BOT “C” KIOV 5-9/16” X 3.50” XO 5-9/16” X 3-9/16” 4” X 3-9/16” 9.5# N-80 BLANK @ 4017’ 4” .012 GA 140 SCRN W/ 6-1/16” CENT IN MID & PIN END 4-5/8” X 3-9/16”@ 4127’ SNAP LATCH 5.00” X 3.25” SNAP LATCH SEALS W/ CHAM BTM4.00” X 3.25” 7 4,308' 2,981' BOT “DA” SUMP PACKER 5-11/16” X 4” X 3-1/4”@ 4308’ Updated By: JLL 04/14/20 McArthur River Field Well: M-09 Last Completed: 09/07/1996 PTD: 196-127 API: 50-733-20476-00 PROPOSED PERFORATION DETAIL (Tie-In Log Intervals - DIL Depths) Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT SPF Date COMMENTS SZ-18 2,590’ 2,600’ 2,120 2,125’ 10 6 11/08/17 2-7/8” 6 SPF Razor Carrier SZ-18 ±2,600’ ±2,646’ ±2,125’ ±2,148’ ±46’ Future Proposed SZ-20 2,982’ 3,010’ 2,314’ 2,329’ 28’ 6 11/06/17 2-7/8” 6 SPF Razor Carrier SZ-22 ±3,220’ ±3,241’ ±2,434’ ±2,444’ ±21’ Future Proposed SZ-22 ±3,247’ ±3,289’ ±2,447’ ±2,468’ ±42’ Future Proposed SZ-23 3,320’ 3,330’ 2,484’ 2,488’ 10’ 6 11/07/17 2-7/8” 6 SPF Razor Carrier SZ-24 ±3,451’ ±3,476’ ±2,550’ ±2,562’ ±25’ Future Proposed A2 3,677' 3,681' 2,662' 2,664' 4' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,689' 3,704' 2,668' 2,676' 15' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,710' 3,816' 2,679' 2,731' 106' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2A 3,868' 3,902' 2,757' 2,774' 34' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 3,942' 3,948' 2,794' 2,797' 6' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A3 3,970' 3,977' 2,808' 2,812' 7' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A5A 4,151' 4,165' 2,901' 2,909' 14' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,186' 4,248' 2,919' 2,951' 62' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,266' 4,298' 2,960' 2,976' 32' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE RECEIVED STATE OF ALASKA ' ALARAOIL AND GAS CONSERVATION COMM ION NOV 2 8 2017 • REPORT OF SUNDRY WELL OPERATIONSAOG CC 1.Operations Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Performed: Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing❑ Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory 0 196-127 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic 0 Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20476-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018730 Trading Bay Unit M-09 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Middle Kenai Gas Pool 11.Present Well Condition Summary: Total Depth measured 4,500 feet Plugs measured N/A feet true vertical 3,076 feet Junk measured N/A feet Effective Depth measured 4,398 feet Packer measured See Schematic feet true vertical 3,026 feet true vertical See Schematic feet Casing Length Size MD TVD Burst Collapse Structural Conductor 488' 28" 488' 488' Surface 838' 13-3/8" 838' 837' 3,450 psi 1,950 psi Intermediate 1,488' 9-5/8" 1,488' 1,451' 6,870 psi 4,760 psi Production 3,491' 7" 4,494' 3,074' 8,160 psi 7,020 psi Liner Perforation depth Measured depth 2,590-4,298 feet tiiAN � ) True Vertical depth 2,120-2,976 feet � � � Tubing(size,grade,measured and true vertical depth) 7" 29#/L-80 1,003(MD) 1,000(TVD) Packers and SSSV(type,measured and true vertical depth) See Schematic 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 512 0 10 14 Subsequent to operation: 0 6345 0 10 200 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Developments Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil ❑ Gas 0 WDSPL❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 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: 317-507 Authorized Name: Stan W.Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarloweahilcorp.com Authorized Signature: Ski., Z74Date: 4t/ z ibf l l Contact Phone: (907)283-1329 z-_,-r7 Form 10-404 Revised 4/2017 �6T rS ,� ° L r• >`, ,7 iTh- W4'// 7 RE�rvt� C �k—e L C cu{/Submit Original Only McArthur River Field H 1111 Well: M-09 SCHEMATIC Last Completed:09/07/1996 • PTD: 196-127 II ii, ,r A1a4ka.1,1.1 API: 50-733-20476-00 CASING DETAIL RKB:MSL=160' Size Wt Grade Conn ID Top Btm RKB to Seafloor =345' 28" Surf 488' 1 13-3/8" 68 K-55 BTC 12.415 Surf 838' 28' 1 C:::).11112IL 9-5/8" 47 L-80 BTC 8.681 Surf 1,488' 7" 29 L-80 NSCC 6.184 1,003' 4,494' TUBING DETAIL 7" 29 L-80 KC Butt 6.184 Surf 1,003' TOC@756' JEWELRY DETAIL 13-3/8"` ' No Depth Depth ID Item 3 (MD) (TVD) 1 CIW 12"X 7"TWO STEP TBG HANGER W/7"BUTT TOP&BOTTOM W/"J"PROFILE �� 2 474' 474' 3.50 HES 5.963"SVLN WI BAL LINE W/5.693"SCSSSV WI BAL LINE(3.50"ID)ON 5.963" "RB"LOCK MANDREL TOL7"@ el 3 1,003' 1,000' 6.64'BAKER SEAL ASSEMBLY FOR TIE BACK EXTENSION 1,003' A2 GRAVEL PACK & 4 3,524' 2,586' BOT SC-1R PACKER 5-13/16"X 4.00" 11 UPPER EXT 5-9/16"X 4-13/16" 9-5/8 SLIDING SLEEVE 5-13/16"X 4-1/4" SEAL BORE 5-9/16"X 4.00" LOWER EXT 5.00"X 4-7/16" BOT"C"KIOV 5-5/8"X 3.50" XO 5-9/16"X 3-9/16" TOC @ 1,484' 4"X 3-9/16"9.58 N-80 BLANK @ 3554' fir 4".012 GA 140 SCRN W/5-3/4"CENT IN MID&PIN END 4-5/8"X 3-9/16"@ 3645' BOT"F"SEATING NIPPLE 4-3/4"X 3.313"@ 3825' S-22B SNAP LATCH 5.00"X 3.25" SNAP LATCH SEALS W/1/2 MULE SHOE 4.00"X 3.25" A2&A3 GRAVEL PACK 5 3,828' 2,737' BOT SC-1R PACKER 5-13/16"X 4.00"@ 3828' UPPER EXT 5-9/16"X 4-13/16" SLIDING SLEEVE 5-13/16"X 4-1/4" SEAL BORE 5-9/16"X 4.00" LOWER EXT 5.00"X 4-7/16" SZ-18 BOT"C"KIOV 5-9/16"X 3.50" XO 5-9/16"X 3-9/16" SZ-20 4"X 3-9/16"9.58 N-80 BLANK @ 3858' SZ-23 4".012 GA 140 SCRN W/5-3/4"CENT IN MID&PIN END 4-5/8"X 3-9/16"@ 3863' BOT"F"SEATING NIPPLE 4-3/4"X 3.313"@ 3984' S-22B SNAP LATCH 5.00"X 3.25" 4 SNAP LATCH SEALS W/1/2 MULE SHOE 4.00"X 3.25" A5 GRAVEL PACK 6 3,986' 2,817' BOT SC-1R PACKER 5-13/16"X 4.00"@ 3986' A-2 UPPER EXT 5-1/2"X 4-13/16" SLIDING SLEEVE 5-13/16"X 4-1/4" SEAL BORE 5-9/16"X 4.00" LOWER EXT 5.00"X 4-7/16" 00 BOT"C"KIOV 5-9/16"X 3.50" IIIIIII5 XO 5-9/16"X 3-9/16" 4"X 3-9/16"9.51*N-80 BLANK @ 4017' 4".012 GA 140 SCRN W/6-1/16"CENT IN MID&PIN END 4-5/8"X 3-9/16"@ A-2&A-3 4127' rnmenSNAP LATCH 5.00"X 3.25" --- SNAP LATCH SEALS W/CHAM BTM4.00"X 3.25" X 7 I 4,308' I 2,981' I BOT"DA"SUMP PACKER 5-11/16"X 4"X 3-1/4"@ 4308' Sill 6 PERFORATION DETAIL k •- = (Tie-In Log Intervals-DIL Depths) A-5A&A-5 Zone Top Btm Top Btm FT SPF Date COMMENTS (MD) (MD) (TVD) (TVD) SZ-18 2,590' 2,600' 2,120 2,125' 10 6 11/08/17 2-7/8"6 SPF Razor Carrier 7 SZ-20 2,982' 3,010' 2,314' 2,329' 28' 6 11/06/17 2-7/8"6 SPF Razor Carrier 0 SZ-23 3,320' 3,330' 2,484' 2,488' 10' 6 11/07/17 2-7/8"6 SPF Razor Carrier A2 3,677' 3,681' 2,662' 2,664' 4' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,689' 3,704' 2,668' 2,676' 15' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE _r., A2 3,710' 3,816' 2,679' 2,731' 106' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE .,. A2A 3,868' 3,902' 2,757' 2,774' 34' 12' 8/31/1996 19 PPF 20/40 CARBOLITE PBTD:4,398' TD:4,500' A3 3,942' 3,948' 2,794' 2,797' 6' 12' 8/31/1996 19 PPF 20/40 CARBOLITE MAX HOLE ANGLE=61.12 @ 2,701' A3 3,970' 3,977' 2,808' 2,812' 7' 12' 8/31/1996 19 PPF 20/40 CARBOLITE ASA 4,151' 4,165' 2,901' 2,909' 14' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,186' 4,248' 2,919' 2,951' 62' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE Updated By:JLL 10/26/17 A5 4,266' 4,298' 2,960' 2,976' 32' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date M-09 Eline 50-733-20476-00 196-127 11/6/17 Future Daily`Operati s ` `' 11/06/2017-Monday Work Permit&JSA. Spot unit and rig up. Pressure test lubricator to 250 psi low/ 1500 psi High (o-ring leaked - replaced and tested). RIH w/3-1/8 GG and 14' of 2-7/8" 6 spf Razor carrier guns-84 holes. Perf depth 2996'-3010' (7'from CCL to top shot, CCL depth 2989'). Had trouble getting down past 2100' -Shut well in and went to 3200'to run log. Sent log to town for correlation. Perf @ 14:05. POOH, OOH -Shut down due to production alarm. Rig down, secure equipment and standby for flow test. 11/07/2017-Tuesday Complete work permit &ISA. Spot unit and rig up. Pressure test Lubricator to 250 psi low/2500 psi high. RIH with 14' of 2-7/8" 6 spf razor(84 holes) carrier guns. Perf depth 2982' to 2996' (7'to CCL at 2975'). Sent log to town for correlation. Upper SZ-20 sand. Fire guns, POOH and flow test. Prep guns for next interval. RIH with 10' of 2-7/8" 6 spf razor(60 holes) carrier guns. Peri depth 3320' to 3330' (7'to CCL at 3313'). Sent log to town for correlation. SZ-23 Sand. Perf- POOH. Line was stuck in grease head, closed rams and worked loose, open rams and POOH. Rig down for the night. 11/08/2017-Wednesday Complete work permit and JSA. Rig Up. RIH with 10' 2-7/8 6 spf Razor Carrier guns (60 holes). Perf Depth 2590' to 2600' (7' form CCL depth of 2583'to top shot). Correlate and send log to town. **SZ-18 sand. Perforate and POOH. Rig Down. Operations complete. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date M-09 Eline 50-733-20476-00 196-127 11/6/17 Future Daily Operations: 11/06/2017 - Monday Work Permit &JSA. Spot unit and rig up. Pressure test lubricator to 250 psi low/ 1500 psi High (o-ring leaked - replaced and tested). RIH w/3-1/8 GG and 14' of 2-7/8" 6 spf Razor carrier guns-84 holes. Perf depth 2996'-3010' (7' from CCL to top shot, CCL depth 2989'). Had trouble getting down past 2100' -Shut well in and went to 3200'to run log. Sent log to town for correlation. Perf @ 14:05. POOH, OOH -Shut down due to production alarm. Rig down, secure equipment and standby for flow test. 11/07/2017 -Tuesday Complete work permit &JSA. Spot unit and rig up. Pressure test Lubricator to 250 psi low/2500 psi high. RIH with 14' of 2-7/8" 6 spf razor (84 holes) carrier guns. Perf depth 2982' to 2996' (7' to CCL at 2975'). Sent log to town for correlation. Upper SZ-20 sand. Fire guns, POOH and flow test. Prep guns for next interval. RIH with 10' of 2-7/8" 6 spf razor(60 holes) carrier guns. Perf depth 3320' to 3330' (7' to CCL at 3313'). Sent log to town for correlation. SZ-23 Sand. Perf- POOH. Line was stuck in grease head, closed rams and worked loose, open rams and POOH. Rig down for the night. 11/08/2017-Wednesday Complete work permit and JSA. Rig Up. RIH with 10' 2-7/8 6 spf Razor Carrier guns (60 holes). Perf Depth 2590' to 2600' (7'form CCL depth of 2583' to top shot). Correlate and send log to town. **SZ-18 sand. Perforate and POOH. Rig Down. Operations complete. VOF741 • y\��\�yy� s� THE STATE Alaska Oil and Gas ti�► is 0,fkL.AS}(A. Conservation Commission 333 West Seventh Avenue �, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis Operations Manager Hilcorp Alaska, LLC SCON6ii OV 1 3 2017, 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai Gas Pool, Trading Bay Unit M-09 Permit to Drill Number: 196-127 Sundry Number: 317-507 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair S� DATED this� day of October, 2017. RBDRIS U L/'I CV - 2 2017 OCT 26 2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 Operations shutdown❑ Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing ❑ Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other. 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC . Exploratory 0 Development 196-127 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic 0 Service © 6.API Number Anchorage,AK 99503 50-733-20476-00-00 . 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 228A ' _ Will planned perforations require a spacing exception? Yes 0 No El / Trading Bay Unit M-09 ' 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL0018730 McArthur River Field/Middle Kenai Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 4,500 - 3,076- 4,398 s 3,026 • 838 psi N/A N/A - Casing Length Size MD TVD Burst Collapse Structural Conductor 488' 28" 488' 488' Surface 838' 13-3/8" 838' 837' 3,450 psi 1,950 psi Intermediate 1,488' 9-5/8" 1,488' 1,451' 6,870 psi 4,760 psi Production 3,491' 7" 4,494' 3,074' 8,160 psi 7,020 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(It): 3,677-4,298 • 2,662-2,976 7" 29#/L-80 1,003 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): See Schematic See Schematic r 12.Attachments: Proposal Summary a Wellbore schematic d 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development❑, / Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 11/10/2017 OIL 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 9 . WAG 0 GSTOR ❑ SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned ❑ 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: Stan W.Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmaliowe0hlICom.com 1 Authorized Signature: S4-..........., Contact Phone:��283-1329 %...... Date: 1 D 12`( t COMMISSION USE ONLY Conditions of approval: Notify Commission so t at a representative may witness Sundry Number. 3 6bqii Plug Integrity ❑ BOP Test 0 Mechanical Integrity Test ❑ Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No 0 (� RBDu S S LL-12V r mac/ r,LU i�n7 Spacing Exception Required? Yes 0 Nod Subsequent Form Required: O — 2 APPROVED BY ( ;, I' Approved by: COMMISSIONER THE COMMISSION Date: `u 4t A 10/27-f i.- ,, 0/q4, 7( 1 Form 10-403 Revised 4/2017 Approved application is of approval. u 36 -17 SubmitFand ne GiRIGtisiRAL Attachments iDuplicate �4 • • Well Work Prognosis IIilrarp Alaska,LLC Date: 10/20/2017 Well Name: Trading Bay Unit M-09 API Number: 50-733-20476-00 Current Status: Gas Well Leg: B-2 (NE corner) Estimated Start Date: 11/10/2017 Rig: E-Line Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 196-127 First Call Engineer: Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Second Call Engineer: Stan Golis Office: 907-777-8356 Current Bottom Hole Pressure: 1,050 psi @ 2,120'TVD 0.495 psi/ft SIBP Maximum Expected BHP: 1,050 psi @ 2,120'TVD 0.495 psi/ft high case for new perfs Maximum Potential Surface Pressure: 838 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) **Well to be perforated well flowing Brief Well Summary: Well M-09 is a gas well completed in the A Sands.This project will add perforations in the SZ-18 &SZ-23. E-line Procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. RU e-line guns and perforate with well flowing per program. 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic McArthur River Field • • Well: M-09 SCHEMATIC Completed:09/07/1996 PTD: 196-127 Hileorp Alaska,LLC API: 50-733-20476-00 RKB:MSL=160' CASING DETAIL RKB to Seafloor =345' Size Wt Grade Conn ID Top Btm 1 28" Surf 488' 28., 1::, taill [ 13-3/8" 68 K-55 BTC 12.415 Surf 838' 2 9-5/8" 47 L-80 BTC 8.681 Surf 1,488' 7" 29 L-80 NSCC 6.184 1,003' 4,494' TUBING DETAIL TOC @756' 7" 29 L-80 KC Butt 6.184 Surf 1,003' 13-3/8" A JEWELRY DETAIL 4 3 No Depth Depth ID Item 7 (MD) (TVD) 1 CIW 12"X 7"TWO STEP TBG HANGER W/7"BUTT TOP&BOTTOM W/"1"PROFILE Tar @ :' 2 474' 474' 3.50 HES 5.963"SVLN W/BAL LINE W/5.693"SCSSSV W/BAL LINE(3.50"ID)ON 5.963" �, "RB"LOCK MANDREL 1,003' VF` 1 3 1,003' 1,000' 6.64'BAKER SEAL ASSEMBLY FOR TIE BACK EXTENSION All 1 A2 GRAVEL PACK 9-5/8" 4 3,524' 2,586' BOT SC-1R PACKER 5-13/16"X 4.00" UPPER EXT 5-9/16"X 4-13/16" SLIDING SLEEVE 5-13/16"X 4-1/4" SEAL BORE 5-9/16"X 4.00" LOWER EXT 5.00"X 4-7/16" BOT"C"KIOV 5-5/8"X 3.50" TOC @ 1,484' 1411XO 5-9/16"X 3-9/16" 4"X 3-9/16"9.5#N-80 BLANK @ 3554' 4".012 GA 140 SCRN W/5-3/4"CENT IN MID&PIN END 4-5/8"X 3-9/16"@ 3645' 74, BOT"F"SEATING NIPPLE 4-3/4"X 3.313"@ 3825' S-22B SNAP LATCH 5.00"X 3.25" 1 SNAP LATCH SEALS W/1/2 MULE SHOE 4.00"X 3.25" >'' A2&A3 GRAVEL PACK )2 5 3,828' 2,737' BOT SC-1R PACKER 5-13/16"X 4.00"@ 3828' UPPER EXT 5-9/16"X 4-13/16" SLIDING SLEEVE 5-13/16"X 4-1/4" SEAL BORE 5-9/16"X 4.00" IX LOWER EXT 5.00"X 4-7/16" BOT"C"KIOV 5-9/16"X 3.50" r, XO 5-9/16"X 3-9/16" 4"X 3-9/16"9.54*N-80 BLANK @ 3858' 4".012 GA 140 SCRN W/5-3/4"CENT IN MID&PIN END 4-5/8"X 3-9/16"@ 3863' BOT"F"SEATING NIPPLE 4-3/4"X 3.313"@ 3984' 4 S-22B SNAP LATCH 5.00"X 3.25" SNAP LATCH SEALS W/1/2 MULE SHOE 4.00"X 3.25" A5 GRAVEL PACK A-2 6 3,986' 2,817' BOT SC-1R PACKER 5-13/16"X 4.00"@ 3986' UPPER EXT 5-1/2"X 4-13/16" SLIDING SLEEVE 543/16"X 4-1/4" (30 SEAL BORE 5-9/16"X 4.00" LOWER EXT 5.00"X 4-7/16" Pt 6 BOT"C"KIOV 5-9/16"X 3.50" - - XO 5-9/16"X 3-9/16" A-2&A 3 4"X 3-9/16"9.58 N-80 BLANK @ 4017' .gairoisemasommag 4".012 GA 140 SCRN W/6-1/16"CENT IN MID&PIN END 4-5/8"X 3-9/16"@ 4127' a SNAP LATCH 5.00"X 3.25" • X SNAP LATCH SEALS W/CHAM BTM4.00"X 3.25" ' NA 6 7 I 4,308' I 2,981' I BOT"DA"SUMP PACKER 5-11/16"X 4"X 3-1/4"@ 4308' A-5A&A-5 PERFORATION DETAIL (Tie-In Log Intervals-DIL Depths) Zone Top Btm Top Btm FT SPF Date COMMENTS 7 (MD) (MD) (TVD) (TVD) A2 3,677' 3,681' 2,662' 2,664' 4' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,689' 3,704' 2,668' 2,676' 15' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,710' 3,816' 2,679' 2,731' 106' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE 7" 7 A2A 3,868' 3,902' 2,757' 2,774' 34' 12' 8/31/1996 19 PPF 20/40 CARBOLITE L . a� A3 3,942' 3,948' 2,794' 2,797' 6' 12' 8/31/1996 19 PPF 20/40 CARBOLITE PBTD:4,398' TD:4,500' A3 3,970' 3,977' 2,808' 2,812' 7' 12' 8/31/1996 19 PPF 20/40 CARBOLITE MAX HOLE ANGLE=61.19 @ 2,701' A5A 4,151' 4,165' 2,901' 2,909' 14' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,186' 4,248' 2,919' 2,951' 62' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,266' 4,298' 2,960' 2,976' 32' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE Updated By:JLL 06/14/17 • McArthur River Field Well: M-09 H 0 PROPOSED Last Completed:09/07/1996 PTD: 196-127 llileorp Alaska,LLC API: 50-733-20476-00 CASING DETAIL RKB:MSL=160' Size Wt Grade Conn ID Top Btm RKB to Seafloor =345' 28" _ Surf 488' r 1 13-3/8" 68 K-55 BTC 12.415 Surf 838' 28" 2L 1 9-5/8" 47 L-80 BTC 8.681 Surf 1,488'IIIICMIll ' [ 7" 29 L-80 NSCC 6.184 1,003' 4,494' TUBING DETAIL 7" 29 L-80 KC Butt 6.184 Surf 1,003' TOC @756' JEWELRY DETAIL 13-3/8"L I No Depth Depth ID Item 3 (MD) (TVD) 1 OW 12"X 7"TWO STEP TBG HANGER W/7"BUTT TOP&BOTTOM WI"1"PROFILE 2 474' 474' 3.50 HES 5.963"SVLN WI BAL LINE W/5.693"SCSSSV W/BAL LINE(3.50"ID)ON 5.963" "RB"LOCK MANDREL TOL7'@ 3 1,003' 1,000' 6.64'BAKER SEAL ASSEMBLY FOR TIE BACK EXTENSION 1,003' A2 GRAVEL PACK 4 3,524' 2,586' BOT SC-1R PACKER 5-13/16"X 4.00" it 1 UPPER EXT 5-9/16"X 4-13/16" 9-5/8 SLIDING SLEEVE 5-13/16"X 4-1/4" SEAL BORE 5-9/16"X 4.00" LOWER EXT 5.00"X 4-7/16" BOT"C"KIOV S-5/8"X 3.50" XO 5-9/16"X 3-9/16" TOC @ 1,484' 4"X 3-9/16"9.58 N-80 BLANK @ 3554' 4".012 GA 140 SCRN W/5-3/4"CENT IN MID&PIN END 4-5/8"X 3-9/16"@ 3645' BOT"F"SEATING NIPPLE 4-3/4"X 3.313"@ 3825' 5-228 SNAP LATCH 5.00"X 3.25" SNAP LATCH SEALS W/1/2 MULE SHOE 4.00"X 3.25" A2&A3 GRAVEL PACK 5 3,828' 2,737' BOT SC-1R PACKER 5-13/16"X 4.00"@ 3828' UPPER EXT 5-9/16"X 4-13/16" SLIDING SLEEVE 5-13/16"X 4-1/4" SEAL BORE 5-9/16"X 4.00" LOWER EXT 5.00"X 4-7/16" SZ-18 BOT"C"KIOV 5-9/16"X 3.50" XO 5-9/16"X 3-9/16" 4"X 3-9/16"9.5#N-80 BLANK @ 3858' -sz_23 4".012 GA 140 SCRN W/5-3/4"CENT IN MID&PIN END 4-5/8"X 3-9/16"@ 3863' BOT"F"SEATING NIPPLE 4-3/4"X 3.313"@ 3984' S-22B SNAP LATCH 5.00"X 3.25" 4 SNAP LATCH SEALS W/1/2 MULE SHOE 4.00"X 3.25" A5 GRAVEL PACK 6 3,986' 2,817' BOT SC-1R PACKER 5-13/16"X 4.00"@ 3986' ' - A-2 UPPER EXT 5-1/2"X 4-13/16" --. SLIDING SLEEVE 5-13/16"X 4-1/4" -- - SEAL BORE 5-9/16"X 4.00" LOWER EXT 5.00"X 4-7/16" 00 1, BOT"C"KIOV 5-9/16"X 3.50" 5 XO 5-9/16"X 3-9/16" 4"X 3-9/16"9.58 N-80 BLANK @ 4017' 4".012 GA 140 SCRN W/6-1/16"CENT IN MID&PIN END 4-5/8"X 3-9/16"@ A-2&A-3 4127' SNAP LATCH 5.00"X 3.25" SNAP LATCH SEALS W/CHAM BTM4.00"X 3.25" F Al X 7 I 4,308' I 2,981' I BOT"DA"SUMP PACKER 5-11/16"X 4"X 3-1/4"@ 4308' 12 6 PERFORATION DETAIL __ (Tie-In Log Intervals-DIL Depths) - A-5A&A-5 Zone (MD) (MD) (TVD) (TVD) FT SPF Date COMMENTS 'rr are / SZ-18 ±2,590' ±2,600' ±2,120 ±2,125' ±10 6 Future Proposed 7 SZ-23 ±2,982' ±3,010' ±2,314' ±2,329' ±28' 6 Future Proposed SZ-23 ±3,320' ±3,330' ±2,484' ±2,488' ±10' 6 Future Proposed A2 3,677' 3,681' 2,662' 2,664' 4' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,689' 3,704' 2,668' 2,676' 15' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE A2 3,710' 3,816' 2,679' 2,731' 106' 12' 9/3/1996 59.4 PPF 20/40 CARBOLITE & A2A 3,868' 3,902' 2,757' 2,774' 34' 12' 8/31/1996 19 PPF 20/40 CARBOLITE PBTD:4,398' TD:4,500' A3 3,942' 3,948' 2,794' 2,797' 6' 12' 8/31/1996 19 PPF 20/40 CARBOLITE MAX HOLE ANGLE=61.1°@ 2,701' A3 3,970' 3,977' 2,808' 2,812' 7' 12' 8/31/1996 19 PPF 20/40 CARBOLITE A5A 4,151' 4,165' 2,901' 2,909' 14' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE A5 4,186' 4,248' 2,919' 2,951' 62' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE Updated By:1LL 10/20/17 A5 4,266' 4,298' 2,960' 2,976' 32' 12' 8/28/1996 4.8 PPF 20/40 CARBOLITE Pages NOT Scanned in this Well History File XHVZE 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. I ~(~- 1~.7 Fi~ Number of Well History File 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 Scanned by: Beverly~Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is~ ,, , PERMIT 96-127 96-127 96-127 96-127 96-127 96-127 96-127 96-127 96-127 96-127 96-127 96-127 96-127 DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS TDT LDT/CN PIL/SFL PERF 8/31/96 PERF 9/2/96 PACK CET/GR/CCL GR/CCL CBT/GR/CCL DRY ~~%~) DRY DRY DRY q~AR 3900-4302 ~~AR 1488-4469 ~L~YLAR 1488-4495 6~MYL~ 3300-3656 ~LAR 3100-3450 ~4000-4350 ~"~00-4392 ~/900-4350 ~0-4392 ~50-1830 ~1830-2790 ~/2790-3780 ~780 -4500 Page: 1 Date: 08/12/98 RUN RECVD 09/25/96 09/25/96 09/25/96 09/25/96 09/25/96 10/11/96 10/11/96 10/11/96 10/11/96 10/08/97 10/08/97 10/08/97 0/08/ 7 10-407 ~COMPLETION DATE DAILY WELL OPS R ~//1-/~/ TO ~/7 /Q~/ Are dry ditch samples required? ~ And received? Was the well cored? yes ~Analysis & description received? Are well tests required?I,~es ~~R~eceived? Well is in compliance Initial COMMENTS Gary A. Orr Senior Petroleum Engineer Dear Mr. Hart: Unocal Energy Resources Division 909 West 0th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7813 UNOCAL ) ' October 7, 1996 Mr. Jack Had Alaska Oil & Gas Conse~ation Commission aO01 ~orCupino Drivo ~ ,~~ Anchora~o, ~K Unocal has finished drilling Well M-9 and recompleting Well M-5 on the Steelhead Platform in the McArthur. River Field, Grayling Gas Sands Pool. Please find attached Gas Well Open Flow Potential Test Reports for Well M-9 (A2, A3, and A5 sands commingled) and for Well M-5 (D2 sand and D2, D1, C1 sand commingled). Please note that a large portion of the data requested on Form 10-421 is not provided. Due to the automation that exists on the Steelhead Platform, the recording of this information was not needed to get accurate flow measurements. The computerized system is programmed and calibrated to provide accurate flow measurements. Pressures for the buildup and step-rate test are recorded tubing pressures for Well M-9. For the test of the .D2 sand in Well M-5 the buildup pressure was recorded using downhole pressure gauges. Pressures for the four flow periods for the D2 sand are surface recorded tubing pressures. For the buildup and step-rate test in Well M-5 for the D2, D1, C1 commingled test, all pressures were recorded using downhole pressure gauges. If you have any questions concerning this work, please feel free to call me at (907) 263- 7813. Sincerely, · Orr RECEIVED NOV 1 4 1996 0il & ~1#~ .C. ~. C0mmljli0n Anohorige ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST I FPORT la. TEST: INITIAL B lb. STABILIZED B / NON STABILIZED D A-2, A-3, A-5 SANDS ANNUAL B MULTIPOINT B CONSTANT TIME SPECIAL D OTHER ISOCHRONAL 2, Name of Operator 7. Permit~-I~--~ 3. Address 8. APl N'aw~oer- PO Box 190247, Anchorage, AK 99519-0247 50- 733-20476 4. Location of Well 9. Unit or Lease Name TRADING BAY UNIT 10. Well Number 1035' FNL, 608 FVVL, SEC 33, T9N-R13W-SM M-9 ,,//" 11. Field and Pool MRF-GGS 5. Elevation in Feet (indicate KB, DF etc. 16. Lease Designation and Serial Number I 160 I ADL 18730 9/7/96 4500 4398 PERFORATION WITH GRAVEL PACK 16. casing Size Weight per foot, lb. I.D. in inches Set at ff. Perforations: From To 7" LINER 29 6.181 4494 3677 4298 17. Tubing Size Weight per foot, lb. I.D. in inches Set at ft. 7" 29 6.181 1003 22. Producing thru: Reservoir Temp. °F Mean Annual Temp.°F Barometric Pressue (Pa), psia Tbg. B Csg. B 80 23. Length of flow channel (L)3987.5 Iverticle Depth (H)2806. 06 I Ga' I °/°CO2 1%N2.12 .92 %H2S I Pr°var I Meterrun ITaps0 24. Flow Data Tubing Data Casing Data Prover Choke Duration of Line X Orifice Pressure Diff. Temp Pressure Temp Pressure Temp Flow No. Size (in.) Size (in.) peig hw °F psig °F psig °F Hr. 1. 1051 59 2 2. 930 2 3. 830 2 4. 70O 2 5. Basic Coefficient I -- Flow Temp. ! Gravity Super Comp. -~ hwPm Pressure Factor Factor Factor Rate of Flow (24-Hour) No. Fb or Fp Pm Ft F~ Fpv Q, Mcfd 1. 6.5 2. 13.0 3. 19.5 4. 26.0 5. for Separator for Flowing Pr Temperature Tr Z Gas Fluid No. T G~ G 1. 540 .894 .56 2. 540 .905 3. 540 .914 Critical Pressure 4. 540 .926 Critical Temperature Form 10-421 Rev. 7-1-80 CONTINUED ON REVERSE SIDE A!aSk.:-~. O~l & 03.':.:, 6o';~., O,o'!',(it~B'w')~ duplicate I-n.'_; ,' .... '~, Pc 1132.65 PSIA Pc2 1282896 Pf 1203.62 pf2 1448701 NO. Pt Pt2 PC2-Pt2 PW PW2 PC2-PW2 PS PS2 Pt~-PS2 1. 1065.65 1135610 147286 66.33 1131.98 1281379 167322 2. 944.65 892364 390532 58.08 1002.73 1005467 443234 3. 844.65 713434 569462 51.42 896.07 802941 645760 4. 714.65 510725 772171 42.94 757.59 573943 874758 5. 25. AOF (mCFD) 38237 n =.84 Remarks: Assumed N= 1 for calculating AOF All pressures were recorded with downhole guages. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed / ~',,,~.,,,3. //~'"/.,,'~ --- Title Senior Petroleum Engineer Date 9/26/96 AOF Fb Fp Fg Fpv Ft G Gg GOR hw H L n Pa Pc Pf Pm Pr Ps Pt Pw Q Tr T Z DEFINITIONS OF SYMBOLS Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia. Basic orifice factor Mcfd -~ hwPm Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor = -V/ 1/Z dimensionless Flowing temperature factor, dimensionless Specific gravity of flowing fluid (air=1.000), dimensionless Specific Gravity of separator gas (air=1.00), dimensionless Gas-oil ration, cu. ft. of gas (14.65 psia and 60 degrees F.) per barrel oil (60 degrees F.) Meter differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back- pressure equation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia Shut-in pressure at vertica! depth H, psia Static pressure at point of gas measurement, psia Reduced pressure, dimensionless Flowing pressure at vertical depth H, psia Static column wellhead pressure corresponding to Pt, psia Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.65 psia and 60 degrees F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back-Pressure Testing of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10-421 Unocal Oil & Gas 909 West 9th Ave. Anchorage, AK 99501 Tel: (907) 273-7889 Fax: (907) 263-7828 E-mail: epardacl~anchorage.unocal, com UNOCAL Debra Childers Geoscience Clerk DATA TRANSMITTAL 96-31 October 8, 1996 To: From' Laurie Taylor Debra Childers 3001 Porcupine 909 W. 9th Avenue Anchorage, AK 99501 Alaska Oil & Gas Anchorage, AK 99519-6247 Unocal TBU M-9 dry samples 850- 1830 TBU M-9 dry samples 1830 - 2790 TBU M-9 dry samples 2790 - 3780 TBU M-9 dry samples 3780 - 4500 Please acknowledfle receipt by,signing an~ retumin¢ one copy of this transmittal or FAX to (907) 263-7828. Unocal Oil & Gas 909 West 9th Ave. Anchorage, AK 99501 Tel'. (907) 273-7889 Fax: (907) 263-7828 E-mail: epardacl~anchorage.unocaLcom UNOCAL Debra Childers Geoscience Clerk DATA TRANSMITTAL 96-30 October 7, 1996 To: From' Laurie Taylor Debra Childers 3001 Porcupine 909 W. 9th Avenue Anchorage, AK 99501 Alaska Oil & Gas Anchorage, AK 99519-6247 Unocal TBU M-5 Blueline / Film Production Packers 1 9/10/96 TBU M-5 Blueline / Film Completion Record 1 9/14/96 TBU M-5 Blueline / Film GR/CCL/LOG 1 9/14/96 TBU M-5 Blueline / Film Completion Record I 9/20/96 TBU M-9 Biueline / Film Cement Bond Log CBT/GR/CCL I 8/26/96 TBU M-9 Blueline / Film Permanent Sump Packer 1 8/26/96 TBU M-9 Blueline / Film Gamma Ray/CCL 1 8/27/96 TBU M-9 Blueline / Film Cement Evaluation Log CET/GR/CCL 1 9/16/96 Please acknowleC:j~ receip.~ signing and returning one copy of this transmittal or F~ to (907) 263-7828. Received by: Date: OCT Unocal Oil & Gas 909 West 9th Ave. Anchorage, AK 99501 Tel: (907) 273-7889 Fax: (907) 263-7828 E-maih epardac1~ anchorage.unocaL com UNOCAL Debra Childers Geoscience Clerk DATA TRANSMITTAL 96-28 SEP 2 5 ]996 September 23, 1996 To: L. Taylor 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal ~ GP AN-23RD Blueline / Film Completion Record 1 9~04~96 riGP AN-37 Blueline / Film Completion Record 2 1/8 ENERJET 1 9/01/96 MGS 17595-15RD Blueline / Film Completion Record Scallop Guns 1 8/27/96 MGS 17595-15RD Blueline/Film Completion Record 2 1/8 ENERJET 1 8/19/96 SCU 323-9 Blueline / Film Gamma Ray / CCL 1 8/14/96 SCU 323-9 Blueline / Film Tubing Cutter 1 8/14/96 SCU 323-9 Blueline / Film Completion Record 1 9/16/96 SCU 323-9 Blueline / Film Gamma Ray / CCL 1 9/16/96 SCU 323-9 Blueline / Film Completion Record 1 9/17/96 SCU 332-4 Blueline / Film Completion Record 1 8/18/96 SCU 332-4 Blueline / Film Gamma Ray / CCL 1 8/18/96 SCU 332-4 Blueline / Film Tubing Cutter 1 8/18/96 SRU 14-15 Blueline / Film Thermal Decay Time Log~ 1 8/15/96 '.S.' RU 212-27 Blueline / Film Thermal Decay Time Log(' 1 8/14/96 SRU 23-22 BlUeline / Film Thermal Decay Time Log"> 1 8/15/96 .SRU 331-27 Blueline / Film Thermal Decay Time Log (~ 1 8/17/96 SRU 41A-15 Blueline / Film Thermal Decay Time Log ~ 1 8/15/96 SRU 43-28 Blueline / Film Thermal Decay Time Log-,,/ 1 8/16/96 TBU M-5 Blueline / Film Baker Plug Tubing Puncher 1 9/08/96 TBU M-9 Blueline/Film Compensated Neutron Lithodensity f 1 8/23/96 TBU M-9 Blueline / Film Perforating Depth Control 1 8/31/96 TBU M-9 Blueline / Film Perforating Depth Control 1 9/02/96 TBU M-9 Blueline / Film Phasor Induction - SFL 1 8/23/96 TBU M-9 Blueline / Film Thermal Decay Time Log f 1 8/31/96 Please acknowledge ~¢eipt by signing and retuming one copy of this transmittal or FAX to (907) 263-7828. ,-- STATE OF ALASKA ALASKA Ol,_ AND GAS CONSERVATION L,,JMMISSION WELL COi'viPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: X SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number UNOCAL 96-127 3. Address 8. APl Number P.O. Box 196247 Anchorage, AK 99519-6247 50-733-20476 4. Location of well at surface Leg B-2, Slot #1 ! !~0M?! ~i;-~-i-',,'~ 9. Unit or Lease Name 1035' FNL, 608' FWL, Sec. 33, TDN, R13W, SM ; '~ '~;~' i i I,f,.X.~ .'t1~ Trading Bay Unit At Top Producing Interval i ~ '~i! 10. Well Number 591' FSL, 1795' FWL, Sec. 28, TDN, R13W, SM @ 3677' MD ! ~,~£:~;L'}.,..~ ~. ; !'i M-9 At Total Depth ! ~--'~--~-'~-'-;- ?~~" "~' ? 11. Field and Pool 1177' FSL, 2198' FWL, Sec. 28, TDN, R13W, SM @ 4500' MD McArthur River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Grayling Gas Sands Pool 160' RKBI ADL 18730 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I 16. No. of Completions 8/16/96 8/23/96 9/7/96 Comp.I 187 feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) I 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 4500'MD/3076'TVD 4398'MD/3025'TVDI Yes: X No: 474 feet MD NA 22. Type Electric or Other Logs Run DIL/LDT/CN L/GR/CBL/CET/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I CASING SIZE WT. PER FT. GRADE TOP DO'II'OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 13-3/8" 68 K-55 76' 838' 17-1/2" 1600 sx Lead/390 sx Tail: Circ 560 sx to surface 9-5/8" 47 L-80 74' 1468' 12-1/4" 527 sx Lead/469 sx Tail: TOC @ 800'(-)by TS 7" 29 L-80 1003' 4494' 8-1/2" 650 sx @ 14.5 ppg: Circ Cement to surface 24. Perforations open to Production (MD+'FVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) MD TVD MD 'I-VD 7" 29# L-80 74' - 1003' 1003' A2 3677'-3681' 2661 '-2663' A5A 4151 '-4165' 2900'-2908' A2 3689'-3704' 2667-2675' A5 4186'-4248' 2918'-2950' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. A2 3710'-3816' 2678'-2730' A5 4266'-4298' 2959'-2975' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED A2A 3868'-3902' 2756'-2773' A2 HRVVP w/9290 lb 20/40 CarboLite A3 3942'-3946' 2793'-2796' All perforations 12 jspf A2A & A3 HRWP w/2100 lb 20/40 CarboLite A3 3970'-3977' 2808'-2811' A5A & A5 HRWP w/2710 lb 20/40 CarboLite 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lilt, etc.) 9/7/96I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 9/9/96 24 TEST PERIOD => 0 14500 24 NAI 0 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 757 0 24-HOUR RATE => 0 14500 24 NA 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED None ORIGINAL Alaska Oil & Gas Cons. CommJssio~ Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T. Tyonek "A" 3556' 2602' 31. LIST OF ATTACHMENTS Wellbore Schematic, Summary Of Daily Operations, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge j INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space 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 productin 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 gro.u, nd'.le~el (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental rebordS f°r thi~ well should shOw the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Form 10-407 STEELHEA~, PLATFORM WELL # M-9 CURRENT COMPLETION: SEPTEMBER 7, 1996 13-3/8"~838' TOL 7" @ 1003' 9-5/8" @ 1488' A2 PERFS A2A & A3 PERFS A5A & A5 PERFS 7" ~ 4494' KB = 160' 3 11 15 22 23 27 35 38 x PBTD = 4,398' DPM' TD = 4,500' MAX HOLE ANGLE = 61.1° ~ 2,701' SIZE WT CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 13-3/8 68 K-55 BTC 76' 838' 9-5/8 47 L-80 BTCt 74' 1488' 7" 29 L-80 NSCC 1003' 4494' Tubing 7" 29 L-80 KCButt 74' 1003' 6.64' BAKER SEAL ASSEMBLY FOR TIE BACK EXTENSION JEWELRY DETAIL 1. CIW 12" X 7" TWO STEP TBG HANGER W/7" BUTT TOP & BOTTOM W/"J" PROFILE. 2. HES 5.963" SVLN W/BAL LINE W/5.693" SCSSSV W/BAL LINE (3.50" ID) ON 5.963" "RB" LOCK MANDREL ~ 474". A2 GI~4VEL PACK: 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. A2A BOT SC-IR PACKER 5-13/16" X 4.00" (~ 3524' UPPER EXT 5-9/16" X 4-13/16" SLIDING SLEEVE 5-13/16" X 4-1/4" SEAL BORE 5-9/16" X 4.00" LOWER EXT 5.00" X 4-7/16" BOT "C" KIOV 5-5/8" X 3.50" XO 5-9/16" X 3-9/16" 4" X 3-9/16" 9.5/t N-80 BLANK .~ 3554' 4" .012 GA 140 SCRN W/5-3/4" CENT IN MID & PIN END 4-5/8" X 3-9/16" ~ 3645' BOT "F" SEATING NIPPLE 4-3/4" X 3.313" ~ 3825' S-22B SNAP LATCH 5.00" X 3.25" SNAP LATCH SEALS W/1/2 MULE SHOE 4.00" X 3.25" & A3 GRAVEL PACK: 15. BOT SC-1R PACKER 5-13/16" X 4.00" !9 3828' 16. UPPER EXT 5-9/16" X 4-13/16" 17. SLIDING SLEEVE 5-13/16" X 4-1/4" 18. SEAL BORE 5-9/16" X 4.00" 19. LOWER EXT 5.00" X 4-7/16" 20. BOT "C" KIOV 5-9/16" X 3.50" 21. XO 5-9/16" X3-9/16" 22. 4" X 3-9/16" 9.5//N-80 BLANK ~ 3858' 23. 4" .012 GA 140 SCRN W/5-3/4" CENT IN MID & PIN END 4-5/8" X 3-9/16" ,~! 3863' 24. BOT "F" SEATING NIPPLE 4-3/4" X 3.313" :'~ 3984' 25. S-22B SNAP LATCH 5.00" X 3.25" 26. SNAP LATCH SEALS W/1/2 MULE SHOE 4.00" X 3.25" A5 GRAVEL PACK: 27. BOT SC-IR PACKER 5-13/16" X 4.00" ¢~ 3986' 28 UPPEREXT 5-1/2" X 4-13/16" 29. SLIDING SLEEVE 5-13/16" X 4-1/4" 30. SEAL BORE 5-9/16" X 4.00" 31. LOWER EXT 5.00" X 4-7/16" 32. BOT "C" KIOV 5-9/16" X 3.50" 33. XO 5-9/16" X 3-9/16" 34. 4" X 3-9/16" 9.5//N-80 BLANK ~ 4017' 35. 4" .012 GA 140 SCRN W/6-1/16" CENT IN MID & PIN END 4-5/8" X 3-9/16" ~ 4127' 36. SNAP LATCH 5.00" X 3.25" 37. SNAP LATCH SEALS W/CHAM BTM4.00" X 3.25" 38. BOT "DA" SUMP PACKER 5-11/16" X 4" X 3-1/4" ~ 4308' TOP BTM ZONE PERFORATION DATA (Tie-In Log Intervals--DIL Depths) SPF DATE COMMENTS 3677'-3681' A2 3689'-3704' A2 3710'-3816' A2 3868'-3902' A2A 3942'-3948' A3 3970'-3977' A3 4151'-4165' A5A 4186'.4248' A5 4266'-4298' A5 12 9/3/96 12 9/3/96 12 9/3/96 12 8/31/96 12 8/31/96 12 8/3196 12 8/28/96 12 8/28/96 12 8/28/96 59.4 PPF 20/40 CARBOLITE 59.4 PPF 20/40 CARBOLITE 59.4 PPF 20/40 CARBOLITE 19 PPF 20/40 CARBOLITE 19 PPF 20/40 CARBOLITE 19 PPF 20/40 CARBOLITE 4.8 PPF 20/40 CARBOLITE 4.8 PPF 20/40 CARBOLITE 4.8 PPF 20/40 CARBOLITE O:XDRILLING\SCHEMATIC\TBU~STEELHEADXM-9DIAG.DOC REVISED: 9/10/96 DRAWN BY: PAR Steelhead Platform Well: M-9 Summary of Well Operations 8/15/96 8/16/96 8/17/96 8/18/96 8/19/96 8/20/96 8/21/96 8/22/96 8/23/96 8/24/96 8/25/96 8/26/96 SKID RIG OVER LEG B2 SLOT #1. NU & FUNCTION TEST DIVERTER SYSTEM. RIH W/17-1/2" DRILLING ASSBY & CLEANOUT CONDUCTOR F/430' - 488'. DIRECTIONALLY DRILL 17-1/2" HOLE F/488' - 510'. DIRECTIONALLY DRILL 17-1/2" HOLE F/510' - 850'. POOH. RUN & CEMENT 13-3/8" CASING ~ 838' WITH 3133 CF CLASS "G" ~ 12.8 PPG F/B 449 CF CLASS "G" ~ 15.8 PPG. GOOD RETURNS THROUGHOUT JOB. CIRCULATED 197 BBLS CEMENT TO SURFACE. WOC. ND DIVERTER, NU & TEST 16-3/4" BOP. TAG CEMENT IN 30" ANNULUS 8' BELOW STARTING HEAD W/1-1/2" PVC. FINISHNU & TESTING 16-3/4" BOP. RIH W/12-1/4" DRILLING ASSBY. TEST CASING TO 2500 PSI. CLEANOUT CEMENT F/740' - 850'. DRILL 10' OF NEW HOLE TO 860'. CONDUCT LEAK OFF TEST TO 14.4 PPG. DIRECTIONALLY DRILL 12-1/4" HOLE F/860' - 1171'. DIRECTIONALLY DRILL 12-1/4" HOLE F/1171' - 1490'. POOH. CHANGE RAMS TO 9-5/8" & TEST BOP. RUN & CEMENT 9-5/8" CASING ~ 1488' WITH 1038 CF CLASS "G" ~ 12.8 PPG F/B 544 CF CLASS "G" ~ 15.8 PPG. LOST COMPLETE RETURNS AFTER 50% OF TAIL PUMPED. RETURNED SPACER TO SURFACE. RAISE BOP, SET SLIPS & CUT OFF CASING. SET OUT BOP. RAN TEMP SURVEY & FOUND TOP OF CEMENT ~ 700'-800'. FILLED 13-3/8" X 9-5/8" ANNULUS W/4.8 BBLS. NU TUBING SPOOL. NU & TEST BOP. RIH W/8-1/2" DRILLING ASSBY & TAG CEMENT ~ 1380'. CLEANOUT CEMENT F/1380' - 1478' & TEST CASING TO 2500 PSI. DRILL 8- 1/2" HOLE F/1490' - 1500'. CONDUCT LEAK OFF TEST TO 16.0 PPG. DIRECTIONALLY DRILL 8-1/2" HOLE F/1500' - 3465' DIRECTIONALLY DRILL 8-1/2" HOLE F/3465' - 4500'. POOH. RUN DIL/CNL/LDT/GR F/4500'- 1490' ON WIRELINE. CHANGE RAMS TO 7" & TEST BOP. RUN & CEMENT 7" LINER F/4494' - 1003' WITH 929 CF CLASS "G" ~ 14.5 PPG. CIRCULATED 10 BBLS CEMENT TO SURFACE. SET HANGER & PUH TO 752'. CIRCULATE OUT 30 BBLS CEMENT. POOH. CHANGE RAMS F/7" TO 3-1/2" & TEST BOP. RIH 8-1/2" ASSBY & CLEANOUT CEMENT TO TOP OF LINER ~ 1003'. POOH. RIH W/6" ASSBY & CLEAN OUT CEMENT TO 4398'. POOH. RUN CET/CBT/GR/CCL. TEST CASING TO 3000 PSI. RUN& SETB~~T~I-E!VID BACK PACKER ~ 1003'. RIH W/6" CLEANOUT ASSBY TO 4398' & ~I~Ip, NGF~ WELL OVER TO COMPLETION FLUID. 1996 Alaska Oil & Gas Cons. commission Anchorage 8/27/96 FILTER COMPLETION FLUID. POOH. RUN & SET BAKER SUMP PACKER 4308' ON WIRELINE. RU GRAVEL PACK PUMPING EQUIPMENT. 8/28/96 RIH W/TCP GUN ASSMBY AND PERFORATE A5 ~ 4266'-4298', 4186'-4248', 4151'-4165' W/12 JSPF ~ 600 psi UNDERBALANCE. SIDP 300 PSI IN 9 MINUTES. REVERSE ENTRY & POOH. 8/29/96 RIH W/CLEANOUT ASSBY & CLEANOUT THROUGH SUMP PACKER ~ 4300' TO 4302'. POOH. RIH WITH GRAVEL PACK ASSEMBLY..012" SCREEN F/ 4300'-4119', SC1R PACKER SET ~ 3986'. 8/3O/96 GRAVEL PACK A5 PERFS W/2710 LB 20/40 CARBOLITE. POOH. RIH & BREAK KOIV. RUN TDT & VERIFIED GOOD PACK. POOH. 8/31/96 RIH & SET PACKER PLUG ~ 3986'. SPOT SAND. POOH. RIH W/TCP GUN ASSMBY AND PERFORATE A3 & A2A ~ 3970'-3977', 3942'-3948', 3868'-3902 W/ 12 JSPF ~ 1000 PSI UNDERBALANCE. SIDP 1150 PSI AFTER FLOWING FOR 10 MIN TO CLEAN UP. REVERSE ENTRY & POOH. 9/1/96 RIH W/CLEANOUT ASSBY & CLEANOUT & RETRIEVE PACKER PLUG 3986'. POOH. RIH W/GRAVEL PACK ASSBY USING .012" SCREEN & SC-1L PACKER ~ 3827'. GRAVEL PACK A3 & A2A PERFS W/2100 LB 20/40 CARBOLITE. 9/2/96 POOH. RIH & SET PACKER PLUG ~ 3827'. SPOT SAND. POOH. RIH W/TCP GUN ASSBY. 9/3/96 PERFORATE A2 ~ 3677'-3681', 3689'-3704', 3710'-3816' W/12 JSPF ~ 950 PSI UNDERBALANCE. SIDP 1140 PSI AFTER FLOWING FOR 10 MIN TO CLEAN UP. REVERSE ENTRY & POOH. RIH W/CLEANOUT ASSBY & CLEANOUT & RETRIEVE PACKER PLUG ~ 3827'. POOH. RIH W/GRAVEL PACK ASSBY USING .012" SCREEN & SC-1R PACKER ~ 3523. GRAVEL PACK A2 PERFS W/ 9290 LBS 20/40 CARBOLITE. 9/4/96 POOH. CHANGE RAMS TO 7" & TEST BOP. RIH W/SEALS ON 7" TUBING & WLR SCSSSV. FUNCTION TEST SCSSSV. STAB INTO TIE BACK EXTENSION ~ 1003' AND TEST SEALS TO 2500 PSI. PUH & SPACE OUT. 9/5/96 INSTALL HANGER. CIRCULATE PACKER FLUID. LAND HANGER & TEST SEALS TO 2500 PSI. INSTALL BPV. ND BOP. NU & TEST TREE. 9/6/96 RIH W/MOTOR ON COILED TUBING & BREAK KNOCK OUT ISOLATION VALVES ~ 3551'RTM & 3855'RTM. RIH W/NOZZLE ON COILED TUBING TO 3500' CTM & UNLOAD WELL WITH NITROGEN. 9/7/96 CONTINUE TO LIFT WELL WITH NITROGEN ~ 3500'CTM. TURN WELL OVER TO PRODUCTION ~ 0200. SKIDDING RIG TO M-5 ~ 1130. END OF OPERATIONS. Created by jones Dote plotted : 26-Aug-@6 Plot Reference is M-9 Version ~I0, Coordinates are in feet reference slot ~/B2-1. True Vertical Depths ore reference RNB. 200 400 600 80O 1000 .+- ~ 1200 400 --~ 1600 o-- ~ 1800 2000 '1-- I V 2200 240o 26oo 2800 5000 3200 5400 --- Baker Hughes INTEO --- L 30 Casing 13 3/8 Casing 9 5/8 Cosing UNOCAL Structure : ST£ELHEAD Platform Well: M-g Field : McAdhur River Field Location : TBU, Cook Inlet, Alaska UNOCALe) East (feet) -> 200 0 200 40(3 600 800 1000 1200 1400 1600 1800 A2 Rvsd 17-Jun-96 o 2400 2200 2000 1800 1600 1400 1200 1000 8O0 600 400 2O0 0 200 __ A2 Rvsd 17-Jun-96 i i i i i i i i i t i i i i i i i i i i i i i i i i i i , i i i i 200 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 Vertical Section (feet) -> Azimuth .55.10 with reference 0.00 N, 0.00 E from slot //B2-1 Z ~' SURVEY CALCULATION AND FIELD Wb,{KSHEET Job No. 0450-79207 Sidetrack No. Page 1 of 3 Company UNOCAL Rig Contractor & No. Pool Alaska Field MCARTHUR RIVER FIELD A~tic Well Name & No. STEELHEAD PLATFORM/M-9/TRADING BAY UNIT Survey Section Name Definitive Survey BHI Rep. MIKE ROSS ~~ WELL DATA Target TVD (FT) Target Coord, N/S Slot Coord, N/S -1035,82 Grid Correction .0,000 Depths Measured From: RKB ~ MSL r--] ssr-] Target Description Target Coord, E/W Slot Coord, E/W 607,94 Magn, Declination 22,000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m~ lOmr-] Vert. Sec, Azim, 35,10 Magn, to Map Corr, 22.000 Map North to: OTHER SURVEY DATA Survey Survey Incl, Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (ET) (DD) (DD) (FT) (F'r) (FT) (F'I') (Per 100 FT) Drop (-) Left (-) 0.00 0,00 0,00 0,00 0,00 0,00 0,00 TIE IN POINT 17-AUG-96 RGSS 50,00 0,18 30.80 50,00 50,00 0.08 0,07 0,04 0,36 0,36 17-AUG-96 RGSS 100,00 0,27 211,31 50,00 100,00 0,04 0,03 0.02 0.90 0,18 17-AUG-96 RGSS 150,00 0,34 181,53 50,00 150.00 -0,20 -0,21 -0,05 0,34 0,14 17-AUG-96 RGSS 200,00 0,12 54,99 50,00 200,00 -0,28 -0.33 -0,01 0,84 -0,44 17-AUG-96 RGSS 250.00 0,08 .301.25 50,00 250.00 -0.23 -0.28 0.01 0,34 -0,08 17-AUG-96 RGSS 300,00 0,30 157,72 50,00 . 300,00 -0.30 -0,39 0,03 0,73 0,44 17-AUG-96 RGSS 350,00 0,33 183,97 50,00 350,00 -0,50 -0,65 0,07 0,29 0,06 17-AUG-96 RGSS 400,00 0.34 160.18 50,00 400.00 -0,70 -0,94 0,11 0,28 0,02 17-AUG-96 RGSS 434,00 0,41 56,77 34.00 434.00 -0.65 -0.96 0.24 1,74 0,20 17-AUG-96 RGSS 495,00 0,15 143,50 61,00 495,00 -0,47 -0,91 0.47 0.70 -0,43 17-AUG-96 RGSS 525,00 0,59 73,11 30,00 525,00 -0,36 -0.90 0,64 1.86 1,47 17-AUG-96 RGSS 555,00 1,30 59,40 30,00 554,99 0,07 -0,68 1,08 2,47 2,37 ,_ 17-AUG-96 RGSS 585.00 1,90 57,20 30.00 584,98 0.84 -0.23 1,79 2,01 2.00 17-AUG-96 RGSS 615.00 2,70 56,70 30.00 614,95 1,96 0,42 2,80 2.67 2.67 17-AUG-96 RGSS 645,00 3.50 57,50 30,00 644,91 3,46 ' 1,30 4,17 2.67 2,67 17-AUG-96 RGSS 675,00 4,20 57,60 30,00 674,84 5,32 2,38 5.87 2,33 2,33 , i 7-AUG-96 RGSS 705.00 5,00 57.70 30,00 704,75 7,54 3,67 7,90 2,67 2,67 0.33 17-AUG-96 RGSS 735.00 5,80 59,90 30,00 734,61 10,13 5,13 10.32 2,75 2.67 7,33 17-AUG-96 RGSS 802,00 7,20 58,50 67,00 801,18 17,06 9,02 16,82 2,10 2,09 -2,09 19-AUG-96 RGSS 827.00 6,90 63,80 25.00' 825,99 19,81 10.50 19,51 2:86 -1.20 21.20 19-AUG-96 RGSS 887.00 7,00 63.50 60,00 885.55 26,19 13.73 26,01 0,18 0.17 -0,50 19-AUG-96 RGSS 946,00 7,60 57,00 59,00 944,07 32,97 17,45 32,50 1.73 1,02 -11,02 19-AUG-96 RGSS 1003.00 9.70 53.90 57,00 1000,42 41.01 22.34 39,55 3,77 3.68 -5,44 I ~' SURVEY CALCULATION AND FIELD W~,,~KSHEET Job No. 0450-79207 Sidetrack No. Page 2 of 3 ·: [! [4 -"1 Company UNOCAL Rig Contractor & No. Pool Artic Alaska Field MCARTHUR RIVER FIELD Well Name & No. STEELHEAD PLATFORM/M-9/TRADING BAY UNIT Survey Section Name Definitive Survey BHI Rep. MIKE ROSS J~llli~r~=~ WELL DATA Target TVD (F'r) Target Coord. N/S Slot Coord. N/S -1035.82 Grid Correction 0.000 Depths Measured From: RKB ~ MSL ~ SS~ Target Description Target Coord. E/W Slot Coord. E/W 607.94 Magn. Declination 22.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30mE] 10m0 reft. Sec. Azim. 35.10 Magn. to Map Corr. 22.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole' Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) 'DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (FT) (FI') (Per ~O0.FT) Drop (-) Left (-) 19-AUG-96 RGSS 1083.00 12.90 47.00 80.00 1078.86 56,14 32.40 51.53 4.34 4,00 -8,62 20-AUG-96 RGSS 1126.00 16.00 42.80 43.00 1120.50 66.71 40.03 59.06 7.60 7.21 -9.77 20-AUG-96 RGSS 1184.00 18.60 36.00 58.00 1175.88 83.88 53.38 69.94 5.67 ' 4.48 -11.72 20-AUG-96 RGSS 1215.00 20.40 34.30 31.00 1205.10 94,23 61.84 75.89 6.09 5.81 -5.48 .. 20-AUG-96 RGSS 1272.00 23.00 31.60 57.00 1258.06 115.28 79.54 87.32 4.88 4.56 -4.74 20-AUG-96 RGSS 1345.00 25.80 32.90 73.00 1324.53 145.40 105.03 103.43 3.90 3.84 1.78 20-AUG-96 RGSS 1402.00 27.78 35.44 57.00 1375.41 171.08 126.27 117.87 4.01 3.47 4.46 -I 22-AUG-96 MWD 1535.00 32.70 39.70 133.00 1490.29 237.93 179.20 158.82 4.03 3.70 3,20 22-AUG-98 MWD 1585.00 36.60 40.30 50.00 1531.41 266.25 200.97 177.09 7.83 7.80 1.20 22-~UG-96 MWD 1630.00 40.10 40.90 45.00 1566.70 294.04 222.16 195.27 7.82 7.78 1.33 22-AUG-96 MWD 1678.00 43.00 39.40 48.00 1602.62 325.75 246.50 215.78 6.39 6.04 -3.12 22-AU G-96 MWD 1713.00 44.00 39.20 35.00 1628.01 349.77 265.14 231.04 2.88 2.86 -0.57 22-AUG-96 MWD 1770.00 45.70 38.00 57.00 1668.42 389.90 296.56 256,11 3.33 2.98 -2.10 22-AUG-96 MWD 1862.00 48.50 37.90 92.00 1731.04 457.20 349.70 297.55 3.04 3.04 -0.11 22-AUG-96 MWD 1953.00 52.50 38.40 91.00 1788.91 527.30 404.90 340.93 4.42 4.40 0.55 22-AUG-96 MWD 2049.00 55.30 37.00 96.00 1845.47 604.78 466.27 388.34 3.14 2.92 -1.46 22-AUG-96 MWD 2142.00 59.10 34.70 93.00 1895.84 682.92 529.64 434.08 4.58 4.09 -2.47 22-AUG-96 MWD 2234.00 59.90 34,50 92.00 1942.53 762.19 594.89 479,10 0.89 0,87 -0.22 22-AUG-96 MWD 2328.00 60.70 34.80 94.00 1989.11 843.84 662.06 525.52 0.90 0.85 0.32 22-AUG-96 MWD 2421.00 59.50 34.10 93.00 2035.47 924.45 728.54 571.1 3 1.44 -1.29 -0.75 : 22-AUG-96 MWD 2515.00 60.30 33.90 94.00 2082.61 1005.76 795.96 616.60 0.87 0.85 -0.21 22-AUG-96 MWD 2607.00 60.80 33.90 92.00 2127.84 1085.86 862.45 661.28 0.54 0.54 0.00 22-AUG-96 MWD 2701.00 61.10 33.60 94.00 2173.48 1168.01 930.78 706.94' 0.42 0.32 -0.32 22-AUG-96 MWD 2795.00 59.70 34.10 94.00 2219.91 1249.72 998.65 752.46 1.56 -1.49 0.53 ~' SURVEY CALCULATION AND FIELD WC,(KSHEET Job No. 0450-79207 Sidetrack No. Pag~ 3 of 3 Company UNOCAL Rig Contractor & No. Pool Artic Alaska Field MCARTHUR RIVER FIELD Well Name & No. STEELHEAD PLATFORM/M-9/TRADING BAY UNIT Survey Section Name Definitive Survey BHI Rep. MIKE ROSS WELL DATA Target TVD (FT) Target Coord, N/S Slot Coord, N/S -1035,82 Grid Correction 0,000 Depths Measured From: RKB ~ MSL r-] ssE~ Target Description Target Coord, E/W Slot Coord, E/W 607,94 Magn, Declination 22,000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOffr~ 30m~ lom~ Vert, Sec, Azim, 35,10 Magn, to Map Corr, 22,000 Map North to: OTHER i SURVEY DATA Survey Survey Incl, Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (F'r) (FT) (Per 100 FT Drop (-) Left (-) 22-AUG-96 MWD 2887,00 60,40 33,70 92,00 2265,84 1329,41 1064,82 796,92 0,85 0,76 -0,43 22-AUG-96 MWD 2980,00 59,30 34,70 93,00 2312,56 1409,82 1131,33 842,12 1,50 -1,18 1,08 22-AUG-96 MWD 3073,00 59,80 34,60 93.00 2359,69 1489,99 1197,28 887,70 ,0,54 0,54 -0,11 22-AUG-96 MWD 3167,00 60,00 34,70 94,00 2406,83 1571,31 1264,18 933.94 0,23 0.21 0,11 22-AUG-96 MWD 3257,00 60,90 34,40 90,00 2451021 1649,60 1328,67 978,34 1.04 1,00 -0.33 22-AU G-96 MWD '3352,00 59,20 35,10 95,00 2498,64 1731,91 1396.30 1025,25 1,90 -1,79 0,74 23-AU G-96 MWD 3446,00 59,60 35,40 94,00 2546,49 1812,82 1462,37 1071,95 0,51 0,42 0,32 23-AUG-96 MWD 3540,00 60,20 35,10 94,00 2593,63 1894,14 1528.79 1118.88 0,70 0.64 -0,32 23-AUG-96 MWD 3634.00 60.50 34.80 94.00 2640.14 1975.83 1595.75 1165.68 0.42 0.32 -0.32 .~.. 23-AUG-96 MWD 3730,00 60,10 34,40 96,00 2687,70 2059,22 1664,39 1213,03 0,55 -0,42 -0,42 23-AUG-96 MWD 3822,00 60,90 34,80 92,00 2733,00 2139,28 1730,30 1258,50 0,95 0.87 0,43 _c:). ¢.. ,..... 23-AUG-96 MWD 3915,00 59,20 34,50 93,00 2779,43 2219.86 1796,54 1304.37 1,84 -1,83 -0,22 23-AU G-96 MWD 4009,00 59,20 34,60 94,00 2827,56 2300.60 1863,00 1350,22 0,00 0,00 0,00 23-AUG-96 MWD 4102,00 59,00 34,10 93,00 2875,32 2380,39 1928,89 1395,25 0,51 -0,22 -0,54 23-AU G-96 MWD 4193.00 59,20 34,90 91.00 2922,05 2458,47 1993,24 1439,48 0.78 0,22 0,88 23-AUG-96 MWD 4287.00 60,00 34.70 94,00 2969.62 2539.55 2059.81 1485,75 0.87 0.85 -0,21 23-AUG-96 MWD 4381.00 50,20 34.30 94,00 3016,48 2621.03 2126,97 1531.90 0,42 0.21 -0.42 23-AUG-96 MWD 4460.00 60,10 34.10 79,00 3055,80 2689,54 2183.64 1570,42 0.25 -0,13 -0.25 23-AUG-96 MWD 4500,00 60,10 34.10 40,00 3075,74 2724.21 2212.35 1 589,86 0.00 0.00 0,00 Projected Data - NO SURVEY TONY KNOWLE$, GOVERNOR ALASI~& OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 30, 1996 Dale Haines, Drilling Mgr. UNOCAL P O Box 19-0247 Anchorage, AK 99519-0247 Re: Trading Bay Unit M-9 UNOCAL Permit No: 96-127 Sur. Loc. 1035'FNL, 608'FWL, Sec. 33, T9N, R13W, SM Btmhole Loc. 1211'FSL, 2161'FWL, Sec. 28, T9N, R13W, SM ~ 3076'TVD Dear Mr. Haines: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill 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) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission at 279-1433. 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. TONY KNOWLES, GOVERNOR ALASI~& OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 ADMINISTRATIVE APPROVAL NO. 228.03 The application of Union Oil Company of California, operator of the Trading Bay Unit (TBU), to drill and complete the Trading Bay Unit M-9 Middle Kenai Gas Pool production well. Mr. Kevin Tabler, Land Manager Alaska Business Unit UNOCAL Corp. P. O. Box 196247 Anchorage, AK 99519-6247 Dear Mr. Tabler: Your application of July 15 1996 for a permit to drill and complete the Trading Bay Unit M-9 well requires exception to spacing requirements set forth in Conservation Order No. 228. The drilling and completion of the Trading Bay Unit M-9 well is expected to provide additional oil recovery from the Middle Kenai Gas Pool in the Trading Bay Unit. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling and completion of the Trading Bay Unit M-9 well pursuant to Rule 3 of Conservation Order No. 228. DONE at Anchorage, Alaska and dated July 22, 1996. David W., Johnston Commissioner BY ORDER OF THE COMMISSION Unocal Corporation Oil & Gas Operations 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 UNOCAL July 15, 1996 Kevin A. Tabler Land Manager Alaska Business Unit Mr. Bob Crandall Alaska Oil and Gas Conservation Commission 3 001 Porcupine Drive Anchorage, AK 99501-3192 STEELHEAD PLATFORM PERMIT TO DRHJL AND SPACING EXCEPTION Dear Mr. Crandall: Union Oil Company of California (Unocal), as Operator of the Trading Bay Unit (TBU), requests your approval to drill TBU M-9, ADL 1873 0, from the Steelhead Platform and further requests Administrative Approval for a well spacing exception to Rule 1, pursuant to Rule 3, Conservation Order No. 228. Additionally, in triplicate, is our application for Permit to Drill M-9 (form 10-401) pursuant to 20 AAC 25.005 and our check No. 2000036 in the amount of $100.00 as required under 20 AAC 25.005 (c) (1). TBU M-9: The specific location, interval and depth are as follows: Surface Location: 1035' FNL, 608' FWL, Sec.33, T9N, R13W, SM Top Productive Interval: 538' FSL, 1714' FWL, Sec 28, T9N, 13W, SM ~ 2615' TVD Total Depth: 1211' FSL, 2161' FWL, Sec 28, T9N, R13W, SM ~ 3076' TVD If you require additional information, please contact the undersigned at (907) 263-7600 or Pat Ryan, Drilling Department at (907) 263-7864. Enclosures truly yours, T able~r~~'~ jUL I 9 i9,'¢~ Alaska. 0il & Gas Cons. Unocal Corporation 909 W. 9th Avenue Anchorage, AK 99501 907-263-7660 UNOCAL( Dale Haines Drilling Manager Monday, July 15, 1996 Mr. David Johnston Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Ak 99501-3192 Dear Mr. Johnston' Enclosed, please find the application for the Permit to Drill (Form 10-401) for the Steelhead Platform Well M-9. The intent of this well is to provide a high structural location in the A sand series to maximize gas recovery. UNOCAL plans to spud this well approximately August 8, 1996. The casing program planned for this well is reduced in size as compared to previously drilled gas wells from Steelhead, however the setting depths are per the regulations in particular Conservation Order 228 as ammended. Unocal will employ the existing diverter and BOP system presently on board Steelhead. For well control purposes, a fracture gradient of .8 psi/ft has been used at both the 13- 3/8" and 9-5/8" shoe depths. UNOCAL'S recent drilling experience in the Cook Inlet has demonstrated true shallow fracture gradients ranging from 0.75 - 0.94 psi/ft (see Leak Off Test Data). For the kick conditions analyzed, the maximum bottom hole pressure remains well below the anticipated fracture pressure. UNOCAL plans to complete M-9 as a flowing gas well. Due to the shallow depth of the targetted reservoirs, sand control using screens and gravel packs will be employed to complete the well. The 7" liner will be tied back to surface giving a monobore completion. The tie back will include a 7" WL retrievable SSSV. Please contact the undersigned with any questions regarding this application. Sincerely, Dale Haines Drilling Manager enclosure STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill: X Reddll: I 1 b. Type of well Exploratory: Stratigraphic Test: Development Oil: Re-Entry: Deepen: I Service: Developement Gas: X Single Zone: Multiple Zone: 2. Name of Operator UNOCAL 3. Address P.O. Box 190247 Anchorage, AK 995190247 4. Location of well at surface Leg B-2 Slot #1 1035' FNL, 608' FWL, Sec. 33, T9N, R13W, SM At top of productive interval 538' FSL. 1714' FWL, Sec. 28, T9N, R13W, SM @ 2615' TVD At total depth 1211' FSL, 2161' FWL, Sec 28, T9N, R13W, SM @ 3076' TVD 12. Distance to nearest property line 1714 feet 13. Distance to nearest well see proximity analysis feet 16. To be completed for deviated wells Kickoff depth: 500 feet Ma)dmum hole angle: 60 18. Casing program size 5. Datum Elevation (DF or KB) 160' rkb feet 6. Property Designation ADL 18730 7. Unit or property Name Trading Bay Unit 8. Well number M-9 9. Approximate spud date August 7, 1996 14. Number of acres in property 384O 10. Field and Pool McArthur River Field Grayling Gas Sands Pool 11. Type Bond (see 20 AAC 25.025) Number U62-9269 Amount $200000 15. Proposed depth (MD and TVD) 4500' MD/3075' TVD feet 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Mac, mum surface 213 psig At total depth ('r'VD) 134~ psig Quantity of cement Setting Depth Bottom TVD MD TVD 82 850 849 81' 1500' 1456' 997' 4500' 3075' Specifications Top Hole Casing Weight Grade Coupling Length MD (include stage data) 17-1/2" 13-3/8" 68~ K-55 Butt 768' 82 Lead 975 sx + 375 sx Tail 12-1/4" 9-5/8" 47# L-80 Butt 1423' 81' Lead 175 sx + 400 sx Tail 8-1/Z' 7" liner 29~ L-80 NSCC 3500 1000' 880 sx Tail 19. To be completed for Redfill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet true vertical feet Effective depth: measured feet true vertical feet Casing Structural Conductor Surface Intermediate Production Line~ Perforation depth: measured Plugs (measured) Junk (measured) Length Size Cemented Measured depth True vertical depth 406' 28" Driven 488' 488'_. RECEIV ED jUl_.. Alaska Oil & G~s Cor~s. Commission true vertical 20. Attachments: Filing fee: X Property Plat: X BOP Sketch: X Diverter Sketch: X Drilling program: X Ddlling fluid program: X Time vs. depth plot: X Refraction analysis: Seabed report: 20 AAC 25.050 requirements: X 21. I herby certify that the foregoing is true and correct to the best of my knowledge: Signed: D ~ ~'~ ~ 'ritle: Ddlling Manager Date: /~ /~, ,/'I' Commission Use Only F . ' Permit Number I APl number Approval date I See cover letter ¢~'-/'~-- 7 50- 7,~3"' -~- 0 ~7Z 7~ 1- -~ 0 _c>] ~ for other requirements Conditions of approval Samples required: [ ] Yes ~ No Mud log required: [ ] Yes ~4, No Hydrogen sulfide measures [ ] Yes "~ No Directional survey required ~ Yes [ ] No Required working pressure for BOPE []2M; ~/I~3M; []5M; []1OM; []15M Other:. Original Signed By by order of Approved by David W. Johnston Commissioner the Commission Date: Form 10-401 Rev. 12-1-85 Submit in triplicate UNOCAL STEELHEAD M-~ PROPOSED LOCATION · · · INTEREST AD L T - UNOCAL-50% MARATHON-50~ f Proposed Loca-:~on I1 " ~-9 Well x~-Sreelhead I Platform I kL 3~ 33 3840 3~C ~ UNOCAL- 100% i 35 5 P~6 AC ~ HBP HBP 94 7~DL- 18730 ~ ADL- 1759{5 I ,~ ..... --"-- MARATIION-50% UNOCM~- 100% SHELL-66,~7Z UNOCAL-50% I SBI-33,3~ ~ 6 5 4 I I STEELHEAD M-9 16-Jul-96 DRILLING HAZARDS: Lost Circulation Zones: 480' - 1500' Low Pressure Zones: None Over Pressured Zones: None Shallow Gas Zones: 950' - 4500' PRELIMINARY PROCEDURE 1 SKID RIG FROM NW LEG TO NE LEG 2 CONNECT SERVICE LINES, INSTALL CATWALK AND V-DOOR 3 NLT 30" RISER 4 NU DIVERTER AND OVERBOARD LINES 5 FUNCTION TEST DIVERTER FROM ALL STATIONS 6 FINISH PREPARING FLOOR, SPOT APRS AND SCIENTIFIC DRILLING 7 PU DIRECTIONAL BHA AND RIH TO TAG PILE SHOE 8 FILL PILE AND RISER, FUNCTION PUMPS AND TEST ENTIRE FLUID SYSTEM 9 GYRO SURVEY DRIVE PILE AT 100' INTERVALS 10 SPUD WELL AND DRILL 17-1/2" HOLE TO 850' 11 CBU AND SPOT LCM PILL IF NECESSARY 12 SHORT TRIP TO REMOVE SIDE ENTRY SUB 13 CBU, POOH 14 RU CASING TOOLS AND RUN 13-3/8" CASING 15 RU CEMENTERS AND PRESSURE TEST LINES 16 CIRCULATE WELL AND RECIPROCATE CASING 17 CEMENT 13-3/8" CASING 18 RD CEMENTING EQUIPMENT AND WASH OUT RISER 19 WOC 20 BACKOUT AND LD LANDING JOINTS 21 ND 30" DIVERTER AND RISER 22 CUT 13-3/8" CASING AND WELD ON STARTING HEAD 23 NLT 13-3/8" 5M X 16~3/4" 5M ADAPTER AND 16-3/4" RISER AND BOP 24 TEST BOP TO UNOCAL AND AOGCC SPECIFICATIONS 25 PULL TEST PLUG AND SET WEAR BUSHING 26 MU 12-1/4" DIRECTIONAL BHA AND RIH 27 CLEAN CEMENT OUT TO SHOE 28 PRESSURE TEST 13-3/8" CASING TO 2000 PSI 29 DRILL OUT OF CASING AND 10' OF NEW HOLE 30 CIRCULATE WELL 31 PERFORM LEAK OFF TEST 32 DRILL 12-1/4" HOLE WITH GYRO SINGLE SHOTS FROM 850 - 1500' 33 CBU AND SPOT LCM PILL IF NECESSARY 34 SHORT TRIP TO 13-3/8" SHOE 35 CBU, POOH 36 CHANGE RAMS TO 9-5/8" AND TEST DOOR SEALS TO 2000 PSI 37 RU CASING TOOLS ANTD RUN 9-5/8" CASING 38 RU CEMENTERS AND PRESSURE TEST LINES 39 CIRCULATE WELL AND RECIPROCATE CASING 40 CEMENT 13-3/8" CASING 41 RD CEMENTING EQUIPMENT AND WASH OUT RISER 42 WOC 43 BREAK 13-5/8" ADAPTER FLANGE, LIFT RISER AND INSTALL SLIPS 44 CUT 9-5/8" CASING AND REMOVE LANDING JOINTS 45 INSTALL 13-5/8" 5M X 13-5/8" 5M TUBING SPOOL 46 LOWER AND MU ADAPTER FLANGE 47 TEST BOP TO UNOCAL AND AOGCC SPECIFICATIONS JUL Alaska 0~1 & Gas Cons. C~~mrnissi°n MgEST2.XLS 7/16/96 48 PULL TEST PLUG AND SET WEAR BUSHING 49 MU 8-1/2" DIRECTIONAL BI-IA _.MNrD RIH 50 CLEAN CEMENT OUT AND DRILL FLOAT COLLAR 51 PRESSURE TEST 9-5/8" CASING TO 3500 PSI 52 DRILL OUT OF CASING ANrD 10' OF NEW HOLE 53 CIRCULATE WELL 54 PERFORiM LEAK OFF TEST 55 DISPLACE HOLE TO POLYMER MUD 56 DRILL 8-1/2" HOLE WITH MWD FROM 1510 - 3500' 57 CBU 58 TRIP FOR BIT AND PU SPERRY NUCLEAR LWD 59 TIH ,,MX,rD MAD PASS OPEN HOLE AT 200'/HOUR 60 DRILL 8-1/2" HOLE WITH MWD FROM 3500 - 4500' 61 CBU 62 TOH, LD LWD AND BHA 63 CHANGE RAMS TO 7" AND TEST DOOR SEALS TO 2000 PSI 64 RU CASING TOOLS AND RUN 7" LINER 65 ~MU BAKER LINER HANGER AND RIH ON DRILL PIPE 66 CIRCULATE ~VELL AND RECIPROCATE LINER 67 RU CEMENrrERS AND PRESSURE TEST LINES 68 CEMENT 7" LINER 69 SET 7" LINER HANGER 70 SET 7" LINER TOP PACKER 71 RD CEMENTING EQUIPMENT 72 POOH LD DP AND SETTING TOOL 73 LD 5" DP WHILE WOC 74 CHANGE RAMS TO 3-1/2" AND PRESSURE TEST BOP 75 ~MU 8-1/2" CLEAN OUT ASSEMBLY AND PU 4-3/4" DC AND 3-1/2" DP 76 CLEAN OUT TO TOP OF LI/qER AT ABOUT 1000' 77 CBU AND PRESSURE TEST LINER TOP TO 2500 PSI 78 TOH, LD 8-1/2" EQUIPMENT, PU 6" CLEAN OUT ASSEMBLY 79 TIH, PU REiMAINDER OF 3-1/2" DP 80 CLEAN OUT 7" LINER TO LANDING COLLAR AT ABOUT 4380' 81 CBU AND PRESSURE TEST TO 2500 PSI 82 POOH 83 ND BELL NIPPLE AND ~ SHOOTING FLANGE 84 RU SCHLUMBERGER AND RUN CET/CBT/GR/CCL FROM TD TO SURFACE 85 RIH W/SHEAR SUB ON 3-1/2" DP 86 CIRCULATE ANrD DISPLACE MUD WITH FI~V. CLEAN PITS. BUILD BRINE 87 CIRCULATE WELL WITH FIW, PUMP DIRT MAGNET SWEEP 88 DROP BALL AND PUMP TO SEAT 89 PRESSURE TEST DP TO 2500 PSI. SHEAR BALL. 90 DISPLACE COMPLETION FLUID INTO WELL 91 WHEN WELL IS DISPLACED, REVERSE CIRCULATE AND FILETER BRINE 92 POOH 93 ~MU SUMP PACKER AND RIH ON 3-1/2" DP 94 RU SOS Al,rD RUN GR CORROLATION LOG 95 POSITION PACKER AT ABOUT 4260', DROP BALL AND SET PACKER 96 CIRCULATE AND FILTER BRINE 97 POOH 98 PU ABOUT 150', 12 SPF TCP GUNS AND RIH ON 3-1/2" DP 99 TAG SUMP PACKER, SPACE OUT, AND SET SHOOTING PACKER 100 PRESSURE UP AND FIRE TCP GUNS AND MONITOR PRESSURE INCREASE 101 REVERSE OUT AND CIRCULATE AND FILTER BRINE 102 POOH, LD SPENT GUNS 103 RIH ~V/CASING SCRAPER ON 3-1/2" DP 104 CIRCULATE ANrD FILTER BRINE 105 POOH 106 MU GP ASSEMBLY 107 RIH W/ASSEMBLY, STING IN, DROP BALL AND SET PACKER AT 3907' 108 RELEASE FROM PACKER 109 LOCATE TOOL POSITIONS AND ESTABLISH RATES AND PRESSURES 110 CIRCULATE 20/40 MESH SAND INTO PLACE 111 REVERSE OUT AND TEST PACK. CLOSE SLIDING SLEEVE AND TEST. 112 POOH TO CLOSE KOIV 113 REVERSE CIRCULATE AND FILTER BRINE M9EST2.XLS 7/16/96 M9EST2.XLS 114 115 116 117 118 119 120 121 122 123 124 125 126 127 128 129 130 131 132 133 134 135 136 137 138 139 140 141 142 143 144 145 146 147 148 149 150 151 152 153 154 155 156 157 158 159 160 161 162 163 164 165 166 167 168 169 170 171 POOH RIH WITH PACKER PLUG AND SET IN GP/SUMP PACKER AT 3907' PLACE 2 SX SAND ON PLUG CIRCULATE AND FILTER BRINE POOH PU ABOUT 42' GUNS, 119' BLANK, AND 162' GUNS AND RIH ON 3-1/2" DP TAG SUMP PACKER, SPACE OUT, AND SET SHOOTING PACKER PRESSURE UP AND FIRE TCP GUNS AND MONITOR PRESSURE INCREASE REVERSE OUT AND CIRCULATE AND FILTER BRINE POOH, LD SPENT GUNS RIH W/3-1/2" DP W/PLUG RETRIEVING TOOL REVERSE CIRCULATE DEBRIS/SAND AND RETRIEVE PLUG CIRCULATE AND FILTER BRINE POOH MU GP ASSEMBLY RIH W/ASSEMBLY, STING IN, DROP BALL AND SET PACKER AT 3423' RELEASE FROM PACKER LOCATE TOOL POSITIONS AND ESTABLISH RATES AND PRESSURES CIRCULATE 20/40 MESH SAND INTO PLACE REVERSE OUT AND TEST PACK. CLOSE SLIDING SLEEVE AND TEST. POOH TO CLOSE KOIV REVERSE CIRCULATE AND FILTER BRINE POOH CHANGE RAMS TO 7" AND TEST DOOR SEALS TO 2000 PSI RU CASING CREW TO RUN 7" MONOBORE TIEBACK MU BAKER BULLET SEAL ASSEMBLY ON MODIFIED 7" CASING RIH AND MU 7" SSSV NIPPLE AT 450' RKB CONTINUE RIH W/7" TUBING, MU 7" HANGER HANG OFF ABOVE TIEBACK AND CIRCULATE IN PACKER FLUID DRAIN 16-3/4" RISER, LOWER AND ENGAGE TIEBACK LANDING HANGER RUN IN LOCK DOWN SCREWS PRESSURE UP ON ANNULUS AND TEST TO 2500 PSI HAVE TUBING OPEN RELEASE ANNULUS PRESSURE. RU SLICKLINE ON 7" LANDING JOINT RIH W/STANDING VALVE AND SET IN NIPPLE ABOVE UPPER GP ASSY PRESSURE TEST TUBING TO 2500 PSI RELEASE PRESSURE AND RECOVER PLUG RU PULLING TOOLS AND RECOVER SLEEVE FROM SSSV NIPPLE PUAND RUN 7" SSSV OPEN 7" SSSV AND PRESSURE TUBING TO 500 PSI, BLEED OFF REPRESSURE TUBING TO 500 PSI, CLOSE SSSV, BLEED OFF RD SLICKLINE BACKOUT AND RETRIEVE LANDING JOINTS ND BOP AND RISER NU 7" TREE WITH DUAL WINGS INSTALL TREE TEST PLUG TEST TREE TO 5000 PSI RETRIEVE TREE TEST PLUG RU DOWELL COILED TUBING UNIT W/LUBRICATOR TO RIG FLOOR RU COIL BOP AND INJECTOR HEAD TEST BOP TO 4500 PSI PU IMPACT TOOL (HIP TRIPPER) ON HYDRAULIC RELEASE ENTER WELL BORE AND PRESSURE UP TO 500 PSI TO EQUALIZE SSSV OPEN SSSV RIH AND PROCEED TO JET COMPLETION FLUID FROM WELL BREAK KIOV ABOVE A-2 INTERVAL CONTINUE TO RIH AND BREAK REMAINING KIOVs ASSURE WELLBORE IS CLEAR THROUGH SUMP PACKER AT 4260' POOH W/CTU RD CTU EF.r:" :IVED dui_ ?1'16/96 qlda(I STEELHEAD PLATFORM WELL # M-9 TRADING BAY UNIT PROPOSED COMPLETION COMPLETION DESCRIPTION 1) 7" 47# L-80 BTCKC Tubing ff 1000' - 82' 2) HES 5.963" ID SSSV Landing Nipple F/WL Ret. Safety. Valve ~ +/- 450' 3) Baker SC-1R Top Gravel Pack Packer ~ +/-3400' 4) 4" 9.5# SSWW Screen Packed w/ 20/40 Sand F/+/- 3400' - 3900' 5) Baker SC-IR Center Gravel Pack Packer ~ +/-3900' 6) 4" 9.5# SSWW Screen Packed w/ 24/40 Sand F/+/- 3900' - 4300' 7) Baker DAB Sump Packer t~ +/-4300' RKB = 160' 2 28" Structural Casing ~ 488' RKB (141 'BML) 13-3/8" 68# K-55 BTC Surface Casing ~ 850' 7" 47# L-80 BTCKC in TBE f/I000' - 81' 7" Liner Top @ +/- 1000' w/Liner Top Packer 9-5/8" 47# L-80 BTC Intermediate casing @ 1500' R CEIVED T' 29# L-80 NSCC Liner F/4500' - 1000' Dote olotted : 28-Jun-~ Plot R~arence ~s M-9 Ve~i~ ~10. C~rd;notes ore ;n feet reference slot ~B2-1 True Ve~;col ~~erence RKB. UNOCAL Structure : STEELHEAD Platform Well : M-g Field : McArthur River Field Location : TBU, Cook Inlet, Alaska UNOCAL ) 300 300 600 goo 1200 1500 1800 2100 2400 2700 3000 3300 300 ,,. ! East (feet) -> .300 0 .300 600 900 1200 i i ! i z ! i ! ! J. 1500 1800 i t i T.O. & End a~ Nekl - 3224,20 T~d, 2¢e2.83 N, A2 Rvsd 17-Jun-96 End of Hold - 0.00 Inc, 500.00 Md, 500.00 Tvd, 0.00 Vs 2.00 9 5/8 Casing 4.00 DLS: 2.00 deg per 100 ft 6.00 13 3/8 Casing 8.81 12.60 16.49 20.42 DLS: 4.00 deg per 1OO ft 24.38 28.34 32.32 9 5/8 Casing 36.29 40,28 44.26 48.25 52.24 60.22 End of Build/Turn - 60,30 Inc, 2202.10 Md, 1937.09 Tvd, 735.10 Vs 2700 2400 2100 1800 1500 1200 goo 600 300 300 Z Target - 60.30 Inc, 3570.89 Md, 2615.25 Tvd, 1923.71 Vs End of Hold - 60.30 Inc, 4095.68 Md, 2875.25 Tvd, 2579.41 Vs T.D. & End of Hold - 60.30 Inc, 4800.00 Md, 3224.20 Tvd, 2991.01 Vs ~ i i '1 i i i !i i' ' i i! · i ! i ! i i .300 600 900 1200 1500 1800 2100 2400 2700 3OOO Vertical Section (feet) -> Azimuth 55.10 with reference O.00 N, 0,00 E from slot #B2-1 i UNOCAL STEELHEAD Platform ~ett : M-9 stol #B2-1 McArthur River Field TBU, Cook Inlet, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : M-9 Version #10 Our ref : prop1657 License : Date printed : 28-Ju~-96 Date created : 13-Jun-96 Last revised : 28-Jun-96 Field is centred on n60 50 4.803,w151 36 18.018 Structure is centred on n60 50 4.803,w151 3~ 18.018 Stol location is n60 49 54.603,w151 36 5.~54 SLot Grid coordinates are N 24994~.702, E 214Z2~.125 Slot Local coordinates are 1035.82 S 607.94 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True Horth UNOCAL STEELHEAO Platform,M-9 McArthur River Fie[d,TBU, Cook InLet, ALaska Measured [ncLin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth ¢ 0 0 R O ! N A T E S 0.00 0.00 60.00 0.00 0.00 500.00 0.00 60.00 500.00 0.00 600.00 2.00 60.00 599.98 0.87 700.00 4.00 60.00 699.84 3.49 800.00 6.00 60.00 799.45 7.85 0.00 0.00 1.51 6.04 13.59 850.00 7.00 60.00 849.13 10.68 900.00 8.81 53.77 898.65 14.46 1000.00 12.60 46.81 996.90 26.46 1100.00 16.49 43.66 1093.68 44.31 1200.00 20.42 40.72 1188.52 67.91 18.49 24.22 38.36 56.01 77.09 1300.00 24.38 39.11 1280.95 97.16 1400.00 28.3~ 37.92 1370.54 131.91 1500.00 32.32 37.01 1456.84 171.99 1600.00 36.29 36.28 1539.42 217.22 1700.00 40.28 35.67 1617.90 267.35 PROPOSAL LISTING Page 1 Your ref : g-9 Version #10 Last revised : 28-Jun-96 1800.00 44.26 35.16 1691.89 322.17 1900.00 48.25 34.71 1761.02 381.39 2000.00 52.24 34.32 1824.96 444.72 2100.00 56.23 33.96 1883.40 511.87 2200.00 60.22 33.64 1936.05 582.49 DogLeg Vert Deg/lOOft Sect 2202.10 60.30 33.64 1937.09 584.01 2500.00 60.30 33.64 2084.69 799.46 3000.00 60.30 33.64 2332.41 1161o06 3500.00 60.30 33.64 2580.13 1522.66 3570.89 60.30 33.64 2615.25 1573.93 0.00 0.00 2.00 2.00 2.00 4000.00 60.30 33.64 2827.85 1884.26 N 4095.68 60.30 33.64 2875.25 1953.46 N 4500.00 60.30 33.64 3075.57 2245.87 N 4800.00 60.30 33.64 3224.20 2462.83 N 2.00 4.0O 4.00 4.00 4.00 101.50 E 4.00 129.12 E 4.00 159.81E 4.00 193.42 E 4.00 229.80 E 4.00 268.76 310.11 353.65 39~.18 446.46 0.00 0.00 1.58 6.33 14.23 19.37 13 3/8" Casing Pt / End 1st Curve 25.76 43.7O 68.45 99.89 137.85 182.16 2.32.61 9 5/8" Casing Pt 288.93 350.87 E 4.00 418.12 E 4.00 490.34 E 4.00 567.20 E 4.00 648.31 E 4.00 733.28 447.47 E 4.00 590.80 E 0.00 831.38 E 0.00 1071.96 E 0.00 1106.07 E 0.00 1312.54 1358.57 1553.12 1697.46 7'35.10 End of Final BuiLd 993.7~ 1427.97 1862.15 1923.71 Rvsd TARGET LA2) 0.00 0.00 0.00 0.00 2296.:3~ 2379.&1 A5 2730.51 2991.01 TO / 7" Casing Pt Att data is in feet unless otherwise stated. Coordinates from slot #B2-1 and TVD from RKB (160.25 Ft above mean sea LeveL). Bottom hole distance is 299t.t4 on azimuth 34.58 degrees from uelihead. Total DogLeg fee' leetipath is 61.0~ degrees. Vertica! section I; from ~ettllead on azimuth 35.10 degree~. CaLcuLation uses the mlnlm, m~ curvature method. Presented by Baker Hughes INTEQ UNOCAL STEELHEAO Platform,H-9 McArthur River Field,TBU, Cook Inlet, Alaska PRO(~C)SAL LISTING Page 2 Your ref : N-9 Version #10 Last revised : 28-Jun-96 Con~e~ts (n weltpath ~ TVO Rectangular Coords. Cce~ent 500.00 500.00 0.00 N 0.00 E 850.00 849.13 10.68 N 18.49 E 13 3/8" Casing Pt / End 1st Curve 1500.00 1456.8~ 171.99 N 159.81E 9 5/8' Casing Pt 2202.10 1937.09 58~.01N 447.47 E End of Final Build 3570.89 2615.25 157'~.93 N 1106.07 E Rvsd TARGET 4095.68 2875.25 1953.46 N 1358.57 E A5 ~800.00 3224.20 2462.83 N 1697.~ E TD / ?" Casing Pt Casing positions in string Tc~) 140 To)) TV) Rectangular Coords. Bot MO Bot TV) Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 850.00 8~9.13 10.6814 18.49E 13 3/8" Casing - 550.00 550.00 0.22N 0.38E 1500.00 1456.8~ 171.99N 159.81E 9 5/8" Casing 1200.00 1184).52 67.91N 7T.O9E 4800.00 3224.20 2~62.83N 1697.46E 7" Casing Targets associated with this weklpath Target name Geographic Location T.V.O. Rectangukar Coordinates Revised A2 Rvsd 1?-Jun-96 2615.25 1680.00N IO00.OOE 3-May-96 RECEIVED JUL i 9 i',,)9G Alaska Oil & Created by jo~es [Dar: T Maunder ~te I~Ot. ted: 10-Jui-96 Plot R~er~e is M-9 V~ ~10. Coordinat~ ore in fl~ mfl~ I~t ~B2-1. T~e Ve~cel ~hl ore r~ere~e RKB. 20 10 150 O0 UNOCAL Structure: ST££LHEAD Platform Well : Field: UcArthur River Field Locatlon : TBU, Cook Inlet, Alaska East (feet) -> 20 50 40 50 70 80 UNOCAL 90 100 110 120 150 150 140 130 120, 1400 1100 130 120 110 110 1 O0 9Q 5OO 1.300 1300 100 gO 8O 8O 70 5O 3O 2O 10 2O 12O0 gOO 1000 1100 1000 )00 200 56OO Alaska JUL 1 9 199B C01~s, C0!-~ffP, issioB 70 2O 10 10 Z O 4O 2O 10 10 2O 40 50 60 70 East (feet) -> 80 go 100 110 120 130 Created I~ .j,,ne~ For: T Matu3der O~3te ~ott~: 10-Jul-95 Plot Reference is M-9 Version ~10. Coordinates ere in feet reference slot True Vertical Dep{hs are reference RKB. UNOCAL 800 760 720 Structure: STEELHEAD Platform Well : Field : McArthur River Field Location : TBU, Cook Inlet, Alaska 68O 640 600' 560 520 480 440 400 360 80 120 160 200 240 280 8500 200O 3300 2600 East (feet) -> 320 360 400 53OO 5200 ~00 440 480 520 5~0 60~3 640 ~700 '800 5100 610( 50OO 1900 ~4OO 4000 4100 800 1700 53O0 800 89OO 2OOO 4200 O0 43O0 UNOCAL 76O 720 520 280 240 160 120 8O 8O 120 1500 9100 2~ 5OO 9200 2BO 320 360 400 East (feet) -> 44~ 32O 240 44O 480 520 5~0 6OO 540 ¢,eote~ ~y ~o,~e~ For: T Maundez:~ Dote p~otted: lO-Jul-96 P~ot Reference ~ M-8 Yer~o~ ~rlO. Coordinates are ~ fa~ reference slot I~82-1. Tr~e Ver[~col Oe~hs Ore reference RKB. 480 520 560 600 1480 UNOCAL $1ructure : STE£U-IEAD Platform Well : Field : IdcArthur River Field Location : TBU, Cook Inlet, Alaska East (feet) -> 640 680 720 760 800 840 880 920 UNOCAL 960 1000 1040 1CLBO 1480 1440 1400 1360. 1320 1280 O0 5200 62( 7500 2500 750O 760O 1440 1400 1360 1320 1280 1240 1200 1180, 1120 1080 1040. 5800 59~ 5400 77~ 56OO 78OO 7900 5700 8000 1240 1200 1160 1120 1080 1040 1000 1aa0 960 920 880 840 8O0 55OO 56O0 5700 58O0 g6o 920 76O 720 76O East (feet) -> 720 520 560 6O0 640 680 720 760 800 840 880 g20 g6O 1000 1040 lOaO Created by jone~ For: T Oote ~ett~: lO-Jul-g6 Coord;~otes ore in T~e Vel/cai ~bs ore r~er~ce R~. 840 880 2000 1960 1920 18BO 1840 ~600 176( 6900 1 156o 1520 26OO 920 960 710~ 70C 85OO UNOCAL Structure : STEELHEAD Platform Field = McArthur River Field Locatio~: TBU, Co~k inlet, Alaska East (feet) -> 1000 1040 1080 1120 1160 1200 1240 '200 glOO 9000, 8g{ 700 8700 68( 6gol 86OO 27O0 27OO UNOCAU8 12~ 1320 1360 1400 2000 lg60 1920 1880 ).8OO 1800 1760 71 O0 1720 1520 1480 14~0 1440 1400 1360 320, 1280 JLIL 1 9 ~.t~,~ J,l :J g '" ' Alaska Oil & 240 920 g~o 1040 10~0 1120 11~0 East (feet) -> 1200 1240 1280 1320 13~0 1400 1240 Creotecl by jones For: T )~auader Date plotted: lO-Jul-96 I:'fot Reference is M-9 Version ~10. Coordinates ore in fee[ reference slot ~82-1, True Vertical D~pths ore reference RKB. 2520 2480. 2440 2400 UNOCAL Structure: STEELHEAD Platform Well : H-9 Field: McAHhur River Field Location : TBU, Cook Inlet, Alaska 2360 2320 2280 2240 2200 2160 2120 UNOCAL ) East (feet) -> 1160 1200 1240 1280 1320 1560 1400 1440 1480 1520 1560 1600 1640 1680 1720 1760 I ~ I I t I I I I I I I I I I I I I I I J J I I I I I I ,I . 10200 7700 / oooo oo 2OO 5100 5000 2520 2480 2440 2400 2360 2320 2280 2240 /X 2200 I Z o 2160 2120 (D 2080 2080 2040 2040 2OO0 2OO0 1960' 1960 1920 1880 1920 1880 1840- 1800 A/ask~ 0~I ~ Gs.s Cons. Co~a?,ission 1160 1200 1240 1280 1320 1360 1400 1440 1480 1520 1560 1600 1640 1680 1720 1760 East (feel) -> UNOCAL Sfruc~ure: STEELHEAD Platform Well : M-g F~eld : McArfhur River rleld Location : TBU, Cool< Inlet, Alaska WELL PROFILE DATA ..... PO;hr MO h~c Dir TVD N a~,,h [alt · on 0.00 0.00 ~.~ 0.~ 0.~ 0.~ ~ of H~d ~.~ 0.~ 60.~ ~.~ 0.~ 0.~ .OP 8~.~ 7.~ ~.~ 849.13 10.~ 18.49 *d ~f Bui~um 2202.10 ~.~ 33.~ 1937.~ ~.01 447.~7 :~qet ~70.89 ~.~ ~.64 261 ~25 1573.93 ~ 106.07 ~d of H~d ~5.~ ~.~ ~.64 2875~5 19~.46 1358.57 D. $ ~ of ~ ~.~ ~.~ 33.64 3~2~.20 2462.83 1597.4e 520 330 V. ~¢f.Oea~/100 19.37 2.00 735.10 ¢.0~ 1923.71 0.0~ 2379.4 ! 0.0~ 2~.Ot 0.0~ 35O 0 ~0 34O 2O TRUE NORTH 310 UNOCALe ICreoted by jones For: T Maunder Dote plotted : 28-Jun-96 Plot Reference is M-9 Yeti;on II0. Coordinotes ore ;n fe~t reference slot NB2-1. /~ m~-,,~j 30 40 5O 300 6O 290' 7O 28O 8O 270 9O 26O 100 250 110 24-0 120 210 200 190 ,4ormol Plane Travelling Cylinder - Feet 150 14 150 JL~L 1 9 'i~':-;~'' 180 170 Alaska 0~1 & All depths shown ore Meosured depths on Reference Well UNOCAL STEELHEAD PLatform WeLL : N-9 slot IB~-I McArthur River FieLd TBU, Cook InLet, ALaska 3-D MINIMUM DISTANCE CLEARANCE Baker Hughes INTEQ REPORT Your ref : M-9 Version #10 Our ref : prop1657 License : Date printed : lO-JuL-96 Date created : 13-Jun-96 Last revised : 28-Jun-96 FieLd is centred on n60 50 4.803,w151 36 18.018 Structure is centred on n60 50 4.803,w151 36 18.018 Slot location is n60 49 54.603,w151 36 5.754 Slot Grid coordinates are N 2499/,63.702, E 214223.123 Slot local coordinates are 1035.82 S 607.94 E Projection type: alaska - Zone 4, Spheroid: CLarke - 1866 Reference North is True North Report is Limited to clearances tess than 200 DECREASING CLEARANCES of Less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object ~et tpath PGHS <O-12930'>,,M-28,STEELHEAD PLatform PGMS <3700-11700'>,,M-25,STEELHEAD PLatform PGMS <O-109~'>,,M-29,STEELHEAD PLatform GSS <975-2660'>,,M-29,STEELHEAD PLatform PGHS <12486-15276'>,,M-27,STEELHEAD PLatform MSS <1103-2265'>,,M-26,STEELHEAO PLatform PGNS <2700-9101'>,,M-14,STEELHEAD PLatform PMSS <1006-7952'>,,M-15 St,STEELHEAD PLatform PMSS <lO06-1449,>,,M-15,STEELHEAD PLatform PGNS <0-5185~>,,M-19,STEELHEAO PLatform MSS <1363-1859~>,,RLF #2,STEELHEAO PLatform PGNS <0-2310~>,,RLF #1,STEELHEAO PLatform PMSS <808-1165~>,,RLF #2,STEELHEAO PLatform MSS <0-735'>,,01t #2,STEELHEAD PLatform PGNS <O-14575~>,,M-30,STEELHEAD PLatform PGNS <0-857~>,,B1-8, STEELHEAO PLatform PGNS <0-785,>,,B1-6,STEELHEAO PLatform PG#S <0-7434~>,,#-13,STEELHEAO PLatform PGNS <500-928~>,,B1-2,STEELHEAD PLatform PGNS <0-5600">,,N-5,STEELHEAO PLatform PNSS <6595-6988~>,,N-l,STEELHEAO PLatform PGqS <O-TZSO'>,,#'ISt#1,STEELHEAD PLatform PGNS <O-?419,>,,N-2,STEELHEAO PLatform GSS <O-1421~>,,*Iq-&*,STEELHEAO PLatform PGNS <O-6440~>,,N-7,STEELHEAO PLatform CLosest approach with 3-O MinimLe Distance method Last revised Distar~e M.D. Diverging from M.D. 23- Jun-95 101 .? /+60.0 460.0 23- Jun-95 105.5 533.3 533.3 23- Jun-95 105.5 533.3 533.3 23-Jt~-95 92.6 ?00.2 700.2 PR-Jun-95 109.7 500.0 500.0 ?.3- Jun-95 145.7 80.0 320.0 23-Jun-95 149.8 0.0 460.0 ?.3- Jtaq-95 149.8 0.0 460.0 23-Jun-95 135.8 633.3 633.3 23- Jta't- 95 166.1 1433.7 1433.7 23- JLm-95 258.9 1625.0 1625.0 23-Jun-95 425.7 1200.0 1200.0 r~ ?EIVE ~-dun-95 110.9 500.0 500.0 1~';':-~' ~'~ ~-dt~-95 110.6 340.0 340.0 ~-,,1~-95 10Z.1 460.0 460.0 -jun- 155.3 dUL 1 9 23-JL~-95 100.1 733.3 733.3 23-dc?t-95 10.1 300.0 300.0 ~-Jun-95 9.0 0.0 533.~,lask~ 011 & I~s CoilS. OO~IT,~,~, ?J-dm-95 9.0 0.0 533.3 Anchor~o ~-d~r~-95 8.2 ~80.0 ~80.0 ?.~- dm-95 $.1 500.0 500.0 28-Jun-96 10.6 260.0 260.0 PGMS <0-7250'>,,N-3 ELHEAD Platform 23-Jun-~5 PMSS <10247-10355~>,,#-..~STEELHEAO Platform 23-Jun-95 PMSS <10741-12018'>,,H-31St#1,STEELHEAO Platfo 23-Jun-95 PMSS <9365 - 10588'>,,1432ST#1,STEELHEAD Ptatfo 23-Jun-95 PMSS <1386 - 9833~>,~N-32,STEELHEAO Platform ?.3-dun-95 PMSS <898~ - 12583~>,,N32St#2,STEELHEAD P[atfo 23-Jun-95 PGHS <O-927'>,,B1-10,STEELHEAO Platform 23-Jun-95 PMSS <12281 - 12660'>,,H32St#J,STEELHEAO P[atf 23-Jun-95 6.5 105.7 105.7 100.3 100.3 100.3 100.3 100.3 0,0 :533.3 533.3 566.7' 566.7 566.7 566.7' 566.7 0.0 533.3 533.3 566.7, 566.7 566.7 566.7 566.7, UNOCAL STEELHEAD Platform,M-9 McArthur River Field, TBU, Cook Intet, Ataska CLEA..,dCE LISTING Page 2 Your ref : M-9 Version #10 Last revised : 28-Jun-96 Reference we[[path Object we[[path : PGMS <O-12930'>,,M-28,STEELHEAD Platform M.D. T.V.D. Horiz Min'm TCy[ Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 O.ON O.OE 0.1 0.1 66.1N 76.3W 310.9 100.9 100.9 O.ON O.OE 100.3 100.3 65.9N 76.3W 310.8 100.8' 100.8' O.ON O.OE 200.4 200.4 65.4# 76.2~ 310.6 100.5' 100.5' O.ON O.OE 300.5 300.5 65.0N 76.0~ 310.5 100.0' 100.0' O.ON O.OE 400.9 400.9 64.6N 75.4~ 310.6 99.3* 99.3* 500.0 600.0 700.2 800.6 901.4 500.0 600.0 700.0 800.0 900.0 O.ON O.OE 501.1 501.1 64.0N 74.5W 310.6 98.2* 98.3* 0.9N 1.5E 602.6 602.5 63.6N 72.7~ 310.2 97.3* 97.3* 3.5N 6.1E 702.9 702.8 63.2N 69.4~ 308.4 96.3* 96.3* 7.914 13.6E 802.7 802.5 63.5N 65.71~ 305.0 97.0 97.0 14.6N 24.4E 902.5 902.3 04.1N 62.4W 299.7 99.9 100.0 1003.2 1106.6 1212.3 1321.0 1433.7 1000.0 1100.0 1200.0 1300.0 1400.0 26.9N 38.9E 1003.5 1003.2 65.2N 59.0QI 291.4 105.1 105.4 45.7N 57.3E 1103.8 1103.4 67.6N 54.8QI 281.0 114.2 115.1 71.2N 79.9E 1204.0 1203.5 72.1N 51.5W 270.4 131.4 134.4 104.0N 107.0E 1306.9 1306.0 80.ON 49.21W 261.3 158.2 164.9 144.8N 139.1E 1414.6 1412.7 94.5N 46.6~ 254.8 192.9 2C~+.6 Att data is in feet ~tess otherwise stated. Casing dimensions are not inctuded. Coordinates from slot #B2-1 and TVO from RKB (160.25 Ft above mean sea [ever). Total Dogleg for ~et[path is O.OOclegrees. Vertical section is from~etthead on azimuth 35.10 degrees. Catcu[ation uses the minimua curvature ~ethod. Presented by Baker Hughes INTEQ UNOCAL STEELHEAO PLatform, N-9 McArthur River Field, TBU, Cook Inlet, Alaska CLEARANCE LISTING Page 3 Your ref : #-9 Version #10 Last revised : 28-Jun-96 Reference weLLpath Object wellpath : PGMS <3700-11700'>,,H-25,STEELHEAO Platform M.D. T.V.D. Horiz #in'm TCyt Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 O.ON O.OE 0.0 7.9 61.2N 82.5W 306.6 103.1 - O.ON O.OE 91.8 99.7 61.3N 82.7'd 306.6 102.9' 102.9 O.ON O.OE 192.3 200.2 61.2N 82.6W 306.5 102.8' 102.8' O.ON O.OE 292.8 300.7 61.0N 82.4W 306.5 102.5' 102.5' O.ON O.OE 392.4 400.4 60.5N 82.0QI 306.4 101.9' 101.9' 500.0 600.0 700.2 800.6 901.4 500.0 600.0 700.0 800.0 900.0 0.13t4 O.OE 491.3 499.2 58.9N 83.1~ 305.4 101.9. 101.9. 0.gN 1.5E 592.4 600.0 54.811 86.3g 301.6 103.1 103.1 3.5# 6.1E 691.9 699.2 61.7g 83.3~ 303.1 106.7 106.8 7.9N 13.6E 795.1 802.3 63.8~1 81.01d 300.6 109.9 110.0 14.6N 24.4E 891.2 898.4 65.4N 80.6g 295.8 116.6 117.0 1003.2 1106.6 1212.3 1321.0 1000.0 1100.0 1200.0 1300.0 26.9N 38.9E 992.9 1000.0 61.6N 81.914 286.0 125.6 126.4 45.7ti 57.3E 1092.8 1099.9 60.814 82.3W 276.2 140.4 142.6 71.2N 79.9E 1193.4 1200.4 60.5N 82.0~ 266.2 162.3 167.9 104.0N 107.0E 1292.4 1299.5 60.7tl 82.0~ 257.1 194.0 206.9 Att data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates fro~stot #B2-1 and TVO from RKB (160.25 Ft above mean sea [eve[). Total Dogleg for ~ettpath is 0.00 degrees. Vertical section is free ~etthead on azimuth 35.10 degrees. Calculation uses the mini~ curvature aethod. Presented by Baker Nughes INTEQ UNOCAL STEELHEAD Platform,M-9 P4cArthur River Fietd, TBU, Cook Inlet, Alaska CLFJLqJ~..~ LISTING Page & Your ref : #-9 Version #10 Last revised : 28-Jun-96 Reference we[[path Object weJlpath : PGI4S <O-109:~8~>,,#-29,STEELNEAO PJatform M.D. T.V.D. Horiz Min'm TCy[ Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 100.0 200.0 300.0 /+00.0 0.0 100.0 200.0 300.0 400.0 O.ON O.OE 0.0 0.0 60.4N 88.8~1 304.2 107.4 107.4 O.ON O.OE 99.8 99.8 60.4N 88.914 304.2 107.5 107.5 O.Ofl O.OE 200.2 200.2 60.4N 89.1W 304.1 107.7 107.7 O.ON O.OE 300.7 300.7 60.1N 89.0~ 304.1 107.4' 107.4' O.ON O.OE 401.1 401.1 59.2N 88.5W 303.8 106.5' 106.5' 500.0 500.0 600.0 600.0 700.2 700.0 8O0.6 800.0 901.4 900.0 O.ON O.OE 500.5 500.5 57.6N 88.5~ 303.1 105.6' 105.6' 0.gN 1.5E 599.3 599.3 56.0N 89.4~ 301.2 106.3 106.4 3.5N 6.1E 699.1 699.0 54.711 91.0t4 297.8 109.7 109.9 7.9N 13.6E 799.0 798.9 53.5N 92.6~1 293.2 115.7 116.0 14.6N 24.4E 899.2 899.1 52.2N 94.1~ 287.6 124.3 124.9 1003.2 1000.0 1106.6 1100.0 1212.3 1200.0 26.911 38.9E 998.9 998.8 50.6N 95.3~ 280.0 136.2 137.6 45.7N 57.3E 1097.5 1097.3 48.0N 96.714 270.8 154.1 157.9 71.2N 79.9E 1195.4 1195.2 44.6N 98.814 261.5 180.8 189.8 Att data is in feet ~less otherwise stated. Casing dimensions are not included. Coordinates from slot #62-1 and TVO fre~ RICB (160.:~5 Ft above mean sea level). Total Dogleg for aettpath is 0.00 degrees. Vertical section is fr0~ ~etthead on azimuth 35.10 degrees. Calculation uses the ainimua curvature mtethod. Presented by Baker Nughes INTEQ UNOCAL STEELHEAO PLatform,#-9 NcArthur River FieLd,TBU, Cook Inlet, ALaska CLEARA,¢E LISTING Page 5 Your ref : M-9 Version #10 Last revised : 28-Jun-96 Reference weLLpath C)bject wet[path : GSS (975-2660'>,,M-29,STEELHEAD PLatform N.D. T.V.D. Horiz #in'm TCyL Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Oist Dist 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 O.ON O.OE 0,0 0.0 60.4N 88.8W 304.2 107.4 107.4 O.ON O.OE 99.8 99.8 60.4N 88.91~ 304.2 107.5 107.5 O.ON O.OE 200.2 200.2 60.4N 89.1W 304.1 107.7 107.7 O.ON O.OE 300.7 300.7 60.1N 89.0~ 304.1 107.4' 107.4' O.ON O.OE 401.1 401.1 59.2N 88.5W 303.8 106.5' 106.5' 500.0 600.0 700.2 800.6 901.4 500.0 600.0 700.0 8O0.0 900.0 O.ON O.OE 500.5 500.5 57.6N 88.5W 303.1 105.6' 105.6' 0.9N 1.5E 599.3 599.3 56.0N 89.4W 301.2 106.3 106.4 3.5N 6.1E 699.1 699.0 54.7N 91.0W 297.8 109.7 1(K~.9 7.9tl 13.6E 799,0 198.9 53.5N 92.6~ 293.2 115.7 116.0 14.6# 24.4E 899.2 899.1 52.2N 94.1W 287.6 124.3 124.9 1003.2 1106.6 1212,3 1000.0 1100.0 1200.O 26.9N 38.9E 998.6 998.5 50.6N 95.3W 280.0 1~6.3 137.8 45.7N 57.3E 1097.8 1097.6 47.811 97.3W 270.8 154.6 158.3 71.2# 19.9E 1194.9 1194.6 45.1N 99.6~ 261.7 181.4 190.0 Att data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot ~82-1 and TVO fraaRKB (160.25 Ft above mean sea Level). Total Oogteg for wettpath is 0.00 degrees. Vertical section is from wellhead on azimuth 35.10 degrees. Calculation uses the min{Mcurvature method. Presented by Baker Hughes INTEQ UNOCAL STEELHEAD Ptatform,N-9 McArthur River Fietd, TBU, Cook Inter, Ataska CLEARANCE LISTING Page 6 Your ref : M-9 Version #10 Last revised : 28-Jun-96 Reference wet[path Object we[[path : PGMS <12486-15276'>,,#-27,STEELHEAD Platform M.D. T.V.D. Rect Coordi nates Horiz Min'm TCy[ M.D. T.V.D. Rect Coordinates Bearing Oist Dist 0.0 0.0 O.ON O.OE 100.0 100.0 O.ON O.OE 200.0 200.0 O.ON O.OE 300.0 300.0 0.0# O.OE 400.0 400.0 0.0# O.OE 0.1 0.1 61.3N 76.714 308.6 98.2 98.2 100.3 100.3 61.1N 76.714 308.5 98.0' 98.0' 200.2 200.2 60.711 76.71,1 308.4 97.8* 97.8* 300.4 300.4 60.3N 76.7W 308.1 97.6* 97.6* 401.1 401.1 59.641 76.5W 307.9 97.0* 97.0* 500.0 500.0 O.ON O.OE 600.0 600.0 0.gN 1.5E 700.2 700.0 3.5N 6.1E 800.6 800.0 7.9N 13.6E 901.4 900.0 14.6N 24.4E 502.3 502.3 58.5N 75.5W 307.8 95.5* 95.5* 603.0 602.9 57.0W 73.3W 306.9 93.6* 93.6* 703.0 702.9 56.0W 70.1W 304.6 92.6* 92.6* 802.9 802.7 56.1N 66.5W 301.0 93.6 93.6 903.5 903.2 56.711 62.711 295.8 96.8 96.9 1003.2 1000.0 26.9fl 38.9E 1106.6 1100.0 45.7N 57.3E 1212.3 1200.0 71.2N 79.9~ 1321.0 1300.0 104.0N 107.0E 1433.7 1400.0 144.8N 139.1E 1005.4 1005.0 58.5# 57.714 288.1 101.7 101.9 1108.9 1108.2 62.0N 50.4~ 278.6 109.2 109.7 1213.0 1211.7 67.4N 41.3W 268.2 121.8 123.2 1319.5 1317.4 75.6N 30.5W 258.3 141.6 145.1 1427.6 1424.3 85.5N 18.5W 249.4 170.2 177.9 Att data is in feet t~less otherwise stated. Casing dimensions are not inctuded. Coordinates fro~ slot #82-1 and TVO frown RKB (160.25 Ft above mean sea lever). Total Dogleg for ~ettpath is 0.00 degrees. Vertica[ section is fro~ wellhead on azieuth :$5.10 degrees. Ca[cutation uses the aini~ curvature methocl. Presented by Baker Hughes INTEQ UNOCAL STEELHEAO PLatform,M-9 McArthur River Fie[d,TBU, Cook InLet, ALaska CLEARRaCE LISTING Page 7 Your ref : H-9 Version #10 Last revised : 28-Jun-96 Reference NeLLpath Object we[Lpath : MSS <1103-2265'>,,#-26,STEELHEAD PLatform M.D. T.V.D. Horiz Min'm TCyt Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Oist 0.0 100.0 200.0 300.0 600.0 0.0 100.0 200.0 300.0 600.0 O.ON O.OE 0.0 8.3 71.3N 83.4W 310.6 110.0 - O.ON O.OE 91.8 100.0 71.3N 83.4W 310.6 109.7' 109.? O.ON O.OE 191.8 200.0 71.3# 83.4~ 310.6 109.7 109.? O.ON O.OE 291.8 300.0 71.3N 8~.4W 310.6 109.7 109.7 0.0# O.OE 391.8 400.0 71.3# 8~.4~ 310.6 109.7 109.? 500.0 6O0.0 700.2 800.6 901.4 500.0 600.0 700.0 800.0 900.0 O.ON O.OE 491.8 500.0 71.3N 83.4W 310.6 109.7 109.? 0.911 1.5E 591.8 600.0 71.3N 83.4W 309.7 110.3 110.3 3.5N 6.1E 691.8 ?00.0 71.3N 83.4W 30?.2 112.2 112.3 7.91,1 13.6E 791.0 799.3 71.4N 83.4~ 303.2 116.0 116.1 14.6N 24.4E 893.1 901.3 70.914 83.91~ 297.5 122.1 122.3 1003.2 1106.6 1212.3 1321.0 1000.0 1100.0 1200.0 1300.0 26.9N 38.9E 991.4 999.6 70.ON 83.91~ 289.3 130.1 130.8 45.711 57.3E 1090.4 1098.6 72.1N 84.3W 280.6 144.0 146.1 71.2N 79.9E 1191.5 1199.6 77.9N 84.6~ 272.3 164.7 169.0 104.0N 107.0E 1299.3 1306.8 88.6N 83.214 265.6 191.0 198.0 AIL data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #B2-1 and TVO from RI(B (160.25 Ft above mean sea [eve[). Total DogLeg for ~ettpath is 0.00 degrees. Vertical section is froauetthead on azimuth 35.10 degrees. CaLcuLation Uses the mini~ curvature aethod. Presented by Baker Hughes INTEQ UNOCAL STEELHEAD PLatform,M-9 McArthur River Fie[d, TBU, Cook InLet, ALaska CLEARANCE LISTING Page 8 Your ref : #-9 Version #10 Last revised : 28-Jun-96 Reference ~e[Lpath Object uettpeth : PGMS <2700-9101'>,,H-14,STEELHEAD PLatform Horiz #in'm TCy[ N.O. T.V.D. Rect Coordinates M.D, T.V.O. Rect Coordinates Bearing Dist Dist 0.0 0.0 O.ON O.OE 0.0 7.9 13.2S 145.21~ 264.8 146.0 - 100.0 100.0 O.ON O.OE 92.0 99.9 13.3S 145.21~ 264.8 145.8' 145.8 200.0 200.0 O.ON O.OE 192.1 200.0 13.6S 145.ZW 264.6 145.8 145.8 300.0 300.0 0.0# O.OE 292.0 300.0 14.0S 145.2t,/ 264.5 145.8 145.8 400.0 400.0 O.ON O.OE 392.0 399.9 14.4S 145.21,1 264.3 145.9 145.9 500.0 500.0 O.ON O.OE 492.0 499.9 15.1S 145.1W 264.1 145.9 145.9 600.0 600.0 0.gN 1.5E 591.8 599.8 15.8S 145.1W 263.5 147.6 147.7 700.2 700.0 3.5N 6.1E 691.6 699.5 16.7S 145.3W 262.4 152.7 153.0 800.6 800.0 7.9N 13.6E 791.3 799.2 17.6S 145.6~ 260.9 161.3 162.1 901.4 900.0 14.6N 24.4E 890.3 898.2 18.9S 146.21~ 258.9 173.8 175.8 1003.2 1000.0 26.9N 38.9E 990.4 998.3 20.7S 146.8g 255.6 191.7 195.7 Att data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot ~B2-1 and TVO from RKB (160,25 Ft above mean sea LeveL). Total DogLeg for ~ettpath is 0.00 degrees. Vertical sectie~ is froa ~etthead on azieuth 35.10 degrees. CaLcuLation uses the aini~u~ curvature eethod. Presented by Baker Hughes I NTEQ UNOCAL STEELHEAD Platform,N-9 McArthur River Fie[d,TBU, Cook Inlet, Alaska CLEARANCE LISTING Page 9 Your ref : N-9 Version #10 Last revised : 28-Jun-96 Reference wetLpath Object we[tpath : PMSS <1006-7952'>,,M-15 St,STEELHEAD Platform M.D.T.V.D. Horiz #in'm TCyt Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing DJst DJst 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 O.ON O.OE 0.0 0.0 18.7S 148.6W 262.8 149.8 149.8 O.ON O.OE 99.8 99.8 18.9S 148.6W 262.7 149.8 149.8 O.ON O.OE 199.9 199.9 19.4S 148.7W 262.6 150.0 150.0 O.ON O.OE 299.9 299.9 19.8S 148.7W 262.4 150.0 150.0 O.ON O.OE 399.7 399.7 20.4S 148.8W 262.2 150.2 150.2 500.0 600.0 700.2 800.6 901.4 500.0 600.0 700.0 800.0 900.0 O.ON O.OE 498.4 498.4 21.5S 148.8W 261.8 150.4 150.4 O.gfl 1.5E 596.8 596.8 23.6S 149.814 260.8 153.3 153.6 3.5N 6.1E 692.6 692.4 27.7S 152.4W 258.9 161.7 162.8 7.9N 13.6E 788.6 788.1 34.0S 156.7~ 256.2 175.9 178.6 14.6N 24.4E 884.2 883.1 42.6S 162.2W 253.0 195.9 201.4 Alaska Oil & Gas Co,'~s, C.3!-¢missior~ An¢..:cra2o Att data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from stol #82-1 and TV) from RIQi (160.25 Ft above mean sea level). Total Dogleg for ~e[[path is 0.00 degrees. Vertical sectio~ is free ue[[head e~ azieuth 35.10 degrees. Ca[cu[atien uses the ainiu curvature method. Presented by Baker #ughes INTEQ UNOCAL STEELHEAO PLatform,M-9 McArthur River FJe[d, TBU, Cook InLet, ALaska CLEARadCE LISTING Page 10 Your ref : M-9 Version #10 Last revised : 28-Jun-96 Reference weLlpath Object we[tpath : PNSS <1006-1449'>,,#-15,STEELHEAO Ptatform M.D. T.V.O. Horiz Nin'm TCy[ Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 O.ON O.OE 0.0 0.0 18.7S 148.61~ 262.8 149.8 149.8 O.ON O.OE 99.8 99.8 18.9S 148.6W 262.7 149.8 149.8 0.0# O.OE 199.9 199.9 19.4S 148.71~ 262.6 150.0 150.0 O.ON O.OE 299.9 299.9 19.8S 148.7g 262.4 150.0 150.0 O.ON O.OE 399.7 399.7 20.4S 148.8~1 262.2 150.2 150.2 500.0 600.0 700.2 800.6 901.4 500.0 600.0 700.0 800.0 900.0 O.ON O.OE 498.4 498.4 21.5S 148.814 261.8 150.4 150.4 o.gN 1.5E 596.8 596.8 2~.6S 149.8U 260.8 153.3 153.6 3.5N 6.1E 692.6 692.4 27.7S 152.4W 258.9 161.7 162.8 7.9N 13.6E 788.6 788.1 34.0S 156.7U 256.2 175.9 178.6 14.6N 24.4E 884.2 883.1 42.6S 162.214 253.0 195.9 201.4 ALt data is in feet ta~tess otherwise stated. Casing dimensions are not included. Coordinates from slot #B2-1 and TVO from RKB (160.25 Ft above mean sea LeveL). Total DogLeg for ~eLLpath is 0.00 degrees. Vertical section is from NekLhead on azimuth 35.10 degrees. CaLcuLation uses the mini~mzn curvature method. Presented by Baker Hughes I#TEQ UNOCAL STEELHEAD PLatform, N-9 NcArthur River Fietd,TBU, Cook Inlet, Maska CLEAI~RNCE LISTING Page 11 Your ref : #-9 Version #10 Last revised : 28-Jun-96 Reference ~eLLpath Object wetlpath : PGHS <O-5185'>,,H-19,STEELHEAO PLatform M.O. T.VoO. Rect CoordJ nates Horiz Min'm TCy[ #.O. T.V.D. Rect Coordinates Bearing Dist Oist 0.0 0,0 O.ON O.OE 100.0 100,0 O.ON O.OE 200.0 200.0 O.ON O.OE 300.0 300.0 0.0# O.OE 400.0 400.0 O.ON O.OE 0.2 0.2 13.6S 141.2'd 264.5 141.9 141.9 100.6 100.6 14.0S 140.91~ 264.3 141.6' 141.6' 200.4 200.4 14.5S 140.5g 264.1 141.3' 141.3' 301.1 301.1 14.8S 140.1g 264.0 140.9' 140.9' 402.6 402.6 14.9S 139.0~ 263.9 139.9' 139.9' 500.0 500.0 600.0 600.0 700.2 700.0 800.6 800.0 901.4 900.0 O.ON O.OE 0.gN 1.5E 3.5N 6.1E 7.9N 13.6E 14.6N 24.4E 504.1 504.1 15.2S 136.8g 263.6 137.~" 137.7' 605.6 605.5 1?.OS 133.1~ 262.4 135.9' 135.9' 705.8 705.5 20.2S 128.5g 260.0 136.7 136.7 805.0 804.5 25.3S 123.8g 256.4 141.4 141.8 905.5 904.6 32.4S 118.5~ 251.8 150.5 151.5 1003.2 1000,0 1106.6 1100.0 26.9N 45.711 38.9E 1005.5 1004.2 39.3S 113.0~1 246.4 165.7 168.6 57.3E 1105.3 1103.8 43.3S 108.4g 241.8 188.1 194.7 Att data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #B2-1 and TVO from RKli (160.25 Ft above mean sea Lever). Total DogLeg for ~e[tpath is 0.00 degrees, Vertical section is free ~eLthead o~ azimuth 35.10 degrees. Catcutation uses the mtni~ curvature ~ethod. Presented by Baker Ilughes INTEQ UNOCAL STEELHEAO PLatform,#-9 McArthur River FieLd,TBU, Cook Inlet, ALaska CLEAk,aCE LISTING Page 1Z Your ref : H-9 Versio~ #10 Last revised : 28-Jun-96 Reference wellpath Object we[[path : MSS <1363-1859'>,,RLF #2,STEELHEAD Platform M.D. T.V.D. Horiz Min'm TCy[ Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dtst Oist 1321.0 1300.0 1433.7 1400.0 104.0# 107.0E 1571.0 1451.0 21.4S 120.5E 175.9 196.7 276.9 144.8N 139.1E 1627.9 1479.4 10.3N 82.7E 202.8 166.1' 166.1' JUL i 9 '"":'""" Anc',~crs. go Att ~ta is in f~t ~t~s otherwise stat~. Casi~ di~si~ are ~t i~[~. C~rdi~t~ fr~ slot ~-1 a~ T~ fr~ R~ (1~.25 Ft a~ve ~an sea level). Total D~[~ for ~tt~th is 0.~ ~grees. Vertical ~ti~ is fr~ ~[[he~ ~ azi~th ~5.10 Ca[cu[ati~ ~ the mini~ curvature ~th~. Pres~t~ ~ ~ker H~. I NTEQ UNOCAL STEELHEAD PJatform,M-9 HcArthur River Fietd,TBU, Cook Inlet, Alaska CLEARANCE LISTING Page 13 Your ref : #-9 Version#10 Last revi~ed : 28-Jun-96 Reference ~e[ [path Object ~eltpath : P~S <O-14575'>,,N-30,STEELHEAO Ptatform M.D.T.V.D. Horiz #in'e TCy[ Rect Coordinates H.D. T.V.D. Rect Coordinates Bearing Dis[ Dist 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 O.ON O.OE 0.1 0.1 69.2N 88.1W 308.1 112.0 112.0 O.ON O.OE 100.3 100.3 69.2N 88.fid 308.2 111.9' 111.9' O.ON O.OE 200.3 200.3 68.9g 87.91J 308.1 111.7' 111.7' O.ON O.OE 300.4 300.4 68.5N 87.9g 307.9 111.4' 111.4' O.Og O.OE 400.3 400.3 68.7tl 87.21/ 308.2 111.0~ 111.0' 500.0 500.0 6O0.0 6O0.0 700.2 700.0 800.6 800.0 901.4 900.0 O.ON O.OE 499.7 499.7 69.8# 86.21~ 309.0 110.9' 110.9' 0.9N 1.5E 598.6 598.6 71.1N 85.714 308.9 112.0 112.0 3.5N 6.1E 697.0 696.9 72.9N 86.71,1 306.8 115.9 116.1 7.914 13.6E 795.6 795.5 75.2N 89.21,1 303.2 123.0 123.4 14.6N 24.4E 895.5 895.3 7T.71W 92.(N 298.5 132.4 133.1 1003.2 1000.0 1106.6 1100.0 1212.3 1200.0 26.9N 38.9E 996.3 996.0 79.9N 94.3W 291.7 143.4 144.4 45.711 57.3E 1094.3 1094.0 82.9N 96.8~1 283.6 158.6 161.4 71.2N ~.9E 1193.8 1193.3 88.~ ~.~ 2~.6 1~.7 1~.4 ALt data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from stot #B2-1 and TVO from RKB (160.25 Ft above mean sea fever). Totat DogLeg for ~ettpath is 0.00 degrees. Vertical section is fremweLLhead on azimuth 35.10 degrees. Catcutation uses the min;~curvature method. Presented by Baker Hughes INTEQ UNOCAL STEELHEAD Platform,M-9 HcArthur River FieLd,TBU, Cook lntet, Alaska CLEARR,~E LISTING Page 14 Your ref : #-9 Version #10 Last revised : 28-Jun-96 Reference ~ettpath Object uettpath : PGHS <O-857'>,,B1-8, STEELHEN) Ptatform M.D. T.V.D. Horiz #tn'm TCyL Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 O.ON O.OE 0.6 -0.1 65.0N 90.CN 305.8 111.1 111.1 O.ON O.OE 100.7 100.0 65.2N 90.(N $05.9 111.1 111.1 O.ON O.OE 200.9 200.1 65.1# 90.0i4 305.9 111.0' 111.0' 0.0# O.OE 301.2 300.4 64.6N 90.Og 305.7 110.8' 110.8' 0.0# O.OE 400.0 399.2 64.7),1 89.91,1 305.7 110.8' 110.8 500.0 600.0 700.2 800.6 901.4 500.0 600.0 700.0 800.0 900.0 O.ON O.OE 500.0 499.3 65.7N 90.5g 306.0 111.9 111.9 0.914 1.5E 599.9 599.1 64.3N 92.01W 304.2 113.0 113.0 3.5# 6.1E '699.8 698.9 61.7N 94.711 300.0 116.3 116.4 7.914 13.6E 799.5 798.6 59.0N 97.5~ 294.7 122.4 122.7 14.6N 24.4E 857.0 856,0 57,1N 99.214 289.0 137.9 - Alaska Oil 8, Ga,'-~ Co;'~s, Co?nmission Att data is in feet ta~[ess otheruise stated. Casing dimensions are not included. Coordinates from slot ~B2-1 and TVO from RKB (160.25 Ft above mean sea [eve[). Totat Oogteg for uettpath is 0.00 degrees. Vertical section is free ue[[head on azimuth $5.10 degrees. Catcu[ation uses the miniu curvature method. Presented by Baker Hughes I#TEO UNOCAL STEELHEAO Platform,#-9 NcArthur River Field,TBU, Cook Inlet, Alaska CLEAR~.,~E LISTING Page 15 Your ref : #-9 Version #10 Last revised : 28-Jun-96 Reference ~etLpath Object wettpath : PGMS <O-?85'>,,B1-6,STEELHEAD Platform 14.0. T.V.D. Rect Coordinates Horiz Min'm TCy[ N.O. T.V.D. Rect Coordinates Bearing Oist Oist 0.0 0.0 O.ON O.OE 100.0 100.0 O.ON O.OE 200.0 200.0 O.ON O.OE 300.0 300.0 O.ON O.OE 400.0 400.0 O.ON O.OE 0.8 0.1 57.614 84.9~/ 304.1 102.6 102.6 100.8 100.0 57.2N 85.0~ 303.9 102.5' 102.5' 200.9 200.1 56.9N 85.21,1 303.8 102.5' 102.5' 300.9 300.1 56.5N 85.3W 303.5 102.3' 102.3' 401.0 400.2 56.1N 85.4W 303.3 102.2' 102.2' 500.0 500.0 O.ON O.OE 600.0 600.0 0.91t 1.5E 700.2 ?00.0 3.5N 6.1E 800.6 800.0 7.9tt 13.6E 901.4 900.0 14.6N 24.4E 499.2 498.5 55.7tl 85.91~ 303.0 102.4 102.4 599.6 598.8 55.8N 87.5~ 301.7 104.6 104.6 699.3 698.5 55.8N 89.1U 298.8 108.6 108.7 785.0 784.2 56.1N 90.3~ 294.9 115.7 ?85.0 784.2 56.1N 90.3~ 289.9 168.2 r:," 'IVED 1998 ;,,tas!~a Oil & G~'~s Cons. ComrP,[s~iori anchora~o Att data i~ in feet la, tess otherwise stated. Casing dimensions are not included. Coordinates from stol ~2-1 and TVO free RIC8 (160.25 Ft above mean sea level). Total Dogleg for we[tpath is 0.00 degrees. Vertical section is from wellhead on azimuth 35.10 degrees. Catcutatio~ uses the minimize curvature method. Presented by Baker flughes IN?EQ UNOCAL STEELHEAD Ptatform,H-9 McArthur River Fietd~TBU, Cook Inlet, Ataska CLEARAaCE LISTING Page 16 Your ref : H-9 Version #10 Last revised : 28-Jun-96 Reference ~ellpath Object ~eLLpath : PGMS <O-7434'>,~M-13,STEELHEAO PLa[forth M.D. T.V.D. Horiz Nin'm TCy[ Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dis[ Dis[ 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 O.ON O.OE 0.0 7.9 12.3S 154.9~1 265.5 155.6 O.ON O.OE 92.0 99.9 12.3S 155.0~ 265.5 155.5' 155.5 O.ON O.OE 192.2 200.1 12.3S 155.0~/ 265.5 155.5' 155.5' O.ON O.OE 292.2 300.1 12.5S 154.8~ 265.4 155.3' 155.3' O.ON O.OE 392.0 400.0 12.85 154.8~ 265.3 155.3' 155.3' 500.0 600.0 700.2 800.6 901.4 500.0 600.0 700.0 800.0 900.0 O.ON O.OE 491.4 499.3 13.3S 155.0t~ 265.1 155.6 155.6 0.gN 1.5E 589.1 597.0 13.85 156.21~ 264.7 158.4 158.7 3.5# 6.1E 684.8 692.7 14.1LS 159.21~ 2~.7 166.5 167.5 7,9N 13.6E 780.2 78~.0 16.9S 164.3W 262.1 180,1 182.6 14.6N 24.4E 874.1 881.5 20.25 171.2W 259.9 199,5 205.2 .,~.:.., Oii ~... '-",'-::~ :"*' ° Comrc, lssiOfi &It ~ta is in f~t ~tess otherwise stat~. 6asi~ di~in are ~t i~t~. Ce~i~te fr~ stot ~2-1 ~ T~ fr~ R~ (1¢.25 Ft ~ve can sea [ever). Total O~t~ for ~[t~th is 0.~ ~r~. Vet[ica[ s~ti~ is fr~ ~tthe~ m azi~th 55.10 ~re~. Catcutati~ ~es the eini~ cu~ature mth~. Pres~t~ ~ Baker ~es INTEa UNOCAL STEELHEAO PLatform,M-9 McArthur River Fietd,TBU, Cook InLet, ALaska CLEAI~NCE LIST[NG Page 17 Your ref : N-9 Version #10 Last revised : 28-Jun-96 Reference ~eLtpath Object wettpath : PGNS <500-928'>,,B1-2,STEELHEAD PLatform Horiz Min'm TCyL M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Oist Oist 0.0 0.0 O.ON O.OE 0.2 0.2 70.ON 79.lN 311.6 105.6 105.6 100.0 100.0 O.ON O.OE 100.0 100.0 69.9N 79.1W 311.5 105.6' 105.6' 200.0 200.0 O.ON O.OE 200.3 200.3 69.714 ~9.1W 311.4 105.4' 105.4' 300.0 300.0 0.0# O.OE 300.4 300.4 69.3N 79.0U 311.2 105.1' 105.1' 400.0 400.0 O.ON O.OE 399.5 399.4 69.5# 78.6~ 311.5 105.0' 105.0' 500.0 500.0 O.ON O.OE 502.0 502.0 70.6N 78.2~1 312.1 105.4 105.4 600.0 600.0 0.9kl 1.5E 604.5 604.4 69.7N 74.0~ 312.3 102.2' 102.3' 700.2 700.0 3.5N 6.1E 702.9 702.7 70.2N 68.7~1 311.7 100.2' 100.2' 800.6 800.0 7.9N 13.6E 801.7 801.3 72.1N 64.71~ 309.4 101.3 101.3 901.4 900.0 14.6N 24.4E 903.3 902.9 F2.5N 61.6W 304.0 103.7 103.7 1003.2 1000.0 26.9N ~.gE 928.0 927.6 72.711 60.7~1 294.7 131.4 - ALL data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #B2-1 and TVD from RKB (160.Z5 Ft above mean sea LeveL). Total Oogteg for uettpath is 0.00 degrees. Vertical section is free ~etthead on azimuth 35.10 degrees. CaLcuLation uses the minimua curvature aethod. Presented by Baker Hughes INTEQ UNOCAL. STEELHEAD PLatform,#-9 McArthur River FieLd, TBUi Cook InLet, ALaska CLEANa~CE LIST]NG Page 18 Your ref : H-9 Version #10 Last revised : 28-Jun-96 Reference weL[path Object wetLpath : PGNS <O-5600~>,,N-5,STEELHEAD PLatform M.D. T.V.D. Rect Coordinates Horiz Minim TCyL M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 0.0 0.0# O.OE 100.0 100.0 0.0# O.OE 200.0 200.0 O.ON O.OE 300.0 300.0 O.ON O.OE 400.0 400.0 O.ON O.OE 0.0 7.9 0.BS 10.1g 265.5 12.9 - 92.1 100.0 0.SS 10.1W 265.5 10.2' 10.2 192.1 200.0 O.ILS 10.1g 265.6 10.2' 10.2' 292.1 300.0 0.8$ 10.1g 265.7 10.1' 10.1' 392.0 400.0 0.8S 10.21~ 265.3 10.2 10.2 500.0 500.0 O.ON O.OE 600.0 600.0 0.gN 1 .SE 700.2 700.0 3.5N 6.1E 800.6 800.0 7.9N 13.6E 901.4 900.0 14.6N 24.4E 492.0 499.9 1.OS lO.OW 264.8 10.7 10.7 592.0 599.9 1.1S 11.4~ 261.5 13.1 13.1 691.9 699.8 1.1S 12.4~ 255.9 19.0 19.1 791.7 799.7 1.1S 13.6~ 251.7 28.7 28.9 891.6 899.5 1.1S 14.814 248.2 42.2 42.7 1003.2 1000.0 26.9N 38.9E 1106.6 1100.0 45.7N 57.3E 1212.3 1200.0 71.2N 79.9E 1321.0 1300.0 104.0N IO?.OE 991.7 999.6 O.7S 15.9W 243.2 61.3 62.8 1092.0 1099.9 0.2N 16.6~ 238.4 86.8 90.4 1192.4 1200.4 1.ON 17.0t.I 234.1 119.7 127.5 1292.8 1300.7 2.1N 17.4W 230.7 160.8 176.6 Att data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #82-1 and TVD from RI(B (160.25 Ft above mean sea LeveL). Total DogLeg for ~e[tpath is 0.00 degrees. Vertical section is from weLLhead on azimuth 35.10 degrees. Ca[cu[al;ion uses the minim[aa curvature ~ethod. Presented by Baker Hughes ]NTEQ UNOCAL STEELHEAD Platform,M-9 NcArthur River Fie[d, TBU, Cook Inlet, Alaska CLEAIb, aCE LISTING Page 19 Your ref : #-9 Version #10 Last revised : 28-Jun-96 Reference we[[path Object wet[path : PNSS <6595-6988'>,,M-1~STEELHEAD Platform M.D. T.V.D. Horiz #in'm TCyL Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 O.ON O.OE 2.7 0.0 6.4N 6.3W 315.5 9.0 9.0 O.ON O.OE 102.7 100.0 6.ON 6.8~1 311.7 9.1 9.1 O.ON O.OE 202.7 200.0 5.2N 7.6~ 304.7 9.2 9.2 O.ON O.OE 302.7 300.0 4.6N 8.1W 299.7 9.4 9.4 O.ON O.OE 402.8 400.0 4.9N 8.214 300.7 9.5 9.5 500.0 500.0 600.0 600.0 700.2 700.0 800.6 800.0 901.4 900.0 O.ON O.OE 502.8 500.0 5.5N 7.5~ 306.2 9.3' 9.3' 0.gN 1.5E 602.8 600.0 5.9N 6.8~I 301.2 9.7 9.7 3.5N 6.1E 702.8 700.1 6.2N 6.3~ 282.2 12.7 12.7 7.9N 13.6E 803.0 800.2 7.4N 5.6~ 268.7 19.2 19.3 14.6N 24.4E 903.7 900.8 12.2N 4.1~ 265.1 28.6 28.7 1003.2 1000.0 1106.6 1100.0 1212.3 1200.0 1321.0 1300.0 1433.7 1400.0 26.911 38.9E 1005.3 1001.8 22.1N 1.71~ 263.1 40.9 41.3 45.711 57.3E 1108.6 1103.9 38.0N 2.0E 262.0 55.9 56.6 71.2N 79.9E 1214.4 1206.9 61.0N 7.2E 262.0 73.8 74.9 104.0N 107.0E 1324.0 1311.7 92.3N 14.9E 262.8 93.6 95.3 144.8N 139.1E 1436.2 1416.3 131.8N 24.1E 263.5 116.8 119.7 1551.7 1500.0 1676.7 1600.0 194.7ti 176.8E 1554.0 1522.8 180.8N 34.8E 264.4 144.5 148.9 255.2N 221.1E 1681.6 1633.7 242.3N 48.7E 265.7 176.1 181.8 Alask,:,' "Oil 8,. r,,:,,.,~.,.o 0o%.. C..ommisst[~r', Att data is in feet untess otherwise stated. Casing dimensions are not inctL_ded_. Coordinates from slot ~B2-1 and TVO from RKB (160.25 Ft above mean sea lever). Tota[ Oogteg for we[tpath is 0.00 degrees. Vertica[ sectio~ is froe ~ettheed o~ aziauth 35.10 degrees. Catcutatio~ uses the miniu curvature aethod. Presented by Baker Nughes I#?Ea UNOCAL STEELHEAD Platform, M-9 McArthur River Field, TBU, Cook Inlet, Alaska CLEARANCE LISTING Page 20 Your ref : M-9 Version #10 Last revised : 28-Jun-96 Reference we[lpath Object weLlpath : PGMS <O-7250'>,~M-lSt#1,STEELHEAO PLatform M.D. T.V.D. Horiz Hin'm TCyt Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 0.0 100.0 100.0 200.0 200.0 300.0 300.0 400.0 400.0 O.ON O.OE 2.7 0.0 6.4N 6.3W 315.5 9.0 9.0 O.ON O.OE 102.7 100.0 6.ON 6.8W 311.7 9.1 9.1 O.ON O.OE 202.7 200.0 5.2N 7.6W 304.7 9.2 9.2 O.ON O.OE 302.7 300.0 4.6N 8.1W 299.7 9.4 9.4 O.ON O.OE 402.8 400.0 4.9N 8.2W 300.7 9.5 9.5 500.0 500.0 600.0 600.0 700.2 700.0 800.6 800.0 901.4 900.0 O.ON O.OE 502.8 500.0 5.5N 7.5g 306.2 9.3' 9.3* 0.9N 1.5E 602.8 600.0 5.9N 6.814 301.2 9.7 9.7 3.5N 6.1E 702.8 700.1 6.2N 6.3~ 282.2 12.7 12.7 7.9N 13.6E 803.0 800.2 7.4N 5.614 268.7 19.2 19.3 14.6N 24.4E 903.7 900.8 12.2# 4.1~ 265.1 28.6 28.7 1003.2 1000.0 1106.6 1100.0 1212.3 1200.0 1321.0 1300.0 1433.7 1400.0 26.9N 38.9E 1005.3 1001.8 22.1N 1.714 263.1 40.9 41.3 45.7N 57.3E 1108.6 1103.9 38.0N 2.0E 262.0 55.9 56.6 71.2N 79.9E 1214.4 1206.9 61.0N 7.2E 262.0 73.8 74.9 104.0N 107.0E 1324.0 1311.7 92.3N 14.9E 262.8 93.6 95.3 144.8N 139.1E 1436.2 1416.3 131.814 24.1E 263.5 116.8 119.7 1551.7 1500.0 1676.7 1600.0 194.711 176.8E 1554.0 1522.8 180.8N 34.8E 264.4 144.5 148.9 255.2N 221.1E 1681.6 1633.7 242.3N 48.7E 265.7 176.1 181.8 Att data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from sLot #82-1 and TVO from RKB (160.25 Ft above mean sea level). Total Dogleg for wet[path is 0.00 degrees. Vertical section is from ~etthead on azimuth 35.10 degrees. Calculation uses the mini~uacurvaturemethed. Presented by Baker Hughes I#TEQ UNOCAL STEELHEN) Platform, N-9 #cArthur River Field,TBU, Cook Inlet, Alaska CLE~NCE LISTING Page 21 Your ref : #-9 Versio~ #10 Last revised : 28-Jun-96 Reference wel lpath Object ~ettpath : PGNS <O-7419'>,,#-2,STEELHEAD Platform M.D. T.V.D. Horiz #in'm TCyt Rect Coordinates M.D. T.V.D. Rect Coordfnates Bearing Dist Dist 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 O.ON O.OE 2.7 0.0 7.]S 5.2W 215.5 9.0 9.0 O.ON O.OE 102.8 100.0 7.5S 5.1~ 214.2 9.0 9.0 O.ON O.OE 202.8 200.0 7.7S 4.6Q/ 210.9 8.9* 8.9* O.ON O.OE 302.8 300.0 7.45 4.~ 209.7 8.5* 8.5' O.ON 0.0£ 402.7 4OO.O 7.OS 4.L~ 211.0 8.2* 8.2* 500.0 600.0 700.2 800.6 901.4 500.0 600.0 700.0 800.0 900.0 O.ON O.OE 502.7 499.9 7.3S 4.7W 212.6 8.7 8.7 0.gfl 1.5E 602.7 599.9 7.9S 5.214 217.2 11.1 11.1 3.5# 6.1E 702.6 699.8 8.7S 5.6~ 2~.7 16.9 16.9 7.9N 13.6E 802.0 799.2 11.0S 5.9~1 225.9 27.2 27.4 14.6N 24.4E ~;~)0.7 897.7 16.9S 5.4~ 223.4 43.4 44.3 1003.2 1106.6 1212.3 1000.0 1100.0 1200.0 26.9N 38.9E 998.4 994.8 27.2S 2.81~ 217.6 68.5 71.9 45.7N 57.3E 1088.4 1083.4 42.6S 1.0E 212.5 106.0 118.2 71.2N 79.9E 1175.9 1168.3 63.4S 5.7E 208.9 156.9 188.4 Att data is in feet unless otherwise stated. /.;,i]CiiO!'2,~O Casing dimensions are not included. Coordinates from slot ~82-1 and fro free RKIt (160.25 Ft above mean sea I. evet). Total Dogleg for ~ettpath is 0.00 degrees. Vertical section i~ from ~etthead on azteuth 35.10 degree~. Calculation uses the einiaMa curvature ~ethod. Presented by Baker Hughes I#TEQ UNOCAL STEELHEAD PLatform,N-9 McArthur River FieLd, TBU, Cook Inlet, ALaska CLEARANCE L]ST]NG Page 22 Your ref : M-9 Version #10 Last revised : 28-Jun-96 Reference ~eLtpath Object weltpath : GSS <O-1421'>,o*M-4*,STEELHEAD Platform Horiz #in'm TCyt M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Oist Oist 0.0 0.0 O.ON O.OE 0.0 0.0 4.ON 1.71~ 337.5 4.3 4.3 100.0 100.0 O.ON O.OE 100.0 100.0 4.ON 1.?U 337.5 4.3 4.3 200.0 200.0 O.ON O.OE 200.0 200.0 &.ON 1.7U 337.5 4.3 4.3 300.0 300.0 O.ON O.OE 300.0 300.0 4.ON 1.7U 337.5 4.3 4.3 400.0 400.0 O.ON O.OE 400.0 400.0 3.3# 2.0~ 328.4 3.8* 3.8* 500.0 500.0 O.ON O.OE 500.0 500.0 2.2N 2.2U 314.7 3.1' 3.1' 600.0 600.0 0.91t 1.5E 600.0 599.9 4.1N 0.9~1 323.3 4.0 4.0 700.2 700.0 3.5N 6.1E 699.9 699.7 9.ON 0.4E 314.2 8.0 8.0 800.6 800.0 7.9ti 13.6E 800.2 799.7 16.6N 2.9E 309.1 13.8 13.8 901.4 900.0 14.6N 24.4E 900.6 899.6 25.4N 6.5E 301.2 20.9 21.0 1003.2 1000.0 26.9N 38.9E 1001.7 1000.1 36.2N 10.4E 288.0 29.9 30.1 1106.6 1100.0 45.7N 57.3E 1104.3 1101.5 50.9N 15.3E 277.1 42.3 42.7 1212.3 1200.0 71.2N 79.9E 1209.9 1204.8 71.6N 22.5E 270.4 57.6 58.3 1321.0 1300.0 104.0N 107.0E 1317.5 1309.0 96.8N 32.2E 264.5 75.7 77.1 1433.7 1400.0 144.8N 139.1E 1421.0 1407.9 125.6N 41.7E 258.8 99.6 - 1551.7 1500.0 194.7N 176.8E 1421.0 1407.9 125.6N 41.7E 242.9 177.5 Att data is in feet ca~tess otherwise stated. Casing dimensions are not included. Coordinates from slot #B2-1 and TVD from REIi (160.25 Ft above mean sea Level). Total Dogleg for ~etLpath is 0.00 degree~. Vertical section is from ~etthead on azimuth 35.10 degrees. Calculation uses the mtniu curvature method. Presented by Baker llughes INTEG UNOCAL STEELHEAO Platform,M-9 McArthur River Fie[d,TBU, Cook Inlet, Alaska CLEARANCE LISTING Page 23 Your ref : #-9 Version #10 Last revised : 28-Jta¥96 Reference weLLpath Object ~ettpath : PGNS <O-6440'>,,#-7, STEELHEAD Ptatform N.D. T.V.D. Rect Coordinates Horiz Nin'm TCyL M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 0.0 100.0 100.0 200.0 200.0 300.0 300.0 400.0 400.0 O.ON O.OE O.ON O.OE O.ON O.OE O.ON O.OE O.OH O.OE 0.0 0.0 5.2N 10.91~ 295.5 12.1 12.1 100.1 100.1 4.6N 10.6W 293,2 11.6' 11.6' 200.0 200.0 3.7N 10.1W 290,3 10.7. 10.7' 299.9 299.9 3.5N 10.1~ 289.2 10.7' 10.7' 399.8 399.8 3.6N 11.0U 288,1 11.6 11.6 500.0 500.0 600.0 600.0 700.2 700.0 800.6 800.0 901.4 9O0.0 O.ON O.OE 0.gN 1.5E 3.5N 6.1E 7.9N 13.6E 14.6N 24.4E 499.8 499.8 4.9N 12.L~ 291,9 13.2 13.2 599.9 599.7 lO.ON 11.1~ 305,7 15.6 15.6 699.2 698.3 20.6N 6.5~ 323,6 21.3 21.3 798.0 795.4 37.1N 1.1E 336.8 32.2 32.5 896.3 890.8 58.8N 11.4E 343.7 47.0 47.5 1003.2 1000.0 26.9N 38.9E 1106.6 1100.0 45.7N 57.3E 1212.3 1200.0 71.2N 79.9E 1321,0 1300.0 104.0N 107.0E 1433.7 1400.0 144.8N 139.1E 995.9 986.1 84.2N 24.2E 345,6 60.7 61.2 1097.5 1082.3 112.9N 40.1E 345,7 71.6 71.9 1200.6 1178.4 144.7N 59.5E 344.5 79.3 79.4 1306.3 1275.2 180.8N 81.8E 341.8 84.5 84.6 1416.1 1373.3 222.7N 107.6E 338.0 88.2 88.2 1551.7 1500.0 194.711 176.8E 1676.7 1600.0 255.2N 221.1E 1811.4 1700.0 328.7N 273.3E 1960.0 1800.0 418.9N 336.0E 2130.3 1900.0 532.9N 413.3E 1529.9 1471.8 271.2N 137.8E 332.9 90.4 90.4 1650.1 1570.6 329.4N 173.7E 327.4 92.8 92.8 1781.1 1672.8 399.6N 215.9E 321.0 95.2 95.2 1926.0 1779.9 483.8N 264.9E 312.4 98.3 98.4 2093.1 1895.9 588.1N 324.9E 302.0 104.3 104.5 2329.1 2000.0 675.8N 508.6E 2530.9 2100.0 821.8N 605.7E 2732.8 2200.0 967.8N 702.8E 2934.6 2300.0 1113.8N 799.9E 3136.4 2400.0 1259.711 897.0E 2289.6 2022.3 718.4N 400.1E 291.4 118.6 119.1 2491.4 2142.0 859.0N 481.4E 286.7 136.4 136.9 2694.4 2256.3 1004.5N 564.8E 284.9 153.5 153.9 2899.0 2361.5 1157.4N 650.8E 286.3 167.1 167.4 3102.0 2459.8 1312.3N 737.9E 288.3 177.9 178.2 3338.3 2500.0 3540.1 2600.0 1405.731 1551.7tl 994.1E 3303.4 2555.3 1466.9N 824.8E 289.9 188.4 18~.6 1091.3E 3503.6 2653.9 1618.1N 911.2E 290.3 199.4 1~.7 RE, CEiVED ~tt data is in feet untess other.ise stated, Casing diaensions are not inctuded. Coordinates from stot #B2-1 and TVO from RKB (160.25 Ft above mean sea fever). Total Oogteg for ~ettpeth is 0.00 degrees. Vertical section is from ~etthead on azieuth 35.10 degrees. Catcutation uses the minimtza curvature aethod. Presented by Baker Hughes I#TEQ UNOCAL STEELHEAO Platform, M-9 McArthur River Field,TBU, Cook Inlet, Alaska CLEAR^NCE LISTING Page 24 Your ref : M-9 Versioo #10 Last revised : 28-Ju~-96 Reference welLpath ~oject wetlpath : PGMS <O-7250'>,,M-3,STEELHEAD Platform M.D. T.V.D. Horiz Min'm TCyL Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 O.ON O.OE 0.0 0.0 3.4S 5.6W 238.7 6.5 6.5 O.ON O.OE 100.0 100.0 3.6S 5.5'd 237.1 6.6 6.6 O.ON O.OE 200.0 200.0 3.9S 5.5W 234.4 6.7 6.7 O.ON O.OE 299.9 299.9 4.4S 5.6QI 231.9 7.1 7.1 O.ON O.OE 399.8 390.8 5.6S 6.1W 227.6 8.3 8.3 500.0 500.0 600.0 600.0 700.2 700.0 800.6 800.0 901.4 900.0 O.ON O.OE 499.8 499.8 7.7S 7.OW 222.4 10.4 10.4 0.9N 1.5E 599.8 599.7 10.1S 7.6W 219.9 14.3 14.3 3.5N 6.1E 699.7 699.6 12.5S 8.OW 221.3 21.3 21.4 7.9N 13.6E 799.5 799.4 14.9S 8.4W 224.1 31.7 32.0 14.6N 24.4E 899.4 899.3 17.0S 9.OW 226.6 46.0 46.7 1003.2 1000.0 1106.6 1100.0 1212.3 1200.0 1321.0 1300.0 26.9N 38.9E 999.5 999.3 18.6S 9.5W 226.7 66.5 68.3 45.7N 57.3E 1099.5 1099.3 19.7S 9.8W 225.7 93.7 98.1 71.2N 79.9E 1199.5 1199.3 20.4S 10.1W 224.5 128.4 137.7 104.0N 107.0E 1299.4 1299.3 20.7S 10.4W 223.3 171.3 189.7 dUL i 9 i!}96 · . A!ask~ Oil & C:?,s C;cms. Att data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #B2-1 ar~ TVt) from RKB (1~).25 Ft above mean sea level). Total Dc~lteg for wettpath is 0.00 degrees. Vertical section is from wellhead on azimuth 35.10 degrees. calculation uses the minimtm curvature mthed. Presented iff Baker #ughes INTEO UNOCAL STEELHEAD PLatform,N-9 McArthur River Fietd,TBU, Cook Inter, Alaska CLEARAa~E LISTING Page 25 Your ref : M-9 Version #10 Last revised : 28-Jun-96 Reference ~elLpath Object ~eLLpath : PMSS <10247-10355'>,,M-31,STEELHEAD Ptatform M.D. T.V.D. Horiz Min'm TCyt Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 O.ON O.OE 0.1 0.1 65.5N 86.0~1 307.3 108.1 108.1 O.ON O.OE 100.3 100.3 65.3N 85.9"d 307.2 107.9' 107.9' O.ON O.OE 200.1 200.1 65.2N 85.8~ 307.2 107.8' 107.8' O.ON O.OE 300.5 300.5 65.0# 85.71~ 307.2 107.6' 107.6' O.ON O.OE 401.0 401.0 63.9N 85.9~/ 306.6 107.0' 107.0' 500.0 600.0 700.2 800.6 901.4 500.0 600.0 700.0 800.0 900.0 O.ON O.OE 501.1 501.0 62.3N 85.8~ 306.0 106.0' 106.0' 0.gN 1.5E 600.0 600.0 61.0N 85.8W 304.6 106.0 106.1 3.5# 6.1E 698.7 698.7 59.9t4 86.8~ 301.3 108.7 108.8 7.9N 13.6E 796.0 795.9 59.4N 89.6~ 296.5 115.5 116.0 14.6N 24.4E 893.7 893.5 59.7N 94.4W 290.8 127.3 128.5 1003.2 1106.6 1212.3 1000.0 1100.0 1200.0 26.914 38.9E 991.9 991.5 60.5N 100.1W 283.6 143.2 145.6 45.7N 57.3E 1090.8 1090.3 62.1N 105.814 275.8 164.3 168.9 71.2H 79.9E 1192.8 1192.1 65.4N 110.9~ 268.2 191.1 199.0 fi !rr:IVED JUl_ Att data is in feet unless otherwise stated. Casingdimensior~ are not included. Coordinates from stot ~2-1 and ?VO from RICB (160.25 Ft above mean sea teve[). Total Oogteg for ~e[tpath is 0.00 degrees. Vertical section is fr~ ~et[head on azimuth 35.10 degrees. Catcutati~lases the mini~ curvature eethod. Presented by Baker Hughes I#TEQ UNOCAL STEELHEAD Platform,#-9 NcArthur River Field, TBU, Cook Inlet, Alaska CLEAraNCE LISTING Page 26 Your ref : #-9 Version #10 Last revised : 28-Jun-96 Reference we[ [path Object we[[path : PNSS <lO741-12018'>,,#-31St#1,STEELHEAD Platform M.D. T.V.D. Horiz Min'm TCy[ Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Oist Oist 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 O.ON O.OE 0.1 0.1 65.5N 86.01,1 307.3 108.1 108.1 O.ON O.OE 100.3 100.3 65.3N 85.9'd 307.2 107.9' 107.9' O.ON O.OE 200.1 200.1 65.2N 85.814 307.2 107.8' 107.8' O.ON O.OE 300.5 300.5 65.0N 85.7t/ 307.2 107.6' 107.6' O.ON O.OE 401.0 401.0 63.9N 85.9t4 306.6 107.0' 107.0' 500.0 600.0 700.2 800.6 901.4 500.0 600.0 700.0 800.0 900.0 O.ON O.OE 501.1 501.0 62.3N 85.8~ 306.0 106.0' 106.0' O.gN 1.5E 600.0 600.0 61.0N 85.814 304.6 106.0 106.1 3.5N 6.1E 698.7 698.7 59.9N 86.814 301.3 108.7 108.8 7.9fl 13.6E 796.0 795.9 59.4N 89.614 296.5 115.5 116.0 14.6N 24.4E 893.7 893.5 59.7N 94.4W 290.8 127.3 128.5 1003.2 1106.6 1212.3 1000.0 1100.0 1200.0 26.914 38.9E 991.9 991.5 60.5N 100.1W 283.6 143.2 145.6 45.71t 57.3E 1090.8 1090.3 62.1N 105.8W 275.8 164.3 168.9 71.2N 79.9E 1192.8 1192.1 65.4N 110.91~ 268.2 191.1 199.0 Att data is in feet untess otherwise stated. Casing dimensions are not inctuded. Coordinates from stot #B2-1 and TVD from RK8 (160.25 Ft abovemean sea fever). ?otat Dogleg for we[tpath is 0.00 degrees. Verticat section is from ~etthead on azimuth 35.10 degrees. Catcu[ation uses the minimu~ curvature ~ethed. Presented by Baker Hughes INTEQ UNOCAL STEELHEAD Platform,M-9 #cArthur River Fie[d, TBU, Cook Inlet, Ataska CLEAk~,CE LISTING Page 27 Your ref : H-9 Version #10 Last revised : 28-Jun-96 Reference ~eLLpath Object weLLpath : P#SS <9~5 - 1058~I>,,FLT2ST#1,STEELHEAD PLatform M.D.T.V.D. Horiz Minim TCyL Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 O.Og O.OE 0.1 0.1 66.4N 80.6U 309.5 104.4 104.4 O.ON O.OE 100.2 100.2 66.2N 80.7U 30~.4 104.4' 104.4' O.ON O.OE 200.3 200.3 66.0N 80.5W 309.3 104.1' 104.1' O.ON O.OE 300.4 300.4 65.~ 80.4W 309.2 103.8' 103.8' O.ON O.OE 402.2 402.2 64.3N 79.81,1 308.9 102.5' 102.5' 500.0 600.0 700.2 800.6 901.4 500.0 600.0 700.0 800.0 900.0 O.ON O.OE 500.9 500.9 62.0N 79.3W 308.0 100.6' 100.6' 0.gfl 1.5E 600.7 600.7 61.1N 78.9W 306.8 100.4' 100.4' 3.5N 6.1E 701.6 701.5 60.1N 78.5W 303.8 101.8 101.8 7.9fl 13.6E 801.6 801.5 58.5N 77,7U 299.0 104.5 104.6 14.6N 24.4E 901.0 900.9 57.2N 77.011 292.8 110.0 110.3 1003.2 1106.6 1212.3 1321.0 1000.0 1100.0 1200.0 1300.0 26.9g 38.9E 1001.2 1001.1 56.2N 76.4~ 284.3 118.9 119.7 45.hl 57.3E 1099.1 1099.0 54.7N 76.71,1 273.9 134.3 136.9 71.2N 7~.9E 1199.7 1199.5 51.714 76.9g 262.9 158.0 164.6 104.0N 107.0E 1296.6 1296.4 47.2N 77.1W 252.8 192.7 208.7 ,JUL. Alaska Oil & Gas Cons, commission /k[~'~ ...... ALt data is in feet ~[ess otherwise stated. Casing dimensions are not included. Coordinates from stot #B2-1 and TVT) from RKB (160.25 Ft above mean sea revel). Total Dogleg for ~e[tpath is 0.00 degrees. Vertical section is from ~etthead on azimuth 35.10 degrees. CaLcuLation uses the minimtza curvature method. Presented by Baker Hughes INTEG UNOCAL STEELHEAD Ptatform, H-9 HcArthur River Field,TBU, Cook inlet, Alaska CLEARANCE LISTING Page 28 Your ref : M-9 Versio~ #10 Last revised : 28-Jun-96 Reference ~etLpath Object wettpath : PMSS <1386 - 9833'>,,M-32,STEELHEAD PLatform H.D. T.V.D. Horiz Hin'm TCy[ Rect Coordinates H.D. T.V.D. Rect Coordinates Bearing Dist Dist 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 400.0 O.ON O.OE 0.1 0.1 66.4N 80.614 309.5 104.4 104.4 O.ON O.OE 100.2 100.2 66.2N 80.7~ 309.4 104.4' 104.4' O.ON O.OE 200.3 200.3 66.0N 80.5W 309.3 104.1' 104.1' O.ON O.OE 300.4 300.4 65.7N 80.4W 309.2 103.8' 103.8' O.ON O.OE 402.2 402.2 64.3N 79.81,/ 308.9 102.5' 102.5' 500.0 600.0 700.2 800.6 901.4 500.0 600.0 700.0 800.0 900.0 O.ON O.OE 500.9 500.9 62.0N 7~.3~ 308.0 100.6' 100.6' 0.gN 1.5E 600.7 600.7 61.1N 78.91~ 306.8 100.4' 100.4' 3.5N 6.1E 701.6 701.5 60.1N 78.5W 303.8 101.8 101.8 7.9N 13.6E 801.6 801.5 58.5N 77.7g 299.0 104.5 104.6 14.6N 24.4E 901.0 900.9 57.2N 77.0g 292.8 110.0 110.3 1003.2 1106.6 1212.3 1321.0 1000.0 1100.0 1200.0 1300.0 26.9N 38.9E 1001.2 1001.1 56.2N 76.4W 284.3 118.9 119.? 45.7N 57.3E 1099.1 1099.0 54.7N 76.7~/ 273.9 134.3 136.9 71.2N 79.9E 1199.7 1199.5 51.7N 76.9t4 262.9 158.0 164.6 104.0N 107.0E 1~6.6 1296.4 47.2N T'/'.lW 252.8 192.7 208.7 Att data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #B2-1 and TVO from RKB (160.~5 Ft above mean sea LeveL). Total Dogleg for ~ettpath is 0.00 degrees. Vertical section is froa ~elLhead on azt~Jth 35.10 degrees. CaLcuLation uses the minieua curvature ~ethod. Presented by Baker Hughes I#TEQ UNOCAL STEELHEAO Platform,#-9 HcArthur River FieLd,TBU, Cook Inlet, ALaska CLEAkANCE LISTING Page 29 Your ref : H-9 Version #10 Last revised : 28-Jun-96 Reference ~eLLpath Object weLLpath : PHSS <~958 - 1258~">,,I~2St#2,STEELHEAO PLatform M.D.T.V.O. tloriz #in'e TCyL Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Otst Dist 0.0 100.0 200.0 300.0 0.0 100.0 200.0 300.0 0.0# O.OE 0.1 0.1 66./*# 80.~ 30~.5 104.4 104.4 O.ON O.OE 100.2 100.2 66.21~ 80.71,1 309.4 104.4' 104.4' O,ON O.OE 200.3 200.3 66.0N ~).SW 309.3 104.1' 104.1' O.OH O.OE 300./, 300.4 65.7~ 80.4',,I 30~.2 103.8' 103.8' O.ON O.OE 402.2 402.2 64.3# 79.8~ 308.9 102.5' 102.5' 500.0 600.0 700.2 800.6 901 .& 500.0 600.0 700.0 800.0 900.0 O.ON O.OE 500.9 500.9 62.0N 79.3W 308.0 100.6' 100.6' O.9fl 1.5E 600.7 600.7 61.1N 78.9~1 306.8 100./** 100.4' 3.5N 6.1E 701.6 701.5 60.1N 78.5~ 303.8 101.8 101.8 7.9ti 13.6E 801.6 801.5 58.5N 77.71~ 299.0 104.5 104,6 14.6N 24.4E 901.0 900.9 57.2N 77.01~ 292.8 110.0 110,3 1003.2 1106.6 1212.3 1321.0 1000.0 1100.0 1L=~30.0 1300.0 26.9ti 38.9E 1001.2 1001.1 56.2N 76.4W 284.3 118.9 119.7 45.711 57.3E 1099.1 1099.0 54.7N 76.71,1 273.9 134.3 136.9 71.2N 79.9E 1199.7 1199.5 51.711 76.9~1 262.9 158.0 164.6 104.0# 107.0E 1296.6 1296.4 47.2N 77.1~ 252.8 192.7 208.7 RECEIVED JUl_ ALL data ia in feet mLe~s otheruise stated. Casing diaensiona are not included. Coordinate free slot I~.-1 and TVO free ~ ¢160.~ Ft above eean sea Level). Total Dogleg for ~eilpeth is 0.00 dagreee. Vertical sectten is fre~ ~eLlhead en ezteuth ~5.10 degree~. CaLcuLstton ~ the einleue curvature mthod. Prezented by Baker Hu~ez IlITEa UNOCAL STEELHEAO PLatform,M-9 McArthur River FieLd,TBU, Cook InLet, ALaska CLE~LaJICE LISTING Page 30 Your ref : ~!-9 Version #10 Last revised : 28-Jun-96 Reference ~et ,path Object weLLpath : PGHS <O-927'>,,81-10,STEELHEAD P[atfore Horiz Nin'm TCyL #.O. T.V.D. Rect Coordinates M.D. T.V.O. Rect Coordinates Bearing Dis, Dis, 0.0 0.0 0.0# O.OE 0.1 0.1 66.4N 80.6~ 309.5 104.4 104.4 100.0 100.0 O.ON O.OE 100.2 100.2 66.2N 80.71~ 309.4 104.4' 10~.4' 200.0 200.0 0.1311 O.OE 200.3 200.3 66.0N 80.5~1 :~9.3 104.1' 104.1' 300.0 300.0 O.ON O.OE 300.4 300.4 65.7N 80,61~ 309.2 103,8' 103.8' 400.0 400.0 0.0# O.OE 402.2 402.2 64.3N 79.8~/ 308.9 102.5' 102.5' 500.0 500.0 O.ON O.OE 500.9 500.9 62.0N 79.:~1 308.0 100.6' 100.6' 600.0 600.0 O.9fl 1.5E 600.7 600.7 61.1N 78.9~1 306.8 100.4' 100.4' 700.2 700.0 3.5N 6.1E 701.6 701.5 60.1N 78.5W 303.8 101.8 101.8 800.6 800.0 7.9tl 13.6E 801.6 801.5 58.5N 77.7t/ 299.0 104.5 10~.6 901.4 900.0 14.6N 24.4E 901.0 900.9 57.2N 77.0t~ 292.8 110.0 110.3 1003.2 1000.0 26.9N 38.9E 927.0 926.9 56.9N 76.9~1 284.5 140.2 At[ data is in feet un,ess otherwise stated. Casing dimemions ere not inc[u~bd. Coordinate~ fro~ .lot ~i2-1 and TVI) frma RICB (160.~ Ft above mean sea Level). Toter DogLeg for .ettpath ts 0.00 degree. Vertical ~ectton ia rrm. ~eiihead on ezteutk 35.10 degree~. Cetc~tsl;iOfl tines the mintu curvoure method. Presented by Baker Hughes I MTB{ U14OCAL STEELHEAD Platform,#-9 NcArthur River FieLd,TBU, Cook Inlet, ALaska CLEARANCE LISTI14G Page 31 Your ref : N-9 Version #10 Last revised : 28-J~-96 Reference ~eL[path Object wellpath : PMSS <12281 - 12660'>,,M32StfS,STEELHEAD Platform H.D, T.V,D. Horiz Nin'm TCyt Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Oist 0.0 100.0 200.0 300.0 400.0 0.0 100.0 200.0 300.0 4O0.O O.ON O.OE 0.1 0.1 66,414 80.6U 309.5 104.4 1C~.4 O.ON 0.0~ 100.2 100.2 66.214 80.71~ 309.4 104.4' 104.4' O.ON O.OE~ 200.3 200.3 66.0N 80.5W 309.3 104.1' 10~.1' O.ON O.OE 300.4 300.4 65.7N 80.4W 309.2 103.8' 103.8' O.ON O.OE 402.2 402.2 64.314 79.8U 308.9 102.5' 102.5' 500.0 500.0 600.0 600.0 700.2 700.0 800.6 800.0 901.4 900.0 0.014 O.OE 500.9 500.9 62.0N 79.3W 308.0 100.6' 100.6' 0.911 1.5E 600.7 600.7 61.1N 78.g'd 306.8 100.4' 100.&* 3.5N 6.1E 701.6 701.5 60.1N 78.5~ 303.8 101.8 101.8 7.~N 13.6E 801.6 801.5 58.514 T7.71~ 299.0 104.5 104.6 14.6N 24.~E 901.0 900.9 57.2N 7T.OW 292.8 110.0 110.3 1003.2 1000.0 1106.6 1100.0 1212.3 1200.0 1321.0 1300.0 26.~1 38.9E 1001.2 1001.1 56.2N 76.4W 284.3 118.9 119.7 45.714 57.3E 1099.1 1099.0 54.7]4 76.7~/ 273.9 134.3 136.9 71.214 79.9E 1199.7 1199.5 51.7N 76.9~ 262.9 158.0 164.6 104.014 107.0E 1296.6 1296.6 47.214 77.1~ 252.8 192.7 208.7 ALL data is in feet unless otherwise stated. Ca~ing dieensier~ are not included. Coordinate~ from clot ~-1 ~ TVD fro~ RKB (160.25 Ft above man sea level). Tote& Dogleg for ueLtpath is 0.00 degrees. Vertical section i$ free metLhead on aziauth 35;10 degrees. Ca[~u[iti~n Us~ the ainiu curvature method. preeanted by Baker Hughes I#TEG DRILLING FLUIDS M-I Drilling Fluids L.L.C. C . . . , . DEPTH INTERVAL UNOCAL STEELHEAD PLATFORM WELL M-9 0-+ 850' TMD 17-1/2" HOLE 13-3/8" CASING MUD TYPE GENERIC MUD ~2 MUD ADDITIVES POTENTIAL PROBLEMS M-I GEL / M-I BAR / SODA ASH / CAUSTIC SODA / LIME / NUT PLUG / KVVIK SEAL HOLE CLEANING i GRAVEL / GAS KICK / LOST CIRCULATION TREATM ENTSIPROCEDU RES Build spud mud system with prehydrated bentonite in fresh water and fleered inlet water. Build mud weight to 9.3 ppg with Barite. Lost circulation is a potential problem. An LCM pill made with nut plug mica, and Kwik-Seal should be available if required. Drill hole. Adjust viscosity as required. K.O.P. @ 5(X)'. Ddll to :!: 850'. Use all solids control equipment. Raise viscosity if gravel sections are encountered. Spot LCM pill pdor to running 13-3/8" casing. 4. Recycle mud for 12-1/4" interval. ANTICIPATED SPUD MUD PROPERTIES':'.:: Mud Density 9.3 - 9.4 ppg Funnel Viscosity 44 - 100 sec/qt Plastic Viscosity 10 - 15 cps Yield Point 10 - 30 ~100 ft= Gels 8- 20 Fluid Loss (APl) No Control pH 8.5 - 9.5 NOTE: DO NOT EXCEED M.A.C. of products or use products not approved in the discharge permit. See letter requesting authorization for list of approved products and M~.C. C~ DRILLING FLUIDS M-I Drilling Fluids L.L.C.. UNOCAL STEELHEAD PLATFORM WELL M-9 DEPTH INTERVAL MUD TYPE MUD ADDITIVES POTENTIAL PROBLEMS + 850' - + 1500' ( 1455' 'I'VD) 12-1/4" HOLE 9-5/8" LINER GENERIC MUD #2 M-I GEL / M-I BAR / SODA ASH / POLY- PAC / SPERSENE / SODIUM BICARBONATE / CAUSTIC SODA I FLO-VIS HOLE CLEANING / TIGHT HOLE / BIT BALLLING / GUMBO CLAYS / HOLE ENLARGEMENT I GAS KICKS I COAL SLOUGHING O MI4~$ 'I'REATMENTS/PROCEDURES 10. 1. Drill the 13-3/8" collar, cement and shoe. Treat this fluid as required to avoid excessive cement contamination. Maintain mud weight at minimum 9.2 ppg. 2. Build additional volume as required with prehydrated bentonite in fresh water and filtered inlet water. 3. Pump viscous sweeps if required by hole conditions. 4. Control density with barite, F,I.W., and solids control equipment. Dump all sand traps as required. 5. Report drill solids analysis on mud check sheet. 7. Use Defoam-X if foaming becomes a problem. 8. Prehydrate all bentonite in fresh water. 9. Drill to T.D. If hole conditions warrant, spot a viscous pill on bottom. Spot LCM pill prior to running 9-,5/8" liner. Evaluate quality of mud and save for reuse in the 8-1/2" interval, p~ E C E IV E [~ C. DRILLING FLUIDS M-! Drilling Fluids L.LC. ANTICIPATED 12'114" MUD PROPERTIES Mud Density Funnel Viscosity Plastic Viscosity Yield Point Gels Fluid Loss (APl) pH MBT Drilled Solids 9.2 - 9.6 ppg 40- 70 sec/~ 10 - 15 cps 10 - 20 ~/100 fff 6/12/18 No Control to 8cc 8.5 - 11.0 < 30 ppb < 75 ppb NOTE: This mud program is a guideline only. Hole conditions should dictate actual mud properties. DO NOT exceed M.A.C. of products or use products not approved in the discharge permit. See letter requesting authorization of list of approved products and M.A.C. DRILLINI FLUID5 M-I Drilling Fluids L.L.C. UNOCAL STEELHEAD PLATFORM WELL M-9 DEPTH INTERVAL 1500'- 4800' (324(7 TVD) 8-1/2' HOLE 62° HOLE ANGLE MUD TYPE GENERIC MUD #2 MUD ADDITIVES POTENTIAL PROBLEMS M-I GEL / M-I BAR I SODA ASH / POLYPAC I FLO-VIS I SODIUM BICARBONATE / RESINEX I SOLTEX I SPERSENE / CAUSTIC SODA/LCM MATERIAL / DEFOAM X I LUBE 167 / PHPA HOLE CLEANING/TIGHT HOLE/BIT BALLINGISLOUGHING COAL/GAS KICKS/HOLE ENLARGEMENT TREATMENTS/PROCEDURES 1. Treat system for cement contamination. Evaluate mud from 12-114" interval. Build new mud if ddlled solids are excessive. Maintain mud weight at minimum 9.0 ppg. Convert mud to PHPA mud system for additional inhibition. 2. High hole angles (62°) increase the probability of cuttings bed formation. Elevated Iow shear rate rheologies can be increased to inhibit the formation of ct~ngs beds. Maintain 3 rpm readings - >10. If cutting beds form rotation and reciprocation are the most effective method of removal. NOTE: High Iow shear rate theologies can entrain gas. Extra care should be taken while drilling, circulating, and tripping through these gas sands. Sloughing coal beds may be a problem. The addition of Soltex and Resinex has proven benef'mial in minimizing these problems in Cook Inlet. 4. Drill to T.D. Run 7' liner. DRILLING FLUIDS M-I Drilling Fluld~ L.L.C. 8-112" ANTICIPATED MUD PROPERTIES Mud Weight ppg Funnel Viscosity Plastic Viscosity YP Gels 3 rpm Fluid Loss (APl) Fluid Loss (HPHT) pH MBT Drilled Solids m 9.0- 9.6 ppg 40- 70 sec/qt 10 - 15 cps 10 - 20 #/100 ftz 6/12/18 >10 #15 cc 8.5 - 11.0 < 30 ppb < 75 ppb NOTE: This mud program is a guideline only. Hole conditions should dictate actual mud properties. DO NOT exceed M.A.C. of products or use products not approved in the discharge permit. See letter requesting authorization of list approved products and M.A.C. Plan View STEELHEAD PLATFORM DIVERTER SYSTEM Rig Subatructure N~ 16' Oiverter Line Section View 15' Remote OI)eratecI Bail Valve Concluctor Rlaer ....j 29-1/24 500 I~sl Fla FilIL .... a ~ Flow Line Hydrtl 18-3/4° 5000 Type GK Annular Kill Line 1~-314° 10,000 osJ Doublegate Checl~ Valve Plpe Rama Blind Choke Line Gate Valve Gate Valve I Pipe Rime Gate VIIvi HCR Valve 16-3/4' 10.000 Oal Singlegate STEELHEAD PLATFORM Preventer Schematic 16-:~14' 5000 pti Rlaer RECEIVED JUt. 1 9 199~ / Alask~ Oil & (~; Co,~. (~o,TimlSslon B~II ~1~ STEELHEAD PLATFORM CHOKE MANIFOLD , TO GAS B~STER TO DERRICK VENT TO SHALE SHAKERS · CHOKE LI.E -i~ I ALL VALVES IN FLOW PATH ARE 3-1/10' 5OOO PSI CAMERON GATE ,TYPE SECTION AA CENTRIFUGE CLEANER DESANDER ~ DESANDER -- CLEAN£R PIT ~, PIT A PIT PIT ~ PIT 100 Bbll 100 IbM CCI)," 113 Bb~ ~lp*//' 113 Bble 105 Bble/~ 1.O~ IM~/M '[ ~ RESERVE PIT ,i ..... lot Bbll tip I o~ o~ o ,..,.-~ o o ~o ..~~.__ ~ ........ . .... ~ ~ ~ ~~~. o I'1 o 1.08 Iblu/~ [ ~ 3,05 gble/I. I~. MIX PIT PILL PIT 8~ Bblo Cop ~O eblo O.TY Bblu/M 0.76 0 0 0 0 ........ MUD RETURN DITCH I EQUALIZER AGITATOR MUD GUN STEELHEAD PLATFORM MUD PIT LAYOUT STEELHEAD PLATFORM WELL # M-9 TRADING BAY UNIT ROTARY KELLY BUSHING (RKB) Elev. 160' DRILL DECK LEVEL Elev. 126' PRODUCTION DECK LEVEL Elev. SEA LEVEL (MLLW) Elev. 0' MUD LINE Elev. - 187' 28" Structural Casing ~ 488' RKB (141 'BML) 13-3/8" 68# K-55 BTC Surface Casing (~ 850' 9-5/8" 47t/L-80 BTC Intermediate Casing ~ 1500' RECEIVED · Alaska 011 & Gas Con~. (30rrff~i[4~iol~ 7" 29# I.,-80 NSCC Liner F/4500' - 1000' CASING DESIGN WELL: STEELHEAD M-9 FIELD: TRADING BAY UNIT DATE: 16-Jul-96 1, MUD WT, I 8,8 PPG 2. MUD WT, II 9,4 PPG 3. MUD WT, III 9.4 PPG DESIGN BY: P.A. RYAN MS,P. 106 psi 223 psi TENSION MINIMUM WEIGHT TOP OF STRENGTH DESCRIPTION W/O BF SECTION TENSION CASING SIZE Bo'FrOM TO.._~P LENGTH WT. GRADE THREAD LBS LB.__~S 1000 LBS 13-3/8" 850 82 768 68 K-55 BTC 52224 52224 1069 TVD 850 82 9-5/8" 1500 82 1418 47 L-80 BTC 66646 66646 1086 TVD 1456 82 7" 4500 1000 3500 29 L-80 BTC 101500 101500 676 'I-VD 3075 1000 INTERVAL TD.__E 20.47 16,30 6.66 NOTES: See attached for calculation of M.S.P, including assumptions & estimates. * Collapse pressure is calculated; Normal Pressure Fluid Gradient for external stress (.44 psi/fi) and the casing evacuated for the internal stress (0 psi/E) COLLAPSE COLLAPSE PRESS ~ RESIST. BOTTOM w/o TENSION PSI___~* PS..__Jl 374 1950 641 4750 1353 7020 CD___EF 5.21 7,41 5.19 BURST MINIMUM PRESSURE YIELD PSI** PS...~I 641 3450 1353 6870 1353 8160 BDF 5.39 5,08 603 ** Burst pressure is calculated; (BHP @ depth next csg assuming' a Normal Fluid Gradient (.44 psi/ft)) Steelhead Platform Well # M-9 Trading Bay umt July 16, 1996 Hole Section 1 Depth Interval: 0'-850' 17-1/2" hole size 13-3/8" casing to 850' Mud weight: Shoe depth (13-3/8"): Est. fracture gradiem of 13-3/8" shoe: Depth of next hole section (12-1/4"): BHP gradient: Gas gradiem (assume worst case): 9.4 ppg=0.49 psi/ft 850' MD/850' TVD 0.80 psi/t't 1500' MD/1456' TVD 0.44 psi/ft 0.0 psi/fl Gas kick situation in wellbore. Assume 3/4 mud & 1/4 gas. MSP=BHP - Hydrostatic Pressure MSP=BHP - (3/4 mud + 1/4 gas) MSP=(1456'x.44 psi/fO - ((.75(1456'x0.49 psi/fl)) + (.25(1456'x0.0 psi/~)) MSP=- 106 psi Therefore, the hydrostatic pressure at the 13-3/8" shoe (Hpsh) is the greatest when the gas (kick) bubble reaches the 13-3/8" shoe, if a constant BHP is applied. A conservative estimate would be the MSP plus the hydrostatic pressure at the 13-3/8" casing depth (Hpcsg). Hpsh= MSP + Hpcsg Hpsh= 106 + (850'x0.46 psi/ft) Hpsh= 523 psi This (Hpsh = 523 psi) is less than the fracture pressure at the same shoe (Fpsh) and thus adequate to handle the well kick scenario. Hpsh = 523 psi < Fpsh = 0.80 psi/fl x 850' = 680 psi. Steelhead Platform Well # M-9 Pressure Calculations Hole Section 2 Depth Imerval: 850'-1500' 12-1/4" hole size 9-5/8" casing to 1500' Mud weight: Shoe depth (9-5/8"): Est. fracture gradient of 9-5/8" shoe: Depth of next hole section (8-1/2"): BHP gradiem: Gas gradient (assume worst case): 9.4 ppg=0.49 psi/ft 1500' MD/1456' TVD 0.80 psi/ft 4500' MD/3075' TVD 0.44 psi/fl 0.0 psi/fl Gas kick situation in wellbore. Assume 3/4 mud & 1/4 gas. MSP=-BHP - Hydrostatic Pressure MSP=-BHP - (3/4 mud + 1/4 gas) MSP=-(3075'x.44 psi/fl) - ((.75(3075'x0.49 psi/fl)) + (.25(3075'x0.0 psi/fl))) MSP= 223 psi Therefore, the hydrostatic pressure at the 9-5/8" shoe (Hpsh) is the greatest when the gas (kick) bubble reaches the 9-5/8" shoe, if a constant BHP is apphed. A conservative estimate would be the MSP plus the hydrostatic pressure at the 9-5/8" casing depth (Hpcsg). Hpsh= MSP + Hpcsg Hpsh= 223 + (1456'x0.49 psi/fl) Hpsh= 936 psi This (Hpsh = 936 psi) is less than the fracture pressure at the same shoe (Fpsh) and thus adequate to handle the well kick scenario. Hpsh = 936 psi < Fpsh = 0.80 psi/fl x 1456' = 1165 psi. File name: m9cal.doc RECEIVED Alaska Oil &. Ga~ Cons. Gorrlmi~,ioH Well # Baker Platfom Date Leak Off Test (LOT) Data Cook Inlet, Alaska Revised March 15, 1996 Unocal Energy Resources Alaska Csg Size Shoe Depth (TVD) Frac Grad. (psi/ft.) EMW (PPg) Ba 28 Ba 30 Ba 30 Ba 28 Ba 29 Ba 29 Ba 30 Ba 28 Ba31 Ba31 Ba31 10-10-93 24" 802' 0.94 10-24-93 24" 803' 0.83 10-28-93 18-5/8" 2011' 0.94 11-17-93 18-5/8" 2135' 0.75 12-17-94 18-5/8" 2054' 0.76 12-29-93 13-3/8" 5869' 0.85 01-27-94 13-3/8" 5467' 0.93 03-01-94 13-3/8" 3509' 0.75 03-04-96 18-5/8" 801' 0.82 03-09-96 13-3/8" 2076' 0.80 03-15-96 9-5/8" 5937' 1.02 Grayling Platform G-40 G-40 01-24-90 18.10 15.90 18.10 14.50 14.61 16.33 17.96 14.40 15.68 15.40 19.70 16" 1926' 0.96 18.46 13-3/8" 4977' 0.86 16.54 (FIT) Monopod Platform A-lrd 04-04-91 A-8rd 07-01-89 A-20rd 03-30-90 A-20rd 04-13-90 A-28rd 11-20-89 A-28rd 11-27-89 9-5/8" 1132' 1.07 20.57 9-5/8" 3760' 1.02 19.61 13-3/8" 755' 0.95 18.20 9-5/8" 1931' 0.85 16.30 20" 240' 0.75 14.42 13-3/8" 1140' 0.97 18.65 Granite Point Platform 11-13rd 02-14-92 51 08-07-92 51 07-28-92 51 08-25-92 50 05-27-92 50 06-04-92 50 06-27-92 9-5/8" 9966' 0.96 18.40 13-3/8" 3803' 1.00 19.20 18-5/8" 1010' 0.87 16.80 9-5/8" 9592' 1.05 20.20 18-5/8" 982' 0.91 17.50 13-3/8" 4208' 0.84 16.20 9-5/8" 9877' 0.93 17.90 Dillon Platform 16 04-22-94 18-5/8" 1131' 16 06-16-94 13-3/8" 3640' 16 07-04-94 9-5/8" 9469' 17 04-27-94 18-5/8" 1142' 17 05-01-94 13-3/8" 3560' 17 05- 9-5/8" 9213' 18 07-26-94 18-5/8" 1132' 18 08-01-94 13-3/8" 3988' 1.12 0.82 NA 1.01 0.83 NA 1.02 0.80 21.72 15.80 14.2 (FIT) 19.47 15.90 16.5 (FIT) 19.63 15.3 RECEIVED JUL 1 9 i99G Alaska Oil & Gas Cons. Commission Anchorago Leak Off Test (LOT) Data Page 2 Anna Platform 1 ltd 10-23-94 13-3/8" 2976' 1 ltd 11-11-94 9-5/8" 8750' 3rd 12/10/94 9-5/8" 7839' 50 2/8/95 18-5/8" 1160' 50 2/13/95 13-3/8" 4251 50 3/8/95 9-5/8" 9844' 51 1/29/95 18-5/8" 1130' 51 5/15/95 13-3/8" 3796' 51 6/3/95 9-5/8" 9842' 52 2/3/95 18-5/8" 1153' 52 3/27/95 13-3/8" 3940' 52 4/15/95 9-5/8" 9470' 7rd2 8/25/95 9-5/8" 4439' Notes: All fracture gradients reported have been corrected for air and water gaps. (FIT)-Formation Integrity Test 0.89 17.2 0.92 17.7 (FIT) 0.75 14.5 1.38 26.6 1.01 19.5 .86 16.5 1.36 26.2 .71 13.6 .88 17.0 (FIT) 1.41 27.0 .84 16.15 .91 17.6 (FIT) .96 18.5 Filename Lotdata. doc RECEIVED Alaska Oil & Gas Oons. ¢ommissior~ A~lchorage 'ENGINEERING · WELLPERMIT CHECKLIST COMPANY~_-,/~o~__~'/ 'WELLNAMET'"_.L~r"~' ,,~-' 7 PROGRAM:expEl de~"reddlE! servn wellboreseg I'-]ann. disposalEar~_req [] FIELD&POOL ..~~).~'-,~"('~ INITCLASS,~ /'~?'~' . GEOLAREA ~:;'.2__~3 UNIT# /'/.~(~?~'~_,) ON/OFFSHORE ,~"'" ADMiNiSTR/~,¥1'ON ..... . REMARKS 1. Permit fee attached ....................... IY'~ N 2. Lease number appropriate .................... Y1y N 3. Unique well name and number ................. Y IN 4. Well located in a defined pool .................. Y j N 5. Well located proper distance from ddg unit boundary .... .~.Y{ N ,2.,/~.....~..~/ (~ ~//~::~,~ ~..,~~,,-.---~ --...~.~ 6. Well located proper distance from other wells ........ .~.Y{ N 7. Sufficient acreage available in drilling unit. ......... '1' Yj N 8. If deviated, is wellborn plat included ............. { .Y~ N 9. Operator only affected party .................. /. Y! N ' 10. Operator has appropriate bond in force ............ \ YIN 11. Permit can be issued without conservation order ...... 12. Permit can be issued without administrative approval .... 13. Can permit be approved before 15-day wait. ........ APPR D~,TE ' GEOLOGy DATE Conductor s~'ing provided .................. ~.Y~N Surface casing protects all known USDWs ......... (~ N CMT vol adequate to circulate on conductor & surf csg . . . N CMT vol adequate to tie-in long s~ng to surf csg ...... .(~N CMT will cover all known productive horizons ......... .~ N Casing designs adequate for C, T, B & permafrost ..... .(,,~ N Adequate tankage or reserve pit. ................/Y;) N If a re-drill, has a 10-403 for abndnmnt been approved....~Y H Adequate wellbore separation proposed .......... . . ( If diverter required, is it adequate ................. N Ddlling fluid program schematic & equip list adequate .... N ' BOPEs adequate ........................ (~ ~)N BOPE press rating adequate; test to ~~ psig.~ Choke manifold complies w/APl RP-53 (May 84) ....... Work will occur without operation shuldown .......... .~ ~) N Is presence of H2S gas probable ............... Y (~) Permit can be issued w/o hydrogen sulfide measures ..... Y N//'/...,~ ) ,,~ Data presented on potential overpressure zones ....... Y/N'" ...~;2'~,,/,,;7-7, Seismic analysis of shallow gas zones ............. /,Y/N Seabed condiiJon survey (if off-shore) ........... ~. Y N Contact name/phone for weekly progress, mpo~...../... Y N lexp~oramry omy. I 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. 33. 34. GEOLOGY: ENGINEERING: COMMISSION: JDH ~ JDN TAB ~ Comments/Instructions: 'qjb- A.'~FOR~ist rev 4~:J6
