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Home My WebLink About203-1821. 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): 3,958 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: Casey Morse Contact Email:Casey.Morse@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 N/A McArthur River Middle Kenai Gas Same 2,809 3,868 2,748 948psi 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 203-182 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20480-01-00 Hilcorp Alaska, LLC Trading Bay Unit M-16RD Length Size Proposed Pools: 488' 488' L-80 TVD Burst 2,618 8,160psi MD 6,870psi 3,450psi836' 1,177' 840' 488' 28" 13-3/8" 9-5/8"1,200' 840' 1,200' 3,085 - 3,808 3,956' 2,222 - 2,707 2,808'7" Other: CTCO / N2 Operations 1/31/2025 4-1/2" See schematic See schematic 3,956' Perforation Depth MD (ft): 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 1:58 pm, Jan 22, 2025 325-026 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.01.22 13:04:38 - 09'00' Dan Marlowe (1267) DSR-1/22/25A.Dewhurst 23JAN25BJM 1/24/25 X 10-404 BOP test to 2500 psi *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.01.24 14:53:39 -09'00'01/24/25 RBDMS JSB 012925 CT Cleanout Well: Steelhead M-16RD Well Name:M-16RD API Number:50-733-20480-01-00 Current Status:Offline Gas Producer Leg:Leg A1 (SW corner) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:203-182 First Call Engineer:Casey Morse (603) 205-3780 (c) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Maximum Expected BHP:1,219 psi @ 2,707’ TVD 0.45psi/ft to deepest TVD Max. Potential Surface Pressure: 948 psi Using 0.1 psi/ft Brief Well Summary Gas producer M-16RD died off in mid-2023. A coil cleanout was performed in January 2024 that successfully returned the well to its prior rates. The production declined rapidly again starting in December 2024. Given the historical issues with debris and prior success with coil cleanout, it’s likely that another coil FCO will have a good chance at restoring connection to the gravel pack below and restore rate. The goal of this project is to clean out the gravel pack completion and restore rate. Pertinent wellbore information: -WL-SSSV installed: Will need to be pulled, reset, and tested after work is complete - Live GLV’s currently installed - Inclination:62 degree sail angle from 1700 – 2900’ MD.48 degree below there to PBTD - Pertinent events o 5/19/11: 6MM flowrate and no water. SZ-17 was 3000mcfd and SZ 18 was 650mcfd at ~230psi FBHP o 2/1/12: Starts producing water and solids. Production log from March-2001 in from M-16 (parentbore) suggest SZ-17 and SZ-18 to blame An RST log run in M-16 also in March-2001 suggest SZ-18 was likely wet, but SZ-17 is not o 11/17/12: RWO complete All perfs squeezed off Straddled off SZ-17 and SZ-18 SZ-19 and SZ-21 added, and all others Re-Perf’d. All re-gravel packed PT of IA to 1000psi passed (only for 15mins) after tubing was run o 10/19/18: SL bailed for 4 days, and eventually made it down to 3613’ SLMD uncovering down to the SZ-23A. rate improved from 500mcfd to 1200mcfd o 2/11/21: SL drifted to 3839’ SLMD o 2/16/21: Bobbled through something at 2809 (metal marks on GR). Sit down at 3207' SLMD o 2/18/21: 2-3/8” x 20’ dummy gun made it to 3750’ SLMD o 10/10/22: SL drift couldn’t get past 2822’ o 1/14/2024: RU coil tubing to run a jet nozzle and clean out to 3,859’. Production rate restored CT Cleanout Well: Steelhead M-16RD Coiled Tubing FCO Procedure 1. MIRU Coiled Tubing and pressure control equipment 2. PT lubricator to 250psi low / 2500psi high 3. MU FCO BHA 4. RIH and cleanout to PBTD 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. Stand back CT and flow test well Attachments: 1. Current Wellbore Schematic – no change 2. CT BOP Drawing 3. Nitrogen procedure REVISED by JLL: 02/12/2024 SCHEMATIC Steelhead Platform Well: M-16RD Last Completed: 11/16/2012 PTD: 203-182 API: 50-733-20480-01-00 TD = 3,958’’(MD)/ 2,809’(TVD) PBTD = 3,868’(MD)/ 2,747(TVD) RKB to Hanger = 71.78’ Hangar Type:McEvoy 11”x7” NNSCC Type J BPV 11”x7” 2 3 SZ-17 A-2 4 SZ-18 SZ-22 SZ-23A SZ-21 SZ-19 SZ-23 5 107 6 8 9 10 11 12 13 14 15 16 17 18 20 21 19 29 30 31 32 33 34 3536 37 2223 24 25 26 2728 Upr A-2 TOC 715’ CBL 11/13/2003 1 X On/Off CASING DETAIL SIZE WT GRADE Type ID TOP BTM. 28” Structural Surf. 488’ 13-3/8” 68 K-55 Surface 12.415" Surf 840' 9-5/8” 47 L-80 Intermediate 8.681” Surf 1,200' 7” 29 L-80 Production 6.184" Surf 3,956' TUBING DETAIL 4-1/2” 12.6 L-80 IBT Mod SCC 3.958" Surf 2,618' Note: Window in 9-5/8” at 1,200’ MD (1,177’ TVD) FIT=13 ppg EMW JEWELRY DETAIL No.Depth MD Depth TVD OD ID Item 1 71.78’ 71.78’ CIW 4-1/25" BTC Top and Bottom with "H" BPV 2 472' 472’ 5.500 2.12/3.958 SSSV w/4-1/2” IBT Connections-WL insert (SSSV ID 2.12) 3 1,624' 1,486’ 6.000 3.958 Gas Lift Mandrel 4 2,631' 1,983’ 6.000 3.958 Gas Lift Mandrel 5 2,647' 1,991’ 5.200 3.958 4-1/2" L-80 IBT Flow Coupling 6 2,653' 1,994’ 5.200 3.813 4-1/2" IBT "X" Landing Nipple 7 2,654' 1,994’ 5.200 3.958 4-1/2" L-80 IBT Flow Coupling 8 2,697' 2,014’ 5.200 2.812 X/O 3-1/2” 8RD X 4-1/2” IBT-MOD BX 9 2,698' 2,015’ 5.875 2.813 T-2 On-Off Tool 10 2,700' 2,016’ 5.875 2.992 7" 20-29# AS1-X Retrievable Packer 11 2,971' 2,154’ 5.060 2.992 4.000" Locator Tubing Seal Assy w/6' seals 12 2,972' 2,155’ 5.813 4.000 7" 20-29# AS1-X Isolation Packer 13 2,974' 2,156’ 5.500 4.408 Millout Extension 14 2,979' 2,159’ 6.060 2.992 Packer Bottom Adapter 15 2,986' 2,163’ 4.500 2.813 3-1/2" EUE "X" Landing Nipple 16 2,994' 2,167’ 5.500 2.992 3-1/2" Production Overshot w/ 3-1/2" EUE Box 17 2,994' 2,167’ 3.500 2.992 3-1/2" Hook-Up Nipple w/3-1/2" NU 10rd Pin 18 3,065' 2,209’ 3.920 2.992 3-1/2" L-80 / .008 Gauge GP Screen x 5 (total 150' screen) 19 3,215' 2,306’ 4.250 2.992 X/O 3-1/2" NU 10rd Box x 3-1/2" EUE Pin 20 3,216' 2,307’ 4.750 2.992 4.000 Snap Latch Seal Assy w/2' seals 21 3,217' 2,308’ 5.813 4.000 7" 20-29# AS1-X Isolation Packer 22 3,219' 2,309’ 3.500 2.992 3-1/2”EUE8RD 9.2#n l-80 Pup Joint 23 3,225' 2,313’ 4.500 2.813 Map 2.813 "X" Profile Nipple 24 3,230' 2,316’ 5.500 2.992 3-1/2" Production Overshot w/ 3-1/2" EUE Box 25 3,231' 2,317’ 3.500 2.992 Polished Hook-Up Nipple 26 3,269' 2,343’3.920 2.992 3-1/2" L-80 / .008 Gauge GP Screen x 12 (total 360' screen) 27 3,630' 2,588’ 4.250 2.992 X/O 3-1/2" NU 10rd Box x 3-1/2" EUE Pin 28 3,630' 2,588’ 4.750 2.992 Snap Latch Seal Assy w/2' seals 29 3,631' 2,589’ 5.875 4.000 MAP 7" 20-29# Isolation Packer 30 3,633' 2,590’ 5.875 4.090 Packer / Tubing Adapter w/ 3-1/2" EUE Box Down 31 3,641' 2,595’ 4.500 2.813 MAP 2.813 ”X” ProfileNipple 32 3,662' 2,610’ 4.500 2.992 3-1/2" Production Overshot w/ 3-1/2" EUE Box 33 3,664' 2,611’ 3.500 2.992 Polished Hook-Up Nipple 34 3,701' 2,636’3.920 2.992 3-1/2" L-80 / .008 Gauge GP Screen x 5 (total 150' screen) 35 3,852' 2,737’ 4.250 2.50 X/O 3-1/2" NU 10rd Box x 2-7/8" EUE Pin 36 3,852' 2,737’ 4.750 2.438 3.250" Snap Latch Seal Assy w/2' seals 37 3,853' 2,738’ 5.813 3.250 MAP 7" 26-32# Model D Sump Packer PACKER DETAIL No. MD TVD OD ID Item 10 2,700' 2,016' 5.875 2.992 7" 20-29# AS1-X Retrievable Packer 12 2,972' 2,155' 5.813 4 7" 20-29# AS1-X Isolation Packer 21 3,217' 2,308' 5.813 4 7" 20-29# AS1-X Isolation Packer 29 3,631' 2,589' 5.875 4 MAP 7" 20-29# Isolation Packer 37 3,853' 2,738' 5.813 3.25 MAP 7" 26-32# Model D Sump Packer REVISED by JLL: 02/12/2024 SCHEMATIC Steelhead Platform Well: M-16RD Last Completed: 11/16/2012 PTD: 203-182 API: 50-733-20480-01-00 PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Comments SZ-17 2,756' 2,816' 2,042' 2,072' 60 Nov. 2003 Squeezed SZ-18 2,890' 2,930' 2,110' 2,131' 40 Nov. 2003 Squeezed SZ-19 3,085' 3,100' 2,222' 2,232' 15 11/12/2012 Open 3,118' 3,121' 2,243' 2,245' 3 11/12/2012 Open 3,141' 3,146' 2,257' 2,261' 5 11/12/2012 Open 3,159' 3,203' 2,269' 2,298' 44 11/12/2012 Open SZ-21 3,280' 3,287' 2,350' 2,355' 7 11/8/2012 Open 3,300' 3,307' 2,364' 2,369' 7 11/8/2012 Open 3,333' 3,337' 2,386' 2,389' 4 11/8/2012 Open SZ-22 3,380' 3,428' 2,419' 2,451' 48 11/8/2012 Open 3,428' 3,448' 2,452' 2,465' 20 Nov. 2003 Open SZ-23 3,474' 3,484' 2,483' 2,490' 10 11/8/2012 Open SZ-23A 3,528' 3,531' 2,519' 2,521' 3 11/8/2012 Open 3,551' 3,556' 2,535' 2,538' 5 11/8/2012 Open 3,583' 3,587' 2,556' 2,559' 4 11/8/2012 Open 3,606' 3,618' 2,571' 2,579' 12 11/8/2012 Open 3,531' 3,542' 2,521' 2,529' 11 Nov. 2003 Open Upr A-2 3669’ 3689’ 2614’ 2628’ 20’ 02/19/21 Open A-2 3,725' 3,743' 2,652' 2,664' 12 11/3/2012 Open 3,768' 3,788' 2,681' 2,694' 20 11/3/2012 Open 3,808' 3,843' 2,707' 2,731' 35 11/3/2012 Open 3,748' 3,768' 2,667' 2,681' 20 Nov. 2003 Open 3,788' 3,808' 2,694' 2,707' 20 Nov. 2003 Open KLU A-1 Well Head Rig Up 1 1 1 1 4 1/16" 15K Lubricator - 10 ft 100" Gooseneck HR680 Injector Head 4 1/16" 10K Flow Cross, 2" 1502 10k Flanged Valves 4 1/16" 15K Lubricator - 10 ft API Flange Adapter 10K to 5K for riser/wellhead Hydraulic Stripper 4 1/6" 15K API Bowen CB56 15K 4 1/16" 10K Combi BOPs Blind/Shear Ram Pipe/Slip Ram 4 1/16" 10K bottom flange 4 1/16" 5K flanged Riser - 10 ft if necessary STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops 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 3,958 feet N/A feet true vertical 2,809 feet N/A feet Effective Depth measured 3,868 feet See schematic feet true vertical 2,748 feet See schematic feet Perforation depth Measured depth 3,085 - 3,808 feet True Vertical depth 2,222 - 2,707 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 2,618 (MD) 1,977 (TVD) Packers and SSSV (type, measured and true vertical depth) See schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Middle Kenai Gas 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: Other: N2 Operations 12 323-681 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ryan Rupert Ryan.Rupert@hilcorp.com 907 777-8503Operations Manager N/A 488 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 488 N/A 211 Size 488 030637 0 2070 13-3/8" 9-5/8" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-182 50-733-20480-01-00 3. Address: Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0018730 McArthur River / Middle Kenai Gas Trading Bay Unit M-16RD Plugs Junk measured Length measured TVD Production Liner 1,200 3,956 Casing Structural 1,177 2,808 1,200 3,956 840 Conductor Surface Intermediate 28" 4,760psi 7,020psi 3,450psi 6,870psi 8,160psi 840 836 Burst Collapse 1,950psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Kayla Junke at 3:17 pm, Feb 14, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.02.14 14:54:30 - 09'00' Dan Marlowe (1267) RBDMS JSB 022724 DSR-2/14/24 REVISED by JLL: 02/12/2024 SCHEMATIC Steelhead Platform Well: M-16RD Last Completed: 11/16/2012 PTD: 203-182 API: 50-733-20480-01-00 TD = 3,958’’(MD)/ 2,809’(TVD) PBTD = 3,868’(MD)/ 2,747(TVD) RKB to Hanger = 71.78’ Hangar Type:McEvoy 11”x7” NNSCC Type J BPV 11”x7” 2 3 SZ-17 A-2 4 SZ-18 SZ-22 SZ-23A SZ-21 SZ-19 SZ-23 5 107 6 8 9 10 11 12 13 14 15 16 17 18 20 21 19 29 30 31 32 33 34 3536 37 2223 24 25 26 2728 Upr A-2 TOC 715’ CBL 11/13/2003 1 X On/Off CASING DETAIL SIZE WT GRADE Type ID TOP BTM. 28” Structural Surf. 488’ 13-3/8” 68 K-55 Surface 12.415" Surf 840' 9-5/8” 47 L-80 Intermediate 8.681” Surf 1,200' 7” 29 L-80 Production 6.184" Surf 3,956' TUBING DETAIL 4-1/2” 12.6 L-80 IBT Mod SCC 3.958" Surf 2,618' Note: Window in 9-5/8” at 1,200’ MD (1,177’ TVD) FIT=13 ppg EMW JEWELRY DETAIL No.Depth MD Depth TVD OD ID Item 1 71.78’ 71.78’ CIW 4-1/25" BTC Top and Bottom with "H" BPV 2 472' 472’ 5.500 2.12/3.958 SSSV w/4-1/2” IBT Connections-WL insert (SSSV ID 2.12) 3 1,624' 1,486’ 6.000 3.958 Gas Lift Mandrel 4 2,631' 1,983’ 6.000 3.958 Gas Lift Mandrel 5 2,647' 1,991’ 5.200 3.958 4-1/2" L-80 IBT Flow Coupling 6 2,653' 1,994’ 5.200 3.813 4-1/2" IBT "X" Landing Nipple 7 2,654' 1,994’ 5.200 3.958 4-1/2" L-80 IBT Flow Coupling 8 2,697' 2,014’ 5.200 2.812 X/O 3-1/2” 8RD X 4-1/2” IBT-MOD BX 9 2,698' 2,015’ 5.875 2.813 T-2 On-Off Tool 10 2,700' 2,016’ 5.875 2.992 7" 20-29# AS1-X Retrievable Packer 11 2,971' 2,154’ 5.060 2.992 4.000" Locator Tubing Seal Assy w/6' seals 12 2,972' 2,155’ 5.813 4.000 7" 20-29# AS1-X Isolation Packer 13 2,974' 2,156’ 5.500 4.408 Millout Extension 14 2,979' 2,159’ 6.060 2.992 Packer Bottom Adapter 15 2,986' 2,163’ 4.500 2.813 3-1/2" EUE "X" Landing Nipple 16 2,994' 2,167’ 5.500 2.992 3-1/2" Production Overshot w/ 3-1/2" EUE Box 17 2,994' 2,167’ 3.500 2.992 3-1/2" Hook-Up Nipple w/3-1/2" NU 10rd Pin 18 3,065' 2,209’ 3.920 2.992 3-1/2" L-80 / .008 Gauge GP Screen x 5 (total 150' screen) 19 3,215' 2,306’ 4.250 2.992 X/O 3-1/2" NU 10rd Box x 3-1/2" EUE Pin 20 3,216' 2,307’ 4.750 2.992 4.000 Snap Latch Seal Assy w/2' seals 21 3,217' 2,308’ 5.813 4.000 7" 20-29# AS1-X Isolation Packer 22 3,219' 2,309’ 3.500 2.992 3-1/2”EUE8RD 9.2#n l-80 Pup Joint 23 3,225' 2,313’ 4.500 2.813 Map 2.813 "X" Profile Nipple 24 3,230' 2,316’ 5.500 2.992 3-1/2" Production Overshot w/ 3-1/2" EUE Box 25 3,231' 2,317’ 3.500 2.992 Polished Hook-Up Nipple 26 3,269' 2,343’3.920 2.992 3-1/2" L-80 / .008 Gauge GP Screen x 12 (total 360' screen) 27 3,630' 2,588’ 4.250 2.992 X/O 3-1/2" NU 10rd Box x 3-1/2" EUE Pin 28 3,630' 2,588’ 4.750 2.992 Snap Latch Seal Assy w/2' seals 29 3,631' 2,589’ 5.875 4.000 MAP 7" 20-29# Isolation Packer 30 3,633' 2,590’ 5.875 4.090 Packer / Tubing Adapter w/ 3-1/2" EUE Box Down 31 3,641' 2,595’ 4.500 2.813 MAP 2.813 ”X” ProfileNipple 32 3,662' 2,610’ 4.500 2.992 3-1/2" Production Overshot w/ 3-1/2" EUE Box 33 3,664' 2,611’ 3.500 2.992 Polished Hook-Up Nipple 34 3,701' 2,636’3.920 2.992 3-1/2" L-80 / .008 Gauge GP Screen x 5 (total 150' screen) 35 3,852' 2,737’ 4.250 2.50 X/O 3-1/2" NU 10rd Box x 2-7/8" EUE Pin 36 3,852' 2,737’ 4.750 2.438 3.250" Snap Latch Seal Assy w/2' seals 37 3,853' 2,738’ 5.813 3.250 MAP 7" 26-32# Model D Sump Packer PACKER DETAIL No. MD TVD OD ID Item 10 2,700' 2,016' 5.875 2.992 7" 20-29# AS1-X Retrievable Packer 12 2,972' 2,155' 5.813 4 7" 20-29# AS1-X Isolation Packer 21 3,217' 2,308' 5.813 4 7" 20-29# AS1-X Isolation Packer 29 3,631' 2,589' 5.875 4 MAP 7" 20-29# Isolation Packer 37 3,853' 2,738' 5.813 3.25 MAP 7" 26-32# Model D Sump Packer REVISED by JLL: 02/12/2024 SCHEMATIC Steelhead Platform Well: M-16RD Last Completed: 11/16/2012 PTD: 203-182 API: 50-733-20480-01-00 PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Comments SZ-17 2,756' 2,816' 2,042' 2,072' 60 Nov. 2003 Squeezed SZ-18 2,890' 2,930' 2,110' 2,131' 40 Nov. 2003 Squeezed SZ-19 3,085' 3,100' 2,222' 2,232' 15 11/12/2012 Open 3,118' 3,121' 2,243' 2,245' 3 11/12/2012 Open 3,141' 3,146' 2,257' 2,261' 5 11/12/2012 Open 3,159' 3,203' 2,269' 2,298' 44 11/12/2012 Open SZ-21 3,280' 3,287' 2,350' 2,355' 7 11/8/2012 Open 3,300' 3,307' 2,364' 2,369' 7 11/8/2012 Open 3,333' 3,337' 2,386' 2,389' 4 11/8/2012 Open SZ-22 3,380' 3,428' 2,419' 2,451' 48 11/8/2012 Open 3,428' 3,448' 2,452' 2,465' 20 Nov. 2003 Open SZ-23 3,474' 3,484' 2,483' 2,490' 10 11/8/2012 Open SZ-23A 3,528' 3,531' 2,519' 2,521' 3 11/8/2012 Open 3,551' 3,556' 2,535' 2,538' 5 11/8/2012 Open 3,583' 3,587' 2,556' 2,559' 4 11/8/2012 Open 3,606' 3,618' 2,571' 2,579' 12 11/8/2012 Open 3,531' 3,542' 2,521' 2,529' 11 Nov. 2003 Open Upr A-2 3669’ 3689’ 2614’ 2628’ 20’ 02/19/21 Open A-2 3,725' 3,743' 2,652' 2,664' 12 11/3/2012 Open 3,768' 3,788' 2,681' 2,694' 20 11/3/2012 Open 3,808' 3,843' 2,707' 2,731' 35 11/3/2012 Open 3,748' 3,768' 2,667' 2,681' 20 Nov. 2003 Open 3,788' 3,808' 2,694' 2,707' 20 Nov. 2003 Open Well Name:MRF M-16RD API #:50733204800100 Field:McArthur River Field Start Date:1/14/2024 Permit #:203182 Sundry #:323-681 End Date:1/16/2024 1/14/2024 1/15/2024 1/16/2024 Well Operations Summary PJSM and PTW, Well flowing at 1.0MM, Stab coil into injector head. BOPE test per AOGCC and Hilcorp standards to 250psi/2500psi - Test Good. M/U 4-1/16" Riser from wellhead to top deck. Stab on BOPE's. Spot N2 pump and tanks, run hard line. SDFN RIH with 2.25" down jet nozzle. Dry tag 2 times at 3160' (middle of upper screen section). PU to 2900' and prepare to clean out. Come online at 2900' with 1bpm 6% KCL (at 115F), 500MCFD GL, and 720MCFD Nitrogen. Easy washing down to 3700' (top of lowermost screen section) then washed through multiple bridges to 3,859' CTMD (PBTD). 1:1 returns throughout. N2 lift well from 3859' MD until dry, Recovered all KCL pumped. SDFN MIRU SLB Coil #1, Spot equipment, RU hardline, RU R4R tanks and hoses, Mix 300bbl of 6% KCL, add steam hose to heat to 100F. SDFN Daily Operations: Page 1 of 1 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Karson Kozub To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Juanita Lovett; Daniel Scarpella Subject:SLB 1 1-15-24 Date:Wednesday, January 17, 2024 7:59:18 AM Attachments:AOGCC ok to BOPE test every 7 days per leg M-16,M-20,M-21.pdf SLB 1 1-15-24 .xlsx Some people who received this message don't often get email from kkozub@hilcorp.com. Learn why this is important Attached is the BOPE test form for SLB 1 on 1-15-24. We will be weekly testing instead of on each well for TBU "Steelhead" wells M-16RD (PTD 2031820), M-20 (PTD 2090930), per AOGCC approval email dated 1/10/24. Regards, Karson Kozub Wells Foreman Cook Inlet Offshore Office: (907) 777-8434 Cell: (907) 570-1801 Email: kkozub@hilcorp.com Hilcorp Alaska, LLC The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 7UDGLQJ%D\8QLW05' 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmit to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:1 DATE: 1/15/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2031820 Sundry #323-681 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/2500 Annular:N/A Valves:250/2500 MASP:948 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0NA Permit On Location P Hazard Sec.NA Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 0NA Test Fluid Water Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 1.75" Top Load P Trip Tank NA NA Annular Preventer 0NAPit Level Indicators NA NA #1 Rams 1 1.75" Blind/Shear P Flow Indicator NA NA #2 Rams 1 1.75" Pipe/Slip P Meth Gas Detector NA NA #3 Rams 0NAH2S Gas Detector NA NA #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 2 2" 2x2 FMC P Time/Pressure Test Result HCR Valves 0NASystem Pressure (psi)2900 P Kill Line Valves 2 2" 2x2 FMC P Pressure After Closure (psi)2200 P Check Valve 1 2" FMC P 200 psi Attained (sec)25 P BOP Misc 2 EQ Ports P Full Pressure Attained (sec)81 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):NA No. Valves 5P ACC Misc 0NA Manual Chokes 2P Hydraulic Chokes 0NA Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 0 NA #1 Rams 20 P Coiled Tubing Only:#2 Rams 15 P Inside Reel valves 1P #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:4.0 HCR Choke 0 NA Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 1/13/24 11:09hrs Waived By Test Start Date/Time:1/15/2024 9:00 (date) (time)Witness Test Finish Date/Time:1/15/2024 13:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg SLB SLB CT1 BOPE testing weekly instead of on each well for TBU "Steelhead" wells M-16RD (PTD 2031820), M-20 (PTD 2090930), per AOGCC approval email dated 1/10/24. Bryson Lowe Hilcorp Karson Kozub TBU M-16RD Test Pressure (psi): Blowe2@slb.com kkozub@hilcorp.com Form 10-424 (Revised 08/2022) 2024-0115_BOP_SLB1_TBU_M-16RD 9 9 9 999 9 9 9 9 MEU 9 -5HJJ 1 Karson Kozub From:Ryan Rupert Sent:Friday, January 12, 2024 2:01 PM To:Regg, James B (OGC) Cc:McLellan, Bryan J (OGC); Bryson Lowe; Cedric Stephane Saa Mouofo; Karson Kozub; Dan Marlowe; Juanita Lovett; Daniel Scarpella; Ryan Rupert; J.C. Waski Subject:RE: [EXTERNAL] RE: Steelhead CT campaign: Jan-2024 Thanks Jim- ,ŝůĐŽƌƉǁŝůůƉůĂŶŽŶKWƚĞƐƟŶŐĞǀĞƌǇϳĚĂǇƐǁŚŝůĞŽŶƚŚĞ^tůĞŐ;D-16RD and M-ϮϬͿ͕ĂŶĚƚŚĞŶKWƚĞƐƚŝŶŝƟĂůůǇ ƌĞŐĂƌĚůĞƐƐŽĨƟŵŝŶŐǁŚĞŶǁĞŵŽǀĞƚŽƚŚĞEůĞŐ;D-21). Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Wednesday, January 10, 2024 2:27 PM To: Ryan Rupert <Ryan.Rupert@hilcorp.com> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: [EXTERNAL] RE: Steelhead CT campaign: Jan-2024 BOPE test is required when move to new leg. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Monday, January 8, 2024 2:38 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Karson Kozub <kkozub@hilcorp.com>; Daniel Scarpella <Daniel.Scarpella@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com> Subject: Steelhead CT campaign: Jan-2024 CAUTION:External sender. DO NOT open links or attachments from UNKNOWN senders. 2 Jim- We have a 3 well CT campaign coming ƵƉŽŶƚŚĞ^ƚĞĞůŚĞĂĚWůĂƞŽƌŵ͘ tĞĂŶƟĐŝƉĂƚĞƐƚĂƌƟŶŐdŽƉĞƌĂƟŽŶƐĂƐƐŽŽŶĂƐ Sat 1/13/24.dŚĞǁŽƌŬŝƐƉůĂŶŶĞĚƚŽďĞĞǆĞĐƵƚĞĚĐĂŵƉĂŝŐŶƐƚǇůĞƵŶƟůĂůůϯǁĞůů͛ƐdƐĐŽƉĞƐŚĂǀĞďĞĞŶĐŽŵƉůĞƚĞĚ͘ M- 16RD and M-20 are on the SW leg and M-21 is on the NE leg. Given that the work will be performed by Schlumberger, ĂŶĚĂůůϯǁĞůůƐĂƌĞŽŶƚŚĞƐĂŵĞƉůĂƞŽƌŵ͕,ŝůĐŽƌƉǁŽƵůĚůŝŬĞƚŽƌĞƋƵĞƐƚĂǀĂƌŝĂŶĐĞƚŽƚŚĞKWƚĞƐƟŶŐ requirements. Hilcorp requests to test CT BOP’s weekly instead of on each well for this campaign. Please advise if this is acceptable. Thank you. Ryan Rupert CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 3 CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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): 3,958 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 Other: CT / N2 Operations 1/3/2024 4-1/2" See schematic See schematic 3,956' Perforation Depth MD (ft): 1,200' 3,085 - 3,808 3,956' 2,222 - 2,707 2,808'7" 488' 28" 13-3/8" 9-5/8"1,200' 840' MD 6,870psi 3,450psi836' 1,177' 840' Length Size Proposed Pools: 488' 488' L-80 TVD Burst 2,618 8,160psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 203-182 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20480-01-00 Hilcorp Alaska, LLC Trading Bay Unit M-16RD AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY CO 228A McArthur River Middle Kenai Gas Same 2,809 3,868 2,748 948psi N/A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.12.20 13:42:57 - 09'00' Dan Marlowe (1267) 323-681 By Grace Christianson at 2:37 pm, Dec 20, 2023 Middle Kenai Gas Perforate BJM 1/8/234 SFD 1/4/2024 CT BOP test to 2500 psi. DSR-1/4/24 X 10-404 Dump bail 25' of cement on top of CIBP at 2290' MD *&:JLC 1/8/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.01.08 10:08:06 -09'00'01/08/24 RBDMS JSB 010924 FCO + Recomplete Well: Steelhead M-16RD Well Name:M-16RD API Number:50-733-20480-01-00 Current Status:Offline Gas Producer Leg:Leg A1 (SW corner) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:203-182 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Maximum Expected BHP:1,219 psi @ 2,707’ TVD 0.45psi/ft to deepest TVD Max. Potential Surface Pressure: 948 psi Using 0.1 psi/ft Brief Well Summary Gas producer M-16RD died off in mid-2023 has been offline since. Historical SL bailing jobs have been successful at restoring rate. The latest SL attempt was unsuccessful to even get to top perf. Given the steep sail angle, it’s believed that a proper CT FCO will have a good chance at restoring connection to the gravel pack below and restore rate. If the cleanout is unsuccessful, the existing completion will be isolated, and the well recompleted to shallower sands (still within the Middle Kenai Gas Pool). The SZ-15 up to top pool (SZ-10) will require an IA cement job for recompletion. The goal of this project is to cleanout the gravel pack completion and restore rate. If unsuccessful, an uphole recomplete is the next step. Pertinent wellbore information: -WL-SSSV installed: Will need to be pulled, reset, and tested after work is complete - Live GLV’s currently installed - Inclination:62 degree sail angle from 1700 – 2900’ MD.48 degree below there to PBTD - Pertinent events o 5/19/11: 6MM flowrate and no water. SZ-17 was 3000mcfd and SZ 18 was 650mcfd at ~230psi FBHP o 2/1/12: Starts producing water and solids. Production log from March-2001 in from M-16 (parentbore) suggest SZ-17 and SZ-18 to blame An RST log run in M-16 also in March-2001 suggest SZ-18 was likely wet, but SZ-17 is not o 11/17/12: RWO complete All perfs squeezed off Straddled off SZ-17 and SZ-18 SZ-19 and SZ-21 added, and all others Re-Perf’d. All re-gravel packed PT of IA to 1000psi passed (only for 15mins) after tubing was run o 10/19/18: SL bailed for 4 days, and eventually made it down to 3613’ SLMD uncovering down to the SZ-23A. rate improved from 500mcfd to 1200mcfd o 2/11/21: SL drifted to 3839’ SLMD o 2/16/21: Bobbled through something at 2809 (metal marks on GR). Sit down at 3207' SLMD o 2/18/21: 2-3/8” x 20’ dummy gun made it to 3750’ SLMD o 10/10/22: SL drift couldn’t get past 2822’ o cleanout the gravel pack completion and restore rate. 1,219 psi @ 2,707’ TVD FCO + Recomplete Well: Steelhead M-16RD Coiled Tubing FCO Procedure 1. MIRU Coiled Tubing and pressure control equipment 2. PT lubricator to 250psi low / 2500psi high 3. MU FCO BHA 4. RIH and cleanout to PBTD 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. Stand back CT and flow test well E-Line Perf / prep for recomplete procedure 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 2500psi high 3. RIH and set a 3-1/2” CIBP isolating all open perfs.Target set depth = 2,983’ MD 4. RIH and perforate Middle Kenai Gas Pool sands from ±2,725 – ±2,950 MD (±2,028 – ±2,142 TVD) per RE/Geo. 5. Stand back EL and flow test If flow test is unsuccessful, setup for uphole CT recomplete 6. Set 3-1/2” CIBP to isolate all open perfs a. Want to set just below Upper packer at 2700’ MD b. Target set depth = 2,720’ MD 7. Punch tubing for cement circulation path to IA a.Target depth = 2622’ b. Want to punch just above lower GLM (2,631’ MD) 8. Set 4-1/2” cement retainer at a target depth = 2,600’ MD 9. RDMO EL perforate Middle Kenai Gas Pool sands from ±2,725 – ±2,950 MD (±2,028 – ±2,142 TVD) FCO + Recomplete Well: Steelhead M-16RD Cement IA Procedure 10. Fluid pack Tubing + IA with water (WBV = 187bbls) 11. CMIT-TxIA to 1500psi to confirm casing integrity 12. SL DGLV STA #1 at 1624’ MD 13. RU cementers and PT to 1500psi 14. Establish injectivity down tubing taking returns to surface up the 4-1/2” x 7” IA 15. Pump Fullbore IA cement a. Target ToC in IA at 1,000’ MD b. Aiming for above 9-5/8” shoe c. Aiming for 500’+ above top pool (1,533’ MD) d. Required volume ~93bbls 16. WoC 17. MIT-IA to 1500psi E-Line Perf Procedure 18. MIRU E-line and pressure control equipment 19. PT lubricator to 250psi low / 2500psi high 20. RIH and perforate the flush zone (SZ-15) of the Middle Kenai gas Pool between ±2,380’ – ±2,575 MD (±1,863 – ±1,957 TVD) per RE/Geo 21. Use nitrogen or Gas Lift to depress water in tubing into flush zone perfs (SZ-15 sand) a. Water from pushing the cement downhole will be the fluid displaced into the flush zone (clear fluid) b. 40bbls max volume to be displaced c. SZ-15 flush zone is wet in M-16RD (see log below) 22. Set CIBP above SZ-15 perfs leaving a dry wellbore (approximately 2,290’ MD) 23. RIH and perforate Middle Kenai gas Pool Sands from ±1,533 – ±2,300 MD (±1,428’ -- ±1,825’ TVD) per RE/Geo 24. RDMO EL Middle Kenai gas Pool between ±2,380’ – ±2,575 MD Where will TOC be inside the tubing? -bjm (±1,863 – ±1,957 TVD) perforate t perforate Middle Kenai gas Pool Sands from ±1,533 – ±2,300 MD (±1,428’ -- ±1,825’ TVD) Per Operator cross-section and email dated 1/3/2024, top of Middle Kenai Gas Pool is 1,533' MD in this well. SFD FCO + Recomplete Well: Steelhead M-16RD SZ-15 Proposed Flush Zone: x M-16RD and parent M-16 show wet on both resistivity tracks in the proposed SZ-15 flush zone (10 ohm cutoff) x Upper SZ-15 above our proposed flush zone was gas productive in parent (labeled inactive in M-16 track) x Original resistivity in parent, M-16, shows gas bearing when drilled in 1997 x When relogged in 2003 for M-16RD sidetrack, that zone then showed watered out CONTINGENCY: (if any zone makes unwanted solids or water) 1. RU Gas Lift or nitrogen to tubing and PT nitrogen lines to 1500psi 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 / 2500psi high 5. Set 4-1/2” CIBP or patch per OE 6. RDMO Nitrogen and EL Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. CT BOP Drawing 4. Nitrogen procedure As Completed: 11/16/12 As Perfed: 11/12/12 REVISED by JLL: 03/03/21 Steelhead M-16RD SCHEMATIC TD = 3,958’’(MD)/ 2,809’(TVD) PBTD = 3,868’(MD)/ 2,747(TVD) RKB to Hanger = 33.75’ Hangar Type:McEvoy 11”x7” NNSCC Type J BPV 11”x7” 2 3 SZ-17 A-2 4 SZ-18 SZ-22 SZ-23A SZ-21 SZ-19 SZ-23 5 107 6 8 9 10 11 12 13 14 15 16 17 18 20 21 19 29 30 31 32 33 34 3536 37 2223 24 25 26 2728 Upr A-2 TOC 715’ CBL 11/13/2003 1 X On/Off CASING DETAIL SIZE WT GRADE Type ID TOP BTM. 28” Structural Surf. 488’ 13-3/8” 68 K-55 Surface 12.415" Surf 840' 9-5/8” 47 L-80 Intermediate 8.681” Surf 1,200' 7” 29 L-80 Production 6.184" Surf 3,956' TUBING DETAIL 4-1/2” 12.6 L-80 IBT Mod SCC 3.958" Surf 2,618' Note: Window in 9-5/8” at 1,200’ MD (1,177’ TVD) FIT=13 ppg EMW JEWELRY DETAIL No.Depth MD Depth TVD OD ID Item 1 33.75’ 33.75’ CIW 4-1/25" BTC Top and Bottom with "H" BPV 2 472' 472’ 5.500 2.12/3.958 SSSV w/4-1/2” IBT Connections-WL insert (SSSV ID 2.12) 3 1,624' 1,486’ 6.000 3.958 Gas Lift Mandrel 4 2,631' 1,983’ 6.000 3.958 Gas Lift Mandrel 5 2,647' 1,991’ 5.200 3.958 4-1/2" L-80 IBT Flow Coupling 6 2,653' 1,994’ 5.200 3.813 4-1/2" IBT "X" Landing Nipple 7 2,654' 1,994’ 5.200 3.958 4-1/2" L-80 IBT Flow Coupling 8 2,697' 2,014’ 5.200 2.812 X/O 3-1/2” 8RD X 4-1/2” IBT-MOD BX 9 2,698' 2,015’ 5.875 2.813 T-2 On-Off Tool 10 2,700' 2,016’ 5.875 2.992 7" 20-29# AS1-X Retrievable Packer 11 2,971' 2,154’ 5.060 2.992 4.000" Locator Tubing Seal Assy w/6' seals 12 2,972' 2,155’ 5.813 4.000 7" 20-29# AS1-X Isolation Packer 13 2,974' 2,156’ 5.500 4.408 Millout Extension 14 2,979' 2,159’ 6.060 2.992 Packer Bottom Adapter 15 2,986' 2,163’ 4.500 2.813 3-1/2" EUE "X" Landing Nipple 16 2,994' 2,167’ 5.500 2.992 3-1/2" Production Overshot w/ 3-1/2" EUE Box 17 2,994' 2,167’ 3.500 2.992 3-1/2" Hook-Up Nipple w/3-1/2" NU 10rd Pin 18 3,065' 2,209’ 3.920 2.992 3-1/2" L-80 / .008 Gauge GP Screen x 5 (total 150' screen) 19 3,215' 2,306’ 4.250 2.992 X/O 3-1/2" NU 10rd Box x 3-1/2" EUE Pin 20 3,216' 2,307’ 4.750 2.992 4.000 Snap Latch Seal Assy w/2' seals 21 3,217' 2,308’ 5.813 4.000 7" 20-29# AS1-X Isolation Packer 22 3,219' 2,309’ 3.500 2.992 3-1/2”EUE8RD 9.2#n l-80 Pup Joint 23 3,225' 2,313’ 4.500 2.813 Map 2.813 "X" Profile Nipple 24 3,230' 2,316’ 5.500 2.992 3-1/2" Production Overshot w/ 3-1/2" EUE Box 25 3,231' 2,317’ 3.500 2.992 Polished Hook-Up Nipple 26 3,269' 2,343’3.920 2.992 3-1/2" L-80 / .008 Gauge GP Screen x 12 (total 360' screen) 27 3,630' 2,588’ 4.250 2.992 X/O 3-1/2" NU 10rd Box x 3-1/2" EUE Pin 28 3,630' 2,588’ 4.750 2.992 Snap Latch Seal Assy w/2' seals 29 3,631' 2,589’ 5.875 4.000 MAP 7" 20-29# Isolation Packer 30 3,633' 2,590’ 5.875 4.090 Packer / Tubing Adapter w/ 3-1/2" EUE Box Down 31 3,641' 2,595’ 4.500 2.813 MAP 2.813 ”X” Profile Nipple 32 3,662' 2,610’ 4.500 2.992 3-1/2" Production Overshot w/ 3-1/2" EUE Box 33 3,664' 2,611’ 3.500 2.992 Polished Hook-Up Nipple 34 3,701' 2,636’3.920 2.992 3-1/2" L-80 / .008 Gauge GP Screen x 5 (total 150' screen) 35 3,852' 2,737’ 4.250 2.50 X/O 3-1/2" NU 10rd Box x 2-7/8" EUE Pin 36 3,852' 2,737’ 4.750 2.438 3.250" Snap Latch Seal Assy w/2' seals 37 3,853' 2,738’ 5.813 3.250 MAP 7" 26-32# Model D Sump Packer PACKER DETAIL No. MD TVD OD ID Item 10 2,700' 2,016' 5.875 2.992 7" 20-29# AS1-X Retrievable Packer 12 2,972' 2,155' 5.813 4 7" 20-29# AS1-X Isolation Packer 21 3,217' 2,308' 5.813 4 7" 20-29# AS1-X Isolation Packer 29 3,631' 2,589' 5.875 4 MAP 7" 20-29# Isolation Packer 37 3,853' 2,738' 5.813 3.25 MAP 7" 26-32# Model D Sump Packer As Completed: 11/16/12 As Perfed: 11/12/12 REVISED by JLL: 03/03/21 Steelhead M-16RD SCHEMATIC PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Comments SZ-17 2,756' 2,816' 2,042' 2,072' 60 Nov. 2003 Squeezed SZ-18 2,890' 2,930' 2,110' 2,131' 40 Nov. 2003 Squeezed SZ-19 3,085' 3,100' 2,222' 2,232' 15 11/12/2012 Open 3,118' 3,121' 2,243' 2,245' 3 11/12/2012 Open 3,141' 3,146' 2,257' 2,261' 5 11/12/2012 Open 3,159' 3,203' 2,269' 2,298' 44 11/12/2012 Open SZ-21 3,280' 3,287' 2,350' 2,355' 7 11/8/2012 Open 3,300' 3,307' 2,364' 2,369' 7 11/8/2012 Open 3,333' 3,337' 2,386' 2,389' 4 11/8/2012 Open SZ-22 3,380' 3,428' 2,419' 2,451' 48 11/8/2012 Open 3,428' 3,448' 2,452' 2,465' 20 Nov. 2003 Open SZ-23 3,474' 3,484' 2,483' 2,490' 10 11/8/2012 Open SZ-23A 3,528' 3,531' 2,519' 2,521' 3 11/8/2012 Open 3,551' 3,556' 2,535' 2,538' 5 11/8/2012 Open 3,583' 3,587' 2,556' 2,559' 4 11/8/2012 Open 3,606' 3,618' 2,571' 2,579' 12 11/8/2012 Open 3,531' 3,542' 2,521' 2,529' 11 Nov. 2003 Open Upr A-2 3669’ 3689’ 2614’ 2628’ 20’ 02/19/21 Open A-2 3,725' 3,743' 2,652' 2,664' 12 11/3/2012 Open 3,768' 3,788' 2,681' 2,694' 20 11/3/2012 Open 3,808' 3,843' 2,707' 2,731' 35 11/3/2012 Open 3,748' 3,768' 2,667' 2,681' 20 Nov. 2003 Open 3,788' 3,808' 2,694' 2,707' 20 Nov. 2003 Open As Completed: 11/16/12 As Perfed: 11/12/12 REVISED by CRR: 12/20/23 Steelhead M-16RD PROPOSED SCHEMATIC TD = 3,958’’(MD)/ 2,809’(TVD) PBTD = ±2,230’ (MD) RKB to Hanger = 33.75’ Hangar Type:McEvoy 11”x7” NNSCC Type J BPV 11”x7” 1 2 SZ-17 A-2 5 SZ-18 SZ-22 SZ-23A SZ-21 SZ-19 SZ-23 6 8 9 10 12/13/14 15a / 15b 16 17 18 20 21 19 29 30 31 32 33 34 3536 37 2223 24 25 26 2728 Upr A-2 TOC 715’ CBL 11/13/2003 3 X On/Off 4 11 CASING DETAIL SIZE WT GRADE Type ID TOP BTM. 28” Structural Surf. 488’ 13-3/8” 68 K-55 Surface 12.415" Surf 840' 9-5/8” 47 L-80 Intermediate 8.681” Surf 1,200' 7” 29 L-80 Production 6.184" Surf 3,956' TUBING DETAIL 4-1/2” 12.6 L-80 IBT Mod SCC 3.958" Surf 2,618' Note: Window in 9-5/8” at 1,200’ MD (1,177’ TVD) FIT=13 ppg EMW JEWELRY DETAIL No.Depth MD Depth TVD OD ID Item 33.75’ 33.75’ CIW 4-1/25" BTC Top and Bottom with "H" BPV 1 472' 472’ 5.500 2.12/3.958 SSSV w/4-1/2” IBT Connections-WL insert (SSSV ID 2.12) 2 1,624' 1,486’ 6.000 3.958 Gas Lift Mandrel (to be dummied) 3 ±2,290’ n/a 4-1/2” CIBP 4 ±2,600’ n/a 4-1/2” Cement Retainer 5 2,631' 1,983’ 6.000 3.958 Gas Lift Mandrel (Orifice valve installed) 6 2,653' 1,994’ 5.200 3.813 4-1/2" IBT "X" Landing Nipple 8 2,697' 2,014’ 5.200 2.812 X/O 3-1/2” 8RD X 4-1/2” IBT-MOD BX 9 2,698' 2,015’ 5.875 2.813 T-2 On-Off Tool 10 2,700' 2,016’ 5.875 2.992 7" 20-29# AS1-X Retrievable Packer 11 ±2,720’ n/a 3-1/2” CIBP 12 2,971' 2,154’ 5.060 2.992 4.000" Locator Tubing Seal Assy w/6' seals 13 2,972' 2,155’ 5.813 4.000 7" 20-29# AS1-X Isolation Packer 14 2,974' 2,156’ 5.500 4.408 Millout Extension 15a ±2,983’ n/a 3-1/2” CIBP 15b 2,986' 2,163’ 4.500 2.813 3-1/2" EUE "X" Landing Nipple 16 2,994' 2,167’ 5.500 2.992 3-1/2" Production Overshot w/ 3-1/2" EUE Box 17 2,994' 2,167’ 3.500 2.992 3-1/2" Hook-Up Nipple w/3-1/2" NU 10rd Pin 18 3,065' 2,209’ 3.920 2.992 3-1/2" L-80 / .008 Gauge GP Screen x 5 (total 150' screen) 19 3,215' 2,306’ 4.250 2.992 X/O 3-1/2" NU 10rd Box x 3-1/2" EUE Pin 20 3,216' 2,307’ 4.750 2.992 4.000 Snap Latch Seal Assy w/2' seals 21 3,217' 2,308’ 5.813 4.000 7" 20-29# AS1-X Isolation Packer 22 3,219' 2,309’ 3.500 2.992 3-1/2”EUE8RD 9.2#n l-80 Pup Joint 23 3,225' 2,313’ 4.500 2.813 Map 2.813 "X" Profile Nipple 24 3,230' 2,316’ 5.500 2.992 3-1/2" Production Overshot w/ 3-1/2" EUE Box 25 3,231' 2,317’ 3.500 2.992 Polished Hook-Up Nipple 26 3,269' 2,343’3.920 2.992 3-1/2" L-80 / .008 Gauge GP Screen x 12 (total 360' screen) 27 3,630' 2,588’ 4.250 2.992 X/O 3-1/2" NU 10rd Box x 3-1/2" EUE Pin 28 3,630' 2,588’ 4.750 2.992 Snap Latch Seal Assy w/2' seals 29 3,631' 2,589’ 5.875 4.000 MAP 7" 20-29# Isolation Packer 30 3,633' 2,590’ 5.875 4.090 Packer / Tubing Adapter w/ 3-1/2" EUE Box Down 31 3,641' 2,595’ 4.500 2.813 MAP 2.813 ”X” Profile Nipple 32 3,662' 2,610’ 4.500 2.992 3-1/2" Production Overshot w/ 3-1/2" EUE Box 33 3,664' 2,611’ 3.500 2.992 Polished Hook-Up Nipple 34 3,701' 2,636’3.920 2.992 3-1/2" L-80 / .008 Gauge GP Screen x 5 (total 150' screen) 35 3,852' 2,737’ 4.250 2.50 X/O 3-1/2" NU 10rd Box x 2-7/8" EUE Pin 36 3,852' 2,737’ 4.750 2.438 3.250" Snap Latch Seal Assy w/2' seals 37 3,853' 2,738’ 5.813 3.250 MAP 7" 26-32# Model D Sump Packer As Completed: 11/16/12 As Perfed: 11/12/12 REVISED by CRR: 12/20/23 Steelhead M-16RD PROPOSED SCHEMATIC PERFORATION DATA Zone Top (MD)Btm (MD) Top (TVD) Btm (TVD) FT Date Comments SZ ±1,533’ ±2,300’ ±1,428’ ±1,825’ Future SZ-15 ±2,380’ ±2,575’ ±1,863’ ±1,957’ Future SZ-17 2,756' 2,816' 2,042' 2,072' 60 Nov. 2003 Squeezed SZ ±2,725’ ±2,950’ ±2,028’ ±2,142’ Future SZ-18 2,890' 2,930' 2,110' 2,131' 40 Nov. 2003 Squeezed SZ-19 3,085' 3,100' 2,222' 2,232' 15 11/12/2012 To be isolated 3,118' 3,121' 2,243' 2,245' 3 11/12/2012 To be isolated 3,141' 3,146' 2,257' 2,261' 5 11/12/2012 To be isolated 3,159' 3,203' 2,269' 2,298' 44 11/12/2012 To be isolated SZ-21 3,280' 3,287' 2,350' 2,355' 7 11/8/2012 To be isolated 3,300' 3,307' 2,364' 2,369' 7 11/8/2012 To be isolated 3,333' 3,337' 2,386' 2,389' 4 11/8/2012 To be isolated SZ-22 3,380' 3,428' 2,419' 2,451' 48 11/8/2012 To be isolated 3,428' 3,448' 2,452' 2,465' 20 Nov. 2003 To be isolated SZ-23 3,474' 3,484' 2,483' 2,490' 10 11/8/2012 To be isolated SZ-23A 3,528' 3,531' 2,519' 2,521' 3 11/8/2012 To be isolated 3,551' 3,556' 2,535' 2,538' 5 11/8/2012 To be isolated 3,583' 3,587' 2,556' 2,559' 4 11/8/2012 To be isolated 3,606' 3,618' 2,571' 2,579' 12 11/8/2012 To be isolated 3,531' 3,542' 2,521' 2,529' 11 Nov. 2003 To be isolated Upr A-2 3669’ 3689’ 2614’ 2628’ 20’ 02/19/21 To be isolated A-2 3,725' 3,743' 2,652' 2,664' 12 11/3/2012 To be isolated 3,768' 3,788' 2,681' 2,694' 20 11/3/2012 To be isolated 3,808' 3,843' 2,707' 2,731' 35 11/3/2012 To be isolated 3,748' 3,768' 2,667' 2,681' 20 Nov. 2003 To be isolated 3,788' 3,808' 2,694' 2,707' 20 Nov. 2003 To be isolated SLB Stack Drawing Not Drawn To Scale--- For Reference Only 2 1/16 10M Flanged Plug Valve (Manual) from KP Well Floor HR 580 Injector Head with 72" Gooseneck 4.06" 10K Conventional Stripper – 1.75" C062 Pin Connection Manual 2 1/16 10M Provided by client Blind/Shear Pipe/Slip 4 1/16 10M Combi BOP Lubricator to Injector Head 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 Christianson, Grace K (OGC) From:Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent:Friday, January 5, 2024 8:23 AM To:McLellan, Bryan J (OGC) Cc:Rixse, Melvin G (OGC) Subject:RE: [EXTERNAL] RE: TBU M-16RD (PTD 203-182) RWO Hilcorpwillcommittodumpbail25’ofcementontopoftheCIBPwesetat±2,290’MD Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) From:McLellan,BryanJ(OGC)<bryan.mclellan@alaska.gov> Sent:Thursday,January4,20249:55PM To:RyanRupert<Ryan.Rupert@hilcorp.com> Cc:Rixse,MelvinG(OGC)<melvin.rixse@alaska.gov> Subject:[EXTERNAL]RE:TBUMͲ16RD(PTD203Ͳ182)RWO Ryan, I’mcopyingMelonthisrequestbecauseI’monvacaƟonunƟl1/9andhemayneedtostepinifyouwanttoexecutethis projectbeforeyouhearfromme. BryanMcLellan SeniorPetroleumEngineer AlaskaOil&GasConservationCommission Bryan.mclellan@alaska.gov +1(907)250Ͳ9193 From:McLellan,BryanJ(OGC) Sent:Thursday,January4,20249:42PM CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION:Externalsender.DONOTopenlinksorattachmentsfromUNKNOWNsenders. 2 To:RyanRupert<Ryan.Rupert@hilcorp.com> Subject:TBUMͲ16RD(PTD203Ͳ182)RWO Ryan, ThesundrydoesnotindicatewhereyouplantoleaveTOCinsidethetubing. Pleaseproposeaplantoleavecementontopofeitherthecementretainerat2600’orCIBPat2290’MDto permanentlyisolatethedeeperperfsfromtheperfsattopofpoolat1533’MD. Regards BryanMcLellan SeniorPetroleumEngineer AlaskaOil&GasConservationCommission Bryan.mclellan@alaska.gov +1(907)250Ͳ9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1 Da v i e s , S t e p h e n F ( O G C ) Fr o m : Ma t t h e w P e t r o w s k y < m p e t r o w s k y @ h i l c o r p . c o m > Se n t : We d n e s d a y , J a n u a r y 3 , 2 0 2 4 2 : 2 5 P M To : Da v i e s , S t e p h e n F ( O G C ) Cc : De w h u r s t , A n d r e w D ( O G C ) ; M c L e l l a n , B r y a n J ( O G C ) ; R y a n R u p e r t Su b j e c t : RE : [ E X T E R N A L ] T B U M - 1 6 R D ( P e r m i t 2 0 3 - 1 8 2 , S u n d r y 3 2 3 - 6 8 1 ) - Q u e s t i o n At t a c h m e n t s : M- 1 6 R D L o g D a t a . l a s ; M c A r t h u r R i v e r F i e l d - M - 1 6 R D - M i d d l e K e n a i G a s P o o l C o r s s - S e c t i o n . p d f He l l o St e v e , Iho p e th i s eͲma i l he l p s ad d r e s s so m e of th e qu e s t i o n s yo u ha d in re g a r d to TB U MͲ16 R D (P e r m i t 20 3 Ͳ18 2 , Su n d r y 32 3 Ͳ68 1 ) . Be l o w an d at t a c h e d is su p p o r t i n g in f o r m a t i o n sh o w c a s i n g th e Mi d d l e Ke n a i Ga s Po o l at th e Mc A r t h u r Ri v e r Fi e l d (v i a NͲScr o s s se c t i o n ) as we l l as an LA S of th e MͲ16 R D ’ s lo g da t a . I’ v e in c l u d e d asn a p s h o t of th e De f i n i t i o n of Po o l s se c t i o n fr o m CO 22 8 A , wh i c h me n t i o n s TB U KͲ02 as th e re f e r e n c e we l l fo r th e Mi d d l e Ke n a i Ga s Po o l . Th e cr o s s Ͳse c t i o n in c l u d e d sh o w s th e re l a t i o n s h i p be t w e e n TB U KͲ02 /TB U MͲ18 /TB U MͲ16 R D /MͲ16 . It is fl a t t e n e d on th e SZ Ͳ10 ma r k e r (w i t h th e SZ Ͳ10 zo n e sh a d e d gr e e n to as s i s t in id e n t i f i c a t i o n ) , wh i c h re p r e s e n t s th e To p of th e Mi d d l e Ke n a i Ga s Po o l . Pl e a s e do n ’ t he s i t a t e to re a c h ou t if yo u ha v e an y ad d i t i o n a l qu e s t i o n s an d / o r co n c e r n s . Th a n k yo u . So m e pe o p l e wh o re c e i v e d th i s me s s a g e do n ' t of t e n ge t em a i l fr o m mp e t r o w s k y @ h i l c o r p . c o m . Le a r n wh y th i s is im p o r t a n t 2 3 4 Matthew J. Petrowsky | | | | | | | | | | | Fr o m : Ry a n Ru p e r t <R y a n . R u p e r t @ h i l c o r p . c o m > Se n t : We d n e s d a y , Ja n u a r y 3, 20 2 4 1: 3 6 PM To : Ma t t h e w Pe t r o w s k y <m p e t r o w s k y @ h i l c o r p . c o m > Su b j e c t : FW : [E X T E R N A L ] TB U MͲ16 R D (P e r m i t 20 3 Ͳ18 2 , Su n d r y 32 3 Ͳ68 1 ) Ͳ Qu e s t i o n Ry a n R u p e r t CI O O p s E n g i n e e r ( # 1 3 0 8 8 ) 90 7 - 3 0 1 - 1 7 3 6 ( C e l l ) 90 7 - 7 7 7 - 8 5 0 3 ( O f f i c e ) Fr o m : Da v i e s , St e p h e n F(O G C ) <st e v e . d a v i e s @ a l a s k a . g o v > Se n t : Tu e s d a y , De c e m b e r 26 , 20 2 3 9: 4 2 AM To : Ry a n Ru p e r t <Ry a n . R u p e r t @ h i l c o r p . c o m >; Ju a n i t a Lo v e t t <jl o v e t t @ h i l c o r p . c o m > Cc : De w h u r s t , An d r e w D(O G C ) <an d r e w . d e w h u r s t @ a l a s k a . g o v >; Mc L e l l a n , Br y a n J(O G C ) Su b j e c t : RE : [E X T E R N A L ] TB U MͲ16 R D (P e r m i t 20 3 Ͳ18 2 , Su n d r y 32 3 Ͳ68 1 ) Ͳ Qu e s t i o n Th a n k yo u , Ry a n an d Ju a n i t a . Ha p p y Ho l i d a y s to yo u an d yo u r fa m i l i e s . Th a n k s Ag a i n an d Be We l l , St e v e Da v i e s CA U T I O N : Ex t e r n a l se n d e r . DO NO T op e n li n k s or at t a c h m e n t s fr o m UN K N O W N se n d e r s . 5 AO G C C CO N F I D E N T I A L I T Y NO T I C E : Th i s eͲma i l me s s a g e , in c l u d i n g an y aƩac h m e n t s , co n t a i n s in f o r m a Ɵon fr o m th e Al a s k a Oi l an d Ga s Co n s e r v a Ɵon Co m m i s s i o n (A O G C C ) , St a t e of Al a s k a an d is fo r th e so l e us e of th e in t e n d e d re c i p i e n t ( s ) . It ma y co n t a i n co n Įde n Ɵal an d / o r pr i v i l e g e d in f o r m a Ɵon . Th e un a u t h o r i z e d re v i e w , us e or di s c l o s u r e of su c h in f o r m a Ɵon ma y vi o l a t e st a t e or fe d e r a l la w . If yo u ar e an un i n t e n d e d re c i p i e n t of th i s eͲ ma i l , pl e a s e de l e t e it , wi t h o u t Į rs t sa v i n g or fo r w a r d i n g it , an d , so th a t th e AO G C C is aw a r e of th e mi s t a k e in se n d i n g it to yo u , co n t a c t St e v e Da v i e s at 90 7 Ͳ79 3 Ͳ12 2 4 or st e v e . d a v i e s @ a l a s k a . g o v . Fr o m : Ry a n Ru p e r t <Ry a n . R u p e r t @ h i l c o r p . c o m > Se n t : Fr i d a y , De c e m b e r 22 , 20 2 3 9: 0 0 AM To : Da v i e s , St e p h e n F(O G C ) <st e v e . d a v i e s @ a l a s k a . g o v >; Ju a n i t a Lo v e t t <jl o v e t t @ h i l c o r p . c o m > Cc : De w h u r s t , An d r e w D(O G C ) <an d r e w . d e w h u r s t @ a l a s k a . g o v >; Mc L e l l a n , Br y a n J(O G C ) Su b j e c t : RE : [E X T E R N A L ] TB U MͲ16 R D (P e r m i t 20 3 Ͳ18 2 , Su n d r y 32 3 Ͳ68 1 ) Ͳ Qu e s t i o n I’ l l wo r k on th e s e re q u e s t s . As fo r ti m i n g , as lo n g as we ha d ev e r y t h i n g pr o c e s s e d by Fr i 1/ 5 , th a t wo u l d wo r k ju s t fi n e . Me r r y Ch r i s t m a s Ry a n R u p e r t CI O O p s E n g i n e e r ( # 1 3 0 8 8 ) 90 7 - 3 0 1 - 1 7 3 6 ( C e l l ) 90 7 - 7 7 7 - 8 5 0 3 ( O f f i c e ) Fr o m : Da v i e s , St e p h e n F(O G C ) <st e v e . d a v i e s @ a l a s k a . g o v > Se n t : Th u r s d a y , De c e m b e r 21 , 20 2 3 4: 2 5 PM To : Ry a n Ru p e r t <Ry a n . R u p e r t @ h i l c o r p . c o m >; Ju a n i t a Lo v e t t <jl o v e t t @ h i l c o r p . c o m > Cc : De w h u r s t , An d r e w D(O G C ) <an d r e w . d e w h u r s t @ a l a s k a . g o v >; Mc L e l l a n , Br y a n J(O G C ) Su b j e c t : RE : [E X T E R N A L ] TB U MͲ16 R D (P e r m i t 20 3 Ͳ18 2 , Su n d r y 32 3 Ͳ68 1 ) Ͳ Qu e s t i o n Ry a n , To co n f i r m Hi l c o r p ’ s po o l to p pi c k of 15 3 3 ’ MD in TB U MͲ16 R D , pl e a s e pr o v i d e awe l l Ͳlo g cr o s s se c t i o n th a t de m o n s t r a t e s co r r e l a t i o n of th e Mi d d l e Ke n a i Ga s Po o l to p fr o m th e re f e r e n c e we l l in CO 22 8 A th r o u g h se v e r a l in t e r v e n i n g we l l s to TB U MͲ16 R D . Du e to th e Ho l i d a y se a s o n , I’ l l be in th e of f i c e to m o r r o w , ne x t Tu e s d a y , an d th e n ou t un t i l Ja n u a r y 2nd . Is th e es t i m a t e d st a r t da t e of Ja n u a r y 3rd gi v e n on th e ap p l i c a t i o n fo r m st i l l ac c u r a t e ? CA U T I O N : Ex t e r n a l se n d e r . DO NO T op e n li n k s or at t a c h m e n t s fr o m UN K N O W N se n d e r s . 6 Th a n k s an d Be We l l , St e v e Da v i e s AO G C C CO N F I D E N T I A L I T Y NO T I C E : Th i s eͲma i l me s s a g e , in c l u d i n g an y aƩac h m e n t s , co n t a i n s in f o r m a Ɵon fr o m th e Al a s k a Oi l an d Ga s Co n s e r v a Ɵon Co m m i s s i o n (A O G C C ) , St a t e of Al a s k a an d is fo r th e so l e us e of th e in t e n d e d re c i p i e n t ( s ) . It ma y co n t a i n co n Įde n Ɵal an d / o r pr i v i l e g e d in f o r m a Ɵon . Th e un a u t h o r i z e d re v i e w , us e or di s c l o s u r e of su c h in f o r m a Ɵon ma y vi o l a t e st a t e or fe d e r a l la w . If yo u ar e an un i n t e n d e d re c i p i e n t of th i s eͲ ma i l , pl e a s e de l e t e it , wi t h o u t Į rs t sa v i n g or fo r w a r d i n g it , an d , so th a t th e AO G C C is aw a r e of th e mi s t a k e in se n d i n g it to yo u , co n t a c t St e v e Da v i e s at 90 7 Ͳ79 3 Ͳ12 2 4 or st e v e . d a v i e s @ a l a s k a . g o v . Fr o m : Da v i e s , St e p h e n F(O G C ) Se n t : Th u r s d a y , De c e m b e r 21 , 20 2 3 12 : 3 6 PM To : Ry a n Ru p e r t <Ry a n . R u p e r t @ h i l c o r p . c o m >; Ju a n i t a Lo v e t t <jl o v e t t @ h i l c o r p . c o m > Cc : De w h u r s t , An d r e w D(O G C ) <an d r e w . d e w h u r s t @ a l a s k a . g o v >; Mc L e l l a n , Br y a n J(O G C ) Su b j e c t : RE : [E X T E R N A L ] TB U MͲ16 R D (P e r m i t 20 3 Ͳ18 2 , Su n d r y 32 3 Ͳ68 1 ) Ͳ Qu e s t i o n Ry a n , Ial s o no t i c e d th a t AO G C C al s o do e s n ’ t ha v e di g i t a l we l l lo g da t a fo r th e in i t i a l we l l TB U MͲ16 (P T D 19 7 Ͳ16 2 ) ei t h e r . Co u l d Hi l c o r p pl e a s e pr o v i d e GR , SP (i f av a i l a b l e ) , re s i s t i v i t y , an d po r o s i t y (d e n s i t y , so n i c , an d ne u t r o n , if an y of th e s e ar e av a i l a b l e ) da t a in LA S fo r m a t fo r th i s we l l to o ? Th a n k s , , St e v e Da v i e s AO G C C Fr o m : Da v i e s , St e p h e n F(O G C ) Se n t : Th u r s d a y , De c e m b e r 21 , 20 2 3 10 : 2 8 AM To : Ry a n Ru p e r t <Ry a n . R u p e r t @ h i l c o r p . c o m >; Ju a n i t a Lo v e t t <jl o v e t t @ h i l c o r p . c o m > Cc : De w h u r s t , An d r e w D(O G C ) <an d r e w . d e w h u r s t @ a l a s k a . g o v >; Mc L e l l a n , Br y a n J(O G C ) Su b j e c t : RE : [E X T E R N A L ] TB U MͲ16 R D (P e r m i t 20 3 Ͳ18 2 , Su n d r y 32 3 Ͳ68 1 ) Ͳ Qu e s t i o n 7 Ry a n , AO G C C do e s no t ha v e an y di g i t a l we l l lo g da t a fo r th i s we l l . Co u l d Hi l c o r p pl e a s e pr o v i d e GR , SP (i f av a i l a b l e ) , re s i s t i v i t y , an d po r o s i t y (d e n s i t y , so n i c , an d ne u t r o n , if an y of th e s e ar e av a i l a b l e ) da t a in LA S fo r m a t ? Th a n k s , St e v e Da v i e s AO G C C Fr o m : Ry a n Ru p e r t <Ry a n . R u p e r t @ h i l c o r p . c o m > Se n t : We d n e s d a y , De c e m b e r 20 , 20 2 3 4: 3 5 PM To : Da v i e s , St e p h e n F(O G C ) <st e v e . d a v i e s @ a l a s k a . g o v >; Ju a n i t a Lo v e t t <jl o v e t t @ h i l c o r p . c o m > Cc : De w h u r s t , An d r e w D(O G C ) <an d r e w . d e w h u r s t @ a l a s k a . g o v >; Mc L e l l a n , Br y a n J(O G C ) Su b j e c t : RE : [E X T E R N A L ] TB U MͲ16 R D (P e r m i t 20 3 Ͳ18 2 , Su n d r y 32 3 Ͳ68 1 ) Ͳ Qu e s t i o n Th e to p pe r f re q u e s t e d in th e su n d r y eq u a l s to p po o l . 15 3 3 ' MD Ry a n Ru p e r t 90 7 Ͳ30 1 Ͳ17 3 6 ͲͲ Ͳ Ͳ Ͳ Ͳ Ͳ Ͳ Or i g i n a l me s s a g e Ͳ Ͳ Ͳ Ͳ Ͳ Ͳ Ͳ Ͳ Fr o m : "D a v i e s , St e p h e n F(O G C ) " <st e v e . d a v i e s @ a l a s k a . g o v > Da t e : 12 / 2 0 / 2 3 4: 0 1 PM (G M T Ͳ09 : 0 0 ) To : Ry a n Ru p e r t <Ry a n . R u p e r t @ h i l c o r p . c o m > Cc : "D e w h u r s t , An d r e w D(O G C ) " <an d r e w . d e w h u r s t @ a l a s k a . g o v >, "M c L e l l a n , Br y a n J(O G C ) " Su b j e c t : [E X T E R N A L ] TB U MͲ16 R D (P e r m i t 20 3 Ͳ18 2 , Su n d r y 32 3 Ͳ68 1 ) Ͳ Qu e s t i o n Ry a n , CA U T I O N : T h i s e m a i l o r i g i n a t e d f r o m o u t s i d e t h e S t a t e o f A l a s k a m a i l s y s t e m . D o n o t c l i c k l i n k s o r o p e n a t t a c h m e n t s u n l e s s y o u r e c o g n i z e t h e se n d e r a n d k n o w t h e c o n t e n t i s s a f e . CA U T I O N : Ex t e r n a l se n d e r . DO NO T op e n li n k s or at t a c h m e n t s fr o m UN K N O W N se n d e r s . 8 Pl e a s e pr o v i d e th e me a s u r e d de p t h fo r Hi l c o r p ’ s pi c k fo r th e to p of th e Mi d d l e Ke n a i Ga s Po o l in TB U MͲ16 R D . Th a n k s an d Be We l l , St e v e Da v i e s AO G C C CO N F I D E N T I A L I T Y NO T I C E : Th i s eͲma i l me s s a g e , in c l u d i n g an y at t a c h m e n t s , co n t a i n s in f o r m a t i o n fr o m th e Al a s k a Oi l an d Ga s Co n s e r v a t i o n Co m m i s s i o n (A O G C C ) , St a t e of Al a s k a an d is fo r th e so l e us e of th e in t e n d e d re c i p i e n t ( s ) . It ma y co n t a i n co n f i d e n t i a l an d / o r pr i v i l e g e d in f o r m a t i o n . Th e un a u t h o r i z e d re v i e w , us e or di s c l o s u r e of su c h in f o r m a t i o n ma y vi o l a t e st a t e or fe d e r a l la w . If yo u ar e an un i n t e n d e d re c i p i e n t of th i s eͲ ma i l , pl e a s e de l e t e it , wi t h o u t fi r s t sa v i n g or fo r w a r d i n g it , an d , so th a t th e AO G C C is aw a r e of th e mi s t a k e in se n d i n g it to yo u , co n t a c t St e v e Da v i e s at 90 7 Ͳ79 3 Ͳ12 2 4 or st e v e . d a v i e s @ a l a s k a . g o v Th e i n f o r m a t i o n c o n t a i n e d i n t h i s e m a i l m e s s a g e i s c o n f i d e n t i a l a n d m a y b e l e g a l l y p r i v i l e g e d a n d i s i n t e n d e d o n l y f o r t h e u s e of t h e i n d i v i d u a l o r e n t i t y n a m e d a b o v e . I f y o u a r e n o t a n i n t e n d e d r e c i p i e n t o r i f y o u h a v e re c e i v e d t h i s m e s s a g e i n e r r o r , y o u a r e h e r e b y n o t i f i e d t h a t a n y d i s s e m i n a t i o n , d i s t r i b u t i o n , o r c o p y o f t h i s e m a i l i s s t r i c t l y p r o h i b i t e d . I f y o u h a v e r e c e i v e d t h i s e m a i l i n e r r o r , p l e a s e i m m e d i a t e l y n o t i f y u s b y r e t u r n e m a i l or t e l e p h o n e i f t h e s e n d e r ' s p h o n e n u m b e r i s l i s t e d a b o v e , t h e n p r o m p t l y a n d p e r m a n e n t l y d e l e t e t h i s m e s s a g e . Wh i l e a l l r e a s o n a b l e c a r e h a s b e e n t a k e n t o a v o i d t h e t r a n s m i s s i o n o f v i r u s e s , i t i s t h e r e s p o n s i b i l i t y o f t h e r e c i p i e n t t o e n s ur e t h a t t h e o n w a r d t r a n s m i s s i o n , o p e n i n g , o r u s e o f t h i s m e s s a g e a n d a n y a t t a c h m e n t s w i l l n o t ad v e r s e l y a f f e c t i t s s y s t e m s o r d a t a . N o r e s p o n s i b i l i t y i s a c c e p t e d b y t h e c o m p a n y i n t h i s r e g a r d a n d t h e r e c i p i e n t s h o u l d c a r r y o u t s u c h v i r u s a n d o t h e r c h e c k s a s i t c o n s i d e r s a p p r o p r i a t e . Th e i n f o r m a t i o n c o n t a i n e d i n t h i s e m a i l m e s s a g e i s c o n f i d e n t i a l a n d m a y b e l e g a l l y p r i v i l e g e d a n d i s i n t e n d e d o n l y f o r t h e u s e of t h e i n d i v i d u a l o r e n t i t y n a m e d a b o v e . I f y o u a r e n o t a n i n t e n d e d r e c i p i e n t o r i f y o u h a v e re c e i v e d t h i s m e s s a g e i n e r r o r , y o u a r e h e r e b y n o t i f i e d t h a t a n y d i s s e m i n a t i o n , d i s t r i b u t i o n , o r c o p y o f t h i s e m a i l i s s t r i c t l y p r o h i b i t e d . I f y o u h a v e r e c e i v e d t h i s e m a i l i n e r r o r , p l e a s e i m m e d i a t e l y n o t i f y u s b y r e t u r n e m a i l or t e l e p h o n e i f t h e s e n d e r ' s p h o n e n u m b e r i s l i s t e d a b o v e , t h e n p r o m p t l y a n d p e r m a n e n t l y d e l e t e t h i s m e s s a g e . Wh i l e a l l r e a s o n a b l e c a r e h a s b e e n t a k e n t o a v o i d t h e t r a n s m i s s i o n o f v i r u s e s , i t i s t h e r e s p o n s i b i l i t y o f t h e r e c i p i e n t t o e n s ur e t h a t t h e o n w a r d t r a n s m i s s i o n , o p e n i n g , o r u s e o f t h i s m e s s a g e a n d a n y a t t a c h m e n t s w i l l n o t ad v e r s e l y a f f e c t i t s s y s t e m s o r d a t a . N o r e s p o n s i b i l i t y i s a c c e p t e d b y t h e c o m p a n y i n t h i s r e g a r d a n d t h e r e c i p i e n t s h o u l d c a r r y o u t s u c h v i r u s a n d o t h e r c h e c k s a s i t c o n s i d e r s a p p r o p r i a t e . Th e i n f o r m a t i o n c o n t a i n e d i n t h i s e m a i l m e s s a g e i s c o n f i d e n t i a l a n d m a y b e l e g a l l y p r i v i l e g e d a n d i s i n t e n d e d o n l y f o r t h e u s e of t h e i n d i v i d u a l o r e n t i t y n a m e d a b o v e . I f y o u a r e n o t a n i n t e n d e d r e c i p i e n t o r i f y o u h a v e re c e i v e d t h i s m e s s a g e i n e r r o r , y o u a r e h e r e b y n o t i f i e d t h a t a n y d i s s e m i n a t i o n , d i s t r i b u t i o n , o r c o p y o f t h i s e m a i l i s s t r i c t l y p r o h i b i t e d . I f y o u h a v e r e c e i v e d t h i s e m a i l i n e r r o r , p l e a s e i m m e d i a t e l y n o t i f y u s b y r e t u r n e m a i l or t e l e p h o n e i f t h e s e n d e r ' s p h o n e n u m b e r i s l i s t e d a b o v e , t h e n p r o m p t l y a n d p e r m a n e n t l y d e l e t e t h i s m e s s a g e . Wh i l e a l l r e a s o n a b l e c a r e h a s b e e n t a k e n t o a v o i d t h e t r a n s m i s s i o n o f v i r u s e s , i t i s t h e r e s p o n s i b i l i t y o f t h e r e c i p i e n t t o e n s ur e t h a t t h e o n w a r d t r a n s m i s s i o n , o p e n i n g , o r u s e o f t h i s m e s s a g e a n d a n y a t t a c h m e n t s w i l l n o t ad v e r s e l y a f f e c t i t s s y s t e m s o r d a t a . N o r e s p o n s i b i l i t y i s a c c e p t e d b y t h e c o m p a n y i n t h i s r e g a r d a n d t h e r e c i p i e n t s h o u l d c a r r y o u t s u c h v i r u s a n d o t h e r c h e c k s a s i t c o n s i d e r s a p p r o p r i a t e . 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 3,958 feet N/A feet true vertical 2,809 feet N/A feet Effective Depth measured 3,868 feet See schematic feet true vertical 2,748 feet See schematic feet Perforation depth Measured depth 3,085 - 3,808 feet True Vertical depth 2,222 - 2,707 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 2,618 (MD) 1,977 (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: TVD 488 measured true vertical Packer 7" 28" 3,956 MD 488 840 measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 160 Casing Pressure STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-182 50-733-20480-01-00 Plugs ADL0018730 Trading Bay Unit M-16RD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-057 20 Authorized Signature with date: Authorized Name: 0 WINJ WAG 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 29 N/A Oil-Bbl 629 Water-Bbl Intermediate N/A Junk 5. Permit to Drill Number: 715 McArthur River Field / Middle enai Gas PoolN/A measured 1,200 3,956 Size 33 Production Casing Structural Liner Length 488 840 Conductor Surface 7,020psi 13-3/8" 9-5/8" 1,200 6,870psi 907 777-8376 8,160psi 836 1,177 2,808 Collapse Katherine O'Connor Katherine.oconnor@hilcorp.com Tubing Pressure 1,950psi 4,760psi 3,450psi 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 10:20 am, Mar 04, 2021 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.03.03 15:29:15 -09'00' Dan Marlowe (1267) DSR-3/4/21 SFD 3/16/2021 K BJM 4/6/21 RBDMS HEW 3/5/2021 As Completed: 11/16/12 As Perfed: 11/12/12 REVISED by JLL: 03/03/21 Steelhead M-16RD SCHEMATIC TD = 3,958’’(MD)/ 2,809’(TVD) PBTD = 3,868’(MD)/ 2,747(TVD) RKB to Hanger = 33.75’ Hangar Type:McEvoy 11”x7” NNSCC Type J BPV 11”x7” 2 3 SZ-17 A-2 4 SZ-18 SZ-22 SZ-23A SZ-21 SZ-19 SZ-23 5 107 6 8 9 10 11 12 13 14 15 16 17 18 20 21 19 29 30 31 32 33 34 3536 37 2223 24 25 26 2728 Upr A-2 TOC 715’ CBL 11/13/2003 1 X On/Off CASING DETAIL SIZE WT GRADE Type ID TOP BTM. 28” Structural Surf. 488’ 13-3/8” 68 K-55 Surface 12.415" Surf 840' 9-5/8” 47 L-80 Intermediate 8.681” Surf 1,200' 7” 29 L-80 Production 6.184" Surf 3,956' TUBING DETAIL 4-1/2” 12.6 L-80 IBT Mod SCC 3.958" Surf 2,618' Note: Window in 9-5/8” at 1,200’ MD (1,177’ TVD) FIT=13 ppg EMW JEWELRY DETAIL No.Depth MD Depth TVD OD ID Item 1 33.75’ 33.75’ CIW 4-1/25" BTC Top and Bottom with "H" BPV 2 472' 472’ 5.500 2.12/3.958 SSSV w/4-1/2” IBT Connections-WL insert (SSSV ID 2.12) 3 1,624' 1,486’ 6.000 3.958 Gas Lift Mandrel 4 2,631' 1,983’ 6.000 3.958 Gas Lift Mandrel 5 2,647' 1,991’ 5.200 3.958 4-1/2" L-80 IBT Flow Coupling 6 2,653' 1,994’ 5.200 3.813 4-1/2" IBT "X" Landing Nipple 7 2,654' 1,994’ 5.200 3.958 4-1/2" L-80 IBT Flow Coupling 8 2,697' 2,014’ 5.200 2.812 X/O 3-1/2” 8RD X 4-1/2” IBT-MOD BX 9 2,698' 2,015’ 5.875 2.813 T-2 On-Off Tool 10 2,700' 2,016’ 5.875 2.992 7" 20-29# AS1-X Retrievable Packer 11 2,971' 2,154’ 5.060 2.992 4.000" Locator Tubing Seal Assy w/6' seals 12 2,972' 2,155’ 5.813 4.000 7" 20-29# AS1-X Isolation Packer 13 2,974' 2,156’ 5.500 4.408 Millout Extension 14 2,979' 2,159’ 6.060 2.992 Packer Bottom Adapter 15 2,986' 2,163’ 4.500 2.813 3-1/2" EUE "X" Landing Nipple 16 2,994' 2,167’ 5.500 2.992 3-1/2" Production Overshot w/ 3-1/2" EUE Box 17 2,994' 2,167’ 3.500 2.992 3-1/2" Hook-Up Nipple w/3-1/2" NU 10rd Pin 18 3,065' 2,209’ 3.920 2.992 3-1/2" L-80 / .008 Gauge GP Screen x 5 (total 150' screen) 19 3,215' 2,306’ 4.250 2.992 X/O 3-1/2" NU 10rd Box x 3-1/2" EUE Pin 20 3,216' 2,307’ 4.750 2.992 4.000 Snap Latch Seal Assy w/2' seals 21 3,217' 2,308’ 5.813 4.000 7" 20-29# AS1-X Isolation Packer 22 3,219' 2,309’ 3.500 2.992 3-1/2”EUE8RD 9.2#n l-80 Pup Joint 23 3,225' 2,313’ 4.500 2.813 Map 2.813 "X" Profile Nipple 24 3,230' 2,316’ 5.500 2.992 3-1/2" Production Overshot w/ 3-1/2" EUE Box 25 3,231' 2,317’ 3.500 2.992 Polished Hook-Up Nipple 26 3,269' 2,343’3.920 2.992 3-1/2" L-80 / .008 Gauge GP Screen x 12 (total 360' screen) 27 3,630' 2,588’ 4.250 2.992 X/O 3-1/2" NU 10rd Box x 3-1/2" EUE Pin 28 3,630' 2,588’ 4.750 2.992 Snap Latch Seal Assy w/2' seals 29 3,631' 2,589’ 5.875 4.000 MAP 7" 20-29# Isolation Packer 30 3,633' 2,590’ 5.875 4.090 Packer / Tubing Adapter w/ 3-1/2" EUE Box Down 31 3,641' 2,595’ 4.500 2.813 MAP 2.813 ”X” Profile Nipple 32 3,662' 2,610’ 4.500 2.992 3-1/2" Production Overshot w/ 3-1/2" EUE Box 33 3,664' 2,611’ 3.500 2.992 Polished Hook-Up Nipple 34 3,701' 2,636’3.920 2.992 3-1/2" L-80 / .008 Gauge GP Screen x 5 (total 150' screen) 35 3,852' 2,737’ 4.250 2.50 X/O 3-1/2" NU 10rd Box x 2-7/8" EUE Pin 36 3,852' 2,737’ 4.750 2.438 3.250" Snap Latch Seal Assy w/2' seals 37 3,853' 2,738’ 5.813 3.250 MAP 7" 26-32# Model D Sump Packer PACKER DETAIL No. MD TVD OD ID Item 10 2,700' 2,016' 5.875 2.992 7" 20-29# AS1-X Retrievable Packer 12 2,972' 2,155' 5.813 4 7" 20-29# AS1-X Isolation Packer 21 3,217' 2,308' 5.813 4 7" 20-29# AS1-X Isolation Packer 29 3,631' 2,589' 5.875 4 MAP 7" 20-29# Isolation Packer 37 3,853' 2,738' 5.813 3.25 MAP 7" 26-32# Model D Sump Packer As Completed: 11/16/12 As Perfed: 11/12/12 REVISED by JLL: 03/03/21 Steelhead M-16RD SCHEMATIC PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Comments SZ-17 2,756' 2,816' 2,042' 2,072' 60 Nov. 2003 Squeezed SZ-18 2,890' 2,930' 2,110' 2,131' 40 Nov. 2003 Squeezed SZ-19 3,085' 3,100' 2,222' 2,232' 15 11/12/2012 Open 3,118' 3,121' 2,243' 2,245' 3 11/12/2012 Open 3,141' 3,146' 2,257' 2,261' 5 11/12/2012 Open 3,159' 3,203' 2,269' 2,298' 44 11/12/2012 Open SZ-21 3,280' 3,287' 2,350' 2,355' 7 11/8/2012 Open 3,300' 3,307' 2,364' 2,369' 7 11/8/2012 Open 3,333' 3,337' 2,386' 2,389' 4 11/8/2012 Open SZ-22 3,380' 3,428' 2,419' 2,451' 48 11/8/2012 Open 3,428' 3,448' 2,452' 2,465' 20 Nov. 2003 Open SZ-23 3,474' 3,484' 2,483' 2,490' 10 11/8/2012 Open SZ-23A 3,528' 3,531' 2,519' 2,521' 3 11/8/2012 Open 3,551' 3,556' 2,535' 2,538' 5 11/8/2012 Open 3,583' 3,587' 2,556' 2,559' 4 11/8/2012 Open 3,606' 3,618' 2,571' 2,579' 12 11/8/2012 Open 3,531' 3,542' 2,521' 2,529' 11 Nov. 2003 Open Upr A-2 3669’ 3689’ 2614’ 2628’ 20’ 02/19/21 Open A-2 3,725' 3,743' 2,652' 2,664' 12 11/3/2012 Open 3,768' 3,788' 2,681' 2,694' 20 11/3/2012 Open 3,808' 3,843' 2,707' 2,731' 35 11/3/2012 Open 3,748' 3,768' 2,667' 2,681' 20 Nov. 2003 Open 3,788' 3,808' 2,694' 2,707' 20 Nov. 2003 Open Upr A-2 3669’ 3689’ 2614’ 2628’ 20’ 02/19/21 Open Well Name Rig API Number Well Permit Number Start Date End Date M-16RD Eline 50-733-20480-01 203-182 2/13/2021 2/19/2021 Daily Operations: 02/19/21 - Friday Arrive OSK heliport. Fly to platform. Arrive platform. Safety meeting w/ SH operations & ELU crew. MIRU ELU. MU tool suite: RS, GR/CCL, Firing Head & w/ 2-375" x 20' Razor Low Swell, 6 spf, 60* Phase perf gun. Surface test Firing Head - PASS. Surface Test GR/CCL - PASS. CCL - Top Shot = 9.20'. Move to well. Pressure Test WLV & Lub = 250 Lo/1500 Hi, replace lubricator O-ring. Repeat Press Test - Pass. T/IA = 17/34. Open Swab & RIH to 3771' CCL. Log up to 3300' CCL. Clean GR from 3690' - 3600' CCL, adjust GR settings & drop down for repeat pass. Log up from 3813' - 3300' CCL w/ same clean GR signature 3690' - 3600'. Down load LAS & pdf copy of logging pass & send for review & approval . Log verified - No Correction. RBIH to 3821' CCL. 3821' CCL log up to 3659.8' CCL (3659.8' CCL + 9.2' CCL - TS = 3669' Top Shot). T/IA = 17/34. Fire 2.375" X 20', 6spf, 60* phase perf gun perforating Zone Upper A2 @ 3669' - 3689'. Log up 200 & POOH'. T = 25 psi & increasing. T/IA = 17/32. At surface, close swab valve & bleed off all pressures. Rig off WH, Perf Gun OOH w/ all shots fired. RD ELU. Secure well, well room & drill deck. Fly crew to beach. Job Complete. Hilcorp Alaska, LLC Well Operations Summary 02/13/21 - Saturday Move over from M-09. MIRU make up gamma/ccl. Test wire. Good test. Make up Gun #1 20', 2.375" 6 spf, 11gram, 60* phase, razor gun. Stab on well, PT Low/High 250/1500. Good test. Bleed down to zero. Open well, WHP 20, Flow rate 650,000. RIH, tag at 2872.6'. Work Eline up and down going different speeds, still not able to make it past tight spot. POOH, RDMO Eline. 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): 3,958'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 Authorized Signature: Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length Size 6,870 psi N/A 488' COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 203-182 50-733-20480-01-00Anchorage, AK 99503 Hilcorp Alaska, LLC Trading Bay Unit M-16RD CO 228A 12.6 / L-80 TVD Burst 2,618' 8,160 psi Tubing Size: MD 3,450 psi836' 1,177' 840' 488'488' 28" 13-3/8" 9-5/8"1,200' 840' 3,956' Perforation Depth MD (ft): 1,200' 3,085 - 3,808 3,956' See schematic Tubing Grade:Tubing MD (ft): 2,222 - 2,707 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. 2/14/2021 4-1/2" Daniel E. Marlowe See schematic 2,809' 3,868' 2,748' 1,020 psi 2,808'7" Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 2:53 pm, Jan 27, 2021 321-057 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.01.27 14:25:25 -09'00' Dan Marlowe (1267) DLB 01/27/2021 X DSR-2/1/21 GAS 10-404 gls 2/3/21 Comm. on Required? Yes 2/3/21 dts 2/3/2021 JLC 2/3/2021 RBDMS HEW 2/3/2021 Well Work Prognosis Well Name:Trading Bay Unit M-16RD API Number: 50-733-20480-01 Current Status:Gas Well Leg:A-1 (SW Corner) Estimated Start Date:02/14/2021 Rig:E-Line Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett Permit to Drill Number:203-182 First Call Engineer:Katherine O’Connor Office: 907-777-8376 Cell: 214-684-7400 Second Call Engineer:Karson Kozub Cell: 907-570-1801 Current Bottom Hole Pressure:735 psi @ 2465’ TVD Maximum Expected BHP:1134 psi @ 2620’ TVD Maximum Potential Surface Pressure:1020 psi Based on 0.1 psi/ft gas gradient Brief Well Summary: The M-16RD well is producing from the Tyonek SZ-19/21/22/23/24 and A-2. This well production is in stable but steady decline since the recompletion/gravel pack completion was installed in November 2012. The objective of this program is to add more perforations uphole in the upper A-2 sand. E-line Procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. 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 Approx 3669 - 3689 ft md) (upper A-2 sand) As Completed: 11/16/12 As Perfed: 11/12/12 REVISED by KDK: 10/28/2020 Steelhead M-16RD TD = 3,958’’(MD)/ 2,809’(TVD) PBTD = 3,868’(MD)/ 2,747(TVD) RKB to Hanger = 33.75’ Hangar Type:McEvoy 11”x7” NNSCC Type J BPV 11”x7” 2 3 SZ-17 A-2 4 SZ-18 SZ-22 SZ-23A SZ-21 SZ-19 SZ-23 5 107 6 8 9 10 11 12 13 14 15 16 17 18 20 21 19 29 30 31 32 33 34 3536 37 2223 24 25 26 2728 TOC 715’ CBL 11/13/2003 1 X On/Off CASING DETAIL SIZE WT GRADE Type ID TOP BTM. 28” Structural Surf. 488’ 13-3/8” 68 K-55 Surface 12.415" Surf 840' 9-5/8” 47 L-80 Intermediate 8.681” Surf 1,200' 7” 29 L-80 Production 6.184" Surf 3,956' TUBING DETAIL 4-1/2” 12.6 L-80 IBT Mod SCC 3.958" Surf 2,618' Note: Window in 9-5/8” at 1,200’ MD (1,177’ TVD) FIT=13 ppg EMW JEWELRY DETAIL No.Depth MD Depth TVD OD ID Item 1 33.75’ 33.75’ CIW 4-1/25" BTC Top and Bottom with "H" BPV 2 472' 472’ 5.500 2.12/3.958 SSSV w/4-1/2” IBT Connections-WL insert (SSSV ID 2.12) 3 1,624' 1,486’ 6.000 3.958 Gas Lift Mandrel 4 2,631' 1,983’ 6.000 3.958 Gas Lift Mandrel 5 2,647' 1,991’ 5.200 3.958 4-1/2" L-80 IBT Flow Coupling 6 2,653' 1,994’ 5.200 3.813 4-1/2" IBT "X" Landing Nipple 7 2,654' 1,994’ 5.200 3.958 4-1/2" L-80 IBT Flow Coupling 8 2,697' 2,014’ 5.200 2.812 X/O 3-1/2” 8RD X 4-1/2” IBT-MOD BX 9 2,698' 2,015’ 5.875 2.813 T-2 On-Off Tool 10 2,700' 2,016’ 5.875 2.992 7" 20-29# AS1-X Retrievable Packer 11 2,971' 2,154’ 5.060 2.992 4.000" Locator Tubing Seal Assy w/6' seals 12 2,972' 2,155’ 5.813 4.000 7" 20-29# AS1-X Isolation Packer 13 2,974' 2,156’ 5.500 4.408 Millout Extension 14 2,979' 2,159’ 6.060 2.992 Packer Bottom Adapter 15 2,986' 2,163’ 4.500 2.813 3-1/2" EUE "X" Landing Nipple 16 2,994' 2,167’ 5.500 2.992 3-1/2" Production Overshot w/ 3-1/2" EUE Box 17 2,994' 2,167’ 3.500 2.992 3-1/2" Hook-Up Nipple w/3-1/2" NU 10rd Pin 18 3,065' 2,209’ 3.920 2.992 3-1/2" L-80 / .008 Gauge GP Screen x 5 (total 150' screen) 19 3,215' 2,306’ 4.250 2.992 X/O 3-1/2" NU 10rd Box x 3-1/2" EUE Pin 20 3,216' 2,307’ 4.750 2.992 4.000 Snap Latch Seal Assy w/2' seals 21 3,217' 2,308’ 5.813 4.000 7" 20-29# AS1-X Isolation Packer 22 3,219' 2,309’ 3.500 2.992 3-1/2”EUE8RD 9.2#n l-80 Pup Joint 23 3,225' 2,313’ 4.500 2.813 Map 2.813 "X" Profile Nipple 24 3,230' 2,316’ 5.500 2.992 3-1/2" Production Overshot w/ 3-1/2" EUE Box 25 3,231' 2,317’ 3.500 2.992 Polished Hook-Up Nipple 26 3,269' 2,343’3.920 2.992 3-1/2" L-80 / .008 Gauge GP Screen x 12 (total 360' screen) 27 3,630' 2,588’ 4.250 2.992 X/O 3-1/2" NU 10rd Box x 3-1/2" EUE Pin 28 3,630' 2,588’ 4.750 2.992 Snap Latch Seal Assy w/2' seals 29 3,631' 2,589’ 5.875 4.000 MAP 7" 20-29# Isolation Packer 30 3,633' 2,590’ 5.875 4.090 Packer / Tubing Adapter w/ 3-1/2" EUE Box Down 31 3,641' 2,595’ 4.500 2.813 MAP 2.813 ”X” Profile Nipple 32 3,662' 2,610’ 4.500 2.992 3-1/2" Production Overshot w/ 3-1/2" EUE Box 33 3,664' 2,611’ 3.500 2.992 Polished Hook-Up Nipple 34 3,701' 2,636’3.920 2.992 3-1/2" L-80 / .008 Gauge GP Screen x 5 (total 150' screen) 35 3,852' 2,737’ 4.250 2.50 X/O 3-1/2" NU 10rd Box x 2-7/8" EUE Pin 36 3,852' 2,737’ 4.750 2.438 3.250" Snap Latch Seal Assy w/2' seals PACKER DETAIL No. MD TVD OD ID Item 10 2,700' 2,016' 5.875 2.992 7" 20-29# AS1-X Retrievable Packer 12 2,972' 2,155' 5.813 4 7" 20-29# AS1-X Isolation Packer 21 3,217' 2,308' 5.813 4 7" 20-29# AS1-X Isolation Packer 29 3,631' 2,589' 5.875 4 MAP 7" 20-29# Isolation Packer 37 3,853' 2,738' 5.813 3.25 MAP 7" 26-32# Model D Sump Packer 03 133/8" 95/8" window 1200ft 7" 28" As Completed: 11/16/12 As Perfed: 11/12/12 REVISED by KDK: 10/28/2020 Steelhead M-16RD PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Comments SZ-17 2,756' 2,816' 2,042' 2,072' 60 Nov. 2003 Squeezed SZ-18 2,890' 2,930' 2,110' 2,131' 40 Nov. 2003 Squeezed SZ-19 3,085' 3,100' 2,222' 2,232' 15 11/12/2012 Open 3,118' 3,121' 2,243' 2,245' 3 11/12/2012 Open 3,141' 3,146' 2,257' 2,261' 5 11/12/2012 Open 3,159' 3,203' 2,269' 2,298' 44 11/12/2012 Open SZ-21 3,280' 3,287' 2,350' 2,355' 7 11/8/2012 Open 3,300' 3,287' 2,364' 2,369' 7 11/8/2012 Open 3,333' 3,337' 2,386' 2,389' 4 11/8/2012 Open SZ-22 3,380' 3,428' 2,419' 2,451' 48 11/8/2012 Open 3,428' 3,448' 2,452' 2,465' 20 Nov. 2003 Open SZ-23 3,474' 3,484' 2,483' 2,490' 10 11/8/2012 Open SZ-23A 3,528' 3,531' 2,519' 2,521' 3 11/8/2012 Open 3,551' 3,556' 2,535' 2,538' 5 11/8/2012 Open 3,583' 3,587' 2,556' 2,559' 4 11/8/2012 Open 3,606' 3,618' 2,571' 2,579' 12 11/8/2012 Open 3,531' 3,542' 2,521' 2,529' 11 Nov. 2003 Open A-2 3,725' 3,743' 2,652' 2,664' 12 11/3/2012 Open 3,768' 3,788' 2,681' 2,694' 20 11/3/2012 Open 3,808' 3,843' 2,707' 2,731' 35 11/3/2012 Open 3,748' 3,768' 2,667' 2,681' 20 Nov. 2003 Open 3,788' 3,808' 2,694' 2,707' 20 Nov. 2003 Open SFD 1/28/2021 3,287'7 Btm: ~3307' MD As Completed: 11/16/12 As Perfed: 11/12/12 REVISED by JLL: 01/21/2021 Steelhead M-16RD PROPOSED TD = 3,958’’(MD)/ 2,809’(TVD) PBTD = 3,868’(MD)/ 2,747(TVD) RKB to Hanger = 33.75’ Hangar Type:McEvoy 11”x7” NNSCC Type J BPV 11”x7” 2 3 SZ-17 A-2 4 SZ-18 SZ-22 SZ-23A SZ-21 SZ-19 SZ-23 5 107 6 8 9 10 11 12 13 14 15 16 17 18 20 21 19 29 30 31 32 33 34 3536 37 2223 24 25 26 2728 Upr A-2 TOC 715’ CBL 11/13/2003 1 X On/Off CASING DETAIL SIZE WT GRADE Type ID TOP BTM. 28” Structural Surf. 488’ 13-3/8” 68 K-55 Surface 12.415" Surf 840' 9-5/8” 47 L-80 Intermediate 8.681” Surf 1,200' 7” 29 L-80 Production 6.184" Surf 3,956' TUBING DETAIL 4-1/2” 12.6 L-80 IBT Mod SCC 3.958" Surf 2,618' Note: Window in 9-5/8” at 1,200’ MD (1,177’ TVD) FIT=13 ppg EMW JEWELRY DETAIL No.Depth MD Depth TVD OD ID Item 1 33.75’ 33.75’ CIW 4-1/25" BTC Top and Bottom with "H" BPV 2 472' 472’ 5.500 2.12/3.958 SSSV w/4-1/2” IBT Connections-WL insert (SSSV ID 2.12) 3 1,624' 1,486’ 6.000 3.958 Gas Lift Mandrel 4 2,631' 1,983’ 6.000 3.958 Gas Lift Mandrel 5 2,647' 1,991’ 5.200 3.958 4-1/2" L-80 IBT Flow Coupling 6 2,653' 1,994’ 5.200 3.813 4-1/2" IBT "X" Landing Nipple 7 2,654' 1,994’ 5.200 3.958 4-1/2" L-80 IBT Flow Coupling 8 2,697' 2,014’ 5.200 2.812 X/O 3-1/2” 8RD X 4-1/2” IBT-MOD BX 9 2,698' 2,015’ 5.875 2.813 T-2 On-Off Tool 10 2,700' 2,016’ 5.875 2.992 7" 20-29# AS1-X Retrievable Packer 11 2,971' 2,154’ 5.060 2.992 4.000" Locator Tubing Seal Assy w/6' seals 12 2,972' 2,155’ 5.813 4.000 7" 20-29# AS1-X Isolation Packer 13 2,974' 2,156’ 5.500 4.408 Millout Extension 14 2,979' 2,159’ 6.060 2.992 Packer Bottom Adapter 15 2,986' 2,163’ 4.500 2.813 3-1/2" EUE "X" Landing Nipple 16 2,994' 2,167’ 5.500 2.992 3-1/2" Production Overshot w/ 3-1/2" EUE Box 17 2,994' 2,167’ 3.500 2.992 3-1/2" Hook-Up Nipple w/3-1/2" NU 10rd Pin 18 3,065' 2,209’ 3.920 2.992 3-1/2" L-80 / .008 Gauge GP Screen x 5 (total 150' screen) 19 3,215' 2,306’ 4.250 2.992 X/O 3-1/2" NU 10rd Box x 3-1/2" EUE Pin 20 3,216' 2,307’ 4.750 2.992 4.000 Snap Latch Seal Assy w/2' seals 21 3,217' 2,308’ 5.813 4.000 7" 20-29# AS1-X Isolation Packer 22 3,219' 2,309’ 3.500 2.992 3-1/2”EUE8RD 9.2#n l-80 Pup Joint 23 3,225' 2,313’ 4.500 2.813 Map 2.813 "X" Profile Nipple 24 3,230' 2,316’ 5.500 2.992 3-1/2" Production Overshot w/ 3-1/2" EUE Box 25 3,231' 2,317’ 3.500 2.992 Polished Hook-Up Nipple 26 3,269' 2,343’3.920 2.992 3-1/2" L-80 / .008 Gauge GP Screen x 12 (total 360' screen) 27 3,630' 2,588’ 4.250 2.992 X/O 3-1/2" NU 10rd Box x 3-1/2" EUE Pin 28 3,630' 2,588’ 4.750 2.992 Snap Latch Seal Assy w/2' seals 29 3,631' 2,589’ 5.875 4.000 MAP 7" 20-29# Isolation Packer 30 3,633' 2,590’ 5.875 4.090 Packer / Tubing Adapter w/ 3-1/2" EUE Box Down 31 3,641' 2,595’ 4.500 2.813 MAP 2.813 ”X” Profile Nipple 32 3,662' 2,610’ 4.500 2.992 3-1/2" Production Overshot w/ 3-1/2" EUE Box 33 3,664' 2,611’ 3.500 2.992 Polished Hook-Up Nipple 34 3,701' 2,636’3.920 2.992 3-1/2" L-80 / .008 Gauge GP Screen x 5 (total 150' screen) 35 3,852' 2,737’ 4.250 2.50 X/O 3-1/2" NU 10rd Box x 2-7/8" EUE Pin 36 3,852' 2,737’ 4.750 2.438 3.250" Snap Latch Seal Assy w/2' seals PACKER DETAIL No. MD TVD OD ID Item 10 2,700' 2,016' 5.875 2.992 7" 20-29# AS1-X Retrievable Packer 12 2,972' 2,155' 5.813 4 7" 20-29# AS1-X Isolation Packer 21 3,217' 2,308' 5.813 4 7" 20-29# AS1-X Isolation Packer 29 3,631' 2,589' 5.875 4 MAP 7" 20-29# Isolation Packer 37 3,853' 2,738' 5.813 3.25 MAP 7" 26-32# Model D Sump PackerUpr A-2 As Completed: 11/16/12 As Perfed: 11/12/12 REVISED by JLL: 01/21/2021 Steelhead M-16RD PROPOSED PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Comments SZ-17 2,756' 2,816' 2,042' 2,072' 60 Nov. 2003 Squeezed SZ-18 2,890' 2,930' 2,110' 2,131' 40 Nov. 2003 Squeezed SZ-19 3,085' 3,100' 2,222' 2,232' 15 11/12/2012 Open 3,118' 3,121' 2,243' 2,245' 3 11/12/2012 Open 3,141' 3,146' 2,257' 2,261' 5 11/12/2012 Open 3,159' 3,203' 2,269' 2,298' 44 11/12/2012 Open SZ-21 3,280' 3,287' 2,350' 2,355' 7 11/8/2012 Open 3,300' 3,287' 2,364' 2,369' 7 11/8/2012 Open 3,333' 3,337' 2,386' 2,389' 4 11/8/2012 Open SZ-22 3,380' 3,428' 2,419' 2,451' 48 11/8/2012 Open 3,428' 3,448' 2,452' 2,465' 20 Nov. 2003 Open SZ-23 3,474' 3,484' 2,483' 2,490' 10 11/8/2012 Open SZ-23A 3,528' 3,531' 2,519' 2,521' 3 11/8/2012 Open 3,551' 3,556' 2,535' 2,538' 5 11/8/2012 Open 3,583' 3,587' 2,556' 2,559' 4 11/8/2012 Open 3,606' 3,618' 2,571' 2,579' 12 11/8/2012 Open 3,531' 3,542' 2,521' 2,529' 11 Nov. 2003 Open Upr A-2 ±3669’ ±3689’ ±2614’ ±2628’ ±20’ Future Proposed A-2 3,725' 3,743' 2,652' 2,664' 12 11/3/2012 Open 3,768' 3,788' 2,681' 2,694' 20 11/3/2012 Open 3,808' 3,843' 2,707' 2,731' 35 11/3/2012 Open 3,748' 3,768' 2,667' 2,681' 20 Nov. 2003 Open 3,788' 3,808' 2,694' 2,707' 20 Nov. 2003 Open SFD 1/28/2021 3,287'7 Btm: 3307' MD ? Upr A-2 ±3669’±3689’±2614’±2628’±20’Future Proposed RECEIVED • STATE OF ALASKA JAN 15 2013 4 A OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate El Other' Performed: Alter Casing ❑ Pull Tubing El Stimulate - Frac ❑ Waiver ❑ Time ExtensionL I Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development El Exploratory ❑ 203 -182 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphik❑ Service ❑ 6. API Number: Anchorage, AK 99503 50- 733 - 20480 -01 7. Property Designation (Lease Number): 8. Well Name and Number: .r ADL0018730 - Trading Bay Unit / M -16RD 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): r. McArthur River Field / Middle Kenai Gas 11. Present Well Condition Summary: Total Depth measured 3,958 feet Plugs measured None feet true vertical 2,809 feet Junk measured None feet Effective Depth measured 3,868 feet Packer measured See Schematic feet true vertical 2,748 feet true vertical See Schematic feet Casing Length Size MD TVD Burst Collapse Structural 488' 26" 488' 488' Conductor Surface 840' 13 -3/8" 840' 836' 3,450 psi 1,950 psi Intermediate 1,200' 9 -5/8" 1,200' 1,177' 6,870 psi 4,760 psi Production 3,958' 7" 3,958' 2,809' 8,160 psi 7,020 psi Liner Perforation depth Measured depth See Schematic feet CANNED MAR 1 8 2013 True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" L -80 12.6# 2,618" (MD) 1,977' (TVD) Packers and SSSV (type, measured and true vertical depth) (5) Packers - See Schematic SSSV N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Attempted to squeeze perforations @ 2,756' - 2,816' and 2,890' - 2,930' without success. Isolated same between two packers. 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 0 0 260 246 Subsequent to operation: 0 1970 5 100 108 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ -, Gas p WDSPL GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP SPLUGD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -304 Contact Ted Kramer Email tkramer@hilcoro.com Printed Name Ted Kramer Title Sr. Operations Engineer Signaturely Phone 907 777 -8420 Date 1/15/2013 RBDMS JAN 2 8 2013 1 L • Z rq Form 10 -404 Revised 10/2012 A 7/274'1 - Submit Original Only • • Trading Bay Unit • SCHEMATIC Well No.: M -16RD Ilileorp Alaska, LLC Completion 11/18/03 CASING DETAIL RKB to Hanger = 33.75' SIZE WT GRADE Type ID TOP BTM. Hangar Type:McEvoy 11 "x7" NNSCC Type J BPV 11 "x7" 28" Structural Surf. 488' J al 1 13 -3/8" 68 K -55 Surface 12.415" Surf 840' 9 -5/8" 47 L -80 Intermediate 8.681" Surf 1,200' s [ I l 7" 29 L -80 Production 6.184" Surf 3,956' TUBING DETAIL 2 4 -1/2" 12.6 1 L -80 IBT Mod sp. cl. 3.958" Surf 2,618' JEWELRY DETAIL No. Depth OD ID Item 1 0 CIW 4- 1/25" BTC Top and Bottom with "H" BPV 2 472' 5.500 3.958 SSSV w/ 4 -1/2" IBT Connections ME r.� r 3 1,624' 6.000 3.958 Gas Lift Mandrel 4 5 2,631' 6.000 3.958 Gas Lift Mandrel 2,647' 5.200 3.958 4 -1/2" L -80 IBT Flow Coupling 6 2,653' 5.200 3.813 4-1/2" IBT "X" Landing Nipple 7 8 2,654' 5.200 5.200 3.958 2.812 2.813 4 -1/2" L -80 IBT Flow Coupling 2,697' X/0 3 -1/2" 8RD X 4 - 1/2" IBT -MOD BX 9 2,698' 5.875 T -2 On -Off Tool 10 2,700' 5.875 2.992 7" 20 -296 AS1 -X Retrievable Packer 4.000" Locator Tubing Seal Assy w /6' int r�� . 11 2,971' 5.060 2.992 seals 5 6 12 2,972' 5.813 4.000 7" 20 -296 AS1 -X Isolation Packer 7 13 2,974' 5.500 4.408 Millout Extension 14 2,979' 6.060 2.992 Packer Bottom Adapter 15 2,986' 4.500 2.813 3 -1/2" EUE "X" Landing Nipple 9 3 -1/2" Production Overshot w/ 3 -1/2" ::_"-•• ► _ .. . 0 16 2,994' 5.500 2.992 EUE Box :•SZ - 17 2,9994' 3.500 2.992 3 - 1/2" Hook -Up Nipple w/3 -1/2" NU lOrd Pin SZ -18 3 -1/2" L -80 / .008 Gauge GP Screen x 5 1 18 3,065' 3.920 2.992 (total 150' screen) ►_1 IMI r.::::: • 12 1 19 3,215' 4.250 2.992 X/0 3 -1/2" NU lOrd Box x 3 -1/2" EUE Pin fa _MIII 15 20 3,216' 4.750 2.992 4.000 Snap Latch Seal Assy w /2' seals j 116 21 3,217' 5.813 4.000 7" 20 -296 AS1 -X Isolation Packer ammo. 17 22 3,219' 3.500 2.992 3- 1 /2"EUE8RD 9.2#n 1 -80 Pup Joint i 23 3,225' 4.500 2.813 Map 2.813 "X" Profile Nipple : S7- - 24 3,230' 5.500 2.992 3 - 1/2" Production Overshot w/ 3 -1/2" EUE Box { 25 3,231' 3.500 2.992 Polished Hook -Up Nipple 18 26 3,269' 3.920 2.992 3 L - / .008 Gauge GP Screen x 12 - __ (total 360' screen) 2Q �as .I 1 y 27 3,630' 4.250 2.992 X/0 3 -1/2" NU lOrd Box x 3 -1/2" EUE Pin i + 21 28 3,630' 4.750 2.992 Snap Latch Seal Assy w /2' seals • a a -s . 29 3,631' 5.875 4.000 MAP 7" 20 -296 Isolation Packer 23 1.01/1 Packer /Tubing Adapter w/ 3 -1/2" EUE { �za 30 3,633' 5.875 4.090 Box Down 25 SZ 21 31 3 4.500 2.813 MAP 2.813 "X" Profile Nipple 32 3,662' 4.500 2,992 3 -1/2" Production Overshot w/ 3 -1/2" = -22 EUE Box 26 33 3,664' 3.500 2.992 Polished Hook -Up Nipple cSZ -23 3 -1/2" L - / .008 Gauge GP Screen x 5 34 3,701' 3.920 2.992 (total 150' screen) '= - 23A 35 3,852' 4.250 2.50 X/0 3 - 1/2" NU lOrd Box x 2 - 7/8" EUE Pin 28 ; a ; - 27 • 36 3,852' 4.750 2.438 3.250" Snap Latch Seal Assy w /2' seals , 0 . .. -..1 9 37 3,853' 5.813 3.250 MAP 7" 26 -326 Model D Sump Packer 3116►.ili'. • ' 'g ' , PACKER DETAIL 432 3 No. MD TVD OD ID Item i y 10 2,700' 2,016' 5.875 2.992 7" 20 -296 AS1 -X Retrievable Packer 34 A -2 12 2,972' 2,155' 5.813 4 7" 20 -296 AS1 -X Isolation Packer ' 35 21 3,217' 2,308' 5.813 4 7' 20 -296 AS1 -X Isolation Packer 36 29 3,631' 2,589' 5.875 4 MAP 7" 20 -296 Isolation Packer 37 37 3,853' 2,738' 5.813 3.25 MAP 7" 26 -326 Model D Sump Packer d i .... v...= r` N`-Li TD = 3 958 "(MD) / 2,809'(TVD) Note: Window in 9 -5/8" at 1,200' MD (1,177' TVD) PBTD = 3,868'(MD)/ 2,747(TVD) FIT =13 ppg EMW REVISED by JLL: 01/14/2013 • • Trading Bay Unit • SCHEMATIC Well No.: M -16RD Hilcorp Alaska, LLC Completion 11/18/03 PERFORATION DATA Zone T p( Btm(MD) Top(TVD) Btm(TVD) FT Date Comments SZ -17 2,756' 2,816' 2,042' 2,072' 60 Nov. 2003 Squeezed SZ -18 2,890' 2,930' 2,110' 2,131' 40 Nov. 2003 Squeezed 3,085' 3,100' 2,222' 2,232' 15 11/12/2012 Open SZ 19 3,118' 3,121' 2,243' 2,245' 3 11/12/2012 Open 3,141' 3,146' 2,257' 2,261' 5 11/12/2012 Open 3,159' 3,203' 2,269' 2,298' 44 11/12/2012 Open 3,280' 3,287' 2,350' 2,355' 7 11/8/2012 Open SZ -21 3,300' 3,287' 2,364' 2,369' 7 11/8/2012 Open 3,333' 3,337' 2,386' 2,389' 4 11/8/2012 Open SZ 22 3,380' 3,428' 2,419' 2,451' 48 11/8/2012 Open 3,428' 3,448' 2,452' 2,465' 20 Nov. 2003 Open SZ -23 3,474' 3,484' 2,483' 2,490' 10 11/8/2012 Open 3,528' 3,531' 2,519' 2,521' 3 11/8/2012 Open 3,551' 3,556' 2,535' 2,538' 5 11/8/2012 Open SZ -23A 3,583' 3,587' 2,556' 2,559' 4 11/8/2012 Open 3,606' 3,618' 2,571' 2,579' 12 11/8/2012 Open 3,531' 3,542' 2,521' 2,529' 11 Nov. 2003 Open 3,725' 3,743' 2,652' 2,664' 12 11/3/2012 Open 3,768' 3,788' 2,681' 2,694' 20 11/3/2012 Open A -2 3,808' 3,843' 2,707' 2,731' 35 11/3/2012 Open 3,748' 3,768' 2,667' 2,681' 20 Nov. 2003 Open 3,788' 3,808' 2,694' 2,707' 20 Nov. 2003 Open I REVISED by .ILL: 01/14/2013 • • • 14 Hilcorp Alaska, LLC Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M -16RD 50- 733 - 20480 -01 203 -182 9/8/2012 12/12/2012 Daily Operations; 09/09/12 Sunday Rig up lubricator and pressure test to 250 psi low / 2,500 psi high. RIH with 3.7" GR to 478' and tag SSSV. POOH. RIH with 4" GS w/S prong to 478', latch and POOH with valve. RIH with 2.73" GR to 2,647' and sit down. POOH and discover metal marks on GR. RIH with 2.25" DD bailer to 2,700'. RIH with 2.50" LIB to 2,647' and worked through. P/U 50' - RIH and set back down @ 2,647'. POOH. RIH with 2.25" DD bailer to 3,390' and sit down to 3,395'. POOH and recovered full bailer with sand and mud. RIH with tappered 2.75" LIB to 2,647' with one sit down. POOH and note crescent impression of parted tubing. RIH with 2.30" GR to 2,647' and able to work through. POOH. RIH with 2.50" LIB to 2,647' and able to work through obstruction. POOH and rig down. Skid rig over waterflood. Rig down utility lines, equipment and hoses in NW upper wellbay and transfer to SW upper wellbay. Move rig skid jacks from south to north side of rig. 09/10/1 Mon d8y _ .. { . Finish skiding rig south up to wire line operations on leg A -1 & secure skid operations. Install DSA & XO spoo o n riser, work on chg /out fan shroud on drawworks cooling fan. R /up Extreme Video 1- 11/16" downhole video camera. Test lubricator t/ 250 psi low / 2,500 psi high. RIH and tied into xn nipple @ 2,583'. RIH slowly logging f/ 2,620' t/ 2,826'. Appears tools & LIB was hitting the lip of ID change on XO @ 2,650' & suspect area @ 64.5 deg. POOH and L/D camera. P /up 2.72" GR w/ centrilizers to mimic radial torch assy. RIH t/ set do @ 3,370' wim RKB. POOH. RIH w/ CCL & wt bars. Pull logging pass f/ fill TD 3,378' t/ 2,400' for tie in for cuts. POOH. P /up 1- 9/16" tubing puncher loaded w/ green nose 3/8" - 1/2" holes X 12 @ zero deg phased. RIH and place gun on depth punch tbg f/ 2,527.3' t/ 2,531'. POOH. All shots fired. Rig down. Test lubricator 250 psi low / 2, 500 psi high. RIH with 2.73" GR to 2,872'. Had slight bobble indications @ KOIV's @ 2,109' and 2,662'. POOH and R/D wireline. R/D wireline bridge and hatch covers on SW well bay. Transfer remainder of equipment from NW to SW well bay. Install hatch covers on NW well bay. R/U utility hoses in SW well bay. Start Skiding rig south over Leg A -1. Pump pill train to TBPF. Jim Regg, AOGCC, waived witness of BOP test. Skid rig south and east over M -16RD. Secure stairs, rig jacks and handrails. Install siesmic clamps. Tie in utility lines from upper well bay to rig. R/U koomey lines. Mill 41/2" tubing from well head to rig floor and circulating lines. *Production bleeding down tubing and annulus. Tie in annulus to production header. Test line to 500 psi. Test mud lines to rig floor and riser joint @ 3,000 psi. Ensure stroke counters and PVT's are operational. Install Lo -Torq valve in annulus line and retest @ 500 psi. Pull MP #2 suction screen. 09/12/12 - Wednesday Replace leaking Lo -Torq valve on annulus and retest @ 500 psi. Line up and pump 9.5 ppg 6% KCL down tubing taking returns to production (gas) holding 100 psi back pressure. Pump 20 bbls of sized salt pill and chase with 18 bbls 6% KCL. Shut annulus bull head 20 bbls. Shut down with no pressure increase, allow sized salt pill to soak /set. Line up and pump 28.5 bbl sized salt pill @ 5 bpm /70 psi. Chase with 11.5 bbls 6% KCL. Shut annulus bull head. Allow pill to soak. Prepare pipe skate for transport. Build KCL volume. Pump down tbg taking returns annulus(gas). R/U a -line. Test lubricator @ 2,500 psi. RIH with cutter to 3,221' and tagged fill. 156' high. POOH. Mix KCL volume and build sized salt pill. R/D a -line and R/U slickline unit. Test lubricator @ 2,500 psi. RIH with 2.5" DD bailer to 3,222'. Work down to 3,229'. P/U and set back down @3,223'. POOH. Recover 1/2 cup of clay. C/O to 2.25 DD bailer. RIH and bail 3,229' - 3,246'. Soft to hard -pack clay recovery on 8 bailing runs. Slip & cut & rehead wire / total 10 run t/ 3,246' w/ 25' hole cleaned out. Secure slick line unit. • • Hilcorp Alaska, LLC Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M -16RD 50- 733 - 20480 -01 203 182 9/8/2012 12/12/2012 is � M/U 2.5" DD bailer RIH work tools 3,235' WL RKB. POOH 1/4 full bailer of same sticky, dry, hard packed, clay type mater Fluid level noted @ 1,540' wl rkb. R/D slickline & R/U pump, NPFT & wait on approval to pump. Pump 9.5 ppg 6% KCL dn tbg holding 100 psi back pressure @ 7 bpm @ 160 psi. Pump 17 bbls sized salt pill @ 10.5 ppg & chased it to tbg punch holes w/ 21 bbls of brine shut in annulus & bull headed 2.5 bbls w/ no build up. Left pill 12 bbls high to gravitate in. Nip /down tree & remove to top deck for send in & rebuild. Inspect lift threads, control line plugged. Nip /up BOP's, choke line, kill line, work boat & modify flow nipple. • 09/14/12 - Friday ' N/U BOPE. Finish flanging up choke and kill lines and torquing bolts. Install Koomey hoses and flow nipple. Function test BOPE. Test BOPE @ 250 psi Low / 3,000 psi High with 4 -1/2" and 4" tubulars. Pull two -way check. Jim Regg, AOGCC, waived witness to test @ 1750 hrs on 9- 10 -12. Tested deluge system. Tested all H2S and methane sensors. Circulate down tubing @ 5 bpm /60 - 280 psi taking returns to production with 9.Sppg 6% KCL. Caught fluid @ 21 bbls and returns to surface @ 43 bbls total pumped. Shut down. Pump 17 bbl sized salt pill, chase with 21 bbls KCL and squeeze 18 bbls pill into formation. Pressure increased from 250 psi to 350 psi @ 5 bpm. Well is static at annulus needle valve after 10 minutes. Back out lock -down screws. Pull tubing hanger off seat at 95K up weight. Pull seals out of PBR 22' with little indication of seals pulling out. Line up well on trip tank and establish loss rate @ 7 BPH. Pull tubing hanger to floor and lay down same. Stand back landing joint. Flush flow line to rig pits. POOH standing back 4- 1/2" BTC tubing. Roll up and discard SSSV control line. L/D SSSV and GLM. Install wear ring (Complete recovery of completion string & all SS bands recovered on CC line). P/U fishing bha #1. RIH w/ 4" dp out of derrick t/ 2,564'. Kelly up & establish parameters. Engage & latch fish @ 2,593'. POOH, Work BHA & L/D fish. Complete recovery of PBR + pup + XN nipple + anchor. Monitor well 15 min = static loss @ 10 bph / pull wear ring. Set test plug R/U trip tank on annulus. Chg btm rams t/ 2 -7/8" & top rams t/ 4" & test same. Also test annular on 2 -7/8 ". Test at 250L/3000H. R/D test joint. Install wear bushing. Change out elevators. M/U Drag tooth mill. TIH picking up 1,257.25' - 2 -7/8" DP. RIH w/ DC & jars out of 'derrick. 09/16/12 - Sunda 5'53'3 ,; 35 .; f RIH 4 -3/4" dc & jars and HT38 out of derrick W/ 2 -7/8" clean out assembly t/ 2,600'. Kelly up & establish parameters. Tag top of prk @ 2,622' & enter screen t/ 2,670'. Pull above pkr. Pump 20 bbl sized salt pill. Shut in &t bull head. RIH tag @ 2,816' (perfs, possible salt) wash ream & stage rate up t/ 5 bpm @ 1200 psi t/ 2,873'. RIH t/ 3,179' safety wash t/ tag @ 3,233' wash & ream t/ 10 3,323' wash f/ 3,323' t/ tag @ anchor @ 3,818'. Rotate & recip pipe & Circ clean. Pump bbl high vis sweep while washing each std dn w/ 100 -200% increase @ shakers. POOH t/ 2,611' (above prk). Rotate & recip & circ clean. RIH and tag @ 3,818' with no obstructions noted. Pipe displacement was zero barrels. POOH slowly to 2,611' standing back 4" HT38 drill pipe. POOH standing back 4" HT38 drill pipe to 2 -7/8" clean out string. Suspend operations due to high winds (60 mph +). • • Hilcorp Alaska, LLC HilcorpAlaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M -16RD 50- 733 - 20480 -01 203 -182 9/8/2012 12/12/2012 Daitperations: 09/17/12 - Monday Operations suspended due to high winds (50 mph +) Continue POOD L/D 2 -7/8" Dp clean out assy. R /up a -line. RIH w/ 2.50" Radial torch assy. t/ 2 664' WLM RKB. Tools unable to fall. POOH, add weight bar and RIH w/ same. Pull tie in Y pass & place #1 g p cutter on depth & cut 4" Blank Pup 1' under 5.75" welded lugs @ 3,377' WLM RKB. POOH. Re -build cutter anchor, RIH w/ 2.50" Radial torch assy. Pull tie in pass & place #2 cutter on depth. Unable to get good anchor. POOH chk tools. Change out anchor fingers to longer set. RIH. Correlate to blank pipe at 2,838' and tools shorted out. POOH. Rope socket shorted out /rehead same. RIH and correlate to cut @ 2,844'. Fire 2.50 radial torch. Close anchor and P /U. Tools hung. Worked tool and pulled out of rope socket @ 1800 #. POOH. Mobilize slickline crew for fishing cutter assembly out of hole. R/D a -line unit and spot slickline unit. R/U slickline. RIH with 1 -1/4" JDC overshot w/ 2.72 bell guide. Recover fish @ 2,825' WLM. Full recovery. Cutter had signs of blow back #2 cut @ 4" Blank Pup 1' under 5.75" welded lugs @ 2,844' could be marginal. B/D L/D fish. Rig down slickline. Rig up a -line. Rehead rope socket. RIH w/ 2.50 radial torch cutter assembly. 09/18/12 - Tuesday Continue RIH w/ 2.50" Radial torch assy. Pull pass & Tie in to Pkr & KOIV. Place cutter on depth, sever 4" blank pipe @ 2,657' WLM RKB 7' do from collar leaving 11.81' smooth blank. POOH chk tools, had GP sand in nozzels & signs of blow back. R/D E -line clear floor & skate. P/U BHA #3 PRT. RIH t/ 2,609' establish parameters. Circ. btm up @ 2,616' @ 8 bpm @ 500 psi & wash of top pkr / stab pkr. Pump 20 bbl sized salt pill & balance w/ 19 bbls brine. POOH with Packer and 6'11" 4" tbg cut off. Lay Down Fish. PU BHA #4, RIH to top of fish @ 2,657'. Filled pipe every 5 stands. Ran slowly to prevent surging formation with wash pipe assembly. Establish parameters. Washover screens from 2,657' - 2,855' (cut 2,847') @ 3 BPM /140 psi. Saw slight bridge at top of perfs @ 2,756'. Pumped 10 bbl / 130 vis sweeps every +/- 40' while washing over. POOH to above top of fish @ 2,657'. POOH with BHA #4 wash pipe assembly. Lay down jars, boot basket and one joint of wash pipe. Make up BHA #5 overshot assembly. 10/22/12 - Monday Skid rig to M -16RD. Check well for pressure. Set 2 way check. Nipple down tree and check threads in hanger by screwing in a pup. Nipple up BOPs- risers. Install kill / choke lines. 10/23/12 - Tuesday Make up 4 -1/2" test jt assembly. Test lower rams and floor valve to 250 psi low / 3,000 psi high. Rig down 4 -1/2" test jt assembly. Rig up 4" test jt assembly. Test all BOP equip to 250 psi low / 3,000 psi high. Witness of BOPE test waived via email 10/22/12 by Jim Regg, AOGCC. Perform accumulator test, rig down test equip. Move 7 stands of 3 - 1/2" tbg over in derrick so it wouldn't be behind 4 -1/2" tbg. Rig up to pick up landing jt. Pull two way check- one LDS will not back out more than 1/8 ". Confer with Anchorage office. Decided to remove BOPE and grind down tip of LDS inside tbg spool. Set TWC. N/D BOPE. Set BOPE /riser aside. Secure well to grind LDS off flush with tbg head spool. Visual inspection of LDS shows it to be retracted into spool body enough to allow hgr to pass. The LDS nose has been damaged by pulling hgr across it preventing the LDS from backing out to the normal 4- 5/8". This LDS could only be backed out to 4 -1/8 ". Functioned the other LDS to verify hgr clearance. N/U BOPE. 10/24/12 - Wednesday Nipple up BOPs. Function test. Shell test BOPs to 250 psi low and 3,000 psi high. Rig down test equip. Pull TWC, screw in landing jt. Back out lockdowns on hanger. Pull hanger to floor with 91K up wt, break out and L/D same. POOH with 4 -1/2" tbg, L/D first 4 jts [40' jts], stand the rest 25 stds back in the derrick. Change over to 3 -1/2" handling tools, run 7 stds of 3 -1/2" tbg in hole and POOH laying it down. Rig down tbg tongs. Install wear ring. P/U Mill BHA, RIH w/ Mill BHA - tag cement at 2,668'. Mill cement from 2,668' to retainer at 2,712' DPM. Mill retainer at 2,712' DPM. Mill cement to 2,770'. Clean shaker screens - pump 20 bbl sweep. Mill cement 2,770' - 2,817'. • • 1E4 Hilcorp Alaska, LLC Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M -16RD 50- 733 - 20480 -01 203 -182 9/8/2012 12/12/2012 mauckall1111111r.: 27; Mill hard cement f/ 2,817' t/ 2,920', 30 FPH. Mill soft cement f/ 2,920' t/ 2,962' at 45 to 80 FPH. POOH. L/D Mill BHA. Pick up 7" Scraper BHA. RIH with Bit Scraper to 2,962'. POOH with scraper, L/D scraper BHA. P/U Baker Retreivomatic test packer BHA, RIH set test packer at 2,873' between upper and lower perfs. Online to test csg - well was injecting into lower perfs at 1.2 bpm/ 590 psi - upper perfs were taking fluid. Unseat packer - circ DP. P/U and set packer at 2,736' above upper perfs at 2,756'. On line PT csg to 1,250 psi 10 mins. Conduct injectivity test at 1 bpm / 160 psi - 3 bpm / 290 psi - 5 bpm / 485 psi. Unseat packer, POOH, L/D Baker test packer. M/U RIH with Baker cement retainer. Drill string stacked out going down, POOH with setting tool, leaving cement retainer set at 192'. MU Milling BHA. 7 6[12 Friday � c # ' . d Mill on retainer at 192'. Drilled approximately 1' and retainer fell. Hole took 20 bbls to fill. RIH chasing bottom of retainer. Hung up @ 2,898'. Had to pump and rotate to finish chasing it to bottom [2,962']. Circ. hole clean. POOH and lay down tools. Make up XOs and running tool with retainer. RIH with Baker squeeze retainer set at 2,870'. Establish injection rate -1 bpm /465 psi - 2 bpm /600 psi - pump 5 bbls FIW - PT lines 3,000 psi - pump 20.8 bbls 15.9 ppg- disp 14 bbls /1 bpm 350 psi - SD 10 mins press bled dn to 250 psi - disp 5 bbls more at 1 bpm 450 SD 20 mins press bled dn to 312 psi -disp 5.2 bbls more at 1/2 bpm 475 final psi - total disp 24.2 bbls. CIP at 2130 hrs. Unsting from retainer. Pull 1 std, insert DP wiper and pull 1 std. CBU trace of cement returns. Clean trip tank and pipes, POOH with setting tool, L/D Baker setting tool. Strap and P/U 200' 3 -1/2" tbg off deck to use as stinger. RIH to 2,820', pump and spot 15 bbl LCM pill. Pull 6 stds, monitor well for losses and prep for Braden head squeeze. 10/27 041.4 , , s., v �. � Monitor well for 40 min, 3.3 BBLS loss. Braden head squeeze 3/4 BPM at 200 psi, 10 bbls pumped away. Bled down to 110 psi in 5 min, pump 15 bbls at 3.4 BPM at 220 psi, bled to 140 psi in 5 min. RIH f/ 2,370' t/ 2,820', pump 15 BBL LCM pill and spot as a balanced plug. POOH to 2,370', monitor well for 30 min, 2.8 BBL loss. Perform Braden head squeeze, pump 5 bbls at 3/4 BPM at 195 psi, bled off to 31 psi in 50 min. Pump 7.2 BBLS at 3/4 BPM at 165 psi, bled down to 125 Psi in 5 min. RIH to 2,869', and circ at 6 BPM at 300 psi. Space out and pick up cement equipment. Pump 15 bbls FIW, test lines 1,000 psi, and 3,000 psi. Close hydril and set up to take returns through choke. Pump 7.4 BBLS cement, 5 BBLS FIW, and displace with 22.5 BBLS 9.5 brine. CIP at 1515 hrs. Lay down cement equip. POOH 3 stds. Put wiper ball in pipe and circ pipe clean. Monitor well. Braden head squeeze, Pump 1 BBL . at .2 BPM at 132 psi, pressure bled down to 0 psi in 15 min. Open well up and monitor well. Top of cement went below top of perfs. POOH. P/U 2 jts 3 -1/2" tbg for stinger and stand in derrick. L/D 6 -1/4" Spiral DC out of derrick. WOC. M/U Mill BHA to dress off cement. RIH with Mill BHA to 2,560 +/ -. Circ. cond well prep to wash cement. RIH and tag at 2,779'. Wash / mill soft cement to 2,839'. Stop rotary set 10k down on firm cement. Circ cond well - mix 20 bbls LCM pill. Circ hole clean, pump 15 BBL LCM Pill, leave 7 BBLS in pipe. Shut in and squeeze 7 BBLS into perf at 1/2 BPM and a final pressure of 280 psi. Shut down and monitor pressure for 5 Min. Pressure bled down to 243 psi. POOH to 2,457'. Monitor well for losses, 1/2 bbl loss - 30 mins. Squeeze 3 bbls LCM away, POOH. L/D Mill BHA. M/U 3 -1/2" stinger. RIH to 2,650', Spot 14 bbls LCM leaving it in DP. RIH to 2,839'. R/U cement head and squeeze 15 bbls LCM at 1/2 bpm - 280 psi, monitor well for loss. Prep to cement. Spot 7.7 bbls balance cement across perfs 2,756' - 2,816' - 117' above perfs (2,639'). CIP at 2100 hrs. Pull 4 stands drop DP wiper ball. Circ / clean well - no cement returns. L/D cement head and pup jts. Monitor well for loss. • • Hilcorp Alaska, LLC Hik orpAlaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M -16RD 50- 733 - 20480 -01 203 -182 9/8/2012 12/12/2012 Daily Operations: 10/29/12 - Monday P/U BHA, RIH to 2,566'. Circ. hole clean, pressure test csg to 1,200 psi for 30 min. Wash in hole to 2,659', tag cement. Drill soft cement f/ 2,659' t/ 2,720'. Drill hard cement to 2,858'. CBU, test perfs, pressure up to 400 PSI. Pressure bled down to 286 psi in 5 min. Drill cement f/ 2,858' t/ 2,869'. Drill retainer at 2,870'. Drill hard cement to 2,962', Circ /condition well at 2,962'. Confer with Anchorage Eng prior to drill out of retainer at 2,975'. Bleed off of upper perfs at 2,756', leaving potential of upper perfs taking the pre -pack or unloading on top of tools. Drill cement f/ 2,962' t/ 2,970'. Continue drilling on CIBP at 2,970'. 10/30/12 - Tuesday Drill on BP at 2,975', not making any hole. Break bit and boot baskets, clean boot baskets, make up boot baskets and mill. RIH with mill BHA, Mill on BP at 2,975' - no progress. POOH with mill BHA. L/D mill, empty boot baskets, M/U mill tooth bit w /boot baskets. RIH w /bit BHA, tag BP at 2,975'. Drill on BP at 2,975' w /various weights, rotary and pump speeds. Start weekly BOPE testing choke manifold valves 1 -2 -3. Mill on BP 2,975' - 2,977' broke through, push to 3,865'. Continue testing BOP's. Circ condition well. Monitor well. 10/31/12 - Wednesday Continue POOH. L /D, clean & check BHA. Pull wear ring, wash out stack w/ fire hose & r /up hose f/ annulus to trip tank to monitor well during BOP test. Test BOP 250 psi low / 3,000 psi high. AOGCC witness of test waived by Jim Regg on 10 -29 -12 @ 10:57 hrs. via E -mail. Pull test plug and install wear bushing. R/D test equip. R/U to load MP thru choke @ 2,200 psi @ 7.5 bpm. PU /MU 7" scraper BHA. RIH with 7" scraper BHA tag at 3,865'. Circ / clean well. Pull 2 stds DP flowing. Circ / Cond well to balance out fluid. Continue POOH. L/D 7" scraper BHA. M/U BOT BHA. RIH with BOT pkr, Break circ and set packer at 3,642'. 11/01/12 - Thursday Perform injectivity test w/ packer set @ 3,642' in to A -2 perfs f/ 3,748' t/ 3,808'. POOH w /packer to 2,708' above SZ -17 perfs @ 2,756'. Spot 20 bbl sized salt pill t/ packer & close bypass & bull head 20 bbls @ 1 bpm w/ start psi of 400 psi & max squeeze psi of 600 psi, dn pump = 300 psi, 30 sec = 261 psi, 1 min = 207 psi, 2 -min = 191 psi , 3 -min = 179 psi, 4 -min = 169 psi & 5 min = 159 psi, open bypass. Spot 25 bbl sized salt pill to packer & close bypass & bullhead 17 bbls @ 1 bbp @ 240 psi w/ max squeeze psi of, 280 psi, dn pump 250 psi, 30 sec = 215 psi, 1 min = 211 psi, 2 min = 205 psi, 3 min = 198 psi 5 min = 194 psi. Release packer pull 3 std dump 8 bbl SSP / monitor well. POOH L/D BOT 7" retrieve -o- matic. P/U 6" bit + 2 J -bsk + scraper + 1 J -bsk. RIH tag 3,865'. POOH with scraper BHA. L/D scraper BHA. R/U Wire Line. RIH w /Tri -Point 5.815" gauge ring & junk bsk tag TD @ 3,865'. POOH. P/U Model D sump packer @ 5.813 ". RIH, log on depth and park at 3,840' with top of sump packer at 3,853'. Fire to set packer. Did not set. POOH and check system. RIH with sump packer, unable to go down hole past 2,910'. POOH. L/D packer. P/U Gauge Ring Junk Basket, RIH t/ 3,865'. POOH. RIH with sump packer set down @2,910' (SZ -18 perfs). POOH. L/D E -line. P/U bit scrapers and RIH. 11/02/12 - Friday RIH w/ bit & scrapers. Kelly up rotate, reciprocate, circ & work tools f/ 2,865' t/ 2,955'. RIH tag TD @ 3,865'. Rotate, reciprocate & work tools f/ 3,853' t/ 3,793' & circ btm up. POOH t/ 2,938'. Kelly up rotate, reciprocate, circ & work tools f/ 2,845' t/ 2,938'. Continue POOH. L/D chk & clean BHA. R/U E -line. RIH w/5.815" gauge ring & junk bsk set down @ TD of 3,865'. POOH. P/U Tri- Point 7" 26 -32# model "D" sump packer, tie -in to SLB CBL log Dated 11 -13 -2003 & place on depth w/ top @ 3,853'. Set same w/ good surface indication of fire. POOH. R/D E -line. P/U SLB 4.72" 21 spf 4621 power flow TCP guns. RIH w/ Guns on DP, tag sump packer & snap in & out of same @ 3,853'. P/U Drop ball. R/U lines, test 3,000 psi & space out. Place gun on depth w/ btm shot @ 3,843'. Pressure up on dp t/ 2,060 psi fire guns perf interval A2 sand f/ 3,808' t/ 3,843', f/ 3,768' t/ 3,788' & f/ 3,725' t/ 3,743'. Reverse circ DP volume X2 thru choke to clear gun gas. Monitor well on trip tank for 30 min. Re -tag sump packer to check for fill. POOH to spent guns. Lay down perforation guns. P/U Pre -pack assy run in hole and set @ 3,618'. • • Hilcorp Alaska, LLC Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M -16RD 50- 733 - 20480 -01 203 -182 9/8/2012 12/12/2012 11/03 M, = urday. Circ rate = 3 bpm @ 460 psi / Injection rate =1 bpm = 500 psi, 2 bpm = 700 psi, 3 bpm = 1050 psi / perform pre -pack w/ 375 bbls, 9600# of 30/50 Econo -pack gravel pack sand @ 3 bpm @ 800 psi achieve sand out @ 1500 psi leaving 400# sand in pipe. Open bypass & reverse out Dp volume @ 2.5 bpm @ 75 psi clear sand from pipe. Unseat packer & monitor well. R/D & blow down lines & equipment. POOH. L/D pre -pack assy. P/U 2 -7/8" muled shoe pup jt & XO. RIH w/ stinger on DP Tag sand @ 3,700'. R/U to reverse out. Reverse sand f/ 3,700' t/ 3,862' @ 2.5 BPM /80 psi. POOH 3 stands to 3,574'. Allow sand to settle for 1 hour. Monitor well. RIH and tag @ 3,853'. Reverse into sump packer with stinger to 3,862'. Reverse circulate 1 -1/2 DP volumes. Pull up hole 40'. Allow sand to stabilize 1/2 hour. Re- engage sump packer @ 3,853' ( +9' stinger) without issue. POOH with stinger. 11/04/1 _ `'nday P/U .008 GA screen assy #1 & install inner string. RIH w/ screen assy #1 on Dp. Space out & tag @ 3,851' (2' high). Work tools f/ 3,851' t/ 3,852' (unable to work tools to sump Prk @ 3,852'). POOH to screens, L/D packer & inner string. Stand back screens & blank. P/U muleshoe and RIH to 3,850'. M/U reverse circulating assembly. Found top of sand /obstruction @ 3,852.5'. Reverse circulate down to 3,862' at 4 BPM/185 psi. Reverse circulate 2 drill pipe volumes at 4 BPM /185 psi. Pull up 40' above sump packer. Allow well to stabilize 1 hour. Sting back into sump packer to 3,862' without issue. B/D reverse circulating assembly. POOH with stinger assembly. L/D same. Run gravel pack screens out of derrick. Run inner string and packer assembly and drill collars. RIH with gravel pack assembly #1. 11/05/12 - Mor't ffir � RIH with gravel pack assembly #1. Space out & Snap in & out of sump packer @ 3,853' w/ no problems. Set JS -3 GP packer & test back side t/ 180 psi. R /up & blow thru line. Establish circ rate = 1 bpm = 35 psi, 2 bpm = 160 psi & 3 bpm = 360 psi. Pump 137 bbls w/ total 2600# 30/50 Econo -pack Gravel pack sand @ 3 bpm screened out w/ 1520 psi - re- stressed twice t/ 1500 psi w/ 1850# sand to screens 400# sand to blank = 21.5' blank covered & extra 350# sand to perf = 4.79 PPF w/ total of 86.79 PPF total to perfs. Open bypass & reversed out 2X dp volume (80 bbls @ 4 bpm @ 180 psi) no sand noticed in returns. Release packer. L/D space out pups & POOH 2 std. R/D & blow do lines & Monitor well. POOH for isolation packer assy. L /dn & chk tools. P/U M/U isolation packer BHA. RIH with isolation packer assembly to 3,642'. P/U single joint. P/U 105K, 5/0 90K. Engage hook -up nipple @ 3,661' placing packer @ 3,630'. Pick up to neutral weight. Drop setting ball. Chase with 11 bbls until ball seated. Pressure up in 500 psi increments to 2000 psi two times. Pressured up to 2500 & 3000 psi (ball seat should have sheared). Pressure slowly bleeding off. P/U 4' to check for set (no indication). Slack off to 75K with no downward movement. Discuss, options. Pulled to 195K until setting tool sheared free. Packer set @ 3,623' by calculation. Pull up 19' to tool joint and attempt to circulate. String plugged. Ran back in and tagged top of packer @ +- 3,623'. Monitor well. Blow down top drive. Packer is MAP Oil tools Model 'D'. POOH with setting tool. Recovered setting ball. 11106 ,AZ Chg/out spinner motor on iron roughneck. P /up BOT packer mill assy, RIH tag @ 3,624'. Mill packer f/ 3,624' t/ 3,625.5', packer fell free. RIH tag junk @ 3,630'. Circ clean. POOH for spear assy. L /dn chk & clean BHA. P /up Bowen "C" Dimension spear and RIH. Engage fish @ 3,629'. Set down 10K and push to 3,634'. POOH with minimal drag. No fish. Inspect grapple. No signs of engagement. RIH with same BHA. Engage fish @ 3,633'. Set down 10K and push to 3,637'. P/U with 10 - 20K overpull. POOH slowly with fish due to drag. Complete recovery. Break down fish and spear assembly. Make up scoop head /scraper BHA. RIH with clean out assembly to hook -up nipple @ 3,661'. Swallow hook -up nipple 4' to 3,665'. Pull back up 6'. Circulate bottoms up @ 4 BPM /210 psi. Re- engage hook -up nipple. Stand back one stand. POOH with overshot /scraper assembly. • • Hilcorp Alaska, LLC Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M -16RD 50- 733 - 20480 -01 203 -182 9/8/2012 12/12/2012 Daily Operations: 11/07/12 - Wednesday POOH with Tri -Point scoop head overshot /scraper/ j- basket / magnet assembly. L /down clean & check BHA. P /up & M /up Tri -Point isolation assembly. RIH w/ isolation assy. Space out / Establish parameters P/U = 105k, DN wt = 90k. Engage hook up nipple @ 3,661', drop setting ball & chase down w/ MP @ 1 bpm. Ball on seat w/ 7.4 bbls, pressure up in stages 0 -800 psi. 800 -2,000 psi (saw 3 shifts @ 1,200, 1,520 & 1,750 psi), 2,000 -2,900 & sheared off. P /up & re -tag packer set @ 3,631' w/ scoop head @ 3,664' w/ 3' of engagement w/ hook up nipple. L /down working single & monitor hole. POOH. Check & L /dowi setting tool. Prep to p /up gun assembly #2. M /up safety jt. P /up SLB 4.72" 21 spf 4,621 power flow TCP guns @ 120/60 phased. RIH w/ TCP gun on dp to 3,626'. M/U circulating assembly. Tag and set isolation packer plug @ 3,631' w/ 15K set down. Pick up +/ -8' to put guns on depth. Drop setting ball. Test lines @ 3,000 psi. Fire guns with 2,200 psi. Perforate intervals: SZ 21 (3,280' - 3,287', 3,300' - 3,307', 3,333' - 3,337'), SZ 22 (3,380' - 3,428'), SZ 23 (3,474' - 3,484'), SZ 23A (3,528' - 3,531', 3,551' - 3,556', 3,583' - 3,587', 3,606' - 3,618'). Reverse circulate two drill pipe volumes @ 3 BPM /160 psi. Open bT. Reciprocate pipe to insure free movement. Circulate drill pipe volume due to underbalance. Monitor well and establish loss rate @ 3.2 BPH. B/D circulating assembly and blow down lines. POOH to BHA. Circulate gun gas out of well @ 3 BPM /180 psi. POOH and lay down perforation gun assembly. All shots fired. Loss rate 0.5 BPH. P/U M/U stage 2 pre -pack assembly: Muleshoe, Model JS -3A retrievable packer, X0, 9- 4 -3/4" drill collars, XO = 287.11. RIH with pre -pack assembly to 3,170'. M/U circulating assembly. Set packer @ 3,180'. 11/08/12 - Thursday Test lines t/ 2,500 psi. Establish parameters, circ rate = 2 bpm @ 140 psi & 4 bpm @ 500 psi. Injection rate = 2 bpm @ 470 psi, 3 bpm @ 625 psi. Perform pre -pack w/ total 669 bbls & 20,000# 30/50 Econo -pack gravel pack sand @ 3 bpm @ 600 psi w/ less than 100 psi build up @ 12,500# sand away. Reduce rate to 2 bpm w/ less than 100 psi build up. Reduce rate @ 18,400# sand away t/ 1.5 bpm w/ less than 100 psi build up. Down pump @ 19,200# away & 800# in pipe & let said fall out for 30 min. Bring pump back on line @ 2 bpm w/ 2.8 bbl pumped & sand out @ 1,356 psi / 1,356 -375 psi in one min. Open by -pays reverse circ @ 3.5 bpm @ 160 psi 3x dp volume. First dp volume v/ trace sand back. 2nd dp volume 400# est. back, 3rd dp volume clean. Un -seat packer and monitor well. Blow down all lines. POOH for 2 -7/8" tbg mule shoed stinger for reverse out of sand. L /down GP packer & p /up 2 -7/8" tbg mule shoed stinger. Monitor well. RIH w/ stinger tag sand @ (3,258'- 22' above top shot) = 122.25 PPF to perfs. R /up Reverse out said f/ 3,258' to top packer @ 3,400' @ 3 8PM /110 psi. Had problems with losing 10' - 15' on connections. Increased pump rate to 3.5 BPM /160 psi. Reverse out said from 3,400' to 3,538'. Washing down in 15' increments and then circulating @ 4 BPM /180 psi to clear string. 11/09/12 - Friday Continue washing down and reverse circulating sand in 15' bites f/ 3,538' to Tag @ 3,629.47' @ 3.5 BPM /160 psi. (1 -1/2' high of parker @ 3,631') up rate t/ 4 bpm /180 psi (unable pass perf debris) clear sand from pipe. POOH 4 std t/ 3,397' (above top shot @ 3,280') Monitor hole for one hour 8.0 bph loss rate. RIH dry tag @ 3,629.47'. Blow down lines. POOH for BOT perf debris cleat out assy. L /down 2 -7/8" stinger & p /up perf debris c /out assy. RIH w/ 6" "borium" drag tooth shoe + 5 -3/4" reverse circ junk basket + XO + (3) 4 -3/4" Junk baskets + bit sub + string magnet + 4 -3/4" bumper sub + (9) 4 -3/4" DC's / dry t @ 3,629.5'. P /up / Drop ball & pump to seat & shift reverse basket to reverse mode. Establish parameters up wt 118k, down wt 90k, @ 20 rpm @ 4k tq. 4 bpm = 400 psi, 6 bpm = 880 psi & 8 bpm = 1280psi. Work tools f/ 3,629.5' t/ 3,631'. Down pump & dry tag . Blow down lines & monitor well losses @ 8 bph. POOH slowthru perfs (pulled l0k over @ 3,477' (SZ23 perfs) worked pipe, continue pooh. Break down BHA. M/U BHA. RIH with the 6" "borium" drag tooth shoe + 5 -3/4" reverse circ junk basket + XO + (3) 4 -3/4" Junk baskets + bit sub + string magnet + 4 -3/4" bumper sub + (9) 4 -3/4" Dcs. Dry tagged @ 3,629.5'. P /up / Drop ball & pump to seat & shift reverse basket to reverse mode. Establish parameters up wt 118k, down wt 90k, @ 20 rpm @ 4k tq. 4 bpm = 418 psi, 6 bpm = 780 psi & 8 bpm = 1345psi. Work tools f/ 3,629.5' t/ 3,631'. Dovn pump & dry tag. Blow down lines & monitor static well losses @ 3.2 bph. POOH slowthru perfs saw nothing @ 3,477' (SZ23 perfs), continue POOH. Bred( down BHA. L/D cleanout BHA. M/U Tri -Point 4.880" Short Catch Overshot w/2.625" grapple + X0. RIH overshot BHA on 4" DP to 3,593'. Establish parameters up wt 110k, down wt 90k, ease down and engage protection plug at 3,630'. Set down 15K, P/U and pull free. POOH with overshot BHA. • • 1 Hilcorp Alaska, LLC Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M -16RD 50- 733 - 20480 -01 203 -182 9/8/2012 12/12/2012 11/10/12 - Saturday Continue POOH, recover packer protection plug. Prep to p /up GP screen assembly #2. M /up safety jt. P /up Tri -Point GP screen assembly #2. RIH w/ GP assembly #2 on dp. Tag packer @ 3,631' & snap in & out. Set GP packer @ 3,213'. Circ both ways w/ all dp + 15 k top drive wt (40k) good test. R /up lines test 2,500. Estklish circ rates 1 bpm = 100 psi, 2 bpm = 274 psi & 3 bpm = 650 psi. Perform gra,el pack. Pump 179 bbls w/ total 5,250# 30/50 Econo -pack gravel pack sand @ 3 bpm screened out w/ 1,400 psi - restressed twice t/ 1,400 psi w/ 4,450# sand to screens 500# sand to blank = 25' blank covered & extra 300# sand t/ perfs = 3 PPF w/ total 123.25 PPF total to perfs. Opened by -pass reversed out 3X dp volume w/ trace of sand / unseat packer & released screens. POOH 5 std to get inner string dove screens @ 3,166'. Monitor hole. Blow down lines. POOH for isolation packer assembly. R/U and lay down 12 jts 1.5" inner string. Ste packer and pups on rig floor. M/U model "D" isolation packer, pups, overshot, hookup nipple and XO's. RIH on 4" DP to 3,211', P/U 102k, S/O 89K. Continue S/O and engaged hook -up nipple @ 3,230', continue S/0 to 3,233'. P/U to neutrd weight. Drop setting ball, chased at 1 bpm until ball seated. Pressured up to 3,000 psi and sheared off. P/U and re- tagged packer. Scoop head set at 3,233' w/ 3' of engagement, packer set at 3,217'. Blow down top drive, monitor well for static loss at 1 BPH. POOH lay down running tools. M/U bushing puller. RIH pull wear bushing. R/U BOP test equipment. Set test plug. Fill stack, riser and choke manifold. 11/11/12- Sunday Test BOPE 250 psi low / 3,000 psi high. AOGCC witness waived by Mr. Jim Regg 11 -10 -12 @ 18:03 hrs. R /down test equipment. Set wear ring. M /up safety jt. P /up SLB 4.72" 21 spf 4,621 power flow TCP guns @ 120/60 phased w/ Tri -point protection plug installed. RIH w/ guns on dp tag isolation packer @ 3,216.5' & install protection plug w/ 15k down wt. Drop ball. R /up lines. Place guns on depth w/ Btm shot @ 3,203'. Test lines t/ 1,800 psi. Fire guns & perf interval SZ -19 sand f/ 3,085' - 3,100', 3,118' - 3,121', 3,141' - 3,146', 3,159' - 3,203'. Reverse circ thru choke 3X dp volume to clear gun gas. Open well. Move guns. Monitor well. Blow down & R /down lines. POOH. Check and L/D guns (all shots fired as planned). P /up Pre pack assy. Monitor well. RIH 19 stands DP, 20 jts HWDP and 3 additional stands DP to 2,971'. M/U circulating assembly and set packer at 2,970', 115' above top perf @ 3,085'. Close bag. Test backside at 180 psi. Test lines t/ 2,000 psi. Establish parameters, circ rate = 1 bpm @ 40 psi & 2 bpm @ 150 psi, 3 bpm @ 800 psi. Injection rate = 1 bpm @ 465 psi, 2 bpm @ 618 psi, 3 bpm @ 800 psi. Perform pre -pack w/ total 239 bbls & 7,200 Ibs 30/50 Econo -pack gravel pack sand @ 3 bpm @ 800 psi w/ less than 100 psi build up @ 6,400# sand away. Reduced rate t/ 1.5 bpm w/ less than 100 psi build up. Load pipe w /800# sand. Stop pump @ 6,400# sand away & 800# in pipe & let sand fall out for 30 min. Bring pump back on line @ 2 bpm, 1.5 bbls away pressure built to 730 psi and broke down. Stop pump and let sit an additional 30 min to let sand dehydrate. 11/12/12 - Monday Pump on line @ 1 bpm said out t/ 1,410 psi w/ 2 bbls away/ down pump/ 30 sec = 449 psi, 1 min = 327 psi, 2 min = 110 psi. Restress t/ 1,427 psi w/ .9 bbls away, down pump, 30 sec = 509 psi, 1 min = 360 psi, 2 min = 230 psi. Open bypas reverse circ 4X dp volume. Pull porker loose. Blow down & R/D lines. Monitor well losses @ 7.2 bph. POOH. L/D pre -pork assembly. P /up 2 -7/8" reverse out assembly. Monitor well losses @ 6.9 bph. RIH tag sand @ 3,069' (16' above top perf @ 3,085') = 49.46 PPF to perfs. R/U lines reverse out sand f/ 3,069' t/ 3,213.8' in 15' bites & clearing pipe @ 3 4 -1/2" bpm keeping psi below200 psi. Rotated string 1/2 turn and tagged packer top at 3,215.8'. Reverse circ two pipe volumes until fluid cleaned up and no sand returns. Stop pump and dry tag top of packer twice w /5k at 3,215.8'. R/D reverse circ equipment. POOH 2 stands to get reverse stinger above top perf. Wait 1 hr to allow any sand and debris to settle. RIH two stands and dry tag approx. 3" high (3,215.5'). P/U rotate string 1/2 turn, dry tag again +/- 3" high. Rack back 3 stands, break down reverse circ equipment, blow down circ lines. POOH for Baker cleanout assembly. L/D 2 -7/8" stinger. M/U 6" "borium" dry tooth shoe + 5 -3/4" reverse circ junk basket + XO + (3) 4- 3/4" Junk baskets + bit sub + string magnet + 4 -3/4" bumper sub + (9) 4 -3/4" DC's. RIH 30 staids and a double, dry tag @ 3,216'. P/U / Drop ball & pump to seat & shift reverse basket to reverse mode. Establish parameters up wt 110k, down wt 90k, @ 5 rpm 3k tq. 2 bpm = 80 psi, 4 bpm = 380 psi, 6 bpm = 835 psi & 8 bpm = 1,270psi. Work tools f/ 3,210' t/ 3,216'. Dow pump & dry tag. Blow down lines & monitor static well losses @ 6.4 bph. POOH slowthrough perfs, cont POOH, broke down BHA, had nothing in reverse basket. Static loss at 3.8 bph. M/U 4.880" Short Catch Overshot w/2.625" grapple + XO. RIH with overshot on DP. • • Hilcorp Alaska LLC Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M -16RD 50- 733 - 20480 -01 203 -182 9/8/2012 12/12/2012 Daily open 11/13/12_ Tuesday Continue RIH w/ Tri -Point 4.880" Short Catch Overshot w/2.625" grapple + XO and engage top of plug at 3,213'. Up wt 103K, down wt 88K. Set down 15K on plug. P/U w/ 10K over pull and saw wt drop off. Set down 15K and repeat. POOH 2 stands (above top perf). Monitor well. POOH from 3,024' with plug. Lay down plug and BHA. Rig up to P/U screens. Monitor well at 6.4 BPH Loss. P/U screen assembly #3. Snap latch assembly, 5 sand screens, 2 blanks, polished hook up nipple, 6 jts of inner string, 4 inner string pup jts, clutch jt, Gravel Pack XO tool, Packer, and XO to 3 -1/2' IF. RIH with 3 stands of 4 -3/4" DCs and continue RIH with 4" DP and 4" HWDP. R/U Gravel Pack circ assembly. Snap into packer at 3,216'. Set gravel pack packer at 2,976'. Attempt to test back side with 30K down on packer. No test. Put an extra 15K f/ TD, still no test. Circ down string through ball seat at 4 BPM. Retest back side to 180 PSI and packer held. Test lines to 2,000 psi. Estklish circ rates: 3 BPM at 550 Psi, 2 BPM at 305 Psi, 1 BPM at 60 Psi. Perform gravel pack with 30 -50 sand. Sand out after pumping 2,550 Ibs sand at 3 BPM @1,400 Psi. Shut down and wait until press at 0 Psi. Restress t/ 1,400 psi. 1 Min = 360 psi, 2 Min = 241 Psi, Restress t/ 1,400 Psi (gain, 1 Min = 388 Psi, 2 Min =249 Psi. Reverse circ 2 -1/2 times DP volume. Got bask 200 Ibs sand. Unseat packer and release from hook up nipple. Rig down Gravel pack circ head and pull 3 stands to get inner string above screens. Line up on trip talk to monitor well. Blow down GP circ lines. Static loss at 6.4 BPH. POOH for isolation packer assembly. L/D Tri -Point running tools, 1 -1/2" inner string, remove circ hoses, manifold, handling equipment from rig floor. Static loss at 3.2 BPH. M/U 40.70' of Tri -Point model "D" isol#ion packer assembly, RIH on 4" DP to 2,970'. P/U single DP, up wt 100k, down wt 87k, ease down and engage top of hook up nipple at 2,994', con't S/0 to 2997'. Drop ball and M/U top drive, pump ball down at 2 bpm for 11 bbls and seat ball. Press up in stages 800/2,000/2,800 psi and set packer top at 2,971.65'. L/D single. Monitor well while blow down top drive. R/D circ lines to RFR talk. Static loss at 6.8 BPH. POOH 31 stands. L/D j- hydraulic setting tool. R/U Weatherford tubing tongs. P/U / M/U 4" seal assembly w /6' of seals, pups and X0, 8 jnts 3 -1/2" 9.2# L -80 IBT -Mod tbg, X0, 7" ASI -X retrievtile packer, on -off tool, XO and pup, 1 jt 4.5" 12.6# L -80 IBT tbg. 11/14/12 - Wednesday Cont. RIH w/ flow couplings, X landing nipple, GLM #1, and 4.5" 12.6 #, L -80, IBT -Mod tubing from derrick. (Drifted 4.5" tbg aid pups at 3.77 ") GLM wouldn't go into 7" csg. POOH. GLM has a OD of 6.25 ", ID of csg 6.184 ". La, down GLM, break out OX sub on top of on /off tool. Make up XO back to 4" DP and 4" DP pup. P/U 1 staid 4" DP and run in past BOPs. RIH with seals, 3 -1/2" tbg, and isolation packer on 4" DP. Break circulate and tag packer with seals to confirm depth. Packer at 2,971'. Spot 15 BBL pill with .5% CRW-132. Stab seals into packer. Pump down backside & check for returns up DP. Seas held. Attempt to set Packer by putting right hand turns into the pipe. Started out with 1/2 turns and worked up to 3 turns. Finally picked up on the pipe about 30' and worked it back down. Couldn't see seals going back in due to Packer being already set and not picking up with string. Latch into packer, set down 20K under down and P/U 50K over up weight to ensure packer was set. Packer set at 2,699.85'. Set 20K down on Packer and test backside to 1,000 Psi for 10 min on chat. Attempt to release from Packer by applying left hand turns at 1/2 turn on each attempt. After getting up to 3 turns in the pipe we would apply right hand torque to get turns back in. Finally after numerous attempts we got unlatched from the packer. Pull one stand and blow down TD and lines. POOH and lay down tools. Start cleaning sand out of open top RFR talk. M/U on /off tool w /XO and 5.991" OD GLM. RIH on 4.5" 12.6 #, L -80, IBT -Mod tubing from derrick 23 stands to 2,491'. P/U SSSV. R/U PWS spool aid banding, install control line. Cont. RIH 2 more stands f/ derrick and P/U 3 joints from deck, installing 2 bands per joint on control line. M/U landing joint, ease down and engage packer at 2,700', mark pipe for space out. M/U XO and top drive, rotate string 1 round to left and release from packer no problem. POOH L/D landing jnt. M/U 3.80' + 8.83' space out pups. M/U 4.5" CIW type "H" BPV profile hanger w /pup, connect control line to hanger and test at 4,800 psi f/ 15 min (good). Drain stack /riser, land hanger up weight 90k, down weight 83k, RILDS, L/D landing joints, R/U test pump to annulus and test backside at 1,000 psi f/ 15 min (good) while R/D and remove equipment. P/U "T" bar and install BPV. N/D BOPE. • Hilcorp Alaska, LLC Hilcorp Alaska, LL( Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M -16RD 50- 733 - 20480 -01 203 -182 9/8/2012 12/12/2012 Daily Operations: 11/15/12 - Thursday Cont. N/D BOPE, remove turnbuckles, choke aid kill lines, accumulator hoses, break bottom flange and set stack back to the side, pull two sections of riser. Nipple up tree, test well head flange to 5,000 Psi, and nipple up production lines. Install 2 way check. Test tree to 5,000 Psi. Rig up to lay down DP out of derrick with mouse hole in rotary table. Lay down DP and clean pits. L/D mouse hole and prep to R/U PWS. M/U 4.5" x 3" lubricator sections on tree. R/U and test at 2,000 psi f/5 min, changed out 0 -ring and re -test (good). Spot tools and equipment on rig floor. Spot unit and R/U sheaves. M/U PWS tool assembly. RIH and retrieve SSSV sleeve at 474' WLM. POOH. Rig crewprepping rig service lines for skid. PWS RIH w/ 2.5" RB and pull prong at 3,227' WLM. POOH. RIH w/ 2.25" pump bailer to 3,228' WLM. POOH. No debris in bailer. RIH w/ 3.5" GS and pull PX plug at 3,228' WLM. POOH. RIH w/ 2.5" RB to pull prong at 3,641'. 11/16/12 - Friday RIH w/ 2.5" RB to pull prong at 3,641'. Ran into obstruction and could not get past 3,236'. POOH. RIH w/ 2.25" bailer to top of prong at 3,641'. POOH. No recovery. Run #7, RIH and pull prong off top of plug at 3,641'. Run #8, RIH and retrieve PX plug out of X nipple at 3,644' WLM. Run #9, RIH and pull Dummy valve from GLM at 2,630'. Run #10, RIH and pull Dummy valve from GLM at 1,622'. Run #11, RIH and set valve with 1/4" orifice in GLM at 1,622'. Run #12, RIH and set valve with 5/16" orifice in GLM at 2,630'. Dress retrievable SSSV. Run #13, RIH and set in SSSV. Test valve with production. Pull off of valve and POOH. Rig down slick line. Well turned over to production at 16:10 hrs. Rig up to lay down tubulars out of derrick. L/D 4 3/4" DC - 4" DP from derrick. Blowdown, drain, R/D service lines and ready same for removal from well bay. Prep to remove pipe skate. 12/12/12 - Wednesday Pressure test lubricator to 2,500 psi. RIH w/ 2.25 DD bailer to 476 KB. POOH. RIH w/ 1.75 swedge from 3,200 KB to 3,650 KB and work tool for 1 hour. Continue working tools for additional 1 -1/2 hour with no change. Rig down slickline. Secure well and return to production. • • SlrNSE n[LASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Ted E. Kramer Sr. Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai Gas Pool, TBU M -16RD Sundry Number: 312 -304 Dear Mr. Kramer: 1/45 Au G 2.02 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, „ Cathy V Foerster Chair DATED this l of August, 2012. Encl. RECEIVED • u 4 ex . aV` STATE OF ALASKA O g//57/ 7 ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate p Pull Tubing 0 - Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Complete El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC Development p Exploratory ❑ 203-182 + 3. Address: Stratigraphic ❑ Service ❑ 6. API Number. 3800 Centerpoint Drive, STE 100, Anchorage, AK 99503 50- 733 - 20480 -01 r 00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number property line where ownership or landownership cianges: Spacing Exception Required? Yes ❑ No ❑ Trading Bay Unit / M -16RD ' 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0018730 • McArthur River Field / Middle Kenai Gas 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD ( Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 3,958 •A§ ,P 4' '4 `' - 3,868 2,747 None None Casing Length Size MD TVD Burst Collapse Structural 488' 28" 488' 488' Conductor Surface 840' 13 -3/8" 840' 836' 3,450 psi 1,950 psi Intermediate 1,200' 9 -5/8" 1,200 1,177' 6,870 psi 4,760 psi Production 3,956' 7" 3,956' 2,808' 8,160 psi 7,020 psi Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 4 -1/2" L -80 12.6# 2,618' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): SC -1R Packer, FB -1 Packer and N/A (SSV) 2,619'(MD) & 1,978' (ND), 3,813' (MD) & 2,711' (ND) and N/A (SSV) 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Development — El • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9 /7/2012 Oil ❑ Gas p WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Printed Name Ted E. Kramer Title Sr. Operations Engineer Signature Phone (907) 777 -8420 Date 8/6/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ' t 2. 6rZ Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: • 83OP fcsf / 36012 0 /,75 1 Subsequent Form Required: L� / / 1-7/, r 4 APPROVED BY Approved by: or 'e,w COMMISSIONER THE COMMISSION Date: e j - / Z. RBDMS it G 16 2012 , Iii.--/-": ORIGINAL Form 10 403 Revised 1/2010 �' f Submit in Duplicate 1., l • • Well Work Plan Well: M -16RD Hilcorp Alaska, LLC Date: 08 /04/2012 Well Name: M -16RD API Number: 50- 733 - 20480 -01 Current Status: Gas Producer Leg: Leg Al, SW Corner Slot #4 Estimated Start Date: September 7, 2012 Rig: Steelhead Rig 51 Reg. Approval Req'd? August 30, 2012 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 203 -182 First Call Engineer: Ted Kramer (907) 777 -8420 (0) (985) 867 -0665 (M) Second Call Engineer: Melissa Eisele (907) 777 -83119 (0) AFE Number: Current Bottom Hole Pressure: 510 psi @ 2,707 ND (Calculated from 30 day shut in surface pressure ending approx. July 15 2012 — fropm plot) Maximum Expected BHP: 1150 psi @ 2,579' ND Max. Anticipated Surface Pressure: 300 psi (Using 0.1 psi /ft to surface) /5 — � /(z5 f5q2-- pSL Well Summary M -16RD was completed as a gas producer on 11- 18 -03. The completion plan for this well was to perforate the well in 5 zones (See Current Perforations), install sand screens across the perforated interval and pump a gravel pack to reduce the risk of sand production. This completion was executed as planned until the gravel pack. During this operation a mechanical problem with the sand blender caused an early screen out of the gravel pack. Attempts to re -pump this gravel pack were un- successful. Therefore, sand control was limited to the sand screens. The M -16RD produced well and was making 5 MMscfd at 160 psi ( + / -) in February of this year when it began producing water. The water production was from February to the latter part of May was manageable (10 to 20 bwpd) and the well continued to produce at 5 MMscfd. In late May, the well began producing sand and the well was shut in. It is believed that water production brought sand with it and eventually cut the sand screen allowing sand production to surface. The well was brought back on in late June but at a much lower rate to avoid the water and sand production. Forward Plan: The workover plan for this well is to remove the current completion, squeeze off the suspected water producing zone, perforate additional zones, run screens and gravelpack. Procedure: 1. MIRU Steelhead Rig # 51. 2. ND wellhead and NU BOP stack. Pressure test BOP to 250 psi. low / 3,000 psi high. Note: notify AOGCC 48 hours in advance of test for the opportunity to witness bop test. 3. Kill well with Kill fluid 6% KCL. • • Well Work Plan Well: M -16RD Hilcorp Alaska, LLC Date: 08/04/2012 4. RU E -line. RIH and make cuts at 3372', 2838', and 2650'. MD 5. MU, RIH with Spear and recover latch and PBR Barrel. LD same. 6. MU RIH with SC -1 Pkr Retrieving tool washing as we go to wash sand out of well. Latch and release pkr. POOH and lay down same. 7. MU TIH with 5 -3/4" TSS washpipe washing down over each screen section (3 total) and remove. 8. Remove S -22 Snap latch. 9. TIH with Milling assembly and mill and retrieve BAKER FB -1 packer. 10. RIH with Bit and Scraper and cleen out to TD. POOH with same. 11. PU RBP and RIH to 2975' and set. Dump bail 25' of sand on top of RBP. Q 6 12. PU cement retainer and RIH to 2,020' and set. ? � uv'e 7 13. Cement squeeze perforations from 2,042 - 2930'. POOH with cement string. WOC. s 4,, Liety 14. PU RIH with bit to 2,010'. Drill out cement to 2,950. Wash out sand on top of RBP. POOH with 15. PU workstring, RIH and retrieve RBP at 2,975'. 16. Change well over to completion fluid. 17. RU Schlumberger TCP Perforating and RIH W/ TCP perforating guns and perforate the following zones: Measured Depth Ft. TVD SZ 19 3085 - 3100 15 2222 - 2232 3118 - 3121 3 2243 - 2245 3141 - 3146 5 2257 - 2261 3159 - 3203 44 2269 - 2298 SZ 21 3280 - 3287 7 2350 - 2355 3300 - 3307 7 2364 - 2369 3333 - 3337 4 2386 - 2389 SZ 22 3380 - 3428 48 2419 - 2451 SZ 23 3474 - 3484 10 2483 - 2490 SZ 23A 3528 - 3531 3 2519 - 2521 3551- 3556 5 2535 - 2538 3583 - 3587 4 2556 - 2559 3606 - 3618 12 2571- 2579 A2 3725 - 3743 12 2652 - 2664 • • Well Work Plan Well: M -16RD Hilcorp Alaska, LLC Date: 08/04/2012 3768 — 3788 20 2681— 2694 3808 — 3843 35 2707 — 2731 Total 234 18. RD Schlumberger. 19. PU Completion screens and packers and RIH and Set. 20. RU Gravel Packing Pumping company. Pump Gravel pack according to Gravel Pack procedure. 21. ND BOP NU Well head. APT 6#45/ 22. RU Coil Tubing. Jet in well with Nitrogen. 23. RD Coil tubing. 24. Turn well over to production. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematics • • Trading Bay Unit SCHEMATIC Well No.: M -16RD Ililcorp Alaska, LLC Completion 11/18/03 CASING DETAIL RKB to Hanger = 33.75' SIZE WT GRADE Type ID TOP BTM. Hangar Type: McEvoy 11 "x7" NNSCC Type 1 BPV 11 "x7" 28" Structural Surf. 488' J 1 r 13 -3/8" 68 K -55 Surface 12.415" Surf 840' a l 1 MOP 9 -5/8" 47 L -80 Intermediate 8.681" Surf 1,200' 7" 29 L-80 Production 6.184" Surf 3,956' , l 2 1h1ti� 0 _. „-- - ,s,14. TUBING DETAIL 4 1/2" 12.6 L 80 IBT Mod sp. cl. 3.958" Surf 2,618' MO JEWELRY DETAIL NO. Depth ID Item f . P G �� )( IAA 1 0 CIW 4- 1/25" BTC Top and Bottom with "H" BPV 1 111 a 3 - A I V% 2 476' 3.813" HES XXO Nipple ✓(% A 3 2,541' SMD -1A Gas Lift Mandrel 4 1 4 2,583' X- Nipple 5 \ 5 2,591' PBR MOON" 6 ✓\ 6 2,616' 3.75 XN Nipple -.11111.1107 7, 8 7 2,618' 80 -40 Model "E" Anchor 8 2,619' SC 1R Packer Ii'►� 9 2,650' KOIV Mod C (knocked open) 10 2,677' Baker Excluder 2000 Screen 1 I 11 2,751' Bakerweld 140 12 gauge Screen 1 1 10 12 3,232' Baker Excluder 2000 Screen I I 13 3,269' Bakerweld 140 12 gauge Screen A- , l 14 3,380' Baker Excluder 2000 Screen 11 SZ-17 7'1-64" 'M p 15 3,454' Bakerweld 140 12 gauge Screen I mil? 16 3,565' Baker Excluder 2000 screen =SZ 18 Zia 17 3,813' S -22 Snap Latch a 18 3,813' FB -1 Packer ; I■ 6 Rg+'aa75",M.0 I 12 PERFORATION DATA I I 1 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Comments -- _ SZ -17 2,756' 2,816' 2,042' 2,072' 60 Nov. 2003 Open • SZ -18 2,890' 2,930' 2,110' 2,131' 40 Nov. 2003 Open 13 SZ -22 3,428' 3,448' 2,452' 2,465' 20 Nov. 2003 Open = v SZ -23A 3,531' 3,542' 2,521' 2,529' 11 Nov. 2003 Open !1 U ✓ .' i A -2 3,748' 3,768' 2,667' 2,681' 20 Nov. 2003 Open I I 14 A -2 3,788' 3,808' 2,694' 2,707' 20 Nov. 2003 Open I I 1 I =S Z -22 Note: Window in 9 -5/8" at 1,200' MD (1,177' ND) FIT =13 ppg EMW 15 - - = SZ -23A I III 1 1 I I 1 _A -2 t % ` ti �l .4 PI 18 / i'� TD = 3,958 "(MD) / 2,809'(TVD) PBTD = 3,868'(MD)/ 2,747(TVD) REVISED by TDF: 7/20/12 + • 1110 Trading Bay Unit PROPOSED Well No.: M -16RD Hilcora Alaska, LLC Completion 11/18/03 CASING DETAIL RKB to Hanger = 33.75' SIZE WT GRADE Type ID TOP BTM. Hangar Type McEvoy 11 "x7" NNSCC Type J BPV 11 "x7" 28" Structural Surf. 488' J 1 l 13 - 3/8" 68 K -55 Surface 12.415" Surf 840' 9 5/8" 47 L-80 Intermediate 8.681" Surf 1,200' O 2 7" 29 L-80 Production 6.184" Surf 3,956' TUBING DETAIL 4 -1/2" 12.6 L -80 IBT Mod sp. cl. 3.958" Surf 2,618' All JEWELRY DETAIL 1 L 11 NO. Depth ID Item 4 1 1 0 CIW 4- 1/25" BTC Top and Bottom with "H" BPV IIII MI 3 2 476' 3.813" HES XXO Nipple 3 2,541' SMD -1A Gas Lift Mandrel iIE '' ' 4 -6 4 2,583' X- Nipple 5 ` s 5 2,591' PBR 1•101•11 6 ��■P i 7, 8 A G l `� 6 2,618' 3.75 8N Nipple 7 2,618' 80 -40 Model "E" Anchor 8 2,619' SC -1R Packer 9 9 2,650' KOIV Mod C (knocked open) 10 Packer 11 Gauge Screen j 12 Packer 1 13 Packer 14 Gauge Screen .' SZ -17 15 Packer 16 Packer Z -18 17 Gauge Screen 18 Packer 10 ►_� ►_-o+ PERFORATION DATA 11 - SZ -19 TO (M Zone p Btm(MD) Top(TVD) Btm(TVD) FT Date Comments 12 MI ► D) SZ -17 2,756' 2,816' 2,042' 2,072' 60 Nov. 2003 Squeezed 13 �� loStil SZ -18 2,890' 2,930' 2,110' 2,131' 40 Nov. 2003 Squeezed : ,■•,. , SZ -19 ±3,085' ±3,100' ±2,222' ±2,232' ±15 Future Open / , 'h ±3,280' ±3,287' ±2,350' ±2,355' ±7 Future Open SZ -21 ±3,300' ±3,287' ±2,364' ±2,369' ±7 Future Open ±3,333' ±3,337' ±2,386' ±2,389' ±4 Future Open SZ -21 ±3,380' ±3,428' ±2,419' ±2,451' ±48 Future Open ±3,118' ±3,121' ±2,243' ±2,245' ±3 Future Open 14 51 ` PESZ -22 y„ f • ' , ; .^ SZ -22 ±3,141' ±3,146' ±2,257' ±2,261' ±5 Future Open �{ = ±3,159' ±3,203' ±2,269' ±2,298' ±44 Future Open SZ -23 3,428' 3,448' 2,452' 2,465' 20 Nov. 2003 Open ' `, SZ -23 ±3,474' ±3,484' ±2,483' ±2,490' ±10 Future Open .-' _ SZ -23A ±3,528' ±3,531' ±2,519' ±2,521' ±3 Future Open ):` ., ±3,551' ±3,556' ±2,535' ±2,538' ±5 Future Open 15 ►�� ►�14 SZ -23A ±3,583' ±3,587' ±2,556' ±2,559' ±4 Future Open ±3,606' ±3,618' ±2,571' ±2,579' ±12 Future Open 16 7-7 3,531' 3,542' 2,521' 2,529' 11 Nov. 2003 Open 17 rk.r" A -2 ±3,725' ±3,743' ±2,652' ±2,664' ±12 Future Open 18 . ` . 4 4 ■1 ±3,768' ±3,788' ±2,681' ±2,694' ±20 Future Open A -2 ±3,808' ±3,843' ±2,707' ±2,731' ±35 Future Open 3,748' 3,768' 2,667' 2,681' 20 Nov. 2003 Open TD = 3,958 "(MD) / 2,809'(TVD) 3,788' 3,808' 2,694' 2,707' 20 Nov. 2003 Open PBTD = 3,868'(MD)/ 2,747(TVD) Note: Window in 9 -5/8" at 1,200' MD (1,177' TVD) FIT =13 ppg EMW REVISED by TDF: 7/20/12 II • • BOP SCHEMATIC Hilcorp Alaska, LLC Trading Bay Unit Well No.: M -16RD Completion 11/18/03 Rig floor BoR rddp pan 1 e>s• 22" pipe for air boot flanges 9.43' 5.10' Hydril i 1 I I I C U 5.46' 16 a.- 000 _ ktoonpool deck top to wellhead room Mar 055 95 1 1 1 1 1 Top of 1tnpool 0 deck 98• { , rf • 1 .. If � II " 1II:,Q 3.00' r I I r 3.56' 1 1 1 1 1 DSA16% 10M X 16% 5M 1 66' 1 1 1 1 1 44 y 1 S5' flange above rq sub grating Rig sub gratin •• Riser, 16'% 5M API hub X 16 3/4 10M FE Upper Wellhead Room to Rlg Sub Grating 23 4]' 1 5 3S clamp above Moor ♦ Upper wellhead room floor Riser, 16 % 5M FE X 16 a /. 5M API hub 11 I Wellhead Moor b Upper We1Ree8 Room . — _ *f ^�� ikr'1 -I ■,e., I J , �, I � ari ii _ 1 r, �� It rll ` +I RFVISFn by JLL: 08/06/2012 • • ~~~~ FrdnCI5C0 Castro Chevron North America Exploration and Production -,~! Technical Assistant 3800 Centerpoint Dr. Suite 100 '~ > -;` ~ Anchorage, AK 99503 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com DATE June 28, 2010 ~-~ ~ ;~ ,~ =,~ -, To: AOGCC Mahnken, Christine R _ ~ F~ ~ ~~' 333 W. 7th Ave. Ste# 100 .~~f~s~;`~~~;: ~.) ~~ ~ ; ~ f..11~~1.3 Anchorage, AK 99501 _ ~~ ~ ~ " . ~. Transmitted herewith is one DVD containing the following data. • D-48L1 • Formation evaluation logs -LAS ~ ~ .~~~.d /~j~ (~~ / 1 • Gamma ray logs -LAS • K-12RD2 -~ ~Q~-151 l ~ ~~~ • K-12RD2_Final_Survey.xls l Q! ~ ~ • K-12RD2_Tops.xlsx ~~~ -~~ • MPR-Gamma ray logs -LAS, CGM, PDF K-18RD / 9 ~ ~ • ~D/ _//~ • K-18RD_Final_Survey.doc l -LAS D it N t 19 ~S~ ~ ron • ens y eu ogs ~b ~ _ /N ~ • K-18RDPB1 • UBI log -LAS, PDS, DLIS ~~ ,y y ~ ~b ~ • survey.xls • K-24RD2 ~ 9 ~ j ~ X153-/~a • Density Neutron logs -LAS --- • Final Mudlog Report -LAS, DOC c~0~ 'f~ C) 19 'Ff t, • M-06 • Final logs; Depth, Formation Evaluation, Realtime, Time -LAS, PDS, DLIS • M-lOTops.xlsx • USIT log -PDS t~U9 -d 5' 3 l ~ ~,~ • Final logs; Depth, Formation Evaluation, Realtime, Time -LAS, PDS, DLIS • M-10PB1 • Final logs; Depth, Formation Evaluation, Realtime, Time -LAS, PDS, DLIS _ /~ • M-16RD_Tops.xlsx • Final logs; Cement Bond Log, Completion Record -PDS • M-17 M-17_Tops.xlsx • M17_MWD_Survey.pdf • Final Mudlog Report -LAS, DOC, DBF, MDX, PDF, DAT • Final logs; Depth, Formation Evaluation, Cement Bond, Plug Setting, Perforation - LAS, PDS, DLIS, TIFF Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: Date: I~ • • MICROFILMED 03/01/2008 DO NOT PLACE ,," ," ~,~;_ ~_ ,~~ . k_:. =~~ ~: f ANY NEW MATERIAL UNDER THIS PAGE F:\I,aserFiche\CvrPgs_Inserts~Microfilm_Marker.doc Iq~ DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 Permit to Drill 2031820 Well Name/No. TRADING BAY UNIT M-16RD Operator UNION OIL CO OF CALIFORNIA 1 . it ~ LA. ~ tc ('" '.;j J.v.¡v1 ) API No. 50-733-20480-01-00 D(ù'^-- ~~ ~ 0,(,.,., /~, J 9":~/~J t vV",N,LI~ \)st\V't- \)'^'~~'^ C C'JL,àQ.C1l~¿ I~-- MD 3958,...---" TVD 2566 ./ Completion Date 11/19/2003 /' Completion Status 1-GAS ~_____··_.M_'_'._ REQUIRED INFORMATION Mud Log No Samples No ----,-_.~ DATA INFORMATION Types Electric or Other Logs Run: LWD, GR, N/D, Res Well Log Information: Logl Electr Data Digital Dataset Type Med/Frmt Number Name Log Log Run Scale Media No 5 BM 2 2 BM 2 ._~------~ ~ ! Cement Evaluation c/o C Las 12441 Completion Q.'(' .}¡Jv~ ~ ED C Pds 12441 Completion ~-- Completion Well Cores/Samples Information: Name Interval Start Stop Sent ADDITIONAL INFORMATION Well Cored? Y ~. Daily History Received? Chips Received? '''''YTN Formation Tops Analysis Received? ~ ---_.,-,.~--- Comments: M í\s l ~ Compliance Reviewed By: Current Status 1-GAS UIC N ____·~·_m_..__....~_.__~_____ ___ -------- Directional surveC~Y~~~._.___ (data taken from Logs Portion of Master Well Data Maint Interval OH 1 Start Stop CH ---~--~ . Received Comments Received 500 3859 Case 2/261.2004 CE¿ment Bond Log 2755 3806 Gase 2/2612004 t6mþleÍÌon Record 4.72" HSD Powerflows, 7" Model "'FA'''Sump Packer 2755 3806 Case 2/26/2004 Completion Record 4.72" HSD'Powerflows, 7" Model "FA" Sump Packer 2755 3806 Case 2/26/2004 .---.---'-.------------- Sample Set Number Comments . &IN ~N ~ . ) " ~ \'~V\GlJ, t.~'" ) )1 FlL.,)JS~ ~ ì ¡:;e~.J..~ù~. Date: . STATE OF ALASKA . RECEIVED ALASKÄ ~. AND GAS CONSERVATION COMMIS", WELL COMPLETION OR RECOMPLETION REPORT Þ,ti,9,biilP 0 2006 1a. Well Status: OilD Gas0 Plugged 0 AbandonedD SuspendedD WAGD 1b. Well Class: & Gas Cons.-r. . 20AAC 25.105 20AAC 25.110 Development 0 ~~ä~oryU fJfrIrnission GINJ 0 WINJ 0 WDSPL 0 No. of Completions J Other Service 0 Stratigraphic "fIMtJ 2. Operator Name: 5. Date Completed 12. Permit to Drill Number: Union Oil Company of California 11/20/2003 203-182 3. Address: 6. Date Spudded: 13. API Number: PO Box 196247, Anchorage, AK 99519 November 6,2003 50-733-20480-01 4a. Location of Well (Governmental Section): 7. Date TO Reached: 14. Well Name and Number: Surface: 1041' FNL & 463' FWL, See 33, T9N, R13W, SM November 9,2003 M-16RD Top of Productive Horizon: 8. KB Elevation (ft): 15. Field/Pool(s): 375' FSL & 563' FWL, See 28, T9N, R13W, SM 160' above MSL McArthur River Field 9. Plug Back Depth(MD+TVD): .Grayling Gas Sands nla þ\ . f¿ or f\ I>..; 10. Total Depth (MD + TVD): 16. Property Designation: 3,958'/2,566' Steel head Platform 11. Depth Where SSSV Set: 17. Land Use Permit: 476' 19. Water Depth, if Offshore: 20. Thickness of Permafrost: 187 feet MSL nla Total Depth: 1,212' FSL & 900' FWL, See 28, T9N, R13W, SM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 214,078 y- 2.499.462 TPI: x- 214,212 y- 2,500,875 Total Depth: x- 214,568 y- 2,501,704 18. Directional Survey: Yes 0 No 0 21. Logs Run: LWD - GR, Resistivity, Neutron, Density ..$C1"'I'\ nla 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 28" 0 488' 0 487' Driven 13-3/8" 68# K-55 0 840' 0 846' 17-1/2" 1,350 sxs 9-5/8" 47# L-80 0 1,200' 0 1,176' 12-1/4" 575 sxs 7" 29# L-80 0 3,956' 0 2,808' 8-1/2" 109 bbl PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.): Flowing Oil-Bbl: ..... nla Oil-Bbl: -+ nla 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): See schematic 26. Date First Production: December 2, 2003 Date of Test: Hours Tested: 12/2/2003 24 hours Flow Tubing Casing Press: Press. 599 645 27. Production for Test Period Calculated 24-Hour Rate 24. TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 2,616' 2,619' SIZE 4-1/2" 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Gas-MCF: 8,950 Gas-MCF: 8,950 Choke Size: I Gas-Oil Ratio: nla nla Oil Gravity - API (corr): nla Water-Bbl: 2 Water-Bbl: 2 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". of'-"~"." ....". ~ em,,,: .e,'" I~~~ I-Þ!~-·¡ <,,,,,,,.~_,,,,,.-.._.~.,, none j., ð r u_)W..J 12..<.,,,...1/1171: 1'1/./) Form 10-407 Revised 12/2003 U ') I G I f\ 'A I h, I J' ¡ \~ L. AFE 161498 G ., n Q.{1'\ 1<. ßDlv1..JONTINUED ON REVERSE 28. GEOLOGIC MARKE:. NAME TVD ShoelO 1,200 1,176 SZ7SB 1,241 1,213 SZl1cr 1,811 1,584 SZ13SB 2,068 1,714 SZ16ST 2,381 1,863 PERF-1A 2,816 2,072 SZ18cr 3,059 2,205 SZ20cr 3,262 2,337 SZ22cr 3,453 2,469 SZ23BST 3,581 2,555 A2ST 3,725 2,651 PERF-4 3,748 2,667 PERF-4A 3,768 2,680 PERF-5 3,788 2,694 PERF-SA 3,808 2,707 A2CB 3,869 2,748 30. List of Attachments: Directional survey, schematic, daily operations summary. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name: Timothv C. Brandenburg S;g"aruæ ~c JS-f 29. ..ORMATION TESTS Include and briefly surwze test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". none Contact: Larry Buster 263-7853 Title: Drilling Manager Phone: 907-276-7600 Date: I Sundry Number or NIA if C.O. Exempt: 1- Zc. '-Ok" 203-182 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 AFE 161498 J 3J 4 5 6 9 10 11 12 L Well Name: Operator: Field: API: Permit: .W~II Type: Well Status: RKB TDITVD: PBTD/PBTVD: M-16RD Unocal Alaska McArthur River Field 50-733-20480-01 203-182 Gas well Active 71.9' 3,958'/2,809' 3,868'/2,747' Casing Detail Size Wt Grade Type Top (FT) Btm 28" Structural 0 488 488 13-3/8" 68# K-55 Surface 0 840 840 9-518" 47# L-80 Intermediate 0 1,200 1,200 7" 29# L-80 Production (BTC) 0 3,956 3,956 Tubing Detail Size I Wt I 4-1/2" 1.4.6# Grade IType L-80 IBT Mod sp. cl. I Top (FT) I· Btm (FT) . .1. Lengtt¡ (FT) 0.00 2,618.00 Jewelry Detail Type 1. CIW 4-1/2" BTC top and bottom with "H" BPV 2. HES XXO Nipple (3.813" 10) 3. SMD-1A Gas Lift Mandrel 4. X-Nipple 5. PBR 6. XN Nipple (3.75" 10) 7. 80-40 Model "e" Anchor 8. SC-1 R Packer 9. KOIV Mod C (knocked open) 10. Bakerweld 140 12 gauge and excluder 2000 screens 11. S-22 snap latch 12. FB-1packer Perforation Detail Date SPF Zone Nov-03 SZ-17 Nov-03 SZ-18 Nov-03 SZ-22 Nov-03 SZ-23A Nov-03 A-2 Nov-03 A-2 ILast Revised: Depth o 476' 2,583' 2,616' 2,618' 2,619' 2,650' 3,813' Status Active Active Active Active Active Active Top (FT) Btm (FT) Leogth(FT) 2,756.00 2,816.00 2,890.00 2,930.00 3,428.00 3,448.00 3,531.00 3,542.00 3,748.00 3,768.00 3,788.00 3,808.00 60 40 20 20 11/18/2006 I Revised By: IDED 11/5/03 . . PU 8-1/2" window mill assy and RIH. 11/6/03 CBU after 8.5" starter bit and 8.510 water melon mill at 1263'. POOH. RU APRS RIH Tag 7" liner top at 1,265' RKB. Set bridge plug at 1,225' RKB. Orient and shear pin in whipstock to set at 1,200'. PU window milling BHA and whipstock. RIH. Orient and shear pin in whipstock to set at 1,200'. Startto mill window. 11/7/03 Finish milling 42' window in 9 5/8" casing. Conduct 13.2 ppg EMW FIT test. POOH with mill assy. PU drilling BHA and RIH. Orient in window and drill to 1,577' with 9.2 ppg water base mud. 11/8/03 Drill from 1,577' to 3,225' with 9.4 ppg water base mud. 11/9/03 Drill from 3,225' to 3,958' with 9.6 ppg water base mud. Circulate. Pump out of hole. Circulate until clean at window 1,200'. Continue POOH. Change top rams to 7" in BOP shell stack (250 psi and 3,000 psi). RU in preparation to run casing. 11/10/03 Run 7" casing to 3,950'. MU cement head. Break circulation and reciprocate casing. Circulate, condition mud and clean hole. Pump 5 bbl CW 100 (pressure testto 4,000 psi.) Pump 25 bbl CW 100 drop bottom plug. Pump 10 bbl mudpush XLO with rig pump. Pump 109 bbllitecrete cement slurry 12 ppg and drop top plug and pump 10 bbl FIW. Displace with 133 bbl drilling mud until bumping plug at 1,346 strokes. Pressure up to 1,500 PSI. Open bag and monitor. Annulus is static. 11/11/03 RD cement equipment. Set slips in 11" 5M tubing head. Cut 7" casing and dress stub. Remove bell nipple. Install spool and pack off. Test to 3,800 psi (ok). NU BOPs and change rams; 3-1/2" in top and 4-1/2" in bottom. LD 7" casing. Change out bales and elevators. LD jars and 2 joints HWDP. RU to test BOPs. Test BOPs 250-3,000 psi. 11/12/03 MU BHA. RIH to float collar at 3,868'. Open well and circulate long way to clean up completion fluid. 11/13/03 POOH. Test casing 2,047' to 2,039 psi in 30 minuntes on chart (ok). Change top set of rams to 7", pull wear ring. Set test plug and test door seals to 3,000 psi. RU e-line and 7" lubricator. Lock same in rams and test 1,000 psi (ok). RIH with CBL log tag PBTD at 3,867' WLM and log to 500' (Good bond to ETOC at 716'). Make perforating gun runs with 4-5/8" guns. 11/14/03 Continue making perforating gun runs. 11/15/03 M-16 Redrill, 161498 morning report summary, CONFIDENTIAL: last revised 1/19/2006, Page 1. Change rams and pull wear ring. 'test plug and test rams 250-3,000 psi (o.U bit and scraper. RIH, tag PBTD at 3,868'. Pick up to 3,820' displace hole with 3% KCL. RU eline. RIH with 7" model FA sump packer and set same at 3,813'. RU to run Bakerweld, 12 gauge screens. 11/16/03 RU to run 2-7/8" inter string. Run 2-7/8" wash pipe inter string inside 4" screen. PU and MU Baker SC-1 packer. RIH with gravel pack assy on 3-1/2" DP. Drop 1-5/8" ball and pressure up to 1,900 psi for 5 min. Reverse out ball. Reverse circulate tubing clean. Pump 60 bbl of 5 ppb bleach in 3% KCL. Shut in and monitor well. Open well and monitor on trip tank. Hook up and test lines to 6,600 psi. Perform gravel pack. 11/17/03 POOH and stand back 3-1/2" DP. LD gravel pack running tools. Pooh and LD 2-7/8" inter string wash pipe. PU rabbit and run 4-1/2" gas lift completion. Latch in to gravel pack packer at 2,619'. Pressure up back side to 500 psi for 5 min and check snap latch seals (ok). Pull 30k over and sheer seals out of PBR and space out. 11/18/03 Install hanger and run seal assy to top of PBR. Spot 3% KCL with 1% corrosion inhibitor in annulus. Land tubing hangar. Test annulus 2,000 psi 15 minutes (ok). Set BPV. ND down BOP. NU production tree and flowline. Tested void to 5,000 psi 15 minutes (OK). Install two way check, test tree 250 psi low and 5000 psi (good test). RIH and knock out KOIV at 2,647', continue in hole to 2,744'. 11/19/03 RIH to bottom at 3,868' no obstructions. RIH and set safety valve in XXO. POOH. RD slickline. LD 5" DP. 11/20/03 Clean rig floor. Release rig from M-16RD at 00:00 hrs. M-16 Redrill, 161498 morning report summary, CONFIDENTIAL: last revised 1/19/2006, Page 2. . . I Report Name I Well I Date Created Position Log M-16RD 1/10/2006 KB Surf X Surf Y Well Name CURRENT STATUS API (ft) (ft) (ft) M-16RD UNKNOWN 507332048001 160 214,078 2,499,462 MD TVD SSTVD X Off YOff X Y Inc Azimuth (ft) (ft) (ft) (ft) (ft) (ft) (ft) (deg) (deg) ° ° 160 ° ° 214,078 2,499,462 ° ° 90 89 71 ° ° 214,078 2,499,462 0.2 200 180 179 -19 ° ° 214,078 2,499,462 0.1 14 270 269 -109 ° ° 214,078 2,499,462 0.1 260 360 359 -199 ° 0 214,078 2,499,462 0.1 28 450 449 -289 ° 0 214,078 2,499,462 0.2 93 559 558 -398 ° 1 214,078 2,499,463 2.3 334 648 647 -487 -2 8 214,076 2,499,470 6.8 332 701 700 -540 -5 15 214,073 2,499,477 9.8 335 737 735 -575 -7 21 214,071 2,499,483 11.3 338 800 797 -637 -11 33 214,067 2,499,495 13 348 863 858 -698 -13 47 214,065 2,499,509 12.9 351 958 950 -790 -14 71 214,064 2,499,533 15.9 2 1,053 1,041 -881 -11 99 214,067 2,499,561 18.7 6 1,147 1,128 -968 -4 132 214,074 2,499,594 23.9 14 --"'" 1,200 1,176 -1,016 1 154 214,079 2,499,616 26 19 1,248 1 ,219 -1,059 9 175 214,087 2,499,637 30.4 17 1,347 1,298 -1,138 27 231 214,105 2,499,693 42.8 16 1 ,443 1,367 -1 ,207 45 296 214,123 2,499,758 46 13 1,537 1,431 -1,271 60 363 214,138 2,499,825 48 9 1,630 1,489 -1,329 72 434 214,150 2,499,896 53.9 6 1,725 1,541 -1,381 80 513 214,158 2,499,975 59.7 4 1,819 1,588 -1 ,428 86 595 214,164 2,500,057 60.2 2 1,914 1,636 -1,476 90 676 214,168 2,500,138 59.5 1 2,008 1,683 -1,523 95 758 214,173 2,500,220 60.2 3 2,102 1,731 -1,571 100 839 214,178 2,500,301 59.5 2 2,196 1,776 -1,616 106 921 214,184 2,500,383 62.7 3 2,289 1,819 -1,659 112 1,003 214,190 2,500,465 61.8 3 2,381 1,863 -1 ,703 118 1,084 214,196 2,500,546 61.3 2 2,478 1,910 -1,750 123 1,168 214,201 2,500,630 60.8 2 2,574 1,956 -1 ,796 128 1,252 214,206 2,500,714 62 1 2,667 2,000 -1,840 131 1,335 214,209 2,500,797 61.9 1 2,761 2,044 -1,884 134 1,417 214,212 2,500,879 61.5 360 2,859 2,093 -1,933 138 1,502 214,216 2,500,964 59 2 2,952 2,143 -1,983 146 1,581 214,224 2,501,043 56.6 6 3,044 2,196 -2,036 159 1,654 214,237 2,501,116 52.7 12 3,142 2,258 -2,098 181 1,728 214,259 2,501,190 49.4 18 3,237 2,320 -2,160 208 1,793 214,286 2,501,255 47.3 24 3,329 2,383 -2,223 241 1,852 214,319 2,501,314 46.9 31 3,424 2,449 -2,289 278 1,910 214,356 2,501,372 46.3 30 3,522 2,515 -2,355 316 1,971 214,394 2,501,433 48.3 32 3,615 2,578 -2,418 353 2,029 214,431 2,501,491 47.2 31 3,707 2,639 -2,4 79 390 2,086 214,468 2,501,548 48.2 32 3,802 2,703 -2,543 429 2,146 214,507 2,501,608 47.8 32 3,897 2,767 -2,607 466 2,204 214,544 2,501,666 47.1 31 3,917 2,781 -2,621 474 2,217 214,552 2,501,679 46.8 30 3,958 2,809 -2,649 490 2,242 214,568 2,501,704 46.8 30 . Unocal Alaska . 909 W 9th Ave Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 Email: oudeand@unocal.com UNOCALE!> '''''''-Alaska Debra A Oudean G & G Technician ;;Wi January 29, ~ DATA TRANSMITTAL To: Lisa Weepie 333 W 7th Ave, Suite 100 Anchorage, AK 99501-3539 AOGCC From: Debra Oudean 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Alaska Transmitting as follows: I Cfij- CiP Lf ¡IBU ~:?~ COMPLEll~~REg2!!.~'~""_^"'_""~~""'W~'M'~~'!~~~) .....1 . JIBU M-1 : COMPLETION RECORD OWEN X-SPAN PATCH ¡5INCH: 1211212003: 1719-Œt <[~~~:1·]~~!~ì§~Ä~~ºº·~·.........·..····..··]51~ç0T·1711!?q9~1~!)9:~~~9 } '59-dt9 !IBU r.1:131~()r.1~~~II()~ ~~~()~[)?:!)~~[)~()~~~JE.TS.!51~9H!!1111~1299~1??~~:??9~ J ~~~%Þ1i~~~~l~=··. PER~Z~~~~~~~ª~~~~~;;~~lf~~~~~Æ==~::···J::~.c.~..~:L].1.I?l?QO.~? ~'J~:~~~J~~~~~:~~~~~2HSDP~FLOWS7.j:~~11;i;~*i~::: çq / ::> ITBU M-5 ¡COMPLETION RECORD VELOCITY STRING PACKER INCH ..11.....1...1../...2....5..../...2....0....0....3....1...5. .0-33....5...0.. J U -,.J3 ~ 'TUBING PUNCHER! .. . L . ........ 1 Jâ~l*~.M.,j].jC!.~._..., 1J&LPll)1~J!......19..........,... J1j~mJ1....J1.J9 .... ...........'1/~t~~1~········ .. ..I~······lci···················· .j1·~1Eit= 1f}LJi. I 1 0 ............¡ .J RECEIVED FE8 2 6 2004 ÞJaska Oil & Gas Cons. Commistlon ~Jichorage t Please acknowledge receipt by signing and retuming one copy of this transmittal or FAX to (907) 263-7828. I Receive~l~~'-O§'<~.~,j~./V\ I Date: . ~~!Æ~! (ill} !Æ~!Æ~~~!Æ . I AI,ASIiA OILAlWD GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 FRANK H. MURKOWSKI, GOVERNOR ADMINISTRATIVE APPROVAL NO. 228.06 Re: The application of Union Oil Company of California, operator of the Trading Bay Unit (TBU), to drill and complete the TBU M-16RD Middle Kenai Gas Pool production well. Mr. Kevin Tabler Land/Government Affairs Unocal Alaska POBox 196247 Anchorage, AK 99519-6247 Dear Mr. Tabler: Your application of October 16, 2003, for a pennit to drill and complete the TBU M- 16RD well requires exception to spacing requirements set forth in Rule 1 of Conservation Order No. 228. The drilling and completion of the TBU M-16RD well is expected to provide additional gas recovery from the Middle Kenai Gas Pool in the TBD. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling and completion of the TBU M-16RD well pursuant to rule 3 of Conservation Order No. 228. DONE at Anchorage, Alaska and dated October 28,2003. ~ Randy Ruedrich Commissioner Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION . ~~!Æ~E ffi)} !Æ~!Æ~~~!Æ . FRANK H. MURKOWSKI, GOVERNOR AI/ASHA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Larry Buster Drilling Engineer Unocal Corporation PO Box 196247 Anchorage AK 99519-6247 Re: McArthur River Field M-16RD Unocal Corporation Permit No: 203-182 Surface Location: 1041' FNL & 463' FWL, Sec. 33, T9N, R13W, SM Bottomhole Location: 1218' FSL & 895' FWL, Sec.28, T9N, R13W, SM Dear Mr. Buster: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. Unocal Corporation assumes the liability of any protest to the spacing exception that may occur. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ?-~ ¡e. _.-L ~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this U day of October, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Exploration, Production and Refineries Section e e Unocal Alaska Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519-6247 Telephone (907) 276-7600 UNOCAL8 ,'" --Alaska Larry Buster Drilling Engineer October 20, 2003 Alaska Oil and Gas Conservation Commission 333 West ih Avenue Anchorage, Alaska 99501 Attn: Commission Chair Sarah Palin Re: Application For Permit to Drill (form 10-401) Steelhead Well M-16 RD Commissioner Palin: Attached is an Application for Permit to Drill (form 10-401) for the Steelhead Well M-16 RD. The original M-16 well will be abandoned in accordance with previously approved Sundry Application: 303-296. After abandoning the original well, we plan to sidetrack and "Re-Drill" this Steelhead Well, M-16 RD. Please call me at 263-7804 or the drilling engineer for this project, Skip Coyner, at 263-7690 with any questions you may have. LWB/s Attachment :.: , OQ1GINAL .... STATE OF ALASKA ALASKA OIL ~ GAS CONSERVATION C~ISSION PERMIT TO DRILL 20 AAC 25.005 Redrill: X 11 b. Type of well Deepen: Service: 1a. Type of work Drill: Re-Entry: 2. Name of Operator Unocal Cororation 3. Address P.O. Box 196247, Anchorage, AK 99519-6247 4. Location of well at surface 1041' FNL & 463' FWL, Sec 33, T9N, R13W, SM ? At top of productive interva SZ-17 337' FSL & 565' FWL, See 28, T9N, R13W, SM At total depth 1218' FSL & 895' FWL, See 28, T9N, R13W, SM 12. Distance to nearest 13. Distance to nearest well property line 337' feet 16. To be completed for deviated wells Whipstock depth: 1200 feet 62 18. Casing program size Casing M-30, 80' at 1200' MD Original KOP = 500 ft Maximum hole angle: Specifications Grade Coupling L-80 BTC-Mod Hole 8-1/2" 7" Weight 26# 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical 3625 feet 2667 feet Effective depth: 3446 feet 2530 feet measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Size 28" Length 406' 768' 1419' 13-3/8" 9-518" frl\J&'t Development Oil: Multiple Zone: Exploratory: Stratigraphic Test: Developement Gas: X Single Zone: 5. Datum Elevation (OF or KB) 10. Field and Pool 160' feet McArthur River Field 6. Property Designation Grayling Gas Sands Pool ADL 18730 7. Unit or property Name Trading Bay Unit 8. Well number M-16 RD 9. Approximate spud date 11/1/2003 14. Number of acres in property 3840 11. Type Bond (see 20 MC 25.025) Number U62-9269 Amount $200000 . 15. Proposed depth (MD and TVD) 3958' MD: 17. Anticipated pressure (see 20 MC 25.035 (e)(2») Maximum surface 390 psig At total depth (TVD) Setting Depth 2807' TVD feet 650 psig Length 3876' Top MD TVD 82' 82' Bottom MD TVD 3958' 2807' Quantity of cement (include stage data) 274 sx UteCrete (12 ppg) Plugs (measured) 2159' - Cmt RTNR Planned Cmt RTNR at 1550' MD (303-296) Junk (measured) 2182' - Baker Model FA PKR Cemented Driven Measured depth 448' True vertical depth 448' 1350 sx 575 sx 850' 1eœ 849' 1436' 3624" 2 0 2650' 2363' measured 7" 880 sx 1751'-1808', 1959'-2004',2092'-2130' true vertical 1613'-1651', 1748'-1776', 1826'-1848' 20. Attachments: Filing fee: X Property Plat: BOP Sketch: X Diverter Sketch: NIA Drilling program: X Drilling fluid progran:-.2< Time vs. depth plot: X Refraction analysis: NIA Seabed report: NIA 20 AAC 25.050 requirements: 21. I herby certify t ore~ tl.i.S. true ¡ nd correct to the best of my knowledge: Questions: call Skip Coyner at 263-7690 f C-... ~ ~~), , \ 1 Sig. d: 1. \ ,... J \.JL\ Title: ~ r: \ ~ ^ j ¡; /\C." r, Date: \ \)'l..c \ 61" Commission Use Only ,.1 Permit Number I API number I APprova~d e J See cover letter ;J..-D :3 - / ß ?--- 50- 733-20480 - ð ~ ! i) ~ I tr3 . for other requirements Conditions of approval Samples required: [] Yes ~o Mud log qui red: [] Yes 0 Hydrogen sulfide measures [] Yes Þ«NO Directional survey required ){Yes [] No Required working pressure for BOPE [] 2M; [] 3M; [] 5M; [] 10M; [] 15M Other: ~Ca \> ~~ ~ C) Ç> -\-(!. c:.~ Approved by Ie.---~ ¡&..~ ~..¡;::t"¿ . '-t... Commissioner Form 10-401 Rev. 1£85 by order of the Commission Date: / cr~/OJ Submit in triplicate ORIGINAL ~ UNOCAL~ e . October 17, 2003 Steel head Platform, Slot A 1-4: Well No.: M-16 RD Trading Bay Unit, McArthur River Unit Re-Drill - Sidetrack - Twin Prepared by: S Coyner ~ C-- (907) 263-7690 Objective: Re-Drill Steelhead, M-16 The objectives of this Re-Drill (sidetrack) are to: a) Plug and abandon the existing wellbore to the TOL b) Sidetrack the well at ± 1200' MD using a whipstock c) Re-drill (twin) the original well to access targets SZ-17 through SZ-23B d) Gravel pack the well in the SZ-17, SZ-22 & SZ-23B gas sands. e) Run the completion Current Status: Unable to flow against line pressure Current Mechanical Status: · RKB: 160 ft · Annulus fluid: 9.5 PPG KCL brine wI corrosion inhibitor · Landing Nipple for WLlSSSV: 4148 MD, 3.813" ID · 7" Tie-Back Seal Nipple: 1229' MD · Upper SC-1R Packer: 1615' MD · Soft (unknown> Fill: 1850' MD · Perforations: 1751' -1808' MD } 1959' - 2004' MD 5-1/2" Screens: 1620' - 2137' MD 2092' - 2130' MD · 7" Middle SC-1R Packer: 2138' MD · 7" SC-1 L Packer 2149' MD · Cement to 2138' MD · 4" Cement Retainer: 2150' MD · 4" Baker Model "FA" Packer: 2182' MD Notify the AOGCC field inspector 24 hrs before moving over the well and when ready for the BOPE tests. 1 ~ UNOCAL€Ø e e Pre-Rig Work: 1. Check the "Lock-Down-Screws" on the tubing head and test the void in the 7" tubing hanger. 2. Load the 7" tubing with filtered inlet water. Establish an injection rate down the 7" tubing. Rig Work: 1. Move the drilling rig over the well from M-13: Leg A-1, Slot 4. 2. RlU E-Line. Set a 7" cement RTNR at.:t 1550' MD as per approved application to abandon No. 303-296. Pressure test the RTNR and 7" to 1500 psi. RID E-Line. 3. Set a storm packer through the tree at.:t 300'. Test the storm packer to 3000 psi. 4. ND tree. NU BOPE and test the BOPE to 250 psi 1 3000 psi (or as designated on the permit to drill) against the storm packer. Retrieve the storm packer. 5. RIH with the stinger on 3-1/2" drill pipe. Sting in to the RTNR and establish an injection rate. 6. RlU Dowell. Test Lines to 2000 psi. Mix and pump.:t 10 bbl of class "G" cement. Displace with 11 bbl of inlet water. Pull out of the RTNR and dump the last % bbl of cement on the RTNR. Circulate the DP clean. POOH. Test to 2000 psi. 7. Lay down the 7" tubing. 8. RIH with a bit and casing scraper on 5" DP (P/U DP). 9. Set a CIBP in the 9-5/8" casing at.:t 1222' MD. 10. Set a 9-5/8" whipstock with bottom-trip anchor on the CIBP, oriented high-side. 11. Mill the window. Circulate the hole clean. POOH. LID the mills. 12. RIH with the "build assembly" on 5" DP. Drill 20' of new hole and CBU. 13. Run an FIT to 13 ppg EMW at the window = 1177' TVD (see below): The 13-3/8" shoe was tested to 13.0 ppg EMW at 837' TVD The 9-5/8" shoe was tested to 15.7 ppg EMW at 1438' TVD The maximum expected reservoir pressure is :!: 900 psi at 2020' TVD: EMW = 8.6 ppg. .I The maximum expected ECD at the window with 9.3 ppg mud is ~ 10.0 ppg In accordance with the amendments to C.O. 228, Rule 4, Auxiliary Casinq and Cementinq Requirements dated 5/12/1998, the 9-5/8" casing string in this well constitutes the "Auxiliary Casinq" string at the window depth of 1177' TVD. BOPE will be installed, tested and used throughout. The 13 ppg FIT at the window depth exceeds the required value to safely drill this well to the planned TVD of 2807'. 2 ~ UNOCAL(; Formation Tops, etc.: 13-3/8" Shoe Whipstock/Window SZ-12 sand SZ-17 sand SZ-22 sand SZ-23B sand A-2 sand PTD e MD 841' 1200' 1817' 2762' 3369' 3537' 3720' 3958' e TVD 837' 1177' 1598' 2040' 2405' 2520' 2645' 2807' Notes LOT = 13.0 ppg FIT to 13 ppg Gas, 650#, EMW = 6.2# Gas, 650#, EMW = 5.2# Gas, 650#, EMW = 5.0# Gas, 650#, EMW = 4.7# MW at PTD = 9.3# ~ 14. Drill ahead building angle to ~ 620 as per the attached directional drilling plan. Hold angle to the uppermost target (SZ-17) at 2762' MD (2040' TVD). Then drop angle at 50/100' to the final sail angle of ~ 470. Hold the final sail angle through the remaining targets and to prD: 3958' MD (2807' TVD). Watch for seepage and lost circulation while drilling the depleted gas sands below 2762' MD. Minimize ECD, control drill and maintain "sized" CaC03 in the mud to control seepage and losses. 15. At TD, circulate and condition the hole for casing. Make a wiper trip up to the window but do not pull the bit into cased hole. Return to bottom and circulate the hole until it's clean and stable. POOH. LID the 5" DP and BHA. 16. R/U to run 7" casing. Change out rams to 7" and test same. Run the 7" casing. Fill the casing every joint through the top drive. Break circulation at the window. Continue running 7" casing to TD. Circulate and reciprocate the casing while conditioning the mud prior to cementation. 17. R/U Dowell and test lines. Mix and pump 30 bbl of "GW-10V' wash followed by 30 bbl of "MudPush XL" spacer. Mix and pump 274 sx (109 bbl) of "LiteCrete" mixed at 12 ppg. The programmed cement volume includes 50% open-hole excess and a TOC = 700' MD. Displace the top plug with filtered inlet water. Bump the plug with 1000 psi. Check the floats. Flush out the BOP stack and wellhead with water. Close the annular and WOC. RID Dowell. 18. After WOC until the initial T.T. of the cement, open the annular and check for flow. N/U the BOP's and set the slips on the 7" casing. Cut the 7" and N/U an 11" (5M) tubing head. Re-set the BOP's. Test the wellhead and the BOPE per AOGCC regulations to the permitted pressure. 19. RIH with a bit, casing scraper and casing brush on 3-1/2" DP and circulate the well with filtered inlet water at high pump rate until clean. Displace with 3% KCL water. Spot a 75 bbl polymer "perf pill" and POOH. 3 ~~ UNOCALfj e it 20. RlU E-Line with a full 7" riserllubricator and packoff. Perforate the SZ-17, SZ-22, SZ-23B and A-2 sands with 4" HSC, 12 spf as directed by the gas team. Keep the hole full with KCL water. Monitor losses. Pump another pill if necessary. Set the "sump packer" as directed. RID E-Line. 21. P/U the gravel pack assembly and wash pipe. RIH on DP. Keep the hole full and constantly monitor the trip tank. Gravel Pack the well as directed. Reverse circulate the tubing clean. POOH. LID DP and the wash pipe. The KOIV should allow the hole to stay full. 22. Run the 4-1/2" completion assembly as follows: No. Item(s) Drift ID Length Top Bottom 1 ea 4-1/2" Landing Joint 3.833" 89' RKB 89' 1 ea Tubing Hanger 3.833" 1 ' 89' 90' 1 ea Cross-Overs and 4-1/2" pup joints 3.833" 20' 90' 110' 12 ea 4-1/2",12.6#, L-80, BTC-Mod Tubing 3.833" 360' 110' 470' 1 ea 4-1/2",12.6#, L-80, BTC-Mod pup jt 3.833" 10' 470 480 1 ea 4-1/2" HES, XXO nipple 3.833" 2' 480' 482' 1 ea 4-1/2",12.6#, L-80, IBT-Mod pup jt 3.833" 10' 482' 492' 71 ea 4-1/2",12.6#, L-80, IBT-Mod Tubing 3.833" 2130' 475' 2622' 1 ea 4-1/2",12.6#, L-80, IBT-Mod pup jt 3.833" 10' 2622' 2632' 1 ea 4-1/2" x 1" GLM wI a dummy valve 3.833" 6' 2632' 2638' 1 ea 4-1/2",12.6#, L-80, IBT-Mod pup jt 3.833" 10' 2638' 2648' 1 ea 4-1/2",3.812" "X" nipple 3.833" l' 2648' 2649' 1 ea 4-1/2", 12.6#, L-80, IBT-Mod pup jt 3.833" 10' 2649' 2639' 1 ea PBR 3.833" 10' 2639' 2649' 1 ea 4-1/2",3.812" XN nipple wI 3.75" NoGo 3.833" l' 2649' 2650' 1 ea Baker Snap Latch seal nipple for SC-1 PKR 3.833" 3' 2650' 23. After running the completion, sting into the SC-1 packer and then shear out the PBR. Space out and install the tubing hanger. Displace the IA with packer fluid containing corrosion inhibitor. The freeze point of 6% KCL water is 270 F. 24. Sting into the PBR and land the tubing hanger. RILD. Test the IA to 2000 psi. 25. Set a BPV. N/D BOP's. N/U the tree. Replace the BPV with a TWC. Test the tree and hanger to 3000 psi. 26. Pull the TWC. Install a BPV. Secure the well. Release the Rig. Post Rig 1. RlU Slick Line. Pull the BPV. 2. If desired, Pull the dummy valve and freeze protect the IA with diesel. 3. Set a gas lift valve. 4. RIH with sinker bars and break the KOIV flapper. 5. Set the WRSSV. 6. Re-install the flow line. 4 ~ UNOCALfj e e Attachments: · Current well bore diagram · Sidetrack diagram · Sidetrack casing diagram · Sidetrack completion diagram · BOP diagram - Steel head Platform · Directional Drilling Plan · Drilling Fluid Plan · Cement Plan · Application for Spacing Exception (informational copy) 5 COMPLETION DESCRIPTION I) 7" 29# lo80 NSCC Tubing fJ 1778' - 68' 2) HES 5.963" ID SSSV Landing Nipple FI Safety Valve @ +/-448'. (Min. ID = 3.50") 3) Baker SC-IR Packer @ +1-1615'. 4) 4" 9.5# SSWW Screen & Blank Packed wI )«> Carbolite F/2137' - 1620'. 5) Baker SC-IR Packer@2138'. 6) Baker SC-IL Packer @ 2149' 7) 4" 9.5# SSWW Screen & Blank Packed wI 20/40 Carbolite F/2674'-2154'. 8) Baker SC-IR Packer @ 2675'. 9) 4" 9.5# SSWW Screen & Blank Packed wI 20/40 Carbolite F/3415'-2679'. 10) BakerDASump Packer@+1-3416' 11) 4" Baker 'FA' pkr (min. ID= 1.875") (Note: Sheared off packer at 2154' & pushed same downhole to 2182'. Packer is partially set) 12) Cement retainer at 2159' (cement to perfs) TD @ 3625' te STEELHEADPLATFORM WELL # M-16 TRADING BAY UNIT COMPLETION AS OF 9/24/02 RKB = 160' C2 -=> L L "" L ~ ~3 4 L 10 .~ '. - 7" TBG Hanagr McEvoy 1 I" x 7" NSCC bottom Type J BPV I l"x 7" 28", Structural Casing @ 488' RKB (141 'BML) ~ 113-3/8" cement to surface ~ 13-318" 68# K-55 BTC Surface Casing @ 840' í 7" 29# L-80 NSCC 1295-68' 7" Liner Top @ +1- 1262' wI ZXP Liner Top Packer rOC inside 7" x 9-5/8" liner lap ~ 9-5/8" 47# lo80 BTC Intermediate Casing @ 1506' r-5/8" cement to surface 1751-1808' MD 1959-2004' MD 2092-2130'MD 5 6 2485-2559'MD 2612-2667'MD 3211-3239'MD 3387-3409'MD 7" 29# L-80 KC Butt Liner from 3623' - 1778' 7" 29# L-80 NSCC Liner from 1778'- 1295' RKB'_ Mean Sea Level 250'- Mud Line 500'_ 750'_ 1000'- 1250'- 1500'- 1750'- 2000'- 2250' 2500' _ 2150'_ 3000' _ 28" Drive Pipe at 488' MD 13~3/8"Casing at 840' MD LOT = 13.0 ppg 7"Tie~Back at 1262' MD 5/8" Gas String at 1506' MD LOT = 15.7 ppg Perforations: 1751' - 1808' 1959' - 2004' 2092' - 2130' Steel head Platform M..16 Current Schematic RKB'_ Mean Sea Level 250' _ Mud Line 500' _ 750' _ 1000'- 1250'- 1500' - 1750'_ 2000'- 2250' _ 2500' _ 2750'_ 3000' _ 28" Drive Pipe at 488' MD 3-3/8"Casing at 840' MD LOT:::: 13.0 ppg ... Cut Window in 9-5/8" 1200' -1222' MD ... ... ... FIT :::: 13.0 ppg ....... ...... ...... ........ ............ .... 9-5/8" at 1506' MD LOT = 14.1 ppg ........ ........ ....... ...... ...... ....... ........... 62" ...... ....... ....... ......... ---l Steel head Platform M-16 RD (Sidetrack) 11/01/2003 ...... ...... ....... 8-1/2" Hole .... .... .... ... 9.3 ppg Mud ........ ....... ...... ....... ...... ...... ........... ... ... ... ... ... ... ... ... ... \ \ \ \ \ \ '\ '\ '\ '\ '\ ...... ........ ...... ....... ... ... ... ... ... ... ... \ \ \ \ 47" '\ \ \ \ \ \ \ RKB'_ Mean Sea Level 250' _ Mud Line 500'_ 750'_ 1000'- 1250'- 1500'- 1750'- 2000'- 2250' _ 2500' _ 2750'_ 3000' _ Steel head Platform M-16 RD (Sidetrack) 11/01/2003 28" Drive Pipe at 488' MD Planned TOC for 7"Casing at 7£1£1' MD 47° 7" Production Casing At 3958' MD (2807' TVD) RKB'_ Mean Sea Level 250'- Mud Line 500'_ 750' _ 1000'- 1250'- 1500'- 1750'_ 2000'- 2250' _ 2500' _ 2750'_ 3000' _ 9-5/8" at 1506' MD Steel head Platform M-16 RD (Sidetrack) 11/0112003 28" Drive Pipe at 488' MD Planned TOC for 7"Casing at 700' MD 13-3/8"Casing at 840' MD 4-112" Production Tubing Perforate & Gravel Pack SZ-17, SZ-23B & 47° 7" Production Casing At 3958' MD (2807' TVD) ,e FILLUP. LINE dJMJ::::: 16 3/f 10,OOOpsi DOUBLEGATE CHECK VALVE e ~ FlOW LINE r ..., L .J ~ _---,1 [ [ HYDRILL 16 3/4" 5000psi f TYPE GK ANNULAR Ir-_ = ---- I PIPE RAMS Ir-= ] ] PIPE RAMS -----J\ I ..- IL--- I CHOKE lJNE ---Þ- GATE VALVE I I GATE VALVE _ ---, I I ,.--' [ -J 16 3/4- PIPE RAIlS 10,OOOpsi -----.J I I '----- SINGLEGATE I I \ 16 3/4- 5000psi RISER -'\ ~ ~EALL VALVE WEllHEAD ~ STEELHEAD PLATFORM PREVENTER SCHEMATIC Sperry-Sun Drilling Services UNOCAL Alas Steel He M-16 . - posal Report 14 October, 2003 Surface Coordinates: 2499462.65 N, 214079.98 E (60.83182° N, 151.60240° W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing: 160.00ft above Mean Sea Level e .p....,...,y-.ul'l CAlL-LING SEAVIc:eS A Halliburton Company Proposal Ref: pro88 [ Unocal Alaska Inc. AHa"'burto"C.",...y Kenai & Cook Inlet l :5 a. (!) o 1500 - ro u :e ~ '" o '" "' " -¡¡ ~ ¡¡¡ 13 ø 3000 o 500 - 1000 - 2000 - 2500 o Scala: 11nch ~ 500ft M.16;¡:,l!WP07 Proposal Data Well Well ft True North per 100 feet (US Survey) N,O,OO E Measured Depth Incl. Dogleg Rate Azim. Vertical Depth Northing. Eastings Vertical Section 12,000 6.500 0.000 $,000 0.000 0,003 0.000 0.000 KOP: (Whipstock @ HS/25° Left TF) Start Dir@ 12.000o/100ft: 1200,00ftMD,1176.84ftTVD Decrease Dir Rate @ 6.500"/100ft: 1220.00ftMD,1194.64ftTVD End Dir, Start Sail @ 62,132°: 1764.90ftMD,1573,88ftTVD Begin Dir @ 5,00001100ft : 2762,09ft MO, 2040.00ft TVO End Dir, Start Sail @46.984° /: 3257,71ftMD,2329,42ftTVD BW.(¡() Total Depth: 3957.57 ft MO, 2806.86 ft TVD I 500 I 1000 1500 Vertical Section (Well) I 2000 2500 Section Azimuth: 10,814' (True North) ~ (¡) 0'1 CO € ~ 1000 - '" o ¡¡¡ " -¡¡ ,EO ¡¡¡ 0 13 ø Scale: 1inch 500ft r Eastings(Well) 500 ¡ 1000 ¡ 2000 - r::;J.lJl ¡ 1500 - End Dir, Start Sail @ 46.9 : 3257.71ftMD,2329,42ftTVD Begin Dir@ 5,OOoo/100ft : 2762.09ft MD, 2040.00ft TVD 500 - End Dir, Start Sail @62.132° : 1764.90ftMD,1573.88ftTVD Decrease Dir Rate @ 6.500°/1 o Oft : 1220,00ftMD,1194,64ftTVD KOP : (Whipstock @ HSI 25" Left TF) Start Dir @ 12.00001100ft : 1200.00ftMD,1176.84ftTVD o Scale: 1 inch z 500ft I 500 I 1000 Reference is True North Wel!: Eastings(Well) Current Well Properties M·16 St WP07 Horizontal Coordinate$: Ref. Global Coordinate$ : Ref. Structure: Ref, Geographical Coordinates: RKB Elevation: 2499462,65 N, 214079.98 E 34.1515,63,62 W 60,83182' N, 151,60240' W 160.00ft above Mean Sea Level 160,00ft above Project V Reference True North Feet (US Survey) North Reference : Units : Sperry-Sun Drilling Services Proposal Report for Steel Head - M-16AD WP07 Revised: 14 October, 2003 Kenai & Cook Inlet Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) '1200.00 25.969 19.003 1016.85 1176.85 154.12N 2.97W 214080.77 E 150.83 KOP : (Whipstock @ HSI 25° LI TF) Start Dir @ 12.000·/100ft : 1200.00ftMD,1176.84ftTVD 1220.00 28.369 19.003 1034.64 1194.64 162.76 N 0.00 E 214083.96 E 12.000 159.87 Decrease Dir Rate @ 6.5000/100ft : 1220.00ftMD,1194.64ftTVD 1300.00 33.150 14.991 1103.38 1263.38 214096.76 E 6.500 200.52 1400.00 39.261 11.228 1184.04 1344.04 214111.41 E 6.500 259.50 e 1500.00 45.465 8.343 1257.90 1417.90 214124.37 E 6.500 326.82 1600.00 51.727 6.017 1324.01 1484.01 2499861.56 N 214135.48 E 6.500 401.62 1700.00 58.028 4.064 1381.52 1541.52 2499942.80 N 214144.60 E 6.500 482.95 1764.90 62.132 2.936 1413.88 2499998.83 N 214149.39 E 6.500 538.73 End Dir, Start Sail @ 62.132° : 1764.90ftMD,1573.88ftTVD 1800.00 62.132 2.936 1430.29 57.88 E 2500029.77 N 214151.74 E 0.000 569.46 1816.50 62.132 2.936 1438.00 58.63 E . 2500044.31 N 214152.84 E 0.000 583.91 SZ-12 1900.00 62.132 2.936 1477.03 62.41 E 2500117.92 N 214158.42 E 0.000 657.03 2000.00 62.132 2.936 1523.77 66.94 E 2500206.07 N 214165.10 E 0.000 744.60 2100.00 62.132 2.936 1570.52 71.47 E 2500294.22 N 214171.78 E 0.000 832.17 2200.00 62.132 2.936 1617.26 76.00 E 2500382.37 N 214178.47 E 0.000 919.74 2300.00 62.132 2.936 1664.00 80.53 E 2500470.52 N 214185.15 E 0.000 1007.31 2400.00 62.132 2.936 1710.75 1870.75 1098.42 N 85.05 E 2500558.67 N 214191.83 E 0.000 1094.88 2500.00 62.132 2.936 1757.49 1917.49 1186.71 N 89.58 E 2500646.82 N 214198.51 E 0.000 1182.44 2600.00 62.132 2.936 1804.23 1964.23 1275.00 N 94.11 E 2500734.97 N 214205.20 E 0.000 1270.01 2700.00 62.132 2.936 1850.98 2010.98 1363.28 N 98.64 E 2500823.12 N 214211.88 E 0.000 1357.58 2762.09 62.132 2.936 1880.00 2040.00 1418.10 N 101.45 E 2500877.85 N 214216.03 E 0.000 1411.95 Begin Dir @ 5.0000/100ft : 2762.09ft MD, 2040.00ft ~. SZ-17 M-16 ST WP07 SZ-17 Ge Target, 50.00 Radius., Current Target 2800.00 60.822 4.495 1898.10 2058.10 1451.34N 103.61 E 2500911.02 N 214219.00 E 5.000 1445.00 2900.00 57.459 8.807 1949.41 2109.41 1536.57 N 113.49 E 2500995.99 N 214230.96 E 5.000 1530.57 3000.00 54.255 13.446 2005.55 2165.55 1617.74 N 129.39 E 2501076.75 N 214248.83 E 5.000 1613.29 3100.00 51.243 18.463 2066.09 2226.09 1694.24 N 151.19 E 2501152.69 N 214272.49 E 5.000 1692.52 3200.00 48.464 23.903 2130.59 2290.59 1765.49 N 178.72 E 2501223.25 N 214301.76 E 5.000 1767.67 14 October, 2003· 10:34 Page 2 of 8 Dr/llQuest 3.03.02.002 Sperry-Sun Drilling Services Proposal Report for Steel Head - M-16~9 ,POl Revised: 14 October, 2003 Kena; & Cook Inlet Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3257.71 46.984 27.250 2169.41 2329.41 1804.00 N 197.13 E 214321.11 E 5.000 1808.95 End Dir, Start Sail @ 46.984° : 3257.71 ftMD,2329.42ftTVD 3300.00 46.984 27.250 2198.27 2358.27 1831.49 N 214335.93 E 0.000 1838.61 3368.50 46.984 27.250 2245.00 2405.00 1876.02 N 214359.95 E 0.000 1886.65 SZ-22 3400.00 46.984 27.250 2266.49 2426.49 1896.49 N 214370.99 E 0.000 1908.74 3500.00 46.984 27.250 2334.71 2494.71 1961.49 N 214406.04 E 0.000 1978.86 3537.08 46.984 27.250 2360.00 2520.00 214419.04 E 0.000 2004.86 SZ-23B .- 3557.60 46.984 27.250 2374.00 2534.00 214426.23 E 0.000 2019.26 Target - M-16 ST WP07 S Current Target 3600.00 46.984 27.252 2402.93 2562.93 2501480.93 N 214441.10 E 0.003 2048.99 3700.00 46.984 27.257 2471.15 2631.15 2501545.09 N 214476.16 E 0.003 2119.12 3720.31 46.984 27.258 2485.00 2501558.12 N 214483.28 E 0.003 2133.36 A-2 M-16 ST WP07 A2 Geo Target, 100.00 Radius., Current Target 3800.00 46.984 27.258 2539.37 378.70 E 2501609.25 N 214511.23 E 0.000 2189.24 3837.57 46.984 27.258 2565.00 391.28 E 2501633.36 N 214524.40 E 0.000 2215.59 3900.00 46.984 27.258 2607.59 412.18E 2501673.41 N 214546.29 E 0.000 2259.37 , 3957.57 46.984 27.258 2646.86 431.46 E 2501710.34 N 214566.48 E 0.000 2299.74 Total Depth: 3957 .57ftMD ,2806.86ftTVD 7in Liner All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 10.814° (True). Magnetic Declination at Surface is 20.193°(13-0ct-03) e Based upon Minimum Curvature type calculations, at a Measured Depth of 3957.57ft., The Bottom Hole Disþlacement is 2299.74ft., in the Direction of 10.814° (True). The Along Hole Displacement is 2342.34ft, the Planned Tortuosity is 3.326°/100ft and the Directional Difficulty Index is 5.1. 14 October, 2003· 10:34 Page 3 of 8 DrlllQuest 3.03.02.002 Kenai & Cook Inlet Comments Measured Depth (ft) 1200.00 1220.00 1764.90 2762.09 3257.71 3957.57 Sperry-Sun Drilling'Services Proposal Report for Steel Head - M-16RJ1 WP07 Revised: 14 October, 2003 ., Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 1176.85 154.12 N 2.97W 1194.64 162.76 N 0.00 E 1573.88 537.71 N 56.30 E 2040.00 1418.10 N 101.45 E 2329.42 1804.00 N 197.13 E 2806.86 2258.90 N i @ 12.000o/100ft: 1200.00ftMD,1176.84ftTVD ftMD,1194.64ftTVD OftMD,1573.88ftTVD 762.09ft MD, 2040.00ft TVD ° : 3257.71ftMD,2329.42ftTVD e Formation Tops Formati on P I a n e P r Poi n t (Below Well Origin) Measured Sub-Sea Dip Up-Dip Depth Depth Northings Eastings Formation Name (ft) Angle Dirn. (ft) (ft) (ft) (ft) 1438.00 0.000 358.601 1816.50 1598.00 1438.00 583.27 N 58.63 E SZ-12 1880.00 0.000 358.601 2762.09 2040.00 1880.00 1418.10 N 101.45 E SZ-17 2245.00 0.000 358.601 3368.50 2405.00 2245.00 1876.02 N 234.22 E SZ-22 2360.00 0.000 358.601 3537.08 2520.00 2360.00 1985.59 N 290.66 E SZ-23B 2485.00 0.000 358.601 3720.31 2645.00 2485.00 2104.69 N 352.01 E A-2 14 October, 2003· 10:34 e Page 40' 8 DrlllQue.t 3.03,02.002 Sperry-Sun Drilling Services Proposal Report for Steel Head· M-161./) WP07 Revised: 14 October, 2003 Kenai & Cook Inlet Casing details From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical. Depth Depth (ft) (ft) Casing Detail <Surface> <Surface> <Run-TO> <Run-TO> 7in liner - Targets associated with this wellpath Target Entry Coordinates Target Name TVD Northings Eastings Target Target (ft) (ft) (ft) Shape Type M-16 ST WP07 A2 DO Poly @ 95% w/MWD 2645.00 2104.69 N 352.01 E Polygon Current Target 2485.00 2501558.12 N 214483.28 E 60.83758° N 151.60043° W Target Boundary Point #1 2645.00 2175.34 N 385.09 E #2 2645.00 2152.89 N 406.60 E #3 2645.00 2126.21 N 417.42 E #4 2645.00 2098.75 N 419.16 E #5 2645.00 2071.78 N 412.36 E #6 2645.00 2047.03 N 396.29 E #7 2645.00 2028.80 N 370.13 E #8 2645.00 2026.99 N 337.27 E #9 2645.00 2044.66 N 309.82 E e #10 2645.00 2070.85 N 293.90 E #11 2645.00 2098.70 N 288.30 E #12 2645.00 2125.88 N 291.47 E #13 2645.00 2151.29 N 303.05 E #14 2645.00 2172.75 N 323.87 E #15 2645.00 2183.81 N 353.89 E 14 Oçfob@r, 1003 . 10:34 Pllfl@ 5 of , DrIllQuf.' 3.03.01.001 Sperry-Sun Drilling Services Proposal Report for Steel Head:M-16A/) WP07 Revised: 14 October, 2003 . Kenai & Cook Inlet Targets associated with this wel/path (Continued) Mean Sea Level/Global Coordinates #1 #2 #3 #4 #5 #6 #7 # M-16 ST WP07 A2 Geo Target 2645.00 Mean Sea Level/Global Coordinates: 2485.00 Geographical Coordinates: Target Radius: 100.00ft 14 October, 2003· 10:34 2501627.94 N 214518.08 E 501604.97 N 214539.03 E 01578.04 N 214549.20 E 1550.54 N 214550.26 E 523.75 N 214542.81 E 99.40 N 214526.14 E 01481.81 N 214499.54 E 2501480.80 N 214466.65 E 2501499.14 N 214439.64 E tit 2501525.71 N 214424.36 E 2501553.69 N 214419.44 E 2501580.78 N 214423.28 E 2501605.90 N 214435.47 E 2501626.85 N 214456.81 E 2501637.17 N 214487.09 E 60.83777" N 151.60024° W 60.83771° N 151.60012° W 60.83764° N 151.60006° W 60.83756° N 151.60005° W 60.83749° N 151.60009° W 60.83742° N 151.60018° W 60.83737" N 151.60033° W 60.83737" N 151.60051° W 60.83741° N 151.60066° W 60.83749° N 151.60075° W 60.83756° N 151.60078° W 60.83764 ° N 151.60077" W 60.83771 ° N 151.60070° W 60.83777" N 151.60059° W 60.83780° N 151.60042° W e 2104.69 N 352.01 E Circle Current Target 2501558.12 N 214483.28 E 60.83758° N 151.60043° W Page II of 8 DrlllQue,t 3.03.02.002 Sperry-Sun Drilling S(lrvlces Proposal Report for Steel Head - M-1fA/) WP07 Revised: 14 October, 2003 Kenai & Cook Inlet Targets associated with this wellpath (Continued) M-16 ST WP07 SZ238 Target Entry Coordinates TVD Northings Eastings Target Target (ft) (ft) (ft) Shape Type 297.53 E Point Current Target 214426.23 E 151.60073° W 1418.10 N 101.45 E Polygon Current Target 2500877.85 N 214216.03 E 60.83570° N 151.60183° W 010 #1 2040.00 1448.11 N 103.13E #2 2040.00 1445.14 N 114.81 E #3 2040.00 1437.13N 123.31 E #4 2040.00 1426.99 N 127.72 E #5 2040.00 1416.33 N 128.57 E #6 2040.00 1405.74 N 126.07 E #7 2040.00 1396.04 N 119.75 E #8 2040.00 1389.44 N 109.39 E #9 2040.00 1389.07 N 96.80 E #10 2040.00 1395.46 N 86.10 E #11 2040.00 1405.48 N 79.77 E #12 2040.00 1416.33 N 77.61 E #13 2040.00 1426.89 N 78.88 E #14 2040.00 1436.68 N 83.47 E #15 2040.0q 1444.61 N 91.70 E Mean Sea Level/Global Coordinates #1 1880.00 2500907.81 N 214218.44 E #2 1880.00 2500904.56 N 214230.05E #3 1880.00 2500896.34 N 214238.35 E #4 1880.00 2500886.10 N 214242.51 E #5 1880.00 2500875.42 N 214243.10 E #6 1880.00 2500864.89 N 214240.34 E #7 1880.00 2500855.35 N 214233.79 E #8 1880.00 2500849.00 N 214223.27 E #9 1880.00 2500848.94 N 214210.67 E #10 1880.00 2500855.59 N 214200.13 E #11 1880.00 2500865.76 N 214194.05 E #12 1880.00 2500876.66 N 214192.15 E #13 1880.00 2500887.19 N 214193.68 E #14 1880.00 2500896.86 N 214198.p1 E #15 1880.00 2500904.59 N 214206.93 E P'rlO T of' Drl/lQue.t 3.03.02.002 e Target Name M-16 ST WP07 SZ-17 DO Poly @95% w/MWD e 14 Oetober, 2003. 10:34 Kenai & Cook Inlet Targets associated with this wellpath (Continued) M-16 ST WP07 SZ-17 Geo Target 14 October, 2003· 10:34 Sperry-Sun Drilling Services Proposal Report for Steel Head· M-16fffJ WP07 Revised: 14 October, 2003 60.83578° N 60.83577° N .83575° N .83573° N 3570° N 567" N 0.83564° N 60.83562° N 60.83562° N 60.83564° N 60.83567" N 60.83570° N 60.83572° N 60.83575° N 60.83577° N 2040.00 1880.00 1418.10 N 2500877.85 N 60.83570° N eographical Coordinates: Target Radius: 50.00ft Page B of B 151.60182° W 151.60176° W 151.60171° W 151.60168° W 151.60168° W 151.60169° W 151.60173° W 151.60179° W 151.60186° W 151.60192° W 151.60195° W 151.60197" W 151.60196° W 151.60193° W 151.60189° W 101.45 E 214216.03 E 151.60183° W e Circle Current Target e Dr/llQue.t 3,03.02,002 Company: Field: Reference Site: Reference Well: Reference Wellpath: Unocal Alaska McArthur River Field Steelhead M-16 PlanM-16ß.Ð e Halliburton Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 25.00 ft Depth Range: 1200.00 to 3957.57 ft Maximum Radius: 595.76 ft Survey Program for Definitive Wellpath Date: 10/10/2003 Validated: No Planned From To Survey ft ft 90.00 1200.00 1200.00 3957.57 Casing Points MD ft 1200.00 3957.00 M-16 Gyro (90.00-1240.00) (0) Planned: Plan M-16 ST (wp07) V14 Date: 10/13/2003 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Version: 0 Toolcode CB-GYRO-SS MWD TVD Diameter Hole Size Name ft in in 1176.85 9.625 12.250 9-5/8" Csg Window 2806.47 7.000 8.500 7" Summary < Site Dolly Varden Dolly Varden Dolly Varden Dolly Varden Dolly Varden Dolly Varden Dolly Varden Dolly Varden Dolly Varden Dolly Varden Dolly Varden , Dolly Varden Dolly Varden Dolly Varden Dolly Varden Dolly Varden Dolly Varden Dolly Varden Dolly Varden Dolly Varden Dolly Varden Grayling Grayling Grayling Grayling Grayling Grayling Grayling Grayling Grayling King Salmon King Salmon King Salmon King Salmon King Salmon King Salmon King Salmon King Salmon King Salmon King Salmon King Salmon King Salmon King Salmon Offset Wellpath Well' Leg.4.1 Slot 5 Leg A1 Slot 5 Leg A1 Slot 9 Leg A1 Slot 9 Leg A2 Slot 1 Leg A2 Slot 2 Leg A2 Slot 2 Leg A2 Slot 3 Leg A2 Slot 4 Leg A2 Slot 4 Leg À2 Slot 4 Leg·A2 Slot 9 Leg A2 Slot 9 Leg B1 Slot 1 Leg B1 Slot 1 Leg B1 Slot 5 Leg B1 Slot 5 Leg B1 Slot 6 Leg B1 Slot 7 Leg B1 Slot 7 Leg B1 Slot 7 Leg 2 Slot 38 Leg 2 Slot 40 Leg 2 Slot 40 Leg 2 Slot 41 Leg 2 Slot 44 Leg 2 Slot 46 Leg 2 Slot 46 Leg 3 Slot 11 Leg 3 Slot 5 Leg 1 Slot 1 Leg 1 Slot 1 Leg 1 Slot 2 Leg 1 Slot 2 Leg 1 Slot 3 Leg 1 Slot 3 Leg 1 Slot 3 Leg 1 Slot 4 Leg 1 Slot 5 Leg 1 Slot 6 Leg 1 Slot 7 Leg 1 Slot 7 Leg 1 Slot 8 Wellpath 0-40 VO D-40RD VO 0-43 VO D-43RD VO 0-01 VO 0-17 VO D-17RD VO 0-11 VO 0-07 VO D-07RD VO D-07RD2 VO 0-05 VO D-05RD VO 0-08 VO D-08RD VO 0-16 VO D-16RD VO 0-22 VO 0-02 VO D-02ARD VO D-02RD VO G-31 VO G-01 VO G-01 RD VO G-09 VO G-30 VO G-06 VO G-06RD VO G-33 VO G-24 VO K-21 VO K-21 RD VO K-30 VO K-30PB VO K-18 VO K-18RD VO K-18RDPB VO K-17 VO K-23 VO K-19 VO K-22 VO K-22RD VO K-20 VO Reference MD ft Offset MD ft Reference: Error Model: Scan Method: Error Surface: Tool Name e Time: 09:37:36 Page: Well: M-16, True North Rebuilt Site 160.0 Db: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Camera based gyro single shots MWD - Standard Ctr-Ctr No-Go Distance Area ft ft Allowable Deviation ft Warning Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range e Halliburton e Anticollision Report Company: Unocal Alaska Date: 10/13/2003 Time: 09:37:36 Page: 2 Field: McArthur River Field Reference Site: Steel head Co-ordinate(NE) Reference: Well: M-16, True North Reference Well: M-16 Vertical (fVD) Reference: Rebuilt Site 160.0 Reference Well path: Plan M-16 RJ) Db: Oracle Summary < Offset Wellpath Reference Offset Ctr-Ctr No-Go Allowable Site Well Well path MD MD Distance Area Deviation Warning ft ft ft ft ft King Salmon Leg 2 Slot 13 K-13 VO Out of range King Salmon Leg 2 Slot 13 K-13RD VO Out of range King Salmon Leg 2 Slot 13 K-13RD2 VO Out of range King Salmon Leg 2 Slot 10 K-09 VO Out of range King Salmon Leg 2 Slot 11 K-04 VO Out of range King Salmon Leg 2 Slot 11 K-04RD VO Out of range King Salmon Leg 2 Slot 12 K-11 VO Out of range King Salmon Leg 2 Slot 14 K-02 VO Out of range King Salmon Leg 2 Slot 14 K-02RD VO Out of range King Salmon Leg 2 Slot 15 K-07 VO Out of range King Salmon Leg 2 Slot 15 K-07RD VO Out of range King Salmon Leg 2 Slot 16 K-05 VO Out of range King Salmon Leg 2 Slot 9 K-15VO Out of range King Salmon Leg 2 Slot 9 K-15RD VO Out of range King Salmon Leg 4 Slot 25 K-08 VO Out of range King Salmon Leg 4 Slot 25 K-08RD VO Out of range King Salmon Leg 4 Slot 25 K-26 VO Out of range King Salmon Leg 4 Slot 25 K-26RD VO Out of range King Salmon Leg 4 Slot 26 K-01 VO Out of range King Salmon Leg 4 Slot 26 K-01 PB VO Out of range King Salmon Leg 4 Slot 26 K-01 RD2 VO Out of range King Salmon Leg 4 Slot 27 K-10 VO Out of range King Salmon Leg 4 Slot 27 K-10RD VO Out of range King Salmon Leg 4 Slot 28 K-16 VO Out of range King Salmon Leg 4 Slot 29 K-012 VO Out of range King Salmon Leg 4 Slot 29 K-12RD VO Out of range King Salmon Leg 4 Slot 30 K-06 VO Out of range King Salmon Leg 4 Slot 30 K-06RD va Out of range King Salmon Leg 4 Slot 31 K-24 VO Out of range King Salmon Leg 4 Slot 31 K-24RD VO Out of range King Salmon Leg 4 Slot 31 K-24RD2 VO Out of range King Salmon Leg 4 Slot 32 K-03VO Out of range King Salmon Leg 4 Slot 32 K-03RD VO Out of range Steel head M-01 M-01 V2 1201.22 1200.00 180.09 20.09 160.01 Pass: Major Risk Steel head M-02 M-02 V4 1202.92 1275.00 301.43 24.44 276.99 Pass: Major Risk Steelhead M-03 M-03 V2 1211.86 1250:00 229.52 19.63 209.89 Pass: Major Risk Steelhead M-04 M-04 V4 1207.76 1200.00 189.25 21.12 168.14 Pass: Major Risk Steel head M-05 M-05 V2 1200.00 1225.00 202.64 19.75 182.90 Pass: Major Risk Steel head M-07 M-07 V2 1204.83 1175.00 190.71 25.08 165.63 Pass: Major Risk Steel head M-09 M-09 V2 1206.36 1200.00 239.17 21.01 218.15 Pass: Major Risk Steel head M-12 M-12 V6 1215.91 1250.00 112.38 19.13 93.25 Pass: Major Risk Steel head M-13 M-13 V2 1206.10 1300.00 245.97 18.58 227.38 Pass: Major Risk Steel head M-14 M-14 V2 1211.66 1275.00 198.95 17.82 181.12 Pass: Major Risk Steel head M-14 M-14RD V2 1211.66 1275.00 198.95 17.82 181.12 Pass: Major Risk Steel head M-15 M-15 V3 1208.00 1325.00 297.38 26.72 270.66 Pass: Major Risk Steel head M-16 M-16 V4 1200.00 1200.00 0.00 4.45 -4.45 FAIL: No Errors Steelhead M-19 M-19RD V4 1208.69 1275.00 221.60 19.54 202.06 Pass: Major Risk Steelhead M-25 M-25 V3 1214.67 1225.00 123.98 16.62 107.36 Pass: Major Risk Steel head M-26 M-26 V1 1216.42 1225.00 111 .23 20.72 90.51 Pass: Major Risk Steelhead M-27 M-27 V4 1200.00 1200.00 135.25 24.55 110.70 Pass: Major Risk Steelhead M-28 M-28 V2 1202.05 1200.00 125.14 18.72 106.41 Pass: Major Risk Steel head M-29 M-29 V2 1205.38 1225.00 124.99 19.76 105.22 Pass: Major Risk Steel head M-30 M-30 V2 1201.93 1200.00 80.25 19.26 60.99 Pass: Major Risk Steel head M-31 M-31 V2 1209.77 1225.00 108.84 19.86 88.98 Pass: Major Risk Steel head M-31 M-31L 1 V1 1209.77 1225.00 108.84 19.86 88.98 Pass: Major Risk Steelhead M-32 M-32 V2 1210.81 1225.00 129.55 17.18 112.37 Pass: Major Risk Steel head M-32 M-32RD2 V2 1210.81 1225.00 129.55 17.18 112.37 Pass: Major Risk e e Drilling Fluids Program UNOCAL Steelhead Platform M-16 RD Prepared by: Lee Dewees Reviewed by: Deen Bryan Presented to: Larry Buster/Skip Coyner Friday, September 19, 2003 M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax ~..... .............. ,DRI.UNI:i ,..~ FLUIDS e DRILLINEi FLUIDS e M-I Drilling Fluids L.L.c. 721 West First Avenue Anchorage, Alaska 99501 Phone (907) 274-5564 Fax (907) 2709-6729 Friday, September 19,2003 UNOCAL 909 West 9th Avenue Anchorage, Alaska 99501 ATTN: Larry Buster Skip Coyner Gentlemen; Enclosed is a drilling fluids program for the Steelhead M-16RD gas well. Included is a Flo Pro NT drilling fluid program. This system is designed to have minimum drill solids. Sized calcium carbonate is added to the system to limit whole mud losses and reduce filtrate invasion. This program includes 3% KCI, however concentrations in excess of 3% may cause LC 50 values to be exceeded, assuming that mud and cuttings are discharged under the NPDES permit. Mud and cuttings sheen testing, heavy metals, gas. chromatograph, monthly and end of well bioassay testing and report- ing will be required to comply with these regulations. The proposed system has been successfully used to drill similar intervals in Cook Inlet. Please call if you have any questions regarding the mud program. Lee Dewees Project Engineer M-I Drilling Fluids 907274-5533 e e Interval Summary 8 1/2" M-16RD D.rilUngFluidSystem SeawaterBio-po1ymer F10- Drill NT KeyProducts F10- Vis / Po1ypac UL / Asphoso1/ MI Bar / Caustic Soda Resinex/ Klagaurd/Lubetex/Dua1 F10/KC1/Greencide/citric acid Safe Carb/Dual F10/ NaC1/G1ass Beads Solids Control Swaco Shale Shakers / Mud Cleaner /518 Centrifuge PotentialProblems Hole cleaning / coal sloughing / drill solids buildup / lost circulation! stuck pipe/shallow gas Depth Interval (ft) 1200'· - Plastic Viscosity (cp.) 12-20 Yièld Point (lb/100ft2) 15-20 API Fluid Loss (mI/30min) < 10 cc's 8-12 · Drill cement and shoe with existing spud mud. · Run leak off test to establish fracture gradient at the kick off window. · Build Flo-Pro NT mud system with the following; II ppb KCl, 2.0 ppb Flo-Vis, 6 ppb Dual Flo, 4-6 ppb Kla- gaurd, Adjust pH to 9.0 - 9.5 w/Caustic Soda. Adjust 3 RPM reading to > 8 w/Flo-Vis, Raise mud weight to 8.9 ppg with NaCl. Increase mud weight to 92 ppg with Safe Carbo Use Optibridge calculation. · If coal becomes a problem, add Soltex (Asphsol) and Resinex up to 4 - 8 ppb. · Maintain 3-4 ppb Klagaurd to inhibit clay swelling. · Add Lubetex for lubricity. DO NOT ADD MORE THAN 1 %. ADDITIONS GREATER THAN 1 % COULD FAIL THE BIO-ASSA Y TEST. · Keep drill solids to a minimum by use of all solids control equipment and water additions. · Add Lubetex to system for lubricity and to help sliding. (pilot test to confIrm sheen test compliance) · Monitor ALC 50 values to ensure ability to discharge mud and cuttings. M-I Drilling Fluids L.L.C. 721 West First A venue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRILLING FWDS - e Interval Summary 8 1/2" M-16RD DrillingFluidSystem Seawater Bio-polymer Flo-Drill NT KeyProducts Flo- Vis I Polypac UL I Asphosoll Ml Bar I Caustic Soda Resinex/ KlagaurdlLubetexIDual Flo/KCl/Greencide/citric acid Safe Carb/Dual Flol NaCI/Glass Beads SoUdsControl Swaco Shale Shakers I Mud Cleaner 1518 Centrifuge PotentialProblems Hole cleaning I coal sloughing I drill solids buildup I lost Circulation/I stuck pipe/shallow gas . · Increase mud weight as required. Shallow gas can be a problem on the Steelhead Platform. . Consider the use of a Form A Set AK lost circulation pill if significant loss of returns are encountered · Use MIX II and/or calcium carbonate for losses if the drill string contains a MWD and a mud motor, M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax ..,..... ... ................. .....·D.RIL. LI. Iii '.~FJIIIOC: ~.ì·················'·'·'."·······;;r"'~.~. ; [, . . 'iii r . . ( ~,m:lf Til11TT ill 1~ , ¿: I' OPTIBRIDcl:™ Operator: Wen Name: Location: Comments: CI 1999-2001 M~I LL.C _ All RIøhts RøsBl¥8d M-I LLC Attic Steeihead Optimum Blend Optimum Bridging Agent Blend 1,0 0,9 0.8 c: 0.7 0 '5 .Do ij 0.6 a :1\ Ü; .. 0.6 U 1i .... ... ... 0.4 'fii "5 E => u 0.3 0.2 0.1 -rX1Q-2 ~ '1 x1 0". 1';'10" 1 x10' 1 ;'10" 1 x10' 1x104 -, Max Permeability : Sand Control Device: 750 mDal"C: 010 - 060 - 090 D10 ia..get I Blend: D5D Target I Blend: D90 T....get I Blend: 1.5 26.0 123.7 mlcl"ons microns microns 1.1 27.4 88.8 Optimum Blend for 0 to 100 % CPS Range Brand Name A-Safs_Carb 2 (\IF) B-Safe-Carb 10 (F) C-S.fe-Carb 20 D-Safe-Carb 40 (M) E-Safe-Carb 250 (C) F-S.fe-Carb 500 (XC) Brldplnq Aøent ßb/bbh 0.0 0.0 22.5 12.5 0.0 0.0 JlJ>U 0.0' 0.01 64.21 35.8' 0.0' 0.01 o 35.8% Simulation Accuracy Calcium Carbonate eddød : Avg Error 0 - 100 % CPS Range: Max Errol" 0 _ 100 % CPS Range: 35 Ib/bbl 1.66 % 12.07 % , '1 ) 4 Operator: Wen Name: Location: Comments: QpTIBRIDGE™ IC) '999_2001 M-J LL.C _ All Rlahts Res8N8d M-I LLC Attic Steelhead Optimum Blend Optimum Bridging Agent Blend 1.0 0.9 0.8 c: 0.7 0 :g .Do ii 0.6 a ,; ~ 0.5 ~ D. .. i 0.4 "S § u 0.3 0.2 0.1 -r"10-2 ''¡x10·' 1 x10" 1,,10' 1 x10" lIII1r,mllil~~t.lI-.]j 'm "_.IØ~,8iêiiif!¡ii~f~ 1 ;'10' 1 x10" MaJC Pe...meablllty : Sand Contl'"ol Døvice : 550 mDal'"c 010 . 060 090 D10 Target I Blend: 0.9 1.2 microns 050 TII..get I Bland: 23.5 22.3 miCl"ons D90 Target I Blend: 76.0 100.0 microns Optimum Blend for 0 to 100 % CPS Range B....nd Name A-S.f.·Carb 2 (VF) B-Safe_Carb 10 (F) C-Safe-Carb 20 O-Safe_Carb 40 (M) E-Safe-Carb 250 (C) F-Safe-Carb 500 (XC) Brldøln(l Aaentnb/bbl1 0.0 0.0 29.1 5.9 0.0 0.0 JlJ>U 0.01 0.0' 83.11 16.91 0.0' 0.01 D C 83.1% Simulation Accuracy Calcium Carbonete added: Avg Erro... 0 - 100 % CPS Range: Max Enol'" 0 _ 100 % CPS Range: 35 1.61 10.61 Ib/bbl % % '¡¡U!\l~J]¡L;illi!JlJ¡! ~.¡¡¡¡.I__íif.â:.;;;;~~¡:;¡~:S!~."~n.:M1í."" M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRILLING FlIIIOC; ~'í¿.~~p~~tl· 6" Drill Pipe ORPM MD: .... ft TVD: 2715. ft Bìt Stze: 8.5 In. Oat..: 9/1912003 Operator: Unocal Well Name: M-16RO Loca.t'on: St:eelhead Country: US Geometry Depth ITVD (ft) Cag I H DiB (In.) (ft) AV (ft/min) Density (Ib/gal) 9.4 9.6 9.B 10.0 10.2 0 PV,VP,LSVP 10 20 Angle 30 60 30 0 250 500 750 90 9.2 j! 263 ~ ~ 28) \ ..::f. ESD _SYF ECD+Cut, Hole Clean Ind VO OF P Pressure Loss (%) 25 50 75 MD; 3899 ft Operator: Unocal 6" Drill Pip.. TVD: 2715 ft Welt Name: M-16RD 80 RPM Bit: Size; 8J5 In. Location: st..lhead Date; 9/1912003 Country: US Geometry Depth ) 'TVD (ft) Csg I H [)fa (In.) (ft) Density (Ib/gal) 9.4 9:6 9.8 10.0 10.2 0 } PV,VP,LSYP 10 20 AV (ft/min) 30 0 250 SOD 750 263 Angle 30 60 90 9.2 ECD f'Y... ESD \ -\- I 28) ........--.- -.-..-...-..--..-..-- ..::f. _Syp ECD+Cut, M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax Hole Clean Ind VO OF P Pressure Loss (0/0) 25 50 75 DRilliNG FWIDS M-I Drilling Fluids L.L.C. 721 West First A venue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax ..",-... .... DRI.l.ING ,~ FWIDS e SchlBlbep" * CemCADE well cementing recommendation for Operator Country State :UNOCAL : USA : Alaska Well Field M-16 ST Prepared for Proposal No. Date Prepared : Mr. Skip Coyner : 1 : 09-19-2003 Location Service Point Business Phone : FAX No. Steel head Anchorage, Alaska 907-273-1739 907 -561-8417 Prepared by : Chris Avant Phone 907-317-8254 E-Mail Address:CAvant@slb.com ~\ßN~ t ~ ~(¡ATE ~ C/) " ::: ::¡. õ- ro to g;. "t1 .... ;;:- ~ CD Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schiumberger assumes no liability for advice or recommendations made concerning resuns to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data, The information presented is Schlumberger's best estimate of the actual resuns that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting, The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any condllions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notlly the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. . Mark of Schlumberger Client Well String District Country Loadcase UNOCAL M-16 ST Anchorage, Alaska USA Base e Sill... Section 1: well description Configuration Stage Rig Type Fluids Return to Mean Sea Level SeaBed Depth Mud Line Total MD BHST Bit Size MD (ft) 1200.0 : Casing : Single : Fixed Offshore : RIG]LOOR : 100.0 ft : 150.0 ft : 20.0 ft : 3958.0 ft : 91 degF : 8 1/2 in Previous String OD Weight (in) (Ib/ft) 95/8 47.0 ID (in) 8.681 OD (in) Casing/Liner Weight ID Grade (Iblft) (in) 29.0 6.184 K55 U1 g. 3 v CD t.Ò (þ "' Landing Collar MD : 3878.0 ft Casinglliner Shoe MD : 3958.0 ft MD (ft) 3958.0 Burst Thread (psi) 5610 HYD Joint (ft) 40.0 Collapse (psi) 5400 " "' <' '" ro 7 Mean OH Diameter : 8.500 in Mean Annular Excess : 50.0 % Mean OH Equivalent Diameter: 9.158 in Total OH Volume : 224.7 bbl (including excess) Max. Deviation Angle : 62 deg Max. DLS : 46.845 deg/100ft Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 3720.3 14.00 8.30 A-2 Sandstone 3958.0 14.00 8.30 Sandstone Reference depth for pressure conversion to equivalent density or pressure gradient is RIG_FLOOR Geothermal Temperature Profile TVD Temperature Gradient (ft) (degF) (degF/100ft) 0.0 45 0.0 99.9 40 -5.0 149.8 36 -6.0 2806.3 91 1.6 MD (ft) 0.0 100.0 150.0 3958.0 Page 2 M-16 Recom¡Hetion.cfw; 10-1~2003; LoadCase Base; Version wcs-cem44_104 Client Well String District Country Loadcase e UNOCAL M-16ST Anchorage, Alaska USA Base Section 2: fluid sequence Original fluid Mud 9.40 Ib/gal Pv : 15.000 cP 144.1 bbl 313.3 bbl 700.0 ft Displacement Volume Total Volume TOC -- Ty: 17.00 Ibf/100ft2 Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (Ib/gal) CW100 30.0 0.0 8.32 k:2.09E-5 Ibf.s^n/ft2 n:1.000 MudPUSH XL 10.5 30.0 680.0 10.50 pv:22.000 cP Ty:19.00 Ibf/10Oft2 ppg LiteCRETE 109.2 3258.0 700.0 12.00 Pv:81.491 cP Ty:33.51 Ibf/100ft2 Mud 144.1 0.0 9.40 Pv:15.000 cP Ty:17.00 Ibf/10Oft2 ¡Section l~.;J~~XI1PJJ~g__ª~b~~tlJl~ Start Job: Ensure mud conditioned as per design. . 'Pumping Schedule Volume Stage Time Cum.Vol (bbl) (min) (bbl). Name Flow Rate (bbVmin) CW100 MudPUSH XL 10.5 ppg Pause LiteCRETE Pause Mud Mud 4.0 4.0 30.0 30.0 7.5 7.5 0.0 4.0 0.0 4.0 2.0 0.0 109.2 0.0 134.1 10.0 10.0 0.0 80 Drop bottom plug 27.3 109.2 80 10.0 0.0 80 Drop top plug 33.5 134.1 80 5.0 144.1 80 01:40 313.3 bbl hr:mn Tot_I End Job: Record plug bumping and retums to surface. BHCT 86 degF Simulated BHCT 76 de9F CT at TOC 73 degF Static temperatures : At Time I (hr:mn) Top of Cement (degF) Bottom Hole (de9F) Temperature Results I Simulated Max HCT Max HCT Depth Max HCT Time I (hr:mn) (degF) (degF) ------------ 1 Comment: @GraPhic:</t:Fluid_sequen] ce If: I li:Depth Scale + Fluid Sequence + Static Well Security > . m no' --' m no -- . -- m....... fCot11l11ent:) ::> 0- CP «3 ~ "'0 .... ;;:. ¡u ít - - - - - - - - - - - - ~ ~ - - - - - - - - -- 30.0 30.0 Inj, Temp. (degF) 80 80 Comments 77 degF 3392.6 ft 01 :40:48 hr:mn:sc I Geo. Temp. 47 degF 91 degF ..{ Comment: @Graphic:</t:Pump_Sched 1 l ule If:! Ii: Standard Plots vs Time:3:4 > M-16 Recompletion.cfw; 1~15-2003; LoadCase Base; Version wcs-cem44_104 Page 3 Client Well String District Country Loadcase UNOCAL M-16 ST Anchorage. Alaska USA Base e -. Section 4: centralizer placement Top of centralization Bottom Cent. MD Casing Shoe NB of Cent. Used NB of Floating Cent. Bottom MD (ft) 3958.0 Nbr. 48 :3000.0 ft :3948.0 ft :3958.0 ft :48 :48 Cent. I Joint 2/1 Centralizer Placement Cent. Name Code Min. STO (%) @ Depth (ft) 3000.4 SPIRAGLlDER-7-6- SPlRAL0850 S071 0.0 Centralizer Description Cent. Name Code Casing Max. Min. OD Rigid OD OD (in) (in) (in) SPIRAGLlDER-7-6- S071 7 8.252 8.252 Yes SPlRAL0850 Centralizer Tests Hole Size Running Restoring (in) Force Force (Ibf) (Ibf) NA N.A. N.A. Origin Hannover (1) - Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications ft % 0- o o 0- 1,0 N 0_ o o o 1,0_ Pipe Standoff M-16 Recompletion.cfw; 10-15-2003; LoadCase Base; Version wcs-cem44_104 Page 4 (f) <"J '::7' ~ 3 0- \'P ..., (Q \'P ..., Comment: @GraPhic:</t:Well_Central] izer If: I ~i: Depth Scale + Pipe Standoff> ø Client Well String District Country Loadcase ...- UNOCAL M-16 ST e Anchorage. Alaska USA Base Section 5: WELLCLEANlaminar Annular Zone of Interest Top: 3100.0 ft Bottom: 3958.0 ft All preflushes are displacing the original mud. All cement slurries are displacing the last selected preflush (or the original mud) Fluid Name Effective Laminar Flow Displacement Max. (Qmin) @ (MD) Min. (Qmax) @ (MD) (ft) Min. Effective (bbl/min) (ft) (bbl/min) Vol. (bbl) LiteCRETE 3958.0 16.6 3100.0 1.0 Flow rate ranges to get effective laminar flow displacement for all selected fluids: Qmin : 1.0 bbl/min Qmax : 16.6 bbl/min Differential Velocity Criterion has been selected Section 6: WELLCLEAN turbulent Annular Zone of Interest Top : 3100.0 ft Bottom: 3958.0 ft Fluid Name Full Turbulent Flow Displacement Max.(Qcrit) @ (MD) (ft) Min. Contact Time (bbl/min) (min) 1.1 3958.0 @ Depth. (ft) CW100 Minimum annular flow rate to get all selected fluids in turbulent flow all around the annulus and across the zone of interest: Qmin : 1.1 bbllmin Page 5 M-16 Recompletion.cfw; 10-15-2003: LoadCase Base; Version wcs-cem44_1 04 @ Depth (ft) (J) n -' c- ~ c.ó (t> .., "'0 .., <' w ro Client Well String District Country Loadcase e UNOCAL M-16ST Anchorage, Alaska USA Base Section 7: fluid descriptions Mud DESIGN Fluid No: 1 Rheo. Model At temp. : BINGHAM : 80 degF MUD Mud Type : WBM Water Type : Sea VOLUME FRACTION Solids : 5.0 % Oil : 1.0% Water : 94.0 % Density Pv Ty Gel Strength Silll,-- : 9.40 Ib/gal : 15.000 cP : 17.00 Ibf/100ft2 : (lbf/100ft2) Job volume : 144.1 bbl MudPUSH XL 10.5 ppg DESIGN Fluid No: 2 Rheo. Model At temp. : BINGHAM : 70 degF SPACER Spacer Type: LAM Mud Type : WBM BASE FLUID Type : Sea water Porosity : 91.8 % Water/Spacer : 91.8 % Density Code 0031 Weighting Agent(s) Cone. 102.66 Ib/bbl of spacer () Density 270.31 Ib/ft3 (lbIft3) I Code 0182 Additives Cone. Function 7.0000 Ib/bbl of base fluid TURB. SPACER Density Pv Ty Gel Strength : 8.60 Ib/gal : 10.50 Ib/gal : 22.000 cP : 19.00 Ibf/100ft2 : (lbf/100ft2) (f) (") :;¡- ~ -' C) œ u:i (!) .., Job volume: 30.0 bbl "tJ .., <' '" ro M-16 Recompletion.cfw ; 10-15-2003; LoadCase Base; Version wcs-cem44_' 04 Page 6 Client Well String District Country Loadcase UNOCAL M-16ST Anchorage, Alaska USA Base Fluid No: 3 Rheo. Model At temp. : BINGHAM : 80 degF DESIGN BLEND Name : G Dry Density : 199.77 Ib/ft3 Sack Weight: 94 Ib BASE FLUID Type : Sea water Additives Code D962 D600G Cone. Proprietary Blend 2.000 gal/sk blend Fluid No: 4 Rheo. Model At temp. : POWER_LAW : 90 degF WASH Wash Type : CW100 Mud Type : WBM BASE FLUID Type : Fresh water I Code D122A Additives Cone. 0.500 gal/bbl of wash e -- LiteCRETE DESIGN SLURRY Mix Fluid Yield Porosity : 6.139 gal/sk : 2.23 ft3/sk : 36.7% Density Pv Ty Gel Strength : 12.00 Ib/gal : 81.491 cP : 33.51 Ibf/100ft2 : (lbf/100ft2) Density : 8.60 Ib/gal Job volume: 109.2 bbl Quantity : 274.42 sk Solid Fraction : 63.3 % Base Fluid : 3.939 gal/sk Density : 8.32 Ib/gal k : 2.09E-5 Ibf.s^n/ft2 n : 1.000 Gel Strength : (lbf/100ft2) en ("1 :T ë :3 r:r <P ~ ::g "U .... <' to ro Function LiteCRETE GASBLOK CW100 DESIGN WaterNVash : 98.8 % Density : 8.32 Ib/gal Job volume : 30.0 bbl M-16 Recompletion.cfw; 1().1s.2003: LoadCase Base; Version wcs-œm44_1()4 Page 7 Function CHEM WASH CO Client Well String District Country Loadcase UNOCAL M-165T Anchorage, Alaska USA Base e Section 8: design graphics ft 0- o Ó 0- It) N o c::i o o 1.0- ALidSeQsœ 7.5 10.0 -.. Ib' g:¡I 12.5 15.0 M1.~ .... MK~ .-- M1.~ -Fi'a:; -Rre -~ \ (J) (") ::T ¡: ~ 0- IP ... (D IP ... "'tJ ... < OJ ro DjraTic V\él1 Sau-Iy M-16 Recompletion.c1iN; 10-15-2003; LoadCase Base; Version wcs-cem44_104 Page 6 UNOCAL M-16 ST e -- Client Well String District Country Loadcase : Anchorage, Alaska USA Base ¿ c: « '" ,...: 90 120 150 180 210 Pumped Volume (bbl) 240 270 300 330 o ~ - Well Head Pressure WHP o 330 (J) g. :3 0- It> tÒ CD .... ~ Cl. J: 3: o "tI .... <' OJ ro ê 'Ë ~ s m a:: ~ ¡¡: CD - Acquired a Out I , : -- Acquired Q In .' , - - - ~ a Out -- In , ' ¡ ... -- , " - I,: : , r , , , at 3958 ft o 1 1 Pumped Volume (bbl) 330 0 ~ ê 'Ë ª- ~ g ~ ¿ c: « 0 0 1 1 Pumped Volume (bbl) M~16 Recompletion.cfw; 10-15-2003; loadCase Base; Version wcs-cem44_104 Page 9 ~ .,' e Unocal Alaska ~ Union Oil Company of Califomi 909 West 9th Avenue, P.O. Box 1 247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 Fax (907) 263-7698 UNOCAL. Kevin A. Tabler, Manager Land/Govemment Affairs October 16, 2003 Mr. Steve Davies Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 APPLICATION FOR SPACING EXCEPTION Trading Bay Unit, Steelhead Platform, M-16 RD ADL-18730 ADL-17594 J"\~j~j Dear Mr.efAluli:l.ll.· Union Oil Company of California (Unocal) hereby submits this Application for Spacing Exception to drill the referenced "M-16 RD" well in the Trading Bay Unit. Our anticipated spud date is November 1,2003. In accordance with 20 AAC 25.005 (a), a Permit to Drill and associated filing fees will be submitted later this week. The M-16 RD well is situated within the same governmental section as the M-9 well and other wells, requiring a spacing exception in accordance with 20 AAC 25.055 (a)(4) and if the results of the M-16 RD well are successful, will be within 3000' of a well capable of producing ftom the same pool. This regulation provides in pertinent part, "not more than one well may be drilled to and completed in that pool on any governmental section; a well may not be drilled or completed closer than 3,000 feet to any well drilling to or capable of producing ftom the same pooL" At the date of this mailing, in accordance with 20 AAC 25.055 (d)(1), notice of our intent to drill has been sent by certified mail to all owners, landowners, and operators of all outlying properties within 3,000 feet ofthe M-16 RD well. A copy of this application (landowner notice) along with a certified mailing receipt has been attached to this application. Additionally, the owners and the landowner (State of Alaska) are the same on both sides of all property lines associated with this well. e e Pursuant to 20 AAC 25.055 (d)(2), enclosed is a plat, identified as Exhibit "A", which shows the location of the well for which the exception is sought and all adjoining properties. Also enclosed, Exhibit "A-I" identifies the owners, landowners and operators associated with the lease (ADL-18730) and adjoining lease (ADL-17594). Pursuant to 20 AAC 25.055 (d)(3), an affidavit is enclosed stating the undersigned is acquainted with the facts and verifying that all facts are true. It is requested that the Alaska Oil and Gas Conservation Commission approve an exception to Rule 1 through administrative approval under Rule 3 of Conservation Order 228 for the drilling of the proposed M-16 RD well. If you require additional information regarding the M-I6 RD well, please contact Mr. Skip Coyner, drilling engineer at 263-7690, or you may contact .the undersigned at 907- 263-7600. Enclosures cc: Marathon T9N R13W M-19RD ADL-17594 M-12 ~ G-'18 -07 29 27 e __~______~_.____~_____·_ø__________ 32 33 34 e ----------~-- I I . I I I , , I I . -----.-·~-------------------------------------r------------------------------------------------------~-- Exhibit A e e EXHIBIT "A-I" LEASE LANDOWNER OWNERS OPERATOR ADL-18730 State of Alaska (Sections 26 Wl/2, 27,28,33,34 T9N-RI3W) Unocal, Marathon P.O. Box 196168 Anc., Ak 99519-6168 <:W.~ 701) I 0120 0005 S<{lJ b '785/ Unocal Unocal ADL-17594 State of Alaska (Sections 16, 17 S/2,NE/4, 20,21,29,30,31,32 T9N-R13W) Unocal, Marathon P.O. Box 196168 Anc., Ak 99519-6168 It tit VERIFICATION OF APPLICATION FOR SPACING EXCEPTION COOK INLET, ALASKA ADL-18730 ADL-17594 M-16 RD well I, KEVIN A. TABLER, Manager, Land and Government Affairs, Union Oil Company of California, do hereby verify the following: I am acquainted with the application submitted for the drilling of the M -16 RD well in the Trading Bay Unit. I have reviewed the application submitted for the exception to 20 AAC 25.055 (a)(4) and all facts therein are true. I have reviewed the plat attached to said application, and it correctly portrays pertinent and required data. DATED at Anchorage, Alaska this 16th day of October, 2003. ~,.~.J~ ~vin A. Tabler Mgr., Land & Govt. Affairs STATE OF ALASKA ) ) ss ) THIRD JUDICIAL DISTRICT SUBSCRIBED TO AND SWORN before me this 16th day of October, 2003. ~~\\\\IIIIIII/II~ ~~ þ.. 87';. ~..._ ø~~"';;;;;îó;¡~~~ ~;:jl cJ1",...~, !Ii .....,.~ ~ ~ I i NOTAllY} I ~"."" PUBLIC!~ .::" ~ A...~.... iI!!iii: w~'" b. 14, '1{:0' ~~ , 4J'i·Öf'·~\."õl ~1111lI''''\~ ~;-~. o...l~ ItbiARY-PUBLIC IN AND FOR THE STATE OF ALASKA My Commission expires: .J. ~ 1'/ - 0" tit -- U.S. Postal -., . CERTIFIED MAIL RECEIPT (Domestic Mail Only; No Insurance Coverage Provided) r""I U1 0:0 a- ...a 0:0 0:0 U1 Postage $ Certified Fee U1 Return Receipt Fee C (Endorsement Required) C Restricted Delivery Fee C (Endorsement Required) C ru m c Sent To Total. Postage & Fees $ J. Brock Riddle r""I USiièët;ï!Pt:-ÑÕ.;U Marathon Oil Company C .or PO Box No. ~ ·-ëïiÿ,"siãiã:žip<4- P.O. Box 196168 Anchorage, AK 99519-6168 ~___"P"IIU"I___'" iBDa.~L~ÞI.II~'iI.r"ilr...¡ :F FOR INQUIRIES CONTACT LOCATION WHERE INVOICES WERE SUBMITTED 1031548 10-20-03 2006883 10-20-03 DRTL'LPERMITM16ÖCT03 10082216 100.00 100.00 e RECE'\ED OCT 2 02103 0·, & Gas Cons. Commission Alaska I Anchorag! FORM 4-2B 181 (REV. 11-95) PRINTED IN U.S.A. DETACH STUB BEFORE DEPOSITING CHECK 100.00 100.00 Union Oil Company of California Accounts Payable Field Disbursing 2006883 UNOCALe Pay On:e'Hundred Dollars And OOCen:ts************************************************************ e Check Amount *******100.00 ~ M"~l;:r~ II' 200 baa :'11' -:0:'. .00 20 c¡-: :. ~ ¡. ¡. a ¡. :. ? II' e e TRANSM1T AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~~ {~ /I/(r / ¡; ~ PTD# ;LD 3-- /?J 2- CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API num ber last two (2) digits are between 60-69) "CLUE" Tbe permit is for a new wellbore segment of existing well ~ Permit No, API No. Production sbould continue to be reported as a function· of tbe original API number. stated above. BOLE In accordance witb 20 AAC 25.005(1), all records, data and logs acquired for tbe pilot bole must be clearly differentiated in botb· name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION / DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates Tbe permit is approved subject to full compliance witb 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order appr~rïDg a spacing exception. ¿(;¿DC t:t.kJ (Companv Name) assumes tbe liability of any protest to tbe spacing . exception tbat may occur. All dry ditcb sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from wbere samples are first caught and 10' sample intervals through target zones. iii:!!t]';~:'j!n~~~ Field & Pool MCARTHUR RIVER, MIDKENAI GAS - 520550 Administration Well Name: TRADING BAY UNIT M-16RD PTD#:2031820 Company UNION OIL CO OF CALIFORNIA Initial ClasslType SER I PEND GeoArea 820 Unit 12070 1 pß(rTJitfee <lttache.d. . . . . . . . . . . . . . . . . . . . . . . _ _ _ _ _ _ _ . Yßs. _ _ . . . . . . . 2 Le<lsßnumberappropriale_ _ _ _ _ . . _ . . _ . . . . . . . . . . . . . . . _ _ _ . _ Yes _ _ _ _ _ . . . . . . . . . . . 3 .U.ntque well_I'Jamß.and ou.rTJb.e( _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ . . Yßs. _ _ _ _ _ _ _ _ _ _ _ _ . . _ . _ _ . 4 Well Jocatßd tnadefine.d.)Jool _ _ . _ . . . . . . . . . . . . . . . . . . . . . _ . . _ _ Yßs _ _ Mi.ddle Kenai Gas F?ool <ls.define.din CO 228.Q2. _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . . . . . . . 5 Well Jocatßd proper_dtstance_fromdriJling uniLboundar:y. . . . . . _ _ ..... _ . _ _ _ YßS _ _ _ _ . _ . . . . . . . . . . . . _ 6 Well Jocatßd proper.dtstance.from other wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _. _ _ Yßs..... 10.-acredriJlingunitsper_CQ22.8,_ 7S_utficient acreag.eayailable tn_drilJiog. u.nit. . . . . . . . . . . . . . . . . . . . . _ _ _ _ _ _ _ _ Yßs _ _ _ . _ . _ _ . . . . . . . . . . . . . _ . . . . 8 Jfdßyiated, is_ weJlbore platjnclu.ded _ . _ _ _ . . . . . . . . . . . . _ . . _ . _ _ _ _ _ _ _ . . . . _ _ YßS _ _ _ _ _ _ _ _ _ . _ . . . . . . . . . . . . . . . . . . . 90.)Jerator onl}' affected party _ . _ . . . . . . . . . . . . . . _ . . . . . . . . _ . . . _ _ _ _ _ Yßs _ _ . . . . . . . . . . . . . . . . . . . 10 .Qper.ator bas.approprtate_b.ond tnforœ _ _ _ _ . _ _ .... _ .. ... _ . . . . . . . . . Yßs . _ _ _ _ _ _ _ . _ _ . . . . . . . . . . . . . . . . . . . . _ . . . . . 11 Pß(rTJil can be tssu.ed without co_nserva.tion order. . . . . . . . . . . . . _ . _ _ _ _ _ _ _ _ _ Y ßS . . _ . . . . . . . . . . . . . . . . . _ . . . _ . . . . . . . . . Appr Date 12 Pß(rTJilcao be tssu.ed without <ld.rTJinist(ative_approyaJ _ _ . . . _ No. . . .. .. Text fOO~,drTJinist(ative_App(oYal is_aJtachßd.. _ . _ _ _ . . . . . . . . . . . . . . . . . . . . . _ SFD 10/27/2003 13 .C.ao permit.be approved before .15-day. wait. _ . Yes. . . . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . _ .. _.. _ _ . . . . . . . . . . . . . . . . . . . . . . . . 14 Well Jocatßd wtthin area and.strata authorlzed by.lojectioo Ordß( # (putlO# in commßots) (For NA .. _ . . . . . . . . . _ _ _ . _ . _ _ . . . . . . . . . . . . . . . . . . . . . . _ . 15 _All welJs.Withir1.1l4.mile.area.of (eyiew idßottfied (Fo(service.w.ell on I}'). . _ _ . . . . . . NA . _ _ _ _ _ _ _ _ . . . . . . _ _ _ . . . . _ . . . . . . _ _ . _ . . . . . . . . . . . . . . . . . . _ 16 Pre-produced iojector; .duration.of pre-.)Jro.duction IßSs. than. 3 months. (For service well only) _ NA _ . . . . . . . . . . . . . . . . _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . . . . . . . . . . . . . . . . . . . . . . 17 .ACMP. Fjnding.of COI'Jsi;;lency.has been issued forJbis proiect _ _ _ . . . . . . . . . . NA . _ _ Be-drilLof exjsJiog well. . . . . . . . . . _ . . . . . . . _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ . 18 .C.oodu.clor st(ing.provided . _ . . . . . _ Yßs . . Con.ductor in placß, sidetrack.of existiog well, _ _ _ . . _ . _ . . . . . . . . . . . . . . . . . . . . . _ _ . . 19 .S.ul1acß .casing. protects all known USDWs _ _ _ _ _ . . . . . . . . . . . . . _ . . . . _ _.. NA . _ 81l aqu~eJS eXßmptßd 40 CfB 147.. t021b)(3)(iv) . 20 _CMTvoLadeQu.ateJo circulate_on cond_uctor.&surfcsg .............. _ _ _ _ _ _ _ NA _ _ _Casin.ginplace,sidetrack.ofexistiOgWelt. ...... 21 .CMTvoladeQu.ateJotie-inJong_stringto_sur:fcsg_ _......... _ _ _ .. Yßs _ _ _ _ _F?lannßdcemenltopisJnsidß.the.casiog...... ... _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _.. 22 _CMTwill coyeralll<oown.)Jro.ductiye borilons. . . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ YßS. . . . . . . . . . . . _ _ _ . . _ . . _ . . . . . . . . . . . . . . . . . . 23 Casing desigos ad.eç¡ua.te fO( C,.T, B.&.permafrost . _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ . . . Yßs. . . _ . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . 24 A.dequale_tankage_or reserve pit _ _ . . . . _ _ . . . . . . . . . . . . . . . . . . . . _ _ _ _ _ _ _ _ _ YßS _ _ _ _ _ . Big 00 existing platform,.e.quippe.d.with stßeLpits. _ No reseNepjt.)Jlanoed. Wa_stediscbarge.dpe( NF'DES.. . . . . . 25 Jfa.re-d(ilt has.a. tOA03 for abandonment beßO approved _ _ _ _ _ _ . _ . . . . Yßs _ . . _ 30_3-2B6 pr.eviou.sly.approye.d, . . . . . _ _ _ . . . . . . . . . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . 26 _A.dequalewellboreseparation.)Jro.)JO$.e.d............ . . . . . . _ . _ _ _ _ _ _ _ _ _ _ Yßs. . . . . . . F?ro~imit}'.analysis perfO(rTJe_d. Nearb}'wellbores identified, Gyro;;pO$.sib!e, _ . . .. ................. 27 Jf.diverterrequired,doesitmeelreguJa.tions...... _ . _.. NA... _.. ..Sidet(ackpe_rfor.med.belowsurfaceca.sing..BOPstack.willbeused......................_ Appr Date 28 _Drilliogfluid.PJogramschematic.&.equiplistadequale_ _ _ _... Yßs...... . Maximu.meX.)Jectedfor:mationpressul"e.8.5.EMW._ MWplanned9.2~9.4ppg............... TEM 10/27/2003 29 S.DPEs,.do.they meelreguJation _ . . _ _ . . . . . . . . . . . . . . . . . . . . _ _ _ _ _ Yßs _ _ _ _ . . . . . . . . . . . . . . . . . . . ~ 30 S.DPE-Pfess raJiog ap.)Jrop(iate;.testto.(pu.t psig in.comments) _ _ _ _ _ _ _ _ _ _ _ . _ . . . Yßs. . . . . . . M8SF' calculated at 390p;;i, _Suodry approved with. 3000 psi teslreQujrement.. . . . . . . . . _ 31 _C.hoke.manifold cOrTJpJies wIAPLRF'-53 (May 84) . _ _ _ . _ _ . _ _ _ _. _ _ _ . . . Yßs . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ . . . . . . . . . . . _ . . _ . . _ . . . . . . . . . . . . . . . _ . _ . 32 Work will oçCU( withoutoperation .shu.tdown. _ _ _ _ _ _ Yßs . . . _ _ _ _ _ _ _ _ _ . . . . . . . . . . . . . . . . . . _ _ . . . . . _ . . . . . . _ . 33 Is presence. of H2S gas. prob.able _ . _ _ _ . . . . . _ . No _ _ . . _ . . . . . . . . . . . . . . . 34 MecbantcaLcoodition of wells wiJhin 80B verified (for.se(Vice welJ onJy) _ _ _ _ _ _ _ _ _ _ _ . . NA . . . . . . . . . . . . . _ _ _ _ _ _ _ _ _ _ _ . . _ _ . . _ _ . . _ . . . . _ . . . . . . . . . . . . . . . . . . . . . . . Program SER OnlOff Shore Off Well bore seg Annular Disposal o o - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - e Engineering - - - - - - - - - - - - - - - - e - - - - - - - - - - - - - - -- - - - - -- Appr SFD 35 36 Date 37 10/27/2003 38 39 PßlJ1)it. cao be tssu.ed w/Q hydr.ogen. s.ulfide meaSu(es _ . . . . . . . . . _ . . _ _ _ . . .Y ßS . . . . . . . . . . _ _ . _ _ _ _ _ . . . . . . _ _ . _ . _ . . . . . . . . . . . . . . . . . . . . . . . .D.ata.preseoted on. pote.ntial overpres.sure .zones _ _ _ _ . . . _ _ . _ . . _ . . . . _ . . . . . . YßS . . . . _ EX.)Jected reservoir .)Jre;;suJe is Æ,7.-. 8.6 ppg.MMW; will be drUled with.9.2 -_ 9.3 PP-9.rTJu_d, _ _ _ _ . _ . . _ _ Sßi;;micanalysis of shaJlow gas.zooes. . . . . . . . . . . . . . . . . _ . NA . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . .Seabed .conditioo survey (if off-shoœ). .... _. _...... _ . . . . . . . . . . . . NA . . . _ _ _ . . . . . . . . . . . . . . . . . . . . . . . . . _ . _ . . . . . . . . . . . . . _ Conta_ct namelphoneJorweekly progress. reports [explorator:y _only] _ _ . . . . _ _ _ NA _ . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . Date: Engineering Date C PU?Ii~ ~ ,~.../ TEXT FOR ADMINISTRATIVE APPROVAL REGARDING SPACING EXCEPTION IS ATTACHED. Commissioner: ommlSSloner u/ /~_~ ry IO/¿ o/"(? ~. ~ L-, /qI~~3 Geology Geologic Commissioner: DTs